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Home My WebLink About191-1331. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,560 11,444 Casing Collapse Conductor Conductor Conductor Surface 1,540psi Production 7,950psi Liner 10,780psi Liner 10,780psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Eric Dickerman Contact Email:Eric.Dickerman@hilcorp.com Contact Phone:(907) 564-4061 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng CO 76B 229' 33" 229' 229' Granite Point Hemlock Undef Oil, Middle Kenai Oil Same 11,407 Subsequent Form Required: Suspension Expiration Date: 10,900psi 3,090psi 683' Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Length Size AOGCC USE ONLY 12,460psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018761 191-133 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20026-01-00 Hilcorp Alaska, LLC Granite Pt St 11-13RD L-80 TVD Burst 8,457 12,460psi MD 11,407'7" 11,560' Proposed Pools: 294' 294' 11,451 10,809 2,910psi N/A 10,060' 4,018' 3,993' 9,960' 684' 4,018' 8,546 - 11,377 1,773' 5.919" 8,464 - 11,232 294' 26" 18" 13-3/8" 684' 9-5/8" Other: Tubing Patch 12/9/2025 11,451'473' 2-7/8" 11,303' See Schematic See Schematic Perforation Depth MD (ft): 10,060' No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.11.24 14:48:51 - 09'00' Dan Marlowe (1267) 325-725 By Grace Christianson at 3:03 pm, Nov 24, 2025 DSR-11/24/25TS 11/25/25 MGR28NOV25 10-404 11/28/25 GPF GP 11-13RD Add Perf Revision 1 Page 1 of 2 Well Name:Granite Pt St 11-13RD API Number:50-733-20026-01 Current Status:Online Permit to Drill Number:191-133 Estimated Start Date:December 2025 Rig:Eline/Slickline Regulatory Contact:Juanita Lovett Estimated Duration:3 days First Call Engineer:Eric Dickerman Cell Number:307-250-4013 Second Call Engineer:Casey Morse Cell Number:603-205-3780 Current Bottom Hole Pressure:4,000 psi at 10,904 TVD. Nodal analysis from 6/05/2025 flowing bottomhole pressure survey. MPSP:2,910 psi (Based on 0.1 psi/ft. gas gradient) Last Shut-in WHP:400 psi Min. ID:2.313 2-7/8 X nipple,with patch installed Min. ID will be 0.925 Max. Deviation:18.98 degrees at 10,900 md Pools:Granite Point Hemlock Oil Pool and Granite Point Middle Kenai Oil Pool Brief Well Summary: Granite Point State 11-13RD is an oil well that was drilled and completed March 1992 in the Granite Point Hemlock Oil Pool. The well was worked over in October 1995 to replace the tubing. A fracture stimulation was performed on the Hemlock formation in Q4 2013 placing ~47k# of proppant into formation. In July 2015, the well was worked over again to perforate the Granite Point Middle Kenai Oil Pool in the Tyonek C5 C12 sands. A portion of the target perf intervals was shot from 8/29/25 8/30/25 with no change in production rates. Started troubleshooting the gas lift design to make sure it was optimized but found the well was lifting from the unloading valve in gas lift mandrel 2 at 4,158 md. Replaced the unloading valve at 4,158 but the lift point did not move downhole. Stacked out the tubing and IA with lift gas, then bled the IA down. The tubing tracked indicating T x IA communication. Confirmed that a majority of the lift gas is entering the tubing at 4,158 on 11/6/25 with a pressure/temperature survey. Set patch across gas lift mandrel 2 on 11/8/25. The patch allowed the well to unload. Additional gas lift troubleshooting indicates production rates can increase with a new gas lift design. Objective: Eline add perforations in the Granite Point Middle Kenai Oil Pool.Replace Gas Lift Valves and set a tubing patch over Gas Lift Mandrel 2. Eline:COMPLETE 1. MIRU Eline on GP11-13RD, Leg #3. 2. Pressure test PCE to 250 psi low / 3,500 psi high. 3. Perforate the target Tyonek C sand intervals between a top at 8,496 md / 8,414 TVD and a bottom at 8,998 / 8,912 TVD. GPF GP 11-13RD Add Perf Revision 1 Page 2 of 2 a. All perforations in Granite Point Middle Kenai Oil Pool. b. All runs will be fully lubricated. 4. RDMO Eline. Slickline: 5. MIRU Slickline on GP11-13RD, Leg #3. 6. Pressure test PCE to 250 psi low / 3,500 psi high. 7. Pull the patch set for diagnostics across Gas Lift Mandrel 2 from 4,141 4,186. 8. Replace gas lift valves in gas lift mandrels 3, 4, 5, and 6. 9. Replace patch across Gas Lift Mandrel 2 from ±4,141 to ±4,186. 10. Stack tubing and IA out with lift gas, then perform a drawdown test on the patch by bleeding off IA pressure to ± 100 psi. a. Gas lift supply pressure on the platform is 1,000 psi. b. ID of the patch is 0.925. 11. RDMO Slickline. Attachments: 1. Current/Proposed Wellbore Schematic (Same) Updated by: JLL 11/24/25 Granite PointPlatform Well #: GP 11-13RD Completed: 07/10/2015 PTD: 191-133 API: 50-733-20026-01 SCHEMATIC TD =11,560ft PBTD @ 11,451ft RKB to MSL 114.75 RKB to Mudline = 189.75 1 2 3 4 5 6 X 18 13-3/8 9-5/8 7 26 33 Exp-Liner 10,978 to 11,451 7 Tubing tail cut @ 10,835 on 8/9/2015 7 Fish (x-nipple & WLEG) 11,444 DV Collar @ 2,265 TOC @ 6,150 TOC @ Hanger CASING DETAIL Size (in) WT (lb/ft) Grade Conn ID (in) Top (ft) Btm (ft) 33 Outside Driven Conductor Welded Surf 229 26 Inside Driven Conductor Welded Surf 294 18 79.59 B Ventura Surf 684 13-3/8 61.0 J-55 8 round 12.515 Surf 4,018 9-5/8 47 N-80 Butt 8.681 Surf 6,773 9-5/8 53.5 P-110 Butt 8.535 6,773 10,060 7 32 P-110 Butt TKC 6.094 9,787 11,560 5.919 32 Exp. Liner GII 5.271 10,978 11,451 TUBING DETAIL 2-7/8 6.5# L-80 8rd EUE 2.441 Surf 8,457 JEWELRY No Depth (MD) Depth (TVD)ID OD Item 42.50 Tubing Hanger 1 330 330 2.313 4.610 SCSSV Superior BTE-5 2 4,141 4,112 0.925 2.875 Tubing Patch (4,141 4,186) 3 8,414 8,333 2.441 4.750 Chemical Injection Sub SFO-iCI 4 8,434 8,353 4.000 8.250 9-5/8 DLH Hydraulic Retrievable Packer 5 8,449 8,368 2.313 3.668 X-Nipple 6 8,457 8,376 2.441 3.700 WL Re-Entry Guide 7 10,830 10,712 3.250 Model D Permanent Packer Zone Top (MD) Btm(MD) Top (TVD) Btm(TVD) Amt Date C-5A Lwr 8,546' 8,586' 8,464 8,504 40 08/30/25 C6A 8,648' 8,686' 8,565' 8,603' 38' 8/30/25 C6B 8,721' 8,738' 8,637' 8,654' 17' 07/03/15 C7A 8,877' 8,901' 8,792' 8,816' 24' 07/03/15 C7C 8,919' 8,998' 8,833' 8,911' 79' 8/29/25-8/30/25 C7C 9,013' 9,040' 8,926' 8,953' 27' 07/03/15 C8D 9,306' 9,331' 9,216' 9,241' 25' 07/03/15 C9A 9,439' 9,466' 9,348' 9,374' 27' 07/03/15 C9A 9,475' 9,485' 9,383' 9,393' 10' 07/03/15 C9B 9,578' 9,591' 9,485' 9,498' 13' 07/03/15 C9B 9,610' 9,635' 9,516' 9,541' 25' 07/03/15 C9C 9,711' 9,720' 9,616' 9,625' 9' 07/03/15 C9C 9,744' 9,756' 9,649' 9,661' 12' 07/03/15 C9C 9,786' 9,797' 9,690' 9,701' 11' 07/03/15 C9D 9,836' 9,855' 9,740' 9,758' 19' 07/03/15 C9D 9,945' 9,989' 9,847' 9,891' 44' 07/03/15 C9D 10,188' 10,195' 10,088' 10,095' 7' 07/03/15 C9D 10,211' 10,228' 10,111' 10,128' 17' 07/03/15 C10 10,319' 10,327' 10,218' 10,226' 8' 07/03/15 C11 10,626' 10,655' 10,517' 10,545' 29' 07/03/15 C12 10,732' 10,750' 10,619' 10,636' 18' 07/03/15 C12 10,802' 10,807' 10,686' 10,690' 5' 07/03/15 Hemlock 11,032 11,220 10,904 11,083 188 3/12/1992 11,032 11,102 10,904 10,970 70 2/12/2011 11,245 11,377 11,106 11,232 132 3/12/1992 11,205 11,215 11,068 11,077 120 11/16/2013 11,205 11,215 11,068 11,077 60 11/27/2013 11,032 11,377 10,904 11,232 345 06/02/14 06/29/14 GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,304 2,302 2.441 SFO-1 10 DOME 1098 7/10/2015 2 4,158 4,129 2.441 SFO-1 10 DOME 1074 11/05/2025 3 5,700 5,647 2.441 SFO-1 DOME Future 4 6,868 6,803 2.441 SFO-1 DOME Future 5 7,726 7,652 2.441 SFO-1 DOME Future 6 8,334 8,254 2.441 SFO-1 ORIFICE Future Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 09/12/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250912 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 8/28/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/19/2025 AK E-LINE CIBP BRU 224-34T 50283202050000 225044 8/17/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/22/2025 AK E-LINE Perf BRU 224-34T 50283202050000 225044 8/27/2025 AK E-LINE Perf BRU 241-23 50283201910000 223061 8/20/2025 AK E-LINE Plug/Perf GP 11-13RD 50733200260100 191133 8/29/2025 AK E-LINE Perf KALOTSA 6 50133206850000 219114 8/14/2025 AK E-LINE PPROF MGS ST 17595 06 50733100730000 166003 8/19/2025 AK E-LINE Drift MGS ST 17595 06 50733100730000 166003 8/26/2025 AK E-LINE Drift MGS ST 17595 11 50733200130000 167017 8/17/2025 AK E-LINE CBL MGS ST 17595 20 50733203770000 185135 8/21/2025 AK E-LINE CBL MPI 1-61 50029225200000 194142 8/19/2025 AK E-LINE Patch NCIU A-21A 50883201990100 225075 8/23/2025 AK E-LINE Perf END 1-23 50029225100000 194128 7/14/2025 HALLIBURTON MFC40 END 2-74 50029237850000 224024 7/12/2025 HALLIBURTON MFC40 END 3-07A 50029219110100 198147 7/13/2005 HALLIBURTON COILFLAG END 3-15 50029217510000 187094 7/15/2025 HALLIBURTON MFC24 NS-20 50029231180000 202188 9/2/2025 HALLIBURTON COILFLAG PBU 01-13A 50029202700100 225052 8/18/2025 HALLIBURTON RBT-COILFLAG PBU 07-24A 50029209450100 225045 8/3/2025 HALLIBURTON RBT-COILFLAG PBU C-34C 50029217850300 225068 8/25/2025 HALLIBURTON RBT SD-07 50133205940000 211050 8/14/2025 HALLIBURTON TMD3D ODSK-14 50703206100000 209155 9/8/2025 READ CaliperSurvey Please include current contact information if different from above. T40874 T40875 T40875 T40875 T40875 T40876 T40877 T40878 T40879 T40879 T40880 T40881 T40882 T40883 T40884 T40885 T40886 T40887 T40888 T40889 T40890 T40891 T40892 T40893 GP 11-13RD 50733200260100 191133 8/29/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.12 14:33:03 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 08/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250807 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 23 50133206350000 214093 6/26/2025 AK E-LINE PPROF T40741 BCU 25 50133206440000 214132 7/16/2025 AK E-LINE Plug/Cement T40742 BRU 211-35 50283201890000 223050 6/11/2025 AK E-LINE Perf T40743 BRU 211-35 50283201890000 223050 6/20/2025 AK E-LINE PPROF T40743 BRU 213-26 50283201920000 223069 7/7/2025 AK E-LINE Perf T40744 BRU 213-26T 50283202040000 225038 7/2/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 7/4/2025 AK E-LINE Perf T40745 BRU 213-26T 50283202040000 225038 6/28/2025 AK E-LINE Perf T40745 BRU 241-23 50283201910000 223061 7/18/2025 AK E-LINE Perf T40746 GP 11-13RD 50733200260100 191133 6/2/2025 AK E-LINE PPFROF T40747 KBU 32-06 50133206580000 216137 7/1/2025 AK E-LINE PPROF T40748 MPU E-28 50029232590000 202055 5/8/2025 AK E-LINE Caliper T40749 MPU F-21 50029226940000 196135 7/10/2025 AK E-LINE Caliper T40750 MPU G-02 50029219260000 189028 7/6/2025 AK E-LINE Puncher T40751 MPU I-01 50029220650000 190090 7/7/2025 AK E-LINE TubingPunch T40752 NS-19 50029231220000 202207 6/27/2025 AK E-LINE Perf T40753 PBU J-07C 50029202410300 225026 5/29/2025 BAKER MRPM T40754 PBU N-07B 50029201370200 223122 6/7/2025 BAKER MRPM T40755 PCU-05 50283202030000 225037 7/10/2024 AK E-LINE Perf T40756 TBU D-07RD2 50733201170200 192155 7/19/2025 AK E-LINE Perf T40757 TBU M-09 50733204760000 196127 7/18/2025 AK E-LINE Perf T40758 Please include current contact information if different from above. T40747GP 11-13RD 50733200260100 191133 6/2/2025 AK E-LINE PPFROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.08.08 11:16:55 -08'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,560 11,444 Casing Collapse Conductor Conductor Conductor Surface 1,540psi Production 7,950psi Liner 10,780psi Liner 10,780psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Eric Dickerman Contact Email:Eric.Dickerman@hilcorp.com Contact Phone:(907) 564-4061 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng CO 76B 229' 33" 229' 229' Granite Point Hemlock Undef Oil, Middle Kenai Oil Same 11,407 11,451 10,809 2,910psi N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 12,460psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018761 191-133 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20026-01-00 Hilcorp Alaska, LLC Granite Pt St 11-13RD Length Size Proposed Pools: 294' 294' L-80 TVD Burst 8,457 12,460psi MD 10,900psi 3,090psi 683' 3,993' 9,960' 684' 4,018' 11,407'7" 294' 26" 18" 13-3/8" 684' 9-5/8"10,060' 4,018' 11,560' Perforation Depth MD (ft): 10,060' 8,553 - 11,377 1,773' 5.919" 8,471 - 11,232 8/15/2025 11,451'473' 2-7/8" 11,303' See Schematic See Schematic No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:37 pm, Jul 18, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.07.18 15:10:24 - 08'00' Dan Marlowe (1267) 325-428 A.Dewhurst 05AUG25 DSR-7/18/25MGR22JUL25 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.08.06 08:25:57 -08'00'08/06/25 RBDMS JSB 080725 GPF GP 11-13RD Add Perf Page 1 of 2 Well Name:Granite Pt St 11-13RD API Number:50-733-20026-01 Current Status:Online Permit to Drill Number:191-133 Estimated Start Date:8/15/2025 Rig:Eline Regulatory Contact:Juanita Lovett Estimated Duration:1 day First Call Engineer:Eric Dickerman Cell Number:307-250-4013 Second Call Engineer:Casey Morse Cell Number:603-205-3780 Current Bottom Hole Pressure:4,000 psi at 10,904’ TVD. Nodal analysis from 6/05/2025 flowing bottomhole pressure survey. MPSP:2,910 psi (Based on 0.1 psi/ft. gas gradient) Last Shut-in WHP:400 psi Min. ID:2.313’’ – 2-7/8” X nipple Max. Deviation:18.98϶ at 10,900’ md Pools:Granite Point Hemlock Oil Pool and Granite Point Middle Kenai Oil Pool Brief Well Summary: Granite Point State 11-13RD is an oil well that was drilled and completed March 1992 in the Granite Point Hemlock Oil Pool. The well was worked over in October 1995 to replace the tubing. A fracture stimulation was performed on the Hemlock formation in Q4 2013 placing ~47k# of proppant into formation. In July 2015, the well was worked over again to perforate the Granite Point Middle Kenai Oil Pool in the Tyonek C5 – C12 sands. Objective: Eline add perforations in the Granite Point Middle Kenai Oil Pool. GPF GP 11-13RD Add Perf Page 2 of 2 Eline: 1. MIRU Eline on GP11-13RD, Leg #3. 2. Pressure test PCE to 250 psi low / 3,500 psi high. 3. Perforate the target Tyonek C sand intervals between a top at 8,496’ md / 8,414’ TVD and a bottom at 8,998’ / 8,912’ TVD. a. All perforations in Granite Point Middle Kenai Oil Pool. b. All runs will be fully lubricated. 4. RDMO Eline. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated by: JLL 01/13/2023 Granite PointPlatform Well #: GP 11-13RD Completed: 07/10/2015 PTD: 191-133 API: 50-733-20026-01 SCHEMATIC TD =11,560ft PBTD @ 11,451ft RKB to MSL 114.75’ RKB to Mudline = 189.75’ 1 2 3 4 5 X 18” 13-3/8” 9-5/8” 7” 26” 33” Exp-Liner 10,978’ to 11,451’ 6 Tubing tail cut @ 10,835’ on 8/9/2015 7’ Fish (x-nipple & WLEG) 11,444’ DV Collar @ 2,265’ TOC @ 6,150’ TOC @ Hanger CASING DETAIL Size (in) WT (lb/ft) Grade Conn ID (in) Top (ft) Btm (ft) 33” Outside Driven Conductor Welded Surf 229’ 26” Inside Driven Conductor Welded Surf 294’ 18 79.59 B Ventura Surf 684 13-3/8 61.0 J-55 8 round 12.515 Surf 4,018 9-5/8 47 N-80 Butt 8.681 Surf 6,773 9-5/8 53.5 P-110 Butt 8.535 6,773 10,060 7 32 P-110 Butt TKC 6.094 9,787 11,560 5.919 32 Exp. Liner GII 5.271 10,978 11,451 TUBING DETAIL 2-7/8 6.5# L-80 8rd EUE 2.441 Surf 8,457’ JEWELRY No Depth (MD) Depth (TVD)ID OD Item 42.50’ Tubing Hanger 1 330’ 330’ 2.313 4.610 SCSSV – Superior BTE-5 2 8,414’ 8,333’ 2.441 4.750 Chemical Injection Sub – SFO-iCI 3 8,434’ 8,353’ 4.000 8.250 9-5/8” DLH Hydraulic Retrievable Packer 4 8,449’ 8,368’ 2.313 3.668 X-Nipple 5 8,457’ 8,376’ 2.441 3.700 WL Re-Entry Guide 6 10,830’ 10,712’ 3.250 Model D Permanent Packer PERFORATIONS Zone Top (MD) Btm(MD) Top (TVD) Btm(TVD) Amt SPF Date C-5A Lower 8,553' 8,585' 8,471' 8,503' 32' 5 07/03/15 C6 8,648' 8,685' 8,565' 8,602' 37' 5 07/03/15 C6B 8,721' 8,738' 8,637' 8,654' 17' 5 07/03/15 C7A 8,877' 8,901' 8,792' 8,816' 24' 5 07/03/15 C7B 8,919' 8,997' 8,833' 8,911' 78' 5 07/03/15 C7C 9,013' 9,040' 8,926' 8,953' 27' 5 07/03/15 C8D 9,306' 9,331' 9,216' 9,241' 25' 5 07/03/15 C9A 9,439' 9,466' 9,348' 9,374' 27' 5 07/03/15 C9A 9,475' 9,485' 9,383' 9,393' 10' 5 07/03/15 C9B 9,578' 9,591' 9,485' 9,498' 13' 5 07/03/15 C9B 9,610' 9,635' 9,516' 9,541' 25' 5 07/03/15 C9C 9,711' 9,720' 9,616' 9,625' 9' 5 07/03/15 C9C 9,744' 9,756' 9,649' 9,661' 12' 5 07/03/15 C9C 9,786' 9,797' 9,690' 9,701' 11' 5 07/03/15 C9D 9,836' 9,855' 9,740' 9,758' 19' 5 07/03/15 C9D 9,945' 9,989' 9,847' 9,891' 44' 5 07/03/15 C9D 10,188' 10,195' 10,088' 10,095' 7' 5 07/03/15 C9D 10,211' 10,228' 10,111' 10,128' 17' 5 07/03/15 C10 10,319' 10,327' 10,218' 10,226' 8' 5 07/03/15 C11 10,626' 10,655' 10,517' 10,545' 29' 5 07/03/15 C12 10,732' 10,750' 10,619' 10,636' 18' 5 07/03/15 C12 10,802' 10,807' 10,686' 10,690' 5' 5 07/03/15 Hemlock 11,032’ 11,220’ 10,904’ 11,083’ 188’ 8 3/12/1992 11,032’ 11,102’ 10,904’ 10,970’ 70’ 6 2/12/2011 11,245’ 11,377’ 11,106’ 11,232’ 132’ 8 3/12/1992 11,205’ 11,215’ 11,068’ 11,077’ 120’ 12 11/16/2013 11,205’ 11,215’ 11,068’ 11,077’ 60’ 6 11/27/2013 11,032’ 11,377’ 10,904’ 11,232’ 345’ 06/02/14 – 06/29/14 GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,304’ 2,302’ 2.441 SFO-1 10 DOME 1098 7/10/2015 2 4,158’ 4,129’ 2.441 SFO-1 10 DOME 1074 7/10/2015 3 5,700’ 5,647’ 2.441 SFO-1 12 DOME 1043 7/10/2015 4 6,868’ 6,803’ 2.441 SFO-1 12 DOME 1017 7/10/2015 5 7,726’ 7,652’ 2.441 SFO-1 12 DOME 992 7/10/2015 6 8,334’ 8,254’ 2.441 SFO-1 12 ORIFICE 10/18/2015 Updated by: EPD 07/18/2025 Granite PointPlatform Well #: GP 11-13RD Completed: 07/10/2015 PTD: 191-133 API: 50-733-20026-01 PROPOSED TD =11,560ft PBTD @ 11,451ft RKB to MSL 114.75’ RKB to Mudline = 189.75’ 1 2 3 4 5 X 18” 13-3/8” 9-5/8” 7” 26” 33” Exp-Liner 10,978’ to 11,451’ 6 Tubing tail cut @ 10,835’ on 8/9/2015 7’ Fish (x-nipple & WLEG) 11,444’ DV Collar @ 2,265’ TOC @ 6,150’ TOC @ Hanger CASING DETAIL Size (in) WT (lb/ft) Grade Conn ID (in) Top (ft) Btm (ft) 33” Outside Driven Conductor Welded Surf 229’ 26” Inside Driven Conductor Welded Surf 294’ 18 79.59 B Ventura Surf 684 13-3/8 61.0 J-55 8 round 12.515 Surf 4,018 9-5/8 47 N-80 Butt 8.681 Surf 6,773 9-5/8 53.5 P-110 Butt 8.535 6,773 10,060 7 32 P-110 Butt TKC 6.094 9,787 11,560 5.919 32 Exp. Liner GII 5.271 10,978 11,451 TUBING DETAIL 2-7/8 6.5# L-80 8rd EUE 2.441 Surf 8,457’ JEWELRY No Depth (MD) Depth (TVD)ID OD Item 42.50’ Tubing Hanger 1 330’ 330’ 2.313 4.610 SCSSV – Superior BTE-5 2 8,414’ 8,333’ 2.441 4.750 Chemical Injection Sub – SFO-iCI 3 8,434’ 8,353’ 4.000 8.250 9-5/8” DLH Hydraulic Retrievable Packer 4 8,449’ 8,368’ 2.313 3.668 X-Nipple 5 8,457’ 8,376’ 2.441 3.700 WL Re-Entry Guide 6 10,830’ 10,712’ 3.250 Model D Permanent Packer PERFORATIONS Zone Top (MD) Btm(MD) Top (TVD) Btm(TVD) Amt SPF Date 8,496’ 8,998’ 8,414’ 8,912’ Proposed C-5A Lower 8,553' 8,585' 8,471' 8,503' 32' 5 07/03/15 C6 8,648' 8,685' 8,565' 8,602' 37' 5 07/03/15 C6B 8,721' 8,738' 8,637' 8,654' 17' 5 07/03/15 C7A 8,877' 8,901' 8,792' 8,816' 24' 5 07/03/15 C7B 8,919' 8,997' 8,833' 8,911' 78' 5 07/03/15 C7C 9,013' 9,040' 8,926' 8,953' 27' 5 07/03/15 C8D 9,306' 9,331' 9,216' 9,241' 25' 5 07/03/15 C9A 9,439' 9,466' 9,348' 9,374' 27' 5 07/03/15 C9A 9,475' 9,485' 9,383' 9,393' 10' 5 07/03/15 C9B 9,578' 9,591' 9,485' 9,498' 13' 5 07/03/15 C9B 9,610' 9,635' 9,516' 9,541' 25' 5 07/03/15 C9C 9,711' 9,720' 9,616' 9,625' 9' 5 07/03/15 C9C 9,744' 9,756' 9,649' 9,661' 12' 5 07/03/15 C9C 9,786' 9,797' 9,690' 9,701' 11' 5 07/03/15 C9D 9,836' 9,855' 9,740' 9,758' 19' 5 07/03/15 C9D 9,945' 9,989' 9,847' 9,891' 44' 5 07/03/15 C9D 10,188' 10,195' 10,088' 10,095' 7' 5 07/03/15 C9D 10,211' 10,228' 10,111' 10,128' 17' 5 07/03/15 C10 10,319' 10,327' 10,218' 10,226' 8' 5 07/03/15 C11 10,626' 10,655' 10,517' 10,545' 29' 5 07/03/15 C12 10,732' 10,750' 10,619' 10,636' 18' 5 07/03/15 C12 10,802' 10,807' 10,686' 10,690' 5' 5 07/03/15 Hemlock 11,032’ 11,220’ 10,904’ 11,083’ 188’ 8 3/12/1992 11,032’ 11,102’ 10,904’ 10,970’ 70’ 6 2/12/2011 11,245’ 11,377’ 11,106’ 11,232’ 132’ 8 3/12/1992 11,205’ 11,215’ 11,068’ 11,077’ 120’ 12 11/16/2013 11,205’ 11,215’ 11,068’ 11,077’ 60’ 6 11/27/2013 11,032’ 11,377’ 10,904’ 11,232’ 345’ 06/02/14 – 06/29/14 GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,304’ 2,302’ 2.441 SFO-1 10 DOME 1098 7/10/2015 2 4,158’ 4,129’ 2.441 SFO-1 10 DOME 1074 7/10/2015 3 5,700’ 5,647’ 2.441 SFO-1 12 DOME 1043 7/10/2015 4 6,868’ 6,803’ 2.441 SFO-1 12 DOME 1017 7/10/2015 5 7,726’ 7,652’ 2.441 SFO-1 12 DOME 992 7/10/2015 6 8,334’ 8,254’ 2.441 SFO-1 12 ORIFICE 10/18/2015 STATE OF ALASKA AL,_..A OIL AND GAS CONSERVATION COME. JION 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 Cl Plug for Redrill Cl Perforate New Pool❑ Repair Well ❑ Re-enter Susp WeLl Other: Cut Tubing Tail E] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development CI Exploratory El 191-133 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic0 Service❑ 6.API Number: Anchorage,AK 99503 50-733-20026-01 7.Property Designation(Lease Number): 8.Well Name and Number ADL0018761 Granite Pt St#11-13RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Granite Point Field/Hemlock Undefined Oil&Middle Kenai Oil Pools 11.Present Well Condition Summary: Total Depth measured ( 11,560 feet Plugs measured N/A fee%EC E1 V E r true vertical , 11,407 feet Junk measured 11,444 feet AUG 31 2015 Effective Depth measured 11,451 feet Packer measured 8,434&10,830 feet true vertical 10,809 feet true vertical 8,353&10,712 feet eOGCC Casing Length Size MD TVD Burst Collapse Structural Conductor 684' 18" 684' 683' Surface 4,018' 13-3/8" 4,018' 3,993' 3,090 psi 1,540 psi Production 10,060' 9-5/8" 10,060' 9,960' 10,900 psi 7,950 psi Liner 1,773' 7" 11,560' 11,407' 12,460 psi 10,780 psi Liner 473' 5.919" 11,451' 11,303' 12,460 psi 10,780 psi Perforation depth Measured depth See Schematic feet yrs SEP Vertical depth See Schematic feet SCANNED SEP 1 7 1K Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 8,457'(MD) 8,376'(TVD) DHL Hyd. Ret. Packer 8,434'(MD)8,353'(TVD) Packers and SSSV(type,measured and true vertical depth) Model D Perm Packer 10,830'(MD) 10,712'(TVD; SSSV 330'(MD)330'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 40 48 5 840 54 Subsequent to operation: 71 76 75 893 56 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ DevelopmenQ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil , 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ 3USP❑ 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: N/A Contact Ted Kramer Email tkramer anhilcorp.com Printed Name /C Ted Kramer Title Sr.Operations Engineer Signature i v ��'� Phone (907)777-8420 Date 8/31/2015 q_ -1 ( Form 10-404 Revised 5/2015 ' , Submit Original Only �� RBDMSt' 0 1 2015 ' Granite Point Platform SCHEMATIC Well#: GP1113RD Completed: 07/10/2015 mi:• u:..►:..LI.c PTD: 191-133 API: 50-733-20026-01 CASING DETAIL Size(in) WT(Ib/ft) Grade Conn ID(in) Top(ft) Btm(ft) RKB to Hanger=42.5' 18 79.59 B Ventura Surf 684 i . 1 13-3/8 61.0 J-55 8 round 12.515 Surf 4,018 L. 9-5/8 47 N-80 Butt 8.681 Surf 6,773 2 9 5/8 53.5 P-110 Butt 8.535 6,773 10,060 18" 3 7 32 P-110 Butt TKC 6.094 9,787 11,560 5.919 32 Exp.Liner Gil 5.271 10,978 11,451 4 TUBING DETAIL 5 2-7/8 6.54 L-80 8rd EUE 2.441 Surf 8,457' 6 JEWELRY Depth Depth C 7 No (MD) (TVD) ID Item 13-3/8" 1 330' 330' 2.131 SCSSV 8 2 2,304' 2,302' 2.441 GLM 9 3 4,158' 4,129' 2.441 GLM ID 10 4 5,700' 5,647' 2.441 GLM II 11 5 6,868' 6,803' 2.441 GLM _ 6 7,726' 7,652' 2.441 GLM X X 7 8,334' 8,254' 2.441 GLM 8 8,414' 8,333' 2.441 Chemical Injection Sub L - , 9 8,434' 8,353' 4.000 9-5/8"DLH Hydraulic Retrievable Packer 9-5/8" 10 8,449' 8,368' 2.313 X-Nipple 11 8,457' 8,376' 2.441 WL Re-Entry Guide 12 10,830' 10,712' 3.250 Model D Permanent Packer PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date C-5A g 553' 8,585' 8,471' 8,503' 32' 5 07/03/15 Lower C6 8,648' 8,685' 8,565' 8,602' 37' 5 07/03/15 12 >`Ipc C6B 8,721' 8,738' 8,637' 8,654' 1T 5 07/03/15 xp-Liner C7A 8,877' 8,901' 8,792' 8,816' 24' 5 07/03/15 Tubing 10;978'to C7B 8,919' 8,997' 8,833' 8,911' 78' 5 07/03/15 tail cut @ 11,451' 10,835' C7C 9,013' 9,040' 8,926' 8,953' 27' 5 07/03/15 on C8D 9,306' 9,331' 9,216' 9,241' 25' 5 07/03/15 8/9/2015 C9A 9,439' 9,466' 9,348' 9,374' 27' 5 07/03/15 C9A 9,475' 9,485' 9,383' 9,393' 10' 5 07/03/15 - C9B 9,578' 9,591' 9,485' 9,498' 13' 5 07/03/15 C9B 9,610' 9,635' 9,516' 9,541' 25' 5 07/03/15 C9C 9,711' 9,720' 9,616' 9,625' 9' 5 07/03/15 C9C 9,744' 9,756' 9,649' 9,661' 12' 5 07/03/15 C9C 9,786' 9,797' 9,690' 9,701' 11' 5 07/03/15 C9D 9,836' 9,855' 9,740' 9,758' 19' 5 07/03/15 C9D 9,945' 9,989' 9,847' 9,891' 44' 5 07/03/15 7. 7'Fish C9D 10,188' 10,195' 10,088' 10,095' 7' 5 07/03/15 (x-nipple C9D 10,211' 10,228' 10,111' 10,128' 17' 5 07/03/15 &WLEG) C10 10,319' 10,327' 10,218' 10,226' 8' 5 07/03/15 11,444' fr C11 10,626' 10,655' 10,517' 10,545' 29' 5 07/03/15 \ / C12 10,732' 10,750' 10,619' 10,636' 18' 5 07/03/15 C12 10,802' 10,807' 10,686' 10,690' 5' 5 07/03/15 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 7!L 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/2011 TD=11,560ft PBTD @ 11,451ft 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 Hemlock 11,205' 11,215' 11,068' 11,077' 120' 12 11/16/2013 11,205' 11,215' 11,068' 11,077' 60' 6 11/27/2013 11,032' 11,377' 10,904' 11,232' 345' 06/02/14- 06/29/14 Updated by: JLL 08/31/15 • Hilcorp Alaska, LLC Hileorp Alaska,LL(: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St#11-13RD 50-733-20026-01 191-133 8/7/2015 8/9/2015 Daily Operation§r; • , 08/07/2015-Friday Hold PJSM w/operators and Slickline crew.Fill out permits.Assess equipment,rehead line and RU to run CCL depth,determination. PU tools and lubricator and PT to 1500 psi.RIH w/weight bars,centralizer and 1-11/16"CCL.Tag packer(10830').Appears CCL dropped into top of packer about 1'-2'.POOH. OOH.Discussed depth results and decided to run GR/CCL to confirm depth due to discrepancy with slickline depths.RIH w/weight bars,GR/CCL,centralizer and 2.00"magnet.Logged correlation pass and verified packer top(10830').(Made-26'correction).POOH.(Retrieved metallic sand on magnet).OOH.Rig back and rig up slickline to bail. Shut well in for slickline to get bailers downhole,changed tool string to accommodate liner top.Made multiple passes,retrieving rubber and sand. 08/08/2015-Saturday Attend platform safety,operations meeting,permitting.Continue slickline operations,bailing,etc.Slickline determined making 6'-7' of hole in the tailpipe.RU E-line to make depth determination w/CCL. RIH w/centralizer,CCL and 2.00"magnet.Set down on packer with magnet,made attempts to get in w/o success.POOH.OOH.Remove magnet and top centralizer.RIH,Log packer&tailpipe. (Could see packer top&bottom and 4'of 2-7/8"tailpipe).POOH.OOH.Rig back for the night. 08/09/2015-Sunday Attend platform safety,operations meeting,permitting.MU 1-9/16"tubing puncher w/4 shots.(4'-2"CCL to top shot-5'-6"to bottom of gun).RIH while stacking gas in tubing.1000 psi.Tagged top of packer,had difficulty getting gun through.Worked for 30 minutes and fell through.Set gun to perf from 10,836'-37'.Attempted to detonate w/o success.POOH. OOH.MU 2-1/16"Spectra jet cutter.RIH(Weight bar,e-line jar,centralizer,CCL,jet cutter firing head and 2.063"jet cutter). Log packer&tailpipe to confirm depth.Set cutter at 10,835',fire,and drop down to confirm removal of tail pipe.SITP 1150psi.POOH.OOH,RD. STATE OF ALASKA A, JKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate❑ Pull Tubinip Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate❑ Alter CasinCl Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pod CI Repair Well ❑ Re-enter Susp WeO Other: Gas Lift Completion LI 2.Operator 14.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 191-133 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service El 6.API Number: Anchorage,AK 99503 50-733-20026-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018761 Granite Pt St#11-13RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Granite Point Field/Hemlock Undefined Oil&Middle Kenai Oil Pools 11.Present Well Condition Summary: Total Depth measured 11,560 feet Plugs measured N/A CAE EIV{E 0 true vertical 11,407 feet Junk measured N/A feet JUL 2 7 2015 Effective Depth measured 11,451 feet Packer measured 8,434&10,830 feet true vertical 10,809 feet true vertical 8,353&10,712 feet 10 G C C Casing Length Size MD TVD Burst Collapse Structural Conductor 684' 18" 684' 683' Surface 4,018' 13-3/8" 4,018' 3,993' 3,090 psi 1,540 psi Production 10,060' 9-5/8" 10,060' 9,960' 10,900 psi 7,950 psi Liner 1,773' 7" 11,560' 11,407' 12,460 psi 10,780 psi Liner 473' 5.919" 11,451' 11,303' 12,460 psi 10,780 psi Perforation depth Measured depth See Schematic feet rrrr True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 8,457(MD) 8,376'(TVD) DHL Hyd.Ret.Packer 8,434'(MD)8,353'(ND) Packers and SSSV(type,measured and true vertical depth) Model D Perm Packer 10,830'(MD)10,712'(TVD; SSSV 330'(MD)330'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 65 56 94 785 71 Subsequent to operation: 43 25 0 767 57 14.Attachments(required per 20 AAC 25.070.25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory CI DevelopmenEj Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ El 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: 315-335 Contact Ted Kramer Email tkramer©hilcorp.com Printed Name Ted Kramer Title Sr.Operations Engineer Signature � 41. Phone (907)777-8420 Date 7/27/2015 RBDMS(} AUG - 2 2015 7e_ J317—i,.c- Form 10-404 Revised 5/2015Submit Original Only 1 ,�7(/) Granite Point Platform 14 SCHEMATIC Wl #: GP 11-13RD Completed: 07/10/2015 PTD: 191-133 Ililrorn Alaska.I.Lf. API: 50-733-20026-01 CASING DETAIL Size(in) WT(Ib/ft) Grade Conn _ ID(in) Top(ft) Btm(ft) RKB to Hanger=42.5' 18 79.59 B Ventura Surf 684 1 13-3/8 61.0 J-55 8 round 12.515 Surf 4,018 9-5/8 47 N-80 Butt 8.681 Surf 6,773 in [ 2 9-5/8 53.5 P-110 Butt 8.535 6,773 10,060 7 32 P-110 Butt TKC 6.094 9,787 11,560 18" 3 IR 5.919 32 Exp.Liner GII 5.271 10,978 11,451 41111 TUBING DETAIL 5 2-7/8 6.5# L-80 8rd EUE 2.441 Surf 8,457' la 6 JEWELRY Depth Depth L 7 No (MD) (ND) ID Item 13-3/8" 1 330' 330' 2.131 SCSSV 8 2 2,304' 2,302' 2.441 GLM 9 3 4,158' 4,129' 2.441 GLM Et 10 4 5,700' 5,647' 2.441 GLM 11 5 6,868' 6,803' 2.441 GLM _ 6 7,726' 7,652' 2.441 GLM X x 7 8,334' 8,254' 2.441 GLM 8 8,414' 8,333' 2.441 Chemical Injection Sub Li 9 • 8,434' 8,353' 4.000 9-5/8"DLH Hydraulic Retrievable Packer 9-5/8" - 10 8,449' 8,368' 2.313 X-Nipple 11 8,457' 8,376' 2.441 WL Re-Entry Guide 12 10,830' 10,712' 3.250 Model D Permanent Packer - 13 10,842' 10,724' 2.315 X Landing nipple PERFORATIONS Zone Top(MD) _ Btm(MD) Top(ND) Btm(ND) Amt SPF Date C-5A 8,553' 8,585' 8,471' 8,503' 32' 5 07/03/15 Lower C6 8,648' 8,685' 8,565' 8,602' 37' 5 07/03/15 12 ' C6B 8,721' 8,738' 8,637' 8,654' 17' 5 07/03/15 xp-Liner C7A 8,877' 8,901' 8,792' 8,816' 24' 5 07/03/15 13 II 10,978'to C7B 8,919' 8,997' 8,833' 8,911' 78' 5 07/03/15 1 11,451' C7C 9,013' 9,040' 8,926' 8,953' 27' 5 07/03/15 a. C8D 9,306' 9,331' 9,216' 9,241' 25' 5 07/03/15 C9A 9,439' 9,466' 9,348' 9,374' 27' 5 _ 07/03/15 . t C9A 9,475' 9,485' 9,383' 9,393' 10' 5 07/03/15 C9B 9,578' 9,591' 9,485' 9,498' 13' 5 07/03/15 C9B 9,610' 9,635' 9,516' 9,541' 25' 5 07/03/15 C9C 9,711' 9,720' 9,616' 9,625' 9' 5 07/03/15 C9C 9,744' 9,756' 9,649' 9,661' 12' 5 07/03/15 C9C 9,786' 9,797' 9,690' 9,701' 11' 5 07/03/15 C9D 9,836' 9,855' 9,740' 9,758' 19' 5 07/03/15 f: Ag C9D 9,945' 9,989' 9,847' 9,891' 44' 5 07/03/15 C9D 10,188' 10,195' 10,088' 10,095' 7' 5 07/03/15 k = C9D 10,211' 10,228' 10,111' 10,128' 17' 5 07/03/15 C10 10,319' 10,327' 10,218' 10,226' 8' 5 07/03/15 C11 10,626' 10,655' 10,517' 10,545' 29' 5 07/03/15 iii 7 C12 10,732' 10,750' 10,619' 10,636' 18' 5 _ 07/03/15 C12 10,802' 10,807' 10,686' 10,690' 5' 5 07/03/15 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 L ' 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/2011 TD=11,560ft PBTD @ 11,451ft 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 Hemlock 11,205' 11,215' 11,068' 11,077' 120' 12 11/16/2013 11,205' , 11,215' 11,068' 11,077' 60' 6 11/27/2013 11,032' 11,377' 10,904' 11,232' 345' 06/02/14- 06/29/14 Updated by: JLL 07/24/15 Hilcorp Alaska, LLC Hilrorp.tiaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St#11-13RD 50-733-20026-01 191-133 6/24/2015 7/10/2015 Daily Operations:- , 06/24/15-Wednesday Circulated a total of 1100 bbls of FIW at 2 BPM 125#s in reverse send returns to production facility. Stopped circulating and watched well for 30 mins.Installed BPV and left casing open to breath. N/D tree. N/U 13 5/8"x 5k riser,mud cross,dual rams&Hydril. Shut- in casing at 1430 hrs due to high level LEL alarm and flow.Initial shut-in at 30#s,built to 38#in 1 hr and held there. Connect kill and choke lines to mud cross and all accum lines to BOPE-functioned same. Raised and scoped up derrick,attached all guys lines. Positioned driller's shack.Mounted rig floor w/handling tools and McCoy tongs.Installed BOP remote panel and choke panel. Mounted walkways to driller's shack and off-side rig floor.Lined up thru choke to hold 100#s BP while pumping tbg volume. Checked casing pressure, holding at 38#s.No increase in last 11 hrs. Bled dry gas pressure off thru gas buster. Checked BPV and decision was made to load tbg with fresh volume of FIW before pulling. 06/25/15-Thursday Pumped 96 bbls down tbg thru BPV at 2 BPM 0 PSI.Received returns at 40 bbls in-stopped pumping and allowed fluid to equalize. Removed BPV with no issues and installed 2-way check. M/U test jt w/ported sub on btm,pumpin,SV,IBOP on top, screw into hanger and filled stack. Tested BOPE following Moncla 404 test procedure 250#s/low 3500#s high(as per Sundry 315-335)as required by Hilcorp and AOGCC. Test Witness requested 6/23/2105 7:57 AM-witness waived by Mr.Jim Regg 6/23/2015 9:47 AM. Backed out test jt to test blinds and left ported sub in hole.Finished BOPE test. Sucked fluid down as far as possible and separated BOP stack at unihead clamp.Backed out ported sub and reconnected riser to tbg head. Shell tested break to 3500#s. Cameron removed 2-way check and fluid dropped out. M/U landing jt and screwed into hanger. Backed out hold down pins.Cleared floor of personnel and began pulling on string,hanger moved off seat at 72k, at 105k landing jt stripped out of hanger. Called for tool hand and tools to spear into hanger. Laid down IBT landing jt. Performed general housekeeping while waiting on hand and tools by helicopter. P/U 3 1/2"PH6 landing jt w/10'pup&SV. Made up Knight Itco spear w/2.922"grapple and speared into pup below tbg hanger. Picked up to 72k and hanger moved off seat,at 110k pkr released weighting 85k. Pulled hanger to surface.B/O hanger w/ pup&XO.Pressured open SSSV.Shucked spear and B/D Knight tools. N/U 11"5 x 13 5/8"5 spool. Pulled OOH w/production string to SSSV.Released pressure and B/O valve. Continued OOH-1,300'of 10,932'OOH at report time. 06/26/15-Friday POOH w/3 1/2"RTS-8 production string standing back tbg and laying down pups,SSSV,11 mandrels,sliding sleeve,inj sub, pkr, X-nip &re-entry guide. Stopped at 1230 hrs and midnight to circ tbg volume displacing oil. Cleared and cleaned work area. M/U BHA#1(8 3/8"Rock bit,7"scraper f/9 5/8"casing,bit sub,XO)-323'in hole at report time. 06/27/15-Saturday TIH w/BHA#1(8 3/8" x 2 1/4"rock bit, 7"x 2 1/4"casing scraper,6"x 2"bit sub,4 3/4"x 2"XO sub=9.33')on 3 1/2"9.3#RTS-8 tbg strapping doubles in derrick. Checked P/U at stand#156-62k P/U 53K S/O-tagged 25'in+156 stands=9,778'(PM). Circulated 20,000 stks in rev at 2 1/2-3 BPM 300#s PSI. Broke off hose and opened well-both sides static. POOH w/BHA#1 pumping 2 bbls every 10 stands. B/D 9 5/8"cleanout run and M/U 7"cleanout run(BHA#2-6"x 1 1/2"rock bit,5 1/4"x 1 1/2"scraper for 7"casing, 4 3/4"x 1 1/2"bit sub,4 3/4"x 2"XO sub=7.51'). TIH w/BHA#2("'1,260'at report time). 06/28/15-Sunday Continued TIH w/BHA#2(6"x 1 1/2"rock bit,5 1/4"x 1 1/2"casing scraper,4 3/4"x 1 1/2"bit sub,4 3/4"x 2"XO sub)on 3 1/2"9.3# RTS-8 tbg string.Moncla pusher noticed flexing of draw works and shutdown operations.Consulted w/Moncla supervisors and their decision was to chain block in derrick and unbolt/remove draw works in order to repair problem. Secured well and removed draw works.Found broken welds on mounting nuts.Planned fix and called for 2nd welder. Welded and reinforced mount.Installed draw works and unchained block.Tested pulled before CIH. Continued in hole w/6"bit&scraper to 10,629'(all 3 1/2"RTS-8 tbg in hole- we'll pickup enough 3 1/2"PH-6 to reach—10,850'). Hilcorp Alaska, LLC Ilileorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St#11-13RD 50-733-20026-01 191-133 6/24/2015 7/10/2015 Daily Operations: 06/29/15-Monday P/U 7 jts of 3 1/2"PH6 tbg w/XO and TIH to 10,853'. Lined up to pump hole volume plus in reverse. Pumped 820 bbls FIW in rev at 2 1/2 BPM 230 PSI sending returns to Trading Bay Production Facility. POOH w/BHA#2(6"bit&scraper). B/D BHA-cleared floor. Held PJSM w/Pollard EL,crane&rig crews. N/D 13 5/8"x 11"spool and N/U 13 5/8"x 7 1/16"spool f/packoff connector. Hung EL sheaves and M/U Run#1(5.969" gauge ring,#20 junk basket,3 1/8"Gamma Gun,1 3/8"rope socket). TIH to 9,805'and set down- could not get deeper. POOH-B/D tools(nothing in junk basket). M/U Run#2(pump out plug set at 1200-1500 PSI,10'2 7/8"L80 EUE pup,adapter,10'2 7/8"L80 EUE pup,adapter,5.813"Mdl'D'pkr,E4 setting tool w/sleeve,3 1/8"Gamma Gun,1 3/8"RS). TIH 100 ft/min to 10,870'-correlated on depth to Petra DPCL.Logged into position and set pkr top at 10,830'-logged off. POOH&R/D Pollard EL. M/U 2'3 1/2"mule shoe and TIH to displace w/diesel. 40 stands in hole at report time=2,506'. 06/30/15-Tuesday Continued in hole w/3 1/2"RTS-8 mule shoe to 10,838'(PM)and tagged top of pkr lightly. P/U to 1st connection and broke off single. R/U to circ in reverse. Loaded clean active tank with 125 bbls of fuel oil(1st tote). Stood by for MV Resolution to return from Bruce with 2 additional totes of fuel oil. Pumped 750 bbls of diesel fuel oil at 2 BPM 230-1200-130 PSI using 5 additional totes w/125 bbls in each. Opened well and had slight utube on tubing side.Shut-in well with gauges on both sides.Monitored for 30 mins with no pressure build. Opened well to static conditions on both side,fluid level stable at hanger. POOH w/3 1/2"TB+muleshoe. N/D 13 5/8"x 11"spool-M/U 3 1/2"test jt w/plug. 07/01/15-Wednesday Wrong test plug on location, called and lined up blanked test hanger. Cleared and cleaned work area while waiting on blanked hanger. M/U blanked hanger w/ported sub on test jt, pumpin,SV&IBOP on top.Landed same and attempted to fill stack but had returns on casing.Pulled test plug and found seals missing.Installed new seals.Attempted to shell test to 3500#s but had to work thru several leaks. With all leaks repaired we still had a 100#leak in 5 min 3500#test. Called f/Haliburton storm pkr&lined up Pollard S/L. Received a test plug and M/U same on test jt.Landed plug. Attempted to fill stack and got returns on casing.Pulled plug and found that o-rings were missing. Drained stack and removed clamp at tbg head.Picked up riser and lowered test plug in place without seals fully seating in tbg head.Installed new o-rings and visually landed test plug. N/U BOPs and attempted to fill stack with same results,returns on casing. Called for Pollard SL crew&Haliburton tool hand. L/D test jt(o-rings not on plug)and N/D 13 5/8"x 11"spool. N/U 13 5/8"x 7 1/16"spool. Moved TCP racks and spotted SL unit.Cleared and cleaned while waiting on personnel. Received and oriented Pollard&Haliburton personnel. N/U 7 1/16"flange w/WL connector. R/U sheaves&M/U full lubricator, stabbed tool string. M/U to well and tested to 1500#s. 07/02/15-Thursday TIH w/Pollard SL Run#1(2.32"gauge,spang&oil jars,knuckle,10'of 1 1/2"stem,rope socket). Worked thru top of liner and CIH to 10,842'(SLM).POOH,B/O gauge. M/U Run#2(XLine running tool Idd w/PX plug+previous tool string minus gauge). TIH to 10,860' and proceeded to set plug in X-nipple. SL power pack died.Fuel system problem initially then turned into a starter problem. SL operator called for parts.Mechanic on board at 1530 hrs.Replacement power pack on the way at 1600 hrs. Rig crew cleaning and servicing were needed. Mechanic unable to repair power pack. Replacement power pack on board.Connected same and continued attempting to set PX plug in nipple.POOH w/plug still in running tool.Seals measured over size. Redressed tools. TIH w/Run#3 (same as#2 w/redressed running tool&plug)to X-nipple at 10,860'(SLM). Proceeded thru sequence to set plug.POOH to find PX plug still latched in running tool. R/D/R Pollard SL. M/U 3 1/2"test jt w/modified tbg hanger blanked w/2-way check+ported sub, pumpin, V,IBOP on top. Landed test jt and worked pressure up to a successful 3500#shell test,repairing leaks as needed. Tested BOPE as required by Hilcorp and AOGCC to 250#s/low 3500#s/high as specified by Sundry.Tested Annular to 250#s/low 2500#s/high. Performed accumulator draw down test.Presently building 2 7/8"test jt. Hilcorp Alaska, LLC llileorp Alaska,LLC Well Operations Summary Well Name API Number _Well Permit Number Start Date End Date Granite Pt St#11-13RD 50-733-20026-01 191-133 6/24/2015 7/10/2015 Daily Operations: 07/03/15-Friday Finished testing 13 5/8"x 5K BOP stack+safety equipment as per Hilcorp&AOGCC requirements following Moncla 404 test procedure. Tested 250#s/low 3500#s/high.Tested annular 250#s/low 2500#s/high. Witness was waived by Mr.Regg 6/30/15 15:46 hrs. Laid out test jt w/blanked hanger. N/U 13 5/8"x 11"spool. Held PJSM with TriPoint,rig and crane crews,discussing TCP assembling. M/U perforating guns as per perforation request(btm shot 10,807'/top shot 8,553'). 2,254'of 4 1/2"EHC Idd 5 SPF,60 deg phasing,Geo Super DP 39.0 grm RDX chrg. TIH w/TCP assm on drifted 3 1/2"RTS-8 tbg at 1 stnd/min as per TriPoint. Tagged at 10,838(PM)10,830'(correlated). Checked fluid level-hole full. P/U 23'to put guns on depth and M/U SV. Closed Hydril, dropped bar, after 3 mins&5 secs received positive indication of fire.Well went on vacuum.Monitored well f/30 mins.Pumped 10 bbls of diesel prior to starting out. POOH w/TCP assm pulling 1/2 speed until we cleared perfs,pumping 3 bbls every 10 stands. 07/04/15-Saturday Finished POOH to TriPoint TCP assembly. B/D shot TCP assembly.After laying down the 1st few guns there were concerns about diesel containment.Rigged up vac unit. Finished L/D guns.All shots fired. Cleared all TriPoint handling equipment off floor.Cleaned work area. RI 30 stands of 3 1/2"RTS-8 tbg w/mule shoe,staying above fluid level(diesel)at 2000'. Laid out 4 jts at a time in V-door to be moved by crane(no catwalk). 07/05/15-Sunday RIH 25 stands of 3 1/2"RTS-8 tbg at a time, staying above fluid level.Diesel at"'2000'(as checked by production). Laid out 4 jts at a time in V-door to be moved by crane(no catwalk). At 76 jts laid out and 16 jts in hole we saw evidence of fluid rise. Shut-in well and circulated around.Tripped in hole to 3,806'and circulated around again.Ran in all remaining tbg(264 jts)to 8,251'. R/U lines to circ and took gas kick.Shut-in well and monitored pressure-225#s on casing,820#s on tubing. Bled casing to zero. Bled tbg to 80#s (mostly fluid). Circulated LW at 2 bbls/min 0 PSI.Took 30 bbls to get returns.Slowed rate to 1.5 BPM 150 PSI holding 100#s BP. Slowed rate to 1 BPM/250#s of BP when gas hit surface. Once gas was circulated out rate was increased to 2 BPM w/100#s of BP being held. Opened well at 1 1/2 hole volumes pumped with slight flow on tbg.Continued circulating to 2 hole volumes pumped. 07/06/15-Monday Continued circulating down tubing to kill and stabilize well. Stopped pumping and checked f/flow.Slight flow on tbg,would not balance. Circulated another full hole volume.Stopped pumping and flow on tbg was worse.Pumped 20 bbls clean#2 diesel down tbg with some reduction in flow.Pumped 2nd 20 bbls down tbg with more reduction in flow.Pumped 3rd 20 bbls down tbg with tbg dead and slight flow on casing now. Watched well for 1 hr with no reduction in flow. Shut-in well while cleaning active tank before mixing 180 bbls of 6%KCL-0#s on tbg-0#s on casing. 1500 hrs casing has 32#. Loaded active tank with 176 bbls of FIW and built 180 bbl volume of 6%KCL. 150#s on casing-150#s on tbg. Bled all pressure to zero. Circulated 170 bbls of 6%KCL L/W at 2 BPM 0 PSI as balanced plug at EOT. Pressure increased from 0 to 220#s during last 300 stks. Shut-in well for 30 mins. 100#s on tbg&casing.Bled all pressure off and left well open w/watch. N/D 13 5/8"x 11"spool and M/U test jt w/test plug.Screwed into string and lowered same in well.Made several attempts to test with this setup but failed. At report time we are changing out to tbg hanger. 07/07/15-Tuesday Standby for Cameron hand and 2-way check since test plug failed.On weather hold. Cancelled BOPE test after conversation with Mr. Regg(to be conducted once OOH). Cleared floor and POOH w/20 stands to check fill-ups. Ran in same 20 stands. POOH w/3 1/2" RTS-8 workstring/production string vacuuming and laying down singles in 4's then moving to pipe racks. Pumped 2 bbls every 20 jts laid out. N/D 13 5/8"x 11"spool. Began building 2 7/8"test jt using completion hanger(assisted by Cameron). • • Hilcorp Alaska, LLC Hi'corp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St#11-13RD 50-733-20026-01 191-133 6/24/2015 7/10/2015 Daily Operations: 07/08/15-Wednesday M/U 2 7/8"test jt using completion tbg hanger blanked w/2-way check(Cameron assisting). Landed hanger but pins would not run in all the way.Purged diesel from lines. Pressured up to 1000#s and hanger pins ran in completely. Tested safety valve, variable pipe rams,C2(HCR)&K3 250#s low/3500#s high-charted for 5 mins each. Pulled fluid level down in stack and pulled B/D test jt. Cleared floor. Held PJSM with Pollard,TriPoint,rig&crane crew prior to starting on production assembly. R/U Pollard to run control line f/ chem inj sub-laid out and strapped 50 jts tbg. P/U 8.25"DHL hyd set/retrievable pkr and M/U 2 7/8"6.5#8rd pups w/2.313"X- Nipple and WL re-entry guide.M/U Pollard chem inj sub w/pups. Continued RIH w/production assembly on 2 7/8"6.5#8rd tbg as designed(minus sliding sleeve). M/U SSSV at report time. 07/09/15-Thursday Finished RIH w/production assm.N/D 13 5/8"x 11"spool.M/U tbg hanger to string and terminated chem&SSSV cntrl lines to same. M/U landing jt while sucking fluid level down in riser.Landed hanger(placing EOTbg at 8,457').Ran in two hold down pins,backed out landing jt and installed 2-way check. Filled riser w/6%KCL and closed blinds.Tested to 3600#s for 10 mins-good test. Opened well. Pulled 2-way check and M/U landing jt-dropped bar-opened casing valve. R/U hoses to pressure up down tbg using diesel. Pressured up to 3500#s(as per TriPoint)and held for 30 mins setting pkr at 8,433'. Released pressure.Pulled landing jt. Tied into casing w/tbg open.Pressured up to 1500#s(on chart)and held for 30 mins. Released pressure and installed BPV.Closed casing valve. Cleared and R/D rig floor. Moved driller's shack back.Scope in/laid over derrick.Prepped derrick for move. Rolled up accum lines and cleaned area around BOP stack. N/D BOPE N/U Tree. Assisted production mounting valves and flow lines while crane crew was staging equipment to be move to Grayling. Spotted Pollard SL in NE corner. Cameron tested void 500#s low 5000#s high for 5 mins. Pulled BPV and installed 2-way check.Shell tested tree to 500#s low 5000#s high f/5 mins. R/U Pollard w/full lubricator.Tested same to 2500#s. M/U SL Run#1(2"JDC w/1 1/2"spang&oil jars,knuckle,10'of stem,rope socket). RIH and tag/latch drop bar at 8,433'- POOH. 07/10/15-Friday Slickline recovered drop bar in top of pkr at 8,433'and 7 dummy mandrels(1-chem inj sub,8,413'&6 gas lift mandrels,8,334',7,725' 6,868',5,699',4,157',2,304'). SL1/d mandrels w/orifice valves in all GLMs.L/D valve in chem inj sub then pulled RHCP plug in nipple at 8,449'. R/D/R Pollard SL. Gr-r<A ire, 1 I t-'s \ Pr" (qI153o Regg, James B (DOA) From: Daniel Duckworth - (C) <dduckworth@hilcorp.com> Sent: Wednesday, July 08, 2015 9:06 AM ' ec /1' I15 To: Regg, James B (DOA) Cc: Ted Kramer;Trudi Hallett; Dan Marlowe Subject: GP 11-13RD/ Moncla 404 BOPE Test After Shutin Just tested pipe rams (w/2 7/8" tb), C2 (HCR) & K3 against tb hanger w/2-way check installed 250#s low/3500#s high, on chart holding each test 5 mins. Good test- preparing to run completion. Chart and form will be in '0' drive well folder shortly and available upon request. SVIE it 11 1'r 1 'zi14 ? I - I 3 ice) 330 Regg, James B (DOA) From: Daniel Duckworth - (C) <dduckworth@hilcorp.com> Sent: Monday, July 06, 2015 11:50 AM Q f To: Regg,James B (DOA) Subject: Re: GP 11-13RD Shutin Before pulling tb Sent from my iPhone On Jul 6, 2015, at 10:40 AM, Regg,James B (DOA) <jim.regg@alaska.gov<mailto:jim.regg@alaska.gov»wrote: Before or after pulling tubing and production packer? Jim Regg Supervisor, Inspections AOGCC SCANNED ,; 2 i 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 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 Jim Regg at 907-793-1236 or jim.regg@alaska.gov<mailto:iim.regg@alaska.gov>. From: Daniel Duckworth - (C) [mailto:dduckworth@hilcorp.com] Sent: Monday,July 06, 2015 9:09 AM To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay Cc: Ted Kramer; Dan Marlowe Subject: GP 11-13RD Shutin Mr. Regg, we shutin yesterday to contain well pressure and we'll be testing the components used as soon as we get our well stable. Date,Time of BOPE Use: 7/5/2015, 1600 hrs Well/Location/PTD#: GP 11-13RD/Granite Point Platform/191-133 Rig Name: Moncla 404 Operator Contact: Dan Duckworth Operations Summary: while circulating gas out BOPE used: pipe rams, C2 (HCR), K3 Reason for BOPE use: gas expansion Action Taken/To be taken: circulated gas from well- BOPE was last tested 7/3/2015 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday,June 29, 2015 3:31 PM To: 'Ted Kramer' Cc: Juanita Lovett Subject: RE: GP 11-13RD Program Change Sundry# 315-335 PTD# 191-133 Ted, The change in procedure and completion is approved as stated below and as shown on new schematic. Also do a positive test once the packer(w/plug is set )to 1500 psi. (step 6a.)to verify packer is set before circulating diesel. Guy Schwartz Senior Petroleum Engineer AOGCC SCANNED JUL 0 22015 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at(907-793-1226)or(Guv.schwartz@alaska.gov). From: Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Monday, June 29, 2015 2:22 PM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett Subject: GP 11-13RD Program Change Sundry # 315-335 PTD# 191-133 Guy, Hilcorp would like to change the program on the above well due to well conditions encountered. The Hemlock zone currently perforated in this well has enough reservoir pressure that the well holds a column of 8.4 PPG fluid just below the well surface (+/-4,806 psi @ 10,990'TVD). The Pressure in the Tyonek is believed to be 2,100 psi based on pressures encountered in the offset well GP-50. The well plan calls for adding the Tyonek interval to this well. Since the Tyonek reservoir is also sensitive to water,the desire is to shoot these perforations using diesel as the completion fluid. Because of the potential pressure difference, Hilcorp proposes to set a permanent packer with an isolation plug in it at 10,830' (+/-)to isolate the Hemlock interval so that the tyonek can be perforated in diesel. Once the well is shot and produced to document what the tyonek will contribute,the isolation plug will be pulled and the two intervals comingled and produced. The change to the procedure will be as follows will be after step#6: 6a.) RU E-line, RIH with a model D permenant packer,with plug installed )to 10,830'and set. RD E-line. 6b.) RIH W/workstring to 10,815' and circulate diesel . 6c.) Shut down and monitor well for 30 min.to insure plug is holding on a negative test. Return to Step#7 in the sundry procedure. 1 The Second schematic attached above shows the addition of the model D packer. Timing wise,we will be picking up this packer in the morning. Please advise if this is acceptable to the AOGCC or call me to discuss. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 2 • Granite Point Platform II Well#: GP 11-13RD Proposed Completed: Future PTD: 191-133 Hilmrn A6ek..1.IA: API: 50-733-20026-01 CASING DETAIL RKB to Hanger=42.5' Size(in) WT(Ib/ft) Grade Conn ID(in) Top(ft) Btm(ft) i 14 18 79.59 B Ventura Surf 684 1 [ 1 13-3/8 61.0 J-55 8 round 12.515 Surf 4,018 9-5/8 47 N-80 Butt 8.681 Surf 6,773 2 9-5/8 53.5 P-110 Butt 8.535 6,773 10,060 18" 3 7 32 P-110 Butt TKC 6.094 9,787 11,560 E 1 4 5.919 32 Exp.Liner Gil 5.271 10,978 11,451 TUBING DETAIL 5 2-7/8 8rd EUE .992 +/-8,453 6 JEWELRY I Depth Depth , 1g 3ia 7 \ No (MD) (TVD) ID Item 1 326 326 2.292 SCSSV \L ) 8 +/-2,304 +/-2,302 2.44- GLM I::=F .._4::=51.11M11 9 3 +/-4,164 +/-4,137 2.441 GLM X 10 4 +/-5,686 +/-5,633 2.441 GLM L_____A 11 5 +/-6,856 +/-6,792 2.441 GLM 6 +/-7,715 +/-7,641 2.441 GLM A ,x 7 +/-8,324 +/-8,244 2.441 GLM 8 +/-8,388 +/-8,308 2.441 Chemical Injection Sub 9-5/8" 9 +/-8,404 +/-8,323 2441 Packer 10 +/-8,446 +/-8,365 2.310 X-Nipple 11 +/-8,453 +/-8,372 2.441 WL Re-Entry Guide ® 9 PERFORATIONS Zone ,,.r'Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date 54 / ±8,553 ±8,585 ±8,471' ±8,503' Future Lower C6 ±8,648' ±8,685 ±8,565' ±8,602' Future C6B ±8,721' ±8,738 ±8,637' ±8,654' -117 Future Exp-Liner C7A ±8,877' ±8,901 ±8,792' ±8,816' ±24' Future 10,978'to C7B ±8,919' ±8,997 ±8,833' ±8,911' ±78' Future 11,451' C7C ±9,013' ±9,040 ±8,926' ±8,953' ±27' Future A, C8D ±9,306' ±9,331 ±9,216' ±9,242 ±25 Future C9A ±9,439' ±9,466 ±9,348' ±9,374' ±27 Future C9A --9,475' ±9,485 ±9,383' ±9,393' '.' Future C9B 3,578' ±9,591 ±9,485' ±9,49b Future C9B ±9,610' ±9,635 ±9,516' ±9,541' ±25' Future C9C ±9,711' ±9,720 ±9,616' ±9,625' ±9' Future C5, ±9,744' ±9,756 St), ±9,66: ±12 Future C9C ±9,786' ±917,p7 ±9,701' ±11 Future C9D ±9.836' 85 ±9,740' ±9,758' ±19 Future C9D ±9,989 ±9,847' a,.-±9,891' ±44 Future C9D 0,188' ±10,195' _t10088 ±10,095' ±7' C9D ±10,211' ±10,228' R ±10,111' ±10,128' ±17' Future 0.0 ±10, 9' ±10,327' ±10,218' ±10,226' ±8' Future 0,626 ±10,655' ±10,517' ±10,54' ±29' Future ±10,732 ±10,750' ±10,619' ±10,636' ±18' Future ±10,80? ±10,807' ±10,686' ±10,690' ±5' Future 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 Q 11.- 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/2011 TD=11,560ft PBTD @ 11,451ft 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 Hemlock 11,205' 11,215' 11,068' 11,077' 120' 12 11/16/2013 11,205' 11,215' 11,068' 11,077' 60' 6 11/27/2013 11,032' 11,377' 10,904' 11,232' 345' 06/02/14- 06/29/14 Updated by DEM 2015-05-29 Granite Point Platform n- Proposed Well#: GP 11-13RD Completed: Future Hilawn Alaska.I.IA: vtp ,A-- PTD: 191-133 (� API: 50-733-20026-01 CASING DETAIL RKB to Hanger=42 Size(in) WT(Ib/ft) Grade Conn ID(in) Top(ft) Btm(ft) ] iir 18 79.59 B Ventura Surf 684 IN 1 13-3/8 61.0 J-55 8 round 12.515 Surf4,018 9 5/8 47 N-80 Butt 8.681 Surf 6,773 • • 2 9 5/8 53.5 P-110 Butt 8.535 6,773 10,060 18" 3 7 32 P-110 Butt TKC 6.094 9,787 11,560 M. 5.919 32 Exp.Liner Gil 5.271 10,978 11,451 4 ill TUBING DETAIL 5 8rd EUE 2.992 +/-8,453 6 JEWELRY L itDepth No Depth Depth ID Item 13-3/8" (MD) (TVD) 1 326 326 2.292 SCSSV I 8 +/-2,304 +/-2,302 2.45 t,LM 9 3 +/-4,164 +/-4,137 2.441 GLM in UK 10 4 +/-5,686 +/-5,633 2.441 GLM 11 5 +/-6,856 +/-6,792 2.441 GLM �/ �/ 6 +/-7,715 +/-7,641 2.441 GLM ✓< ✓\ 7 +/-8,324 +/-8,244 2.441 GLM 8 +/-8,388 +/-8,308 2.441 Chemical Injection Sub L 9-5/8" 9 +/-8,404 +/-8,323 2441 Packer 10 +/-8,446 +/-8,365 2.310 X-Nipple 11 +/-8,453 +/-8,372 2.441 WL Re-Entry Guide 12 +/-10,830 +/-10,712 3.250 Model D Permanent Packer 13 +/-10,834 +/-10,715 2.313 X Landing nipple PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date C-5A ±8,553 ±8,585 ±8,471' ±8,503' ±32 Future Lower 12 l., I ililrP.- C6 ±8,648' ±8,685 ±8,565' ±8,602' ±37 Future xp-Liner C6B ±8,721' ±8,738 ±8,637' ±8,654' ±17 Future 13 • 10,978'to C7A ±8,877' ±8,901 ±8,792' ±8,816' ±24 Future ■ 11,451' C7B ±8,919' ±8,997 ±8,833' ±8,911' ±78' Future .." ±9,013' ±9,040 ±8,926' ±8,953' ±27' Future -( ±9,306' ±9,331' ±9,216' ±9,241' ±25' Future ±9,439' ±9,466' ±9,348' ±9,374' ±27' Future ±9,475' ±9,485' ±9,383' ±9,393' ±10' Future C9B ±9,578' ±9,591' ±9,485' ±9,498' ±13' Future C9B ±9,610' ±9,635' ±9,516' ±9,541' 7` Future w(� C9C ±9,711' ±9,720' 9,616' ±9,625' Future =MMIIIM__ C9C ±9,744' ±9,756' ±9,649' ±9,661' *1, Future ' s'Y C9C ±9,786' ±9,797' ±9,690' ±9,701' ±11 Future ppd- C9D ±9,836' ±9,855 ±9,740' ±9,758' ±19 Future C9D ±9,945' ±9,989' ±9,847' ±9,891' ±44 Future C9D ±10,188 ±10,195' ±10,088' ±10,095' ±7' Future C9D ±10,211 ±10,228' ±10,111' ±10,128' ±17' Future C10 ±10,319 ±10,327' ±10,218' ±10,226' ±8' Future C11 ±10,626 ±10,655' ±10,517' ±10,545' ±29' Future C12 ±10,732 ±10,750' ±10,619' ±10,636' ±18' Future C12 ±10,802 ±10,807' ±10,686' ±10,690' Future L ' 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 TD=11,560ft PBTD @ 11,451ft 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/2011 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 Hemlock 11,205' 11,215' 11,068' 11,077' 120' 12 11/16/2013 11,205' 11,215' 11,068' 11,077' 60' 6 11/27/2013 - 11,032' 11,377' 10,904' 11,232' 345' 06/02/14 06/29/14 • v OF � • 6,,v1-�\V/j,'s7 THE STATE Alaska Oil and Gas i\ SIKi\ Conservation Commission 333 West Seventh Avenue it —"- GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax 907.276 7542 www aogcc.alaska gov iUN �3 5 7a15 Trudi Hallett SC.1 4° Operations Engineer ( I — 133 Hilcorp Alaska, LLC 1 f 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Granite Point Field, Hemlock Undefined Oil Pool, Granite Pt St 11-13RD Sundry Number: 315-335 Dear Ms. Hallett: 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, /a?0-4...0(ic Cathy . Foerster Chair DATED this-day of June, 2015 End. • RECEIVED • MAY 28215 STATE OF ALASKA O� ‘7Z/7i- ALASKA OIL AND GAS CONSERVATION COMMISSION �.,��JJ� f APPLICATION FOR SUNDRY APPROVALS CC 20 AAC 25.280 1 Type of Request Abandon El Plug Perforations ❑ Fracture Stimulate El Pull Tubing El. Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program El Plug for Rednll❑ Perforate New Pool 0• Repair Well ❑ Re-enter Susp Well ❑ Other: Gas Lift Completion _ I] • 2 Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC • Exploratory El Development El • 191-133 • 3 Address 3800 Centerpoint Drive,Suite 1400Stratigraphic I:1 Service El6.API Number: Anchorage,AK 99503 50-733-20026-01 . 7.If perforating 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 76,Rule 2 Will planned perforations require a spacing exception? Yes El No El / Granite Pt St#11-13RD • 9.Property Designation(Lease Number): 10 Field/Pool(s) ADL0018761 • Granite Point Field/Hemlock Undefined Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft) Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured) Junk(measured) - 11,560 . 11,407 . 11,451 - 10,809 N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 684' 18" 684' 683' Surface 4,018' 13-3/8" 4,018' 3,993' 3,090 psi 1,540 psi Production 10,060' 9-5/8" 10,060' 9,960' 10,900 psi 7,950 psi 1 Liner 1,773' 7" 11,560' 11,407' 12,460 psi 10,780 psi Liner 473' 5.919" 11,451' 11,303' 12,460 psi 10,780 psi Perforation Depth MD(ft) Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft) See Schematic I See Schematic 3-1/2" 9.3#/L-80 10,932 Packers and SSSV Type. Packers and SSSV MD(ft)and ND(ft): Hyd Ret Packer&SCSSV X-Profile Back Up • 10,883'(MD)10,762'(TVD)&326'(MD)326'(ND)• 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work. Detailed Operations Program ❑ BOP Sketch El Exploratory El Stratigraphic El Developmev0- Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/3/2015 Commencing Operations: OIL 0 • WINJ El WDSP❑ Suspended ❑ 16.Verbal Approval: Date. GAS El WAG El GSTO❑ SPLUG El Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Trudi Hallett Email thalleft hilcorp.com Printed Name Trudi Hallett Title Operations Engineer "Lit Signature tVAPhone (907)777-8323 Date 5/28/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3i5- 33� Plug Integrity El BOP Test 11� Mechanical Integrity� ` Test El Location Clearance ❑ Other .1 3 gs gee ( G5/ ( mAsP -_ 3z-o'‘ /54% Spacing Exception Required? Yes ❑ No d Subsequent Form Required `/ — / O 1 BY Approved by:( PL COMMISSIONER HE COMMISSION Date: _z _i� liSI:PPROVED s-Z. 8-IS OFpirlvatNAL ✓ 647 Submit Form and Form 10-403 Revised 5/2015 for 12 months from the date of approva. RBDMS_1hments in upli to i? - 1015 • Well Work Prognosis Well: GP-11-13RD Hileorp Alaska,LLC Date: 05/27/2015 Well Name: GP-11-13RD API Number: 50-733-20026-01 Current Status: Producer Leg: 3 Estimated Start Date: June 03, 2015 Rig: Rig 404 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 191-133 First Call Engineer: Ted Kramer Office: 907-777-8420 Cell:985-867-0665 Second Call Engineer: Trudi Hallett Office: 907-777-8323 Cell:907-301-6657 AFE Number: Current BHP: 5,300 psi @ 11,067ft ND/11,203ft MD From PBT 2009 Max.Expected BHP: 5,300 psi @ 11,067ft ND/11,203ft MD From PBT 2009 Max Anticipated Surface Pressure : —3,209 psi @ 8471'ND Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4)and adjusting to new top perf based on 4057 psi @ 8471'ND. Brief Well Summary GP 11-13RD was drilled and completed in March 1992 as a gas lift producer in the Hemlock sands. The well initially came on production at 1,500 bopd at a tubing pressure of 1,500 psi with no artificial lift. GP 11-13RD was hydraulically fractured in December of 2013 and brought back on gas lift.This workover will be adding new perforations uphole in the Tyonek Formation and then will be completed as a gas lift producer. The estimated TOC in the 9-5/8"casing is^'7,100'. During completion operations on Feb. 11, 1992, 351 bbls of 15.8 ppg cement was pumped displaced with 716 bbls of mud-having full returns. A cement bond log was run March 3, 1993 confirming a sufficient bond several hundred feet above the proposed top perf @ 8,553' MD. 'V p If' The last 9-5/8"casing test was completed Nov. 30, 2013. Set test packer @ 10,602, pressured up to 3,000 psi and charted for 30 min.Tested good. The spacing exception has been reviewed and a map detailing that work is attached. Procedure: 1. MIRU Rig 404 over 11-13RD. 2. Notify AOGCC 48 hours before pending BOPE test. 3. Set BPV, ND tree, NU BOPE. 4. Test all BOP equipment per AOGCC guidelines and Hilcorp BOPE testing procedures to 250 psi LOW and 3,500 psi HIGH.1 5. Shift sliding sleeve and circulate hydrocarbon out of well. 6. Pull tbg and production packer standing back tbg. 7. PU and RIH with TCP guns and perforate per program. SwF 8. PU and RIH with gas lift completion production tbg string and set pkr @ +/-8400' and hang off same. 9. Test to 1500 psi charting for 30 min. 10. ND BOPE, NU tree,and test same. 11. Turn well over to production. II Well Work Prognosis Well: GP-11-13RD Hilrorp Alaska,LLC Date: 05/27/2015 Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current Wellhead Diagram/Proposed Wellhead Diagram (Same) 4. BOP Stack 5. Rolling BOP Test Procedure Granite Point Platform II SCHEMATIC Well#: Last Completed: eted:ted:11-112 12/18/2013 PTD: 191-133 Hibor,Alaska.LU API: 50-733-20026-01 RKB to Hanger=42.5' ] II CASING DETAIL 1 Size(in) WT(lb/ft) Grade Conn ID(in) Top(ft) Btm(ft) 18 Conductor Surf 684 2 13-3/8 61.0 1-55 12.515 Surf 4,018 18 9-5/8 47 N-80 8.681 Surf 6,773 11 9-5/8 53.5 P-110 8.535 6,773 10,060 3 7 32 P-110 6.094 9,787 11,560 111 5.919 32 Exp.Liner Gil 5.271 10,978 11,451 4 TUBING DETAIL 4 III , 3-1/2 9.3 L-80 RTS-8 2.992 Surf 10,932 13-3/8" 5 I 6 JEWELRY 7 No Depth ID Item 1 326 2.813 SCSSV X-Profile Back Up X 8 2 2,304 2.992 GLM 3 4,164 2.992 GLM L 9 4 5,686 2.992 GLM 9-5/8" 5 6,856 2.992 GLM 10 6 7,715 2.992 GLM III 7 8,324 2.992 GLM 8 8,811 2.992 GLM 11 9 9,327 2.992 GLM 10 9,841 2.992 GLM 12 11 10,355 2.992 GLM MA 12 10,839 2.992 GLM RID 13 13 10,854 2.813 GXA Sliding Sleeve Non-Elastomeric(opens up/B shifting Tool) 1 14 14 10,867 2.992 Chemical Injection Sub 15 15 10,883 2.992 Hyd Retr Packer,7"26-324,40K Shear X; 16 16 10,925 2.813 EUE X Nipple 17 Exp-Liner 17 10,932 2.992 WL Re-Entry Guide 10,978'to 11,451' a- PERFORATIONS 3g-- Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/2011 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 Hemlock 11,205' 11,215' 11,068' 11,077' 120' 12 11/16/2013 11,205' 11,215' 11,068' 11,077' 60' 6 11/27/2013 11,032' 11,377' 10,904' 11,232' 345' 06/02/14— 06/29/14 7 L. TD=11,560ft PBTD @ 11,451ft Updated by JLL 07/25/14 Granite Point Platform .11 Well#: GP 11-13RD Proposed Completed: Future Ililearn Alaska.l.l.f, PTD: 191-133 API: 50-733-20026-01 CASING DETAIL RKB to Hanger=42.5' Size(in) WT(Ib/ft) Grade Conn ID(in) Top(ft) Btm(ft) .[] , 18 79.59 B Ventura Surf 684 1 13-3/8 61.0 J-55 8 round 12.515 Surf 4,018 9-5/8 47 N-80 Butt 8.681 Surf 6,773 2 9-5/8 53.5 P-110 Butt 8.535 6,773 10,060 18" 3 7 32 P-110 Butt TKC 6.094 9,787 11,560 4 5.919 32 Exp.Liner Gil 5.271 10,978 11,451 TUBING DETAIL 5 3-1/2 9.3 L-80 RTS-8 2.992 Surf +/-8,453 6 JEWELRY L 7 .\ No Depth Depth ID Item 13-3/8" 111 (MD) (TVD) I'1111 8 1 326 326 2.813 SCSSV X-Profile Back Up 1 9 2 +/-2,304 +/-2,302 2.992 GLM 10 3 +/-4,164 +/-4,137 2.992 GLM ft if ,11 4 +/-5,686 +/-5,633 2.992 GLM 12 ti, 5 +/-6,856 +/-6,792 2.992 GLM Aly' 6 +/-7,715 +/-7,641 2.992 GLM /u\ 7 +/-8,324 +/-8,244 2.992 GLM • L , u JL 0 8 +/-8,375 +/-8,295 2.813 Sliding Sleeve 9-5/8" 9 +/-8,388 +/-8,308 2.992 Chemical Injection Sub 10 +/-8,404 +/-8,323 2.992 Packer 11 +/-8,446 1 +/-8,365 2.813 X-Nipple 12 +/-8,453 +/-8,372 2.992 WL Re-Entry Guide PERFORATIONS Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) Amt SPF Date C-5A ±8,553' ±8,585' ±8,471' ±8,503' ±32' Future Lower C6 ±8,648' ±8,685' ±8,565' ±8,602' ±37' Future C6B ±8,721' ±8,738' ±8,637' ±8,654' ±17' Future Exp-Liner C7A ±8,877' ±8,901' ±8,792' ±8,816' ±24' Future 10,978'to C7B ±8,919' ±8,997' ±8,833' ±8,911' ±78' Future 11,451' C7C ±9,013' ±9,040' ±8,926' ±8,953' ±27' Future C8D ±9,306' ±9,331' ±9,216' ±9,241' ±25' Future /$' C9A ±9,439' ±9,466' ±9,348' ±9,374' ±27' Future C9A ±9,475' ±9,485' ±9,383' ±9,393' ±10' Future C9B ±9,578' ±9,591' ±9,485' ±9,498' ±13' Future C9B ±9,610' ±9,635' ±9,516' ±9,541' ±25' Future C9C ±9,711' ±9,720' ±9,616' ±9,625' ±9' Future C9C ±9,744' ±9,756' ±9,649' ±9,661' ±12' Future main C9C ±9,786' ±9,797' ±9,690' ±9,701' ±11' Future L C9D ±9,836' ±9,855' ±9,740' ±9,758' ±19' Future _ 1 C9D ±9,945' ±9,989' ±9,847' ±9,891' ±44' Future C9D ±10,188' ±10,195' ±10,088' ±10,095' ±7' Future 1, C9D ±10,211' ±10,228' ±10,111' ±10,128' ±17' Future 7 C10 ±10,319' ±10,327' ±10,218' ±10,226' ±8' Future C11 ±10,626' ±10,655' ±10,517' ±10,545' ±29' Future \ i C12 ±10,732' ±10,750' ±10,619' ±10,636' ±18' Future C12 ±10,802' ±10,807' ±10,686' ±10,690' ±5' Future 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 L 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/2011 TD=11,560ft PBTD @ 11,451ft 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 Hemlock 11,205' 11,215' 11,068' 11,077' 120' 12 11/16/2013 11,205' 11,215' 11,068' 11,077' 60' 6 11/27/2013 11,032' 11,377' 10,904' 11,232' 345' 06/02/14- 06/29/14 Updated by DEM 2015-05-27 • a a U E Q 9 m 25 $ W .S LL • to ~ ccO Z ; r- a f E V ZIX W = a e • R' .0 • 0 cc a• I O O C7 in O o 0 Y O 0O .� O (n E tA cc O sJ co a o U d Y p C a of M C •- O_ a, ac 7 - a -.-+ a 2 ? ri O (6 'a m en O L C C 4.4 a) ' Q1 c 7 i--1 0 Q E N m 7,' p C E Q V) a c-( O e--( C " ac o COC 3 L d .0 N Y cc E LL m2 10 e Z L 3 �I O a) C C01 ,--i 0. 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I I I 1 1 1 I I I I I I I I I I I E o N I O ix) `--I c-I {y I F C 1 L I M 1 (� NI ID a I Irl �I(y C Q rl L I -O v N I ._ U -O (n N 1 O w Z a+ Y I 1L - O CL 5. z f I \ • - ~ I- . /I 9 1 1 M 1 I -Y - -i - I I rr ,\ I j I 0 \--L------- f I 1 \ I I ,- I \I NI /CI 1 I J 1 to v1 M C U et a a vC 0 e- Cl O O a U lr D E N L • r ..,i- Ti r-I o 111E 0 J r> m JO O Q N a c-1 a rliU a Q M 11 (D cn F- Granite Point Platform 11-13RD Current liilrnrp Milan.1A.t, 05/26/2015 Granite Point Tubing hanger,FMC-UH- ,. 11-13RD TC-1A-EN,13 5/8 5M X 334 �1 18 X 13 3/8 X 9 5/8 X IBT lift and susp,w/3"type 3 1/2 H BPV,2-Y.continuous control line,6.990"EN BHTA,Bowen,3 1/8 5M FE X 3"Bowen lill .. ,I. IMI Vin._li.. Valve,Swab,WKM-M, t.k(4., 3 1/8 5M FE,HWO,EE trim '(p k i....,, V � .n..`Ti.n Valve,SSV,Wing,WKM-M, 3 1/8 5M,w/15"OMNI oper Tee,stdd,3 1/8 5M X 3 1/8 5M ,.. wn.. 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AA trim 18"EN hanger ■ 111.1110,`,.� .��r-i. rLPUI Conductorhoung, fr• 18" 13 3/8" 1_ 9 5/8" 3'A" But' Stack Moncla 02/25/2015 nnrurp 1u11rRw-i.0 I I III Iii Iii Iii 4.54' • rysh o GK L8-5001 fill"iiTii lil lil it III 111 lit I11 2 7/8-5 variables or Cameron 4.67' — II * _ dual flex rams — Blinds li l I I I11'1�111i1 Kill Side111 11 111 1111 Choke side 2.00' 31/85Mw/HCR } 85Mw/HCR I - - , I11 ill Ali 111 I11• }��'� �� / MEL 1.00'to 2.00' IIIF I1. 11; ll; III Drill deck 11.00' Riser 13 5/8 5M FE X 13 5/8 5M FE I11•I11 iii I11 III r 111'111 I I. II .1 2.00 Spacer spool 13 5/8 5M FE X 13 5/8 5M FE I...,1 lil lil llit Moncla Rig 404 BOP Test Procedure i❑ieorp;u,aka.�.�.(, Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, Grayling WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska. HA #1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. Moncla Rig 404 BOP Test Procedure Hi!carp:1i,.ka. Attachment#1 d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3,4,9. After test, open valves 3 &4. Leave 9 closed. iii) Valves 5, 6,9. After test, open valves 5&6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. e) Close C-2. This is the HCR(the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test,open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/- 3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not"Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~:~/~~_~ile N umber of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: GrayScale, halftones, pictures, graphs, charts-. Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA Diskettes, No. n Other, No/Type OVERSIZED .1:3' Logs 'of various kinds . Other COMMENTS:' Scanned by: Beverly Diann~than Lowell TO RE-SCAN Notes: 'j~/ '~~ Date:~/~'-/¢ Is/ '~'~ Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: /si 7c67 ! ESATE I' arF d =,ad, ✓,=1 L 3 t A t , ° Gcv"t?RN012 SEAN P.\RNELI Anchorage A�askc 995013572 p' ,. 333 Wes Seventh Avenue VI- 9C7 2-'c 33 Dan Taylor Operations Engineer Hilcorp Alaska, LLC "`SEpNNED J U L 1 5 2 , �lr 014 133 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granit Pt Field, Hemlock Undefined Oil Pool, Granite Pt St 11-13RD Sundry Number: 314-324 Dear Mr. Taylor: 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, 10-1,44,__ Cathy P oerster Chair DATED this day of May, 2014. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . i ter APPLICATION FOR SUNDRY APPROVALS 2QMC 25.280 1.Type of Request: Abandon 0 Plug for Redrill❑ Perforate New Pool 0 Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate 0 • Pull Tubing❑ Time Extension 0 Operations Shutdown 0 Re-enter Susp.Well El Stimulate❑ Alter Casing❑ Other. 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC- Exploratory ❑ Development 0• 191-133 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20026-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 V Will planned perforations require a spacing exception? Yes ❑ No 0/ Granite Pt St 11-13RD • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018761 , Granite Pt/Hemlock Undefined Oil • 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): 11,560 . 11,407. 11,451 10,809 • N/A N/A Casing Length Size MD TVD Burst Collapse Conductor 684' 18" 684' 683' Surface 4,018' 13-3/8" 4,018' 3,993' 3,090 psi 1,540 psi Production 10,060' 9-5/8" 10,060' 9,960' 10,900 psi 7,950 psi Liner 1,773' 7" 11,560' 11,407' 12,460 psi 10,780 psi Liner 473' 5.919" 11,451' 11,303' 12,460 psi 10,780 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 3-1/2" 9.3#/L-80 10,932' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Ret.Pkr/SCSSV Packer 10,883'(MD)10,762'(TVD)/SSSV 326'(MD)326'(TVD) 12.Attachments: Description Summary of Proposal 9 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development 0/ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/30/2014 Oil 0✓ Gas ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: WINJ 0 GINJ ❑ WAG 0 Abandoned ❑ Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylor a(�hilcorp.com Printed Name Dan Ta lor/ Title Operations Engineer Signature Phone 907 777-8319 Date 5/20/2014 _ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\i*-32L-( Plug Integrity El BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Spacing Exception Required? Yes 0 No Or Subsequent Form Required: i 0 I (.) 1 APPROVED BY /y Approved by: P9a-ei4...0"--- COMMISSIONER THE COMMISSION Date: - Z 3— fic, 5122411 b�S S 1a311� �g i 1=�A' A Submitsn Form and Form 10-403(Revised 10/2012) Approve a i t ivt� IiTi�`r16_�l onths from the date of approval. Attachments in Duplicate4 RBDMS MAY 2 3 Well Prognosis Well: GP 11-13RD Hilcorp Alaska,LI) Date:5/19/2014 Well Name: GP 11-13RD API Number: 50-733-20285-01 Current Status: Producer Leg: 3 Estimated Start Date: May 30,2014 Rig: Gran. Point Platform Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 191-133 First Call Engineer: Dan Taylor (907)777-8319(0) (907)947-8051 (M) Second Call Engineer: Reid Edwards (907) 777-8421 (0) AFE Number: Current Bottom Hole Pressure: 5,300 psi @ 11,067ft TVD/11,203ft MD From PBT 2009 Maximum Expected BHP: 5,300 psi @ 11,067ft TVD/11,203ft MD From PBT 2009 Max. Potential Surface Pressure: —1,387 psi 5,300psi—(0.354psi/ft* 11,067ft ND) Brief Well Summary GP 11-13RD was drilled and completed in March 1992 as a gas lift producer in the Hemlock sands. The well initially came on production at 1,500 bopd ata tubing pressure of 1,500 psi with no artificial lift. GP 11-13RD was hydraulically fractured in December of 2013 and brought back on gas lift. The well is currently making J25bopd and 67bwpd based on last well test. This application for Sundry Approval outlines the procedure for re-perforating in the Hemlock sand over the intervals {+/- 11,032ft to+/-11,377ft MD)../ Procedure 1. Identify and record fluid level. 2. Hold pre-job safety meeting. 3. Prepare well for e-line perforating. a. Check well head pressure. b. Ensure crown and wing valves are closed. c. Bleed pressure from well head. d. Ensure there is no trapped pressure. e. Ensure there is proper lighting for operations. - f. Keep excess personnel away from operations. g. Ensure perforating unit is grounded. 4. Rig up wireline valves, lubricator, head catcher, grease injection head, pack-off, line wiper and wire line. a. Test lubricator to+/-1,500psi. b. Max potential surface pressure—1,387psi. 5. Run in hole with Dummy Gun, GR/CCL and weight bars to tag (Min ID=2.813in). 6. Run in hole with perforating gun, GR/CCL and weight bars. a. Tie in to correlation log. b. Well will be perforated while balanced. c. Perforate interval+/-11_324ft to+/-11 364ft MD(Total =40ft MD). `' i. Total runs—2. ii. Pull out of hole checking for all shots fired. 7. Shut in master valve. 8. Bleed off pressure in lubricator. 9. Rig down wireline valves, lubricator, head catcher,grease injection head, pack-off, line wiper and wire line. 10. Turn well over to production. 11. Place well on gas lift until new perforation contribution is observed. If measureable oil production is observed the complete proposed perforation interval will be shot(+/-11,032ft to+/-11,377ft MD)? 12. Production to function test SCSSSV not less than 14 days after stable production is resumed. Attachments: 1. As-built Well Schematic. 2. Proposed Well Schematic. 3. Wire Line Surface Equipment Diagram. Granite Point Platform II Well#: GP 11-13RD Last Completed: 12/18/2013 + :llaxku.LLC PTD: 191-133 Hilcoru API: 50-733-20026-01 RKB to Hanger=42.5' CASING DETAIL 1 2 IS. Size(in) WT(Ib/ft) Grade Conn ID(in) Top(ft) Btm(ft) 18 Conductor Surf 684 13-3/8 61.0 J-55 12.515 Surf 4,018 18" 9-5/8 47 N-80 8.681 Surf 6,773 9-5/8 53.5 P-110 8.535 6,773 10,060 3 7 32 P-110 6.094 9,787 11,560 5.919 32 Exp.Liner Gil 5.271 10,978 11,451 4 TUBING DETAIL } 3-1/2 9.3 L-80 RTS-8 2.992 Surf 10,932 13-3/8" 5 6 JEWELRY 7 No D(eft;h ID Item 1 326 2.813 SCSSV X-Profile Back Up 8 X 2 2,304 2.992 GLM 3 4,164 2.992 GLM 4 5,686 2.992 GLM L 9 9-5/8' 5 6,856 2.992 GLM i 10 6 7,715 2.992 GLM 7 8,324 2.992 GLM 8 8,811 2.992 GLM 11 9 9,327 2.992 GLM 10 9,841 2.992 GLM 12 11 10,355 2.992 GLM IN 12 10,839 2.992 GLM frg 13 # 13 10,854 2.813 GXA Sliding Sleeve Non-Elastomeric(opens up/B shifting Tool) ■ ill 14 14 10,867 2.992 Chemical Injection Sub 15 15 10,883 2.992 Hyd Retr Packer,7"26-32#,40K Shear 16 16 10,925 2.813 EUE X Nipple 17 Exp-Liner 17 10,932 2.992 WL Re-Entry Guide 10,978'to 11,451' PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt _ SPF Date IMMENIND 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/2011 Hemlock 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 11,205 11,215 11,068 11,077' 120' 12 11/16/2013 11,205 11,215 11,068 11,077' 60' 6 11/27/2013 IIIMMIIIIIIF 18 7 TD=11,560ft PBTD @ 11,451ft Updated by JLL 01/17/14 Granite Point Platform 14 PROPOSED Well#: GP 11-13RD Last Completed: 12/18/2013 PTD: 191-133 Hik»ra Alaska LLC. API: 50-733-20026-01 RKB to Hanger=42.5' CASING DETAIL LI r i If 1 Size(in) WT(Ib/ft) Grade Conn ID(in) Top(ft) Btm(ft) 18 Conductor Surf 684 2 13-3/8 61.0 J-55 12.515 Surf 4,018 18" 9-5/8 47 N-80 8.681 Surf 6,773 9-5/8 53.5 P-110 8.535 6,773 10,060 3 7 32 P-110 6.094 9,787 11,560 5.919 3 2 Exp.Liner Gil 5.271 10,978 11,451 4 TUBING DETAIL 3-1/2 9.3 L-80 RTS-8 2.992 Surf 10,932 L 13-3/8" 5 I 6 JEWELRY 7 No Depth ID Item (ft) 1 326 2.813 SCSSV X-Profile Back Up 8 \ 2 2,304 2.992 GLM X 3 4,164 2.992 GLM 4 5,686 2.992 GLM 9 9-5/8" 5 6,856 2.992 GLM 6 7,715 2.992 GLM 10 7 8,324 2.992 GLM 8 8,811 2.992 GLM 11 9 9,327 2.992 GLM 10 9,841 2.992 GLM 12 11 10,355 2.992 GLM 12 10,839 2.992 GLM • ! 13 # 13 10,854 2.813 GXA Sliding Sleeve Non-Elastomeric(opens up/B shifting Tool) a ! it 14 14 10,867 2.992 Chemical Injection Sub 15 15 10,883 2.992 Hyd Retr Packer,7"26-32#,40K Shear 16 16 10,925 2.813 EUE X Nipple Exp-Liner 17 10,932 2.992 WL Re-Entry Guide 17 10,978'to 11,451' PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/2011 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 Hemlock 11,205' 11,215' 11,068' 11,077' 120' 12 11/16/2013 11,205' 11,215' 11,068' 11,077' 60' 6 11/27/2013 11,032' 11,377' 10,904' 11,232' 345' Future G TD=11,560ft PBTD @ 11,451ft Updated by DT 05/20/14 ,,, . - 1 . Wireline Pressure Control Certification Level 2 - 10K Line Wiper Stuffing Box r 1.1 I Packoff L 4 ,...._...., Grease Injection Control Head ' Pres _. sure Control Grease Injector Unit I I Gall check valve! Head Catcher _ 11. '"..--1-•:,:,•••:'.. '' ilkjri _ 11 �. If i •Ir} . t_ ' Lubricator 0 Tool Trap I. !1 Ii _ Mi - EN Wireline e11ii-m-1111i;1 = Valves 6. 11� Wellhead ',, Flange Adapter RECEIVED STATE OF ALASKA ALA ,OIL AND GAS CONSERVATION COMM!, )N 'JAN 2 1 2014 REPORT OF SUNDRY WELL OPERATIONSl��C i 1.Operations Abandon El Repair Well❑ Plug Perforations 0 Perforate ❑ Other 0 Install Exp Liner/Complete Performed: Alter Casing❑ Pull Tubing 0 Stimulate-Frac 0 Waiver ❑ Time Extension❑ Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well El 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory El 191-133 - 3.Address: 3800 Centerpopint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20026-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018761 r Granite Pt St 11-13RD e 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): r Granite Pt Field/Hemlock Undefined Oil 11.Present Well Condition Summary: Total Depth measured — 11,560 feet Plugs measured N/A feet true vertical 11,407 feet Junk measured N/A feet Effective Depth measured r 11,451 feet Packer measured 10,883 feet true vertical 10,809 feet true vertical 10,762 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 684 18" 684' 683' Surface 4,018 13-3/8" 4,018' 3,993' 3,090 psi 1,540 psi Intermediate 6,773 9-5/8" 6,773' 6,710' 6,870 psi 4,750 psi Production 3,287' 9-5/8" 10,060' 9,960' 10,900 psi 7,950 psi Liner 1,773' 7" 11,560' 11,407' 12,460 psi 10,780 psi Liner 473' 5.919" 11,451' 11,303' Perforation depth Measured depth See Schematic feet SUNNED J U h n LU�, True Vertical depth See Schematic feet J !'�S�pN Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 10,932(MD) 10,809 (ND) Packers and SSSV(type,measured and true vertical depth) Ret.Pkr 10,883'(MD)10,762'(ND) SCSSV 326'(MD)326'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDM MAY 1 fi 2014 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: 82 26 128 866 170 Subsequent to operation: 22 15 79 582 72 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development0 ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil •0 Gas ❑ WDSPL❑ GSTOR El WINJ El 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: 313-420&313-442 Contact Dan Taylor Email dtavlorahilcorp.com Printed Name Dan Taylor Title Operations Engineer Signature Phone (907)777-8319 Date 1/20/2014 7/e: 6 - ci iq Form 10-404 Revised 10/2012 /0 44 ' l Submit Original Only i I Granite Point Platform Well#: GP 11-13RD Last Completed: 12/18/2013 PTD: 191-133 Hikaro Aluka.LLC API: 50-733-20026-01 RKB to Hanger=42.5' CASING DETAIL 1 Size(in) WT(lb/ft) Grade Conn ID(in) Top(ft) Btm(ft) 18 Conductor Surf 684 2 13-3/8 61.0 1-55 12.515 Surf 4,018 18" 9-5/8 47 N-80 8.681 Surf 6,773 9-5/8 53.5 P-110 8.535 6,773 10,060 3 7 32 P-110 6.094 9,787 11,560 5.919 32 Exp.Liner Gil 5.271 10,978 11,451 4 TUBING DETAIL 3-1/2 9.3 L-80 RTS-8 2.992 Surf 10,932 13-3/8" 5 6 JEWELRY 7 No Depth ID Item 1 326 2.813 SCSSV X-Profile Back Up 8 2 2,304 2.992 GLM 3 4,164 2.992 GLM L 9 , 4 5,686 2.992 GLM 9-5/8" 5 6,856 2.992 GLM 10 6 7,715 2.992 GLM 111 7 8,324 2.992 GLM 8 8,811 2.992 GLM 11 9 9,327 2.992 GLM III 10 9,841 2.992 GLM 12 11 10,355 2.992 GLM in i�: 13 12 10,839 2.992 GLM I C 13 10,854 2.813 GXA Sliding Sleeve Non-Elastomeric(opens up/B shifting Tool) 14 14 10,867 2.992 Chemical Injection Sub 15 15 10,883 2.992 Hyd Retr Packer,7"26-3211,40K Shear al 16 16 10,925 2.813 EUE X Nipple 17 Exp-Liner 17 10,932 2.992 WL Re-Entry Guide 10,978'to 11,451' e / PERFORATIONS Zone Top(MD) BtmD)M Top(TVD) Btm(TVD) Amt SPF Date 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/2011 Hemlock 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 11,205 11,215 11,068 11,077' 120' 12 11/16/2013 11,205 11,215 11,068 11,077' 60' 6 11/27/2013 q 18 L TD=11,560ft PBTD @ 11,451ft Updated by JLL 01/17/14 111 Hilcorp Alaska, LLC 11iIcnrpAlaska.IAA Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 11-13RD 50-733-20026-01 191-133 10/8/2013 12/19/2013 Daily Operations: 10/08/13-Tuesday Rigging up. 10/09/13-Wednesday HSM.Unhooked wellhead from production.Installed BPV.Took clamps off wellhead,landed 3-1/2"8 RD connection in top of tree. P/U and L/D on the deck.Cleaned well head surface and void.Installed valve to hold open SSV. M/U riser on well head.Installed BOP's, set cat walk and beaver slide. 10/10/13-Thursday PTSM.Cont.R/U BOP's.R/U accumulator lines.M/U 2-7/8"test jt,fill stack&choke manifold,shell test t/2500 psi.Test BOP's w/2- 7/8" tj as per Hilcorp&AOGCC regulations. Test 250 psi low/2500 psi high,5 min ea.Test good.Witness waived by Jim Regg @ 11:42 on 10-9-13. Pull test jt,pull BPV&install TWC to test blinds. 10/11/13-Friday Cont.bleed 11-13RD down.R/U&pull BPV. Line up well t/gas buster.R/U jt to hanger&R/U e-line. RIH w/2.25 jet cutter&SSSV hold open sleeve t/10,915',make cut. POOH and L/D e-line.R/U to circulate well t/production w/9.6 ppg Brine(6%KCL&sodium chloride).Circulate well t/production w/9.6 ppg Brine(6%KCL&sodium chloride)@ 2 BPM 1-1/2 hole vol till clean,fcp 170 psi,S/D monitor well. Pull landing jt and install TWC. 10/12/13/13-Saturday R/U&test blind rams.Install flow nipple,flow line,front wind wall panels,drip pan&false rotary beams.Pull hanger,unseated @ 82k,cont pull up t/100k wt fell off t/95k,cont pull wt fell t/82k.Break&L/D hanger. Hole on vacuum.Pumped 95 bbls brine w/o catching fluid. Prep deck to L/D tubing. POOH w/2-7/8" butt tubing. Pump tubing displacement 6%KCL every 20 jts.Production shooting fluid levels every hour monitoring for change in level.L/D sssv&control line. L/D 261 jts,7 glm w/pups.Fluid put in hole: 895 bbls 9.6 brine+32 bbls 6%kcl=927 bbls total. Calculated fluid loss after initial fill 109 bbls. 10/13/13-Sunday Coot._PO01-1,w12-7[8"production string. L/D total 342 jts,24 pups,11 GLM,1 SSSV,&seal assy,total 10,895'. Clean&clear rig floor. Install wear bushing. P/U Packer milling BHA#1,shoe,top bushing,jars,6-4.75 collars=201.12'. TIH t/10,925'tag,up wt 150,dn wt 120.P/U swivel&M/U.Wash jt dn @ 3 bpm,120 psi,rt wt 136,tq 4k, wk dn.75 through obstruction CBU getting scale returns. Circulate clean.Make connection,tag packer @10,947'.Calculated fluid loss after initial fill 109 bbls,0 loss f/today. 10/14/13-Monday Mill on packer @ 10,947't/10,950',up wt 150 dn 120,rt 136 tq 4-5,pump 3 BPM 180 psi. POOH and L/D shoe-finding rubber,slips, and mandrel pieces in shoe. Clean&clear floor. 10/15/13-Tuesday P/U BHA#2 overshot,bumper sub,jar's,acc,3 ea 4-3/4"dc,2 boot baskets,bit sub,xo=233.22'.TIH t/10,944'. P/U swivel,up wt 148, dn wt 136,CBU @ 14Sgpm,285 psi.Slack off to latch fish,set 20k down p/u w/no over pull 2x,spudded on fish&it started to move down hole went down t/10,970'. P/U with no noticeable overpull or drag. L/D swivel. POOH w/BHA#2.L/D BHA#2,no fish. P/U BHA#3,Burn shoe w/cable catch,2 jts w/p,top bushing,LBS,Jars,6-4.75 collars,acc,xo=285.60'.TIH w/BHA#3.Calculated fluid loss after initial fill 109 bbls,0 loss f/today. 10/16/13-Wednesday Cont TIH t/10,970'tag fish,up wt145,dn wt 130.P/U swivel,wash down pushing fish down t/11,062'.Mill over fish t/11,073'rot wt 134,tq 4-5k circ 3 bpm,210psi.Circulate&condition fluid,wt up t/9.3ppg,circulate 1.5x balance out.L/D swivel&3 jts,POOH t/ BHA. Calculated fluid loss after initial fill 109 bbls,0 loss f/today. Hilcorp Alaska, LLC Alaska.W. Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 11-13RD 50-733-20026-01 191-133 10/8/2013 12/19/2013 Daily Operations: 10/17/13-Thursday Cont.L/D BHA#3 had piece of lower ring from packer and pieces of asphaltenes.P/u BHA#4 overshot w/ext&4-1/8"grapple,LBS, jars,6-4.75 drill collars,acc,xo=223.59'.TIH t/11,059',P/U swivel, up wt 148,dn wt 136,Washed down over fish @ 11,062'saw a pump increase going over shut pump down,slid down,set down 24k,p/u 20k over pull w/o coming free,p/u another 5 k and pulled free, set back down&stacked out picked up with no over pull,kicked pump on had an increase pressure build shut down pump. POOH,L/D BHA#4 no fish,had marks&metal shaving in 4-1/8"grapple. P/U BHA#5 overshot w/ext&4"grapple,LBS,jars,6-4.75 drill collars,acc,xo=223.07'.TIH t/11,059',P/U swivel,up wt 148,dn wt 138,Washed down over fish @ 11,062'saw a pump increase going over,set down on fish w/35k,p/u 19k over pull dropping off t/16k overpull,dropping off t/regular up wt,set back down stacking 305k,p/u with op of 14k,&12k falling back to original p/u wt. 10/18/13-Friday POOH w/BHA#5,w/no fish,had impression on outside of leading edge on overshot of packer slip,had metal shavings in grapple.Rig maintenance,clean&clear floor,conference call w/Engineers&fishing specialists discussing next runs.Wait on mill being dressed. Pull wear bushing&set test plug,m/u test jt,fill stack&valve manifolds w/water. Test BOP's as per Hilcorp&AOGCC regulations, witness waived by Jim Regg @ 16:47 on 10-18-13,test 250/2500 psi 5 min ea.R/D test jt,install wear bushing.P/U BHA#6,5-7/8" mill,boot basket,bit sub,magnet,jar,6-4.75 drill collars,xo=212.26'. TIH t/11,047',P/U swivel,get parameters,up wt 150,dn wt 135,rt wt 142,pump 135 gpm,285 psi,rot 55rpm,tq off 3.4k. 10/19/13/13-Saturday Tag tof @ 11,070'.Mill down 4.3't/11,074',up wt 150,dn wt 135,rt wt 142,pump 130 gpm,240 psi,rot 55rpm,tq off 3.4k on 4k. CBU. C/O tongs. POOH, L/D BHA, mill had good markings @ 4.25&3-3/8"along with other wear,magnet full&boot basket w/pieces of slips.P/U BHA#7,spear w/3.198 grapple,drain sub,LBS,jars,6-4.75 collars,xo,=226.81'.TIH t/11,074'tag tof,unable to get into fish. R/U&circ to try&clean tof still unable to enter. POOH,L/D BHA find no marking on spear.Clean&clear floor. 10/20/13-Sunday Wait on pilot style mill.Cut Drill line,plug rig components into platform power,replace snail on centrifugal pump for mud pump, general housekeeping. P/U BHA#8 pilot mill,2 boot baskets,bit sub,string magnets,LBS,jar,6 4.75 drill collars,xo,232.98'.TIH t/11,049',p/u swivel wk down to top of fish,up wt 150 dn wt 138 rt wt 140 tq 2k,off,3500 on,pump 90 gpm,150 psi,tag tof @ 11,074'.Mill on fish,p/u changing parameters,made 6"first hour,making no progress last 2 hours.POOH t/BHA,had small mark on pilot mill&good markings on upper mill.No fluid loss last 24hrs. 10/21/13-Monday Continue L/D BHA,clear tools f/rig floor.P/U BHA#8,Taper tap,xo subs,1-jt 3-1/2"PH-6 pipe,xo,LBS,jar,6-4.75 drill collars,acc, xo,=262.22'.TIH t/11,066',P/U Swivel,up wt 150,dn wt 138,wk down t/tof @ 11,074'tag,rot at 30 rpm,tq 4k,wk down on fish, stop rot,p/u,wk 3x tq out at 4k,p/u no over pull,L/D swivel.POOH,L/D BHA,taper tap came back engaged into seal bore ext. L/D fish,seal bore ext,2-7/8"pup jt perforated,xn,2-7/8"jt,xo,isolation tool,mechanical tubing release/wle guide. P/U BHA#9,Bit,7" scraper,bit sub,bumper,jar,xo,40 jts 3-1/2"tubing,db xo,9-5/8"scraper,bit sub,TIH t/10,995',(9-5/8"scraper @ 9,756'),Wk string 5x,up wt 142,dn wt,132,CBUx2,till clean pump 3 bpm,230 psi.No fluid loss last 24hrs. 10/22/13-Tuesday L/D swivel,POOH,f/10,995',L/D 9-5/8"&7"scraper BHA. P/U 7"RTTS BHA,=12.07'.TIH t/10,970'up wt 140,dn wt 132. Set RTTS @ 10,970'R/U&test casing t/1500 psi f/20 min good,bleed off,R/D,POOH,L/D 7"RTTS BHA. Pull floor pans,drip pan,flow line,install 13-5/8"x 7-1/16"spool,halls head adapter. Hilcorp Alaska, LLC iiikorp.11aska. Well Operations Summary Well Name _API Number Well Permit Number Start Date _End Date GP 11-13RD 50-733-20026-01 191-133 10/8/2013 12/19/2013 Daily Operations: 10/23/13-Wednesday Finish install of halls head/riser&re-install floor.Sort,prep&p/u BHA#10-Wavy btm shoe,7-jts 5.75 wp,xo bushing,top bushing, bumper sub,jar,6-4.75 dc,xo=434.23'.TIH slow to keep from over flowing,tag tof @11,125'.Wk on winterization for rig. Install Halls head element,p/u power swivel,get parameters,up wt 152,do 128,tq 3200 off on 4900,pump 3.5 BPM 260 psi. Attempt to wash over fish,no go,made approx.6-10"first 3 hrs,decide to POOH t/look at shoe. Pull halls head element,I/d swivel,POOH t/6933'.Calculated fluid loss after initial fill 109 bbls after pulling seals,no fluid loss last 24hrs. 10/24/13-Thursday HSM,Continued SOOH W/3-1/2"PH-6 WS,SB drill collars,6 joints of wash pipe,laid down single joint of wash pipe and burn shoe. Shoe completely worn out.ND Halls head adapter and flow nipple lines.Pulled wear bushing,installed test plug,Made ready to test BOP's.Set plug and started BOP test.Tested BOP's,annular 250 psi low/2500 psi high,all other BOP components 250 psi low/2500 psi high. Witness of test waived by Jim Regg,AOGCC. Sent all fluids in pits to production,started cleaning pit system. NU Halls head and hooked up flow nipple lines. 10/25/13-Friday HSM.MIRU slick-line unit.RIH W/5"LIB,tagged top of fish @ 11,128'. POOH,had single marks in center of LIB. RBIH W 4.5"LIB, tagged same depth. POOH,recovered identical marks on LIB.RBIH W/3"RE magnet,tagged TOF @ 11,128'.POOH,recovered 2 cups of metal debris,1 solid piece 3/4"X 3". RBIH W/same magnet,tagged same. POOH,recovered Gas lift latch,a long piece of metal and another solid piece which appears to be the balance isolation tool. RBIH W/magnet,POOH.Recovered fine shavings and debris. RBIH W/4.5 LIB,tagged top of fish @ 11,128'.POOH,2 small punctures on face of LIB,RDMO Slick line Unit.MU BHA#10-5-3/4" wavy bottom burn shoe,7 jts of 5-3/4"wash pipe,Bumper jar,oil jar,drill collars and 3-1/2"PH-6 WS. TIH W/173 stands and a single,tagged top of fish @ 11,126'. MU Power swivel set parameters and began burning over. Burned approx.3 inches and shoe fell approx.12 inches.Continue burning over TCP guns. 10/26/13-Saturday HSM.continued to burn over/wash over TCP guns,made a total of 3 ft with shoe.Turned shoe for 7.5 hrs total. Stopped making hole- total depth 11,128 ft.SOOH W/3-1/2 PH-6 WS,6 drill collars,7 jts of wash pipe,jars,and burn shoe,laid down burn shoe,shoe worn out and flared out to 6",has marks inside up to 2 ft.MIRU E-Line Unit.MU,RIH W/5"Rare Earth Magnet and centralizers,tagged top of fish @ 11,126'.POOH,recovered 13"body of Balanced Isolation tool.RBIH,tagged same,POOH,recovered small sliver of metal. RDMO E-Line Unit.MU BHA#11 (233.16')and TIH W/5.875 OD 3 blade Junk Mill,2 boot baskets,2 in-line magnets,bumper jar,oil jar,6 drill collars,and 133 stands of 3-1/2"PH-6 WS. 10/27/13-Sunday HSM.Continue TIH With BHA#10-5.875"3 blade junk mill on 3-1/2" PH-6 WS,tagged top of fish @ 11,128'.MU power swivel and pump line,broke circulation and began milling on fish @ 9:30 am. Took 3 hrs to make first 10 inches of hole,started milling a little better after first 10 inches. Continued to mill on fish until 1800 hrs,made total of 4'2",total depth 11,132'. No fluid loss during milling.Circ bottoms up,Shut down pump,RD pump line and Power swivel,and laid down 10 ft pup.SOOH W/3-1/2"PH-6 WS,SB 6 drill collars,laid down jars,laid down mill.Emptied pits while SOOH.RU E-Line Unit.RIH W/5"magnet,POOH,recovered fine metal shavings. Continued cleaning pits in preparation to run down hole camera.Filling pits with filtered inlet water to make 9.3 Kcl fluid. 10/28/13-Monday HSM.E-Line RIH W/4"LIB,Tagged top of fish @ 11,135'.POOH,LIB had marks in center,no distinct marks as to what we tagged. Loaded pits with 125 Bbls of filtered inlet water,mixed Kcl and oilfield salt to make 9.3 lb fluid. MU 3-1/2"mule shoe on 3-1/2"PH-6 WS,TIH,tagged TOF @ 11,131 ft. PU 1 ft off bottom,circulated 20 gallons of diesel and 380 Bbls of clean 9.3 fluids to production. Production sent fluids to Granite Point Tank Farm. Service Rig and equipment.Helicopters and boats on weather hold. Hilcorp Alaska, LLC ►:, �.,.►.lA Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 11-13RD 50-733-20026-01 191-133 10/8/2013 12/19/2013 Daily Operations: 10/29/13-Tuesday HSM.MIRU E-Line Unit.MU down hole camera and RIH,took pics/video of fish and casing above fish from 11,100'-11,132'.Images show tubing sticking up,and something inside tbg.Casing appears to be in good shape,perfs were clearly visible and looked good. POOH.RDMO E-Line Unit and equipment.RD pump in sub and TIW valve.SOH W/3-1/2"PH-6 WS,laid down 3-1/2"Mule shoe.MU BHA#14-Flat bottom shoe(6"OD),2 Jts of 5-3/4"Wash pipe,Bumper Jars,Oil Jars,6-Drill collars,and 173 stands of 3-1/2" PH-6 WS. PU Power swivel,MU swivel and pump line,broke circulation,tagged top of fish @11,130',started washing/burning over fish. Washed down 27ft,started taking weight and torqueing up,end of tools @ 11,157'. Continue to circulate off bottom and move pipe up and down to ensure free while repairing frayed torque cable. 10/30/13-Wednesday HSM.Fixed Power swivel tie back line. At 900 hrs-continued to wash over guns,stopped making hole @ 11,167'.Recovered asphalteens,rubber and metal across shakers.SOOH,Laid down Power swivel,removed halls head rubber, began SOH.SOOH W/ 173 stands of 3-1/2"PH-6 WS,laid down burn shoe,recovered 2 big pieces of metal. MU BHA#14,5-3/4"Wavy bottom shoe(5" ID),7 jts of wash pipe,bumper jar,oil jar,and 6 drill collars,TIH W/167 stands of 3-1/2 PH-6 WS. 10/31/13-Thursday HSM.MU Power Swivel,and Pump line,started pump @ 3.8 Bbls/min,445 psi,broke circulation. Tagged top of fish @ 11,167', started to burn/wash over,burn shoe torqueing from 3200 up to 6800 from start,burned over 1 ft in 4 hrs,very hard,no drag while PU,circulated 2 bottoms up. LD Power swivel.SOOH W/3-1/2"PH-6 WS,SB 6 Drill collars,laid down jars,SB 6 jts of wash pipe,when breaking connection between 6 and 7 jt,found 2-3/8"tbg sticking up,7th joint had fish in it,laid down fish,fish consists of 2-7/8"X 2- 3/8"crossover with 8 inches of 2-7/8"tube sticking up,3-2-3/8"X 10'pups,1-2-3/8"X 4'Pup,and a .70 bushing,recovered wireline cutter bar,and other materials,recovered 2.5 gallons of metal debris.1/2" up tp 7".ND Halls head rubber assembly and flow line. MU test plug on test joint.Pulled wear bushing,flipped test plug over and installed in well-head,loaded stack with fresh water, performed void test on Bop stack to ensure test plug set.Bop test was waived by Jim Regg to test on 11-1,called and received variance to test early by Jim Regg and Lou Grimaldi. Testing Bop's to 250 low and 2500 high,testing Annular to 250 low and 2500 high,all tested good. 11/01/13-Friday HSM.Pulled Test plug out of wellhead,replaced 0-Rings,greased and reinstalled,loaded riser and Bop stack with water,performed pre void test to 2500 psi,found 3 lock pins leaking on wellhead,bled pressure of bop stack,repacked inner packing and retightened, pins stopped leaking, got pre-test to 2500 to hold,started testing bop's,tested annular to 250 low and 2500 high,tested bop's to 250 low and 2500 high.All tested good.Recalibrated gas detection sensors,checked pressure in nitrogen bottles,replaced 2 Schrader valves on nitrogen bottles,pressured bottles back up to 1000 psi. Pulled test plug,installed wear bushing,NU Halls head rubber adapter and crossover flange to annular preventer,made up dresser sleeve and flow lines,re installed floor panels of rig floor.MIRU Slick line Unit.RIH W.3.5 Rare Earth Magnet,tagged top of fish @ 11,168'wlm,POOH.Recovered several big 1-1/2"pieces of wire- line tools and a cup full of smaller metal debris.MU 2.85 GR,RIH and Tagged fish same,worked gauge ring up/down several times to try and loosen up any debris left in hole,POOH.Metal marks on gauge ring. MU 4.5 Rare Earth magnet and RBIH,could not get past 7"Liner top,POOH. Recovered very fine metal shavings. MU 3.5"Rare Earth Magnet,tagged top of fish @ 11,168'wlm,POOH. Recovered several big pieces of metal,repeated run,no recovery except fine shavings.MU 3.5"LIB,RIH,Tagged top of fish and POOH, Impression shows top of guns. RDMO Slick-line Unit.Made up BHA#15. MU 5-3/4"OD burn shoe on 7 jts of 5-3/4"wash pipe,jars, oil jars,6 drill collars and 3-1/2"WS,TIH W/100 stands. 11/02/13-Saturday HSM.Continued TIH W/BHA#15,5-3/4"OD burn shoe on 7 jts of 5-3/4"wash pipe,jars,oil jars,6 drill collars and 3-1/2"WS,total of 176 stands and a single,tagged top of fish @ 11,168'. Worked shoe/wash pipe down 2 ft over 5 hrs,during process we were pumping 3.7 Bbls/min @ 475 psi,torqueing up from 3200 to 6800 ft pounds.Had trouble making hole,a total of 2 ft of hole made,total depth is 11,170'. Laid down power swivel and pump line.SOOH W/3-1/2"PH-6 WS,SB 6 Drill collars,laid down jars,SB 3 stands of wash pipe,had a single hanging with shoe MU,broke out shoe,shoe worn out.MU BHA#16,5-3/4"Flat bottom shoe(5"ID),7 jts of wash pipe,bumper jar,oil jar,and 6 drill collars,TIH W/176 stands and a single jt of 3-1/2"PH-6 WS,tagged top of fish @ 11,170'.RU Power swivel and pump lines,started pumping @ 3.8 Bbls/min @ 465 psi,broke circulation and began putting weight down on burn shoe. Torque running from 3300-6800 with 4-6 k down on shoe. Hilcorp Alaska, LLC �I,�•�:�.1.1.4' Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 11-13RD 50-733-20026-01 191-133 10/8/2013 12/19/2013 Daily Operations: 11/03/13-Sunday HSM,Continued burning over fish,took 1.5 hrs to break through hard spot and to get shoe to cut steady,shoe was torqueing up from 4200-6800,after the shoe stopped torqueing and started cutting steady,we made 1 ft of hole,Total depth is 11,171'.Recovered metal and rubber across shaker.,Shoe appeared to be worn out,Stopped swivel,ran pump up to 6.5 Bbls/min and circulated 2 bottoms up to ensure clean.Shut down pump,recovered metal and rubber. RD pump lines and power swivel,removed halls head rubber. SOOH W/176 stands of 3 1/2 PH-6 WS.Laid down worn out shoe„ MU BHA#17,5 3/4 Wavy bottom shoe(5"ID),7 jts of wash pipe,bumper jar,oil jar,and 6 drill collars,TIH W/176 stands and a single jt of 3 1/2 PH-6 WS,tagged top of fish @ 11,170.RU Power swivel and pump lines,started pumping @ 3.8 Bbls/min @ 465 psi,broke circulation and began putting weight down on burn shoe.,Torque running from 3300-6800 with 4-6 k down on shoe. Burned through hard spot and started making hole after 1hr, burned/washed down a total of 4 ft over 3.5 hrs. Shoe appeared to be worn out,Stopped swivel,ran pump up to 6.5 Bbls/min and circulated 2 bottoms up to ensure clean.Shut down pump,recovered metal and rubber., RD pump lines and power swivel,removed halls head rubber and started SOOH,SOOH W/21 stands of 3 1/2 PH-6 WS. 11/04/13-Monday HSM.Finished SOOH W/3-1/2"PH-6 WS,SB 3 stands of drill collars,laid down jars,SB 3 stands of wash pipe.Removed Burn shoe from single joint of wash pipe,burn shoe worn out.MU BHA#18,5-3/4"Wavy bottom shoe(5"ID),7 jts of wash pipe,bumper jar, oil jar,and 6 drill collars,TIH W/176 stands and a single jt of 3-1/2"PH-6 WS,tagged top of fish @ 11,170'. RU Power swivel and pump lines,started pumping @ 3.8 Bbls/min @ 465 psi,broke circulation and began putting weight down on burn shoe.Torque running from 4200-6800 with 4-6 k down on shoe. Tagged 1 ft higher than left off.Worked through 2 hard spots at 11,173'and 11,181'.Burned/washed down a total of 38 ft over 3.5 hrs.Total depth is 11,211'. Shoe appeared to be worn out,shut swivel down, ran pump up to 6.5 Bbls/min and circulated 2 bottoms up to ensure clean.Shut down pump,recovered metal and rubber. RD pump lines and power swivel,removed halls head rubber and started SOOH,SOOH W/147 stands of 3-1/2"PH-6 WS. 11/05/13-Tuesday HSM.Finished SOOH W/Remaining 26 stands of 3-1/2"PH-6 WS. SB 3 stands of drill collars,laid down jars,SB 3 stands of wash pipe, removed burn shoe from single joint of wash pipe,burn shoe worn out.MU BHA#19,5-3/4"Flat bottom shoe(5"ID),7 jts of wash pipe,bumper jar,oil jar,and 6 drill collars. TIH W/173 stands and a single jt of 3-1/2" PH-6 WS,tagged top of fish @ 11,210'.RU Power swivel and pump lines,started pumping @ 4.0 Bbls/min @ 400 psi,broke circulation and began putting weight down on burn shoe. Torque running from 4200-6800 with 4-6 k down on shoe. Tagged 1 ft higher than left off.Burned/washed down a total of 4 ft over 3.5 hrs.Total depth is 11,215'.Shoe appeared to be worn out.Shut down swivel,ran pump up to 6.5 Bbls/min and circulated 2 bottoms up to ensure clean.Shut down pump,recovered metal and rubber. RD pump lines and power swivel,removed halls head rubber.SOOH W/3-1/2"PH-6 WS,SB 3 stands of drill collars,laid down jars,SB 3 stands of wash pipe.Removed burn shoe from single joint of wash pipe and laid down joint of wash pipe.Burn shoe worn out.MU BHA#20,5-3/4"Overshot loaded with 3-3/8" grapple,bumper jar,oil jar,and 6 drill collars.TIH W/28 stands of 3-1/2"PH-6 WS. 11/06/13-Wednesday HSM,Continued TIH WI BHA#20,5"Overshot loaded with 3 3/8"grapple,bumper jar,oil jar,and 6 drill collars.TIH W/total 175 stands of 3 1/2"PH-6 WS,up weight is 151K.Attempted to engage fish,could not get latched up.MU Power swivel and attempted to work overshot over fish,PU,had over pull of 13k, Laid down swivel and SOOH,showed drag of 2-6K for several stands.SOON W/3 1/2"PH-6 WS,SD drill collars,laid down accelerator jar,broke down empty overshot,basket grapple show metal marks at entry point, appeared metal was deflecting before going inside grapple,marks show 4 5/8"outside to outside rings.MU BHA#21,5 3/4" Overshot loaded with 4 5/8"grapple,bumper jar,oil jar,and 6 drill collars.TIH W/total 175 stands of 3 1/2"PH-6 WS,up weight is 151K,attempted to engage fish @ 11,166'.Overshot and grapple went right on fish,PU had 10K over PU weight,Jarred overshot down on fish several times to ensure good bite,PU,pulled 45 K over pick up weight,guns started moving up hole.Continued to come out of hole,fish dragging from 10-45K over up weight,SOOH W/26 stands. 11/07/13-Thursday Continue POOH f/9,528',stand back collars,L/D jars,pull t/overshot w/guns,L/D 22-4 5/8"x16'guns&tail w/bull nose.RIH w/3 stands W/P,POOH&L/D same.RIH w/3 stands drill collars,POOH&L/D same.M/U BHA#22,8 3/8"taper mill,bit sub=6.13',N/D Halls head adapter.TIH t/TOL @ 9,787',P/U swivel,dress off TOL,rot wt 120,tq off 2500,on 3500,circ 3.5 bpm,240 psi.R/D swivel, POOH t/3,650'. Hilcorp Alaska, LLC tricor!) Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 11-13RD 50-733-20026-01 191-133 10/8/2013 12/19/2013 Daily Operations: 11/08/13-Friday Cont.POOH f/3,650'.L/D BHA#22 Bit sub,taper mill.M/U test jt,drain stack,pull wear bushing,set test plug,C/O 7-hanger L/D pins on well head.Test BOP's as per Hilcorp&AOGCC regulations,witness waived by Jim Regg @ 9:58 on 11-8-13,test 250/2500 psi,5 min ea,1 f/p on choke valve,cycle valve,refill choke manifold retest good.Pull test plug,set wear bushing,R/D test jt&L/D.R/U halls head adapter&lines,blow down surface lines,&choke manifold. P/U BHA#23,5 7/8" bladed junk mill,5.9"string mill,bit sub,oil jar,2-4 3/4"drill collars,xo=84.22'.TIH t/11,043'.Install halls head element.P/U power swivel. Wash&ream f/11,032't/11,136', up wt 148,dn wt 124,rot wt 140,circ 3.5 bpm,410 psi,tq 3600-3900. 11/09/13-Saturday Cont.wash&ream(/11,136't/11,446',up wt 148,dn wt 124,rot wt 140,circ 3.5 bpm,410 psi,tq 3600-3900.Tag fill @ 11,425' t/11,446'junk in hole on btm,pulled tight coming off btm.Circulate and condition fluid,circulate 1.5 hole volume @ 4.5 bpm 560 psi, weight system up t/9.8ppg. R/d power swivel&Halls head element,POOH,L/D BHA. R/u slick line W/caliper log,gamma CCL, temp tool. RIH w/logging tools,@ approx 7,700'pin on right angle drive to depth counter broke,repaired pin POOH w/logging tools.Re calibrate memory tools,surface test tools good.RIH w/logging tools t/tag @ 11,424',start log up @ 5:40. 11/10/13-Sunday Cont.memory log out of hole w/slick line caliper log,gamma CCL, temp tool.Out of hole with caliper log f/11,424',looked at logs had to make a 38'adjustment to line up t/perfs.Send data t/engineers for analysis.While waiting run 2.75 LIB t/11,434' bring out showing liner top markings otherwise clean.Run 2.25"bailer t/11,434'bring back sand.Logs came back showing caliper log starting at 11,378'.Discuss options,decide to run caliper log to try&get more data below perfs for liner set.M/U slick line W/caliper log, gamma CCL memory tools,program,surface test good.RIH t/11,438'log coming out of hole. Logs showing 14'good casing below perfs to set seals for liner.R/d slick line.PJSM,prep for picking up expandable liner.R/D Foster tongs,BJ's c/o slips&elevators,p/u Weatherford tongs,set up tq turn eq&test. Finalize running talley for liner,p/u handling tools).P/U Ex-80 5.5 od 17#Exp. pipe assy, shoe,launcher,1-anchor jt,9 full jts,top anchor jt,=395.32'tq.turn pipe t/1830#.R/D Weatherford tongs&elevators. R/u 2 7/8" handling tools. 11/11/13-Monday Cont.R/u 2 7/8" handling tools&p/u 20 jts 2 7/8" inner string w r/a marker 31.5'above liner top.TIH w/5.5 od 17#Exp.liner assembly on 3 1/2" PH6 work string t/11,323'tag up,(70'higher than needed)stood back stand,p/u single to work string,set down 10 k,pulled off 30k over.R/U e-line RIH w/gamma CCL tools verify string depth. R/d e/line. POOH w/5.5 od 17#Exp.liner assembly t/8,164'. Cut&slip drill line. Cont.POOH t/859'w/liner assembly. 11/12/13-Tuesday Cont.POOH w/liner assembly t/427'.R/u&L/d 2 7/8"inner string,finding small amount of sand on both debris catchers on inner string.R/u 5.5"liner handling tools.L/D EX-80 5.5"liner.C/O handling tools.P/U BHA#24,5 3/4"wavy btm shoe dressed 5 7/8",top bushing,xo sub,5.969 string mill,bit sub,5.875 string mill,oil jar,4-4.75 drill collars,xo=157.18'.TIH t/11,178'. Install Halls head element.P/u 4jts 3.5 wk string.TIH t/11,302'. P/u swivel,wash&ream f/11,302't/11,364',rot wt 140, tq 6300,circ @ 3.5 bpm, 220 psi. Hole tight from 11,317't/11,348',cycle through mupile times t/clean up.Cont.wash t/11,470',taking wt at 11,444',wash t/11,470',string packed off while reversing,attempt to clear unsuccessful.R/d swivel&start POOH. 11/13/13-Wednesday Cont/POOH wet.L/D BHA.There was some course sand carried out in plugged pipe& the shoe was broke off at box&left in hole. R/u E-line, ran in hole w/gamma ccl,junk basket,5.9'gauge t/11,450'. Set down @11,250'worked it&fell through,tagged bottom @ 11,450'.Logged coming up hole hung @ 11,350'worked free cont.POOH and R/D. Prep to run liner,c/o handling equip&prep liner. P/U Ex-80 5.5"od 17#Exp.pipe assy,shoe,launcher,12 full jts,top anchor jt,tq.turn pipe t/1830#,p/u inner string 20 jts 2- 7/8"inner string w/RA sub. TIH w/5.5"od 17#Exp.liner assembly on 3-1/2" PH6 work string t/6,085'. Hilcorp Alaska, LLC Ilil.•orpAlaska,LLl. Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 11-13RD 50-733-20026-01 191-133 10/8/2013 12/19/2013 Daily Operations: 11/14/13-Thursday Cont.TIH w 17#5.5" EX-80 Exp.Pipe on 3.5"work string tag btm @ 11,466' DPM. P/U to 11,446'. R/u E-line,GR/CCL,RIH t/tag @ 11,431'logged pass t/10,550'(RA marker @ 10,942'). Correlated to SLB CBL,POOH and R/D.R/U test lines t/3500,pump 20 bbls down work string,drop dart,pump down @ 3 bpm 260 psi,land dart pressure up t/1750 psi,slack off to put btm on correlated depth 11,451'. Expand 17#5.5" EX-80 Exp. Pipe to set,pump 1.5 bpm 3100-3300psi,land btm of liner @ 11,451',top @ 10,978',expanded id 5.33".R/U&pressure test liner t/1500 psi,30 min,&chart,good.R/d test subs&blow down lines.POOH.Run 4.75" DC out of derrick&L/D.R/D Halls head/flow nipple assembly,M/U test jt,pull wear bushing,set test plug. 11/15/13-Friday Cont.R/U test equip.Test BOPE as per Hilcorp&AOGCC regulations,witness waived by Jim Regg @ 1:24 on 11-14-13. Test BOPE 250 psi low,5000 psi high,test Annular 250 psi low,2500 psi high,good.Pull test plug,install wear bushing.Spot e-line equip.M/U Wireline conveyed(HSD)3-3/8"Power jet 3406,6 spf guns,GR/CCL,RIH,tie in from 11,310't/10,360'using SLB CMT log dated 3-3- 1992, placing top shot @ 11,205'elm,btm shot @ 11,215'elm,send correlation log t/engineer for confirmation. Fire guns,monitor hole, static POOH.L/D guns all fired.P/U gun assembly#2 RIH correlate same,set top shots @ 11,205',btm @ 11,215',fire guns, monitor hole static.POOH L/D guns all fired.R/d E-line equip. M/U halls head/flow nipple assy. 11/16/13-Saturday P/U BHA,7"packer,xo,R Nipple=11.98.TIH t/10,909' DP measurement._R/U test&chart packer t/2000 psi good,pressure up 600 psi p/u string,monitor for pressure loss,mark pipe where bypass opens,set down 40k on packer.R/U wireline make 2 runs t/10,900' set plug in R nipple.Test 3-1/2"PH6 workstring t/8000psi&chart,good.R/U wireline RIH&retrieve plug @ 10,900'. R/D test equip &winterize. Prep pits to move. Unload&spot sand king. Unload frac sand. 11/17/13-Sunday Install hopper&load frac sand into sand king. Install suction hose&flow line to pits. Install splash guard on handrails around frac equip.Run power for chemical tote heat blankets.Wait on weather. 11/18/13-Monday Unload frac equip from boat&spot.Hook up lines to 400 bbl upright tanks,unload chem totes&wrap w/heat blankets. Unload iron baskets&layout. 11/19/13-Tuesday R/u frac equip. Install HP lines,chemical totes,run cable etc.Frac crew cont r/u,rig crew mix 60 bbls 9.8 brine in pits,release packer let relax.POOH. 11/20/13-Wednesday R/D test eq.Set wear bushing,pull floor&install flange&flow nipple. TIH t/10,909'set packer. R/u&mix 60 bbls 9.8 brine. 11/21/13-Thursday Cont.mix brine.R/u t/test packer. Test frac packer @ 10,909'to 2000 psi, hold for 30 min&chart,good.R/U wireline.RIH t/10,900' set plug in R nipple. R/u&test tubing t/8600 psi f/30 min good. R/U wireline. Pull plug f/R nipple. R/d wireline. 11/22/13-Friday Tested packer bypass valve-good.R/u 3"lines t/workstring.PT lines t/11,000 psi against BH wheel valve-good. Set pop off. Pressure up annulus t/2,000 psi.Pump data frac.collect injection rate&pressure. Pumped 338 bbls total.Flush&blow down surface eq&lines. R/U e-line.RIH w/pressure/temperature survey tools t/4,700'unable to reach desired depth. 11/23/13-Saturday RDMO E-Line Unit and equipment. Loaded approx 200 Bbls of potable water from boat to up-right frac tanks.Installed frac equipment to well.Installed lines to/from blender to up right tanks,mixed fluids and kcl to 3%in tanks,made ready to attempt to frac.Primed all surface lines and tested Frac equipment to 11,050 psi against BH wheel valve. Set pop off @ 9980 psi,attempted to frac Hemlock.Purged and rigged down all frac equipment.Bled 1600 psi off annulus of well.SITP-4600 psi @ 3 am,bled down to 2600 psi recovering 20 Bbls of flush fluid.Shut tubing in to get rid of fluid on tank. Mixed kill weight fluid in rig pits to 9.8. Hilcorp Alaska, LLC ['item")Alaska.LIR: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 11-13RD 50-733-20026-01 191-133 10/8/2013 12/19/2013 Daily Operations: 11/24/13-Sunday HSM.Hooked up lines from rig tank to production.Pumped 53 Bbls of fluid from tank recovered while bleeding tubing down.Loaded 480 Bbls of potable water from boat to up right tanks. After bleeding tbg completely down,PU on 3"WS approx.4'-9"and shifted sleeve open.Monitored well as fluid u-tubed out of tubing from annulus.Once fluid stopped coming out tbg,PU to 128K and released Frac packer.Monitored open well,no change. Hooked up rig pump to annulus and pumped 43 Bbls of 9.8#kill fluid down annulus. Started getting pressure on tbg side.Shut down and monitored both tbg. Annulus open,showed to be u-tubing from kill weight fluid. Started recovering trace of oil.Circulated approx 850 Bbls down annulus out the tubing. Shut down and monitored well for an hour. Start TOH W/3-1/2"WS laying down single with crane.Laid down total of 108 jts of 3-1/2"WS. 11/25/13-Monday HSM.Continue TOH laying down 3" PH-6 WS. Laid down total of 314 joints. SOOH W/remaining 19 stands of 3-1/2"PH-6 WS.Laid down 7"Tri-point frac packer,sent to beach for rebuild. Loaded 314 jts of 3-1/2"PH-6 WS onto boat to send to beach.RD Halls Head Rubber adapter. NU Shooting flange and Lubricator crossover.MIRU E-Line Unit.RIH W/GR/CCL/CBL. Logged from 9,700'-11,438'. Tagged bottom @ 11,438'. POOH. MU 3-3/8"perf gun and GR/CCL.Correlating depths to perforate Hemlock. 11/26/13-Tuesday HSM.Continued to correlate perf depth with office and E-Line Unit.Logged short pass to ensure on depth. Perforated Hemlockfrom 11,205'-11,215'. Perforated with a single 10 ft gun(3 3/8"Owen gun,6 SPF,60%phasing). POOH. RDMO E-Line Unit and equipment. ND Shooting flange.NU Flow nipple and equipment for flow line,drained well head riser. Made ready to Test Bop's. Bop test waived by Jim Regg. Pulled Wear bushing and installed Test Plug.Loaded riser and performed void test against test plug. Begin Bop test.Tested Annular to 250 psi Low and 2500 psi high,test Bop's 250 psi low and 5000 psi high,test 3"Pipe Rams and 5"Pipe Rams.Off loaded and tallied total of 133 joints of 5"S-135 frac WS. 11/27/13-Wednesday HSM.Continue to prep rig and equipment for frac.Pumped 50 Bbls of 9.8 Kcl fluid from pits to production. Pressured wash pit system. Cleaned leg room 3 around well head. Purged all equipment for temperature change. Continue to install winterization enhancements.Tested BOPE 250 psi low/5000 psi high. Witness of test waived by Jim Regg,AOGCC. 11/28/13-Thursday HSM.Continue to prep rig and equipment for frac.Pumped 120 Bbls of filtered inlet water to rig tank. Mixed kcl and oilfield salt to weight up to 10pds/gallon fluid. TIH W/133 jts of 5"S-135 Drill Pipe. 11/29/13-Friday HSM.Continued SOH W/5"S-135.SOOH W/total of 66 stands. MU Frac BHA,2-7/8"mule shoe,1-10ft X 2-7/8"gauge carrier mandrel,X-Over,Tri-point frac packer,XN-Nipple w/RNP plug(no prong),X-over. TIH W/3-1/2"PH-6 WS,total of 54 jts.MU X-over and continued TIH W/5"S-135 WS. TIH W/total 210 joints of 5". 11/30/13-Saturday HSM.Continued TIH W/5"S-135 WS. TIH W/total of 282 jts, set packer @ 11,602'. EOT @ 10,613'.PU weight 236 K. RU test pump, tested and charted annulus/packer to 3000 psi,tested good. MIRU Slick-line Unit.RIH and set prong in plug @ 10,579'.RD moved out of the way. RU test pump on WS,attempted to test Tbg.TIW body leaking at 8300 psi.Bled pressure off.R/D TIW,set up to send to beach to be rebuilt. Hilcorp Alaska, LLC 1Ia•La.1.1.( Well Operations Summary _ Well Name API Number Well Permit Number Start Date End Date GP 11-13RD 50-733-20026-01 191-133 10/8/2013 12/19/2013 Daily Operations: 12/01/13-Sunday HSM.Laid down TIW valve,sent in for repair. MIRU Slick-line Unit.RIH W/2"RB,tagged plug @ 10,578'. Could not see prong latch. POOH. Attempted 2 more runs,no success,last run recovered grit and sand in RB.Installed TIW,RU 15 k pump,attempted to test/chart frac string,pressure up to 11,440 psi,pressure started falling immediately,could not see any leaks on surface.Decided to try and retrieve prong and plug to see if they were leaking.MU 2-1/4"Pump Bailer,RIH tagged fill @ 10,558'.Stroked bailer multiple times. POOH-Recovered 3/4 bailer body full of sand/scale. RBIH W/same bailer to 10,562',POOH,recovered very little fill in bailer. RBIH W/2 JU to 10,562',worked tools up/down several times,POOH,no recovery. RBIH W/2-1/2"Drive Down Bailer,to 8,913'sat down worked tools,tools sticky. POOH.RBIH W/1-3/4"Drive down Bailer to 10,520',worked tools several times and fell down to 10,571'.POOH,recovered 3/4 full of sand. RBIH W/1-3/4" Drive down bailer to 10,529'worked tool,fell down to 10,543'. Worked tool several times,fell down to 10,573'.Worked tool several times,POOH,bailer had very little fill in it.RBIH W/1 3/4 Drive down bailer to 10,576. Worked tool several times,POOH,recovered quarter sized piece of hard plastic and sand. RBIH W/2"JU to 10,573', Worked tool several times,POOH,no recovery. RBIH W/1-3/4"Drive down bailer to 10,576',POOH,recovered bailer full of sand. Continue to bail on top of prong and plug. 12/02/13-Monday HSM.Continued with slick-line operations. RIH W/1.75"DD Bailer to 10,529',worked tool a few times,tools fell to 10,573'. Worked tools,POOH,recovered 1/2 bailer body full of sand. RBIH W/1-3/4"Drive down bailer to 10,529', worked tool,fell down to 10,543', worked tool several times,fell down to 10,576',worked tool several times.POOH,recovered piece of plastic.RBIH W/2"JU to 10,573',worked tools up/down several times,POOH,no recovery. RBIH W/1-3/4"Drive down bailer to 10,574'.Worked tool several times,POOH,recovered 1/2 bailer body full of sand/mud. RBIH W/2-1/4"pump bailer to 10,572'.Worked tool several times,POOH, recovered sand. RBIH W/2-1/4" pump bailer to 10,572'.Worked tool several times,POOH,recovered sand. Also had new metal marks.RBIH W/2"JU to 10,578',worked tools up/down several times,POOH, no recovery.Tool was sheared. RBIH W/2"JD to 10,578,'worked tools up/down jarring for several hrs,finally came free.POOH,recovered Prong. RD moved out of the way.Hooked pump line up to pump down the annulus out the tbg to production,attempted to displace hole with 10 lb KWF. Attempted to pump down casing and out tubing,pressured up to 2700 psi with no returns. Bled pressure off and swapped to pump down tbg and out casing. Tubing pressured up immediately.Plug appears to be plugged off.RU slick-line.RBIH W/2-1/4" pump bailer to 10,572'. Worked tool several times,POOH,recovered very little sand. RBIH W/2"GS to 10,580',latched plug,stroked jars twice,plug come free. Start POOH,got to crossover at 8,913',could not get plug through cross over.Sheared off plug while trying to pull through X- over. Went back down to ensure not stuck in x-over,plug fell to bottom. POOH,RDMO slick-line. 12/03/13-Tuesday HSM.PU to 139k,released packer,laid down 1 jt of 5"S-135. Well started burping,hooked pump lines up to displace down casing out tbg to production.Circulated 600 Bbls of 10 lb KWF.Attempted to start TOH,could not get McCoy Tongs to break connections. Hooked McCoy unit to weatherford power pack,started laying down 5"S-135 WS. 12/4/2013-Wednesday Hook hawk jaw unit to Weatherford electric power pack.Begin TOH laying down 5"S-135 drill pipe at 3:00 pm,PU weight 248K,laid down total of 95 joints of 5". Started SOOH W/5"S-135,SOOH W/total of 55 stands,loaded hole every 5 stands coming out. Off loaded boat and back loaded weatherford equipment to beach. Hilcorp Alaska, LLC HiIcorpAlaska,IAA Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 11-13RD 50-733-20026-01 191-133 10/8/2013 12/19/2013 Oiry:. 14:: r r x..ut:aca"�+ps�...� n •'� ,.w Feu 2x;. *1°ax� s, ��s>� sur�.nr .�.m� R �.�naxxacr a...o,� `"s.,� �+, .a.�,. �u� rer ,�� ,.�,s�am��.,,, ws.�r�,��; .x.ca.<u�.-.��uox�<,. �� .. 12/5/2013-Thursday Continued SOOH W/5"S-135 WS,total of 95 stands in the derrick,Laid down X-over with RN Plug stuck in it.Continued SOOH W/3- 1/2"WS,SB total of 27 stands of 3-1/2"PH-6 WS,Laid down R-nipple,Packer and memory tool. Made up 3-1/2"test joint on test plug. RIH and pulled wear bushing, turned plug over and set in wellhead,loaded riser,bop stack,and manifolds with water. Tested void to 3,000psi. Performed Bop test 250psi low and 5,000psi high on all bop equipment except annular. Annular test 250psi low and 2,500psi high. Test Pipe rams on 3-1/2"WS and 5"S-135 WS,both to 250psi low and 5,000psi high. Pulled test plug. MIRU Moncla Foster tongs,MU Frac BHA,2-7/8"mule shoe,1-10ft X 2-7/8"gauge carrier mandrel,X-Over,Tri-point frac packer,R-Nipple w/RNP plug and prong,X-over. TIH W/3-1/2"PH-6 WS,total of 27 stands. Tested to 10K,continued TIH,picking up singles off deck with crane,TIH with 18 more singles,total of 36 stands and BHA in hole. Loading tbg while TIH. 12/6/2013-Friday Continue to TIH WI 3-1/2"PH-6 WS,tested BHA and 3-1/2"to 11k,tested good,MU X-over 4"IF X 3-1/2"PH-6,TIH W/12 stands of 5"S-135 WS,tested X-over and 12 stands to 10k,tested good. Continued to TIH W/95 stands 5"S-135 from derrick,tested to 10K psi, tested good. Continue to TIH W 5"singles off of west deck,TIH W/total at 54 singles,set packer @ 10,600 ft,left EOT @ 10,610 ft. Loaded and tested Annulus to 3K,charted for 20 mins,test good. 12/7/2013-Saturday RU pump line to annulus,pressured up on casing to 3,000psi,tested and charted for 20 mins,tested good. MIRU Baker Pump Iron to rig floor and to top of TIW valve,attempted to test to 11,400',pressured up on WS,had 106psi/min leak off on WS,attempted to make minor changes and retest,no change. Leak off the same,106psi/min.;Attempted to test tbg 5 times,isolating different valves and iron. Contacted AOGCC engineer and received confirmation to perform job as planned. Confimation come via email by Guy Swartz. MIRU Pollard Slick-line unit,RIH W/2"JD tool to 10,610,could not latch fish. POOH,no recovery. RIH W/2"JU tool to 10,610,worked tool several times,could not latch fish. POOH,no recovery. RBIH W/2.25" drive down bailer,tagged same depth @ 10,610',worked bailer several times,POOH recovered bailer half full of scale. RBIH W/2.25"drive down bailer,RIH tagged fill @ 10,611'. Stroked bailer multiple times,POOH recovered 1/4 bailer body full of sand/scale. RBIH W/same bailer to 10,611'. POOH, recovered 3/4 full in bailer. RBIH W/same bailer to 10,613'. POOH,recovered very little fill in bailer. RBIH W/2 JU to 10,613', worked tools up/down several times,showing 300 psi over pull every time,POOH,no recovery. 12/8/2013-Sunday RBIH W/2.25"Pump Bailer to 10,618',W/T,POOH,recovered full bailer. RBIH W/2.25"Pump Bailer to 10,618',W/T,POOH, recovered full bailer. RBIH W/2.25"dump bailer to 10,618',WIT,POOH,recovered full bailer. RBIH WI same bailer to 10,618',W/T, POOH,recovered 1/2 full bailer. RBIH W/same bailer to 10,620',WIT,POOH,recovered 1/2 full in bailer.RBIH WI same bailer to 10,621,W/T,POOH,recovered 1/4 full in bailer. RBIH W/same bailer to 10,621',W/T,POOH,recovered 1/8 full in bailer. RBIH W/ same bailer to 10,622',W/T,POOH,recovered 1/8 full in bailer. RIH W/2"JU tool to 10,621',worked tool several times,could not latch prong. POOH,no recovery. RIH W/2.5"GS to 10,623',worked tool several times,could not latch fish. POOH,no recovery. RBIH W/1.75"dump bailer to 10,623,W/T,POOH,recovered 1/2 full bailer. RBIH W/2.25"dump bailer to 10,623',W/T,POOH, recovered full bailer. RBIH W/2.25"Pump Bailer to 10,623',W/T,POOH,recovered full bailer. RIH W/2.5 GS to 10,624',worked tool several times,latched plug,jarred several times,plug came free. POOH,recovered plug,RDMO Pollard Slickline Unit and equipment. Hooked up frac stand pipe and frac equipment,Baker started equipment and prime all equipment,ready_to frac. Hilcorp Alaska, LLC Ililcorp:,1aska.LLI: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 11-13RD 50-733-20026-01 191-133 10/8/2013 12/19/2013 Daily Operations: 12/9/2013-Monday Hooked up frac equipment,stand pipe to well head,tested iron to 11,200psi,set 3 pumps,pop offs @ 9,600,9,700,9,800. Performed mini frac to collect data for frac job,during mini frac valve body of 15K TIW started leaking,finished mini frac,recorded leak off test, bled well down,swapped TIW valve to 10K valve and notified AOGCC,gave verification that was OK to continue with frac job. • Retested frac lines and tested TIW to 11K,tested good.Baker Hughes performed frac to Hemlock zone,placed approx.47,483 lbs of sand to reservoir. We left a total of 10,117 lbs of carbo bond in pipe when it screened out. Shut down frac. Total Bbls pumped 699 Bbls.Recorded leak off again and bled pressure down to 4,500psi. Average treating pressure 8,650psi @ 12 Bbls/min. Started flowing well back to pits,recovering sand and gel,flowed back approx 245 Bbls,started seeing trace of oil,shut well in,SITP-600 psi. Started cleaning up decks,RDMO Baker equipment,removed 3 pumps,blender and 3 baskets of iron and misc.equipment. 12/10/2013-Tuesday Monitor Shut in well pressure,remove frac equipment from deck, clean frac sand out of WOR manifold,lines,and pits. Move WO pit system back into place,and hook up pit equipment. Shut well in at 4 am,SITP-400 psi,SITP at 6 pm is 1,000 psi. Hooked well up to production,started flowing well to production. Loaded pits with 3%left from frac and mix Kcl/salt to make 10 ppg KWF. Continued to off load frac equipment to boat,had to stop due to high winds. PU on WS to 248K and packer released. Pulled up hole 10 ft,shut pipe rams on 5",hooked lines up to circulate down annulus out the tbg to production. Circulated first 150 Bbls of 10 ppg kwf to production. 12/11/2013-Wednesday HSM.Mixed and circulated 280 Bbls of 10 ppg KWF down the annulus out the tbg to production.Shut down pumping and monitored well for 20-30 mins,well appeared to be static. Started TOH laying down 5"S-135 Frac WS,laid down total of 68 jts,filling hole every 10 jts out.HSM with Slick-line. MIRU Unit.RIH W/1-3/4"drive down bailer,tagged fill @ 11,003',W/T several times down to 11,007' wlm. POOH.Recovered frac sand in bailer. RDMO SLick-line Unit.Continued laying down 5"S-135 Frac WS,laid down a total of 155 joints of 5"WS. 12/12/2013-Thursday Cont.L/D 5"DP,88 jts,243 total. C/o derrick fingers,I/d hawkjaw,r/d Weatherford power pack,c/o handling tools t/3 1/2",POOH 3 1/2"ph6 work string&stand back. L/D r nipple,packer,gauge carrier&mule shoe.M/U test jt,pull wear ring,set test plug,fill stack. Test BOPE as per Hilcorp&AOGCC regulations,witness waived by Jim Regg @ 14:56 on 12-11-13.Test BOPE 250 low,5000 high,test Annular 250 low,2500 high,had issues with test plug leaking, repair&cont.test,all good. 12/13/2013-Friday Pull test plug.Install wear ring.L/D test jt,blow down surface lines&eq.C/o handling tools t/2-7/8".C/O flow nipple t/halls head assy.P/U c/o assy.2-7/8"PH-6 mule shoe,19 jts 2-7/8"PH-6 tubing. C/O handling eq.P/U 3-1/2"RTS-8 tubing t/6,538'. P/u 190 jts. 12/14/2013-Saturday Cont. p/u 3-1/2" RTS-8 tubing f/6,538't/8,729'.P/u 260 jts total. RIH w/9 stands of 3-1/2" PH-6. POOH w/same&I/d 18 jts,TIH w/ 36 stands 3-1/2"PH-6 t/10,961'. Install Halls head element,shaker chute,catch pan&cuttings tank.Mixing 100 bbls of 10 ppg brine. R/U power swivel lines&P/U swivel&warm up.Wash down f/10,961't/11,023',up wt 112 dn wt 98,circ @ 4.5 Bpm,cbu fluid weight dropped f/9.9 t/8.5 @ bu carring frac sand.Circulate&condition fluid,weight up light fluid to balance system. Cont.wash t/11,085',pump 4.5 bpm,540 psi. 12/15/2013-Sunday Cont.wash f/11,085't/11,466'dpm,@ 4.5 bpm,480 psi, up wt 120,dn wt 105,recovered 11.3 bbls frac sand. No sand recovery last 71',lost 28 bbls while cleaning out.CBU x2,clean @ 4.5 bpm,480 psi.Service rig.R/d swivel,halls head element,blow down stand pipe&mud manifold,while monitoring hole,static.POOH t/8,731'. L/d 3-1/2"PH-6 tubing,89 jts,filling hole every 20 jts,POOH t/4,105'w/3-1/2"RTS-8 tubing,stand back in derrick. Hilcorp Alaska, LLC Hilcorp Alaska,1.1.<: Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 11-13RD 50-733-20026-01 191-133 10/8/2013 12/19/2013 Daily Operations: 12/16/2013-Monday Cont POOH f/4,105'w/3-1/2"RTS-8 standing back in derrick t/599'.L/D 2-7/8"19 jts PH-6 tubin.e.Clean.&clear rig floor.Pull halls head adapter off,install flow nipple&flow line,pull wear bushing.R/u t/run Gas lift completion,spot spooler&install sheave in derrick. R/U clamp tools,stock rig floor w/cannon clamps.Run 3-1/2"RTS-8 9.3# L-80 gaslift completion as per program.P/U WL re- entry guide,x-nipple,(1)3-1/2"jt EUE tubing,pup jt,7"hyd.retrievable packer,pup jt,xo t/3-1/2"RTS-8,pup jt,chemical injection sub,pup jt,pup jt,sliding sleeve,pup jt,pup jt,GLM#1 pup jt.Install chemical injection line&test connection t/1200 f/5 min good, test valve at 2650 good.Cont.p/u 3-1/2"RTS-8 completion t/4,674'=143jts&8 GLM,installing cannon clamps every other connection,&top&bottom of every GLM. 12/17/2013-Tuesday Cont.p/u 3-1/2"RTS-8 completion F/4,674't/9,803'up wt 98,dn wt 82. Wk pipe to get through liner lap,pump 3 bpm @ 130psi wk pipe until fall through tagged up again @ 9,810'&9,848',r/d circulating line&blow down surface eq. Cont.p/u 3 1/2"RTS-8 completion t/10,606',p/u SCSSV,install control line&function test valve,test t/5,000 f/15 min good. Cont.p/u 3-1/2"RTS-8 completion t/10,890'. P/U FMC 13-5/8"5m Hanger M/u control line&test same good,land hanger,verify landed good,up wt 104, dn 90,p/u 390 jts total,&11 GLM,180 single line cannon clamps,4 dual line clamps,9 bands. Drop bar,pressure UP t/3,500psi set packer @ 10,882',tubing @ 10,932'. 12/18/2013-Wednesday Cont.packer setting procedure holding 3,500 psi f/15 min,bleed down,r/u test packer t/2,000 psi,had leak on hose connection at wellhead,repaired&re-tested t/2000 f/10 min&charted,good. R/u wireline,rih run#1 w/2"JDC pull prong,run#2 rih w/GS& pulled RHCP plug. Clean BOP stack,pump out pits t/production,r/d suction lines f/pits t/pump,r/d discharge lines&pop off lines f/ pump. Prep pump t/move. Clean pits,pull floor,n/d flow nipple,annular,double-gate,mud cross&riser. Prep wellhead for tree connection. 12/19/2013-Thursday N/u tree,test void t/250 low&5,000 high hold each 10 min good,test tree 250 low 500.0 high. Hold each 10min good,turn over t/ Production. 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O C 4J N C p J m 0 C) H— O m W Li X S X x k Z c Advancing Reservoir Performance .�:■ axons Hilcorp Alaska LLC Granite Pont St 11 13R A • POST TREATMENT REPORT Granite Point St 11-13RD API#:50-733-20026 Hemlock Formation Kenai Offshore County,AK Job#: 10011027677 Proposal#: 1001162089C Presented To: Prepared By: Mr. Reid Edwards Nicolas Ricca Field Engineer Date of Completion: December 9,2013 Advancing Reservoir Performance 11111. Well Information General Well Data Well Name: Granite Point St 11-13RD Date Started: 12/9/2013 Stage: 1 Date Completed: 12/9/2013 County,State: Kenai Offshore County,AK Treated By: Justin Baldwin API#: 50-733-20026 Engineer: Nicolas Ricca Perforations Perforation Summary Measured True Vert. Perf Dia. Number of Perfs: 60 1: 11205-11215 11077-11087 0.400 Perf Diameter: 0.4 Shots Per Foot: 18 Wellbore Data MD ND Casing OD Weight 1 10978 10978 7.00 32 2 11515 11082 5.92 17 MD ND Tubing OD Weight 1 5 15 7674 7674 1 3.5 9.3 10609 10609 Reservoir Data Formation Hemlock Formation Type Conglomerate Design F.G. 0.85 psi/ft Design BHFP 9420 psi Design BHST 190°F Advancing Reservoir Performance g. Job Summary Injection Rate Iniection Pressure Job Average: 11.1 bpm Job Average: 8607 psi Job Maximum: 12.7 bpm Job Maximum: 9984 psi Job Pressures Max Allowable(psi): 10000 psi Pre ISDP: 6173 psi Post Job: WHP(psi): 455 psi 5 min: 4617 psi 5 min: 8298 psi 10 min: 4080 psi 10 min: 8111 psi 15 min: 3582 psi 15 min: 7954 psi Proppant Fluid Volume Carbolite: 38400 lbs Pad Volume: 149 bbls CarboBond Lite 20/40: 19200 lbs Treatment Volume: 403.8 bbls Flush Volume: 98.2 bbls Chemical Inventory Chemical Proposed Planned For Actual Variance GLFC-5D111111.11111.111111111W 241.6 293.5 Lbs 3.68% BF-8L 108.0 45.9 36.5 Gal -20.42% XLW-30AGA Gal -0.84% FloBack 30 59.0 25.4 30.0 Gal -11.45% ClayMaster 5C 59.0 25.4 23.0 Gal -13.42% Enzyme G HT-III 19.0 30.9 95.0 Gal -4.57% HP CRB-LT 74.0 20.0 20.0 Lbs 0.00% X-Cide 207 25.0 12.0 12.0 Lbs 0.00% GBW-18 0.0 10.0 10.0 Lbs 0.00% Advancing Reservoir Performance :. BAKER HUGHES Job Notes & Appendix Stage 1:Ran DFIT before pumping frac job,determined fluid efficiency to be approximately as planned. Added 0.5 scour, then pumped according to design. During 4 ppg stage,pressure began steadily increasing,and continued during 5 ppg stage and flush until pumps started kicking out. Flushed 98 bbls,leaving 10117 lbs of CarboBond Lite in the pipe. Appendix- -Treatment Report - Design Worksheet -Stage Summary - Chemical Variance -Chemical Load Sheet -Treatment Charts -Quality Control - Fann 50 Breaker Test - Proposal - Field Receipt ri- IMULATION TREATMENT REPORT J BAKER HUGHES Date 09-DEC-13 District Kenai F.Receipt 10011027677 Customer HILCORP ENERGY CO Lease GRANITE PT ST#11-13RD Well Name GRANITE PT ST#11-13RD Field GRANITE POINT Location GRANITE POINT PLATFORM County Kenai Offshore State Alaska Stage No 1 Well API -API 50733200260000 WELL DATA Well Type: OLD Well Class: OIL Depth TD/PB: 11205 Formation: Geometry Type Tubular Type OD Weight ID Grade Top Bottom Perf Intervals TUBULAR DP 5 17.93 4.276 P-110 0 7674 Top Bottom SPF Diameter TUBULAR CSG 7 32 6.094 0 11510 11205 11215 18 .4 TUBULAR DP 3.5 13.3 2.764 7674 10609 Packer Type Packer Depth 10609 FT TREATMENT DATA LIQUID PUMPED AND Fluid Type Fluid Desc Pumped Volume(Gals) Prop.Description Volume Pumped(Lbs) CAPACITIES IN BBLS. TREATMENT FLUID Lightning 3000 23.218 CARBOLITE.20/40 38.400 Tubing Cap. 160 TREATMENT FLUID Linear Gel 37.850 CARBOBOND LITE 20/40 19.200 Casing Cap. 19.5 TREATMENT FLUID Linear Gel 4.124 TREATMENT FLUID Lightning D 3000 28.166 Total Prop Qty: 57,600 Annular Cap. 342 PAD 3%KCI 5.082 Open Hole Cap. 0 Fluid to Load 0 Pad Volume 398 Previous Treatment UNKNOWN Previous Production UNKNOWN Treating Fluid 1197 Hole Loaded With BRINE Treat Via:Tubing 0 Casing ❑ Anul. ❑ Tubing&Anul. ❑ Flush 98 Ball Sealers:_ 0 _In. 0 Stages Type Overflush -80 Auxiliary Materials 10o MESH 1400# Fluid to Recover 1693 PROCEDURE SUMMARY Time Surface Slurry Slurry Rate AM/PM Treating Pressure-Psi BBLS.Pumped BPM Comments STP Annulus Stage Total 00:00 0 0 0 0 0 7-17-13 05:15 0 0 . 0 0 0 Yard Call,J.Baldwin,J.Cress,T.Mount,J.Waters 16:30 0 0 _ 0 0 0 oticed damage to frac pump,called into inform yard 17:15 0 0 0 0 0 Call yard and ordered fuel hose extensions,had bulk plant re- load gel from broken tote into new 18:30 0 0 0 0 0 Crew arrive on platform,C.Zoda,J.Payne,Rob,Verrenge, Gonzo,J.Waters,Steve Hoffine,James Cress Back to beach 19:00 0 0 0 0 0 Crew in site oriantation 19:45 0 0 . 0 0 0 PJSM with production,crew,rig crew 20:00 0 0 0 0 0 Rig up for frac 00:00 0 0 0 0 0 11-19-13 00:00 0 0 . 0 0 0 All but 3 crew to bed,3 personnel to re-spot frac pump 08:00 0 0 0 0 0 Pre-Job rig up meeting 10:00 0 0 0 0 0 Wait on crane,Salt water pump went out at night,crane was needed to pull pump 11:00 0 0 0 0 0 Still on stand by for crane 12:29 0 0 0 0 0 Start with crane,finish up iron,spot KCL pallets,Spot chem totes 14:00 0 0 , 0 0 0 Iron rigged up,start bucket testing 19:00 0 0 I 0 0 0 Rig up to KCL tanks,blender wont start,re-rig air supply to start unit 00:00 0 0 0 0 0 11-20-13 01:30 0 0 0 0 0 Rig up 2nd water tank to KCL,crane back from dinner,hang hose in tank,had to unbolt tank lids 03:30 0 0 0 0 0 Finish up last KCL tank,Start Blow down 06:00 0 0 0 0 0 Finish blow down,crew to bed 14:00 0 0 _ 0 0 0 PJSM,Fill out permits,HRA'S 20:35 0 0 0 0 0 2 Injuries on rig not involving Baker,Running Ian and troubleshooting 22:39 0 0 _ 0 0 0 Shut down,secure equipment,crew to bed 00:00 0 0 0 0 0 11-21-13 09:30 0 0 0 0 0 Safety Meeting,fill out permits Renee Printed on:December 9,2013 5'.18 PM Jr8000 Treatment Report-Supplement NKN \ ) Date_ 09-DEC-13 District Kenai F.Receipt 10011027677 Customer HILCORP ENERGY CO Lease GRANITE PT ST#11-13 Well Name GRANITE PT ST#11-1 Field GRANITE POINT Location BJS.KENAI County Kenai Offshore State Alaska Stage No 1 Well API -API 50733200260000 TIME Treating Pressure-Psi Surface Slurry Slurry Rate Comments BBLS.Pumped BPM STP Annulus Stage Total 00.00 0, 0 0 0 0 7-17-13 05.15 0 0 0 0 0 Yard Call .1 Baldwin,J Cress,T Mount .1 Waters 16:30 0 0 0 0 0 oticed damage to frac pump.called in to inform yard 17:15 0 0 0 0 0 Call yard and ordered fuel hose extensions,had bulk plant re- load gel from broken tote into new 18:30 0 0 0 0 0 Crew arrive on platform,C.Zoda,J.Payne,Rob,Verrenge, Gonzo,J Waters Steve Hoffine James Cress Back to beach 19.00 0 0 0. 0 0 Crew in site orientation 19.45 0 0 0 0 0 PJSM with production,crew,rig crew 20.00 0 0 0 0 0 Rig up for frac 00.00 0 0 0 0 0 11-19-13 0000 0 0 0 0 0 All but 3 crew to bed,3 personnel to re-spot frac pump 08.00 0 0 0. 0 0 Pre-.lob rig up meeting 10:00 0 0 0 0 0 Wait on crane,Salt water pump went out at night,crane was needed to pull pump 11.00 0 0 0 0 0 Still on stand by for crane 12:29 0 0 0 0 0 Start with crane,finish up iron,spot KCL pallets,Spot chem totes 14.00 0 0 0 0 0 Iron rigged up start hucket testing 19:00 0 0 0 0 0 Rig up to KCL tanks,blender wont start,re-rig air supply to start unit 0000 0 0 0 0 0 11-90-13 01:30 0 0 0 0 0 Rig up 2nd water tank to KCL,crane back from dinner,hang hose in tank.had to unbolt tank lids 0330 0 0 0. 0 0 Finish up last KCL tank Start Blow down 06.00 0 0 0. 0 0 Finish blow down crew to hed 1400 0 0 0 0 0 PJSM Fill out permits,HRA'S 20:35 0 0 0 0 0 2 Injuries on rig not involving Baker,Running Ian and troubleshooting 92.39 0 0 0 0 0 Shut down secure equipment.crew to bed 0000 0 0 0 0 0 11-21-13 09.30 0 0 0 0 0 Safety Meeting fill out permits 1000 0 0 0 0 0 Start all equipment 1200 0 0 0 0 0 Rotate crew to lunch 13.00 0 0 0 0 0 Run heater to hydration 14.00 0 0 0, 0 0 All Equipment runnig waiting on e-line before we start mini frac 1827 0 0 0 0 0 Shutdown equipment crew off 00.00 0 0 0 0 0 11-92-13 07.00 0 0 0, 0 0 Crew up Pollard e-line crew on board 07.50 0 0 0 0 0 work permit and hot work permit sighned off 08.11 0 0 0 0 0 equipment running 08:29 0 0 0 0 0 PJSM with all crews,Rig,Production,Baker Hughes,Pollard, ELY 08.50 0 0 0 0 0 Circulate chemicals,Rig up floor 10.15 0 0 0 0 0 Rigging up stand pipe 11.30 0 0 0 0 0 All Rigged up ready to PT.Crew sent to lunch 1200 0 0 0 0 0 Back nn deck ready to PT 1295 0 0 0 0 0 Prime tnicks 1245 0 0 0 0 0 PT lines to 11000,check the check valves Treating Pressure Injection Rates Shut In Pressures Customer Rep. Dan Taylor • Minimum 7334 Treating Fluid 11.1 ISDP BJ Rep. JUSTIN BALDWIN Maximum 9984 Flush 7.4 5 Min. 8298 Job Number 10011027677 Average 8607 Average 11.1 10 Min. 8111 Rec.ID No. Operators Max.Pressure 15 Min. 7954 .Distribution 10000 Final 4288 In Min. 25 Flush Dens.lb./gal. 8.48 Report Printed on:December 9,2013 5.18 PM Jr8001 ri ( Treatment Report-Supplement BAKER HUGHES Date 09-DEC-13 _ District Kenai F.Receipt 10011027677 Customer HILCORP ENERGY CO Lease GRANITE PT ST#11-13 Well Name GRANITE PT ST#11-1 Field GRANITE POINT Location BJS,KENAI County Kenai Offshore __State Alaska Stage No 1 Well API -API 50733200260000 TIME Treating Pressure-Psi Surface Slurry Slurry Rate Comments BBLS.Pumped BPM STP Annulus Stage Total 1254 0 0 0 0 0_PT lines stepped pressure with individual truck 12.57 0 0 0 0 0 Bleed off to well 1259 0 0 0 0 0 Set N2 psi to 400 1310 0 0 0 0 0 425 psi on n2 13:42 0 0 0 0 0 9750psi,multiple pops of pop off to confirm,co man said ok to 9750 1345 0 0 0 0 0_Gell up hydration 1 - • 1 48 9 0 Start mini frac. 15.35 0 0 140 188 9 0,open well 16:30 0 0 0_.-_ 188.9_ 0,shutdown 16.46 0 0 0 188 9 0 Gell up again 1713 0 0 0 188.9 0 Ready to pump 17.14 0 0 181 369 9 0 Open to pumps 17.36 0 0 0 369.9 0_shutdown mini frac 17:17 0 0 0 369.9 0 Truck one taken offline,due to lack of discharge pressure from blender.Increased discharge pressure from blender truck back or 1744 0 0 0 3699 0 open to trucks 17.58 0 0 0 369.9 0 Bleed down to 2500 18:00 0 0 0 369.9 0 Stoped bleeding down, Let psi level out,closed in well with 4600psi 18.17 0 0 0 369 9 0_Stop Job on Job master 1918 0 0 0 369 9 0 Fan Pumps blow down equipment,lines hoses 21.35 0 0 0 369.9 0 Finish Blow down 21.45 0 0 0 369.9 0_Post Job Meeting with crew 22.00 0 0 0 369.9 0 Crew to bed Wake up time 0800 00.00 0 0 0 369 9 0 11-23-13 0800 0 0 0 369 9 0 Crew up talk with customer 0845 0 0 0 369 9 0 Pre job safety meeting permits sighned off 09.:00 0 0 0 369 9 0 KCL Tanks 12,3 1250 0 0 0 369.9 0_Rig Floor rigged up 13:15 0 0 0 369.9 0 Helicopter tied up crane,need crane to spot enzime tote,and 100 mesh at blender 1341 0 0 0 369 9 0 Crane moving 100 mesh and en7ime to blender 1.513 0 0 0 369 9 0 Prime trucks,Go through valve line up 15:20 0 0 0 369.9 0 Closed valve on blender,viberated shut,couldnt get water to blender 1526 0 0 0 369.9 0_prime stand pipe to well 15:28 0 0 0 369 9 0 equalise to open TIW 2100psi 15.29 0 0 0 3619 0 Well open, 1600psi 1530 3500 0 0 369 9 0 shutdown,close 3"frac valve to test lines 15:32 0 0 0 369.9 0,PT I ine_step trucks up to 11000psLcheck the check valves 15.36 11050 0 0 369 9 0,Check valves hold hold test 5 minutes 15.41 10907 0 0 369 9 0 Pressure test pass 1543 0 0 0 3699 0_test/set N2 Pop Off,403 psi valve pressure 1547 0 0 0 369 9 0 Test pop off 15:48 0 0 0 369.9 0 Pop off set to 10,032psi,ok by Reid Edwards and Donny Huffman 15:50 0 0 0 369 9 0 Spool down unit 1555 0 0 0 369 9 0 Flowback in tub of blender,tracing out chemical hoses Treating Pressure Injection Rates Shut In Pressures Customer Rep. Dan Taylor Minimum 7334 Treating Fluid 11.1 ISDP BJ Rep. JUSTIN BALDWIN Maximum 9984 Flush 7.4 5 Min. 8298 Job Number 10011027677 Average 8607 Average 11.1 10 Min. 8111 Rec.ID No. Operators Max.Pressure 15 Min. 7954 Distribution 10000 Final 4288 In Min. 25 Flush Dens.lb./gal. 8.48 Report Printed on:December 9,2013 5:18 PM Jr8001 Treatment Report-Supplement BAKER HUGHES Date 09-DEC-13 District Kenai F.Receipt 10011027677 Customer HILCORP ENERGY CO Lease GRANITE PT ST#11-13 Well Name GRANITE PT ST#11-1 Field GRANITE POINT Location BJS.KENAI County Kenai Offshore State Alaska Stage No 1 Well API -API 50733200260000 TIME Treating Pressure-Psi Surface Slurry Slurry Rate Comments BBLS.Pumped BPM STP Annulus Stage Total 16.05 0 0 0 369 9 0 Move fluid from the blender tub to the blled off tank 16.07 0 0 0 369 9 0 Gell up Hydration unit 16.17 0 0 0 369 9 0 Hydration unit suction pump with not roll the unit 16:21 0 0 0 369 9 0 Suction pump air locked Pump now working 1631 0 0 0 369 9 0 Ready to Frac 16.36 0 0 0 369 9 0 Instructed to P0.1.1ili7e the well©1600 psi 16:39 1500 0 0 369 9 0 Open the well 16.40 0 0 0 369 9 0 Bring lip trucks 1642 0 0 0 369.9 0 Discharge PSI Fell off 16.45 7518 0 0 369 9 11 6 Caught Discharge PSI 1647 8100 0 0 369 9 13 8 Bring Up rate 16:49 8800 0 0 369 9. 14 1650 9200 0 95 1 465 0 Pump over psi kicked out 1650 0 0 24 1 489 1 0 Stage 100 mesh 16:57 591 Blender nuke not reading on JM,Prop Rate not reading,on and off on the screen 16.53 101 9 591 Stage linear 17:00 591 All truck in 1st gear 16.59 591 lost pump due to over psi hack online 17.06 632.6 Start x-link and buffer 1704 8814 2560 41 6 632 6 Stage 5#100 mesh 17:15 9078 750.4 17.08 117 8 750 4 Start x-link Pad 1718 750 4 lost pump hack online kick out 1717 9170 750 4 Lost pump due to kick out,back online 1720 750 4 Pump kick out 1724 91 5 841 9 Cut x-link and buffer,pump kick out,hack online 1726 23 8 865.7 Over flush per ELY consult to drop hydration 17.31 8870 865 7 1734 8775 865 7 17.41 865.7 Bring all pumps online per Fl Y consultant 17.39 8900 865.7 bring on water in hydration to clean box and lines 17.41 865 7 Begin Step down test 1742 865 7 Step down complete 1743 865.7 Monitor well 18.30 865.7 Report Ankle injury to office/hilcorp 18.58 865.7 Close in TIW bleed off lines 1904 865 7 I Ines bleed off Stop.Inh nn Oh master 1925 865.7 Rig Down Meeting with crew 19.40 865.7 Start rig down/blow down procedure 23:30 865.7 Crew to bed All crew going home on boat 0630 n6.00 865 7 Crew awake 00:00 0 0 0 865.7 0 11-24-13 0730 865 7 Crew on boat 11.30 865 7 Crew at dock 13.00 865 7 Meeting with crew at yard nn-nn 865 7 11-30-13 06:30 865.7 Yard call- J.Baldwin,J.Waters,R.Henderson,G.Gonsales,N. Oostman Treating Pressure Injection Rates Shut In Pressures Customer Rep. Dan Taylor Minimum 7334 Treating Fluid 11.1 ISDP BJ Rep. JUSTIN BALDWIN Maximum 9984 Flush 7.4 5 Min. 8298 Job Number 10011027677 Average 8607 Average 11.1 10 Min. 8111 Rec.ID No. Operators Max.Pressure 15 Min. 7954 Distribution 10000 Final 4288 In Min. 25 Flush Dens.lb./gal. 8.48 Report Printed on:December 9,2013 5.18 PM Jr8001 .4' Ci\ , Treatment Report-Supplement BAKER MUGHES Date 09-DEC-13 District Kenai F.Receipt 10011027677 Customer HILCORP ENERGY CO Lease GRANITE PT ST#11-13 Well Name GRANITE PT ST#11-1 Field GRANITE POINT Location BJS,KENAI County Kenai Offshore State Alaska Stage No 1 Well API -API 50733200260000 TIME Treating Pressure-Psi Surface Slurry Slurry Rate Comments BBLS.Pumped BPM STP Annulus Stage Total 0700 865 7 Crew at heliport waiting for chopper 0800 865.7 Crew on Platform 08:45 865 7 PJSM with Baker Crew 08:10 865.7 R.Henderson,N.Oostman rig oriantation,Get permitting sighned off 09.00 865 7 Start Equipment Check Chemicals Start agitationg gel 10:05 865.7 Oostman to get water Samples from tanks to KCL,Working on Viking pump Change out.Waiting for ACID and XLW 30 AG to sl- 11-10 865 7 Crew to Lunch 11.30 865 7 2nd crew onboard C 7oda M Eberhard R Virragia J.Herald 1200 865 7 Meeting with new crew,Crane tied up with running drill work 1400 865.7 Talk with Clint with ELY Dan Taylor Reid Edwards 15.06 865.7 KCL Tanks safety meeting 1510 865 7 Start KCL Tank 3 1715 865 7 KCL 3 Tanks Complete 1720 865 7 1st half crew to dinner 17:37 865.7 Talk with CO Man about getting James Cress to Location,told us at 1620 to have him at heliport at 1700. Didnt make it on the f 1750 865.7 Crew to Dinner 18.45 865 7 Donny wants us to monitor casing test 1900 865 7 Crew moving chem totes and running chem hoses 2030 865 7 James Cress nn location 21:10 865.7 Crew to bed,J.Waters and J.Baldwin stay up to unload boat and monitor caseins test 23:50 865.7 Check in with Donny about start time for casing test,Waiting on wireline to get prong from plug 0000 865.7 12-1-13 0320 865 7 Wake up by Donnie for casing test 0323 8651 Start Monitoring 03.46 _ 865 7 Rig pump having hard time with pressuring up casing 03.47 8170 865 7 Pump Stalled 0351 865 7 Rig crew checking for leaks 03157 865.7 TIW Leaking 0341 865 7 Rig Cant bleed off pressure 0451 865.7 Pressure bleeding off 0551 865.7 Pressure bleed to 0 Stop.Ioh 07:00 865.7 PJSM with crew,Discuss hazards and items needing done for wilaY 07.00 865 7it on rig.TIW valve sent to beach for rebuild 0730 865 7 Crew working on deck J Baldwin to Bed C Aida on deck 09.30 865 7 All Chemicals are circulating 11.05 865.7 Flowback claymaster bucket tested 11.10 865 7 Crew to lunch 1234 865 7 Justin on deck,Hydration burketiested 13:00 865.7 Ready to our fullest ability,waiting on rig to install TIW to test tubing and then pull plug_circulate well 1630 865 7 Start monitor of casing test 1812 865 7 Casing test wouldnt test,wireline to pull plug and check seals 0000 865 7 12-2-13 Treating Pressure Injection Rates Shut In Pressures Customer Rep. Dan Taylor Minimum 7334 Treating Fluid 11.1 ISDP BJ Rep. JUSTIN BALDWIN Maximum 9984 Flush 7.4 5 Min. 8298 Job Number 10011027677 Average 8607 Average 11.1 10 Min. 8111 Rec.ID No. Operators Max.Pressure 15 Min. 7954 Distribution 10000 Final 4288 In Min. 25 Flush Dens.lb./gal. 8.48 Report Printed on:December 9,2013 5.18 PM Jr8001 FA' (- Treatment Report-Supplement BAKER HUGHES Date 09-DEC-13 District Kenai F.Receipt 10011027677 Customer HILCORP ENERGY CO Lease GRANITE PT ST#11-13 Well Name GRANITE PT ST#11-1 Field GRANITE POINT Location BJS,KENAI County Kenai Offshore State Alaska Stage No 1 Well API -API 50733200260000 TIME Treating Pressure-Psi Surface Slurry Slurry Rate Comments BBLS.Pumped BPM STP Annulus Stage Total 0730 865 7 Crew Safety Meeting 08:00 865.7 Crew thawing ice in belly pans to pump out,clean location, wirelin still bailing and trying to pull plug. 11.00 865 7 Crew I unch 11.30 865 7 Waiting on rig to pt tubing 1800 865 7 Waiting on rig/Wireline to pull plug 00.00 865 7 12-3-13 05:30 865.7 Crew awake,Hilcorp sending crew home via boat while rig pulls drill pipe to fix plug 14.00 865 7 Crew at yard waiting for call to platform 0000 865 7 12-6-13 14:30 865.7 Yard Call,J.Baldwin,J.Cress,J.Waters,C.Zoda,N.Ricca, R Veerrengia.T.Mount N.Oostman.G.Gonzales.S.Hoffine 16.30 865 7 Crew on boat 19.45 865 7 Crew on Location 20.00 865 7 Meet with Donnie Tanks heated to 100,80,80._turn off heaters 20.30 865.7 Stir Gel,Roll chem pumps,Start Hydration and Blender 21.30 865.7 Crew to Bed,Equipment Secure 0000 865 7 12-7-13 05.30 865 7 SimOps Safety Meeting With Platform Crews 0545 865 7 Released 06.00 865 7 Baker Hughes Crew Meeting in TMV 06:05 865.7 Crew Released to equipment to get cables pulled,equipment started 06.54 865.7 Start Pumps 0714 865.7 Rig Not ready to rig up well head/Equipment 07:21 865.7 BHI Ready to rig up well head,waiting on rig,rig is testing Annulus 07.33 865.7 Start Rig up of wellhead 0832 865 7 Rig Floor Rigged up 08.51 865 7 Ready to prime rip Re rig Blow Down on floor 0908 865 7 Tee on floor rigged lip 0917 865.7 Prime upcomplete,open well head 09.21 11300 865 7 Pressure test lines 09:23 865 7 Pump in gear 0929 865_7 Bleed Off 0932 865.7 open to well for tubing test 09.33 11345 865 7 PT Tubing 09.35 4500 865 7 Pressure coming up 09.40 865 7 Bleed ofd leak on rig floor 09.43 865 7 Pressure up 0945 11345 865 7 Close in ground valve monitor for 20 minutes 0950 865 7 Bleed off,I eak nn the floor at tee,replace gasket 1005 865 7 Spool up Open to truck 1008 11300 865 7 Pressure up Tubing 1012 11075 865.7 Monitor 1015 10590, 865 7 Monitor 1020 10050 865 7 Monitor 1025 9460 865 7 Monitor Treating Pressure Injection Rates Shut In Pressures Customer Rep. Dan Taylor Minimum 7334 Treating Fluid 11.1 ISDP BJ Rep. JUSTIN BALDWIN Maximum 9984 _ Flush 7.4 5 Min. 8298 Job Number 10011027677 Average 8607 Average 11.1 10 Min. 8111 Rec.ID No. Operators Max.Pressure 15 Min. 7954 Distribution 10000 Final 4288 In Min. 25 Flush Dens.lb./gal. 8.48 Report Printed on.December 9,2013 5:18 PM Jr8001 IIA' Treatment Report-Supplement BAKER HUGHES Date 09-DEC-13 District Kenai F.Receipt 10011027677 Customer HILCORP ENERGY CO Lease GRANITE PT ST#11-13 Well Name GRANITE PT ST#11-1 Field_.__QL ANITE POINT Location IMS.KENAI County Kenai Offshore State Alaska Stage No 1 Well API -API 50733200260000 TIME Treating Pressure-Psi Surface Slurry Slurry Rate Comments BBLS.Pumped BPM STP Annulus Stage Total 10.32 865 7 Ground Valve Leaking 10.33 865 7 Bleed Off 10:39 865 7 Grease ground valve 10.41 865.7 relocating transducer to rig floor below our frac valve 10:59 865.7 Ready to pressure test tubing 11.02 865 7 Pressure up 11.06 11076 39 865 7 Valve on floor closed 11.09 10418 46 865.7 Monitor 11.10 865_7 Rotate 3 to lunch J Water J Cress,R Verngia C Zoda 11.18 865 7 Bleed off the pressure 11:25 865.7 Swap Rig up on well head to help isolate problems,Rig is trying to remove TIW Valve 12.16 865 7 Rig Floor Ready 12.19 865.7 CO Man Donnie in TMV ready to test 1222 865.7 Pump in gear 12A2 865 7 Close in wheel valve on well head 12.4'3 865 7 Re-Rig floor for hetterisolation 13.00 __865 7 Rig Floor ready 13.04 865 7 Pressure 1306 865 7 Shutdown 13.07 10875 304 865 7 2x2 valve on well heart,valve_is rigs,leaking Possible TIW 13.11 10390 352 865 7 Monitor 1315 10085 388 865 7 Monitor 1320 9609 449 865 7 Monitor 13.25 9130 512 865 7 Monitor 13:35 8461 612 865 7 Monitor 13.39 8157 659 865 7 Bleed off per Donnie 13.45 1659 865.7 CO Man has us stop bleeding down 13:47 0 0 865 7 Bleed psi off completly 13.51 865 7 Rig putting 2500 on backside 1355 865 7 Pressure Up 13.57 300 1785 865 7 Monitor 1400 470 2549 865 7 Monitor 14.02 50 2525 865 7 2x2 valve on floor was opened 14.03 865.7 Spool up Blender 1405 865 7 Pressure up 1408 10960 2780 865.7 Monitor 14.10 10704 2820 865 7 Monitor 14.15 10291 2884 865 7 Monitor 14.25 9545 2788 865 7 Monitor 14:40 8909 2933 865.7 Monitor 1450 8330 2819 865 7 Monitor 14:56 8653 Bleed off wireline pulling plug 19:35 865.7 Blow down equipment and chemicals per Donnnie and Reid Edwards.Rack back equipment for night. 20:30 865 7 Crew to bed 0500 Ready to work 00.00 865 7 12-8-13 05:00 865.7 Crew awake,Wireline couldnt get plug or prong. Wait on wireline to bail debri from prong Treating Pressure Injection Rates Shut In Pressures Customer Rep. Dan Taylor Minimum 7334 Treating Fluid 11.1 ISDP BJ Rep. JUSTIN BALDWIN Maximum 9984 Flush 7.4 5 Min. 8298 Job Number 10011027677 Average 8607 Average 11.1 10 Min. 8111 Rec.ID No. Operators Max.Pressure 15 Min. 7954 Distribution 10000 Final 4288 In Min. 25 Flush Dens.lb./gal. 8.48 Report Printed on.December 9,2013 5,18 PM Jr8001 ri ( - Treatment Report-Supplement BAKER HUGHES Date 09-DEC-13 District Kenai F.Receipt 10011027677 Customer HILCORP ENERGY CO. Lease GRANITE PT ST#11-13 Well Name GRANITE PT ST#11-1 Field GRANITE POINT Location BJS.KENAI County Kenai Offshore State Alaska Stage No 1 Well API -API 50733200260000 TIME Treating Pressure-Psi Surface Slurry Slurry Rate Comments BBLS.Pumped BPM STP Annulus Stage Total 1200 865 7 Wait on wireline to bail dehri and pull plug 1600 865 7 Wait on wireline to hail dehri and pull plug 1800 865 7 Wait on wireline to bail debri and pull plug 21:00 865.7 Wait on wireline to pull prong and prong,Crew wake up time to 0330 ready to work 0400 00:00 865.7_ __ 12-9-13 0400 865 7 Meeting with crew in galley 04:10 865.7 Crew starting equipment and circulating chemicals,rig up to wellhead 04:35 865.7 Rig floor Rigged up,chemicals are rolling,double checking all hoses and cables 0520 865 7 Simops meeting with platform crews Pre FRAC Safety meeting 0545 865 7 Meeting over,Crew to equipment 0557 865 7 Start Prime Up 06.00 865 7_ Start Job Master 0608 865 7 Open well Prime up standpipe 06.13 11300 865 7 Pressure test lines_check valves holding 0615 11360 865.7 Pressure Test 0620 11100 865.7 Good Pressure Test 06.23 865.7 Test Pop Off 435psi 10596psL shutdown Bleed down 0626 10257 865 7 Pop off set,405psi 10257psi 06:30 865.7 Per consultant,set pump kick outs ant 10000psi only for mini frac 0633 865.7, Open to well I ive well 06.33 0 865 7 Rig pressure up Annulus to 2500psi 06.46 2500 865 7 Pressure on backside 0648 865 7 Start mini frac 06:50 865.7 2nd pump online 06.53 865.7 Pump 3 online 06.57 8810 2083 0 865 7 12 7 Monitor 0700 0 865J TIW Leaking 0700 0 865.7 Start Step down 0701 121 986 7 Shutdown 0708 4385 1635 0 986 7 Monitor 07.10 4098 1699 0 986 7 0 Monitor 0727 3091 1648 986 7 0 Monitor 0651 6953 0 865 7 7 6 1st Breakover 0719 3424 1634 0 986 7 0 Monitor 07.30 2982 1654 986 7 0 Monitor 0792 3301 1638 0 986 7 0 Monitor 07:31 986 7 .Bleed down well and lines per Donnie DSM to fix TIW Valve 0659 8063 2188 0 865 7 11 3 Monitor 0739 986.7. Well bleed to Q closed in wheel valve 07.58 986 7, Stop Job on Joh Master 08.10 986 7 Stop Job due to accident on rig floor 0900 986 7 Safety meeting in galley to talk about accident and plan forward 09:22 986.7 Meeting over,crew looking over location and equipment prior to main job 09.30 986 7 Build en7ime per Consult Treating Pressure Injection Rates Shut In Pressures Customer Rep. Dan Taylor Minimum 7334 Treating Fluid 11.1 ISDP BJ Rep. JUSTIN BALDWIN Maximum 9984 Flush 7.4 5 Min. 8298 Job Number 10011027677 Average 8607 Average 11.1 10 Min. 8111 _Rec.ID No. Operators Max.Pressure 15 Min. 7954 Distribution 10000 Final 4288 In Min. 25 Flush Dens.lb./gal. 8.48 Report Printed on:December 9,2013 5:18 PM Jr8001 FA C _ Treatment Report-Supplement BAKER ES Date 09-DEC-13 District Kenai F.Receipt 10011027677 Customer HILCORP ENERGY CO Lease GRANITE PT ST#11-13 Well Name GRANITE PT ST#11-1 Field GRANITE POINT Location BJS.KENAI County Kenai Offshore State Alaska Stage No 1 Well API -API 50733200260000 TIME Treating Pressure-Psi Surface Slurry Slurry Rate Comments BBLS.Pumped BPM STP Annulus Stage Total 0950 0 986.7 spool up to pressure test 0954 0 986 7 Start Pressure Test 0957 10960 0, 986 7 Pressure Test 10.00 0; 986 7 Load hopper with Sand 10.02 0 986 7 Bleed offgood test 1002 2512 0 986 7 Rig pressure up hackside 10:10 0 986.7 Gel up Hydration 10.26 0 986 7 Open Well 10.29 0 986 7 Fquali7e TIW to open 10.30 0 986 7 Open to Trucks 10.31 0 986.7 Equalise 2500psi 10.33 0 986 7 Bleed down to open TIW 10.36 0 986.7 Rig needs to bleed down to open TIW 1038 455 0 986 7 Well is open 10.40 _ 0 986.7 1st pump online 1040 5 991 7 2nd pump online 10.41 224.3 1216 Stage Pad 1042 0 1216 Referance nikes blender/inline 1043 8255 2696 11 6 1227 6 12 6 Stage 1# 1047 8698 2423 46 9 1274 5 12 6 Stage 2# 1046 8551 2513 100 5 1375 12 6 Stage 3# 10.52 8700 2169 120 8 1495 8 12.6 Stage 4# 1055 8399 2286 92 2_ 1588 12 4 Stage 5# 11.31 9210 0_ 1692 8 11 2 Drop gear 11.18 7887 2380 104 8 1692 8 12 5 Stage Flush 11.34 0 1692 8 pump 1 down cut clay and flowback 11.36 0 1692 8 pump 2 down on kick out 11:33 9472 2206 0 1692.8 11 Decrease throttle 11.43 0 1692 8 pump 1 first gear 11.45 0_ 1692 8 Pumps down,10.117#sand in pipe 11.50 8298 2209 0 1692 8 Monitor 11.55 8111 2239 0 1692 8 Monitor 12.00 7954 2267 0 1692 8 Monitor 12.00 0 . 1692 8 Bleed down to 4000psi,turn over to rig StarLclean up Treating Pressure Injection Rates Shut In Pressures Customer Rep. Dan Taylor Minimum 7334 Treating Fluid 11.1 ISDP BJ Rep. JUSTIN BALDWIN Maximum 9984 Flush 7.4 5 Min. 8298 Job Number 10011027677 Average 8607 Average 11.1 10 Min. 8111 Rec.ID No. Operators Max.Pressure _15 Min. 7954 Distribution 10000 Final 4288 In Min. 25 Flush Dens.lb./gal. 8.48 Report Printed on:December 9,2013 5:18 PM Jr8001 Pi'C. /lIRe, ||!. !! I% I.: /ee! ! } RR ! ilja RRRRe! 105 RRRe! /§ mesas 10 eiR! ! |\, � w |!|! I| /\\/( 1! /B§ !!| I_ #aeR: � 2 !! � ems: illdRne !l■ aG#R! ill 41r! !I■ 0,1111 1 �I U! I |1|I!} || iSRe ! ! II «ne-! g; yaee, , REQ"! ° P, M |. 1,, ,,0 ƒ . . 1 !`]!!! 1 1111!!!! P, - -1 §= - | , & ll '-i 1 /igQg > 6 . ? iti .|i!| - \ ) � ;m f 1 6..� COMPANY: Hilcorp Alaska LLC Min Max Average WELL: Granite Point St 11-13RD Pressure 7334 9984 8607 API#: 50-733-20026 Rate 3.8 12.7 11.1 BAKER CTY/STATE: Kenai OffstAK Visc 0.0 0.0 0.0 HUGHES S/T/R: 0 pH 0.00 0.00 0.00 FORMATION: Hemlock Temp 0.0 0.0 0.0 Stage# 1 FRAC STAGE 1 6258 Gal Crosslink Gel Pad 3150 Gal Crosslink Gel SLF 2549.6 Carbolite 462 Gal Crosslink Gel SLF 392.4 Carbolite 1932 Gal Crosslink Gel SLF 3670.6 Carbolite 3772 Gal Crosslink Gel SLF 12548 Carbolite 4360 Gal Crosslink Gel SLF 19239.5 Carbolite 3284 Gal Crosslink Gel SLF 19200 CarboBond Lite 20/40 4124 Gal Linear Gel Flush Lightning Crosslink Gel 23218 Gals Total Gals Lightning Linear Gel 4124 Gals 27342 Total Bbls 651 Sand Laden 16960 Gals SAND 38400#Carbolite 19200#CarboBond Lite 20/40 651 CUM BLWTR 651 0# 27342 CUM GLWTR 27342 57600#TOTAL SAND 57600 CUM SAND 57600.1 Job Comments: Ran DFIT before pumping frac job,determined fluid efficiency to be approximately as planned. Added 0.5 scour,then pumped according to design. During 4 ppg stage,pressure began steadily increasing, and continued during 5 ppg stage and flush until pumps started kicking out. Flushed 98 bbls,leaving 10117 lbs of CarboBond Lite in the pipe. c8i 0 cc L±1 M • U W O.- J °C W w 0 o) 00 c cD o Z� T/>D d U Q z 10 0 H > LL 0 —0 W W O O LI O .62 .8!:.! O Q H W 00 N O Ln ( N O O O J OW -1 CO v CO v Ln o O o •• Cl D Z • 2 C7 N O ri v O O O in U Qz >Z O a OO ID 0 Ln Ln N 0 O O O O O 0 C J W CO CO Ln O COLn O N O H 0 N CO CO co N O) N r . OQ a) H I _c 0 U o ca 0) CO v v Cr) 0 0 0 -0 • W W z 0 OW V 4 N N N CO N Nd 50 � 0c N (� J Z a_ > O W O W W Li. I- 0 0 W Ln LC) L` Ln O Ln O 0 C) w -1 O N No N O_I- M ZLU (0 N NNCL N U) N L0 Z aa) aO O na o O O 0 O O O O O O O a = mow o 0 0 0 0 o a o 0 J . — Cl) (5 vai o 0 QLn Ln N 0 0 0 0 O O V w Fa- O N C) CO CO N 0) O N O W U O C.) Zw Ln o co O O o O o O + I n to V O 0 O (D O U Z N N N 0 N CO W Q > 0 — ZO Ln V Ln O Ln O 0 O Q w CO W Ln CO N 0) N O w- ton V CO C6 r N ot) _1 Ci) W W W > cn O Q I > z � _ ° U ° u) CC (0 < to U -1 w C7N — C7 Ln o co O o O O o O (0 O M Ln O CA O 0) N1 Cin CO CO CON O) O r in aF a H • 0 CO 0 0 O CO 0 0) C) 6) Lf) O W W 0 LU Ln N- N • • LU d O O Q 0_ N rn 05 o U N C C O U U J O U IL D , 11111. kill egi O cc a (� co J 0 CN Q HU u_le 1 CC coc m a T v cc a E - N 0 CC (3 CO X LL C.) W i X 0 0 I— LOAD SHEET District: Kenai,Alaska DATE OF JOB: December 9,2013 Customer: Hilcorp Energy WELL NAME: Granite Point#11-13RD Rev.# WAREHOUSE: Kenai Alaska FIELD RECEIPT NO: ORIGINAL Quantity Sent Quantity Returned Verified PRODUCT ITEM Before Frac After frac Net To Field DESCRIPTION NO. UOM ordered BULK PLANT LOCATION LOCATION BULK PLANT Usage LOT NUMBER Receipt XLW-30AG L488560-330• GAL 330 330 330 295 35 052412 XLW-32* 499630 GAL 64 331 316 299 17 052413 BF-8L 425143 GAL 140 361 357 295 62 67848 BF-7L 488007 GAL 0 0 0 CLAYMASTER 5C 499808 GAL 77 323 323 270 53 705609 BC-3 488187 GAL 0 0 0 FLO-BACK 30 488255 GAL 77 166 165 101 64 n/a Enzyme G HT-III GAL 25 0 183 0 183 n/a GBW-22C 488530 GAL 0.25 3 3 1 2 1BC74-111812 Water 399000 GAL 24.75 0 0 0 n/a GBW-18* 488224 LBS 70 50 40 10 Water for GBW-18 399000 GAL 0 0 0 XCIDE 207 100486 LBS 33 36 6 30 20/40 sand 100002 CWT 0 0 0 KCL 100114 LBS 0 0 0 FLEXSAND MSE 499911 LBS 0 0 0 S-8C Sand 100 Mesh 100122 LBS 0 3400 3400 2000 1400 ES-4A 411251 GAL 130 305 305 305 2012203AW HIGH PERM CRB LT L488175-50 LBS 100 100 100 80 20 HIGH PERM CRB 488157 LBS 96 100 100 65 35 s,092813-01V CARBOBOND LITE 426927 LBS 19200 19200 19,200 0 19200 CARBO LITE 20/40 499847 LBS 38628 70400 38,400 0 38400 0 GLFC-5D PER/K 398373 GAL 663 791 712 208 505 KEN-BP-072012 ES-4 675 411340 GAL 448 341 2012203AW PSA-5 100 488164 LBS 66 21 1001P12202 PSA-65L 4 488165 GAL 2.7 3.2 0.8 _u S0511121 US-40 6 100104 GAL 4.0 4.7 1.2 3.0 n/a GW 488301 LBS 2,652 3,164 830 2,018 912901 HCL (28%) 100088 GAL 330 330 330 0 SODA ASH 100237 LBS 1650 2000 2000 0 CI-27 488220 GAL 1 1 1 0 F-300 100090 LBS 16.5 16.5 17 0 GW-24LE 424242 GAL 0 0 0 0 COMMENTS: ORDERED QTY INCLUDES 30%EXCESS OVER PROPOSAL ISSUED BY: Bryan Hutchins DATE: 11/18/2013 RECD TO LOCATION BY: Justin Baldwin DATE: RET.VERIFIED BY: DATE: RETURN APPROVAL: DATE: CUSTOMER SIGNATURE: , OD (!sd) snlnuud N 0 0 of 0 0 0 0 CD CD 'CB Lr) o �o o I I I I I I I I I I I I I I I a> (esd) O!IBH PUBS H8 (esd) VSd sup! 0 ca r o to o v -a I I I 1 I r0 E 0 a> co 0 - U a .y o O �\ Q O _Q Rho ;12 LO y 110- c c 0 'E d N — - o E '5 at i= 0 co 0 - o M 'V! o W d V _ tri ca — , ; co ' litilli 000 c M = f r--- m JaL Nc. �� M0 alb N C Q 0 �0 Q .0NQa - N o C � Qw Co 0 0 al me 0 Ca ____ -- 1 o 1.- r 1 a , t to C1L = o L. 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(O V• 't c° OD 't O c V N O O Co Z Z Z o CO c CO 0 Z v N od a Id: M F W O a v ^ E o E E E E EEE EEE E I— v o E N 'a o aaa a aaa Etna a 17, 0.1 U O = E IIc •g a a F. w U ° .. 111 ell a� N al v �W; w= m Lu E > a) a) ca rn a) a) N H �� co ', N N c O 70 co co N co -6 U N a) '81 N LLj Ta a a s w r) `o 4) n = = c ` o aa c 244) ? a -o A `� m < (/) C E c E E 0) aa)) -a o o m Y -o E m o .v •o o < 0 a) co I 0 a) a) 0 n a) > > z a) 0 >, CO .c__ 65 0 co co s r E 00 0' (o (OF- F- F- 0) I- (nalLI- a 2065 x }- 200 O li Well Site Proppant Quality Control BHI Proppant Quality Control Date: November 16,2013 Customer: Hilcorp _ Sample Description Loading on Trailers Well GP 11-13RD Worked By Joshua Herald Field Granite Point Platfc TRUCK Truck number No. Sack No. No. Trucking company Sample taken m rEs ❑ NO Weight slip available?Attach all. f7 YES m NO Nominal size from list below m res ❑ NO Is total weight for each size appropriate for job requirements? o res ❑ NO Is the truck content acceptable? 0 YES ❑ NO SIEVE ANALYSIS o 'Brady'Type Sand 0 Resin Coated Sand 0 Sintered Bauxite o "Ottowa"Type Sand 0 Ceramic Proppant 0 Other(specify) Nominal size from list below: Is total weight for each size appropriate for job requirement 121 yes p No El Correct Color © Low Dust la Correct Appearance Q Oversize<0.1% la Fines<1.0% la In Size>90% O Sample Acceptable? Sample 1 Sample 2 Sample 3 Sample 4 Size: 20/40 Size: 20/40 Size: 20/40 Size: 20/40 Type:Carbo Bond Type: Carbo Bond Type: Carbolite Type: Carbolite Mesh Grams % Mesh Grams % Mesh Grams % Mesh Grams % 16 0.0 0.00% 16 0.0 0.00% 16 0.0 0.00% 16 0.0 0.00% 20 3.6 7.26% 20 3.9 7.74% 20 _ 1.7 3.13% 20 1.5 2.84% 30 45.7 92.14% 30 46.1 91.47% 30 51.1 94.11% 30 49.9 94.51% 35 0.3 0.60% 35 0.4 0.79% 35 1.3 2.39% 35 1.2 2.27% 40 0.0 0.00% 40 0.0 0.00% 40 0.2 0.37% 40 0.2 0.38% 50 0.00 0.00% 50 0.00 0.00% 50 0.0 0.00% 50 0.0 0.00% Pan 0.0 0.00% Pan 0.0 0.00% Pan 0.0 0.00% Pan 0.0 0.00% _ _ 0.00% 0.00% 0.00% 0.00% Total 49.6 100.00% Total 50.4 100.00% Total 54.3 100.00% Total 52.8 100.00% In Size: 92.74% In Size: 92.26% In Size: 96.87% In Size: 97.16% l Recognized proppant or gravel sizes:6/12,8/16,12/20,16/30,20/40,30/50,40/70,50/70 I Signature: Joshua Herald r'.. Rocky Mountain Region Laboratory BAKER 899 Baseline Place Brighton, CO 80601 HUGHES (303)659-7347 Fax Phone (3 3)659-7401 BJ SERVICES Prepared for Hilcorp Alaska GP #11 Granite Point Field Kenai County, Alaska Hemlock Formation Treatment Fluid Lightning 3000 D High Temperature Pressurized Viscometer Testing Results Prepared for Reid Edwards Laboratory Project No.S11-029-13B Prepared By: Marc Babel Rocky Mountain Region Laboratory 899 Baseline Place Brighton,CO 80601 11/26/2013 BAKER Rocky Mountain Region Laboratory HUGHES Water Analysis Report Pro'ect# S11-029-13B Customer/Well Information Company: Hilcorp Alaska Date: 11/26/2013 Well Name: GP#11 Prepared for: Reid Edwards Location: Granite Point Field Submitted by: Joshua Herald State: Kenai County,Alaska Prepared by: Marc Babel Formation: Hemlock Water Type: 3% KCI Brighton Tap Depth: 11065 ft Back•round Information Reason for Testing: Completion type: Well History: Unknown Special Considerations: Brighton tap water with 3% KCI Sample Characteristics Sample Temp: 60 (°F) Viscosity: 1 cp pH: 7.68 Color: Clear Specific Gravity: 1.020 Odor: None S.G.(Corrected): 1.020 @ 60°F Turbidity: Clear Resistivity(Calc): 1.32 S2-m Filtrates: None Sample Composition CATIONS mg/I me/I ppm Sodium(calc.) 1854 80.6 1817 Calcium 107 5.4 105 Magnesium 7 0.6 7 Barium 0 0.0 0 Potassium 0 0.0 0 Iron 0.60 0.0 0.59 ANIONS Chloride 2840 80.1 2784 Sulfate 260 5.4 255 Hydroxide 0 0.0 0 Carbonate _ < 1_ Bicarbonate 83 1.4 81 SUMMARY Total Dissolved Solids(calc.) 5151 5050 Total Hardness as CaCO3 296 5.9 291 Scaling Tendencies CaCO3 Factor 8915.545 Calcium Carbonate Scale Probability--> REMOTE CaSO4 Factor 27941.68 Calcium Sulfate Scale Probability > REMOTE Comments 1 R � Fluid System \VI1 Li Lightning 3000 D BAKER g g Containing: HUGHES 7.5 gpt GW-3LDF Rocky Mountain Region 0.9 gpt XLW-30AG Laboratory 2.0 gpt BF-8L (10.5 pH) For 1.0 gpt Claymaster 5C Hilcorp Alaska 1.0 gpt FloBack 30 GP High Perm CRB as indicated #11 Kenai County Enzyme G HT Ill as indicated Alaska HP-CRB LT as indicated Hemlock Formation ` 3% KCI Brighton Tap Apparent Viscosity Profile 1200 1.0 gpt Enzyme G HT-III 0.75 ppt High Perm CRB 1000 — -- 7' l v w , 0800t : 2.0 gpt Enzyme G HT-III 0.8 ppt High Perm CRB-LT 2.0 gpt Enzyme G HT-III a 1.0 ppt High Perm CRB .600 i 1 cn n I 2.0 gpt Enzyme M1 XI i400 0.5 ppt High Perm CRB-LT Q. M , Q ‘ / 200 2.0 gpt Enzyme G HT-III / \ 0.7 ppt High Perm CRB-LT Temperature I ‘ 2.0 gpt Enzyme G HT-III 1.0 ppt High Perm CRB-LT ^ 1 0 100 150 200 250 1.0 gpt Enzyme G HT-III 1.0 ppt High Perm CRB-LT I Time, min. @ 190 °F Rocky Mountain Region Laboratory Time "0" at Instrument Start Brighton, CO 80601 File: S11-029-13B Date: 11/26/2013 Analyst: Marc Babel i Fluid System FAN Li Lightning 3000 D BAKER g g Containing: HUGHES 7.5 gpt GW-3LDF Rocky Mountain Region 0.9 gpt XLW-30AG Laboratory 2.0 gpt BF-8L (10.5 pH) For 1.0 gpt Claymaster 5C Hilcorp Alaska 1.0 gpt FloBack 30 GP High Perm CRB as indicated #11 Kenai County Enzyme G HT III as indicated Alaska HP-CRB LT as indicated Hemlock Formation / 3% KCI Brighton Tap Apparent Viscosity Profile 1400 — 1200 r ci :,'1000 - : - o o � f dU 800 f� 44 1 a ,' (' Tik011014 N o 600 1 5 igi it hS* 401 ,4114, 03 400 o. 4:C li Nikii- 11. 6,11 iwiNg 200 I I 41111111* Temperature 0 — v- 0 5 10 15 20 25 30 I Time, min. @ 190 °F Rocky Mountain Region Laboratory Time"0" at Instrument Start Brighton, CO 80601 File: S11-029-13B Date: 11/26/2013 Analyst: Marc Babel Customer Name: Hilcorp Alaska Date: November 26, 2013 Well Name: GP#11 County, State: Kenai County, Alaska Test Type: Lightning 3000 D Test id#: s11029Ba4.XLS Formation: Hemlock Inst. Geometry,R1-B5X: 0.8503 1/sec. Per rpm Depth: 11065 Test Temperature: 190 Testing Machine: Brookfield Viscometer B RPM settings for Calculated Shear Shear rates to Sweep Interval: 30 min shear rate vs shear Stress Sweep report Power stress sweep: Points: Law Peak Viscosity: 1058 cp Time to Peak: 9.25 min 235 200 viscosites: Initial pH: 176 150 40 Final pH: 118 100 100 59 50 170 Apparent Viscosity at Requested Shear Rates Time/Mins. Temp. Viscosity,cP. @ N Prime K Prime Shear Rate Shear Rate Shear Rate 100 sec.-1 40 100 170 0.47 72 35 App. Viscosity at 468 1/sec 35 35 35 10.17 161 921 20.12 183 508 0.5500 0.0991 902 597 470 34.03 186 434 50.73 187 553 0.4883 0.1144 830 519 396 _ 65.57 187 555 81.42 187 515 0.4794 0.1209 849 527 400 95.98 187 526 _ 112.07 187 470 0.4549 0.1287 825 501 375 126.62 187 495 142.68 187 501 0.5079 0.1016 792 505 389 157.18 187 515 173.32 187 537 0.6051 0.0638 712 496 402 189.87 187 484 Base Gel Hydration Time , Temp App. Visc Base Gel Hydration 0 . 64 1 3 64 28 35 5 _ 64 28 in 30 _ 7 64 28 @) 25 10 64 28 y 20 / , Base Gel Quality 8 ami 15 Temp Time > v 10 5 T1 (Closure): c a) 0 T2 Crown): � R 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Comments: a Time, min. Gelling Agent: 7.5 gpt GW-3LDF Gel Stablizer: 0 Crosslinker: 0.9 gpt XLW-30AG Breaker Catalyst: Enzyme G HT III as indicated Ph Buffer Agent: 2.0 gpt BF-8L(10.5 pH) Surfactant: 0 Salt or KCL: 0 Load Recovery Agent: 1.0 gpt FloBack 30 Breaker: _High Perm CRB as indicated _ Clay Protection: 1.0 gpt Claymaster 5C Comments: Other: HP-CRB LT as indicated Other: 0 Customer Name: Hilcorp Alaska Date: November 26, 2013 Well Name: GP #11 County, State: Kenai County, Alaska Test Type: Lightning 3000 D Test id#: s11029Ba5.XLS Formation: Hemlock Inst. Geometry,R1-B5X: 0.8503 1/sec. Per rpm Depth: 11065 Test Temperature: 190 Testing Machine: Brookfield Viscometer- B RPM settings for Calculated Shear Shear rates to Sweep Interval: 30 min shear rate vs shear Stress Sweep report Power stress sweep: Points: Law Peak Viscosity: 984 cp Time to Peak: 9.47 min 235 200 viscosites: m Initial pH: 176 150 40 Final pH: 118 100 100 59 50 170 Apparent Viscosity at Requested Shear Rates Time/Mins. Temp. Viscosity,cP.@ N Prime K Prime Shear Rate Shear Rate Shear Rate 100 sec.-1 40 100 170 0.47 75 34 App. Viscosity at 468 1/sec 34 34 34 4.37 , 88 76 , 6.67 128 559 8.97 . 155 . 936 . 11.27 _ 167 850 13.57 175 644 15.87 179 494 20.17 183 488 0.5849 0.0592 613 419 336 24.10 186 364 28.05 186 _ 227 31.98 . 187 143 34.95 187 95 38.88 186 92 • 42.82 186 46 Base Gel Hydration Time Temp , App. Visc Base Gel Hydration 0 65 1 3 65 28 ''' 35 5 65 28 L 30 7 65 28 25 10 65 28 N 20 o Base Gel Quality 2 c215 Temp Time > 10 5 T1 (Closure): c T2 (Crown): a 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Comments: a Time,min. Gelling Agent: 7.5 gpt GW-3LDF Gel Stablizer: 0 Crosslinker: 0.9 gpt XLW-30AG Breaker Catalyst: Enzyme G HT Ill as indicated Ph Buffer Agent: 2.0 gpt BF-8L (10.5 pH) Surfactant: 0 Salt or KCL: 0 Load Recovery Agent: 1.0 gpt FloBack 30 Breaker: High Perm CRB as indicated Clay Protection: 1.0 gpt Claymaster 5C Comments: Other: HP-CRB LT as indicated Other: 0 Customer Name: Hilcorp Alaska Date: November 26, 2013 Well Name: GP#11 County, State: Kenai County, Alaska Test Type: Lightning 3000 D Test id#: s11029Aa5.XLS Formation: Hemlock Inst. Geometry,R1-B5X: 0.8503 1/sec. Per rpm Depth: 11065 Test Temperature: 190 Testing Machine: Brookfield Viscometer-A RPM settings for Calculated Shear Shear rates to shear rate vs shear Stress Sweep report Power Sweep Interval: 30 min stress sweep: Points: Law Peak Viscosity: 927 cp Time to Peak: 7.63 min 235 200 viscosites: Initial pH: 176 150 40 Final pH: 118 100 100 • 59 50 170 Apparent Viscosity at Requested Shear Rates Time/Mins. Temp. Viscosity,cP. @ N Prime K Prime Shear Rate Shear Rate Shear Rate 100 sec.-1 40 100 170 0.45 70 30 App. Viscosity at 468 1/sec 30 30 _ 30 10.23 172 612 20.17 188 489 0.5383 0.0788 687 450 _ 352 34.93 190 331 50.82 190 278 1.1871 0.0022 206 245 270 65.53 190 263 81.47 190 280 1.0580 0.0042 247 260 268 96.25 190 249 112.07 190 248 1.0681 0.0036 221 235 244 126.68 190 226 142.67 190 243 1.1873 0.0018 174 206 228 156.92 191 231 173.33 190 229 1.2035 0.0016 160 193 215 1. 176.18 190 236 Base Gel Hydration Time Temp App. Visc Base Gel Hydration 0 1 F 3 %- 1.2 5 1 ■ i 7 0.8 10 N 0.6 Base Gel Quality o w 0.4 Temp Time > ' 0.2 T1 (Closure): ( ) 0 T2 Crown : dA 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Comments: a Time, min. Gelling Agent: 7.5 gpt GW-3LDF Gel Stablizer: 0 Crosslinker: 0.9 gpt XLW-30AG Breaker Catalyst: Enzyme G HT III as indicated Ph Buffer Agent: 2.0 gpt BF-8L (10.5 pH) Surfactant: 0 Salt or KCL: 0 Load Recovery Agent: 1.0 gpt FloBack 30 Breaker: High Perm CRB as indicated Clay Protection: 1.0 gpt Claymaster 5C Comments: Other: HP-CRB LT as indicated Other: 0 Customer Name: Hilcorp Alaska Date: November 26, 2013 Well Name: GP#11 County, State: Kenai County,Alaska Test Type: Lightning 3000 D Test id#: s11029Aa6.XLS Formation: Hemlock Inst. Geometry,R1-B5X:0.8503 1/sec. Per rpm Depth: 11065 Test Temperature: 190 Testing Machine: Brookfield Viscometer A RPM settings for Calculated Shear Shear rates to Sweep Interval: 30 min shear rate vs shear Stress Sweep report Power stress sweep: Points: Law Peak Viscosity: _ 879 cp- Time to Peak: 6.73 min 235 200 viscosites: Initial pH: 176 150 40 Final pH: 118 100 100 59 50 170 Apparent Viscosity at Requested Shear Rates Time/Mins. Temp. Viscosity,cP.@ N Prime K Prime Shear Rate Shear Rate Shear Rate 100 sec.-1 40 100 170 0.45 73 28 App. Viscosity at 468 1/sec 28 28 28 4.33 86 62 6.73 139 879 8.95 _ 164 _ 824 11.33 177 697 13.55 183 _ 524 15.93 186 398 20.15 189 435 0.2559 0.2175 669 338 228 23.93 190 _ 330 26.77 _ 190 _ 342 30.57 190 236 33.45 190 166 37.25 190 103 40.10 190 57 Base Gel Hydration Time Temp App. Visc Base Gel Hydration 0 1 3 1.2 5 g 1 7 z, 0.8 10 0 0.6 Base Gel Quality N y 0.4 - Temp Time > `- 0.2 - T1 (Closure): _ (Crown): d 0 T2 Crown . RS 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Comments: Q Time, min. Gelling Agent: 7.5 gpt GW-3LDF Gel Stablizer: 0 Crosslinker: 0.9 gpt XLW-30AG Breaker Catalyst: Enzyme G HT III as indicated Ph Buffer Agent: 2.0 gpt BF-8L (10.5 pH) Surfactant: 0 Salt or KCL: 0 Load Recovery Agent: 1.0 gpt FloBack 30 Breaker: .High Perm CRB as indicated Clay Protection: 1.0 gpt Claymaster 5C Comments: Other: HP-CRB LT as indicated Other: 0 Customer Name: Hilcorp Alaska Date: November 26, 2013 Well Name: GP#11 County, State: Kenai County, Alaska Test Type: Lightning 3000 D Test id#: s11029Ba6.XLS Formation: Hemlock Inst. Geometry,R1-B5X: 0.8503 1/sec. Per rpm Depth: 11065 Test Temperature: 190 Testing Machine: Brookfield Viscometer B RPM settings for Calculated Shear Shear rates to shear rate vs shear Stress Sweep report Power Sweep Interval: 30 min stress sweep: Points: Law Peak Viscosity: 1155 cp Time to Peak: 12.18 min 235 200 viscosites: Initial pH: 176 150 40 Final pH: 118 100 100 59 50 170 Apparent Viscosity at Requested Shear Rates Time/Mins. Temp. Viscosity,cP.@ N Prime K Prime Shear Rate Shear Rate Shear Rate 100 sec.-1 40 100 170 0.47 74 35 App. Viscosity at 468 1/sec 35 35 35 10.17 162 975 , 20.12 183 625 0.5390 0.0982 859 563 441 33.95 187 428 . 50.77 187 373 0.7287 0.0258 454 354 306 65.60 187 355 . 81.40 187 356 0.8591 0.0140 400 351 326 96.15 187 354 . 112.03 187 . 383 0.8428 0.0159 426 369 339 126.22 187 356 142.73 187 352 0.8522 0.0135 374 326 302 157.18 187 344 F 173.42 187 292 0.9006 0.0108 359 328 311 201.00 187 276 Base Gel Hydration Time Temp . App. Visc Base Gel Hydration r 0 64 1 3 64 _ 28 35 5 64 28 @� 25 7 64 28 10 64 28 vii 20 Base Gel Quality c°. d 15 Temp Time co , 10 5 r Ti (Closure): 0 T2 (Crown). ,`tea 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Comments: Q Time,min. Gelling Agent: 7.5 gpt GW-3LDF Gel Stablizer: 0 Crosslinker: 0.9 gpt XLW-30AG Breaker Catalyst: Enzyme G HT III as indicated Ph Buffer Agent: 2.0 gpt BF-8L (10.5 pH) Surfactant: 0 Salt or KCL: 0 Load Recovery Agent: 1.0 gpt FloBack 30 Breaker: High Perm CRB as indicated Clay Protection: 1.0 gpt Claymaster 5C Comments: Other: HP-CRB LT as indicated Other: 0 Customer Name: Hilcorp Alaska Date: November 26, 2013 Well Name: GP#11 County, State: Kenai County, Alaska Test Type: Lightning 3000 D Test id#: s11029Aa7.XLS • Formation: Hemlock Inst. Geometry,R1-B5X: 0.8503 1/sec. Per rpm Depth: 11065 Test Temperature: 190 Testing Machine: Brookfield Viscometer A RPM settings for Calculated Shear Shear rates to shear rate vs shear Stress Sweep report Power Sweep Interval: 30 min stress sweep: Points: Law Peak Viscosity: 869 cp • Time to Peak: 7.17 min 235 200 viscosites: Initial pH: 176 150 40 Final pH: 118 100 100 • 59 50 170 • Apparent Viscosity at Requested Shear Rates Time/Mins. Temp. Viscosity,cP.@ N Prime K Prime Shear Rate Shear Rate Shear Rate 100 sec.-1 40 100 170 0.48 72 32 App. Viscosity at 468 1/sec 32 32 32 5.37 _ 108 198 8.48 161 763 11.77 178 608 14.88 185 480 _ 20.18 189 . 376 0.5597 0.0635 599 400 317 26.08 190 221 32.00 190 198 36.92 190 102 42.83 190 63 50.80 190 51 1.5095 0.0001 32 51 67 51.78 _ 190 _ 54 52.78 190 53 • 51.78 190 54 E 52.78 190 53 Base Gel Hydration Time Temp App. Visc Base Gel Hydration 0 64 1 3 64 28 ,- 35 5 64 28 @, 30 25 i • • 7 64 28 ' 20 10 64 28 N Base Gel Quality C.) m 15 Temp Time > . 10 -- Ti (Closure): 5 T2 (Crown): m 0 R 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Comments: Q Time,min. I Gelling Agent: 7.5 gpt GW-3LDF Gel Stablizer: 0 Crosslinker: 0.9 gpt XLW-30AG Breaker Catalyst: Enzyme G HT III as indicated Ph Buffer Agent: 2.0 gpt BF-8L (10.5 pH) Surfactant: 0 Salt or KCL: 0 Load Recovery Agent: 1.0 gpt FloBack 30 Breaker: High Perm CRB as indicated_ Clay Protection: 1.0 gpt Claymaster 5C Comments: _ Other: HP-CRB LT as indicated Other: 0 Customer Name: Hilcorp Alaska Date: November 26, 2013 Well Name: GP#11 County, State: Kenai County, Alaska Test Type: Lightning 3000 D Test id#: s11029Ba7.XLS Formation: Hemlock Inst. Geometry,R1-B5X: 0.8503 1/sec. Per rpm Depth: 11065 Test Temperature: 190 Testing Machine: Brookfield Viscometer- B RPM settings for Calculated Shear Shear rates to shear rate vs shear Stress Sweep report Power Sweep Interval. 30 min stress sweep: Points: Law Peak Viscosity: 1062 cp Time to Peak: 9.33 min 235 200 viscosites: Initial pH: 176 150 40 Final pH: 118 100 100 59 50 170 Apparent Viscosity at Requested Shear Rates Time/Mins. Temp. Viscosity,cP.@ N Prime K Prime Shear Rate Shear Rate Shear Rate 100 sec.-1 40 100 170 0.45 80 33 App. Viscosity at 468 1/sec 33 33 33 10.12 162 868 . 20.12 . 184 593 0.5667 0.0713 690 464 369 34.87 187 342 50.75 187 269 0.9152 0.0076 268 248 _ 237 64.65 187 182 , 81.43 . 187 158 1.6742 0.0001 66 123 175 95.93 187 172 112.07 187 140 1.7664 0.0001 49 100 150 127.42 187 134 142.67 187 139 1.7597 0.0001 46 92 137 156.48 187 140 173.35 187 117 1.7148 0.0001 43 82 120 178.28 187 120 Base Gel Hydration Time Temp App. Visc Base Gel Hydration 0 _ 64 1 3 64 28 •-• 35 5 64 28 m,In 30 -/r- - 7 64 28 25 10 64 28 y 20 Base Gel Quality o 40,) 15 Temp . Time >10 5 T1 (Closure): _ c 0 T2 (Crown): m 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Comments: Q Time, min. Gelling Agent: 7.5 gpt GW-3LDF Gel Stablizer: 0 Crosslinker: 0.9 gpt XLW-30AG Breaker Catalyst: Enzyme G HT III as indicated Ph Buffer Agent: 2.0 gpt BF-8L (10.5 pH) Surfactant: 0 Salt or KCL: 0 Load Recovery Agent: 1.0 gpt FloBack 30 Breaker: High Perm CRB as indicated Clay Protection: 1.0 gpt Claymaster 5C Comments: Other: HP-CRB LT as indicated Other: 0 Id" BAKER HUGHES Proposal No: 10011620890 HILCORP ENERGY CO GRANITE PT ST#11-13RD API # 50-733-20026-0000 GRANITE POINT Field Kenai Offshore County, Alaska October 17, 2013 Fracturing Proposal Prepared for: Prepared by: Reid Edwards Joshua Herald Operations Engineer Technical Support Engineer Hilcorp Alaska LLC Bus Phone: 907-776-4084 Bus Phone: 907-777-8421 Email: Joshua.Herald@bakerhughes.com Email: reedwards@hilcorp.com Mobile: 907-398-8303 Mobile: 907-250-5081 Service Point: Service Representatives: BJS, KENAI Rod Edwards Bus Phone: 907-776-4084 Account Manager Bus Phone: 907-267-3487 Fax: 907-776-4087 Mobile: 907-229-6536 Powered by PowerVision Gr4105 Operator Name: HILCuRP ENERGY CO ri� Well Name: GRANITE PT ST#11-13RD BAKER Job Description: Lightning 3500 HUGHES Date: October 17, 2013 Proposal No: 1001162089C JOB AT A GLANCE Surface Treating Pressure (max) 7,190 psi Total Rate(max) 18.00 bpm Estimated Pump Time (HH:MM) 01:20 Frac Fluid 53,810 gals Lightning 3500 Flush 4,379 gals Linear gel Proppants 38,628 lb CARBOLITE, 20/40 19,202 lb CARBOBOND LITE 20/40 1 po,t Pmt1r71,41- OGtobcr 17.2013 4:44 PMPage Gr4111 Have more questions? You can find us at: http://www.bakerhughes.com/products-and-services/pressure-pumping Operator Name: HILCOr.. ENERGY CO Mai Well Name: GRANITE PT ST#11-13RD BAKER Job Description: Lightning 3500 HUGHES Date: October 17, 2013 Proposal No: 1001162089C WELL DATA RESERVOIR DATA Formation Hemlock Depth to Middle Perforation 11,354 ft Reservoir Pressure 5,300 psi Fracture Gradient 0.85 psi/ft Bottom Hole Fracture Pressure 9,651 psi Bottom Hole Static Temperature 190 ° F PERFORATED INTERVAL DEPTH(ft) Shots per Foot Pelf Diameter Total Perfs MEASURED TRUE VERTICAL (in) 11,349 - 11,359 11,349 - 11,359 I 6 0.75 I 102 Total Number of Perforations 102 Total Feet Perforated 10 ft TUBULAR GEOMETRY Top Bottom Tubing 3 1/2" O.D. (2.922" .I.D) 10.3#P-110 0 11,000 Casing 7" O.D. (6.094" .I.D) 32# 0 11,510 End of Tubing 11,000 ft Pump Via Tubing Report Printed on October 17.2013 444 PM Page 2 Gr4119 Have more questions? You can find us at: http://www.bakerhughes.com/products-and-services/pressure-pumping Operator Name: HILCO, :NERGY CO r�I Well Name: GRANITE PT ST#11-13RD BAKER Job Description: Lightning 3500 HUGHES Date: October 17, 2013 Proposal No: 1001162089C FLUID SPECIFICATIONS Frac Fluid: Lightning 3500 Pumped Liquid 53,810 Gallons Mixed Liquid Volume: 56,400 Gallons Components: 8.75 gpt GLFC-5D Gelling Agent 2 gpt BF-8L Buffers/pH Control Product 1 gpt Clay Master-5C Clay Stabilization Product 1 gpt Flo-Back 30 Surface Tension Reducer 1 ppt High Perm CRB Gel Breaker 0.9 gpt XLW-32 Crosslinker 0.4 ppt X-CIDE 207 StimPlus Products 0.25 gpt EnZyme G HT-III Gel Breaker Flush: Linear gel 4,379 Gallons Components: 8.75 gpt GLFC-5D Gelling Agent 4 ppt High Perm CRB Gel Breaker 1 gpt Clay Master-5C Clay Stabilization Product 1 gpt EnZyme G HT-III Gel Breaker 1 gpt Flo-Back 30 Surface Tension Reducer 0.4 ppt X-CIDE 207 StimPlus Products Proppants 38,628 lb 100% CARBOLITE, 20/40 19,202 lb 100% CARBOBOND LITE 20/40 Additive volumes may change baseed on actual well conditions pending laboratory testing. Base fluid is estimated at 6% KCL. Report Printed on October 17,2013 4 44 PM Page 3 a it Have more questions? You can find us at: http://www.bakerhug hes.com/products-and-services/pressure-pumping Operator Name: HILCC ENERGY CO ra- Well Name: GRANITE PT ST#11-13RD BAKER Job Description: Lightning 3500 HUGHES Date: October 17, 2013 Proposal No: 1001162089C FRACTURE TREATMENT SCHEDULE INPUT PARAMETERS TVD Depth (Mid Perforation) 11,354 ft MD Depth (Mid Perforation) 11,354 ft Perforations Number 102 Perforation Diameter 0.750 in Bottom Hole Frac Pressure 9,651 psi l Bottom Hole Static Temperature 190 ° F Top Bottom Tubing 3 1/2" O.D. (2.922" I.D.) 10.3#P-110 0 11,000 Casing 7"O.D. (6.094" I.D.) 32# 0 11,510 CALCULATED RATES, PRESSURES & HHP REQUIREMENTS Maximum Minimum Average Surface Treating Pressure (psi) 7,190 5,344 6,801 Slurry Rate (bpm) 18.0 18.0 18.0 Proppant Rate (lbs/min) 4,002 724 3,009 Slurry Hydraulic Horsepower 3,173 2,358 3,001 PROCEDURE Fluid Proppant Type Volume Conc. Type Stage Cum Stage I (gal) (ppa) (lbs) (lbs) 1 Lightning 3500 6000 Mini Frac 2 Lightning 3500 35870 Pad 3 Lightning 3500 480 1.000 100%CARBOLITE, 20/40 480 480 4 Lightning 3500 690 2.000 100%CARBOLITE, 20/40 1380 1860 5 Lightning 3500 1300 3.000 100%CARBOLITE, 20/40 3900 5760 6 Lightning 3500 1960 4.000 100%CARBOLITE, 20/40 7840 13600 7 Lightning 3500 2590 5.000 100%CARBOLITE, 20/40 12950 26550 8 Lightning 3500 2013 6.000 100%CARBOLITE, 20/40 12078 38628 9 Lightning 3500 1147 6.000 100%CARBOBOND LITE 6882 45510 10 Lightning 3500 1760 7.000 100%CARBOBOND LITE 12320 57830 11 Linear gel 4379 Flush 57830 Total 58189 I 57830 Report Printed on October 17 2013 4.45 PM Page 4 Gr4141 Have more questions? You can find us at: http://www.bakerh ug hes.com/products-and-services/pressure-pumping Operator Name: HILCC ENERGY CO ./ Well Name: GRANITE PT ST#11-13RD BAKER Job Description: Lightning 3500 HUGHES Date: October 17, 2013 Proposal No: 1001162089C FRACTURE TREATMENT SCHEDULE TREATMENT SCHEDULE Surface Rates Volume Stage Treating Slurry Clean Prop. Rate Slurry Fluid Pump Pressure (bpm) Fluid (Ib/min) Stage Cum. Stage Cum. Time Stage (psi) (bpm) (bbls) (bbls) (bbls) (bbls) hh:mm:ss 1 7190 18.0 18.0 142.9 142.9 142.9 142.9 00:07:56 2 7190 18.0 18.0 854.0 996.9 854.0 996.9 00:47:26 3 6898 18.0 17.2 724.0 11.9 1008.8 11.4 1008.3 00:00:39 4 6608 18.0 16.5 1389.1 17.9 1026.7 16.4 1024.8 00:00:59 5 6325 18.0 15.9 2002.4 35.1 1061.8 31.0 1055.7 00:01:56 6 6054 18.0 15.3 2569.5 54.9 1116.7 46.7 1102.4 00:03:03 7 5795 18.0 14.7 3095.6 75.3 1192.0 61.7 1164.0 00:04:11 8 5550 18.0 14.2 3584.9 60.6 1252.6 47.9 1212.0 00:03:22 9 5568 18.0 14.1 3553.4 34.9 1287.5 27.3 1239.3 00:01:56 10 5344 18.0 13.6 4001.1 55.4 1342.9 41.9 1281.2 00:03:04 11 6298 18.0 18.0 104.3 1447.2 104.3 1385.5 00:05:47 Total Pump Time: 01:20:23 1 Report Printed on: October 17,2013 4:45 PM Page 5 6,4141 Have more questions? You can find us at: http://www.bakerhughes.com/products-and-services/pressure-pumping i Operator: HILCOR. ANERGY CO .gi/ Well Name: GRANITE PT ST#11-13RD Job Description: Lightning 3500 BAKER Date: October 17, 2013 HUGHES Proposal No: 1001162089C PRICE ESTIMATE Product Material QTY UNIT PRODUCT DESCRIPTION UNIT GROSS DISC NET PRICE AMOUNT (%) AMOUNT 25 lbs X-CIDE 207 99.25 2,481.25 30.0 1,736.88 510 gals GLFC-5D 110.50 56,355.00 30.0 39,448.50 19 gals EnZyme G HT-III 0.00 0.00 30.0 0.00 100 gals ES-4A, Greenskeeper Solvent 66.00 6,600.00 30.0 4,620.00 108 gals BF-8L 53.00 5,724.00 30.0 4,006.80 19.2.00 lbs CARBOBOND LITE 20/40 3.50, 67,200.00 35.0 43,680.00 74 lbs High Perm CRB 69.50 5,143.00 30.0 3,600.10 59 gals Flo-Back 30 135.50 7,994.50 30.0 5,596.15 49 gals XLW-32 43.60 2,136.40 30.0 1,495.48 1. 59 gals Clay Master-5C 172.50 10,177.50 30.0 7,124.25 _ 38_628 lbs CARBOLITE, 20/40 2.51 96,956.28 30.0 67,869.40 Product Material Subtotal: $260,767.93 $179,177.56 Service Charges QTY UNIT PRODUCT DESCRIPTION UNIT GROSS DISC NET PRICE AMOUNT (%) AMOUNT 7 day Equipment Operator-daily charge 1,165.00 8,155.00 0.0 8,155.00 1 day Mechanic-daily charge 1,165.00 1,165.00 0.0 1,165.00 1 ea Personnel Surcharge- Frac>5000 2,525.00 2,525.00 0.0 2,525.00 1 2hrs Comp. Sand Proportioning, 11-20 bpm 3,325.00 3,325.00 30.0 2,327.50 2 ea Service Supervisor- Daily Charge 1,420.00 2,840.00 0.0 2,840.00 i 1 8hrs Technical field rep., 1st 8 hours 1,210.00 1,210.00 0.0 1,210.00 4 hrs Technical field rep., after 8 hour 165.50 662.00 0.0 662.00 1 8hrs Lab Technician on Location, 1st 8 Hrs 890.00 890.00 0.0 890.00 Service Charges Subtotal: $20,772.00 $19,774.50 Customer will be charged for all'SPECIAL PROPPANTS'delivered to location,whether they are pumped or not. All proppants other than standard grade frac sand are considered'SPECIAL PROPPANTS'. The technical data contained in this proposal is based on the best information available at the time of writing and is subject to further analysis and testing. The pricing data contained in this proposal are estimates only and may vary depending on the work actually performed. Pricing does not include federal,state and local taxes or royalties. This quotation is based on Baker Hughes being awarded the work on a first call basis and within thirty(30)days of the proposal date. These prices will be subject to review if the work is done after thirty(30)days from the proposal date,or on a second or third call basis. Report Printed on October 17 2013 4 45 PM Page 6 6,4161 Have more questions?You can find us at:http://www.bakerhughes.com/products-and-services/pressure-pumping Operator: HILCOR. ,LNERGY CO FG' Well Name: GRANITE PT ST#11-13RD Job Description: Lightning 3500 BAKER Date: October 17, 2013 HUGHES Proposal No: 1001162089C PRICE ESTIMATE Equipment QTY UNIT PRODUCT DESCRIPTION UNIT GROSS DISC NET PRICE AMOUNT (%) AMOUNT 6000 hrs Diagnostic/Pre-Pad Pumping 1.68 10,080.00 30.0 7,056.00 6000 2hrs Frac HHP, 7001-8000 psi 25.90 155,400.00 30.0 108,780.00 10 ea Radio Communications 231.00 2,310.00 30.0 1,617.00 1 job Continuous Mix Liquid Gel Processing 8,725.00 8,725.00 30.0 6,107.50 1 job Data Acquisition, Frac/Acid-Enhanced 7,425.00 7,425.00 30.0 5,197.50 1 day Computer Command Center 2,145.00 2,145.00 30.0 1,501.50 1 day Sand King, less than 300,000 lb 2,470.00 2,470.00 30.0 1,729.00 2 job Densiometer 1,540.00 3,080.00 30.0 2,156.00 2 job 3 in Frac Valve 650.00 1,300.00 30.0 910.00 1 job Pop-Off Release Valve 343.00 343.00 30.0 240.10 • 1 job N2 pressurized pop-off valve 1,720.00 1,720.00 30.0 1,204.00 480 gals Proppant Conc Charge/0.1-1.0 lbs , 0.15 72.00 30.0 50.40 3950 gals Proppant Conc Charge/1.1-4.0 lbs 0.17 671.50 30.0 470.05 5750 gals Proppant Conc Charge/4.1-6.0 lbs 0.34 1,955.00 30.0 1,368.50 1760 gals Proppant Conc Charge/6.1-9.0 lbs 0.55 968.00 30.0 677.60 7 day ,Hazardous Chemical Storage Tank 515.00 3,605.00 30.0 2,523.50 Equipment Subtotal: $202,269.50 $141,588.65 TOTAL: $483,809.43 $340,540.71 Customer will be charged for all'SPECIAL PROPPANTS'delivered to location,whether they are pumped or not. All proppants other than standard grade frac sand are considered'SPECIAL PROPPANTS'. The technical data contained in this proposal is based on the best information available at the time of writing and is subject to further analysis and testing. The pricing data contained in this proposal are estimates only and may vary depending on the work actually performed. Pricing does not include federal,state and local taxes or royalties. This quotation is based on Baker Hughes being awarded the work on a first call basis and within thirty(30)days of the proposal date. These prices will be subject to review if the work is done after thirty(30)days from the proposal date,or on a I second or third call basis. Report Printed o,r October 17,2013 4:45 PM Page 7 G,4161 Have more questions?You can find us at:http:/Iwww.bakertughes.com/products-and-services/pressure-pumping r1 KER CONDITIONS HUGHES The services and products will be provided under the attached Baker Hughes Incorporated Worldwide Terms and Conditions. By requesting that Baker Hughes provide the services and products described herein, Customer accepts all of the terms and conditions of this proposal, including the attached Baker Hughes Incorporated Worldwide Terms and Conditions. In the event that Customer and Baker Hughes have executed a Master Services Agreement covering the services and products to be provided, such Master Services Agreement shall govern in place of the Baker Hughes Worldwide Terms and Conditions. Report Printed on: OCT-17-13 04:45 Gr4175 NOTE:THIS AGREEMENT CONTAINS PROVISIONS THAT INDEMNIFY AND/OR RELEASE THE INDEMNIFIED AND/OR RELEASED PARTY FROM THE CONSEQUENCES OF ITS OWN NEGLIGENCE .,.. AND OTHER LEGAL FAULT. ER TERMS AND CONDITIONS BAK HUGHES Worldwide Orders for rental equipment("Equipment"),services("Services'',and the supply or sale of products,chemicals,or NO1W1THSTANDING PARAGRAPH B.ABOVE,SHOULD CUSTOMER FAIL TO RECOVER SUCH TOOLS equipment("Products")to be provided by Baker Hughes Incorporated through its bred or indirect subsidiaries(in each LOST IN THE WELL,OR SHOULD SUCH TOOLS BECOME DAMAGED IN THE WELL,OR DAMAGED case such subsidiary is referred to herein as"BHI"and shall be severally liable for all obligations of BHI herein arising DURING RECOVERY,CUSTOMER SHALL REIMBURSE BHI FOR THE COST OF REPAIRING ANY TOOLS from or related to the order)to its customers(each a"Customer")are subject to acceptance by BHI,and any orders so SO DAMAGED,OR THE REPLACEMENT VALUE OF ANY SUCH TOOLS THAT ARE LOST OR NOT accepted will be governed by the teens and conditions stated herein and any additional teens proposed or agreed to in REPARABLE. writing by an authorized representative of BHI(these terms and conditions and any such additional terms collectively referred to herein as the"Agreement'). FURTHER,NOTWITHSTANDING PARAGRAPH B.ABOVE,ALL RISKS ASSOCIATED WITH LOSS OF OR DAMAGE TO TOOLS WHILE IN THE CUSTODY OR CONTROL OF CUSTOMER OR DURING 1.PAYMFNTTFRMS TRANSPORTATION ARRANGED BY OR CONTROLLED BY CUSTOMER,SHALL BE BORNE BY Unless alternate payment terms are specified or approved by the BHI Credit Department,all charges billed by BHI must CUSTOMER. be paid within thirty(30)days of the date of invoice.For invoices unpaid after thirty(30)days,at BHI's option,discounts from list price may be revoked and interest may be charged at the rate of ten percent(10%)per annum unless such rate E.NOTWITHSTANDING ANYTHING CONTAINED IN THIS AGREEMENT TO THE CONTRARY,CUSTOMER contravenes local law in which case the interest will accrue at the maximum rate allowed by law.Operating,production SHALL RELEASE,INDEMNIFY,DEFEND AND HOLD BHI INDEMNITEES HARMLESS FROM AND AGAINST or well conditions that prevent satisfactory operation of Equipment,Services or Products do not relieve Customer of its ANY AND ALL CLAIMS ASSERTED BY OR IN FAVOR OF ANY PERSON,PARTY,OR ENTITY(INCLUDING payment respansibily. BHI INDEMNITEES)ARISING OUT OF OR RELATED TO:(I)LOSS OF OR DAMAGE TO ANY WELL OR HOLE(INCLUDING BUT NOT UMITED TO THE COSTS OF RE-DRILL AND SIDETRACK),(II)BLOWOUT, 2.CANCELLATION AND RETURNS FIRE,EXPLOSION,CRATERING OR ANY UNCONTROLLED WELL CONDITION(INCLUDING BUT NOT Product:Orders for Products that are subject to cancellation after acceptance by BHI,but before delivery,will be UMITED TO THE COSTS TO CONTROL A WILD WELL AND THE REMOVAL OF DEBRIS),(Ill)DAMAGE TO subject to a restocking charge of at least twenty-five percent(25%),plus any packing and transportation costs incurred ANY RESERVOIR,GEOLOGICAL FORMATION OR UNDERGROUND STRATA OR THE LOSS OF OIL, before delivery.Products specially built or manufactured to Customer specifications,or orders for substantial quantities WATER OR GAS THEREFROM,(IV)THE USE OF BH INDEMNITEES RADIOACTIVE TOOLS OR ANY manufactured specially for Customer,may not be cancelled. CONTAMINATION RESULTING THEREFROM(INCLUDING BUT NOT LIMITED TO RETRIEVAL OR CONTAINMENT AND CLEAN-UP),(V)POLLUTION OR CONTAMINATION OF ANY KIND INCLUDING BUT Products may be rethmed for credit only with prior written authorization from BH.Such Products must be unused,in NOT UMITED TO THE COST OF CONTROL,REMOVAL,CLEAN-UP AND REMEDIATION,OR(VI)DAMAGE reusable condition,and with original unopened containers.Credit will be issued for the quantity returned at the original TO,OR ESCAPE OF ANY SUBSTANCE FROM,ANY PIPELINE VESSEL,OR STORAGE OR PRODUCTION purchase price,less a restocking charge of at least twenty-five percent(25%)and any actual packing and transportation FACIUTY. costs incurred by BHI.No credit will be given for shipping charges incurred by Customer. F.CUSTOMERACKNONLEDGESTHAT CUTTINGS AND WASTE REMAIN CUSTOMERS EouiomentiServices:In the event Customer cancels an order for Services,Customer shall be liable for all costs incurred RESPONSIBIUTY.CUSTOMER SHALL RELEASE,INDEMNFY,DEFEND AND HOLD BHI INDEMNITEES by BHI in the mobilization/demobilization related thereto,and any other reasonable costs incurred by BHI incident to such HARMLESS FROM AND AGAINST ANY AND ALL CLAIMS,ASSERTED BY OR IN FAVOR OF ANY PERSON cancellation.In the event Customer cancels an order for Equipment,Customer shall be table for any transportation OR ENTITY ARISING OUT OF OR RELATED TO THE TRANSPORTATION,STORAGE,TREATMENT, costs incurred by BHI in the mobilization/demobilization of the Equipment.In addition,a restocking charge of at least DISPOSAL OR HANDLINGOF CUTTINGS AND WASTE,INCLUDING,WITHOUT UMITATION, twenty-five percent(25%)of the original Equipment order may be applied at BHI's sole discretion. CONTAMINATION OF,OR ADVERSE EFFECTS ON THE ENVIRONMENT OR ANY FORM OF PROPERTY, OR ANY VIOLATION OR ALLEGED VIOLATION OF STATUTES,ORDINANCES,LAWS,ORDERS,RULES 3.THIRD-PARTY CHARGES.TAXES AND REGULATIONS(INCLUDING,WITHOUT UMITATION,ALL CLAIMS UNDER THE COMPREHENSIVE Customer shall pay all third-party charges,in compliance with BHI's current price list and any sales,use,rental or other ENVIRONMENTAL RESPONSE,COMPENSATION,AND LIABIUTY ACT("CERCLA'),42 U.S.C.§§9601 ET taxes that may be applicable to transactions hereunder.Customer shall pay all applicable customs,excise,import and SEQ.,OR OTHER APPLICABLE STATUTES OR REGULATIONS). other duties unless otherwise agreed to in writing by an authorized representative of BHI.Customer shall provide necessary import licenses and extensions thereof. G.CUSTOMER SHALL RELEASE,DEFEND,INDEMNIFY AND HOLD BHI INDEMNTEES HARMLESS FROM AND AGAINST ANY CLAIMS FOR CONSEQUENTIAL DAMAGES ASSERTED BY OR IN FAVOR OF ANY 4.RISK OF LOSS AND TITLE CONSIGNMENT STORAGE MEMBER OF CUSTOMER INDEMNITEES.BHI SHALL RELEASE,DEFEND,INDEMNFY AND HOLD Unless otherwise agreed to in writing between BHI and Customer:(i)for Product sales within the United States of CUSTOMER INDEMNITEES HARMLESS FROM AND AGAINST ANY CLAIMS FOR CONSEQUENTIAL America,title and risk of loss shall pass to Customer as soon as the Products depart BHI's point of origin;and(ii)for DAMAGES ASSERTED BY OR IN FAVOR OF ANY MEMBER OF BHI INDEMNITEES. Product sales outside the United States of America,INCOTERM 2010"CPT'shall apply with the following exception: TITLE AND RISK OF LOSS REMAIN WITH BHI UNTIL THE PRODUCTS REACH THE PORT OF ENTRY.For H.In the event this agreement is subject to the indemnity or release limitations in Chapter 127 of the Texas Civil Products provided on consignment the risk of loss shall pass to Customer as soon as the Products depart BHI's point of Practices and Remedies Code(or any successor statute),and so long as such limitations are in force,each party origin;however,the file shall remain with BHI until the Product is used by Customer. covenants and agrees to support the mutual indemnity and release obligations contained in Paragraphs B.and C.above by carrying equal amounts of insurance(or qualified self-insurance)in an amount not less than U.S. In the event BHI agrees to store Products after title passes to Customer,the risk of loss shall remain with Customer.If $5,000,000.00 for the benefit of the other party as indemnitee. any such Products remain on BHI's premises for more than two(2)years from the date initially placed in storage,title shall revert back to BHI,and BHI may resell or scrap any such Products with no lability to Customer for any proceeds I.THE EXCLUSIONS OF LIABILITY,RELEASES AND INDEMNITIES SET FORTH IN PARAGRAPHS B. generated therefrom. THROUGH G.OF THIS ARTICLE 5,AND ARTICLES 6 AND 10,SHALL APPLY TO ANY CLAIM(S)WITHOUT REGARD TO THE CAUSE(S)THEREOF INCLUDING BUT NOT UMITED TO PRE-EXISTING CONDITIONS, 5. LIABILITIES-RELEASES AND INDEMNIFICATION: WHETHER SUCH CONDITIONS BE PATENT OR LATENT,THE UNSEAWORTHINESS OF ANY VESSEL OR A.In this Agreement()"BHI Indemnitees"means BHI,its parent,subsidiary and affiliated or related companies;its VESSELS,IMPERFECTION OF MATERIAL,DEFECTOR FAILURE OF PRODUCTS OR EQUIPMENT, subcontractors at any tier;and the officers,directors,employees,consultants,and agents of all of the foregoing;(i) BREACH OF REPRESENTATION OR WARRANTY(EXPRESS OR IMPUED),ULTRAHAZARDOUS "Claims"means all daims,demands,causes of action,liabilities,damages,judgments,fines,penalties,awards,losses, ACTIVITY,STRICT UABIUTY,TORT,BREACH OF CONTRACT,BREACH OF DUTY(STATUTORY OR costs,expenses(including,without limitation,attorneys'fees and costs of litigation)of any kind or character arising out OTHERIMSE),BREACH OF ANY SAFETY REQUIREMENT OR REGULATION,OR THE NEGLIGENCE, of,or related to,the performance of or subject matter of this Agreement(ii)"Consequential Damages"means any GROSS NEGUGENCE,WILLFUL MISCONDUCT,OR OTHER LEGAL FAULT OR RESPONSIBIUTY OF ANY indired,special,punitive,exemplary or consequential damages or losses(whether foreseeable or not at the date of this PERSON,PARTY,OR ENTITY(INCLUDING THE INDEMNIFIED OR RELEASED PARTY),WHETHER SUCH Agreement)under applicable law and damages for lost production,lost revenue,lost product,lost profit,lost business, FORM OF NEGUGENCE BE SOLE,JOINT OR CONCURRENT,ACTIVE OR PASSIVE. lost business opportunities,or charges for rig time,regardess of whether the same would be considered direct,indirect, special,punitive,exemplary or consequential damages or losses under applicable law;(v)"Customer Indemnitees" J.REDRESS UNDER THE INDEMNITY PROVISIONS SET FORTH IN THIS ARTICLE 5 SHALL BE THE means Customer,its parent,subsidiary and affiliated or related companies;its co-lessees,co-owners,partners,joint EXCLUSIVE REMEDIES AVA LABLE TO THE PARTIES HERETO FOR THE CLAIMS COVERED BY SUCH operators and joint venturers;its client or customer if it is not the end user of the Equipment,Services,or Products;its PROVISIONS. other contractors at any tier;and the officers,directors,employees,consultants,and agents of ell of the foregoing;(v) "Cuttings and Waste"means any drill cuttings and associated muds,waste or materials from the well arising from or 6.DIRECTIONAL DRILLING processed pursuant to this Agreement;and(vi)'Tools"means Equipment and any of BHI Indemnitees'instruments, Customer shall famish BHI with a well location plan(certified by Customer as correct)setting out the surface equipment or tools. location of the well,the lease,license,or property boundary lines,and the bottom hole location of Customer's directionally drilled well.If,in the course of drilling the well,it becomes evident to BHI that the certified plan is in B.BH SHALL RELEASE,INDEMNIFY,DEFEND AND HOLD CUSTOMER INDEMNITEES HARMLESS FROM AND error,BHI shall notify Customer of the error,and Customer shall be responsible to regulate al directional dulling AGAINST ANY AND ALL CLAIMS ARISING OUT OF OR RELATED TO(I)PERSONAL OR BODILY INJURY,ILLNESS, factors so that Customer's well bottom hole location will be situated on Customer's property,license,or leasehold SICKNESS,DISEASE OR DEATH OF ANY MEMBER OF BHI INDEMNITEES,AND(II)LOSS,DAMAGE OR at total depth of the well being drilled.CUSTOMER SHALL RELEASE,DEFEND,INDEMNIFY AND HOW BH DESTRUCTION OF REAL OR PERSONAL PROPERTY,WHETHER OWNED,LEASED,OR CHARTERED,OF AM' INDEMNITEES HARMLESS FROM AND AGAINST ANY CLAIMS ARISING OUT OF,OR RELATED TO, MEMBER OF BH INDEMNITEES. SUBSURFACE TRESPASS ARISING OUT OF DIRECTIONAL DRILLING OPERATIONS OR OTHER OPERATIONS PERFORMED BY BHI INDEMNITEES OR CUSTOMER INDEMNITEES. C.CUSTOMER SHALL RELEASE,INDEMNIFY,DEFEND AND HOLD BHI INDEMNITEES HARMLESS FROM AND AGAINST ANY AND ALL CLAIMS ARISING OUT OF OR RELATED TO(I)PERSONAL OR BODILY INJURY,ILLNESS, 7.CUSTOMER WARRANTY/BINDING AUTHORITY SICKNESS,DISEASE OR DEATH OF ANY MEMBER OF CUSTOMER INDEMNITEES,AND(II)LOSS,DAMAGE OR If Customer is not the sole owner of the mineral interests,the well or the field,Customer's request for Services, DESTRUCTION OF REAL OR PERSONAL PROPERTY,WHETHER OWNED,LEASED,OR CHARTERED,OF ANY Egripnent or Products shall constitute Customer's warranty that Customer is the duly constituted agent of each MEMBER OF CUSTOMER INDEMNITEES. and every owner and has full authority to represent the interests of the same with respect to all decisions taken throughout the provision of any Services,Equipment or Products hereunder.CUSTOMER SHALL RELEASE, D.SHOULD TOOLS BECOME LOST OR DAMAGED IN THE WELL OR HOLE WHEN PERFORMING OR DEFEND,INDEMNIFY AND HOLD BHI INDEMNITEES HARMLESS FROM AND AGAINST ALL CLAIMS ATTEMPTING TO PERFORM THE SERVICES HEREUNDER,IT IS UNDERSTOOD THAT CUSTOMER SHALL MAKE RESLLTING FROM THE ALLEGATION BY ANY PERSON OR ENTITY THAT CUSTOMER HAS EVERY EFFORT TO RECOVER THE LOST OR DAMAGED TOOLS AT ITS SOLE COST.CUSTOMER SHALL MISREPRESENTED OR LACKED SUFFICIENT AUTHORITY TO REPRESENT SUCH PERSON OR ENTITY ASSUME THE ENTIRE RESPCNSIBIUTY FOR FISHNG OPERATIONS IN THE RECOVERY OR ATTEMPTED AS WARRANTED BY CUSTOMER IN THIS ARTICLE. RECOVERY OF ANY SUCH LOST OR DAMAGED TOOLS.NONE OF BHI'S EMPLOYEES ARE AUTHORIZED TO DO ANYTHING WHATSOEVER NOR SHALL ANY OF BHI'S EMPLOYEES BE REQUIRED BY CUSTOMER TO DO 6.ACCESS TO WELL AND WFI I SITE STTNRAITF ANYTHING,OTHER THAN CONSULT IN AN ADVISORY CAPACITY WITH CUSTOMER IN CONNECTION WITH With respect to onshore and offshore operations,Customer shall provide at its expense adequate means of SUCH FISHING OPERATIONS. transportation required for Tools,Products and BHI personnel to gain access tom return from a well site,and Rev.1 January Report Printed on: OCT-17-13 04:45 Gr4175 shall obtain at Customer's expense all permits,licenses or other authorization required for BHI to enter upon work PRODUCTION FORECASTS AND RESERVE ESTIMATES,FURNISHED BY BH TO CUSTOMER areas for the purposes contemplated.When necessary to repair roads or bridges,or to provide transportation to HEREUNDER),AND CUSTOMER HEREBY AGREES TO RELEASE,DEFEND,INDEMNFY AND HOLD BH move Tools,Products or BHI personnel,such shall be arranged and paid for by Customer. INDEMNITEES HARMLESS FROM ANY CLAIMS ARISING OUT OF THE USE OF SUCH INTERPRETATIONS AND/OR RECOMMENDATIONS. Customer shall provide proper storage space at the well site,meeting all applicable safety and security requirements and consistent with good Industry practices,f.the Tools end Products,inducing,without limitation,all explosive and BHI will endeavor to transmit data to Customer as accurately and securely as practicable in accordance with radioactive materials. current industry practice.Notwithstanding the foregoing,BHI does not warrant the accuracy of data transmitted by electronic processes and will not be responsible to Customer for accidental or intentional interception of such data 9.RADIOACTIVE SOURCES by others. Radoactive sources which may be used in BHI's'Services are potentially dangerous.Customer agrees to comply with all applicable governmental regulations governing the use and handling of radoactive sources.In the event a BHI does not represent or warrant that the Products are or will be compliant with the requirements of REACH(the radioactive source becomes stack in a well,Customer,at Customer's sole risk and expense will make a reasonable Registration Evaluation Authorisation and Restriction of Chemicals Regulation 1907/2006,as amended)and all attempt to recover such radioactive source in accordance with 10 C.F.R§39.15(a)(1)-(4)or other applicable implied warranties as to compliance with REACH("REACH Compliance")are hereby excluded to the fullest extent regulations and use special precautions to prevent damaging the source during recovery operations.If the source permitted by law.Without prejudice to the foregoing,BHI shall use reasonable endeavors to obtain or maintain cannot be recovered,Customer,at Customer's sole risk and expense,will isolate the radoactive material by REACH Compliance in respect of the Products where required by law,unless it is Customer's responsibility to cementing it in place or by other means consistent with 10 C.F.R§39.15 or other applicable statutes or regulations. obtain or maintain REACH Compliance or any noncompliance is caused by any ad or omission of Customer.In the event BHI receives written notice from any competent authority,or in its reasonable opinion decides,that any 10.WARRANTY of the Products are not or will not become REACH Compliant,it shall inform Customer in writing within a A.Swim: BHI warrants that the Services shall conform to the material aspects of the specifications agreed to in reasonable time and may suspend any further deliveries of the relevant Products and/or terminate the Order. writing by BHI and Customer.In the event that the Services fail to conform to such specifications,BH shall re- Customer shall promptly provide such information to BHI as may be required in order to obtain and maintain perform that part of the non-conforming Services,provided BHI is notified thereof in writing by Customer prior to REACH Compliance in respect of the Products and shall comply with its obligations under REACH. BHI's departure from the work site. THIS ARTICLE 10 SETS FORTH CUSTOMER'S SOLE REMEDIES AND BHI'S ONLY OBLIGATION WITH B.Ewjpment:BHI warrants that the Equipment will be of the types specified by and agreed to in writing by BHI and REGARD TO DEFECTIVE OR NON-CONFORMING SERVICES,EQUIPMENT OR PRODUCTS EXCEPT AS IS Customer,and will be in good operating condtion.Liability for loss or damage to Equipment is set forth in Article 5. OTHERWISE EXPRESSLY PROVIDED PURSUANT TO THE PROVISIONS OF THIS ARTICLE 10,BN MAKES NO WARRANTY OR GUARANTEE OF ANY KIND,EXPRESS OR IMPLIED,INCLUDING NO IMPLIED C.products'(Excluding doll bits,electric submersible pumps and associated cable and surface equipment,specialty WARRANT(OF MERCHANTABIUTY OR FITNESS FOR A PARTICULAR PURPOSE REGARDING ANY chemical Products and specialty Products):BHI warrants that the Products shall conform to BHI's published SERVICES PERFORMED OR EQUIPMENT OR PRODUCTS SUPPUED BY BHI HEREUNDER.IN NO EVENT specifications or the specifications agreed to in writing by BHI and Customer.If any of the Products fail to conform to SHALL BHI BE UABLE FOR RIG TIME INCURRED BY CUSTOMER INDEMNTEES AS A RESULT OF such specifications upon inspection by BHI,BH,at its option,shall repair or replace the non-conforming Products DEFECTIVE OR NON-CONFORMING SERVICES,EQUIPMENT OR PRODUCTS. with the type originally fumished or issue credit to the Customer,provided 91-111s notified thereof in writing within thirty(30)days after delivery of the particular Products. 11.LOST EQUIPMENT INDEMNITY BUY-BACK In some locations,lost equipment indemnity buyback("LEIB")is available for some Tools.LEIB must be D.DIABEI:BHI warrants that the drill bits to be provided by BHI pursuant to this Agreement shall conform to BHI's purchased by Customer prior to the Tools leaving BH's point of origin.Regardless of LEIB,Customer shall make published specifications.If any of the drill bits fail to conform to such specifications upon inspection by BHI,Bull,at every reasonable effort to recover BHI's Tools lost or damaged in a well or hole in accordance with Paragraph 50. its option,shall repair or replace the non-conforming drill bits with the type originally furnished or issue omit to the BHI reserves the right not to offer LEIB at its sole discretion. Customer,provided BHI is notified thereof in writing within ninety(90)days from the date of shipment. 12.INSURANCE E.Pectic Submersible Pumas and Associated Cable and Surface Ewioment BHI warrants that the dec4ical Upon written request,each party shall furnish to the other party certificates of insurance evidencing that adequate submersible pumps and associated cable and surface equipment to be provided by BHI pursuant to this Agreement insurance to support each party's obligations hereunder has been secured.To the extent of each party's release shall conform to BHI's published specifications.If any of the electric submersible pumps or associated cable or and indemnity obligations hereunder,each party agrees that all such insurance policies shall()be primary to the surface equipment fail to conform with such specifications upon inspection by BHI,BHI,at its option,shall repair or other party's instrance,(l)include the other party,its parent,subsidary and affiliated or related companies,its replace the non-conforming electric submersible pumps or associated cable or surface equipment with the type subcontractors and other contractors,and its and their respective officers,directors,employees,consultants and originally furnished,provided BH is notified thereof in writing within the earlier of twelve(12)months from the date of agents as additional insured,and(ii)be endorsed to waive subrogation against the other party,its parent, installation or eighteen(18)months from the date of shipment.Warranty claims by Customer must be submitted to subsidary and affiliated or related companies,its subcontractors and other contractors,and its and their respective BHI within sixty(60)days of the failure date of the electric submersible pumps or associated cable or surface officers,directors,employees,consultants and agents. equipment. 13.CHANGE OF DESIGN F.Specialtv Chemical Products:BHI warrants that the specialty chemical Products to be provided by 81-1 pursuant BHI expressly reserves the right to change or modify the design and construction of any of its Products without to this Agreement shall,upon departure from BHI's point of origin,conform to the published physical and chemical obligation to famish or instal such changes or modficatios on Products previously or subsequently sold. specifications established by BHI for each such Product.If any of the specialty chemical Products fail to conform to such specifications,BHI,at its option,shall replace the non-conforming specialty chemical Products with the type 14.PATENTS originally famished or issue credit to the Customer,provided BHI is notified thereof in writing within thirty(30)days BHI warrants that the use or sale of Equipment or Products hereunder will not infringe valid patents of others by after the specialty chemical Products depart BFI's point of origin. reason of the use or sale of such Equipment or Products per se,and hereby agrees to hold CUSTOMER harmless against judgment for damages for infringement of any such patent,provided that Customer shall promptly notify G.Scedaltn Products In the event BHI is to provide Products to Customer based upon Customer's specific request BHI in writing upon receipt of any daim for infringement,or upon the fling of any such suit for infringement, that BHI develop,manufacture,test or put to use Products that are intended to satisfy a unique need identified by whichever first occurs,and shall afford BHI full opportunity,at BHI's option and expense,to answer such claim or Customer and are not"standard"Products of BH,Customer hereby recognizes and agrees that the specialty threat of suit,assume the control of the defense of such suit,and settle or compromise same in any way BHI sees Products being provided do not necessarily have or contain the same or similar characteristics as Bill's"standard" fit.BHI does not warrant that such Equipment or Products:(i)will not infringe any such patent when not of 611's Products,including,but not limited to,a historical performance against which future performance can be measured. manufacture,or specially made,in whole or in part,to the Customer's design specifications;or(ii)if used or sold in In developing,manufacturing,testing and putting to use any specialty Products,BFI will be relying upon information combination with other materials or apparatus or used in the practice of processes,will not as a result of such and specifications provided by Customer relating to the unique needs of Customer.As such,BHI shall have no combination or use,infringe any such patent,and BFI shall not be liable and does not hold Customer harmless for responsibility for the design,manufacture or engineering of any such specialty Products,even though BHI may have damages or losses of any nature whatsoever resulting from actual or alleged patent infringement arising pursuant participated in the development and manufacture of the specialty Products,or for any Customer-furnished materials, to(i)and(i)above.THIS PARAGRAPH STATES THE ENTIRE RESPONSIBIUTY OF BHI CONCERNING information and specifications.If,upon inspection by BHI,any of the specialty Products fail to meet the PATENT INFRINGEMENT specifications agreed to in writing by Customer and BH,then BHI shall,at its option,repair or replace the non- conforming specialty Products with()the type originally furnished to Customer,or(i)substituted Products having 15.CONFIDENTIALITY BHIs"standard"spedfiwtions and qualifications. Each party shall maintain all data and information obtained from the other party in strict confidence,subject only to dsdosure required by law or legal process.In the event that BHI owns copyrights to,patents to,or has filed patent H.Discharge Services:Except to the extent that 81-11 has agreed to provide its discharge compliance engineering applications on,any[ethnology related to the Services,Products or Equipment furnished by 81i1 hereunder,and if services("Discharge Services")to Customer pursuant to this Agreement,BHI shall have no responsibility for BHI makes any improvements on such technology,then such improvements shall not fall within the confidentiality achievement of and compliance with any specific oil retention or similar requirements mandated by any applicable obligations of BHI included herein,and 81-1I shall own all such Improvements,induding drawings,specifications, local,state or federal law or regulation.If Discharge Services are rendered by BHI and agreed oil retention or similar calculations and other documents. requirements are not met then Bill shall,at its option,re-perform the Discharge Services,or provide a credit to Customer to cover any documented adratonal disposal costs incurred by Customer as a result of the nonconforming The design,construction,application and operation of BHI's Services,Equipment and Products embody proprietary Discharge Services,provided that such credit shall be limited to 3%of the amount charged for the nonconforming and confidential information.Customer shall maintain this information in strict confidence and shall not dsdose it Discharge Services. to others,subject only to disdosre required by law or legal process.To the extent permissible by law,Customer shall not reset the Products or Equipment(or drawings related thereto)to others or reverse engineer or permit BHI's warranty obligations hereunder are non-transferrable and shall not apply if the non-conformity was caused by others to reverse engineer,for the purpose of manufacturing,similar Products or Equipment. ()Customer's failure to properly store or maintain the Products or Equipment,(i)abnormal well conditions,abrasive materials,corrosion due to aggressive fluids or incorrect specifications provided by Customer,(u)unauthorized 16.t_UENS_ATTACHMENTS AND ENCUMERANcE0 alteration or repair of the Products or Equipment,(iv)the Products or Equipment are lost or damaged while on Customer grants to EHI a lien upon and a security interest in()any interest that Customer now owns or hereafter Customer's site due to Customer's or any third party's negligence,vandalism or force majeure(inducing,but not acquires in the lands,leasehold interests,pipelines,pipeline right-of-ways,personal property and fixtures arising limited to,lightning),or(0)use or handing of the Products or Equipment by Customer in a manner inconsistent with out of,pertaining to,located on,or used in connection with the development of,the mineral property on which the BHIs recommendations.Further,BHI's warranty obligations shall terminate if Customer fails to perform its Services,Products,or Equipment were performed or installed(the"Mineral Property"),(ii)the oil and gas when obligations under this or any other Agreement between the parties. extracted from the fdneral Property,inducing the proceeds thereof,(iii)the contract rights,inventory and general intangibles pertaining to the Mineral Property,and(iv)any claim against any worldng interest owner of the Mineral All non-conforming Products shall be delivered to the service facility designated by BHI.All transportation charges Property arising from nonpayment of joint interest billings or lease operating expenses.This lien and security and removal and reinstallation charges related to the repair or replacement of non-conforming Products shall be interest shall be for the purpose of securing performance of Customer's obligations to BHI under this Agreement borne by Customer.Any parts for which BH provides replacement under this warranty shall become the property of Customer authorizes Bill to have filed a financing statement and any other instruments BHI determines to BHI.With regard to materials or equipment famished by third parry vendors and/.suppliers,BHI's liability therefor be necessary or appropriate to perfect the lien and security interest created hereby.Upon request,Customer shall shall be limited to the assignment of such third party vendor's or supplier's warranty to Customer,to the extent such execute any document determined by BHI to be necessary or appropriate to perfect this lien and security interest warranties are assignable.The warranty period for any repaired or replaced Products shall be only for the remainder under all applicable laws and the real property rec.dng statutes of the state in which the Mineral Property is of the original warranty period. located.If BN is unable to obtain proper execution of such documentation within a reasonable period of time after the request is made,then Customer hereby appoints BHI as Customer's true and lawful agent and attorney-in-fact, Interpretations,research,analysis,recommendations,advice or interpretational data(spedficaly inducing,without to execute all documents on its behalf,and to otherwise take such actions on its behalf,as BHI deems necessary limitation,any preliminary cuttings reinjection program and any engineering designs,geological studies or analyses, or appropriate,to perfect the len and security interest created or contemplated hereby.This appointment is well programs,reservoir models,or drilling production optimization or management programs)("Interpretations coupled with an interest and may not be revoked for as long as any portion of Customer's obligations hereunder and/or Recommendations")famished by BHI hereunder are opinions based upon inferences from measurements, remains outstanding. The lien and security interest created hereby are in addition to,and not in lieu of,any other empirical relationships and assumptions,and industry practice,which inferences,assumptions and practices are not liens and security interests now existing or hereafter coming into existence,and securing the performance of infallible,and with respect to which professional geologists,engineers,drilling consultants,and analysts may rifler. Customer's obligations hereunder,whether voluntary or involuntary,inducing any liens arising by statute or Accordingly,BHI does not warrant the accuracy,correctness,or completeness of any such Interpretations and/or common law in favor of mechanics and/or materialmen. Recommendations,or that Customer's reliance or any third party's reliance on such Interpretations and/or Recommendations will accomplish any particular results.CUSTOMER ASSUMES FULL RESPONSIBILITY FOR Should Customer commit a breach of any of the terms and conditions of this Agreement be named as a debtor in THE USE OF SUCH INTERPRETATIONS AND.OR RECOMMENDATIONS AND FOR ALL DECISIONS BASED a bankruptcy proceeding,or become insolvent;should Customer,or any of its assets,be the subject of a THEREON(INCLUDING,WITHOUT UMITATION,DECISIONS BASED ON ANY OIL AND GAS EVALUATIONS, receivership proceeding;or should any creditor or other person or entity attach or levy Customer's property or Rev.1 January 2012 Report Printed on: OCT-17-13 04:45 Gr4175 equipment,BH shall immedatety have the right,without notice and without liability for trespass or damages,to BY FINAL AND BINDING ARBITRATION CONDUCTED IN ACCORDANCE WITH THE UNCITRAL ARBITRATION retake and remove any of its Products or Equipment wherever it may be found.CUSTOMER SHALL RELEASE, RULES(THE"RULES"). DEFEND,INDEMNIFY AND HOLD BHI INDEMNITEES HARMLESS FROM ANY AND ALL UENS AND ENCUMBRANCES AGAINST PRODUCTS OR EQUIPMENT FURNISHED HEREUNDER AND SHALL RETURN The Tribunal shall be composed of three arbitrators,with each party appointing one arbitrator,and the two arbitrators SAME PROMPTLY TO BHI FREE OF ANY UENS OR ENCUMBRANCES. so appointed appointing the third arbitrator who shall act as the presiding arbitrator of the Tribunal(the"Tribunal").The appointing authority under the Rules shall be the London Court of International Arbitration.The language of the 17.FORCE MAJEURE arbitration shall be English.The seat of arbitration shall be London,England,and the proceedngs shall be conducted If either party is unable by reason of Force Majeure to carry out any of its obligations under this Agreement,other and concluded as soon as reasonably practicable,based upon the schedule established by the Tribunal.My monetary than obligations to pay money,then on such party giving notice and particulars in writing to the other party within a award shall be made in U.S.Dollars,free of any tax or other deduction,and shall indude interest from the date of any reasonable time after the occurrence of the cause relied upon,such obligations shall be suspended."Force Majeure" breach or other violation of the Agreement to the date paid in full at a floating rate of interest equal to the prime rate of shall include any event that is beyond the reasonable control of the party so affected inducing,without limitation, interest in effect at Citibank,NA.,New York,USA.,from time to time. acts of God,laws and regulations,government action,war,civil disturbances,hijack,piracy,criminal action by a third party,threats or acts of terrorism,strikes and labor problems,delays of vendors or carriers,lightening,fire,flood, B.For Services,Equipment or Products provided,or to be provided,by BHI in the Americas:THIS AGREEMENT washout,storm,breakage or aeddent to equipment or machinery,and shortage of raw materials.In the event that SHALL BE GOVERNED BY AND INTERPRETED IN ACCORDANCE WITH THE SUBSTANTIVE LAWS OF any suspension due to Force Majeure exceeds ten(10)consecutive days,either party may terminate this Agreement OKLAHOMA,EXCLUDING CONFLICTS OF LAW AND CHOICE OF LAIN PRINCIPLES.ANY DISPUTE, by written notice to the other party,and Customer shall be liable for demobilization and any other reasonable costs CONTROVERSY OR CLAIM("DISPUTE")ARISING OUT OF OR IN CONNECTION WITH THIS AGREEMENT OR incurred by BH inddental to such termination. THE FURNISHING OF EQUIPMENT,SERVICES OR PRODUCTS HEREUNDER SHALL BE RESOLVED BY FINAL AND BINDING ARBITRATION CONDUCTED IN ACCORDANCE WITH THE COMMERCIAL RULES OF 18.INDEPENDENT CONTRACTOR ARBITRATION OF THE AMERICAN ARBITRATION ASSOCIATION(THE"RULES"),The tribunal shall be composed It is expressly understood that BHI is an independent contractor,and that neither BH nor its principals,partners, of one(1)neutral arbitrator it the Dispute Involves a maximum exposure of less than$1,000,000.If the parties are employees or subcontractors are servants,agents or employees of Customer. unable to agree on a neutral arbitrator,one will be appointed pursuant to the Rules.If the Dispute involves a maximum exposure equal to or in excess of 31,000,000,then the Tribunal shall consist of three(3)arbitrators,with each party In all cases where BHI's employees(defined to include BHI's and its subcontractors'direct,borrowed,special,or appointing one arbitrator,and the two arbitrators so appointed appointing the third arbitrator who shall act as Chair(the statutory employees)are covered by the Louisiana Workers'Compensation Act La.R.S.23:102 et seq.,BHI and "Tribunal").The seat of arbitration shall be Houston,Texas,and the proceedings shall be conducted and concluded as Customer agree that all Services,Products and Equipment provided by BHI and BHI%employees pursuant to this soon as reasonably predicable,based upon the schedule established by the Tribunal. Agreement are an integral part of and are essential to the ability of Customer to generate Customers goods, products,and services for the purpose of La.R.S.23:106(A)(1).Furthermore,BHI and Customer agree that C.For any arbitration conducted in accordance with Paragraph A.or B.above,the following shall apply:No award Customer is the statutory employer of BHI's employees for purposes of La.R.S.23:1061(A)(3). shall be made for Consequential Damages.Judgment upon the award rendered by the Tribunal pursuant hereto may be entered in,and enforced by,any court of competent jurisdiction.All statutes of limitation that would otherwise be 19.LAWS.RULES REGULATIONS.AND EXPORT CONTROL applicable shall apply to the arbitration proceeding.Any attorney-client privilege and other protection against BHI and Customer agree to be subject to all laws,rules,regulations and decrees of any governmental or regulatory disclosure of privileged or confidential information,inducing,without imitation,any protection afforded the work- body having jurisdiction over the Services,Equipment or Products to be provided by BHI or the work site or that may product of any attomey,that could otherwise be claimed by any party shall be available to,and maybe claimed by,any otherwise be applicable to BHI's or Customer's performance under this Agreement. such party in any arbitration proceeding.The parties shall treat all matters relating to the arbitration as confidential. Subject to each party's right to cooperate fully with the Urited States authorities,the parties understand and agree that Customer acknowledges that Equuipment,Services,Products and/or related technical data covered by this this confidentiality obligation extends to information concerning the fad of any request for arbitration,any ongoing Agreement may be subject to U.S.and/or foreign trade controls.Customer agrees that it will not sell,re-export or arbitration,as well as all matters discussed,discovered,or divulged,(whether voluntarily or by compulsion)during the transfer Equipment,Products and/or related technical data except in full compliance with ant governmental course of such arbitration proceeding.It is the desire of the parties that any Dispute is resolved efficiently and fairly requirements induding but not limited to economic sanctions and export controls administered by the U.S. and the Tribunal shall act in a manner consistent with these intentions Department of Treasury,U.S.Department of Commerce and U.S.Department of State.Customer agrees to comply with all BHI requests for trade compliance information,statements,and other assurances inducing,without limitation, 21.ASSIGNMENT requests for End-User and Routed Transaction certifications.Any breach of this provision shall be deemed a BHI shall have the right to assign this Agreement to any of its subsidiaries,affiliated or related companies without the material breach of this Agreement and suffiulent basis for BHI to reject any or all orders or to terminate the consent of Customer. Agreement. 22.S1FNFBAI BHI reserves the right to refuse to fulfill any order or otherwise perform under this Agreement if BHI in its sole Failure of Customer or BHI to enforce any of the terms and conditions of this Agreement shall not prevent a discretion determines that such action may violate any law or regulation.Customer agrees that such refusal, subsequent enforcement of such terms and conditions or be deemed a waiver of any subsequent breach.Should any cancellation,or termination of the Agreement by BHI will not constitute a breach of BHI's obligations under this provision of this Agreement,ora portion thereof,be unenforceable or in conflict with governing country,state, Agreement and Customer hereby waives any and all daims against BHI related to such refusal,cancellation,or province,or local laws,then the validty of the remaining provisions,and portions thereof,shall not be affected by such termination. unenforceability or conflict,and this Agreement shall be construed as if such provisions,or portion thereof,were not contained herein.This Agreement contains all representations of the partes and supersedes all pin oral or written 20.GOVERNING LAIN AND ARBITRATION agreements or representations.Customer acknowledges that it has not relied on any representations other than those A.Except for Services,Equipment or Products provided,or to be provided,by Billie North or South America(the contained in this Agreement This Agreement shall not be varied,supplemented,qualified,or interpreted by any prior "Americas"):THIS AGREEMENT SHALL BE GOVERNED BY AND INTERPRETED IN ACCORDANCE WITH course of dealing between the parties or by any usage of trade and may only be amended by an agreement executed ENGLISH LAW,EXCLUDING CONFUCTS OF LAIN AND CHOICE OF LAW PRINCIPLES.ANY DISPUTE, by both parties.In the event that any conflict exists between the provisions of this Agreement and any other terms and CONTROVERSY OR CLAIM("DISPUTE")ARISING OUT OF OR IN CONNECTION WITH THIS AGREEMENT OR conditions set forth in Customer's purchase orders,field work orders,work tickets,invoices,statements,or any other THE FURNISHING OF EQUIPIENT,SERVICES OR PRODUCTS HEREUNDER SHALL BE RESOLVED type of memoranda or other documents used by Customer in the normal course of business,whether oral or written, the provisions of this Agreement shall govern. Rev.1 January 2012 Report Printed on: OCT-17-13 04:45 Gr4175 Operator: HILCORP ENERGY CO FA Well Name: GRANITE PT ST#11-13RD BAKER Date: October 17, 2013 HUGHES Proposal No: 1001162089C PRODUCT DESCRIPTIONS BF-8L A liquid pH control agent used to adjust fracturing gels into the pH range of 8.5 to 10.5. This product was designed to retain its buffering capacity at high temperatures. CARBOBOND LITE 20/40 J523 CARBOLITE, 20/40 A man-made, low density, medium strength ceramic proppant. It has a density only slightly higher than sand while providing improved conductivity. It is used in medium closure pressure situations. Registered Trademark of Carbo Ceramics. Clay Master-5C A concentrated low molecular weight polyamine used in water, brine or acids to protect the formation against damage due to clay swelling, sloughing and migration. EnZyme G HT-III A patented, polymer specific enzyme breaker custom formulated to degrade polymer into non-damaging components. Flo-Back 30 Recovery of aqueous fracturing fluids can pose special problems, particularly in tight reservoirs with low bottomhole pressures. Flo-Back 30, a non-ionic liquid surfactant, relieves those problems by substantially increasing the fluid recovery rate for all aqueous fracturing fluids, including foamed, gelled and crosslinked systems, as well as matrix acidizing fluids. GLFC-5D A high yield guar gum gelling agent slurried in an environmenatlly friendly carrier. Used to prepare hydraulic fracturing fluid systems. High Perm CRB A controlled release breaker(C.R.B.) for use in water-base fracturing fluids. Controlled release coating allows proppant transport and then after pumping it degrades the base polymer for crosslinked and linear gel systems. XLW-32 A liquid Borate crosslinker(Boric Acid) used in gel systems. Report Printed on:October 17,2013 4:45 PM Page 8 Gr4163 Have more questions?You can find us at: http://www.bakerh ughes.com/products-and-services/pressu re-pumping Operator Name: HILCORP ENERGY CO .A' Well Name: GRANITE PT ST#11-13RD BAKER Date: October 17, 2013 HUGHES Proposal No: 1001162089C End of Report Report Printed on:October 17,2013 4 Grlast (Ou) 0 0 0 0o 0 0 N 0 0 0 N O C) O O O 1 . c.„. O O N O I� . . ..t . , 0„ . . . F— O 4 O V O M O o N M N 0 W O CO 00 6 (O u) V) 101 Z z O CO N CO a) O a0 O N CO N a) co co o0 V N W Mi 1 M O a) a) (D M (D I co O u7 M V N co .-- (c70 N V M N MV M CO ((0 (n0 MO (O I� >Q CL K W W Z CO N ZZ 13W a2 z W o 0 0 0 0 0 0 0 0 0 0 0 0 0 c 0 0 0 0 m e U 0 0 0 0 0 0 0 (f) 0 0 0 0 0 0 0 0 0 0 J 0 o Co M M M M M M M M M M M M M M M M Q Q. O Z O a) w a Qm a) 0000000000000000 000 2 V N oO (n o 0 0 0 C) 0 a) C) C) C) N a) 0 a) O O O W- W In H. 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ENnnIV uma ;mit3Eaalt ,,,,,,,, 2.g. � Schwartz, Guy L (DOA) From: Daniel Taylor <dtaylor @hilcorp.com> Sent: Friday, November 29, 2013 10:56 AM To: Schwartz,Guy L(DOA) Cc: Wallace, Chris D(DOA) Subject: RE:GP 11-13RD Frac, Sundry:313-442, PTD: 191-133 , Attachments: GP 11-13RD Proposed Frac Procedure Rev 2.pdf Guy, %�NO We tested BOP's on Wednesday 11/27 to 5,000psi and that number has been corrected on the updated procedure. We will be holding 2,500psi on the annulus and we will be testing to 2,500psi. Prior to testing the string we will run in hole with a 20kpsi PRR plug set in the RN nipple. We will be testing the string to 110%of the maximum STP of 10,300psi (._. ,,:,60psi)with an Atigun 15kpsi water pump. Please see the updated procedure and diagram. Thank you sir. Re'' ds. Da.: .,aylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 SCANNED , From: Schwartz, Guy L(DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, November 29, 2013 9:57 AM To: Daniel Taylor Cc: Wallace, Chris D (DOA) Subject: RE: GP 11-13RD Frac, Sundry: 313-442, PTD: 191-133 Dan, 1)In step 1 the BOP should be tested to 5000 psi. 2)What pressure are you holding on the IA during the frac? If 2500psi the test in step 5 should be 2500 also. 3)How are you going to test the frac string to 110% ? I assume you will set a plug in a nipple in the 3 .5" tubing? ( The frac program calls for 10300 psi max surface pressure but in step 6 you only test string to 8722 psi??) 4) please provide a schematic of the surface hookup to BJ pumps showing safety valve position and x-over to drillpipe etc. They must also be rated to the max anticipated treating pressure. Guy Schwartz Senior Petroleum Engineer AOGCC 90T301-4533 cell 907-793-1226 office From: Daniel Taylor [mailto:dtavorahilcorp.com] Sent: Friday, November 29, 2013 8:58 AM 1 To: Schwartz, Guy L(DOA) Cc: Wallace, Chris D (DOA) Subject: RE: GP 11-13RD Frac, Sundry: 313-442, PTD: 191-133 Guy, Please see the attached revised frac procedure and calculations for GP 11-13RD. I will make myself available today for any questions you might have. Thank you. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Wallace, Chris D (DOA) [mailto:chris.wallacer8alaskagov] Sent: Monday, November 25, 2013 11:39 AM To: Daniel Taylor Cc: Reid Edwards; Schwartz, Guy L(DOA) Subject: FW: GP 11-13RD Frac, Sundry: 313-442, PTD: 191-133 Dan, With the new information below and the old sundry approval in hand, please update the procedure and schematics to incorporate proposed changes for our review. Please confirm burst rating for each component in the workstring and well at time of fracture including the 5 inch drill pipe grade and pressure rating. We have the 3.5" P110 burst as 13,970 psi. 7 inch casing 32# P110 buttress burst as 11,640 psi. Please confirm if the expandable liner is in the well and if so what burst rating it has. Please confirm 110% calc as per item 13, and settings for 15 d. and e. and if back pressure will be held on the IA? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907) 793-1250(phone) (907) 276-7542(fax) chi ris.wallaceL alaska.gov From: Schwartz, Guy L(DOA) Sent: Monday, November 25, 2013 10:05 AM To: Wallace, Chris D (DOA) Subject: Fwd: GP 11-13RD Frac, Sundry: 313-442, PTD: 191-133 Can u look at this? Sent from my iPhone 2 Begin forwarded message: From: Daniel Taylor<dtaylor @hilcorp.com> Date: November 25, 2013 at 9:32:46 AM AKST To: "guy.schwartz@alaska.Rov"<guy.schwartz(cDalaska.gov> Subject:GP 11-13RD Frac,Sundry:313-442,PTD: 191-133 Guy, We made an attempt to hydraulically fracture the Hemlock in GP 11-13RD this weekend. The anticipated surface treating pressure as stated in the Sundry was +/-7,190psi. We pressure tested the iron to 11,000psi against the wheel valve above the 10kpsi TIW. During the frac we reached a surface treating pressure of 9,350psi at 10bpm with no definitive break over. No sand was pumped. Because no closure pressure was observed we will need to treat at higher pressures. As stated above the max pressure on the pumps is 11,000psi. We will switch out the 10kpsi TIW with a 15kpsi TIW. We will reduce the friction pressure in the pipe running 5in 19.5ppf(ID=4.276in)to +/-9,000ft where we will cross back over to the 3.5in P110 (ID=2.992). We are investigating the possible use of a delayed cross linker that may offer further reduction in friction. These changes are an effort to ensure we are successful on this fracture. We feel that this frac is key to the development of the Hemlock formation in the Granite Point Field. What will you need from us in order apply these changes sir? Thank you and please call me with any questions that you might have. Reid Edwards and I will make ourselves available to discuss. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 3 ' %~ kb A " 12 Granite Point Platform II Well#: GP 11-43RD Frac Procedure Fracture String k "1 a ka.I IA N PTD: 191 133 ��, �,W do � API: 50-733-20026-01 /I.Z.-7 .r3 Procedure: 1. Pressure Test BOP. a. 250 psi low/5,000 psi high(Notify AOGCC 24 hrs. before pending BOPE test). 2. Remove back pressure valve. 3. Double check all rams and valves for correct operating position. 4. Pick up and run in hole with retrievable 9,000psi isolation packer and frac string. a. Set packer at+/- 10,900ft b. Stager frac string i. 0 to 9,000ft 5" 19.5Ib/ft S-135 ii. 9,000ft to 10,900ft 3.5" 12.95Ib/ft P110 5. Pressure test packer to 2,500psi and chart 30min. 6. Pressure test work string: a. Rig up slick line and run in hole with 20kpsi PRR test plug and set inside of RN nipple. b. Pull out of hole and rig down slick line. c. Pressure test work string to 11,350psi(110%of STP) and chart. 7. Install 15,000 psi TIW safety valve. 8. Prepare rig and platform for fracture treatment. a. Hold pre job safety stand down to identify all hazards b. Review attached MSDS sheets c. Shut in BOP d. Rig up fracture treatment equipment. i. Rig up pressure relief valve(s)on treating line s)between pumps and wellhead. e. Install surface casing pressure gauge and pressure reef valve. f. See the attached calculations based on the anticipated maximum surface treating pressure of 10,300psi. 9. Begin fracture treatment as per Baker Hughes Hydraulic Fracturi g procedures. a. Monitor and record all annular pressures 10. Upon shutting off fracturing pumps allow well to bleed down through choke manifold. 11. Flow back well to 100bbl upright tank on deck. a. Ensure fluid has broken before routing to production. 12. In the event well continues to flow(BHP=5,300psi)bullhead weighted fluid to perforations. a. Ensure well is dead. 13. Pull out of hole with retrievable isolation packer and lay down the same. 14. Pick up and make up production string, seal assembly,anchor latch, gas lift mandrels, SCSSV, and capillary string. a. Run in hole spacing out 15. Land new hangar. a. Pressure test to verify seals 1,500psi for 10min. 16. Set back pressure valve. 17. Nipple down BOP and install tree. 18. Remove back pressure valve. 19. Turn well over to platform production. 20. Prior to the submission of Form 10-404 submit information required by the Interstate Oil and Gas Compact Commission/Groundwater Protection Council hydraulic fracturing web site(www.fracfocus.org). Granite Point Platform Well#: GP 11-13RD Frac Procedure Fracture String PTD: 191-133 API: 50-733-20026-01 Casing Size WT Grade Collapse Internal Min Body Wall Con. ID Drift Cement Top(MD,ft) BTM (in) (Ibs/ft) (psi) Yield Yield Thickness (in) (in) Top (MD,ft) (psi) (1000Ibs) (in) (MD) 18 - - - - - - - - - - 41 684 133/8 61.0 J-55 1,540 3,090 962 0.430 - 12.52 12.36 - 41 4,018 95/8 47.0 N-80 4,750 6,870 1,086 0.472 - 8.68 8.53 - 41 6,773 9 5/8 53.5 P-110 7,950 10,900 1,710 0.545 BUTT 8.54 8.38 7,100 6,773 10,060 7 32.0 P-110 10,780 12,460 1,025 0.453 BUTT 6.09 5.97 9,787 9,787 11,560 5.919 17.5 EX-80 3,800 7,160_ 416 0.294 GII 5.33 5.27_ - _ 10,978 11,451 Parameters Annulus Fluid Density= 10 ppg Parameter 5" 3.5" Total Tubular Max Treating Density= 11.04 ppg* Friction f 0.044599303 0.0312043 Pressure Drop Applied Anular Pressure= 2,500 Flow Rate 7.00 7.00 from Friction Max Treating Pressure= 10,300 SG 1.32 1.32 (psi) AP 433 381 814 Treating Fluid Densities 3%KCL- Stage 1 PPA 2 PPA 3 PPA 4 PPA 5 PPA 8.48 lb/gal Fluid Density 9.08 9.63 10.13 10.6 11.04 Maximum Differential **reference points located on below diagram Maximum Differential Pressure at Depth(psi) Below Formation Premium Premium Premium Item Depth(TVD) String Annulus Friction AP Packer (0.479psi/ft) AP Tubing % X 90% % X 85% % Surface - - - - - - - 15,638 66% 14,074 73% 13,292 77% A Surface 10,300 2,500 - 7,800 - - - 15,638 50% 14,074 55% 13,292 59% B 8,913 15,417 7,135 433 7,849 - - - 15,638 50% 14,074 56% 13,292 59% C 10,779 16,488 8,105 814 7,568 - - - 21,429 35% 19,286 39% 18,215 42% D 10,968 - - 814 - 15,782 5,254 10,528 12,460 84% 11,214 94% 10,591 99% Maximum Differential Pressure across packer set at(TVD): 10,779 ft Below Above Friction AP Pkr 100% % 15,674 psi 8,105 psi 814 psi 6,754 psi 9,000 psi 75% Summary: The viscosity of the cross-linked fluid for the above calculations was 200cp. The total loss in pressure due to friction in the string was 8l4psi. Maximum surface treating pressure is 10,300psi. The assumption was made that we have 85%of premium Tin 321b P110 tubing which brings us to 99%of its burst rating. This model only takes into account the confining stress on the casing provided by a 0.435psi/ft gradient. The combination of cement behind pipe and the formation provides additional support. Granite Point Platform Well#: GP 11-13RD Frac Procedure Fracture String PTD: 191-133 Hilrora Alaska,IAA API: 50-733-20026-01 Fracture String A L L 3-3:a B 2 \ / 9.619' 3 C 4 RN 5 PG Expandable Liner D l 7. G .� Granite Point Platform Well#: GP 11-13RD Frac Procedure Fracture String PTD: 191-133 Ililcorp 11n.ko.IA A. API: 50-733-20026-01 Surface Hookup 3in 1502 15,000psi Wheel Valve ■ XO 3in 1502 Box X 3.5in PH6 Pin LI 15,000psi TIW Valve 0 XO 3.5in PH6 Box X 4.5in IF Pin OF 7 w,* \\I%% s� THE STATE Alaska • il and aS �� ►�-�'� ®f onservati n Commission GOVERNOR SEAN PARNELL *,,, 333 West Seventh Avenue pF�,,,,,,,;;:' Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Dan Taylor Operations Engineer c �� Hilcorp Alaska, LLC swot) 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 111130 Re: Granite Point Field, Hemlock Undefined Oil Pool, Granite Pt St 11-13RD Sundry Number: 313-442 CAS Dear Mr. Taylor: 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 thisZa day of August, 2013. Encl. III *Ilk , 4 z8 fi L° $t� AUG 1 3 2.0 1' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOG C 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ /� (Perforate p ` Pull Tubing 15 ' Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ sC f't uiate ��".�'3Alter Casing❑ Other Fracture/Run New Completion El • 2.Operator Name: 4.Current ell Class: 5.Permit to D911 Number. Hilcorp Alaska,LLC Exploratory ❑ Development El 191-133 ✓ 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20026-01 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 Will planned perforations require a spacing exception? Yes ❑ No GI - Granite Pt St 11-13RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018761 • Granite Pt/Hemlock Undefined Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11,560 • 11,407 • 11,510 11,359 11,510'(Cement Retainer) 11,123' Casing Length Size MD ND Burst Collapse Structural Conductor 684' 18" 684' 683' Surface 3,993' 13-3/8" 4,018' 3,993' 3,090 psi 1,540 psi Intermediate 6,710' 9-5/8" 6,773' 6,710' 6,870 psi 4,750 psi Production 3,287' 9-5/8" 10,060' 9,960' 10,900 psi 7,950 psi Liner 1,773' 7" 11,560' 11,407' 12,460 psi 10,780 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic See Schematic 2-7/8" 6.5#/L-80 10,935' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Otis"BIND"Permanent Packer/Camco TRSV SSSV Packer 10,926'(MD)10,803'(ND)/SSSV 311'(MD)311'(TVD) 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Stratigraphic❑ Development El • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 8/20/2013 Commencing Operations: Oil El " Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG El Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Taylor Email dtaylor @hilcorp.com Printed Name Dan Ta • ��/"� Title Operations Engineer Si.nature_--- Phone 907777-8419 Date 8/132013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 513- yea Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ \� Other: Soon J.._ ADP e,S1- RBDMS OCT 1 0 2013.- Spacing Exception Required? Yes ❑ No L/ Subsequent Form Required: t 0—'I c'-' > Fr,C FOC (J S f v6A� (� SS/� APPROVED BY ( 2 al f Approved by: COMMISSIONER THE COMMISSION Date: J J dZies G1)14 8/1`12013 e'!g•13 , � Submit Form and Form 10-403(Revised 10/2012) Approve h iokij ja 44 r IO 1ths fr m the date of approval. achments in Duplicate .,,Sc,___ S Well Prognosis Well: GP 11-13RD Hilcorp Alaska,LL Date:8/13/2013 �� S'O-733o.z -o\ GD�J Well Name: GP 11-13RD API Number: 50-733- - 1 Current Status: Producer Leg: 3 Estimated Start Date: August 20, 2013 Rig: Gran. Point Platform Reg.Approval Req'd? 10-403 _ Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 207- I`11133© First Call Engineer: Dan Taylor (907) 777-8319 (0) 907) 947-8051 (M) C,py�J Second Call Engineer: Reid Edwards (907) 777-8421 (0) AFE Number: 1322353 Current Bottom Hole 5,300 psi @ 11,067ft TVD/ 11,203ft MD 0.47 psi/ft at mid-perf, PBT 2009 Pressure: Maximum Expected BHP: 5,300 psi @ 11,067ft TVD/ 11,203ft MD 0.47 psi/ft at mid-pert, PBT 2009 Max. Allowable Surface 0 psi using 0.479psi/ft pressure Pressure: — gradient, -9.2ppg Brief Well Summary GP-11-13RD was drilled and completed in March 1992 as a gas lift producer in the Hemlock reservoir. The well initially came on production at 1,500 bopd and at a tubing pressure of 1,500 psi with no artificial lift. Production has declined steadily to its current rate of 30 bopd at a 50%watercut and a reservoir pressure of 5,300 psi. • S L; , The well has recently been worked over and a temporary kill string placed in hole. Perforations will be made at the bottom section of the Hemlock Sand and the well will be hydraulically fractured. A gas lift completion will be run in line with a SCSSSV and the well placed back on production. Fracture Parameters The following information is provided in response to the proposed AOGCC regulations on hydraulic fracturing. This Sundry tracks the AOGCC's statues and regulations found in Chapter 5 of Title 31 of the Alaska Statues and Title 20, Chapter 25 of Alaska's Administrative Code. Granite Point Platform is located within the Granite Point Field and currently has a full aquifer exemption. Section a) 6. Detailed casing and cementing information; • Top of Cement for 9 5/8in and 7in casing was determined by Schlumberger Cement evaluation Log dated 3-Mar-1992 (See Attachment) • 13 3/8in casing cemented Jul 1967 with 660 sacks of Class "G" cement and tested casing to 2,000psi. • 18in casing cemented Jul 1967 with total of 1,000 sacks of Class "G" cement and tested casing to 500psi. Table 1.Summary of Casing Parameters Size WT Grade Colapse Menial Ivin Body WaN" Con. N) Drift Atement Top BTI ', (in) (bit) (psi) Yidi Yield Thickness (in) (n). Top p ( ,fl) (MD,ft) (psi) (1000#s) (n) .A14)) 18 - - - - - - - - - - 41 684 13 3/8 61.0 J-55 1,540 3,090 962 0.430 - 12.52 12.36 - 41 4,018 95/8 47.0 N-80 4,750 6,870 1,086 0.472 - 8.68 8.53 - 41 6,773 95/8 53.5 P-110 7,950 10,900 1,710 0.545 BUTT 8.54 8.38 7,100 6,773 10,060 7 32.0 P-110 10,780 12,460 1,025 0.453 BUTT 6.09 5.97 9,787 9,787 11,560 Well Prognosis Well: GP 11-13RD Hhlcorp Alaska,LL Date: 8/13/2013 Section a) 7. An assessment of each casing and cementing operation performed to construct or repair the well with sufficient supporting information, including cement evaluation logs and other evaluation logs approved by the commission, to demonstrate that casing is cemented below the base of the lowermost freshwater aquifer and according to 20 AAC 25.030 and that all hydrocarbon zones penetrated by the well are isolated; • See Table 1 for summary of casing parameters and cement tops. • No freshwater aquifers are present Section a) 8. Pressure test information if available and plans to pressure test the casings and tubing installed in the well; • 7in casing cemented Feb 1992 and tested liner lap to 1,500psi, tested good. • 9 5/8in casing cemented Feb 1992 and tested to 3,000psi for 30min, tested good. • See Table 1 for casing pressures over last 4 months • Fracture treatment will take place through fracture string and into 5.5in expandable liner (Post expansion Drift = 5.271 in) set over the interval +/-11,015ft to +/-11,390ft MD. RTTS test packer will be set within expandable liner and tested down work string 2,000psi for 30min and on back side 2,000psi for 30min and charted. •9 5/8 in 2000 •13 3/8 in •20 in •r no y a N N 200 - 20 T_ 1-Apr 21-Apr 11-May 31-May 20-Jun 10-Jul 30-Jul Date(2013') Figure 1 Recorded casing pressures Apr 1,2013 to Jul 28,2013. Section a) 9 Accurate pressure ratings and schematics for the wellbore, wellhead, BOPE, and treating head; • See Table 1 for accurate pressure ratings of casing • The wellhead is a Unihead, OCT type 2, 13 5/8in rated to 5,000psi • The BOP is a Hydril 13 5/8in rated and tested to 5,000psi Section a) 10 Data for the fracturing zone and confining zones including lithologic description, geological name, measured depth (MD) and true vertical depth (TVD), measured and true vertical thickness, and estimated fracture pressures for the fracturing zone and confining zones; Well Prognosis Well: GP 11-13RD Hilcorp Alaska,Lb Date:8/13/2013 Table 2.Geologic data summary Geologic name of objective Oligocene Hemlock Sand Poorly sorted,pebble to cobble Lithologic Description conglomeratic,fine to medium grained, sandstone Measured Depth 11,035ftto 11,376ft True Vertical Depth 10,907ft to 11,231 ft Target Sand Thickness—MD 341 ft Target Sand Thickness—TVD 324ft Estimated Fracture Pressures for Fracture Zone 0.85 psi/ft Estimated Fracture Pressures for Confining Zone 0.85 psi/ft—No data available Section a) 11 The geologic name and depth (MD and TVD) to the bottom of all freshwater aquifers within the one- mile radius of the proposed wellbore trajectory; • Within a one mile radius of the proposed wellbore trajectory there are no fresh water aquifers. Section a) 12 The location, orientation, and a report on the mechanical condition of each well that may transect the confining zones and information sufficient to support a determination that such wells will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory; Table 3.Surroundin•well information. NDE*indicates that the well did not penetrate Hemlock sands. WELL PTD Location Description Mechanical Condition AN-5 167-014 1992'N of 11-13RD Actice producer in Nid Tyonek Group, NDE* N/A MUC-I-3 178-019 1269'NE of 11-13RD Active waste water in injector, NDE* N/A GP-11-13 167-033 447'N of 11-13RD P&A No known AnnCom Issues GP-11-13 167-033 488'Nof 11-13RD P&A N/A GP-31-13 166-055 1759'E of 11-13RD Actice producer in Md Tyonek Group, NDE* No known AnnCom Issues GP-22-13 168-021 844'SE of 11-13RD P&A N/A GP-32-13 172-021 2181'SE of 11-13RD P&A No known AnnCom Issues GP-33-13 167-018 2250'SE of 11-13RD P&A N/A GP-52 196-045 1219'S of 11-13RD Batch drilled to conductor pipe; NDE No known AnnCom Issues GP-50 192-041 2030'S-SW of 11-13RD Current Hemlock Producer N/A GP-13-13 167-021 2062'S-SW of 11-13RD Actice producer in IVid Tyonek Group, NDE* No known AnnCom Issues GP-31-14RD1 - 1092'W of 11-13RD P&A N/A GP-31-14RD2 100-266 1443'W of 11-13RD Actice producer in NM Tyonek Group, NDE" No known AnnCom Issues GP-31-14 166-056 2629'S-SE of 11-13RD P&A N/A Section a) 13 The location, orientation, and geological data of known or suspected faults and fractures that may transect the confining zones, and information sufficient to support a determination that any such faults and fractures will not interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory; • Two faults have been mapped in the area, although no corresponding fault cuts can be clearly identified to confirm their presence. Proposed Fault 1 is located 1,186ft from the target fracture sands and Fault 2 is located 805ft from the target fracture sands. Neither of these faults (if present) display any significant vertical (greater than 30ft to 50ft) or lateral displacement and are not considered sealing faults. Both faults appear to die out laterally within the field and vertically within the +/-1,500ft Middle Tyonek Group section. Hemlock sands across the field have a similar pressure profile. We do not believe these faults (if present) will intersect the I Well Prognosis Well: GP 11-13RD Hilcorp Alaska,LL, Date:8/13/2013 proposed fracture based on their proximities to one another. If the fracture did intercept a fault it would not be expected to transmit fluids into any overlying aquifers as the fault appears to die out in within, or slightly above, the target section. Section a) 14 A detailed copy of the proposed hydraulic fracturing program including, but not limited to, the pumping procedure by stage where applicable, with a chemical disclosure based on the total amounts and volumes per well including; (Please see the attached fracturing program and MSDS sheets) Section a) 14 a) The estimated total volumes planned; Component Total Frac Fluid 58,810 gal Flush 4,379 gal Proppant(Carbolite,20/40) 38,628 lbs Proppant(Carbobond Lite 20/40) 19,202 lbs Section a) 14 b) The trade name, generic name, and purpose of all base fluid(s) and additives to be used. The estimated or maximum rate or concentration of each additive shall be provided in appropriate measurement units; Frac Fluid:Lightning 3000 Flush:Linear Gel Trade Name Generic Name/Purpose Concentration Trade Name Generic Name/Purpose Concentration GLFC—5D Gelling Agent 7.5 gpt GLFC—5D Gelling Agent 7.5 gpt High Perm CRB-LT Gel Breaker 4.0 ppt High Perm CRB-LT Gel Breaker 4.0 ppt BF—8L Buffers/pH Control Product 1.5 gpt BC—3 Gel Breaker 1.0 gpt BC—3 Gel Breaker 1.0 gpt Clay Master—5C Clay Stabilization Product 1.0 gpt Clay Master—5C Clay Stabilization Product 1.0 gpt Enzyme G—I Gel Breaker 1.0 gpt Enzyme G-1 Gel Breaker 1.0 gpt Flo—Back 30 Surface Tension Reducer 1.0 gpt Flo-Back 30 Surface Tension Reducer 1.0 gpt X—CIDE 207 StimPlus Products 0.4 ppt XLW—32 Crosslinker 0.7 gpt X—CIDE 207 StimPlus Products 0.4 ppt Section a) 14 c) The chemical ingredient name and the Chemical Abstracts Service (CAS) Registry number, as published by the Chemical Abstracts Service (a division of the American Chemical Society, see www.cas.org), for each base fluid and each additive used. The actual or maximum concentration of each chemical ingredient in each base fluid and additive used shall be provided in percent by mass. In addition, the actual or maximum concentration of each chemical ingredient in the hydraulic fracturing fluid shall be provided in percent by mass. Freeze-protect fluids pumped before and/or after hydraulic fracturing should not be included; • Please see attached MSDS sheets Section a) 14 d) The estimated weight or volume of inert substances, including proppants and other substances injected; Component Total CARBOLITE,20/40 38,628 lbs CARBOBOND LITE,20/40 19,202 lbs 1E4 • • Well Prognosis Well: GP 11-13RD Hilcorp Alaska,LL Date:8/13/2013 Section a) 14 e) The maximum anticipated treating pressure and information sufficient to support a determination that the well is appropriately constructed for the proposed hydraulic fracturing program; Parameter Limitation Max.Anticipated Treating Pressure +/-7,190 psi ® kb- Retrievable Packer(Set Depth=10,050 ft) 10,000 psi Pressure on Back Side +/-2,000 psi Differential Across Packer +/-5,200 psi • Max.Anticipated BH Pressure(10ppg slurry) +/-12,962 psi Overburden Pressure to Surface(8.3ppg) +/-4,790 psi Differential Across 7 in CSG +/-8,171 psi BOP/Choke 5,000 psi Section a) 14 f) The designed height and length of the proposed fracture(s), including the calculated MD and TVD of the top of the fracture(s) accompanied by a description of the methods and assumptions used to determine designed fracture height and length; Zone Height(ft) 1/2 Length(ft) MD(ft) TVD;(ft) Oligocene Hemlock 210 320 10,810 10,690 Sand • Assumptions and calculations summarized in Model (See Attachment) • Stim-Plan software program Section a) 15 A detailed description of the plan for post fracture wellbore cleanup and fluid recovery through to production operations. • All frac pumps will be shut off and tubing pressure monitored. When pressure has become stable below (+/-5,000 psi) initial flow-back will be routed through the frac manifold to the choke. • Fluids will be routed to 400bbl upright tanks on deck where samples will be taken and tested. Once fluid has cleaned up it will be routed to the produced water beam tank where oil will be skimmed and produced water will be disposed of. Section b) When hydraulic fracturing through production casing or through intermediate casing, the casing must be tested to 110% of the maximum anticipated pressure differential to which the casing may be subjected. If the casing fails the pressure test it must be repaired or the operator must use a temporary casing string (fracturing string). • We will be hydraulic fracturing through a fracture string Section c) When hydraulic fracturing through a fracturing string, the fracturing string must be stung into a liner or run on a packer set not less than 100 ft MD below the cement top of the production or intermediate casing and tested to not less than 110% of the maximum anticipated pressure differential to which the fracturing string may be subjected. • Fracture string will be run on a packer set within an expandable liner at+/-1,263ft below TOC of 7in liner and will be tested to 110% of the maximum anticipated differential pressure. • Well Prognosis Well: GP 11-13RD Hilcorp Alaska,LL Date:8/13/2013 Section d) A pressure relief valve(s) must be installed on the treating lines between pumps and wellhead to limit the line pressure to the test pressure determined in (a)14 (E) of this section; the well must be equipped with a remotely controlled shut-in device unless the operator requests and obtains a waiver from the commission. • Pressure relief valves will be placed on the treating lines between pumps and wellhead to limit the line pressure to +/-7,190psi (maximum anticipated treating pressure) • The stimulation setup will be evaluated for the implementation of a remotely controlled shut-in device and in in the event that a waiver should be necessary one will be requested from the commission. Section e) The placement of all hydraulic fracturing fluids shall be confined to the approved formations during hydraulic fracturing. • Only approved formations will receive fracturing fluids Section f) If the surface casing annulus is not open to atmospheric pressure, then the surface casing pressures shall be monitored with a gauge and pressure relief device while hydraulic fracturing operations are in progress; the annular space between the fracturing string and the intermediate or production casing must be continuously monitored; the pressure in such annular space may not exceed the pressure rating of the lowest rated component that would be exposed to pressure should the fracturing string fail. • The annular space will be continuously monitored throughout the length of the frac. Procedure: 1. Skid Rig over well center. 2. Load pits with filtered inlet water. 3. Set back pressure valve. /tfi° 4. Nipple down tree and nipple up BOP. a. Pressure test BOP to 250 psi low/ 1 psi high (Notify AOGCC 24 hrs. before pending BOPE test). Sao 5. Remove back pressure valve. 6. Double check all rams and valves for correct operating position. 7. Release tubing hangar and lay down.K i U Sin 8. Rig up a-line, pressure control equipment, and perforating guns. 9. Run in tT T with guns and perforate interval +/-11,348ft to +/-11,358ft MD. 10. Pull out of hole with perforating guns and lay down the same. did 31/ 11. Pick up and run in hole with retrievable 10,000psi isolation packer. a. Set packer at+/- 11,050ft 12. Pressure test packer to 2,000psi and chart 30min. 78ao s• 13. Pressure test work string to 110% of maximum anticipated pressure differential. 7/88/'sz, 1( l.1 = P 14. Install 10,000 psi TIW safety valve. I— Bo Copsz, 15. Prepare rig and platform for fracture treatment. S1ot(sl X I•/ = S"72or, a. Hold pre-job safety stand down to identify all hazards b. Review attached MSDS sheets c. Shut in BOP d. Rig up fracture treatment equipment. i. Rig up pressure relief valve(s) on treating line(s) between ppurflpp„and wellhead. III e. Install surface casing pressure gauge and pressure relief valve. FH b1� 16. Begin fracture treatment as per Baker Hughes Hydraulic Fracturing procedures. • • Well Prognosis Well: GP 11-13RD Hilcarp Alaska,LL Date:8/13/2013 a. Monitor and record all annular pressures 17. Upon shutting off fracturing pumps allow well to bleed down through choke manifold. 18. Flow back well to 400bbl upright tank on deck. a. Ensure fluid has broken before routing to production. 19. In the event well continues to flow(BHP = 5,300psi) bullhead weighted fluid to perforations. a. Ensure well is dead. 20. Pull out of hole with retrievable isolation packer and lay down the same. 21. Pick up and make up production string, seal assembly, anchor latch, gas lift mandrels, SCSSV, and capillary string. a. Run in hole spacing out 22. Land new hangar. a. Pressure test to verify seals 1,500psi for 10min. � p�G� �� 23. Set back pressure valve. s 24. Nipple down BOP and install tree. 25. Remove back pressure valve. 26. Turn well over to platform production. 27. Prior to the submission of Form 10-404 submit information required by the Interstate Oil and Gas Compact Commission/Groundwater Protection Council hydraulic fracturing web site (www.fra cfo c u s.o rg). Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Schematic 4. Additives—MSDS 5. Frac Model HUNKS Proposal No: 1001162089B HILCORP ENERGY CO GRANITE PT ST#11-13RD API# 50-733-20026-0000 GRANITE POINT Field Kenai Offshore County,Alaska July 24, 2013 Fracturing Proposal Prepared for: Prepared by: Reid Edwards Joshua Herald Operations Engineer Technical Support Engineer Hilcorp Alaska LLC Bus Phone: 907-776-4084 Bus Phone: 907-777-8421 Email: Joshua.Herald@bakerhughes.com Email: reedwards @hilcorp.corn Mobile: 907-398-8303 Mobile: 907-250-5081 Service Point: Service Representatives: BJS, KENAI Rod Edwards Bus Phone: 907-776-4084 Account Manager Bus Phone: 907-267-3487 Fax: 907-776-4087 Mobile: 907-229-6536 Powered by PowerVision Gr4105 • • Operator Name: HILCORP ENERGY CO E., Well Name: GRANITE PT ST#11-13RD BAKER Job Description: Lightning 3000 MGM Date: July 24, 2013 Proposal No: 1001162089B JOB AT A GLANCE Surface Treating Pressure(max) 7,190 psi Total Rate(max) 18.00 bpm Estimated Pump Time(HH:MM) 01:20 Frac Fluid 53,810 gals Lightning 3000 C'74, KC k Flush 4,379 gals Linear gel Proppants 38,628 lb CARBOLITE, 20/40 19,202 lb CARBOBOND LITE 20/40 Report Printed on: July 24,2013 6:17 PM Gr4111 Page 1 Have more questions? You can find us at: http://www.bakerhughes.com/products-and-services/pressure-pumping S Operator Name: HILCORP ENERGY CO Well Name: GRANITE PT ST#11-13RD BAKER Job Description: Lightning 3000 HUGHES Date: July 24, 2013 Proposal No: 1001162089B WELL DATA RESERVOIR DATA Formation Hemlock Depth to Middle Perforation 11,354 ft Reservoir Pressure 5,300 psi Fracture Gradient 0.85 psi/ft Bottom Hole Fracture Pressure 9,651 psi Bottom Hole Static Temperature 190 ° F PERFORATED INTERVAL DEPTH(ft) Shots per Foot Pert Diameter Total Perfs MEASURED TRUE VERTICAL (in) 11,349- 11,359 11,349- 11,359 I 6 0.75 I 102 Total Number of Perforations 102 Total Feet Perforated 10 ft TUBULAR GEOMETRY Top Bottom Tubing 3 1/2"O.D. (2.922" .I.D) 10.3#P-110 0 11,000 Casing 7"O.D. (6.094" .I.D) 32# 0 11,510 End of Tubing 11,000ft Pump Via Tubing Report Printed on July 24,2013 6:17 PM Page 2 Gr4119 Have more questions? You can find us at: http:llwww.bakerh ug hes.com/prod ucts-a nd-services/pressure-pumping • Operator Name: HILCORP ENERGY CO �/.. Well Name: GRANITE PT ST#11-13RD BAKER Job Description: Lightning 3000 HUNKS Date: July 24, 2013 Proposal No: 1001162089B FLUID SPECIFICATIONS Frac Fluid: Lightning 3000 Pumped Liquid 53,810 Gallons Mixed Liquid Volume: 56,400 Gallons Components: 7.5 gpt GLFC-5D Gelling Agent 4 ppt High Perm CRB-LT Gel Breaker 1.5 gpt BF-8L Buffers/pH Control Product 1 gpt BC-3 Gel Breaker 1 gpt Clay Master-5C Clay Stabilization Product 1 gpt Enzyme G-I Gel Breaker 1 gpt Flo-Back 30 Surface Tension Reducer 0.7 gpt XLW-32 Crosslinker 0.4 ppt X-CIDE 207 StimPlus Products Flush: Linear gel 4,379 Gallons Components: 7.5 gpt GLFC-5D Gelling Agent 4 ppt High Perm CRB-LT Gel Breaker 1 gpt BC-3 Gel Breaker 1 gpt Clay Master-5C Clay Stabilization Product 1 gpt Enzyme G-I Gel Breaker 1 gpt Flo-Back 30 Surface Tension Reducer 0.4 ppt X-CIDE 207 StimPlus Products Proppants 38,628 lb 100% CARBOLITE, 20/40 19,202 lb 100% CARBOBOND LITE 20/40 Additive volumes may change based on actual well conditions pending laboratory testing. Base fluid is estimated at 6% KCL. Report Printed on: July 24,2013 6:17 PM Page 3 Gr4127 Have more questions? You can find us at: http://www.bakerhug hes.com/productsand-services/pressure-pumping • • Operator Name: HILCORP ENERGY CO EMI Well Name: GRANITE PT ST#11-13RD BAKER Job Description: Lightning 3000 HUGHES Date: July 24, 2013 Proposal No: 1001162089B FRACTURE TREATMENT SCHEDULE INPUT PARAMETERS - )3p6a e' TVD Depth (Mid Perforation) 11,354 ft 6P`'"4 p,!0 MD Depth (Mid Perforation) 11,354 ft 13 Perforations Number 102 Perforation Diameter 0.750 in Bottom Hole Frac Pressure 9,651 psi Bottom Hole Static Temperature 190 ° F r - Top Bottom Tubing 3 1/2"O.D. (2.922" I.D.) 10.3 P-110 0 11,000 Casing 7"O:D. (6.094" I.D.) 32# P//0 ffj8J 11,510 ° 417* P/Ib/N.r4 o /u/ d{u CALCULATED RATES, PRESSURES &HHP REQUIREMENTS Maximum Minimum Average Surface Treating Pressure (psi) 7,190 5,344 6,801 Slurry Rate(bpm) 18.0 18.0 18.0 Proppant Rate (Ibs/min) 4,002 724 3,009 Slurry Hydraulic Horsepower 3,173 2,358 3,001 PROCEDURE Fluid Proppant Type Volume Conc. Type Stage Cum Stage (gal) (ppa) (Ibs) (Ibs) 1 Lightning 3000 6000 Mini Frac 2 Lightning 3000 35870 Pad 3 Lightning 3000 480 1.000100%CARBOLITE,20/40 480 480 4 Lightning 3000 690 2.000100%CARBOLITE, 20/40 1380 1860 5 Lightning 3000 1300 3.0001100%CARBOLITE, 20/40 3900 5760 6 Lightning 3000 1960 4.0001100%CARB0LITE, 20/40 7840 13600 7 Lightning 3000 2590 5.0001100%CARB0LITE,20/40 12950 26550 8 Lightning 3000 2013 6.000100%CARBOLITE, 20/40 12078 38628 9 Lightning 3000 1147 6.000 100%CARBOBOND LITE 6882 45510 10 Lightning 3000 1760 7.0001100%CARBOBOND LITE 12320 57830 11 Linear gel 4379 1 Flush 57830 Total 58189 57830 Report Printed on July 24,2013 6:17 PM Page 4 Gr4141 Have more questions? You can find us at: http://www.bakerhug hes.com/productsand-services/pressure-pumping III • r Operator Name: HILCORP ENERGY CO 1 1 Well Name: GRANITE PT ST#11-13RD BAK Job Description: Lightning 3000 HUGHES Date: July 24, 2013 Proposal No: 1001162089B FRACTURE TREATMENT SCHEDULE TREATMENT SCHEDULE Surface Rates Volume Stage Treating Slurry Clean Prop. Rate Slurry Fluid Pump Pressure (bpm) Fluid (lb/min) Stage Cum. Stage Cum. Time Stage (psi) (bpm) (bbls) (bbls) (bbls) (bbls) hh:mm:ss 1 7190 18.0 18.0 142.9 142.9 142.9 142.9 00:07:56 2 7190 18.0 18.0 854.0 996.9 854.0 996.9 00:47:26 3 6898 18.0 17.2 724.0 11.9 1008.8 11.4 1008.3 00:00:39 4 6608 18.0 16.5 1389.1 17.9 1026.7 16.4 1024.8 00:00:59 5 6325 18.0 15.9 2002.4 35.1 1061.8 31.0 1055.7 00:01:56 6 6054 18.0 15.3 2569.5 54.9 1116.7 46.7 1102.4 00:03:03 7 5795 18.0 14.7 3095.6 75.3 1192.0 61.7 1164.0 00:04:11 8 5550 18.0 14.2 3584.9 60.6 1252.6 47.9 1212.0 00:03:22 9 5568 18.0 14.1 3553.4 34.9 1287.5 27.3 1239.3 00:01:56 10 5344 18.0 13.6 4001.1 55.4 1342.9 41.9 1281.2 00:03:04 11 6298 18.0 18.0 104.3 1447.2 104.3 1385.5 00:05:47 Total Pump Time: 01:20:23 Report Printed on. July 24,2013 6.17 PM Page 5 Gr4141 Have more questions? You can find us at: http://www.bakerhug hes.com/prod ucts-and-services/pressure-pumping Granite Point Platform Well#: GP 11-13RD • H E M AT I C Last Completed: Future • S PTD: 191-133 Moon)Alaska.IAA: API: 50-733-20026-01 RKB to Hanger=42.5' CASING DETAIL Grade Conn ID Top Btm 18" Conductor 41' 684' 18 13-3/8" 61.0# 1-55 12.515" 41' 4,018' 9-5/8" 47# N-80 8.681" 41' 6,773' 9-5/8" 53.5# P-110 8.535" 6,773' 10,060' 7" 32# P-110 6.094" 9,787' 11,560' 32# Exp.Liner TUBING DETAIL L � 13-3/8^ '-7/8" 6.4# N-80 BTC 2.992" JEWELRY Depth ID Item L 9-5/8' c7/1 Ex, `able Lin•- / 3/5/93—398'of TCP Guns(Max OD—4.625")dropped from tubing release @ 10,984'. I� 9/28/10- Guns tagged @ 11,123'SLM. PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 Hemlock 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/11 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 TD=11.560' Cement Ret.@ 11.510' Updated by JLL 08/01/13 ti • • Granite Point Platform Well#: GP 1143RD SCHEMATIC Last Completed: 03/12/92 Hilcoro Aleaka,LLC API: 0-733 3 A��,,✓.✓ API: 191-1-20026 01 RKB to Hanger=42.5' 1 V r 60-17: CASING DETAIL o U 1 Size WT Grade Conn ID Top Btm 18" Conductor 41' 684' 13-3/8" 61.0# J 55 12.515" 41' 4,018' 18" 9-5/8" 47# N-80 8.681" 41' 6,773' 9-5/8" 53.514 P-110 8.535" 6,773' 10,060' 2 7" 32# P-110 TUBING DETAIL 6.094" 9,787' 11,560' U 3 2-7/8" 6.5# L-80 BTC 2.441" 46' 10,935' 13-3/8" 4 JEWELRY 5 No pth ID Item - 42.5' FMC/OCT 5M Tubing hanger w/CIW"H"BPV Profile 6 43' 2.992" 3-1/2" x 2',9.2#L-80 Tubing Pup M 46' 2.441" 3-1/2"x 2-7/8" BT&C X-over 7 1 311' Camco"TRSV"Retrievable SSSV 1M 2 2,193' 2.441" 2-7/8"Camco"MMM"Gas Lift Mandrel �/ 8 3 3,863' 2.441" 2-7/8"Camco"MMM"Gas Lift Mandrel V\ 4 5,130' 2.441" 2-7/8"Camco"MMM"Gas Lift Mandrel 9 , 5 6,054' 2.441" 2-7/8"Camco"MMM"Gas Lift Mandrel Z. 9-5/8" M (/ 6 6,791' 2.441" 2-7/8"Camco"MMM"Gas Lift Mandrel �f-1 7 7,623' 2.441" 2-7/8"Camco"MMM"Gas Lift Mandrel 11 8 8,263' 2.441" 2-7/8"Camco"MMM"Gas Lift Mandrel M 9 8,935' 2.441" 2-7/8"Camco"MMM"Gas Lift Mandrel . 12 10 9,576' 2.441" 2-7/8"Camco"MMM"Gas Lift Mandrel " A li 10,246' 2.441" 2-7/8"Camco"MMM"Gas Lift Mandrel Ii%6 13 12 10,826' 2.441" 2-7/8"Camco"MMM"Gas Lift Mandrel 4 Pakr depth is Q \/ 10,926' 13 10,902' 2.313" Halliburton/Otis"X"Landing Nipple v` ' 14 >� 14 10,926' 3.250" Otis"BWD"Permanent Packer(Ran 3/12/92) A 15 10,935' 2.35" Halliburton/Otis Locator Sub(On end of tubing run 10/2/95) 15 16 10,984' 2.125" End of Tubing @ Mech.Tubing Release(Guns dropped 3/5/93) 16 3/5/93—398'of TCP Guns(Max OD—4.625")dropped from tubing release @ 10,984'. 9/28/10- Guns tagged @ 11,123'SLM. PERFORATIONS / Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 Hemlock 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/11 / 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 / / # / �_ /' /" ' ! � (J/ /_ l /` / # /, V' 1 , 1 1 TD=11,560' Cement Ret.©11,510' Updated by DMA 11-28-12 • 0 Well Granit#e: Point GP 11-13R Platform D 1 Last D PROPOSED pleted: PT :Com191-133 Future Hilcuro Alaska.IRA, API: 50-733-20026-01 RKB to Hanger=42.5' i 111 CASING DETAIL 1 Size WT Grade Conn ID Top Btm 18" Conductor 41' 684' 2 13-3/8" 61.0# J 55 12.515" 41' 4,018' 18" 9-5/8" 47# N-80 8.681" 41' 6,773' 9-5/8" 53.5# P-110 8.535" 6,773' 10,060' . 3 7" 32# P-110 6.094" 9,787' 11,560' IF5.919" 32# Exp.Liner 11,015' 11,390' 4 TUBING DETAIL 3-1/2" 9.3# L-80 BTC 2.992" Surf ±10,959' L 1 13-3/8" 5 IF 6 III JEWELRY No Depth ID Item 7 1 ±300' SCSSV 2 ±2,303' GLM X 8 x` ' 3 ±4,181' GLM 4 ±5,703' GLM L 9 5 ±6,814' GLM 9-5/8" 6 ±7,674' GLM 7 ±8,330' GLM 10 8 ±8,835' GLM 9 ±9,340' GLM 11 10 ±9,847' GLM 11 ±10,353' GLM 12 12 ±10,870' GLM DD❑ 13 13 ±10,917' Sliding Sleeve 14 ±10,930' Chemical Injection Mandrel 14 15 ±10,940' Hydraulic Retrievable Packer r . 15 16 ±10,952' X Nipple Kir 16 17 ±10,959' WLEG , r E Expandable e Liner 18 11,510' Cement Retainer 1 7 11 015-11,390' i WI 10/(0610 1103 X/10104 PERFORATIONS iiZone Top(MD) BtD'M I 1 Mil Top(TVD) Btm(TVD) Amt SPF Date T f 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 Hemlock 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/11 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 Hemlock ±11,347' ±11,357' ±11,204' ±11,213' 10' Future ✓ WINO 7" L TD=11,560' Cement Ret.©11,510' Updated by JLL 08/01/13 • • Granite Point Platform Rental BOP 03/11/2013 H11c41fp:%Isektl_11.11A. Granite Point Platform A r- ' 2013 Workovers N/" BOP Drawing(Moncla) I eAk , i. i. i t 454' Hydril crwsesnoa Ili ;Ii !I: I�IIi it :t t :I'. iI 4.67' — I , 2 7/8-5 variables - 13 5/8-5000 IF_ - Blind II 11 it 11'1/I It It 111 2.00' OII -'1 1 r ��; 2 1/16 5M Choke and Kill valves t� Mil'lil It. ii, i' ;I !II 2.00 Drill deck 19.75' Riser 13 5/8 5M FE X 13 5/8 5M #13 API hub Top of wellhead @ 19.75'below deck • •• Granite Point Platform 11-13RD Current IliIrnrp ALirku.I.id. Tubing hanger,FMC-UH- Granite Point TC-1A-EN,13 5/8 5M X 3 Y: 11-13RD IBT lift and susp,w/3"type 18 X 13 3/8 X 9 5/8 X H BPV,'I.non continuous 2 7/8 control line,6.990"EN BHTA,Bowen,3 1/8 5M FE X 3"Bowen ., ... Mill Valve,Swab,VG-M, ^�•. 31/85M FE,HWO,EE trim arA1 =+ ■1111 ��, Valve,Wing,WKM-M, 2 9/16 5M,w/D-122 oper / i i Tee,stdd,3 1/8 5M X �i i 29/165M I. ! ! P. •.. . Valve,Master,CIW-FL, .pimp 3 1/8 SM FE,HWO,EE trim ilog,.10 Valve,Master,CIW-FL, ^`• 3 1/8 SM FE,HWO,EE trim c. ...1, .I I ol, ,., Adapter,FMC-ASP,13 S/8 SM % �-- API clamp X 3 1/8 5M,w/ AL 6.990"extended neck pocket Unihead,OCT type 2,13 5/8 5M API _ hub top X 13 3/8 BTC casing bottom, � II AIL G> w/2-2"LPO on lower section,2-2 J : O. 1/16 SM SSO on upper section,IP internal lockpin assy �. Valve,WKM-M,2 1/16 5M . •a Valve,VG-100,2 1/16 SM HWO,AAtrim � l e,J r t- � , HWO,AAtrim•;.AIL ► , . I: • 111. i ° , Starting head,OCT, *mil I�mir`:,� *-1- "um. 211/4 2M Hub it 24'/.1M "hi l� Valve,OCT-20,2"LPO,HWO, Hub w/2-2"LPO,prepped El r � , ', AA trim 18"EN hanger l.l_, r— ;lA "i_j. imm VIIIMIN Conductor housing, Or I ! rid i Y. 241MHubX . 24"Buttweld ' ' I I 18" 13 3/8" —95/8" 27/8" II • • Granite Point Platform 11-13RD Harm?:1larlcn-1.1 i Proposed Tubing hanger,FMC-UH- Granite Point TC-1A-EN,13 5/8 SM X 3 Y 11-13RD IBT lift and susp,w/3"type 18 X 13 3/8 X 9 5/8 X H BPV,Y.non continuous 2 7/8 control line,6.990"EN BHTA,Bowen,3 1/8 5M FE X 3"Bowen Valve,Swab,VG-M, ..r � 3 1/8 5M FE,HWO,EE trim �:.7 „ ,. Valve,Wing,WKM-M, 2 9/16 5M,w/0-122 oper Tee,stdd,3 1/8 SM X `I 29/165M i ® ® '+ Valve,Master,CIW-FL, . ii... 3 1/8 5M FE,HWO,EE trim �,,r �riTi,. •Valve,Master,CIW-FL, 11u` 3 1/8 SM FE,HWO,EE trim ':1,4d,. Adapter,FMC-ASP,13 5/8 5M .t `" API clamp X 3 1/8 5M,w/ Unihead,OCT type 2,13 5/8 SM API 6.990"extended neck pocket hub top X 13 3/8 BTC casing bottom, J �Q, w/2-2"LPO on lower section,2-2 : �.. 1/16 5M SSO on upper section,IP l� internal lockpin asst' 1— , , , ' 4 Valve,WKM-M,2 1/16 5M AB ,`. Valve,VG-100,2 1/16 5M HWO,AAtrim r� a r t .�� g HWO,AAtrim . '.i ' MT it N I:3' 1114 • I SUER Al gam-r!� '■'1. Starting head,OCT, �. 'l. 211/42M Hub x24Y.1M a� �� Valve,OCT-20,2"LPO,HWO, Hub w/2-2"LPO,prepped f/ r �- t AA trim 18"EN hanger '111 r■Iii p N�is_l. Conductor housing, 1,111111 IIIIPr°. 24Y.1MHubX 24"Buttweld II 111 I 11Aa I I II I 18" 13 3/8" 9 5/8" 1 2 7/8" I . STIMPLAN(TM),NSI,Tulsa,OK-www.nsitech.com Frac Summary*GP-11-13RD Filename:O...GP-11-13RD StimPlan Simulation Elevated Stress(7-17-13).STP;19-Jul-2013 Well ID:GP-11-13RD Perforated Interval:TVD(ft) Top 11349.8 Bottom 11359.4 I Formation Temperature(F) 190 Notes FORMATION LAYER DATA-Multi-Layer Height Growth Depth(ft) Stress(psi) Gradient Modulus Toughness Loss Coef. Spurt Top Bottom Thickness Top Bottom (psi/ft) (MMpsi) (psi*sgrt(in)) (ft/sqrt(min)) (gal/100ft^2) 10918.3 10989.1 70.8 9347.0 9377.7 0.433 1.50 2000.0 0.00440 0.00 0.0 10989.1 11020.5 31.4 7433.0 7446.6 0.433 2.50 2000.0 0.00000 0.00 0.0 11020.5 11033.7 13.2 11020.5 11026.2 0.433 0.50 2000.0 0.00440 0.00 0.0 11033.7 11043.0 9.3 10592.4 10596.4 0.433 3.50 2000.0 0.00000 0.00 0.0 11043.0 11063.9 20.9 9607.4 9614.3 0.330 4.00 2000.0 0.00150 0.00 0.2 11063.9 11080.4 16.5 10510.7 10517.8 0.430 4.00 2000.0 0.00000 0.00 0.0 11080.4 11134.0 53.6 9418.3 9436.0 0.330 5.50 2000.0 0.00150 0.00 0.2 11134.0 11185.0 51.0 10243.3 10260.1 0.330 4.50 2000.0 0.00150 0.00 0.2 11185.0 11215.0 30.0 9507.3 9517.2 0.330 5.00 2000.0 0.00150 0.00 0.2 11215.0 11265.0 50.0 9644.9 9661.4 0.330 4.50 2000.0 0.00150 0.00 0.2 I 11265.0 11310.0 45.0 9575.3 9590.1 0.330 5.50 2000.0 0.00150 0.00 0.2 11310.0 11325.0 15.0 10065.9 10070.9 0.330 5.50 2000.0 0.00150 0.00 0.2 11325.0 11380.7 55.7 9626.3 9644.7 0.330 6.50 2000.0 0.00150 0.00 0.2 11380.7 10811.7 0.430 3.50 2000.0 0.00000 0.00 0.0 FORMATION: Permeability(md) 0.500 TEMPERATURE: Bottom Hole(F) 190 PRESSURE: Reservoir Pressure(psi) 5300.0 Closure Pressure(psi) 9636.1 DEPTH: Well Depth(ft) 11349.8 Fluid Pressure Gradient(psi/ft) 0.411 Perforations Top(ft) 11349.8 Bottom(ft) 11359.4 Initial Top(ft) 11349.8 Bottom(ft) 11359.4 E-StimPlan N-Fracs No Acidizing No Coupled Model No 3-D SIMULATOR PROGRAM CONTROL Frac Grid(Top)(ft) 10918.0 Frac Grid(Bottom)(ft) 11600.0 Max Expected Xf(ft) 984.2 Allow Post TSO Height Growth No Use FEM Width Calculations No Calculated Results E-StimPlan Pumping Schedule-GP-11-13RD Licensed To:E-StimPlan 3D 6.11 -NSI School Use Only Half Length 'Hydraulic'Length(ft) 320,3 Propped length(ft) 299.9 PRESSURE: Max Net Pressure(psi) 462.9 Final Net Pressure(psi) 381.2 Surface Pres-End of Pad(psi) 7640.0 Surface Pres-Start of Flush(psi) 1553.2 Surface Pres-End of Job(psi) 2129.1 Maximum Hydraulic Horsepower 4872.2 TIME: Max Exposure to Form.Temp.(min) 38.6 Time to Close 27.9 RATE: Fluid Loss Rate during pad(BPM) 6.13 EFFICIENCY: At end of pumping schedule 0.32 PROPPANT: Average In Situ Conc.(Ib/ft^2) 0.5 Average Conductivity(md-ft) 350.9 Fcd(KfW/k/Xf) 2.34 HEIGHT: Max Fracture Height(ft) 209.9 WIDTH: Avg width at end of pumping(in) 0.21 VOLUMES: Total Fluid Volume(M-Gal) 47.8 Total Proppant Volume(M-Lbs) 57.8 (TM).NSI Technologies,Tulsa,OK Licensed To: E-StimPlan 3D 6.11 -NSI School Use Only WELL ID: GP-11-13RD DEPTH: Well Depth(ft) 11349.8 PRESSURE: Reservoir Pressure(psi) 5300.0 Closure Pressure(psi) 9636.1 TEMPERATURE: Bottom Hole Temperature(F) 190.0 • • **Pumping Schedule** GP-11-13RD SI Vol Fl Vol Conc(PPG) Rate Fluid Prop Cum Proppant Pump Time (M-Gal) (M-Gal) Start End (BPM) Type Type (M-Lbs) (min) 35.87 35.87 0.0 0.0 18.00 6 3 0.0 47.4 0.50 0.48 1.0 1.0 18.00 6 3 0.5 0.7 0.75 0.69 2.0 2.0 18.00 6 3 1.9 1.0 1.48 1.30 3.0 3.0 18.00 6 3 5.8 2.0 2.31 1.96 4.0 4.0 18.00 6 3 13.6 3.1 3.17 2.59 5.0 5.0 18.00 6 3 26.5 4.2 4.02 3.16 6.0 6.0 18.00 6 3 45.5 5.3 2.32 1.76 7.0 7.0 18.00 6 3 57.8 3.1 Total Slurry 50.4 Total Fluid 47.8 Total Proppant 57.8 Avg.Conc 1.2 Total Pump Time 66.7 min Pad% 71.1 Proppant Data Proppant ID No.3 20-40 CarboLite Specific Gravity 2.65 Damage Factor(1.0=No Damage) 0.70 Proppant Stress 0 2000 4000 8000 10000 KfW @ 2#/sq ft and-ft) 12500 10700 8900 3700 2000 Fluid Data Fluid ID No.6 Lightning 3000 Specific Gravity 0.95 Data @Wellbore @FormTmp 0.25 hr 0.50 hr 1.0 hr 1.5 hr vis(cp @ 401/sec) 700.0 30.0 680.0 545.0 91.0 58.0 non-Newtonian n' 0.52 0.54 0.60 0.69 0.99 0.14 K(Ib/sec/ft^2)x1000 0.08 0.00 0.06 0.04 0.00 0.03 Friction Data Pipe Friction Q(BPM) P/dL(psi/100ft) Data 5.0 4.0 10.0 10.0 15.0 17.3 20.0 25.9 25.0 35.0 Measured Depth(ft) 11500.0 Time History*NSI STIMPLAN 3-D Fracture Simulation GP-11-13RD Time Pen Pres Rate Prop SI Vol Efficiency Loss Hght W-Avg (min) (ft) (psi) (BPM) (PPG) (M-Gal) (BPM) (ft) (in) 0.3 27.4 463 18.00 0.0 0.2 0.47 16.7 56 0.05 3.6 108.3 312 18.00 0.0 2.7 0.36 10.3 153 0.06 7.0 125.9 331 18.00 0.0 5.3 0.34 13.0 196 0.07 10.3 141.8 287 18.00 0.0 7.8 0.35 12.8 196 0.09 13.7 148.0 316 18.00 0.0 10.4 0.36 10.1 196 0.12 17.1 156.0 321 18.00 0.0 12.9 0.37 9.5 196 0.14 20.5 172.0 264 18.00 0.0 15.5 0.36 14.3 196 0.14 23.8 193.3 269 18.00 0.0 18.0 0.34 13.6 196 0.14 27.2 198.7 301 18.00 0.0 20.6 0.34 11.6 196 0.15 30.6 210.1 293 18.00 0.0 23.1 0.34 11.5 196 0.16 34.0 220.4 322 18.00 0.0 25.7 0.34 12.6 196 0.17 37.4 225.3 314 18.00 0.0 28.3 0.34 11.3 210 0.18 40.8 240.8 332 18.00 0.0 30.9 0.34 12.5 210 0.18 44.2 248.9 326 18.00 0.0 33.4 0.34 12.3 210 0.19 47.4 258.1 341 18.00 0.0 35.9 0.34 12.7 210 0.19 47.5 258.3 343 18.00 1.0 35.9 0.34 12.5 210 0.19 48.1 262.0 345 18.00 1.0 36.4 0.33 12.8 210 0.19 48.1 262.2 344 18.00 2.0 36.4 0.33 12.8 210 0.19 49.1 266.8 331 18.00 2.0 37.1 0.33 12.9 210 0.19 49.1 266.9 331 18.00 3.0 37.2 0.33 13.0 210 0.19 51.1 273.6 336 18.00 3.0 38.6 0.33 12.5 210 0.19 51.2 273.7 336 18.00 4.0 38.7 0.33 12.4 210 0.19 54.1 277.9 347 18.00 4.0 40.9 0.33 13.4 210 0.20 54.3 278.2 348 18.00 5.0 41.0 0.33 13.2 210 0.20 57.7 290.1 359 18.00 5.0 43.7 0.32 13.0 210 0.20 58.3 292.3 362 18.00 5.0 44.1 0.32 12.8 210 0.20 58.4 292.5 362 18.00 6.0 44.1 0.32 12.8 210 0.20 61.8 302.0 368 18.00 6.0 46.7 0.32 14.9 210 0.20 63.6 304.5 381 18.00 6.0 48.1 0.32 15.4 210 0.20 63.8 304.8 382 18.00 7.0 48.2 0.32 13.8 210 0.20 66.7 311.3 381 18.00 7.0 50.4 0.32 12.7 210 0.21 71.0 318.7 306 0.00 7.0 50.4 0.27 11.8 210 0.18 74.7 320.2 276 0.00 7.0 50.4 0.24 10.1 210 0.16 78.1 320.3 254 0.00 7.0 50.4 0.21 8.6 210 0.15 83.9 320.3 221 0.00 7.0 50.4 0.17 8.1 210 0.12 88.4 320.3 198 0.00 7.0 50.4 0.15 7.3 210 0.10 92.1 320.3 178 0.00 7.0 50.4 0.13 6.3 210 0.09 94.6 320.3 153 0.00 7.0 50.4 0.12 5.7 210 0.08 • • GEOMETRY SUMMARY*At End of Pumping Schedule GP-11-13RD Distance Pressure W-Avg Q Sh-Rate Hght(ft) Bank Prop (ft) (psi) (in) (BPM) (1/sec) Total Up Down Prop Fraction (PSF) 14 323 0.26 9.0 17 210 173 19 181 0.00 0.02 41 319 0.26 8.4 14 210 173 19 181 0.00 0.02 68 313 0.26 7.8 14 210 173 19 181 0.00 0.01 95 304 0.25 7.1 13 210 173 19 181 0.00 0.01 123 295 0.25 6.5 13 201 163 19 181 0.00 0.01 150 283 0.23 5.9 13 201 163 19 181 0.00 0.01 177 270 0.22 5.2 13 201 163 19 181 0.00 0.01 205 256 0.20 4.5 14 200 163 19 181 0.00 0.01 232 236 0.17 3.9 17 196 159 19 181 0.00 0.01 259 209 0.13 3.1 21 196 159 19 181 0.00 0.00 286 178 0.09 2.0 30 169 132 19 169 0.00 0.00 314 104 0.03 1.0 85 144 106 19 0 0.00 0.00 PROPPANT SUMMARY*At End of Pumping Schedule GP-11-13RD ' Lb/Sq-Ft Lost to Embedment 0.200 Distance KfW Prop Concentration(Total lb/sq foot) (ft) (md-ft) Prop ID 1 13.6 697 0.75 40.9 670 0.73 68.2 623 0.69 95.4 565 0.64 122.7 522 0.61 150.0 439 0.54 177.2 341 0.45 204.5 226 0.35 231.8 109 0.24 259.0 29 0.15 286.3 0 0.06 311.3 0 0.00 Average Conductivity(md-ft) 385 PROPPANT SUMMARY*At Fracture Closure G P-11-13RD Lb/Sq-Ft Lost to Embedment 0.200 Distance KEN Prop Concentration(Total lb/sq foot) (ft) (md-ft) Prop ID 1 13.6 482 0.60 40.9 468 0.59 68.2 454 0.58 95.4 432 0.56 122.7 410 0.54 150.0 386 0.52 177.2 348 0.49 204.5 304 0.46 231.8 245 0.40 259.0 221 0.37 286.3 182 0.33 320.3 0 0.15 Average Conductivity(md-ft) 351 • • i BJ SERVICES COMPANY Reg n USA MATERIAL SAFETY DATA SHEET SECTION I - GENERAL INFORMATION PRODUCT NAME: High Perm CRB-LT ITEM NUMBER : 488175 CHEMICAL DESCRIPTION: Encapsulated oxidizing breaker PRODUCT USE: Breaker-water SUPPLIER: BJ Services Company ADDRESS: 11211 FM 2920 Tomball,TX 77375 EMERGENCY TELEPHONE NUMBER (800)424-9300 for CHEMTREC (202)483-7616 Alaska and International PREPARED BY: BJ Services Environmental Group (281)351-8131 DATE PREPARED: September 21, 2000 Supersedes:April 16, 1997 HMIS HAZARD INDEX HEALTH: 2 FLAMMABILITY: 0 REACTIVITY: 3 PERSONAL PROTECTION: e SECTION II - HAZARDOUS COMPONENTS HAZARDOUS COMPONENTS CAS# PERCENT HAZARD Ammonium persulfate 7727-54-0 >60 Oxidizer Crystalline silica 7631-86-9 1-10 Irritant SECTION III - FIRE AND EXPLOSION HAZARD DATA FLASHPOINT(METHOD): N.A. UPPER EXPLOSION LIMIT(% BY VOL): N.A. LOWER EXPLOSION LIMIT(%BY VOL): N.A. AUTO-IGNITION TEMPERATURE: N.A. EXTINGUISHING MEDIA: Product is non-flammable, use media appropriate for surrounding material. SPECIAL FIRE FIGHTING PROCEDURES: Non-flammable EXPLOSION DATA: N.A. HAZARDOUS COMBUSTION PRODUCTS: N.E. SECTION IV - HEALTH HAZARD DATA PRIMARY ROUTES OF ENTRY: Inhalation, eye and skin contact, ingestion ACUTE OVEREXPOSURE EFFECTS: High Perm CRB-LT-USA-Revised 10/30/2006/Page 1 UNCONTROLLED WHEN PRINTED • • SKIN CONTACT: Prolonged exposures may result in skin burns and ulcerations. SKIN ABSORPTION: Not expected route of entry EYE CONTACT: Very dangerous in case of eye contact. This product is an eye irritant. INHALATION: Over-exposure by inhalation may cause respiratory irritation. INGESTION: N.E. CHRONIC OVEREXPOSURE EFFECTS: There is no known effect from chronic exposure to this product. Repeated or prolonged exposure is not known to aggravate medical conditions. EXPOSURE LIMITS: HAZARDOUS COMPONENT ACGIH TLV OSHA PEL Ammonium persulfate 2 mg/m3 2 mg/m3 Crystalline silica 0.1 mg/m3 0.1 mg/m3 CARCINOGENICITY, REPRODUCTIVE EFFECTS: Not listed as carcinogenic-IARC,NTP, or OSHA TERATOGENICITY, MUTAGENICITY: N.E. TOXICITY STUDIES: LD(50) 820 mg/kg (oral-rat)Ammonium persulfate 160 mg/kg (oral-rat)Crystalline silica LC(50) N.E. SECTION V - FIRST AID PROCEDURES FOR EYES: In case of contact, check for and remove any contact lenses. Flush eyes with plenty of water for at least 15 minutes. Lift upper and lower lids and rinse well under them. Get medical attention, preferably an ophthalmologist if irritation occurs. FOR SKIN: Flush all affected areas with plenty of water for several minutes. Remove and wash any contaminated clothing and shoes. Get medical attention if skin irritation occurs. FOR INHALATION: Remove to fresh air. If breathing is labored, give oxygen. If breathing has stopped, give artificial respiration. Keep person warm, quiet and get medical attention. FOR INGESTION: Watch for obstruction in the victim's mouth. Remove, if possible, what is causing the obstruction, but do not force fingers or hard object between the victim's teeth. Have conscious person drink several glasses of water or milk. INDUCE VOMITING by sticking finger in throat. Seek immediate medical attention. SECTION VI - PHYSICAL DATA High Perm CRB-LT-USA-Revised 10/30/2006/Page 2 UNCONTROLLED WHEN PRINTED s • APPEARANCE AND ODOR: Orange solid with slight acrid odor. SPECIFIC GRAVITY: N.E. VAPOR PRESSURE: N.A. VAPOR DENSITY(air=1): N.A. EVAPORATION RATE: N.A. BOILING POINT: N.A. FREEZING POINT: N.A. SOLUBILITY IN H20: Partially soluble in cold water. pH: 4.5-5(1%aqueous solution) SECTION VII - REACTIVITY DATA CHEMICAL STABILITY: Stable INCOMPATIBLE MATERIALS: Highly reactive with reducing agents, organic materials. Slightly reactive to reactive with metals, moisture.Very slightly to slightly reactive with acids, alkalis. HAZARDOUS POLYMERIZATION: Does not polymerize HAZARDOUS DECOMPOSITION PRODUCTS: N.E. SECTION VIII - SPECIAL/PERSONAL PROTECTION VENTILATION: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air movement. RESPIRATORY PROTECTION: Dust respirator. Be sure to use a MSHA/NIOSH approved respirator or equivalent. PROTECTIVE GLOVES: Chemical resistant EYE PROTECTION: Chemical splash goggles OTHER PROTECTIVE EQUIPMENT: Eyewash bottles or other rinsing equipment should be easily accessible. SECTION IX - HANDLING PRECAUTIONS LEAK AND SPILL PROCEDURES: Wear necessary protective equipment. Sweep up and place in DOT approved container for reuse or disposal. WASTE DISPOSAL: If this product becomes a waste, it meets the requirements of a RCRA hazardous waste with the code of D003.Always dispose of according to all local/state/and federal regulations. HANDLING & SPECIAL EQUIPMENT: Keep away from heat. Keep away from sources of ignition. Keep away from combustible materials. DO NOT breathe dust. Avoid contact with skin and eyes. Keep away from incompatibles such as reducing agents, organic materials, metals, moisture. STORAGE REQUIREMENTS: Oxidizing materials should be stored in a separate cabinet or room. Product has a shelf life of twelve months. SECTION X - REGULATORY INFORMATION High Perm CRB-LT-USA-Revised 10/30/2006/Page 3 UNCONTROLLED WHEN PRINTED • SHIPPING INFORMATION PROPER SHIPPING NAME: Oxidizing, solid, n.o.s. (contains ammonium persulfate) HAZARD CLASS: 5.1 UN/NA NUMBER: UN1479 PACKING GROUP W/"PG": PG III SUBSIDIARY RISK: N.A. REPORTABLE QUANTITY(RQ): N.A. EMERGENCY RESPONSE GUIDE#: 140 ENVIRONMENTAL INFORMATION SARA TITLE III SECTION 302/304 This product does not contain ingredients listed as an Extremely Hazardous Substance. SECTION 311/312 Immediate SECTION 313 This product does not contain ingredients(at a level of 1%or greater)on the List of Toxic Chemicals. OTHER REGULATORY INFORMATION TSCA INVENTORY: All of the components in this appear on the TSCA inventory. CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore,vendee assumes the risk in his use of the material. Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document Today 2 I Telephone number 09/21/00 3 I Address Change 10/30/06 High Perm CRB-LT-USA-Revised 10/30/2006/Page 4 UNCONTROLLED WHEN PRINTED • • / BJ SERVICES COMPANY Region: MATERIAL SAFETY DATA SHEET USA 1 PRODUCT AND COMPANY IDENTIFICATION Product Name: BC-3 Item Number: 488187 Product Use: Breaker catalyst Supplier: BJ Services Company 5500 Northwest Central Dr Houston,TX 77092 (281)351-8131 IN CASE OF EMERGENCY CALL: (800) 424-9300 for CHEMTREC (703) 527-3887 for International HMIS HAZARD INDEX HEALTH: 1 FLAMMABILITY: 1 REACTIVITY: 0 PERSONAL PROTECTION: b 2 COMPOSITION/INFORMATION ON INGREDIENTS Ingredient Non-hazardous 100 3 HAZARDS IDENTIFICATION PRIMARY ROUTES OF EXPOSURE: Inhalation. Eye contact. Skin contact. ACUTE OVEREXPOSURE EFFECTS: INHALATION: May be harmful if inhaled. Exposure to high vapor/mist concentrations may cause respiratory tract irritation. INGESTION: Not a likely exposure route. EYE CONTACT: May cause mild eye irritation. SKIN CONTACT:May cause mild skin irritation. EXPOSURE LIMITS: Non-hazardous 4 FIRST AID MEASURES INHALATION: If inhaled, remove from area to fresh air.Get medical attention if respiratory irritation develops or if breathing MSDS for BC-3 Page 1 • becomes difficult. INGESTION: Rinse mouth out with water. Drink plenty of water. If large quantities were ingested,seek medical advice. EYES: In case of contact, immediately flush eyes with plenty of water for at least 15 minutes and get medical attention if irritation persists. SKIN: Wash with water or soap and water. Remove contaminated clothing and launder before reuse. Get medical attention if irritation persists. 5 FIRE FIGHTING MEASURES FLASHPOINT(METHOD): 370°F(COC) LOWER EXPLOSION LIMIT(%v/v): Not applicable/available UPPER EXPLOSION LIMIT(%v/v): Not applicable/available AUTO-IGNITION TEMPERATURE: Not available/applicable SPECIAL HAZARDS: Product will burn in fire situation. EXTINGUISHING MEDIA: Water fog, carbon dioxide, foam, dry chemical. SPECIAL FIREFIGHTING PROCEDURES: Fire-fighters should wear self-contained breathing apparatus and full protective clothing when fighting chemical fires Cool exposed containers with water spray. HAZARDOUS COMBUSTION PRODUCTS: Oxides of carbon. 6 ACCIDENTAL RELEASE MEASURES Wear specified protective equipment. Small spills-Cover spill with absorbent material.Scoop absorbed material into a suitable container for disposal. Large spills-Dike to contain. Prevent from entering sewers or waterways Recover product to suitable containers or vessel for reuse, if possible,or for disposal. 7 HANDLING AND STORAGE HANDLING: Wear specified protective equipment. Use only in a well ventilated area. STORAGE REQUIREMENTS: Keep container tightly closed, in a cool,well ventilated place. 8 EXPOSURE CONTROLS/PERSONAL PROTECTION SPECIFIC ENGINEERING CONTROLS: Use only in a well ventilated area. PERSONAL PROTECTIVE EQUIPMENT: Appropriate respiratory protection shall be worn when applied engineering controls are not adequate to protec against inhalation exposure. Chemical resistant goggles. Rubber gloves. Neoprene gloves. Coveralls. 9 PHYSICAL AND CHEMICAL PROPERTIES PHYSICAL STATE: Liquid COLOR: Clear ODOR: Essentially None ODOR THRESHOLD: Not available/applicable SPECIFIC GRAVITY: 1.1 @ 25°C VAPOR PRESSURE: 1 mm Hg @ 132°C MSDS for BC-3 Page 2 • • VAPOR DENSITY(air= 1): 11.1 EVAPORATION RATE: < 1 (n-butyl acetate=1) BOILING POINT: 297°C FREEZING POINT: -42°C pH: Not available SOLUBILITY IN WATER: Negligible 10 STABILITY AND REACTIVITY STABILITY: Stable under normal conditions of use. INCOMPATIBILITY/CONDITIONS OF REACTIVITY: Strong oxidizers. HAZARDOUS THERMAL DECOMPOSITION PRODUCTS: Carbon monoxide.Carbon dioxide. HAZARDOUS POLYMERIZATION: Will not occur. 11 TOXICOLOGICAL PROPERTIES CHRONIC EFFECTS: Not determined. SENSITIZATION: Not known. CARCINOGENICITY: None of the components of this product have been listed as carcinogenic by IARC, NTP or OSHA. (IARC- International Agency for Research on Cancer)(NTP-National Toxicology Program)(OSHA-Occupational Safety& Health Administration(US)) MUTAGENICITY: Not known. REPRODUCTIVE TOXICITY: Not known. 12 ECOLOGICAL INFORMATION No specific information available 13 DISPOSAL CONSIDERATIONS WASTE DISPOSAL: Consult local waste authorities for direction and/or approvals prior to disposal. 14 TRANSPORT INFORMATION DOT Proper Shipping Name: NOT RESTRICTED MSDS for BC-3 Page 3 • • UN No.: NA AIR TRANSPORT(ICAO/IATA) Proper Shipping Name: NOT RESTRICTED UN/ID No.: NA MARINE TRANSPORT(IMDG/IMO) Proper Shipping Name: NOT RESTRICTED UN/ID No.: NA 15 REGULATORY INFORMATION SARA TITLE III: SECTION 302/304 This product does not contain substances listed in Appendix A and B as an Extremely Hazardous Substance. SECTION 311/312 Immediate SECTION 313 This product does not contain ingredients(at a level of 1%or greater)on the List of Toxic Chemicals. TSCA INVENTORY: The substances in this product are included on or exempted from the TSCA 8(b) Inventory (40 CFR 710) CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product. 16 OTHER INFORMATION ISSUE DATE: 10/21/2004 PREPARED BY: BJ SERVICES ENVIRONMENTAL GROUP REFERENCES: Suppliers' Literature. Dangerous Properties of Industrial Materials,9th ed.; N. Irving Sax, 1996. CCINFOdisc(Core Collection), Canadian Centre for Occupational Health and Safety,2004. International Marine Dangerous Goods Code,2002 Edition , International Maritime Organisation,2002. Dangerous Goods Regulations,45th ed., International Air Transport Association,2004. TDG Clear Language Regulations,as published in the Canada Gazette Part II,August 2001. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet Additionally,vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore,vendee assumes the risk in his use of the material. MSDS for BC-3 Page 4 0 • Revision: 1 Status: Approved&Released MSDS Revision History: Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document 10/21/99 2 I Telephone number 12/07/00 3 I Removed experimental designation 01/14/02 4 All Update to 16 part format 10/21/04 MSDS for BC-3 Page 5 LifijBJ SERVICES COMPANY Region: MATERIAL SAFETY DATA SHEET USA SECTION I - GENERAL INFORMATION PRODUCT NAME: BF-8L ITEM NUMBER: 425143 CHEMICAL DESCRIPTION: An alkanolamine in water PRODUCT USE: Buffer for fracturing SUPPLIER: BJ Services Company ADDRESS: 5500 Northwest Central Dr Houston TX 77092 EMERGENCY TELEPHONE NUMBER (800)424-9300 for CHEMTREC (202)483-7616 Alaska and International PREPARED BY: BJ Services Environmental Group (281)351-8131 DATE PREPARED: August 4, 2000 Supersedes: December 1992 HMIS HAZARD INDEX HEALTH: 3 FLAMMABILITY: 2 REACTIVITY: 0 PERSONAL PROTECTION: i SECTION II - HAZARDOUS COMPONENTS HAZARDOUS COMPONENTS CAS# PERCENT HAZARD Monoethanolamine 141-43-5 85 Irritant,toxic SECTION III - FIRE AND EXPLOSION HAZARD DATA FLASHPOINT(METHOD): 146°F (PMCC) UPPER EXPLOSION LIMIT(% BY VOL): N.E. LOWER EXPLOSION LIMIT(% BY VOL): N.E. AUTO-IGNITION TEMPERATURE: N.E. EXTINGUISHING MEDIA: Dry chemical, CO2,foam or water spray. SPECIAL FIRE FIGHTING PROCEDURES: Water or foam may cause frothing. Use water to cool fire-exposed containers. If a leak or spill has not ignited, use water spray to disperse the vapors and to provide protection for persons attempting to stop the leak. EXPLOSION DATA: None HAZARDOUS COMBUSTION PRODUCTS: Ammonia, carbon monoxide, and carbon dioxide may be formed on burning in limited air supply. N.E.=Not Established N.A.=Not Applicable MSDS for BF-8L...Page 1 • SECTION IV - HEALTH HAZARD DATA PRIMARY ROUTES OF ENTRY: Skin and eye contact, skin absorption, inhalation, ingestion ACUTE OVEREXPOSURE EFFECTS: SKIN CONTACT: Causes local discomfort or pain, severe excess redness and swelling, with chemical burns. SKIN ABSORPTION: Toxic. Prolonged or widespread skin contact may result in the absorption of potentially harmful amounts of material. EYE CONTACT: Liquid causes severe irritation, experienced as discomfort and pain, with blinking and excess tear production, and seen as marked excess redness and swelling of the conjunctiva and chemical burns of the eyes. INHALATION: Vapors may be irritating and cause coughing and discomfort in the nose, throat, and chest. Prolonged exposure may cause local injury to the respiratory tract. INGESTION: May cause chemical burns of the mouth, throat, esophagus, and stomach. Signs and symptoms will include pain or discomfort in the mouth, chest, and abdomen, nausea, vomiting, diarrhea, dizziness, drowsiness, faintness, weakness, collapse and coma. Aspiration may occur during swallowing or vomiting, resulting in lung injury. CHRONIC OVEREXPOSURE EFFECTS: May possibly cause kidney and liver damage. May aggravate asthma and inflammatory or fibrotic pulmonary disease. Because of its irritating properties, this material may aggravate an existing dermatitis. EXPOSURE LIMITS: HAZARDOUS COMPONENT ACGIH TLV OSHA PEL Monoethanolamine 3 ppm 3 ppm CARCINOGENICITY, REPRODUCTIVE EFFECTS: Do not use sodium nitrite or other nitrosating agents in formulation containing this product. Suspected cancer-causing nitrosamines could be formed. TERATOGENICITY, MUTAGENICITY: No effects listed. TOXICITY STUDIES: LD(50) 1-2 g/kg (oral rat) LC(50) N.E. SECTION V - FIRST AID PROCEDURES FOR EYES: Flush thoroughly with water for at least fifteen minutes. Get immediate medical attention. FOR SKIN: If drenched, remove contaminated clothing under safety shower and flood N.E.=Not Established N.A.=Not Applicable MSDS for BF-8L...Page 2 • • exposed areas with water. Get immediate medical attention. Wash clothing before reuse. FOR INHALATION: Remove to fresh air. If breathing has stopped, give artificial respiration. Keep person warm, quiet and get medical attention. FOR INGESTION: DO NOT induce vomiting. Never give anything by mouth to an unconscious person. Get medical attention. SECTION VI - PHYSICAL DATA APPEARANCE AND ODOR: Light colored liquid, no odor SPECIFIC GRAVITY: 1.03 VAPOR PRESSURE: N.E. VAPOR DENSITY(air=1): N.E. EVAPORATION RATE: Nil BOILING POINT: N.E. FREEZING POINT: Less than SOLUBILITY IN H20: Appreciable pH: 12 SECTION VII - REACTIVITY DATA CHEMICAL STABILITY: Stable INCOMPATIBLE MATERIALS: Avoid contamination with strong acids, strong bases, strong oxidizing agents, aldehydes, ketones, acrylates, organic anhydrides and organic halides. HAZARDOUS POLYMERIZATION: Does not polymerize HAZARDOUS DECOMPOSITION PRODUCTS: See combustion products SECTION VIII - SPECIAUPERSONAL PROTECTION VENTILATION: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air movement. RESPIRATORY PROTECTION: Not needed unless cleaning large spills or upon entry into tanks, vessels or other confined spaces in which case a supplied air respirator should be worn. PROTECTIVE GLOVES: Rubber or neoprene EYE PROTECTION: Goggles with face shield. DO NOT wear contact lenses when handling this product. OTHER PROTECTIVE EQUIPMENT: Eyewash bottles or other rinsing equipment should be easily accessible. When handling large quantities subject to splashes and spills, impervious suits, gloves and rubber boots must also be added. SECTION IX - HANDLING PRECAUTIONS LEAK AND SPILL PROCEDURES: Avoid all personal contact. Contain spill if possible. Wipe up or absorb on suitable material and shovel up. WASTE DISPOSAL: If this product becomes a waste it does not meet the requirements of a RCRA hazardous. Always dispose of according to all local, state, and federal laws and regulations. N.E.=Not Established N.A.=Not Applicable MSDS for BF-8L...Page 3 • HANDLING &SPECIAL EQUIPMENT: Do not get in eyes, on skin or clothing. Avoid breathing vapor or mist. Keep container closed. Use only in well-ventilated area. Wash thoroughly after handling. STORAGE REQUIREMENTS: Minimum feasible handling temperatures should be maintained. Periods of exposure to high temperatures should be minimized. Water contamination should be avoided. SECTION X - REGULATORY INFORMATION SHIPPING INFORMATION PROPER SHIPPING NAME: Ethanolamine solutions HAZARD CLASS: 8 UN/NA NUMBER: UN 2491 PACKING GROUP W/"PG": PG III SUBSIDIARY RISK: N.A. REPORTABLE QUANTITY(RQ): N.A. EMERGENCY RESPONSE GUIDE#: 153 ENVIRONMENTAL INFORMATION SARA TITLE III SECTION 302/304 This product does not contain ingredients listed as an Extremely Hazardous Substance. SECTION 311/312 Immediate, Delayed SECTION 313 This product does not contain ingredients (at a level of 1%or greater)on the List of Toxic Chemicals. OTHER REGULATORY INFORMATION TSCA INVENTORY: All of the components in this appear on the TSCA inventory. CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore,vendee assumes the risk in his use of the material. Revision: 1 Status: Approved&Released MSDS Revision History: Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document Today 2 I Telephone number 08/04/00 N.E.=Not Established N.A.=Not Applicable MSDS for BF-8L...Page 4 • i N.E.=Not Established N.A.=Not Applicable MSDS for BF-8L...Page 5 I BJ SERVICES COMPANY Region: MATERIAL SAFETY DATA SHEET USA SECTION I - GENERAL INFORMATION PRODUCT NAME: Clay Master 5C ITEM NUMBER : 499808 CHEMICAL DESCRIPTION: Quaternary polyamines PRODUCT USE: Clay control SUPPLIER: BJ Services Company ADDRESS: 5500 Northwest Central Dr Houston TX 77092 EMERGENCY TELEPHONE NUMBER (800)424-9300 for CHEMTREC (202)483-7616 Alaska and International PREPARED BY: BJ Services Environmental Group (281)351-8131 DATE PREPARED: August 4, 2000 Supersedes:December 19, 1995 HMIS HAZARD INDEX HEALTH: 1 FLAMMABILITY: 1 REACTIVITY: 0 PERSONAL PROTECTION: d SECTION II - HAZARDOUS COMPONENTS HAZARDOUS COMPONENTS CAS# PERCENT HAZARD No hazardous ingredients N.A. N.A. N.A. SECTION III - FIRE AND EXPLOSION HAZARD DATA FLASHPOINT(METHOD): >200°F (PMCC) UPPER EXPLOSION LIMIT(% BY VOL): N.E. LOWER EXPLOSION LIMIT(% BY VOL): N.E. AUTO-IGNITION TEMPERATURE: N.E. EXTINGUISHING MEDIA: Dry chemical, CO2,water spray or regular foam SPECIAL FIRE FIGHTING PROCEDURES: This material may burn, but does not readily ignite. Move container from fire area if you can do so without risk. Apply cooling water to sides of containers that are exposed to flames until well after fire is out. Stay away from ends of containers. EXPLOSION DATA: None listed HAZARDOUS COMBUSTION PRODUCTS: May form oxides of carbon, nitrogen, and chlorine N.E.=Not Established N.A.=Not Applicable MSDS for Clay Master-5C...Page 1 • • SECTION IV - HEALTH HAZARD DATA PRIMARY ROUTES OF ENTRY: Eye and skin contact, inhalation ACUTE OVEREXPOSURE EFFECTS: SKIN CONTACT: May cause mild irritation SKIN ABSORPTION: No effects listed EYE CONTACT: May cause mild irritation INHALATION: May cause mild irritation INGESTION: May cause nausea CHRONIC OVEREXPOSURE EFFECTS: No effects listed EXPOSURE LIMITS: HAZARDOUS COMPONENT ACGIH TLV OSHA PEL No hazardous ingredients N.A. N.A. CARCINOGENICITY, REPRODUCTIVE EFFECTS: Not listed as carcinogenic- IARC, NTP, or OSHA TERATOGENICITY, MUTAGENICITY: No effects listed TOXICITY STUDIES: LD(50) N.E. LC(50) N.E. SECTION V - FIRST AID PROCEDURES FOR EYES: Immediately flush with running water for at least 15 minutes. FOR SKIN: Wash with soap and water, removing clothing if contaminated FOR INHALATION: Remove to fresh air. If breathing is labored, give oxygen. If breathing has stopped, give artificial respiration. Keep person warm, quiet and get medical attention. FOR INGESTION: DO NOT INDUCE VOMITING. Give large amounts of water or milk to drink. Consult a physician for further instructions. SECTION VI - PHYSICAL DATA APPEARANCE AND ODOR: Clear amber liquid SPECIFIC GRAVITY: 1.144 VAPOR PRESSURE: N.E. VAPOR DENSITY(air=1): N.E. EVAPORATION RATE: N.E. BOILING POINT: N.E. FREEZING POINT: N.E. SOLUBILITY IN H20: Soluble pH: 7 N.E.=Not Established N.A.=Not Applicable MSDS for Clay Master-5C...Page 2 I • SECTION VII - REACTIVITY DATA CHEMICAL STABILITY: Stable INCOMPATIBLE MATERIALS: Strong oxidizers HAZARDOUS POLYMERIZATION: Does not polymerize HAZARDOUS DECOMPOSITION PRODUCTS: Oxides of carbon, nitrogen, and chlorine SECTION VIII - SPECIAL/PERSONAL PROTECTION VENTILATION: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air movement. RESPIRATORY PROTECTION: None required under normal conditions. Use SCBA when entering tanks. PROTECTIVE GLOVES: Chemically resistant/non-slip EYE PROTECTION: Chemical safety goggles/safety glasses OTHER PROTECTIVE EQUIPMENT: Coveralls, splash aprons, eyewash bottles or other rinsing equipment should be easily accessible. SECTION IX - HANDLING PRECAUTIONS LEAK AND SPILL PROCEDURES: Stop leak if you can do it without risk. Take up with sand or other noncombustible absorbent material and place in DOT approved containers. WASTE DISPOSAL: If this product becomes a waste it does not meet the requirements of a RCRA hazardous waste. Always dispose of according to all local/state/and federal regulations. HANDLING&SPECIAL EQUIPMENT: Clean up spills promptly.Wash contaminated clothing. STORAGE REQUIREMENTS: No special recommendations. SECTION X- REGULATORY INFORMATION SHIPPING INFORMATION PROPER SHIPPING NAME: Not DOT Regulated HAZARD CLASS: N.A. UN/NA NUMBER: N.A. PACKING GROUP W/"PG": N.A. SUBSIDIARY RISK: N.A. REPORTABLE QUANTITY(RQ): N.A. EMERGENCY RESPONSE GUIDE#: N.A. ENVIRONMENTAL INFORMATION SARA TITLE III SECTION 302/304 This product does not contain ingredients listed as an Extremely Hazardous Substance. SECTION 311/312 Immediate N.E.=Not Established N.A.=Not Applicable MSDS for Clay Master-5C...Page 3 • • SECTION 313 This product does not contain ingredients (at a level of 1%or greater) on the List of Toxic Chemicals. OTHER REGULATORY INFORMATION TSCA INVENTORY: All of the components in this appear on the TSCA inventory. CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore,vendee assumes the risk in his use of the material. Revision: 1 Status: Approved&Released MSDS Revision History: Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document Today 2 I Telephone number 08/04/00 N.E.=Not Established N.A.=Not Applicable MSDS for Clay Master-5C...Page 4 • BJ SERVICES COMPANY CANADA Region: MATERIAL SAFETY DATA SHEET Canada SECTION I - PRODUCT INFORMATION Product Name: Enzyme G Solutions Product Use: Frac gel breaker. Chemical Family: Enzyme solution. Supplier: BJ Services Company Canada 1300, 801 -6th Avenue SW Calgary,Alberta, Canada T2P 4E1 Phone: (403)531-5151 IN CASE OF EMERGENCY CALL: (403) 531-5151 (24 hrs) SECTION II - HAZARDOUS INGREDIENTS Ingredient % ACGIH TWA: ACGIH STEL: CAS# Non-hazardous 100 NA NA NA=Not available SECTION III - PHYSICAL AND CHEMICAL PROPERTIES PHYSICAL STATE: Liquid SPECIFIC GRAVITY: — 1.0 COLOR: Clear,colorless to pale yellow VAPOR PRESSURE: Not available ODOR: None VAPOR DENSITY(air=1): Not available ODOR THRESHOLD: Not applicable EVAPORATION RATE: Not available FREEZING POINT: —0°C BOILING POINT: — 100°C SOLUBILITY IN WATER: Miscible. pH: 7 COEFFICIENT OF WATER/OIL DISTRIBUTION: > 1 SECTION IV - FIRE AND EXPLOSION DATA NFPA-FLAMMABILITY CODE: 0 FLASHPOINT(METHOD): None LOWER EXPLOSION LIMIT(%v/v): Not applicable UPPER EXPLOSION LIMIT(%v/v): Not applicable AUTO-IGNITION TEMPERATURE: Not applicable MSDS for Enzyme G Solutions...Page 1 UNCONTROLLED COPY i • SPECIAL HAZARDS: None. EXTINGUISHING MEDIA: Use appropriate media for surrounding fire. SPECIAL FIREFIGHTING PROCEDURES: None required; however,when fighting chemical fires, self-contained breathing apparatus and protective clothing is recommended. HAZARDOUS COMBUSTION PRODUCTS: None. SENSITIVITY TO STATIC DISCHARGE: No SENSITIVITY TO MECHANICAL IMPACT: No SECTION V -STABILITY AND REACTIVITY STABILITY: Stable under normal conditions of use. INCOMPATIBILITY/CONDITIONS OF REACTIVITY: None known. HAZARDOUS THERMAL DECOMPOSITION PRODUCTS: None known. HAZARDOUS POLYMERIZATION: Will not occur. SECTION VI -TOXICOLOGICAL PROPERTIES PRIMARY ROUTES OF EXPOSURE: Eye contact. Skin contact. ACUTE OVEREXPOSURE EFFECTS: INHALATION: Not a likely exposure route. INGESTION: Not a likely exposure route. Product has low oral toxicity. EYE CONTACT: May cause mild eye irritation. SKIN CONTACT: Prolonged contact may cause mild irritation. CHRONIC EFFECTS: None known. SENSITIZATION: Not known. CARCINOGENICITY: None of the components of this product have been listed as carcinogenic by IARC, NTP or OSHA. IARC- International Agency for Research on Cancer NTP-National Toxicology Program OSHA- Occupational Safety&Health Administration(US) MSDS for Enzyme G Solutions...Page 2 UNCONTROLLED COPY • MUTAGENICITY: Not known. REPRODUCTIVE TOXICITY: Not known. SYNERGISTIC PRODUCTS: None known. SECTION VII - PREVENTATIVE MEASURES SPECIFIC ENGINEERING CONTROLS: Use only in well ventilated area. PERSONAL PROTECTIVE EQUIPMENT: Chemical resistant goggles. Rubber gloves. Coveralls. HANDLING: Wear specified protective equipment. STORAGE REQUIREMENTS: Protect from freezing. ACTION TO BE TAKEN IF MATERIAL IS RELEASED OR SPILLED: Wear specified protective equipment. Small spills - Cover spill with absorbent material. Scoop absorbed material into a suitable container for disposal. Large spills - Dike to contain. Recover product to suitable containers or vessel for reuse, if possible, or for disposal. WASTE DISPOSAL: Consult local waste authorities for direction and/or approvals prior to disposal. SPECIAL SHIPPING INFORMATION: Comply with all local,federal and international transportation regulations. SECTION VIII - FIRST AID MEASURES INHALATION: If inhaled, remove from area to fresh air. Get medical attention if respiratory irritation develops or if breathing becomes difficult. INGESTION: Rinse mouth out with water. Drink plenty of water. If large quantities were ingested, seek medical advice. EYES: Flush eyes with plenty of water and get medical attention if irritation persists. SKIN: Flush skin with water. Remove contaminated clothing and launder before reuse. SECTION IX - CLASSIFICATION SHIPPING NAME: NOT RESTRICTED UN NUMBER: NA TDGR NA MSDS for Enzyme G Solutions...Page 3 UNCONTROLLED COPY • • AI R-ICAO/IATA NA SEA-IMO/IMDG NA WHMIS Not controlled SECTION X - PREPARATION INFORMATION ISSUE DATE: 19/11/2003 SUPERSEDES: 02/11/2000 REVISIONS: General review. PREPARED BY: Chemical Technology Centre REFERENCES: Suppliers' Literature. Dangerous Properties of Industrial Materials, 9th ed.; N. Irving Sax, 1996. CCINFOdisc (Core Collection) , Canadian Centre for Occupational Health and Safety, 2001. International Marine Dangerous Goods Code, 2002 Edition, International Maritime Organisation, 2002. Dangerous Goods Regulations, 43rd ed., International Air Transport Association, 2002. TDG Clear Language Regulations, as published in the Canada Gazette Part II, August 2001. Revision: 2 Status: Approved&Released MSDS Revision History: Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document 02/11/00 2 N/A General review. 19/11/03 MSDS for Enzyme G Solutions...Page 4 UNCONTROLLED COPY • LA. BJ SERVICES COMPANY on: egi MATERIAL SAFETY DATA SHEET Re SECTION I - GENERAL INFORMATION PRODUCT NAME: Flo-Back 30 ITEM NUMBER: 488255, 488327 CHEMICAL DESCRIPTION: Surfactant PRODUCT USE: Surface tension reducer, surfactant SUPPLIER: BJ Services Company ADDRESS: 5500 Northwest Central Dr Houston TX 77092 EMERGENCY TELEPHONE NUMBER (800)424-9300 for CHEMTREC (703)527-3887 Alaska and International PREPARED BY: BJ Services Environmental Group (281)351-8131 DATE PREPARED: April 30, 2004 Supersedes: August 31, 2000 HMIS HAZARD INDEX HEALTH: 1 FLAMMABILITY: 0 REACTIVITY: 0 PERSONAL PROTECTION: b SECTION II - HAZARDOUS COMPONENTS HAZARDOUS COMPONENTS CAS# PERCENT HAZARD No hazardous ingredients N.A. N.A. N.A. SECTION III - FIRE AND EXPLOSION HAZARD DATA FLASHPOINT(METHOD): None UPPER EXPLOSION LIMIT(% BY VOL): N.E. LOWER EXPLOSION LIMIT(% BY VOL): N.E. AUTO-IGNITION TEMPERATURE: N.E. EXTINGUISHING MEDIA: This product is not expected to burn unless all the water is boiled away. Use media appropriate for surrounding fire. SPECIAL FIRE FIGHTING PROCEDURES: Use water to cool fire exposed containers. EXPLOSION DATA: None HAZARDOUS COMBUSTION PRODUCTS: Carbon monoxide during combustion N.E.=Not Established N.A.=Not Applicable MSDS for Flo-Back 30...Page I • SECTION IV - HEALTH HAZARD DATA PRIMARY ROUTES OF ENTRY: Skin and eye contact ACUTE OVEREXPOSURE EFFECTS: SKIN CONTACT: Brief contact may cause mild irritation. Prolonged contact may cause severe irritation and dermatitis. SKIN ABSORPTION: Not absorbed by skin. EYE CONTACT: May cause slight to moderate irritation. INHALATION: Not expected to pose an inhalation hazard. INGESTION: May cause irritation to the membranes of the mouth, throat, and gastrointestional tract. Nausea, vomiting, cramps and diarrhea may occur. CHRONIC OVEREXPOSURE EFFECTS: None known EXPOSURE LIMITS: HAZARDOUS COMPONENT ACGIH TLV OSHA PEL No hazardous ingredients N.E. N.E. CARCINOGENICITY, REPRODUCTIVE EFFECTS: Not listed as carcinogenic- IARC, NTP, or OSHA TERATOGENICITY, MUTAGENICITY: No effects listed. TOXICITY STUDIES: LD(50) N.E. LC(50) N.E. SECTION V - FIRST AID PROCEDURES FOR EYES: Immediately flush with plenty of water for at least 15 minutes. If irritation persists, contact a physician. FOR SKIN: Flush skin with water or wash with mild soap and water if available. If irritation persists, contact a physician. FOR INHALATION: Remove to fresh air. If breathing has stopped, give artificial respiration. Keep person warm, quiet and get medical attention. FOR INGESTION: Do not induce vomiting. If vomiting occurs spontaneously, keep victim's head below hips to prevent aspiration into the lungs. Give large quantities of water to dilute. Never give anything by mouth to an unconscious or convulsing person. Seek immediate medical attention. SECTION VI - PHYSICAL DATA APPEARANCE AND ODOR: Pale yellow liquid with mild odor N.E.=Not Established N.A.=Not Applicable MSDS for Flo-Back 30...Page 2 • S SPECIFIC GRAVITY: 1.16 VAPOR PRESSURE: N.E. VAPOR DENSITY(air=1): N.E. EVAPORATION RATE: N.E. BOILING POINT: Approx.235°F FREEZING POINT: < 0°F SOLUBILITY IN H20: Complete pH: N.E. SECTION VII - REACTIVITY DATA CHEMICAL STABILITY: Stable INCOMPATIBLE MATERIALS: Strong oxidizing agents HAZARDOUS POLYMERIZATION: Does not polymerize HAZARDOUS DECOMPOSITION PRODUCTS: Carbon monoxide during combustion SECTION VIII - SPECIAUPERSONAL PROTECTION VENTILATION: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air movement. RESPIRATORY PROTECTION: Not normally required under conditions of normal use. PROTECTIVE GLOVES: Rubber or neoprene EYE PROTECTION: Goggles OTHER PROTECTIVE EQUIPMENT: Eyewash bottles or other rinsing equipment should be easily accessible. SECTION IX - HANDLING PRECAUTIONS LEAK AND SPILL PROCEDURES: Dike or contain spill to prevent material from entering waterways. Pump large spills into salvage containers. Soak up residue or small spills with absorbent pads, clay, or dirt and place in salvage containers. WASTE DISPOSAL: If this product becomes a waste it does not meet the requirements of a RCRA hazardous waste. Always dispose of according to local/state/federal regulations. HANDLING&SPECIAL EQUIPMENT: Do not get in eyes, on skin or clothing. Do not take internally. STORAGE REQUIREMENTS: Keep container closed when not in use. Store drums with the bung up. Carefully vent container before removing bung. Wash thoroughly after handling. SECTION X - REGULATORY INFORMATION SHIPPING INFORMATION PROPER SHIPPING NAME: Not DOT Regulated HAZARD CLASS: N.A. UN/NA NUMBER: N.A. PACKING GROUP W/"PG": N.A. SUBSIDIARY RISK: N.A. REPORTABLE QUANTITY(RQ): N.A. EMERGENCY RESPONSE GUIDE#: N.A. N.E.=Not Established N.A.=Not Applicable MSDS for Flo-Back 30...Page 3 • . ENVIRONMENTAL INFORMATION SARA TITLE III SECTION 302/304 This product does not contain ingredients listed as an Extremely Hazardous Substance. SECTION 311/312 N.A. SECTION 313 This product does not contain ingredients (at a level of 1% or greater)on the List of Toxic Chemicals. OTHER REGULATORY INFORMATION TSCA INVENTORY: All of the components in this appear on the TSCA inventory. CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore,vendee assumes the risk in his use of the material. Revision: 1 Status: Approved&Released MSDS Revision History: Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document Today 2 I Dropped experimental designation 11-13-98 3 I Telephoone number 08/31/00 4 I Added item#,changed phone#for Intl Chemtrec 04/30/04 N.E.=Not Established N.A.=Not Applicable MSDS for Flo-Back 30...Page 4 • Li? BJ SERVICES COMPANY Region: MATERIAL SAFETY DATA SHEET USA 1 PRODUCT AND COMPANY IDENTIFICATION Product Name: GLFC-5D Item Number: 398373 Product Use: Gellant-Water Supplier: BJ Services Company 5500 Northwest Central Dr Houston,TX 77092 (281)351-8131 IN CASE OF EMERGENCY CALL: (800) 424-9300 for CHEMTREC (703) 527-3887 for International HMIS HAZARD INDEX HEALTH: 1 FLAMMABILITY: 1 REACTIVITY: 0 PERSONAL PROTECTION: h 2 COMPOSITION/INFORMATION ON INGREDIENTS Hazardous Component I CAS# I Percent I Hazard Alkanes/Alkenes Multiple I 45-50 I Irritant Guar gum I 009000-30-0 I 45-50 I Irritant 3 HAZARDS IDENTIFICATION PRIMARY ROUTES OF EXPOSURE: Inhalation. Skin contact. Eye contact. ACUTE OVEREXPOSURE EFFECTS: INHALATION: May cause central nervous system depression. INGESTION: Product has a low order of acute oral toxicity,but minute amounts aspirated into the lungs during ingestion may cause severe pulmonary injury or death. EYE CONTACT: May cause mild eye irritation. SKIN CONTACT:May cause mild skin irritation. Prolonged contact may cause drying of skin. EXPOSURE LIMITS: HAZARDOUS COMPONENT IACGIH TLV I OSHA PEL I LC50(inhalation) I LD50(oral) I Alkanes/Alkenes 5 mg/m3 5 mg/m3 NA NA Guar gum NA NA NA 6770 mg/kg rat MSDS for GLFC-5D Page 1 • • 4 FIRST AID MEASURES INHALATION: If inhaled, remove to fresh air. If not breathing give artificial respiration, preferably mouth-to-mouth. If breathing is difficult give oxygen.Only trained personnel should administer oxygen. Get medical attention. INGESTION: DO NOT induce vomiting. Get medical attention! If vomiting occurs, keep head lower than hips to prevent aspiration. EYES: In case of contact, immediately flush eyes with plenty of water for at least 15 minutes and get medical attention. SKIN: Flush skin with water or soap and water, if available, for at least 15 minutes. Remove contaminated clothing and shoes.Seek medical attention if irritation persists. 5 FIRE FIGHTING MEASURES FLASHPOINT(METHOD): >200°F(SFCC) LOWER EXPLOSION LIMIT(%v/v): Not applicable/available UPPER EXPLOSION LIMIT(%v/v): Not applicable/available AUTO-IGNITION TEMPERATURE: Not available/applicable SPECIAL HAZARDS: None. EXTINGUISHING MEDIA: On small fires,dry chemical,dry sand, or CO2 may also be effective in large quantities. For large fire,water spray or fog. Foam. SPECIAL FIREFIGHTING PROCEDURES: Cool exposed containers with water spray. Fire-fighters should wear self-contained breathing apparatus and full protective clothing when fighting chemical fires. HAZARDOUS COMBUSTION PRODUCTS: Oxides of carbon. 6 ACCIDENTAL RELEASE MEASURES Dike to contain. Cover spill with absorbent material. Scoop absorbed material into a suitable container for disposal. 7 HANDLING AND STORAGE HANDLING: Avoid contact with skin and eyes. Do not inhale vapors. STORAGE REQUIREMENTS: Keep container closed when not in use. Keep away from ignition sources. 8 EXPOSURE CONTROLS/PERSONAL PROTECTION SPECIFIC ENGINEERING CONTROLS: Adequate ventilation should be provided to keep concentrations below acceptable exposure limits. PERSONAL PROTECTIVE EQUIPMENT: Appropriate respiratory protection shall be worn when applied engineering controls are not adequate to protec against inhalation exposure. Safety glasses. Neoprene gloves. Rubber gloves. 9 PHYSICAL AND CHEMICAL PROPERTIES PHYSICAL STATE: Liquid COLOR: Light brown,Tan ODOR: Mild Hydrocarbon MSDS for GLFC-5D Page 2 i • ODOR THRESHOLD: Not available/applicable SPECIFIC GRAVITY: 1.00-1.01 VAPOR PRESSURE: Not available/applicable VAPOR DENSITY(air= 1): Not available/applicable EVAPORATION RATE: Not available/applicable BOILING POINT: Not available/applicable FREEZING POINT: Not available/applicable pH: Not available/applicable VISCOSITY(F): Not available/applicable SOLUBILITY IN WATER: Insoluble 10 STABILITY AND REACTIVITY STABILITY: Stable. INCOMPATIBILITY/CONDITIONS OF REACTIVITY: Strong oxidizers. HAZARDOUS THERMAL DECOMPOSITION PRODUCTS: Carbon monoxide.Carbon dioxide. HAZARDOUS POLYMERIZATION: Will not occur. 11 TOXICOLOGICAL PROPERTIES CHRONIC EFFECTS: None known. SENSITIZATION: Not known. CARCINOGENICITY: None of the components of this product have been listed as carcinogenic by IARC, NTP or OSHA. (IARC- International Agency for Research on Cancer)(NTP-National Toxicology Program)(OSHA-Occupational Safety& Health Administration(US)) MUTAGENICITY: Not known. REPRODUCTIVE TOXICITY: Not known. 12 ECOLOGICAL INFORMATION No specific information available 13 DISPOSAL CONSIDERATIONS WASTE DISPOSAL: As local regulations may vary;all waste must be disposed/recycled/reclaimed in accordance with federal, state, and local environmental control regulations. MSDS for GLFC-5D Page 3 • 14 TRANSPORT INFORMATION LAND TRANSPORT(DOT) Proper Shipping Name: NOT RESTRICTED UN No.: NA AIR TRANSPORT(ICAO/IATA) Proper Shipping Name: NOT RESTRICTED UN/ID No.: NA MARINE TRANSPORT(IMDG/IMO) Proper Shipping Name: NOT RESTRICTED UN/ID No.: NA 15 REGULATORY INFORMATION SARA TITLE III: SECTION 302/304 This product does not contain substances listed in Appendix A and B as an Extremely Hazardous Substance. SECTION 311/312 Immediate SECTION 313 This product does not contain ingredients(at a level of 1%or greater)on the List of Toxic Chemicals. TSCA INVENTORY: The substances in this product are included on or exempted from the TSCA 8(b)Inventory (40 CFR 710) CALIFORNIA PROP 65: This product does not contain substances which require warning under California Proposition 65. 16 OTHER INFORMATION ISSUE DATE: 12/14/2004 PREPARED BY: BJ SERVICES ENVIRONMENTAL GROUP REFERENCES: Suppliers' Literature. Suspect Chemicals Sourcebook Guide to Occupational Exposure Values-2004,American Conference of Governmental Industrial Hygienists,2004. Dangerous Properties of Industrial Materials,9th ed.; N. Irving Sax, 1996. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet Additionally,vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore,vendee assumes the risk in his use of the material. Revision: 1 Status: Approved&Released MSDS Revision History: Revision: Sec/Para Changed Change Made: Date 1 N/A Initial Issue of Document Today MSDS for GLFC-5D Page 4 • MSDS for GLFC-5D Page 5 • BJ SERVICES COMPANY Region: MATERIAL SAFETY DATA SHEET USA SECTION I - GENERAL INFORMATION PRODUCT NAME: XLW-32 ITEM NUMBER: 499630,499796 CHEMICAL DESCRIPTION: Boric oxide in methanol PRODUCT USE: Crosslinker SUPPLIER: BJ Services Company ADDRESS: 5500 Northwest Central Dr Houston TX 77092 EMERGENCY TELEPHONE NUMBER (800)424-9300 for CHEMTREC (202)483-7616 Alaska and International PREPARED BY: BJ Services Environmental Group (281)351-8131 DATE PREPARED: November 10, 2000 Supersedes: June 14, 1999 HMIS HAZARD INDEX HEALTH: 2 FLAMMABILITY: 3 REACTIVITY: 0 PERSONAL PROTECTION: b SECTION II - HAZARDOUS COMPONENTS HAZARDOUS COMPONENTS CAS# PERCENT HAZARD Methanol 67-56-1 < 90 Flammable Boric oxide 1303-86-2 <20 Toxic SECTION III - FIRE AND EXPLOSION HAZARD DATA FLASHPOINT(METHOD): 68°F (TCC) UPPER EXPLOSION LIMIT(% BY VOL): N.E. LOWER EXPLOSION LIMIT(% BY VOL): N.E. AUTO-IGNITION TEMPERATURE: N.E. EXTINGUISHING MEDIA: CO2, dry chemical, water spray/fog, or foam. Use water to keep containers cool. Isolate "fuel" supply from fire. Contain fire fighting liquids for proper disposal. SPECIAL FIRE FIGHTING PROCEDURES: Do not enter confined fire space without proper personal protective equipment including NIOSH approved self-contained breathing apparatus with full facepiece operated in the positive pressure demand mode. Do not inject a solid stream of water or foam into hot, burning pools; this may cause splattering and increase fire N.E.=Not Established N.A.=Not Applicable MSDS for XLW-32...Page 1 • S intensity. Evacuate personnel to a safe area. Keep unnecessary people away. EXPLOSION DATA: This material is volatile and readily gives off vapors that may travel along the ground or be moved by ventilation and ignited by pilot lights, other flames, sparks, heaters, smoking, electrical motors, static discharge, or other ignition sources at locations distant from material handling point. Never use welding or cutting torch on or near drum (even empty) because product (even just residue) can ignite explosively. Containers may explode from internal pressure if confined to fire. Keep containers cool. Keep unnecessary people away. HAZARDOUS COMBUSTION PRODUCTS: Smoke, carbon monoxide and carbon dioxide SECTION IV - HEALTH HAZARD DATA PRIMARY ROUTES OF ENTRY: Skin and eye contact, inhalation ACUTE OVEREXPOSURE EFFECTS: SKIN CONTACT: May produce skin irritation, redness, peeling, defatting and dermatitis. SKIN ABSORPTION: Exposure to this material can result in absorption through skin causing a health hazard. EYE CONTACT: May cause moderate irritation, including burning sensation, tearing, redness, swelling and blurred vision. INHALATION: Overexposure may cause coughing, shortness of breath, dizziness, intoxication and collapse. Can cause nasal and respiratory irritation, weakness, fatigue, headache, and possible unconsciousness and even death. INGESTION: Can cause gastrointestinal irritation, acidosis, nausea, vomiting, diarrhea, ocular toxicity ranging from diminished visual capacity to complete blindness, and death. CHRONIC OVEREXPOSURE EFFECTS: May cause liver abnormalities, kidney damage, eye damage, lung damage, brain damage and nervous system damage. EXPOSURE LIMITS: HAZARDOUS COMPONENT ACGIH TLV OSHA PEL Methanol N.E. 200 mg/m3 Boric oxide N.E. 10 mg/m3 CARCINOGENICITY, REPRODUCTIVE EFFECTS: Not listed as carcinogenic- IARC, NTP, or OSHA TERATOGENICITY, MUTAGENICITY: No effects listed TOXICITY STUDIES: LD(50) N.E. N.E.=Not Established N.A.=Not Applicable MSDS for XLW-32...Page 2 S LC(50) N.E. SECTION V - FIRST AID PROCEDURES FOR EYES: Flush eyes immediately with large amounts of water for at least 15 minutes. Lift lower and upper lids occasionally. Get medical attention. o pP Y FOR SKIN: Wash with soap and water. Remove contaminated clothing and launder contaminated clothing before reuse. Get medical attention if redness or irritation develops. FOR INHALATION: Remove to fresh air. If breathing is labored, give oxygen. If breathing has stopped, give artificial respiration. Keep person warm, quiet and get medical attention. FOR INGESTION: Call a physician immediately. Give victim a glass of water. DO NOT induce vomiting unless instructed by a physician or poison control center. Never give anything by mouth to an unconscious person. SECTION VI - PHYSICAL DATA APPEARANCE AND ODOR: Clear, colorless liquid; alcohol odor SPECIFIC GRAVITY: 0.885 VAPOR PRESSURE: N.E. VAPOR DENSITY(air=1): N.E. EVAPORATION RATE: N.E. BOILING POINT: N.E. FREEZING POINT: N.E. SOLUBILITY IN H20: Complete pH: N.A. SECTION VII - REACTIVITY DATA CHEMICAL STABILITY: Stable INCOMPATIBLE MATERIALS: Avoid contact with strong oxidizing agents, strong alkalies, and strong mineral acids. HAZARDOUS POLYMERIZATION: Does not polymerize HAZARDOUS DECOMPOSITION PRODUCTS: Thermal decomposition or combustion may produce smoke, carbon monoxide and carbon dioxide. SECTION VIII -SPECIAUPERSONAL PROTECTION VENTILATION: The use of mechanical ventilation is recommended whenever this product is used in a confined space. Where engineering controls are not feasible, assure use is in an area where there is natural air movement. RESPIRATORY PROTECTION: If workplace exposure limits of product or any component is exceeded, an NIOSH/MSHA approved air supplied respirator is advised in absence of proper environmental control. OSHA regulations also permit other NIOSH/MSHA respirators (negative pressure organic vapor type) under specified conditions. Engineering or administrative controls should be implemented to reduce exposure. PROTECTIVE GLOVES: Neoprene, nitrile, polyvinyl alcohol (PVA), polyvinyl chloride (PVC) EYE PROTECTION: Chemical splash goggles or face shield in compliance with N.E.=Not Established N.A.=Not Applicable MSDS for XLW-32...Page 3 • • OSHA regulations is advised; however OSHA regulations also permits safety glasses under certain conditions. The use of contact lenses is not recommended. OTHER PROTECTIVE EQUIPMENT: Eyewash bottles or other rinsing equipment should be easily accessible. SECTION IX - HANDLING PRECAUTIONS LEAK AND SPILL PROCEDURES: Eliminate sources of ignition. Persons not wearing suitable personal protective equipment should be excluded from area of spill until clean-up has been completed. Shut off source of spill if possible to do so without hazard. Prevent material from entering sewers or watercourses. Provide adequate ventilation. Contain spilled materials with sand or earth. Recover undamaged material for reuse or reclamation. Place all collected material and spill absorbents into DOT approved containers. WASTE DISPOSAL: If this material becomes a waste it does meet the requirements of a RCRA hazardous waste with the waste code D001.Always dispose of according to all local/state/and federal regulations. HANDLING & SPECIAL EQUIPMENT: Avoid contact with eyes, skin, or clothing. Avoid breathing vapors or mist. Keep away from heat sparks, and open flames and never use a cutting torch on or near container or explosion may result. Vapors may travel to areas away from the work site and ignite. Do not transfer to improperly marked container. Do not use pressure to empty container. Use with adequate ventilation. Wash thoroughly after handling. Containers should be grounded and bonded to receiving container when being emptied. STORAGE REQUIREMENTS: Keep container closed and away from heat, sparks, and open flames. SECTION X - REGULATORY INFORMATION SHIPPING INFORMATION PROPER SHIPPING NAME: Flammable liquids, n.o.s. (contains methanol) HAZARD CLASS: 3 UN/NA NUMBER: UN1993 PACKING GROUP W/"PG": PG II SUBSIDIARY RISK: N.A. REPORTABLE QUANTITY(RQ): N.A. EMERGENCY RESPONSE GUIDE#: 128 ENVIRONMENTAL INFORMATION SARA TITLE III SECTION 302/304 This product does not contain ingredients listed as an Extremely Hazardous Substance. SECTION 311/312 Immediate, Fire, Delayed SECTION 313 This product does contain ingredients(at a level of 1%or greater) on the List of Toxic Chemicals: N.E.=Not Established N.A.=Not Applicable MSDS for XLW-32...Page 4 • • Methanol 67-56-1 <90% OTHER REGULATORY INFORMATION TSCA INVENTORY: All of the components in this appear on the TSCA inventory. CALIFORNIA PROP 65: None of the chemicals on the current Proposition 65 list are known to be present in this product. The information contained herein is based on data considered accurate. However, no warranty is expressed or implied regarding the accuracy of these data or the results to be obtained from the use thereof. Vendor assumes no responsibility for injury to vendee or third persons proximately caused by the material if reasonable safety procedures are not adhered to as stipulated in the data sheet. Additionally, vendor assumes no responsibility for injury to vendee or third persons proximately caused by abnormal use of the material even if reasonable safety procedures are followed. Furthermore,vendee assumes the risk in his use of the material. Revision: 1 Status: Approved&Released MSDS Revision History: Revision: Sec/Para Changed Change Made: Date 1 NIA Initial Issue of Document Today 2 X RQ is N.A. 6-14-99 3 I Telephone number 11/10/00 N.E.=Not Established N.A.=Not Applicable MSDS for XLW-32...Page 5 • . BAINIEs Material Safety Data Sheet Baker Petro lite Section 1. Chemical Product and Company Identification Product Name X-CIDE®207 INDUSTRIAL MICROBIOCIDE Code XC207 Supplier Baker Petrolite Version 2.0 A Baker Hughes Company 12645 W.Airport Blvd. (77478) P.O. Box 5050 Sugar Land,TX 77487-5050 For Product Information/MSDSs Call: 800-231-3606 (8:00 a.m.-5:00 p.m. cst, Monday-Friday)281-276-5400 Material Uses Microbiocide Effective Date 7/16/2003 24 Hour Emergency CHEMTREC 800-424-9300(U.S.24 hour) Print Date 7/16/2003 Numbers Baker Petrolite 800-231-3606(North America 24 hour) CANUTEC 613-996-6666(Canada 24 hours) CHEMTREC Int'l 01-703-527-3887(International 24 hour) National Fire Protection Flammability Association(U.S.A.) Health 0 Reactivity Co. Specific Hazard Section 2. Composition and Information on Ingredients Name CAS# %by Weight Exposure Limits 1)5-chloro-2-methyl-4-isothiazolin-3-one 26172-55-4 5-10 TWA:0.076 STEL:0.23 (mg/m3) from Manufacturer. 2)2-Methyl-4-isothiazolin-3-one 2682-20-4 1-5 TWA: 1.5 STEL:4.5 (mg/m3) from Manufacturer. 3)Magnesium nitrate 10377-60-3 5-10 Not available. 4)Magnesium chloride 7786-30-3 1-5 Not available. 5)Diatomaceous earth,calcined 91053-39-3 30-60 TWA: 10 (mg/m3) from ACGIH(TLV) TWA:3 (mg/m3) from ACGIH (TLV)Respirable. TWA: 15 (mg/m3) from OSHA(PEL)Total. TWA: 5 (mg/m3) from OSHA(PEL)Respirable. 6)Crystalline silica:cristobalite 14464-46-1 0.1-1 TWA:0.05 (mg/m3) from ACGIH(TLV)Respirable. TWA:0.05 (mg/m3) from OSHA(PEL)Respirable. 7)Crystalline silica:Quartz(SiO2) 14808-60-7 0.1-1 TWA:0.05 (mg/m3) from ACGIH(TLV)Respirable. TWA:0.1 (mg/m3) from OSHA Respirable. The OSHA Exposure Limit for cristobalite has been revoked. The OSHA Exposure Limit for quartz has been revoked. Section 3. Hazards Identification Physical State and State:Granular.Solid.,Color: Tan. Red.,Odor: Mild. Appearance CERCLA Reportable Not applicable. Quantity Hazard Summary DANGER. May cause chronic effects. May be corrosive to eyes, skin and respiratory tract. Contains a component that may cause cancer. May cause skin sensitization(allergic reaction). Routes of Exposure Skin(Contact), Eyes, Inhalation. Potential Acute Health Effects Continued on Next Page X-CIDE®207 INDUSTRIAL MICROBIOCID Page:2/7 Eyes May be corrosive to the eyes. May cause eye burns and permanent eye injury. Skin May be corrosive. Skin contact may produce burns. Skin sensitizer. May cause allergic skin reactions with repeated exposure Inhalation May be irritating to lungs. Ingestion Not considered a likely route of exposure,however, may be corrosive if swallowed. Medical Conditions Exposure to this product may aggravate medical conditions involving the following: respiratory tract, aggravated by Exposure skin/epithelium,eyes. See Toxicological Information(section 11) Additional Hazard Not available. Identification Remarks Section 4. First Aid Measures Eye Contact Immediately flush eyes with plenty of water for at least 15 minutes, occasionally lifting the upper and lower eyelids. Get medical attention if irritation occurs. Skin Contact Remove contaminated clothing and shoes immediately.Wash affected area with soap and mild detergent and large amounts of water until no evidence of chemical remains (approximately 15-20 minutes). Get medical attention immediately. Inhalation Remove to fresh air. Oxygen may be administered if breathing is difficult. If not breathing, administer artificial respiration and seek medical attention. Get medical attention if symptoms appear. Ingestion Get medical attention immediately. If swallowed,do not induce vomiting unless directed to do so by medical personnel. Wash out mouth with water if person is conscious. Never induce vomiting or give anything by mouth to a victim who is unconscious or having convulsions. Notes to Physician Not available. Additional First Aid Not available. Remarks Section 5. Fire Fighting Measures Flammability of the Products lot regulated as flammable or combustible. OSHA Flammability Class Not available. Autoignition temperature Not available. Flash Points CLOSED CUP: Higher than 93.3°C(200°F).(SFCC) Flammable Limits L.E.L. Not available. U.E.L. Not available. Products of Combustion These products are carbon oxides (CO, CO2) Hydrogen chloride fumes. nitrogen oxides (NO, NO2...) Oxides of silicon. Sulfur oxides (SO2, SO3...) Oxides of magnesium. Aluminum oxides(AIOx) Oxides of iron.. Fire Hazards in Presence ofOpen Flames/Sparks/Static. Heat. Various Substances Fire Fighting Media In case of fire, use foam, dry chemicals, or CO2 fire extinguishers. Evacuate area and fight fire from a and Instructions safe distance. Water spray may be used to keep fire-exposed containers cool. Keep water run off out of sewers and public water ways. Protective Clothing(Fire) Do not enter fire area without proper personal protective equipment, including NIOSH approved self-contained breathing apparatus. Special Remarks on Fire Avoid temperature extremes. During a fire, irritating and highly toxic gases may be generated by thermal Hazards decomposition or combustion. Hazardous combustion products may include hydrogen chloride, carbon monoxide,carbon dioxide and oxides of nitrogen and sulfur. IContinued on Next Page • • IX-CIDE®207 INDUSTRIAL MICROBIOCID, Page: 3/7 Section 6.Accidental Release Measures Spill Put on appropriate personal protective equipment. Evacuate surrounding areas, if necessary. Vacuum or carefully scoop up spilled materials and place in an appropriate container for disposal. Waste must be disposed of in accordance with federal,state and local environmental control regulations. Other Statements Not applicable. Additional Accidental Not available. Release Measures Remarks Section 7. Handling and Storage Handling and Storage Put on appropriate personal protective equipment. Avoid contact with eyes, skin, and clothing. Avoid breathing vapors or dusts. Use only with adequate ventilation. Store in a dry, cool and well ventilated area. Keep away from incompatibles. Keep container tightly closed and dry. Additional Handling and Not available. Storage Remarks Section 8. Exposure Controls/Personal Protection Engineering Controls Provide exhaust ventilation or other engineering controls to keep the airborne concentrations of vapors or particles below their respective threshold limit value. Ensure that eyewash stations and safety showers are proximal to the work-station location. Personal Protection Personal Protective Equipment recommendations are based on anticipated known manufacturing and use conditions.These conditions are expected to result in only incidental exposure.A thorough review of the job tasks and conditions by a safety professional is recommended to determine the level of personal protective equipment appropriate for these job tasks and conditions. Eyes Chemical safety goggles. Use full face shield if splashes could occur. Body Wear long sleeves and chemical resistant apron to prevent repeated or prolonged skin contact. Respiratory Respirator use is not expected to be necessary under normal conditions of use. In poorly ventilated areas,emergency situations or if exposure levels are exceeded, use NIOSH approved full face respirator. Hands Chemical resistant gloves. Feet Chemical resistant boots or overshoes. Other informatior Nitrile gloves. Butyl rubber gloves. Protective Clothing (Pictograms) Pit Additional Exposure Contr Substance may be harmful if swallowed. In extreme cases(ingestion)may cause liver and/or kidney Remarks damage. Section 9. Typical Physical and Chemical Properties Physical State and Granular.Solid. Odor Mild. Appearance pH Not available. Color Tan. Red. Specific gravity Not available. Density Not available. Vapor Density >1 (Air= 1) Continued on Next Page • S Page:4/7 X-CIDE®207 INDUSTRIAL MICROBIOCID, P g Vapor Pressure Not Available or Not Applicable for Solids. Evaporation Rate Not Available or Not Applicable for Solids. VOC Not available. Viscosity Not available. Pour Point Not available. Solubility(Water) Dispersible Boiling Point Not available. Physical Chemical Bulk Density: 48.52 lb/cu.ft. (6.49 lb/gal or 0.7773 g/mL) Comments Section 10. Stability and Reactivity Stability and Reactivity The product is stable. Conditions of Instability Not available. Incompatibility with VariousDxidizing material. Substances Hazardous Decomposition Not applicable. Products Hazardous Polymerization Hazardous polymerization is not expected to occur. Special Stability& Not available. Reactivity Remarks Section 11. Toxicological Information Component Toxicological Information Acute Animal Toxicity 1)5-chloro-2-methyl-4-isothiazolin-3-one Not available. 2)2-Methyl-4-isothiazolin-3-one Not available. 3)Magnesium nitrate ORAL(LD50):Acute: 500 to 5000 mg/kg[Human]. 4)Magnesium chloride ORAL(LD50):Acute:4700 mg/kg[Mouse].2800 mg/kg[Rat]. 5)Diatomaceous earth,calcined Not available. 6)Crystalline silica:cristobalite Not available. 7)Crystalline silica:Quartz(S102) Not available. Chronic Toxicity Data 1)5-chloro-2-methyl-4-isothiazolin-3-one Not available. 2)2-Methyl-4-isothiazolin-3-one Not available. 3)Magnesium nitrate Repeated small oral doses of nitrate may cause weakness, depression, headache and mental impairment. Magnesium nitrate is a methemoglobin-forming agent, chronic exposure may effect the ability of the blood carry oxygen causing the lips and skin to turn blue. Magnesium nitrate has not been evaluated for its carcinogenicity in humans or animals. Generally, nitrates can be reduced to nitrites, under anaerobic conditions(without oxygen),and nitrites can react with amines to form carcinogenic N-nitrosamines(Reprotext). 4)Magnesium chloride Continued on Next Page • • X-CIDE®207 INDUSTRIAL MICROBIOCID Page: 5/7 Magnesium chloride is a component of this product. Magnesium chloride has caused chromosome abberrations in human cells, but was not mutagenic in mouse or hamster cells. Magnesium chloride was inactive for inducing DNA damage in the B.subtillis rec assay. (Micromedex) 5)Diatomaceous earth,calcined Not available. 6)Crystalline silica: cristobalite Silica crystalline as Cristobalite is a component of this product. Cristobalite is listed by NTP as a suspect carcinogen, by OSHA as a possible carcinogen, and by IARC as a possible carcinogen. Silica exists in several forms, but only the crystalline materials produce the chronic pulmonary condition termed specifically silicosis. Chronic inhalation of airborne crystalline silica dust may lead to fibrotic lung disease,silicosis or cancer(based on animal studies and limited evidence of carcinogenicity in humans). An inhalation study in humans at a dose of 16 mppcf/8H/17.9Y intermittent produced toxic effects to the lungs, thorax, or respiration resulting in fibrosis,focal(pneumoconiosis),cough and dyspnea(RTECS). An intratracheal (inside the airway tube between the voice box and chest cavity) dose of 200 mg/kg in rats produced lung, thorax, or respiration effects resulting in fibrosis,focal (pneumoconiosis).(RTECS) An intrapleural (inside the membrane lining of the lung cavity) dose of 90,and 100 mg/kg in rats produced tumors, and blood lymphomas(malignant but treatable cancer)including Hodgkin's disease(a type of lymphoma cancer). (RTECS) 7)Crystalline silica:Quartz(Si02) Crystalline silica as quartz is a component of this product. Prolonged inhalation of respirable crystalline quartz may cause delayed chronic lung injury - silicosis. Silicosis is a form of disabling pulmonary fibrosis which can be progressive and may lead to death. Silicosis may progress without further exposure to silica (Hathaway et al, 1991). Chronic inhalation of silica dust suppressed the immune response in mice (Scheuchenzuber et al, 1985), and a decreased immune response has also been shown in silicotics (Barlogova et al, 1981). The effect of silica on the immune mechanism may be mediated by its toxicity to pulmonary macrophages, a critical component of the immune response, and may have implications for the increased susceptibility of silicotics to respiratory infections, particularly tuberculosis. Inhaled crystalline silica particles induced several signs of pulmonary injury and inflammation in rats exposed to an airborne concentration of 50 mg/m3 for 6 hours per day for 5 days(Driscoll et al, 1991). IARC (International Agency for Research on Cancer) rates crystalline silica as a "Probable Human Carcinogen" (Group 2A). The US NTP(National Toxicology Program)rates respirable crystalline silica as an"Anticipated Carcinogen". Silica has been inactive for inducing DNA damage in the B. subtilis rec assay(Kanematsu et al, 1980), chromosome damage or sister chromatid exchanges in hamster cells(Price-Jones et al, 1980), chromosome damage in human cells (Oshimura et al, 1984), in vitro oncogenic transformation of hamster cells into cancer cells(Oshimura et al, 1984), and induction of micronuclei in mouse bone marrow (Vanchugova et al, 1985). Crystalline silica has caused DNA strand breaks in vitro; etching the surface with hydrofluoric acid reduced this activity. At the time of this review, no reproductive studies were found for silica in humans. Few reproductive data are available for silica.As a component of welding fume, it caused infertility and fetal death in rats(Dabrowski et al, 1966). Intratracheal instillation of silica prolonged the estrus cycle in rats (Parsadanian, 1967). So-called "soluble silica" was tested for reproductive effects in rats, but the results were not available at the time of this review(Smith et al, 1973). Product Toxicological Information Acute Animal Toxicity DERMAL(LD50):Acute:>5000 mg/kg[Rabbit]. Target Organs respiratory tract,skin/epithelium,eyes. Other Adverse Effects Eye Irritation Score=4(Extreme Irritant/Corrosive). Skin Irritation Score=4(Extreme Irritant/Corrosive). Prolonged exposure to silica may cause a lung disease called silicosis. Symptoms of silicosis include pain in the chest,coughing and tiring after slight excursions. Section 12. Ecological Information Ecotoxicity Ecotoxicity in water(LC50):9.2 mg/I 96 hours[Sheepshead minnow]. BOD5 and COD Not available. Biodegradable/OECD Not available. Toxicity of the Products of Not available. Biodegradation Continued on Next Page • • X-CIDE®207 INDUSTRIAL MICROBIOCID Page: 6/7 Special Remarks An EcoToxTM Report, and/or the material's environmental fate is available upon request at the following number: 1-800-235-4249,then press 4. Section 13. Disposal Considerations Responsibility for proper waste disposal rests with the generator of the waste. Dispose of any waste material in accordance with all applicable federal, state and local regulations. Note that these regulations may also apply to empty containers, liners and rinsate. Processing,use,dilution or contamination of this product may cause its physical and chemical properties to change. Additional Waste Remarks Not available. Section 14. Transport Information DOT Classification Corrosive solid, acidic, organic, n.o.s., (contains 5-ch loro-2-methyl-4-isothiazolin-3-one, o a; 2-Methyl-4-isothiazolin-3-one),8, UN3261, II `Q (oRRO<n I 8 DOT Reportable Quantity Not applicable. Marine Pollutant Not applicable. Additional DOT informationNot available. Emergency Response Guic 154 Page Number Section 15. Regulatory Information HCS Classification Target Organ Effects.Corrosive.Sensitizer.Contains a component that may cause cancer.. U.S. Federal Regulations Environmental Extremely Hazardous Substances: Not applicable to any components in this product. Regulations SARA 313 Toxic Chemical Notification and Release Reporting: Not applicable to any components in this product. SARA 302/304 Emergency Planning and Notification substances: Not applicable to any components in this product. Hazardous Substances(CERCLA 302): Not applicable to any components in this product. SARA 311/312 MSDS distribution-chemical inventory-hazard identification:immediate health hazard; delayed health hazard; Clean Water Act(CWA)307 Priority Pollutants: Not applicable to any components in this product. Clean Water Act(CWA)311 Hazardous Substances: Not applicable to any components in this product. Clean Air Act(CAA)112(r)Accidental Release Prevention Substances: Not applicable to any components in this product. Threshold Planning Not applicable. Quantity(TPQ) TSCA Inventory All components are included or are exempted from listing on the US Toxic Substances Control Act Status Inventory. This product contains the following components that are subject to the reporting requirements of TSCA Section 12(b)if exported from the United States:5-chloro-2-methyl-4-isothiazolin-3-one; 2-Methyl-4-isothiazolin-3-one. State Regulations State specific information is available upon request from Baker Petrolite. International Regulations Canada All components are compliant with or are exempted from listing on the Canadian Domestic Substance List. WHMIS(Canada) D-2A, E European Union All components are included or are exempted from listing on the European Inventory of Existing Commercial Chemical Substances or the European List of Notified Chemical Substances. Continued on Next Page • • X-CIDE®207 INDUSTRIAL MICROBIOCID Page: 7/7 International inventory status information is available upon request from Baker Petrolite for the following countries:Australia,and Australia(NICNAS),China, Korea(TCCL), Philippines(RA6969),or Japan. Harmonized Tariff Code 3808.90.30.00 Other Regulatory This product is subject to regulation under the US Federal Insecticide, Fungicide and Rodenticide ACT Information (FIFRA)and is therefore exempt from US Toxic Substance Control Act(TSCA)Inventory listing requirements. EPA Registration No. 10707-44. Offshore Chemical Notification Scheme(OCNS)rating: Group A O-VII Section 16. Other Information Other Special File 59 Considerations 07/16/03- Change to Section 15. Baker Petrolite Disclaimer NOTE: The information on this MSDS is based on data which is considered to be accurate.Baker Petrolite,however,makes no guarantees or warranty, either expressed or implied of the accuracy or completeness of this information. The conditions or methods of handling, storage, use and disposal of the product are beyond our control and may be beyond our knowledge.For this and other reasons, we do not assume responsibility and expressly disclaim liability for loss, damage or expense arising out of or in any way connected with the handling,storage, use or disposal of this product. This MSDS was prepared and is to be used for this product. If the product is used as a component in another product, this MSDS information may not be applicable. • • Schwartz, Guy L (DOA) From: Daniel Taylor <dtaylor @hilcorp.com> Sent: Monday,August 19,2013 3:35 PM To: Schwartz,Guy L(DOA) Subject RE:GP 11-13RD (PTD 313-442) Frac and run completion. Attachments: GP 11-13RD Proposed 08-01-13.doc Guy, Please see the updated schematic for 11-13RD. I apologize for not getting this in on the original application. Ideally we would run the expandable liner and move right into the fracturing proposal. If logistics prevents this immediate transition then a kill string will be run and the treatment postponed. 1. The annulus will be filled with 6% KCL and pressured up to 2,000psi. 2. The frac string will be tested to 8,000psi which is approximately 110%of maximum anticipated treating pressure (+[7,190). 3. The packer will be set and tested to 2,000psi and charted 30min. Regards, Dan Taylor Operations Engineer Hilcorp Alaska, LLC. 0: 907-777-8319 C: 907-947-8051 From: Schwartz, Guy L(DOA) [rnaiito cgoy.schwartz:d,ala ka.gov] Sent: Monday,August 19, 2013 2:33 PM To: Daniel Taylor Subject: GP 11-13RD (PTD 313-442) Frac and run completion. Dan, Can you provide an updated schematic showing the kill string/scab liner for the sundry application. Also: 1. Are you holding pressure on the IA during the frac..if so at what pressure? 2. What are you testing the frac string to?My calcs show 8000 psi is about 110%of max treating pressure. 3. Make sure packer is tested in step 21. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office 1 • RECEIVED STATE OF ALASKA AAA OIL AND GAS CONSERVATION COMRION MAY 0 3 2013 REPORT OF SUNDRY WELL OPERATIONS AOtCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other ❑ Performed: Alter Casing ❑ PuII Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other 0 Re -enter Suspended WeII❑ 2. Operator s / 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development IS Exploratory ❑ 191 -133 3. Address: 3800 Centerpopint Drive, Suite 100 StratigraphiC Service ❑ 6. API Number: j Anchorage, AK 99503 50- 733 - 20026 -01 1 7. Property Designation (Lease Number): ,/ 8. Well Name and Number: / ADL0018761 Granite Pt St 11 -13RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ,/ Granite Pt Field / Hemlock Undefined Oil 11. Present Well Condition Summary: Total Depth measured 11,560 feet' Plugs measured 11,510' feet true vertical 11,407 feet Junk measured 11,123' feet Effective Depth measured 11,510 feet Packer measured 10,926 feet true vertical 11,359 feet true vertical 10,803 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 684' 18" 684' 683' Surface 3,993' 13 -3/8" 4,018' 3,993' 3,090 psi 1,540 psi Intermediate 6,710' 6 -5/8" 6,773' 6,710' 6,870 psi 4,750 psi Production 3,287' 9 -5/8" 10,060' 9,960' 10,900 psi 7,950 psi Liner 1,773' 7" 11,560' 11,407' 12,460 psi 10,780 psi I Perforation depth Measured depth See Schematic feet MNEO MAY 13 2013, True Vertical depth See Schematic feet «7��1�G Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.5# / L -80 10,935' (MD) 10,812' (TVD) Packers and SSSV (type, measured and true vertical depth) BWD Pkr 10,926' (MD) 10,803' (TVD)"C 6Tea 'MSC SSSV 311' (MD) 311' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treated tubing to 10,935', perforations from 2 separate intervals: 11,032' to 11,220' & 11,245' to 11,377' Treatment descriptions including volumes used and final pressure: Pumped 5,712 gal of Xylene and a total of 320,230 scf of Nitrogen. Ending pressure = 3,800 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 30 30 25 550 80 Subsequent to operation: 25 55 45 965 115 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development LII Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil p Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -088 Contact Dan Taylor Email dtavlor( hilcorp.com Printed Name Dan Taylor Title Operations Engineer Signature % Phone (907) 777 -8319 Date 5/3/2013 Form 10 -404 Revised 10/2012 i 5:74 RBDMS MAY - 6 101 submit Original Only • • Hilcor p Alaska, LLC Hil orp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 11 -13RD 50- 733 - 20026 -01 191 -133 3/3/2013 4/5/2013 Daily Operations: 03/03/13 - Sunday Well Site Supervisor AOL 3 -2 -13 7pm. Begin organizing operations. 03/04/13 - Monday RU slickline unit. Inspected and verified gauge ring size. (2.3 ") NU lubricator to WH and tested to 1,000 psi. Test Good. RIH with 2.3" gauge ring. Tight spots around gas lift valves 6- 11.(7,600'- 10,820' WLM) Ran in hole to 10,860' WLM. POOH. RU and RIH with scratcher. Work tight spots above and below each gas mandrel down to 10,860' WLM. POOH. RD Slickline for night. Well turned back over to production to flow for night to try to clear debris. Well secure and flowing. 03/05/13 - Tuesday RU slickline, RIH with brush working down to 10,860' WLM. No tight spots seen. POOH. Flow well for two hours. SD gas lift and bleed off well. Prepare slickline to RIH and pull gas valves. Delay in the arrival of chemical to be blended at facility. ETA unknown at this point. SD slickline operations. RD. Well put back on line till later date. 03/13/13 - Wednesday Rigging up. 03/14/13 - Thursday Tested area for hot work permit. RU slickline. Tested lubricator stack to 1,000 PSI. Bled off pressure. RIH to set stop in hole and remove gas valves. SD operation for night. Well SI and secured. 03/15/13 - Friday Expro finished pulling gas valves, and starting to replace with dummy valves. (Viton seals installed on DV's). Operation SD for night. Well SI and secured. 03/16/13 - Saturday Pulled remaining gas valves OOW and replaced them with dummy valves. RIH and pulled slip stop OOH. POOH and RD. Well SI and secure. Production in control of well, and filling casing overnight to prepare for treatment job. 03/17/13 - Sunday MIRU all service equipment for pump job. Transferred chemicals from totes to 5,500 gal. ISO tank and blended with air. Cranked all deck engines with no issues. Rigged up and ready for Stimulation job A.M. Production filled back side. (took 530 bbls) Operations SD for night. Well SI and secure for night. 03/18/13 - Monday Completed RU and transfer of Xylene mixture in ISO. Ensured 2x2 block valve shut above master valve on WH and pressure tested flowback iron to tank to 2,000 PSI. Tested good. SI 2x2 block valve on flowback iron and tested treatment iron to 6,500 PSI. Tested Good. Bled off pressure to FB tank. Pumped diesel thru pump and returned thru flowback iron to tank. Blew line down from pump with N2 to FB tank. Pressure up casing to 500 PSI. Open well and had 19 PSI on it. ST FP at .3 bpm and N2 pump at 600 SCFM. Walked casing up in 500 PSI increments as tubing PSI rose 1,000 PSI over casing PSI, stopping with 2,000 PSI on casing. At 15:30 tubing PSI was 2,600 PSI and casing holding 2,000 PSI. Having issues with keeping the N2 rate called for in the procedure. Only able to get about 400 -500 SCFM rate at this time. Total pumped at this time was 37 bbls chem. mix. Treatment PSI stabilizes at 4,430 PSI with casing having little to no change in pressure. A 200 PSI drop in PSI occurred at 16:15 on tubing, another break 5 min. later which was only 100 PSI. Pressure stabilizes for 30 minutes giving a chance to establish a good injection rate of .6 BPM. Tubing pressure starts to climb and reaches 4,500 PSI (max treatment psi) and N2 SD. FP still at .3 bpm. 67 bbls of xylene mix pumped away at this point with 220K SCFM N2 gone. After 10 min. back on with N2 at 400 SCFM. Shortly after coming back on with N2 a increase in casing psi is noticed (2,241 from 2,000 psi) Tubing PSI 4,367 SD and watched pressure on tubing and casing as they fell. With tubing PSI at 3,408 and casing PSI at 1,927 came on line with FP at .75 bpm to see if tubing and casing psi would rise together. Tubing came up 500 PSI and casing had no response. Continued to pump chemical with no N2 to establish some hydrostatic psi. Pumped 8 bbls away and came on line with N2 at 600 SCFM and reduced FP rate to .3 BPM. 88 bbls of chemical pumped away at this point. Casing PSI keeps increasing and having to be bled off. SD N2 with 94 BBLS of chem. mix gone and pumping straight fluid at .5 bpm. Continued pumping and lowered rate of FP to .3 bpm and completed pumping xylene mixture. Total of 136 bbls pumped. ST N2 at 300 SCFM. Tubing PSI 2,647 Casing PSI 1,990. Able to raise rate to 500 SCFM and maintain tubing pressure below 4K PSI and saw communication with tubing again with 60,500 SCF N2 gone. With 3,800 tubing psi this amount equates to 49.6 bbls which in tubular volume puts the area in question around 8,636' (between 8th and 9th GLM) Continued to pump till 78K SCF was pumped to ensure tubular volume was cleared and SD. SIW and block valve on WH. Bled pressure off to flowback and pump diesel thru pump and all treatment /flowback iron and blow out with N2 to return tank. SD for night. Well secure and soaking in Xylene /Nitrogen mix. • • Hilcorp Alaska, LLC Hilcorp Alaska. LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date GP 11 -13RD 50- 733 - 20026 -01 191 -133 3/3/2013 4/5/2013 Daily Operations: 03/19/13 - Tuesday RD all equipment except flowback package. Opened well with choke closed to establish WH PSI. PSI at 2,750. Opened choke and started bleeding down well. Only thing returned was N2 no fluids. Bled down to 0. SIW RD flowback equipment and got it ready to send to shore. Production NU cap on WH and monitoring PSI. Well building pressure (450 psi). Production cracked choke and taking returns to well cleanout tank for night. All other operations SD. 03/23/13 - Saturday RIH installed standing valve. Had trouble RIH due to thick asphaltene sludge. Pulled the top 6 dummy valves and installed top 6 GLV's to attempt to flow all of tubing volume out per gas lift. Expro to take couple of days off during this process. 03/25/13 - Monday Rig up and PT lubricator to 1,000 psi. RIH with Gauge ring 2.5 GU to 10,860' could not latch the Junk basket. POOH. Make another trip to see if we could latch, could not. POOH. RIH and pull dummy valves due to the Junk basket at the bottom, finish pulling all of the dummies left in the well will start install them tomorrow. 03/26/13 - Tuesday Rig up and pressure test lubricator to 1,000 psi. RIH to install valves. RIH and set Gas lift valves. RIH with 2.313 brush, work down to 10,832. POOH. RIH set last valve. POOH. Rig down and clean up. 03/27/13 - Wednesday RIH with bailer and scratcher to clean asphaltenes from well. Attempted to pull junk basket w/o success. 04/01/13 - Monday Rig up and pressure test lubricator to 1,000 psi. RIH with wire brush beat down to 10,852'. POOH. RIH with 2.25 guage ring tag @ 10,813' work down to 10,850'. POOH. RIH with 2.25 bailer work down to 10,818' with several trips. Lay down tools and rehead clean up equipment. 04/02/13 - Tuesday Rig up and pressure test lubricator to 1,000 psi. Work 2.25 bailer down from 10,818' to 10,836' with 8 trips in the well. We have 24 feet to go, lay down tools clean equipment rehead the wire and free up the spangs. 04/03/13 - Wednesday Rig up RIH with 2.25 bailer work 10,837' to 10,842'. POOH. Bail down to 10,860' pick up 1.75 bailer and clean out the junk basket. RIH with 2.25 GU unable to latch work the tool on bottom for a while. RU a cable scratcher 2.30 and work the basket from the bottom to the top about 3 feet, POOH. RIH with 2.25 GU and work the fish neck several times to see if we could get it to set, unable to get the GU tool to latch. 04/04/13 - Thursday Rig up P/T to 1,000 psi. RIH With 2.25 bailer. POOH, put on 1.75 Bailer and RIH. POOH. RIH with cable scratcher work thru the basket, work with GU latch and bailers to try and retrieve the Junk Basket. POOH. RIH with a 1.75 drive down bailer. POOH cleaned up the tool and noticed that it had a small point dent in the lip of the bailer. R/U to fish Gas lift valve. Got the first valve out noticed that it had marks of another valve below it, so RIH to get the next valve. Finally got the valve out. RIH with the 2.25 GU fish tool and latch the Junk Basket. 04/05/13 - Friday Continue RIH and latched the Junk Basket. POOH and got the junk basket. Discovered that it had a lip in the internal that would catch the latch of a valve and allow the spring to work, so the valve could bounce and made for extremely difficult fishing. RIH and retrieve the standing valve. RIH and set the orifice valve in the pocket. RIH and set # 6 gas lift valve back in pocket. RD equipment and return to production. • Well #: GP 11-13RD Granite Point Platform SCHEMATIC Last Completed: 03/12/92 PTD: 191 -133 Hi!cora Alaska. LLf. API: 50- 733 - 20026 -01 RKB to Hanger = 42.5' CASING DETAIL o u 1 Size WT Grade Conn ID Top Btm 18" Conductor 41' 684' 13-3/8" 61.0# J -55 12.515" 41' 4,018' 18" 9 -5/8" 47# N -80 8.681" 41' 6,773' 9 -5/8" 53.5# P -110 8.535" 6,773' 10,060' I 2 7" 32# P -110 6.094" 9,787' 11,560 TUBING DETAIL 3 2 -7/8" I 6.5# L -80 I BTC I 2.441" 46' 10,935' 13 4 JEWELRY - 5 No Depth ID Item - 42.5' FMC /OCT 5M Tubing hanger w/ CIW "H" BPV Profile 6 43' 2.992" 3 -1/2" x 2' , 9.2# L -80 Tubing Pup - 46' 2.441" 3 -1/2" x 2 -7/8" BT & C X -over 7 1 311' Camco "TRSV" Retrievable SSSV - 2 2,193' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel �/ 8 v 3 3,863' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel V� /� 4 5,130' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel L 9 5 6,054' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 9 = 6 6,791' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 10 7 7,623' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel - 11 8 8,263' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel - 9 8,935' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 12 10 9,576' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel II 11 10,246' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 13 Pak depth ia@J °'9� 12 10,826' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 13 10,902' 2.313" Halliburton /Otis "X" Landing Nipple = ' 14 14 10,926' 3.250" Otis "BWD" Permanent Packer (Ran 3/12/92) 15 10,935' 2.35" Halliburton /Otis Locator Sub (On end of tubing run 10/2/95) 15 16 10,984' 2.125" End of Tubing @ Mech. Tubing Release (Guns dropped 3/5/93) 16 3/5/93 — 398' of TCP Guns (Max OD — 4.625 ") dropped from tubing release @ 10,984'. 9/28/10 - Guns tagged @ 11,123' SLM. PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 Hemlock 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/11 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 r / // � _ � ' i 4 ,,,,.. .,. TD = 11,560' Cement Ret. @ 11,510' Updated by DMA 11 -28 -12 • ti T' • • �� \ % %tv THE STATE Alaska Oil and Gas _ f „ ALAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue (4'ALAS1p. Anchorage, Alaska 99501 -3572 Main: 907.279.1 433 ,A ^D Fax: 907.276.7542 Ted Kramer SCNHE n 1Y1Hi� Sr. Operations Engineer (qt 33 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Granite Point Field, Hemlock Undefined Oil Pool, Granite Pt St 11 -13RD Sundry Number: 313 -088 Dear Mr. Kramer: 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 P. oerster Chair DATED this 22-day of February, 2013. Encl. • FEB 19 2013 STATE OF ALASKA O 13 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pod ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ 7 . Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate El • After Casing ❑ Other. /€_4c. . t►d 2. Operator Name: 4. Current Well Class: 5. Permit to Drill ■ mber: Hilcorp Alaska, LLC Exploratory ❑ Development p • 191 -133 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. Anchorage, AK 99503 50- 733 - 20026-01 • 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? WA Will planned perforations require a spacing exception? Yes ❑ No ❑ Granite Pt St 11 -13RD • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018761 • Granite Pt / Hemlock Undefined Oil - 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): • 11,560 11,407 • 11,510 11,359 11,510' (Cement Retainer) • 11,123' Casing Length Size MD TVD Burst Collapse Structural Conductor 684' 18" 684' 683' Surface 3,993' 13 -3/8" 4,018' 3,993' 3,090 psi 1,540 psi Intermediate 6,710' 9 -5/8" 6,773' 6,710' 6,870 psi 4,750 psi Production 3,287' 9 -5/8" 10,060' 9,960' 10,900 psi 7,950 psi Liner 1,773' 7" 11,560' 11,407' 12,460 psi 10,780 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 2 -7/8" 6.5# / L -80 10,935' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Otis "BIND" Permanent Packer / Camco TRSV SSSV Packer 10,926' (MD)10,803' (TVD) / SSSV 311' (MD) 311' (TVD) 12. Attachments: Description Summary of Proposal El • 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development BI • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/28/2013 Oil IEI • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ted Kramer Email tkramer @hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature Phone 907 777 -8420 Date 2/19/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5 © � �• 13. UX Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS FEB 2 5 1013 Spacing Exception Required? Yes ❑ No LYJ Subsequent Form Required: 1 6 II oq l � — APPROVED BY Approved by:( ' " ' COMMISSIONER THE COMMISSION Date: 2 - L1 -/ 3 RL Form a nd OF L Approved applicat ion is va for 12 months from the date of approval. Attachments in Duplicate .1r y • • Well Prognosis Well: GP- 11 -13RD Hilcorp Alaska, LL Date: 2/15/2013 Well Name: GP- 11 -13RD API Number: 50- 733 - 20026 -01 Current Status: SI Leg: #3 Estimated Start Date: Feb 28 2013 Rig: NA Reg. Approval Req'd? NA Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777 -8332 Permit to Drill Number: 191 -133 First Call Engineer: Ted Kramer (907) 777 -8420 (0) Second Call Engineer: Reid Edwards (907) 777 -8421 (0) (907) 250 -5081 (M) AFE Number: Current Bottom Hole Pressure: — 5,290 psi @ 11,100'TVD (Pressure buildup data from 2010) Maximum Expected BHP: — 5,530 psi @ 11,200' TVD Max. Allowable Surface Pressure: — 5,000 psi (Maximum expected pumping pressure during stimulation) Brief Well Summary Well was drilled and completed in 1992 as a Hemlock producer. Initial rates were — 1500 bopd with no water and is now producing at — 30 bopd and 30 bwpd. This well has had a history of asphaltene deposition in the tubing and formation with several attempts to help remove by scraping tubing and xylene squeezes into the formation. Most of the xylene squeezes showed an increase in production rates although were not sustainable. The last xylene squeeze was attempted in 1999. A PBU was run in 2010 and revealed the well had significant skin damage which is assumed to be cause by asphaltene deposition in the formation. A re- perforation attempt was made after the PBU results and showed no improvement in well performance. The last tag in the well was made at 11,123' MD in October 2010. The tag is assumed to be the top of — 400' of TCP guns that were released in March 1993. A foamed nitrogen / xylene mixture is planned to be pumped into the formation to help remove near wellbore damage caused by asphaltene deposition. Nitrogen is being utilized to help with diversion as well as flow back of the well. Notes Regarding Wellbore Condition • Bottom hole pressure is approximately 5300 PSI Brief Procedure: 1. Run 2.3" gauge ring to 10975' 2. Run 2.3" brush or scraper over any tight spots found during gauge run 3. Pull gas lift valves from well and replace with dummies 4. Ensure annulus is fluid packed with FIW 5. Perform MIT to ensure tubing and IA are isolated from each other ✓ 6 6. Rig up Baker equipment to well 7. Pressure test lines 8. Apply 2000 psi to casing 9. Pump foamed xylene stage followed by N2 flush 10. Rig down Baker equipment 11. Rig up flow back to well clean out tank • • Well Prognosis Well: GP- 11 -13RD Hilcorp Alaska, LL Date: 2/15/2013 12. Start flow back and allow well to clean up 13. Turn over to production and apply gas lift Attachments: 1. As -built Schematic • • Granite Point Platform Well #: GP 11 -13RD SCHEMATIC Last Completed: 03/12/92 nar.,, r v:r.1 :r. 1,1,1. PTD: 191 -133 API: 50- 733 - 20026 -01 RKB to Hanger = 42.5' .] CASING DETAIL o — 1 Size WT Grade Conn ID Top Btm 18" Conductor 41' 684' 13 -3/8" 61.04 1-55 12.515" 41' 4,018' 18 " 9 -5/8" 47# N -80 8.681" 41' 6,773' _ 9 -5/8" 53.54 P -110 8.535" 6,773' 10,060' III 2 7" 32# P410 6.094" 9,787' 11,560' TUBING DETAIL 3 2 - 7/8" 6.54 L-80 BTC 2.441" 46' 10,935' 13 -3/8" 4 JEWELRY 5 No Depth ID Item - 42.5' FMC /OCT 5M Tubing hanger w/ CIW "H" BPV Profile 6 43' 2.992" 3 -1/2" x 2' , 9.2# L -80 Tubing Pup - 46' 2.441" 3 -1/2" x 2 -7/8" BT & C X -over 7 1 311' Camco "TRSV" Retrievable SSSV • - 2 2,193' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel I./ 8 \/ 3 3,863' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel V\ /� 4 5,130' 2.441" 2 - 7/8" Camco "MMM" Gas Lift Mandrel 9 5 6,054' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel Z. 9-5/8" 6 6,791' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel - 10 7 7,623' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 11 8 8,263' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel - 9 8,935' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 12 10 9,576' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 11 10,246' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 13 pakr depth is,4 12 10,826' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 10,926' 13 10,902' 2.313" Halliburton /Otis "X" Landing Nipple 14 14 10,926' 3.250" Otis "BWD" Permanent Packer (Ran 3/12/92) 15 10,935' 2.35" Halliburton /Otis Locator Sub (On end of tubing run 10/2/95) 15 16 10,984' 2.125" End of Tubing @ Mech. Tubing Release (Guns dropped 3/5/93) 16 3/5/93 — 398' of TCP Guns (Max OD — 4.625 ") dropped from tubing release @ 10,984'. 9/28/10 - Guns tagged @ 11,123' SLM. ' PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Date / 11,032' 11,220' 10,904' 11,083' 188' 8 3/12/1992 it Hemlock 11,032' 11,102' 10,904' 10,970' 70' 6 2/12/11 11,245' 11,377' 11,106' 11,232' 132' 8 3/12/1992 7 0 4 r 1 % ., TD = 11,560' Cement Ret. @ 11,510' Updated by DMA 11 -28 -12 w64 STATE OF ALASKA 3�/ /Zrstf ALASKA. AND GAS CONSERVATION COMMISSIW REPORT OF SUNDRY WELL OPERATIONS 1. Abandon U Repair Well 11 Plug Perforations U Stimulate 11 Other 11 Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 ' Re -enter Suspended Well ❑ 2. Operator Union Oil Company of Califomia 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 • Exploratory p ry 191 -133 • 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 733 - 20026 -01 . 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018761 (Granite Point Platform) Granite Pt St 11 -13RD . 9. Field /Pool(s): Granite Point Field / Hemlock Undef OiI Pa't7t' • �- 10. Present Well Condition Summary: Total Depth measured 11,560' • feet Plugs measured N/A feet true vertical 11,407' • feet Junk measured 11,123' MD (fish) feet measured 11,123' feet Packer measured 10,926' feet true vertical 11,123' feet true vertical 10,803' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 684' 18" 684' 682' Surface 3,993' 13 -3/8" 4,018' 3,993' 3,090psi 1,540psi Intermediate 6,710' 9 -5/8" 6,773' 6,710' 6,870psi 4,750psi Production 3,287' 9 -5/8" 10,060 9,960' 10,900psi 7,950psi Liner 1,773 7" 11,560' 11,407' 12,460psi 10,780psi Perforation depth Measured depth 11,032'- 11,220'; 11,246- 11,377' True Vertical depth 10,903'- 11,082'; 11,106- 11,232' / Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 10,935' MD 10,811' TVD Packers and SSSV (type, measured and true vertical depth) BWD Permanent Packer/TRSV SSSV 10,926' /311' MD 10,803' /310' TVD 11. Stimulation or cement squeeze summary: summa E Intervals treated (measured): _ N/A . NNED MAR , r 1 Q 1 ;FEB 4 2011 Treatment descriptions including volumes used and final pressure: t► N/A GI & G s COWL Cn sjon 12. Representative Daily Average Production or Injection Data Anchorage Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 33 75 24 600psi 92psi Subsequent to operation: 28 77 46 600psi 100psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development E Service ❑ StratigraphE Daily Report of Well Operations X 15. Well Status after work: Oi1 0 . Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSPD SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Chris Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature . ignature x < T Phone 276 -7600 Date 2/22/2011 RBDMS MAR 01 201 ' A z-45.// Form 10-404 Revised 10/2010 Submit Original Only Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) jWater Depth (ft) GP 11 -13RD GRANITE PT ST 11 -13RD ADL0018761 5073320026 AR4230 109.00 Primary Job Type Job Category Objective Actual Start Date Actual End Date Perforation - Re- Perforation Well 9/28/2010 9/29/2010 Services Primary Wellbore Affected Wellbore UWI Well Permit Number GP 11 -13RD 507332002601 1911330 9/20/2010 00:00 9/29/2010 0 ,: , .,1 � Operations Summary RU slickline, pressure test lubricator 250psi low /2500psi high. RIH w/ 2.0" GR and 1.75 "x20' dummy gun and tag TCP guns at 11,123'RKB SLM. RD slickline. 'I4 00:00.,, 101 2010 00 :00 at •F ,•. Operations Summary RU Eline. Pressure test lubricator 250psi low /2500psi high. RIH with 1- 11/16" PowerSpiral 7.5spf 45deg perf guns, place guns on depth, guns did not fire, POOH. Made second run w/ perf guns, guns did not fire, POOH. Trouble shoot wireline issues. r a t r rr rr a i "e� r,°e'`00 Operations Summary RIH with 1- 11/16" PowerSpiral 7.5spf 45deg perf guns, perforate from 11,092' to 11,102'. Made second run w/ perf guns, guns did not fire, POOH. RD Eline. Shut down operations to trouble shoot wireline issues. 2111/2011 00:00 - 2/12/2011 00 :04 = `• «� ....,<" , Operations Summary RU Eline. Pressure test lubricator 250psi low /2500psi high. RIH w/ 2.0" GR and tag fill at 11,101'. RIH with 1- 11/16" Showgun 6spf 60 deg perf guns, and perforate 11,071'- 11,092'. Operations Summary RIH with 1- 11/16" Showgun 6spf 60 deg perf guns, and perforate 11,051' - 11,072' & 11,032'- 11,053'. RD Eline, turn well over to production. / . ALAS KA A, 00&E Team • Granite Poi Platform Well # GP 11 -13RD UNOCAL 76 Completion Date 3/12/92 (W /O 10/2/95) RKB to Hanger = 41' J . API # 51- 73,3 -21 26 -01 CASING AND TUBING DETAIL 1 SIZE W T GRADE CONN ID TOP BTM. 18" Conductor Surf 684' 13 -3/8" 61.0# J -55 12.515" Surf 4,018' 9 -5/8" 47# N -80 8.681" Surf 6,773' 9 -5/8" 53.5# P -110 8.535" 6,773' 10,060' 2 7" 32# P -110 6.094" 9,787' 11,560' . Tubing: 2 -7/8" 6.5# L -80 BTC 2.441" Surf 10,935' El 3 4 JEWELRY DETAIL 5 NO. Depth ID Item - 42.5' FMC /OCT 5M Tubing hanger w/ CIW "H" BPV Profile 6 43' 2.992" 3 -1/2" x 2',9.2# L -80 Tubing Pup - 46' 2.441" 3 -1/2" x 2 -7/8" BT & C X -over 7 - 1 311' Camco "TRSV" Retrievable SSSV E 8 V 2 2,193' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 3 3,863' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel L 9 4 5,130' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 10 - 5 6,054' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 11 6 6,791' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel - 12 7 7,623' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel _ © 8 8,263' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 13 P dept is@ t 10,926 9 8,935' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 14 10 9,576' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 11 10,246' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 15 12 10,826' 2.441" 2 -7/8" Camco "MMM" Gas Lift Mandrel 13 10,902' 2.313" Halliburton/Otis "X" Landing Nipple 16 14 10,926' 3.250" Otis "BWD" Permanent Packer (Ran 3/12/92) 15 10,935' 2.35" Halliburton/Otis Locator Sub (On end of tubing run 10/2/95) 16 10,984' 2.125" End of Tubing @ Mech. Tubing Release (Guns dropped 3/5/93) * 3/5/93 – 398' of TCP Guns (Max OD – 4.625 ") dropped from tubing release • @ 10,984'. Guns tagged @ 11,123' SLM (9/28/10). F ::: _— PERFORATION DATA v` ZONE TOP BTM AMT SPF DATE Hemlock 11,032' 11,220' 188' 8 3/12/92 • Hemlock 11,032' 11,102' 70' 6 2/12/11 TD = 11,560' Cement Ret.@ 11,510' Hemlock 11,245' 11,377' 132' 8 3/12/92 GP11- 13RDSchm Comp 022011.doc DRAWN BY: BGA 2/8/05 REV BY: SBJ 2/20/11 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~~~~~ 1(O~'~Ek;:~ DATE: P. I. Supervisor FROM: Bob Noble SUBJECT: Petroleum Inspector Oct 29, 2008 No-Flow Granite Pt. State 11-13RD Union PTD 1911330 Oct 29, 2008: I traveled to Union Oil Company of California (Union)'s Granite Point platform to perform a No-Flow on Granite Pt State 11-13RD. On arrival I met with platform operator Ted Medley and went over the State of Alaska's No-Flow requirements. We went to the well and observed the following pressures: T/I/O/00=0/0/160/50 psi. A half-inch bleed hose was attached to the tree cap though a 0-60 psi Perma-Cal test gauge and a 180-1800 SCFH Erdco flow meter. The only thing I had them change in the equipment rig-up was the end of the bleed hose that was attached to a drain manifold. I had them remove it, as I wanted it open ended to be sure there was no backpressure and so I could see what was coming out. Summary: 10:00: Valve on production string was shut in for 30 min to build pressure. 10:30: Valve on production string opened just long enough to check the flow rate and pressure. The pressure was less than 1 psi and the flow rate was 250 SCFH. Well was shut in for an hour. 11:00: Valve again opened to check the flow rate and pressure. The pressure was less than 1 psi and the flow rate was 350 SCFH; well was left open to allow pressure to bleed down. Within 1 minute, the rate had dropped off to below the 180 SCFH that the flow rate gauge would read. The well was shut in again for longer pressure build up. 12:00: Well was opened after a 1-hour shut in just long enough to check the flow rate and pressure. The observed pressure was less than 1 psi and the flow rate was 350 SCFH. Well shut in for 3 hours. 14:00 Well opened up and following tubing pressur~arTtt"fl"ow rakes observed: 0 min -- <1 psi; 450. SCFH; 1 min -- <1 psi; 350 SCFH; 2 min -- <1 psi; <180 SCFH; 3 min -- <1 psi; no flow. ~~~~~~~ ;~ : ~ t Attachments: none MEMORANDUM TO: Randy Reudrich Commissioner THRU: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 17, 2003 SUBJECT: No-Flow Test Unocal / Granite Pt. PLT Granite PT ST 11-13RD PTD 1911330 Granite Point Field June 17, 2003: I traveled to the Granite Point Platform in Cook Inlet to witness a No-Flow Test on Unocal's Granite Point Field well 11- 13RD. Unocal representative Stewart Allison performed the test today in a safe and proficient manner. Well 11-13RD was lined up from the production tubing through an Armor-Flow model # 3461-03T0 flow meter (180 SCFH to 1800 SCFH span) and a 1/2" hose terminating in an open top drum. The gas lift was shut in 12 hours previous to the test and the well was allowed to depressure into the test separator. Flow from the well was monitored for 3 hours with readings recorded every 30 minutes. Unassisted gas flow from the ~vell exceeded the maximum permissible 900 SCF hourly flow rate during the test and no significant fluid was produced. I requested that a fluid level in the well be shot to determine if it was rising but the necessary equipment was not onboard the platform. Summary: I witnessed a No-Flow Test on Unocal's Granite Point Field well 11-13RD on the Granite Point Platform in Cook Inlet. Attachments: none CC; Dwight Johnson / Ted Medley (Unocal) Operator: U~ocal Date 6/17/2003 Operator Rep: Stewart Allison AOGCC Rep: Jeff Jones Field/Unit/Pad Granite Point Field/PLT Well: Granite PT ST 11-13RD "~' '"'"(' .~' ""' ~as ~ ' ....... ' 12:00PM ~00SGFH None StouTest 12:BOPM lB00 SGFH None 1:00 PM 1 ~00 SGFH None Double blocked lift gas I:B0 PM 1100 SGFH None 2:00PM lsd0 SGFH None 2:BOPM 14~0 SGFH None B:00PM 1200 SGFH None Produced to open top container through Armor-Flow meter model #3461-03T0. Total liquid produced: none RJF 09/19/02 Page 1 of l 2003-0617_No-Flow_Granite Pt 11-13P,_D__ij.xls MEMORANDUM TO: Julie Heusser, Commissioner THRU: TOm Maunder, P. I. Supervisor FROM: John Crisp, Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 10, 2001 SUBJECT: Safety Valve Tests Granite Point Platform Granite Point Field May 10, 200!.; I traveled to UNOCAL's Granite Point Platform and witnessed the semi annual safety valve system testing. I found a very clean platform with sign's of regular maintenance and much fresh paint in evidence. The Safety Valve Systems were tested. 9 wells and 26 components were tested with two failures. Ted Medley lead operator conducted the testing today, he demonstrated good test procedure and was a pleasure to work with. The SSSV on GP'50 failed to close. This is a repeat of the previous tests failure; I exPressed the AOGCC's concern for the repair & retest of the failures. The AOGCC test report is attached for reference. Su, mmarv; I witnessed the semi annual Safety Valve System testing at UNOCAL's Granite Point Platform in the Granite Point Field. Granite Point Platform, 9 Wells, 26 components 2 failures. 7.7% failure rate, Attachment: SVS Granite Point Pit. 05-10-01jc N.ON-CONF!DENTIAL SVS Granite Point Pit. 05-10-0ljc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Ted Medley _ AOGCC Rep: jOhn Crisp ..... Submitted By: John Crisp. ~_ Date: Field/Unit/Pad: Granite Point Field & Pit. Separator psi: LPS 60 HPS 5/10/01 i i i i i i ii i i iii ii i .11 i i . i [. : i Well Permit Separ Set L/P Test Test Test Date oi~ WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE -1~1:-'13-~' 191i'330 60 40 33 P ,~-~4 V OIL 13-i 3 '~ ~'67021 (3 60 40 40 '~; .... P~ '1~ ......... OIL 'i 605s0 3 l_l'4RD5 "' 1002660 .............................. 31-23 " ' 1670840 60 40 '4'0, i'....... P ........... OIL- 32'13RD 1926200 "60 '"3,0 40 P' P P ...... oil ,,, , ~ , , , , ,,, , , ,,,, ,_ , 42-23RD 1951450 60 40 34 e e P OIL 44-14 167~J620i 6'6' 40' ..... 36!' "P e P' ' '0Ii~ '5'0 "i9204i''0 ~0 ' '~0 33 ' e "P' ' 8 ......... 0iL 51 ..... i920720 601 40 "35 ' P ' pA P ............ oi'L 54 1960130 60 40 34 e e ~ OIL Wells: 9 ComponentS: 26 Failures: 2 Failure Rate: 7.t39% [2] 90 Remarks: SSV on well 1,1, 71,3. ,failed~ t0 ,ho.!d.D,P..,This gate v. alve._ .~ be ~.,rvice, d,.&.re-tested. .ss: °n W~ll ~P-50 failed to close, Ted Medley will comaet Unocal Supervisors about AOGCC;s c0x4c~m for the repair & re-test of GP50's SSSV. RJF 1/16/01 Page 1 of 1 SVS Granite Point Pit. 5-10-01jc MEMORANDUM TO: THRU: Julie Heusser, .~' Commissioner Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission FROM: John Crisp, SUBJECT: Petroleum Inspector DATE: 'December 7, 2000 Safety Valve Tests Granite Point Platform Granite Point Field December 7, 2000; I traveled to UNOCAL's Granite Point Platform and witnessed the semi annual safety valve system testing. I found a very clean platform with sign's of regular maintenance and much fresh paint in evidence. The Safety Valve Systems were tested. 9 wells and 26 components were tested with two failures. Ted Medley lead operator conducted the testing today, he demonstrated good test procedure and was a pleasure to work with. The AOGCC test report is attaChed for reference. Summary; I witnessed the semi annual Safety Valve System testing at UNOCAL's Granite Point Platform in the Granite Point Field. Granite Point Platform, 9 Wells, 26 components 2 failures. 7.7% failure rate. Attachment: SVS Granite Point Pit. 12-07-00jc NON-CONFIDENTIAL SVS Granite Point Pit. 12-07-00jc.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: nocal Operator Rep: Ted Medley AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Granite Point Field & Pit. Separator psi: LPS 60 HPS 12/7/00 Well ' Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE ll-13RD 1911330 60 40 33 P ~ P P OIL , 13-13 1670210 60 40 37 P (5) P 12/8/00 OIL 31-13 1660550 · 31-14RD2 1002660 31-23 1670840 60 40 35 P P OIL 32-13RD 1920200 60 40 35 P P P OIL ,,, 42-23RD 1951450 60 40 40 P P P OIL 44-14 1670620 60 40 35 ' P P P OIL 50 1920410 60 · 40 35 e P (~) ~~1,~.~_\~,~ OIL 51 1920720 601 40 35 e e e OIL 54 1960130 60 40 36 e e P OIL _ Wells: 9 Components: 26 Failures: 2 Failure Rate: 7.7% El00 my Remarks: Well 31023 is a no flow. 12/13/00 Page 1 of 1 SVS Granite Point Pit. 12-07-00jc.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo~, DATE: Chairman THRU: Blair Wondzell, ~ FILE NO' P. !. Supervisor 3/'~sk)~ FROM: Lou Grimaldi,~¢o.~ SUBJECT: Petroleum Inspector September 25, 1995 AOJJIYCD.DOC BOP test (_..o Granite Point Platform Granite Point Field PTD #91~ Monday, September 25, 1995: I witnessed the initial BOP test on the newly activated rig on the Granite Point platform. Nabors Drilling has the contract for this round of drilling and has done a excellent job of bring this rig up. I found a well thought out and solidly constructed rig that should have no problems handling the upcoming program. The test went quite well with all components functioning properly and holding their respective pressure tests. There was one leak found, this being the flange at the bottom of the riser. Once tightened this connection presented no more problems in our subsequent tests. ! did not consider this as a failure due to the fact that it was a newly made up connection and leaked on its first pressure up and once retightened held for all the following tests. While I was aboard the platform I observed various contract companies checking out the rigs BOPE subsystems (Gas detectors, Remote Choke Panel, Visualogger, etc.). Some of these components required minor adjustments or repairs and ali were in ready condition by the time we were finished testing. SUMMARY: I witnessed the initial BOP test on the newly activated rig on the Granite Point platform. Test time 5 hours, No failures. Attachments: AOJJIYCD.XLS cc: Dan Williamson (Unocal Drilling Supt.) OPERATION: Drlg: Workover: X Drlg Contractor: Nabors Operator: Unocal (Granite Point Platform) Well Name: GP 11-13 Casing Size: 7" Set @ Test: Initial X Weekly STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Rig No. GPP PTD # 91-.334- Rig Ph.# Rep.: Shane Hauck 9/25/95 776-6658 Rig Rep.: Mike Williams 7765 Location: Sec. 13 T. 1ON R. 12W Meridian Seward Other TEST DATA MISC. INSPECTIONS: Location Gen.: Housekeeping: Reserve Pit: N/A Standing Orders: OK P.T,D.: OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve OK Well Sign OK OK (Gen) Drl. Rig OK Hazard Section OK Test Quan. Pressure 1 250/3500 I 250~5000 I 250~5000 1 250~5000 1 250~5000 2 250/5000 2 250/5000 N/A N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Gas Detectors P P H2S Detectors P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. 1 Test Pressure P/F 250/5000 P 1 25O/5OOO P 1 25O/5OOO P 1 250/5000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 15 Test Pressure P/F 250/5000 P 32 250/5000 P 1 P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure Attained 2 Blind Switch Covers: Master: Nitgn. Btl's: 3,100 P 2,000 P minutes 28 minutes 13 X Remote: 4 Bottles ( + 2 spares) 2500 Average Psig. SeC. sec. x TEST RESULTS Number of Failures: 0 ,Test Time: 5.00 Hours. Number of valves tested 29 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Hub Connection on riser leaked on initial pressure test, tightened and retested "OK". Good rig up. Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Louis R. Orimaldi FI-021L (Rev. 2/93) AOJJIYCD.XLS PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA_PLUS 91-133 CBT/GR 91-133 EPT 91-133 GCT 91-133 LDT 91-133 LDT/NEUTRON 91-133 ML/GR 91-133 MUD 91-133 PIL/GR/CAL 91-133 RFT 91-133 407 91-133 91-133 DAILY WELL OP SS DIRECTIONAL 91-133 DRY DITCH 91-133 5229 91-133 5230 L 5740-11434 L 7900-11545 L 0-11458 L 7900-10071 L 7900-11545 POROSITY L 10045-11542 L 4000-11560 L 4000-11542 L 8264-9630 R COMP DATE: 03/12/92 R 12/16/91-03/12/92 R 0-11560 S 4020-11560, SS#842 T 3995-11567, OH-DTE~DSI T 0-11560, GCT ~?~- Are dry ditch samples required? yes ~ And received? Was the well cored? yes ~Analysis & description received? Are well tests required? yes ~eceived? y~-~~ Well is in compliance Initial Comments ~. ~~) Page: Date: 1 03/21/94 2 04/21/92 1 04/21/92 3 04/16/92 1 04/16/92 1-2 04/16/92 2 04/16/92 04/16/92 1-2 04/16/92 1 04/21/92 04/09/92 04/09/92 04/09/92 04/16/92 1-2 04/16/92 3 04/16/92 RUN DATE_RECVD -------- Unocal North Americ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITYAL April 21, 1992 HAND DELIVERED TO: Larry Grant 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION FROM: Dick Stewart P O Box 196247 Anchorage AK 99519-6247 ALASKA REGION Granite Point Field ll-13RD Transmitting as Follows: Log Cemem Evaluation log ~ 1 EPT ~ 1 RFT / 1 Blueline Sepia PLEASE ACKNOWLEDGE RECEIPT OF THIS SIGNING AND RETURNING ONE COPY. THANK YOU. DATED: ~'--- ~/-- 7~ DOCUMENT TRANSMITYAL BY RECEIVED APR 2 1 1992 Alaska Oil & Gas Cons. Commission Anchorage Unocal North Americar Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Alaska Region UNOCAL ) DOCUMENT TRANSMITTAL April 16, 1992 HAND DELIVERED TO: John Boyle FROM: Dick Stewart 3001 Porcupine Drive Anchorage AK 99501 ALASKA OIL & GAS CONSERVATION COMMISSION P O Box 196247 Anchorage AK 99519-6247 ALASKA REGION Transmitting as Follows: Granite Point Field ll-13RD 1 blueline and 1 sepia as follows: ~'"' Phasor Induction log ~--Density Neutron Porosity log ~'~Litho Density log ~/~ Microlog ~~l~l'f GCT Directional Survey Mudlog op apes and listings: ,¢~o CT Direction Survey 7~/ .C ~ en Hole Edit .v(/ .;"2 2,7 ~_L~ 2- ashed and dried cuttings: 10 boxes covering the interval from 4020' MD to 11,560' MD. PLEASE ACKNOWLEDGE RECEIPT OF THIS SIGNING AND RETURNING ONE COPY. THANK YOU. DATED: DOCUMENT TRANSMITTAL BY RECEIVED APR 1 6 1992. Alaska Oil & Gas Gons. Oommission Anchorage Ab S ONS .V t, ONCO. S,ON WELL COMPLETION OR RECOMPLETION EPORT AND LOG : ; 1. Status of Well Classification of Service Well OIL ~ GAS D SUSPENDED D ABANDONED[Z] SERVICE D 2. Name of Operator :: 'i-' ~i i i'; ~' 7. Permit Number (UNOCAL) UNION OILCOMPANYOFCALIFORNIA 3. Address . 8. APl Number P.O. BOX 196247, ANCHORAGE, AK 99519 ,~-~' ~3~ ~ 50_733_20026_ 1 ,. 4. Location of well at surface GRANITE POINT PLATFOF~I LEG #3 CONDUCTOR #9 - ~' ;f; '~ 9. Unit or Lease Name UNOCAL- MOBIL STATE # 1 2384' FN L & 1368' FWL F/NW CORNER SECTION 13 T1ON, R12W, S.M. At Top Producing Interval ~ r~'~'rJ~ I 10. Well Number 11032' MD 1166' FNL & 1169' FWL F/NW CORNER SECTION 13 T10N, R12W, S.I~I.. -~~i 11--13 REDRILL At Total Depth~ ~'~'~'~-"~'~ ~J~'-R~J~ t 11. Field and Pool e~.-....~,~=,~.~ GRANITE POINT 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. MIDDLE KENAI 109 RKBI ADL- 18761 12. Date Spudded 13. Date T.D. Reached 114. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 01 -- 11 --92 02--25--92I 03-- 12--92I 75 Feet MSLI SINGLE 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional SUrvr~,~ 120. Depthwhere SSSV set ]21. Thickness of Pelmafrost YES ~[ NOI II 295 feetMDI NA 11560'MD / 11407'TVD 11510'MD / 11359'TVD 22. Type Electric or Other Logs Run DI L/DSI/M I_/GR/SP/LDT/CN I_/EPT/G R/FM I/RFT/AM S/C ET/GCT 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BO-I-I-OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 9- 5/8' 47 & 53.5# N - 80 / P- 110 0' 10060' 12-1/4" 1700 SXS 7" 32# P110 9787' 11560' 8-1/2" '700 SXS 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE I DEPTH SET (MD) I PACKER SET (MD) 2-7/8' 10950' 10926' 11032'--11220' MD 10903'-11082' TVD 11245'-11377' MD 11106'-11232' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED ALL AT 8 SPF NA 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lilt, etc.) 03--12-92I FLOWING Date of Test Hours Tested PRODUCTION FOF OIL-BBL GAS-MCF WATER-BBL CliO KE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water.Subn~.C l Di Alaska u. Form 10--407 rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed , TItle ~ . _ct , INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27'. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". 18" @ 684-' d-55 @ 401 2 TUBING DETAIL: 2-7/8", 6.4#, N-80, SC BU-I-I- ALL TUBING DEPTHS ARE DIL TOPS 1) OTIS TBG. RETRIEVABLE SSSV ~ 295' 2) CAMCO "KBMG" GAS LIFT MANI3RELS (16) 16) 9895' 15)94,3,3' 14)8977' 1,.3)8521' 12)8069' 11) 7567' 10) 7059' 9) 6553' 8) 6048' 7) 554,3' 6) 5037' 5) 4530' 4) 3806' 3) ,3093' 2) 2`340' 1) 1392' 3) OTIS "XA" SLEEVE @ 10906' 4) OTIS "BWB" PERM PACKER @ 10926' 5) OTIS "XN" NIPPLE @ 10948' 6) VAN TCP GUNS (,310' ACTUAL GUNS) 4-5/8" x 8 SPF DEEP PEN. 7" TOL @ 9787' 9-5/8" 53.5// Pl10 & 4-7 # @ 10060' 7" L @ 11560' 52# Pl10 N-80 DROP BAR (11') AT 11020' WELL PRODUCING THRU "BIT" AT 10982' TCP MECH. TUBING RELEASE AT lO984j~ [C[ ! V E APR - 9 1992 Alastla Oil .& Gas Cons. CDr HEMLOCK INTERVALS /~nchorage. 11032'- 11220' DIL 1124-5'- 1 1377' DIL CEMENT RETAINER AT 11510' ETD UNION WELL Granite Pt. 11- 13 Redrill ACTUAL COMPLETION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL SCALE' NONE DATE- 05- 16-92 mission Unocal Drilling/Workover Recor~ Alaska Region Lease: Unocal Mobil State Well: GP 11-13 Field: Granite Point Date: ETD: Details of Operation - Description/Results 12/16/91 9464' RU Myers wireline on long string and test lubricator. RIH with 2.25" gauge ring to 9464' WLM. RU on short string and RIH to SSSV. Pull SSSV, 1280 psi below valve. RIH with 2.625" gauge tool to 4500' WLM (3rd "CX" GLM). POOH. 12/20/91 Accepted PAA Rig #431 at 0000 hrs. RU dual landing joints on tree. Pumped 409 bbls fresh, water down short string with returns on the long string via GLM at 8971'. All string have zero pressure and annulus (tbg & csg) are dead. RU Meyers on short string and RIH to GLM at 4529. POOH with GLV. RIH to next GLM at 5352' and POOH with GLV. Crowned out and dropped GLV. RIH and located GLV at 5352'. Retrieve GLV and work up hole to 328'. Unable to move further. 12/21/91 Spear fish at 328' and attempt to work free, negative. Numerous attempts were made to retrieve, all negative. Worked fish up to 240'. Rig down Meyers. RU APRS on long string. 12/22/91 RIH with 2.125" jet cutter. Compare completion detail with collar locate, running 8' deep. Tie in and cut long string at 9459' WLM. RIH with 2.25" jet cutter and cut LS tubing at 8205' WLM. RIH and cut LS at 8038' WLM. Immediately gained 10 psi on tubing annulus. RU and pumped 484 bbls down LS taking returns on the annulus. RU on SS and RIH with collar locate to correlate completion detail. TOF at 286' one foot inside ball valve I ' Prep to set BPV. 12/23/91 Set FMC BPV(s) on each string. Nipple down tree. Discovered LS BPV not set correctly. Re-install tree. RU landing joints and circulate well with 39 bbls (dn the SS and returns on LS). Monitor well, Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 2 Date: m ETD: 12/23/91 cont. 12/24/91 9464' 12/25/91 12/26/91 12/27/91 12/28/91 12/29/91 mmm Details of Operation - Description/Results ok. RU Otis on LS and set "DW" plug at 66' below top of DCB spool. ND tree and begin installing BOPE. NU BOP and monitor well. BPH. Function test BOPE. NU. Fluid loss is 10 Continue with Test BOPE to 250 psi low and 5000 psi high. Test kill valve at top drive 250 low and 5000 high. Pre-test ok. RU on LS and retrieve tubing plug. Repeat same on SS. RIH on LS and cut tubing at 312' WLM. RIH on SS and cut at 60'. RU tong service. Pull and retrieve 60' of SS concentric tubing and 269.6' of LS. Tubing hangers did not come. MU spear and attempt to fish hanger, negative. RIH with taper tap and screw into fish at 43'. POOH, no recovery. RIH with taper tap #2 and screw into fish at 43'. POOH and recovered same. PU FMC test plug and attempt to set, negative. Search for proper test plug. Test choke manifold and top drive valves to 250 psi low and 5000 psi high. Test Koomey unit, all testing witnessed by Lou Grimaldi of the AOGCC. Continue to search for test plug. MU HOWCO bridge plug and attempt to set at 55', negative. Re-set plug numerous times without success, need weight below plug to set. Obtained verbal permission from the AOGCC to delay test until tubing is retrieved from well. Obtained modified test plug and set same. Test BOPE stack to 250 psi low and 5000 psi high. Lay down test plug and set wear bushing. PU and RIH with fishing assembly #1. Catch SS at 67' DPM. RIH with wireline and jar fish down to 289'. Continue to jar fish down to 351'. RU tubing cutter on SS and cut 3-1/2" tubing at 338' WLM. POOH. and recover 275.38' of 3-1/2" tubing from the SS including SSSV profile and control line. RIH and engage Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 3 Date: ETD: 12/29/91 cont. 12/30/91 9464' 12/31/91 01/01/92 01/02/92 01/03/92 Details of Operation - Description/Results LS at 327'. CBU. POOH with LS and recover 2-7/8" tubing and related jewelry. Recovered 7699.31' of 2-7/8" tubing and 8 GLMs. RIH with FA #2 and catch TOF at 345' DPM. Attempt to recover fish from short string without success. Attempt to release SS with right hand rotation, negative. POOH. RIH with outside tubing cut tool and cut SS at 418' DPM. POOH. Recovered tubing and fish. Re-dress overshot and catch TOF at 418'. RIH with impression block to 6025'WLM. Block revealed GLM valve top. RIH with pulling tool. Jar valve free and POOH. GLM lock broke in half. RU and cut SS at 6023'. POOH. Lay down tubing and GLMs. Recovered 5605.85' of tubing and 4 GLMs. Re-dress overshot and RIH while picking up drill pipe. Catch TOF at 6018' and perform blind backoff and POOH. Recovered 21.15' tubing and 1/2 of GLM. GLM had backed off at top threads in its body. GLV remains in the hole. RIH and catch TOF at 6038'. RU wireline and RIH. Spear GLV at 6643' and POOH. Recovered GLV. RIH with pulling tool to GLM at 7317' and latch valve. Jar valve free to 7310', no further movement. Shear off and POOH. RU and cut SS at 7321'WLM and POOH. POOH and recovered 1275.67' of 3-1/2" tubing. RU outside cutter and RIH while picking up drill pipe. Attempt outside cut at 7332'. POOH. No recovery. Redress overshot and RIH picking up bumper sub, jars and drill collars. Engage TOF at 7308', trip jars one time and fish appeared to pull free, had 30,000# drag. Circulate and lost all drag. POOH (slow). POOH. Lay down 3-1/2" tubing, recovered 801' of completion (jarred snap latch from packer). Re-dress overshot and RIH to TOF at 8024'DPM. Attempt to latch fish, Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 4 Date: ETD: Details of Operation - Description/Results 01/03/92 cont. 01/04/92 9464' 01/05/92 01/06/92 8025' 01/07/92 4170' negative. POOH. Re-dress overshot to catch collar and RIH. Engage fish to 8041'DPM. Jar on fish + six hours without success. Possible movement of 18"-24". POOH. POOH. Cut and slip drill line and service Nat'l power swivel. PU BHA and RIH to top fill at 8103'. Clean out fill to 8106'. CBU and pump high viscous sweep. Returns indicated fill was barite. POOH. Lay down BHA and MU BHA. RIH and engage TOF at 8041' and jar fish free, no increased drag or weight. POOH. Recovered 32.75' of 2-7/8" tubing. TOF at 8056'. RIH with 8-1/2" bit and 9-5/8" casing scraper to 8050'. Circulate. POOH. RU wireline and pick up gyro survey tool. RIH with gyro to 7950'. Survey wellbore to 3200' at 25' stations and from 3200' to surface at 100' stations. RU Schlumberger and RIH with CBT/GR/CCL to 4300' and log back to surface without pressure applied to casing. Change upper pipe rams. RIH with Howco EZSV and set at 8025'DPM. Pressure test backside to 3500 psi for 5 minutes. RU Dowell cement unit and pressure cement line, choke/kill/standpipe system to 7500 psi. Correct cement unit equipment problems and leaks as required. Function test cement unit with 50 sacks of cement. Pressure test DS cement lines to 7000 psi, ok. Apply 1000 psi to annulus. Establish breakdown rate on Tyonek intervals from 8246'-9835'DIL with 4 BPM at 930 psi. Down squeeze through cement retainer with 5 bbls water ahead, followed with 143 bbl of 15.8 ppg cement at 4 BPM and 220 psi. Begin displacement with water and pressure increase to 2175 psi FSP. Un-stab from retainer and dropped 3 bbls cement on top. Pull 5 stands and reverse circulate DP. POOH. A total of 700 sx of class "G" cement with 0.2% D65, 0.25% D800 and 0.05 gal per sx D47. Make Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 5 Date: ETD: Details of Operation - Description/Results 01/07/92 cont. up 9-5/8" cement retainer and RIH. Set same at 4170 DPM. POOH. Perform BOPE test. Lay down test plug. 01/08/91 Make up 9-5/8" casing cutter and RIH. Perform mechanical casing cut at 4120'. Circulate and POOH. RIH with 9-5/8" casing spear. Change pipe rams. Spear casing at ± 100' and pull casing free with 250,000# (minus 80,000# for Hook etc.) Pull casing 7' and circulate well, some gas. Pull casing and begin to lay down same. Casing mandrel and packoff in good condition. 01/09/92 4170' Continue to lay down casing. Rig casing tools and fishing BHA. Clean mud pits and RIH with underreamer assembly to 4000'. CCM. Underream open hole to 17-1/2" beginning at 4043' (first encountered weight) to 4118'. CBU. POOH. 01/10/92 3787' Continue to POOH and lay down underreamer assembly. Pick up tubing stinger (12 joints) and RIH to 4170'. Circulate and displace mud with fresh water. Pull to 4018' and test surface lines to 3000 psi. Perform leak off test (LOT) on 13-3/8" casing shoe at 4018'MD/3992'TVD using water .433 psi/ft and surface pressure of 930 psi equates to a 12.8 ppg EMW. RIH to 4163'. RU Dowell and pressure test lines to 5000 psi. Pumped 30 bbls of 2% caustic pre-flush, 26 bbls spacer "Mud Pusher" at 11 ppg, mixed and pumped 425 sacks of class "G" cement with 0.75% D65 and 0.05 gps of D47 to a slurry weight of 17 ppg, followed with 3.6 bbl of spacer and displaced with water to balance plug from 4163' to 3787'. Pull to 2992' and squeezed 1/2 bbl with 100 psi applied for 3 hours. POOH and lay down tubing. CIP at 1600 hrs, estimate TOC at 3787'. WOC. Note: This completes the plug and abandonment for Granite Point #11-13 per the approved sundry application (Permit #67-33 / Approval #91-334). Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 6 -Date: ETD: Details of Operation - Description/Results 01/11/92 01/12/92 01/13/92 01/14/92 01/15/92 01/16/92 3787' 4076' 4124' 4229' 4345' 4496' Continue to WOC. Perform miscellaneous maintenance and other minor construction projects. Lay down 6-1/2" drill collars and install 13-3/8" wear bushing. PU drilling BHA #1 (Steerable motor), 47 joints of 5" HWDP, jars and test Teleco MWD. RIH. RIH to 3856' TOC and drill soft cement stringers to 3881' (hard cement). Drill 12-1/4" hole of hard cement to 4010' and circulate. Pressure test 13-3/8" casing to 2000 psi for five minutes, ok. Drilled 12-1/4" hole in hard cement to 4033'. Orient motor assembly and begin time drilling at 4033' KOP. Time drill to 4076'. Continue to time drill from 4076'-4105'. Pull to 13-3/8" shoe and perform LOT. Unable to achieve leak off at 2000 psi which is maximum allowable on the 13-3/8" casing. Discharge and clean pits, mix and build drilling mud system. Directional drill 12-1/4" from 4105' to 4124'. Drilled to 4229'. POOH for bit change. Test choke manifold and BOPE. Attempt to set test plug, unable to obtain seal. Re- set plug and ruined three sets of seals. RIH with storm packer and set at 61' to isolate wellbore. Test packer to 2000 psi, ok. Lift BOP stack and inspect wellhead. Located lock down pin from old tubing hanger protruding into seal area. Remove lock down pin. Re-install BOP stack. Run test plug in place. Lift BOP stack and test plug now in proper position. Re-install BOP stack and prep to test BOP. Test BOPE to 5000 psi, ok. RIH with BHA #1 and drilled 12- 1/4" hole from 4229'-4345'. Drilled 12-1/4" from 4345'-4454'. CBU. POOH. Discovered mud motor shaft had parted. RIH with BHA #2 (Rotary semi packed assembly) to 4400'. Ream to 4454' and drilled to 4496'. Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page ? ___ Date: ------ 01/17/92 01/18/92 01/19/92 01/20/92 01/21/92 01/22/92 01/23/92 01/24/92 ETD: Details of Operation - Description/Results ---- 5060' Drilled 12-1/4" hole from 4496' to 4765'. Short trip eight stands, good hole conditions. Drilled to 5060'. 5588' Drilled 12-1/4" hole from 5060' to 5152'. Short trip six stands, good hole conditions. Drilled from 5152' to 5452'. Short trip another six stands, hole conditions ok. Drilled from 5452'-5588'. 5899' Drilled 12-1/4" hole from 5588' to 5710'. Short trip five stands. Drilled from 5710' to 5899'. CBU. POOH. Make BHA #3 (rotary semi-packed assembly) and RIH. 6500' Drilled 12-1/4" hole from 5899' to 6202'. Short trip seven stands. Drilled from 6202 to 6500'. 6971' Drilled 12-1/4" hole from 6500' to 6590'. Short trip nine stands. Drilled to 6928'. Short trip six stands, tight spots and swabbing action from 6644'-6457'. Drilled to 6971'. 7119' 7400' 7501' Drilled 12-1/4" hole from 6971'-7112'. CBU. POOH. Test BOPE. Make up BHA #16 (steerable motor) and RIH to 4018'. Slip and cut drilling line. Directional drilled from 7112'-7119'. Directional drilled 12-1/4" hole fr 7119'-7400' with motor assembly. Directional drilled 12-1/4" hole from 7400'-7466' with motor assembly. POQ~%\~.~e~%~ Change out BHA for rotary (semi-pac~3. RIH. Ream from 7406'-7466'. Drilled 12-1/4" hole to 7501'. 01/25/92 7829' Directional drilled 12-1/4" hole from 7501'-7654'. Short trip to 7143', hole conditions good. Drilled from 7654'-7820' short trip to 7330' hole conditions good Drilled to 7829'. Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 8 Date · 01/26/92 01/27/92 01128192 01/29/92 01/30/92 01/31/92 02/01/92 02/02/92 02/03/92 02/04/92 02/05/92 02/06/92 ETD: 8076' 8306' 8597' 8728' 8870' 9054' 9196' 9407' 9560' 9752' 9990' 10082' Details of Operation - Description/Results Continued drilling to 7951'. Short trip to 7424', good hole conditions. Drilled to 8076'. CBU. CCM. POOH, tight spots at 5839' and 5742'. POOH. Change out bit and drilling jars. Make up BHA #18 (rotary semi-packed) and RIH. Wash and ream from'7826'-8076'. Drilled 12-1/4" hole from 8076'-8306'. Drilled 12-1/4" hole from 8306'-8447'. Short trip to 7895' tight spot at 8387' Drilled to 8597'. Drilled 12-1/4" hole from 8597'-8668'. Short trip six stands, ok. Drilled from 8668'-8728'. CBU and CCM. POOH. Completed POOH. Test BOPE. Make up BHA #18 with a new bit and RIH to 4018'. Slip and cut drilling line. RIH and ream from 8641'-8728'. Drilled to 8870'. Drilled to 9054'. POOH. Change out bit and RIH. Ream from 8826'- 9054'. Drilled to 9100'. Backed reamed tight spot from 9054-'9013'. Drilled to 9196'. Drilled from 9196'-9407'. Drilled 12-1/4" hole from 9407'-9512'. Short trip six stands, ok. Drilled and survey from 9512 '-9560'. CBU. POOH for bit and BHA change. Make up BHA #20 and bit #10. RIH and ream from 9382'-9560'. 12-1/4" hole from 9560'-9752'. Drilled Continue drilling 12-1/4" hole from 9752'- 9882' Short trip from 9882'-9382' hole conditions good. Drilled from 9882'- 9990'. Drilled to 10082' 9-5/8" casing point ! · CBU and short trip to 9200'. RIH to 10082' and circulate and condition mud. POOH. Lay down BHA and perform BOPE test. Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 9 Date: ETD: Details of Operation - Description/Results 02/07/92 02/08/92 02/09/92 02/10/92 10082' Rig Schlumberger and RIH with Log run #1 (Phasor Dual Induction/Dipole Sonic/Microlog/Gamma Ray/SP). Tagged bottom at 10072'WLM. Logged to the 13- 3/8" casing shoe at 4018'. POOH. RIH with log run #2 (Density/CNL/EPT/GR) and logged same interval. POOH. RIH with log run #3 (FMS - Image & Dipmeter mode). Experienced tool telemetry problems at 7700' on way in hole. POOH. Changed out FMS and telemetry card on GR/AMS. RIH and problem occurred at 7900'. POOH. Changed out AMS/GR and RIH to 10079'. Logged interval to 4018'. RIH with BHA #21. Tagged tight hole at 9897' DPM. Ream fro 9897' to 10082'. CCM. Completed CCM. POOH. RU Schlumberger and RIH with log run #4 (RFT). Obtained 14 sets at intervals from 8264' (2450 psi) to 9630' (1965 psi). POOH. RIH with BHA #21 to 10082' and CCM for 9-5/8" casing. POOH. Completed POOH. Lay down BHA, pull wear bushing and change top rams to 9-5/8". RU to run 9-5/8" casing. Pick up 80 joints of 9-5/8", Pll0, 53.5# casing off boat and RIH. Made up Howco float shoe, two joints of 53.5# Pll0, Howco float collar, with (75) "S-4" bow spring centralizers ran over collars beginning on joint #1, 3 thru #76, ran total of 80 joints of 53.5# Pll0 and 160 joints of 47#, N-80 back to surface. Made of casing crossover (Butt pin x 8rd pin) to FMC fluted hanger with crossover (8rd pin x Butt box) landing joint. Tagged bottom at 10073' csg meas. RU cement circulating head and establish circulation. Moved casing string with 600-625,000 #. Pulled up 16' when fluted hanger caught itself in lower pipe ram cavity. Casing immediately parted, suspect in top of hanger. Shut down operations while securing rig. Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 10 Date: 02/11/92 02/12/92 ETD: Details of Operation - Description/Results 9975' Cut and slip drilling line. PU and MU casing spear with packoff. RIH and engage casing fish at 39' (bottom of fluted hanger 3.30' above wellhead profile). Pulled 675,000#, negative movement. Attempt to circulate, negative. Continue to work casing, eventually broke circulation and re-stored pipe movement. Worked fluted hanger through BOP stack. CCM while working pipe, verified casing integrity with circulation count and pressures, and pipe movement. Lay down casing spear and packoff. RU and PU two additional joints of 9-5/8" casing. Made of two joints and RU cement circulating head. CCM, had original pressure and pump rate before incident. Ready to cement, pumped 25 bbls water, dropped plug #1, pumped 75 bbls of MudPush spacer weighted at 11.5 ppg, dropped plug #2. Pressure tested cement lines to 3000 psi, ok. Mixed and pumped 1700 sxs (351 bbls) at 5 BPM of class "G" cement with .05 gps D47, 0.1 gps D135, 1.0 gps D600 and 0.025 gps DS01 to a slurry weight of 15.8 ppg. Dropped plug #3 followed with 10 bbls of water behind. Displaced with drilling mud at 11.5 BPM. Pumped 716 bbls of mud displacement, shut down and check plug drop on #3, ok. Check floats, ok. Pumped and additional 22 bbls and bumped plug with 2500 psi, plug held. Total displacement was 104% of theoretical. CIP at 2055 hours. Casing shoe for 9-5/8" at 10056' csg meas. Reciprocated casing throughout entire job (up wt max of 675,000# / dn wt min of 400,000#) with full mud returns. Estimated TOC at 7100'. Top of 9-5/8" 53.5# Pll0 at 6773' csg meas. Raised BOP stack and set FMC emergency slips "C-22" with 500,000# hanging weight. 9975' Rig down cement head and lay down one joint of casing. Cut casing above wellhead and install FMC packoff device, test same to 3800 psi, ok. Drill out tubing hanger hold down screws, tap same and replace. Clean active mud system and build new mud (439 bbls). Lay down ...... Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 11 Date: ETD: Details of Operation - Description/Results 02/12/92 cont. 02/13/92 10018' 02/14/92 10133' 02/15/92 10305' 02/16/92 10352' 02/17/92 10489' fishing tools and nipple up BOP. Test choke manifold and prep test plug. Completed test plug preparation and set same. Test BOPE. Pick up and RIH with BHA #21 (rotary building assembly). Tagged float collar at 9979'DPM (4' deep). Test casing to 3000 psi for 30 minutes, ok. Drilled wiper plugs, float collar and soft cement to 10018'. Lost pump pressure. Investigate problem and discovered rubber piece from plugs had packed off in pumps and Teleco screens. Remove rubber from active pit system, mud pumps, and drill string. Circulate down hole from 10018'-10022'. Drilled hard cement to 10050'. Test casing to 2500 psi for 15 minutes, ok. Drilled cement to float shoe at 10060'. Lost SCR system, down time of 2.5 hours. Test 9-5/8" casing to 5000 psi for 10 minutes, ok. Drilled float shoe to 10063'. Perform L.O.T. to 4420 psi at surface, no break down. Limited at surface with mud pumps. Test equates to a 18.4 ppg EMW. Circulate and increase mud weight to 76 pcf. Directional drilled 8- 1/2" hole to 10133'. Drilled 8-1/2" hole from 10133'-10246', check for flow, increase mud weight to 79 pcf. Drilled to 10305', short trip to casing shoe at 10060'. Perform load test on SCR. Continue with load test, down 3 hours for SCR problems. RIH and drilled to 10311'. POOH for bit change. RIH and ream from 10060'-10311' (rough, coal sloughing). Drilled 8-1/2" hole to 10352'. Drilled from 10352'-10406'. Increased mud weight to 82 pcf. Short trip to casing shoe. RIH and drilled 8-1/2" hole to 10489'. Experienced trip gas of 3425 units. Increase mud weight to 85 pcf. CBU. POOH for BHA change. Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 12 Date: ETD: Details of Operation - Description/Results 02/18/92 02/19/92 02/20/92 02/21/92 02/22/92 02/23/92 10605' 10774' 10947' 11004 11222' 11362 ' POOH and make up BHA #23 (semi-packed rotary). RIH and ream from 10349'-10489'. Drilled 8-1/2" hole from 10489'-10605'. Drilled to 10718' Short trip to 9973' - , trip out good. RIH to 10112' and took weight. Ream from 10112'-10142', RIH and tight at 10290'-10315'. Ream entire interval to 10718' Drilled to 10738' after 5' drilling break picked up and back reamed, no decrease in torque. Picked up and unable to pull through. Worked tight spot from 10730'-10735', unable to back ream or move up/d~~"~ Jar on drill string for 40 minutes. Eventually able to slack off and gained rotation. Picked up and back reamed. Increased mud weight from 85-90 PCF, gas of 3675' u~ ~~'i~~b~ck ~round a ' s~.~ from 90-400 units. Drilled 8-1/2" hole from 10738'-10774'. ' Drilled and surveyed 8-1/2" hole from 10774'-10947', connection gas 220 units and back ground increased from 40-90 units. Increased mud weight from 90 to 94 PCF. POOH ~- ~ ........................................................................................ POOH. Test BOPE. Picked up BHA #24 (slight pendulum dropping assembly) and RIH to 10135' (tight). Reamed entire open hole interval from 10135'-10947'. Drilled from 10947'-11004'. Increased mud weight from 94 to 97 PCF. Drilled from 11004'-11222'. Short trip to 9994' tight spots at 10302' 10218' 10145'. RIH to 11004' and break circulation, loss 600 psi of pump pressure. At bottoms up had 3675 units of gas and oil show on the pit. Increased mud wei~ht to 101 PCF~ appears l~S~§~i~ ~~~'~~'~on bit. pressure POOH, one blown out jet on bit. Make up new bit and RIH, ream from 11115'-11222'. Drilled and surveyed 8-1/2" hole from 11222'-11362,. Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 13 Date: ETD: Details of Operation - Description/Results 02/24/92 11486' Drilled to 11486' and CBU. POOH, tight from 11050'-10928' pulled 80M# overpull. POOH. 02/25/92 11560' POOH. Make up BHA #26 (semi-packed rotary) and RIH. Ream from 11397'-11486'. Drilled and survey 8-1/2" hole from 11486- 11560' total depth. CBU. 02/26/92 11560' POOH to 9-5/8" casing shoe at 10060'. Circulate and RIH to l1560'TD. CCM for open hole logs. POOH. Rig up Schlumberger and RIH with log run #1 (DITE/DSI,GR,ML,AMS). Logged interval from 11548' DIL to 10060'. POOH. RIH with log run #2 (FMI,GR). Logged same interval and POOH. RIH with log run #3 (LDT,CNL,GR,AMS). 02/27/91 11560' Completed open hole log run #3. RIH with o 11560'. Circulate and condition mud for 7" liner, POOH. Rig up to run casing, hold safety meeting. Pick up TIW "CLS-2" set shoe (Pll0) and make up on bottom of 7" 32# Pll0, one joint of casing and a type "L" float collar (L80) on top, one joint of casing then a type "L" landing collar (Pll0) on top. All float equipment was Baker Locked and joints #1 & 2 had a Milam turbolator centralizer set screwed in place halfway on each joint. Continued to make up 7" liner and installing two turbolators (free floating) on each joint separated with a dog collar (set screw in place halfway on each joint). Ran a total of 41 joints (1750.11') of 7" 32# Pll0 casing all with TKC Buttress connections. Picked up a TIW 7" 32# x 9-5/8" 53.5# single cone I/B Hydro hanger of Pll0 grade. Hanger includes a "LG-6" tieback sleeve of Pll0 grade. Circulate entire liner volume and RIH filling every 10 stands. 02/28/91 Continue RIH with 7" liner to 9830' Make up circulating head, top drive swivel manifold and flag sub, stand back in derrick. Perform rotating and torque test and record up/dn weights. RIH (slow), tight knot at 10156', drilled through Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 14 Date- 02/28/92 02/29/92 03/01/92 ETD: Details of Operation - Description/Results cont. interval and RIH. Circulate, reciprocate and rotate liner while mixing spacer. With cement unit pump 5 bbls water ahead, test lines to 3500 psi (ok), pumped 5 bbls water, 53 bbls of spacer (14.5 ppg) with rig pump. Pumped 700 sx of 15.8 ppg class "G" cement with 0.05 gps D047, 0.05 gps D080, 0.1 gps D135, 0.03 gps D801, and 1.0 gps D600. Dropped wiper plug and chased with 10 bbls water behind. Displaced with mud (13.5 ppg) using rig pumps, at 1689 stk did not see plug catch wiper plug, at 2184 stk did not bump as calculated, continued to pump and 2289 stk plugs began to bump, pressure increase from 600 to 3000 psi. At this point the pop offs on the mud pumps blew. Attempt to reset plugs, negative. Pumped a total of 2557 stks. Set liner on bottom at 11560'. Release from hanger and pulled five stands (1-3 wet, 4 & 5 dry). Reverse circulated, had approximately 50 bbls of clabber mud and good cement. POOH. Lay down liner tools and prepare to test BOPE. Planned for TOC to be + 200' above TOL which is at + 9787' DPM. '9787' Test BOPE. RIH with 8-1/2" clean out assembly and tagged TOC at 9338'. Soft cement to 9362'. Cleaned out firm cement from 9362' to 9787' DPM and TOL. CCM. POOH. RIH with 6" clean out assembly while picking up 3-1/2" drill pipe and 4-3/4" drill collars. 11513 ' RIH and tagged cement at 9796', cleaned out to 9799'. RIH to 11467' top of plugs, drilled out plugs and landing collar to the float collar at 11513' ETD. No cement between LC and FC. CBU and monitor well, ok. POOH. RU Schlumberger and RIH with USIT/CBT/GR to 11200' and tool set down. Attempt to work tool deeper, negative. POOH. Rig up and RIH with CET/GR log to 11205' and tool set down. Logged interval from 11165'-10075' with 1000 psi applied to annulus. Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 15 Date: ETD: Details of Operation - Description/Results 03/02/92 03/03/92 03/04/92 03/05/92 11513 ' 11510' POOH. Configure CET/GR tool for 9-5/8" and RIH. Logged interval from 9780'-5750' with 1000 psi applied to annulus. POOH. RIH with tandem (7" & 9-5/8") casing scrapers to 11513' ETD, no problems RIH. CCM and increase MW from 97-101 pcf. POOH. RU Schlumberger and RIH with CET/GR to 11450', unable to reach ETD. Log interval from 11450'-9750' with 1000 psi applied to annulus. POOH. POOH. Pick up GCT (Gyro) and RIH to 10200', unable to go deeper. Gyro wellbore from 9787' to surface. RIH with RTTS packer, multi-service valve and set same at 9710'. Perform 1500 psi dry test on liner lap. Test indicated fluid entry into wellbore ( ± 80 bbls). Open by-pass on RTTS and circulate well through choke system. Continue to circulate well on choke. Gas units of 5000 high, shut-in well SIDPP=550 psi and SICP=600 psi. Circulate well on choke with 600 psi back pressure. Gas level at 880 units. Continue to circulate with increased back pressure of 850 psi. Increased mud weight to 101 pcf. Rig up DS and test lines to 10000 psi. Attempt to bullhead 65 bbl, negative at 8500 psi (surface). Bleed pressure and shut-in well, SIDPP=75 psi in 35 minutes. Build 200 bbls of mud volume and increase mud weight to 105 pcf. Circulate mud around while on choke with 880 psi back pressure. Circulate mud and monitor wellbore. POOH, slowly. Pick up 7" EZSV retainer and RIH to 11510' DPM, break circulation and set same. Test below retainer to 4500 psi, pressure held. Circulate well, gas units were 5000+ (high) and level at 620 (low). Monitor well and check for flow, negative. POOH, pick up 9-5/8" RTTS, multi -service valve and RIH. Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 16 Date: 03/06/92 03/07/92 03/08/92 03/09/92 03/10/92 ETD: 11510' Details of Operation - Description/Results Set RTTS at 9718'DPM with tail at 11451', cycle valve open and dry test liner lap to 1500 psi, test indicates a good lap. Release packer and reverse circulate. Entire mud system (hole and active pits) contains 10% oil and will not pass sheen test. Agreed to process mud through centrifuges and strip out solids. Continued to process mud system, completed processing 821 bbls from 14 ppg to 12.4 ppg. Displace oily water to gross production system. Reverse circulate well to displace hole volume with raw seawater. Completed displacement of wellbore with raw seawater. Clean active pit system. Reverse circulate 200 bbls fresh water, followed with 50 bbls of 2% caustic sweep, repeat the same water/caustic sweep two more times. Circulate long way with a 100 bbl sweep of 4.2 ppb of "Dirt Magnet", followed with 100 bbls of fresh water. Displace entire hole volume with fresh water and 3% KCL completion fluid. Complete displacement with completion fluid. POOH. Lay down RTTS packer and service tools, continue POOH. Rig up Schlumberger and RIH with GCT (gyro) tool. Survey wellbore from l1457'WLM to surface. Did not tag 11510' ETD due to concern for damage to gyro tool. Pick up Vann TCP guns 4-5/8" OD x 8 SPF with 25 gram deep penetrating charge set for 60 degrees phasing to perforate the intervals 11032'-11210'; 11245'-11377' DIL. RIH with TCP guns on bottom of Otis "BWD" permanent drillable packer and tail assembly on drillpipe. Complete RIH with TCP guns and packer. Rig up Schlumberger and RIH with gamma ray to correlate TCP guns on depth. POOH. Drop packer setting ball and set Otis "BWD" 7" permanent packer at 10940' DIL. Release from packer and POOH. Lay down 3- 1/2,, DP and 4-3/4" DC. Change BOP rams to 2-7/8" and rig up to run completion string. RIH with Otis seal assembly, Unocal Drilling/Workover Record Granite Point 11-13 Redri11 Page 17 Date: ETD: 03/10/92 cont. 03/11/92 11510' 03/12/92 Details of Operation - Description/Results completion equipment and 2-7/8" tubing all hydro-testing to 5000 psi. Completed running 2-7/8" single completion while hydro-testing, no connections failed. Install SSSV and stab seal assembly into packer and test backside to 500 psi. Space out tubing string, install FMC tubing hanger "UH-A" and control line to SSSV. Land tubing hanger and test seals to 500 psi, ok. Install BPV, remove BOP and install CIW 3" 5M valve tree. Test tree to 5000 psi and noticed leak via the tubing hanger in the wellhead. Remove tree and pick up tubing hanger to change out seals. Change seals twice and each time pressure test failed. Wait on seals. Installed new version of seals and test seals, tree and control line to 5000 psi. Rig up Otis wireline and test lubricator to 1000 psi, ok. RIH and shift open XA sleeve at 10905'WLM. POOH. Displace the tubing with Nitrogen bottles until tubing pressure was 750 psi, taking returns on the annulus. RIH with and shift close XA sleeve. Confirm XA is closed by pressure up on the tubing with Nitrogen, ok. POOH. Rig up drop bar for TCP guns and lubricator. Equalize lUbricator with tubing pressure. Prepare production equipment for well production. Bleed tubing pressure from 750 to 500 psi. Underbalance is ± 3000 psi with a 500 psi cushion of Nitrogen. Dropped TCP firing bar and detonate TCP guns at 1317 hrs. Perforated the Hemlock at intervals from 11032-11210'; l1245'-l1377'DIL. Released rig at 1200 hrs and prepare for move to well ~32-13. ORIGINAt SUB- SURFACE DIRECTIONAL SURVEY [~ UIDANCE F~ ONTINUOUS ~-~ OOL RECEIVED APR - 9 t992. Na~ .O.i! ,& Gas OoHs. Oommkssto~ Company UNOCAL I I I I I I I I II JII I I Well Name GP ll-13RD(2384'SW & 1368'E OF NW CORNER,SEC 13,T10N,R12W)_ I II I II · I I I I I I II Field/Location GRANITE POINT, KENAI, ALASKA iii , i II I I II i Job Reference No. 92182 Lo. q~ed. By: MC CROSSAN Date 9-MARCH-92 Computed By:, R. KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR UNOCAL GP 11-13 RD GRANITE POINT KENAI, ALASKA SURVEY DATE: 09-MAR-92 ENGINEER: MCCROSSAN METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: TANGENTIAL- Averaged Oeviation and azimuth LINEAR HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 85 DEG 0 MIN EAST COMPUTATION DATE: 12-MAR-92 PAGE 1 UNOCAL GP 11-13 RD GRANITE POINT KENAI, ALASKA DATE OF SURVEY: 09-MAR-92 KELLY BUSHING ELEVATION: 110.90 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN ENGINEER: MCCROSSAN 0.00 -110.90 0 0 N 0 0 E 99.98 -10.92 0 0 S 32 21 E 199.98 89.08 0 56 5 69 52 W 299.90 189.00 2 52 S 76 13 W 399.71 288.81 4 11 N 63 2 W 499.43 388.53 4 18 N 57 54 W 599.15 488.25 4 21 N 56 4 W 698.85 587.95 4 20 N 55 38 ~ 798.60 687.70 3 54 N 55 48 ~ 898.38 787.48 3 23 N 56 1 ~ VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DISTo AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 0 45 -0 12 -3 59 -9 34 -15 42 -21 38 -27 27 -32 8~' -37 87 0 O0 100 O0 200 O0 300 O0 40O O0 500 O0 600 O0 70O O0 800.00 900.00 1000.00 998.24 887.34 1100,00 1098.14 987.24 1200.00 1198.06 1087.16 1300.00 1298.00 1187.10 1400.00 1397.94 1287.04 1500.00 1497.92 1387.02 1600.00 1597.88 1486.98 1700.00 1697.87 1586.97 1800.00 1797.83 1686.93 1900.00 1897.82 1786.92 2000 O0 1997 80 1886.90 78 1986 88 73 2086 83 72 2186 82 68 2286 78 65 2386 75 61 2486 71 58 2586 68 54 2686 64 O0 2O97 O0 2197 O0 2297 O0 2397 O0 2497 O0 2597 O0 2697 O0 2797 2 56 N 58 31 ~ 2 30 N 57 19 W -45 2 4 N 56 34 W -49 1 47 N 53 41 W -51 1 34 N 52 7 W -53 1 27 N 52 8 W -55 1 23 N 51 43 W -57 1 15 N 52 43 W -59 1 15 N 50 41 W -60 1 16 N 52 4 W -62 -42 17 97 05 62 80 72 51 16 72 29 2100 2200 2300 2400 2500 2600 2700 2800 2900 1 16 N 53 57 W 1 21 N 52 10 W 1 22 N 56 18 W 1 23 N 52 16 W 1 26 N 54 40 W 1 23 N 55 50 W 1 25 N 53 48 W 1 24 N 54 40 W 1 25 N 54 10 W 1 19 N 54 8 W -63.99 -65.68 -67.50 -69.30 -71.11 -73.02 -74.84 -76.74 -78.62 -80.38 O0 2897.53 2786.63 -82.27 -85.26 -89.27 -91.87 -92.06 -88.82 -82.14 -74.09 -65.87 -57.81 3000.00 2997.50 2886.60 1 43 3100.00 3097.34 2986.44 4 27 3200.00 3196.87 3085.97 6 37 3300.00 3296.06 3185.16 7 59 3400.00 3394 77 3283.87 10 27 3500.00 3492 59 3381.69 13 23 3600.00 3589 39 3478.49 15 12 3700.00 3685 85 3574.95 15 24 3800.00 3782 21 3671.31 15 36 3900.00 3878 50 3767.60 15 35 N 53 56 W N 34 31W N 23 1W N 11 54 W N 0 31W N 7 42 E N 12 10 E N 12 53 E N 12 47 E N 12 10 E 0.00 0.03 1 .87 2.01 1.1,4 0.02 0.34 0.25 0.73 0.73 2 6 ;1 15 18 0 O0 N 0 90 S 1055 2285 1 03 S 75 N 80'N 07 N 17 N 75 N 0 O0 E 0 53 E 0 02 W 3 40 W 9 29 W 15 72 W, 22 06 W 28 35 ~' 34 39 0.00 N 0 0 E 1 .05 S 30 46 E 1.05 5 1 17 W 4.10 S 56 8 W 9.34 S 83 4O W 15.96 N 80 5 W 23.09 N 72 52 W 30.43 N 68 40 W 34 W 37.54 N 66 10 W 65 W 43.86 N 64 41 W 0 28 0 32 0 38 0 39 0 29 0 35 0 07 0 49 0 O0 0 O7 21 72 I~ 24 26 28 29 31 33 34 35. 37 44 23 W 20 N 48 27 W 36 N 51 55 W 27 N 54 29 W 98 N 56 63 W 59 N 58 70 W 06 N 60 63 W 51N 62 41W 86 N 64 23 N 65 66 69 71 09 W 73 79 W 75 49 28 N 63 51W 54 O0 N 63 22 W 57 90 N 62 55 W 61 21 N 62 30 W 64 08 N 62 6 w 66 N 61 43 W 06 N 61 24 W 31 N 61 4 W 44 N 60 46 W 59 N 60 30 W 0 11 0 O0 0 30 0 08 0 47 0 47 0 09 0 24 0.06 0.04 38.52 N 39.91 N 41.31N 42.72 N 44.21 N 45.63 N 47.09 N 48.48 N 49.9.1N 51.30 N 67 61W 69 71 73 75 77 79 81 83 85 77 81 N 60 20 W 42 W 80 37 W 82 30 W 84 25 W 87 29 W 89 24 ~' 92 28 W 94 28 W 97 17 w 99 08 N 60 6 W 46 N 59 56 W 84 N 59 46 W 28 N 59 34 W 75 N 59 27 W 18 N 59 17 W 64 N 59 11 W 10 N 59 4 W 43 N 58 56 W 1 .87 3.04 2 37 2 07 3 48 321 0 90 0 17 0 17 0 59 52.68 N 87.19 W 101.87 N 58 51 W 56.65 N 90.55 W 106.81 N 57 58 W 65.23 N 95.32 W 115.51 N 55 37 W 77.36 N 98.99 W 125.63 N 52 0 W 93.16 N 100 57 W 137.08 N 47 11 W 113.79 N 99 11 W 150.90 N 41 3 W 138.41 N 94 57 W 167.63 N 34 21 W 164.18 N 88 74 W 186.63 N 28 24 W 190.26 N 82 77 W 207.48 N 23 31 W 216.51 N 76 98 W 229.79 N 19 34 W COMPUTATION DATE: 12-MAR-92 PAGE 2 UNOCAL GP 11-13 RD GRANITE POINT KENA[, ALASKA DATE OF SURVEY: 09-MAR-92 KELLY BUSHING ELEVATION: 110.90 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/5OUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3974 88 3863.98 15 22 N 11 58 E -49 99 4100.00 4071 4200.00 4169 4300.00 4267 4400.00 4365 4500.00 4463 4600.00 4561 4700.00 4659 4800.00 4758 4900.00 4856 84 3960.94 13 29 N 4 18 E -44 38 27 4058.37 12 31 N 21 50 W -41 99 15 4156.25 11 4 N 4 50 W -40 99 34 4254.44 10 56 N 8 18 W -41 65 49 4352.59 11 0 N 9 4 W -42 85 71 4450.81 10 48 N 9 55 W -44.30 98 4549.08 10 30 N 10 47 W -46.01 34 4647.44 10 14 N 11 50 W -47.98 77 4745.87 9 58 N 12 39 W -50.22 1 25 2 69 1 10 1 77 0 55 0 2,5 0 39 0 42 0 27 1 O8 242 62 N 71 41 W 252.91 N 16 24 W 266 83 N 67 289 28 N 67 309 73 N 68 328 51N 7O 347 38 N 73 366 04 N 76 384.24 N 79 401.90 N 83 419.13 N 87 90 W 275.33 N 14 17 W 46 W 297.04 N 13 8 W 24 W 317.16 N 12 26 W 55 W 336.00 N 12 7 W 40 W 355.05 N 11 56 W 49 ~' 373.95 N 11 48 W BO ~ 392.44 N 1t ~4 W 32 W 410.45 h 11 43 W 08 W 428.08 N 11 44 W 5000.00 4955 34 4844.44 9 39 N 13 20 W -52 59 5100.00 5053 5200.00 5152 5300.00 5251 5400.00 5350 5500.00 5449 5600.00 5548 5700.00 5647 5800.00 5746 5900.00 5845 98 4943.06 9 15 N 14 11 W -55 71 5041.81 8 57 N 15 22 W -57 52 5140.62 8 49 N 16 31 W -60 36 5239,46 8 39 N 17 29 W -63 25 5338.35 8 33 N 18 41 W -67 13 5437.23 8 24 N 20 36 W -70 10 5536.20 8 16 N 21 48 W -74 09 5635.19 7 56 N 22 32 W -78 16 5734.26 7 55 N 24 4 W -83 O9 74 63 73 10 79 79 93 24 0 24 0 50 0 56 0 60 0 19 0 05 0 21 0.76 0.62 0.42 435 67 h 90 91 W 445 05 N 11 47 W 451 466 481 496 510 524 537 55O 563 59 N 94 89 N 98 70 N 103 20 N 107 43 N 112 34 N 116 84 N 122 92 N 127 47 N 132 81 W 461 81W 477 01W 492 38 W 507 01W 522 94 W 537 13 W 551 43 W 565 85 W 578 43 N 11 51 W 23 N 11 57 W 59 N 12 4 W 69 N 12 13 W 58 N 12 23 W 23 N 12 34 W 53 N 12 48 W 47 N 13 1 W 92 N 13 16 W 6000.00 5944 20 5833.30 7 52 N 24 52 W -87.74 6100.00 6043 24 5932.34 8 4 N 26 29 W -92.64 6200 O0 6142 27 6031.37 8 6 N 26 58 W -97.80 6300 O0 6241 25 6130.35 8 12 N 27 16 W -103.17 6400 O0 6340 25 6229.35 8 7 N 27 56 W -108.59 6500 O0 6439 25 6328.35 8 9 N 28 13 W -114.15 6600 O0 6538 21 6427.31 8 16 N 29 28 W -119.91 6700 O0 6637 14 6526.24 8 27 N 29 48 W -125.99 6800 O0 6736 04 6625.14 8 38 N 30 14 W -132.30 6900.00 6834.90 6724.00 8 40 N 31 3 W -138.77 010 0 42 012 0 35 0 68 0 56 0.51 0.37 0.23 0.46 576 O0 N 138 47 W 592 41 N 13 31 W 588 47 N 144 6OO 95 N 150 613 57 N 157 626 10 N 163 638 55 N 170 651 03 N 177 663 72 N 184 676.61N 192 689.52 N 199 48 W 605 75 W 619 24 W 633 78 W 647 45 W 660 33 W 674 54 W 688 O0 W 703 62 W 717 95 N 13 48 W 57 N 14 5 W 40 N 14 22 W 17 N 14 40 W 91 N 14 57 W 75 N 15 14 W 9O N 15 32 W 33 N 15 51W 84 N 16 9 W 7000.00 6933 74 6822.84 8 50 N 31 50 W -145.50 7100.00 7032 7200.00 7131 7300.00 7230 7400.00 7329 7500.00 7428 7600.00 7527 7700.00 7626 7800.00 7725 7900.00 7824 56 6921.66 8 46 N 30 42 W -152.38 49 7020.59 8 0 N 16 26 W -157.43 51 7119.61 8 3 N 3 34 W -158.24 49 7218.59 8 21 N 3 31 W -157.77 40 7317.50 8 36 N 5 2 W -157.61 28 7416.38 8 32 N 6 36 W -157.83 19 7515.29 8 29 N 7 31 W -158.34 08 7614.18 8 22 N 8 38 W -159.12 07 7713.17 8 11 N 9 54 W -160.20 0.51 1.13 2.81 0.53 0.52 0.44 0.37 0.21 0.09 0.60 702,49 N 207.51 W 732.50 N 16 27 W 715.55 N 215.57 W 747.31 N 16 46 W 728.78 N 221,80 W 761.78 N 16 56 W 742 47 N 223.80 W 775,47 N 16 46 W 756 70 N 224 58 W 789 32 N 16 32 W 771 41 N 225 70 W 803 75 N 16 19 W 786 23 N 227 22 W 818 40 N 16 7 W 800 93 N 229 02 W 833 04 N 15 57 W 815 42 N 231 07 W 847 53 N 15 49 W 829.59 N 233 39 W 861 80 N 15 43 W UNOCAL GP 11-13 RD GRANITE POINT KENAI, ALASKA COMPUTATZON DATE: 12-MAR-92 PAGE 3 DATE OF SURVEY: 09-MAR-92 KELLY BUSHING ELEVATION: 110.90 FT ENGINEER= MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERT[CAL DOGLEG RECTANGULAR COORDZNATES HOR[Z. DEPARTURE MEASURED VERTICAL VERTICAL DEVZATION AZIMUT~ 5ECTZON SEVER[TY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 8000.00 7923.07 7812.17 8 7 N 11 39 W -161 65 8100.00 8022.10 7911.20 7 53 N 13 49 W -163 8200.00 8121.16 8010.26 7 59 N 16 53 W -166 8300.00 8220.22 8109 32 7 41 N 19 2 W -169 8400.00 8319.28 8208 38 7 48 N 21 4 W -172 8500.00 8418.34 8307 44 7 58 N 22 48 W -176 8600.00 8517.40 8406 50 7 50 N 24 27 W -180 8700.00 8616.43 8505 53 8 2 N 25 55 W -185 8800.00 8715.44 8604 54 8 7 N 27 33 W -190 8900.00 8814.41 8703 51 8 16 N 28 10 ~ -196 47 O0 04 58 58 9,4 74 95 59 0 15 0 43 0 44 051 0 18 0 33 0 15 0 38 0 35 013 843.41 N 236.05 W 875 82 N 15 38 W 856.99 N 239.07 W 889 870.26 N 242.77 W 903 883.29 N 246.97 ~ 917 895.92 N 251.62 W 930 908.67 N 256.75 W 944 921.25 N 262.23 W 957 933.78 N 268.15 W 971 946.28 N 274.47 W 985 958.96 N 281.24 W 99~ 71 N 15 35 W 49 N 15 35 W 17 N 15 37 W 58 N 15 41W 25 N 15 47 W 85 N 15 53 W 52 N 16 ~ W 28 N 16 10 W 35 N 16 21W 9000.00 8913.40 8802.50 8 9 N 28 26 W -202 26 9100.00 9012.37 8901.47 8 20 N 29 38 W -208 9200.00 9111.28 9000,38 8 37 N 31 11 W -214 9300.00 9210.10 9099.20 8 54 N 32 50 W -221 9400.00 9308.87 9197.97 9 2 N 33 44 W -228 9500.00 9407.64 9296.74 8 58 N 35 23 W -236 9600.00 9506.38 9395.48 9 10 N 36 2 W -244 9700.00 9605.11 9494.21 9 13 N 37 52 W -252 9800.00 9703.82 9592.92 9 32 N 38 24 W -261 9900.00 9802.56 9691.66 8 35 N 34 12 W -269 O0 31 24 63 34 44 77 59 95 0.39 971.56 N 288.03 W 1013.36 N 16 31 W 0.57 984.05 N 294.89 W 1027.29 N 16 41 W 0.63 996.77 N 302.33 W 1041.61 N 16 52 W 0.20 1009.69 N 310.42 W 1056.33 N 17 5 W 0.15 1022.71 N 318.98 W 1071,30 N 17 19 W 0.41 1035.62 N 327.84 W 1086.27 N 17 34 W 0.76 1048.45 N 337.10 W 1101.31 N 17 49 W 0.11 1061.15 N 346.58 W 1116.31 N 18 5 W 0.93 1073,87 N 356.54 W 1131.51 N 18 22 W 1.29 1086.31 N 366,02 W 1146.32 N 18 37 W 10000100 9901.56 9790 66 7 43 N 21 59 W -275 59 10100 O0 10000.74 9889 64 6 52 N 2 5 E -277 37 10200 O0 10099.94 9989 04 7 48 N 31 0 E -272 52 10300 O0 10198.78 10087 88 9 30 N 43 34 E -262 13 10400 O0 10297.13 10186 23 11 36 N 52 31 E -247 52 10500 O0 10394.68 10283 78 13 23 N 57 28 E -228 59 10600 O0 10491.59 10380 69 15 7 N 62 39 E -206 16 10700 O0 10587.85 10476.95 16 20 N 67 36 E -180 71 10800.00 10683.38 10572.48 17 50 N 69 26 E -152 37 10900.00 10778,27 10667.37 18 59 N 70 17 E -121.94 1.59 1098.73 N 372.77 W 1160.25 N 18 44 W 3.07 1111.13 N 375.64 W 1172.91 N 18 41 W 2.86 1122.90 N 371.81 W 1182.86 N 18 19 W 1.82 1134.76 N 362.41 W 1191.23 N 17 43 W 2.83 1146.76 N 348.80 W 1198.63 N 16 55 W 1.65 1159.17 N 330.87 W 1205.47 N 15 56 W 2.09 1171.50 N 309.44 W 1211.68 N 14 48 W 2,24 1182.74 N 284.88 W 1216,57 N 13 33 W 1.37 1193.44 N 257.37 ~ 1220.87 N 12 10 W 1,33 1204.36 N 227.77 W 1225.71 N 10 43 W 11000.00 10872.89 10761.99 18 18 N 71 52 E -90.52 11100.00 10968,00 10857.10 17 49 N 74 45 E -60.26 11200.00 11062.95 10952.05 18 18 N 76 36 E -29.28 11300.00 11158.12 11047.22 17 31 N 78 26 E 1.13 11400.00 11253.53 11142.63 17 6 N 82 14 E 30,98 11500.00 11349.62 11238.72 16 36 N 83 53 E 52.10 11560,00 11407.12 11296.22 16 36 N 83 53 E 69.24 2.53 1214.97 N 197.16 W 1230.86 N 9 13 W 0.80 1223.69 N 167.54 W 1235.10 N 7 48 W 0.98 1231,53 N 137.14 W 1239.14 N 6 21 W 1.65 1238.30 N 107.21 W 1242.93 N 4 57 W 1.29 1243.13 N 77.66 W 1245.56 N 3 34 W 0.00 1242.44 N 56.40 W 1243.72 N 2 36 W 0.00 1244.27 N 39.36 W 1244.89 N 1 49 W COMPUTATION DATE: 12-MAR-92 PAGE 4 UNOCAL GP 11-13 RD GRAN[TE POINT KENAI, ALASKA DATE OF SURVEY: 09-MAR-92 KELLY BUSHING ELEVATION: 110.90 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4OO0 5000 6000 7000 8000 9000 O0 O0 1997 O0 2997 O0 3974 O0 4955 O0 5944 O0 6933 oo 7923 O0 8913 0.00 -110.90 0 0 998 24 887.34 2 56 80 1886.90 1 16 50 2886 60 1 43 88 3863 98 15 22 34 4844 44 9 39 2O 5833 3O 7 5~ 7~ 6822 8~ 8 5E 07 7812 17 8 7 40 8802 50 8 9 N 0 0 E N 58 31 W -42 N 53 57 W -63 N 53 56 W -82 N 11 58 E -49 N 13 20 W -52 N 24 52 W -87 N 31 50 W -145 N 11 39 W -161 N 28 26 W -202 0 O0 17 99 27 99 59 74 50 65 26 0.00 0.28 0.11 1 .87 1 .25 0.24 0.10 0.51 0.15 0.39 0 O0 N 21 72 N 44 38 52 N 67 52 68 N 87 242 62 N 71 435 67 N 90 576 O0 N 138 702 49 N 207 843 41N 236 971 56 N 288 23 W 49 61W 77 19 W 101 41W 252 91W 445 47 W 592 51 w 732 05 w 875 03 W 1013 0 O0 E 0 O0 N 0 0 E 28 N 63 51W 81 N 60 20 W 87 N 58 51W 91 N 16 24 W 05 N 11 47 W 41 N 13 31 w 5O N 16 27 W 82 N 15 38 W 36 N 16 31W 10000.00 9901.56 9790.66 7 43 11000.00 10872.89 10761.99 18 18 11560.00 11407,12 11296.22 16 36 N 21 59 W -275.59 N 71 52 E -90.52 N 83 53 E 69.24 1 .59 2.53 0.00 1098.73 N 372.77 W 1160.25 N 18 44 W 1214.97 N 197.16 W 1230.86 N 9 13 W 1244.27 N 39.36 W 1244.89 N 1 49 W COMPUTATION DATE: 12-MAR-92 PAGE 5 UNOCAL GP 11-13 RD GRANITE POINT KENAI, ALASKA DATE OF SURVEY: 09-MAR-92 KELLY BUSHING ELEVATION: 110.90 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/5OUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 110 92 210 93 311 01 411 22 511 50 611 79 712 08 812 33 912.54 '0.00 -110.90 110 90 210 90 310 90 410 9O 510 90 610 90 710 90 810 9O 910.90 0 0 N 0 0 E 0.00 0 2 S 10 49 W 100.00 1 11 5 69 10 W 200.00 2 58 5 80 23 W 300. O0 4 15 N 61 27 W 400.00 4 18 N 57 43 W 500.00 4 21 N 56 0 W 600.00 4 19 N 55 39 W 700.00 3 50 N 55 48 W 800.00 3 19 N 56 9 W 0 O0 0 45 -0 31 -4 13 -10 03 -16 11 -22 08 -27 98 -33 54 -38 43 0 O0 0 22 2 38 2 32 0 57 0 O3 00~o 0 30 0 38 C 67 0.00 N 0.90 S 1.13 S 2.41 S 0.65 S 3.21 N 7.3O N 11.59 N 15.64 N 19. 15 N 0 O0 E 0 53 E 0 21 W 3 94 W l0 O1 W 16 45 W 22 80 W 29 10 ~' 35 03 W 4O 0.00 N 0 0 E 1.04 S 30 25 E 1.15 S 10 37 W 4.62 S 58 32 W 10.04 S 86 17 W 16.76 N 78 58 W 23.94 N 72 15 W 31.32 N 68 17 ~' 38.36 N 65 57 w 25 W 44.5~ N 64 33 ~ 1012.67 1010.90 900.00 1112 78 1110.90 1000 O0 1212 1312 1412 1512 1613 1713 1813 1913 85 1210.90 1100 O0 90 1310.90 1200 O0 96 1410.90 1300 O0 98 1510.90 1400 O0 03 1610.90 1500 O0 04 1710.90 1600 O0 07 1810.90 1700.00 08 1910.90 1800.00 2 53 N 58 56 W -42.69 2 26 N 57 3 W -46.40 2 0 N 56 7 W -49.42 1 45 N 53 29 W -51.92 1 33 N 52 6 W -54.06 1 25 N 52 52 W -55.95 1 23 N 51 37 W -57.74 1 14 N 54 13 W -59.37 1 15 N 50 47 W -60.93 1 17 N 53 15 W -62,51 0.43 0.2O 0.36 0.39 0.18 0.4O 0.05 0.66 0.00 0.17 22.06 N 44.78 W 24.50 N 48.72 W 26.61 N 51.93 W 28,50 N 54.62 W 30.20 N 56.91 W 31.79 N 58.95 W 33.26 N 60.87 W 34.68 N 62.63 W 36.04 N 64.31 W 37.41 N 66.02 W 49.92 N 63 47 W 54.53 N 63 18 W 58.35 N 62 52 W 61.61 N 62 26 W 64.42 N 62 3 W 66.97 N 61 40 W 69.37 N 61 21W 71.59 N 61 1W 73.72 N 60 44 W 75.88 N 60 28 W 2013.10 2010.90 1900.00 1 17 2113.14 2110.90 2000.00 1 22 2213.18 2210.90 2100.00 1 22 2313,18 2310.90 2200.00 1 23 2413.22 2410.90 2300.00 1 26 2513.26 2510.90 2400.00 1 23 2613.29 2610.90 2500.00 1 25 2713.32 2710.90 2600.00 1 24 2813.35 281'0.90 2700.00 1 24 2913.37 2910,90 2800,00 1 20 N 52 12 W -64 21 N 52 26 W -65 91 N 56 55 W -67 75 N 52 8 W -69 53 N 54 57 W -71 36 N 54 6 W -73 26 N 54 24 W -75 OB N 54 19 W -76 99 N 54 5 W -78.86 N 54 29 W -80.61 0Ol 0 O0 0 39 012 0 32 0 27 0 15 0.22 0.13 0.07 38.69 N 67.84 W 40.10 N 69.67 W 80 41.48 N 71.63 W 82 42.91 N 73.55 W 85 44.40 N 75.52 W 87 45.81 N 77.55 W 90 47.28 N 79.50 W 92 48.67 N 81.54 W 94 50.11 N 83.55 W 97 51.48 N 78 10 N 60 18 W 39 N 60 5 W 78 N 59 56 tN 16 N 59 44 W 60 N 59 33 W 07 N 59 26 tN 50 N 59 16 W 96 N 59 10 W 42 N 59 3 W 85.42 W 99.73 N 58 56 W 3013.41 3010.90 2900.00 1 59 3113.60 3110.90 3000.00 4 51 3214.14 3210.90 3100.00 6 49 3315.00 3310.90 3200.00 8 19 3416.42 3410.90 3300,00 10 58 3518.83 3510.90 3400.00 13 54 3622.29 3610.90 3500.00 15 17 3726.00 3710.90 3600.00 15 28 3829.80 3810.90 3700.00 15 35 3933.61 3910.90 3800.00 15 30 N 49 43 W -82.58 N 33 6 W -85.78 N 21 6 W -89.73 N 10 5 W -92.08 N 1 13 E -91.79 N 9 1 E -87.80 N 12 35 E -80.40 N 12 55 E -71.97 N 12 36 E -63.44 N 11 59 E -55.17 2.10 2.58 2.2O 2.73 3.47 2.89 0.69 0.14 0.23 0.27 52.98 N 87.54 W 102.32 N 58 49 W 57.52 N 91.14 W 107.78 N 57 45 W 66.81 N 95.92 W 116.89 N 55 9 W 79.46 N 99.38 W 127.25 N 51 21 W 96.18 N 100.56 W 139.15 N 46 16 W 118.18 N 98.47 W 153.83 N 39 48 W 144.13 N 93.32 W 171.70 N 32 55 W 170.93 N 87.20 tN 191.88 N 27 2 W 198.07 N 81.01 W 214,00 N 22 15 W 225.30 N 75.09 tN 237.49 N 18 26 W UNOCAL GP 11-13 RD GRANITE POINT KENA[, ALASKA COMPUTATION DATE: 12-MAR-92 PAGE 6 DATE OF SURVEY: 09-MAR-92 KELLY BUSHING ELEVATION: 110,90 FT ENGINEER; MCCROSSAN INTERPOLATED VALUE5 FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTZCAL DEVIATZON AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 4037 27 4010 90 3900.00 14 14 N 9 30 E -47.35 4140 4242 4344 4446 4548 4650 4751 4853 4954 15 4110 61 4210 56 4310 43 4410 26 4510 08 4610 76 4710 41 4810 94 4910 90 4000.00 13 0 N 4 11 W -43.11 90 4100.00 11 59 N 1 33 W -41.38 90 4200.00 10 52 N 7 5 W -41.14 90 4300.00 11 1 N 8 32 W -42.16 90 4400.00 10 54 N 9 20 W -43.50 90 4500.00 10 41 N 10 19 W -45.12 90 4600.00 10 23 N 1! 18 W -47.00 90 4700.00 10 10 N 12 23 W -49.15 90 4800.00 9 4~ N 13 5 W -51.50 551 1 33 1 65 0 56 0 57 0 50 0 26 0 5O 0 07 0 55 251.99 N 69 58 W 261.42 N 15 26 W 276.04 N 67 298.34 N 67 318 13 N 69 337 27 N 71 356 44 N 74 375 23 N 78 393 45 N 81 411 15 N 85 428 28 N 89 42 W 284.15 N 13 44 W 64 W 305.91 N 12 46 W 13 W 325.55 N 12 16 W 83 W 344.83 N 12 1 W 85 W 364.22 N 17 52 W 12 W 383.28 N 1~ 46 ~ 60 W 401.82 N 17 43 ~ 31 W 419.9i N 11 43 ~' 17 W 437.46 N 11 46 W 5056.35 5010 90 4900.00 9 24 N 13 59 W -53.98 5157.67 5110 5258.90 5210 5360.08 5310 5461.21 5410 5562.36 5510 5663.42 5610 5764.46 5710 5865.43 5810 5966.38 5910 90 5000.00 9 5 N 14 31 W -56.61 90 5100.00 8 51 N 15 54 W -59.41 90 5200.00 8 41 N 16 52 W -62.46 90 5300.00 8 36 N 18 8 W -65.75 90 5400.00 8 27 N 19 31 W -69.36 90 5500.00 8 18 N 21 7 W -73.30 90 5600.00 8 5 N 22 7 W -77.46 90 5700.00 7 49 N 23 39 W -81.70 90 5800.00 7 52 N 24 8 W -86.21 0 89 0 29 0 34 0 19 0 31 0 43 0 40 0 92 0 44 0 34 444.73 N 93 09 W 454.37 N 11 49 W 460.47 N 97 475.63 N 101 490.45 N 105 504.95 N 110 519.17 N 115 532.93 N 120 546.33 N 125 559.15 N 130 571.82 N 136 11 W 470.60 N 11 55 W 25 W 486.29 N 12 1 W 61 W 501.69 N 12 9 W 18 W 516.83 N 12 19 W 05 W 531.77 N 12 30 W 21 W 546.32 N 12 43 W 55 W 560.58 N 12 57 W 93 W 574.27 N 13 11 W 57 W 587.90 N 13 26 W 6067 34 6010.90 5900.00 7 59 N 26 3 W -90.98 6168 33 6110.90 6000.00 8 1 N 26 50 W -96,15 6269 34 6210.90 6100.00 8 12 N 27 18 W -101,51 6370 37 6310.90 6200.00 8 7 N 27 43 W -106.96 6471 36 6410.90 6300.00 8 8 N 28 19 W -112.53 6572 40 6510.90 6400.00 8 11 N 29 5 W -118.29 6673.48 6610.90 6500.00 8 25 N 29 36 W -124.36 6774.57 6710,90 6600.00 8 38 N 30 11 W -130.67 6875.72 6810.90 6700.00 8 38 N 30 49 W -137.17 6976.87 6910.90 6800.00 8 45 N 31 31 W -143.91 0.52 0.29 0.33 0.36 0.58 0.37 0.35 0.38 0.31 0.50 584 38 N 142 46 W 601.49 N 13 42 W 596 98 N 148 74 W 615 24 N 13 59 W 609 70 N 155 24 W 629 622 39 N 161 82 W 643 634 98 N 168 52 W 656 647 58 N 175 40 W 670 660 34 N 182 61 W 685 673.31 N 190 08 W 699 686.39 N 197.75 W 714 699.48 N 205.65 W 729 15 N 14 17 W 09 N 14 34 W 96 N 14 52 W 92 N 15 9 W 13 N 15 27 W 63 N 15 46 W 31 N 16 4 W 08 N 16 23 W 7078.08 7010.90 6900.00 8 48 N 31 20 W -150.90 7179.21 7110.90 7000.00 8 10 N 20 44 W -156.68 7280.19 7210.90 7100.00 8 0 N 4 28 W -158.30 7381.20 7310.90 7200.00 8 17 N 3 15 W -157.85 7482.30 7410.90 7300.00 8 34 N 4 51 W -157.62 7583.44 7510.90 7400.00 8 32 N 6 34 W -157.75 7684.54 7610.90 7500.00 8 30 N 7 27 W -158.25 7785.66 7710.90 7600.00 8 22 N 8 30 W -159.00 7886.70 7810.90 7700.00 8 13 N 9 37 W -160.04 7987.71 7910.90 7800.00 8 7 N 11 29 W -161.45 0.63 2.98 0.88 0.48 0 33 0 40 012 0 10 0 49 017 712.69 N 213.83 W 744 08 N 16 42 W 726.02 N 220.80 W 758 739.71 N 223.62 W 772 753.99 N 224.42 W 786 768.78 N 225.48 W 801 783.78 N 226.93 W 815 798.67 N 228.72 W 830 813.36 N 230.76 W 845 827.73 N 233.07 W 859 841.71 N 235.71 W 874 86 N 16 55 W 77 N 16 49 W 68 N 16 35 W 17 N 16 21W 97 N 16 9 W 77 N 15 59 W 46 N 15 50 W 92 N 15 44 ~ 09 N 15 39 W COMPUTATION DATE: 12-MAR-92 PAGE 7 UNOCAL GP 11-13 RD GRANITE POINT KENAI, ALASKA DATE OF SURVEY: 09-MAR-92 KELLY BUSHING ELEVATION: 110.90 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE NEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 8088.68 8010.90 7900.00 8189 65 8110.90 8000.00 8290 61 8210.90 8100,00 8391 54 8310.90 8200.00 8492 48 8410.90 8300.00 8593 44 8510.90 8400.00 8694 41 8610.90 8500.00 8795 41 8710.90 8600.00 8896.45 8810.90 8700.00 8997.48 8910.90 8800.00 7 53 7 57 7 43 7 47 7 57 7 49 8 2 8 7 8 1°,9, 8 9 N 13 21W -163 23 N 16 40 W -165 70 N 18 44 W -168 75 N 20 55 W -172 26 N 22 44 W -176 26 N 24 15 W -180 64 N 25 49 W -185 46 N 27 29 W -190 70 N 28 9 W -196.39 N 28 26 W -202.12 0.33 0.60 0.61 0 19 0 36 0 25 0 35 031 0 16 0 38 855 49 N 238.70 W 888 16 N 15 35 W 868 88 N 242.35 W 902 882 09 N 246.57 W 915 894 85 N 251.20 W 929 907 71 N 256.35 W 943 920 44 N 261.86 W 956 933 08 N 267.80 W 970 945 71 N 274.17 W 984 958.51 N 281.00 W 998 971.25 N 287.86 W 1013 05 N 15 35 W 91 N 15 37 W 44 N 15 41W 21 N 15 46 W 96 N 15 53 W 75 N 16 1W 65 N 16 10 W 85 N 16 20 W 01 N 16 31W 9098.52 9010.90 8900 O0 9199.61 9110.90 9000 O0 9300.81 9210.90 9100 O0 9402.06 9310.90 9200 O0 9503.30 9410.90 9300 O0 9604.57 9510.90 9400 O0 9705.86 9610.90 9500.00 9807.19 9710.90 9600.00 9908.43 9810.90 9700.00 10009.42 9910,90 9800.00 8 20 8 37 8 54 9 2 8 59 9 9 9 14 9 27 831 7 40 N 29 36 W -207.91 N 31 10 W -214.28 N 32 50 W -221.30 N 33 46 W -228 78 N 35 26 W -236 60 N 36 1W -244 81 N 37 55 W -253 28 N 38 20 W -262 24 N 33 20 W -270 54 N 20 47 W -275 97 0.59 0.63 0.18 0.14 0.37 0.78 0.14 2.3,4 1 .55 1 .25 983 86 N 294.78 W 1027.07 N 16 4t W 996 1009 1022 1036 1049 1061 1074 1087 1099 72 N 302.30 W 1041.56 N 16 52 W 80 N 310.49 W 1056.45 N 17 5 W 97 N 319 16 W 1071,60 N 17 20 W 04 N 328 14 W 1086,77 N 17 34 W 04 N 337 53 W 1102.00 N 17 50 W 89 N 347 15 W 1117.19 N 18 6 W 80 N 357 27 W 1132.63 N 18 23 W 35 N 366 71 W 1147.52 N 18 38 W 90 N 373 26 W 1161.51 N 18 45 W 10110.24 10010 90 9900.00 10211.06 10110 10312.30 10210 10414.07 10310 10516.69 10410 10620.03 10510 10724.05 10610 10828.90 10710 10934.52 10810 11040.00 10910.90 10800 9O 10000 O0 90 10100 90 10200 90 10300 90 10400 90 10500 90 10600 90 10700 6 52 7 59 O0 9 42 O0 11 58 O0 13 42 O0 15 24 O0 16 46 O0 18 7 O0 19 15 O0 18 1 N 4 39 E -277 18 N 32 40 E -271 N 44 44 E -260 N 53 25 E -245 N 58 13 E -225 N 63 44 E -201 N 68 15 E -174 N 69 40 E -143 N 70 42 E -110 N 73 31 E -78 63 55 10 O9 30 14 77 97 34 3.14 2.83 2.09 2.53 2.01 2.07 1 .96 1 .21 0.95 1.34 1112.35 N 375.55 W 1174.04 N 18 39 W 1124.19 N 371.02 W 1183.83 N 18 16 W 1136.23 N 360.95 W 1192,19 N 17 37 W 1148.49 N 346.52 W 1199.63 N 16 47 W 1161.25 N 327.54 W 1206.56 N 15 45 W 1173.89 N 304.77 W 1212.81 N 14 33 W 1185.33 N 278.53 W 1217.61 N 13 13 W 1196.56 N 249.01 W 1222.20 N 11 45 W 1208.15 N 217.09 W 1227.50 N 10 11 W 1218.64 N 185.26 W 1232.64 N 8 39 W 11145.12 11010.90 10900.00 18 22 11250.44 11110.90 11000.00 17 46 11355.35 11210.90 11100,00 17 31 11459.60 11310.90 11200.00 16 36 11560.00 11407.12 11296.22 16 36 N 75 22 E -46.45 1.78 N 77 10 E -13.78 0.48 N 81 10 E 17.72 1.31 N 83 53 E 40.57 0.00 N 83 53 E 69.24 0.00 1227.30 N 154,00 W 1236.92 N 7 9 W 1235.07 N 121.89 W 1241.07 N 5 38 W 1241.22 N 90,81 W 1244,54 N 4 11 W 1241.21 N 67.87 W 1243.07 N 3 8 W 1244.27 N 39.36 W 1244.89 N 1 49 W UNOCAL GP 11-13 RD GRANITE POINT KENAI, ALASKA MARKER LAST READ[NG GCT TD COMPUTATION DATE: 12-MAR-92 PAGE 8 DATE OF SURVEY; 09-MAR-92 KELLY BUSH[NG ELEVATION= 110.90 FT ENGINEER: MCCROSSAN INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 238a'SW & 1368'E OFF NW COROFF NW COR, SEC13 MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11457.60 11308.66 11197.76 1245.18 N 61.10 W 11560.00 11407.12 11296.22 1244.27 N 39.36 W UNOCAL GP 11-13 RD GRANZTE POINT KENAI, ALASKA MARKER LAST READING GCT TD COMPUTATION DATE: 12-MAR-92 PAGE 9 DATE OF SURVEY: 09-MAR-92 KELLY BUSHING ELEVATION: 110.90 FT ENGINEER: MCCROSSAN SURFACE LOCATION = 2384'SW & 1368'E OFF NW COROFF NW COR, SEC13 TVD RECTANGULAR COORDINATES FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 11308.66 11197.76 1245.18 N 61.10 W 11407.12 11296.22 1244.27 N 39.36 W MEASURED DEPTH BELOW KB 11457.60 11560.00 FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORZZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 11560.00 11407.12 11296.22 1244.89 N 1 49 W 01:111431:10 WELL: GP 11-13RD (2384'SW & 1368'£ OF NW CORNER,SEC 13,T10N,R12W) HORIZONTAL PROJECTION WELL' GP 11-13RD (2384'SW & 1368'E OF NW CORNER,SEC 13,T10N,R12W) VERTICAL PROJECTION ~ -1~ -1000 .800 0 0 ~ ~ PFRM~T ~ ~ COMPLETION DATF .6,0GCC GEOLOGICAL MATERIALS INVENTORY LIST · ..~ / /~ ! ~'~'" CO. CONTACT & NO. ~ O~ ~-~' form received received date " comments 401 no completion report 403 yes no sundry application i 404 yes no report of sundry application Open required received Cased requi~t~'d ~-ce-ived 5~:0dUCtioerequired received hole log ~ hole log log MUD v'~ / GCT ~ ~ TEMP DILJSFL / /' CNL PROD DLL CBT ' PflESS ~ ~,,~,'~--' sPINNER "' BHCISL CET ~/( ~ ~_~ , BHC/AC ' -- E~:D' - ~ ( ~ ~ O~-HEFI DATA LSS PERF Survey ~ REC ~ 'SSS ' 'PACKER 'Digital' Data FDC_ Well CNL Te~t~ FDC RWD required received SAMPLES required received MWD LDT!CNL ~ '~' I,~ ' dry ditch ~/~ ~ ~ ) .. CYBER core LOOK Analysis , ,, ../ NGT ALASKA OIL AND GAS CONSERVATION COMMISSION December 2, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Gary S Bush Regional Drilling Manager UNOCAL Corp. P. O. Box 190247 Anchorage, AK 99519-0247 re: Granite Point 11-13 RD UNOCAL Corp. Permit No. 91-133 Sur. Loc 2384'FNL. 1368'FWL, Sec. 13, T10N, R12W, SM Btmhole Loc l174'FNL, 1213'FWL, Sec. 13, T10N, R12W, SM Dear Mr. Bush: Enclosed is the approved application for permit to drill the above referenced well. The permit· to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling Operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. D~avid W~Jo~nston, Chairman Alaska O~l~ahd Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. ~ ~ Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ,~iL AND GAS CONSERVATION C D.,.,vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill - Redrill lb. Type of well. Exploratory ,~ Straiigraphic Test ~ Development Oil Re-Entry - Deepen Service - Developement Gas ~_ Single Zone F-; Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool (UNOCAL) Union Oil Company of California 114' RT above MSL feet Granite Point 3. Address 6. Property Designation Middle Kenai P.O. Box 196247, Anch., AK 99519 ADL-18761 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) ::k~Y' Leg #3, Conductor 9, Granite Point ,A~F~[~ olf3~)Sr~(~ '~-" ..,vbl. United Pas Ins Co -2"3"8'4' tivFe/}~t~ervc~,13 T10N, R12W, S.M. 8. Well nu~6~'~-"*" o..+,, #, Number 11,09A3~ MD, 10945' TVD, 1174' FNL & 1213' FWL, T10N, R12W, SM c~,anlf_~_ p~. 11-1~ ]~D U62-9269 total depth 19. Approximate spudg~ate Amount 11,848' MD & 11,700' TVD, 1174' FNL & 1213' FWL, T10N, R12W, S:~{ ~ $200,000 ,., 12. Distance to nearest 13. Distance to nearest well 14. Number oJ ~cre$ in p, rop, e_,f, ty 15. Proposed depth (MD and TVD) property line ;:'~'A' ~ 1150' feet GP 11-13 90 feet 5089 ,//~,'~~-' 11,848'/11,700' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kicl~off depth 4018' feet Maximum hole angle 16 0 Maximum surface 1960 psig At total depth fi'VD) 8190 psig ...... 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) .... 12-1/4" 9-5/8" 53.5 B-110 ]~utt IOIW' u U i0,100; 995i; i960 sx 8-1/2" '/" 3z P-iiu BuU: 2046: 9600: 965i' ii,646: ii,700: 227 ~x ~ '1 .., 19. lo be completed for Redrill, Re-entry. and Deepen Operations. Present well condition summary Total depth: measured 11653' feet Plugs (measured) 11,603'-11,653' ~.~ true vertical 11427' feet 11603 ' NONE Effective depth: measured 11378' feet Junk (measured) ~,,i.,.)V _ ~ lj¢39~, true vertical feet YrOe ~/ei~Bi~l ~pt~ Casing Length Size Cemented Measured depth /~ncn0rage Structural Conductor 684' 18" 580 SX 684' 683' S u rface 4018' 13-3/8" 2395 sx 4018 ' 3992' Intermediate 10143' 9-5/8" 1650 sx 10143 ' 9944 ' Production 1680' 7t' 425 sx 9971'-11651' 9773'-11425' Liner Perforation depth: measured See Attachment 1 true vertical ,,, 20. Attachments Filing fee ~ Property plat [] BOP Sketch 5~ Diverter Sketch [] Drilling program l~ Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. ! hereby certify ;,h, at the foregoing is true and correct to the best of my knowledge Signe S. BUSH Title REGIONAL DRILLING ~NAGER Date Commission Use Only Permit Number ] APl number I ApPro_v~ date Ieee cover letter ~/°/..5>-~ I 50--7~',3--' ;~___.c:~o~.~"-C::~? } /~]-, ~ "- ~/ l for other requirements Conditio'~s of approval Samples req_uir.ed E2 Yes .~ No "Mud log requ]red' L-] Yes ~No ........... Hydrogen sulfide measures [] Yes ~1~ No Directional survey required ~ Yes [] No Required working' pressure for BOPE~ []2M; [] 3M; ~ 5M; [] 10M; ~Z] 15M 0 th e ro~~..~ .. by order of Appr Commissioner the commission Date / ~'""",--~ a, ,1,[~--,..,~ ..,,,1~ -.,.-~ %a~. ~ --'-~-~ -'t , , ,, Form 10-401 Rev. ' --~.~..% % submit in triplicate WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 December 2, 1991 ADMINISTRATIVE APPROVAL NO. 76.24 Re: The application of Union Oil Company of California to drill and complete the Granite Point ll-13RD well as a Middle Kenai Oil Pool production well. Gary S. Bush Regional Drilling Manager UNOCAL Corp. P. O. Box 190247 Anchorage, Ak 99502-0247 Dear Mr. Bush: Your application of November 5, 1991 for a permit to drill and complete the Granite Point ll-13RD requires exception to spacing requirements set forth in Conservation Order No. 76. The drilling and completion of the Granite Point ll-13RD well is expected to provide additional oil recovery from the Middle Kenai Oil Pool in the Granite Point Field. The Alaska Oil and Gas Conservation Commission hereby,,,,, authorizes the drilling and completion of the Granite Point ll-13RD well' pursuant to Rule 7 of Conservation Order No. 76. Sincerely, Russell A. Douglass Commissioner BY ORDER OF THE COMMISSION t~ printed on recycled paper b y Drilling Procedure: Granite Point 11-13RD 2) 3) 7) 8) 9) 10) 11) 12) 13) 14) 15) 16) 17) 18) Move in and rig up. Kill the well with 64 pcf spud mud. Set BPV. Nipple down the tree and nipple up the BOPE. Pull existing dual 3 1/2" completion from 11,035' including the Baker packer at 9907'. Run into well to 11,603' (PBTD) and abandon all existing perforations with cement. Run in hole with a 9 5/8" cement retainer and set at 4150'. Cut and pull the existing 9 5/8" casing from 4100'. Clean out inside the 13 3/8" casing to 4100'. Underream the section (4018'-4100') to 17" and lay a balanced kickoff plug from 4150' to 3800'. Kick off the plug, perform leak off test at the 13 3/8" casing shoe (4018') and begin the 12 1/4" redrill. Directionally redrill a 12 1/4" hole from 4018' to 10100' MD. Run open hole logs. Run and cement 9 5/8" casing to 10100' MD. Directionally drill a 8 1/2" hole from 10100' to TD. Run open hole logs. Run and cement a 7" liner from 9800' to TD. Perforate the Hemlock zone (~ 400') with TCP guns. Run a single 2 7/8" production tubing string. Place well on production. Note: Should !-I2 S be encountered, UNOCAL will conform to all requirements as set forth in 20 AAC 25.065. RECEIVED NOV - 5 Alaska Oil & Gas Cons. anchora~ 11-13 GI~ANIT~ POINT STAT~ I 1-13 1-Otis Ball. Valve ~ 277' in 3 1/Z" Tubin~ Z-Otis Ball Valve ~ 291' Lu Z 7/8" Tubing. 3-Can~co i~M Side l=ockeC tviancireis in Z 7/8" Tubiz~ 2570' 46Z7' 597I' 7001' 7567' 7916' 8965' 4-Otis Type CX Gas Lift Nlandrel-- in 3 1/Z" T~bin~: 2149' 3560' 4529' 5352' 6032' 665I' 7326' 7806' 5-Baker Dual. P~cker ~ 8112' 6-Otis Type Q No-Go @ 8125' in 3 1/2" Tuhiz~. Bottom o£ B I/2" Tubin~ @ 8128' 7-Otis Type X ?_=.d4.~ Nipple @ 8965' in Z 7/8" Tub£ 8-Otis Polisk Nipple ~ 8971' in Z 7/8" T~biz~ 9-Otis XO Slidiz~ ~leeve @ 9841' in Z 7/8" T~hiz~ 10-Tubiz~ Plu~ in 2 7/8" Tuhin~ @ 9865' II-Otis Tubin8 Overshot Divider ~ 9906' in 2 7/8" 1Z-Baker Siu~le HFdro Set l=acker @ 9907' IB-Otis Type N No-Go Nipple ~ ll,0BZ' in. 2 7/8" Tubi Bot~cn~ o£ 2 7/8" Tubing' @ 11,035' I4-1~er~ora~ons: " ;i RECEIVED NOV - 5 %99 ~ ' Anchorage -'- II,~l ~j . .. 8ZOO' 8Z46'/8Z96' 85Z0'/8615' 8680'/8710' 8750'/8760' 8905'/8925' 8940'/907.5' 9042'/9072' 9335'/9360' 9460'/9470' 9482'/9497' 9624'/96~S4' 96S0'/9675' 9690'/9700' 974Z'/9749' 9815'/9835' 10, O00' 11,130'/ll,ZS0' 11,310' / 11,540' Shu~. In~ RFCEIVED F!OV - 5 iEi~ Alaska Oit~,,.~ ~' Gas Cons. Comlgissio~ Anchora§e Unocal-Mobil State #1 Granite Point 11-13 Redri11 Mud Program Mud type: Seawater/Fresh water polymer mud Hole size: Depth: 12-1/4" & 8-1/2" 4018' to 11848' measured depth Mud Properties: Weight-. Viscosity: PV: YP: pH: Gels: API Filtrate: HPHT (200 deg): 9.5 to 13.5 ppg 45-55 sec/qt 10-15 cP 15-20 lbs/100 sq ft 9.5-10.0 10/30 5-8 cc's/30 min 15-17 cc's/30 min FILL- UP KILL LINE Co~,~ract CHOKE psi FLOW ANNULAR BOP 135/8"3000 psi PIPE RAMS 135/~5000 psi BLIND RAMS 13%"5000 psi J DRILLING SPOOL -77x~ 35~5000 I] 4" 5000 1 PIPE RAMS 13%"5000 psi 1 Exhibit LINE-- RISER ~3%" 5000 psi RECEIVED Alaska Oil & Gas Cons. Commission Anchorage GRANITE POINT PLATFORM BOPE STACK 13%" 5000 psi #2 TO 10" CROWN VENT (;AS BUSTER /~~SHAKER TO CHOKE PANEL lSWACOI CHOKEt NOTE: SWACO CHOKES EACH HYDRAULICALLY ACTUATED VIA REMOTE. BOPE MANUAL ISWACOI CHOKEI CHOKE MANIFOLD Unocal PLATFORM RIGS 4-1/16~ & 3-1/8", 5M MSP L.E2MD~ 4,~JO RESERVE PIT 500 BBL RESERVE PIT 500 BBL ............ TO RIG Mud Pumps Ideco T- 1600 Ideco T- 1600 CENTRIFUGE DESILTER DESANDER DEGASSER SHAKERS TRIP TANK 20 BBLs LOCATED AT RIG ACTIVE MUD SYSTEM 540 NOMINAL BBLs EQUIPMENT LIST ON OTHER PAGE ATTACHED UNOCAL GRANITE PT. MUD PIT DRAW N: CLL SCALE: NONE DATE: 10-28-9 1 Granite Point Mud System & Related Equipment: The mud system being provided (see attached drawing) will be equipped with a barite recovery system for use while drilling with weighted mud systems. Two (2) Ideco T-1600 1600 HP, with 7-1/2" bore x 12" stroke triplex mud pump with 5000 psi fluid ends. Centrifugals - all pumps are 6" x 8" x 14" mission magnum. System complete with the following charge pumps: A. Two (2) charge pumps for both triplex pumps. B. One (1) pump for desander C. One (1) pump for mudcleaner D. One (1) pump for hopper/gun line Ail pumps powered with 100 HP motors Active tank is 540 bbl nominal volume which consists of: A. 25 bbl sand trap RECEIVED B. 145 bbl desander tank C. 144 bbl desilter tank D. 144 bbl centrifuge tank [~!0V~ -~ ~l(~°! E. 43 bbl suction tank F. 22 bbl slugging and pill pitAlaska0il&~asc°ns'o°mmissi0n G. 18 bbl chemical tank Anch0ra~ Pit system will be equipped with pit level indicator using visual and audio warning devices, fluid flow sensor, methane and Hydrogen Sulfide detection units. An auger system with three augers at the centrifuge, active pit, and transport area. Solids control equipment consist of the following: A. Two (2) Derrick Plus Model Flow Line Cleaners. B. Demco desander with two (2) each 12" cones. C. Pioneer desilter with (12) each 4" cones. D. Degasser, Drillco rated at 800 gpm E. Agitators, five (5) with 32" & 24" impellers F. Mud Hopper, Geosource Sidewinder G. Centrifuge, Two (2) Pioneer Mark I Two (2) 500 bbl each reserve pits internally coated with an Epoxy-coal tar system. Pits include 3" gun lines and agitators in each unit. Fresh water storage on the platform is a beam tank with a 2500 bbl minimum capacity. Filtered Inlet Water (FIW) is readily available. Storage for mud products on the platform is limited to a sack storage system on the piperacks and drill decks which is space limited. UNOCAI Structure · GRANITE POINT Platform Well· ll-13Rd Field : Granite Point Field Location : Cook Inlet, Alaska 0 3200 0 0 0 ~ 3600 · . 4OOO o ~ 4400 4800 5200 6400 · -- 7200 (:D 7600 8OO0 8800 _ 9200 - 9600 V 10000 _ 10400- _ 10800- _ 11200- _ 11600~ _ 12000~ 40O Created by : jones FOR: L LOHOEFER Date plotted ; 17-0ot-91 Plot Reference is 11-15 Rd Version ~4. Coordinates are in feet reference slot True Vertical Depths are reference wellhead. I--])~1~] EAST M A N ~Zfl/liICH RISTENSEN RKB ELEVATION: 95' N 7.3 DEG W ~a~0' (TO TARGET) **PLANE OF PROPOSAL** KOP '1¥D=3992 IMD=4018 DEP=253 DEG / 100' DOGLEG END OF TURN 7VD=4429 TMD=4471 DEP=371 AVERAGE ANGLE 15.53 DEG 15.00 BEGIN ANGLE DROP FVD=6751 TMD=6860 DEP=1011 15.00 1 1.00 9.00 7.00 1 DEG / 100' DOGLEG 5·00 1.00 END ANGLE DROP 7VD=8265 TMD=8415 DEP=1220 TARGET - T/ HEMLOCK TVD=10945 TMD=II093 DEP=I220 TARGET - B/ HEMLOCK TVD=II500 TMD=II648 DEP=i;3;30 ID IVD=11700 TMD=11848 DEP=1220 800 1200 1600 2000 Vertical Section on 352.70 azimuth with reference 0.00 S, 0.00 E from slot #3-9 TARGET LOCATIONS: J 117¢' FNL, 1213' FWL SEC. 13, TION, R12W TARGET- T/ HEMLOCK TVD=10945 TMD=l1093 DEP=1220 NORTH 1210 WEST 155 300 I KOP / TIE-IN'-.---.~. SURFACE LOCATION: J 2384' FNL, 1368' FWL SEC. 13, TION, R12W ORIGINAL HOLE~ <-- West 200 lO0 o 10o I I I I I I 1700 1600 ~1500 ~1400 ~1200 ~1100 800 400 : o _ RECEIVED A I I Z 0 Alaska Oil & Gas Cons. Commission Anchorag~ TARGET ANGLE "VERTICAL" Wes Scale 1 ' 100.00 500 400 500 I I I I UNOCAL Will: 11--1 I.~)Mt~n: C~k InlM', klmska 2OO lO0 I I I I 5300 51 O0 4900 4700 11700 7900 45OO ° 900 7100 69OO 670O 6500 6300 6100 0 100 200 5go0 5700 5500 5300 51 O0 7700 7500 7300 71 O0 6900 6700 6500 6300 6100 5900 5700 5500 5300 5100 4900 4700 ~500 4300 ,,oo R£C£[VED 41,~ska Oil ~'~ ~as Cons. Anchora~.e CorflrflJssk 1500 - 1200 -1100 - 1000 - 900 - 800 - 700 - 600 - 500 - 400 ' - 300 200 ! 0 UNOCAL GRANITE POINT Platform slot Granite Point Field Cook Inlet, Alaska CLEARANCE REPORT Your ref : 11-13 Rd Version #4 Our ref : prop252 Other ref : Date printed : 17-0ct-91 Date created : 4-Sep-91 Last revised : 17-0ct-91 Field is centred on O.O00,O.O00,3.00000,N Structure is centred on n60 57 52.745,w151 20 20.066,-189 Main calculation performed with 3-D minimum distance method Object wetlpath GMS/MSS <0-11150-15715~>,,MUC I-I,GRANITE POIN GMS <O-10874~>,,31-13,GRANITE POINT Platform GMS <O-10225'>,,22-13,GRANITE POINT Platform GMS <O-10874~>,,13-13,GRANITE POINT Platform GMS <O-12200~>,,12-24,GRANITE POINT Platform GMS <O-11800~>,,11-24,GRANITE POINT Platform GMS <O-10830~>,,MUC I-2,GRANITE POINT Platform GMS <9700-10640~>,,24-13Rd,GRANITE POINT Platf GMS <O-10560~>,,24-13,GRANITE POINT Platform GMS/MSS/GMS <O-12471~>,,44-11,GRANITE POINT Pl GMS <8900-11986~>,,32-23Rd,GRANITE POINT Platf GMS <O-12000~>,,32-23,GRANITE POINT Platform GMS <O-IO191~>,,31-14Rd#2,GRANITE POINT P[atfo GMS <O-11011~>,,31-14Rd#1,GRANITE POINT Platfo GMS/MSS <O-8876~>,,31-14,GRANITE POINT Platfor GMS/MSS/GMS (O-14544~>,,42-23,GRANITE POINT PI GMS <O-10850~>,,44-14,GRANITE POINT Platform GMS <O-11200~>,,31-23,GRANITE POINT Platform GMS <2700-10200~>,,32-13,GRANITE POINT Platfor GMS <O-11450~>,,33-13,GRANITE POINT Platform GMS <9200-11410~>,,33-14Rd,GRANITE POINT Platf GMS <O-11473~>,,33-14,GRANITE POINT Platform GMS <O-11653~>,,ll-13,GRANITE POINT Platform Closest approach Last revised Distance M.D. Diverging from 22-May-91 1780.1 4018,0 11848.4 22-May-91 688.9 4018.0 10680.0 22-May-91 319.8 4018.0 4018.0 22-May~91 - . 22-May-91 - 22-May-91 - - 22-May-91 346.2 4018.0 10440.0 22-May-91 - 22-May-91 - 22-May-91 1041.3 4018.0 11760.0 22-May-91 - 22-May-91 - 22-May-91 1298.6 4018.0 7636.0 22-May-91 1298.6 4018,0 7382.8 22-May-91 1298.6 4018.0 4018.0 22-May-91 - 22-May-91 - - 22-May-91 - - 23-Ju[-91 - - 20-Jul-91 - - 22-May-91 - - 22-May-91 - - - 22-May-91 0.0 4018.0 8038.1 RECEIVED Naska Oil & Gas Cons, Com~-nission ~,nchora[~e UNOCAL GRANITE POINT Ptatform, 11-13Rd Granite Point Fietd,Cook [ntet, Ataska CLEARANCE LISTING Page 1 Your ref : 11-13 Rd Version #4 Last revised : 17-0ct-91 Reference wel[path Object we[lpath : GMS <O-11653~>,,11-13,GRANITE POINT Platform M.D. Angle fm Min'm TCy[ T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates HighSide Dist Dist 4018.0 4067.6 4119.5 4171.4 4223.2 3992.1 245.6N 73.6W 4018.0 3992.1 245.6N 73.6W -90.0 0.0 0.0 4040.0 258.7N 71.3W 4067.6 4040.0 258.7N 71.0W +74.0 0.3 0.3 4090.0 272.3N 69.3W 4119.5 4089.9 272.5N 68.1W +75.9 1.2 1.2 4140.0 2~5.0N 67.8W 4171.4 4139.8 286.3N 65.0W +78.0 2.8 2.8 4190.0 299.7N 66.7i4 4223.2 4189.5 300.2N 61.8~ +79.5 4.9 4.9 4275.1 4327.0 4378.8 4430.7 4471.1 4240.0 313.5N 66.1~ 4274.9 4239.2 314.6N 58.6W +78.6 7.6 7.6 4290.0 327.2N 66.0W 4326.6 4288.7 329.3N 55.5W +77.6 10.8 10.8 4340.0 341.0N 66.3~ 4378.3 4338.0 344.2N 52.0W +78.3 14.8 14.8 4390.0 354.8N 67.2~ 4429.9 4387.3 359.0N 48.4W +79.9 19.4 19.5 4429.0 365.6N 68.1~ 4470.2 4425.8 370.7N 45.6W +81.1 23.4 23.5 4482.6 4534.5 4586.4 4638.3 4690.2 4440.0 368.6N 68.4~ 4481.6 4436.6 374.0N 44.8~ +81.1 24.5 24.6 4490.0 382.4N 69.914 4533.2 4485.8 389.2N 41.2W +80.8 29.7 29.8 4540.0 396.2N 71.3W 4584.7 4534.9 404.4N 37.6~ +80.4 35.0 35.2 4590.0 410.1N 72.714 4636.4 4584.2 419.6N 33.8~ +80.3 40.4 40.7 4640.0 423.9N 74.1W 4688.2 4633.7 434.6N 30.3W +80.4 45.6 45.8 4742.1 4794.0 4845.8 4897.7 4949.6 4690.0 437.7N 75.6~ 4739.9 4683.1 449.3N 26.8W +80.8 50.6 50.8 4740.0 451.5N 77.0~ 4791.3 4732.2 463.8N 23.1~ +81.2 55.8 56.1 4790.0 465.4N 78.4W 4843.0 4781.6 478.4N 19.3W +81.6 61.1 61.4 4840.0 479.2N 79.8~ 4894.9 4831.4 493.0N 15.714 +82.0 66.1 66.4 4890.0 493.0N 81.2~ 4946.8 4881.1' 507.5N 12.4~ +82.3 71.0 71.3 5001.5 5053.4 5105.3 5157.2 5209.1 4940.0 506.8N 82.714 4998.6 4930.7 521.9N 9.OW +82.6 75.7 76.0 4990.0 520.6N 84.1~ 5050.4 4980.5 536.2N 5.8~ +83.0 80.4 80.7 5040.0 534.5N 85.5~ 5102.5 5030.4 550.3N 2.714 +83.5 84.8 85.1 5090.0 548.3N 86.914 5155.0 5081.0 564.4N 0.1E +84.0 89.0 89.2 5140.0 562.1N 88.4W 5207.2 5131.2 578.4N 2.7E +84.4 92.9 93.1 5261.0 5312.9 5364.8 5416.7 5468.6 5190.0 575.9N 89.8W 5259.4 5181.5 592.2N 5.0E +85.0 96.5 96.8 5240.0 589.8N 91.2~ 5311.5 5231.8 605.6N 7.2E +85.6 100.0 100.2 5290.0 603.6N 92.6~ 5363.4 5282.0 618.7N 9.2E +86.4 103.3 103.5 5340.0 617.4N 94.0~ 5415.4 5332.3 631.6N 11.3E +87.2 106.6 106.8 5390.0 631.2N 95.5W 5467.6 5382.9 644.2N 13.2E +88.1 109.7 109.8 5520.5 5440.0 645.0N 96.9W 5520.0 5433.8 656.6N 14.9E +89.1 112.6 112.8 5572.4 5490.0 658.9N 98.3W 5572.5 5484.8 668.9N 16.4E +90.1 115.2 115.4 5624.3 5540.0 672.7N 99.7i4 5624.7 5535.5 681.0N 17.5E +91.1 117.6 117.7 5676.2 5590.0 686.5N 101.2~ 5676.5 5585.9 693.1N 18.5E +92.1 119.9 120.1 5728.1 5640.0 700.3N 102.6~ 5728.5 5636.6 705.2N 19.6E +93.0 122.3 122.4 5780.0 5690.0 714.2N 104.0~ 5780.9 5687.5 717.2N 20.4E +94.0 124.4 124.5 5831.8 5740.0 728.0N 105.4~ 5833.1 5738.3 729.2N 21.0E +94.9 126.4 126.5 5883.7 5790.0 741.8N 106.8W 5885.1 5788.9 741.3N 21.5E +95.7 128.4 128.4 5935.6 5840.0 755.6N 108.2~ 5937.4 5839.7 753.5N 21.9E +96.5 130.2 130.2 5987.5 5890.0 769.4N 109.714 5989.8 5890.6 765.9N 22.0E +97.2 131.8 131.8 6039.4 6091.3 6143.2 6195.1 6247.0 5940.0 783.3N 111.1~ 6042.0 5941.4 778.3N 22.0E +97.9 133.2 133.2 5990.0 797.1N 112.5W 6094.1 5992.0 790.7N 21.9E +98.5 134.6 134.6 6040.0 810.9N 113.9W 6146.4 6042.8 803.0N 21.6E +99.2 135.8 135.8 6090.0 824.7N 115.4W 6198.8 6093.7 815.3N 21.0E +9<2.9 136.8 136.8 6140.0 838.6N 116.8W 6251.2 6144.6 827.5N 20.3E +100.6 137.6 137.6 6298.9 6190.0 852.4N 118.2W 6303.8 6195.9 839.5N 19.3E +101.4 138.3 138.3 6350.8 6240.0 866.2N 119.6~ 6355.7 6246.4 851.5N 18.3E +102.2 138.8 138.9 6402.7 6290.0 880.0N 121.0~ 6408.1 6297.3 863.6N 17.2E +103.0 139.4 139.4 6454.6 6340.0 893.8N 122.5~ 6460.9 6348.6 876.2N 15.8E +103.6 139.7 139.7 6506.5 6390.0 907.7N 123.9W 6514.5 6400.5 889.3N 13.8E +104.1 139.4 139.4 6558.4 6440.0 921.5N 125.3~ 6566.9 6451.2 902.4N 11.7E +104.5 6610.3 6490.0 935.3N 126.7W 6618.8 6501.4 915.6N 9.4E +104.8 6662.2 6540.0 949.1N 128.2~ 6670.4 6551.2 928.8N 7.2E +105.1 6714.1 6590.0 962.9N 129.6W 6722.2 6601.2 942.0N 5.0E +105.4 All data is in feet un[ess otherwise stated Coordinates are from slot #3-9 and TVDs are from wet[head. Vertical section is from wellhead on azimuth 352.70 degrees. Calculation uses the minimum curvature method. 138.8 138.8 138.0 138.0 137.3 137.3 136.7 136.7 R CEIVED Alaska Oil & G,,',~s Cons. Cornn~ission M.D. UNOCAL GRANITE POINT Ptatform, 11-13Rd Granite Point Field,Cook Inlet, Alaska Reference wel[path CLEARANCE LISTING Page 2 Your ref : 11-13 Rd Version #4 Last revised : 17-0ct-91 Object wettpath : GMS <O-11653'>,,11-13,GRANITE POINT Platform T.V.D. Rect Coordinates Angle fm Min'm TCy[ M.D. T.V.D. Rect Coordinates HighSide Dist Dist 6766.0 6640.0 976.8N 131.0W 6774.2 6817.8 6690.0 990.6N 132.4W 6826.4 6860.3 6730.9 1001.9N 133.6W 6869.4 6869.7 6740.0 1004.4N 133.8W 6878.8 6921.6 6790.0 1017.9N 135.2W 6930.7 6973.2 6840.0 1030.9N 136.6W 6981.8 7024.8 6890.0 1043.4N 137.9W 7033.1 7076.2 6940.0 1055.5N 139.1~ 7084.4 7127.6 6990.0 1067.1N 140.3W 7135.6 7178.8 7040.0 1078.2N 141.4~ 7186.8 7230.0 7090.0 1088.9N 142.5W 7238.0 7281.0 7140.0 1099.0N 143.6W 7289.3 7331.9 7190.0 1108.8N 144.6~ 7340.7 7382.8 7240.0 1118.0N 145.5~ 7391.8 7433.6 7290.0 1126.9N 146.4~ 7442.5 7484.3 7340.0 1135.2N 147.3W 7492.9 7534.9 7390.0 1143.1N 148.1W 7543.3 7585.5 7440.0 1150.6N 148.9~ 7593.7 7636.0 7490.0 1157.6N 149.6~ 7644.3 7686.4 7540.0 1164.2N 150.3W 7695.0 7736.8 7590.0 1170.3N 150.91~ 7745.5 7787.1 7640.0 1176.0N 151.5~ 7795.6 7837.4 7690.0 1181.2N 152.0~ 7845.4 7887.6 7740.0 1186.0N 152.5W 7894.8 7937.8 7790.0 1190.4N 153.0~ 7944.7 7988.0 7840.0 1194.3N 153.4~ 7994.9 8038.1 7890.0 1197.8N 153.7~ 8044.6 8088.2 7940.0 1200.8N 154.0W 8093.8 8138.2 7990.0 1203.4N 154.3W 8143.0 8188.3 8040.0 1205.6N 154.5W 8192.2 8238.3 8090.0 1207.3N 154.7W 8241.4 8288.3 8140.0 1208.6N 154.9W 8290.4 8338.3 8190.0 1209.5N 154.9W 8339.2 8388.4 8240.0 1209.9N 155.0~ 8387.8 8413.4 8265.0 1210.0N 155.0~ 8412.2 8438.4 8290.0 1210.0N 155.0~ 8436.4 8488.4 8340.0 1210.0N 155.0W 8485.2 8538.4 8390.0 1210.0N 155.0W 8534.0 8588.4 8440.0 1210.0N 155.0~ 8583.0 8638.4 8490.0 1210.0N 155.0W 8631.8 8688.4 8540.0 1210.0N 155.0W 8680.4 8738.4 8590.0 1210.0N 155.0~ 8728.6 8788.4 8640.0 1210.0N 155.0W 8776.2 6651.5 955.1N 2.8E +105.8 136.1 136.1 6702.0 967.9N 0.6E +106.3 135.4 135.4 6743.7 978.3N 1.5W +106.8 134.8 134.8 6~52.9 980.6N 2.OW +107.0 134.6 134.6 6803.2 992.8N 4.8~ +107.6 133.5 133.5 6852.9 1004.6N 7.4W +108.2 132.4 132.5 6902.7 1016.2N 9.9W +108.6 131.4 131.4 6952.7 1027.6N 12.4W +109.1 130.3 130.4 7002.6 1038.6N 15.0W +109.4 129.1 129.2 7052.6 1049.6N 17.5~ +109.6 127.8 127.8 7102.6 1060.6N 20.1W +109.6 126.3 126.4 7152.5 1071.6N 22.8W +109.4 124.5 124.6 7202.7 1082.5N 25.6W +109.1 122.5 122.6 7252.6 1092.9N 28.7W +108.8 120.2 120.3 7302.2 1103.0N 31.9~ +108.4 117.7 117.8 7351.5 1113.1N 34.9W +107.6 115.1 115.2 7400.7 1123.5N 37.9~ +106.6 112.5 112.7 7449.9 1134.1N 40.8W +105.1 109.8 110.0 7499.3 1144.9N 43.8~ +103.2 107.0 107.2 7548.7 1156.0N 47.0W +100.9 104.0 104.2 7597.7 1167.2N 50.4W +98.1 100.8 101.0 7646.4 1178.6N 53.9~/ +94.7 97.8 98.0 7694.7 1190.1N 57.4W +90.8 95.2 95.3 7742.7 1201.8N 60.8W +86.3 93.1 93.2 7791.0 1213.5N 64.3W +81.4 91.6 91.6 7839.7 1225.0N 68.2W +76.0 90.5 90.5 7887.9 1236.3N 72.4W +70.5 90.1 90.1 7935.7 1247.5N 76.4W +64.7 90.7 90.7 7983.4 1258.7N 80.6~ +58.9 92.4 92.5 8031.2 1269.8N 84.8W +53.2 95.2 95.5 8078.8 1280.9N 89.0~ +47.7 99.2 99.7 8126.4 1291.9N 93.4~ +42.6 104.4 105.1 8173.7 1302.8N 97.8W +38.0 110.6 111.7 8221.0 1313.7N 102.0W +34.0 118.0 119.6 8244.6 1319.1N 104.1W +26.7 122.1 123.9 8268.2 1324.5N 106.2~ +25.0 126.3 128.3 8315.6 1335.2N 110.5~ +22.1 135.2 137.4 8363.0 1346.0N 114.9W +19.6 144.3 147.0 8410.6 1356.7N 119.4~ +17.5 153.8 156.7 8458.0 1367.3N 124.2W +15.8 163.4 166.7 8505.2 1377.9N 129.2W +14.5 173.4 177.0 8551.9 1388.4N 134.3~ +13.7 183.6 187.8 8598.0 1399.0N 139.6W +13.3 194.2 199.0 All data is in feet un[ess otherwise stated Coordinates are from slot #3-9 and TVDs are from wellhead. Vertical section is from wet[head on azimuth 352.70 degrees. Calculation uses the minimum curvature method. UNOCAL GRANITE POINT Platform slot #3-9 Granite Point Field Cook Inlet, Alaska PROPOSAL LISTING Your ref : 11-13 Rd Version #4 Our ref : prop252 Other ref : Date printed : 17-0ct-91 Date created : 4-Sep-91 Last revised : 17-0ct-91 Field is centred on O.O00,O.O00,3.00000,N Structure is centred on n60 57 52.745,w151 20 20.066,-189 UNOCAL GRANITE POINT Platform, 11-13Rd Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : 11-13 Rd Version Last revised : 17-0ct-91 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E $ Deg/lOOFt Sect 4018.00 15.53 11.11 3992.14 245.63 N 73.62 W 0.00 4100.00 15.43 8.06 4071.17 267.20 N 69.97 W 1.00 4200.00 15.37 4.30 4167.58- 293.59 N 67.11 ~ 1.00 4300.00 15.38 0.53 4264.01 320.07 N 66.00 ~ 1.00 4400~00 15.44 356.77 4360.41 346.62 N 66.63 W 1.00 252.99 ST Tie-In Point 273.92 299.74 325.86 352.28 4471.14 15.53 354.13 4428.97 365.55 N 68.13 ~ 1.00 4500.00 15.53 354.13 4456.78 373.24 N 68.92 W 0.00 5000.00 15.53 354.13 4938.52 506.41 N 82.62 ~ 0.00 5500.00 15.53 354.13 5420.26 639.59 N 96.32 ~ 0.00 6000.00 15.53 354,13 5902.01 772.76 N 110.02 ~ 0.00 371.24 End of Turn 378.97 512.80 646.64 780.48 6500.00 15.53 354,13 6383.75 905.93 N 123.72 W 0.00 6860,29 15.53 354,13 6730.88 1001.90 N 133.59 W 0.00 6900.00 15.13 354,13 6769.18 1012.34 N 134.67 ~ 1.00 7000.00 14.13 354,13 6865.94 1037.47 N 137.25 W 1.00 7100.00 13.13 354.13 6963.12 1060.92 N 139.66 ~ 1.00 914.31 1010.75 Begin Angle Drop 1021.25 1046.50 1070.07 7200.00 12.13 354,13 7060.70 1082.68 N 141.90 W 1.00 7300.00 11.13 354,13 7158.64 1102.73 N 143.96 ~ 1.00 7400.00 10.13 354,13 7256.92 1121.09 N 145.85 ~ 1.00 7500.00 9.13 354,13 7355.51 1137.74 N 147.57 ~ 1.00 7600.00 8.13 354,13 7454.38 1152.67 N 149.10 W 1.00 1091.93 1112.09 1130.54 1147.26 1162.27 7700.00 7.13 354,13 7553.49 1165.88 N 150.46 ~ 1.00 7800.00 6.13 354.13 7652.82 1177,37 N 151.64 ~ 1.00 7900.00 5.13 354,13 7752.34 1187.14 N 152.65 ~ 1.00 8000.00 4.13 354.13 7852.01 1195.17 N 153.47 ~ 1.00 8100.00 3.13 354,13 7951.80 1201.48 N 154.12 W 1.00 1175.55 1187.10 1196.91 1204.99 1211.32 8200.00 2.13 354.13 8051.70 1206.05 N 154.59 W 1.00 8300.00 1.13 354.13 8151.66 1208.88 N 154.88 ~ 1.00 8400.00 0.13 354.13 8251.65 1209.98 N 155.00 ~ 1.00 8413.35 0.00 0.00 8265.00 1210.00 N 155.00 ~ 1.00 8500.00 0.00 0,00 8351.65 1210.00 N 155.00 ~ 0.00 1215.92 1218.77 1219.87 1219.89 End Angle Drop 1219.89 9000.00 0.00 0.00 8851.65 1210.00 N 155.00 ~ 0.00 9500.00 0.00 0.00 9351.65 1210.00 N 155.00 ~ 0.00 10000.00 0.00 0.00 9851.65 1210.00 N 155.00 W 0.00 10500.00 0.00 0.00 10351.65 1210.00 N 155.00 ~ 0.00 11000.00 0.00 0.00 10851.65 1210.00 N 155.00 ~ 0.00 1219.89 1219.89 1219.89 1219.89 1219.89 11093.35 0.00 0.00 10945.00 1210.00 N 155.00 ~ 0.00 11500.00 0.00 0.00 11351.65 1210.00 N 155.00 W 0.00 11648.35 0.00 0.00 11500.00 1210.00 N 155.00 W 0.00 11848.35 0.00 0.00 11700.00 1210.00 N 155.00 W 0.00 1219.89 A - T/ Hemlock 1219.89 1219.89 1219.89 TD All data is in feet unless otherwise stated Coordinates are from slot ~3-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 352.70 degrees. Calculation uses the minimum curvature method. UNOCAL GRANITE POINT P[atform, 11-13Rd Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : 11-13 Rd Version #4 Last revised : 17-0ct-91 Co~nents in wel[path MD TVD Rectangular Coords. Con~nent 4018.00 3992.14 245.63 N 73.62 W ST Tie-In Point 4471.14 4428.97 365.55 N --68.13 W End of Turn 6860.29 6730.88 1001.90 N 133.59 ~ Begin Angle Drop 8413.35 8265.00 1210.00 N 155.00 ~ End Angle Drop 11093.35 10945.00 1210.00 N 155.00 W A - T/ Hemlock 11848.35 11700.00 1210.00 N 155.00 ~ TD Casing positions in string Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 3992.14 245.63N 73.62W n/a 11700.00 1210.00N 155.00~ 7" Liner Targets associated with this we[lpath Target name Position T.V.D. Local rectangular coords. Date revised B - B/ Hemlock not specified 11500.00 1210.00N 155.00~ 4-Sep-91 A - T/ Hemlock not specified 10945.00 1210.00N 155.00~ 4-Sep-91 ALL data is in feet unless otherwise stated Coordinates are from slot ~3-9 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 352.70 degrees. Calculation uses the minimum curvature method. UNOCAL GRANITE POINT Platform, 11-13Rd Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 1 Your ref : 11-13 Rd Version #4 Last revised : 17-0ct-91 Measured Inclin. Azimuth True Vert. R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOFt Sect 4018.00 15.53 11.11 3992.14 2138.10 S 1294.76 E 0.00 252.99 4100.00 15.43 8.06 4071.17 2116.52 S 1298.41 E 1.00 273.92 4200.00 15.37 4.30 4167.58- 2090.13 S 1301.27 E 1.00 299.74 4300.00 15.38 0.53 4264.01 2063.66 S 1302.38 E 1.00 325.86 4400.00 15.44 356.77 4360.41 2037.10 S 1301.75 E 1.00 352.28 ST Tie-In Point 4471.14 15.53 354.13 4428.97 2018.17 S 1300.25 E 1.00 371.24 4500.00 15.53 354.13 4456.78 2010.49 S 1299.46 E 0.00 378.97 5000.00 15.53 354.13 4938.52 1877.31 S 1285.76 E 0.00 512.80 5500.00 15.53 354.13 5420.26 1744.14 S 1272.06 E 0.00 646.64 6000.00 15.53 354.13 5902.01 1610.96 S 1258.36 E 0.00 780.48 End of Turn 6500.00 15.53 354.13 6383.75 1477.79 S 1244.66 E 0.00 914.31 6860.29 15.53 354.13 6730.88 1381.83 S 1234.79 E 0.00 1010.75 6900.00 15.13 354.13 6769.18 1371.38 S 1233.71 E 1.00 1021.25 7000.00 14.13 354.13 6865.94 1346.25 S 1231.13 E 1.00 1046.50 7100.00 13.13 354.13 6963.12 1322.80 S 1228.72 E 1.00 1070.07 Begin Angle Drop 7200.00 12.13 354.13 7060.70 1301.05 S 1226.48 E 1.00 1091.93 7300.00 11.13 354.13 7158.64 1280.99 S 1224.42 E 1.00 1112.09 7400.00 10.13 354.13 7256.92 1262.63 S 1222.53 E 1.00 1130.54 7500.00 9.13 354.13 7355.51 1245.99 S 1220.81 E 1.00 1147.26 7600.00 8.13 354.13 7454.38 1231.05 S 1219.28 E 1.00 1162.27 7700.00 7.13 354.13 7553.49 1217.84 S 1217.92 E 1.00 1175.55 7800.00 6.13 354.13 7652.82 1206.35 S 1216.74 E 1.00 1187.10 7900.00 5.13 354.13 7752.34 1196.58 S 1215.73 E 1.00 1196.91 8000.00 4.13 354.13 7852.01 1188.55 S 1214.91 E 1.00 1204.99 8100.00 3.13 354.13 7951.80 1182.24 S 1214.26 E 1.00 1211.32 8200.00 2.13 354.13 8051.70 1177.67 S 1213.79 E 1.00 1215.92 8300.00 1.13 354.13 8151.66 1174.84 S 1213.50 E 1.00 1218.77 8400.00 0.13 354.13 8251.65 1173.74 S 1213.38 E 1.00 1219.87 8413.35 0.00 0.00 8265.00 1173.72 S 1213.38 E 1.00 1219.89 8500.00 0.00 0.00 8351.65 1173.72 S 1213.38 E 0.00 1219.89 End Angle Drop 9000.00 0.00 0.00 8851.65 1173.72 S 1213.38 E 0.00 1219.89 9500.00 0.00 0.00 9351.65 1173.72 S 1213.38 E 0.00 1219.89 10000.00 0.00 0.00 9851.65 1173.72 S 1213.38 E 0.00 1219.89 10500.00 0.00 0.00 10351.65 1173.72 S 1213.38 E 0.00 1219.89 11000.00 0.00 0.00 10851.65 1173.72 S 1213.38 E 0.00 1219.89 11093.35 0.00 0.00 10945.00 1173.72 S 1213.38 E 0.00 1219.89 11500.00 0.00 0.00 11351.65 1173.72 S 1213.38 E 0.00 1219.89 11648.35 0.00 0.00 11500.00 1173.72 S 1213.38 E 0.00 1219.89 11848.35 0.00 0.00 11700.00 1173.72 S 1213.38 E 0.00 1219.89 A - T/ Hemlock TD All data is in feet unless otherwise stated Coordinates are from NW Corner of Sec. 13 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 352.70 degrees. Calculation uses the minimum curvature method. UNOCAL GRANITE POINT Ptatform, 11-13Rd Granite Point Field,Cook Inlet, Alaska PROPOSAL LISTING Page 2 Your ref : 11-13 Rd Version #4 Last revised : 17-0ct-91 Comments in weLLpath ND TVD Rectangular Coords. Comment 4018.00 3992.14 2138.10 S 1294.76 E ST Tie-In Point 4471.14 4428.97 2018.17 S ~300.25 E End of Turn 6860.29 6730.88 1381.83 S 1234.79 E Begin Angle Drop 8413.35 8265.00 1173.72 S 1213.38 E End Angle Drop 11093.35 10945.00 1173.72 S 1213.38 E A - T/ Hemlock 11848.35 11700.00 1173.72 S 1213.38 E TD Casing positions in string 'A' Top ND Top TVD Rectangular Coords. Bot ND Bot TVD Rectangular Coords. Casing n/a 3992.14 2138.10S 1294.75E n/a 11700.00 1173.72S 1213.38E 7" Liner Targets associated with this wellpath Target name Position T.V.D. Local rectangular coords. Date revised B - B/ Hemlock not specified 11500.00 1173.72S 1213.38E 4.-Sep-91 A - T/ Hemlock not specified 10945.00 1173.72S 1213.38E 4-Sep-91 All data is in feet unless otherwise stated Coordinates are from N~ Corner of Sec. 13 and TVDs are from wellhead. Vertical section is from wellhead on azimuth 352.70 degrees. Calculation uses the minimum curvature method. 1 18" @ 684' Z] ~3-~/8" 6 J-55 @ zt-o 18'Z 7" TOL @ 9800' e-5/8" 53.5// Pl10 @ 10100' 7" L @ 11900' 2 4 'x TUBING DETAIL: 2-7/8", 6.4#, N-80, BUTT 1) SUBSURFACE SAFETY VALVE 2) GAS LIFT MANDRELS 5) "XA" SLIDING SLEEVES 4) PERMANENT PACKER 5) "X" LANDING NIPPLE 6) RE-ENTRY GUIDE WELL Granite Pt. ii- 13 Redrill PROPOSED COMPLETION UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: CLL SCALE' NONE DATE' 10-28-9 1 Granite Point 11-13 Redrill 10/28/91 Anticipated pressure: Maximum surface pressure calculation; Mud weight: ............................ 102 PCF = .71 psi/ft. Shoe (9-5/8") depth: ....................... 10100'MD/9951'TVD Estimated fracture gradient (9-5/8" shoe): ...... 0.95 psi/ft. Total depth: .............................. l1848'MD/l1700'TVD Bottom hole pressure gradient: ................. 0.70 psi/ft. Gas gradient (assume worst case) ................. 0.0 psi/ft. Wellbore volume with gas kick situation: 3/4 mud & 1/4 gas. Maximum surface pressure = Btm hole press - Hydrostatic press MSP = BHP - (3/4 mud + 1/4 gas) MSP=(ll700 ft * .70 psi/ft) - ((.75 (11700 ft * .71psi/ft.)) + (.25 (11700 ft * 0 psi/ft.))) MSP = 1960 psi. Therefore, the greatest hydrostatic pressure at the 9-5/8" shoe (HPsh) is when the gas bubble reaches the shoe if a constant BHP is applied. A conservative estimate would be the maximum surface pressure (MSP) plus the hydrostatic pressure at that casing depth (HPcsg). HPsh = MSP + HPcsg HPsh = 1960 psi +(9951 ft * .71 psi/ft.) HPsh = 9025 psi This (HPsh = 9025 psi) is less than the fracture pressure at the same shoe (FPsh = .95 psi/ft * 9951 ft = 9453 psi) and thus sufficiently adequate to handle the well kick. This scenario is considered extreme since actual well kicks have seen a maximum of 300 psi on the shut-in casing pressure. ,,__,,. STATE OF ALASKA AL,~ ' OIL AND GAS CONSERVATION COMMIE APPLI I'ION FOR SUNDRY APPHOVALS 1. Type of Request: Abandon ~ Suspend __ Alter casing __ Repair well __ Change approved program __ Pull tubing __ Variance __ 2..Nar. ne of uj~era[or 5. Type of Well: union olI Company of California Development.~ Exploratory __ 3'~.d~e. SSBoX 196247, Anch , AK, 99519 Stratigraphic__ · Service __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ Stimulate __ Perforate __ Other __ 4. Location of well at surface Leg #3, Conductor 9, Granite Point 6. Dat~Bele~j~ign (D~: or KB) aDov~ MS~et 7. I~r~lr]o~]~az~e State #1 8. Well number W, SM GP 11-13 9. Permit number 67-33 10. APl number 50-- 133-20026 2384' FNL & 1368' FWL, F/NW Corn. Sec. 13, At top of productive interval 8246' MD, 8083' TVD 1102' FNL & 1277' FWL, T10N, R12W SM At effective depth 11,603' MD, 11,378' TVD 740' FNL & 1392 FWL, T10N, R12W, SM At total depth 11,653' MD, 11,427' TVD 740' FNL & 1414' FWL, T10N, R12W, SM T10N, RI 11. Field/Pool ~anite Point/Middle Ken 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,653 11,603' to 11,653' feet PlugS(measured) 11,427 feet 11,603 feet Junk(measured) None 11,378 feet Casing Structural Conductor Surface Intermediate Production Liner ~ngth 684' 4018' 10,143' 1680' Size Cemented Measureddepth ~uevedicaldepth 18" 580 SX 684' 683' 13-3/8" 2395 SX 4018' 3992' 9-5/8" 1650 SX 10,143' 9944' 7" 425 SX 9971'-11,651' 9973'-11,425 RECEIV £ Perforation depth: measured See attachment #1 Nov - 4 1991 true vertical Tubing (size. grade, and measured depth) Packers and SSSV (type and measured depth) ~laskaO~l&GasCons. Coml 2-7/8", 6.4#/ft., N-80, 11,035' Anch0r~ 3-1/2", 9.2#/ft., N-80, 8128' Baker single hyd pkr @ 9907' Baker dual hyd · , , pkr @ 8112' Otis SSSV @ 227 in 3-1/2" tbs, Ot SSSV @ 291' in 2-7/8" TBG 13. Attachments Description summary of proposal -,X- Detailed operations program __ BOP sketch x 14. Estimated date for commencing operation 15. Status of well classification as: November 28, 1991 16. If proposal was verbally approved Oil ~ Gas __ Suspended __ Name of approver Date approved Service 17. I hereby certify that tl7'e f~regoing is true ~ correct to the best of my knowledge. SI;~;~ GARY S..~S'~'"'-~' ~)~~Title REGIONAL DRILLING MANAGERDato ,o/Z.~/~, FOR COMMISSION USE ONLY Conditions of approval: Not,~y Commission so representative may witness I Approve% Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~ 0 '7 Approved Copy Returned Approved by order of the Commissioner ORIGINAL SIGNED BY I,ONNIE C. SMITH Form 10-403 Rev 06/15/88 Commissioner Date II. SUBMIT IN TRIPLICATE is Abandonment Procedure: Granite Point 11-13 UNOCAL plans to abandon the existing wellbore in the following manner. 1) 2) 3) 4) 5) 6) 7) 8) Move in and rig up. Kill the well with 64 pcf spud mud. Set BPV. Nipple down the tree and nipple up the BOPE. Pull existing dual 3 1/2" completion from 11,035' Including the Baker packer at 9907'. Run into well to 11,603' (PBTD) and lay a balanced cement plug approximately 573' in height within the 7" liner (minimum of 105 sx) with top at 11,030'. Pull up hole and reverse circulate pipe clean. This plug will abandon the perforations from 11,130' to 11,540'. Run into well to 9885' and lay a balanced cement plug approximately 361' in height within the 9 5/8" casing (minimum of 135 sx) with top at 9524'. Pull up hole and reverse circulate pipe clean. This plug will abandon the perforations from 9624' to 9835'. Run into well to 9524' and lay a balanced cement plug approximately 289' in height within the 9 5/8" casing (minimum of 105 sx) with top at 9235'. Pull up hole and reverse Circulate pipe clean. This plug will abandon the perforations from 9335' to 9497'. Run into well to 9122' and lay a balanced cement plug approximately 317' in height within the 9 5/8" casing (minimum of 120 sx) with top at 8805'. Pull up hole and reverse circulate pipe clean. This plug will abandon the perforations from 8905' to 9072'. Run into well to 8805' and lay a balanced cement plug approximately 385' in height within the 9 5/8" casing (minimum of 145 sx) with top at 8420'. Pull up hole and reverse circulate pipe clean. This plug will abandon the perforations from 8520' to 8760'. Run into well to 8346' and lay a balanced cement plug approximately 246' in height within the 9 5/8" casing (minimum of 95 sx) with top at 8100'. Pull up hole and reverse circulate pipe clean. This plug will abandon the perforations from 8200' to 8296'. 9) 10) 11) Note: Run in hole with a 9 5/8" cement retainer and set at 4150'. Cut and pull the existing 9 5/8" casing from 4100'. Clean out inside the 13 3/8" casing to 4100'. Underream the section (4018'-4100') to 17" and lay a balanced kickoff plug from 4150' to 3800'(minimum 298 sx). The cement kickoff plug will prevent any hydrocarbon movement into shallower zones. Kick off the plug, perform leak off test at the 13 3/8" casing shoe (4018') and begin the 12 1/4" redrill. Should ~S be encountered, UNOCAL will conform to all requirements as set forth in 20 AAC 25.065. RECEIVED NOV - 4 Alas Oil & Gas O0ns. 'Ancho[age ITEM (1) Fee (2) Loc , , ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE D)4TE, [2 ~hru ~ ~. (3) Admin [8] 9. [9 thr,u, 13] 10. ~,~/~ 1/-/~-q/ 11. [10 & 13] 12. 13. C~) Casg '~,~'~'~.. /]-ff-~-~]' 14. [14 thru 22] 15. C5) BOPE [23 thru 28] 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. geol ogy. DWJ~----(~ eng i neer i nq~ MT.M.~ LCS/- B dH ~ur- f ¢Z"7 rev 03/29/91 io/6.01.1 Is permit fee attached ............................................... Is well to be located in a defined pool .............................. Is well located proper distance from property line ................... Is'well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviat, ed & is wel/bore plat included ................... 7. Is operator the only affected ,party .................................. 8. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is lease nLrnber appropriate .......................................... Does well have a unique name & nLrnber ................................ Lease & Well YES L NO REMARKS ..... . p __- Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonn~nt procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of divc~c;-~ BOPE attached .... Does BOPE have sufficient pressure rating -- test to,.Z?<:~ psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. ,,. INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE / 0 --! "FZ Well Histo.ry 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 APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. ALASKA COMPUTIN~ CENTER ....... SCHLU~BERGE~ ..... -'--~ COMPANY NAME : UNOCAL WELL NAME :: GP 11-13 RD .FIELD NAME : GRANITE POINT BOROUGH : KENAI STATE : ALASKA API NUMBER : 50-733-ZOOZ6-O! REFERENCE NO : g21~6 RECEIVED APR 1 6 1992 Alaska 011 & Gas Cons. Commi~lon Anchorage LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 1T-MAR-1992 18:17 PAGE: **** REEL HEADER SERVICE NAME : EDIT DATE : 92/013/17 ORIGIN : FLIC REEL NAME : 92146 CONTINUATION ,~ : PREVIOUS REEL COMMENT : UNOCAL~pGRANITE POINT~GP 11-13ROtSO-733-20026-01 **** TAPE HEADER **** SERVICe, NAME : EDIT DATE : 92/03/17 ORIGIN : FLIC CONTINUATION a : ~ PR~VIO:US TaPE : COMMENT : UNOCAL~GRAN~TE POINT~GP 11-13R0~50-733-20026-0~ **** FILE HERDER FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001A07 DATE : 92/03/17 MAX AEC SIZE : FILE TYPE : LO LAST FILE : SCHLUMBERGER WELL SERVICES COMPANY NAME: UNOCAL WELL: GP 11-13RD FIELD: GRANITE POINT BOROUGH: KENAI STATE: ALASKA API NUMBER: 50-733-20026 LOCATION: Z384e S & 1368tE ac NW CORNER SECTION: 13 TOWNSHIP: 1ON RANGE: 12W PERMANENT DATUM: MLLW ELEVATION: O" LOG MEASURED FROM RKB 110.9j ABOVE PERMANENT DATUM .IS TAPE VERIFICA'TION LISTING iCHLUMBERGER ALASKA COMPUTING CENTER 17-MAR-1992 18:17 PAGE: ELEVATIONS RUN #1 DATA: RUN NUMBER: DATE LOGGED: TO DRILLER: TO LOGGER: CASING 1: 1 06-FEB-19'92 1008'5' 10072' 13.375# @ OR'ILLER DEPTH OF 4023t BIT SIZE 1: 12.25" @ 10085" TYPE FLUID lin HOLE: FGM DENSITY: 9.T LB/GAL PH: MUD RESISTIVITY: FILTRATE RESISTIVITY: 1.68 MUD CAKE RESISTIVITY: RUN #g OATA: OATE LOGGED: FE~-26-19gZ RUN NUMBER:: TD DRILLER: 11560' TD LOGGER: VISCOSITY: 56 S FLUID LOSS: 5 C3 ~ 60 DEGF ~ 60 DEGF @ 60 DEGF TYPE FLUID IN HOLE: PHPA DENSITY: 13.5 PH: 10 VISCOSITY: FLUID LOSS: MUD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 2.57 1.33 3.51 ~ 59 DEGF @ 59 OEGF @ 59 DEGF MAXIMUM TEMP RECORDED: 140 DEGF LOGGING OISTRICT: LOGGING ENGINEER: WITNESS: KENAI CRYER STEWART DATE JOB STARTED: 16-MAR-92 JOB REFERENCE NO: 921~6 LDP/ANA: R. KRUWELL FILE EDIT. 00! UNOCAL GP 11-13 RD API ~ 50-733-20026-01 DATA SAMPLED -.5 FT .IS TAPE YERIFICATION LISTING ~CHLUMBERGER aLASKa COMPUTING CENTER 17-MAR,-1992 18:17 PAGE: 3 EXTENSION NAMES · OTE PMASOR I! ON .O'SI OIPO~E Si iR SONIC · MLT~ MICROLO! · L D,T L ITHO Ti ..C NT COM'PENSATEO .EaT ELECTROMAGNETIC IMA'GER N TOOL TABLE TYPE : CONS TUNI CN UNOCAL FN GRANITE POINT WN GP 11-13 RD APIN 50-733-20026-01 FL 2384:eS & 1368'E SEC'T 13 TOWN 1ON RANG 12W COUN KENAI STAT ALASKA VALU DEFI OF NW CORNERO COMPANY NAME FI ELD NAME WELL NAME API SERIAL NUMBER FIELO LOCATION SECTION 'TOWNSHIP RANGE COUNTY STATE OR PROVINCE NATI :USA WITN D. STEWART SON 5'~8509 POAT MLLW EPD FT O. LMF RKB APO FT 110o9 EKB FT 110.9 EDF FT -999.25 EGL FT -999.25 TOD FT 11560. OFT PHPa DFD G/C3 13..5 DFPH 10. DFV S DFL F3 ·. AMS OHMM 2.57 MST DEGF 59. RMFS OHMM ! MFST DEGF 59. RMCS OHMle 3.51 MCST OEGF 59. BHT OEGF 140. NATION tIITNESS NAME SERVICE ORDER NUMBER PERMANENT DATUM ELEVATION OF PERMANENT DATUM LOG MEASURED FROM ABOVE PERMANENT DATUM ELEVATION OF KELLY BUSHING ELEVATION OF DERRICK FLOOR ELEVATION OF GROUND LEVEL TOTAL DEPTH - DRILLER DRILLING FLUIO TYPE DRILLING FLUID DENSITY DRILLING FLUIO PH DRILLING FLUID VISCOSITY DRILLING FLUID LOSS RESISTIVITY OF MUD SAMPLE MUD SAMPLE TEMPERATURE RESISTIVITY OF MUD FILTRATE S MUD FILTRATE SAMPLE TEMPERATU RESISTIVITY OF MUD CAKE SAMPL MUD CAKE SAMPLE TEMPERATURE BOTTOM HOLE T~MPERATUR~ LIS TAPE VERIFICATION LISTING 5CHLUMx3ERGER ALASKA COMPUTING CENTER 1T-MAR-1992 18:17 PAGE= TABLE TYPE ': CURV DEFI DEPT DEPTH M'CAL LARGE ARM HOIA HOLE.DIAMETER TENS TENSION HTEN HE AD TENSION IOOF tDQF DEEP INDUCTION QUALITY FACTOR IMQF IMQF MED INDUCTION QUALITY FACTOR MTEM MUO TEMPERATURE MAES MUD RESISTIVITY IIRD DEEP INDUCTION REAL INTERMEDIATE CONDUCTIVITY IIXO OEEP INOUCTION QUAD INTERMEDIATE CONDUCTIVITY IIRM MEDIU~ INDUCTION REAL INTERMEDIATE CONDUCTIVITY IIXM MEDIUM INDUCTION QUAD INTERMEDIATE CONOUCTIVITY IOPH INDUCTION OEEP PHASOR RESISTIVITY IMPH INOUCTION MEDIUM PHASOR RESISTIVITY I'LD OEEP INDUCTION STANDARO PROCESSEO RESISTIVITY ILM MEOIUM INDUCTION STANDARD PROCESSED RESISTIVITY SFLU SFL RESISTIVITY UNAVERAGED SP SPONTANEOUS POTENTIAL SPD OITE SP GR ,GAMMA RAY TENS TENSION HTEN HEAD TENSION MTEM MUD TEMPERATURE MRES MUD RESISTIVI'TY MCAL LARGE ARM HDIA HOLE DIAMETER PR POISSONeS RATIO OTR2 DELTA-T SHEAR UPPER DIPOLE MODE RECEIVER DTMZ DELTA-T SHEA~ ~PPER DIPOLE MOOR COMPENSATED OT4P DELTA-T COMP E SIONAL HF MONOPOLE COMPENSATEO CP[S) DT4S DELTA-T SHEAR HF MONOPOLE COMPENSATED CP&S) GR GAMMARAY TENS TENSION HTEN HEAD TENS[ON MTEM MUO TEMPERATURE MRES MUO RESISTIVITY MCAL LARGE ARM HOIA HOLE OIAMETER GR GAMMA RAY TENS TENSION HTEN HEAD TENSION MAES MUD RESISTIVITY MTEM MUD TEMPERATURE TNRA THERMAL NEUTRON RATIO CALIBRATED RTNR RAW THERMAL NEUTRON RATIO RCFT RCFT RCNT RCNT CFTC CFTC CNTC CNTC TNPH THERMAL NEUTRON POROSITY .'IS TAPE YERIF'ICaTIDN LISTING ;CHLUMBERGER ~LASKA COMPUTING CENTER 17-MAR-1992 18:17 DEFI NPHI GR TENS HTEN MRES MTEM CALI LL LU LS LITH SS! SS2 LSHV SSHV QLS qSS RHOB DRHO DPHI GR TENS HTEN MRES MTEM NYR FVR GR NEUTRON POROSITY GAMMA RAY TENSION HE AD TENSION MUD RESISTIVITY MUD TEMPERATURE CALIPER LONG LOWER WINDOW COUNT RATE LONG UPPER 1-Z WINOOW COUNT RATE CLUI+LUZ) LONG SPACING COMPUTED COUNT RATE CLL+LU/Z) LITHOLOG WINDOW COUNT RATE SHORT SPACING ! WINDOW COUNT 'RATE SHORT SPACING Z WINDOW COUNT RATE LONG SPACING HIGH VOLTAGE SHORT SPACING HIGH VOLTAGE QUALITY CONTROL OF LONG SPACING FOR LOT QUALITY CONTgOL ON SHORT SPACING FOR LOT PHOTOELECTRIC FACTOR BU'LK DENSITY DELTA OENSITY PO~O SITY GAMMA RAY TENSION HEAe TENSION ~-~D RESISTIVITY M~O TEMPERATURE NEAR VgLTAGE REFERENCE FAR VOLTAGE REFERENCE GAM~A RAY PAGE: DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 6~EB TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 320 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 3 12 68 13 66 0 14 65 FT .IS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 17-MAR-1992 18:17 PAGE: TYPE REPR COOL: V,~LUE 15 66 68 16 66 0 66 ~ :SET TYPE- CHAN ~ NAME SERV UNIT SERVICE API AP:I API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER e LOG TYPE CLASS MOO NUMB SAMP ELEn CODE CHEX) DEPT FT 548509 O0 000 O0 0 ! I ! ~ 68 0000000000 nCA~L DTE IN 548509 O0 000 O0 O I I I ~ 68 HDIA OTE FT 548509 O0 000 O0 0 I I 1 4 68 TENS DTE L5 =548509 O0 000 O0 0 1 ! I 6 68 HTEN DT~ L~ 548509 O0 000 O0 0 I I ! ~ 68 IDQF OTE 548509 O0 000 O0 0 I 1' '1 4 68 IMQF DTE 548509 00 000 00 0 ! I I 4 68 MTEM DTE DEGF 548509 O0 000 O0 0 I 1 1 4 68 MRES DTE OHMM 548509 O0 000 O0 0 I I 1 6 68 IIRO OTE MMHO 548509 O0 000 O0 0 1 1 1 4 68 IIXO DTE nMHO 548509 O0 000 O0 0 1 1 1 4 68 IIRM OTE MMHO 548509 O0 000 O0 0 I I 1 4 68 IIXM DTE nMHO 548509 O0 ~000 O0 0 1 1 I 4 68 IOPH DTE OHMM 548509 O0 000 O0 0 I I I 4 68 InPH DTE OMMM 548509 00 000 00 '0 I I I 6 68 ILD DTE OHMM 548509 O0 000 O0 0 I I I 6 68 ILn DTE OHMM 548509 O0 000 O0 '0 I ! 1 4 68 SFLU DTE OHMM 548509 O0 000 O0 0 I 1 I 4 68 SP OTE nv 548509 O0 000 O0 0 I I I 6 68 SPD OTE 548509 O0 000 O0 0 I I I 4 68 GR OTE GAPI 548509 00 000 00 0 I I I 4 68 TENS DSI LB 548509 O0 000 O0 0 1 I I 4 68 HTEN DSI LB 548509 O0 000 O0 0 1 I I 6 68 MTEM 05I DEGF 548509 O0 000 O0 0 I I I 4 68 MRES DSI OHMM 548509 O0 000 O0 0 1 1 I 4 68 MCAL DSI IN 548509 O0 000 O0 0 I ! I 4 68 HOIA DSI FT 568509 O0 000 O0 0 I I I 6 68 PR OSI 54850g O0 000 O0 0 1 ! I 4 68 DTR2 OSI 548509 O0 000 O0 0 1 I I 4 68 DTMZ DSI 548509 O0 000 O0 0 I 1 1 4 68 DT4P OS! 548509 O0 000 O0 0 I 1 1 4 68 OT6S O$I 548509 O0 000 O0 0 I I I 4 68 GR OSI GAPI 548509 O0 000 O0 0 I I I ~ 68 TENS MLT L~ 568509 O0 000 O0 0 I I I 4 68 HTEN MLT L8 568509 O0 000 O0 0 I I I 4 68 MTEM MLT DEGF 548509 O0 000 O0 0 I 1 I 6 68 MRES MLT OHMM 568509 O0 000 O0 0 1 I 1 4 68 MCAL MLT IN 548509 O0 000 O0 0 I I I 4 68 HDIA MLT FT 548509 O0 000 O0 0 I I I 4 68 GR MLT GAPI 568509 O0 000 O0 0 I I I 4 68 TENS CNT LB 548509 00 000 00 0 I I 1 4 68 HTEN CNT LB 548509 00 000 00 0 I I I 6 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 .IS TAPE VERIFICATION LISTING ;CHLUMBERGER aLASKA COMPUTING CENTER 1T-MAR-1992 18:17 PAGE: NAME SERV UNIT SERVICE aPI ~API aPI API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER a LOG TYPE CLASS MOO NUMB SAMP ELEM Cage CHEX) MR'ES CNT OHMM 54850g O0 000 O0 :0 Z ! ! 4 68 0000000000 MTEM CNT OEGF :54850g O0 000 O0 0 ! ! ! 4 68 0000000000 TNRA CNT 548509 O0 000 O0 0 1 ! ! 4 68 0000000000 RTNR CNT 548509 O0 000 O0 '0 1 ! 1 4 68 0000000000 RCFT CNT CPS 548509 O0 000 O0 0 1 ! ! 4 68 0000000000 R:CNT CNT CPS 548509 O0 000 O0 0 ! ! ! 4 68 0000000000 CFTC CNT CPS 548509 O0 000 O0 0 ! ! ! 4 68 0000000000 CNTC CNT CPS 548509 O0 000 O0 0 ! 1 1 4 68 0000000000 TNPH CNT PU 548509 O0 000 O0 0 ! ! ! 4 68 000000.0000 NPHI CN'T PU 548509 O0 000 O0 ~0 ! ! ! 4 68 0000000000 GR CNT GAPI 548509 O0 000 O0 0 I ! ! 4 68 O00OO00000 TENS LOT LB 548509 O0 000 O0 0 ! ! I 4 68 0000000000 HTEN LOT LB 548.509 O0 000 O0 0 ! ! 1 4 68 0000000000 MRES .LOT OHMN 548509 O0 000 O0 '0 1 ! .t 4 68 0000000000 Iq'TEN LOT DEGF 568509 O0 000 O0 0 I I I 4 68 0000000000 CALI LOT IN 548509 O0 000 O0 0 ! 1 1 4 68 0000000000 LL LOT CPS 568509 O0 000 O0 0 ! 1.. X 4 68 0000000'000 LU LOT CPS 548509 O0 000 O0 0 ! ! ! 4 68 O:O00000000 LS LOT CPS 548509 O0 000 O0 0 ! ! ! 4 68 0000000000 LITH LOT CPS 548509 O0 000 O0 0 1 i I 4 68 OOOO000000 SS! LOT CPS 548509 O0 000 O0 0 ! 1 ! 4 68 0000000000 552 LDT CPS 548509 O0 000 O0 0 ! ! I 4 68 OOOOO00000 LSH¥ LOT V 548509 O0 000 O0 0 ! ! ! 4 68 0000000000 SS'HV LDT V 548509 O0 000 O0 0 I ! 1 4 68 0000000000 QLS LOT 548509 O0 000 O0 0 I 1 1 4 68 0000000000 QSS LOT 548509 O0 000 O0 0 ! ! ! 4 68 0000000000 PEF LOT 548509 O0 000 O0 0 ! ! ! 4 68 00,0000.0000 RHOB LDT G/C3 548509 O0 000 O0 0 ! ! ! 4 68 0000000000 ORHO LOT G/C3 548509 O0 000 O0 0 ! ! 1 4 68 0000000000 DPHI LOT PU 548509 O0 000 O0 0 ! I I 4 68 0000000000 GR LOT GAPI 548509 O0 000 O0 0 ! ! I 4 68 0000000000 TENS EPT LB 548509 O0 000 O0 0 ! ! 1 4 68 0000000000 HTEN EPT L8 548509 O0 000 O0 0 ! 1__ 1__ 4 68 0000000000 MRES EPT OHMM 548509 O0 000 O0 0 ! I 1 4 68 0000000000 MTEM EPT DEGF 548509 O0 000 O0 0 ! ! X 4 68 0000000000 NVR EPT V 548509 O0 000 O0 0 ! ! ! 4 68 0000000000 FVR EPT V 548509 O0 000 O0 0 I 1__ I 4 68 0000000000 GR EPT GAPI 548509 O0 000 O0 0 I ! ! 4 68 0000000000 DATA DEPT. 11567.000 MCAL.DTE -999.250 HDXA.DTE -999.250 TENS.DTE HTEN.DTE -g99.250 IDQF.DTE -999.250 IMQF.DTE -999o250 MTEN.OTE MRES.DTE -999.250 IIRD.DTE -999.250 IIXD.DTE -999.250 IIRN.OTE IIXM.DTE -g99.250 IDPH.DTE -999.250 IMPH.DTE -999.Z50 ILO.DTE ILM.DTE -g99.250 SFLU.DTE -99g.250 SP.DTE -999.250 SPO.DTE GR.OTE -999.250 TENS.DSI -999°250 HTEN.DSI -999.250 MTEM.DSI MRES.DSI -999.250 MCAL.DSI -999.250 HOIA.OSI -ggg.z50 PRoDSI DTRZ.OSI -999.250 DTMZ.DSI -999.250 DT4P.DSI -99g.zsO DT4S.DSI -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 .IS TAPE VERIFICATION LISTING 1T-MAR-1992 18:17 PAGE: ~CHLUMBERGER ALASKA COMPUTING CENTER GR.OSI -999.250 TENS.MLT -999.250 HTEN.NLT -999.250 MTE~.MLT -999,,,250 HRES.MLT -999.250 MCAL.HLT -999.250 HDIA.MLT -999.250 GR.MLT -999.250 TENS.CNT 3740.000 HTEN.CNT -252.50:0 MR'ES.CNT -0.02~ MTEM.CNT 84.688 TNRA.CNT 1.551 RTNR.CNT 1.627 RCFT.CNT 3275.802 RCNT.CNT 5406.914 CFTC.CNT 3667.060 CNTC.CNT 5628.080 TNPH.CNT ~2.809 NPHI.CNT ~7.576 GR.CNT 49.688 TENS.LOT 3'740.000 HTEN.LOT -252.500 MRES.LDT MTEM.LDT ~4.688 C~LZ.LDT 2.760 LL.LDT ~47.250 LU.LOT 292.250 LS.LDT 293.500 LITH.LOT 3~.t72 SSI.'LOT 2~Z.~25 SSI.LOT 258.500 LSHV.LDT t848.000 SSHV.LDT ~627.000 QLS.LOT -0.083 QSS.LDT PEF.LDT 6.64~ RH~B.LDT 2.387 DRHO.LD'T 0.049 DPHI.LOT ~5 GR.LD'T 49.688 TENS.EPT 3740.000 HTEN. EPT -252.500 MRES.EPT MTEM. EPT 84.688 NVR.EPT 3.289 FVR.EPT 0.243 GR.EPT ~9.688 DEPT. 11500.000 MCAL.DTE -999.250 HDIA.DTE 9.565 TENS.OTE 7240.000 HTEN.OTE 1359.313 IDQFoDTE 0.000 IMQF-OTE 0.000 NTEM. OTE 181.986 NRES.OTE -0.033 IZRD.DTE &0.254 [IXO*DTE 8.919 IIRM. OTE 47.832 IIXM. DTE 6.965 IDPH.DTE 25.121 [MPH. OTE 22.217 ILD.DTE 22.601 [LM-OTE 19.861 SFLU.OTE 28.866 SP.DTE 0.125 SPO.DTE 231.956 GR.OTE 10.58'6 TENS.DS[ 7240.000 HTEN. OS[ 1359.313 NTE)t. OS[ 181.986 MRES.D$I -0.033 MeAL.DS! -999.250 HDIA.DS[ 9.565 PR.OSi 0.298 DTRZ.DSI 134.668 OTM2oDS! 132.365 OT4P'DS[ 71.023 DT4S.DSI 131.508 GR.OSI 10.586 TENS.MLT 7240.0'00 HTEN.flLT 1359.313 )ITEN. NLT 181.986 MRES.NLT -0.033 MCAL.MLT -999.250 HOIA.MLT 9.565 GR.)ILT 10.586 TENS.CNT 6795.000 HTEN.CNT 755.500 MRES..CNT -0.024 MTEH-CNT 84.688 TNRA.CNT 1.747 RTNR.CNT 1.758 RCFT.CNT 2391.000 RCNT.CNT 4142.502 CFTC.CNT 2698. 587 CNTC. CNT 4410o 212 TNpH. CNT 13',975 N'PHI.CNT' 14.590 GR.CNT 46.375 TENS.LOT 6795.000 HTENoLOT 755.500 ~RES.L:DT -0.024 MTEt4.LDT 84.688 CALIoLDT 8.930 LL.LDT 117.688 'LU.LDT 224.,500 LSoLDT 229.875 LITH.LDT 37.063 SS1.LOT 204.375 SSI.LOT 25&.625 LSHV.LDT 1849.000 SSHV.LOT 1627.000. QLS.LDT -0.024 C~SS.LDT 0.045 PEF.LDT 8.969 RHOB.LDT 2.560 DRHO.LDT 0.059 DPHI.LDT 5.452 GR.LDT 46.375 TENS.EPT 6795.000 HTEN.EPT 755.500 MRES.EPT -0.024 MTEM.EP'T 84.688 NVR.EPT 3.285 FVR. EPT 0.243 GR.EPT 46.375 DEPT. 11400.000 HCAL.DTE -999.250 HDIA.OTE 9.965 TENS.DTE 7055.000 HTEN.OTE 1388.092 IOQF.DTE 0.000 IMQF.DTE 0.000 MTEM. DTE 181.747 MRES.OTE -0.032 IIRD.DTE 29o158 ItXDoDTE 5..268 IIR)I.DTE 38.853 IIXM.OTE -20.275 IDPH.DTE 33.010 If~PH. DTE 23.463 ILD.DTE 31.581 ILM.DTE 24.467 SFLU.DTE 31.284 SP.DTE 0.188 SPD.DTE 302.652 GR.OTE 23.762 TENS.DS[ 7055.000 HTEN.OS! 1388.092 MTE)I.OS! 181.747 MRES.DSI -0.032 ~CAL.DS! -999.250 HDIA.DSI 9.965 PR.OSI 0.259 DTR2.DSI 102.819 OTMZ.DSI 101.133 OT4P.DSI 57.702 DT4S.OSI 108.640 GR.OSI 23.762 TENS.I~LT 7055.000 HTEN.MLT 1388.092 MTE)I.MLT 181.747 MRES.HLT -0.032 MCAL.MLT -999.250 HDIA.MLT 9.965 GR.MLT 23.762 TENS.CNT 6445.000 HTEN.CNT 710.000 MRES.CNT -0.024 MTEM.CNT 84.688 TNRAoCNT 1.743 RTNR.CNT 1.797 RCFT.CNT 2517.226 RCNT.CNT 4702.563 CFTC.CNT 2846.850 CNTC.CNT 4952.943 TNPH.CNT 15.301 NPHI.CNT 14.132 GR.CNT 31.656 TENS.LOT 6445.000 HTEN.LDT 710.000 )IRES.LOT -0.02~ MTEM.LOT 84.688 CALI.LOT 9.242 LL.LOT 101.313 LU.LDT 197.750 LS.LOT 200.125 L[TH.LDT 33.719 SS1.LOT 192.500 SSI.LOT 247.875 LSHV.LOT 1850.000 SSHV.LDT 1628.000 QLS.LDT -0.021 QS S.LI:)T 0.008 PEF. LDT 6.852 RHOB.LOT 2.623 DRHO.LDT 0.033 DPHI.LOT 1.629 GR.LDT 31.656 TENS.EPT 6445.000 HTEN.EPT 710.000 MRES.EPT -0.024 MTEM. EPT 84.688 NVR.EPT 3.291 FVR. EPT 0.249 GR.EPT 31.656 .IS TAPE YERIFICATION LISTING gCHLUMBERGER ALASKA COMPUTING CENTER 17-MAR-1992 18:17 PAGE: DEPT. 11300.000 MCAL.DTE HTEN.DTE 1362.865 IOQF.D'TE MRESoOTE --0.032 IIRD.OTE IIXM.OTE -I2.687 IDPH.DTE ILM. OTE 37.486 SFLU.OTE GR.DTE 40. 149 'TENS.OSI MRES.OSI -0.032 MCAL.DSI DTR2.OS! 108.039 OTMZ.DS! GR.OSI ¢0.149 TENS.MLT MRES.MLT -0.032 MCALoMLT TENS.CNT 6515.000 HTEN.CNT TNRA.CNT 1.385 RTNR.CNT CFTC..CNT 4643.149 CNTC.CNT GR.CNT 46.188 TENS.LOT M'TEM.LOT 84.625 CALI.LDT LS.LOT 207° 000 LITH.LOT LSH¥.LOT 1850.000 SSHV.LOT PEF.LOT 4.410 RHOB.LDT :GR.LDT ~6.188 TENS.EPT MTEM.EPT 84.625 NVR.EPT DEPT. 11200.000 MCAL.DTE HTEN. OTE 1346.543 IDQF.DTE MRES.DTE -0.032 IIRD.DTE IIXM. OTE -10.448 IOPH.OTE ILM. DTE 40.357 SFLU.OTE GR.OTE 37.673 TENS.OSI MRES.OSI -0.032 MCAL.OSI OTR2-OSI 1%9. 837 OTM2.OSI GR.OSI 37.673 TENS.MLT MRES.MLT -0.032 MCAL.MLT TENS.CNT 6530. 000 MT EN.CNT TNRA.CNT ~.30~ RTNR.CNT CFTC.CNT 5387.%~Z CNTC.CNT GR.CNT 35.~38 TENS.LOT MTEM.LOT 8~.500 CALI.LOT LS.LOT 216.625 LITM.LOT LSHV.LDT 18~9.000 SSHV.LOT PEF.LDT 3.3&~ RHOB.LOT GR.LDT 35.a38 TENS.EPT MTEM.EPT 84. 500 NVR. EPT DEPT. 11100.000 MCAL.OTE HTEN.DTE 1367.279 [DQF.DTE MRES.OTE -0.033 IIRD.OTE IIXM.OTE -10.500 IDPH.OTE ILM.DTE 21.076 SFLU.OTE GR.OTE 60.871 TENS.DSI MRES.DSI -0.033 MCAL.DS! DTRZ.D$I 122.279 OTM2.DSI GR.DSI 40.871 TENS.MLT MRES. NLT -0.033 MCAL.MLT TENS.CNT 6355.000 HTEN.CNT TNRA.CNT 1.504 RTNR.CNT -999.250 HDIA.DTE 0.000 IMQF.OTE 16.452 IIXD.OTE 57. 564 IMPH. DYE 50.982 SP-DTE 7085.000 HTENoOS[ -999.250 HDIA.DS! 104.798 DT4P.DS! 7085.000 HTEN.MLT -999.250 HDIA.MLT 705.500 MRES.CNT 1.554 RCFT.CNT 6156.475 TNPH-CNT 6515.000 HTEN.LOT 9.789 LL.LDT 40o 531 SS1.LOT 1629.000 QLS.LOT 2.583 DRHO.LDT 6515o0'00 flTEN.EPT 3.287 FVR.EPT -999..250 HD[AoDTE 0.000 IMQF.OTE 14.595 I[XD. OTE 67.912 IMPH. D'TE 58. 011 SP.DTE 7395.000 HTENoDS! -999.250 HDIA.DSI 118.483 DT4P.OSI 7395.000 HTEN. MLT -999,.250 HDIA.NLT '717.500 MRES.CNT 1.360 RCFT.CNT 6970,910 TNPH.CNT 6530.000 HTEN.LDT 8.414 LL.LDT 54.531 SS1.LOT 1629.000 QLS.LDT 2.552 DRHO.LDT 6530.000 HTEN.EPT 3.293 FVR.EPT -999.250 HDIA.OTE 0.000 [MQF.OTE 25.628 IIXD.DTE 34°833 TMPH.DTE 33o061 SP.DTE 7285.000 HTEN.DST -999.250 HDIA.DS! 120.384 OT4P.OSI 7285.000 HTEN. MLT -999.250 HDIA.MLT 707.500 MRES.CNT 1.510 RCFT.CNT 10. 604 0.000 3.251 38.184 0.313 1362.865 10.604 64.249 1362.865 10. 60'~ -0.024 4211.772 9.081 705.500 105,750 186-125 -0.010 0.008 70 5.500 0.243 8. 950 0.000 2.959 40.141 0.375 1346.543 8.950 67.266 1346.543 8.950 -0.024 4709.758 9.369 717-500 113.125 181.500 0.022 -0.003 717.500 0.247 9.600 0.000 4.684 24.170 0.563 1367.279 9.600 69-906 1367.279 9.600 -0.024 2872.254 TEN$.DTE MTEM.DTE iIRM.OTE ILD.DTE SPD.DTE MTEM.DSI PR.DSI DT4S.OSI NTEN.NLT G R. ML 'T MTEM.CNT RCNT.CNT NPHI.CNT MR E $. LOT LU.LDT SS2.LOT QSS.LDT OPHIoLOT MRES.EPT G'R.EPT TENS.DTE MTEM.DTE IIRM.OTE ILD.DTE SPO.DTE MTEN. DS! PR.DSI DT4S.DS! MTEM. MLT G R. MLT MTEM.CNT RCNT.CNT NPHI.CNT MRES.LDT LU.LDT SS2.LDT QSS.LOT DPHI.LOT MRES.EPT GR.EPT TENS.DTE MTEM.DTE IIRN.DTE ILO.DTE SPD.DTE PR.DSI DT4S.DS! MTEN.MLT GR.MLT MTEM.CNT RCNT.CNT 7085.000 182.204 25.384 55.724 0.199 103.350 182.204 40.1¢9 84.625 5730. 546 8.106 -0.024 202.500 247.750 -0.012 4.052 -0.024 ~,6.188 7395.000 181.921 Z 3.581 62. 877 2¢1.334 181.921 0 262 1 o 9: s4 4 181.921 37 °673 84. 500 6550.100 8.538 -0.024 206.875 247.375 -0.026 5.933 -0.024 35.438 7285.000 181.205 45.083 34.027 197.590 181.205 0.246 116.724 181.205 40.871 84.125 5713.361 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 17-MAR-1992 18:17 PAGE: 10 CFTC.CNT 3493.500 CNTC.CNT GRoCNT 60.28! TENS.LOT MTEM.LDT 86.125 CALI.LOT LS.LOT 219.125 LITH.LDT LSH¥.LDT 1869. 000 $SHV.LOT PEF.LDT 3.346 ~HOB.LOT 'GR. LD,T 60° 281 TEN'S o EPT MTEM. EPT 84. !25 'NVR.EPT DEPT. 11000.000 MCAL.OTE HTEN. DTE 1392.208 IDQF.OTE MRES.DTE -0.033 IIRD.DTE IIX'M.'OTE -18.769 IOPH.OTE ILM. OTE 7.089 SFLU.OTE GR'OTE 47.934 TENS.DS,! MRES.O$I -0.033 MCAL..DSI DTR2.DSI 152.t83 DTM2.OSI GRoOSI 67.93.4 TENS.MLT MRES.NLT -0.033 MCAL.MLT TENS.CNT 7910.000 HTEN.CNT TNRA.CNT 3.142 RTNR.CNT CFTC.CNT 850.896 CflTC.CNT G:R.CNT 51.313 TENS.LOT MTEHoLDT 83.563 CALI.LOT LS.LDT 275. 500 LITH.LOT LSH¥.LDT 1848.000 SSHV-LOT PEF.'LOT 18.109 RHOB.LOT GR..LOT 51.313 TENSoEPT MTEN.EPT 83. 563 NVRoEPT DEPT. 10900.000 MC~L.OTE HTEN. DTE 1388.888 IDQF.DTE MRES.OTE -0.033 IIRO.DTE IIXM.OTE -16.660 IDPH.DTE ILM. DTE 8.566 SFLU.DTE GR.OTE 69.038 TENS.DS! MRES.O$I -0.033 MCAL.DS! DTR2.0SI 168.676 DTMZ.O$I GR.OS! 69.038 TENS.MLT MRES.MLT -0.033 flCAL.MLT TENS.CNT 6975.000 HTEN.CNT TNRA.CNT 2. 526 RTNR.CNT CFTC.CNT 1526.655 CflTC.CNT GRoCNT 50.125 TENS.LDT MTE~I.LDT 83.063 CALI.LDT LS.LOT 272.750 LITH.LOT LSHV.LDT 1869.000 SSHV.LOT PEF.LDT 6.637 RHOB.LDT GR.LDT 50.125 TENS.EPT MTEM. EPT 83. 063 NVR. EPT DEPT. 10800.000 MCAL.OTE HTEN.DTE 1¢01.017 IOQF.DTE MRES.OTE -0.033 IIRD.DTE IIXM. DTE -12.802 IDPH.DTE 5524.960 TNPH.CNT 13.027 NPHI.CNT I0.565 6355. 000 HTEN.LDT 707.500 NRES.LDT -0.014 9.262 LL.LDT 116.638 L,U.LDT 209.375 55.938 SS1.LDT 189.500 SS2.LDT 250.375 1628. 000 QLS.LOT 0.020 QSS.LOT -0. 003 2. 560 DRHO.LDT 0.012 DPHIoLDT 5.435 6355.000 HTEN. EPT 707.500 M.RES. EPT -0.016 3.285 FVRoEPT 0..244 GR.EPT 40.281 -999.25.0 HOZA.DTE 11.357 TENS.DTE 7205.000 0o000 IMOF.OTE 0.000 MTEM. OTE 180.229 125.227 IIXO. DTE 12.011 IIRM. OTE 133.186 6.908 IMPH:.OTE 6.958 ILD.DTE 6.927 6.957 SP.DTE 0.525 SPO.DTE 250.834 7205.000 HTEN. DS! 1391. Z08 NTEM. DSI 180.229 -999.250 HOIA. O$! 11.357 PR.OS! 0.271 145.426 OTGP-DS! 81.480 DT4S.DS! 107.171 7205o000 HTEN.MLT 1392.208 RTEN. HLT 180.229 -999.250 HDIA.MLT 11.357 GR. NLT 47.936 830.000 NRES.CNT -0.025 MTEN.CNT 83.563 3.333 RCF'T.CNT 736.089 RCNT.CNT 2661.9,87 2658.066 TNPH.CNT 35.184 NPttI.C,NT 33.329 7910.000 HTEN.LOT 83'0.000 MRES.LDT -0.025 10.773 LL-LDT 139..000 LU.LDT 273.000 41.875 SS1.LOT 207.750 SS2.LOT 263.000 1628.000 OLS,'LOT -0.069 QSS.LDT 0.052 2.433 DRHO.LDT 0.064 DPHI'LD'T 13.133 7910.000 HTEN.EPT 830.000 MRES.EPT -0.025 3.289 FVR.EPT 0.Z43 GR.EPT 51o313 -999.250 HDIA.DTE 11.176 TENS.DTE 6930.000 0.000 IHQF.OTE 0.000 MTEM.DTE 179.233 74.606 [IXD. DTE 5.410 [[RM.OTE 110.399 12.213 I~PH-DTE 8.695 ILD.DTE 11.866 6.016 SP.DTE 0.813 SPD.DTE 239.582 6930.000 HTEN.DS! 1388.888 MTEMoOS! 179.233 -999.250 HOIA. OS! 11.176 PR.DS! 0.306 161.063 DT4P.DS! 85-143 DT4S.DS! 116.250 6930.000 HTEN.MLT 1388.888 MTEN.#LT 179.233 -999.250 HOIA.MLT 11.176 GR.NLT 69.038 773.500 MRES.CNT -0.025 MTEM.CNT 83.063 2.705 RCFT. CNT 1161.400 RCNT.CNT 3077.338 4141.277 TNPH.CNT 28.999 NPHZ.CNT 24.619 6975.000 HTEN.LDT 773.500 NRES.LDT -0.025 10.438 LL.LDT 142.750 LU.LDT 259.750 60.031 SS1.LDT 189.250 SS2.LDT 261.250 1628.000 GLS.LDT -0.010 QSS.LDT -0.014 2.605 DRHOoLDT -0.006 DPHI.LDT 14.866 6975.000 HTEN. EPT 773.500 MRES.EPT -0.025 3.295 FVR.EPT 0-256 GR.EPT 50.125 -999,.250 HOIA.DTE 13.093 TENS.OTE 6985.000 0.000 IMQF.OTE 0.000 MTEM.DTE 178.347 47.713 IIXD. DTE 6.460 IIRM.DTE ¢9.965 20.397 IMPHoDTE 20.140 ILD.DTE 18.846 .IS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER DEPT. I0700.000 MCAL.OTE HTEN.OTE 1373.0&Z 1DQF.DTE NRES.DTE -0.033 IIRO.OTE IIXM. DTE -18.251 IOPHoDTE ILM. DT;E t4. 575 SFL:U. OTE GR.DTE 37.908 TENS.DS[ MRES.OSI -0.033 MCALoDS! DTRZ..DSI 213.19B OTM2.OSI GR.OSI 37.908 TENS.NLT HRES.RLT -0,.033 NC~L.MLT TENS.CNT 6900.000 HTEN.CNT TNRA.CNT 3.524 RTNR.CNT CFTC.CNT 681.159 CNTC.CNT GR.CNT 38. 500 TENS.LOT MTEH...LDT 81.938 CAL[,,LDT LSoLDT 312.500 L[TH.LOT LSHV.LOT 1843.000 SSHV.LOT PEFoLDT 5.938 RHOB.LOT GR.LDT 38.500 TENS.EPT NTEfl. EP*T 81.938 NVR.EPT DEPT. 10600.000 NCAL.DTE HTEN.DTE la06.294, [DQF.DTE MRES.DTE -0.033 I/RDoDTE IIXM.DTE -10. 843 ZOPH.DTE ILM. DTE ZO.Z37 SFLU.OTE GR.OTE 84.94,3 TENS.DSI MRES.OSI -0.033 MCAL.OSI DTRZoDSI 112.981 DTM2.DSI GR-OSI 84.943 TENS.#LT MRESoMLT -0.033 NCAL.MLT TENS.CNT 6835.000 HTEN.CNT TNRA.CNT 2.266 RTNR.CNT CFTC.CNT 1729.641 CNTC.CNT GR.CNT 82.938 TENS.LDT MTEM.LDT 81.750 CALl.LOT LS.LOT [99.250 L[TH.LDT LSHV.LDT 184,8.000 SSHV.LDT 17-MAR-1992 18:17 21.010 SP.OTE 6985. 000 HTEN.OSI -999.250 HOIA.DSI 110.867 DT4P.DSI 6985. 000 HTEN.MLT -999.250 HD:IA.NLT 727. 000 MRES.CNT 1.928 RCFT.CNT 514,3.726 TNPH.CNT 7000.000 HTEN. LOT 12.383 LL.LOT 38.875 SSI.LOT 1627.000 QLS.LDT 2.54,3 DRHO. LDT 7000.000 HTEN.EPT 3.305 FVR.EPT -999.250 ftDIA.OTE 0.000 IMQF.OTE 22. 287 IMPH.DTE 29'387 SP. DTE 6850.000 HTEN.OS! -999.Z50 NDIA.DS! ZOO. 534 DT4P.DS[ 68:50.,000 HTEN.MLT -999.250 HOIA.WLT 767.500 NRESoCNT 3.96¢ RCFToCNT 2446.345 TNPH.CNT 6900.000 HTEN.LDT 12.617 LL.LOT 56.813 SS1.LDT 1626o000 QLS.LDT 2.321 DRHO.LOT 6900.000 HTEN. EPT 3.307 FVR.EPT -999. 250 HDIA.DTE 0.000 [MQF.OTE 37.913 IIXD. DTE 25.261 IMPH.DTE 25.341 SP.OTE 6835.000 HTEN.OSI -999.Z50 HOIA.OS[ 107. 581 OT4P.DS[ 6835.000 HTEN.MLT -999.250 HD[A.NLT 729.000 MRES.CNT 2.401 RCFT.CNT 3995.591 TNPH.CNT 6835. 000 HTEN.LOT 10.344 LL.LDT 31.047 SS1.LDT 1627.000 QLS.LOT 0.875 1401.017 13.093 58.837 14,01.017 13.093 -0.025 2508.801 14.568 727.000 112-750 191.625 -0.02.3 0.014 727.000 OD Z5.3 13.459 0.000 3. 211 16.392 0.875 1373.042 13.459 89.540 1:373-04Z 13"'459 -O.OZ5 630.Z97 41.560 767'500 165.875 196. Z50 -0.004 0.000 767.500 0.258 11.314 0.000 2.873 Z0.443 0.875 1406.Z94 11.314 64.228 1406.Z94 11.314, -0.025 1507.448 22.963 729.000 101.750 192.375 -0.004 SPD.DTE MTEN.DSI PR.OSI DT4S.DSI MTEN.CNT ECNT.CNT N PHI. CNT HRE $.LDT LU.LOT SSZ.LDT QSS.LDT DPHIoLDT MRES.EPT GR.EPT TENS.DTE ILD.OTE SPD.OTE MTEM.OSI P R - D $ I D T 4, S. D S I NTEN.~ILT GR,..MLT NTEN.CNT RC#T.CNT NPN I. CNT MRES.LOT LU. LOT SSZ.LOT QSS.LOT OPHI.LOT MRES.EPT GR.EPT TENS.DTE WTEH.OTE [LD.DTE SPO.OTE NTEN.OSI PR.DS[ DT4S.DS! ~TEM.~LT GR.NLT #TEM. CNT RCNT.CNT NPHT.CNT MRES.LOT LU.LDT SS2.LOT QSS.LDT PAGE: 241olS0 178.347 0.304 95.540 178.347 49.895 82.500 4992°694 12.616 -O.OZ5 216.375 256.000 -0.008 6.498 -0.025 48.594 6850.000 177.~18 65.099 20.738 267.622 177.4,18 0.375 1Z0'0¢4 177.418 37.908 81.938 Z540.181 39.435 -0.025 293.500 289.500 -0.050 19.913 -0.025 38.500 6835.000 177.571 46.947 23.738 234,.4,17 177.571 0.223 112.a08 177.571 84.943 81.750 3901.775 20.640 -0.025 195.000 246.875 0.011 .IS TAPE VERIFICATION LISTING ~CH'LUMSERGER ALASKA COMPUTING CENTER 1T-MAR-1992 18:17 PAGE: 12: PEF.LOT 8.219 RHOB.LDT GR.LDT 82.938 TENS.EPT MTEM.EPT 81.750 NVR.EPT DEPT. 10500.000 MCAL.DTE HTEN. OTE 1389.75.! IOQF.OTE MRES.OTE -0.033 tIRD.DTE IIXM. OTE -9.382 IOPH.OTE ILM.DTE 8.462 SFLU.OTE GR.OTE 54.745 TENS.DSI MRES.OSI -0.033 MCAL.OSI DTR2.OSI ~45.857 OTM2.0SI GR.OS~ 5&.T&5 TENS.MLT MRES.MLT -0-033 MCAL,MLT 'TENS.CNT 7365.000 HTEN.CNT TNRA.CNT 2.73~ RTNR.CNT CFTC.CNT 1239.080 CNTC.CNT GR.CNT 5:g. S9& TENS.LOT MTEM.LDT 8~.250, CALI.LOT LS.LDT 233.87'5 L~TH,LOT L'SHV.LDT ~8~6.000 SSMV.LDT 'PEF.LDT 7.770 ~HOB.LOT GR.LDT 5g.$g& TENS.EPT MTEM. EPT 8~.250 NVR.EPT OEPT. 10400.000 MCRL.OTE HTEN.DTE 1423.201 IOQF.OTE MRES.OTE -0.034 IIRD.DTE IIXM.OTE -10.792 IOPH.OTE ILM. OTE 7.276 SFLU. OTE GR.OTE 44.893 TENS.OSI MRES.OSI -0L034 MCAL.DSI DTRZ.O$I 159.767 DTM2.OSI GR.OSI 44. 893 TENS.MLT MRES.MLT -0.034 MCAL.NLT TENS.CNT 7265.000 HTEN.CNT TNRA.CNT 3. 293 RTNR.CNT CFTC.CNT 784. 551 CNTC.CNT GR.CNT 47.250 TENS.LOT MTEM.LDT 80.875 CaLI.LOT LS.-LDT 287.250 LITM.LOT LSHV.LOT 1844.000 SSHV.LOT PEF.LDT 8.547 RHOB.LOT GR.LOT 47.250 TENS.EPT MTEM.EPT 80. 875 NVR.EPT DEPT. 10300.000 MCAL.DTE HTEN. OTE 1357.705 IOQF.OTE NRES.DTE -0.034 IIRD.OTE IIXMoDTE -11.306 IOPH.DTE ILM.OTE 14.424 SFLU.OTE GR.DTE 72.778 TENS.OSI MRES.DSI -0.034 MCAL.DSI DTRZ.OSI 131.169 DTM2.DSI GR.DSI 72.778 TENS.MLT 2.622 DRHO.LOT 6835.000 HTEN.EPT 3.309 FVR.EPT -999.250 HDIA.DTE 0.000 IMQF.DTE 94.7¢8 IIXD.DTE 9.474 IMPH.OTE 8.452 SP.OTE 6730.000 HTEN,OS! -999.250 HDIA.DSI 13'7.660 OT4P'OSI 6730.000 HTEN. MLT -999.250 HDIA.MLT 737,.000 MRES:,CNT 2.886 RCFT.'CNT 3268.728 TNPH. CNT 7365,,000 HTEN. LDT 11.352 LL.LOT 35.656 :SSt. LOT 1626.000 QLS.LOT 2.511 DRHO'LOT 7365.000 HTEN.EPT 3.305 FVR. EPT 999' 250- HDIA.DTE · 0.000 ~MQF. DYE 106.602 IIXD. DTE 8.295 IMPH. OTE 7.466 SP.DTE 6635.000 HTEN. DSI -999.250 HOIA.OSI 148.487 DT4P.DSI 6635.000 HTEN.NLT -999.250 HOIA.MLT 842. 500 NRES.CNT 3.548 RCFT.CNT 2597.498 TNPH. CNT 7265.000 HTEN.LDT 12. 773 LL.LDT 38.688 SS1.LOT 1626.000 QLS.LOT 2.364 ORHO.LDT 7265.000 HTEN.EPT 3.305 FVR. EPT -999.250 HDIA.DTE 0.000 IMQF.OTE 50.502 IIXD.DTE 17.910 IMPH.DTE 15.865 SPoDTE 6610.000 HTENoDS! -999.250 HDIA.DSI 113.855 OT4P.DSI 6610.000 HTEN.MLT 0.032 729.000 0.258 11.941 0.000 7.415 8.668 1.000 138 9.761 11.941 73'309 1389-761 -0.025 1177.8'28 27.274 737.000 12'1'688 196.500 ~0.002 0.022 737.000 0.257 13.178 0.000 6.569 7.615 1.000 1423.201 13.178 79.311 1423.Z01 13.178 -0.025 727.628 36.914 842.500 148.750 196.625 -0.034 0.004 842.500 0.254 14.027 0.000 3.786 14.930 1.063 1357.705 14.027 65.807 1357. T05 DPHI.LDT MRES.EPT GR.EPT TEN$.OTE MTEM. DTE IIRM. DTE, ILO.DYE SPD.DTE MTEM. OSI PR-DSI DT4S.OSI MTEM.MLT G R - ML 'T MTEM.CNT RCNT.CNT NPHI.CNT MRES.L:DT LU.LOT SSZ.LOT QSS.LOT OPHi.LOT ,MRES.EPT GR.EPT TENSoDTE NTEH. DTE IIRM.OTE ILO.OTE SPO.OTE MTEM.DSI PR.OSI DT4S.OSI MTER. MLT GR. MLT MTEM. CNT RCNT.CNT NPHI.CNT MRES.LDT LUoLOT SSZ.LDT S. LDT MRES.EPT GR.EPT TENS.DYE MTEM.DTE I'IRM.OTE ILD.DTE SPD. DTE MTEM.DSI PR.DSI OTaS.OSI MTEMoMLT 1.689 -0.025 82.938 6730.000 176.472 111.742 9.316 238,813 176.472 0.302 116.430 176,472 54.745 81.250 3482.810 26.924 -0.025 224..25:0 258.750 0.008 8.436 -0.025 59.594 6635.000 176.040 129.785 8.215 314.131 176.~040 0.300 105.667 176.040 44.893 80.875 2477.383 35.127 -0.025 277.000 266.750 0.006 17.330 -0.025 47.250 6610.000 175.483 65.775 17.548 248.847 175.483 0.249 118.739 175.483 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER MRES.MLT -0.03& MCAL.HLT TENS.C,NT 6885.000 HTEN.CNT TNRA.CNT 2:.724 t~TNR.CNT CFTC.CNT [196.016 CNTC.CNT GR.CNT 77.375 TENS.LOT MTEMoLDT 80.563 CaLl. LOT LS.iLOT 191. 500 LITH.LDT LSHV.LDT 1846.00.0 SSHV.LOT PEF.LOT 5.988 RHOS.LOT GR.LDT 77.3'75 TENS.EPT ~TEfl. EPT 80. 563 NVR. EPT DEPT. 10200.000 MCAL.OTE H'TENoDTE 131T.603 IOQF.OTE MRES.O'TE -0.034 I[RO.OTE TIXM. OTE -6.781 [DPH.OTE [LN. OTE 9.938 SFLU.DTE G:R.OTE 29.87! TENS.DS[ MRESoOS[ -0.034 MCAL.05[ OTR2-OS[ [55.292 'GR'OS[ 29,871 TENS-MLT MRES.MLT -0.03~ MCAL.NLT TENS.CNT 6~25.000 HTEN.CNT TNRa. CNT 3.63[ RTNR.CNT CFTC-CNT 582.539 CNTC.CNT GR.CNT 3&.78[ TENS.LOT MTEM'.LOT 79.938 CaLl. LOT LS.LDT 259.000 L~TH.LOT :L SHV.LOT [8~3.000 SSHV.LOT PEF.LOT 6.~5 RHOB.LDT GR.LDT 3~.78[ TENS.EPT MTEM. EPT 79. 938 NVR.EPT DEPT. 10100.000 MCAL.OTE HTEN.DTE 1353.518 IDQF.DTE MRES. OTE -0.03¢ IIXM. OTE -31. 262 [DPH.DTE ILM.DTE 238.725 SFLU.OTE GR.DTE 44.741 TENS.DS[ MRESoOSI -0.034 MCAL.OSI DTR2.0ST 114.158 DTM2.0S[ GR.DS[ 44.T41 TENS.MLT MRES.NLT -0.034 MCAL.MLT TENS.CNT 6180.000 HTEN.CNT TNRA.CNT 4.033 RTNR.CNT CFTC.CNT 463.744 CNTC.CNT GR.CNT 52.281 TENS.LDT MTEM.LDT 79.313 CALI.LDT LS.LDT 529.500 LTTH. LOT LSHV.LOT 1836.000 SSHV.LDT PEF.LDT 53,531 RHOB.LOT GR.LDT 52.281 TENS.EPT HTEM. EPT 79.313 NVR.EPT 17-~AR-1992 18:17 -999.250 HDIA.MLT 735.500 MRES.CNT 2-921 RCFT.CNT 3195.224 TNPH.CNT 6885.000 HTEN.LOT 14°336 LL.LOT 30.516 SS1.LOT 1625'000 QLS.LDT 2.681 DRHO.LDT 6885.000 HTEN.EPT 3.297 FVR.EPT -999.250 HOXA.OTE 0.000 [MQF.DTE 60.603 [[XD. DTE 14.958 IMPH. OTE 12. 552 SP.DTE 6370.000 HTEN. DS[ -999.250 HD~A.DSI l~l.191 OT4P.OSI 63T0.000 HTEN.MLT -999.250 HDIA.MLT 659.500 MRES.CNT 3. 949 RCFT.CNT 2036. 706 TNPH.CNT 6425.000 HTEN'LOT 18,922 LL.LOT 38o781 SS1.LOT 1 624.000 QLS.:L OT 2.428 ORHO.LOT 6415. 000 HTEN.EPT 3.301 FVR.EPT -999,250 HD[A.OTE 0.000 [MQF.OTE 19,571 [[XD.DTE 52.749 INPH.DTE 45.799 SP.DTE 6220.000 HTEN.DS[ -999.250 HDIA. DS[ 90.164 DT4P.DS[ 6220.000 HTEN.MLT -999.250 HDZA.#LT 588.000 WIRES.CNT 4,.281 RCFToCNT 1887o508 TNPH.CNT 6180.000 HTEN.LDT 22.063 LL.LOT 49.750 SS1.LOT 1625.000 QLS.LDT 1.883 DRHOoLDT 6180.000 HTEN.EPT 3.303 FVR.EPT 14.027 -0.02'5 1071.143 2 6.091 73 S. 500 95.375 198,125 -0.040 0.064 73 5. 500 0.253 18,911 o:ooo 1 727 10.946 -0,125 1317..603 18.911 63-275 1317.603 18.911 -0.025 544.770 36,955 65 9. SO0 133.875 192.250 -0.025 0.003 659.500 0.251 0.000 -1.533 500005 1353.518 20.402 81.307 1353.518 20,402 -0.026 411.256 45.571 588.000 256.000 183,125 -0.128 -0.119 588.000 0.253 GR.MLT ftTER.CNT RCNT.CNT NPHZ.CNT HRES.LDT LU-LDT SSZ.LDT ~SS.LDT D PH !. LDT M'RE.S.EPT GR.EPT TENS.OTE HTEN;,DT E ZIRlq.DTE ILO.DTE SPO.DTE ~TEM. DSI PR.OS[ DT4S.DSI MTEMoNLT GR.NLT MTEN.CNT RCNT.CNT NPH[.CNT MRES.LOT LUoLOT SS2.LOT QS S. LOT OPH[.LOT MRES.EPT GR.EPT TENS. DTE MTEM. DT E [[RN.DTE [LO.DTE SPO.OTE NTENoOSI PR.DSI DT~S.DS[ MTEN. NLT GR.#LT NTEM.CNT RCNT.CNT NPH[.CNT NRES.LOT LU.LOT SSZ.LOT QSS.LDT DPHI.LDT MRES.EPT GRoEPT PAGE: 13 72.778 80.563 3041.377 25.635 -0. 025 192.250 250.250 0.015 -I. 878 -0 77 ' 375 6370.000 174'003 95 '266 14. 812 283 .'077 174.003 0.348 85.689 174.003 29.8'71 79.938 1923.071 38.356 -O.OZ5 · 250.500 254.875 O. 014 13.44T -0,025 34.781 6220.000 174,173 3,992 48.525 284,346 174,173 -999.250 110,362 174.173 44.741 79.313 1746.267 44.218 -0.026 547.000 220.000 0,182 46.492 -0.026 52.281 LIS TAPE VERIFICATION LISTZNG SCHLUMBERGER ALASKA COMPUTING CENTER 17-NAR-1992 18:17 P AGE: 14 DEPT. 10000.000 MCAL.DTE HTENoOTE 1517.068 ID~F.OTE MRES. DTE -0.049 IIXM. DTE 12.146 IDPH. DTE '[LMoDTE 17. 595 SFLU.DTE GR.OTE -47.663 TENS.DSI MAES.DS[ -0.0,49 MCAL.OS[ OTR2.DS[ [~7.053 GR.DS[ &7.663 TENS.NLT MRES.~LT -0.0~9 ~CAL.M:LT T'ENS.CNT 63[0.000 HTEN.CNT TNRA.CNT 3.259 RTNR.CNT CFTC.CNT 799.030 CNTC.CNT GR.CNT 16.688 TENS.LOT HTEM.LOT Z68.~50 CaLZ.LOT LS. LOT 2Z0.500 LZTH.LOT LSHV.LDT 1828.000 SSHV.LOT PEF.LDT 3.338 RHOB.LOT GR.LOT 26.688 TENS.EPT MTEMoEPT [68. 350 NVR.EPT DEPT. 9900.000 MCAL.OTE HTEN'OTE 1549.732 IDQF.OTE MR~S.DTE -0.0~9 [ZRD.DTE ~R.OTE 81' TEN~.DSI MAES-DS[ -0.049 MCAL.DS[ DTRZ.DS[ 116.0~8 GR..DS[ 81-286 TENS.MLT MRES.MLT -0.049 MCAL.~LT TENS.CNT 6180.000 HTEN.CNT TNRA.CNT 2.742 RTNR.CNT CFTC.CNT 1021.787 CNTC.CNT GR.CNT 86.250 TENS.LOT MTEM.LOT 168.461 CAL1.LOT LS.LDT 218. 375 LZTH-LOT LSHV.LDT 1829.000 SSHV-LDT PEF.LDT 2.805 RHOB.LOT GR.LOT 86.250 TENS.EPT MTEM. EPT 168.462 NVR. EPT OEPT. 9800.000 MCAL.OTE HTEN. OT~ 1539.742 MRES.OTE -0.0~9 IIXN.DTE I1.147 IOPH.OTE ILM.DTE 1S.9&Z SFLU.DTE GR.DT~ 82.571 T~NS.DSI NR~S.DSI -0.0~9 NCAL.OSI DTR2.OSI 1&1.822 DTM2.DSI GR.DSI 82.571 TENS.MLT MRES.MLT -0.049 MCAL.NLT T~NS.CNT 6085.000 HTEN.CNT TNRR.CNT 3.182 RTNR.CNT 8.052 0..000 45.287 19096I 9. 944 7'615.000 8. 052 139:.362 7615. 000 80052 I060.000 30411 2584.760 6310o000 12.258 60.500 1 612. 000 2. 560 6310.000 3. 334 12.285 O. 00.0 43.085 12,,147 7430.000 120285 120.855 74300000 1Z. 185 1094.000 2.81 273109 ~ 6180.0~0 11.852 590531 1613.000 2.610 6180.o000 3.375 12.434 0o000 51.089 18.495 100671 7510.000 12.434 1360659 7510.000 12.434 1069.000 3.571 HOZA.DTE ZMQF. DTE IZXD. DTE I#PH. DTE SP.DTE HTEN'OSI HDIA. DS! OT4P'OS[ HTENoMLT HD[A.MLT #RESoCNT RCFT,CNT TNPHoCNT HT EN. LOT LL'LDT SSI.LDT QLS.LOT O R H:O:. LOT HTE#. EPT FVR.EPT HOiA.DTE IMQF. D T E ZZXD.DTE [NPHoDTE SP. D TE HT'ENoOS! DT~P-OS! HTEN.RLT HOIA.MLT MRESoCNT RCFT.CNT TN P H. C NT HTEN.LDT LLoLOT SS1.LOT QLS.LOT ORHg. LOT HTEN. EPT FVR.EPT HDIA.DTE ZMQF.DTE IIXD. OTE I#PH.DTE SP.DTE HTEN. DSI HDIA.D$! DT4P.DS! HTEN.MLT HDIA.NLT MRES.CNT RCDT.CNT -9990250 O. 000 0.293 17.813 0.000 1517,,,068 -999.250 690103 1517.068 -999.250 -00039 686.790 35099.7 I 060. 000 114'688 190o:375 O. 009 0.014 1060.000 0.267 -999.0 [SO O'O00 1.474 18.423 -0.125 1549.732 -999o150 63.750 1 54 9. 732 -9990250 -00039 9010349 26.886 1094.000 111.188 2000500 -0.026 O. 057 1094.000 0.305 -9990250 0.000 2.282 16.641 -00125 153 9. 742 -9990150 71.864 1539.742 -999.250 -0.039 737.580 TENS.DTE MTEM. DTE ZLO.DTE SPO.DTE MTEM. DSI pRoDSI DT4S.DSI MTEH.NLT GRoMLT MTENoCNT RCNT.CNT NPHI.CNT MRE ,S. LDT LU.LDT SS2oLOT QSS.LOT DPH[ oLDT MRES.EPT GRoEPT TENS.OTE MTEN.OTE IIRM.DTE ILOoOTE PO.OTE MTE~.DSI PR.DSI DT4SoDS! MTENoNLT GR. NLT MTEM.CNT RCNToCNT NPH~oCNT MRESoLOT LU.LOT SS2.LOT QSS.LOT MRES.EPT GR.EPT TENS.OTE MTEMoDTE IIRW. DTE ILO. DT E SPO.DTE I OT4SoDSI MTEN.MLT GR. tI, ILT IqTEt4.CNT RCNToCNT 7615.000 1613.122 5 3.9 69 19.762 216.006 163.122 0.337 132.472 163. I22 47'.663 168.350 2486o~855 34.760 -0.039 211.750 256.000 -0.015 S.463 -0 °039 26.688 7430.000 163.587 51.088 20.782 153. 644 163.587 0.307 82.378 163.587 81.286 168.662 2562.187 26.488 375 260.500 0.005 2.441 -0.039 86.250 7510.000 163.254 59.538 17.708 210.505 163.254 0.309 141.989 163.254 82.571 168.125 2403.275 .IS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER CFTC.CNT 802.872 CNTCoCNT GR.CNT 91o 750 TENS.LOT MTEM.LDT 168. 125 CALI.LDT LS.LDT 203.125 LITH.LOT LSHV.LDT 1829.000 SSHV.LDT PEF.LDT 3.145 RHOB.LOT GR.LDT 91.750 TENS.EPT MTEMo EPT 168o12,5 NVRoEPT DE:PT. 9700.000 MCAL.DTE HTEN.DTE 1539.005 IDQF.DTE MRES. OTE -0.049 IIRDoDTE IIXM. DTE 6.837 IOPH.DTE ILNoOTE 11.675 SFLU.OTE · GR.DTE 56.086 TENS.DSI MRES.DSI -0.049 MCAL.DS! D'TRZ.DSI 165.836 DTM2.DSI GR:.O$[ 56.086 TENS.MLT MRESoMLT -0.049 MCAL.MLT TENS.CNT 61110°000 HTEN.CNT TNRA.CNT 3.831 RTNR.CNT CFTC.CNT 574.430 CNTC.CNT GR.CNT 63.531 TENS.LOT MTERoLDT 167. 225 CALZoLOT LS.LOT 330.000 L[TH.LDT LSHV.LDT 1827.000 SSHV.LDT PEF.LDT 2. 291 RHOB.LOT GR.LDT 63.53! TENS.EPT NTEM. EPT 167.225 :NVR.EPT DEPT. 9600.000 MCAL.DTE HTEN.DTE 1549.246 IOQF.DTE MRES.OTE -0.049 IIRD.OTE IIXM.DTE 15.296 IDPH.OTE ILM.DTE 19.993 SFLU.OTE GR.OTE 73.051 TENS.DS! MRES.DSI -0.049 MCAL.DSI DTRZ.DSI 141.969 DTM2.OSI GR.DSI 73.051 TENS.MLT MRESoMLT -0.069 MCAL.MLT TENS.CNT 6125.000 HTEN.CNT TNRA.CNT 3.346 RTNR.CNT CFTC.CNT 661.972 CNTC.CNT GR.CNT 81.813 TENS.LOT MTEM.LDT 166.550 CaLI.LDT LS.LDT 272.250 LITH.LOT LSHV.LOT 1825.000 SSHV.LOT PEF.LDT Z. 828 RHOB.LDT GR.LDT 81.813 TENS.EPT MTEM. EPT 166.550 NVR.EPT DEPT. 9500.000 MCAL.DTE HTEN.DTE 1524.359 IDQF.OTE MRES.DTE -0.050 IIRD. DTE IIXM.DTE 12.163 IDPH.DTE 17-MAR-1992 18:17 2474.496 TNPH.CNT 6085.000 HTEN.LDT 12.563 LL.LDT 55. 500 SSI.LOT 1 612.000 O L $ - :L O T 2.60'1 ORHO. LOT 6085°000 HTEN.EPT 3.381 FVR.EPT 13.304 HDIA. OTE 0.000 IMQF.DTE 70.888 IIXD. D'TE 12.551 IMPH.OTE 8°655 SP.DTE 7410.000 HTENoDSI 1:3.304 HDIA.DSI 160.596 DT4P.OSI 7410.000 HTEN.MLT 13.304 HOIA.NLT 1082.0:00 MRES.CNT 4.127 RCF:T.CNT 2092.230 TNPH.CNT 6110o000 HTEN,LDT 13.078 LL.LDT 107.250 ~SSI.LDT 1613.000 QLS.LOT Zo:311 DRHO.LOT 6110.000 HTEN. EPT 3.379 FVR.EPT 13.428 HDIA.DTE 0.000 IMQF.DTE 46.133 IIXO.DTE 20.549 IMPH.DTE 15.345 SP.DTE 7460.000 HTEN.OSI 13.428 HDIA.DSI 136.177 DT4P.DS! 7460.000 HTEN.MLT 13.428 HDIA.NLT 1075.000 #RES.CNT 3.579 RCFT.CNT 2096.839 TNPH.CNT 6125.000 HTEN.LDT 13.596 LL.LDT 88.125 SS1.LDT 1613.000 QLS.LDT 2.483 ORHO.LDT 6125.000 HTEN.EPT 3.393 FVR.EPT 15.358 HDIA.DTE 0.000 IMQF.OTE 68.928 [[XO. OTE 13.484 IMPH.DTE 33.403 1069.000 107.125 181.750 0.052 0.003 1069.000 0.315 -999.250 0.000 2.151 11.241 -0.125 1539.005 -999.250 72.1151 1539.005 -999.250 -0.039 474.148 42.128 1082.000 177.875 197.375 0.017 0.001 1082.000 0.313 -999.250 0.000 2.425 21.08Z -0.188 1549.246 -999.250 66.526 1549.246 -999.250 -0°039 619.664 34.153 1075.000 146.625 209.250 0.040 0.059 1075.000 0.330 -999.250 0.000 3.989 15.765 NPHI .CNT MRES.LDT LU. LOT SS2.LDT QSS.LOT DPlJJ.LOT MRES.EPT GR.EPT TENS.DTE · MTEM. OTE IIRM.DTE ILO. DT E SPO.OTE MTEM.OSI PR. DSI DT~S.DSI MTEMoRLT GR.MLT MTEM.CNT R CNT. CN'T NPH !. C NT MRES.LDT L~..LOT SS .LOT QSS.LDT DPH:[ .LOT MRES.EPT GR.EPT TENS.DTE MT EM. DT E IIRN. OTE ILD.DTE SPD.DTE MTEM. DSI PR.DSI DT4$.DSI NTEM.MLT GR .MLT MTEM.CNT RCNToCNT NPH~oCNT MAES.LOT LU.LOT SS2.LDT QSS .LOT OPlJI.LOT MRES.EPT GR.EPT TENS.OTE MTEM.DTE IIRM.DTE ILO.DTE PAGE: 15 33.208 -0. 039 192.125 246.250 -0.028 2.954 -0.039 91.750 7410.000 162.851 81.176 .583 162.851 0.374 91.906 162.851 56.086 167.225 2008.233 44.833 -0.039 304.000 278.000 -0.014 20.466 -0.039 63.531 7450.000 162.457 47.517 20.351 222.819 162.457 0.343 120.919 162.457 73.051 166.550 2175.972 35.711 -0.039 251.125 276.250 0.012 10.130 -0.039 81.813 7325.000 161.537 66.693 13.319 LIS TAPE YERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING ILM.OTE I4. 225 GRoDT~ 69.555 MRES.DSI -0.050 OTR2.OSI 170.480 GR.OSI 69.555 MRES.MLT -0.050 TENS.CNT 5890.000 TNRA.CNT 3. 200 CFTC.CNT 6TI. 330 GR.CNT 77.8[3 MTEM.LDT 165.313 LS.LDT LSHV.LDT [820.000 PEF.LOT 2.336 GR.LDT 77.813 MTEM. EPT [65. 313 DEPT. 9600°000 HTEN. OTE !567.378 MRES.OTE -0.050 IIXfl. OTE 8° 696 'ILRoOTE 12.603 GR.OTE 86.30¢ MAES.OS[ -0.050 OTRZ.O$I 126.869 GRoOSI 86. 304 MRES.~T -0.050 TENSoCNT 5955.000 TNRA.CNT 2.971 CFTC.CNT 871.531 GR.CNT 96.625 MTEM.LDT 164.750 LS.LDT 282. 500 LSHV.LOT 1826.000 PEF.LDT 2.771 GR.LDT 96.625 MTEM. EPT 164.750 DEPT. 9300,,,000 HTEN.OTE 1565.344 MRES.DTE -0.050 IIXM.DTE 8.111 ILM. DTE 28.765 GR.DTE 86.597 MRESoD$I -0.050 DTR2.DSI 158. 960 GR.DS! 86.597 MRE$.MLT -0.050 TENS.CNT 5755°000 TNRA.CNT 2.631 CFTC.CNT 1101.903 GRoCNT 91.688 MTEM.LOT 164.075 LS.LDT 262.250 LSHV.LOT 1814.000 CENTER 1T-MAR-1992 18:17 SFLU.OTE 13.159 SP.DTE 'TENS.OSI 7325.000 HTEN.DS[ MCAL.DS! 15. 358 HDZA.DSI OTM2.DSI 160.933 DT4P.DSI TENS.NLT 7325.000 HTEN. MLT MC AL.'MLT 15. 358 HOIA,. MLT HTEN.CNT 1062.000 MRES.CNT RTNR .CNT 3.431 RCFT.CNT CNTC.CNT 2250°996 TNPH.CNT TENS.LOT 5.890.000 HTEN. LOT CALI.LDT 16. 516 LL.LDT LITHoLOT 184.500 SS1.LOT SSHV.LOT 1612.000 QLS.LOT RHOB.LDT 2.112 OR,HO.LOT TENS.EPT 5890-000 HTEN. EPT NVR.EPT 3.396 FVR. EPT MCAL.OTE 12.161 HDIA.DTE I D Q F. 0 T E 0.000 I M QF. D T E IIRD.DTE 63- 110 I'IXD. DTE IDPH.DTE 14.001 IHPH. DTE SFLU. DTE 10o 171 SP. DTE 'TENS.DS'I 7260.000 HTEN.DSI MCA!L.DS! 12.161 HDZA.DS! OTM2.DS! 120.380 DT4PoOSI TENS.MLT TZ60. O00~ HTEN. MLT MCAL.NLT 12.161 HOIar. IqLT HTEN.CNT 111'4.00:0 NRES.CNT RTNR.CNT 3.073 RCFT. CNT CNTC.CNT 2512.606 TNPH.CNT TENS.LOT 5955°000 HTEN. LDT CALI.LOT 13.666 LL.LOT LZTH.LOT 88.875 SS1.LDT SSHV.LOT 1613.000 QLS.LOT RHOB.LDT 2.442 ORHO.LDT TENS.EPT 5955.000 HTEN.EPT NVR.EPT 30606 FVR. EPT MCAL.OTE 12.856 HDIA.DTE IDQF.DTE 0.000 !M~F.DTE IIRD.DTE 28.665 IIXD.OTE IDPH.DTE 34. 568 IMPH.DTE SFLU.DTE 24.108 SP.OTE TENS.DS! 7265.000 HTEN. DS! MCAL.DSI 12. 856 HDZA.OS! OTM2.DS! 152.556 DT4P.DSI TENS.MLT 7265.000 HTEN.MLT MCAL.NLT 12.856 HDIA.NLT HTEN.CNT 1061.000 MRES.CNT RTNR.CNT 2.637 RCFT.CNT CNTC.CNT 2890°067 TNPH.CNT TENS.LOT 5755.000 HTEN.LDT CALI.LDT 1Z.866 LL.LDT LITH.LDT 96.750 SS1.LDT SSHVoLDT 1614.000 OLS.LDT -0.188 1526.359 ,-999. 250 82,269 15.26. 359 -999.250 -0.060 592.056 35.636 1062.000 295.750 238. 250 -0.021 0.08I 1062.000 0.329 -999.250 0.000 2.173 12.818 -0.188 1567o378 -999.250 70.334 1567.378 -999.250 -0-040 765.586 29.668 1114.000 150.750 206.250 0.017 0.062 1114.000 0.335 -999.250 0.000 0.635 30.873 0.000 1565.364 -999.250 69.202 1565.344 -999.250 -0.040 1050.488 26.163 1061.000 139.875 192.125 0.027 SPO.DTE MTEM.DSI PR.DS! DTaS.DSI MTEM.MLT GR.MLT MTEMoCNT RCNT.CNT NPHI.CNT MAES.LOT LU. LOT SS2.LDT QSSoLDT ,PHI.LOT MRES.EPT GR'EPT TENS.DTE MTEM.DTE !.IRN. DTE ILD.DTE SPOoDTE MTEM.DSI PR.DSI OT4S.OS! MTEM.MLT GR.MLT MTEN.CNT RCNT.CNT NPHI.CNT MRES.LDT LU.LDT SSZ.LDT QSS.LOT PAGE: 16 193.051 161~ 5~7 s 149.019 161.537 69.555 165.313 2109.591 31.914 -0.060 503.5'00 338.750 0.010 32. 598 -0.0¢0 77.813 7240.000 161.3~7 75.2{7 13.812 175.648 161.337 0.241 127.709 161.337 86. 304 I66.750 2658.921 29.601 -0.040 263.500 273.500 0.015 12.609 -0.060 96.625 7265.000 160.087 33.061 32.588 111.125 160o087 0.370 130.271 160.087 86.597 164.075 3096.447 24.836 -0.040 244.750 275.000 -0.046 LIS TAPE YERIFICATION LISTING SCHLUMBERGER AL~SK.~ COMPUTING CENTER PEF.LDT 2o6¢I RHOS..LDT GR.LDT '91.688 TENS.EPT MTEM. EPT 166. 075 NVR, EPT DEPT. 9200.000 MCAL.DTE HTEN. DTE 1581.332 IOQF.DTE MRES.OTE -0o050 IIRD.DTE IIXM, OTE 9.590 IDPH.OTE ILM, OT,E 8°566 SFLU.DTE GR.OTE 59.109 TENS.DSI MRES.O$I .-O.OSO MCAL.OSI OTR2,0SI 152,229 DTM2,0SZ GR,OS~ 59.~09 TENS,M:LT MRES, MLT -0.050 MCAL.MLT TENS.CNT 5TZO,O00 MTEN.C~T TNRa. CNT 3. OZ? RTNR,CgT CFTC.CNT 850,970 CNTC.CNT GR,CNT 65,375 TENS,LOT MTEM,LOT 263. 063 CaLI,LOT ~LS,LOT 219,750 LITe,LOT LSHV.LOT 2829.000 SSHV,LOT PEF,LDT 2.688 RHOB-LOT G~.LDT 65.375 TE~$.EPT MTEM. EPT ~63.063 NVR, EPT DEPT. 9100.000 MCAL.DTE HTEN.DTE 1528.616 IDQF.DTE MRE S*.,OTE -0.051 IIRD.DTE I'IXM. DTE 3.923 IOPH.DTE ILFI. DTE 29.925 SFLU.DTE GR.OTE 62.820 TENS,OSI MRES.DSI -0.051 MCAL.D$I OTR2.OSI 271.062 OTM2.OSI GR.OSI 62.820 TENS.MLT MRES,MLT -0.051 MCAL.MLT TENS.CNT 5870.000 HTEN.CNT TNRA.CNT 4.740 RTNR.CNT CFTC.CNT 354.195 CNTC.CNT GR.CNT 55.313 TENS.LDT MTEM.LDT 162.163 CALI.LDT LS.LD-T 1637.000 LITHoLOT LSHV.LDT 1816.000 SSHV.LDT PEF.LDT 1.521 RHOB.LDT GR.LDT 55.313 TENS.EPT MTEM. EPT 162. 163 NVR.EPT DEPT. 9000.000 MCAL.DTE HTEN. DTE 1498.162 IDQF.DTE MRES.DTE -0.051 IIRD.DTE IIXM. DTE 5.799 IOPH.DTE ILM. OTE 57.986 SFLU.DTE GR.DTE 62.763 TENS.DSI MRES.OSI -0.051 MC~L.DSI DTRZ.DS! 136.607 DTM2.DSI GR.OSI 62.763 TENS.MLT 17-MAR-1992 18:17 2.656 ORHO.LOT 5755,000 HTEN.EPT 3.40'4 FVR.EPT 12.210 HDIA.DTE O. 000 IMQF,DTE 99.163 IIXD.DTE 8.905 IMP'H.OTE 6.815 SP.DTE 7190.000 HTEN.DSI 12. 210 HDIA.DSI 165.670 OT6P.DS! 7190.000 HTEN.MLT 12.210 HDIA.MLT 106Z.000 MRES.CNT 3.022 RCFT'CNT 2520,,,580 TNPH.CNT 5710..000 HTEN,LDT 13.258 LL.LDT 63.219 SS1.LDT 1 616, O00 Q.LS.LOT 2. 563 DRHOeLOT 5710.000 HTEN. EPT 3.610 FVR.EPT 10.679 HDIA.DTE O, 000 INQF.DTE 37.595 IIXD. OTE 25.750 IMPH.OTE 28. 241 SPoDTE 6920.000 HTEN.DSI 10.679 HDIA.DSI 257.186 DT6P.DSI 6920.000 HTENo#LT 10.679 HDIA.RLT 1205.000 NRES.CNT 5.511 RCFT.CNT 1667.180 TNPH.CNT 5870.000 HTEN.LDT 14.067 LL.LDT 598.000 SS1.LOT 1612.000 QLS.LOT 1.404 ORHO.LDT 5870.000 HTEN.EPT 3.412 FVR.EPT 9.460 HDIA.DTE 0.000 IMQF.DTE 11.675 IIXD.DTE 116.837 INPH.DTE 30,607 SPoOTE 6760.000 HTEN.DSI 9.660 HDIA. DSI 129.817 DT6P.DSI 6760.000 HTEN.MLT 0.006 1061.000 0.337 -999.250 0.000 5,078 8.399 0.000 1581.33 Z -999.250 73.067 1581.33Z -999.250 -'0.0¢0 757°668 31.124 1062.000 1120250 189.625 -0o021 0.013 1062o000 0.342 -999.250 0.000 0.360 22.342 015 -999.250 93.629 1528.616 -999,,, -0.06030'6.-90 68.~83 1205.000 B01o000 219.125 -0.066 -0.018 1205.000 0.366 -999.250 0.000 0.315 57.099 0.188 1¢98.162 -999.250 63.180 1498.162 OPHI,LDT MRES,EPT GR.EP'T TENS.DTE MTEM. DTE IIRM.OTE ILO, OTE SPD.DTE MTE~,OSI PR.OSI DT4S.DSI MTEM.MLT GR.MLT MTEM.CNT RCNT.CNT NPHI,CNT MRES.LDT LU.LDT SSI.LOT QSS,LOT DPHIoLDT MRES.EPT GR.EPT TENS.OTE #TEN. OTE IIRM.OTE ILD.OTE SPO.DTE MTE M.D.S ! PR.DS! DT4$.DSI M'TEM. NLT GR. NLT MTEN.CNT RCNToCNT NPHIoCNT MRES,LDT LU,LOT SS2.LDT QSS.LDT DPHI.LDT #RES.EPT GR.EPT TENS.DTE #TEM. DTE IIRM.DTE ILD.DTE SPO.OTE NTEM, OSI PR.DSI OT6S.OSI NTEM.MLT PAGE: 17 11.727 -0.040 91.688 7190. 000 160.024 110.423 8.732 161. 608 160,,024 0.331 142.156 160.026 59.109 163.063 2417.226 30.666 -0.040 216.875 255,125 -0-016 5.274 -0.040 65.375 6920.000 159.562 31,782 24.293 138.223 159.562 0.426 115.596 159.562 62.820 162.163 1486.505 61.003 -0.060 1672.000 369.500 -0.031 75.510 -0.040 55.313 6760.000 159.232 16.621 91.636 94.957 159.232 0.345 122.506 159.232 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER MRES=MLT -0.051 MCAL.MLT TENS.CNT 5685.000 HTEN.CNT TNRa:,CNT 3. 217 RTNR.CNT CFTE.CNT i0'98.049 CNTC.CNT GR.CNT 51.094 TENS.LOT MTEN.LDT 16~.712 CALI.LDT LS.LDT 322.500 L[TH.LDT LSHV.LDT 1823.000 SSHV.LOT PEF. LDT 2.137 RHOS.LOT GR.LDT 51.0g~ TENS.EPT MTEM. EPT 151.712 NVR.EPT DEPT. Bgo0.o00 MCAL.DTE HTEN.OTE I546.353 [O~}F.OTE fiRES.DTE -0.051 IZRD.OTE [IXN.DTE 7.323 tDPH.OTE [LM.OTE 28.785 SFLU.DTE GR.DTE 59.003 TENS.OS[ MRESoOSI -0.051 MCAL.DSI DTRZ.OSI 131.477 OTM2.OS! GR.OSI 59.003 TENSoNLT MRES.NLT -O.OSI MCAL.NLT TEN$.CNT 5695. 000 HTEN.CNT TNRA.CNT 2.551 RTNR.CNT CFTC.CNT 1160.695 CNTC.CNT GR.CNT 61.031 TENS.LOT MTEN.LDT 161.150 CALZ.LDT LSoLDT 295.750 LITH.LDT LSH¥.LDT 1824.000 SSHV.LDT PEF.LDT 2.461 RHOB.LDT GE.LOT 61.031 TENS.EPT MTEM. EPT 161.1 50 NVR.EPT DEPT. 8800.000 MCAL.DTE HTEN.OTE 1550.122 IOQF.OTE NRES. DTE -0.051 [IRD.O'TE IIXN.OTE 6.465 [DPH.OTE ILM.DTE 22.996 SFLU.OTE GR.DTE 46.702 TENS.DS[ MRES.DS[ -0.051 MCAL.OS! DTR2.O$! 121.662 OTM2.DS! OR.OS[ 46.70Z TENS.MLT MRES.MLT -O.OSI MCAL.MLT TENSoCNT 5645.000 HTEN.CNT TNRA.CNT 2. 271 RTNR.CNT CFTC.CNT 1446.356 CNTC.CNT GR.CNT 53.906 TENS.LOT MTEI~.LOT 159.800 CALl.LOT LS.LDT 209.500 LITH.LDT LSHV.LDT 1822.000 SSHV.LDT PEF.LDT 2.336 RHOBoLDT GE.LOT 53.906 TENS.EPT MTEM. EPT 1 59. 800 NVR. EPT 1T-MAR-199[,18:17 9.460 HDZA.NLT 1037.000 MRES.CNT 3.276 RCFT.CNT 2905.371 TNPH.CNT 5685.000 HTEN.LDT 12.641 LL.LOT [11.625 SSI.LOT 1613.000 QLS.LDT 2.347 DRHO.LDT 5685.000 HTEN. EPT 3.414 FVR.EP'T 12.070 HO[A.DTE 0.000 [MQF.DTE 23.815 I[XO.DTE 45.172 INPH.DTE 17.846 SP.DTE 6815.000 HTEN. D$[ 12.070 HDIA.OS[ 124.77Z DT4P.DS! 6815.000 HTE:N. MLT 12.070 HO[A.MLT I029.000 MRES.CNT 2.691 RCFT.CNT Z848.510 TNPHoCNT 5695.000 HTEN. LDT 12.656 LLeLDT 89.875 SS1.LOT 1613.000 QLS.~LOT Z.453 ORHO. LOT 5695.000 HTEN. EPT 3.420 FVR.EPT 12.823 HD[A.DTE 0.000 [MQF.DTE 37.649 IIXD. OTE 25.563 INPH.DTE 18.662 SP.OTE 6745.000 HTEN.DS! 12.823 HDIa. DS[ 115.956 DT4P.D'SI 6745.000 HTEN. NLT 12.823 HDXA.MLT 1055.000 NRES.CNT 2.431 RCFT.CNT 3317.970 TNPH.CNT 5645.000 HTEN.LDT 13.828 LL.LDT 59. Z81 SS1.LDT 1613.000 ~LS.LDT 2-595 DRHO.LDT 5645.000 HTEN. EPT 3.424 FVR.EPT -999.250 -0.040 983.334 26.623 1037.000 173.000 205.500 0.010 0.021 1037.000 0.346 -999.250 O. gO0 O. 939 Z6-326 0.438 1546.353 -999.Z50 68.9Z2 1546.353 -999.250 -0.040 968.601 Z3o734 1029.000 7.875 0.010 0.081 1029.000 0.350 -999.250 0.000 0.534 24.704 0.625 1550.12Z -999.250 67.095 1550.122 -999.Z50 -0.041 1306.789 20.743 1055.000 109.313 189.125 0.024 0.015 1055.000 0.347 GR.HLT MTE~t. CNT RCNT.CNT NPHI. CNT MRES .LOT LU.LOT SSZ.LDT ~S S. LDT DPHI.LDT MRES.EPT GR.EPT TENS. OTE MTEH.DTE II;M. OT'E ILO. OT E SPD.OTE PR.DS[ DT4S.DS[ NTEN.MLT GR..NLT MTEM.CNT RCNT.CNT NPHI.CNT MRES.LOT LU. LOT SS2.LOT QSS.LDT DPHI.LDT NRES.EPT GR.EPT TENSoDTE NTEM.'OTE IIRM.DTE ILD.DT E SPO.DTE NTEN.DS[ PR.DS[ DT4S.DS! MTEM.MLT GR.NLT MTEMoCNT RCNT.CNT NPHT .CNT MRES.LDT LU.LOT SS2.LOT ~SS.LDT DPHZ .LDT M~ES.~PT GR.EPT PAGE: 18 42.763 161.712 3282.098 33.802 -0.040 299.250 291.250 -0.022 18.378 -0.0.40 51.094 6815.000 159.037 33.038 40.996 67.387 159.037 0.280 122.302 159.037 59.003 161.150 2496.935 23.707 -0.040 276.250 293.000 0.003 11. 964 -0.040 61.031 6745.000 157.918 61.330 24.226 96.611 157.918 0.248 125.662 157.918 46.702 159.800 3003.634 19.050 -0.041 200.375 251.125 -0o011 3.312 -0.041 53.906 IS TAPE YERIF,ICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER DEPT. 8700.000 MCAL,DTE HTEN.DTE 1526,640 ~O. QF.DTE M:RES. DTE -0.052 IIRD.OTE IIXM. OTE 4.921 IDPH.OTE ILM, DTE 11.704 SFLU.DTE GR,OTE 65.553 TENS.DS! MRES.O$[ -0.052 MCAL.DS! OTRZ,OSI 179.537 OTM2,DSI GR,DSI 65.553 TENS,MLT MRES,MLT -0,052 MCAL.MLT TENS,CNT 5565,000 ~TEN,CNT TNRA,CNT 2,&27 RTNR.CNT CFTC,CNT 857.,g&~ CNTC,CNT GR.CNT 7~,a38 TENS,LOT MTEM,LDT 159,35.0 CALI,LOT LS,LDT 290'750 LITH,LOT LSHV.LOT 1825,000 SSHV,LOT PEF,LOT 2.713 RHOB,LOT GE,LOT 7~,438 TENS,EPT MTEM. EPT 1 59.350 NV R.EPT DEPT. 8&O0.O00 ~CAL.OTE ~HTEN. DTE 1493.087 IOQF.~TE MRES.DTE -0.052 [IRD.DTE IIXM. OTE 8.609 IDPH.DTE ~LM-DTE 13.~09 SFLU.DTE GR-DTE 80.229 TENS.DSI MRES.DSI -0'052 MCAL.DSI DTRZ.DSI ~.073 OTMZ.DS~ GR.OSI 80.229 TENS.~LT MRES.MLT -0.052 MCAL.MLT TENS.CNT 5520.000 HTEN.CNT TNRA.CNT 2.869 RTNR.CNT CFTC.CNT 819.038 CNTC.CNT GR.CNT 90.313 TENS.LOT MTE~.LDT 158.~50 CaL[.LDT LS.LDT 275.000 LITH.LDT LSHV.LDT 1821.000 SSHV.LOT PEF.LDT 2. 525 RHOB.LDT GR.LDT 90.313 TENS.EPT ~TEM. EPT ~ 58.~50 NVR.EPT DEPT, 8500.000 MCAL.DTE HTEN.OTE 1571,703 IDQF.DTE #RES.DTE -0.052 IIRD.DTE IIXM.DTE 6.689 IDPH.DTE ILM.OTE 25.563 SFLU.DTE GR.DTE 38.475 TENS,OSI MRES,OS[ -0.052 MCAL.DS! OTRZ,DS[ 133,605 DTN2.DSI GR.OSI 38.475 TENS.MLT MRES.MLT -0o052 MCAL.~4LT TENS,CNT 55[0o000 HTEN.CNT TNRA.CNT 1.925 RTNR.CNT 17-MAR-lgg2, 18:17 12. 384 HDIA.DTE 0.000 IMQF,OTE 75.389 IIXO,OTE 11o487 IMPH.OTE 9o 215 SP. D'TE 6730.000 HTEN.DSI 12.384 HDiA.OS! 170. 596 OT4P.OSI 6730.000 HTEN. MLT 12o384 HOIA,MLT 1050,000 MRES,CNT 2o756 RCFT.CNT 2233,929 TNPH. CNT 5565,000 HTEN,L'DT 13,289 LL'LOT 100.938 SS1-LOT 161Z.000 QLS.LDT 2,390 OR'HO, LOT 5565. 000 HTEN. EPT 3,422 FVR'EPT 11. 390 HDIA. DTE 0-000 IMQF.OTE 62- 810 IIXO-OTE 14. 282 INPH,O'TE 10-019 SP,OTE 6500,000 flTEN'OS! 11.390 LHD!A-OSI 131. 582 DT4P,DS! 6500, 000 HT E N, NL T 11.390 HDIA.MLT 1075,000 MRES,CNT 3.244 RCFT.CNT 2365.351 TNPH. CNT 5520.000 HTEN.LDT 14o 594 LL.LOT 86,375 SS1,LDT 1611.000 QLS,LOT 2.431 ORHO,LOT 5520.000 HTEN, EPT 3.424 FVR,EPT 12.020 HDIA.DTE 0.000 IMQF,DTE 43.498 IIXD.DTE 22. 558 IMPH.DTE 22.276 SP. DTE 6610.000 HTEN.DSI 12.020 HDIA. DSI 129.423 OT4P.DS! 6610.000 HTEN. MLT 12.020 HDIA. MLT 1059.000 MRES.CNT 1.905 RCFT.CNT -999,250 0.000 3,182 10,954 1,063 1526,640 -999.250 48.626 1526,640 -999.250 -0.0¢1 814o317 25.629 1050.000 153,875 194.375, -0.001 0.003 1050-000 0,352 -999.250 0,000 0.937 13.376 1.438 1493.087 -999.250 70,'347 1493.087 -999.250 -0.041 764,186 29.263 1075.000 146.875 198.875 0.022 0.015 1075o000 0.346 -999.250 0.000 3.295 26.153 1.750 1571.703 -999.250 75.446 1571.703 -999.250 -0.041 1888.323 TENS.OTE MT EM. OT E IIRH.DTE ILD.DTE SPO.DTE HTEM,DS! PR.DSI DT4S.O$! t4TEM.M'LT GR.MLT MTEM.CNT RCNT,CNT NPH[. CNT HRES.LOT .L U. L O T SS2.LDT ~rSSeLDT DPHI-LDT MRES,EPT GR,EPT TENS.,DTE MTEN, OTE IIRM. OTE ILD,DTE SPO.DTE #TEN.OS! PR.DSI DT4S.OSI MTEN.MLT GR.NLT MTEN.CNT RCNToCNT NPH I. CNT #RESoLDT LU,LOT SS2.LOT ~SS.LOT DPHI.LDT NRES.EPT GR. EPT TENS,OTE MTEM, OTE IIRN, OTE ILD.DTE SPD.OTE MTEN.OSI PR,OSI MTERoHLT GR.MLT MTEM.CNT RCNT.CNT PAGE: 19 6730.000 157.461 80.973 11.541 132.663 157.461 0.456 81.57'1 157:.461' 65.553 159.350 2240.635 24.594 -0.041 273,500 267,250 -0,008 15.734 -0.041 74.438 6500.000 156,806 70.729 14.125 104.410 156.806 0,300 116.801 156.806 80.229 158.450 2321.295 27.713 -0.041 256.250 260.750 0.024 13.267 -0.041 90.313 6610.000 156.740 37.192 21.055 1.276 156.740 0.243 126,723 156,740 38,675 158.113 3978.388 LIS TAPE VERIFICATION LISTZNG SCHLUMBERGER ALASKA COMPUTING CENTER CFTC.CNT 2167.357 CNTC.CNT GR.CNT 40.78! TENS.LOT MTEMoLDT 158.113 CALI.LDT LS.LDT 311.250 LZTH.LOT LSHVoLDT 1821.000 SSHV.LOT PEF.LD'T 2.135 RHOB.LDT GR.LDT 40.781 TENS.EP'T MTEM.EPT 158.113 NVR.EPT DEPT. 8400.000 MCAL.DTE HTEN.OTE 1585.740 IOQF.DTE MRES.DTE -0.052 ZZRD.DTE I IXN..OTE 5. 544 IDPH. DTE ILM.DTE 30.266 SFLU.OTE GR.OTE 59.792 TENS.DSI MRES. OSI -0.052 MCAL.DSI DTRZoOSI Z24o462 OTM2.DSI GR.OS: 59.792 TENS.MLT MRES.HLT -0.052 MCAL.MLT TENS.CNT 5~0.000 HTEN.CNT TNRA.CNT ~. 818 ~TNR-CNT CFTC.tNT 327.227 CNTC.CNT GR.CNT 60.03I TENS.LOT MTEM.LDT 156.875 CALI.LOT LS.LDT 1~25.000 LITH.LOT LSHV.LDT 1808.000 SSHV.LOT PEF.LDT 1.600 RHOB'LDT GR.LDT 60.031 TENS.EPT MTEM. EPT 156. 875 NVR. EPT DEPT. 8300.000 MCAL.OTE HTEN. DTE 1533.600 ' IDQF.OTE MRES.OTE -0.053 ZZRDoDTE IIXM. OTE 16.363 IDPH.DTE ILM.OTE 5.175 SFLU.DTE GR.DTE 37.721 TENS.DSZ MRES.DSI -0.053 MCAL.DS! DTR2.OSZ 135.636 DTN2.OSZ GR.OSI . 37.721 TENS.MLT MRES. MLT -0.053 NCAL.MLT TENS.CNT 5285.000 HTEN.CNT TNRAoCNT 2.412 RTNR.CNT CFTC.CNT 1334.792 CNTC.CNT GR.CNT 43.594 TENS.LDT MTEM.LDT 155.863 CALZ.LDT LS.LDT 237. 375 LITH.LOT LSHV.LDT 1820.000 SSNV.LOT PEF.LOT 2.697 RHOB.LDT GR.LDT 43.594 TENS.EPT MTEM. EPT 155.863 NVR.EPT DEPT. 8200.000 MCAL.DTE HTEN.DTE 1526.829 IDQF.DTE MRES.DTE -0.053 IZRO.DTE IIXM.OTE 4.144 IDPH.DTE 17-MAR-1992 18:17 4189.902 TNPH.CNT 5510.000 HTEN.LOT 12.281 LL.LOT 113.125 SS1.LOT 1611. 000 QLS.LOT 2. 364 DRHO' LOT 5510o000 HTEN.EPT 3.426 FVRoEPT 14.5'79 HDZA.DTE 0.000 IMQF. DTE 9.164 IIXD:'DT, ~8.451 IMPH. OT[ 36.02.Z SP. OTE 6510.000 HTEN. DSZ 14.579 HDIA.OSZ 213o44,0 6510,, 000 HTEN:o MLT 14.5'79 HOIA.MLT 1071.000 : MRES.CNT 5-029 RCFT.CNT 1568.816 TNPHo CNT 5 440'.0.00 HTEN.LOT 17.813 LL.L OT 586°000 SSloLOT O- 0'00 QLSoLOT 611. 504 DRHO'L DT 5440.000 HTEN.EPT 3.4Z8 FVR.EPT 15.838 HDIA.DTE 0.000 I#QF.OTE 163.930 IiXD.DTE 5.335 INPH.DTE 3.578 SP.DTE 6335.000 HTEN. OSZ 15.838 HOIA.DSZ 132.516 DT4P.OSZ 6335.000 HTEN. MLT 15.838 HDIA.NLT 1080.000 MRES.CNT 2- 353 RCFT.CNT 3066.897 TNPH.CNT 5285.000 HTEN.LDT 16. 219 LL.tDT 72.313 SS1.LDT 1609,.000 QLS.LDT 2.508 DRHO.LOT 5285.000 HTEN. EPT 3.445 FVR.EPT 13.445 HDIAoDTE 0.000 ZMOF.OTE 21.727 IMPH. DTE 16.327 NPHI.CNT 1059.000 MRES.LDT 165.500 LU. LOT 202.875 SS2.LDT 0.000 QSS.LD'T 0.015 OPHI.LDT 1059.000 MRES. EP'T 0.351 GR.EPT -999.250 TENS.DTE 0.000 MTEM. DTE 2.830 IIRM.DTE 30.106 ILD.DTE 2.t25 SPD.OTE 1585.740 NTEW.DSI -999'250 PRo'OSI 119.360 O T.4 S. 0 S Z 1585.740 MTEH. MLT - 999° :250 GR. NL'T -0.0-42 MTEM.CNT 288°798 RCNT.CNT 71.614 NPHIoCNT 107t.000 NRES.LOT 736.000 LU.LOT 230-750 SS2.LDT -0 - 011 ~ S:iS - L O T ' O.OOZ D~toLDT 1071o000 ~RES.EPT 0'351 GR.EPT -999.250 TENS.OTE 0.000 MTEM.OTE 18.874 ZZRM.OTE 5.343 ILD.DTE 0.063 SPD.DTE 15'33.600 MTEM.DST -999.250 PR.OSZ 72.006 DT4$.DS! 1533.600 MTEM.MLT -999.250 GR.MLT -0.042 #TEN.CNT 1175.419 RCtIT.CNT 19.712 NPHI.CNT 1080.000 MRES.LDT 124.938 LU.LDT 187.750 SSZ.LDT 0.019 QSS.LOT 0.004 DPNI.LDT 1080.000 MRES. EPT 0.374 GR.EPT -999.250 TENS.DTE 0.000 MTEM. OTE 0.388 IIRM.DTE 22.444 ILO.DTE PAGEt 20 14.464 -0.041 291.250 285.500 -0. 021 17.346 -0.041 40.781 6510.000 155.29'9 31.425 32.175 31.765 155. 299 0.272 145.)53 155. 99 5.9.792 156.875 1546.151 60.624 -0 1379.000 377.7'50 -0.020 69-459 60.031 6335.000 154.710 181.808 5.278 112.050 154.710 0.291 131.477 15¢.710 37.721 155.863 2941.423 20.216 -0.042 224.875 257.500 -0.023 8.603 -0.042 43.594 6335.000 154.710 49.212 20.099 LIS TAPE VERIFICATION LISTING SCHLUMBERGER aLaSKa COMPUTING CENTER ILM. DTE 19o30Z SFLU. DTE GR.OTE 67.513 TENS.DSI MRES.DSI -0.053 MC~L.DSI DTR2.OSI 230.619 OTM2.OSI GR.OSI 67.513 TENS.MLT MRE S. MLT -0.053 MC AL oMLT TENS,CNT 5140.000 HTEN.C'NT TN'RR. CNT 3. 179 RTNR.CNT CFTC.CNT 712. 252 CN'TC.CNT GR.CNT 91.000 TENS.LDT MTEN.LDT 155. 525 CALI.LOT LS.LDT 214.750 LITH.LDT LSHV.LDT 1811.000 SSH¥.LDT PEF.LDT 4.035 RHO.B.LOT GR.LOT 91.000 TENS.EPT MTEN. EPT 155. 525 NVR.EPT DEPT. 8100.000 MCAL.OTE HTEN. OTE 1515.940 IDqF.DTE MRES. OTE -0.053 IIRD.DTE IIXI~.OTE 7.201 IOPH.DTE IL',M- DTE 13.667 SFLU.DTE GR.DTE 52-075 TENS.:DS! MRES.OSI -0.053 MCAL.DS.! DTR2.OSI 157.672 DTM2.OSI GR.OSI 52.075 T'ENS.;MLT MRES.MLT -0.053 MCAL.MLT TENS.CNT 5195.000 HTEN.CNT TN:RA.CNT 2. 430 RTNR.CNT CFTC,CNT 1519.315 CNTC.CNT GR,oCNT 56.656 'TENS.LOT MTEM.LDT 155.188 CALI.LOT LS.LDT 261.000 LITH.LDT LSHV.LDT 1819.000 SSHV.LDT PEF.LDT 2.389 RHOB.LDT GR.LDT 56.656 TENS.EPT MTEM. EPT 155o188 NVR. EPT DEPT. BO00.O00 NCAL.OTE HTEN.DTE 1561.855 IDQF.DTE MRESoOTE -0.053 I[RD.OTE IIXM. DTE 9.449 [OPH.OTE ILM. DTE 10.239 SFLU.DTE GR.OTE 54.642 TENS.OSI MRES.DSI -0.053 MCAL.DSI DTR2.DSI 170.578 DTM2.OSI GR.OSI 54.642 TENS.MLT MRES.NLT -0.053 MCAL.MLT TENSoCNT 5095.000 HTEN.CNT TNRA.CNT 2.714 RTNR.CNT CFTC.CNT 993.068 CNTC.CNT GR.CNT 61.719 TENS.LOT MTEMoLDT 154.625 CALI.LOT LS.LDT 270.250 LITH.LDT LSHV.LDT 1819.000 SSHV.LOT 17-MAR-1992 18:17 2¢. 317 SP.OTE 6335.000 HTEN.OSI 13.445 HOIA. OSI 219.596 OT4P.OSI 6335.000 HTEN. MLT 13.445 HDIA.MLT 1056.000 MRES. CNT 3.313 RCFT.CNT 2282. 815 TNPH.CNT 5140.000 HTEN'LOT 14.531 LL.LDT 71.375 SS1.LDT 1609.000 QLS.LOT 2. 563 DRHO.LOT 5140'000 HTEN. EPT 3.447 FVR.EPT 12.070 HDIA.DTE 0.000 IMG'F'DTE 73.439 IIXO,.OTE 12. 910 I MPH. OT E 10. 188 SP-OT E 6 200' 000 H T E N. D S I 12.070 HO'IA.DS! 149.678 DT4P'D$I 6200.000 HTEN'#LT 12-070 HDIA'MLT 1068.000 ~ MRES. CNT Z. 646 RCFT. CNT 3605.861 TNPHoCNT 5:195. 000 HTEN-LDT 13. 828 LL.'LD'T 80.625 SS1.LOT 9. 000 GLS-LOT 1602o440 DRHOOLOT 5195.000 HTENoEPT 3. 443 FVR, EPT 12.426 HDIA.DTE 0.000 [NQF.OTE 82.960 [[XD.DTE 11.188 [MPH. OTE 7.722 SP.OTE 6315.000 HTEN. DSI 12.426 HOIA.OSI 160.139 DT4P.OSI 6315.000 HTEN.NLT 12.426 HDIA.NLT 1073.000 MRES.CNT 2.B85 RCFT.CNT 2687.537 TNPH.CNT 5095.000 HTENoLDT 14.531 LLoLOT 84.188 SS1.LDT 1609.000 QLS.LDT 0.125 1526.829 -999.250 77.982 1526.829 -99 9. 250 -0.042 673.500 34.246 1056.000 111.688 178o625 0-014 -O. O 07 1056.000 0°373 -999.250 0.000 5.259 14.170 0.125 151 5.940 - 999 o Z 50 77.920 1515o940 -99 9. 250 -0.042 1414.101 21.906' 10'68.00-0 136.750 185.375 -0.003 -0.007 1068.000 0.367 -999.250 0.000 5.826 10.352 0.125 1561.855 -999.250 82-170 1561.855 -999.250 -0.042 895.635 26.523 1073.000 143.125 193.250 0.010 SPO.DTE MTEMoDSI PR.DSI DT¢$.OSI MTEM. MLT GR.MLT MTEM.CNT RCNT.CNT NPHI.CNT MRES.LDT LU.LOT SS2.LOT ~SS.LOT D, HI'LDT MRES.EPT GR.EPT TENS-DTE MTEN.DTE ILOoDTE SPD.DTE MTER. OSI PR.OSI OT4S.OSI MTEM-MLT GR.MLT M.TENoCNT RCNT.CNT NPHI.CNT MRES.LDT LU.LDT SS2.LDT QSS.LDT DPHI.LDT MRESoEPT GRoEPT TENS.DTE MTEN.DTE I IRN.OTE ILO. DT E SPD.DTE MTEN. DSI PR.OS[ DT4SoDS! MTEM. MLT GR. NLT NTEM.CNT RCNT.CNT NPHT.CNT MRES.LDT LU.LOT SS2.LDT QSS.LDT PAGE: 21 80.829 154.710 0.428 -999.250 154.710 67.513 155.525 2261.177 32.384 -0.042 206.125 252.750 -0.054 5.266 -0.042 91.000 6200-000 154'3:17 69.400 12'513. 1151.050, 15.4.317 0.314 142.1'82 15;4-317 52°075 155.188 3332.8.67 21.425 -0.'042 248.250 265.500 -0.045 12.741 -0.042 56.656 6315'000 153.924 92.478 10.752 81.148 153.924 0.321 155.011 153.92& 54.642 156.625 2656.090 25.419 -0.042 254.250 264.500 -0.010 LIS TAPE YERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER 17-MAR-1992 18:17 'PEF.LDT 2. 453 RHDB.LDT GR*.LDT 61.719 TENS.EPT 5095-000 MTEM. EP'T 1 54.6 25 :NVR. E PT 3.445 DEPT. 7900.000 MCAL.DTE HTEN. OTE, 1591. 718 IOQF.DTE MRES.DTE -0.054 IIRD. DTE IIXM.OTE 11.983 IDPH'.OTE ILM. O'T,E 6.697 SFLU,.DTE GRoOTE 31.803 TENS.OSI MRES*.OSI -0.054 MCAL*.DSI DTRZoOSI 134..585 DTM2oDS! GR.DS,[ 31.803 TENS.MLT MRES.MLT -0.054 MCAL.MLT TENS.CNT 4990.000 MT EN.CNT TflRA*.CNT 1.907 ' RTNR.CNT CFTC.CNT Z040.210 CNTC'CNT GR.*.CNT 32.406 TENS.LOT MT.EM.LOT 153. 837 CALI.LDT LS.LDT 222.250 LITH.LOT LSH¥.LDT 1821.000 SSH¥.LDT PEFoLDT 2.633 RHOB.LOT GR.LDT 32.406 TENS.EPT MTEM.EPT 153.837' NVR.EPT DEPT. 7800.000 MCAL.OTE HTEN. DTE 1607.294 IDQF.OTE MRES.OTE -0°054 IZRO.OTE IIXM. OTE 11.993 IDPH.DTE ILM.OTE 7.738 SFLU.OTE GR.OTE 59.84.1 TENS.OSI MRESoDSI -0.054 MCAL.DS! DTR2.DSI 153.595 OTM2.DSI GR.O$I 59. 841 TENS.MLT MRESoMLT -0.054 MCAL.MLT TENS.CNT -999.250 HTEN.CNT TNRA.CNT -999.250 RTNRoCNT CFTC.CNT -999.250 CNTC*.CNT GR*.CNT -999.250 TENS.LOT MTEM.LDT -999.250 CALI.LDT LS.LDT -999.250 LITH.LDT LSHV.LDT -999.250 SSHV.LDT PEFoLDT -999. 250 RHOB.LDT GR.LDT -999.250 TENS.EPT MTEM. EPT -999.250 NVR.EPT DEPT. 7700.000 MCAL.DTE HTEN.DTE 1624..417 IDQF.DTE MRESoOTE -0°054 IIRD.OTE IIXM. DTE 12.111 IDPH.DTE ILM. OTE 6. 868 SFLU.DTE GR.OTE 67. 802 TENS.DSI MRES.DSI -0.054 MCAL.DSI DTRZ. DS! 159.8&1 DTM2.OSI GRoDSI 67. 802 TENS.MLT 15.159 0.0.00 I24~.627 7*. 180 6195..000 15.159 129.04.0 6195.000 15.I59 1076- OOO I. 923 4051. 804. 4990.000 15.750 66.500 16 09. O00 2. 556 49900000 3.44.5 15.466 0o000 113.787 7.899 5. 237 6175.000 15..466 147,,989 6175.000 15.4.66 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 14.546 0.000 117.287 7.380 6.239 6090.000 153.943 6090.000 DRHO.LDT HTEN. EPT FVR.EPT HDIA.DTE IMQF.DTE IIXD. OTE IMPH.DTE SP.DTE HTEN.DSI HDIAiDSI OT4P.DSI HTEN.MLT HDXA. MLT 'MR E S. C NT R.CFT.CNT TNP'MoCNT NTEN.LOT LL.LOT SSI .LOT QL S. LOT ORHOo LOT HTEN. EPT FVR. EPT HOIA.OTE I MQF.. D T E IIXD. OTE IMPH.DTE SP. OTE HTEN.DSI HOIA.DSI OT4P.DS! HTEN. MLT HDIA.MLT MRES.CNT RCFT.C#T TNPH.CNT tit EN. L DT LL.LOT SS1.LDT QLS.LOT ORNO.LDT HTEN. EPT FVReEPT HDIA.DTE IMQF.DTE IIXD.DTE IMPH.DTE SP. DTE HTEN.DSI OT4P.DSI HTEN.MLT 0.005 1073'000 O. 36*9 -999.250 0.000 11.305 6.868 0.125 15,91..718 -999. SO 67. iz 1591.718 -999.250 -O.04Z 1 831.651 15.480 1076.000 11'5.188 189.125 O. 002 0.011 1076 o 000 O. 368 -999.250 0o000 I0.001 7.363 0.125 1607*.294. -999.250 75*.829 1607.29¢ -999.250 -999.250 -999.250 -99'9.250 -999*.250 -999o250 -999.250 -999.250 -999.250 -999*.250 -999.250 -999.250 0.000 9.541 6.658 -0.188 1624..4.17 -999.250 76.557 1624.417 OPHI.LDT MRES. EPT GR.EPT T E N S. O T E MTEM.DTE IIRM. OTE ILO. DT E SPO.DTE MTEM.OSI PR.OSI DT4S.DSI MTEN. MLT GR.MLT MTEM.CNT RCNT.CNT NPHi. CNT MRES.LDT LU. LD T SS,?.. LDT ~SS.LOT DPHI.LDT MRES. EPT GR.EPT T E N S., DT E MTER. DTE I ~RM. DT E "IL O. DT E SPD.DTE MTEM. DSI PR.DSI DT4S.DSI MTEN.NLT GRoMLT NTEM'CNT RCNT.CNT NPH !. CNT MRES.LDT LU.LDT SS2.LOT QSS.LOT OPHIoLOT MRES*.EPT GR. EPT TENS.DTE MTEM.OTE IIRN. DTE IL D. DT E SPO.DTE MTEM.DSI PR.DSI DT4S.DSI MTEM.MLT PAGE: 22 13.226 -0.0~2 61.719 6195. 000 15,3.140 140.897 7.029 100.001 153.140 0.313 125.454 153.14,0 31.803 15,3.837 3935.274 12.825 -0.042 214.125 2'54-87'5 -0.016 5.724 -0.042 32.406 6175.000 15:2.617 122.108 7.842 102.011 152.617 O. 322 98.063 152.617 59.841 -999.250 -999*.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 6090.000 152.158 137.431 7.323 132.399 152.158 0.336 146.080 152.158 .IS TAPE VERIFICATION LISTING ~CHLUMSERGER ALASKA COMPUTING CENTER MRES.~tLT -0.054 MCAL.NLT TEN S. C N T - 999. Z S 0 M T E N . C N T TNRA.CNT -999.250 RTNR.CNT CFTC.CNT -999.250 CNTC.CNT GR.CNT -999. 250 TENS.LOT MTEM. LDT -999.250 CRLI.iLOT LS.LDT -99'9.25:0 LITH.LOT LSHVoLDT -999.250 SSHV.LOT PEF.LOT -999.250 RHOS.LOT GR.LDT -999.250 TENS.EPT MTEM.EPT -999.250 NVR.EPT DEPT. 7600.000 MCAL.OTE HTE'NoOTE 1584.818 IDQF.DTE MRES. OTE -O. 0 54 II RO.OTE IIXM. DTE 9.281 IOPft. OTE ILMoOTE 7.749 SFLU.OTE GR.DTE 64-550 TENS.OSI M:RES.. DSI -0.054 MCAL.DSX O?R2.OSI 158.250 DT'M2. DS! GR.OSI 64.550 TENS.MLT MRES. MLT -0.05¢ MCAL.MLT TENS..CNT -999.250 HTENoCNT T NRA o CNT -999.250 RT N R. C NT CFTC.CNT -999.250 CNTC.CNT GR.CNT -999.25:0 TENS.'LOT MTEM.LDT -999.250 CALI.LDT LS.LDT -999.250 LITH.LOT LSHV.LDT -999. 250 SSHV.LOT PEF.LDT -999.250 RHOB.LDT GR.LDT -999.250 TENS.EPT MTEM.EPT -999.250 NVR.EPT DEPT. 7500.000 MCAL.OTE HTEN.OTE 1571.a29 IDQF.DTE MRES.DT.E -0.054 IIRO-DTE IIXM. DTE 14.382 IOPH.OTE ILM. DTE 4.559 SFLU. OTE GR. DTE 53.831 TENS.OSI MRES. DSI -0.054 MCAL.OSI DTR2.OSI 160.0'12 DTM2.DSI GR.DSI 53.831 TENS.MLT #RES.MLT -O.O5& MCAL.MLT TENS.CNT -999.250 HTEN.CNT TNRA.CNT -999.250 RTNR.CNT CFTC.CNT -999.250 CNTC.CNT GR.CNT -999.250 TENS.LOT MTEM. LDT -999.250 CALI.LDT LS.LDT -999.250 LITH.LDT LSHV.LDT -999.250 SSHV.LDT PEF.LDT -999.250 RHOB.LDT GR.LDT -999.250 TENS.EPT MTEM.EPT -999. 250 NVR.EPT I?-MAR-1992 18:17 t4.546 HOIA.MLT -999.250 MRES.CNT -999.250 RCFT.CNT -999.2.50 TNPH.CNT -999.250 HTEN.LDT -999. 250 LL'L _OT -999.2S0' S~S1.LD T -999.250 OLS.LOT -999.250 DRHO.LD'T -999.2'50 HTENoEPT -999.250 FVR.EPT 15.963 HDXA.OTE 0.000 IMQF.DTE 100. 579 IIXO.DTE 8.517 IMPH. OTE 6. 368 SP.DTE 5855. 000 HTEN. OSI 15.963 HDiAoDSI 151. 318 OT&'P. OS! 58S5.000 HTEN.MLT 15.963 HOZA.MLT -999.25'0 MRES'CNT -999.250 RCFT.CNT - 999.250 TNPHo CNT -999. 250 'MT EN.LDT -999.250 LL.LDT -999.250 SSloLDT -999. 250 QLS.'LDT -999. 250 DRHO.LDT -999.250 HTEN.EPT -999.250 FVR.EPT 13.469 HOIA.DTE 0.000 IMQF.DTE 176.920 IIXD.DTE 4.791 INPH.DTE 3-706 SP.DTE 5980.000 HTEN.DSZ 13.469 HDIA.DS! 154.668 OT4P.DSI 5980.000 HTEN.RLT 13.¢69 HOIA.#LT -999. 250 NRES.CNT -999. 250 RCFT. CNT -999.250 TNPH.CNT -999. 250 HTEN. LDT -999. 250 LL.LOT -999.250 SS1.LDT -999.250 QLS.LDT -999. 250 DRHO.LDT -999. 250 HTEN.EPT -999.250 FVR. EPT -999.250 -999.250 -999.250 -999.250 -999.250 -g 9 9.250 -999. 250 -999.250 -999.250 - 999.250 -999. 250 -999.250 0.000 5. 383 7.492 -0.188 1584.818 -999.250 77.60,5 158'4.818 -999.~50,. -999. 50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999°250 -999.250 -999.250 -999.250 0.000 17.196 4.634 -0.375 1571o4.29 -999°250 79.026 1571.429 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 GR.MLT MTEM.:CNT R CNT.CNT NPHI.CNT MRES.LDT L U-LOT SSZ.LOT QSS.LOT DPH I. LO T MRE S. EPT GRoEPT TENS.OTE MTE~M. OT E ! IR M-DT E ILO.OTE SPD.DTE HTEM. DSI PR.DSI DT4S.OS! MTEN. MLT GR'MLT MTEM.CNT RCNT.CNT NPH I. CNT MRE S. LOT LU.LDT SS2.LDT QSS.LDT DPHI.LDT MRES. EPT GR.EPT TENS. DTE MTEMoDTE IIRM.DTE ILD.DTE SPD.OTE MTEM.DSI PRoOSI DT4$.DSI NTEM. NLT GR.MLT MTEM.CNT RCNT.CNT NPHI.CNT MRES.LOT LU.LDT SS2.LDT QSS.LDT DPHI.LOT MRES. EPT GR .EPT PAGE: 23 67.802 -999.250 -999.250 -999.25 0 -999.25'0 -999.25:0 -999.250 -999.250 -999.25'0 -999.250 -999.250 5855.000 151.634 1gl .939 8.528 135.445 151.634 0.322 1¢8.555 151.634 64.550 --999.250 -999. 250 -999.250 -999.250 -999.250 -999.2 SO -999.250 -999,,250 -999.250 -999.250 598.0.000 151.111 206.021 4.740 92.274 151.111 0.323 158.845 151.111 53.831 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 -999.250 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER DEPTo 7'~00.000 ~CAL.:OTE HTEN.DTE 1552.350 ID~F.DTE MRESoDTE -0.05~ IIRO.OTE IIXM.DTE 8.925 IOPH.DTE ILM.OTE 12.699 SFLU.DTE G,R.DTE 59.121 TENS.OSI MRES.D$I -0.054 MCAL.DSI DTRZ.DSI 159.855 OTMZ.DSI GR.DSI 59.1Z1 TENS.HLT NRE$.MLT -0.054 NCAL.HLT TENS.CNT -999.250 HTEN.CNT TNRA.CNT '-999.250 RTNR.,CNT CFTC.CNT -999.250 CNTCoCNT GR.CNT -999.250 TENS.LOT NTEM.LOT -999.250 CALI.LOT LS.LDT -999.250 LITH-LOT LSHV.LDT -999.250 SSHV.LOT PEF.LDT -999.250 RHOB.LOT GR.LDT -999.250 TENS.EPT MT Eft. EPT -999.250 NVR. EPT OEPT. 7300.000 MCAL.DTE N'TEN.DTE 1563.453 IDQF.DTE MRES.DTE -0.055 IIRD.DTE IIXM.DTE 4. 201 IDPH.OTE ILM.DTE 34.422 SFL~UoDTE GR.DTE &S..872 TENS.DSI MRES.DSI -0.055 MCAL.OSI DTR2.OSI 283.477 DTM2.0SI GR.OSI 45.872 TENS.MLT MRES.MLT -0.055 MCAL.MLT TENSoCNT -999.Z50 HTEN.CNT TNRA.CNT -999.250 RTNR.CNT CFTC.CNT -999.250 CNTC,.CNT GR.CNT -999.250 TENS.LOT MTEM.LDT -999.250 CALl. LOT LSoLDT -999.250 LITH.LDT LSHVoLOT -999.250 SSHV.LDT PEF.LDT -999.250 RHOB.LDT GR.LDT -999.250 TENS.EPT MTEM.EPT -999. 250 NVR.EPT DEPT. 7200.000 MCAL.OTE HTEN.DTE 1556.772 IDQF.DTE HRESoDTE -0.055 IIRO.OTE IIXM. DTE 8.031 IDPH.OTE ILM.DTE 10.177 SFLU.DTE GR.OTE 41.986 TENS.DSI MRES.DSI -0.055 MCAL.DSI DTRZ.DSI 141.328 OTM2.DSI GR.DSI 41.956 TENS.MLT MRES.MLT -0.055 MCAL.MLT TENS.CNT -999.250 HTEN.CNT TNRA.CNT -999.250 RTNR.CNT 17-MAR-1992 18:17 13.743 HDIA.DTE O. 000 IMQF.DTE 68.101 IIXO.OTE 13.901 IMPH.OTE 10. 528 SP.OTE 5865.000 HTEN. OSI 13.743 HDIA.OS! 153.956 DT4P. DS[ 586~.000 HTEN. MLT 13. T 43 HO I A. M L T -999.250 MRES.CNT -999.250 RCFT.CNT -999.250 TNPH.CNT -999.250 HTEN.LOT - 999. Z50 LL.LOT -999.250 SS1.LOT -999.250 QLS.LOT -999. Z50 DRHS.LDT -999oZ50 HTEN. EPT -999. 250 FVR. EPT 13.875 HDIA.DTE 0.000 I.MOF. OTE 40.468 IIXD.DTE 31.467 IMPH. DTE 31.1'15 SP.DTE 5795.000 HTEN.OSI 13.875 HDIA.DSI 271.259 OT4P.DSI 5795.000 HTEN.I~LT 13.875 HDIA.MLT -999.250 MRES.CNT -999.2S0 RCFT.CNT -999. 250 TNPH.CNT -999.250 HTEN.LDT - 999. Z'SO LL. LDT -999.250 SSZ.LDT -999.250 QLS.LDT -999.250 DRHO.LDT -999.250 HTEN.EPT -999.250 FVRoEPT 11.308 HOIA.DTE 0.000 IMQF.DTE 79.656 IIXD.DTE 11.966 IlqPH.DTE 6.312 SP.DTE 5785.000 flTEN.DS! 11.308 HDIA.DSI 127.097 OT4P.DSI 5785.000 NTEN.MLT 11.308 HDIA.MLT -999.250 MRES.CNT -999.250 RCFT.CNT -999.250 0.000 4.730 12.697 -0.563 156Z.350 -999.250 80.867 1562.350 -999.250 .-999.250 -999.Z50 -999.250 -999.Z50 - 999.250 -999. ZSO -999.Z50 -999.Z50 -999.250 -999.250 -999.250 0.000 3.547 40.586 -0.750 1563.¢$3 -999. Z50 111o965 1563.453 -999.250 -999. Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -99 9.250 -999.250 -999.250 -999.250 0.000 5.70Z 10.306 -0.875 1555.772 -999.Z50 81.305 1556.77Z -999.250 -999.250 -999.250 TENS.DTE MTEM. DTE IIRM.OTE ILD.D'TE SPD.DTE NTEM.OSI PR.DSI OT4S.OSI MTEM.MLT G R. ML T MTEM.CNT RCNT.CNT NPHI.CNT MRESoLOT LU.LDT SS2.LOT pQSS.LDT D HI.LOT MRES. EPT GR.EPT TENS,. OTE MTEM. DTE IIRM. DTE ~LD.OTE SPD.OTE HTEM.OSI PR.DSI DT4S .OSI GR.MLT MTE~I.CNT RCNT.CNT NPHI.CNT NRES.LDT LU.LDT SSI.LOT QSS.LDT DPHI.LDT MRES.EPT GR.EPT TENS.OTE MTEN. DTE IIRM. OTE ILD.DTE SPD-DTE MTEM. OSI PR.DSI DT4S.DSI MTEM.MLT GR.MLT MTEM.CNT RCNT.CNT PAGE: 5865.000 150.525 74.661 13.¢22 124.819 150.525 0.309 148.548 150.525 59.121 -999.250 -999.250 -999.250 -999.250 -999.250 -999 -999.250 -999.250 -999.250 5795.000 .149.939 Z7.638 26.879 73.464 149.939 0.397 -999.250 149.939 45.872 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5785.000 149.609 93.042 11.516 58.539 149.609 0.154 -999.250 1~,9.609 4~1.996 -999.250 -999.250 LIS TAPE VERIFICATION LISTZNG .SCHLUMBERGER aLASKA COMPUTING CENTFR CFTC.CNT -999.250 CNTC.CNT GRoCNT -999.250 TENS.LOT MTEM.LDT -999.250 CA:LI.LOT LS.LOT -999. 250 LITH.~LOT LSHV.LDT -999.250 SSHV.LOT PEF.LDT -999.250 RHOS.LDT GR.LDT -999. 250 TENS. EPT MTENoEPT -999.250 NVR. EPT OEPT. 710:0.000 NCAL.DTE HTEN-OTE 1509.563 [DQF.DTE MRES.OTE -0.056 [[RD.D'TE I i'XM. OTE 9. 549 [DPH. OTE [L~I'"DT E 8.82! SFLU.OTE 6:R. OTE 79.~46: TENS.OS[ MAES.OS! -0.056 MCAL.OS[ DTRZ.OS[ [59.915 GR..OS[ 79.446 TENS.MLT MRES.MLT -0.056 flCaL.MLT 'T E~NS'CNT -999. ZSO HTEN.CNT TNRA.CNT -999.250 RTNR.CNT CFTC. CNT -999.2 50 CNTC.CNT GR-CNT -999.250 TENS.LOT MTEM.LOT -999.250 CRLI.LOT LS.LDT -999.250 L~TN.LOT LSHV.LOT -999.~5:0 SSHV-LDT PEF.LDT -999. 50 RHOB.LOT GR-LDT -999.250 TENS. EPT MTEM. EPT -999. 250 NVR.EPT DEPT. 7000.000 MCAL.D'TE HTEN. DTE 1596. 224 [DQF.OTE MRES.OTE -0.056 [[RO.OTE IIXM. OTE 5.428 IOPH.OTE ILM. DTE 13.229 SFLU.OTE GR.OTE 6&.49& TENS.OS[ MRESoDS[ -0.056 NCAL.OS[ DTR2.DS[ 1¢4.763 DTM2.OS! GR.DS! 64.494 TENS.MLT MRES,MLT -0.056 MCAL.NLT TENS.CNT -999. 250 HTEN.CNT TNRA.CNT -999.250 RTNR.CNT CFTC.CNT -999.250 CNTC.CNT GR.CNT -999.250 TENS.LOT MTE#.LDT -999.250 CaLI.LOT LS.LDT -999.250 L[TH.LDT LSHV.LDT -999.250 SSHV.LOT PEF.LDT -999.250 RHOB.LDT GR.LDT -999.250 TENS.EPT MTEM.EPT -999. 250 NVR.EPT DEPT. 6900.000 NCAL.DTE MTEN. DTE 1599.051 IDQF.OTE MRES.DTE -0.056 IIRD.DTE IIXM.DTE 12.198 IDPH.DTE 17-MAR-1992 18:17 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999. 250: -999.250 11.639 0.000 91.710 9.750 7.618 5 655" 000 I1.639 1¢9.153 5655.000 11 '63 9 -999. 250 -999. -999.250 -999. 250 -999.250 -999° 250 -999.250 - 99'9. Z 5 O -999. 250 -999.250 11.506 0.000 62.997 1¢. 340 8.504 5 855. 000 11.506 139.494 5855.§00 11.506 -999.250 -999.250 -999.250 -999.250 -999.250 -999,,250 -999.250 -999.250 -999.250 -999.250 13.478 0.000 112.083 8.214 TNPH. C NT HTEN.LDT L L. L O T SS1.LOT QL S. LDT ORHO.LOT HTEN.EPT FYR. E PT HO[A.DTE IMQF.DTE [IXO. DTE IMPH. DTE SP.OTE HTEN. 0 SI HOIA.OSI OT4P.OSI HTEN-MLT HO! . ML T MRE~.CNT RCFT.CNT T N PH ,, C NT HT EN. ~L 0 T LL.LDT SSI.LOT qL $. LOT ORHO.:L OT HTEN'EPT FYR. EP'T HDIa. DTE, ZNQF.OTE ZIXD. OTE ['MPH.OTE SP.OTE HTEN. DSZ HDIA.DSZ DT4P.DSZ HTEN.RLT MRES.CNT RCFT.CNT TNPH.CNT HT EN. LOT LL.LDT SS1.LDT QLS.LDT ORHO.LDT HTEN.EPT FVR.EPT HDIA.DTE IMQF.DTE Z[XO.DTE IMPH. DTE -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999.250 0.000 6.124 9.476 -1.125 150'9.563 -999.250 80-787 1509o563 -999.250 -999.250 -999..250 -99~ 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 4.989 12.429 -1.563 1596.224 -999,250 82.245 1596.224 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 9.328 7.991 NPHI.CNT MRES,.LO'T LU.LDT SS2.LDT S. LOT MRES.EPT GR.EPT TEN,S.OTE MTEM.OTE IIRM.OTE ILD.DTE SPO.OTE MTEMoOSI PR,OS! DT4S.DS! MTEM. MLT GR.MLT MTEH.CNT RC#'ToCNT NPHI.CNT MRES.LOT LU.LOT SSI.LOT ~SSoLDT OPHZ.LOT NRES.EPT GR.EPT TENS.DTE ~TEN.DTE [LD'OTE SPD.DTE MTEM.OSI PR.DSZ DT4S.OSI MTEM. MLT GR.NLT MTEMoCNT RCNT.CNT NPHI.CNT MRES.LDT LU.LDT SSZ.LDT QSS.LDT DPNI.LDT MRES.EPT GR.EPT TENS.DTE MTEM.OTE IIRM.DTE ILD.DTE PAGE: 25 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5655.000 148.502 107'.238 9.725 65.937 148 ' 502 0.292 105.3 94 148.502 79.4¢6 -999.250 '-999.250 -999.250 -999.250 -999 o 250 -999.250 -999.250 -999.250 -999'250 -999,,250 5855.000 148.241 71.687 14.221 71-742 148.241 O. 234 153. 595 148.241 64.494 -999.250 -999.250 -999.250 -999.250 -999.250 -999 -999.250 -999.250 -999..250 -999 5640.000 147.283 117.6~7 7.998 LIS TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER ILR.OTE 8.034 SFLU.OTE GRoDTE 70.610 TENS.OSI MRES,,.DSI -0.05.6 MCAL.OSI DTRZ. DS! 150.521 DTM2.OS! GR.OS[ 70.610 TENS.MLT MRESoML'T '-0.056 MCAL.MLT TENS.CNT -999.2S0 HTEN.CNT TNRA.CNT -999.250 RTNR.CNT CFTC.CNT -999.2.50 CNTC.CNT GR.CNT -999,250 TENS.LOT MTEM. LBT -999.250 CALi.LDT LS.LOT -999,.2.50 LITH.LOT L S H V. L D T - 9 99.2 ~ 0 S S HV. L O T PEFoLDT -999. 250 RHOB.LDT GRoLDT -999. 250 TENS.EPT MTEN. EPT -999.2. SO N VR. E PT DEPTo 6800.000 MCAL.DTE HTEN..OTE 1620.312 IDQF.DTE MRESoDTE -0.056 IXRD. OTE ZI~XN.oOTE 9.537 ]:OPH.DTE' r:]:LN,. OT E 7. 956 SFLU. OTE GR.OTE 76.059 TENS.DS1 MRES.OSI -0.056 MCAL.OSZ DTRZ.OSZ 162.270 OTMZ.OSZ GR.O:SI 76.059 TENS.MLT MRES.MLT -0.056 MC~L.MLT TE~S. CNT -999.250 HTEN'.CNT TNRR.CNT -999.250 RTNR.CNT CFTC.CNT -999.250 CNTC.CNT GR.CNT -999.250 TENS.LOT HTEM.LDT -999. 250 CALl. LOT LS.LOT -999.250 LXTfl. LDT LSHV.LDT -999.250 SSHV.LOT PEF.LDT -999. 250 RHOB.LOT GR.LDT -999. 250 TENS.EPT MTEM. EPT -999.2 50 NVR.EPT DEPT. 6700.000 MCAL.DTE HTEN..DTE 1540.109 ZOQF.OTE MRES.OTE -0.056 I]:'RD.DTE IIXMoDTE 1.616 IDPH.DTE ILM.DTE 19. 630 SFLU.OTE GR.DTE 58.342 TENS.DS]: MRES.DS! -0.056 MCAL.DS! DTRZ.DS[ 235.361 DTM2.OSI GR.O$I 58.362 TENS.MLT MRES.MLT -0.056 MCAL.MLT TENS.CNT -999.250 HTEN.CNT TNRA. CNT -999.250 RTNR.CNT CFTC.CNT -999.250 CNTC.CNT GR.CNT -999.250 TENS.LDT MTEM.LDT -999.250 CALI.LDT LS.LDT -999.250 LITH.LDT LSHV.LDT -999.250 SSHV.LDT 17-MAR-1992 18:17 6. 308 SP. TE 5640'000 HTEN.~SZ 13.478 HDIA.OSI 145.027 DT~P...DS! 5640.000. HTEN.#LT -999.250 MRES.CN'T -999.250 : RCFT.CNT -999.250 TNPH.CNT -999.250 HTEN. LDT - 999. Z 50 L.L.. LDT -999.250 SSloLOT -999. 250 QLS.LDT -999.250 ORNO'LDT -999.250 HTEN. EPT -999.250 FVR.EPT 13.6913 HO]:A.DTE 0.000 IHQF.DTE 10;,- 096 IIXD.OTE .363 IM PH.. DTE 8.278 SP.OTE 5705,,000 HTEN.OSI 13.693 HDIA.DSI 156.851 DT4P.DSI 5705.000 HTEN. MLT 13.693 HDIA. MLT -999.2'50 #RES. CNT -999. ZSO RCFT.CNT -999.250 TNPH. CNT -999.250 NTEN. LDT -999.250 LL.LDT -999.250 SS~.LDT -999.2S0 QLS,,LDT -999.250 DRHO.LOT -999.2S0 HTEN. EPT -999.250 FVR.EPT 13.312 HD]:A.DTE 0.000 ]:MQF.DTE 47.425 IIXD. DTE 19. 878 ZMPH.DTE 13.670 SP.DTE 5515.000 HTEN.DS! 13.312 HDIA.DST 225. 523 DT4P.DSZ 5515.000 HTEN. MLT 13.312 HD]:A.MLT -999.2:50 MRES.CNT -999.250 RCFT.CNT -999..250 TNPH. CNT -999.250 tlTEN.LOT -999.250 LL.LDT -999.250 SS1.LDT -999.250 QLS.LDT -1.875 1599'051 -999.250 76. Z 27 1599.051 -999.250 -999.250 -999.250 -999.250 -9:99.250 -999.250 -999. 250 -999.250 -999o250 -999.250 -999.250 -999.250 0.000 8.775 8.295 -2.188 1620.312 -999.250 80.809 1620'312 -9:99-250 -999.250 -999. ZSO -999.'250 -999'250 -999.o250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 0.036 17.679 -2.375 1540.109 -999.250 114.920 1540.109 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 SPO.OTE MTEM.OSI PR.OSI DT4S.OSI MTEM.MLT MTEM.CNT RCNT.CNT N P:H I. CNT MRES.LDT LUo LOT SS2.,LOT QSS.LO'T OPHI.LDT MRES.EPT GR,,EPT TENS.DTE MTEM, oDTE IIR~.DTE IL O. OT E SPOoOTE PR.OSI DT4S.OSI MTEM-HLT GR-MLT MT EH. CNT RCNT.CNT NPHI.CNT MRES.LOT LU.LOT SSZ.LOT QSS.LDT DPN]:.LDT MRES,,,EPT GR. EPT TENS.DTE MTEM.DTE IIRM.OTE ILO.DTE SPD.DTE MTEM.DSI PR.DSI DT~S.DSI MTEM.MLT GR.MLT MTEM.CNT RCNT.CNT NPHI.CNT MRES .LOT LU.LOT SS2.LDT QSS.LOT PAGE: 26 70.268 147.283 0.309 100.456 147.283 70.610 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5705.000 146.520 118.794 8.312 84.248 146.5Z0 0.319 15:4-660 146.520 76.059 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5515.000 145.740 48.392 19.363 42.768 145.740 0.325 138.591 145.7¢0 58.342 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS T~PE VERIFICATION LISTING SCHLU:XBERGER ALASK:A COMPUTING CENTER PEF.LDT -999.250 RHOB.LDT GR.LDT -999.250 TENS.EPT MTEM. EPT -999. 250 NVR.EPT DEPT. 6600.i000 MCAL.DTE HTEN.DTE 1513.909 MRES.DTE -0.057 I! O.OTE IIXR. OTE 7°246 IOPH.OTE ILI.OT~ IO.T6S SFLU.OTE GR.OTE T9.S63 TENS.OSI MRES.OSI -O,O~T MCAL.DSI OTR2.OSI 210.224 DTM2.OSI GR.OSI 79.563 TENS.MLT MRESoMLT -0.057 MCAL.MLT TENS.CNT -999.250 HTEN.CNT TNRA.CNT -999.250 RTNR.CNT CFTC.CNT -999. 250 CNTC.CNT GR.CNT -999. 250 TENS.LOT MTEMoLOT -999.250 CALI.LOT LS.LDT -999.250 LITH.LDT LSHV.LDT -999.250 SSHV.LDT PE'F.LDT -999. 250 RHO. B.LDT · GR.LDT -999.250 TENS-EPT MTEM. EPT -999. 250 NVR. EPT DEPT. 6500.000 MCA:L.DTE HTEfl. DTE 1510.781 IDOF.DTE MRES~,DTE -0.057 I[RO.DTE IIXN. OTE 10.002 IDPH.DTE ILM.DTE 7.052 SFLU.DTE GR.OTE 38.&52 TENS.DSI MRES.DSI -0.057 MCAL.DS! OTRZ.DSI 159.381 DTM2.DSI GR.O$I 38.452 TENS.MLT MRESoMLT -0.057 MCaL.MLT TENS.CNT -999.250 HTEN.CNT TNRAoCNT '-999.250 RTNR.CNT CFTC.CNT -999. 250 CNTC.CNT GR.CNT -999.250 TENS.LOT MTEMoLDT -999.250 CALIoLOT LS.LDT -999.250 LITM.LOT LSHV.LDT -999.250 SSHV.LDT PEFoLDT -999.250 RHOB.LDT GR.LDT -999.250 TENS.EPT MTEN.EPT -999. 250 NVRo EPT DEPT.. 6400. 000 flCAL.OTE HTEN. DTE 1501.801 IDQF.DTE MRES.DTE -0.057 IIRO.DTE IIXM.OTE 2.767 IDPH.DTE ILM. OTE 12. 861 SFLU.DTE GR.OTE 44.803 TENS.DSI MRES.DSI -0.057 MCAL.DSI OTR2.OSI 176.634 DTM2.OSI GR.DSI 44.803 TENS.HLT 1T-MaR-lOg2 18:17 -999.250 DRHO.LDT -999.250 HTEN.EPT -999.250 FVR. EPT 1Z.782 HOIA.OTE 0.000 [NQF OTE 78..¢37 IIXD:DTE 11.622 I~PH. OTE 10.079 SP.DTE 5370.000 HTEN.DSI 12.782 HDIA.OSI 2~00.406 OT4P. DS! 5370.000 HTEN.MLT 12.T82 HOI~o~LT -999.250 MRES.CNT -999.250 R'CFT.CNT -999.250 TNPH.CNT -999.250 ' HTEN.LDT -999.250 LLoLDT -999.250 SS1.LOT -9'99.250 QLS.LDT -999.25.0 DEN:O.LOT -999.250 HTENoEPT -999.250 FVR.EPT 10.960 HO-IA.DTE 0o000 iMQF.OTE 157o 848 IZXO.DTE 5. 554 ..I'HPH.OTE 8.005 SP.DTE 5370. 000 HTEN.OSI 10.960 H:D~A.DS! 152.959 OT4P.DS! 5370.000 HTE:N. MLT 10.960 HDIA.~LT -999'250 ~RES.CNT -999.250 RCFToCNT -999.250 TNPH.CNT -999.250 HTEN.LDT -999.250 LL.LDT -999.250 SS1.LOT -999.250 QLS.LDT -999.250 DRHO.LDT -999.250' HTEN.EPT -999.250 FYR. EPT 11.548 HDIA.DTE 0.000 IHQF.DTE 72.341 IIXD.DTE 12.713 [~PH.DTE 9.768 SP.DTE 5305.000 HTEN.DS! 11.548 HDIA.DSI 170.770 DT4P.OS! 5305.000 HTEN.MLT -999.250 -999.250 -999. 250 -999.250 0.000 2. 683 10.881 - 2.750 1513.909 -999. 250 97.557 1513.909 -999.ZS0 -999.250 -999.250 -999.. 250 -999.150 -999.250 -99'9.250 -999.150 -999.150 -999o150 -999.250 -999.250 0.000 1 9- 330 7.145 -3.063 1510.781 -999.250 86.322 1510.781 -999.150 -999.250 -999.150 -999. -999.250 -999,.250 -999.250 -999.250 -999.250 -999.150 -999.250 0.000 4.329 13.187 -3.188 1501.801 -999.250 86.624 1501.801 DPHI.LD~T MRES.EPT GR.EPT TENS.OTE NTEM.DTE IIRM.DTE ILO.DTE SPO. DTE MTEM.OSI PR.OS! DT4S.OS! MTEM.MLT GR.MLT MTEM. CNT RCNT.CNT NPH~.CNT H:RES.LDT LU.LDT SSI.LOT ~SS.LDT OPHI.LDT MRES. EPT GRoEPT TENS. OT E NTEN. OTE IIRN. DTE ILOoOTE SPO.OTE #TEM. DSI PR. OSI DT4S.DS! ~TEM. MLT GR.#LT MTEMoCNT RCNT.CNT NPNIoCNT MRES.LDT LU.LOT SSZ.LDT QSSoLDT OPHIoLDT MRES.EPT GR.EPT TENS.DTE MTEM. DTE IIRM.DTE ILD.DTE SPD.OTE MTEM.DSI PR.DSI DT4S.OSI MTEM.MLT PAGE: 27 -999.250 -999.250 -999.250 5370.000 145.529 87.993 11.344 aO.010 145.529 0.345 119.993 1&5.529 79.563 -999.250 -999.250 -999.250 -999.250 -999.250 -999..250 -999.250 -999.250 -999.25:0 -99'9.250 5370.000 133.869 5.479 17.482 144.748 0.266 150.609 144.748 38.452 -999.250 -999°250 -999.250 -999°150 -999.250 -999.250 -999 o 250 -999.250 -999.250 -999.250 5305.000 143.732 73.728 12.339 32.906 1¢3.732 0.327 159.680 1~3.732 LIs TAPE VERIFICATION LISTING SCHLUMBERGER ALASKA COMPUTING CENTER MRES.MLT -0.057 MCAL.MLT TENSoCNT -999.250 HTEN.CNT TNRA.CNT -999. 250 RTNR.CNT CFTC.CNT -999.250 CN'TC.CNT GR.CNT -9'99.250 TENS.LOT MTEM.LDT -999o ZSO CALI.LDT LS-LDT -999.250 LITHoLOT LSHV.LDT -999.250 SSHV.LOT PEF.LDT -999.250 RHOB.LOT GR.LDT -999. 250 TENS.EPT MTEM.EPT -999. 250 NVR.EPT DEPT. 6300.000 MCAL.OTE HTEN. OTE 153:8.622 IOQF.OTE M:RESoOTE -0.058 IZRO.DTE iZXM. OTE 5.096 ~DPH.DTE ILM-DTE 14-118 SFLU.DTE GR.DTE 33.038 TENS.DSZ MRES.OSI -0.058 MCAL. O'S! OTR2.OSI 139.3&3 GR.DSI 33.038 TENS.MLT MRES. MI~T -0.058 MCAL.MLT TENS.CNT -999. 250 HTEN.CNT TNRAo CNT -999. 250 RTNR.CNT CFTCoCNT -999. 250 CNTC-CNT GR.CNT -999.250 TENS.LOT MT'EN. LDT -999:.250 CALIo,LOT LS. LDT -999. 250 LZTN-LOT LSHV.LDT -999.250 SSHV.LOT PEF.LDT -999.250 RHOB.LOT GR.LDT -999.250 TENS-EPT MTEM.EPT -999. 250 NVR. EPT DEPT. 6200.000 MCAL.DTE HTEN. DTE 1574.332 IDQF.DTE MRES.OTE -0.058 IIRD.OTE IIXM.DTE 10.071 IDPH.DTE ILM.OTE 6.009 SFLU.DTE GRoDTE 79.241 TENS.DS! MRES.OSI -0.058 MCAL.DSI OTRZ. OSI 195.847 OTM2.0SI GR.DSI 79.241 TENS.MLT MRES.MLT -0.058 MCAL.NLT TENS.CNT -999.250 HTEN.CNT TNRA.CNT -999.250 RTNR.CNT CFTC.CNT -999.250 CNTC.CNT GR.CNT -999.250 TENS.LOT MTEM.LDT -999.250 CALI.LDT LS.LDT -999.250 LITH.LDT LSHV.LDT -999.250 SSHV.LDT PEF.LDT -999.250 RHOB.LDT GR.LDT -999.250 TENS.EPT MTEM.EPT -999. 250 NVR.EPT 17-MAR-1992 18:17 11.548 HDIA.MLT -999.250 MRES.CNT -999. 250 RCFT.CNT -999. 250 'TNPH. CNT -999.250 HTEN.LDT -999.250 LL.LOT -999.250 SS1.LOT -999. 250 QLS.LDT -999.250 DRHO.LOT -999. 250 HTEN. EPT -999.2'50 FWR.EPT 11.5151 HDIA.DTE 0.000 XMQF'DTE T 8.817 I ! XO. DT E 11.903 I#PH.OTE 12. I'50 SP.DTE 5 330.000 HTEN.DSI 11. 515 H'DZA. 134.918 DT4P.DS! 53300 000 HTEN'NLT 11. 515 HDZA. MLT -999.250 MRES.CNT -9990250 RCFT.CNT - 999.250 T N PN: C NT -999.250 HTEN LOT -999.250 LL.LDT -999. 250 SS1.LDT -999° 25:0 QLS-LOT - 999. 250 ORHD.LDT -999.250 HTEN. EPT -999.250 FVR.EPT 11.424 HDIA.OTE 0.000 IHQF.DTE 118.298 IZXO.DTE 7.481 ZMPH.DTE 4.683 SPoDTE 5360.0,00 HTEN.DS! 11.424 NDZA.DS! 186.251 DT4P.DSI 53600000 HTEN.MLT 11.424 HDIA.#LT -999.250 NRES.CNT -999.250 RCFT.CNT -999.250 TNPHoCNT -999. ZSO HTENoLDT -999.250 LL.LDT -999. 250 SS1.LOT ' -999.250 QLS.LDT -999.250 ORHO.LDT -999.250 NTENoEPT -999.250 FVR.EPT -999.250 -999.250 -999. 250 -999'250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0.000 8.0'02 I4.827 -3.250 1 538.6ZZ -999.250 79.020 1538.622 -999.250 -999.250 -999.250 -999.250 -99 90 250 -999.250 -999. ~ 0 -999.250 -9990250 -999.250 -999.250 0.000 7.724 6.146 -3.313 1574.332 -9990250 96.955 -99 ZSO -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999o250 -999.250 -999.250 -999.250 GR.MLT M'TEM. CNT RCNT.CNT NPHI.CNT MRES.LDT LUoLDT SSZ.LD'T Q SS. L D T DPHI. LOT M.R E S o EPT GR. EPT TENS.DTE MTEM-DTE IIRNoDTE ILO.DTE SPD.DTE MTEM. OSI PR.DSI DT4 S. DS I MTEM..MLT G R. ML T MT EM:. CNT RCNToCNT NPHI.CNT MRES.LOT LU.LOT S S 2 o LOT QSS.LDT OPHZ.LOT MRES.EPT GR.EPT TENS. DTE MTEM. OTE IIRM.DTE ILD.DTE SPD.OTE MTEM.OSI PR.DSI DT4S.DSI MTEN.MLT G R. MLT MTENoCNT RCNT.CNT NPHIoCNT MRES.LDT LU.LOT SS2.LOT QS 5. LOT OPHI.LDT MRES.EPT GR.EPT PAGE: 28 44.803 -999.250 -999.250 -999.250 -999.25:0 -999.250 .-999.250 -999.250 -999.250 -999.250 -999.250 5330.000 163.154 67.195 11.542 19.699 I43.154 0.239 157.204 143.I54 33.038: -999.250 -999.250 -999.250 -999.250 -999.250 -999. 50 -999, 50 -999.250 -999.250 -999.250 5360.000 142.952 156.854 7.339 38.338 142.952 0.314 -999.250 142.952 79.241 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS TAPE VERIFICATION LISTING S'CHL:UMBERGER A:LASKA COMPUTING CENTER DEPT. 6100.000 MCAL.DTE HTEN.DTE 1571.054 IOQF.O'TE MRES.OTE -0.058 IIRO.OTE IIXM'. OTE 7.642 IOPH.OTE MoOTE 11.033 SFLU.OTE I~R-OTE 76.765 TENS.OSI MRES.OSI -0.058 MCAL.OSI DTR2.0Si ~56.536 OTM2.OSI GR.OSI 76.T65 T~NS.MLT MRES.MLT -0.058 MCAL.MLT TENS.CNT -999.250 HT~N.CNT TNRA.CNT -999.250 RTNR'C~T CFTC.CNT -999.250 CNTC.CNT GR..CNT -999.250 TENS.LOT MTEM. LOT -999.250 CaLi.LOT LS.LDT -999. 250 LITH.LOT LSHV.LOT -999.250 SSHV.LOT PEF.LOT -999.250 RHOB.LOT GR.LDT -999. 250 TENS.EPT ~ MTEM.EPT -999. 250 NVR.EPT DEPTo 6000.000 MCAL.OTE HTENoDTE 1572o201 'IDQF.OTE MRES.OTE -0.058 IIROoDTE II~fl. OTE 10. 558 I§PH.OTE ILM. DTE 9.~96 SFLU.DTE GR.OTE 50. '59 TENS.OSI MRES.OSI -0°058 MCALoOSI OTR2.0SZ 15'8.820 OTM2.0S! GRoOSI 50.059 TENS.MLT MRES.MLT -0.058 MCAL.MLT TENSoCNT -999.250 HTEN.CNT TNRA.CNT -999.250 RTNR.CNT CFTC.CNT -999,,,250 CNTC.CNT GR.CNT -999.250 TENS.LOT MTEMoLDT -999.250 · CALI.LDT LS.LDT -999.250 LITHoLDT LSHV. LDT -999.250 SSHV.LDT PEF.LDT -999.250 RHOB.LDT GR.LDT -999.250 TENS.EPT MTEM. EPT -999° 250 NVR.EPT DEPT. 5900.000 MCAL.DTE HTEN. DTE 1565.645 ZOQF.DTE MRES.DTE -0.059 IIRD.DTE IIXM. DTE 5.443 IDPH.DTE ILM. OTE 10.517 SFLU.DTE GR. DTE 56.660 TENS.DSI MRESoOSI -0.059 RCAL.DS! DTR2.O$I 160. 386 DTMZ.OSI GR.OS! 56.660 TENSoMLT MRES.MLT -0.059 MCAL.I~LT TENSoCNT -999.250 HTEN.CNT TNRA.CNT -999. 250 RTNR.CNT 17-MAR-1992 18:17 11.150 0.000 83.438 10.950 7. 874 5275.000 11.150 148.599 5275°000 11.150 -999.250 -999°250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999'250 -999.250 9.411 O. O00 100.546 9.692 8.133 5150.000 9.411 152,o420 5150.000 9.411 -999°250 .-999.250 -999o250 -999.250 -999.250 -999. SO -999.150 -999.250 -999.250 -999°250 12.707 0.000 75.400 12.027 7.186 5065.000 12.707 155.574 5065.000 12.707 -999.250 -999.250 HOIA .OTE I-MQF. DTE IIXD. DTE IMPH.DTE SP.OTE HTEN.OS! OT.4P. D S ! HTEN.MLT HOIAoMLT MRES.CNT RCFT.CNT TNPHoCNT HT ENo L D T LLoLDT SS1.LDT GL S o L D T ORHO.L OT HTEN. EPT F'YR. EPT HOIA.DTE I Iq QF.' T E IIXD.~TE ZHPH. DTE SP.DTE HTEN..DS! HOIA.OSI DT4P. DSI HTEN'MLT HDIAoMLT MRES.CNT RCFT-CNT TNPHoCNT HTEN.LOT LL.LOT SSloLOT QLSoL'. OT DRHO.LDT HTEN. EPT Ft/R.EPT HDIA.DTE XXXDoDTE IMPH.DTE SPoDTE HTEN.O$I HDIA.OSI DT4P.OSI HTEN.MLT HOIA.MLT MRES.CNT RCFT.CNT -999°250 0.000 5.165 11.290 -3.125 1571.054 -999-250 81.395 1571,.o054 -999o250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9'99.250 -999.250 -999.250 -999.250 -999.250 O. 000 12.100 9.879 -2.875 157 Z o ZO 1 - 999.250 78°446 157 2.201 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 0o000 3.200 10.817 -2,.563 1 565,.645 -999.250 80.827 1565.645 -999.250 -999.250 -999.250 TENS.DTE MTEH.DTE tIR~I.OTE ILO.DTE SPD.DTE MTEM.OSI PR.DSI DT4S.OSI NTE~t. NLT GR. MLT MTE~q. CNT RCNT.CNT NPHI.CNT MRES.LDT LU.LDT SSZ,,LOT QSSoLDT OPHI. LOT MRESo EPT GRoEPT TENS. OTE MTElq. DT E IIRM. OTE ILD.OTE SPOoOTE MT E M.,,DS I 'PR.OS! DT4S.OSZ MTEM. MLT GR.MLT MTEMoCNT RCNToCNT NPHioCNT #RES.LOT LU.LOT SS2.LOT QSS.LOT OPHIoLOT MRES.EPT GR.EPT TENS.DTE MTEN. OTE IIRM.DTE SPD.DTE PR.DS! DT4S.DSI MTEtq. lqLT GR.IqLT f4TEM.CNT RCNT.CNT PAGE: 29 5275.000 142:.608 85.869 10.67'7 45.655 142.608 0.286 151.019 142.608 76.765 -999.250 -999°250 -999.250 -999.250 -999.250 -999-250 -999-250 -999o250 -999.250 -999.250 5150.000 141.914 9T. 627 9.430 43. 771 14.1.914 0 110,,661 141. 914 50.059 -999. 250 -99'9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5065.000 141.207 90.'055 12.000 82.620 141.207 0.315 -999.250 141.207 56.660 -999.250 -999.250 LIS TAPE VERIFICATION LZSTZNG SCHLUIqBERGER ALASKA COMPUTZNG CENTER CFTC.CNT -999.250 CNTC.CNT 6R.CNT -999. 250 TENS.LOT NTEN.LDT -999.2:50 CAL!.LOT LS.LDT -999.250 LITH.LOT LSHV.LDT -999.250 SSHV.LDT PEF.LDT -999.250 RHOB.LOT 6R.LDT -999.25.0 TENS.EPT MTEM. EPT -999.250 NVR.EPT DEPT. 5800.000 NCAL.OTE HTEN. DTE ! 536.273 ~OQF.OTE NRES.OTE -0.059 IIRO.OTE IIXM. OTE 2.490 IDPH.DTE [[M.OTE [~.[2Z SFLU.OTE GR,.OTE ~6.TT3 TENS.OS[ MRES.OSI -0.059 MCaL.DS[ OTR2.DSI ~T5.9,65 OTM2.DSI GR.OSi 46.7T3 TENS.MLT MRES.MLT -0' 059 MCRL. MLT TENS..CNT -999.250 MTEN.CNT TNRA.CNT -999.250 RTNR.CNT CFTC. CNT -999.2 50 CNTC .CNT ~R.CNT -999. 250 TENS.LOT MTEM. LDT -999. 250 CAL~.LDT LS.LDT -999.250 LITH.LDT LSHV.LDT -999. 250 SSHV.LDT PEF. LDT -999. 250 *GR.LOT -999.250 TENS.EPT MTEM'. EPT -999.250 NVR.EPT DEPT. 5700.000 MCAL.DTE HTENoDTE 1574.877 IOQF.DTE MRESoOTE -0.060 IIXM. DTE 3.617 [DPH.OTE [LM. OTE 27.381 SFLU.OTE GR.DTE 44-471 TENS.OS[ MRESoOS! -0.060 MCAL.DS[ DTRZ.DS[ 278.558 OTfl2.DS[ GR.OSI ~4.471 TENS.MLT MRES.MLT -0.060 MCAL.#LT TENS.CNT -999.250 HTEN.CNT TNRA.CNT -999.250 RTNR.CNT CFTC.CNT -999.250 CNTC.CNT GR.CNT -999. 250 TENS.LDT MTEN.LDT -999.250 CALl.LOT LS.LD? -999.250 L[TH.LDT LSHV.LDT -999.250 SSHVoLDT PEF.LOT -999.250 RHOB.LOT GR.LDT -9 99.250 TENS. EPT MTEM. EPT -999.250 NVR.EPT DEPT. 5600.000 MCALoDTE HTEN.DTE 1602.383 IDQF.DTE NRES. OTE -0.060 [[RO.DTE IIXM. OTE 9.592 [DPH.DTE 17'-MAR-1992.18:17 -999. 250 TNPH.CNT -999.250 -999.250 HTEN.LDT -999.Z50 -999. 250 LL.LDT -999.250 -999.250 SS1-LDT -999.250 - 999.25:0 OLS'LOT -999.250 -999.250 ORHO'LDT -999.250 -999.250 HTEN-EPT -999.250 -999.250 FVR.EPT -999.250 12.484 HDIA.OTE O. 000 IHQF.OTE 58.376 IIXD,. DTE 15.974 INPH. OTE 9.538 SP. DTE 5015-000 HTEN. OS[ 169.155 DT4P.DSI 5015.0,00 HT~N'MLT 12.~8& HDI:::A. NLT -999.250 MRES.CNT - 999. Z50 R CFT. C NT -999.250 TNPH'CNT -999. ZSO HTEN.LOT - 999. ZSO LL.LDT -999.250 SS1.LDT -999.Z50 : ~LS.LDT -999.250 DRHO.LOT -999. 250 HTEN~ ~PT -999. ZSO FVR-EPT 13.652 HOZA.DTE 0.000 29. 509 IZXO.OTE 43. 531 ~MPH.OTE 50. 111 SP-DTE 5095.000 HTEN.DS! 13.652 NOIA.OS! 267. OB2 DT4P 5 095.000 HTEN'#L T 13.652 HD/A.NLT -999.250 NRES.CNT -999.250 RCFT.CNT -999.250 TNPH.CNT -999. 250 HTEN. LDT -999.250 LL.LDT -999.250 SS1.LDT -999o250 QLS.LDT -999.250 ORHO.LOT -999.250 HTEN. EPT -999.250 FVR.EPT 14.008 HDIA.OTE 0.000 [MQF.OTE 122.802 IIXD.DTE 7.135 Z~PH.DTE -999.250 0..000 2.997 1,4o306 -2.250 1536o273 -999.250 87.452 1536o273 -999.250 - 999° 250 -999.250 -999.250 -999°250 -999.250 -999.250 - 99'9. Z 50 -999~.250 -999.250 -999o250 -999.250 0o000 2.554 33.605 -2.250 1574.877 -999.250 121.896 1574.877 -999.250 -999.250 -999.250 -999.250 -999.250 -999'250 -999.250 -999o250 -999.250 -999o250 -999.250 -999.250 0.000 8.326 6.589 NPH[.CNT HRES.LOT LU.LOT SS2oLDT. QSS.LDT OPH~.LOT MRES.EP'T GR.EPT TENS.OTE MTEM. OTE [IRM. DTE ILO.OTE SPO.DTE M'TEM.DS! DT4S.DS! HTEN.NLT GR.RLT MTEM'CNT RC#ToCNT NPH~oCNT #RES.LOT LU. LOT SS2.LDT QSS.LOT OPH[.LDT MRES.EPT GR.EPT TENS.DTE MTE~.DTE IIR~.OTE ~LD.DTE SPO.OTE NTE#.OS! 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CNT -999.250 CNTC.CNT GR.CNT -999. 250 TENS.LOT NTEM.LOT -999.250 CALZoiLOT LS,.LDT -999.250 LITH.LOT LSH'¥.LDT -999.250 SSHV.LOT PEF.LDT -999.250 RHO'8,.LDT GR.LOT -999.250 TENS.EPT MT EH. EPT -999.250 NYR.EPT DEPT. 5000.000 MCAL.OTE HTEN.DTE 1609.686 ZOQF.DTE MRES.DTE -0.062 IIRD..OTE IIXM. DTE 8.526 IOPH.OTE ILM.,DTE 5. 823 SFLU'DTE "GR.DTE 62.118 TENS.DS! tqRESoOS! -0.062 MCAL.DS! DT,R2. OSI 192.309 OTM2.0SI GRoOSi 62.118 TENS.NLT HRES.HLT -0.062 ~CAL.NLT TENS.CNT -999'250 HTEN.CNT TNRR.CNT -999.250 ~T~R.CNT CFTC.CNT -999.250 CNTC.CNT GR.CNT -999. 250 TENS.LOT HTEM. LOT -999.2S0 CaLI.LOT LS.LDT .-999.2 SO LZTH.LDT LSHV.LDT -999. 250 SSHV.LDT PEF.LOT -999.2S0 RHOB.LDT GR.LDT -999.2S0 TENS.EPT MTEM.EPT -999.250 NVR.EPT DEPT. 4900.000 MCAL.D'TE HTEN.OTE 1582.541 IOQF.DTE MRES.DTE -0.063 i[RD.DTE IIXN. DTE 9.234 [DPH.OTE ILM. DTE 4.788 SFLU.OTE GR.DTE 38.872 TENS.DS! MRES.DSI -0.063 HCaL.OS! OTR2.DSI 188.508 OTM2.DSI GRoD$I 38.872 TENS.MLT MRES.MLT -0.063 MCAL.MLT TENS.CNT -999.250 HTEN.CNT TNRAoCNT -999.250 RTNR.CNT CFTCoCNT -999.250 CNTC.CNT GR.CNT -999.250 TENS.LOT MTEM.LDT -999.250 CALT.LDT LS.LDT -999.250 LXTH.LDT LSHV.LDT -999.250 SSHV.LDT PEF.LDT -999. 250 RHOB.LOT GR.LDT -999.250 TENS.EPT MTEM.EPT -999.2 50 NYR.EPT 17-MAR-1992 18:17 12.036 HOZA.MLT -999.250 -99'9.250 MRES.CNT -999.250 -999.250 RCFT.CNT -999.250 -999..250 TNPH.CNT -999.250 -999.250 HTEN.LOT -999.250 -999..250 LL.LDT -999.250 -999.250 SSI.LOT -999.250 -999.250 OLS.LOT -99'9.250 -999.250 DRHO.LDT -99:9.250 -999.250 HTEN. EPT -999.250 -999.250 FVRoEPT -999.250 13.933 HDZAoDTE 0o000 133. 296 IIXD.DTE 6.47.4 IM~PH. DTE 4. 307 SP. D T E 47S0.000 HT'EN.DS! 13.933 HD~.A.DSZ 185.617 OT4P.DS~ 4750. 000 HTEN~MLT 13. 933 HDZA.,MLT -999. ~SO SS~*LOT -999.250 ORHO.LOT -999.250 HTEN. EPT -999.250 FVR-EPT 14. 157 HOZA.DTE 0.000 Z#QF. DTE 160.794 ZZXD.DTE 5°477 Z~4PH.DTE 3.089 SP.DTE 4535.000 HTEN. 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