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Home My WebLink About171-029Nolan 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: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API # PTD # Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' 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: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' 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: 1/21/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260121 Well API # PTD # Log Date Log Company Log Type AOGCC E-Set# BCU 16RD 50133205540100 207125 12/3/2025 AK E-LINE PPROF T41253 BRU 211-35 50283201890000 223050 11/7/2025 AK E-LINE Perf T41254 BRU 213-26 50283201920000 223069 11/23/2025 AK E-LINE Perf T41255 BRU 213-26T 50283202040000 225038 11/4/2025 AK E-LINE Perf T41256 BRU 241-34S 50283201980000 224077 11/9/2025 AK E-LINE Perf T41257 BRU 241-34T 50283201810000 220052 11/6/2025 AK E-LINE Perf T41258 BRU 244-27 50283201850000 222038 12/13/2025 AK E-LINE Perf T41259 BRU 244-27 50283201850000 222038 12/19/2025 AK E-LINE StripGun T41259 GP ST 17586 9 50733204480000 193062 11/13/2025 AK E-LINE Perf T41260 IRU 241-01 50283201840000 221076 12/21/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/30/2025 AK E-LINE Perf T41261 IRU 241-01 50283201840000 221076 12/16/2025 AK E-LINE Plug T41261 IRU 241-01 50283201840000 221076 11/26/2025 AK E-LINE Plug/Perf T41261 KALOTSA 01 50133206570000 216132 11/19/2025 AK E-LINE Perf T41262 KBU 31-18 50133206490000 215024 11/8/2025 AK E-LINE Drift/PPROF T41263 KU 12-17 50133205770000 208089 11/14/2025 AK E-LINE StimGun T41264 LRU C-01RD 50283200610100 201168 11/27/2025 AK E-LINE RCT/Perf T41265 MPI 2-32 50029220840000 190119 12/10/2025 AK E-LINE LDL T41266 MPI 2-38 50029220900000 190129 12/5/2025 AK E-LINE LDL T41267 MPU H-16 50029232270000 204190 12/3/2025 AK E-LINE CBL T41268 MPU H-16 50029232270000 204190 11/19/2025 AK E-LINE TubingCut T41268 MPU I-14 50029232140000 204119 11/13/2025 AK E-LINE CBL T41269 NCIU A-06A 50883200260100 225071 11/28/2025 AK E-LINE Perf/Plug T41270 NCIU A-08 50883200280000 169063 12/2/2025 AK E-LINE GPT T41271 NCIU A-19 50883201940000 224026 12/16/2025 AK E-LINE GPT T41272 NCIU A-19 50883201940000 224026 12/12/2025 AK E-LINE GPT/Perf/Plug T41272 NCIU A-19 50883201940000 224026 12/17/2025 AK E-LINE Perf T41272 NCIU A-21A 50883201990100 225075 12/30/2025 AK E-LINE PPROF T41273 OP19-T1N 50029234910000 213068 11/19/2025 AK E-LINE TubingPunch T41274 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:35 -09'00' 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: PCU D-10 50283202080000 225082 12/9/2025 AK E-LINE Perf T41275 SCU 322C-04 50133101040100 215217 12/4/2025 AK E-LINE TubingPunch T41276 SRU 222-33 50133207150000 223100 12/7/2025 AK E-LINE Plug T41277 SU 43-10 50133207390000 225107 11/26/2025 AK E-LINE CBL T41278 TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf T41279 TBU D-24A 50733202240100 174064 12/2/2025 AK E-LINE TubingPunch T41280 TBU D-24A 50733202240100 174064 11/21/2025 AK E-LINE TubingPunch T41280 TBU M-10 50733205880000 209154 11/15/2025 AK E-LINE Perf T41281 Please include current contact information if different from above. TBU A-12RD 50733200760100 171029 11/29/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.01.21 13:56:51 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 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): 8,473 6,745 Casing Collapse Structural Conductor Surface 1,540psi Intermediate 3,810psi Production 10,750psi Liner 7,020psi 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 Trading Bay Middle Kenai B Oil Same 6,085 5,910 4,050 883psi 6695 & 6020 PRESENT WELL CONDITION SUMMARY CO 93B 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: AOGCC USE ONLY 8,160psi 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 ADL0018731 171-029 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20076-01-00 Hilcorp Alaska, LLC Trading Bay St A-12RD Length Size Proposed Pools: L-80 TVD Burst 4,735 11,640psi MD 6,330psi 3,090psi 264' 1,061' 5,186' 264' 1,066' 20" 13-3/8" 264' 9-5/8"7,490' 1,066' 7,490' 4,747 - 5,324 7,261' 7" 3,412 - 3,727 5,002'7" Other: 10/20/2025 8,468'1,207' 2-7/8" 6,081' See schematic See schematic 7,261' Perforation Depth MD (ft): 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 9:10 am, Oct 07, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.10.07 05:47:02 - 08'00' Dan Marlowe (1267) 325-606 A.Dewhurst 10OCT25MGR22OCT25 DSR-10/10/25 10-404 10/23/25 Monopod A-12RD Add and Re-perf Page 1 of 2 Well Name:TBF-A-12RD API Number:50-733-20076-01-00 Current Status:Online, Producer Permit to Drill Number:171-029 Estimated Start Date:10/20/25 Rig:Eline 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:1,224 psi at 3,417 TVD. A-22 SBHPS 07/08/2025 MPSP:883 psi (Based on 0.1 psi/ft. gas gradient) Last Shut-in WHP:278 psi Min. ID:2.25 2-7/8 XN nipple Max. Deviation:60.5 at 3,221 md Field:Trading Bay Pool:Middle Kenai B Oil Pool Brief Well Summary: A-12RD was worked over in March, 2025. The well was converted from a C/D zone injector into a B zone producer. The initial rate was disappointing at 53 bfpd, 47% water cut. The well has declined to ~ 8 bfpd on the last test. A pressure survey was conducted in June 2025 which showed extremely low inflow, and the pressure was still building after 2 weeks shut-in and was 590-psi. The pressure survey indicated the possibility of severe skin damage. The reservoir pressure prediction for the B zone is ± 1,200 psi. This pressure was confirmed with a SBHP in A-22 LS (B 31-8,33-6 sands) in 7/2025. Objective: Eline re-perforate Middle Kenai B 31-8, 33-6, 41-8 sands. Add perforations in the 40-4 sand. Monopod A-12RD Add and Re-perf Page 2 of 2 Eline: 1. MIRU Eline on A-12RD. 2. Pressure test PCE to 250 psi low / 2,500 psi high. 3. Perforate the target Middle Kenai B sand intervals between a top at 4,748 MD / 3,412 TVD and a bottom at 5,329 MD / 3,729 TVD. a. All perforations in the Trading Bay field Middle Kenai B Oil Pool. b. All runs will be fully lubricated. 4. RDMO Eline. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated by: JLL 03/20/25 SCHEMATIC Trading Bay Unit Well # A-12RD API: 50-733-20076-01-00 PTD: 171-029 Completed: 03/08/25 PBTD = 5,910 TD = 8,475 HOLE ANGLE thru Interval = 40.7 RKB to MSL = 101, MSL to Mudline = 66 1 2 7261 50-3 51-6 CZNS6 3 C-5 C-4 4 C-7 C-7 C-2 47-5 47-5 47-5 C-1 8 C-7 6 7 XN 5 DV Collar @ 2010 D Zone DV Collar @ 3,982 Middle Kenai B CASING AND TUBING DETAIL SIZE WT GRAD E CONN ID TOP BTM. 20 Conductor Weld Surf ~264 13-3/8 61 J-55 Butt 12.515 Surf 1066 9-5/8 43.5 N-80 Butt 8.755 Surf 7490 7 32 P-110 X-line 6.094 7261 8468 Tie Back 7 29 N-80 Butt 6.184 Surf 7261 Tubing Detail: 2-7/8 6.5 L-80 8RD EUE Surf 4,735 Milled out of casing somewhere between 6,771 6,787 on 1/30/2015 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt Accum SPF Last Perf Date Present Condition MKB 31-8 4,747 4,827 3,412 3,455 80 5 03/07/25 Open MKB 33-6 4,888 5,013 3,489 3,557 125 5 03/07/25 Open MKB 41-8 5,237 5,324 3,679 3,727 87 5 03/07/25 Open Isolated Perforation Details on Page 2 Jewelry Detail NO.Depth (MD) Depth (TVD)ID OD Item 38.15 38.15 Tubing Hanger 1 310 310 HES NE Tubing Retrievable SSSV 2 2,047 1,903 2.347 4.750 2-7/8 GLM, with 1 DGLV loaded 3,788 2,883 2.347 4.750 2-7/8 GLM, with 1 DGLV loaded 4,629 3,347 2.347 4.750 2-7/8 GLM, with 1 DGLV loaded 3 4,677 3,373 DHL Retrievable Packer 4 4,727 3,401 2.250 2.875 XN Nipple 5 4,735 3,405 WLEG 6 6,020 4,111 7 Cement Retainer (TOC 5,910) 7 6,040 4,122 3.990 5.870 Tri-Point Hydraulic Set Liner Top Packer 8 6,695 4,561 CIBP Cement Details 13 3/8Cemented to surface with 1200 sk Class G. 300 cu ft of returns to surface.ToC at surface. 9 5/8 Cemented to surface on 3/9/1972 through the casing shoe with 650 sk Class G cement with 8% gel and 250 sk Class G, and 870 sk through DV collar. Approximately 535 cu.ft. of cement returns noted in drilling report.ToC at surface. 7 Liner Cemented with 200 sk Class G with 1% CFR-2. Liner lap squeezed with 200 sk Class G with 1% CFR- 2. Squeezed 100 sk Class G with 1% CFR-2 into punches from 7,521' - 7,522' and 7,700' - 7,701'. Squeezed 50 sk Class G with 1% CFR-2 into perforations at 7,092' - 7,122'. 7 Tie Back Cemented to surface with 1,400 sk Class G during Nov. / Dec. 1972 RWO. Good cement returns noted in drilling report.ToC at surface. Fish Details 6,745Baker Model F Packer. Milled & pushed downhole. 1/1/15 Updated by: JLL 03/20/25 SCHEMATIC Trading Bay Unit Well # A-12RD API: 50-733-20076-01-00 PTD: 171-029 Completed: 03/08/25 ISOLATED PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt Accum SPF Last Perf Date Present Condition C-1 6,158' 6,183' 4,197' 4,207' 25' 6 01/31/15 Isolated (3/4/25) C-2 6,238' 6,314' 4,239' 4,286' 76' 6 01/31/15 Isolated (3/4/25) CZNS6 6,404' 6,418' 4,349' 4,359' 14' 6 01/31/15 Isolated (3/4/25) C-4 6,444' 6,470' 4,377' 4,395' 26' 6 01/31/15 Isolated (3/4/25) C-5 6,528' 6,634' 4,436' 4,515' 108' 6 01/31/15 Isolated (3/4/25) C-7 6,811' 6,851' 4,650' 4,680' 40' 2 12/5/1972 Isolated C-7 6,886' 6,926' 4,707' 4,738' 40' 2 12/5/1972 Isolated C-7 6,960' 6,980' 4,764' 4,780' 20' 2 12/4/1972 Isolated 47-5 7,092' 7,122' 4,868' 4,892' 30' 2 12/4/1972 Isolated 47-5 7,102' 7,122' 4,876' 4,892' 20' 2 3/27/1972 Isolated w/ tie back liner ran on 12/1/72 47-5 7,160' 7,180' 4,922' 4,938' 20' 4 12/4/1972 Isolated 50-3 7,514' 7,520' 5,207' 5,212' 6' 2 3/26/1972 Isolated 7,521' 7,522' 5,213' 5,213' 1' 8 3/19/1972 Cmt sqz'd f/ bond 7,700' 7,701' 5,367' 5,368' 1' 4 3/17/1972 Cmt sqz'd f/ bond 51-6 7,715' 7,721' 5,380' 5,385' 6' 2 3/26/1972 Isolated 51-6 7,732' 7,740' 5,395' 5,402' 8' 2 3/26/1972 Isolated Updated by: EPD 10/02/25 PROPOSED SCHEMATIC Trading Bay Unit Well # A-12RD API: 50-733-20076-01-00 PTD: 171-029 Completed: 03/08/25 PBTD = 5,910 TD = 8,475 HOLE ANGLE thru Interval = 40.7 RKB to MSL = 101, MSL to Mudline = 66 1 2 7261 50-3 51-6 CZNS6 3 C-5 C-4 4 C-7 C-7 C-2 47-5 47-5 47-5 C-1 8 C-7 6 7 XN 5 DV Collar @ 2010 D Zone DV Collar @ 3,982 Middle Kenai B CASING AND TUBING DETAIL SIZE WT GRAD E CONN ID TOP BTM. 20 Conductor Weld Surf ~264 13-3/8 61 J-55 Butt 12.515 Surf 1066 9-5/8 43.5 N-80 Butt 8.755 Surf 7490 7 32 P-110 X-line 6.094 7261 8468 Tie Back 7 29 N-80 Butt 6.184 Surf 7261 Tubing Detail: 2-7/8 6.5 L-80 8RD EUE Surf 4,735 Milled out of casing somewhere between 6,771 6,787 on 1/30/2015 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt Accum SPF Last Perf Date Present Condition MKB 31-8 4,747 4,827 3,412 3,455 80 5 03/07/25 Open, Reperf MKB 33-6 4,887 5,013 3,489 3,557 125 5 03/07/25 Open, Reperf MKB 40-4 5,072 5,105 3,590 3,608 33 5 TBD MKB 41-8 5,237 5,329 3,679 3,729 92 5 03/07/25 Open, Reperf Isolated Perforation Details on Page 2 Jewelry Detail NO.Depth (MD) Depth (TVD)ID OD Item 38.15 38.15 Tubing Hanger 1 310 310 HES NE Tubing Retrievable SSSV 2 2,047 1,903 2.347 4.750 2-7/8 GLM, with 1 DGLV loaded 3,788 2,883 2.347 4.750 2-7/8 GLM, with 1 DGLV loaded 4,629 3,347 2.347 4.750 2-7/8 GLM, with 1 DGLV loaded 3 4,677 3,373 DHL Retrievable Packer 4 4,727 3,401 2.250 2.875 XN Nipple 5 4,735 3,405 WLEG 6 6,020 4,111 7 Cement Retainer (TOC 5,910) 7 6,040 4,122 3.990 5.870 Tri-Point Hydraulic Set Liner Top Packer 8 6,695 4,561 CIBP Cement Details 13 3/8Cemented to surface with 1200 sk Class G. 300 cu ft of returns to surface.ToC at surface. 9 5/8 Cemented to surface on 3/9/1972 through the casing shoe with 650 sk Class G cement with 8% gel and 250 sk Class G, and 870 sk through DV collar. Approximately 535 cu.ft. of cement returns noted in drilling report.ToC at surface. 7 Liner Cemented with 200 sk Class G with 1% CFR-2. Liner lap squeezed with 200 sk Class G with 1% CFR- 2. Squeezed 100 sk Class G with 1% CFR-2 into punches from 7,521' - 7,522' and 7,700' - 7,701'. Squeezed 50 sk Class G with 1% CFR-2 into perforations at 7,092' - 7,122'. 7 Tie Back Cemented to surface with 1,400 sk Class G during Nov. / Dec. 1972 RWO. Good cement returns noted in drilling report.ToC at surface. Fish Details 6,745Baker Model F Packer. Milled & pushed downhole. 1/1/15 Updated by: EPD 10/02/25 PROPOSED SCHEMATIC Trading Bay Unit Well # A-12RD API: 50-733-20076-01-00 PTD: 171-029 Completed: 03/08/25 ISOLATED PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt Accum SPF Last Perf Date Present Condition C-1 6,158' 6,183' 4,197' 4,207' 25' 6 01/31/15 Isolated (3/4/25) C-2 6,238' 6,314' 4,239' 4,286' 76' 6 01/31/15 Isolated (3/4/25) CZNS6 6,404' 6,418' 4,349' 4,359' 14' 6 01/31/15 Isolated (3/4/25) C-4 6,444' 6,470' 4,377' 4,395' 26' 6 01/31/15 Isolated (3/4/25) C-5 6,528' 6,634' 4,436' 4,515' 108' 6 01/31/15 Isolated (3/4/25) C-7 6,811' 6,851' 4,650' 4,680' 40' 2 12/5/1972 Isolated C-7 6,886' 6,926' 4,707' 4,738' 40' 2 12/5/1972 Isolated C-7 6,960' 6,980' 4,764' 4,780' 20' 2 12/4/1972 Isolated 47-5 7,092' 7,122' 4,868' 4,892' 30' 2 12/4/1972 Isolated 47-5 7,102' 7,122' 4,876' 4,892' 20' 2 3/27/1972 Isolated w/ tie back liner ran on 12/1/72 47-5 7,160' 7,180' 4,922' 4,938' 20' 4 12/4/1972 Isolated 50-3 7,514' 7,520' 5,207' 5,212' 6' 2 3/26/1972 Isolated 7,521' 7,522' 5,213' 5,213' 1' 8 3/19/1972 Cmt sqz'd f/ bond 7,700' 7,701' 5,367' 5,368' 1' 4 3/17/1972 Cmt sqz'd f/ bond 51-6 7,715' 7,721' 5,380' 5,385' 6' 2 3/26/1972 Isolated 51-6 7,732' 7,740' 5,395' 5,402' 8' 2 3/26/1972 Isolated 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Converted to Producer Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 8,473 feet 6,695 & 6,020 feet true vertical 6,085 feet 6,745 feet Effective Depth measured 5,910 feet See schematic feet true vertical 4,050 feet See schematic feet Perforation depth Measured depth 4,747 - 5,324 feet True Vertical depth 3,412 - 3,727 feet Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80 4,735 (MD) 3,405 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: Middle Kenai B Oil 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 3,810psi 10,750psi 3,090psi 6,330psi 11,640psi 1,066 1,061 Burst Collapse 1,540psi measured TVD Production Liner 7,490 7,261 1,207 Casing Structural 5,186 5,002 7" 7,490 7,261 8,468 6,081 264 1,066 264Conductor Surface Intermediate 20" 13-3/8" 9-5/8" 8,160psi 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 171-029 50-733-20076-01-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018731 Trading Bay / Middle Kenai B Oil Trading Bay St A-12RD Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 32 Gas-Mcf MD N/A 1460 Size 264 951615 0 14000 77 325-049 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Eric Dickerman Eric.Dickerman@hilcorp.com 907-564-4061Operations Manager N/A Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 4:07 pm, Apr 08, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.04.08 14:28:29 - 08'00' Dan Marlowe (1267) RBDMS JSB 041025 DSR-4/11/25 CDW 04/09/2025 Updated by: JLL 03/20/25 SCHEMATIC Trading Bay Unit Well # A-12RD API: 50-733-20076-01-00 PTD: 171-029 Completed: 03/08/25 PBTD = 5,910’ TD = 8,475’ HOLE ANGLE thru Interval = 40.7q RKB to MSL = 101’, MSL to Mudline = 66’ 1 2 7261’ 50-3 51-6 CZNS6 3 C-5 C-4 4 C-7 C-7 C-2 47-5 47-5 47-5 C-1 8 C-7 6 7 XN 5 DV Collar @ 2010’ D Zone DV Collar @ 3,982’ Middle Kenai B CASING AND TUBING DETAIL SIZE WT GRAD E CONN ID TOP BTM. 20” Conductor Weld Surf ~264’ 13-3/8” 61 J-55 Butt 12.515” Surf 1066’ 9-5/8” 43.5 N-80 Butt 8.755” Surf 7490’ 7” 32 P-110 X-line 6.094” 7261’ 8468’ Tie Back 7” 29 N-80 Butt 6.184” Surf 7261’ Tubing Detail: 2-7/8” 6.5 L-80 8RD EUE Surf 4,735’ Milled out of casing somewhere between 6,771’ – 6,787’ on 1/30/2015 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt Accum SPF Last Perf Date Present Condition MKB 31-8 4,747’ 4,827’ 3,412’ 3,455’ 80’ 5 03/07/25 Open MKB 33-6 4,888’ 5,013’ 3,489’ 3,557’ 125’ 5 03/07/25 Open MKB 41-8 5,237’ 5,324’ 3,679’ 3,727’ 87’ 5 03/07/25 Open Isolated Perforation Details on Page 2 Jewelry Detail NO.Depth (MD) Depth (TVD)ID OD Item 38.15’ 38.15’ Tubing Hanger 1 310’ 310’ HES NE Tubing Retrievable SSSV 2 2,047’ 1,903’ 2.347 4.750 2-7/8” GLM, with 1” DGLV loaded 3,788’ 2,883’ 2.347 4.750 2-7/8” GLM, with 1” DGLV loaded 4,629’ 3,347’ 2.347 4.750 2-7/8” GLM, with 1” DGLV loaded 3 4,677’ 3,373’ DHL Retrievable Packer 4 4,727’ 3,401’ 2.250 2.875 XN Nipple 5 4,735’ 3,405’ WLEG 6 6,020’ 4,111’ 7” Cement Retainer –(TOC 5,910’) 7 6,040’ 4,122’ 3.990” 5.870” Tri-Point Hydraulic Set Liner Top Packer 8 6,695’ 4,561’ CIBP Cement Details 13 3/8”Cemented to surface with 1200 sk Class G. 300 cu ft of returns to surface.ToC at surface. 9 5/8” Cemented to surface on 3/9/1972 through the casing shoe with 650 sk Class G cement with 8% gel and 250 sk Class G, and 870 sk through DV collar. Approximately 535 cu.ft. of cement returns noted in drilling report.ToC at surface. 7” Liner Cemented with 200 sk Class G with 1% CFR-2. Liner lap squeezed with 200 sk Class G with 1% CFR- 2. Squeezed 100 sk Class G with 1% CFR-2 into punches from 7,521' - 7,522' and 7,700' - 7,701'. Squeezed 50 sk Class G with 1% CFR-2 into perforations at 7,092' - 7,122'. 7” Tie Back Cemented to surface with 1,400 sk Class G during Nov. / Dec. 1972 RWO. Good cement returns noted in drilling report.ToC at surface. Fish Details 6,745’Baker Model F Packer. Milled & pushed downhole. 1/1/15 Updated by: JLL 03/20/25 SCHEMATIC Trading Bay Unit Well # A-12RD API: 50-733-20076-01-00 PTD: 171-029 Completed: 03/08/25 ISOLATED PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt Accum SPF Last Perf Date Present Condition C-1 6,158' 6,183' 4,197' 4,207' 25' 6 01/31/15 Isolated (3/4/25) C-2 6,238' 6,314' 4,239' 4,286' 76' 6 01/31/15 Isolated (3/4/25) CZNS6 6,404' 6,418' 4,349' 4,359' 14' 6 01/31/15 Isolated (3/4/25) C-4 6,444' 6,470' 4,377' 4,395' 26' 6 01/31/15 Isolated (3/4/25) C-5 6,528' 6,634' 4,436' 4,515' 108' 6 01/31/15 Isolated (3/4/25) C-7 6,811' 6,851' 4,650' 4,680' 40' 2 12/5/1972 Isolated C-7 6,886' 6,926' 4,707' 4,738' 40' 2 12/5/1972 Isolated C-7 6,960' 6,980' 4,764' 4,780' 20' 2 12/4/1972 Isolated 47-5 7,092' 7,122' 4,868' 4,892' 30' 2 12/4/1972 Isolated 47-5 7,102' 7,122' 4,876' 4,892' 20' 2 3/27/1972 Isolated w/ tie back liner ran on 12/1/72 47-5 7,160' 7,180' 4,922' 4,938' 20' 4 12/4/1972 Isolated 50-3 7,514' 7,520' 5,207' 5,212' 6' 2 3/26/1972 Isolated 7,521' 7,522' 5,213' 5,213' 1' 8 3/19/1972 Cmt sqz'd f/ bond 7,700' 7,701' 5,367' 5,368' 1' 4 3/17/1972 Cmt sqz'd f/ bond 51-6 7,715' 7,721' 5,380' 5,385' 6' 2 3/26/1972 Isolated 51-6 7,732' 7,740' 5,395' 5,402' 8' 2 3/26/1972 Isolated Page 1/2 Well Name: TBF A-12RD Report Printed: 4/8/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Wellbore API/UWI:50733200760100 Field Name:Trading Bay Field State/Province:ALASKA Permit to Drill (PTD) #:171029 Sundry #:325-049 Rig Name/No:56 Jobs Actual Start Date:2/23/2025 End Date: Report Number 1 Report Start Date 2/23/2025 Report End Date 2/24/2025 Last 24hr Summary Start new well. R/D off A-13 and prepare to MOB. MOB 11' north and 9' east to A-12. Begin R/U and build kill mud. SICP: 460 psi SITP: 460 psi Report Number 2 Report Start Date 2/24/2025 Report End Date 2/25/2025 Last 24hr Summary Build 11 ppg KMW (approval to attempt kill with 11 ppg mud per Bryan McLellan). Continue to R/U from MOB. R/U E-Line and PT to 250 psi low / 2500 psi high. Make GR, logging run and tbg punch tbg at 6000'. Report Number 3 Report Start Date 2/25/2025 Report End Date 2/26/2025 Last 24hr Summary Build and condition 11 ppg KMW. Attempt to bullhead 11 ppg KMW, no success. Perform 2nd circulation of drillers method with 11 ppg KMW. Weight up and condition mud. Report Number 4 Report Start Date 2/26/2025 Report End Date 2/27/2025 Last 24hr Summary Increased mud weight in active to 11.1 ppg. Circulate 4 times, surface to surface holding 500 psi back pressure on choke. 10.9 ppg mud weight in/out. Shut in well and monitor pressure. Clean and organize rig. Clean reserve pit. Wait on boat for more mud chemicals. Continue to monitor pressure. SITP: 190 psi SICP: 165 psi. Report Number 5 Report Start Date 2/27/2025 Report End Date 2/28/2025 Last 24hr Summary Build and circulate 12.2 ppg KMW. Build and circulate 12.4 ppg trip margin mud. Monitor pressure. Pressure continues to increase. Report Number 6 Report Start Date 2/28/2025 Report End Date 3/1/2025 Last 24hr Summary Weight up 12.4 ppg mud to 13.1 ppg while circulating. Circulated an additional 3 surface-to-surface. MW in and out 13.1 ppg. Shut down and monitored pressure. Confirmed well dead. R/D high pressure lines. Set BPV. N/D production tree. N/U BOP. Report Number 7 Report Start Date 3/1/2025 Report End Date 3/2/2025 Last 24hr Summary Finish BOP N/U. R/U and Test BOP to 250 psi low / 3000 psi high as per Sundry 325-049. Witness waived by Jim Regg. Pull blanking plug and BPV. Pull hanger and L/D. Circulate surface to surface. Report Number 8 Report Start Date 3/2/2025 Report End Date 3/3/2025 Last 24hr Summary Circulated and Conditioned mud for 13 ppg in/out with 50 viscosity. L/D 4 ½” completion tubing. Service rig. Slip and cut drill line. P/U cleanout BHA and TIH. Report Number 9 Report Start Date 3/3/2025 Report End Date 3/4/2025 Last 24hr Summary TIH with Cleanout BHA #1 to 6032’. Circulate and Condition well. TOH and L/D BHA #1. P/U and TIH with cement retainer. Set cement retainer @ 6020’. Established injection rates @ .5 bpm w/2000psi, 1 bpm w/2300psi and 1.5 bpm w/2500psi. Rigged up for cement job. Report Number 10 Report Start Date 3/4/2025 Report End Date 3/5/2025 Last 24hr Summary Performed cement squeeze/job. Pumped 26.6 bbl of 15.3 ppg cement through retainer and spot 5.9 bbl of 15.3 ppg cement on top of retainer. POOH to 5643’. Pumped wiper ball and circulated surface-to-surface. TOH and L/D cement stinger. P/U and TIH with cleanout BHA #3. Circulated @ 5521’ while WOC. TIH and tag @ 5680’. Wash down to 5890’. Report Number 11 Report Start Date 3/5/2025 Report End Date 3/6/2025 Last 24hr Summary Wash down to 5910’ and tag cement w/5K. Circulate 2 btm up. Perform casing pretest. Reverse circulate and displace 13+ ppg mud with 3% KCl. Monitor bbl in/out. Good displacement. Perform casing test to 2200 psi for 30 minutes. Good test. Clean Rig circulating system of WBM. Report Number 12 Report Start Date 3/6/2025 Report End Date 3/7/2025 Last 24hr Summary Finished cleaning rig circulating system. Circulated 2 btms up with clean 3% KCl. TOH from 5866’ and L/D BHA #3. Washed out BOPs. P/U and began TIH with TCP guns. Report Number 13 Report Start Date 3/7/2025 Report End Date 3/8/2025 Last 24hr Summary TIH with 4-1/2" 5SPF DP TCP Assembly as per Tripoint running procedure to 5342’. R/U and RIH with E-Line to correlate perforation depths. Confirmed depth with office. Drop ball and fire guns. Perforated F/5324’ – T/5237’, F/5013’ – T/4888’ and F/4827’ – T/4747’. Circulated 2 bottoms up. TOH to 679’. L/D TCP assembly. Prepare to run completion. Page 2/2 Well Name: TBF A-12RD Report Printed: 4/8/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Report Number 14 Report Start Date 3/8/2025 Report End Date 3/9/2025 Last 24hr Summary P/U and TIH with 2-7/8” gas lift completion to 4738’ as per tally. Landed hanger and ran in lock down pins. Dropped prong and pressured up and set packer. Made several attempts to test tubing and packer. No success. Pulled prong and RACP plug. Report Number 15 Report Start Date 3/9/2025 Report End Date 3/10/2025 Last 24hr Summary RIH with slickline and set PXN plug and prong in XN nipple. Tested tubing and packer with MIT-T to 3800 psi for 30 mins on chart. Performed MIT-IA to 1500 psi for 30 mins on chart. N/D BOP and associated components. N/U production tree. Pulled BPV and Installed TWC. Test production tree to 5000 psi. Pulled TWC and turned well over to production. Began rigging down lines, hoses and equipment in preparation for skidding rig. Report Number 16 Report Start Date 3/15/2025 Report End Date 3/16/2025 Last 24hr Summary SVS test passed. AOGCC witness waived by Adam Earl. 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: 3/18/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250318 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN-51 50733204640000 195004 3/1/2025 READ CAliperSurvey AN-51 50733204640000 195004 3/1/2025 READ CaliperSurvey/SBHPS BCU 18RD 50133205840100 222033 2/25/2025 AK E-LINE Perf BCU 18RD 50133205840100 222033 2/26/2025 AK E-LINE Plug/Perf BRU 212-26 50283201820000 220058 2/28/2025 AK E-LINE PT Survey BRU 221-26 50283202010000 224098 2/27/2025 AK E-LINE PPROF BRU 241-34S 50283201980000 224077 3/1/2025 AK E-LINE PPROF IRU 11-06 50283201300000 208184 2/26/2025 AK E-LINE DepthDetermination IRU 11-06 50283201300000 208184 3/8/2025 AK E-LINE PlugSetting MPU E-42 50029236350000 219082 2/22/2025 AK E-LINE Caliper MRU A-12RD 50733200760100 171029 3/7/2025 AK E-LINE Correlation MRU A-13 (REVISED)50733200770000 168002 2/6/2025 AK E-LINE TubingPunch MRU M-32RD2 50733204620200 217091 3/4/2025 AK E-LINE Correlation PBU 13-24B 50029207390200 224087 1/4/2025 HALLIBURTON RBT PBU 16-24A 50029215360100 224158 2/23/2025 HALLIBURTON RBT-COILFLAG PBU F-21 50029219490000 189056 2/25/2025 READ CaliperSurvey SD37-DSP01 50629234510000 211089 2/28/2025 HALLIBURTON WFL-TMD3D Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40221 T40221 T40222 T40222 T40223 T40224 T40225 T40226 T40226 T40227 T40228 T40229 T40230 T40231 T40232 T40233 T40234 MRU A-12RD 50733200760100 171029 3/7/2025 AK E-LINE Correlat Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.03.18 15:55:41 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Eric Dickerman Cc:Rixse, Melvin G (OGC) Subject:RE: PTD 171-029, Sundry 325-049, Trading Bay St A-12RD - Kill Weight Fluid Date:Tuesday, February 25, 2025 10:12:00 AM Eric, Hilcorp has approval to lower the kill fluid to 11.0 ppg, assuming the well is dead after kill fluid is displaced to the perfs. Regards Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Eric Dickerman <Eric.Dickerman@hilcorp.com> Sent: Sunday, February 23, 2025 11:32 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: PTD 171-029, Sundry 325-049, Trading Bay St A-12RD - Kill Weight Fluid Bryan, Regarding A-12RD workover, we plan to kill the well with an 11.0 ppg kill weight fluid instead of 12.0 ppg as written in Sundry 325-049 to avoid excessive losses. Diagnostics after submitting the sundry have repeatedly shown a wellhead pressure of 465 psi with a full column of water. This calculates out to a 10.6 ppg KWF using the top perf TVD of 4,197’ and 8.4 ppg filtered inlet water. An 11.0 ppg KWF would provide 100 psi overbalance at the top perf. The initial well kill will be performed with the injection tree still installed, and we will be prepared to weight up if necessary, before ND tree and NU BOPs. Thank you, Eric Dickerman Hilcorp – CIO Ops Engineer Cell: 307-250-4013 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 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): 8,473 N/A Casing Collapse Structural Conductor Surface 1,540psi Intermediate 3,810psi Production 10,750psi Liner 7,020psi 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 Other: Convert to Producer 2/13/2025 8,468'1,207' 4-1/2" 6,081' Hyd packer & N/A 6,040 (MD) 4,122 (TVD) & N/A 7,261' Perforation Depth MD (ft): 7,490' 6,158 - 6,634 7,261' 7" 4,197 - 4,515 5,002'7" 20" 13-3/8" 264' 9-5/8"7,490' 1,066' MD 6,330psi 3,090psi 264' 1,061' 5,186' 264' 1,066' Length Size Proposed Pools: L-80 TVD Burst 6,068 11,640psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018731 171-029 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20076-01-00 Hilcorp Alaska, LLC Trading Bay St A-12RD AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager 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 CO 93B Trading Bay Middle Kenai C Oil Middle Kenai B Oil 6,085 6,695 4,561 2,036psi 6,695 No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 325-049 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.01.30 13:33:31 - 09'00' Dan Marlowe (1267) Perforate New Pool 10-404 Pressure test to 2200 psi and tag top of cement per 20 AAC 25.112(g) Test Safety Valve system within 5 days of returning to production after RWO. SFD 2/10/2025 X BJM 2/13/25 DSR-1/31/25 BOP test to 3000 psi, annular test to 2500 psi rf *&: 2/13/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.13 16:26:14 -09'00' RBDMS JSB 021825 Trading Bay State A-12RD RWO for Injector to Producer Conversion Well Name:A-12RD API Number:50-733-20076-01-00 Current Status:Offline, Injector Leg:Monopod Regulatory Contact:Juanita Lovett Permit to Drill Number:171-029 First Call Engineer:Eric Dickerman 307-250-4013 Second Call Engineer:Casey Morse 907-777-8322 Current Pool:Middle Kenai C – top picked at 6,135’ md Proposed Pool:Middle Kenai B – top picked at 4,735’ md Maximum Expected BHP (Kenai C):2,450 psi at 4,143’ tvd - SBHPS 10/30/2022 - (11.4 ppg KWF) Max. Potential Surface Pressure (Kenai C):2,036 psi - Using 0.1 psi/ft to surface Maximum Expected BHP (Kenai B):1,564 psi at 4,400’ tvdss / 4,501’ tvd – original reservoir pressure - (6.7 ppg KWF) Max. Potential Surface Pressure (Kenai B):1,114 psi - Using 0.1 psi/ft to surface Well Summary: Trading Bay State A-12RD is currently an offline injector on the Monopod platform. The RD sidetrack was completed in February 1972 targeting Kenai C and D zone injection. The well was repaired with a cemented 7” tie back after a collision while drilling A-25. The well remained on injection from 1972 to 1984 when it was shut in for tubing by annulus communication. A 2015 workover found damaged 7” tieback below 6,700’, so the well was plugged back to an upper Kenai C zone injector and new tubing was installed. In 2019 the injection system on Monopod was removed from service due to equipment failure, subsequently allowing this project to repurpose the well as a producer. Objective: Rig workover to convert from injector to producer. Isolate Kenai C injection. Perforate Kenai B interval. Install gas lifted upper completion. Notes on Wellbore condition: - Most recent casing test: Passed 1,500 psi on 2/1/2019. - 9-5/8” casing cemented to surface on 3/9/1972 through the casing shoe with 650 sk Class G cement with 8% gel and 250 sk Class G, and 870 sk through DV collar. Approximately 535 cu.ft. of cement returns noted in drilling report. Confirmed with CBL. - 7” tie back cemented to surface with 1,400 sk Class G during Nov. / Dec. 1972 RWO. Good cement returns noted in drilling report. Confirmed with CBL. Trading Bay State A-12RD RWO for Injector to Producer Conversion RWO Procedure: 1. Skid Monopod Rig 56 in to position over A-12RD. 2. RU eline with lubricator. PT PCE to 250 psi low / 2,500 psi high. Punch tubing above packer +/- 6,015’ md. RD eline. 3. Circulate well to KWF: a. KWF will be 12 ppg mud until Kenai C sands are isolated. b. KWF will be 8.5 ppg 3% KCl after Kenai C sands are isolated. c. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading. d. Total WBV = 229 bbl. i. Tubing volume = 93 bbl. ii. IA to current packer volume = 106 bbl. iii. Production casing below current packer volume = 30 bbl. 4. Set BPV/TWC, ND tree, NU Hilcorp BOP stack (see attached). a. Notify AOGCC 48 hours in advance for witness. b. Test BOPE to 250psi Low / 3,000psi High / 2,500psi Annular. c. BOPE will be used as needed to circulate the well. 5. Pull BPV/TWC. 6. Pull hanger to floor, then lay down existing 4-1/2” completion from seal assembly leaving permanent packer in hole at 6,040’. 7. PU work string. 8. RIH and set 7” cement retainer as deep as possible, +/- 6,020’ md. a. Plan to pump 26 bbl of 15.3 ppg cement through retainer. Fill up volume from 7” CIBP at 6,695’ to retainer at 6,020’ = 25.1 bbl. b. Place at least 3 bbl (75’) of 15.3 ppg cement on top of retainer. TOC at +/- 5,945’. c. If zone squeezes off early while pumping through retainer, unsting from retainer and place at least 5 bbl (100’) of cement on top of retainer. 9. Pressure test wellbore to 1,500 psi for a charted 30 minute test. 10. Circulate wellbore to 3% KCl. 11. POOH and rack back workstring. 12. MU TCP guns on workstring per RE and GEO perforating table. 13. RU eline to confirm tie in with GR/CCL. RD Eline. 14. Perforate Kenai B target intervals, +/- 4,750’ to 5,343’ md. 15. Circulate well clean, ensure no flow, POOH and lay down TCP guns. 16. Run new 2-7/8” gas lifted upper completion. a. Target packer at +/- 4,700’ md (3,417’ tvd). b. Tubing retrievable subsurface safety valve planned at +/- 310’ md. c. Completion to be ran with live GLVs. 17. Land completion and set production packer. 18. MIT-T to 1,500psi for a charted 30 minute test. 19. CMIT-TxIA to 1,500psi for a charted 30 minute test. 20. Set BPV/TWC, ND BOP. 21. NU tree and test, pull BPV/TWC. 22. RDMO RWO crew and equipment. 23. Slickline to pull packer setting equipment as needed. Test SSSV & SSV within 5 days of returning to production post RWO. -bjm Pressure test cement plug to 2200 psi (0.25 x casing shoe TVD). RU E-line and tag top of cement per 20 AAC 25.112(g). -bjm Trading Bay State A-12RD RWO for Injector to Producer Conversion Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Drawing 6. Fluid/Flow Diagram 7. RWO Sundry Change Form Updated by: JLL 01/30/25 SCHEMATIC Trading Bay Unit Well # A-12RD API: 50-733-20076-01-00 PTD: 171-029 Completed: 02/02/15 PBTD = 8,468’ TD = 8475’ HOLE ANGLE thru Interval = 40.7q RKB to MSL = 101’, MSL to Mudline = 66’ 1 2 7261’ 50-3 51-6 CZNS6 3 C-5 C-4 4 C-7 C-7 C-2 47-5 47-5 47-5 C-1 5 C-7 DV Collar @ 2010’ X D Zone DV Collar @ 3,982’ CASING AND TUBING DETAIL SIZE WT GRAD E CONN ID TOP BTM. 20” Conductor Weld Surf ~264’ 13-3/8” 61 J-55 Butt 12.515” Surf 1066’ 9-5/8” 43.5 N-80 Butt 8.755” Surf 7490’ 7” 32 P-110 X-line 6.094” 7261’ 8468’ Tie Back 7” 29 N-80 Butt 6.184” Surf 7261’ Tubing Detail: 4-1/2” (polycore) 12.6 (unlined) 13.55 (lined)L-80 Extended BTC 3.640” Surf 6,068’ PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt Accum SPF Last Perf Date Present Condition C-1 6,158' 6,183' 4,197' 4,207' 25' 6 01/31/15 Open C-2 6,238' 6,314' 4,239' 4,286' 76' 6 01/31/15 Open CZNS6 6,404' 6,418' 4,349' 4,359' 14' 6 01/31/15 Open C-4 6,444' 6,470' 4,377' 4,395' 26' 6 01/31/15 Open C-5 6,528' 6,634' 4,436' 4,515' 108' 6 01/31/15 Open C-7 6,811' 6,851' 4,650' 4,680' 40' 2 12/5/1972 Isolated C-7 6,886' 6,926' 4,707' 4,738' 40' 2 12/5/1972 Isolated C-7 6,960' 6,980' 4,764' 4,780' 20' 2 12/4/1972 Isolated 47-5 7,092' 7,122' 4,868' 4,892' 30' 2 12/4/1972 Isolated 47-5 7,102' 7,122' 4,876' 4,892' 20' 2 3/27/1972 Isolated w/ tie back liner ran on 12/1/72 47-5 7,160' 7,180' 4,922' 4,938' 20' 4 12/4/1972 Isolated 50-3 7,514' 7,520' 5,207' 5,212' 6' 2 3/26/1972 Isolated 7,521' 7,522' 5,213' 5,213' 1' 8 3/19/1972 Cmt sqz'd f/ bond 7,700' 7,701' 5,367' 5,368' 1' 4 3/17/1972 Cmt sqz'd f/ bond 51-6 7,715' 7,721' 5,380' 5,385' 6' 2 3/26/1972 Isolated 51-6 7,732' 7,740' 5,395' 5,402' 8' 2 3/26/1972 Isolated Milled out of casing somewhere between 6,771’ – 6,787’ on 1/30/2015 Jewelry Detail NO.Depth (MD) Depth (TVD)ID OD Item 38.15’ Tubing Hanger 1 6,024’ 4,113’ 5.000” 5.870” 5” Seal Assembly w/15’ Seal Bore Receptacle 2 6,040’ 4,122’ 3.990” 5.870” Tri-Point Hydraulic Set Liner Top Packer 3 6,057’ 4,132’ 2.813” 4.500” X-Nipple 4 6,068’ 4,138’ 2.991” 4.500” WLEG 5 6,695’ 4,561’ CIBP Cement Details 13 3/8”Cemented to surface with 1200 sk Class G. 300 cu ft of returns to surface.ToC at surface. 9 5/8” Cemented to surface on 3/9/1972 through the casing shoe with 650 sk Class G cement with 8% gel and 250 sk Class G, and 870 sk through DV collar. Approximately 535 cu.ft. of cement returns noted in drilling report.ToC at surface. 7” Liner Cemented with 200 sk Class G with 1% CFR-2. Liner lap squeezed with 200 sk Class G with 1% CFR- 2. Squeezed 100 sk Class G with 1% CFR-2 into punches from 7,521' - 7,522' and 7,700' - 7,701'. Squeezed 50 sk Class G with 1% CFR-2 into perforations at 7,092' - 7,122'. 7” Tie Back Cemented to surface with 1,400 sk Class G during Nov. / Dec. 1972 RWO. Good cement returns noted in drilling report.ToC at surface. Fish Details 6,745’Baker Model F Packer. Milled & pushed downhole. 1/1/15 Updated by: JLL 01/30/25 PROPOSED Trading Bay Unit Well # A-12RD API: 50-733-20076-01-00 PTD: 171-029 Completed: FUTURE PBTD = 8,468’ TD = 8475’ HOLE ANGLE thru Interval = 40.7q RKB to MSL = 101’, MSL to Mudline = 66’ 1 2 7261’ 50-3 51-6 CZNS6 3 C-5 C-4 4 C-7 C-7 C-2 47-5 47-5 47-5 C-1 8 C-7 5,6 7 DV Collar @ 2010’ D Zone DV Collar @ 3,982’ Middle Kenai B CASING AND TUBING DETAIL SIZE WT GRAD E CONN ID TOP BTM. 20” Conductor Weld Surf ~264’ 13-3/8” 61 J-55 Butt 12.515” Surf 1066’ 9-5/8” 43.5 N-80 Butt 8.755” Surf 7490’ 7” 32 P-110 X-line 6.094” 7261’ 8468’ Tie Back 7” 29 N-80 Butt 6.184” Surf 7261’ Tubing Detail: 2-7/8” Surf ±4,750’ Milled out of casing somewhere between 6,771’ – 6,787’ on 1/30/2015 PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)Amt Accum SPF Last Perf Date Present Condition Middle Kenai B ±4,750’ ±5,343’ ±3,417’ ±3,737’ ±587’ Future Proposed C-1 6,158' 6,183' 4,197' 4,207' 25' 6 01/31/15 Open (Isolate) C-2 6,238' 6,314' 4,239' 4,286' 76' 6 01/31/15 Open (Isolate) CZNS6 6,404' 6,418' 4,349' 4,359' 14' 6 01/31/15 Open (Isolate) C-4 6,444' 6,470' 4,377' 4,395' 26' 6 01/31/15 Open (Isolate) C-5 6,528' 6,634' 4,436' 4,515' 108' 6 01/31/15 Open (Isolate) C-7 6,811' 6,851' 4,650' 4,680' 40' 2 12/5/1972 Isolated C-7 6,886' 6,926' 4,707' 4,738' 40' 2 12/5/1972 Isolated C-7 6,960' 6,980' 4,764' 4,780' 20' 2 12/4/1972 Isolated 47-5 7,092' 7,122' 4,868' 4,892' 30' 2 12/4/1972 Isolated 47-5 7,102' 7,122' 4,876' 4,892' 20' 2 3/27/1972 Isolated w/ tie back liner ran on 12/1/72 47-5 7,160' 7,180' 4,922' 4,938' 20' 4 12/4/1972 Isolated 50-3 7,514' 7,520' 5,207' 5,212' 6' 2 3/26/1972 Isolated 7,521' 7,522' 5,213' 5,213' 1' 8 3/19/1972 Cmt sqz'd f/ bond 7,700' 7,701' 5,367' 5,368' 1' 4 3/17/1972 Cmt sqz'd f/ bond 51-6 7,715' 7,721' 5,380' 5,385' 6' 2 3/26/1972 Isolated 51-6 7,732' 7,740' 5,395' 5,402' 8' 2 3/26/1972 Isolated Jewelry Detail NO.Depth (MD) Depth (TVD)ID OD Item 38.15’ Tubing Hanger 1 ±310’ ±309’ SSSV 2 ±2,196’ ±2,000’ GLM ±3,774’ ±2,900’ GLM ±4,650’ ±3,389’ GLM 3 ±4,700’ ±3,417’ Packer 4 ±4,750’ ±3,445’ WLEG 5 ±5,945’ ±4,113’ Cement TOC 6 ±6,020’ ±4,155’ 7” Cement Retainer 7 6,040’ 4,122’ 3.990” 5.870” Tri-Point Hydraulic Set Liner Top Packer 8 6,695’ 4,561’ CIBP Cement Details 13 3/8”Cemented to surface with 1200 sk Class G. 300 cu ft of returns to surface.ToC at surface. 9 5/8” Cemented to surface on 3/9/1972 through the casing shoe with 650 sk Class G cement with 8% gel and 250 sk Class G, and 870 sk through DV collar. Approximately 535 cu.ft. of cement returns noted in drilling report.ToC at surface. 7” Liner Cemented with 200 sk Class G with 1% CFR-2. Liner lap squeezed with 200 sk Class G with 1% CFR- 2. Squeezed 100 sk Class G with 1% CFR-2 into punches from 7,521' - 7,522' and 7,700' - 7,701'. Squeezed 50 sk Class G with 1% CFR-2 into perforations at 7,092' - 7,122'. 7” Tie Back Cemented to surface with 1,400 sk Class G during Nov. / Dec. 1972 RWO. Good cement returns noted in drilling report.ToC at surface. Fish Details 6,745’Baker Model F Packer. Milled & pushed downhole. 1/1/15 Cement will be bullheaded into these perfs. -bjm Monopod Platform A-12RD Current Wellhead 01/27/2025 13 3/8'’ 9 5/8'’ 4 ½’’ Valve, Master, WKM-M, 4 1/16 5M FE, HWO, FF trim Valve, Swab, WKM-M 4 1/16 5M FE, HWO, FF trim BHTA, Bowen, 4 1/16 5M FE x 7'’ quick union top Adapter, Cactus-EN-6.25'’, 11 5M stdd x 4 1/16 5M stdd top, w/ 2- 1'’npt control line exits Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/ 15'’ air operator 7'’ Tubing head, CW, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO, w/ HPS bottom w/ 1- 2 1/16 5M WKM-M valves Tubing hanger, CW-CCL, 11 X 4 ½ BTC lift and 4 ½ BTC susp, w/ 4'’ Type H BPV profile, 2- 3/8 CCL, 6 ¼ extended neck, 17-4PH stainless steel Monopod A-12RD 13 3/8 X 9 5/8 X 7 X 4 1/2 Casing spool, CIW-WF, 13 5/8 3M X 13 5/8 3M, w/ 2- 2 1/16 5M SSO Casing head, Shaffer-KD, 13 5/8 3M X 13'’ SOW bottom, w/2'’ LPO Monopod Platform A-12RD Proposed Wellhead 01/27/2025 13 3/8'’ 9 5/8'’ 2 7/8'’ Valve, Master, WKM-M, 3 1/8 5M FE, HWO, EE trim Valve, Upper master, WKM-M, 3 1/8 5M FE, HWO, EE trim Valve, Swab, WKM-M 3 1/8 5M FE, HWO, EE trim BHTA, Bowen, 3 1/8 5M FE x 3'’ quick union top Adapter, Cactus-EN-6.25'’, 11 5M stdd x 3 1/8 5M stdd top, w/ 2- 1'’npt control line exits Tubing hanger, Cactus-EN- CCL, 3 ½ EUE 8rd lift and susp x w 6 ¼ od ext neck, 3'’ type H BPV profile, DD-NL material Valve, Wing, SSV, WKM-M, 3 1/8 5M FE, w/15'’ air operator 7'’ Tubing head, CW, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO, w/ HPS bottom w/ 1- 2 1/16 5M WKM-M valves Monopod A-12RD 13 3/8 X 9 5/8 X 7 X 2 7/8 Casing spool, CIW-WF, 13 5/8 3M X 13 5/8 3M, w/ 2- 2 1/16 5M SSO Casing head, Shaffer-KD, 13 5/8 3M X 13'’ SOW bottom, w/2'’ LPO Monopod Platform 2025 BOP 01/22/2025 Drill deck 1.76' Riser 13 5/8 5M FE X 13 5/8 5M FE 14.20'’ UOCD 1911 13 5/8 5M Shaffer Shaffer SL Mud Cross 13 5/8 5M FE X FE w/ 3 1/8 5M EFO w/ 2 1/16 5M manual and HCR valves for choke and kill lines 3.74' 13 5/8 5M Rig Floor 16'’ Pipe 2 7/8-5.5 Variables Blind 26.25' Bottom of air boot flange 5' below rig floor 2.83' Spool 13 5/8 5M X 11 5M1.00' 14.20' Hilcorp Monopod Rig 56Flow DiagramLEGEND:Fluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveAutomatic Choke Manual ChokePressure Gauge Knife ValveMUD PUMP4.30'PIT SYSTEMCHOKE MANIFOLDChoke LinePanic LineC12C13C15C14C16ABC4C5C6C7C2C10C9C11C8C3PHCR1OpenClosedClosedOpenOpenOpenOpenAnnularVBRBLINDSucƟonMUD PUMP SHAKER SHAKERKill LineTrip TankPPC1CGAS BUSTERHCR24”Demco kill lineFlow linePPHilcorp Monopod Rig 56Flow DiagramReverse Circulating4”Demco kill lineLEGEND:Fluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveAutomatic Choke Manual ChokePressure Gauge Knife ValveMUD PUMP4.30'PIT SYSTEMCHOKE MANIFOLDChoke LinePanic LineC12C13C15C14C16ABC4C5C6C7C2C10C9C11C8C3PHCR1OpenClosedOpenOpenOpenOpenClosedAnnularVBRBLINDSucƟonMUD PUMP SHAKER SHAKERKill LineTrip TankPPC1CGAS BUSTERHCR2Flow linePP411CTo GasBusterWhite Normally Open3-6-7-15Black Normally Closed1-2-4-5-8-9-1011-12-13-14-16FromBOP141310123281B567A91615DToPanicLineToSendingUnitMonopodRig51ChokeManifoldItem3 & 54, 13, 15, 161-2, 6-12, 14AB-CDĞƐĐƌŝƉƟŽŶ3 1/8 5M Vetco 2200T Gate Valve4 1/16 5M Cameron Gate Valve3 1/8 5M Cameron Gate ValveSwaco 2 9/16 10M Super Choke3 1/8 5M Cameron H2 Manual Choke3 1/8 5M Cameron H2 PosiƟve ChokeInstall 4 1/16 5M APIinstrumentŇange belowpanic line w/ ½ npt drainportsMonpopod ValveAlignment –Long WayValvePosiƟon (O-Open/ C-ClosedMonpopod Valve Alignment–ReverseValve PosiƟon (O-Open/ C-ClosedAnnular O Annular CVBR O VBR OBlind O Blind OC1 C C1 CC2 C C2 CC3 O C3 OC4 C C4 CC5 C C5 CC6 O C6 OC7 O C7 OC8 C C8 CC9 C C9 CC10 C C10 CC11 C C11 CC12 C C12 CC13 C C13 CC14 C C14 CC15 O C15 OC16 C C16 CHCR1 C HCR1 CWing1 (W1) O Wing1 (W1) OHCR2 C HCR2 CWing2 (W2) O Wing2 (W2) ODemco 4” Kill Line C Demco 4” Kill Line OStandPipeValve(SP1) O StandPipeValve(SP1) CCement Line (CL1) C Cement Line (CL1) CTrip Tank 1 (TT1) C Trip Tank 1 (TT1) CReverse Line (RV1) C Reverse Line (RV1) OMudPump1(MP1) O MudPump1(MP1) OMudPump2(MP2) O MudPump2(MP2) OMudPump3(MP3) O MudPump3(MP3) OMudPump4(MP4) O MudPump4(MP4) OPitOutlet1(PO1) O PitOutlet1(PO1) OPitOutlet2(PO2) C PitOutlet2(PO2) CPit Outlet 3(PO3) C Pit Outlet 3(PO3) CMP3SP1PO3PO2MP4MP1MP2MP3MP4MP1MP2W2 W1W2CEMENTLINEW1TT1TT1RV1RV1CL1PO1PO3PO2PO1 Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Trading Bay St A-12RD (PTD 171-029)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 1 McLellan, Bryan J (OGC) From:Eric Dickerman <Eric.Dickerman@hilcorp.com> Sent:Friday, February 7, 2025 3:54 PM To:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] TB St A-12RD (PTD 171-029) RWO sundry Bryan, Please see the zone tops as picked by our Geologist as follows: The zone tops are as follows: x Middle Kenai A: above surface casing approx. 1,066’ MD / (1,061’ TVD) x Middle Kenai B : 4,731’ MD / (3,403’ TVD) – Note: I picked the top at 4,735’ md in the sundry. x Middle Kenai C: 6,136’ MD / (4,178’ TVD) – Note: I picked the top at 6,135’ md in the sundry. x Middle Kenai D: 7,911’ MD / (5,556’ TVD) x Middle Kenai E: 8,234’ MD / (5,856’ TVD) x No Hemlock visible on log Thank you, Eric Dickerman Hilcorp – CIO Ops Engineer Cell: 307-250-4013 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Friday, February 7, 2025 2:47 PM To: Eric Dickerman <Eric.Dickerman@hilcorp.com> Subject: [EXTERNAL] TB St A-12RD (PTD 171-029) RWO sundry Eric, I’m reviewing this RWO sundry. Where are the tops of the various pools in this well? Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored); Brooks, Phoebe L (OGC) Subject:FW: Trading Bay St A-12RD (PTD 1710290) - AIO 12.005 Compliance Temperature Survey - October 2022 Date:Tuesday, November 8, 2022 9:04:50 AM Attachments:A-12rd Schematic 2015-02-25.pdf A-12RD static 10-30-22.pdf From: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Saturday, November 5, 2022 10:29 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Subject: Trading Bay St A-12RD (PTD 1710290) - AIO 12.005 Compliance Temperature Survey - October 2022 Mr Wallace, Per AIO 12.005 (Administrative Approval), Trading Bay St A-12RD (Monopod), requires a biennial temperature survey. The 2022 survey was completed on 10/30/2022. The survey data (see attached plot) is consistent with previous temperature surveys (2016 and 2020) and does not show any indication of out of zone injection. Note: This year’s tag depth was 6090’ MD (prior tag depth was 6550’ MD). The packer depth is 6040’ MD, so this depth is sufficiently deep to log the entire casing down to the packer. Let me know if you have any questions or require additional information/data. Thanks Josh Allely Well Integrity Engineer Kenai – Hilcorp Alaska 907-777-8505 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Updated by: JLL 02/26/15 SCHEMATIC Trading Bay Unit Well # A-12RD API: 50-733-20076-01-00 PTD: 171-029 Completed: 02/02/15 PBTD = 8,468’ TD = 8475’ HOLE ANGLE thru Interval = 40.7qq RKB to MSL = 101’, MSL to Mudline = 66’ 1 2 7261’ 50-3 51-6 CZNS6 3 C-5 C-4 4 C-7 C-7 C-2 47-5 47-5 47-5 C-1 5 C-7 DV Collar @ 2010’ X D Zone DV Collar @ 3,982’ CASING AND TUBING DETAIL SIZE WT GRAD E CONN ID TOP BTM. 20” Conductor Weld Surf ~264’ 13-3/8” 61 J-55 Butt 12.515” Surf 1066’ 9-5/8” 43.5 N-80 Butt 8.755” Surf 7490’ 7” 32 P-110 X-line 6.094” 7261’ 8468’ Tie Back 7” 29 N-80 Butt 6.184” Surf 7261’ Tubing Detail: 4-1/2” (polycore) 12.6 (unlined) 13.55 (lined) L-80 Extended BTC 3.640” Surf 6,068’ PERFORATION DATA Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt Accum SPF Last Perf Date Present Condition C-1 6,158' 6,183' 4,197' 4,207' 25' 6 01/31/15 Open C-2 6,238' 6,314' 4,239' 4,286' 76' 6 01/31/15 Open CZNS6 6,404' 6,418' 4,349' 4,359' 14' 6 01/31/15 Open C-4 6,444' 6,470' 4,377' 4,395' 26' 6 01/31/15 Open C-5 6,528' 6,634' 4,436' 4,515' 108' 6 01/31/15 Open C-7 6,811' 6,851' 4,650' 4,680' 40' 2 12/5/1972 Isolated C-7 6,886' 6,926' 4,707' 4,738' 40' 2 12/5/1972 Isolated C-7 6,960' 6,980' 4,764' 4,780' 20' 2 12/4/1972 Isolated 47-5 7,092' 7,122' 4,868' 4,892' 30' 2 12/4/1972 Isolated 47-5 7,102' 7,122' 4,876' 4,892' 20' 2 3/27/1972 Isolated w/ tie back liner ran on 12/1/72 47-5 7,160' 7,180' 4,922' 4,938' 20' 4 12/4/1972 Isolated 50-3 7,514' 7,520' 5,207' 5,212' 6' 2 3/26/1972 Isolated 7,521' 7,522' 5,213' 5,213' 1' 8 3/19/1972 Cmt sqz'd f/ bond 7,700' 7,701' 5,367' 5,368' 1' 4 3/17/1972 Cmt sqz'd f/ bond 51-6 7,715' 7,721' 5,380' 5,385' 6' 2 3/26/1972 Isolated 51-6 7,732' 7,740' 5,395' 5,402' 8' 2 3/26/1972 Isolated Milled out of casing somewhere between 6,771’ – 6,787’ on 1/30/2015 Jewelry Detail NO. Depth (MD) Depth (TVD) ID OD Item 38.15’ Tubing Hanger 1 6,024’ 4,113’ 5.000” 5.870” 5” Seal Assembly w/15’ Seal Bore Receptacle 2 6,040’ 4,122’ 3.990” 5.870” Tri-Point Hydraulic Set Liner Top Packer 3 6,057’ 4,132’ 2.813” 4.500” X-Nipple 4 6,068’ 4,138’ 2.991” 4.500” WLEG 5 6,695’ 4,561’ CIBP Well: Field:10/30/2022HilcorpA-12RD Monopod 50 60 70 80 90 100 110 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 500 1000 1500 2000 2500 3000 3500 4000 Temperature (Deg. F)Depth-MD, (feet)Pressure (psia) Press 2020 Perfs 13 3/8"9 5/8"7"4 1/2" Packer Press 2022 Temp 2022 Temp 2016 Temp 2020 Pressure-Temperature Profile 1. RIH 2016, 2020 vs 2022 Report date: 11/4/2022 Wallace, Chris D (CED) From: Julie Wellman - (C) <Julie.Wellman@hilcorp.com> Sent: Monday, November 16, 2020 2:14 PM To: Wallace, Chris D (CED) Cc: Dan Marlowe; Katherine O'connor; Juanita Lovett Subject: TBF A-12RD (PTD #171029) Notification of TAA communication Hello Chris, TBF A-012RD has shown recent evidence of TAA communication as you can see in the TIO plot below. Per our conversation this afternoon, we can continue to inject for 30 days while we run diagnostics. Our tentative diagnostic plan is below and will be updated based on results: 1. Test wellhead seals 2. Pending wellhead test results, run temp survey 3. Additional diagnostics as required MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 5, 2019 TO: Jim Re ��ji� qb�l� Tests P.1. Supervisor I 'l� SUBJECT: Mechanical Integrity HILCORP ALASKA LLC A-12RD FROM: Bob Noble TRADING BAY ST A-12RD Petroleum Inspector See: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name TRADING BAY ST A-12RD API Well Number 50-733-20076-01-00 Inspector Name: Bob Noble 171-029-0 2/1/2019 Permit Number: Inspection Date: Insp Num: mitRCN190202120216 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well A-12RD - Type Inj W TVD 4121 Tubing 2574 2575 2574 =574 2576 PTD 71oz90 Type Test SPTTest psi 1500 IA 1297 1662 1661 667 j 1662 BBL Pumped: 0.6 • BBL Returned: 0.6 - OA 92 92 9' 92 —�9'- Infrrval 4YRTST Notes: Tuesday, February 5, 2019 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ,---, DATE: Monday,March 09,2015 Jim Regg / P.I.Supervisor �7<t II ' SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC A-12RD FROM: Johnnie Hill TRADING BAY ST A-I2RD Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvj NON-CONFIDENTIAL Comm Well Name TRADING BAY ST A-12RD API Well Number 50-733-20076-01-00 Inspector Name: Johnnie Hill Permit Number: 171-029-0 Inspection Date: 2/11/2015 Insp Num: mitJWH150221131214 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min A-12RD W' 1— 4121 800 " 800 800 800 Well Type Inj ITVD FTubing PTD I1710290 Type Test SPT Test psi lsoo IA 0 1670 1670 - 1670 - — IntervalIrNITAL P/F r P ./I OA! o 0 0 0 Notes: Good test,Great guys to work with , QEDf'"— `', j e Monday,March 09,2015 Page 1 of 1 Brooks, Phoebe L (DOA) vTpti 1110290 From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Monday, March 09, 2015 9:32 AM To: Brooks, Phoebe L (DOA) Subject: A-12RD and BCU-03RD schematics Attachments: A-12rd Schematic 2015-02-25.docx; BCU-03RD Actual Schematic 3-04-15.xls Sorry about that, Phoebe. We get the schematics updated in time for the 10-404 submissions (within 30 days after the work is completed)which is usually after the initial MITs are done on the injectors. The A-12RD & BCU-03RD schematics are attached. Larry From: Brooks, Phoebe L(DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Monday, March 09, 2015 9:11 AM To: Larry Greenstein Subject: RE: MIT Monopod 02-11-15 Hi Larry, I had a reminder set for myself on this one...the last time we talked, I believe you just had the draft on file and I haven't seen anything sent in just yet so, I was hoping you could send this one my way?And, would you mind also looking into the well schematic for BCU-03RD PTD#2030440? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission > w �� 1 Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE: Phis 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Brooks, Phoebe L (DOA) Sent: Friday, February 13, 2015 10:16 AM To: 'Larry Greenstein' Subject: RE: MIT Monopod 02-11-15 Hi Larry, Will you send me the schematic for A-12RD? I'm also going to change the AOGCC Rep to reflect Johnnie Hill so that it will import correctly. 1 Trading Bay Unit .. liti SCHEMATIC Well #A-12RD Completed: 02/02/15 RKB to TBG Head=34.7' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BIM. Zi 1 L. 13-3/8" 61 K-55 Butt 12.515" Surf Surf 1066' 9-5/8" 43.5 N-80& Butt 8.755" 7490' P-110 7" 32 P-110 X-line 6.094" 7261' 8468' DV Collar Tie Back @ 2010 7" 29 N-80 Butt 6.184" Surf 7261' ) I1141/4._DV Collar Tubing: 1 @ 3,982' 4-1/2" 12.6/13.55 L-80 Butt 3.640" Surf 6,068' i 1 - - 2 _tic 3 Jewelry Detail 4 NO. Depth (MD) ID Item 34.7 Tubing Hanger C-1 C-2 1 6,024' 5.000 5"Seal Assembly w/15'Seal Bore Receptacle CZNS6 2 6,040' 3.990 Tri-Point Hydraulic Set Liner Top Packer C-4 C-5 3 6,057' 2.813 X-Nipple 5 4 6,068' 2.991 WLEG C-7 5 6,695' CIBP C-7 C-7 Milled out of casing somewhere between 6,771'-6,787' 1/30/2015 47-5 PERFORATION DATA 47-5 Last Top Btm Top Btm Accum Perf 47-5 Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Present Condition C-1 6,158' 6,183' 4,197' 4,207' 25' 6 01/31/15 Open ZI 7261' C-2 6,238' 6,314' 4,239' 4,286' 76' 6 01/31/15 Open - CZNS6 6,404' 6,418' 4,349' 4,359' 14' 6 01/31/15 Open LL C 4 6,444' 6,470' 4,377' 4,395' 26' 6 01/31/15 Open 50-3 C-5 6,528' 6,634' 4,436' 4,515' 108' 6 01/31/15 Open C-7 6,811' 6,851' 4,650' 4,680' 40' 2 12/5/1972 Isolated C-7 6,886' 6,926' 4,707' 4,738' 40' 2 12/5/1972 Isolated = C-7 6,960' 6,980' 4,764' 4,780' 20' 2 12/4/1972 Isolated 51-6 47-5 7,092' 7,122' 4,868' 4,892' Isolated 30' 2 12/4/1972 47-5 7,102' 7,122' 4,876' 4,892' 20' 2 3/27/1972 Isolated w/tie back liner ran on 12/1/72 47-5 7,160' 7,180' 4,922' 4,938' 20' 4 12/4/1972 Isolated 50-3 7,514' 7,520' 5,207' 5,212' 6' 2 3/26/1972 Isolated 7,521' 7,522' 5,213' 5,213' 1' 8 3/19/1972 Cmt sqi d f/bond D Zone 7,700' 7,701' 5,367' 5,368' 1' 4 3/17/1972 Cmt sqz'd f/bond 51-6 7,715' 7,721' 5,380' 5,385' 6' 2 3/26/1972 Isolated 51-6 7,732' 7,740' 5,395' 5,402' 8' 2 3/26/1972 Isolated / PBTD=8468' TD=8475' KB ELEV=101' HOLE ANGLE thru Interval=40.7° Updated by: _ILL 02/26/15 Brooks, Phoebe L (DOA) pmt$. ►7 l o 2110 From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Monday, March 09, 2015 11:24 AM To: Brooks, Phoebe L (DOA) Subject: RE: A-12RD and BCU-03RD schematics Attachments: Al2RD Position Log 2002-05-07.xlsx Looks like we have one from 2002, Phoebe...maybe that'll explain the 20' difference. Larry From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Monday, March 09, 2015 11:21 AM To: Larry Greenstein Subject: RE: A-12RD and BCU-03RD schematics Larry, Would you mind sending me the most recent directional survey you have on file? Thank you, Phoebe Phoebe Brooks Statistical Technician II SCANNED MAP ( Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Larry Greenstein [mailto:IgreensteinOhilcorp.com] Sent: Monday, March 09, 2015 11:18 AM To: Brooks, Phoebe L (DOA) Subject: RE: A-12RD and BCU-03RD schematics Hello Phoebe Resent the BCU-03RD MIT with the TVD instead of the MD for the packer depth. As for A-12RD, I checked again and our Petra system still kicks out the 4122' TVD for the MD of 6040' of the packer. Don't know why there is a discrepancy of 20', but that's what we have...sorry. Still doesn't affect the test pressure of 1500 psi, but it's curious why there is this difference in depths. Larry 1 r Report Name Well Date Created Position Log A-12RD 5/7/02 KB Surf X Surf Y Well Name CURRENT STATUS API (ft) (ft) (ft) A-12RD INJECTOR- DRILLED 507332007601 101 218,864 2,523,131 MD TVD SSTVD X Off Y Off X Y Inc (ft) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 0 0 101 0 0 218,864 2,523,131 0 100 100 1 0 0 218,864 2,523,131 0 150 149 -48 0 0 218,864 2,523,131 0.3 200 199 -98 0 0 218,864 2,523,131 0.3 250 249 -148 0 0 218,864 2,523,131 0.3 300 299 -198 1 0 218,865 2,523,131 1 350 349 -248 2 -1 218,866 2,523,130 3.3 400 399 -298 4 -4 218,868 2,523,127 5 450 449 -348 8 -7 218,872 2,523,124 5.8 500 499 -398 12 -8 218,876 2,523,123 3.8 550 549 -448 14 -7 218,878 2,523,124 3 600 599 -498 17 -6 218,881 2,523,125 3 650 649 -548 19 -4 218,883 2,523,127 4.8 700 698 -597 20 0 218,884 2,523,131 5.3 750 748 -647 19 4 218,883 2,523,135 5 800 798 -697 16 8 218,880 2,523,139 6 850 848 -747 11 10 218,875 2,523,141 5.5 900 898 -797 6 11 218,870 2,523,142 6.8 950 947 -846 0 13 218,864 2,523,144 8.3 1,000 996 -895 -6 17 218,858 2,523,148 10.8 1,030 1,026 -925 -12 20 218,852 2,523,151 12 1,060 1,055 -954 -18 22 218,846 2,523,153 12.8 1,133 1,126 -1,025 -33 29 218,831 2,523,160 14.3 1,163 1,155 -1,054 -41 32 218,823 2,523,163 16 1,194 1,185 -1,084 -49 33 218,815 2,523,164 15 1,227 1,217 -1,116 -57 34 218,807 2,523,165 14.3 1 1,259 1,248 -1,147 -65 34 218,799 2,523,165 15 1,289 1,277 -1,176 -73 34 218,791 2,523,165 16 1,374 1,358 -1,257 -99 36 218,765 2,523,167 19.5 _ 1,467 1,444 -1,343 -134 37 218,730 2,523,168 24.5 1,529 1,499 -1,398 -161 38 218,703 2,523,169 28 1,629 1,586 -1,485 -212 39 218,652 2,523,170 33 1,692 1,638 -1,537 -247 40 218,617 2,523,171 35.5 1,786 1,712 -1,611 -304 41 218,560 2,523,172 39 1,911 1,807 -1,706 -386 45 218,478 2,523,176 43 2,035 1,895 -1,794 -473 53 218,391 2,523,184 46.8 2,124 1,954 -1,853 -539 60 218,325 2,523,191 49 2,235 2,027 -1,926 -622 66 218,242 2,523,197 49 2,314 2,079 -1,978 -682 67 218,182 2,523,198 49.5 2,408 2,138 -2,037 -755 66 218,109 2,523,197 52.5 2,605 2,252 -2,151 -916 67 217,948 2,523,198 56.8 2,814 2,364 -2,263 -1,092 73 217,772 2,523,204 58.5 3,030 2,476 -2,375 -1,277 82 217,587 2,523,213 59 3,221 2,572 -2,471 -1,441 87 217,423 2,523,218 60.5 3,485 2,709 -2,608 -1,667 75 217,197 2,523,206 57 3,703 2,832 -2,731 -1,846 72 217,018 2,523,203 54 3,982 2,994 -2,893 -2,073 91 216,791 2,523,222 55.3 4,214 3,123 -3,022 -2,264 111 216,600 2,523,242 57.3 4,575 3,317 -3,216 -2,566 150 216,298 2,523,281 57.8 4,745 3,409 -3,308 -2,707 172 216,157 2,523,303 56.3 5,136 3,623 -3,522 -3,029 234 215,835 2,523,365 57.5 5,251 3,686 -3,585 -3,123 255 215,741 2,523,386 56.8 5,562 3,856 -3,755 -3,375 318 215,489 2,523,449 56.8 5,784 3,979 -3,878 -3,550 379 215,314 2,523,510 56 5,845 4,013 -3,912 -3,596 400 215,268 2,523,531 57 6,093 4,150 -4,049 -3,782 488 215,082 2,523,619 55.5 6,309 4,281 -4,180 -3,936 565 214,928 2,523,696 50 6,558 4,455 -4,354 -4,094 646 214,770 2,523,777 41 6,638 4,516 -4,415 -4,139 671 214,725 2,523,802 39.8 1 6,939 4,746 _ -4,645 -4,310 763 214,554 2,523,894 40.8 7,450 5,150 -5,049 -4,585 912 214,279 2,524,043 34.8 7,791 5,444 -5,343 -4,734 999 214,130 2,524,130 25.8 8,087 5,716 -5,615 -4,831 1,065 214,033 2,524,196 21.3 8,215 5,836 -5,735 -4,865 1,091 213,999 2,524,222 18.3 8,354 5,969 -5,868 -4,897 1,117 213,967 2,524,248 15.8 8,473 6,084 -5,983 -4,921 1,137 213,943 2,524,268 14.3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair Well ❑ Plug Perforations El Perforate E Other 0 Complete Performed: Alter Casing ❑ Pull TubingEl Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑ Exploratory❑ 171-029 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑, 6.API Number: Anchorage,AK 99503 50-733-20076-01 7.Property Designation(Lease Number): 8.Well Name and Number: RECEIVED ADL0018731 Trading Bay St/A-12RD 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): FEB 2 7 2015 Trading Bay Field/Middle Kenai C Oil Pool G 11.Present Well Condition Summary: AOGCC Total Depth measured 8,475 feet Plugs measured 6,695 feet true vertical 6,118 feet Junk measured N/A feet Effective Depth measured 6,695 feet Packer measured 6,040 feet true vertical 4,561 feet true vertical 4,122 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,066' 13-3/8" 1,066' 1,061' 3,090 psi 1,540 psi Intermediate 7,490' 9-5/8" 7,490' 5,184' 6,330 psi 3,810 psi Tie Back Liner 7,261' 7" 7,261' 5,001' 11,640 psi 10,750 psi Liner 1,207' 7" 8,468' 6,079' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet SCANNED ANYtD :F True Vertical depth See Schematic feet t!6 Tubing(size,grade,measured and true vertical depth) 4-1/2" 12.6#/L-80 6,068'(MD) 4,138'(TVD) Packers and SSSV(type,measured and true vertical depth) Hyd Set Pkr 6,040'(MD)4,122'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): NIA 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: 0 0 628 1250 1250 Subsequent to operation: 0 0 3342 2 844 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development LI Service El Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ 2 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: 314-559&315-048 Contact Trudi Hallett Email thallett(a hilcorp.com Printed Name Trudi Hallett Title Operations Engineer Signature Phone (907)777-8323 Date 2/27/2015 4 y-Y i s' RBDMS..t MAR - 2 2015 Form 10-404 Revised 10/2012 ; /4,� l�� Submit Original Only l/ Trading Bay Unit : n SCHEMATIC Well #A-12RD Completed: 02/02/15 RKB to TBG Head=34.7' CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 13-3/8" 61 K-55 Butt 12.515" Surf 1066' 9-5/8" 43.5 N-80& Butt 8.755" Surf 7490' P-110 7" 32 P-110 X-line 6.094" 7261' 8468' DV Collar Tie Back @ 2010' 7" 29 N-80 Butt 6.184" Surf 7261' 4 DV Collar Tubing: @ 3,982' 4-1/2" 12.6/13.55 L-80 Butt 3.640" Surf 6,068' OloMIC 1R:O 2 t''C'r 1 U iry1D illC-1 Jewelry Detail NO. Depth (MD) ID Item 34.7 Tubing Hanger C-p 1 6,024' 5.000 3.990 5"Seal Assembly w/15'Seal Bore Receptacle CZNS6 2 6,040' Tri Point Hydraulic Set Liner Top Packer A, C-4 C-5 3 6,057 2.813 X-Nipple 5 4 6,068' 2.991 WLEG C-7 5 6,695' CIBP C-7 C-7 47-5 Milled out of casing somewhere between 6,771'-6,787' 1/30/2015 PERFORATION DATA 47-5 Last Top Btm Top Btm Accum Perf 47-5 Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Present Condition C-1 6,158' 6,183' 4,197' 4,207' 25' 6 01/31/15 Open // ,- 7261' C-2 6,238' 6,314' 4,239' 4,286' 76' 6 01/31/15 Open CZNS6 6,404' 6,418' 4,349' 4,359' 14' 6 01/31/15 Open 4 , C-4 6,444' 6,470' 4,377' 4,395' 26' 6 01/31/15 Open 50-3 C-5 6,528' 6,634' 4,436' 4,515' 108' 6 01/31/15 Open C-7 6,811' 6,851' 4,650' 4,680' 40' 2 12/5/1972 Isolated E. C-7 6,886' 6,926' 4,707' 4,738' 40' 2 12/5/1972 Isolated C-7 6,960' 6,980' 4,764' 4,780' 20' 2 12/4/1972 Isolated 51-647-5 7,092' 7,122' 4,868' 4,892' Isolated 30' 2 12/4/1972 47-5 7,102' 7,122' 4,876' 4,892' 20' 2 3/27/1972 Isolated w/tie back liner ran on 12/1/72 47-5 7,160' 7,180' 4,922' 4,938' 20' 4 12/4/1972 Isolated 50-3 7,514' 7,520' 5,207' 5,212' 6' 2 3/26/1972 Isolated 7,521' 7,522' 5,213' 5,213' 1' 8 3/19/1972 Cmt sgz'd f/bond D Zone 7,700' 7,701' 5,367' 5,368' 1' 4 3/17/1972 Cmt sqz'd f/bond 51-6 7,715' 7,721' 5,380' 5,385' 6' 2 3/26/1972 Isolated 51-6 7,732' 7,740' 5,395' 5,402' 8' 2 3/26/1972 Isolated PBTD=8468' TD=8475' KB ELEV=101' HOLE ANGLE thru Interval=40.7° Updated by: JLL 02/26/15 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-12RD 50-733-20076-01 171-029 12/27/14 2/2/15 Daily Operations: 12/27/14-Saturday Nipple up riser.Couldn't MU riser because spacer spool flange was hitting the main platform support beams. Pull riser back out and turn it over to get spacer spool on top.Stab riser back on and nipple up same. Nipple up BOPE and torque all bolts. Function test BOPE. Make up test joint.Test BOPE on 3 1/2"and 4"pipe at 250 L/3000 H as per sundry.AOGCC(Lou Grimaldi)waived witness of test at 1610 hrs on 12-27-14. 12/28/14-Sunday Test BOPE on 3 1/2" oioe at 250 L/3000 H as per sundry. Pull BPV and install TWC.Test blind rams. Pull TWC.AOGCC(Lou Grimaldi)waived witness of test at 1610 hrs on 12-27-14. MU landing jt. Back out LDS. Pull hanger free w/58k.Wt fell back to 55k. [String wt with blocks to cut should have been 79.6k]well static. Pull hanger to floor. Lay dn hanger and landing jt. POOH washing and laying dn tbg.Spotted a hole in tbg at about 535'and 6'below that the whole side of the tbg was gone for about 8".After that tbg didn't have any holes but it did have 1/4"to 1/2"of scale on the outside of the tbg. Laid down 71 jts and a 4'stub=approx 2,160'of tbg.This should put the top of the fish at about 2,203'.Clean and clear rig floor of tbg equip.Strap 4 3/4 DCs and put them in the door. PU 4 3/4 DCs and stand them back in the derrick.Change out saver sub to HT38. Install wear bushing. P/U M/U BHA#1: Rolling dog overshot(5 3/4"),3 jts 5 3/4"wash pipe,top bushing,double pin sub, bit sub, BS/OJ,9 ea 4 3/4" DC's,XO=400.01. RIH picking up 4" HT38 drill pipe to 778'. Began taking weight and stacking out.Wash and ream as necessary, picking up drill pipe from 778'to 1,813'. Unable to wash down without rotating. Circulate at 8 BPM/800 psi.Getting very brackish returns with lots of scale chips/cuttings over shakers.Circulate hole clean at 8 BPM/800 psi. Recovered 6 bbls of cuttings. Recovered 147 lbs off of ditch magnet. Hole is stable with 0 losses and 0 units of gas. Blow down top drive. POOH with BHA#1. Hung up at 1,530'. Had to circulate stand out after freeing pack-off at 8 BPM/550 psi. 12/29/14-Monday POOH with BHA#1.Stand back DCs. Break off cut lip guide and extension.Stand back WP. PU BHA#2.6"junk mill,4 boot baskets, Bit sub,String magnet, Bumper sub,Oil jars, Pump out sub,9 DCs,XO=338.20. RIH picking up 4" DP to 1,800'. Wash and ream f/1,800'to 2,038'. Never did tag anything. Running 10 BPM,2500 psi and 60 RPM. Nose on saver sub was getting flared out due to setting down on tool joint. Dress saver sub.Continue washing and reaming f/2,038't/estimated top of fish at 2,203'.Still didn't tag anything.Circ bottoms up.Got back 2.5 bbls of scale over shakers and 100 lbs off ditch magnets. Blow dn TD and monitor well.0 BPH loss rate. POOH to BHA.Stand back DCs and lay down boot baskets and mill. PU BHA#3.6"X 4 3/4" mill shoe,T-Dog overshot,9 jts 5 3/4 WP,Top sub, Dbl pin sub, Bit sub w/float, Bumper sub,Oil jars,String magnet, Pump out sub,9 DCs,XO=596.76'.Service rig and equipment. RIH picking up 4" HT38 drill pipe to 2,200'. Establish parameters: Up/Dn/Rot 55K,46K,50K at 40 RPM/5.5 K torque.Circulate STS at 8 BPM/950 psi. No losses and 0 gas units. Engage TOF at 2,206'and saw slight pressure increase to 1000 psi.Wash and ream down to 2,240'. P/U 20' with no overpull.Wash and ream down to 2,298'. P/U 35'with no overpull.Wash and ream down to 2,392'. P/U 35'with no overpull.Wash and ream down to 2,487'and set down 10K. P/U and gained 40K over but pulled off T-dog twice. Pull up to 2,411'and jarred at 115K and pull up to 125K for 6 licks.T-dog slipped off and not able to get another bite. 0 losses while circulating with 0 units of gas. POOH with BHA#3.Work BHA#3. Lay down fish. Recovered 181.01'of tubing. New TOF at 2,390'. P/U M/U BHA#4. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-12RD 50-733-20076-01 171-029 12/27/14 2/2/15 Daily Operations: 12/30/14-Tuesday M/U BHA#4.Cut lip guide,Overshot w/3 7/8 grapple,XO sub,9 jts 5 3/4 WP,Top bushing, Dbl pin sub, Bit sub w/float, Bumper sub,Oil jars,String magnet, Pump out sub,9 DCs, Intensifier jars,XO=606.20'. PU 6 jts of 4" DP. Install safety valve.Service Rig and Top drive. RIH picking up 4" DP to 2,374'. Fill pipe and establish parameters. Up wt 64k, Dn wt 51k, Rt wt 56k.78 spm 860 psi.Wash down over fish at 2,390'and seen 300 psi pressure increase.Wash down to tbg collar at 2,416'. PU to 90k and bleed jars. PU to 100k.Start jarring up at 115 and jar 9 times working jarring up to170k. PU to 175 and lock brake down. Bring pump rate up to 9.5 BPM and fish pulled free. PU w/50k increase to 2,406'and circ while preparing to POOH.Attempt to pull on elevators but pulled tight. Pump out of the hole 3 stds still pulling 50k over our up wt. POOH w/fish on elevators to BHA. Lay dn intensifier jars and stand back 3 stds of DCs. LD magnet,jars and bumper sub. Stand back 2 stds of WP. LD 2 jts of WP. Cut tbg off on the bottom of the jt of WP with the overshot and lay dn in one section. POOH laying down fish [3 1/2 butt tbg]Joint#60 had a 2" hole.Jts 61-135 pulled wet.Jt 135 was packed off.Jts 136 to 143 pulled dry. Recovered 143 joints, 2 pup jts,Seal Assembly and 2'of metering sub.The joint above seal assy has what appears to be partial tubing cut. Clean and power wash rig floor,stairs and cellar area. Clean and organize top deck. Service rig. Lay out and PU BHA#5 as follows: PRT Assy w/3 1/2" Bull Nose,4" PRT Grapple,6' PRT Mill,4 boot baskets, Bit sub w/float, Bumper Sub,Oil Jar,String Magnet, Pump out Sub,9 Drill Collars, Intensifier Jar,XO Sub to Drill Pipe.Total Length=353.52'.TIH with 20 stands 4" HT 38 Drill pipe from Derrick.Continue to TIH from 2,247'to 2,627' picking up 12 jts 4"drill pipe from catwalk.Continue TIH on stands from 2,627'. Daily Magnet Metals Recovered=34.5 lbs.Total Magnet Metals Recovered=286.5 lbs. Daily Average Loss Rate=0 BPH. 12/31/14-Wednesday Wash through tight spots f/2,627't/2,908'. RIH on elevators to 2,995'.Wash f/2,995't/3,579'. RIH on elevators t/5,360'. Wash f/5,360' t/5,450'. PU and had bad spot at 5,430'. Looks like a bad spot in the csg.Work through it again and wash to 5,743'. Continue washing in the hole f/5,743't/top of packer at 6,730'.9 BPM 2470 psi. Wash dn on packer w/PRT. Packer was packed off inside so we wash down to get mill on packer. Mill on packer at 6,730'w/PRT. Mill to 6,731' using varied parameters. Never could get mill to get a good bite or any fair amount of torque.Acted like it was spinning. Did get grapple to grab a couple times and had a 30k overpull, but kept pulling out. Decided to POOH and inspect tool. Blow down TD and monitor well. Hole static. POOH from 6,686'to 353'. Encounter 15K to 20K over pulls @ 5,440'and 5,389'. Work BHA.Clean String Magnet(10Ibs metal)and Junk Baskets(50 lbs Metal)Lay down PRT and recovered what appears to be internal sleeve of PKR on the PRT Grapple. PU BHA#6 as follows: 6"OD Mill Tooth Bit,7"Csg Scraper,4 boot baskets, Bit sub w/float, Bumper Sub,Oil Jar,String Magnet, Pump out Sub,9 Drill Collars, Intensifier Jar,XO Sub to Drill Pipe.Total Length=348.99'. RIH 1 stand to 443'. Service rig. TIH with Scraper Assy from 443'to 6,588'. P/U 128K,S/0 70K. Encountered and wiped through tight spot @ 5,355'. No other issues. M/U Top Drive.Circulate hole volume @ 385 GPM with 1620 psi. No change in solids on shakers @ bottoms up. POOH with Scraper from 6,588'to 5,438'and encounter tight spot in casing with 20-25K over pull. MU Top Drive and work scraper across tight spot several times with pump on.Shut down pump and work scraper across tight spot several more times with pumps off.Still encountering 15-20K over pull. Blow down Top Drive. String Magnet Metals Recovered=10 lbs. Daily Magnet Metals Recovered= 177 lbs.Total Magnet Metals Recovered =473.5.5 lbs.Junk Basket Metals Recovered=50 lbs.Total Metals=523.5. Daily Average Loss Rate=0 BPH. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-12RD 50-733-20076-01 171-029 12/27/14 2/2/15 Daily Operations: 01/01/15-Thursday POOH w/csg scrapper. Had tight spot that we had to work through at 5,438'and 5,358'. Continue POOH to BHA. Stand back DCs,lay dn bit and csg scrapper.Wash out boot baskets with no recovery. Run BHA#7. MU 6" packer mill w/3 1/2 nose mill 4 boot baskets, Bit sub w/float, Bumper sub,Oil jars,String magnet, Pump out sub,9 DCs, Intensifier jar,XO sub =348.47'. RIH w/packer mill to top of packer at 6,731'. Had to work through bad spots in the csg at 5,351',5,360',5,389'. and 5,440'. Break circ and establish parameters. Mill on packer w/3 1/2 nose ext at 6731'. Had trouble getting 3 1/2 nose in packer but after milling it down for 1/2 hr it fell in. Mill on packer for 6"and packer went down hole.Chase to 6,745'and continue milling. Continue milling on packer and pump pressure started to increase. PU 6,705'with pump running and it was pumping us out of the hole.Shut pump down and PU w/a slight increase in up wt. If you turn the pump on it acts like it is packed off and your wt falls off. Hole not swabbing when pulling slow. Decided to POOH slow and inspect tools. Blow dn equip and POOH to 5,480'.Try to screw into jt in the table so we can pump through the tight spots.Saver sub stripped out when we screwed it in. Secure well and change out saver sub. Lay dn and change out 4" DP jt that saver sub stripped out in. Continue to POOH from 5,450'to 348'. Encounter and work through tight spot @ 5,389'with 35K over pull. Work BHA.Clean String Magnet(17 lbs Metal)and Boot Baskets(98 lbs metal). Lay down PKR Mill. Service Rig. M/U BHA#8 RTTS and TIH to 5,295'. P/U 1 single to 5,305'. P/U 100K,S/0 70K. Set RTTS at 5,305'.Set down 25K.Close Annular and test casing to 2500 psi for 30 min.Test good. Release RTTS. Lay down 1 single. POOH with RTTS from 5,295'. String Magnet Metals Recovered=17 lbs. Daily Magnet Metals Recovered=162 lbs.Total Magnet Metals Recovered=635.5 lbs.Junk Basket Metals Recovered=98 lbs.Total Metals=733.5. Daily Average Loss Rate=0 BPH. 01/02/15-Friday Continue POOH w/7" RTTS. Lay dn tools. Clear floor of tools and MU wireline lubricator. RU E-line. RIH w/caliper logging tool to 6,500'and log back to surface. Lay dn tools and RD e-line. PU BHA#8. 6"Junk mill,4 boot baskets, Bit sub w/float, Bumper sub,Oil jars,String magnet, Pump out sub,9 DCs, Intensifier sub,XO=348.37'. Run 1 stand of DP. Cut drilling line. RIH w/junk mill from 442'to 6,681'. MU Top Drive,wash down with no rotation and tag TOF @ 6,747'. Establish parameters: P/U 127K,S/0 74K, Rot 94K,80 RPM, 10.9K free toque.8 BPM 1800 psi. Mill on fish from 6,747'-6,748', adjusting parameters as needed.WOB varied from 2-28K with very little if any change in torque while milling. Monitor well. Break off and blow down Top Drive. Fill trip tank. POOH from 6,748'to 348'(BHA). Work BHA.Clean String Magnet (10 lbs Metal). Lay down Boot Baskets, lay down and inspect Junk Mill. MU BHA#9 with 3 1/4"spear with 4.01 Nominal catch grapple.TIH with DC's and 1 Stand Drill pipe. Clean Boot Baskets(60 lbs Metal).Service Rig. TIH with spear assy from 745'. String Magnet Metals Recovered=10 lbs. Ditch Magnet Metals Recovered=25 lbs.Total Magnet Metals Recovered =675.5 lbs.Junk Basket Metals Recovered=60 lbs.Total Metals=833.5. Daily Average Loss Rate=0 BPH. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-12RD 50-733-20076-01 171-029 12/27/14 2/2/15 Daily Operations: 01/03/15-Saturday RIH to 6,685'. Establish parameters. Work down to top of fish.Tag w/nose at 6,746'started taking 5k and had about 100 psi increase. Kept going down to 6,756' before we sat dn. PU and pull 30k over up wt and fish started moving up hole.Wt fell back to about a 5k over pull,occasionally pulling up to 15k over. POOH slow.Stand back collars and clean off string magnet. Pull up to spear. No recovery. Did get 17.5 lbs off magnet. Lay dn spear. Service rig and top drive. PU BHA#10- 6"X 4 3/4" mill shoe, 2 jts WP,Top Bushing, Dbl pin sub,4 boot baskets, Bit sub w/float, Bumper sub,Oil jars,String magnet, Pump out sub,9 DCs, Intensifier jar,XO=412.17'. TIH from 412'to 6,745'. M/U Top Drive. Establish Parameters. Wash down to TOF @ 6,748.4'pumping 7.5 BPM with 1300 psi.Circulate above fish working pipe to clear junk from top of fish. 130K P/U, 75K S/O,94K Rot. Mill from 6,748.4'to 6,749.4'with 80 TD RPM, 11K TQ, 1-10K WOB. Made 1 foot before mill played out. Set down 40K with no rotation several times. P/U off bottom with 40K over pull and 25K constant drag. Check for flow. Blow down Top Drive. POOH from 6,749'with 20-25K Drag. Had to pull 30-50K over to get through tight spots in casing @ 5,480'to 5,340'. Work BHA. Lay down accel jar,stand back DC's.Clean String Magnet(10Ibs Metal). Lay down Boot Baskets. Lay down Jars and Magnet. Lay down Wash Pipe and Mill Shoe. Recovered 1 ft of fish which appears to be the seal bore extension. Clean out Boot Baskets(12 lbs Metal)Clean and clear rig floor in preparation for BOPE Test. String Magnet Metals Recovered=10 lbs. Ditch Magnet Metals Recovered=87.5 lbs.Junk Basket Metals Recovered =12 lbs.Total Metals=942 lbs. Daily Average Loss Rate=0 BPH. 01/04/15-Sunday Pull wear ring and RU test jt. Land test jt and purge system.Attempt to test w/upper rams and Hydril. Had slow bleed off. Try lower rams with same results. Pull test plug. File dn bad spot on sealing groove and redress.Set test plugs and had same results. Pull test plug again and flush stack down through wellhead. Re-dress test plug. Land plug and purge system. Test all BOP equip to 250 and 3000 psi. Had 4 fail/passes. Had to tighten door on blind rams,grease and operate#6 choke manifold valve, and pull apart and clean both manual chokes on choke manifold. PVTs and Gas Alarms passed all tests.Test witnessed by Jeff Jones w/AOGCC. RD test equip and set wear ring. Lay down running tool.C/O elevators. P/U BHA#11 as follows:Taper Tap w/4 1/8" nose to 5 3/8"top, 1 jts WP,Top Bushing,6"OD String Mill, Dbl pin sub,4 boot baskets, Bit sub w/float, Bumper sub,Oil jars,String magnet, Pump out sub,9 DCs, Intensifier jar,XO=386.68. RIH 1 stand Drill Pipe to 480'. Service Rig. TIH from 480'to 5,300'. M/U Top Drive. Establish Parameters: 7.5 BPM,950 psi,80 TD RPM,9400 free TQ, 10-11K Milling TO, Up Wt 110K, Dn Wt 74K, Rt Wt 85K. Work String Mill in tight spots at 5,338'to 5,420'. Pull past same depths with a little over 5K over pulls. Continue to TIH on elevators from 5,500'to 6,699'. M/U Top Drive,establish parameters. Pumps Off 140K Up Wt, Pumps on @ 5 BPM w/590 psi Up/wt 133K,S/O 85K.Wash down with no rotary and tag top of fish @ 6,749'with 2k dn/wt.Start working Tapered Tap into suspected top of fish from 6,749 to 6,751'. Pick Up hole with pumps on @ 140K.S/O to top of fish again working tap. Pick up hole with pumps off and 145K Up Wt.5K over. Monitor Well. Blow down Top Drive. POOH from 6,700'to 2,000'. String Magnet Metals Recovered =0 lbs. Ditch Magnet Metals Recovered=15 lbs.Junk Basket Metals Recovered=0 lbs.Total Metals=967 lbs. Daily Average Loss Rate=0 BPH. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-12RD 50-733-20076-01 171-029 12/27/14 2/2/15 Daily Operations: 01/05/15-Monday POOH w/taper tap. Recovered 7 lbs off string magnet. PU to bottom of string mill and WP had broken off at the thread on the drive sub. Left 1 jt of 5 3/4 WP,and a taper tap in the hole.34'long. Lay dn drive sub,string mill,and boot baskets. No recovery from boot baskets. 7lbs f/string magnets. Service rig.Work on hyd adjustment to speed up ST80. Work on general rig maintenance while waiting on tools coming on boat. PU BHA#12. Itco Spear[4 7/8 to 5.041,XO sub,stop sub w/5 1/2 stop ring, bumper sub,oil jars,string magnet,pump out sub,9 DCs,intensifier jars,XO=326.75. RIH w/spear 6,686'. Fill pipe and get parameters. Slack off and go into top of WP fish at 6,718'and slid spear into top of WP to 6,721'. PU w/a 10k overpull.Then it fell back to 5k with a occasional extra 3 to 4K overpull. Blow dn TD. POOH with spear to BHA. Work BHA.Stand Back DC's. Lay down fish(spear with wash pipe/taper tap). Lay down all fishing tools and wash pipe from derrick. TIH with 2 stands DC's. MU RTTS. TIH with RTTS from 180'to 6,500'. Set RTTS at 6,500'.Set down 25K.Close Annular and test casing to 2500 psi for 30 min.Test good. Release RTTS. Blow Down Top Drive. POOH with RTTS from 6,500'to surface with RTTS. Reconfigure RTTS with Storm Valve. RIH 2 stands and set RTTS @ 190'. Release from Storm Valve,stand back 2 stands. Lay down Stinger. Pressure test Storm valve below blind rams to 2500 psi and chart for 30 min. String Magnet Metals Recovered =16.5 lbs. Ditch Magnet Metals Recovered=10 lbs.Junk Basket Metals Recovered =10 lbs.Total Metals= 1003.5 lbs. Daily Average Loss Rate=0 BPH. 01/06/15-Tuesday , Pressure test storm valve and packer 2 stds dn.Test to 2500 psi for 30 min on a chart.Good test. Blow dn equip and drain /f stack. Nipple dn BOPS and trolley stack to the side. RU picking eye on riser. Continue breaking bolts on tbg spool and remove spool. Cut and remove remaining bolts. Prep stub and new spool. Install new TBG Spool.Test Void to 3000 psi for 15 Min.Test Good.Assist crane crew with working the boat. N/U BOPE and associated equipment. String Magnet Metals Recovered=0 lbs. Ditch Magnet Metals Recovered=0 lbs.Junk Basket Metals Recovered=0 lbs.Total Metals=1003.5 lbs. Daily Average Loss Rate=0 BPH. ETOF @ 6,749'. Land test plug.Close blind Rams and test Shell to 250/3000psi.Test good. Pull and lay down test plug. TIH 2 stands and retrieve RTTS/Storm Valve.Stand back drill pipe and 2 stands drill collars. Clear rig floor to run 2 7/8" Kill String. RIH picking up 2 7/8"tubing Kill String to 1,783'. MU Tubing hanger and land tubing 1,825'. RILDS. 01/07/15-Wednesday R/dn tbg handling equipment. L/dn landing jt set BPV. Nip dn BOPE trolley out of way. Pull riser. Drain pits to production. Start clean same. Set nip/up dry hole tree.Test void 250-5000 psi, 15 min each,Ok. Pull BPV. Install TWC and test tree t/ 250-5000 psi 15 min each,ok. 01/25/15-Sunday Install BPV. Nipple down tree. Install riser. Nipple up BOPE. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-12RD 50-733-20076-01 171-029 12/27/14 2/2/15 Daily Operations: 01/26/15-Monday Nipple up BOPE.Get BOPs set on riser.Tighten bottom flange on riser and the break under the BOPs.Swap choke and kill line flanges. Finish nippling up all assorted BOP equip. Function test all BOP equip. MU 4"test jt.and test sub on Topdrive. Screw into hanger with test jt.Attempt to fill stack. Had to tighten flange on mud line coming through deck. Fill stack and purge lines. Test BOPS with,4"and 2 7/8"to 250 low and 3000 psi high as per sundry. Unable to get a test on annular with 2 7/8". Received okay to proceed as per Jim Regg(AOGCC)at 2115 hrs on 1-26-15.Test all gas alarms and PVTs.Witness of test was waived by Jim Regg.Assist e-line with RU off to the side of the rig,and have them punch holes in A-12 tbg f/ 3,790't/3,810'. Lay down test joint. Pull TWC valve. Blow down lines and drain choke manifold. Make up landing joint. Back out lock down screws. Unseat tubing hanger and pull up 5'. Circulate STS volume at 8 BPM/700 psi. Monitor well. Well is static. Pull and lay down landing joint and tubing hanger. POOH laying down 2 7/8" kill string. Pick up BHA#1: 4.961"spear,stop sub,XO,double pin sub,bit sub, BS/OJ,9 ea 4 3/4" DC's,Acc Jars,XO=319.80. Rig down Weatherford tongs. Install wear bushing(9" ID).Clear rig floor.Well is static. 01/27/15-Tuesday RIH with BHA#1(spear assembly). Fill pipe at 3,025'and continue RIH to 6,743'. Fill pipe and circ bottoms up.Get parameters. 150k up,77k dn,4 BPM,360 psi.Work dn and started to see increase in pump press and started taking wt at 6,749'.Set dn 10k. PU with slight drag and still had 15 psi in pump pressure. Kill pump and set 20k dn. PU with slight drag. Blow dn TD and mud line. POOH to BHA. LD acc jars and stand back DC. Pull spear to the floor. No fish or marks on grapple like it had been ahold of the fish. Lay dn spear. Service rig. MU BHA#2.Spear dressed with 4.010 grapple, DbI pin sub, Bit sub w/float, Bumper sub,Oil jars, Pump out sub,9 DCs,Acc jars,XO=317.18'. RIH to 3,545'and fill pipe.Continue RIH to 6,740'. Change dyes in TD grabber. Circ hole clean. Establish parameters.4 BPM 460 psi,Tag fish at 6,749'had a pressure increase of 300 psi.Set there 1 min and pressure fell back to 460 psi.Set down f/10k to 30k several times with no increase in up wt. Never did get another pressure increase and couldn't seem to get worked into the fish. Blow down and POOH from 6,743'to 317'. Lay down Accel Jar,stand back drill collars,inspect and lay down spear. No recovery. MU BHA#3 with 5 3/4"Wash Pipe Ext,Top Sub, Double Pin Sub,3) Boot Baskets, Bit sub with float,String Magnet, Bumper Sub,Oil Jar, Pump Out Sub.Attempt to make up Rotary shoe and discovered the threads were TSWP and not TSS. Service Rig while expediting Rotary Shoe to Heliport. Mill shoe on board at 2400 hrs. MU 6"x 4 3/4" MM Rotary Shoe.TIH 350'to 750'. Continue to TIH from 750'to 6,652'. MU Top Drive,fill pipe. Establish parameters: Pu Wt 152K, Dn Wt 74K, Rot Wt 95K,5 BPM,500 PSI,60 RPM. Tag TOF @ 6,750'. Mill on fish with Rotary Mill Shoe from 6,750'. String Magnet Metals Recovered =0 lbs. Ditch Magnet Metals Recovered=0 lbs.Junk Basket Metals Recovered=0 lbs.Total Metals=1003.5 lbs. Daily Average Loss Rate=0 BPH. ETOF @ 6,749'. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-12RD 50-733-20076-01 171-029 12/27/14 2/2/15 Daily Operations: 01/28/15-Wednesday Mill over fish w/6"X 4 3/4"mill shoe f/6,750'to 6,755'. Blow dn TD and POOH to 4,941'. The hub broke on the hyd pump cooling fan.Can't use ST 80 so we rigged up the air spinners. Had PJSM and continued POOH to BHA. Pull 15k over coming through tight spot at 5,389't/5,340'. Stand back DCs and break off mill shoe. Mill shoe was about 50%worn on the face and outside.The cutters on the inside were only wore for the first 1",after that they looked new.Apparently washed over something smaller than 4 3/4". Lay dn and clean boot baskets and string magnet. Recovered 9 lbs off boot baskets and 12 lbs off the magnet. Mu BHA#4.5 5/16 X 3 1/2 Box tap, Dbl pin sub, Bit sub w/float,String magnet, Bumper sub,Oil jars, Pump out sub,9 DCs,Acc jars,XO=328.62'. RIH to 3,710'and fill pipe.Continue RIH to 6,745'. Circ 1 full circ to get all the air out. Establish parameters.150k up,75 dn,94 rt,5 BPM 470 psi, 10 rpm,7k torque. Rotate dn over fish and started to gain pump press at 6,751'.Torque increased to 12k but kept falling off. Made several attempts setting down up to 30k. Pressure fell off and never would press up again no mater how much was set dn. Did have a couple of 20k overpulls but wt kept falling back to normal up wt. Made it down to 6,755'. Blow dn TD and POOH. Lay down Box tap BHA and recovered 2.32'of fish.Appears to be seal bore extension. Recovered 11 lbs metal from string magnet. PU BHA#5: 6"OD 6 bladed MM Junk Mill,3) Boot Baskets, Bit sub w/float,String magnet, Bumper sub,Oil jars, Pump out sub,9 DCs,Acc jars,XO= 342.66'. TIH with BHA#5 from 342'to 6,486'(65 stds). Inspect and C/O Saver Sub. Continue TIH to 6,750'. MU top drive. Fill Pipe.Tag TOF no rotation @ 6,755'with 10K dn. Establish parameters: Pu Wt 150K, Dn Wt 75K, Rot Wt 94K,5 BPM, 840 PSI,60 RPM,8-9K TQ. 2-3K WOB.Start Milling from 6,755'to 6,764'. CBU @ 9 BPM,2130 psi. Mostly metal fines @ bottoms up.Continue milling from 6,764'to 6,766'. Service rig. String Magnet Metals Recovered= 11 lbs. Ditch Magnet Metals Recovered=47 lbs.Junk Basket Metals Recovered=0 lbs.Total Metals=1061 lbs. Daily Average Loss Rate=0 BPH. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-12RD 50-733-20076-01 171-029 12/27/14 2/2/15 Daily Operations: 01/29/15-Thursday Mill on junk w/6"mill f/6,766't/6,771'. Couldn't make any more hole and pump pressure would fall off a couple hundred lbs when we picked the string up off bottom. Blow dn TD and POOH to BHA. Lay dn acc jars and stand back DCs. Pull up and everything below magnet was left in the hole.6"junk mill,3 Boot baskets, Bit sub,&2.05'of the bottom of the magnet were left in the hole=22.97'.This leaves us a 4 7/8" FN.Clean magnet and recovered 10.5 lbs. Service rig and TD. MU overshot w/4 7/8 grapple and RIH to 6,725'. Break circ and establish parameters. Rotate at 20 RPM and work dn on fish.As soon as we saw a slight pressure increase we shut dn rotation.Slide down over and set dn 10k w/200 psi pressure increase. PU and pressure did not fall off.Set back down 20k and pressure increased 300 psi. PU and pressure didn't bleed off, plus we had a 3k increase in up wt. Blow dn and POOH. Recovered all of BHA. Lay down BHA.Clean Junk Baskets.Junk Baskets had 27 lbs mostly coal,some cement chunks and very little metal. PU BHA#7: 6"OD 6 Concave bladed MM Junk Mill,3)Boot Baskets, Bit sub w/float, Bumper sub,Oil jars, Pump out sub,9 DCs,Acc jars,XO=331.85'. Service rig. TIH ,l from 426'to 6,750'. MU Top Drive.Wash down to 6,769'. Rotate down to 6,771'. Circulate bottoms up before milling r ^,�',�11� ahead @ 11 bpm with 2320 psi. Had fine sand/coal and very little metal @ bottoms up. Establish milling parameters @ 5 BPM,550 psi,60 RPM,8.8K TQ„ 5-10 WOB. Mill from 6,771'to 6,776' 10-15 fph average.Very little reactive torque. �` Suspect drilling formation. Circulate Bottoms Up from 6,776'. No metals mostly fine coals at bottoms up.Consult with 04'5 Project Engineer. Decision made to mill 10' looking for calculated TOF @+/-6,782'. Mill from 6,776'to 6,787'with same parameters 22 fph average. Circulate bottoms up at same rate. Had mostly coal fines and no metals.Consult with project engineer. Decision made to swap hole over to clean fluid and run camera and bond log. Circulate and monitor well while prepping for fluid swap.Shut down pump periodically and monitor for flow.Well static at 05:00 hrs. String Magnet Metals Recovered=0 lbs. Ditch Magnet Metals Recovered =25 lbs.Junk Basket Metals Recovered=0 lbs.Total Metals=1086 lbs. Daily Average Loss Rate=0 BPH. • Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-12RD 50-733-20076-01 _ 171-029 12/27/14 2/2/15 Daily Operations: 01/30/15-Friday Circ hole clean while rigging up to change over to clean FIW. Test transfer lines and start pumping dirty FIW to production shipping line. Fill reserve pit with clean FIW. Pump 100 bbls to production and start to displace well with clean FIW. Pump 508 bbls clean FIW through well before returns cleaned up at the shakers. Continue pumping dirty fluid to production while blowing down TD and POOH to BHA. [Pumped 783 bbls dirty FIW to production]. Lay dn Acc jars and stand back DCs. Break and lay dn the rest of the BHA.Clean Boot baskets. Recovered 37 lbs of coal and metal.Only about ten percent was metal.Clear floor of fishing tools. Unload e-line equip off boat and spot same.Continue cleaning pits. Rig E-Line and lubricator. RIH with GR/CCL.Set down @ 6,708'WLM. PUH logging GR/CCL from 6,700'to 6,400'. Down load and send logs to Mr. Frankforter. POOH with GR/CCL. MU Casing Caliper Log tool string. RIH with Csg Caliper logging tool,set down @ 6,755'WLM. PUH and encounter over pull @ 6,743'. Log casing from 6,734'to 6,400'. POOH from 6,400'with casing caliper. Down load and review Caliper Log with Mr.Taylor via phone call to confirm CIBP setting depth of 6,695'. Lay down Casing Caliper logging tool. Rehead E-Line for CIBP setting tool. MU CIBP to E-Line. RIH with BOT 3BBN-1, 7" 17#-35#CIBP to 6,713'. Log CCL and tie into casing collars from previous Casing Caliper log.(CCL to middle of Element=9.20') Park @ 6,685.80'CCL, placing the center of CIBP @ 6,695'. Initiate setting sequence with 1100 lbs line tension dropping to 600 bbls after 55 seconds.Wait 5 minutes. PUH with 900 lbs line tension. RIH and tag BP to confirm. POOH with CIBP Setting Tool. Lay down setting tool and rig down E-line. Close blinds and test top of CIBP to 1500 psi.Chart same for 30 minutes. String Magnet Metals Recovered=0 lbs. Ditch Magnet Metals Recovered=26 lbs.Junk Basket Metals Recovered=0 lbs.Total Metals=1112 lbs. Daily Average Loss Rate=0 BPH.Shipped 783 bbls FIW to Trading Bay. r• Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-12RD 50-733-20076-01 171-029 12/27/14 2/2/15 Daily Operations: 01/31/15-Saturday Rig dn test equip and service rig.Clear floor of tools that we won't be needing. Pull wear ring. RU to test rams and Hydril on 4 1/2".Test to 250 and 3000 psi. No failures. RD test equip.Set wear ring. Prep to PU perf guns. MU safety jt. Hold PJSM. RIH picking up 4.5",6 SPF, 135 deg phase perf guns. PU firing head, 1 jt 3 1/2 tbg, Ported flow sub, 2 jts 3 1/2 tbg, RA marker sub,XO,=585.96'. RIH w/perf guns on 4" DP to 6,634' Bull Plug Depth DPM. PU 10' Pup jt. MU Bar Drop Assy and set aside. Rig up E-Line. RIH with 1 11/16'tools GR/CCL tool string.Tie into GR/CCL log dated Fri Jan 30,2015. Locate RA marker @ 6,045'WLM. Placing top shot @ 6,153'(5'shallow). POOH with E-Line.Set E-Line aside. Slack off on Dp 10'. PU 2'to string wt and park @ 6,642' DPM. RIH with E-Line and tie into same GR/CCL log and locate RA marker at 6,053'+/- WLM.Confirm tie in with town and to move up hole 2.5'. POOH with E-Line. Rig down E-Line. Pick up hole 2.5', placing the RA marker @ 6,050'and top shot @ 6,158' WLM. MU Bar drop/pump in sub assembly. PJSM on perforating. Close annular and line up on choke manifold. Drop bar with detonation after 4 minutes. Circulate 42 bbls through choke @ 4 bpm with 350 psi. Losses while circulating through choke were.84 bpm.Open annular and CBU x2 @ 6 bpm 660 psi with 66 max gas units. Loss rate while pumping=24 bph. Rig down bar drop assy. Lay down 10'pup jt. Monitor well on trip tank with 6 bph static loss rate. POOH from 6,640'to 600'. PJSM on laying down perf guns. Lay down perf guns. Clean up rig floor. Remove gun handling equipment from rig floor. Perform Injectivity test: @ 1BPM: 1 bbl=125 psi, 2 bbl=180 psi, 3 b1=200, 4 bbl=220 psi, 5 bbl=230 psi, 6 bbl=235, 7 bbl=240, 8 bbl=240 psi, 9 bbl=250 psi, 10 bbl=250. Rig up to run Packer on drill pipe. Ru Weatherford tongs etc. String Magnet Metals Recovered=0 lbs. Ditch Magnet Metals Recovered= 0 lbs.Junk Basket Metals Recovered=0 lbs.Total Metals= 1112 lbs.Static Loss Rate=6 BPH. @ 2BPM: 11 bbl=365 psi, 12 bbl=410 psi, 13 bbl=430, 14 bbl=450 psi, 15 bbl=465 psi, 16 bbl=480, 17 bbl=490, 18 bbl=500 psi, 19 bbl=500 psi, 20 bbl=500. @ 3BPM: 21 bbl=600 psi, 22 bbl=640 psi, 23 bbl=690, 24 bbl=715 psi, 25 bbl=740 psi, 26 bbl=750, 27 bbl=760, 28 bbl=765 psi, 29 bbl=780 psi, 30 bbl=790, 31 bbl=795, 32 bbl=810, 33 bbl=815 psi, 34 bbl=820 psi, 35 bbl=820. Bleed off From 820 psi: 1 min=540 psi, 2 min=117 psi, 3 min=85 psi, 4 min=68 psi, 5 min 50 psi. 02/01/15-Sunday Service rig and TD. RIH w/packer on 4" DP t/5,301'.Set dn 10k.Took 25k to pull free. Work through tight spot at 5,301' by setting dn 15k and working back up,not pulling over 25k. Using pump to help work free on the up stroke.After about 1 1/2 hrs we got it worked down to 5,393'where it wouldn't go dn anymore with 15k.Called town and the decision was made to put more wt on the packer to push it through.Set 25k and packer went right through the tight spot. RIH to and set packer on depth at 6,040'. Drop ball. RU to circ. Pump slow watching for ball to seat.Took 19 min for ball to seat. Pressure up on packer to 3500 psi.Saw good indication of packer setting at 2900 psi. Hold pressure on packer for 30 min. Bleed pressure off DP and test ann to 2500 psi for 10 min on a chart. [This tested the packer.Will test again when we land out].Good test. Release from packer.Top of seal bore 6,023.74,top of packer at 6,040'. POOH with packer running tool and lay dn same. Pull wear bushing. MU 5"Seal Bore Assy. Hold PJSM on running 4 1/2"completion. Pick up and RIH with 4 1/2",poly lined,extended Butt tubing.Tag and locate top of seal bore on jt#193 in hole @ 6,027'. Pass seals through seal bore and no go @ 14.5'in on jt 194. PU to String wt.Close bag and PT to 500 psi to verify seal in.Space out tubing. MU tubing hanger. l+ Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date A-12RD 50-733-20076-01 171-029 12/27/14 2/2/15 Daily Operations: 02/02/15-Monday rfi. � MU landing jt and MU hanger. Pump and spot packer fluid on back side. Land hanger and run in LDS.Test back side to 2500 psi for 30 min on a chart. LD and break dn landing jt and set BPV. Nipple dn BOP. Unbolt annular remove from cellar. PU stack and trolley to the side. Pull riser and clean up wellhead. Nipple up tree.Test hanger void to 5000 psi. Pull BPV set TWC.Test tree to 5000 psi. Pull TWC set BPV.Skid Rig from A-12RD. RELEASE RIG FROM A-12RD @ 24: 00HRS.Total Metals = 1112 lbs. Daily Losses to well=18 bbls. Total fluid loss to well=147 bbls. OF Tye �w1�j,.4. THE STATE Alaska Oil and Gas -t-=d�� of F•,;. LASIc:A Conservation Commission -:_ _ A " � — 333 West Seventh Avenue ►wh GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276 7542 www.aogcc.alaska.gov Ted Kramer SCONEE° I r 9 j 0 i` Operations Engineer �[(Jr Hilcorp Alaska, LLC I 1 I 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C Oil Pool, Trading Bay St A-12RD Sundry Number: 315-048 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 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, rarzf? Daniel T. Seamount, Jr. Commissioner DATED this day of February, 2015 Encl. . RECEIVED STATE OF ALASKA JAN 3 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon 0 Plug for Redrill ❑, perforate Nev Pool❑ Repair Well 0 Change Approved Program Q , Suspend 0 Plug Perforations[fes.I TCP Perforate Q , Pull Tubing Q - Time Extension 0 Operations Shutdown CI Re-enter Susp.Well ❑ Stimulate❑ Alter Casing❑ Other. Complete ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development ❑ 171-029 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service Q • 6.API Number. Anchorage, AK 99503 50-733-20076-01 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO g38 Will planned perforations require a spacing exception? Yes ❑ No ❑., / Trading Bay St/A-12RD• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018731 Trading Bay Field/Middle Kenai C 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): 8,475 , 6,118 , 8,468 , 6,079 , N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1,066' 13-3/8" 1,066' 1,061' Intermediate 7,490' 9-5/8" 7,490' 5,184' Tie Back Liner 7,261' 7" 7,261' 5,001' Liner 1,207' 7" 8,468' 6,079' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6,811'-7,740' - 4,650'-5,402' 3-1/2" 9.2*/N-80 Butt 7,057 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker Model F Pkr&Baker Model D Pkr/SSSV:N/A • 6,730'(MD)4,588'(TVD)&7,037'(MD)4,825'(TVD) /SSSV:N/A 12.Attachments: Description Summary of Proposal Q 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: 1/30/2015 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: /-3c••-/5 WINJ 0 ' GINJ El WAG ❑ Abandoned ❑ Commission Representative: C Sc:Li;4.,(L, GSTOR ❑ SPLUG CI17.I hereby certify that the foregoing is trued correct to the best of my knowledge. Contact Ted Kramer Email tkramer@hilcorp.com Printed Name Ted Kramer Title Operations Engineer Signature "7-"- l� Phone (907)777-8420 Date 1/30/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '‘S— O'-16 Plug Integrity ❑ BOP Test Q Mechanical Integrity Test ❑., Location Clearance ❑ Other: _ 7— Spacing Exce tion Required? Yes L p q ❑ No Subsequent Form Required: �I C% "�� APPROVED BY /4—// Approved by: COMMISSIONERt� JTHE COMMISSION Date: l'k`- i 1 11.341/ "7,4A-� 1$Submd Form and Form 10-403( ised 10/2012) / ORdiaGeitiN,Acto:12 months from the date of approval. Anachme in Duplicate RBDMS FEB - 6 2015 • Well Work Prognosis Well: A-12rd Hilrorp Alaska,LLC Date: 01/30/2015 Well Name: Monopod A-12RD API Number: 50-733-20076-00 Current Status: Water Injector Leg: N/A Estimated Start Date: November 15,2014 Rig: Monopod Platform Rig#56 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 171-029 First Call Engineer: Ted Kramer (907)777-8420(0) (985)867-0665 (M) Second Call Engineer: Dan Marlowe (907)283-1329 (0) (907)398-9904(M) AFE Number: Current Bottom Hole Pressure: 2,018 psi @ 4,617'TVD Based on SIBHP survey 10/23/2013 Maximum Expected BHP: -2,100 psi @ 4,617'TVD Adding one add'C-Zone sand within the C-Zone Pool currently open Max.Anticipated Surface Pressure: -462 psi Using 0.1 psi/ft gradient per 20 MC 25.280(b)(4) Brief Well Summary The A-12RD is operating under an Administrative Approval dated 2013-09-25.This well has communication between the tubing and inner annulus. It currently is on injection at a rate of 350 bpd with 1,100 psi on the tubing.This work-over will restore tubing integrity,cleanout the well, and increase injection rates back to 4,000 bpd. Change to approved program:(Sundry#314-559) Due to milling damage to the casing,changes to the approved program are listed below. A review of cement integrity was completed per AOGCC request: t 5� C ( t P :i6�7c)- Dresser Atlas Cement Bond Log ran on 12/02/72 showed the following: 6,688' up to 6490'(90%bonded) 6,490' up to 6,400' (80%bonded) 7"cs� 6,400 up to 6,250'(90%bonded) 6,250' up to 6,170(70%bonded) 6,170 up to 6,028(90%bonded) There is a good spot at 6,050'to set the packer with 90%bonding 20 feet above and below of good cement bond. Procedure: 1. Skid rig and RU over A-12rd. 2. RU E-line. Make 2" Gauge Ring Run to determine if we can make an inside cut above lower packer. If plugged cut in middle of first full joint above metering sub. If open cut in middle of first full joint above lower packer. 3. Cut tubing in middle of first full joint above upper packer. POOH and RD E-line. 4. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250psi LOW and 3,000psi HIGH. 5. PU landing joint and make-up to tubing hanger. Pull hanger up to floor height by pulling free from tubing cut.Circulate Hydrocarbons from well. Well WoWrkelPrognosis 2rd Hilrorp Alaska,LLC Date: 01/30/2015 6. POOH, LD tubing. 7. RIH latch onto tubing stub above upper packer. 8. POOH with seals and LD tubing. 9. Mill and retrieve upper injection packer. • In an attempt to recover the upper injection packer, it was determined that Rig #56 had gone outside of the casing somewhere between 6,771'and 6,787'. packer. POOH, LD tubing. - • . 13. Clean out fill to+/ 8,000'.Circulate with FIW to clean wellbore. POOH. • RIH w/downhole camera to evaluate damaged casing • RIH w/caliper log from 6,650' up to 6,500' looking for good spot to set CIBP (NOTE: we already have a caliper log from 6,500'to surface) • Set bridge plug+/-6,700' 14. ' - - . - - - -. - . - ' _ e'. - .- - , test casing to ^'2,500 psi and chart for 30 minutes. 15. POOH 200' and PU storm packer. RIH and set same at 200' and hang off string. Pressure test to 1,500 2,500 psi(perAOGCC edits in approved sundry)and chart. Release from storm packer, POOH. Replace tubing head. Test lower flange to 2500 psi.Shell test BOPE. (per AOGCC edits in approved sundry) 16. RIH, engage storm packer, release same, POOH, LD storm packer and retrievable packer. • NOTE: Steps#14 through#16 were completed prior to having run the kill string on Jan. 6, 2015. 17. PU TCP guns and RIH and perforate per Perf Recommendations. • New perforations (C-1 through C-5 sands within the Middle Kenai C Pool) - attached on edited proposed schematic) 18. After detonation, circulate perf gas, confirm well is static, POOH. 19: PU injection packer and plastic lined tubing. • , • - -. - . _ e' • - . perforatien)(per AOGCC edits in approved sundry) • RIH w/packer at+/-6,050' (within 200' of top perforation) 20. Spot 1-2%by volume Packer fluid on backside. 21. Land the tubing hanger and set packer. 22. Conduct WO MIT, pressure test annulus to—2,500 psi and chart for 30 minutes. 23. Set BPV. NU tree,test same. 24. Place well on injection. Well is expected to take between 4,000 and 5,000 bwpd at full header pressure and new perforations. 25. Schedule the Initial MIT and apply to retract A1O 12.003(Admin Approval)with AOGCC within 2 weeks of stable injection.(perAOGCC edits in approved sundry) Attachments: 1. Original Well Schematic 2. Proposed Well Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram S. BOP Stack Trading Bay Unit . .11 SCHEMATIC Well #A-12RD Re-Completed: 12/8/72 RKB to TBG Head=34.7' CASING AND TUBING DETAIL Tree connection:? SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt 12.515 Surf. 1066' G , 9-5/8" 43.5 N-80&P-110 Butt 8.755 Surf 7490' 7" 32 P-110 X-line 6.094 7261' 8468' I I Tie Back [JV Collar 29 N-80 Butt 6.184 Surf 7261' ©:o10 Tubing: 3-1/2" 9.2 N-80 Butt. 2.992 0' 7057' 1 c ><1 i 2 NO. Depth Item o s 34.7 3-1/2"CIW 8rd X Butt Tubing Hanger I1 6730' Locator Seal Assy.w/8.2'of seals. C-7 2 6730' Baker Model"F"Pkr. Cl 3 6780' Otis Metering Sub C-7 4 7028' Locator Seal Assy.w/20.02'of seals. 5 7037' Baker Model"D"Retainer Production Packer 4 6 7055' Otis"N"Profile Ni le,2.875 = PP >"A 5 7 7056' Mule Shoe 6 btm 7057' /7 47-5 =47-5 STIMULATIONS 47-5 Acid Squeeze w/Mutual Solvent 3/72 Acid Squeeze 12/72 X 7261' Z \ PERFORATION DATA Accum Last 50-3 Zone Top Btm Amt SPF Perf Date Present Condition C-7 6,811' 6,851' 40' 2 12/5/1972 Open for Injection § C-7 6,886' 6,926' 40' 2 12/5/1972 Open for Injection ll C-7 6,960' 6,980' 20' 2 12/4/1972 Open for Injection 47-5 7,092' 7,122' 30' 2 12/4/1972 Open for Injection 7,102' 7,122' 20' 2 3/27/1972 Isolated w/tie back liner 51-6 47-5 ran on 12/1/72 47-5 7,160' 7,180' 20' 4 12/4/1972 Open for Injection s 51-6 50-3 7,514' 7,520' 6' 2 3/26/1972 Open for Injection 7,521' 7,522' 1' 8 3/19/1972 Cmt sqz'd f/bond 7,700' 7,701' 1' 4 3/17/1972 Cmt sqz'd f/bond 51-6 7,715' 7,721' 6' 2 3/26/1972 Open for Injection PBTD=8468' TD=8475' 51-6 7,732' 7,740' 8' 2 3/26/1972 Open for Injection KB ELEV=101' HOLE ANGLE thru Interval=40.7° DRAWN BY: SLT Trading Bay Unit PROPOSED Well #A-12RD Completed: Future RKB to TBG Head=34.7' _ CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 1 I 13-3/8" 61 J-55 Butt 12.515" 39.00' 1066' d 9 5/8" 43.5 N-80& Butt 8.755" 39.00' 7490.00' P-110 _ 7" _ 32 P-110 X-line 6.094" 7260.97' 8468.00' DV Collar Tie Back @ 2010' 7" 29 N-80 Butt 6.184" 36.30' 7260.97' DV aTubing: @ 3,982'Collr 12.6/13.55 L-80 Butt 3.598" Surf ±6,040' NO. Depth Depth ID Item mowiiii t4 (MD) (TVD)1IM134,7 Tubing Hanger ±6,000 Tri-Point Stim-Top Production Packer C-1 C-2 CZNS6 3 ±6,030' X-Nipple 4 ±6,040' WLEG C-4 2 C-5 5 ±6,700 CIBP 5 SIA C-7 C 7 * Milled out of casing somewhere between 6,771'-6,787' 1/30/2015 C7 PERFORATION DATA Last -2 Top Btm Top Btm Accum Perf * • 47-5 Zone (MD) (MD) (ND) (ND) Amt SPF Date Present Condition '(\'57 �"�` C-1 ±6,158' ±6,183' ±4,197' ±4,207' ±25' 6 Future , '",// 47-5 C-2 ±6,238' ±6,314' ±4,239' ±4,286' ±76' 6 Future 1 CZNS6 ±6,404' ±6,418' ±4,349' ±4,359' ±14' 6 Future 47-5 C-4 ±6,444' ±6,470' ±4,377' ±4,395' ±26' 6 Future C-5 ±6,528' ±6,634' ±4,436' ±4,515' ±108' 6 Future C-7 ±6,811' ±6,851' ±4,650' ±4,680' Re-perf 4 7261' 40' 2 12/5/1972 Open for Injection C-7 ±6,886' ±6,926' ±4,707' ±4,738' Re-perf 40' 2 12/5/1972 Open for Injection C-7 ±6,960' ±6,980' ±4,764' ±4,780' Re-perf 50-3 20' 2 12/4/1972 Open for Injection 47-5 ±7,092' ±7,122' ±4,868' ±4,892' Re-perf 30' 2 12/4/1972 Open for Injection 47-5 7,102' 7,122' 4,876' 4,892' 20' 2 3/27/1972 Isolated w/tie back liner 51-6 ran on 12/1/72 47-5 ±7,160' ±7,180' ±4,922' ±4,938' Re-perf 20' 4 12/4/1972 Open for Injection 50-3 ±7,514' ±7,520' ±5,207' ±5,212' Re-perf 6' 2 3/26/1972 Open for Injection 7,521' 7,522' 5,213' 5,213' 1' 8 3/19/1972 Cmt sqz'd f/bond 7,700' 7,701' 5,367' 5,368' 1' 4 3/17/1972 Cmt sqz'd f/bond D Zone 51-6 ±7,715' ±7,721' ±5,380' ±5,385' 6' Re-perf 2 3/26/1972 Open for Injection 51-6 ±7,732' ±7,740' ±5,395' ±5,402' 8' Re-perf 2 3/26/1972 Open for Injection PBTD=8468' TD=8475' KB ELEV=101' HOLE ANGLE thru Interval=40.7° Updated by: TRH 1-30-15 • . ti Monopod Platform A-12RD Current Wellhead 10/14/2014 IIiIroth ,la't,,,.I.LA. Monopod Tubing hanger,CIW-DCB, A-12RD 11 X 3 1/2 EUE lift and 13 3/8 X 9 5/8 X 7 X 3 1/2 3 1/2 IBT susp,w/3" type H BPV profile, 6'/,"EN a o p rj) Tree,Block,CIW-F,11 5M FE X 3 1/8 5M,double master .0/�• and wing,6'/.pocket T` ,. • prepped for control line exit, EE trim A .,, /1.1) ill p(V I tin , r- 1, et t,) Tubing head,CIW-DCB, x. i ri r:.: 13 5/8 3M X 11 5M,w/2- ur } ill 2 1/16 5M EFO,X-bottom Valve,CIW-F,2 1/16 SM FE, prep w/1%:VR profile 1.04 HWO,AA 01 i in — _ ui .,. 111 Casing spool,CIW-WF, Ili ' iii Valve,CIW-F,2 1/16 5M FE, 13 5/8 3M X 13 5/8 3M, _ 4241 HWO,AA w/2-2 1/16 5M SSO Ni r , ") g-j, Ili = ; um Casing head,Shaffer-KO, r 135/83MX 13"SOW II i bottom,w/2"LPO III III � � Ili ) r 1 •• 2"LP plug valve a • Monopod Platform A-12RD Proposed Wellhead 10/14/2014 IfHenrp.11;14a.1.1.1: Monopod Tubing hanger,SME-Cl,11 X A-121304 Y WE lift and 41',TC-2 13 3/8 X 9 5/8 X 7 X 4 1/2 susp,w/4"Type Ft BPV profile,2.3/8 CO.,611 extended neck,17.4PH stainless steel BHTA,Bowen,4 1/16 SM X 7"-5 SA Bowen Union Full Stainless Steel ME I 11111M111 I io^/2 - Valve,Swab,WKM-M, 0 0e / `t 4 1/16 5M FE,HWO,FF trim t;1.f Q `''l,a- ,, o 10 �' Valve,Wing,WKM-M, 3 1/8 5M FE,w/15"Safeco \ ---/ — operator,FF trim /' Full Stainless Steel Valve,Master,WKM-M, ; 4 1/16 5M FE,HWO,FF trim - O.JO _ 1 C' Q Adapter,Seaboard,11 5M FE 111 - X41/16 SM,w/6Y.pocket, UN i 2-Y,CCL exits,Full Stainless •-=-7.'4---•, Steel . _..-:._.._r. MI Tubing head,S-8,13 5/8 3M iIIl lik pg(r� x 11 SM,w/2.2 1/16 SM 1 '� .i 0 tflttf SSO,w/BG bottom i7 0 r „ �Lj sv/1-21/I6SM1NKM-M - - " .- �pD�p�_I111'• valves h 1111 iii 1E 7I 1�1 Valve,C11V-F,21/16 SM FE, Casing spool,CIW-WF, f / t 1 HWO,AA 135/83M X 135/83M, m) [O�q�o, 1Nl• w/2-2 1/16 SM 550 ;. l g 1I1 ' 111 tf s Casing head,Shaffer-KO, ii 135/83M X13"SOW 111 '' - bottom,w/2"LPO �." 2"LP plug valve III ) 2 Uri' i IK • • • Monopod Platform 2014 BOP Stack(Wor'cover) 10/07/2014 nilrorla nii.kll,11.1d: Rig floor Bottom of to boot Iltr.bc l l r. 1 I S.bcto.v rig Ilam 142' 97' illi I I ++e 4 54' • Hydril ' 26.25' III III I11ill IIl 7 7/85.5 Vzdab!es 2.83' . f--- Wind _ • 71/165.'.1 mmoot and 21/16 SMmanual and 1.76• UCR vel:es lot shote tilde III 111 111 111 III IICR vak:s 30+1;4 11 _0I'{ 1 'i,o.'):774;11011"41' �� r 111 rt' mill I/1 ° �� • • 27/85.5 Varl4b!es II III III IJII I Witted 11.00' li lii iil til III III 'III III Is' I til til til II • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) or t Sent: Friday,January 30, 2015 4:02 PM v To: 'Ted Kramer'; Bettis, Patricia K(DOA) Cc: Trudi Hallett;Juanita Lovett Subject: RE:A-12RD Change of Program Sundry(315-048) - PTD#171-029 Ted, You have verbal approval to procedure with the new sundry( PTD 315-048)as proposed. I have your sundry application in hand and will get it to you early next week. Make sure you have this email on location. Guy Schwartz Senior Petroleum Engineer AOGCC 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). Original Message From:Ted Kramer [rnailto:tkramer@hilcorp.com] Sent: Friday,January 30, 2015 3:55 PM To: Schwartz,Guy L(DOA); Loepp,Victoria T(DOA) Cc:Trudi Hallett;Juanita Lovett Subject: A-12RD 9-5/8" Casing- PTD#171-029 Guy, Attached is what we found on the 9-5/8" casing string. The 9-5/8" cement job was circulated to surface-535 cu ft. of cement returns. Therefore we should have cement behind the 9-5/8" as well. I would like to ask for verbal approval to continue the A-12RD workover program change based on this information. Respectfully, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 1. Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday,January 30, 2015 10:19 AM To: 'Ted Kramer'; Bettis, Patricia K(DOA) Cc: Trudi Hallett; Dan Marlowe; Marvin Rogers- (C);James Lott - (C) Subject: RE:A-12 Program Change - Sundry#314-559, PTD#171-029 Ted, My sundry copy (on the proposed perfs) shows the top perforation to be at C-5 6528-6634' on the original sundry. There are no Cl or C4 perfs ... your packer depth was proposed at 6420' and now will be somewhere near 6000 ft. md. Also.. due diligence needs to be done regarding the cement coverage behind the casing strings. For some reason I didn't catch this in my first review of the sundry. Guy Schwartz Senior Petroleum Engineer AOGCC 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 1 or(Guy.schwartz@alaska.aov). From:Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Friday,January 30, 2015 10:08 AM To: Schwartz, Guy L(DOA); Bettis, Patricia K (DOA) Cc: Trudi Hallett; Dan Marlowe; Marvin Rogers-(C); James Lott- (C) Subject: RE: A-12 Program Change - Sundry # 314-559, PTD #171-029 Guy, These are not NEW perfs (from the original Sundry),they were included in the original Sundry, we are just dropping off the bottom perfs and adding a plug above the casing damage. Do we still need a new Sundry? Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday,January 30, 2015 9:59 AM To:Ted Kramer; Bettis, Patricia K(DOA) 1 Cc: Trudi Hallett; Dan Marlowe; Marvin Rogers- (C); James Lott-(C) Subject: RE: A-12 Program Change - Sundry # 314-559, PTD #171-029 Ted, This will take a new sundry... ("change approved operation"). Since you are moving uphole a significant amount & adding new perfs you will need to re-verify cement coverage ( behind both 7" and 9 5/8" casing) above your new proposed packer setting depth. We can expedite the sundry we get the supporting data right away. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 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(Guy schwartz@alaska.gov). From:Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Friday, January 30, 2015 9:30 AM To: Schwartz, Guy L(DOA); Loepp, Victoria T(DOA) Cc:Trudi Hallett; Dan Marlowe; Marvin Rogers-(C); James Lott- (C) Subject: A-12 Program Change - Sundry # 314-559, PTD #171-029 Guy and Victoria, This morning at 0300 Hilcorp determined that Monopod Rig#56 had had gone outside of the casing on the above well somewhere between 6,771 and 6,787 feet. We started recovering coal and cement pieces over the shakers. We have shut down milling operations and are currently swapping the fluid to clear FIW in order to make a camera run to determine where we went out. The new plan forward for this well is as follows: 1.) Circ well to clean fluid. POH. 2.) Run Camera looking for bad csg. 3.) Run a Caliper log from 6,650(+/-) up to 6500' looking for good spot to set CIBP (Note: We already have a caliper log from 6,500'to surface). 4.) Set bridge plug at approx.6700' [To be determined] 5.) Run perf guns and perf Cl through C-5 from 6158'to 6634. [Approx] 6.) Run injection completion with PKR set+/-100 feet above top perf. I have attached a new perf request form of what we intend to perforate. It says draft on the form,that will be changed to final once we shoot the intervals. Please let me know if this causes the AOGCC any concerns or questions. Respectfully, 2 1 Ted Kramer Sr.Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 3 I64. P7-6 (7(O Z`tu Regg, James B (DOA) From: Marvin Rogers - (C) <mrogers@hilcorp.com> / Sent: Tuesday, January 27, 2015 3:10 PM N e�(( �I Z�();— To: Regg, James B (DOA) Subject: RE: Monopod A-12RD BOP Test I just checked with the Toolpusher that did the accumulator test and he told me that he had operated the upper rams twice.That is probably why we had the longer time for full pressure up. When I noticed you E-mail we had just got out of the hole and the blinds were closed. This gave me a good opportunity to check the accumulator. I thought maybe one of the pumps was air locked because we had repaired several drip type leaks during the skid and nipple up. Everything seems to be in good working condition. Thank you for the heads up. flHilcorp Alaska, LLC Mg`✓i , R n;lei s DSM Monopod Platform SCANNED �i•' [907] 776-6675 E-Mail: mrogers@hilcorp.com From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, January 27, 2015 2:03 PM To: Marvin Rogers - (C) Subject: RE: Monopod A-12RD BOP Test Good report. One of the trends we track is accumulator performance–"200psi Attained" and "Full Pressure Attained"–1/26/15 test results were 45 and223sec, respectively. Looking at accumulator performance since the beginning of September, the time to attain full pressure has trended from approx. 170sec to 223sec (only 3 tests prior to the last one exceeded 200sec)–the previous 4 tests were 186sec (12/28), 177sec (1/4), 198sec (1/11), and 183sec(1/17). Suggest this be checked into. Thank you. Jim Regg Supervisor, Inspections AOGCC 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 iim.regg@alaska.gov. 1 , From: Marvin Rogers - (C) [mailto:mrogers(ahilcorp.com] Sent: Tuesday, January 27, 2015 7:55 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Juanita Lovett; Trudi Hallett Subject: Monopod A-12RD BOP Test UHilcorp Alaska, LLC Ri,v%vt Rre+er s DSM Monopod Platform [907] 776-6675 E-Mail: mrogers@hilcorp.com 2 - STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 662 )1274 BOPE Test Report Submit to: jim.reggta'�.alaska.gov AOGCC.Inspectors(a alaska.gov phoebe.brooks(cD.alaska.qov Contractor: Kuukpik Rig No.: 56 - DATE: 1/26/15 Rig Rep.: Davidson/Borgen Rig Phone: 776-6675 Operator: Hilcorp Alaska Op Phone. 776-6675 Rep.: Rogers/Brumley E-Mail mrogers@hilcorp.com Well Name: TBU A-12RD - PTD# 1710290 • Sundry# 314-559 Operation: Drilling: Workover: X Explor.: Test: Initial. X Weekly: Bi-Weekly: Test Pressure(psi): Rams: 250/3000 • Annular: 250/3000 - Valves: 250/3000 -MASP: 1639 psi MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P Well Sign P - Upper Kelly 1 P Housekeeping P - Rig P - Lower Kelly 1 P PTD On Location P • Hazard Sec. P Ball Type 1 P Standing Order Posted P Misc. NA Inside BOP 1 P FSV Misc 0 NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 3/8"5M F ✓ Pit Level Indicators P P #1 Rams 1 2 7/8 x 5 VBR ' P - Flow Indicator P P #2 Rams 1 13 3/8"Blind P - Meth Gas Detector P P ' #3 Rams 1 2 7/8 x 5 VBR -. P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA Quantity Test Result Choke Ln.Valves 1 3 1/8"5M P Inside Reel valves 0 NA HCR Valves 2 1/16 x 3 1/8"5 P Kill Line Valves 1 2 1/16"5M P Check Valve 0 NA . ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3025 P CHOKE MANIFOLD: Pressure After Closure(psi) 1275 P Quantity Test Result 200 psi Attained(sec) 45 P No. Valves 14 P Full Pressure Attained(sec) 223 - P - Manual Chokes 2 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles Avg. (#and psi): 6 @ 2316 P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures 1 Test Time: 7.5 Hours Repair or replacement of equipment will be made within 0 days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov 1 Remarks: Tested on 4"and 2 7/8"test joints. Unable to get a test on annular preventer with 2 7/8"test joint Received verbal and written okay from Jim Regg to proceed as per e-mail on 1-26-15 at 2115 hrs.Tested H2S and methane gas sensors with no failures. L_- A-f4&C,C„i AOGCC Inspection 24 hr Notice Yes Date/Time 1/25/2015 6:00 Waived By Jim Regg Test Start Date/Time: 1/26/2015 14:30 (date) (time) Witness ,Test Finish Date/Time: 1/26/2015 10:00 PM Form 10-424(Revised 06/2014) BOP Kuukpik 56 1-26-2015 A-12RD.xlsx • Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, January 26, 2015 10:53 PM To: Rick Brumley- (C); Marvin Rogers - (C); Paul Mazzolini;James Lott - (C); Luke Keller; Dan Marlowe; Shane Hauck; Robert Borgen - (C);Jim Davidson - (C) Cc: Schwartz, Guy L(DOA) Subject: RE:Annular Preventer A-12RD Thank you for documenting our conversation. It is as we agreed. Good luck. Jim Regg Supervisor, Inspections AOGCC 907-793-1236 Sent from Samsung Mobile Original message From: "Rick Brumley- (C)" <rbrumley@hilcorp.com> Date: 01/26/2015 9:31 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg@alaska.gov>,"Marvin Rogers - (C)" <mrogers@hilcorp.com>,Pau1 Mazzolini <pmazzolini@hilcorp.com>,"James Lott - (C)" <jlott@hilcorp.com>,Luke Keller <lkeller@hilcorp.com>,Dan Marlowe <dmarlowe@hilcorp.com>,Shane Hauck <shauck@hilcorp.com>,"Robert Borgen - (C)" <rborgen@hilcorp.com>,"Jim Davidson- (C)" <jdavidson@hilcorp.com> Subject: Annular Preventer A-12RD Monopod 56, A-12RD Workover-Injector Mr. Regg, As we were unable to get a test on the 13 3/8" annular preventer with 2 7/8" tubular I contacted you at 2110 hrs on Monday,January 26, 2015. We have 1825' of 2 7/8" kill string in the well at this time. We were able to obtain good tests on the 2 7/8" x 5" variables in the upper and lower rams. We are presently working with 4" HT38 drill pipe and the completion string will be 4%2"tubing. As per our conversation it was agreed that we could continue with our operations with a 4" safety joint made up and ready for use while pulling the kill string. Hilcorp appreciates the allowance to move forward! Thank you, Rick Brumley Hilcorp DSM Monopod Platform 776-6875 Office 232-5709 Cell 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, January 05, 2015 4:34 PM To: 'Marvin Rogers - (C)'; Ted Kramer Cc: Trudi Hallett; Juanita Lovett; Dan Marlowe; Daniel Taylor Subject: RE: A-12RD Running a Kill String and Moving to A-13 - Sundry # 314-559, PTD# 171-029 Ted, Plan looks good for moving off the well and securing it. Should have you an approved A-13 sundry very soon. Guy Schwartz Senior Petroleum Engineer AOGCC 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 (Guy.schwartz(Ealaska.gov). From: Marvin Rogers - (C) [mailto:mrogers@hilcorp.com] Sent: Monday, January 05, 2015 3:56 PM To: Ted Kramer; Schwartz, Guy L (DOA) Cc: Trudi Hallett; Juanita Lovett; Dan Marlowe; Daniel Taylor Subject: RE: A-12RD Running a Kill String and Moving to A-13 - Sundry # 314-559, PTD# I think we have close to the same plan. Hilcorp Alaska, LLC mal-vw Rogers DSM Monopod Platform [907] 776-6675 E -Mail: mrogers@hilcorp.com SQA# JAN 1 5 2015 From: Ted Kramer Sent: Monday, January 05, 2015 3:47 PM To: 'Schwartz, Guy L (DOA)' Cc: Trudi Hallett; Juanita Lovett; Dan Marlowe; Daniel Taylor; Marvin Rogers - (C) Subject: RE: A-12RD Running a Kill String and Moving to A-13 - Sundry # 314-559, PTD# Guy, Here is the work we plan to do on A-12RD prior to moving to A-13: 2.) PU RIH with Test packer to 6,500' (+/-) and set. Pressure test casing to 2,500 psi. Test on Chart for 30 minutes. 3.) Release RTTS, PU hole and pick up Storm valve to run on top of RTTS. Run in hole two stands and set. Pressure test same to 2,500 psi. on chart. 4.) Release off of Storm valve. 5.) ' ND BOP and change out wellhead. 6.) NU BOP and test. RIH and release RTTS packer. POOH with same. 7.) PU and Run in hole with 1,800' of kill string. 8.) Secure well, install BPV, ND BOP, NU wellhead and test. 9.) Prep to Skid Rig to A-13. Performing the casing pressure test now will give us time to plan the completion for A-12RD if the casing should not pass. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 From: Schwartz, Guy L (DOA)[_riaiIto: guy.schwa rtz(aalaska.gov] Sent: Monday, January 05, 2015 2:14 PM To: Ted Kramer Cc: Trudi Hallett; Juanita Lovett; Dan Marlowe; Daniel Taylor Subject: RE: A-12RD Running a Kill String and Moving to A-13 - Sundry # 314-559, PTD# Ted, I would like to see a detailed plan of how you will suspend the current well A-12RD first... Do you have a preferred place that is better to stop operations on A-12RD? You may keep working on the same sundry (314-599) when you return as soon as you finish A-13 ESP swap. An email of the procedure will be fine. A-13 ESP Swap sundry should be approved shortly. Guy Schwartz Senior Petroleum Engineer AOGCC 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 if, 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, January 05, 2015 1:31 PM To: Schwartz, Guy L (DOA) 2 Cc: Trudi Hallett; Juanita Lovett; Dan Marlowe; Daniel Taylor Subject: A-12RD Running a Kill String and Moving to A-13 - Sundry # 314-559, PTD# Guy, The Monopod Rig is currently on the A-12RD injection well pulling the current completion under the above Sundry. As you are probably aware from working on the A-13 Sundry, A-13 which is the largest well on the Monopod platform (500+ BOPD) , experienced an ESP Failure last week. As soon as we receive the approved Sundry to repair A-13, Hilcorp plans to run a kill string and move off of A-12RD and pull and replace the ESP in A-13. We then will come back and finish the A-12RD injector. In light of this development, I wanted to let you know of Hilcorp's plan and ask what we need to do Sundry wise when we come back to A-12RD. Do we need to close out and resubmit this sundry, or, can we come back to this well under the current Sundry after the 7 to 10 days required to pull and replace A-13? Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 Here is the new plan -POH and lay do all the Baker fishing tools. -Run 2 stands of DCs in the hole and PU the RTTS -RIH w/ RTTS and set at 6500' -Test csg to 2500 psi for 30 min on a chart. If it won't test keep moving it up the hole until it does. -After test POH to RTTS and PU storm valve on top of it. -RIH 2 stds and set RTTS. Test csg to 2500 psi. -Release from storm valve and stand back DP. -Nipple down BOPs and change out tbg spool. -Nipple up BOPs and do a body test to 250 and 3000 psi. L__=,V�Tel� _17� -RIH and retrieve RTTS and stand back DCs. -� old -PU and run 1800' of 2 7/8 kill string and land out in new spool. -Set BPV and nipple do BOPS. -Nipple up sng valve tree and test. -Skid rig to A-13 (- '(")4,? SSP ) Mout igAr-K. 7D 14'tZ9 Hi1mris Alla ka. IJA, Monopod A-12RD 13 3/8 X 9 5/8 X 7 X 3 1/2 Tree, Block, CIW-F,115M FE X 3 1/8 SM, double master and wing, 6 X pocket prepped for control line exit, EE trim Casing spool, CIW-WF, 13 5/8 3M X 13 5/8 3M, w/ 2- 21/16 SM SSO Casing head, Shaffer -KD, 13 5/8 3M X 13" SOW bottom, w/ 2" LPO Monopod Platform A-12RD Current Wellhead 14/14/2014 Tubing hanger, CIW-DCB, 11 X 3 1/2 EUE lift and 31/2 IBT susp, w/ 3" type H BPV profile, 6 V EN V -F, 21/16 5M FE, HWO, AA IW -F, 21/16 SM FE, HWO, AA dug valve Tubing head,ClW-DCB, �( - 135/83MX11SM, w/2 - 21/16 5M EFO, X -bottom z 1/16 prep w/ 1 % VR profile Casing spool, CIW-WF, 13 5/8 3M X 13 5/8 3M, w/ 2- 21/16 SM SSO Casing head, Shaffer -KD, 13 5/8 3M X 13" SOW bottom, w/ 2" LPO Monopod Platform A-12RD Current Wellhead 14/14/2014 Tubing hanger, CIW-DCB, 11 X 3 1/2 EUE lift and 31/2 IBT susp, w/ 3" type H BPV profile, 6 V EN V -F, 21/16 5M FE, HWO, AA IW -F, 21/16 SM FE, HWO, AA dug valve Hilnxp :1Ttt«ka. TJA. Monopod A-12RO 13318X9518X7X41/2 BHTA, Bowen, 41/16 5M X 7"-5 SA Bowen Union Full Stainless Steel Valve, Swab, WKM-M, 4 1/16 5M FE, HWO, FF trim Valve, Master, WKM-M, 41/16 SM FE, HWO, FF trim ` Tubing head, 5.8, 13 5/8 3M N x115M,W/2.211165M SSO, w/ BG bottom w/ 1- 21/16 5M WKM-M valves Casing spool, CIW-WF, 13 5/8 3M X 13 5/8 3M, w/ 2- 21/16 SM SSO Casing head, Shaffer -KO, 13 5/8 3M X 13" SOW bottom, w/ 2" LPO Monopod Platform A-12RD Proposed Wellhead 10/14/2014 Tubing hanger, SME-CL,11 X 4 Y,.EUE lift and 4 Y. TC -2 susp, w/4" Type H BPV profile, 2.3/8 CCL, 6 Y extended neck, 17-4PH stainless steel Valve, Wing, WKM-M, 31/8 SM FE, w/ 15" Safeco operator, FF trim Full Stainless Steel Adapter, Seaboard, 11 SM FE X 4 1/16 SM, w/ 6 Y. pocket, 2- Y, CCL exits, Full Stainless Steel Valve, CIW-F, 21/16 SM FE, HWO, AA 2 -LP plug valve PT -0 1T1 -U7_9 Loepp, Victoria T (DOA) From: Regg, James B (DOA) Sent: Wednesday, December 24,2014 12:26 PM To: Loepp, Victoria T (DOA) Subject: FW: Monopod A-12RD Rolling BOP Test Contingency Plan, PTD 171-029, Sundry # 314-559 Follow Up Flag: Flag Status: Follow up Flagged Good observations from Lou. Hilcorp probably does not have an alternate profile for setting a plug (they should confirm) but they could use a RTTS or other slip -style plug to get the BOPE tested. Jim Regg Supervisor, Inspections AOGCC 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. From: Grimaldi, Louis R (DOA) Sent: Wednesday, December 24, 2014 12:07 PM To: Regg, James B (DOA) Subject: RE: Monopod A-12RD Rolling BOP Test Contingency Plan, PTD 171-029, Sundry # 314-559 Yes I did and the test procedure in itself seems OK although I wonder if opening up all those pathways with tubing punches and cutters prior to nipple down/up is wise. I would suggest looking at setting a profile plug or lacking a landing nipple a slip style plug to get BOPE on and then do the wireline work. I am on my cellphone if you would like to discuss. - - -->: Lou Lou Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission (907) 776-5402 (Home) (907) 252-3409 (Cell) SCANNEID JAN 0 5 2015 -------- Original message -------- From: "Regg, James B (DOA)" Date: 12/24/2014 11:39 (GMT -09:00) To: "Grimaldi, Louis R (DOA)" Subject: FW: Monopod A-12RD Rolling BOP Test Contingency Plan, PTD 171-029, Sundry # 314-559 Did you have a chance to review this procedure? Seems to be different from what we have approved in past; I am looking for past approval for comparison. I'd appreciate your thoughts. Jim Regg Supervisor, Inspections AOGCC 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 iim.regg@alaska.gov. From: Regg, James B (DOA) Sent: Tuesday, December 23, 2014 12:22 PM To: Grimaldi, Louis R (DOA) Subject: FW: Monopod A-12RD Rolling BOP Test Contingency Plan, PTD 171-029, Sundry # 314-559 Jim Regg Supervisor, Inspections AOGCC 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 iim.regg@alaska.gov. From: Loepp, Victoria T (DOA) Sent: Tuesday, December 23, 2014 12:21 PM To: Regg, James B (DOA) Subject: FW: Monopod A-12RD Rolling BOP Test Contingency Plan, PTD 171-029, Sundry # 314-559 Rolling BOP test for your review - From: Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Tuesday, December 23, 2014 10:45 AM To: Loepp, Victoria T (DOA) Cc: Schwartz, Guy L (DOA); Daniel Taylor; Dan Marlowe; Juanita Lovett; Shane Hauck; Rick Brumley - (C) Subject: Monopod A-12RD Rolling BOP Test Contingency Plan, PTD 171-029, Sundry # 314-559 Victoria, To further our phone conversation from yesterday, I have attached a copy of our plan on testing BOP's on our next well in the event we run into problems with the well head. We will attempt to test the BOP's as stated in the Sundry, but I felt it was prudent to have a contingency plan in place since it is the Holiday weekend. Attached is the procedure of how we will test the BOP if corrosion prevents us from testing in the normal fashion. We anticipate being on the A-12RD late Friday if our schedule holds. I believe I told you on the phone that Lou Grimaldi was going to be out on the Monopod early this morning and that we would walk through the procedure with him. As luck would have it, we are currently on a weather hold for flying due to fog, and are trying to get him out on a boat but that has not been finalized at this point. Please let me know if you have any Questions or concerns, Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 Loepp, Victoria T (DOA) From: Regg, lames B (DOA) Sent: Monday, December 22, 2014 3:21 PM To: Loepp, Victoria T (DOA); Grimaldi, Louis R (DOA) Subject: RE: A-12RD PTD # 171-029, Sundry #314-559 Rolling BOP test Follow Up Flag: Follow up Flag Status: Flagged There is a pre -approved procedure for Hilcorp to use in conducting BOPE tests when a BPV or TWC cannot be installed due to a damaged profile. Guy and I were involved in those discussions and it has been used on several wells. I don't have any issues with it being used here if they follow the same procedure. Lou might — based in discussions tomorrow - identify improvements in the procedure so let's wait for his feedback before responding. Jim Regg Supervisor, Inspections AOGCC 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 iim.regg@alaska.gov. From: Loepp, Victoria T (DOA) Sent: Monday, December 22, 2014 2:57 PM To: Regg, James B (DOA) Subject: FW: A-12RD PTD # 171-029, Sundry #314-559 Rolling BOP test Proposal for rolling BOP test on Monopod injector if threads on wellhead bad. MPSP is 1639 psi. Lou will be out there tomorrow. How do you want this handled? From: Ted Kramer [mailto:tkramer@hilcorp.com] Sent: Monday, December 22, 2014 2:29 PM To: Loepp, Victoria T (DOA) Subject: A-12RD PTD # 171-029, Sundry #314-559 Victoria, As we discussed on the phone, we will most likely be rigging up to test BOPS' on this well this weekend. My question / concern is that this well is the first injector we have worked on on Monopod and we do not know what the condition is of either the BPV profile or the lift threads for setting a 2 -way check. Since this week is a Holiday rolling into the weekend, I would like to get the procedure prepared as to how we will change the wellhead on this well in the event the above occurs. We have shut the injector down in preparation for the workover and the injection pressure bled to zero psi., 45 minutes after shutting off injection. Therefore, I do not believe the well is going to try to flow back at us. Lou Grimaldi is planning to be on the platform tomorrow. Our DSM, Shane Hauck, is planning on showing him how we plan on handling a "Rolling BOP" situation, I will write up tomorrow afternoon and send it to you for comment. Thanks, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907-777-8420 C 985-867-0665 THE STATE Dan Marlowe GOVERNOR SEAN PARNELL Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 SCANNED NOV Q 7 2014 Anchorage, AK 99503 Re: Trading Bay Field, Middle Kenai C Oil Pool, Trading Bay St A-12RD Sundry Number: 314-559 Dear Mr. Marlowe: k-11-021 Alaska Oil and Gas 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 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, Cathy 1Foerster Chair DATED this G� d of October, 2014 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION �o I3IlH APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED OCT 14 2014 h7.3 / d J 2.31/l 4— AQrr,r 1. Type of Request: Abandor ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ • Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. Complete 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑ Stratigraphic ❑ Service 171-029 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20076-01 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 938 Will planned perforations require a spacing exception? Yes ❑ No / Trading Bay St / A-12RD ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018731 I Trading Bay Field / Middle Kenai C Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8,475 • 6,118 '8,468 .6,079 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,066' 13-3/8" 1,066' 1,061' Intermediate 7,490' 9-5/8" 7,490' 5,184' Tie Back Liner 7,261' 7" 7,261' 5,001' Liner 1,207' 7" 8,468' 6,079' Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): 6,811' - 7,740' 4,650' - 5,402' 3-1/2" 9.2# / N-80 Butt 7,057 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker Model F Pkr & Baker Model D Pkr / SSSV: N/A 6,730' (MD) 4,588'(TVD) & 7,037' (MD) 4,825'(TVD) / SSSV: N/A 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El, Exploratory ❑ Stratigraphic ❑ Development ❑ Service [ ' 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/15/2014 Oil ❑ Gas ❑ WINJ E] • GINJ ❑ WDSPL [I Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(ftilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signaturelip�,..__ Phone (907) 283-1329 Date 10/13/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Ltl Mechanical Integrity Test L!d Location Clearance ElOther: ��C�I- %C -S T < MA 5J4 - `%39 1c (it I-1-i►,.-� Deer .c ` /kL /4ZD lZ Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY �// Approved by: 7� COMMISSIONER THE COMMISSION Date: /&. Zo - /y Form 10-43 (Revised 10/2012) Rj Q I 1Aa oh'1111 -6 20t �/BCMS NOV Submit Form and A p,,.N AL 12 months from the date of approval. Attachments in Duplicate Hileorp Alaska, LLC Well Work Prognosis Well: A-12rd Date: 09/30/2014 Well Name: Monopod A-12rd API Number: 50-733-20076-00 Current Status: Water Injector Leg: N/A Estimated Start Date: November 15,2014 Rig: Monopod Platform, Rig # 56 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 171-029 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP: open Max. Anticipated Surface Pressure: 2,018 psi @ 4,617' TVD Based on SIBHP survey 10/23/2013 -2,100 psi @ 4,617' TVD Adding one add'I C -Zone sand within the C -Zone Pool currently' -462 psi ? Using 0.1 psi/ft gradient per 20 AAC 25.280(b)(4) _ Brief Well SummaryL2 _ OtAs P The A-12rd is operating under an Administrative Approval dated 2013-09-25. This well has communication between the tubing and inner annulus. It currently is on injection at a rate of 350 bpd with 1,100 psi on the tubing. This work -over will restore tubing integrity, cleanout the well, and increase injection rates back to 4,000 bpd. ' Prnrarb i ra 1. Skid rig and RU over A-12rd. 2. RU E -line. Make 2" Gauge Ring Run to determine if we can make an inside cut above lower packer. If plugged cut in middle of first full joint above metering sub. If open cut in middle of first full joint above lower packer. 3. Cut tubing in middle of first_full joint above upper packer. POOH and RD E -line. 4. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250psi LOW and 3,000psi HIGH. 5. PU landing joint and make-up to tubing hanger. Pull hanger up to floor height by pulling free from tubing cut. Circulate Hydrocarbons from well. 6. POOH, LD tubing. 7. RIH latch onto tubing stub above upper packer. 8. POOH with seals and LD tubing. 9. Mill and retrieve upper injection packer. 10. If lower tubing was plugged wash over and make an outside cut in middle of first full joint above lower packer. POOH, LD tubing. 11. RIH latch onto tubing stub above lower packer. POOH with seals and LD tubing. 12. Mill and retrieve lower injection packer. 13. Clean out fill to +/- 8,000'. Circulate with FIW to clean wellbore. POOH. 14. PU retrievable test packer and RIH to 6,750'. Set packer, test casing to-2,500._p1i and chart for 30 minutes. Lr-` 15. POOH 200' and PU storm packer. RIH and set same at 200' and hang off string. Pressure test too psi and chart. Release from storm packer, POOH. Replace tubing head. fi� Ott -J - 4 z sQ-a 13 L S LV -T-, - 6 c) P. Hileorp Alaska, LLC Well Work Prognosis Well: A-12rd Date: 09/30/2014 16. RIH, engage storm packer, release same, POOH, LD storm packer and retr}'evable packer. 17. PU TCP guns and RIH and re -perforate per Perf Recommendations. `� 18. After detonation, circulate perf gas, confirm well is static, POOH. 19. PU injection packer and plastic lined tubing. RIH, with packer at �O' (within 200' of top perforation). 20. Spot 1-2% by volume Packer fluid on backside. 21. Land the tubing hanger and set packer. 22. Conduct WO MIT, pressure test annulus to 2,500 psi and chart for 30 minutes. 23. Set BPV. NU tree, test same. 24. Place well on injection. Well is expected to take between 4,000 and 5,000 bwpd at full header pressure and new perforations. 25. Schedule the Initial MIT with AOGCC within 2 weeks of stable injection. Attachments: �i.� -1 AA IZ . U o 3 1. Current Well Schematic �pP ` L� 2. Proposed Well Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Stack RKB to TBG Head = 34.7' Tree connection: ? ov Collar @ 2010' 1 2 3 C-7 C-7 C-7 4 5 6 7 47-5 47-5 47-5 7261' 50-3 51-6 51-6 PBTD = 8468' TD = 8475' KB ELEV = 101' HOLE ANGLE thru Interval = 40.7° SCHEMATIC SIZE WT 13-3/8" 61 9-5/8" 43.5 7" 32 Tie Back N-80 & P-110 Butt 8.755 7" 29 Tubing: 7261' 3-1/2" 9.2 Trading Bay Unit Well # A-12RD Re -Completed: 12/8/72 CASING AND TUBING DETAIL Depth Item GRADE CONN ID TOP BTM. K-55 Butt 12.515 Surf. 1066' N-80 & P-110 Butt 8.755 Surf 7490' P-110 Vine 6.094 7261' 8468' N-80 Butt 6.184 Surf 7261' N-80 Butt. 2.992 0' 7057' NO. Depth Item PERFORATION DATA 34.7 3-1/2" CIW 8rd X Butt Tubing Hanger 1 6730' Locator Seal Assy. w/ 8.2' of seals. 2 6730' Baker Model "F" Pkr✓ 3 6780' Otis Metering Sub 4 7028' Locator Seal Assy. w/ 20.02' of seals. 5 7037' Baker Model "D" Retainer Production Packer 6 7055' Otis "N" Profile Nipple, 2.875 7 7056' Mule Shoe 6,960' him 7057' 20' STIMULATIONS Acid Squeeze w/ Mutual Solvent 3/72 Acid Squeeze 12/72 DRAWN BY: SLT PERFORATION DATA Zone Top Btm Amt Accum SPF Last Perf Date Present Condition C-7 6,811' 6,851' 40' 2 12/5/1972 Open for Injection C-7 6,886 6,926' 40' 2 12/5/1972 Open for Injection C-7 6,960' 6,980' 20' 2 12/4/1972 Open for Injection 47-5 7.092' 7,122' 30' 2 12/4/1972 Open for Injection 47-5 7,102' 7,122' 20' 2 3/27/1972 Isolated w/ tie back liner ran on 12/1/72 47-5 7,160' 7,180' 20' 4 12/4/1972 Open for Injection 50-3 7,514' 7,520' 6' 2 3/26/1972 Open for Injection 7,521' 7,522' 1' 8 3/19/1972 Cmt sgz'd f/ bond 7,700' 7,701' 1' 4 3/17/1972 Cmt sgz'd f/ bond 51-6 7,715' 7,721' 6' 2 3/26/1972 Open for Injection 51-6 7,732' 7,740' 8' 2 3/26/1972 Open for Injection DRAWN BY: SLT RKB to TBG Head = 34.7' Tree connection: ? 1 DV Collar @ 2010' 3 4 C-5 C-7 C-7 C-7 47-5 47-5 47-5 7261' 50-3 51-6 51-6 PBTD = 8468' TD = 8475' KB ELEV = 101' HOLE ANGLE thru Interval = 40.7° Trading Bay Unit PROPOSED Well # A-12RD Completed: Future CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt 12.515 Surf 1066' 9-5/8" 43.5 N-80 & P-110 Butt 8.755 Surf 7490' 7" 32 P-110 X -line 6.094 7261' 8468' Tie Back 7" 29 N-80 Butt 6.184 Surf 7261' Tubing: C-7 ±6,811' ±6,851' ±4,650' ±4,680' 4-1/2" 12.6/13.55 L-80 TPL-4040 Surf ±6,440' NO. Depth (MD) Depth (TVD) ID Item 34.7 Last Tubing Hanger 1 ±6,400 Top Btm Tri -Point Stim-Top Production Packer 2 ±6,430' Zone X -Nipple 3 ±6,440' (TVD) Amt WLEG PERFORATION DATA Updated by: JLL 10/07/14 Accu Last Top Btm Top Btm m Perf Zone (MD) (MD) (TVD) (TVD) Amt SPF Date Present Condition C-5 ±6,528' ±6,634' ±4,436' ±4,515' ±106' Future C-7 ±6,811' ±6,851' ±4,650' ±4,680' Re-perf 40' 2 12/5/1972 Open for Injection C-7 ±6,886' ±6,926' ±4,707' ±4,738' Re-perf 40' 2 12/5/1972 Open for Injection C-7 ±6,960' ±6,980' ±4,764' ±4,780' Re-perf 20' 2 12/4/1972 Open for Injection 47-5 ±7,092' ±7,122' ±4,868' ±4,892' Re-perf 30' 2 12/4/1972 Open for Injection 47-5 7,102' 7,122' 4,876' 4,892' 20' 2 3/27/1972 Isolated w/ tie back liner ran on 12/1/72 47-5 ±7,160' ±7,180' ±4,922' ±4,938' Re-perf 20' 4 12/4/1972 Open for Injection 50-3 ±7,514' ±7,520' ±5,207' ±5,212' Re-perf 6' 2 3/26/1972 Open for Injection 7,521' 7,522' 5,213' 5,213' 1' 8 3/19/1972 Cmt sgz'd f/ bond 7,700' 7,701' 5,367' 5,368' 1' 4 3/17/1972 Cmt sgz'd f/ bond 51-6 ±7,715' ±7,721' ±5,380' ±5,385' 6' Re-perf 2 3/26/1972 Open for Injection 51-6 ±7,732' ±7,740' ±5,395' ±5,402' 8' Re-perf 2 3/26/1972 Open for Injection Updated by: JLL 10/07/14 .H Hilmrp Alaska, UA-. Monopod A-12RD 13 3/8 X 9 5/8 X 7 X 3 1/2 Tree, Block, CIW-F, 11 SM FE X 3 1/8 SM, double master and wing, 6 Y4 pocket prepped for control line exit EE trim ( 'Tubing head, CIW-DCB, �1$ 135/83MX11SM,w/2- 2 1/16 SM EFO, X -bottom prep w/ 1 % VR profile Casing spool, CIW-WF, 13 5/8 3M X 13 5/8 3M, w/ 2- 2 1/16 SM SSO Casing head, Shaffer -KD, 13 5/8 3M X 13" SOW bottom, w/ 2" LPO Monopod Platform A-12RD Current Wellhead 10/14/2014 Tubing hanger, CIW-DCB, 11 X 3 1/2 EUE lift and 3 1/2 I BT susp, w/ 3" type H BPV profile, 6%"EN N -F, 2 1/16 SM FE, HWO, AA IW -F, 2 1/16 5M FE, H W O, AA Plug valve 1}ilrnrr� :VxrkM„ T.T(: Monopod A-12RD 13 3/8 X 9 5/8 X 7 X4 1/2 Valve, Swab, W 41/16 5M FE, HW Valve, Master, W 41/165M FE, HW( ` Tubing head, S-8, 13 5/8 31 N x 115M, w/ 2- 21/16 SM SSO, w/ BG bottom w/ 1- 2 1/16 5M WKM-M valves Casing spool, CIW-WF, 135/83MX135/831V w/ 2- 21/16 SM SSO Casing head, Shaffer -KD, 13 5/8 3M X 13" SOW bottom, w/ 2" LPO Monopod Platform A-12RD Proposed Wellhead 10/14/2014 Tubing hanger, SME -CL, 11 X 4 Y EUE lift and 4 %TC -2 susp, w/ 4" Type H BPV profile, 2- 3/8 CCL, 6 X extended neck, 17-4PH stainless steel BHTA, Bowen, 41/16 5M X 7"-5 SA Bowen Union Full Stainless Steel ing, WKM-M, w/ 15" Safeco :or, FF trim inless Steel 15M FE pocket, ainless J -F, 2 1/16 SM FE, -IWO, AA ve Monopod Platform 2014 BOP Stack (Workover) 10/07/2014 Hilnirp Alaska. LIA: r Wallace, Chris D (DOA) From: Trudi Hallett [thallett@hilcorp.com] Sent: Wednesday, November 06, 2013 8:52 AM To: Wallace, Chris D (DOA) Cc: Larry Greenstein Subject: Trading Bay ST A-12RD (PTD 1710290) Temperature Survey Attachments: A-12RD Temp Survey 6-28-05 vs 10-23-13.xis; aiol2-003 for A-12RD 9-25-13.pdf Hi Chris, Trading Bay ST Well A-12RD (PTD 1710290) was granted a return to Injection under Administrative Approval (AIO 012.003) on September 25, 2013 with the expiration date of September 25, 2015. As required by AOGCC, the approval of continued injection is granted per certain conditions, of which are the following: I. Hilcorp shall re-establish injection and perform a temperature survey after one month of monitoring; 2. Hilcorp shall monitor and record wellhead pressures and injection rate daily; 3. Hilcorp shall submit to AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report. 4. Hilcorp shall perform a temperature survey every 2 years: 5. Hilcorp shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; 7. Hilcorp shall submit to AOGCC an annual surveillance report evaluating the performance of the EOR injection by April 1't of each year covering injection operations during the previous calendar year. The report shall include data sufficient to characterize the injection operation, including among other information, the following: injection and annuli pressures (i.e. daily average, maximum, and minimum pressures); fluid volumes injected; injection rates; mechanical condition of the injection wells; and integrity of confining layers. An assessment of the applicability of the injection order findings, conclusions, and rules based on actual performance shall be included with the annual performance report; and 8. This administrative approval shall expire 24 months after the cf cctivc date shown below unless an extension is approved according to Rule 8 of A10 12.000. Attached you will find the temperature survey performed on Trading Bay ST A-12RD and a copy of the Area Injection Order No. 012.003 for your review. Injection was established on September 28th, 2013 and as requested, Hilcorp performed a temperature survey on October 23, 2013 (within one month after re-establishing injection). The survey (see attached) is consistent with the previous survey run on June 28th, 2oo6. The current survey confirms that all injected fluids are being contained within the approved zones of injection. The anomaly at +/- 4200' MD is also consistent with the previous survey thus giving no concern that the injected fluids are not confined. Unless otherwise stated from the AOGCC, Hilcorp will continue to inject into Trading Bay ST A-12RD with daily recording and monitoring as well as adhering to all of the above requirements. Please contact myself or Larry Greenstein if you have any questions or concerns. I appreciate your time. Thank you- Trudi Hallett f Reservoir Engineer Cook Inlet Offshore Asset Team I Hilcorp Alaska, LLC; Hilcorp A Company Built on Energy thallettAhilcorp.com O: 9117.:' , ,1'.i i C: 907.7-50J)'747 Hilcorp Alaska, LLC Well: A-12RD I Field: Monopod 10-23-2013 500 1000 1500 2000 2500 3000 3500 Q 4000 D 4500 t d 5000 5500 6000 6500 7000 7500 8000 8500 55 65 Perls 3 1/2" 6-28-05 Temp Report date: 11/6/2013 75 85 95 105 115 Temperature (Deg. F) 13 3/8" 9 5/8" - - 7" X10-23-13 Pressure -%K—PKR PKR 2 10-23-13 Temp 50 • • Chevron Steve Lambert Union Oil Company of California Advising Petroleum Engineer P.O. Box 196247 Anchorage, , AK AK 99519 -6247 Tel 907 263 7658 Fax 907 263 78484 7 Email salambert@chevron.com RECEIVED January 9, 2006 JAN 1: 1 nut') Tom Maunder Alaska Oil & Gas Cons, Commission Alaska Oil and Gas Conservation Commission Anchorage 333 W. 7 Ave., Suite #100 Anchorage, AK 99501 -3539 Continuation of Shut -in Status Well No A -12RD Injector 5 APP. 2 1 20 11 Monopod Platform Trading Bay Field Dear Tom, This letter serves as a follow -up to the assessment of well utility for well A -12 submitted on September 6, 2005. Unocal requests approval under Area Injection Order 12, for the continuation of status as a shut -in injector of non - hazardous Class II fluids for the Monopod Platform Well No(A -12 RD, Injector (Permit # 171 -029) in Trading Bay Field. To support this request, Unocal submits the following information and documentation: 1. Schematic (attached). 2. Temperature surveys (attached). 3. Maximum allowable injection pressure calculation in graphical form (attached). 4. Brief /relevant well history (below and attached). Well A -1205 was drilled through the West Foreland in March 1968 and abandoned. In March of 1972, the well was redrilled through the "C" sands in the 2 -A Fault Block and completed as a dual string injection well. In August of 1972, well A -25 drilled into well A -12RD. A -12RD was shut -in and worked over in December 1972. During the workover, the 9 5/8" casing was found to be parted at 3,640'. The casing was repaired and squeezed and the 7" liner was tied back to the surface and cemented to surface. The well was completed as a single string "C" zone injector. Following the repair, A- 12RD became the primary "C" zone water injector. The well initially injected at rates in excess of 6,000 BWPD. The well was shut -in in 1984 due to communication between the tubing and casing annulus. Due to concerns about the well's down -dip location and the conversion of up structure wells to injection, it was decided not to resume injection in the A -12RD location. Temperature surveys run in 1998, 2002 and 2005 have confirmed that injected fluids continue to be contained within the "C" sands and there are no indications of crossflow in the wellbore. Union Oil Company of California / A Chevron Company http: / /www.chevron.com • . Tom Maunder Alaska Oil and Gas Conservation Commission January 9, 2006 Page 2 Depending on the results of field development, it may be desirable to return this well to injection in the future. Unocal will seek concurrence from the AOGCC before attempting to return this well to injection. Unocal will continue to monitor and record daily tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure the injected water is contained within the completion interval. Thank you for your consideration and if you have any questions regarding this request please contact me at 263 -7658 or Larry Greenstein at 263 -7661. Sincerely, ( Steve Lambert cc: MIT book Well File Union Oil Company of California / A Chevron Company http: / /www.chevron.com A -12RD Well History • • Last Update: 12/29/2005 Date Description 3/1/68 Drilled thru West Foreland and abandoned. 3/1/72 Redrilled thru "C" sands and completed as dual injector. 12/1/72 A -25 drilled into welibore. Found parted casing at 3,640'. Squeezed bad casing and ran 7" liner tie -back to surface. Completed as single string injector. 6/1/84 Communication between tbg and csg. Well shut -in. 5/29/98 Temperature survey confirmed zone isolation. 6/28/05 Ran 2.50" GR to 1250' and tagged up. Had to jar up to free. Ran 2.25" GR to 6780' (Otis metering sub) and tagged up. Unable to work deeper. Ran temp survey to 6780'. C: \Documents and Settings\salambert\Local Settings \Temp\Al2RDWellHistoryJHM Page 1 of 1 ,. • • Pressure (psia) 0 250 500 750 1000 1250 1500 1750 2000 2250 0 '---- Mi lliiiillligilill. 500 1000 _ Oil 1500 _ '1111111 2000 - - Milliglilli - — 0 2500 - ii - 3000 0 3500 2 a) 4000 - — 0 4500 x \ 5000 — - — 5500 - 6000 - 6500 7000 i I - 1 55 65 75 85 95 105 115 Temperature (Deg. F) 6 -28 -05 Pressure — Perfs 13 3/8" —9 5/8" 7" 3 1/2" —6-28-05 Temp —5-17-02 Temp Monopod A -12RD Temp Survey Comparison 40 50 60 70 80 90 100 110 120 0' -r 500' 1,000' 13 -3/8" RIH 05/29/1998 RIH 05/17/2002 1,500' 2,000' 9 -5/8" 2,500' 7" 3,000' 3,500' 4,000' I I 5,235' Wire slipped out of detent gear, repair unit 4,500' _ _ - - -_ 5,000' 5,500' 6,000' 6,500' mi IL 7,000' 7,500' A -12RD Temp Survey 1998 and 2002 1/9/2006 8:43 AM Jeff Dolan Temp chart UNOCAL 76 • • i t Re- Completed 12/8/72 RKB to TBG Head = 34.7' Tree connection: ? CASING AND TUBING DETAIL G , SIZE WT GRADE CONN ID TOP BTM. 13 -3/8" 61 K -55 Butt 12.515 Surf. 1066' I ' 9 -5/8" 43.5 N -80 & P -110 Butt 8.755 Surf 7490' 7" 32 P - 110 X - line 6.094 7261' 8468' 1DV Collar Tie Back @ 3,982' 7" 29 N -80 Butt 6.184 Surf 7261' Tubing: 3 -1/2" 9.2 N -80 Butt. 2.992 0' 7057' 1 >1 I 2 JEWELRY DETAIL 1 o J 3 NO. Depth ID Item 34.7 3 -1/2" CIW 8rd X Butt Tubing Hanger 1 6730' ? ? ?? Locator Seal Assy. w/ 8.2' of seals. C -7 2 6730' Baker Model "F" Pkr. C -7 3 6780' Otis Metering Sub 4 7028' Locator Seal Assy. w/ 20.02' of seals. C -7 5 7037' Baker Model "D" Retainer Production Packer 6 7055' 2.760 Otis "N" Profile Nipple, 2.875 4 7 7056' Mule Shoe C = ,X 5 btm 7057' No ow „�� 6 / STIMULATIONS Acid Squeeze w/ Mutual Solvent 3/72 47 -5 Acid Squeeze 12/72 = 47 -5 --,— 47 -5 Zr X 7261' PERFORATION DATA = 50 -3 Accum Last Zone Top Btm Amt SPF Perf Date Present Condition g 6,811' 6,851' 40' 2 12/5/72 Open for Injection g 6,886' 6,926' 40' 2 12/5/72 Open for Injection 6,960' 6,980' 20' 2 12/4/72 Open for Injection 7,092' 7,122' 30' 2 12/4/72 Open for Injection 7,102' 7,122' 20' 2 3/27/72 Isolated w/ tie back 51 -6 liner ran on 12/1/72 7,160' 7,180' . 20' 4 12/4/72 Open for Injection 51 -6 7,514' 7,520' 6' 2 3/26/72 Open for Injection 7,521' 7,522' 1' 8 3/19/72 Cmt sqz'd f/ bond 7,700' 7,701' 1' 4 3/17/72 Cmt sqz'd f/ bond 7,715' 7,721' 6' 2 3/26/72 Open for Injection 7,732' 7,740' 8' 2 _ 3/26/72 Open for Injection PBTD = 8468' TD = 8475' KB ELEV = 101' HOLE ANGLE thru Interval = 40.7° A - I 2rdSch12-8-72 Comp REVISED: 1/9/2006 DRAWN BY: SLT A -12RD Maximum Allowable Operating Pressure Graph Pressure (PSI) 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000 0 Run date : /4/2006 8:24:23 AM Safe operatin • ressures (surface gauge) Production = 571. p i. @ 70% nominal casing yield Intermediate = 14 0 si. limited by fracture pressure at shoe Surface = 283 psi li ted by fracture pressure at shoe Current Pres- re readings Surveillance Thresholds TBGPRESS = 0 Warning = Alert = CSGPRESS = 85 Warning = Alert = CSGPRESS2 = 1 Warning = Alert = CSGPRESS5 = 0 Warning = Alert = 1,000 Casing Detail Size Weight Grade Yield Top Bottom Liner Segment 7 29 N -80 8160.0 36.3 3982.2 Liner Stgcollar 29 N -80 8160.0 3982.2 3984.9 Liner Segment 29 N -80 8160.0 3984.9 7261.0 Liner Hanger 29 N -80 8160.0 7261.0 7279.1 Liner Segment 7 32 X -LINE 7279.1 8465.6 Liner Shoe 7 8465.6 8468.0 Production Casino 9.6 5 43.5 N -80 6327.0 39.0 2010.3 Production Stgcol r 9.6 • 43.5 N -80 6327.0 2010.3 2012.5 Production Casin• 9.62 43.5 N -80 6327.0 2012.5 7490.0 2,000 Intermediate Casi g 13.3 • 61 J -55 3094.0 39.0 1066.0 Casing Para ••ters / Assu ptions Production casing , ield @ 70% of n. inal with fluid weight of 0.433 #/ft Intermediate casi . yield @ 45% of .mina) with fluid weight of 0.433 #/ft Surface casing yi= d @ 45% of nomi :I with fluid weight of 0.433 #/ft Fracture gradient - 0.7 #/ft API : 50733200 .01 Permit: 1710290 3,000 Workbook : A -12 I Casing Pressure An- ysis @70 percent 20060104.xls 0 H - 4 000 - - a a) 5,000 Variable Definitions RP = Reservoir Pressure CYP = Casing Yield Pressure SF = Safety Factor (70% for working annulus; 45% for outer annuli) HP = Internal Fluid Hydraulic Pressure MASP = Maximum allowable surface working pressure Graphical calculation method Inside pressure potential == Outside pressure containment 6,000 Therefore HP + MASP =RP +(CYP *SF) Rearranging MASP =RP + (CYP *SF) -HP - Internal Fluid Hydraulic Pressure Formation facture pressure © 0.7 #/ft - Production CYP @ 70% -Outside Containment for Production casing - MASP (production casing) -- Intermediate CYP © 45% 7,000 -Outside Containment for Intermediate casing MASP (Intermediate casing) Surface CYP @ 45% - Outside Containment for Surface casing MASP (Surface casing) • Current Pressure Readings Disclaimers (fine print) Casing yield values taken from published sources where specifications are known. If specifications are unknown then values are the lowest value of probable materials. TVD interpolated from Openworks directional surveys. Values should be +/- 25 ft @ 10,000 ft. MD Graphical Casing Pressure Analysis ver 24a.xls 8,000 ) Unocal Alaska Resourcl:.. ) Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCALe ~·.I~"'\' I, ..,.... C.' E~ ; ·~.·t, :......'¡r- '0- . ~~. ··t"-"- """". ," ~. ,M ,Jt;;."""~.J.,, ' ¡,..... SEP 0 ~: 200~~ Steve Lambert Reservoir Engineer September 6,2005 '~,;;. ŒI {& ~ CUrJi. ç.~-~.,~ ~,;'~jrjf:$~~ ;j'1 \,. ~~,-\- ~p.f'-- f""" \{ iiJ'\ ~,-. . -r-. ~,,~ . ,.' '\:¿ß r- ~.f"'·- " K5, S k ., . ,"0 ~'.,.C"''''-'\ "'-~? ~ 'I -~ ~~ . CP . . ~ '-ð\\'-~ .. 'ì. \ <- ~~ , \ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 \1l/0'Jßt ASSESSMENT OF WELL UTILITY TRADING SAY STATE WELL NO. A-12RD PERMIT NO. 171-029 SUNDRY APPROVAL NO. 302-298 MONO POD PLATFORM TRADING SAY FIELD Dear Tom: SC/\N ~\~ EJ> 1 h 200,h J, l!} ~. J.,<,i In response to a request by the AOGCC on a Sundry Approval (No. 302-298) for Monopod Well No. A- 12RD (Permit No. 171-029), Trading Bay Field, Chevron submits the following information concerning an assessment of the well's utility. Well No. A-12RD, an injector which was shut-in in April 1984 due to a failed MIT, is being retained for potential future utility as an injector. Please note that this information has been reported to the AOGCC (Mr. Jack Hartz) yearly on an annual shut-in well report. However, in the event that this report is not sufficient as a response to the sundry or has not been reaching you, we are additionally notifying you through this submittal. Attached for informational purposes are copies of the annual shut-in reports for 2002, 2003, and 2004 mentioned above, a copy of the sundry, and a schematic. Chevron will monitor and record daily injection rates and tubing and casing pressures on the well and provide a report to the AOGCC on a monthly basis. A temperature survey will be run every two years to insure that fluids continue to be contained within the completion interval. Please call me at (907)263-7658 if you have any questions. Sincerely, ~~À~· Steve Lam bert JHM:jll Attachments O:\OOE\OOEFields\Monopod\Wells\A-12\A-12RD\State_Forrns\Correspondence\A-12RD Sundry Response Sep05.doc UNION OIL COMPANY OPERATED PROPERTIES WELL DATA FIELD ~ÄCAJj¡;'í87Jì~~?~~~~~~~ß¡k~t SUMMARY fiiRtJ~~~}OCft1.ij-':':ß -. fBRtí~ì1M~'$ë:i4mfli.~laaJ~lr U. U II :' líš.1:JliE~~á1~.:rw SUMMARY ~~'HFïKj~t?,W.MöÑõEö~.:A~.2iìt';: SUMMARY WELL 17 46 52 27RD 9 NO WELLS U~J Information for AOGCC on Sbut-In Wells Reg 10 ACC 15.115 ;l~œ~ /~. DATE Mecbanical Condition SHUT-IN Wby well was Sbut-In Future UtiUty of Well Jul-95 Bad Casing Jul-95 Communication between tubinY/casing Jul-95 Colapsed Casing Jul-92 Communication between tubing/casing Mar-89 Leaking Bottom hole assembly Potential cleanout and return to injection Potential WO candidate Potential redrill candidate Potential for Coil tubing clean out Potential redrill candidate Won't take water Won't take water Low Production Won't take water High water production' -' 5RD May-86No known damage INo injection on platforin Potential conversion to a producer. 5 Apr-88No known damage INo Production IPotential redriU for Tyonek. 6 May-86 No known damage No injection on platform Poetential redrill candidate to Hemlock 10 Feb-87 Abandoned Potential redrill candidate 12RD May-86 No known damage No injeçtion on platform Possible conversion to a producer. 14 Dec-OO No known damage Produced water Under evaluation 16 Feb-87 Abandoned Potential redrill candidate 18 Apr-89CoIlapsed Casing 100% water production Potential for Workover. 31 May-86 Cement Plugged back above perfs No injection on platforin Potential to redriU to Tyonek or Hemlock. 34 Apr-86 TP&A'd Poor perfonnance, uneconomic. Potential conversion to gas producer. 40 Jan-81 Collapsed Casing Lost produœon 8fter casing çollapsed Potential redrill candidate for gas well. NO WELLS ~~ A-4 A-5RD2 S&L A-IO S&L A-12RD A-23 S&L A-26 A-30 NO WELLS h;¿';;mf -' May-98 Tubing plugged up with paraffin Ju1-86 No known damage Apr-83 Collapsed casing Apr-84 Failed MIT. Fish in tubing Jun-86 Collapsed casing Jun-78 Communication tbg/çsg Oct-95 No known damage Extreme paraffin problems Both strings quit taking water Producing Coal Failed MIT Producing Coal FaUed MIT, tubing obStnJctions Water production due to WF bteakthrougb Potential gas producer or redrill for oil. Potential to add perfs & return to injection. Potential redrill for HemJock Injection. Potential to return to Injection. Potential to shoot uphole gas Potential to·reactivate with a variànce. Potential to cOnvert to B-Zone Injector. Pue 3 n"....._I_.... C!I..__..~.I~--""" 4"InL__a. '1'- UNION OIL COMPANY OPERA TED PROPERTIES WELL DATA FIELD WELL j.~Ã''-Dl~OD _~-:u! "'" . ., A-3RD3 A-4 A-5RD2 S&L A-lO S&L A-12RD A-22 A-23 S&L A-26 A-3D SUMMARY NO WELLS ~i{,;,~ ~~W~fm-w 12A-1O 314-3 21-3 23B-3 21-8 41B-9 212-1 0 41A-15 14-22 23-22 331-27 23-27 34-28 33A-8 14-15 243B-4 43B-15 24-33 43-9 Information for AOGCC on Shut-In Wells Reg 20 ACC 25.115 IP Írn· / Ii /Of AITA I'Ir 'y ~ 1- DATE Mechanical Condition SHUT-IN Why well was Shut-In Future Utility of Well Aug-02 No known damage May-98 Tubing plugged up with paraffin Jul-86 No known damage Apr-83 Collapsed casing Apr-84 Failed MIT, Fish in tubing Oct-02 No known damage Jun-86 Collapsed casing Jun-78 Communication tbglcsg Oct-95 No known damage Limited gas lift gas available (low oil pn Potential to restore production. Extreme paraffin problems Potential gas producer or redrill for oil. Both strings quit taking water Potential to add perfs & return to injection. Producing Coal Potential redrill for Hemlock Injection. Failed MIT Potential to return to Injection. Limited gas lift gas available (low oil prl Potential to restore production. Producing Coal Potential to shoot uphole gas Failed MIT, tubing obstructions Potential to reactivate with a variance. Water production due to WF breakthrou~ Potential to convert to B-Zone Injector. ~ Jan-97 milled through csg during plug remova rocks to 7000' Possible Tyonek gas I Hem dewatering Mar-98 no known damage no flow Possible WO for Tyonek gas Jan-99 parted tbg no flow Possible dewatering Apr-98 punched hole in tbg high water Possible dewatering Aug-96 parted tbg high water (Hem) no flow (G Zone) Possible dewatering Nov-95 no known damage no flow Possible WO for Tyonek gas Oct-90 no known damage high water Possible Sterling gas Dec-85 no known damage - partial P&A high water Possible Tyonek gas Sep-89 no known damage - partial P&A high water Possible Beluga gas Aug-84 no known damage no flow Possible Tyonek gas Aug-81 no known damage high water Possible water disposal Jul-86 hole in tbg high water Possible water disposal Oct-DO Tbg I Csg communication failed pressure MIT, passed temp survey Possible gas storage Oct-DO csg damage liner overlap high water Possible WO for rod pump Sep-83 no known damage no flow Possible WO for Tyonek gas Sep-99 no known damage no flow Possible water disposal Oct-99 no known damage no flow Possible water disposal Aug-83 no known damage - partial P&A Rocks and high GOR Possible Hemlock redrill May-98 punched hole in tbg high water Possible dewatering ~ Page 5 WeICCount_ShucIn_Status_2004_Complete.XLSShuCIn_ WelCStatus UNION OIL COMPANY OPERATED PROPERTIES WELL DATA FIELD ~'ØJi-~D~~;~ -~~ J~~liLfJ; 1>"1 _;;ç; WELL 5RD 5 6 10 12RD 14 16 18 31 34 40 SUMlVIARY NO WELLS ~>-lnf[J!f J7 ~tt'...~~fIIR>OD A-3RD3 A-4 A-5RD2 S&L A-10 S&L A-12RD A-20RD A-22 A-23 S&L A-26 A-30 SUMlVIARY NO WELLS t.~~~;--~ Information for AOGCC on Shut-In Wells Reg 20 ACC 25.115 DATE Mechanical Condition SHUT -IN May-86lNo known damage Apr-88lNo known damage May-86 No known damage Feb-87 Abandoned May-86 No known damage Dec-OO No known damage Feb-87 Abandoned Apr-89 Collapsed Casing May-86 Cement Plugged back above perfs Apr-86 TP&A'd Jan-81 Collapsed Casing Aug-02 No known damage May-98 Tubing plugged up with paraffin Jul-86 No known damage Apr-83 Collapsed casing Apr-84 Failed MIT, Fish in tubing Apr-90 No known damage Oct-02 No known damage Jun-86 Collapsed casing Jun-78 Communication tbglcsg Oct-95 No known damage Why well was Shut-In INo injection on platform INo Production No injection on platform No injection on platform Produced water 100% water production No injection on platform Poor performance, uneconomic. Lost production after casing collapsed t/5~ f)T' /j // û~· I Future Utility of Well ATTACHMENT 1 _ J!I~ t" ;r IPotential conversion to a producer. IPotential redrill for Tyonek. Poetential redrill candidate to Hemlock Potential redrill candidate Possible conversion to a producer. Under evaluation Potential redrill candidate Potential for Workover. Potential to redrill to Tyonek or Hemlock. Potential conversion to gas producer. Potential redrill candidate for gas well. -" Limited gas lift gas available (low oil pr4 Potential to restore production. Extreme paraffm problems Potential gas producer or redrill for oil. Both strings quit taking water Potential to add perfs & return to injection. Producing Coal Potential redrill for Hemlock Injection. Failed MIT Potential to return to Injection. Dry in 25A sand Potential plugback to other A sands Limited gas lift gas available (low oil pn Potential to restore production. Producing Coal Potential to shoot uphole gas Failed MIT, tubing obstructions Potential to reactivate with a variance. Water production due to WF breakthrou~ Potential to convert to B-Zone Injector. Page 6 --' v Well_CouncShuCIn_Status_Jan05 Rev.XLSShucIn_ Well_Status .' It UNOCALe RKB to TBG Head = 34.7' Tree connection: ? L ) ~ SIZE WT I 13-3/8" 61 'lDV Collar 9-518" 43.5 @ 2010' 7" 32 Tie Back 7" 29 Tubing: 3-1/2" 9.2 I ~ :t>< 2 I 0 I 3 C-7 ==== C-7 ==== C-7 4 r::: :::::J ><e c>< 5 - 6 ~7 47-5 == 47-5 ====47-5 z Z 7261 ' L ~ ~ 50-3 : - 51-6 - 51-6 - ~ ~ PBTD = 8468' TD = 8475' KB ELEV = 101' HOLE ANGLE thru Interval = 40.7° A-12rdSch12-8-72 Comp small. doc NO. 2 Depth 34.7 6730' 6730' 6780' 7028' 7037' 7055' 7056' btm 7057' ) Trading Bay Unit Well # A-12RD Re-Completed 12/8/72 3 4 5 6 7 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. K-55 Butt 12.515 Surf. 1066' N-80 & P-110 Butt 8.755 Sun 7490' P-II0 X-line 6.094 7261' 8468' N-80 Butt 6.184 Surf 7261 ' N-80 Butt. 2.992 0' 7057' JEWELRY DETAIL ID Item 3-1/2" CIW 8rd X Butt Tubing Hanger ???? Locator Seal Assy. wi 8.2' of seals. Baker Model "F" Pkr. Otis Metering Sub Locator Seal Assy. wi 20.02' of seals. Baker Model "D" Retainer Production Packer 2.760 Otis "N" Profile Nipple, 2.875 Mule Shoe STIMULATIONS Acid Squeeze wi Mutual Solvent 3/72 Acid Squeeze 12/72 PERFORATION DATA Accum Last Zone Top Stm Amt SPF Perf Date Present Condition 6,811' 6,851' 40' 2 12/5/72 Open for Injection 6,886' 6,926' 40' 2 12/5/72 Open for Injection 6,960' 6,980' 20' 2 12/4/72 Open for Injection 7,092' 7,122' 30' 2 12/4/72 Open for Injection 7,102' 7,122' 20' 2 3/27/72 Isolated w/ tie back liner ran on 12/1/72 7,160' 7,180' 20' 4 12/4/72 Open for Injection 7,514' 7,520' 6' 2 3/26/72 Open for Injection 7,521' 7,522' 1 ' 8 3/19/72 Cmt sqz'd f/ bond 7,700' 7,701' 1 ' 4 3/17/72 Cmt sqz'd f/ bond 7,715' 7,721' 6' 2 3/26/72 Open for Injection 7,732' 7,740' 8' 2 3/26/72 Open for Injection REVISED: 9/1/2005 DRAWN BY: SLT i, MEMORANDUM TO: "h Ké"11' 5' L~(04 THRU: Jim Regg P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector Well Name: TRADING BAY ST A-12RD Pad: 800 Packer Well: A-12RD Type Inj. N TVD P.T. 1710290 TypeTest SAMT Test psi Interval OTIffiR F P/F NON-CONFIDENTIAL i¡ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, May 14, 2004 SUBJECT: Mechanical Integrity Tests UNION OIL CO OF CALIFORNIA A-12RD TRADING BAY ST A-12RD Src: Inspector \ll-Od-Íj Lou Grimaldi API Well Numbe 50-733-20076-01-00 Inspector Name: Permit Number 1710290 Inspection Date: Type Test M=Annulus Monitoring P=Standard Pressure Test R=Intemal Radioactive Tracer Survey A=Temprature Anomaly Surve D=Differential Temprature Test Number of Failures: 5/13/2004 Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 6118 IA 50 200 175 160 ISO 135 200 OA 10 10 10 10 10 10 Tubing 70 190 160 160 160 ISO Notes: Well not injecting, test required by AOGCC for sundry. Target pressure 0000 psi could not be obtained. TubingIIA tracked each other and appeared to be in communication. Well will be monitered according to sundry. Interval l=lnitial Test 4=Four Year Cycle. V=Required by Variance W=Test during Workover O=Other (describe in notes) Total Time during tests: hourIs Type INJ. Fluid Codes F =FRESH WATER INJ, G=GAS INJ. S=SALT WATER INJ. N=NOT INJECTING M.I.T.'s Performed: Friday, May 14,2004 Page] of 1 Monopod A-12RD Subject: Monopod A-12RD Date: Wed, 09 Apr 2003 11:46:46 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Jeff Dolan <dolanjj@unocal.com>, Hal Martin <martinh@unocal.com> Jeff and Hal, Greetings. I am in need of some information regarding this well. From all I can see, it is a SI injector and has been SI for some time. In checking the file, the well was originally completed as a dual injector but was worked over in the mid 80s and converted to a single injector. We do not have any records regarding the workover. Is it possible to send over the work reports for that operation?? Please give me a call when you have a chance. Tom Tom Maunder <tom maunder~admin.state.ak, us> Sr, Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 4~9~2003 11:54 AM ~ fD~MECHANICAL INTEGRITY P,~OR~ TVD; TOP:7_2~/ MD _ Liner: 7 ~ ~e ~ ~'e~ t, ~L- _ Shoe :" ~__~_~_MD _ Tub ing: El=. P a'cker ~v -~ ~D Sole Size MECHANICAL INTEGI{ITY - PART ' Annulus Press Test: IP. ;' 1S rain Co~.-ents: ., ; 30 rain _ INTEGEIT~ - .PART ~2 ' ' . '~/~c,~ .... ..r,". :..,..~-.,.;. ,_, .., , . Cement V.ol~es: ~=. Liner . __ . ./ ~ ~~~~, ... Cement Bdnd Log (Yes or No)_ t/'~_.~ Part #1: Part #2 ~ rev. 05/20/87 ' ."".',. .? ,STATE OF ALASKA A'i'ASI;G OIL AND.GAS CONSERVATION COMMISSION ' APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: " Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: X Perforate: Other: '~']-MIT 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNOCAL Development: 101' RT above MLLW feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 - 6247 Service: -~- Trading Bay State 4. Location of well at surface 8. Well number Conductor #26, 1617' FSL 571' FEL Sec 4 T9N, R13W, SM. A-12RD At top of productive interval 9. Permit number 2217' FSL, 459' FWL Sec 4 T9N, R13W, SM. 1710290 At effective depth 10. APl number 2630' FSL 236' FEL Sec 5 T9N, R13W, SM 50-733-20076-01 At total depth 11. Field/Pool 2630' FSL 236' FEL Sec 5 T9N, R13W, SM Trading Bay Field "C" zone 12. Present well condition summary Total depth: measured 8,475' feet Plugs (measured) true vertical 6,085' feet Q4NNEE;, g 3 2003 Effective depth: measured 8,468' feet Junk (measured) true vertical 6,079' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1066' 13 3~8" 1066' 1061' Intermediate 7490' 9 5/8" 7490' 5184' Tie Back liner 7261' 7" 7261' 5001' Liner 1207' 7" 8468' 6079' Perforation depth: measured See Attachment ?',".~ ,,',.7, ,i: .... i! .... ~', ~i.,...~" i~ii.' 'i" ' · ,, . .,, '::,,. }.','.. ' ~,,.. ,,,., ".,~ true vertical - Tubing (size, grade, and measured depth) 3-112", 9.2#, N-80, Buff. @ 7,057' . .. ..., . ...... Packers and SSSV (type and measured depth) Baker Model "F" @ 6,730' Baker Model "D" @7,037' 13. Attachements Description summary of proposal: Detailed operations program: BOP sketch: Temperature survey, We 14. Estimated date for commencing operation 15. Status of well classification as: N/A 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: Water Injection 17. I hereby certifyJZ~lL[he foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity BOP Test Location clearanceI ~"~2' Subsequent form required 10 ~"'~.,~ ~\~ ~ ~ ~-------~,. -.. Mechanical Integrity Test '~ ' - :~ · 5~(3 f~..-~ ~,~[~..~, Approved ,, order of the Commissioner ~"~ ~--~'~¢,~ . ,'~~ Commissioner Date Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE Perforations ATTACHMENT TO APPLICATION FOR SUNDRY, A-12RD ..Zone MD Top MD Btm Amt TVD TopTVD Btrr 6,811' 6,851' 40' 4,648' 4,679' 2 6,886' 6,926' 40' 4,706' 4,736' 2 6,960' 6,980' 20' 4,763' 4,778' 2 7,092' 7,122' 30' 4,867' 4,891' 2 7,102' 7,122' 20' 4,875' 4,891' 2 7,160' 7,180' 20' 4,921' 4,937' 4 7,514' 7,520' 6' 5,205' 5,210' 2 7,521' 7,522' 1' 5,211' 5,212' 8 7,700' 7,701' 1' 5,366' 5,366' 4 7,715' 7,721' 6' 5,378' 5,384' 2 7,732' 7,740' 8' 5,384' 5,400' 2 Accum Last SPF Perf Date Present Condition 12/5/1972 12/5/1972 12/4/1972 12/4/1972 3/27/1972 12/4/1972 3/26/1972 3/19/1972 3/17/1972 3/26/1972 3/26/1972 Open for Injection Open for Injection Open for Injection Open for Injection Isolated w/tie back liner ran on 12/1/72 Open for Injection Open for Injection Cmt sqz'd f/bond Cmt sqz'd f/bond Open for Injection Open for Injection 5C;ANNED APR 3 2003 8/22/2002 5:25 PM A12RD 20020822 Request for SI MIT.xls Perforations NOTE TO FILE Trading Bay Field (TBF) A-12RD PTD 171-029 302-298 Unocal has submitted a temperature survey to demonstrate mechanical integrity for this injection well and has requested to keep the well in service with known tubing x annulus (T x IA) communication. This note evaluates Unocal's request and recommends approval of it. According to the RBDMS database, this well has not been in service since early 1984. The file does not have much information since the original completion in 1971. The well was drilled as an injection well. There is a record in the MIT binder that Blair examined the bond log on 6/15/89 and concluded that MI was indicated. It is unclear why the well has not been in service for so long. In the mid 1980s, Unocal applied to workover the well converting to a single completion from the dual originally run. There is no subsequent report of such workover, although the drawing in the file would indicate that the workover was performed. I have contacted Unocal to provide what information they might have to complete our files on this work. In 1998, Unocal attempted a "SI MIT" and provided pressure observations for a 1-week period. This information was not conclusive in demonstrating wellbore integrity. Subsequently, a temperature survey was performed May 5, 1998. The information gathered at that time was accepted and demonstrated that there were no temperature anomalies present in the wellbore. Unocal performed a subsequent survey May 17, 2002 and essentially the same thermal profile was developed. There is a general warming in the wellbore that would be expected since no injection has occurred. Area Injection Order 12 allows injection into Southern Portion of Trading Bay Field, developed by the Monopod Platform. The BHL of well A-12RD is located in the covered area. The portion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Trading Bay Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(iv) and 20 AAC 25.440(c). Granting Unocal's request will not endanger any fresh water. I recommend acceptance of the submitted temperature information. Unocal should add this well to the monthly monitoring report and plan to perform another temperature survey in May 2004. Unocal should be reporting this well as required by 20 AAC 25.115 (a) [Shut-In Wells]. In addition to those requirements, Unocal should provide an assessment of the future utility of this well prior to the end of 3rd quarter 2003. Tom Maunder, PE Sr. Petroleum Engineei' April 9, 2003 M:\UIC File Reviews\030409-TBF A-12RD.doc Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 UNOCAL{) .,' Alaska September 16, 2002 State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Attn: Tom Maunder Re: Trading Bay Field Monopod - A-12RD Shut in MIT Dear Mr. Maunder: A temperature survey was mn on May 17 2002, in well A-12RD (Permit # 1710290 API 50- 733-20076-01). This survey is plotted in depth along with the May 29th 1998 survey The well has been shut in since 1984. The new survey shows no changes in the well since the 1998 survey. We request a grant of the continuance of the Shut In MIT status for A-12RD. I have enclosed a plot of the temperature surveys (1998 and 2002). If you have any questions regarding this, please contact myself at 263-7807 or Hal Martin at 263-7675. Sincerely, Jeffery J Dolan Waterflood Technician Cook Inlet Waterflood Management Enclosures I!,~...... .... Aogcc Monopod A- ! 2RD Application forSl M IT 20020823.doc jjd 40 5O Monopod A-12RD Temp Survoy Comparison 60 70 80 90 100 110 120 500' 1,000' 1,500' 2.000' 2,500' 3000' 3,500' 4,000' 4,500' 5,000' 5,500' 6,000' 6,500' 7,000' ~RIH 05/29/1998 ~RIH 05/17/2002 5,235' Wire slipped out of detent gear, repair unit 7,500' A-12 Temp Survey 1998 and 2002 xls 9/16/2002 11:03 AM Jeff Dolan Temp char[ JUN-29-98 MON 13:41 UNOO L SSET GRP NO. 9072637874 P. O1/O1 Unocal Corporation 909 West 9"' Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCALG June 29,1998 Wendy Mahan Alaska Oil and Gas Co. nservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Wendy, Re: Status of Unocal's Cook Inlet Injector Work This letter is to provide you with an update of the work conducted since our March 27, ] 998 letter which you signed granting time extensions for various wells. Testing or work was completed on the following Anna 46-42 .~.z King 4RD · ~q-a~l King 15RD ~o-Dolly D- 16RD -io~ Dolly D-22 Grayling 22 Grayling 36DPN Monopod A- 12RD2 Monopod A-29 Baker 9 King 22RD wells and the results of this work i.s listed: : SI MIT approved on 4/17/98. : SI MIT approved on 4117/98, workover scheduled. : SI MIT approved on 4/17/98. Jug test proved communication, workover scheduled. : SI MIT approved on 4/17/98. : SI MIT approved on 4/17/98. : Workover completed on 4119198. : Workover completed on 4/28/98. : SI MIT approved on 6/03/98. : SI MIT approved on 6/03/98. : SI MIT approved on 6103/98, planning acid treatment to clean tubing for testing, : Variance granted on 6/09/98, Jug test proved casing integrity. Anna 27-42 :Coil Tubing clean out completed on 6/25/98, furlher testing scheduled to prove casing integrity. Anna 19-42 :Coil Tubing cleanout completed on 6/27/98, further testing scheduled to prove casing integrity. Granite Point 33-14RD: Wireline fishing continuing to remove wire and wireline fish from well. Grayling 5 : Redrill in progress. Testing or work w~ attempted on the following shut-in wqlls and a.time extension until September 30, 1998 i.~ r~equested to complete further work and testing ' ' - Anna ! 9-42- Coil Tubing clean out completed on 6/27/98, further testing scheduled to prove casing integrity. o l~, Anna 27-42: Cell Tubing clean out completed on 6/25/98, further testing scheduled to prove casing integrity. o'4 Grayling 28: Coil Tubing cleanout planned to follow currently active rig program. o~ Grayling 40' Workover schedule in current rig schedule. -4~-o,~z. King 4RD · SI MIT granted on 4/17/98, workov~r scheduled. o%.~King 15RD ' SI MIT granted on 4117/98. Jug test proved communication, workover scheduled. As you can see we are making excellent progress. Unocal respectfully requests a time-extension until September 30, 1998 to complete the work on the above listed Anna wells. The Grayling and King work will be executed per our current drilling schedule. Please call mc if' you have any questions or clarification on these issues. Cook Inlet Waterflood Management Please acknowledge the approval of the time extension and your receipt of this letter by.. f..axin~b~ack a sigriecl of this letter to Christopher Ruff at 263-7874 (fax). Wendy~Vlahan AOGCC Date SCANNED JAN 4 2[1 3 JUN 29 1998 Alaska Oil & Gas Cons. Common 08:34 UNOCAL A$$£? GAS ( GRP NO. 9072637874 ( Unocal Corporation Agricultural Products 909 West 9a Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCALe P, 02/05 June 2, 1998 Wendy Mahan State of Alaska Alaska Oil and Gas Conservation Commission 3001 Por~pine Drive Anchorage, AK 99501 Re: Trading Bay Field MONOPOD A-12RD This letter is to document your approval of Monopod A-12RD Shut-ln M1T's. Attached is a copy of the temperature survey completed on May 29, 1998. Please review this data. If this well passes its Shut-in MIT, please sign and send a copy of this leller to my fax at 263-7874 othenvise call me at 263.7830. giaee/" Cook Inlet Watcrilood Mam~meat Please return a signed and dated copy of this letter to document the approval of the SI MIT for our records. AOGCC JAN 2 4 2003 Aogcc Monopod A-12RD SI MIT.doc 06/02/98 JUN-03-98 NED 08:34 U!{Onal. ASSET GAS GNP FAX ItO, 9072~7874 P, 03/05 4O Monopoct A-12RD Temp Survey 50 60 70 BO 90 10C 110 1,500' 3500' 4 4 500' 5.000' 5. ~00' 7,000' A-12 Temp Survey.xls Running In Steve Tyler 612198 JUN-O~-98 ~D 08:~8 -, UNOCAL ~$$ET G~$ GRP ( NO, 9072!~'7874 P, 04/05 Monopod A-12RD Temperature Survey Procedure · :. Gage Tubing. Tag for fill. · :o R/H at 60' per min making 3 minute stops every even 1,000' to fill depth. Record time and depth at each stop. · :. Wait 10 minutes on bottom. POH at 60 fi per min. making 3 minute stops every even 1,000'. · :* RD Slickline. SCANNED JAN 2, 4 20{}3 JUN-03-98 NED 08:38 , , &q 50-733-20076-01 _bopd_. Plollofln Cofldbclof 26. UN?C,~L ~SSET GhS GRP IBSA-12RD ~rf~o~ ~ Si°leF'teid FAX NO, 9072~F,~7874 m(B [~v, I01 FI, il51. P~l ~ion 4o,7 ~ P. 05/05 611)J) - r~34.r FIICl8 kill r m o- mtJ'SBEA mls~~.~17~ ' r O0 3ZAll/II X-Lm,lli~M,II m ~ 7' oo 2t~/11 II-l)jimddlJll 1181~ 6118' 6GANNE~ jAN 2 m-~TBImClIIir I/3U- 61~r 77,~ - mol ~ 51-6, r. 3~ mu. ~ PLIn 51-k r, 3/J6/72 mzJ. 7122; p61s474 ~, N-,IlK HAR-27-98 FRI 13:52 UNOCAL ASSET GAS GRP FAX NO. 9072637R74 Uno~al Corporation 909 West 9'~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 P, 01/01 UNOCAL(B I~arch 27, 1998 Wendy Mehan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Status of Unocal's Cook Inlet Injector Work Dear Wendy, This letter is to provide you with an update of tim work conducted since our Sanuaty 23, 1998 letter which Blair signed granting time extensions for various wells. Testing or work was completed on thc followin_~, wells ~d the results of this work is listed' Anna. 29-42: Well head inspection completed (no leaks), Variance granted on 3/3/98. Baker 4: MIT passed on 2/.15/98 by Leu Orimaldi Bruce 31-42: Coil Tubing operation completed to repair leaking cement plug. Pressure test completed. GP 33-14RD: SI MIT successfully completed on 2/11/98. GP 22-13RD2: Variance granted on 3/1'//98, MIT completed on 12/15/97. Grayling 16: Workover completed on 3/26/98. MIT Passed. Monopod A-SRD2: MIT passed on 1/28/98 by Leu Grimaldi Testing or work was att~mpt¢.d on the following, shut-in wells An_d a time exlensi0n tmtil 3une 30, 1998 is rpqueste, d tocomplete further work. and testin_~. Anna 19-42: Scale clcanout of tubing completed, further testing scheduled to prove casing integrity. Anna 2?-42: Scale cleanout of tubing completed, further testing scheduled to prove casing integrity. Anna 46-42: Temp Survey ran on 2/17/98, survey should prove no flow and allow SI status. Baker 9: MIT attempted on 2/15/98, further wireline testing scheduled to prove casing hltcgrity. Monopod A-12RD2: SI MIT attempled, Temp Survey scheduled to prove no flow. Monopod A-29 : SI MIT scheduled to prove no flow/casing integrity King 4RD : WFL indicates possible casing leak, well shutin, further testing and workover scheduled. King 15RD: WFL indicates possible casing leak, well shutin, further testing scheduled. King 22RD: WFL indicates possible casing leak, well shutin, further testing scheduled. Grayling 5 : Workover/Redrill scheduled in current drilling schedule. Grayling 22 : Workover/Redrill scheduled in current drilling schedule. Grayling 28 ' Workover/Redrill scheduled in currant drilling schedule. Grayling 36DPN : Workover/Redrill scheduled in current drilling schedule. Grayling 40 : Workover/Redrill scheduled in current drilling schedule. Unocal respectfully requests a time-extension until June 30, 1998 to complete the work on the above listed Anna, Baker and Monopod wells. The Grayling and King work will be executed per our current drilling scho. dul.e. P_l~llse call me if you have any queslions or clarification on these issues. R E C E~V ~ L) ~ MAR 27 '~998 Senior Reservoir Engineer Cook Inlet Watofflood Mana~ 0i~ & Gas Cons. GornmmStOn Anchorage Please acknowledge t~e approval of tile time extension and )'our receipt of this letter by faring back a signed copy of this letter to Christopher Ruff at 263-7874 (fax). CVCndy~l~jclum' Dat[~ '1 - AOGCC SCANNED JAN g 4 2003 Unocal Corpo ration,r~" Agricultural Products 909 West 9th Avenue, P.O. Box t96247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UN.OCAL ¢, ~ t January 26, 1998 · i', U,'" Blair Wondzcll State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Approval and Time.Extension of Monopod Shut-in MIT's Dear Blair: · Thank you for your assistance last Friday. In order to document our conversation and update our well files would you please sign and date the A-SR and tho A-26 shut-in lvllT's for verification that they have passed and fax mc a copy at 263-/874. In addition would you ploase sign and fax back a copy of this letter verifying a time extension until the end of March 1998 for Unocal to redo the shut-in MIT's for the A-12RD2 and the A-29 Monopod wells. Senior Reservoir Engineer Please indicate your approval for the time-extension until the end of March 1998 by signing and foxing a copy of this letter to 26]-7874. Thanks again for your help in this matter. Agr~'d to by: Blair Wondzell/~ Petroleum Engi~er AOGCC Date ( Unoca~ AlasKa Resources dnocal Comorat~on 909 West 9th Avenue. P.O. Box ~ 95247 .:,.ncnoraae, AlasKa 995! 9-624;' Teleonone (907/£75-T6C.0 UNOCAL January 23, 1998 Blair Wondzell State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Status and Plans for MIT testing of Cook Inlet Injection Wells Dear Blair: Thank you for your assistance in helping us complete our mechanical integrity testing of water injectors in the Cook Inlet Area. The following is a status of our efforts to date. We also request a time extension for a group of wells listed below to allow us to complete testing work. We request a time extension for completing MIT testing on the following wells until the end of March 1998: Currently shut-in wells Granite Point Field Anna 19-42 Anna 27-42 Anna 46-42 ..... ~ ............. ,- ~,~,, 33-i '"'"' "'-' ~'!' n I.~ Middle Ground Shoal Field Baker #4 Baker #9 Currently injecting wells Tradin,q Bay Field Monopod Platform A-8RD2 Wells Needing Repair The shut-in MIT on t3ruce Platform Well. # 31-42 indicated a problem with the temporary abandonment which was completed on 10/7/88. We will develop and send to you a proceaure for repairing or permanently abandoning this well. An MIT on shut-in Granite Point Platform Well. # 33-14 indicated a mecl"ianical problem with this well. We will develop and send to you a procedure for repairing or permanently abandoning this well. We also want to confirm your receipt and approval of .the following shut-in MIT tests. For our records, please sign and return a copy of the following shut-in MIT tests: Baker #8 Baker #12 Monopod A-5R cz Monopod A- 12R2 Monopod A-26 ~J~.,.,- Monopod A-29 Please. indicate your approval of the shut-in tests and the time extension requested by signing and returning a copy of this letter. Thanks again for your help in this matter. Sincerely, '*'J'eff S m~ Reservoir Engineer Agreed to by: Blair Wondzell ~,/ ' Petroleum Engineer AOGCC .RUG-19-97 TUE 08:26 UNOCRL R$$ET C,R$ C-RP FRX NO, 9072837874 Proc,edure for MIT on Shut-in Monopod Injector P, 06/06 1. Record daily tubing, casing, and outer casing pressures for a consecutive 10 day period. ................ Oute.r,,,Casing Pressure Date Tubing Pressure Casing Pressure 13-3/8" 20" .. . 7/7/97 275 psi 250 .Psi 50 psi 0 psi 7,/8,/97 ......... 275 p,sl ..... 250 psi, , . 50 psi 0 psi 7/9/97 275 psi ..... 250 psi .... 50,psi 0 psi 7/10/97 ., . 275 psi 250 psi 45.psi 0 psi 7111/97 .... 275 p,s! L, ,245 psi ..... 45 psi 0 7/12197 ,, ,2,,,7, 5 psi 255 psi ..... 45 psi. 0 ps!. 7/13/97 280 psi .... 250 psi 40 psi 0 psi 7/14/97 280 p.s.! ........... 245 psi ,, 40,,p, si ,0 psi . 7/15/97 280 psi .245 psi 40.psi 0 psi.. 7116/97 280 psi 250 psi 40 psi 0 psi "'"':: 19 1997 Unocal North Americ;y' Oil & Gas Division ~.. Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson: I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, Regional Drilling Manager. GSB / 1 ew CONDUCTOR 1 2 3 4 5 6 7 8 9' lO ll 12 13 14 15 16 17 lB 19 2O, 21 22 24 25 26 27 28 29 30 31 32 MONOPOD CENTER FROM SOUTHEAST CORNER, SECTION 4, TgN, R13W . "Y" = 2,523,126 "X" = 218,871 "Y" COORD. 2,523,134.3 2,523,130.2 2,523,125.7 2,523,121.7 2,523,118.2 2,523,114.4 2,523,113.2 2,523,113.2' 2,523,114.8 2,523,117.7 2,523,121.8 2,523,126.4 2,523,130.3 2,523,133.8 2,523,137.6 , 2,523,138.8 2,523,138.8 2,523,137..2 2,523,132.8 2,523,129.4 2,523,132.0 2,523,128.4 1.2,52.3,_l.2Zl..R .-.: ..._. 2,523,333.9 2,523,120.9 2,523,131.4 2,523,118.1 2,523,127.2 2,523,123.6 2,523,120.0 2,523,122.6 2,523,119.2 LAT. = 60053, 48.65:1' '~/'~'- ~'~ ~'- ~'~' LONG. 151°34' 43.51 ~ ~'/~,~-aW//,t6,~, "X" COORD. WELL # FS__LL FEL 218,880.9 A-28 1621 554 218,883.2 A-25 1617 551 218,883.9 A-30 1612 551 218,883.2 1608 551 218,881.3 A-27 1605 '553 218,876.8 A-23 .16D1 557 · 218,873.0 A-21 and RD 16DO 561 218,869.0 A-22 1600 565 218,864.6 A-14 1601 570 218,861.1 A-13 1604 573 218,858.8 A-17 1608 576 218,858.1 'A-8 1612 577 218,858.8 A-15 1616 577 218,860.7 A-24 and RD 1620 574 218,865.2 A-29 1624 570 218,869.0 A-9 and RD 1625 566 218,873.0 A-19 1625 562 218,877.4 A-18 1624 558 238,875.7 A-11 1619 559 218,878.6 A-3 1616 556 .. 218,870.8 A-1 1618 564 218,873.9 A-7 1615 561 .~ ?.l ~ ~.6 -~ ....... A-4 ..... 1611 558 218,867.0 A-6 1600 :568 218,878.1 A-32 1607 556 218,863.9 A-12 and RD 1617 571 .218,875.0 A-20 1604 559 218,865.1 A-2 1613 570 218,868.1 A-16 1610 566 218,871.1 A-26 1606 563 218,863.4 A-10 1609 571 2.18,866.3 A-5 and RD 1605 568 l&2 Union Oil and Gas(D:",ision: Western Region Union Oil Company ol' California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union September 23, 1985 Hr. C.V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Dear Nr. Chatterton: TRADING BAY FIELD A-12RD Attached for your approval are three copies of Union's intention to perforate and pull tubing in Well A-12RD. Please return a copy of the approved Sundry Notice to the undersigned. Very truly yours, Candace Lockw~.. Environmental Department cwl Attachments ~s~,~ Oi~ & G~s Cons. Com~ss~o~ k STATE OF ALASKA ALASK OIL AND GAS CONSERVATION C~JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL,[~ OTHER [] 2. Name of Operator UN[ON 0IL COMPANY OF CALIFORNIA 3. Address PO BOX 6247 ANCHORAGE AK 99502 4. Location of Well Cond. #26, 1617'N & 571'W of SE Cot., Sec. 4, TgN, R13W, SM. 5. Elevation in feet (indicate KB, DF, etc.) RT lOl' MSL I 6 . Lease Designation and Serial No. ADL-18731 7. Permit No. 7] -29 8. APl Number 5o- 733-20076-0] 9. Unit or Lease Name Trading Bay State 10. Well Number TBS A-12RD 11. Field and Pool Trading Bay Field "C" Zone 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing ~' Other ~' Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting anv proposed work, for Abandonment see 20 AAC 25.105-170). 1.) 2.) 4.) 5.) 6.) 7.).. 8.) 9.) 10.) 11.) 12.) 14.) 15.) Move in and rig up over well A-12. Kiii weIi, instaIi BPV, remove tree, instaii and test BOPE to !3000 psi. PuIi and iay down existing duai compIetion assembiy. CIean out to ETD a ! 8428' & run CBL and casing inspection Iogs from ~ 5500-8000'. Squeeze cement the C-7 interval for abandonment. CIean out retainers and cement to + 8428'. Pressure test the C-7 biock squeeze. Squeeze cement again if necessary. Perforate the C-5 sand (70ft., 8/HPF) & reperforate the 47-5, 50-3 & 51-6 sands (20ft., 4/HPF). Acidize all sands. RIH with an RTTS and set ~ + 6475', directly above the C-5 sand. Inject into the C-5, 47-5, 50-3 & 51-6 sands & run an injection profile. If individual sand is not taking reasonable injection, straddle and re-acidize. Complete well with a single 3-1/2" tubing string. ~ ~ C E ~V E D Land tubing, install BRV, remove BOPE, install and test tree. Place well on injection. Release rig. SEP25 8 Alaska 0~ & Gas Cons. C0mnr Anchorage · 14. I here~a~:o~d Signed Lawrence U. Cu[czng' The space below for Commission use' correct to the best of my knowledge. ~'_'~ Title ENVIRONMENTAL SPECIALIST D~;l~-12-85 Conditions of Approval, if any: Approved by ' ^pproveCt_C~op¥ ~teturn~ - -- By Order of COMMISSIONfiR the Commission Date ,issi~ Form 10-403 Rev, 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE Of ALASKA C(",.,0M 0 ~ ALASK!", OIL AND GAS CONSERVATION MISSION SUNDRY, NOTICES AND REPORTS ON WELLS ' DRILLING WELL [] COMPLETED WELL [] OTHER ~ 2. Name of Operator 7. Permit No. Union Oil Company of California 71-29 3. Address 8. APl Number P.O. Box 6247 Anchorage, Alaska 99502 5o-733-20076-01 4. Location of Well Cond 26, 1617'N & 571'W of SE Cor, Sec 4, T9N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) ET 101' MSI 12. I 6 . Lease Designation and Serial No. ADL 18731 9. Unit or Lease Name Trading Bay State 10. Well Number TBS A-12 RD 11. Field and Pool Trad.ing Bay Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [~] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed proposed work, for . 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any Abandonment see 20 AAC 25.105-170). 14. I herel~cer~fy that the fj;~qj~is true and correct to the best of my knowledge. ' Signed.ji'~m'~'~'ll'Lall'd~q~ ' ~"' Title Dist. Drilling Superintendent Date The~;~elow for Commission use Move Rig #56 over well~ TBS A-12 and rig up. Kill well, install BPV, remove tree, install and test BOPE,.to 3000 psi. Pull and lay down existing compl'etion assembly. Clean ou+ to ETD @ 8428' and run CBL'and casing inspection logs. Squeeze cement' the C-7 and 47-5 intervals for abandonment. ~'~7 Clean out retainers and cement ~7-~ 7~,~-~.J~- Pressure test the C-7 and .47-5 block squeezes. If necessary, squeeze cement again.~-~ Perforate the C-5 sand and reperforate' the 50-3. and 51-6 sands. ~-~' ~°' Acidize',a,l,1 sands using a circulating wash,tool 5-/-~ ?~,~-- 77~ ~,z- . . 77jZ-77~o Inject .into.the C-5, 50-.3, and 51-6 sands and run an injection profile. If an individual sand is not taking reasonable injection, then straddle and re-acidi ze. Complete well with singlle 3 1/2" tubing string. ?~c~,~_ -~:~o' Land tubing, .install BPV,.remove BOPE, install and test tree. Place well on injection and move rig. /~....,,~.~ !.?. ii:!! i?,. i.:,:-:: [i~.~.,t~l~..,.:./~,jo_.(~,~ ~"-( I'~ T '"~~'~-~ i:'~ . '~ 7/4.0 - 7, ,~' o - 02/28/84 Conditions of Approval, if any: : Approved by I)RI6 NAL SII;MEi) COMMISSIONER Approved Copy By Order of the Commission ' Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Gas D~}'"'sion: Western Region Union Oil Company ot California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 ~'l' c. ~o"~ -'~ ~ ~O ', .~y ~4, ~97~ "l~ ~'~:':~t' Hr. ttomer ~rre11 Division of 0il ~ Gas ~001 Porcup~e Drive ~chorage, Alas~ 99504 ~a: unlen TBSA-27 TBSA-12 RD TBS A-29 TBS A-1 WO Dear Mr. Burrell: Enclosed please find the Drilling Histories (2 copies each) for the above captioned wells. JRC/sk Enclosures Very truly yours, Callender District Drilling Supt. MAY ! ? 19/3 D!\,'~$IC i'~ ,,. F C IL AND O,.kS ANCHORAGE SEC TOOL /T'SHIP/ a HODEL ~4AKE: & MODEL / ,_'/~/ '"7'~ UNDER /__ ~.,.'.~'--'7-~ DRILL COLLARS: NO, J_? O.D.- ~' J-~' LENGTH SPUD DATE,-/T'"~-/:_/'"J~ SURF, I.D. INTER., T.D. DRILL COLLARS: NO. O.D. I.D .... LENGTH RUN SIZE MAKE JETS-32NO BIT DEPTH NO. I MUD DULL COHO. '- NO. SER. NO. OUT REMARKS (FAILURE, MUD, ETC.) /- z. C'~-m~J~'7- .T REED REPRESENTATIVE PHONE i ii Reed DdllingTools Division _ II III RO.Box 2119 Houston Texas 77001 i _ ii i i F,,,403 o,," COM~^,Y TOOL P_U_..S H Bli ,RIG N O,---~:b-- RECORD FLD./TOWN DR DR DR SEC./T'SHIP/ RANGE RiG MAKE ~AKE & ~ODEL SHEET TOOL RECORD NO., NO. JOINTS: MAKE.~ .UNDER s,u~ ~,,, ~-~-?z s~,,. ~ -...~-~,,~ co~A,S: ,o. MAKE EL , INTER. .T. D. DRILL COLLARS: NO. , , O.D.,--I.D.~LENGTH. ACCUM. WT, VERT, PUMP NO, 1 NO 2 MUD DULl,, COND, REMARKS RUN , JETS.32ND BIT DEPTH FOOT. HOURS HOURS I000 RPM NO. SIZE MAKE TYPE SER NO. OUT AGE' DEV. PRESS. -- ................ ' ................................. . ( FAILURE, MUD, ETC. ) I Z 3 ' LB. SPM LIN, SPM LIN. WT. VIS. T B i~ ........ , ~,_,~, ~ ~¢~ ~ ~ ~, ,, REED REPRESENTATIVE PHONE ii ii i Reed DrillingTooLs Division P.O.Box 2119 Houston Texas77001 i ii iii ii F,-403 LINION OIL CO. OF CALIFORNIA DRILLING RECORD SHEET D' pAGE: NO LEASE. Trading Bay State __WELL NO. A,12 RD FIELD Trading. Bay · DATE E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 2-21-72 22 23 '24 25 26 '27 28 29 3- 1-72 2 900' + 1150' 1076' 1235' 1823' 2235' 3221' 3946' 4636' 5406' 5721' 5850' 6347' 6871 ' 7439' 7500' 7500' 7'500' Began moving rig-to A-12 at.8-O0 A. M., 2-21-72. Stopped rig over A-10 for ll hours to perform wireline work such as recovering fish, closing sleeves, setting plug, etc. Continued move to A-12 at 7:00 P. M., 2-21-72. Installed riser and. BOPE on existing casing"head. Flanged up BOPE. Tagged top of cement at 890'.._Tested pipe rams 2500 psi. Killed and choked 2000 psi, drilled cement with 12 1/4" bit to 1150'. Conditioned mud.. Opened hole to 14", 1066' to ll50'. Circu- lated clean. RIH and hung open end. DP at 1145'. 'Mixed 200 sacks Class "G" cement with 10% sand, 5% nut plug. Displaced with 97 cu. ft. mud. CIP at l:O0 A. M. POOH. Tagged top at 1-O0 P. M. at 914'. Cleaned out to 1076', circulated clean. Ran Multi-Shot..G~ro Survey to 10'60" Made up Dyna-dri 11. Oriented drill and Dyna-drilled 1076' - 1235'. Sand line parted. Drilled and surveyed 1235' - 1330' RI With building set up. Drilled 1330' - 1572' POOH. Changed d-riiling assembly. Drilled and surveyed .12 1/4" hole i572' - 1823'. Drilled and surveyed to 2134'. POOH. Changed drilling assembly. RI with Dyna.-drill. Drilled from 2124'to 2235' for left hand turn. POOH. RI with drilling assembly and reamed from 2124' - 2235'. Drilled and surveyed to 2453'. POOH. Changed drilling assembly to lock up. Drilled and surveyed to 3221'. Dril 1 ed and surveyed' to 3946 '-. o . Drilled and surveyed to 4214'. POOH. CY~anged near bit stabilizer to' 12". RIH, drilled and surveyed to' 4636'.' ' Dril led and surveyed to' 5406'. Drilled 12 1/4" hole to 5593'o. POOH. RIH with Dyna-drill. Drilled and surveyed to 5721'. Needed more right turn. Drilled to 5747' POOH. Tight spOt at 31-60'. RIH with drilling as- sembly and drilled 12 1/4" hole to 5850'. POOH tight.spot at 3160'. RIH. Reamed from 3100' to 3200'. Drilled and surveyed 12 1/4" hole to 6347. " Drilled and surveyed 12 1/4" hole to 6871'. No tight sp~ts on trip for bit changed at 6638'. Drilled and surveyed 12 1/4" hole to 7439'. Drilled and surveyed 12 1/4" hole to 7500'. Circulated and conditioned for logs. Ran Schlumberger DIL and Sonic'-GR. Finished running Schlumberger Sonic-GR' and.FDC-CNL-GR logs. RIH and circulated and conditioned for casing. RU and ran 181 joints 9 5/8" 43.5# N-80 and P-110 buttress casing with shoe at 7490'. Float collar .at 7400' and DV collar at 2011'. Cemented thru shoe with 650 sacks Class ':G" cement, 8% gel, 1% CFR-2 follOwed by 250 sacks Class "G" cement premixed with 1/2 cu. ft. per sack perlite, held. - . [qAY ! ? Ig'/3 .... '"',' i: OIL AND GAS Ab!CHORAG.~ - UNION OIL CO. OF CALIFORNIA' DRILLING RECO .RD 'SHEET D PAGE NO... 4 LEASE Trading Bay State . WELL 'NO.A-1.2.RD FIELD_ Trading.Bay. DATE E.T.D. , DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 3-9-72 Contd. lO ll 12 13 14 15 16 7500' 7738' 8112' 8354' 8473' 8439' 7261' 8439' CIP 4:50 P. M., 3-9-72. Cemented thru D.V. with 870 sacks Class "G" cement premixed with 1/2 cu. ft. per sack perlite, 4% gel, 1% CFR-2. Displaced with 84 cu. ft. mud. Bumped plug. Float held. Approxi, mately 535 cu. ft. of cement returned. CIP l l:lO P..M. 9 5/8" CASING DETAIL Bottom Top Lien(tth Jts Description 7490. O0 7487.92 2.08 7487.92 7402.05 85.87 2 7402.05 7400.47 1.58 7400 .'47 7398.39 2.08 7398.39 2012.46 5385.93 130 2012 46 2010.31 2.15 - 2010.31 39.00 1971.31 '48 39. O0 -0- 39. O0 - - .9 5/8" .Howco Float Shoe 9 5/8"' 43.5# N-80 But.tr:ess Csg. 9 5/8" Howco Float Collar 9 5/8" Howco Diff. Fill Collar '-9 5/8~ 43.5# N-80 Bu-ttress Csg. 9 5/8" Howco DV Cement Collar 9 5/8" 43.5# N-80 Buttress Csg. Elevation 180 Total Landed 9 5/8" casing and flange up BOPE. Tested' BOPE to 3000 psi, OK. Drilled out DV and tested to 1500 psi, OK.. Drilled out-shoe. Drilled and surveyed to 7738'. Drilled and surveyed 8 1/2" hole to 7791. POOH. Changed drilling as' sembly to drop angle. RI, drilled and surveyed 8 1/2" hole to 8112'. Drilled and surveyed 8 1/2" h'ol'e to 8354'.. Drilled and surveyed 8 1/2" hole to 8473'. Circula-ted and conditioned for logs; POOH. RU and ran Schlumberger, DIL, FDC-CNL-GR and HRD logs. Finished running HRD. RIH and circulated and 6ondi. tioned for 7" casing. RU and ran 39 joints 7" 32# X-line casing with shoe at 8468', plugged catcher at 8439' and hanger at 7261' Cemented. with 200 Sacks Class "G" cement premixed with 1% CFR-2. Dispiaced with 96.4. cu. ft. mud. BUmped· plug'; Float did not hold. CIP 6:45 P. M., 3-14-72. POOH. 7" Liner Detai 1 From To Le.n§th Descripti on 8468.00 . 8465.63 2.37 8465.63 "' 8439.85 25.78 8439.85 8438.98 O. 87 8438.98 7279.07 1159. O1 7279.07 7260.97 18.10 TIW Guide Shoe 1 it. 7" 32# XLline Casing TIW Plug Catcher 38 its. 7" 32,f x-line Casing 1 TIW Liner Hanger PU 3 1/2" drill pipe. Tagged .top of liner at 7261". No cement. POOH. RI with RTTS and set at 7190'. Breakdown lap with 19 cu. ft per minute at 1300 psi. Squeezed with 200 sacks Cla'ss "G" cement with i% CFR-2. Displaced with 741 cu. ft. mud to a final press of 2500 psi. POOH. RI with 8 1/2' bit and casing scraper. Tagged./ cement at 7221'. Drilled out. to 7261 '. RIH with 5 7/8" bit and 7" casing scraper and cleaned out cement to 8439'. Tagged top of hard cement at 8000'. RU and ran Dresser-Atlas CB~j- RIH with 9 5/8" RTTS to 2350' and tested laP to 2300 psi for 10 minu s, OK. ;~,~,~ ~ F ~iL ~,FID OAS ANCHORAGE : UNION OIL CO. OF' CALIFORNIA DI~i LLING RECORD SHEET D PAGE NO, 5 LEASE' Trading Bay State WELL NO.A-12 RD I;IELD, Tradinq Bay - DA'rE 3-17-72 18 19 '20 21 22 23 24 E. T. D. 7535' 7535 7555 8439' 8439' 7075' 7075' 7261' DETAILS OF OPERATIONS. DESCRIPTIONS & RESULTS RIH with RTTS and set at 7490'. RU and perforated four holes at 7700' Brokedown perforations with 8 cu. ft. per minute at 2300 psi. S.queezeJ perforations with 100 sacks' Class "G" cement with 1% CFR-2. Displaced with 694 cu. ft. mud to a final press of 2825 psi. CIP'5:15 A. M., 3-17-72. Reversed out. Set RTTS at 7303. RU and ran Dresser four shot gun through drill pipe. Could not get below 7511'. POOH. RD Dresser. POOH. Rotary motor shorted out. RIH with 5 7/8" bit-and 7" casing scraper. Washed out green icement to 7535' POOH. RIH with RTTS and set at 7303. Perforated four holes at 752i'. -Pumped 2 cfm at 3000 psi. POOH. Set Howco EZ drill retainer-on wireline at 7471'. 'RIH and stabbed into retainer. Test-perfs to 5000 psi for fiVe minutes and annulus to 2500 psi for five minutes. Circulated while repairing-rotary motor. Test on D.V.,. OK. Finished repairing rotary motor. RIH with bit, drilled out retainer and · cleaned out to 7555' Perforated four holes at 7521'. Ran l-i°wco EZ- drill retainer on wi~eli.ne, set at 7451'. RIH with Howco'stinger and broke- down perfs with 10 cfm at 2650 psi. Squeezed perforations ~.~ith''' 100 sacks Class "G" cement with 1% CFR-2. to a final pressure of 3000' psi. Re- versed 25 cu. ft. cement. CIP 11-25 P. M., 3-19-72. POOH. WOC. RIH with. bit. Drilled retainer at 7451' and hard cement to 7700'. Cleaned out cement stringers to 8439'. POOH. Changed over to 66# filtered Inlet water. RU and ran Dresser-Atlas GR-CBL. Ran 9 5/8" RTTS to 6785'. Perforated t.hru drill pipe with Dresser-Atlas two 1/2" hpf 681!' - 6851' Broke- down perfs at 2400 psi and 4 bpm. Acidized with'BO0 gallons Jf Solvent B, 1600 gallons 2 1/2% HCL, 3000 gallons mud acid and 1600 gallons HCL. Displaced at bpm at 2100 psi. Injected 600 bbls filtered Inlet water to a final pressure of 1900 psi. Displac?d filtered Inlet. water with 66# salt water. Set RTTS at 6864" Test'to 1000 psi.. Perfo'rated 2 1/2" hpf from 6886'-6926' ]~/ RTTS at 6864' Tested to 650 · psi-had co[mnunication. Se~-~tts at 6785' and acidized ~ith 800 gallons of Solvent B,1600 gallons HCL, 3000 gallons mud acid and 1600 qallons HCL. Displaced at 2 bpm at 400 psi. Displaced w/ 600 bbls. f~ltered Inlwt water. Set RTTS at 6940'. Perforated two 1/2" hpf from 6960'- 6980'. Pressured to 550 psi with communication thru 'perfs abov.~---- --S'~t--~-TS at 7068'. Perforated.7092'-7122'. Brokedown perfs w/ 2000 psi at 2 bpm. Acidized with 800-~-~ ~i~ent B, 1600 gallons 2- 1/2% UCL, 3000 gallons mud acid and 1600 gallons 2-1/2% HCL. While injecting' 450 bbls filtered Inlet water at 2 bpm, communication started to open perfs above. Rams were closed and displacement continued. Ran Howco EZ drill retainer on wirelin~, set at 7075'. RIH and stabbed into retainer. Mixed and pumped 50 sx. class "G" cmt. w/l% - CFR2. Displaced w/ filtered Inlet water. CIP'10:45 pm.. WOC. Cleaned out hard cement from 6974' to 6982'. WOC to 10-30 pm. Cleaned out hard cement to 7075'. W2shed to 7060'. DO retainer. Firm cement to 7097', stringers to 7127'. Cleaned out to top of liner Circ hole clean~ Set RTTS at 7068'. Brokedown perfs ~.~/ 2100 p;i and injected 2~vm at 2050'psi. Moved RTTS to 7146' and tested to 2500 psi --pk. Perforated two 1/2" hpf from 7160'-7180' Brokedown perfs w/8 cmf at 2400 psi. Co~nunicated to ope~-~ ~-~61 POOH. RIH with 5-7/8" bit and worked ti~ru and cleaned out junk on top of l i'ner. Worked free and POOH to ]. d. casing scraper. MAY 'i ? ig? . -DIV:$1Gti (;I'"-OIL Ab:ID C)A~ A),IcHORAGI~ UNION .OIL CO. OF CALIFORNIA DRILLING RF'CORD -SHEET D PAGE. NO,,,- 6- ' . LEASE TRADING BAY STATE %VELL NO. A-12 RDFIELD TRAIlINg RAY DATE 25 26 27 28 29. 30 31 E. T. D. 8428' 8428' 84281 84281 8428' 8428' 8428' DETAILS OF OPERATIONS, DESCRIPTIONS 8{ RES. liLTS. RIH w/ 5-7/8" bit on 4-3/4" DC's. Unable to get into liner without rotating. POOH. RIH w/ 8-1/2" bit and broke up junk on-top of liner.. POOH. RIH w/ 5-7/8" bit and cleaned out to 8428'. Junk from Dresser-Atlas guns. Set RTTS at 7490' and tested to 2500 psi. Shot two 1/2" hpf from251_4~ to 7520'_,__ Pressured to 3000 psi which dropped to 2500 psi after 5 m~ Set RTTS at 7677'. and perforated two 1/2" hpf-from 7715,-7721'. Pressured to 3000 psi. Spotted 380 gallons mud acid acroSs p~rfs. Displaced w/ Howco Set RTTS at 7490'. Pumped-'5 cfm at 2500 psi. Acidized with 300 jallons Solvent B, 750 gallons 2-1/2% HCL, 1200 gallons mud'acid and 750 gallons 2-1/2% HCL. Displaced wi th 600 bbls filtered Inlet water. Moved_RTTS to 7677' Brokedown perfs from 7715' to 7721', with 1.1 cfm at 2700 psi. Per~orated two 1/2" hpf, 7732-7740. Brokedown perfs w/ 17 cfm-at 2700 psi. Acidized with 664 gallons Solvent B, 2000 gallons 2-1/2% HCL, 2800 gallons mud acid and 200 gallons HCL. Displaced tool, pumped away at 2500 psi and 2 bpm, injected w/ platform injection system. Layed down RTTS. RIH w/ 9-5/8" RTTS and. set at 7037'. Inject w/ plat- form injection system until rate stabilized at 4000 B/D at llO0.psi. RU and ran GO-International profile logs. Reset RTTS at 6508'. Dresser- Atlas perforated 2 hpf from 7102' to 7122' and 7160' to 7180'. RU and ran GO-International profile logs. RIH w/ 5 7/8" .bit and cleaned out to 8428' RU and ran 9-7/8" wireline Guiberson packer on Dresser- Atlas. Packer stuck at 5836'. Pulled out of"rope socket. RIH w/ overshot, three 6-1/4" DC and BS. Pushed packer, to liner-top at 7621'. POOH. Overshot did not pick up packer. T IH w/ 6-'5/8" skirted Overshot. Worked over fishing neck but could not move packer. Pull. ed setting tool out of pacJ~er and POOH. RIH w/ 8 3/8" Tri'State packer retriever below junk sub jars and BS. Milled over and retrieved packer. RIH w/ 5-3/4" bit and cleaned out to.8428'. POOH RIH w/' 8-1/2" bit and cleaned out to 7261' POOH. RU and ran ~50 joints 3-1/2" 9.2# N-80'buttress tubing. Long Jtring packer at 7037' and short string packer at 6738' Tested long string packer w/14 cu. ft./minute at 1100 psi for 5 ~inutes - ok. Attempted to seat donuts in hanger. Short string donut would not seat. Respaced short string and seated donuts in hanger. Set short sting packer at 6738'. NU tree. Tested packer at 6750 ?/1500 psi for 5 minutes "- ok. Opened XO sleeve and displaced 72#/cu. ft. salt water inhibited w/A-lO1 from 6738 tb surface. RIG RELEASED AT 12-00 pm, 3/31/73. Completed at dual Middle Kenai "C"-Water Injection well. NIAY ! ? ig?'3 DiV]StC;I'4 - i: OIL /,.FID GA~ Ab~CHORAGE UNION OIL CO. OF CALIFORNIA' DRILLING RECORD SM EET D PAGE NO. LEASE Trad i ng Ba~/ State WELL No.A-12 RD FIELD Trading .Bay- DATE E. T. D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESLrLTS TUBING DETAIL Long String 2 7/8" Otis "N" Nipple 2 7/8" N80 EUE 8-Rd pup Jt. ~ 1/2" 8-Rd x 2 7/8". 8-Rd x-over. Guib. 9 5/8" 36-47// x 3 1/2" RH1 packer 2 7/8" Rd x 3 1/2" Rd x-over 2 7/8" NB0 EUE 8-Rd pup jr, 2 7/8" Otis "X0" sleeve 2 7/8" Otis expansion jr. 3 1/2" Butt. x 2 7/8" EUE 8-Rd x-over 3 1/2" NB0 Butt. Tubing 3 1/2" 10-Rd x 3 1/2" .Butt, x-over Guib. 9 5/8" 36-47# 3 1/2" x 3 1/2" Rh 2 packer. 3 1/2" N80 Butt. x 3 1/2" ~UE 8-Rd. pup j t. 3 1/2" N80 Butt.'Tubing 3 1/2" Otis "XO" sleeve 3 1/2" N80 Butt. Tubing 3 1/2" NBO Butt. pup Jr. 3 1/2" H80 Butt. Tubing 3 1/2".Butt-. Otis expansion Jr. · 3.1/2" N80 Butt. Tubing 3 1/2". 8-Rd x 3 1/2" Butt. C/W Hanger Landed below zero JTS, LENGTH BOTTOM 'TOP 1 4 27 3 189. 1..1-1 7054..04 7052.93 8. O0 7044.93 ] .12 7043.81 6.81' 7O37.0O 1..08 7035.92 4..09 7031.83 3.03 7028.80 3.15 7025.65 1.24 7024.41 274.62 6749.79 l ~06 6748,73 9.80 6738.93 4.20. 30.95' 3.98 121.82 i6.10 831.08 15.27 5687.67 .86 37.00 6734.73 67O3.78 6699,80 6577.98 6571.88 5740.80 5725.53 37.86 37.00 -0- D","':'" i': OIL AND GAS ] -; ..,.,1 ~.: j '4 '-. (lOl')Above MLLI{) R.T. Tubing Hanger TUBING DATA 37' .Short String 3-1/2" N-80 Buttress to XO @ 6747' 2-7/8" N-80 8-RD to N Nipple @6750' · Long String 3-1/2" H-80 Buttress to XO @ 2-7/8" ti-80 EUE to :1 Nipple @ 7054' · VALVE DATA 13-3/84 Casing @ 1066' 61// J~$5 Buttress Short'String 3-1/2" Otis XO Sleeve @ 6728' Lon'g _String 3-1/2" Otis XO Sleeve @ 6699' 2-7./8" Otis XO Sleeve @ 7028' 9-5/8" P~cker @ 6.739' 9 5/8" x 3 1/2" x $ 1/2" Guiberson RH-2~ . _ ._ ~:: 'Packer @. 7037' ~- x 3 1/2" Guiberson Rill 7" Liner Top @ 7.26]' TD 8473' ETD 8428' DATE F'O~IA 24'/ (NEW 5/(,6) oO · . WELL SCHEMATIC TRADING BAY FIELD. 9-5/8" 'Casing @ 7490' 45.5# N-80 ~ P-llO Buttress. 7" Liner @ 8468' 32# P-llO x-li~e. AfFD. .. SCALE DATE ' 12RD' ' '" Original Completion A- _3- -3]=_Z2~_ UNION OIL COM?ANY OF GALIF-OP, IqIA C~D. ~ : Ai'iCi"IC)RAG~ Memorandum Union Oil Company ~'-~, California ~y 15, 1973 Form 935A ~Rev 11/67) TO %'~1 l~q IT B~\Y CONCEP~N: Due to a mix-up inmailing lists and inconsistency in forms, all repair records and drilling well records since February 21, 1972 are being redone and distributed. You will be receiving copies that you may or nmy not have already received soon. Please.replace rinse on file with the new records. District Drilling Supt. JRC/sk Form No. P--4 STATE (~1~ ALASKA OIL AND GAS CONSERVATION CONWIITTEE SUBMIT IN DUPLICAT~ MONTHLY REPORT OF DRILLING AND WORKO.VER OPERATIONS ~. A~I NTJ~[EKIC~L CODE 8. LEJ%SE DESiGAIATION ADL- 18731 WELL WELL OTHER 8. L~IT,F.%R~ OR LEASE NAME 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS OF OPEI~4,~OR - 909 West 9th Av,.nue. Anchnrn~_ Al n~kn OQ~I 4. ~CA~ON OF W~ ' ~ ' Conductor 29' 1617'N ~d 571'W from SE comer. Section 4: T~N~ R13W~ S. M. __ A-ND POOL, OR 1%'ILDCA? HOLE Section 4: TgN, R13W, S. M. 12. PEB/VIIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA_%'GES IN HOLE SIZE, CASING AND CEiViENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED. PEHFORATIONS. TESTS AND RESULTS, FISI-II~G JOB~. JUNK LN HOLE A_~D SIDE-TI~ACKED HOLE AND A2/Y OTI-IER SIGNIFICANT CHA~GES IN HOLE COI~DITIONS. 7037'. Set second 7" wireline production packer at 6_730' buttress tubing with flow control nipple between packers. pipe at 7057'. Installed tree and tested 5000 psi-ok. Commenced operations on TBS A-12 RD W. O. at 12:01 am, 11/7/72~ Operations from the 30th of November to comp le't ion a?e' as 'follb~s.' Completed r~ng 7" 29# N-80 buttress casing tie back string. Tied into liner at 7261'. Cemented bottom stage tie back string with 600 sx class "G" cement. Cemented top stage with 800 sx class "G" cement. Had good cement returns to surface. Removed BOP's. Installed tubinghead and tested same. Tested 7" casing - ok. Drilled out float equipment and tie back receptacle. Ran Gamma Ray log from 7530' to 6600' and cement bond log from 7530' to surface. Perforated 7180' to 7160' and 6926' to 6916. Set retrievable bridge plug at 7230' and RTTS tool at 7151'. Perforations communicated behind 7" casing.. Reset RTrs tool at 6712'. Mixed 350 sx of class "G" cement. Squeezed to final pressure of 3000 psi. Drilled out cement to 7160'. Washed down to top of bridge, plug at 7230' Rigged up wireline unit. Perforated 2 holes/ft., 7122' to 7092', 6980' to 6960' and 6926' to 6916'. Set R/TS tool at 7050' and acidized perfs from 7122 ' to 7092'. Perforated 2 holes/ft, from 7180' to.7160', 6916' to 6886' and 6851' to 6811'. Reset retrievable bridge plug at 7230' and RTTS tool at 7145'. Acidized perfs from 7180' to 7160'. Reset retrievable bridge plug at 7030' and RTTS tools at 6963'. Acidized perfs from 6980' to 6960'. Reset bridge pl6g at 6939' and R/TS tool at 6870'. Acidized perfs from 6926 ' to 6886'. Reset retrievable bridge plug at 6864'. Reset R/TS tool at 6778'. Acidized perfs from 6851' to 6811'. Retrieved bridge plug. Set RTTS tool at 6651'. Rigged UP and ran water injection profile logs. Checked ETD at 8428' with logging tools.' Set 7" wireline permenant production packer at . Ran 3 1/2" 9.2# N-80 Landed tubing with tail Released _.rig at 12-00 Midnite, 12/8/72. ANCHORAG~ he feb y ~ir~t h eOe ,o in~ ~./~7~ ~ eorree% VNOTE--Report on this form is required for each calendar month, regardless of the status of operations, anf must ~ filer Jo ~uplJ~t~ Division of MJ~es & ~Jnerals by the 15th of th~ succeeding month, unless othe~ise dire~ed. l"orm No. 1~---4 REV. STATE OF A[ASI<A OIL AND GAS CONSERVATION CON~ITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE ~. Alii NUI~{ERICAL ~ODE 6. LEd%SE DESIGATATION A.%-D SEq{IAL NO. ADL - 18751 T. IF INDIA]~, ALOTTEE OR THIBE NAME OIL [] GAS ~-~ OTHER WELL WELL 2.NAME OF OPERATOR Union 0il Com~anv of.California 3.ADDRESS OF OPERATO~ 909 West 9th Av~nue~ Anchorage; Alaska 99~01 4.LOCATION OF WF_J~L Conductor 29, 1617'N and 571'W from SE comer. Section 4: T9N, R13W, S. H. 8. L~'IT,FAHA{ OH LEASE NAME Tr,.tH ,~ g. WELL NO. ~ ' State A-12 10. F~ ~ND P~L. OH WILDCAT Trad~ Bay Field - He~ock* n. s~., T.. ~. ~.. f~O~{ HO~ o~ Section 4: TgN, R13W, S. M. 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MON~I, CHANGES IN HOLE SIZE, CASING AND C~'M_E~NTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFOKATIONS. TESTS AND RESULTS. FISHING JO]~. JUNK IN HO.LE AND SIDE-TRACKED HOLE AND ANY O3~IER SIGNIFICANT C'I..LA. NGES IN HOLE CONDITIONS. Commenced operations on TBS A-12 RD W. 0. at 12:01 'am~ '11/7/72. Installed BPV's in dual 5 1/2" tubing string'. ' Remove~ xmas tree, installed BOP and tested ok. Re- leased short string of tubing from dual hydraulic packer at 6738'. Pulled and laid down $ 1/2" tubing. Unable to pull long string and hydraulic packer. Cut long string tubing at 6974' below dual packer. Pulled out of hole with 5 1/2" long string tubing. Dual packer hung up at 5640'. Cut tubing at 3556'. Pulled and laid down tubing. M/lled over packer and pushed packer down hole to 6516'. Unable to get tools through damaged casing at 3640'. Ran impression block and found casin~. to be parted., at 3640' and out of alignment. Ran 5 1/2" tubing stringer in ~61e i° top dual packer at 6516'. Dumped 250' sand bridge on top of packer. Ran Howco casing ali&mment tools and set across part in casing at 5640'. Cemented damaged casing with 1750 sx class "G" cement with 5% sand and 18% salt. Final squeeze pressure - 1200 psi. Drilled out casing aliDmment tool and cement. Dressed out parted casing to 8 1/2" OD with mill. Fished remainder of tubing and dual packer out of hole. Milled over single packer at 7020' and retrieved same. Cleaned out well to ETD to 8428' Dressed out top of 7" liner and tie back reciprocal at 7261'. Installed 7" casing head ~ool. Now: Running 7" casing tie back string. OEC a Im m N oP : ic-'eEoc ...... .... ~V ~, . ~-'?~.. FILE, . Im -m - -- 14. I hereby c~i~y that the fore. in.true and ~ . ~o~~'~~'/~~~~~ m~,~-,, ~lg ~,~, ~.~ Dece~er 13, '~D-/Z==-'--~ ~' NOT~:~p;~'on~;T~'~--~quired for each calendar month, regardless of the status of operations, and must ~ filed in dupli~ ' with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. Form I~S¥. 9-30-69 Submit "Intentions" in Tripli~at~ & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to decpen Use "APPLICATION 'FOR ~'ERI~I'i'~-'' 'for such 'p~o~osal~.) . . o,,. oA- [] WELt.- WELt. OTHER 2.NAME OF OPERATOR UNION OIL G~IPANY OF CALIFORNIA 99501 3. ADDRESS OF OPERATOR 909 West 9thAvenue, Anchorage, Alaska 4. LOCATION OF WELL A,,u..tace Conductor 26, 1617'N and 571'W, from SE corn- er. Section 4' T9N, R13W, S. M. AP1 NU~CAL CODE I_,F_,ASIil DESIGNATION AND SERIAL NO. ADL- 18731 ?. IF INDIA-N, AJ_J.l)'l'r~-'w- OR TRIBE NAz~,IE 8. UNIT, F~ OR I~SE NA/VIE T~dln~ ~v ~i~ld - Hemlock O~E~VE) ~ct[on 4; TgN, "R13W, S. M, 13. ELEVATIONS (Show whether DF, RT. GR. etc. 12. PliiiiiVflT NO. ! RT to MLLW 110'. [ ,4. Check Appropriate Box To Indicate Nature of N~tice, Report, or Other Data ' NOTICE OF INTENTION TO: fRACTURE TREAT I-- MCLTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONs , Other) SUBBEQUENT REPORT OF: i I. WATER SHUT-OFF { i REPAIRINO WELL SHOOTINO OR ACIDIZINO , ; ABANDONMEIk'T* ] (Other) { (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) ,.5. O~:RCR~R£ PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. 1. Move rig over well A-12RD. 2. Install BPV, remove tree, install and test BOP's. 5. Kill well w/ weighted Inlet water if required. 4. Collapsed casing indicated at approximately 2500'5,D. 5. Cut tubing above collapse. 6. Attengt to determine extent of damage and if possible, repairw/a 7" tie back string. 7. If possible to tie back, cement 7" to surface from liner to top. 8. Run 2 5/8 ~ 2 7/8" dual tubing strings as before. 9. Remove BOP's, install tree and returnwell to injection If the repair as above is not possible, a redrill may be considered. Estimated starting date of November 3, 1972. *Texaco subthrust fault block 16. I hereby c~'~t't~ that the ~eg~ isJmue and correct ' t'/ o:un ~. ~ax~enuer (This s~ce for Stat~ omce..us~)~ ..... CONDITIONS O?'APPRO~iL, TITLE OCT 2 t. 1972 District Drlg. ~t. nA~ October / See Instructions On Reverse Side 20, 1972 DATE //~ ": ' Approved Copy - 'Returned ~/O- ~ ~,~ '~ ._~_~_:_ .. OIL CO; OF' C/-\LIIrC' -.;',IlA on,.-.,-_,-,, . WELL R2~COI','D '- ~,~. PaGE NO. I -[;,,,L,%$s__[l.'.r.~.!.di_n.~y State WEI.,L NO.A-12 Im Ji'I,~ ! ,D Trad in q__~.a_y__ LOCATION__ Conductor t~26, 1620'N & 574'W from SE corncr Section 4~ .iI.~gN~ __ R13I;'~ ,%1. PEi'iMIT NO. 67-8_8 ..... SERI.*~.~ NO. ~M)L 187'~ SPUD DATE . 1/~1~_7.2 ........ COMP. DATE ~3/3_1J.72 COi',!TIlACTOR__lV°deco RIG NO. 56 TYPE UNIT 0ilwell 860 DRILL PIPE DESCIIIPTION S" 19~S0~ HTC >al ELFA:ATIONS: WATEI~ DEYrit 62' R.T. TO OCEAN FLOOR 174' R.T. TO MLL~V 112' T.1) ..... 'd:!7~' T.V.D._~'__ R.T.~t;O DRILL DECK 22_.07~; - - :': ~ ' ' ;.': ,'~'~" Sec. S010' D~v~,vr~o,~ (~.~.L.) ,., ~07~ ,., ~ , ~.T. TO ~no~uc~r~~q~. -~o,s2~. CASING fz TUBING t~ORD ' ' ...... SIZE ~3-3/s", 9?S/S" 11 V.'EIG}iT 6117 43.5# 32# TIII'iEAD buttress· but~'s X-Line GRADE J-5S N-80 P-ilO PERFORATING RECORD DEPTH - REMARi(~ L -1~$~' Cmtd to,.surf. ----_~ 7490' DV at 2011" ~~.. ....... -. .FIG m ~zd w/100~ "G" ~t. ~--I a ~?~ ' ,, ~zd e ~en 7700-7701 7521-7522 6811-6851 6886-6926 3/17/72 19 __21____ 22 II 1! 22 6960-6980 , "' 22- 7092-7122 " 7160-7180 ., 7514-7520 ~ 24 26 7732-7740 .~' 7102-7!22 26 7715-7721 26 27 REAS_O/L_ cmt injection II II II II II INITIAL PRODUCTION 'DATE__ IHTEIiVAL N_ET OIL CUT. . ORk. V.] C.P. T.P. . · . . , ' . '. . · . WELL It~AD_A_S SE M B_L Y TYPE: CASING HEAD: 13-3/8" Shaffer ".k~" 12" Series 900 w/2'i S.E. Side Outlets CASING HANGER: Shaffer "KD" 13-3/8" x 9-g/8" hgr w/packoff ' . CASING SPOOL: 9-5/8" Cmneron (20446-12-1010)'DC-B' 1'2'".3000 psi btm flange..w/12" x 9~5/8'' seal x 10" 5000 psi top'flg, ' · -. -TUBING HEAD:__ ' TUBING HANGER:. Cmneron DC-B 10" NOM 3-1/2" Ebq2 top x 3-1/2'-' buttress 'btm ? TUBING tlEAD TOP' 10" 5000 psi MASTER VALVES:.cmner°n ~ typo F 3-1/8" . bore dual master valve w/ 2-1/16" win~_valve · CIIRISTMAS 'FREE TOP CONN.:_ 3-1/2" 8rd UI~IIk~,N UIL ~U. ur'-. MUD RECORD_ ,. PAGE NO, 2 LEASE_ Trading Bay_ State TYPE Lignosulfonate NO. A-12 RD FIELD. _. Trading Bay WELL DISTRIBUTOR Mn.~cobar _ DATE I DEPTII WEIGHT VISC. W.L. PH SALT OIL SAND SOLIDS. REbiARKS 2/2__________2. . I 1150 78~l 65 5.8 11.0 191:I - 1 - 23 1070 76.5 I 60 4.8 11.0 19,',I tr 1 14 Drld ~nt. 24 1235_ } 78I 58 5.0' 11.0 19,Xl 2 1.5 14 25 1825 ! 77 ! 53 S.0 10.5 19~1 3 1.5. 14 26 2255 ! 77 154 5.6 :LO.O 19,'.I 3 1 15 27 5221. I 76 64 5.2 1'9.5_!~.',I '3' .2 '1!i 28 394~6 I 78 I 51 5.0 10.5 19M 5 1 15 - 29 4636]j ~-~ ] ~0_ 5.0 9.5I 1951 4 1 16 3/1 5406 [ 80 'i 49 5.0 10.0[ 19M 3 1.5 16 2 572! [ 80i'50 ,5.0 I10.5[ 19M 4 J l.5 16 3 5850 180.5 i68 5.4 9.5 lgM 3 [ 3 16 5 6871 i 80 52 4.8 113.0 lgM 2 I .16 6 74391 R0 512 4.R 113.5 ]gM 12 1 . 16 7 74~0 ! 80._~ I _~7 _~_3. ~__~ ~9;,.,i 2 '~ 17 8 7-q013 { 81 60 I ~;_1'1 113_13 3RM ~. 1 16 Cmt 9 7500 80 ,1.6 524 ii 20_L 19M 1 1 15 - ' 10 7791 81 64 4.6 11.0 191,I 1 1.5 17 11 8112 81.5 51 4.2 11.0 19M 1 1 17 12 8554 81.5 53 4.6 10.5 191'..I 1 1 -17 13 8473 80 66 4.8 10.5 1Nq 1 1 17 -. .. . -- . .. _ __ i .. .~' .. · . . . __ .. _ · . . i UNION OIL CO. OF CALIFORNIA DrilliNg RECORD SHEET D ' PAGE NO LEASE Trading Bay State WELL NO. A-12 RI~iELD_' Trading Bay DATE E.T.D. 2/21/72 22 23 24 25 26 27 28 29 3/1/72 2 3 4 900'+- 1150' 1070' 1235' 1823' 2235' 3221' 3946' 4636' 5406' 5721' 5850' 6347' 6871' 7439' 7500' 7500' 7500' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS --. Began moving rig to A-'12 at-.8:00 am 2/21/72. Stopped rig over A-10 for 11 hrs to perfom wireline Work such as recover fish, close sleeves, set plug, etc. Continued move to A-12 at 7:00 pm 2/21/72. Installed riser and BOE on existing casing head. Flange up BOE. Tag top of cmt at 890'. Test pipe rams 2500 psi. Kill ~ choke 2000 psi, drill c~_t with 12-1/4" bit to 1150'. Cond mud. 'Open hole to 14" 1066' to 1150' Circ clean. Rill & hung oedp at 1145'. Mix 200 sx Class "G" cmt w/10% sand, 5% nut plug. Disp w/97 cu.ft, mud. CIP at 1'00 am. PO. Tag top at 1:00 pm at 914' CO to 1076' circ clean. Ran b~lti-Shot Gyro Survey to 1060' Made up DDrl. Orient DDrl & DDrld 1076'~1255'. Sand line parted. bDrld ~ surveyed 1235'-1330'. RI w/building set up. Drld 1330'-1572'. PO. Chng drlg assem. Drld ~ surveyed 12-1/4" hole 1572'-1823'. Drld ~ surveyed to 2235'. Drld ~ surveyed to 3221'. Drld ~ surveyed to 3946'. Drld ~ surveyed to 4636'. Dr ld & surveyed to 5406'. Drld 12-1/4" hole to 5593'. PO. Rill w/DDrl. DDrld & surveyed to 5721'. DDrld to 5747'. POll. RIH with drlg assem. & drld 12-1/4" hole to 5850'. Drld ~ surveyed 12-1/4" hole to 6347'. Drld & surveyed 12-1/4" hole to 6871'. Drld ~ surveyed 12-1/4" hole to 7439'. Drld [ surveyed 12-1/4" hole to 7500'. Circ & condition for logs. Ran Schlumberger DIL and Sonic-GR. .. Finished rng Schlumberger Sonic-GR and FDC-CNL-GR logs. Rill & circ & condition'for csg. RU & ran 181 jts 9-5/8" 43.5# N-80 & P-ll0 buttress csg w/shoe at 7490'. Float collar at 7442' and DV collar at 2011'. Cmtd thru shoe w/650 sx Class "G" cmt, 8% gel, 1% CFR-2 followed by 250 sx Class "G" cmt Premixed with 1/2 cu.ft, per sk perlite, 4'% gel, 1% CFR-2. Disp w/3065 cu.ft, mud. Bmnped plug. Float held. Approx 535 cu. ft. cmt returns. ClP 11:10 pm. (SEE 9-S/8" CASING DETAIL ATTACIIED) LEASE UNIO ,OIL CO. OF CALIFOt IA DRILLING RECORD SHEET D 4 PAGE NO.- .. Trading Bay State WELL NO. A-12 RD FIELD. Trading Bay DATE 3/10/72 11 12 13 14 16 17 18 19 2O 21 E.T.D. 7791' 8112' 8354' 8473' 8437' 7261' 8439' 8439 ' j' 8439 ' 8439' 8439' 8439' DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS Land 9-5/8" Csg & flange up. BOE. Test BO~ to 3000 psi ok. Drld Out DV and tested to 1500 psi ok. Drilled out shoe. Drld ~ surveyed to 7791'. Drld ~ surveyed 8-1/2" hole tO 8112'. D~ld & surveyed 8-1/2" hole to 8354'. Drld & surveyed 8-1/2" hole to '8473. Circ & con/[ for' logs. PO. P0J & ran Schltmtberger DIL, FDC-CNL-GR ~ P2[D logs. Finished rng HRD. Rill & circ & cond for 7" csg. RU ~ ran 39 jts 7" 32# X-Line csg w/shoe at 8468', plug catcher at 8439' and hanger at 7261' Cmtd w/200 sx Class "G" cmt premixed with 1% CFR-2. Disp w/964 cu.ft, n.~. bmtped plug. Float did not hold. CIP 6:45 pm 3/14/72. POll. 7" Liner Detail Front To , Length 8468.00 8465.63 2.37 8465.63 8439.85 25.78' 8459.85 8458.98 0.87 8458.98 7279.07 1159.01 7279.07 7260.97 18.10 ' DesCriPYi'off TIW-GUi~e Shoe 1 jt 7" 32# X-line csg. TIW plug catcher 38 its 7" 32# X-line csg. 1 TIW li~r hanger PU 5-1/2" dp. Tag top of liner' at 7261". No cmt. PO. RI w/RTrS [ set at 7190' Breakdown lap w/19 cu.ft, per min at 1500 psi. Sqz w/200 sx Class "GL cmt w/l% CFR-2. Dispw/741 cu.ft, mud to a final'press of 2500 psi. PO. RI with 8~1/2'' bit ~ csg. scraper. Tagged cmt at 7221'. Drld out. Rill with 5-7/8" bit [ 7" csg scraper and CO cmt to 8459'. Tagged ~op of hard cmtt at 8000'. RU & ran Dresser-Atlas CBL. Rill with 9-5/8" RTrS to 2350' [ tested lap to 2300 psi for 10 min. ok. RIII w/R'ITS [ set at 7490'. RU & perf four{holes at 7700'/ Brokedown'perfs w/8 cu.ft, per min. at 2500 psi. Sqzd perfs w/100 sx Class "G" w/l% CFR-2. Dispw/694 cu.ft, mud to a final press of 2825 psi. CIP 5:15 am. 3/17/72.' Reversed out. Set RTTS at 7505. RU [ ran Dresser 4 slmt gun thru dp. Could not get bel~ 7511'. PO. RD Dresser. PO. RotarTmotor shorted out. Rill with 5-7/8" bit [ 7" csg scraper. Washed out green cmt to 7535'. PO. RIIiw/RT£S [ set at 7505. Perfd four holes at 7521'. I~an~ed 2 cfm at 5000 ps5 PO. Set llowco EZ drill retainer on wireline at 7471'. RII! [ stab into. retainer.. 'rest perfs to 5000 psi for 5 min and annulus to 2500 psi for 5 min. Circwhile repairing rotarymotor; -r~z-~a~DO -~-- · . .. _.~-7~ ;zt~.. F~mshed repairing rota.~3rnmtr. Rill w/bit,' Drld out retainer [ CO to 7555'. Perforate 4 h~les at 7~2~'. emn Ilowco EZ drill retainer.on wireline, set at 7451 . Rib w/llowco stinger and brokedmmperfs w/10 cfm at 2650 psi. Sqz perfs w/100 sx Class "G" ant w/l% CFR-2 to::a final pressure of 3000 psi. Reversed 25 cu.ft, cmt. CIP 11:25 pm. PO. I%~C. RIIlw/bit. Drld retainer at 7451 and hard cmt to 7700'. CO' ant stringers to 8459'. PO. Ctmg over to 66# filtered Inlet wtr. RU [ ran Dresser-Atlas GR-CBL. Ran 9-5/ RTrs to'6785'. Perfd thru dp w/Dresser-Atlas two 1/2" l~f 6811'-6851'. Brokedo~m perfs at 2400 psi [ 4 bpm. Acidized with 800 gals. Solvent-B, 1600 gals 2-1/2% tEL, 3000 .gals nmd acid [ 1600 gals IICL. Disp at 2 bpmat 2100 psi. Injected 600 bbls filtered Inlet wtr to a finai pressure of 1900 psi. Disp filtered'Inlet wtrw/66# salt wtr. Set RITS at 6864'. Test to'1000 psi. o.. UNIC OIL CO. OF CALIFG qIA DRILLINg RECORD SHEET D PAGE NO LEASE Trading Bay State WELL NO. -Ji~12_llD_ FIELD Trading Bay DATE 3/22/72 23 24 25 26 28 29 30 31 E, T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 8459' 8439' 8439' 8459' 8459' 8459' 8428' 8428' 8428' 8428' Perfd frmn 6886'-6926'. Tested to 650.psi. Set RTrS at 6785' & acidized with 800 gals Solvent B,1600 gals-lEL, 3000 gals mud acid,& 1600 gals IEL. Disp at 2 bpm at 400 psi. Dispw/600 bt)ls filtered Inlet ~tr. Set RTTS at 6940· Perfd ~'o 1/2" lyf from 696.0'-6980'. Pressured to 550 psi with c~munication thru perfs above· -Set RTrs at 7068'. Perfd 7092'-7122'. Brokedmm perfs ~2000 psi at 2 bpm. Acidized with 800 gals Solvent B, 1600 gals 2-1/2% tEL, 3000 gals mud acid & 1600 gals 2-1/2% injecting 450 bbls filtered Inlet wtr at 2 bpm, communication started to open perfs above· Rams were'closed and displacement continued. Ran ltowco EZ drill retainer on wireline, set at 7075'. Rill and stabbed into retainer· ~iixed [ pm~ed 50 sx Class "G" cmtw/l% CFR-2. Displacedw/filtered Inlet wtr. CIP 10:45 ~n. WOC. C0 from 6974' to 6982'. I%DC to 10:30 pm. DO hard cmt to 7075'. DO retainer Firm ant to 7097' stringers to 7127' CO to top of liner · ,- · Circ hole clean. Set RTrs at 7068'. Brokedowm per~s w/2100 psi and injected 2 bpm at 2050 psi. Moved RTrS to 71~6 and tested to 2500 psi ok. Perfd B,,o 1/2" hpf from 7160'-7180'. Brokedownperfs w/ 8 cf~ at 2400 psi. Conmunicated to open perfs above. PO. RI with 5-7/8" bit [ worked thru and CO junk on top of liner..Worked free and PO to 1.d. csg scraper. RI with 5-7/8" bit on 4-3/4" DC's. Unable to get into liner without rotating. PO. RI with 8-1/2" bit,~ broke up junk on top of .liner. 'PO. RI with 5-7/8" bit ~ CO to 8428. Junk from Dresser-Atlas guns. Set RT£S at 7490' ~ tested to 2500 psi. Shot ~,o 1/2" hpf from 7514' to 7520'. Pressured to 3000 psi which dropped to 2500 psi after 5 min. Set IrFI'S at 7677' [ perfd two 1/2" hpf from 7715'-7721'. Pressured to 3000 psi. Spotted 380 gals mud .acid across perfs. Disp w/tlowco. Set RTTS at 7490'. Pumped 5 'cfm at 2500 psi~ Acidized with 300 gals Solvent B, 750 gals 2-1/2% tiCL, 1200 gals mud acid, ~ 750 gals 2-1/2%'I-~L. Disp with 600 bbls filtered inlet wtr. Moved RTTS to 7677.'2 Brokedo~m perfs from 7715' to 7721' with 11 cfm at 2700 psi. Perfd B,,o .1/2" hpf 7732-7740'. Brokedo~m perfs w/17 cfm at 27.00 psi. Acidizedwifl~ 664 gals Solvent B, 2000 gals 2-1/2% tEL, 2800 gals mud acid-and 2000 gals }EL. Disp tool [ injectedw/platform injection system.' Layed dram R/TS. Rill with 9-5/8" RTrS and set at 7057. Inject w/platform injection system until rate stabilized at 4600 B/D at 1100 psi. RU [ ~an GO-Int'l profile logs. Reset RTTS at 6508. Dresser-Atlas perfc[ 2 hpf from 7102 to 7122 m~d 7160 to 7180. RU & rm~ GO-Int'l profile logs. Rill w/5-7/8" bit & CO to 8428' RU ~ ran 9-7/8" wireline Guiberson pkr on Dresser-Atlas. Pkr stuck at 5~36. Pulled out of rope socket. Rill w/overshot, three 6-1/4" DC & BS. thashed pkr to liner top at 7621'. B3II. Overshot did not pick up pkr. RIH with 6-5/8" skirt6d overshot.. Worked over fishing neck but could not move pkr. Pulled 'setting .tool out of pkr and B3II. Rill with 8-3/8" Tri-State pkr retriever belin,- junk sub jars and BS. Milled over and retrieved pkr. Rill with 5-3/4" bit & CO to 8428. PO. RI with 8-1/2" bit & CO to 7261'. PO. RU & rmx 4.50 its 3-1/2" 9.2# N-80 buttress tbg. Long string pkr at 7037 and short string pkr at 6738. Tested long string pkr w/14 cu.ft./min at 1100 psi for 5 min ok. ~ Attempted to seat donuts in' hanger. Short string donut would not seat. Respaced short string and seated donuts in hanger. Set short string pkr. hlJ tree. Tested pkr at 6750 w/1500 psi for 5 min ok. (h)ened XO sleeve and displaced 72tt/cu.ft. salt wtr inhibited w/A-101 from 673S to surface. · ,,I~, I~:I,]'~\S],D at ]_2'00 p.m. 3/3]./72 Completed at dual lqid~le Kenai "C" _2 ~,~,~ water injection well. ./ · . -_ . %:-~. - . . . . . UNIOi~iOIL CO. OF CALIFO-{ ]iA DRILLING RECORD SHEET D 6 PAGE NO.~ LEASF, Trading Bay State WELL NO. A: 12. RD FIELD Trading. Bay DATE 2/9/72 E.T.D. DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9-5/8" CASING DETAIL Bottom' Top Len. gih Jts 7490.00 7487.92 2.08 7487,92' 7402.05 85.87 7402.05 7400.47 1.58 7400.47 7598.59 2.08 7398.59 2012.46 5585.95 2012.46 2010.31 2:15 2010.51 $9.00 1971.51 59.00 -0- 59.00 150 48 D3s~iption .... 9-5/8'"'lloWCo"~loat Shoe -9-5/8" 45:-5#'N-80 buttress csg. 9-5/8" I[owco Float Collar 9-5/8" tiowco Diff. Fill Collar 9-S/8" 45.5# N-80 buttress csg. 9-S/8" I!mqco DV mt collar 9-S/8" 45.S~ N-80-buttress csg. Elevation Landing j t 5.93' above RT. 180 Cut off 9.61'. Total .. / P. O. Box 1106 Dallas Texas 75221 Prepared For MR. Lease 'T'~ ~; I $ize CASING ---; Size LINER 7 FIRST STRING , SECOND STRING THIRD STRING TUBING PART NUMBER Size Size ~. ~ :,:_ -. %..~ .'- .,-- -! Size Company JWell No. jField jWeight , ='~ jGrade / . . I q/.::-*'~- I JWeight J Weight Grade Weight ',grade ~ r~ t ~ .. J "7 ,x Weight Grade DESCRIPTION Thread /~;-;_, .,-r ? Thread ,i'~ ,./: T" T hre od Dote .~..!-, []~'e w CompJetion [] Workover Depth Depth Depth Depth ESTIMATE Depth · . ~,: ,- -'i '::)T*,~* '.-::] ...... ,*"' i ' -- ~ j~, .,~) t.~_ ~.. "'?..; ,.;? , --/ .-, ~, , ,." -~.. :., .~.. u,~ ..... · 'F 'f'" Y.. a; ..- , ~ ..- -- ;*:~:., ~ .'~..~_% . ~. ,.., ,~ ~.~ -.~'/:,~ f-:' :,~.,,'.,,., ,~-~:.,. . ,.--,.,,., ,,, ~.:( ,, -i:-;'/- ?,, ~/,;"- ' ": '-~ '~ -,-,,- ,',.. ,, ~-; ,. .... '. - i,'r~ ~. ' :~:'r,., y,? -e "' ' ~,? .,'.,~ }?), .., ,,~: ' '"~ :;"'.'."r~ " ...... ,5-,.~. ~,o, t.l%~ ,*'~ ,~'??~*-. , '* F *" · . . ,:-.- .' ,~. _ : ,% :,~_ (~;°. ~'~'. ,-"':'::?' ,J~'~,- f; . ~'~ ~.e':~ ;; ,,;~.~.:,,-.?--'--: "~:": ::'"--' ,':."J-' i %°,, '"' :£ G'*~.tO "..*.;~.~"-*:" .-; ,", ,.:.: :.,r. .:',- ~ i · ,.','_.~-/- -. ~ ~ · . · . - ._ - -..~. .. ;- ,.... /"t- . r ' - ,i , ', TOTAL ESTIMATE Completion Procedure ./ I ~-I7 ouO Prepared By t.t .S ~(,',_.. ~_ iGuibers°n Warehouse JTelephone ID T No. .._ r'--'t' ,.<', ~ .-P e.k l ,-.- ·'r DIVISION OF DRESSER INDUSTRIES, INC. BOX 1106 e DALLAS, TEXAS 7522i ,, i Prepared For Company Date Lease Well No. . I Field I Co. or Parish State i~ [~ New Completion ' /q. ' "/% / ' r-] Workover v''r ,-'...' ...'-t..~ ~ Ct .) '( ~, Si ze Weight Grade Thread Depth CASING L/:4, .? / >g · &. ~ L-,' / Si ze Weight Grade Thread Depth LIN ER r7 t! 'e ~':"' "~" . TYPE OF TUBING FOR STRING O/'-/.'-i ,~~,.~h . L,$i ze Weight Grade j T"read' '_/?. -o .,,. ' l ...... ._, - . ?~' k.-" i ~'~' · '-.' & ') JOINTS DESCRIPTION .. FOOTAGE. .. ! FROM TO -, ~/-e,./q¢/,;,..~ a '7, b o 0 3' zoo ' v" ,-· · /~'"', ~'7 ~7..0.~.._¢.3 ~.7, fz:3 ¢.,7,.k .?,,.;. /.:¢,~,,/ ¢.,,?,,,,:¢.,.,,.,, ..;,:, .... ; . , . I _ ~ , · %: · , . .. , ',,:-- .. . · i .~ ¢~ 4.? ,¢ .¢ ,,, ' - ~ :, ,7~" ,/ ?0 /''' -': A:., "~ , ~ 6,/O ~.~ .. -, -- / .,,.; ¢~:. ,. ~.._,. ~- - -' :::"" ' '-~'?.',:'~ ~ o-'-/ /"~,, t ~ I, ~. ~ ' '.- '~'"; ':~ "' ' "*'" ''~ ';' '~' :'.-.. L,,~.~., ,,. ,_..'.; ':'~'~-: '2 ",' '"" ' .... :' ,--9 ~' '.?/... .~ '..'-,._4 x' 0 ~'J-,',",---~.. ' ~, ._. , I '"'-/'" ..',- ~o ~,.,/¢ '//.~,-, -- . .... J ':' '" ",~-f-o ~3,,f:/ X .3 '/" ! tf ~,~0 --;-'. .... ,a ~ '-~.'-'-- ?-r,'. ~:~,.,~ .... .. ~ 3,~",~/-,~o /~,¢/¢~,, 'D. TV,~,2 b7q9,79 3 ~ ,~)u~ x ~'TJ~, £vg g-~,/ ~'.oo~'~. hay .~oO~t, ql _27/,/..,,,,z-~o ?,,,.. ~-~._.t. -, ?e,.;~ .T'J-- ~Lo?, ,.'.20 ...,-',. ~t._~. 2o~,5:, 22. ~, , ,:., , -~, ,, .. , ,/ ,..,~.. 6,, ~r ~ , -'" ~ .'.' ~,ID :"'Z:'. r.:,-~,,.¢ ;, :..'. ?~ ..... ,.-.t ~-0,...,.-,-~... -.- .- ';,?/' /, " ' ' " / I,~1 7~..':;~-.- ,'3-. ~) 'S .'" , / /./ ~ .,.~ /2 .. .... . . · . , ..... ~ ...... · . ~-,~ ......*...~, ~.~.,',;-. L ............................. ~ DIVISION OF DR~]SSEI"I INDUSTRII=S. INC. BOX 1106 · DALLAS, TEXAS 75221 Prepared For Company Date Lease Well No. J Field ........ /5 / f t ~ ,~, p~ I Co. or Parish State ~ ~ . / New Completion Size ~ Weight Grade Thread Depth cAs~.o ,:/.... / - · ~.~ >,, ~ Si ~e Weight G~e Th~e~ D~pth LINER '7 ' -;~ '~'" "' ~' ! I ~ ~ ' TYPE 0F TUBING FOR STRING N0. . : ~.. , ~ · ~/,~, ,. · ~ ......... , .- ~ I~ ' r~ 7, ~ ~ 37, ~ ~ 5~ ~' ~._.~., q - ~ &;. · . :. . .~-1- ,- t~ ' ' ' ), ~ ~ f' ' ' ~,~-.{fl ~ , ~ % - ~ - . :., ~ ':~ 470 ._ . _ . ....... .~ ~ /?-6'0 (::oYt' .~.,'~,~ ,,:T, . ~' r:~~, '. ~/.. , ~,9~ .1 ~ t, - ' / , ~.. _' -'""~ .. :~ ~0 . ,.. ~,~ ,,.., ~ ~7~z ~:-~ ~. """ "' '" , , -:, , :, Z, .q~ ~-Z~l~, ~.~ C~;q;b ~7 ~ "/'z ,.~:I.~ ,; ,,, . .~ ,, .,. . ~, _ . .. f ... ..... · .. ., = _ WELL COMPL w EI. Io w ELL b. TYPE: OF COMPLETION: oven ~N n~CK R~SVR. Other 2.NAME OF OP~'RATOR Union Oil Company of California ADDRESS OF OPERATOR 909 W. 9th Ave., Anchorage, Alaska 99501 ~°0C^TZ0X OF WEnL (Re~ort Iocatio~ clear~ and in accordance wi~ a~y State requirements)* · ts~r~c, 1620'N ~ 574'W fm SE cor. Sec. 4, T9N, R13W, SM. At top prod. interval reported below At total depth 1077'N~ 4893~W of surf. loc. LONG STRING ~. API N~CAL CODE 50 - 133- 20076 -01 6. LF~E DESIGNATION A-,ND SERiAl, NO. ADL 18731 IF INDI~d~, AiJ~O/~CEE OR TRIBE NAi%LE 8. UNIT,F2~IM OR L,E, ASE NAME Trading Bay State 9. WELL NO. A-12 RD (22-4) 10. FIFJ.,D A,ND POOL, OR %¥1LDCAT ?fading Bay 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, R15W, SM. 12. PEP~IT NO. 71-29 2/22/72 3/13/72 3/31/72 RT 101' above MSL 60' above MSW · ~-~OW1VI. ANY* ROTARY TOOLS ~ABI,E TOOLS 8473', 6118' 8468', 6115' 2 8475' -- "C" Sand Top 6157', 4190' , btm 7791' , 5471' , SURVEYMADE Middle Kenai,,D,' Sand Top 7791' 5471' btm 84~5' 6090' I yes 24.TYPE ELECTRIC AND OTHER LOGS RUN DIL~ Soni¢-GR~ FIX;-CNL~ t-IRD~ £BL-GR ! CASING RE.RD (Report all strings set in well) CA. SLNG SIZE WEIGHT, LB/PT. DEPTH SET (MD, 13-3/8" 61# 1066' 9-5/8" 45.5# 7490' HOLE SIZE CEMr,,N'TING i:LEC OI%D 1200 sx "G" 650 sx "G" ! A~C)UNT PULLED none none . 26. LINE~ 7" ' 7261' { 8468' 200 ini. eCtio~ 28. PEP~FORATrONS OPF, N TO 1~ (Interval, size and number) 7092-7122 2 1/2" hpf 7102-7122 2 1/2" hpf 7160-7180 4 1/2" hpf 7514-7520 2'~/2" hpf 7715-7721 2 1/2" hpf 7732-7740 2 1/2" hpf All acidized with 2-1/2% HCL 6 mud acid i -20. PI%ODUCTION 27. TUBING SC~EEN (MD) SIZE DE?TIt SET (MD) I PACKER SET (MI)) 6749' 6738' 29. ACID, SL'OT, FiL%,C"FURE, CE~%IENT SQUEEZE, ETC. Dm~'-~T'/I IZCTEKV2~L (MD) J ANiOUNT ~D ~IND O.F MA7~'~AL US~ 7700 4 1/2".~ ~zdw/100 sx ~t 7521 4 1/2" I ~zd ~/l~sx ~t / ~;- ~OW, TUBING Ic~smG PRESS~ ICAL~T~ OI~BBL~ -- A~~.~{ [.,, WA~BBL. IO~L GRAV~Y-~I (C'O~,) } F I { · ' ~ ~ -- . ' ,, ;.-....~ . - .~ ......... 32. i, is~ o~ ATTACHMENTS 33. I hereby~ ~~ ~ce~lf/that t nd attached information Is complete and correct as determined from alUavallable records INSTRUCTIONS General: This form is designed for submitting a complete and correct weii completion reper~ end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not o,~herwise showr~) for depth measure- mentsgiven in ether spaces on this form and in any attachments. Items :20, ,,nd ]]:: If this well is completed for separate production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p:cJuci~g interval, or i.,~tervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item'S&: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item '~8: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). SUMMARY OF FORMATION TESTS INCLUDIN(; INTERVJkL TESTED, PHF_,SSUHE DATA A_N'D B. ECOVERIES OF OIL. GAS. 35. GEOLOGIC M AHI~EI~ -~. WATER AND MUD ~,~-AS. C,~T~ ~U~ V~,T. ~r~, Middle Kenai "C" ~157 ~ 4190' None },'liddle Kenai "D" 779]' 5471' -~ . . -. _. _ .. a~. co~.s DATA. AU~ACU U~Z~ ~m~i~esS o~ L~OLOGV. ~O~0~T~. ~Ac~-~. A~~' ~i~ AND ~'P~TED SHOWS OF OiL, G~' oR WA~-. None I,'m':u P - ? SUBMIT IN D .:ATE* STATE OF ALASKA iSeeotherin- S! l'l~¢t iorl.~ On reverse side: WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: On,w~.Llo [ ~-- UaSW£LL [] DiOr ~] Other water injection b. TYPE OF COMPLETION: wr.r.,.'xr:w CovzsW°nK ~ .£m,- ~]£x mxcKT"uo [] mF~.n£svR. ~] Other redrill i. N&ME OF OPERATOR Union 0il Company of C~!ifornia 3. ADDRESS OF 0PEEATOR 909 W. 9th Avenue; Anchorage. Alaska 99501_ 4. I.oc^~ox or wF. Ln (Report location clearl~-'a~ iff accordanc~ wit~ any State requirer~,t~)* At s~c, 1620'N ~ 574'W fun SE cdr. Sec. 4, TSN, R15~, At top prod. interval reported below At total depth 1077'N, 4893'W of surface location Stt0RT STRING 5. APl NUM.EH~CAL CODE 50-155-20076-01 6. T-mU&SE D~'~GNATION A..ND SERL~L NO. ADL 18751 IF INDIAN, ~%LJ~O~'rlgE OR TRIBE NAME UNIT,F.a--r~VI OR L~_.ASE NAME Trading Bay State 9. WELL NO. A-12 RD C22-4) 10. FIEI.~ A21'D POOL, OR WILDCAT Trading Bay 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, R15W, SM. 12. PEP~MIT NO. 71-29 2/22/72 { 3/13/72 I 3/31/72 ! RT 101' above MSL__. i 60' above MSW =r. I .oo,.,. 8473, 6118 / 8468. 6115 / 2 I 8473' t '-- PRODUCINGIN~RVAL(S), OF ~IS'CO~P~TIO~--T~, BOSOM, NAMg (~ AND ~)' I=. WAS DI~c-rlO'NAL Middle Kenai "C" S~d Top 6157', 4190' , b~ 7791' , 5471' ~' s'uawy~D~ "D" S~d'Top 7791' 5471' bm 8445' 6090' . yes 24. TYPE ELECTII.IC A_ND OTH~ LOGS RUN DIL, Sonic-GR, FDC-CNL-GR, t.~J3, CBL-GR , ! ~--q. CASING RECORD (Re~rt all strings set in well) C*S~NG SIZE ! WEIGh, LB/FT.~ G~DE .1 DEP~ ~T (~) 9-5/8" 4 7490.' 12-1/4' 26. LINER ~ECO~ CEIi~N'TING RECOi:~D { ~NIOUNT PULLED 1200 sx CLass "G" ! none 650 sx "G" w/8% gel, 2~0 "G" w/urlt thru shoe. 870 sx "G" ~/~rlt thru DY '-- none 27. TUBING RECOI:I,D DEPTH SET (M~D) ~ PACKER SET (1V~D) 7" 7261,' 8a68' ! 200 3-1/~." , 28. PERFORATIONS OP?A%I T (Interval, size and number) 29. ACID, St!O~. Fi%A~CTCTIRE, CF_a~E'NT SQUE~Z,~., ETC, : 6811-6851 2 1/2" hpf 6886-6926 2 1/2" hpf 6960-6980 2 1/2" hpf DISTIl 1N'TERVA.L, (MD) / A. NiOUNr A.ND KIND O'F 1VIA.TERIAL USED 6811-6851 (2,1,/,T' hp, f)')Acidized w/2-1/2% HCL 688'6-6926' [ ' ~ ~ nmd acid .,' 69'60-6980 "l " -~ iii ~. PRODUCTION DATE FIRST Pr~ODUCTION [ I:~ODUCT1.O'.N ME'II/OD (Flowit~g, gas Ii/t, pumping--size and type of pump) [WELL STATUS (Producing or - ' I snut-ln) . Ii ~ [~'] ~:, ~ I on injectzon L ;' -- '-" · t ...... z-~BBL. OIL O~riY-~I (CORR.) t o~' 82. LIST ~TT&C~M~NT8 33. I hereb~r that th ' d attached information is complete and correct as determined from all-available records smm~v.>/~.~"~L/)._ _/ ~. Dist. Drlg. Supt. DATE4/1_5/72__ /'/- d nn it. Ca'~ r~nae'r - - , *(See [ndrucfions ~nd Spaces [or Ac[c[ifionu[ Da~o on Reverse Side) INblKUL, i ILJINb General: This form is designed for submitting a complete and correct ,,~,,ei! completion report end log on all types of lanJs and leases in Alaska. item: lb: Indicate which eievation is used as reference (where not otherwise shown) for depth measure- ments given in other spaces on this form and in any at:achments. Items 20, a,d 22:: If this well is completed for separatc prcd-jction from more than one interval zone (multiple completion), so state ~n item. 20, and i.n item 22 show the ptcJucir~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interva': reported in ite,.-n 30. Submit a separate report (page) on this form, adequately identified, for each additiona! intel val to be seperately'produced, show- ing the acktitional data pertinent to such interval. Itom26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above). ' 34. SUNIMAR¥ OF FO~.MA'FI&N TF-.ST~ IN('LUDIN(~ INTEI%V~%L TESTED. PREF, SURE DATA A3~D ~COVERIES OF OII'-[ G'AS. WATER AND MUD MEAS. I~E-~TH T~RU~ VERT. b~lP~{ Middle Kenai "C" 6157' 4190' None Middle Kenai "D" 7791' 5471' , 341. COIiE DATA. A'I'I'AC!! BRIEF DESCRIPITION'S OF LITHOLOGY, POROSITY. FRACTURES. APPA.P,~E:I~'~ I~1~8 AND DETECTED .";IIOWS OF OIL.. GA.S OR WATER-] i i i iii None l- TANGENTIAL METHOD UNION OIL OF CALIF. REDRILL ~-12 WELL COMP RPT 03/28/72 PREP By SCS '~E~SURED D E V I A T I D N IOTA[ CC-CRDINATES C L 0 S U R E S ,. ; . DOG LEG SECTION ' DEPTH ANGLE DIRECTION lO0 0 ___, 150 .... 0 .... 1 200 0 1 250 0 1 __300 .......... 1.. 350 3 1 400 5 __ 45'" .......... 5..4 550 3 0 ..... 600 ............. 3 . 0 650 4 45 ?00 5 15 ....... 750 .......... 5 ..... 0 800 6 0 850 5 30 ..... 900 ........... 6 45 950 8 15 1000 10 45 ... 1030 .......... 12. 0 1060 12 45 1133 14 1 ...1163 · 16... 1194 15 ; .'12, 14 1 ?"12 ¢,r ......... 15 .... 1289 16 1374 19 3 1467 ........... 2!4,.. 3 1529 28 1629 33 D AT MD = O. O' N OE 5' S...89E .... 5~ N 81E 5' ' N 81E O~ ......... $__39E 5' S 33E O' S 46E 5~ ..~ ...... S..65E ....... ' N 89E ' N 72E ' .......... N. 52E ............... ' N 25E TVD SUB SEA LATITUDE DEPARTURE DISTANCE- ANGLE SEVERITY DISTANCE . 00, TVD = 0.00, LATITUDE = 0.00, DEPARTURE = 0.00 100. 149. 199. 249. 299. 349. 399. 449. 499. 549. 599. 649. O0 -0.99 0,00 0',00 99 ............. 48,99' O,OOS ......... 0,21E 99 98,99 O',03N 0'.43E 99 . 148,'99 O.O6N 0.64E 99 .......... 198.99. 0.61S .............. 1.1gE ......... 91 248'.91 2.995 2.74E 0.00 0.00 0.000 O.O0 ' 0.2.1_.S....~9.00E 0..500 ..... rO-2l' 0.43-N 86.00E 0.087 -0.41 · 0,65 N 84.32E 0.000 -0.62- ..1..3~__S ..... 62,'87E. _.1,80.2" .r.l,30_. 4.05 S 42.51E 4.515 -3.32 ' 72 298.72 6.01S 5.87E 46 ............. 348,46 ...............8.13S-. .......... 10,AlE 36 398..36 8.07S 13.68E 29 448.29 7,26S 16..17E 2'2 ............ 498.22 ' 5.65S ......... 18.23E._ ....... 05 548.05 1',90S 19,9'8E 8.41S 44.31E 3.946 13.21...~...52.01E .......... 15.89 S- 59'44E. 5.7~1 17.73 S 65,79E 2,485 19.,09.._~..72,76E _~2,082 20,07 S 84,55E 4.96'5 -7.03 -11.92.. -15,10 -17.35 -19..02_ -19.92, ' N 1W 698. ~ ....... N.31W ................ 748. ' N 53W 798. ' ~ 78W 8~8. , ' N 67W 947. 84 597,84 2,66N 19,gOE 615 ..........6~7,6'5 ................ 6,40N ......... 17.66E ..... 37 697.37 9.-54N . 13.48E 14 747.14 10.54N -8.80E 80 .......... 796'.80 12.06N..._.]___' .... 3.12E___ _ 28 846,28 14.86N 3.47W 20.08 'N 82.36E 4.598 -18.86 iS.78..N_._'70.O7E ' - 5.321 .... ~15..87: 16,52 N 54,70E 4.628 -11.12 13,73-N 39.84E '.5,065 -6.32 .12.46_..N___14.51E ': 2,579 -0.45. 15,27 N 13.17W 3.648 6.59i ' N 62W 996. ' ...... N. 66W ........... 1025. ' N 69W '1055. 5' N 68W 1125. 0m ......... N 75W ......... 1154. om N 83W 1184. 5' S 85W 1216. 40 895.60 19.24N 75 ............ 92q.75 ............. 21,78N O1 . 95A.01 24.15N 76 1024.76 30o88N 60 ........ 1053'60 33'02N ....... 54 1083.56 34.00N 53 1115.53 33.29N .tl.71W 22.53 N-31.32W '5.260- 15.57 1.7.41W ......... 2 7.88_.N. 38.63 W__,_4.924. .... :_.21 .. 68. 23.59W 33.76 N 44.32W 3,292 28,23 40,25W 50.73 N 52,49W 2,079 45.95- _48.24W .... 5 8,46_.._.N._55' 60 W._~.8. ,.422 ...... 54,21... 56.20W 65.69 N 58,82W -7.605 62.19 64.29W 72.40 N 62.62W" 9.440 69.95': O~ ..... N...89W ...... 1247. O' N 85W 1276. O' N 90W 1356. O' ......... N..90W .......... 1441. om N 90W 1495. om N 89W .1579. 44 ......... 1146.44 33.44N ...... ,_.72.57W ...... 27 1175.27 -34.16N 80.81W 40 1255.40 -- 34-.'16N. 109.18W 03 ........... 1340.03 34._16N 147..75W 77 1394.77 34.16N 176.86W 64 '1478.64 35.11N 231.31W · . 79. g 1._N._ .65 . 25 W_~. 87.74 N 67.08W '114.40 N 72.62W 151.65 N 76.g8W 180.13 N 79.-06W 5 233,~6 N 81-36W. J ,lin 5.279 '78._06.; 4.877 86.26 4.487 113.98: 5....336 ..... 151.64..~ 5.645 180.07'- 5.025 233,46: " ' D I R E Cm. T I. O'N A L .......... S;___U_.._R ..V._..E... Y INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB SEA DEPTH ................................... UN! ON....OIL.....OF. CAL TF._REDRTLL A-.12 ..NELL_.. MEASURED _DEPTH TVD ....... SUB SEA. TOTAL COORDINATES LAT ! TUDE ........ DEPA-RYURE__ "1'005 1001. '-~'~ 1 ! 01. _._1211 ............... 1201. 1315 1301· 1423 1401. ....... 1535 1501. 1655r 1601. 1782 17~1· ___.1919 ...... 18~1.00 ........ 1700. 2066 1901o00 1~00. 2219 2001.00 1900. ..... 2377~ .............. 2101.00 ............ 2000. 43E 2.2E 99E 76E 29E 81E 24. E 69E 60W 42W 36W 56W 51W 25W ..... 55W 63W 12W 201 201.00 100.00 O.03N O. .... 301 301.00 ..... 200.C0 ..... -0.665 1. qO1 401.00 300.00 -6.075 502 .501.00 400.00 -8.055 -13. 602 601.00 ____500.00 -5.525 ...... 18. 702 701.00 600.00 2.83N lg. 803 801.00 700.00 9.60N 13. C3 901 O0 800 O0 12 24N 2 O0 900.00 19.64N -12. 00 1000.00 28.53N -34. O0 ......... llO0.O0 ............ 33.64N .......... .60· O0 1200.00 34.16N -89. O0 1300.00 34.16N -129. OO .......... 1400.00....- ............ 34.22N ....... -180. O0 1500.00 34.84N -246. O0 1600.00 34.47N -324. 00. ~9.35N ........~418. O0 47.72N -525.-89W O0 52.25N -640.-69W O0 ........... 48.42N ...... -762.54W..i MD-TVD VERTICAL D I F F E R E_.N-CE._._CO_R.R_E_C_T_I_ON 0 0 .0 0 0 0 1 1 ] O. 2556 2201.00 2100.00 47.56N -9.10.80W 2744 2301.00 2200.00 49.63N -1071.08W ..... 2938 2401.00 ....... 2300.00 ........... 54.36N .... ~1236.26W__ '136 2501.00 2400.00 55.51N -1408.03W "---~328~ 2601.00 2500.00 58.93N -1571.36W ...... 3510 ................. 2701.00 ....... 2600.00 ............ 66.86N ..-1722.75W 3680 2801.00 2700.00 74.07N -1860.20W 3855 2901.00 2800.00 83.74N -2003.14W 4033 3001.00 ...... 2900.00 9~.75N ....... ~2~49.98W 4218~ 3101.00 3000.00 '108.4IN -2304.90W 1 2 2 4 6 !0 14 22 · .34 54 81 118.. 165 218 276 355 443 ....... 537. 635 727 809 879 954 1.032__ 11i? 0 1 2 2 4_ 8 12 20 27 47 53 58. 79 88 94_ 98 92 .82 .... 7O 75 7._8. 8.5 O I R E C.T.I'-'.'O'N INTERPOLATED VALUES A L ........... S U .R V..E..Y._ _P_AGE FOR NON SURVEY POINTS _.TANGENT_IAL._METHOD ............ UNION OIL..OE..CALIF. ..... REDRILL.A..12 .WELL MEASURED TOTAL COORDINATES _MARKER DEPTH ..... TVD .......... SUB SEA ............ LATITUDE DEPARTURE ..... 4750 3388.84 3287.84 165.73N -2749'. C2W 4883 3460. 13W 5065 .... 3558. 81W 5238 3652. 03W · 5487 3788. 97W 5855_ ..... 3992. 06W 6157 4168. 26W 6232 4216. 33W ...... 6366 ....... 4309. llW 6403 4337. 74W 6526 4430. 64W 6690 ...... 4555. 16W 6796 4635. 82W 7010 4802. 0.4W .7080 .. 4859. 60W ,7435 5151. 89W I 7510 5217. 85W : 7690 .... 5379. 7830 5507. 7910 5581. 7977 .... 5644. 8030 5693. 8087 5746. .................. 8135 8258 8362 30 3359.30 187,13N 09 ...... 3457.09 ........... 216.42N 17 3551.17 245.58N 69 3687.69. 292.24N 84 ........ 3891.84 ......... 4G1.73N 78 4067.78 505.34N 99 4115.9'9 529.62N 51 ........ 4208.51 .......... 571.53N 43 4236.43 582o55N 26 4329.26 619.18N 31] ....... 4454.31 ....... 667..35N 61 4534.61 698.76N 28 4701.28 759.51N 80 ....... 4758.80 ......... 777.63N 48 5050.48 869oqgN 85 5116.85 886o80N -2859. ._:._~3009. -3152. -3354, -3640. -3862. -3914. .... r4001. -4.022. -4094. ........ -4189. --4256° -4370. .',4405. -4585. ~4615. 97 ........... 5278.97 - 927. 29 5406.29 957. 85 5480.85 974. 30 .........5543.30 ............. 988. 69 5592.69 999. 82 5645.82 1011. .... 5792.40 ......... 5691,40 ' 1020. 5909.77 5808.77 1042. 6009.92 5908.92 1059, CTN .... ..-_4682,881~ 78N -4732.07W 41N -4755..82W 34N ..... .-4775.72W 36N -4791.4.5W 21N -4808.37W 25N .... _-. 4820,38W 52N -4849.58W 77N -4871.67W 36. ...... 5989.36 ........... 1072.35N ....... -.. . ' D I . R 'E mC T. I O'N..A L ........ S ..... U.''R'----¥':--E'--Y .................. --J~.A.GE ' 1 INTERPOLATED VALUES FOR EVEN 1000 FEET OF NEASURED DEPTH .............................. UNION_.OI.L._OF...CALIE. ....REDRILL A-12,.WELL.._COMP_..R~I_.OB/28/.72__.P.R~P..__B_Y..._SCS~__._ HEASURED TOTAL COORDIHATES I~D-TVD ._DE PTH ........ T.VD. .......... SUB ..SEA ............. LATITUDE ........ DEPARTURE .... D.I F F. ER. ENCE~ VERTICAL .C. 0 .R R E..G_T.I,O 1000 996.40 895.40 .... 20C0 1856o38~._17B5o38 3000 2433.11 2332.11 4000 2.983.31 2882.31 .... 5000 .......... 3523.17 ....... 3422.17 ..... 6000 4074.97 3973'.97 7000 4794°07 4693°07 ~ 0 Q ................ 5 6 6.5 .~,__._~ ....... 5~6~..7.~ ..... · , _ 92.35N/'-2122. 205 ..96N.._z~_..29-56 · OOW 452.23 N'~--'- 37-48.36W '~- 756.92N -4364. gTW .9..93,12N ..... .--_~7..8.2,~5.~ 3 566 1016 __14~6 1925 '2205 ,~.33~____. 3 140 423 450 460. 449 280 ! ................................................... D_ I.R E C T ! 13 N.A L ....... S_U.R..V. E..Y . INTERPOLATED VALUES FOR EVEN 100 FEET.OF SUB SEA DEPTH EAGE '2 ............................. UNION_OIL._OF_.CALIF. .... REORILL. A.12 WELL COMP.RP_!.._O3/28/72_.P_R._EE__B_Y_.._SCS .......... MEASURED _DEPTH .......................... T.VO ..... SUB S 44C5 __4592 4773 4959 5145`/ 5327 55C9 5689 :-'~-'"5869 6046 v ___ 6207 ............. 6355 6487 3201 _3301 3401 3501 3601 3701 3801 3901 4001 4101 _4201 4301 4401 6619 ................ 4501 6750 / 4601 6882 4,~01 .7oc8 ..... S ............. 4 o1 7130 4901 7252 5001 374..~__ ............... 5101 491 5201 602 5301 713 5401 823 5501 7930 ~ 5601 8038 5701 8144 5801 8249 5901 ..... 8353 6001 8456 v 6101 .00 3100. .00 ..... 320C. .00 3300. .00 3400. .00 ..... 3500. .00 3600. .00 3700. .00 ....... 3800. .00 3900. .00 4000. .00 ........ 4100. .00 4200, .00 4300. .00 ......... 4400. ,00 4500. .00 4600. .00 .......... '~700. .00 4800. .00 4900. .00 ............. 5000. .00 5100. ,00 5200, · 00 ......... 5300. .00 5400. .00 5500. .00 ......... 5600'. .00 5700. .00 5800. ..00 .... 5900. .00 6000. TOTAL COORDINATES MD-TVD VERTICAL EA ............ LATI.TUDE ..... DEPARTURE ............ D I'F FE..RE NC E]_____C 0 R R EC_TI..O.E__ . O0 12'?.73N -2462.21W 1204 87 00 .........147.I8N -2618.67W..' 1291 87 .-IA .~ G E NT_I...A L_.. HJ~TJ~ OD_ O0 169. O0 199. O0 .......... 229. O0 262. O0 296. O0 .............. 347. O0 406. O0 468. O0 ......... 521. O0 560. O0 607. O0 ......... 646. O0 685, O0 724. 00 ......... 759. O0 790, O0 822, O0 .......... 853. 00 882. O0 907. 00 ...... 932. 00 956. 00 978. O0 .......... 1000, O0 1021. O0 1040. O0 ..... 1058. O0 1074, 36N -2767.75W 1372 32N -2921.83W 1458 -35N ....... .3075.69W 1544 15N -3224.64W 1626 46N -3373.25W I708 58N __-351~.23W ...................... 1788 81 86 86. 82 82 80 74N -3650.81W -24N -3782.68W 57N __r3897.O5W 17N -3994.-51W 63N --4-071.97W 30N ...~414-7.86W 22N -4224.24W 34N' -43C1.01W llN._~369.25W ..... 60N -4431o06W ION -4492.87W 59N .... ..4554.68W 61N -4608.88W 45N -4650.23W 30N.__r4691.57W. 38N -4730.0.7W 68N -4761.9-2W 1868 1945 ................... 2006. 2054 2086 2118_ 2149 2181 ,. _2207 : 2229 225I 99N ..... ~4793.78W ............. 233.7 96N -4822.64W 2343 99N -4847.o64W 2348 36N ...... r~869.86W 2352. O1N -4889.90W 2355 80 77 61 ,' 48 32 32 31-. 32 ........ 26 22 22 22'13 ............ 22 2.290 17 2301 11 ..... 2312 1I__ 2322 10 2329 7 6 5 .... ' m . ' ' ..... ' ........................................... ~ I .R . E. C . T . I O'.'N. A 'L ............. S . .U--. R______.V.__E.__...y TANGENTIAL METHOD UNION OIL OF CALIF' REDRILL A--12 WELL cO/4P RPT. 0'3/28/72 PREP BY SCS PAGE. ...... 2_ ~ DEPTH ANGLE DIRECTION TVD SUB SEA 1786 39 O' S 90W 1703 _1911 ..... ..43 .... LO.' .... N..87W 1795 2035 46 45' N 86W 1880 2124 q9 0 _2235 ....... 49. 0 2314 49 30 2408 52 30 _.? '5 ....... 56 45 Z.~4 58 30 3030 59 0 _ 3221 ........... 60 30 3485 57 0 3703 54 0 __ 3982 55 15 4214 57 15 4575 57 45 _4745 ........ 56.15 5136 57 30 5251 56 45 _.5562 ........ 56 45 5784 56 0 5845 57 0 _6093 ........ 55_.30 '~09 50 0 ",~.,,.58 41 0 ..6638 ....... 39 45 6939 40 45 7450 34 45 .... 7791 ............ 25_45 8087 21 15 TOTAL"CO'~]RoiN~TE,~ ....... T'"['"-~'-'~"-UT"-~,'""E s oc.G · . LATITUDE DEPARTURE DISTANCE ANGLE SEVERITY DISTANCE' ': N 84W 1938 ' .......... N._gCW ............ 2011 ' S 88W 2062 ' S 88W 2120 " ..... S .... 90W .........2228 ' N 89W 2337 ' N 88W 2448 ' ........ £ 89W ......... 2542 ' N 87W 2686 ' N 87W 2814 ' ..... N 86W .............2973 ' , N 85W 3099 I e N 83W 3291 ...... UN._82W ..... 3386 ' N 79N 3596 ' N 78W 3659 ~ .......... N .77W ............. 3829 ~ N 67N 3953 ' N 67W 3987 ' ...... N 65~ ......... 4127 ' N 65W 4266.49 ' N 63W 4454.41 ' ..... N 63W ......... 4515.92 ......... ' N 63W 4743.94- ' N 63W 5163,81' 5 ...... N 59W' 5470.94 ~ N 55W 5746.82. .98 1602.98 34.47N 327,05W .40 ......... 1694.40 38'.93N ........ 412,18W ...... · 36 1-779.36 45.23N 502..28W .75 1837.75 52.25N 569..08W .57 ........... 1910.57 ............... -52.25N .......652.85W . .88 1961.88 50.16N 712.~9W ,10 2019.10 47.56N 787.4-2W 4.351 269.04 328.86 N 83.98W 3.778 326.82. 414.02_.N._ 84.60W 3.,.565 . 410.92.. 504,31' N 84,85W 3,077 500,27 571.48 N 84.75W 3.027 567.02 .654.94_._N ..85.42W. ..... .4.. 67.8 ...... 648.83_ 714.65 N 85.97W 2.C19 707.02- 788.85 N 86.54'W 3.191 779.24 ,11 ........... 2127,11 ,32 2'236,32 50.67N 1130.34W 1131.48 N 87.43W .56. 2347.56 57'.13N 1315.38W -1316.62 N 87.51W .62 ............ 2441,62 ............. 54.23N ........ 1481.59W ....... 1482..58_..N .87.90W ....... .40 2585.40 65.81N' 1702.70W 1703,97-N 87.78W .54 2713.54 75.04N 1878.82W 1880.32 N 87.71W . . .57 ............. 28'72.57 ............ 91.03N ..... 2107.-50W ....... :_..2109.47.N 87.52W ........ ............ 47.56N . 952.17W ........... 953.35..N 87..14~ ...... 2.:'10 .......... 940..14. 0.929 1114.83 0,458 1296.93 1,567 ......... 1458,63.._ 1,853 1677,06 1.376 1851.06 0.5'34 ....:._207.7.83. · 07 2998,07 .71 3190.71 .16 ............ 3285.16 .......... · 24 3495.24 .29 3558.29 · 81 ....... 3728,81 .95 38'52.95. ,18 3886.18 .65 ......... 4026.65 ....... 4165.49 4353.41 4414.92 4642.94 5062.81 53.6.~.9~. 5645.82 108.0-4N 2301.88W 2304.41 N 87.31W 0.933 2271.33 · 145.25N 2664.91W 2608.96 N 86.80W 0.487 2575.27 164.92N-. ...... 2744.89W .... '2749.84..N .... 86'.56W.__-_1.010_ . 2716.21... 227.84N 306'8.59W 3.077.04 m 85.75W. 0.717 3045.87 247o84N 3162.66~ 3172.36 N 85.51W 0.97.9 3142.04 ........... 306.34N ...... 3416.08W ......... 3429.79 N.. 84.87W__'2.0.26 8' ........ 3402.11.: 378.2-6N 3585.50W 3605.40 N 83.97W 3.764 . 3583.02 398.25N 3632.59.W 3654.36 N 83.74W 1.e39 3633.31 ! - ..484,62N ....... 3817,82W.__.3848'~46.N ..... 82,76W_ 0_,~C2 ..... 3832,78.~ 554.55N 3967.79W 4006'.35 N 82.04W 2.546 3994.26 . . 628.71N 4113.34W 4161.11 N 81.30N 3.6.59 4152.35 651.94N...4158.92W ..... .4209.71__N. 81.09N_ .....,.1.562 ....... 4201.'t3b_ 741.14N 4333.99W 4396.90 N'80.29W 0.332 4392.00' '873,.37N 4593.51W. '4675.80 N 79.23W 1.174 4673.88 ..... 94_9 . 67.N .... 4.720...49.W__ __4_. 81 ~.,._08__N__7. _8_:.62 W_~2... 703_._ 4_8 I_4.o .29._. lOll,21N 4808,37W '- 4913,55 N.78.12W 1,612 '4913.34. _ '..._' ..... '~ ................. ' ............ _ ................................. D I . R.__ E._ .C .._T. I.. 0 N_.. A...L ............. 5___U__R__.¥._E._¥_ TANGENTIAL METHOD UNION OIL OF CALIF. REDRILL A-12 WELL COMP RPT 0B/28/72 PREP BY SCS ...... -'~EAsijR-E'6'""~] E V-i'"'.~ .... ~;"! '0'"~ ................................................................. 'i:01AL COC-RDiN/tTE~-----~'-"~]'-~-"~--~]'--R E S DEPTH ANGLE DIRECTION TVD SUB" SEA LATITUDE DEPARTURE DISTANCE ANGLE 8215 18 15' N 53W 5868°38 8354 15 ~5' N 52W 6002o16 ____8.Z~ 7_3. .... ~1.~ .... 15_.*. ..... N._5. 2W. 6.1.!?~.5~. ___C.LOSURE .... 5_01_ 0_...2_~ ....... 5901.16 1058.56N 4870.12W z, 983.84 N 77.73W' 60..1.~_,.5,~, ....... 1.Q.7..~,~,._5~_.N,___4..8.9_3~_2...O._W 5_g_!O.2q N '/7-o59W , N__.7_7_-_._ 3 5 ...... W PAGE 3 . DDG LEG SECTICN sEVERITY 'DISTANCE 2.'402 494~.79 1.810 4983.82 ~,., 2,60- 5 I~1 Ill ..... ~..i ..... ~-,.- Document Transmittal Umon 0~1 Comp,"mv of (2ol~f,,.~n~;'~ I').ATt~ .~li?~k.lll'l'ED I ACCOUIHTI~JG MONTH 4/28/72 ~°~'lr. John Leverson , Division of 0il ~ Gas Harry C. Lee AT State of Alaska Southern Alaska Distric~ TRANSMITTIN6 TM~ FOLLO~ING: ~ , , 5'~ DIL~ Run 1 { 2 2" BHC-S_9oic, _Run 1 ~ 2 ...... S" BI'IC-So~ Run 1 ~ 2 2'; FDC. Run 1 m~d 2 S" FDC, RU~~Run. I. Oi rec~ ~.._S~~ ~cstem 909 %'F ~;1 9'Bt' AVENLIE,. 5i'H FLOOE FORM 369 (REV 2/70~ PRINTED IN U.S.A. 9-~-~ STATE OF AL/%SKA susMrr OIL AND GAS CONSERVATION CO~I~EE 50-133-20076-0 J J C. ENG .J~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~L 18731 I--~-~NG ~'~''' ~ o~, ~ o,.,, water inje r~ -'- ox[ ApR I 1972 raains I /,' ~ ........... ." 909 W. 9~ Ave., ' ..... Conductor 27, 1617~N Section 4, TgN, ~$~, 12. P~IT ~0. 7~-29 REPORT TOTAL DEPT~I AT END OF MONTH, CI-IA.NG~S IN HOLE SIZE, CASING A~ C~TING JOBS INCLUDING DEPTH SET ~ VOL~S US~, P~OBTIONS, ~TS ~ ~SULTS. FISHING JO~, J~K ~ HO~ ~D SIDE-~CKED HOLE ~ ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS, STATE A-12 RhI)RILL, MARC[-'[ 197_2. Continued directionally drilling 12-1/4" hole from 4656' DIL log. Sonic stopped at 5104'. PO ~ removed springs. Reran sonic, gamma ray, density SNP logs. Drld 12-1/4" hole 7450'-7500'. Ran 181 its 9-5/8" 45.5# N-80 buttress csg. Landed at 7490' Float collar at 7442' DV at 2011' Cmtd thru shoe at 7490' w/6~.0 sx 9 ' Class "G'" cmt w~8% gel ~ 1% CFR-2, followed by 250 sx "G". CIP 11:00 pm 3/9/72. Good :~ returns to surface. Installed 12" 900# x 10" 500# tbg head. Te"ste~ guF, oK. Orld DV, ~ Tested ok. Drld float collar and shoe. Drld 8-1/2" hole 7500'-8473'TD. Ran DIL, BHCS, FDC, CNL, GR ~ }.FID logs. Ran 39. j~...s.....7',. 32#. ext.r, pmeline csg. Shoe at 8466', plug '.' )rcatcher at 8437', liner hah~r at 7259'.' Cmtd w/20'0-'~'~' Class "G" cmt w/l% CFR-2. ~ CIP 7:00 pm 3/~4/72. Tagged top of lin.e,r w/~'~'~"~'"'"~1~'~'~"~""7261'. No cmt. Sqzd liner . top w/200 sx ~'G.'.L...cmt w/l% CFR-2 witl'~ RTIS at 7190'. Final pressure 2500#. Tagged cmt at'7226'"'""; ....... Drl~ out to 7261'. co mt to 8458'. Ran CBL. Tstd liner lap to 2300# with ~ 81# mud. - ........................................................ ~ -7450'. RU ~ ran Schlumberger ~. .... Set R/rS at 7490'. Perfd four holes at 7700' w/link DiCone jets. ..w/_L%-C2R~2. Sqzd to a 2825# final. Reset RTrs at 7505'. Perfd four holes at 7521'. PO. RI w/EZ drill retainer on wireline, set at 7471" Stabbed into retainer w/dp. Unable to breakdown holes w/5000#. Tstd area above retainer to 2500#, no breakdown. Assume RTrs bypass leak .~ no holes at 7521' on orig breakdown attempt. CO retainer ~ cmt to 7555'. ............................ ..p...e...r...f__fg_..u_r___h...9~9_~.__w/_qpg _gl~._.......a_.t..._..7_5._~l.;~ Run Howco EZ drill retainer on wireline, set at 7451'. Stabbed in w/~p. ,Sqzd w/75 sx "G" cmt w/l% CFR-2 to a final 5000#. .Sqzd. w/100 sx :'G', mt ..: , ... 'RIH w/bit. Drld retainer at 7451'. Hard mt to 7700', stringers to 8430'. Change over to 66# filtered Inlet wtr. Rlm Dresser-Atlas bond log, ok.. Ran 9-5/8" RTTS to 6785'. Perfd with two 1/2" hpf 6811'-6851'. Pumped 800 gals Solvent "B", 1600 gals 2-1/2% }.ICL, 3000 gals mud acid, 1600 gals 2-1/2% I.ICL. Displaced at'2 BPM at 2100#, Disp w/600 bbls filtered Inlet wtr to 1900# final press. Moved RTTS to 6864'. Set same. Test to 1000# ok. Perfd two 1/2" hpf 6886'-6926' w/R/rS at 6864', .. Zone c~mmnicated w/upper zone at STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPO'RT OF DRILLING AND WORKOVER OPERATIONS WELL 2. N~_~!J~- OF OPERATOR 3. ADDRESS OF OPERATOR 4. LOCATION OF w~ OTHER TBS A-12 RD Ccontinued) Page 2 SUBMIT I~ DUPLICATE ~.API NI/~IERICAL CODE LEASE DESiGI~ATION AND SERIAL '7. IF INDIA)~, ALOTi~:~- O1~ TRIBE NAIVE 8. L.~IT,F.Z~M OR LEASE N.M~IE 9. WELL .'N'O. 10. FIJ~) AND POOL, OR WILDCAT il. SEC., T., R., M., (BOTTOm HOLE OBJECTrV~ 1~-. PERA~IT NO. ~3. REPORT TOTAL D~l'ri AT END OF MONTH, CHANGES IN HOLE ~.z,.~, CASING A/FD CENIENTING JOBS INCLUDING DEPTH SET A1N-D VOLUMES USE'D, PERFORATIONS, TESTS AND RESULTS. FISHING JO~, J~K ~ HO~ ~D SIDE-~CK~ HOLE ~D ~Y O~ SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. 650~. Reset pkr at 6785'.. P~ed 800 gals Solvent "B"~ 1600 gals 2-1/2% HCL 3000 gals ~ud acid ~ 1600 gals 2-1/2% HCL. Disp w/filtered Inlet wtr as foll~s: ~Solv~nt "B", 2 BP~ 400 psi; 2-1/2% HCL~ 2B~ 800 psi; md acid, 2 B~ 1800 psi; 2-1/2~ IiCL~ 2B~ 2200 psi~ Press draped to 800 psi for 7 min ~en to -0- in 5-1/2 hrs. Stabilized at 700 psi.' Total displac~ent 600 bbls filtered Inlet wtr. Reset R~S at 6940'. Perid ~o 1/2" hpf 5950'-6980'. Pressured to 550 psi. Com~cated w/peris above. Re~et R~S at 7068'. Perfd two 1/2" hpf 7092'-7122'. Broked~ peris at 2000 psi at Z B~. ~ed 800 gals Solvent "B"~ 1500 gals 2-1/2% t-l~, 3000 gals ~md acid~ 600 gals 2-1/2% HCL. Injected acid at 2 B~ for 25 rain at ~ 1700~. Press dropped to 450 psi, c~icating w/upper zone. Set wireline mt f ..... ~_~07 zdf sx"G" mtwi~ i · ,,,,, .... ~~~..~ ~ 1, CFR-2 th~ retainer ~ gerfs t 7092' . _.:... ._=: ....__ _ P / / C. Rill ~/drl ass~. Fnd to of ~ '. ~ , ... . ~ p . t a} 6974 . Drld ard ~t to ~98Z . ~ld ~t retainer at 7075'. ~!d Ho~co EZ dr~ll ~ f~m mt to 7097'. ~ to top of liner. ~ R~S~ set at 7068'. Tstd sqz to 2100~ ok. Fomation brokedo~ at 2100~. Injected filtered Inlet ~tr at 2 cfm at 2050~ for ~ hrs. Reset R~$ at 7146'. Per~d mo 1/2" hp~ 7160'-7180~. Zone con~icated ~/upper peris. RIH ~i~ 5-7/8" bit ~ scraper. Drld ~m j~ at liner top~ 7260' to 7261'. Bit ~ scraper stopp~ at 7278'~ tilht. '~ 8-1/2" bit to liner top, circ cle~. Rer~ 5-7/8" bit to 8459', circ hole cle~. RI ~/R~S, set at 7490'. Perfd t~o 1/2" bpi at 7514- 7520'. Pressured to $000~ ve~ slo~ bleed o~f to 2500# over 5 ~in. Reperfd s~e 6' inte~al ~ith mo 1/2" bpi. Repressured ~ above ~i~ s~e bre~do~. Moved R~S to 76~7'. Per~d ~ 1/2" bpi frml 7715'-7721'. Tested R~S. Pressured peris to $000~+. No 'bleed off 10 ~in.+. ~lled R~S free. Spotted ~80 ~als I-~ acid across peris at 7514"-7520'. ~aited 15 min. Set R~S at 7490'. ~ed ~00 lals Solvent "B" 750 lals 2-1/2t HCL, 1200 ~als md acid, 750 ~als 2-1/2t HCL. 9isplaced ~/filterel Inlet. ~tr. Rate 1500 bbls/day at 650~ after 6 hrs. Moved R~S to 7677'. Tested holes at 7715'-7721', broked~ inte~al at 2700~ at 11 c~. Perfd ~ith mo 1/2" bpi at 7752'- 7740'. Broked~ inte~al at 2700~ at 17 c~. For~,~ No. P--4 ~zv. 9-~-e~ STATE OF ALASKA s~B~crr m D~LICATE ~. APl NUA~ERiCAL CODE OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE'PORT OF DRILLING AND WORKOVER OPERATIONS 1. ~KL~ WELL OTHER NAME OF OPERATOR 6. LEASE DESIGNATION A.~'D SEEIAL NO. ?. IF INDIA~, ALOTTEE O~ TRIBE NAME 8. L~.'IT,F.&/~{ OR L~EASE N.~AE 3. ADDRESS OF OPEI%ATOR 9. WELL NO. 4. LOCATION OF WELL 10. FIF. J~D A_ND POOL. OR WILDCAT TBS A-12 RD (continued) Page 5 11. SEC., T., R.. M., (BO~FOM HOLE om, mcTnrE) 12. PER,MIT NO. 13. REPORT TOTAL DEP/TI AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFO'P,.ATIONS, TESTS A_ND FCESULTS, FISHING JOBS, JUNK IN HOLE A.ND SIDE-TP. ACKED ROLE AND ANY OTHER SIGNIFICANT CHANG. ES IN HOLE CONDITIONS. Acidized w/664 gals Solvent "B", 2000 gals 2-1/2% }.ICL, 2800 gals mud acid ~ 2000 gals 2-1/2% ICL. Began injection at 2S00# at 2 cfm, S-1/2 hrs dropped to 1100# at 2000 BPD. Set 9-S/8" RTTS at 7057'. Injected wtr for rates ~ profiles. Moved RTTS to 6S08'. Reperfd two 1/2" hpf 7107'-7122' ~ 7160'-7180'. Inject filtered Inlet wtr for rates ~ profiles. Circ hole clean at 8428'. PO. Ran 9-S/8" permanent pkr on wireline. Stopped at S856', stuck. Ran fishing tools w/skirted overshot. Pulled setting tool out of pkr. Retrieved same. Ran mill and pkr retrieving tool. Rec pkr. CO to 8428'. Ran dual tbg strings (4S0 its 3-1/2" buttress) w/Guiberson dual pkr at 67S0 ~ single pkr at 7057'. Set ~ tstd pkrs. NU xmas tree. Tstd ok. Disp filtered Inlet wtr with 72# inhibited salt wtr above top pkr. RIG R~LEASED at 12:00 Midnight 5/,51/72. Prep to move to A-26. Completed as dual Middleq(enai "C" water injection well. 14. I hereby Dist. Drl§_ Supt_ ,:,,,.'~ 4/6/72 N port on this form is .quired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. F~ No. ~'---4 STATE OF ALASKA l~t .' 9-30-G? OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. o,~ [] cA, ~] o,uE~ water injection WELL ~ELL 2. NAME OF OPERATOR Union 0il Company of California 3.ADDRESS OF OPI/IP~TOR 909 W. 9tJ~ Ave., Anchorage, Alaska 99501 SUBA{IT IN DUPLICAT~ 4. LOCATION OF WELL Conductor 22, 1612'N ti 521'W fm St~ corner Section 4, T9N, R13W, SM. [-~;'-~L i'-c. 50-133-20076-01 ..... ('} .... t'-'.~ ~-~ ~' i'~qF~ 8. L~ ~ESiG~A~ON AND S~1~ ~.._' ~L 18731 "-?-~ ~:OL [-- 2'~SOL .... IF INDIA~ AMT~g O~ TRIBE ! _. ~_ ~ J 3 GEOL '--i ..... nr~ j Tr~ing Bay State I-'-6~AFT'"-]'--- ...................... ~.W~hL~O. .. I...S~C ..... J A-12 l'~ (1~-~) CONFER: ................ lo. ~-~ ~ ~L. o~ wm~c~' ~!LE: 11. SEC., T., R., M., (BOSOM HO~ o~~ 1~. PERMIT NO. 71-29 RF_~ORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING Alh~D CEMENTING JOBS INCLUDING DEPTH SET A.N"D VOLIYM'ES USED, PEI~OH.~,TIONS, TESTS AND R.ESULTS, FISHING JOBS, JUI~K IN HOLE A_~D SIDE-TItACKED HOLE AND A.N'Y OTHER SIGNIFICANT CH, A~I~ES IN HOI.2/I CONDITIONS. TRADING BAY STA'I~ A-12 REDRILL.~ February 1972 R_IG pOddED frm~ A-Z1RD to A-12~D at 8'00 am 2/21/72. Move over A-12. Install riser on existing 12" 5000#' csg head. Install ti t~st 12~r'3300~E. RI with 12-1/4" bit. Locate top ant in existiag 13-3/8" at 890' (shoe of 15-3/8" at 1066,). Drld out sp0,tty cmt 890'- 1150'. Under ream 12-1/4" hole'to 14" hole 1066'-1150'. l.kmg open end drill pipe at 1150'. C~t across sl~oe of 15-3/8" w/200 sx ClaSs "G" mixed w/10% sand ti 5% nut plug. CIP 1:00 am 2/23/72. WOC 12 hrs. Tagged top cmt 914'. Drld hard ant 914'-1076', KOP. DDrld 12-1/4" hole 1076'-1350', sidetracking original hole. Directionally drilled 12-1/4" hole 1530'-4656'. Now drlg. ,. 14. I hereb, certify with the Division of Mrnes & Minerals by the 15th of the succeeding month, unless othe~ise directed. ' October 29, 1971 Re: Trad/ng Bay State A-12 RD (13-4) lhicm 0tl Co~pmy of ~altfornia, Operator ~erm~c 1,~o. 71-29 Mr. ~ert T. Anderson 909 West 9th A~ ~or~e, ~amka ~$Ol referenced ~11 at a i~i~ ~ te t~ Plafo~ Well $~les ~g ~ e~ps are ~ ~ed. A ~ecti~i saucy is ~g~red. in t~ ev~ of ~si~ o~ ~~t ple~e moti~ ~is office a~q~ety ~ adv~.~ ~ that we ~ h~ a ~t~ss p.~sent. ~omer L, ~urrell Chairm~ Alaska Oil and Gas ~set~atiom Committee Fm~losure ce: Department of Fish and Oam~ w/o emcl. Robert T. Anderson District Land Manager Union Oil and Gas D~: 'on: Western Region Union Oil Company of California 909 W. 9th Avenue, Anchorage, Alaska 99501 Telephone: (907) 279-7681 union 'August 24, 1971 Division of Oil and Gas 3001.Porcupine Drive Anchor.age, Alaska 99504 I'-e: I 1 ENG ..... ..... l'"4 .... j-"5 ENG 'J .... I ~ O~OL'I'~% --1'-3' ~EOL 't~ ,'1 --,Er ...... i'~ I ~.~FTI ~;~EC I'-- CONFER: TRADING BAY FIELD CoOk'Inlet; Alaska Drilling Permit No. 69-103' State 'A-12 RD ' (13'rl 4) Attention: Homer Burrell, Chairman Conservation Committee Gentlemen: Reference is made'to the subject Drilling Permit ApplicatiOn dated July 27, 1971 approved."by the Cha'irman August 12',' 1971. Your letter of August 12,'.1971 refunded.our.'$1'OO..OO, permit fee inasmuch as our previous permit for State A-12' RD (33~4) approved October 30, 1969 does not expire until October 29,' 1971. Please be advised that it is our desire to amend the approximate date of well commencement for A-12 RD'(13-14) to December' 1,' 19'71.. In view of these circumstances we resubmit our check in the amount of.$100.00 representi.ng additional required drilli.ng permit fee. WR:jb Enclosure Very truly you?,('-') AIASg& OIL &RD CAS CONSIiltVATIOtl C~]~ iugasC 12, 1971 St:aCe A-12 RD (1'3-~) l'era/t No o - 69-103 llatim. Oil .Cempm~ ,of ,California 909 tMs'~ 9~h ~ve~e la.he-aSa,, Alas~ 99,501 Tour theme fo~ ~100..00 ie 'betaS, ~ecurnea since .the (3~4) ~ ~d ~c~ 30., 1969 ~ ~~ 29,, I971. STATE O,F ALASKA OIL AND GAS CONSERVATION ,COMMITTI .,AMENDED APPLICATION FOR PERMIT TO DRILL, DEEPEN, O iR. TYPE OF WORK DRILL J~ DEEPEN t--I b. TYPE OF WELL 8INGLE o,L [] °*' [] OT..R Water In~ector ,.o,E WELL _ WELL 2. NAME OF OPERATOR Union ()il C~;9~an~ of ~!ifornia 3. ADDRESS lYF OPERATOR 909 West 9th Avenue, And~rage, Alaska .... 99501 4. LOCATION O'F WELL A~s.r,ace Conductor 26, 1617'N ~ 571'b' fm SE ~er ~c. 4, T9N, * ' T~ "C' Z~e: 590'N ~ 3774'W {m surf. loc. 6074' ~s. D~ST~CE ~N ~S AND DmE~ON FiOM N~A~E~T TdWN O~rPOST OFF~u~r ---- ' Approx 27 :~!r miles north of Kef_n!, Alaska 14. BOND INFOR1VIATION: TYPEStatewidesu~ety,n~/orNo. B-$5372 United Pacific Insurance Co.. 15. DISTANCE FROM PROPOSED* /16. NO. OF ACRES IN LEASE LO,CATION TO NEAREST . P~OPnT~ OR LEASE LINE, ~. 600' 3,8~0 (A ~1~o to nearest drig, unit, if any) i'll'DISTANCE FROM PROPOSED LOCATION* ] 19. PROPOSED D~-P~H TO NEAREST WELL DRILLING, COMPLETED, [ ' OR APPLIED FOR, FT. 1 ,000I 8444'MD ~' 6175'WD 21. ELEVATIONS (Show whether DF, RT, GR, etc.) 101' RI' above HSL , , 23. FI~OPOSED cASING AND CEMENTING PROGRAM 50-133-20076-01 5. 6. LEASE DESIGNATION AND SIiIRIAL NO. ATII. 8. UNIT~FARM OR LEASE NA1ViE 9. WELL NO.~ " State A-12 Ifl~ C15-4) 10. I~IELD AND POOL, OR %VILDCAT M!dd}., e ,~?ai ~ Trading Bay-,;c.,* a In. SEC., T., R., ~OLE O~EOTIVE~ .gec.. 5, TgN, R13W.., SM. $100,000.00 17. NO. ACRES ASSIGN~m TO THiS WELL ~0 20. ROTARY OR CABLE TOOLS rotary 22. APPROX. DATE WORK WILL ~TART~ October 1, 1971 ', r SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRAI3E SETTING DEPTH QUANTITY OF CmMENX ~.,.[~ 'J-~5 1~66' ~xisting csg in orig well A-12 17-1/2'~ 15-3/8" " ':'" __ _ . , , ,.,, .. SEIi A T T A C !.i I:. DI¥ISION OF OiL AND OAS ANCHO~AG~ ~ ABOVE SPACE DI~CRIBE I~ROPOS~D P1ROGRA.M: If proposal is to deepen or plug back, give data on pre~ent productive zone and proposed new productive zof~e. Ii proposal is to drill or deepen direot'onally, give pertinent data on subsurface locations and measured and' true vertical depths. Give blowout preventer program. ~. I hereby certify that th_~gregping is True and Correc~ ~, ~'(This space ~r S~,e o,fi~ u., COND~NS OF ~V~, IF A~: Y~ NO ' [ u ~ [ SEE ~NSMITTAL I DI~ON~ SURVEY R~U~ [ A.P.I. ~C~ CODE , ~ ~Es u NO [ 50--133--20076--01 ~.~v~ ~.~,.0ctob-r 30. Dlstelct Land Manage ATTACI~fENT TO P-1 FORM - ]RADING BAY STATE A-12 RD (13-4) Present S...t~....t..us' Origiml ~ell A-12: 15-5/8" csg cmt @ 1066'. 12-1/4" hole to 7558'TD. Cmt plug 5225'-5072' w/100 sx Cmt plug 1150'-1045' w/125 sx Cmt plug 1013'-915' w/75 sx Well Abandoned 5/17/68. Proposed RD,.,,,Designated as Well A-lZ ~RD: Propose utilizing original wellbore to shoe of existing 15-5/8" csg for most efficient surface slot usage. Redrill KOP 1066'5D. l. . S. 6. 7. 8. 9. 10.. ll. 12. 15. hmtall 12" 3000# BOE on existing 13-5/8" csg ~ csg head. · CO existing abandonment cmt plugs to I150', (shoe .of 13-3/8" csg @ 1066'). Under-ream under shoe to 14" 6 lay sand-cmt plug CO cmt to 1070' KOP. i~,~';., C :, ..... ','-. Directionally re/trill 12-1/4" ]tole to 6900'+-. ' Run electric logs. Run & cmt 9-5/8" csg @ 6900'+-. Directionally drill 8-1/2" hole to 8444'TD. ANC~IORA(~ Run electric logs.. ;'.' Rrm ~ cmt 7" liner fr~m 6800'-8444'. Change over to filtered Inlet Wtr. Block sql.. for zone segregation top of Middle Kenai '~)" ~ top of Middle Kenai :'C'" intervals. Perforate Middle Kenai "C" zone for injection. Set production pkr @ top of "C" zone ~ run single string of 5-1/2'" tbg. Install xmas tree ~ place "C" zone on water injection. * Target LOC~_ions: ~ck-Off. Point: Shoe of orig. 15-5/8" csg - 1066'MD, i'060'TVD, 32' departure @ N66°W course. 20'N ~ 29'W fm surf. location. Top of "C"_ _Zone: .590'N I 5774'W fqa surf. location. 6074-'~,- 4150'TVD, 5815' departure @ NSI°W course. TopC-7 Sand:' 792'N ~ 4328'W fm surf. location. 6905'MD, 4750'TVD, 4597" departure @ N79eW course. Top "~Y" Zone: 922'N ~ 4685'W fm surf, location. 7842'MD, ~S80'TVD, ~:772' departure @ N78°W course. Bott~u Hole Location: 948'N ~ 4758'W fm surf. location. 8444'MD, 617~"TVD,-4850' departure @ N78oW course. 3?. ADL 18775 5 A-12RD/ PBHL -"--"- TMD 8444 TVD 6175 TO 9259 A-24 TD 9066 4. . 43 TMD 6905 * , '~ T TARGET A ~ ~o,~,o~,~ ... 5 [I /t--- '"~': /~0~o7~ ""-- .. · ~o TVD4150 A-8 ~ ~1 ~! / i - TO 74~ ...... -' ~-~'/ ~A'4 ~ 10,603 UNION TB~ ID 7~60 TD8310 UN ION-MA RATHON &DL 18731 s-3~~'~ / t T$-9 TDIO,770 T S - 5 'iD 10,3 87 ' -I ARCO I / T,-, / ' -~ /~ T~,o,~,~ /t / / ................... ...... / TDSZIT.~3~Oh, 456 TD 10,458 '~7 TS- 7 RD // ," k ~ s- ~ / / ~ TDIO,~ ~ m~ . T~ / / TD~S~ _ // ' ' -'~/S 7 ~ / TO 12,353 TD 10,014 / TEX / . TBS ~ I ' TD 10,746 ADL 17597 . ADL 18776 R ISW ,, !j}. , ~UI... 2, 9 1,9/i I ' I j ~I.VI~,~ OF OIL AND ANCHO~OB "~1~ A .-3 TO 11,637 ADL 18731 JO T ADL 17596 JJ ETB ~1 TD 10,364 UNION OIL COMPANY OF CALFORNIA ALASKA DISTRICT TRADING BAY FIELD COOK INLET, ALASKA LOCATION PLAT TRADING BAY STATE A-12RD(I3-4) DATE: JULY 20,1971 1":'2000' oas 9 N November 17, 1969 FILE Fir. Robert T. Anderson Union 0il Company of California 2805 Denali Street Anchorage, Alaska 99503 Dear Mr. Anderson: Re: Trading Bay State A-12 (33-4) Redrill, Union Oil Co. Of Calif. Operator In reference to the subject offshore drilling the following stipulations a're required to protect fish and game resources: · No material foreign to the environment will be discharged from this platform. This inc'ludas garbage, trash, refuse, petroluem and/or its products and debris. , Drilling operations are not to interfere with commercial fishing. 3. The Habitat Biologist's Office, 1018 west International Airport Road, Anchorage~ Alaska 99502 will be notified prior to abandonment of this location.. .,' Statement: The foregoing provisions do not relieve the'lessee and/or his contractOrs or assignees of any responsibilities or provisions required by law or regulation' of'the State of Alaska or the federal government. cc: B. Hilliker H. Burre11 P. Denton RJW:bb ANCH~£~BE 99~02 ,, Mr. Robert T. Anderson Union Oil Company of California 2805 Denali Street Anchorage,~Alaska 99503 November 5, 1969 Dear Mr. Anderson: Re: Trading 'Bay State A-12(33-4) Re-drillin§, Union Oil Co. of Calif., Operator In reference to the subject drilling, the folloWing stipu.lations are.prequired to protect fish and game resources: No material foreign to the environment will be discharged from this platform. This includes garbage, t'rash, refuse, petroleum and/or its products, and.debris. 2" 'Oil industry operati'ons in.this area are not to .interfere with .commercial fishing. 3. The Habitat Biologist's Office, 1018 West International Airport Road, Anchorge, Alaska 99502 will be notified on complettion of the subject drilling operation. Statement: '' The foregoing provisions do not relieve the lessee and/Or his contractors or assignees of any responsibilities or provisions required by law or. regulation of the State of Alaska or the federal government. RJW:bb cc: B. Hilliker P. Denton H. Burrell -- NOV 171969 "'"' ~ ' Kel!'h la. lull I ler ~r~ernor ALASKA OIL AND gAS CONSERVATION C~01~ITTE. E ]SOO I Pomp I ne Dr I ye O~l'ober 30~ I.q69 Pall Trading Bay Stere A-12 C3~4) Redri I I Union OII ~ny of Cai I fornla, Operator 0ear SI,r= Encl= Is the approved application far per-It to drt 1.1 the above referenced vet l:~ cia er about :November I, 1.969., free the Henoped PI. afford, ~lell sa~le~ K eere ~lla are net requlr~.. A dl.reetteaal ~u.rvey is required. heh eleetrle leg, sepia, .aK print,, fi.ted, purslmt' to AS 3t,OLO~0 ami. the .appll..elble regul'atlee&..~ shall t.m~lude tl~ .ea. ll. brat. lee file and eeehen, tce. l zena pa~ltlees of all leg traces~ both .before and after tim log run., Eaeh leg. ~lml.l ~ a'll fereat date lm~laalag {.i)'type ef fluid in tlm helea ('2) ebange$ la mud tlqm ami ad. dltlonal ~impt~., sCa. te-~,. '(4) eq~.l=t .data,, and '(.5) eqe.l~t tn the ~vent of iul~lor~ ar .8btade~, please netlfy this .offl .ce edeq~'tel¥ tn .advance se. that .,~e' may have a .vltm~s present, Very. truly Ho~r L, l~rrell bc:tosere ¢¢t lX~a-hmnt of Fish .ami ~ v/o .eric.!, .Oepartamt of" 'Labor u/o enc:l.. Union Oil and Gas I~'~'' on- Western Region Union Oil Company or' California 2805 Denali Street, Anchorage, Alaska 99503 Telephone (907) 277-1481 union October 23, 1969 Division of Oil and,Gas $001 Porcupine'Drive Anchorage,'Alaska 99504 Attention: Mr. Thomas Marshall, Jr. TRADING BAY FIELD State of Alaska A-12 Redrill Hemlock Zone Lower Fault Block Gentlemen' We resubmit a drillipg permit for the above captioned well redrawn to reflect the initial target, which does not violate spacing regulations. Very truly yours, WR: jb Enclosure Robert T. Anderson Distric~~Man. age~ RECEIVED ~J~V. 9-30-~1 STATE OF ALASKA SURMIT IN ~R[4 (Other lnstruction~ ., reverse side) OIL AND GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK ].ft. TYPE OF WORK R~ DRILL [] DEEPEN [-] PLUG BACK b, TYPE OF WELL OIL ~'~ OAE [~] 8INGLE ['] MIII.TIP,,~ [] WELL WELL OTHER ZONE ZONE 2. NAME OF OPERATOR Union Oil Company of California 3. ADDRESS Ote OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATION OF WELL Atsurface Conductor 26, 1617'N & 571'W from SE corner Sec. 4 TgN, R13W, S.M. At pro~osedprod, zone Hemlock Formation (Trading Bay Lower Fault Block) 1820'N & 1080'W from SE corner Sec. 4, 'TgN, R13W, S.M. 13. DISTANCE IN MILES AND DIRECT:ON FAOM NEAREST TOWN OR POST OFFICE* :'.:pproximately 27 air miles NW of Kenai, Ala 14. BOND INFOR/V[ATION: TYPE Statewide Surety and/or No. United Pacific 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 10 1'~. DISTANCE FROM PROPOSED LOC~TION* TO NEAREST WELL DRILLING, COMPLETED. ~ OR APPLIED FOR, FT. 21. ELEVATIONS (Show whether DF, RT. GR, etc. I RT 101' above MSL 0.00 DEPTH ;01'MD, 10,271'VD AND CEM~NG PROGRA.M ........ ~" ! ~t~,, APl .50- 1.33-2009'6-0 I ' I F OIL AND. '. CS' D~IGNA~ON ~ S~ NO~ ADL ~873~ 1. IF INDIAN, ALLO'i-r.'~a~ OR 'rl:~lBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay State 9. WELL NO. A-12 (33-4) Redrill 10. FIELD AND POOL, OR WILDCAT I rading Bay_Fi~ld~_He~lock one 'Lower ~ault Block SEC., T,, R., M., C BOTTOM HOLE OBJECTIVE) Sec. 4, T9N, R13W, S.M. ., amour $100,000.00 17. NO. ACRES ASSIGNED TO THiS WELL 40 20. ROTARY OR CABLE TOOLS Rotary APPROX, DATE WORK WILL START* November 1, 1969 SIZE OF HOLE SIZE OF S~4-z'iNO DEPTH QUANTITY OF CEMEN~ 17½" J-SS 1066' - cement to surface 12¼" .S# N-80 7000' 1650. sacks 8½" N-80 6800' 10 1000 sacks ,. Install BOE on exis,.%i""~g 13-3/8" casing and dreSs off cement plugs to 1100'. Sidetrack original well bor..~nd directionally drill 12¼" hole to 7000'_+.. 'Run electric logs. Run 9-5/8" casing..~ill 8½" directional bole'to 10,301'_+TD. Run electric logs. 'If productive,' run'rand cement 7" liner 6800' - 10,30'1', and complete as indicated from lower fault block. If non-productive, abandon and complete'from upper fault block, middle Kenai Interval thru dual 2-.7/8" testing 'strings. *Top Hemlock Lower Fault' 1820'N & 1080'W from SE corner Sec. 4, T9N, R13W, S.M. Bottom Hole Location' 1820'N & 1080'W from SE corner Sec. 4, TgN, R13W, S.M. IN ABOVE SPACE DESCRIBE I~ROPOSED I~tOGRA/~: If pr~:E~osal is to deepen or pluE back, g*ve data on present productive zone and proposed new productive z~. If proposal is to drill or deepen direet'.onally,, give pertinent data on subsurface locations and rneasur~d and true vertical depths. Give blowout preventer pro~ra.m. [ DIRECTIONAL SURVEY RE~Ull~.ED Es [] NO . 24. I hereby certify that hjk~Fo[ego_ing is True~an~ Co~.r~ect .~ . (This space fo~ State office use) CO~I~ITIONs OF APPROVAL, IF ANY: SAMPLL A~~ CORE CHIPS R3~I~1,TZ:KEO ' ../ ' [] Y~S ,~.~o SEE TRANSM I TTAL LETTER ~.P.L :N'~/ME~%ZCJtT~ CODE District Land Manage: October .30r 1969 ?z~-~., Cha i rman *See Inmuctions On Reverse Side DAT~ October 30, 1969 ADL 18775 28 `33 9 J6 UNION _~WTB .~ I TD 6528 A-I6 TD 7460 A- TD 80[5 UNION T B -it-3 TD 7260 1 ~D6627 A-15 ~ A-6 TD 7;558 A-8 A-lO A-13 A~5 I TD 7646 I I I I J UN ION -MA RATHON ADL 16731 TVD R 13W .3,3 ~TD 6509 [-4 TD 10,603 ADL 17597 . ADL 18776 ,0A-20 ARCO TBS-i+ TD 10,950 T I0 N -....~p A ..3 TO 11,637 ADL 18731 . .,,,..,~ 9 JO ADL 17596 JJ ETB ~-I TD 10,364 LOCATION PLAT TRADING BAY STATE A-12 RD (33-4) DATE: OCT 2t 1969 I"= 2000' TRADING BAY FIELD COOK INLET, ALASKA UNION OIL COMPANY OF CALFORNIA ALASKA DISTRICT CHECK LIST FOR NEW WELL PERMITS Lease & Well No. ~'/~--*- Yes No Remarks 1. Is well to be located in a defined pool ................. ~ 2 Do statewi de ru 1 es apply · u · · · · · · · · · · · · · · · · · · · · · · · · · 3. Is a registered survey plat attached .................. ~ 4. -; well located proper distance from property line ........... ~ . 5. Is well located proper distance from other wells ............ v · Is sufficient undedicated acreage available in this pool ........ ~ 111 ~ 7. Is well to be deviated ......................... v ® 9. Can pemit be approved before ten-day wait ............... 10. Does operator have a bond in force .................... ided /~ ll, Is conductor string prov ...................... 12, Ts enough cement used to circulate on conductor and surface ....... . 13. Will cement tie in surface and intermediate or production strings . , . .. 14. Will cement cover all possible productive horizons ...... . . . . 15. Will surface casing cover all fresh water zones ............ ~ .... ,. 16. Will surface csg. internal burst equal .5 psi/ft, to next string .... 17. Will all casing give adequate safety in collapse and tension ...... · 18. Does BOPE have sufficient pressure rating ............... Is operator the only affected party ................... _l/._ ,___ Additional Requirements: hl// v,~-~--~C/ 0 ~,~_uJ /o~e/,/~~_~ CHECK LIST FOR NEW WELL PERMITS -- Lease & ;.lell No. /¢~/£ ~/') 1. Is well to be located in a defined pool ................. /6~~ 2. Do statettide rules apply ........... . ............. 3. is a registered survey plat attached .................. 4. Ts t:~ell located proper distance from property line ........... ~zm~y~ 5.,:~.~ ~.~ell located p'roper distance from oti~er ¥~,ells ............ ~ 6. Is su'fficient undedicated acreage avail,able in 'this pool ........ y/~JK ~ 7~ Is well to be deviated .................. ~........ ~. ., 8 Is operator the only ai-~'..:... ..'~ r,,~rty ......... 9. Can peFmit be approved l:.efo're t'.en,-day wait ............... lO. Does operator nav.° a bond ~it force ................... 11 Is conductor stroh§ provided ........... · · · · · · · · · · i' 17. Is enough cement used to ciro~late, on conductor and surface . . . . . . .. 13' !ill'cement 'Lie in surface and intermediate or production strings . . . ,,',_..~ 14. Will cement cover all possible productive horixons ........... -'.:--? 15. Will surface casing cover all fresh water zone~ 16. Will surface cst. internal burst equai~'.5 psi/ft· to next string .... - 17. Will all casing give adequate safety in collapse and tension ...... ~ =.~ i8. Does BOPE i~ave sufficient pressure rating ............... ~ V Addi~unal Requirements Approval_Recommended: TRM__~~, o~ KLV HWK.____~k/-~__~~ LCS Jc~