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182-072
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ 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 9,455 feet 4,190 & 8,107 feet true vertical 9,124 feet N/A feet Effective Depth measured 4,157 feet 3,107 & 8,187 feet true vertical 4,134 feet 3,105 & 7,910 feet Perforation depth Measured depth 3,392 - 4,074 feet True Vertical depth 3,389 - 4,053 feet 3,137 MD 3,135 TVD Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 L-80 & 9.3 N-80 8,199 MD 7,992 TVD AS1-X Ret Pkr 3,107 (MD) 3,105 (TVD) Packers and SSSV (type, measured and true vertical depth)Baker F Pkr 8,187 (MD) 7,910 (TVD) Baker TE-5 SSSV 307 (MD) 307 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer 9-5/8" 7" 8,332 MD 625 4,232 9,455 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 5680 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 182-072 50-733-20355-00-00 Plugs ADL0018742 Granite Pt St 18742 46 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-302 98 Authorized Signature with date: Authorized Name: 0 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 233 N/A Oil-Bbl 0 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 0 Granite Point Field / Undefined Gas Pool & Middle Kenai Oil PoolN/A measured 4,139 Size 248 Production Casing Structural Liner 1,334 Length 625 4,232 Conductor Surface 7,020psi 5,600psi 20" 13-3/8" 907 777-8376 7,510psi 625 4,208 8,050 9,124 Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,130psi2,730psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,160psi Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:17 pm, Sep 03, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.09.03 11:50:18 -08'00' Dan Marlowe (1267) gls 9/17/20 RBDMS HEW 9/4/2020 DSR-9/3/2020 SFD 9/8/2020 Updated By: JLL 08/31/20 SCHEMATIC Granite Point Field Well: Granite Pt St 18742-46 Completed: 11/07/15 API: 50-703-20355-00 PTD: 182-072 PBTD =4,157’ TD =9,455’ 20” RKB: MSL =105’ 7” GS5 3 2 4 6 8 13-3/8” 9-5/8” C-4 10 C-5 C-6 C-7 C-8 8,213’ 4 Holes No Cement Bond 07/30/82 Calculated TOC 6,003’ 11 1 5 7 Tagged TOC 7,781’ Tubing cut w/ TOF@ 8,168’ Pumped 27 bbls cement into retainer Top of 9-5/8” 4,193’ Est’d. TOC 4,157’ Fish: 20’ 2-1/8” Razor Charge Perf Guns GS4A GS4 GS2 9 X On/Off CASING DETAIL Size Wt Grade Conn ID Top Btm Comments 20” 94.0 K-55 19.124” Surf 625’ 1,500 sacks Class G 13-3/8” 54.5 K-55 12.459” Surf 1575.5’ 2,555 sacks Class G68.0 K-55 12.415” 1575.5’ 2,704.4’ 72.0 L-80 12.347” 2,704.4’ 4,232.2’ 9-5/8” 43.5 S-95 8.755”4,193’ (cut)4,337.6’ 675 sacks Class G47.0 S-95 8.681” 4,337.6’ 6,225.5’ 53.5 S-95 8.535” 6,225.5’ 8,332.4’ 7”29.0 N-80 6.184” 8,121.3’ 9,272.0’305 sacks Class G29.0 S-95 6.184” 9,272.0’ 9,455’ TUBING DETAIL 3-1/2” 9.3 L-80 SuperMax 2.992 Surf 3,137’ 3-1/2” 9.3 N-80 DSS-HTC 8,168’ 8,199’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 33.25’ 33.25’ Tubing Hanger 1 307’ 307’ 2.812 5.380 SSSV – Baker TE-5 2 3,056’ 3,054’ 2.992 4.890 Chemical Injection Mandrel 3 3,104’ 3,102’ 2.812 11.880 3-1/2” T-2 On/Off Connector 4 3,107’ 3,105’ 2.992 12.000 13-3/8” AS1-X Retrievable Packer 5 3,126’ 3,124’ 2.812 4.500 3-1/2” X-Nipple 6 3,137’ 3,135’ 2.992 4.500 3-1/2” Wireline Re-Entry Guide 7 4,190’ 4,166’ CIBP w/ Cement plug 8 8,107’ 7,833’ CRET w/ Cement plug 9 8,168’ 7,891’ Top of 3-1/2” tbg 10 8,187’ 7,910’ Baker F Packer w/ locator and 10’ Seal Assembly 11 8,199’ 7,922’ Muleshoe PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Comments Date Status GS2 3,392’ 3,414’ 3,389’ 3,411’ 22 6 2-1/8” Tri Phase 11/11/15 Open GS4A 3,800’ 3,820’ 3,788’ 3,808’ 20 6 2-1/8” Tri Phase 11/12/15 Open GS4A 3,800’ 3,833’ 3,788’ 3,820’ 33’ 4 25gram 60* phasing Spiral Strip Gun 08/16/20 Open GS4 3,909’ 4,000’ 3,892’ 3,982’ 91’ 4 25gram 60* phasing Spiral Strip Gun 08/14/20 & 08/15/20 Open GS4 3,909’ 3,931’ 3,894’ 3,915’ 20 6 2-1/2” Razor Charges 11/21/15 Open GS5 4,045’ 4,067’ 4,025’ 4,047’ 20 6 2-1/2” Razor Charges 11/21/15 Open GS5 4,045’ 4,074’ 4,025’ 4,053’ 29’ 4 25gram 60* phasing Spiral Strip Gun 08/14/20 Open C-4 8,330’ 8,374’ 8,048’ 8,091’ 44' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged C-5 8,458’ 8,518’ 8,171’ 8,229’ 60' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged C-6 8,551’ 8,596’ 8,260’ 8,303’ 45' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged C-7 8,840’ 8,878’ 8,537’ 8,573’ 38' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged 8,950’ 9,017’ 8,642’ 8,706’ 67' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged 9,056’ 9,077’ 8,743’ 8,763 21' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged C-8 9,198’ 9,226’ 8,879’ 30’ 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged 9,246’ 9,296’ 8,925’ 8,972’ 50' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged 9,304’ 9,324’ 8,980’ 8,999’ 20' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged GS4 3,909’ 4,000’ 3,892’ 3,982’ 91’ 4 25gram 60 phasing Si lSti G &Open GS5 4,045’ 4,074’ 4,025’ 4,053’ 29’ 4 gpg Spiral Strip Gun 08/14/20 Open GS4A 3 800’ 3 833’ 3 788’ 3 820’ 33’ 4 25gram 60 phasing 08/16/20 Open Rig Start Date End Date SL / EL 8/13/20 8/16/20 08/13/20 - Thursday Arrive on the Anna. Get orientation and have PJSM with ops and Slickline. MIRU Slickline unit, make up 2.50" bailer, head to well, stabbed on well, PT low/high 250/1000. Op en well, swab 19, WHP 600, IA 250, OA 20. RIH, Drift down to 4100' cleanly, POOH. Tagged up, swab shut, bleed down, blow down, pop off well. Drive down bailer empty. Make up 2.80" gauge ring, head to well, stabbed on well, open up. RIH, Drift cleanly down to 3200' SLMD, (3234' RKB) with 2.80" gauge ring. POOH, RDMO. Eli ne crew arrive on Platform. Get the guys orientation and walk down of the platform done. MIRU ELU. Make up 2.5", 9', 4 spf, 25gram, 60* phasing, Spiral strip gun. Stab on well, PT WLV and lubricator 250 low/ 1500 high. Pass. Pop off well, lay down gun and lubricator. Re-head Eline, put new grease tubes in. SDFN. 08/14/20 - Friday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20355-00 182-072 Well Name Granite Pt St 18742 #46 PJSM & Permit. T/IA/OA= 500/250/20. Make up Gun #1. 2.5", 9', 4 spf, 25gram, 60* phasing, Spiral strip gun. Stab on well, Open well, RIH to 4150' ELMD. Log up to 3100'. Se nd log to town for correlation and confirmation to shoot gun #1. Make -11' correction, send back for approval. Got the approval to shoot GS5 4045'-4074' (Matthew Hunter, Brock Rust). RIH to 4100' pu to CCL depth 4059.4'. CCL to top shot 5.6', CCL to bottom shot 14.6'. Shoot GS5 formation 4065'-4074'. Log up 200', No change in tubing pressure. WHP 500, IA 250, OA 20. POOH. Got hung up at tubing tail @3137'. Work Eline up/down, made it through. CTOOH. Tagged up, swab shut, bleed down, pop off well. Spiral strip was bent up. Make up Gun #2. 2.5", 20', 4 spf, 25 gram, 60* phase, Spiral strip gun. Stab on well, open up, RIH to 4125', pu getting on depth. CCL depth 4039.4', CCL to top shot 5.6', CCL to bottom shot 25.6'. Shoot GS5 Formation 4045'-4065'. Log up 200', POOH. No change in pressures. WHP 500, IA 250, OA 20. Got few overpulls at tubing tail 3137'. Worked pa st, COOH. Tagged up, swab shut, bleed down, pop off well, break off bent strip gun, Make up Gun #3. 2.5", 21', 4 spf, 25 gram, 60* phase, Spiral strip gun. Stab on well, open well, WHP 500, IA 250, OA 20, RIH to 4125' log up to 3150', send log to Engineers for approval to shoot GS4 formation 3909'-4000'. Make -1' correction, got approval to shoot 3909'-4000' (Matthew Hunter, Brock Rust). RIH to 4125'. Pu getting on depth, CCL depth 3973.4', CCL to top shot 5.6', CCL to bottom shot 26.6' Shoot GS4 3979'-4000', log up 200', POOH. No change in WHP, WHP 500, IA 250, OA 20. At 307' (SSSV) pulled heavy, pulled out of the rope socket. Got all wire to surface, swab sh ut, bleed down, pop off well, lay down lubricator. Move Eline stuff out of the way. Get slickline unit spotted in place. Call out slickline to fish. Waiting for Slickline crew to arrive. Slickline crew on platform, PJSM, get permit started. MIRU Slickline. Slickline made up with wt bar, oil jar, spangs and 2" RB Pulling tool. RIH tag fish at 246' rkb could not latch up, POOH, put 2.70" OD skirt on 2" RB Pulling tool. RBIH, tag fish at 246' got latched up. 4th jar hit pulling tool sheared. POOH. Take off RB pulling tool. Make up 2" JD with 2.70" skirt. RIH, tag fish at 244', latched up, pu got 1 jar hit, fish started moving up hole. Pulled heavy all the way to surface. Tagged up, swab shut, bleed down, pop off well. All 39' of Eline tools recovered. RD slickline. Fly Slickline crew to beach. SDFN Shoot GS5 formation 4065'-4074'. Shoot GS5 Formation 4045'-4065'. GS4 3979'-4000', Make up Gun #1. 2.5", 9', 4 MIRU ELU. Make up 2.5", 9', 4 spf, 25gram, 60* phasing, Rig Start Date End Date SL / EL 8/13/20 8/16/20 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 50-733-20355-00 182-072 Well Name Granite Pt St 18742 #46 08/15/20 - Saturday PJSM & Permits. Test Eline wire, make up tools, pu 30' lubricator, make up Gun #4, 2.5", 20', 4 spf, 60* phase, 25 gram spiral strip gun. Stab on well. Open well, Swab 19 turns, WHP 440, IA 250, OA 20. RIH to 4125'. Using the approved log, Pick up to shot depth. CCL depth 3953.4'. CCL to top shot 5.6', CCL to bottom shot 25.6'. Shoot GS 4 formation from 3959'-3979'. We saw a slight bobble in WHP. Lo g up 200'. POOH. At surface, WHP 390, IA 250, OA 20. Make up Gun #5, 2.5", 20', 4 spf, 60* phase, 25 gram spi ral strip gun. Stab on well, Open up Swab 19 turns, RIH. WHP 380, IA 250, OA 20. RIH to 4125', PU getting on shot depth. CCL Depth 3933.4', CCL to top shot 5.6', CCL to bottom shot 25.6'. Shoot GS4 formation 3939'-3959'. Log up 200'. POOH. WHP 370, IA 250, OA 20. Tagged up, swab shut, bleed down, pop off well, lay lubricator down, break off spent spiral strip gun. Make up Gun #6. 2.5", 15', 4 spf, 60* phase, 25 gram spiral strip gun. Stab on well, RIH to 4100', log up getting on depth to CCL depth 3918.4', CCL to top shot 5.6', CCL to bottom shot 20.6'. Shoot GS4 from 3924'-3939', log up 200', POOH. WHP came up 20 psi. WHP 390, IA 250, OA 20. OOH. Break down spi ral strip. Make up Gun #7. 2.5", 15', 4 spf, 60* phase, 25 gram spiral strip gun. Stab on well. RIH to 4125'. Pu getting on depth. CCL depth 3903.4', CCL to top shot 5.6', CCL to bottom shot 20.6'. Shoot GS4 formation 3909'-3924'. Log up 200'. Drop back down and Pull log from 4040' -3100'. Send in for approval to shoot GS4A 3800'-3833'. Got Approval (Matthew Hunter, Brock Rust). POOH. Tagged up, swab shut, bleed down, pop off well. Break down Eline tool string. Re-head Eline. Test wire, good test. Make tools back up. Secure drill deck for the night. Job in progress. 08/16/20 - Sunday PJSM & Permits. T/I/O= 340/250/20. Fire up Eline unit. Test wi re. Make up Gun #8. 2.5", 20', 4spf, 60* phase 25 gram Spiral strip gun. Stab on well, Open up, RIH to 4100'. Usi ng the approved tie in log, PU getting on depth to CCL depth 3807.4'. CCL-to-top shot 5.6', CCL-to-bottom shot 25.6'. Shoot GS4A 3813'-3833', log up 200', 40 PSI increase in WHP. WHP 380/IA 250/OA 20. POOH. At surface, bleed down, pop off well, break off spent spiral strip gun. Make up Gun #9, 13', 2.5", 4 spf, 60* phase, 25 gram spiral strip gun. Stab on well, open up, RIH to 4100', PU getting on shot depth. CCL depth 3794.4', CCL to top shot 5.6', CCL to bottom shot 18.6'. Shoot GS4A 3800'-3813', Log up 200', no change in WHP. WHP 380, IA 250, OA 20. POOH. Tagged up, swab shut, bleed down, pop off well. RDMO ELU. Turn well over to production. Rig down complete, cleaned up work area secured unit on North end of platform. Fly Eline crew to land. Shoot GS4 formation 3909'-3924'. Shoot GS4A 3813'-3833', 4 formation from 3959'-3979'. Shoot GS4A 3800'-3813', Shoot GS4 formation 3939'-3959'. Log up 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6.API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): Granite Point Field / Undefined Gas Pool, Middle Kenai Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 9,455'N/A Casing Collapse Structural Conductor Surface 1,130 psi Intermediate Production 5,600 psi Liner 7,020 psi 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 Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.Oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9,124' 4,157' 4,134' 1,241 psi 1,334' 7" 8,050'9-5/8" 9,455' 9,124' Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 7/30/2020 3-1/2" Daniel E. Marlowe AS1-X Ret. Pkr / Baker F Pkr & Baker TE-5 SSSV 8,332' Perforation Depth MD (ft): 3,392 - 4,067 4,139' 3,107 (MD) 3,105 (TVD) / 8,187 (MD) 7,910 (TVD) & 307 (MD) 307 (TVD) Tubing Grade:Tubing MD (ft): 3,389 - 4,047 Perforation Depth TVD (ft): 20" 13-3/8" 625' 4,232' 625' 4,206' 625' 4,232' 9.3 L-80 & 9.3 N-80 TVD Burst 3,137 & 8,199 7,510 psi 8,160 psi Tubing Size: MD 2,730 psi 182-072 50-733-20355-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC Granite Pt St 18742 46 20 AAC 25.055 (A)(4) COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018742 Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 4,190 & 8,107 Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:30 am, Jul 17, 2020 320-302 Daniel Marlowe I am approving this document 2020.07.16 15:53:00 -08'00' Daniel Marlowe DSR-7/20/2020SFD 7/17/2020 10-404X VTL 7/23/20dts 7/23/2020 JLC 7/23/2020 Com m.23/2020 JLC 7/23/2020 RBDMS HEW 7/24/2020 Well Work Prognosis Well Name:Granite Point AN-46 API Number: 50-703-20355-00 Current Status:Gas Well Leg:Leg #3 (South corner) Estimated Start Date:7/30/2020 Rig:E-Line Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett Permit to Drill Number:182-072 First Call Engineer:Katherine O’Connor Office: 907-777-8376 Cell: 214-684-7400 Second Call Engineer:Karson Kozub Office: 907-777-8434 Cell: 907-570-1801 Current Bottom Hole Pressure:1,602 psi @ 3,615’ TVD 0.44 psi/ft SIBP Maximum Expected BHP:1,602 psi @ 3,615’ TVD 0.44 psi/ft high case for new perfs Maximum Potential Surface Pressure:1241 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)( 4) Brief Well Summary: Well AN-46 is a gas well currently open in the Grayling gas sands. Plan is to add perforations as well as perforate existing zones to increase penetration in GS1, GS4, GS4A and GS5. E-line Procedure: 1. MIRU E-line, PT lubricator to 1500 psi Hi 250 Low. 2. RU e-line guns and perforate per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Updated By: JLL 11/24/15 SCHEMATIC Granite Point Field Well: Granite Pt St 18742-46 Completed: 11/07/15 API: 50-703-20355-00 PTD: 182-072 PBTD =4,157’ TD =9,455’ 20” RKB: MSL =105’ 7” 3 2 4 6 8 13-3/8” 9-5/8” C-4 10 C-5 C-6 C-7 C-8 8,213’ 4 Holes No Cement Bond 07/30/82 Calculated TOC 6,003’ 11 1 5 7 Tagged TOC 7,781’ Tubing cut w/ TOF@ 8,168’ Pumped 27 bbls cement into retainer Top of 9-5/8” 4,193’ Est’d. TOC 4,157’ Fish: 20’ 2-1/8” Razor Charge Perf Guns 9 X On/Off CASING DETAIL Size Wt Grade Conn ID Top Btm Comments 20” 94.0 K-55 19.124” Surf 625’ 1,500 sacks Class G 13-3/8” 54.5 K-55 12.459” Surf 1575.5’ 2,555 sacks Class G68.0 K-55 12.415” 1575.5’ 2,704.4’ 72.0 L-80 12.347” 2,704.4’ 4,232.2’ 9-5/8” 43.5 S-95 8.755”4,193’ (cut)4,337.6’ 675 sacks Class G47.0 S-95 8.681” 4,337.6’ 6,225.5’ 53.5 S-95 8.535” 6,225.5’ 8,332.4’ 7”29.0 N-80 6.184” 8,121.3’ 9,272.0’305 sacks Class G29.0 S-95 6.184” 9,272.0’ 9,455’ TUBING DETAIL 3-1/2” 9.3 L-80 SuperMax 2.992 Surf 3,137’ 3-1/2” 9.3 N-80 DSS-HTC 8,168’ 8,199’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 33.25’ 33.25’ Tubing Hanger 1 307’ 307’ 2.812 5.380 SSSV – Baker TE-5 2 3,056’ 3,054’ 2.992 4.890 Chemical Injection Mandrel 3 3,104’ 3,102’ 2.812 11.880 3-1/2” T-2 On/Off Connector 4 3,107’ 3,105’ 2.992 12.000 13-3/8” AS1-X Retrievable Packer 5 3,126’ 3,124’ 2.812 4.500 3-1/2” X-Nipple 6 3,137’ 3,135’ 2.992 4.500 3-1/2” Wireline Re-Entry Guide 7 4,190’ 4,166’ CIBP w/ Cement plug 8 8,107’ 7,833’ CRET w/ Cement plug 9 8,168’ 7,891’ Top of 3-1/2” tbg 10 8,187’ 7,910’ Baker F Packer w/ locator and 10’ Seal Assembly 11 8,199’ 7,922’ Muleshoe PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Comments Date Status 3,392’ 3,414’ 3,389’ 3,411’ 22 6 2-1/8” Tri Phase 11/11/15 Open 3,800’ 3,820’ 3,788’ 3,808’ 20 6 2-1/8” Tri Phase 11/12/15 Open 3,909’ 3,931’ 3,894’ 3,915’ 20 6 2-1/2” Razor Charges 11/21/15 Open 4,045’ 4,067’ 4,025’ 4,047’ 20 6 2-1/2” Razor Charges 11/21/15 Open C-4 8,330’ 8,374’ 8,048’ 8,091’ 44' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged C-5 8,458’ 8,518’ 8,171’ 8,229’ 60' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged C-6 8,551’ 8,596’ 8,260’ 8,303’ 45' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged C-7 8,840’ 8,878’ 8,537’ 8,573’ 38' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged 8,950’ 9,017’ 8,642’ 8,706’ 67' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged 9,056’ 9,077’ 8,743’ 8,763 21' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged C-8 9,198’ 9,226’ 8,879’ 30’ 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged 9,246’ 9,296’ 8,925’ 8,972’ 50' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged 9,304’ 9,324’ 8,980’ 8,999’ 20' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged Updated By: JLL 07/14/20 PROPOSED Granite Point Field Well: Granite Pt St 18742-46 Completed: 11/07/15 API: 50-703-20355-00 PTD: 182-072 PBTD =4,157’ TD =9,455’ 20” RKB: MSL =105’ 7” GS5 3 2 4 6 8 13-3/8” 9-5/8” C-4 10 C-5 C-6 C-7 C-8 8,213’ 4 Holes No Cement Bond 07/30/82 Calculated TOC 6,003’ 11 1 5 7 Tagged TOC 7,781’ Tubing cut w/ TOF@ 8,168’ Pumped 27 bbls cement into retainer Top of 9-5/8” 4,193’ Est’d. TOC 4,157’ Fish: 20’ 2-1/8” Razor Charge Perf Guns GS4A GS4 GS2 GS1 9 X On/Off CASING DETAIL Size Wt Grade Conn ID Top Btm Comments 20” 94.0 K-55 19.124” Surf 625’ 1,500 sacks Class G 13-3/8” 54.5 K-55 12.459” Surf 1575.5’ 2,555 sacks Class G68.0 K-55 12.415” 1575.5’ 2,704.4’ 72.0 L-80 12.347” 2,704.4’ 4,232.2’ 9-5/8” 43.5 S-95 8.755”4,193’ (cut)4,337.6’ 675 sacks Class G47.0 S-95 8.681” 4,337.6’ 6,225.5’ 53.5 S-95 8.535” 6,225.5’ 8,332.4’ 7”29.0 N-80 6.184” 8,121.3’ 9,272.0’305 sacks Class G29.0 S-95 6.184” 9,272.0’ 9,455’ TUBING DETAIL 3-1/2” 9.3 L-80 SuperMax 2.992 Surf 3,137’ 3-1/2” 9.3 N-80 DSS-HTC 8,168’ 8,199’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 33.25’ 33.25’ Tubing Hanger 1 307’ 307’ 2.812 5.380 SSSV – Baker TE-5 2 3,056’ 3,054’ 2.992 4.890 Chemical Injection Mandrel 3 3,104’ 3,102’ 2.812 11.880 3-1/2” T-2 On/Off Connector 4 3,107’ 3,105’ 2.992 12.000 13-3/8” AS1-X Retrievable Packer 5 3,126’ 3,124’ 2.812 4.500 3-1/2” X-Nipple 6 3,137’ 3,135’ 2.992 4.500 3-1/2” Wireline Re-Entry Guide 7 4,190’ 4,166’ CIBP w/ Cement plug 8 8,107’ 7,833’ CRET w/ Cement plug 9 8,168’ 7,891’ Top of 3-1/2” tbg 10 8,187’ 7,910’ Baker F Packer w/ locator and 10’ Seal Assembly 11 8,199’ 7,922’ Muleshoe PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT SPF Comments Date Status GS1 ±3,272’ ±3,279’ ±3,270’ ±3,277’ FUTURE PROPOSED GS2 3,392’ 3,414’ 3,389’ 3,411’ 22 6 2-1/8” Tri Phase 11/11/15 Open GS4 ±3,414’ ±3,424’ ±3,411’ ±3,421’ FUTURE PROPOSED GS4A 3,800’ 3,820’ 3,788’ 3,808’ 20 6 2-1/8” Tri Phase 11/12/15 Open GS4A ±3,800’ ±3,833’ ±3,788’ ±3,820’ FUTURE PROPOSED GS4 ±3,908’ ±4,000’ ±3,893’ ±3,982’ FUTURE PROPOSED GS4 3,909’ 3,931’ 3,894’ 3,915’ 20 6 2-1/2” Razor Charges 11/21/15 Open GS5 4,045’ 4,067’ 4,025’ 4,047’ 20 6 2-1/2” Razor Charges 11/21/15 Open GS5 ±4,045’ ±4,074’ ±4,025’ ±4,053’ FUTURE PROPOSED C-4 8,330’ 8,374’ 8,048’ 8,091’ 44' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged C-5 8,458’ 8,518’ 8,171’ 8,229’ 60' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged C-6 8,551’ 8,596’ 8,260’ 8,303’ 45' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged C-7 8,840’ 8,878’ 8,537’ 8,573’ 38' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged 8,950’ 9,017’ 8,642’ 8,706’ 67' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged 9,056’ 9,077’ 8,743’ 8,763 21' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged C-8 9,198’ 9,226’ 8,879’ 30’ 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged 9,246’ 9,296’ 8,925’ 8,972’ 50' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged 9,304’ 9,324’ 8,980’ 8,999’ 20' 4 2-1/8” Enerjet, 0 Phase 09/28/15 Plugged • i v°62.-o72 Debra Oudean Hilcorp Alaska, LLC 2Z �� AK_GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 Hilrnrp:tlurkn.1.1.! Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATA LOGGED 5 tg/2o1G K BENDER DATE: 5/13/2016 To: AOGCC REIS' ED Makana Bender MAY 13 "-b l6 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 AOGCC DATA TRANSMITTAL GRANITE POINT AN-46 Prints RESERVOIR MONITORING TOOL PERFORATION RECORD CEMENT BOND LOG RMTI SIGMA ANALYSIS CD CBL 12/11/2015 4:18 PM File folder ft. PERF 12/11/2015 4:18 PM File folder RMT 12/11/2015 4:17 PM File folder %ate JUN 1 3 2016 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: STATE OF ALASKA ALIDKA OIL AND GAS CONSERVATION COM ION • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate Cl Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate El Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other:Perf Breakdown:1 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development L J Exploratory El 182-072 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service❑ 6.API Number: Anchorage,AK 99503 50-733-20355-00 7.Property Designation(Lease Number): 8.Well Name and Number: ; ADL0018742 Granite Pt St 18742 46 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): AN 1 5 2016 N/A Granite Point Field/Undefined Gas Pool 11.Present Well Condition Summary: iC C Total Depth measured 9,455 feet Plugs measured 4,190&8,107 feet true vertical 9,124 feet Junk measured N/A feet Effective Depth measured 4,157 feet Packer measured 3,107&8,187 feet true vertical 4,134 feet true vertical 3,105&7,910 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 625' 20" 625' 625' Surface 4,232' 13-3/8" 4,232' 4,206' 2,730 psi 1,130 psi Intermediate Production 8,332' 9-5/8" 8,332' 8,050' 7,510 psi 5,600 psi Liner 1,334' 7" 9,455' 9,124' 8,160 psi 7,020 psi Perforation depth Measured depth 3,392-4,067 feet �y True Vertical depth 3,389-4,047 feet 31 1 ! ,i"` 3 .-` F 3-1/2" 9.3#/L-80 3,137'(MD) 3,135'(TVD) Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/N-80 8,199'(MD) 7,922'(TVD) AS1-X Ret Pkr 3,107'(MD)3,105'(ND) Packers and SSSV(type,measured and true vertical depth) Baker F Pkr 8,187'(MD)7,910'(ND) SSSV 307'(MD)307'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 3,392'-4,067' Treatment descriptions including volumes used and final pressure: 30 bbls 6%KCL;final pressure 1000 psi @ 2.25 bpm.Pumped another 30 bbls 6%KCL;pressure 1000 psi @ 2 bpm.Shut down;Final pressure 519 psi 4 hours after pump job. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 10 3 Subsequent to operation: 0 0 0 18 283 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas El WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ El WAG El GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-723 Contact Trudi Hallett-(907)777-8323 Email thallettahilcoro.com Printed Name Stan W.Golis Title Operations Manager Signature ‘D'(-,,,y 1..) .= Phone (907)777-8356 Date I ' 1 s P.to i: i'/ 7.6 Form 10-404 Revised 5/2015 RBDMS LL IAN 2 1 2016 �/'//6 Submit Original Only • • Granite Point Field.14 Well: Granite Pt St 18742-46 SCHEMATIC Completed: 11/07/15 Hilcorp Alaska,LLC API: 50-703-20355-00 PTD: 182-072 RKB:MSL=105' CASING DETAIL " Size Wt Grade Conn ID Top Btm Comments I 1 20" 94.0 K-55 19.124" Surf 625' 1,500 sacks Class G 20I [ 54.5 K-55 12.459" Surf 1575.5' 13-3/8" 68.0 K-55 12.415" 1575.5' 2,704.4' 2,555 sacks Class G 2 72.0 L-80 12.347" 2,704.4' 4,232.2' 3 4 9-5/8" 43.5 S-95 8.755" 4,193' 4,337.6' 675 sacks Class G Si 5 47.0 S-95 8.681" 4,337.6' 6,225.5' Est'd.TOC. 6 53.5 S-95 8.535" 6,225.5' 8,332.4' 4,157 29.0 N-80 6.184" 8,121.3' 9,272.0' „Yrs•sem 7" 305 sacks Class G 7 29.0 S-95 6.184" 9,272.0' 9,455' 13-3/8" TUBING DETAIL Topof9-5/8" 3-1/2" 9.3 L-80 SuperMax 2.992 Surf 3,137' Fish:20' 4,193' 2 ug, 3-1/2" 9.3 N-80 DSS-HTC 8,168' 8,199' Razor JEWELRY DETAIL Charge PerfGuns Depth Depth No ID Item (MD) (TVD) 33.25' 33.25' Tubing Hanger 1 307' 307' 2.812 SSSV 2 3,056' 3,054' 2.992 Chemical Injection Mandrel 3 3,104' 3,102' _ 2.812 3-1/2"T-2 On/Off Connector Calculated 4 3,107' 3,105' 2.992 13-3/8"AS1-X Retrievable Packer TOC 6,003' 5 3,126' 3,124' 2.812 3-1/2"X-Nipple • 6 3,137' 3,135' 2.992 3-1/2"Wireline Re-Entry Guide , Tagged 7 4,190' 4,166' CIBP w/Cement plug .!,, a >4 T007,781' 8 8,107' 7,833' CRET w/Cement plug 9 8,168' 7,891' Top of 3-1/2"tbg • ...h."- ;! t ,4 10 8,187' 7,910' Baker F Packer w/locator and 10'Seal Assembly l --,--e-- 11 8,199' 7,922' Muleshoe Tubing cut ' ,:lL w/TOF@ 8,213`4 Holes 8,168' No Cement Bond 07/30/82 10 11 PERFORATION DETAIL Zone Top Btm Top Btm FT SPF Comments Date Status C-4 (MD) (MD) (TVD) (TVD) a IL 3,392' 3,414' 3,389' 3,411' 22 6 2-1/8"Tri Phase 11/11/15 Open 9-5/8" 3,800' 3,820' 3,788' 3,808' 20 6 2-1/8"Tri Phase 11/12/15 Open • 3,909' 3,931' 3,894' 3,915' 20 6 2-1/2"Razor Charges 11/21/15 Open 4,045' 4,067' 4,025' 4,047' 20 6 2-1/2"Razor Charges 11/21/15 Open ' C-5 2-1/8"Enerjet,0 C-4 8,330' 8,374' 8,048' 8,091' 44' 4 Phase 09/28/15 Plugged • Pumped 27bbls C-5 8• ,458' 8,518' 8,171' 8,229' 60' 4 2-1/8"Enerjet,0 09/28/15 Plugged cement into Phase retainerC-6 8,551' 8,596' 8,260' 8,303' 45' 4 2-1/8"Enerjet,0 09/28/15 Plugged C-6Phase 8,840' 8,878' 8,537' 8,573' 38' 4 2-1/8"Enerjet,0 09/28/15 Plugged Phase C-7 8,950' 9,017' 8,642' 8,706' 67' 4 2-1/8"Enerjet,0 09/28/15 Plugged ath-.ri Phase F. C-7 9,056' 9,077' 8,743' 8,763 21' 4 2-1/8"Enerjet,0 09/28/15 Plugged Phase 2-1/8"Enerjet,0 9,198' 9,226' 8,879' 30' 4 phase 09/28/15 Plugged T r C$ 2-1/8"Enerjet,0 • 4 . C-8 9,246' 9,296' 8,925' 8,972' 50' 4 Phase 09/28/15 Plugged PBTD=4,157' TD=9,455' 9,304' 9,324' 8,980' 8,999' 20' 4 2-1/8"Enerjet,0 09/28/15 Plugged Phase Updated By:JLL 11/24/15 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Granite Pt St 18742 #46 Pumping 50-733-20355-00 182-072 12/20/15 12/20/15 Daily Operations: 12/20/2015 -Sunday R/u CMT pump, mixed 30 bbls 6%KCL, filled hole 10 bbls, PT linest/4500 psi good, pumped 8 bbls pressuring up t/ 1000psi started injecting, finish pumping 30 bbls, s/d pressure 900 psi, mix 30 bbls 6%KCL, 15 min psi drop t/840 PSI, pumped 12 bbls @ 2.25BPM 1000 psi, s/d 900psi, repair psi gauge, 20 min pressure drop t/800 psi,Pump 5 bbls @ .5 bpm 800 psi, 5 bbls @ 1 BPM 900 psi, 5bbls@ 1.5 BPM 950 psi, 5 bbls @ 2 BPM 1000 psi, s/d pressure 900 psi monitor f/45 min psi drop t/720psi, flush & r/d cmt pumping eq. install gauge cont. monitor& log pressure every 30 min, @ 519psi shut in f/4 hrs. • L OF Ty �i"-1�y,�s, THE STATE Alaska Oil and Gas 6 ,;--i.t7 of TKA Conservation Commission iki• _ ___ ALAS tats _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *" Main: 907.279.1433 oFALAJ a r�> ; Fax: 907.276.7542 OotE `-c.G 0 9 . E www.aogcc.alaska.gov Stan W. Golis Operations Manager V X-- 0 ')— Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Granite Point Field, Undefined Gas Pool, Granite Pt St 18742 46 Sundry Number: 315-723 Dear Mr. Golis: 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 '. Foerster Chair DATED this "ay of December, 2015 Encl. RBDMS 1�p 'EC 17 2015 • • RECEIVED STATE OF ALASKA NOV 3 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS /2I j 4115 20 AAC 25.280 ' 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Perf Breakdown I]• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number Hilcorp Alaska, LLC Exploratory ❑ Development IM 182-072 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99503 50-733-20355-00 • 7. If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? N/A Anr.... if Will planned perforations require a spacing exception? Yes ❑ No El Granite Pt St 18742 46 • 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0018742 ' Granite Point Field/Undefined Gas Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,455 - 9,124 , 4,157- 4,134 • 3,500 psi • 4,190&8,107 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 625' 20" 625' 625' Surface 4,232' 13-3/8" 4,232' 4,206' 2,730 psi 1,130 psi Intermediate Production 8,332' 9-5/8" 8,332' 8,050' 7,510 psi 5,600 psi Liner 1,334' 7" 9,455' 9,124' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3,392-9,324 3,389-8,999 3-1/2" 9.3#L-80&9.3#/N-80 3,137&8,199 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): AS1-X Ret Pkr, Baker F Pkr&SSSV 3,107'(MD)3,105'(TVD),8,187'(MD)7,910'(TVD)&307'(MD)307'(TVD) 12.Attachments: Proposal Summary U Wellbore schematic D 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 2 •• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/15/2015 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS U . WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Trudi Hallett(907)777-8323 Email thallett(aahilcorp.com Printed Name Stan W.Golis Title Operations Manager eit Signature • Phone (907)777-8356 Date 11/30/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 36'1 2... Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes U No ❑ Spacing Exception Required? Yes ❑ No L✓J Subsequent Form Required: /0 •-LI 0 y RBDMS';";! C 1 7 2015 f APPROVED BY Approved by: Y LOp COMMISSIONER THE COMMISSION Date: �Z _� �J s 1,14231,14231,1423 1a1/S ,,r 114 5/../iSubmiForm ane Form 10-403 Revised 11/2015rR v 1'CI 1 id for 12 months from the date of approval. Attachments in Duplicate • • Well Work Prognosis Well: AN 46 Hilwrp Alaeka,Iii Date: 11/30/2015 Well Name: AN-46 (Granite Point API Number: 50-733-20355-00 State 18742-46) Current Status: SI Producer Leg: Leg#3 (South) Estimated Start Date: December 15, 2015 Rig: N/A Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 182-072 First Call Engineer: Trudi Hallett Office: 907-777-8323 Cell: 907-301-6657 Second Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Current BHP: 1560 psi @ 3220'TVD Max. Expected BHP: 1560 psi @ 3220' TVD Max. Potential Surface Pressure(MPSP): 3,500 psi treatment pump pressure limit Brief Well Summary Well An-46 is a shut-in gas producer completed in the Undefined Gas Pool in Granite Point Field. This well has been perforated and penetration to the reservoir is suspect. The purpose of the proposed well work is to try and break down the perfs to establish connectivity to the reservoir most recently perforated. Hilcorp plans to fill the remainder of the wellbore with 6% KCI and then bullhead an add'I 40 bbls of KCI fluid down to push out into the perforations. Procedure 1. MIRU pumping equipment. 2. Pressure test surface lines to 3,500 psi. 3. Mix 6% KCL and pump in the following sequence: a. Pump ± 20 bbls 6% KCI down tubing to fill wellbore. b. Pump 6% KCL @ ±1 bpm to push into formation (±40 bbls). 4. Shut down pump. 5. RD Pumping equipment. 6. Return well to production. Attachments: 1. As-built Schematic 2. Flow Diagram im • • Granite Point Field Well: Granite Pt St 18742-46 SCHEMATIC Completed: 11/07/15 Mean)Alaska,LLC API: 50-703-20355-00 PTD: 182-072 RKB:MSL=105' CASING DETAIL ISize Wt Grade Conn ID Top Btm Comments 1 20" 94.0 K-55 19.124" Surf625' 1,500 sacks Class G 20"i [ 54.5 K-55 12.459" Surf 1575.5' 13-3/8" 68.0 K-55 12.415" 1575.5' 2,704.4' 2,555 sacks Class G 2 72.0 L-80 12.347" 2,704.4' 4,232.2' 3 1 III 4 9-5/8" 43.5 S-95 8.755" 4,193' 4,337.6' 675 sacks Class G all 5 47.0 5-95 8.681" 4,337.6' 6,225.5' Est'd.TOC. 6 53.5 5-95 8.535" 6,225.5' 8,332.4' 4,157 * 00. 1/4---). - 29.0 N-80 6.184" 8,121.3' 9,272.0' 7 29.0 5-95 6.184" 9,272.0' 9,455' 305 sacks Class G 13-3/8" TUBING DETAIL Topof9-5/8" 3-1/2" 9.3 L-80 SuperMax 2.992 Surf 3,137' Fish:20 4,193' 3-1/2" 9.3 N-80 DSS-HTC 8,168' 8,199' 2-118" Razor JEWELRY DETAIL Charge PerfGuns Depth Depth No (MD) (TVD) ID Item 33.25' 33.25' Tubing Hanger 1 307' 307' 2.812 SSSV 2 3,056' 3,054' 2.992 Chemical Injection Mandrel 3 3,104' 3,102' 2.812 3-1/2"T-2 On/Off Connector Calculated 4 3,107' 3,105' 2.992 13-3/8"A51-X Retrievable Packer TOC 6,003' ! 1 5 3,126' 3,124' 2.812 3-1/2"X-Nipple 6 3,137' 3,135' 2.992 3-1/2"Wireline Re-Entry Guide 't"VA Tagged 7 4,190' 4,166' CIBP w/Cement plug 4 gfri .' ,, ,,`*1'± TOC7,781' 8 8,107' 7,833' CRET w/Cement plug • +�`''+:,�. '; 9 8,168' 7,891' Top of 3-1/2"tbg 1 We *; _ " ' 10 8,187' 7,910' Baker F Packer w/locator and 10'Seal Assembly -0.,L8 11 8,199' 7,922' Muleshoe °,i .. ,( '-, Tubingcut ' R , w/TOF@ ,„!Y.;'. 8,213'4Holes No cement 8,168 % 0 a,Bond 07/30/82 11`.4. 11141 PERFORATION DETAIL Top Btm Top Btm ?AI, "" Zone FT SPF Comments Date Status ' iujl/ ' ' C-4a 14:'4-* i (MD) (MD) (ND) (ND) tt r - 3,392' 3,414' 3,389' 3,411' 22 6 2-1/8"Tri Phase 11/11/15 Open 9-5/8" 7,/. ^-k' 3,800' 3,820' 3,788' 3,808' 20 6 2-1/8"Tri Phase 11/12/15 Open •`A� 3,909' 3,931' 3,894' 3,915' 20 6 2-1/2"Razor Charges 11/21/15 Open r •j , 4,045' 4,067' 4,025' 4,047' 20 6 2-1/2"Razor Charges 11/21/15 Open 4! ,'"%1 C-5 2-1/8"Enerjet,0 V,C... C-4 8,330' 8,374' 8,048' 8,091' 44' 4 Phase 09/28/15 Plugged ` s ' :4 Pu 27bl s 'r'• 2-1/8"Enerjet,0 Pumped K C-5 8,458' 8,518' 8,171' 8,229' 60' 4 Phase 09/28/15 Plugged cement into ux wt,L- retainer 9� 1' 4 2-1/8"Enerjet,0 opt..: _ C-6C-6 8,551' 8,596' 8,260 8,303' 45' phase 09/28/15 Plugged '+",/ #�r t,; 2-1/8"Enerjet,0 f 8,840' 8,878' 8,537' 8,573' 38' 4 phase 09/28/15 Plugged 14{ 2-1/8"Enerjet,0 '� {da' C-7 8,950' 9,01T 8,642' 8,706' 67' 4 phase 09/28/15 Plugged ,0 •,t{; ''n . k 9,056' 9,07T 8,74T 8,763 21' 4 phase 09/28/15 Plugged nc? 9,198' 9,226' 8,879' 30' 4 2-1/8"Enerjet,0 09/28/15 Plugged C., Phase r G8 2-1/8"Enerjet,0 C-8 9,246' 9,296' 8,925' 8,972' 50' 4 09/28/15 Plugged ♦ Phase PBTD=4,157 TD=9,455' 9,304' 9,324' 8,980' 8,999' 20' 4 2-1/8"Enerjet,0 09/28/15 Plugged Phase Updated By:JLL 11/24/15 o S S m m m m z n m 0 Z 0 2 A Cl C'yy X X fig A tn 4001 1111111!! ! 11111 - 0 ma Z F m 171 rA - o or, O Z 2Q cy O 5 6 a) c Lo 0 0 N N O O y .. 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(V 44llfjgR N N ti m/// (0 )- • vi N N N W a •i.• .4�i/M \ 1111111111111111111141 ! m f " W N 1-J I Z N Ocp a O CL a_ CO 0 W m m a a 0 I I Q \\ % A H �� m m N 1 J A O r N (h J Q o rx '• a Z \i Z o co N 0 a • ,n •N, Aa COC N z N m O m CO Cl N N a a Z r- co cc � / a Z N a a N a a Z M FD ii r)mM CL to qt' o0 z c? (a0) a a Z Q aNo ZU a s i CV aIL / LO Na __. MN'''" r STATE OF ALASKA AICA OIL AND GAS CONSERVATION COMIPSION -• REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing I] Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 . Re-enter Susp Well❑ Other:Convert to Gas Producer[ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑ Exploratory❑ 182-072 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 2 6.API Number: Anchorage, Property Designation(Lease Number): 8.Well Name and Number: 50-733-2035 i , „ ADL0018742 Granite Pt St 18742 46 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Nn V e , 5 N/A Granite Point Field/Undefined Gas Pool y v. 11.Present Well Condition Summary: l CC Total Depth measured 9,455 feet Plugs measured 4,190&8,107 feet true vertical 9,124 feet Junk measured N/A feet Effective Depth measured 4,157 feet Packer measured 3,107&8,187 feet true vertical 4,134 feet true vertical 3,105&7,910 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 625' 20" 625' 625' Surface 4,232' 13-3/8" 4,232' 4,206' 2,730 psi 1,130 psi Intermediate Production 8,332' 9-5/8" 8,332' 8,050' 7,510 psi 5,600 psi Liner 1,334' 7" 9,455' 9,124' 8,160 psi 7,020 psi Perforation depth Measured depth 3,392-9,324 feet CANE MN Z. 2 W b True Vertical depth 3,389-8,999 feet 3-1/2" 9.3#/L-80 3,137'(MD) 3,135'(ND) Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/N-80 8,199'(MD) 7,922'(TVD) AS1-X Ret Pkr 3,107'(MD)3,105'(ND) Packers and SSSV(type,measured and true vertical depth) Baker F Pkr 8,187'(MD)7,910'(ND) SSSV 307'(MD)307'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 200 Subsequent to operation: 0 0 0 7 38 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I] Exploratory❑ Development Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ . 16.Well Status after work: Oil ❑ Gas I] WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-555 Contact Trudi Hallett-(907)777-8323 Email thallettAhilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature �. t�1 Phone (907)777-8356 Date 11/30/2015 7‘ 6L'$'/sem RBDM91EC 0 3 2015 Form 10-404 Revised 5/2015 / / //� Submit Original Only . • ini • • Granite Point Field SCHEMATIC Well: Granite Pt St 18742-46 Completed: 11/07/15 Hilcorp Alaska,LLC API: 50-703-20355-00 PTD: 182-072 RKB:MSL=105' CASING DETAIL 1-1 Size Wt Grade Conn ID Top Btm Comments 1 20" 94.0 K-55 19.124" Surf 625' 1,500 sacks Class G 1/1/ [ 20„ 54.5 K-55 12.459" Surf 1575.5' 13-3/8" 68.0 K-55 12.415" 1575.5' 2,704.4' 2,555 sacks Class G 2 72.0 L-80 12.347" 2,704.4' 4,232.2' ---r.,... 3 4 9-5/8" 43.5 5-95 8.755" 4,193' 4,337.6' 675 sacks Class G 1 at 5 47.0 5-95 8.681" 4,337.6' 6,225.5' Est d.TOC 6 53.5 S-95 8.535" 6,225.5' 8,332.4' 4,157' ' 29.0 N-80 6.184" 8,121.3' 9,272.0' 305 sacks Class G 7 29.0 5-95 6.184" 9,272.0' 9,455' 13-3/8 1 I TUBING DETAIL Topof9-5/8" 3-1/2" 9.3 L-80 SuperMax 2.992 Surf 3,137' Fsh:20 4193' 3-1/2" 9.3 N-80 DSS-HTC 8,168' 8,199' 2-1/8" Razor JEWELRY DETAIL Charge Pelf Guns Depth Depth No ID Item (MD) (TVD) 33.25' 33.25' Tubing Hanger 1 307' 307' 2.812 SSSV 2 3,056' 3,054' 2.992 Chemical Injection Mandrel 3 3,104' 3,102' 2.812 3-1/2"T-2 On/Off Connector Calculated "" 4 3,107' 3,105' 2.992 13-3/8"AS1-X Retrievable Packer TOC 6,003' 1 5 3,126' 3,124' 2.812 3-1/2"X-Nipple 6 3,137' 3,135' 2.992 3-1/2"Wireline Re-Entry Guide ¢ Tagged 7 4,190' 4,166' CIBP w/Cement plug '*" TOC7,781' ' 8 8,107' 7,833' CRET w/Cement plug ►? ,' glv� 9 8,168' 7,891' Top of 3-1/2"tbg .b i.... ,• If - V� 10 8,187 7,910' Baker F Packer w/locator and 10'Seal Assembly 8 R V���rp_A;�y11 8,199' 7,922' Muleshoe ps, Tub ng a ;>- ' " a 8,213'4Holes w/TOF@rt e R+.y." »4-.. No Cement 8,168 91 , if t, Bond 07/30/82 10 koPERFORATION DETAIL t ii Ai ANA. ,,,„ Top Btm Top Btm ' Zone FT SPF Comments Date Status (MD) (MD) (TVD) (TVD) ... C-4 3,392' 3,414' 3,389' 3,411' 22 6 2-1/8"Tri Phase 11/11/15 Open 9-5/8" {;i..:q3,800' 3,820' 3,788' 3,808' 20 6 2-1/8"Tri Phase 11/12/15 Open k,, ti 3,909' 3,931' 3,894' 3,915' 20 6 2-1/2"Razor Charges 11/21/15 Open �i:st.) w , C5 4,045' 4,067' 4,025' 4,047' 20 6 2-1/2"Razor Charges 11/21/15_ Open 1» :`:011•,: C-4 8,330' 8,374' 8,048' 8,091' 44' q Z-1/8""Enerjet,0 09/28/15 Plugged .1.„.,k# k Phase _ _ ° ,.\ 2-1/8"Enerjet,0 Pumped27bbls C-5 8,458' 8,518' 8,171' 8,229' 60' 4 Phase 09/28/15 Plugged cement into - retainer P * "` 2-1/8"Enerjet,0 Cf C-6 8,551' 8,596' 8,260 8,303' 45' 4 09/28/15 Plugged Phase 2-1/8"Enerjet,0 0 .411 8,840' 8,878' 8,537 8,573' 38' 4 Phase 09/28/15 Plugged �»'t j' C-7 8,950' 9,017' 8,642' 8,706' 67' q 2-1/8''Enerjet,0 09/28/15 Plugged •P, . ' Phase ar '4` ,0 1, s,fn zit; 9,056' 9,07T 8,743' 8,763 21' 4 phase 09/28/15 Plugged 9,198' 9,226' 8,879' 30' 4 2-1/8"Enerjet,0 09/28/15 Plugged ,t" F Phase C-8 7 i*"' ,A'" C-8 9,246' 9,296' 8,925' 8,972' 50' 4 2-1/8"Enerjet,0 09/28/15 Plugged A Phase PBTD=4,157' TD=9,455' 9,304' 9,324' 8,980' 8,999' 20' 4 2-1/8"Enerjet,0 09/28/15 Plugged Phase Updated By:JLL 11/24/15 • Hilcorp Alaska, LLC n • Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742#46 50-733-20355-00 182-072 9/23/15 11/22/15 Daily Operations: 09/23/15-Wednesday Continued with R/U of Moncla 404, stringing up drill and hoist lines. Laid out and connected circ lines.Void tested tbg hanger to 3500#s and set BPV (0 PSI on tbg&9 5/8"- 300#s on 13 3/8"). N/D tree N/U 13 5/8" 5k stack. Tightened all flanges and attached accum hoses. Raised and scoped up derrick. Mounted rig floor and stairway on off-side. R/U foster tongs, position handling equipment on rig floor, hookup wt indicator and air to service equipment. Continue with R/U and preparation for state rig inspection and BOP witness. Began M/U test jt. 09/24/15-Thursday M/U 3 1/2" PH-6 test jt w/8 rd ported sub w/X-over on btm - pumpin,TIW& IBOP on top. M/U to hanger. Worked thru complete pre-BOPE test. Received 2- light plants and air compressor to support workover operations. Positioned and put same in service. Mounted wind walls around rig floor. Bolted up 11" x 13 5/8" spool. Positioned pollution pan under rig floor. Wired up lights in accum house plus checked pre-charge on bottles,filled as necessary. Hooked up air volume tank. Cleaned and filled active pit w/drill water. Continued prepping for state inspection and BOPE witness. 09/25/15- Friday Continued preparing for AOGCC rig inspection and witnessed BOPE test. Secured well w/ BPV and mustered all personnel in galley.AOGCC onboard at 1000 hrs. Landed 3 1/2" test jt in tbg hanger and filled stack w/8.4# DW.Tested all BOPE equipment 250#s/low 2500#s/ high as directed per Hilcorp and AOGCC requirements. Chuck Scheve,AOGCC, witnessed test. Received approval from State to proceed with W/O operations. Pulled 2-way check and screwed into hanger with 3 1/2" PH-6 pups w/8rd X-over(S/V on top). Assisted Cameron backing out hold down pins. Unload boat, spot E-line eq. backload boat. Pull hanger free @ 60k. Cont. p/u t/130k, set slips. R/u tongs, break off pup jt. L/d same. R/U e/line. Re- head m/u lubricator&string. P/T lubricator t/ 1500, good. RIH w/CCL & 2.5"jet cutter t/8,300', log up t/8,100' correlate cut in first jt above seals @ 8,171'. Fire cutter,good indication at surface cutter fired. POOH t/surface. Cutter fired. R/D e-line. 09/26/15-Saturday Latched and picked up on tbg- moving uphole weighing 80k. Pulled to hanger and laid out same. Prepared floor and deck to lay down recovered production string. POOH w/ recovered 3 1/2" 9.3#DSS-HTC production tbg to 191 jts out.All personnel mustered to designated areas for fire & abandon platform drill. Continued POOH w/ recovered production string. 260 jts, 2-pups, 1 cut jt 20.53' =8,133.56' pipe meas. TOF @ 8,168.22'. Clean &clear floor. Strap & prep BHA, Unload boat. P/U BHA#1 =8 3/8 bit, 9 5/8 scraper, bit sub=7.13'. TIH. P/u 3 1/2" PH-6 work string t/4,034', up wt 53k, do wt 50k. 09/27/15-Sunday . Continued TIH w/8 3/8" rock bit w/scraper f/9 5/8" casing on 3 1/2" 12.95# P-110 PH-6 TB to 7' out on single#262 = 8,125'. P/U 97k S/O 80k. P/U 1' off lit and M/U S/V w/ Kelly hose. R/U to circ in reverse over shaker w/pipe rams closed. Circ 2.2 BPM @ 220 PSI (rate dictated by production ability to dispose of fluid). Slowed t/ 1.5 BPM 75 psi, circulated hole volume clean. Line up, attempt t/inject. Pressure up t/2327 psi. Pumped 10.7 bbls @ .75 BPM.Shut down, pressure bled down t/2092 first min, 1888-2nd, 1707- 3 min, 1549-4 min, 1405-5 min, 859 10 min, 258-20 min,0-40 min. R/d circulating lines. POOH. L/d BHA. M/U Tripoint CRET f/9 5/8" casing w/centralizer and handling pup. Closed blinds and pressured up to 2400#s to plot bled off. Confer w/ Engs about plan forward. • Hilcorp Alaska, LLC Wel • l Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #46 50-733-20355-00 182-072 9/23/15 11/22/15 Daily Operations: 09/28/15-Monday Standby while discussing cementing options w/ Engs.TIH w/Tripoint CRET f/9 5/8" casing (centralized w/handling pup) to 8,110' (end of jt). Set CRET @ 8,107' w/ 1/4 round RHT(P/U 97k S/O 80k)- push/pulled twice to energize slips. Tested back side to 1500#s and bled off pressure. Rotated out of CRET and stung back in. Pressured up to 1000#s on backside. Tested SLB iron to 4500#s and released press. Opened S/V and began pressuring up on TB down thru pkr and into 7" wellbore slowly. Observed pumpin rate of 1 BPM 3300#s. Increased pressure to 3500#s with no break.Took 15 mins to bleed down to zero. Discussed options with Hilcorp&SLB Engs-formulated plan forward. R/u Pup jt,TIW& side entry PIS t/top of string. Pull stinger out of retainer. Close annular break circ. w/cmt pump @ 3bpm circulating through choke holding 1000 psi back pressure on annulus. Shut down & blend cmt 15.8 ppg, yield 1.16 ft/sx, 5.107 gal/sx drill water) pump 55 bbls slurry down wk string @ 3BPM holding 1100 psi back pressure on ann. S/d pump, sting into retainer, squeeze 27 bbls slurry through retainer altering pump rate t/ keep at max pressure of 3500.S/d at 3500 no longer able t/ inject. Un-sting f/retainer. Pump remaining 28 bbls slurry until bal. S/d monitor well -static. R/d circulating lines. POOH t/ 7,374'-calculated top of cement is 7,710'. CBU x3 @ 112 GPM, 280 psi, clean. R/d circ lines. POOH t/7,012'. M/U 9 5/8 RTTS w/storm valve. TIH t/7,261', set packer, @ 256' back out running tool. POOH & I/d same. R/U test packer 250/2500 &chart,good. Isolate & r/d ann. lines, blind same. R/d drip pan r/u t/pick stack. Began N/D TB head. 09/29/15-Tuesday Finished unbolting BOP stack at TB spool. Picked up same and unbolted TB spool from casing head (cut bolts to remove head). Worked head out with air hoist and chain ratchet. Welded 9 5/8" casing slips to casing to aid in removal. N/U 13 5/8" 3M x 13 5/8" 5M DSA and 13 5/8" 5M 2' spool. Bolt up BOP stack. Added a 2' 13 5/8" 5M spool on top of annular to raise air slips. Filled riser and closed blinds. Shell tested breaks to 2500#s on chart. Released pressure. P/U screw-in sub and TIH t/256'. M/u t/Halb storm pkr. P/u release packer. POOH I/d same.Tih f/7,012',t/7,781' tag TOC. POOH t/7,767'. R/u t/circulate, break circ, shut in. R/u pt plug t/1500 f/30 min on chart good. R/d circulating line. POOH I/d 3 1/2 wk string. L/d 124 jts. Cont. POOH standing back 68 stands in derrick. L/d cmt stinger. P/U Casing cutter BHA#3. 09/30/15-Wednesday Finished M/U Knight internal pressure casin_gcutter fJ 9 5/8" casing.TIH w/cutter(at a speed directed by KOTs that with prevent cutter blades from opening)to 4,234'. Laid out single. R/U Hilcorp power swivel. N/U 11" 5M x 7 1/16" 5M spool of w/stripping head. Worked thru issues to get swivel rigged up and running. M/U to string and established parameters, start pumping, had leak on swivel packing, repair same. Make cut @ 4,200' rot @ 100 rpm, tq 1500-4000, final circulating rate 1.75 bpm, 560 psi, up wt 54k, do wt 52k. R/d swivel &stripper head. R/u tongs. POOH, inspect cutter' blades.Good fAh indication of first cut from markings. RIH w/cutter t/86'.,_MJu stripper head &swivel; P/u make cut @75' (from top of 't slips) rot @ 100 rpm, tq 1800-4000, final circulating rate 2.3 bpm, 890 psi. R/d swivel & stripper head. R/u tongs. B/D internal casing cutter. • • S Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742#46 50-733-20355-00 182-072 9/23/15 11/22/15 Daily Operations: 10/01/15-Thursday M/U Knight Itco spear w/8.688 grapple.Speared into 9 5/8" casing at casing head. Attempted to pull cut at 75' with max pull of 160k. Worked pipe for 30 mins before decision was made to R/U casing jacks. Released spear and POOH w/same. Broke off PH-6 tbg and M/U IF jt on spear. R/D tongs and cleared floor for mounting casing jacks. Rigged up jacks w/ studs fastened to 11" x 13 5/8" spool. Connected hose and cranked unit.Added IF pup to handling jt and latched same. Set slips, tied elevators and slips, pulled to 236k and slips on 9 5/8" casing released. Pulled cut piece of 9 5/8" to surface. Closed bag on 9 5/8" and shucked spear. R/D casing jacks and N/D 11" x 13 5/8" spool. Speared into casing and pulled same to surface. Secured casing and shucked spear. Laid down Knight spear assembly then laid down 37.88' piece of 9 5/8" casing. Began preparing to N/U 2nd dual ram section w/3 1/2" &9 5/8" ram blocks loaded. Spoke w/ Mr. Regg concerning BOPE reconfiguration and emailed diagram of needed BOP stack. Received an email from Mr. Regg/AOGCC to suspend workover operations on AN-46 and secure well. Closed blinds on stack and began focusing on issues Mr.Tornai identified during his visit last Friday. Rig crew cleaned and organized work area. Cleaned rig floor, c/o pad eyes on same, built new fire ext. hangers, blew down all surface lines, installed grating in front of rig engine. Housekeeping& rig maintenance. 10/02/15- Friday Rig crew continuing with housekeeping and maintenance while AOGCC has workover operation suspended. Received permission from Mr. Regg to continue with 9 5/8" casing recovery using requested BOPE configuration. N/D annular and N/U 2nd dual pipe ram w/3 1/2" blocks in top &9 5/8" blocks in btm. Nippled annular on top of 2nd dual.Tq flanges on BOPE. Function test good. Move floor up t/accommodate new BOPE configuration. M/U 3 1/2 t/j. Fill stack&surface eq. w/drill water. Shell test good.Test BOPE as per Hilcorp &AOGCC regulations. Witness was waived by AOGCC Jim Regg @ 9:23 am 9-30-15.Tested w/3-1/2"TJ's. Test 250 low, 2500 high as per Sundry. Presently making last BOPE test w/9 5/8" pipe rams. 10/03/15-Saturday Finished testing BOPE as per Hilcorp and AOGCC requirements, 250#s/low 2500#s/high. Witness waived by Mr.Jim Regg/AOGCC. Laid down 9 5/8" test jt. M/U Knight spear assembly(6 1/2" x 3" packoff carrier, 6 1/2" x 3" Itco spear w/ 8.681" grapple, 6 1/2" x 3" stop sub, 6 1/2" x 2 1/4" X-over sub= 11.82'). Made up on 3 1/2" 15.50#S-135 IF DP. TIH and engaged 9 5/8" casing at 77'. R/U Kelly hose and pulled to 50k on indicator. Closed pipe rams and circulated LW at 2 BPM 475 PSI f/2600 stks-fluid never dirtied up (1920 units gas max at 1780 stks then cleared up). Shutdown pump and opened rams. Began working pipe to 200k indicator wt (Moncla max). Held weight at 200k and closed annular. Pumped at 2 BPM to see if that would help lift casing- no go. Stopped pumping and opened annular.Slacked down to neutral to begin R/U jacks. R/U jacks.Welded pad eyes to strong-back beams. Chained riser w/4- 15k chains (double w/ratchet binders)to support some of the down force from jacking on wellhead. Setup tattletales on riser at main deck and 13 5/8" valve in well bay. P/U on casing to 275k and pipe started traveling then started u-tubing. R/U circulating lines. Circulated in rev 2 BPM,44 PSI, cont. work pipe with jack, wt decreasing t/194k.Sid monitor well -static. Open annular, cont. wk pipe, drag cont. dropping off.Swap t/rig pull 150k falling t/ 145k. R/d jack. Pull & I/d 2 singles wk string. P/u Weatherford power tongs for casing. Pull casing t/surface, shuck spear, break& I/d first jt. (connections tight). L/d spear. Laid down 1st full jt of 9 5/8" casing then changed out Weatherford tongs to stronger set and re-rigged snub lines due to tight connections. • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742#46 50-733-20355-00 182-072 9/23/15 11/22/15 Daily Operations: 10/04/15-Sunday POOH laying down 9 5/8" casing. B/O overshot at 1,142'. Cold cut one connection that tongs could not break. Total of 95 jts of 9 5/8" casing laid down =4,160.27' +33.25' elevation =4,193.52'. R/D Weatherford casing tongs. Presently clearing rig floor in preparation to remove 2nd dual ram body. 10/05/15-Monday Finished clearing rig floor. With blind rams closed, annular and top dual ram body(3 1/2" &9 5/8") were unbolted leaving 4- bolts secured (each) in case we're permitted to proceed. Slipped and cut drill line. 0920 hrs received permission from Mr. Regg(by email)to reconfigure BOP stack. 1008 hrs received permission from Mr. Regg to proceed w/CIBP &cement. L/D annular and top set of 13 3/8" dual pipe rams w/3 1/2" &9 5/8" blocks. N/U annular on top of 2 7/8" x 5"variables& blinds. Lowered rig floor. M/U test plug on 3 1/2" tbg and land same in 9 5/8" casing head. Shell tested breaks to 250#/low 2500#s/high on chart 5 mins each. Pulled and laid down test jt w/plug. 1627 hrs AOGCC instructed Hilcorp to cease W/O operation after setting CIBP &cement. M/U 12" bit w/Swaco scraper f/ 13 3/8" casing w/BJs. R/U Fostert _.. .... tongs.TIH w/bit&scraper to 2,996' and broke circulation. Continued in and tagged at 4,022'. P/U to connection. L/D 11" x 13 3/8" spool. N/U stripping head. P/U power swivel and M/U single. Installed strippin_g,.rubber. 'f M/U to string and landed rubber. Began circ in rev at 3 BPM 260 PSI. Washed/rotated down to 4,022' and tagged again. Took 1 hr to get past this spot (seemed to be the scraper holding us up- no torque, no drag, no overpull,just taking weight). Dropped thru and continued in hole rotating&circ to 9 5/8" casing stub at 4,200. Saw max gas of 1300 units.As new hole was made we would get gas units then it would circulate out. No continuous influx. Presently circ hole clean- full returns. 10/06/15-Tuesday Circulated hole clean at 4,200' sending returns to production. Reduced rate to 2 BPM 200 PSI to match rate fluid was going to production. Diluted drilling mud in returns. No gas after bottoms up. Full returns. B/O L/D power swivel. N/D 13 3/8 x 7 1/16" stripping head. N/U 11" x 13 3/8" spool. POOH w/ 12" Varel rock bit and Swaco scraper f/ 13 3/8" casing. B/D bit &scraper. M/U Tripoint CIBP f/ 13 3/8" 72#casing w/ running tool on 3 1/2" 12.95# PH-6 workstring.TIH (as directed by Tripoint)to 4,200' and tagged 9 5/8" stub lightly(P/U 56k S/O 50K). Picked up to_4 190' and set CI@P Tested plug to 1500#s. Rotated out of BP and pulled up 2'. RAJSLB cementing (held PJSM discussing cement procedure at tour change) and tested iron to 200#s. Opened well and established circ. Spotted 5 bbls of 15.8 ppg, yield 1.16 ft/sx, 5.107 gal/sx DW cement on top of CIBP at 4,190' holding 300#s BP. TOC est at 4,157'. B/O HP cementing lines(well balanced) & pulled two stands. Reversed out two tbg volumes at 4,066'.Tested 13 3/8" to 1500#s on chart for 30 mins. POOH w/3 1/2" PH6 workstring. B/O Tripoint running tool. M/U 3 1/2" mule shoe and TIH w/ PH6 workstring to 3,784'. M/U Halb storm pkr w/valve +3 stands (211.03') and continued in hole setting pkr in 13 3/8" casing at 207'. Released from pkr and POOH laying down 3 stands of workstring.Tested storm pkr to 1500#s for 30 mins on chart. Closed blinds and began preparing rig for inactivity. rr"' Hilcorp Alaska, LLC • Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742#46 50-733-20355-00 182-072 9/23/15 11/22/15 Daily Operations: 10/31/2015-Saturday Standby. Waiting on arrival of Moncla day crew, crane crew, welder and 2nd WSM. Held PJSM w/all rig and support personnel emphasizing 'Stop Work Authority'. All permits and JSAs generated and signed. Worked M/V Titon offloading winterization and Halliburton EL equipment. Checked fluids and cranked rig. Raised and scoped out derrick. Secured same with all guy lines. Tarped mud pump hut and placed in position. Setup light plants and air compressor. R/U heater and ran lines to BOP stack.Shutdown overnight. 11/01/2015-Sunday Held PJSM w/crews. Generated all JSAs and work permits. Continued winterizing W/O equipment.Tarped 1st and 2nd rig carrier hut and set in place. Worked M/V Titon offloading more winterizing huts. Modified 3rd hut frame that goes over draw works. Wrapped BOP stack with pit liner. Shutdown overnight. 11/02/2015- Monday Continued with winterization of W/O components.Tarped 3rd carrier section and began building 4th & last section of carrier hut(a new section). Hung wind walls under rig carrier. Raised rig floor to work height. Rested night crew till midnight because of late arrival to platform (weather hold yesterday till 1500 hrs). High winds prevented placing winterization over remainder of carrier and rig tanks. Closed ends of pump shed and rigged up lighting inside same. Secured all huts against high winds. 11/03/2015-Tuesday Continued with winterization after winds settled.Tarped 3rd section of rig carrier hut and set same in place. Built hut over active/shaker tank and began building 4th section of rig carrier hut. Placed heater trunks inside BOP stack enclosure. Temps presently at 52 degrees F. Hung tarping over active/shaker tank. Continued installing tarping and securing huts over W/O equipment. R/U lighting in huts. 11/04/2015-Wednesday Wired up heaters and trouble shot electrical issues. Tarped 4th (final) section of carrier hut and set in place. Total Safety and Quadco on location to go thru their systems. All audible and visual gas alarms tested by Total Safety. M/U test plug on jt of 3 1/2" tb. Filled active tank with 100 bbls DW. Mr. Regg/AOGCC waived rig inspection and BOPE test witness at 16:48 hrs. Completed winterization. Finished M/U test jt w/pumpin, safety valve and IBOP. Landed test plug and filled stack w/ DW. Closed annular and purged air from system. Tested all BOP equipment to 250#s low/2500#s high as per Hilcorp and AOGCC requirements. Performed accumulator draw-down test. Drained stack and began unbolting same at 13 3/8" casing head. • • Hilcorp Alaska, LLC • Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742#46 50-733-20355-00 182-072 9/23/15 11/22/15 Daily Operations: 11/05/2015-Thursday N/D BOP stack at 13 3/8" casing head.jU CIW-DCB 13 5/8" 3M x 13 5/8" 5M prod tb head and bolted stack up. Shell tested to 1500#s f/37 mins on chart. Prepared rig floor to run tubing(moved slips and elevators to floor and R/U Foster tongs). M/U Halliburton storm pkr retrieving tool and TIH to 195'. Waiting on a starter motor for mud pump and a Halliburton tool hand (both on boat). N/D 11" x 13 5/8" spool and repaired starter on pump. Plumbed in 5th heater to BOP stack and rig floor. Installed one pull cylinder in derrick for BJ tongs. Offloaded tool hand from M/V Titon and screwed into pkr. Open valve and well U-tubed until stable. Released pkr and allowed elements to relax. Laid out 6 jts of 3 1/2" PH-6 workstring then worked Halb storm pkr and valve. POOH laying down 122 jts of workstring& muleshoe, pumping displacement every 15 jts (20 bbls total). Cleared and cleaned rig floor. Moved EL unit into position. 11/06/2015- Friday R/U HLS EL equipment to the point of making up tools.Telemetry section of EL tools where not loaded on last night's boat. Stood by while waiting on tools.Tools arrived via M/V Titon. Off loaded and continued w/ EL R/U.TIH w/ RMT tools (pulse neutron)tagging btm at 4,150'. Recorded repeat then main pass from 4,150'to 200'. POOH- HLS prepped for CBL log. RMT LAS& PDF files loaded in '0' drive. Engineer notified. HLS repaired line damaged from picking lubricator up to high and then had to call for backup telemetry section for CBL. Receiving tools via night flight at 0030 hrs.TIH w/CBL to 4,150'. HLS Eng determined that log should be pulled with pressure applied. Pressured up to 400#s and began recording co, CBL. 11/07/2015-Saturday HLS finished recording CBL. R/D HLS E-Line equipment. Loaded CBL pdf& las files to '0' drive. Prepared rig floor to run pipe. R/D Moncla Foster tongs and R/U Hilcorp 5.5" McCoy tongs. Plumbed tong hydraulics into rig system when Moncla power pack failed. Held PJSM with rig and crane crews,Tripoint and Pollard. R/U sheave for 1/4" control line. P/U Tripoint AS1-X mech set pkr f/13 3/8" casing and ran in w/production assembly (as designed on proposed diagram + pinned on/off tool above pkr) on new 3 1/2" 9.3# N-80 SuperMax tubing, strapping, drifting and torqueing to diamond pa,,,, mark on pin. Function tested SSSV at 2000#s (opened/closed). M/U hanger plus control lines. Landed hanger and t'� assisted NOS rep running in hanger pins. Displaced (reversed) 8.4#drill water with 8.6#6% KCL at 2 BPM 200#s with returns going to GPTF-507 total bbls pumped. Ran in hold-down pins and set pkr at 3,107'. Pull tested to 65k(35k above string weight). 30k P/U-30k S/O. R/U hoses and tested casing to 1500#s for 36 mins (Initial MIT)-good test. Released pressure. B/O landing jt. 11/08/2015-Sunday NOS (Northern Oil Solutions) set BPV in tubing head. Cleared rig floor. Removing tarping and heater trunks in BOP stack area then R/D floor. Bled down accum and R/D L/O lines. N/D BOP stack along with disconnecting pump lines and dismantling active tank winterization tarp and frame.Assisted NOS preparing tubing head to receive tree and then N/U same. Void tested hanger and shell tested tree to 5000#s. Turned well over to production at 1830 hrs. Continuing with demob. Back loaded M/V Titon w/tongs, choke house, baskets w/misc rig equipment, remote for swaco, stairways, rig tank canopy frame work, gas buster and Hilcorp mixing tank. Removed all testing equipment from lower production deck and prepped derrick to be scoped down. Scoped down derrick and placed same in headache rack. Removed all guy lines and secured them to derrick. Unstrung drill line onto spool and attached same to derrick. Removed canopy from mud pump. Cleaned shaker tank and remove lower wind walls on rig carrier. • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #46 50-733-20355-00 182-072 9/23/15 11/22/15 Daily Operations: 11/09/2015- Monday No operations to report. 11/10/2015-Tuesday On standby waiting arrival of Pollard SL crew. Pollard onboard (via helicopter). Crew received orientation from Expeditor. Spot and R/U slickline equipment. M/U rope socket w/ 1 3/4" stem x 2, knuckle, oil jar, spang jar and swab mandrel w/3 swab cups for 3 1/2" tb. Opened tree and tagged fluid at hanger. TIH to 100' and pulled fluid. Made 8 runs total swabbing fluid level down to 700'. Made another 14 runs and had fluid level pulled down to 1,700' (22 total Runs). R/D Pollard SL equipment and released crew. HLS setup and prepared for 1st perforating run next morning. Shutdown overnight. 11/11/2015-Wednesday HELD OFFICE ROUND TABLE CONFERENCE CALL. HELD PLATFORM SAFETY,JSA& OPS MTG. START R/U OF E/L.TESTING TO 3000 PSI WITH GR,CCL AND PSI TOOL STRING. GOOD. M/U 2 1/8" X 22' LOADED, 6 SPF TRIPHASE, DEEPSTAR HALLIBURTON PERF GUNS WI GR,CC, AND PSI TOOL. GUNS ARMED. OPEN WELL AND RIH SLOW. COMPUTER STARTED HAVING MAJOR ISSUES AND FAILED. CALLED OFFICE TO INFORM ENGINEERS. COMPUTER UP AND RUNNING. ALL PROGRAMS WORKING. RIH AND LOG. SEND CORRELATION LOG TO OFFICE TO VERIFY. GOOD, LOG INTO PLACE. PRODUCTION OPENED SSV ON WING AND CRACKED CHOKE TO A 4. SHOT WELL BHP 736 PSI. LOST 100 LBS. OF WT.THEN WEIGHT RECOVERED 550 PSI. MONITOR WELL AND BHP FORM TOOLS. NO CHANGE, WHP SLOWLY COMING UP BUT, WITH WING OPEN GAS IS INJ. INTO THE TBG. WAITED 20 MINUTES AND NO BIG CHANGE IN BHP. (25 PSI).TALKED TO OFFICE. POOH. ALSO WINDS PICKING UP AND WEATHER DETERIORATING. POOH. WHEN WE REACHED SURFACE, WINDS AVERAGING 40 MPH. L/D LUBRICATOR AND SHUT OPERATIONS UNTIL BETTER WEATHER. (FLUID LEVEL GOING IN HOLE EST. 2,000', FLUID LEVEL POOH 1,620'. CONTINUE TO MONITOR WEATHER AND WELL. 11/12/2015-Thursday HELD PLATFORM SAFETY&OPS MTG WITH ALL PERSONNEL. WOW. CK WELL-0- PSI. HELD JOB SPECIFIC JSA MTG. & CALL IN OPERATIONS MTG. WEATHER CALMED DOWN. M/U 2 1/8 X 22'TRI PHASE, 6 SPF DEEPSTAR STRIP PERFORATING GUN. WHEN REMOVING NIGHT CAP NOTICE A LITTLE PSI UNDER IT. BLED IT OFF (25 PSI) NEEDLE VALVE ON NIGHT CAP WAS BAD, SEAT HAD BROKEN OFF OF NEEDLE. REPAIRED AND ALL IS FINE. RIH, LOG IN PLACE,SENT LOG TO OFFICE, SHOOT PERFS FROM 4,045-4,067. BHP 1066 BEFORE SHOOTING, AFTER SHOOTING, NO CHANGE. CALLED OFFICE. POOH. FLUID RIH - 1,500' FLUID LEVEL POOH - 1,500'. OOH, M/U GUNS SAME, OPEN WELL-0- PSI WHP. RIH, FLUID LEVEL 1,500'. LOG IN PLACE AND SHOOT WELL AT 3,909 -3,931'. BHP WAS 1105 PSI, AFTER SHOOTING 1133 PSI. NO CHANGE AT SURFACE. MONITORED FOR 20 MINUTES AND CALLED OFFICE. POOH FLUID LEVEL 1,500', -0-WHP. POOH. OOH, WAITING ON BOAT TO ARRIVE WITH 4TH GUN. PERFORATING GUN ARRIVED. M/U 20'X 2 1/8"TRI PHASE, 6 SPF, DEEPSTAR PERFORATING GUN. RIH WHP-0-. LOG UP, CORRELATE AND SHOOT AT 3,800-3,820' BHP BEFORE SHOOTING 1,076,AFTER SHOOTING 1071. FLUID LEVEL GOING IN 1,450'.AFTER MONITORING FOR 20 MINUTES, NO INCREASE IN WHP. CALLED OFFICE AND POOH. FLUID LEVEL POOH 1,420'. OOH. R/D ALL E/L RELATED EQUIPMENT AND READY FOR DEMOBE. SDFN WHILE PRODUCTION MONITORS WELL. • Hilcorp Alaska, LLC • Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742#46 50-733-20355-00 182-072 9/23/15 11/22/15 Daily Operations: 11/13/2015- Friday HELD PLATFORM SAFETY MTG WITH ALL PERSONNEL. HELD CONFERENCE CALL WITH COOK INLET AND ALSO OPERATIONS CALL WITH OFFICE. HELICOPTER ARRIVED WITH S/L PERSONNEL AND WE SENT IN HALLIBURTON. HELD JOB SPECIFIC JSA AND OPS MTG. START TO R/U SLICKLINE AND WHILE TWIST TESTING WIRE IT KEPT FAILING. WE PULLED AND CUT 1,300' OF WIRE AND FOUND GOOD WIRE THAT PASSED THE TWIST TEST TWICE. WHEN WE WENT TO TIE THE KNOW FOR ROPE SOCKET THE WIRE BROKE AS IF SUPER BRITTLE. CALLED OFFICE. CALLED TO SWAP OUT UNITS, PACK UP S/L UNIT TO BACKLOAD ON BOAT. BOAT ARRIVED AND SWAPPED S/L UNITS AND BACKLOADED HES E/L. R/U AND HELD ANOTHER JSA MTG. TEST, RIH WITH 3 1/2 SWAB CUPS.TBG PSI 25.TAGGED FLUID LEVEL AT 1,250' POOH SWABBING FLUID. RAN BACK IN HOLE AND TAGGED SAME.TALKING TO PRODUCTION WE HAVE NO CHECK VALVES IN LINE SO ALL OF THE FLUID WE SWAB IS GETTING PUSHED BACK ON TOP OF SWAB CUPS DUE TO SYSTEM PRESSURE. CALLED OFFICE. R/D S/L AND SECURE WELL. SDFN. ORDERED TANK, GAS BUSTER, SINGLE 5M CHOKE AND IRON TO BE HERE AT DAYLIGHT. 11/14/2015-Saturday HELD SAFETY MTG WITH ALL PERSONNEL ON PLATFORM. CONFERENCE CALL AND WSM CALL. STANDBY FOR BOAT TO ARRIVE. BOAT ARRIVED. OFFLOAD IRON AND TANK. HELD JSA&OPS MTG. R/U IRON,TANK AND CHOKE TO GAS DIFUSER. OPEN WELL 25 PSI. BLEED WELL THROUGH CHOKE TO ZERO. CLOSE CROWN VALVE AND R/U S/L WITH 3 1/2 SWAB CUP ASSEMBLY. OPEN WELL AND RIH. INITIAL TAG AT 1,140' PULLED 100' AND RECOVERED GOOD FLUID AND SLIGHT GAS. WORK TO 3,050' AND HAD GOOD FLUID AND MAKING MORE GAS. WELL BELCHING AND BURPING UP SOME FLUID THEN LOADING UP AND DIED. RIH AND TAG FLUID AT 3,050' AND WENT DOWN TO 3,150. POOH AND RECOVERED APPROX. 1/2 BBL. NOT HARDLY ANY GAS. WAIT FOR 45 MINUTES AND RIH AGAIN. SAME. WAITED ONE HR. RAN IN HOLE AND STOPPED AT 3,110'.POOH, NO FLUID. CALLED OFFICE AND R/D S/L, SECURE WELL& SDFN. 11/15/2015 -Sunday HELD PLATFORM SAFETY MTG WITH ALL PERSONNEL. HELD CONFERENCE CALL. CK WELL.SLIGHT BLOW (MAYBE 10 PSI). R/U S/L WITH 3 1/2 SWAB CUP ASSEMBLY. RIH TO 3,100' POOH NO FLUID. CALLED OFFICE. R/D S/L, TANK AND IRON. SECURE WELL.TURNED WELL OVER TO PRODUCTION. 11/20/2015- Friday Arrive at shop collect items for job. Arrive at heliport wait for boat. Load boat. Arrive at Anna Platform. Unload boat spot equipment.JSA. Rig up E-Line. Lay down. 11/21/2015-Saturday JSA. Finish Rig up. Pressure test *pump very slow*. Pressure test good @ 2,500. Waiting to bleed off lubricator gravity drain. Rig up Gun#1 check gamma and CCL R1 P2. Open swab RIH. Encoder problems on unit. Problem fixed RIH. Record down from 317' R1 P3. Record up @4,057' R1 P4 Correlation run R1 P4. Correlation from town good RIH. Shoot Gun #1 @4,055'Top Shot R1 P8. POOH. Pre job about high wind and change gun. OOH Bleed down change gun. Pre job about high wind and slick surface laying down. Hilcorp Alaska, LLC • Well Operations Summary Well Name API Number Well Permit Number Start Date End Date Granite Pt St 18742 #46 50-733-20355-00 182-072 9/23/15 11/22/15 Daily Operations: 11/22/2015-Sunday JSA. Rig up check tool R1 P8. RIH with Gun#2. Correlation @ 3,950' R1 P10. Send Correlation to town. RIH, Record up to 3,958' top shot R1 P13. Waiting to fire gun due to production set up. Shoot Gun #2 top shot @ 3,958'. POOH R1 P13. Stuck @3,094'. After working tool didn't come, asked if okay to pull out of rope socket. Pulled out of rope socket. POOH to surface. Rig down. Depart for OSK. • S Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, November 10, 2015 12:27 PM To: 'Trudi Hallett' Cc: Stan Golis;Juanita Lovett Subject: RE:AN-46/Moncla 404 Sundry No. 315-555, PTD: 182-072 Trudi, Bond log looks adequate to perforate your proposed zones. Thanks for the update and good luck. Regards, Guy Schwartz Sr. Petroleum Engineer 2,0 lb AOGCC 907-301-4533 cell toE '.s L 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: Trudi Hallett [mailto:thallett@hilcorp.com] Sent: Tuesday, November 10, 2015 8:47 AM To: Schwartz, Guy L(DOA) Cc: Stan Golis; Juanita Lovett Subject: AN-46/ Moncla 404 Sundry No. 315-555, PTD: 182-072 Good Morning,Guy- Please find the attached CBL and the proposed perf intervals below for the Anna 46.We plan to swab the well down this evening to 1700'and then shoot our first 20'perf interval tomorrow morning. Dependent upon the results,we will continue to the next interval and so on. Perf order and interval recommendations An-46. Gun Top Base interval Sand 1 3393 3413 20 2800_Gas_Sd (Gas_Sand_2) 2 4046 4066 20 3500_Gas_Sd (UT_5) 3 3910 3930 20 3350_Gas_Sd (TM 1) 4 3800 3820 20 3300_Gas_Sd (Gas_Sand_1) Let us know if you have any questions. Thanks! 1 Grezita, i-sj .e 614-z 4 • • )TitO 7z-o Regg, James B (DOA) From: Daniel Duckworth - (C) <dduckworth@hilcorp.com> t Sent: Sunday, November 08, 2015 10:05 AM 1l To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Cc: Trudi Hallett; Ted Kramer; Dan Marlowe; Juanita Lovett Subject: AN-46/ Moncla 404 BOPE Test Attachments: AOGCC BOPE Test Report 11 Nov 15.xlsx;TEST CHARTS 7-5-2015.pdf; Total Safety GDS Test.pdf Follow Up Flag: FollowUp Due By: Sunday, November 08, 2015 3:07 PM Flag Status: Flagged SCANNED SEP 1 92016, • STATE OF ALASKA • OIL AND GAS CONSERVATION COMMISSION BOPE Test Report +vl i< Submit to: jim.regq@alaska.gov AOGCC.Inspectors@alaska.gov phoebe.brooks c(D,alaska.gov Contractor: Moncla Rig No.: 404 DATE: 11/5/15 Rig Rep.: Terry Davis Rig Phone: 9077766754 Operator: Hilcorp Alaska Op. Phone: 9077766754 Rep.: Jimmy Crabtree E-Mail jcrabtree@hilcorp.com Well Name: AN-46 - PTD# 1820720 - Sundry# 315555 Operation: Drilling: Workover: X Explor.: Test: Initial: Weekly: X Bi-Weekly: Test Pressure(psi): Rams: 250-2500 Annular: 250-2500 - Valves: 250-2500 MASP: 1238 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen. P - Well Sign P Upper Kelly 0 NA Housekeeping P Rig P Lower Kelly 0 NA PTD On Location P • Hazard Sec. NA Ball Type 2 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 NA NA Annular Preventer 1 . 13 5/8 P - Pit Level Indicators P . P - #1 Rams 1 . 2 7/8"x 5" P Flow Indicator NA NA #2 Rams 1 blind - P Meth Gas Detector P - P #3 Rams 0 NA 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 I 2 1/16" P Inside Reel valves 0 NA HCR Valves 1 - 2 1/16" ' P Kill Line Valves 3 2 1/16" P Check Valve 0 NA ACCUMULATOR SYSTEM: BOP Misc 0 NA Time/Pressure Test Result System Pressure(psi) 3000 - P _ CHOKE MANIFOLD: Pressure After Closure(psi) 1900 P Quantity Test Result 200 psi Attained (sec) 34 , P , No.Valves 10 P Full Pressure Attained (sec) 160 - P Manual Chokes 1 • P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P . Nitgn. Bottles#&psi (Avg.): 6 @ 2200 - P CH Misc 0 NA ACC Misc 0 NA Test Results Number of Failures: 0 Test Time: 4_0 , Hours Repair or replacement of equipment will be made within N/A days. Notify the AOGCC of repairs with written confirmation to:AOGCC.Inspectors@alaska.gov Remarks: Tested w/3 1/2"tubing. Witnessed waived 11/4/15 4:31 PM by email. AOGCC Inspection 24 hr Notice Yes Date/Time 10/30/15 2:46 PM Waived By Jim Regg Test Start Date/Time: 11/5/2015 0:00 (date) (time) Witness Test Finish Date/Time: 11/5/2015 4:00 A-¢qC kcet ', - 7.54- C(.Lu,,-1-5 -Te Sl- 5P.7 vt2,-t c'L - CELS ' s lei 1� t- Form 10-424(Revised 11/2015) AOGCC BOPE Test Report 11 Nov 15.xlsx 60 0 Il/5/,S 7-- z,,cS i � � Ani 5 ✓ ____,-:--4500J --.. ` .9Gi Yf� LJ / .._j 1_ _ �. 7 y �.% _ s PrO 113Lz° ..,.--1-----:3500 ---_-7-__`' ��., / /i,� 3000 —=——__'`-------. -� \ �N /;' \ ? '„ .�' --_. �'/ 7. /` 2500 -- --- '„''',-..„,''...N ,,N'‘,..N\N\\\\\\' \' / /c/ ' /.',/ ,'''' iv ''\,..---- '..------'',-----;._- -------,- . ' ---- ''''' 'Z',,\ N \''47/. ''''.\ '\75,‘- '\ \ /'-f r/� 1500 v Aw o, j '/ / . '. ---- '. --- -------- '' '\' ',N ' N''', \'''.<\-0/ J! / — i \ .gip �\ / O ��// ; / • 00 is p ,' t t` \ / 1 ;Ao � / ' /� ' � . v mss° 0 \ ` \�� \ \ t� l • I "0 ci, (i., / R ' - ' / �'/ / l,r.y,ltic log. .,b \ -k ti' 1 {fir f ' r / 1lo� %� r4. 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S - \ ' /O -6 N... tiA oo£ � fSNfl � a sd -__ 0Y • �- Gran S1zt [6-74-z—�'rtrlr.Z,#-4(.. • prt, f e 7z-o 0,...crAttro BOP EQUIPMENT TESTS ,,t ten.mot. Rig:404 Operator: HILCORP Location: Granite point Date 11-5-15 Lease No:Cook Inlet Well No.AN-46 Previous Test Date Test Station Used: BOP EQUIPMENT PERIODICAL TESTS TEST LOW TEST HIGH TEST REMARKS NO. Pressure Time Pressure Time Record all items tested,failed test and repairs TEST MADE WITH 3-1/2" TEST JOINT 1 260 PSI 5 MIN 2535 PSI 5 MIN HYD MI,M2,M10,K3,1BOP 2 270 PSI 5 MIN 3249 PSI 8 MIN PIPE RAMS,TIW,K2,M3,M4,M9 3 240 PSI 5 MIN " 3275 PSI 7 MIN KI,M5,M6 4 N/A N/A 1200 PSI 2 MIN MANUEL CHOKE 5 N/A N/A 1370 PSI 2 MIN SUPER CHOKE 6 200 PSI 5 MIN- 3400 PSI 5 MIN C2 HCR 7 260 PSI 6 MIN - 3275 PSI 6 MIN Cl 8 200 PSI 47 SEC ' 3000 PSI 3.47 SEC ACC DRAW DOWN 9 260 PSI 5 MIN ° 3270 PSI 5 MIN - BLIND M7,M8 11111111-11 FLUID USED:8.5 SW CHECKLIST ACCUMULATOR TEST Does all equipment hold pressure without excessive pumping? INITIAL PRESSURE 3000 PSI Yes® No❑ ACCUMULATOR VOLUME–GALLONS Yes®mNooto❑r void clean and reservoir filled to proper level? Closing Ending Volume To Is maximum allowable casing pressure posted on the rig floor? Item Time Pressure Close Open Yes® No❑ Annular Are accumulator and remote station tagged as to their function? 2-7/8 X 5 Rams Yes® No❑ BLIND Rams Is there a spare annular packing element on board? Annular packing element Yes�_ No❑ Rams At least one set of ram inserts Yes CO No 0 Rams Bonnet seals Yes® No O CHOKE HCR Drill crews instructed to function pipe and blind rams each trip? Yes El No❑ KILL HCR N/A N/A Are HCR valves closed after testing? Final Pressure 1900 3000 Yes 0 No TOTAL TIME TO Are both kill line valves closed after testing? RECHARGE 34 SEC 160 Yes❑ No Do all rig personnel meet regulatory agency requirements? Yes El No SIGNOFFS Toolpusher:Anthony Edmon Operator Rep.: G ?!%j NOTES:NITROGEN BOTTLES AVG.2200 PSI Driller: Johnathin INITIAL 200 PSI BUILD UP ON KOOMEY Matrisciano RECHARGE=34 SECONDS /�d 4' Other: ` NOTE:All pressures are in PSI 41111, ,k,t(OACIAik,44A — &OFE-rz5)- • Total Safety U.S., Inc. _ i L f 5 15 209 E.51st Avenue &r2.Z (f- pi-- sicktiai<6iYf?.. °n.,,,,4-4 Anchorage,AK 99503 °a TOTAL SAFETY® Phone:(907)743-9871 I Ems%7 s�' Fax:(907)743-9872 I° GAS DETECTION SYSTEM TEST SHEET M 1 Customer: Onshore: Offshore: e Report Date: Time: AFE/Job#: ` Rig/Location: Drilling Company: Company Representitive: Telephone Number: Total Safety Technician: Current Site Activity: ,'w Type of System: Type of Test: Calibration Bump Test Sensor#1 Sensor#2 Sensor#3 Type of Sensor: Type of Sensor: Type of Sensor: Location: Location: Location: . Calibrated from: Calibrated from: Calibrated from: Bumped at: Bumped at: Bumped at: Low alarm <30 seconds: Low alarm<30 seconds: Low alarm<30 seconds: Battery Voltage: Battery Voltage: Battery Voltage: Comments: Comments: Comments: Sensor#--4 Sensor#5 Sensor':#6 Type of Sensor: Type of Sensor: Type of Sensor: Location: Location: Location: Calibrated from: Calibrated from: Calibrated from: Bumped at: Bumped at: Bumped at: yv Low alarm <30 seconds: Low alarm<30 seconds: Low alarm < 30 seconds: ` Battery Voltage: Battery Voltage: Battery Voltage: Comments: Comments: Comments: Sensor#7 Sensor#8 Sensor#9. Type of Sensor: Type of Sensor: Type of Sensor: Location: Location: Location: Calibrated from: Calibrated from: Calibrated,from: Bumped at: Bumped at: Bumped at: Low alarm <30 seconds: Low alarm<30 seconds: Low alarm <30 seconds: Battery Voltage: Battery Voltage: Battery Voltage: Comments: Comments: Comments: Sensor#10 Sensor# 11' Sensor#12 Type of Sensor: Type of Sensor: Type of Sensor: Location: Location: Location: Calibrated from: Calibrated from: Calibrated from: Bumped at: Bumped at: Bumped at: Low alarm <30 seconds Low alarm <30 seconds: Low alarm< 30 seconds: Battery Voltage: Battery Voltage: Battery Voltage: Comments: Comments: Comments: Total Safety Technician Company Represenitive Date: Date: White-Office Canary-Customer Pink-File r _ • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, October 30, 2015 2:20 PM To: 'Trudi Hallett' Cc: Juanita Lovett Subject: RE:AN-46/ Moncla 404 Sundry No. 315-555, PTD: 182-072 (approval to restart) Trudi, I have reviewed the sundry for AN-46 along with well reports for the work completed to date. Your time plan forecast below(first 7 time steps)summarize the rig plan forward to get to back to the original approved sundry.... (Replace tubing spool, pull storm packer and kill string). You have approval to restart operations on approved sundry 315-555 as proposed. A rig inspection in conjunction with a witnessed BOPE test will be required before operations can continue. Regards, Guy Schwartz SC.M4S6 MAY 1 12016 Sr. 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: Trudi Hallett [mailto:thallett@hilcorp.com] Sent: Friday, October 30, 2015 1:46 PM To: Schwartz, Guy L(DOA) Cc: Juanita Lovett Subject: FW: AN-46/ Moncla 404 Sundry No. 315-555, PTD: 182-072 Good afternoon, Guy—attached is the "as is" schematic, approved sundry, pressure test charts from when we shut down, and below is the proposed timeline going forward. Please advise if you need further information. We anticipate to be ready for our rig inspection and BOPE test mid-week next week.Thank you - 1 • • Tem plate Planning Forecast ,:jei1 flame G-15 TIME ESTIMATED DAYS: 5.3 PROCUCTNE 0.0 ACTUAL DAYS: 0.0 UNPLANNED 0.0 0.0 IROUBLE 0.0 DAYS TOTAL 0.0 Estimated Completion Day 11/8115 7 130 F INSERT ROW I DELETE ROME SELECT ACELL ON A COLUMN AND CLICK THIS BUTTON TO PRINT NE}4f�25 RONV S� Tit.E START pW.11 a F.S7 A atA.. START END P MARI CODE DAY E,E .T ES ?IFTIO' ):= '"C`s 04.PATICN CATETIME LATE TP.E P Tues Winterde Maeda 404&bring uptemps 72.0 0.0 11113.15 12 DD PM 11 5 15 1200 PM rig will be broul P Fn AOGCC ra2 inspection&ROPE ant 8.0 0.0 11515 12:00 PM 11.e 158.00 PMt P Fri NO BODE at 13 3,.8"cas in0 heed 3..0 0.0 11.`e.it 8 00 PM 11 5 15 11 30 PM P Fri install completions pool 3.0 0.0 11 5 15 11.00 PM 11.`7:'15 2 00 AM Camer P Set KU BODE end shell last to 15000s 3.0 0.0 117 15 233 AM 11 i 7 15 5:00 AM P Sit Open wetland retieuestarn pct. 2.0 0.0 11:7;'15 5:00 AM 11 7:157'00 AM Hailiburto Ni, P Sat POOH lar no down wont sling 6.0 0.0 117'15 700 AM 117 r'15 1,00 Ph1 ....---- ; P Sat RU Halliburton EL and reoxd bond Irk-RTD EL 7.0 0.0 117'15 1:00 PM 11 7.158.00 PM Hal iiburts OAC P Sat hLt-TI-I wI pia and production string-s ening.. 8.0 0.0 117 1!800 PM 11 8 15 4 00 AM Trip of nt 8 i r 3.120`. 1' .�l7P Sun Testanrulus to 15000s 130 mins on chart 1.0 0.0 11'8'15 4:00 AM 11.$ 15 5:00 Ahi Camer 5`'�N� Nc Sun `MU narnger&land same 2.0 0.0 11 8'15 5 00 AM 11.8 15700 AM !P Sun Testannuk.s to 15001rs on chart 1.0 0.0 11 8 15 7'00 AM 11.8'158'00 Ahl P Sun B Olsndr+g jt and install EP./.RAD Nan 4.0- . 0.0 111.15 8.00 AM 11'8'15 1200 PM P Sun ND ROPE 4.0 0.0 11 8 1! 12:00 PM 118'154:00 PM P Sun NU tea and sheNtest 3.0 A 0.0 A 11.8;15 a:00 PM 11 8-1!7 00 PM P Sun Turn well over to production 0.0 0.0 11-8 15 7:00 PM 11'$.'1!7:00 PM P Sun 0.0 0.0 118 15 700 PM 1118 157 00 PM Thanks- Tra,di. Trudi Hallett I Operations Engineer Cook Inlet Offshore Asset Team 1 Hilcorp Alaska. Ll.0 Hilcorp A Company Built on Energy thallett@hilcorp.com 0: 907.777.8323 C: 907.301.6657 From:Trudi Hallett Sent: Thursday, October 08, 2015 10:43 AM To: 'Regg,James B (DOA)'; Daniel Duckworth - (C) Cc: Ted Kramer; Dan Marlowe; Harold Soule - (C); Schwartz, Guy L(DOA); Juanita Lovett Subject: RE: AN-46/ Moncla 404 Sundry No. 315-555, PTD: 182-072 Mr. Regg-attached is the summary for the Anna 46 final day of well work complying with the AOGCC's workover suspension mandate. I have also attached the current(as-is)wellbore schematic and pressure test charts. Please let me know if there is any add'I information you need.All rig crews and support personnel are standing by until further notice. 2 • • Hilcorp Alaska, LLC Operations Summary Wit Name *Pi Number Well Permit Nur,te, Sund ■ Granite Pt St 18742 146 50-733-20355-00 182-072 315-555 Daily Operations: 10/06/15-Tuesday Circulated hole clean at 4,200'sending returns to production. Reduced rate to 2 BPM 200 PSI to match rate fluid was going to production. Diluted drilling mud in returns.No gas after bottoms up.Full returns.B/0 L/D power swivel. N/D 13 3/8 x 7 1/16"stripping head. N/U 11"x 13 3/8"spool. POOH w/12"Varel rock bit and Swaco scraper f/13 3/8" casing.BID bit&scraper. M/U Tripoint CIBP f/13 3/8"721 casing w/running tool on 3 1/2"12.9511 PH-6 workstring. TIH(as directed by Tripoint)to 4,200'and tagged 9 5/8"stub lightly(P/U 56k S/O 50K).Picked up to 4,190'and set GBP. Tested plug to 1500lis. Rotated out of BP and pulled up 2'. R/U SLB cementing(held PJSM discussing cement procedure at tour change)and tested iron to 200#s. Opened well and established circ.Spotted 5 bbls of 15.8 ppg,yield 1.16 ft/sx, 5.107 gal/sx DW cement on top of CIBP at 4,190'holding 300es BP. TOC est at 4,157'.8/0 HP cementing lines(well balanced)&pulled two stands.Reversed out two tbg volumes at 4,066'.Tested 13 3/8"to 1500#s on chart for 30 mins. POOH w/3 1/2"PH6 workstring. 13/0 Tripoint running tool.M/U 31/2"mule shoe and TIH w/PH6 workstring to 3,784'. M/U Halb storm pkr w/valve+3 stands(211.03')and continued in hole setting pkr in 13 3/8"casing at 207'. Released from pkr and POOH laying down 3 stands of workstring.Tested storm pkr to 150011s for 30 mins on chart.Closed blinds and began preparing rig for inactivity. Thanks- TrlA.di. From: Regg, James B (DOA) [mailto:jim.regg@lalaska.gov] Sent: Monday, October 05, 2015 10:08 AM To: Daniel Duckworth - (C); Trudi Hallett Cc: Ted Kramer; Dan Marlowe; Harold Soule - (C); Schwartz, Guy L (DOA) Subject: RE: AN-46/ Moncla 404 Thank you. OK to install second barrier(CIBP and cement) in the 13 3/8" at the top of 9 5/8" casing. What are your plans to verify the plug? How much cement on top of the CIBP is planned.When work is completed, send a summary of the work to suspend the well (including actual plug setting depth and volume of cement)and a schematic of the well's configuration. 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.sov. 3 • From: Daniel Duckworth - (C) [mailto:dduckworth@hilcorp.com] Sent: Monday, October 05, 2015 9:40 AM To: Regg, James B (DOA) Cc: Trudi Hallett; Ted Kramer; Dan Marlowe; Harold Soule - (C) Subject: RE: AN-46/ Moncla 404 Presently we only have one barrier in this well which is our blind rams-the top of the 9 5/8" is 4,193' and the btm of the 13 3/8" is 4,232'. The top of the cement behind our 9 5/8" is calculated to be 6,003'-we need that second barrier(CIBP &cement) in our 13 3/8" at the top of the 9 5/8". Please advise,thanks! From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Monday, October 05, 2015 9:20 AM To: Daniel Duckworth - (C) Subject: RE: AN-46/ Moncla 404 Ok to remove double gate from BOPE stack and shell test the stack. Unclear the status of your well and how it is secured. 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: Daniel Duckworth - (C) [mailto:dduckworth@hilcorp.com] Sent: Sunday, October 04, 2015 4:47 PM To: Regg, James B (DOA); Schwartz, Guy L(DOA) Cc: Trudi Hallett; Ted Kramer Subject: AN-46/ Moncla 404 Mr.Jim at the rate we're laying 9 5/8" casing down we should be out of the hole in the early hrs of the morning. We will close the blind rams at that point. If permitted we would like to remove that dual ram stack w/the 9 5/8" blocks since they're not needed anymore-shell test the stack and be prepared to P/U 13 3/8" cleanout assy inorder to plug off that casing w/CIBP &cement. Please advise as to how far we can go,thanks! 4 IlliArt 410 ° '.4A-----(.._(.,' y Granite Point Field S7 "" IWell: Granite Pt St 18742 46 111 ('- ' CHEMATIC U Completed: Future (As of 10/7/2015) API: 50-703-20355-00 Ilileorp Alaska,I.I.0 g.3 S "Q ,,, PTD: 182-072 RKB:MSL=105' CASING DETAIL Size Wt Grade Conn ID Top Btm Comments 1-_ ---._:°‘#"t----- 1 [ 20" 94.0 K-55 19.124" Surf 625' 1,500 sacks Class G /0" 54,5 K-55 12.459" Surf 1575.5' 13-3/8" 68.0 K-55 12.415" 1575.5' 2,704.4' 2,555 sacks Class G 72.0 L-80 12.347" 2,704.4' 4,232.2' "G2 9-5/8" 43.5 S-95 8.755" 4,193' 4,337.6' 675 sacks Class G ' 47.0 S-95 8.681" 4,337.6' 6,225.5' fEst'd.Toe 53.5 S-95 8.535" 6,225.5' 8,332.4' 0 4,157 29.0 N-80 6.184" 8,121.3' 9,272.0' 3 7 29.0 S-95 6.184" 9,272.0' 9,455' 305 sacks Class G 13-3/8' TUBING DETAIL Top of 9-s(8" 3-1/2" PH-6 Workstring Surf 3,784' Kill String 4,193' 3-1/2" 9.30 N-80 DSS-HTC 8,168' 8,199' JEWELRY DETAIL Depth Depth No ID Item (MD) (TVD) 1 207' 207' Halliburton Storm Packer w/valve 2 3,784' 3,773' Kill String 3 4,190' 4,166' CIBP w/Cement plug Calculated 4 8,107' 7,833' CRET w/Cement plug TOC 5,003' 5 8,168' 7,891' Top of 3-1/2"tbg 6 8,187' 7,910' Baker F Packer w/locator and 10'Seal Assembly ` t':,s.A'M .'r�'+. Tagged 7 8,199' 7,922' Muleshoe ' :' TOC 7.751' 4 To6ingcut �� 8,213'4 Notes PERFORATION DETAIL vow@ . 8168 5 = No Cement Top Btm Top Btm aond07/3o/82 Zone FT SPF Comments Date Status 6 (MD) (MD) (TVD) (TVD) • 7 2-1/8"Enerjet,0 C-4 8,330' 8,374' 8,048' 8,091' 44' 4 phase 09/28/15 Plugged • C-4 C-5 8,458' 8,518' 8,171' 8,229' 60' 4 2 1/BPhaseJet,0 09/28/15 Plugged 9-5/8- 0 C-6 8,551' 8,596' 8,260' 8,303' 45' 4 2-1/8"Enerjet, 09/28/15 Plugged Phase •- (.5 8,840' 8,878' 8,537' 8,573' 38' 4 2-1/8"Enerjet,0 09/28/15 Plugged Phase C-7 8,950' 9,017' 8,642' 8,706' 67' 4 2-1/8"Enerjet,0 09/28/15 Plugged Pumped 27 kis Phase cement into 0 9,056' 9,077' 8,743' 8,763 21' 4 2-1/8"Enerjet, 09/28/15 Plugged retainer Phase Cb 2-1/8"Enerjet,0 9,198' 9,226' 8,879' 30' 4 phase 09/28/15 Plugged C-8 9,246' 9,296' 8,925' 8,972' 50' 4 2'1/8"Enerjet,0 09/28/15 Plugged . . Phase 9,304' 9,324' 8,980' 8,999' 20' 4 2-1/8"Enerjet,0 09/28/15 Plugged C-7 Phase I 7. C-8 I PBTD x,365' TD=9,455' Updated By:JLL 10/08/15 • (AtaLt,k P4- sTetie_ 1/6747._ /,14,1-4c, f" iS2- 7Z-C) aegg, James B (DOA) From: Trudi Hallett <thallett@hilcorp.com> Sent: Thursday, October 08, 2015 10:43 AM 10(011( To: Regg, James B (DOA); Daniel Duckworth - (C) Cc: Ted Kramer; Dan Marlowe; Harold Soule - (C); Schwartz, Guy L (DOA); Juanita Lovett Subject: RE: AN-46/ Moncla 404 Sundry No. 315-555, PTD: 182-072 Attachments: An-46 Schematic as of 2015-10-07.pdf; Scan0008.pdf; Scan0007.pdf Mr. Regg—attached is the summary for the Anna 46 final day of well work complying with the AOGCC's workover suspension mandate. I have also attached the current(as-is)wellbore schematic and pressure test charts. Please let me know if there is any add'l information you need.All rig crews and support personnel are standing by until further notice. Hilcorp Alaska, LLC Operations Summary API Hw b+r' We=Pram 2 Numbtr Sur.ry a 'Granite Pt St 18742 446 50-733-20355-00 182-072 315-555 Daily s: esday Circulated hole clean at 4,200' sending returns to production. Reduced rate to 2 BPM 200 PSI to match rate fluid was going to production. Diluted drilling mud in returns. No gas after bottoms up. Full returns. 8/0 LID power swivel. N/D 13 3/8 x 7 1/16" stripping head. N/U 11" x 13 3/8"spool. POOH w/ 12"V'arel rock bit and Swaco scraper 1/13 3/8" casing. 8/0 bit&scraper. M/U Tripoint CIBP f/ 13 3/8" 724 casing w/running tool on 3 1/2" 12.954 PH-6 workstring. TIH {as directed by Tripoint)to 4,200' and tagged 9 5/8"stub light {Pit) 56k 5/0 50K). Picked up to 4,190'and set CIBP. Tested plug to 15004s. Rotated out of BP and pulled up 2'. R/U SLB cementing(held PJSM discussing cement procedure at tour change)and tested iron to 2004s. Opened well and established circ. Spotted 5 bbis of 15.8 ppg,yield 1.16 ftJsx, 5.107 gallsx DW cement on top of CIBP at 4,190' holding 3004s BP. TOC est at 4,157'. 8/0 HP cementing lines(well balanced)&pulled two stands. Reversed out two tbg volumes at 4,066'. Tested 13 3/8"to 15004s on chart for 30 mins. POOH W'/3 1/2" PH6 workstring. B/0 Tripoint running tool. MJU 3 1/2" mule shoe and TIH w/ PH6 workstring to 3,784'. M/U Halb storm pkr w/valve + 3 stands{211.03')and continued in hole setting pkr in 13 3/8"casing at 207'. Released from pkr and POOH laying down 3 stands of workstring. Tested storm pkr to 15004s for 30 mins on chart. Closed blinds and began preparing rig for inactivity. Thanks- SCAMtiED JUL 2 12016 From: Regg, James B (DOA) [mailto:jim.regg©alaska.gov] Sent: Monday, October 05, 2015 10:08 AM To: Daniel Duckworth - (C); Trudi Hallett Cc: Ted Kramer; Dan Marlowe; Harold Soule - (C); Schwartz, Guy L (DOA) Subject: RE: AN-46 / Moncla 404 1 • • Granite Point Field SCHEMATIC Well: Granite Pt St 18742-46 Completed: Future (As of 10/7/2015) API: 50-703-20355-00 Hilum %lulka.IAA' PTD: 182-072 RKB:MSL=105' CASING DETAIL Size Wt Grade Conn ID Top Btm Comments 1 20" 94.0 K-55 19.124" Surf 625' 1,500 sacks Class G 54.5 K-55 12.459" Surf 1575.5' 20" € 13-3/8" 68.0 K-55 12.415" 1575.5' 2,704.4' 2,555 sacks Class G 72.0 L-80 12.347" 2,704.4' 4,232.2' j 2 iiiiiiiiie 9-5/8" 43.5 5-95 8.755" 4,193' 4,337.6' 675 sacks Class G 47.0 S-95 8.681" 4,337.6' 6,225.5' Est'd.TOC 53.5 S-95 8.535" 6,225.5' 8,332.4' T 014,15T 29.0 N-80 6.184" 8,121.3' 9,272.0' 4 - = 3 7" 305 sacks Class G T ' 29.0 S-95 6.184" 9,272.0' 9,455' 13-3/8' A 1 TUBING DETAIL Top of 9-5/8" 3-1/2" PH-6 Workstring Surf 3,784' Kill String 4'193 3-1/2" 9.30 N-80 I DSS-HTC 8,168' 8,199' JEWELRY DETAIL Depth Depth No ID Item (MD) (TVD) 1 207' 207' Halliburton Storm Packer w/valve 2 3,784' 3,773' Kill String 3 4,190' 4,166' CIBP w/Cement plug Calculated 4 8,107' 7,833' CRET w/Cement plug TOC 6,003' T., 5 8,168' 7,891' Top of 3-1/2"tbg 6 8,187' 7,910' Baker F Packer w/locator and 10'Seal Assembly ;.,,,-0,..)",,1-4' .usa Tagged 7 8,199' 7,922' Muleshoe r. TOC 7,781' ' f. 4 Tubing cut A� �� 8,213'4Holes PERFORATION DETAIL w(TOF- i.iii r, , . , , No Cement 8x168' 5 ' ' ",,t Bond 07/30(82 Zone Top Btm Top Btm FT SPF Comments Date Status 6 (MD) (MD) (TVD) (TVD) fir '17 *`, '"i 2-1/8"Enerjet,0 + zg $ C-4 8,330' 8,374' 8,048' 8,091' 44' 4 phase 09/28/15 Plugged T '* 2-1/8"Enerjet,0 i " C-4 C-5 8,458' 8,518' 8,171' 8,229' 60' 4 09/28/15 Plugged ♦ f Phase 91.44141Z . 2-1/8"Enerjet,0 -S JS. i, � ' C 6 8,551' 8,596' 8,260' 8,303' 45' 4 Phase 09/28/15 Plugged 1 C-5 8,840' 8,878' 8,537' 8,573' 38' 4 2-1/BPha eget 0 09/28/15 Plugged vil:T 2-1/8"Enerjet,0 �, °�. C-7 8,950' 9,017 8,642' 8,706' 67' 4 09/28/15 Plugged Pumped 27 bbls i'"` Phase + 2-1/8"Enerjet,0 cement into 9,056' 9,07T 8,743' 8,763 21' 4 phase 09/28/15 Plugged retainer ie „ C-6 2-1/8"Enerjet,0 �; "AI' 9,1989,2268,879' 30' 4Phase 09/28/15 Plugged 2-1/8"Enerjet,0 , j,' C-8 9,246 9,296 8,925 8,972 50 q Phase 09/28/15 Plugged bs i 2-1/8"Enerjet,0 C-7 9,304' 9,324' 8,980' 8,999' 20' 4 Phase 09/28/15 Plugged i r C-8 PBTD=9,365' TD=9,455' Updated By:iLL 10/08/15 • • 600 • -- 4500 i • jf _ ffi r► 5d4 1 / ,,- - ''›- --T-Js- ---2N.J---- ---77.--------__ ,_ ' " :.- ' N:\ / ssA i t / ,,,\\-\\ `e rr. ` `\�� \7 - 2000- --- _ `, soo �� \h ° / / 7 ---- ' "`'- _� \ �s \yip° � - �1000 � � pp7 °° // 4') 0 / • � � pp 1 ospp''0 i j ____/.7-50.-'• --�_ c00 \\ \ \ \ \ // ° co ; I i t / 7 ( = N0. MC MP50001 t. �. \7 ME7 HR � \ \ \\ t\' ! i! j -_.}- .._---- CHART \ I PUT ON 1 TAKEN OFF }1 1, t Y, A - I_OCA 71DN 1, P -4jp M C.;) I 11. I •41\\ \ _ RESM .� 1 ,1 / 1 / . - �.. 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(3- q-etnike P-i-- S-We_II 74-7 PrA (e2,2...072J:3 6-x.4cP -5 � (6 74Z-- 4. eicqz, Regg, James B (DOA) From: Regg, James B (DOA) ,�[ Sent: Friday, October 02, 2015 1:27 PMS i"1� t To: 'Trudi Hallett' Subject: RE:AN - 46 Sequence of Events With the 9-5/8" Casing Cuts +d1� its—05 Yes 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. Original Message same) From: Trudi Hallett [mailto:thallett@hilcorp.com) Sent: Friday, October 02, 2015 1:24 PM To: Regg,James B (DOA) Subject: Re: AN -46 Sequence of Events With the 9-5/8" Casing Cuts Hi Mr. Regg, Do we have approval to move forward with the proposed BOPE configuration Mr. Duckworth sent to you yesterday?We are due for weekly BOPE test today. Please advise.Thank you, Sir. Trudi Hallett 907-301-6657 Sent from my iPhone > On Oct 2, 2015, at 1:07 PM, Regg,James B (DOA) <iim.regg@alaska.gov>wrote: >Thank you for the daily reports and summary below. Hilcorp is authorized to continue pulling the 9-5/8" casing before suspending workover operations on Anna 46 (PTD 1820720). >Jim Regg 1 Qrzec 16-74z__ A-4.4A-A Regg, James B (DOA) From: Regg,James B (DOA) az/I-, Sent: Friday, October 02, 2015 1:07 PM 2eetei To: 'Ted Kramer' Cc: Juanita Lovett; Stan Golis;Trudi Hallett; Foerster, Catherine P (DOA); Seamount, Dan T (DOA) Subject: RE: AN - 46 Sequence of Events With the 9-5/8" Casing Cuts 315 555 Thank you for the daily reports and summary below. Hilcorp is authorized to continue pulling the 9-5/8" casing before suspending workover operations on Anna 46(PTD 1820720). Jim Regg Supervisor, Inspections AOGCC SCOW � '"Y ,; 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.reggcalaska.gov. Original Message From: Ted Kramer [mailto:tkramer@hilcorp.comj Sent: Friday, October 02, 2015 12:09 PM To: Regg,James B (DOA) Cc:Juanita Lovett; Stan Golis Subject: AN -46 Sequence of Events With the 9-5/8" Casing Cuts Jim, Attached please find rig reports for 10/1/2015 and 10/2/2015. These reports end as of 0600 on the date of the report and reflect work completed for the prior 24 hours. The 10/1/2015 report shows that the first cut of the 9-5/8" at 4,200' occurred 1900 to 2000 hrs on Wednesday V September 30, 2015. The second cut at 86' occurred 0200 to 0300 hrs the morning of October 1, 2015. The shallow cut was made because we were not confident that the 404 could pull enough to both unseat the slips and pull the casing. The shallow cut would allow Hilcorp to pull the 9-5/8" slips/hanger separately and get it out of the way. Hilcorp's WSM recognized that we needed 9-5/8" rams in the stack to be able to pull the 9-5/8" casing. Adding the additional double gate to the stack allows for the 9-5/8" Rams. 1 • Hilcorp's WSM called Lou Grimaldi and discussed the situation with him and toldm what Hilcorp wanted to do. Lou advised the Hilcorp WSM to call you directly and get permission to modify the BOP stack. That is the background for ,, Hilcorp's e-mail from Danny Duckworth to you on October 1, 2015. The cuts were already made prior to being advised by you in your e-mail dated 4:03 PM October 1, 2015 that Hilcorp was to suspend all workover operations until further notice. No reason was given in the e-mail as to why. Danny ' contacted me and I told him the secure the well and await further orders. That was immediately done. Hilcorp requests that we be allowed to return to work to finish pulling the 9-5/8" casing. --- Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 2 cPF Arima elf, • , ?Ts 1 8Z 012.0 Sunk 315-555" HILCORP ENERGY COMPANY DAILY OPERATIONS REPORT REPORT NO. I 9 IDATE: I 10/1/2015 �+� JOB: 1522358 AN-46 Workover-Convert tO Gas Producer "11`j 4,i -11.I t LEASE: WELL: GP=AN-45 AFE/PROJ NO: 1522358 l FIELD: Granite Point Field COUNTY/PARISH 1 APPT: STATE: AK ^'-`''64-'k —tf3k•rv` PRESENT OPERATION AT REPORT TIME: IM/U Knight spear for 9 5/8'casino. DAILY COST: $70,116 CUM.JOB COST: 5686,519 AFE Budget 51,791.350 CUM,DRILL COST: CUM,CMPL COST: Total DEC Cost: REPORTED BY: Denny DuekwMNHarold Soule CONTRACTOR REP: PHONE 907-776.8754 CONTRACTOR I RIG ft ' LAST BOP TEST: f 9'25120'5 NEXT BOP TEST: 10/2/2015 FUNC DUE: test from remote FLUID: I TYPE: OW WEIGHT: 5.4 DAILY LOSS: I 3 ICUM LOSS: 1 57.5999 CASING DATA PRODUCTION TUBING SIZE: WT: DEPTH: ID: SLZDWTITHD: GRADE ID: SIZE: WT: DEPTH: , ID: „ SIZE: WT: DEPTH: ID: SIZE: WT: DEPTH: ID: ., EQUIPMENT DATA Packer, SIZE/DEPTH:I NIPPLES: DEPTH: ID: SCSSV: DEPTH: ID: NIPPLES: DEPTH: 10: NIPPLES: DEPTH: ID: NIPPLES: DEPTH: ID: TBG HD/FLANGE: PROD TREE: SMALLEST ID: I I DEPTH: I IPBTD:I ELEVATION: IWD: PRESENT PERFS: 0 to 0 Packer Fluid: FROM TO ACTIVITY SUMMARY(Chronologleal order for the last 24 his.) 6:00 7:30 Feesned MN Knight a lersa pressure casing cutter 1/9 518-casing. 7:30 12:00 TIH w/cutter(at a speed directed by KOTs that with prevent alter blades from opening)to 4234'.Laid out sincle. 12:00 18:00 RN Hil,kxp power swivel-NN 11-5M x 7 1116.5M spool w/stripping head.Worked Nru issues to get swivel nooec up and running. V��r 18:00 19:50 MN to state and established parameters,start pumping.had leak on swivel packing.repair same. T' .�� 19:00 20:00 Make nal 04200 rot aIla 100 rpm.tq 1500.4000.final drcuWeng rate 1.75 bpm,560 psi.up wt 5414 do wt 52k /. 8 20:00 21:30 R/d swivel 8 smpper head,flu tongs J 21:30 23:30 POOH,nspect cutter'blades,good indication of first at from markings. \` 23:30 2:00 RIH w/atter V 86',m/u stripper Mad 8 swivel --s? 2:00 3,00 P/u make cel 075(from top of slips)rot at 100 rpm.tq 1800-4000,final osculating rate 2.3 bpm.890 psi 3:00 8:00 Rid swivel 8 stepper head.r/u tongs-B/D internal casing cutter. ACCIDENTS? Job Type Job Type Cap WO Dap 011C Code-Description I PREVIOUS I DAILY I CUM Code-Description I PREVIOUS I DAILY I CUM TANGIBLE COSTS INTANGIBLE COSTS Expeditor $6,840 51.520 $8,380 peak welder $6,300 $700 57,200 5-war catenng 012,948 51404 $14,352 peak cane crew 531.503 53,500 535.000 Art edeen $16,266 $16,288 electrician $1.500 51.500 Tnpdet $11,780 511.780 ICC-CompletionfWorkover E'9 $195,985 $2',560 3217,945 ICC-Power,Fuel 8 Water 545.000 55.300 $50000 boat•cauor4 $54.625 55 375 $60,500 Pathfinder helicopters 519.100 52.200 $21.300 maters nags 513.503 513,503 ICC-Rentals 52.100 5300 52,400 ICC-Rentals•C l 541.223 51,792 $ , ICC-Rentals-42 51.792 $ 1$1,792702 CC-Rentals-5 3 55,600 $440 $6,040 ICC•Rentals•is 4 54.500 5400 $4,900 ICC-Rentals-s5 5529 5.10 $638 ICC-Rentals-a 6 5720 5.20 5940 ICC-Logging 8 Nksc 0reline $3,675 33,679 ICC-Lo9png 8 Misc Wireline-a 1 $2,598 52,598 ICC-Fishing Tools S Services $4,600 514,522 519.122 ICC-Cementing Services 548.030 548.030 ICC-Supernsion/Consuean: 528.800 03,200 832,000 ICC-Completion Overread $33885 52,-19 537,434 ICC-wee Control:rsurance $23.178 53,124 526,302 I GPF lL 4 10 p l6za7z • 315-SSc • HILCORP ENERGY COMPANY DAILY OPERATIONS REPORT REPORT NO. I 10 IDATE: 1 10/2/2015 JOB: 1522358 AN-46 Workover-Convert to Gas Producer � LEASE: WELL: GPF AN-46 AFEIPROJ NO: 1522358 ` /yrs^'` FIELD: Granite Point Field COUNTY/PARISH f API4. I STATE: AK PRESENT OPERATION AT REPORT TIME: [Wet secured as per AOGCC I(]i` - I C(?- DAILY COST: $72.972 CUM.JOB COST: 5759.491 AFE Budget $1,791.850 CUM.DRILL COST: CUM.CMPL COST: Total DEC Cost REPORTED BY: Danny Duckwortll/Harold Soule CONTRACTOR REP: PHONE 907-T76-6754 CONTRACTOR/RIG& LAST BOP TEST: 9/25/20'5 NEXT BOP TEST: 10/2/2015 FUNC DUE: funC:on from remote FLUID: TYPE: OW WEIGHT: 8.4 DAILY LOSS: l I CUM LOSS: ::7.9999 CASING DATA PRODUCTION TUBING SIZE: WT: DEPTH: ID: SIZE/WT/THD: „ GRADE I ID: SIZE: WT: DEPTH: ID: SIZE: WT: DEPTH: ID: , • SIZE: WT: DEPTH: ID: i EQUIPMENT DATA Packer. S¢HDEPTH: NIPPLES: DEPTH: ID: I SCSSV: 1 DEPTH: 110: NIPPLES: DEPTH: ID: I NIPPLES: ll DEPTH: ID: NIPPLES: DEPTH: ID: TBG HD/FLANGE: PROD TREE: SMALLEST ID: I I DEPTH: j IPEITD:I ELEVATION: IWD: PRESENT PERFS: Om 0 Packer Fluid: FROM TO ACTIVITY SUMMARY(Chronological oder teethe last 24 hrs.) MA)Knight lea spear w/8.688 grapple-speared into 9 5/8"casing at casing!mac-attempted to pull cut at 75 with max pull of 160k-worked pipe for 30 mins 6:00 9:00 before decision was made to RE)casing lacks. Released spear and POOH w/same. Broke off PH-6 tb and M/U IF jt on spear. R/D tongs and cleared floor for mounting casing jacks. 9;00 12:00 Rigged up jacks WI studs fastened to 11"x 13 5/8"spool-connected nose and cranked unit-added IF pup to handling jt and latched same.Set sups-tied elevators and slips pulled to 236k and slips on 9 5/8"casing released-pulled cut piece o19 5(8"to surface-dosed bag on 9 5B"and shucked spear. 72:170 1400 12/0 casing jacks and N/D 11".13 518"spool.Speared into casing and pulled same to surface-secured casing and shucked spear.Laid down Knight spear assembly then laid down 37.88'piece of 9 518"casing. 14:00 7600 Began preparing to N/U 2nd dual ram section w/3 1/2 6 9 5/8"ram blocks loaded.Spoke w/Mr.Regg concerning BOPS reconfiguration and emailed diagram of needed BOP stack. Received an email from Mr.Regg/AOGCC to suspend workover operations on AN-46 and secure well.Closed blinds on stack and began focusing on issues 18:00 6:00 Mr.Tomei identified dung his vise last Friday.Rig crew cleaned and organized work area.Cleaned ng tido,do pad eyes on same.bud new fire ext.hangers. blew down all surface lines.installed grating in front of ng engin.Housekeeping 8 nq maintainance. ACCIDENTS? f Job Typo Job Type Cap WO J so 1/V0 Code.Description 1 PREVIOUS I DAILY I CUM Code•Description I PREVIOUS I DAILY I CUM TANGIBLE COSTS INTANGIBLE COSTS EVedrtor 58,360 5760 59.120 peak welder $7.200 5900 58,100 5-star ostenng 514.352 31,404 $15,756 peak crane crew 335.000 33.500 338,500 art edelen $16226 nleanoan $16.286 51,500 $7.500 Tnpo.nt 511,780 $11 780 emewn 315,560 515,580 ICC-CompetionAnorkover Rig ICC-PONT,Fuel&Water 3031-Calleut 4217.9x5 321.960 5238,905 550.000 35,000 555.000 560.500 5$.875 586,375 Path der helicopters321.300 52.200 323.500 Lateral reqs 373.503 $13.503 ICC-Rentals 32.400 5300 02.700 ICC-Rentals-at 543.020 51.792 564,812 ICC-Rentals-a 2 St.792 57 792 ICC-Renals-a3 56040 5440 56480 ICC•Rentals-aa $4,900 $400 055.300 ICC-Rentals-a5 $638 3176 5748 ICC-Rentals-ab 5840 3:20 5960 ICC-Legging&Mac WireNx 53,679 33679 ICC-Logging 8 Mist Wireline-a 1 52.596 52,596 ICC-Fisting Toots&Services 513122 32.200 521.322 ICC-Cemeneng Services 548.030 518,030 ICC-Supernsion/Corwrtam 332029 S3,200 $35200 ICC-Commotion Overhead 537434 43,955 341.389 ICC-Wee Control Insurance 323302 33.296 $29.598 J 1 je P+- s t, i 74z ik4(- • • Pri) I`iZO7Z-v Regg, James B (DOA) From: Daniel Duckworth - (C) <dduckworth@hilcorp.com> 0161 Sent: Thursday, October 01, 2015 3:25 PM To: Regg,James B (DOA) Subject: AN-46 Sundry#315-555 Request for BOP reconfiguration Attachments: Scan0694.pdf ✓ UWE 5ctto i\ Due to well work conditions (pulling 9 5/8" casing)we are requesting a change to our BOP stack to include pipe rams for the 9 5/8" casing that will be pulling. We could not find a single stack so we had to go with a double. We will be ready to pretest/test on our weekly schedule tonight at midnight. SCANNED 4 1 * S ,----- ,, ,,,„(70•,,:t4.1104, ',"11-:,%•'-e,'''A'''', / v ,;,11(,/ l''''' 4 54. 'VA/ A GAnKniu3lawr8p.e5rvoeonatle(r '4'7117'7,711/1:47/ 7,4..k.111'.:1141t141 l' door rams Doublele .541 cameron 13' 8 sty v •3.4r2 rape raMS BOTOOM:95I8 rams 4.8r - '' 1,'•111S!,-'''el'//°.,,/1"./,., ,,/.. do7rams eieros ,v, 'r 8-:40,1:1,7.11.: ,„:1,,e -% •,',,,,,4 13_5,8.5m a varible stylerams 4 4' TOP:2-7/8-5 ...,,,,.m„,,facts‘te,s4..itori soiTom:minds v 467. lr'ler.777,717171/Arr 14 Vk.k1f7"4" rr ',./4triN4,54'%* ' A '',„4, °';/.fi0;1,', 4, ','../ Choke sole -' F---w „,,..., ,,, zgi OAI kill side 3-.118"5°"11CR "A 'i'A r 44,4111,0 V .4t4k/11: ;,., i . 4, 2.00 3,1/8 SM w/HCR 1 . i // Jr, . ,,,, , ' V 13-5/8"5M FE riser " 4 ':' X,0 11 00' trk ip ,• ' _____—> _ '-': I IN 2.001 ' ..,, . . ... A Oh A , I 18., ' . , ,. . , > , a. , - gr IF 1133.-515/8fr SM 2'spacer spool + t " > "5M x 13-5/83M DSA i APIIICiec 464 . QFpiA-rztr>,-- prb 147167z-° /01415 • • e\v/%%'sv THE STATE Alaska Oil and Gas ofT Conservation Commission e sKA. 333 West Seventh Avenue ITh. GOVERNOR BILL WALKER Anchorage. Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 SCOW DEL. 2. I ZO15 www.aogcc.alaska.gov Trudi Hallett c� Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Granite Point Field, Middle Kenai Oil Pool, Granite Pt St 18742 46 Sundry Number: 315-555 Dear Ms. Hallett: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this f 0 day of September, 2015 Encl. • • RECEIV SEP 08205 STATE OF ALASKA 0755)//‘ 1 IS ALASKA OIL AND GAS CONSERVATION COMMISSION AOG(+c APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations 0 . Fracture Stimulate ❑ Pull Tubing 0' Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing 0 Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool 0 - Repair Well 0- Re-enter Susp Well ❑ Other: Convert to Gas Producer s 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC . Exploratory ❑ Development ❑ 182-072 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic C] Service 0 6.API Number: Anchorage,AK 99503 50-733-20355-00 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055(a)' Granite Pt St 18742 46 Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0018742 • Granite Point Field/Middle Kenai 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): 9,455 - 9,124 8,180 7,903 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 625' 20" 625' 625' Surface 4,232' 13-3/8" 4,232' 4,206' 2,730 psi 1,130 psi Intermediate Production 8,332' 9-5/8" 8,332' 8,050' 7,510 psi 5,600 psi Liner 1,334' 7" 9,455' 9,124' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8,330-9,324 • 8,048 8,999 3-1/2" 9.3#/N-80 8,199 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker Model Fl Packer 8,187'(MD)7,910'(TVD) 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ tvelopmenl 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 9/20/2015 OIL ❑ WINJ ❑ WDSP❑ Suspended El 16.Verbal Approval: Date: GAS 0- WAG ❑ GSTO❑ SPLUG LI Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett Email thallett(ahilcorp.com Printed Name Trudi Hallett Title Operations Engineer Signature rt`h�.(� Phone (907)777-8323 Date 9/8/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so thattha representative may witness Sundry Number: 31 - 555 Plug Integrity ❑ i- BOP Test - /�Mechhaanical Integrity Test ❑ Location Clearance ❑7 Other: �t �f� /'c � . ( �A �7 - L 3 C�3 r S- Spacing Exception Required? Yes ❑ No g/ Subsequent Form Required: /Q•^ 9 0`i /(295). �� / APPROVED BY Approved by: /�—'yLn COMMISSIONER THE COMMISSION Date: g-7 -/ 74., x_1`1 —t Iiiii - SEP 21 2015 ORIGINAL2c ,/-k�RB�M S t Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of appro a� 1. Attachments n Duplicate • • Well Work Prognosis Well: AN 46 Hileorp Alaska,LLC Date: 09/08/2015 Well Name: AN-46 (Granite Point API Number: 50-733-20355-00 State 18742-46) Current Status: SI Injector Leg: Leg#3 (South) ANr"" Estimated Start Date: September 20, 2015 Rig: Moncla 404 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 182-072 First Call Engineer: Trudi Hallett Office:907-777-8323 Cell: 907-301-6657 Second Call Engineer: Ted Kramer Office: 907-777-8420 Cell: 985-867-0665 Current BHP: 2500 psi @ 8,537'TVD (8,840' MD) Max. Expected BHP: 2500 psi @ 8,537'TVD (8,840' MD) Max.Anticipated Surface Pressure (MASP) 1238 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) and adjusting to the approximate new top perf based on 1560 psi @ 3220'ND. Brief Well Summary AN-46 is a shut-in injection well with communication between the 9-5/8" and 13-3/8" annulus at the proposed completion depth. This project will plug current perforations within the C sands, cut and pull the 9-5/8"casing, and re-complete uphole as a gas well. ! eoqir � N . 03 Well Work Procedure: 1) RU over AN-46. 2) Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 2,500 psi HIGH. 3) RU Eline. PU on injection string and cut in first full joint above seal assy @ ±8,167'. POOH, LD tubing. 4) PU 3-1/2" work string and RIH with bit/scraper 9-5/8" CO assy to TOL. POOH. 5) RIH with CRET and set just above liner lap @ ±8,110'. 6) RU cementing equipment and pump tligt bbls Class G cement into CRET and squeeze into 7" et liner to plug existing perfs and isolating liner hanger. `r` ` 7) PU above CRET and spot an add'I ±3 bbls cement on top_of CRET @ ±8,110' to put TOC @ ±8,090'. PU WS, circulate,WOC. --� % 4 I5e1) 8) PU storm packer, RIH set same at 200' and hang off string. Pressure test to 2,500 psi and chart. 9) Release from storm packer, POOH. ND tbg head. Re-Rig BOPE. 10) Test all flange breaks to 2,500 psi and chart. 11) RIH, engage storm packer, release same, POOH, LD same. 12) PU and RIH w/9-5/8" casing cutters on 3-1/2" WS and tag to confirm TOC. 13) PU to ±4,200'. Cut and pull 9-5/8" casing from 4200'. LD same. 14) Run bit and scraper in 13-3/8" to top of 9-5/8" casing at±4,200'. 15) Set CIBP at±4,180'and dump±20' cement on top. r.s 3��,,,,F, 473UP s� tr, 16) Pressure test 13-3/8"to o ps(tharting for 30 minutes.--' 17) Run GR/CBL/RST log in 13-3/8" casing from ±4,150' to surface. 18) PU storm packer. RIH and set same at 200' and hang off string. Pressure test to 500 psi and chart. 19) Release from storm packer, POOH. 20) Install 13 5/8 3M x 13 5/8 5M completion spool on top of casing spool. • Well Work Prognosis Well: AN 46 Hilcorp Alaska,i.i.c Date: 09/08/2015 21) Test all flange breaks tosi and chart. RIH, engage storm packer, release same, POOH, LD storm packer. 22) Run 3-1/2" completion and set packer @ ±3,120'. �� 23) ND BOPE, NU tree,test same. i leer I� '2? 24) RU Wireline to swab well down and perforate per log. 25) RD Wireline. J` 26) Turn well over to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Stack lti • • Granite Point Field Well: Granite Pt St 18742-46 Schematic Last Completed: 04/29/1987 Hilcorp Alaska,LLC c API: 50-703-20355-00 PTD: 182-072 RKB:MSL=105' \—/i CASING DETAIL 2 XO, Size Wt Grade Conn ID Top Btm Comments 3 20" [ [ 1 20" 94.0 K-55 19.124" Surf 625' 1,500 sacks Class G 4 54.5 K-55 12.459" Surf 1575.5' 13 3/8" 68.0 K-55 12.415" 1575.5' 2,704.4' 2,555 sacks Class G 13-3/8" 72.0 L-80 12.347" 2,704.4' 4,232.2' 47.0 S-95/N-80 8.681" Surf 1,142.0' 40.0 S-95 8.835" 1,142.0' 1638.7' 9-5/8" 43.5 S-95 8.755" 1638.7' 4,337.6' 675 sacks Class G 47.0 5-95 8.681" 4,337.6' 6,225.5' 53.5 S-95 8.535" 6,225.5' 8,332.4' 29.0 N-80 6.184" 8,121.3' 9,272.0' 7 305 sacks Class G 29.0 S-95 6.184" 9,272.0' 9,455' TUBING DETAIL DSS5 3-1/2" 9.30 N-80 HTC Surf 8,199' JEWELRY DETAIL Depth Depth No (MD) (TVD) ID Item 1 33.3' 34' 10"Cameron DCB Single SS Tubing Hanger 2 35' 35' 3-1/2"DSS end 3-1/2"Buttress XO Calculated 3 45' 45' 3-1/2"DSS Pup TOC 6,003' 4 55' 55' 3-1/2"DSS Pup 5 8,182' 7,905' 3-1/2"DSS-HTC Tubing 6 8,187' 7,910' 3-1/2"DSS Pup 7 8,187' 7,910' Baker F Packer w/Locator and 10'Seal Assembly 8 8,199 7,922' Muleshoe 8,213'4Holes 6- No Cement Bond 07/30/82 7 8C-4PERFORATION DETAIL Top Btm Top Btm Comments 9-5/8" Zone FT SPF Date Status (MD) (MD) (TVD) (TVD) C-4 8,330' 8,374' 8,048' 8,091' 44' 4 2-1/8"Enerjet,0 Phase 8/11/82 C-5 C-5 8,458' 8,518' 8,171' 8,229' 60' 4 2-1/8"Enerjet,0 Phase 8/11/82 C-6 8,551' 8,596' 8,260' 8,303' 45' 4 2-1/8"Enerjet,0 Phase 8/11/82 8,840' 8,878' 8,537' 8,573' 38' 4 2-1/8"Enerjet,0 Phase 8/11/82 C-7 8,950' 9,017' 8,642' 8,706' 67' 4 2-1/8"Enerjet,0 Phase 8/11/82 9,056' 9,077' 8,743' 8,763 21' 4 2-1/8"Enerjet,0 Phase 8/11/82 C-6 9,198' 9,226' 8,879' 30' 4 2-1/8"Enerjet,0 Phase 8/11/82 C-8 9,246' 9,296' 8,925' 8,972' 50' 4 2-1/8"Enerjet,0 Phase 8/11/82 9,304' 9,324' 8,980' 8,999' 20' 4 2-1/8"Enerjet,0 Phase 8/11/82 = C-7 7' C-8 Notes a 11 PBTD=9,365' TD=9,455' Updated By:JLL 08/13/15 • Granite Point Field Well: Granite Pt St 18742-46 H • PROPOSED Completed: Future ffilcorp Alaska,LLC API: 50-703-20355-00 PTD: 182-072 RKB:MSL=105' CASING DETAIL 1 Size Wt Grade Conn ID Top Btm Comments -ammo 2 20" 94.0 K-55 19.124" Surf 625' 1,500 sacks Class G 1 WI 54.5 K-55 12.459" Surf 1575.5' 13-3/8" 68.0 K-55 12.415" 1575.5' 2,704.4' 2,555 sacks Class G 72.0 L-80 12.347" 2,704.4' 4,232.2' 3 ag 4 9-5/8" 43.5 S-95 8.755" ±4,200' 4,337.6' 675 sacks Class G III 5 47.0 S-95 8.681" 4,337.6' 6,225.5' 53.5 S-95 8.535" 6,225.5' 8,332.4' 4ii111 6 7„ 29.0 N-80 6.184" 8,121.3' 9,272.0' 305 sacks Class G 29.0 5-95 6.184" 9,272.0' 9,455' 13-3/8" TUBING DETAIL I ► r43. _ 3-1/2" 9.30 L-80 Supermax Surf ±3,170' 3-1/2" 9.30 N-80 DSS-HTC ±8,170' ±8,199' JEWELRY DETAIL Depth Depth No (MD) (TVD) ID Item 1 33.3' 34' Tubing Hanger 2 ±300' ±300' SSSV 3 ±3070' ±3068' Chemical mandrel 4 ±3120' ±3118' 4.00" ASI-X 13-3/8"Mechanical Packer Calculated 5 ±3170' ±3168' EOT TOC 6,003' 6 ±4180' ±4156' CIBP w/Cement plug 7 ±8110' ±7834' CRET w/Cement plug 8 ±8170' ±7894' Top of 3-1/2"tbg 9 8187' 7910' Baker F Packer w/locator and 10'Seal Assembly 10 8199' 7922' Muleshoe 8,213'4Holes PERFORATION DETAIL 8 No Cement 9 Bond07/30/82 Zone Top Btm Top Btm (MD) (MD) (TVD) (TVD) FT SPF Comments Date Status _ 10 -- ±3,222 ±4,000 ±3,220' ±3,877' ±778' 6 Interval will be based Future Proposed on logs C-4 C-4 8,330' 8,374' 8,048' 8,091' 44' 4 2 1/Sphaserjet,0 8/11/1982 Plugged 9 5/8 f C-5 8,458' 8,518' 8,171' 8,229' 60' 4 2-1/8"Enerjet,0 8/11/1982 Plugged Phase C-5 C-6 8,551' 8,596' 8,260' 8,303' 45' 4 2-1/8"Enerjet,0 8/11/1982 Plugged Phase 8,840' 8,878' 8,537' 8,573' 38' 4 2-1/8"Enerjet,0 8/11/1982 Plugged Phase C-7 8,950' 9,017' 8,642' 8,706' 67' 4 2-1/8"Enerjet,0 8/11/1982 Plugged Phase C� 2-1/8"Enerjet,0 9,056' 9,077' 8,743' 8,763 21' 4 Phase 8/11/1982 Plugged 9,198' 9,226' 8,879' 30' 4 2-1/8"Enerjet,0 8/11/1982 Plugged Phase C� C-8 9,246' 9,296' 8,925' 8,972' 50' 4 2-1/8Phaser�et 0 8/11/1982 Plugged 9,304' 9,324' 8,980' 8,999' 20' 4 2-1/8"Enerjet,0 8/11/1982 Plugged Phase 7' ,• - C-8 • 11 PBTD=9,365' TD=9,455' Updated By:TRH 09/08/15 • • , Anna Platform An-46 Current 08/14/2015 H lenrl: IL•.,:kn.1.l.t, An-46 Tubing hanger,CIW-DCB-FBB, 20X133/8X95/8X 11X3'/:EUElift X3%:BTC susp, 3'/ w/3"type H BPV profile, Stainless Steel Material BHTA,CIW,3 1/16 10M FE X External Acme knockup r r-wr 1.1 I 1.1 IR Valve,swab,CIW F, � 3 1/16 10M FE,HWO, FF trim 4 N / :i t:. Valve,lower master,CIW-F, " Prat`' 3 1/16 10M FE,HWO, FF trim - �4 Adapter,CIW,11 5M FE X [n1 ��- ..� fril3 1/16 10M Stdd,6''A slick MIN neck pocket Tubing head,CIW-DCB, :nil . uin13S/83MX115M,w/2- it — III 2 1/16 5M SSO,X-bottom Valve,CIW-F,2 1/16 5M FE, pfepitp - Azf 7 `. HWO Qty 2 III I WI In ;i: Casing spool,CIW-WF,21'/.2M X 13 5/8 3M,w/2-2 1/16 5M ISI r III Valve CIW-F,21/165MFE, EFO,X bottom prep 3 � '- O HWO 1 •III nl e 1......" Casing head,CIW-WF,21''/.2M X I'I SOW,w/2-2 1/16 2M EFO .I. IRI 1I5I Valve,ClW-F,21/162MFE, HWO IIIrJ( : In-b.1 a-- • • 11 Anna Platform An-46 Proposed Ilihi,rp nia.ka.1.11, 08/14/2015 An-46 Tubing hanger,Seaboard SM-E- 20X133/8X3''A CCL,135/8x3'EUE 8rd lift and susp,w/3"type H BPV profile,3- 'A"npt control line ports,DD specs BHTA,Bowen,3 1/8 5M FE X 3"Bowen top II .n 'II Ii.• Valve,swab,WKM-M, 61 31/85MFE,HWO, ti ® o®, DD trim ,® ,..111111111.... Valve,WKM-M,3 1/8 5M FE,w/ 15"OMNI operator 111 - • Li . �ii Valve,upper master,WKM-M, , 3 1/8 5M FE,HWO, r (O 4.1 DD trim ®®® ! Valve,lower master,WKM-M, 3 1/8 5M FE,HWO, DD trim Completion Spool, - paiSa Seaboard-S,13 5/8 3M x ' I j EUU 13 5/8 5M top,prepped for drift of 13 3/8 casing 11 1 . ail at Casing spool,CIW-WF,21 Y.2M III ISI Valve CIW-F,2 1/16 5M FE, X 13 5/8 3M,w/2-2 1/16 5M - _ E ;f fn111111. L ? HWO EFO,X bottom prep III �IIII 4. Iii I III - at IN .F Casing head,CIW-WF,21'/.2M X — '9 SOW,w/2-2 1/16 2M EFO I I I �j IRI Valve,CIW-F,2 1/16 2M FE, 1 � ,y CSD HWO Btit Stack Moncla 02/25/2015 III!rnrp;11auk;i.Lia 2015 Workovers BOP Drawing Moncla 5• Tt 4.54' Hydril4 GK 13 5/8-50aMill tit IiI III til lit III 111 111 III IP 4.67' Cl U _ 2 7/8-5 variables or Cameron • Ail 16. Edual flex rams 11! y - Blinds til III Iii lit 1111 air Kill Side ISI Ingt i■I ,,r Choke side 2.00' OI1MJii::i: I1 ;3 1/8 5M w/HCR 3 1/85Mw/HCR - r 1.00'to 2.00' to aim,I!' In Drill deck 11.00' Riser 13 5/8 5M FE X 13 5/8 5M FE lit iii til III Iii III III III I!I III 2.00 Spacer spool III 13 5/8 5M FE X 13 5/8 5M FE til tillil HI Iii • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LEA, Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve, or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand, or MU landing (test)joint to lift-threads d) For ESP wells- Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr.Jim Regg (AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure • • Moncla Rig 404 BOP Test Procedure Hilrorp Alaska,i.r.c Attachment#1 c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure (floor valves,gas detection,etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile /penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-1 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. • . Moncla Rig 404 BOP Test Procedure flacm,,Alaska,i�.c Attachment#1 d) Open C-1. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves,to 250 psi low and 3,000 psi high,for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. ii) Valves, 3,4, 9. After test, open valves 3&4. Leave 9 closed. iii) Valves 5, 6,9. After test,open valves 5&6, leave 9 closed. iv) Valves, 7, 8,9. After test,open all valves. e) Close C-2. This is the HCR (the hydraulic controlled remote)valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test,open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test K-1, K-2, and K-3 on the kill (pump-in) side by pressuring up on tubing.Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre-charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/-3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual" so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • • ai c in 0 o c) 0_ N .y Is c m w .� E p al es v �, — colo — 03 c� ) SSte " 3 30 °o o _ = m o n •. a� a� a c0- Q 113 o w p c CMI 1. N W G) N ca a) _c O N N 3 a) (Ni aa))co o0o E c as o Q ▪ V a) `� o .c 3 i c4- "0O •N OY cn Q ao v .� c c`o o co a) C C M a) _0 m a) G) Z c �'0 O .5 `� c `- o -0 C) c d C = a) N o 0 Q W C d _C •_ 0 (0 ,.. 3 — -- tea) a) ..a a) U C N 72 Q `p co _c N .(' m (0 M •V C Et m N it .cn ' Z O N co CU a) 0 N •N m N Z Q 4- 4-, a) Q. (Z' a) 13 a) m a•� C.) Q a) .-. -p C O C N a) N F- QD F- Eod W 1- ? co M LO CO N U 0 ro 0 o ct Q a N 0 Z a N Q J cc N-,a N > N co N- 1- V a Z , cc O a z p Z d I d/' Z Q N o o � r Q N CO 1Y re M .1- V cc Ch CONJ 0sj M 1 �mNI CL Q �� N- N CC m ° m - CO Q COCD CO •• V Q Q Q !' o Q if 1\ CO 0 co A ■ m cc Q aiff Z Q _co N L� I a a �+ z� � ■ � Co :j ' • 'A 2 Q� b � "All.17.— _, • 1111 r ii u N �:( ' l‘< 11\-. CZ)cc N N �!� EL ft W •. ■ N V J V N -g ix if a r2 (n ++ � VCC QNW 0 To N a } V a' m m NFd m m Q 1• MO 7 G' u O O c�Cc) th N r� Q .�`�. ■ Na Q a 01 N 1 CO Z m m z r co < o Q Q t O Ce - co N Q Q CV - Q •` a N_ - Z O Z N Z , M Q `n Q Q a a m Q M Z Q , 00 1— etw M m ¢ . Q Q 10 z Lo ti Qc Z Q Q M O CO J r < u - - Q Z O U 0 co Q .. Q Q ZQ Lo COLO CV Q._ r- • Bettis, Patricia K (DOA) From: Trudi Hallett <thallett@hilcorp.com> Sent: Wednesday, September 09, 2015 1:48 PM To: Bettis, Patricia K (DOA) Subject: RE: Granite Pt St 18742-46: Sundry Application Attachments: Granite Pt St 18742-46 Spacing Excep Review.pdf Hi Patricia— Please let me know if this is sufficient. Thanks- Trwokv From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Wednesday, September 09, 2015 10:16 AM To: Trudi Hallett Subject: Granite Pt St 18742-46: Sundry Application Good morning Trudi, Please submit a spider map that shows the proposed Granite Point Field, undefined Gas Pool perforation intervals for Granite Pt St 18742-46 along with perforated intervals in surrounding wells that are open to this undefined gas pool, regardless of whether those wells are currently on production or suspended. 20 AAC 25.055(a)(4). If a well is P&A'd, or if the perforations within the undefined gas pool have been squeezed and said well is recompleted in a different pool, this needs to be noted. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, September 09, 2015 10:16 AM To: Trudi Hallett (thallett@hilcorp.com) Subject: Granite Pt St 18742-46: Sundry Application Good morning Trudi, Please submit a spider map that shows the proposed Granite Point Field, undefined Gas Pool perforation intervals for Granite Pt St 18742-46 along with perforated intervals in surrounding wells that are open to this undefined gas pool, regardless of whether those wells are currently on production or suspended. 20 AAC 25.055(a)(4). If a well is P&A'd,or if the perforations within the undefined gas pool have been squeezed and said well is recompleted in a different pool, this needs to be noted. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettisPalaska.gov. 1 • • Roby, David S (DOA) From: Jeff Allen <jallen@hiicoro.com:, Sent: Friday, September 11, 2015 8:11 AM To: Roby, David S (DOA) Cc: Ted Kramer. Larry Greenstein;Juanita Lovett;Trudi Hallett Subject: RE: Sundry application for GP St 18742-46 (PTD 182-072) Mr. Roby, We are not proposing to return the well to injection because we do not believe that the AN#46 is a key injection well. The prior operator did a good job of flooding the top of the structure and we believe that the opportunity for further water injection is on the flanks of the structure. The AN 50,AN 51,GP 32-13RD,GP 54,and GP 42-23RD were all drilled in the mid 1990's and found the flanks of the structure to be oil bearing and at original saturations. We are currently evaluating lateral injectors to provide support to these wells and increase recovery on the flanks. The lateral wells will allow us to inject more water at a lower injection pressure in these relatively tight formations. The AN#46 workover allows us to test the shallower zones for gas and if successful should set up 1 to 2 drill wells for next year to further delineate these reservoirs. We believe that the potential for gas is very high and will serve to extend the field life as well as allow us to capture a new resource from Granite Point field. Thanks, ( G '1 Jeff Allen , Reservoir Engineer ,4 . f74 Hlcorp Alaska, LLC 0:(907)777—8440 C: (281)883—9720 From:Trudi Hallett Sent: Wednesday, September 09, 2015 4:39 PM To: Jeff Allen Cc: Ted Kramer; Larry Greenstein;Juanita Lovett Subject: Fwd: Sundry application for GP St 18742-46(PTD 182-072) Jeff-Could you please address Mr. Roby's questions and concerns below. Let me know if you need anything from me. Thanks! Trudi Sent from my iPhone Begin forwarded message: From:"Roby, David S(DOA)"<dave.roby@alaska.gov> Date:September 9, 2015 at 4:29:28 PM AKDT To:"thallett@hilcorp.com"<thallett@hilcorp.com> Subject:Sundry application for GP St 18742-46(PTD 182-072) 1 • • Trudi, I'm reviewing the reference sundry application and have a couple of questions for you. First, in reviewing our files for this well there is some conflicting information and I was hoping you could clear things up for me. When the well was shut in in 1995 our records indicate it was injecting approximately 800 BWPD,yet the most recent submittal in our file,which was received from Unocal in 2005,stated the well was shut in due to an inability to pump into the formation. Prior submittals indicated that the well was a key injector and they were looking to return it to service after a failed MIT. Can you please clarify what the current state of the well is and whether or not it could be repaired and returned to service? Second, if it can be repaired and returned to service why are you proposing to recomplete this well as a gas well in a shower zone instead? Thanks, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 2 • • PTU / S2 - C - Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Friday, September 11,2015 2:31 PM To: Jeff Allen Cc: Larry Greenstein; Schwartz,Guy L(DOA);Wallace Evans Subject: Anna Well 46 Shallow Tyonek Sands Test Flaring Follow Up Flag: Follow up Flag Status: Flagged Jeff, Thank you for the explanation. Approval is granted to flare for up to 10 days and up to 15 MMSCF for the purpose of testing the Anna Well Shallow Tyonek Sands. If additional time is needed for the testing or if flaring of additional gas production is anticipated, please notify me and we will revisit. Please report the gas flaring on the Monthly Gas Disposition Report, Form 10-422. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer SCANNED State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppa laska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Jeff Allen [mailto:jallen@hilcorp.com] Sent: Friday, September 11, 2015 8:29 AM To: Loepp, Victoria T(DOA) Cc: Larry Greenstein; Schwartz, Guy L(DOA); Wallace Evans Subject: RE: Anna Well 46 Shallow Tyonek Sands Test Victoria, 1) We expect rates to be between 500 MCFD and 5 MMCFD. This will be the first gas test from the Anna platform and very little is known about the reservoir permeability. 2) Anna platform is not currently set up to handle high pressure gas. If the testing does prove that the reservoirs are gas bearing we will need to reactivate the LEX plant at Granite Point Tank Farm as well as provide compression to get it into the sales pipeline. We are planning on producing the well through the test separator and taking it to flare. 1 • 3) We are requesting 10 days tallow for any issues while testing the well, length of the test will depend on the reservoir deliverability. If the well produces at rates over 3 MMCFD the test can be concluded in as little as 2 days but since this will be the first test on Anna there is a large amount of uncertainty regarding perm and tank size. 4) We will get pressure data before we flow the well and once we produce^'5 MMCF of gas we will shut the well in for a PBU. This will allow us to get an idea of perm,skin,as well as a very coarse indication of OGIP. We have asked for permission to flare more than 5 MMCF in case we have any problems with hydrate formation or separator shut downs during the test procedure which may require us to restart the testing. We believe that this test provides for the minimum amount of flaring as determining OGIP from flowing material balance would likely require us to produce for over two weeks. Thanks, Jeff Allen Reservoir Engineer Hilcorp Alaska, LLC 0: (907)777—8440 C: (281)883—9720 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp(aalaska.gov) Sent: Thursday, September 10, 2015 2:34 PM To: Wallace Evans Cc: Jeff Allen; Larry Greenstein; Schwartz, Guy L(DOA) Subject: RE: Anna Well 46 Shallow Tyonek Sands Test Please provide a proposal for testing/flaring for approval including in the description: 1. Daily rates expected 2. Setup, why flaring 3. Why 10 days is needed vs a shorter test period 4. Measures taken to minimize flaring You may do this via email. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(c�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoa@alaska.gov 2 • • From: Wallace Evans [mailto:wevans@ihilcorp.com] Sent: Friday, September 04, 2015 8:25 AM To: Loepp, Victoria T(DOA) Cc: Jeff Allen; Larry Greenstein Subject: Anna Well 46 Shallow Tyonek Sands Test Victoria, I wanted to give you a heads up on a planned flaring event that is going to happen on the Anna platform in approximately 2-4 weeks. The team plans to test Anna well 46 in the shallow Tyonek sands at the Granite Point field for gas. They anticipate flaring up to 25MMcf over a 10 day period. The testing will allow them to determine if the resource is actually there and what the size potentially is. Once these questions are answered the well will be shut in until it is ready to flow to sales. Please let me know if you have any further questions for the team. Thank you Wally Evans Air Quality Environmental Specialist Hilcorp Alaska Inc. 3800 Centerpoint Drive suite 1400 Anchorage,Alaska 99503 Phone: (907)777-8394 Fax: (907)777-8560 3 Ima.~Project Well History File Cove~ ~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J <L~- (~ ~_ Well History File Identifier Organizing .~do~) RESCAN [] ~olor items: ff/"~'~Yscale items: ~ Poor Quality Originals: [] Other: NOTES: ~d DIGITAL DATA [] Diskettes. No. [] Other. No/Type OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) ~ Logs of various kinds ~ther BY: BEVERLY ROBIN VINCENT~ARIA' WIelDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL' 'MARIA WIND~ DA Scanning Preparation Is~ ~si TOTAL PAGES BY: WINDY DATE: - · /S/ BEVERLY ROBI SHERYL MA~A Production Scanning Stage 1 PAGE COUNT FROM SCANNED FLEE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: y YES NO .y: BEVE LY '"CEN ' MA.,A W, ND Y DATE: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO · BY; BEVERLYH,s ,o~ROBINu~LSSS S~EC,~.VINCENAITr~N~RIA WINDYI~ DATE:~///~/~)~.~~.-. / /S/ RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IS/ General Notes or Comments about this file: Quality Checked (done) 12110/02Rev3NOTScanned,wpd ) Unocal Alaska ResourG ) Unocal Corporation 909 West 9th Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCALfi r:;'1;:7.: (~. E 1\)" E C' ·~'=~r.J- t~ September 6,2005 ~~._ Ot.~ & Gii ~'Ji. ())j\Wfa~:fíkn ~~~'!:~~':)f:$~~ Hal Martin Reservoir Engineer .L" "'~"'l>-'\t;"\C\'.. ,,~~~s. ~Sj \)'\ Q:)'~'5~·\CA¡'t.:\" '<..~'t~\c.~ "ðV'è ~ Io~ ~ '>~ , f.li~- ... ~l, '-(: Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 ASSESSMENT OF WELL UTILITY GRANITE POINT 18742 WELL NO. 46 I PERMIT NO. 182-072 SUNDRY APPROVAL NO. 302-399 ANNA PLATFORM GRANITE POINT FIELD (1", '~:"j:!t.~\'¡It..~~~) (~))ED 1 ~1 ?OU~~ \:Ji \t.;f Ii 1\ tl I~ ~ ~j 8;J". "., ,-, Dear Tom: In response to a request by the AOGCC on a Sundry Approval (No. 302-399) for Granite Point 18742 Well No. 46 (Permit No. 182-072), Anna Platform, Granite Point Field, Chevron submits the following information concerning an action plan for this well. Anna Well No. 46, an injector which was shut-in in July 1995 due to an inability to pump in to the formation, will continue to be considered as a future workover candidate. 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)263-7675 if you have any questions. Sincerely, a-L~ ' Hal Martin JHM:jll Attachments O:\OOE\OOE Fields\GP F\An na\ W ells\An-461 nj\State _Fonns\Correspondence\An~46 Sundry Response SepOS.doc UNION OIL COMPANY OPERATED PROPERTIES WELL DATA FIELD MimK::m¡;í8'f4Ïf.;if.r~~,;~~~ SUMMARY JíiIUJ~~·ri(~~~.I.t~~; fBR1i~~~~r!m·i·~":1Jtf IBkt}(ZK~fï14~~~~~:J.1 SUMMARY TRÃØINCIiÄ-~·J(i.œör.€MÖ~ÒP.ö~ ., ~..;~ " SUMMARY WELL 17 46 52 27RD 9 NO WELLS ·.m!ll:':;)~ 5RD 5 6 10 12RD 14 16 18 31 34 40 NO WELLS ~fiIB A-4 A-5RD2 S&L A-I0S&L A-12RD A-23 S&L A-26 A-30 NO WELLS - Information for AOGCC on Shut-In Wells Reg 20 ACe 25.115 DATE Mechanical Condition SHUT-IN Jul-95 Bad Casing Ju1-95 Communication between tubing/casing Ju1-95 Colapsed Casing lul-92 Communication between tubing/casing Mar-89 Leaking Bottom hole assembly May-86 No known damage Apr-88 No 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 ColIapsed Casing May-98 Tubing plugged up with paraffin lul-86 No known damage Apr-83 Collapsed casing Apr-84 Failed MIT, Fish in tubing lun-86 Collapsed casing Jun-78 Communication tbglcsg îOct-95 No known damage Page 3 Why well was Shut-In Won't take water Won't take water Low Production Won't take water High water production No injection on platfonn No Production No injection on platfonn No injection on pIatfonn Produced water 100% water production No injection on platforin Poor perfonnance, uneconomic. Lost production after casing collapsed Extreme paraffin problems Both strings quit taking water Producing Coal Failed MIT Producing Coal Failed MIT, tubing obstructions Water production due to WF breakthrough 1/4 ;/ ~ /¿;j A/LCLmtl - _ ~ Future Utility of Well Potential cleanout and return to injection Potential WO candidate Potential redrill candidate Potential for Coil tubing clean out. Potential redril1 candidate .-' Potential conversion to a producer. Potential redrill for Tyonek. Poetential redrilI candidate to Hemlock Potential redrill candidate Possible conversion to a producer. Under evaluation Potential redriD candidate Potential for Workover. Potential to redrilI to Tyonek or Hemlock. Potential conversion to gas producer. Potential redrill candidate for gas well. ~ Potential gas producer or redrill for oil Potential to add perfs & return to injection. Potential redrill for Hemlock Injection. Potential to return to Injection. Potential to shoot upho1e gas Potential to reactivate with a variance. Potential to convert to B-Zone Injector. Download_SteYeMcMaines.XLSShuUn_ We1LStatus UNION On. COMPANY OPERA TED PROPERTIES WELL DATA FIELD _WELL -. ,J..,- J - 3RD 5 9 17 27RD 29 37 46 52 SUMMARY NO WELLS JI1IR~ ~1:~~~~. ' ,_.~--, ~~~ r ~f~r';;.~t~ ~~'~~.'~- -=~r: 5RD : .~<' ;; i '-II.:'; ~ ~ Æ, - ~ -;';;:;~ ~ 5 !_j)J:-~' , __'_ _____ ;"'"-f,~0... . _, 6 10 12RD 14 16 18 31 34 40 SUMMARY NO WELLS Information for AOGCC on Shut-In Wells Reg 20 ACC 25.115 DATE Mechanical Condition SHUT-IN Why well was Shut- In Sep-97 No known damage. Low oil production. Dec-02 No known damage. Low oil production. Mar-89 Leaking Bottom hole assembly High water production Jul-95 Bad Casing Won't take water Jul-92 Communication between tubing/casing Won't take water Nov-02 No known damage. Will not take water. Apr-02 Casing leak. Failed MIT Jul-95 Communication between tubing/casing Won't take water Jul-95 Colapsed Casing Low Production May-86lNo knoWn damage Apr-88 I No 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 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 Page 4 1&_ ~~/ I/;~% 02; ATIAC.NVl ~. Future Utility of Well Possible conversion to injection. Possible conversion to injection. Potential redrill candidate Potential clean out and return to injection Potential for Coil tubing clean out. Possible restore injection. Possible restore injection. Potential WO candidate Potential redrill candidate -' IPotential conversion to a producer. IPotential redrill for Tyonek. ''Y Poetential redrill candidate to Hemlock Potential redrill candidate Possible conversion to a producer. Under evaluation Potential redrill candidate Potential for W orkover. Potential to redrill to Tyonek or Hemlock. Potential conversion to gas producer. Potential redrill candidate for gas well. W elCCouncShucIn_Status_2004_Complete.XLSShucIn_ Well_Status UNION On. COMPANY OPERA TED PROPERTIES WELL DATA FJELD '*_,,'I!_\.:... _'¿'cf~J~ ~"..~r~/-,I .'": SUMl\1ARY WELL 3RD 5 9 17 27RD 29 37 46 52 26 NO WELLS : - )[1. -- Information for AOGCC on Shut-In Wells Reg 20 ACC 25.115 DA TE Mechanical Condition SHUT-IN Why well was Shut-In Sep-97 No known damage. Low oil production. Dec-02 No known damage. Low oil production. Mar-89 Leaking Bottom hole assembly High water production Jul-95 Bad Casing Won't take water Jul-92 Communication between tubing/casing Won't take water Nov-02 No known damage. Will not take water. Apr-02 Casing leak. Failed MIT Jul-95 Communication between tubing/casing Won't take water Jul-95 Colapsed Casing Low Production Jan-03 9-5/8" to 13-3/8" Casing Comm. Mechanical Integrity Probllem Page 5 f!5 6?f/'j;) 6' / "(,/JO- ATTACHMENT 1 // // . ~. Future Utility of Well Possible conversion to injection. Testing for conversion to injection - 12/04. Potential redrill candidate Potential cleanout and return to injection Potential for Coil tubing clean out. Possible restore injection. Possible restore injection. Potential WO candidate Potential redrill candidate Possible Workover Candidate J V_' ./ ~ WelLCouncShucln_Status_JanOS Rev .XLSShuCln_ W elLStatus f!:. "',.114 O!tct: Spud DaW Surfaoe to.loru SubIurfaoe Locdon: ElevatIon: 1Dt P80Ì Ca1nt: Perf~.: initiai lnJ-tlont initial stlmufatlem "....voIr D9ta\ eor.d Int8I'II01I: osr lntwYat. and Reeulta: Lot ~...... y¡ mwmz POINT ADL 11148 au. NO. ... IØDDLI KØJI SØDS PLUTORK AHIU. 112M2 a..t 3. Slot t. Q. P. P!iI~f.. Anne 121' fHt. m' FD. Sea. t2. naN, Rt 2W. s.M. 10 - ,... FNt. 2212P1L. Seo. 12. TtON, IUft. SaU. 105' ICI-USI. Mal' 1\1J: It24' '30' 1Wz t03'r 20" .., 1C-5S CoIhI Nt at '15' wilt t~ IX. otment 13 W. 721 N-IO, 14, '1. and Uf K-55 Cell.... Nt at 423r """ UOS .. Dt.,.ad I ~. 40. a.s. 47 and S3.5f s-es c.Int let at e»r wfth .75 IX. Utr-Int r. 21' N-IO and 1-.5 ...... Nt ot '121-'451' Set .. 305 .. OI_...."t C-4: 11330-1374' C-Ss I4N-Utr C-I: 1551-lSIr C-7s 1840-11".. ..50-lOt .,. t058-t01r c-a: '111-1228" t24&-12M' .304-.324' 2l7l11PD et 5SOO .... AnnuIut "...,.. 3000 '" Nane None None SonIa. Dual""""" ~I......: Ray SP ~-'45S' c.m.nt Bond 13OO-8J04' _CoI\pI,IU~ ..._ Depth 1. 1,. ew"'.on SInof. ~ ~ ~'.. I. 3 tl2" DSS and 3 tIT' 8úttrteì XO 35'- 3. 3 1t.r' DSS !'UP 45' .. 3 112" DSS PuP SS' 5. 3 112" DSS-NTC Tubing "12* I. ~ '12" DSS Pup "17' 7, 8aIcr Loaotor ond Seal þ-.. ~ .,... a.UuIIlhoe (A. run ~1JI1) 1 '- ,.-. -'II . 2 '-- p . ~ '2er, '41 CSA au' ~ T s ~ . 13 ~.M. ". . II .. '6.1 CSA 4~ g & ~, 21' Utw tOP at 1121' . ,-;( -~, ~ ~1374' . SiB". 40. ~1 .7 . 53.5' CSA D.J.)2' a.taa' li 151r ~ r: 8551' ~ es.,· i [:::: .. .,la' . ~24' PIIID' t.3l!ll .. · . .. · · · .. ' 10 '455' .r'/¿/// /)a. STATE OF ALASKA ALASKA 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: X Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: 105' KB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Granite Point 18742 P.O. BOX 196247 ANCHORAGE, AK 99519 Service: X 4. Location of well at surface Leg 1, conductor 8 on the Anna Platform 8. Well number 829' FNL, 673' FEL, Sec 12, T10N, R12W, S.M. 46 At top of productive interval 9..Permit number 1874' FNL, 1937' FEL, Sec 12, T10N, R12W, S.M. 1820720 At effective depth 10. APl number 1888' FNL, 2237' FEL, Sec 12, T10N, R12W, S.M 50-733-20355-00 At total depth 11. Field/Pool 1886' FNL, 2262' FEL, Sec 12, T10N, R12W, S.M. Granite Point Field/Middle Kenai "C" Sands 12. Present well condition summary Total depth: measured 9,455' feet Plugs (measured) true vertical 9,123' feet Effective depth: measured 9,314' feet Junk (measured) true vertical 8,988' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 625' 20" 1500 sx 625' 625' Surface 4232' 13 3/8" 2555 sx 4232' 4206' Intermediat~ Production 8332' 9 5/8" 675 sx 8322' 8039' Liner 1334' 7" 305 sx 8121-9455' 7846-9124' Perforation depth: measured Top @ 8330' Bot @ 9324' true vertical Top @ 8047' RECEIVED Tubing (size, grade, and measured depth) 3-1/2", N-80 @ 8198' Packers and SSSV (type and measured depth) Baker Model F1 packer SA 8187' D~C, .i~,~ 0 2002 13. Attachements Description summary of proposal: Detailed operations program: ~L~$k~l~i~xs(~l~0~JS, 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: X 17. I hereby ~,a~ certify th~going is the best of my knowledge. Jeff Dol~...~~/// Signed: f/ ~ FoRTitle:cOMMISSIoNWaterfI°°d TechnicianusE ONLY Date: 12/26/2002 approval: Notify Commission so representative may witness IApproval Conditions of No. Plug integrity___ BOP Test._.__~ Location clearance. ~ ~ I ,._~'Z~ ~-- Mect'ja,nical Integrity Test__ Subsequent form required 10-~r~ ~'~,~ ~, Approved by order of the Commissioner ~~ /~----~Z~-~~.__~.~ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE NO 625 1142 1575 1639 2704 4230 4232 4338 6222 8113 8121 8130 8180 8187 8188 8190 8199 8199 8210 8331 8332 9272 9314 9321 9365 9410 9411 9453 9455 PBTD (ftKB) 9,455.0 TD (ftKB) S~ematic, ~ual Casing, 625ftKB Casing, 4,232ftKB Extension Packer, 8,187-8,190 -- Seals, 8,188-8,199 Fill, 8,180-8,210 Casing, 8,332ftKB Fill, 8,210-9,314 __ Liner Casing, 9,272ftKB -- Fill, 9,314-9,321 Fill, 9,321-9,365 E'l D (ffKB) __ Liner Casing, 9,455ffKB KB Elevation (ft) KB-TH (ft) 105.00 33.25 625.0ftKB 232.2ftKB 8,332.4ftKB Liner Casing 9,272.0ftKB Liner Casing, 9,455.0ftKB Standard Tubing set at 8, f 99.3ftKB on 4/29/1987 Top (ftKB) Corr MD Top Item Des (ftKB) ID (in) Hanger 33.3 Crossover 34.31 Standard Tubing 34.7 Locator Joint 8,187.1 Standard Tubing 8,188.1 Muleshoe 8,198.8 Other In Hole Run Date Fill 10/29/1986 4/29/1987 Seals 4/29/1987 Extension Packer 3/2/1989 Fill 2/16/1998 Fill 2/16/1998 F II Make Model CAMERON Des Top (ftKB) 9,321.0 8,188.1 8,187.0 9,314.0 8,180.0 8,210.0 Perforations Date Zone Top (ftKB) 7/30/1982 8/11/1982 8/1 1/1982 8/11/1982 8/11/1982 8/11/1982 8/11~1982 8/11/1982 8/11/1982 8/11/1982 8,213.0 8,330.0 8,458.(~ 8,551.0 8,84O.O 8,950.0 9,O56.O 9,198.0 9,246.O 9,3O4.O Shot Dens Btm (ftKB) ~shots/ft) 8,213.0 8,374.0 4.0 8,518.0 4.0 8,596.0 4.0 8,878.0 4.0 9,017.0 4.O 9,077.0 4. 9,228.0 4.O 9,296.O 4.0 9,324.0 4.0 Current Status Verified By: ' Verified Date: Rpt Name: Single Corrected I 1 / 1 45 0' 65 ANNA Platform AN 46-42 Temperature Suntey Ran on 2116/98 85 105 125 145 500' 1,000' 1,500' 2,000' 2,500' 3,000' 3,500' 4,000' 4,500' 5,000' 5,500' 6,000' 6,500' 7,000' 7,500' 8,000' AN 46 Temp 2-26-98.xls 12/30/2002 Steve Tyler LAST WORK: Date Finaled 1982 8/26 1998 2/16 ANNA PLATFORM APl # 50-733-20355-00 GRANITE PT. ST. 18742 AN # 46 WELL HISTORY 2/16/98 · Work Performed Completed as a water injector. Ran temp and pressure survey. TAG FILL w/2.79" GAUGE RING @ 8,180'KB. RIH w/ TANDEM SURVEY INSTRUMENTS. MAKING 7 MINUTE STOPS EVERY 1000' AND HANG FOR 10 MINUTES @ 8,170'KB. MAKE 2 MINUTE STOPS EVERY 1,,000' ON THE WAY OUT TOO. RDMO. UNOCAL~) Anna 46-42 Permit # 1820720 AP1 # 50-733-20355-00 RECEIVED DEC .~0 2002 ~aska Oil & Gas Cons. Commissio~ Anct~ora~e Packet cover sheet An 46-42.doc jjd Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Tel ephone (907) 263-7805 UNOCAL Alaska December 26, 2002 State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 Attn: Tom Maunder Re: Request for Time Extensions Dear Mr. Maunder: This letter is to notify you of the status of outstanding, work (according to my records) and ask for time extensions on these projects. I have enclosed a 10403 form for each of these wells plus basic information packets for those wells. Anna Platform 27-42 29-42 ~ 46-42 Granite Point Platform 22-13RD2 33-14RD Shut in 1992 Not returned to service Shut in 11/18/2002. Tubing plugged during wireline operation. Shut in'1995 Not returned to service Shut in 07/22/2000 Shut in 10/30/1999 Baker Platform 7 Shut in 10/05/2002 9RD2 Shut in 02/15/1998 The Anna wells were not returned to service primarily due to insufficient water injection capacity. Well An 29-42 was able to maintain over 3,200# on the tubing and casing with zero rate for 2 weeks which is strong evidence that the casing integrity is good. The pressure has been slowly bleeding off since isolating the well from the surface. Well GP 33-14RD is currently scheduled for baseline temperature survey. In January 2003, further diagnostic work will be needed to resolve the tbg/csg communication issues. Well GP 22-13RD2 was a conversion project which experienced apparent tubing / casing communication and was shut in on 07/26/2000 The Baker Platform waterflood is now shut in. In conjunction with the suspension of oil operations on the Baker platform, plans to secure the downhole injectors are being developed. If you have any questions regarding this, please contact myself at 263-7807, Hal Martin at 263-7675 or Phil Ayer at 263-7620. Aogcc 2002 requests for Time extentions.doc Sincerelyr jeffe* j D0lin~~~E [~/E D Water flood Technician Cook Inlet Water flood Manageme¥~tL'~Fic'F' 3 0 2002 '- "'~ ' ~ Naska0il & Gas Cons. Commission i ~' '~, ........ Anchorage NOTE TO FILE Granite Point 18742 fl46 Anna-46-42 PTD 182-072 302-399 Unocal has applied for a time extension to perform an MIT on this injection well, which has not recently injected. This note evaluates Unocal's request and recommends approval of it. The record indicates that the original well was originally completed as an injector in 1982. It last passed a standard MIT in February 1991. Following the Mt. Spurr eruption the well was returned to service. Injection ceased in 1995. The well has not been injected into since. In August 1998, Unocal performed a temperature survey to demonstrate there were no anomalies present. That temperature survey shows a smooth temperature increase curve until the completion interval where a significant cooling is noted. In early 2002, Unocal proposed to return the well to injection service and take advantage of the ability to obtain a waiver to inject into the well while providing additional monitoring information. As noted in the file note from that time, performing periodic temperature logs while reporting monthly rate and pressure data is an acceptable method to demonstrate continued integrity. For various reasons, Unocal never returned the well to service. A requirement of that sundry (302-099) was to perform another temperature survey within 60 days of returning the well to service. Since no water has been injected into the well, Unocal has not performed the subsequent survey and has submitted a sundry requesting a time extension. Although Unocal has not resumed injection into the well, they have included tJ~e well on the monthly monitoring reports: The only pressure consistently reported for this well is an outer annulus pressure of 250 psi. Examination of the pressure records indicates that this pressure is steady. On occasion, it appears that attempts are made to bleed the pressure down. The pressure returns to the original value the by the next day. Area Injection Order 6 allows injection into the Northern Granite Point field. The BHL of well 46 is located in the covered area. The '~rtion of aquifers beneath Cook Inlet described by a 1/4 mile area beyond and lying directly below the Granite Point Field are exempted for Class II injection activities by 40 CFR 147.102(b)(2)(B) and 20 AAC 25.440(c). Granting Unocal's request will not endanger any fresh water. I recommend that Unocal's request for a time extension be granted. At this time, Unocal has not stated when they might attempt to return the well to service by addressing addition of injection capacity. Unocal should continue to provide the monthly monitoring information and prior to the end of 3rd quarter 2003 provide the Commission with an action plan for this well. This requirement will be in addition to the regulatory requirement to provide an annual report on SI wells. Given Unocal's present action in the Inlet to SD two other platforms, it is probably unlikely that this well will be returned to service any time soon. Tom Maunder, PE Sr. Petroleum Engineer March/l~, 2003 400 Anna 46 350 300 250 200 150 lO0 50 0 [-.--- rate --a- tbg csg -~: outer csg J Unocal Corporation Alaska Business Unit 909 West 9~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCAL March 13, 2002 Tom Maunder State of Alaska Alaska Oil and Gas Conservation Commission 333 W 7th Ave # 100 Anchorage, Alaska 99501-3539 RECEIVED Re: Variance for AN-46 Dear Tom: AN-46 (Permit//1820720, API# 507332035500) has been shut-in since the end of 1996. Now that we have the process worked out for variances on these types of wells that fail a conventional MIT, we would like to get as many wells on injection as possible to increase the ultimate recovery of the field. AN-46 is one of the key old injectors which will help support our new group of injectors and producers. The well had a baseline temperature survey was run for a shut-in MIT on 2/16/1998. The well last passed a conventional MIT back in 1991 and has tbg/csg communication now. We are proposing to bring this well back on injection, run a Step Rate Test and a follow- up temperature survey after the well has stabilized. Enclosed is the 10-403 form requesting permission to inject. Another 10-403 will be submitted with the results of the Step Rate Test and follow-up temperature survey to obtain a Variance to inject into this well. Senior Reservoir Engineer Cook Inlet Waterflood Management ORIGINAL \XAk-Anchorage\GroupsXAOGCC\CorrespondencesXAn-46 Re-activation cover letter.doc Jeff Dolan ( STATE OF ALASKA ALASKA 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: Perforate: Other: Permission to Inject 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Development: 105' KB MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Granite Point 18742 P.O. BOX 196247 ANCHORAGE, AK 99519 Service: X 4. Location of well at surface Leg 1, conductor 8 on the Anna Platform 8. Well number 829' FNL, 673' FEL, Sec 12, T10N, R12W, S.M 46 At top of productive interval 9. Permit number 1874' FNL, 1937' FEL, Sec 12, T10N, R12W, S.M. 1820720 At effective depth 10. APl number 1888' FNL, 2237' FEL, Sec 12, T10N, R12W, S.M 50-733-20355-00 At total depth 11. Field/Pool 1886' FNL, 2262' FEL, Sec 12, T10N, R12W, S.M. Granite Point Field/Middle Kenai "C" Sands 12. Present well condition summary Total depth: measured 9455' feet Plugs (measured) true vertical 9036' feet Effective depth: measured 9365' feet Junk (measured) true vertical 9036' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 625' 20" 1500 sx 625' 625' Surface 4232' 13 3/8" 2555 sx 4232' 4206' Intermediate Production 8332' 9 5/8" 675 sx 8322' 8050' Liner 1334' 7" 305sx 8121-9455' ~ ;~ '~ 8 Perforation depth: measu red Top @ 8330' ~ ~ Bot @ 9324' true vertical Top @ 8052' .~ ~, ~ .~ ... Sot @ 8996' 1¥t;'47~ ! ~ Tubing (size, grade, and measured depth) 3-1/2", N-80 @ 8198' Alaska 0ii & Gas Cons, Commission Packers and SSSV (type and measured depth) Baker Model F1 packer SA 8187' A~oilom§e 13. Attachements Description summary of proposal: X Detailed operations program: BOP sketch: Permission to inject to obtain variance after well stabalizes and data is gathered. 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oil: Gas: Suspended: Name of approver Date approved Service: X 17. I hereby certify that the [oreg,ojn,~ is true and correct to the best of my knowledge. Signed: [~/' Title: Senior Reservoir Engineer Date: 311412002 FOR COMMISSION USE ONLY =,, Conditions of approval: Notify Commission so representative may witness[[Appr°val No. Plug integdty~ BOP Test Location clearance Mechanical Integrity Test "~.' Subsequent form required 10- I.~[~)t-~ ~ OTiCnal Signed Camm¥ Oechsli .,Approved by order of the Commissio.er Commissioner Date 3/~ Form 10-403 Rev 06/15/88 ORIGINAL SUBMIT IN TRIPLICATE GRANITE POINT ADL 18748 WELL NO. 48 IflDDLE KIN'Al SANDS PIATIPOIUf ANN& 11:) - 1eeC' Iqdl.. ~ ~ 12. TtON, Iq12g, SAr. t05' ~ 045S' 1'VDt. 9124' 0360' ~ 0O37* 20", O4tl K-_OS r. odno sd et I2S* with t500 mt. ~. ~ _.~. ,. ,,..,.,., ,-, c.,.., .., 423,12" e S,~** 40. os, 47 ~ s3.ff s-es Ce,bg eot d 8332* with 675 ~ ~ C~-Bt 0108-0228' 0248--0280' 03O4--0324* L 3 1/'~ DSS ~ld 3 I/2' BMbIM XO 30* t/2'* SO' 3 l/t" T. WO 81ea. ~ e345' 0' 65 ANNA Platform AN 46-42 Temperature Suntey Ran on 2/16/98 85 105 125 145 500' 1,000' 1,500' 2,000' 2,500' 3,000' 3,500' 4,000' 4,500' 5,000' 5,500' 6,000' 6,500' 7,000' 7,500' 8,000' AN 46 Temp 2-26-98.xIs 3/14/02 Steve Tyler Amoco Production Company Daily Drilling Wire -Daily Report [~ *: ;* i 1 One-.me entry un,ess changed. Identification Date I Flac (Well) ' IChange! Sort'l :: I~int Code :¥-'. lDiatHct IAPI/CPA Well No. IO/~' ITy. pe :'' I~asa IState. · ' !;'-".:'~:'I?~-'~.t~,~'.~:"' ! . !'- I? ..... I~','.,'~1', Operations iSpud Dat~ I Days From IDays Present Operation I/ / / ' ISpud,-~,,-~ IOperated I ~ Mud / Test Depth Type Weight Viscosity WL PV 3 ::,:: I I TypeIAmount Water I HT-HP-WL I Solids LblBbl Solids Removal Unit I Solids Removal Unit 2 H~rdraulics and Bit Bit No. Size Type Jets132nd Depth Out Feet Hours FtlHr Wt(M) RPM Condition Comment Seq. .... T B G R No. Bit No. Size Type Jets132nd Depth Out Feet Hours FtlHr Wt(M) RPM Condition Comment Seq.'" T B G R No. Bit No. Size Type Jets132nd Depth Out Feet Hours FtlHr Wt(M) RPM Condition Comment Seq. T B G R No. Deviation Depth Inclination Direction IDepth Inclination Direction Depth Inclination Direction I I Depth Inclination Direction I I Time Distribution, Hours I I Drilling ITrip I Rig Rep ISu~eys ILost Circ. IFishing ICSG & IWOC level. I Other I 8 0 C tg. · Typ IHoursl · - Costs ! Daily Mud Cost 9 C::) I Temperature lO Cumulative Mud Cost IDaily Well Cost Cumulative Well Cost Weather ' I (~Precip"atl°n I~'~"- IWave IPeri°d [Swe" IMCS Iv'sibi'ty Pe~inent Data KB Depth ~ OD I Other Ceiling IHeave IPitch IRoll I I I I Casing t Depth Set Casing Top Date Set Typ Remarks Called In By: ~-~ ~ Call Received By: ~ L... ~ [~ over FORM 663A Jul-79 ANC 102 Revi~{on 10/81 Amoco Production Company Daily Drilling Wire Dally_ Report identification One-time entry unless changed. Date / / I Flac (Wall) IChang* ~ort '1 Print Code .~ IDIstrlct IAPIICPA Well NO. IO/S ITYP* IC~asS' Istate -7,/~/~1':~--/~--~1 ~ I ='1""","'°"1 N~fn_e. Number$ ..... .. . . Field-Area Operations , ,Tot., Depth ,PBTD , Presem Operatlon ,Progress ,Formation ,Spud. Dat, ~ I Days From IOays` ~ I r / :/: ::~!lSp~_d IOperated I II · <%'::"1 I .--T-- ,. .,. ~ ~ ¥'~,.. ,.J Mud - / w.,0.,v._, I"v "°"°l°'°'"'c" ,c.,c,. .o,,I . o,. I-- Water I HT-HP-WL I Solids LblBbl Solids Removal Unit I Solids Removal Unit 2 4 A~] ~.. ~ ~.~.Temp. Fluid LossI BT~nlte ~--~Drilled~} Barite~ ~Type ~ Wi OF ~ WtUF ~ GPM Type_._ ~ Wi OF i WtUF ~ GPM Hydraulics and Bit Pump Pressure GPM Bi Ann-Vel Pump Onrsize I .'.~f Hole ~,~ngth I ---SPM Liner ~.."~ Size I Length~;~,, I '""SPM Bit No. Size Type Jets132nd Depth Out Feet Hours FtlHr Wt(M) RPM Condition Comment Seq. )~ g~ ~ ~/'"(~ /'? IF,rl/:l~ '1"1~ I" .o. Bit No. Size Type Jets132nd Depth Out Feet Hours FtlHr Wt(M) RPM Condition Comment Seq. I I '1~ I~ I" .o. Bit No. Size Type Jets/32nd Depth Out Feet ~Hours Ft/Hr Wt(M) RPM Condition Comment Seq. 7 IDepth Deviation Inclination Direction Inclination Direction Inclination Direction Depth Depth Depth Inclination Direction Inclination Direction Inclination Direction I I Tima Distribution, Hours Depth i Inclinationl Direction I SN~?'I I Drilling ITrip I Rig Rep ISurveys ILost Circ. IFishing ICSG & IWOC IEva~. I .~1 Iz:"l. I I I . '~7~~ I/~ I I Daily Mud Cost Temperature Other I Other Icirculate ILube I Costs I Cumulative Mud Cost IDaily Well Cost Cumulative Wetl Cost AuthOrized Well Cost~: ,~.?~:i. ::lLatest Estimated Well I I Weather IPrecip~°n W'nd IWave 'Per'°d ISwe" IMCO 'Vis'bi"tY 'Ce"'ng 'IHeave IP'tch IR°''~:/~ I I I I~I ~,o~e-,- ~OOO ,i Pertinent Data Remarks ~4 Ca,ed,n By: , ~ :~ ~ i ~ · Call Received By: ~ '~'~'J ~ Over FORM 663A Jul-79 Amoco Production Company Daily Drilling Wire Dally Report [ - I One-time entry unless changed. Identification . Operations I I Total Depth IPBTD , Present Operation IPr°~ss IFormation ISPUd.Date IDays Fr°m IDays Mud 3 TestDepthlTYpel' WeightlVisc°sity IwL I~" IPv IYP Gels 0/lOl%S°lids IChl°ridel [Calcium %°'ll TypeOtherl Amou.t IMBT Water I HT-HP-WL I Solids Lb/Bbl Solids Removal Unit 1 Solids Removal Unit 2 4 AddedI, ~.m,. I .u. LossI Bentonite I Drilled I Barite Type i W, o~ I wt OF I GPM Type i wto~ I w,~ I ~"~ Hydraulics and Bit Bit No. Size Type I Jets132nd · Depth Out Feet 'Hours FtlHr Wt(M) RPM Condition Comment Seq. Bit No. Size Type Jets132nd Depth Out Feet Hours FtlHr Wt(M) RPM Condition Comment Seq. Bit No. Size Type Jets132nd Depth Out Feet Hours i FtlHr ~ Wt(M) RPM Condition Comment Seq. 6 T B G R No. Deviation Depth Inclination Direction I Depth Inclination Direction I I I Depth I Inclinationl Direction I SN~q'' I Time Distribution, Hours Drilling ITrip I Rig Rep ISurveys ILost Circ. lFishing ICSG & IWOC IEval. I Other I Other ICirculateJLube I .),//~D~:~.!i~t~! ~s~:!lumula~.tive IMud C°stI Daiily W~el...~/.i~:~s~tCT~? ~.~/:i!~ttSive Wle,. C°stType ,Auth~ri::u:S~eil ~st Type ,Late~t:::ir:~ted Well ~oR:: ~ Weather Pertinent Data PB Depth I OD ID Casing t Depth Set Casing Top Date Set Typ I I I I I Remarks FORM 663A Jul-79 ANC 102 Revision 618i:"~;~~:'~'~!'?~ Amoco Production Company Daily Drilling Wire Dally Report I ' I One-time entry unless changed. Identification Operations 2 ~/I I~.c- Mud 3 ,~-~//Test Dept'ITypell I ~"~lWeightlVisc°sity.~,~ IwL IpH ~' IP~' IYP~ /~lGels 5~i %Solids~,~.~ i~/~..~lChl°ricle ICa:~"/~ilI Type Otherl Amount 4 3'~'I ~"°' I'~'~°~"I ~'~"I~'~'Drilled i ~)BarlteType I'V'°~ I w,~. I ~ ~" I Wi OF I WtUF Hydraulics ~nd Bit Pump Pressure GPM Purr;p On H°le '~ Lengt'~-i I Sec°nd Pump On H°le 5 ,,~ q34~-· I /~~ LinerSiz.~ ! ~P~ I LFSize I Leah i ~~ Bit No. Size Type Jets/32nd D~pt~ Out Feet Hours Ft/Hr Wt(M) RPM Condition Comment Seq. 6 /~ /~, ~~ /Xl mira ~ ~ ~ ~ ~ ~ ~ ~ ~1~ I~ I R ~~ No. Bit No. Size Type Jets/32nd Depth Out Feet Hours Ft/Hr .Wt(M) RPM Condition ~mment Seq. ' T B G R No. Bit No. ~Size Type Jets132nd Depth Out Feet Hours F~Hr Wt(M) RPM Condition Comment Seq. T B G R No. Deviation Depth Inclination Direction I Depth Inclination Direction Depth Inclination Direction I Depth Depth Depth Inclination Direction InClination Direction Inclination Direction Time Distribution, Hours Costs Weather I:, Temperature I Prec~ation I/~1 ,Wind ,Wave . ,Period I I'Swell IIMCS I/~ ,Visibility I ` :~'~'''~ ]'Heave I'Pitch IRoll Pertinent Data IDate :,,.: :'~!: I Date:::i.': ~1 Depth Remafi~s Called In By: ~"'~. S Cai, Received By: K'~'-'~ ,,~ Over FORM 663A Jul-79 Remarks, C~mt'd. ,, , .,~ 28 Option B -- Deviation Control Data Survey M.D. Inclination Direction T.V.D. Coordinate N-S Coordinate E-W Horizontal Vertical Section Seq. No. Displacement No. ., BA Option D -- Drilling AIsembly Drilling Assembly -- From Bottom Up DA Component Length O.D. I.D. Seq. No, DA ,,/t/'"~ u~:/~ I .///-~ I ,,, I DA ~/T ~~ I ~, 73 !. I. DA I /7 I 1 ! DA .~'-O~~ ! ~,g~ I. .I DA I I I DA I I ........ DA I I ! DA I I I DA ~ ~ .. I DA I I I DA I ! ! DA I 1. BM~-Stinoer t.enq~h.. ~',;n', W~ -. ~ ~:,~, W"F ~'~C<<,~P?' :~; ,:~,~,:~( O;F TORQUE RBL , NOTE TO FILE Waiver to Inject Water with a Tubing Leak Unocal Granite Point Field--Anna Platform (18742) AN-27RD... 167-016...302-010 AN-46... 182-072...302-099 Unocal has applied to return 2 wells on Anna Platform in Granite Point Field to injection service. Both wells cannot pass the standard annulus pressure test due to tubing leaks. Granting variances for such wells is not unusual, a procedure has been established on the North Slope where mechanical integrity is usually demonstrated by setting a tailpipe plug and simultaneously testing the tubing and annulus. With integrity successfully demonstrated and a monthly report of the daily injection rate and pressure such wells are returned to service. For these wells, Unocal proposes to demonstrate that the injected water is confined to the intended zone by running a temperature log after the wells have been returned to injection and comparing the new log with baseline logs previously obtained. Comparison of the logs is an acceptable method for demonstrating mechanical integrity. Unocal prefers to use the temperature logs in lieu of setting a plug due to the risk of not being able to retrieve the plug when the pressure tests are completed. AN-27 RD was drilled as a service well in 1977 and was in service until the end of 1991. It last passed the standard MIT in 1992. A baseline temperature survey was performed in mid 1998. Winton has reviewed the file and assessed the well for MIT Part II and has concluded that mechanical integrity is indicated. I concur with his assessment. AN-46 was drilled as a service well in 1982 and also was in water injection service until the end of 1991. It last passed a standard MIT in 1991. A baseline temperature survey was performed in early 1998. Blair performed the original MIT Part II assessment and concluded that mechanical integrity was indicated. Unocal's proposal to return the wells to injection service is reasonable. The methodology they propose for demonstrating the continued integrity of the wells is acceptable and should satisfactorily that the water is being injected in to and confined within the intended zone(s). I recommend that sundries 302-010 and 302-099 be approved. In addition to the actions proposed by Unocal, a monthly report of the daily operating rates and pressures should be submitted for each well. Thomas E. Maunder, PE Sr. Petroleum Engineer JUN-29-98 MON 13:41 UNOOaLa$SET GaS GRP F~X NO. 9072637874 P, U1/U1 Unocal Corporation 909 West 9* Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL June 29, 1998 Wendy Mahan Alaska Oil and Gas Conservation 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, 1998 letter which you signed granting time extensions for various wells. Testing or work was comoleted on the following wells and the results of. this work is listed: Anna 4642 : SI MIT approved on 4/17/98. ':15 -o4-z King 4RD q,~-t~34 King 15RD ~o- ~to-Dolly D-16RD 6~-~ Dolly D-22 n~.,~a Grayling 22 fi3. ~ Grayling 36DPN ~t-o~ Monopod A-12~2 ~z-~z~ Mono~ A-29 ~4- ~ Baker 9 qg. o~n King 22RD SI MIT approved on 4/17/98, 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 4/19/98. : Workover completed on 4/28/98. : SI MIT approved on 6/03/98. : SI MIT approved on 6/03/98. SI MIT approved on 6/03/98, 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, further 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 : Re, drill in progress. Testing or work was attempted on the following shut-in wells and a time extension until September 30, 1998 is requested to complete further work and testing~ 65 - o ~ Anna 19-42: Coil Tubing clean out completed on 6/27/98, further testing scheduled to prove casing integrity. '-.[:/. o lg Anna 2742: Coil Tubing clean out completed on 6/25/98, further testing scheduled to prove easing integrity. -~- oq Grayling 28: Coil Tubing cleanout planned to follow currently active rig program. ~ - 05 Grayling 40: Workover schedule in current rig schedule. -45-04~- King 4RD : SI MIT granted on 4/17/98, workovor scheduled. "4~' ~%4King 15RD: SI MIT granted on 4/17/98. 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 me 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 faxing.back a si~ned canv of this letter to Christopher Ruff at 263-7874 (fax). ~ ' ' Wendy-Maban Dat ' JUN 2 ,q 1998 AOGCC Alaska Oil & Gas Cons. Commis~on Ancho~ge APR:-03-98 FRI 08:33 UNOOAL ASSET GAS GRP ( FAX NO, 9072637874 Unocal Corporation Agricultural Products 900 West 9~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 263-7830 UNOCALe P, 02/12 April 1, 1998 Wendy Mehan State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: Granite Point Field Dear Wendy: This letter is to document your approval of Anna AN 46-42 Shut-In MIT. Attached is a copy of the temperature survey completed on 2/16/98. Please r~wicw this data. flit passes it's Shut-In MIT, please sign and send a copy of this letter to my fax at 263-7874 otherwise call me at 263-7830. se~r ~oir Engineer CookOut Waterflood Management Please return a signed and dated copy of this letter to document notification for our records. Wendl~lhan ' Dat~ AOGCC Aogcc AN 46-42 MIT. doc 04/01/98 ~PR?03-98 FR! 08:34 45 O' UNOORL ¢tSSET GRS GRP 65 F,q× NO, 9072637874 ANNA Platform AN 46-42 Temperature Survey Ran on 2/16/98 85 lO5 12~ P, 03/12 145 1 ,CIO0' 2,000' 2,500' 3,000' 3,500' 4,000' 4,500' 5,500' 6,000' 6,500' 7,000' 7,500' 8,000' AN 46 Temp. xls 4/1/98 Steve Tyler ¢tPI~-03-98 FRI 08: 38 UNOCRL RSSET GPtS GRP FRX NO, 9072637874 P, 05/12 SEQUENCE OF EVENTS ANNA PLATFORM WELL # A-46 2-16-98 12:05 Start clocks wait for bombs to start 12:40 RIH in hole at 60' per min. making two min. every even 1,000' 15:11 On bottom make 10 min. stop at 8,180' pooh at 60' per min. making two min. stops every even 1,000' 17:45 Out of hole check information looked good 1.8:30 Make out survey plots shut down for night fiPR-03-98 FRI 08:38 UNOOfiL fiSSET G~S C-RP ( NO, 9072637874 P, 04/12 UNOCAL ANNA PLATFORM TEMP. & PRESSURE SURVEY WELL # A-46 2-16-98 38~B, 88 24~. ~0 21~. 80 180~. 88 12~. 0~ 9.9 0.6 1.2 1.8 2.4 3.9 3.6 4.2 4.8 5.4 6.0 E lapsed Ti me < Hours ) i6~. 0t] 147.~ t34.00 9.5, (]0 82.00 69.80 56.88 43.88 38.08 c z LL UNOCFtL FI. B Probe ~ '1 lt112B2 T~mper-at ur~ vs T line E;~ POLLRED I~ IRF-L INE AF'R 05 1998 '1 ! I I I '1'"1 -1 ....... I I I ! J i '1' I I i ' I I I ~- 1 ! I I~!' '1 .... ! ! '1 I' '~1 I I I CUMULRT I UE T I ME m i mu f es I '1 I'"1 I-~1 -! I 1 _J W --~ UNOCBL B-qB TEMPE~BT[~E B~RD Plof (~B/O21~B I ..... ·'1 .... I' ! ' ! '"! "I I ' i -ir ....I' '! I ! I t i" ' 1' 'i i ir 'l i I .... i" '! .... I I I '1 --'1 '1 c~ Z 0 TEMPERBTURE (F) STBRBURBT ELECTRONICS RECORDER t~ 102B2 INC. 27E1~. eel 9~i1. ~}El UNOCAL TVD vs P/T ;t- 46 POLLRRD NT RELINE RNH~I 2- t6-98 F23~)2~.6. DRT TEHP. & PRESSURE SURVEY 0. El 8::L8, I~ ::1.636. · 2454. · 3272 , ~1 41~JEl. III 49El8. El 5?26. El 6544. ~1 7362. E! 8:1.81~, I~ Depth ~.34. ~)El t.2 i. 00 9~. 82, 69. 43. ~)0 Z O '-ri x Z O cID CD --.1 --.4 C~ CD CO hP1~-03-98 FRI 08:39 UNOOhL RSSET G.qS GRP F,'q× NO, 9072837874 P. 10/1~ STARBURST ELECTRONICS INC. Subsurface Temperature Measurements Company: Address: Well name: Location: Field & pool: Production interval: Mid point perf: Well status: Test type: Elevations KB: Date of test: Shut in date: Tubing pressure before: Tubing pressure after: Casing pressure before: Casing pressure after: Tubing diameter: Casing diameter: Probe serial #: UNOCAL CAVIAR ST. A-46 ANNA WATER INJECTOR TEMPERATURE GRAD 40' CF: 98/02/16 12:05:00 10262 Depth Stops Time Stop Temperature Gradient (F) (F/f) Surface 10oo.oo 2O00,00 3OOO.OO 4000.00 5000.00 6000.00 7000.00 8000.00 8180.00 12:05:00 - 12:40:00 12:55:36 - 12:57:36 13:14:48 - 13:16:48 13:32:30 - 13:34:30 13;50:50 - 13:52:50 14:09:38 - 14:11:38 14:28:15 - 14:30:15 14:47:15 - 14:49:15 15:05:40 - 15:07:40 15:11:10 - 15:22:10 54.02 0,0000 75.18 0,0212 93,50 0.0183 88.43 -0,0051 97.46 0.0090 109,50 0,0120 123,39 0,0139 136.63 0.0132 147.82 0.0112 149.14 0.0073 P~PR;-03-98 FRI 08: 40 Depth Stops UNOO/tL aSSET Time Stop 8000.00 7000.00 6000.00 5000.00 4000.00 3000.00 2000.00 1000.00 0.00 15:25:50 - 15:27:50 15:44:35 - 15:46:35 16:00:26 - 16:02:26 16:13:33 - 16:15:33 16:26:50 - 16:28:50 FPIX NO, ~072837874 Temperature Gradient (F) (F/f) 147.95 136.73 123.50 109.66 97.53 16:40:08 - 16:42:08 88.49 16:52:56 - 16:54:56 87.62 17:05:52 - 17:07:52 93.91 17:20:20 - 17:40:00 59.83 P, 11/12 Temperature On Bottom: 59.83 Recorder # 10262 '. ' P, 12/12 ~PR,.-03-98 FRI 08: 40 UNOOPL ASSET GAS GRP F~IX NO, 9072637874 COMPANY: ONOCAL WELL NAME: A-46 WELL LOCATION: ANNA ~£ST TYPE : TEMP. & PRESSURE SURVEY PAGE: C DATE : 01/30/98 FILE REF: F230216,gAT HH/DD hh:mm:ss hhhh.hhhh ft ft Psig Psig/ft ' Deg F Deg 02/16 12:40:00 .5833 ,000 .000 .010 55.748 o2/16 12:57:00 .8667 1000.000 1000.000 .010 58,505 .003 02116 13:16:00 1.1833 2000.000 2000.000 .010 60,487 ,002 02116 13:34:00 1.4833 3000.000 3000.000 ,010 61,717 ,001 02/16 13:52:00 1,7833 4000,000 4000.000 .010 62.211 .000 02116 11:11:00 2.1000 5000.000 5000.000 .010 62,42g ,000 02116 14:30:00 2.4167 6000,000 6000.000 .010 62.710 .000 02Z16 14:49:00 2.7333 7000.000 7000.000 .010 62,941 .000 02/16 15:07:00 3,0333 8000.000' 8000,000 .010 50,075 -,013 02116 02 O2 O2 02' 02' 02' Ol 15:13:00 3,1333 8180.000 8180.000 .010 50.075 '16 I5:18:00 3.2167 8000.000 8000.000 .010 50.075 '15 15:37:00 3.5333 ?000.000 7000,000 2255,446 -2,255 145,830 -,096 '16 15:53:00 3,8000 6000,000 6000,000 1876.663 .3?9 135,889 ,010 ~16 16:06:00 4,0167 5000,000 5000.000 1519,521 ,357 125.168 .011 ~16 16:19:00 4,2333 4000,000 4000.000 1116.614 ,403 112.219 .013 ~16 16:33:00 4,4667 3000.000 3000,000 676.537' .440 99.497 .0t3 ~I6 16:45:00 4.6667 2000,000 2000.000 278.177 .398 90,832 .oog t16 16:58:00 4,8633 1000.000 1000.000 .010 ,2?8 88.668 ,002 ~16 17:21:00 5.2667 .000 .000 6.457 -,006 81.479 .007 MPP/?V~ @ 1000.000 .010 -.006 88,668 .00~ H~R-27-98 FRI 13:~2 UNOCAL ( ASSET GAS GRP FAX NO, 9072~Fq7874 PI 01/01 Unocal Corporation 909 West 9'~ Avenue, P.O. Box 196247 Anchorage, Alaska 99519-6247 UNOCAL(B :March 27, 1998 Wendy Mehan Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dent 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 January 23, 1998 letter which Blair signed granting time extensions for various wells. Testing or work was completed on the following wells and 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 Lou Grimaldi 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 3/17/98, 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 Lou Gfimaldi Tasting or work was attempted on the foll0w~.'ng, sh~_~-in wells _a~_d a ~e exp-n.~i0n umi.! ~e 30, 1998 is to complete ~ work.~d teeing A~ 19-42: Sc~e cle~out of robing compl~ed, ~ ~sfing ~hed~ to p~e casing ~te~F. A~a 27-12: Sc~e cle~out of robing complete~ ~er t~g ~hed~ to pr~e c~ing ~te~'. A~ 46~2: Tamp S~ey ~ on 2/17/98, s~ey shoed pr~e no flow ~d ~low SI s~tus. B~er 9: ~ aUempted on 2/1~/98, ~ ~l~e t~g scheduled to pr~e casing ~e~W. Monopod A-12~2: SI ~ a~empted, Tamp S~y sched~ed to prove no flow. MonopM A-29 : SI ~ sched~ed to pr~e no flow/casing King 4~ : ~ iMi~aes possible casing le~ ~11 ~ufin, ~cr icing ~d workover ~hcduled. ~ng 15~: ~ ~caes possible casing le~ well ~t~, ~er tesfi~ sched~ed. ~g 22~: ~ indicates possible casing le~ well ~n, ~ te~i~ ~hed~ed. Grayling 5 : Workover~ll sch~ in ~ml ~ sched~e. Grayling 22 : Workover~e~ll sch~ulM ~ c~nt ~g schM~e. Grayling 28 : Workover~fill schedul~ ~ ~m ~ sched~e. Grayling 36DPN : Workover~edfi~ sch~d~ in cu~ent ~ schM~e. Grayling 40 : Work~'er~edfi~ sch~uled in c~t ~g sched~e. Uno~l respec~lly ~quests a time~xtension ~fiI J~e 30, 1998 to complete ~e work on ~e a~ve listed B~er ~d MonopM we~. ~e ~ayli~ ~d ~g ~& ~H be ex~uted ~r o~ c~ent ~ling ~h~ule.~se ~11 mc if you have ~y qu~tions or cl~c~on on ~ese issue. R ~ C ~ ~ ~AR 27 Savor Rese~oir En~n~r ~ok Inlet Wai~o~ Mam~ 0~ a Sas ~ns. ~ncnora9e Please ac~owl~g~ ~e a~pr~al of the time exte~ion ~d your receipt offs leper by f~ng ba~ a si~ed copy oft~s letter to C~aopher R~ at 263-~874 (fax). endy~h~ Da~ ! ' AOGCC Unocal AlasKa Resources Unocal Corporation 909 West 9th Avenue. P.O. Box 196247 ~nct~orage, AlasKa 99519-6247 Telephone (907~ 275-T600 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 Ann a_2..~42 ........ , ....... ~.,~,,.., ~,~ 33-14RD Middle Ground Shoal Field Baker #4 Baker #9 Currently injecting wells Tradinq Bay Field Monopod Platform A-8RD2 Wells Needing Repair The shut-in MIT on Bruce 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 procedure for repairing or permanently abandoning this well. An MIT on shut-in Granite Point Platform Well. # 33-14 indicated a mechanical 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 Monopod A-12R2 Monopod A-26 Monopod A-29 ~, a~.o 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, Reservoir Engineer Agreed to by: Blair Wondzell Petroleum Engineer AOGCC W. G. Smith District Manager July 29, 1987 Amoco Production Company Post Office Box 100779 Anchorage. Alaska 99510 907-562-2147 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' C. V. Chatterton, Chairman Fi le' FEW-IO4-WF Gentlemen: Report of Sundry Well Operations GP 18742 No. 46 Platform Anna, Cook Inlet, Alaska Attached in duplicate for your records is a State of Alaska Form 10-404, Report of Sundry Well Operations, outlining work recently completed on GP 18742 Well No. 46. A hole was found in the 9 5/8-inch casing at 421 feet RKB. The 9 5/8-inch casing was replaced from 1'142 feet to surface and pressure tested to 3,000 psi. .The well was recompleted and placed back on injection on July 10, 1987. Questions concerning this report may be directed to Kurt Unger at 562-2147, extension 211. Very truly yours, District Manager KWU/dds Attachments STATE OF ALASKA ~_ AL/( .-~ OIL AND GAS CONSERVATION CO ,SSION REPORTOF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator Amoco Production Company 3. Address P.O. Box 100779~ Anchora.qe~ ^laska 99501 4. Location of well at surface 829' FNL, 673' FEL, Sec. 12, T10N, R12W, S.M. At top of productive interval 1874' FNL, 1937' FEL, Sec 12, T10N, R12W, S.M. At effective depth 1888' FNL, 2237 FEL, Sec 12, T10N, R12W, S.M. At total depth 1886' FNL, 2262 FEL, Sec. 12, T10N, R12W, S.M. 5. Datum elevation (DF or KB) 105' KB 6. Unit or Property name Granite Point 7. Well number 46 8. Approval number 7-210 9. APl number 50-- 733-20355 10. Pool Midd]e Kenai "C" Feet 11. Present well condition summary Total depth: measured true vertical 9455 feet 9124 ~feet Effective depth: measured 9365 true vertical 9036 feet feet Plugs (measured) Junk (measured) Casing Length Size Structural Conductor 625' 20" Surface Z~232' 13 3/8" Intermediate Production 8332' 9 5/8" 'Liner 1334' 7" Perforation depth: measured Top at 8330' true verticBa~ttOm at 9324' Top at 8052' Bottom at 8996' Tubing (size, grade and measured depth) 3 1/2" N80 at 8,198' Packers and SSSV (type and measured depth) Baker Model F1 packer SA 8187' 12. Stimulation or cement squeeze summary Cemented Measured depth True Vertical depth 1500 SX 625' 625' 2555 SX 4232' 4206' 675 SX 8332' 8050' 305 SX 8121-9455' 7846-9124' AUG 0 5 Intervals treated (measured) None Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation July 22~ 1987 - ~njectin.q 949 BWPD at 3708 psi 14. Attachments Daily Report of Well Operations '~ Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~'...~ -c~ ~/'-- ~ 7 Title Di strict Manager Date 7/2,9/87 ] Submit in Duplicate AMOCO PRODUCTION COMPANY END OF W L_ CHRONOLOGICAL REPORT DENVER REGION **-m ANCHORAGE DISTRICT *** 05/0.3/87 *** PAQE 1 *~ JOB. INI.TIATION REPORT- .CD[tPANY OPEnA,._,D. REPAIR DEVELOPMENT AP]: 5073320.~'5500 ' '· FLAC' 84.2~0~'.' ', ':. "" '. ' : ' : ' ';' ' -- . . . , . . QRANiTE POINT .... KENAI'. O/S,STATE; 'ALASKA " ' , , OPERATOR' AMOCO PRODUCTION .. . . AMOCO W.I..' O. 6250 .". AUTH HORIZON ZONE' O1 -. AUTH DATE 03/20/87, AU'TH COST $614000 CONTRACTOR (~) .~NFG.w,.t ~,-,. ! ,_.- ~_~ ,, PARKER, 0!50 DENVER RE~ION ~ ANCHORAGE DISTRICT *** 05/03/87 *** PAGE *** 04/16/87 , QRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC. 84270~-02-6, API .507~32035500, AUTH COST · AMOC'O W:"I. -0.'~25~' ~. ---'- '- .. .. OPERATIONSi TD'9~55"FT~ P~TD V365~..NU/BOP .. " , ... REMARk5: COMMENCED OPERATtONS'O00i HRs.c~-'l~87· CHRON TIME DISTR'IBUTION (HRS')' -- -. "" " -2.00 - .OTHER,'' SKID RI~ TO.LEG 3' 2.50 - · OTHER, 'HOOK UP SERVICE. LINES X ECT - 1.00.- ND, ". INSiALL BP UALVE DID TREE '." 0.50 - NuBoP, NIPPLt. N~ UP ~OPS. NOTIFIED STATE OF UPCO~IN~ ~OP. TEST JO~ INITIATION REPORT' DIRECTIONAL HOLE CURRENT WELL ACTIVITY-AUTHORiZED, DATE lO/i~/Sa ,~lOsO PRODUCTIO,N: , QRANITE POINT, PARKER 150, FLAC 84270~-02-&, APl = .....~ .... ~ ......~ A~7TM COST' a~QCO ~. ~. O. ~0 OPERATIONS TD 9455 FT PDI'D o~xD, · , ~., LAY, DE)Wr~ SEA!_ ,.~ COSTS' DATLY. WELL $11587, CUM WELL $11q~-~.,o, CHRON TIME DISTRIBUTION ~. O0 - . NUBOP) NIPPLE UP 2. 50 - TSTBOP, TEST ~OP~. TO 3500 ¢ oR' ~ ~REAH OUT~ HANGER 1. O0 - PT'G, PULI_ TBG HANGER TD r-LL~._R /~ . . LOOKED GOOD 2. 50 - CIRC, CIRC W/S. 4 SW V. O0 - PTG, PULL 3-!/2 TB~ STAND BACK 2?43 FT. IN DERRICK X LAY DOWN 160 JTS X SEAt_ F~SSY. DID D~OT LOCATE ANY HOLE ~= - WERE . TORN FROM DAMAGED TB¢. SEAt_ ASSEMBLY =,:.AI_~ B~DLY LOCATOR DO~N APPROX. 4 FT iNDICATIN¢ THE SEALS HAD ~EEN HORSING IN THE P~R, 04/18/87 *** , GRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 84270~-02-&, API 507332035500, AUTH COST $614000, AMOCO W. Io 0.6250 OPERATIONS: TD 9455 FT, PBTD ~3~5, LAY DOWN PKR W/dUNK PKR COSTS: DAILY WELL $10777, CUM WELL CHRON TIME DISTRIBUTION (HRS): ~.50 - TRIP, INTO LINER TOP AT 8121 2.50 - CIRC, REV 2. 50 - TRIP, X L/D 8-1/2" BlT 3. 50 - TRIP, IN W/MILL X PMR PLUCKER DENVER REQION ~ ANCHORAGE DISTRICT ~ 05/03/87 ~ PAGE 3 2. 50 - OTHER, MILL 7" PKR AT 8200 FT. 3, 30 - TRIP, OUT X L/D VILLi P~,R PLUCKER; X JUNK PKR ~'~ 04/19/87 ~ .. -~ . . . . '" .. , QRANITE PO'~NT} '.PARKER '.i50,. AMOCO PRODVtT!0~, ... ... -. 'FLAC. 84'2709.~02-&, APl 50733203550~,-' AUTH ,.qc.x.~.u.~, $61'4000,. , . AMOCO .Wi'{.. ~. 6250 , . . OPERATIONS' TD ~455 'ET,. PBTD ~365', RETRIEVABLE PKR' .COSTS: DAILY WELL- $16777~, CUM WELL $3~i41 CHRON TIME DISTRIBUTION. (HRS)' . 8. O0 --' 'RBXS, 5-7~8 BIT X 7" SCRAPER TO' 8300 REV CIRC 2-1/2 HRS. TOH L/D TOOLS 3. 50 - TRIP, IN W/7" RETR BP - SET 8260 FT: , .~00 ~ = 2. 50 OTHER PRESS 9-5/8 ANN ~" , ._.l -- :)t_EE ]'0 1350 PSi IN :- MiN. MOVE RETR ~P UP '-' '- ~E, AT 8170 F~. PRESS TEqT W/ SAME RESULTS ~ 50 - TRTP OUT X ~ /D RUNNIN9 ]'no~ S 2. O0 - TRIP, IN W/ 9-5/8" RETR PKR 4. 50 - ~THER, 5ET P~4, R AT q-;ZOO FT. TEST 9-5/8 TO SURF 3000 PSI BLED *"~0 8GO.. PSI ~_~ M~N;., ~.'":'-"~/"~~, ._,, o SO0_ PSI IN 2 MIN; TE¢'~ 9-5/S TO 8!70 FT. 3000 PS'i --' OK. 13-3/8 ZERO PRES%. SET PP:,R AT n13B FT. Tr:~ e-siS TO ¢URF 3000 PSI BLED TO 500 PSI ! MI?q; ].3-~/8 DO0 PS! i MIN; TEST .......... ~K. 13-3/8 Z .... 0 PRESS 9--5./c~ --- 9!70 FI" 2000 Pf-~t ._ r-., ~p . SET Pt&R AT !0~70 FT. 'i'!iST 9-5/8 TO SURF. 3000 PSi BLED 'I'D 300 FSI 1 ~IN~ ].3-'3/;~, 3OO PSi i ~I]:N¢ TEST 9-5/8 TO 8170 FT. i500 PS! OF, ~3--~/a ZERO PRESS 1. O0 - TRIP, OUT X L/D RETRIEVAMATE Pi&Fi 04/20/87 , ~RANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAg 8~2709-02-6, AP1 507332035500, AUTH COST $&14000, AMOCO w.~. o. 6~0 OPERATIONS: TD 9855 FT, PgTD 9365, CLEAN X SVC RiO COSTS' DAILY WELL $18002, CUM WELL $57143 ~t;~ 05 1987 CHRON TIME DISTRIBUTION (HRS)' 2.00 - RSER, SLIP X CUT DRL¢ LINE ._¢a$~,Oil&GasOo~s.~|~iO-~ 3.00 - OTHER, TES] 9-5/8" CSg W/RETR BRIDGE PLUG mf' 839 650 FT TO 1500 PSI -SAME RESULTS UPPER LEAK 5.00 - FISH, 8RD XO ABOVE BP RETR TOOL BACKED OFF' - ATTEMPT TO SCREW BACK IN 8 83'7 Fl'. RAN TSA OVERSHOT X RETRIEVED RUNNING TOOL I BRIDGE PLUG - OK AT 837 FT. 2.50 - OTHER, TEST CSQ W/BP AT 470 FT. -OK HELD 3000 PSI ABOVE-- AT 650 -UPPER LEAK- AT 567 -UPPER LEAK- LEAK IS BETWEEN 1020 FT X 470 FT. 3.50 - RSER, ADd BRAKES - REPAIR SHEAR RELIEF. DENVER REGION *** ANCHORAGE DISTRICT ***. 05/03/87 *~* PAGE 0.50 - OTHER, L/D BAKER X TSA TOOLS 2. 50 - RTE, LOCKDOWN HANGER - REPACK SAME 4. 50 - OTHER, CLEAN RIG X UPPER DECK *** .0412'1/87 *** GRANITE POINT, 'PARKER i50. AMoc'O' PRODUCTt'oN,' '.' .. *******************-************************************************************************ FLAC 842709-02-6,- AP1 507'332035500,''AUTH COST.'$61~000;' : -- '" AMOCO W.I. 0.'6250. .- OpERATI'ONS' TD 9455 FT, PBTD.9365, SUSPEND OPERATIONS · COSTS: D~ILY WELL' $1~342, CUM WELL $69485 REMARKS' SUSPEND OPERATIONS WHILE A~UIRIN~ REPAIR MATERIALS X EQUIPMENT FOR DAMAGED 9=5/8" CS~. " CHRON TIME DISTRIBUTION (HRS)' 18.00 - SD, DRAIN X WINTERIZE MUD PUMP - CHAN~E UNiT CRANE BOOM HOIST ~OVE 3-I/~ ~ TO MAISE ~OOH FOR 5 DP X 9-5/~" CSg. CHg OUT PONY SUB oP~o~~,,,~.,,~,,_ ,~iTTINgS X gREASE SAME - CHAN~E BOTH .... ~xmK,. BANDS ON DRAWWOR!~S. , GRANITE POINT, PARKER i50, AMOCO PRODUCTION, FLAC 84~709--0~-6, AP! 507332035500, AL)TH COST s6!4000, AMOCO W.i. O. 6~50 OPERATIONS: TD 9455 FT' COSTS: CUM WELL $69485 REMARKS: SUSPEND OPERATIONS WHILE A~UIRiNO REPAIR MA]'ERiALS X EQUIPMENT FOR DAMAGED 9-5/8" CHRON TIME DISTRIBUTION (HR5)' 24.00 - OTHER, WAITiNg ON SURPLIES 04/23/87 , ~RANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 842709-02-6, APl 507332035500, AUTH COST S614000, AMOCO W.i. 0.6250 OPERATIONS: TD 9455 ET COSTS: CUM WELL $69485 REMARKS: SUSPEND OPERATIONS WHILE A~UIRINQ REPAIR MATERIALS X E~UIPMENT FOR DAMAGED 9-5/8" CSg. CHRON TIME DISTRIBUTION (HRS): 24.00 - OTHER, WAITINg ON SUPPLIES 04/24/87 *** DENVER REGION *** ANCHORAGE DIS]'RICT *** 05/03/87 *** PAGE 5 , (~RANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 842709--02-6, API 507332035500, AUTH COST $614000, AMOCO W.I. O. 6250 OPERATIONS: TI} 9455. FT, PBTD 9365, ND BOP COSTS' DALLY .WELL $8072, CUM WELL $77557 REMARKS-- RESTAR.':C'ED OPERATIONS. AT'..12.-NOON -~N-4-..-23'-87. ' . . . · · CHRON' TIME· .D'I-STRI'BUTION (H'RS)' . - - -. 3. 50 - TRIP, TO X 3=1/2 BUTT TB£~ LAYDOWN '~'3 .J]'S '"' .... . , 6. O0 - LOG,, RUN CALIPER LOg FOUND. NO HOLE X.' LO(...-' · 2. 50 - TRIP, PU CUTTER 7, 5"'DP~ TR'IP IN ~'.'mUL,--"q'= -f'O 10'3't' .TO CUT 9-518, CSg · . O. 50- OTHER, CUT 9-5/8" CSG AT 1034 1. 50 - CIRC, .CIRC 9-5/8 X 13-3/8 CSg 1. O0 - TRIP, TO X CUTTER 3. O0 NUBOP ND BOPS AND SWITCH " - , ARO,JN.~: SPOOLS TO BE ABLE TO PULL o ;'-,J,, o CSg ~-~ 04/2=/87~ , CRANITE POINT, PARKER i50, AMOCO PRODLiC"f'!ON, ~NQCO ~. I. O. 6250 OPERATIONS: TD 9,-1,55 FT, P~TD 9365, RUNN!NLJ ~'-.5/S" CASING COSTS: DALLY WELL '$72300, CUM WELL $!49857 CHRON TIME DISTRIBUTION 2. O0 -- NDgOP, INSTALL SPOOL 2. 50 - OTHER, STA~ 9-5/8" CS~ W/SPEAR; PLIL. L. CS(~ SLIPS FR~E N/225000~ X REMOVE FROM CS~; --' PULL TO FLOOR -REMOVE SPEAR 4. 50 - TRIP, POH LD 9-5/8" CS~; LD ~;2 ....~ 5' :5;' X LAND ,2'T X CUT JT FOUND HCu~ 421 F'r 3. O0 - NDBOP, INSTALL NEW APl RINC4-'tN S'TAC~&-iNSPEC'T ~OWL. 3. O0 - TRIP, RIH WITH SPEAR; STA~ !N CUT PIPE AT 103~ BUILD UP TORgUEJ APPEARED TO G&CK OFF FISHIN~ STRING TRIPPED OUT HOLE - CHECF, ALL CONNECTIONS - OK 3. O0 - TRIP, RIH HOLE W/SPEAR ~ACKED CASINg OUT W/TOOL~ DID NOT USE STRING SHOT "PON L.D 2 JTS PLUS CUT OF~ 1. O0 - RI¢, RI¢ DOWN FISHIN¢ TOOLS 1. O0 - TRIP, RIH TO ]'OP CS~ W/12-i/4" ~!T. POH 1. O0 - RI~, RI¢ UP TO RUN 9-5/8" CSG 3. O0 - RC, RIH W/9-5/8" CS~ WITH 5PECLAL TRI-STATE SCREW- IN-SUB. TORQUE TURI~ ALL RECEIVED 04/26/87 gRANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 842709-02-6, AP I 507332035500, AUTH COST $614000, DENVER REGION ~ ANCHORAGE DISTRICT ~- 05/0.3/87 ~ PAgE AMOCO W o I. 0. 6250 OPERATIONS' TD 9z~55 FT, PBTD 93&5, RIH TO CLEAN FILL COSTS- DAILY WELL $24971, CUM WELL $174828 CHRON TIME DISTRIBUTION <HRS)' O. 50 - OTHER, -~'~: ...... - ...... SCREW NEW CS¢, "NTO OLD - PUT lOOO0. FT--L~ TORQUE INTO WHDLE STRiN¢ X ~ORI&ED DOWN. '.-- .R~ 26 J.TS OF NEW.CS~ TOTAL W/K8 1142 '2.'50-'-TSTCSO', RI~'UP'LINES TO"TES~ CS~ TO. 3000 ~Si FOR 30' " MI~' - PIPE IN".TENSIOR"350000~ ' ' ~. 50 - 'OTHER, 'P/U 5TACK - CUT CSG~ SET 5LIPS~ CHG 5POOES .. .- . - . .C~ ~-~ _ TEST SLIPS 3000 'PSI¢ o~ SET iN SLIPS ,.,~0000~. TNSTALL FLOW NIPPLE- 2. O0 -' TRIP, RIH X POH X L/DOWN 5" DP 1. O0 - OTHER, CH~ 5-1/2" - 3" RAMS-TONGS-ELEV 1. O0 -- TRIP, RIH X LD 4-3/4 DC 3. 50 - TRIP, RIH W/3-1/2 DP TO 8160 FT. RET ~P 3. O0 - TRIP, POH W/BP 1. O0 - TRIP, RIH TO CLEAN FILL 04/27/87 , gRANiTE POINT, PARKER i50, AMOCO P!RODLiCTi{3!'q, FL. AC 8~2709-02-6, AP1 507332035500, *'""" r"~"~;':' SS~4nO0 AMOCO ~. ~. O. 6250 OPERATIONS' TD 9455 FT, P!~TD 9365, WAi]"~NC; !31".~ T'nn, c COSTS' DALLY WELL $i2798~,, CUM WELL ~'"'¢~-Ju~:~n*;.4 CHRON TIME DISTRIBUTION (t4RS)' 1. O0 - TRIP, RIH W/BIT 5--7/8 O. 50 - OTHER, SLIP DRLG L. INE 1. 50 - TRIP, P/U 37 JTS DP TAG FILL 9305 F'T. 6. O0 - CIRC, ~'"'' ~- .... CIRC REAM X REVERSE'] (;';Ti~n ] ........ ¢, C IRC CLEAN 3. O0 - TRIP, RIH W/BAKER MODEL F '.'" ~ ~__. ' {'~-" "~-'*-]' SET ACIDENTLY GOING THRU LINER TIE~AE.K AT 8i27. TOP OF HAN~ER 8121 1. 50 - OTHER, WORK PKR COULD NOT RETRIEVE-' RELEASE TO[IL POH 3. O0 - TRIP, POH W/PRR 5ETTIN¢ TOOL_ 3. O0 - OTHER, RUN ELECTRIC LINE IN HOLES R!"J UP APR ELECTRIC LINE - TRY TO DETERMINE EXACT L. OCATZON OF PKR-'CONFIRM PKR TOP IS IN BOT'TOFi OF HANGER TiE~ACK. 1. 00 - P/U, P/U 10 DC X STAND'ACK 3. 50 - OTHER, REPAIR SAFETY ITEMS-REPAiR R];Q BRA~;ES-' ~.~ 04/28/87 t'-' / gRANITE POINT, PARKER 150, AMOCO PRODUCTION, 'aska0il&GasO0ns. O0rn~iSBi~.fl- FLAC 842709-02-6, AP I 507332035500, AUTH COST $614000, DENVER REQION ~.*~ ANCHORAGE DISTRICT ~ 05/03/87 *~ PAGE AMOCO W. I. O. 6250 OPERATIONS: TD 9455 FT, PBTD 9365,- TEST PKR COSTS' DAILY WELL $171~4, CUM WELL $319958 CHRON TIME DISTRIBUTION 2. O0 OTHER WAIT ON TOOLS - REPAIR SAFE'TY ~ ~=,-,_, CLEEAN SHAKER PITS 1.'00 - 'OTHER, 'MAKE-UP .P'. R'. '1'. 'ASSEM . .. ' · 2.-00' - TRIP, RIH W/3-I/2 DP TO .81.28 PKR 2. O0 - FISH, P/U KELLY; MILL ON Pt<R " ~E-fRIEVE dUNK 3. 00.- TRIP, POH W/dUNK PKR ." · 3. 50 - RBXS, RIH W/6" BiT X 8200 FT' SCRAPER '. ~_.~50 - CIRC, CLEAN HOLE . 2. 50 - TRIP, POH' W/&" B~'¥ X SCRAPER · ~_.-~ 50 -- TRIP, RI~ UP BA.~ER MODEL F ?)~Ft - P*~H..~. W/PF..R ON WIRELINE; SET AT 8180 FT; POH Ri.w uU~:,~ Wi'pF''~ ~ O0 - TRIP, RIH WITH TES'T SEALc 1. O0 - OTHER, RI~ U~ AND TEST PKR ~.--~-~.- 04/29/87 ~.'~ , GRANI rE POINT, PARK~.·~ 1...u, ~.lflOCO r ~ ~ -~ %-i~ ;~--i~ %-~- ~ ~- ~r ~ .-~. ~--,~'~- ~- ~' -~ ~" .-~, '~- % ~ ~' e~' ~-~- -~ e~ ~- ~ ~- ~' % ~ ~- ~' ~ ~' , ..... ~ :.~' '~' '~.~' ~ ~ ~ ................... AMOCO W.I. 0 6250 COSTS DAILY WELL $37~8.:, CU~'i WELl ..... CHRON TiME DISTRIBUTION 10. O0 - LDTRIP, POH X I_D 3-i/2 DP 2. O0 - OTHER, RI¢ UP PKR SEALS ,,Y n~,..,-~,'~'~c'~-"i-P:S;'"F ..... 12. On_ -. RTD, P/U X R!'H W/3--1/2 DSS '"'~ ::E~ ..... X ;3AI'EE'~:~ .... SEiA~_. AE~r_~' ~- 04/30/87 , ORANITE POINT, PARKER 150, AMOCO PRODUCTION, FLAC 842709-02-6, AP1 507332035500, AUTH COST $6~.4000, AMOCO W.I. 0.6250 OPERATIONS: TD 9455 FT, PBTD 9365, SKIDDIN~ COSTS: DAILY WELL $19808, CUM WELL $3'7~947 CHRON TIME DISTRIBUTION (HRS): 3.00 - RTG, RIH W/3-1/2" DSS HTC 1.50 - OTHER, STA~ IN PKR TB~ DEPTH FOR P!&f~ - 8!~7 FT. SHOE AT 8198 FT TEST AT 3000 PSI FOR 30 MIN - SPACE OUT TOG INSTALL HANGER. 2. 50 - CIRC, INHIBITED FLUID, FRESH ~AI-ER W/CAUSTIC, B!OCID WELLAID 840. PH-11.0. 1.50 - OTHER, LAND TOG W/15000 LB ON LOCATOR 3.50 - NOBOP, ND BOP 6.00 - NU, NU TREE; TEST TREE TO 5800 PSI - INSTALL LINES; CLEAN RIG FLOOR NEW STAINLESS STEEL AdG 0 5 1~7 ~as~ Oil & G~$ C~.s. Anchorage DENVER RE~ION ~ ANCHORAQE DISTRI_C.]' -~-~-~ 05/03/87 ~.~.~ PAgE MASTER VALVE INSTALLED 5.00 - OTHER, UNHOOK SERVICE LINE~ CHANGE OIL IN RIQ; REWORK PUMP; BLOWOUT ALL LINES X WORK OVER MUD PUMP 1.00 - MO, SKID RI~ ,~. ~- 05/01/87 · · . . , '~RAN~TE POINT', PARKER .150, AMOCO PRFJDU~T!.F~-.:'.i. ' FLAC 842709-02-6, AP1 507332035500, AUTH AMOCO W.I. O. 6250 OPERATIONS: TD 9455 FT, PBTD ~365, RI~ 'RELEASED COSTS' DAILY WELL $8866, CUM WELL' REMARKS ~LEA~ RI~ oYACK OL;T DECK ............ WELL ~_~. RI~ RELEASED AT ~ NOON i~['l .4,.'30/~7 CHRON TIME DISTRIBUTION (HRS)' ~ O0 - MO, S~ID RIG 4. O0 - OTHER, CLEAN DECK; RELEASE 12. O0 - OTHER, WORK 3 MAN CRANE CREW 'l-O '~-'~:~,,*c=F~ ~i~ i"O OTHER PLATFORM RECEIVED 0il & Gas Cons.. Anchorag~ DENVER REGION *** ANCHORAGE DISTRICT .*~* 05/03/87 END-OF-dOB SUMMARY' *** FINALLED dOB INFORMATION' ~RANITE POINT, , , KENAI O/S STATE, ALAS~qA OPERATOR' AMOCO PRODUCTION OPERATIONS COMPLETED DATE 04/30/~'~,~ TOTAL DEPTH 9455 F'T, PLUg I~AC~. TOTAL DEPTH CUMULATIVE dOB COST USELESS FOOTAGE 0 FT W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 March 26, 1987 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 AttentiOn· C. V. Chatterton, Chairman File- FEW-O52-WF Application for Sundry Approval G.P. 18742 Well No. 46 Platform Anna, Cook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403 outlining our proposal to. repair Granite Point 18742 Well No.'46. This injection well was shut-in on January 26, 1987, after we confirmed communication between the tubing, 9 5/8-inch casing, and 13 3/8-inch casing. The proposed workover will investigate the casing integrity and repair the casing communication by running a 7-inch liner tieback or by repairing 9 5/8-inch casing. The well will then be recompleted with a new string of internally coated tubing. We anticipate beginning repair operations On the well on April 1, 1987. A BOP sketch and current wellbore diagram are attached. Sufficient notice will be given so that a representative from your office may witness the BOP testing. Please contact Jeff Blagg at 562-2147 if you have questions or require additional information. Very truly yours, W. G. Smith District Manager Attachments JCB/dds STATE OF ALASKA APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing ;ID Time extension [] Change approved program [] Plugging [] Stimulate ,~ Pull tubing I~ Amend order [] Perforate [] Other [] 2. Name of Operator Amoco Production Company 3. Address P.O. Box 100779, Anchorage, Alaska 99501 4. Location of well at surface 829' FNL, 673' FEL, Sec 12; T10N; R12N, S.M. At top of productive interval 1874' FNL, 1937 FEL, Sec 12, T10N, R12W, S.M. At effective depth 1888' FNL, 2237 FEL, Sec 12, T10N, R12N, S.M. At total depth 1886' FNL, 2262 FEL, Sec. 12, T10N, R12 N, S.M. 5. Datum elevation (DF or KB) 105' KB 6. Unit or Property name Granit~ Pnint 7. Well number 46 8. Permit number 82-72 9. APl number 50- 733-20355 10. Pool Middle Kenai '"'C" feet 11. Present well condition summary Total depth: measured true vertical 9,455 feet 9,124 feet Plugs (measured) Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9,365 feet 9,036 feet Length Size 62' 20" 4:,232' 13 3/8" 8,332' 9 5/8" 1,334' 7" measured Top at 8,330' Bottom at 9,324' true vertiCa~op- at 8,052 ' Bottom at 8,996' Junk(measured) Cemented Measured depth True Vertical depth 1,500 sx 625' 625' 2,555 sx 4,232' 4,206' 675 sx 8,332' 8,050' 305 sx 8,I2I-9,455' 7,846'-9,124' Tubing (size, grade and measured depth) 3½" N-80 at 8,209' Packers and SSSV (type and measured depth) Baker Model F-1 at 8,200 feet 12.Attachments Description summary of proposal [] Detailed operations program ] BOP sketch 13. Estimated date for commencing operation April 13, ]987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby cert!.fy that th.c~foreg~ng istrue an~ correct to the best of my knowledge Signed ,~~. _,.....~~ Title District Man~ger Commission Use Only Date 03 /2~r/87 Conditions of approval Approved by ~¥ t~i~I~ ~. ~,,~lii~'~ Form 10-403 Rev 12-1-85 Notify commission, so representative may witness I Approval No. [] Plug integrity ~BOP Test [] Location clearanceI -~" , ,, ,-: ,-- by order of -'-- 'Commissioner the commission Date Submit in triplicate Description Summary of Proposal 1. Set back-pressure valve, nipple down tree, nipple up BOP's and test to 3,500 psi, pull back-pressure valve. 2. Pull tubing and seal assembly. 3. Investigate casing integrity to determine location and severity of the 9 5/8-inch casing leak. 4. Mill and retrieve Model F-1 packer set at 8,200 feet. 5. Set a bridge plug at 8,200 feet. 6. Dependent on the results in Step 3: a. Run 7-inch liner tieback from 8,121 feet to cover bad 9-5/8-inch casing. Cement liner. or Repair 9 5/8-inch casing utilizing an external casing patch or back-off/replacement method. 7. Retrieve bridge plug. 8. Set packer at 8,200 feet. 9. Run new seal assembly and internally coated 3 1/2-inch N-80 tubing. Sting into packer at 8,200 feet and land tubing. 10. Set back-pressure valve, nipple down BOP's nipple up tree, and test to 5,600 psi, pull back-pressure valve. 11. Run state required annulus pressure test. 12. Return well to injection. SPUD DATE: SURFACE LOCATION: SUBSURFACE.LOCATION: ELEVATION: I'D: PBD: INITIAL POTENTIAL~ INITIAL STIMULATION: CASING RECORD: COHPLETION RECORD PFRFO2ATIONS: P, ESEP, VOI R DATA: CORES: D ;; 'F: ~' r: L -r'.¢ T I VE TESTS: L r'": I 'tVE[!TORY: GRANITE POINT ADL 18742 WELL N0.46 MIDDLE KENAI SANDS g6-28-82 LEG 3; SLOT 2; G.P. PLATFORM ANNA. 829' FNL, 673' FEL, SEC. 12, TI~N, R12W, S.M. 1886' FNL, 2262" FEL, SEC. 12, TINN, R12W, S.M. 1~§' KB, MSL GL. 9,455' MD, TVD: 9,124' 9,365' MD, TVD~ 9,~37' 2879 BWIPD @ 558~ PSI; ANNULUS PRESSURE 3~8~ PSI. NONE. 2~", 94# K-55 TO 625', SET W/15~ SX. 13-3/B", 72# N-88, 54, 61, 68# K-55 TO 4232', SET W/2555 SX. 9-5/8", 4~, 43.5, 47, 53.5# S-95 TO 833Z', SET W/675 SX. 7" LINER 29# N-8~, S-95 FROM 81Z1-9455', SET W/305 SX. 1) CAMERON 1~" SINGLE TBG. HANGER. 2) 3-1/2" BUTT TBG W/ABC COLLARS. 3) 3-1/2" BUTT PUP. 4) SEAL LOCATOR. 5) SEAL ASSEMBLY. 6) 3-1/2" BUTT PUP W/SLIM LINE COLLAR. 7) MULESHOE. C-4: 8339-8374' C-7: C-5: 8458-8515' 8551-8596' C-B: 884~-8878' 895~-9~17' 9~5G-9~77' 9198-9228' 9246-929G' 93~4-9324' 34' 8179' 8183' 8184' 82Z8' 82Z9' NONE. NONE. NONE. SONIC. DUAL INDUCTION. GAHHA RAY. SP 8332-9455'. CEMENT BOND G3~-83~4'. AS RUN 12-~6-84 __1 BAKER MODEL 'F-I' PACKER IW/4" BORE SET @ B2~' ON DP 8-7-8Z. I.D. SEAL ASSY 3.~". XX 4 XX = 5 ' 6 7 IIIIIII · TOP OF 7" LINER @ ."8121 ' PBO- 9,365' TD= 9,455' ":~ · ,. '" SHE£T NO. OF '~'~'~ Amoco Production Company ~,~. ENGINEERING 6HART APPN . - ........... ~ , ', ~--~-+-~--, .... : ..... ~.__~ .... ........ . ~ ~ ........ ~ r -~ .... , . . ., Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 W. G. Smith District Manager January 29, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 File: FEW-O22-986.511/WF Gentlemen: Granite Point 18742 Welt No. 46 Granite Point Field, Cook Inlet, Alaska Reference is made to a telecon between M. T. Minder and F. E. White on January 27, 1987, regarding the lack of mechanical integrity of the tubing/casing annulus in the referenced well. It was confirmed on January 26, 1987 that there is communication between the tubing, 9 5/8-inch casing, and the 13 3/8-inch casing in Granite Point 18742 Well No. 46. The well is currently shut in and will remain shut in until a workover to reestablish the mechanical integrity of the well has been completed. An Application for Sundry Approval, Form 10-403, will be forwarded for your approval under a separate cover letter after we develop an economic proposal to repair the well. This letter represents written notification of well integrity failure of the referenced well which is required under Rule 7, Area Injection Order No. 6, Northern Portion of Granite Point Field, dated September 4, 1986. Please contact Fred White at 562-2147 if you have questions or require additional information. Sincerely, W. G. Smith Di stri ct Manager FEW: cm O07/FEW January 8, 1985 File' TJZ-O12-WF Amoco Production Company (USA) Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Notice Granite Point 18742 Well No. 46 Platform Anna, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-403', Sundry Notices and Reports on Wells, subsequent to repairing a communication leak in Granite Point 18742 Well No. 46. A leak was found in the seal assembly. The well was returned to injection and is currently injecting 2,416 BWPD at 5,430 psi. Please direct any questions concerning the project to Mike Schwein in our Anchorage office. Very truly yours, W. G. Smith District Manager Attachment MTS/dds RECEIVED JAN 1 0 l B5 Na$i<a Oil & Gas Cons. comm'msion Anchorage )l STATE OF ALASKA OC ALASKA L AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL,I~ OTHER [] 2. Name ~moco Production Company 82-72 o Op_erator, 7. Permit No. 3. Addressp 0. Box 100779, Anchorage Alaska 99510 8. APINumber · , 50- 733-20355 9. Unit or Lease Name Granite Point 18742 4. Locatiop of Wp. JI Leg 5, Slot 2, Granite Point Platform Anna 829' FNL, 673' FEL, Sec. 12, TiON, R12W, S.M. 5. E levat i~ncj~ Jeek~s'ndic t ~LKe. DF, etc.) 6. Le~LDe~n~n and Serial No. 10. Well Number 46 1 1. Field and Pool Granite Point Field Middle Kenai "C" Sands 12. 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 [] [] Other [] Pulling Tubing ~ Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10.407 for each completion.) 13. Describe Proposed or completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company performed the following work: 1. Circulated and killed well. 2. Set back-pressure valve, nippled down tree, nippled up BOP's and tested to 2,500 psi. Pulled back-pressure valve. 3. Pulled tubing and seal assembly. 4. Ran new seal assembly and tubing using existing packer set at 8,200 feet. 5. Set back-pressure valve, nippled down BOP's, nippled up tree and tested to 5,600 psi. Pulled back-pressure valve. 6.'~ Returned the well to injection. RECEIVED JAN 1 0 1985 Alaska Oil & Gas Cons. Commissi~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. (/~ / ~,~ District Manager Signed(/d C"[ ~J/'~ __ -_,-__' Title The space below for Commission use 01/08/85 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate W. G. Smith District Manager Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 October 22, 1984 File: TJZ-160-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Notice of Intent Granite Point 18742 Well No. 46 Platform Anna, Cook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of our intent to repair a communication leak in Granite Point 18742 Well No. 46. The well is currently shut-in due to tubing/annulus communication. We plan to begin this work as soon as possible. Any questions concerning this project may be directed to Mike Schwein in our Anchorage office. Very truly yours, W. G. Smith Di strict Manager Attachment MTS/dds RECEIVED AlasKa 0ii & Gas Cons. Commission -Anchorage ( STATE OF ALASKA N('f5 ALASKA OiL AND GAS CONSERVATIO dMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~) OTHER [] Name of Dperator Amoco Production Company Addressp. 0. BOX 100779, Anchorage, Alaska 99510 4'L°cati°t~¢e§, Slot 2, Granite Point Platform Anna 829' FNL, 673' FEL, Sec. 12, TION, R12W, S.M. 5. Elevatio~ ~f~etKB ,(indicateMsL 'KB DF, etc.) 12. 7. Permit No. 82-72 8. APl Number 50- 733-20355 9. Unit or Lease Name Granite Point 18742 10. Well Number 46 11. Field and Pool Granite Point Field 6. Lease Designation and Serial No. Mi ddl e Kenai Sands ADL 18742 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 or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.'105-170). Amoco Production Company plans to' 1. Rig up wireline and test lubricator to 2,500 psi. Perforate tubing at 8,150 feet. 2. Circulate and kill well. 3. Set back-pressure valve, nipple down tree, nipple up BOP's and test to 2,500 psi. Pull back-pressure valve. 4. Pull tubing and seal assembly. 5. Run new seal assembly and Atlas Bradford DSS-HTC coated tubing. 6. Set back-pressure valve, nipple down BOP's, nipple up tree and test to 5,600 psi. Pull back-pressure valve'. 7. Return the well to injection. the best of my knowledge. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the~L~oing i~ue a~d corre~o Signed ~/~j~~ The space below for Commission use Title District Manager DatelO/22/84 Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 COMMISSIONER Approved Copy RetFrned / / I ByOrderof ~._ ~T~ri~e- the Commission Date ~ ,,- ~, .' Submit Intentions ~ and "Subsequent Reports" in Duplicate ALASKA OIL AND GAS CONSERVATION COMMISSION Date: March 15, 1983 · SAY S. HI~tlOND, 300 ! PORCUPINE ~)RiVE.ANCHORAGE, AI. ASKA To: Amoco Prod. Company Re: sEPIA of TRAVEL TIME TRACER LOGS Transmitted-via 1 1 1 l' 1 ~eazT~t are the following: Descri t~_~ of Item Granite Pt. 18742 #MUC 1-3 G.. PT. 18742 #7RD G. PT. 18742 #19 G. PT. 18742 #27 RD G. PT. 18742 #28 G. PT. 18742 #29 G. ,Ff. 18742 t/46 RECEIVED 7'83 ANCttORAGE DISTRICT MAR 2 2 1983 Please acknowledge receipt by Alaska Oil & Gas Cons. Commission Anchorage . : n- signing and returnz ~ one copy of this letter· ALASKA OIL Yours very truly, & GAS CONSERVATION COMMISSION ALASKA OIL STATE OF ALASKA AND GAS CONSERVATION COM[~IISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: Amoco Production Company P.O. Box 779 Anchorage, Alaska 99510 -% Receipt of the ._ ._c3..,". ~:~: following material which was transmitted via is hereby acknowledged: QUANT I TY ,/ ~ (~,..~ ~-~) DESCRIPTION ~/ - ~Tv~ > / Copy sent YES ~ to sender NO __ L. A. Darsow District Superintendent September 10, 1982 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 File: LAD-966-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Well Completion Report Granite Point 18742 Well No. 46 Platform Anna, Cook Inlet, Alaska Enclosed in duplicate is State of Alaska Form 10-407, Well Completion or Recompletion Report and Log, for the subject well. A directional survey, magnetic tape of the logs, and a well history are also enclosed for your information. Yours very truly, L. A. Darsow District Superintendent Enclosures KEO/klt (~mI ~ .... STATE Of ALASKA /~ ALASKa..~;.~.ND GAS CONSERVATION ~ .... iSSlON WELL COMPLETION OR RECOMPLETION'j EPORT AND LOG · 1. Status of Well Classification of Service Well · OIL [] ' GAS [] SUSPENDED [] ABANDONED [] SERVICE ~ Water Injection 2. Name of Operator 7. Permit Number Amoco Production Company 82-72 3. Address 8. APl Number P. 0. Box 779, Anchorage, Alaska 995]0 50- 733-20355 4. Location of wellatsurface Leg 3, SI ot 2, G.P. PI atform Anna 9. unit or Lease Name 829'FNL, 673'FEL, Section 12, TION, R12W, S.M. Granite Point State 18742 At Top Producing lnterval C-4 Sand, 1870'FNL, 1925'FEL, Secl:l,C~/~,Tl~lC; lO. WellNumber T1ON, R1 2W, S.M. VERIFIED 46 At Total Depth Surf. 1~_ 11. Field and Pool 1886'FNL. 2262'FEL, Section 12, TION, R12W, S.~.H. ~ 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Middle Kenai Sands 105' KBI Granite Point State 18742 Granite Point Field 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore 116. No. of Compietions 6-28-82 . 8-4-82 8-26-82 Comp.1177feetMSL 1 17. Total Depth (MD+TVD)18.Plug Back Depth (MD+TVD)19. Directional SurveY9455. MD, 9124' TVl) 9365' MD, 9037' TVDYES I~ NO [] I2°' Depm where sssv setN/A feet MD I21' Thickness °f Permafr°st0 22. Type Electric or Other Logs Run · Dual Induction, Sonic, Gamma Ray/Spontaneous Potential (SP); Cement Bond Log Inside 9-5/8" , 23. CASING, LINER AND CEMENTING RECORD. Casinq SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED SEE ATT,~CHED SH[:ET ]' 24. Perforations open to P[oduct on (MD+TVD of Top and Bottom and. 25. TUBING RECORD ' I :.. in.terval, size and number) ,. SIZE DEPTH SET (MD) PACKER SET (MD) Net 3-1/2" N-8~ 8228' 8200' MD TVD Interval ,. ~one. }i' 8330-8374' 8048-8090' 44' C-4 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8458~-8596' 8171-8303' . 1 ' ' .05 ,: · ·; C-5 . DEPTH INTERVAL (.MD) AMOUNT& KIND OF MATER AL USED 8840'9077' 8536-8762' 126' C-7 .'. . 9198-9324' 8878-8999' 100' C-8 · ~i~e"~ 0/36" 27. PRODUCTION TEST Date First Production . . . . Method of .Operation: (Flowing, gas:lift, etc.) '.., .: . ~,; ,:,: ~'8Z1:~,82 ' . . ,, ,.. - Water Injection, . '.. · Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO · . 8-26..82 :.. 24,. TESTP. ERIQDI~ ,,.:', 0 :.,.''0.. 2879 ' -'I N/A: ' Fl~'~u~i'ng ",'.. Casing Pressur.e CALCULATED i~ OlL-BBI' GA'S-MCF WATER.-BBL OIL GRAVITY-APl (corr) 'Press.' ~500 "',3000 ' ' 24-HOUR RATE '~' '. 0 ' ..;'" ,'0". ., 2879 N/A . : 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. , . .' .~.; .' . ,~...,,....-... · .. : .. .. , · ... , · . :.. , None · . ... . , . ~..~ ?~'~ . .,· Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE . GEOLOGIC MARKERS ' ORMATIONTESTS "' . ' ! '" NAME Include interval tested, pressure data, all fluids recovered and gravity, ~ MEAS. DEPTH TRUE VERT. DEPTH GOR. and time of each phase. 31 ...LIST OE ATTACHMENTS 32. I here~3y certify that theforegoing is true end correct to the best of my knowledge . '~ ' Signed .. Title Superintendent, . Date INSTRUCTIONS General:' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of ·Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherWis.e shown) for depth measurements given -in other spaces, on this form and in any attachments. I-tem 16 and24:' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the Producing inten/als for only the interVal reported in item 27. Submit a separate form for each additional interval to.be separately produced, showing the data pertinent to such interval; Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none", Form 10-407 ATTACHMENT TO STATE OF ALASKA FORM 10-407 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 23. Casing Size Wt. Per Ft. Grade Amoco Production Company Granite Point 18742 Well No. 46 Platform Anna, Cook Inlet, Alaska Casing, Liner and Cementing Record Setting Depth MD .Top Bottom Hole Size Cementin~ Record Amount P~ed 20" 94# K-55 0 625' 26" 1500 Sacks Class G 13-3/8" 72# N-80 54#, 61#, 68# K-55 0 4232' 17-1/2" 2555 Sacks Class G 9-5/8" 40#, 43.5#, S-95 47#, 53.5# 0 8332' 12-1/4" 675 Sacks Class G 7" 29# N-80 S-95 8121' 9455' 8-1/2" 305 Sacks Class G 811120 Granite Point 15742 Well No. 46 Platform Anna Directional Survey DEVIAT.,ON SURVEY CALCUL_A'F'ON~?, USIN~ VARIOUS :',~FntJDS. DO YOU NEED INSTRUCTIONS FOR RUNNINg PRO~-;RAM? WHAT IS THE NAblE OF YOUR DEViAi'ION FILE? gpno. 46 DO SURVEY CALCULATIONS START FROM SURFACE? CALULATiON METHOD: ENTER A FOR ,ANW__~ ~' ~ '~ Ng ~=RA~I PtETHOD ENTER B FOR BALANCED TANGENTIAL METHOD ENTER M FOR MINIMUM CURVATURE METHOD ENTER ME FOR MERCRY METHOD ENTER R FOR RADIUS OF CURVATURE METHOD ENTER T FOR ]'AN(}ENTIAL ~' .... n TARCET DIRECTION ( N, s~ ~1. 3, ~ START PRINTOUT AT NHAT DEPTH 0 RADIUS EIF CURVATURE METHOD ION OR mLOSURE.., DIR~uTI,~,. _TS ~_-~-*. 3 DEGREES 'gPNO. 46 ' AUO* 16, 1982 ~ '~7 PM MEAS. DEPTH NORTH DEPTH ( TVD ) -SOUTH ~,~! 416 416. O0 ~599 598. 98 ,~,~f~' --764 763. 94 1164 1t63. 81 1474 i473. 69 1766 1765. ~I 2060 =0~9. 2374 2372. 9~ 2680 2678. 59 2990 2988. '~ 330~ 3302. 6~ 3481 3477. 40 , I! 3635 3628. 24 ',~ ~ ~036 4016. 33 ~.375 0.74 -0.52 0.45 -~.43 ~ 33 -0. ,~ -0. 04 -0. i6 :,~ 19 -6.30 6.04 -t4.19 11.05 -~3.05 15.28 -~.~" 78 18.27 -47.83 20. 18 -62.38 21. 09 -77. ~'~1 20.48 -88.91 19.85 -96.08 10 54 -1~3. ~ 96 -12 ~7 -i~ 68 -41.24 -159.14 -85 30 -203.98 4191.57 -115 03 -238.18 4343.99 -140 32 -271,14. 4593 4550.04 -179 99 -~.. 95~ 4790 4731.70 -227 31 -389.44 4944 4871.97 -272.25 -43~.38 5047 4965.03 -304.00 -465.04 ~216 5118.95 -360.94 -504.91 5371 5261.36 -414.96 -533.63 ~ ~'~.~ · '~,C.'~. ~ --~ -0. 06 1.61 2.13 0.15 3. 55 7. 30 11. 08 16. 81 25. 91 36. 07 47. 07 56. 59 62. 57 ,-32.24 112. 44 149. 99 ~12. 53 ':257. 80 ,-- 9 ,.34 ~ / ,,..,'. 04 446. 05 509. 22 553. O0 6,19. 72 675. 91 --'. q"~30 ].. ,,u~:~,~4~,?0. 25 N35W n. 0 2 N79W 1.25 S!SW 0 8 k7 S20W 1.25 S77E ! I 0 S74W 1.50 N69W ! 8 7 N71W i.50 N71W 0 0 ~5 N67W 1.75 N57W 0 '=' 2.25 N64W O.~ =~'N64W 37 N66W £.o~ ~-~ N6~W, 3.00 N8~W 0.3 65 N.~W ~. 50 NB2W O. 80 ~ ' nO S89W 0.2 9*~ N77W ~°. 25 S85W O, ~ N78W D. O0 S85W ~.7 114 N85W 8. ~0 S40W 3. 5 !34 S84W 14. 50 S40W 3.9 164 S75W 14. 50 S44W 0.7 ~,=~ S67W ~4.. 75 S47W O. 3 =04 S64W 1.4.25 SS1W 0. 6 =~ S63W 16.25 S54W 1.4 376 S61W ~!.75 S58W 2.6 451 S60W 23.75 S45W 2.7 ~13 S58W 25.00 S45W 0.8 DD6 S57W 25.75 S43W 1. 1 6~! S54W 23.00 S27W 4.2 676 SS~W 23. 50 S29W 0.6 / ~u"~ 2~. _ S30W 0.3 s7.s~ ~956 6171 6360 6547 6737 697! 7215 / 7655 7723 7862 7946 8089 8140 8306 ~4~0 8708 909~ 9416 5609.83 5799.55 6001.09 6179.66 6357.12 6537.16 6757.9! 6987.73 7282.09 7401.61 7465.86 7597.77 -544.82 -611.&O -608.00 -656.37 -666.99 -702.75 -713.71 -743.37 -756. li -784.31 --796.6'9 -829.39 -844.49 -890.56 -891.48 -'957.67 -946. =-'7 -i C)48._ '~7 -966. 75 -1086. -977. 21 -1106. 25 -997. 44 -!!45. 12 7677.82 -1008.59 -!167.97 7814.93 -~0~5 ~3 1~04 78~4. !~ -1030. 52 -1217 8024.59 -1043.33 -1257 8201.45 -1055.60 -1307 8409.92 -1065.56 -1369 8776~65 -1067. 54 -1483 9086.48 -1058.47 -1577 93 22 84 05 92 72 9455 9!23. 87 -!056. 64 -!588. B~7.. 96 .~.,~9, S48W ~-_=.~ 50 ~92. ~ -,~ S47W ~I. O0 ~6s 47 ~o S46W i° '~ t!4D. 4! 1'i~0 S¢6W 19. O0 1~-.. ~") 227 ~ 75 1 ~)4. 79 1410. 22 I''=~ 45 '~. I . .4 S4BW 19. 1474. ~ 1476 S49W 19. 00 1517. 33 ~slo~, · S49W .~7. 75 15~. 14 i543 S49W 17. 50 1594. 28 ~5 °~t~" 4. 5 ~/-~'~,~,. 9e ="634 SSOW 1~ O0 . o~.~ 17. 00 ITM. 73~ i ~ ~, 36 I SS~W ~. O0 18~5 41 I~='~8 S54W 1= 50 ~ 893 '~ ...' ..... i''~ ....S56W 15. 50 !900. 66 !90~ S56W !6. 50 34W O. S37W I. S39W O. ~43~ ~ ~ . ~45W n SSiW 1. S53W O. ¢57W n S61W 0. S6~W O. S62W O. S63W O. S65W O. S66W 1 S69W 2. S76W 576W I S86W I N88W 0 N8IW 0 NSOW O. 7 3 7 0 4 ! 4 6 5 9 8 4 1 I 1 3 7 7 VERTICAL ¢_.,TICAL C TRUE ~ ~R DEPTH ALCUL. ,~"~*' USING RADTUS OF CUR~ATUn SECTION OR Ctf'i~t~RF DIRECTM ~ '~ ,_ ..... ~iu~-4 t~ 2~t.~ DEGREES GPNO. 46 AUG 16, 1982 7.33 PM (FORMATION. TOPS ONLY) TRUE VERTICAL SUBSEA DEPTH DEPTH DEP TH ~_mo! '¢~.RT I'C NORTH '- -SOUTH -WEST SECT I ON 7735 7630 8006.00 7881 7776 8158.00 7978 7873 8258.00 8001 7896 8282.00 8116 8011 8402.00 8333 8228 8623. O0 8518 8413 8822.00 8840 8735 9159.00 9059 8954 9388.00 9086.48 898i~48 9416. -1015.66 -1183.48 1558.66 -1031.91 -1221.63 1598. 59 -1039.63 -1246.09 1622. 51 -1041.48 -1251.97 !628.25 -1049.73 -1283.51 1658.03 -1061_90 -i346.85 1715.07 -1066.15 -1403.70 1762.09 -1065~ 67 -1503.21 1839.45 -1059.~5 -!569. 81 1887~ 4~ -1058.47 -1577.95 !893.28 LAST POINT IS DEEPEST SURVEY IN FILE. Chronological History of Events Granite Point 18742 Well No. 46 Platform Anna, Cook Inlet, Alaska Date 6/27/82 6/28/82 6/28-7/1/82 7/2-7/12/82 7/13-7/26/82 7/27-7/28/82 7/29/82 7/30/82 ,?/31-8/4/82 8/5-8/6/82 8/7/82 8/8/82 8/9/82 8/10-8/11/82 8/12/82 8/13-8/26/82 Event Operations commence; install riser and rig up to spud. Clean out 30" conductor and spud well. Drill 26" hole to 631', run and cement 20" casing at 625'. Drill 17-1/2" hole to 4242', run and cement 13-3/8" casing at 4232'. Run leak-off test to 14 PPG equivalent mud weight. Drill 12-1/4" hole to 8385'. Run dual induction, sonic, SP, gamma ray log from 4232-8385'. Run and cement 9-5/8" casing at 8332'. Run cement bond log 6300-8304'. Perforate four holes in 9-5/8" casing at 8213'. Attempt to establish injection rate in perforations. Maximum pressure 2500 psi, maximum rate 0.071 BPM. Drill 8-1,/2" hole to 9455'. Run dual induction, sonic, SP, gamma ray with caliper log from 8332-9455'. Run 7" liner, 8121-9455', and cement. Clean out casing to PBTD of 9365', test liner lap, negative and positive test okay. Displace well with filtered Inlet water. Set packer at 8200'. Run 3-1/2" tubing, hydrotest to 5800 psi and land in packer. Nipple down B.O.P.E. and nipple up wellhead. Perforate 8330-8374', 8458-8518', 8551-8596' 8840-8878' 8950-9017' 9056-9077' 9198-922~' 9246-9296', 9304-9324' with 2-1/8" tubing guns, 4 JSPF at zero-degree phasing. Install flowlines and initiate water injections. Repairs to surface waterflood equipment. Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. Operator, Wel 1 Nam~ and Number and Materials to be received by: Reports ' Date Required Date Received Remarks Completion Report Yes We11' History Yes _Samples · , \ Core Chips ~/X/~'/"~., ~'" .... ...... ' d: fx~' ' i,~ , , , ~ , · ,, , Core Description /~: /$/,~.,. ( ,~ Registered Survey Plat y -- , , , , Inclination. Sudsy . s , , ,,. . ..Dire~i°nal, . ~ey .... ~ ~. ~ _ ~; ~'~ ~ _ ~ ~ ~ ~' ~ ~ ~ ~, ... Drill. St~ Test Ro~s . , ,, ,, - .,, - L. A. Darsow District Superintendent August 13, 1982 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 File: LAD-880-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' Monthly Report of Operations Granite Point State 18742 Well No. 46, Platform Anna Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced well, reporting July 1982 activities. Very truly yours, L. A. Da rsow Di stri ct Superintendent Attachment WHP' cm CEIYED UG ! ? 1982 /~!aska OiI & Gas Cons. Commission Anchorage MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~ Granite Point 18742 Well No. 46 Workover operation [] 2. Name of operator 7. Permit No. Amoco Production Company 82-72 3. Address 8. APl Number P. 0. Box 779, Anchorage, Alaska 99510 so_733-20355 4. Location of Well atsurface Leg 3, Slot 2, Granite Point Platform Anna 829' FNL, 673' FEL, Section 12, TION, R12N S.M. Primary Target: C-5 Sand; 1800' FNL; 1900 FEL, Sec. 12, TION, R12W, S.M. ,-8000' SUBSEA 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 105' KB Granite Point State 18742 9. Unit or Lease Name Granite Point State 18742 10. Well No. 46 11. Field and Pool Middle Kenai Sands Granite Point Field For the Month of July ,1982 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud Date - 06-27-82 TD-8700' on July 31 8069' Drilled during July No'fishing operations or directional problems 13. Casing or liner run and quantities of cement, results of pressure tests 13 3/8" casing set at 4232.2' on 7/10/82. Cemented with 1855 sacks of cement. 9 5/8" casing set at 8332 on 7/27/82. Cemented with 675 sacks of cement. 14. Coring resume and brief description None 15. Logs run and depth where run Logged DIL and BHC Sonic Log from 8385 to 4232' 6. DST data, perforating data, shows of H2S, miscellaneous data None AUG 1. ? i982 Oil & Gas Cons. Commission ,~nchorag9 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED TITLE F)i~trict Superintendent DATE 08/13/82 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and .must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate R~.v. 7-1 -ROI L. A. Darsow District Superintendent July 14, 1982 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 File: LAD-763-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' Monthly Report of Operations Granite Point State 18742 Well No. 46, Platform Anna Cook Inlet, Alaska Attached in duplicate is State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced well, reporting June 1982 activities. Very truly yours, L. A. Darsow Di stri ct Superintendent Attachment LRN' cm ALASKA L AND GAS CONSERVATION C MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well)~] Granite Point 18742 Well No. 46 Workover operation [] 2. Name of operator Amoco Production Company 3. Address P. O. Box 779, Anchorage, Alaska 99510 4. Location of Well at surface Leg 3, Slot 2, Granite Point Platform Anna 829' FNL, 673' FEL, Section 12, TION, R12N S.M. Primary Target: C-5 Sand; 1800' FNL; 1900 FEL, Sec. 12, TION, R12W, S.M.,-8000' SUBSEA 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. !D.~' KBI Granite Point State 18742 7. Permit No. 82-72 8. APl Number s0-733-20355 9. Unit or Lease Name ~ranite Point State 18742 10. Well No. 46 11. Field and Pool Middle Kenai Sands Granite Point Field For the Month of ,lune ,1982 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud Date - 06-27-82 Depth at end of month - 631' KB, Drilled 631', no fishing operations or directional problems. 13. Casing or liner run and quantities of cement, results of pressure tests Ran 20 inch 94 #1 Ft. K-55 buttress casing in 26 inch hole to 625'. Cemented this casing with 1000 SX Class G cement, with 10% gel and 2% calcium chloride and 500 SX Class G cement with 2% calcium chloride. 14. Coring resume and brief description None 5. Logs run and depth where run None .1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. TITLE District Superintendent DATE07/14/82 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and .must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate EMOR, ,NDU, M of Alaska TO:c. y~ha~erton DATE:JUly 12, 1982 Cha~~ THRU: Longs C. Smith ~ ~ F,LE NO: 108A/T Com~ ssioner ~ TELEPHONE NO: FROM:~ ~ ~O~ ~troleum Ins~ctor SUBJECT:WitneSS BOPE Test on Amoco's 946 Sec. 12, T10N, R12W, SM Platform ~Annar Cook Inle_t Saturday, .July 10, 1982 - I departed my home at 12:00 noon ~or a 12:30 p.m. showup and 1:00 p.m. departure via AAI Twin Otter for Kenai arriving at 1:30 p.m. I rented a car and drove to the Amoco heliport where we departed via Bell 204 }Ielicopter at 3.-30 p.m. and arrived on Platform Anna at 3:50 p.m. Sunday, July 12, 1982 - BOPE tests on Well #46 began at ~-~'20 p.m' and w~re completed at 3:40 p.m. BOPE inspection report is attached. I departed Platform Anna at 4:15 p.m. arriving at the Amoco heliport at 4:30 P.m. and back in Kenai at 4:55 p.m.., I departed Kenai via AAI Twin Otter at 5:00 p.m.. arriving in Anchorage at 5:30 p.m. and at my home at 6:00 p.m. In summa fy, I wi tnessed success.fu 1 BOPE tests on Amoco' s Well #46, Platform Anna. 02-O01/%(Rev.10/79) 41'81 L(~' STATE OF ALAS~t,\ ALASKA OI -CAS CONSERVATION CC~ISSION B.O.P.E. Inspection Report Representative -~ ~ ~,~ o~.~)~ /~,~Casing Set @ ~Z~ ft. Rig # ~ ~ Representative~~ location, General Well Sign Ceneral Housekeeping__ Peserve pit POPE Stack Annular Preventer Pipe Paros Blind Rams Choke Line Valves__ H.C.R. Valve-.. Kil 1 Line Valves Check Valve__ Test Pressure ACCUMUIATOR SYSTEM Ful 1 Charge Pres sure ~ 9 A--O Pressure After Closure /~ ~ o Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: psig psig min /2 sec. ~? min /~sec. N2 ~~ -~-~ ~ ~ee~ ~~ ._~psiq Controls: b~ster _ ~)/~ . Remote ~/f_ B__l.%n_d~s_.~itch cover Kelly and Floor Safety Valves Up~r Kelly. Test Pressure Lower Kelly Test Pres sure Ball Type.. Test Pressure Ins ide BOP~ ~/~. Test Pres sure Choke Manifold No. Valves__ No' flanges ~; A~j ustable Chokes_ ~ Hydrauically operated choke Test Pressure Test Results: Failures ~ Test Time.' /-~ hrs... Repair or Replacement of failed equipment ~to be made within days and Inspector/Ccmmission office notified. Di str ibut ion orig. - AO&CCC cc - Operator. cc - Supervisor- Inspector l~la7 17, 1982 Mr. L. A. Darsow District Superintendent P. O. Box ??9 Anchorage, Alaska 9~)$t0 Granite Point State 18742 No. 46 Amoco Production Company Permit No. 82-?2 Sur. Loc. 829'1~L, 6?3'FEL. Sec 12, T1ON, RI2W, SMo Btmhole Loc. I$50'FNL, 2300'FEL, Sec 12, T10N, R12~', SM. Dear ~ir. Darsow~ Enclosed ia the approved application for peri, it to drill the above ~e ferenced wel 1. Well samples and a ~ud log are not ~equired. A continuous di~,ecttonat ~.~vay is required as ~r ~0 AAC ~.950(b)(5). If available, a tape containing the digitized log tnfo~ation shall be su~itted on all logs for copying except e~eri~ntal l~s, velocity ~veys and di~te~ surveys. Many rivers in Alaska and thel~ drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas afc subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5. Alaska Administrative Code). Prior to coem~ncir~ operations you ~y ~ contacted by the Habitat ~ordinator's Offlee, Debutant of Fish and Game, Pollution of any waters of the State is prohibited by A~ 46, Chapter 3. Article ? and the regulations pl'omulgat.ed thereunder (Title 18, Alaska Administrative Code, Chapter ?.0) an~ by the Federal Water Pollution Control Act, as a~ended. Prior to commencing operations you my be contacted by a representative of the Del~artment of gnviro~ntal Conservation. To aid us in scheduling field ~ork, we would app.r, eciate your notifying this office within 48 hours after the well is s~dded, l~e would al so like to be notified so that a representative of the Commission may be present to witness testing of blowout p~evente~ equipment before surface casin~ shoe is drilled. arson. -2- Granite Point State 18742 No. 46 ~&ay 17, 1982 In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. ¥. Chatterfon Chairman of BV ORDER OF T.'~ CO~MiSS~ON Alaska Oil and Gas Conservation ~ission Eno 1 o sure cc: Department of Fish · Game, Habitat Section w/o encl. Department of ttnvironmental Conservation w/o encl. CVC = be L. A. Darsow District Superintendent Amoco Production Company Post Office Box 779 Anchorage. Alaska 99510 907 - 272-8471 May 4, 1982 File: LAD-463-WF Mr. C. V. Chatterton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupi ne Drive Anchorage, Alaska 99501 Dear Sir: Application for Permit to Drill Granite Point 18742 Well No. 46 Platform Anna, Cook Inlet, Alaska Attached in triplicate is a completed State of Alaska Form lO-401, Application for permit to Drill Granite Point 18742 Well No. 46. We propose to drill this well from Granite Point Platform Anna to a target location at the top of the Middle Kenai C-5 Sand, 1800' FNL, 1900' FEL, -8000' SS and a bottomhole location in the C-9 Sand, 1850' FNL, 2300' FEL, -9110' SS, Section 12, TION, R12W, Seward Meridian. This well is to be completed as a water injection well to improve oil recovery from the crestal area of the Granite Point Field. Also attached is our company draft No. 185999 dated May 4, 1982, in the amount of $100 to cover the filing fee. Two plats showing the location of the well in relation to the Granite Point Structure and Granite Point Platform Anna are attached, along with sketches of the BOP stacks. There are no offsetting operators affected by this proposal. A~s~ 0~ & Gas Cons. comm'ms~0n Anchorage Mr. C. V. Chatterton May 4, 1982 LAD-463-WF Page 2 We also wish to obtain an exception to the provisions of Conservation Order No. 76 (dated September 12, 1969) of the Alaska Oil and Gas Conservation Commission regarding well spacing. Please refer to the attached structure map of the C-5 Sand showing the quarter section in question, proposed location of Well No. 46, and existing location of the following wells: Granite Point 18742 Well No. 3 - Granite Point 18742 Well No. 4 - Granite Point 18742 Well No. 19 - Producer (Anna) Producer (Anna) Injector (Anna) Drilling of the subject well is scheduled to commence approximately May 24, 1982. Please contact K. E. O'Connell in our Anchorage office should any questions concerning this application arise. Yours very truly, L. A. Darsow Di strict Superintendent Attachments KEO/klt STATE OF ALASKA ALASK~('olL AND GAS CONSERVATION (3(_ MMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [-I DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE r-I STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator RECEIVED Amoco Production Company 3. Address P. O. Box 779, Anchorage,. Alaska 99510 MAY 0 71982 4. Location of well at surface Leg 3; S1 et 2, G.P. Platform Anna 829' FNL, 673' FEL, Section 12, T10N, R12W, S./~p.ska0il&GasC0n$ At topofproposedproducingintervalC-5 Target Sand at -8000' Subsea~,nch°rag~ 1800' FNL, 1900' FEL, Section 12, TION, R12W, S.M. At tota~ depth 1850' FNL, 2300' FEL, 9600' MD, 9216' TVD, -9110' SS, Section 12, TION, R12W, S.M. 5. Elevation in feet (indicate KB, DF etc.) 105' KB 6. Lease designation and serial no. Granite Point State 18742 9. Unit or lease name (t~0~l~l~¢onPoint State 18742 10. Well number 46 11. Field and pool Middle Kenai Sands Granite Point Field 12. Bond information (see 20 AAC 25.025) Type B1 an ket Surety and/or number Surety - 874698 Amount $200,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 8 miles SSW of Ty0nek miles 3400' FWL ADL 18742 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 9600'MD, 9216'TVD feet 5060 20. Anticipated pressures KICK OFF POINT 3250 feet. MAXIMUM HOLE ANGLE~_,,O~ o (see 20 AAC 25.035 (c) (2) 19. If deviated (see 20 AAC 25.050) I15. Distance to nearest drilling or completed GP 18~2 #3 is 1200' N. feet 18. Approximate spud date .~ 24' 1982 ~__.~6 ) psig@ 0 Surface ~ psig@921 6 ft. TD (TVD) tel in 21 Proposed Casing, Liner and Cementing Program SIZE ~'ASlNG AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 26" 20" 94# K-55 Butt 600 0 I 0 600 'l 600 To Surface, Class G 17½" 113-3/8 72# N-80 Butt. 4200. 0 ~ 0 4200 14170 To surface, Cl'ass G .4,61,6~#K-55 Butt' ' I " 12¼" 19-5/8" 40,43,E,S-95 IButt I 8500 0 ! 0 8500 118220 To CoVer C-1 Sand.~: ,, /., 47;,53.E# / / l¢<,>r;'L ' [ ' ' .8½ '~,:~7: :~,2.9#~' N-80 {Butt j 1300 8200 ~7920 19500 19216 To Cover Liner ' 22. Describe proposed program:~d Operator proposes to directionally drill subject well from Leg 3, Slot 2, Granite Point Platform Anna to a Middle Kenai Sand target at 1800' FNL, 1900' FEL, Section 12, TION, R12W, S.M. Total depth estimated at 9600' MD, 9216' TVD after adequate penetration of the Middle Kenai Sands. After log evaluations, zones of interest will be perforated, and the well placed on water injection. There are no affected operators. A location plat and BOPE sketches are attached. NOTE: Casing design factors of 1.125, 1.0, and 1.8 will be used for collapse, burst, and tensile strengths respectively. Estimated maximum mud weight required is 11.0 PPG. Target diameter is 500'. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~/~/.,/,/"-U~.,'" TITLE District Superintendent DATE 5/4/82 The space below for Commission use CONDITIONS OF APPROVAL Samples required [~YES ~NO Permit number APPROVED BY Form 10-401 Rev. 7-1-80 Mud log required Directional Survey required I APl number []YES {~NO ]~YES []NO I ApprOval date ~.~~~~~r//82/ . SEE COVER LETTER FOR OTHER REQUIREMENTS ~-'~ ~ ~~ ~/~/~,_../~/ ,COMMISSIONER DATE May 17, 1982 / by order of the Commission Submit in triplicate ,le PAN AM E HBP 10,300 TM° 994"/ TV°/ 844 ~~-)79 2Co ' 10,§7:5 m~,077 TM3 /%~ 9q09 TVD 9889 TVDx -8076, 114 TMD TV° 10,700 TMOn__ 9 /Vo, ~ 7946 /5(4-4) ~ ~ 10,800 TM° 9507 Tv° ~"- 8388 10,370 9818 10,330 TMD I0~101 TVD 8811 6 vc~R6-- ADL : 18 742 · 14 '1 .. TIO N Dole Surveyor ' · :,, NOTE' . . · 'The Iocot,on of plotforrn l~gs ~;~S occomplish~.d b~ usJr, g IriangulaI~.on star'ohs Dud, Trin~ly. on5 Tyor, ck'Offs~l. -:? ...... . ...... ,?':..~/::,-:,.. _ .~. ~]'>:':':' . .. I '" " ' ' :~ ''~:: ': I'YONEK PLATFORM "A" . SURVEYED ': i'AN AMERICAN' PETROL.EUt,:I BOx ......... ...~ f.] M LINDSEY ~ ASSOC . _ LEG. NO I LEG. NO. 2 LEG NO. 3 LEG NO. L~T. 60'~58'37 ~$" L~T. ~°~B ~S9~" LAT ~O~58'}~S3'' LA~ 60~55'37 LONGISI°~8'4G.O,~' LONG ISt°18'~5 2~" LONG. 151°IB'CG 82" LONG 151° 18'47 .......... · " "' ,,o~ ,,~. :~. ,-,o., ,,c ~, ,=o,.. ,~ :o~. ,,o.., ,,~ co: t~s' sour, ~ ~o' sout~ s ~%4' sou:. 8 ~' sour. 6~' west ' . ~oo' ~'ls't ~76' ~esr .' ' 7o~' west ' I hereby cerlify lhol I om p¢operly reglsler, ed and licensed~V~ ,..') o'7oc 3o Or my StlpO, vlSiOn arid lh3l oil dimonsions gl'd olh~r delails ore correct. · AMOCO Amoco Production Com _ay · ~l~a~' ENGINEERING CHART SHEET NO. FILE APPN DATE BY ~" FILLUP · Alaska Oil & Gss Cons. 4nChorage C°rnuiiSsio0 . Amoco Production Corn ny ENGINEERING CHART SHEET NO. FILE OF APPN T I " ?-.' 300 · ~YDRI~ ANNULAR BOP) 1, I lOgO ,"t- ~ '[ ' I~/',,r-I , . E, oP I L///¢ ! : ~UD "'"' ~Z." [ SI'la FFER - 1 ! (~/" L,,,_~ ) i RE'CEIVED MAY' 0 ? 19,82 .Alaska 0il & Gas Cons, Oommissian . (AMOCO) Amoco Production Company SHEET NO. FILE APPN OF .".~ SUBJE CT ,_RESEARCH ENGINEERING CHART ! i ........ r i i ' - ............. i , . ~ ................ ~ ............................... ~ .......................... ~ ................ T ........... ? ................ ~ ............. , ........ w ......... -~ '. ............... ! ......... ~ ......" .......... ~ .......~ ......... t ........... 4- ............ -4. ................ ~ ........................ ~ ............. ~ ......... 4----.....--~ ........... ~ ............. ~ ............ ? ................................. ; ........... -~ ........ ! ............. i ............. ~- ........... i ............... p ........... ~ .......................... ~ _ [ ....... ...... ......... ................ .......... ..... z ........ ~ ............... ~ ......... ~ ........... ~ ......... z ......... i ........... ~_..= ......... ~ ............ ~ ....... ~ ............... ~ ....... : ........ _~ .............. ~ .............. ~ ..... 4 ............ { .............. ~ .......... f ........... : ............. fl ................. ~E-[...EtYE~ ~-...---...-.-~ ~ i i MYO? 9 ~ ........... ~ ............. T ........................ ~ ....... ~ ........ ~ ......... ~ .................. ~ ................ ~'"'"'"'~ ................................ ~ .......... t ............. r .......... ~ .......... ~'--'-'~ ........................... ~ ........................................... ~ ............ t ............... I .................. r .............. T .................................................... ~ , ~, .............. ~ ......... ......... ' ........... *, .................................... 1 *i ............. ' ................... ~ ....................... 7 t~ ......................... ~ e ....... ~, ..................................................................................... t ~ ~ t ~N,..¢a¢~.~....~.~....~s~ ~,..,...,. ~ ........ ~ ........ ~. .......... ~ ............. P ............ ~ ..................... 4 ............. i .............. P.---..~ ........ ~ ................. ! ............. e ............ ~ ......... [ ....... p........-~ ............ ~ ........... ~ .......... 4 .............. ~ ........ ~ ........ i .......... ~.-.¢ ~ ............. ~.-.--~ ........... ; ............ ~-.., ..... 35 uNIO~I- k*O81 ~ 36~ 5Z~RO- I ' 8514 F. LV. 107 KB 32(2'1) 7 14 "I'GP lC -I ...... .~tDt ~g~47 RECEIVED 18 MAY 0 ? ~982 · Oil & Gas Cons. Commission Anchorag9 i~y 17, 1981 A D ~'! I N I S T R.A T I V E A P P 12 O V A L NO. 76.18 ..~ £3 L 3 .... il_ , I Re: The application of Amoco Production Company to drill the Granite Point 18~42 No. 4_ti well as part of the pressure .~. maintenance project approved by Conservation Order No. 76. Mr.-L. A, Dars'ow District Superintendent Amoco Production Company. P' O. Box 779 Anchorage, Alaska 99510 Dear Mr. Darsow: The application was received on May 7, 1981 and stated that the referenced well would be located to improve oil recovery from the crestal area of the Granite Point reservoir. The Alaska Oil 'and Gas Conservation Commission hereby authorizes the drilling, c~{pletion and injection of water into the referenced ~ell pursuant to Rule 7 of Conservation Order No. 76, Yours very truly, / '~'~.7 i-~arry ~, Kugl~r ~mt sstoner BY Tile ORI)E}[ OF TIiE CO~,~,,II SS IO}~ CHECK LIST EOR NEW WELL PERMITS Company Lease & Well No. ~ ITeM APPROVE DATE (2) L o__Ec ~- ! _>' ~ ,2. (~thru 8) ' 3. 5. 6o 7. 8. \, (3) Admin _~~ ,ae'-/~"f2~ 9. (9 thru 11) -' 10. 11. (4) .Casg ' /-/~'~~'' --~~thr u 20) 12. 13. 14. 15. 16. 17. 18. 19. 20. ' f~21 thru' (6) Ad d :. ~ j--'7~~''~ 21. 22. 23. 24. 25. Is the permit fee attached ........................... Is well to be lOcated in a defined pool .............. Is well located proper distance 'fr°m. property line ... Is well located proper distance from other wells ..... Is sufficient undedicated acreage available in this po Is well to be deviated and is well bore plat included Is operator the only affected Party '... ............... Can permit be approved before ten-day wait . .......... YES NO · REMARKS Doe operato have bond in force s r a ................................. d Is a conservation order neede ..................................... Is administrative approval needed ....................... ............. Is conductor string PrOvided eeeeeeeeeeeeeeeeeeeeeeeee eeeeeeeeeeeee · Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons .................. Will surface casing protect fresh water zones .................... Will all casing give adequate safety in collapse, tension and burs Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed .......................... Is diverter syst required ' a em e · · · · · I · · · · · e · · e · · · · e · · · · · · · · · · · e · · · e · Are necessary diagrams of diverter and BOP equipment attached ..... Does BOPE have sufficient pressure rating - Test to ~OO pslg Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. requirements ............................................. Additional Addit ional Remarks: ~Z Geology: ~Engine~ng: ~w~ ~ ncs WVA ~~ RAD ~ JAL ,,~ MTPC~ rev: 01/13/82 INITIAL I GEO. UNIT ON/OFF POOL CLASS STATUSI AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. · No special effort has been made to chronologically organize this category of information. ********************** [~VP 010.H0i ERIFICA~,I[]N LISTING PAGE SERVICE NAMM ISMRVIC D.TE ~82/09/ 2 ORIGIN i R~EL NAME :REEL CONTINUATION ~ 101 REVI...U$ REED OMMENTS IRE£L COMMENTS s rvzc PREVIOUS TAPE COMMENTS :TAPE CO~NTS ********** EOF ********** FIDE NAME ISERVIC,OO1 ERVICE NAME DATE ~ MAXIMUM LENGTH : I0~4 FILE~¥PE . PREVIOUS FILE ** I~ORMATION RECORDD * MNE~ CL. NTENIS CN RANG: ?OWN'I ECT': OUNI $TAT. CTRYI MNE~ PRES: A~OCO PRODUCTION COMPANY GRANiIE POINT 18742 WELD ~46 ~RANITM POINT ON CO~TE~TS DILOOIF ** R~CORD ' · E T~.P .... 047 ** 000 o00 02,4 000 000 o2@ 0~5 0(>0 000 014 uoo ooo o03 560 Ooo oo3 065 o0 ooo o02 o6~ oo ooo o~2 QuO 000 006 o55 000 060 006 000 000 007 0 b 5 .5¥P 010.HOi YERIFIC. A'~ION blSTING PAGE 2 RECORD TYPE 047 RECORD TYPE 0~7 ** COMMENTS '~ .......... COMPANY = AMOCO PRODUCTION COMPANY FIEI, D = GRANIT~ POINT COUNTY STATE RUN #2, DATE bOP': HGH OTTO~ DgPTM OP DEPTH ASlNG IT SIZE TYPE FbUID bOGGED. 4 AUG 1.982 9450 8260 bVP 010,HO! DENSITY VISCOSITY FLUID LOSS R~ RMF R~'AT BHT VERIFICATIGN LISTING ~ 9,6.~. = g:5 c3 JOB eUMBER AT ACC: 10707,6552J RUN #1, DATE LOGGED128 dULY 1982 bDPl HGH 8368 4244 . . LOW SOLtD~ NON DISPERSE[ 7,6 BOTTOM DEPTH TOP D~PTH CAS'lNG BIT SIZE TYPE FLUID ISCOSITY PH bVP OIO,H01 VERIFICATION LISTING . PAGE FLUID bOSS RMF RM AT BHT ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE DATUM SPECIFICATION BLOCKS M,,E~ SERVICE SERVICE-UNIT ID ORDER # D !,PT SFLU ibm P DIb R DIL T BHC GR CALl BHC BHC SIZE REPR ~,ODE 'ENTRY LOG:TYPE CLA~S ~OD' NO;' "L~vEL CPO F~ -0 . 0 o -0. O' 4 o t HM~ - 7 12 46 0 O- 4 0 I . 68 H~ 7 0 - 0 0 O 4 0 i ~V. -7 = 1 0 , .... 0 4 0 1 0 0 . GAPI 7 3i 32 O' [' 4 '. 1 U S,/E' 60 52 '32 0 o ~ 0 1 GAPI 60 ~t - ~2 0 O. 4 : 0 ! !~ 60 28 3 0 O 4 0 J_ (~ S NV ** DATA DEPT R DEPT SP ** 9458,5000 SFL[I -999,2500 GR _ 26.70.31 66,3750 bVP OIO,H ! VERIFICATION DMPT 9300 SP ~27~ ~ 98, DEPT 9200 SP GR 57. DEPT 9100, SP ~29, GR i08, DEPT 9000. DEPT 8900, SP '52, GR 97, DEPT 8800, SP -57, GR 70, DEPT ~700 SP GR 90. DEPT 8600, SP -73, GR 116. D~PT 8500, SP '94, GR 40, DEPT ~400, DEPT 8300 SP -64: G~ 86. DEPT 8~00, SP 82, GR 59. DEPT 8100, SP GR I06. DEPT 8000 SP -47 0000 SFI.,U 5000 3125 CALl 0000 SFLU 5000 GR 3750 C~b! 0000 0000 GR 5000 ,0000 8FI,,U ~0000 ER 0000 SFLU 5313 G_, 6250 CALl 0000 SFLU 6!.I87'5' ILD 5625 57,7813- CA~I 78i3 CALl .... 7,7109 SP 0000 SFLU II 1.641 0 "8 313 OR 10 ~93:75 C- bi 9375 CALl 8.3828 SP ,9062 0313 G 9~,.:250 CALl 6250 C~LI ,2422 SP 0000 SFL{] 200o,00O0 ILD 2013 G~ 7::,2500 C ;1562 0000 SFLU 21.2344 ILD 7813 GR 90'187-5 CALl 1875 CAbI ~-21097: SP 0000 SFLU 20,8750 ILD 8750 CALl ' .6094 SP 0000 SFLU 459,6875~ 0625 GR ,1250 CALl i250 C~hI -'" ~i797 0000 SFLU 52 6875 b8 ~: 5 C~bI 50{, 0 GR 6875 CA1., .g414 8P I6 ~344 ~'5 8§6~312., CALl .,6563 SP 18.8906 59 3750 -999' . 11.6484 ILO 109,5000 CALl -999'2500 1.2.5938 90.7500 3!,953! ILD 26.2969 ILS 9~,62-50 CAbI ~ . 7,9766 DT .,9766 SP ..~7,5313 23.7031 . .7. 9414 DT !4 3516 Sl' 8. 656 3 '"~' ' -64 ' 50OO i. 4.9844 -99~ _2.:500 -999 2500 DT ,0oo0 10.953! -999.2500 DT P AG.E 26.3906 '76.1~75 49.5000 73,3750 ~0.~511 82.1875 98.~750 69.3750 23.9375 102.0(,00 34.375O 60.b938 18,50n0 74,00oo !8,3906 80.0CO0 24.5~56 72.5625 26.7969 71.0000 13.8750 78.0000 14.2JO9 83.7500 12.203! 72,3'15{) 10.539J bVP OiO,HOI VE I~'iCA.~ION 90.7500 CALl D£PT 7900 0000 SFLU SP -34:5000 GR. GR 88,8i25 CALl DEPT 7800 sp .37~iooo ~r ~6 DEPT 7700,0000 SFLU 4..0000 cat.,z DEPT 7~00 0000 SFLU SP -78:5000 GR, GR 24.5000 CALI DEPT :500 0000 SFLU SP 115:0000 GR' GR 100.3125 CAI:,I DEPT 7400,0000 SFLU SP "85.5000 OR GR 58,6250 CALl DEPT :300,0000 SF[.U SP 212,0000 GR GR 43.2500 CALI DEPT 7200,0000 SFLU SP ,,119,5000 GR 87.2500 CALl DEPT 7!00 0000 SFb[I s~ ',9o:oooo sr DEPT ~900 0000 SFLU SP 141:50~0) GR'" OR 98.8750 CAt, I DEPT ~800,0000 SFLU SP 141,0000 GR GR t01,5625 CAt, I DEPT 6700,0000 SFLU SP -131,5000 * Or 8.6, h 3750 C~ '] LIoTI NO -999. 999; 6: '999, 6, -999' 126, -999, ~00 ~ 6. 58 -999 44 43 -909 ~2 -999 7 66 .-999 9 63 -999 I8 9-8 '999 !2 ~IOl 999 5 86 '999 .5938 ,8750 .8984 2500 ,3164 2500 SF -47,0000 0391 ]LD , 11.1406 8125 CALl ~999,25©0 DT 2500 SP '34.5000 !o55 ihn ~,~9~ 2187 CAhI -999 ¢ ~ , ~5-,)U D:T 2500 S~ '37;0000 7~52 ILD 7,2031 0000 CAi, I- ~ :,999,~5OO 2500 SP '63.5000 0625 ILD 23'5781 iL~ 5000 :CALl--999 ~500 PT 25'00SP 8437 !LD 11,7266 IL~ $125 : CALl :-999.2500 DT 2500 SP '115.0000 B125 ILD 6.757~ IL~ 6250 CA~I ~ '999,2509 D 2500 SP '85.5-000 7188 ILQ ~9.3!25 IL~ 2500 ~CA~ -999-~500 ~5oo sp~* 2~13 ILD 7,9180 I.La 250.0 . C.tLI - 999,2500 2500 ' S~ '!i9.5 ~-~00 '~0 0000 ILO 8,1953 IL~ 1875 CALZ ~999,2S00 2500 SP :,Ig0~0O0O 7813 !LD 10,9~9'7 03!3 CAbI ~999,2500 2500 SP I1115000 !7,2'500 Ih~ DT 14 i, 0o06 7. 1406 I t,.~ 999,2500 OT PAGE 10.8203 82.5625 6,3203 77.7500 7.0o78 72.1875 28.3750 122,0000 10.0703 80,0000 6,8945 78,7500 33.7188 62,0000 7.0953 79.3750 7,6445 78,375O 9.0797 7b.7500 16.57~1 70,1875 11.5734 75.750(3 6 . 44.53 DEPT ~600,0000 SFLU SP I ,0000 GR ~.0000 C~LI DEPT ~500,0000 SFbt{ SP 174,0000 GR Gg 82,6250' CALT DEPT ~400,0000 SFLIJ 5P 1.54'5000 G GR 44~2500 CALI DEPT ~300 0000 SFLU SP '136:5000 GR OR 38,4688 CaLI DEPT 1200,0000 SFLU 8P 114,0000 GR 80,3750 CALl 0000 SFbU DEPT 6100, 8P -t10,0000 93.7500 0000 SFbU DEPT 5900, 0 SP -!19,5 O0 GR GR I02,8750 C~L! 0000 SFLU OEPT 5800,. Sp '127,5000 DEPT 5700,0000 ~FLU SP -9~,0000 GR- GR 6 ,1250 CAb] DEPT 5600,0000 SFLU SP -141,0000 GR GR 56,~125 C~LI DgPT 5900,0000 SFLU SP -100,0000 GR 65,2500 DEPT 5400,0000 SYLU SP -145,000~ GR G~ 94,562 CALI DEPT ~300,0000 SP 136,5000 428 7500 2-2:0000 Cah~ -999,~500 SP 7,7852 IL~ -999~2500 SP ~.7.7!88 IL~4 -999-2500 DT '14220000 ~89i ~ ~ g. I L F~ D T 49,I875 ILD 22.7500 44,2500 : C_~LI' -999..2500. ' .'-~r -999.2500 SP 'I54.5003 4063 -999,2500 SP t3615000 11, I172 ILD 80'3-750 CALl -999'2500 501,7500 42,9062CAbl -99:9,2§00SP 7. 7539 93,7500 C LI -999~500 10.9297 ILO -999,2500 5,5938 -99", soo s' 1.5.3516 ILO 11.9922 6 1250 CALl '99~:2500 SP I2.3047 9,101 6 -999,2500 DT '114. 000 85.5625 ti6.oooo e. 078 1 - 999,2500 D T lO .8281 IL~ -t19.500o 5. 5469 ~999,950~ DT D T I3.953! ~ -~ ' 0 999,250 i ;oooo 8 ~233 ZLD 10.4453 IL~ 65 2500 A. LI -999,2500 DT -999.2500 ~ · ' .p. -~oo;6ooO 9,2~91 -999,2500 DT 0,5938 ILD -999. 2500 SP 0430 IL.D 7.078i IL~4 0625 CALl -999.2500 DT PAGE 31.9844 120,0000 8.0594 92.0000 23.7656 73.5625 10,4&t~8 84,5 ,25 83.3750 67,0625 117,i875 7.68]6 84.0000 10,4453 80,0000 5.o6a4 Io5,i~75 lO,3359 84,5625 12.8281 8'7.1875 9,5459 86.1875 8.9453 82,5625 6.6484 87.7500 DVP 010 HO1VE~I.~f~A~ON LI~iNG GtR 65. 0625 CALI DEPT 5200,0000 SFLU SP -11~0000 G~ GR 62.3125 CALI DEPT 5100,0000 SFLU GP 61,8437 CALl DEPT ~000,0000 SFLU SP 151'0000 GR: GR 52,7500 CALI DEPT 4900,0000 SFLU Sp ,,128,5000 G~ 37. 0000 CaLl DEPT 2800 0000 SFLU SP 126:5000 OR GR 77,0625 CAL1 4700 0000 SFLU DEPT 4600..0000 SFI, U -114' 18. 5000 .$i25 CALI DEPT 4~00,0000 SFLU SP 88,5000 GR: GR 58.5313 CALl DEPT 4400,0000 SFLU SP '75'0000 OR GR 66.5625 CAL~ SP -168,0000 GR 44,6563 CALI DEPT 4200.0000 SFLU SP -3o2'000o 6R GR 30,0313 CALl ** FIbE TRA~LER ** FILE NAME :SERVIC,0OI SERVICE NAME : 7 62 -999 6 6-1 "999 6 52 '999 97 "999 26 77 -999 7 61 "999 5 48 -999 7 -999 4 66 '999 44 -999 '999 999 -999.2500 Sp '136,5000 ,3125...CA!.~I -9'99~2500 OT 80' 3750 2500 SP -118 ;0000 r ,~: .' _ · :% .... .. ,7~6! ILD g,6~53 tI.,M 8,14fi4 ,8437. CAbI -"999,2500 OT 88,7500 ,2500 SP 'I01.0000 t500 CAbI ' ,-999~2500 DT 92,7500 . 2'500 SP .ISt,O000 .oooo t_,D s ,0000: :C-AL.t : 999,~500 D~ 126,1875 '2'50o SP -i~8.500o' ., 0625 .:CALI_ ,, 999, . soo sP ,8!25 CAGt ~999 ', 2500 SP- ~ ~ I.':1. i, ,5313 -C.A~I ,,~.99. .2500 SD ,5625 :C~Lt .99~'2500 [5~~ 109 ,2500 - SI~ '- .751ooo0 ,6563 CALl -9_99.2::> Oo DJ' 105 ;2500 SP ' -168;0000 ~ ,' · ~ ,* ..... ~ ~. ~ .. · . - ....d - ~ - - . ,0313 CAbI -999 2500 D'P 6 .2soo sp .oooo D oOO,oOOo ooo , 4531 --CAbI ~99g. ~-500 D t~ 5b ,2500 BP ..... "299; 5000 , . , .7656 ,1875 .7070 , 18'15 ,96R7 ,4414 , '7 5 o o · 25 ] g .1875 .3672 ,5625 ,0000 : 0000 78i3 bVP OIO,H01 VERIFICATION LISTING V~RSION ) DATE : MAXIMUM LENGTH : 1024 rILE TYPE : NEXT FILE NAME ** TAPE TRAILER ** SERVICE NAME :SERVIC DATE :82/09/ 2 ORIGIN :1070 TAPE NAME :65522 CONTINUATION # :01 NEXT TAPE NAME : COMMENT8 ~TAPE COMMENTS ** REEL TRAILER ** SERVICE NAME ~SERVIC DATE 5821091 2 ORIGIN : REEL NAME :REEL ID CONTINUATION # ~01 NEXT REEL NAME ~ COMMENTS :REEL COMMENTS RE~:EIYE~ MAY I ~-~982 Alaska Oil & ,.~ao Cons. CommisslOl~ An. chorag9
