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166-029
1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 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): Middle Ground Shoal / MGS Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,238'N/A Casing Collapse Structural Conductor Surface 1,540 psi Intermediate 3,090 psi Production 7,020 psi Liner 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 9,187'7" 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. 5/1/2021 2-7/8" Daniel E. Marlowe Baker S-3 Perm Packer & Baker T5 SSSV 9,562 - 13,130 2,733' 9,499 (MD) 6,015 (TVD) & 324 (MD) 324 (TVD) Tubing Grade:Tubing MD (ft): 6,060 - 9,086 Perforation Depth TVD (ft): Tubing Size: 9-5/8"10,647' 2,625' 13,238' Perforation Depth MD (ft): 10,647' 2,217' 6,908' 2,625'13-3/8" 6.5 / N-80 TVD Burst 9,531 8,160 psi MD 3,090 psi 166-029 50-733-10078-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC MGS A11-01 N/A9,187' 13,120' 9,076' ±3,500 psi COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018754 Other: Oil Safe AR Acid Soak Authorized Signature: Operations Manager Katherine O'Connor N/A PRESENT WELL CONDITION SUMMARY Length Size 5,750 psi Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:48 pm, Mar 16, 2021 321-135 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.03.16 13:38:54 -08'00' Dan Marlowe (1267) Oil Safe AR Acid Soak OIL DSR-3./17/21SFD 3/16/2021gls 3/17/21 10-404 Comm. on Required? Yes 3/18/21 dts 3/17/2021 JLC 3/18/2021 RBDMS HEW 3/18/2021 Well Prognosis Well Name:MGS A11-01 API Number: 50-733-10078-00-00 Current Status:Gas-Lifted producer Leg:Leg #1 Estimated Start Date:5/1/2021 Rig:N/A Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:166-029 First Call Engineer:Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Second Call Engineer:Karson Kozub (907) 777-8434 (O) (907) 570-1801 (M) Current Bottom Hole Pressure (top perf): 2,000 psi @ 6,060’ TVD 0.330 lbs/ft (6.35 ppg) Maximum Expected BHP (Hemlock):2,960 psi @ 8,970’ TVD 0.330 lbs/ft (6.35 ppg) Maximum Potential Surface Pressure:±3500 psi (treatment pump limit) Brief Well Summary The Middle Ground Shoal A-11-01 is currently producing from the Tyonek B, C, F, and the Hemlock 1, 2, & 3 sands. This project will stimulate the well in an attempt to remediate suspected carbonate scale buildup. Procedure: 1. MIRU pumping equipment. 2. Pressure test surface lines to ±3,500 psi (treatment pump limit) 3. Pump ±7,150gallons Oilsafe AR (synthetic acid) 4. Displace with ±55 bbls FIW 5. Shut down pump and let for ±72 hours. 6. Rig down pumping equipment 7. Turn over to production Attachments: 1. Well Schematic Current 2. Fluid Flow Diagrams 3. Oilsafe AR – Technical Data Sheet 170 bbls 2 7/8" cap = .0058 bbl/ft _____________________________________________________________________________________ Updated By: JLL 5/25/16 SCHEMATIC Middle Ground Shoal Well: MGS A11-01 Last Completed: 12/02/2001 PTD: 166-029 API: 50-733-10078-00 PBTD =13,152’ TD =13,238’ KB: 38’ Water Depth: 75’ MSL 7” 9-5/8” Scale Top @ 9,610’ Slickline 5/2014 13-3/8” Top of sand @ 13,120’ w/ BHP Bomb w/ Slickline 4/5/02 B Zone C Zone H Zone F Zone E Zone D Zone X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8” 61 J-55 BTC 12.515” Surf 2,625’ 9-5/8” 47 N-80 BTC 8.681” Surf 62’ 40 8.835” 62’ 7,269’ 43.5 8.755” 7,269’ 9,485’ 47 8.681” 9,485’ 10,647’ 7” 29 N-80 X-Line 6.184” 10,505’ 13,238’ TUBING DETAIL 2-7/8” 6.5 N-80 8rd EUE 2.441” Surf 9,531’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 324’ 324’ Baker T5 SSSV 2 1,953’ 1,805’ GLM #1 3 4,398’ 3,215’ GLM #2 4 5,875’ 4,009’ GLM #3 5 7,188’ 4,708’ GLM #4 6 8,144’ 5,205’ GLM #5 7 8,874’ 5,615’ GLM #6 8 9,409’ 5,953’ GLM #7 (Orifice) 9 9,453’ 5,983’ 2.313” XN Nipple 9Cr 10 9,499’ 6,015’ Baker S-3 Perm Packer 194-47 11 9,519’ 6,029’ 2.205” XN Nipple 9Cr 12 9,531’ 6,038’ Baker WL Re-entry Guide PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status B 9,562' 9,637' 6,060' 6,113' 75' B 9,670' 9,760' 6,137' 6,203' 90' C 9,807' 9,833' 6,238' 6,257' 26' C 9,930' 9,955' 6,330' 6,349' 25' C 9,972' 10,047' 6,362' 6,420' 75' C 10,100’ 10,130’ 6,462’ 6,485’ 30’ 4/26/16 Open C 10,200’ 10,225’ 6,541’ 6,561’ 25’ 4/26/16 Open C 10,248’ 10,268’ 6,579’ 6,595’ 20’ 4/26/16 Open E 10,893' 10,910' 7,117' 7,131' 17' F 11,372' 11,419' 7,518' 7,558' 47' F 11,688' 11,700' 7,788' 7,798' 12' F 11,706' 11,716' 7,803' 7,812' 10' H1 12,053' 12,138' 8,109' 8,185' 85' H1 12,158' 12,181' 8,202' 8,223' 23' H1-H2 12,195' 12,512' 8,235' 8,519' 317' H2 12,538' 12,586' 8,542' 8,585' 48' H2 12,616' 12,854' 8,613' 8,829' 238' H3 12,905' 12,970' 8,876' 8,936' 65' H3 12,990' 13,005' 8,955' 8,969' 15' H3 13,063' 13,081' 9,023' 9,040' 18' H3 13,094' 13,110' 9,052' 9,067' 16' H3 13,116' 13,130' 9,072' 9,086' 14' Wireline Detail & Fish Date Depth Description 12/15/2017 10,452’ 2-1/2” wireline scratcher 04/05/2002 13,120’ Tag with Survey tools 02/02/2001 9' of 1-1/2" leaded stem, 1-1/4" bumper sub and panex P/T tool 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 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 13,238 feet N/A feet true vertical 9,187 feet N/A feet Effective Depth measured 13,120 feet 9,499 feet true vertical 9,076 feet 6,015 feet Perforation depth Measured depth 9,562 - 13,130 feet True Vertical depth 6,060 - 9,086 feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5 / N-80 9,531 MD 6,038 TVD 9,499 (MD) 324 (MD) Packers and SSSV (type, measured and true vertical depth)Baker S-3 Perm. 6,015 (TVD) Baker T5 SSSV 324 (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: Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,160psi Daniel E. Marlowe Operations Manager Burst Katherine.oconnor@hilcorp.com Tubing Pressure 1,540psi3,090psi 907 777-8376 5,750psi 2,217 6,908 9,187 Katherine O'Connor 2,625 Conductor Surface 7,020psi 3,090psi 13-3/8" 10,647 Size 718 Production Casing Structural Liner 2,733 Length Intermediate 9,562 – 13,130 Junk 5. Permit to Drill Number: 13 Middle Ground Shoal / MGS Oil PoolN/A measured 22 Gas-Mcf 563 7150 acid pumped with 55 bbl FIW displacement. Final tubing pressure 90psi Oil-Bbl 11 Water-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-286 81 Authorized Signature with date: Authorized Name: 160 WINJ WAG STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 166-029 50-733-10078-00-00 Plugs ADL0018754 MGS A11-01 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 28 Representative Daily Average Production or Injection Data 8167 Casing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 9-5/8" 7" 10,647 MD 2,625 13,238 TVD measured true vertical Packer Other: Oil Safe AR measured Collapse PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:38 pm, Aug 24, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.08.24 12:01:12 -08'00' Dan Marlowe (1267) DSR-8/24/2020 RBDMS HEW 8/27/2020 SFD 8/28/2020gls 9 /21/20 Oil Safe AR _____________________________________________________________________________________ Updated By: JLL 5/25/16 SCHEMATIC Middle Ground Shoal Well: MGS A11-01 Last Completed: 12/02/2001 PTD: 166-029 API: 50-733-10078-00 PBTD =13,152’ TD =13,238’ KB: 38’ Water Depth: 75’ MSL 7” 9-5/8” Scale Top @ 9,610’ Slickline 5/2014 13-3/8” Top of sand @ 13,120’ w/ BHP Bomb w/ Slickline 4/5/02 B Zone C Zone H Zone F Zone E Zone D Zone X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8” 61 J-55 BTC 12.515” Surf 2,625’ 9-5/8” 47 N-80 BTC 8.681” Surf 62’ 40 8.835” 62’ 7,269’ 43.5 8.755” 7,269’ 9,485’ 47 8.681” 9,485’ 10,647’ 7” 29 N-80 X-Line 6.184” 10,505’ 13,238’ TUBING DETAIL 2-7/8” 6.5 N-80 8rd EUE 2.441” Surf 9,531’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 324’ 324’ Baker T5 SSSV 2 1,953’ 1,805’ GLM #1 3 4,398’ 3,215’ GLM #2 4 5,875’ 4,009’ GLM #3 5 7,188’ 4,708’ GLM #4 6 8,144’ 5,205’ GLM #5 7 8,874’ 5,615’ GLM #6 8 9,409’ 5,953’ GLM #7 (Orifice) 9 9,453’ 5,983’ 2.313” XN Nipple 9Cr 10 9,499’ 6,015’ Baker S-3 Perm Packer 194-47 11 9,519’ 6,029’ 2.205” XN Nipple 9Cr 12 9,531’ 6,038’ Baker WL Re-entry Guide PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status B 9,562' 9,637' 6,060' 6,113' 75' B 9,670' 9,760' 6,137' 6,203' 90' C 9,807' 9,833' 6,238' 6,257' 26' C 9,930' 9,955' 6,330' 6,349' 25' C 9,972' 10,047' 6,362' 6,420' 75' C 10,100’ 10,130’ 6,462’ 6,485’ 30’ 4/26/16 Open C 10,200’ 10,225’ 6,541’ 6,561’ 25’ 4/26/16 Open C 10,248’ 10,268’ 6,579’ 6,595’ 20’ 4/26/16 Open E 10,893' 10,910' 7,117' 7,131' 17' F 11,372' 11,419' 7,518' 7,558' 47' F 11,688' 11,700' 7,788' 7,798' 12' F 11,706' 11,716' 7,803' 7,812' 10' H1 12,053' 12,138' 8,109' 8,185' 85' H1 12,158' 12,181' 8,202' 8,223' 23' H1-H2 12,195' 12,512' 8,235' 8,519' 317' H2 12,538' 12,586' 8,542' 8,585' 48' H2 12,616' 12,854' 8,613' 8,829' 238' H3 12,905' 12,970' 8,876' 8,936' 65' H3 12,990' 13,005' 8,955' 8,969' 15' H3 13,063' 13,081' 9,023' 9,040' 18' H3 13,094' 13,110' 9,052' 9,067' 16' H3 13,116' 13,130' 9,072' 9,086' 14' Wireline Detail & Fish Date Depth Description 12/15/2017 10,452’ 2-1/2” wireline scratcher 04/05/2002 13,120’ Tag with Survey tools 02/02/2001 9' of 1-1/2" leaded stem, 1-1/4" bumper sub and panex P/T tool Rig Start Date End Date Slickline 7/19/20 8/2/20 08/02/20 - Sunday Brought well online after acid soak. Slowly increase gas lift throughout the day until gas is at the screened orifice. Well flowing. 07/27/20 - Monday Finish pumping FIW down tbg. 55 bbls pumped. Soak for 3+ days. Finish filling IA with FIW. 640 bbls total pumped. Final IAP 50 psi. Spotted high pressure pump, pressure test pump to 3500 psi. Pass. Start pumping acid down tbg. 1375 gallons pumped. Final TBG/IA/OA = 100/12/36 psi 07/25/20 - Saturday Continue pumping safe acid down tbg. 2575 gallons pumped. Continue pumping safe acid down tbg. 5500 gallons pumped. Final TBG/IA/OAP = 100/11/37 psi. 07/26/20 - Sunday Finish pumping safe acid down tbg. 7150 gallons pumped. Purge lines with FIW. Rig up tbg to FIW. Start pumping FIW down tbg. Pump FIW down TBG. 53 bbls pumped. Final TBG/IA/OAP = 90/11/36 psi. 07/23/20 - Thursday Rig up to IA. Continue filling IA with FIW. 210 bbls pumped. Final IAP 11 psi. 07/24/20 - Friday Finish filling IA with FIW. 355BBL total added to IA, final IA pressure 79psi. Rigged up pump and hoses testing same to 3500 psi. Continue bleeding IA from 280 to 75 psig. IA bleed from 75 to 30 psig. Rig up 300psi rated hose from low pressure waterflood (118 psi) w/ check valve at tree. Fill IA with FIW at 11 gpm with tubing vented to production header. 143 bbls (6,000 gallons) at report time. 07/21/20 - Tuesday 07/19/20 - Sunday SI well and bleed IA from 540 to 280 psig 07/20/20 - Monday Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name MGS A11-01 50-733-10078-00-00 166-029 1.Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address: 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): Middle Ground Shoal / MGS Oil Pool 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 13,238'N/A Casing Collapse Structural Conductor Surface 1,540 psi Intermediate 3,090 psi Production 7,020 psi Liner 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 9,187'7" 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. 7/20/2020 2-7/8" Daniel E. Marlowe Baker S-3 Perm Packer & Baker T5 SSSV 9,562 - 13,130 2,733' 9,499 (MD) 6,015 (TVD) & 324 (MD) 324 (TVD) Tubing Grade:Tubing MD (ft): 6,060 - 9,086 Perforation Depth TVD (ft): Tubing Size: 9-5/8"10,647' 2,625' 13,238' Perforation Depth MD (ft): 10,647' 2,217' 6,908' 2,625'13-3/8" 6.5 / N-80 TVD Burst 9,531 8,160 psi MD 3,090 psi 166-029 50-733-10078-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC MGS A11-01 N/A9,187' 13,120' 9,076' ~3500psi COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018754 Authorized Signature: Operations Manager Katherine O'Connor Other: Oil Safe AR N/A PRESENT WELL CONDITION SUMMARY Length Size 5,750 psi Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 1:17 pm, Jul 07, 2020 320-286 Daniel Marlowe I am approving this document 2020.07.07 11:42:12 -08'00' Daniel Marlowe SFD 7/7/2020VTL 7/13/20 DSR-7/7/2020 10-404X Comm. q 7/13/2020 dts 7/13/2020 JLC 7/13/2020 RBDMS HEW 7/16/2020 Well Prognosis Well Name:MGS A11-01 API Number: 50-733-10078-00 Current Status:Gas-Lifted producer Leg:Leg #1 Estimated Start Date:7/20/2020 Rig:N/A Reg. Approval Req’d?403 Date Reg. Approval Rec’vd: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:166-029 First Call Engineer:Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Second Call Engineer:Dan Marlowe (907) 283-1329 (O) (907) 398-9904 (M) Current Bottom Hole Pressure (top perf): 2,000 psi @ 6,060’ TVD 0.330 lbs/ft (6.35 ppg) Maximum Expected BHP (Hemlock):2,960 psi @ 8,970’ TVD 0.330 lbs/ft (6.35 ppg) Maximum Potential Surface Pressure:±3500 psi (treatment pump limit) Brief Well Summary The Middle Ground Shoal A-11-01 is currently producing from the Tyonek B, C, F, and the Hemlock 1, 2, & 3 sands. This well has a history of fill deposits in the liner and through the producing zones. This project will stimulate the well in an attempt to remediate suspected carbonate scale buildup. Procedure: 1. Review approved sundry and discuss any questions/concerns with engineer. 2. MIRU pumping equipment. 3. Pressure test surface lines to ±3500 psi (treatment pump limit) 4. Pump ±640 bbls FIW into IA (fill up volume) taking returns up the tbg. Max pumping pressure 1500 psi. 5. Pump ±7,150gallons Oilsafe AR (synthetic acid) down the tbg. Max pumping pressure 3500 psi. 6. Displace with ±55 bbls FIW 7. Shut down pump and let for ±72 hours. 8. Rig down pumping equipment 9. Turn over to production Attachments: 1. Well Schematic Current 2. Fluid Flow Diagrams 3. Oilsafe AR – Technical Data Sheet _____________________________________________________________________________________ Updated By: JLL 5/25/16 SCHEMATIC Middle Ground Shoal Well: MGS A11-01 Last Completed: 12/02/2001 PTD: 166-029 API: 50-733-10078-00 PBTD =13,152’ TD =13,238’ KB: 38’ Water Depth: 75’ MSL 7” 9-5/8” Scale Top @ 9,610’ Slickline 5/2014 13-3/8” Top of sand @ 13,120’ w/ BHP Bomb w/ Slickline 4/5/02 B Zone C Zone H Zone F Zone E Zone D Zone X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8” 61 J-55 BTC 12.515” Surf 2,625’ 9-5/8” 47 N-80 BTC 8.681” Surf 62’ 40 8.835” 62’ 7,269’ 43.5 8.755” 7,269’ 9,485’ 47 8.681” 9,485’ 10,647’ 7” 29 N-80 X-Line 6.184” 10,505’ 13,238’ TUBING DETAIL 2-7/8” 6.5 N-80 8rd EUE 2.441” Surf 9,531’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 324’ 324’ Baker T5 SSSV 2 1,953’ 1,805’ GLM #1 3 4,398’ 3,215’ GLM #2 4 5,875’ 4,009’ GLM #3 5 7,188’ 4,708’ GLM #4 6 8,144’ 5,205’ GLM #5 7 8,874’ 5,615’ GLM #6 8 9,409’ 5,953’ GLM #7 (Orifice) 9 9,453’ 5,983’ 2.313” XN Nipple 9Cr 10 9,499’ 6,015’ Baker S-3 Perm Packer 194-47 11 9,519’ 6,029’ 2.205” XN Nipple 9Cr 12 9,531’ 6,038’ Baker WL Re-entry Guide PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status B 9,562' 9,637' 6,060' 6,113' 75' B 9,670' 9,760' 6,137' 6,203' 90' C 9,807' 9,833' 6,238' 6,257' 26' C 9,930' 9,955' 6,330' 6,349' 25' C 9,972' 10,047' 6,362' 6,420' 75' C 10,100’ 10,130’ 6,462’ 6,485’ 30’ 4/26/16 Open C 10,200’ 10,225’ 6,541’ 6,561’ 25’ 4/26/16 Open C 10,248’ 10,268’ 6,579’ 6,595’ 20’ 4/26/16 Open E 10,893' 10,910' 7,117' 7,131' 17' F 11,372' 11,419' 7,518' 7,558' 47' F 11,688' 11,700' 7,788' 7,798' 12' F 11,706' 11,716' 7,803' 7,812' 10' H1 12,053' 12,138' 8,109' 8,185' 85' H1 12,158' 12,181' 8,202' 8,223' 23' H1-H2 12,195' 12,512' 8,235' 8,519' 317' H2 12,538' 12,586' 8,542' 8,585' 48' H2 12,616' 12,854' 8,613' 8,829' 238' H3 12,905' 12,970' 8,876' 8,936' 65' H3 12,990' 13,005' 8,955' 8,969' 15' H3 13,063' 13,081' 9,023' 9,040' 18' H3 13,094' 13,110' 9,052' 9,067' 16' H3 13,116' 13,130' 9,072' 9,086' 14' Wireline Detail & Fish Date Depth Description 12/15/2017 10,452’ 2-1/2” wireline scratcher 04/05/2002 13,120’ Tag with Survey tools 02/02/2001 9' of 1-1/2" leaded stem, 1-1/4" bumper sub and panex P/T tool From: Katherine O"connor To: loepo. Victoria T (CED); Schwartz. Guy L (CED) Cc: Dan Marlowe Subject: All -01 Update PTD 166-029 Date: Monday, July 20, 2020 10:20:47 AM Attachments: Approved - MGS All -01 -Sundry 320-286 071320.pdf Guy/Victoria We will be using a low pressure line to fill up the IA with FIW, and instead will pressure test the surface lines after the IA has been fluid packed (i.e. steps 3 and 4 are swapped) Thanks Katherine O'Connor CIO Operations Engineer Katherine.oconnor@hilcorp.com W: (907) 777-8376 C:(214)684-7400 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately nofify us by return email or telephone if the senders phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax 907.276.7542 www.aogcc.alaska.gov Re: Middle Ground Shoal Field, B, C, D, E, F, G and MGS Oil Pools, MGS A11-01 Permit to Drill Number: 166-029 Sundry Number: 319-068 Dear Mr. Golis: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 401—� Daniel T. Seamount, Jr. Commissioner DATED this 2-0 day of February, 2019. 3BDMSJ FEB 10 P019 STATE OF ALASKA FEB ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ��gg 9n ncc 9a 9An W @. 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture ti illate ❑ 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: OX -5+6F 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 166-029 ' 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-10078-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No Q MGS A11-01 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018754 • 1 Middle Ground Shoal / B,C and D Oil & E,F and G Oil Pools + M G9 O.' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 13,238 9,187 13,120 9,076 ±5,000psi N/A –13,120 Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,625' 13-3/8" 2,625' 2,217' 3,090 psi 1,540 psi Intermediate 10,647' 9-5/8" 10,647' 6,908' 5,750 psi 3,090 psi Production 2,733' 7" 13,238' 9,187' 8,160 psi 7,020 psi Liner Perforation Depth MD (ft): Perforation Depth TVD III Tubing Size: Tubing Grade: Tubing MD (ft): 9,562 - 13,130 6,060 - 9,086 2-718" 6.5# / N-80 9,531 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker S-3 Perm Packer & Baker T5 SSSV 9,499 (MD) 6,015 (TVD) & 324 (MD) 324 (TVD) 12. Attachments: Proposal Summary ❑✓ Wellbore schematic ✓ 13. Well Class after proposed work: Detailed Operations Program p BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/15/2019 OIL ❑✓ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golfs Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlOwe hllcor .Com CCom�(( p Contact Phone: (907) 283-1329 � Z Authorized Signature: <i`Vy.� �+: Date: 1 Z � Q COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: G�o coy Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ u Spacing Exception Required? Yes E]No Ek -'Subsequent Form Required: `C7 — / d C/ 41Z� � APPROVEDBY'�77 ) Approved by: COMMISSIONER THE COMMISSION f 20 l 1 Date: G. 9 ,v17 Form 1 REE F Ed k, a pli ationts : f�r']Vr�p f ire data of approval. Surma Form and 0 llllllllJlll ��'II' VVVVVY i^t Lg�ments in uplicata R IL7wrp A6eka, LLC Well Prognosis Well Name: MGS A11-01 API Number: 50-733-10078-00 Current Status: Gas -Lifted producer Leg: Leg #1 Estimated Start Date: 3/15/2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 166-029 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Mike Quick (907) 777-8442 (0) (907) 317-2969 (M) Current Bottom Hole Pressure: 2,424 psi @ 6,600' TVD 0.400 lbs/ft (7.69 ppg) Maximum Expected BHP (Hemlock): 2,424 psi @ 6,600' TVD 0.400 lbs/ft (7.69 ppg) Maximum Potential Surface Pressure:±5,000 psi (treatment pump limit) Brief Well Summary The Middle Ground Shoal A-11-01 is currently producing from the Tyonek B, C, F, and the Hemlock 1, 2, & 3 sands. This project will stimulate the well in an attempt to remediate suspected carbonate scale buildup. ' Procedure: 1. MIRU pumping equipment. 2. Pressure test surface lines to ±5,000 psi (treatment pump limit). 3. Pump ±7,150gallons Oilsafe AR (synthetic acid) 170 4. Displace with ±55 bbls FIW 5. Shut down pump and let for±72 hours. % 6. Rig down pumping equipment 7. Turn over to production Attachments: 1. Well Schematic Current 2. Fluid Flow Diagrams 3. Oilsafe AR —Technical Data Sheet K tura Alaska, LLC KB: 38' Vater Depth: 75' MSL PMD=73,152' TD=13,238' SCHEMATIC Middle Ground Shoal Well: MGS All -03 Last Completed: 12/02/2001 PTD: 166-029 API: 50-733-10078-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 61 J-55 BTC 12.515" Surf 2,625' 1,805' 47 N-80 BTC 8.681" Surf 62' 40 8.835" 62' 7,269' 43.5 8.755" 7,269' 9,485' 47 8.681" 9,485' 10,647' 7" 29 N-80 X -Line 6.184" 10,505' 13,238' TUBING DETAIL N-80 8rd EUE 2.441" Surf 9,531' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID Item 1 324' 324' Baker T5 SSSV 2 1,953' 1,805' GLM #1 3 4,398' 3,215' GLM#2 4 5,875' 4,009' GLM #3 5 7,188' 4,708' GLM#4 6 8,144' -7-,V-5,615' 5,205' GLM#5 7 T8 GLM #6 8 9,409' 5, 953' GLM #7 (Orifice) 9 9,453' 5,983' 2.313" XN Nipple 9Cr 10A 9,955' 6,015' Baker S-3 Perm Packer 194-47 11 6,029' 2.205" XN Nipple 9Cr 12 10,047' 6,038' Baker WL Re-entry Guide 75' C Updated By: AL 5/25/16 Wireline Detail & Fish Date PERFORATION DETAIL 12/15/2017 10,452' 2-1/2" wireline scratcher 04/05/2002 Zone Top (MD) Btm (MD) Top (TVD) Btm ( FT Date Status B 9,562' 9,637' 6,060' 6,113' 75' B 9,670' 9,760' 6,137' 6,203' 90' C 9,807' 9,833' 6,238' 6,257' 26' C 9,930' 9,955' 6,330' 6,349' 25' C 9,972' 10,047' 6,362' 6,420' 75' C 10,100' 10,130' 6,462' 6,485' 30' 4/26/16 Open C 1 10,200' 10,225' 6,541' 6,561' 25' 4/26/16 Open C 10,248' 10,268' 6,579' 1 6,595' 20' 4/26/16 Open E 10,893' 10,910' 7,117' 7,131' 1 17- F 11,372' 1 11,419' 7,518' 7,558' 1 47' F 11,688' 11,700' 7,788' 7,798' 12' F 11,706' 11,716' 7,803' 7,812' 10' H1 12,053' 12,138' 8,109' 8,185' 85' 141 12,158' 12,181' 8,202' 8,223' 23' H1-1-12 12,195' 12,512' 8,235' 8,519' 317' H2 12,538' 12,586' 8,542' 8,585' 48' H2 12,616' 12,854' 8,613' 8,829' 238' H3 12,905' 12,970' 8,876' 8,936' 65' H3 12,990' 13,005' 8,955' 8,969' 15' H3 13,063' 13,081' 9,023' 9,040' 18' H3 13,094' 13,110' 9,052' 9,067' 16' H3 13,116' 13,130' 9,072' 9,086' 14' Updated By: AL 5/25/16 Wireline Detail & Fish Date Depth Description 12/15/2017 10,452' 2-1/2" wireline scratcher 04/05/2002 13,120' Tag with Survey tools 02/02/2001 9' of 1-1/2" leaded stem, 1-1/4" bumper sub and panex P/T tool Updated By: AL 5/25/16 —_ 03sinsa �. wvao aonaevaa m t>MM >w dAnd NNOM ll3M 31SYMOd VM1 a 1 3n DEISM ONV Wdld rran im row 3KHSA�O AIN1 N000 enne our XIV1 NJ1aH Oil Safe ARO Is a safe yet functional replacement for traditional hydrochloric acid treatments and other commonly used ollfield acid treatments. It is non-regulated by 1R DOT, CanadianTDG and carries a triple sero hazardous materials information system score. 00 Safe AR® biodegrades inl0 days or less and is approved by the US EPA as a Designed for the Environment product. Our standard Oil Safe AR® formula includes iron control agents, de-muldriiers and requires no organic acid additions or corrosion inhibitors under most conditions. AND BENEI ITS: • Anexcelienteh-hm for Ino, apauheed trealmenla, inJeelhmn .lbAnd die. poe.l wells and varmlar eoaks • Ae"ims pporgaNe acid additions to help retard rrmalion rates Slanderd lumina include...de tent and de-mulatAenyetem • Reguhea no Iron control agent addition for most applications • EPA DBE form], biodegradable in 10 days or team; Approved tar direct d9 - charge; made with Cleengredienta end DIE ingredients approved by the EPA • Safe on moatm eche piping And pumping equlpment • Nontoxic; raw Nosing; non mut•geNc; no VOC's • No secondary containment raquhad as per Chapter 02-761FA.C. • EliminataeleuWTts • An excellent choice far work -ever proleda, buliheed lreetmenb and cement reme Nation • Aegdres Ag addidwul corrosion inhibitor step for most applications • 100%biodegradable, acid free and naturally iMWlted DISSOLVING PROPERTIES ACIDTYPE -%C-CW Oil Safe All& 50% Solution 88.76% Oil Safe AR030%Solution 64.00 7 %HCI 46.48% 16%HCI 87.39% 7%HCI +100 gpt of 89%Acetic Acid 76.08% I6%HCI+100 gpt of 86% Acetic Acid 97.87% 10%Acetic Add 31.00% 13%AceticACid 63.09% Foch test aEewwu mrdudeQMN I cabin Inch d matmtalptandln so mler ad WimandaAowedbwaxlora Mat 100'P. TYPICAL PHYSICAL PROPERTIES: I DIRECTIONS FOR USE: I I Dilution Rates: 30.100% with HAD based on the build-up and the reaction rate required for the Note: Oil Safe AR®concentrate contains iron control agents and de-mulsiRers. No organic acid or corrosion inhibitors are required due to the power of our patented Syntech®. A typical ratio for an acid frac is one part OB Safe AR® and one part H'O. Blending ratios may vary based on specific applications and recommendations from your consultants at HearBand Energy Group, Ltd. I STORAGE AND HANDLING: OB Safe ARC has a storage life ofbelter than one year. Keep container closed when not in use. As with all chemicalproducts andmateriais, take care as to where you afore them. Safety glasses are suggesledfor use when handling this product. No special gloves orprotective equipment are required when handling this product. When pumping this product, it is strongly recommended to we manufacturer approved hose couplings or fittings. DO NOT USE ALUMINUM ITIVINGS. 316 Stainless Steal, polypropylene, polyethylene are recommended. 00 Safe ARO is shipped in bulls tanker trucks from the manufacturing facility. Smaller packaging quantities are available uponrequest. Aemnunendaaavyhen In Me, dela ah -las, auedm haabeti<mcl b be reliable. ever.., Me me efMa lNomuam le beyond Ne maw l olHertlaMlbaryy4M1ouR Udq andne guaranhq ar- pneedorlmp4edbmadeh Me mmlheblamedlrrat usMN acvwMaaca MM fencaaawenaLlWetlmf pruacs.lhebvyerm,alavumeailrerpomfb111ty,4MuditgG{I,vyetQemaye ma Me ndn,.a Ndx pmducluewa, wNmmbinadon MM oNernuhriW yablallleW bmr cobs Iabnuaaaue roapemhuMuwrmmmaMatlen to LQtlnga mypalenr STATE OF ALASKA AIlikA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations El Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate LI Other Stimulate ❑ Alter Casing❑ Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 166-029 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-10078-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018754 MGS A11-01 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Middle Ground Shoal/B,C and D Oil&E,F and G Oil Pools 11.Present Well Condition Summary: RECEIVED Total Depth measured 13,238 feet Plugs measured N/A true vertical 9,187 feet Junk measured —13,120 feet MAY 25 2016 Effective Depth measured 13,120 feet Packer measured 9,499 feet true vertical 9,076 feet true vertical 6,015 CC Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,625' 13-3/8" 2,625' 2,217' 3,090 psi 1,540 psi Intermediate 10,647' 9-5/8" 10,647' 6,908' 5,750 psi 3,090 psi Production 2,733' 7" 13,238' 9,187' 8,160 psi 7,020 psi Liner Perforation depth Measured depth 9,562-13,130 feet True Vertical depth 6,060-9,086 feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/N-80 _...gam' 6,038'(ND) Packers and SSSV(type,measured and true vertical depth) Baker S-3 Perm Pkr 9,499'(MD)6,015'(ND) Baker T5 SSSV 324'(MD)324'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): J 0 ��jj N/A SCANNED JAN 6 2Ja?i 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: 61 33 72 591 78 Subsequent to operation: 68 34 74 596 81 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ DevelopmentE Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-215 Contact Dan Marlowe(907)283-1329 Email dmarlowe(cahilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature ///. 61 Phone (907)777-8356 Date 5 Rs"s I i , 2/- 1G Form 10-404 Revised 5/2015 RBDMS 1,.L MAY 3 1 2016 Submit Original Only .. il • • Mideldlel:MGround GSA11-01 Shoal W SCHEMATIC Last Completed: 12/02/2001 PTD: 166-029 Hilcorp Alaska,LLC API: 50-733-10078-00 KB:38' Water Depth: 75'MSL CASING DETAIL J 1 Size Wt Grade Conn ID Top Btm 13-3/8" 61 J-55 BTC 12.515" Surf 2,625' 47 8.681" Surf 62' 40 8.835" 62' 7,269' 9-5/8" N-80 BTC 0 43.5 8.755" 7,269' 9,485' 47 _ 8.681" 9,485' 10,647' 7" 29 N-80 X-Line 6.184" 10,505' 13,238' 11 13-3/8" TUBING DETAIL ii 2-7/8" 6.5 N-80 8rd EUE 2.441" Surf 9,531' JEWELRY DETAIL Depth Depth No (MD) (ND) ID Item 1 324' 324' Baker T5 SSSV 2 1,953' 1,805' GLM#1 XN 3 4,398' 3,215' GLM#2 , 4 5,875' 4,009' GLM#3 5 7,188' 4,708' GLM#4 X 6 8,144' 5,205' GLM#5 7 8,874' 5,615' GLM#6 8 9,409' 5,953' GLM#7(Orifice) 9 9,453' 5,983' 2.313" XN Nipple 9Cr BZone 10 9,499' 6,015' Baker S-3 Perm Packer 194-47 11 9,519' 6,029' 2.205" XN Nipple 9Cr 12 9,531' 6,038' Baker WL Re-entry Guide C Zane @9,610' APERFORATION DETAIL Slickline 't 0 Btm e 5/2014 : Zone Top(MD) Btm(MD) Top(ND) FT Date Status �, (ND) '£, % ►• B 9,562' 9,637' 6,060' 6,113' 75' 9-5/g' , ,, F ;L B 9,670' 9,760' 6,137' 6,203' 90' C 9,807' 9,833' 6,238' 6,257' 26' DZone C 9,930' 9,955' 6,330' 6,349' 25' ,„� 0 EZone C 9,972' 10,047' 6,362' 6,420' 75' '. ,,- C 10,100' 10,130' 6,462' 6,485' 30' 4/26/16 Open tiwC 10,200' 10,225' 6,541' 6,561' 25' 4/26/16 Open ` C 10,248' 10,268' 6,579' 6,595' 20' 4/26/16 Open +{ W_`' E 10,893' 10,910' 7,117' 7,131' 17' FZone F 11,372' 11,419' 7,518' 7,558' 47' F 11,688' 11,700' 7,788' 7,798' 12' O ,, F 11,706' 11,716' 7,803' 7,812' 10' • / H1 12,053' 12,138' 8,109' 8,185' 85' '' H1 12,158' 12,181' 8,202' 8,223' 23' H1-H2 12,195' 12,512' 8,235' 8,519' 317' , ; , " H2 12,538' 12,586' 8,542' 8,585' 48' :f. ;',, 0±; H2 12,616' 12,854' 8,613' 8,829' 238' � 0H3 12,905' 12,970' 8,876' 8,936' 65' t«:, ; H Zone H3 12,990' 13,005' 8,955' 8,969' 15' ' - H3 13,063' 13,081' 9,023' 9,040' 18' Top of sand ;D H3 13,094' 13,110' 9,052' 9,067' 16' @13,120'w/ H3 13,116' 13,130' 9,072' 9,086' 14' BHP Bomb w/ -^ Slick ine it 4/5/02 ,q 7 6. PBTD=13,152' TD=13,238' Fish: 02/02/2001-9'of 1-1/2"leaded stem,1-1/4"bumper sub and panex P/T tool Updated By:JLL 5/25/16 • • ElHilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A11-01 E-Line 50-733-10078-00 166-029 4/26/16 4/27/16 Daily Operations: 04/26/2016-Tuesday Fly ELU crew to Platform A. Platform orientation,Safety meeting, Permit to Work&JSA.Clear pipe deck and drill deck to allow for ELU rig up. RU ELU. PU GR/CCL tool suite and function test-PASS. PU firing head assembly and function test- PASS. PU Perf Gun#1(1.75"OD X 20'GeoDynamics Razor,6spf,60 deg. phase). 11.0'GR source to top perf shot. Pressure Test lubricator and WLV-FAIL HI TEST. Leak at 3-1/2",8RD X-over Swedge to WH threaded connection.Tighten threads and Retest-FAIL. Remove 3-1/2",8RD swedge from WH Threaded connection. MU 3-1/2",8RD Swedge to Hammer Up WH connection. Pressure Test lubricator and WLV-FAIL HI TEST.3-1/2"8RD Swedge still leaks at threads. Remove Swedge/Hammer up connection. Remove 3-1/8",5K WH Flange and install 3-1/8", 5K X Bowen Flange. Pressure Test Lubricator and WLV=250 LO/2000 HI-PASS. RIH with GR/CCL and 20' Perf Gun#1.WELL FLOWING. Initial T/IA OA= 100/567/12 psi. 10,352'WLM PUH for correlation log to 10,000'WLM.9.5'depth correction. RIH to 10,342'. PUH logging to 10,237'GR source depth (+11.0'GR source to top shot correction) placing perf shots on depth 10,248'-10,268'. Fire shots. POOH.T/IA/OA= 100/557/11 psi.At surface. LD Perf Gun#1.Shots Fired. PU Perf Gun#2 (1.75"OD X 25' GeoDynamics Razor,6spf,60 deg. phase). 10.0'GR source to top perf shot. RIH.T/IA/OA=100/557/11 psi. 10,352'WLM. PUH for correlation log to 10,079'WLM.4.0'depth correction. RIH to 10,300'. PUH logging to 10,190'GR source depth (+10.0'GR source to top shot correction) placing perf shots on depth 10,200'-10,225'. Fire shots. POOH.T/IA/OA= 100/557/11 psi.At surface. LD Perf Gun#2.Shots Fired. PU Perf Gun#3 (1.75"OD X 30'GeoDynamics Razor,6spf,60 deg. phase). 10.0'GR source to top perf shot. RIH.T/IA/OA=100/556/11 psi. 10,320'WLM. PUH for correlation log to 10,000'WLM. Depth Correct. RIH to 10,253'. PUH logging to 10,090'GR source depth (+10.0'GR source to top shot correction) placing perf shots on depth 10,100'-10, 130'. Fire shots. POOH.T/IA/OA= 100/556/112 psi.At surface. LD Perf Gun#3.Shots Fired. PU Perf Gun#4 (1.75"OD X 30'GeoDynamics Razor,6spf, 60 deg. phase). 10.0'GR source to top perf shot. RIH.Tool set down at 9,870'WLM bottom of tool (9,830'GR depth+ 10'GR-shot+30' perf gun).Work tool mutiple passes up and down attempting to pass without success.Stop and inspect wire for damage. No wire damaged.Continue making attempts to pass and again without success. Unable to reach perf depth =10,070'- 10, 100'. POOH. Production Operator turns well into Test Separator.At surface with unfired Perf Gun#4. Close Swab. LD Perf Gun #4 and GR/CCL tool suite. Nite Cap WLV/Lubricator assembly.Secure pipe and drill decks.SDFN.Job Ongoing. Final T/IA/OA= 100/552/12 psi. 04/27/2016-Wednesday HEC SLU crew arrives to Platform.Safety Meeting, Permit to Work&JSA. RD ELU Lubricator and WLV assembly. RU SLU on well to work restriction @ 9,870'WLM. RIH with SLU and 2-7/8"scratcher tool BHA. SLU worked series of restrictions in tubing from 8,800'to EOT @ 9,531'.SLU continued in hole to set down @ 9,815'WLM. Worked restriction w/2-7/8" scratcher to 9,821'WLM.SLU would lose f000tage w/each PU hole and have to continue woking back to 9,821'. Unable to pass 9,821'and losing jar action on final attempts.SLU POOH. RD ELU and SLU.Call for Helicopter. Fly ELU &SLU crews to beach.Job Ended. VOFTjt • • e%.'\I//7,6 6. THE STATE Alaska Oil and Gas Of KA Conservation Commission 2 h 333 West Seventh Avenue Off, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 t'sMain: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400C.05 Anchorage, AK 99503 Re: Middle Ground Shoal Field, B, C, D, E, F, and G Oil Pools, MGS Al 1-01 Permit to Drill Number: 166-029 Sundry Number: 316-215 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, 11 Daniel T. Seamount, Jr. Commissioner DATED this day of April, 2016. RBDMS L L APR 0 7 2016 • RECEIVED STATE OF ALASKA J' \ APR 0 4 2016 • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 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. Hilcorp Alaska, LLC Exploratory ❑ Development 0 ' 166-029• 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ClService ❑ 6.API Number. Anchorage,AK 99503 50-733-10078-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 44' Will planned perforations require a spacing exception? Yes ❑ No 0 ,r MGS A11-01 , 9. Property Designation(Lease Number): 10.Field/Pool(s): ADL0018754 • Middle Ground Shoal/B,C and D Oil,E,F and G Oil Pools• 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): 13,238 . 9,187 r 13,120 • 9,076 1,820 psi N/A -13,120 N Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,625' 13-3/8" 2,625' 2,217' 3,090 psi 1,540 psi Intermediate 10,647' 9-5/8" 10,647' 6,908' 5,750 psi 3,090 psi Production 2,733' 7" 13,238' 9,187' 8,160 psi 7,020 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,562-13,130 • 6,060-9,086 2-7/8" 6.5#/ N-80 9,531 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker S-3 Perm Packer and Baker T5 SSSV " 9,499(MD)6,015(TVD)and 324(MD)324(TVD) . 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 " Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 4/18/2016 Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ 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 Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature ){{s... Phone (907)777-8356 Date Li ( 4 I 1 to COMMISSION USE ONLY Conditions of approval: Notify Com ssion 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 ❑ RBDMS Li- APR 0 7 2016 Spacing Exception Required? Yes El Nod Subsequent Form Required: /, LI z:• V i / APPROVED BY /---/i Approved by: COMMISSIONER THE COMMISSION Date: // .4 L(- 5'!4' 'M 4 IS)1c. ,r /r//6 GR4,G,INA.L, Subs in Form ane Form 10-403 Revi d 11/2015 for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: A11-01 Hilcorp Alaeka,LLC Date: 03/31/2016 Well Name: MGS A11-01 API Number: 50-733-10078-00 Current Status: Gas-Lifted producer Leg: Leg#1 West Corner Estimated Start Date: April 18, 2016 Rig: N/A (E-Line) Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 166-029 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Current Bottom Hole Pressure: 2,425 psi @ 6,060'TVD 0.400 psi/ft SIBHP @ top perf Maximum Expected BHP: 2,425 psi @ 6,060'TVD 0.400 psi/ft SIBHP @ top perf Maximum Potential Surface Pressure: 1,820 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Brief Well Summary Well Middle Ground Shoal A11-01 is a gas-lifted oil well completed in the Hemlock zone.This project will add Hemlock sands not currently perforated. E-line Procedure: 1. MIRU E-line, PT lubricator to 2,000 psi Hi 250 Low. 2. RU e-line guns and perforate per program. Record tubing pressures before and after perforating run. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Middle Ground Shoal • • Well:MGS A11-01 • II SCHEMATIC Last Completed: 12/02/2001 PTD: 166-029 API: 50-733-10078-00 Hilcorp Alaska,LLC KB:38' Water Depth: 75'MSL CASING DETAIL Size Wt Grade Conn ID Top Btm ' ' 13-3/8" 61 J-55 BTC 12.515" Surf 2,625' •" 47 8.681" Surf 62' 9-5/8" 40 N-80 BTC 8.835" 62' 7,269' i 43.5 8.755" 7,269' 9,485' 47 8.681" 9,485' 10,647' 7" 29 N-80 X-Line 6.184" 10,505' 13,238' 13-3/8 TUBING DETAIL 2-7/8" 6.5 N-80 8rd EUE 2.441" Surf 9,531' JEWELRY DETAIL Depth Depth No ID Item (MD) (TVD) 1 324' 324' Baker T5 SSSV I 2 1,953' 1,805' GLM#1 3 4,398' 3,215' GLM#2 XN 4 5,875' 4,009' GLM#3 5 7,188' 4,708' GLM#4 6 8,144' 5,205' GLM#5 x 7 8,874' 5,615' GLM#6 /sAir 8 9,409' 5,953' GLM#7(Orifice) 9 9,453' 5,983' 2.313" XN Nipple 9Cr _ 10 9,499' 6,015' Baker 5-3 Perm Packer 194-47 11 9,519' 6,029' 2.205" XN Nipple 9Cr 12 9,531' 6,038' Baker WL Re-entry Guide Scale Top PERFORATION DETAIL @9,610' `4,::: Zone Top(MD) Btm(MD) Top(ND) Btm FT Date Status Slickline t'- % , . (TVD) 5/2014 ", b* . ' "'A B 9,562' 9,637' 6,060' 6,113' 75' 4•a,a `. B 9,670' 9,760' 6,137' 6,203' 90' 9-5/8" �< �� C 9,807' 9,833' 6,238' 6,257' 26' • ✓ 'X C 9,9702' 10,047' 6,3602' 6,420' 75' ee F 13' 101,372 ' 101,419' 7,117' 7,518' 7,558' 17' 47' d F 11,688' 11,700' 7,788' 7,798' 12' ,' '' F 11,706' 11,716' 7,803' 7,812' 10' H1 12,053' 12,138' 8,109' 8,185' 85' H1 12,158' 12,181' 8,202' 8,223' 23' '' ~, H1-H2 12,195' 12,512' 8,235' 8,519' 317' ''').i' H2 12,538' 12,586' 8,542' 8,585' 48' '�' H2 12,616' 12,854' 8,613' 8,829' 238' gH3 12,905' 12,970' 8,876' 8,936' 65' H3 12,990' 13,005' 8,955' 8,969' 15' H3 13,063' 13,081' 9,023' 9,040' 18' H3 13,094' 13,110' 9,052' 9,067' 16' '. H3 13,116' 13,130' 9,072' 9,086' 14' t 4 rs, Top of sand ilkt.y @13,120'w/ `s.sfs teat's',}q's Fish: BHP Bomb t , f} ' 9'of 1-1/2"leaded stem,1-1/4"bumper sub and panex P/T w/Slickline f 4/5/02 y f4 Ps• tool PBTD=13,152' TD=13,238' Updated By:AL 03/31/16 Well:MiddleMGS Ground A1101 Shoal PROPOSED Last Completed: 12/02/2001 . 11 PTD: 166-029 ' API: 50-733-10078-00 Hilcorp Alaska,LLC KB:38' Water Depth: 75'MSL CASING DETAIL _I Size Wt Grade Conn ID Top Btm 13-3/8" 61 J-55 BTC 12.515" Surf 2,625' 47 8.681" Surf 62' ill. � 9-5/8" 40 N-80 BTC 8.835" 62' 7,269' 43.5 8.755" 7,269' 9,485' MP . 47 8.681" 9,485' 10,647' =Mil7" 29 N-80 X-Line 6.184" 10,505' 13,238' 13-3/8" ■ TUBING DETAIL MEW 2-7/8" 6.5 N-80 8rd EUE 2.441" Surf 9,531' ■ ®'l JEWELRY DETAIL ., No Depth Depth ID Item ■ (MD) (TVD) 1 324' 324' Baker 15 SSSV ® 2 1,953' 1,805' GLM#1 `*1ll 3 4,398' 3,215' GLM#2 ® 4 5,875' , 4,009' GLM#3 5 7,188' 4,708' GLM#4 I© 6 8,144' 5,205' GLM#5 roiis . loop ' 7 8,874' . 5,615' GLM#6 ANEW 8 9,409' 5,953' GLM#7(Orifice) 9 9,453' 5,983' 2.313" XN Nipple 9Cr BZone 10 9,499' 6,015' BakerS-3 Perm Packer 194-47 11 9,519' 6,029' 2.205" XN Nipple 9Cr 12 9,531' 6,038' Baker WL Re-entry Guide C Zone Scale Top ,,(1 @9,610 PERFORATION DETAIL Slid line rt.! Btm 5/2014 r, • ' + ;,, Zone Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status ,, B 9,562' 9,637' 6,060' 6,113' 75' B 9,670' 9,760' 6,137' 6,203' 90' 4 4 C 9,807' 9,833' 6,238' 6,257' 26' j D Zone > LI' C 9,930' 9,955' 6,330' 6,349' 25' i 0yr EZone C 9,972' 10,047' 6,362' 6,420' 75' ,,:; 1C ±10,070' ±10,130' ±6,438' ±6,485' ±60' Future Proposed 4 %r.`1, i C ±10,200' ±10,225' ±6,541' ±6,561' ±25' Future Proposed l'" 1 j=='_ C ±10,248' ±10,268' ±6,579' ±6,595' ±20' Future Proposed of;;;; '` D ±10,553' ±10,583' ±6,828' ±6,853' ±30' Future Proposed ,'} , ;R FZone D ±10,714' ±10,757' ±6,964' ±7,001' ±43' Future Proposed E 10,893' 10,910' 7,117' 7,131' 17' 4. 4d F 11,372' 11,419' 7,518' 7,558' 47' , '' F 11,688' 11,700' 7,788' 7,798' 12' �� ' F 11,706' 11,716' 7,803' 7,812' 10' i, /1aH1 12,053' 12,138' 8,109' 8,185' 85' R 71.'„ H1 12,158' 12,181' 8,202' 8,223' 23' il ,.+ H1-H2 12,195' 12,512' 8,235' 8,519' 317' 21 ' H2 12,538' 12,586' 8,542' 8,585' 48' +5". , H Zone H2 12,616' 12,854' 8,613' 8,829' 238' % %-- H3 12,905' 12,970' 8,876' 8,936' 65' Top of sand r ,,'�ZI H3 12,990' 13,005' 8,955' 8,969' 15' * .., @ 13,120'w/ i r H3 13,063' 13,081' 9,023' 9,040' 18' BHP Bomb w/ - ' H3 13,094' 13,110' 9,052' 9,067' 16' Slicldin4/5/02e %, , ' H3 13,116' 13,130' 9,072' 9,086' 14' ,, . , 7, PBTD=13,152' TD=13,238' Fish: 02/02/2001-9'of 1-1/2"leaded stem,1-1/4"bumper sub and panex P/T tool Updated By:AL 03/31/16 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations AbandonTT Repair Well Plug Perforations L Perforate Other Acid stimulaiton Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver E] Time Extension Change Approved Program ❑ Operat. Shutdown E] Stimulate - Other El Re-enter Suspended Well 2. Operator XTO Energy 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑� Exploratory ❑ Stratigraphic 11 Service ❑ 166-029 3. Address: 9127 S Jamaica St, Englewood, CO 80112 6. API Number: 50-733-10078-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 0018756 Middle Ground Shoal A11-01 L 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Gamma Ray + CCL MGS E, F, G Oil Pool LIG 11. Present Well Condition Summary: Total Depth measured 13,238 feet Plugs measured N/A feet AOGCVr((�"� true vertical 9,187 feet Junk measured N/A feet Effective Depth measured 13,152 feet Packer measured 9,499 feet true vertical 9,050 feet true vertical 5,982 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 370' 24' 370' 370' Surface 2,625' 13-3/8" 2625' 2202' 2730 psi 1130 psi Intermediate 9610' 9-5/8" 9610' 6052' 6330 psi 3810 psi Production 2733' 7" 13238' 9147' 9060 psi 5410 psi Perforation depth Measured depth 10893 - 13130 True Vertical depth 9080-9165 Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# N80 tbg @ 11 199'MD, 7050' TVD Packers and SSSV (type, measured and true vertical depth) 9-5/8" Baker S-3 Perm Packer at 9499' MD 5982' TVD and SSSV at 324' MD, 324' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Squeezed 10% HCI into the perforation to remove scale 13. Representative Daily Production Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 20 95 44 643 psi 0 Subsequent to operation: 95 107 150 680 psi 100 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El Service ❑ Stratigraphic Daily Report of Well Operations 16. Well Status after work: Oil Gas WDSPL GSTOR ❑ WINJ WAG ❑ GINJ SUSP SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1314-252 Contact Sephra Baca Email Sephra 13aca(a_)_xtoenergy.com Printed Na a Title Regulatory Analyst i Signature Phone _ 4 F' 3 Date ?tj Form 10-404 Revised 10/2012 g q Submit Original Only ��//y� rlmBOMS aur 13 260V To ENERGY July 24, 2014 Alaska Oil and Gas Conservation Commission Attn: Cathy Foerster 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 Re: Form 10-404, report of sundry well operations Objective: Coil Tubing Cleanout, Perforating and Acidize to Remove Scale Middle Ground Shoal # A11-01 Production Well Middle Ground Shoal Field E, F & G Oil Pool Cook Inlet, Alaska API: 50-733-10078-00 RECEIVED AUG 13 2014 AOGCC XTO Energy hereby submits the report of sundry well operations to perform well cleanout for scale, perforate existing interval and acidize. Enclosed are the following attachments: 1. Form 10-404 Report of Sundry Well Operations 2. Workover Daily Activity Report 3. Current Wellbore Diagram If additional information is required, please contact me at 719-845-7813 Sincerely, Sephra Baca, Regulatory Analyst Copy to: Bola Adeyeye, Operations Engineer, Office: 303-397-3606 To 1 \1 It(�1 MGS A11-01 Cook Inlet, Alaska Leg 1, Conductor 2 API # 733-10078-00 Spud 6-28-66 Surf Csg: 13 3/8", 61 Ib, J55. Set @ 2,625'. Cmt'd w/ 3,400 sx. Intermediate Csg: 9 5/8", N80. Set @ 10,647'. Cmt'd w/ 1,250 sx. 0 - 62' :47# 62 - 7,269' :40# 7,269 - 9,485' :43.5# 9,485 - 10,647' :47# Prod Liner: 7", 29 Ib, N80. Set @ 10,505 -13,238'. Cmt w/ 500 sx. Tagged with CT at 13062; - May 2014 Top of sand @ 13,120' (4-5-02) w/BH Bomb w/ slickline. PBTD: 13,152' MD (9,050' TVD) TD: 13,238' MD (9,187' TVD) Current Completion AAA 8-7-2014 KB: 38' Water Depth: 75' MSL Tbg: 2 7/8" 6.5# N80 EUE 8R @ 9,531' Set on 12-2-01 Item MD ND Psc Pso Port 12053'-12138' (perf'd 12080 - 120' — May 2014) GLM #1 1953' 1804' 909 950 10 GLM #2 4398' 3213' 891 915 10 GLM #3 5875' 4006' 869 901 12 GLM #4 7188' 4704' 847 871 12 GLM #5 8144' 5200' 826 845 12 GLM #6 8874' 5611' 804 821 12 GLM #7 9409' 5949' Orifice 16 Baker T5 SSSV @ 324' X Nipple 9C @ 9,453' (2.313" ID) 33' Jt of 2 7/8" 6.5# N80 6' Pup Jt 2 7/8" 6.5# N80 X -Over 2 7/8" EUE x 4 1/2" Butt @ 9,493' X -Over 4 1/2" Butt x NSCT Pup Jt 9 5/8" Baker S-3 Perm Packer 194-47 @ 9,499' X -Over 4 1/2" Butt x NSCT Pup Jt X -Over 4 1/2" Butt Box x 2 7/8" 8R Pin @ 9,508' 10' Pup Jt 2 7/8" 6.5# N80 8R XN Nipple 9Cr (2.205" ID) @ 9,519' 10' Pup Jt 2 7/8" 6.5# N80 8R Baker WL Re-entry Guide @ 9,531' _ FL -FP: 9562'-9637' FL -FP: 9670'-9760' FP -FS: 9807'-9833' FS -FW: 9930'-9955' FS -FW: 9972'-10047' GN -GO: 10893'-10910' GO -GR: 11372'-11419' GR -GS: 11688'-11700' GR -GS: 11706'-11716' HC -HD: 12053'-12138' (perf'd 12080 - 120' — May 2014) HE -HF: 12158'-12181' HI -HN: 12195'-12512' (perf'd 12345' - 385' -May 2014) HN -HR: 12538'-12586' HN -HR: 12616'-12854' (perf'd 12670'— 740'— May 2014) HR -HZ: 12905'-12970' HR -HZ: 12990'-13005' HR -HZ: 13063'-13081' HR -HZ: 13094'-13110' HR -HZ: 13116'-13130' 9 9 Daily Activity and Cost Summary_sls ENERGY Well Name: Middle Ground Shoal A11 -01L API/UWI 50733100780000 Location Field Name Middle Ground Shoal Permit Number 166-029 State/Province Alaska Well Configuration Type Directional Original KB Elevation (ft) 116.00 Gr Elev (ft) 0.00 KB -Ground Distance (ft) 116.00 Spud Date 6/28/1966 Rig Release Date 9/6/1966 Total Depth (ftKB) Jobs Job Category Primary Job Type / Initial Job Type Secondary Job Type / Final Job Type Start Date End Date Well Maintenance Coil clean out Reperf & 5/13/2014 00:00 5/28/2014 06:00 Acidize Objective - Summary Daily Operations Rpt No. Report Start Date Report End Date 'Operation Summary # 1 1.0 5/13/2014 5/14/2014 Crew continued rigging up Coil equipment on A -platform. Crew on C -platform back loaded the rest of the equipment and transported to A -platform. Offloaded same. Spotted and rigged up PTS, Acid, N2, tanks. Rigged up BOP stack on to the A11-01 well. Boat arrived with Baker's pump and injector head. Offloaded same equipment and continued rigging up. Rig crew is cleaning pits and mixing fluid in prep Ifor BOP testing. struction Summary # 3 No. Report Start Date Report End Date Operation Summary # 1 2.0 5/14/2014 5/15/2014 Crew completed rigging up Coil equipment on A -platform. Rig crew has completed rigging all pump lines on the PTS tank and the return line to the coil pump. Rig crew mixed 100 bbl of 3% KCI FIW. Coil crew installed coil connector and attempted to pull test to 30k. Weight indicator only showed pulling to 10k. crew, cross referenced the hydraulic pressure which indicated 30k of pull. Replaced load cell which fixed problem. Completed BOP testing 250/5000psi (GT). M/u milling assembly. Held start-up meeting with operations, Coil and, rig crews. Operator isolated well. -13 Can clean out mob Dumping .5 bbl/min at. 375 psi. Larks # 2 struction Summary # 3 No. Report Start Date Report End Date Operation Summary # 1 3.0 5/15/2014 5/16/2014 Continued clean out w/1.69" motor and a 2.125" mill pumping .5 bbl/min at 375 psi. Sporadically milled scale down to a 3 ft' bridge at 9700' CTM and loss circulation. Baker's engineer ran circulating program to see if N2 would help. It was identified that pumping within a 9 5/8" wellbore and the limiting parameters of the 1.69" motor N2 would not help. POOH w/ milling BHA. Contacted subsurface engineer and decision was made to run a 2.125" motor and N2. M/u 2.125" milling BHA and Rih pumping at 1 bbl/min. w/ 600 scf/min of N2 at 2600psi. Cleaned out hard scale to 9,900' CTM Pumping sweeps as needed. N2 pump failed and had to be repaired. Boat arrived with ISO tank and 5000gai of acid was dumped into the on deck poly tank. Backload boat. N2 pump repaired and coil is currently back on bottom milling. Larks # 2 struction Summary # 3 No. Report Start Date 4.0 5/16/2014 End Date Operation Summary # 1 5/17/2014 Milled down to 10,900' pumping'/4 bbl/min w/600 scfs of N2 at 2600psi pump pressure. We lost returns 'just for a minute and got stuck. We were able to get free by pulling 52k and surging the pump. We pulled up to 8500' and shut down pump due to being out of N2. Crew serviced equipment. Boat arrived and crew off loaded 6000 gal of N2 and 5000 gal of acid. Acid was transferred to on deck poly tanks. Crew transferred N2 to pump tank. Cooled down N2 pump and broke circ. Pumping .9 bbl/min w/365 scfs of N2 at 1853 psi of pump pressure. Tagged scale at 11675'CTM and continued milling down to 11,990' CTM. Lost returns and had to short trip back to top of liner at 10505'CTM. Currently returning back to bottom to continue milling. www.xtoenergy.com Page 1/3 Report Printed: 7/24/2014 Daily Activity and Cost Summary_sls ENO Well Name: Middle Ground Shoal A11-01L API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733100780000 Circulating at .9 bbl/min. Cooled down N2 pumps and added 300 scfs of N2 at 1600 psi of pump Middle Ground Shoal 166-029 Alaska I Directional Original KB Elevation (ft) Gr Elev (ft) KB -Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 116.00 0.00 116.00 6/28/1966 9/6/1966 hole to 8500' CTM. Circulating at .9 bbl/min. Cooled down N2 pumps and added 300 scfs of N2 at 5.0 5/17/2014 5/18/2014 Continued milling down pumping .9 bbl/min w/300 scfs of N2 at 1800psi pump pressure. We were able A11-01 - Pumped 2nd half of acid schedule across top half of oerfs utilizing Roto -jet nozzle. Pumped to get to 13,000' CTM. POOH w/ coil and milling BHA. Made up logging BHA w/ votex wash nozzle. Boat arrived and crew off loaded 8000 gal of N2. Made up Logging BHA. Ran in hole to 8500' CTM. Circulating at .9 bbl/min. Cooled down N2 pumps and added 300 scfs of N2 at 1600 psi of pump 3% KCL/FW and 300 bbls KCL/FIW. POOH & R/D CT. Spot and connect PTS flow back tank. Move pressure. Ran in hole down to 12200' CTM where pick up weight showed some over pull. Coil is currently working thought this section. Forward plan is to get to 13000' and and log up at 40 ft/min flagging coil at 12200' and 12550'md. Larks # 2 Remarks # 2 struction Summary # 3 No. Report Start Date ! Report End Date Operation Summary # 1 6.0 5/18/2014 5/19/2014 POOH w/ coil and milling BHA. L/O same. Made up logging BHA w/ 2.125" votex wash nozzle. Ran in Report End Date hole to 8500' CTM. Circulating at .9 bbl/min. Cooled down N2 pumps and added 300 scfs of N2 at 9.0 5/21/2014 1600 psi of pump pressure. Ran in hole down to 13062' CTM where we tagged solid and could not D A11-01 - Finished R/U PTS tank for flow back. Opened well for flow back at 10:00 am.30 bbls fluid make further hole. Flagged bottom and began pulled up 40'/min logging. Logged up to 8400' CTM. Flagging pipe at 12565' and 12215' corrected depth. POOH w/ logging/wash nozzle assembly. M/u Remarks # 2 perforating BHA w/ 40 feet of 1.56 perf guns (6 shots/ft 60 deg phase.) Rih correcting depth at flags. Tagged at 12776'md. Attempted to pull coil up with a max overpull of 48k. Pumped down backside at 1.5 bbl/min surging pump and was able to get free. Contacted sub -surface engineer and decision was Rpt No. Report Start Date made to perf second interval. Pumped ball and fired guns perforating from 12670' to12740'md. POOH Operation Summary # 1 UO spent guns. Forward plan is to get new perforating depths from subsurface and continue with next 5/23/2014 two gun runs. Larks # 2 struction Summary # 3 Remarks # 2 No. Report Start Date Report End Date Operation Summary # 1 7.0 5/19/2014 5/20/2014 A11-01 - M/U 2nd perf gun BHA, 40' of 1.56" (6 spf w/ 60 degree phase). RIH same to flagged depth. Correct depth & RIH to 12,345' (top shot). Pumped'/2' ball and fired gun, perforating from IZ34,5.,I.a- 1 ,;�85'. POOH and UD spent gun. M/U 3rd perf gun BHA, 40' of 1.56" (6 spf w/ 60 degree phase). RIH same to flagged depth. Correct depth and pull up hole to 12,080' (top shot). Pumped ''/2' ball and fired gun, perforating from 12,080' to 12,120'. POOH and UD spent gun. M/U Roto -jet and function test same.RIH to 13,050' Circulating "KCL/FIW. Pump first half of acid schedule across bottom half of perforations. Pull up hole and start pumping second half of acid schedule across top half of >� perforations. Larks # 2 - - 8.0 5/20/2014 5/21/2014 A11-01 - Pumped 2nd half of acid schedule across top half of oerfs utilizing Roto -jet nozzle. Pumped additional 1000 gals. 10% HCL across perfs in 9 5/8" csg. 9562'-10047' md. Displaced acid w/ 30 bbls 3% KCL/FW and 300 bbls KCL/FIW. POOH & R/D CT. Spot and connect PTS flow back tank. Move BOPE and riser over to A13-01 LN. Go through CT pump (had problems with pump losing prime while pumping acid schedule). Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 9.0 5/21/2014 5/22/2014 A11-01 - Finished R/U PTS tank for flow back. Opened well for flow back at 10:00 am.30 bbls fluid flowed back at report time. PH of 2.0. Neutralizing returns and pumping to injection well. Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 10.0 5/22/2014 5/23/2014 A11-01 - Flowing back to PTS tank. After getting G/L rate adjusted, flowed back total of 173 bbls fluid w/ PH of 5. Remarks # 2 Construction Summary # 3 www.xtoonergy.com Page 2/3 Report Printed: 7/24/2014 tDaily Activity and Cost Summary_sls ENERGY Well Name: Middle Ground Shoal A11-01L API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733100780000 Middle Ground Shoal 166-029 Alaska Directional Original KS Elevation (ft) Gr Elev (ft) KB-Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 116.00 0.00 116.00 6/28/1966 9/6/1966 Daily O rations Rpt No. Report Start Date Report End Date Operation Summary # 1 11.0 5/23/2014 5/24/2014 A11-01 - Well flowing back to PTS tank. 244 bbls flowed last 24 hours, 417 bbls total. PH is 5. Remarks # 2 _— Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 12.0 5/24/2014 5/25/2014 A11-01 - 181 bbls flowed back last 24 hrs. PH is 4.0. Currently 598 total bbls flowed back. Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date �eport End Date Operation Summary # 1 13.0 5/25/2014 5/26/2014 A11-01 - Flowed back 139 bbls fluid last 24 hrs. 737 bbls total fluid flowed back. PH is 5. Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 14.0 I 5/26/2014 5/27/2014 A11-01 - 166 bbls flowed back in last 24 hrs. 906 bbls total flowed back. PH is 6.0. Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 15.0 5/27/2014 5/28/2014 Turn well over to production. Total flowed back to PTS tank, 915 bbls w/ final PH of 6.0. Remarks # 2 Construction Summary # 3 www.xtoenergy.com Page 3/3 Report Printed: 7/24/2014 • 7r. �17%%4N� THE STATE ,-La L? .1 C', 1 b .i �., Win-''E'' �'� L_.j_'—_ "i_ 1 _�)>I\ . .a`It 1 . _e: 333 West Seventh Avenue fK. �i \ bk\ 3R SP.��N I\RNEL1, Anchorage Alaska 99501 3572 P ,Ac r)' 997 279.'A3? Sandra Haggard SCANNED MAY 0 7 Regulatory Analyst Z�a4 6(o_ ©�XTO Energy 9127 South Jamaica Street Englewood, CO 80112 Re: Middle Ground Shoal Field, B, C, D, E, F, & G Pools, MGS Al 1-01 Sundry Number: 314-252 Dear Ms. Haggard: 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, / p_7?„,v_i______ athy P. oerster Chair DATED this 2 day of April, 2014. Encl. • • ti -..J t t t3 - ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 41./2.4/ " 20 AAC 25.280 - fit✓ � 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well 0 • Change Approved Program❑ Suspend 0 Plug Perforations 0 re.-Perforate 0• Pull Tubing❑ Time Extension❑ Operations Shutdown 0 Re-enter Susp.Well ❑ Stimulate 0 Alter Casing❑ Other 'Coil tubing cleanout•• . _ 0 2.Operator Name: 4.Current Wel Class: 5.Permit to Drill Number. S{L XTO Energy Exploratory ❑ Development 0 166-029 '. 3.Address: 6.API Number: Stratigraphic 0 Service 0 9127 South Jamaica Street,Englewood,CO 80112 50-733-10078-00-00 • if•'g'/Y 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Perfing existing zone Will planned perforations require a spacing exception? Yes 0 No 0 Middle Ground Shoal Al 1-01' 9.Property Designation(Leas umber): 10.Field/Pool(s): 'PItio �/{3 ADL 1�7-56 1 6)?-511 MGS E,F,G Oil pols I Irl(7-S a(--, (' 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): • 13,238 -9,187 • 13,152 - 9,050 None Fill @ 13,120' Casing Length Size MD TVD Burst Collapse Structural Conductor 370 24 370' 370' Surface 2,625 13-3/8" 2625' 2202' 3,090 psi 1,540 psi Intermediate 9610' 9-5/8" 9610' 6052' 5,750 psi 3,090 psi Production Liner 2733' 7" 13238' 9147' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10893-13130 • 9080-9065 2-7/8 6.5#N80 8RD EUE 11199 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 9 5/8"Baker S-3 Perm Packer Packer at 9499'MD,5982'TVD and SSSV at 324'MD,324'TVD 12.Attachments: Description Summary of Proposal 0 • 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0. Exploratory ❑ Stratigraphic❑ Development 0 ' Service 0 14.Estimated Date for May 2014 15.Well Status after proposed work: Commencing Operations: Oil 0• Gas ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sandra Haggard Email Sandra Haggardextoeneray.com Printed Name Sandra Haggard Title ��/O/ �/ { ,{�/ Signature Phone 303-397-3672 Date Y lJ � / --14-Feb-14 tise COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \Li.- 2fp 2 Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: LIS-0 e) r,; dgd Tes RBDMSMAY 0 7 2014 Spacing Exception Required? Yes 0 NoIU/ Subsequent Form Required: /0 --fO' /� APPROVED BY Approved by: �� COMMISSIONER THE COMMISSION Date: 1--7i2 J/� 7 2-1.fg-,Y /4A 4/i�imY o" Submit Form and Form 10-403(Revised 10/2012) App RplIcG 5Tkrnonths from the/�to of approval. Attachments in Duplicate )(TO R E 1 AOGCC A121110,2014 Alaska Oil and Gas Conservation Commission Attn: Cathy P.Foerster, Chair 333 W. 7th Ave., Suite 100 Anchorage,Alaska 99501 Re: Form 10-403,Request for Sundry approval Objective: Coil Tubing Cleanout,Perforating and Acidize to Remove Scale Middle Ground Shoal#All-OIL MGS Field Cook Inlet,Alaska API: 50-733-10078-00 PTD#: 166-029 XTO Energy Inc.hereby submits its Application for Sundry Approval for coil tubing cleanout, perforating and acidizing to remove scale deposits in the well. Attached is the following information for your files: 1. Form 10-403 Application for Sundry Approval 2. Proposed job procedure 3. Present wellbore schematics and deviation survey If you require additional information,please contact me at 303-397-3672 Sincerely, Sandra Haggard,Regulatory Analyst Copy to: Bola Adeyeye,Operations Engineer XT0 To: Cathy P. Foester Guy Schwartz Victoria Ferguson CC: John Baker Matthew Deveau Scott Griffith From: Ajibola Adeyeye Re: MGS All-OIL(PTD: 166-029) Cook Inlet,Platform A Coil Tubing Cleanout,Re-Perforate and Acidize to Remove Scale OBJECTIVE: r L The objective of XTO Energy proposed workover for MGS A11-01 producer well is to clean-out and KLtp acidize scale deposit in the tubing and across the production interval;the well has a history of scale deposit,requiring periodic cleanout.The plan includes mechanical cleanout of the tubing and liner via coil tubing,jet nozzle/mill.Afterwards,the well will be acidized to remove additional solids in the wellbore and across the production interval;diverting agent will be spotted to improve the distribution of acid into the perforations.A selected section of the existing production interval will be re-perforated and acidized to create flow paths around scaled perforations that did not adequately cleanout WELL HISTORY: All-01 was drilled in 1966. This well was completed in the FL through HZ zones;production from the upper zones 'F' was isolated from the rest of the producing interval.However,the dual completion was removed in 2001 and all zones were comingled. The well IP's at 1911 BOPD 53BWPD and 773 MCFD. The well has a history of fill deposits in the tubing and across the production interval.The most recent coil tubing cleanout on this well was in 2002. Since then,there have been multiple slickline run to remove scale deposits in the tubing. Substantial volume of fill is expected at the bottom of the well due to deposits and accumulation of scale removed during the slickline scratcher runs. The anticipated start date for this workover is May 2014.Please contact me at 720-539-1660 with any questions or concerns. Sincerely, Bola Adeyeye Operations Engineer PLF 9-8-05 ;till° NERGY Current Completion MGS Al 1-01 ■ • / KB: 38' Water Depth: 75' MSL Cook Inlet, Alaska J Tbg: 2 7/8"6.5# N80 EUE 8R @ 9,531' Leg 1, Conductor 2 Set on 12-2-01 API #733-10078-00 J Item MD TVD Psc Pso Port Spud 6-28-66 1 / GLM#1 1953' 1804' 909 950 10 1 �4 GLM#2 4398' 3213' 891 915 10 J GLM#3 5875' 4006' 869 901 12 GLM#4 7188' 4704' 847 871 12 Surf Csg: 13 3/8", 61 Ib, J55. GLM#5 8144' 5200' 826 845 12 Set @ 2,625'. Cmt'd w/3,400 sx. J GLM#6 8874' 5611' 804 821 12 GLM#7 9409' 5949' Orifice 16 Baker T5 SSSV @ 324' J X Nipple 9Cr @ 9,453' (2.313" ID) 33' Jtof27/8"6.5# N80 Intermediate Csg: 9 5/8", N80. 6' Pup Jt 2 7/8" 6.5#N80 Set @ 10,647'. Cmt'd w/ 1,250 sx. / J X-Over 2 7/8" EUE x 4 1/2" Butt @ 9,493' 0-62' :47# / X-Over 4 1/2" Butt x NSCT Pup Jt 62-7,269' :40# 9 5/8" Baker S-3 Perm Packer 194-47 @ 9,499' 7,269-9,485' :43.5# / J X-Over 4 1/2" Butt x NSCT Pup Jt 9,485- 10,647' :47# 0 ■ X-Over 4 1/2" Butt Box x 2 7/8" 8R Pin @ 9,508' 10' Pup Jt 2 7/8"6.5# N80 8R XN Nipple 9Cr(2.205" ID) @ 9,519' / ■ U 10' Pup Jt 2 7/8"6.5# N80 8R Baker WL Re-entry Guide @ 9,531' 5-6-05: Scale Top @ 9610'. A FL-FP: 9562'-9637' Can not make progress w/SL. . . FL-FP: 9670'-9760' /V scale FP-FS: 9807'-9833' �/ FS-FW: 9930'-9955' J : . . '� FS-FW: 9972'-10047' Prod Liner: 7", 29 lb, N80. : : GN GO: 10893'-10910' Set @ 10,505-13,238'. Cmt w/500 sx. GO GR: 11372'-11419' GR-GS: 11688'-11700' • GR-GS: 11706'-11716' : :„ HC-HD: 12053'-12138' :�' HE-HF: 12158'-12181' _• HI-HN: 12195'-12512' HN-HR: 12538'-12586' :•: HN-HR: 12616'-12854' HR-HZ: 12905'-12970' A HR-HZ: 12990'-13005' HR-HZ: 13063'-13081' Top of sand @ 13,120' (4-5-02) : :::: HR-HZ: 13094'-13110' w/BH Bomb w/slickline. ::::::•••• :::::::::::::::::— HR-HZ: 13116'-13130' lh::>::::::: PBTD: 13,152' MD (9,050'TVD) . :::::::::::::::::::: A TD: 13,238' MD (9,187'TVD) V XT0ERGY MGS All-01L Workover Package for Coil Tubing Cleanout, Perforate and Acidize Operations Engineer: Bola Adeyeye Office: (303)3973606 Cell: (720)5391660 Well Identifier i Well Name: MGS A11-01L Permit to Drill Number: 166-029 API #: 50-733-10078-00-00 Objective Perform coil tubing cleanout to remove scale and other debris in the well.Soak well with acid, perforate existing zone and squeeze acid in the perforations; perform scale inhibitor squeeze. Background A11-01 was drilled in 1966.This well was completed in the FL through HZ zones; production from the upper zones 'F' was isolated from the rest of the producing interval. However,the dual completion was removed in 2001 and all zones were comingled.The well IP's at 1911 BOPD 53 BWPD and 773 MCFD. The well has a history of fill deposits in the tubing and across the production interval.The most recent coil tubing cleanout on this well was in 2002.The well was cleanout using a mixture of Xylene and 10% HCI, more acid was squeezed into the formation to clean near wellbore damage.A net gain of 14 bopd and 8 bwpd was realized after the cleanout and acidizing. Since the last cleanout in 2002,there have been multiple slickline run to remove scale deposits in the tubing.Substantial amount of fill is expected at the bottom of the well due to deposits and accumulation of scale removed during the slickline scratcher runs. Precautions Prior workover on this well indicated sand purge and deposit in the rat-hole and possibly covering the bottommost set of perforation (13,116'—13,130'). Gel sweeps might be essential for adequate cleanout. Caution should also be taken while cleaning the sand due to existing fish (wireline & BH bomb) Workover History Activity Date Comments Well drilled June 1966 Initially dual completion (FL—FW isolated from rest) Pulled dual completion Oct 2001 Comingled all producing zones, single completion string Coil tbg cleanout&acidize March 2002 DAD acid used for cleanout, 1460 8 BW net gain Scratcher run on slickline Sept 2002 Stopped at 9282'jarred, cut hard scale to 9372' Scratcher run on slickline April 2003 Encountered resistance @ 9460—9552', cut more scale Psi build-up test on SL Feb 2005 At 9,585' MD (6,040 TVD) pressure was 1401 psi Scratcher run on SL May 2005 Cut light scale bridges (9379'—9549')tagged fill at 9572' Current Well Status Well is currently producing 18 bopd,44 bwpd, 95 mcfd. Lift gas is continuously injected at 1057 mcfd. MGS A11-01:Coil Tubing Cleanout and Acidizing Procedure FINAL Wellbore Construction Detail ID Drift Cap. Annular 100% 1.25 SF 100% 1.33 SF Bbl/Ft Bbl/Ft Burst Burst Collapse Collapse Prd Tbg: 2-7/8", 6.5# L80@ 9,531' 2.441 2.347 0.00579 0.0302 13570 10856 13310 10007 Prd Liner—7", 29#, N80 @13,152' 6.184 6.059 0.0177 8160 6528 7020 5278 Intermediate Csg—9-5/8", 40#, 43.5#and 47# L80 set at 10,647' Surf Csg—13-3/8",61#,J55 @ 2,625' 12.515 12.359 0.1521 3090 2472 1540 1157 Well Data Surface Casing: 13-3/8", 61#, J55. Set at 2,625'. Cmt with 3,400 sxs Intermediate Casing: 9-5/8", 40#, 43.5# & 47# L80. Set at 10,647', cemented with 1,250 sxs Drilling Liner: 7", 29#, N80. Set at 13,238'. Cmt with 500 sx Top of liner at 10,505' PBTD: "13,152' Tubing: 2-7/8" 6.5#, L80. EOT at 9,531' Packer: 9-5/8" Baker S-3 Permanent Packer 194-47 @ 9,499' BHST: 240 F BHP: 3300 psi Smallest ID: Nipple milled to 2.205" ID at 9,519' Max Deviation: 60.25 deg at 6,900' MD Other: Top of sand at 13,120' tagged 4-5-2002. There is fish (BH bomb) below the tagged depth, actual depth is unknown. MGS A11-01:Coil Tubing Cleanout and Acidizing Procedure FINAL o- Vendor Outline Coil Tubing unit—Baker/BJ Services Josh Herald 907-398-8303 Chemical Supply—Baker Petrolite Clyde Willis 907-229-0052 Bits, Motors, BHA Colin Walderp/Jeffery Canter 907-283-8131 Crane Operator—All American Pete Dickinson 907-230-6541 Rousterbout & Drill Supv—All American Pete Dickinson 907-230-6541 GR—CCL logging tool - Schlumberger Barry Milazzo 817-915-9555 Perforating Gun - Schlumberger Scot Shier 469-315-0786 Flowback Iron —All American Oilfield Craig Rang 907-252-6799 KCI Supply— Mi Swacco Bob Myles 907-252-4218 Materials Required ■ 12000 gal 10% HCI Acid ■ 50 bbl Gel pill (supplied by Baker Hughes) ■ 250 bbl 3% KCI —Fresh Water (mixed out of fresh water) ■ 1000 bbl 3% KCI— FIW (fixed out of filtered inlet/sea water) ■ Nitrogen foam will be used for diversion and to assist fluid cleanout ■ 300 gal of Baker Scale Inhibitor, this will be flushed with 3% KCI FIW Equipment Required ■ 1.75" Coil Tubing Unit ■ 1.75" Pipe and blind rams, BOPE ■ 55 ft Lubricator ■ Crane; provided by the platform ■ 2 PTS tanks—250 bbl each Diverting Agent (Nitrogen Foam) 75Q ■ Nitrogen volume—260 Mscf. Pumped volume of 3% KCI Fresh water with N2= 850 gal ■ 3 gpt FAW-21 foaming agent Acid Additives and Other Chemicals ■ 10 % HCI —Inorganic acid used to acidize the formation ■ 50 gpt US-40—mutual solvent. Formation water wetting agent & reduce surface tension ■ 25 ppt Ferrotrol 300—acid treatment fluid to prevent precipitation of ferric hydroxide } 25 gpt Super A sol (WLC 603)—Mutual solvent (sec section below) ■ 3 gpt NE-945—Non Emulsifier ■ 5 gpt CI-27—corrosion protection of tubular, casing & BHA ■ 20 gpt Ferrotrol 280L- acid treatment fluid to prevent precipitation of ferric hydroxide ■ 1.0 gpt Clay Master-5C—to prevent formation damage due to scale swelling Lead Fluid Super A-Sol (WLC 603) Mutual solvent,for removal of oil layer& water wet the rock ■ 2000 gal super A-Sol mixed in 2000 gal 3% KCI fresh water. This will be divided into 4 stages, 1000 gal for each stage MGS A11-01:Coil Tubing Cleanout and Acidizing Procedure FINAL Scale Inhibitor Squeeze • 610 gal of mutual solvent A-sol (WLC603) mixed in 15 bbl 3% KCI - FIW • 610 gal of scale inhibitor (SCW4004) mixed in 82 bbl FIW...Please call Operations engineer to discuss required volume for over-flush Other Chemicals • Soda Ash —to neutralize spent acid before sending to disposal well • H2S Scavenger—for cleanout returns that might have residual H2S • 2.8 gpt FRW-16A— Friction reduction agent for the FIW Well;fir°Schematic:A11-01 PLF 9-8-05 NERGY / Current Completion MGS A11-01 •I • • / KB:38' Water Depth:75'MSL Tb Cook Inlet,Alaska jl g:2 7/8"6.5#N80 EUE 8R @ 9,531' Leg 1,Conductor 2 , Set on 12-2-01 API#733-10078-00 Spud 6-28-66 04, J of nem MD TVD Psc Pso Port GLM#1 1953' 1804' 909 950 10 "e�j GLM#2 4398' 3213' 891 915 10 J GLM#3 5875' 4006' 869 901 12 GLM#4 7188' 4704' 847 871 12 Surf Csg: 13 3/8",61 Ib,J55. GLM#5 8144' 5200' 826 845 12 Set©2,625'. Cmt'd w/3,400 sx. J GLM#6 8874' 5611' 804 821 12 GLM#7 9409' 5949' Orifice 16 Baker T5 SSSV @ 324' J X Nipple 9Cr©9,453'(2.313"ID) 33'Jt of 2 7/8"6.5#N80 Intermediate Csg:9 5/8",N80. /�// ////r 6'Pup Jt 2 7/8"6.5#N80 Set @ 10,647'. Cmt'd w/1,250 sx. J X-Over 2 7/8"EUE x 4 1/2"Butt @ 9,493' 0-62':47# ,/l X-Over 4 1/2"Butt x NSCT Pup Jt 62-7,269':40# // / 9 5/8"Baker S-3 Perm Packer 194-47 @ 9,499' 7,269-9,485':43.5# // J X-Over 4 1/2"Butt x NSCT Pup Jt 9,485-10,647':47# ■ ■ / X-Over 4 1/2"Butt Box x 2 7/8"8R Pin @ 9,508' ■ /// XN Nipple 9Cr(2.255"ID) 9,519' 10'Pup Jt27/8"6.5#N808R 0/ Baker WL Re-entry Guide©9,531' 5-6-05:Scale Top©9610'. / — FL-FP: 9562'-9637' Can not make progress w/SL. 1010 — FL-FP: 9670'-9760' //r5.ale.. �/w FP-FS: 9807'-9833' r /I FS-FW: 9930'-9955' r/rr '/. FS-FW: 9972'-10047 Prod Liner 7",29 lb, N80. •;:;T GN-GO: 10893'-10910' •Set @ 10,505-13,238'. Cmt w/500 sx. //, ►,�,1 GO-G R: 11372'-11419' ' /!!/!/,1�1 GR-GS: 11688'-11700' • GR-GS: 11706'-11716' / HC-HD: 12053'-12138' HE-HF: 12158'-12181' / HI-HN: 12195'-12512' / • HN-HR: 12538'-12586' HN-HR: 12616'-12854' HR-HZ: 12905'-12970' HR-HZ: 12990'-13005' HR-HZ: 13063'-13081' HR-HZ: 13094'-13110' Top of sand @ 13,120' (4-5-02) :]:::::::::::::•:•::,:::::::::•:•:•:. HR-HZ: 13116'-13130' w/BH Bomb w/slickline. / :: ::r, PBTD: 13,152'MD(9,050'TVD) y/ "`:i TD: 13,238'MD(9,187'TVD) '//// / MGS A11-01:Coil Tubing Cleanout and Acidizing Procedure FINAL zi • Production Trend (6 year) MGI. All-OiL BBL 1500 ,75 1 400 i0 1-300 .65 1.200 60 1.1 OO .S5 1.000 SD 1 500 '""!y ( 45 00 ill 1'0 �'.. SA i 1 ,40 RSI t 35 600 1.11111 ,, ,,1, ,I •1 I .90 500 .25 400 ]0 300 13 200 10 100 'rn�\!S 0 1 Iilii - J .0 1OI1/OP .1 131 7;, ,0H 1;1 4I, 7/1 10H 1;1 .1 1i1 10/0 1/1 4/1 7;, 10/1 lit 4131 TH 0/30/13 -9.. —d —Wt.. ..W .In; —0..,n}-0. CO2'.sd —CO2 Y1wYen —d0/T-,y.• —O.rry-• --LM.Koti.,uw Production Chart (5 year) MCF BBL All-01 L 1,200 120 1,000 100 800 80 ll0 800 N1111101 Il , , li 1/iiimoo IBO 40040 i mil'4.10I! Aro it *Aril 1 iii1[11, I l I 1 NI In zozoo ✓ Y o LMY.tr.a11 Uli,l�r,l� .k ....�+.+I, 1. *.mu���+�,PI Alli I��l+I � 1_l.+l�io 4/4109 811 1111 211 511 8/1 11/1 2/1 5/1 8/1 11/1 2/1 5/1 8/1 11/1 2/1 5/1 8/1 11/1 413/14 D Gas - ®Oil —■Water —■Water Inj —■Gas Injection ❑CO2 Prod —■CO2 Injection —■Gas Target —■Oil Target •••LinePressure Clear Selections Lift Gas Injection and Production Pressure Chart Ptil All-01 L Hr Dn 1,200• •30 1,D00I I 25 800• 1 •20 I II-800-....A........6 +) r+I0*15 et 4 a+ 400- .1At -+ 10 200 - 11: 5 4/41• 09 8/1 1111 2/1 5/1 8/1 11/1 2/1 5/1 8/1 11/1 2/1 5/1 8/1 11/1 211 5/1 8/1 11/1 4/3/14 —■Casing Pressure 'DTubing Pressure —■Annulus Pressure —•■SurfaceCasingPressure ❑InterCasingPressure 0 Down Hours . ■SoapStick Clear Selections MGS A11-01:Coil Tubing Cleanout and Acidizing Procedure FINAL • Summary Procedure 1. Nipple up the slickline unit, BOP and lubricator. Run into the well with the retrieving tool to pull the SSSV.Send the SSSV to the shop for inspection and redress, if necessary. 2. Move in the coil tubing unit and all associated equipment.Conduct safety meeting to review the daily work program and communicated associated risk with the entire crew. A ; 3. Test BOPE, NU injection head and lubricator with the holding support of the crane 4. Pickle the coil tubing with acid and flush with 3%brine water, dispose appropriately. Ljs-bo ,,5� 40p orf 5. Pick up the vortex jet nozzle, CCL, GR memory tool (placed in a carrier)on 1.75" coil tubing and run into the well. • 6. Continue cleaning the production tubing, reduce speed upon approach of the end of tubing. Cleanout the inside of the 5" liner, and continue until approach a tagged depth. Spot acid across the production interval to soften any existing solid bridges. 7. Perform an extra bottom to top of liner cleanout record tagged depth during each downward 05" c_T trip. Flag depth as recommended by the SGhhtr beT er logging technician for proper depth measurement of proposed depth to be perforated. Pull the coil tubing out of the well. 8. If tagged high during the jet nozzle trip, pick up mill and motor. Run into well to clean additional solids in the liner, clean out the fill covering the bottommost perf, attempt to clean down to 13,140'. 9. Lay down the bit and motor. Pick up the perforating gun and run into well. Confirm the target perforating depth, drop the ball to fire the gun. Pull the gun assembly out of well and run the next set guns to perforate the subsequent zones. • 10. Pick up the roto-jet tool, run into the well. Pump the recommended acid design for the job. Shut `/ in the coil tubing annulus and squeeze acid into the perforations. 11. Pull the coil tubing out of well and allow acid to soak for 1-2 hrs 12. Nipple down lubricator, BOPE and move the coil tubing over to the next well. 13. Resume the injection of lift gas on the well. Flow back well to the PTS tank, monitor flow and take periodic pH level of the fluid 14. Once the fluid pH is at recommended level ("pH 5 for an extended time), prepare scale inhibitor mixture and bullhead into the well to enable effective squeeze into the producing zones. 15. Resume lift gas injection and collect fluid samples periodically to measure the scale inhibitor residual Risks and Safety Considerations 1. All PPE's(FRC's, hard hat, safety glasses, steel toe boots) must be worn at all times, no exception.Additional PPE's might be required for personnel involved in other specific roles. 2. Pressure test will be required on the BOPE,surface lines and manifolds; refrain from the vicinity of the equipment during these tests. Following AOGCC guideline,the BOPE will be set-up as follow(Top to Bottom) - One annular type preventer MGG All-01:Coit"1.Libing Cleanout odd Acidizing Procedure FINAL 6 • - One blind/shear rams - One pipe ram that is sized for the 1.75" coil tubing 3. Lubricator and injection head will be held with crane during the coil tubing work, personnel should stay clear of the lifting area as much as necessary. 4. Acid and other hazardous chemicals will be mixed in tanks and used during the cleanout process.All required PPE must be used when handling and mixing these chemicals; MSDS sheets must also be available within close proximity of these chemicals 5. Perforating guns will be used on the wells; manufacturer recommended precautions should be exercised for the handling and storage of these guns. Pre-Mobilization Plan for Production Operators ***Approximately 1 week prior to resuming coil tubing cleanout, shut off the lift gas supply into the annulus. Open the well to flow up the tubing to bleed-off effluent gas in the well. If well stop flowing, shut-in the well and periodically open to flow to bleed off head gas in the tubing. DETAILED PROCEDURE Major Notes ***Anticipated shut in pressure on this well is 3300psi. Production tree and wellhead are rated to 5000 psi. ***Do not include bleach or chlorinated chemical for the treatment of FIW ***Nitrogen foam will be used for diversion during the acid squeeze ***There if fish (BH Bomb) below the bottommost perforation, proper care need to be exercised when cleaning below tagged depth to avoid getting stuck in the rat-hole ***** Note: 3% brine water mixed from fresh water must be used as spacer fluid whenever acid is pumped. Refrain from allowing FIW to get in contact with the acid. ***** Mobilize, Set-up Equipment, Ria-Up 1. Move in All American Service crew to prepare the platform for the cleanout program, prep work will include insuring space for equipment location are cleared and measured for spotting ahead of time. Ensure crew is on-site at least 3 days prior to coil tubing mobilization. IVIGS All 01, Coil I ubing Cleonout and Acid,zing Procedure FINAL 7 2. Prior to staging equipment, conduct safety meeting to review the work program; potential hazards should be identified and communicated to the entire crew involved in the program 3. Stage the PTS tanks, move in the 1.75" Coil Tubing unit, lubricator, injector head, acid/other chemical vessels and all associated equipment required for the workover. Set-up the site, lay down and connect pipes to flowback/PTS tank and manifolds. Prepare fresh water mixed adequately with KCI to create 3% brine solution in the mud/PIT tank. - Two PTS tanks will be used on each platform during this program;this will enable adequate flowback of dirty fluid from multiple workover wells before sending offshore. Substantial cleanout of dirty fluid to the disposal well will help in minimizing the amount of sludge transported offshore. - Debris catcher/filter should be installed on the flowback line before the PTS tank to capture solids returns. Filter should be monitored and periodically emptied. - Ensure there are accessible valves on the flowback line to collect and monitor cleanout fluid on the upstream and downstream of the PTS tanks. Test BOPE and Pickle Coil Tubing 4. Ensure the master and wing valves are closed, re-check to insure the lift gas line is properly locked/tagged and closed. Nipple up pipe rams, blind rams,annular preventer, lubricator and injector head, hoist the lubricator and injector head with the support of the crane. 5. Contact AOGCC 48 hours prior to BOP test,test BOPE to 250 psi and 5000 psi, low and high pressure for both shell and pipe tests. 6. Pump pipe volume of acid down the coil tubing to pickle and flush with 3%brine water that is conditioned from fresh water. Send the used acid and flush fluid to the PTS tank and be disposed appropriately. Cleanout with Vortex Jet Nozzle,Acid Soak and Mill Scale 7. Pick up the regular/vortex let nozzle,gamma ray and CCL memory tool, assemble the BHA. Memory tool will be installed in the carrier to enable flow across it. 8. Make-up BHA to the coil tubing connector and run into the well. Continue tripping into the well at 100fpm while washing out solids and other debris in the tubing with slick 3% KCI FIW and circulating at 1 -2 BPM 9. Continue cleanout and monitor the annulus pressure and returns for difficulty in lifting fluid. Establish circulation with nitrogen, pump down with the foaming agent as necessary to enhance the fluid flowback. Periodically collect samples on the flowback line and assess the effectiveness of the cleanout. MGS All-01: Coil Tubing Cleanout and Acid/zing Procedure FINAL 8 10. Continue cleaning the tubing while proceeding with caution through delicate/restricted sections such as the gas lift valves,X-over/BHA, 'XN' nipple 11. Reduce the speed while approaching the end of tubing. Continue cleanout through the liner and proceed slowly until tagged. - Pull up every 300 ft to ensure the coil tubing is not getting stuck, pump 5 bbl slugs of gel sweeps to improve the clean-ups. - If tagged high or unable to get to the bottom of the well, pump down 500 gal of acid and spot on top of the scale. Mill will be necessary for further cleanout 12. Make an extra up-down pass from the liner top at 40 fpm and clean additional scale on the perforations,continue downward till bottom is tagged. Flag the depths recommended by the logging technician while pulling out of the well. - If there are traces of barium sulfate in the scale (or radioactive tendency),the additional pass will help in assessing the success of cleaning out the deposits in the perforations,via the GR log. 13. Pull the vortex jet tool and logging tools out of the well. Download the log data and send to the production engineer. 14. If unable to get to bottom of the well with the roto-jet tool, pick up 1-11/16" motor and 2 -3/8" bit. Run into well at 80 fpm, mill out additional scale deposit in the liner Re-Perforating Exiting Producing Interval Via TCP The perforating gun will be put together at the Schlumberger's workshop into transportable sections and delivered to the platform; each run will consist of 40 ft gun with a 5 ft firing head. This will provide adequate space to trip and pull through the 50 ft lubricator A shear pin must be included on the BHA to release of the guns; in situation of last resort. The flagged depth on the CCL/GR log from earlier run will be used for depth correlation. 15. Hold a pre-job safety meeting before picking up the perforating guns. Designate the essential personnel allowed on the rig floor while assembling and running the gun.All non-essential members must stay away from the location during the perforating events. 16. Assemble to 40 ft gun and the firing head, run the coil tubing with connector through the lubricator to make-up to the gun assembly. Gradually pull out with the coil tubing to pull the gun while pulling up the lubricator with the crane. MGS A11-01. coil Tubing Cleanout and Acidizing Procedure FINAL 9 17. Position the lubricator over the well;flange back the lubricator onto the BOP. Open the master valves and trip the perforating gun into the well. 18. Correlate and ascertain the depth to be perforated (refer to table 1), drop the ball and pump down to seat. Continue pumping to gradually pressure up to 3000 psi and engage the firing head, observe signals that indicates the gun is fired.Such sign includes sudden vibration on the lubricator/wellhead,and fluid surge out of the annulus. Table 1: Perforating gun data Run# Perforating Interval (ft) Target Interval Comments 1 TBD TBD Gun spec 1.56", 60 deg, 6spf, PJ1606 2 TBD TBD Gun spec 1.56",60 deg,6spf, PJ1606 3 TBD TBD Gun spec 1.56", 60 deg, 6spf, PJ1606 19. Upon confirmation that the gun fired, carefully trip out while exercising some caution across the constricted depths(end of tubing, sliding sleeve and `XN' profiles). 20. Trip out to the surface; close the master valve and laydown the perforating gun. 21. Repeat steps 17-21 for the second and third run of the 40 ft gun. Acid Squeeze 22. Pick up the roto-jet tool and run in at 100 fpm while circulating slick 3% KCI FIW.Continue cleaning the tubing and across the liner top,take returns up the CT annulus and circulate foamed nitrogen as necessary. 23. While at the topmost perforation on the 'G' interval (10,893'), pump down 10 bbl 3% KCI—fresh water as spacer, 10 bbl 10% HCI acid and tail with another 10 bbl 3% KCI-fresh water. Slow down the pumping rate to1/4-Y2 bpm as the acid approach the end of the tubing 24. Gradually proceed deeper into the liner while washing the perforation at this reduced rate, cleanout to the tagged depth. 25. Pull up the coil tubing to 12,200',the middle of the perforations. MCi5 A11-OL Col tubing Cleanout and Acidixing Procedure FINAL 10 26. Pump fluid down the tubing while following the tabled sequence below.After 15 bbl of the 3% KCI—Fresh water in step 1 have exited the coil tubing, close the coil tubing annulus(refer to table 2). - Record time and rate when each fluid is pumped to estimate time of 3% KCI-fresh water at bottom of coil tubing. 27. Continue pumping the fluid as recommended to squeeze the acid into the formation. Table 1: Fluid Sequence for Acid Squeeze(FW=Fresh Water and FIW=Filtered injection Water) Step Fluid Volume Comment/Purpose 1 3% KCI—Fresh Water(FW) 15 bbl Displacement of 3% KCI—FIW into perfs 2 Foamed 3% KCI FW 850 gal Diverting agent to prevent acid into opened zones 3 50%Super A-sol in FW 1000 gal Mutual solvent-remove oil layer in rock&water wet 4 10% HCI acid 2000 gal Acid stage 1- squeeze into formation 5 Foamed 3% KCI FW 850 gal Nitrogen foam diverting agent (65 Mscf N2) 6 50%Super A-sol in FW 1000 gal Mutual solvent-remove oil layer in rock&water wet 7 10% HCI acid 2300 gal Acid stage 2—squeeze into formation 8 Foamed 3% KCI FW 850 gal Nitrogen foam diverting agent (65 Mscf N2) 9 50%Super A-sol in FW 1000 gal Mutual solvent-remove oil layer in rock&water wet 10 10% HCI acid 2700 gal Acid Stage 3—Squeeze into formation 11 Foamed 3% KCI FW 850 gal Nitrogen foam diverting agent (65 Mscf N2) 12 50%Super A-sol in FW 1000 gal Mutual solvent-remove oil layer in rock&water wet 13 10% HCI acid 3000 gal Acid Stage 4—Squeeze into formation 14 3% KCI —Fresh Water 15 bbl Spacer 15 3% KCI —FIW 300 bbl Tubing vol+100%over-displ(liner top to deepest perf) 28. Pull the coil tubing out of the well, lay down the roto-jet nozzle. Shut in the well, nipple down the coil tubing lubricator and BOPE. Move coil tubing over to the next well. 29. Allow acid to soak for 1-2 hours. Monitor and chart the tubing pressure. 30. After 1—2 hrs and upon consultation with the production engineer, open well to flowback to the PTS tank and resume injection of lift gas to aid liquid unloading. Monitor returns and send flowback fluid into the disposal well. - pH of the flowback fluid must be measured and recorded, send record of the data to production engineer and Baker Hughes chemical contact before proceeding to the next step 31. Once the fluid pH is at recommended level (pH^ 5)for an extended time, shut off lift gas supply. MGS A11-01.Coil Tubing Cleanout and Acidizing Procedure FINAL 11 Scale Inhibitor Squeeze 32. Prepare scale inhibitor mixture. Engage the mud pump and bullhead the scale inhibitor as recommended in table 3. Flush with 3% KCI—FIW and shut in the well for 24 hours. Table 3: Scale Inhibitor Squeeze—Fluid Sequence Fluid Type Volume (gal) Comment Mutual Solvent(WLC603) 610 gal in 15 bbl FIW Scale Inhibitor(SCW4004) 610 gal in 82 bbl FIW 3%KCI—FIW(flush) To be determined (call Bola) Call production engineer to discuss 33. After 24 hours and upon the approval of the production engineer, handover well to production team and resume injection of the lift gas. 34. Collect labelled bottle sample of fluid on an hourly basis, send sample Baker Hughes lab for further testing for scale inhibitor residuals. Well Log MCS All 01:Coil Tubing cleanout and Acidizing Procedure_FINAL 2 Well Directional Survey • ss Kick or WellName MD TVD HoleAngle Azmth Elev xcoord ycoord Zdepth Closure E/-W N/-S A11-01 0 0 0 0 116 -432 6912 116 0 0 0 A11-01 100 100 0.32 303 116 -432.2 6912.2 16 0.3 -0.2 0.2 A11-01 200 200 0.57 293 116 -432.9 6912.5 -84 1.1 -0.9 0.5 A11-01 300 300 1.07 306 116 -434.1 6913.2 -184 2.5 -2.1 1.2 A11-01 400 399.9 4.32 340 116 -436.2 6917.3 -283.9 6.8 -4.2 5.3 A11-01 500 499.3 8 357 116 -437.8 6927.8 -383.3 16.9 -5.8 15.8 A11-01 600 598.2 8.75 355 116 -438.9 6942.4 -482.2 31.1 -6.9 30.4 A11-01 700 696.7 11.42 14 116 -437.1 6959.5 -580.7 47.8 -5.1 47.5 A11-01 800 794.2 14.07 19 116 -430.8 6980.6 -678.2 68.7 1.2 68.6 A11-01 900 890.8 15.92 22 116 -421.7 7004.9 -774.8 93.4 10.3 92.9 A11-01 1000 986.6 17.32 23 116 -410.7 7031.3 -870.6 121.2 21.3 119.3 A11-01 1100 1082.3 16.5 14 116 -401.5 7058.8 -966.3 149.9 30.5 146.8 A11-01 1200 1177.5 19.32 13 116 -394.3 7088.7 -1061.5 180.6 37.7 176.7 A11-01 1300 1270.2 24.57 15 116 -385.2 7124.9 -1154.2 218 46.8 212.9 A11-01 1400 1361.3 24.17 15 116 -374.5 7164.7 -1245.3 259.2 57.5 252.7 A11-01 1500 1450.2 30.07 17 116 -361.9 7208.5 -1334.2 304.7 70.1 296.5 A11-01 1600 1534.6 34.92 19 116 -345.2 7259.6 -1418.6 358.2 86.8 347.6 A11-01 1700 1615.1 37.82 19 116 -325.9 7315.6 -1499.1 417.3 106.1 403.6 A11-01 1800 1693.7 38.5 14 116 -308.4 7374.8 -1577.7 479.1 123.6 462.8 A11-01 1900 1767.5 46.32 14 116 -292.1 7440.2 -1651.5 546.4 139.9 528.2 A11-01 2000 1836.7 46.17 13 116 -275.3 7510.5 -1720.7 618.6 156.7 598.5 A11-01 2100 1904.7 48.07 10 116 -260.7 7582.3 -1788.7 691.8 171.3 670.3 A11-01 2200 1970.7 49.32 6 116 -250.3 7656.6 -1854.7 766.5 181.7 744.6 A11-01 2300 2033.7 52.57 5 116 -242.8 7733.9 -1917.7 843.4 189.2 821.9 A11-01 2400 2091.9 56.25 4 116 -236.5 'E -1975.9 923.9 195.5 903 A11-01 2500 2147.1 56.75 5 116 -229.9 7898.1 -2031.1 1006.6 202.1 986.1 A11-01 2600 2202.1 56.57 5 116 -222.6 7981.3 -2086.1 1089.6 209.4 1069.3 A11-01 2700 2257.8 55.75 4 116 -216.1 8064.1 -2141.8 1172.2 215.9 1152.1 A11-01 2800 2314.3 55.42 2 116 -211.8 8146.5 -2198.3 1254 220.2 1234.5 A11-01 2900 2371 55.42 4 116 -207.5 8228.7 -2255 1335.7 224.5 1316.7 A11-01 3000 2428.4 54.65 4 116 -201.8 8310.5 -2312.4 1417.3 230.2 1398.5 A11-01 3100 2486.2 54.75 8 116 8391.6 8391.6 -2370.2 1498.7 238.8 1479.6 A11-01 3200 2544.8 53.5 7 116 -182.7 8471.9 -2428.8 1579.7 249.3 1559.9 A11-01 3300 2604.2 53.5 6 116 -173.6 8551.8 -2488.2 1660 258.4 1639.8 A11-01 3400 2663.2 54.25 8 116 -163.7 8632 -2547.2 1740.8 268.3 1720 A11-01 3500 2720.9 55.25 8 116 -152.3 8712.8 -2604.9 1822.4 279.7 1800.8 A11-01 3600 2776.8 56.75 7 116 -141.5 8795 -2660.8 1905.3 290.5 1883 MGS A11-0.1: Coil Tubing Cleanout and/Iodizing ProcedureeFINAL ' A11-01 3700 2830.6 58.25 9 116 -129.8 8878.5 -2714.6 1989.6 302.2 1966.5 A11-01 3800 2883.6 57.75 8 116 -117.2 8962.4 -2767.6 2074.4 314.8 2050.4 A11-01 3900 2936.5 58.25 7 116 -106.2 9046.5 -2820.5 2159.2 325.8 2134.5 A11-01 4000 2989 58.5 7 116 -95.8 9131 -2873 2244.3 336.2 2219 A11-01 4100 3041.8 57.75 8 116 -84.7 9215.2 -2925.8 2329.2 347.3 2303.2 A11-01 4200 3095.3 57.5 8 116 -73 9298.8 -2979.3 2413.7 359 2386.8 A11-01 4300 3149.8 56.5 7 116 -62 9382 -3033.8 2497.5 370 2470 A11-01 4400 3205.7 55.5 9 116 -50.5 9464.1 -3089.7 2580.4 381.5 2552.1 A11-01 4500 3261.3 57 10 116 -36.8 9546.1 -3145.3 2663.5 395.2 2634.1 A11-01 4600 3316.1 56.5 9 116 -23 9628.5 -3200.1 2747.2 409 2716.5 A11-01 4700 3372 55.5 8 116 -10.7 9710.5 -3256 2830.1 421.3 2798.5 A11-01 4800 3428.3 56 9 116 1.5 9792.3 -3312.3 2912.7 433.5 2880.3 A11-01 4900 3482.8 58 9 116 14.6 9875.1 -3366.8 2996.6 446.6 2963.1 A11-01 5000 3535.4 58.5 10 116 28.7 9959 -3419.4 3081.6 460.7 3047 A11-01 5100 3587.3 59 10 116 43.5 10043.2 -3471.3 3167.1 475.5 3131.2 A11-01 5200 3639.3 58.25 9 116 57.6 10127.4 -3523.3 3252.4 489.6 3215.4 A11-01 5300 3691.6 58.75 11 116 72.4 10211.3 -3575.6 3337.7 504.4 3299.3 A11-01 5400 3743.5 58.75 11 116 88.7 10295.2 -3627.5 3423.1 520.7 3383.2 A11-01 5500 3795.9 58 10 116 104.3 10379 -3679.9 3508.2 536.3 3467 A11-01 5600 3848.7 58.25 9 116 118.3 10462.7 -3732.7 3593.1 550.3 3550.7 A11-01 5700 3901.3 58.25 9 116 131.6 10546.7 -3785.3 3678.1 563.6 3634.7 A11-01 5800 3954.3 57.75 8 116 144.1 10630.6 -3838.3 3762.9 576.1 3718.6 A11-01 5900 4007.7 57.75 8 116 155.9 10714.3 -3891.7 3847.5 587.9 3802.3 A11-01 6000 4061.1 57.75 10 116 169.1 10797.9 -3945.1 3932.1 601.1 3885.9 A11-01 6100 4115 57 11 116 184.5 10880.7 -3999 4016.3 616.5 3968.7 A11-01 6200 4168.9 57.75 11 116 200.5 10963.3 -4052.9 4100.4 632.5 4051.3 A11-01 6300 4222.4 57.5 10 116 215.9 11046.4 -4106.4 4184.8 647.9 4134.4 A11-01 6400 4276.5 57 8 116 229.1 11129.4 -4160.5 4268.9 661.1 4217.4 A11-01 6500 4330.1 58.25 9 116 241.6 11213 -4214.1 4353.4 673.6 4301 A11-01 6600 4384.2 56.25 10 116 255.4 11295.9 -4268.2 4437.5 687.4 4383.9 A11-01 6700 4439.4 56.75 10 116 269.9 11378 -4323.4 4520.9 701.9 4466 A11-01 6800 4492.5 59 9 116 283.9 11461.6 -4376.5 4605.5 715.9 4549.6 jf►11-01 6900 4543.1 it 60.25 j 10 116 298.1 11546.6 -4427.1 691.8 730.1 46344 A11-01 7000 4593.3 59.5 9 116 312.4 11631.9 -4477.3 4778.3 744.4 4719.9 A11-01 7100 4643.9 59.75 8 116 325.2 11717.3 -4527.9 4864.6 757.2 4805.3 A11-01 7200 4695 58.75 10 116 338.6 11802.1 -4579 4950.5 770.6 4890.1 A11-01 7300 4746.9 58.75 10 116 353.4 11886.3 -4630.9 5036 785.4 4974.3 A11-01 7400 4798.9 58.5 9 116 367.5 11970.5 -4682.9 5121.3 799.5 5058.5 A11-01 7500 4851.4 58.25 10 116 381.6 12054.5 -4735.4 5206.5 813.6 5142.5 A11-01 7600 4903.8 58.5 11 116 397.1 12138.2 -4787.8 5291.6 829.1 5226.2 A11-01 7700 4955.9 58.75 12 116 414.1 12221.9 -4839.9 5376.9 846.1 5309.9 MGS A11-01:Coil Tubing Cleanout and Acidizing Procedure FINAL 14 A11-01 7800 5007.4 59.25 11 116 431.2 12305.9 -4891.4 5462.5 863.2 5393.9 A11-01 7900 5058.3 59.5 12 116 448.4 12390.2 -4942.3 5548.5 880.4 5478.2 A11-01 8000 5108.9 59.75 11 116 465.6 12474.8 -4992.9 5634.7 897.6 5562.8 A11-01 8100 5159.5 59.5 11 116 482 12559.5 -5043.5 5720.9 914 5647.5 A11-01 8200 5211.3 58 11 116 498.3 12643.4 -5095.3 5806.4 930.3 5731.4 A11-01 8300 5264.7 57.5 10 116 513.8 12726.5 -5148.7 5890.9 945.8 5814.5 A11-01 8400 5319 56.75 12 116 529.8 12809 -5203 5974.9 961.8 5897 A11-01 8500 5374.5 55.75 14 116 548.5 12890 -5258.5 6057.8 980.5 5978 A11-01 8600 5430.5 56.25 13 116 567.8 12970.6 -5314.5 6140.5 999.8 6058.6 A11-01 8700 5486 56.25 14 116 587.2 13051.4 -5370 6223.5 1019.2 6139.4 A11-01 8800 5542.5 55 14 116 607.2 13131.5 -5426.5 6305.7 1039.2 6219.5 A11-01 8900 5600.4 54.25 15 116 627.6 13210.5 -5484.4 6387 1059.6 6298.5 A11-01 9000 5659.7 53 15 116 648.4 13288.2 -5543.7 6467.1 1080.4 6376.2 A11-01 9100 5720.5 52 13 116 667.6 13365.2 -5604.5 6546.2 1099.6 6453.2 A11-01 9200 5783 50.75 14 116 685.9 13441.2 -5667 6624.2 1117.9 6529.2 A11-01 9300 5847.2 49.25 14 116 704.4 13515.5 -5731.2 6700.6 1136.4 6603.5 A11-01 9400 5913.7 47.5 16 116 723.7 13587.7 -5797.7 6775 1155.7 6675.7 A11-01 9500 5982.2 46 15 116 743.2 13657.9 -5866.2 6847.5 1175.2 6745.9 A11-01 9600 6052.3 45 15 116 761.7 13726.8 -5936.3 6918.5 1193.7 6814.8 A11-01 9700 6123.5 44.25 16 116 780.4 13794.4 -6007.5 6988.4 1212.4 6882.4 A11-01 9800 6195.5 43.5 17 116 800.1 13860.9 -6079.5 7057.3 1232.1 6948.9 A11-01 9900 6269.7 40.75 17 116 819.7 13925 -6153.7 7123.9 1251.7 7013 A11-01 10000 6345.7 40.25 18 116 839.2 13987 -6229.7 7188.3 1271.2 7075 A11-01 10100 6422.5 39.5 20 116 860.1 14047.6 -6306.5 7251.6 1292.1 7135.6 A11-01 10200 6500.3 38.25 20 116 881.6 14106.6 -6384.3 7313.5 1313.6 7194.6 A11-01 10300 6579.7 36.75 19 116 901.9 14163.9 -6463.7 7373.6 1333.9 7251.9 A11-01 10400 6660.2 36 20 116 921.7 14219.8 -6544.2 7432.2 1353.7 7307.8 A11-01 10500 6741.9 34.5 21 116 941.9 14273.9 -6625.9 7489 1373.9 7361.9 A11-01 10630 6850.4 32.25 18 116 965.8 14341.3 -6734.4 7559.6 1397.8 7429.3 A11-01 10670 6884.3 32 21 116 972.9 14361.3 -6768.3 7580.6 1404.9 7449.3 A11-01 10764 6964.4 31 21 116 990.5 14407.2 -6848.4 7629 1422.5 7495.2 A11-01 10911 7089.1 33 25 116 1021 14478.8 -6973.1 7705.1 1453 7566.8 A11-01 10966 7135 33.75 24 116 1033.5 14506.3 -7019 7734.5 1465.5 7594.3 A11-01 11068 7221.5 30.25 25 116 1055.9 14555.5 -7105.5 7787 1487.9 7643.5 A11-01 11254 7379.9 33 28 116 1099.5 14642.7 -7263.9 7881 1531.5 7730.7 A11-01 11274 7396.6 33.25 27 116 1104.6 14652.4 -7280.6 7891.5 1536.6 7740.4 A11-01 11350 7460.6 32.25 26 116 1122.9 14689.2 -7344.6 7931.1 1554.9 7777.2 A11-01 11382 7487.7 32 26 116 1130.4 14704.5 -7371.7 7947.6 1562.4 7792.5 A11-01 11406 7508 32 25 116 1135.9 14716 -7392 7959.9 1567.9 7804 A11-01 11441 7537.7 32.25 25 116 1143.7 14732.9 -7421.7 7978 1575.7 7820.9 A11-01 11502 7589.3 32 27 116 1157.9 14762 -7473.3 8009.4 1589.9 7850 MGSA11-01:Coil Tubing C7ennout and Arid/zing Procedure FINAL t A11-01 11540 7621.7 31 25 116 1166.6 14779.9 -7505.7 8028.6 1598.6 7867.9 A11-01 11585 7660.3 31 24 116 1176.3 14800.9 -7544.3 8051.2 1608.3 7888.9 A11-01 11700 7759.4 30 27 116 1201.4 14853.6 -7643.4 8107.8 1633.4 7941.6 A11-01 11850 7890.6 28 29 116 1235.5 14917.8 -7774.6 8177.6 1667.5 8005.8 A11-01 11978 8003.6 28 29 116 1264.6 14970.4 -7887.6 8235.1 1696.6 8058.4 A11-01 12068 8083.4 27 31 116 1285.4 15006.4 -7967.4 8274.6 1717.4 8094.4 A11-01 12164 8169.2 26.5 34 116 1308.6 15042.8 -8053.2 8315 1740.6 8130.8 A11-01 12298 8289.1 26.5 36 116 1342.8 15091.8 -8173.1 8370.1 1774.8 8179.8 A11-01 12492 8462.3 27 41 116 1397.2 15160.1 -8346.3 8448.5 1829.2 8248.1 A11-01 12566 8528.6 26 44 116 1419.5 15184.4 -8412.6 8477.1 1851.5 8272.4 A11-01 12686 8637 24.75 47 116 1456.1 15220.5 -8521 8520.3 1888.1 8308.5 A11-01 12805 8745.5 23.75 50 116 1492.7 15252.9 -8629.5 8560 1924.7 8340.9 A11-01 12900 8832.7 23 51 116 1521.8 15276.8 -8716.7 8590 1953.8 8364.8 A11-01 13000 8925.3 21.5 54 116 1551.8 15299.9 -8809.3 8619.3 1983.8 8387.9 A11-01 13089 9008.3 20.5 52 116 1577.3 15319.1 -8892.3 8643.8 2009.3 8407.1 A11-01 13208 9119.7 20.75 57 116 1611.4 15343.4 -9003.7 8675.5 2043.4 8431.4 A11-01 13238 9147.8 20.75 57 116 1620.3 15349.2 -9031.8 8683.2 2052.3 8437.2 MGS A11-01:Coil Tubing Cleanout and Acidizing Procedure FINAL 16 Schlumherger Coil Tubing Conveyed Perforating Clien: Weil Fielc Date Gun XTO 'cc+ 1-1e: 1'-1.+a"-14 '.56in 6SPF 1636PJ EOP�P Coil Connector I Uncorrected Flag Depth Check Valve I J CD Tool Reference to EOP(-) Correlation Depth Shift(+) Disconnect 11 1'MT Corrected EOP at Flag= 0 8GF Ring Heac oo-l.eg" V2'Bal Corrected EOP at Flag its s...-- EO-to Too hot; + . 3 77 -1--i f Top Shot Top Shot at Flag= 3.77_- _ 20ft'.515in Gun' + 41 33 - 22 00=1.55'• I. _a r 20ft 1.56in G,.r oo=t.E5' Bottom Shot Bottom Nose aiaa 0 70 OD=1.55' TOF BO"-Of. INTERVAL SRIF 00 HARGE RJN# 20's GUN SERIAL NJMBERS 20's 0 1 0 2 0 3 0 4 •56'HGD 3.--PJ' '35-3.5 gm Exoosive Load-0.17'Ent Hole-11 3'Per'.-2-7:13'Casing-1.75'Max Swe4 Prepared By: Revewed By Client Representative: WCP:TCP:SDP-05a Soo:Shier Revision:AKA1 5 05-May-O5 MGS A11-01:Coil Tubing Cleanout and Acidizing Procedure_FINAL . OFFSHORE Well Head Rig Up vpku BAKER #00Q, " � N HUGHES Qy I ii- 96"Gooseneck eihvi ailik 0 1` `-_1,---JA r �!MI1 C ;11r;' 1, i S&S 800L Injector Head K Hydraulic Stripper 4 1/6"10K 4 A- Crossover4 1/16"10K x 5 1/16"10K 5 1/16"10K Lubricator -10 ft 4 4 5 1/16" 10K Flow Cross-2 ft 4 Crossover 5 1/16" 10K x 4 1/16" 10K i.. .( 4 1/16"15K Combi BOPS Blind/Shear Ram (I. ■) 1 Pipe/Slip Ram IC ''4 '" 4 4 1/16" 10K Flow Cross III r4---4 1/16" 15K Blind/Shear Ram May 8, 2002 XTO Energy Inc. 3000 North Garfield Suite 175 Midland, Texas 79705 915-682-8873 915-687-0862 (Fax) Alaska Oil and Gas Conservation Commission Attn: Cammy Taylor 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Subject: Submission of Form 10407 for the A11-01 U&L Recompletion in the Middle Ground Shoal Field, Platform A. Dear Ms. Taylor,. Please find attached a secondary Recompletion Report Form 10407, the Daily Workover Report, and current wellbore schematic for the A11-01 U&L well. This well had been approved for the commingling of the "BCD" and "EFG" pools on September 6, 2001, with the tubular well work completed in December 2001. The Coil Tbg stimulation had been postponed due to the cold weather conditions until April 2002. XTO performed the 800 bbl acid treatment the 1st week of April. The appropriate paper work is attached in duplicate. Please call me if you have any questions at (915) 620-6743. Sincerely, Paul L. Figel Sr. Production Engineer Cc: Doug Schultze Doug Marshall Tim Smith List of Attachments: 1. Recompletion Form 10-407 2. Current Wellbore Diagram 3. Daily Workover Reports · o · ~--'~ STATE OF ALASKA ~'~ ALAbr',A OIL AND GAS CONSERVATION COM,,,,SSION WELL' COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL '[~ GAS ~ ' SUSPENDED O ABANDONED r'-] SERVICE 2. Name of Operator 7. Permit Number XTO Energy Inc. 66-29 3. Address 8. APl Number 3000 N. C~rfield, Ste 175, Mi~lar~Q, TX 79705 · 50- ?33-10078-00 4. Location of weld at surface 9. Unit or Lease Name Platfom A, Leg 1,Cond 7,1627'N & 435'W fr/SE Oor, Sec.ll,T8N, R13W, S.M. Micklle 6~mzr~ S~oal At Top Producing ~nterval 10. Well Number 6806.82'N & 1106.50'E fron surface ~ DATE ~ All-01 LF~L At Total depth .. · I 11. Field and Pool 8432.09'N a 1966.15'E from surface 5. Elevation in feet (indicate KB, DF, etc.) :1 6. Lease Designation and Serial N,). ~ Z4:3~/":B(:~" & "I~'~" ~F ~ 116'I State A~ 18754 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband115. Water Depth, if offshore 116. No. of Completions 6/28/66 9/6/66 ' 12/02/01I 75' feet MSLI 1 17. Total Depth (MD+ TVD) ,8. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set I 21. Thickness of Permafrost 13238' + 9187' 13152'+ 9050' YES [] NOI--iI 324' feetMD I 22. Type Electric or Other Logs Run 23. cASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE. TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 61 J55 0 2625' 18-1/2" 3400 S~ 9-5/8" 47 & 40 NS0 0 10647' 12-1/4" 1250 7" 29 NS0 10505' ' 13238' 8-1/2" 500. S~ · :, . 24. Pedorations open to Production (MD + TvD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD} PACKER SET (MD} 2-7/8" 9531' 9499' C~L,~le Zones: 9562'-10047' ([vJD) 6056-6418' (TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5 ]:~nte_~ca~s: (294' & 1176 ];~rEs). DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10893-133.30' (MD) 7114-9086' (TVD) 9562-33130' 800 ]313.1. ~ ~,clcl 14 ]:nterva~s: (938' & 3752 ~s) 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) ~1./T/t'19J Date-df Test Hours Tested PRODUCTION FOR I'OIL'BBL GAS-MCF WATER-BBL CHOKE sIZE GAS-OIL RATIO 4/;Z7/02 ;I,2, TEST PERIOD ~-8 55.5 46 3.28/64 1982 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 90 725 ][:)Sig 24-HOUR RATE 56 111 92 35 dec~. 28. . CORE DATA Brief description of lithology, porosity, fractures,; apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - 49 - 29. 30. GEOLOGIC MARKEF .... ' FOr~MATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and NAME MEAS. DEPTH TRUE VERT. DEPTH time of each phase. ~l~.:~l~c ~r~ ~ Fon~ation Tests ~o~ti~, 1966. 31. LIST OF A~ACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection: water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Form 10-407 - 50 - MIDDLE GROUND SHOAL A, WELL %ll-01U&L AFE %: 200109 FIRST REPORT: 4/2/2002 Objective: Coil Tubing Cleanout and Stimulate Perforations 04/01/02 Unloaded 2 boats & std rigging up coil tubing unit. DWC: $15,450 CWC: $15,450 AFE #: 200109 FIRST REPORT: 412/2002 Objective: Coil Tubing Cleanout and Stimulate Perforations 04/02/02 Unloaded boat & cont'd rigging up coil tubing unit. DWC: $15,520 CWC: $30,970 AFE %: 200109 FIRST REPORT: 4/2/2002 Objective: Coil Tubing Cleanout and Stimulate Perforations 04/03/02 Cont'd rigging up coil tubing unit. Press tstd all lines to 5,000%. Flushed coil tubing w/40 bbls of FIW. Pickled coil tubing w/13 bbls of 15% HCL acid followed by 40 bbls of FIW. Installed Dowell jet blaster tool. Press tstd lubricator to 5,000%. 01:30 to 6:00: RIH w/coil tubing ~ 60' p/m while ppg FIW ~ 1.5 BPM. Slowed down to 5' p/m ~-each gas-lift mandrell. Stopped @ 9,398' & washed down to EOT @ 9,531'. DWC: $17,900 CWC: $48,870 AFE #: 200109 FIRST REPORT: 4/2/2002 Objective: Coil Tubing Cleanout and Stimulate Perforations 04/04/02 06:00 Mixing foamer, KCL and cooling down N2 unit. 07:00: RIH from 9,500' to 13,050' with Dowell jet blaster. Pmpd 3% slick KCL FIW and N2 while taking returns to tank. Liquid rate 1.0 BPM, N2 rate 340 scf/m, WHP 69 psig, CT 2,770 psig. 08:45: RIH from 13,050' to 13,125' Pmpd 30 bbls of Flo Vis for gel sweep to circulate bottoms up. Liquid rate 1.0 BPM, N2 rate 340 scf/m, WHP 103 psig, CT 3,700 ps~g. 09:45: Pmpd 50 bbls of Flo Vis for gel sweep followed by 150 bbls of 3% slick FIW. Liquid rate 1.0 BPM, N2 rate 340 scf/m, WHP 80 psig, CT 3,580 psig. 13:00: Shut down N2 unit and pmpd 100 bbls of 3% slick FIW. Liquid rate 1.5 BPM, WHP 66 psig, CT 3,800 psig. 14:30: Started pmpg 87 bbls of DAD acid, followed by 41 bbls of 3% slick FIW, followed by 44 bbls of DAD acid while P0H to 9,400' Liquid rate 1.0 BPM, WHP 140 psig, CT 3,780 psig. 18:05: Let DAD acid soak for 30 minutes. 18:35: RIH with coil tubing aG 30' p/m while circulating 3% slick FIW. Tagged fill at 13,125'. POOH to 13,100'. Liquid rate 1.4 BPM, WHP 35 psig, CT 4,000 psig. 21:30: Pmpd 20 bbls of Flo Vis for gel sweep followed by 250 bbls of 3% slick FIW. Liquid rate 1.45 BPM, WHP 15 psig, CT 4,000 psig. 00:45: Started pmpg 190 bbls of DAD acid. 01:15: Began acid wash POOH from 13,100' to 9,400' while POOH at 10' p/m for perforations and 60' p/m over blank pipe. Liquid rate 1.0 BPM, WHP 21 psig, CT 4,300 psig. 05:30: Let DAD acid soak for 30 minutes. DWC: $124,000 CWC: $172,870 MIDDLE GROUND SHOAL A, WELL #ll-01U&L AFE #: 200109 FIRST REPORT: 4/2/2002 Objective: Coil Tubing Cleanout and Stimulate Perforations 04/05/02 06:00: RIH with coil tubing to 13,100' 07:00: Std pumping Flo-Vis gel sweep followed by 250 bbls of 3% slick KC1 FIW while POOH with coil tubing fr 13,100' to 9,350". Liquid rate 1.3 BPM, WHP 20 psig, CT 4,150 psig. 09:00: Reduced pump rate at 9,350' to .5 BPM and continued POOH with coil tubing. Liquid rate .5 BPM, WHP 20 psig, CT 1,010 psig. 11:15: Coil tubing out of hole. Changed out scale blaster and pressure tstd lubricator to 5000#. 13:00: Had power pack problems with coil tubing. 15:30: RIH with coil tubing jet blaster at 60' p/m while pumping 3% slick KC1 FIW at 1./2 BPM to 9,350' Liquid rate 1/2 BPM, WHP 18 psig, CT 920 psig. 17:45: At 9,350' increased pump rate to 1.1 BPM and continued RIH with coil tubing. Liquid rate 1.1 BPM, WHP 36 psig, CT 4,040 psig. 18:35: Tagged fill with coil tubing at 13,120'. Did not have any more fill. Finished mixing 10% DAD acid. 19:40: Started injecting 475 bbls of 10% DAD acid while POOH at 4' p/m. Shut in CT annulus and begin acid squeeze. Liquid rate 1.0 BPM, WHP 29 psig, CT 3,650 psig. 24:00: Continued' to POOH with coil tubing at 4' p/m. Liquid rate 1.0 BPM, WHP 1,2.00 psig. 02:35: Continued to POOH with coil tubing at 4' p/m. Redused pump rate due to higher coil tubing pressure. Liquid rate 3/4 BPM, WHP 1,225 psig, CT 4,000 psig. 05:15: Finished squeezing all of 10% DAD acid. Started overflush of 3% KC1 FIW and N2. Liquid rate .8 BPM, N2 rate 340 scf/m. WHP 1,400 psig, CT 3,900 psig. DWC: $134,000 CWC: $316,870 AFE %: 200109 FIRST REPORT: 4/2/2002 Objective: Coil Tubing Cleanout and Stimulate Perforations 04/06/02 06:00: Continued with overflush of 3% KC1 FIW and N2. Made two passes with coil from 9,540' to 13,120' Liquid rate .8 BPM, N2 rate 340 scf/m, WHP 1,413 psig, CT 3,600 psig. 13:30: Finished pumping 3% KC1 FIW and N2. Liquid rate .8 BPM, N2 rate 340 scf/m, WHP 3,010 psig, CT 4,300 psig. POOH with coil tubing while pumping N2 with no FIW. N2 rate 340 scf/m. Opened up coil tubing annulus while POOH. 15:45: Out of hole with coil tubing and started rigging down. 20:30: Rigged up lines to production tank and pressure tstd all lines. 21:30: Started blowing down N2 to production tank with vent line open. DWC: $29,000 CWC: $345,870 AFE ~: 200109 FIRST REPORT: 4/2/2002 Objective: Coil Tubing Cleanout and Stimulate Perforations 04/07/02 06:00: Continued rigging down coil tubing and began cleaning decks on platform. 07:00: Bled of all N2 off of well. Put well on production. 11:15: Shut in well to fix leak on production testing tank. Tbg 300 psig, Csg 870 ps. ig. 12:30: Put well back on production. Tbg 780 psig, Csg 850 psig. 06:00: Well has made approximately 250 bbls of liquid in 20 hours of flow. Tbg 240 psig, Csg 800 psig. DWC: $5,000 CWC: $350,870 MIDDLE GROUND SHOAL A, WELL #ll-01U&L AFE #: 200109 FIRST REPORT: 4/2/2002 Objective: Coil Tubing Cleanout and Stimulate Perforations 04/08/02 16:00: Returned well to production. Rigged down all equipment and cleaned up. Tbg 80 psig, Csg 670 psig. Well was producing 7 to 9 bbts per hour. DWC: $13,000 CWC: $363,870 AFE #: 200109 FIRST REPORT: 4/2/2002 Objective: Coil Tbg Cleanout & Stimulate Perfs 04/09/02 Well in test unloading 100% FIW ~ 7 BPH. Csg Press @ 670 psi lifting at orifice. AFE #: 200109 Objective: Coil tbg Cleanout & Stimulate Perfs 04/10/02 Well in test producing 19 BOPD & 139 BWPD. FIRST REPORT: 4/2/2002 AFE ~: 200109 Objective: Prod Test 04/11/02 Well in test producing 29 BOPD & 118 BWPD. load. FIRST REPORT: 4/2/2002 Still recovering acid AFR #: 200109 FIRST REPORT: 4/2/2002 Objective: Prod Test 04/12/02 Well in test producing 35 BOPD & 103 BWPD. Still recovering acid load. AFE #: 200109 0bjective: Prod Test 04/13/02 Well in tets producing 48 BOPD & 90 BWPD. FIRST REPORT: 4/2/2002 Still recovering acid load. AFE #: 200109 Objective: Prod Test 04/14/02 Well in test producing 52 BOPD & 84 BOPD. FIRST REPORT: 4/2/2002 Still recovering acid load. AFE #: 200109 Objective: Prod Test 04/15/02 Well in test producing 56 BOPD & 84 BWPD. FIRST REPORT: 4/2/2002 Still recovering acid load. AFE #: 200109 Objective: Prod Test 04/16/02 Well in test producing 52 BOPD & 86 BWPD. FIRST REPORT: 4/2/2002 Still recovering acid load. AFE #: 200109 0bjective: Prod Test 04/18/02 Well in test producing 84 BOPD & 56 BWPD. FIRST REPORT: 4/2/2002 AFE #: 200109 FIRST REPORT: 4/2/2002 Objective: Prod Test 04/27/02 Well producing ~ 56 BOPD, 92 BWPD & 111 mscf/d. Csg press ~ 725 psi & injecting 941 mscf/d. Final Report MGS A11-01 Cook Inlet, Alaska Leg 1, Conductor 7 Spud: 6-28-66 Surf Csg: 13 3/8", 61 lb, J55. Set @ 2,625'. Cmt'd w/3,400 sx. Intermediate Csg: 9 5/8", N80. Set @ 10,647'. Cmt'd w/1,250 sx. 0 - 62' :47# 62 - 7,269' :40# 7,269 - 9,485' :43.5# 9,485 - 10,647' :47# Current Completion PLF 5-8-02 Tbg: 2 7/8" 6.5# N80 EUE 8R @ 9,531' Set on 12-2-01 Item MD TVD Psc Pso Port GLM #1 1953' 1804' 909 950 10 GLM #2 4398' 3213' 891 915 10 GLM #3 5875' 4006' 869 901 12 GLM #4 7188' 4704' 847 871 12 GLM #5 8144' 5200' 826 845 12 GLM #6 8874' 5611' 804 821 12 GLM #7 9409' 5949' Orifice 16 Baker T5 SSSV @ 324' X Nipple 9Cr @ 9,453' (2.313" ID) 33' Jt of 2 7/8" 6.5# N80 6' Pup Jt 2 7/8" 6.5# N80 X-Over 2 7/8" EUE x 4 1/2" Butt @ 9,493' X-Over 4 1/2" Butt x NSCT Pup Jt 9 5/8" Baker S-3 Perm Packer 194-47 @ 9,499' X-Over 4 1/2" Butt x NSCT Pup Jt X-Over 4 1/2" Butt Box x 2 7/8" 8R Pin @ 9,508' 10' Pup Jt 2 7/8" 6.5# N80 8R XN Nipple 9Cr (2.205" ID) @ 9,519' 10' Pup Jt 2 7/8" 6.5# N80 8R Baker WL Re-entry Guide @ 9,531' FL-FP: 9562'-9637' FL-FP: 9670'-9760' FP-FS: 9807'-9833' FS-FW: 9930'-9955' FS-FW: 9972'-10047' Prod Liner: 7", 29 lb, N80. Set @ 10,505 -13,238'. Cmt w/500 sx. G N-GO: 10893'-10910' GO-G R: 11372'-11419' G R-GS: 11688'-11700' G R-GS: 11706'-11716' HC-H D: 12053'-12138' H E-H F: 12158'-12181' HI-HN: 12195'-12512' HN-HR: 12538'-12586' HN-HR: 12616'-12854' HR-HZ: 12905'-12970' H R-HZ: 12990'- 13005' HR-HZ: 13063'- 13081' H R-HZ: 13094'-13110' HR-HZ: 13116'-13130' PBTD: 13,152' MD (9,050' TVD) TD: 13,238' MD (9,187' TVD) December 21, 2001 TO ~ERGY XTO Energy Inc. 3000 North Garfield Suite 175 Midland, Texas 79705 915-682-8873 915-687-0862 (Fax) Alaska Oil and Gas Conservation Commission Attn: Cammy Taylor 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Subject: Submission of Form 10407 for the A11-01 U&L Recompletion in the Middle Ground Shoal Field, Platform A. Dear Ms. Taylor, Please find attached the Recompletion Report Form 10-407, the Daily Workover Report, and current wellbore schematic for the A11-01 U&L well. This well had been approved for the commingling of the "BCD" and "EFG" pools on September 6, 2001. The original procedure had included performing a coil tubing acid stimulation after the new completion string had been set. Unfortunately, due to the extreme cold weather in Cook Inlet, the stimulation treatment is being postponed to the spring of 2002 when warmer temperatures will allow us to safely perform this 5 day operation. Therefore, at this time, I am submitting the Form 10407, which details the current recompletion and will resubmit another Form 10407 after the coil tubing acid treatment has been performed in 2002. Please call me if you have any questions at (915) 620-6743. Sincerely, Paul L. Figel Sr. Production Engineer Cc: Doug Schultze Doug Marshall Tim Smith List of Attachments: 1. Recompletion Form 10407 2. Current Wellbore Diagram 3. Daily Workover Reports ORIGINAL RBD $ BFL RECEIVED DEC 2-7 ZOO1 Alad,,a Oil & Gas Cons. Commi~ion AnchoraDe DEC 3 0 2001 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well 2. Name of Operator 7. Permit Number z'z'o zne.:gr n-~c. 6{;-39 3. Address 8. APl Number 3000 N. Garfield, Ste 175, Midland, TX 79705 so- 733-10078-00 4. Location of well at surface 9. Unit or Lease Name Platfoz:m A, Leg 1,Clond 7,1627'N & 435'W fr/SE O:=,Sec.ll,TSN, R13W, S.M. Midc]le Gzolaxl Shoal At Top Producing Interval] ~ '10. Well Number 6806.82'N & 1106.50'E fron surface At Total depthI _~., 11. Field and Pool 8432.09'N & 1966.15'E frcm surface 5. Elevation in feet (indicate KB, DF, etc.)z]F @ 116' I6' Lease Designati°n and serial~ iState A~][, 18754, 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or AbandJ 15. Water Depth, if offshore I 16. No. of Completions 6/28/66 9/6/66 12/02/01I 75' feet MSLI 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set I 21. Thickness of Permafrost I I 13238' + 9187' 13152'+ 9050' YES [~] NO[--] 324' feetUD 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8- {;1 0~i5 0 26;35' 11~-1/2- 3400 mc 9-5/8" 47 & 40 iNS0 0 10647' 12-1/4" 1250, 7" 29 NS0 10505' 13238' 8-1/2" 500, 24. Pedorations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) interval, size and number) ""'-7'°'' 9~31' 9499' C~m~tlgle Zeros: 9562' -10047' (MD) 6056-6418' (TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5 Zntervals: (294' & 1176 [oerfs). DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10893-13130' (MD) 7114-9086' (Tv'D) 14 3:n~s-. (938' & 3752 [3errs) 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) !~_/o2/n'~I , ~'-~ ?,~ft Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 12/09/01 12 TEST PERIOD 11.5 43.5 38.5 128/64 3783 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 100 570 [~Si 24-HOUR RATE 23 87 77 35 dec$. 28. CORE DAIA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED DEC g 7 2001 Alallka Oil & Gas Coos. Commission Aachorage Form 10-407 Submit in duplicate Rev. 7-1-80 ORIGINAL 29. 30. GEOLOGIC MARKERS ~-~JRMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and NAME MEAS. DEPTH TRUE VERT. DEPTH time of each phase. ~eologic ~ and ~)zmatica~ ~ests ~uxz~i~ ~ ~g~ ~leti~ ~~ti~, 1966. ,,~ 3~. LIST OF A~AOH~ENTS ~ly ~~ ~s ~ ~~ ~tic 32. ) hereby ce~ify that the fore~oin9 is~ and correct to the best of my knowledge F~A ~ Title ~-~i=~ Date 12/20/01 Signed INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval repoded 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Form 10-407 MGS A11-01U & L Cook Inlet, Alaska Leg 1, Conductor 7 Surf Csg: 13 3/8", 61 lb, J55. Set @ 2,625'. Cmt'd w/3,400 sx. Intermediate Csg: 9 5/8", N80. Set @ 10,647'. Cmt'd w/1,250 sx. 0 - 62' :47# 62 - 7,269' :40# 7,269 - 9,485' :43.5# 9,485 - 10,647' :47# Current Completion PLF 12-20-01 Tbg: 2 7/8" 6.5# N80 EUE 8R @ 9,531' Set on 12-2-01 Item MD TVD Psc Pso Port GLM #1 1953' 1804' 909 950 10 GLM #2 4398' 3213' 891 915 10 GLM #3 5875' 4006' 869 901 12 GLM #4 7188' 4704' 847 871 12 GLM #5 8144' 5200' 826 845 12 GLM #6 8874' 5611' 804 821 12 GLM #7 9409' 5949' Orifice 16 Baker T5 SSSV @ 324' X Nipple 9Cr @ 9,453' (2.313" ID) 33' Jt of 2 7/8" 6.5# N80 6' Pup Jt 2 7/8" 6.5# N80 X-Over 2 7/8" EUE x 4 1/2" Butt @ 9,493' X-Over 4 1/2" Butt x NSCT Pup Jt 9 5/8" Baker S-3 Perm Packer 194-47 @ 9,499' X-Over 4 1/2" Butt x NSCT Pup Jt X-Over 4 1/2" Butt Box x 2 7/8" 8R Pin @ 9,508' 10' Pup Jt 2 7/8" 6.5# N80 8R XN Nipple 9Cr (2.205" ID) @ 9,519' 10' Pup Jt 2 7/8" 6.5# N80 8R Baker WL Re-entry Guide @ 9,531' FL-FP: 9562'-9637' FL-FP: 9670'-9760' FP-FS: 9807'-9833' FS-FW: 9930'-9955' FS-FW: 9972'-10047' Prod Liner: 7", 29 lb, N80. Set @ 10,505 -13,238'. Cmt w/500 sx. PBTD: 13,152' MD (9,050' TVD) TD: 13,238' MD (9,187' TVD) G N-GO: 10893'- 10910' GO-GR: 11372'-11419' G R-GS: 11688'-11700' G R-GS: 11706'-11716' HC-H D: 12053'-12138' H E-H F: 12158'-12181' HI-HN: 12195'-12512' H N-H R: 12538'-12586' H N-HR: 12616'-12854' H R-HZ: 12905'-12970' H R-HZ: 12990'-13005' H R-HZ: 13063'-13081' H R-HZ: 13094'-13110' H R-HZ: 13116'-13130' Top of sand @ 13,073' w/ BH Bomb w/slickline. MIDDLE GROUND SHOAL A, WELL #11-01U&L AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 10/19/01 RU WL on Long String (All-01 Lower). Press tstd lubricator. RIH w/ 2.30" tapered gauge ring. Stopped ~ 9,000' (MD). Found FL @ 7,900' (MD). POH. RIH & attempted to pull #6 GLV @ 7,935' (MD). Tried to retrieve GLV for 30", unsuccessful. Tried for 30" Pulled up to GLV %5. P0H w/GLV #5 @ 7,163' (MD). RD off Long String & RU on Short String (All-01 Upper). Press tstd lubricator. RIH w/2.30" tapered gauge ring. Stopped @ 1,590' (MD). POH. Tool string was full of paraffin. RIH w/1.90" tapered gauge ring. Stopped at 1,631' (MD). POH. Tool string was full of paraffin. RD WL. DWC: $66,908 CWC: $66,908 AFE #: 101039 Objective: Pull Dual Completion & Run New Single String 10/23/01 FIRST REPORT: 10/19/2001 RU & attempted to pull SS. Pulled 80% of tensile rating, no success. Attemtped to pull LS. Pulled 80% of tensile rating, no success. Attempted to pull both strings, no success. RU APRS WL. RIH dwn LS w/2-1/4" jet cutter. Set dwn @ 7,612' Worked tools to 7,630' Stuck tools. Cut LS ~ 7,630' (shot fired). POH & RD APRS WL. RU & attempted to pull LS. Pulled 90% tensile rating, ptd tbg (high). LD 11 its of tbg & stub (335.76") w/hanger break. Ptd pipe was a clean lateral break w/inside deterioration. RU APRS WL on SS. RIH w/2-1/4" jet cutter. Set dwn @ 4,870' PU & located cutter. Fired cutter & cut in mud jt ~ 4,858' POH & RD APRS WL. RU & pulled SS. Rec hanger, XO, 2 pup its, SSSV, 2 GLM's, x-nipple, 153 its of 2-7/8" tbg & cut off jr. Repl top driver saver-sub. DWC: $28,622 CWC: $95,530 AFE #: 101039 Objective: Pull Dual Completion & Run New Single String 10/24/01 FIRST REPORT: 10/19/2001 Repl top drive saver-sub. MU fishing assbly to catch LS ~ 390' TIH. Latched onto LS. Worked & pulled on LS, no success. RU APRS WL. RIH & attempted cut ~ 7,630' No cut. RIH to 8,975' POH & PU 2-1/8" cutter. RIH. Unable to get past 8,350' PU to 8,333' Cut LS, POH & RD WL. POH & LD 2-7/8" tbg fr/LS. Rec 267 its, 1 cut off, 1 SSSV, x-nipple & 6 GLM's w/pups. PU & MU fishing assbly to catch top of SS @ 4,858' WLM @ report time today. DWC: $28,326 CWC: $123,856 AFE #: 101039 Objective: Pull Dual Completion & Run New Single String 10/25/01 FIRST REPORT: 10/19/2001 PU & MU fishing assbly to catch top of SS ~ 4,858' TIH w/fishing assbly. Tagged & caught SS fish @ 4,858'. Worked pipe & jarred one time. Jarred SS free. POH & LD fishing assbly. POH & LD SS 2-7/8" tbg. Rec 146 its of 2-7/8" tbg, 1 XO-Latch & 4 GLM's. Entire short string was rec. Re-dressed OS & MU fishing assbly for LS. TIH w/fishing tools. Worked over & caught LS fish ~ 8,333' Worked pipe & jarred on same, no success. Press up on LS to 1,000 psig. Press bled to 100 psig. RU APRS WL unit on LS. MU 2-1/8" cutter. Prep to cut tbg. DWC: $22,009 CWC: $145,865 MIDDLE GROUND SHOAL A, WELL #11-01U&L AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 10/26/01 Fin RU APRS WL unit on LS. RIH w/2-1/8" cutter. Set dwn ~ 8,660' Worked dwn & chased WL fish to 9,144' PU 7' & cut tbg @ 9,131' WLM. POH & RD APRS WL. P0H w/3-1/2" DP. POH & LD 2-7/8" tbg. Rec 27 its & cut off from LS. Chg'd out pipe rams & press tstd to 3,000 psig, tstd OK. MU fishing assbly, dressed overshot & grapple. TIH w/OS. Slipped & cut drlg line. Worked over & caught fish @ 9,131' DPM. Worked pipe & jarred. Jarred free. Had extra wt. T0H w/fish. Serviced rig & top drive. POH. No rec. OS & grapple full of oily scale. Broke dwn OS & re-dressed w/new grapple. Chg'd out top ext of fishing assbly. TIH w/fishing assbly. TOF ~ 9,131' DWC: $22,009 CWC: $167,874 AFE ~: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 10/27/01 TIH w/fishing assbly. Tagged & caught fish ~ 9,131' Jarred on same, no movement. RU APRS WL unit. RIH w/2-1/8" jet cutter. Set dwn ~ T0F @ 9,131' Unable to enter TOF. P0H w/cutter. RU slickline unit. RIH w/2-1/4" WL grab. Attempted to catch WL fish. Set dwn 8 T0F @ 9,131'. Made 2 trips. POH, no rec. RD slickline unit. Rel fish w/DP fishing asbly. P0H w/tools. PU & MU outside cutting assbly w/wash pipe. TIH w/outside cutting assbly. Attempting to work over fish ~ 9,131' DWC: $30,509 CWC: $198,383 AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 10/28/01 Worked over fish @ 9,131' Cont'd over fish w/wash pipe/outside cutter. Located on 1st collar above GLLM #7. Cut tbg ~ 9,294' TOH. LD outside cutter BHA. Rec 5 its of 2-7/8" tbg & cut off (163') & 170' of WL junk. New T0F @ 9,294'. MU fishing assbly. TIH w/fishing tools. Tagged TOF @ 9,294' Worked over & caught fish. RU slickline unit & RIH w/2-1/4" WL grab tool. Attempted to catch WL fish. Would catch & then jar off. POH w/no rec. RIH & repeated. Fished fr/8,990'-9,304' Unable to go below 9,304'. POH, no rec. RIH w/i-i/2" WL grab, no success. POH. RIH w/2.25" IMP blk. DWC: $22,121 CWC: $220,504 AFE ~: 101039 Objective: Pull Dual Completion & Run New Single String 10/29/01 RIH w/2.25" IMP blk on slickline to 9,304' FIRST REPORT: 10/19/2001 Made impression & POH. IMP blk indicated junk. RD slickline. Performed manual blind back off @ 9,294' POH w/fishing assbly. LD partial fish & OS. Rec 5 its of 2-7/8" tbg w/GLM #7 & x-nipple. Ttl rec 182.09' New TOF @ 9,476' PU rope spear fishing assbly & TIH. Lost wt @ 9,350' Rot spear. TOH, no rec. Chg'd out pipe rams for VBR's. Pulled wear ring. Set tst plug & tstd pipe rams to 250-3,000 psig, tstd OK. Pulled tst plug & set wear ring. MU rope spear assbly #2. TIH & tagged top of tbg fish 8 9,470' Csg tight fr/9,350'-9,397' Rot spear. TOH w/rope spear assbly. DWC: $30,121 CWC: $250,625 MIDDLE GROUND SHOAL A, WELL %ll-01U&L AFE #-. 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 10/30/01 Fin P0H w/rope spear assbly %2. Rec 150' of slickline. RIH w/rope spear assbly %3. Slipped & cut 100' of drlg line. RIH & tagged T0F @ 9,476' Rot spear. POH w/rope spear assbly, no rec. Attempted to tst BOP, unable to get tst plug to seal. Used 2 sets of rubbers. Called AOGCC, rec'd OK to go ahead until new seals could be brought out via chopper. Tstd surf equip to 250-3,000 psig, tstd OK. PU OS grapple fishing assbly. TIH w/OS. Worked over fish @ 9,476' Unable to rot. Appears that there is no pup j t on top of pkr. RU slickline unit. RIH w/2.25" IMP block. POH w/IMP block, no markings, scale on TOF. Set back slickline. RU to rev circ to clean TOF. DWC: $24,624 CWC: $275,249 DMC: $1,150 CMC: $1,150 AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 10/31/01 RU & rev circ two tbg vols. RIH w/2.25" IMP blk on slickline. POH w/IMP blk. Revealed possible WL junk. RIH w/WL grab & fished for WL junk. POH, no rec. POH w/OS/grapple assbly. LD OS. Pulled wear ring & set tst plug. MU tst assbly. Attempted to get tst plug to hold. Worked on rubber seals, etc., finally got tst. Tstd BOP to 250-3,000 psig, tstd OK. Pulled tst plug. RD tst assbly. Inst wear ring. PU & MU pkr milling assbly. TIH to mill pkr @ 9,476'. DWC: $80,426 CWC: $355,675 DMC: $0 CMC: $1,150 AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/01/01 Fin TIH w/milling assbly. Milled dual 9-5/8" pkr fr/9,476'-9,478' w/carbide junk mill. POH & LD carbide junk mill. Cleaned junk baskets (lots of scale & 1 qt pkr junk). RIH w/8-1/2" pkr mill w/metal munchers. Milled dual 9-5/8" pkr fr/9,478'-9,480'. DWC: $22,009 CWC: $377,684 DMC: $0 CMC: $1,150 AFE ~: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/02/01 Milled on pkr. Unable to make anymore hole (appeared to be spinning). Circ hole. POH. Cleaned junk baskets (4 gals of metal & scale). LD mill (mill worn over entire face). PU 1-3/4" x 3-3/4" taper tap. RIH. Worked tap into pkr & worked fish. Able to see some movement & able to turn whatever taper tap was latched into for a while, then taper tap seized up. Attempted to rel taper tap fr/fish (appeared to tel). POH. Left 2 jts 3-1/2" drill pipe & taper tap in hole (TOF 9,410'). Serviced rig. Ran back in hole to screw into taper tap fish. DWC: $22,479 CWC: $400,163 DMC: $0 CMC: $1,150 MIDDLE GROUND SHOAL A, WELL %ll-01U&L AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/03/01 TIH. Screwed into fish ~ 9,410' Worked fish free. TOH. Rec dual pkr (9.78'), 1 full jt of tbg & tbg stub (36.99'). PU 8-3/8" guide, outside cutter, 14 its of 7-5/8" x 6-3/4" WP. TIH. Worked outside cutters & WP over T0F 8 9,893'. Cut 2-7/8" tbg. TOH. Now LD 2-7/8" tbg. DWC: $112,851 CWC: $513,014 DMC: $0 CMC: $1,150 AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/04/01 Fin LD 12 its of 2-7/8" tbg. Rec 200' of WL inside tbg & 800' hanging below cutter. Hole taking fluid again. TIH w/WL spear & BS. Tagged up @ 9,899' Fished for WL. TOH. Rec 100% of WL wrapped around tools. TIH w/4 stds w/WL spear. Fished for WL. TOH. TIH w/20 stds w/WL. Fished for WL. TOH. Rec 10' of WL. TIH w/OS. Tagged fish @ 9,893' Worked over TOF. Jarred on fish. Performed manual backoff. TOH. DWC: $22,929 CWC: $535,943 DMC: $243 CMC: $1,393 AFE ~: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/05/01 Fin TOH. Rec 3 its of 2-7/8" tbg. MU outside tbg cutter & 14 its of WP. TIH. Worked tbg cutter over fish fr/9,982'-10,062'. Unable to rotate, had to shear cutters to get off of fish. TOH. Stood back WP. LD tbg cutter. MU 8-1/2" burning shoe on WP, bumper sub, jars & 9 - DC's. TIH. Washed over fish fr/9,982'-10,343'. Solid fill on pkr @ 10,343'. Ppg sweep to clean hole. DWC: $23,289 CWC: $559,232 DMC: $243 CMC: $1,636 AFE ~: 101039 Objective: Pull Dual Completion & Run New Single String 11/06/01 FIRST REPORT: 10/19/2001 Ppd sweep. Circ btms up. TOH. Stood back DC's. LD jars & bumper sub. Stood back WP. LD burning shoe. MU outside tbg cutter. Ran 14 its WP. PU new bumper sub. TIH. Worked outside tbg cutter over fish fr/9,982'-10,347' Mixed & ppd sweep. Circ btms up. Cut 2- 7/8" tbg ~ 10,318' TOH. LD 2 its of WP. RU tbg tongs. Rec & LD 11 jts & cut off 2-7/8" tbg (332.83'). LD 7-5/8" wash pipe. Prep to run OS & jars to attempt to jar pkr free. DWC: $36,273 CWC: $595,505 DMC: $828 CMC: $2,464 AFE ~: 101039 Objective: Pull Dual Completion & Run New Single String 11/07/01 FIRST REPORT: 10/19/2001 Fin LD 7-5/8" WP. MU 8-1/8" 0S dressed w/2-7/8" grapples, bumper sub, jars, 9 - 6-1/4" DC's. TIH. Slipped & cut drlg line. Latched onto fish w/OS. Worked & jarred on fish, no success. TOH. LD OS. PU metal muncher burning shoe, 3 its of 7-5/8" WP, 3 junk baskets, bumper sub, jars & 9 - 6-1/4" DC's. TIH. Worked over fish @ 10,318' Washed to 10,345.5' Milled on pkr fr/10,345.5'-10,347' DWC: $35,590 CWC: $631,095 DMC: $1,389 CMC: $3,853 MIDDLE GROUND SHOAL A, WELL #ll-01U&L AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/08/01 Milled on pkr fr/10,347'-10,349' Ppd sweep & dry job. TOH. Stood back 3 its WP. LD burning shoe (marks on shoe indicate being over pkr #3). Mill in good condition. Pulled wear bushing. Tstd BOP to 250-5,000 psig, tstd OK. Tom Maunder w/AOGCC waived the witnessing of the tst. MU 8-1/8" OS dressed w/2-7/8" grapples, bumper sub, jars, 9 - 6-1/4" DC's, ACC jars. TIH to attempt to pull pkr. DWC: $31,712 CWC: $662,807 DMC: $715 CMC: $4,568 AFE #: 101039 FIRST REPORT= 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/09/01 TIH w/OS. Worked over 2-7/8" tbg @ 10,318' w/OS. Worked & jarred on fish. Ran 2.19" gauge ring on WL (stopped ~ 10,321'). Ran 1.70" gauge ring on WL (stopped @ 10,322'). POH w/WL & RD WL. Jarred & worked fish. Fish pulled free. Ppd pill. TOH w/15 stds. Well std to flow. Circ gas bubble thru ck. Circ btms up. TIH w/14 stds to 10,181' Circ btms up. Ck'd for flow. Slowly TOH. Rec cut off jt of 2-7/8" tbg above pkr, 9-5/8" pkr & XO below pkr. Ail tbg below btm pkr still in hole. DWC: $31,951 CWC: $694,758 DMC: $954 CMC: $5,522 AFE %: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/10/01 LD pkr (7.11"), cut-off jt of tbg (28.35') . PU 7-5/8" OS dressed w/3- 21/32" grapples. TIH w/OS. Circ btms up. Attempted to work OS onto 2-7/8" tbg collar @ 10,353' Unable to get a good bite on fish. Ppd dry job. TOH w/OS. Chg'd out 7-5/8" OS. PU 8-1/8" OS dressed w/3- 5/8" grapples. PU new ACC jars. TIH. Worked over fish w/OS. Worked fish. OS jarred loose w/30K over pull. Worked over fish w/OS again. Pulled 100K straight pull. Attempted blind back off. TOH. DWC: $39,617 CWC: $734,375 DMC: $120 CMC: $5,642 AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/11/01 Fin TOH. Rec 2.30' of 2-7/8" tbg w/collar looking up. Btm end badly kinked. LD OS. MU 8-1/2" bladed mill & 3 junk baskets. TIH. Slipped & cut drlg line. TIH. Milled top of fish fr/10,355'- 10,360' Ppd sweep. T0H w/mill. LD 8-1/2" mill & junk baskets. PU hollow mill & 8-1/8" OS dressed w/2-7/8" grapples. TIH. Dressed T0F w/hollow mill. Latched onto fish w/OS. RU & ran slick line. DWC: $31,117 CWC: $765,491 DMC: $120 CMC: $5,762 MIDDLE GROUND SHOAL A, WELL #11-01U&L AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/12/01 Ran slick line gauge ring (2.186"). Stopped ~ pmp out sub (2-3/16" ID). Ran gauge ring #2 (1.70"). Unable to enter TOF ~ 10,368' WLM. Worked & jarred on fish. 2-7/8" tbg parted. Ppd dry job. TOH. Rec 12.12' of 2-7/8" tbg. LD OS (TOF milled over, restricting WL tools fr/entering) . Serviced rig & strapped wash pipe. MU outside tbg cutter. PU 15 its of 5-3/4" wash pipe (448.92') & bumper sub. TIH. Washed over 2-7/8" tbg fr/10,372'-10,812' Worked 2-7/8" outside cutter & cut tbg. Circ & ppd sweep. Ppd dry job. TOH. DWC: $31,437 CWC: $796,928 DMC: $440 CMC: $6,202 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/13/01 TOH. LD bumper sub & top jt of WP. LD partial fish & 14 its of 2- 7/8" tbg (437.10'). Stood back WP. LD tbg cutter. PU burning shoe, WP, jars & 9 - 4-3/4" DC's. TIH. Washed over 2-7/8" tbg fr/10,792'- 11,292' Washed over past sliding sleeve & top set of perfs (no fill). Ppd sweeps & dry job. TOH w/WP. LD burning shoe. PU 2-7/8" outside cutter. TIH w/outside tbg cutter. DWC: $34,096 CWC: $831,024 DMC: $2,312 CMC: $8,514 AFE ~: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/14/01 TIH w/2-7/8" outside tbg, cutter & 5-3/4" wash pipe. Worked over fish fr/10,792'-11,292' Cut 2-7/8" tbg ~ 11,275'. Ppd dry job. TOH. LD partial fish & 16 its of 2-7/8" tbg (482.91'). Re-dressed tbg cutter & MU wash pipe. TIH w/tbg cutter & WP. Worked over fish fr/11,275' Attempted to cut 2-7/8" tbg ~ 11,755' Appeared that the cutter knives broke before cut was completed. Circ hole w/high vis sweep. Prepared to chg out drlg line. TOH to inspect tbg cutter. DWC: $32,952 CWC: $863,976 DMC: $270 CMC: $8,784 AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/15/01 Chg'd out drlg line. Ran slickline 1.89" gauge ring to 11,280' Ran 1.82" WL broaching tool to 11,283' POH. RD slickline. Worked cutter off fish. P0H w/wash over pipe. POH. Stood back 5-3/4" WP. LD 2-7/8" outside cutter. MU hollow mill & 5-3/4" OS dressed w/2- 7/8" grapples, 10 stds 3-1/2" DP, bumper sub & jars, 9 - 6-1/4" DC's & ACC jar. RIH. Worked over & jarred fish @ 11,274' w/OS. RU slickline. RIH w/0.6" to 2.17" swedge. Worked thru TOF ~ 11,280' WLM. RIH @ 11,350' w/swedge @ rpt time. DWC: $32,686 CWC: $896,662 DMC: $903 CMC: $9,687 MIDDLE GROUND SHOAL A, WELL #ll-01U&L AFE #: 101039 Objective: Pull Dual Completion & Run New Single String 11/16/01 Fin RIH w/slickline & swedge to 12,268' WLM. FIRST REPORT: 10/19/2001 POH & RD slickline unit. RU APRS WL. RIH w/2-1/8" cutter to 12,245' WLM. Cut tbg ~ 12,227' WLM. POH w/cutter, shot fired. Worked pipe & jarred on same, no success. RU APRS WL. RIH & ran free point indicator. Pipe free to 12,163' WLM. Pipe had little movement @ 12,193' POH w/tools. PU string shot & RIH. Worked two rounds of LH torque in pipe. Shot string shot 8 12,163' WLM. POH & RD APRS WL. Completed back off w/12 rounds of LH torque, pipe free. Circ btms up & ppd pill. Std TOH w/DP. DWC: $31,783 CWC: $928,445 DMC: $0 CMC: $9,687 AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/17/01 TOH w/DP. Handled BHA. POH & LD 9 its of tbg plus cutoff (294.25'). New top of fish @ 11,569' tbg meas. Press tstd BOPS to 250-3,000 psig, tstd OK. PU OS Grapple fishing assbly. TIH. Worked over top of fish ~ 11,569' DPM. RU APRS WL. RIH w/2-1/8" chem cutters. Cut tbg @ 12,148' WLM. POH w/chem cutters above jars. Unable to pull fish. Fin P0H w/chem cutters. RU chem cutter #2. RIH. DWC: $31,783 CWC: $960,228 DMC: $0 CMC: $9,687 AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/18/01 Fin RIH w/chem cutter %2. Cut tbg @ 11,854' WLM. P0H w/chem cutter. RD APRS WL. Ppd dry job. TOH w/partial fish. SD & secured rig due to high winds (48 knots w/gusts). Fin TOH. Rec 9 its of tbg plus cutoff (280.48'). PU wash pipe BHA. Serviced rig & top drive. TIH w/WP. Iron ruff-nek dwn. Lost tong in hole. Washed over top of fish @ 11,289' DPM. Broke circ & vis up mud. DWC: $31,783 CWC: $992,011 DMC: $0 CMC: $9,687 Ai~E #: 11/19/01 101039 FIRST REPORT: 10/19/2001 Raised vis on mud. Washed over fish to 11,994' DPM. Washed over fish fr/11,994'-12,140' DPM. Bad torque & drag. Circ out sd. Std TOH. Stuck @ 12,130' Worked out to 12,120' Worked stuck pipe. Pulled free. High drag to top of liner. Circ hole. T0H to 10,505' DPM. Circ sweep (circ out some sd). Ppd dry job. TOH. Chg'd out jars & BS. Junk marks on wash pipe. PU & MU OS assbly. TIH to catch fish @ 11,849' DPM. Will attempt to pull 299' of fish (cut @ 12,148' ). DWC: $41,431 CWC: $1,033,442 DMC: $1,148 CMC: $10,835 MIDDLE GROUND SHOAL A, WELL #ll-01U&L AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/20/01 TIH w/OS assbly to 10,505' DPM. Slipped & cut drlg line. Fin TIH. Tagged & worked over top of fish @ 11,849' DPM. Ppd dry job. POH & rec 9 full its & 2 cutoff its of 2-7/8" tbg (298.89'). New est top of fish ~ 12,147.89' DPM. Serviced rig & top drive. PU 3 its of wash pipe assbly. TIH. Worked over top of fish. Washed to 12,242' (15' below jet cut ~ 12,227' WLM). High torque. Circ & sweep hole. Prep to TOH. Located 13 its of 5-3/8" wash pipe fr/UNOCAL (Tuboscope). Will pick wash pipe up for next trip. DWC: $41,182 CWC: $1,074,624 DMC: $0 CMC: $10,835 AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/21/01 Fin circ sweep. POH & circ fr/7" liner. Ppd sweep around in 9-5/8" csg. P0H & LD 5-3/4" wash pipe. PU overshot assbly. RIH. Attempted to catch fish @ 12,148' Mixed & ppd dry job. POH. No rec. Fish never got into grapple. Serviced rig & top drive. RIH 2nd time w/overshot assbly to catch fish ~ 12,148' DWC: $32,682 CWC: $1,107,306 DMC: $0 CMC: $10,835 AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/22/01 Fin TIH w/OS assbly #2. Worked over fish ~ 12,148' Ppd pill. T0H w/OS. Rec 82.46' of 2-7/8" tbg, lwr 3' split fr/getting dwn beside itself. LD fish, DC's & 5-3/4" wash pipe. Repr'd top drive. PU +/- 300' of 5-3/8" wash pipe w/top sub dressed to dress top of fish @ 12,227' WLM. TIH w/wash pipe. Slipped & cut drlg line. Fin TIH to 12,192' DPM. Washed over fish fr/12,242'-12,360' DPM. Less torque than the larger wash pipe. DWC: $31,783 CWC: $1,139,089 DMC: $0 CMC: $10,835 AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/23/01 Cont'd washing over fish fr/12,360'-12,574' DPM. Dressed T0F (fish has dropped 47'). Circ btms up & ppd sweeps. Circ up 6 bbls of fmt sd & small pieces of metal. POH. Handled BHA (fmt sd & metal in junk baskets). PU OS grapple assbly w/mill control. TIH 2 stands. Top drive hydraulics malfunctioned. Trouble shooting top drive hydraulics. DWC: $32,653 CWC: $1,171,742 DMC: $870 CMC: $11,705 MIDDLE GROUND SHOAL A, WELL %ll-01U&L FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion-& Run New Single String 11/24/01 Fin reprs to top drive hydraulics. Fin TIH w/OS assbly. Worked over & caught fish. TOH. POH & LD fish (full recovery). Recovered 26 its of 2-7/8" tbg, 2 "N" nipples, 1 shear/out WL reg, 1 cut/off & 100' of slickline. Joint above lwr "N" nipple was packed w/slickline, but no bomb. Ttl of 805.39' of fish rec. Tbg tail was @ 13,073' tbg meas. LD 5-3/8" wash pipe. Press tstd BOP/diverter to 250-5,000 psig w/AOGCC rep, tstd OK. Chg'd out VBR's w/3-1/2" rams. Pull tstd plug. Set wear ring. PU & MU flat btm mill assbly. PU 3- 1/2" DP & TIH. DWC: $32,309 CWC: $1,204,051 DMC: $0 CMC: $11,705 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/25/01 TIH w/flat btm mill. Set dwn @ 11,706' DPM. Attempted to wash past 11,706', no go, quit milling (afraid of milling hole in csg) o Circ & ppd sweep. POH, no significant marks on mill. PU tapered 5-13/16" mill & TIH. Tagged fill @ 12,910' DPM. Washed fr/12,910'-13,073' DPM. Unable to pass 13,073' DPM (in HR/HZ), 38' of perfs below PBTD. Circ & ppg sweeps. Getting sd back in rtns. Plan to POH above liner. Waited 1 hr & TIH to ck for fill before disp hole & pits w/clean FIW containing 3% KCL prior to completion. DWC: $24,309 CWC: $1,228,360 DMC: $0 CMC: $11,705 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/26/01 Circ & ppd sweep @ 13,073' DPM. Short tripped above 7" liner top. Serviced rig & top drive. Waited for fill to settle. TIH & set dwn @ 13,073' DPM (no addt'l fill). Circ & swept hole. Cleaned trip tnk & active pits (1-5). Backloaded boat & mixed 3% KCL w/FIW. Cleaned pollution pan & pipe rack while disp hole w/3% KCL/FIW. Circ until clean fluid in rtns. NOTE: Have rtl of 44 bbls of fmt sd mixed w/polymer @ surf. Std TOH. Plan to LD all but 9,500' of 3-1/2" DP. DWC: $32,809 CWC: $1,261,169 DMC: $0 CMC: $11,705 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/27/01 TOH. LD 3-1/2" DP (all but 9,500'). PU tbg tail assbly & pkr & TIH on DP. Dropped & ppd ball. Press up to 1,000 psig & 2,000 psig. Pulled 13K tens & set pkr @ 9,450' DPM w/tbg tail @ 9,486' DPM. P0H & LD 3-1/2" DP (1,350'). Slipped & cut drlg line. TOH. Serviced rig & top drive. Fin TOH. LD Baker setting tool. RU tongs. Chg'd out rams for 2-7/8" Pulled wear ring & tstd door seals & function tstd rams. Conducted safety mtg. PU Baker seal assbly. Std ih hole w/2-7/8" tbg. DWC: $76,234 CWC: $1,337,403 DMC: $0 CMC: $11,705 MIDDLE GROUND SHOAL A, WELL %ll-01U&L FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/28/01 Fin running 2-7/8" completion tbg. Unable to stab into pkr w/seal assbly. Finally stung in 1-1/2', unstung & stung back in. Unable to get seal assbly past 1-1/2' Called Paul Figel, instructed to pull tbg. TOH & stood back tbg. LD GLM's. Junk marks on muleshoe & up 1' on seals. Appears that junk is on top of pkr & probably jammed dwn into bore. SD WOO. Discussing options w/Midland office. DWC: $55,553 CWC: $1,392,956 DMC: $24,931 CMC: $36,636 FIRST REPORT: 10/19/2001 Objective: Pull Dual Completion & Run New Single String 11/29/01 Discussed plan with Midland office. Called for boat with 3-1/2" DP to rtn. Unloaded DP. Chg'd pipe rams to 3-1/2" Function tstd rams. Serviced rig & top drive. PU 3-1/2" DP. Waited on boat with 6-1/2" DC's, jars, pkr milling & fishing tools. Unloaded boat. PU & MU pkr milling assbly. TIH w/pkr milling assbly. Tagged pkr ~ 9,450' DPM. Milled pkr fr/9,450'-9,453' Ppd periodic sweeps to clean hole. Pkr dropped. Fin circ sweep around & dumped same. PU 3- 1/2" DP to chase pkr. DWC: $30,622 CWC: $1,423,578 DMC: $0 CMC: $36,636 Objective: Pull Dual Completion & Run New Single String 11/30/01 FIRST REPORT: 10/19/2001 Picked up DP & chased pkr to 10,498' (top of 7" liner ~ 10,505'). Ppd sweep. Circ well. Ppd dry job. TOH w/pkr mill. LD pkr mill. PU spear & 2 junk baskets. TIH. Fished for 9-5/8" pkr @ 10,498' Slowly TOH w/pkr dragging. LD 9-5/8" pkr & tail pipe. PU 8-1/2" mill & 9-5/8" csg scraper. TIH to 8,258' took weight. Washed through tight spot. Cont'd TIH. DWC: $32,809 CWC: $1,456,387 DMC: $0 CMC: $36,636 AFE #: 101039 Objective: Pull Dual Completion & Run New Single String 12/01/01 FIRST REPORT: 10/19/2001 Circ & ppd 2 - 20 bbl sweeps. Ppd dry job. TOH (top drive tilt malfunctioning. Chg'd out service loop on top drive. TOH (top drive tilt still not working). LD 9-5/8" csg scraper & 2 junk baskets (scale & sd in junk baskets). PU Baker Retrive-O-Matic pkr & ported sub. Worked on top drive tilt. Chg'd out wires to tilt & float. Chg'd out float solenoid (still not working). TIH w/Retrieve-O-Matic pkr. Slipped & cut drlg line. Set Retrieve-O-Matic pkr @ 9,520'. Press tstd csg to 1,000 psig (good tst). Dropped dart. Opened ported sub. Rev out 10 bbl sweep. DWC: $37,876 CWC: $1,494,263 DMC: $0 CMC: $36,636 MIDDLE GROUND SHOAL A, WELL #11-01U&L AFE #: 101039 Objective: Pull Dual Completion & Run New Single String 12/02/01 Fin rev circ 10 bbl sweep (looked good). TOH. FIRST REPORT: 10/19/2001 Stood back 95 stds of DP. LD 39 its DP & Baker Retrieve-O-Matic pkr. Quadco (Steve Edwards) trouble shooting link tilt problem. Chg'd output relay (working OK). Chg'd rams to 2-7/8" LD 6-1/4" collars. Pulled wear ring. RU tbg tongs. Ran 2-7/8", 6.5%, N-80, 8rd tbg. MU CIW tbg hanger. Slacked off just above WH. Mixed & ppd 10 bbls of CI, spotted between pkr & btm GLM. Dropped 2" pkr setting ball, drained stack & landed tbg hanger. Press up on pkr w/annular valve open to 1,000 psig, OK. Sheared out @ 3,000 psig. Monitored annular valve, no rtns. Set BPV & ND BOP. Btm of wleg @ 9,531.37', "XN" nipple @ 9,518.90', Baker 9-5/8" SB3 pkr @ 9,498.86', 1 jt of 2-7/8", 6.5#, N- 80, 8rd tbg, "X" nipple @ 9,453.20', 1 jt of tbg, #7 GLM ~ 9,409.76', 16 its tbg, #6 GLM @ 8,874.17', 22 its tbg, %5 GLM % 8,144.38', 29 its tbg, #4 GLM @ 7,188.60', 40 its tbg, %3 GLM @ 5,874.91', 45 its tbg, #2 GLM @ 4,398.64', 75 its tbg, %1 GLM % 1,953.81',50 its tbg, Baker T5 SSSV @ 319.82', 8 its tbg, 3 pup its & CIW hanger ~ 38.50' DWC: $25,789 CWC: $1,520,052 DMC: $0 CMC: $36,636 ×TO Flwg Tst Report: Hemlock Prod Test WH Press CP Gas Time (psig) (psig) Inj 7:00 PM 200 300 250 8:00 PM 450 760 250 10:00 PM 300 840 250 Rec (Bbls) BPH % CUT Remarks 100 Start Gas Lift 13 13 100 36 18 100 Ttl Flwd: 49 MIDDLE GROUND SHOAL A, WELL #ll-01U&L AFE #: 101039 Objective: Pull Dual Completion & Run New Single String 12/03/01 Fin ND BOP. Pulled riser. MU landing its. FIRST REPORT: 10/19/2001 Landed tbg. NU tree & tstd same. Chg'd out service loop on top drive. RR @ 12:00 (12:00 pm) 12/2/01. Prep to move to MGS A33-11 (fr/leg #1 to leg #4). DWC: $141,400 CWC: $1,661,452 XTO Flwg Tst Report: Hemlock Prod Test 9,562 - 13,130' DMC: $0 WH Press CP Gas Rec Time (psig) (psig) Inj (Bbls) BPH % CUT Remarks 12:00 AM 130 880 250 30 15 100 2:00 AM 250 860 250 44 22 100 4:00 AM 300 860 250 31 15.5 100 6:00 AM 100 870 350 30 15 100 8:00 AM 100 880 460 37 18.5 100 10:00 AM 140 880 · 572 46 23 100 12:00 PM 110 870 685 73 36.5 100 2:00 PM 115 850 685 65 32.5 100 5:00 PM 100 850 685 70 23.3 100 8:00 PM 100 840 685 74 24.6 100 11:00 PM 100 820 685 67 22.3 100 CMC: $36,636 Ttl Flwd: 567 AFE #: 101039 Objective: Prod Test 12/04/01 Prod tstg well. XTO Flwg Tst Report: Hemlock Flow Test Time 2:00 AM 5:00 AM 8:00 AM 1:00 PM 6:00 PM 11:00 PM 9,562 - 13,130' WH Press CP Gas (psig) (psig) Inj 100 800 750 100 700 750 100 610 800 100 580 800 100 580 800 100 580 800 FIRST REPORT: 10/19/2001 Rec (Bbls) BPH % CUT Remarks 62 20.6 100 28 9.3 100 19 6.3 99.9 28 5.6 99.9 26 5.2 99.9 25 5 96 Ttl Flwd: 188 MIDDLE GROUND SHOAL A, WELL #ll-01U&L AFE#: 101039 Objective: Prod Test 12/05/01 Ran 12 hr prod test. XT0 Flwg Tst Report: Hemlock 9,562 - 13,130' Plow Test Time FIRST REPORT: 10/19/2001 WH Press CP Gas Rec (psig) (psig) Inj (Bbls) BPH % CUT Remarks 90 570 756 120 5 95 Ttl Plwd: 120 AFE #: 101039 FIRST REPORT: 10/19/2001 Objective: Prod test 12/06/01 12 hr prod test. Incr inj gas to 895 msf/d. Will test well every 12 hours for next few days. XTO Flwg Tst Report: Hemlock 9,562 - 13,130' Flow Test Time WH Press CP Gas Rec (psig) (psig) Inj (Bbls) BPH % CUT Remarks 100 590 895 112 4.7 92 Ttl Flwd: 112 AFE #: 101039 Objective: Prod Test 12/07/01 Ran 12 hr prod test. XTO Plwg Tst Report: Hemlock 9,562 - 13,130' Plwg test report WH Press CP Gas Rec Time (psig) (psig) Inj (Bbls) BPH % CUT Remarks 7:00 AM 100 600 961 Start test 11:00 AM 100 600 961 16 4 96 2:00 PM 100 595 979 13 4.3 96 FIRST REPORT: 10/19/2001 Ttl Plwd: 29 MIDDLE GROUND SHOAL A, WELL #ll-01U&L AFE #: 101039 Objective: Pord Test 12/08/01 Ran 12 hour prod test. XTO Flwg Tst Report: Hemlock 9,562 - 13,130' Flwg test report WH Press CP Gas Time (psig) (psig) Inj 2:00 AM 100 595 990 7:00 AM 100 595 968 8:00 AM 100 595 968 9:00 AM 100 595 925 10:00 AM 100 595 925 11:00 AM 100 595 925 1:00 PM 100 595 947 2:00 PM 100 595 947 FIRST REPORT: 10/19/2001 Ttl Flwd: Rec (Bbls) BPH % CUT Remarks Start Test 20 4 96 4 4 86 4 4 86 4 4 74 4 4 74 9 4.5 74 4 4 84 49 AFE %: 101039 0bjective: Prod Test 12/09/01 Ran 12 hr prod test. XT0 Flwg Tst Report: Hemlock 9,562 - 13,130' Flwg Prod test. · WH Press CP Gas Time (psig) (psig) Inj 2:00 AM 100 570 947 7:00 AM 100 570 947 8:00 AM 100 570 947 10:00 AM 100 570 947 11:00 AM 100 570 901 1:00 PM 100 570 901 2:00 PM 100 570 901 FIRST REPORT: 10/19/2001 Rec (Bbls) BPH % CUT Remarks Start Test 22 4.4 84 4 4 85 8 4 85 4 4 85 8 4 70 4 4 70 Ttl Flwd: 50 09/05/01 07'~5 WELL DATA SURFACE CASING: INTERMEDIATE CASING; LINER: TUBING: PERFORATIONS: XTO Energy, Inc, MOS AU-O: U & COOK INLET, ALASKA 13 3/8" 61#J55. Set @ 2,625'. Cmt w/3,400 9 518" 47-40# NS0, Set @ 10,647'. Cmt w/1[,250 7" 29 # NS0. TOL @ 10.505'. Set @ 13,235'. Cmt w/500 LS: 2 7/$" 6.5~ NS0 811. EUE @ 12,870' SS: 2_ 7/8" 6.5# NSO CSHydril IPC (~3 9,483' Short String Perfs: FL-I~ 9562-9657'. 9670-9760' FP-FS 9807-9833' FS-FW 9930-9955', 9972-100t7' Long String Perfs: GN-GO 10893-10910' C~O-OR 11372-11419' GR-GS 11688-11700'. ! 17I)6-I 1716' HC-I-tD 12053-12138' I'tE-IIF 12158-12181' I-tI-I-~ 12195-12512' }RI-I-IR 12538-.12586', 12616-12854' HR-HZ 12905.. 12970', 12990-13005', 1306:3-13081 ', 13094-131 t 0', 13 [ 16- 13130' OBJECTIVE: ,Rep. air DH Failure and Commi ,ngle Production NOTE: ]BHP Bomb Fish is in Long String. Top of the slicldine is @ 9,060'. 1. RU Sl[cklin¢ on the Long String. Test BOP's to 2,000 psi. In thc long string, RII-I with gauge ring to 9,000', POOH. REH to pull out GLV #6 in the long string, RU on Short String & te,t BOP's to 2,000 psi. In the short st. ring, R.1}I with gauge ring to 9,100'. RD SL. ,,~ '~,~ o.~,¢..¥,%'~ v'X. ~,,~ ~:t~% 2. Kill well by aim FIW down the long string. Set BPV. ~ tree and N-tJ BOP's and t~st to 250 & 5,000 psi. e,~t,,xa~x'~.'~X~x,,'~l { 3. RU WL APR$ on short string and test lubricator to 2,000 p~i, RIH with Jo! cutter and em $S @ ± 9,100'. POOH, RU on LS and ret~t lubricator to 2,000 psi. R.rl-I with jet cutter in L$ and cut tbg @ :1: 9,000'. POOH with WL and RD. 4. RU dual tbg tongs & slips. TOH simultaneously with $$ and L$ and lay down pipe. Send TBG to onshore and hay, all pil~ inspected for NOP,2vl per OIL 1.00(n)-I ['Revised 1110-92). 5. PU 3 W' DP. TIH with overshot., BHA on 3 W' DP. Fish Packers ~ 9.483' and 10,384'. 6. TIH with 6" bit, a scraper for 7" 29#, + 2.700' of 3 ~" DP, scrapor for 9 $/8" 47~ on 3 ~" DP. Space out to run 7' scraper to PBTD @ 13,152' and 9 5/8" scraper to TOL @ 10,505'. Circ well clean with FIW. POOH. 7, RIH 9 518' Baker DB Packer assembly on 3 W' DP as follows: Final Procedure 7-03-01 09/05/01 07:35 '1~915 65? 08,6Z XTO Energy, Inc, MGS All-01 U & L 7-03-01 t-'-~em ' "- Length _. _T~p... ' .... B-ottom 9 5/~" Igaker DB Packer'194 - 32 '~' 4 9450 ~ ' 9454 l~'akcr Seal Bore Extension I0' 9454 9464 XO Acme Box to 2 7/8" 8rd ET.IH, i 9464 9465 g 7/8" 6.5# NS0 8R EUE Pu[~ Jt I0 9465 9475 Oti~ 5.205" XN Nipp!e 9er 1 .......... 9~475 ~'476 .... 2 7/8" 6.5# NS0 8R EUE Pup ,It. l0 9476 9486 'Baker WI.'~'-entry Guide with Pump out I 9486 9487 plug sat ~ 3,81}0 to 4000psi Set pkr assembly ~ +/-9,450'. POOH with DP and LD. 8, Tilt with Baker seal assembly, GLM, and SSSV and g 718" 6,5# NS0 8R EUE tbs as follows: Item Length Top ~ Bottom 2 7t8" 6.5# NS0 8R EUE Tbs ~0_O_ .......... 0 300 Baker T5 SSSV 5 300 305 ~5~*_~. ~i~p~_(2.313.~.~) 9~ ......... ! ............... 94JC 9a12 2 7/8" 6,5~ NS0 8R ED~ Pup Jt 6 984 9450 Locator Sub w/12' of Seals (2 seals units, 1I 9450 9461 spacer robe, 2 seal units, size 80-32) GLM TVD MD Port Pst I Pso l [,800 1,948 10 909 950 2 3,200 4,376 I0 891 .....915 3 4,000 5,863 12 : 869 901 4 4,700 7,179 12 847 871 5 5,200 8,1'44 12 ' '826 .... 845 7 5,950 9,41~. . L6 . .Orifice ._ 9. Hang off 2 718" tbg. SetBPV. NDBOP's. NUwellh~dandt~sttoS,000psi. Pull out BPV. Prcsstcsttbgto t,000 psi for 15 minutes. Monitor t'alloff. Continuv to pre~sur¢ up on tbg m ~xp¢¢tcd pump out press of +/- 2,840 psi. (Expected reservoir press is 1,680 psi and a hydrostatic press of 2,640 psi @ 5,976' TVD,) 10. Return well to production and release rig. Test well for 3 days with I hour rsadings for 1~t 24 hours~ I 1, ?rodu~: w~ll. 12- Afmr rig is SD on Platform, MIRU Coil Tbs for Acid treatment on well. NH BOP's and test to 4,000 psi. Continue gas lift well while R.U:-I with let tool on I ~" CT while circ with diesel to 13,130'. Close CT annulus & Coil Ibg wash pews 10,893 -13,1':10' (925' Net) & 9,562 -IO,047' (291' Net) with 20,000 gal HCL NEFE, Scale Inhibited Acid 4- 35Q N2 @ 2-3 BPM- Make 3 passes across zone. Flush to bottom port'with diesel. Pump 100% N2 while POOH. RD CTU. , Final Procedure 7-03-01 RECEIVED 5 AJ86kll Oil & 6alt Corl6. (;Ol-ilmisglo~ ' AnchoreOe 09/05/01 07:35 '~'915 687 0862 CROSS TIi~iBERS r. XTO Energy, Inc. MOS All-ill U & L ! , , 7-03-01 13- Put well on Gas Lift and teat for 2-3 days while gathering hourly production tbr the 1" 48 hours. 14, RU' SL. Test BOP's to 2,000 psi. RII-I with 2.0" gauge ring to 13,130' & check for fill, POOH &:PI), 15. RU Schlumberger WL and lubricator. Pre~$ teat lubricator to 3.000 psi. Rill with PSP Production Log. lt.n Prod Log across perf's 10,893 -13,130' & 9,562 -10,047' while (]as Lifting w~ll. RD WL and send report MidIand offi¢c. Paul Fig~l fJ Production Engineer . . Vice President Opcratiou$, Alaska Final Procedure 7:03-01 RECEIVED SEP 5 2001 Alaska Oil & Gas Cons. Gomm~smm, Anchomge QryTestl 9/3/2001 MIDDLE GROUND SHOAL 044.002 1012211968~SHELLIPAN AMERICAN Permitted to commingle "A" and "BCD" pools in MGS 17595 #12. Yes MIDDLE GROUND SHOAL 044.006 5/1/1969 PAN AMERICAN Permitted to commingle "BCD" and "EFG" in MGS 17595 #14. Yes MIDDLE GROUND SHOAL 344.009 12/2/1969 PAN AMERICAN Permitted to commingle "A" with "BCD" or "EFG" in MGS 17595 #7. Yes MIDDLE GROUND SHOAL 044.014 3/21/1973 AMOCO Permits commingling in MGS 17595 #6. Yes MIDDLE GROUND SHOAL 044.019 10/25/1974 AMOCO Permits commingling in MGS 17595 #7. Yes MIDDLE GROUND SHOAL 044.020 4/9/1975AMOCO Allows commingling of fluids in MGS 17595 #5. Yes MIDDLE GROUND SHOAL 044.040 10/30/1987 AMOCO Authorizes commingling "BCD" & EFG" Oil Pools. Yes MIDDLE GROUND SHOAL 044.047 11/30/1992 UNION Commingle production of "BCD" and "A" in Platform Baker MGS 17595 #27. Yes MIDDLE GROUND SHOAL 044.052 2/23/1994 UNOCAL Commingle prod of A and BCD pools in MGS, Platform Baker MGS 17595 well # 28. Yes MIDDLE GROUND SHOAL 044.053 3/14/1994 UNOCAL Commingle production of "A", BCD and EFG pools, platform Baker MGS 17595 well 28. Yes MIDDLE GROUND SHOAL 044.063 8/15/1996 UNOCAL Authorizes the commingling of the referenced production from Well No. 15RD pursuant to Rule Yes MIDDLE GROUND SHOAL 056 1/3/1968 PAN AMERICAN Permits commingling of "A" with "BCD" or"EFG" downhole with downhole valves. Yes MIDDLE GROUND SHOAL 062 :; 3/27/1968 PAN AMERICAN Allows commingling in wellbore of "AEFG" pools in 17595 #4. Periodic tests required. Yes MIDDLE GROUND SHOAL 089 4/6/1970 PAN AMERICAN Permits commingling of "A" with "EFG" in well bore in Well MGS 17595 ~t. Yes MIDDLE GROUND SHOAL 099 3/15/1971~AMOCO Permits substitution of spinner survey to allocate prod of oil pool "A" and oil pools "EFG". Wells Yes Page 1 IOO0 5O8 5O0 MIDDLE GROUND SHOAL - El C & D O / POOL MIDDLE GROUND SHOAL - E F & G OIL POOL MGS SHELL A MIDDLE GROUND SHOAL BC&DOILPOOL ~,IGS SHELl_ A 000 mOO l?i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CUMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casiHg: Repai'F'well Plugging: Time extension Stimulate': Change approved prograrr X Pull tubing: X VarianCe: Perforate: Other: .... 2. Name of Operato 5. Type of well 6. Datum elevation (DF or KB XTO ENERGY, INC. Development X DF @ 116' feel 3. Address Exploratory 7. Unit or Property nam~ , 3000 N. GARFIELD, STE. 175 Stratigraphio: MIDLAND, TX 79705 Service: MIDDLE GROUND SHOAL 4. Location of well at surface "~ ~' ,~' 8. Well number Platform "A", Leg #1, Conductor 7, 1,627' N - 435' W, SE Corner Sec. 11,T,I~N-RI$ W, S.M. A11-01 U & L At top of productive interv~ 9. Permit numv~ 6,806.82' N & 1,106.50' E FROM SURFACE ~'~ 66-29 At effective deptf 10. APl numbe~ S0- 733-1~0~ At total deptf '11. Field/Poo '~'~'" 8,432.09' N & 1,966.15' E FROM SURFACE MGS/"BOD" & "EFG" 12. Present well condition summar Total depth: measured 13,238' feel Plugs (measured', true vertica 9,187' feel Effective depth: measu red 13,152' feel Junk (measu red 12,870' - 9,060' true vertica 9,050 ' feel Casing Length Size Cementec Measured deptf True vertical depth Structural Conductor Surfaoe 2,625' 13-3/8" 61# J55 3,400 SX 2,625' 2,216' Intermediate 10,647' 9-5/8" 40-47# N80 1,250 SX 10,647' 6,904' Production Liner 2,733' 7" 29# N80 500 SX 13,238' 9,187' Perforation depth measured 9,562' - 10,047' - 5 INTERVALS 10,893' - 13,130' - 14 INTERVALS true vertical 6,056' - 6,418' 7,114' - 9,086' Tubing (size, grade, and measured deptt' SHORT STRING: 2-7/8", 6.5#, NS0 HYDRILL CS IPC @ 9,483'. LONG STRING: 2-7/8", 6.5#, N80 EUE 8R @ 13,051' Packers and SSSV (type and measured deptl' L.S.: GUIBERSON RH-1 @ 10,391' S.S.: GUIBERSON RH-2 @ 9,495' 13. Attachement.~ Description summary of proposal X Detailed operations prograrr BOP sketch: 14. Estimated date for commencing operatic 15. Status of well classification as October 1,2001 16. If proposal well verbally approve( Oil: X Gas: Suspended: Name of approver Date approved Service: 17. I hereby ~ that the foreggj~g is true and correct to the best of my knowled.( Conditions of approval: Notify Commission so representative may witness ~~,~t ~\ ~ ~t,.~:~ ~..%.~- JApproval No. , ... ,,,.- Plug integrity.~ BOP Test ~ Location clearan~e~_._~.~J ~j~l"~"~ Mechanical Integrity Test Subsequent form required 10- ~ ! ,, Approved by order of the Commissioner ,Original Sl~lled By Commissioner Date q Cammy Oechsli RECEIVE Form 10-403 Rev 06/15/88 ORIGINAL AUG g 8 2001 Alaska 0il & Gas Cons. Commission Anchorage SUBMIT IN TRIPLICATE July 5, 2001 ~EN~ERGY XTO Energy Inc. 3000 North Garfield Suite 175 Midland, Texas 79705 915-682-8873 915-687-0862 (Fax) Alaska Oil and Gas Conservation Commission Attn: Mr. Hartz 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Subject: Request for the approval to commingle production, "BCD" and "EFG" Pools, in the Middle Ground Shoal Field, Platform A, for the MGS A 11-01 U&L Well. Dear Mr. Hartz, XTO Energy Inc. (formerly known as Cross Timbers Operating Company), as operator of Platform A, requests that the Alaska Oil and Gas Conservation Commission (AOGCC) approve the commingling of oil and gas production from the Middle Ground Shoal Field "BCD" and "EFG" pools in the MGS Well # A11-01 U&L pursuant to Rule 6 of the Conservation Order No. 44. Additionally, XTO Energy requests waiver of the requirement to provide complete separation of flowstreams from separate pools. The AOGCC has granted approval to commingle production in several Middle Ground Shoal wells in the past. Two recent approvals to commingle zones in the "A", "BCD" and "EFG" pools were for Unocal on Platform Baker MGS 17595 Well #15RD in 1996 and Well #BA-28 on March 14, 1994 (AA44.53). Those approvals were similar to this application insofar as commingling without separation of flowstreams was permitted. BACKGROUND XTO Energy purchased Shell Oil Company's working interest in two Cook Inlet properties and assumed Operatorship of Platform A and Platform C effective October 1998. XTO Energy holds 100% working interest in both Platforms. XTO Energy has aggressively developed reserves on both Platforms since acquiring ownership. Several recompletions have been performed in attempts to increase production and maintain economic viability from marginal reserves in these mature pools. In the case of the "BCD" and "EFG" pools on Platform A, the potential along the east and west flanks is marginal due to depletion and water encroachment from offset injection wells. RESERVES AND DEVELOPMENT STRATEGY -?/~i') '~'~ lt-~ ..... ' A11-01 U&L was completed in 1966 by Shell Oil in the "F" portions of the "BCD" pool and in the "G" and "H" portions of the "EFG" pool as a dual gas lift well. During Shell's ownership, several problems persisted while trying to obtain efficient gas lifting of both tubing strings. Those problems still persist, as there appears to be a tubing leak in one or both strings preventing efficient gas lifting of the wells. Costs to repair and recomplete the A11-01 U&L must be minimized due to the late stage of production from the well. A single Gas Lift String has been recommended as an economically viable method to produce both the "BCD" and "EFG" pools simultaneously, leading to the recovery of additional reserves. After receiving approval as applied for herein, XTO plans to pull the failed dual completion from the "BCD" and "EFG" pools in the//Al 1-01 U&L well and set a single production string that will commingle both zones utilizing gas lift for artificial lift. State p~~ng of the A11-01 U&L from February, 2000 indicated a 24 hour shut-in pressure in the ~645~-~(~"ffeference subsea datum -6151 ft TVD) and a 24 hour shut-in pressure for the EFG zone of ?'1677# (@"'~e~e subsea datum of-8082 ft TVD). WELL EQUIPMENT CONSTRAINTS All oil producing zones at Middle Ground Shoal Field require artificial lift in order to be effectively produced to the surface. XTO's request to commingle production from the "BCD" and "EFG" zones is based upon the necessity of using gas lift equipment. XTO's request that the AOGCC waive the requirement to provide separation of flowstreams is due to the fact that a second separate gas lift string would not only be cost prohibitive at this late stage of well production, but the complexity of a dual string gas lift system will make any future work difficult to justify. ECONOMIC CONSIDERATIONS ~5~ ~' After over 35 years of operations of Platform A, oil production remains near the economic limit for operation dependent upon the volatile crude prices over the past few years. While XTO Energy believes that potential development remains, capital and operating expenses must be minimized or further development may be unwarranted. Replacing both dual production gas lift strings would be considerably more expensive than to proceed with a single gas lift production string. Additionally, the single string would be more efficient from both the gas lift aspect and from the operational aspect. A dual production string poses more expense for future repairs, usually requiring an expensive workover rig, while single string completions can rely on less expensive coil tubing units for repairs. Due to the mature state of the All-01 U&L, on production since 1966, XTO believes the only option that economically justifies the workover on the All-01 U&L is to proceed with a single production string producing from both the "BCD" and "EFG" pools. PRODUCTION ALLOCATION To allocate production from Well A11-01 U&L between the "BCD" and "EFG" pools, XTO Energy proposes to initially allocate oil and water production in proportion to the amount of perforated interval in each zone. In this case the "BCD" pool is perforated in 294' and the "EFG" pool contains 938', making a total of 1,232'. Therefore, the "BCD" would be allocated 24% of the production while the "EFG" would be allocated 76%. CONCLUSIONS In summary, XTO Energy requests the AOGCC permit the commingling of oil and gas production from the Middle Ground Shoal Field "BCD" and "EFG" pools in the MGS Well A11-01 U&L. Further, XTO requests waiver of the requirement to complete separation of flowstreams from the two zones. This will allow XTO the only economic and viable option to workover the All-01 U&L and to return the well to positive economics by permitting more efficient operations and hydrocarbon recovery. Please direct any operational questions to Paul Figel at (915) 620-6743. Questions of a reservoir, or geologic nature may be directed to Tim Smith, Reservoir Engineer (817) 885-2246 or Mike Langeler, Geologist (817) 885-2581. Please notify me at my number included above as soon as the approval has been granted. Thank you for your assistance. Sincerely, Paul L. Figel Production Engineer Cc: Doug Schultze Doug Marshall Tim Smith Mike Langeler List of Attachments: 1. Wellbore Diagram (Proposed) 2. Structure Map of the "F" Zones 3. Structure Map of the "G" and "H" Zones ~ERGY MGS A11-01U & L Cook Inlet, Alaska Leg 1, Conductor 2 Surf Csg: 13 3/8", 61 lb, J55. Set @ 2625'. Cmt'd w/3400 sx. Intermediate Csg: 9 5/8", N80. Set @ 10647'. Cmt'd w/1250 sx 0-62' 47# 62-7269' 40# 7269-9485' 43.5# 9485-10647' 47# Proposed Completion PLF 7-05-01 Tbg: 2 7/8" 6.5# N80 EUE 8R @ 9,487' Item MD TVD Pso Psc Port GLM #1 1948' 1800' 950 909 10 GLM #2 4376' 3200' 915 891 10 GLM #3 5863' 4000' 901 869 12 GLM #4 7179' 4700' 871 847 12 GLM #5 8144' 5200' 845 826 12 GLM #6 8858' 5600' 821 804 12 GLM #7 9412' 5950' Orifice 16 Baker T5 SSSV @ 300' Otis "X" Nipple 9Cr @ 9415' (2.313" ID) I jt of 2 7/8" 6.5# N80 Pup Jt. 6' 2 7/8" 6.5# N80 Locater Sub 12' of Seals (80-32) 9 5/8" Baker DB Permanent Packer 194-32 @ 9,450' 10' Sealbore Extension XO Acme Box to 2 7/8" 8R 10' 2 7/8"6.5# N80 8R Pup Jt Otis XN Nipple 9Cr (2.205" ID) 10' 2 7/8"6.5# N80 8R Pup Jt Baker WL Re-entry Guide @ 9487' Prod Liner: 7", 29 lb, N80. Set @ 10505 -13238'. Cmt w/500 sx Short String FL-FP: 9562'-9637' FL-FP: 9670'-9760' FP-FS: 9807'-9833' FS-FW: 9930'-9955' FS- FW: 9972'- 10047' PBTD: 13152' TD: 13238' Long String GN-GO: 10893'-10910' GO-G R: 11372'-11419' GR-GS: 11688'- 11700' G R-GS: 11706'-11716' HC-H D: 12053'- 12138' H E-H F: 12158'-12181' HI-H N: 12195'-12512' HN-H R: 12538'- 12586' H N-H R: 12616'-12854' HR-HZ: 12905'- 12970' HR-HZ: 12990'-13005' HR-HZ: 13063'- 13081' HR-HZ: 13094'- 13110' HR-HZ: 13116'-13130' i' -6,176' -5,861' UNOCAL "BAKER" 13 B-12 W 2 : ? : ? :' XTO ENERGYINC : -01 .~ -5,894' ? A44-02 O A41A-11 A32-11 O O -5,eo6' -5,964' 0 500' 1000' A22-01 O -6,174' A13-01 / -5,~4' ~ ~ / '/A2~IRD O: ~ "B,C,D" ACTWE ~ :/ ~~ / '6,!74' ~ COMPLETION ~ ~ ~" ~:-- _-- ~ ~ PRODUCER8 ~ ~ ~ ~ ..- .;~ ';: INJECTOR O / ~%, ~. ~ ,~ . / -'~; / ?? ./:~4~1/ MIDDLE GROUND SHOAL FIELD / / / / / ~/ KennJ Coun~ Of~hore / / ,/: ? ,/'-07"' Cook lnlet, Alaska ( / / /: :/ / Al1-01 COMMINGLEING A 1-12 : ,: ? / / / O / :/ ,: / / WELLS POSTED T/FL SAND ~-6,~5' / : / ;; / STRU~URE MAP T/FL SAND ZONE CON~UR IN~RVAL: 200' T-FL SAND = T/"B,C,D" POOL GEOLOGIST: MIKE I.ANGELER DATE: AUGUST, 2001 R 13 W 2 x~o ENERGY;]NC 1 All-01 -7,121'~ O : -s,75~'/ / ~ A33~1 A23~ RD > ~ -8,134' -6,878' ? : :~ - -7,~' : :' ' ., : ' SYMBOL KEY :' 2: ~ ': "E,F,G" ACTIVE :>" .-' :' - : COMPLETION / : ~ ~ P&A "E,F,G" : ~ PRODUCERS ,/ ~ .? ~: : ~ "E,F,G" .... ¢_~¢ INJECTOR -~ A14~ 1 _~ PENET~TION : 11 ,., ;~ ; ONLY1 02/ _/' : : ABAN~NED / ~ - ~ ._ -.~. INJECTOR ? ?/ ' : - MIDDLE GROUND SHOAL FIELD ~-'~' :':~ -7,~i'; ' .... X / / ~: : : All-01 COMMINGLEING ~: :/ WELLS ~STED TIGN ~AND :: :: :~. :: : :' ~: STRU~URE MAP T/GN SAND ZONE ;:' :~ ~: ~ : CON~UR IN~RVAL: 200' : :> T~N SAND = TI"E,F,G" POOL GEt. lET: MIKE ~E~R DATE: AUGUST, 2~1 0 50~ 10~' ~~ ~m~.~ im~. MIDDLE GROUND SHOAL - B C _D OIL POOL -- -- _ Alias DATE All-01 19660930 All-01 19661031 All-01 19661130 Alt-01 19661231 All-01 19670131 All-01 19670228 All-01 19670331 All-01 19670430 All-01 19670531 All-01 19670630 All-01 19670731 All-01 19670831 All-01 19670930 All-01 19671031 All-01 19671130 All-01 19671231 All-01 19680131 All-01 19680229 All-01 19680331 All-01 19680430 All-01 19680531 All-01 19680630 All-01 19680731 All-01 19680831 All-01 19680930 All-01 19681031 All-01 19681130 All-01 19681231 All-01 19690131 All-01 19690228 All-01 19690331 All-01 19690430 All-01 19690531 All-01 19690630 All-01 19690731 All-01 19690831 All-01 19690930 All-01 19691031 All-01 19691130 All-01 19691231 All-01 19700131 All-01 19700228 All-01 19700331 All-01 19700430 All-01 19700531 All-01 19700630 All-01 19700731 All-01 19700831 All-01 19700930 All-01 19701031 All-01 19701130 All-01 19701231 All-01 19710131 All-01 19710228 All-01 19710331 All-01 19710430 All-01 19710531 All-01 19710630 All-01 19710731 All-01 19710831 All-01 19710930 All-01 19711031 All-01 19711130 All-01 19711231 All-01 19720131 All-01 19720229 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 842 855 719 667 470 450 459 465 451 371 379 377 420 361 360 320 299 280 265 145 138 176 188 184 203 196 172 186 237 214 215 187 174 174 184 164 138 149 156 197 165 177 170 145 165 138 144 128 122 142 139 144 149 168 130 148 137 131 140 131 115 121 111 83 111 82 402 433 395 369 260 257 313 320 341 321 299 237 346 355 351 311 200 375 289 86 75 133 137 101 152 126 109 101 102 77 101 86 69 82 59 73 63 76 84 101 91 91 91 76 94 76 79 73 62 77 80 87 84 95 76 85 78 75 81 75 67 61 56 49 61 46 29 23 20 14 15 5 14 15 5 41 16 16 17 14 14 10 12 17 8 15 34 17 36 20 9 22 15 10 18 16 11 33 44 28 24 41 19 37 52 32 20 22 22 21 14 17 20 16 15 19 16 2O 21 22 25 18 21 2O 19 21 16 17 2O 12 14 11 477 507 550 553 554 572 682 689 756 865 788 629 824 985 977 972 669 1336 1088 592 543 759 728 547 748 646 636 545 430 363 469 461 398 469 322 446 453 512 535 513 552 516 534 525 571 551 549 569 505 541 576 603 565 567 580 575 569 572 577 570 585 505 505 591 547 559 5 32 52 73 86 97 110 124 138 149 161 172 185 196 207 217 226 233 238 241 245 251 256 262 268 274 279 285 292 298 305 310 316 321 326 331 335 340 344 350 355 360 365 370 375 379 383 387 390 394 399 403 407 412 416 420 425 429 433 437 440 444 447 450 453 456 MIDDLE GROUND SHOAL - B C _D OIL POOL -- -- -- Alias DATE All-01 19720331 All-01 19720430 All-01 19720531 All-01 19720630 All-01 19720731 All-01 19720831 All-01 19720930 All-01 19721031 Alt-01 19721130 All-01 19721231 All-01 19730131 All-01 19730228 All-01 19730331 All-01 19730430 All-01 19730531 All-01 19730630 All-01 19730731 All-01 19730831 All-01 19730930 All-01 19731031 All-01 19731130 All-01 19731231 All-01 19740131 All-01 19740228 All-01 19740331 All-01 19740430 All-01 19740531 All-01 19740630 All-01 19740731 All-01 19740831 All-01 19740930 All-01 19741031 All-01 19741130 All-01 19741231 All-01 19750131 All-01 19750228 All-01 19750331 All-01 19750430 All-01 19750531 All-01 19750630 All-01 19750731 All-01 19750831 All-01 19750930 All-01 19751031 All-01 19751130 All-01 19751231 All-01 19760131 All-01 19760229 All-01 19760331 All-01 19760430 All-01 19760531 All-01 19760630 All-01 19760731 All-01 19760831 All-01 19760930 All-01 19761031 All-01 19761130 All-01 19761231 All-01 19770131 All-01 19770228 All-01 19770331 All-01 19770430 All-01 19770531 All-01 19770630 All-01 19770731 All-0t 19770831 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 72 83 79 75 70 71 87 134 129 139 92 104 101 113 71 85 55 51 64 72 73 162 158 161 140 145 167 168 172 188 182 169 157 171 170 178 184 171 178 180 139 138 153 142 141 130 135 121 126 124 129 130 129 145 141 143 124 110 122 106 83 100 130 119 127 21 146 42 298 68 42 43 66 284 86 70 29 57 64 26 151 92 0 0 32 5 62 70 57 68 75 81 87 93 92 91 84 84 92 89 93 93 91 86 89 84 78 85 80 78 75 66 66 68 65 65 1102 69 75 181 230 121 165 358 112 117 179 229 190 187 8 10 13 12 15 31 37 28 21 23 16 17 9 14 9 11 7 7 10 8 8 24 22 24 19 21 17 27 28 31 35 36 40 33 37 38 32 35 37 34 44 54 43 40 42 41 26 40 42 39 43 37 41 36 35 40 48 47 41 35 43 56 43 46 32 285 1759 531 3973 977 590 497 496 2205 617 758 274 563 572 359 1770 1685 0 0 443 68 385 443 353 484 517 485 517 541 488 499 496 533 537 524 521 506 533 482 495 605 565 556 565 555 576 489 547 540 524 505 8509 536 517 1285 1612 972 1504 2928 1061 1402 1793 1766 1602 1471 456 458 461 463 464 464 464 467 471 475 479 482 485 488 492 494 496 498 500 502 503 505 510 515 520 524 528 533 539 544 550 555 560 565 570 575 581 586 592 597 600 604 608 613 617 622 626 630 633 637 641 645 649 653 657 661 666 669 673 676 679 682 685 689 692 696 MIDDLE GROUND SHOAL - B C _D OIL POOL -- -- -- Alias DATE All-01 19770930 All-01 19771031 All-01 19771130 All-01 19771231 All-01 19780131 All-01 19780228 All-01 19780331 All-01 19780430 All-01 19780531 All-01 19780630 All-01 19780731 All-01 19780831 All-01 19780930 All-01 19781031 All-01 19781130 All-01 19781231 All-01 19790131 All-01 19790228 All-01 19790331 All-01 19790430 All-01 19790531 All-01 19790630 All-01 19790731 All-01 19790831 All-01 19790930 All-01 19791031 All-01 19791130 All-01 19791231 All-01 19800131 All-01 19800229 All-01 19800331 All-01 19800430 All-01 19800531 All-01 19800630 All-01 19800731 All-01 19800831 All-01 19800930 All-01 19801031 All-01 19801130 All-01 19801231 All-01 19810131 All-01 19810228 All-01 19810331 All-01 19810430 All-01 19810531 All-01 19810630 All-01 19810731 All-01 19810831 All-01 19810930 All-01 19811031 All-01 19811130 All-01 19811231 All-01 19820131 All-01 19820228 All-01 19820331 All-01 19820430 All-01 19820531 All-01 19820630 Alt-01 19820731 All-01 19820831 All-01 19820930 All-01 19821031 All-01 19821130 All-01 19821231 All-01 19830131 All-01 19830228 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 111 112 118 108 112 119 131 118 65 87 58 49 144 138 147 144 137 87 127 117 135 132 172 147 153 139 153 147 156 149 147 140 147 148 122 128 135 122 116 112 97 143 131 117 118 169 167 167 185 142 190 198 189 174 168 168 180 200 194 184 203 172 167 189 203 196 243 212 226 175 381 258 170 214 251 92 277 4O 0 286 0 199 198 46 108 101 231 166 225 170 343 130 157 306 258 183 340 253 324 331 355 212 156 128 222 182 121 149 148 268 75 121 0 111 197 204 229 207 262 203 434 531 299 279 357 286 537 101 21 139 313 294 48 48 37 52 48 46 43 41 21 29 16 12 30 34 28 32 34 24 45 41 1 27 35 49 34 54 48 46 34 47 49 47 49 59 43 45 44 41 39 37 54 36 44 50 50 48 65 65 73 47 81 85 91 75 72 72 48 39 43 50 46 76 73 67 80 67 2182 1887 1920 1628 3391 2174 1298 1818 3856 1057 4744 817 0 2076 0 1386 1445 527 847 864 1708 1257 1309 1158 2239 942 1030 2087 1658 1230 2311 1809 2202 2229 2912 1657 1152 1045 1916 1625 1242 1044 1132 2290 635 712 0 664 1062 1436 1206 1047 1382 1165 2579 3162 1664 1395 1836 1553 2646 588 126 735 1541 1504 700 703 706 710 713 716 721 724 726 729 730 732 736 741 745 749 754 756 760 764 768 772 777 782 786 790 795 800 804 809 813 817 822 826 830 834 838 842 845 849 852 856 860 863 866 871 877 882 887 892 897 904 909 914 920 925 930 936 942 948 954 959 964 970 976 982 MIDDLE GROUND SHOAL - B C _D OIL POOL -- -- _ Alias DATE All-01 19830331 All-01 19830430 All-01 19830531 All-01 19830630 All-01 19830731 All-01 19830831 All-01 19830930 All-01 19831031 All-01 19831130 All-01 19831231 All-01 19840131 All-01 19840229 All-01 19840331 All-01 19840430 All-01 19840531 All-01 19840630 All-01 19840731 All-01 19840831 All-01 19840930 All-01 19841031 All-01 19841130 All-01 19841231 All-01 19850131 All-01 19850228 All-01 19850331 All-01 19850430 All-01 19850531 All-01 19850630 All-01 19850731 All-01 19850831 All-01 19850930 All-01 19851031 All-01 19851130 All-01 19851231 All-01 19860131 All-01 19860228 All-01 19860331 All-01 19860430 All-01 19860531 All-01 19860630 All-01 19860731 All-01 19860831 All-01 19860930 All-01 19861031 All-01 19861130 All-01 19861231 All-01 19870131 All-01 19870228 All-01 19870331 All-01 19870430 All-01 19870531 All-01 19870630 All-01 19870731 All-01 19870831 All-01 19870930 All-01 19871031 All-01 19871130 All-01 19871231 All-01 19880131 All-01 19880229 All-01 19880331 All-01 19880430 All-01 19880531 All-01 19880630 All-01 19880731 All-01 19880831 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 452 175 169 163 177 163 174 174 204 179 148 188 196 161 255 208 201 208 198 203 200 204 189 183 187 176 171 179 176 175 159 162 186 142 175 157 151 168 129 153 183 186 182 197 203 193 206 195 191 196 193 209 195 192 193 198 205 205 202 205 196 193 196 199 187 186 234 157 216 280 348 224 230 281 41 240 181 334 324 311 277 145 0 182 240 187 344 203 210 25 135 170 62 218 142 163 269 132 369 242 78 89 66 51 50 98 175 171 184 82 103 101 134 93 92 85 60 63 76 88 94 87 79 85 77 71 74 73 78 75 64 98 151 68 61 64 59 67 49 61 51 59 53 52 49 57 0 40 39 47 48 48 49 45 45 46 51 50 40 50 50 60 67 62 50 74 40 69 70 68 54 65 52 55 63 52 53 69 64 63 62 63 61 52 61 59 62 57 57 57 55 52 63 63 56 58 55 64 517 893 1279 1714 1961 1371 1324 1619 200 1340 1223 1780 1656 1926 1087 696 0 873 1210 920 1727 996 1111 136 723 964 364 1215 811 933 1697 813 1980 1709 446 566 436 305 384 640 957 922 1010 414 508 526 648 474 483 432 308 300 389 460 486 440 385 413 382 345 376 376 400 376 343 527 996 1001 1006 1011 1017 1022 1027 1032 1039 1044 1049 1054 1060 1065 1073 1079 1085 1092 1098 1104 1110 1116 1122 1127 1133 1139 1144 1149 1155 1160 1165 1170 1175 1180 1185 1190 1194 1199 1203 1208 1214 1219 1225 1231 1237 1243 1249 1255 1261 1267 1273 1279 1285 1291 1297 1303 1309 1315 1322 1328 1334 1340 1346 1352 1357 1363 MIDDLE GROUND SHOAL - B C _D OIL POOL Alias DATE All-01 19880930 All-01 19881031 All-01 19881130 All-01 19881231 All-01 19890131 All-01 19890228 All-01 19890331 All-01 19890430 All-01 19890531 All-01 19890630 All-01 19890731 All-01 19890831 All-01 19890930 All-01 19891031 All-01 19891130 All-01 19891231 All-01 19900131 All-01 19900228 All-01 19900331 All-01 19900430 All-01 19900531 All-01 19900630 All-01 19900731 All-01 19900831 All-01 19900930 All-01 19901031 All-01 19901130 All-01 19901231 All-01 19910131 All-01 19910228 All-01 19910331 All-01 19910430 All-01 19910531 All-01 19910630 All-01 19910731 All-01 19910831 All-01 19910930 All-01 19911031 All-01 19911130 All-01 19911231 All-01 19920131 All-01 19920229 All-01 19920331 All-01 19920430 All-01 19920531 All-01 19920630 All-01 19920731 All-01 19920831 All-01 19920930 All-01 19921031 All-01 19921130 All-01 19921231 All-01 19930131 All-01 19930228 All-01 19930331 All-01 19930430 All-01 19930531 All-01 19930630 All-01 19930731 All-01 19930831 All-01 19930930 All-01 19931031 All-01 19931130 All-01 19931231 All-01 19940131 All-01 19940228 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 195 197 196 197 180 183 192 184 196 190 189 195 188 188 181 163 209 177 176 178 180 172 148 164 161 172 178 165 151 166 163 164 167 170 143 149 154 159 148 152 155 170 151 157 171 159 167 165 148 161 161 159 166 152 148 164 156 153 157 153 145 138 138 177 143 135 120 110 131 108 99 122 105 69 61 92 61 91 91 104 105 104 94 178 74 103 64 59 53 86 88 84 76 81 96 73 73 112 116 121 143 123 170 165 172 165 139 121 130 105 201 75 104 88 89 85 47 86 74 66 61 121 91 111 119 84 85 93 93 90 108 93 61 58 6O 62 64 65 54 51 43 49 48 39 41 46 46 47 42 41 44 45 52 48 46 48 46 48 51 48 54 56 53 53 45 49 60 62 43 37 56 43 45 38 48 47 48 49 50 50 50 50 53 61 53 59 54 56 62 57 57 53 57 59 75 58 53 59 618 558 669 547 546 669 548 375 309 488 324 467 482 553 582 637 451 1006 423 582 353 344 360 526 546 490 430 494 635 439 449 681 695 713 996 823 1109 1039 1164 1085 894 710 857 670 1177 471 622 533 599 532 289 54O 449 431 410 734 585 721 759 548 587 670 669 509 754 687 1369 1375 1381 1387 1393 1398 1404 1409 1415 1421 1427 1433 1439 1444 1450 1455 1461 1466 1472 1477 1483 1488 1492 1498 1502 1508 1513 1518 1523 1527 1532 1537 1543 1548 1552 1557 1561 1566 1571 1575 1580 1585 1590 1595 1600 1605 1610 1615 1619 1624 1629 1634 1639 1644 1648 1653 1658 1662 1667 1672 1676 1681 1685 1690 1695 1699 MIDDLE GROUND SHOAL - B C _D OIL POOL -- -- -- Alias DATE All-01 19940331 All-01 19940430 All-01 19940531 All-01 19940630 All-01 19940731 All-01 19940831 All-01 19940930 All-01 19941031 All-01 19941130 All-01 19941231 All-01 19950131 All-01 19950228 All-01 19950331 All-01 19950430 All-01 19950531 All-01 19950630 All-01 19950731 All-01 19950831 All-01 19950930 All-01 19951031 All-01 19951130 All-01 19951231 All-01 19960131 All-01 19960229 All-01 19960331 All-01 19960430 All-01 19960531 All-01 19960630 All-01 19960731 All-01 19960831 All-01 19960930 All-01 19961031 All-01 19961130 All-01 19961231 All-01 19970131 All-01 19970228 All-01 19970331 All-01 19970430 All-01 19970531 All-01 19970630 All-01 19970731 All-01 19970831 All-01 19970930 All-01 19971031 All-01 19971130 All-01 19971231 All-01 19980131 All-01 19980228 All-01 19980331 All-01 19980430 All-01 19980531 All-01 19980630 All-01 19980731 All-01 19980831 All-01 19980930 All-01 19981031 All-01 19981130 All-01 19981231 All-01 19990131 All-01 19990228 All-01 19990331 All-01 19990430 All-01 19990531 All-01 19990630 All-01 19990731 All-01 19990831 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 115 124 158 140 130 136 127 136 129 133 133 126 109 120 132 108 113 138 115 104 125 118 121 145 149 127 136 133 133 131 87 121 113 113 122 102 102 108 107 106 99 115 105 93 99 82 8O 83 75 88 89 81 75 77 75 74 68 72 66 50 48 57 75 69 68 78 83 81 84 72 82 36 59 78 54 65 108 94 73 33 104 122 139 68 101 125 119 98 80 90 17 57 55 83 57 71 114 75 78 30 47 70 63 110 65 35 27 72 52 20 32 8 2 8 4 18 74 0 0 0 0 18 14 14 11 8 8 9 13 11 10 14 60 52 46 59 62 33 42 38 41 43 41 47 64 38 20 44 34 26 42 44 42 38 45 16 24 35 24 24 27 27 0 35 39 38 37 48 28 38 43 41 45 33 34 47 41 55 55 50 6O 46 49 51 59 54 54 57 57 51 51 32 31 43 57 55 49 48 718 652 535 512 633 264 466 574 418 493 811 749 671 278 782 1129 1230 491 874 1199 956 827 661 620 117 446 409 623 433 543 1314 622 686 267 389 683 622 1022 610 326 274 628 496 210 321 93 22 98 52 210 837 6 3 2 0 238 206 189 171 164 177 152 179 158 151 178 1702 1706 1711 1715 1719 1723 1727 1731 1735 1739 1743 1747 1750 1754 1758 1761 1765 1769 1772 1775 1779 1783 1786 1791 1795 1799 1803 1807 1811 1815 1818 1822 1825 1829 1832 1835 1838 1842 1845 1848 1851 1855 1858 1861 1864 1866 1869 1871 1874 1876 1879 1881 1884 1886 1888 1891 1893 1895 1897 1898 1900 1901 1904 1906 1908 1910 MIDDLE GROUND SHOAL - B C _D OIL POOL -- -- _ Alias DATE All-01 19990930 All-01 19991031 All-01 19991130 All-01 19991231 All-01 20000131 All-01 20000229 All-01 20000331 All-01 20000430 All-01 20000531 All-01 20000630 All-01 20000731 All-01 20000831 All-01 20000930 All-01 20001031 All-01 20001130 All-01 20001231 All-01 20010131 All-01 20010228 All-01 20010331 All-01 20010430 All-01 20010531 All-01 20010630 All-01 20010731 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 69 68 57 88 66 53 76 81 81 83 69 65 74 69 66 73 95 14 24 36 42 54 55 12 11 7 15 11 10 11 87 13 27 117 64 50 38 38 33 41 31 77 40 47 36 47 48 50 25 50 53 49 40 42 43 37 54 45 36 36 39 35 44 47 52 53 62 44 39 179 156 127 167 166 195 146 1078 162 320 1692 983 681 553 575 456 432 2307 3174 1115 1132 669 850 1912 1915 1916 1919 1921 1923 1925 1927 1930 1932 1934 1936 1939 1941 1943 1945 1948 1948 1949 1950 1951 1953 1955 MIDDLE GROUND SHOAL - E F _G OIL POOL -- -- _ Alias DATE All-01 19660930 All-01 19661031 All-01 19661130 All-01 19661231 All-01 19670131 All-01 19670228 All-01 19670331 All-01 19670430 All-01 19670531 All-01 19670630 All-01 19670731 All-01 19670831 All-01 19670930 All-01 19671031 All-01 19671130 All-01 19671231 All-01 19680131 All-01 19680229 All-01 19680331 All-01 19680430 All-01 19680531 All-01 19680630 All-01 19680731 All-01 19680831 All-01 19680930 All-01 19681031 All-01 19681130 All-01 19681231 All-01 19690131 All-01 19690228 All-01 19690331 All-01 19690430 All-01 19690531 All-01 19690630 All-01 19690731 All-01 19690831 All-01 19690930 All-01 19691031 All-01 19691130 All-01 19691231 All-01 19700131 All-01 19700228 All-01 19700331 All-01 19700430 All-01 19700531 All-01 19700630 All-01 19700731 All-01 19700831 All-01 19700930 All-01 19701031 All-01 19701130 All-01 19701231 All-01 19710131 All-01 19710228 All-01 19710331 All-01 19710430 All-01 19710531 All-01 19710630 All-01 19710731 All-01 19710831 All-01 19710930 All-01 19711031 All-01 19711130 All-01 19711231 All-01 19720131 All-01 19720229 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 939 904 831 795 776 798 469 719 878 836 809 731 746 787 746 650 670 642 705 638 624 596 596 598 549 526 486 470 517 514 485 396 402 362 346 312 299 326 245 282 455 454 438 423 453 414 414 407 444 431 431 425 423 442 422 417 412 407 394 390 384 380 370 373 343 345 381 324 295 270 272 274 239 250 368 397 300 381 265 230 191 172 214 215 193 228 234 216 226 165 198 212 198 184 205 187 184 162 150 152 212 125 124 137 104 133 225 216 211 200 228 202 202 218 213 208 217 226 213 221 215 212 208 202 198 195 195 190 185 185 150 180 21 6 4 0 0 0 5 0 1 4 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 0 1 2 1 1 0 1 3 1 1 1 1 1 1 2 2 2 2 2 2 2 2 2 2 1 1 1 1 1 0 11 0 406 359 355 339 351 343 510 347 419 475 371 521 356 292 257 265 319 335 273 357 375 363 379 277 360 402 408 391 397 363 379 410 374 420 612 400 414 420 425 470 494 475 482 473 503 488 487 535 480 483 504 532 504 500 509 508 505 496 502 501 508 500 500 496 438 522 6 34 58 82 104 125 138 159 187 212 237 259 282 305 328 348 369 385 407 426 445 463 481 500 516 533 547 562 577 592 607 619 630 641 652 661 670 680 686 694 708 720 734 746 760 772 785 798 811 824 837 851 863 876 889 901 914 926 938 951 962 974 985 996 1007 1017 MIDDLE GROUND SHOAL - E F _G OIL POOL Alias DATE All-01 19720331 All-01 19720430 All-01 19720531 All-01 19720630 All-01 19720731 All-01 19720831 All-01 19720930 All-01 19721031 All-01 19721130 All-01 19721231 All-01 19730131 All-01 19730228 All-01 19730331 All-01 19730430 All-01 19730531 All-01 19730630 All-01 19730731 All-01 19730831 All-01 19730930 All-01 19731031 All-01 19731130 All-01 19731231 All-01 19740131 All-01 19740228 All-01 19740331 All-01 19740430 All-01 19740531 All-01 19740630 All-01 19740731 All-01 19740831 All-01 19740930 All-01 19741031 All-01 19741130 All-01 19741231 All-01 19750131 All-01 19750228 All-01 19750331 All-01 19750430 All-01 19750531 All-01 19750630 All-01 19750731 All-01 19750831 All-01 19750930 All-01 19751031 All-01 19751130 All-01 19751231 All-01 19760131 All-01 19760229 All-01 19760331 All-01 19760430 All-01 19760531 All-01 19760630 All-01 19760731 All-01 19760831 All-01 19760930 All-01 19761031 All-01 19761130 All-01 19761231 All-01 19770131 All-01 19770228 All-01 19770331 All-01 19770430 All-01 19770531 All-01 19770630 All-01 19770731 All-01 19770831 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 313 357 355 399 352 369 343 323 356 330 377 404 404 306 378 384 413 366 415 407 509 448 447 435 452 454 430 448 445 469 516 511 522 491 474 510 496 505 506 519 499 497 491 477 476 480 481 487 494 488 503 498 480 480 499 480 485 483 477 478 454 511 502 500 514 483 170 278 185 101 217 140 160 146 159 172 184 184 154 161 181 158 364 312 151 146 209 170 198 187 163 205 206 223 186 206 211 210 210 212 205 213 207 206 215 212 208 210 202 195 197 199 202 225 228 224 226 225 917 226 225 157 127 163 130 352 75 204 189 214 220 207 1 1 2 2 4 1 11 10 4 2 4 1 1 1 2 2 2 2 0 1 1 0 1 1 1 0 0 2 2 2 4 2 2 2 3 4 3 3 3 2 3 2 2 2 4 5 5 5 5 5 5 2 2 2 3 2 5 2 5 5 2 5 3 3 3 6 542 780 520 254 616 379 467 451 448 521 488 455 381 528 479 412 881 853 364 358 411 381 444 429 361 451 480 498 418 439 409 411 402 432 432 418 418 408 425 409 417 423 411 408 413 414 420 462 462 459 449 452 1912 471 451 327 262 338 273 736 165 399 377 428 428 429 1027 1038 1048 1060 1071 1082 1092 1102 1113 1123 1135 1146 1159 1168 1180 1191 1204 1215 1228 1241 1255 1269 1283 1295 1309 1322 1336 1349 1363 1377 1393 1409 1424 1440 1454 1469 1484 1499 1515 1530 1545 1560 1575 1590 1604 1619 1634 1648 1663 1678 1694 1709 1723 1738 1753 1768 1782 1797 1812 1825 1839 1855 1870 1885 1901 1916 MIDDLE GROUND SHOAL - E F _G OIL POOL Alias DATE All-01 19770930 All-01 19771031 All-01 19771130 All-01 19771231 All-01 19780131 All-01 19780228 All-01 19780331 All-01 19780430 All-01 19780531 All-01 19780630 All-01 19780731 All-01 19780831 All-01 19780930 All-01 19781031 All-01 19781130 All-01 19781231 All-01 19790131 All-01 19790228 All-01 19790331 All-01 19790430 All-01 19790531 Ail-01 19790630 All-01 19790731 All-01 19790831 All-01 19790930 All-01 19791031 All-01 19791130 All-01 19791231 All-01 19800131 All-01 19800229 All-01 19800331 All-01 19800430 All-01 19800531 All-01 19800630 All-01 19800731 All-01 19800831 All-01 19800930 All-01 19801031 All-01 19801130 All-01 19801231 All-01 19810131 All-01 19810228 All-01 19810331 All-01 19810430 All-01 19810531 All-01 19810630 All-01 19810731 All-01 19810831 All-01 19810930 All-01 19811031 All-01 19811130 All-01 19811231 All-01 19820131 All-01 19820228 All-01 19820331 All-01 19820430 All-01 19820531 All-01 19820630 All-01 19820731 All-01 19820831 All-01 19820930 All-01 19821031 All-01 19821130 All-01 19821231 All-01 19830131 All-01 19830228 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (mD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 478 478 490 477 498 514 477 474 464 468 493 421 507 487 513 520 516 503 501 519 531 525 501 523 525 519 528 529 510 510 524 538 545 582 547 571 576 571 544 526 623 392 629 581 588 590 583 585 547 565 554 582 557 547 529 577 605 563 554 549 512 559 542 576 572 569 208 252 206 195 309 258 195 326 251 148 236 272 0 114 0 228 229 238 296 232 159 324 260 211 94 191 319 248 390 167 293 227 218 200 232 254 197 75 240 182 121 139 148 268 66 92 0 217 306 954 269 207 149 405 165 25 270 380 253 287 48 132 245 136 282 361 5 1 10 5 1 5 2 5 7 2 2 2 3 2 1 1 5 3 10 3 1 5 5 5 5 '5 5 5 8 5 0 5 5 6 6 6 6 6 3 3 5 216 6 6 3 3 12 12 5 6 6 6 6 11 11 12 4 6 11 6 5 12 6 12 6 12 435 527 421 409 620 502 410 689 540 317 479 647 0 233 0 438 443 474 591 448 300 617 520 403 179 368 605 468 764 327 559 422 400 343 424 444 342 132 441 346 193 355 236 461 113 156 0 371 558 1688 485 356 267 741 313 43 447 675 457 523 94 236 453 235 494 635 1931 1945 1960 1974 1990 2004 2019 2033 2048 2062 2077 2090 2105 2120 2136 2152 2168 2182 2197 2213 2229 2245 2261 2277 2293 2309 2325 2341 2357 2372 2388 2404 2421 2438 2455 2473 2490 2508 2524 2541 2560 2571 2590 2608 2626 2644 2662 2680 2696 2714 2730 2749 2766 2781 2798 2815 2834 2850 2868 2885 2900 2917 2934 2951 2969 2985 MIDDLE GROUND SHOAL - E F _G OIL POOL Alias DATE All-01 19830331 All-01 19830430 All-01 19830531 All-01 19830630 All-01 19830731 All-01 19830831 All-01 19830930 All-01 19831031 All-01 19831130 All-01 19831231 All-01 19840131 All-01 19840229 All-01 19840331 All-01 19840430 All-01 19840531 All-01 19840630 All-01 19840731 All-01 19840831 All-01 19840930 All-01 19841031 All-01 19841130 All-01 19841231 All-01 19850131 All-01 19850228 All-01 19850331 All-01 19850430 All-01 19850531 All-01 19850630 All-01 19850731 All-01 19850831 All-01 19850930 All-01 19851031 All-01 19851130 All-01 19851231 All-01 19860131 All-01 19860228 All-01 19860331 All-01 19860430 All-01 19860531 All-01 19860630 All-01 19860731 All-01 19860831 All-01 19860930 All-01 19861031 All-01 19861130 All-01 19861231 All-01 19870131 All-01 19870228 All-01 19870331 All-01 19870430 All-01 19870531 All-01 19870630 All-01 19870731 All-01 19870831 All-01 19870930 All-01 19871031 All-01 19871130 All-01 19871231 All-01 19880131 All-01 19880229 All-01 19880331 All-01 19880430 All-01 19880531 All-01 19880630 All-01 19880731 All-01 19880831 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 545 594 560 550 603 577 560 566 609 548 469 554 559 517 556 542 524 565 536 551 546 541 501 489 536 513 527 508 494 508 500 506 538 485 450 439 353 496 485 494 476 456 457 449 468 475 490 467 449 462 448 454 442 426 426 422 442 450 427 425 433 419 415 412 390 403 257 314 216 194 384 163 324 241 238 257 74 151 206 0 188 207 216 115 301 825 233 229 238 250 218 205 220 228 92 116 107 135 369 242 103 92 59 87 84 138 128 131 133 123 120 100 106 113 113 119 134 136 149 127 95 154 173 156 155 146 161 158 151 151 136 140 6 0 6 7 3 3 6 3 6 3 5 8 3 3 8 1 1 3 3 3 3 2 2 2 2 3 4 3 1 3 2 2 3 0 3 3 2 2 4 2 2 2 2 2 2 2 3 3 3 3 2 2 6 5 3 3 3 2 3 3 2 3 3 4 3 3 471 529 385 352 636 282 579 425 392 468 157 272 369 0 338 382 413 203 561 1498 428 423 476 510 407 400 418 449 187 228 214 268 685 5OO 228 210 167 175 173 279 270 287 290 273 256 210 216 241 252 256 298 299 336 299 224 364 391 345 363 343 371 376 364 367 350 349 3002 3020 3037 3054 3072 3090 3107 3125 3143 3160 3174 3191 3208 3223 3241 3257 3273 3291 3307 3324 3340 3357 3372 3386 3403 3418 3434 3450 3465 3481 3496 3511 3528 3543 3557 3569 3580 3595 3610 3625 3639 3653 3667 3681 3695 3710 3725 3738 3752 3766 3780 3793 3807 3820 3833 3846 3859 3873 3887 3899 3912 3925 3938 3950 3962 3975 MIDDLE GROUND SHOAL - E F _G OIL POOL _ -- -- Alias DATE All-01 19880930 All-01 19881031 All-01 19881130 All-01 19881231 All-01 19890131 All-01 19890228 All-01 19890331 All-01 19890430 All-01 19890531 All-01 19890630 All-01 19890731 All-01 19890831 All-01 19890930 All-01 19891031 All-01 19891130 All-01 19891231 All-01 19900131 All-01 19900228 All-01 19900331 All-01 19900430 All-01 19900531 All-01 19900630 All-01 19900731 All-01 19900831 All-01 19900930 All-01 19901031 All-01 19901130 All-01 19901231 All-01 19910131 All-01 19910228 All-01 19910331 All-01 19910430 All-01 19910531 All-01 19910630 All-01 19910731 All-01 19910831 All-01 19910930 All-01 19911031 All-01 19911130 All-01 19911231 All-01 19920131 All-01 19920229 All-01 19920331 All-01 19920430 All-01 19920531 All-01 19920630 All-01 19920731 All-01 19920831 All-01 19920930 All-01 19921031 All-01 19921130 All-01 19921231 All-01 19930131 All-01 19930228 All-01 19930331 All-01 19930430 All-01 19930531 All-01 19930630 All-01 19930731 All-01 19930831 All-01 19930930 All-01 19931031 All-01 19931130 All-01 19931231 All-01 19940131 All-01 19940228 0il Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 413 416 417 424 412 416 421 401 418 417 415 422 404 419 414 370 457 401 414 409 424 394 341 390 379 404 426 394 376 413 396 411 398 420 385 406 373 367 384 364 376 389 376 373 395 368 370 374 348 347 354 362 351 345 323 353 362 338 350 339 335 317 356 402 332 316 140 144 151 134 137 143 131 111 129 143 136 127 127 126 128 133 130 126 132 135 153 134 124 143 141 134 143 143 161 153 135 133 128 129 121 127 122 122 127 121 110 108 123 98 121 111 102 72 76 64 57 55 50 48 44 83 87 87 84 86 83 75 73 87 87 78 4 2 3 3 5 4 5 7 7 6 9 6 6 8 9 9 10 11 10 8 12 11 7 8 10 10 10 9 10 14 15 12 17 14 14 13 14 14 14 15 16 14 15 15 18 17 14 15 14 15 15 17 18 16 19 19 19 12 19 19 16 19 16 17 19 14 339 346 362 315 332 344 312 277 308 343 327 302 314 3O0 309 359 284 315 319 331 361 340 363 365 372 333 335 364 427 371 342 323 320 308 314 313 328 333 331 333 293 278 328 263 307 300 277 194 219 185 160 151 143 140 136 237 239 257 240 255 247 237 206 217 261 247 3987 4000 4013 4026 4038 4050 4063 4075 4088 4101 4114 4127 4139 4152 4164 4176 4190 4201 4214 4226 4239 4251 4262 4274 4285 4298 4310 4323 4334 4346 4358 4370 4383 4395 4407 4420 4431 4443 4454 4465 4477 4488 4500 4511 4523 4534 4546 4557 4568 4579 4589 4601 4611 4621 4631 4642 4653 4663 4674 4684 4694 4704 4715 4727 4738 4747 MIDDLE GROUND SHOAL - E F _G OIL POOL Alias DATE All-01 19940331 All-01 19940430 All-01 19940531 All-01 19940630 All-01 19940731 All-01 19940831 All-01 19940930 All-01 19941031 All-01 19941130 All-01 19941231 All-01 19950131 All-01 19950228 All-01 19950331 All-01 19950430 All-01 19950531 All-01 19950630 All-01 19950731 All-01 19950831 All-01 19950930 All-01 19951031 All-01 19951130 All-01 19951231 All-01 19960131 All-01 19960229 All-01 19960331 All-01 19960430 All-01 19960531 Ail-01 19960630 All-01 19960731 All-01 19960831 All-01 19960930 All-01 19961031 All-01 19961130 All-01 19961231 All-01 19970131 All-01 19970228 All-01 19970331 All-01 19970430 All-01 19970531 All-01 19970630 All-01 19970731 All-01 19970831 All-01 19970930 All-01 19971031 All-01 19971130 All-01 19971231 All-01 19980131 All-01 19980228 All-01 19980331 All-01 19980430 All-01 19980531 All-01 19980630 All-01 19980731 All-01 19980831 All-01 19980930 All-01 19981031 All-01 19981130 All-01 19981231 All-01 19990131 All-01 19990228 All-01 19990331 All-01 19990430 All-01 19990531 All-01 19990630 All-01 19990731 All-01 19990831 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (PD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 310 248 296 306 3O8 257 261 274 269 253 244 221 194 178 140 136 130 116 111 112 117 118 117 105 112 113 108 101 96 92 99 87 96 95 91 83 96 87 95 96 94 103 97 101 97 91 84 75 76 64 74 73 75 70 71 68 64 61 59 64 46 47 55 51 56 52 63 49 62 74 59 49 52 47 89 45 39 87 3O 39 25 29 25 19 14 17 23 17 20 18 56 39 32 20 26 12 29 25 26 17 31 37 42 50 65 58 74 65 68 79 64 64 70 65 82 89 69 79 79 79 91 108 92 96 93 98 72 171 139 103 118 139 18 26 16 16 16 15 17 18 20 17 29 16 15 12 14 15 13 12 12 12 12 12 12 11 11 7 7 8 12 15 0 20 13 12 17 19 25 14 13 14 15 13 18 19 19 18 19 18 17 19 17 16 16 16 18 17 13 18 15 16 17 19 13 21 19 20 203 199 210 240 190 190 198 171 331 177 162 394 154 220 180 212 194 163 124 152 200 142 172 175 496 340 299 196 269 131 288 292 275 183 340 447 442 577 689 611 789 632 696 781 654 704 833 875 1084 1391 931 1069 1054 1131 1286 1579 1431 1586 1584 1543 1572 3606 2518 2003 2113 2683 4756 4764 4773 4782 4792 4800 4807 4816 4824 4832 4839 4845 4852 4857 4861 4865 4869 4873 4876 4880 4883 4887 4891 4894 4897 4900 4904 4907 4910 4913 4916 4918 4921 4924 4927 4929 4932 4935 4938 4941 4944 4947 4950 4953 4956 4959 4961 4963 4966 4967 4970 4972 4974 4976 4979 4981 4983 4985 4986 4988 4990 4991 4993 4994 4996 4998 MIDDLE GROUND SHOAL - E F _G OIL POOL _ -- -- Alias DATE All-01 19990930 All-01 19991031 All-01 19991130 All-01 19991231 All-01 20000131 All-01 20000229 All-01 20000331 All-01 20000430 All-01 20000531 All-01 20000630 All-01 20000731 All-01 20000831 All-01 20000930 All-01 20001031 All-01 20001130 All-01 20001231 All-01 20010131 All-01 20010228 All-01 20010331 All-01 20010430 All-01 20010531 All-01 20010630 All-01 20010731 Oil Gas Water Gas Cum Rate Rate Rate Oil Oil (mD) (PD) (PD) Ratio Prod bbl/d Mcf/d bbl/d cf/bbl Mbbl 50 45 106 44 54 50 48 49 51 72 55 56 50 49 48 51 45 0 0 0 0 0 0 113 116 154 94 82 132 103 87 99 146 96 82 75 93 77 78 96 0 0 0 0 0 0 16 25 4 10 19 23 9 17 17 18 15 11 16 13 11 11 12 0 0 0 0 0 0 2263 2544 1448 2168 1520 2626 2163 1794 1928 2023 1740 1473 1512 1894 1613 1530 2162 4999 5000 5004 5005 5007 5008 5010 5011 5013 5015 5016 5018 5020 5021 5023 5024 5026 5026 5026 5026 5026 5026 5026 Nm~e of Operator STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT U'--~t~ or Le~se Nar~, , Field and Pool "~-~:C~" IDatum ReferenceI Oil Gravity IGas Gravity ~ Final Pre.ute Test Data Pr~] :ion and Test DaTa APl ~ ~ Date Shut-in Shut-in T6°l Final PRODUCTION RATES Liquid Wt. of Wt. of Casing Pressure Nell Name and No. Number ~ ~ Tested Time Tubing Depth B.H. Ob~r~d (Bbb. per Day) (Mcfdl ~adient Liquid Gas Pr~sure at ~_ O ~ Pressure MD Temp. Pr~sure ~Oil Water G~ Column Column Datum ,. ,, ~-. ~:.,,,~ ,, , her~ify ~oing is true and corr~t to the best of my knowl~ge. orm 10-412 L S,Jhr,nil in I'),~nlir~Ip STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RESERVOIR PRESSURE REPORT Name of Operator IAddre. Final Pre~ure Test Data Produ~!ion and Tes.t Da. ta APl ~ ~ Dale Shut-In Shut-In T°ol Final PRODUCTION RATES Liquid ;Wt. of Wt. of Casing Pressure Nell Name and No. Number ,= ~ Tested Time Tubing Depth B.H. Observed (Bbb. per Da.y) (Mcfd) Gradient Liquid Gas Pressure at 50- O L~ Pressure MD Temp. Pressure Oil Water Gas Column Column Datum $ ti-O! Lu · , .... ,, i::::¥~ ~the ~°lng is true and correct to the best of my knowledge. TitIe'"~"~- ~',.'3,_3;~%~I.-,~,-~'''r'~ ~ O- , ' orm 10-412 ~,v 7-I RO Submit in D~plicate MEMORANduM TO: THRU: State ot , laska Alaska Oil and Gas Conservation Commission DaVid Johnst~t~ Chairman'"-~'~ Blair Wondz~ P. i. SuPervisor/~7~ FROM: Bobby Fost~'-~ SUBJECT: Petroleum Ingpector DATE: April 21, 1994 FILE NO: 9V31DUBD.doc No Flow Test Shell - MGS - A11-1U&P Platform A Cook Inlet Thursday, April 21, 1994: I traveled this date to Shell's Platform A and witnessed the "No Flow Test" on well A11-1 Upper and Lower strings of tubing. I arrived at the platform and met with Tom Reese, Shell rep., and discussed the testing of the well. Tom said the gas lift had been shut off of the well at 8:00PM - 4- 20 - 94 and the well had been flowed to the test separator until 5:00AM. At this time the separator back pressure had been bled down to 4 - 5 psig. At 9:00 AM I went to the well room and checked all the valves tree to be sure they were open. I saw that the casing still had 480 psig on it. I then went to the test separator and checked all the valves on it. i requested that the fluid dump line be closed off and the gas vent be shut. I began The MIT's on 2 other wells, the subject of another report, and let the well stay shut in for 1 hour. The pressure on the separator now was 40 psig. I requested that the fluid and gas dumps be opened on the separator and the pressure be bled down to 4 - 5 psig - the back pressure on the flare system. After the well - both upper and lower strings were bled down a 1" hose was hooked up to the tree cap and the well was bled to atmosphere. After approximately 15 minutes the gas pressure seemed to be getting higher; I told Tom that he would have to bled the pressure off the casing. I felt that the gas was leaking by the tubing hanger but I wanted to be sure that it was not coming from the formation. The gas was bled off of the casing and a gauge was installed on the swab valve and after being shut in for 30 minutes the pressure read 3 psig on both strings. I recommend to the Commission that this well be classified in the" No Flow status on both the upper and lower strings. Summary: I witnessed the successful "No Flow Test" on Shell's MGS well A11-1- upper and lower strings. Shell Western E&P Inc. O 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 June 11, 1990 Alaska Oil and Gas Conservation Commission ATlN: Elaine Johnson 3001 Porcupi ne Drive Anchorage, Alaska 99501 SUBJECT: TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. Johnson' In a recent telephone conversation you discussed with Ms. Susan Brown-Maunder information that would be helpful to you if we could provide it. Enclosed, for your convenience and use, are the following: 2 location surveys showing the location of Platform A 1 list of conductor/well locations (in relation to the SE corner of Sec. 11, TSN, R13W) for Platform A wells I location survey showing the location of Platform C 1 list of conductor/well locations (in relation to the SE corner of Sec. 23, TSN, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion Report and Log (10-407) for the recently completed well C21-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly/Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc' Susan Elsenbast-AOGCC \LETTERS\AOGCC \061~ 190. DOC RECEIVED MIDDLE GROUND SHOAL Platform "A" WELL/CONDUCTOR LOCAIIONS ~- Center of Leg I @ 1627'N & 435'W from SE corner of Sec.11, TSN, R13W, S,M. ~ ~ A 12-01 1 A 11-01 2 A 43-11 3 A 34-11 ~ 4 A 34-14 RD 5 A 22-14 6 A 12A-01 7 A 13-01 8 1632'N & 437'W from SE corner 1632' N & 432' W " " " 1630'N & 430'W " " " 1625'N & 430'W " " " 1622'N & 433'W " " " 1622'N & 437'W " " " 1625'N & 440'W " " " 16 30' N & 440' W " " " Leg 2 - Center of Leg 2 @ 1681'N & 372'W from SE corner of Sec. 11, T8N, R13W, S.M. A 42-11 9 A 44-O2 10 A 42-14 11 A 41A- 11 12 A 11-12 13 A 11-13 RD 14 A 31-14 15 A 44-11 16 1685'N & 374'W from SE corner 1685'N & 370'W " " " 1683' N & 368' W " " " 1678'N & 368'W " " " 1675'N & 371'W " " " 1675'N & 375'W " " " 1678'N & 378'W " " " 1683' N & 378'W " " " Leg 3 - Center of Leg 3 @ 1620'N & 321'W from SE corner of Sec. 11, T8N, R13W, S.M. Leg 4 - Center of Leg 4 @ 1566'N & 383'W from SE corner of Sec.11, T8N, R13W, S.M. A 33-11 25 A 14-01 26 A 12-12 27 A 24-01 28 A 13-12 29 A 33-14 30 A 41-11 31 A 23-01 32 1571 1571 N & 381'W 1568 N & 378'W 1564 N & 378'W 1561 N & 381'W 1561 N & 385'W 1559'N & 388'W 1569'N & 388'W N & 385'W from SE corner II 11 II II II II II II II II II II II II II II II Oil & G~s t~ons. G~mmlssion Anchom~ SBBC/mgs A ! TgN S.M. I [ I ' ' ' "i'~h' o: · · · · · · · · · ~ ADL 18754 . ~ - ........... , .... i = i , ~ . 9 I0 - " II II 7 . t,,. ,o-,,' ,,..oc ~ : g . ~TlTE G~ID COOED. 37 .; I ZONE 4 ,..,..~..., .... ,''* .' ~ - _ Zl Zt t~ -' - ~4 19 20 . . . ~r · ,~ ~ ~' " ....... .,., , t6 2T ~ 26 " Zg 30 · · . ~... .. ..... , ..... ',., * . ,,. ~ ., ,,q 33 34 35 36 31 32 VtP ' , .. ; ~ : :;. LOCATION OF ' -'JU~ ~ 19~] SE~ CONTAINEO DRILLINO ~ -",l~o. ~ii & Gas Con~. ( remission P R 0 O U C I N 0 P L =,T F O R M ...... = T.~8_.N .... S.M.: _ : _~ gflchora~. _ ____ SHELL r,II~DLE GFi~,~[~D SHOAL , a T 7N S.M., t I PLATFORM COOK INI ET. ALAS,,A ! 4003 eooo ~oo0 APPLICATION BY SHELL OIL CO. .... "~ .............. '--- '' LOS ANGELES~ CALIFORNIA ~ T. 8N. R 13W. S M 5 2 ' ' ' ' ' ADL 14 I0 I I _ _F i__e 7_5~ _ _, I I i I '~ I I I I I l I I LEG NO. ! LEG NQ 2 LEG NO. :3 LEG NO. 4 PLANE X : 232,785 X: 2:32,846 Y = 2,485,845 Y = 2,485,897 C OOED/N,~ TEE X: 2:52,896 Y = 2,485,8:55 X = 232,833 Y: 2,485,783 1627' N I~ 435'W FROM THE SE COR. OF SEC. II,TBN, RI3W, SM. PUBLIC /.AND 1681' N P~ 372' W FROM THE SE COR. OF SEC. II, TBN, Ri3W, SM. D E$ Ct?'I P 7~ I ON 1620'N 'l~ 321' W FROM THE ,SE COR. OF SEC. II, T8N, RI3W, SM. 1566'N I~ 383'W FROM THE SE COR. OF SEC. II, TBN,RI3W, S.M. GEODETIC COORDINA TE$ LAT.- 60047'44.839" LAT.-60°47'45.:56B'' LAT.-60°47'4~.7G8'' LAT.- G0°47'44.244'' LONG.- 151° 29'45.112'', LONG.-151°29' 4:5.942" LONG.-151° 29' 42.~899'' LONG.' 151°29' 44.154" $"P.~$rDE$ Z-41-,'9-I ' ..... ' ~ ELL ~'; ^ "" "' , .t~.:..., .! ,r J] CJ '-' ,,r- -, ,~.c,,_u 'bY ~.,,. ~--. i! SH · '.~ , li-ii,,,:r~ ,,;,; ,~., ,~.~ ~ , Z- 4 1 0 - 2 -~ .~ ~ ALASKA DEPARTMENT ~ NATURAL RES~ES Dt¥-~ISION OF OiL AND OAS DATE "January 8, 19'/4 FROAA~ John C. ~ltlter ~C~ Petro I eum Eng t neet SUBJECT: DO~I~4HO[F RT('~::t~ CHOKE FA 1 LURES, /~' '- SHELL~ PL~TFOR~~', WELL / ~'~- November i, t97~.- A platform in.spec~ton, on Shell's l~gS l~tlatform "^" found the T~" "H" -~c~rm 'Choke ! n -Well No. t I-1 fo'-../eak .very s I I ghf I y. A I so, the Type "H" si'om ~ke ta. Wel I No~ f;5-t U~per fall{ed fo close and the Type "K" sform choke in 't~eil No. 43-1I-failed fo close. ~r 26.,.. 19'/3- B~b Grote, ~latform "A" foreman, called and advised me ~l~e¥ had pal ted ~he S~o~ c~ o~ of ~--t I ~. 11 - t, ~a t red I t, a~d ~n~ 1~ tn ~he wel 1, That s~ choke n~ o~tes p~perly ~It~u? l~klng. ~ at~ pulled ~he s~ cho~ fr~ Well ~. 13-1 Upper, repaired I~, reran It and ~? n~ ~era~es pr~erly. ~ Type 'K" sto~ c~ In ~It ~, 43-11 ~s pulled, cl~n~, and r~n. t~ ~~ lrra~Ically and therefore ~s pul led a ~~ tl~. T~ s~ c~ ~.¢te~ed, c~ked and rerun. Agaln It Wemf~ i r~flcal l y a~ ~ pul. l~ a third t l~. The choke was sen~ to only ~a~lal closure. Pa~s for th~s T~:~-' s~ ¢~km were orde~ by air ~ ~~er t6, I973. ~ ~~r 28, I g73 - ~b Gr~f~ ~aln ~ 1 ted ~o gl ve ~ a report on the Type T~: pa~s ~re r~et~d a~ f~.-~tr~ ~oke ~as Instal led In the well on ~c~er 21, 197~, It ~-..f~d ~d i~ o~~d p~pec. IY. On D~ber 24, 1973, the ~l-~;;clos~ durt~a..~i~ platfo~ shut-In but ~uld ~f On ~~er 25, 1973, ?h~s ~ "K".sfo~ c~ke was a~ln pulled fr~ ~he ~e~l and when disass~te~ If ~s found that fha pin ~ had ~usf b~n rep~ac~ was ~broken ~ain. ~, .~ T~ "~' sto~ c~ repl~nfs have been ordered for ~hts well. ~b ~ill advl'~ ~ .~n these a~l~ and one Is Installed so I can witness Its ~afion. Alas~,., Oil and Gas Conservation Commi~._ '.,;e Field Inspection Report ~/,~',~/,.t ~1~q~' e~. Drilling Perait Well Name & No. "~'A~a,I .O/a'~C.,.~.. 'N° Number Inspected by t~/[~,//~'F Operator's Rep..~_~j~ ~/,~ l o c (~,- _ Contr. Rig No. - S~tisfactory Item Satisfacto~ Item Y~' No Yes No ('~ ( ) 1. Well Sign ~ _ . ( ) '"(~i) ,(~) 2. Safety Valves-~'' () ¢') ..,, ~,;,'. ( ) 3. Safety Valves-Kelly ( ) (~!.;) ,i...',";'(~) 4. Safety Valves-Subsurface ( ) () () () () () ( ) 5. BOP Closing System ( ) 6. Remote Controls ( ) 7. Drilling Spool-outlets ( ) 8. Flor Lines ( ) 9. Kill Lines ( ) 10. Manifold Chokes ( ) 11. Hanifold Pressure Test ( ) 12. BOP Pressure Test ( ) 13. Reserve Pit ( ) 14. Pit Berm ( ) 15. Location Berm ( ) 16. Fuel Berm ( ) 17. Operations off "Pad" ( ) 18. "General Housekeeping" ( ) 19. Abd. Marker in place ( ) 20. Water Well covered SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE. ALASKA 99501 October 24, 1966 State of Alaska Division of Mines and Minerals. Oil and Gas Section 3001 Porcupine Drive Anchorage, Alaska Attention Mr. T. R. Marshall, Jr. Gentlemen: Please find enclosed the following information pertaining to our well Middle Ground Shoal A-il-l: 1. Well Completion Report - submitted in duplicate 2. Well History RI: m · 4. Eastman Single-Shot Directional Survey Composite Dual Induction Laterolog, 2"/100' - 1 print and 1 sepia Very truly yours, Division ~roduction Manager Enclosure Form P~7 ~ SUBMIT IN DUPLIC~* STATE OF ALASKA (See other~h: structions on OIL AND GAS CONSERVATION COMMISSION reverse ~ide) WELL COMPLETION OR RECOMPLETION REPORT AND LOG * la. TYPE OF WELL: WELLOIL ~ ~v~S~L [~] DRY ~] Other b. TYPE OF COMPLETION: NEW ~ WORK[] DEEP- ~] PLUG [~ DIFF. ~] WELL OVER EN BACK IIESVR. Other 2. NAME OF OPERATOR Shell 0il Company 3. ADDRESS OF, O~rRATOR 430 Seventh Avenue, Ancho.rage, Alaska 4. LOCATION OF WELL .(Report location plearly and i~ accordance with any ~tate requirements) * ~tsurface 4.97' N & 2.54' E of center Leg 1. Leg 1 @ 1627' N 435' W from SE corner, Sec. 11, T8N, R13W, S.M. At top prod. interval re~orted below 6806.82 N & 1106.50' E from surface At total depth - 8432.09' N & 1966.15 ' E I 14. PERMIT NO. DATE ISSUED from surface I 66-29 I 6-27-66-~ 15. D~TE SPU~'DED~' 16. DATE '~.D~ REACHED [ i'7. DATE COMPL. 6-28-66 9-6-66 ] 9-24-66 Effective: July 1, 1964 5. LEASE DESIGNATION AND SERIAL' NO. State ADL 18754 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 'None 7. UNIT AGREEMENT NAME None S. FARM OR. LEAS~ NAME Middle Ground Shoal 9. WELL NO. MeGeS. A-11-1 10. FIELD AND POOL, OR WILDCAT :Middle Ground Shoal 11. SEC.., T., a., M;, OR BLOCK.AND SURVEY OR AREA 1, T8N, R13W, S.M. ELEVATIONS (DF, RKB, RT, GR, ETC.)$ D.F. @ ~116." 1.2. BOROUGH [ 13. STATE Ke~ai [ Alaska .II 19. ELEV. CAS~NGHEAD 20. e0rAr~ Dm'tH, ~0 & ~ro )]] 21. PLUG, BA~K T.D., MD & ~ 113,238' (9198' 13,152' (9118') 22. IF MULTIPLE COMPL., 23. IN~ERYALS ROTARY TOOLS HOW MA~Y* DRILLEDBY >. 13,238 ' 24. PRODUCING INTEI~VAL(S), OF THIS COMPLETION~OP, BOTTOM, NAME (MD AND T~D)* CABLE TOOLS WAS DIRECTIONAL 9562' (6058')-10,047' (6423')and SURVEY MADE 1:0,893' (7125')-13,130' (89098') 26. TYPE ELECTRIC AND OTHER LOGS RUN DIL, BHC, CDM, EL, GRN, CBL Yes 27. WAS WELL CORED No 28. CASINO SIZE WEIGHT, LB./FT. 1'3-3/8 61 9-5/8 40-47 CASING RECORD (Report all strings Set i~ well) DEPTH SET (MD) HOLE SIZE CEMEI~TING RECORD · . 2625 ' 18-1/2" 3400 sxs'. 10,647 ' 12-1/4" 1250 sxs. AMOUNT PULLED 29, LINER RECORD SIZE TOP (MD) ~ BOTTOM (MD) 7 10,505' 13,238' PERFORATION RECORD (Interval, size and number) See Reverse Side SACKS CEMENTs 5OO SCREEN (MD) 82. 30. . TUBING RECORD SIZE [DEPT~ SET (MD) PACKER 'SET (MD) · · 2- 7/8' 13,051 ' 2-7/8 -' 10'391' ' · 9~491' 9 ~49;5 ' ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH 'INTERVAL: (MD) J AMOUNT AND KIND 0r MATERIAL USED 10'505~ I 100 sacks 10,850' 50 sacks PRODUCTION' _UpperDATEFIRST PRODUCTION9- 25- 66 [PRODUCTIONMETHOD('FtOw'ing~gaslift~)umj~ing-stzeand~yj~e°f~3'~). flowing , IwELLSTATUS(Pr°duel~tg°rshut-tn) Lqwer 9-26-66 flowing Producing OI~BBL. GAS~MCF. OIL GRAVITY-AP1 WATE%~BBL. I 2 __ ~ FIIlW. TUIING Pl~$S. ] CASING PRESSURE I CALCULATED 100 [ 750 I 24-HOUR GATE 90 960 ' 34. DISPOSITION OF. Gas (BOld, used ]or fuel, vented, etc.) Vented 883 391 1028 I 382 3§. LIST OF ATTACHMENTS ~'T 2t~ 19~6 Well History, Directional Survey, Composite L~g. 36. I hereby certify that the.foregoing and attached information is complete and correct as determined fr~e~L~.v, atla~le.r.eaordi Engine~~~~ __ -- -.~,3 ~(__'" . - .~~__ . ' .. *(See I.slruclio.s g.d Spaces [or idditio.al D~o o. Reverse Side) INSTRUCTIONS . General: This form is designed for submitting a complete and correct well completion report and log on all types or bo~h,:purSuant to applicable Federal and/or State laws and regulations. Any necessary special instructions concerning the use:of this form and the number of copies t6 be submitted, particularly with regard to local, area, or regional procedures and practices, either are shown below or will be issued by, or may be obtained from, the local Federal andf~r- ~ate office. %~_.,~e instructions on items 22 and 24, and 33, below regarding separate reports for separate completions. If no~filc~l prior to th~' time this summary record is submitted, copies of all currently available logs (drillers, geologists, sample and core analysis, all types electric, etc.), forma- tion a~hd?press~Xe tests~.and directional surveys, should be at.tached hereto, to the extent required by applicable Federal and/or State laws and regulations. All attachments shou~.'-.b9 listc~fon this. form, see item 35. ' -- Ifem3:.' If. there' are no applicable State requirements, locations on Federal or Indian land should be described in accordanc~ with Federal requirements. Consult local State or Federal offi .c~ for specific instructions. ~ ' Ifem ]8: ;~Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in othe~ spaces on this form and in any attachments. Hems 22 '~nd 24~ If this well is completed for separate production from more than one interval zone (multiple completion)', so state in item 22, and in ite~n 24 show the producing interval, or intervals, t.op(s), bottom(s) and name(s) (if any) for only the interval reported in item 33. Submit a separate report (page) on ~ form, adequately identified, for each additional ifi't~rval to be separately produced, showing the additional data pertinent to such interval. ' · ISem 2~: ~$ack~.'~.Cem~m/~": Attached supplemental records for this well should show. the details of any multiple stage cementing and the location of the cementing-tool. Hem ~]: 'Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 22 and 24 above.) '_'~ --I , ' - - - ' · ~1 P~rforation Record. (4/ft) 9562-9637' 9670-9760' 9807-9833' 9930-9955' 9972-10,047' 10,893-10 910' 11,372-11,419' 11,688-11,700' 11 706-11 716' 1'2 053-12 138' 12,158-12,181' 12~195-12,512' 12 538-12,586' · ~ 12,616-12,854' 12 905-12 970' 12 990-13,005' 13 063-13 081' 13 094-i3 110' 13 116-13 130' -37. SUMI~IARY OF POROUS ZONES: '" ......... ~ SHOW ALL IMPORTANT ZONES OF POROSITY AND CONTENTS THmREOF; CORED INTERVALS; AND ALL DRILL-STE]~I TESTS, INCLUI~ING 38. ~ GEOLOGIC MARKERS ' DE~H INTERVAL TESTED, CUSHION USED, TIME TOOL OPEN; .FLOWING AND SHUT-IN PRESSURES, AND RECOVERIES .. FOR~IATION 'TOP~ BOTTO~ ' ~ · DESCRIPTION, CON~ENTS, ETC. ,. . TOP ~ ~.. ~ . . . ~ ~ .. . :. ~ MEAS. DEPTH TRUE VERT. DEPTE ~ .. ;. ~,. '. . . .-. . ~ ~ - :~ .~ · , .~ · .. · ~- . . .. ~ · ~ . . . ~ ~ ' . -- .. .. '. ~... ~,~ .-. .. ~ ~ ~ ~., .. . , . ,. -. , 'PD-4,~, (l~e,v. 5-63) Printed In U.S.A. Middle ,~roun,d, ,8hoa~,!. (FI£Lr'JJ' (COUNTY) SHELl. OIL CO~PANY DRH,LING I PORT 8-5-66 1 (.-cTIo# on kt*.t) ,,, ~8N~, .~13W~,. $.~ .... C'rOWNIHIP OR 'RANCHO).' Dr. PTH8 REMARKI Surface Location: Conductor 2, 4.97' N & 2.54' g from Center Leg #1. Leg #1 at 1627' N & 435' W from SE Corner, Section 11, Township 8 North, Range 13 West, Seward Meridi'an. Depth Reference: Derrick Floor at 116' (MLLW) 1966 326 1012 Rigged up over c0ndu~tor 2, leg 1. Drilled cement 318-326'. Drilled hole to 609'. Ran SCHLUMBERGER ELECTRIC LOG~ .RUN 1~ 317-604' · Drilled to 1012'. Ran Sperry Sun' Gyroscopic Survey 0-1005'. 1012 1478 Drilled 466'. 1966 1478 2800 Drilled 597'. Faced turbodrill N4OW, drilled 1738-1757'. Drilled to 2800 2800 CEMENTED 13-3/8" CASING AT 2625' WITH 3400 SACKS CLASS A CEMENT. Ran 13-3/8", 61#, J-55 Buttress casing with Baker float shoe at 2625' and fill up collar at 2582'. Bumped plug with 1000 psi. No returns to surface. Ran 1-1/4" pipe in annulus to 352', cemented with 600 sacks Class A cement mixed with sea water. Good returns throughout. T~sted wellhead OK with 3000 pst. 28O0 4920 Flanged up B.O.Pi.E., tested blind rams OK at 1500 psi for 15 minutes. Ran in with ~2-1/4" bit, found top of cement at 2558', drilled cement to 2600'. Drilled to 4920'. 4920 5OO9 Drilled 89'. Pin in cross-over sub broke, left fish in hole - consists of bit, float sub, stabilizer, monel, drill collar and cross over sub. Ran in with Bowen overshot, recovered fish. 5009 9846 Drilled 12-1/4" hole to 9846'. 9846 Drilled 12-1/4" hole to 10,490'. IIZI 18~" 12~" HOLE CONDITION AT Oil PERIOD DEP'rH lEI' 0T3-3/8" 2625' DRILL PIPit 9.5# RECE, IV[D OCT 1966 DIVISION gF MINE~i & MINI~tIAi,J ANOiO~GE , . IICINED PD 4A (Rev: 5-63) P~inted in U.S.A. , ,"'~'~ SI~[.I'- OIL CO)~)dl~ ' ~ w=L~.o A-11-1 .{ .... Middle Ground Shoal D~~G ~PORT ~' Cook. [n[e~ 9-2-66 ~8~; .... (COUNt) ' - - ' "- .......... -~ -- REMARKS FIIOM I TO ~.ugust, 1966 tC,ont'd 6 10,490 10,508] Drilled 18'. Ran Sperry Sun magnetic multishot survey in drill pipe at 10,497'. Ran Schlumberger logs: ~DUAL IN~)..UCTION..LATEROLO.G~..R.I?'~ I, 2611-10~482'~ ..... and BOREHOLE COMPENSATED SONIC LOG~ RUN 1~ 770 )-'~__!_!.!,.,?,,'.'"' Drilled ahead to 10,508'. 7-8 10,508 10,647 Drilled to 10,647'. 9 10,647 Ran logs: DUAL INDUCTION-LATEROLOG~ RUN 2~ 9300-10~647' AND BOREHOLE ,, , , ,, , , ,, ,, ~ , ,, COMPENSATED SONIC LOG.,. RUN 2~ 10~47.6-10~636.'. 10 10,647 CEMENTED 9-5/8" CASING AT 10~647' WITH 1250 SACKS CLA~S G CEMENT. ~an 10,668", '9'-5'/8" c'a~i'ng""('top 83'",' 47~' N-80; 720'7', 4'0~',' N-80'; 2216' 43 5# N-80; '1162' 47#, N-80) with shoe at 10,647' , · , ~ 11 10,647 Flanged well head, installed BOPE. Tested blind rams OK with 2000 psi. Made up drilling assembly. Had bit, monel, 3 drill collars, bumper sub and 35-1/3 stands pipe made up. Slips tripped, dropped assembly in hole. 12 10,647 10,673 Ran in, screwed into fish, recovered same· Ran in with 8-1/2" bit, found top of cement at 10,480'· Drilled to 10,561'. Tested pipe rams OK with 2000 psi, Hydril OK with 1000 psi. Drilled out shoe at 10,647'. Drilled 26'. 13 10,673 10,700 Ran Sperry Sun Gyroscopic survey on sand line. Drilled 27.'. 14-31 10,700 12,831 Drilled 8-1/2" hole to 12,831'. Septe~ber, 1~ 56 . 1 12,831 12,931 Drilled 100'. 2 12,931 Ran logs': DUAL INDUCTION-LATEROLOG,. RUN 3; 10;648-12~930' BOREHOLE , , , ,. ,, , , , , , ,~ , · ~O~m~.:SATED SONIC LOG, ~U~ 3.~. 10.~6~6-:12 ,922', 3-Am~ HIGH ~Z?.~mT~.~, ~UN..I', 1'0',660-12,931.. '.. " ~" "'""~o.o,~;~.'l~~. o'.=,'0''o ..... ' .... , . , KII~ CI , , I HOLE ~AIIN~ llZl DEPTH ll~l' · ,z,~ .o,~'" ~o R E C ElY [ '9 za"2~2~ zo,~' ~-~/8' zo,~7' 8~" .o,64:' z2,)3z' oc~r 2,5 1966 ...... ,ANCHO~aE DR~LLP~PE 5~"- L9 · ii ' ., [ , Il I' . I '11 I ' ' I" ' '' ] ' ,,"r ' . ~ I "" r & ' I II '"' PD ~A (Rev. 5-63) Printed in U.S.A. · Middle Ground Shoal Cook Inlet (COUNTY) DEPTH~ fROM REMARK~ w,L~ #o. A- 11-1 12,931 13 Drilled 89'. 13,020 13 Ran DUAL INDUCTION-LATEROLOG~-RUN.. 4.~ .12 ~ 930.-1.3 , 014 ' .. Drilled 48'. 13,068 13, Drilled 92'. 13,160 13, Drilled 78'. Ran DUAL INDUCTION-LATEROLOG, RUN 5~ 11~850-13~215'. Ran BOREHOLE COMPENSATED .SONIC LOt, RUN,',4'~ 12,500-13~2'i'6*'. ' PBTD 13,23~ C.EMENT.ED .7" LINER, 10~505..-13~238~' WITH 500 SACKS .CLASS A CEMENT.. Ran 2734 feet, 7", 29(~ X-line N-80 liner with float shoe at 13,238' and fill-up collar at 13,066'. Hung on Burn~ liner hanger at 10,505'. 13,15 Drilled out fill-up collar, cleaned out hard cement to 13,155'. Ran and set Halliburton DM retainer on drill pipe at 13,152'. PBTD 13,15: Ran Halliburton RTTS tool, set packer at 10,300'. Broke down splice (7" x 9-5/8") with 2800 psi. Pumped in 20 cu. ft. water ahead of 100 sacks Class A cement (118 pcf slurry) mixed with 1% CFR-2. Displaced with 10 cu. ft. water and 1115 cu. ft. mud. Staged in last 40 cu. ft. Final pressure 3400 psi. No returns from backscuttle. Ran in with 8-1/2" bit, cleaned out to 10,505' (top of liner). PBTD 13,15: Ran 6" bit, cleaned out cement stringers in top of liner, conditioned hole to 13,152'. Ran GAMMA RAY-NEUTRON-COL. LAR LOG, RUN 1~..9000-13,152'. PBTD PBTD 13,15: Ran CEMENT .BOND LOG., R. ~U~..1. z .7..550-12~600'. Shot 4 holes at 10,850'. Set DM retainer at 10,763', broke down at 2400 psi, had communcation past liner-casing lap at 3 cu. ft./min, and 1500 psi. Pumped 20 cu. ft. water ahead of 50 sacks Class A cement (118 pcf slurry) mixed with 1% CFR-2. Displaced with 10 cu. ft. water and 1063 cu. ft. mud. Held 2000 psi on annulus with 3500 psi on pipe. , · 13,151 Pulled above liner, backscuttled, no cement returned. Pulled out with DM retainer. Shot 4 holes at 9485'. Ran in for W.S.O. test~ CONDi?ION AT ~ , ,,. . . ~"n~ HOLE OABINe IlZl ' IIZ~' ' 18-~" 13-3/8' 12};" ~7 ' 9-5/~ 8~2" ~.38 ' 7" ?BTD IIZ_~_~ - ] ' ,, · , , , ,' ' i ... ' I '11' 326 'J2625 ' PERIOD 2625' 10',647' 10,505'-13,238' RECEIV[, OCT 2,,.5 1966 DIVISION OF MINES & MINE~N~8 ANCHORAGE II I1~ , ,, IIONED 4A (,Rev. 5-63) Printed in U.S.A. Middle Ground Shoal Cook Tnlet DRILLING REPORT FOJ~ PIt]l/OD BZqD~O 9-22-66 A-11-1 WELL NO,.~--~,,.~ ~--- 1 T8N; R13W~ S.M. - ' (TOWNI~#IP OR RANCHO) DEpTHI IqtOll TO PBTD 13 REMARKS W.S.O. #1, 9485'. Used 2012' mud cushion. Set packer at 9436' tail to 9453'. Took 4 minute initial open - had faint blow. for 33 minute initial shut-in. Opened to flow 2 hrs. 39 minute,q. initially weak, gradually increased to moderate after 1 hr. 20 mit). Shut in 'for 4 hr. 5 minute final shut in. Recovered 5± bbl. gas cut mUd (net), '. ISIP 1520/30 m. FSIP 2582/245 m. (rising) IFP/FFP 640/722 HP 3123 Ran in with bit, drilled out retainer at 10,763' circulated hole clean to 13,15Z'. PBTD ' 13,15 PBTD 13,151 Spotted 180 bbls. oil base mud. Perforated (using 2 crack and 2 no plug jets/ft.) the following intervals: 9562-9637' 9670-9760' ' 9807-9833',-9930-9955', 9972-10,047', 10,893-10,910', 11,372-1 ,419' 11,688-11,700' 11 706-11,716' 12 053-12 138' 12 158-12 181' 12,195-12,512' 12,538-12,586' 12 616-12 854' 12 905-12 970' 12,990-13,005' 13,063-13,081' 13,094-13,110' 13 116-13 130' , , , ) ~ Ran in with 8-1/2" bit and scraper to 10,500'. Picked up 2-~/8" tubing. Ran long string to 13,051', with RH-1 packer at 10,391' and RH-2 packer at 9495' and Otis ball valve at 369'. Ran short string of 2-7/8" tubing to 9491'. PBTD 13,15; Landed tubing in head. Removed BOPE and risers, flanged up Christmas tree. MBTD 13, Stuck sinker bar and setting tool in master valve. Conditioned mud to kill well. Pulled lubricator and removed tools. Installed lubricator, , backscuttled mud from tubing. PBTD 13,15 Set RH-1 packer at 10,391' with 1100 psi and tested OK with 1000 psi.. Set RH-2 packer at 9495' with 1500 psi and tested OK with 1500 psi. 2625' 10,647' 10,505'-13,238' RECEIV[,9 · OCT 1966 DIVISION OF MINES & MtNEII~,L.B ANCHORAGE ;Laa {~ev~-§3) Printed In U.S.A. ,. ( ' Hiddle ~round Shoal Cook Inlet . ,. :,!~ ._~A ,, F,, [.. ~. · ~ .i ..... i r % i i ,.ih ~,.~1... ~,,, :,, ~,,, , , "" , , "' I $I-~ OIL DRILLING REPORT FOB. PXiUOD 9-24-66 ' II II ' IIII I I [ II 1 T8N, R13W~ S.M. __ ........ 0.oW~,,,, oR DAY DEPTHS '",,"o;~ ...... vo - ~ber, lC~66 (Con PBTD PBTD HOLE; "1 26'1 2625 d' 12625'! 10,6~ ' ]~0,6a7~' 12, t , -- i . i ,-, 13,152 RIq4ARKI t'd) Tested tubing OK with 4000 psi. Sheared shear-out sub with 5200 psi. Rigged to swab. Swabbed lower zone from 2900', zone began flowing. Released rig 4:00 A.M. September 24, 1966. 13,152 CONDITION AT:3~.E,]~ ~ Oil PERIOD , GAIINO llZl 7' 9-5/~ ' 38 ' 7" 19.5~ 2625' 10,647' 10,505'-13,23~ RECEIV 'D OCT 1966 DIVISION OF MINES & MINEP, AI~ , ANCHORAGE REPORT of SUB-SURFACE DIRECTIONAL SHELL SURVEY OIL COMPANY COMPANY MIDDLE'-GROUND SHOALS A I1-1 .......... - ............,.,~.~=mJ'; NAME ..... ....... :.i COOK I.N L ET,. AL ASK A ... '.'.: ..... LOCATION JOB NUMBER':'.' ........... --;~-:!::?!.::. :.:..,/. L6- 7166 .., ..... / .-, ~,, ,:.?. -:'. :. TYPE OF SURVEY DATE - ~ i i · i Ii' i i '--~ iii ii i ii i i i i SIN(g.E SHOT dUN "'SEPT, IgC6 LONG BEACH RECEIVED OCT ~ 1966 DI¥1$10N OF MINES & MIlNERAL.8 ..... R[C IV[D , ' RECORD OF SURVEY '""""""'"' ~i Dec' 1 Correction 25' ' JO~ NO. L6-7166 ....... ~AI~ June - September, 1966.. TI~UI' COURSl: Dml,'r R I: C T A N (~ U I. A R C O O R D I N A T l: · _~11oN MEASURED DRIII"r VERTICAl. DEVIATION DIRECTION ' " DEPTH ANGI,,[ DEPTH NORTH IOU'I'H ~ i i i iiii ii .1I14033'7 O0 - 33.7; O0 CO0:R.D~ :F~mN :BY OFR 663 I 12 2 O0 05e 15' 439 h8 11 25 N' 26:00'W 16 74 3 81 470 O0 06'/'5' 1,69 27 3 53 N 19' 00'W 20 08 500 00 0~:45' 499 O0 4 05' N 15'00'W 23 99 6 O1 7~&U.~II~.~.~ ~.~ ~ oa ~.~, ¢ 5 527 00 o.'15, 525 72 3 87 NORTH 27 86 6 01 6 511.8 00 09'-00' 546 46 329N OI'-O0'E 31; 15 ? oo ,., -- _-.,,.... 8 616 O0 09:30~ 613 61 6 11 N OZI.'-OO~E4.1 83 9 6~7 00 10t 00' 6~ 1~ 5 38 N 05' O0'E ;47 19 10 '. 710 O0 12'30, 705 65 13 61, N 13'00'E 60 48 1 90 . / ~,.~. 11 7'30oo 3-00, 72 '~/4 ~ 50 N 15'00,E 6~ 8~ 0?# 12 760 O0 3- ;45' 75 28 ~3 N 16'00'E 71 68 1 8 87 oo 16'oo,876 62. 25 91 N 17'-O0'E 10~27 11 05 ~'-5 972 :0017' 30' 957 69 25 56 N 21'00'E 128 13 20 22 16 1035 O0 18'-00, 1017 61 19 ~7 N 18'00'E 146 65 26 24 11~ 1066 O0 160 30' 10147 33 8 80 N 13' O0'E 155 22 28 22 1100 O0 16'-00' 1080 .01 · 937 N 11'-00'E 1614 ;42 30 O1 20 1176 O0 18' 00' 1152 60 11 12 N 11' O0'E 36 34 -- 2I 1209 O0 20'00' 1183 61 i1 29 N lh'O0'E 197 31 37 61 .22 12;40 O0 22~* 30' 1212 25 11 86 N. 11' O0'E 208 95 39 87 2~ l~Sh O0 26'-00' 1315 2_.~ 28 06 N 15'00'E 256 25 " 51 80 '25 1~17 oo 27'15' 1371eo 28 85 N 114'O0,E 28;4 214 58 78 · A-1X-1 , ,, , ,, ~ ~ ~ ~ ,~ ,m~,,~ ~ ~ , , , ,,,,,, , ,, , ,,, ......... [ ............. , , OCT 2,5 1966 '~ .. 1.~NMI~ION OF MINES & MII~ERA~ ""'"'= ~OI NO.,, IB-7166 ~AI~ June Se~s~embez' i i ii TRUW COU I~S" DRii~r R~:CTAMGULAR COO~IMATH~ M~SU RED DRI~ VEnaL D~~N DIRE~N .... ~ 1509 O0 30'30' 1451~ 15 3096 N' 16'O0'E~ 328 17 ~ 1670 O08'00, 1580 6243 10 N 19'00,E 478 86 30 17~ O0 00' 1636 52 .42 13 N 15' O0'E 459 83 111 -- -- 3~ 1765 O0:37'30' 1656 35 ~5 22 N 15:O0'E . bTb ~ 32 1859 O0 ~1'00' 1727 29 61 67 N 16 O0'E ' 533 ~132 34 3~ ~5 O0 ~8'30' 1~55 30 68 90 N16'00'E 663 09 168 38 3520~ O0 ~48'O0' 1864 O0 9 66 N iO'O0'E 672 60 170 ~ , =./¥..-' . ..j 16~86 36' 2109 O0 47' 30' 1898 46 37 60 N 10' oo'E 709 63 3- oo ~9'45' N , 2328 O0 54'00' 2032 101 93 N 08'O0'E oou 86 '200 '~-"~ 2390 O0 56'OO' 2067 28 51 4o N 08'OO'E931 76 2~ 8~ 53 8a ~1 ~66 ~00 55e15' ~ 2278 22 155 28 N 07eOO'E 12~ 65 245 75 oo5~oo, 2 3 o~ 8z zo o7'oo, 5 ~2 2865OO ~5'~6305 N E 13211~ 265 101 0?' OO ' 2989 5 45' 2 2 3116 oo 53~5' 2481 102 ~1 N 07'O0'E 1523 28 ' 280 ~5 3239 O0 53'00' 2555 69 98 ~ N 07'O0'E 1620 ~ 292 oo o -oo, o, ~7 3~ ~ 5~'O0' .266758 72 O0 N 08'O0'E 1770 5~ 312 09 3553 OO 56'30, 2737 12 105 07 N O0'E 1874 324 82 ~9 3616 O0 58"00' 277.0 50 53 42 N 0 ~O0'E 1927 72 332 34 ~ 36~ O0 58'15' 2786 29 25 51 N 08'O0'E 1952 98 335 89 M.~.S. A-11-1 , ~ , ,,,,~ I ~ ~ ~ ii i~ Ullll i i ,~ ~ ~ ~ ~ , ~ ~ ~ ~ ~ i ~ i i " · RECORD OF SURVEY "--'"'"" ~ ~ ~. ~-?Z66 ~ June - Septem~e= 1~6 ~~~OE, , ~UE ~URS[ DRI~ R E C T A N G U ~ A R C O O R D I N A T M~SUR[D DRI~ V[~~ D~~N DIR[~N , '~A~ DE~ ANG~ DISH ~~ ~~ ~ ~ - _ -~ l 3783 O0 57'~5' 2859 39 115 86 N 07'O0'E 2067 97 3~ 01 2962 91 164 07N 07*00'E 2230 81 ~ oo ~.~, ~ o o, 7 4116 00 57'15' 3038 11 116 90 N 06*00'E 2347 07 382 ~ ~ oo 56~3o, 3zo9 86 zo8 ~ ~ o5, oo,~ ~55o? 39z 68 55 4299 00 54'30, 31~0 61 43 15 N O7'O0'E 2497 90) 3~ ~ oo ,oo, 4630 O0 5e30' 3216 26 51 92 N O02603 91 410 ~519 00 ~56e30' 3265 38 7b 22 N 0 eOO'E ~ 41 421 60 ~733 00 55'00' 3388 13 80 28 N 09'00'E ~28~9 98 ~51 95 61 ~28 00 57'30' 3~3917 8012N 08~00'~ 2929 32 ~ 10 8 o ,oo, 62 ~90 O0 5 ~4~' 3471 5~ N E 2981 67 4 I 39 6~ 4~9 00 59~15' 3516 ~9 N 07~O0'E 3057 59 ~ 0 71 - C. ~oz~ oo ~.~o, ~ ~ ~ oo . o~.oo,. ~~ ~. ~ 3 5~3 ~00 58'15, 3665 93 160 73 N 10'00'E 3295 88 521__ ~ ~82 00 58~00' 3781 98 185 71 N 08eOO'E 3479 79 547 13 67 5608 00 58'15' 38~8 28 107 15 N 08'00'E 3585 90 562 05 68 69 5902 O0 57' 15' ~005 97 91 67 N 08'O0'E 3831 61 ' 5~ 59 70 5993 00 57'15' ~055 20 76 53 N 09'O0'E 3907 ~608 71 6138 O0 57*00' ~13h 17 121 61 N 08*O0'E ~02I 63 625 ~9 72 6296 00 56'~5' ~220 80 132 1~ N 09*O0'E ~1581~ 6~6 16 , ~ 6378 00 57'00' ~265 ~6 68 7x ~ ~:O0'E ~226 39 65~ 5~ O0'E b43~ 10. 683 7~ 663i 00 56'00, bb06 94 2097 . 75 6800 00 ~9'30' ~92 7Z 1~56~ N 08'O0'E ~578 307~ 01 M.~.8. ~ A-11-1 RECEIVEr) ~~!, RECO-RD OF SURVEY i ~,~m,,w ~~ D~StON ~ MINES & ~NE~ ~1 NO. ~-7166 ,, ~ June,,- September 1966~~~,, , ii F i in lUll I II ~UE COURSE DR~ -R E C T A N ~ U ~ A R C O O N D I N A T - M~SU R ED DRI~ VE~~ D~ON DIRE~N ...... ~o~ oo ~*oo, 46o3~ ~ 72 . o8~oo,~ 4~4 ~ 73~ 79 7~o oo55~oo, ~5~ ~ ~5~3~ ~ o~oo,~ ~9~ ~ 8o T~8~oo58'3o~ ~7~ o~ 69 o6 ~ o7*oo,E ~985~6 763 86 8~ 7~ oo5~ 3o~ ~3~ 7~ ~7~ ~ o~~oo ~ 5~3 6~~ ~ oo ~,~o, ~8~ ~ ~o ~ . o~,oo,~ ~o ~ ,- ~ '85 7616 oo 57'45, 49~7 55 38 o6 N O?'O0'E . 5~6Z99 ~ 7695 O0 58'45' 4958 53 67 -5~ N 08~O0'E 5334 87 809 83 8~ ~6 O0 59~30' 4984 41 43 9~ N 09"00'E '5378 ~7 81670 oo ) DO01 00 59]45' 5114 76 09e00'E ' N IO'O0'E 5708 73 873 91 8~1 O0 57~00' 5~0 68 128 32 N ll"O0'E 58~4 69 898 10 92 8~83 O0 55~00' 5380 81 157 ~ N IO"O0'E 5989 59 925 879~oo55'oo, 5555 zo~o~ N Z~'OO,E 6~3~ 93 95 900?OO5~'00, ~87 81 169~ N I~'O0,E 640~ 1013 ~ .gZ~OOO5Z'30' 5T58 z5 88~3 N Z3'OO'E 6~908Z ZO3353 ,~ 9~58OO~9'30' 58~777 ZOh9h N Z3*OO'E 659306 1057 98 99 9~50 O0 46'00' ~978 93 66 90 N 13'O0'E 6729 65 ,1~ 9616 O0 44'00' 6098 33 115 32 N i~'00'E 68&1 5~~ 1116 ~' M.O.S. A-11-1 m mm m mm~m m m m immmm ~ m mJ m imm, immm ........ · ,' mm m i "--""" ~ X)~ NO. L6-7166 DAI~ June . September ~UE ~U~E DRI~ RECTAN~U LAR COORDINATE~ M~SU RED DRi~ VE~CAL D~~N DIRE~N .... DE~H A~G~ DE~H _ ~~ ~U~ ~ oo 10~ 99~3 oo ~'3o' 6319 65 ~ 81 N 16~O0'E 703~ 10. 10~3 O0 39~5' 6388 85 -:5755 N 17'O0'E 7093 91 ~88 105 ~0096 ~ 38' 00' 6~2 ~ 57~ N 17' O0'E 7~8 67 1~ 106 10186 O0 3~5' 6533 30 55 10 N IT'O0,E 7201 ~o~ 6 oo ~6, ~5' 660588 5~ ~ N ~'oo,~ "7~5~ Ig~ 103~8 O0 36'00' 6680 31~ 08 ~N 18'00'E ~g~ 11o 1o630 oo ~32'~5' 6900 97 35 22 'N 18'~'E 7437 77 1297 -- 111 10670 O0 32'00' 6934 89 21 ~ N 21'oo'E 7457 1305 112 10764 O0 3i'-"00' 7015 46 ~ '41 N 21'O0'E 7502 _ 132~ ~ ~ 062'~ O0'E 7575 32 13~ 11 10911 O0 33"00' 7138 80 N ~ 10966 ~00 33'~5, 718~ ~ ~ N2 00'E 7603 24 1369 5 11088 O0 33' 15' 7286 51__ _. N 25' O0'E 7663 86 13~ -- -- 117 11~7~ O0 33'Z5' 744~~6 1097 N ~7~O0'E ~53 119118 -13~ O032"15' 7506 ~7 20 81 N 26'00'E 719009 ' 1~2 11311 O0 33"00' 7473 ~9 20 15 N 27'00'E 7771 39 1453 ~13 ~ O0 753361 16 96 N 26'00'E 7305 33 1470 1~ 32' O0 ' -- 121 j 11~6 O0 32'00' 7~53 96 12 72 N 25~00'E 7816 86 1475 122 11441 00 32~15' 7583 56 18 68 N 25"00'E 7833 ~79 1483 '12~ 11502 O0 32'00' 7635 29 32!33 N 27'00'E 7862 59 1498 12~ 115~ O0 31'00' 7667 86 19 ~ N 25~00'E 7880 33 15~ ~5 11585 00 31' 00' 77O6 ~3~ 23~o N 2~' O0'E 7901 50 1516 · ' : ......... ~ ]~:~ ................ R~C~IvED ~~! RECORD OF SURVEY DIVI$1ON OF .MINES & MINE~ ~'"--~ ~ NO. ~-T~66 ~ June - sep~e~be~ _ ~UE ~U~E DRI~ RECTANGULAR GOORDINAT~ M~URED DRI~ VEnaL D~ON DIRE~N , '~ DE~H ~GLE DE~H _ ~~ ~~ ~ ~ ~oo oo~ 3o· ~o, 78o~ "oa ~ 5o , a~, oo,~ ~a~a ~ ~ ~a?8 oo aS~oo, ,~ ~ 6o~ ~o, aa, oo,~ 8o66ao ~o~ oo . . [3o ~2z6h oo26' 3o' 82z7 57 ~2 83 N 3~'00'~ 8~37~ ' ~650 131 ~2298 O0 26'30, 8337 ~9 59 79 N 36'00,E 8~85 81 ~685 133 12h92 O0 27'00' 851086 27 69 ~N hl*OO'E 8252 16 17~1 86 135 1~86 O0 2~'~5' 50 2h ;N 47'00'E 8309 76 ~01 15 136 12805 O0 23~5' 8795 26 h7 92 N 50'O0'E '83~ 56 1837 85 137 O0 23~00' ' 8363 92 ~66 69 8 5~ ~ O0 ' E 13 13ooo oo 2~'3o' 8975 75 3 65 8385 ~6 z3o89 oo 2o'3o' 9o59 z~ 31 ~7: 55'00'E 8~03 3~_ 1921 ~3208 O0 20'~5, 9~70 39 ~2 ~6 N 57'00'E 8~ 30 1957 1~1 13238 O0 20'~5' 9~98 ~ 10 63 N 57'00'E 8~32 09 1966 ~15 O~S~ ~ 8658 ~o, N 13' 08,E . , , e -~M.~.8. ~A-11-1 m mmmm mmm m m ~ mm m m mm m mmm mm Di'4-12 ~tease Date State of Alaska Department of Natural Resources DIVISION OF MINES AND MINERALS Petroleum Branch INDIVIDUAL WELL RECORD Sec ........ T. 8, N R. 13 .W _~ .. Meridian Permit No ...... 6~9__ Operator_. She_il _Oil_ Comp.any ..... Lease No. ADL 18754 or Owner _.M_i_d41a_G_round Shoal I s sued Location (Surface) I&2?'F.~T. ,ha A35,FEL Sec. .. Loc. (Bottom) Well No. _ . A. 11-.! Area Spud Date ..~6r28-66 .... Drilling ceased U. 883 L._ 1028 Suspended. Abandoned 9-25-66 Completed (F-GL-P)~ 9-26-66 IP 391 128 : Top. p~.od. Sd. 2126'FNL and 67!'__~. Sec 1 _ .. ~ -: : . . _ ~, Bottom 501'FNL and 1531' FWL, Sec. 1 @ 13,238 9198 V. D. Total Depth _~.1~32~38 M. D. 83' Wtr. depth MLLT Elevation. 1!6'_ D. F. 37.0° 3.5 Gr ay _3~_~__API Cut__ 750 100 Gas. 38.2 ......... MC, P/D, Bean~/64 CP__~gi0___ psi, TP ,,, 911_ Casingt Size _ Depth;: ... . Sx Cmt Perf: 9562'-9637' ;9670'-. Plugs~ +600 in 9760' :9807'-33' _'.99~Q'-55 '. ;9972'-1.0,047' ~ ~ a~~_ -10.893 '-10.910'; 11.372 '-a 19 ' :.l 1_ RRR ' ~00' ' 11,706 ' '716' ~ 12,053 ' '138 '; 12,158 ' '181 _zo,6 7' Liner 500 -:;. t _ ~ ,_,,_ _ A - " ..... 2 7/8"tbg. w/pckr. 9483' GEOLOGIC PORMAT IONS Surface ~ LOWeSt Tested. psi 12,195 '-512'; 12,538' -586'; 12,616'-854'; 12' {'05 ' -70 ' ;' i2,990'- 13; 005; ~' ' 063: -~'::; - ~- 13,094' -110'; 13,116'-30' Name PRODUCTIVE HORIZONS Depth Contents Ye ar Jan · WELL STATUS . ~e...b ............ Mar...Apr. ..... May June July Aug Sept Oct Nov Dec Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 LAND 13FflCE LEAS, N''MSE. ADL 18754 ~.. LEASE' ~R UNIT NAME LESSEE'S MONTHLY REPORT OF OPERATIONS State .............. _ A_ _l_a_ .s__k_a__ .............. Borough ..... _ K_ .e_ _ _n__a_ _ ~ ........................... Field : _ _ _ ~ '.3:_ _d_ _d_ ! e_ . _ . _O_ _r. .°_ _ _u_ .n_ _ _d_ _ _S_ _ .h. p_a_ ~ _ _ _ i Tl~e followir~g is a eorreot report of operatior~s arcd prodz~etio~ (iT~elz~dir~ drillir~ a~d prodz~eir~ wells) for tl~e rno~tI~ of ___._S__e_2t__e__m--b-_e-_r-_ .................. 19--6--6-- ............................................................................. ./lge~ffs address ...... _4__3__O____S___e_~9_n_.t__h____A_v---e--n--u--e- ........................ Comparcy She 11 0il Comp any Pl~one 272-9541 ' ,o ,;,~o Division Exploitation Engineer ................................................................................... ~/~e~t ............................ ~ ................................ Cv. F~. or GAS 8~zc. A~D BAR~ELS O~ On. ~ o~r ~ (In' thousands) .e to 13, logs a~ o 13,238' at 10,505 to 13, et DM reta splice 00 sacks. h 4 holes '. holes/ft. .0,047', ,910', 1 ,053.12, 158-12,1~ ,905-12, ,990-13,0( 7/8" dual paci released .-66. Si (}ALLONS OF GASOLINE RECOVERED 12,931 · Ceme~ ner at Squeez~ 9562-96~ 1,3,72-11, ,1 , 12,1 ~5 ' 13 C , , :er at 94 tut- in we BARRELS OF W~gR (If none, so state) , 13,020 ted with 3,152'. d 50 sacl 7', 9670 $19', 11 95-12,51: 53-13,08 83' and 11. RE~VIARKS (If drilling, depth; If shut down, oauas; date a~d result of test for ga~ollne content of gas) , and 13,238'. 500 sacks.' <s through 4 holes at -9760' 9807-9833' 688-11,700' ' '12 538-1~ 586' ' 13 094-13 110' ingle packer NOTE.--There were ................................................ runs or sales of oil; ................................................ M cu. ft. of gas sold; runs or sales o£ gasoline during the month. (Write "no" where applicable.) NOTE. Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th o£ the succeeding mor~:~., ~r~sse"°i' i~h~Or i e directed, i~ ..~" .... " -~ OCT b 1966 L)lVlSlOiX,t Ok MliX,l!:~5 & M!i",[5i:LAL$ Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1964 LAND rlFFIE:E LEASE N''M~ER ADL 18754 LEASE IrlR UNIT NAME LESSEE'S MONTHLY REPORT OF OPERATIONS State ......... __A_'_l__.a__s__k_.a__ ................... Borough _.__K__q.n___a_! .............................. Field .......... _Mi_ _d_ d..l___e. .__G_.r_ O_._u__n..d.._. . _S_h___o__a_l__ ..................... Tl~e followin~ is a eorreot report of operations and prod~etior~ (ir, eludir~ drillir~ and produei~,ff wells) for tke montk of ' Augu_.s__t____~ ................... 19__6._6__, _ ........................................................................... ./l~e ~ t' s address ...... ~3__0___S_9_Y_9_-n--t_-h-_--Axg--n--u--e- ...... ,--~ .............. Companv --.~-~--/~-h--e--1-!---O-i-l-:-gP--m-P-a--n-Y ................ ' ................................. .................... -_:_ _ _ff /I P~o,~e ...................... ~7_~:~-5-~!_.~ .......................................... .~e,W s Ut~e ___p~.~_~_~__o_~___r__?__~.S~_t_~_o_~__~~.~ ~ Cu. FT. or GAS SEC. axo BAaEELS OF On, ]~ o~ ~ (In'thousands) to 10 ran DIL ar oie to 10, ran DIL ar asing at 1 with 125( to 12,5 :an DIL lof CEIV OF MINES & ANCHORAGE (}ALLONS OF RECOVERED d Sonic d Sonic BARRE~S OF WA~ER (H none, so state) sacks c logs. logs. .=ment. , Drill,~d ahead REMARKS (If drilling, depth; if shut down, cause; date and result of te~t for gasoline oont~t of gas) to 12,842'. NOTE.--There .were ................................................ runs or sales of oil' . ............................................... M cu. ft. of gas sold; ' runs or sales of gasoline during the month. (Write "no" where applicable.) 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 Division of Mines & Minerals by the 6th o£ the succeeding month, unless otherwise directed. Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1904 i~ LAND DrF'IC£ ~' LE^s~ NUM~ ADL 18754 ~ a~ ~,~ ~ Middle Ground Shoal State LESSEE'S MONTHLY REPORT OF OPERATIONS Jul~ 'State_- _Alaska ' Borough ' Kenai Field Middle Ground Shoal Zl% fotl°wir~ is a oorreo~ repor~ of opera,iotas ar~d prod~otior~ (ir~el~dir~ ~ri~i~ a~a Proa~°i~ wells) for the me,tn of ............. ~U~X ...................... 19~_~__, - ........................................................................... ~ '' address .30 2~k'Av~ ....... - ....Company_-S~~~~: ................. ' - ...... ....................... ...... ............ ....... Anchorage, Alaska , . ............................................................ ~ ................................ ~e~,,s title ........................................... 272-956~ .................................... D~v~s~on ~and ~anggor ..... P~one ............................................... ~ CU. ~T. O~ GAS j GASO~E w ~'~_~ d~ ~d r~ul~ of t~ zor ~o~e SEC. A~ BA~aE~ O~ Om (~'tho~) ~ ~0V~ED no~, ~ s~e; oon~ ot e~) ~o~ ~ _ . - A-11-1 )le 1700-21 Class A , tested ,le 2800-9 Cemented Cemented psi [3-3/8", annulus 61# casi at 2625' with 600 sacks Clas's G cement. ,-, I966 DIVISIO, OF MINES & MIRIE~LS ANCHORAGE runs or sales of oil' . ............................................... M cu. ft. of gas sold.; NOTE.--There were ................................................ runs or sales of gasoline during the month. (Write "no" where applicable.) must NOTE.~Report on this form is required for each calendar month, regardless of the status of operations, and be filed in duplicate with the Division of Mines & Minerals by the §th of the succeeding month, unless otherwise directed. Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Effective: July 1, 1904 LAND r't FFIEIE LEA~E NUM.E. ADL 18754 LEASE nR UNIT NAME LESSEE'S MONTHLY REPORT OF OPERATIONS Stat; .......... __A_ _l_ _ a_p_ k__a_ ......... i ......... Borough ......... _K.e_n_ a_ . '_x_ ........................ Field ....... M '.x_ .d_ _d. !_ _e_ _ .G_r_ _ _o_ _u__n__ .d_ _._.S..h_ ~_a_ . ~ ........................... Tt~e followir~ is a eorreot repot* of operations and prod~etior~ (ineh~din~ drillir~ and prodz, eir~ff wells) for the month of ........... _J__u__n__e_ ........................ 19___6~, _ ............................................. ' .............................. ,4~e~t's address ..... _4__3_0_. _S_.e_ _v_a_n_tJa_Av_eJaue ......................... Company ____$__h__e_ 1~~ _l_ _ _ _0_ ~ .1. ___~_o_ _m_ p_ .a_ B~f .................. ............................... ............................ ........... ........... Pkor~e ..................... 2__7__2__-__9__5_4__]: .............................................. 8~c. ,~ND BA~=~s o~ 0,,. S .A.S e to 327' .e CU. F~. oF GAS (In' thousandS) (}ALLONS OF GASOLINE RECOVERED BARREIS OF WA~=~ (If none, so state) REI~IARKS (If drilling, depth; if shu~ down, oau~e; dat~ and result of test for content of 8'a~) NoTE.--There were ................................................ runs or sales of oil; ................................................ M cu. ft. of gas sold; ............................... '. ............................ runs or sales of gasoline during the month. (Write "no" where applicable.) 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 Division of Mines & Minerals by the 6th of the ~uccecding month, unles~ otherwise directed. ; .,..,.,- ~,:.: - · . i{,.~ AVENUE ,'~ , ,. .{,~ AL. ASKA 99501 / . ,f..?.~<-'- ' ... [,q /~, M±ddle Ground Shoal Field Well No. A-11-1 RECF:IVED SHELL OiL 430 7tH aNCHORAGE. July 1, 1966 Subject: JUL ? 1966 DIVISION ,.)~ M!F,IES & MINERALS ANCHORAGE Division of Lands 344 Sixth Avenue Anchorage, Alaska Attention Mr. Erle Mathis Gentlemen: For your information please be advised that Shell Oil Company, as operator, spudded the subj.ect well on June 28, 1966. _~ih~.s. well which will be bottomed under the S oAoS. State lease ADL(i875~.5 is ' sho~=a on the ~attached plat which we submit for your retention. Yours very truly, ........................... :-:::-. ....... 5,.,~-, ..... ...... ....;5~:;" ......,d.~. --"C-- ,. T. S. Cate Division Land Manager. TSC:m Attachment ~. 1. ~ ~,,~.~ h. 1~ ¢/.~ ~.!i,4. .. .. RECEIVED' PaPSS ADL 17595 SAS ADL 18754 JUL'i 19t55 DIVISION OF MINES & MINERALS ANCHOP-AGE 36 A-4.5-11 ,.9, LEG NO. I . A-23-12 0 i LO-CATION OF LEG NO.I LOCATION OF PRODUCING ZONE WELL NO.A-II-I PUBIC LA N D DESCt?IPTION ' 660'S ,-'--& 660' E 1627' N. 8,, 435' W FROM THE SE COR. OF FROM THE NW COR. OF SEC. II, TSN, RI3W, SM. SEC. I, T8 N, RI3W, S.M. z, '~ -'" ~ ~ SCALE t :2000 r~rr,r~D ~V ~ B ~i - F ' ...... ~4~,- ~ ,, ~i~ ~ ~h~?~ ~,~,~ DArE ~UNE ,s~ : ~i ~' Zi-65156 ' ' ~ A - ~ l ~ - -LOC,-, FIO~,~ UF · ~-~ELL-ATLANTtC-~i~..~NDARD WELL A-II-i IN SEC. I ~,__ ........... ~,~ ~q.t R.i~7. S.M.- u,,O~ iNLE~-S~A~E,OF ALASKA ver~ ~:~-u!y .2 June 27, L966 {inclosed ire tha follovtnS: 1. Check Ho. 1-2~28 far $50.00' ami' approved drii! from Texaco for Trad~ {Jay State 2. Clack No. 1-2g{2{ ~ ~0.~ mM fVp,,roved application for perntt to drill from ~ for Tr-adisi{ Be7 Sl:l~ {3. 3. Ch~ck lb.. LA 2590 for {50.00 ~nd approved ~ppltca~Lou for pemi~ ~o~// drill from Shell ~I Comp~ for Jigs A-II-I. ~h SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE. ALASKA 99501 June 24, 1966 Subject: Middle Ground Shoal Well A-11-1 State of Alaska Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska Attention Mr. T. R. Marshall, Jr. Gentlemen: Enclosed herewith for your approval please find Application For Permit To Drill our well A-11-1 which will be bottomed in the NW/4 of the NW/4 of Section 1, T8N, R13W, S.M. This application is handed to you in triplicate, along with our check for $50.00 as filing fee. Since we anticipate commencing this well on or before Monday, June 27, we ask your immediate consideration of our application. TSC:m Yours very truly, T. S. Cate Division Land Manager Enclosures DIVISION OF MJN~:5 a MINERALS A!~CHORAGE m /.[ :"~. = j.S~ATE OF:ALASKA- · ..... ~('Other:instruettons~r ' -reverse on ..................... -...,. ~ ,._ . _~ side) AND GA~: ~0NSEi~V~T|0N C0~ISSIoN ' APPLICATION FORPERMIT:TO'DRILU, DEEPEN, OR ~ PLUG(' BACK O,L [X] OAS rm SINGLE [[] ..LTIPLE r~ , . WELL ~ OTHER ..... ZONE ZONE WELL ' A .~ _~, '' ..]:: '"', i~-:~- '~ ~.- .......... ,~. ._ ., 2, NAME ,0F, i'0~ER ~)R. : .... "' / '% ''''~ ,'' ' -- ..... ' Shell o Ef£eet~ve~ ,JU!~ 1, 1964 LEASE DESIGNATION AND SERIAL NO. State, ADh:, '18754 ; !6; IF-~[N-DIAN, Afl,JOTTER OR:TRIBE NAME "9.' w~'~ ~0': ...... - ~i:adle '~ro~d Shoal A-11-1 430 Seventh Avenue, Anchorage-~taska LOCATXO~ O~.?WEL~,= (~eport:ioeatl_o_n elearly an~ in'aecordanee :wrlth any. Sta .ts .requirements;* ) Atsurfaee 1627'N - 435'W, SE cDr Section 11, T8N-R13W, S.M. :Leg'~¥~t; c0n'dQctb~"~:7 of~''' Pi~/tf°~ni' A ........ ' ' At proposed prod. zone Please see #23 belo~ 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 18 miles N.W. of Kenai '1'0. /FIELD. A~ POOL, -OR WILDCAT Middle-Groun~ Shoal 11. ~,EC., T., R., M., OR BLK. " 'iiND'SUaV'~'OR' ABRA 1 - TSN-R13W.SM 12. B.OROUGH SIll 13. STATE Kens i Alaska DISTANCE FROM PROPOSED$ LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Al~o to nearest drlg. unit llne~ if any) 660' ~. DISTANCE FROM PROPOSED LOCATIONs TO NEAREST WELL, DRILLING, COMPLETED, OR APPLIED FOR, ON THIS LEA~E, FT. 2200'+ 21. ELEVATIONS (Show whether DF, RT, OR, etc.) 116 ' D.F. 16. NO. OF ACRES IN LEASE 3746 ~o. PEOPOSED .DEPTH 12,450' 17.NO. OF ACRES ~ASSIONED TO THIS WELL 160 20. ROTARY ~)R 'CABLE TOOLS Rat a rv 22[ APPROX. DATE WORK WILL START* 6-27-66 23. PROPOSED CASING AND CEMENTING PROGRAM I SIZE OF HOLE [ SIZE OF CASING WEIGHT PER FOOT 18 1/2" [ 13 3/8" 61.0# 12 1/4" - 9 5/8" 40# - 47# 8 1/2" l, 7" 29 # SETTING DEPTH 2800 ~' + 1.0,850 12,450 + QUANTITY OF CEMEN= 3000 sacks 800 Sacks , 700 Sacks Projected sub-surface location of producing interval Top: 1740' S, 515' E of NW cDr. Section 1 - 9860 (MD) 5955 (TVD) Mid-point: 13'05' S, 570' g of NW cDr. Section 1 - 11,080 (MD) 7060(TVD) Bottom:' 660' S, 660' E of NW cDr. Section 1 - 12,330 .- ,¢' ~- ~\J¥ ~)(MD) 8175 ~V~) This well will be completed to produce from seperate tub~g\~rJ~g%,' t~e upper interval being 9860 - 10,650 and the lower 10,950 - 12,33b~. '~3~\~'. ~[%~ ~ ~Q-'~-:.,~.., (. - =.' ~, IN ABOVE SPACE DESCRIBE PROPOSED PROORAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new .productive zone. If proposal is to drill or deepen direetionally, give pertinent data on subsurface locations and measured and true vertical depths. ' Give blowout preventer program, if any. 24. I hereby ce~~ o~ng~n~True~ ~-~ ~--~ and Co~'rect. (This s~ce for F~ral or State omce use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: APPROVAL DATE THOMAS ~ MARSHALL, JP.. Executive Secretary TITLE DATE Alaska Oil & Gas Conservation Committee *See Instructions On Reverse Side T.-8 N',;, R. 15 W., S.M. Pa PSS ADL 17595 .~6 $1 ,, ~ i SAS- ~;:) ADL 18754 A-II-I 660/ i ~15 $R8 MGS-I -I.. A-25-12 A-43-11 LEG NO. I LOCATION OF LEG NO, I LOCATION OF PRODUCING ZONE WELL NO.A-II-I PUBIC L A N D D ES C/:?IP T/ON 1627' N 8~ 4.35, W FROM THE SE COR. OF SEC. II, TSN, R 15W, S.M. 660'S & 660' E FROM THE NW COR. OF SEC. I, T8 N, RI3W, S.M. III I1__1 I IIIIIII I I I II RAWN BY N.L.B. l ~' ' SHELLOIL COMPANY CHECKED BY E. B. M. , DATE dUNE 1966 LOCATION OF SHELL- ATL.ANT[C-STANDARD WELL A-I I-I DIETERICH-POST CLEARPRINT lO(ON IIII I I II II I I I I! _ SCALE I":aooo' , ..... 2[-21-66156 III II I R.13~ IN SEC. I -COOK INLET-STATE OF ALASKA Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ ,. No special 'effort has been made to chronologically organize this category of information. ,o SCHLUMBERGER· .... m q COMPANY' SHELL 0IL COMPANY 0 ~ ~ ~ .WELL H G S ~A-11-1 0 - o · ~ ~ ~ t~ -- ~ ~ FIELD .,HIDDLE GROUND ~ ~-- ~ .[~'r~ COUNTY KENAI BOROUGH STA~E J i i i i i i ii~ ii Z ~ LocATIoN ' Ofher Services: ~ o~' 4"~7~N & 2 54~E FROg CENI[R LEG ~RD~BSL~E$~ 8 ~ ~ 8 Sec. ~.l .. Twp... 8.~ Pge. 13W i i i i i J J i i J Permanent Datum:__ D, F_,.. , Elev. Elev.~ K.B. Log Measured From g, ~. . , Ft. Above Perm. DOio~ D.F. ' Drilling Measured From D,.Ft ...... .. _. G.L. / ii ii [ i i i ii J i i i ii i i Dote 8-6-~6 8-9-66 9-2-66 .. 9.5,66. RUn'No. ONE "" TWO .... ..' THREE FOUR "' Depth:Driller' 10497 ". ~' 1 0647 '-' 12'931' " 13238 ' Dep~h"Logger 10486 · 10650 '* 12934 ' . 13219 Btm. Log Interval' 1 0482 ' 1 0646' 12930 1321 5 Top Log Interval - 2611 1 0'48 2 1 0648 Casing--Driller J3~ ~2610 13~ ~2610 9~ ~10647 9~'~10647 Casing:Logger 2~ 11 ....... 2~,11 " 1 0648 .... 1 0~48 .......... Bit Size 1 2~ 1 2~ 8 ~.. ..8 ~ ~-~ype 'Fluid in H~ X'P- 20 XP- 20 XP- 20' . XP- 20 ~ ............ , , , . -~ens." jVisc. 79'. ''''~'j~5' ' 78. "J- ' ~2 '77 ·J 7 ~H' 'JFiui~ L~s16~ J2,"3 ml.l.O,3 J 2.2m1':1~"4 .~2...2 ml'll' 3 SourceoJSo~ple' CI'RO'ULgTED' ~'IRCUL'~TED ciRCULaTED CIrCULaTED R,.' ~'MOos. Te~p. 1.;'88.~70 °F 1,.92'~68.°F1.13 0 R,~ ~Me,,.Te~. !__,.03 ~72. °F 1.,.g1.~66 °F 0.,.~ '-TR, ~BHT' 0,98'~13.4.?F 1.02~135°F0.65 (~'14~F.0.88 ¢~154°F ~e S'jn~e Circ. 5 HR S. 8 HR S, · 8' HR S MaX. Rec: letup. ' 134 .'-' aF 135 . 'oF 1.4~ .' . ..... - '.. ,.. '; _ . ,., . , , ~ L I , ' ~- , ,.. h, '., ~, ,: ..... el, g 0 0 :'
