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173-035
1 Winston, Hugh E (CED) From:Carlisle, Samantha J (CED) Sent:Wednesday, September 8, 2021 4:46 PM To:Winston, Hugh E (CED) Subject:FW: Withdraw Sundry #320-430 - MGS A13-12RD PTD: 173-035 From: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov> Sent: Wednesday, September 8, 2021 4:44 PM To: Carlisle, Samantha J (CED) <samantha.carlisle@alaska.gov> Subject: FW: Withdraw Sundry #320‐430 ‐ MGS A13‐12RD PTD: 173‐035 See below… Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250‐9193 From: Juanita Lovett <jlovett@hilcorp.com> Sent: Wednesday, September 8, 2021 3:22 PM To: McLellan, Bryan J (CED) <bryan.mclellan@alaska.gov>; Katherine O'connor <Katherine.Oconnor@hilcorp.com> Subject: Withdraw Sundry #320‐430 ‐ MGS A13‐12RD PTD: 173‐035 Bryan, Please withdraw the above mentioned sundry. The project will not be completed at this time. Scope of work was to add perforations in the Hemlock. Regards, Juanita L Lovett Sr. Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 | Anchorage | AK | 99503 (907) 777-8332 | jlovett@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, 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): 9,900'N/A Casing Collapse Structural Conductor Surface 1,540 psi Intermediate 3,090 psi Production 5,410 psi Liner 7,020 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: 9,596' 9,726' 9,397' 3,528 psi 3,608' 7" 6,271'7" 9,898' 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. 10/24/2020 2-7/8" Daniel E. Marlowe Baker DB Packer & Baker T-5 SSSV 8,578 - 9,723 8,466 (MD) 8,224 (TVD) & 326 (MD) 326 (TVD) Tubing Grade:Tubing MD (ft): 8,323 - 9,394 Perforation Depth TVD (ft): 9,563' 6.5 # / N-80 9-5/8"6,501' 1,593' 6,290' Perforation Depth MD (ft): 6,501' 6,290' 1,592' 6,474' 370' 1,593' 24" 13-3/8" 370' TVD Burst 8,523' 7,240 psi 8,160 psi Tubing Size: MD 3,090 psi 370' 173-035 50-733-20191-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC MGS A13-12RD CO 44A 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 PRESENT WELL CONDITION SUMMARY Length Size 5,750 psi N/A Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 2:04 pm, Oct 09, 2020 320-430 Digitally signed by Daniel Marlowe DN: cn=Daniel Marlowe, ou=Users Reason: I am approving this document Date: 2020.10.08 18:14:42 -08'00' Daniel Marlowe 10-404 Perforate SFD 10/12/2020 DSR-10/12/2020gls 10/12/20 Comm. on Required? Yes 10/13/2020 dts 10/12/2020 JLC 10/13/2020 RBDMS HEW 11/12/2020 Well Work Prognosis Well Name:MGS A13-12RD API Number:50- 733-20191-01 Current Status:Gas Lifted Producer Leg:Leg #4 (West) Estimated Start Date:10/24/2020 Rig:E-line Reg. Approval Required? 403 Date Reg. Approval Received: Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:173-035 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:3,493 psi @ 8,732’ TVD 0.4 psi/ft (7.69 ppg) Maximum Expected BHP:4,366 psi @ 8,732’ TVD 0.4 psi/ft (7.69 ppg) Max Potential Surface Pressure (MPSP): 3,528 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary Well A13-12RD is a gas lifted producer completed in Hemlock sands. This well recently underwent a CTCO and we would like to add perforations in the Hemlock. Procedure: 1. MIRU E-line, PT lubricator to 3750 psi Hi/250 Low. 2. RU e-line guns and perforate 3. RD E-line. 4. Turn well over to production. Attachments: 1. Well Schematic – Current 2. Well Schematic - Proposed Well A13-12RD is a gas lifted producer completed in Hemlock sands. This well recently underwent a CTCO and we would like to add perforations in the Hemlock. _____________________________________________________________________________________ Updated By: JLL 10/17/18 SCHEMATIC Middle Ground Shoal Well: MGS A13-12RD Last Completed: 8/12/2000 PTD: 173-035 API: 50-733-20191-01 PBTD =9,809’ TD =9,900’ 13-3/8” KB: 38’ Water Depth: 73’ 7” 9-5/8” Estimated TOC @ 4,778’ TOC @ 7,250’ Hole @ 5,370’ 24” ted @ 8’ X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 24” Surf 370’ 13-3/8” 61 J-55 BTC 12.515” Surf 1,593’ 9-5/8” 40 N-80 BTC 8.835” Surf 5,131’ 43.5 N-80 BTC 8.755” 5,131’ 6,478’ 47 N-80 BTC 8.525” 6,478’ 6,501’ (TOW) 7” Tieback 26 N-80 BTC 6.276” Surf 6,290’ 7” Liner 29 N-80 BTC SCC 6.184” 6,290’ 9,898’ TUBING DETAIL 2-7/8” 6.5 N-80 EUE 8rd 2.441” Surf 8,523’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 36.66’ CIW Hanger 1 326’ 326’ 2.313 4.630 Baker T5 SSSV 2 1,976’ 1,975’ GLM #1 – Macco 3 3,567’ 3,565’ GLM #2 – Macco 4 4,873’ 4,870’ GLM #3 – Macco 5 5,770’ 5,764’ GLM #4 – Macco 6 6,605’ 6,574’ GLM #5 – Macco 7 7,279’ 7,182’ GLM #6 – Macco 8 7,883’ 7,709’ GLM #7 – Macco 9 8,383’ 8,151’ GLM #8 – Macco - Orifice 10 8,426’ 8,189’ 2.313 3.125 X-Nipple 11 8,465’ 8,223’ 2.437 3.500 Locator Sub w/ 4 seals & muleshoe (11.10’) 8,466’ 8,224’ 3.250 5.750 Baker DB Perm Packer (84-32) 8,470’ 8,227’ 3.250 5.750 10’ Sealbore Extension (80-32) 12 8,515’ 8,267’ 2.205 3.125 XN Nipple 13 8,522’ 8,273’ 2.500 3.625 Wire Re-Entry Guide Wireline Detail & Fish Date Depth Description 09/15/2020 9,726’ CTCO & Tag 09/30/2018 9,398’ CT Tag / Obstruction 09/29/2018 9,696’ CT Tag 03/15/2017 9,394’ 1.5", 1.75", 2", 2-1/2" Scratchers - 1.50" star drill - 1.25" & 1.50" DD bailers 8/2009 9,703’ Wireline tag 8/2000 9,710’ Fish (Packer) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status F 8,578' 8,664' 8,323' 8,401' 86' Open HK1 9,043' 9,067' 8,747' 8,769' 24' Open HK1 9,076' 9,120' 8,777' 8,819' 44' Open HK1 9,203' 9,217' 8,897' 8,910' 14' Open HK2 9,323' 9,365' 9,008' 9,055' 50' Open HK2 9,394' 9,544’ 9,077' 9,222’ 150’ Open HK2 9,562’ 9,723’ 9,239’ 9,394’ 161’ Open _____________________________________________________________________________________ Updated By: JLL 10/07/20 PROPOSED Middle Ground Shoal Well: MGS A13-12RD Last Completed: 8/12/2000 PTD: 173-035 API: 50-733-20191-01 PBTD =9,809’ TD =9,900’ 13-3/8” KB: 38’ Water Depth: 73’ 7” 9-5/8” Estimated TOC @ 4,778’ TOC @ 7,250’ Hole @ 5,370’ 24” ted @ 8’ X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 24” Surf 370’ 13-3/8” 61 J-55 BTC 12.515” Surf 1,593’ 9-5/8” 40 N-80 BTC 8.835” Surf 5,131’ 43.5 N-80 BTC 8.755” 5,131’ 6,478’ 47 N-80 BTC 8.525” 6,478’ 6,501’ (TOW) 7” Tieback 26 N-80 BTC 6.276” Surf 6,290’ 7” Liner 29 N-80 BTC SCC 6.184” 6,290’ 9,898’ TUBING DETAIL 2-7/8” 6.5 N-80 EUE 8rd 2.441” Surf 8,523’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 36.66’ CIW Hanger 1 326’ 326’ 2.313 4.630 Baker T5 SSSV 2 1,976’ 1,975’ GLM #1 – Macco 3 3,567’ 3,565’ GLM #2 – Macco 4 4,873’ 4,870’ GLM #3 – Macco 5 5,770’ 5,764’ GLM #4 – Macco 6 6,605’ 6,574’ GLM #5 – Macco 7 7,279’ 7,182’ GLM #6 – Macco 8 7,883’ 7,709’ GLM #7 – Macco 9 8,383’ 8,151’ GLM #8 – Macco - Orifice 10 8,426’ 8,189’ 2.313 3.125 X-Nipple 11 8,465’ 8,223’ 2.437 3.500 Locator Sub w/ 4 seals & muleshoe (11.10’) 8,466’ 8,224’ 3.250 5.750 Baker DB Perm Packer (84-32) 8,470’ 8,227’ 3.250 5.750 10’ Sealbore Extension (80-32) 12 8,515’ 8,267’ 2.205 3.125 XN Nipple 13 8,522’ 8,273’ 2.500 3.625 Wire Re-Entry Guide Wireline Detail & Fish Date Depth Description 09/15/2020 9,726’ CTCO & Tag 09/30/2018 9,398’ CT Tag / Obstruction 09/29/2018 9,696’ CT Tag 03/15/2017 9,394’ 1.5", 1.75", 2", 2-1/2" Scratchers - 1.50" star drill - 1.25" & 1.50" DD bailers 8/2009 9,703’ Wireline tag 8/2000 9,710’ Fish (Packer) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status F 8,578' 8,664' 8,323' 8,401' 86' Open HK1 9,043' 9,067' 8,747' 8,769' 24' Open HK1 9,076' 9,120' 8,777' 8,819' 44' Open HK1 9,203' 9,217' 8,897' 8,910' 14' Open HK1C ±9,210’ ±9,238’ ±8,904’ ±8,930’ ±28’ Future Proposed HK2 9,323' 9,365' 9,008' 9,055' 50' Open HK2B ±9,380’ ±9,390’ ±9,064’ ±9,074’ ±10’ Future Proposed HK2 9,394' 9,544’ 9,077' 9,222’ 150’ Open HK2 9,562’ 9,723’ 9,239’ 9,394’ 161’ Open HK1C ±9,210’±9,238’±8,904’±8,930’±28’Future Proposed HK2B ±9,380’±9,390’±9,064’±9,074’±10’Future 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 9,900 feet N/A feet true vertical 9,596 feet N/A feet Effective Depth measured 9,726 feet 8,466 feet true vertical 9,397 feet 8,224 feet Perforation depth Measured depth 8,578 - 9,723 feet True Vertical depth 8,323 - 9,394 feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# / N-80 8,523 MD 8,274 TVD 8,466 (MD) 326 (MD) Packers and SSSV (type, measured and true vertical depth)Baker DB Pkr 8,224 (TVD) Baker T-5 326 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: TVD measured true vertical Packer Other: CTCO / N2 Operations OilSafe AR Acid 7" 7" 6,290 MD 370 1,593 9,898 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 9 Representative Daily Average Production or Injection Data 9323 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 173-035 50-733-20191-01-00 Plugs ADL0018754 MGS A13-12RD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-325 85 Authorized Signature with date: Authorized Name: 98 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 29 Gas-Mcf 371 Pumped 62 bbl OilSafe AR displacing with FIW. Final Pressures: T/IA/OA/OOA = 7/810/80/0. Oil-Bbl 2 Water-Bbl Intermediate 8,578 - 9,723 Junk 5. Permit to Drill Number: 6 Middle Ground Shoal / MGS Oil PoolN/A measured 6,501 6,290 Size 524 Production Casing Structural Liner 3,608 Length 370 1,593 Conductor Surface 7,020psi 5,410psi 24" 13-3/8" 9-5/8" 6,501 5,750psi 907 777-8376 7,240psi 370 1,592 6,474 6,271 9,563 Collapse Katherine O'Connor Katherine.oconnor@hilcorp.com Tubing Pressure 1,540psi 3,090psi 3,090psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 8,160psi Daniel E. Marlowe Operations Manager Burst Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:43 am, Oct 06, 2020 Daniel Marlowe I am approving this document 2020.10.05 16:22:46 -08'00' Daniel Marlowe SFD 10/6/2020 CTCO / N2 lSafe AR Acid DSR-10/12/2020gls 10/14/20 Operations Oi RBDMS HEW 10/30/2020 _____________________________________________________________________________________ Updated By: JLL 10/17/18 SCHEMATIC Middle Ground Shoal Well: MGS A13-12RD Last Completed: 8/12/2000 PTD: 173-035 API: 50-733-20191-01 PBTD =9,809’ TD =9,900’ 13-3/8” KB: 38’ Water Depth: 73’ 7” 9-5/8” Estimated TOC @ 4,778’ TOC @ 7,250’ Hole @ 5,370’ 24” ted @ 8’ X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 24” Surf 370’ 13-3/8” 61 J-55 BTC 12.515” Surf 1,593’ 9-5/8” 40 N-80 BTC 8.835” Surf 5,131’ 43.5 N-80 BTC 8.755” 5,131’ 6,478’ 47 N-80 BTC 8.525” 6,478’ 6,501’ (TOW) 7” Tieback 26 N-80 BTC 6.276” Surf 6,290’ 7” Liner 29 N-80 BTC SCC 6.184” 6,290’ 9,898’ TUBING DETAIL 2-7/8” 6.5 N-80 EUE 8rd 2.441” Surf 8,523’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 36.66’ CIW Hanger 1 326’ 326’ 2.313 4.630 Baker T5 SSSV 2 1,976’ 1,975’ GLM #1 – Macco 3 3,567’ 3,565’ GLM #2 – Macco 4 4,873’ 4,870’ GLM #3 – Macco 5 5,770’ 5,764’ GLM #4 – Macco 6 6,605’ 6,574’ GLM #5 – Macco 7 7,279’ 7,182’ GLM #6 – Macco 8 7,883’ 7,709’ GLM #7 – Macco 9 8,383’ 8,151’ GLM #8 – Macco - Orifice 10 8,426’ 8,189’ 2.313 3.125 X-Nipple 11 8,465’ 8,223’ 2.437 3.500 Locator Sub w/ 4 seals & muleshoe (11.10’) 8,466’ 8,224’ 3.250 5.750 Baker DB Perm Packer (84-32) 8,470’ 8,227’ 3.250 5.750 10’ Sealbore Extension (80-32) 12 8,515’ 8,267’ 2.205 3.125 XN Nipple 13 8,522’ 8,273’ 2.500 3.625 Wire Re-Entry Guide Wireline Detail & Fish Date Depth Description 09/15/2020 9,726’ CTCO & Tag 09/30/2018 9,398’ CT Tag / Obstruction 09/29/2018 9,696’ CT Tag 03/15/2017 9,394’ 1.5", 1.75", 2", 2-1/2" Scratchers - 1.50" star drill - 1.25" & 1.50" DD bailers 8/2009 9,703’ Wireline tag 8/2000 9,710’ Fish (Packer) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status F 8,578' 8,664' 8,323' 8,401' 86' Open HK1 9,043' 9,067' 8,747' 8,769' 24' Open HK1 9,076' 9,120' 8,777' 8,819' 44' Open HK1 9,203' 9,217' 8,897' 8,910' 14' Open HK2 9,323' 9,365' 9,008' 9,055' 50' Open HK2 9,394' 9,544’ 9,077' 9,222’ 150’ Open HK2 9,562’ 9,723’ 9,239’ 9,394’ 161’ Open Well Name Rig API Number Well Permit Number Start Date End Date MGS A13-12RD CTU 50-733-20191-01 173-035 9/14/2020 9/21/2020 Daily Operations: 09/21/20 - Monday Well brought online post safe acid soak PJSM & Permits. Make up Run #1( CTC 1.68" X .30' ), (DFCV 1.70" X 1.29') ( Stinger 1.70" x 4.93') ( Stinger 1.70" X 4.93') ( XO 1.5" X .42') ( DJN 1.5" X .50') TOL= 12.37'. Stab on well, fluid pack for pt low/high 250/5000. Open well (swab 15.5 T), T/IA/OA/OOA= 180/884/75/0. RIH, choke open, for dry tag @ 9055', 9055' KB. Fire up pump & bring online w/ FIW = 1.10 BPM, CTP = 4000. RIH digging, w/ wiper trips for cleanup, to 9527' pumping FIW w/ 3 bbl FloVis L gel sweeps. 1:1 returns, T/IA = 12/936, 9527' Gel sweep #1 @ end of coil. Continue digging, pump #2 sweep (3 bbl) & #3 sweep (4 bbl) w/ cleanup wiper trips. Dig to 9726' KB. Chase Sweep #3 back to tbg tail & circulate 4 bbl sweep OOH. RBIH. 9726' KB Circulate OilSafe AR to end of coil. PUH @ 25 fpm laying in 62 bbl of OilSafe AR to 7" prod. liner @ 1.0 bpm pump rate displacing OilSafe AR from coil w/ FIW. 62 bbl OilSafe AR away. Stop pump & POOH, Return to surface. Final T/IA/OA /OOA = 7/810/80/0. Close swab. Break off well, LD BHA & lubricator. Ship all flowback tank fluids to Platform A day tank for transfer to MGS Onshore. Let OilSafe AR soak as per procedures. Rig down BOP & risers. Secure well & well room. Begin rigging down CTU package prepping for backload to boats & move to Platform C. 225 bbls of FIW & 10 bbls of FloVisL shipped to Platform A day tank & transferred to MGS Onshore. Non-produced fluids transfer form emailed to MGS Onshore. 09/14/20 - Monday PJSM & Permits. Rig up Lub, riser and hardline for bop test. Test BOPE as per Hilcorp & AOGCC requirements, witnessed waived 9/13/2020 @ 0820 AM by AOGCC Inspections Supervisor Jim Regg, 250/4500. Emailed BOPE Test Report to AOGCC. Make up BHA, PT low/high 250/3500, RIH w/ BHA #1: CTC(1.68" X 0.30'), DFCV(1.70" X 1.29'), Jar(1.70" X 5.14'), Disco(1.70" X 1.43'), Rupture Sub(1.70 X 0.34, 5K), Circ Sub(1.70" X 0.86'), Titan PDM (1.70" x 11.20'), Junk Mill (2.125" x 0.74') OAL = 21.30'. PT BHA to Disco = 3500. Disco Ball = 1/2" Circ. Sub ball = 0.406". Move to well. PT WHA & Lub = 4500. Open swab (15.5T). Initial T/IA/OA = 70/250/65. RIH w/ motor & 2.125" 3-blade mill for dry tag @ 8886' KB. Bring on pump @ 1.2 bpm, CTP = 2584 psi. Dig to 8890'. PUH into tbg @ 8385' waiting on returns to surface. PR = 1.10 bpm FIW w/ 1:1 returns. RIH slowly & dig to 9180' taking 50' bites w/ wiper trips. T/IA/OA = 11/924/65,9180' dig to 9726' KB. POOH chasing solids to surface. OOH. Final T/IA/OA = 55/797/75. Close swab. Break off well & stand back injector. LD motor & mill, secure injector, well room, drill & pipe deck. SDFN. Job in progress. Shipped 180 bbl of FIW well returns to Platform A/ MGS Onshore and emailed non-produced fluid transfer form to MGS Onshore. 09/15/20 - Tuesday Hilcorp Alaska, LLC Well Operations Summary for dry tag @ 9055', 9055' Test BOPE as per Hilcorp & AOGCC requirements PT WHA & Lub = 4500. 9726' KB Circulate OilSafe AR to end of coil. PUH @ 25 fpm laying in 62 bbl of OilSafe AR to 7" prod. liner @ 1.0 bpm pump rate displacing OilSafe AR from coil w/ FIW. 62 bbl OilSafe AR away. Stop . Dig to 9726' KB. 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): 9,900'N/A Casing Collapse Structural Conductor Surface 1,540 psi Intermediate 3,090 psi Production 5,410 psi Liner 7,020 psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 5,750 psi N/A COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018754 Burst 8,523' 7,240 psi 8,160 psi Tubing Size: 173-035 50-733-20191-01-00Anchorage, AK 99503 Hilcorp Alaska, LLC MGS A13-12RD MD 3,090 psi 370' 1,592' 6,474' 370' 1,593' TVD 24" 13-3/8" 370' 9-5/8"6,501' 1,593' Perforation Depth MD (ft): 6,501' 8,578 - 9,723 6,290' 8,466 (MD) 8,224 (TVD) & 326 (MD) 326 (TVD) Tubing Grade:Tubing MD (ft): 8,323 - 9,394 Perforation Depth TVD (ft): 6.5 # / N-80 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. 8/21/2020 2-7/8" Daniel E. Marlowe Baker DB Perm Pkr & Baker T-5 SSSV 3,608' 7" 6,271'7" 9,898' 9,563' 6,290' Other: CTCO / N2 Operations/Oil Safe AR Acid N/A 9,596' 9,398' 9,081' 3,528 psi Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Jody Colombie at 6:42 pm, Aug 06, 2020 320-325 Digitally signed by Daniel Marlowe DN: cn=Daniel Marlowe, ou=Users Date: 2020.08.06 14:28:14 -08'00' Daniel Marlowe gls 8/19/20 10-404 X DSR-8/7/2020 acid soak DLB 08/07/2020 *4500 psi BOPE test (CTU) X Comm. ption Required? Yes 8/20/2020 dts 8/19/20 JLC 8/19/2020 RBDMS HEW 8/20/2020 Well Work Prognosis Well Name: MGS A13-12RD API Number: 50- 733-20191-01 Current Status: Gas Lifted Producer Leg: Leg #4 (West) Estimated Start Date: 8/21/2020 Rig: Coil Tubing Reg. Approval Required? 403 Date Reg. Approval Received: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 173-035 First Call Engineer: Katherine O’Connor (907) 777-8376 (O) (214) 684-7400 (M) Second Call Engineer: Karson Kozub (907) 777-8384 (O) (907) 570-1801 (M) Current Bottom Hole Pressure: 3,493 psi @ 8,732’ TVD 0.4 psi/ft (7.69 ppg) Maximum Expected BHP: 4,366 psi @ 8,732’ TVD 0.4 psi/ft (7.69 ppg) Max Potential Surface Pressure (MPSP): 3,528 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary Well A13-12RD is a gas lifted producer completed in Hemlock sands. This well has a history of scaling over and a 2019 wireline drift confirmed the liner is scaling up . This procedure will clean-out fill covering the perforations and acidize the perforations. Safety Concerns: x Discuss nitrogen asphyxiation concerns and identify any areas where nitrogen could collect and people could enter. x Consider tank placement based on wind direction and current weather forecast (venting methane and Nitrogen during this job) x Ensure all crews are aware of stop job authority (Review Standard Well Procedure – Nitrogen Operations) Procedure: 1. MIRU Coil Tubing. 2. NU BOP and test to 250psi low / 4,500psi High. (Note: Notify AOGCC 48 hours in advance of test) 3. RIH cleaning out fill to bottom of the perf interval using FIW and/or acid. a. Have milling tool string on hand for contingent scale milling as needed b. Circulate well clean with FIW using N2 assist if needed. 4. Lay ±2210 gallons of Oilsafe AR synthetic acid across perforations 5. Displace with CT volume of FIW. RDMO 6. Soak for ±72 hours 7. Turn well over to operations to POP. Attachments: 1. Well Schematic - Current/Proposed (Same) 2. Wellhead Diagram - Current 3. Coil Tubing BOP Drawing 4. Flow Diagrams ---Nitrogen FCO contingency Well Work Prognosis 5. Oil Safe AR – Technical Data Sheet 6. Standard Well Procedure – Nitrogen Operations 7. Sundry Revision Change Form _____________________________________________________________________________________ Updated By: JLL 10/17/18 SCHEMATIC Middle Ground Shoal Well: MGS A13-12RD Last Completed: 8/12/2000 PTD: 173-035 API: 50-733-20191-01 PBTD =9,809’ TD =9,900’ 13-3/8” KB: 38’ Water Depth: 73’ 7” 9-5/8” Estimated TOC @ 4,778’ TOC @ 7,250’ Hole @ 5,370’ 24” ted @ 8’ X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 24” Surf 370’ 13-3/8” 61 J-55 BTC 12.515” Surf 1,593’ 9-5/8” 40 N-80 BTC 8.835” Surf 5,131’ 43.5 N-80 BTC 8.755” 5,131’ 6,478’ 47 N-80 BTC 8.525” 6,478’ 6,501’ (TOW) 7” Tieback 26 N-80 BTC 6.276” Surf 6,290’ 7” Liner 29 N-80 BTC SCC 6.184” 6,290’ 9,898’ TUBING DETAIL 2-7/8” 6.5 N-80 EUE 8rd 2.441” Surf 8,523’ JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 36.66’ CIW Hanger 1 326’ 326’ 2.313 4.630 Baker T5 SSSV 2 1,976’ 1,975’ GLM #1 – Macco 3 3,567’ 3,565’ GLM #2 – Macco 4 4,873’ 4,870’ GLM #3 – Macco 5 5,770’ 5,764’ GLM #4 – Macco 6 6,605’ 6,574’ GLM #5 – Macco 7 7,279’ 7,182’ GLM #6 – Macco 8 7,883’ 7,709’ GLM #7 – Macco 9 8,383’ 8,151’ GLM #8 – Macco - Orifice 10 8,426’ 8,189’ 2.313 3.125 X-Nipple 11 8,465’ 8,223’ 2.437 3.500 Locator Sub w/ 4 seals & muleshoe (11.10’) 8,466’ 8,224’ 3.250 5.750 Baker DB Perm Packer (84-32) 8,470’ 8,227’ 3.250 5.750 10’ Sealbore Extension (80-32) 12 8,515’ 8,267’ 2.205 3.125 XN Nipple 13 8,522’ 8,273’ 2.500 3.625 Wire Re-Entry Guide Wireline Detail & Fish Date Depth Description 09/30/2018 9,398’ CT Tag / Obstruction 09/29/2018 9,696’ CT Tag 03/15/2017 9,394’ 1.5", 1.75", 2", 2-1/2" Scratchers - 1.50" star drill - 1.25" & 1.50" DD bailers 8/2009 9,703’ Wireline tag 8/2000 9,710’ Fish (Packer) PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status F 8,578' 8,664' 8,323' 8,401' 86' Open HK1 9,043' 9,067' 8,747' 8,769' 24' Open HK1 9,076' 9,120' 8,777' 8,819' 44' Open HK1 9,203' 9,217' 8,897' 8,910' 14' Open HK2 9,323' 9,365' 9,008' 9,055' 50' Open HK2 9,394' 9,544’ 9,077' 9,222’ 150’ Open HK2 9,562’ 9,723’ 9,239’ 9,394’ 161’ Open Platform A Well 13-12RD 08/28/2018 Platform A 13-12RD 13 3/8 x 9 5/8 x 7 x 2 7/8 Tubing hanger, CIW-F-FBB- CL, 11 x 2 7/8 EUE 8rd lift and susp, w/ 2 1/2'’ type H BPV profile, 1- 1/8 npt control line port 13 3/8'’ 9.625'’ BHTA, CIW, External knock-up, 2 9/16 5M FE Valve, Swab, WKM-M, 2 9/16 5M FE, HWO, EE trim Valve, Master, WKM-M, 2 9/16 5M FE, HWO, EE trim V a lv e ,W in g ,W K M -M ,2 1 /1 6 5 M F E ,H W O ,E E trim Casing head, CIW-WF, 13 5/8 3M FE top x 13 3/8 SOW btm, w/ 2- 2 1/16 5M EFO Tubing head, CIW-F, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO, X bottom prep Casing spool, CIW-WF, 13 5/8 3M x 13 3/8 3M , w/ 2- 2 1/16 5M EFO, X bottom prep V a lv e ,W in g ,S S V ,W K M -M ,2 1 /1 6 5 M F E ,E E trim 7'’ 2 7/8'’ Valve, Master, WKM-M, 2 9/16 5M FE, HWO, EE trim Coiled Tubing BOP SWAB VALVE MASTER VALVE HilcorpMonopod Rig 56Flow Diagram Fluids Pumped Fluids ReturnedValve Open Valve ClosedGate Valve Ball ValveButterfly Valve Lo Torq ValveAutomatic Choke Manual ChokePressure Gauge Knife ValveChoke LineP PIT SYSTEM SucƟon SHAKER SHAKER CHOKE MANIFOLDGAS BUSTER Panic LineC12 C13 C15 C14 C16 A B C4 C5 C6 C7 C2 C10 C9 C11 C8 C3 P C1 C STANDARD WELL PROCEDURE NITROGEN OPERATIONS 09/23/2016 FINAL v-offshore Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Facility Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Nitrogen Tank. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure supplier has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Tank. Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Rig Work Over Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: MGS A13-12RD (PTD 173-035)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ECEIVE® APR 0 8 2019 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate U Pull Tubing Li A-61U61a— Li Performed: Suspend ❑ Perforate ❑ Other Stimulate Q Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Oil Safe AR Acid ❑� 2. Operator 4. Well Class Before Work:5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Q Exploratory ❑ Stratigraphic ❑ Service ❑ 173-035 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20191-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018754 MGS Al3-12RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Poo fs): N/A Middle Ground Shoal / E,F and G Oil and Middle Ground Shoal Oil Pools 11. Present Well Condition Summary: Total Depth measured 9,900 feet Plugs measured N/A feet true vertical 9,596 feet Junk measured 9,710 feet Effective Depth measured 9,398 feet Packer measured 8,466 feet true vertical 9,081 feet true vertical 8,224 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 370' 24" 370' 370' Surface 1,593' 13-3/8" 1,593' 1,592' 3,090 psi 1,540 psi Intermediate 6,501' 9-5/8" 6,501' 6,474' 5,750 psi 3,090 psi Production 6,290' T' 6,290' 6,271' 7,240 psi 5,410 psi Liner 3,608' 7" 9,898' 9,563' 8,160 psi 7,020 psi Perforation depth Measured depth 8,578 - 9,723 feet True Vertical depth 8,323 - 9,394 feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5 / N-80 8,523 (MD) 8,274 (TVD) 8,466 (MD) 326 (MD) Packers and SSSV (type, measured and true vertical depth) Baker DB Perm Pkr 8,224 (TVD) Baker T-5 SSSV 326 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8,578 - 9,723 Treatment descriptions including volumes used and final pressure: Pumped 5,775 gallons OIISafe AR acid and 65 bbls FIW. Final pressure 80#. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 27 9 22 352 98 Subsequent to operation: 11 3 28 329 88 14. Attachments (required per 20 A C 25.070, 25.071, & 25283) 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development 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. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-106 Authorized Name: Stan W. Golfs Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe(a)hilcom.com �l Authorized Signature: Date: t Dl Contact Phone: (907) 283-1329 }L _ �j Form 10404 Revised 4/2017 (/// �'� RBLM$J��''%iPR 0 9 2MSubmit Original Only K corp Alaska. LLC KB: 38' Water Depth: 73' SCHEMATIC CASING DETAIL Middle Ground Shoal Well: MGS A13-12RD Last Completed: 8/12/2000 PTD: 173-035 API: 50-733-20191-01 Size Wt Grade Conn ID Top Btm 24" Btm (MD) Top (TVD) (Np) CIW Hanger Surf 370' 13-3/8" 61 J-55 BTC 12.515" Surf 1,593' 9,043' 40 N-80 BTC 8.835" Surf 5,131' 9-5/8" 43.5 N-80 BTC 8.755" 5,131' 6,478' GLM#3-Macco 47 N-80 BTC 8.525" 6,478' 6,501'(TOW) 7" Tieback 26 N-80 BTC 6.276" Surf 6,290' 7" Liner 29 N-80 BTCSCC 6.184" 6,290' 9,898' TUBING DETAIL 2-7/8" 6.5 N-80 EUE 8rd 1 2.441" Surf 8,523' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Zone 36.66' Btm (MD) Top (TVD) (Np) CIW Hanger 1 326' 326' 2.313 4.630 Baker T5 SSSV 2 1,976' 1,975' 9,043' 9,067' GLM#1-Masco 3 3,567' 3,565' HKl 9,076' GLM#2-Macco 4 4,873' 4,870' Open HKl GLM#3-Macco 5 5,770' 5,764' 14' Open GLM #4-Macco 6 6,605' 6,574' 9,055' 50' GLM#5-Macco 7 7,279' 7,182' 9,077' 9,222' GLM#6-Macco 8 7,883' 7,709' 9,723' 9,239' GUM #7-Macco 9 8,383' 8,151' GUM #8-Macco-Orifice 10 8,426' 8,189' 2.313 3.125 X -Nipple 8,465' 8,223' 2.437 3.500 Locator Sub w/4 seals& muleshoe(11.10') 11 8,466' 8,224' 3.250 5.750 Baker DB Perm Packer (84-32) 8,470' 8,227' 3.250 5.750 10'Sealbore Extension (80-32) 12 8,515' 8,267' 2.205 3.125 XN Nipple 13 8,522' 8,273' 2.500 3.625 Wire Re -Entry Guide Updated By: JLL 10/17/18 Wireline Detail & Fish PERFORATION DETAIL Depth Description Zone Top (MD) Btm (MD) Top (TVD) (Np) FT Date Status F 8,578' 8,664' 8,323' 8,401' 86' Open HKi 9,043' 9,067' 8,747' 8,769' 24' Open HKl 9,076' 9,120' 8,777' 8,819' 44' Open HKl 9,203' 9,217' 8,897' 8,910' 14' Open HK2 9,323' 9,365' 9,008' 9,055' 50' Open HK2 9,394' 9,544' 9,077' 9,222' 150' Open HK2 9,562' 9,723' 9,239' 9,394' 161' Open Updated By: JLL 10/17/18 Wireline Detail & Fish Date Depth Description 09/30/2018 9,398' CT Tag/ Obstruction 09/29/2018 9,696' CT Tag 03/15/2017 9,394' 1.5", 1.7511, 211, 2-1/2" Scratchers- 1.50" star drill -1.25" & 1.50" DD bailers 8/2009 9,703' Wireline tag 8/2000 9,710' Fish (Packer) Updated By: JLL 10/17/18 HHilcorp Alaska, LLC Hilrocp Alaaka, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A13-12RD Pumping Unit 50-733-20191-01 173-035 3/18/2019 3/18/2019 Daily Operations: 03/18/2019 - Monday Pressure Test pump and lines to 2000 psi. Pumping tote #1/6 safe acid tbg-400 IA— 507, OA — 72. Pump tote #2/6 safe acid. Tbg —140 IA — 508, IA- 70. Pump tote #3/6 safe acid. Tbg- 0, IA-516, OA-68. Pump tote #4/6 safe acid. Tbg-0, IA-557, OA-63. Pump tote #5/6 safe acid. Tbg-0, IA-585, OA-61. Pump tote #6/6 safe acid. TBG-0, IA-600, OA-59. Pump tote #1/10FIW. Tbg-0, IA-614, OA-58. Pump tote #2/10 FIW. Tbg-0, IA-628, OA-57. Pump tote #3/IOFIW. Tbg-0, IA-642, OA-57. Pump tote #4/IOFIW. Tbg-0, IA-655 OA-60. Pump tote #5/10FIW. Tbg- 0, IA- 670, OA-60. Pump tote #6/10FIW. Tbg-0, IA-688, OA-60. Pump tote #7/10FIW. Tbg-40, IA-706, OA-60. Pump tote #8/IOFIW. Tbg- 30 IA- 724, OA-62. Pump tote #9/10FIW. Tbg-30 IA-743, OA-63. Pump tote #10/10FIW. Tbg-30 IA-763, OA-63. Done pumping (65 bbl)FIW. Tbg-80, IA-785, OA-63. Rigging down and cleaning up. 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 �.00gcc.alaska.gov Re: Middle Ground Shoal Field, E, F, and G Oil and Middle Ground Shoal Oil Pools, MGS A13-12RD Permit to Drill Number: 173-035 Sundry Number: 319-106 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, Daniel T. Seamount, Jr. Commissioner DATED this ?-dfayyoof March, 2019. oMs� MP ft � � 1p19 �8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 95 280 o", rte` fr e A 1 7 rL.. u 1,,"�9rw v -a 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ AC -0 Other Stimulate Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Dil Safe AR (*40)2 2. Operator Name: 4. Current Well Class:5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory 11 Development Q Stratigraphic ❑ Service ❑ 173-035 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20191-01-00 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 A13-12RD 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018754 I Middle Ground Shoal / E,F and G Oil and Middle Grnd Shoal 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): 9,900 9,596 9,398 9,081 ±5,000psi N/A 9,710 Casing Length Size MD TVD Burst Collapse Structural Conductor 370' 24" 370' 370' Surface 1,593' 13-3/8" 1,593' 1,592' 3,090 psi 1,540 psi Intermediate 6,501' 9-5/8" 6,501' 6,474' 5,750 psi 3,090 psi Production 6,290' 7" 6,290' 6,271' 7,240 psi 5,410 psi Liner 3,608' 7" 9,898' 9,563' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (fl): 8,578 - 9,723 8,323 - 9,394 2-7/8" 6.5# / W80 8,523 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker DB Penn Pkr & Baker T-5 SSSV 8,466 (MD) 8,224 (TVD) & 326 (MD) 326 (TVD) 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: 3/20/2019 OIL Q WIND ❑ 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. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarIOW@ hIICOr .COM Contact Phone: (907) 283-1329 S�. Authonzed Signature: Date:3 / S I COMMISSIO USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3P- IOU 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 /'7 // Approved by: COMMISSIONER THE COMMISSION Date: 7 // `!/ 3-7 R MSA/ MAR CP^/Form 10-403 Revised 4/20170'4 Approved application ©a�fol t�i �top�tp date of approval. 117 0 7 2D'01/foe Submit Form and Aft chments in Duplicate . 3.6-/1p U E il.p Alaska, LLC Well Prognosis Well Name: MGS A13-12rd API Number: 50-733-20191-01 Current Status: Gas Lifted Producer Leg: Leg #4 (West) Estimated Start Date: March 20, 2019 Rig: N/A Reg. Approval Req'd? 403 Date Reg. Approval Received: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 173-035 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: Maximum Expected BHP: Maximum Potential Surface Pressure: Brief Well Summary 3,200 psi @ 8,323' TVD 0.384 psi/ft (7.39 ppg) 3,200 psi @ 8,323' TVD 0.384 psi/ft (7.39 ppg) ±5,000 psi (treatment pump limit) Well Middle Ground Shoal A13-12rd is a gas -lifted oil well completed in the Hemlock zone. 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 ±1,650 gallons Oilsafe AR (synthetic acid) Q40 01'q -j 4. Displace with ±60 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. OilsafeAR— Technical Data Sheet 4 C� . Z 71 c, 35-0 H corp Alaska. LLC KB: 38' Water Depth: 73' � :1• a •11 SCHEMATIC CASING DETAII Middle Ground Shoal Well: MGS A13-12RD Last Completed: 8/12/2000 PTD: 173-035 API: 50-733-20191-01 Size Wt I Grade Conn ID Top Btm 24" Btm (MD) Top (TVD) Btm ( CIW Hanger Surf 370' 13-3/8" 61 1-55 BTC 12.515" Surf 1,593' 9,043' 40 N-80 BTC 8.835" Surf 5,131' 9-5/8" 43.5 N-80 BTC 8.755" 5,131' 6,478' GUM #3 -Matto 47 N-80 BTC 8.525" 6,478' 6,501' (TOW) 7" Tieback 26 N-80 BTC 6.276" Surf 6,290' 7" Liner 29 N-80 BTC SCC 6.184" 6,290' 9,898' TUBING DETAIL 2-7/8" 6.5 N-80 EUE 8rd 1 2.441" Surf 8,523' JEWELRY DETAIL NO Depth (MD) Depth (TVD) ID OD Item Zone 36.66' Btm (MD) Top (TVD) Btm ( CIW Hanger 1 326' 326' 2.313 4.630 Baker T5 SSSV 2 1,976' 1,975' 9,043' 9,067' GLM #1 -Matto 3 3,567' 3,565' HK3 9,076' GUM #2 -Matto 4 4,873' 4,870' Open HK1 GUM #3 -Matto 5 5,770' 5,764' 14' Open GLM #4 -Matto 6 6,605' 6,574' 91055' 50' GLM #5 -Matto 7 7,279' 7,182' 9,077' 9,222' GUM #6 -Matto 8 7,883' 7,709' 9,723' 9,239' GUM #7 -Matto 9 8,383' 8,151' GUM #8 -Matto -Orifice 108,426' 8,189' 2.313 3.125 X -Nipple 8,465' 8,223' 2.437 3.500 Locator Sub w/4 seals& muleshoe(11.10') 31 8,466' 8,224' 3.250 5.750 Baker DB Perm Packer (84-32) 8,470' 8, 227' 3.250 5.750 l0'Sealbore Extension (80-32) 12 8,515' 8,267' 2.205 3.125 XN Nipple 13 8,522' 8,273' 2.500 3.625 Wire Re -Entry Guide Updated By: JLL 10/17/18 Wireline Detail & Fish PERFORATION DETAIL Depth Description Zone Top (MD) Btm (MD) Top (TVD) Btm ( FT Date Status F 8,578' 8,664' 8,323' 8,401' 86' Open HKl 9,043' 9,067' 8,747' 8,769' 24' Open HK3 9,076' 9,120' 8,777' 8,819' 44' Open HK1 9,203' 9,217' 8,897' 8,910' 14' Open HK2 9,323' 9,365' 9,008' 91055' 50' Open HK2 9,394' 9,544' 9,077' 9,222' 150' Open HK2 9,562' 9,723' 9,239' 9,394' 161' Open Updated By: JLL 10/17/18 Wireline Detail & Fish Date Depth Description 09/30/2018 9,398' CT Tag/Obstruction 09/29/2018 9,696' CT Tag 03/15/2017 9,394' 1.5", 1.75", 2", 2-1/2" Scratchers- 1.50" star drill -1.25" & 1.50" DD bailers 8/2009 9,703' Wireline tag 8/2000 9,710' Fish (Packer) Updated By: JLL 10/17/18 a��a TNW. �' �� COOK INLET OFFSHORE MMMD OND INSTRUMEM DNGRAII MIRTOBLE YIELL WDRK MDB a®Y1QhYC 00 Safe ARS Is a safe yet functional replacement for tradl0onalhydrochlode acid treatments and other commonly used oEEeld acid treatments. It is non-regulated by US DOT, Canadian TDO and carries a triple rem hazardous materials infomuUon•ystem acre. 0118efe AR® biodegrades In IO day. or less and Is approved by the 118 EPA" a Designed for the Environment product. Our standard OR Safe AR®formula Include. iron control agents, de-MWBMem and requires no organic acid additions or corrosion Inhibitors under most condi0ona. FEATURES AND BENEFITS: • A....]lastehe[.. I., D•ay•pearhead lroaJerome, nl•.Ilanwnlsanddh- poserrnlIa ad.rmolo seals • Raqulres DaorgaNeaald addill.. la help r.land .... It.. rales Bundardformula mcledauudaotenbnd domahi lenytem Rental ... Da Iron somal agsnt.ddlllvn for mon epp9vallam • EPADIEformula; blodsgradable, 1n 10 days arisen approved for dDecl elle. -hares; made with Dlempratlianle and DIS laynn W........dby the EPA • Bare on meal metals, plpingand pumphW equipment • Wmtarlc; nearnmin, non met.,and, no V00'e • No secondary conlalnmenl raqubad as por OLepter 62-701r.A.C. • EIIMnetes laul•nls Aneaoellenl cboleef.rwork-overproJecls, bullhead treatments and cement remadlsllen • Requires na additional corrosion lehlbiter slap for mon•ppllonlom • IW%biodegnd•bie, void nae end naturally Inhibited DISSOLVING PROPERTIES ACIDTYPE %cacor Oubabe AM 100Y. solution ORSafe AE080%Soludon 89.70% OS Safe ARG 80% Solution 94.00 7 %HCI - 48.48% 18% HCI 87.99% 7%HCI +100 gpt of89%AceticAcid 78.00% 18%HCI +100 gpt of88%AcetieAcid 87.87% 10%AcatIcAold 91.00% IB%AceOoAcld 83.09% Y•eatW abeww••wndwladMN I oS1•b.hetmaledslplaudNeOM.i •dWlan•M•Dmretl bw•kbraM •1lWR. Recommended Melon Rater; 80-100% with 1110 based on the severity of the bulld-up and the reaction rate required for the project. Nota: OB Safe ARD concentrate contains bon control agents and de-mulsiBers. No organic acidorcorrosion Inhibitors are required due to the power of ourpatented Synteoh®. A typical mile for an acid Imo la one part OB Safe At* and one partHlO. Blending mRoa may vary basedon specific applications and recommendallonafrom your consultants at Heartland Energy Group, Ltd. 0118010 AR® has a storage life abetter than one year. Keep container closed when not In use. A. with all chemicalproducta andmateriels, take care as to wharayouelore them Safety, glasses are suggested for use when handling this product. No Special gloves Or Protective equipment aro required when handling this product. When pumping if" product, It Is strongly recommended to me menufectmer approved hose couplings orf ldrugs. DO NOT USE ALUMINUM FrITINGS. 370 Stainless Steel, polypropylene, polyethylene are recommended. OR Safe An Is shipped in bulk tanker trucks from the manufacturing facility. Smaller packaging quantities are available upon request. 100,000 L C 10,000 Q LL v ° 1,000 _ Y M r0 _ � O 0 N ami � LL O 100 7 U M C 0 0 0 r � 10 1 Jan -1970 HILCORP ALASKA LLC, MGS A13-12RD (173-035) MIDDLE GROUND SHOAL, MGS OIL Monthly Production Rates Cum. Prod Oil (bbls): 2,015,740 Cum. Prod Water (bbls): 750,238 Cum. Prod Gas (mcf): 887,882 -- --- k i 4 Jan -1990 Jan -1995 Jan -2000 I --_. -.. e Produced _.. eA ° GOR -- a -- Produced Water (BOPM) —a— Produced Oil (BOPM) ,10. Y e� °d n@p^ 6 e ° Yl �n C e e e e � e -- -- — -- --- — — —� 100,000 1 Jan -2020 SPREADSHEET_Prod-Inject_Cu"eS_Well_V119_1730350_MGS A13-12RD_20190306.xlsx 3/6/2019 Jan -1975 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 e Produced Gas (MCFM) ° GOR -- a -- Produced Water (BOPM) —a— Produced Oil (BOPM) 100,000 1 Jan -2020 SPREADSHEET_Prod-Inject_Cu"eS_Well_V119_1730350_MGS A13-12RD_20190306.xlsx 3/6/2019 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, E, F, and G and Middle Ground Shoal Oil Pools, MGS A13-12RD Permit to Drill Number: 173-035 Sundry Number: 3 19-05 7 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, �� Cathy P oerster Commi sioner DATED this j �y of February, 2019. SCANNED FE3 0 7 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEB 4 AOGGG 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q' Stratigraphic ❑ Service ❑ 173-035' 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20191-01-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 44A Will planned perforations require a spacing exception? Yes ❑ No❑ MGS A13-12RD 9. Property Designation (Lease Number):10. Field/Pool(s): ADL0018754 Middle Ground Shoal/ E,F and G Oil and Middle Grind Shoal 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): 9,900 9,596 9,398 9,081 -100psi N/A 9,710 Casing Length Size MD TVD Burst Collapse Structural Conductor 370' 24" 370' 370' Surface 1,593' 13-3/8" 1,593' 1,592' 3,090 psi 1,540 psi Intermediate 6,501' 9-5/8" 6,501' 6,474' 5,750 psi 3,090 psi Production 6,290' 7" 6,290' 6,271' 7,240 psi 5,410 psi Liner 3,608' 7" 9,898' 9,563' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8,578 - 9,723 8,323 - 9,394 2-7/8" 6.5# / N-80 8,523 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker DS Perm Pkr & Baker T-5 SSSV 8,466 (MD) 8,224 (TVD) & 326 (MD) 326 (TVD) 12. Attachments: Proposal Summary El Wellbore schematic 141 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/1/2019 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. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dRlarlowe d hIIcor .cOm Contact Phone: (907) 283-1329 \ Q Authorized Signature: W h-. Date. Z y I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: iG- 0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No E] L/ Spacing Exception Required? Yes No Subsequent Form Required: o — T� ❑ I,1,.-�J,,(( APPROVED BY �,/ �,, Approved by:6124 4rA/'/� — COMMISSIONER THE COMMISSION Date: 2 - 7- �.s,f ORIGINAL RBDMSVV"fEB 0 7 2019Submit Fomand Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. /Attachments in Duplicate /�Z/fi/9 ---A— z-s.If* U Hilrnrp Ala.ka, LLC Well Prognosis Well Name: MGS A13-12rd API Number: 50-733-20191-01 Current Status: Gas Lifted Producer Leg: Leg #4 (West) Estimated Start Date: March 01, 2019 Rig: E -Line Reg. Approval Req'd? 403 Date Reg. Approval Received: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 173-035 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: 3,200 psi @ 8,323' TVD 0.384 psi/ft (7.39 ppg) Maximum Expected BHP: 3,200 psi @ 8,323' TVD 0.384 psi/ft (7.39 ppg) Maximum Potential Surface Pressure: -100 psi Well to be perforated while flowing Brief Well Summary Well Middle Ground Shoal A13-12rd 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 3,500 psi Hi 250 Low. 2. RU a -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 K cars Alaska. LLC KB: 38' Water Depth: 73' PBTD=9,809' TD =9,9W SCHEMATIC CASING DETAIL Middle Ground Shoal Well: MGS A13-12RD Last Completed: 8/12/2000 PTD: 173-035 API: 50-733-20191-01 Size Wt I Grade Conn ID Top Btm 24" Btm (MD) Top (TVD) Btrn (ND) CIW Hanger Surf 370' 13-3/8" 61 J-55 BTC 12.515" Surf 1,593' 9,043' 40 N-80 BTC 8.835" Surf 5,131' 9-5/8" 43.5 N-80 BTC 8.755" 5,131' 6,478' GUM #3-Macco 47 N-80 BTC 8.525" 6,478' 6,501' (TOW) 7" Tieback 26 N-80 BTC 6.276" Surf 6,290' 7" Liner 29 N-80 BTC SCC 6.184" 6,290' 9,898' TUBING DETAIL 2-7/8" 6.5 N-80 EUE8rd I 2.441" Surf 8,523' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Zone 36.66' Btm (MD) Top (TVD) Btrn (ND) CIW Hanger 1 326' 326' 2.313 4.630 Baker TS SSSV 2 1,976' 1,975' 9,043' 9,067' GLM#1-Macco 3 3,567' 3,565' HK3 9,076' GLM #2-Macco 4 4,873' 4,870' Open HKS GUM #3-Macco 5 5,770' 5,764' 14' Open GLM#4-Macco 6 6,605' 6,574' 9,055' 1 50 GLM#5-Macco 7 7,279' 7,182' 9,077' 9,222' GLM#6-Macco 8 1 7,883' 1 7,709' 9,723' 9,239' GUM #7-Macco 9 8,383' 8,151' GLM#8-Macco-Orifice 10 8,426' 8,189' 2.313 3.125 X -Nipple 8,465' 8,223' 2.437 3.500 Locator Sub w/4 seals& muleshoe(11.10') 11 8,466' 8,224' 3.2505.750 Baker DB Perm Packer (84-32) 8,470' 8,227' 3.250 5.750 10 Sealbore Extension (80-32) 12 8,515' 8,267' 2.205 3.125 XN Nipple 13 8,522' 8,273' 2.500 3.625 Wire Re -Entry Guide Updated By: 1LL 10/17/18 Wireline Detail & Fish PERFORATION DETAIL Depth Description Zone Top (MD) Btm (MD) Top (TVD) Btrn (ND) FT Date Status F 8,578' 8,664' 8,323' 8,401' 86' Open HK3 9,043' 9,067' 8,747' 8,769' 24' Open HK3 9,076' 9,120' 8,777' 8,819' 44' Open HKS 9,203' 9,217' 8,897' 8,910' 14' Open HK2 9,323' 9,365' 9,008' 9,055' 1 50 Open HK2 9,394' 9,544' 9,077' 9,222' 150' Open HK2 9,562' 9,723' 9,239' 9,394' 161' Open Updated By: 1LL 10/17/18 Wireline Detail & Fish Date Depth Description 09/30/2018 9,398' CT Tag/Obstruction 09/29/2018 9,696' CT Tag 03/15/2017 9,394' 1.5", 1.7511, 211, 2-1/2" Scratchers -1.50" star drill - 1.25" & 1.50" DD bailers 8/2009 9,703' Wireline tag 8/2000 9,710' Fish (Packer) Updated By: 1LL 10/17/18 H core A.A.. LLC KB: 38' Water Depth: 73' PBTD-J,S09' TD -9,900' PROPOSED CASING DETAIL Middle Ground Shoal Well: MGS A13-12RD Last Completed: 8/12/2000 PTD: 173-035 API: 50-733-20191-01 Size Wt Grade I Conn ID Top Btm 24" Btm (MD) Top (TVD) (TVD) CIW Hanger Surf 370' 13-3/8" 61 1-55 BTC 12.515" Surf 1,593' 9,043' 40 N-80 BTC 8.835" Surf 5,131' 9-5/8" 43.5 N-80 BTC 8.755" 5,131' 6,478' GUM #3-Macco 47 N-80 BTC 8.525" 6,478' 6,501' (TOW) 7" Tieback 26 N-80 BTC 6.276" Surf 6,290' 7" Liner 29 N-80 BTCSCC 6.184" 6,290' 9,898' TUBING DETAIL 2-7/8" 6.5 N-80 EUE 8rd 1 2.441" Surf 8,523' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Zone 36.66' Btm (MD) Top (TVD) (TVD) CIW Hanger 1 326' 326' 2.313 4.630 Baker TS SSSV 2 1,976' 1,975' 9,043' 9,067' GLM #1-Macco 3 3,567' 3,565' HKS 9,076' GUM #2-Macco 4 4,873' 4,870' Open HK1 GUM #3-Macco 5 5,770' 5,764' 14' Open GUM #4 -Matto 6 1 6,605' 1 6,574' ±8,930' ±28' GLIA #5-Macco 7 7,279' 7,182' 9,008' 9,055' GLM#6-Matto 8 7,883' 7,709' ±9,390' ±9,064' GLM#7-Macco 9 8,383' 8,151' 9,394' 9,544' GLM#8-Macco -Orifice 10 8,426' 8,189' 2.313 3.125 X -Nipple 9,239' 8,465' 8,223' 2.437 3.500 Locator Sub w/4 seals& muleshoe(11.10') 11 8,466' 8,224' 3.250 5.750 Baker DB Perm Packer (84-32) 8,470' 8,227 3.250 5.750 10' Sealbore Extension (80-32) 12 8,515' 8,267' 2.205 3.125 XN Nipple 13 8,522' 8,273' 2.500 3.625 Wire Re -Entry Guide Updated By: JILL 01/30/19 Wireline Detail & Fish PERFORATION DETAIL Depth Description Zone Top (MD) Btm (MD) Top (TVD) (TVD) FT Date Status F 8,578' 8,664' 8,323' 8,401' 86' Open HK1 9,043' 9,067' 8,747' 8,769' 24' Open HKS 9,076' 9,120' 8,777' 8,819' 44' Open HK1 9,203' 9,217' 8,897' 8,910' 14' Open HK1C 19,210' ±9,238' ±8,904' ±8,930' ±28' Future Proposed HK2 9,323' 9,365' 9,008' 9,055' 50' Open HK2B ±9,380' ±9,390' ±9,064' ±9,074' ±10' Future Proposed HK2 9,394' 9,544' 9,077' 9,222' 150' Open HK2 9,562' 9,723' 9,239' 9,394' 161' Open Updated By: JILL 01/30/19 Wireline Detail & Fish Date Depth Description 09/30/2018 9,398' CT Tag/Obstruction 09/29/2018 9,696' CT Tag 03/15/2017 9,394' 15", 1.75", 2", 2-1/2" Scratchers -1.50" star drill -1.25" & 1.50" DD bailers 8/2009 9,703' Wireline tag 8/2000 9,710' Fish (Packer) Updated By: JILL 01/30/19 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Plug Perforations F(�act�un�./�timulate Pull Tubing Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ �$t}Ser Stimulate ❑� Alter Casing g ❑ Change Approved Program ❑ 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 ❑r Exploratory ❑ Stratigraphic ❑ Service ❑ 173-035 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20191-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018754 MGS At 3-12RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Middle Ground Shoal / EF and G Oil & Middle Ground Shoal Oil Pools 11. Present Well Condition Summary: Total Depth measured 9,900 feet Plugs measured N/A feet true vertical 9,596 feet Junk measured N/A feet Effective Depth measured 9,398 feel Packer measured 8,466 feet true vertical 9,081 feet true vertical 8,224 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 370' 24" 370' 370' Surface 1,593' 13-3/8" 1,593' 1,592' 3,090 psi 1,540 psi Intermediate 6,501' 9-5/8" 6,501' 6,474' 5,750 psi 3,090 psi Production 6,290' 7" 6,290' 6,271' 7,240 psi 5,410 psi Liner 3,608' 7" 9,898' 9,563' 8,160 psi 7,020 psi Perforation depth Measured depth 8,578 - 9,723 feet True Vertical depth 8,323 - 9,394 feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / N-80 8,523 (MD) 8,274 (TVD) 8,466 (MD) 326 (MD) Packers and SSSV (type, measured and true vertical depth) Baker DB Perm Pkr 8,224 (TVD) Baker T-5 SSSV 326 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 8,578 - 9,390 Treatment descriptions including volumes used and final pressure: 30 bbl (50/50) Xylene/Diesel blend, 47 bbls 7.5% Hydrochloric Acid, Final pressure 2800# 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 9 6 20 413 1 90 Subsequent to operatiomi 15 11 59 477 1 86 14. Attachments (required per 20 AAc 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Service Development p ❑ ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 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: 318-380 Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmadowe@hilcom.com Authonzed Signature: LZ � Date: 10ZS l Ie' Contact Phone: (907) 283-1329 Form 10-404 Revised 4/2017 �8�9 i �DMS�1 QCT 2 42018 � �� Submit Original Only B Hilwrp Alaska, LLC KB: 38' Water Depth: 73' 1 :1• / •11 SCHEMATIC CASING DETAIL Middle Ground Shoal Well: MGS A13-12RD Last Completed: 8/12/2000 PTD: 173-035 API: 50-733-20191-01 Size Wt Grade I Conn ID Top Btm 24" Btm (MD) Top (TVD) (TVD) CIW Hanger Surf 370' 13-3/8" 61 1-55 BTC 12.515" Surf 1,593' 9,043' 40 N-80 BTC 8.835" Surf 5,131' 9-5/8" 43.5 N-80 BTC 8.755" 5,131' 6,478' GLM#3-Macco 47 N-80 BTC 8.525" 6,478' 6,501'(TOW) 7" Tieback 26 N-80 BTC 6.276" Surf 6,290' 7" Liner 29 N-80 BTC SCC 6.184" 6,290' 9,898' TUBING DETAIL 2-7/8" 6.5 N-80 EUE8rd 1 2.441" Surf 8,523' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Zone 36.66' Btm (MD) Top (TVD) (TVD) CIW Hanger 1 326' 326' 2.313 4.630 Baker T5 SSSV 2 1,976' 1,975' 9,043' 9,067' GLM#1-Matto 3 3,567' 3,565' HKl 9,076' GUM #2-Macco 4 4,873' 4,870' Open HKS GLM#3-Macco 5 5,770' 5,764' 14' Open GLM#4-Macco 6 6,605' 1 6,574' 9,055' 50' GLM#5-Macco 7 7,279' 1 7,182' 9,077' 9,222' GLM#6-Macco 8 7,883' 7,709' 9,723' 9,239' GLM#7-Macco 9 8,383' 8,151' GLM#8-Macco -Orifice 10 8,426' 8,189' 2.313 3.125 X -Nipple 8,465' 8,223' 2.437 3.500 Locator Sub W/ 4 seals & muleshoe (11.10') 11 8,466' 8,224' 3.250 5.750 Baker DB Perm Packer (84-32) 8,470' 8,227' 3.250 5.750 10' Sealbore Extension (80-32) 12 8,515' 8,267' 2.205 3.125 XN Nipple 13 8,522' 8,273' 2.500 3.625 Wire Re -Entry Guide Updated By: JUL 10/17/18 Wireline Detail & Fish PERFORATION DETAIL Depth Description Zone Top (MD) Btm (MD) Top (TVD) (TVD) FT Date Status F 8,578' 8,664' 8,323' 8,401' 86' Open HK3 9,043' 9,067' 8,747' 8,769' 24' Open HKl 9,076' 9,120' 8,777' 8,819' 44' Open HKS 9,203' 9,217' 8,897' 8,910' 14' Open HK2 9,323' 9,365' 9,008' 9,055' 50' Open HK2 9,394' 9,544' 9,077' 9,222' 150' Open HK2 9,562' 9,723' 9,239' 9,394' 161' Open Updated By: JUL 10/17/18 Wireline Detail & Fish Date Depth Description 09/30/2018 9,398' CT Tag/Obstruction 09/29/2018 9,696' CTTag 03/15/2017 9,394' 1.5", 1.75", 2", 2-1/2" Scratchers -1.50" star drill - 1.25" & 1.50" DD bailers 8/2009 9,703' Wireline tag 8/2000 9,710' Fish (Packer) Updated By: JUL 10/17/18 UHilcorp Alaska, LLC Hilcorp Aluaka, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A13-12RD CT 50-733-20191-01 173-035 9/26/2018 9/30/2018 Daily Operations: 09/26/18- Wednesday 4 -man SLB CT crew arrived platform- received orientation from production personnel- prepped to onload CT equipment. Worked M/V Resolution receiving SLB inj head, CT reel, N2 pump, Ops cab, mud pump, power pack, N2 tank, generator, hose basket, 2- iron racks, BOP stand, lubricator box, choke manifold and dog house- positioning equipment as needed. Worked MN Titan backloading Pollard Eline equipment then received acid overpack, xylene tank, diesel tank, hydrochloric acid tank, Hilcorp mud tank, shaker and gas buster. R/U electrical and hydraulic from generator and power pack to ops cab and CT reel. Shutin well (due to leaking swab valve)- N/U 4 1/16" 10M riser w/ DSA to 2 9/16" 5M tree flange. N/U CT BOP ram section- ran all flow lines between mud pump, CT reel, choke manifold, flow cross and solids tank P/U injector, attached goose neck and connect hydraulic lines. Worked thru minor hydraulic hose issue- reeled off coil and stabbed thru injector head- secured equipment, SDFN- production brought well back on. Held operations and PJSM w/ production, crane & SLB crews. 09/27/18 - Thursday P/U injector head, M/U 10' lub jt and M/U coil connection. M/U to BOP stub and prepare to test BOPS. 70 psi tb- 450 psi IA (GLP)- 70 psi OA- 0 psi OOA. Found several leaks in production FIW supply line needed for CT BOP testing and C/O- prod op and welder determining repair- ordered parts. Used 1" hose to fill mud pump displacement tank w/ FIW to load CT reel @.5 bpm rate. Shell tested BOP system to 250 psi low 4000 psi high. Tested all CT BOP equipment to 250 psi low 4000 psi high as per Sundry. Witness waived by Mr. Regg, via email 2:17 PM 9/25/18. Needed parts arrived to R/U 2" FIW supply line. Broke off injector head and M/U downward wash nozzle- production ran 2" line and connected from FIW supply to SLB mud pump- worked thru minor leaks. Prepped from C/O RIH. Dropped riser it from inj head and set back same- secured equipment for shutdown. SDFN. Held operations and PJSM w/ production, crane & SLB crews. 09/28/18 - Friday Fired up equipment -turned on FIW supply to mud pump- hooked onto SLB inj head- M/U 10' lub it and rolled on 11/2" coil connector- added 3' stem w/ washdown nozzle. M/U to BOP stub- pressured tested 250 low 4000 high. 70 psi tb pressure, 400 psi IA (GLP), 70 psi OA, 0 psi ODA. Opened well and SIH slowly working out `300' of loose coil. Continued in hole checking weight every 2,000'- PU W at 9,350'= 22k, SOW = 10k- no issues to tag at 9,393' CTM. Brought pump online at 1.3 bpm pumping FIW, caught fluid at 10.5 bbls pumped- pressure at 3200 psi (returns going to prod). Well pressures are 72 psi tb, 867 psi IA, 90 psi OA, 0 psi OOA. Began washing on bottom at 1145 hrs. Made 5' of hale in 45 mins then no additional hole in 75 mins- decision made to POOH (TO reached = 9,398'). Pulled inside tb and circ btms up x 2 (slowly creeping uphole) POOH at 90 fpm. Closed swab valve and B/O inj head at lub jt. B/O wash nozzle and reheaded coil to Weatherford connector- M/U Weatherford tool string (to be ran in)- checked tool- B/0 same. L/D lubjt and set back inj head- secured equipment for shutdown. SDFN. Held operations and PJSM w/ production, crane & SLB crews+ Weatherford. 09/29/186 -Saturday Fired up SLB equipment- P/U inj head and added 10' & 5' lubjts- M/U & rechecked Weatherford tool string (1.7" coil connector, 1.81" dual flapper sub, 1.7" disconnect, 1.7" circ sub, 1.7' ECiD motor w/ 2.09" bladed mill = 13.29'). M/U to BOP stub and pressure tested to 250 low 4000 high. Released pressure and opened swab valve. Pressures before: 68 psi tb, 1175 psi IA, 57 psi OA, 0 psi ODA. TIH w/ CT Run #2 at 80 fpm w/o circ (well lined up to prod header)- checking P/U periodically to tag at 9,398'. Diverted returns from production header to gas buster on rig tank, draining back to production's back flow separator to on -deck tank. Established rate at 1 bpm 2500 psi thru mud motor- stalled initially at 9,398'- P/U and slowly returned to depth -worked thru this spot and eased in hole to 9,420' at 2' ROP- P/U at 9,420' to chase solids into EOT (as planned) TBI to 9,420' and continued in hale at 2 fpm to 9,475'w/ no issue- flushed solids (fine sand) up to EDT at 22' fpm- pulled inside tb tail and circ btms up TBI w/o pump and tagged at 9,398'- unable to get by w/o pumping/turning mill- continued in hole to tag at 9,696' CTM + 15' elevation= 9,711'. Brought pump online at 1 bpm 2700 psi- flushed fine sand/silt uphole pulling CT at 22 fpm- pulled in tb and circ btms up x 2 (creeping uphole slowly). POOH after circ btms up. Closed swab valve and bled off Pressure- B/O inj head- B/D Weatherford tools and B/O lub its- set down inj head and secured equipment SDFN- production instructed to bring well on. Held operations and PJSM w/ production, crane & SLB crews+ Weatherford. Ix/ KHilcorp Alaska, LLC Hil�rory Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Star[ Date End Date MGS A13-12RD CT 50-733-20191-01 173-035 1 9/26/2018 1 9/30/2018 09/30/18 -Sunday Fired up SLB equipment- job paused by SLB until waiver was approved to work East crane w/o functioning weight indicator. 0800 hrs P/U inj head and added 10' lub jt- M/U Weatherford tool string- M/U to BOP stub and pressure tested to 250 low 4000 high. Released pressure and opened swab valve. Pressures before: 72 psi tb, 463 psi IA, 96 psi OA, 0 psi OOA. TIH w/ SLB CT Run# 3 (1.68" Spin Cat Nozzle, 1.7" Stem, 1.7" Circ Sub, 1.7" Disconnect, 1.81" dual BPV, 1.7" connector= 9.38') to top of perfs at 8,578'- began pumping AW at 1 bpm 2700 psi- continued in hole tagging at 9,398' -took 4-5k overpull to get free showing additional drag on weight indicator while pulling out. Pulled into EOT (slowly) circulating btms up TBI pumping, checking P/Us periodically. After several attempts to get past obstruction at 9 398' decision was made to spot 2 bbls of acid at 9,398'. Shut off gas and shutin well - waited 1 hr- opened well to prod header but left gas shut off- attempted to get past 9,398' with no success. Discussed plan forward with Ops Eng- decision made to treat from obstruction to top perf. Slowly worked CT above perfs while mixing chemicals to dilute acid to 7.5% (and increase volume by adding FW) Pumped 50/50 diesel/xylene mix to end of CT located at top of perfs (8,578')- began washing w/ diesel/xylene mix at .7 bpm 2300 psi @ 21 fpm - tagged high at 8,945' -took 20 mins to work thru this spot (pump rate was not reduced). Continued in hole pumping- 30 bbls of diesel mix calculated pumped away at 9,064' (7.5% Hydrochloric acid following diesel mix). Decreased pump rate to .4 bpm 1100 psi (pumping acid)- continued in hole increasing running speed to 50 fpm- stopped at 9,390' and began POOH at 30 fpm pumping .75 bpm 2500 psi- at top of perfs 25 bbls of acid remained in coil- TBI pumping .5 bpm 1500 psi at 30 fpm- stopped at 9,390' and POOH at same rate and speed. 47 total bbls of acid laid across perfs (8,578_to 9,390') Switched over to FIW and pulled inside EOT- pumped btms up x 2 at .9 bpm 2800 psi (moving coil slowly). Allowed acid to soak. Prod turned on gas lift -TBI to 9,390' at .9 bpm 2800 psi- pumped 10 bbls then POOH at 8 fpm pumping to flush treatment from well- once inside tb increased speed, slowed down to 5 fpm to wash 50' either side of all GLMs. Closed swab valve and bled off pressure- B/0 inj head and B/D tool string- dropped off lub jt and set down head - secured equipment for shutdown. Job finished- resting SLB CT crew vL0 Ix/ THE STnTIP 'ALASKA--- GOVERNOR BILL WALKER 10 Alaska Oil and Gas Conservation Commission Stan W. Golis Operations Manager 5cA�p s F P v i 01$ Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Re: Middle Ground Shoal Field, E, F, and G Oil and Middle Ground Shoal Oil Pools, MGS A13-12RD Permit to Drill Number: 173-035 Sundry Number: 318-380 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, (D Hollis S. French 1 l Chair �C J DATED this _ day of September, 2018. RBDM� SEP 0 72018 • • "° fi ° 4 1""TM TV ggp STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ars 1li 1l 8' 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ 6� Suspend ElPerforate ❑ Ot r ttimulate Q Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CTCO ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 173-035' 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20191-01-00 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 MGS A13-12RD 9. Property Designation (Lease Number): 10. Field/Pool(s): I Middle Ground Shoal / E,F and G Oil and Middle Grnd Shoal Oil Pools ' ADL0018754 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,900 9,596 9,703 9,375 2,368 psi N/A 9,710 Casing Length Size MD TVD Burst Collapse Structural Conductor 370' 24" 370' 370' Surface 1,593' 13-3/8" 1,593' 1,592' 3,090 psi 1,540 psi Intermediate 6,501' 9-5/8" 6,501' 6,474' 5,750 psi 3,090 psi Production 6,290' 7" 6,290' 6,271' 7,240 psi 5,410 psi Liner 3,608' 7" 9,898' 9,563' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8,578 - 9,723 8,323 - 9,394 2-7/8" 6.5# / N-80 8,523 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker DB Perm Pkr & Baker T-5 SSSV 8,466 (MD) 8,224 (TVD) & 326 (MD) 326 (TVD) 12. Attachments: Proposal Summary ❑✓ Wellbore schematic ❑� 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Stratigraphic ❑ Development Q • Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/30/2018 OIL ❑✓ • WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑GSTOR ❑ SPLUG El 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. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dirnarlowe(WhIICOrp.Conn Contact Phone: (907) 283-1329 / Authorized Signature: a� c�� Date: COMMISSION USE ONLY Conditions of approval: Notify Commission sot at a representative may witness Sundry Number: k � -' 80 a_�' / Plug Integrity El BOP Test P l Mechanical Integrity Test ElLocation Clearance ElOther: qD&-) % Si Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: J APPROVED BY Ib HE COMMISSION Date: Approved by: AlKstIM A _/ ei ia. IV t J M 10 1114 M L manuc,el-\.ccn I- - ` U — a ■vr+sww� VLF U / b1�l9nit Form and \ Form 10-403 Revised 4/2 7 Approved application is valid for 12 months from the date of approval. Attc ments in Duplicate Well Work Prognosis I ilcorp Alaska, LLC Well Name: MGS A13-12rd API Number: 50- 733-20191-01 Current Status: Gas Lifted Producer Leg: Leg #4 (West) Estimated Start Date: September 30, 2018 Rig: Coil Tubing Reg. Approval Required? 403 Date Reg. Approval Received: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 173-035 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: 3,200 psi @ 8,323' TVD Maximum Expected BHP: 3,200 psi @ 8,323' TVD Max Potential Surface Pressure (MPSP): 2,368 psi Brief Well Summary 0.384 psi/ft (7.39 ppg) 0.384 psi/ft (7.39 ppg) Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Well MGS A13-12rd is a gas lifted producer completed in the F and the Hemlock sands. Recent wireline work has indicated scale formation in the well bore. This procedure will clean-out fill covering the perforations and acidize the perforations. Procedure: 1 1. MIRU Coil Tubing. , ► (A ISS 2. NU BOP and test to 250psi low / ,59fl'psi High. (NOC Notify AOGCC 48 hours in advance of test) 3. RIH cleaning out fill to ± 9,710. Circulate bottoms up. Fluids will be FIW. All returns will be through gas buster to open top rig tanks or to production header. 4. Wash perfs with ±1,400 gallons 50/50 Diesel / Xylene at ±0.75 bpm 5. Wash perfs with ±2,500 gallons of ±10% Hydrochloric Acid at ±0.75 bpm 6. POOH with coil to tubing tail and circulate >2x bottoms up to purge coil and production tubing. 7. Soak for ±1-2 hours. 8. RIH to bottom and displace well to production. 9. POOH and rig down coil. 10. Turn well over to operations. Attachments: 1. Well Schematic - Current/Proposed (Same) 2. Wellhead Diagram - Current 3. Coil Tubing BOP Drawing 4. Flow Diagrams 5. RWO Sundry Revision Change Form • IIileorp Alaska, LLC KB: 38' Water Depth: 73' PBTD=9,809' TD =9,9W SCHEMATIC •Middle Ground Shoal Well: MGS A13-12RD Last Completed: 8/12/2000 PTD: 173-035 API: 50-733-20191-01 CASING DETAIL Size Wt Grade Conn ID Top Btm 24" 8,578' 8,664' 8,323' 8,401' 86' CIW Hanger Surf 370' 13-3/8" 61 J-55 BTC 12.515" Surf 1,593' 8,777' 40 N-80 BTC 8.835" Surf 5,131' 9-5/8" 43.5 N-80 BTC 8.755" 5,131' 6,478' GLM #3 - Macco 47 N-80 BTC 8.525" 6,478' 6,501' (TOW) 7" Tieback 26 N-80 BTC 6.276" Surf 6,290' 7" Liner 29 N-80 BTC SCC 6.184" 1 6,290' 9,898' TUBING DETAIL 2-7/8" 6.5 N-80 EUE 8rd 1 2.441" Surf 8,523' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Status 36.66' 8,578' 8,664' 8,323' 8,401' 86' CIW Hanger 1 326' 326' 2.313 4.630 Baker T5SSSV 2 1,976' 1,975' 8,777' 8,819' 44' GUM #1-Macco 3 3,567' 3,565' 8,897' 8,910' 14' GLM #2 - Macco 4 4,873' 4,870' 9,008' 9,055' 50' GLM #3 - Macco 5 5,770' 5,764' 9,077' 9,222' 150' GUM #4-Macco 6 6,605' 6,574' 9,239' 9,394' 161' GLM #5 - Macco 7 7,279' 7,182' GUM #6-Macco 8 7,883' 7,709' GLM #7 - Macco 9 8,383' 8,151' GLM #8 - Macco - Orifice 10 8,426' 8,189' 2.313 3.125 X -Nipple 8,465' 2.437 3.500 Locator Sub w/ 4 seals & muleshoe (11.10') 11 8,466' 8,224' 3.250 5.750 Baker DB Perm Packer (84-32) 8,470' 3.250 5.750 10' Sealbore Extension (80-32) 12 8,515' 8,267' 2.205 3.125 XN Nipple 13 8,522' 8,273' 2.500 3.625 Wire Re -Entry Guide PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status F 8,578' 8,664' 8,323' 8,401' 86' Wireline tag Open HKl 9,043' 9,067' 8,747' 8,769' 24' Open HK1 9,076' 9,120' 8,777' 8,819' 44' Open HK1 9,203' 9,217' 8,897' 8,910' 14' Open HK2 9,323' 9,365' 9,008' 9,055' 50' Open HK2 9,394' 9,544' 9,077' 9,222' 150' Open HK2 9,562' 9,723' 9,239' 9,394' 161' Open Updated By: JLL 08/29/18 Wireline Detail & Fish Date Depth Description 03/15/2017 9,394' 1.5", 1.75", 2", 2-1/2" Scratchers - 1.50" star drill - 1.25" & 1.50" DD bailers 8/2009 9,703' Wireline tag 8/2000 9,710' Fish (Packer) Updated By: JLL 08/29/18 H0 • Hi" A"*. LII: Platform A 13-12RD 13 3/8 x 9 5/8 x 7x 2 7/8 Valve, Swab 29/165M FE, Valve, Mast 2 9/16 5M FE, Valve, Master, 2 9/16 5M FE, HV Tubing head, CIW-F, 13 5/8 3M x 11 5M, w/ 2 1/16 SM SSO, X bottom Casing spool, CIW-WF, 13 5/8 3M x 13 3/8 3M, w/ 2- 2 1/16 5M EFO, X bottom prep Casing head, CIW-WF, 135/83MFE top x133/ SOW btm, w/ 2- 2 1/16 51 EFO BHTA, CIW, External knock -up, 2 9/16 SM FE Platform A Well 13-12RD 08/28/2018 Tubing hanger, CIW-F-FBB- CL, 11 x 2 7/8 EUE 8rd lift and susp, w/ 2 1/2" type H BPV profile, 1-1/8 npt control line port Schlumberger Coiled Tubing Treating Equipment Layout 1502 Treating Iron 2" 1502 Flowback Iron 2" 0 1502 Nitrogen Iron 1.5 ® LP Suction Hoses 3" Gooseneck i� Plug Valve 2"x2" Check Valve LP Valve Pressure Sensor s Injector CT String Head HR -580 0 Top Load Circ PSI Stripper CO62 5K Lubricator WH PSI 10K PSI Fluid Pump 4.06"10K Treating BOP Line Bleed Stack Pump PSI SLB Flow Suction Hose To Cross Source Tank 4.06" 10K Bac k side cv Pump cv Nitrogen Pump Nitrogen Tank 000 Gallons Riser From N2 Bleed — ea. WH To Stack Deck t Choke G+ r3>ItU Manifold Return DXQ Line To Tank x 0 Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well MGS A13-12RD (PTD 173-035) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date HILCORP ALASKA LLC, MGS A13-12RD (173-035) MIDDLE GROUND SHOAL, MGS OIL Monthly Production Rates 100,000 t C 10,000 0 a 2 1,000 c M N 3 0 I— 10 .. • .. ■ i����i�����1��������I� .. Gas (mcf): 886,356 ■ NOON � �s I NOON ���51�� /���.�■, wit.»� /� �A�������■i •. NOON NOON ■ iq�ril, �����' ��1e. �. 111 �� i111..1��1■����IA�I��w�rri111t�1i.�l���rr �rnrww�rir �w�uv .aa__ ►ara.r vvinm irswwwwww�wawwww �s�11�111�1� �f•�/N�i." :Hie;^'!�I •. •.. ..,.. - :�, ■■■�IL'ti���f■i''a�il �'fAf•��f•�f•���f•t7l�r i�� : Its l�'���■■■■■■�Ili�. ■■���� III• � �l IK r w a���� � '• 611"�1�l�iil SOic� INN NOONS MO 1■11 O !1■OI��..�0 Ili■lull ■■■■■���■■ ■ ■ ■ OEM ■ • ■ 1111 �1■ ,��.;. �.f.�.It��1�wwM�l■.�I.w..Iw1�11AwMl/�1��1w...1#wi�w �w�il i��wliwi��ie""i�l i �i1®iu�iiM i ■■■■■■■_NOMINNININ e■Irtlli�rr 111 __-__ .____� 100,000 10,000 1,000 100 10 1 1 Jan -1970 Jan -1975 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 0 ° O 13 M O 2) M Ms z SPREADSH EET_Prod-I nject_Curves_Well_V114_1730350_MGS_A13-12RD_20180831.xlsx 8/31/2018 STATE OF ALASKA • ALASKIIIL AND GAS CONSERVATION COMMIS.] • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U , Other U Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator XTO Energy Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 173 -035 r 3. Address: 200 N. Loraine, Suite 800, Midland, Tx 79701 Stratigraphic Service ❑ 6. API Number _50-733-20191-01- 01 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 18754 a Middle Ground Shoal #A13 -12RD 9. Field /Pool(s): MGS E, F, G Oil Pool 10. Present Well Condition Summary: Total Depth measured 9,900 feet Plugs measured feet true vertical 9,595.00 ' feet Junk measured 9,710 feet Effective Depth measured 9,703 feet Packer measured feet true vertical 9,400 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1593 13 -3/8 1593 1,595 Intermediate 6501 9 5/8 6501 6,477 '' Production 6290 7 6290 6270 JAN 3 i z Liner 3608 7 9898 9,593 .hake Oil & Gars uuf;s. C,Qinmissiort Perforation depth Measured depth 8578 -9723 feet Andiorace True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 2- 7/8 ",6.5 #,N -80 8523' MD Packers and SSSV (type, measured and true vertical depth) Baker 7" DB1 Perm 8,466' MD SSSV 326 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8578 -9723 n, JAN 2 4 2012. Treatment descriptions including volumes used and final pressure See attached daily report. 288 bbls 10% DAD acid (10% HCL + 25% Xyele). Final rate @ 0.6 BPM @ 3900 psi. 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 34 0 257 435 80 Subsequent to operation: 83 61 214 795 100 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory Development r Service ❑ Stratigraphic ❑ Daily Report of Well Operations Attached 15. Well Status after work: Oil IN Gas Li WDSPL 7 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -229 Contact Paul Figel, Engr. - Tel. No. 432 - 620 -6743 Printed Name Maria Perez Title Regulatory Analyst Signature //4% , fL Phone 432-620 -432f Date 12/29/2011 RBDMS JAN 0 4 2i 4, - i� Form 10 -404 Revised 10/2010 Submit Original Only . • • TO PLF 5 -26 -11 F N T R G Y Present Completion KB: 38' MGS A13 -12RD Water Depth: 73' Cook Inlet, Alaska Leg 4, Conductor 29 / Tubing: 2-7/8 ", 6.5 #, N80 EUE 8R @ 8,523 API No.: 50- 733 - 20191 -01 ® Set on 8 12 00. Spud Original A13 -12: 6 -10 -69 Sidetrack RD: 5 -4 -74 el red' 24" Conductor Csg. Set @ 370'. GLM MD TVD Port Psc Pso #1 1976 1975 10 901 950 #2 3567 3565 10 880 921 Surf Csg: 13 3/8" 61# J55 BTC. #3 4873 4870 10 861 889 Set @ 1,593'. Cmt w/ 1,300 sx. #4 5770 5764 10 839 865 #5 6605 6573 12 819 847 #6 7279 7171 12 798 823 #7 7883 7700 12 775 796 #8 8383 8143 16 Orifice Intermed: 9 5/8 ", Window @ 6,501'. ,...4 (Original 9 5/8" Set @ 8,751'. .- Cmt w/ 700 sk. TOC @ 7,250 Baker T5 SSSV @ 326' Surf - 5,131' : 40# N80 BTC r °- 5,131 - 6,501' : 43.5# N80 BTC X Nipple (2.313" ID) @ 8,426' 32' Jt 2 7/8" 6.5# N80 8R 6' 2 7/8" 6.5# N80 8R Pup Jt. �, 11' Baker Loc Sub w/ 4 Seals @ 8,465' f9;;:, :':M„ 7" Baker DB Perm Packer (84 -32) @ 8,466' Hole in 9 5/8" @ 5,370' on 4-8-77. 3 s. 10' Sealbore Ext. @ 8,470' X over Acme Box to 2 7/8" 8R -,- - d 4' 2 7/8" 6.5# N80 8R Pup Jt. rir WO 32' Jt 2 7/8" 6.5# N80 8R XN Nipple (2.205" ID) @ 8,515' # OA 6' 2 7/8" 6.5# N80 8R Pup Jt. ® WLREG @8,522' 0 A I IP= 1110-=11.11 Prod Liner: 7" 29# N80 BTC. rjo 0 . red Set @ 6,290 - 9,898'. Cmt w/ 1,750 sx. 0 / Tie Back: 7" 26# N80. Set Surf - 6,290'. @ ' ----- GR -GS: 8578' -8664' Cmt w/ 200 sx. 0 Fr, 0, ei 0, 0000 e 'N- er HC -HD: 9043 -9067' ral HC -HD: 9076 -9120' H E -H F: 9203 -9217' 0 lid:0 p Aos PO HI -HK: 9320 -9370' HK-HN: 9394 -9445' 4 ® H K -H N: 9448 -9463' Pio HK-HN: 9464 9544' Fill: 9703' (WL Tag Feb '09) HN -HR: 9560-9610' FISH (pkr): 9,710' (Aug 2000) �� — HN -HR: 9616 -9673' PBTD: 9,809' MD (9,505' TVD) do HN-HR: 9690 -9723' i r / 4„,„ TD: 9,900' MD (9,595' TVD) de A XTO Midand Alaska OCD Report Run Dates: 10/1/2011 - 12/28/2011 Report for: Midland d i' llC )" Engineer: Paul Figel Well Name: Middle Ground Shoal A13 -12R0 API: 5073320191 State: Alaska County: Kenai Peninsula Spud Dt: 06/10/1969 Objective: Acid Stimulation First Reported: 10/03/2011 Finaled: 10/07/2011 Rig: Rig #: Rig Type: RigUp Date: Rig Release Date: AFE#: 1104306 L` [Activity Date: 10/03/2011 Report Date: 10/04/2011 Depth End: Footage: Days from Spud: 15,456.00 Operation Summary: • Crane crew working transfer coil equipment platform to platform and supplys from beach, Coil crews arrive, MIRU SLB coil unit #1 @1930 hrs, boat ended duty shift and left with remaining supplys for job. continue rigging up Coil Tbg unit and flow back tank. Operation Remarks: Mr. Jim Regg of AOGCC waived witness of BOP test @ 1215hrs. 10 -3 -11 Activity Date: 10/04/2011 Report Date: 10/05/2011 Depth End: Footage: Days from Spud: 15,457.00 Operation Summary: 0000 -1600 / MIRU SLB Coil Tubing unit and flow back tank.Ready mud pits and mix 3% KCL FIW 1600 -2100 / Test BOP 250/4500psi repair leaks, accumulator draw down test, Test gas alarms. 2100 -2400 / pop off, lay down test assy. Pick up 1.75 BHA with jet swirl nozzle, stab on. Operation Remarks: Mr. Jim Regg of AOGCC waived witness of BOP test @ 1215hrs. 10 -3 -11 [Activity Date: 10/05/2011 Report Date: 10/06/2011 Depth End: Footage: Days from Spud: 15,458.00 Operation Summary: • 0000 -1100 / Test lube 250 / 4500 psi prep T/ RIH Boat arrives unload acid tanks 1100 -1500 / Open well 580psi. Bleed slowly to flowback tank, RIH W/ 1.75 jet swirl nozzle 60- 80fpm, pumping 3 %KCL slick water @ 1bpm 900psi circ psi slowing down at GLM washing at GLM, (Roll Acid tanks W/ RIH) 1500 -1830 / @8600' start acid down coil for acid soak, @9700' lay in 42bbls 10 %DAD acid 1 bpm 1400psi circ press, to 8570' Soak 30 min. wash out with 10 bbl gel sweep, and 50 bbls slick 3% KCL follow with acid for Acid Wash of Perfs RIH to 9700' 1830 -2000 / Pump 48bbls 10% DAD acid 1 bpm washing perfs F/ 9700' T/ 9000' one pass up, one pass down. chase with 100bbls slick 3% KCL 2000 -2400 / close in well„ pump 198bbls 10 %DAD acid injecting @ .7bpm, 4000psi circ 3000psi wellhead. making 5 passes up and down, Pull up hole T/ 8670' [Activity Date: 10/06/2011 Report Date: 10/07/2011 Depth End: Footage: Days from Spud: 15,459.00 Operation Summary: Report Run on: 12/28/2011 Page 1 of 2 WellView XTO Midand Alaska OCD Report Run Dates: 10/1/2011 - 12/28/2011 Report for: Midland E 4: R <1 • 0000 -0130 / @ 8670' Inject 30 bbls 10% DAD acid making passes 8670' T/ 8570' (pressures getting high on circ pressure, 4450psi circ pressure 2850psi wellhead.) check acid in tank 0130 -1230 / Switch to 3% nonslick with scale inhibitor displace 200bbls @.25bpm, circ psi 4450psi wellhead 3850psi, breaking back with all acid out coil to 4000psi circ press, and 3900psi wellhead @ .6bpm making passes F/ 8570' T/ 9700' shut down pump, POOH with coil., Shut in well rig down coil unit. 1230 -2400 / Clear acid lines and flush tanks, prep tanks for shipment, blow down coil with N2, rig down coil unit. Operation Remarks: 10 -7 -11 @0100hrs, open well to flow back tank @0500 3lbbls flowed back, production starts gas lift. 10 -8 -11 @0530hrs 604bbls total recoverd from well, PH unreadable 10 -9 -11 @0530hrs 860bbIs total recoverd from well, PH unreadable csg press 900psi 10 -10 -11 @0530hrs 1133bbls total recoverd from well. csg press 840psi ©1030hrs shut in well, total recoverd 1348bb1s 10 -12 -11 @0830 Open well to flow back tank 10 -13 -11 @0530 1712bbls total recoverd from well, PH 5 - 6 850psi csg psi @1600hrs Production take's well to production system. Total flowed back to tank1823bbls, PH 5 -6, csg psi 870 [Activity Date: 12/27 /2011 Report Date: 12/28/2011 ` • Depth End: Footage: Days from Spud: 15,541.00 Operation Summary: Well Test: 83 BOPD, 214 BWPD & 61 MCF. Lift gas @ 1191 MCFD w/ CP @ 795 psi. Lifting on GLV t6 of 8. FINAL REPORT. End of Report • Report Run on: 12/28/2011 Page 2 of 2 WellView ., STATE OF ALASKA ALASKOL AND GAS CONSERVATION COMMISSIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Aban. in U Repair Well U Plug Perforations U Stimulate U Other Li Performed: Alter Casi ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program 1 Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator XTO Energy Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ 173 -035 3. Address: 200 N. Loraine, Suite 81 Midland, Tx 79701 Stratigraphic Service ❑ 6. API Number: 50- 733 - 20191 -01 .- 0 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 18754 ° Middle Ground Shoal #A13 -12RD 9. Field /Pool(s): MGS E, F, G Oil Pool 10. Present Well Condition Summary: Total Depth measured 9,900 feet Plugs measured feet true vertical 9,595.00 feet Junk measured 9,710 feet Effective Depth measured 9,809 fe Packer measured feet true vertical 9,504 fee' true vertical feet Casing Length Size MD TVD • I Burst Collapse Structural Conductor 50.1k e,, 41.10L,‘ 6 Surface 1593 1593 1, 5 O�Nt � � Intermediate 6501 9 5/8 iate 6501 9 5/8 6501 Production 6290 7 6290 6270 no g Liner 3608 7 9898 9,593 RECEIVE ' Perforation depth Measured depth 8578 -9723 feet I V+ ` 1 :, t l , True Vertical depth feet l os ai .ail & Gas Cogs. Commission A r,.i: « . r ,, A Tubing (size, grade, measured and true vertical depth) 2- 7/8 ",6.5 #,N -80 8 ' MD Packers and SSSV (type, measured and true vertical depth) Baker 7" DB1 Perm 8,466' 4 D SSSV 326 11. Stimulation or cement squeeze summary: Intervals treated (measured): 8578 -9723 Treatment descriptions including volumes used and final pressur( See attached daily report. JAN 2 G 1312 12. Representative Daily Average Prod , tion or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 55 600 440 85 Subsequent to operation: 354 1150 '5 90 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations Attached 15. Well Status after work: Oil - 1 Gas ❑ WDSPL 7 GSTOR ❑ WINJ ❑ WAG ❑ GINJ 1' SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Numb. or N/A if C.O. Exempt: 311 -229 Contact Paul Figel, Engr. - Tel. No. 432 - 620 -6743 Printed Name Maria Perez t ‘S 0 Title Regulatory Analyst Signature _ Phone 432 - 620 -432E Date 11/22/2011 RSDMS NOV ' ` ' 1 J- Form 10 -404 Revised 10/2010 Submit Original Only XTO Midand Monthly Engineer Report Run Dates: 9/1/2011 - 10/28/2011 Report for: Midland ;ITO : , Engineer: Paul Figel Well Name: Middle Ground Shoal A13 -12RD API: 4 73320191 State: Alaska County: Kenai Peninsula Spud Dt: 06/10/1969 Objective: • 'd Stimulation First Reported: ' •3/2011 Finaled: 10/07/2011 Rig: Rig #: Rig Type: RigUp Date: Rill Release Date: AFE#: 1104306 Activity Date: 10/03/2011 Report 4 • . • 10/04/2011 Depth End: ootage: Days from Spud: 15,456.00 • Operation Summary: Crane crew working transfer coil equipment pla • •• to platform and supplys from beach, Coil crews arrive, MIRU SLB coil unit #1 @1930 hrs, boat ended duty shift and left with remaining supplys for job. continue rigging up C• bg unit and flow back tank. Operation Remarks: Mr. Jim Regg of AOGCC waived witness of BOP test @ 121 10 -3 -11 Activity Date: 10/04/2011 Report Date: 10/05/2011 II Depth End: Footage: Days from Spud: 15,457.00 Operation Summary: 0000 -1600 / MIRU SLB Coil Tubing unit and flow back tank.Ready mud pits and mix 3% K IW 1600 -2100 / Test BOP 250/4500psi repair leaks, accumulator draw down test, Test gas alarms. 2100 -2400 / pop off, lay down test assy. Pick up 1.75 BHA with jet swirl nozzle, stab on. Operation Remarks: Mr. Jim Regg of AOGCC waived witness of BOP test © 1215hrs. 10 -3 -11 Activity Date: 10/0$12011 Report Date: 10/06/2011 ` • Depth End: Footage: Days from Spud: 15,458.00 Operation Summary: 0000 -1100 / Test lube 250 / 4500 psi prep T/ RIH Boat arrives unload acid tanks 1100 -1500 / Open well 580psi. Bleed slowly to flowback tank, RIH W/ 1.75 jet swirl nozzle 60- 80fpm, pumping 3 %KCL slick water @ lbpm 904 • ' circ psi slowing down at GLM washing at GLM, (Roll Acid tanks W/ RIH) 1500 -1830 / @8600' start acid down coil for acid soak, @9700' lay in 42bbls 10 %DAD acid 1 bpm 1400psi circ press, to 8570' Soak 30 min. wash out - 10 bbl gel sweep, and 50 bbls slick 3% KCL follow with acid for Acid Wash of Perfs RIH to 9700' 1830 -2000 / Pump 48bbls 10% DAD acid 1 bpm washing perfs F/ 9700' T/ 9000' one pass up, one pass down. chase with 100bbIs slick 3% KCL 2000 -2400 / close in well„ pump 198bbls 10 %DAD acid injecting @ .7bpm, 4000psi circ 3000psi wellhead. making 5 passes up and down, Pull up hole T/ 8670' Report Run on: 10/28/2011 Page 1 of 2 WellView 'TO XTO Midand Monthly Engineer Report Run Dates: 9/1/2011 - 10/28/2011 Report for: Midland Activity Date: 10/06/2011 Report Date: 10/07/2011 Depth End: Footage: Days from Spud: 15,459.00 Operation Summary: 0000 -0130 / @ 8670' Inject 30 bbls 10% DAD acid making passes 8670' T/ 8570' (pressures getting high on circ pressure, 4450psi circ pressure 2850psi wellhead.) check acid in tank 0130 -1230 / Switch to 3% nonslick with scale inhibitor displace 200bbls @.25bpm, circ psi 4450psi wellhead 3850psi, breaking back with all acid out coil to 4000psi circ press, and 3900psi wellhead © .6bpm making passes F/ 8570' T/ 9700' shut down pump, POOH with coil., Shut in well rig down coil unit. 1230 -2400 / Clear acid lines and flush tanks, prep tanks for shipment, blow down coil with N2, rig down coil unit. Operation Remarks: 10 -7 -11 @0100hrs, open well to flow back tank @0500 3lbbls flowed back, production starts gas lift. 10 -8 -11 @0530hrs 604bbIs total recoverd from well, PH unreadable 10 -9 -11 @0530hrs 860bbIs total recoverd from well, PH unreadable csg press 900psi 10 -10 -11 @0530hrs 1133bbIs total recoverd from well. csg press 840psi @1030hrs shut in well, total recoverd 1348bb1s 10 -12 -11 @0830 Open well to flow back tank 10 -13 -11 @0530 1712bbIs total recoverd from well, PH 5 - 6 850psi csg psi @1600hrs Production take's well to production system. = flowed back to tank1823bbls, PH 5 -6, csg psi 870 End of Report • Report Run on: 10/28/2011 Page 2 of 2 WellView • 0 TO 2/1r PLF 5 -26 -11 Present Completion '97 we" KB: 38' MGS A13 -12RD 1 Water Depth: 73' Cook Inlet, Alaska Tubing: 2-7/8", 6.5 #, N80 EUE 8R @ 8,523' e Leg 4, Conductor 29 ',di I +< Set on 8- 12 -00. API No.: 50- 733 - 20191 -01 P Spud Original A13 -12: 6 -10 -6 <0044 0, Sidetrack RD: 5-4 -74 4 24" Conductor Csg. Set @ 370'. GLM MD TVD Port Psc Pso #1 1976 1975 10 901 950 #2 3567 3565 10 880 921 Surf Csg: 13 3/8" 61# J55 BTC. #3 4873 4870 10 861 889 Set @ 1,593'. Cmt w/ 1,300 sx. #4 5770 5764 10 839 865 #5 6605 6573 12 819 847 #6 7279 7171 12 798 823 #7 7883 7700 12 775 796 TO F #8 8383 8143 16 Orifice Intermed: 9 5/8 ", Window @ 6,501'. f (Original 9 5/8" Set @ 8,751'. t,-:: d Cmt w/ 700 sk. TOC @ 7,250 Baker T5 SSSV @ 326' Surf - 5,131' : 40# N80 BTC s , X Nipple (2.313" ID) @ 8,426' 5,131 - 6,501' : 43.5# N80 BTC 32' Jt 2 7/8" 6.5# N80 8R K::::44 6' 2 7/8" 6.5# N80 8R Pup Jt. 11' Baker Loc Sub w/ 4 Seals @ 8,465' o 7" Baker DB Perm Packer (84 -32) @ 8,466' 10' Sealbore Ext. @ 8,470' Hole in 9 5/8" @ 5,370' on 4 -8 -77. pm ► X -over Acme Box to 2 7/8" 8R 4' 2 7/8" 6.5# N80 8R Pup Jt. M 04 Pr 32' Jt 2 7/8" 6.5# N80 8R XN Nipple (2.205" ID) @ 8,515' 6' 2 7/8" 6.5# N808R Pup Jt. V` `'` 01 WL REG @ 8,522' $ e irlfre ' 4 00. --. 4 0..- Prod Liner: 7" 29# N80 BTC. , re. \.- eio ,, Set @ 6,290 - 9,898'. Cmt w/ 1,750 sx. R. . Tie Back: 7" 26# N80. Set @ Surf - 6,290'. - - -GS: 8578' -8664' Cmt w/ 200 sx. PO +; reid r, # r, , 0 A' .. HC -H c,, 9043 -9067' ral _ HC -HD'\ 9076 -9120' H E -H F: �` , 9203 -9217' 04 r, HI -HK: �'��, 9320 -9370' HK -HN: *,, 9394 -9445' HK -HN: \ 9448 -9463' H K -H N : 9464 -9544' Fill: 9703' (WL Tag Feb '09) HN -HR: '1560 -9610' FISH (pkr): 9,710' (Aug 2000) i, �' HN -HR: ` -9673' PBTD: 9,809' MD (9,505' TVD) HN -HR: 9: 10 -9723' TD: 9,900' MD (9,595' TVD) • i girkti[E ( L t r usELIA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMPIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Maria Perez Regulatory Analyst � � XTO Energy, Inc. 200 N. Loraine, Suite 800 Midland, TX 79701 Re: Middle Ground Shoal Field, E, F, G Oil Pool, MGS A13-12RD Sundry Number: 311 -229 Dear Ms. Perez: s z�� .l t- L k1t yr Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ?b day of July, 2011. Encl. • • TO ENERGY July 20, 2011 Alaska Oil and Gas Conservation Commission Y , ; • : f , .� titi Attn: John Norman, Commissioner 333 W. 7 Ave., Suite 100 Anchorage, Alaska 99501 Re: Form 10 -403, Request for Sundry approval Objective: Coil tbg acid stimulation.. Middle Ground Shoal #A13 -12RD MGS E, F, G Oil Pool Cook Inlet, Alaska API 50- 733 - 20161 -01 XTO Energy Inc. hereby submits its Application for Sundry Approval for coil acid stimulation. Attached is the following information for your files: 1. Form 10 -403 Application for Sundry Approval. 2. Proposed job procedure. 3. Present wellbore schematic If you required additional information, please contact me at A/C 432 - 620 -4325. Sincerely, Maria L. Perez, Regulatory Analyst Copy to: Paul Figel, Engineering Manager 200 N. LORAINE, SUITE 800, MIDLAND, TEXAS 79701 • Imrs,A- . • 4, STATE OF ALASKA 1 op tk ,, , 0 ,,,; ALASKA OIL AND GAS CONSERVATION COMMISSION ; _ i.' " ' • " APPLICATION FOR SUNDRY APPROVALS 1 -1°'° 20 AAC 25.280 '. ,' i I - , i ' - - . t , ,iortt—tiiiiiiiission 1. Type of Request: Abandon El Plug for Redrill 0 Perforate New Pool III Repair Well El Change eApprove0Rpgram 0 Suspend El Plug Perforations 0 Perforate 111 Pull Tubing El Time Extension 11 Operations Shutdown 0 Re-enter Susp. Well 0 Stimulate • - Alter Casing 0 Other: 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: XTO Energy Inc. Development El , Exploratory EI 173-035 , 3. Address: 6 . API Number: Stratigraphic El Service IE 200 N. Loraine, Suite 800, Midland, Texas 79701 50-733-20191-01 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No El Middle Ground Shoal A1 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): 7) i ADL 18754 • MGS E, F, G 0t1 t-„,„ 1 /4,-D, -1. z.;.- i/ 11. PRESENT WELL CONDITION SUMMARY L Total Depth MD (ft): • Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9,900 9,595 9809 9504 None 9710 Casing Length Size MD / TVD Burst Collapse Structural • INCIOr Conductor 2.- Li 7 , 7O Surface 1593 13 3/8 1593 1592 Intermediate 6501 9 5/8 6501 6477 Production 6290 7 6290 6270 Liner 3608 7 9898 9593 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8578-9723 7 2 7/8" / 6.5#, N80 8R EUE . 8523 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 7"Baker DB1 Perm 0' 8466 SSSV 326 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 111 i Exploratory 0 Development Ig • Service 0 , 14. Estimated Date for 10/3/2,611 15. Well Status after proposed work: Commencing Operations: c,-" Oil • Gas 1 WDSPL El Suspended 0 16. Verbal Approval: Date: WINJ 0 GINJ 11 WAG 0 Abandoned Ill Commission Representative: GSTOR El SPLUG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Figel, Engr 432-620-6743 Printed Name Maria Perez Title Regulatory Analyst Signature Phone 432-620-4325 Date 7/20/2011 ///4441-11: / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity El BOP Test 0 Mechanical Integrity Test III Location Clearance El Other: Subsequent Form Required: I 0 ^ 4 0 c4. " APPROVED BY z Approved by: i 0 / JUL 26 COMMISSIONER THE COMMISSION RIG1NAL.. Date: 7 ( 1(t "' BDMS 201 „01 Form 10-403 Revised 1/2010 ''''' -. Submit in Duplicate ` • • PLF 5 -26 -11 E ENERGY Present Completion f K B: 38' MGS A13 -12RD Water Depth: 73' Cook Inlet, Alaska Tubing: 2 7/8 " 6.5 #, N80 EUE 8R @ 8,523' Leg 4, Conductor 29 vt : ,,,t, API No.: 50- 733 - 20191 -01 Set on 8-12-00 . Spud Original A13 -12: 6 -10 -69 Sidetrack RD: 5 -4 -74 9 Ai el 1 24" Conductor Csg. Set @ 370'. GLM MD TVD Port Psc Pso #1 1976 1975 10 901 950 #2 3567 3565 10 880 921 Surf Csg: 13 3/8" 61# J55 BTC. #3 4873 4870 10 861 889 Set @ 1,593'. Cmt w/ 1,300 sx. #4 5770 5764 10 839 865 #5 6605 6573 12 819 847 #6 7279 7171 12 798 823 Pp 6 #7 7883 7700 12 775 796 #8 8383 8143 16 Orifice Intermed: 9 5/8 ", Window @ 6,501'. (Original 9 5/8" Set @ 8,751'. pinia ': Cmt w/ 700 sk. TOC @ 7,250'.) AM iv, 9,,) Baker T5 SSSV @ 326' Surf - 5,131' : 40# N80 BTC Tim U '' X Nipple (2.313" ID) @ 8,426' 5,131 - 6,501' : 43.5# N80 BTC A` z, 32' Jt 2 7/8" 6.5# N80 8R 0 ',M$ a $ . 6' 2 7/8" 6.5# N80 8R Pup Jt. A" 11' Baker Loc Sub w/ 4 Seals @ 8,465' r$ 0 4:‘!:;41 °= 7" Baker DB Perm Packer (84 -32) @ 8,466' ,' :,.., 10' Sealbore Ext. @ 8,470' Hole in 9 5/8" @ 5,370' on 4 -8 -77. , .E; " " X over Acme Box to 2 7/8" 8R 4' 2 7/8" 6.5# N80 8R Pup Jt. 32' Jt 2 7/8" 6.5# N80 8R po ';;‘,.1049:0,, XN Nipple (2.205" ID) @ 8,515' iie r-41 fr r o l/M 6' 2 7/8" 6.5# N80 8R Pup Jt. lip e WL REG @ 8,522' 1 4; 4 0 000 ,A,, kv74110.-M31 110- Prod Liner: 7" 29# N80 BTC. Set @ 6,290 - 9,898'. Cmt w/ 1,750 sx. o ri rapt.a, e s 01 1 Tie Back: 7" 26# N80. Set @ Surf - 6,290'. GR -GS: 8578' -8664' Cmt w/ 200 sx. an PK- PN F A red ON 0, kid HC -HD: 9043 -9067' 0 reA HC -HD: 9076 -9120' e 8 H E -H F: 9203 -9217' HI-HK: 9320 -9370' HK -HN: 9394 -9445' V A _ _-_ HK -HN: 9448 -9463' H K -H N : 9464 -9544' Fill: 9703' (WL Tag Feb '09) _ HN -HR: 9560 -9610' FISH (pkr): 9,710' (Aug 2000) Pa 441� — HN -HR: 9616 -9673' PBTD: 9,809' MD (9,505' TVD)�� HN -HR: 9690 -9723' jom TD: 9,900' MD (9,595' TVD) • /TO ENERGY XTO Energy Inc. MGS A13 -12RD Coil TBG Acid Stimulation Procedure COOK INLET, ALASKA WELL DATA SURFACE CASING: 13 -3/8" 61# J55 BTC. Set @ 1593'. Cmt w/ 1300 sx. INTERMEDIATE CASING: 9 -5/8" 40 & 43.5 #, N80. Set 6501' (Window). Cmt w/ 700 sx. LONGSTRING: 7" 26# & 29 #, N80. Set @ 9898'. Cmt w/ 1950 sx. TUBING: 2 -7/8 ", 6.5 #, N80, 8rd. Set @ 8523'. SMALLEST ID: 2.205" @ XN Nipple @ 8515'. PACKER: Baker 7" DB1 Perm Pkr @ 8466'. PERFORATIONS: GR -GS: 8578 — 8664' HC -HD: 9043 — 9067' & 9076 — 9120' HE -HF: 9203 — 9217' HI -HK: 9320 — 9370' HK -HN: 9394 — 9445', 9448 — 9463' & 9464 — 9544'. HN -HR: 9560 — 9610', 9616 — 9673' & 9690 — 9723'. NET PAY: 504' MAX HOLE DEVIATION: 31 Degrees from 7169 — 7524' BHP: 3500 psi BHST: 168 Deg F PBTD: Fill @ 9703'. Fish (PKR) @ 9710' CURRENT PROD: 34 BOPD & 257 BW on 6- 19 -11. OBJECTIVE: Coil Tbg Acid Stimulation. NOTES: • AFE # 1104306 • Heat FIW to ±100 ° F 5 -23 -11 XTO Energy Inc. • • 2 MGS A13 -12RD Cook Inlet, Alaska Materials Required: ,/ • 15,000 gale' (357 HCL DAD Acid (25% xylene) • 15 bbl Gel Pill (1/2 gal / bbl Liquid HEC -10 + 1 gal Greencide) (Provided by MI) • 700 bbl 3% KCL FIW Water ➢ 7,000 lbs Powdered KCL (1000 lbs KCL /100 bbl FIW for 3 %) (Provided by MI) ➢ 70 gal B145 Friction Reducer (SLB) • N2 bottles to purge reel after job or N2 unit • 100 gal Nalco EC6079A Scale Inhibitor Equipment Required: • 1.75" CTU • Filter Skid (3 -5 micron) • 250 bbl PTS Flowback Tank ➢ Mud Pump to be tied into tank to pump load to A44 -11 Disposal Well ➢ Install 2" line from tank top to production header for gas lift @ EOJ • Return line w/ choke manifold to 250 bbl Surge Tank & to Production Facilities ➢ Manifold to contain a sample catcher to monitor fluids pH DAD Acid System to contain these additives: • 10% HCL • 250 gpt Xylene • 15 gpt U74 Dispersing Agent • 5 gpt A261 Corrosion Inhibitor • 8 ppt A153 Corrosion Inhibitor Aid • 20 ppt L58 Iron Reducing Agent • 5 gpt W60 Anti - sludge • 5 gpt W54 Non - Emulsifier • 2 gpt F103 Surfactant PROCEDURE: 1. MIRU 1.75" Coil Tbg Unit. RU a filter skid between the mud pits & HP triplex. Install press gauges on the CT, CT Annulus & 2 -7/8" prod tbg annulus. Makeup wash nozzle,. Contact the AOGCC 24 hrs prior to BOP test. Press test all lines & BOP's to 5,000 psi. ` Max Press = 4,000 si. CTU operator to ensure all tools to be calipered before RIH. Smallest ID = 2.205" XN Nipphe- J 8515'. 2. Conduct a pre job safety meeting. 5 -23 -11 KTO Energy Inc. 3 MGS A13 -12RD Cook Inlet, Alaska ACID SPOT & SOAK: 3. Open the CT annulus. RIH w/ CT @ 80 fpm while pumping @ 1 BPM slick 3% FIW while in the tbg. Slow CT rate to 5 FPM while passing over the gas lift mandrels (See Wellbore Diagram). Keep rate @ +25 fpm while passing over the perfs. Stop at 9700'. Lay 1000 gal (42 514) 10% DAD from 9700' to 8570' while PUH @ 40 fpm & 1 BPM using slick 3% FIW to displace. PU CT to 8400' & SD. Let acid soak for 30 min. 4. RIH to 9700' @ 40 fpm & 1 BPM while circ out acid with 10 bbl gel pill followed w/ 50 bbl slick 3% FIW. ACID WASH PERF'S: / 5. Acid wash from 9700 — 9000' (do not include perfs 8578- 8664') w/ 2000 gal (48 bbl) 10% DAD @ 1 BPM, moving the CT 30 ft/min. Make 1 pass up and 1 down. 6. From 9700', circ hole clean with 100 bbl slick 3% KCL FIW @ 1.5 BPM. Do NOT mix any friction reducer to FIW beyond this step. ACID INJECTION JOB: � 7. SI the CT annulus. Inject 8300 gal (198 bbl) 10% DAD while making 5 passes across the interval HC- HR from 9700 — 9000' while pumping @ 0.7 BPM and moving the CT @ 12 ft/min. 8. POOH to 8670'. Pump remaining 40 bbl acid across the GR -GS making 4 passes from 8670 — 8570' @ 10 fpm. 9. Mix 100 gal Nalco EC6079A Scale Inhibitor in 200 bbl 3% KCL FIW (no friction reducer). Flush acid with 200 bbl 3% FIW + Scale Inhibitor while making 3 passes across the interval from 8570 — 9700' while pumping @ 0.7 BPM and moving the CT @ 12 ft/min. 10. Open CT annulus. POOH with coil tbg @ 100 fpm. Close the Swab valve. Bleed off press. RD CTU. 11. Slowly start up gas lift taking returns to the PTS tank. Cont to flow into PTS tank until pH is neutral (7). Switch returns into production header & start testing well. Record any use of the disposal well with fluid type, volume and injection rates & press. Overflush by 125 bbl FIW at end of disposing fluids. Paul Figel Engineering Manager 5 -23 -11 ................... ; .......... [/i ii~l I'l r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging, Per/orate Pull tubing . After casing Repair well~ Other X 2. ~Name of_Ope,rator [;ross llmDers 0peratinq Compan.y 3. Address 210 Park Ave.,Suite 2350 0kla. City, 0K.73142 4. Location of well at surface Leg 4,Cond. 29,1561'N&381'W of SE Cnr of Sec.11,T8N,R13W At top of productive interval 5. Type of Well: Development X Exploratory Stratigraphic Service At effective depth Leg 4,Cond. 29,1561'N&381'W of SE Cnr of Sec.ll,T8,R13W, At total depth @9043' MD, :1288'N&646'E of SE Cnr. of Sec.l[,TSN,R13W,SM 6. Datum elevation (DF or KB) 116' KB 7. Unit or Property name Hiddle Ground Shoal feet 8. Well number A13-12RD 9. Permit numbe~approval number 173-035 ~10. APl number 50- 733-20191-01 11. Field/Pool MGS "G" Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 9900 feet Plugs (measured) 9595 feet 9809 feet Junk (measured) 9504 feet Size Cemented 1593' 13-3/8" 1300 sx 6501' 9-5/8" Sidetrack O' 6290' 7" 6290' - 9898' 7" 1750 sx measured 8578' - 9710' true vertical (11 intervals) Tubing (size, grade, and measured depth) 2-7/8",6.5/f,N-80 EUE 8RD~,437' Packers and SSSV (~pe and measured depth) Baker DB packer @ 8,466' Baker TE5 SSSV @ 326'. Measured depth True vertical depth 1593' 1592' 6501' 6477' O' - 6290' O' - 6270' 6290' - 9898' 6270' - 9593' RECEIVED MAY 22 2001 Alaska Oil & Gas Cons, Commissio~ Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) 8578' - 8664' & 9043'-9699' Treatment description including volumes used and final pressure C0/azd trt w/1200g 7-1/2~HCL&2OOO/g Xyl ene. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation 52 71 42 580 85 Subsequent to operation 77 109 47 660 80 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X, 16. Status of well classification as: Oil X Gas .. Suspended Service 17. I hereby certify that the f~'~ing is true and correct to the best of my knowledge. Sign~~'J~ Title Sr. Engineering Tech Form 10-404 Rev O6/15/88 -"- ORI¢INAL Date 05/14/01 I~''~ SUBMIT IN DUPLIC.~.~.~ DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: MSG A13-12RD AFE #: 100433 ESTIPLATED TD: PBTD: COUNTY/STATE: Cook Inlet, AK ACCOUNTING #: 62209 CLASSIFICATION: RESTORE PRODUCTION WITH COILED TUBING USING ACID AND XYLENE WORK ACCOMPLISHED: RESTORE PRODUCTION W/CT USING ACID & XYLENE DESCRIPTION: PLATFORM A COOK INLET CONTRACTOR: OPERATOR: CROSS TIMBERS OPERATING COMPANY o5/oi/oi 05/02/01 o5/o3/oi o5/o4/oi FIRST REPORT. Test Before: 52 BO, 42 BW, 71 MCF, 938 MCF Injected. Objective: Restore Production With Coiled Tubing Using Acid And Xylene. Date First Report: 05/01/01. Rig up CTU and test lines and equipment to 3000 PSI. Hold safety meeting. RIH with 1.73" jet nozzle on 1 h" coil tubing while pumping .5 bbl/min diesel to 8578'. Jet the GR perfs from 8578' to 8664' and HC, HE, HI, and HN perfs from 9043' to 9699' with 1200 gal 7 h% HCL plus additives. Pump 5 bbl diesel spacer and jet same perfs from 9699' to 9043' and 8664' to 8578' with 2000/gal xylene. RIH to 9699' displacing CTU with diesel then pump 300 scf/min N2 while pulling out of hole. Secure well and rig down CTU. DCC: $42,700 CCC: $42,700 GL 24 hrs. Rec 65 BO, 45 BW, 112 MCF. Inject 928 MCF. TP 80#, CP 635#. DCC: $-0- CCC: $42,700 GL 24 hrs. Rec 68 BO, 46 BW, 90 MCF. Injected 981 MCF. TP 80#, CP 660#. DCC: $-0- CCC: $42,700 GL 24 hrs. Rec 77 BO, 47 BW, 109 MCF. Injected 981 MCF. TP 80#, CP 660#. DCC: $-0- CCC: $42,700 FINAL REPORT 210 PARK AVE,, SU~S0 OKLAHOMA CITY, OKLAHOMA 73102 Phone: 40S-232-4011 lax: 405-232.5778 [ [[ [11 1[1[ ii i -I i it i , ] ,,,, , P. , Fax TOM MAUNDER From= BP, ENT ROBERSON ~ Phone: 907-276-7542 APPLICATION FOR APPROVALS Pages: t - 4 (IN~LUD, lNG cO.VER PAGE) CC: [-1 Urg~n~ [] For Review [] Please comment I~1 Please Reply Fi Please Recycle -Cammeflts: ATTACHED IS (1) ONE APPLICATION FOR SUNDRY APPROVAL FOR COILED TUBING JOB. IF YOU HAVE ANY QUESTIONS, PLEASE CALL CHARLES POPE @ (4O5} 3t9-3211. 12:48PM CROSS T~MBERS OP CO 405 23B 5538 /~ , STATE OF ALASKA ~--/ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Type of Request: Abal3dO~ Suspend ~ Operation ahutclown After easing ~ Repair well Plugging Time ext~s~n Change ap~oved program ~ Puff tubing ~ Variance ~ Perorate .... Other .. P.£/4 . Neme._of. Operator_ . . _ ross [lmDerS upe~al:!n~[;p~any 3. Address ;~350 PARK AVl[, SUITE 2350 ~. CI~. ~. 7310E 5. Type of Well; Development ¥ Exploratory $tratlgraphle Sen/Ice 4. Location of well at eurface 'A',Leg 4,C0nd. 29. :1561'N & 381'1,/of SE Cnr of Sec. 11,TSN,R13W,$H At top of productive Interval ~043' (H.D.), 1288'N & 646'E of SE Cm. of Sec, 11,TSN,R13W.$H At effective depth At total depth 09900' (H.O.), ~20g'N & 707'E of SE Cnr. of Sec. 11,TBN,RI3W,SH 6. Datum elevation (DF or KB} 7. Unit o~ Pro, any name Hfddle G~ound'Shoal 8. Well number A13-12RD 9. Permit number 173-035 10, APl number $o- 733-20191-01 11, Field/Pool MOS/'G' Pool feet 1P~, Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9900 feet Plugs (measured) 9595 feet 9809 feet Junk (measured)' 9504 feet Casing Length Structural Conductor surface 1593' Intermediate 6501 ' Production 0' ' 6290' Liner 6290' -9898° Perforation depth: meaeured 8578' - 9710' Size Cemented Measured depth True vertical depth true vertical 13-3/8".61~,J-55 1300 sx 1593' 1592' 9-$/8', N-80&P-110 S~detrack 6501' 6477' 7',26-29~,N-80 41 bbls '~' 0' - 6~90' 0' - 6270' 7',29~,N-$0 1750 sx 6290'-9898' 6270' - 9593' (11 intervals) Tubing (size, grade, and measured depth) 2-7/8',6..~,N-80 EUE SRI~I 8,437', Packem and SSSV~yepaK~dmeasumdde~th) B~iER e 8466'. BA~ER TE5 SSSV e 326', 13, Attachments Description summary of proposal Detailed operations program BOP sketch 14. Eetlmeted date for ~ommencing operation 15. Statue of Weft ¢laesification as~ 04/25/2001 X 16. If proposal wes verbally approved Oil Gas~ Name of approver ~ D~te approved ' Service BRENT ROBERSON igned ~ --~,-~.,x /j .-u' ~,,-~,-- Title SR. ENGINEERZNG TECfl Suspended _. Date 04/11/2001 FOR COMMISSION USE ONLY Conditions of approval: Notify Commissioq~ representative may wltneas "~"~b~ ~-a,~C;3';~ -¥-~.~ Plug IntegMtY BQP Test Location clearance Mechanical Integrity Test ~ Subsequent form required 10- L[~)L_~. ORIGINAL SIGNED B,.' D Taylor Seamoun! Approved by order of the Commission Fo~o-4o3navOe/~/~ CONTACT CHARLES POPE ~ (40'b') 319~3211 ORIGINAL APR 2 7 2001 '0~ ~:48P~ CRO$~ T~RS OP CO 405 ~ 55~8 CROSS TIMBERS OPERATING COMPANY MG$ A13--12RD ......... ..COOK INLET~ ALASKA ELEVATION: WELL DATA SURFACE CASING: INTERMEDIATE CASING: PRODUCTION CASING: TUBING: PERFORATIONS: OBJECTIVE: TD: 9900' (MD) PBTD: 9809' (MD) 13 3/8" 61# J55, Set ~ 1593', 9 5/8" 40. 43.5# N80, P1 I0. Set ~ 6501' 7" 26, 29# NS0. Set at 9898'. HC 9043-9067', 9076.9120' HE 9203-9217' HI 9323.9365', 9394.9445', 9464-9544' . ..... HN 9569-9590', 9640-9670' Restore production with Coiled Tubing using Acid and Xylene RU CTU. NU BOPs and test to 3000 psi. Continue GL well while RIH w/jet tool on 1 ;~" CT while circ w/ diesel to 8550'. Jet the OR perfs from 8578-8664' w/500 gal of 7 ~% HCI plus additives. Circ out. Continue in hole to 9710'. Jet pcrf~ w/2000 gal ofxYlene while POOH. Displace CTU w/diesel. POOH. RD CTU, Allow Xylene to soak for 6 hfs, 2. Put well in test and test tbr 3 days. Take hourly readings of oil, wtr, gas, injection gas, TP and CP- Cross Timbers 0-';~ ting Company Pm~nt Completion MGS A13-12RD Cook Inlet, Alaska Leg 4, Conductor Z9 APl No.: 50,733-20191-01 ST Spud: 4/23174 (OWB 24" Conductor Csg. Set @ 370'. Surf Csg; 13 3/8", 61 lb, J55. Set @ 1593'. Cmt'd w/1300 sx. Prod Csg: 9 5/8", 40 & 43.5 lb, NS01P110. Set @ 6501'. Cmt'd w/ 3/30/77: Ran 7" I~ner to Surf 7"26# NS0 0-6290'. Cmt'd w/41 bbl G Neat. Calc'd TOC 4837'. Liner: 7" 26 lb., NS0.0-6290'. 29 lb,, N80.6290'-9898'. Cmt'd w/1750 PBTD; 9809' TD: 9900' 10/26/2o0o Tbg (Aug 11, 2000): 2 7/8" 6.5~ N80 8R EUE Bkr T5 9S9V ~ 2..313" X Nipple @ 8426' Bkr Loc @ 8465' Bkr DB pkr @ 8466' 2.205" XN nipple @ 8515' WL re-entry guide @ 8522' P. 4/4 Aug 11,2000 GLM MD TVD Po~ PSC Pso #1 1976 1975 10 901 950 #2 3567 3565 10 880 921 #3 4873 4870 10 861 889 ~4 5770 $764 10 839 865 ~ 6605 6573 12 819 847 ~6 7279 7t71 12 798 823 #7 7883 7700 12 775 796 #8 8383 8143 16 Ori§ee RECEIVED APR 2 ? 2001 GR-GS: 8578'-8664' HC-HD: 9043'-9067' HC-HD: 9076'-9120' HE-H F: 9203'-9217' HI-HK: 9323'-9365' HK-HN: 9394'-9445' HK-HN: 9448'-9463' HK-HN: 9464'-9544' HN-HR: 9560'-9590' HN-HR: 9640'-9670' HN-HR: 9690'-9710' 0~/11/~001 14: '26, 14052325778 CTOC OKC PAGE MMISSIOAL_ APPLICATION FOR SUNDRY'APPi / L 01 1. Type of Request: Abandon ~ Suspend .... Operation shutdowns. After casing ~ Repatr Well Plugging Tlrne extension __ Change approved program ! P;J-~ltubing Variance . '. Perforate .Name of Operator . ross Ttm~ers 00eratln.q Comoan¥ 3. Address E350 PAI:{K AVE, SUITE ~.350 0KI.A. Cl~, OK, 73102 §, Type of Well,. Development -X EXplOratory ~ Straflgraphle .... Service 4. Locatian of well at surface 'A',Leg 4,Cond. 29, 1561'N & 381'W of SE Cnr of Sec. l.l.,TSN,R13W,SM At top of productive interval 99043' (H.D,), 1288'N & 646'E of SE Crn. of Sec, ll,T8N.RI3W,SM At effective depth At total depth 09900' (M.D.), 1209'N & 707'E of SE Cnr. of Sec. 11,T8N,R13W,SIt 6. Datum elevation (DF or KB) 116' ~ 7. Unit or Property name Middle Ground Shoe1 8. Well number A13-12RD 9. Permit number, ~ 3.73-035 " 10. APl number 50- 733-2019!-01 11, Field/Pool M~S!'G" Pool 1g, Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9900 ~feet . Plugs (measured} ..... g595 ~f%t 9809 feet Junk (measured) 9504 feet Casing Length Structural Conductor surface 1Bg3' Intermediate 6501 ' Production 0' "6290' Liner 6290' -9898' Perforation depth: measured Size Cemented Meaaumd depth 13-3/8',61#,J-55 1300 sx 1593' g-5/8", N-80&P-110 Sidetrack 6501' 7",26-2~,N-80 4! bbls '~' 0' - 6290' 7',E~,N-80 1750 'sx ' 6290'-9898' 8578' - 97[0' (11 intervals) True verfical depth 1592' 6477' 0' - 6270' 6270' - 9593' true vertical Tubing (size, grade, and measured depth) 2-7/8',6,5~,N-80 £UE ~De 8,437', Paokem and 85SV de~ER . "JIltER ~pep~d measured Iii 8466'. TE5 SSSV e 326' 13. Attachments Description summary of proposal Detailed operations program X BOP sketch 14. Estimated date for commencing operation 15, Status of well classification as,, 04/25/2001 16, If proposal wac verbally approved Oil X, Gas ~ =~arne of approver Date approved Service 17. I hereby certify that the foregoing ie true and correct to the best of my knowledge, BRENT ROBERSON Signed Title SR, ENGINEER.lNG TECH Suspended Date 04/II/2001 FOR COMMISSION USE ONLY Oondltlona of approvah Notify CommlsaIo~o representative may witness Plug integrlty~ BOP Test . . Location clearance Mechanical Integrity Test .__ Subaequent form req.ired 10--. t^""r°v" L- S- Approved by order of the Commission '!.')RIGINAL sIGNED BY' Taylor Seamount Form 10-403 Rev O6/15/88 CONTACT CHARLES POpEREcEiv..~.. Commissioner SUBMIT IN TRIPLICATE ORIGINAL APR 1 i ZOO1 Alaska Oil & Gas Cons. Commission Anchorage 84/11/2881 · 14:26 14852325778 CTOC OKC CROSS TIMBERS OPERATING COMPANY MGS AI3-12RD COOK INLET, ALASKA ELEVATION: TD: 9900' (MD) PBTD: 9809' (MD) P~GE 83 RECEIVED APR 1 1 2001 ~:~ uulm. (,j0flt|h,m~O" Anchorage WELL DATA SURFACE CASING: INTERMEDIATE CASING: 13 3/8"61#J55. Set~. 1593'. 9 5/8" 40, 43.5# NS0, PI 10. Set ~ 6501'. PRODUCTION CASING: 7:' 26, 29# NS0. Set at 9898'. TUBING: PERFORATIONS: HC 9043-9067',9076-9120' HE 9203-9217' HI9323-9365',9394-9445',9464-9544':-' HN9569-9590',9640-9670' OBJECTIVE: Restore production with Coiled Tubing using Acid and Xylene RU CTU. NU BOPs and test to 3000 ps/. Continue GL well while RIH w/jet tool on 1 ½" CT while c/re w/ diesel to 8550'. Jet the GR perfs from 8578-8664' w/500 gal of 7 ¼% HCi plus additives. Circ out, Continue in hole to 9710', Jet perfs w/2000 gal ofxylene while POOH. Displace CTU w/diesel, POOH. KD CTU, Allow Xylene to soak for 6 hrs. 2. Put well in test and test for 3 days. Take hourly readings of oil, wtr, gas, injection gas, TP and CP. 84/11/2881 14: ~2G 14852325778 CTOC OKC ~~ Cross Timbers ~:~,rating Company Present Completion MGS A13-12RD Cook Inlet, Alaska Leg 4, Conductor 29 APl No.: 50-733-20191-01 ST Spud: 4123/74 (owa 6110169) 24" Conductor Csg. Set @ 370', Surf Csg: 13 3/8", 61 lb, J55. Set @ 1593', Cmt'd w/1300 sx. Prod Csg: 9 518", 40 & 43.5 lb, N80IP110, Set @ 6501'. Cmt'd w/ ~dp 10/26/2000 PAGE Tbg (Aug 1 i, 2000): 2 7/8" 6.5# N80 8R I=UE Bkr T5 SSSV @ 326' 2.313" X Nipple @ 8426' Bkr Loc @ 8465' Bkr DB pkr @ 8466' 2.205" XN nipple @ 8515' WL re-entry guide @ 8522' Aug 11, 2000 GLM MD TVO Port PsC Pso #1 1976 1975 10 901 950 #2 3567 3565 10 880 921 #3 4873 4870 10 861 889 #4 5770 5764 10 839 86~ #5 6605 6573 12 819 847 #8 7279 7171 12 798 823 -' #7' 7883 '7700 12 775 796 #8 6383 8143 16 Orifice 84 RECEIVED APR 1 1 2001 3/30/77: Ran 7" liner to Surf 7"26# N80 0-6290'. Cmt'd wi 41 bbl G Neat. Calc'd TOC 4837'. Liner: 7" 26 lb,, NS0, 0-6290'. 29 lb., N80.6290'-9898'. Cmt'd w/1750 sx, GR-GS: 8578'-8664' PBTD: 9809' TD: 9900' HC-HD: HC-HD: HE-HF: HI-HK: HK-HN: HK-HN: HK-HN: HN-HR: HN-HR: HN-HR; 9043'-9067' 9076'-9120' 9203'-9217' 9323'-93650 9394'-9445' 9448'-9463' g464'-9§44' 9560'-9§90' 9640'-9670' 9690'-9710' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request: Abandon Suspend ~ Operation shutdown~ Re-enter suspended well ~ After casing ~ Repair well Plugging Time extension Stimulate Change approved program~ Pull tubing A Variance ~ Perforate~ Other X 2. Name of Operator Cross Timber~ Operatinq Company 3. Address 2350 PARK AVE, SUITE 2350 OKLA. CITY, OK. 73102 5. Type of Well: Development ExPloratory Stratigraphic Service 4. Location of well at surface "A",Leg 4,Cond. 29, 1561'N & 381'W of SE 6nr of Sec. 11,T8N,R13W,SM At top of productive interval ca9043' (M.D.). 1288'N & 646'E of SE 6rn. of Sec. 11,T8N,R13W,SM At effective depth At total depth ca9900' (M.D.), 1209'N & 707'E of SE Cnr. of Sec. 11,T8N,R13W,SM 6. Datum elevation (DF or KB) 116' KB 7. Unit or Property name Mlddle Ground Shoal 8. Well number A13 12RD 9. Permit number _- 73-,35,/94-046 10. APl number 50- 733-20191-01 11. Field/Pool HGS/"G" Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9900 feet Plugs (measured) 9595 feet 9809 feet Junk (measured) 9504 feet Casing Length Structural Conductor Surface 1593' Intermediate6501 Production 0' - 6290' Liner 6290' 9898' Perforation depth: measured Size Cemented Measured depth 13-3/8",61#,J-55 1300 sx 1593' 9-5/8", N-80&P-110 Sidetrack 6501' 7",26-29~,N-80 41BBLS "G" O' - 6290' 7",29#,N-80 1750 sx 6290' 9898' 8578' - 9710' true vertical (11 intervals) ORIGINAL True vertical depth 1592' 6477' 0' - 6270' 6270' - 9593' RECEIVED APR 10 Tubing (size, grade, and measured depth) A~a~l~ 0il & Gas Coas. Commission 2-7/8",6.5~,N-80 EUE 8RDCa 8,437'. Allchorage Packers and SSSV (type and measured depth) Guiberson Uni-pkr VII ca 8887' (JUNK). BAKER HB PKR ca 8437'. BAKER FV6 SSSV ca 328'. 13. Attachments Description summary of proposal Detailed operations program X BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: 05/19/2000 16. If proposal was verbally approved Oil X Gas Name of approver Date approved Service 17.1 here~.certityxth~,~egoing is true and correct to the best of my knowledge. Signed jf,.,,~~,.--~//r/~,.--~ Title SR. ENGINEERING TECH Suspended Date 04/07/2000 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission. ~..representative may witness Plug integrity BOP Test ~" Location clearance IApprova, No. OO' O ]ql Mechanical Integrity Test Approved by order of the Commission Subsequent form required 10- ~,~0¢~ ORIGINAL SIGNED BY Robert N. Christenson Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE CROSS TIMBERS OPERATING COMPANY MGS A13-12RD COOK INLET, ALASKA ELEVATION: WELL DATA SURFACE CASING: INTERMEDIATE CASING: PRODUCTION CASING: TUBING: PERFORATIONS: OBJECTIVE: KB: TD: 9900' (MD) PBTD: 9809' (MD) 13 3/8" 61 It J55. Set ~ 1593'. 9 5/8" 40, 43.5# N80, P110. 7" 26, 29# NS0. Set at 9898'. Set@6501' HC-HD 9043-9067',9076-9120' HE-HF 9203-9217' HI-HK 9323-9365',9394-9445',9464-9544' HN-HR 9569-9590',9640-9670' Remove Junked Packer and Return to Production Note: H2S 0 ppm on 3/30~2000. This well should "no flow" but will definitely SI below 590 psi. If well control is needed, FIW will control this well. Have mud and weight material on location during workover operations. 1. RU SL. Test lubricator. Pull GLV It8. RD SL. . Skid rig and RU. Circ well w/FIW. Install BPV. ND tree and NU BOP's. Test BOP's. Release Bkr (BOT) HB pkr and POOH w/2 7/8" 6.5it L80 8R EUE ABMOD tbg and pkr assembly. LD and send to shore for inspection. Note: This well should circ (Aug 1999 the well circ during CTU operations). If well does not stand full after 1 csg vol, pump only enough FIW to control well. The threads on the BPV were reported as worn during the last workover and will be replaced during this workover. Have a spear in case the lift threads are worn also. o PU 3 %" DP. TIH w/mill and BHA on 3 ½" DP. Locate junked Guiberson Uni VII pkr ~ 8887' and mill up pkr. POOH w/pkr assembly and BHA. TIH w/bit and scraper for 7" 29# csg, on 3 ½" DP to PBTD. Circ well clean. Pump a 40 bbl Xanvis pill to clean well. Circ well clean. If necessary, pump a second pill. Circ well clean using FIW. POOH. 4. RU Schlumberger WL. NU BOP's. Test BOP's. Run and set a Bkr pkr assembly as follows: Item Length Top Btm Bkr DB pkr 3 8450 8453 Seal Bore Extension 10 8453 8463 2 7/8" 6.5# N80 8R EUE 32 8463 8495 Otis XN nipple 2.205" ID 1 8495 8496 2 7/8" 6.5# N80 8R EUE 6 8496 8502 WL Re-entry Guide w/ 1 8502 8503 pmp out plug set @ 2000 psi RECEIVED APR 10 Alaska Oa & Gas Cons. Commission CROSS TIMBERS OPK~tNG COMPANY MGS A13-12RD COOK INLET, ALASKA REMOVED JUNKED PACKER AND RETURN TO PRODUCTION 04/07/00 Set pkr assembly ~ +8450'. RD Schlumberger. TIH w/Bkr seal assembly, gas lift mandrels and 2 7/8" 6.5//N80 8R EUE tbg to top ofpkr as follows: Item Length Top Btm 2 7/8" 6.5# N80 8R EUE 300 0 300 Bkr T5 SSSV 5 300 305 2 7/8" 6.5# N80 8R EUE 8112 305 8417 Otis X nipple 2.313" ID 1 8417 8418 2 7/8" 6.5# N80 8R EUE 32 8418 8450 GBH-22 Iocator seal assy 10 8450 8460 Gas Lift Mandrel Spacing (check with Operations Engineer prior to running for updated design) GLM MD TVD Po~ Ptro Psc Pso #1 1958' 1957' 12 950 882 950 #2 3590' 3588' 12 930 860 910 #3 4842' 4839' 12 910 837 874 #4 5783' 5777' 16 960 813 865 #5 6572' 6542' 16 940 790 830 ~ 7238' 7135' 16 920 767 803 #7 7874' 7693' 16 900 744 776 #8 8356' 8119' 1~" Orifice Locate pkr and land tbg. ND BOP's. NU tree. Press tbg to 2000 psi (plus WHP) and pump out plug in pkr. Return well to production. Note: the threads on the BPV were reported as worn during the last workover and will be replaced at this time. RECEIVED APR 10 2000 Alaska 0il & Gas Cons. Cross Timbers '~ ~ating Company Present Completion MGS A13-12RD Cook Inlet, Alaska Leg 4, Conductor 29 APl No.: 50-733-20191-01 Spud: Orig WB 6110169 Sidetrack: 4123/74 24" Conductor Csg. Set @ 370'. Surf Csg: 13 3/8", 61 lb, J55. Set @ 1593'. Cmt'd w/1300 sx. Prod Csg: 9 5/8", 40 & 43.5 lb, N80/P110. Set @ 6501'. Cmt'd w/ 3/30/77: Ran 7" liner to Surf 7" 26 lb., N80 0-6290'. Cmt'd w/41 bbl G neat. TOC Calc'd 4837' Liner Csg: 7" 29 lb., N80 6290'- 9898'. Cmt'd w/1750 sx. PBTD: 9809' TD: 9900' ~Prepared by: jrs 5121199 Tubing: 2-7/8", 6.5#, N80/L80 EUE 8rd. Baker "FV-6" TRCSSV wi "X" Profile @ 328' GLM MD TVD Po~ Ptm #1 1958' 1957' 12 950 #2 3590' 3588' 12 930 #3 4842' 4839' 12 910 ~, 5783' 5777' 16 960 #5 6572' 6542' 16 940 #~ 7238' 7135' 16 920 #7 7874' 7693' 16 900 #8 8356' 8119' 1/4" Orifice Psc 882 860 837 813 790 767 744 Pso 950 910 874 865 830 803 776 Otis "X" Nipple @ 8398' (2.313" ID) I Jt. 2-7/8" 6.5~ N80 EUE 8rd tbg. Baker "HB" Packer @ 8437' w/40000~ shear I Jt. 2-7/8" 6.5# N80 EUE 8rd Tbg, Otis "XN" Profile Nipple @ 8474' (2.205" ID) Baker Bell Wireline Re-entry Guide @ 8476' 4 Jts. 2-7/8" Tubing Fish (TOF @ 8777') Guiberson Uni-Packer Uni VII @ 8887' (set 4/13/77) Otis "X" Nipple @ 8928' EOT @ 8961' RECEIVED APR 1 0 2~000 .Alaska Oil & Gas Cons. Commiss~ An~or~ GR-GS: HC-HD: HC-HD: HE-HF: HI-HK: HK-HN: HK-HN: HK-HN: HN-HR: HN-HR: HN-HR: 8578'-8664' 9043'-9067' 9076'-9120' 9203'-9217' 9323'-9365' 9394'-9445' 9448'-9463' 9464'-9544' 9560'-9590' 9640'-9670' 9690'-9710' Cross Timbers r- -ating Company ,Proposed Completion MGS A13-12RD Cook Inlet, Alaska Leg 4, Conductor 29 APl No.: 50-733-20191-01 Spud: Orig WB 6110169 Sidetrack: 4/23174 24" Conductor Csg. Set @ 370'. Surf Csg: 13 3/8", 61 lb, J55. Set @ 1593'. Cmt'd w/1300 sx. Prod Csg: 9 5/8", 40 & 43.5 lb, N80/P110. Set @ 6501'. Cmt'd w/ 3/30/77: Ran 7" liner to Surf 7" 26 lb., N80 0-6290'. Cmt'd w/41 bbl G neat. TOC Calc'd 4837' Liner Csg: 7" 29 lb., N80 6290'- 9898'. Cmt'd w/1750 sx. PBTD: 9809' TD: 9900' cdp 4/7/2000 Item Length Top Btm 2 7/8"6.5# N80 8R EUE 300 0 300 BkrT5SSSV 5 300 305 2 7/8" 6.5# N80 8R EUE 8112 305 8417 OtisX nipple 2.313" ID 1 8417 8418 2 7~8" 6.5# N80 8R EUE 32 8418 8450 Bkr DB pkr 3 8450 8453 Seal Bore Extension 10 8453 8463 2 7~8" 6.5~ N80 8R EUE 32 8463 8495 Otis XN nipple 2.205" ID1 8495 8496 2 7~8" 6.5# N80 8R EUE 6 8496 8502 WL Re-entry Guide I 8502 8503 GLM MD 'I'VD Po~ Ptro Psc Pso #1 1958' 1957' 12 950 882 950 #2 3590' 3588' 12 930 860 910 #3 4842' 4839' 12 910 837 874 #4 5783' 5777' 16 960 813 865 #5 6572' 6542' 16 940 790 830 #6 7238' 7135' 16 920 767 803 #7 7874' 7693' 16 900 744 776 #8 8356' 8119' 1/4" Orifice RECEIVED APR 1 0 2000 Alaska 0il & Gas Co~s. Commission Anchorage GR-GS: 8578'-8664' HC-HD: 9043'-9067' HC-HD: 9076'-9120' HE-HF: 9203'-9217' HI-HK: 9323'-9365' HK-HN: 9394'-9445' HK-HN: 9448'-9463' HK-HN: 9464'-9544' HN-HR: 9560'-9590' HN-HR: 9640'-9670' H N-H R: 9690'-9710' r Cross Timbers Operating Company August 23, 1999 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATTN: MR. BLAIR WONDZELL SUBJECT: SUBMISSION OF FORM 10-404 REPORT OF SUNDRY WELL OPERATIONS - ACID TREAT M.G.S. WELL NO. A13-12RD Attached, in duplicate, is the Report of Sundry Well Operations for MGS Well No. A 13-12RD. The workover included cleaning out the scale and paraffin with 15% HC1 and xylene. If you have any questions, please don't hesitate to call me at (907) 776-2511. Thank you! Sincerely, Bill Miller Office Manager Attachments HC01 Box 485, Old Wik Road, Kenai, AK 99611-9704 Onshore phone: (907) 776-2511, Onshore fax: (907) 776-2542 Platform A fax: (907) 776-2522, Platform C fax: (907) 776-2532 www. crosstimbers.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Pull tubing ~ After casing_ Plugging-- Perforate Repair well Other · 2. ~ameof~pe,rator uross ilmoers Operating Company 3. Address 52260 Shell Road Kenai, AK 99611-9704 5. Type of Well: Development X Exploratory Stratigraphic __ Service 4. Location of well at surface At top of productive interval At effective depth Leg 4,Cond. 29,1561'N&381'W of SE Cnr of Sec.11,TS,R13W, At total depth @9043' MD, 1288'N&646'E of SE Cnr. of Sec.11,T8N,R13W,SM 6. Datum elevation (DF or KB) 116' KB 7. Unit or Property name Hiddle Ground Shoal feet 8. Well number A13-12RD 9. Permit numbe~approval number 73-35/94-046/399-125 10. APl number 50- 733-20191-01 11. Field/Pool HGS "G" Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9900 feet Plugs (measured) 9595 feet 9809 feet 9504 feet Length Size 1593' 13-3/8" 6501' 9-5/8" O' - 6290' 7" 6290' - 9898' 7" measured 9043' - 9670' true vertical Tubing (size, grade, and measured depth) (9 intervals) Junk (measured)Top of fish @ 8777' Cemented Measured depth 1300 sx 1593' Sidetrack 6501' O' 6290' 1750 sx 6290' - 9898' ORIGINAL 1592' 6477' O' - 6270' 6270' 9593' 3-1/2",9.3#,N-80 EUE 8RD@0'-342' Packers and SSSV (type and measured depth) Guiberson Uni-packer VII @ 8887' 2-7/8",6.5~,N-80 EUE 8RDLa342'-8961' Otis SSSV @ 306'. 13. Stimulation or cement squeeze summary Intervals treated (measured) 8500' - 8759' Treatment description including volumes used and final pressure G1 ean out/acid treat with 15~ HC1 & Xylene. 14. Prior to well operation 43 Subsequent to operation 161 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing pressure 54 33 520 75 105 121 520 70 15, Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed F ~~~~~~:~ Title 0fl-ice Hanager Date 08/23~99 SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 - 44- ~--DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: A13-12RD AFE #: 99395 ESTIMATED TD: PBTD: COUNTY/STATE: Cook Inlet, AK ACCOUNTING #: 62209 CLASSIFICATION: REMOVE SCALE AND PARAFFIN BUILDUP W/COILED TUBING DESCRIPTION: PLATFORM A COOK INLET CONTRACTOR: OPERATOR: CROSS TIMBERS OPERATING COMPANY GL: KB: DF: 07131/99 08/01/99 FIRST REPORT. Previous production: 43 BOPD + 44 BW + 54 MCF. Input 655 MCF/D. Objective: Remove Scale & Paraffin Buildup w/Coiled Tubing. Work Accomplished: Remove Scale & Paraffin Buildup w/Coiled Tubing. 26 hrs RD off All-12RD2 WIW & move to A13-12RD. Finish RU. Test CT to 4200#. Test BOP's to 4500#. Held safety mtg. Place 1 SCBA on lwr deck, 2 SCBA on upr deck & 3 escape SCBA;s in CT operator cab. Make up BHA: Grapple connector, check vlv, x-over, hydraulic disconnect, pce circ vlv, extension, dwnhole filter, swvl jr, 1 90" gauge ring, rotating nozzle head (2 side jets @ .125" & 1 dwn jet @ 093"), total length 10.145'. TIH w/BHA on 1 3/4" CT @ 50 fpm. Pmpg 1.1 BPM @ 3158 psi. Slow dwn to 15 fpm 50' Gi.V to 50' below GLV. Tag fill @ 8617'. Wash thru. Tag hard fill @ 8719'. Wash thru. SD @ 8759'. Unable to wash thru (Top of fish @ 8777' per well file, might be working along outside of fish and the csg.) Spot 10 bbl of 15% HCl to end of CT. Press to 2000% & allow to bleed off (3 min to bleed to 1000 psi), displacing 1/2 to 1 bbl per sqz for a total of 3 bbl. Displace 7 bbl acid thru pkr @ 1/4 BPM & 2000 psi. Spot 24 bbl of xylene to end of CT. Pmp 5 bbl thru pkr 1 bbt per sqz (5 min to bleed from 2000 to 1000 psi). PU to 6162' & displace remaining xylene thru pkr @ 1/4 BPM, 3416 psi on CT & 3270 psi on WH. POH. RD Dowell. Move to Platform C. Well SI 4 hrs while RD. Turn to test. Used a total of 600 bbl of FIW. Jetting tool scratched on outside lie it was going in between the tbg & csg on top of fish. '~--DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: A13-12RD AFE #: 99395 ESTIMATED TD: PBTD: COUNTY/STATE: Cook Inlet, AK ACCOUNTING #: 62209 CLASSIFICATION: REMOVE SCALE AND PARAFFIN BUILDUP W/COILED TUBING DESCRIPTION: PLATFORM A COOK INLET CONTRACTOR: OPERATOR: CROSS TIMBERS OPERATING COMPANY GL: KB: DF: Gas Inj Fluid Total Time FTP, psi CP, psi WTR Rate Rec. Rec. Cut MCF/D BPH Bbl 2200 980 970 100 2300 175 900 100 450 20 20 2400 100 860 100 530 17 37 DCC: $67,992 CCC: $67,992 08/02/99 Put well in test Gas Inj Fluid Total Time FTP, psi CP, psi WTR Rate Rec. Rec. Cut MCF/D BPH Bbl 0100 80 860 90 530 10 47 0200 90 820 600 14 61 0300 80 820 52 600 12 73 0400 90 820 600 18 91 0500 90 800 66 600 13 104 0600 80 800 600 8 112 0800 90 820 82 656 5 122 1000 90 815 80 656 12 146 1200 90 820 82 757 85 163 1400 90 820 82 883 10 183 1600 90 820 80 883 11.5 206 1800 110 820 82 15.5 237 1900 90 770 1050 Loading up 2000 90 770 990 11 248 ~'-DAILY OPERATIONS REPORT WESTERN DISTRICT WELL NAME: A13-12RD AFE #: 99395 ESTIMATED TD: PBTD' COUNTY/STATE' Cook Inlet, AK ACCOUNTING #' 62209 CLASSIFICATION' REMOVE SCALE AND PARAFFIN BUILDUP W/COILED TUBING DESCRIPTION: PLATFORM A COOK INLET CONTRACTOR' OPERATOR: CROSS TIMBERS OPERATING COMPANY GL: KB' DF- 08/03/99 08/04/99 08/05/99 08/06/99 2200 90 760 990 10.5 269 2400 90 760 66 925 10 289 Intermediate csg press increased from 150 psi to 300 psi. Will bleed off 7 hr test (expressed in 24 hr rates): Gross 254 BFPD, Cut 67%. Clean 84 BO, Wtr 170 BPD, FTP 95 psi, CP 760 psi, Input 900 MCF/D. DCC: $-0- CCC: $67,992 12 hr test (24 hr rates): Gross 266 BFPD, Cut 62%, 101 BOPD, 165 BWPD, FTP 95 psi, CP 760 psi, Inj Gas 869 MCF/D. DCC: $-0- CCC: $67,992 12 hr test (24 hr rates): Gross 280 BFPD, Cut 54%, 128 BOPD, 152 BWPD, 96 MCF/D, FTP 90 psi, CP 740 psi, Inj Gas 861 MCF/D. Bled intermediate csg to 0 psi on 8/02/99 @ 4:30 PM. By 08/03/99 @ 2:00 PM, intermediate csg press had increased to 120 psi. DCC: $-0- CCC: $67,992 12 hr test (24 hr rates): Gross 282 BFPD, Cut 52%, 135 BOPD, 147 BWPD, 94 MCF/D, FTP 85 psi, CP 678 psi, Inj Gas 704 MCF/D. Surf csg press 10 psi. Intermediate csg press 155 psi. DCC: $-0- CCC: $67,992 12 hr test (24 hr rates)' Gross 290 BFPD, Cut 49%, 148 BOPD, 142 BWPD, 111 MCF/D, Inj Gas 775 MCF/D, TP 85 psi, CP 685 psi. DCC: $-0- CCC: $67,992 FINAL REPORT Cro~s 11ml~rs O' "rating Company Present Completion MGS At3.12RD Cook Inlet, Alaska Lei] X, Conductor x APl No.: Spud: Conductor Csg: 24". Set ~ 370'. Cmt'd wl SurfCsg: 13 318", 61 lb, J55. Set ,593'. cmrcl wi Surf Csg: 9 $18", 40~ & 43.5# NS0 & P-110. Set ~ 6,501'. Cmt'd wi Proci Csg: 7', 26-2I~ NSO. Set (~ 9,898' MD. (26# NS0, 0-6290'(2g~ NS0, Crm'cl wt PBTD: 9,809' (MD) 9,900' (MD) btc. 5/11/99 ' Tclbirtg:2 7/8" 6.5~ N80/LS0 8R EUE MC) 'I'VD Port P~o 1gSa' i ~?' t2 gSO 359(7 3585' 12 910 4842' 485~ 12 874 5783' 5777' 16 865 6572' 6542' 16 830 72~8' 7135' t6 803 7874' 7693' 16 776 6~6' 811 cj. 114 Orifice Ptro 95o 930 910 94O 920 9O0 862 86O 8'13 767 Otis "X" NIDI~e ~ 8.398' (2.313" ID). lit. 2-7/8' 6,5# Ne0 EUE 8rd tbg. Baker "HB" Pad;er ~ 8437' w/40,000~ shear ljt, 2-7/8" 6.5~ NS0 EU£ 8rd tbgo Otis "XN" Profile Nipple ~ 8474' (2.205" ID) BaXer Bell Re-Entry Guide (~8.476. GR-GS: 8,578'-8,664' MD 4 its. 2-?18" tt)g ~i~h ('rOF ~ 8~73 Guil~rson UNI-VII Packer (~ 8887' Otis '~(" NipPle ~ 8928' EOT ~ 8981' HC-HD: 9043'-9067', 9076'-9120' HD-HE: HE-HF: 9203'-9217' HI-HK: 9323'-9365' HK-HN: 9394'-9445', 9448'-9463', 9464'-9544' HN-HR: 9560'-9590', 9640'-9670', 9690'-9710' HR-HZ: Cross Timbers Operating Company July 12, 1999 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: SUBMISSION OF FORM 10-403 APPLICATION FOR SUNDRY APPROVAL TO ACID TREAT M.G.S. WELL NO. A13-12RD. Enclosed in triplicate is the Application for Sundry_ Approval, Form 10-403, to stimulate MGS A13-12RD utilizing 7-1/2% HC1. Operations are expected to begin August 1, 1999. If you have any questions, please don't hesitate to call me at (907) 776-2511. Thank you! Sincerely, Bill Miller Office Manager Attachments JUL 15 1999 Naska Oil & Gas Cons. Commission Anchorage HC01 Box 485, Old Wik Road, Kenai, AK 99611-9704 Onshore phone: (907) 776-2511, Onshore fax: (907) 776-2542 Platform A fax: (907) 776-2522, Platform C fax: (907) 776-2532 w~vw. crosstimbers.com STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon , Suspend Operation shutdown Re-enter suspended well ~ After casing Repair weil ~ Plugging Time extension ~ Stimulate X Change approved program Pull tubing ~ Variance ~ Perforate Other 2. NameofOperator Cross Timbers Operating Company 3. Address 52260 Shell Road Kenai, AK 99611-9704 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface "A",Leg 4,Cond. 29, 1561'N & 381'W of SE Cnr of Sec. 11,T8N,R13W,SM At top of productive interval @9043' (M.D.), 1288'N & 646'E of SE Crn. of Sec. 11,T8N,R13W,SM At effective depth At total depth @9900' (M.D.), 1209'N & 707'E of SE Cnr. of Sec. 11,T8N,R13W,SM 6. Datum elevation (DF or KB) 116' KB 7. Unit or Property name Middle Ground Shoal 8. Well number A13-12RD 9. Permit number 73-35/94-046 10. APl number 50- 733.20191-01 11. Field/Pool HGS/"G" Pool feet 12. Present well condition summary Total depth: measured true vertical 9900 feet Plugs (measured) 9595 feet Effective depth: measured 9809 feet Junk (measured) true vertical 9504 feet Casing Length Size Structural Conductor Surface 1593' 13- 3/8", 61#, J- 55 Intermediate6501 9-5/8", N-80&P- 110 Production 0' 6290' 7", 26~, N- 80 Liner 6290' - 9898' 7",29#,N-80 1750 sx Perforation depth: measured 9043' - 9670' (9 intervals) Cemented Measured depth True vertical depth 1300 sx Sidetrack true vertical Tubing (size, grade, and measured depth) 3-1/2",9.3~,N-80 EUE 8RD ~a 0' - 342'. 1593' 1592' 6501' 6477' O' - 6290' O' - 6270' 6290' 9898' 6270' - 9593' RECEiVt D' ORiG!NAL Alaska 011 2-7/8",6.5~,N-80 EUE 8RD(a342' - 8961'. Packers and SSSV (type and measured d~h)@ Guiberson Uni-packer 8887'. 0tis $55V @ 306' 13, Attachments Description summary of proposal Detailed operations program X BOP sketch 14. Estimated date for commencing operation 08/01/1999 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service Suspended __ 17. I hereby ~/~rtj~~d correct to the best of my knowledge. Signed _ _ .. Title 0ffice Hanager Date 07/12/1999 FOR COMMISSION USE ONLY IApprova, No.~ ~¢.../~ Conditions of approval: Notify Commission s.?.,,r, epresentative may witness Plug integrity BOP Test ~'~ Location clearance ~ Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY Robert N. Chdstenson Form 10-403 Rev 06/15/88 Commissioner Date SUBMIT IN TRIPLICATE ~ission ELEVATION: WELL DATA 'B: ~'---~-~D: 9900' (MD) PBTD: 9809' (MD) 'SURFACE CASING: . INTERMEDIATE CASING: PRODUCTION CASING: TUBING: 13 3/8" 61 # J55. Set (~ 1593'. 9 $/8" 40, 43.5# NS0, PI 10. Set @ 6501'. 7" 26,29# N80. Set at PERFORATIONS: GR-GS 8578-8664' HC-HD 9043-9067' 2 1/8" Gun HC-HD 9076-9120' 2 1/8" (Jun HE-HF 9203-9217' 2 1/8" Gun HI-HK 9323-9365' 2 1/8" Gun HI-HK 9394-9445' 2 1/8" Gun HI-HK 9464-9544' 2 1/8" Gun I~-HR 9569-9590' 2 1/8" Gun HN-HR 9640-96/0' 2 l/g" Gun OBJECTIVE: Remove scale and paraffin buildup using Coiled Tubing 1. One week prior to RU CT, tag btm w/SL. Note all tight spots. 2. . MIRU Dowell CTU and pump. Test lines to 5000#. TIH w/jetting tool to junked pkr ~ 8777' Wash through pkr using 1000 gal of 15% HCI and continue in hole to PBTD ~ ~,9809'. Work CT across peffs. Cix¢ well clean using FIW. Displace xylene to EOT. Close surface valves. Spot xylene across peffs from 9043' to 9670'. Displace 2000 gal ofxylene into peffs. POOH w/CT. RD Dowell CT. Allow to soak 4 hrs. GL well back. Obtain samples of all fluids for Dowell to analyze for live acid. Cross Timber~_~erating Company ~-~' PAGE btr: §/11/99 05 P MGS AI3.12RD Cook Inlet, Alaska Leg X, Conductor x APl No.: Spud: Conductor Csg: 24". Set ~} 370'. Cmt'd wi Surf Csg: 13 3/8', 61 It), J55. Set @ 1,593'. cmr¢l wi Surf Csg: 9 $18", 40~ & 43.5# NB0 & P-110. Set @ 6,501'. Cml;'d w/ Prod Csg: 7", 26-29~ NB(}. Set ~ 9,898' MD. (26~ NB0, 0-6290'(2lN1 NB0, 6290'-9,BgB') Cmrd w/ PBTD: 9,80g' (MD) Ti:): 9,900' (MD) ~esent Completion -- GL: KB: Tubing:2 7/a" 6.~ N80,1.80 ,R EUE GLM MI:) 'rvD Port Pso I i 968' 1 Os?' t 2 9S0 2 3590' 3588' 12 910 3 4842' 4839' 12 874 4 5783' 5777' 16 865 5 6572' 6.542' 16 830 6 7238' 7135' 16 803 7 7874' 7693' 16 776 5 6356' 8't 19' 114 Orifice Ptro 95o 93O 910 960 940 92O 9OO 882 86O 837 813 790 767 744 Otis "X" NIl:~le @ 8.398' (2.313" ID). lit. 2-7/8" 6.5~ Ne0 EUE 8rd tbg. Baker "HB" Packer ~ 8437' w140.000~ shear lit. 2-7/8" 6.5~ NB0 EUE 8rd tbg. Otis "XN" Profile Nipple ~ 8474' (2.205" ID) Bal(er 8ell Re-Entry, Guide ~8.476. GR-GS: 8,578'-8,664' MD 4 its. 2-?J8" the F~h ('roi= ~ e7773 Guibersen UNI-VI! Packer ~ 8887' O[i$ "X" NiPl0le ~ 8928' EOT ~ 8981' HC-HD: 9043'-9067', 9076'-9120' ND-HE: HE-HF: 9203'-9217' HI-HK: 9323'-9365' HK-HN: 9394'-9445', 9448'-9463', 9464'-9544' HN-HR: 9560'-9590', 9640'-9670', 9690'-9710' HR-HZ: April 22, 1994 Shell Western E&P Inc, 601 West Fifth Avenue * Suite 800 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' SUBMITTAL OF WELL COMPLETION REPORT (FORM 10-407) for MIDDLE GROUND SHOAL A13-12RD REFERENCE: APPROVAL NUMBERS 94-046 Enclosed are duplicate copies of the Well Completion Report (Form 10-407) for perforating additional pay in the "F" Pool in Middle Ground Shoal A13-12RD. Rig Operations were completed 3/13/94, perforation operations were completed 3/31/94, the date of first production was 4/01/94, and the representative well test date was 4/07/94. If you have any questions or wish to discuss, please call Paul Huckabee at (907) 263-9646. Sincerely, Paul Huckabee Staff Production Engineer ~---~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well ClaSSification of Service Well OIL ~:~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ':'~C~ '~ 2. Name of Operator ¥.;J_z~.r~,_~, 7. Permit Number Shell Western _E&P Inc. ~ 73-35/9~-046 3. Address 8. AP~ Number 601 W. 5th Ave., Suite 920 Anchorage, AK 99501 50-733-20191-01 4. Location of well at surface Platform A,Leg 4, Conductor 29,1561'N 9. Unit or kease Name and 381'W of SE Corner of Sec. 11, T8N,R13W, SM Middle Ground Shoal At Top Producing lnterval 9043' (M.D.) ,1288'N and 646'E of the SE 10. WelINumber Corner of Sec. 11, T8N,R13W,SM A13-12RD At Total Depth 9900' (M.D.),1209'N and 707'E of the SE 11.FieldandPool Corner of Sec. 11, T8N,R13W, SM , 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease Designation and Serial No. MGS "F" & "G" POO 1 s 116' DFIADL 18754 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 5/04/74 5/31/74 6/11/74 80 feetMSLI Single ~ 7. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where sSsv set 21. Thickness of Permafrost 9900 + 9596 9809 + 9504 YES[~ NO[-]I '328feetMD N/A 22. Type Electric or Other Logs Run Schlumberger DIL, SP-CAL BHC, GR-CBL .... 23. CASING, LINER AND CEMENTING RECORD .... SETTING DEPTH MD CASING SIZEIWT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 61 J-55 0' 1593' 17.5" 1300 Sx NoNe 9-5/8" 40-47 N80/Pll ) 0' 8751' 12.25" 700 Sx None 7" 26 N-80 0 ' 6290 ' None 7" 29 6290' 9898' 8.5" 1750 Sx 24. Perforations 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" 8476 ' 8437 ' See attached Perforation Summary 2-7/8" 8777 '-8961' 8887' Junk. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRQDUCTION TEST ..... Date First Production I Method of Operation (Flowing, gas lift, etc.) 4/01/94I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF wATER-BBL CHOKESIZE IGAs-OILRATIO 4/07/94 12 TEST PERIOD ~ 139 92 109 128I 662 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 90 835 24-HOUR RATE ~ 278 184 218 34. 7 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED ,,~.~ska ui~ & Gas Cons. Commis', Anchorage oil Form 10407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate - , 29. 30. GEOLOGIC MARKC~,.,,,: ~m"~RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. See attached Marker Summary -- 31. LIST OF ATTACHMENTS Perforation Summary, Geologic Marker Summary, Daily Reports of Operations 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 log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool I ~.: .,. ,~. ~ ...... .... Item 27' Method of Operation: Flowing, Gas Lift, 'ROd Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 MIDDLE GROUND SHOAL A13-12RD PERFORAT ION SUMMARY ZONE MD TVD GR-GS 8578' - 8664' 8317 - 8394' HC-HD 9043' - 9067' 9076' - 9120' 8748 - 8771' 8780 - 8823' HE-HF 9203' - 9217' 8904 - 8918' HI-HK HK-HN HN-HR 9323' - 9365' 9394' - 9445' 9448' - 9463' 9464' - 9544' 9560' - 9590' 9640' - 9670' 9690' - 9710' 9022 - 9063' 9092 - 9143' 9146 - 9161' 9162 - 9241' 9257 - 9287' 9337 - 9367' 9387 - 9407' Gas Cons. Commission A~chorage : : : OPERATOR: SNEPl SECT/THP/RANGE: GEOLOGIST: 8. N. COXE UPDATED: AUG 21 1993: : FIELD: IIIDDLE GROUND SHOAL AP! NUHBER: DATA ENTRIES BY: : NELL: A 13- 12RD DATA TYPE: TD. : : UNIQUE NELL ID--) <--C1 SEOUENT1AL NUMBER NELL APl NO: : ........................ iNPUT DATA ................................ : ...................... OUTPUT DATA ....................... : :---DEPTHS OF iNTEREST ....... : RES: DIP: D]P: 'OBSERVED' :AVG:AVG:IlUD : ' :HOLE:NELL:CORRECT. : 'CORRECTED": COORDINATES: flEAS.: MARKER : · ERV: A~IG: AZM:' LOG PAYS' · POR: SN: NT ' SUBSEAi CLOS-: ANGL: AZM. · FACTORS: TV: TV: TV: FROM SURF. : DEPTH: NAHE 6543: FP 6580: FS 7007: FN 7151: FZ 7248: GB 7515: GO ?956: GN 7976: GNH]D ?996: GO 8576: GR 8627: GRill D 8678: GS 9043: HC 9081: HCHID 9119: HD 9203: HE 92'21: HEM]D : 9240: HF · 9289: MID PERFi 9323: Hi : 935?: H[HID : 9392: HI( : 9473: HKMID · 9535:B PROD !: 9554: HN : 9636: HNMID : 9719: HR : 9719: HRHID : 9900: TD : : COMIIENTS :OIR:OEG:DEG:GAS:OIL: SD: 3:: 1: :LB/G:DEPTH : URE: · . : - : : : : - : : - . · NELL: A13- 12RD: : · : - - : 3: 3[ # 116 O' : : : : : : : : 1: ~[ # -6398 174 : : : : : : : : Z 1: # -6945 293 : : : : : : : : 3[ 3: # -7028 328 : : 28: I07: O: 32: 32: 133[ 243[ #-7649 622 : : :2R: 107: O: 32: 32: 131: 241[ #-7666 631 · · : · · : : · 1: I[ # -7684 640 · : :29: ilO: O: 64: 64: 123[ 311~ #-8199 900 : : : 29: 110: O: 64: 64: 123[ 311: # -8245 922 : : : · : : : : 3[ I~ # -8291 944 :PHI TOO HIGH : 31: 105: O: 62: 62: !03C 251~ # -8632 1066 :ARB. REOUC. : :31: 105: O: 62: 62: 101[ 251[ #-8669 1075 : : : : : : : : 1: I~ # -8706 : :33: 105: O: 32: 32: 7~ 48:[ #-8788 : :33: 105: O: 32: 32: 71: 481: #-8805 : : : : : : : ~ 1[ # -8873 : :34: 107: O: 44: 44: 5.53[ 58~ # -8906 : :34: 107: O: 44: 44: 5.5~ 58:[ # -8940 : : 34: 107: O: 136: 136: 63C 541~ # -8974 : :34: 107: O: 136: 136: 63[ 54~ # -9055 : : : : : : : 'X 1[ # -9116 : : : : 0:134:134: ?.1~ 54~ # -9135 : : : .' O: 134: 134: 7. It 54~ # -9217 : :32: 103: O: 49: 49:8.7~ 44~ # -9300 : : 3?: 103: O: 49: 49: 8. 71: 44X # -9300 : : : : : : : 1: ~ # -9479 DEG.: DEG.: TSC: TVC:GAS: OIL: SO: E/-N: N/-S: 0.0 18.8 2O. 6 28.4 3O. 3 31.0 27.8 28.3 28. 3 28.4 26.4 26, I 25.8 15.2 14.1 0 1.00 1.00 0 O: 74 O. 71 O. 83 26 171: 80 0.'~40. 80 39 174: 117 0.60 0.66 212 134: !19 0.51 0.63 215 101: 120 O. 56 O. 62 318 77: 123 O. 59 O. 66 434 8: 17 0.56 0.63 0 20 20 616 -87: 17 0.56 O. 63 0 20 20 624 -92: 17 O. 56 O. 63 633 -96: 14 0.57 0.65 0 42 42 878 -198: 15 0.57 0.65 0 42 42 899 -207: 15 0.57 0.66 919 -217: 128 0.10 0,82 0 51 51 1028 -280: 130 0.72 0.84 0 52 52 1037 -286: 1083 13.4 131 0.72 0.84 1043 -292: 1100 ll.g 135 0.72 0.86 0 28 28 1057 -305: 1103 11.6 136 0.~3 0.8~ 0 28 28 1059 -301: 1106 I!.1 138 0.13 0.81 1061 -310: 1112 9. g 143 0.14 0.89 1066 -316: 1116 g.o 147 0.75 0.91 0 40 40 1069 -320: 1120 8.2 151 0.76 0.92 0 40 40 1012 -324: 1124 1.3 154 0.11 0.93 0 121 121 1015 -329: 1130 5.8 114 0.80 0.91 0 132 132 1018 -331: 1132 4.8 194 0.83 o. gg 1079 -343: 1133 4.5 200 0.84 1.00 0 134 134 1079 -344: 1129 5.0 225 0.86 1.02 0 137 137 1074 ~348: 1125 5.6 251 0.89 1.05 0 51 51 1069 -352: !125 5.6 251 0.89 1.05 0 51 51 1069 -352: 1106 9.5 280 0.92 1.09 1048 -352: : A13-12RD: KB : Al3-12RD: FP : AI3-12RO: FS : A13-12RD: FN : A13-12RO: FZ : Al3-12RD: GB : AI3-12RD: GD : Al3-12RD: GN : AI3-12RD: GNM] : Al3-12RD: GO : Al3-12RD: GR : AI3-12RD: GRMI : Al3-12RD: GS : Al3-12RD: HC : A13-12R0: HCIll : Al3-12RD: NO : A13-12RD: HE : AI3-12RO: HEMI : Al3-12RD: HE : A13-12RD: HID : Al3-12RD: HI : Al3-12RD: : A13-12RD: HK : A13-12RD: HKM] : AI3-12RD: B PR : Al3-12RD: HN : AI3-12RD: HNHI : A 13- I2RO: HR : A13-12RD: HRMI : Al3-12RD: TD OPERATOR: SNEPl SEARCHNELLDEPTHS : FIELD: MIDOLE GROUND SHOAL : NELL: Al3-12RD : : : ABBRV. : TRUE : INTERPOL' D: : 2-NAY: SHORT :IlARK: GRID COORDINATES: STRAT: .... : ..... :3D SEISNIC: TIME : NELL :-ER : ................. :THICK:DIP : DIP : GRID :MILLI: NAME :NAME: X-COORO: Y-COORD: DEPTH: ANG.: AZM.: TRACK: BIN :SEC.: : -381 -355 -342 -169 - 106 -63 53 235 243 252 497 518 538 641 656 662 676 618 680 685 688 691 694 691 698 698 693 688 688 661 6841 0 0.0 107.0 0 0 O: 7012 6342 23.0 107.0 0 0 O: 7015 6370 23.2 107.0 0 0 O: 6975 6651 24.7 107.0 0 0 O: 6942 6735 25.2 101.0 0 0 O: 6918 6790 25.5 107.0 0 0 O: 6849 6940 26.4 !07.0 0 0 O: 6754 7194 28.0 107.0 0 0 O: 6749 7205 28.0 I01.0 0 0 O: 6145 7216 28.0 107.1 0 0 O: 6643 7542 29.0 110.0 0 0 O: 6634 7571 29.0 110.0 0 0 O: 6624 1601 29.2 109.4 0 0 O: 6561 ~834 31.0 105.0 0 0 O: 6555 7861 31.0 105.0 0 0 O: 6549 1888 31.6 I05.0 0 0 O: 6536 ~949 33.0 105.0 0 0 O: 6534 7962 33.0 105.0 0 0 O: 6531 ?976 33.2 I05.4 0 0 O: 6525 8013 33.7 106.3 0 0 O: 6521 8039 34.0 107.0 0 0 O: 6517 8065 34.0 101.0 0 0 O: 6512 8091 34.0 107.0 0 0 O: 6504 8155 34.0 107.0 0 0 O: 6498 8205 33. 5 106.0 0 0 O: 6491 8221 33.3 105.7 0 0 O: 6493 8292 32.7 104.3 0 0 O: 6489 8363 32.0 103.0 0 0 O: 6489 8363 32.0 103.0 0 0 O: 6489 8526 32.0 103.0 0 0 O: : : : OPERATOR: SWEPl SECT/TWP/RANGE: GEOLOGIST: 8. H. COXE UPDATED: AUG 27 1993 : : FIELD: MIDDLE GROUND SHOAL APl NUMBER: DATA ENIR]ES BY: :, · WELL: A13-12RD DATA TYPE: TO. : UNIQUE WELL ID--) <--C1 SEQUENTIAL NUMBER WELL APl NO: : : SURVEY DATA INPUT: .............................. INPUT VALUES FOR FIRST LINE ONLY: : ................................ : ................... TRUE COORDINATES: '* ................................... EVEN i iCOORDINATESi i :MEAS:HOLE : WELL :K.B.:VERT.:SUBSEA: FROM SURF.:CLOS-: GRID COORDINATES :FIELD : WELL :SUBSEA: MEAS.:FROM SURF· :CLOS-: DEPTH: ANGLE: AZMUTH: · . olo. ooi o.o: 380: 1.75: 133. O: 505: 4.25: 138. O: 603: 3.00: 126. O: 915: 1.00: 91.0: 1259: 1.75: 52.0: 1593: !. 50: 25. O: lg!7: 1.75: 299.0: 2198: I. 00: 280. O: 2508: 2.00: 267.0: 2732: 3.00: 285.0: 3037: 1.75: 283.0: 3234: 2.25: 281.0: 3534: 1.00: 305. O: 3629: I. 25: 298.0: 3939: 2.00: 251.0: 4470: 3.00: 266. O: 4727: 3.00: 274.0: 5035: 2.75: 283.0: 5194: 3.00: 288.0: "5403: 3.50: 280. O: 5517: 4.75: 335.0: 5572: 6.25: 338.0: 5690: 7.75: 14.0: 5721: 8.50: 16.0: 5839: !1.75: 24. O: 5902: 12.00: 29. O: 5960: 12.00: 32. O; 5992: 12.25: 35. O: 6026: 13.00: 36. O: 6160: 14.25: 43, O: 6203: 15.00: 48. O: 6235: 14.75: 51. O: 6262: 14.75: 50. O: 6294: 14.75: 52, O: 6325: 14.00: 57. O: 6357: 14.00: 57. O: .6483: 16.00: 65.0: 6506: 16. 00: 65. O: 6526:18, 00: 71. O: 6618: 22.50: 86. O: 6711:25,00: 98.0: 5774: 25.50: 98. O: 6829: 25.00: 104.0: 6900: 26.50: 115. O: 6931:27.00: 115. O: 6962: 27.50: 116.0: 7057: 29.50: 118. O: 7169: 30.50: 119, O: 7289: 31.25: 120.0: ELEV:DEPTH: DEPIH: E/-W: N/-S: URE : X-COORD : Y-COORD : : · . : · . : 116: O; 116' 0 O; o; -381 6841: 116: 380: -264 4 -4: 6: -377 6837: 116: 505: -389 9 -9: 12: -372 6832 : 116: 603: -487 13 -13: 18: -368 6828 : 116: 914: -798 23 - 18: 29: -358 6823 : 116: 1258: -II4~ 30 -15: 33: -351 6826 : 116: 1592: -1476 36 -7: 36: -345 6834 : 116: 1916:-1800 33 -1: 33: -348 6840 : 116: 2197:-2081 27 1: 27: -354 6842 : 116: 2507: -2391 19 1: 19: -362 6842 : i16: 2731: -2615 9 3: !0: -372 6844 : 116: 3035:-2919 -3 6: 7: -384 6847 : 116: 3232: -3116 -10 7: 12: -391 6848 : 116: 3532: -3416 -18 10: 20: -399 6851 : 116: 3627:-3511 -19 11: 22: -400 6852 : 16: 3937:-3821 -27 11: 29: -408 6852 : IG: 4467: -4351 -50 7: 50: -431 6848 : 16: 4?24:-4608 -63 ?: 64: -444 6848 : 16: 5033:-4917 -79 9: 79: -460 6850 : 16: 5191:-5075 -86 11: 87: -467 6852 : 16: 5399: -5283 -98 14: gg: -479 6855 : 16: 5513:-5397 -103 19: 105: -484 6860 : 16: 5568:-5452 -I05 24: 108: -486 6865 : 16: 5685: -55(:q -106 31: 112: -481 6878 : 16: 5716:-5600 -105 42: 113: -486 6883 : 16: 5832:-5715 -97 61: 115: -478 6902 : 16: 5893:-5177 -92 12: 111: -413 6913 : 16: 5950:-5834 -85 83: 119: -466 6924 : 16: 5981:-5865 -82 88: 120: -463 6929': 16: 6015:-5899 -77 95: 122: -458 6936 : 16: 6145:-6029 -57 I19: 132: -438 6960 : 16: 6185: -607': -50 126: 136: -431 6967 : 16: 6217: -61Cl -43 132: 139: -424 6973 : 16: 6243: -512' -38 136: 141: -419 6977 : 16: 6274:-6158 -32 141: 145: -413 6982 : 16: 6304:-6188 -25 146: 148: -406 6987 : 16: 6335:-6219 -19 150: 151: -400 6991 : 16: 6457:-6341 I0 166: 166: -371 7007 : 16: 6479: -6363 15 168: 169: -366 7009 : 16: 6498:-6382 21 170: 172: -360 7011 : !16: 6585:-6469 52 176: 184: -329 7017 : 116: 6670:-65".1 89 175: 196: -292 7016 : 116: 6727:-6611 116 1Th 206: -255 7012 : 116: 6777: -6661 139 167: 217: -242 7008 : 116: 6841:-6725 167 156: 229: -214 6997 : 116: 6868:-6752 180 150: 235: -201 6991 : 116: 6896:-6780 193 144: 241: -188 6985 : 116: 6979:'-6863 233 124: 264: -148 6965 : 116: 7076:-6960 283 97: 299: -98 6938 : 116: 7179:-70F3 336 67: 343: -45 6908 : OPERATOR: SWEPI FIELD: MIDDLE GROUND SHOAL NELL: A13-12RD :TRUE :TRUE : :TRUE :VERT.:STRAT: MEASURED: VERT.: THICK: THICK: : : INCREM: DEPTH: E/-W: N/-S: URE : : DEPTH : DEPTH: DEPTH: DEPTH: : : : : : : : · .... : : : A13-12RD: : - 0 0 0 0 AI3-12RD: : : 380 380 380 380 AI3-12RO: : : 505 505 504 504 A13-12RD: : : 603 603 602 602 A13-12RD: : : 915 914 913 913 A13-12RO: : : 1259 1258 1257 1256 A13-12RD: : : 1593 1592 1590 1588 AI3-12RO: : : 1917 1916 1915 1910 A13-12RD: : : 2198 2197 2197 2190 AI3-12RD: : : 2508 2507 2508 2498 AI3-12RD: : : 2732 2731 2733 2720 AI3-12RD: : : 3037 3035 3040 3022 AI3-12RD: : : 3234 3232 3238 3217 AI3-12RD: : : 3534 3532 3540 3512 AI3-12RD: : : 3629 3627 3635 3605 AI3-12RO: : : 3939 3937 3947 3908 AI3-12RD: : : 4470 446? 4483 4426 A13-12RD: : : 4?2? 4?24 4?43 46?6 AI3-12RD: : : 5036 5033 5056 49?6 AI3-12RD: : : 5194 5191 5217 5128 AI3-12RD: : : 5403 5399 5429 5330 AI3-12RD: : : 5517 5513 5545 5439 A13-12RO: : : 5572 5568 5601 5492 A13-12RD: : : 5690 5685 5720 5604 AI3-12RO: : : 5721 5716 5751 5633 AI3-12RD: : : 5839 5832 5867 5741 A13-12RD: : : 5902 5893 592? 5?98 A13-12RD: : : 5960 5950 5983 5850 AI3-12RO: : : 5992 5981 6014 58?8 A13-12RD: : : 6026 6015 6046 5908 A13-12RD: : : 6160 6145 6171 6025 A13-12RD: : : 6203 6186 6211 6062 AI3-12RD: : : 6235 6217 6240 6089 AI3-12RD: : : 6262 6243 6265 6112 AI3-12RD: : : 6294 6214 6294 6139 A13-12RD: : : 6325 6304 6322 6165 A13-12RD: : : 6357 6335 6351 6192 A13-12RD: : : 6483 645? 6463 6295 A13-12RD: : : 6506 6479 6483 6314 AI3-12RO: : : 6526 6498 6500 6330 AI3-12RD: : : 6618 6585 65?5 6398 AI3-12RD: : : 6711 66?0 6644 6462 AI3-12RD: : : 6174 6127 6689 6503 A13-12RO: : : 6829 6777 6729 6539 A13-12RO: : : 6900 6841 6779 6585 A13-12RD: : : 6931 6868 6800 6605 AI3-12RD: : : 6962 6896 6822 6624 A13-I2RD: : : 7057 6979 6885 6681 AI3-12RO: : : 7169 7076 6956 6746 A13-12RD: : : 7289 7179 1030 6813 .RECEIVED Cons. Commission ~m:,h,or~oe .: SEARCHNELLSIIRVEYS TRUE: TRUE: INTERPOL' D: : 2-WAY: VERT: STRA: .... : ..... : 3D SEISMIC: TIME CORR:CORR:OIP : DIP : GRID :M]LLI: FACT: FACT:ANG: AZH.:TRACK: BIN :SEC. 1.00 1.00 0.0 O. 1.00 1.00 !.3 107. 1.00 0.99 1.8 107. 1.00 1.00 2. I 107. 1.00 1.00 3.2 107. 1.00 1.00 4.4 107. 1.00 0.99 5.6 107. 1.00 1.00 6.7 107. 1.00 0.99 7.7 107. 1.00 0.99 8.8 107. 1.01 O. 99 9.6 107. 1.01 0.99 10.7 107. 1.01 0.99 11.4 107, 1.00 0.98 12.4 107. 1.00 0.98 12.8 107. 1.01 0.98 13. g 107. 1.01 0.97 15.7 107. 1.01 0.97 16.6 107. I. 01 0.97 17.7 107. 1.02 0.96 18.3 107. 1,02 0.96 19.0 107. 1.02 0.96 19.4 107. 1.02 0.96 19.6 107, 0,99 0.93 20.0 107, O. 99 O. 93 20. 1 107. 0.97 0.91 20.5 107. 0.96 0.90 20.8 107. O. 96 O. 89 21.0 107. 0.95 0.89 21. 1 I07. 0.95 0.88 21.2 107. 0.93 0.86 21.7 107. 0.91 0.85 21.8 107. 0.91 0.84 21.9 107. 0.91 0.84 22.0 I07, 0.91 0.84 22.2 107. O. gl 0,84 22.3 107. 0.91 0.84 22.4 I07. 0.88 0,81 22.8 0.87 0.81 22.9 107. 0.85 0.78 23.0 107. 0,77 0.71 23,3 I07. 0,72 0.66 23.6 107. 0.71 0.65 23,8 107, 0.72 0.66 24.0 107, 0.?0 0.63 24.3 107. 0.69 0,63 24.4 107. 0.68 0.62 24.5 107. 0.65 0·59 24,8 107. 0.63 0.57 25,2 107. 0.61 0.55 25.7 107. 0 0 O' O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: ,. 0 0 0 O: / 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 . 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 _!0: ~' o o o 0 0 0 . 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 0 0 0 O: 73§7: 7524: 7596: 7656: 7719: 7767: 7887: 7954: 8017: 8070: 8127: 8210: 8350: 8481: 8561: 8687: 8795: 8881: 8914: 9O86: 9224: 9424: 9555: 9749: 9825: 9900: · 31. 27. 27. 27. 27. 27. :28. 28. 28. 27. 26. 27. 28. 27. 26. 25. 22. lg. 75: 122. O: 17.00: 124. O: 14.00: 130.0: !1.50: 136.0: 6. 50: 158. O: 4.50: 200. O: 5.75: 260. o: 6. 75: 276. O: 9.50: · 280. o: 25: 20.0: 116: 7272: -715~ 50: 23.0: 116: 7382: -726'; 75: 25.0: 116: 7446: -732') 75: 18.0: 116: 7499: -738J 50: t3.0: 116: 7555: -743fl 75: 15.0: 116: 7598: -748:? 00: 16.0: 116: 7704: -758q 25: 17.0: 116: 7763:-7647 50: 117.0: !!6: 7818:-7702 50: 112.0: 116: 7865:-7749 50: I10. O: 116:7916: -78e.') 00: 110.0: 116: 7990:°7874 00: !12.0: 116: 8114:-7998 25: 115..0: 116: 8230:--811'1 50: 114.0: 116: 8302:-8186 75: 115.0: 116: 8415:-8299 50: 118.0: 116: 8513:-8397 16: 8594:-8478 16: 8682:-8565 16: 8790:-8674 16: 8924:-8808 16: 9122:-9006 16: 9252:-9136 16: 9446:-9330 16: 9521:-9405 16: 9595: -947q 385 438 465 489 516 536 586 615 641 664 688 723 784 839 872 923 962 989 1014 I038 1060 1078 I079 1067 1059 1048 39: 387: 6: 438: -13: 466: -27: 490: -40: 517: -49: 538: -73: 591: -87: 62 I: -101: 649: -111: 673: - 120: 699: -133: 735: - 156: 799: -180: 858: - I95: 894: -218: 948: -238: ggl: -253:102 h -269: !049: -287: 1077: -308: 1104: -333: 1128: -344: 1133: -353: !124: -353: 1116: -352: 1106: 4 57 84 108 135 155 205 234 260 283 307 342 403 458 491 542 581 608 633 657 679 697 698 686 678 667 6880 : 6847 : 6828 : 6814 : 6801 : 6792 : 6768 : 6754 : 6740 : 6730 : 6721 : 6708 : 6685: 6661 : 6646 : 6623 : 6603 : 6588: 6572 : 6554 : 6533 : 6508: 649?: 6488: 6488: 6489: A13-12RO: 13-12RD: 13- 12RD: Al3- 12RO: Al3- I2RO: A13-12RO: 13-12RO: AI3-12RD: AI3-12RO: 13- r2RD: AI3-12RD: 13-12RD: Al3- 12RD: 13-12RD: 13-12RD: A13-12RD: AI3-12RD: 13-12RD: Al3-12RO: Al3-12RD: a13-12R0: AI3-12RD: AI3-12RO: AI3-12RO: AI3-12RD: 13-12RD: 7397 7272 7096 6872 0.61 0.55 26.0 107.0 0 0 O: 7524 7382 7177 6945 0.67 0.60 26.5 107.0 0 0 O: 7596 7446 7225 6987 0.66 0.59 26.7 107.0 0 0 O: 7656 7499 7264 7023 0.65 0.58 26.9 107.0 0 0 O: 7719 7555 7305 7059 0.65 0.58 27.2 107.0 0 0 O: 7767 7598 7337 7087 0.65 0.57 27.3 107.0 0 0 O: 7887 7704 7414 7155 0.64 0.57 27.8 107.0 0 0 O: 7954 7763 7456 7193 0.63 0.56 28.0 107.0 0 0 O: 8017 7818 7496 7228 0.63 0.55 28.1 107.2 0 0 O: 8070 7865 7530 7258 0.64 0.56 28.2 107.5 0 0 O: 8127 7916 7567 7290 0.66 0.58 28.3 107.8 0 0 O: 8210 7990 7621 7338 0.65 0.57 28.4 108.2 0 0 O: 8350 8114 7710 7416 0.63 0.55 28.6 108.9 0 0 O: 8481 8230 7793 7489 0.64 0.56 28.8 109.5 0 0 O: 8561 8302 7844 7534 0.65 0.57 29.0 109.9 0 0 O: 8587 8415 7926 7606 0.66 0.57 29.3 I09.3 0 0 O: 8795 8513 8000 7670 0.71 0.61 29.8 108.0 0 0 O: 8881 8594 8063 7724 0.75 0.65 30.2 106.9 0 0 O: 8974 8682 8135 ~786 0.79 0.68 30.~ 105.8 0 0 O: 9086 8790 8226 7864 0.84 0.72 31.1 105.0 0 0 O: 9224 8924 8344 7964 0.87 0.73 33.0 105.1 0 0 O: 9424 g122 8525 8115 0.95 0.78 34.0 107.0 0 0 O: 9555 9252 8653 8221 1.00 0.84 33.3 105.7 0 0 O: 9749 9446 8852 8389 1.05 0.89 32.0 103.0 0 0 O: 9825 9521 8932 8457 1.07 0.90 32.0 103.0 0 0 O: ggo0 9595 9013 8526 1.09 0.92 32.0 103.0 0 0 O: PLATF~: A ~LL: Al~12RD ~-~r-~ F~E~N: R.H. $ELTZ w ~TH: S ~ DAILY:SlZ,030.0O C~LAT ZVE: $3~, 7ZO ' DAI Y~: .... O TR! YTD: .... 1 DAYS & DAYS ESTI~TED: ~ OF SKID~RIG ~R TO A1~-1~ - RIG ~ - ,iX Z5 8~ S$1i CHIS S~VU~R) * R/U ~IKS IN ~ TO BL~ OM TeG & ~KLUS - R/U LINES ~i TK - ~N Tea ~ TO BLEO P~E & ~ZT~ TK ~E~RE TO ~E IF TIG iS P~TEO (~ ~I~Ti~) - OLEEO PRE~E 10P~I CFL~IKOIL ~ TK& AKa) - P~ 1~ 88L FtV ST~ TO ~T Fig RE~NS AT A~R~ ~ 69LS (TBG PARTED ~ 32~') * g~ ~0 S~T ~LL IN ~ TO HiGH A~ AT ~ DECK TANK - ~E~E BUILT * TO ~O ~i iN A~ ~5 giN. - ~N TBG ~0 FL~ ~LL TO HE~B ~TtLL w ST~W~ ~ L~iNG ~T AT 0300 * AOOZTIQNAI. C~IISENT$; DRILLS, VISITORS, ZKI)ECTQRS ETC... e '~RT OF DAILY ' H..P~, ~ ~TTiNG ~.OO ~.OO * L..OT~R 3ERVICE (~ E~GI ~.OO ' T~AL C~T~ ~I~S S10,71~.OO ~K STRING RENTAL ~.~ ' ; T~S, SLIPS, ELEV RENTAL ~.~ * T~N~T~TI~t FI~O C~T ~.~ SKCIAL T~LS ETC RENTAL ~.~ * T~T~I~: ~L OTHER ~.~ OTg tOTALS ~.~ * TOT~ TN~AT]~ ~T ~.~ T~ RENTALS ~.~ Fliz \123%A13-12~I~tPT * i DALLY REPOT * * t ' PLATFGRN: Ai I~LL: Al:3-12RD 08-gar-B& FORENAN: R.H. S~LTZ TOTRL P. 01 Id~-bW-l~-~4 k~: l~q {-~L~q bhel I Hlatform H IU * PLATF~t I ~LL: A13-1~ ~-Nar-~ F~E~N: R.H. ~LTZ * Oll YTO: .... 0 Tl~ TTO: .... 1 DAYS g DAYS ESTI~T~: * ~NT$: NO~IOENT$ RE~TED FLUID TYPE: P~TI~ ~IGHT: * SPILLS: ~ ~PILL$ ~T~ RT TO TBG HAIR: TOF: * T]~ ~ ~Y OF ~RATi~S: * 2&.fl0 NRS - FL~ ~LL TO PR~. HE~R/~ ~ ~-Ot~ T~[ - FL~ TO * P~ 19 ~L Fig D~ TBG - R~ FIg LINE - R~ SLIMLINE UNIT TO INSTALL ' $S8~- TEST L~I~T~ TO 1500 ~I - INSTALL Jl GLH VAL~ - $~T ~ * TEST: SS~ TO 5~ PSI - R/D SLICKLINE & L~RI~TOR - R/D LA~IflG JT ' l~ Fig LINE - ~ 20 ~C Fig DM TBG - CLffi SS~ & SET 6PV - H~D * ~FE~Y'~ETING I DIS~SS N/D I N/U - STRIP TREE OF FL~ LINE & I~TR~NTA* " LINES - ~LL TREE - SET RISER · N/U ~S - RIGGING UP TO TEST ' RE~T ll~ * ~LLi C~TI~LLY FL~IK OIL/~S ~ ~ TO ON-DE~ TANK EST~ILISN A ~TE/~ * ~ITI~AL ~~1 DRZLLS, VlSlT~S, INSECT. S ETC... * "ffiT OF DALLY ~T" * ~Pl ~R~S~ I ~: S~O.O0 * Cffil~CT ~RVI~S: ~TERIALS: * A..~T~C~ ~ · ~ S9,9~.00 A..~PI P~SEO RIG * B..~TERI~ S~0.00 B..~K~R FLUIDS & ~DIT ' C..FISNING~ ~.~ C..PACKERS ~.OO * O..C~mllflG. ~.00 D..~IO~ PLUS, RETAINERS ~.~ ' E..STI~[I~, ~HER ~ ~.00 E..TUBING, ~, ~LINGS ~.~ * F..P~T~ EWIP ~RVIC ~.~ F..~S LIFT ~ELS G ' G..~R~I~ ~.~ G..X- I X, NZ~LES ~.~ * I..L~GI~ ~R ELE~RIC ~.~ I..~, K~Y, C~ * J..SLIC/Li~, ~iO~ LI~ SO.~ L..OTHER ~TERIALS PL~ FU ~.00 * K..~LLH~ ~RVI~ ~.~ TOTAL ~TERIALS * TOT~ ~TKT: ~RVI~S S12,~.~ ~g STRING ~NTAL ~.00 * T~S, SLI~, EL~ RENTAL ~.00 * T~N~TATI~: FIX~ ~T ~.00 S~CIAL T~S ETC REMT~ ~.00 ' T~ T~TATi~ ~T ~.~ TOT~ RENT,S ~.~ FN: ~1~13-12~ raPT * DALLY R~T * P~T~: A ~LL: A15-T~ ~-Nar-~ F~E~: R.K. ~LTZ ECEIVED ~:~ 2 5 1994 Gas Cons. Commission Anchorage TOTAl_ P.01 DA! YTD: .... 0 TRZ YTD: .... ;C(]NIIENTS: NO ACCIOENTS REIPC~TLrD DAYS & DAYS ESTDqATED: FLUID TYPE: PRODUCT SON 3 OF * WEIGHT: 8.6* * SPILLS: NO SPILLS REPCNtTEO RT TO TBG HANGER: TOF: ' TINE AiM) SUNIIART OF OPERATIO#S: *Z&.O0 I~S - TEST'lOPS - TEST NTDRZL TO zSO/3SooPsl - TEST RAINS & ASSOCIATED EQUIP TO * ZSO/SQE)O PSi - FtJIICTICN( TEST ACCtJAJLATO~ - R/U SLXCKLINE UNIT & LUBRICATOR* * RIN & PULL SSSV - RiG I)M - CIRC 20 8SL FIV DM TBG (GAS & O~L IN TBG) ' PULL TIG NAliGER C10,000 biT) - TBG UA5 PAJ~TED - HONITC~ ~LL - POOH & STD * TIG JN DERRICK ' 14~ FISHING TOOL ON 3 l/Z" DP - NIH - TAG FISH E 3Z06' * K/U TOP DRIVE - FILL PiPE - Id~lC MR FISH - PiC~ UP Oil TBG TO RELEASE * PACKER (TBG PARTED AT 90,000) - CIRC C2) VOLUI~S - POOH - RECOVERED 3' * 14/U OVERSHOT & Ti# - UOPJC OVeR FISH (WELL STARTED TO FLGU UP DRILL PIPE * ~CREV iN TOP DRIVE) - UI~tC PiPE IN ATTENPT TO RELEASE PACKER (NO LUCK) * ATTEIIr/ TO RELEAS~ OVERSHOT SO b/E COULD CIAO, UNILE ROTATING TO RELEASE * P~T & HAl) EXCESS DRAG & blT. C30,000) - CZRC ¢2) VOLUNES - POOD b// FISH NOTE; t/ELL FLOUING APPROX. & - 5 BBLIIIR ADOITIO#AL CONHENTS; DRILLS, VISITORS, I#S4~OKS ETC... 2 5 1994 &,Gas CoDs. Anchorage ~SLIIMRY OF DALLY CC)ST" * SI~PI SUPERVISION & LAG: S750.00 ' CONTRACT SEIrVICES: HATER [ALS: * A..CONTRACT ~ * RS&D S9,96&.00 A. oSt~P! PURC~ RIG SUP SS.OD * B..CATERING S75D.00 B..WORKOVER FLU*DS & ADDIT SO.O0 * C.. F[SNING SO.O0 C..PACKERS SO.O0 D..CEIENTING $0.00 D..BRII)G~ PLUGS, RETAINERS S0.00 * E..STINULATION, OTHER PURP SO.O0 E..TLIBtNG, PUPS, F..PRODUCT]ON EQUIP SERVIC SS.O0 F..GAS LIFT HANORELS & VAL SS.O0 t G..PERFORATIIIG SO.O0 G..X- & XN NIPPLES SS.O0 #..PACKER, PLUG SETTING SO.O0 H..UELLHEAD EQLi]PHENT SS.QO * Z..LOGGZNG, OTHER ELECTRIC SO.O0 I..BOP, KOONT, CH~E PARTS S108.00 if J..SLIClCLINE, BRAIDED LINE SS.D0 L..OTHER IqATERIALS PLUS FU S18.00 w K..klELLH~J~:) ~RVICE $0.00 TOTAL MATERIALS S126.00 L..OTHER SEtVICE (HUD ENGI SI,650.00 * TOTAL CONTRACT SERVICES $12,364.00 blORC STRING RENTAL SO.OQ * TOOLS, SLIPS, ELE¥ RENTAL SO.O0 TRANSPORTATION: FIXED COST SS.O0 SPECIAL TOOLS ITC RENTAL SS.O0 TRANSPORTATION: ALL OTKR SS.O0 OTHER RENTALS SO.O0 TOTAL TBAIIgK)RTATiOll COST SO.O0 TOTAL RENTALS SO.O0 * *- D~LY REPOT * ' P~TFORM:A ~A13-12RD 11-Mar-94: FOREM~: R.H. SEL~ · , *a ~: ~l ENGIne: P. T. H~~~ *i A~: $21~;,~ DNLY: $16,315.~ CUMU~TI~: $76,293 *a DN ~D: .... 0 ~1 ~D: .... 1 DAYS & DAYS E~I~D: 4 OF 5 ' COM~NT$: NO ACCIDENTS REPUTED FLUID ~: ~ODUC~ON ~1~: * SPI~: N~ SPI~ REPOR~D RT TO ~G ~~R: [OF: *- TI~ ~D ~M~Y OF OPERA~ONS: ~ :a24'~ HRS - ~ FISHING TOOLS - R~ ~D UD 2 7/8' ~G ~ITH 1~' mG ~ ~N ,~ H~ ~L ST~D TO ~OW O~R ~G, ST~ VALVE & CIRC ~O~D) - ~1~ ~ ~ - NO~; DID NOT R~IE~ PACER, ~G P~D ~ ~PROX 6763 - '~ H~ PAC~ & ~OX 4 JTS ~G - C~ ~ RIG FL~ - R~ ~G TOOLS - " BIT & ~ ~~R - ~~ IN HO~ - TAG TOfF FISH ~ 8~ - PUMP ~VIS *. C RC ~ NO~; ~I~G IS IN B~ S~ - ~PE~S IT MAY HA~ BE~ IN CONTACT ~TH ACID - * ' BECA~ OF ~E WIREUNE T~LS ~D D~RIS ON TOP OF THE PACER & THE *a C~D~ON OF ~ (4) JTS OF ~G ON TOP OF T~ PACER, ~E DECIS~N WAS - * ~ NO~; ~ FLO~ ~PROX. 4 - 5 BB~HR 'e ~ ~ ~it & Gns Cons Anchorage *. ~DI~ON~ COM~S; DRI~S, ~$1T~S, IN~~ORS ETC... "_.. ' 'SUMMARY I "._ SWEPI SUPERVISION & LABOR: $1,101.00 -~. CONTRACT SL=RVlCES: * A..CONTRA~ CREW + RS&D *' C..FiSHiNGi * ~ E..STIMUI. ATtON, OTHER PUMPING' *~, F..~ODUC~0N EOUIP SERWCES ' *~ G..PERFORATING H,.PACKER~ PLUG SETTING I..LOGGING~ OTHER ELECTRIC UNE J..$UCKLINE, BRAIDED UNE L.OTHER SERVICE (MUD ENGINEER) TOTAL. CON'I PACT SERVICES OF DAILY COST' MATERIALS: $9,964,00 A..SWEPI PURCHASED RIG SUPPUES $0.00 $750.00 B..WORKOVER FLUIDS & ADDITIVES $0.00 $4,500.00 C..PACKERS $0.00 S0.IX) D..BRIDGE PLUGS, RETAINERS, EZSV $0.00 $9.00 E..'I'UBING, PUPS, COUPLINGS, X-O' $0.00 SO.00 F..GAS UFT MANDRELS & VALVES SO.O0 $0.00 G..X- & XN NIPPLES S0.tX) SO.O0 H..WELLHEAD EQUIPMENT $0.00 $0.00 I..BOP, KOOMY, CHOKE PARTS $0.00 SO.00 L.OTHER MATERIALS PLUS FUEL $0.00 $0.00 TOTAL MATERIALS $9.00 $15,21¢.00 WORK STRING RENTAl_ $0.00 TOOLS, SLIPS, ELEV RENTAL *a $O.00 *~ TRANSPOR rATION: FIXED COST SO.00 SPECIAL TOOLS ETC RENTAl. $0,00 * TRANSPOR'rATION: ALL OTHER $0.00 OTHER RENTALS $0.00 *~ TOTAL TRAN:~PORTATION COST . SO.00 TOTAL RENTALS $0.00 _. TOTI:L P. 0! DAILY REPORT PLATFORM: A WELL: A13-12RD 12-Mar-04 FOREMAN: R.H. SELTZ Al=fi: 2~3~77 ENGINEfit:I: P. T. AUTH: $215,000 DALLY: $15,249.00 CUMULATIVE: $91,542 DAI YTD: .... 0 TRI YTD: ....1 DAYS l DAYS ESTIMATED: $ OF S COMMENTS: NO ACCIDENTS REPORTED FLUID TYPE: FiW WEIGHT: SPILLS: NO SPILLS REPORTED RT TO TBG HANGER: TOF: TIME AND SUMMARY OF OPERATIONS: · 24.00 I-IRS -ClRC. XANVIS PILL - PUMP DRY JOB/BLOW ON UNES - POOH & LiD CSG SCRAPER R/U DIALOG TO RUN CSG CALIPER - COULD NOT GET TOOL TO WORK - R/D DIALOG MAJ HOWCO RTTS & TIH TO 8450' - SET RTTS @ 84,50' & TEST 7' CSG TO 1500 PSI (GOOD 'rE$~ - DISPLACE HOLE W/CLEAN FIW - PUMP OILY RETURNS DN DISPOSAL BLOW ON UNES - POOH - L/D RTTS - SET TEST PLUG - CHANGE RAMS TO 2 7/8' NOTE; WELL FLOWING APPROX. ¢ - 5 BBl./HR RECEIVED *; ADDITIONAL COMMENTS; DRILLS, VISITORS, INSPECTORS ETC... APR Z ~ 19'94 ,; Aiaska 0ii & Gas Cons. Commission .~ Anchorage SWEPI SUPERVISION & LABOR: CONTRACT SERVICES: A,.CONTRACT CREW + RS&D B..CATERING C..FISHING D..GEMENTING E..STIMULATION, OTHER PUMPING F..PRODUCTION EQUIP ~RVICES G..PERFORATING H..PACKER, PLUG SETTING I..LOGGING,.OTI-IER ELECTRIC MNE J..SUCKLINE, BRAIDED LINE ~.VVE~ SER~nCE L.OTHER SERVICE (MUO ENGINEER) TOTAL CONTRACT SERVICES "SUMMARY OF DAILY COST" $750.00 MATERIALS: $9,964.00 A..SWEPI PURCHASED RIG SUPPUES S0.tX) $750.00 B**WORKOVER FLUIDS & ADDITIVES SO.00 $0.00 C..PACKER$ $0.00 $0.00 D..BRIDGE PLUGS, RETAINERS, EZSV SO.00 $0.00 E..TUBING, PUPS, COUPUNGS, X-O'; $0.00 $0.00 F..GAG LIFT MANDRELS & VALVES SO.00 '"* $0,00 G**X- & XN NIPPLES $0.00 $3,785.00 H**WELLHEAD EOUIPMENT $0.00 $0.00 I..BOP, KOOMY, CHOKE PARTS $0.00 *'* $0.00 L..OTHER MATERIALS PLUS FUEL $O.00 *'* $0.00 TOTAL MATERIALS SO.00 $14,499.00 WORK STRING RENTAL $0.00 ~ TOOLS, SUPS, EI. EV RENTAL $0.00 ~ '"' TRANSPOI~TATION: FIXED COST $0.00 SPECIAL TOOLS ETC RENTAL $0.00 ~' '"' TRANSPOt~TATION: ALL OTHER $0.00 OTHER RENTALS SO.O0 ~- ~ I TOTAL .TR ./~SPORTATION COST $0.00 TOTAL RENTALS $0 00 "' TOTRL P. 02 DAILY REPORT ' PLATFORM: A W~:LL: A13-12RO 13-Mar-94 FOREMAN: R.H. SELTZ ' AFE: 263677 ENGINEER: P. T. HUCKABEE *~ AUTH: $215,000 DAILY: $34,6.99.00 CUMULATIVE: $126,516 ~' DAI YTD: .... 0 TRI YTD: .... 1 DAY & DAYS ESTIMATED: 6 OF 5 '"- COMMENTS: NO ACCIDENTS REPORTED FLUID TYPE: KW/PROD WATER ~ DAYS WITHOUT LTA .... 344 ' SPILLS: NO SPILLS REPORTED RT TO TBG HANGER: 37.25' · TIME AND SUMMARY OF OPERATIONS: '"24.00 I-IRS - FINISH CHANGING RAMS TO 2 7~' - TEST BOPS - CLEAR RIG FLOOR & R/U TU~NG *=' TOOLS - HOLD PRE-JOB ~ MEETING - M/U COMPI..ETION TOOLS - P/U & RUN 2 7/8" TBG - NOTE; WELL FLOWED UP 'rBG (2) TIMES, HAD TO STAB FLOOR VALVE & CIRC TBG VOLUME (NO SHUT IN) - R/U I-EAD PIN & ClRC @ 8475' PRIOR TO LANDING 'rBG HANGER - LAND HANGER - TURN IN LOCKING SCREWS - RAJ SUCKLINE & LUBR- CATOR TO RUN PLUG & PRONG - RIH W/BODY - POOH - RIH W/I~ PLUG - POOH R/D SMCKUNE & LUBRICATOR - PRESSURE UP TBG TO 3500 PSI & SET PACKER MONITOR BACKSIDE FOR FLOW. FLOW STOPPED - PRESSURE UP ON BACKSIDE TO 1~500 PSI, PACKER HOLDING - BLEED PRESSURES - PULL LANDING JT - CLOSE SSSV -IN~TALL BPV - PREPARE TO N/D BOPS BAKER PACKER SET ~ 8436' - SEE BAKER COMPLETION DETAIL NOTE; WELL CONTINUALLY FLOWED APPROX. 4 - 5 BBL/HR, STARTED MAKING A LITTLE GAS WHILE RUNNING TBG. ~. ADDITIONAL COMMENTS; DRILLS, VISITORS, INSPECTORS ETC... Anchorag& '"NOTE; BPV THREADS IN TBG HANGER .a,RE GETTING WORN - COULD NOT FIND REPLACEMENT HANGER ""O~ NOT CHANGE OUT 'fflo SPOOL, DI.J~ TO WELL FLOWING - MADE NOl~ IN PLATFORM i~ODUGIION *REVIEWB~ - NOTED ALWAYS CLOSE SSSV PRIOR TO INSTALUNG 8PV WHEN WORKING. QN WELLHEAD *' ,,, "SUMMARY OF OAILY COS'r' : $9,964.00 $760.00 SO.O0 $0.00 SO.DO SO.DO SO.DO $16,085.00 so. DO $7,150.DO $34,699.OO MATERIALS: A..SWEPI PURCHASED RIG SUPPUES B..WORKOVER FLUIDS & ADDITIVES! C..PACKERS D..BRIDGE PLUGS, RETAINERS, EZS~ E..TI. JBING, PUPS, COUPUNGS, X-.~Q'! F..GAS UFT MANDRELS & VALVES. G..X- & XN NIPPLES H..WEU.HEAD EQUIPMENT I..BOP, KOOMY, CHOKE PARTS L.OTHER MATERIALS PLUS FUEL ' TOTAL MATERIALS WORK STRING RENTAL TOOLS, 8UPS, ELEV RENTAL SPECIAL TOOLS ETC RENTAL OTHER RENTALS TRANSPORTATION: FIXED COST TRANSPORTATION: ALL OTHER SWEPI SUPERVISION & LABOR: CONTRACT SEFMCES: A..CONTRACT CREW + RS&D B..CATERING C..FI,~'IING D..CEMENTING E..STIMULATION, OTHER PUMPING F..PRODUCTION EQUIP SERVICES G..PERFORATING H..PACKER, PLUG ,~ETTING I..LOGGING, OTHER ELECTRIC UNE J..SUCKUNE, BRAIDED UNE K..WELLHEAD SERVICE L.OTHER SERVICE (TONG OP.) TOTAL CONTRACT SERVICES TOTAL TRANSPORTATION COST $o.o0 TOTAL RENTALS SO.DO ~0/~0'd B3IddO 3NU Ol U ~uJo.+~lcJ [ ! eqS NO;ad NU~[ :0]: DAILY REPORT PLATFORM: A WELL: A13-12RD l~r-Mar-94 FOREMAN: R.H. SELTZ Al=E: 263677 t ENGINEER: P. T. HUCKAI3EE AUTH: $21S,000 DAILY: $9,532.00 CUMULATIVE: $136,048 . ON YTD: .... 0 TRI '(TO: .... I DAY & DAYS ESTIMATED: 7 OF 5 COMMENTS: NO ACCIDENTS REPORTED FLUID TYPE: FIW/PROD WATER WEIGHT: 8.4 DAYS WITHOUT LTA~... 34,5 SPILLS: NO SPILL~ REPORTED RT TO TBG HANGER; 37~5' TOF: 8777' TIME AND SUMMARY OF OPERATIONS; ~12.00 HR$ - N/D BOP - CHANGE RAMS TO 3 1/2' - REMOVE KILL & CKOKE LiNE VALVES OFF BOP INSTALL BUND FLANGES - PUMP FLUID OUT OF RISER - HOLD PRE-JOB SAFETY MEETING PRIOR TO PULUNG RISER - PULL RISER - SET TREE - RAJ VALVES ON TREE - RAJ SUCKMNE - TEST LUBRICATOR TO 1500 PSI - RIH TO PULL PLUG PRONG i POOH - RIH TO PUM. PLUG BODY - POOH - R/D LUBRICATOR & LANDING JT INSTALL TREE CAP & PRODUCTION UNES - TURN WELL OVER TO PRODUCTION - RIG DOWN RIG RELEASED FROM A13-12RD @ 1800 HRS 3-13-94 RECEIVED · " ADDmONAL COMMENTS; DRILLS, VISITORS, INSPECTORS ETC... AtasKa O~l & Gas Cons. Commissio~ · ' Anchorage 'SUMMARY OF DAILY COST' SWEPI SUPERVISION & LABOR: $1,875.00 CONTRACT SERVICES: MATERIALS: A..CONTRAOT OREW + RB&D $4,983.00 A..SWEPI pURcHASED RIG 8UPPUES $0.00 B.,CATERING $375.00 B..WORKOVER FLUIDS & ADDITIVES! $0.00 C..FISHING $0,00 C..PACKERS $0.00 O..CEMENTtNG $0.00 D.J3RIDGE PLUGS, RETAINERS, EZS}J $0~0 E..STIMULATION, OTHER PUMPING $0.00 E..TUBING, PUPS, COUPUNGS, X-O': $0.00 F..PROOUCTION EQUIP SERVICES $0.00 F..GAS UFT MANDRELS & VALVES. G..PERFORATINO $0.00 G,5(- & XN NIPPLES $0.00 H..PACKER, PLUG GETTING $0.00 H..WELLHEAD EQUIPMENT $414.00 I..LOGGING, OTHER ELECTRIC UNE $0.00 I..BOP. KOOMY, CHOKE PARTS $0.00 J..SUCKUNE, BRAIDED LINE $0.00 I-.OTHER MATERIALS PLUS FUEL' $0.00 K..WELLHEAD SERVICE $1,885.00 TOTAL MATERIALS $414.00 L..OTHER SERVICE (TONG OP.) $0.00 TOTAL CONTRACT SERVICES $9,118.00 WORK STRING RENTAL $O.00 TOOLS, SUPS, ELEV RENTAL . $0.00 TRANSPORTATION: FIXED COST $0.00 SPECIAL TOOLS UTC RENTAL $0.00 TRANSPORTATION: ALL OTHER $0.00 OTHER RENTALS $0.00 TOTAL TRANSPORTATION COST $0.00 TOTAL RENTALS $0.00 T0/I0'd 3DId::~ ~ Ol ~ ma°}~eld IlaqS L40~Jd I,,L:~£:TI ta56T-£T-£O .. DAILY REPORT ~ PLATFORM: A WELL: A13-12RD 31-Mar-94 FOREMAN: R.H. SELTZ *= AFE: 263677 ENGINEER; P. T. HUCKABEE *: AUTH: $31$,000 DAILY: $0.00 CUMULATIVE: $162,364 "' DAJ Y'rD: .... 0 TRI Y'rD: .... I DAY & DAYS ESTIMATED: 7.5 OF 6~ *'- COMMENTS: NO ACCIDENTS REPORTED FLUID TYPE: PRODUCTION WEIGHT: ": DAYS WITHOUT LTA .... 363 *; *' SPILLS: NO SPILLS REPORTED RT TO TBG HANGER: 37.25' TOF: 8777' *' TIME AND SUMMARY OF OPERATIONS: *; ~-16.00 HRS - R/U SCHLUMBERGER TO PERFORATE 'F' POOL (GR-G$) *' TEST LUBRICATOR TO 1500 PS1 *' PERFORATE WI2 1/8' STRIP PHASED ENERJET GUNS (6SPF) '": "' RUN ~1 PERFORATE 8630' - 8664' ~' RUN ~2 PERFORATE 8604' - 8630' RECEIVED · , APR 2 5 1994 ,,. *' ~ ~,.~,z 0iL & Gas. Cons..Commi_%sJo~ ." ~ ~OmON~ COM~S; DRI~S, VISITO~, INS~CTORS ETC... Anchorage ,, *, "SUMMARY OF DAILY COST" '~ SWEPI SUPERVISION & LABOR: $0.00 *: CONTRACT SERVICES: MATERIALS: *' A,.CONTRACT CREW -I- RS&D $0.00 A..SWEPI PURCHASED RIG SUPPUES $0.00 ~ B.,CATERING $0.00 B..WORKO%~ER FLUIDS & ADDITIVES $0.00 ~ C..FISHING $O.00 C..PACKERS $0.00 °: O..CEMENTING $0.00 D..BRIDGE PLUGS. RETAINERS, EZSV $0.00 ': "" E..STIMULATION, OTNER PUMPING $O.00 E..TUBING, PUPS, COUPUNGS, X-O'.' $0.00 '" F..PRODUCTION EQUIP SERVICES $0.00 F..GAS MFT MANDRELS & VALVES $0.00 ~' G..PERFORATING $0.00 G..X- & XN NIPPLES Si)J30 *' H..PACKER, PLUG GE]riNG $0.00 H..WELLHEAD EQUIPMENT $0.00 *' ~. I..LOGGING, OTHER ELECTRIC UNE $0.00 I..BOP, KOOMY, CHOKE PARTS $0.00 *' J..$UCKMNE, BRAIDED UNE $O.00 I_.OTHER MATERIALS PLUS FUEL $0.00 *; *" K..WELLHEAD SERVICE $0.00 TOTAL MATERIALS S0.1X) *' ": L..OTHER ,~RVlCE (TONG OP.) $0.00 *' TOTAL CONTRACT SERVICES $0.00 WORK STRING RENTAL $0.00 * TOOLS, SLIPS, ELEV RENTAL ~0.00 ~ TRANSPORTATION: FIXED COST $0.00 SPECIAL TOOLS ETC RENTAL $0.00 *' TRANSPORTATION: ALL OTHER $0.00 OTHER RENTALS $0.00 *' TOTAL TRANSPORTATION COST $0.00 TOTAL RENTALS $0.00 lO/lO'd ]DId_-ID DNI:J 01 U m~o5leld [Ia~S ~ NI:I<3I:OI P6GI-I£-£O . DALLY REPORT *' PLATFORM; A WELL: A13-12RD 02~-Apr-94 FOREMAN: R.H. SELT'Z ~ AFE: 263677 ENGINEER: *: AUTH: $21S,000 DAILY: $750.00 ' DAf YTD: .... 0 TRI YTD: ....1 DAY & DAYS ESTIMATED: 8. OF 6 " COMMENTS: NO ACCIDENTS REPORTED FLUID TYPE: PRODUCTION WEIGHT: ~. DAYS WITHOUT LTA .... 364 ~- SPILLS: NO SPILLS REPORTED RT TO 'I'BG HANGER: 37.25' TOF: 8777' TIME AND SUMMARY OF OPERATIONS: m12.00 HR$ - PERFORATE PERFORATE WI2 1/8' STRIP PHASED ENERJET GUNS (6SPF) RUN ~3 PERFORATE 8604' - 8578' *; RIG DOWN & MOVE TO A33-14 W'. RECEIVED .~,,PR 2. '5 1994 & & ADDITIONAL COMMENTS; DRILLS, VISITORS, INSPECTORS ETC... Anchorage 'SUMMARY OF DAILY COST' : *' SWEPI SUPERVISION & LABOR: CONTRACT SERVICES: A..CONTRACT CREW + RS&D B..CATERING C..FI~HING D..CEMENTING E..STIMULATION, OTHER PUMPING F..PRODUCTION EQUIP SERVICES G..PERFORATING H.,PACKER, PLUG SETTING I..LOGGING, OTHER ELECTRIC LINE J..SLICKLINE, BRAIDED UNE K..WELU-IEAD SERVICE L..OTHER SERVICE (TONG OP.) TOTAL CONTRACT SERVICES TRANSPORTATION: FIXED COST TRANSPORTATION: ALL OTHER TOTAL TRANSPORTATION COST $750.00 S0.00 $0.00 $0.00 $0.00 $0.00 $o.oo $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 MATERIALS: A..SWEPi PURCHASED RIG SUPPUES B..WORKOVER FLUIDS & ADDITIVES C..PACKERS D..BRIDGE PLUGS, RETAINERS, EZ. SV E..TUBING, PUPS, COUPUNGS, X-O',' F..GAS UFT MANDRELS & VALVES G..X- & XN NIPPLES H..WELLHEAD EQUIPMENT I..BOP, KOOMY, CHOKE PARTS L.OTHER MATERIAL~ PLUS FUEL TOTAL MATERIALS WORK STRING RENTAL TOOLS. SUPS. ELEV RENTAL SPECIAL TOOLS ETC RENTAL OTHER RENTALS TOTAL RENTALS $0.00 ~. $0.00 ~' 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 February 15, 1994 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: SUBMITTAL OF APPLICATION FOR SUNDRY APPROVALS (FORM 10-403) for MIDDLE GROUND SHOAL A13-12RD Enclosed in triplicate is the Application for Sundry Approval for a rig workover to replace the tubing and perforate the "F" pool. If you have any questions or wish to discuss, please call Paul Huckabee at (907) 263-9646. Sincerely, Paul Huckabee Staff.Production Engineer ~ 6 ~99A Gas Gons. Gomm'ms'mn /~ncbomge STATE OF ALASKA "~~ OIL AND GAS CONSERVATION coM'~,,,~N APPLICATION FOR SUNDRY APPROVALS 1 Type of Request: Abandon __ Suspend__ Operation shutdown Re-enter suspended well ' / Alter casing Repair Well Plugging Tim"-; extension Stimulate Change approved program m Pull tubing X Variance Perforate X Other 5. Type bt Well: 6. Datum elevation (DF'or K'~ 2. Name of Operator Shell Western E&P Inc. Development X 116' DF 3. Address 601 West 5th Avenue, Suite 800 Exploratory 7. Unit or Property name ~,~ Anchorage, AK 99501 Stratigraphic Middle Ground Shoal Service 8. Well number 4. Location of well at Platform A, Leg 4, Conductor 29, 1561'N & 381'W of SE Corner of A13-12RD sudace Sec. 11, T8N, R13W, SM 9. Permit number At top of productive 9043' (M.D.), 1288'N & 646'E of SE Corner of Sec. 11, T8N, R13W, 73-35 interval SM 10. APl number At effective depth 50-733-20191-01 9900' (M.D.), 1209'N & 707'E of SE Corner of Sec. 11, T8N, R13W, 11. Field/Pool At total depth SM MGS/"G" Pool 12. Present well condition summary Total depth: measured 9900 feet Plugs (measured) true vertical 9595 feet Effective depth: measured 9809 feet Junk (measured) true vertical 9504 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1593' 13-3/8", 61#, J-55 1300 sx 1593' 1592' Intermediate 6501' 9-5/8", 40-43.5#, N-80 & P-110 Sidetrack 6501' 6477' Production 0'-6290' 7", 26#, N-80 0'-6290' 0-6270' 6290'-9898' 7", 29#, N-80 1750 sx 6290'-9898' 6270'-9593' Pedoration depth: measured 9043'.9670' (9 Intervals) R E C E true vertical Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 EUE 8RD @ 0'-342' :EB 1 6 i994 2-7~8", 6/5#, N-80 EUE 8RD @ 342'-8961' Packers and SSSV (type and measured depth) Gulberson Uni-packer VII @ 8887', Otis SSSV @ 306~ska Utl& Gas Cons. Corrllllj,~ Anchorage 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch ,, 15. Status of well classification as: 14. Estimated date for commencing operation ~'E~ ~..'~ ~ ~:{,.~zt~- Oil X Gas Suspended 16. If proposal was verbally approved m __ Service Name of approver Date approved 17. I hereJ;~Y-C, ertify t~egoing is true and correct to the best of my knowledge Signed~' ~'t,,...,'~'.-~-~ ~~ Title Staff Production Engineer Date '7..-'~( ~ FOR COMMISSION USE ONLY Conditions of approval: NOtify Commission so representative may witness I Approval No. 7'7' Plug integrity~ BOP Test Location clearance '-- Mechanical Integrity Test___ ---Subsequent form requ~'~d 10- ~) ~ Approved COpy Returned 0rj..ina.(:] I SJ.qnee 9y Commissioner Date ,~_,,,,~,~_/,,,~- Approved by order 0!,,the Commission David W, Jnh~_~tr)n 3ion Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DESCRIPTION SUMMARY OF PROPOSAL ATTACHMENT NIDDLE GROUND SHOAL WELL NO. A13-12RD REPLACE TUBING & PERFORATE "F" POOL STATUS MGS A13-12RD has suspected parted tubing at 3206' and a wireline fish in the hole at approximately 3836'. A rig workover is proposed to replace the , ~ tubing, clean out the wellbore to PBTD, and perforate the "F" pool. Twenty- ~pl\~' one feet of pay has al~o ~ee~ ideal'fie~ in t~e lowe~ Hemlock "G" "o~ ~n~ -~'' will be perforated if clean-out PBTD is below 9785'. PROPOSED OPERATIONS SUMMARY MGS A13-12RD is capable of 107 bbl/day unassisted backflow with 150 ppm H2S. Maximum shut in pressures observed were 1500 psi prior to backflow. 1. RU choke manifold and flowlines to work on well with well flowing. RU chemical injection pump to inject slurried MI SSII for H2S neutralization prior to taking well returns to the mud pits. Closely monitor H2S during all operations and shut in flowline to the mud pits if H2S exceeds 50 ppm. 2. ND Tree/NU 5000 psi BOPE and test per API RP 53 and Shell Safe Practices. 3. If tubing is not parted, PU and shear release Guiberson UNI-VII packer (set @ 8887' MD) with straight pull shear release. POOH with 3-1/2" x 2- 7/8" tubing (top 342' is 3-1/2"), packer, SSSV, GLM's, and tubing/packer accessories. Inspect tubing for NORM scale contamination. Send tubing to Tuboscope for CLASSIFAX inspection and potential reuse/repair. NOTE: See attached PROFS note from Ton Reese dated 11/21/93 detailing wireline fish lost in hole. CONTINGENCY a) If tubing is parted, POOH w/ 3206' of 3-1/2" x 2-7/8" EUE 8rd tubing. b) RIH with overshot fishing tools and engage 2-7/8" tubing fish. c) PU and shear release Guiberson UNI-VII packer (set @ 8887' MD) with straight pull shear release. POOH with remaining 2-7/8" tubing, GLM's, packer, and tubing/packer accessories. 4. RIH with 6" mill and clean out wellbore to PBTD at 9809'. Pump 5+ bbl XANVIS polymer sweep to clear debris from wellbore. Dispose of contaminated return fluid down A44-11. POOH. NOTE' CTU clean out encountered hard scale at 9710'. Bottom HN-HR perf at 9710'. Proposed HR-HZ perfs from 9765' , 9785'. DO NOT TAKE SIGNIFICANT RISK OR SPEND SIGNIFICANT $$$ ATTEMPTING TO CLEAN OUT WELLBORE BELOW 9710'. RECEIVED C: \F I LES\PROG\A1312RI G. PRG page 1 FEB 1 6 1994 At~ska Oil & Gas Cons. Commission Anchorage 5. RIH w/ 6" mill and casing scraper to 8500' in preparation of setting a Baker Model "HB" packer at 8450' (+/-). Pump 5+ bbl XANVIS polymer sweep to clear debris from wellbore. Dispose of contaminated return fluid down A44-11. POOH. 6. Run the following equipment on 2-7/8", 6.5#, N-80/L-80, EUE 8rd tubing' a) Baker Wireline Re-Entry Guide (WLREG) b) OTIS 2-7/8" "XN" nipple (2.205" ID) c) one joint 2-7/8" 6.5# N-80 EUE 8rd tubing d) Baker "HB" packer for 2-7/8" x 7" 26# to set at -8450' e) one joint 2-7/8" 6.5# N-80 EUE 8rd tubing f) OTIS 2-7/8" "X" nipple (2.313" ID) g) one joint 2-7/8" 6.5# N-80 EUE 8rd tubing h) Bottom Gas Lift Mandrel (GLM) i) 2-7/8" 6.5# N-80/L-80 EUE 8rd tubing and GLM's per Production Engineering recommendation j) 2-7/8" Baker "FV-6" TRSCSSV w/ 2.313" "X" nipple profile in top & 1/4" SS control line set at- 300'. 7. Install tubing hanger & land tubing. RU Slickline Unit (SLU) & test lubricator. RIH and set plug/prong in "XN" nipple below packer. Pressure up per Baker instruction to set packer. Test tubing to 3500 psi. POOH with plug/prong. RD SLU. Secure hanger in spool. 8. ND BOPE/NU Tree and test each tree component to 5000 psi. Skid rig. 9. Return well to production via gas lift. 10. After production is stabilized, RU Schlumberger Electric Wireline Unit (EWLU) and perforate the "F" pool (GR-GS) from 8575' -8661' with 2-1/8" Retrievable Strip Phased Enerjet guns loaded 6~-P-F -RD-EwLu. Test well and report. C' \F I L ES\PROG\A1312RI G. PRG page 2 RECEIVED FEB 1 6 1994 Al~sk,3 Oil & Gas Cons. Commission Anchorage 9 10 11 12 COMPLETION EQUIPMENT DETAIL SHEET MGS A13-t2RD 7/2q/87 NO. ITEM APPROXIMATE TVD. MD. PSI OR 1. OTIS BALL VALVE 2. KBM GAS LIFT MANDREL #1 3. KBM GAS LIFT MANDREL #2 4. KBM GAS LIFT MANDREL #3 5. KBM GAS LIFT MANDREL #4 6. KBM GAS LIFT MANDREL #5 7. KBM GAS LIFT MANDREL #6 8. KBM GAS LIFT MANDREL #7 9. KBM GAS LIFT MANDREL #8 10. GUIBERSON UNI-PACKER VII 11. OTIS "X" NIPPLE 12. SEATING SUB 306 306 2071 2072 1020 3/16 3752 3760 995 3/16 5088 5091 960 3/16 6125 6140 985 1/4 6828 6891 965 1/4 7314 7445 950 1/4 7597 7768 910 1/4 ]846 8049 OR 3/8 8602 8887 8644 8928 8676 8960 CASING 13 3/8", 61#, J-55 @ 1593' w/1300 sx 9 5/8", 40-43.5#, N-80 & P-t10 @ 6501' 7" 26#, N-80 @ 0 - 6290' 29#, N-80 @ 6290-9898' w/1750 sx PBTD = 9809' TD = 9900' TUBING 3 1/2", 9.3#, N-80 EUE 8RD @ 0 - 342' Z 7/8", 6.5#, N-80 EUE 8RD @ 342' - 8961' PERFORATED ZONE GROSS INTERVAL HC-HD 9043-9067' HC-HD 9076-9120' HE-HF 9203-9217' HI-HK 9323-9365' HK-HN 9394-9445' HK-HN 9448-9463' HK-HN 9464-9544' HN-HR 9560-9590' HN-HR 9640-9670' RECEIVED FEB 1 6 1994 A;tasks Oil & Gas Cons. Commissio~ Anchorage Z MGS A13-12RD PROPOSED WELLBORE DIAGRAM - 2/14/94 2 3 4 5 6 7 XX XXX < <- / \ / -m BAKER "FV-6" TRSCSSV w/ "X" Profile @ 300' 24" Conductor Casing @ 370' 13-3/8" 61# J-55 Surface Casing @ 1593' 2-7/8" 6.5# N-80/L-80 EUE 8rd tubing GLM MD TVD PORT Ptro Psc Pso GAS 1 ' ' 12 2 ' ' 12 3 ' ' 12 4 ' ' 12 5 ' ' 12 6 ' ' 12 7 ' ' _/ "ORIFICE 9-5/8" 40# & 43.5# N-80 & P-110 @ 6501' := GN-GO := GR-GS I := HC-HD := HD-HE := HE-HF := HI-HK := HK-HN := HN-HR := HR-HZ OTIS "X" Nipple @ 8420' (2.313" ID) 1 jt 2-7/8" 6.5# N-80 EUE 8rd tbg BAKER "HB" Packer @ 8450' w/ # shear 1 jt 2-7/8" 6.5# N-80 EUE 8rd tbg OTIS "XN" Profile Nipple @ 8480' (2.205" ID) BAKER Bell Wireline Re-Entry Guide @ 8481' MD 8575' - 8661' MD RECEIVED 9043' - 9067', 9076' - 9120' FEB 1 6 1994 9203' - 9217' ~kaUi~& GasCons. Commissi( 9323' - 9365' Anchorage 9394' - 9445' 9448' - 9463' 9464' - 9544' 9560' - 9590' 9640' - 9670' 9690' - 9710' 9765' - 9785' ? I /////////1< ....... PBTD : 9809' MD .........I\ 7" 26-29# N-80 Production Casing @ 9898' MD (26#, N-80, 0 - 6290'; 29#, N-80, 6290 - 9898') TD: 9900' C: ~F I L ES\PROG\A 1312RI G. PRG page 3 Shell Western E&P Inc. 601 W~st Fifth Av~nu~ - Sui(~ §00 Anchorage, Alaska 99501 December 30, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' SUBMITTAL OF REPORT OF SUNDRY WELL OPERATIONS (FORM 10-404) for MIDDLE GROUND SHOAL A13-12RD REFERENCE: SUNDRY APPROVAL NUMBER 93-196 Enclosed are duplicate copies of the Report of Sundry Well Operations (Form 10-404) for Middle Ground Shoal A13-12RD. Operations were completed 11/21/93. If you have any questions or wish to discuss, please call Paul Huckabee at (907) 263-9646. Sincerely, Paul Huckabee Staff Production Engineer STATE OF ALASKA '>-,,- ~, OIL AND GAS CONSERVATION COMI~ N REPORT'OF SUNDRY WELL oP-' ATIONS 1. Operations performed: Operation shutdown __ Stimulate__X Plugging__ Perforate __ Pull tubing ~ Alter casing__ Repair well ~ Other __ 5. type et Well: 6. Datum elevation (DF or KB) 2. Name of Operator Shell Western E&P Inc. Developmenl X 116' DF feet 3. Address 601 W. 5th Avenue, Suite 920 Exploratory 7. Unit or Property name Anchorage, AK 99501 Stratigraphic Middle Ground Shoal Service -- !8. Well Number 4. Location of well at surface Platform A, Leg 4, Conductor 29, 1561'N and 381'W of SE A13-12RD Corner of Sec. 11, TSN, R13W, SM 9. Permit number/approval number At top of productive Interval 9043' (M.D.), 1288'N and 646'E of the SE Corner of Sec. 11, ~/&".~',,5::i~J-e~93-196 TSN, R13W, SM 10. APl number,.~l. At effective depth 50-733-20191-,~'~ 9900'(M.D.), 1209'N and 707'E of the SE Corner of Sec. 11, 11. Field/Pool At total depth TSN, R13W, SM MGS/"G" Pool 12. Present well condition summary Total depth: measured 9900 feet Plugs (measured) true vertical 9595 feet Effective depth: measured 9809 feet Junk (measured) true vertical 9504 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Su trace 1593' 13-3/8", 61#, J-55 1300 sx 1593' 1592' Intermediate 6501' 9-5/8", 40-43.5#, N-80 & P-110 6501' 6477' Production 0'-6290' 7", 26~, N-80 0'-6290' 0'-6270' Liner 6290'-9898' 7", 29#, N-80 1750 sx 6290'-9898' 6270'-9593' Perforation depth: measured 9043'-9670' (9 Intervals) R ~ C ~ IV E D true vertical D,~L.,, 0 i993 Tubing (size, grade, and measured depth) 3-1/2", 9.3~, N-80 EUE 8RD @ 0'-342' ,,~ ~.,..,. .., 2-7/8", 6/5#, N-80 EUE 8RD @ 342'-8961' Packers and SSSV (type and measured depth) Guiberson Uni-packer VII @ 8887', Otis SSSV @ 306' 13. Stimulation or cement squeeze summary Jet wash and acid squeeze treatment. Intervals treated (measured) 7900' - 8150' & 9043' - 9710' Treatment description Including volumes used and final pressure CTU Acid soak, wash, squeeze. Total acid volume 179 bbls. Treatment pressure = 3320 psi. 14. Representative Daily Averaae Production or Injection Data OiI-Bbl .. Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 39 / 18 33 440 80 Subsequent to operation SI / SI 1400 1300 15. Attachments: M IT test form 16. Status of well classification as: Copies of Logs and Surveys run __ Oil X Gas Suspended Service Daily Report of Well Operations__X -- -- 17. I hereby certify that the foregmng is true and correct to the best of my Knowledge Signed('"~.~..R ~1. -~-~ Title Staff Product ion Engineer Date J'Z-/~0 /4~ ,'- .... ,', ,,',, n^.. n=,*=,oo RIJRMIT IN DIJPI I~ATF Form 10-404 Rev 15/88 * DAILY REPORT * PLATFORM= A WELL.?-~,~-12~ 09-Nov-95 ~ , FOREMAN: T. A. REES ~ AF~,: 261957 '--' F/~GINE~R; P. T. HUC AUTH: 60,000 DAILY: $16,926.00 CUP~JLATIVE: DAI YTD: .... 0 TRI YTD: .... 0 DAYS & DAYS ESTIMATED: I OF ? , , COMMENTS~ NO ACCIDENTS R~POR~ED FLUID TYPE: FIW WEI~ SPILLS{ NO SPILLS REPORTED RT TO TBG HANGER: TOFf ******************************************************************************* TIME AND ~UMMARY OF OPERATIONSt *09{30-06t00 COIL TUBING INC. AND HALLIBURTON ARRIVE ON PLATFORM AND BEGIN *RIC,~ING UP OPERATIONS. ,20~00-01~00 i~H 'WITH WIR~LIN~. PULL BA~L VALVE. RUN 2.~5 GAUGE RING TO 8078. *~l.ll, l 2.10 ,21:00-01 *0L:00-O~ *FIW DOWN * * * * * * GAUGB RING AND TAGGBD FILL AT 9714. ~00 BLEED CASING FROM 475 TO 80. :00 INJECT FIW DOWN CASIN~ AT I BBL P/M. PUMMPED APPROX. CASING. CASING PRESSUI~W~ITT FKOM 100 TO 37~. 250 BBLS PL~TFORH: A W~LL:I~-lZRD 10-Nov-9~ -~)P~: T. A. ~ESE · DAI Y~; .... 0 ~I Y~: .... 0 ~YS a DAYS ~~TED: 2 0F 7. · ~: NO AOOID~ ~~D ~UID ~: F~W ~ID~: · 17: 00-19:1~ RIH WI~ ~. ~ ~I~e ~N MO~ AT 1/2 BBL P~. TAG · 19:15-~:45 A~ ~ ~ ~, ~D FILL. ~ ~ ~710. · 20:15-21:15 ST~ ACID ~. ~ 31 ~ Ol HOL ACID ~ 50~ UP · ~~D ~ 21.5 BB~ OF HCL ACID. ,2I:15-21:45 ~ ~ 7~ TO BEGIN J~ ~SH. ,21~4~22:~ J~ W~H ~ 7900 ~ 81~ ~D 9045 TO 9710. ~ AT · t~ ~ AT 20~ P~. ~ 2~. ~ ~. CSG 4~. ~HD 46 BB~ · ~22:~1:00 ~t.t~D H~ ACID WI~ 2 ~L$ OF FIW AND ~ ~'OF 2.5 · ~~D GEL WI~ 220 ~ OF FIW ~ VIS.CE ACID ~ OE ~O ~ S~ T~K. ~~D ACID WI~ ~ ~ 0F FIW AT 3 ~S .3;~:~ ~ 2~ ~ 0F FIW ~ DISP~ AClU ~ OF ~G IN~ ~0~ T~K. ~ FI~Y ~~ UP. ~ ~8. 47~ ~ ~L. ~. 10~. ~G 11-11-1~ ~8:S~AM ~ROM Shell Plal~pm A TO ~NC ~FFICE ~' OAILY REPORT '" *' PLATFORM: A WELL: A13-12RD 1!-Nov-93 FOREMAN: T. A. REESE ~. AFE: 261957 ENGINEER: P. T. HUCKABEE *" AU't'H: ,~60,000 DAILY: $23,401.00 CUMULATIVE: $71,317.00 ~' ON YTD: ....0 TRI YI'D: .... 0 DAYS & DAYS E~TIMATED: 3 OF 7. '"'COMMENTS: NO ACCIDENTS REPORTED FLUID TYPE: FIW WEIGHT: ~ SPILLS: NO SPILL~ REPORTED RT TO 'I'BG HAN~R: TOF: *'. *, TIldE AND SUMMARY OF OPERATIONS: *'06:00- lg:O0 CONTINUE WITH ACID SUClErTr. SPOT CIR. 21.$ BBI.~ OF 7' 1/2~ OF HCL 'ACID. CLO~E FLOW 'T'. PUMP/SQUEEZE 80 BBLS OF 7 112% HCL ACID FOLLOWED BY ""150 BBI.~ OF FIW. PUMP RATE WA8.3 BBL8 P/M. PRESSURE BEFORE SQUEEZE WAS '%'-'TU TBG: 4700. CTU ANUL. 100; CSG 450; PUT POSSITIVE PRESSURE ON CSG WHILE *'STARTING TO SQEEZE ACID AWAY. PRESSURE WHILE PUMPING WAS: c'ru 'I'BG 3550; "CTU ANUL: 3,320: CSG ~440. ~.1g:00-21:00 POOH wrrH OTU FROM 9710. PRE$SUFE WHEN OUT OF HOLE WA,.~: *CI'U ANUL OR'I'B{3 WA,S ?2S; CSG 800. "21:00-24:00 F:I/D CTU AND START MOVE TO A42-14. From: EP388TAR--VM35 To: EP383RGB--VI~5 EP38DLt4 --Vl~5 R G BLACKBURN D L MARSHALL EP38PTH --VM35 11/22/93 10:32:02 P T HUCKABEE From: TOM REESE Subject: A13-12RD ON 11-19-93. FIND LEAK. RIH ANO PULLEO 1" GAS-LIFT VALVE FROM20?8 (NLM), 2116 (MO). RIH AND ATTEMPTED TO PULL GAS-LIFT VALVE FROM 3760 (MO), BUT COULD NOT LOCATE MANOREL. STOPPEO AT 3780 (NLM), 3818 (MO). ATTEMPTED TO PICK-UP HAl) NO JAR ACTION. COULO GO DOWN HOLE. STOPPEO AT 3798 (NLM), 3836 (MO). COULO NOT PULL UP THE HOLE. NO JAR ACTION. WORKEO NIRE FOR 2 HOURS. OID NOT GET JAR ACTION BACK. LAST PROOUCTION TEST NAS AS FOLLOWS: GROSS 70;° CUT 48; CLEAN 36; INJ 573; PRO0 O; GOR O; TBG 80; CSG ~55; SCP 52/25; H2S 12. cc: EP388CVN--VM35 EP388CVU--VM35 C V NILLOUGHBY C V N~LLOUGHBY EP388MAJ--VM35 EP388NAJ--VH35 MILLER MILLER From: TOM REESE Subject: A13-12RD ON 11-20-93. WORK NIRE AND/OR CUT WIRE. WORKEO NIRE 2 HOURS. GOT CUTTER BARS REN)Y. OROPPEO 1- 1 1/2" X 3~ CUTTER BAR. OIO NOT CUT. WORKEO NIRE FOR 15 MINUTES. STILL OID NOT CUT. OROPPEO 1- 1 7/8" X 3~ CUTTER BAR. OIO NOT CUT. WORKEO NIRE. CUT IMMEOIATELY. POOH. H/U) 4~ ON COUNTER NHEN I GOT OUT OF HOLE. IT INDICATES ABOUT &~ OF WIRE LEFT IN THE HOLE. From: TOM REESE Subject: A13-12RD ON 11-21-93. DETERMIN NHERE LEAK IS. RIH NITH 2.25 IMPRESSION BLOCK. STOPPEO AT 3168 (NLM), 3206 (MD). POOH. HAl) IMPRESSION OF PARTEO TUBING. From: TOM REESE Subject: A13-12RD. TOOLS LOST IN HOLE. TOOLS LOST IN HOLE NERE AS FOLLOWS: 1 1'1/4"' ROPE SOCKET (6'). 1 1 ' 1/2" 1 1'1/2" 1 1'3/4" 1 1 1 1'1/2" 1 1'1/2" 1 2' 1/2" 1 1 '1/4' 1 1' 1/2" 1 1-7/8" KNUCKLE JOINT (9"). X 1'3/~' X'OVER (6'). NEIGHT BAR (5~). X 1'1/2" X'OVER. HYORAULIC JARS (2~ OPEN, 3~ CLOSED). SPANG dARS (5~ OPEN. 3 1/2" CLOSED). "N' KICKOVER TOOL (4~) DANIELS PULLING TOOL(12'). CUTTER BAR (3~). CUTTER BAR (3~). CC: EP388CVW--VM35- C V WILLOUGHBY EP388MAJ--VM35 W A MILLfR Shell Western E&P Inc. 801 West Fifth Avenue Suite 800 Anchorage AK 99501 JULY 2O, 1993 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' SUBJECT- SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NO. Al3-12R Enclosed in triplicate is the application for Sundry Approval to perform a coiled tubing clean out/acid treatment workover on MGS Well No. A13-12R. The workover is anticipated to begin on August 15, 1993. If you have any questions, please call me at (907) 263-9646. Yours truly, P. T. Huckabee Staff Production Engineer PTH/maj Enclosures MAJO4\O12093.WP5 REEEIVED J U L 2 6 199) Alaska Oil & Gas Cons. Comrn'tssion Anchorage · '~ STATE OF ALASKA I'~ ALA,.,.,~ OIL AND GAS CONSERVATION COMMI~'~'~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend__ Operation shutdown Re-enter suspended well Alter casing Repair Well Plugging__ Time extension Stimulate X Change approved program __ Pull tubing Variance Perforate __ Other 5. type ot Well: 6. Datum elevation (DF or KB} 2. Name of Operator Shell Western E&P Inc. Development X 116' DF feet 3. Address 601 West 5th Avenue, Suite 800 Exploratory 7. Unit or Property name Anchorage, AK 99501 Stratigraphic Middle Ground Shoal Service 8. Well number 4. Location of well at Platform A, Leg 4, Conductor 29, 1561 'N & 381'W of SE Corner of A13-12RD surface Sec. 11, T8N, R13W, SM 9. Permit number At top of productive 9043' (M.D.), 1288'N & 646'E of SE Corner of Sec. 11, T8N, R13W, --69-6.1- interval SM 1'0. APl number At effective depth 50-733-20191-J0~ 9900' (M.D.), 1209'N & 707'E of SE Corner of Sec. 11, T8N, R13W, 11. Field/Pool At total depth SM MGS/"G" Pool 112. Present well condition summary Total depth: measured 9900 feet Plugs (measured) ----,e, ORIGINAL Effective depth: measured 9809 feet Junk (measured) true vertical 9504 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1593' 13-3/8", 61#, J-55 1300 sx 1593' 1592' Intermediate 6501' 9-5/8", 40-43.5#, N-80 & P-110 6501' 6477' Production 0'-6290' 7", 26~, N-80 0'-6290' 0-6270' Liner 6290'-9898' 7", 29#, N-80 1750 sx 6290'-9898' 6270'-9593' Perforation depth: measured 9043'-9670' (9 Intervals) ~ true vertical Tubing (size, grade, and measured depth) 3-1/2", 9.3~, N-80 EUE 8RD @ 0'-342' ~, !! 2-7/8", 6/5#, N-80 EUE 8RD @ 342'-8961' ' .... ~;lSka L~t d, u~$ C0JlS. Packers and SSSV (type and measured depth) Guiberson Uni-packer VII @ 8887', Offs SSSV @ 306' Corllm~ Anchorage 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation 08/15/93 Oil X Gas Suspended 16. If proposal was verbally approved -- -- Service Name of approver Date approved 17. I hereby certify th~ tt the foregoing is true and correct to the best of my knowledge Signed ~'~..-~ ~. ~,~ Title Staff Production Engineer Date 07/20/93 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ]Approval No._ I Y Plug integrity BOP Test__ Location clearance~ Mechanical ]n~grity Test.__ Subsequent form required lO- Approved Copy Returned Original Signed By - · Approved by order of the Commission David W. Johnston Commissioner Date .?/'~z. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVALS FORM 10-403 ATTACHMENT DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL WELL NO. A13-12RD We recommend a clean out and xylene/acid treatment of MGS A13-12 via coiled tubing unit (CTU) utilizing the soak/wash/squeeze method of stimulation. MGS A13-12RD has declined at an annual exponential decline rate of 20% since 1981. A 2.25" restriction in the tubing was observed at 8822' in June 1989 indicating possible scale build-up in the tubulars. The water cut has been in the 40-50% range since 1987. Experience with other MGS producers indicates potential scaling tendencies in this water cut range. The latest test was June 28, 1993 at 72 BPD Gross, 43% cut, and 41 BOPD clean. Continued production of this well without remedial stimulation work will result in uneconomic production within 2 years. A 50 BOPD production increase is expected from successful stimulation of this well via coiled tubing unit. proposed Operations Summary 1. Fill wellbore via the annulus with Filtered Inlet Water (FIW). 2. Rig up Coiled Tubing Unit (CTU), xylene/acid treatment materials & equipment, and return fluid processing materials & equipment. 3. Clean out wellbore to PBTD with downhole motor and bit/mill assembly. 4. Xylene/Acid treat via CTU with 5 to 7-1/2% hydrochloric (HC1) acid. 5. Dispose of contaminated fluids in A44-11. Neutralize all return fluids that will be sent to production facilities. 6. Return well to production via gas lift. RECEIVED JUL t 6 1995 Alaska Oil & Gas Gons. Gomm'~sskOn Anchorage Shell Western E&P Inc. An affiliate of Shell Oil Company GINAL 601 West Fifth Avenue Suite 800 Anchorage AK 99501 June 10, 1992 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Gentlemen: SUBJECT: SUBSEQUENT REPORT FOR MIDDLE GROUND SHOAL WELL A13-12RD Upon further review, the approved acid stimulation work on Middle Ground Shoal well A13-12RD has been canceled. Enclosed are duplicates of the Subsequent Report canceling this treatment. If you need additional reports or information, please contact Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, S. B. Brown-Maunder Sr. Environmental Technician Alaska Operations SBBM/dlw Enclosures SBBM\061092.WP5 RECEIVED J UN 1 ? 1992 Alaska Oil & Gas Cons. Commission Anchorage AL~,_,.~'~ OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPi RATION$ 1, Operations performed: Operation shutdown m Stimulate__ Plugging__ Perforate __ Pull tubing__ Alter casing__ Repair well __ Other X 5. type ct Well: 6. Datum elevation (DF or KB) 2. Name of Operator Shell Western E&P Inc. Developmen! X 106' DF feet 3. Address 601 W. 5th Avenue, Suite 810 Exploratory 7. Unit or Property name Anchorage, AK 99501 Stratigraphic Middle Ground Shoal Service 8. Well Number ,, i4. Location of well at sudace Platform A, Leg 4, Conductor 29, 1561'N and 381'W of SE A13-12RD Corner of Sec. 11, TSN, R13W, SM 9/15ermit numb. m.~approval number At top of productive interval 9043' (M.D.), 1288'N and 646'E of the SE Corner of Sec. 11, ~..~~92-122 ~/1 TSN, R13W, SM 10.TE~l-number At effective depth 50-733-20191 9900'(M.D.), 1209'N and 707'E of the SE Corner of Sec. 11, 11. Field/Pool At total depth TSN, R13W, SM MGS/"G" Pool 12. Present well condition summary Total depth: measured 9900 feet Plugs (measured) tnJe vertical 9595 feet Effective depth: measured 9809 feet Junk (measured) true vertical 9504 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1593' 13-3/8", 61#, J-55 1300 sx 1593' 1592' Intermediate 6501' 9-5/8", 40-43.5#, N-80 & P-110 6501' 6477' Production 0'-6290' 7", 26~, N-80 0'-6290' 0'-6270' Liner 6290'-9898' 7", 29#, N-80 1750 sx 6290'-9898' 6270'-9593' Perforation depth: measured 9043'-9670' (9 Intervals) true vertical Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 EUE 8RD @ 0'-342' 2-7/8", 6/5#, N-80 EUE 8RD @ 342'-8961' Packers and SSSV (type and measured depth) Guiberson Uni-packer VII @ 8887', Otis SSSV @ 306' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) JUN 1 7 1992 Treatment description including volumes used and final pressure treatment canceled Alaska 0il & Gas Cons. CommiSsion Anchorage i 4. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments: MIT test form 16. Status of well classification as: Copies of Logs and Surveys run -- Oil X Gas Suspended__ Service Daily Report of Well Operations__ -- -- '~17. I hereby certity tl3at the loregoing ~s true and correct to the best ct my Knowledge ... Sig ned ('~_~ ~-.'- --J~~-' TRIo star f Production Engineer Date Form 10-404 Rev 06~15/88 SUBMIT IN DUPLICATE Shell Western E&P Inc. An affiliate of Shell Oil Company 61NAL 601 West Fifth Avenue Suite 800 Anchorage AK 99501 May 5, 1992 State of Alaska Alaska Oil & Gas Conservation Commission ATTN: Lonnie Smith 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Smith: SUBJECT: SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NO. A13-12RD Enclosed in triplicate is the application for Sundry Approval to perform a coiled tubing unit acid stimulation operation on MGS well A13-12RD. The workover is anticipated to begin on May 16, 1992. If you have any questions, please call Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, S. B. Brown-Maunder Sr. Environmental Technician Alaska Operations SBBM/PTH/dlw Enclosures SBBM~050592B.WP5 RECEIVED MAY - 7 1992 Alaska Oil & Gas Cons. Commission ~chorage ' ' ~- STATE OF ALASKA o,, oo s .w ,o 0 I G I Il L APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend~ Operation shutdown Re-enter suspended well Alter casing' Repair Well Plugging__ Tim'"'~ extension Stimulate X Change approved program Pull tubing Variance Perforate Other 5. Type ct Well: 6. Datum elevation (DF or KB) 2. Name of Operator Shell Western E&P Inc. Development X 116' DF feet , ..... 3. Address 601 West 5th 'Avenue, Suite 800 Exploratory 7. Unit or Property name Anchorage, AK 99501 Stratigraphic ~ Middle Ground Shoal Service 8. Well number 4. Location of well at Platform A, Leg 4, Conductor 29, 1561'N & 381'W of SE Corner of A13-12RD surface Sec. 11, T8N, R13W, SM 9. Permit number At top of productive 9043' (M.D.), 1288'N & 646'E of SE Corner of Sec. 11, T8N, R13W, .,.68-6-1-- 7)- ~' .o"- interval SM 10. APl number At effective depth 50-733-20191-00 9900' (M.D.), 1209'N & 707'E of SE Corner of Sec. 11, T8N, R13W, 11. Field/Pool At total depth SM MGS/"G" Pool 12. Present Well condition summary Total depth: measured 9900 feet Plugs (measured) true vertical 9595 feet Effective depth: measured 9809 feet Junk (measured) true vertical 9504 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1593' 13-3/8", 61#, J-55 1300 sx 1593' 1592' Intermediate 6501' 9-5/8", 40-43.5#, N-80 & P-110 6501' 6477' Production 0'-6290' 7", 26~, N-80 0'-6290' 0-6270' 6290'.9898' 7", 29#, N-80 1750 sx 6290'-9898' 6270'-9593' Perforation depth: measured 9043'-9670' (9 Intervals) RE¢£1V£D Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 EUE 8RD @ 0'-342' 2-7/8", 6/5#, N-80 EUE 8RD @ 342'-8961' - 7 1992 Packers and SSSV (type and measured depth) Guiberson Uni-packer VII @ 8887', Offs SSSV @ 3~tsk8 0JJ & GBS C011S, Cu0~t 'Anchorage ,, 13. Attachments Description summary of proposal X.~ Detailed operations program __ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation 05/16/92 16. If proposal was verbally approved Oil X__ Gas m Suspended Service Name of approver Date approved , 17. I hereby certify Ihat the foregoing is true and correct to the best of my knowledge Signed.(~_..o k....t ~ Title Staff Production Engineer Date ~" FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness ' JApprovai No. Plug integrity__ BOP Test__ Location clearanceJ . 7,,~_ / .22- Mechanical Integrity Test__ Subsequent form require--d 10- ~,o ~, :~:~?,c~,,,od Copy Approved by order of the C Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVALS FORM 10-403 ATTACHMENT DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL WELL NO. A13-12RD MGS A13-12RD has declined at an annual exponential decline rate of 20% since 1981. During 1991, the oil rate decline has increased to 38%. A 2.25" restriction in the tubing was observed at 8822' in June 1989 indicating possible scale build-up in the tubulars. The water cut has been in the 40-50% range since 1987. Experience with other MGS producers indicates potential scaling tendencies in this water cut range. The latest test was May 4, 1992 at 74 BPD Gross, 44% cut, and 41BOPD clean. Continued production of this well without remedial stimulation work will result in uneconomic production within 4 years. A 40 BOPD production increase is expected from successful stimulation of this well via coiled tubing unit. proposed Operations Summary 1. Fill wellbore via the annulus with Filtered Inlet Water (FIW). 2. Rig up Coiled Tubing Unit (CTU), acid treatment materials & equipment, and return fluid processing materials & equipment. 3. Clean out wellbore to PBTD with downhole motor and bit/mill assembly. 4. Acid treat via CTU with 5 to 7-1/2% hydrochloric (HC1) acid. 5. Neutralize all return fluids prior to sending to production facilities. 6. Return well to production via gas lift. RECEIVED MAY - ? 1992 Alaska Oil & Gas Cons. Commission Rnchorage Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 January 17, 1990 Alaska Oil and Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: CANCELLATION OF OUTSTANDING REPORT OF SUNDRY WELL OPERATIONS FOR MGS WELL NOS. A33-14, A12-12, A23-O1RD, A34-11, A34-14RDII, A44-11, A13-12RD AND C31-26 Enclosed are two copies of the Report of Sundry Well Operations for MGS well nos. A33-14, A12-12, A23-OIRD, A34-11, A34-14RD II, A44-11, A13-12RD and C31-26. These workovers were all cancelled and none of the work was performed. If you have any questions concerning these reports, please contact Susan Brown-Maunder at (907) 263-9613. Very truly yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/raf Enclosures SBBL/ao gcc. 011790 ~ _~ STATE OF ALASKA AL~I~KA OIL AND GAs CONSERVATION COMMI~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate __ Plugging Perforate 2. Name of Operator Pull tubing __ Alter casing Repair well Shell Western E&P Inc. 3. Address 601 West Fifth Avenue, Suite 810 Anghgraoe. AK 5. Type of Well: Development Exploratory Stratigraphic Service ORIGINAL OtherL CANCELLED 6. Datum elevation (DF or KB) 4. Location of well at surface Platform "A", Leg 4, Conductor 30 ~ 1561' N & 385' W from SE Corner of Section 11, TSN, R13W, S.M. At top of productive interval 9061' 3008'S and 1417'W from N.E. Corner of Sec. 14, T8N, R 13W, S.M. At effective depth At total depth 12. Present well condition summary Total depth: measured 9,900 ' feet Plugs (measured) true vertical feet 116' KB 7. Unit or Property name Middle Ground Shoal 8. Well number A1'~-19 1~13 9. Permit number/approval number 69-61 /9-319 10. APl number 50-- 733-20191-00 11. Field/Pool "G" Pool Effective depth: measured 9,809' feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 1593 ' 6501 ' 9898 ' measured 9043-9670 ' 9 Intervals true vertical Measured depth 13-3/8", 61#, J-55 1300 sx 1593' 9-5/8", 40-43.5#, N-80&P-110 6501' 7", 26 &29#, N-80 1750sx 9898' True vertical depth RECeiVED feet Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 Buttress @8,949' Packers and SSSV (type and measured depth) PBR set ~ 8,970' 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil x__ Gas __ Suspended __ Service 17. I hereby~c;~i_fy th.~ihe foregoing is true and correct to the best of my knowledge. Signed j' Jfl,,~J~l,~[ ~~L~~ Title D I V l S I ON 0PERAT 10NS MGR. Date 01/17/90 Form 10-404 Rev 06/15/88 SBBL/r swo o011590A1312RD/1 SUBMIT IN DUPLICATE Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 April 26, 1989 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen- SUBJECT: APPLICATION FOR SUNDRY APPROVAL FOR UPCOMING WORKOVER ON MIDDLE GROUND SHOAL (MGS) WELL A13-12RD Enclosed are three copies of the Application for Sundry Approval for the upcoming workover on MGS well A13-12RD. The workover will include per- forating two zones. These operations are expected to commence around May 20, 1989. If you have any questions concerning this application, please contact Susan Brown-Maunder at (907) 263-9613. Very truly yours, ~D' W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/hr Enclosures Alaska Oil & Gas Cons, Cc'mmissiOr~ Anchorage SBBI/asa.O42689a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Operation shutdown ~ Re-enter suspended well __ Plugging __ Time extension __ Stimulate ~ Pull tubing __ Variance ~ Perforate -.X- Other 2. Name of Operator 5. Type of Well: Shell Western E&P Inc. Development~_ Exploratory __ &Address 601 West Fifth Ave,, Suite 810 Stratigraphic__ Anchorage, Alaska 99501 Service__ 4. aLaL~ti~r~o.f~vzc~l~ts~rface PlatforC' A,1Leg 4, Conductor 29. ,6N6.22'S Trom center Leg . Center Leg I @ 1627 and 435'W from S.E. corner Sec. 11 T8N R13W At top of productive interval ' ' ' At effective depth At total depth 6. Datum elevation (DF or KB) 116' KB 7. Unit or Property name Middle 6round Shoal 8. Well number A13-12RD 9. Permit number 69-61 10. APl number 5O-- 733-20191-00 11. Field/Pool "G" Pool feet 12. Present well condition summary Total depth: measured true vertical 9,900 feet Plugs(measured) feet Effective depth: measured true vertical 9,809 feet Junk (measured) feet Casing Length Structural Conductor Surface 1593' Intermediate 6501' Production Liner 9898' Perforation depth: measured true vertical Size Cemented 13-3/8", 61#, ,]-55 9-5/8", 40-43.5#, N-80 & P-110 7", 26 & 29#, N-80 9043- 9670' 9 intervals Measured depth 1300SX 1593' 6501' 1750x 9898' True vertical depth REC EIVED Tub~n_gl(~i,~, gra e,,.,ap, d measured depth). , ~.',:i~, N-80 EUE 8RD 0-342' 2-7/8". 6.5#, N-80 EUE 8RD 342-8961' Packers and SSSV (type and measured depth) APR 2 7 ~ s~ gJl & Gas Cons, C~missior~ ,. , chorage 13. Attachments Description summary of proposal X Detailed operations program X BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: 20, 1989 16. If proposal was verbally approved Oil X Gas ~ Suspended Name of appro/vp.~ Date approved, Service . 17. I hereby, certify'th.at the foregoing is true and correct to the best of m. f knowledge. I , ,4 I / t"'1 ,,~ Signed J/J/~ Title Division Operations Manager FOR COMMISSION USEONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ ~.¢¢ Mechanical Integrity Test __ Subsequent form required 10- ..~pP~oved Copy Returned ORIGINAL SIGNED BY cZ/C-~ ~,z:~ Approved by order of the Commission LONNIE C. SMITH CommJssioner Form 10-403 Rev 06/15/88 IApproval No. Date '¢/¢-~2 ~:~ ~ SUBMIT IN TRIPLICATE P ROGNOS I S WELL MGS A-13-12 RD PERFORATE HR-HZ AND LOWER HE-HF STATUS: Well is gaslifting 160 B/D gross (92 BOPD) PROPOSAL: Perforate HR-HZ and HE-HF with 2-1/8" Atlas Wireline Services Silverjet MECHANICAL DETAILS: See attached Completion Equipment Detail Sheet PROCEDURE: 1. RU slickline unit. Test lubricator to 3500 psi. Pull ball valve. Make drift run to PBTD.~ Tag and record any fill. POOH and rig down slickline unit. 1 Rig up Atlas Wireline with lubricator and grease injection head. Pressure test lubricator to 3000 psi. RIH with Atlas 2-1/8" Silverjet, CCL and GR Gas lift well to test separator during perforating. . Perforate 9760'-9785' and 9743'-9751' and 9220'-9240' with Atlas Wireline's 2-1/8" Silverjet with 4JSPF. Gun to be positioned with magnet. Depths are referenced to Schlumberger DIL log dated 5/30/74. 4~ Take water cuts every two hours after perforating run. Be Have well shut in when tools are in the tubing going in or out of the hole. . Rig down AWS. Produce well for 12 hours then place in test separator for 12 hour test. e Rig up slick line unit. Install ball valve. Rig down slick line unit. Attachments RECOMMENDED: APPROVED' "~(3.- Y'J', ,,~ -od~'~~ DATE: DATE: REEEIVED APR 2 7 ~q ',/'//~'/,F ) :AJas~ ~Oil,& (~as Cons. Cc~missio~ ' ~ ~ ;Anchorage HAVS/041389b MGS A13-12 RD PERFORATE HR-HZ AND LOWER HE-HF COST ESTIMATE Set Up Perforating Surface Pressure Control First 10 Shots (3940) (.50) Next 202 shots (95 x 202) (.50) SUBTOTAL $2,250 88O 1,970 9,595 14,695 Transportation Slickline Unit Unforseen TOTAL 2,000 1,000 3,305 $21,000 HAVS/O41389a g 10 11 12 COMPLETION EQUIPMENT DETAIL SllEET MOS AI3-12RD 3/26/87 NO. AI*PROX 1 MATE TVD. MD. PSI OR 1. OTIS BALI, VALVE 2. REM OAS LIFT MANDREL #1 3. KBM GAS LIFT MANDREL 4. KBM 6AS LIFT MANDREl, 5. KBM OAS LIFT MANUREL #4 6. KBM OAS LIFT MANDREL 7. KBM GAS LIFT MANDREL #6 8. KEN OAS LIFT MANDREl. 9. KEN OAS LIFT MANDREL #8 10. GUIBERSON UNI-PACKER VII 11. OTIS 'X" NIPPLE 12. SEATING SUB 3QO 3O6 2071 2072 3752 3760 5088 5091 6125 6J40 6828 6891 7314 7445 ?597 7768 7846 8049 8602 8887 8644 8928 8676 8960 CASING ]3 3/8". 61#. ,I 55 ~ 1593' w/J300 sx 9 5/8". 40-43.5#, N-80 & P-Il0 0 6501' 7" 26#, N-BO ~ 0 - 6290* ....... 2~9#, N-80 ~ 6290-9898' #/1750 sX I'lrl'l) - 9809'~ TU = 9900' TUBING 3 1/2", 9.3#, N--80 EUE 8RD ~ 0 -- 342' 2 ?/8", 6.5#, N-80 EUE 8RD 0 342' - 8961' PERFORATED ZONE GROSS INTERVAL IIC-lll) 9043-9067* HC-HD 9076-9120' HE-IIF 9203-9217' HI-HK 9323-9365* IlK-liN 9394-9445* HK-IIN 9448-94~3' IlK-liN 94~4-9544' HN-IIR 9560-9590' HN-IlR 9640-9670' : I ! ( , HI" ' I ~ I~-t,t t' 0 P.I '1 .f t · i ! .i , · Ir- ' i--~ ...... ~-- I ! I. I · -- ' i ~ I · ~ I L ! --- ~ · ~ -'-; [-I · ~ '~:, I . z-I I~~ Z'~ ' ' ~ , [' I / [I . * - · . - .. ~ ~ ~ .I /~ - ~ , '~ 'd~ 1. I l, I i , ~' ~ ~ . ~ I l~ ' ' ,~ 1. ~ I J l,~ = ~' i i ~ I I l-I~ · ' ' , ~' I II I [ ~1~ m ~ ~n I ~ I I i I i: , - , ' i, 1. I 1,, I I~ : ' ~ [ s ~..~ _ / , , ' ' ~ I I I ~ m ~ , . · . ~ I m ~ i ~ I ' ' - .. ,,, ', / ' ' h = I.~ I, / ' ~ ~.l s ~ / I~ - , ;, , ~l I I I i~ I 'k~' I I I ! ] 1~] · i , ~ ~ I ~1 ! I / I~ ~ ~' ' l- ~ I I~ i I I _ ,, t ~ ' l~ ! ~ I / l~[ t , -~ ,-_.'- , ,,, ,::/ !~ L , , ~.. ~ ~ - i I ! / ~Bl ~ , ~ : , ' ~. 'T [ [,/ i~! I ] - ' , ] ,, ~ ] / I~1 ' · ' ~ ' ~-- I I Il I ~ ' ~ 1 ,, , ., -~, / t., -- : .~ · ! I I _ i/ : ~ Lt ' ~ i I L '-- ~ lit , ' " I I ~11 [ il ~ In~ ~ - ~ ~ ' I Al I I ! ] 11 I ' ( I LiS ]il /--- i ( I l[ ! I t I 1~ ......... - ' ;~ I ~! I i I 1~ = ~ ; -- , ~ I~I I~1 I~~-~-~'-~' ' ~ ~ I I I i~ I / , ' ~--~ I R I I I I~ ~ ' ' ~L-- ~ I I I I ~m s Il I II ! [ , II I ~ i L " I I I 11 I ,1 II I , - ~' -~ _ [ ~ n lv~l~l ..... ' ~ ~' ll.l~ ~t~ ..................... '-' ~ ~ I '! ' " t ~ ] · ~ I Ill ] PROOUCTION UNIT 860 IUNIT NRRE ! FIELD 6099 LEASE 9VO0~ IHIDOLE OROUNO SHOAL ) RE6ERVO]R OOtO0 (EAST FLRNK ~ ..... : ............... ,-. ........ =:_.=- . . .. _ .... . .... .. ~ . ....... ..~ ...... MIDDLE GROUND SHOAL HR-HZ ZONE BUBBLE MAP S.M.L. 02/8~ m _A23-OIRD ) Ao.o, '~) .A33-0! A32-11 · A,l~m ~A12-12 · A23-12 · :)5 . C LINE 27 SCALE 0 IOO0' 36 24' SHELL WESTERN E&P INC. P.O. BOX 527 SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HO .~.~LjT[~f. fEX~,l 8 f700, --- PLEASE REPLY TO ~NCHO~GE~ ALASKA 99502 ATTN: BETH CUZZORT HOUSTON, TX. 77001 Attention: LOG FILES, WCK 4147 Gentlemen: Enclosed are 1BL printsof the COMPLETION RECORD Company SHELL WESTERN E&P INC. , Well MGS A 1~'12 RD Field MIDDLE GROUND SHOAL ,'County KENAI · State ALASKA on: I Additional prints are being sent to: IBL nrints SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 " · _ ATTN: BRIAN TEPPER,WCK 1128 2BL nrints SHELL WESTERN E&P INC. 601W.FIFTH AVE;SUITE 810 ANCHORAGE, ALASKA 99501 ATTN' TIM PUTNAM 1MYLAR 1BL nrints ARCO ALASKA INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99501 ATTN: JOHN C. HAVARD 1RFOLDED SEPIA .............. · \ ....... tBL nrints STATE'OF ALASKA --~ ALASKA OIL & GAS CONSERVATION,~OMM. 3001 PORCUPINE DR. ANCHORAGE, ALASKA 9950t ATTN: H.W. KUGLER 1BL nrints SHELL r PLATFORM "A" OR "C" C/O SHELL KENAI OFFICE NORTH STAR ROUTE P.O. BOX 485 WIK RD. KENAI, ALASKA 99611 ~.prints 1RROLLED SEPIA ~r~[~s U.S.A. ,INC. P.O. BOX 107839 ANCHORAGE, ALASKA 99510 ATTN' J.L. WEAVER prints The film is RETURNED TO SHELL We appreciate the privilege of serving you. RECEIVED BY- DATE: ~ ~ ~~~. ~~ Ve~ truly yours, ~.~aska 0~ & Gas 'Cons. SCHLUMBERGER OFFSHORE 5ERVICESAn~°rage DAVID REBOL DISTRICT MANAGWR SHELL OIL COMPANY P.O. BOX 831 HOUSTON, TEXAS 77001 October 23, 1974 State of Alaska Division of Oil and Gas 3001 PorcupineDrive Anchorage, Alaska 99501 Gentlemen: Enclosed for'your information"are.the' comPleti°n data' for the Shell-Atlantic-standard MiddleGround Shoal wetl'A-13~12 redrill. Included"are the'following: EJV:ers 1.. CompletionRepOrt (form P-7) in duplicate; ' 2.. 'Well hiStory 3.' TwO Sepias and prints of all electric logs 14. Directional survey, VerY truly'yours, ~G~'T.'Karnes ]Division'Operations Engineer Western Division Attachments cc - Atlantic Richfield'ComPany Standard Oil company Amoco Production comPany United States GeologicalSurvey~ (w/attachments) OCT February 23, 1984 Shell Western E&P Inc. A Subsidiary of Shell Oil Company 200 N. Dairy Ashford P.O. Box 527 Houston, TX 77079 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Chatterton' Enclosed for your information are the following eleven reports submitted in duplicate' Middle Ground Shoal Field Well No. A12A-01 Monthly Report of Drilling Operations Sundry Notice-Subsequent Report of Perforations Well Completion Report & Stimulation Middle Ground Shoal Field Well No. C24-26RD Sundry Notice-Subsequent Report of Stimulation Middle Ground Shoal Field Well No. C34-26 Sundry Notice-Subsequent Report of Stimulation Middle Ground Shoal Field Well No. A13-12RD Sundry Notice-Subsequent Report of Stimulation Seal Island Wildcat Well BF-47#1 Monthly Report of Drilling Operations Sundry Notice-Subsequent Report of Perforations Sundry Notice-Subsequent Report of Abandonment Well Completion Report & Testing Seal Island Wildcat Well OCS Y-181 #1 Sundry Notice-Notice of Intention to Change Plans (in triplicate) Please maintain the confidentiality of this information. RGH 'mh Attachments R. G. Hollis Manager Production Administration Pacific Frontier Division "FEB 27'i984 ;~',;'i::: ,i:'~ _ i.:'; ;::,:h;];F~;'i; STATE OF ALASKA ALAsK';~"(~i L AND GAS CONSERVATION ~"~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Shell Nestern E&P, Inc. 3. Address 601 Nest 5th St., #810, Anchorage, AK 99504 4. Location of Well Conductor 29, Leg 4, Sec. 12, T8N, R13W, Platform A 12. 6. Lease Designation and Serial No. ADL 18754 7. Permit No. 73-35 8. APl Number 50- 733-20191-01 9. Unit or Lease Name HGS 10. Well Number A 13-12 RD 11. Field and Pool MGS "C" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation D[[X Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Proposal' Acid Stimulate 1/17/84 1/18/84 Rigged up coiled tubing and acid equipment. Ran in and spotted 1000 gal. xylene, 2000 gal HCL, 4000 Gal mud acid, and 1000 gal 10% HCL across perfs @ 9719-9043'. POOH Rigged down and RTP. 14. I hereby c, erlify that th.e/foregoing is true and correct to the best of my knowledge. Signed ~'/~ ~%J' ~''''~ Title Div Prod. Adm. Mclr, The space below for Commission use Date 2/9/84 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~__,,- STATE OF ALASKA :,,...,,~ ALASKA OIL AND GAS CONSERVATION CO-MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Shell Oil Company 73-35 3. Address 8. APl Number Wayne Simpson, 601 West 5th St., #810, Anchorage, AK 99501 5o- 733-20191-01 4. Location of Well Conductor 29, Leg 4, Sec. 12, T8N, R13W, Platform A 5. Elevation in feet (indicate KB, DF, etc.) 38' DF 6. Lease Designation and Serial No. APL 18754 9. Unit or Lease Name 10. Well Number A 13-12 RD 11. Field and Pool MGS "C" Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late )~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached. RECEIVED JAN 1 91984 Alaska Oil & Gas Cons, Commission ~chorage 14. I hereby c,¢~tify that/the foregoing is true and correct to the best of my knowledge. Signed Title Mgr. Prod. Adm. The space below for Commission use Date 1/4/84 Conditions of Approval, if any: IIRIGIIII~L SI611[9 it! tlllllll[ II. $111111 Approved by. COMMISSIONER Approved Copy Returned.~ By Order of the Commission Date /__ ]~ O '4~ ~_. Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Acid Stimulate A13-12 Rd Platform A Middle Ground Shoal Field Status' Well gas lifting 340 BDO, 11% cut. Mechanical Details' See attached schematic. Purpose' Acidize using coiled tubing. Procedure- le Rig up wireline. Test lubricator to 3500 psi'. Make drift run to bottom and record depth. P.O.O.H. and rig down. 2o Shut well in for 12 hours prior to acidizing. M.I.R.U. coiled tubing and acidizing equipment. Test lines, tree and coiled tubing to 5000 psi. Test hydraulic system and B.O.P. Test acid concentrations and compatibility according to acid test procedure. Filter all fluids through a 2 micron filter: o R.I.H. with coiled tubing while pumping diesel at minimum rate to 9,719'. Pump following acid treatment. Stage Fluid Volume I Xylene Solvent 1000 gal. 2 10% HC 1 2000 gal. 3 7½% 1½% HC1 HF 4000 gal. 4 10% HC1 . 1000 gal.. Pump treatment at ¼ Bbl per minute. Move coiled tubing across entire interval (9,719'-9,043') during each stage of acid treatment. 0 Displace acid to end of coil with diesel. Over displace by 5 Bbls to flush coil. P.O.O.H. Rig down. e Place well on production. Obtain good 12-hour production test after well cleans up. JAN 1 9 ]984 Alask~ Oil & Gas Cons. Oommis~iol~ DATUM 38' A 13.- COMPLETED Item No. · 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12 R.D. 4-13-77 Description ' Otis Ball Valve KBM G.L. Valve II II II II II II II II II II II II II II Guiberson Unipacker VII Otis X-Nipple Seating Sub M,O. .306 2072. 3760 5091 61~'0 6891 7445 7768 8049 8887 8928 8960 GN 7756 GO 7996 GR 8576 GS 8678 HC 9043 HO 9119 HE 9223 -- HF 9240 'HI 9373 HK 9392' HN 9554 HR 9719 PBTI) TD 9809 9900 CASING 7" 29# N-.80 to 9 5/8 to 6506 9809 ( Note .7" TUBING 1 i ner to 3 1/2" 9.2// N-80 EUE 8-'Rd to 342- 2 7/8" 6.5# N-80 EUE 8-Rd to 8961 · . PERFORATIONS HC/HD1 HC/HD2 HE/HF HI/HK HK/HN1 HK/HN2 . HC/HD 904 907 920 932 939 946 939 907 904 907 956 HN/HR REPERFORATIONS' DOD 3-9063 7-9117 6-9220 5-9365 8-9445 4-9535 4-9544 6-9120 5-9067 6-9098 2-9723 9047-9067 9080-9120J 9401-9448. ~ 9467-9527J 9563-9593J 9643-9673..j Page 52 HC/HD HK/HN HN/HR surface) · (20') (40') (14') (4o') (47) (71) (150) (44') (22) 4JPF Reperf. 6/81 Reperf. 6/81 New 6/81 Reperf. 6/81 Reperf.. 6/81 New 4/17/77 Reperf. 4/18/77 · Reperf. 4/20/77- 9/28/ JAN 1 9 ]984. 8/82, 4 JPF, 8OO 7OO 600 500 400 2( WELL 1,.5-12 PLATFORM A Legend GROSS CLEAN 1982 1985 WESTERN E&P OPERATIONS I~IDDLE GROUND SHOAL FIELD I SHELL-ATLANTIC-STANDARD . ! / ! · I.IIii J I I PaP$$ INJECTION WELL PRODUCING WELL POS 11449 APL 11756 5128k. .+ P.A. PLUGGED & ASND. 0 4000 SCALE IN FT.' J~ E C E i V E j) · w-oo~o~ JAN 1 9 ]984 Naska Oil & 6as Cons. Commission Anchorage ) L o ,,u ,,u l~' W. F. SIMPSON SUNDRY NOTICES AND REPORT- ON WELLS DRILLING WELL [] COMPLETED WELLjJ~( OTHER [] 2. Name of Operator 7. Permit No. Shell Oi'l Company, 73-35 3. Address ........ .- 8. APl Number John Douglas, P,O. BoX 45'00, K.'enai:', AK 99611 .... so- 733-20191-01 4. Location of Well .. Conductor 29, Leg 4, Sec. 12, T8~I', R131~; Platform A 5. Elevation in feet (indicate KB, DF, etc.) 38' D.F. 12. I 6 . Lease Designation and Serial No. ADL ][87 54 :"' 9. Unit or Lease Name 10. Well Number g23-12RD 11. Field and Poo~ Mi'ddle Ground Shoal '.'C" Pool Check Appropriate Box To Indicate Nature Of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) {Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing · [] Stimulate [] Abandon [] Stimulation E~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC ;25.105-170). Status: Nell gas !i'f, ti~? 300 BDO (9% cut)_ from the HC-HR zones. Proposal' Acifli'ze production .members wi'th coiled tubing. 5/4/83 Ri~jged up and pressure tested coil tbg, BOP stack, & Dowell.lines to 5000 PSI. RIH with coi'l tbg to 9710". Began pumping P-20 solvent 24 BBLS @ ¼ BPM @ 4000 PSt', followed by-24 BBLS 10% HCL @ ¼ BPM @ 4000 PSI', followed by 48 BBLS 7½ - 1½% HCL-HF @ ¼ BPM. @ 4000 PSI', followed by 24 BBLS 10% HCL @ ~ BPM @ 4000 PSI[, followed by 15 BBLS diesel flush. POOH and started riggine down. Started to bring well back on production slowly on a 12/64" choke~/~ 14. I hereby certify that th/e foregoing is true and correct to the best of my knowledge. S,gned . /<4~ Title ,~r., .P-r0d, Adm., The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA'l::71~ AND GAS CONSERVATION ~'~'~'~MISSION .SUNDRY NOTICES' AND, REPORTS ON WELLS.. DRILLING WELL [] COMPLETED WELL~ OTHER 2. Name of Operator She] 1 0il Company 3. Address John Douglas, P.O. Box 4500, Kenai, AK 9.9611 4. Location of Well Conductor 29, Leg 4, Sec. 12, T8N, R13W, Platform A 5. Eleva~ior~ in feet (indicate KB, DF, etc.) 38 D.F. 6. Lease Designation and Serial No. ADL 18754 7. Permit No. so- 7 3 3 ~2-~-=-i~ 9. Unit or Lease Name HGS 10. Well Number A13-12RD I 1. Field and Pool MIDDLE GROUND SHOAL "C" POOL 12. Check Appropriate Box T~) Indicate Nature of Notice, Report','or'Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [-'] Alter Casing [] Perforations Stimulate ~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [-] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) SUBSEQUENT REPORT OF: (submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20,AAC 25.105-170). See Attached 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date .4/!9/83 Conditions of Approval, if any: ORIGiNAl. SIGNEI '" BY LOflNIE C. SltllTll Approved by. COMMISSION ER .Approved Copy Returned By Order of the Commission Submit ;'Intentions" in Triplicate Form 10-403 I~n~/ ?.1 ~ ........... i ii ii ~ PRODUCTION PACIFIC FRONTIER DIV. [ · HOUSTON i i 11 i,, ~ i , 11 i~ , , 11 i i , , A13-12 R.D. P1 atform "A" · Middle Ground Shoal Field 4/19/83 Kenai. Alaska ~oea,~oN NU~et, I I I I I III III lift II ffi I I II I I I I I SHELL'S % SHARE O~OE~ ~ OESCRI~ON ................... -- .. mmm mm m m I I [ I l . .. R&R Acidize using coiled tubing $38,000 ' $12,700 · $12.700 . , . . . . . . . Requested by- J.H. Douglas T.S. Burns . . . · . . . ~ . . . . . .. . . . ~ . . . . t · ~u.-,o**~ $3~,09,9 'Sl 2,7~0 Sj 2,7Q,9 gUOG~ AVI 8L~ IN BUDG~ IREMENT ............ ~S,,tON. I ,~w c~,,a~ ~UNOS ~U,.~O ,~ ,UOa~ a~V,S,ON I '"' ~ :- ,, ,, ~ $1 2._700 I , I I I IIII III J I I .,, III I&;I II II I . See a~tached dus~f~cat~on. . .. . . . .. : . . ~ONTINU(D " ' ~ k~ .... I .......... '~(C08~ NO AP~OV A~ .... ...... ....... A 13-12 R.D. JUSTIFICATION COILED TUBING ACIDIZATIONS Funds totalling $38,000 ($12,700 Shell's 1/3 share) are requested to place acid with coiled tubing in well A 13-12, Platform "A", Middle Ground Shoal Field. The economics are as follows: Shel 1 Net Total Gross Expenditure Oil Increase (BDO) P.V.P.A.T. @ 14% % P.V.P.A.T. Pay Out (Months) $ 12,700 $ 38,000 33 100 $235,000. $705,000 1855 1855 2 2 Well A 13-12 Rd was redrilled in July 1974. Initial production from the well was only 432 BDO (0.3% cut). Production declined exponentially at 34%/yr until 1977 when the well was reperforated. Production increased to a rate of 650 BDO (1% cut).but declined rapidly at 28% per year. In 1981, A13-12 Rd was again reperforated and production increased to 540 BDO (9% cut) with a subsequent decline rate...of 32%/year. In 1982, A 13-12 Rd was again reperforated for a third time. Production increased from 347 BDO (10% cut) to 415 BDO (11% cut). Production declined very rapidly (56%/yr) to the current rate of 308 BDO (9% cut). A 13-12 is a prime candidate .for coiled tubing acidization. It has been proven that near wellbore formation impairment is continually occurring in this well. Little water breakthrough has occurred, therefore the possibility of increasing the water production will be small. A 13-12 is completed with one packer and it will be possible to acidize all producing zones maximizing the potential production increase. If a production increase is realized and the rate again decreased .at a rapid rate, an attempt will be made to lessen the decline rate by acidizing with a clay stabilizing acid and/or scale inhibitor. Based on previous reperforation his%ory, a 100 BDO increase is expected. Your approval is recommended. TSB:mh COILED TUBING ACID STIMULATION A 13-12 R.D. W.H. ROOM #4 CONDUCTOR #29 MIDDLE GROUND SHOAL FIELD KENAI, ALASKA Status: Well gas lifting 300 BDO (9% cut) from the HC through HR zones. Mechanical Details: See Attached Schematic Purpose: Acidize production members with coiled tubing. Procedure: ® M.I.R.U. wireline and lubricator. Test lubricator to 3000 psi. Pull ball valve. e R.I.H. with gauge run. Clean out tubing as necessary to bottom. Tag and record bottom (tagged bottom at 9710', 9/82) P.O.O.H. Rig down wireline. e M.I.R.U. coiled tubing and Dowell acidizing equipment.'I Test lines, tree, and coiled tubing to 5000 psi. Test hydraulic system and B.O.P Place well on test separator and monitor production closely through out operation. With well flowing, open swab valve and pump diesel at 1/8-1/16 bbl/min. Be prepared to choke pump outflow line if the equipment will not pump at a slow rate. Note: Filter all fluids through a 2 micron filter placed immediately before' coiled tubing. · R.I.H. with coiled tubing (no more than 100 FPM). If well's production interferes with coiled tubing, choke well back at surface. Note: Do not pump down coiled tubing at a rate faster than the returns and pr. oduction rates out the flowline. Attempt to maintain flowing well conditions at all times. An increase in injection gas may be necessary to keep the well f~o~],QA~d.~r~q~_.up. AI~,~:!~,~ Oi~ & Gas Cons, Com:.,qjs:;ia;-~ An-~hora§e 6. Tag bottom and record depth. Shut.well in at'-surface and" '~' allow well to build up and stabilize. 'Maintain' 1000 psi casing pressure. With the coiled tubing on bottom, pump 1000 gallons (24 bbls) P-20 solvent down coiled tubing at 1/4 bbl/min. Move coil uphole to' treat entire interval (9710'-9043'). e With coiled tubing on bottom, pump 1000 gal. ('24 bbls) 10% HC1 with additives down coiled tubing at 1/4 bbl/min. Move coiled tubing uphole to treat entire interval (9710'-9043'). ® · With coiled tubing on bottom, pump 2000 ga~ (48 bbls) 7½%-1½% HCl-HF acid with additives at 1/4 bbl/min. Move'coiled tubing uphole to treat the entire interval (9710'-9043'). . With coiled tubing on bottom, pump 1000 gal (24 bbls) 10% HC1 with additives at 1/4 bbl/min. Move coil tubing uphole to treat entire interval (9710'-9043'). 10. Displace acid to end of tubing with diesel and pump ~an additional 5 bbls of diesel to flush coil. P.O.O.H. with coiled tubing. 11. Bring well on production on a 12/64".choke. Monitor. acidity of produced fluids. Increase choke size every 4'-hours and record production rates hourly. When tubing pressure reaches separator pressure, open choke to 128/64", take well off test separator, but test daily until stable. TSB 'm~ Approved~.~ Date Coil ed..Tubing Specifications Working Depth (1.255 S.F.) Max. Working Pressure Tensile Strength Tubing O.D. Tubing I.D. Wall Thickness Capacity Tubing Weight 16,500' 5,000 psi 15,300 lbs 1.00 in. 0.850 in. 0.075 in. 0.702 bbls/lO00 ft. ' 29.48 gal/lO00 ft. 0.63 lbs/ft. Cost Estimate A13-12 Coiled Tubing Acidization le 2. 3. 4. 5. 6. 7. 8. 9. 10. 1000 gal P-20 2000 gal 10% HC1 Acid Additives 2000 gal .7-1/2%,1-1/2% HCl-HF Pump 1-1/2 days Tanks 1-1/2 days Lines 1-1/2 days Personnel 1-1/2 days Coiled Tubing @ $5000/day Miscellaneous Total 4,500 2,000 2,400 4,000 3,000 1,200 2,500 5,500 7,500 2,000 $'34,600 Add 10% Contingencies Say Acid Additives Composition $38,000 0.3% 0.4% 10% HC1 (H~droch l'o'ri c Acid) W-35 (antisl udge) F-75N (surfactant) 14 lbs/lO00 gal L-41 (iron sequestering agent) 1.2% A-200 (inhibitor) 7-1/2% - 1'1/2% HCl-HF (Mud Acid) 0.'4% W-35 (antisl udge) 0.4% F-75N (surfactant) 14 lbs/lO00 gal L-41 (iron sequestering agent) 0.8% A-200 (inhibitor) DATUM 3 8 ' COMPLETED Item -No. e 2. 3. 4. 5. 6. 7. 8. 9. 10. · 11. Otis Ball Valve KBM G.L.~ Valve I1 !t , II I1 II II II II Ii II II II II II Guiberson Unipacker VII. Otis X-Nipple Seating Sub .3o ; · 2072. 3760 5091 6140 6891 7445 7758 8049 · 8887 8928 8960 GN GO GR .GS HC HO HE HF · H I HK HN HR 7756 7996 · 8576 8678 9043 9119 9223 9240 9373 9392 9554 9719 PBTD CASING 7" 29# N-.80 to 9 5/8 to 6506 TUBING 9809 (Note 7" liner to 3 1/2" 9.2# N-80 2.-7/8" 6.5# N-80 PERFORATIONS HC/HD1 HC/HD2 HE/HF HI/HK HK/HN1 HK/HN HC/HD HN/HR 9043-9063 9077-91.17 9206'-9220 9325-9365 9398'-9445 9464-95'35 9394-9544 9076-9120 9045-9067 9O76-9098 9562-9723 REPERFORATIONS- HC/HD 9047.-9067- . . 9080'9120 HK/HN . 9401-9448. 9467-9527 HN/HR 9563-9593 9643-9673 · 9809 DOD oo~n ...... Pinna iq9 EUE 8-Rd to 342. EUE 8-Rd to 8961 surface) (20') (4o') (14') (4o') (47) (71) (150) (44') (22) 4JPF Reperf, 6/81 Reperf, 6/81 New 6/81 Re.perf, 6/81 Reperf.. 6/81 New 4/1 7/77 Reperf. 4/1 Reperf. 4/2 10/1/77 & 1 9/28/77.. 8/77 0/77 o/21/; 8/82, 4 JPF, 90o, 19.gm~ PRODUC[ION UNI[ 650 (UNIT NAME) fIELD 5099 (fllD.OR.5!IOAL) LEASE 9700'1 (fliA.Off.EIIL~RDL 187511 RESERVOIR 00100 (~ENAI ZONE - HELL 66026.1A 13-T21 PIPING DIAGRAM CO I LE~ TUB I NG C:LEANOUT AND AC:I Iz:I ZAT~ A 1._-,- 12, '* A 43-11, C3: 1-2 A_ 10% HC:L O. 3% W-35 O. 4% F-75N 25 LBS:/1000 G L-41 1.2% A-200 7 1/2%-I 1/2% O. 4% W-35 O. 4% F-75N 25 LBS/lO00 G. 0 .~'t . o,. A- 200 ii HC:L-HF L-41 · F'-20 SOLVENT _ _ , , i __ , l D I ESEL , · INJECTION WATER FROM WATER PLANT CHOKE M A N I FO L Eh4 ( IF NECES:SARY) PLIMP J. I ~ "' t,k~),xl'2 MZ CRON FLOWLINE TO TEST SEF'ERATOR !" TUBiNA 11 '1 HF. AD I .A~':cbora§e WESTERN E&P OPERATIONS' UIDDLE GROUND SHOAL. FIELD SHELl?ATLANTIC'STANDARD I ,, ,, ,.,,.,, TgN ........ IDL !17S4 PATTERN i i · · iii ii i ]~ _ ] i ' tilL49 IS7Sf .~]20 Ac. dip IS. 1 -I- P~1~$$ iiii . . INJECTION WELL. ' ' · PRODUCING WELL -~P.A. PLUGGED & AI3ND. 0 4000 · SCALE IN FT. · MAY 0,~ ~~ii' & Gas C~,,o.'~','~' Ar:chora~o STATE OF ALASKA ALASKA~ AND GAS CONSERVATION Ct:~,..,A41SSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL E3 COMPLETED WELL [~X OTHER [] 2. l'~rne of Operator Shell Oil Company 3. Address 601 W. 5th Ave. #810, Anchorage, AK 4. Location of Well Surface: Conductor 29, Leg 4 Sec. 12, T8N, R13N Platform A 5. Elevation in feet (indicate KB, DF, etc.) 38' D.F. 12. I 6 . Lease Designation and Serial No. ADL 18754 7. Permit No. .- 8. APl Number so- 73 3--~t70~31~=t- 9. Unit or Lease Name Middle Ground Shoal 10. Well Number A 13-12RD 11. Field and Pool Middle Ground Shoal "C" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate I-'l Alter Casing [] ~ Perforations ~ Altering Casing I-I Stimulate r"] Abandon [] Stimulation [] Abandonment D Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing r-I Other [] Pulling Tubing [] {Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached. 'RECEIVED SEP 2 ]982 Alaska 0it & ~a~ Cons, Commt.lon Anohorage 14. I hereby certify that th/e foregoing is tr~..e and correct to the best of my knowledge. s,g.eu ?~' ~ Tit,e Production Administration The space below for Commission use Date ' 9 / 14/82 ~ Conditions of Approval, if any; By Order of Apprcved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1.80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~ECOMPLETI'ON R ~:'~P"O R T . . A 13-12RD c.....~. Shel 10i 1 Company ~.~ Middle Ground Shoal ~,.,~.~ o,,,, 8/31/82'., - , · .,o-.,,,~. e,. 9/'5/82 38' D.F. 9900' ~rker Hot:izo'rm -- ! · __ _ 9809' D eF'~h ~odudion Data Initial Production . _ _ -- _ .~'~=".*' , °U, nchagg~d ..... ! · · .]aL -- ,,1 , , ~ iiii i i ii ii 9.043'/.9723', at inter..v, al s. 9.5/8 :.,:,.~ 7 _ _ 3½ - tub~.n9 ,, . 2 ~/8 6506' · 9809' _ ~ 342' - ~ 8961' ' ~ 9043 ~L/906~.' .... 9077'/9~17' 9203'/9217' ........ "93~5'/926'b' ' " 9398'/9445' 9464'/953b' 9045'/9067' '9076~/9'0~8, · .. 9560'/9/23' _ 9394'/9544' : 90.7.6 '/9.1,,20' ...... Ad~tl. Pr~. DaN Calcul~ed Po~ential -- -- m n i m n , i il Reperforated }IN/}IR and HK/ttN. 'Fished 31' of gun that fell in-hole· Reperforated tIC/HD zone. All reperforations as per worksheet _ Middle Ground Sh.o~l A i i il iii I ' '- · K.enair AK .8/31/87 o/q/~9 _ .Sec' 12, T8N, R13W _ I IIII II I I ii j I II I I I II I II I I STATUS- Well gas lifting 360 BDO'(~%. cut). PROPOSAL. Reperforate HC/HD, HI/HK, HK/HN and HN/HR zones 'to improVe inflow and increase production, 8/31/82 Dresser Atlas over to perf. A 13-12RD. Rigged up. 9/1/82 Continued on reperforation of A 13-12RD. No apparent increase after shooting HN/IlR (60') started on HK/HN (will be 107').. 9/2/82 Continued on reperforat'ion of A 13-12RD. Picked up lubricator and broke first gun. Ma.de repair but could not get down through tree. Pulled out to take a look and 31' of gun fell down the well. · 9/3/82 WirelTne operator rigged up on well. Operator tagged bottom and picked up'about 31' and brought all of fish out of hole. · 9/4/82 Ran in hole and began reper, forating HCa. HD.' 9/6/82 Finished reperforating HC/HD. Decision was made not tO~reperforate HI/HK. RTP. · RECEIVED · SEP ]982 , Al~ka 011 & Gas Cons. Commission Anchorage __ _ I ~ I I I I I I II ...I .,.I I~_11 · ~. ' ' STATE OF ALASKA i ~>~-~ ALASKA~TrL"AND GAS CONSERVATION C~ISSION SUNDRY NOTICES AND REPORTS ON WELLS 2. Name of Operator Shel 1 Oil 3. Address P. 0. Box 527, Houston,,, Te,xas, 77001 4. Location of Well Surface- Conductor 29, Leg 4 Sec. 12, T8N, R13W Platform A Company 8. APl Number 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial No. 38' D.F. i ADL 18754 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 9. Unit or Lease Name Middle Ground Shoal 10. Well Number A-13-12RD 11. Field and Pool Middle Ground Shoal "C" Pool NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate I~] Alter Casing r-] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Welt [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached. Plan to start activities on 8/30/82. RECEIVED Alaska 0ii & Gas Cons. Commission Anchorage herebye 14.1 'y g ' g' o Signed,. . Title Production Su_erintendentp Date 8/27/82 The space below for Commission use Conditions of Approval, if any: Approved Copy Returned BV Order of Approved by COMMISSIONER the Commission Date.__ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate HIDDLE GROUND SHOAL F!£LD, ALASKA RFPERFORAT]ON S/A/US; Well 9as lifting 360 BDO (9% cut). TD.' 9900', PB?D: 98094 (with top of perforating gun fish at 9772'). MECHANICAL DETAILS: See attached schematic. PROPOSAl.: Reperforate HC/HDo HI/HK, HK/HN and HN/HR zones'to'. improve inflow and increase production_ PROCEDURE: 1. MIRU Dresser Atlas with lubricator and grease (nJect(on head. Pressure test lubricator to 3000 psi. 2, Perforate selected intervals with 4 holes per foot using a 2-1/t6" RSg(d Jet gun loaded with lg gm charges (90° phased) and positioned with a magnet at the bottom of the gun assembly. Depths referenced tO Schlumberger OIL survey dated 5/30/14 (roE, crt these de~ths) and Schlumberger CBL/GR/CCL survey dated 6/7/7~Z - - SEQUENCE ZONE DIL DEPTHS CBL/GR/CCL DEPTHS* 1 HN/HR gS60Ig59D 9563/9593 9~019670 9643/9673 ~ HK/HN 9464/9524'~ 946~/9527 939B/9445~ 9401/9448 3 HC/HD 9072~9117~ 9080/9t20 9~3/9063~ 9047/9067 4 HI/HK 9325/9365~ 9328/9368 *Casing Collars: 8948.5', 8989', 9030', 9073.5', 9113.5', 9155.5', 9199', 9242', g283.5', 932~.§', 936~.§', 9407.5', 9441.§', 9489', 9529.5', 9569.5', 9610', and 9696.5'. (All collars are CBL/GR/CCL depths). Note: Reperforate HI/HK zone last. The ~tl/HK zone is felt to be Q£C£1VED marginally risky to reperforate due to possible excessive water production. The zone should Only be reperforated if incremental response from the other zones are insufficient. AUG 2 ? )982 Consult with T. S, Burns-Houston after th~ HC/HD zone Oi~ & Ga~ Cons. Oomml~ repe~orated. AnchoraBe 3. Keep w~ll "gas lifted down" while perforating. Establish inflow rate with 12, hour (or u(~tll rate stabili)es) flow m test after perforating each zone, i.e., HN/HR, HK/HN, HI/Hr and HE/HD. Send these rates to 1. S. Bums, Houston. 5~ Rig down Dresser Atlas, DATUH 38' I · GN 7750 · GO ? 996 GR 8576 GS 8678 Hg 9043 - HO 9119 _, - HE 9223 : H~ 9240 ~- HI 9373 -= HK 9392 ~ HN 9554 ~ TD 9900 A 13- 1~ R.6. ' COMPLE. TED 4-13-77 Item No. pescript(on Otis Ball'Valve ' 306 1- F, BM I~.L. Valve 2072 2- " " 3760 3. " " 5091 1 II II - 6140 5, " " 6 8 9 6- " 7. " " 7768 8. g- Guiberson Untpacker VII 8887 lC. Otis X-Nipple - 8928 ll. Seating Sub 8960 · CAS I NG · 7" .~9~ N-80 to 9809 9 S/Otto 6506 (Note 7" liner to surface) HC/HD1 HC/HD2 HI/HK HK/HN1 HY,/HN2 H¢/HD HR/HR TUB 1NG 3 1/2" 9.2~ N-80 EUE 8-Rd to 342 2.7/8" 6.5~ N-80 EuE 8-Rd to 8961 · PER FORAT I ORS 90,3-9063 (20') .9077-91 t7 (40') ' 932~-9365 (40') 9398-94~5 (47) 946e,--9535 (71) ' 9394-9544 150) .- New 4~17-77 9076-9120 44') Reperf 4-18-77 9045-9067 22) Reperf 4-20-77 9076-9098 10-1-77 & !0-21~77 9562-9723 -(IJPF 9-28-77 DOD Pege 52 Alaska Oil & Gas Cons. Anchorage C°rnmis~ion '...r.:.1-- ;:'Ir'. · :~.-': H';.;,, · t! ,1: :*. !"7 I~I~. ~.- o ! 4~tl L · : r.:-, AUG 2 ? 1982 alaska Oil & Gas Cons. Commission Anchorage · WESTERt~ £&P OPEP' T,~ONS Page 3 Alaska Oil & Gas Cons. Commission , /Anchorage 1 I I ! ! 't 1 · 0 4000 'SCAt r IN FT., "'1 b iAI I: Ui- ALASI~A ALASKA '~IL AND GAS CONSERVATION C' 'MMISSION SURDRY ,. TICES AND REPORi" . ON WELLS DRILLING WELL n COMPLETED WELL OTHER 2. Name of Operator 3. Address 4. Location of Well Surface: SHELL OIL COMPANY' P.O. Box 92047 Worldway center, Los Angeles 90009 Conductor 29, Leg 4 Section 12, T8N, R13W Platform A 5. Elevation in feet (indicate KB, DF, etc.) i 6 . Lease Designation and Serial No. ADL 18754 7. Permit No. 8. APl Number / 9. Unit or Lease Name Middle Ground Shoal 10. Well Number , A-] 3-] 2ED 11. Field and Pool Middle Ground Shoal "C" Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Ot.~rData NOTICE OF INTENTION TO: SUB~zO'UENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate E] Alter Casing Fl Perforations III Altering Casing Stimulate [] Abandon Fl Stimulation [] Abandonment Repair Well D Change Plans E] Repairs Made [] Other Puli Tubing [] Other [] ' Pulling Tubing D (Note: Report multiple completions on Form 10-407 with a submitted'Form 10-407 for each completion.) ' 0 .0 0 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work. for Abandonment see 20 AAC 25.105-170). · Please see attached RECEIVED, OCT 2 I 8! A/aska 0il & Gas Cons. Commission Anchorage 14. I hereby certify t_ha~/the for,~going is true an~l correct to the best of my knowledge. s~g,,~ ~ Ti,,e Manager Production Administrat~g/~ /~-/~_ The space below for Commission ule for B. Nevil 1 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-14~0 Submit "Intentions" ~n Tfsphcate and "Subsequent Reports" in Duphca~e SHELL OIL COMPANY WELL R. ECOMPLETION REPORT A-13-12RD SHELL OIL COMPANY lira ~~ UnChanged i! im I mi i i i i MIDDLE GROUND SHOAL !!,urtimq., Oatt. 6-1-81 iii ,¢omalefi,on _~rker Horizons · i 6-11-81 . 38' D.F. · . 9900 9809 q- Depth il m imm i · ii i II II · _ -- mi · ~oduction Data ~ ~I~ ~1~ ......... ~'~t~ °~ ~. L i i i · i i mi '1 nltlai Production ,w.[.o.@ i n · _ 9043'/9723' ~~d ~ 6506' i, i ~=,~d ~ 9809' 3 l/2"tubina 9'2# ~ -. ~ 342' 2:,,7/8-~,S 6.5# ,,,~ . .. ~ ,8961,', · , i ill i : , ii i m i i ] .... 904,3 "/9063'. 9045,'/906'7, '" 9077'/9117' . ,9076'/9098' 9203'/9217' 9562'/9723" ' ' ' 9325"/9365' .... ..... 9'398'/9445' ............ ...... 9464'/9535' ....... ~ 9394',1/9544, I I ~U/b'/~ITU' .... _ i i ii i ,111 i i i L .Adotl. Prod. Da~ Calculated Potential. mm __ 1[ i i i i _ __ il n i I i i iii i _ i i L ~~ PerforatedoHE/HF zone and reperforated HC/HD~ HI/HK, and HK/HN zones. , · OCT Oil & Gas Cons. Commission Anchorage MIDDLE GROUND SHOAL II I I II · KENIA, ALASKA 6-1-81 6-11-81 A-13-12RD Section. 12~ T8N, R13W · i _ II i mm mi ii Il I m I I .... II I ' STATUS' Well gas lifting 140-+1 BDO (cut' l'%'frJm H'C/HD',' HI/Hk, HK/~' and HN/H~( zones PROPOSAL' Perforate HE/HF and 'reperforate HC/HD, HI/HK' AND HK/HN zones to improve inflow and' increase '.~roduction. · · ! 6-,1-81 Dresser Atlas perforated 14' H[/HF[9203-9217) ~Ik depth .. ~PF zero phased 6_7,81 Dresser Atlas'reperorated HK/HN (946~-9535) & (9398-9445). , DIL 4 ~PF zero phased 6-1.0'81 Dresser Atlas .reperorated HI/HK (9323~9365) DIL depth' 4~PF zero phased. 6-11-81 - . ~resser gt-las .reperorated HC/HD .{9077-9117) ~ {9043-9063) ~Ik depth 4~[ zero phased. .... , . . . . . - ' RECEIVED ' OCT 2 ~ · 'Naska Oil & Gas Cons; Commission ~ ~chorage I I I I I .... ~ I II III I III ~~ I1 m m m imm m ia STATE OF ALASKA ALASKA ,, , AND GAS CONSERVATION CC~vIISSION SUNDRY I TICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Shell Oil Company 3. Address P.O. Box 92047 Worldwa¥ Center, Los Angeles, CA 90009 4. Location of Well Surface: Conductor 29, Leg 4 Section 12, T8N, R13W Platform A 7. Permit No. 8. APl Number 9. Unit or Lease Name Niddle Ground Shoal 10. Well Number A-13-12RD 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. Middle Ground Shoal ! ADL 18754 "C" Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other I--] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) [] 0 [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See attached. JUN. ~laska 0ii & Qa~ Ancho tuns. rage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,-~, ~'~' /~'~~~ Title_ M~r. Product ion Adminis trat Jet, ate The space below for Commission use For: m. Nevill 5/29/8l Conditions of Approval, if any: Approved Copy Returned BY LI)NNIE C. SMiIti B,,,O,~er Of Approved by COMMISSIONER the Commission ~Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SAS MGS A13-12 RD "'gDLE GROUND SH.OAL FI ELD, ALAS 'v REPERFORATI ON WORKSHEET STATUS' Well gas lifting 140+ BDO (cut 1%) from HC/HD, HI/HK, HK/HN and HN/HR zones. TD' 9900'. PBTD' 9809' (with top of perforating gun fish at 9772'). MECHANICAL DETAILS' See attached schematic. . PROPOSAL' Perforate HE/HF zone and reperforate HC/HD, HI/HK and HK/HN zones to improve inflow and increase production. · PROCEDURE' 1. MIRU Dresser Atlas with lubricator and grease injection head. Pressure test lubricator to 3000 psi. 2~ Perforate selected intervals with 4 holes per foot using a 2.6" Slim Kone steel hollow carrier gun loaded with 12.5 gm Golden Jet charges (zero phased) and positioned with a magnet at the bottom of the gun assembly. Depths referenced to Schlumberger DIL survey dated 5/30/74 (report these depths) and Schlumberger CBL/GR/CCL survey dated 6/7/74. SEQUENCE ZONE DIL DEPTHS CBL/GR/CCL DEPTHS* 1 HE/HF 9203/9217 9206/9220 2 HK/HN 9464/9535 9467/9538 9398/9445 9401/9448 3 HI/HK 9323/9365 9326/9368 4 HC/HD 9077/9117 9081/9121 9043/9063 9047/9067 *Casing Collars: 8948.5', 8989', 9030', 9073.5', 9113.5', 9155.5', 9199', 9242', 9283.5', 9325.5', 9367.5', 9407.5', 9447.5', 9489', 9529.5', 9569.5', and 9610'. (All collars are £BL/GR/CCL depths). 3. Keep well "gas.liFted down" while perforating. me 0 Establish inflow rate with 12+ hour (or until rate stabilizes) flow test after perforating each zone, i.e., HE/HF, HK/HN, HI/HK and HC/HD. Send these rates to K. J. Evans and J. R. McGregor, Houston. .. Rig down Dresser Atlas. KjE-ckv APPROVED V . ~J, ,'~, JUN - 3 ]98i Alaska Oil & Ga~ Co.s. CommiSsior~ Anchorage 9373 969~. · Pa ge 6)2 JUN --T1981 0/77 PDS 18449 ADL SIlO IPB$ 1144l IlL 187S4 · · ... 7 · Jgtq .- ~ ~ka Oil & .~as Cons. Commission Anchorago .. I~AL I POS 1844g ADL II 151~ 1144l ~ :.,- -'.: ::-.~:.! I ,?/ --' '~.. ',.~ l '~' -' I I , ,;.-,,, '-.t~. - :: ;! T/_~ :~i+~. , I:'-.-(,?~., : 'fl'' t J.-'i.:---'?-L;::~ ,' ' - -,,r ~:_. :"_ .::1 ,~, ,,,,,ss I :..-. ~,;,; ". I /~ ,,:.:,.- ,.: .... · , i -t:::-~: ::'M / t'""-.;?..~ / ' i :~_ li~'"t':' :" ~;~:' /': --~ ~ . .,/ ,, I Z~./~, '~.)~'.P.'l, Pt/~'r~O~M °D' i;.k,-. / I.. ~..-A,.. ~, / i ',"... X '// ~:'"~'!i ' II ' '. I ~/ , I I I 1 III , I t .I I!! HF JUN -. ~ 1.98I Alaska Oil & 8as Cons. /tnChorage Commission c~ CO , :: ':.' ' - -- SUBMIT IN D~'~ ,1CATE' STATE OF ALASKA ',see other st ructions on reverse side; OIL AND GAS CONSERVATION COMMITTEE i WELL COMPLETION OR RECOMPLETION REPORT AND LOG* . ,,, ,. . la. TYPE OF WELL: on, ~AS ' W ELI, W ELL DR Y Other b. TYPE OF COMPLETION: .~w ~] WOnK ~, D~r- [3 PI.~ [3 DI~. [3 Redrill %VEI, L OVER EN [lACK nESVR. Other 2 NAME OF OPERATOR Shell 0il Company 3. ADDRESS OF OPERATOR P. 0. Box 831, Houston~ Texas 77001 4. LOC~r~ON Or WELL '-(-Report location clearly and in accordance with any State requireme~,ts)* At ~u~ace 66.22' south and 53.54 east from center leg 1. Leg 1 is 1627' N & 435' W from the SE corner of Sec. ll-8N-13W, SM-. qxo. o_n.rod, interval re~orted below 2IT'N & 688 E of SW corner of Sec. 12-SN-13W, SM At total depth ' 1156.73' north and 681.9 east of 8W corner of Sec. 12-SN- 13W, SM. 5. AP1 NU2VLF_A~CAL CODE #50-133.2Q,19..lr91 6. LEASE DESIGNATION A-ND SERI-AJ~ NO. ADL 18754 ~. IF INDIA. N, ALLOTTEE OR TRIBE NA1V/~ Nons 8. UNIT,F;~IiVi OR LF~kSE NAME Middle Ground Shoal 9. WI~L NO. A-13-12 Rd 10. FIELD AND POOL, OR WIL`DCA. T MGS-G Pool 11. SEC., T., R., M., (BOTTOM HOL~ OtMECTIVE) ~2-TRN-RI 3W; R.M. 12. P~R1VIIT NO, 73-35 13. D~'kTE SP'UDDED ~14. DAT~I T.D. iREJ%CHED '[ l§.r DATE CC}iVI/~ SUSP O/1 ABAND. 115. E[LEVATIONS (DF, RgB, 'RT, GR, l~'l'C)* 117. ELEV. CASiNGHEAD TOSAL DE--H, ~m & T ~LTmLE co L DF-116 ' ' ~ - , ' ~. ., ~ 21. INTERVALS DRILLED BY [ : _ [ HOW~Y' { ROTARY TOOLS 1 CABI,E TOOI,S 9oo / 9s0 (9504) PRODUCING !N~VAL(S), OF ~IS COMP~TIO~--TOP, BOSOM, NA~E (~ AND ~)* ]23. WAS DIRE~ONAL ~ SURVEY MADE 9043-9535 (8747-9234): .i Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN SchlUmberger DIL,.'_ SP'Cal BHC ~ GR-CBL ~. CASING RECORD (Report all strings set in well) CA. SI~G SIZE [ WEIGHT. LB/FT.~ GRz%DI!I I DEPTH SET (1VID) / J-5'~ '[ 1593 13-3/8" [ 61 : , 9'25/8'' | [47,43,5,40 ] P&NI 8751 Miiled ~indo}~ at 6501 , , ! 26 LINER 1R/IgC OIIJ~ SIZ~ TOP (MD)' BOTTOM (A~ID; SACKS CEMENT* 28. PERaVORAT[ONS OPFiN TO PI~ODLTC'rlo1NT (in%crval, size and number) 9043-9063; 9077-9117; 9325-9365; 9398-9445; 9464-9535. Ail perforati0ns~ are ½" jets, 4 holes per foot. HOLE17~SIZE 12¼- DATE OF 6/17 FLOW, TUBING 65 31. DISPOSITION OF ii 30. P~ODUCTION DATE FI1RST PI%ODUCTION [ PI~ODUCT1ON ME'iHOD (Flowii*g, gas lif~, pumping--size and type of pump) ~/11/74 } Gas lift HOURS T'ESI~. ' [CI-tOXE SIZE TEST PEI~OD 6' I ~28/64 ~- [ CA~G PRESS~RM ICAb~~ OI~BBL. C~S (ffold, used for fuel, vented, et~'.)' Sold & Fuel gas / 700 sacks CEMLNTING RECOtl,D ..] ~OUNT PULLED "t None None 32. LIST OF ATTACHMENTS 27. TUBING REGOI>JO SCilEE'N (MD) I SIZE -- i 29. ACID, SilOT, FilACTUI{E, CE2,iENT SQUEEZE, ~C. D~iNonelI~T~V'~ (~D) t AS,iOUNf ~'~D 1.2!ND OF ~IE?2AL US~ ..... PROD'N FOIl oIL,--BBL. G ,a~S--BglC F. 87 I GAS---NICF. 218 i DEPTH SET (MD) j PACKER SET (MD) 8980 8929 [V/ELL 2~TATUS (Producing or Producing W/~TER--BBL. ] GAS-OIL ILkTIO 54 I 1 I ..... 626 WATEi:b~IBBL, [ OIL GRAVITY-Alii (COLOR. I 5 I 35..3. ,, , I TE~T WITNESSED BY 2 sepias + 2 prints of electric logs, history, well survey. ..... 33. I hereby certify that the foregoing a~d attached information is 'comPlete and corre6t as determtn~ from all-available recordff TI LE Division Onerations Engineer DATE ..... · i ill *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS Generel: This form is designed for submitting e complete end correct well completion report end log on ell types of lanJs end leases in Alaske. Item: 16: Indicete which elevetion is used es reference (where not otherwise shown) for depth meesure- mentsgiven in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for seperatc, production from more than one intervel zone (multiple completion), so state in item 20, and in item 22 show the prc-Jucing interval, or intervals, top(s), bottom(s) and neme (s) (if eny) for only the interval reported in item 30. Submit e separate report (page) on this form, edequetely identified, for eech edditional interval to be seperately produce~, show- ing the ack:litionel dete pertinent to such intervel. Itom26: "Sacks Cement": Atteched supplementel records for this well should show the details of any mul- tiple stege cementing and the Iocetion of the cementing tool. Item 28: Submit a seperete completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 3~. SUMM~R¥ OF FORMATION TF~'I'S INCLUDIN(; INTERVAL T~TED. PR~URE DA~A ~~OV~I~ OF OI~ GAS, 35. G~GIC MAR~ WA~ AND MUD N~ ~AS. Top G Pool 9043 8747 ~. C~Rg DATA. AqTAcI[ nR1E~ ~N~ D~KC~gl) SHO~S OF O1~. G~ OR WA~. .. .... ..:.. . ,.., ._ : ,PL.298 ,;;~,v, 5,63) PUnteO ~n ~,b,/~, · ~ 'M'i¢ldle Ground Shoal Cook Inlet, )laska REDRILLING REPORT 4-_0-74 TO 6-1]..-74 t~^~"- ~rts 7:00 a.m. 'fO 7:00 a.m. 4-23 Found tubing scaled up. Bailed fron Pumped in acid with low vo].mne pump, dJ. ssolved scale· 4-24 Retrieved Otis ball valve. Ran in stopped at 3080'. POH. Rigged up 15 % acid and 11 bbls. of water at off tubing. Ran in with wireline. boost acid· Unable to boost with 3~ Ran in and retrieved gas lift valve Mud: 78 pcf, vis 38 sec. 4-25 Circulated and conditioned gas cut raised mud weight. Circulated. Ins Removed well head. Installed BOP. 4-26 Finished nippling up BOP stack. Set 2000 psi. Tested pipe rams and Hydz up 1-t/4" tubing and ran in to 5000' Picked up tubing. Tubing stopped at power tongs turning tubing to 6560', wl=8.6cc, cl=500ppm 4-27 Ran 1-1/4" tubing 6560' to 6868'. circulated for 45 minutes. Ran tubJ mud. Tripped out of hole laying do~ hanger trying to unseat packers. vis 42, w1=8.4cc, cl=500ppm. 4-28 Have 135,000# pull on tubing while to run Dialog, freepoint and jet cut 7490'. Pulled out. Ran in hole wit 7490'. Ran in the hole with freepoJ at 7703', tubing free at 7692'. Ra~ at 6430'. Pulled cutter out. Ran Picking up 1-1/4" tubing. ':' CONDITiO~'A~ FIRST OF PERIOD , ,oL~ I C?,NO S~, I , DEPTH SET . .... 9 5/8 8751 7" 8643-9596 shop perforated uncemented liner , 100/120'. Filled tubing with acid. Rigged-~wireline to check if acid has hole to retrieve gas lift valve. Wireline and pumped acid. Pumped in 25 bbis. of 3000 psi. Boosted acid 2 bbl/hr. Bled .Stopped at 6400'. Hooked up Howco to 3500 psi. Reran wireline to plug at 6400'. at 5942'. Pumped in 78 pcf mud in annulus. mud through choke. Built mud vol~ne, :alled tubing back-pressure valve. Mud: 77 pcf, vis 40 sec. rotary table. Tested blind rams to on 3-1/2" tubing to 1500 psi. Picked · Tested Hydril on ].-1/4" to 700 psi. '6438~. Circulated and cleaned out with 122' in 3 hrs. Mud' 78 pc~, vis 40, Cleaned out bridge 6868/6969' and g 6969/8602'. Circulated and conditioned 1-1/4!' tubing. Screwed into tubing Maximum pull 140,000#. Mud: 78 pcf, waiting for tools. Riggedup Schlumberger tter. Ran freepoint indicator-stopped at spud bar and spudded through bridge at indicator to 8200'. Top packer stuck in hole with jet cutter. Cutter stopped in hole with 2.7" O.D. mill on 1-1/4" tubing. CONDITION E~EFORE STARTING WORK (CROSS OUT ALt. BUr APPROPRIAT~ 1711145) DEeM ~S't (RD. OR DE.) TOP FISH (F) OR JUNK (a) ~ _ · DEPTH PRESENT EFFECTIV.. 9596 BAD ego. (C) OR LINER (L) NOTE--IN ADDITION TO REPORTING ROUTINE RECONDITiONiNG OPER, ATIONS, U-.e< THIS FORM FOR REPORTING THE: FIRST INSTAL* ALLY COMPLETED ON THE PUMP). BAD CASING. FISH LEFT IN MG S-A1 a ska REPORT R E:I~ARK$ A-13-12 Rd Picked up 1-1/4" tubing. Reamed and cleaned out scale 6371/6598' and 6890/6981'. Ran in the hole to 8450'. Circulated. Spotted 1000 gal. of 13% inhibited acid. Displaced acid with 1 bbl. of water followed by drilling mud. Pumped acid at 1 bbl/minute. Pumped acid out of hole and conditioned mud. Mud: 77 pcf, 46 sec, wl~9.1, cl=500ppm. Conditioned mud at 6000'. Pulled out. Laid down 1-1/4" tubing. Circulated through gas valve at 6000'. Conditioned acid out of mud. Ran in the hole with. Dialog jet cutter. Made cut at 7756'. Pulled to 145,000# pull. Unable to pull packer loose. Ran in hole again with jet cutter. Cutter stopped at gas valve at 6000'. Whil~ trying to work cutt-er dOwn the hole the pipe- pulled loose and moved up hole. Pulled out of hole laying down 3-1/2" tubing° Mud: 75 pcf, 47 sec, w1=8.2cc, cl~600ppm, ph=!0, cake=2/32". Finished laying do~n~ 3-1/2" tubing and 1 packer. Ran in hole with over- shot, bumper sub and jars with 6 D.C:'s. Took hold of fish. Jarred on fish for 30 minutes and fish pulled free. Maximum pull was 280,000#. Made trip out of hole. Laid down tubing and packer. Ran in open-end D.P. to 9500' and circulated from bottoms up. Preparing to cement. Mud: 74 pcf, 42 sec, 9.4cc, 640ppm cl, ph=9.5, '2/32" cake. With open-end D.Po at 9500', pumped in 30 cu.ft, of water. Mixed 283 sacks of class G cement with 1% Halad 9, Oo1% HR-7, 118 pcf slurry. Displaced with 10 cu.ft, of water and 870 cu.ft, of mud. CIP at 6:50 A.M. Pulled to 7500'. Closed pipe rams. Held 2000 psi for 5 minutes. Tripped out of hole. Repaired mud. pumps. ~Tr~ed back in. With D.P. hung at 8226', pumped 100 cu.ft, of water. Mixed 240 sacks of ciass G cement, 1% Halad 9, 118 pcf slurry. Displaced with 30 cu.ft, water and 718 cu.ft, mud. CIP at 4:25 P.M. 5-1-74. Pulled to 6000'. Closed- pipe rams. Held 2000 psi for 5 minutes. Tripped out of hole. WOC. Ran back with open-end D.P. to 7680'. Circulated hole. Found top of cement at 7680'. Pulled to 6710' and pumped 100 cu.ft, water. Mixed 100 sacks class G cement, 118 pcf slurry. Displaced with 30 cu.ft, of water and 600 cu. ft. mud. CIP at 3:45 AoM. 5-2-74. Made a trip out of the hole. Laying down excess D.P. Finished trip out of hole. Welded leak in brake rims. Worked on pumps and cleaned out mud suctions while waiting on cement. Made a trip in the hole. Drilled out hard cement 6495/6600'.° Conditioned mud. Made a trip out of the hole. Made up drilling tools. Ran back in. Starting to cut window at 6501'. Mud: 77 pcf, 68 sec, 12cc, 500PpmC1. / Cutting window at/650!7. Cut a 50' window with fish & mill 6501/6551' in 17-1/2 hours. Tr~ppe~f out of hole. Ran back in with jet sub. Mud: 71 pcf, 72 sec, 11.6 cc, 200 ppm NaC1, pH=lO, 2/32" cake. OIL, COMPANY 5-8 Circulated up from bottom at 6600'. Pulled. ~p to 6500'. Circulated do~n~ through window with jet sub. Could not get back into top of casing. POH with a bit bottom single of drill pipe. Ran back in hole with open-end DP. Circulated down from 6550/6600'. Circulated hole clean. Pumped in 100 cu. ft. of water mixed 100 sacks of G cement plus 20% sand, 1% CFH-2. Displaced with 30 cu. ft. of water and 600 cu.ft, of mud. Tripped out of hole. Laid down excess DP. Picked up 30 j ts. of heavy well DP. Prepared rotary clutch while waiting on cement'. Tripped in hole. Mud: 71 pcf, 52 sec, 10.8cc, 200 ppmC1, ph=10, 2/32" cake. Made trip in hole with bit. Cleaned out soft cement from 6300/6480', hard cement from 6480/6506'. Conditioned mud. Made trip out of hole. Made up a dynadrill and monel D.C. Ran in hole, oriented dynadrill, faced S-5-E. Mud: 72 pcf, 47 sec, 12.8 cc, 1800 ppmC1, ph=ll.5, 2/32" cake. Drilled to 6591' with dynadrill. Made 85' in 7-1/2 hrs. Tripped out of hole. Laid down dynadrill. Made up drilling hookup. Ran in the hole and drilled to 6618'. Surveyed. Tripping out of hole. Mud: 73 pcf, 46 sec, 11.8 cc, 2800 ppm-C1, ph=ll, 2/32" cake. Made a trip in the hole with dynadrill. Oriented dynadrill amd ~rilled to 6662~. Surveyed. Tripped out. Laid down dynadrill. Made up drilling hookup. Ran back in the hole. Drilling. Mud: 74 pcf, 51 sec, 9.9 cc, 2600 ppmC1, ph=ll, 2/32" cake. Drilled to 6800' with~i~4. Made a trip out'of the hole. Picked up dynadrill. Ran in hole and faced dynadrill #3 S-20-W. Drilled to 6867' in 6-1/4 hours. Mud: 73 pcf, 46 sec, 7.7 cc, 2800 ppmCl, ph=ll. Made a trip out of hole. Laid down dynadrill. Ran back in with bit and drilled to 6900'. Surveyed. Made a trip out and changed drilling ho°kup. Ran back in. Cleaned out fill and reamed 6820/6900'. Drilled to 6962' with bit #7. Coming out of hole. Mud: 73 pcf, 51 sec, 8cc, 4800 ppmC1, ph=ll, 2/32" cake. Made a trip out of the hole at 6962'. Changed bits. Drilled to 7072' with bit #8. Made a trip out and changed drilling hookup. Ran in hole and reamed 30' to bottom. Drilled to'7169' with bit #9. SurVeyed. Tripped out of the hole at 7169'. Ran back in the hole. Drilling. Mud: 74 pcf, 48 sec, 7.1 cc, 3700 ppm, ph=11,2/32" cake. Drilled to 7289' with bit #10. Tripped. Drilled to 7397' with bit #11. Made a trip out of hole. Mud: 74 pcf, 50 sec,'6.6 cc, 3400 ppmC1, ph=ll. Drilled to 7524' with bit #12. Made a trip. Changed drilling hookup. Ran back in and drilled to 7596' with bit #13. Suz~eying. Had 2 hrs. repairing mud lines. Mud: 74 pcf, 48 sec, 6.4 cc, ph=ll, 2.'3/32, 3200 ppmC1. MGS-Alaska REPORT A-13-12 Rd Made a trip out and picked up dynadrill, Ran in. Oriented dynadrill with Sperry-Sun steering tool and drilled to 7646'. Pulled dynadrill. Made up drilling assembly. Running in. Mud: 74 pcf, 47 sec, 7 cc. Made trip for bit change at 7767'. Drilled to 7875' with bit #16. Mud: 74 pcf, 46 sect 6.8 cc, 2600 ppmC1, ph=10.5, 2/32". Tripped for bit changes, at 7887' and 7964'. Drilled to 801.3' with bit #18. Mud: 75 pcf, 47 sec, 7.2 cc, 2400 ppmCl, ph=10 Drilled to 8017'. POH. Made up dynadrill. Ran in, oriented with Sperry-Sun tool. Reamed from 8005/8017'. Dynadrilled to 8032'. pulled out and changed dynadrill. Ran in and cleaned out from 7946/7987'. Mud: 75 pcf, 48 sec, 6.8 cc, 2200 ppmC1, ph=10. Cleaned out from 7987/8032'. Dynadrilled from 803 8070'. Pulled out, lost ali. 3 cones off bit #20. Ran in 8-7/16 Servco mill and junk sub on drilling assembly. ~illed on cones 3-1/2 hours. Pulled out. Recovered small pieces of Iron junk sub. Made up bit #21. Mud: 75 pcf, 52 sec, 6.6 cc, 2200 ppmC1, ph=10.5, cake=2/32". Ran in drilling assembly to 6500'~ Shut~rig down two hours while production was acidizing. Ran in and drilled to 8089'. Made trip for bit change. Drilled to 8127'. Making trip for bit change. Mud: 75 pcf, 48' sec, 6.4 cc, 1400 ppm¢l, ph=10.5. Drilled to 8210' with bit #23.. Made trip for bit change. Drilled to 8327' with bit #24. Mud: 75 pcf, 46 sec., 6.5 cc. Drilling: Made trips for bit changes at 8350 and 8400. Mud: 77 ppg, 50 sec, 6.5 cc, 1300 ppmC1, ph=10. Drilled to 8481 with Bit 26. Tripped. Drilled to 8561 with Bit #27. Made trip for bit change. Mud: 77 ppg, 50 sec, 6.3 cc. Drilled to 8687 with bit #28.. Tripped. Drilling with bit #29. Mud: 77 pcf, Drilled to 8795' with bit #29. Surveyed. Made trip for bit change. Cleaned out a bridge at 8600'. Reamed from 8600' to bottom. Drilled to 8881' with bit #30. Made trip for bit change. Mud: 77 pcf, 47 sec, 6.2 cc, 1100 ppmC1, ph=10. Tripped in. Drilled to 8974' with bit #31. SUrveyed and made a trip for bit change. On bottom drilling with bit #32. Mud: 77 pcf, 6.3 cc. Drilled to 9224 with bit #32. Tripped. Mud: 77 pcf, 49 sec, 6.2 cc · Drilled to 9362 with bit #33. Mud pumps down 3 hrs. Mud: 77 pcf. .. MGS-Alaska REPORT A-13-12 Rd · Repaired mud pumps for 6.5 hrs. Drilled to 9531. Drilled to 9555' with bit #33. Surveyed. Tripped out of hole. Changed 3 jts. of heavy~ll D.P. and 1 stabilizer. Ran in the hole and reamed 40' to bottom. Drilling. Mud: 77 pcf, 47 sec, 6·4 cc, ph=9 Drilled to 9749' with bit #34. Surveyed and tripped out~ Changed 2 stabilizers. Ran back in the hole. Drilled to 9825' with bit #35. Made a trip out of the hole. Mud: 77 pcf, 6.2 cc. Tripped in the h01e. Drilled to 9900' with bit #36. Made a 10 stand wiping run. Conditioned mud for logs. POH. Ran DIL 9865/6490'. Ran BHC sonic 9844/6490'. Mud: 77 pcf, 4.6cc, ph=9. Made a trip in the hole· Conditioned mud to run liner· POH. Picked up 86 jts of 7" 29# N-80 buttress casing with special clearance couplings · ~ ' , · Shoe at 9898', fillup collar at 9809', top of liner hanger at 6290'. Cir- culated hole clean· Pumped 100 cu.ft, of injection water ahead· Mixed 1750 cu. ft. of 108 pcf slurry, class G cement with 14% salt, 4% gel, 1% CFR-2, 0·6% Halad 9. Displaced with 1430 cu.ft, mud. Bumped plug with 3000 psi. CIP at 4:00 A.M. 6-1-74. Tripping out of hole· Mud:$ 77 pcf, 4.8 cc, ph=8.5 While waiting on cement, changed the chains in drawworks, serviced rig and after 12 hours found top of the cement stringers and soft cement at 4670'. Cement stringers 4670/5700'. Cleaned out fi~nn cement 5700/6290', top of liner hanger. Conditioned mud. Tested liner lap to 2500 psi for 30 minutes. POH. Mud: 72 pcf, 45 sec, 12.6 cc, 200 C1 ppm, ph=ll. Made a trip out of the hole. Laid down 81 jts. of 5" D.P. and 3 D.C's. Ran in the hole with Halliburton tester with 950 cu.ft, water cushion. Set packer at 6272' with tail to 6280'. Opened tester for 1 hr. test. Had 5 ft· rise in 5" D.P. No fluid entry in liner lap. POH. Laid down 3 D.C's. Picked up 3 small D.C's and stood back in the derrick. Waiting on D.P. due to strike at the Nikiski dock by the truckers and longshoremen. Mud: 71 pcf. Repaired pumps and drawworks. ~Ran in hole 19 stands. Shut down at 5:30 P.M. 6-3-74 due to dockstrike. Shut down due to dock strike. Started unloading 3-1/2" D.P. at 8:00 P.M. 6-6-74. Picked up 3-1/2" D.P. and ran in hole. Drilled out cement in top of liner 6290/6357'. Running on in the hole to drill, out float. MGSLAlaska · R~PORT A-13-12 Rd REMAR~ Drilled out cement 9800/9809'. Circulated hole clean. Conditioned mud. Tripped out of hole. Ran CBL 6290/9800'. Reran CBL under 1500# pressure. Made a trip in the hole. Displaced mud with injection water. Displaced water with diesel oil. Rinished displacing diesel oil. Laid down 5" and 3 1/2" DP and D.C's. Rigged up and ran production tubing. Ran production tubing. ~ottom of tubing at 8980'. Gulberson packer at 8929', ball valve at 315'. Set packer and slacked off 30,000# wt. on packer. Stripped out BOP and risers. Installed tubing head, Tested to 2000 psi. Gas lifting diesel down to 7000'. Completed gas lifting out 525 bbls. of diesel. Rigged up Go-International. Perforated Bi-wire torn~do o et 2-1/8 , 22 gr§jp charge. Perfora~e~t four holes ~er foot at the following depths: 9043/9063' (20'), 9077~9117' (40'), 9325~65' (40'), 9398~9445' (47'), 946~535' (71') for a totaI of 218'. Released rig at 9:00 A.M. 6-11-74. Bit # 1 1RR 10 il 12 13 14 Size _ 8 1/2 8 1/2 8 1/2 8 1/2 8 1/2 8 :L/2' 8 1/2 . '8 1/2 8 1/2 8 1/2 8 1/2 8 1/2 8 1/2 8 1/2 8 1/2 8 1/2 Brand Reed Reed Reed Reed Reed Reed Reed Reed Reed Reed Reed Hughes Hughes Reed Hughes Reed WELL A-13-12 Rd. BIT .RECORD Nozzles De__~oth in D_9.pth Out Sl3G S13G Sl3G S13G S13G S13G Sl3G Sl3G Total Feet Hfs · 3-16/32 6495 6600 105 1.5 3-16/32 6216 6506 290 2.75 None 6506 6591 85 9.5 2-11/32 1-14/32 6591 6618 None 6618 6662 2-11/32 1-14/32 Sl3G Sl3G Sl3G XDG ODG Sl3G ODG ST1AG 27 44 6.5 None 6662 6800 138 8.5 6800 6867 6867 6900 2-11/32 1-14/32 67 33 62 110 97 120 107 117 72 5O 6900 6962 " 6962 7072 " 7072 7169 " 7169 7289 " 7289 7397 " 7397'~' 7524 " 7524 7596 None 7596 7646 6.25 1 6 4.75 7 7 7.75 4 4.75 Cond. T/B/O/ 4/i/o 3/~k/]: 8/6/I 5/2/Z 614/I 6/3/I 6/2/I ( 612/I 7/5/z 712/ 118 2/2/~ Bit # 15 16 17 18 19 2O 21 23 24 25 ¸26' 27 28 29 3O Size 8 1/2 1/2 1/2 1/2 1/2 1/2 1/2 1/2 1/2 1/2 1/2 1/2 1/2 1/2 1/2 1/2 Brand Reed Hughes Hughes Smith Smith Hughes Hughes smith Smith Smith Smith Reed Reed Reed Hughes Reed Sl3G XDG, XDG SDGH SDGH XDV WR-7 SDGH SDGH 'SDGH DGHJ S13G S13G S13G ODG 'S13G Nozzles 2-11/32 1-14/32 3-12/32 3-16/32 3-13/32 None None 3-13/32 3-14/32 3-14/32 3-14/32 3-14/32 3-14/32 3-14/32 3-14/32 3-14/32 3-14/32 ~Depth In 7646 7767 7887 7954 8017 8032 8070 8o8.~ 8127 8210 8350 8400 8481 8561 8687 8795 pepth Out 7767 7887 7954 8017 8032 8070 8089 8127 8210 8350 8400 8481 8561 8687 8795 8881 Total Feet 121 120 67 63 15 38 19 38 83 ].40 50 81 80 126 108 86 Well A-!3-12 Rd. Bit Record Page 2 Hrs. Cond. T/B/O/ 7.5 6i2/I 9 6 5.5 3.75 5 3,75 4 8~ , 9' 8 10 8.25 9.5 9 11.5 6/2/I 6/2/I 6/2/ 1/{' -- Lost 3 cones 414/I 4111I 4/4/I · 612/ 1/4 4/3'/ 1/8 7/7/1 ( 51311 5/2i1 2/3/I 6/2/I Bit ~/ 31 33 34 35 36 Size 8 1/2 8 112 8 1/2 8 1/2 8 1/2 8 1/2 Brand Hughes Hughes Smith Reed Hughes Hughes Type ODG J-44 S-4 FP62 ODG ODG Nozzles 3-14/32 3-13/32 3-13/32 3-13/32 3-13/32 3-13/32 D_D~p th In 8881 8974 9224 9555 9744 9825 Depth Out 8974 9224 9555 9749 9825 9900 Total Feet 93 250 331 194 76 75 Mrs. 6 34.5 32.75 22 5.25 5.25 Well A-i3-12 Rd~ Bit Record Page 3 Cond, T/B/G/ 3/3/I 4/4/I 6/2/ 1/8 8/2/ 8/4/ 1/4 8/4/ 1/4 l~'mrm No. P---4 STATE (~.~ALASKA OIL AND GAS CONSERVATION CONV~AI~EE SUBMIT IN DUPLICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. 0IL W~-LL 2. NAME OF OP~%ATOR Shell 0£1 Company 3. XnDRESSOF'O~KRATOa Box 831, Houston, Texas 77001 4. LOCA~ON OF W~I~. Conductor 29, Leg 4, 66.22' S and 53.54' from center of Leg 1. Center Leg 1 location is 1627' and 435' W from Southeast corner of Sec. 11, TSN, R13W. J ~PI Nu~ERICA~L CODE 50-133-20191 6 LEASE DESIGNA~ON AND SERIAL NO. ADL 18754 IF INDIA~, ALO~ ~E~ O~ TRIBE NAME None 8. L.~IT FARM OR LEASE NAME Middle Ground Shoal 9 WELL NO MGS A-13-12 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11 SEC , T., R., M.. (BOTTOM HOLE Sec. 12, TSN, R13W, S.M. 1~-. P]~RA~IT N'O.- 69-61 'i3. R~ORT TOTAL D~IPT~ AT END OF MONTH. CHANGES IN HOLE SIZE. CASING A~ C~TING JOBS INCLUDING DEP~ SET A~ VOL~ USD, P~O~TIONS, ~TS ~ ~SULTS F~NG JO~ J~K ~ HO~ AND SIDE-~CK~ HO~ AND ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~ITIONS A-13-12 ..Report for May 1974 Plugged back liner with cement. Top cement at 6600'. Cut a window in casing at 6501. Drilled to 9900. Ran DIL 9865-6490, Ran BHC sonic 9844-6490. Report for June 1774. Ran and cemented 7", 29~, N-80 Buttress liner from 9898 to 6290. depth 9809. Ran tubing into well. Perforated the HC-HD, HI-HK, HK-HN. Released rig. Reperforated well 6-27-74. Plug back total JUL ! § I974 DIVISION OlAND 14. ! hereby certify %ha% the forego~g ~ ~e ~ ~ 8IO~ ~ DA~ NOTE --Report on this fo~ il required for ~ch calendar ~th% regardless of the status of operotiofls, o.d must ~ filed in duplicate with the oil an4 gas ~onBervatlon commiflee by the 15~ of the suoc~ding mon~, ~le~ otherwise directed. l~rm ~o. P-..4 I~'V. 5-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL J. NP._~_W, OF OPerATOR Shell Oil Company Box 831 ~ Houstont Texas '4'." '~)CATION OF WTM SUBMIT IN DUP- LICAT~ Conductor 29, Leg 4 , , 7700]. ~i A~I ~.mC~,L ~ODE 50-133-20191 8 LEASE DESIGNATION A.~,-D SE1RIAL NO. ADL 1875n T I~ INDIA~, A~IY~ OR TRIBE NAME None 8. L~IT. F.~ OR LEASE N~E Middle Ground Shoal g ~v~ NO ~S A-13-12 10 F~ i~D P~L, OR %VILDCAT .Middle Gr0u~d Shoal o~ Sec. 12~ TdN, R13W, S.M. 12 P~IT NO 13. REpO~ 'TOTAL D~H AT END OF MONTH, CHA~NGES IN BOLE SIZE. CASING A1N-D CEMEN'I'ING JOBS INCLUDING DEPTH SET A1W~ VOLLrMES USED. PERFORATIONS. TESTS ANT) RESULTS FISHING JOBS JI~I~K IN HOLE AND SIDE-TRACKED BOLE A3~D ANY OTHER SIGNIFICANT CH.A. NG~S IN HOLI~ CONDITIONS Report for April 1974 Rigged up over A-13-12, 4/22/74 Ran Macaroni string and cleaned out scale to 8602. Pulled packers out of hole. Prepared to cement off lower zone. certify ~{{t the forego~ris is t~te_~nd correct ' Il I (~ ' i ~ __ _ " oil ..d g.s co. Jervet~n ¢ommlffee by the 15ffi of the suoe~ding mon~. u~le~ Otherwise directed. - SHELL OIL COMPANY SHELL BUILDING 1008 WEST SIXTH STREET LOS ANGELES, CALIFORNIA 90017 November 1, 1973 TELE DRAFT SEC CONFER: FILE: State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr..T, R. Marshall,-Jr,. Gentlemen: Attached'are.three eopies'~of.?ermit.tO':Drill'(FOrml0,401) for our.re-drillof.well A-13~12,1Middle'Ground:Shoal field. ~In accordance with conversationbetween'Mr.'iT; R~'Marshall:and'Mr, iJ;iD, iMcLehaney';this isbeing.re-SUbmitted'.to note.the.Pertinent.changeS"caused'.by.alteration.of .the subsurface target.at.the.top of.the"Producing zone.' .Yours.verY'truly, N. 'G, McKim Division Operations Engineer West CoaSt Division Attachments: cc - w/attaChments Atlantic Richfield Company Standard Oil Company of California AmocoProduction Company ~ U.S.G.S. D!V~SION. ~,r t,, !~.. ,,._~"~'-' GAS A~x'CHOR G October I ?, t 973 Re: Nledle Ground Shoal A-13-1:2 ~ $1ml IOl t Company, ~er~tor Permit No. 73-35 Deer Sir: Enclosed ls the al~roved appllcatlo, for Imr~t to drill tl~ at~ve ref~d veil, on or about No~ 10, I~/3, et a locattem tn S~t!oa II, Tcmnship 81~, Range t~1~., S.~I. l~et I samples, core chips m~d · mud log ere not required. A ~lirectt,on~l is requi red. Nany rivers In Alaska and their dralnage~ systems bare been c!asslfled es t~~t ~ ~ s~fllN ~ ml~lon ~ ~~s fish. ~t'l~$ tn end ~. 7 end the reg. letlons prmmlg~ted ~ (Tit.-te 18. Alaska Adml.i~mtlve CoCa, ~pter 70) aml by the Fedelrat llllt.te~ P~llutt¢~ Col~rol Act. es ~. Prior to cam,enclng e~eratlons yo. my be ~te4 by a-representative of the In tim event el s-~$-ion er at~ml.m.mt p!-eese gl~ thls, office adeq~te ~lgnce notlflc.tlon so that ~e my I~v~ a ~ltness p~t. The.as R. 14arsl~ltl, Executive Secretory Alaska OII end. b ~onserv~t!on Tttg~pJ' CC: Department of Fish and SHELL OIL COMPANY 1008 WEST SIXTH STREET P. O. BOX 3397 LOS ANGELES, CALIFORNIA 90051 State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention Mr. Homer L. Burrell Gentlemen: OCT 5 1973 TELEPHONE: (213)~- j_ J Dt~AF'T J 1 l I ~'~ .... j ~F~ ....... i Attached is the request, in triplicate, to redrill our Middle Ground Shoal A-13-12 well. Included are the following: 1. Proposed Work Sheet 2. Target Map 3. Location Plat 4. $100 Filing Fee Check. Yours very truly, N. G. McKim Division Operations Engineer West Coast Division Attachments cc - w/attachments Atlantic Richfield Company Standard Oil Company of Califo=mia Amoco Production Company U.S.G.S. OCT g I§73 'r,,,,,~"~,,",~' ©F O~L AND ANCHORAG6 ~orm 10'-- 401 . REV. I--I--71 STATE O,F ALASKA OIL AND GAS CONSERVATION ,COMMITTEE PERMIT TO DRILL OR DEEPEN lB. TYPN OF WOrK DRILL E~ DEEPEN [-] SUBMIT IN TRIP~TE (Other instructions on reverse side) .API #50-133-20191-01 ~. LF,~kSm. D~IGNATION A_~rD M~J~L NO. ADL 18754 ?. IF IN'DIAN A. LLO'i-r~,.: OR TRIBE NAME None 8, UNIT~FARM OR LEASE NAME Middle Cround Shoal g. WELL NO. A-13-12-RD 10. F~Eq~D AND POOL OR WILDCAT ~S - C Pool .. SEC., T.. R.. M.. rBOT'rO~ HOL~- OBJECTIVE; 12, T8N, R13W, S.M. 12. b. TYP~ OF WI~LL OIL [~ OA, ~ I~INGL~ ~] W.LL WgLL OTH.. ZON. 2. NAME OF OPEI:L~TOR SHELL 0IL COHPANY 3. ADDRES~ (~ OPERATOR 1008 West Sixth Street .. Los A~g~l es; California 4. LOCATION OF WELL At surface See Below* At proposed prod. zone See Below* _~ 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 17 miles NW of Kenai, Alaska 14. BOND INFORMATION: TY_~ate Wide (~$tyand/orNo. TIC 136503 15, DIIii~A/I~FROM PROPOSED* L~/~A~[~(~I~I TO NEAREST PROPERTY OR LEASE LINE, ler. 16. NO. OF ACRES INLEASE 3746 ' 19. PROPOSET) DEPTH 9825±' (Also to nearest drig, unit, if any) 1~. DISTANCE FROM PROPOSED LOCATION* 1450±' TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, 1;~, 850±' ~mo""t $!00,000 17. NO. ACRES ASSIGNED TO THiS WELL 40 20. ROTARY OR CABLE TOOLS . Rotary M U I,TIPI,I~ ~_~ ZONE 21. ELEVATIONS (Show whether DF, RT, CE, etc.) 22. APPROX, DATE WORK WILL START* 115' D,F, PROPOSED CASING AND CEMENTING PROGRA.M SIZE OF HOLE SIZE OF CASIN(~q. WEIGHT PER FOOT ·GRAD~ SETTING DEPTH quantity. . of.. cement O 5/8" 8751' . - 2Pre.,viously cemented : , , . , ~ 1/2" ?" 29 N-80 6300-9.825_+' .. .900 cu, ft. ~ · *Surface: Conductor 29, Leg~@ 66.22' S and 53.54' E from center Leg 1 @ 1627' N & 435' W from SEcorner, Sec. 11, T.SN., R. 13W., S.M. ** Top of Productive Zone: 265±' S and 1165±' E from surface. (Estimated 1362' N & 730' E from SWcorner Sec. 12, T.8N., R. 13W., S.M. Propose to plug A-13-12 from 9570±' to 6500±' and redrill south easterly. Refer attached Target Map. IN ABOVE SPACE D~SCRIBE I~ROPOSED PROGRAM: If I~oposal is to deepen 'give dtta on present productive zone and proposed new pro'ductlve zone. lt,p?_o.~_.sal ls to drill or a~epen dWeci_[onaily, give pe.r.t, lr!_ent. ~ata' on stibsurfaee IOc~tions arid measUl'ed and true 'ver~ical depthS. (~lv~e blowou[ p~ev~e.nter- program. 24. I hereby certify that the Foregoing is True and Correct (This space for State office use) fSAMPLES AND CORE CHIPS RF~QUI~ [] Y~S ~NO DI~ION~ SURVEY R~~ _~~ Y~ ~ NO CONDITIONS OF APPROVAL, IF ANY: M,U,D LO'C [] v~s [] NO A.P.I. ~CA25 CODE Division Operations 50-133-20191-01 $ ~ $ -/~?~$- A-IS -/Z FD · 111~0' .I · I ~00 - :2.00 - I ORIGINAL RE-DRILL WORK SHEET SAS-MGS Al3-12 RD Surface Location: Platform A, Leg 4, conductor 29. Elevation' D.F. 116' (above (MLLW) OIL AN~ OAS ANCHC)i~AG~ Re-Dri 1 l' 7675-9875'+ Current Status' 9-5/8" casing cemented to 8751 ' (perforated 7800-7844'; 8370-8456'). 7" Liner 8643-9600' (selectively slotted) .Proposed: Plug off 7" liner, re-drill 7675-9875'+ Cement 7" liner 7450-9875'+. Selective-ly jet perforate Hc-Hz. 1. Pull bottom gas lift valve @ 7672'+ and insert circulating valve. 2. Move in and rig up over Leg 4, conductor 29. 3. Kill well by circulating down tubing with 70 pcf mud. Mud used for 5000re-drillppm.NaCl.to be lignosulfonate. Maintain less than l0 cc water loss, 4.. After well is dead, remove wellhead. Install B.O.P.E. and riser assembly- test to 1500 psi ~- - 5. Release packers. Pull and lay down tubing. 6. Pick up and run open end drill pipe to 9,500'+ (tubing fish 0 9514'~). Note' Bottom of 7" liner at 9600', bot~com of' perforations at 9553't. 7. Equalize 325 cuft API Class "G" cement, 120 pcf _slurry. Pull drill pipe to 7500'+ and Braden-head squeeze to 2000 psi for 5 minutes. 8. Release pressure, pull out of hole and wait on cement to set. 9. Run in to top of plug. Equalize sufficient API Class '"G" cement tO fill to 7650'+. Pull drill pipe to 6000'+ and Braden-head squeeze to 2000 psi f~r 5 minutes. 10. Release pressure, pull out of hole and wait on cement to set. ll. Feel for top of' plug. Re-cement as necessary to plug back to 7700'. Page~l of 3 Re-Drill Work Sheet SAS-MGS A13-12 Rd Program, Continued ANcHORAG~ ORIGINAL 12. Run in with drilling assembly and 8-1/2" bit, clean out plug to .7750'+. Mill window in casing from 7675'+ to 7725'+. - 13. Run in with open end drill pipe to 7725'+. Mix and pumfin 50 cu ft API Class "G" cement blended with 20% sand. Pull out, wait on cement to set. 14. Run in with drilling assembly, clean out plug to window in 9-5/8" casing. 15. Run in with Dynadrill, orient tool to drill southerly. Condition mud as necessary to be less than 10 cc water loss. 16. Drill 8-1/2" hole to T.D. (9875'+). Maintain directional control to drill as noted on attached Target Map.-- 17. At T.D. (9875'+) run logs from T.D. to kick-off point: (1) SP-GR-DIL (2) SP-BHC sonic 18. Run 2425'+ of 7", 29#,N,80 Buttress. liner to 9875'+, top at 7450'+. Centraliz~ liner, as hole conditions permit, base~ upon log eval~-ation. Liner Size Interval Length Wt. 7" 7450'+ to 2425'+ 29# 9875'~ - Design Factors Grade Conn. Col'lapse* Tension N-80 Buttress 1.41 NA Burst 1.47 *Based upon 0.48 psi/ft formation gradient with casing evacuated. Liner Equipment Be Float shoe on bottom; Flexi Flow fill-up collar two joints above shoe. Burns rotating hanger - grooved for cementing.. 19. Cement liner with an estimated 625 cu ft.API Class "G" cement blended 'with 14% salt, .4% gel and one lb/sack CFR-2, mixed with injection water. Pr'e flush with a minimum of 50 cu ft injection water. Note: Actual cement volume to be 100% in excess over amount determined from caliper log indication. Page 2 of 3 .~ Re-Drill Work Sheet SAS~MGS Al3-12 Rd P,rogram, Continued Cement ORIGINAL Fill _ Type Cu. Ft. Wt. Yield Mix_Water (psi/.ftL) (ft_3./sx)~ (ft3/,sx) 9875' + to 7450'+ AP I "G" Est. 625 with 14% Use 100% salt + over caliper 4% gel + log 1 #/sx CFR-2 0.783 1.667 0.984 (113 pcf) Notes: Disengage from setting tool prior to cementing. Casing displacement: 0.93 bbls/lO0'. Casing capacity: 21.5 cu ft/lO0'. Use pressure chart and densometer (if available). Label charts with well number and pertinent cementing data. Send to J. H. Smith, Drilling Engineer, Los Angeles. 20. Wait on cement 12+ hours. 21. Run 8-1/2" bit, clean out to top of liner hanger. 22. Pressure test lap. If necessary, run and set cement retainer at 7250'+. Squeeze lap with estimated 200 cu ft API Class "G" cement blended with- 1% water loss additive. 23. If squeeze required (refer to step 22), allow cement to set, clean out to liner top and re-test. Squeeze as required. 24. Run 6" bit, clean out as required. 25. A completion work sheet will be issued, based upon evaluation of logs. Los Angeles, California Page 3 of 3 RECOMMENDED: APPROVED: DATE: . ,rI TSN., R 13W., S.M. 11 12 ADL 18754 A~I 1-12 OCT 9 1~73 DI¥]$1C.j.N OF OIL Al,ID ANCHORAGE 13 LineAl'iON Oi: CONDUCTOR 29, LEG ;~ 4 PU6[.IC 29, LEG N~ 4 LOCATED 66.22~S FROM CENIER OF LEG No 1 No 1 LOCATED 1627~N AND ~AC)M THE SE COR. O~ SEC. li LAND LOCATION OF PRODUCING ZONE WELL A- D£SC#IPTION 8815' (8605' TVD ) 19OO' N. AND 510' E. FROM THE S W COR. OF SEC. 12, T8N, R13W, S.M. REDRILL i:~A'.-,¥N BY': dC SCALE: 1"-2,000' SHELL OIL COMPANY Z21-69112A ~AI'E. Oct. 3~ 1973 LOCATION OF ~iHE~t~.~L~ATLANTIC---STANDARD WELL A-13-12 RD. IN SEC. 11 }~', 8 N., R.13W., S.M. - COOK INLET STATE OF ALASKA CHECK LIST FOR NEW WELL PERMITS Lease & Well No. ~/-/c,~_/~__ ~.~ Yes No Remarks Is well to be located in a defined pool ................. Do statewide rules apply ......................... Is a registered survey plat attached .................. Is well located proper distance from property line ........... Is well located proper dis. tance from other wells ............ Is sufficient undedi'~ated acreage available in this pool ........ · Is w'ell to be deviated .................... Is operator tile only affected party ...... i! i. ............. Can pem~it be approved before ten-day wait ...... ~ ........ . ~. Does operator have a bond i~n force ................... ;~,'..Is 'conductor string provided ............ . '~.,ii'-'~ Is enough ceme~t used to circulate on conductor and surface ~',i~Will cement tie in surface and intermediate or production str n ~,.:.~ Will cement cover ail possible productive horizons ........... i.'~!~ Will surface casing cover all fresh water'zones ............ .- Will surface csg. internal burst equal .5 psi/ft, to next string ,.,,,..Will all casing give adequate safety in collapse and tension .... .;',~"~Does BOPE have sufficient pressure rating ............. proval Recommended: HWK '~/~. ..... LcS
