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Home My WebLink About169-092CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Josh Allely - (C); AOGCC Permitting (CED sponsored) Cc:Dan Marlowe; Juanita Lovett; Regg, James B (OGC); Aras Worthington Subject:RE: [EXTERNAL] RE: 2021 Spurr Platform Yearly Status Report for SPR-01, 02, 03, 04, 06, 08, 09 Date:Wednesday, December 29, 2021 12:50:00 PM Josh, Thanks for the additional information. We are looking forward to seeing Hilcorp’s proposed timeline for Cook Inlet P&A activity. Regards 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: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Wednesday, December 29, 2021 11:36 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: 2021 Spurr Platform Yearly Status Report for SPR-01, 02, 03, 04, 06, 08, 09 Bryan 1. Work done on the legacy derricks consisted of demolition of everything above the heliport deck. When these platforms were acquired from Marathon in 2013, the majority of the derricks had already been removed down to the top or the wind walls. This gives the required clearance for larger helicopters to land on the facility without needing to lease a small helicopter (typically from Homer) to access the facility. 2. Yes 3. No, only a small leased helicopter has been able to land in the past. As you mention, the 2018 report reflects moving the rig 8’ south which we hoped would reduce the required scope by adding sufficient clearance, but upon further evaluation it still wasn’t enough. 4. This verbiage relates to the updated timeline communicated to the AOGCC in 2020 when we experienced a failure of the winch on the unit crane and the timeline to having it fixed was uncertain. The term “achieved” rather then “exceeded” may better describe the summer activity. The work completed brings us current through original planned activity for 2020 which is reflective of the crane issues reported in 2020. 5. Per our conversation, a bigger picture timeline will be presented to the AOGCC that incorporates all upcoming P&A activity in the Cook Inlet area. Thanks Josh Allely Well Integrity Engineer Alaska South Central – Hilcorp Alaska 907-777-8505 From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Tuesday, December 28, 2021 3:05 PM To: Josh Allely - (C) <Josh.Allely@hilcorp.com>; AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Regg, James B (OGC) <jim.regg@alaska.gov> Subject: [EXTERNAL] RE: 2021 Spurr Platform Yearly Status Report for SPR-01, 02, 03, 04, 06, 08, 09 Josh, I have a few follow-up questions on the annual report? 1. Can you describe the work done on the legacy drilling derricks by the small demo crew in 2021? 2. The planned work schedule from the 2017 Suspension Renewal Sundry (attached) says that the Derrick Leg #1 and Leg #2 would be removed by Sept 2020. This milestone was delayed by one year while waiting on additional crane repairs, moving the target for removal of Derrick legs 1 & 2 to Sept 2021. Was that work completed? 3. The 2021 Status Report states “The facility can now accommodate a full-size helicopter to facilitate future P&A activities”. Wasn’t this already true as of 2018? If not, what additional work was accomplished in 2021 to accommodate helicopters? The 2018 Yearly Status Report stated that the rig was skidded out of the way and the platform was then able to “support larger (212) helicopter landings”. 4. The Status Report says that the work done in 2021 on Spurr platform exceeded the planned work schedule submitted to the AOGCC for the suspension renewal. Can you elaborate on what specific milestones were exceeded? 5. Please provide a revised project timeline for the P&A at Spurr. The project timeline that was submitted with the 2017 Suspension renewals is attached as a reference. Thank you CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 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: Josh Allely - (C) <Josh.Allely@hilcorp.com> Sent: Wednesday, December 15, 2021 9:11 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com> Subject: 2021 Spurr Platform Yearly Status Report for SPR-01, 02, 03, 04, 06, 08, 09 On December 15, 2017, the AOGCC approved the Hilcorp Alaska, LLC (Hilcorp) Sundry Applications to renew the suspended status for the Spurr Platform’s North Trading Bay Unit SPR-01, SPR-02, SPR-03, SPR-04, SPR-06, SPR-08 and SPR-09 wells, under Sundry Numbers 317-580, 317-581, 317-582, 317- 584, 317-585, 317-586, and 317-587. As a condition of approval, a yearly platform repair status report was to be submitted to the AOGCC. See attached for platform update. Thanks Josh Allely Well Integrity Engineer Alaska South Central – Hilcorp Alaska 907-777-8505 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 Hilcorp Alaska, LLC Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 December 14, 2021 Jeremy M. Price Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: Spurr Platform Yearly Status Report for Suspended Well Status; Sundry Numbers: 317-580, 317-581, 317-582, 317-584, 317-585, 317-586, 317-587. Dear Chair Price: On December 15, 2017, the AOGCC approved the Hilcorp Alaska, LLC (Hilcorp) Sundry Applications to renew the suspended status for the Spurr Platform’s North Trading Bay Unit SPR- 01, SPR-02, SPR-03, SPR-04, SPR-06, SPR-08 and SPR-09 wells, under Sundry Numbers 317- 580, 317-581, 317-582, 317-584, 317-585, 317-586, and 317-587. As a condition of approval, a yearly platform repair status report was to be submitted to the AOGCC. During 2021, Hilcorp performed the following work on the Spurr platform in preparation of future plugging and abandonment work, exceeding the planned work on the schedule submitted to the AOGCC for the suspension renewal: x Crews were mobilized to Spurr to complete crane repairs. Once the crane was operational, a small demo crew commenced work on the legacy drilling derricks and related equipment. The facility can now accommodate a full-size helicopter to facilitate future P&A activities. Hilcorp is available at the commission’s convenience to discuss the work that was completed this year, as outlined above. Should you have any additional questions, please contact Dan Marlowe at 907-283-1329. Sincerely, Dan Marlowe Operations Manager Hilcorp Alaska, LLC Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.12.14 13:50:33 -09'00' Dan Marlowe (1267) 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: E xploratory Development 3. Address: 3800 Centerpoint Drive, Suite 1400 Stratigraphic Service 6. API Number: 7.If perforating:8.W ell 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): Trading Bay / G-NE Oil, Hemlock-NE Oil Pools 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,387'N/A Casing Collapse Structural Conductor Surface 1,130 psi Intermediate Production 4,130 psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.W ell Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email:Katherine.oconnor@hilcorp.com Contact Phone: (907) 777-8376 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9,962' 9,006' 8,607' 3,214 psi 9,944'9-5/8" 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. N/A 3-1/2" Daniel E. Marlowe N/A N/A 10,369' N/A Tubing Grade:Tubing MD (ft): N/A Perforation Depth TVD (ft): 1,370' 10,369' Perforation Depth MD (ft): 300' 1,370' 36" 13-3/8" 300' North Trading Bay Unit SPR-09 9.2# / N-80 TVD Burst 10,087' 7,510 psi Tubing Size: MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017597 169-092 50-733-20200-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC N/A COMMISSION USE ONLY Authorized Name: 2,730 psi 300' 1,365' Other: Suspended Well Renewal Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 9,006' Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2021.09.20 12:33:31 -08'00' Dan Marlowe (1267) X Suspended status valid through 09/30/2022. DLB DLB 09/21/2021 (No Form) on Requuired? Yes No Subsequent FForm Req CCOMMIS SIOO XX SuspenndedSbtFF ststato COMMISSION q N Suspended statuo SIO qSuspendedstat RBDMS HEW 10/8/2021 Well Name:North Trading Bay Unit SPR-09 Well Pressures (psi):Tubing 0 Surface Location:618’ FNL, 2076’ FEL, Sec 34, T10N, R13W S.M. IA 2 Permit to Drill:169-092 OA 8 API:50-733-20200-00-00 AOGCC Notified:Yes 8/18/1992 AOGCC Inspection Date:9/6/2021 317-582 AOGCC Inspector:Guy Cook Other Notes: Condition of Wellhead: Comments: Attachments:Photo of wellhead Plat - 1/4 mile radius of wellbore Wellbore Schematic Drilled and completed in November of 1969 with a TD of 10,387’ with PBTD of 10,369’ The well was suspended in August of 1992 by pumping a total of 47 bbls cement across the perforations with TOC in tubing at 9006’ and calculated TOC in casing at 9820’ utilizing coil tubing. Top depth of perforations is 10060’ leaving 1054’ of cement above the perforations in the tubing The well was circulated with 260 bbl inhibited FIW then 200 bbl 9.5# brine followed by 65 bbl inhibited FIW to leave weighted fluid in casing Well left SI with flowlines removed and blind flanges installed on tree Hilcorp continues to evaluate the potential to reactive the Spurr Platform, Hilcorp agrees to begin the process of planning the permanent abandonment of these wells Suspended Well Inspection Data Old & rusty, poor condition, no maintenance Condition of Surrounding Surface Location: Rusty, paint flakes everywhere Follow Up Actions Needed:Clean up area and sweep floor Date Suspended: Sundry Number: nt of these wellsplanning the permanent abandonmen Hilcorp continues to evaluate the potential to reactive the Spurr Platform, Hilcorp agrees to begin the process of _____________________________________________________________________________________ Updated By: JLL 11/17/17 SCHEMATIC North Trading Bay Field Well: SPR-09 Last Completed: 01/17/1972 PTD: 169-092 API:50-733-20200-00 PBTD:10,369’TD:10,387’ 9-5/8” RKB to Mudline: 165’ RKB to MLLW: 92’ 13-3/8” 36” Circulation holes in Tbg 9,597’-9,599’ and 10,033’-10,035’ TBG & CSG filled with Inhibited 8.5 ppg FIW and 200 BBL’s 9.5 ppg inhibited brine Calculated TOC in Csg@ 9,820’ Stage Collar @ 3,004’ TOC in Tbg @ 9,006’ CTM X CASING DETAIL Size Wt Grade Conn ID Top Btm 36” Surf ~300’ 13-3/8” 54.5# J-55 BTC 12.615” Surf 1,370’ 9-5/8” 47# N-80 Butt x 8rd 8.681” Surf 40’ 47# S-95 Butt 8.681” 40’ 60’ 43.5# N-80 Butt 8.755” 60’ 6,506’ 47# N-80 Butt 8.681” 6,506’ 8,214’ 47# S-95 Butt 8.681” 8,214’ 10,369’ TUBING DETAIL 3-1/2” 9.2# N-80 Butt 2.992” Surf 10,087’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status 10,060' 10,078' 9,639' 9,656'18' Isolated G 10,090' 10,150' 9,668' 9,727'60' Isolated 10,165' 10,193' 9,742' 9,770'28' Isolated 10,200' 10,278' 9,777' 9,854'78' Isolated HK 10,300' 10,369' 9,876' 9,944'69' Isolated JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 1 2,847’ 2,817’ GLM #1 - Camco 3-1/2” KBM Side Pocket Mandrels w/ Dummy Valves 4,688’ 4,487’ GLM #2 - Camco 3-1/2” KBM Side Pocket Mandrels w/ Dummy Valves 6,190’ 5,922’ GLM #3 - Camco 3-1/2” KBM Side Pocket Mandrels w/ Dummy Valves 7,449’ 7,111’ GLM #4 - Camco 3-1/2” KBM Side Pocket Mandrels w/ Dummy Valves 8,424’ 8,040’ GLM #5 - Camco 3-1/2” KBM Side Pocket Mandrels w/ Dummy Valves 9,149’ 8,747’ GLM #6 - Camco 3-1/2” KBM Side Pocket Mandrels w/ Dummy Valves 9,813’ 9,396’ GLM #7 - Camco 3-1/2” KBM Side Pocket Mandrels w/ Dummy Valves 2 10,037’ 9,616’ Otis XO Sleeve 3 10,040’ 9,619’ Baker Model D Packer 4 Unknown Unknown X Nipple 5 10,369’ Tail Notes: Fill: 10,358’ CTM (7/23/92) Trading Bay Unit North Trading Bay Unit S010N013W Sec. 23 S010N013W Sec. 22 S010N013W Sec. 21 S010N013W Sec. 26 S010N013W Sec. 27 S010N013W Sec. 28 S010N013W Sec. 35 S010N013W Sec. 34 S010N013W Sec. 33 S009N013W Sec. 2 S009N013W Sec. 3 S009N013W Sec. 4 Spark Spurr SPR-09 BHL 0 500 1,000 1,500 2,000 Feet Alaska State Plane Zone 4, NAD27 Legend Quarter-Mile Radius around Well Bore Oil and Gas Unit Boundary Map Date: 9/14/2021 NORTH TRADING BAY SPR-09 Suspended Well Location Map Overview Kenai Tyonek Anchorage HAK Petra Well Symbol Other Oil Dry P&A P&A Oil Suspended Page 8 of 8 I Suspended Well InspectionReview Rep{rf |nspec1No: susGDCI10913153949 Date Inspected: 9/6/2021 ' Inspector: Guy Cook' Type ofinspection: Subsequent Well Name: NTRADING BAY UNIT SPR -0Q Date AOGCCNotified: 9/1/2022 Permit Number: 1690920 Operator: Hi|co/pAlaska, LLC Suspension Approval: ` Operator Rep-, Tom Buchholz Suspension Date: 8/18/1992 Wellbore Diagram Avail? Location Verified? Photos Taken? |fVerified, How? Other (specify incomments) Offshore? W , Well Pressures (psi): Tubing: O - Fluid in Cellar? 11 |A: 2 ' 8PV|nstuUej7 [] ' OA: D VR P|ug(s) Installed? Wellhead Condition The wellhead is infair/poor condition with rust and paint failing off, The valves work asthey should and the gauges work as well. Nosigns ofleaking. ,' Condition ofCellar The cellar is very rusty and is littered with paint chips from the wellheads and surrounding painted surfaces. ^ Suononding5uface Condition Rusty and cove/ed in paint chips that have fell off the wellheads and the walls/ceiling. The platform is rusting away with little tonomaintanenceinprevent itfrom happening. Nnsigns ofhydrocarbons seen. ~ Com ments Location verified byplatform well room map. The wellheads nnthe Spurr have numaintanenceperformed unthem to prevent failures regarding integrity of the wellhead or the platform itself. There isnogreasing/servicing ufthe valves planned inthe future for any ofthe wells. | requested the area around the wells and the surrounding area tobecleaned up so the cellar and floor could be seen easier for inspections and for general safety concerns. L�~ Supervisor[omnnents Photo (1). Well Status changed from S|toSuspended byAOG[[8/1O/1992 ~' (>(z/ZjZ' Tuesday, October 12.2OI1 Suspended Well Inspection — NTBU SPR -09 PTD 1690920 AOGCC Inspection # susGDC210913153949 Photo by AOGCC Inspector G. Cook 9/6/2021 2021-0906_ Suspend_ NTBU_SPR-09_photo.docx Page 1 of 1 Hilcorp Alaska, LLC Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503November 24, 2020 Jeremy M. Price Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: Spurr Platform Yearly Status Report for Suspended Well Status; Sundry Numbers: 317-580, 317-581, 317-582, 317-584, 317-585, 317-586, 317-587. Dear Chair Price: On December 15, 2017, the AOGCC approved the Hilcorp Alaska, LLC (Hilcorp) Sundry Applications to renew the suspended status for the Spurr Platform’s North Trading Bay Unit SPR- 01, SPR-02, SPR-03, SPR-04, SPR-06, SPR-08 and SPR-09 wells, under Sundry Numbers 317- 580, 317-581, 317-582, 317-584, 317-585, 317-586, and 317-587. As a condition of approval, a yearly platform repair status report was to be submitted to the AOGCC. During 2020, Hilcorp performed the following work on the Spurr platform in preparation of future plugging and abandonment work, exceeding the planned work on the schedule submitted to the AOGCC for the suspension renewal: x Mobilized crew to Spurr to demo legacy rigs. During this mobilization the winch on the Unit crane failed. A repair plan has been developed and long lead material is on order to change out the obsolete friction winch to a hydraulic winch system. This material is expected to be delivered in early 2021. The current goal is to have the crane operational by May 2021. Once the crane work is completed, construction work will resume to prepare the facility for P&A activities. With the work completed in 2020, Hilcorp is running one season behind schedule and expects to start well diagnostic work in 2022, a year behind the schedule submitted to the AOGCC with the sundry for suspension renewal. Hilcorp is available at the commission’s convenience to discuss the work that was completed this year, as outlined above. Should you have any additional questions, please contact Dan Marlowe at 907-283-1329. Sincerely, Dan Marlowe Operations Manager Hilcorp Alaska, LLC By Samantha Carlisle at 11:47 am, Nov 24, 2020 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267), ou=Users Date: 2020.11.24 10:59:44 -09'00' Dan Marlowe (1267) Hilcorp Alaska, LLC Post Office 9oa 24" 0; , Anchorage, AK 99 5,.,; 4011 3800 CenterooiM Drwe November 21, 2019 suite 1400 Anchorage, AK 995,1, Jeremy M. Price I�� Chair, Commissioner Vu Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: Spurr Platform Yearly Status Report for Suspended Well Status; Sundry Numbers: 317-580, 317-581, 317-582, 317-584, 317-585, 317-586, 317-587. Dear Chair Price: On December 15, 2017, the AOGCC approved the Hilcorp Alaska, LLC (Ilileorp) Sundry Applications to renew the suspended status for the Spurr Platform's North Trading Bay Unit SPR - 01, SPR -02, SPR -03, SPR -04, SPR -06, SPR -08 and SPR -09 wells, under Sundry Numbers 317- 580, 317-581, 317-582,317-584,-)17-585, 317-586, and 317-587. Asa condition of approval, a. yearly platform repair status report was to be submitted to the AOGCC. During 2019, I lilcotp performed the following work on the Spurr platform in preparation of litiure plugging and abandonment work, exceeding the planted work on the schedule submitted to the AOCCC for the suspension renewal: • Inspected Helideck,'Pipe Rack, and Crane Pedestal Support to evaluate structural Integrity With the work completed in 2019, Hileorp is currently on schedule to start well diagnostic work in 2021 per the schedule submitted to the AOGCC with the sundry for suspension renewal. Hilcorp is available at the commission's convenience to discuss the work that was completed this year, as outlined above. Should you have any additional questions, please contact Dan Marlowe at 907-283-1329. Sincerely, ��" '11 4, Stan Golis Operations Manager Hilcorp Alaska, LLC MDMS±�j NOV 2 7 2019 RECEIVED NOV 2 2 2019 A0GGG • Hilcorp Alaska, LLC December 5, 2018 Hollis French Chair, Commissioner ?-\�b R-AcR z o E Post Office Box 244027 Anchorage, AK 99524-4027 �`Q � 3800 Centerpoint Drive �• •Nil 1i!t (` Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission DEC 10 2018 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: Spurr Platform Yearly Status Report for Suspended Well Status; Sundry Numbers: 317-580, 317-581, 317-582, 317-584, 317-585, 317-586, 317-587. Dear Chair French: On December 15, 2017, the AOGCC approved the Hilcorp Alaska, LLC (Hilcorp) Sundry Applications to renew the suspended status for the Spurr Platform's North Trading Bay Unit SPR -01, SPR -02, SPR -03, SPR -04, SPR -06, SPR -08 and SPR -09 wells, under Sundry Numbers 317-580, 317-581, 317-582, 317-584, 317-585, 317-586, and 317-587. As a condition of approval, a yearly platform repair status report was to be submitted to the AOGCC. During 2018, Hilcorp performed the following work on the Spurr platform in preparation of future plugging and abandonment work, exceeding the planned work on the schedule submitted to the AOGCC for the suspension renewal: • Inspected cranes, ordered replacement parts and performed the following work: o Installed upgraded starting system o Replaced boom clutch o Replaced all load cables o Performed annual crane inspection o Performed load testing Skidded the drilling rig substructure +/-8 feet south, to provide more clearance to the helideck to support larger (212) helicopter landings. With the work completed in 2018, Hilcorp is currently on schedule to start well diagnostic work in 2021 per the schedule submitted to the AOGCC with the sundry for suspension renewal. Hilcorp is available at the commission's convenience to discuss the work that was completed this year, as outlined above. Should you have any additional questions, please contact Michael Quick at 907-777-8442. Sincerely, t�, � Stan Golis Operations Man ger Hilcorp Alaska, LLC RBDM$C 3 2019 V OF 7w .1P / s THE STAT• • Alaska Oil and Gas (4,0611:1 OfA L A SKA Conservation Commission Witt333 West Seventh Avenue JO?® ALAS— jP GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 LA -.tFax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager SCONS `tiN 2 9 :106 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: North Trading Bay Field, G-NE and Hemlock NE Oil Pools, SPR-09 Permit to Drill Number: 169-092 Sundry Number: 317-582 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC • an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French �.� Chair DATED this day of December, 2017. RE : s i - EEC I • RECEIVED STATE OF ALASKA DEC 2 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A�� 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations El Fracture Stimulate ❑ Repair Well El Operations shutdown Suspend ❑ Perforate El Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill El Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing El Other: Suspended Well Renewal [=l• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development ❑ 169-092 ` 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 6.API Number. Anchorage,AK 99503 50-733-20200-00 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 0 / North Trading Bay Unit SPR-09 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017597 • Trading Bay/G-NE Oil,Hemlock-NE 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): 10,387 • 9,962 • 9,006 • • 8,607 3,214 psi 9,006 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 1,338' 13-3/8" 1,370' 1,365' 2,730 psi 1,130 psi Production 10,377' 9-5/8" 10,369' 9,944' 7,510 psi 4,130 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 3-1/2" 9.2#/N-80 9,006 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A NA&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory El Stratigraphic El Development❑ Service 0 • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL El WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG El GSTOR El SPLUG El Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis Contact Name: Michael Quick Authorized Title: Operations Manager Contact Email: mqui s@,I- 1iICOrp.com Contact Phone: (907)777-8442 Authorized Signature: ` d-• Date: t ' I t 2 1'�, COMMISSION USE ONLY Conditions of approval: Notify Commissio so that a representative may witness Sundry Number 311. qa Plug Integrity ❑ BOP Test ElMechanical Integrity Test ❑ Location Clearance ❑ Other: ,i4" 4.4f s�(ii t°/4=-4-44P-4"•‘- re _e' - .P- re,rd' &,.. 13krul s7o.Tv1/4% 1/0.1 Ili -jvct% - J 31, X2.1 Post Initial Injection MIT Req'd? Yes ❑ No ❑ e�g Spacing Exception Required? Yes ❑ No Q/ Subsequent Form Required: NO po4i" ) RED- 3L _ F.: W r,t, APPROVED BY `f < ' Approved by: to.:20 COMMISSIONER THE COMMISSION Date: !i J A \ 4x I A f! 1 4,11 ORIGINAL , /247 Submit Form and \Pl J Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 December 11, 2017 RECEIVED Hollis French DEC 12 2017 Chair, Commissioner �n Alaska Oil and Gas Conservation Commission AOGCC 333 West Seventh Avenue Anchorage, AK 99501-3572 Re: Spurr Platform Request for Renewal of Suspended Well Status Dear Chair French: On October 25, 2017, the AOGCC denied the Hilcorp Alaska, LLC (Hilcorp) Sundry Applications to renew the suspended status for the Spun Platform's North Trading Bay Unit SPR-01, SPR-02, SPR-03, SPR-04, SPR-06, SPR-08 and SPR-09 wells, giving Hilcorp 30 days to submit sundry applications for the plugging and abandonment of these wells. Hilcorp requested and was granted an additional 30 day extension on November 15, 2017. The current suspended well status for these wells expires on January 2, 2018. The Spun platform, located in the Cook Inlet, has been in"lighthouse" configuration since 1992, after Marathon placed reservoir isolating cement plugs in each wellbore, and the AOGCC granted suspension status for each well. Wellhead pressure readings are recorded monthly, and the pressures are stable. An AOGCC inspector witnessed the required well inspections on September 5, 2017. Although Hilcorp continues to evaluate the potential to reactive the Spun Platform, Hilcorp agrees to begin the process of planning the permanent abandonment of these wells. Due to the current condition of the platform, many items will need to be addressed prior to commencing any well work. The platform crane is currently inoperable, and will need to be repaired or replaced. A complete structural review of the helideck and drilling deck is needed, and could lead to subsequent repairs. The living quarters and life support systems are currently not serviceable, and will need to be repaired or replaced. The legacy drilling derricks have been partially deconstructed, and the work to remove the remaining derrick components needs to be completed. Hilcorp is submitting a 10-403 Sundry Application for the renewal of suspended well status for each of these 7 wells, along with the current plug and abandonment plan for each well as requested by the AOGCC. Also included is the current planning schedule for the required platform work that will be completed prior to the execution of well work. This current planning schedule starts the plugging and abandonment well work in July of 2021, and is subject to change based on the actual platform conditions that are encountered. The plug and abandonment plan is based on the currently available well information, and is also subject to change. There is one additional well on the Spurr Platform, North Trading Bay Unit SPR-07, listed as long term ORIGINAL i • Chair Hollis French Re: Spurr Platform Request for Renewal of Suspended Well Status December 11,2017 Page 2 of 2 shut in, that Hilcorp will address with a separate sundry application. The timeframe for work on the SPR-07 well will follow the same planning schedule as the suspended wells on this platform. Hilcorp is available at the commission's convenience to discuss the Sundry Applications. Should you have any additional questions,please contact Michael Quick at 907-777-8442 or Dan Marlowe at 907-283-1329. Sincerely, S 6.....%.3 A rk.:,, Stan Golis 1 Operations Manager Hilcorp Alaska, LLC • • Well Work Prognosis Hilcorp Alaska,1,1,C, Date: 11/28/2017 Well Name: North Trading Bay Field API Number: 50-733-20200-00 SPR-09 Current Status: Suspended Oil Well Leg: Leg#1 (NW corner) Estimated Start Date: Estimated Summer 2022 Rig: TBD Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 169-092 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Mike Quick Office: 907-777-8442 Cell: 907-317-2969 Current Bottom Hole Pressure: 4,154 psi @ 9,403'TVD 0.442 psi/ft(8.50 ppg)well is loaded with KWF Maximum Expected BHP: 4,154 psi @ 9,403'TVD 0.442 psi/ft(8.50 ppg)well is loaded with KWF Maximum Potential Surface Pressure: **3,214 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) **Alternate Pressure Calculation Requested—SPR-09 is Suspended with 0 psi SITP and 8.5 ppg Inhibited FIW above TOC at 9,403' TVD. Max Surface Pressures Recorded since Hilcorp took over the facility Tubing 0 psi IA 2 psi OA 6 psi Brief Well Summary: Well SPR-09 a suspended oil well completed in the Middle Kenai and Hemlock sands. Perforations were isolated with cement in 1992 and wellbore filled with 8.5 ppg inhibited FIW.This project will P&A the well in accordance with 20 AAC 25.112. Prior to well work commencing several items need addressed.These items will have significant impact to anticipated schedule: • Facility crane is inoperable and needs repairs or replacement • Structural review/repair for Helideck and drill deck • Legacy derricks are partially deconstructed (decks must be cleared) • Living Quarters and life support systems are not serviceable and needs repairs or replacement Last Casing Test: 08/04/1992 9,006' 1,500 psi for 30 minutes (Top of cement plug in tubing tagged with coil, IA TOC estimated at 9,820') Procedure: Phase I 1. Rig up pumping equipment 2. Pressure test tubing and IA to 1,500 psi and chart for 30 minutes 3. CONTINGENCY: If pressure test doesn't hold a remedial zone isolation plug will need pumped a. RU E-Line, RIH and punch holes in tubing at±9,000'. b. Establish injection down tubing taking returns up the and circulate enough cement for at least a 100' plug in tubing and IA per 20AAC25.112(c)(1)(C) c. Pressure test tubing and IA to 1,500 psi and chart for 30 minutes • • • Well Work Prognosis Hilrorp Alaska,I.,.c Date: 11/28/2017 Phase II 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line and cut tubing at±1,550'. 3. RD E-line. Phase III 4. Rig up workome_r rig,ca ang jacks, or iack ua rie, 5. Circulate hydrocarbon off the well, if present. Work over fluid will be brine and/or drill water. 6. ND Wellhead, NU BOP and test to 250psi low/2,500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test and plugging operations). 7. BOP's will be closed as needed to circulate the well. 8. Monitor well to ensure it is static. 9. Unseat hanger and POOH with production tubing. 10. RU E-line and set CIBP @ ±1,500' MD. 11. Pressure test to 1,500 psi and chart for 30 minutes. 12. RIH with ±4' of big hole charges to ±1,490' and shoot holes in IA. 13. Place Cement Plug (Satisfies both surface casing shoe and surface plug requirements per 20AAC25.112(c)(3) and 20AAC25.112(d)(1) a. Attempt to establish circulation between the IA and OA: i. If circulation through OA is successful, circulate cement to bring TOC to regulated depth. (Between 10' to 30' below mudline) b. If circulation between the IA and OA is unsuccessful: i. RIH with cement string to ±1,495'. ii. Spot sufficient cement in IA to bring TOC to regulated depth. (Between 10'to 30' below mudline) iii. POOH to 15' below mudline and circulate clean. iv. POOH laying down cement string. 14. ND BOP and install well bore cover plate or dry hole wellhead. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. High level anticipated project schedule • North Trading Bay Field • Well:SPR-09 II SCHEMATIC Last Completed:01/17/1972 PTD: 169-092 Hilcorp Alaska,LLC API: 50-733-20200-00 RKB to Mudline:165' RKB to MLLW:92' CASING DETAIL Size Wt Grade Conn ID Top Btm 36 , 36" Surf "300' ; 13-3/8" 54.5# J-55 BTC 12.615" Surf 1,370' r , 47# N-80 Butt x 8rd 8.681" Surf 40' 133/8 j,t', -. 47# S-95 Butt 8.681" 40' 60' '4' 9-5/8" 43.5# N-80 Butt 8.755" 60' 6,506' • = 47# N-80 Butt 8.681" 6,506' 8,214' 47# S-95 Butt 8.681" 8,214' 10,369' Stage collar TUBING DETAIL @3,034' 3-1/2" 9.2# N-80 Butt 2.992" Surf 10,087' TBG&CSG filled with JEWELRY DETAIL Inhibited 8.5 ppgFlWand Depth Depth 203 BBL's 9.5 No (MD) (ND) ID Item ppg inhibited 2,847' 2,817' GLM#1-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves brine 4,688' 4,487' GLM#2-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves 6,190' 5,922' GLM#3-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves 1 7,449' 7,111' GLM#4-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves 8,424' 8,040' GLM#5-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves 9,149 8,747' GLM#6-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves TOC inTbg@ 9,813' 9,396' GLM#7-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves r 9,006'CTM 2 10,037' 9,616' Otis XO Sleeve 3 10,040' 9,619' Baker Model D Packer 4 Unknown Unknown X Nipple Orculation 5 10,369' Tail holes in Tbg 9,597-9,599' and 10,033'-10,035' dr'-1.: Calculated ❑0❑ • TOC inCsg@' 9,820' X .'. ' PERFORATION DETAILTop Btm Top Btm Zone (MD) (MD) (TVD) (TVD) FT Date Status 10,060' 10,078' 9,639' 9,656' 18' Isolated ' , G 10,090' 10,150' 9,668' 9,727' 60' Isolated 10,165' 10,193' 9,742' 9,770' 28' Isolated 10,200' 10,278' 9,777' 9,854' 78' Isolated HK 10,300' 10,369' 9,876' 9,944' 69' Isolated = Notes: •, Fill: 10,358'CTM(7/23/92) P BTD:10,369' TD:10,387' Updated By:JLL 11/17/17 • . North Trading Bay Field Well:SPR-09 II PROPOSED Last PTD:Com 092 pleted: FUTURE 169 HiIcory Alaska,LLC API: 50-733-20200-00 RKB to Mudline:165' RKB to MLLW:92' CASING DETAIL �R rj�. Size Wt Grade Conn ID Top Btm r,s �. 36" Surf 300' `��• 13-3/8" 54.5# J 55 BTC 12.615" Surf 1,370' 47# N-80 Butt x Srd 8.681" Surf 40' 4 Piiit.�' ° 133/8 fir 1,7 R 47# S-95 Butt 8.681" 40' 60' 9-5/8" 43.54 N-80 Butt 8.755" 60'i'll 47# N-80 Butt 8.681" 6,506' 8,214' ` 47# S-95 Butt 8.681" 8,214' 10,369' 114.41' I to i Stage Collar TUBING DETAIL @3,004' 3-1/2" 9.2# N-80 Butt 2.992" ±1,550' 10,087' TBG&CSG filledwth JEWELRY DETAIL Inhibited 8.5 ppgFlWand No Depth Depth ID Item 200BBL's9.5 (MD) (TVD) ppg inhibited ±185' Top of Cement(must be 10'to 30'below mudline) brine ±1,490' Casing Perfs s ±1,500' CIBP set a minimum of 100'below surface casing shoe ±1,550' Top of E-Line Cut Tubing 2,847' 2,817' GLM#1-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves 4,688' 4,487' GLM#2-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves - TOC inTbg@ 6,190' 5,922' GLM#3-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves 0 9,006'CTM - 1 7,449' 7,111' GLM#4-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves 8,424' 8,040' GLM#5-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves • 9,149' 8,747' GLM#6-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves 'M Grculation 9,813' 9,396' GLM#7-Camco 3-1/2"KBM Side Pocket Mandrels w/Dummy Valves holes inTbg 2 10,037' 9,616' Otis XO Sleeve r� ., 9,597'-9,599' 3 10,040' 9,619' Baker Model D Packer dA and 4 Unknown Unknown X Nipple 10,033'40,035' d 5 10,369' Tail `- a� •.4- Calculated Till In ,7 TOC in Csg @''. •t .I,�.a-..d 9,820' ' , ' PERFORATION DETAIL Zone Top Btm Top Btm FT Date Status (MD) (MD) (TVD) (TVD) .:.t_ 't` r . 10,060' 10,078' 9,639' 9,656' 18' Isolated G 10,090' 10,150' 9,668' 9,727' 60' Isolated .:, .,..t,: ...43:., -, 10,165' 10,193' 9,742' 9,770' 28' Isolated .`.,r »i 10,200' 10,278' 9,777' 9,854' 78' Isolated .tt4 .'4 ='I> HK 10,300' 10,369' 9,876' 9,944' 69' Isolated r ''.... Notes: . Fill:10,358'CTM(7/23/92) 9-5/8" "4 PBTD:10,369' TD:10,387' Updated By:JLL 11/17/17 ` 111 • 0 g ©iJ�J�41r3©© © i7 �7r36:©© i: dl©51 n7 FJ AJ©R: S o ooh so yy� fpr O _�2 0 z p f O tC m'per �pn m'per to m F _ i O(O F O O N O *$ n -'N d (U ()N_ (D 2 'd N "'-2-2 -0.,,,-- 3 T QT_Q 55� - a F ,T, -,-..9. d n 0 (""-1,7i X d o m o y_v A< 0 - w a T a. Qv`l 30 6--o< 3 a m °' H m o w m c m O -92' N49, ..4,. - m ( ° H.c m n m c m o m m co 5 y s a' � 1z F 9 �"m m��co ao m rn �rn rnrn rn cn u� ui oo cr�..� � •_.._.� un o � '.] ] N N N N N Z' N N C2 N N N Q N N N N-'Q2 N N;.3 } _ _ '.O O O O O N N O O N N O O O N O N O O N N O O O N. L a a ',,..N ND ND NJ KJ O O N N O O N N N O ND O O O O O O d 3. 0000 0000 0_ o-m ----.m.- .. 'm aom m�'.,,. 3 u C - 01 c0 f0(T t0 01 0(0 .T '�` 3 . tO(0-.ca�I tO l0(O-.t0 V V Q.V t0 rn-u fT _. m 2. O O Ot 0 0 Ot O_. Ut+0 0 rn O O O O O O O S5 N c,N T N N N N N N N N N N N N N N N N N N N N N N O N C' ON O O N N O O O N O O O N N O NO O O.O O O CO 0 0 C O. N»+N O0 00 0000 0-+ . co-O l0 CO CO CO CO V i o E a E E g z. 4 .a 3 3 I 3 3 t 2 1 t' II s flip ir.„ r ,.. 10 .1.',.' F Igo - ^ A -, so , , _ P1 a1 r. r.i • .a . • Suspended Well Inspection Data Well: SPR-09 Surface Location: 618' FNL, 2076' FEL, Sec 34, T10N, R13W S.M. Permit to Drill: 169-092 API: 50-733-20200-00 AOGCC Inspection Date: 09/05/17 AOGCC Inspector: Mr. Guy Cook Size Pressure (psi) Tubing 3-1/2" 0 Casing 13-3/8" 6 9-5/8" 2 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Drilled and completed in November of 1969 with a TD of 10,387' with PBTD of 10,369'. • The well was suspended in August of 1992 by pumping a total of 47 bbls cement across the perforations with TOC in tubing at 9006' and calculated TOC in casing at 9820' utilizing coil tubing. Top depth of perforations is 10060' leaving 1054' of cement above the perforations in the tubing • The well was circulated with 260 bbl inhibited FIW then 200 bbl 9.5# brine followed by 65 bbl inhibited FIW to leave weighted fluid in casing • Well left SI with flowlines removed and blind flanges installed on tree • Hilcorp continues to evaluate the potential to reactive the Spurr Platform, Hilcorp agrees to begin the process of planning the permanent abandonment of these wells • Condition of Wellhead: Overall okay. Gauges operable. Platform Lighthoused. No production. • Condition of Surrounding Surface Location: Clean up around wellhead, loose paint & rust • Follow Up Actions Needed: Cap or plug any open valves, tubing (Completed) • No SSV. Attachments: • Current Well Schematic • Picture(s) • Plat- 1/4mile radius of wellbore w t 1 '` ' ' lip `�.:1 yµ > r r' z . ., .._ f rx iii; „' ii.„, ,.,... . { k✓ f tilk • ,.' I ) , 1 I t 4 : 4%i .,..,,,.s .4,,,,.. 4", , . , t.:4,- ,.,,, ,,.Y r _ *„ • .... 4.. /111111f- qq ~M w of 401.:-.;°, gyp t / r k -„, f I , )‘ } .,,,'41V i ,, i, • N Trading Bay Field Scale: Interpreter: 1"=500' M.Frankforter Date: Projection: 09/04/2015 NAD27 Alaska State Plane 4 FEET 10,770 S-04 S-03 SPR-09 S-01 RD • S-01 SPR-01 'I .0,\11/ 4s). OF,Tji� STATE .0 \� 1/ s,, THEAlaska Oil and Gas ofLASI�;A Conservation Commission _:_� _ A £ = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov October 25, 2017 Stan W. Golis Operations Manager Hilcorp Alaska,LLC 3800 Centerpoint Drive, Ste 1400 s` DECRED 1 4201Z Anchorage,AK 99503 Re: Sundry Applications for Renewal of Suspended Well Status NTBU SPR-01 (PTD 168-048): Sundry Number 317-465 NTBU SPR-02 (PTD 168-050): Sundry Number 317-467 NTBU SPR-03 (PTD 168-065): Sundry Number 317-470 NTBU SPR-04(PTD 168-066): Sundry Number 317-471 NTBU SPR-06 (PTD 168-090): Sundry Number 317-472 NTBU SPR-08 (PTD 169-027): Sundry Number 317-473 TBU SPR-09(PTD 169-092): Sundry Number 317-474 Dear Mr. Golis: By the applications listed above, Hilcorp Alaska, LLC (Hilcorp) requests the Alaska Oil and Gas Conservation Commission (AOGCC) renew suspension status for the North Trading Bay Unit SPR-01, SPR-02, SPR-03, SPR-04, SPR-06, SPR-08 and SPR-09 wells. Production from the Spun Platform ceased in 1992 with these wells placed in suspension status since that time. For the wells to remain in suspended status, Hilcorp must demonstrate that each well has a future utility as an exploratory, development or service well or is a viable candidate for re-drilling. Hilcorp's requests fail to do so. The request to renew the status of the wells as suspended is DENIED.Within 30 days,Hilcorp must submit Sundry Applications for the proper plugging and abandonment of the aforementioned wells. This denial is without prejudice to Hilcorp's right to submit applications that include sufficient information to demonstrate that each well either has a future utility as an exploratory, development or service well, or is a viable candidate for re-drilling. Sincerely, Hollis S. French Chair,Commissioner RBDNIS ut,1 L 6 2017 • • RECONSIDERATION AND APPEAL NOTICE Unless an application for reconsideration is filed,this is the AOGCC's final order or decision and any appeal must be filed in superior court within 30 days of the date this order or decision is mailed or otherwise distributed. As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction,in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. • • • I OCT 03207 STATE OF ALASKA AOG 01 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ ange Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Sus•ended Well Renewal p 2.Operator Name: 4.Current Well Class: 5.Permit Drill Number. Hilcorp Alaska,LLC Exploratory 0 Development ❑ 169-09 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 6.AP umber. Anchorage,AK 99503 50-733-20200-00 7. If perforating: 8.Well .me and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 No Trading Bay Unit SPR-09 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017597 Trading Bay/G-NE Oil,Hemlock-NE Oil Po. 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): 10,387 9,962 9,006 8,607 P psi 9,006 N/A Casing Length Size MD TVD Burst Collapse ,— Structural Conductor Surface Intermediate 1,338' 13-3/8" 1,370' \ 1,365' 2,730 psi 1,130 psi Production 10,337' 9-5/8" 10,36' 9,944' 7,510 psi 4,130 psi Liner /1 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing ze: Tubing Grade: Tubing MD(ft): N/A N/A 3-1/2" 9.2#/N-80 9,006 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/ANA&N/A 12.Attachments: Proposal Summary ❑ Wellbore schema r 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 14. Estimated Date for LI 15.Well Status after proposed work: Commencing Operations: "NI OIL ❑ WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: 0N.,, GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: 'N., GINJ ❑ Op Shutdown ❑ Abandoned LI 17. I hereby certify that the foregoing is true and th- •rocedure 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: dmarlowe©hilcorp.com Contact Phone: (907)283-1329 Authorized Signature: t� Date: ID PS 111 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number.3 ),7 / I I/v 1(�I/, Plug Integrity ❑ B••Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT r'eq'd? Yes ❑ No ❑ RBDr S LL rJt,i i 6 2U17 Spacing Exception Re. ired? Yes ❑ No ❑ Subsequent Form Required: / APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ORIGINAL Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Suspended Well Inspection Data Well: SPR-09 Surface Location: 618' FNL, 2076' FEL, Sec 34, T10N, R13W S.M. Permit to Drill: 169-092 API: 50-733-20200-00 AOGCC Inspection Date: 09/05/17 AOGCC Inspector: Mr. Guy Cook Size Pressure (psi) Tubing 3-1/2" 0 Casing 13-3/8" 6 9-5/8" 2 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Drilled and completed in November of 1969 with a TD of 10,387' with PBTD of 10,369'. • The well was suspended in August of 1992 by pumping a total of 47 bbls cement across the perforations with TOC in tubing at 9006' and calculated TOC in casing at 9820' utilizing coil tubing. Top depth of perforations is 10060' leaving 1054' of cement above the perforations in the tubing • The well was circulated with 260 bbl inhibited FIW then 200 bbl 9.51# brine followed by 65 bbl inhibited FIW to leave weighted fluid in casing • Well left SI with flowlines removed and blind flanges installed on tree • Hilcorp plans to continue to evaluate potential to reactivate the Spurr platform and therefore have no current plans for abandonment • Condition of Wellhead: Overall okay. Gauges operable. Platform Lighthoused. No production. • Condition of Surrounding Surface Location: Clean up around wellhead, loose paint & rust • Follow Up Actions Needed: Cap or plug any open valves, tubing (Completed) • No SSV. Attachments: • Current Well Schematic • Picture(s) • Plat - 1/4mile radius of wellbore • • NORTH TRADING BAY UNIT SPURR PLATFORM WELL T/S-9 YELL SECURING 8/92 "' AU measurements are RKB to top of equipment Conoietien Stringy•. 0' - 10.087' 3-1/2', 921, N-80 Tb¢ -� L370' 13-3/r, 54.51, J-55 Csg. AU gas lift mandrels are Canco 3-1/2' KBM J Side Pocket Mandrels with Dummy Valves. TBG 6 CSG ➢lQ112 Valve' I.v.SdL FILLED VITH 2,847' 1 Dummy INHIBITED 8.5 mg FIV J 4,688' 2 AND 200 BBL'S 9.3 ppg 6,190' 3 INHIBITED BRINE J 7,449' 4 Out of Pocket TOC IN TBG 8,424' 5 Dummy 9406' CTM 9,149' 6 9,813' 7 • CIRC. HOLES IN TBG I! 9.597.5-9,599' N 9,820' Calcualed TOC in Csg. 10.033.5'-10,035' 10,037' Otis x-0 Sleeve /�_ 10.040' Baker Model 'D' Packer PERFORATIONS DU. /' 10.060' - 10.078' 10.090' - 10.150' 10.165' - 10.193' 10.200' - 10.278' 10.300' - 10.369' F41 B 10.358' CTM 7-23-92 10,369' -5/8'9 43.51 L 471 PBTD • Revision Doty 9/8/92 Revised By' JDM/tvo TD ■ 10.387' Reason Veil Securing 1 Previous Revision 4/15/92 • • ✓y • r %; I S N Trading Bay Field Scale: Interpreter: 1"=500' M.Frankforter Date: Projection: 09/04/2015 NAD27 Alaska State Plane 4 0 1D0 1�3O FEET 1070 S-04 S-03 SPR-09 S-01 RD • z�. S-01 SPR-01 P�OF,TFJ� • • �,i 177,'cv THE STATE Alaska Oil and Gas �w 71 (ALAS KA Conservation Commission Witt2 333 West Seventh Avenue u GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Iliiit � ;. o ;;. Main: 907.279.1433 AL AS Fax: 907.276.7542 www.aogcc.alaska.gov Trudi Hallett RANK ill 2 6 116. Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Trading Bay Field, G-NE and Hemlock-NE Oil Pools,NTBU SPR-09 Permit to Drill Number: 169-092 Sundry Number: 315-607 Dear Ms. Hallett: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this7day of January,2016. \1° • • RECEIVED STATE OF ALASKA SEP 2 5 2 15 ALASKA OIL AND GAS CONSERVATION COMMISSION 0I t e , APPLICATION FOR SUNDRY APPROVALS AD 0 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend E Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspended Well Renewal 0 2.Operator Name: 4.Current Well Class: y(� 5.Permit to Drill Number: Hilcorp Alaska,LLC • Exploratory 111 Development 'T" 169-092 ' 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service [ 6.API Number: Anchorage,AK 99503 50-733-20200-00 • 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 0 d North Trading Bay Unit SPR-09 - 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL0017597 Trading Bay/G-NE Oil,Hemlock-NE Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): - 10,387 ' 9,962 - 9,820 9,402 9,820 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 1,338' 13-3/8" 1,370' 1,365' 2,730 psi 1,130 psi Production 10,337' 9-5/8" 10,369' 9,944' 7,510 psi 4,130 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 3-1/2" 9.2#/N-80 9,006 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: / *43 Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ ,velopment L' Service A 14. Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSP❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTO❑ SPLUG ❑ Commission Representative: GIN,' ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett Email thallett@hilcorp.com Printed Name 31A,(JtITrudi Hallett Title Operations EngineerSignature /— Phone (907)777-8323 Date /Al--//t5 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: (/ —• (4O 7 Plug Integrity ❑ BOP Test CI Mechanical Integrity Test ❑ Location Clearance ❑ !� Other: vi sip&J S-17,,-I-1,. & / cJ w,fiyanA i ao/g. a\A \ ' coo Spacing Exception Required? Yes ❑ No I Subsequent Form Required: 1 V 6 Fes.-,v. 1J ,ES IIII APPROVED BY / Approved by: ( i) �� COMMISSIONER THE COMMISSION Date: — 7 -/6 OR GINAL 124 'all's ?It- la- e)---1 Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • Suspended Well Inspection Data Well: SPR-09 Surface Location: 618' FNL, 2076' FEL, Sec 34, T10N, R13W S.M. Permit to Drill: 169-092 API: 50-733-20200-00 AOGCC Inspection Date: 9/19/15 AOGCC Inspector: Matt Herrera Size Pressure (psi) Tubing 0 Casing IA 0 OA/OOA 4/N/A *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Drilled and completed in November of 1969 with a TD of 10,387' with PBTD of 10,369'. • The well was suspended in August of 1992 by pumping a total of 47 bbls cement across the perforations with TOC in tubing at 9006' and calculated TOC in casing at 9820' utilizing coil tubing. Top depth of perforations is 10060' leaving 1054' of cement above the perforations in the tubing • The well was circulated with 260 bbl inhibited FIW then 200 bbl 9.5# brine followed by 65 bbl inhibited FIW to leave weighted fluid in casing • Well left SI with flowlines removed and blind flanges installed on tree • Hilcorp plans to continue to evaluate potential to reactivate the Spurr platform and therefore have no current plans for abandonment • Condition of Wellhead: Good. Gauges operable. Platform Lighthoused. No production. • Condition of Surrounding Surface Location: Good. No standing water or oil sheen discoloration around well head or in cellar area. • Follow Up Actions Needed: Monitor IA and OA pressure and visual inspection by Operator. • No SSV. Attachments: • Current Well Schematic • Picture(s) • Plat - 1/4mile radius of wellbore • Correspondence/Suspended Well Inspection Report • • NORTH TRADING BAY UNIT SPURR PLATFORM WELL T/S-9 WELL SECURING 8/92 I All neostrenents ore RKB to top of equipment la (:nnMvtion String 0' - 10.087' 3-1/2•, 9.21, N-80 Tbg. J 1.370' 13-3/8', 54.51. J-55 Csg. All gas lift mandrels are Coraco 3-1/2' KBM J Side Pocket Mandrels with Dummy Valves. TBG 1 CSG DInth Voyf Lune FILLED VITH 2847, I Dummy Y 8.5 ppg FIV .J 4,688' 2 AND 200 BBL'S 9.5 PPO 6,190• 3 ' INHIBITED BRINE J 7,449' 4 Out of Pocket TOC 1N TBG 8,424' 5 Dunny ! 9,006' CTM OF 9149' 6 • 9,813' 7 • CIRC. HOLES IN TBG I AND 7 5-9.399' I 9,820' Cnlcunled TOC n Cs¢ 10.033.5'-10.035' AV14037' Otis X-0 Sleeve 7-.:-Ad _ 10.040' Baker Model •D' Packer re PEJ2FORATIONS OIL /' 10.060' - 10.078' 10.090' - 10.130' 10.165' - 10.193• 10.200' - 10,278' 10.300' - 10.369' ',/ /1/~ Fill 1110.358' CTM 7-23-92 14369' 9-5/8•, 43.51 L 471 Cs¢ I I PBTD ■ 10.369' Revision Dntr 9/8/92/4- I Revised Bye JDM/evo I Revised L, , TD is 10.387' Reason, Vett Securing Previous Revisipr 4/15/92 .i,..' 7(--pcic3 • 0 LC) ' 1111 b a 4 .µ: fr I' wY '1.-.''''' w I - '' ' ' , . , .„,, ,,.,, 7 - -,rsti. ,4 :472* • '4 ; �r.4 F c r ' /' ro votistt c ; r Mw,.. �. ... tau A; API St v • . N Trading Bay Field Scale: Interpreter: 1"=500' M.Frankforter Date: Projection: 09/04/2015 NAD27 Alaska State Plane 4 E- • S-04 S-03 SPR-09 S-01 RD S-01 SPR-01 111 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/19/15 Inspector: Matt Herrera Operator: HILCORP Well Name: SPR-09 Oper.Rep: Paul Taylor PTD No.: 169092 Oper.Phone: 907-776-6640 Location Verified? Yes Oper.Email: ptavlor(alhilcorp.com If Verified,How? LAT/LONG Onshore/Offshore: Offshore Suspension Date: 08/01/92 Date AOGCC Notified: 09/09/15 Sundry No.: N/A Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0-PSI Photos Taken? Yes IA 0-PSI OA/OOA 4/N/A-PSI Condition of Wellhead: Good,Gauges operable Platform Abandoned no production Condition of Surrounding Surface Location: Good no standing water or oil sheen discoloration around well head or in cellar area Follow Up Actions Needed: Monitor IA and OA pressure and visually inspection by Operator Comments: No SSV Attachments: Photos of Well Head REVIEWED BY: Insp.Supry Available from Operator Comm PLB 12/2014 Suspended Well SPR-09Form • • Bettis, Patricia K (DOA) f T J /69 -O9Z From: Larry Greenstein <Igreenstein@hilcorp.com> Sent: Monday, November 30, 2015 1:57 PM To: Bettis, Patricia K (DOA) Subject: FW: Spurr Platform Suspended Well Renewal: Applications for Sundry Application Attachments: Spurr Suspended Well Renewal - Explanation for well utility description ....docx Hi Patricia, Hope you had a good Thanksgiving break. Got with Reid and our seismic guys to figure out the timing for the Spurr's suspended well data. They wrote up a couple paragraph explanation (attached) as to why we really can't answer your questions below yet. Getting to those answers is exactly why we did the 3D seismic work this summer. It'll take some time, but the economic redevelopment of Spurr is on our radar,we just don't have enough info to make that decisions yet. Which is why we asked for a renewal of the suspensions for those wells. Please tell me how this reads to you and what else you might need to move forward on the Spurr 403s submitted recently. Larry From: Bettis, Patricia K (DOA) [mailto:patricia.bettis@alaska.gov] Sent: Tuesday, October 13, 2015 3:30 PM To: Reid Edwards Subject: Spurr Platform Suspended Well Renewal: Applications for Sundry Application Good afternoon Reid, According to 20 AAC 25.110, Hilcorp must demonstrate to the commission's satisfaction that each well, i.e., North Trading Bay Unit SPR-09, SPR-08, SPR-06, SPR-04,SPR-03, SPR-02, and SPR-01, (1) has a future utility as a development or service well, or(2) is a viable candidate for redrill. In support of each sundry application, for each individual well please: 1. Describe in detail each potential interval of interest for further testing; 2. Explain why each interval is of interest to Hilcorp, such as remaining reserves; 3. Briefly describe the test procedures to be conducted on each interval; and 4. Provide a specific time frame for conducting the testing. If a well(s) is a candidate for redrilling to a new location, please feel free to schedule a brief technical review meeting with the AOGCC staff. I will hold the sundry applications for these wells pending this additional information from Hilcorp. Thank you, 1 • S Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 S Hilcorp Alaska is currently waiting on the processing of new 3D seismic that was shot over the North Trading Bay Field in the summer of 2015,which includes the Spurr platform,to help determine a future development strategy. Once a development strategy has been identified, a specific plan for each well can be generated at that time. Processing of the new seismic is anticipated to be completed in the fall of 2016 after which time the data can be utilized to aid in development strategy planning. The Spurr platform has been shut in since 1992 and currently does not have facilities installed with the ability of processing hydrocarbons. Significant investment in surface facilities will have to be made in order to return the Spurr platform to production. The number of wells and of which type will dictate what surface facilities will be required and therefore timing and total cost. Economics will then be run with the total capital costs and expected oil and gas reserves to determine if it is economically viable for Hilcorp to pursue re-development of the North Trading Bay Field from the Spurr platform. • • Bettis, Patricia K (DOA) P%J /( —cf9 From: Bettis, Patricia K (DOA) Sent: Tuesday, October 13, 2015 3:30 PM To: 'Reid Edwards' Subject: Spurr Platform Suspended Well Renewal: Applications for Sundry Application Good afternoon Reid, According to 20 AAC 25.110, Hilcorp must demonstrate to the commission's satisfaction that each well, i.e., North Trading Bay Unit SPR-09, SPR-08, SPR-06, SPR-04, SPR-03, SPR-02, and SPR-01, (1) has a future utility as a development or service well, or(2) is a viable candidate for redrill. In support of each sundry application,for each individual well please: 1. Describe in detail each potential interval of interest for further testing; 2. Explain why each interval is of interest to Hilcorp, such as remaining reserves; 3. Briefly describe the test procedures to be conducted on each interval; and 4. Provide a specific time frame for conducting the testing. If a well(s) is a candidate for redrilling to a new location, please feel free to schedule a brief technical review meeting with the AOGCC staff. I will hold the sundry applications for these wells pending this additional information from Hilcorp. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission(AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettisCalaska.gov. 1 . 0 • •Bettis, Patricia K (DOA) / /6 9 - 2 From: Bettis, Patricia K (DOA) Sent: Friday, October 09, 2015 11:27 AM To: 'Reid Edwards' Cc: Trudi Hallett (thallett@hilcorp.com); Larry Greenstein (Igreenstein@hilcorp.com) Subject: RE: Spurr Platform Suspended Well Renewal: Applications for Sundry Approvals Reid, Please forgive the typo in my earlier email. The regulations for Suspended Wells is 20 AAC 25.110, not 20 AAC 25.107. This should help Hilcorp demonstrate to the commission's satisfaction that each well (1) has a future utility as a development or service well, or(2) is a viable candidate for redrilling. Please provide data showing that the well(s) meet the criteria of(1) or(2)above or advise as to your plans to abandon the well(s). Thank you, Patricia From: Reid Edwards [mailto:reedwards@hilcorp.com] Sent: Friday, October 09, 2015 10:24 AM To: Bettis, Patricia K (DOA)<patricia.bettis@alaska.gov> Subject: RE: Spurr Platform Suspended Well Renewal:Applications for Sundry Approvals Patricia, Would you be free for a call sometime today or early next week to discuss this issue? I would like to get a better handle on what further information the commission needs for this approval. Thank you Reid Edwards Reservoir Engineer—Cook Inlet Offshore Hilcorp Alaska LLC Office: 907-777-8421 Cell: 907-250-5081 1 • • From: Trudi Hallett Sent: Wednesday, September 30, 2015 4:16 PM To: Juanita Lovett; Larry Greenstein Subject: Fwd: Spurr Platform Suspended Well Renewal: Applications for Sundry Approvals Sent from my iPhone Begin forwarded message: From: "Bettis, Patricia K(DOA)" <patricia.bettis@alaska.gov> Date:September 30, 2015 at 4:03:17 PM AKDT To: "Trudi Hallett (thallett@hilcorp.com)" <thallett@hilcorp.com> Subject: Spurr Platform Suspended Well Renewal: Applications for Sundry Approvals Good afternoon Trudi, For the requests for renewal of the suspended well status for the North Trading Bay Unit SPR-09,SPR- 08, SPR-06,SPR-04, SPR-03, SPR-02, and SPR-01, under 20 AAC 25.107, Hilcorp must demonstrate to the commission's satisfaction that each well (1) has a future utility as a development or service well, or(2) is a viable candidate for redrilling. Please provide data showing that the well(s) meet the criteria of(1) or(2) above or advise as to your plans to abandon the well(s). Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/19/15 Inspector: Matt Herrera Operator: HILCORP Well Name: NTBU SPR-09 Oper.Rep: Paul Taylor PTD No.: 1690920 Oper. Phone: 907-776-6640 Location Verified? Yes Oper. Email: ptavlorahilcorp.com If Verified,How? LAT/LONG Onshore/Offshore: Offshore Suspension Date: 08/18/92 Date AOGCC Notified: 09/09/15 Sundry No.: 192-114 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA 4 Condition of Wellhead: Good,Gauges operable Platform Abandoned no production Condition of Surrounding Surface Location: Good no standing water or oil sheen discoloration around well head or in cellar area Follow Up Actions Needed: Monitor IA and OA pressure and visually inspection by Operator Comments: No SSV Attachments: Photo(1) REVIEWED BY:��pp�/� Insp.Supry _ 6(2_ 12128115 Comm PLB 12/2014 SCANNED SEP 0 7 2016 2015-0919_Suspend NTBU_SPR-09_mh.xlsx • 0 Suspended Well Inspection—NTBU SPR-09 (Spurr Platform) PTD 1690920 Photos by AOGCC Inspector M. Herrera i tt s�vt; 0 ,,,,. .,...A1,-." ,..1. '1 ,, ''': irk%c`. '''' ',,:. . I, . . , 4 3 i,r i i " h .4 . — 6 "'x .�.... ri x ��~ ,1" .. `�, `, e t . . '1 iti it 4s4 1 20015/09/ 1 10 : 06 A : . . - . ..,,,,,,k ., 2015-0919_Suspend_NTBU_SPR-09_mh.docx Page 1 of 1 Page t ot 2. Schwartz, Guy L (DOA) l �Oq O q ZC) From: Schwartz, Guy L (DOA) Sent: Monday, July 23, 2012 10A2 AM To: 'Vicente, Tara' Cc: Miller, Susan B. (MRO) Subject: RE: Marathon Spurr well question Tara, Since Hilcorp is assuming liability for the Spurr Platform Marathon does not need to file 10-403 sundries addressing the plugging of the platforms wells. Hilcorp has expressed interest in re- evaluating the wells and once their assessment is completed the appropriate action regarding abandonment or possible re -starting the platform will be taken. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Vicente, Tara [mailto:Tara.Vicente@WestonSolutions.com] Sent: Monday, July 23, 2012 7:35 AM To: Schwartz, Guy L (DOA) Cc: Miller, Susan B. (MRO) Subject: Marathon Spurr well question Good morning, I spoke with you about a week ago regarding Marathon's Spurr wells, and you had asked that I send an email so you could chase down an answer. Marathon had planned to abandon the Spurr wells (SPR -01, SPR -02, SPR -03, SPR -04, SPR -06, SPR -07, SPR -08, and SPR -09) in 2012; however, the impending purchase of Marathon assets by Hilcorp this year means that Marathon no longer intends to abandon the wells in order that Hilcorp can evaluate them after the transfer is complete. I don't have a lot of details, but Marathon had correspondence with AOGCC ("from Winton at AOGCC") that they did not need to file 10- 403 sundries to request variance for suspension plugging due to their plans to abandon. In light of the Hilcorp purchase and that Marathon no longer intends to abandon the wells, does Marathon need to file at this time to request a variance for suspension plugging? If you have any questions or need me to chase down additional information, please don't hesitate to contact me. Thank you so much for your time, Tara Vicente Project Manager Weston Solutions, Inc. 425 G Street, Suite 300 Anchorage, AK 99501 tel: 907-276-6610 cell: 907-351-4690 7/23/2012 rage z of tara.vicente@westonsolutions.com CONFIDENTIALITY: This email and attachments may contain information which is confidential and proprietary. Disclosure or use of any such confidential or proprietary information without the written permission of Weston Solutions, Inc. is strictly prohibited. If you received this email in error, please notify the sender by return e-mail and delete this email from your system. Thank you. 7/23/2012 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 10/20/10 Inspector: Lou Grimaldi Operator: Marathon Oil Company Well Name: N. TBU SPR -09 Oper. Rep: Skiba /Baldwin PTD No.: 169 -092 Oper. Phone: 907 - 283 -1371 Location Verified? No Oper. Email: kskibaa,marathonoil.corn If Verified, How? Onshore / Offshore: Offshore Suspension Date: 08/18/92 Date AOGCC Notified: 10/05/10 Sundry No.: 92 -114 - Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 0 Photos Taken? Yes IA 1 OA 2 Condition of Wellhead: Wellhead secure - Condition of - Surrounding Surface Wellroom secure Location: Follow Up Actions None Needed: Attachments: Photo REVIEWED BY Insp. Supry J(3 c( Z�, /( 1 Comm PLB 09/2010 2010- 1020_Suspend_NTBU_SPR- 09_Ig.xls % 4 6 " '11 ' 1,.. .,.'-' , ".. \' ,„,. ' . ' t j . ' '''' ' ' ''' .; ',''' .' Mk ' \\,. ''''. t iiire. 1 as h A L! Y 0 t' ., . ft A • . , -- Ar , ,.:. ..4, . 1 ,. ic e 0 \ 0 .1.3° a \ „ 1 1c 1 . . L _ % y a r .. ,.,. _... ra • } .fig + oft r,` '-", i z 4T f M ' '- 0,- Wiz- -- o1 z,,,,,, t cd • 1,,,,- Jis r , N • MaratTion Alaska Production LLC Alaska Asset Team Marathon P.O. Box 1949 (MARATHO) Alaska Production LLC Kenai AK 99611 ® Telephone 907/283 -1371 Fax 907/283 -1350 December 22, 2010 JAN 1 8 2011 RECEIVED DEC 2 7 2010 Mr. Winton Aubert Alaska Oil & Gas Conservation Commission Alaska Oil & Gas Cons. Commission 333 W 7 Ave Anchorage Anchorage, Alaska 99501 ( ;— Reference: 10 -404 Report of Sundry Well Operations Field: North Trading Bay Well: North Trading Bay Unit SPR -09 Dear Mr. Aubert: Attached for your records is the10 -404 Report of Sundry Well Operations for SPR -9 well. This sundry documents the suspended well inspection performed on October 20, 2010. SPR -9's casing pressures are tracked on a monthly basis. This data is used to monitor the plug and welibore integrity. Presently, the SPR -9 casing pressures range from 2 psi v on the outer annulus to 1 psi on the inner annulus. Marathon is currently working to resolve ownership issues related to the Spurr Platform and its associated wells. Marathon hopes that a resolution, to this situation, can be reached in time to facilitate the abandonment of SPR -9 in the 2012 / 2013 time frame. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, i<4Aftm-/ Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Well Picture KJS '/ Mile Radius Well Plate STATE OF ALASKA DEC 2 7 2010 0/20(i ALASKAWAND GAS CONSERVATION COMMISSI110 Alaska Oil Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Abandon LJ Repair Well L Plug Perforations LJ Stimulate L Other U Initial Suspended Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Time Extension ❑ Well Inspection Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Alaska Production LLC Development El Exploratory - 169 -092 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 r 50- 733 - 20200 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL- 0017597 - .i North Trading Bay Unit SPR -09 9. Field /Pool(s): Trading Bay / G -NE Oil, Hemlock -NE Oil 10. Present Well Condition Summary: Total Depth measured 10,387' feet Plugs measured 9,820' feet true vertical 9,962' feet Junk measured NA feet Effective Depth measured 9,820' feet Packer measured 10,040' feet true vertical 9,402' feet true vertical 9,618' feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface Intermediate 1,338' 13 -3/8" 1,370' / 1,365' 2,730 psi 1,130 psi Production 10,337' 9 -5/8" 10,369' 9,944' 7,510 & 6,870 psi 4,130 & 4,750 psi Liner Perforation depth: Measured depth: Pugged feet True Vertical depth: Plugged feet / Tubing (size, grade, MD & TVD): 3 - 1/2" N - 10,087' MD 7,463' TVD SSSV: NA NA / MD NA TVD Packers and SSSV (type, MD & TVD): Packers: Baker D - Model 10,040' MD 9,618' TVD 11. Stimulation or cement squeeze summary: Suspended well initial inspection information: Intervals treated (measured): * Well head in good condition with no signs of leakage * Well room clean with no hydrocarbons Treatment descriptions including volumes used and final pressure: *Well Pressures: - Tubing = 0 psi - Inner annulus = 1 psi - Outer annulus = 2 psi 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1 0 Subsequent to operation: 0 0 0 1 0 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development • . Service ❑ Stratigraphic ❑ Daily Report of Well Operations 15. Well Status after work: Oil ❑ Gas LJ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 . 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: NA Contact Kevin Skiba (907) 283 -1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature '4 rfjj(jti ‘,4;16,9_, Phone (907) 283 -1371 Date December 23, 2010 Form 10 -404 Revised 10/2010 Submit Original Only Y^ x ti r .41k: ...4 ,. ii r ,sr off )11, it ' a 4 Ivo 4 4 k'::t l e it i # • tri,, fri , . tr ti *y ah . i ■ x ' ' ' inpi f li t i Ile gas M als It ( .i': i X d '± •nr �I: z` el* q ° ( ( k. a its ,„ MARATHON OIL COMPANY NORTH TRADING BAY UNIT Ill SPURR PLATFORM WELL T /S -9 WELL SECURING 8/92 mu All neosurenents ore RKB to top of equipment j;ennlrtinn Strtng: 0' - 10.087' 3 -1/2'. 9.211, N -80 Tbg. J L370' 13-3/8', 54.311, J -55 Cs¢ All gas lift mandrels are Casco 3 -1/2' KBM J Side Pocket Mandrels with Dummy Valves. TBG t CSG Ilta3h yelv111 Ix= FILLED WITH 1847' I Dummy INHIBITED 8.5 ppg FIW J 4,688' 2 , AND 200 BBL'S 9.5 ppg 6.190' 3 • _ INHIBITED BRINE J 7,449' 4 Out of Pocket TOC IN TBG 8,424 5 Du+ny 8 9.006' CTM // 9,149' 6 • �� 9,813' 7 • CIRC. HOLES IN TBG P �/ 9,597.3- 9,599' / AND ' 0.820'i Calcualed TX in Cs¢ 14033.3'- 14033' �.� 14037' Otis X -0 Sleeve 10.040' Baker Model 'D' Packer -! pERFORATn 4S DIL 10.060' - 14078' 14090' - 10.150' , lc —/ A- 14165' - 10.193' 10.200' - 10.278' /1 14300' - 10.369' F41 t 14358' CTM 7 -23 -92 / 10,369' 9 -5/8', 43.51 t 471 Csg. - PBTD • 10.369' Revision Date' 9/8/92 Revised By JDM/evo TD • 10.387' Reason Well Securing Previous Revision 4/15/92 _ URR PLATFORM • NORTH TRADING BAY UNIT S-4 28 27 26 S -09PB SPURR PLATFORM TS-9 S -3 T -5 SURFACE LOCATION 1/4 MILE RADIUS 1RD TS-1 s -1 Alkfr /411//ii P' PPgg TS-5R1 F �! . RD S -3 " ,yi►C�_ _ TS-5-D2 s -2 S -42DPN S -2R D - 8 S - TS-7 33 34 \T,$16 35 S -7 TS -4 S-7RD s19 • _ TS -2 T1ON -R13W ■��' T9 N -R13W 3 e st. a A �q O MARATHON ALASKA PRODUCTION LLC 1:12000 0 1 KILOMETRES SPURR PLATFORM 0 0.50 NORTH TRADING BAY UNIT — J 1 I MILES COOK INLET NAD27 / Alaska zone 4 (EPSG 26734) ALASKA Transverse Mercator Clarke 1866 spheroid September 2010 Natural origin: [150 00 00W, 54 00 00N] Alaska CS27 zone 4 / �, Marathon MARATHON ® Alaska Production LLC Alaska Asset Team P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 August 3, 2009 F �: nil IT P� L Cathy Foerster State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7°i Avenue, Suite 100 Anchorage, AK 99501-3539 Re: 20 AAC 25.300 (Request for Infonnation) — Status of Oil and Gas Wells Dear Ms. Foerster: �ce-k_ oek2 In response to your June 22, 2009 letter requesting a plan of action and timing for such activities associated with the referenced list of inactive wells, please find attached a table with the requested information. As indicated in the table, Marathon anticipates a measured program of P&A activities, averaging three -to -five well abandonments per year. Marathon has already begun such a program with its offshore wells, beginning with the Spark Platform wells in 2009. All of the onshore wells on the list are within active oil and gas leases that are regularly visited and inspected. Marathon anticipates updating plans for its inactive wells in the appropriate annual Plan of Development for each property. Any and all forward activities are subject to funding approval. Please also note that your June 22 letter erroneously referenced "KU 41-08". We believe that your June 22 letter reference to well "KU 41-08" was a typo and is intended to refer to Well KU 41-18. This well matches the referenced drilling permit (171-010). Should you have any questions or wish to review the attached plans with us, please feel free to call Lyndon Ibele at (907) 565-3042. Sincerely, Carri Lockhart Alaska Asset Team Manager Attachment: Marathon plan for list of inactive wells cc: B. Schoffmann L. Ibele K. Skiba T. Stebbins Well Files i V E r f f A L Marathon Oil Company, Alaska Asset Team Anticipated schedule of well abandonment activities Confidential 8/3/2009 Timing lWell I Permit No. I Pad or location 2009-2011 S-1 RD 174-005 Spark S-2RD 174-024 Spark S-3 169-011 Spark S-4 169-034 Spark S-5 169-039 Spark S-7RD 169-096 Spark S-8 171-033 Spark S-9 174-027 Spark TS -1 168-048 Spurr TS -2 168-050 Spurr TS -3RD 168-065 Spurr TS -4 168-066 Spurr TS -6 168-090 Spurr TS-7RD 169-026 Spurr TS -8 169-027 Spurr TS -9 169-092 Spurr 2012-2015 BC 7 176-006 BCU Pad 7 CLU 3 181-058 CLU Pad 3 CLU 4 187-034 CLU Pad 3 KU 33-30 159-015 KGF pad 33-30 KU 42-30 181-091 KGF pad 33-30 KU 44-30 168-07.1 KGF pad 33-30 SU 23-15 161-014 Sterling Unit KU 41-18 171-010 KGF pad 41-18 KU 43-12 169-087 KGF pad 14-6 KU 11-6 165-017 KGF pad 34-31 KU 21-5 169-035 KGF pad 43-32 WF1-21rd 193-183 West Fork WF2-21 192-010 West Fork Marathon ATH Oil Company MARATHON March 1, 2009 Commissioner: Cathy Foerster Alaska Gii and Gas Conservation Commission 333 W. 7`h Avenue Suite 100 Anchorage, AK 99501-3539 � 4.01--0(=� 2 Alaska Asset Team North America Production Operations P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 Re: Notice of Revised Suspended Wells Regulations and Request For Verification of Suspended and Shut-in Well Information Dear Cathy: MAR C 2, 2009 oil a SE's V tars. Gor is., Ull Anchorage Marathon received your letter dated January 28, 2009 (Cert # 7005 1820 00012499 5999) requesting Marathon to validate information contained within it. Marathon has reviewed the data and found it to be accurate. Marathon is in the processes of reviewing and addressing the new regulatory requirements in "20 AAC 25.110 Suspended wells". If you have any questions, please do not hesitate to contact Gary Laughlin at 907-565-3036 or email him at galaughlin@marathonoil.com. Sincerely, 5CAH"K Ben Schoffmann Operations Manager MARATHON OIL COMPANY tUq-04(2_ SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W. 71h AVENUE, SUITE 100 CONSERVATIONCOMMSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 28, 2009 FAX (907) 276-7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 5999 Ben Schoffman Marathon Oil Company PO Box 196168 Anchorage AK 99519-6168 Re: Notice of Revised Suspended Wells Regulations swim 0C I C I ZU)4 and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Schoffinan: Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed are a list of suspended wells and a list of long term shut-in wells operated by Marathon Oil Company. For each list, please verify the information for each well, and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, Cathy P. Foerster Commissioner Enclosures Postal r , r • lT it only: No Insurance Coverage Provided) (Domestic Ma U) .- USE ru PD~ i $8.59 POSp� � Certlfled Fee $2.70 C3 tE Return mmW t RReequuipt � $2.20 ;' rx ® Reetrlcted Delivery Fee f0•� ru (,E i j meM Required) ro 44 gg rzi 'b"'Postage Ben Schoffmanl Ln Marathon Oil Company rte - 35a:. PO Box 196168 or Fo go -;; Anchorage AK 99519-616 it Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. Print your name and address on the reverse so that we can return the card to you. F Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to Ben Schoffman Marathon Oil Company PO Box 196168 Anchorage AK 99519-6168 A. Sjgrt3�- X Agent d3 % ❑Addressee B. Received by (Pn d Name) C. Da of Deliv ry I �VVV� ✓ 4' l�t1s4�1 l a`7 p C) D. Is delive6 address different'from item 1? ❑ Yes If YES, enter delivery address below: ❑ No k1irvice Type Certified Mail Express Mail ❑ Registered \1Return Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service label) 7005 1820 0001 2499 5999 PS Form 3811, February 2004 _ Domestic Return Receipt 0259"2-M-1540 Operator Suspended and Shut In Wells MARATHON OIL CO Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... 'EXPLORATORY 202-129-0 50-133-20517-00-00 ABALONE 1 SUSP 3/9/2003 250 FSL 3000 FEL Sec 29 T 2 N R 12 W SM FEE-OSMAR KASILOF 202-257-0 50-133-20520-60-00 KASILOF SOUTH 1 L1 KENAI C.L.U. 206-121-0 50-133-20563-00-00 CANNERY LOOP UNIT 12 NINILCHIK 208-023-0 50-133-20574-00-00 STERLING 2495 FEL 161-014-0 50-133-10012-00-00 TRADING BAY 174-005-0 50-733-20158-01-00 169-011-0 50-733-20175-00-00 169-096-0 50-733-20197-01-00 171-033-0 50-733-20233-00-00 174-027-0 50-733-20265-00-00 168-048-0 50-733-20120-00-00 168-050-0 50-733-20122-00-00 168-065-0 50-733-20133-00-00 168-066-0 50-733-20134-00-00 168-090-0 50-733-20153-00-00 169-026-0 50-733-20181-00-00 169-027-0 50-733-20182-00-00 X69-092-0 50-733-20200-00-00 Wednesday, January 14, 2009 NINILCHIK UNIT G OSKOLKOFF 7 STERLING UNIT 23-15 N TRADING BAY UNIT S-01 RD N TRADING BAY UNIT S-03 N TRADING BAY UNIT S-07RD N TRADING BAY UNIT S-08 N TRADING BAY UNIT S-09 N TRADING BAY UNIT SPR -01 N TRADING BAY UNIT SPR -02 N TRADING BAY UNIT SPR -03 N TRADING BAY UNIT SPR -04 N TRADING BAY UNIT SPR -06 N TRADING BAY UNIT SPR -07 N TRADING BAY UNIT SPR -08 N TRADING BAY UNIT SPR -09 SUSP 4/15/2004 520 FSL 1340 FWL Sec 28 T 3 N R 12 W SM ADL0384529 ADL0384534 SUSP 9/8/2006 2490 FSL 2365 FWL Sec 4 T 5 N R 11 W SM ADL0324602 ADLO359153 ADL0365454 FEE-TR119 SUSP 6/12/2008 2969 FSL 3023 FEL Sec 23 T 1 N R 13W SM ADL0389180 SUSP 10/23/1966 2715 FNL 1520 FWL Sec 15 T 5 N R 10 W SM FEDA028135 SI 1/25/1992 2608 FSL 2495 FEL Sec 26 T 10 N R 13W SM ADL0035431 SI 2/25/1992 2613 FSL 2495 FEL Sec 26 T 10 N R 13W SM ADL0035431 SI 2/25/1992 2612 FSL 2488 FEL Sec 26 T 10 N R 13W SM ADL0018776 SI 1/25/1992 2577 FSL 2566 FEL Sec 26 T 10 N R 13 W SM ADL0017597 SI 1/25/1992 2570 FSL 2563 FEL Sec 26 T 10 N R 13W SM ADL0017597 SUSP 8/18/1992 615 FNL 2072 FEL Sec 34 T 10 N R 13W SM ADL0017597 SUSP 8/19/1992 664 FNL 2007 FEL Sec 34 T 10 N R 13 W SM ADL0017597 SUSP 8/18/1992 618 FNL 2068 FEL Sec 34 T 10 N R 13W SM ADL0017597 SUSP 8/13/1992 666 FNL 2003 FEL Sec 34 T 10 N R 13W SM ADL0017597 SUSP 8/10/1992 642 FNL 2072 FEL Sec 34 T 10 N R 13 W SM ADL0017597 SI 8/26/1992 622 FNL 2068 FEL Sec 34 T 10 N R 13 W SM ADL0017597 SUSP 8/26/1992 664 FNL 2000 FEL Sec 34 T 10 N R 13 W SM ADL0017597 SUSP 8/18/1992 618 FNL 2076 FEL Sec 34 T 10 N R 13W SM ADL0017597 ALASKA OIL AND GAS CONSERVATION COM MISSION REPORT OF SUNDRY WELL OPERATIONS performed: Operation shutdown .~,lStimulate __ Plugging .~ Pedorate __ 1. Operations Pull tubing __ Alter casing ~ Repair well ~ Othe~ IG 2. Name of Operator / Marathon Oil (:ompany 3. Address P.O. Box 190168 Anchorage~ AK 9951 4. Location of well at surface Leg lA, Pile #5, Spurr 2076' FEL, 618' FNL Sec. 34-10N-13W-SM At top of productive interval ' 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) q?' KR ahnv~ MKI 7. Unit or Property name North Trading Bay 8. Well number TS-9 (SPR-9) Unit feet 9. Permit number/approval number 1,600' FSL, 622' FEL, Sec. 27-10N-13W-SM At effective depth At total depth 1,606' FSL~ 620' FEL 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Sec. 27-10N-13W-SM 10,387' feet 9,962' feet feet 10,3 6 9'. feet 9,944' Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3-1/2" 9.2# N-80 e 10,087' MD Packers and SSSV (type and measured depth) Raker Mnrl~! "n" e 1_0.040' MD Stimulation or cement squeeze summary 09_ 1 1 &/,~'/',"¢,'~¢'-.~ ~'¢,.-~, 10. APl n-uTnb~' '! 5o- 133-20200 11. Field/Pool NTBU Hemlock & 6 Zone Plugs (measured) Junk (measured) Cement P1 ug 9,820' - 10,358 Size Cemented Measured depth True vertical depth 13 3/8" 1,350 sx 1,370' 1,365' 9-5/8" 1,850 sx 10,369' 9,944' Cement plug covering See Attachment #1 perforations. Intervals treated (measured) 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 0 0 0 Subsequent to operation 0 0 0 0 0 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil ~ Gas ~ Suspender~_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-4~4 Rev 06/15/88 Service. L/ Title Operations Enqineerinq Supv. '~ .7'/ Date ~'//¢./,/,~'t, SUBMIT IN DUPLICATE Attachment #1 NTBU Wel 1 TS-9 Cement Plug Covering Perforations. MD 10,060 '- 10,078' 10,090' - 10,150' 10,165' - 10,193' 10,200' - 10,278' 10,300' - 10,369' TVD 9,638' - 9,655' 9,667' - 9,727' 9,741' - 9,769' 9,776' - 9,854' 9,875' - 9,944' \spark\TS9.doc REC[)VED DAILY HELL OPERATIONS TS-9 7/16/92 RU E-line on well. Pressure test wellhead connection~pump in sub then entire lubricator - All 9ood tests. Am 2 sections of 1-1~2" (7 shots), select fire. RIH w~tubing punchers. Tie in across packer, X-O sleeve and GLN #6 & #7. Fire lower gun to punch tubing holes from 10,033.5' - 10,035'. Pull up and fire top gun to punch tbg holes from 9,597.5' - 9599'. Break out guns. All shots fired. RD E-line. RU chicksan lines on wellhead. Start pumping FIW at 2 BPR, 0 psi. Pump pressure up to 250 psi after 165 bbls pumped. Started gettin9 returns to separator. 700 bbls FIW pumped down tbg, 3 BPR, 300 psi. SD pump. TP down 0 psi. Returns clean. RD off well. 7/22/92 RU w/CTU on well Ts-g. 7/23/92 MU BHA on CT consisting of X-O, by-pass tools, nozzle, 2.0" max O.D. PSI test lines to 2000 psi - OK. Pressure up to 4,000 psi - OK. PSI test CT lubricator, BOPE to 2,000 - OK. Pressure up 4,000 - good test. Close shear rams, function OK and tested to 4,000. Run past BOPE w/ 1-1/2" CT, close & test pipe rams, good test. RIH w/CT. Pump at 1/3 BPM, 300 psi while RIH. Tag bottom at 10,358' CTM. PU 3' off bottom w/CT. Obtain rate and pressure with FIW, 1.5 BPM, 3,400 psi. Start mixing cement. Mix 47 bbls class G cement w/O.07 gps CFR-3L and 0.07 gps HR-6L; 15.8 ppg. Start pumpingcement. 1.25 BPM, 2,000 psi. 23.5 bbls cement pumped, 1.25 BPM. Start PU w/ CT at 17 fpm. 47 bbls cement pumped. Start FIW to displace. Main hydraulic hose broke loose on connection - near injector head. CT depth 10,050'. Continue displacing all cement out of CT slowly. SD pump after cement completely displaced. Hydraulic hose connected to injector head. PU CT to 9750; (top of cement). Pump FIW at 1/2 BPM 1000 psi while POOH. Have returns at surface. Finish POOH w/CT. Secure well. WOe. Open up tree valves, 9-5/8" csg to production. TP=O, CP:O. Pump down tbg psi up to 1500 psi. Hold for 30 minutes. Pressure from 1500 down 1425 in 30 minutes. RIH w/ CT to tag top of cement. Tag top of cement in tubing at 9006' CTM. Calculated top should be +/- 9750'. 744' high in tubing : 6.5 bbls. Volume cement above packer calculated totaled 20 bbls leaving 13.5 bbls in tbg/csg annulus. 13.5 bbls is equivalent to 220', putting TOC at 9820' in tbg/csg annulus. Pressure test good. POOH w/ CT after tag. RD CTU. 8/15/92 Otis RU on TS-9. Redress Kinley tubing puncher tool w/ 1/2" button. RIH w/ puncher. Could not get below 2947' POOH. RIH w/ 2.70" gr. Sat down ~ 2945' WLM, work repeatedly. Fell through'. Continue downhole to tag cement 0 8742'. POOH. Repin collar locator on puncher tool. RIH w/ tubing puncher. Set down again @ 2947' Gently work up & down, finally fell through. Ran down, set down again in GLM ~5 ~ 8436'. Pull up to collar ~8308'. Put 200 psi on tbg & jar down to fire puncher. TP down to 180 psi slowly. POOH. Puncher fired. Halliburton pump FIW down tbg to verify circulation. TP up to 1500 immediately. H: \wp\DAI LYt,,IOP R'E'CE]VED SEP 1 $ ~,~ ,Al~sk~t OJt & Gas Cons, Oot~ssio~ Anchora{ja TS-9 (continued) -2- 8/16/92 Rebuild puncher. RIH to 7997' WLM. Punch 1/2" hole. TP stayed @ 200 psi. POOH. Attempt to circulate. TP up to 1500 psi, no rate. Rebuild puncher tool. RIH to 7681' WLM. Punch 1/2" hole. TP stayed ~ 220 psi. POOH. ^ttempt circulation. TP up 1500 psi. No rate. RIH. Set down again in GLM #1 ~ 2945'. Sheared pin in CCL. POOH to repin tool. RIH to 6988' WLM, punch 1/2" hole. TP stayed ~200 psi. POOH. Attempt circulation, TP up 1500 psi. No rate RIH w/ 3-1/2" KOT to GLV #4 ~ 7459' WLM. Unable to latch valve. POOH to GLV #~ ~ 6190. Could not orient. POOH. RIH w/ OK-6 KOT. Orient in GLM #4. Latch & pull GLV #4. POOH, valve #4 recovered. Pump 20 bbl inh. FIW down tbg ~ 2 BPM, 200 psi until taking rtns to separator. $/D pump. Good circulation. RD Otis off TS-9. RU Halliburton. Pumping inhibited FIW ~3 8PM, 400 psi. Pump 260 bbl, then switch to 200 bbl 9.5# brine w/0.75~ KW-132, then displ w/ 65 bbl inhibited FIW to leave weighted fluid in casing from GLM #4 up to 4359'. Weighted brine will fall inhibiting annulus below GLM #4. $/D pump. Finished pumping. Total volume - 545 bbl inhibited fluid. 8/17/92 S/D pumps. Start RD Halliburton. Well secured. 8/18/92 RU lines to inject fuel gas to csg and take rtns from tbg. Degin displacement. Take 16 bbls rtns to production. Close in tree. 16 bbl = 219' of tbg & csg. RD off T$-9. Well secured. Flowline removed and blind flanges installed on tree. Gauges instal led. TP = O, 9-5/8" CP = O, 13-3/8" CP = O. H: \wp\DA I LYWOP NARATHDN DTL CDNPANY NORTH TRADING ]3AY UNIT SPURR PLATIrDRH VELL T/S-9 VELL SECURING 8/9~ TDC IN TOG e %006' CT# CIRC. HOLES IN TOG e %$97.$-%599' AND 10,033.$'-10,035' Att t~eos~,r'ePients ore RKB to top of' equil:ment -- 0' - 10.087' 3-l/a; 92#. N-80 Tb~ L370' 13-3/8; $4.~1. J-$5 CSO. All gas Uf't ~mndreis are Co~co 3-1/~' S~le Pocket #ondrets ruth l~.~y Valves. De~th Vatvell P.,,84 7' I 6,190' 3 7,449' 4 Out oF Pocket 8,4~4' 5 %I49' 6 ' 9,8i3' 7 ' 9,8~0' Colcualed TOC in Csg. 10,037' Otis X-O Steeve 10,040' Baker* Hodet 'D' Pecker* PERI:'DRAT ION~ OIL !0,060' - 10,078° 10,090' - 10,150' 10,165' - 10,193' 10,200' - 10,278' 10,300' - 10,3&9' iF~t e 10,358' CTH 7-23-9~. 10,369' 9-5/8; 43.5l l, 47t Csg. PBTD = 1~369' TD = 1~387' Revision Dote. 9/8/9;~ Revised By, JDH/evo Reoso~ Vett Securm9 Previous Revision: 4/15/9~ ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (gO0 279-14.33 TELECOFY: (907) 275.7542 September 14, 1992 Lyndon C. Ibele ~ Operations Engineering Supervisor Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519-0168 ~.~, ¢' b?.vt'~q Re: Spurr Platform wells TS-l, TS-2, TS-3, TS-4, TS-6, TS-7, TS-8, Dear Mr. Ibele: In reply to your August 12, 1992 letter, the Commission does not object to Marathon's ' proposal to use inhibited filtered inlet water (FIW) in the robing and robing-casing annulus when securing the referenced wells during the temporary shut down of the Spun: Platform. It is understood that the inhibited FIW will be used in the wellbore until such a time as the wells are recompleted or abandoned. Commission approval to use FIW will be granted when the respective application for sundry approvals (form 10-403) for each. well is received, assuming all other proposed operations are in order. David W. Chairman Marathon Oil Company Alaska I~ n DomestiC, , 3duction P.O. Box 190168 Anchorage, AK 99519-0168 Telephone 907/561-5311 August 12, 1992 Mr. D. W. Johnston Head Commissioner b% Alaska Oil & Gas Conservation Commission J~ _~ /I/ Ok' 3001 Porcupine Drive Anchora~e, Alaska 99501 . ) .. ' Re: Spurr Platform-Wells Dear Mr. Johnston: This letter is written at the request of Mr. Mike Minder to advise the AOGCC of a revision to the procedures for plugging-back the producing intervals of the Spurr Platform wells. This revision was discussed with Mr. Minder on 8/12/92 and given his verbal approval. Following the approved plans to isolate perforated intervals with cement and verifying cement integrity by tagging/pressure testing, it is Marathon's plan to circulate inhibited filtered inlet water (FIW) in the tubing and tubing-casing annulus prior to securing the wellbores. The FIW-- with a fluid density of 8.5 ppg -- will be used in place of 9.5 ppg brine as originally proposed. A 9.5 ppg fluid density was required for well control when the Spurr wells were originally drilled in the late 1960's. However, there are no remaining productive intervals which equal or exceed an~g equivalent hydrostatic pressure. Therefore, the inhibited FIW will provide security to the wellbores until such time that they are recompleted or until abandonments are finalized. Please .return a brief ac.c_knowledgement, of receipt and approval records. ~ Sincerely, Operations Engineering Supervisor for Marathon' s LCI/crc RECEIVED H:\wp\920EOS\55.LCI AU G 1 Alaska .Oil .& Gas Gons. ,._Anclm. mga A subsidiary of USX Corporation ALASKA 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 X Time ex'tens,on __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Pedorate __ Other __ 2. Name of Operator Marathon Oil Comnanv 3. Address P.O. Box 190168 Anchorage, AK 9951 4. Location of well at sudace Leg lA, Pile #5, Spurr 2076' FEL, 618' FNL Sec. At top of productive interval 1,600' FSL, 622' FEL, Sec. At effective depth 5. Type of Well: Development ~X Exploratory __ Stratigraphic m Service __ 34-10N-13W-SM 27-10N-13W-SM At total depth 1,606' FSL, 620' FEL, Sec. 27-10N-13W-SM 12. Present well condition summary Total depth: measured true vertical 10,387' feet 9,962' feet Plugs (measured) t Effective depth: measured 10,369 ' feet true vertical 9,944 ' feet Casing Length Size Structural Conductor Sudace Intermediate 13 3/8" Production 9-5/8" Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3-1/2" 9.2# N-80 0 10,087' MD Packers and SSSV (type and measured depth) Baker Model "D" 0 10,040' MD 13. Attachments Description summary of proposal ~ #1, 2, 3, 4, 5 Wellbore Diagrams (Current 14. Estimated date for commencing operation Ma,v, 1992 16. If proposal was verbally approved Name of approver Junk (measured) 6. Datum elevation (DF or KB) feet 92' K_n above MSL Z Unit or Property name North Trading Ray lin'il- S. Well number TS-9 (SPR-9) 9. Permit number 10. APl number 50-- _ _ - 11. Field/Pool NTBU Hemlock & G 7one Cemented Measured depth True vertical depth 1,350 sx 1,370' 1,365' 1,850 sx 10,369' 9,944' RECE V£D See Attachment #1.,- · Detailed operations program __ & Proposed) .X.. BOP sketch 15. Status of well classification as: Oil __ Gas __ Suspended __ Service Idle k~ater Injector Date approved 17. I hereby certify that the foregoing~ true and correct to the best of my knowledge. Signed ,,~~ ~'// Title0perations Engineering Supv. Date [// - "~ ~' FOR COMMISSION USE ONLY Conditions of approval: Nqtily Commission so representative may witness ' I APproval Plug integrity ~ BOP Test_ Location clearance __ .4 /, ~ , . .-. I NO. ¢~ ~..//,,/~_~ Mechanical Infe~rityTest __ Subsequent form required 10- '")~-~"'~" ..kCp~"ovec~ uopy 0R1G~NAL SIGNED BY ~ O~!.~,!tE C. SMITH Returned Commissioner Date Approved by order of the Commission SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 Attachment #1 NTBU We11 TS-9 Current Perforated Intervals MD 10,060 '- 10,078' 10,090' - 10,150' 10,165' - 10,193' 10,200' - 10,278' 10,300' - 10,369' TVD 9,638' - 9,655' 9,667' - 9,727' 9,741' - 9,769' 9,776' - 9,854' 9,875' - 9,944' \spark\TSg.doc RECEIVED Attachment #2 ( ~ SPURR PLATFORM WELL Ts-g PROCEDURE FOR PLUGGING COMPLETED INTERVALS 1. RU slickline. PT lubricator to 1500 psi. RIH w/ 2.5" gauge?~n_g and tag fill. R~slickline. 2. RU.~e. PT lubricator to 1500 psi. RIN and perforate circulation holes from 10,030' t~ i0,032', 4 spf (abOve production packer) and from 9~___00' to 9,602'. RD E-line. 3. RU to pump down tubing while taking returns through choke to production. Pump IW (inlet water) down tubing while taking returns from casing. Fill hole and circulate Until returns are free of oil and gas. 4. RU T~_~_. PT lubricator, coil and surface lines to 4000 psi. RIH and tag fill. 5. Lay cement plug from fill to 9,750'. POH while pumping IW to fill hole. 6. _W_Q~. Pressure test plug and casing to 1500 psi. RIH and tag top of cement. POH and RD CT. 7. RU topump down tubing while taking returns from casing to production. Displace inlet water with 9.5 ppg NaC1. Bleed any remaining pressure from tubing and casing. 8. Remove flowline and gas lift line and install blind flanges. Close all tree valves and casing valves. pmo\H: \WP\TSgPA. WP Attachment #3 MARATHON i]iL C 'ANY NORTH TRADING B~,,, UNIT SPURR PLATFORM WELL T/S-9 Current ALL nemsurements are RKB to ±op oF equipment Comotetion S trin.q: O' - '..0,087' 2-]/;:::", 9.2~, N-80 Tbg, 1,370' 13-3/8% 54.5~, J-55 Csg. All gos lift mandrels are Camco 3-t/2' KBM Side Pocket MandreLs with Dummy VaLves. Depth Vatvet~ Tyoe ~3,847' 1 DUMMy 4,688' P 6,190' 3 7,449' 4 " 8,4~34' 5 ' 9,149' 6 9,813' -- 7 ° 10,037' []]tis X-O SLeeve 10,040' Bc~ker Model 'D' Packer /! I~ iOq. O PERFORATIONS DIL , , ,/ / / 10,060' - 10,078' 10,090' - 10,150' 10,165' - 10,193' 10,200' - 10,878' 10,300' - 10,369' Fill t~ 10,366' E-Line 8-t8-72 10,369' 9-5/8% 43,5~ & 47~ Csg, PBTD = 10,369' Revision Date: 4115192 Revised By: PMO/evo TD = 10,387' Reason: Update Pcevious Revision: 4114/92 Attachment "' :i~ MARATHON OiL ~ANY NORTH TRADING ,, UNIT :;PURR PLATFORM WELL T/S-9 Proposed PPG _T~4 "rlqo C~ % AxtD lfl, O.~Q ' All memsurements ace RKO to top oF equipment Como[e~ion 3' - ;0,087' 3-1/8', 9.8~, N-e0 TUg. 1,370' 13-3/8", 54.5t,,' J-55 Csg. Side Pocket Manolre~s with Dummy Valves. Depth Votvel~ Type ~,847' 1 Dummy 4,688' ~ ' 6,190' 3 ' 7,449' 4 8,4E~4' 5 9,149' 6 ' 9,813' 7 ' 10,037' Otis X-O Steeve 10,040' Baker Modet 'D' Packer PERFORATIONS DIL 10,060' - t0,078' 10,090' - 10,150' 10,165' - 10,193' 10,800' - 10,878' tO,3OO' - 10,369' 10,366' E-Line 8-18-78 10,369' 9-5/8', 43.5# & 47~ Csg. PBTD : 10,369' TD = 10,387' Revision Dote: 4/15/9~ Revised By, PMO/evo Reason: Update Previous Revision: 4/14/9~ Attachment #5 · ' ( SPURR pLATF(~ RM Wireline Lubricator w/A.Ssqciated BOPE -GREASE HEAD (Hydraulically Activated) .... LUBRICATOR MANUALLY OPERATED BOP 13 3/8' Casing -- , ~_ SPURR' PLATFORM Coiled Tubing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Rams 5000 psi WP HYDRAULIC RAMS 13 3/8' Casing Doyle:~'7 '~es Produ~,.~ Aanager Alaska Region Domestic Production Marathon Oil Company September 23, 1988 RO. Box 190168 Anchorage, Alaska 99519 Telephone 9071561-5311 Mr. C. Chatterton Alaska Oil and Gas Conservation Commission 3001Por6upine Drive Anchorage AK 99501 Dear Mr. Chatterton: Marathon Oil Company notified the State on August 30, 1988 of the Change of Operatorship for the Texaco "A" Platform. Marathon has changed the name of the platform to Spurt. Please note this change in your records. DE9-26 cc: B. G. Penn W. D. Kirchner A subsidiary of USX Corporation Marathon Oil Company September 20, 1988 Alask, ( .~n /~:~/,-~ r Domestic Production ~.~~ ~,~Z ~1 RO. Box 190168 -' ' SR Anchorage, Alaska 99519 .... Telephone 9071561-5311 ENG ENG ASS~ STAT 8~AT TEGH~ Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Effective August 1, 1988, the Texaco "A" platform was acquired by UNOCAL and Marathon Oil Company. The platform will be renamed "Spurr" subject to approval from the appropriate authorities. The well names have also been revised to reflect the platform name change. The API numbers will remain the same. In discussing this revision with Joan Miller of AOGC on September 20th, she advised a letter requesting approval on the changes be sent to you with a copy of said letter to be enclosed in the current month production reports. Please let us know if this will be sufficient to officially update the monthly production reports to the State. If you .haVe any questions, please contact Cindy Marolt of Marathon Oil Company at (907) 564-6452. Sincerely, Administrative Supervisor ~jcr/PA1/45 AKPA-033-88 RECEIVED S EP 2 2 1988 ','~'-" 0ii & Gas Cons. Commi .... Anchorage A subsidiary of USX Corporation Alaska ,,(=.on Domestic Production Marathon Oil Company September 20, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton- RO. Box 190168 , - _--~-.-~__~/ Anchorage, Alaska 99519 Telephone 907/561-5311 ~'~l NG ASo~ Effective ~ugust 1, 1988, the Texaco "A" platfOrm was acquired by UNOCAL and Marathon Oil Company. The platform will be renamed "Spurr" subject to approval from the appropriate authorities. The well names have also been revised to reflect-the platform name change. The API numbers will remain the same. In discussing this revision with Joan Miller of AOGC on September 20th, she advised a letter requesting approval on the changes be sent to you with a copy of said letter to be enclosed in the current month production reports. Please let us know if this will be sufficient to officially update the monthly producti6'h"'reports to the State. If you have any questions, please contact Cindy Marolt of Marathon Oil Company at (907) 564-6452. Sincerely, Administrative Supervisor ~jcr/PA1/45 -. AKPA-033-88 A subsidiary of USX Corporation Uno<:ll 011 & Gat DiOr' ~ Unocal Corporation '~ P.O. Box 190247 ~ Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL August 1~, 1~88 Robert T. Anderson C)isbict Land Manage~ AIlskl Otstr~t Mr. Mike Kotowski Division of Oil & ~as State of Alaska Pouch 1070~4 Anchorage, Alaska 99510-?034 NORTH TRADING BAY UNIT State of Alaska Change of Operatorship for Platform "A" Dear Mike: On Ouly 2~, 1988, 9. A. Graham of this office sent a letter to Sim Eason in- dicating a change in operatorship for the North Trading Bay Unit. In that Notice it was indicated that Texaco U.S.A Inc. was resigning and Union Oil Company of California was appointed successor Operator effective 12:01 am August l, 1988. The attached designation of Operator form lO-411 to that Letter has enclosed therewith a Ouly 27, 1988 Letter Agreement fully executed by the Working Interest Owners of the North Trading Bay Unit specifically designating Union' as Sub-Operator of Platform "A". Some confusion may have been created by this Oesignation Notice. and it's the intent of this" letter to clarify that~ Union has been designated Sub-Operator of the North Trading Bay Unit Platform "A" and that Marathon, who is ~-Operator of the North Trading Bay Unit, remains in that capacity as well as Sub-Operator of the Spark Plat- form. We .apologize for any confusion this Notice may have created.' ~ /ery truly yours, · /~7 Kevin A, Tablet Landman AJas~;a.Oil & 8as Co,Is. Ccmmiss~o~] Enclosu~ :, ~[~cho~'age f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 2O AAC 25.O2O 1. Name of Owner Union Oil Company of California Marathon Oil Company ~. ,~.dclress... .union ui~ Company of California Marathon Oil Company P. O. Box 190247 Anchorage AK 99519-0247 P. O. Box 190168 Anchorage AK 99519 3. Notice is hereby given of a designation_ of operatorship for the oil and gas property described below: Property designation: North Trading Bay Unit Texaco "A" Platform Legal description of property: ADL 17597 ADL .78776 ADL 35431 Within the North Trading Bay Unit Property Plat Attached [] 4. Name of Designated Operator Marathon Oil Company 'Address P.O. Box 190168 Anchorage AK 99519-0168 5. Effective date designation August 1, 1988 as of 12:02 a.m. 6. Acceptance of operatorship for the above described property with all attendant responsibilities and obliga- tions is acknowledged By: D~yle ~L~f J-ones / ! Signed Title 7. The owner hereby certifies that the foregoing is true and correct Robert T. 'Anderson- Form 10-411, 12-1-85 Title Attorney-in-Fact Date 8/30/88 Submit in Duplicate ,,, STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name of Owner Union Oil Company of California Marathon Oil Company 2./~ddress,,., union u:].- Company of California P. O. Box 190247 Anchorage AK 99519-0247 Marathon Oil Company P. O. Box 190168 Anchorage AK 99519 3, Notice is hereby given of a designation of operatorship for the oil and gas property described below: Property designation: North Trading Bay Unit Texaco "A" Platform Legal description of property: ADL 17597 ADL .78776 ADL 35431 .. Within. the North Trading Bay Unit -_ Property Plat Attached [] 4. Name,of Designated Operator Marathon Oil Company Address P., 0. Box 190168 Anchorage AK 99519-0168 5. Effective date designation August 1, 1988 as of 12:02 a.m. 6. Acceptance of operatorship for the above described property with all attendant responsibilities and obliga- tions acknowledged Doyle ~lf. Jonef Signed Title is . hereby . Production M~'anage~%s~% RegiorOate 7. The owner hereby certifies that the foregoing is true and correct Robert T. Anderson Form 10-411, 12-1-85 Attorney-in-Fact Date 8/30/88 Submit in Duplicate · ::SIAl I= 01- ALA.MKA ALASKA OIL AND GAS CONSERVATION COMMISSION I COMM DESIGNATION OF OPERATOR 20 AAC 25.020 s"R ENG 1. Name of Owner Texaco ]:ac., Marathon O±1 Coapan~, Mob-i] ~xplorat±on a~d SR GEOL Nort:h Amer±ca and ~n±on O±1 Coapan¥ o~ Cal±~ora±a ,IENG 2. Address Un±on O±1 Coapany of: Cal±~ora:La (Des±gnated Operator) ENG ASS"t']~ ?. O. Sox ].90247 Amcborase, &las~a 99519-0247 STATTECHI. : ~11 ! 3. Notice is hereby given of a designation of operatorship for the oil and gas property described below: Property designation: North Trading Bay Unit Legal description of property: The leases which are within the Agreement Area of the Unit Agreement for the Development and Operation of the North Trading Bay Unit Area. Pursuant ~o .the provisions of Article 5 and 6 of said Agreement, the Working Interest Owners approved Union Oil Company of California as Designated Operator. 4. Name o~ Desi~a~ed Ope~a~o~ Union Oil Company of California Address 909 West 9th Avenue R ~ ( E!'~''''f ~ D P. O. Box 190247 Anchorage, AK 99519-0247 /,,~!~'~ ',J '! ·" ...... ';~' ' ~0~S.'" ........ '~' 5. Effective date designation ,..:.~,~,~,,, O,~ a nas Anch0rag9 7:00 a.m. August 1, 1988 ,, 6. AcceptanCe of operatorship for the above described property with all attendant responsibilities and obliga- tions is hereby acknoWledged UNION OIL COMPANY OF CALIFORNIA Signed G. A. Graham Title District Operations Manager Date 7/29/88 7. The owner hereby certifies that the foregoing is true and correct (SEE ATTACHED LETTER) Signed Title Date Form 10-411, 12-1-85 Submit in Duplicate USA ." (TMU)e.", :;. ' ~ ....-., '10 Univw'zml C~ ~Za · Marathon 0il Company ~. O. Box 3118 Houston, TX ??253 · Attention: Mr. Dan Hlhkle ' Mobll Exploration and ~roducin~ North P. O. box 5444 Denver, CO 80217 ' -. Attention: Mr. Fred Oentl amen: nOH-"l! o"-N-oH.LU~IIJN NO~ 1'10.14 PgGE J ' . Texaco zno. (Texaco) h~s agreed' tO assign to Union Company of caltfo=.n/a '~Un-~on) all of %ts right, t~tle and interest in and tO Sta%e o~ Alaska Lease ADL-17597, sub, eat tO the required approval of the State of Alaska, Department o~ Natural Resources, Division of Oil and A port,on o~ ~iS leO$~ ~S sub, eot to the North Trading Bay Unit- In this re~ard,.~ con~ingent upon approval of this assignment, Texaoo is 'hereby tendering I~s =esi~at!on as S~b-Operator of Plmtfo'rm "A" eXfeotive August 1, 1988, accordan=~ with. A~=1.9 T.4 of that certain a~eement entitled "Uni~ Operati~g Agreement He~loo~ and ~ Formation North Trading Bay Un&t~ Cook Inlet, Alaska", as amended ("NT~UOA") effeotive J~ly 1, 1971. Sub, oct ~0 approval b ]' y, Working Interest O~ers Seventy-five percent (7S%) of .the voting power, Union has Platform "A". Upon su6h approval, Un&o~ will aoce9= all duties, obligations' an~ responsibilities o~ Sub-Operator Marathon and Mob~i, as] Working Interest Owners tn the North Trading Bay Uni~, have, a right under Article 7.4 o~ the NT~UOA to vote for the' seleotion of a succe~nr ............ S~b-Operato=. ~owever', if your ~=~+~,,~ =2~:~"2'~]~""'~'~'J2"-'~'~ uu3ec~o.. =0 U~ZO~ ~ucceed~ng Texaco as S~%-0D~rato-, indicate your a~raement ~-- = ' - - - '' -~ ' -~, C ...... r_ _~. ' . ~X -&gn=ng Uelow/an~ re~u~i~.g One ., ~ / ~ -. ·. ,. . , JUL £ 9 ]'.9'88 .. Marathon 0!1 Company 3u1¥ 27, 1988 Page Z ~Oh-*'l I 0 NOHI~I::;IN NO~-- HO. ~% PR~E 9 In order to expedite ~ch.e sale, a rm~ponse by July 29, 1988 would be ~reatl~ apprectatmd. In the meantime, should you have any quem~ions regarding this matte=, Dlease contac~ Mr. Dic~ ~rouch wlth union at (818) 304-7716. TEXACO INC'. UNION OIL COMPANY OF CALIFORNIA By:: Date: ~ AGREED AND ACCEPTED: Datm: MOBIL E?P DENUER CO -~ H K~ub"' 'Fex ~.co USA lOu...,versm~U n~verl~a)O;n/C;t¥CA Plaza M~n~ - ' · 818 ~0~ 2000 July 27, 1988 ' Marathon Oil Company P. O. Box 3128 Houston, TX ?7253 Attention: Mr. Dan Hinkle Mobil Exploration and Producing North P. O. box 5444 Denver, CO 80217 Atte~tion: Mr. Fred Pier,on Gentlemen: ~ · Tex~co Inc. (Texaco) has agreed to assign to Union Oii - Company of Californ~..a (Union) all of its right, title and £n%erest in..an~ to S~a%~ o~ Alaska Lease ADL-17597, to the require~ ~ppro~i of the State of Alaska, of Natural Resources, Division of Oil and Gas. A portion of ~ie 10a8% is subject ~o the Nort~ Trading'Bay Unit. In %h~ =ega=d,. contingent upon approval of this Sub-O~erato=.o~ ~la~o~ "A" ~ffective August 1, 1988, accordance w%th ar~tCl$ g.4 o= that certain agreement' entitled "Unz~ ODe~m~tn~ A~reemen~ ~eml°ek and G Fora%ion Nor~ Trading Ba~ Uni~'C~ok Inleg, Alaska", as amended ("NTBUOA") effec i e Ju y , ~Ubj~ct to ~pprOv~1 b~ Workin~ Inte~e~ O~rs comprising seventy-five percen~ (75%) of the voting power, Union ha~ agreed to assume Texaco's position as Sub-Operator of P19%~o~ ~A"..Upon such approval, Union will accept '~11 du=ie~, ooiigm~ton~ and responsibilities of Sub-Operator Platfo~ "A" aS S$~ forth in the NTBUOA, effective August 1, Mara~on and Mobil, as~Working Interest ~ner~ in the North Trading Bay Unif, have'~a right under ~r%icle g.~ of th~ NTBUOA to vote for the. selection of a successor Sub-Operator. Mowever, if your respective comDantss have no objmc~ion ~o Union succeeding Texaco as Sub-Opera,or, please indicaSe your agreement b~,~.,..-...-~"4~ below ~nd.~--~""~n~.--..-..= one office. Marathon 0il Company o6 al July 27, 1988 Page 2 In order ~O expedite the sale, a response by July 29, 1988 would be g=eatly appreciated. In the meantime, should you have any que$~ions regarding this ma~ter, please contact Ms. Dick Crouch with Union at (818) $04-7716. TEXACO INC. · By: I.ts Attorney in AGREED~ND ACCEPTED: MARATHON 0~ COMPANY Date: UNION 0IL COMPANY OF CALIFORNIA 7- 27- ,_... AGREED AND ACC£PTED= MO~Z ~~t~ON & PRODUC~ U.S. INC. ~~, a~ a~ ~ MO~ ~~ON ~ PRODU~ Date: CO . '.L.. .i. 8-3 6 ~DL-3691 · AMOCO I 8-31-96 ADL-369126 A 1-31-96 DL .LEHNOORFF SANTA Fe ADL-63279 522.00 NICOLAI CREEK UNIT ADL-326119 LEHNOORFF SANTA Fe - r-91 I I I I I I 'F I SANTA FE MOBIL '~"co I I 11-30--g0 A 0 L- 1 7 5 g 7 ADL ADL- ~5904Z:=~ .... Q 326134 5,120.00 Ac. I I I -! I TCXACO UNION .. BAY POOL' ~tar 'a* I II 1,738.00 Ac. , I ,SANTA l 28.16 Ac. PROC). FAC. ADL-17585 5,619.67 Ac. ,,4 NORTH TRADING BAY UNIT amOCO 6 DANCO I I 8-31-96 ADL-369116 AeK)CO I a~dOC O I tEXACO o ./ MOS,. l,,, $, .o Form P--3 REV. 9-306 STATE O,F ALASKA Smbrnit "Intentions" in Triplicat~ ~' & "Subsequent Reports" in Duplicat,_ ; % OIL AND GAS CONSERVATIO. N COMMrl-[EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen use "APPLICATION 'FOR ~ER~I'i'~-' 'for such 'p~o~osal~.) . , 0IL ~ GAS ~ WELL 1__2 WELL ~ OTHER Water Inject ion 2. NAME OF OPERATOR Atlantic Richfield Company 3.ADDRESS OF OPERATOR P. O. Box 360, Am. chorage, Alaska 99510 4. LOCATION OF 1,VELL At surface Platfom Leg lA, Pile #5 2076'W & 618'8 of NE Corner Sec. 34, T10N, R13W, SM 5. AP1 NUIVIF_~ICAL CODE .50-133-200200 6. LEASE DESIGNATION A.ND SEi~IAL NO, ?. IF INDIAN, ALLOTTEE OR TRIBE NAME ADL 17597 8. UmT, FAP~ OR ~SE NAMe. North Trading Bay Unit 9. VTIELL NO. TS -9 10. FIELD AND POOL, OR WILDCAT Trading Bay "G" & Hemlock Pools 11. SEC., T., R.. M., (BOTTOM HOLE OBJECTIVE) Sec. 27, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PERMIT NO. 92 ' KB 6 9-92 14. Check Appropriate Box To Indicate N~,at'ure of N~tlce, Re ~ort, or Other D~ta ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT j j MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT RI[PORTOF: WATER SIIUT-OFF j~ REPAIRING WELL ~ FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING , ABANDONMENT* (Other) Startup of Water Injection (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. · On 2-9-72 at 4:00 p.m. water injection commenced. Pertinent initial data are shown below: Water Injected: Period: Surface Injection Pressure: Average Injection Rate: 45 BBLS 8 Hours 3075 PSIG 135 BWPD 16. I hereby cert/~hat the foregoin~ is true and correct SIGNED J<, 1,% · TITLE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side AtlantieRichfie~dCompany North American Producing Division North Ala~' "District Post Offic6~,ox 360 Anchorage, Alaska 99501 Telephone 907 277 5637 January 24., 1972 C. O:'.~OL ~-. 5 ::: ~''~ I ~.~ u,j ..... ....... s~C .. _ FILE: State of Alaska Department of Natural Resources Oil & Gas Division 30'01 Porcupine Drive Anchorage, Alaska 99504 ATTENTION: Mr. Homer Burrell'' RE: North Trading Bay Unit TS-9 Permit 69-9'2 Gentlemen: We are enclosing State of Alaska. Form P-3, · Subsequent Notice of reperforating selective zones an~~ _the ab?!.e~me~nt~io~ned well to an~i~l~.~ Very truly' yours, /,,,-)/ Sr. Dist. Drlg. Supervisor /WTS/mm Enclosure: Form P--3 P~gV. 9-30-69 STATE OF ALASKA Submit "Intentions" in Triplicate & "Sub~quent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to dr/il or to deepen Use "APP-LICATION 'FOR ~'EI{~IT--" ~or such 'p~o~osal~.) · ~ 1. WELL WRLL OTHER Water Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3.ADDRESS OF OPERATOR P. 0. Box 360, Anchorage: Alaska 99510 4. LOCATION OF WF~LL · At sub'face Platform Leg iA, Pile #5 2076' W & 618' S of NE cr Sec 34, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc. 92' KB Check Appropriate Box To I,ndi'c~te N, ature of N~ti'ce, Re: NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT ,MULTIPLE COMPLETE SHOOT OR ACIDIZE J J ABANDON$ REPAIR WELL CHANGE PLANS ~Other) AP1 NU'M.F_..RICA. L CODE 50-133-200200 6. LEASE DESJGNA'FION A.ND SEiq/A.L NO. ADL 17597 ?. IF INDIAN, A.LLO'i-r~:w. OR TRiBE NA_~IE 8. UNIT, FA_B/Vi OR LEASE NAME North Tradin~ Bay Unit -- 9. WELL NO. TS-q 10. FT~.T.r~ AND FOOL, OR WILDCAT Tradin~ Bay "G" & Hemlock Pools 11. SEC., T.,~R., M., (BOTTOM HOLE O~JECTIVE) Sea 27. T]ON. R]RW. SM 12. PERATIT NO. 69-92 zor*, or Other D~ta SUBSEQUENT REPORT OF: , , WATER SItUT-OFF REPAIRING WELL } FRACTURE TRI~ATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEiqT$ (Other) Reperforate & complete as wtr ector. (NOTE: Report results of multiple completion on Well Completion or Reeompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all perttneut details, and give pertinent dates, including estimated date of starting an)' proposed work. Began operations on 1-9-72. Killed well w/salt water, Removed tree & nippled up BOPE. Pulled Packer. Perforated w/2jspf 10369-10339', & 10310-10300'. Perforated two 1/2" jspf 10310-10339' & 10090-10150'. Perforated four 1/2" jspf 10200-10278', 10165-10193' & 10060-10078'. Set packer ~ 10040' Ran 321 its 9.2# N-80 buttress tubing w/bottom ~ 10037'. Gas lift valves ~ 2~47', 4688' , 6190' , 7449' , 8424' , 9149' & 9813' . Nippled up xmas tree & tested to 3000 psi OK. Released rig @ 10:30 A.M,. 1-16-72. Selective zone water injection well. 16. I hereby certify that f~e~or~,gotn,.ll~cr~ae correct SIG:~:~D ~/A./..Zr/// .. ,,T~, Sr. Dist. Dr lg. Supervisor (This spac State office u~s~) ,. APPROVED B~ CONDITIONS OF APPROVAL, IF AI~: TITLE DATE See [nstrudions On Reverse Side Atlan'ticRichfieldCompany North Am~p.ican Producing Division North AI~, '3istrict Post Offic~uox 360 Anchorage, Alaska 99501 Telephone 907 277 5637 December 2, 1971 State of Alaska Department of Natural Resources Oil & Gas Division 30'01 Porcupine Drive Anchorage, Alaska 99504 ATTENTION: Mr. Homer Burrell RE: North Trading Bay Unit TS-9 Permit 69-92~ Gent lemen: We. are enclosing the Sundry Notice.with our intention to reperforate and convert the above mentioned well to an injection well. Very trusty yours B.. T. Loudermilk Dist, Drilling SUper?is or BT ,/W J/mm Enclosure: [,)EC 2 t9i'1 DIVISION OF OIL AND Form REV. 9-30-6 9 S~bmtt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMII-I'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form /or proposals to drill or to deepen use "APP-L,IC:kTION 'FOR ~'EP,~A~IT~-'' 'for such 'p£o~)osal-~.) . . W£LL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Co~any 3. ADDRESS OF OPERATOR P. 0. Box 360~ Anchorage, Alaska 99510 4.,,OCAT~O~ O~ ^t,u,'~e Platform Leg iA, Pile #5 2076' W & 618' S of NE er Sec 34, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, OR, etc. 92' KB Ch~ck Appropriate Box To indicate N, ature of NOtice, Re, NOTICE OF INTENTION TO: 14. TE~T WATER SHUT-OFF I I FRACTURE TREAT SHOOT OR ACIDIZE [ J REPAIR WELL tOther) ;/ PULL OR ALTER CASING j MULTIPLE COMPI,ETE ABANDON* CHANGE PLANS Reperforate 5. AP1 N~CA.L CODE 50-133-200200 6. LEA~E DES/GNA"lION A-ND SERIAL NO. ADL 17597 7. IF IN]DIAN, AJ.J-~O'i-rEE OR TRIBE NA1VI~ 8. UNIT, FA. RM OR LEASE NAME ~r~v-t_.h q~nA!ng ]~y TTn~+. 9. WELL NO. ?s #9 10. FIELD AND POOL, OR WILDC.~T Ba "G" Trading 7, & Hemlock Pools 11. SEC., T., R., M., (BOTTOM I-IOL~ OBJECTIVE) Sec 27~ T%0N~ R13W: SM 12. PER1VLIT 1~O. 69-92 mr% or 'Other D~ta ' SUBSEQUENT REPORT OF: WATER SItUT-OFF REPAIRING WELL J FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEI',fT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) I5. DESCRIBE PROPOSED OR COMPLNTED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. Move rig over well on 12-15-71. Kill well w/filtered salt water & pull completion assembly & clean out to 10375'. Perforate w/4 holes/ft w/4" casing gun - 10,060-10,1078' 10,165-10,193 ' 10,200-10,278 ' Perforate w/2 holes/ft w/4" casing gun - 10,090-10,150' 10,300-10,375 ' Set drillable packer ~ + 10,000'. Rerun completion assembly. Release rig. Utilize as injection well. D1VISlON OF OIL AND CA,5 16. I hereby certify thH the forf~oin~ is true.nd TITLE Dis*,: Drilling Supervisor DATE / ,,,7. ~ ~2- '-" 7/ correct (This space for State ofl~e_use)] , APPROVED BY .. CONDITIONS OF ~P~t~)VAL, IF ANX: See Instructions On Reverse Side Approved Copy Returned Form P--3 ~ REV. 9-30-6~ i STATE OF ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION; COMMITrEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR P~IT~" for such proposals.) 5. API ~CAL CODE 6. ~ D~ffA~O~ ~- S~ NO. ~L g 17597 ~. I~ ~I~, ~~ Og T~BE N~ 0IL [] GAS ~--~ WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT, FA3~IV[ OR LJ~kSE HA-ME TEXACO Inc. State of Alaska 31 ADDRESS OF OPERATOR P. O. Box 4-1579, Anchorage, Alaska 9950'3 4. IX)CATION. O,F WELL At surface 13. ELEVATIONS (Show whether DF, RT, GR, etc. KB = 92 ' MSL 14. 9. WELL NO. TS ~ 9 10. FIELD ~ POOL, OR WILDCAT Tradinq Bay NE Pool 11. SEC., T., R., M., (BOTTOM HOI.~ OBJECTIVE) Sec. 27-10~-13~, S.~. 12. PERMIT NO. I 69-92 Check Appropriate Box To [ndi'cate Nature of NOtice, RepOrt, or Other 'Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I [ PULL OR ALTER CASING FRACTURE TREAT [ } MULTIPLE COMPI,ETE SHOOT OR ACIDIZE [__] ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDON MEN'T$ (Other). NOTE: RePOrt results.of multiple completion on Well ompletion or Recompletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. · · · Skiiled rig over TS # 9, installed blow-out equipmeDt,. and pulled well. (Completed 11-30-70) Reperforated 10,090 - 10,150 and 10,300 - 10,.37~5KB with .two Dresser-Atlas 4" carrier jets per foot. (Complete 12-1-7t Reran tubing and placed well on production. (Completed 12-2-70) ' Note: During the above work the automatic shut-in, device mandrel was omitted from the well· This certifies that well TS ~. is incapable of flowing oil or gas in a ,q~ ~.,%y[~ainst atmospheric pressure· V~:.,.:...~~ ¥! , t7 16. (Thls/~Fe ·for~t~te o~&e u'l~se~ // APP~VED B~ TITLE CONDITIONS OF APPROVAL, IF A~: 9!VIStO'N OF Git AND ~A~ DATE 12-- 4--:.7 .. DATE See l~nstructions On Reverse Side DEG - (Superior Oil)'MUB-GAB / STATE OF ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir Use "~PPLICATION FOR PERMIT--" for such proposals.) ~. API 'NUI~P, RICAL CODE 6. ~--Ea~U-'N'AT~UN' I(~D~~ NO. ADL { 17597 1. 7. IF INDIA/q, ALLO~I~EE OR TR/BE NA-~E OIL ~'~ GAS ~'~ WELL WELL OTHER 2. NAME OF OPERATOR TEXACO Inc. 3. ADDRESS OF OPERATOR P. O. Box 4-1579t Anchoraqe, Alaska 99503 4. LOCATION. O,F WELL At surface 13. ELEVATIONS (Show whether DF, RT, GR, etc. KB = 9 2' 14. Check Appropriate Box To I,n.d,i'cate Nlature of N~oti'ce, Re 8. UNIT, FARNI OR LEASE NA/VIE state of Alaska 9. WELL NO. TS ~ 9 10-. FIELD A~NT) POOL, OR WILDCAT ~{n~ R~v NE Pool 11. SEC., T., R., M.,'(BOTTO/~ HOL~ OBJECTIVE) Sec. 27-10N-13W, $.M. 12. P ERM/T 69-92 3ort, or ~Other NOTICE OF INTENTION TO: FRACTURE TREAT I I MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANOE PLANS (Other) · SUBSEQUENT REPORT 0F: WATER SII.UT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONME~T' (Other) NoTE: Report results of multiple completion on Well ompleti0n or Recompletion RePort and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an.y proposed work. ., . , .... ® Ski~ed rig over TS ~ 9, installed blow-out equipment,, and pulled well. (Completed 11-30-70) Re~er~orated 10,090 - 10~150 and 10,300 -'10,375KB with two Dresser-Atlas 4' carrier jets per foot. (Complete 12-1-7( e Reran tubing and placed well on productioru (~ompleted 12-2-70) · Note: During the a~ove work the automatic shut-in device mandrel was omitted from the well. This certifies that well TS is incapable of flowing oil or gas in_a~y~.q~a~n,t£~y~--,against ' atmospheric pressure. 16. I hereby certify that :.the foregoin$ is true and correct (This spa~e ~or~ate~ ~~ APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE RDF: j om DEG - (Superior Oil) See l~nstrucfions On Reverse Side MUB-GAB PETROLEUM PRODUCTS January 6, 1970 Mr. Homer L. Burrell State of Alaska Division of Oil & Gas 3001 Porcupine Dr. Anchorage, Alaska 99501 TEXACO 'INC. P. O. BOX 4-1579 ANCHORAGE, ALASKA 99503 TEXACO Inc. ~A -~ ~ .... ..OKG ~ T-S WELL NO. ~K',~LV HWK~ REL ~ ,,~' , ..... ;(- Dear Homer: In accordance with your letter dated December 19, 1969, enclosed are forms P-4, Monthly Report of Drilling and Workover Operations, for September, October, and November, 1969. We regret the delay in furnishing you with this information. Yours very truly, TEXACO In · C. H. BrOwn District Landman CHB:bw Enclosures l~rra No. 1~---4 REV. STATE OF ALASKA SUBMrr nv Dm:,Lma.'m OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. o,L [] o,. © 2. NAME OF OPERATOR TEXACO Inc. 3. ADDRESS OF OPEI{ATOR P. 0. BOX 4-1579, Anchoraqe, Alaska 99503 4. LOCATION OF WELJ~ 2,076' West and 618' South of the Northeast corner of Sec. 34, T10N-R13W, S.M. ~. API NUAIERICA~ CODE API 50-133-200200 LEASE DESiGA1ATION AND SERIAL NO. ADL ~17597 '7. IF INDIA]~, ALOTTEE OR TRIBE NAME 8. L,~IT,F.~RAI OR LEASE State of Alaska 9. WELL NO. TS ~9 10. FIELD A_ND POOL. OR WILDCAT Trading Bay NE 11. SEC., T., R., M., (BOq~POM HOL2g OBJ~CT~) Sec. 27, T10N-R13W, 1~-. PERlVlIT NO. 69-92 S.M. 13. REPORT TOTAL DEPTH AT END OF MONTH, CF_A_NGES IN HOLE SIZE, CASING ANT) CEMENTING JOBS INCLUDING DEPTH SET ~ VOLLrNIES USED, PERFOt{ATIONS, TESTS A/XrD RESULTS. FISHING JOBS, JUIqK IN HOLE A_ND SIDE-TILACKED HOLE A. ND A/~Y OTHlgR SIGNIFICA/~T ~GES IN HOLI~ CONDITIONS. For month of September, 1969: Refer to attached Summary 14. I hereby certi and correct Sm~mD /~/~" ~ ~TLE Dist. Superintendent D.~ January 5, 1970 ?NO~E--R~on this form is required for each calendar month, r egardless of the status of operations, and must be file~ in duplicate wi[h~e Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. FAW: bw l~rr~ No. P---4 B. EV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMIT[EE SUBMIT IN DUPLICATE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS AP1 NUAIERICAL CODE AP! 50-133-200200 6. LEASE DESiGN'A ~'~ION AXD SERIAL NO. ADL 4~17597 2. NAME OF OPEP~ATOR 8. L~-'IT,F.~AI OR LEASE N.~E TEXACO Inc. State of Alaska 3. ADDRESS OF OPEI~ATOi~ P. O. Box 4-1579, Anchorage, Alaska 99503 4. LOCATION OF WFJ.,L 2,076' West and 618' South of the Northeast corner of Sec. 34, T10N-R13W, S.M. 9. WELL NO. TS ~9 10. FTF. Lr~ AND POOL. OR WILDCAT Tradtna Bay NE Il. SEC.. T., R~, M.. (B~TOM HOLE Sec. 27, T10N-R13W, 19-. PIKRlViIT NO. 69-92 13. REPORT TOTAL DEPTH AT END oF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PEP~FOKATIONS, TESTS AND RESULTS, FISHING JOB~, JUNK IN HOLE AND SIDE-TRACKED HOLE ANT) A2~Y OTI-I~R SIGNIFICANT CI-IA~ES IN HOI~ COBrDITIONS. For month of October, 1969: Refer to attached Summary 14. I hereby certify that the foregoing is true and correct NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. PAW: bw l"orra No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~. API NUAiERICAJ~ CODE API 50-133-200200 6. LEASE DESiGI~Ai"ION AND SERIAL NO. ADL 917597 1. T.IF INDIA]q[ALOTTEE OR TRIBE NAME OIL ~ GAS [] WELL W~-LL OTHER 2. NAME OF OP~kTOR 8, L~'IT,F.~{ OR LEASE TEMCO Inc. State of Alaska 3. ADDRESS OF OPhiR P. O. Box 4-1579, Anchorage, Alaska 99503 4. IX)CATION OF WFJ~L 2,076' West and 618' South of the Northeast corner of Sec. 34, T10N-R13W, S.M. 9. WELL NO. TS ~9 10. ~'lh2.,D AND POOL. OR WILDCAT Trading Bay NE I1. SEC., T., R., M., (BOTTOM HOLE oB.mcrn~ Sec. 27, T10N-R13W, 12. PERMIT NO. 69-92 S.Me 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AN~ VOLUATES USED, PERFORATIONS, TESTS A_ND RESULTS, FISHING JOB~, JLrNK L~ HOLE A_ND SIDE-TI~ACKED HOLE ANT) ANY OTtIEt{ SIGNIFICA/~T CIiAN.GF~ IN HOL~ CONDITIONS. For month of November, 1969: Refer to attached Summary 14. I hereby true and correct S~Gm~ ~'~//~-/~--~ ~Dist. 2uoerintendent DA~ January 5, 1970 ..... , j' ,df. ~ ~,'.l~clr-.r.;~r- " /~/'NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. FAW: bw ,,, Form P--7 ;~ SUBMIT IN DUP E* STATE OF ALASKA (See °the~'in- structio~s on OIL AND GAS CONSERVATION COMMITTEE reverse side) WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: h. TYPE OF COMPLETION: NEW [X[ WOnK [~] %VELL OVER OIL [] 6AS WELL WELL ~-~ DEEP- ~-~ PLUG ~-~ EN BACK 2. NAME OF OPERATOR TEXACO Inc. 3. A~DRESS OF OPERATOR' DRY :' Other DIFF. r.~SVR. ~-] i. Other ~: 50-133-2. 0~.2 ~, ,,G 6. LEASE DES/GNATION ~ ~Eltli~ NO. ADL 17597 HW~(_ i8. 'UNIT,FA/{1VI OR LEASE~,~.M,E State of Al~a. 9. WELL NO. TS %9 P. O. Box 4-1579, Anchorage, Alaska 99503 10. FLlf;I-J) AiYDPOOL;ORWILDC~AT ~. LOC*TION OF WELL (Report lo~iion olear~ and in accordance with an~ ~tate requirements)* Trad ing Bay NE At su~ace Platform Leg ~, Pile No. 5 Or 2,076 ' W and u. s~c., T..R..~.. ~18' p~d. Of the NE corner ~of S c. ~"10N- 3W M. o~~) ~n~ 6~2~ t top e SE co~ne~ of Sec. 27-10N-13W, S~M. Sec. 27, t°t~'~e~l,606' N and 620' Wes~ of Che SE co~ne~ of ,~.~ZT~O. Sec. 27-10N-13W, S.M. '" 69-92 13. D~ ~DD~ 114-D*~ T.D. ~C7 {'i5. DA~ CO'~ SUSP ~~· 9-4-69' 10-17-6 , 11-,12-69 o KB = 92 ' M.S.~. ~ 32 ' KB 18. T~ D~H, ~ & TVD,9. PLUG, ~CK ' MD '& ~D~. ~ ~L'F~ CO~L., t21. INTERVALS DR(LLED BY ~, .' '{ [ ~W~Y* SOT*~ ~00LS CA.L~ TOOLS 10,387, 9,962 { 10,369, 9,944 { ' ~ ~'~- All. ~. PRODUCING ~T~V~(S), OF~IS OOM~TIO~P,'Bo~0M, ~E (~ ~D ~)* 23. W~S DIREC~O~ { SURVEY ~ADE Hemlock: 10,300, 9'87.5 Top "G"~Sand: 10,090, 9,670 Top ;10, 375, " 9, 950 Bottom* 10~150~ 9 727 B~tOm YeS 24. ~P~ E~CTKIC ~D OT~~ ~GS RUN ~" DIL, CFDL, BHC-I { A2~OUNT PULLED CA, SING SIZE WEIGHT, LB/FT. 13 9 43 ..5-47 mma RECORD all .strings set in well) DEPTH .SET (M/)) HOLE SIZE CEIIILN'TING RECOI~D SeM. LINER BEC O.I%D SIZE TOP (MD) BOTTOM (A~D) SACKS CENIENT* SCREEN (MD) 28. "G" Sand: Hemlock -' .,, size and ~number) 10,090 to 10,150--12~½'' holes/ft. (Shot 3 times) 10,300 to 10,375*-8-½." holes/ft. (Shot twice) * Wire 'line meas! ~rement 27. TUBING SIZE DEI~ SET (1VID) ~ PACKER SET (MD) 056 983 29. ACID, SHOT, FX;~CTURE, C'F2~ENT SQUEEZE, ETC. 162 090-10 ) AMOI,/NT..Zdh'rD I~IND..O,F M;iT~R/AL USISD ales-Squeezed 34 ax. ales-Squeezed 20 ax. ales-Squeezed 37 ax. Class "G Class "G Class"G Mud DATE FIRS~ PI-{ODUCTION 11-I-69 "il-i-!9[. 8.5 172/64 FLOW, ~B~G [CAS~G ~Ss~ [CALC~ OI~BBL. 7o I soo I 181 31. D~SPO. S~T]0N OF CAS (Sold, used fo~ fuel, vented, etc.) Vented and used for fuel ..... PRODUCTION PRO'DUCT10,N lVlETIiOD (Flowing, gas lif't-.l~flmpii}g~size and type of p~p) Gas Lift WELL STATUS (Producing or shut-in) S I OIL--BBL. GAS--IV{CF. WATEI%--B.IAL. ] GAS-OIL t%~TIO { 64.1 I 17.7 I 5.7 [ '275 '.].]GAS--1VICF. WATEH~BBL. . [ OIL GRAVITY-APl'" (CORR.) 82. LIST OF ATTACHMENTS Completion Repo~t and Directional: Survey 33. I hereby~. -/ff ,certify that .the~. foregoij~,Tand attached information Is complete.and correct as determined fF6-fi~ a~l?~rds SIGNE~~'~/~ TITLE DiS.t. Superintendent DATE 12-10-69 /~XI.""~'-. Barber l,--' *(See Instructions and Spaces for Additional Data on Reverse Side) Aci INSTRUCTIONS --General: Thi.s form is:designed for submitting:a complete and correct well co'repletion report end log on 'all tyl~es of lends end leases in Aleske. -Item: 16: Indicate which elevation is used es ~eference (where not otherwise' shown) for depth.measure- ments given:in cther speces on this-'form end in.any attachments. ._. '~, i!tem~"20/.~,~d 22.:: if this well is completed for separatc, production from mor. e than one interval zone (multiple cO'repletion), so stere in item 20~ and in item 22 show the p, cducing interval, or intervels, 'top(s), botto, m(s) end name (s) (if any) for onlyZthe interval reported in item 30. Submi!' e separate report (page) on 'this fb?m, adequately id. entitled/for each adctitional interval to be-~se, perately produced, shdw- ing the ~'~fdition. el .dat~ pertinent fo such '~nter(;al. " .. . · Item26: "S~cks Cement": Attached supPlemental records for this well should sh, ow the details of eny mul- tiple,stage cementing 'anti the Ioc~tion °f'"the cementing tool. ' Itemi'.28:.Submit a separate completion report.on this form for each intervel tol-.be~., separately produced. (See ~nstruction-for items 20 and 22 abOye). ,, , 'i. ,] ': 'i'b/IMA. Ry OF' I~)~/TATION T~,~']'S "iNCLU~.IN(~ INTERVAl. T~TED, P~U'R~ DA~ ~ ~V~ OF OI~ GAS,- ,.: . ':. ;.;. :,; ' t 35. G~GIC MAR1(~ * ' WAT~ AND MUD , , .... '~--lease refer ~m .the COmpletion Report .... ~s. '"~ : , ' '"' Top Hemlock "10,300 9,875 ..,.' y. i.' :. ..... ,. . ,. .... , ...... . . ., · . .' . : .... i , '.:/ CO~' DATA, A~'PACII: B~IE?-D~C~IPITIO~S O~ Lrr~i0~OGY. ' ' ' '' .0 ,.AND DE'FECTE1) StlOWS OF OIL, G~' OR WA~. · .... ',. : . ........... , , - . , : ,,~ i. IONE . ' .. ~ . t .. .. .. i.- . '.,. ..... .... .-~,- . . _ . [. '?, -~..- , -~ ~:;.' ~ . . . ,,. ., . : TEXACO Inc. COMPLETION REPORT--NEW WELL AREA: Trading Bay, Alaska WELL: Texaco-Superior Trading Bay TS ~9 FI.ELD: Trading Bay Field LOCATION: SURFACE: Trading Bay Platform "A", Leg IA, Pile No. 5, or 2,076' West and 618' South of the Northeast corner of Section 34, T10N-R13W, S. M. BOTTOM-HOLE: At TD: 1,606' North and 620' West of the Southeast corner of Section 27, T10N-R13W, S. M. ELEVATION: KB is 92' M.S.L. DATE: December 10, 1969 RDF :bw (12-5-69) DRILLED BY: Loffland Bros. Drilling Co. DATE/~COMMENCED WORK: September 4, 1969 DATE COMPLETED WORK: NoVember 12, 1969 DATE OF OPEN FLOW POTENTIAL TEST: N/A Texaco Inc.-Superior Oil Co. Trading Bay Platform "A" Well TS %9 Completion Report -2- December 1~ 1969 SUMMARY TOTAL DEPTH: 10,387' MD; 9,962' TVD PLUGGED DEPTH: 10,369' MD: 9, 94.4' TVD CAS ING: 13 3/8", 54.5%, J-55, Butt, Surf. to 1,370' 9 5/8", 47%, S-95, Butt. -- 52 jts. 9 5/8", 47%, N-80, Butt. -- 41 jts. 9 5/8", 43.5%, N-80, Butt. --157 jts. 9 5/8", String: Surf. to 10,369'*, KB. PERFORAT IONS: "G" Sand: Tubing Guns: 10,090 to 10,150, 4-½ holes/ft. Tubing Guns: 10,090 to 10,150, 4-½ holes/ft. Casing Guns: 10,090 to 10,150, 4-½ holes/ft. Hemlock: Tubing Guns: 10,300 to 10,375', 4-½"holes/ft. Casing Guns: 10,300 to 10,371, 4'½"holes/ft. * NOTE: Drillers' measurements differ from wireline measurements which were correlated to the DIL log with the Gamma Ray log. ELECTRICAL SURVEYS: 1. Dual-Induction Laterolog 2. Compensated Formation Density Log 3. Borehole Compensated Sonic Log 4. High Resolution Dipmeter 5. Cement Bond-Gamma Ray Log 1,364 - 10,387 8,00~ - 10,387 8,000 - 10,375 3,000 - 10,387 8,000 - 10,356 FORMATION TESTS: Zone Date Test Oil Lenqth Choke Rate Water ~bnm ation , Rate Gas GOR Tpfi/Cp oApI 'i "G" Sand 10-31-69 No Production from "G" Sand Hemlock 11-6-69 24 hr. 72/64 123 BPD 1 BPD 34 275 80./850 36° Texaco Inc.-Superior Oil Co. Trading Bay Platform "A" Well TS ~9 ' ~ Completion Report -3- Decemberl0, 1969 MORNING REPORT SUMMARY SeDtember 4, 1969 Skidded rig over Pile ~5 of Leg IA and rigged up. Mixed mud and spudded well. Drilled to 180' with a 12¼" bit and a 17½" hole opener. ~S_eptember 5, 1969 Drilled a 12~" hole to 1,091' and opened hole to 17½" to 423'. (75 PCF) SePtember 6, 1969 Drilled ahead to 1,383' with a 12~" bit and opened to 1,383' ~" hole opener. (72 PCF) with a 1.2 ~ptember 7, 1969 Ran 32 jts., 13 3/8", 54.5.~, J~55 Buttress with shoe at 1,370' and float collar at 10327'. Cemented with 1,200 sacks Class "G" cement. Used a top and bottom plug. Rigged down riser and ran in 1" stinger and did a top job with 150 sacks, Class "G" cement. Nippling up BOPE at report time. S_~eptember 8, 1969 Finished nippling up. Test BOPE consisting of a pipe, spool, blind, pipe and hydril 12" 3 000~ stack and 13 3/8"--both O K Installed bowl protector. Drilled a 12~" hole to 1,914'. (72 PCF) September 9-12, 1969 Texaco Inc.-Superior Oil Co. Trading Bay Platform "A" . Well TS #9 Complet ion Report -4- December 10, 1969 September 13-19, 1969 Found.top of plug at 2,576' and polished off to 2,587'. Oriented dyna drill, kicked off plug, and drilled a 12~" hole to 4,922'. (75 PCF) September 20-26, 1969 Continued drilling a 12¼" hole to 7,200'. Lost roller ~off of roller reamer 9-24-69. Recovered junk with a magnet 9-24-69. September 27-October 4~ 1969 Continued drilling with a 12¼" bit to 8,794'. (75 PCF) END OF MONTH: Drilling at 8,000 feet. (74 PCF) BEGINNING OF MONTH: Drilling at 8,000 feet. (74 PCF) October 5, 1969 Continued drilling a 12~" hole to 8,912'. Lost two rollers and pins off of a Grant stabilizer' Ran in 11½" Globe basket and recovered three pieces of junk. October 6, 1969 Ran in 12~" bit and found 20' of fill: cleaned out. Spun on junk for one hour. Ran in Globe basket--made 2'; pulled out with no recovery. Ran in with 12¼" bit, cleaned out 6° of fill and spun on junk for three hours. Qc.t.ob~er 7, 1969 Texaco Inc.-Superior Oil Co. Trading Bay Platform "A" Well TS #9 Completion Report , --5-- December 10, 1969 October 18, 1969 Ran Density, Sonic, and Dipmeter logs. October 19-20, 196~9 Conditioned hole and ran 251 jts. of 9 5/8" casing as follows: 52 jts., 47~, S-95 Buttress, 10,369 - 8,214' 41 jts., 47#, N-80 Buttress, 8,214- 6,506' 157 jts., 43.5#, N-80 Buttress, 6,506 - 60' 2, 10' pups, 47~, S-95 Butt., 60 - 40' 1 jt., 47#, N-80 Butt.xSrd, 40 - 0' Shoe at 10,369', float collar at 10,3~57', shut-off baffle at 9,896' and DV collar at 3,004'. Cemented through shoe with 200 cu, ft. of water mixed with 500# of caustic followed by 1,000 sacks of Class "G" cement premixed with 1% D-31 friction reducer and 18% salt by weight of mixing water. Slurry weight was 123 PCF. Dropped plug and opened DV Collar. Pumped in 850 sacks of Class "G" as above preceded bY 50 cu. ft. fresh water. Measured in and drilling on DV collar at report time. October 21, 1969 Drilled out to float collar at 10,359' DP measure. Circulate clean and ran CBL-Gamma Ray-Collar Locator ~og. Float collar at 10,364' wireline measure. Shot 4-½" holes at 10,292' for squeeze. October 22, 1969 Ran and set Halliburton E-Z Retainer at 10,187'. Established breakdown rate of 3 CFM at 6,000 p~i. Went up to 6,100 psi and broke back to 4,600 psi, pumping away at 12 CFM. Squeezed with 150 sacks Class "G", pumping at 9 CFM with 6,000 psi. Final pressure was 6,800 psi. Reversed out 36 sacks, left 40 sacks in the casing with 34 sacks behind pipe. Pulled out and shot 4-½" holes at 10,162'. Ran and set retainer at 10,092'. Established breakdown rate of 3 CFM at 4,200 psi. Changed to 3.5 CFM at 6,000 psi after 15 CF pumped in. Squeezed with 50 sacks Class "G", pumping 2 CFM at 6,600 psi. Final pressure was 6,800 psi. Squeezed with 2,500# back pressure on annulus. Backscuttled 5 sacks, left 25 sacks in casing, and 20 sacks behind pipe Shot 4-½" holes at 10,087'. · Texaco Inc.-Superior Oil Co. Trading Bay Platform "A~' Well TS %9 Completion Report December 10, 1969 Octoberj. 23, 1969 Ran and set retainer at 9,997'. Established breakdown rate of 8 CFM at 6,000 psi. Pumped in 100 sacks Class "G" cement at 6,000 psi w~.th final pressure o.[ 7,000 psi. Squeezed with 2,500 psi back pressure in annulus. Reversed out 30 sacks, left 33 sacks in casing, wi. th 37 sacks behind pipe. Ran in and drilled out retainer and hard cement to 10,092 ~. Circulated clean and tested casing to 3,000 psi for 15 minutes--hei~ October 24, 1969 Shot 4-½" holes at 10,085'. Ran in Cook WSO Tester with 950' of water cushion. Packer set at 10,065', tail at 10,086' Very weak blow for one minute during one-half hour test. Pulled out. Chart showed that tool did not open. Re-ran tester with packer at 10,042' and tail at 10,063'. Tested for one hour--weak blow for 14 minutes; then dead. Pulled out and found 10' of fluid rise (rotary mud). Initial hydrostatic pressure was 4,851 psi: final hydrostatic was 4,840 psi. Initial and final flowing pressures were 380 psi. Ran in with an [~" bit and drilling on retainer at 10,092'. October 25, 1969 Drilled out retainer and cement to 10,168'. Cleaned out to 10,184'. Circulated hole clean, tested casing to 3,000 psi for 15 minutes--held O.K. Shot 4-%" holes at 10,160'. Ran in with Cook tester with 950' water~ cushion. Set packer at 10,135' with tail at 10,156'. Opened to~'~with light blow for 7 minutes; then dead for the remainder of the one-hour test. Pulled out and found 35' of net fluid rise (rotary mud). Initial hydrostatic pressure was 4,839 psi; final hydrostatic was 4,829 psi; initial and final flowing pressures were 419 psi. Ran in and drilled out retainer at 10,187'. Drilled cement to 10,294'. OCt.ober ...2...6, 1969 Cleaned out to top of fill-up collar at 10,357'. hole clean; test~ ~~ ~- ~ ~ Texaco Inc.-Superior Oil Co. Trading Bay Platform "A" Well TS ~9 Completion Report December 10, 1969 Pulled out and found 30' of fluid rise (rotary mud). Initial hydrostatic was 4,806 psi, final hydrostatic was 4,829 psi. Initial flowing and final flowing pressures were 455 psi. October 27-28, 1969 Ran in open ended to bottom and reversed hole clean. Recovered 5 gallons of metal and rubbers. Pulled back 5 stands and changed over to fresh water. Laid down drill pipe and pulled wear bushing. Ran 319 joints of 3½, 9.3~, N-80 Buttress tubing with accessories as follows: Otis ball valve at 307; Camco KBM gas lift mandrels" and BK valves at 3,581, 4,796, 5,645, 6,276, 6,689, 7,446, 8,077, 8,585, 9,121, and 9,940; Otis "XO" sliding sleeve at 9,978; Guiberson RH-1 packer at 9,983; Otis "X" nipple at 10,023; and Guiberson shear seating sub at 10,056. Removed BOP, installed Xmas tree and tested to 3,000 psi. Dropped ball, but could not pressure up to set packer. Ran in Otis and found sliding sleeve open; sleeve was run closed. Closed sleeve, pressured up and set packer. Sheared out ball with 3,000 psi. Packer and tubing held 2,100 psi with annulus open. October 29, 1969 Gas lifted well for 16 hours and recovered approximately 300 bbls. of fluid. Shot 4-½" Schlumberger jet holes per foot through tubing in the "G" Sand from 10,090' to 10,150' (wire- line measure). October 30-31, 1969 Gas lifting well--no production. Ran in Schlumberger and Perforated as before (10-31-69). Texaco Inc.-Superior Oil Co. Trading Bay Platform "A" Well TS ~9 . Completion Report -8- December 10, 1969 November 2, 1969 Ran Otis gradient survey while gas lifting 122 BFPD in heads. Survey showed that all gas lift valves working properly. Killed well with salt water, removed well head and installed BOPE. November 3-4, 1969 Tested BOP equipment with 1,500 psi. Pulled packer and pumped in 500 bbls. of diesel followed by 40 bbls. of salt water. Pulled tubing. Ran Schlumberger 4" carrier guns and perforated 4-½" holes per foot from 10,090' to 10,150' and from 10,300' to 10,371' (4' fill on bottom) wireline measure. Re-ran tubing as before, installed and tested tree, set packer and sheared out ball. Placed well on gas lift. November 5-7, 1969 Testing well. 124 BFPD, 0.4% cut (11-6-69). Well shut in 11-7-69. November 8, 1969 Rig up for acid job. B.J. pumped in 10,000 gallons of Dowell Ultra mud acid, followed by 1,000 gallons of diesel and 3,650 gallons of fresh water. Maximum pressure on tubing was 1,700 psi; final pressure was 100 psi. Initial annulus pressure was 740 psi and final was 960 psi. Placed well on gas lift. November 9-12, 1969 Testing well, Released rig and tender 11-12-69. November 1, 1969 D_JYJ~ION OF Oil AND~ Gas lift and test--no production from "G" Sand. Ran Schlum- berger and perforated Hemlock with 4-½" jet holes per foot from 10,300' to 10,375' (wireline measure). Produced 181 BOPD after Hemlock perforation. PLATFORM TEXACO' SUPERIOR "A" TS-9 Leg Pile lA 5 ERNAI~O ~' o v ~, o 7969 JOR NO. AK-6912 CO~,PANY TEXACO~ INC. WELL T,5. NO, 9 TEXACO-SUPERIO~ PLATFORM A LEG lA PILE 5 M,S,L, g2 FT, RECURD OF -SURVEY ALL CALCULATIONS PERFORMED BY I B ~ ELECTRON[C COMPUTER TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH O M SUB DRIFT SEA D[REC DEG, TOTAL COORDINATES 0 0 0 0.00 -92.00 N 0 E 0.00 5 0.00 W 100 0 0 100.00 8.00 N 0 E 0.00 5 0.00 W 213 0 4 212,99 120,99 5.76 E 0.03 S 0.15 E 303 2 30 302.91 210,91 N 73 E 1.10 N ~.90 E 423 4 25 422,55 330.55 N 56 E 6.28 N 11.57 E 491 3 ~9 490.~0 398,40 N 5~ E 8.82 N 15.33 E 555 3 ~5 554,26 462.26 N 51 E 11.~5 N 18.59 E 619 4 0 618.11 526.11 N ~7 E 1~.~9 N 21.85 E ABOVE INFORMATION FROM SPERRY-SUN GYRO SURVEY NO, .5U0-15507 712 4 30 710,82 618.82 N 50 E 839 5 0 837.3~ 745,34 N 43 E 96~ 5 0 961.86 859e86 N ~4 E 1091 5 0 1088e38 996e38 N 55 E 1120 5 0 1117,27 1025.27 N 40 E 1150 6 15 11~7,09 1055.09 N 28 E 1183 7 15 1179,83 1087.83 N 36 E 1285 7 BO 1280.95 1188.95 N 23 £ 1384 7 15 1379.16 1287,16 N 35 E 19.19 N 27.4~ E 27,28 N 3~.99 E 35,12 N ~2.5~ E 41.47 N 51.63 E 43.40 N 53.25 E 46.29 N 54,78 E 4~.66 N 57,23 E 61,91 N 62,43 E 72,14 N 69,60 E ABOVE INFORMATION FROM SPERRY-SUN SINGLE SHOT SURVEYS 1474 7 30 1468,39 1376.39 N 46 E 1569 8 15 1562.41 1470.~1 N 49 E 1663 9 0 1655,25 1563.25 N 50 E 1758 9 0 1749.08 1657,08 N 55 E 1853 9 0 1842.91 1750.91 N 53 E CLOSURES DISTANCE ANGLE D M S U,O0 5 0 0 0 W 0,00 5 0 0 0 W 0,15 S 75 59 b9 E ~.06 N 7~ 8 46' E 13~16 N 61 30 ~5 E 17e69 N ~0 5 58 E 2i.~ N 58 2~ ~ E 26.23 N 56 26 27 E 3~,~9 N 55 2 25 E 55,18 N bO 28 19 E 66,22 N 51 13 ~i E 68.70 N 50 49 3 E 71.72 N' 4g ~8 21E 75.77 N ~9 D 16 E 87,93 N 45 14 28 E 100.25 N 43 58 18 E DOG LEG SEVERITY ~ECTIUN DEG/tOOFT DISTANCE 0,000 0.00 0.07t 2.702 3.06 1,797 11.59 0,S68 15.78 0.53i 0,588 0.602 4t,99 O.07U 52.70 0,754 62.98 ~.153 72.90 le$51 ~$.00 1.57~ 80.30 N 78,05 E 111.99 N ~ ii * E 1.591 109.94 89,25 N 88.34 E 125.58 N 4~ 42 23 E 0.900 123,~m 98,70 N 99e60 E 140e2~ 107.22 N 111.78 E 116.17 N 123.65 E 169.66 N ~6 ~7 9 E U.329 104.93 1947 9 15 1935,69 1843,69 N 37 E 2042 9 30 2029,39 1937,39 N 39 E 2137 9 30 2123.08 2031,08 N 39 2231 9 45 2215.73 2123,73 N 37 2326 10 30 2309,14 2217,14 N 41 E 2421 11 15 2402,31 2310.31 N 44 2315 1~ 15 2493,81 2~01e81 N a6 2610 14 15 2585.89 2493.89 N 44 2704 14 0 2677,09 2589,09 N 27 2799 14 15 2769,17 2677e17 N 27 E 289% 15 45 2860,60 2768,60 N 2'1 2988 20 30 2948e65 2856e65 N 24 3178 2~ 30 ~123~85 3031.85 N 24 3272 24 30 3209e39 3117e39 N 26 3~67 25 15 3295~31 ~203.31 ~ 28 3461 26 45 3379.25 3287,25 ~I 2~ 3556 27 45 3453,33 3371,33 N 28 3651 28 0 3547,21 3455,21 N 29 3745 28 45 3629,62 3537,62 N 29 3840 28 45 3712e91 3620e91 N 30 3935 2*7 0 3797,55 3705e55 N 30 4029 26 30 3881,68 3789,68 N 30 4124 24 45 3957e95 3875e95 N 32 4219 25 0 4054,05 3962,05 N 33 4313 2~ 15 4139e76 4047,76 ~ 33 4502 24 0 4311.90 4219e90 N 33 4597 2~ 15 4~98e52 4306.52 N 35 4881 18 30 4666,75 457~,'~5 N 38 E 4976 18 0 4757e10 4665,10 N 35 5070 18 0 4846,50 ~7~4.~0 N 34 E 5165 17 45 4936e98 4844e98 N 33 5259 17 15 5026,75 4934.75 N 34 5354 17 0 5117,60 5025e60 N 34 5449 16 ~5 5208e57 5116,57 N 3½ 5543 16 45 5298e58 5206e58 i~ 3~ E 5638 16 15 5389e78 5297e78 N 34 57~3 16 30 5480,87 5388,8'7 N 34 5827 15 45 9571e34 5479e34 N 33 5922 16 0 5~62e06 5570eb6 N 3~ 6016 15 30 5753e24 5661,2~ N 32 6111 16 45 5844,21 5752,21 N 31 E 6206 16 0 5935,53 5843,53 N 31 E 128,24 N 132,74 E 18~57 N 45 59 18 E Z,TJ~ i~O,O0 165e98 N 161.18 E 231,36 N ~ 9 35 5 0e44~ 2Z-Tel~ 179,0~ N 172,5~ E Z~8,65 N 4~ 56 23 E 1,08Z 207,3~ N 200e91E 288,72 N 44 5 50 E 2,175 2~3.53 224,1~ N 217e15 ~ 312,10 N 44 5 24 E 1.16~ 305,50 2~4,43 N 227,48 E 33~,90 N ~2 56 36 E 4,40b 329.11 265e26 N 2~8e10 E 356.45 N 41 54 38 E 0.263 352.35 385e~3 N 293,07 E 484,20 N 37 1~ 55 E 1.579 53Ze66 N 369.8Z E 64~.4~ N 34 ~O l~ E 1.053 571,67 N 391,~4 E 692e84 N 34 2~ 3 E U,558 611e21N ~13,36 E 737,~7 N 3% 4 ~3 ~ W,798 650,78 N 436,21E 783e~ N 33 49 59 ~ 0,50~ 75~.t~ N 499,8d E 90~,11 N 3~ 23 38 E 2,055 9Od,AA 857,59 N 564,37 g 102be64 N 33 20 55 ~ O.5ZO 889e66 N ~85-20 E 1064e~7 N 33 20 l0 E 0,79~ 1064.8-~ W21,o2 N b07,58 E 110~,87 N 33 23 ~1E 0,90~ AlU3,~7 948.55 N 626e44 E 113be74 N 33 26 28 E 4,21t 1021,7~ N 678,32 E 1226.41N 33 3~ 47 E O.bZt 1ZZ6.38 104~.82 N b94,57 E 1255,~ N 33 3~ 22 ~ O,3d9 1070.11N 710e34 E 1284,42 N 33 34 34 [ Ocli7 12d4.39 1093e22 N 725,93 E 1312,29 N ~3 35 7 E 0,~21 131Z.gb 1116,25 N 741,4~ ~ 1340e06 N 33 35 38 E 0e26~ 1138e9~ N 796,77 f 1367,44 N ~3 3b 7 E 0,Z63 . llbl,6b N 771,52 E 139~,53 N 33 35 25 ~ 0.307 1183.70 N 786,39 E 1421,11 ~ 33 '35 52 E 0,60~ 12Ob.O/ N 801,~8 E 14~,10 N 33 3b 19 E 0,d53 l~SB.Ob 1227.47 N $A5.37 E 1473,61N 33 35 42 E 0.85i 1316,65 N '~70,54 E 157~,42 N 33 28 1~ E U,789 15/8,40 6300 15 15 6026,22 9934,22 N 30 E 6395 16 45 5117,19 6025,19 N 32 E 6490 18 0 6207,54 6115,54 N 33 E 6679 18 45 6386,90 6294,90 N 31 E 7097 21 45 6743,37 6651,37 N 29 E 7152 22 15 6831,29 6739,29 N 28 [ 7247 22 15 6919,22 6827,22 N 27 [ 7341 21 30 '7006,68 6914e68 N 28 E 7436 21 0 7095e37 7003e37 N 26 ~ 7442 21 0 7100,97 7008,97 N 26 [ 1338,06 1361.28 1~85.90 140~.98 1~61,66 1514~0~ 597,%1E 975,45 E 991,5U [ 157~,2~ N 102'5,27 1638,72 N 10~7e78 1669032 N 107~,70 1671,25 N 1073,65 160~,10 N ~ 25 5 E 1588,87 N ~ 2~ 52 E 1777.74 N 3~ 1~ ~O [ 1~80,36 ~ 3~ 2 31 E 1950,4~ N 32 50 30 ~ 198~,27 N ~2 4~ 29 E ABOVE INFORMATION FRO~ SPERRY-SUN mULI'ISHOT SURVEYS NO. N$-16518 7508 20 15 7162,89 70'?0,89 N 27 E 7538 19 ~5 7191,13 7099.13 N 27 E 7601 19 0 7250,69 7158,69 N 29 [ 76~8 18 45 7342,55 7250,55 N 28 E 7762 18 30 7403,24 7311,24 N 29 E 782~ 18 ~5 7~61,95 7369.95 N 29 E 7887 18 15 7521,78 7429,78 N 29 E 7951 17 45 7582,73 7490,73 N 27 E 8074 16 15 7700,82 7608.82 N 29 E 82~1 1~ 0 7852,47 7760,47 N 27 E 8356 15 45 7972,78 7880,78 N 32 ~ 8481 15 15 8093.38 8001,~8 N 35 E 8533 14 ~5 81~3,66 80~1,66 N 33 E 8646 13 ~5 8253.~2 81~1,42 N 36 E 8794 11 ~5 8398,32 8306,32 N 39 E 8892 11 15 8~94,44 8402,4~ N 40 ~ 9095 11 15 8693,54 8601,54 N 35 E 9283 12 15 8877,26 8785,26 N 36 ~ 9476 lZ 15 9065086 8973,86 N 36 E 9531 12 30 9119,5~ 90'27056 N 35 E 9610 12 30 9195,69 9101,69 N 37 5 9712 12 30 9296027 9204,27 N 40 E 9885 12 0 9~650~9 9373,49 N ~3 E 10014 10 45 9592.22 9500,22 N 4~ f 10154 8 ~5 9730,60 963~.60 N ~7 E 10276 7 15 9851.62 9759,62 N 4S E 10387 6 1~ 9961.96 9869,96 N ~7 E t691,60 N lO~4.0Z E 2009.1~-N ~2 39 9 E 1700,6~ N 1088,62 f 2019,22 N ~2 37 27 f 171b,5~ N 1098,56 f 20~,59 N ~2 35 15 E 17~6,11N lll~e20 E 2070.18 N ~2 31 8 E 1763,87 N 1123,0~ E 209A,0~ N ~2 29 5 E 1781.30 N 1132.71E 2110.~ H 32 2'~ 5 E 17~8,55 N 1142,27 1815,94 N 1151,13 1846,04 N 1167.82 1882,25 N 1185.2~ 1911,02 N 120~,25 1937,~5 N 1223.10 1~49,06 N 1230,31 1970,79 N 1245,10 2008,8~ N 1277.~6 2041,30 N 1300,07 2073,5~ N 1323,52 2117,02 N 1378e90 2190,34 N 1~20o~ 2204,86 N 1~36,02 2215,5~ N 1~47,09 2223,80 N 1~5,93 2224.~8 N ~2 lJ 1~ E 225~,81N ~2 1~ 2 E 2291,55 N ~2 i5 26 E 2~0~,89 N 32 lb gl E 2~31,6~ N ~2 ~ 1~ E 2301,53 N ~2 2~ 2~ E 2380.58 N 32 27 2 E 2459,95 N 32 32 57 E 2500,~4 N B2 36 2t E 251Z,73 N B2 ~? 1E 25~9,7~ N ~2 38 ~8 E 2551,68 N 32 4Z ~6 E 2587'07 N 32 91 9 E 2610,60 N 32 5/ ~9 E 2631,27 N 33 ~ 33 f 26~6.28 N 33 ~ 2 E 265~,01N 33 12 ~5 E ABOVE INFORMATION FROM SPERRY-SUN.SINGLE SHOT SURVEYS i.270 O,~ZO 17~9e10 0.532 1777.7~ 2,i32 t809,79 0-65~ l~dO-35 0,~ 2090,87 0,40~ 2110.7~ 0,79~ 2i30.~2 1,242 21½9.~2 1,2£~ 2258e45 O,75b 1,3~ 230~.~7 1,100 0,5~9 2380,~ OeOOO 0.~99 2b12.99 0e637 1,0t~ 2010.58 1.449 26~1,28 1,~35 26~6,Z7 0,907 26~.01 BOTTOM~ HOLE' CLOSURE 2658.01 FEET AT N 33 12 46 E MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. TRUE >~EASURED VERTICAL SUB NO-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 192 192. 100, 0 O 292 292. 200. 0 0 392 392. 300. 0 0 493 492. mOO. 1 1 593 592, 500. 1 0 693 692e 600. 1 0 793 792e 700, 1 O 894 892, 800. 2 1 994 992e 900. 2 0 1095 1092e 1000. 3 1195 1192, 1100' 3 0 1296 1292. 1200. 4 1397 1392, 1300, 5 1 1498 1492, 1400. 6 1 1599 1592. 1500. 7 1 1700 1692, 1600. 8 1 1801 1792. 1700, 9 1903 1892e 1800. 11 2 2004 1992. 1900. 12 1 2105 2092, 2000. 13 1 2207 2192e 2100, 15 2 2309 2292, 2200, 17 2 2410 2392. 2300. 18 1 2513 2492. 2400. 21 3 2616 2592. 2500, 2~ 2719 2692, 2600. 27 2823 2792, 2700, 31 292~ 2892. 2800. 36 5 3035 2992, 2900. ~3 7 3143 3092. 3000. 51 8 3253 .~92, 3100. 61 3363 5292, 3200. 71 LO 3475 3392, 3300. 83 12 3988 3~92. 3400. . 96 3702 3592, 3500. 110 14 3816 3692e 3600e t24 3929 3792. 3700e 137 13 ~040 3892. 3800. 148 11 0.0.% S 0.~2 E 0.97 N 3.~+5 E A'~,25 N 20,5Z E 18,2~ N 2b,~l E 2~e38 N 32.29 E 30,72 N 3~,31 E ~6,63 N ~4,72 E ~1.71 N 51,83 g ~1,13 N 57,86 E 82.55 N 80,6~ E 92e2~ N 91,93 E 102,0W N 1OW,37 E 111,31. N 117.2~ E 122.9~ N i28.46 E 135,95 N 138.14 E 1~9,22 N 148,33 E 162,72 N 158.73 ~ 176.65 N 170.~5 E 190.90 N 183.99 E 207,05 N 200,~0 E Z25,52 N 217.85 E 2%7,80 N 229,20 E 271,00 N 2~1.02 E 298e9~ N 25~.~8 E 33~.~1 N 2'70,~1 E 372,77 N 2~7,~ E Wl3,~W N 30'6.69 E ~9~.52 N 352.20 E 545,99 N 377.21 E 59~,1~ N ~03,35 E b40.85 N 430.~7 E 728,~9 N 481.26 E 4261 ~80 4590 4697 4802 4908 501~ 5118 5223 5327 5432 5536 5640 5745 5848 5952 &056 6161 6265 6369 6474 6579 6684. 6790 6895 7002 7110 7218 7325 7432 7539 7645 7750 7856 7961 8065 8168 8272 8376 8480 8583 8685 8788 8890 3992, 3900, 159 4092, 4000, 169 4192, 4100, 179 4292, 4200. 188 4392e 4300, 198 4~92, ~400o 205 4592, ~500, 210 4692e 4600e 216 4792e 4700, 221 4892, 4800, 226 4992, ~900, 231 5092, 5000, 235 5t92, 5100, 240 5292, 5200, 244 5392, 5300, 248 5~92e 5400, 253 5592, 5500, 256 5692, 5600, 260 5792, 5700. 264 5892, 5800, 269 5992, 5900. 273 6092e 6000, 277 6192, 6100, 282 6292, 6200, 287 6392, 6300, '292 6492, 6400, 29~ 6592, 6500, 303 6692, 6600, 310 6792, 6700, 318 6892, 6800, 326 6992e 6900, 7092, 7000, 3~0 7192, 7100. 347 7292, 7200, 353 7392, 7300, 358 7492, 7400. 36~ 7592, 7500, 369 7692, 7600, 373 7792, 7700, 376 7892e 7800, 380 7992, 7900, 384 8092, 8000, 388 8192, 8100, 391 8292, 8200, 393 8392, 8300, 396 8492, 8~00, 398 1 lO 10 9 10 7 5 6 5 5 5 4 5 4 4 -5 ~+ 4 5 5 5 6 5 7 8 8 7 7 7 5 6 5 4 3 3 3 2 767,59 s06,19 882,22 919,21 9%9 .'76 977,46 100~,41 103l,l~ 1058,03 1084,27 1109,76 11~4e81 1160,00 118~,25 1208,70 1256,33 1280,73 1505,9~ 1329,98 135~,85 1381,66 1~08,65 1437,60 1~b5,74 1494.10 1526,5b 1596,38 163~,61 1668,15 1700,90 1790,9~ 1760,58 1789,96 1818,30 1867,81 1891,70 1915,31 19~7,69 1958,6~ 1977,02 199~e19 2008,48 505.92 530,99 580,37 605,89 027,28 64~.7~ 666,19 684,~6 702.50 119,89 737,08 753,98 786,76 ~03,19 818,60 833,95 864,11 878,2~ 96~.1~ 980.00 998.45 10~6.55 1055.06 1072 · 1~ 1088.76 1105.14 1121,22 11~?.51 1166,57 1178,91 11~,17 1207,25 1222,89 1237,17 1264,24 899! 8592. 8500. 399 1 9093 8692. 8600. ~0! 2 9~96 8792, 8700, ~0~ 9298 8892* 8800. ~06 2 9400 8992. 8900. 408 2 9503 9092. 9000. 411 3 9605 9192, 9100. 413 9708 9292. 9200. 416 9810 9392. 9300. 418 2 9912 9492. 9400. 420 2 10014 9592, 9500. 422 2 10115 9692. 9600, 429 1 10216 9792. 9700, 424 202~,75 2041.04 2058,59 2076.16 2093.72 2111.4~ 2129.27 21~6,29 2161.90 2176,88 2190,31 2200,81 2210929 1288,49 1299.90 1312,b4 1338.1b 1350,91 1364.08 1378-29 1392,78 1~0b.99 1~2U,41 INTERPOLATED VALUES FOR EVEN 1000 FEET OF NEASURED DEPTH, TRUF ~EASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL ~OORDINATES 1000 997. 905. 2000 1987. 1895. 3000 2959. 2867, 4000 3855, 3763. 5000 4779, 4687, 6000 5737e 5645, 7000 6690. 65989 8000 7~29, 7537e 9000 5600, ~508. 10000 9578' 9~86, 36,92 N 1)5,40 N 322.42 N 713,25 N 1027-89 N 1267,11 N 1526e01N 1827,9~ N 2026-11N 218~.49 N ~5.13 E 137.7b E 265.02 E ~72.27 E 840,68 E 998,15 E 1157.78 E 1289.~ E 1418,60 E MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 Fk~T OF TRUL VERTICAL DEPTH, TRUE MEASURED VERTICAL MD-TVD VERTICAL DEPTH DEPTH UIFFERENCE CORRECTION TOTAL COORDINATES 100 100. 0 0 200 200. 0 0 300 300. 0 0 400 400, 0 0 501 500' 1 1 601 600. 1 0 701 700, 1 0 802 800. 2 902 900, 2 0 1002 lO00. 2 0 1103 .1100. 3 1 1203 1200, 3 0 1304 1300. 4 1 1405 '1400, 5 1 1506 1500. 6 1 1607' 1600, 7 1 1708 1700, 8 1 1810 1800, 10 2 1911 1900e ll l 2012 2000. 12 1 2114 2100. 14 2 2215 2200, 15 1 2317 2300, 17 2 2419 2400. 19 2 2521 2500, 21 2 2625 2600, 25 2728 2700, 28 2831 2800, 31 2936 2900. 36 5 30~3 3000. 43 7 3152 3100, 52 3262 3200, 62. 10 3372 3300, 72 3.8~ 3~00~ ~ 12 3598 3500, 98 14 3711 3600, 111 13 3825 3700, 125 3938 3800, 138 13 O.OO $ u.uO U.O~ $ 0.13 5.30 N 10.12 9,21 N l~,~Z t~.53 N 20',~ LB,b4 N 2b,~9 2W,~ N 32.7b 37,03 N 45,29 52.10 N ~$,27 63.89 N ~,82 8~.~i N 8lebi 9~.07 N ~2.~0 102e77 N 10~.~1 112,08 N llB,~2 137,0> N 13B,~l 150,2~ N 1~9.17 t77.77 N 171.~ 192,04 N 185.09 227,30 N ZI~,/5 2~9,$1 N 230,12 27~.01N 2~2,0~ 501,b~ N 2~,19 ~37.26' N 271.b~ 37~,95 N 288.8~ 416,62 N ~08,g~ )~9.71 N ~79,27 ~9b.9~ N .0b.~ ~,bb N ~32.~b b89.19 N 458,~8 ~049 ~269 4~79 ~99 ~021 ~126 ~0 56W9 ~753 ~857 6065 6169 6273 6377 6587 6693 6798 6903 70~0 71~8 7226 7334 7~41 75~7 7759 7864 7969 8177 82~0 8488 8591 8694 8796 3900 · 1.49 ~000, 159 10 ~.100, 169 10. 4200, 179 10 4300, 189 10 ~+400e 199 10 4500, 205 6 4600, 211 4700, 216 5 4800. 221 5 4900. 226 5 5000. 231 5100, 236 5 5200e 2~0 4 5300, 244 5400, 249 5500, 253 5600, 257 5700. 261 5800, 265 5900, 269 6000. 273 4 6109, 277 6200, 282 6300, 287 6400, 293 6 6500, 298 6600. 303 6700, 310 7 6800, 318 8 6900, 32,5 8 7000, 334 8 7100e 341 7 7200, 347 6 7300, 353 6 7400, 359 6 7500, 364 5 7600. 369 5 7700e 373 7800, 377 7900e 380 3 8000, 384 8100. 388 8300, 394 3 8400, 396 2 731.6Z 770,72 ~09,Zi 922,06 97~,b2 1033,2~ 10~6.3~ 1111,7~ 1~6,80 1~62,0~ 1ZlOe59 1282,80 1307,91 1331,67 1383,8~ 1~3908b 1~b7093 1529,35 1670=9~ t703=~1 1733,35 176Z,9Z 1820,3~ 1~69,7Z 1939,~2 1978e3J N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N '.507 · 96 532.,96 582,.41 607,89 628,84 b~8 · ~6 686,12 70~,89 755 · ~3 77~ · 76 7~U ~0~ 819,~b 879.~2 930,17 ~6~, W6 981 ,~3 OO0,OO 019,26 05~,54 090, i~ i~ · 19 ~5~,b7 ZZ~05 265,Z~ 8898 8500. 398 2 2009,7b 9000 8600, mOO 2 2026.05 9102 8700° 402 2 2042,43 9204 8800. 404 2 2060.0u 9306 8900. 406 2 2077,56 9409 9000. 409 3 2095,13 9§11 9100, 411 2 2112,90 9613 9200, ~13 2 2130,67 9716 9300, 416 3 2147,~0 9818 9400. %18 2 21~3,14 9920 9500, ~20 2 Z177,9~ 0022 9600e ~22 2 2191~15 0123 9700. 42~ I 2201.~ 0224 9800, 424 1 2210,99 1300.90 1579,~ 1~32.~'! HEASURED DEPTHS FOR EVERY iOOFT DISTANCE OUT{PLANE OF 8OTT~M HOLE CLOSUNE MEASURED DISTANCE DEPTH OUT 1381 100.00 2042 200.00 2560 300.00 2949 400.00 3216 , 500.00 3450 600.00 ~665 70OEO0 3876 80OEO0 4104 900,00 4344 1000,00 4587 1100,00 4890 1200.00 5217 1300,00 5562 1400.00 5922 1500.00 6288 1600.00 6618 1700,00 6933 1800.00 7204 1900.00 7481 2000.00 7789 2100,00 813~ 2200,00 8513 2300,00 8991 2400,00 9472 2500.00 9955 2600.00 -i Leg 1A Pile 5 i ._ .3~QO0 .... ! ! Form REV. 9-30-6? STATE OF ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a difflerent reservoir. Use "APP.LICATION FOI~ PERMIT--" for such proposals.) O,L GAR WELL WELL OTHER 2. NAME OF OPEI~ATOR TEXACO Inc. 3. ADDRESS OF OPERATOR Box 4-1579, .Anchorage, 4. LOCATION. OF WELL Alaska 99503 .~t.ur~=e 2,076' West and 618' South of the Northeast corner of Sec. 34, T10N-R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, OR, etc. K.B. = 92' + M.S.L. 14. ~' TRM 5.APl NUMEH/C~ CODE API 50-133-200200 $. LEASE DESIGNATION' ~D S~REL ADL ~17597 ~. I~ ~I~, ~~ O~ ~B~ -- H~ ......... 8. UNIT, FA/{M OR LEASE NAiVIE State of Alaska 9, WELL NO. TS ~9 10. FIELD A2qD POOL, OR WILDCAT Tradinq Bay NE 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 27, T10N-R13W, 12. PEP~VIIT NO. 69-92 Check Appropriate Box To I,ndi'case Nlature of NOtice, Re ~ort, .or 'Other 'Data SoS. NOTICE OF INTENTION TO: TEST WATER SHUT-OFF t I PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS (Other) eUBeEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASINO ~'J~~AC IDIZ ING ABANDONMEN'T* (Other) NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and ~Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent~ dates, including estimated date of starting any proposed work, On 11-8-69 the subject well was treated with t0'000 gal. of Dowell inhibited Ultra Mud Acid followed by 1,000 gal. diesel and by 3,650 gal. of fresh water. Mechanical difficUlties were experienced and it is possible not all the acid was displaced into the formation. DIVISION OF OIL ~ GAS 16. I hereby c a ue and correct IJ/. s. B~rber (This sp,~[c~/for State office use) TITLE Dis t. SuDerintendent DATE 11/12/69 APPROVED BY CONDITIONS OF APPROVAL, IF ANY: JGC: bw TITLE See l~n:strucfions On Reverse Sid,e Approved Copy Returned DATE KE IT N !",. !~II. 1.£2 , fiO?,/££fifiR ANGgOP~ASE September 9, 1969 Mr. J. S. Barber Di stri ct Superintendent Texaco Incorporated Box 4-1 579 Anchorage~ Alaska 99503 Dear Sir' Re' TS #9 Texaco Inc., Operator FILE In reTe'rei.ce to the subject offshore drill-site the following stipulations are required to protect fish and game resources' l. No material ..... =,n to u:,~ environment will be discharged from this platform. This includes garbage: trash, refuse, petrol.eum and/or its products: drilling mud, and debris. 2. Drilling ~.o.~,ons are not to interfere with commercial fishing. 3. The Habitat Biologist's Office, 1018 West International Airport Road~ Anchorage~ Aiaska~ 99502, will be notified prior to abandonment of this location. Statement~ The foregoing provisions do not relieve the lessee and/or his contractors or assignees of any responsibilities or provisions required by law or regulation of the State of Alaska or the federal governmq'~}t. Robert d. ~?ien~ld Habitat Biologist cc- B. Hilliker H. Burrel 1 P. Denton I:)I¥1$10N OF OE AND G~t,3 DlVlStOR ~ OIL Al~ ~ Texaco Inc., Dlstrt~ ~ ~t579 ~r Sir': '[-~ttltld Is till ~ ~I lctlft~ ~ l~lf ti: drl l I ttle rlrle~ JlJl! .l~lJs ~ c~re ~Ips ~r..~t ~l,r~l. A dl~io.~l ~ is r,~l~. Tt~ 9 ~J/tt". ,~1 lit ViP cJst~ strl~gs ,,st I~ till In vlth elecfrlc Iog~ tepla, lad fluid I'.: ~ ~1:... (2) ~ In ~ ~ ~ a~lfl~l Alaska OII & Gas ;~ti.~ ~1~ ~ of: Labor v/o ~i. DRILLING PROGRAM TEXACO - SUPERIOR TP~ADING BAY STATE WELLS 1. Drill a 12-1/4" hole to 1350' + K.B. (36" Piling driven to + 300' K.B.) 2. Open hole to 17-1/2" and run and cement 13-3/8" casing at 1350'--+. 3. Install 13-5/8", 3000~ Hydril and positive gates. 4. Drill 12-1/4" directional hole to 9-5/8" casing setting depth. 5. Run electric log and other services. 6. Run and cement 9-5/8" casing. 7. Complete.the well in accordance with existing field rules. MUD PROGRAM Depth 0' - 1,350 ' 1,350' - 4,000' 4,000 ' - T.D. weiqht- viscosity water Loss T_k2p_q 70-75 75-100 .... Gel-Water 70-80 40-60 6-10 Ge 1-Water ' 70-80 40-50 4-8 Low Solids FAW: j m 9-3-69 Union Oil Company~f California 2805 Denali Street, r.,,~chorage, Alaska 99503 Telephone (907) 277-1481 Robert T. Anderson District Land Manager union · September 3, 1969 Mr. Homer Burrell Director Division of Oil and Gas 3 001 Porcupine Drive Anchorage, Alaska 99503 ~ -- il iii 1 KLV .... ---.-_ HWK, REt _ FILE _ Re: APPLICATION FOR PERMIT TO DRILL TS ~9 TRADING BAY NE Gentlemen: Union Oil Company of California, as an affected operator pursuant to Section 2060 of the State Oil and Gas Conservation Regulations, has no objection to the sUbject well being drilled as set forth in the referenced Application dated September 3, 1969. RTA/nr Yours very truly, · CC: Claude Brown Texaco Inc. P. O. Box 664 Anchorage, Alaska Form 401 ANC-A (New 7/67) AtlanticRichfieldCompany North Ame~c'~ roducing Division Alaska District Post Office Box 360 Anchorage, Alaska 99501 Telephone 907 277-5637 September 3, 1969 Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska Attention' Mr. Homer Burrell, Director Re' Texaco-Superior Well No. TS-9 North Tradingj. Ba~, Field Gentlemen' This is to formally advise and confirm our telephone conversation of this date that Atlantic Richfield Company has no objections to the location for the subject well which we understand will be located 1600 feet north and 550 feet west from the southeast corner of Section 27, TION, R13W, SM. This well offsets ADL-35431 which lease is owned by ARCO. This is a notice required by Article 2060 of the Oil and Gas Conservation Regulations. Very truly yours, Gordon Dav 1 s Di strict Landman GD'db . cc' Texaco~Inc. P. O. BOx 664 Anchorage, Alaska 99501 Attention- Mr. Claude H. Brown Mr. Paul Norgaard D/Y/S/ON OF 0/[ AND OA~S (Other instructions on ~orm P--1 reverse side) p~-%r. 9-30-~ STATE OF ALASKA OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK l&. TYPE OF WORK DRILL ~ DEEPEN J-'l PLUG BACK [-] APl 50-133-200200 6.LEASE DESIGNATION ~ SER/AL NO. ADL %17597 I. IF INDIAN, A. LLO'C~iE OR TI~LBE NA,M.~ b, TYPE OF WELL WELL WELL OTHER ZONE ZONe. 2. NAME OF OP~TOR TEXACO Inc. 3. ADDR~ ~ OP~R Bo~ 4-1579, ~nchora~e, ~laska 99503 8. UNIT, FARM OR LEASE NAME State of Alaska 9. WELL NO. TS % 9 10. FIELD AND POOL. OR WILDCAT 4. LOCATION OF WELL ^tsurface2076'W and 618'S of the NE corner of Sec. 1600'51' and 550'W of the SE corner of Sec. 13. DISTANCE~N~ ~l~F.~k'~qD' ~II~.EC~!O~q'I~.IOM NEAREST TO~N OR POST OFFICE* 27.3 miles, N21°10' West from Kenai, Alaska 34, 27, Trading Bay NE 11.SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 27, T10N-R13W, S.M. 12. 14. BOND INFORMATION: TYP~tatewide surety and/or NO. B-17 dated January. 18, ,. 1962 -'il6. NO. OF ACRES IN LEASE 550' t 5120 18, DISTANCE FROM PROPOSED LOCATION* 19. PROPOSET) DEPT~ oR APPLIED FoR, ~. 1050' 10,600' 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE. FT. (Also to nearest dr(g, unit, if any) _,~o~: $100,000 l~. NO. ACRES ASSICNED TO THiS WELL 80 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF. RT. CiR. etc.~ 22. APPROX. DATE WORK WILL START* DF. (Kelly Bushing) September 4, 1969 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH QUANTIT! OF CEMEN= ]7-1/2" 13-3/8" 5~.5_~. J ' 1350' 1200 sx. 12-1/4" 9-5/8" 43.5-47~ S-N 10.600' 2300 sx. ,, (See attached copy of Drilling Program) Atlantic Richfield and the Trading Bay Unit are affected operators in accordance with Section 2060 "Deviation" of the Conservation Regulations. They have been furnished a copy of this application by registered mail. RDF: jm IN ABOVE SPACE DESClTIBE PROPOSED PROGRAM: If proposal is to deepen or plug back. give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directlonall¥,, give pertinent data o~ subsur/ace locations and rneasur~[ and true vertical depths. Give blowout preventer program. 24. I hereby certify t~,at Correct ~Ai: S_ ~e. rber ..... ~r ~ ' (Thi~ space ~ S~te office u~) CONDI~ONS OF ~PROV~, IF A~: I SAMPLES AND CORE CHIPS [] YES ~ NO ' DIRECTIONAL SURVEY j :lid Y~s 0 No DATE September 3, 196.9 ~r~.....-Dist. suDerinten~ APPROVED See transmittal letter A.P.L ~CAL CODE 50- I ~3-200200 · ,~PROVm. D.r~ Santamhar 5: 1969 D i rector ~.D. i v i s i on of 0 i I & Gas D,~ .Septem..ber 5, 196,,9 *See Inmuctio., On Revere, Side ,u ? / 6 T,S Company Texaco Inc. ADL 17597 Lease & Well No. TS //9 CHECK LIST FOR NEW WELL PERMITS . ' · .' .~ .- ' ' · ..... Yes No Remarks i 1. Is well to be located in a defined pool. :~' 2. Do statewide rules apply ............... .... }~-4,".'~:']s well located prOPer distance fr°m property line'"',-."; ":'~:':::~ :':;:',: ::.,::':2'~.2 :::::0i:'~'::'~ '::::'",."'. '' ',:'.:~' ':<-.'::.::,:~: :':,~ ' ::. ,~.'-. ~:. '. ~:::., .: :- .-_ ':~ ::- · :.'..-: well to be deviated '. :-' ,'<~: . .'?:::'::,':?:::~::;~:?:'-, operator hav~ '~:'~'6nd in'force.. .'. enough', tocirculate on ConductOr and surfaCe. ~. ,.. ~..~. 11 ~ent t~e in surface:and tnt~m d~ate .or...product~on strings ~-:- :.. ~ :-: .: -.... : ~... -.. , .:. - -.:...= :.:.~ .. . ~::::..16.:" Wtll surface csg. internal burst equal ,5 psi/ft, to next string 17. Will all casing give adequate safety in collapse and tension '. ..... )8. Does BOPE have sufficient pressure rating . . : ' :' ~.... ' .\. ~ ,.- -.-.... -....:..~, . Additional Requirements: Approva~J~l Recommended: " ' TR~ . m ~ 1~ REL KLV OKG UI. IV J ', ) /<~