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CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To: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 & Hemlock-NE Oil, Undefined Gas Pools 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,250'N/A Casing Collapse Structural Conductor Surface 1,130 psi Intermediate Production 4,420 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 10,094' 7,680' 7,541' 2,576 psi 10,045'9-5/8" 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 2-7/8" Daniel E. Marlowe N/A & N/A N/A 10,242' N/A & N/A Tubing Grade:Tubing MD (ft): N/A Perforation Depth TVD (ft): 1,379' 10,242' Perforation Depth MD (ft): 1,379' 300'300' 36" 13-3/8" N Trading Bay Unit SPR-03 6.4# / N-80 TVD Burst 8,829' 8,700 psi Tubing Size: MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0017597 168-065 50-733-20133-00-00Anchorage, AK 99503 Hilcorp Alaska, LLC N/A 300' COMMISSION USE ONLY Authorized Name: 2,730 psi1,364' Other: Suspended Well Renewal Authorized Signature: Operations Manager Katherine O'Connor PRESENT WELL CONDITION SUMMARY Length Size 7,680' 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 12:32:17 -08'00' Dan Marlowe (1267) SFD 9/28/2021 eption RRequired?? Yes Noo Subsequueent Form :COMMISS e :COMMISS m S ep :MIS m RBDMS HEW 10/8/2021 Well Name:North Trading Bay Unit SPR-03 Well Pressures (psi):Tubing 112 Surface Location:618’ FNL, 2068’ FEL, Sec 34, T10N, R13W S.M.IA 133 Permit to Drill:168-065 OA 0 API:50-733-20133-00-00 AOGCC Notified:Yes 8/18/1992 AOGCC Inspection Date:9/6/2021 317-585 AOGCC Inspector:Guy Cook Other Notes: Condition of Wellhead: Comments: Attachments:Photos of wellhead Plat - 1/4 mile radius of wellbore Wellbore Schematic Drilled and completed in November of 1968 with a TD of 10,250’ with 9 5/8” casing run to 10242’ The well was suspended in August of 1992 by pumping 44 bbls cement across the perforations with TOC at 7680’ utilizing coil tubing. Top depth of perforations is 8870 leaving 1190’ of cement above the perforations The well was circulated with 680 bbl inhibited FIW down the tubing to the casing and 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: _____________________________________________________________________________________ Updated By: JLL 11/10/17 SCHEMATIC North Trading Bay Field Well: SPR-03 Last Completed: 06/13/1983 PTD: 168-065 API:50-733-20133-00 PBTD:10,189’TD:10,250’ 9-5/8” RKB to Mudline: 165’ RKB to MLLW: 98’ BF-2 1 3 4 5 6 Stage collar @ 3,252’ 13-3/8” 36” 2 Cement Plug @ 9,210’ G-5 UG-5 H-1,2 H-3 Circulation holes in Tbg 8,805-8,807’ TBG & CSG filled with Inhibited 8.5 ppg FIW TOC @ 7,680’ CTM Circulation holes in Tbg 8,402’- 8,404’ UG-1 UG-2 UG-3 G-2 G-3 G-4 XN CASING DETAIL Size Wt Grade Conn ID Top Btm 36” Surf ~300’ 13-3/8” 54.5# J-55 Butt 12.615” Surf 1,379’ 9-5/8”43.5#, 53.5#N.P.LTC & Butt 8.755” 8.535”Surf 10,242’ TUBING DETAIL 2-7/8” 6.4# N-80 EUE 8rd 2.441” Surf 8,829’ PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD)FT Date Status BF-2 8,870' 8,875' 8,716' 8,721' 5' Jul-79 Isolated UG-1 9,002' 9,022' 8,848' 8,868' 20' Jul-79 Isolated UG-2 9,070' 9,080' 8,916' 8,926' 10' Feb-90 Isolated UG-3 9,152' 9,167' 8,998' 9,013' 15' Jul-79 Isolated JEWELRY DETAIL No Depth (MD) Depth (TVD)ID Item 33’ 33’ 2-7/8” Tubing Hanger 1 304’ 304’ 2.31” Otis Ball Valve Landing Nipple 2 8,442’ 8,290’ Otis DW Tubing Plug 3 8,775’ 8,622’ 2.313” Otis XA Sliding Sleeve 4 8,809’ 8,656’ 3.0” Baker FH Double Grip Hyd Packer Size 51A2 5 8,822’ 8,668’ 2.205” Otis XN Nipple (NoGo) 6 8,828’ 8,674’ 2.437” Baker Shear Out Ball Seat Notes: Fill tag @ 9,183’ CTM 8/1/92 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-03RD 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-03RD Suspended Well Location Map Overview Kenai Tyonek Anchorage HAK Petra Well Symbol Other Oil Dry P&A P&A Oil Suspended Page 3 of 8 .. Suspended Well Inspection �����Report |nspectNo: susGD[210913134233 Date Inspected,: 9/6/2021 |nspector� Guy Cook - Well Name: NTRADING BAY UNIT SPR'O] Permit Number" 1680650 ' Suspension Approval: ' Suspension Date: 8/18/1992 - Location Verified? ILY], |fVerified, How? Other (specify incomments) Offshore? k Type ofInspection: Subsequent ' ' Date AQ5D[Notified: 9/1/2021 Operator Hi|co/pAlaska, LLC Operator Rep-. Tom Buchholz Wellbore Diagram Avail? b� ' Photos Taken? Well Pressures (psi): Tubing: 112 ' Fluid in Cellar? [] |4: 133 - BPV|nuteUed7 OA: ` O ~ VRP|ug(s)Installed? VVeUheadConditiun The wellhead isinfair/poor condition with rust and paint failing off. The valves work as they should and the gauges work as well. Nosigns ofleaking. � OznditionofCellar The cellar is very rusty and is littered with paint chips from the wellheads and surrounding painted surfaces. ^' Surrounding Surface[nn6ilion Rusty and covered in paint chips that have fell off the wellheads and the walls/ceiling. The platform isrusting away with little tonomaintanencetoprevent itfrom happening. Nosigns ofhydrocarbons seen. ,. Comments Location verified byplatform well room map. The wellheads onthe Spurr have no maintanence performed on them to prevent failures regarding integrity of the wellhead or the platform itself. There is no greasing/servicing of the valves planned in the future for any of the wells. | requested the area around the wells and the surrounding area to be cleaned up so the cellar and Oon/ could be seen easier for inspections and for general safety concerns. Supervisor[omments Photo (1). Well Status changed from S|toSuspended bYAOG[CO/18/1g92 ~ ,Jm� ^�77� Tuesday, October l2,Z02l Suspended Well Inspection — NTBU SPR -03 PTD 1680650 AOGCC Inspection # susGDC210913134233 Photo by AOGCC Inspector G. Cook 9/6/2021 2021-0906_Suspend NTBU_SPR-03_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 Box 244027 Anchorage, AK 995244027 3800 Centcrpcml orva November 21, 2019 suite 1400 Anchorage, AK 59Sn- Jeremy M. Price Chair. Commissioner c)(06D 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 Ililcorp 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 2019, 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 Helideck. Pipe Rack, and Crane Pedestal Support to evaluate structural Integrity With the work completed in 2019, 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 Dan Marlowe at 907-283-1329. Sincerely, ��Stan Golis Operations Manager Hilcorp Alaska, LLC RBDMS t" J NOV 2 7 2019 NOV 2 2 2019 Af7GGG 0 Hilcorp Alaska, LLC ICANWX December 5, 2018 1 r Hollis French Chair, Commissioner Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 "VU1 p -C 10 2018 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)�U, Stan Golis Operations Man ger Hilcorp Alaska, LLC RBDAns% ,0'EC 131018 1y ,1", . � /OF THE STAT• Alaska Oil and Gas 470, ofA TAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OFg_ Main: 907.279.1433 ALAS/b"' Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operations Manager H��p a � %(1 ?{ Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: North Trading Bay Field, G-NE and Hemlock-NE Oil Pools, SPR-03 Permit to Drill Number: 168-065 Sundry Number: 317-585 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 kl Chair DATED this is day of December, 2017. R E n s L ✓ Ld . I 5 LT:17 • • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 1 2 2017 APPLICATION FOR SUNDRY APPROVALS qc 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ perations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Suspended Well Renewal 2, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development El . 168-065 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number Anchorage,AK 99503 50-733-20133-00 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 ❑ / North Trading Bay Unit SPR-03 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017597 - Trading Bay/G-NE&Hemlock-NE Oil,Undefined Gas 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): 10,250 ' 10,094 ' 7,680, . 7,541 2,576 psi 7,680 N/A Casing Length Size MD TVD Burst Collapse Structural 267' 36" 300' 300' Conductor Surface Intermediate 1,346' 13-3/8" 1,379' 1,364' 2,730 psi 1,130 psi Production 10,209' 9-5/8" 10,242' 10,045' 8,700 psi 4,420 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 2-7/8" 6.4#/N-80 7,680 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A&N/A N/A&N/A 12.Attachments: Proposal Summary 2 Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development E t Service Cl 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0' 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 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: mquick( hilcorp.Com Q 13-/ 11--/ t Contact Phone: (907)777-8442 Authorized Signature: ... dC,n Date: a. COMMISSION USE ONLY Conditions of approval: Notify Commission s that a representative may witness Sundry Number 3/ 7. 6Y 5 Plug Integrity ❑ BOP Test❑I J Mechanical Integrity Test C) Location Clearance ❑ Other: / ye- 611.' /��W I-.r-o-n.,. ri r -,..v S ` "�' 1" 4.,- sus 54-6 vol,4 ratI, nI r 31, zo2.I Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Fi' Subsequent Form Required: AA u r m !G? "' ' f 7 APPROVED BY t )d S Approved by: (tAaLr-r ,'/ COMMISSIONER THE COMMISSION Date: 6` `,..., , ��\ �43 "iiii4 � 4 7 70..-- /2 -/4t-l7 , o � j Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 13 mon hs from the date of royal. Attachments in Duplicate • • Hilcorp Alaska, LLC 111 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 `,c December 11 2017 RECEI ED DEC 12 2017 Hollis French Chair, Commissioner AOGCC Alaska Oil and Gas Conservation Commission V 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 Spurr 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 Spurr 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 Spurr 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 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, Stan Golis Operations Manager Hilcorp Alaska, LLC • • Well Work Prognosis Hilcorp Alaska,LLCDate: 11/28/2017 Well Name: North Trading Bay Field API Number: 50-733-20133-00 SPR-03 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: 168-065 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: 3,329 psi @ 7,534'TVD 0.442 psi/ft(8.50 ppg)well is loaded with KWF Maximum Expected BHP: 3,329 psi @ 7,534'TVD 0.442 psi/ft(8.50 ppg)well is loaded with KWF Maximum Potential Surface Pressure: **2,576 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) **Alternate Pressure calculation requested—SPR-03 is Suspended with 96 psi SITP and 8.5 ppg Inhibited FIW above TOC at 7,534' TVD. Max Surface Pressures Recorded since Hilcorp took over the facility Tubing 96 psi IA 124 psi OA 2 psi Brief Well Summary: Well SPR-03 a suspended oil well completed in the Tyonek sands. Perforations were isolated with cement in 199 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: 08/02/1992 7,680' 1,500 psi for 30 minutes (Top of cement plug tagged with coil) 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. RIH and add tubing punch holes at±7,675' b. Establish injection down tubing taking returns up the IA 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 Hilcnrp 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 1. Rig up workover rig, casing jacks, or jack-up rig. 2. Circulate hydrocarbon off the well, if present. Work over fluid will be brine and/or drill water. 3. 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). 4. BOP's will be closed as needed to circulate the well. 5. Monitor well to ensure it is static. 6. Unseat hanger and POOH with production tubing. 7. RU E-line and set CIBP @ ±1,500' MD. 8. Pressure test to 1,500 psi and chart for 30 minutes. 9. RIH with ±4' of big hole charges to ±1,490' and shoot holes in IA. 10. 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. 11. 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-03 14SCHEMATIC Last PTD: 168-065 Completed:06/13/1983 Ililcorp Alaska,LLC API: 50-733-20133-00 RKB to Mudline:165' RKB to MLLW:98' CASING DETAIL �. , [l Size Wt Grade Conn ID Top Btm 36" Surf -300' 1.,y. 13-3/8" 54.5# J-55 Butt 12.615" Surf 1,379' '*r.-4.9,; 43.5#, LTC& 8.755" 13-3/8"` 'ta' 9-5/8" 53.5# N.P. Butt 8.535" Surf 10,242' ="'-' TUBING DETAIL a 2-7/8" 6.4# N-80 EUE 8rd 2.441" Surf 8,829' Stage collar ©3,257 TBG&cSG JEWELRY DETAIL filled with Inhibited8.5No Depth Depth ID Item ppgFIW (MD) (TVD) 33' 33' 2-7/8"Tubing Hanger 1 304' 304' 2.31" Otis Ball Valve Landing Nipple 2 8,442' 8,290' Otis DW Tubing Plug 3 8,775' 8,622' 2.313" Otis XA Sliding Sleeve Ta@ 4 8,809' 8,656' 3.0" Baker FH Double Grip Hyd Packer Size 51A2 Circulation . r 7,680' 5 8,822' 8,668' 2.205" Otis XN Nipple(NoGo) holes inTbg ', CIM 6 8,828' 8,674' 2.437" Baker Shear Out Ball Seat 8,402'-8,404' P ' # 2 r s ; =111 ..:":C. 3 arculation at, ,9 k." holes in Tbg r' ".- 8,805-8,807 i 4 '4 '' ' 5 PERFORATION DETAIL ' Top Btm Top m ,. a,. 6 Zone FT Date Status 1l (MD) (MD) (TVD) (ND) $ BF-2 8,870' 8,875' 8,716' 8,721' 5' Jul-79 Isolated # ' '4 ,..-ViUG-1 9,002' 9,022' 8,848' 8,868' 20' Jul-79 Isolated ,90:0,bBF-2 a,' 4.�y. UG-2 9,070' 9,080' 8,916' 8,926' 10' Feb 90 Isolated • - UG1 UG-3 9,152' 9,167' 8,998' 9,013' 15' Jul-79 Isolated Ik " ," /- UG-2 , .4i :'t 'i+rteklz,i; P UG3 Cement Plug @ * r „ .r y; 9,210' w SS r ! UG-5 41,44.. + a G2 Ai 0, S'adv t y;'"?.'q`.^: t. a *``,S'n_;•'• G4 t } `' 1 .t `S . G5 IN , Notes: ' f "t ," H-12 Fill tag @ 9,183'CTM 8/1/92 ,t t;ti- Y H-3 9-5/8" i 7„r t.f. PBTD:10,189' TD:10,250' Updated By:JLL 11/10/17 • Well: TradingSPR-03 Bay Field Proposed Last Completed: FUTURE PTD: 168-065 Hilcorp Alaska,LLC API: 50-733-20133-00 RKB to Mudline:165' RKB to MLLW:98' CASING DETAIL t„ p.i Size Wt Grade Conn ID Top Btm '.* �., , .,i 36" Surf -300' I' i 'X' 13-3/8" 54.5# J-55 Butt 12.615" Surf 1,379' .1 " 43.5#, LTC& 8.755" 3/8" e3t14 9-5/8" N.P. Surf 10,242' ,, _ 53.5# Butt 8.535" �,�. TUBING DETAIL It h 2-7/8" 6.4# N-80 EUE 8rd 2.441" ±1,550' 8,829' Stage collar @ 3,252 TBG&CSG JEWELRY DETAIL filled with Inhibited8.5No Depth Depth ID Item ppgFIW (MD) (TVD) ±185' Top of Cement(must be 10'to 30'below mudline) ±1,490' Casing Perfs ±1,500' CIBP set a minimum of 100'below surface casing shoe . TCS @ ±1,550' Top of E-Line Cut Tubing Circulation 4• • _ 'j 7,680' 2 8,442' 8,290' Otis DW Tubing Plug holes inTbg r,,,41.; v.;* CTM 3 8,775' 8,622' 2.313" Otis XA Sliding Sleeve 8,402'-8,404' i'4 4 8,809' 8,656' 3.0" Baker FH Double Grip Hyd Packer Size 51A2 t a :at; . ',< 2 5 8,822' 8,668' 2.205" Otis XN Nipple(NoGo) '1 6 8,828' 8,674' 2.437" Baker Shear Out Ball Seat i*14 1!1 • i,4 3 Circulation 110, ' `r' holes inTbg '.' �1 8,805-8,807' ±' 4 r a „ ,; • • wticNVNtiti 6' v o ,.. com � > w o � � � a � w al K fi ;21i15.-'.11 N r 0 _N 2 j j a m Z A x T fD ( c° T 9,P. W S f v d n a y m �2 i _ c*N T D_ a =.m m n� =.N f R-7,m .. -d� „, o S = mv g om N j m RI H 'a o m---Dc53 ° RI D m ' Q_v 3Q0 _ zme N dOg1 2 O NNp EyN O n U N 73 5 -1 D — '^ 3 F F 3 N CT m CO ,m os CO CO Ch Ch Ch a cn cn cn—-- 0 e o c.cc;en e O ,,,_......._ N E m N Na N N N N N W2 92 N N N N co N j 0 N N 0 0 0 N ' Z O N O O O N N O O N N O co O N O 6 4 'a_S ;;;z;::;: :;:; ; Oshi N i ;:i;;ii W O O(n CD ha P 3 33 t m k 3 - z s s � . -- 9i W 3 E E , , - 4 1 ,.., n _ 2r $y II = o r I Qs s s F. 9i I 1 I Wi e gyy ,DS 4 2 wm 9 • • Suspended Well Inspection Data Well: SPR-03 Surface Location: 618' FNL, 2068' FEL, Sec 34, T10N, R13W S.M. Permit to Drill: 168-065 API: 50-733-20133-00 AOGCC Inspection Date: 09/05/17 AOGCC Inspector: Mr. Guy Cook Size Pressure (psi) Tubing 2-7/8" 90 Casing 13-3/8" 2 9-5/8" 122 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Drilled and completed in November of 1968 with a TD of 10,250' with 9 5/8" casing run to 10242'. • The well was suspended in August of 1992 by pumping 44 bbls cement across the perforations with TOC at 7680' utilizing coil tubing. Top depth of perforations is 8870 leaving 1190' of cement above the perforations • The well was circulated with 680 bbl inhibited FIW down the tubing to the casing and 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 • Follow Up Actions Needed: Cap any open valves, tubing (Completed) • No SSV. Attachments: • Current Well Schematic • Picture(s) • Plat- 1/4mile radius of wellbore 11111 3 - RD 10 )1 j }� 4.A 1lf ' r 1111 1J14 r y 111" MB1 Nit 3 1111 S-01 RD S-01 SPR-01 S-08 SPR-01 PB • SPR-03RD f SPR-03PB , S-02 S-02RD S-02DPN f,d 1 t SPR-08 S-05 SPR-06PB SPR-06 S-07 •;Do FEE. N Trading Bay Field S-07RD Scale: Interpreter: 1"=500' M.Frankforter Date: Projection: 09/04/2015 NAD27 Alaska State Plane 4 : 1.•OF Tit, • y*yp\11/7; s. THE STATE Alaska Oil and Gas ", te, of1LA ( 1 Conservation Commission " - -=A k t- 2_:_ .- 333 West Seventh Avenue i17 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OA''ALA �� Fax: 907.276.7542 www.aogcc.alaska.gov October 25, 2017 Stan W. Golis Operations Manager �Q1� Hilcorp Alaska, LLC ® � .0 1 3800 Centerpoint Drive, Ste 1400N�� 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 NTBU 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 Spurr 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, darC- -- Hollis S. French Chair, Commissioner RBBIV3S Lk- IA,i /L 6 2317 • • 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. gp`f { • • RECEIVED STATE OF ALASKA OCT 0 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,A, 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate El Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Sus._•ded Well Renewal 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill P'umber: Hilcorp Alaska,LLC Exploratory ❑ Development 0 168-065 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic El Service EI 6.API Num.-r: Anchorage,AK 99503 50-733- '133-00 7.If perforating: 8.Well Name a d 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 Tr.•ing Bay Unit SPR-03 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017597 Trading Bay/G-NE&Hemlock-NE Oil,Undefine• as 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): 10,250 10,094 7,680 7,541 0 psi 7,680 N/A Casing Length Size MD TV y Burst Collapse Structural 267' 36" 300' .00' Conductor Surface Intermediate 1,346' 13-3/8" 1,379' .`1,364' 2,730 psi 1,130 psi Production 10,209' 9-5/8" 10,242' .? 10,045' 8,700 psi 4,420 psi Liner �l Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: bing Grade: Tubing MD(ft): N/A N/A 2-7/8" c ..4#/N-80 7,680 Packers and SSSV Type: / - kers .111111P11 MD(ft)and TVD(ft): N/A&N/A </ /A&N/A 12.Attachments: Proposal Summary ❑ Wellbor6schematic El '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work. Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the p,.cedure 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: 56.w,. (.•. ' Date: "0(5 14 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number, 3i7 4/7D Plug Integrity ❑ BOr Test❑ Mechanical Integrity Test El Location Clearance ❑ Other: Post Initial Injection MIT --q'd? Yes ❑ No ❑ RBDWIS Lk-- VL i L. 0 L01 Spacing Exception Re..red? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: �� GJJ'mAaL Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for n f doval. Attachments in Duplicate • • Suspended Well Inspection Data Well: SPR-03 Surface Location: 618' FNL, 2068' FEL, Sec 34, T10N, R13W S.M. Permit to Drill: 168-065 API: 50-733-20133-00 AOGCC Inspection Date: 09/05/17 AOGCC Inspector: Mr. Guy Cook Size Pressure (psi) Tubing 2-7/8" 90 Casing 13-3/8" 2 9-5/8" 122 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Drilled and completed in November of 1968 with a TD of 10,250' with 9 5/8" casing run to 10242'. • The well was suspended in August of 1992 by pumping 44 bbls cement across the perforations with TOC at 7680' utilizing coil tubing. Top depth of perforations is 8870 leaving 1190' of cement above the perforations • The well was circulated with 680 bbl inhibited FIW down the tubing to the casing and 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 • Follow Up Actions Needed: Cap any open valves, tubing (Completed) • No SSV. Attachments: • Current Well Schematic • Picture(s) • Plat- 1/4mile radius of wellbore • • 1 NURTH TRADING BAY UNIT SPURR PLATFORM VELL T/S-3 WELL SECURING COMPLETED 8/92 _Completed 6/13/83 AU measurements ore RKB to top of equipment 33' 2-7/8' Tbg Hngr 304' Otis Batt Valve Landing Nipple (2.31' 1.D.) Comoleticn String. 0'-8829' 2-7/8' 6.41, N-80 CUE Brd Butt. Tbg. L 1379' 13-3/8', 34.51, J-35 Csg 3 _ TBG a CSG FILLED WITH INHIBITED 8.5 ppg FIV 10,242' 9-5/8', 43.5 I. 53.51 K P, LTC and Butt Csg TOC P 7,680• TM fff 8442' Otis DV Tbg plug. CIRC. HOLES IN TBG. 8 8775' Otis XA Sliding Sleeve (2.313' ID). $402.5'-8,404' T / 8809' Baker FH Double Grip Hyd Pkr size 51A2 AI (3.0' ID). 8622' Otis XN P4ppte (NoGO 2.205' ID). A CIRC. HOLES ' 8828' Baker Shear-out Ball Seat (2.437' ID). IN TBG P 8805.5'-8807' "'— �'�� �� PERE'MATIONS Ill, BF-2 8870'-8875' 4 SPF 0' Phasing 7/79 UG-1 9002'-9022' BF-2 UG-2 9070'-9080' 2/90 UG-3 9152'-9167' 7/79 UG-1 UG-2 ZTagged fat 8 9,183' CTM 8-1-92 9210' Cement Plug 10/79 UG-5 0 G-2 0 G-3 0 G-4 W G-5 Q H-1,2 Revision Date, 9/8/92 ...... H-3 Revised By' JDM/evo IPBD e 10.189' Reason Vett Seciring / �_s,. TD 8 10250' Previous Revision 4/14/92 111.1111:'' ivt# , I 4 / a ,/ 4 • J. 44. r aerie ; r EINSI • 7,c - • 0 S-01 RD 0 S-01 SPR-01 il • ....___ S-08 ••3,3! SPR-01PB • - .° / SPR-03RD / I SPR-03PB 4 —464:i ••!.:: S-02 / -0- •:4!.!, S-02RD . S-02DPN * SPR-08 • S-05 •:1:..7, Z.\ ••fh: SPR-06PB 0 SPR-06 0 S-07 rV...........LiTm i;30 -(7)-- FEET N Trading Bay Field S-07RD Scale: Interpreter: 1"=500' M.Frankforter 0 Date: Projection: 09/04/2015 NAD27 Alaska State Plane 4 OF T�� • • c",\ \I%% s,. THE STATE Alaska Oil and Gas ti�►���� ®f /` SKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 1110X-Tj'�.. Main: 907.279.1433 ®FALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Trudi Hallett Operations Engineer Hilcorp Alaska, LLC SC,t. NEC tN x 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Trading Bay Field, G-NE and Hemlock-NE Oil Pools,Undefined Gas Pools NTBU SPR-03 Permit to Drill Number: 168-065 Sundry Number: 315-603 Dear Ms. Hallett: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster , Chair DATED this 1'"`day of January, 2016. • r RECEIVED SEP 2 5 2015 STATE OF ALASKA 0725 t, 7 114 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC; APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown El Suspend❑ 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: 5.Permit to Drill Number: Hilcorp Alaska,LLC - Exploratory ❑ Development 0 . 168-065 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic Cl Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20133-00 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-03 (1, SSC. rr 9.Property Designation(Lease Number): 10. Field/Pool(s). ADL0017597 ' Trading Bay/G-NE&Hemlock-NE Oil,Undefined Gas 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): 10,250 ' 10,094 7,680 7,541 7,680 N/A Casing Length Size MD TVD Burst Collapse Structural 267' 36" 300' 300' Conductor Surface Intermediate 1,346' 13-3/8" 1,379' 1,364' 2,730 psi 1,130 psi Production 10,209' 9-5/8" 10,242' 10,045' 8,700 psi 4,420 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): N/A N/A 2-7/8" 6.4#/N-80 7,680 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: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ nvelopment 0 - Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSF❑ Suspended 0 ' 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOLI SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Trudi Hallett Email thallett@hilcorp.com Printed Name Trudi Trudi allett Title Operations Engineer 1A5-/Signature '� 1 t ," Phone (907)777-8323 Date 5 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -2)16_ O Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: A StAsptivi Sli.c..IIAs Lic,kei uyvh-96vmmle7 .2) IA? . s,,,,6,,0 '‘ .\tO OD tik Spacing Exception Required? Yes El No WI/ Subsequent Form Required: © rooks, r1/4.)ell.147 . APPROVED BY / Approved by: PI ' 44 j _f, COMMISSIONER THE COMMISSION Date: — 7 /So / ORIGINAL 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-03 Surface Location: 618' FNL, 2068' FEL, Sec 34, T10N, R13W S.M. Permit to Drill: 168-065 API: 50-733-20133-00 AOGCC Inspection Date: 9/19/15 AOGCC Inspector: Matt Herrera Size Pressure (psi) Tubing 87 Casing IA 140 OA/OOA 2/N/A *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Drilled and completed in November of 1968 with a TD of 10,250' with 9 5/8" casing run to 10242'. • The well was suspended in August of 1992 by pumping 44 bbls cement across the perforations with TOC at 7680' utilizing coil tubing. Top depth of perforations is 8870 leaving 1190' of cement above the perforations • The well was circulated with 680 bbl inhibited FIW down the tubing to the casing and 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 • • NURTH TRADING BAY UNIT SPURR PLATFORM WELL T/S-3 WELL SECURING COMPLETED 8/92 Comaleted 6/13/83 Alt measurements are RI(8 to top of equipment 33' 2-7/8' Tbg Hngr 304' Utis Ball Valve Landing Nipple (2.31' 1.D.) Connletnnn Strings 0'-8829' 2-7/8. 6.411, N-80 EUE 8rd Butt. Tbg. G 1379' 13-3/8', 54.51, J-55 Csg TBG i CSG FILLED WITH INHIBITED 8.3 ppg FIW (nr ! 7�, I0.242' 9-5/8', 43.5 R 53.51 N. P, LTC and Butt Csg j��-�''` � 8442' Otas DV Tbg plus. ell HOLES IN TBG. ! • 8775' Otis XA Sliding Sleeve (2.313' ID). 8.402.5'-8,404' 8809' Baker FH Double Grip Hyd Pkr size 51A2 (3A' ID). 8822' Otis XN Nipple (NoGo 2205' ID). CIRC. HIZES jr. + . 8828' Baker Sheor-out Ball Seat (2.437' ID). 1N TBG ! 8805.5'-8807' f AAV PERFORATIONS DU BF-2 8870'-8873' 4 SPF 0• Phasing 7/79 UG-1 9002'-9022' BF-2 UG-2 9070'-9080• 2/90 UG-3 9152'-9167' • 7/79 UG-I UG-2 Togged FM ! 9183' CTM 6-1-92 9210' Cement Plug 10/79 _r..� UG-5 ^rte a G-2 Q G-3 0 G-4 W G-5 Q H-1,2 Revision Date' 9/8/92 ~-® H-3 Revised By' JDM/evo LTDBD ! 10. a� Reason, wen Securing Previous Revision, 4/14/92 h 44„. ., gay k , a }„ *^ r CD.. • 1, : ; , ' 1 Cn--`— wa. 4, _. OD .�(!... 3 i " 4 V K } ', . ,. : . .. ' 114 ie. 0 ' ..40,:tr...,-:,,,...:,,...:,...i.,..„...„:„ 'i2-4' A -' ''',.. ''' 14,-'' '., _,., , syr V ' air ,. �. - a • . yam,' -14 y ,..... 9. . , . 'S. ,... . , , 4 ' I " '. , 1. tov .„-,:- ...,..., #.',:: " -,' ' •', .''.."7 Vit° r. a.. t 3 ... ai.ys v 0 ,a it, ' .,•t w " g fi§ ,,,i. c., .. , ...... . . oh. . .1*4 ' ,.., . .t.lik.. . .. . .,"' ' a ry s� .., :, .. • ilic , ., iilb,„..,. .. .. . , ... , ,, . . . ,..7,,,,,..% .„. . . ..,........aik \t4A �, r 5 ‘4-111 aNt » V S +t rPs .. E „ --ar :n ?` x 1�� y 4 • • S-01 RD S-01 SPR-01 • • S-08 SPR-01 PB _} SPR-03RD :-: SPR-03PB S-02 972 S-02 RD S-02 DPN SPR-08 • S-05 SPR-06PB SPR-06 S-07 N Trading Bay Field S-07RD Scale: Interpreter: 1"=500' M.Frankforter • Date: Projection: 09/04/2015 NAD27 Alaska State Plane 4 . • S 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-03 Oper.Rep: Paul Taylor PTD No.: 168065 Oper.Phone: 907-776-6640 Location Verified? Yes Oper.Email: ptavlorc hilcoro.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 87-PSI Photos Taken? Yes IA 140-PSI OA/OOA 2/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-03Form • • Bettis, Patricia K (DOA) T- /6S - 0C4 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, • • 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 • • 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) Prn lig 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.bettis@alaska.gov. 1 • • Bettis, Patricia K (DOA) ; /Cgo 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: "Truth 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-03 Oper.Rep: Paul Taylor PTD No.: 1680650 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.: 192-109 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 87 Photos Taken? Yes IA 140 OA 2 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: Insp.Supry )7 f Z >j i' Comm SCONE° SEP 0 7 2.016 PLB 12/2014 2015-0919_Suspend_NTBU_SPR-03_mh.xlsx • • Suspended Well Inspection—NTBU SPR-03 (Spurr Platform) PTD 1680650 Photos by AOGCC Inspector M. Herrera x imaistall. .. * ' ' -A 44,-"."0, , iii . ,,._,,,„,„.,... ,... _ ,,,,.. ...,, ,,..,. . • : ,, 1 A..., , . - ,-- , -,14., , ,,, iiitt....i... ; I - , . - ,.,..„ . is . , .. . , ,,, _ ,..,,, 7 S . : t ..4, by # #t„.„.#.. . • .,„,..„. :. . ctt � I " �' it" 0 t. . f £ 1 .' ° •- x .a'� ,,,by 1 111 f —"`h i1* • b + r^. ,:,...ti :x ^y 7 + '" i .A. o k c/....-', gip ,, 2015/05/ 19 10 : 05 t 41,, ,A/11111111k 2015-0919_Suspend_NTBU_S PR-03_mh.docx Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, July 23, 2012 10:42 AM To: 'Vicente, Tara' Cc: Miller, Susan B. (MRO) Subject: RE: Marathon Spurr well question rage 1 of i 14 o (�O 5 0 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 -03 Oper. Rep: Skiba /Baldwin PTD No.: 168 -065 Oper. Phone: 907 - 283 -1371 Location Verified? No Oper. Email: kskibaa.marathonoil.com If Verified, How? Onshore / Offshore: Offshore Suspension Date: 08/18/92 Date AOGCC Notified: 10/05/10 Sundry No.: 92 -109 - Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 55 Photos Taken? Yes IA 105 OA 2 „ *q^ 0 rt E 201'; Condition of mie," Wellhead: No gate valve on OA - Condition of Surrounding Surface Wellroom secure Location: Follow Up Actions None Needed: Attachments: Photos (2) REVIEWED BY: Insp. Supry (� 1z41 Comm PLB 09/2010 2010 -1020 Suspend_NTBU_SPR- 03_Ig.xls it * T a t i � . : t t G.° ' ' ' 1.. ■D . k.. , y 1f � C n t ' A . oliCedifill . - . ,. :,,I . 0 ii # i • A. 0 li. . ' i: ;4: b ' • .. s ti ' ' 1 Y'-'1111 Nk . x { n . • i t � ' - , e , w z. %. +a 4 y w i • 41 i ' 1 ao.'"''''''''' . al � " ` • } e t 11,,i;iiiiiiiii ' aa lor . t- o , * ......,--- ,,. ., i '.0 0 • .... - , Olt • , • ' i ........ .... • - ... , .... . ... . _..... , --"O 1 ,0 1 . 1 " . .. . f V ACt - • „ - , , to . , .. i - . . I . ... ........). . . . . - 4 • • ........ , ...• 4 - . r - ___,........ , • ..,,,,,, _,.. ... ' .. . J , , . • 4.. a ..■ 40.0 44.* 'I?'" , .„..„,._ ir# . ... -.4 ' )1^-" '7 ; Co — 62 — 01 1;19 , pt cil , - ,-o-s YIRN ` i Maraon Alaska Production LLC Alaska Asset Team M Marathon P.O. Box 1949 Alaska Production LLC Kenai, AK 99611 MARATHON ® Telephone 907/283 -1371 Fax 907/283 -1350 December 20, 2010 WOOED JAN 1 6 Z ` RECEIVED Mr. Winton Aubert DEC 7 2010 Alaska Oil & Gas Conservation Commission 333 W 7 Ave Alaska Oli & Gas COM. Commi8408 Anchorage, Alaska 99501 Anchorage Reference: 10 -404 Report of Sundry Well Operations 0 W Field: North Trading Bay Well: North Trading Bay Unit SPR -03 Dear Mr. Aubert: I Attached for your records is the10 -404 Report of Sundry Well Operations for SPR -3 well. This sundry documents the suspended well inspection performed on October 20, 2010.' SPR -3's casing pressures are tracked on a monthly bases. This data is used to mo • • • r the plug and wellbore int dt . Presently, the SPR -3 casing pressures range fro 2 .si on the outer annulus to 05 si 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 -3 in the 2012 / 2013 time frame. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, a 3 ..QAP S s %-.5 Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File Well Pictures KJS '/ Mile Radius Well Plate ., ®tee � �.R.d STATE OF ALASKA DEC 2 7 201Q, f 2 0 ALASKA" AND GAS CONSERVATION COMMISSIIII u, „n Commission REPORT OF SUNDRY WELL OPERATIONS 4r,lvr0 1. Operations Abandon U Repair Well U Plug Perforations U Stimulate U 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 0 Exploratory a 168 -065 3. Address: PO Box 1949 Stratigraphic ❑ Service ❑ 6. API Number: Kenai Alaska, 99611 -1949 - 50- 733 - 20133 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL- 0017597 - North Trading Bay Unit SPR -03 9. Field /Pool(s): Trading Bay / G -NE & Hemlock -NE Oil, Undefined Gas 10. Present Well Condition Summary: Total Depth measured 10,250' feet Plugs measured 7,534' feet true vertical 10,094' feet Junk measured NA feet Effective Depth measured 7,680' feet Packer measured 8,809' feet true vertical 7,534' feet true vertical 8,655' feet Casing Length Size MD TVD Burst Collapse Structural 268' 36” 300' 300' Conductor Surface Intermediate 1,347' 13 -3/8" 1,379' / 1,363' 2,730 psi 1,130 psi Production 10,210' 9 -5/8" 10,242' 10,046' 8700, 9440, 10900 4420, 5300, 7950 Liner Perforation depth: Measured depth: Plugged feet / True Vertical depth: Plugged feet Tubing (size, grade, MD & TVD): 2 - 7/8" N - 8,829' MD 8,675' TVD SSSV: NA NA MD NA TVD Packers and SSSV (type, MD & TVD): Packers: Baker FH 51A2 Hyd / 8,809' MD 8,655' TVD 11. Stimulation or cement squeeze summary: Suspended well intial 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 = 55 psi } / - Inner annulus = 105 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 0 105 55 Subsequent to operation: 0 0 0 105 55 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development 0 -- Service ❑ Stratigraphic ❑ Daily Report of Well Operations 15. WeII Status after work: Oil ❑ Gas Li WDSPL GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 12 - 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 (<1 1 ( 1_, ,,,......6 kilite Phone (907) 283 - 1371 Date December 20, 2010 HBDMS DEC 2 - 7 1 lw Form 10 -404 Revised 10/2010 Submit Original Only c i . a ,.. ., ,. ,..., 1» : �' x. £ :. ' -, t *. .,... ,,,,„,.., . „.,, rS k } - ,... ,.„....,..,.,....... ,..., Ok y n ., 1 1 • „ •t 1161,... rs.3 — ' 4 ' ', "4041111111W 1 `"w . r. n _ ' mini r. ; ; ` 1 1111, r ' , - ...,%74 .1i' Ili ' kr ,J .., ,....,.. ... ,,„, ,..,_.....,,,, :„,...,..,,,, ^ ' ! t / - t s r ww., ��. � . � 4 '. , 0 - iiipip, t ..., 0 4,44ir l if', 2 ti / r al e I • $ f 1 s i q i • c MARATHON OIL COMPANY NORTH TRADING BAY UNIT • SPURR PLATFORM WELL T /S -3 WELL SECURING COMPLETED 8/92 Completed 6/13/83 Alt measurements are RKB to top of equipment 33' 2 -7/8' Tbg lingr 304 Otis Ball Valve Landing Nppte (2.31 1.11.) Ccndetion Straux 0' -8829' 2 -7/8' 6.41, N -80 EUE 8rd Butt. Tbg. 4 1379' 13-3/8', 54.51, J -55 Csg. _ TBG i CSG FILLED WITH INHIBITED 83 ppg Flw 10.242' 9 -5/8', 43.5 1. 53.51 M. P, LTC and Butt Csg TON ! 7 CTM (///' 8442' Otis DV Tbg plop. CIRC. HOLES IN TBG. ! 8775' Otis XA Stlatng Sleeve (2.313' ID). 8.4023' -8.404' I 8809' Baker FH Double Grip Hyd Pkr size 3112 (3.0' ID). / 8822' Otis XN tipple (NOGo 2205' ID). 8828' Baker Sl+tor -out Batt Seat (2.437' ID). CIRC. HOLES 1�� IN TBG ! 8803.5' -8807• •--' �� erSEOLDURISAIL BF-2 8870' -8873' 4 SPF 0' Phasing 7/79 /// UG -I 9002' -9022' • BF - 1 UG -2 9070' -9080' 2/90 116-3 9152' -9167' 7/79 U6 UG -2 /// Tagged fat 8 9183' CTM 8 -1 -92 9210' Cement Plug 10/79 .....Q G -2 " co G -3 0 G -4 E G -5 Q "2 Revision Doty 9/8/92 ......0 H -3 Revised Bye JON/evo IPBD 8 10.189' Reasons vent Secereng G , TD ! 10.250' Previous Revision, 4/14/92 II NURR PLATFORM • NORTH TRADING BAY UNIT S -4 28 27 26 S -09PB SPURR PLATFORM TS-9 s -3 2 T SURFACE LOCATION ::: MILE RADIUS S -1 RD TS -1 s A - TS -1 Pi 3 9 1: -- J-`e3 s2 TS-5-D2 {{� � / S -02DPN S -2R D S -8 s - p TS -7 ' 33 4 -6 35 • ` S-7 TS-4 °S -7RD II( i S -9 TS -2 ,% T10N -R13W ��` '''''rr\''- T9 N -R13W Q 3 4 A0 -q CS MARATHON ALASKA PRODUCTION LLC 1:12000 0 1 KILOMETRES SPURR PLATFORM 0 0.50 NORTH TRADING BAY UNIT L J l I 1 MILES COOK INLET NAD27 / Alaska zone 4 (EPSG 26734) ALASKA Transverse Mercator Clarke 1866 spheroid September 2010 Natural origin: [ 150 00 OOW, 54 00 OON] Alaska CS27 zone 4 �! Marathon MARATHON ® Alaska Production LLC August 3, 2009 Cathy Foerster State of Alaska Alaska Oil and Gas Conservation Commission 333 W. 7°i Avenue, Suite 100 Anchorage, AK 99501-3539 Alaska Asset Team P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565-3076 F Re: 20 AAC 25.300 (Request for Information) — Status of Oil and Gas Wells Dear Ms. Foerster: 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 lbele at (907) 565-3042. Sincerely, (il 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 %ANNEU Marathon Oil Company, Alaska Asset Team Anticipated schedule of well abandonment activities Confidential 8/3/2009 Timing [Well 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 44-30 168-071 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 WF1-21 rd 193-183 West Fork WF2-21 192-010 West Fork Q Marathon Oil Company March 1, 2009 Commissioner: Cathy Foerster Alaska Gii and Gas Conservation Commission 333 W. 7`h Avenue Suite 100 Anchorage, AK 99501-3539 � (_A.._ -s —ac&.15_ 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: ; [ "IED MAR �, 2 2009 AJA,-*F pie d gee Cons. Cot �is� t t �r�clSor�I�o Marathon received your letter dated January 28, 2009 (Cert # 7005 1820 0001 2499 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, r Ben Schoffmann Operations Manager MARATHON OIL COMPANY SARAH PALIN, GOVERNOR IF, 0 MASSA OiL AND GAS %/ 333 W 71h AVENUE, SUITE 100 CONSERVATION COMUSSION I ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 28, 2009 FAX (907) 276-7 54 2 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 5999 Ben Schoffman Marathon Oil Company PO Box 196168 S( 0 0 0 i`l Anchorage AK 99519-6168 Re: Notice of Revised Suspended Wells Regulations 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 U.S. Postal Service - CERTIFIED MAIL,,. RECEIPT (Domestic Mail Only; No Insurance Coverage Provided) For delivery information visit our website at www.usps.com r 1+ ti ' • 1 tv TOW P°F Ben Scho?furan o Marathon Oil Company r® SAM.:" PO Box 196168 or ro so Na Anchorage AK 99519-616 K 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. IlE Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: Ben Schoffinan Marathon Oil Company PO Box 196168 Anchorage AK 99519-6168 A. X Agent B. Received by (Pnh d Name) C. Da of Deliv ry -P "L'I 49 -VP -Ll 0 D. Is deliv address different from item 1? ❑Yes If YES, enter delivery address below: ❑ No rvice Type Certified Mail Express Mail ❑ Registered Return Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) 0 Yes 2. Article Number (Transfer from service label) 7005 1820 0001 2499 5999 PS Form 3811, February 2004 Domestic Return Receipt 02595-02-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 11-1 SUSP 4/15/2004 520 FSL 1340 FWL Sec 28 T 3 N R 12 W SM ADL0384529 ADL0384534 KENAI C.L.U. 206-121-0 50-133-20563-00-00 CANNERY LOOP UNIT 12 SUSP 9/8/2006 2490 FSL 2365 FWL Sec 4 T 5 N R 11 W SM ADL0324602 ADL0359153 ADL0365454 FEE-TR119 NINILCHIK 208-023-0 50-133-20574-00-00 NINILCHIK UNIT G OSKOLKOFF 7 SUSP 6/12/2008 2969 FSL 3023 FEL Sec 23 T 1 N R 13 W SM ADL0389180 STERLING 161-014-0 50-133-10012-00-00 STERLING UNIT 23-15 SUSP 10/23/1966 2715 FNL 1520 FWL Sec 15 T 5N R IOW SM FEDA028135 TRADING BAY 174-005-0 50-733-20158-01-00 N TRADING BAY UNIT S-01 RD SI 1/25/1992 2608 FSL 2495 FEL Sec 26 T ION R 13 W SM ADL0035431 169-011-0 50-733-20175-00-00 N TRADING BAY UNIT S-03 SI 2/25/1992 2613 FSL 2495 FEL Sec 26 T ION R 13 W SM ADL0035431 169-096-0 50-733-20197-01-00 N TRADING BAY UNIT S-07RD SI 2/25/1992 2612 FSL 2488 FEL Sec 26 T ION R 13 W SM ADL0018776 171-033-0 50-733-20233-00-00 N TRADING BAY UNIT S-08 SI 1/25/1992 2577 FSL 2566 FEL Sec 26 T ION R 13W SM ADL0017597 174-027-0 50-733-20265-00-00 N TRADING BAY UNIT S-09 SI 1/25/1992 2570 FSL 2563 FEL Sec 26 T ION R 13 W SM ADL0017597 168-048-0 50-733-20120-00-00 N TRADING BAY UNIT SPR-01 SUSP 8/18/1992 615 FNL 2072 FEL Sec 34 T ION R 13W SM ADL0017597 168-050-0 50-733-20122-00-00 N TRADING BAY UNIT SPR-02 SUSP 8/19/1992 664 FNL 2007 FEL Sec 34 T ION R 13 W SM ADL0017597 168-065-0 50-733-20133-00-00 N TRADING BAY UNIT SPR-03 SUSP 8/18/1992 618 FNL 2068 FEL Sec 34 T ION R 13 W SM ADL0017597 168-066-0 50-733-20134-00-00 N TRADING BAY UNIT SPR-04 SUSP 8/13/1992 666 FNL 2003 FEL Sec 34 T ION R 13W SM ADL0017597 168-090-0 50-733-20153-00-00 N TRADING BAY UNIT SPR-06 SUSP 8/10/1992 642 FNL 2072 FEL Sec 34 T ION R 13W SM ADL0017597 169-026-0 50-733-20181-00-00 N TRADING BAY UNIT SPR-07 SI 8/26/1992 622 FNL 2068 FEL Sec 34 T ION R 13 W SM ADL0017597 169-027-0 50-733-20182-00-00 N TRADING BAY UNIT SPR-08 SUSP 8/26/1992 664 FNL 2000 FEL Sec 34 T ION R 13 W SM ADL0017597 169-092-0 50-733-20200-00-00 N TRADING BAY UNIT SPR-09 SUSP 8/18/1992 618 FNL 2076 FEL Sec 34 T ION R 13W SM ADL0017597 Wednesday, January 14, 2009 STATE OF ALASKA ~,.:m->~' ALASKA OIL AND GAS CONSERVATION COM MISSION REPORT OF SUNDRY WELL OPERATIO I IG I /l 1. Operations performed: Operation shutdowr~~ Stimulate__ Plugging Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator / 5. Type of Well: Development X Marathon 0i ] Company i ExploratoryZ 3. Address Stratigraphic __ P.O. Box 190168 Anchorage, AK 9951 Serv~oe__ 4. Location of well at surface Leg lA, Spurt Platform 618' FNL, 2,068' FEL Sec. 34-10N-13W-SM At top of productive interval ' 516' FNL, 635' FEL, Sec. 34-10N-13W-SM At effective depth At total depth 557' FNL, 560' FEL, Sec. 34-10N-13W-SM 12. Present well condition summary Total depth: measured 10,250 ' feet true vertical 10,094 ' feet Effective depth: measured 9 210 ' feet true vertical ' feet 9,056' Plugs (measured) Junk (measured) Pedorate __ Other ~ -- 6. Datum elevation (DF or KB) g2' KB above MSL 7. Unit or Property name North Tradin,q Bay Unit 8. Well number T~:_'~ ( (: DD_"~ DI~ ~9~_P~r~Tu~b~/'~i:J'proval number 10. APl number so- ?33-20133 11. Field/Pool North Tradinq Bay cement ~ 9210' Cmt plug 7,680' - 9,183' Cemented Measured depth True vertical depth 800 sx "G" 1,379' 1,363' 2,300 sx "G" 10,242' 10,046' Casing Length Size Structural Conductor Surface Intermediate 1,379' 13 3/8" Production 10,242' 9-5/8" Liner / Perforation depth:measUred Cement BF-2 true vertical uG- 1 UG-3 plug covering perforations. 8870' - 8875' MD 8691' - 9002' - 9022' MD 8820' - 9152' - 9167' MD 8967' - 8696' TVD 8840' TVD 8982' TVD feet Tubing (size, grade, and measured depth) 2-7/8" 6.4# N-80 EUE 8rd Tbg to ~e8,822' Packers and SSSV (type and measured depth) RnkPr FH ~n-h!e ~'in HuH nb~ r~1~9 (q A" 13. Stimulation or cement squ~ze'~u~¢ r- ........ · -- - Intervals treated (measured) Treatment description including volumes used and final pressure Tn1 n nnnq, -- ~ · . vvvv RECEIVED 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 0 570 Subsequent to operation o o 0 O 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations .~_ 16. Status of well classification as: Oil__ Gas _ , Suspended ._~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Title Operati ons Enqi neeri nq S~py. Date 9//~///~., SUBMIT IN DUPLICATE DAI'LY gELL OPERATIONS TS-3RD 7/17/92 Test DW plugo Bleed TP to separator pressure, TP up from 30 to 480 psi° Plug appears to be leaking. Otis & Halliburton rigging up on T$-3. PT Halliburton lines to 3000 psi. Test Good. PT Otis lubricator to 3000 psi, Good. Begin pumping down tubing 8 I BPM. TP-510 psi, CP--160 psi. Take +/- 20 bbls liquid returns. Close annulus & bullhead down tubing 0 I BPM. TP & CP up to 1500 psi° Rate slowed to +~- 1/3 8PM P 1500 psi. S/D pump. Monitor TP & CP for i hr. TP & CP down from 1500 psi to 380 psi° RIH w~RB pulling tool w~ 22" long 5~8" equalizing prong to 8400' WLM. Set down on plug P 8450'. Allow 15 min to equalize. Attempt +/- 20X to latch DW plug, no success. POOH. Remove equalizing prong. RIH, latch plug first try. Jar Down lOX before plug released. POOH. Recovered 1004 of plug. RD Otis, secure well. TP-CP:150 psi. 7/20/92 SWS on Spurr. MU weight bars'/CCL and PT lubricator to 3000 psi. Good. Arm Two 1-1/2' puncher guns. Open well & RIH. RIH & tie-in to packer. Shoot 2' above packer ~ 8809', from 8805.5' - 8807'. Log up to 8400', shoot 2' above collar from 8402.5' - 8404'. POOH. LD guns. All shots fired. RD SWS. 7/31/92 $RU CTU & Halliburton. NU 5K valve to top of tree for CTU PT. RU lubricator. Pump in sub, BOPs, and injector head. Hook up lines & returns. 8/1/92 PT surface lines to 4000 psi. Function test & PT blind rams, tubing rams, and check valve. All good. Pump FIW down tubing to clear gas from tbg & csg, I BPM, 200#. Pump pressure up to 500 psi. Started taking returns P 118 bbl away. Start mixing salt pill to control fluid loss. Mix 30 bbl pill. Start pumping salt pill down tbg. Take returns for 45 bbls, then close in rtns & bullhead +/- 5 bbls. Locked up & pressure to 600 psi. Start RIH 0 100 FPM and pumping 1/3 BPM. S/D pump & RIH to tag fill ~ 9183' CTM. Pull back up to tbg tail while mixing cement. Start mixing cement - 45 bbls. Start pumping down CT w/ CT-tbg annulus open for rtns. RIH w/CT to 9175' CTM and pump 22 bbl CT volume as spacer to wash remaining salt pill from casing. Pump 1.5 bbl cement above nozzle, then POOH @ 15 FPM laying plug in w/ TOC staying +/- above nozzle. When all of 44 bbl cement away, switch to FIW to displace. Continue laying plug. All of cement out of CT. S/D pump. Pooh fast to 7000', then pump 5 bbl FIW to be sure CT is clean. POOH while pumping 1/4 BPM to keep hole full. WOC. 8/2/92 Establish rtns pumping down tbg @ 1BPM. Pump 10 bbls, take 9 bbl rtns. S/I backside & PT to 1500 psi. After 30 min., pressure @ 1450 psi & solid. Start RIH w/ CT to tag top of cement plug. Set down 8 7680' CTM & PU. Attempt to RIH, no deeper. POOH. Circulate 10 more bbl to ensure hole is full. S/I tbg & csg. Finish RD on TS-3. Well secure. H: \wp\DA I LYWOP RECEIVED S EP 1 5 992 Alaska OiJ & G~s Coi'~s. Co~mis$~of" A,~chora~ TS-3RD (continued) -2- 8/12/92 SRU Halliburton on TS-3. Begin pumping FIW w/ 0.754 KW-132, circulate e 2 BPM, TP:IO00 psi. CP=50 psi, taking rtns from csg to production. 620 bbl away, S/D pump. Close tree valves & start RD. Complete RD from TS-3. Final TP=CP=O psi. 8/18/92 SRU lines to inject fuel gas to tbg and take rtns from csg. Begin displacement. Stop taking rtns after 8 bbls. Losing differential across circ hole. Need to displace from csg to tbg due to small capacity of tbg. 8/19/92 Resume displacement, take 8 bbls more rtns, total of 16 bbls displaced: 219' of tbg & csg. Rigged down on TS-3. Secure well. Remove flowlines & blind flange tree. Install gauges. 9Z8/92 TP : O, 9-5/8" CP : O, 13-3/8" CP : O. H:\wp\DAILYWOP RECEIVED HARATHDN OIL COHPANY NORTH TRADING BAY UNIT SPURR PLATFDRH VELL T/S-3 VELL SECURING Ci~qPUCTICD 8/9E 6/13/83 TBG & CSG I,ILLED VITH INHIBITED 8.5 PI>O I'IV TOC e 7,~0' CTN CIRC. HD. ES IN TBCL 8,40~J5°-8o404 CIRC. IN TBG ~eosure~ents ore RKB to top oF eClUq~nent 33' E-7/8' Tlog Hngr ~04' Otis Boll Votve Lonckng I~pple CE.3I' I.D.) ConcOct;on - 0'-8829' E-7/8' E~411o N-80 EU[ 8~d Butt. Tb~ 1379' 13-3/8; 54.5ll, J-5~5 CsG IPBD e 10,189' TD ! IO, e4e' 844E' 8775' 8809' 88E8' 9-5/8; 43.5 L 53.51l N, P, LTL ond Butt Csg Ot;s DV Tbg plu~ Ot;s XA SI;crmg Sleeve C~.313' ID). Boker l,H Double Gr~ Hyd Pkr size 51A~ (3.0' ID). Ot;s XN N;ppte CNoGo ~0~' ID). Boker Sheor-out Bott Seot (~.437' ID). PERF'~R&TIDN-~ niL 7/79 · E/90 7/79 BF-E 8870'-8875' 4 SPl, O' PhGsing UG-! 900~'-90EE' DI,-E UG-E cj070'-9080' ' ' UG-3 915~'-9167' ' ' UG-I UG-3 Togged FAt @ 9,183' CTH 8-1-9~ ,,o. ,:.,.,,... ,o,,, RECEIVED o-e SFP 1 5 Alaska Oil & Gas Cor~s. Co:::m~ss~oo' 8-3 -4 AnchoraB~ G-$ H-ia Rev~smn Dote, 9/8/9~ H-3 Revised By, JDH/evo Reosom Vett $eO, ring Previous Revisiom 4/14/9~ ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-14.33 TELECOPY: (907) 278-7542 September 14, 1992 Lyndon C. Ibele Operations Engineering Supervisor Marathon Oil Company P.O. Box 190168 Anchorage, Alaska 99519-01686 Re: Spun' Platform wells TS-I, TS-2, TS-3, TS-4, TS-6, TS-7, TS-8, TS-9 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 tubing and tubing-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. Sincerely, Chairman Marathon Oil Company Alaska i Domestic. ,oduction RO. Box 190168 Anchorage, AK 99519-0168 Telephone 907/561.5311 August 12, 1992 Mr. D. W. Johnston Head Commissioner' Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive ~' Dea~ N~, Johnston~ "~ "'- ..... " This ]ette~ is written at the ~equest of H~, Hike H~nde~ to advise the AOGCC of a pevis~on to the p~ocedu~es fo~ plugging-back the p~oduc~ng intervals of the gpur~ Platform we]Is. This revision was discussed with N~, Ninde~ on 8/12/92 and g~ven his verbal approval. Foi]ow~ng the approved plans to isolate perforated ~n~e~va]s w~th cement and v?~fying cement ~nteg~ity by tagging/p~essu~e testing it is Ha~athon's plan circulate inh~kited filtered ~niet water (F[~) ~n the ~ub~ng and tubing-casing annulus prio~ to securing the we]]bo~es, The F[~ -- with a fluid density of 8.5 PPg -- wi]] be used in place of 9.5 ppg brine as originally p~oposed, A 9.5 ppg fluid dens~y was required ~op ~e]] control when the 5pur~ wells were originally d~i]]ed in the ]ate 1960's However, the~e are no ~emainfng p~oductive ~nte~va]s which equal o~ exceed an~g equ~valen~ hydrostatic p~essu~e. Therefore, the inhibited F[~ wi]] provide security to the we]]hopes unt~] such time that they are ~ecomp]e~ed o~ un~] abandonments a~e finalized. Please ~eturn a brief ~cknew]e~of receip~ and approval fo~ Napathon s ~ordS~ ~ : , Sincerely, Operations Engineering Supervisor Lei/crc RECEIVED H: \wp\920E08\55. LCI AU G 1 4199J Alaska .Oil .& Gas Gons. Gomm'tss[on .'.Anchomga. A subsidiary of USX Corporation- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 0 APPLICATION FOR SUNDRY APPROVALS RIG IN,AL 1. Type of Request: Abandon m Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown m Re-enter suspended well m Plugging X__ Time extension ~ Stimulate __ Pull tubing ~ Variance m Perforate __ Other __ 2. Name of Operator i1~ 5. Type of Well: Development M,-3ra~:hnn 0'i 1 ¢_.nm,nany Exploratory 3. Address Stratigraphic __ P.O. Box 1901§8 Anchorage, AK 995 Service~ 4. Location of well atsurface Leg lA, Spurr P1 atform 618' FNL, 2,068' FEL, Sec. 34-10N-13W-SM At top of productivb interval 516' FNL, 635' FEL, Sec. 34-10N-13W-SM At effective depth At total depth 557' FNL, 560' FEL 12. Present well condition summary Total depth: measured true vertical Effective depth' measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Sec. 34-10N-13W-SM 6. Datum elevation (DF or KB) 7. Unit or Property name North Tradino Bav 8. VVell number · ~. ~e'C'm i ~ ~'L] r~o e'¢ / 68-65 10. APl number 50- q33-20133 11. Field/Pool North Tradin,q Bay Length 10,250' feet 10,094' feet feet 9,210' feet 9,056' Size 13 3/8" 9-5/8" Unit Plugs(measured) cement ~ 9210' Junk(measured) .1 Cemented MeasL~e~th ..,,,r~T(~t~t,"~ical depth feet 800 sx "G" 1,379' 1,363' 2,300 sx "G" 10,242' 10,046' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) BF-2 8870' - 8875' MD 8691' UG-1 9002' - 9022' MD 8820' UG-2 9070' - 9080' MD 8916' UG-3 9152' - 9167' MD 8967' - 8696' TVD - 8840' TVD - 8926' TVD - 8982' TVD 2-7/8" 6.4# N-80 EUE 8rd Tbg to e8,822' Packers and SSSV (type and measured depth) Baker FH Double Grid Hyd. pkr. 5~A2 f~.O" ID) fa ~Og'.: Otis BVLN fa .t04' 13. Attachments Description summary of Proposal ~ Detailed operatiqns.program ..Z_ BOP sketch Z... #1, 2, 3, 4 Wellbore Diagrams (Current & Proposed) x 14. Estimated date for commencing operation May, 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil~ Gas.Y,_ Suspended__ Service 17. I hereby certify that the foreg, l, oing is true and correct to the best of my knowledge. Signed /~P Title Operations Engineering Supv. -- "-" " FOR COMMISSION USE ONLY Conditions of approval: N9tify Commission so representative may witness Plug integrity ~ BOP Test __ Location clearance __ Mechanical Intf~g~'ity Test __ Subsequent form required 10- ORIGINAL SIGNED BY ' ~,~,m'E C. SMITH Approved by order of the Commission ,, -;rod Copy ,-.,:..,..:,: l~ed 5.1. 9;~ Comrni~ Form 10-403 Rev 06/15/88 Date I Approval No. f,~ ..- / ~ 9 Date L~. ~ c~. ~,~ SUBMIT IN TRIPLICATE Attachment #1 ~-- SPURR PLATFORM WELL TS-3RD PROCEDURE FOR PLUGGING COMPLETED INTERVALS 1. Bleed tubing pressure to zero. Monitor for pressure buildup. Fill tubing and casing with kill weight brine by pumping and bleeding. 2' RU CTU. RU chicsan w/ choke off casing to production. PT lubricator and lines to 4000 psi RIH and latch and release DW plug at 8,442' Allow to equalize. Check ~ell for flow. If okay, POH. If well flows, ~irculate kill weight brine taking returns through choke until gas is cleared from wellbore. POH and RD CT. 3. RU E-line. PT lubricator. Shoot circulation holes in tubing from.8_8~8~_03_,' to 8,805', 4 spf (above packer) and 8,400' to 8,402', 4 spf. RD E-line. 4. RU CTU. PT lubricator, coil, surface lines to 4000 psi. RIH and tag fill. 5. Lay cement plug from fill to 8,650'. POH while pumping kill weight brine to fill hole. 6. WOC. Pressure test plug and casing to 1500 psi. RIH and tag top of cement. POH and RD CTU. 7. RU to pump down tubing. Displace hole with 9.5 ppg NaC1 brine. Bleed any trapped pressure. RD. 8. Remove flowline and gas lift line and install blind flanges. Close all tree valves and casing valves. pmo\H.-\WP\TS3PA.WP 6112183 Attachment #2 YlARATN~N F~ii ]MPANY NDRTN TRADINtJ ~AY UNIT SPURR PLATFORM WELL T/S-3 Current At~ measuremen%s are RKB to raid oF ec!~ilDment 33' 2-7/8' Tbg Hngr 304' Zt;s BaLL Vatve L,?,nc~ing NiPote 3'-88P9' 2-7/8' 6.4~, N-80 EUE 8r'c~ But;%. Tb9, 8448' 877~' 8809' 8888' BF-2 UG-i ~B~ UG-2 ua-3 i379' 13-3/8', 54.5~, J-55 Csg. 10,242' 9-5/8% 43.5 & 53.5~ N, P, LTC and Butt Csg _-t~s D~/ Tbg piu9. Stis XA Sliding Sleeve (8.313' iD). 3c~ker FH Doulote Grip Hyd Pkr size 5iA8 (,3.0' ID). _-.tis XN Nlopte (NoGo 8.80~' 3~ker Shear-out Bait Sea% (3.437' PERFORATIONS D]L 8870'-8875' 4 SPF 0° Phasing 9008'-9088' ' 9070'-9080' ' 9158'-9167' 7/79 · 2/90 7/79 ............ ~ G-5 UG-3 Tagged F;tt ~ 9206' DIL 2/8/90 9210' Cement Ptug 10/79 UG-5 iPBD @ !0,189' rD ~ 10,850' Revision Date: 4/14/98 Revised By: PMB/evo Reason: Update Previous Revision: 6/10/90 Attachment #3 MARATHON OIL ~""!-PANY NORTH TRADING r' UNIT SPURR PLATFORM V/ELL T/S-3 Proposed Comptete¢ 6/13/83 Att measurements are RKB to top oF equipment 33' 2-7/8' Tbg Hngr 304' Otis Bat[ Vatve Landing Nippte (2.31' I.D.) Comptetion String: 0'-8829' 2-7/8' 6.4~, N-80 EUE 8rd Butt. Tho. 1379' 13-3/8°, 54.5~, J-55 6sg. 10,242' 9-5/8% 43.5 & 53.5ff N, P, LTC and Butt Csg 8775' 8809' Dt~s XA Stlding Steeve (8.313' iD). Baker FH Doubte Grip Hyd Pkr size (3.0' ID). 8822' 8888' Otis XN Nipp(e (NoGo 2.205' ID), Barker Shear-out BaLi $eclt (2.437' ID). BF-8 UG-1 UG-2 BF-2 UG-2 UG-3 PERFDRAT[BNS DIL B870'-8875' 4 SPF O' Phasing 7/79 9002'-9022' ' ' - 9070'-9080' ' ' 2/90 9152'-9167' ' ' 7/79 UG-3 Tagged Fitt [~ 9206' DIL 2/8/90 9210' Cement Ptug 10/79 UG-5 G-2 G-3 -4 G-5 H-I,2 H-3 IPBD e 10,189' TD e 10,250' Revision Date; 4/14/98 Revised By: PMO/evo Reason: Update Previous Revision: 6/10/90 Wireline a~acnmenl~ F~ SPURR PLATF~. ~IM Lubricator w/Ass(~ciated BOPE . . , GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP .. 13 3/8' Casing -- S.PURR -PLATFORM Coiled Tubing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Rams 5000 psi WP 13 3/8' Casing ~ STATE OF ALASKA AL/-~SKA OIL AND GAS CONSERVATION COMMISSION O [[ REPORT OF'SUNDRY WELL OPERATIONS ibiNAL 1. Operations performed: Operation shutdown ~ Stimulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate ~ Other 2. Name of Operator Marathon 0i1 Company 3. Address P.O. Box 190168 Anchorage, AK 4. Location of well at surface Leg lA, 9951~ 5. Type of Well: Development X__ Exploratory __ Stratigraphic __ Service __ Spurr P1 atform 618' FNL, 2,068' FEL Sec. 34-10N-13W-SM At top of productive interval ' 516' FNL, 635' FEL0 Sec. 34,10N-13W-SM At effective depth At total depth ' FNL 560' FEL Sec. 34-10N-13N-SM 12. Present well condition summary Total depth: measured 10,250 ' feet true vertical 10,094 ' feet Effective depth: measured 9,210 ' feet true vertical feet 9,056' Plugs (measured) J u nk (measu red) Casing Length Size Cemented Structural Conductor Surface Intermediate 1,379' 13 3/8" 800 sx "G" Production 10,242' 9-5/8" 2,300 sx "G" Liner Perforation depth: measured true vertical BF-2 UG-1 UG-3 8870' 9002' 9152' - 8875' MD - 9022' MD - 9167' MD Tubing (size, grade, and measured depth) 2-7/8" 6.4# N-80 EUE 8rd Tbg Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary to 08,822' Intervals treated (measured) Treatment description including volumes used and final pressure 6. Datum elevation (DF or KB) 92' KB above MSL 7. Unit or Property name North Trading Ba.y Unit 8. Well number · {).-P~rmi't'~[J~b~r~approval number 00-072 10. APl number 50- 733-20133 11. Field/Pool North Trading Ba.y cement fa 9210' Measured depth 1,379' 10,242' True vertical depth 1,363' 10,046' 8691' 8820' 8967' - 8696' - 8840' - 8982' TVD TVD TVD RECEIVED feet 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 2/5/90 NA 64 Subsequent to operation 2 / 14/90 NA 0 0 350 0 0 Tubing Pressure 35O 450 15. Attachment~ #.1. Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas ,v, Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Operations Engineer Date ,~-/?' ?42 SUBMIT IN DUPLICATE Attachment #1 We11 TS-3 (SPR-3) Summary of Daily Well Operations 2/7/90 RU w/reline and PT lubricator w/ methanol, OK. RIH to 300' WLM and pull SCSSV. RIH w/ gauge rings and tag fill g 8869' WLM, POH. 2/8/90 RIH w/ bailer to 9238' WLM, POH. RIH w/ gauge ring to top of cmt plug, POH. RU E-line and PT lubricator w/ methanol, OK. RIH and make logging passes from cmt plug at 9211' ELM to tbg tail. POH. 2/9/90 Made three logging passes w/ well flowing. POH, RD logging equipment. RU perforating equipment and PT lubricator to 3500 psi, OK. RIH w/ 1-11/16" 4 SPF, 0 phase strip guns, correlate and perforate from 9070' - 9080' DI~. POH, RD. Pressure building in tbg and csg. 2/10/90 RU w/reline and PT lubricator w/ methanol to 3000 psi. RIH w/ shifting tool, clear obstruction at 8358' WLM and tag "XN" nipple at 8820' WLM. Verified that sliding sleeve was closed. 2/11/90 Made several runs w/ gauge rings and cut scale to 8597' WLM. POH, RD. TP = 3100 psi; 9-5/8" CP = 2900 psi. RU pumping equipment to kill well. Pump 75 bbls 2~o KCl water at 2-3 BPM, 3000 psi. Bleed CP while pumping. Pump additional 25 bbls at 1/2 BPM, 3000 psi. CP = 3450 psi. SD pumping equipment and continue to bleed CP. Calculated tbg leak at 1180' TVD. 2/12/90 Continue to bleed CP. Pump 76 bbls of 24 KCl water down csg to kill well. RD. TP & CP dropping. RU pump-in-sub, lubricator, and "DW" tbg plug. PT, OK. Pump 140 bbls of 24 KC1 water down tubing while bleeding CP. Final pump pressure TP : 250 psi, 9-5/8" CP : 0 psi. All gas bled off csg, no fluid returns. 2/13/90 RIH w/ "DW" tbg plug and set at 8442' WLM, POH & RD. Monitor pressures. Final TP = 450 psi, 9-5/8" CP = 0 psi. Well shut-in until further evaluation. \docs\spark\ts3. doc Marathon Oil Company Alask, Jgion Domestic Production P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 March 15, 1990 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Report .of Sundry Well Operations" with appropriate attachments for Spurr Platform Well TS-3 (SPR-3). Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely,^ m T. J. Kovacevich District Operations Engineer Attachment \docs\ml\6.doc Ri CEIVED A subsidiary of USX Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS OR 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging ~ Time extension ~ 2timulate ~ Change approved program __ Pull tubing __ Variance ~ Perforate ~ Other 2. Name of OPerator ! 5. Type of Well: ,, Marathon Oil Company I Devel°pment ~'~- Exploratory __ 3. Address Stratigraphic ~ P.O. Box 190168 Anchorage, AK 9.951 Service~ 4. Location of well at surface Lug IA, ~purr Piatform 6. Datum elevation (DF or KB) 92' KB above MSL 7. Unit or Property name North Trading Bay 8. Well number 618' FNL, 2,068' FEL, Sec. 34-10N-13W-SM At top of productive interval 516' FNL, 635' FEL, Sec. 34-10N-13W-SM At effective depth Att°t~5dTepthFNL, 560' FEL, Sec. 34-10N-13W-SM 9, Perm"number ' 68-65 10. APl number 5o- ~33-20133 11. Field/Pool North Trading Bay feet Unit 12, Present well condition summary Total depth: meas'ured true vertical 10 250' , feet Plugs (measured) 10,094' feet Effective depth: · measured 9,210 ' feet Junk (measured) true vertical 9,0 5 6 ' feet cement (a 9210' Casing Length Size Cemented Measured depth Structural Conductor Surface Intermediate 1,379' 13 3/8" 800 sx "G" 1,379' Production 10,242' 9-5/8" 2,300 sx "G" 10,242' Liner Perforation depth:measured BF-2 8870' - 8875' MD 8691' - UG-1 9002' - 9022' MD 8820' - true vertical UG-3 9152' - 9167' MD 8967' - Tubing (size. grade, and measured depth) 2-7/8" 6.4# N-80 EUE 8rd Tbg to (a8,822' P k rs an _V(t. an meas d ept) ~er ~o[~e ~r]pU~y~d: i~r~r. 51A2 (3.0" ID)[a 8803' 13. Attachments i & 2 Description summary of proposal X__ Detailed operations program 14. Estimated date for commencing operation February 12, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: 8696' TVD 8840' TVD 8982' TVD True vertical depth 1,363' 10,046' RECEIVBD FEB - 6 1990 Alaska Oil & Gas Cons, Ce BOP sketch ,v, Anc-nolag~ Oil __ Gas .._Z. Suspended __ Service Date ~.../.,5"/~0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved Copy ORIGINAL SIGNED B~ Re.turned Approved by order of the Commission Commissioner J Approval NO. Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Attachment #1 Spurr Platform Well TS-3 Procedure 1. SI TS-3. RU slickline and PT lubricator w/ methanol to 3000 psi. 2. RIH and retrieve SCSSV at -300'. POH. RIH w/ 2.15" GR and tag fill. POH. RD slickline. · Flow well 5-6 hrs prior to logging. RU logging equipment and PT lubricator to 4000 psi. RIH with TDT-P/GR/CCL tools and log from cement plug (-9210' MD) to tubing tail. Make three passes with well flowing and two passes with well shut-in. POH. e Evaluate TDT-P results and select intervals to be perforated. Anticipated intervals are: BF-2 8870' - 8900' DIL (30') BF-1 8825' - 8850' DIL (25') . RU perforating equipment (2-1/8" strip guns, 4 SPF), RIH, correlate and perforate the selected intervals while flowing the well. e RD perforating equipment. RU slickline and PT lubricator to 4000 psi. RIH and set SCSSV. POH. RD. Note: Maximum anticipated SBHP is 4000 psi. docs~oe46~50, doc RECEIVED FEB - 6 1990 Alaska Oil & Gas Cons. Gore Anctiorage Attachment #2 SPURR PLATF,.RM Wireline Lubricator w/Assqciated BOPE ! . , -- GREASE HEAD (Hydraulically Activated) LUBRICATOR OPERATED BOP RECEIVED FEB - 6 1990 Alaska 0ii .& Gas Cons. Commissi011 N~cliorage .. 13 3/8' Casing - Marathon Oil Company Alask, ,gion Domestic Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 February 2, 1990 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval is an "Application for Sundry Approvals" with appropriate attachments for Spurr Platform Well TS-3. Should you have any questions regarding any application ob report, please contact me at (907) 561-5311. Sincerely, T. J. Kovacevich District Operations Engineer Attachment em~docs~ml~6 RECEIVED FEB - 6 1990 Alaska 0il & Gas Cons. Go. mmtSsl~ ~cliorage A subsidiary of USX Corporation Doyle~. ',,'"~es Produ~,. lanager Alaska Ruujion Domestic Production Marathon Oil Company September 23, 1988 RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 Mr. C. Chatterton Alaska Oil and Gas Conservation Commission 3001 PorCupine 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 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 //I. ~t ~ . . . 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 ProduCtion rreports 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 Unocal Oil & Gas Dt Unocal Corporation" RO. Box 190247 Anchorage. Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL August 19, 1988 Robert T. Anderlon DiStrict Land Manager Alaska District Mr. Mike Kotowski Division of Oil & 9as State of Alaska Pouch 107034 Anchorage, Alaska 99510-?034 NORTH IRADIN9 BAY UNIT State of Alaska CHange Of 0peratorsh~p for Platform Dear Mike: On 3uly 2~, 1988, 9. A. Graham of this office sent a letter to Oim 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 Designation-NotiCe and it's the intent of .this letter to clarify that Union has been designated Sub-Operator of the North Trading Bay Unit Rlatform "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. 2ery truly yours, · ~"~ i'"' '" /~2 Kevin A. Tablet Landman Ala~:~ 0~1 & Gas Cons. EnclOsu~ ', ~ucho[age .~..~ ~'~'", ( ~ 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. Addres[.'. .union ul± Company of California Marathon Oil Company P. O. Box 190247 Anchorage AK 99519-0247 P. O. Box 190168 Anchorage AK 99519 . Notice is hereby given of a designation of operatorship for the oil and gas property described below: Property designation: North Tradln§ ~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 ?. O. Box 190168 Anchorage AK 99519-0168 5.'E'ffective 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 By: /~r f~.~ff/_ Doyle ~ - J°nef Signed Title is hereby 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 · SI-ATE (DF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DESIGNATION OF OPERATOR 20 AAC 25.020 'TSR ENG · 1. Name of Owner North ~e~ica sa~ ~ioa Oil Compa~ o~ Csli~o~ia ~.SR~EOL '1 I ENu AS~ '2. Address Union Oil Company of California (Designated Operator) P. O. Box 190247 STAT T~GH~ Anchorage, Alaska 99519-0247 STAT ..... T~CH~ ,~1.~: 3. Notice is hereby given of a designation of operatorship for the oil amd gas property described below: Property designation: North Trading Bay Unit ~ Legaldescription 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 to the provisions of Article 5 and 6 of said Agreement, the Working Interest ~ers approved Union Oil Company of California as . Designated Operator. Property Plat Attached ,,. 4. Name of Designated Operator Union Oil Company of California Address 909 West 9th Avenue ~ E ~ ~ ~ '%~[ P. O. Box 190247 ~chorage, ~ 99519-0247 .... " 5. Effective date'designati0n ,:~&~;.~a 0ii ~ d;~3 dons. Anch0rag9 7:00 a.a. August ~, ~988 6. Acceptance of 0peratorship for the above described property with all attendant responsibilities and obliga- tions is hereby acknowledged Si~nod G. ~. Graham Titlo DSstrScr OperarSons ~anager Dato 7/29/88 , 7. Tho owner horoBy cortifios that tho [oro~oin~ is truo and corroct (SEE ATTACHED LETTER) Signed Title Date Form 10-411, 12-1-85 Submit in Duplicate C FI Ko~u~ ''-' i~mtton$ · ' · -. Marathon Oil Company ~ · . O. Box 3128 ~ Houston/ TX ?72~3 ' · · Attention: Mr. Dan Hihkle ' Mobil Exploratlon and ~roducing North America P. O. box 5444 ~ Denver/ CO 80217 ~ ' Attention: Mr. Fred P~er~on Gentlemen= { rlOH-'l] 0 NOHJ. tfl~IflN NO~ MO. 14 P~£ O . Texaco Ino. (Texaco) h~as agreed to assign to Union Oil Company Of Californ/a ;(Union) all of its right, ~l~le and interest An and ~o $=a%e of Alaska Lease APL-1789?, subject tO =he required approval ~f the State of Alaska, Dep~=ment o~ Natural Resources, Division of Oil and Gas. A portion o~ this le~ i~ subject to ~he North Trading Bay Unit~ In this re~ard,] contingent upon approval of this assignment, Texaco is hemeby tendering l~s Tesi~at~on as Sub-Operator of PlatfO~ "A" e~feotive AUgust 1, 198~, in entitled "Uni~ Operati~g Agreement He~loo~ an~ ~ Formation North Trading Bay Unit~ Cook Inlet, Alaska", as amended ("NT~UOA") effective J~ly 1, 19~1. A SUbject ~o approval bye' Working Interest O~ers comprising seven=y-~lve Percent (7~%) of ~he votin~ power, Union has agreed to assume Te~ac~'s peri%ion as Sub-Operator of Pla~fo=m "A". Upon such approval, UnIo~ will acteD= all duties, obligations and responsibilities of Sub-Opera,o= of Platfo~ "A" as set fo~h in the NTBUOA, effective' August !, Marathon and Mobil, as Working In~e=es~ Owners in the No=th Tradin~ ~ay Unl~, have' a r~ght under Article 7.4 of the NT~UOA to vote for the~ select!on of a successor Sub-Operate=. ~owever.', if your restective companies have no objection ~o Union succeedi~.~ Texac~ as Sub-Operator,-~please indicate your agreemenD by si~ning ~elow and. retU~nI~-g one copy to this office. ~ - /%:~ . . ~ ~'~' ' ,. · . .. . .- .. . · , ..: . : Mara=hon 051 ¢omDany e~ al July 27, 1988 Pa~e 2 In order to e~edite th.e sale, a rasponse by July 29, 1988 would be ~eatl~ appre¢~a~Gd. Zn the mean~mG, should you have any ques~ions regarding this mat,:e=, please contac= Mr. Dic~ Crouch wSth Union at (818) 504-7718. TEXACO INC-. UNION OIL COMPANY OF CALIFORNIA BY:_ DAte: . --~ - ' AGREED AND · · AGREED AND ACCEPTED: Date: - ~C ~ K~"' Los ~ Ol~,~ion~ July 27, 1988 i0 ,Jn~ve:$a! City Piaza Unwersa! ¢~/CA 91608-1097 8'1.8 ~ 2000 · & · , MarathOn 0il Company P. 0. BOX 3128 Houston, TX ??253 Attention: Mr. Dan Hinkle Mobil ExDlorat±on and Producing North America P. O. box 544¢ Denver, CO 80217 Attention: Mr. Fred Gentlemen: Tex~co Inc. (Texaco) has agreed to assign to Union Compaz~y of Californ~a (Union) all of its right, title and in%crest in and %o S~a%e cE Alaska Lease ADL-1g597, to the required eD~ro~l of the State of Alaska, Department of Natural Resources, ~ivision of Oil and Gas. A portion of this leas& i~ sub, eot to the Nort~ ?fading Bay Unit. in %h£~ =*g&rd,.eontingent upon approval of this Sub-Operator o~ ~1 ' # " . a~=o~m A effective Au-u~ · ~aoo' ,n~i~~.,~,.~~ -:~.o= =nat certain agreement - ~ ~=~ uuau ~era=~ng Agreement Hemlock and G Formation North Trading BaY Uni~' Cook Inlet, Alaska", as amended ("NTBUOA") effective July 1, 1971.. ' Sub, eot to approval by-Working Interes~ Owners comprising eeven%¥-£ive perCen2 (75%) of the voting ~ower, Union has agreed to assume Texaco~s D0a~tion as Sub-Opera%or of Pla%£orm "A". Upon suc~ aD~rov&l, Union will accept '~11 dutie=, obi£ga~tone and responsibilities of Sub-Opera~or of Platform "A" aS Se2 forth in the NTBUOA, effec~ive August 1 1988. t , · f Marathon and Mobil, aslWo~king Interest Owners in the North Trading Bay Unt~, have~a right under ~r%icle 7.& of the NTBUOA to vo~e ~or the. selection of a successor Sub-ODera2o~. RoWever, if your respective companies have no objection ~o Union suCceeding Texaco a~ Sub-Opera,or, please - - = ....... ~ by slgn~ below ~nd re COpy tO this office. ~ ....... one Marathon 0il Comp&ny e~ al July 27, 1988 Page 2 · In order kO ~xpedite the sale, a response by July 29, 1988 would be g=e&tly appreciated. In the meantime, should you h&ve any qu®$=~ons regarding this ma~er, please contact M=. Dick Crouch w~h Union at (818) $04-7716. TEXACO ZNC. · I.ts Attorney in F~ , AGREED ~D ACCEPTED: MARATHON OI~ COMPAN~ Date: UNION 0IL COMPANY OF CALIFORNIA By: Date :. ~ AGREED AND ACCEPTED= MO~Z ZX~O~ON a PltODUCIN~ U~. INC. ~ A~ ~ MO~ ~~ON ~ PRODU~Q Date: ICI .,.L. 8-31 ADL-369125 I · AMOCO 8-31-96 ADI.,-369126 A 8-31-96 ON SANTA FE 11-30-90 AOL' ~59042 · · ,ADL--32..6.143 -- .LEHNOORFF S~NTA Fi ,26 __'2'_- II 1,738.00 ! I ADI.-12tl I0 'L EHNOO~II:II' · SANTA /KS ADL-63279 522.00 Ac. NICOLAI CREEK UNIT ADL-326119 .. 28,16 Ac. (XACO .. _ ?(X&C:;0 AC~ / UNION ",. c , .,~.n; .~: fiAD · ;.: '" I,' .T lNG :':....'-, · e... ~ 9'' -- '' ..d~le tee · e~ ,. ,-.. ;7 "" ; ' '~" Lc," ' ~ * Od'/ · ' : ... 'T .-~.. ,.;~- · e~,.~I ,',- ,.,, ~ °, .- ' '~'" .. · · ,,~,·e UNION Id&RAT HON · : · -,, 'o ,1,*; · ,,, ,, · LEHNDORFF SANTA Fe 6- 30r-91 MOBIL '["c° ADL-17597 5,120.00 Ac. ADL 32613'1 I I I I I I 'F I I I BAY POOL ieee I I I I I I I I I I ~"~' I /v · .dO//v6 I Oar u/v/r _1. e · · f. ee ,5' ., · I AOl ~ ?".if, ADL- 17585 ,.'~v;" ..,. 5,619.67 Ac. , a ~4QCO ,<.: .:, ...... + NORTH" TRADING BAY UNIT I 36 ~'~11 I ...... ;- ..... 'f' - 3" ! t I 6 DANCO I I I I I · 8-31-96 -t- ADL-369116 &MO(: G tEXACO C--CrOtON aMOCO ;,,~..,;; ..... ~'.t~7.. ........ ~. o · (e · . ./ STATE OF ALASKA ~ ALASt OIL AND GAS CONSERVATION COMk 31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other ~ 2. Name of Operator Texaco Inc. 3. Address 550 W. 7th Ave., #1320, Anchorage, Alaska 99501 4. Location of well at surface 618'S, 2068'W of NE corner of Sec. 34-10N-13W, S.M. At top of productive interval 561'S, 635'W of NE corner of Sec. 34, 10N-13W, S.M. At total depth 557'S, 560'W of NE corner of Sec. 34-10N-13W. S.M. 5. Datum elevation (DF or KB) KB i.s 32.57' 6. Unit or Property name ADL 17597 7. Well number T/S #3 R/D 8. Approval number 68-65 9. APl number 50- 7 332013300 10. Pool North Trading Bay Unit 11. Present well condition summary. Total depth: measured 10,250' true vertical feet Plugs (measured) feet Effective depth: measured true vertical feet Junk (measured) feet PBTD = 9500' Retainer at 9210' with 100 Sx cenent Feet Casing Structural Conductor Surface Intermediate Production Liner }pell:~erforation depth: Length Size 20m' 13 3/8" 9 5/8" Cemented Measured depth True Vertical depth 800 Sx Class "G" 1379' 2300 Sx Class "G" 10,242' measured 9152' tO 8870' in intervals RECEIVED MAR- 6 1987 true vertical Tubing (size, grade and measured depth) 2 7/8", 6.5#, N-80~ to 8819' Alaska Oil & Gas Cons. Commission Anchorage Packers and SSSV (type and measured depth) Otis surface control SSSV at 304' 12. This is to notify you of actuation and testing of SSSV from subject well on 2/28/87. 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1325 I 0 1325 1 0 Tubing Pressure 1425 1425 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Sig n_____~e Form 10-404 Rev. 12-1-85 Title District Manager Date 3/3/87 Submit in Duplicate 02:O01B (Rev. 10/76) STATE of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION TO: ~File FROM: William Van Alen~TF/ Petroleum Geologist DATE: September 9, 1980 FILE NO: TELEPHONE NO: SUBJECT: Re: Texaco - Superior Trading Bay Unit #TS - 3 (RD). On 12/5/68, the subject well was completed as an oil well with production through perforations below 9710' in the defined Trading Bay "G" NE and Hemlock NE Oil Pools. On' 8/24/79 a drillable bridge plug was set att9500' and on 10/5/79-the well' was recompleted as a gas well with production through a net of 45' of perforations between 8870' and 9167' Flow rate was reported as 2567 MCF/D of gas consisting of 9~..28% methane and 6.72% nitrogen and having a BTU of 942. At a September 9, 1980 meeting among Commissioners Hamilton, Kugler, and Smith, petroleum engineer Douglass and petroleum geologist Van Alen, it was agreed that the above indicated gas production is non-associated dry gas production from an unde- fined gas pool lying stratigraphically above the Trading Bay "G" NE Oil Pool. References: CO #69, 1-24-69 CO #74, -6-24-69 Form. P--7 SUBMIT IN DUPL 'E. STATE OF ALASKA I See other in- structions on OIL AND GAS CONSERVATION COMMITTEE r~¥e~'se side) [ I i WELL cOMPLETION OR RECOMPL~TION REPORT AND LOG* AP1 NUM, ERICAL CODE 50-133-20133-00 $.~LEASE DESIGNA;fIO~' A_ND SERIAL NO. 2~ ADL 17597 ?. IF INDIA.N, ALIX)TTEE OR TRIBE NAi~E 8. UNIT,FAR1VI OR LEASE NAME State of Alaska la. TYPE OF WELL: b. TYPE OF COMPLETION: NEW r--] wonK F-] %VELL OVER ii OIL [~' t;A8 ~ ~- F---[ Other WELL WELL [L~Is DRY DIFF. ~_~ DEEP- F-~ BAcKPLUG F-'l nESVR.~ Other EN _ 2, NAME OF OPERATOI~ Texaco Inc. ~ 3. ADDgESS (J~ O~ERAT.0R P.O. Box 4"~579, Anchorage, AK 99509 ~. WELL ,NO, T/S #3 0i FI~-T,D AaND POOL, OR WILDCAT NOrth Trading Bay LOCATION OF WELL (Repor~ location clearlM and in accordance with a~y ~tate requirements) { Atsur~ace6l'8' South, 2068' West from NE cor Sec. 34-10N- 3W,S.M. on Texaco-Su'P. erior Platform "iA". At t~p prod. interval replorted below ' _ 516~ SoUth, 635 West from NE cor. '!Sec. 34-10N-I3W, S.M. At total depth 557' SOuth, 560' West f~om NE Cor. Sec. 34-10N-t3W, S.M. ReCommence -25'79 : : '~usP. 10-5'79· 192' K.B. MSL 10250" ' ' 21" ' ~w~i.~,~* ~o~ ~OOLS (10094) [9 ~ 0% (9056') 22. PRODUCING'INTERVAL(S), OF- THiS COM?LETIOiN'-2-iTOP, BOTTOM, iNTAME (MD AND TVDI* MD 8870-9167 (VD 8716-9013) Lower' "F" zone, North Trading Bay 11. SEC., T., R., M., (BO'CI~M HOLE OBJECTIVE) Sec. 34-10N-13W, S.M. t2. PE~'VIIT NO. 68-65 RT, GR, ETC)*IlT. ~. CASINGHEA~D 'INTERVALS 'DRILLED BY '[ C^aLE TO0t,S ! 23. WAS DI~ON~ SURVEY ~DE ,1 24. TYPE EI-~CTRIC AND OTHER LOGSRUH~: ' CNL loa.. 7049'- 1Q099' ,, C,~SING SIZE 13 3/8" ~ 9 5/8" CASI1NTG RECORD (Report all strings sei in well) 54. !~'~ [ j~55 ! 1379," ' ! 17b." I' 43.5#,47# ['NL801/102427~. & 53.5~ t& P-l]1 26. LINER 1R~CO~ 't~D -- .... s~.~ -[,To~ (~) ~o~o~ (~ [SACI~S:'C~* I ' j,.j ~ ~ ~. PE~O~TIONS OP~ TO PRO~UC ~O : (Inte~al, s~e ~d nmber) 8870-8875 4-1/2" 3or bolos/fl 9002-9022 " 915~-9167 " i I 30. PI%ODUUPION i i CI~IENTIIffG RECO1R~ A.IVIOUNT PULLED 800 sacks Class G 2300. sacks Cli~ss G. TUBING RESOleD SC~ (iM[D) ] SIZE DEPTH S~"I' (MD) Z //8" 8'819' ' 8804' 20. ACID, SI-lOT, Fi'~CTURE, CENIENT SQUEEZE, ETC. DI~-~'~I-I ~VAL (MD)- ii A~OUN'r AND IgiIND O,F IVIATER,IAJ~ U~,D PACKER SET (MI)) DATE FIR.ST' PI~ODUCTION I L:~O'DUCTION METHOD (Flowing, gaa' lii(tYp~mp~g--size and type of pump) [WmLL ST~WS (~oduc~ or ]0-3-79 [ ~ Flowing : ] ~'~'~)Shut-in DATE OF TruST, [HO~S T~ '[~OI{E SIZE [PEOD'~ FOR OIDBBL. "'~~CF. WA~B~. [ GAS-0IL ~O 10-3-79, ,, ~ST P~OD · l 4 ,l' 1/4 . ,] .... ;- 0 428 I 0 i 1- I TEST WITNESSED BY Vented "~'" ,~ .... 32. LIST OF" ATTACHMENTS rr: ~ / f"':',~('[:._; ~ Workover History ~L..,:. ~, 33. I hereby certify that the foregoing a~ttached information Is complete and correct as determined from all-available tee'orals , 818N~D ~ TITLE ~ e ons Supervi , · (~ee Instructions an~ S~ces for A~itionul Data on Reverse ~i~e) INSTRUCTIONS General: This form is designed for submitting a.complete and correct well completion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- mentsgiven ~n other spaces on this form .and in .any attachments. Items. 20, and 22:: If this well is completed for Separato production from more than one interval zone (multiple completion), so state in item 20, .and in item 2.2 show the prc.zJucing interval, or intervals, 'top(s), bottOm(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each adc~itional interval to be seperately produced, show- ing ,the adiditional data pertinent to such interval. Item26: "Sacks Cement": Attached supplementa l. . records for this well should show the details of any mul- tiple stage cementing'anc~ the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~. (See instruction for items 20 and 22 above). ! , ~IARY Ob" Ii~ORB/rA'PION TF_.~$ INC.'L, UDING INTEFIVXL TY_.STED, I~RF-,SSURE DATA'AND R.F__,COV~IES OF OIL', GAS. 35. GI~OIbOG IC M/kRK~ · WATF-,R AND MUD , : . ....... MEAS. D~ ~Ug V~T. '~ 8870~'L8875') 'Max rate. on pump 1800 BW/D, TP 300~/CP 900~ : 9002'~9022') ' ' 9152'-9167') Max, rate flowing 855 BW/D, 9 BO/D (99% cut), ' 9248'-9263') t200 MCF/D TP lOOf, 50/64 Choke. F zone 7684' 7538' 8870'-8875') G zone 9710' 9557' "9002'-9022') ' Flowed 1850 MCF/D, TP 20Of, 5/1'6'.' Choke. 9152'-9167') Hemlock 9908' 9753' 9248'-9263') No flow, recovered 328 BW/I.5 hrs, no oil or gas . 8870 '-8875') 9002'-9022') Max. flow 2'567 MCF/D, T.P. 1750~, 1/4" choke. 9152'-9167') , .... , DST -~ Produc Test (Final Form 10-403 REV, 1~-10~73 Subml t "1 ntentions" in Triplicate & °'Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proDosals.) O,L b-FI GAS [--1 WELL""' WELL CT.ER 2, NAME OF OPERATOR TEXACO, INC. 5. APl NUMERICAL CODE 50-I 33-20133-00 6. LEASE DESIGNATION AND SERIAL NO. ADL 17597 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME State of A1 aska 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 4-1579, Anchorage, AK 99509 T/S #3 4. LOCATION OF WELL Atsurface Texaco/Superior Platform "A" Cook Inlet, Alaska 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KB = 92' MSL 14, Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND I:~:)OL, OR WILDCAT · North Trading Bay Unit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, T 10N, 13W, S.M. 12. PERMIT NO. 68-65 )ort, or Other Data NOTICE OF INTENTION TO.' SUBSEQUENT REPORT OF= TEST WATER SHUT-OFF L.~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) i-..===1 PULL OR ALTER CASING L~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR AClDIZING (Other) REPAIRING WELL ALTERING CASING ABANDONMENT* (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log fQrm.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent detllll, and give pertinent dates, Including estimated date of starting any proposed work. l) Kill well as necessary with salt water and install 32", 3000 psi. BOPE.. 2) Pull Reda Pump. 3) Trip, 9-5/8" casing scraper to 10,250' PBTD or to top of fill... 4) Set permanent'bridge plug at 9500'+ to plug off perforations from 9.710" to 10,124', 5) Run packer with retrievable bridge--plug and straddle test recently perforated upper "G" intervals to evaluate production. New intervals are; 9248'-9263', 9152':-9167, 9002'-9022', 8870'-8875'. Obtain flow test through production facilities 6) Cement squeeze intervals producing significant water volumes. All zones ~esting dry gas to be left open. 7) Run production packer with sliding sleeve on 2-7/8" tubing using sub-surface safety valve. Set 100+' below the mud line. Install production tree. 8) Return well to prOduction and Obtain stabilized flow tes't. F?, C IVFD 1979 Anc~ulage 16. I hereby r,..erU.fy triat, t.rte.~.j'egoing is true and correct SiGNED.by: ~~ TITLEGeneral Superintendent DATE8-3-79 D. C. Hartman ........ (This space for State office u~) . CONOITIONSO~APPROVAL, IFAN~: / TITLE - n.. ~ ~ ~ Retumed BY ORDER OF THE ~ Instructions On Reve~ Side Form ! 0-403 REV. 1-10~73 Submit °'Intentions" in Triplicate & "SubSe¢luent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS - (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OwIELLLr~WELLGAS E~ OTHER NAME OF OPERATOR Texaco Enc. 3. ADDRESS OF OPERATOR P. O. Box 4-1579, Anchorage, Alaska 99.509 4. LOCATION OF WELL Atsudace Texaco/Superior Platform "Inlet, Alaska 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 14. KB = 92 ' MSL Check Appropriate Box* To Indicate Nature ~:J~ll~i~e, Re [5. APl NUMERICAL CODE 50-133-20133-00 6. L~SE DESIGNATION AND SERIAL NO. ADL 17597 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME State of Alaska 9. WELL NO. T/S # 3 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, TiON,13W $. M. 12. PERMIT NO. ,i~.~,'.,~ 68-65 )crt, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF= WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AClDIZlNG ABANDONMENT* (Other) Test qas sands (NOTEs Report results of multiple completion on Well COml~letion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ~letall~, and give pertinent dates, Including estimated date of starting any proposed work. 1. Killed well, installed BOPE, P~!! p~mp and set drillable bridge plug at 950f · · · · Straddle test upper "G" sands. 8805 %o 92.~0. Test. all gas at 1400 MCF/Day rate with 1320 psi surface 'P~ess,ure 'on 1/4'" choke. Straddle test intervals from 9210 to 9500'. Ail water entry 1032 B/D rate. Set cement retainer at 9210, Run 2-1/2" tubing to 8819', Valve 310'. s~eezed with 100 sx of Class. "G" cement. Baker Hydraulic Packer 8804', Otis x 6 Ball Flow test: Initial shut in pressure after clean up. 3236 psi. 1/8" choke - 1008 mcf/d at 2822 psi , clea= 3/16" choke - 1811 mcf/d at 2210 psi,~ med. mist wa%er 1/4" choke - 2567 mcf/d at 1750 psi, very light mist water· 16. I hereby certify that the foregoing is true and correct /' (This spac~ for State office use) Gestural S~pemtn%ende~YE ,, [0-12-79 APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE . DATE See Instructions On Reverse Side DUPLICATE COPY - ORIGINAL SIGNED AND MAILED FROM LOS Form 10-403 ~ Submit "1 ntentions" in Triplicate REV. 1-~0~73 ' ~ & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL I___1 OTHER 2. NAME OF OPERATOR Texaco Inc. 3. ADDRESS OF OPERATOR P. 0, BOx 4-1579, Anchorage, AK, 99509 4. LOCATION OF WELL Atsurface Texaco/Superior Platform "A" COok Inlet, Alaska 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KB : 92' MSL 14. CheCk Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) £nmmi nal ~NL~ELE3 Ul~ /-I~-/~ J CO~__._ ~ -j~j COMM ~5. AP, NUMER,CAL COD[ ' ~RES E~ 50-133-20133-00 / _l 1~~ 6. LEASE DESIGNATION AND S~, ~L ~ ~ ENO __ ADL 17597 J 4 EN~ 8. UNIT, FARM OR LEASE NAME J SCaCe of Alaska ~J'STATTEC ~. WELL NO. ~j 5TAT T~ T/S f3 ~O. FIELD AND POOL, OR WILDCAT ..... North Trading Ba~ Unit ~ILF: 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, T 10N, 13W, S.M. 12. PERMIT NO. 68-65 )ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF r'~ REPAIRING WELL FRACTURE TREATMENT~ ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion 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. l) Kill well as necessary with salt water. 2) Install 12", 3000 psi, BOPE. 3) Pull existing pump, run CNL-GR logs. 4) Reperforate existing intervals as necessary. 5) Perforate Upper "G" intervals as follows: 9167'-9152', 9022'-9002', and 8875'-8870'. 6) Return well to production. (E-l.og depths) 9263'-9248', RECEIVED JUL 2 3 1979 Alaska 011 & Gas Cons. ¢0mmlssio, Aneherage ~- ' 16. I hereby certify that the foregoing is true l~nd correct '- ~ J~a~_~~/~z_ General Superintendent E July 23, 1979 SIGNED ~, n r', '~,/ _~ TITLE ~_ - .... DAT ....... ~,. F. F~I'll]~[' -~ (This space for State off~ u~) ~ ~ / Should ~he addi~nal ~e~~s~ in a subStantial increase ~n production, a conservation orde~ APPROVEBBY ~ U~_ TITLE,Commission DATE .July 23; 3979 CONDITIONS OF APPROVAL, IF : BT ORDER OF THE COMMI~SION A~r~ ~ (and hearing) ~11 be required. Form 10-402 REV. 1~1-0-,7~ STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) 1. OwlELLLB GAS D OTHER WELL 2. NAME OF OPERATOR Texaco Inc. 3. ADDRESS OF OPERATOR P O. Box 4-1579, Anchorage, AK 99509 4. LOCATION OF WELL Atsurface Texaco/Superior Platform "A" Cook Inlet, Alaska 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KB : 92' MSL CheCk Appropriate Box To Indicate Nature of Notice, Re 14. 5. APl NUMERICAL CODE 50-133-20133-00 6. LEASE DESIGNATION AND SERIAL NO. ADL 17597 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME State of Alaska 9. WELL NO. T/S #3 10. FIELD AND POOL, OR WILDCAT North Trading Bay Unit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, T 1ON, 13W, S.M. 12. PERMIT NO. 68-65 3oft, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING sHooTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion 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. 1) Kill well as necessary with salt water. 2) Install 12", 3000 psi, BOPE. 3) Pull existing pump, run CNL-GR logs. 4) Reperforate existing intervals as necessary. 5) Perforate Upper "G" intervals as follows' (E-log depths) 9263-'9248', 9167,:-' -9152 ' , 9022'~9002', and 8875'-8870'. KWK/smf 6) Return well to production. 16. I hereby certify that the fore~im~ is true and correct SIGNED.. ~ TITLE C. P. Farmer July 18 1979 ~eneral ~uperintenden~ATE' ' (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.. TITLE DATE See Instructions On Reverse Side 1, Form P--3 FLEV. 9-3069 S~brntt "Intentions" in Triplioate & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATIO,N COMMI1WEE ~UNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-LICATION 'FOR ~'EH.I~iT~" 'for such 'p~o~osals.) 0IL ~OAS [] WELL WELL OTHER 2. NAME OF OPERATOR ^tlantic Richfield Compan7 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4.LOCATION OF WELL Atsurface 618' S and 2068' W of the NE Corner of Section 34, T10N, R13W, SM 13. ELEVATIONS (Show whether DF, RT, OR, etc. 92' KB 14. 5. AP1 NU1VLF2JCAL CODE 50-133-20133 LEASE DIgC~IGNATION A.ND SERIAL NO. ADL 17597 7. IF INDIA.N, ALLOTTEE OR TRIBE NAAVIE 8. UNIT, FAPdVI OR LEASE NAME North Trading Bay Unit 9. WELL NO. TS-3 RD 10. F~J~D AND POOL, OR WILDCAT Tradin~ Bay,) G~ ~ Hemlock NE Pool 11, SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 34, T10N, R15W~ SM 12. PERMIT 1~0. 68-65 Check Appropriate Box To }ndicate Nature of NOtice, Re: ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI.ETE SHOOT OR ACIDIZE ABANDONs REPAIR V,'~nLL CHANOE PLANS IOther) SUBSEQUENT REPORT OF: WATER SItUT-OFF { REPAIRING WELL J FRACTURE TRleATM~NT --__ ALTERING CASING --i ' SHOOTING OR ACIDIZINO j ABANDONMENT* (Other) RePlace submersible Dumvin~ ipment. (NOTZ: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR CO.MPLETED OPERATIONS (Clearly state all pertinent detailsl and give pertinent dates, including estimated date of starting an}' proposed work. Commenced workover operations 3-14-74. RU and loaded well with diesel. Removed wellhead tree, installed and tested BOP, and pulled tubing and in-hole electric submersible pumping equipment. Picked up and assembled replacement pumping equipment and RIH on 2-7/8" tubing (315 joints). Landed completion assembly with bottom of Reda pump motor at 9633' MD. Installed and tested tree and flowline. Prepared to start pump. Lynes pressure sentry at 9562' MD read 2870 psi prior to pump start-up. Started pump and returned well to production 3-20-74. / 16. I hereby certify thai~-~%%'t~ngJ~tr~ie and correct (This space for 8ta~e omee use) APPROVED BY CONDITIONS OF APPROVAL, IF Al/X: TITLE Bi st. rlrillin~ Sunervisor TITLE See Instructions On Reverse Side DATE AtlanticRi~hfieldCompany North Am,,,---"~'.~ Producing Division Alaska Dis_ ~ Post Office Bo~x 360 Anchorage, Alaska 99501 Telephone 907 277 5637 January 11, 1972 State of Alaska Department of Natura~ Resources 0il & Gas Division 3001 Procupine Drive Anchorage, Alaska 99504 Attention: Mr. Homer Burrell Re: North Trading Bay Unit Well TS-3 Gentlemen: Attached is a P-3 Subsequent Notice of replacing the Reda pump on the above mentioned well. Very tru yours, B. T. Loudermilk Dist. Drlg. Supervisor Attachment DiVISiON REV. 9-30-6 9 S~abrntt "Intentions" in Triplicate ~ ' & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATION; COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-LICATION 'FOR ~-El~i'i'-~' 'for such 'pi:o~osal~.) . , OIL ~ GAS ~'~ WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360~ Anchorage~ Alaska 99510 4. LOCATION OF WF-~LL / At sUrface 618' S & 2068' W of NE Cr Sec 34, T10N,'R1BW, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc. 92' KB 5. AP1 N~CAL CODE 50-133-20133 6. LEASE DIE~GNATION A-ND SERIAL NO. ADL 17597 7. IF INDIA.N, ALLO'i-r~:E OR TRIBE NA3VLE 8. UNIT, FA~hVI OR LEASE NAME North Trading Bay Unit 9. WELL NO, TS } 10. FL~L,D A~ID POOL, OR WILDCAT ~ Tra.8in~ Ba.v G & Hemlock Pools 11. SEC., T.,~R., M.,~ (BOTTOM HOL~ OBJECTIVE) Sec '34, T10N, R13W, SM 12. PERMIT IVO. 68-65 Check Appropriate Box To Indicate Nature o~ N~ti'ce, Re, tort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT -- MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ~ ABANDONs REPAIR WELL CHANOE PLAI~S iOther) SUBSEQUENT REPORT OF: WATER RIIUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDON,MEN'Ts (NOTE: Report results of multipl~ completion on Well Completion or Recompletlon Report and Log form.) i5. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Finis...hed Rig up 1-4-72. Pulled tubing. Cut off & test8d cable to Reda pump. Pulled out of hole w/tubing & Reda pump. Ran in hole w/Reda pump on 104 stands 2-7/8" tubing. Installed tubing hanger. Made cable splice above & below tubing hanger. Landed tubing. Nippled up wellhead. Tested wellhead w/3000 psi OK. Released Rig @ 4:00 PM 1-7-72. 16. I hereby certify tha~he for~oins ts true a.n~ correct SIGNED TITLE Dist. Drlg. Supervisor (This space for State office use) APPROVED BY CONDITION~ OF &PPROYAr', IF AICI'; TITLE DATE See Instructions On Reverse Side State of Alaska Division of Oil & Gas 3001 Porcupine Dr. Anchorage, Alaska PETROLEUM PRODUCTS January 18, 1971 TEXACO INC. P. O. BOX 4-1579 ANCHORAGE, ALASKA 99503 PRESSURE BUILD-UP SURVEY TRADING BAY FIELD TEXACO-SUPERIOR WELL TS-3 ATTENTION: Mr. O. K. Gilbreth Gentlemen: In accordance with Rule 5 of Conservation Order No. 69, the subject Pressure Build-up Survey data is being transmitted. The well was shut in at 1:30 P.M. on December 17, 1970, with a subsurface pressure recording device located at a depth of -9296 vertical sub-sea. Tabulated below are the incremental shut-in time and the datum pressure: Shut-in Pressure Shut-in Pressure Time, Hr. psig Time, Hr. psig 0 700 17 2690 1 1120 18 2700 2 1440 19 2720 3 1705 20 2730 4 1910 21 2740 5 2055 22 2750 6 2170 23 2770 7 2270 24 2780 8 2340 26 2800 9 2410 28 2820 10 2460. 29.5 2830 11 2520 30.25 2840 12 2550 31.75 2850 13 2590 33.25 2860 14 2620 35 2870 15 2640 16 2670 ANCHO~G~ Very truly yours, FAW: bw TEXACO Inc. ~/J. $. Barber District Superintendent Form . , Su~m~t 'Inteations" in T~iDlicate & "Subsequent l{eports" kn Duplicate STATE; OF ALASKA OIL AND GAS CO, NSER'VATION~ ,C~tTTEE .SUNDRY NOTIC*ES AND REPORTS. .ON wELLS (Do not use -this form for prc~po~ls t,o dril! 'or to deepen or p'~ug back t~ a d~ff~e~ent ~e~, om ~ o~s . ~ . w~L~ W~ 0T~a , ,_ ~ - _ , . 'k ~ o~'o~oR TEXACO Inc'. 3. 'ADDI~SS OF 0~ATOB Box 4-1579, Anchoraqe, Alaska 995Q~ 4. LOCATION. OF %VELL ~u~.~ 618' S and 2068' W of the N.E. Corner of Sec. 34-10N-13W, SMB & M 13. ELEVATI'O~S (ShOw whether DF, RT, Gl{, etc. KB = MS L + 92' Check Appropriate Box To I~cate I~ture of NIoti'ce, Re NOTICE OF INTENTION TO : TEST WATER SHUT-OFF ~ PULL OR ALTER CASING ~ FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZ' :1 ABANDON' REPAIR WELL CHANGE PLAN8 (Other) '5. AP1 N~OAL CODE 50-133-20133 T,I~,A,~.i~, DI~,IGNATION AATD SERIAL NO. ADL # 17597 IF INDIAN; AT.T,O'A-r~.U~ OR TI{IBE NAME 8. UNIT, FARM OR ~.~SE NAME State of Alaska: 9. WI~--'L NO. TS % 3 1~. F,-~.,-r) ~ POOL, OR WILDCAT Trading Bay~ N.E. Ii. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, 10N-13W, Pool SMB & "M 12. PEP, blIT NOi 68-65 (Other) NOTE: Report results of multiple completion on Well ompletion or Recompletion RepOrt and ,Lo~ form.) DESCRIBE PR°POSED OR COMPLETED OPERATIONS (Clearly state all perttneut details, and give pertinent dates, including estimated date of starting an}' proposed work, The purpose of this notice is to notify the Division of Oil and Gas that when the tubing was rerun in TS ~ 3 on 10-27-70, the automatic ·shut-in device mandrel was omitted from the well. This notice certifies that well TS # 3 is incapable of flowing oil or gas in any quantity against atmospheric pressure. I hereby ce~ ~~>~°i//Zue &nd c°rre~ / / J'f. ~-S 2 BarDer (This spLce~or State office use) TITLE Dist. Superintendent DATE APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE FAW: j om DEG-Superior Oil See lnstrucfions On Reverse Side ( ) Approved COpy Returned Form P--3 HEV. 9-30-67 STATE O,F 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 "A/~PLICATION FOR PEi~MIT--" for such proposals.) OTHER Alaska 99503 1. WELL WELL 2. iN;~VIE OF OPEHJ~TOR TEXACO Inc. 3. ADDRESS OF OPE~iATOR Box 4-1579, Anchorage, 4.LOCATION. O,F WELL Atsur£ace 618' S and 2068' W of the N.E. Corner of Sec. 34-10N-13W, SMB & M 13. ELEVATIONS (Show whether DF, RT, GR, etc. KB = MS L + 92' Check Appropriate Box To I~nd, i'cate Nmture of NOHce, Re NOTICE OF INTENTION TO: 5. API N~CAL CODE 50-133-20133 6. LF~S~, DESIGNATION AND SERIAL NO. ADL ~ 17597 7. IF INDIA_~q, ALIA)'i-rr~E OR TRIBE NA_NLE 8. UNIT, FAKM OR LEASE NAME State of Alaska 9, W~.',L NO. WATE. SHUT-O~ FRACTURE TREATMENT SHOOTING OR ACIDZ~'ING (Other) ~ TS 9 3 10. FIELD A2qD POOL, OR WILDCAT Tradina' Bay. N.E. Pool SEC., T., R., M.~' (BOTTOM HOLE OBJECTIVE) Sec. 34-10N-13W, SMB & M No~: Report results of multiple completion on Well omp, letion or Recompletion Report and Log form.) 14. SHOOT OR ACIDIZE I I ABANDON$ REPAXR WELL ~ CHANGE PLANS (Other) ~, or :Other 'Data SUBE~QUENT R~PORT OF: REPAIRING WELL ALTERING CARING ARANDONME~T* DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an.y proposed work. 1. Rigged up and pulled the existing tubing· 2. Reperforated the following intervals: 2 - %" holes per ft. · "G" Sand: 9710 9770 Hemlock: 9910 - 10,060; 10,070 - 10,090 Reran tubing with bottom-hole electric pump and returned well to produc~ion. P!V!rqON OF OiL AND GAS ANCI-IQitAOll (Thl~ space for State office use) TITLE Dis t Superintendent DATE APPROVED BY CONDITI~ON8 OF APPBOVAL, Iii~ AI~I~: TITLE DATE 11/2/70 RDF: jom 11/2/70 See ln:strudions On Reverse Side Approved Copy' Returned .... · 1,~aY '20, .... 1969 ,,. - - .- . - ?.. ....... .._--~ . .~'-~ "..~ ....-- 'v ~ Division o-s_ Oil ~:~,_~'*~ Gas ~ ' - ...... ~--~, Azaska 99~0e . , TEXACO' INC. . . P. 0..BOX l[164' ANCt-101AAGE. ALA$I(A 9950f _ . . , :" ':--TRADILNG BAY TS ~2 TRADING BAY TS Dear · ~:..'!r o Butte!!: in accordance with your four letters da-ted May 9, 1969 requesting certain ~n~o?mation and reports pertaining to the =' ' !lowing: - four captioned we!!s~ enclosed please ,_rna the fo Directional Survey Electric log, sepia Dir act '!c:.:~a ! Suzv.e':~ ~ ~-~c~,_"='~ ~ ..... ~-: ~ lea.,: sepia '/_:!::~::~2:::Z:~z':c:m:~.: Or,.e copy -~"-"' '""'--'-'"'" well history SaDi-~ o:- s zo~ of or':.cjinal hole One copy ckronolcgica! ~ ..... 'gOrY SUBMIT IN DU~ ATE OF ALASKA OIL AND GAS CONSERVATION cOMMITTEE .'ti - on side) WELL cOMPLETION OR RECOMPLETION REPORT'AND LOG* ~ II I1' la. TYPE OF WELL: OIL ~'~J]~,~S ~-~ WELL WELL DRY Other b. TYPE OF COMPLETION: V;ELL OVER EN BACK RESVR. Other 2. NAME OF OPERATOR TEXACO Inc. - ~-. i , 3. A~!DR~SS O~r OPERA?OR P,O. BoX 664, Anchorage, Alaska 995_0-1 5. LOCATION OF WELL ('~Re~.ort ;ooat{on ~]e(~i'~g ~d {~ ~cor~;~c~ ~{~ ~g ~;~ req~{~e~8) ~,,u~=e 618 ' South 'and 2,068' west of ~-N0rtheast corner Section 3~,-T10N-RI3W, S.M. .~ - -. t top prod. inte~al reported: ~e~ow :- ~ .... 558' Sou~h '~d 590" West of N.E. cornier ~,Sec~ 34, At total dep~ ' ~--~3~ 557'/Sou~h and 560i. ~e~t of N.E. co~r SeC. d. 34, 50-133-20133 L~ nr~k~o~' ~D S~L NO. ~ ADL ~17597 ~ · 8. UNIT FA.R1VI OR LEASE NAME state of Alaska 9. WELL 2{0. TS 10~ FIELD A~FD POOL, OR WILDCAT Trading Bay 11. ~EC., T., R., M., (BGeI~OM HOLE OBJECTIVE) Sec. 34, T10N-R13W, S.M. 12. PI~L~IT N'O, T10N-R13W_, SiM. ~ : ~.~ _-. , 68-65 8;2'1-68' [ 11-16-68 [' 12-5.68 ' :--~ :'~1 K.B:. :~= MSL + 92' ] 32' K.B. &UZDU ? ~ - 'l &~O~': ~ ~,,~ .." I ~W~ :;' 'l ROTARY TOOLS I CABLE TOOLS Inn,ga' ~' . J--~0033-~ ~, ~- ,[ ~O, ' m~ ~ .~J All [ ~. P~uCIHG ~V~(S), OF ~S eo~TIQ~P. BO~M, N~E i{~ A~ ~)* J~. W~ DI~E~OHAL .... } SURV~ ~DE 9710'-9885' M.D' -"G" san'd ' 9908' ~' ~D154 '~ Hemlock Sand I ' ~ - :-~ ~ Yes 9555 '-9?29' "~.V.D. "G" ~anfl 9752' ~ 999~> ~D Hemlock Sand. ' C~G ~ (~e~ all ;strings s~ in w~ll)- : :'~: 13-3/8" [" "54,5-[-.J~55[ 1370'' I t7~5" . .,~00sx. ciasa .:' '9-5/8" [43..5L53.~-.N~P:/[ 10~42'~ [ i2~'~'.'': ~100sx. Cla~s G . , [:' ' '-. ~' '[ :' [ 3212'- ] ~2~"'. la00sx. Class g (s~a~te job) ---, '- . .' ~ ': · . : , ,. · t.- ]2~'.'NOM I 9690' 9618 Dual 28. PE~O~TIONS OP~ ~ PRODU~N (inte~al, size and 'num~) ~. i~;~ ACID, SI-lOT, F~'~, C~T SQUEEZE, ~C. 9710-9770, 9780-9880, 9826-98-56, ~D~-~mv~(~) {~o~'r~m~o~m~u~ 9866-9876, 9908~10058, 10069'10124 ;10113' 235 sx. Class G 9881' 125 Class G 4-1/2,' holes per foot. ~. .. ~. ~ODU~ON - D~ FIE.ST P~DU~ON ~ ~ODUCTION METHOD (Flowing, gas 1if. t, pumpm'~--size and type of p~p) . , - . silut-in · 12-7-68 [ Flowxng - (See reverse for separate zone~) ~producxng : ~1~ -7-68, ~4. 90/64. ~ '~. [~,. ~19.90.. - ] 489 [ 2 245 S~G P~S~ C~~_ OI~BBL. GA~ff. WA~B~, [OIL GRAVI~-~ (C~.) 75 Psi I 0 ] ~ [ 19.90 l: 489 I 2 w El 36.5+ 31..DiSPOSiTION O~ OAS (SOld, used ]or fuel, vented, eta.) : _ rE~ 1T~ ss~T~ne~ -- Vented ., J. L. Mahaney ' 82. LIST OF ATTACHMENTS Complete D.I.L. log, C~pleto Di~0~ona1 Survey s~ ~ h~s.,~g. D~st. Supt. ~ ~-2-6~ ~ *(See ~..~,.cfio.s ~.J S~ce. [o, AJgifio.~[ Dm~ o. Reverse JGC:jm INSTRUCTIONS -:General: This form is designed for'submit'ting-a compete and correct well completion repori and Iog.'on . . · . ~ll:tyf)es of lan.d~, and le'ases in Alaska. -.Item.il 16: Indicate which elevation is Used as ¢'eference (where not otherwise shown) for depth measure- kmen:~'s given'..ln other spaces on this :form a'nd ir)~any attachments .... "items 20'; a,~ :22:: If'th~s well is comp.let.ed for ~separato production from more 'than 'one interval zone .. · (.mul'tjple ..Conlpietion)., so state in item ,2Qf,?nd in item "27 show the producing interval, or intervals, 'top(s), bottom(s)' and 'no;rna (s;) (if any) f®r~ only '. the interval: reported in item 30. Submit a separate re~ort (page) on .th~s form, adequately '8~nt f'led, for each adC, d'~onal ~nte vol to be ,separately produced, show- lng .the* additional data pe~;tin~ii};'!;o such ,interval. · , Item26: "Sa'¢ks Cement": Atta0hed supplemental records for this well should show the details of',&ny mul- tiple stage cementing and the Ioc¢ion of'the c~menti'ng tool. . " Item'28: Submit a separate compl~tio6 report.on this form for each interval to be separatel, y produced. (See instruction for items 20': and 22 above). · ....~ . ~'i~Y OP. 9"O{:~¥IATION '~TS II~LUDtN(] INTF-I-{VAL TINTED, P~UR~ DAT~ ~ ~OM~I~ OF O1~, GAS.- ' ' ........ " j '' .... ~ ~ '.J ~,-': 35. .'~GIC M~RK~ : .'~ ' WAT~ AND M~D , .~; , , , . .... ; .,, ' ~AS.. "G" Sand; 1127 B0'PD}):: 1 BWPD, 313 MCFPD, 90/6.4 .choke ";"" ' .."~' -. ' · . · 75 psi .~ubSng pressure; ..36.0'A.P.I. GR., 277 GCC. Hemlock.. ...- 9908' 975'2' ,. ..~, , , ~ . HemlOck. Sand;. 863: BOPD, 1BWPD, 17'6MCFPD, 90/64 choke '". ' '" '; 75. PSi tubing pressure, 37.5'.A,:P.I. ', GR~ 203 GOR. ' >~ ' ': . . ; ": .. ~ , , , , -. 'jAND DETELn'ED SHOWS' OF OIL, G~O~ WA~. , ~~ . . -, ., . . _ TEXACO INC. Well History T-S ~3 Trading Bay Platform "A" MORNING REPORT SUMMARY Note: The daily morning reports cover the time interval from shout 7:00 A.M. of the previous day to about 7:00 A.M. of the day recorded. Date & Depth Footaqe Remarks s-20-6s (0) 0 Started moving on location at midnight. Skidding to Pile ~,1, Leg lA with Rig 15. 8-21-68 (129) 437 Spudded at 12:01 A.M., 8-21-68. Drilled out the pile with a 12-1/4" bit followed by a 17t~'' reamer. Mud 72 PCF. 8-22-68 (654) 1091 8-23-88 (309) 14.00 Drilled with sea water to 350'. Changed over to a mud system and lost circulation for 2 hours drilling below 762'. Drilled a 12~t~'' hole and reamed to 17t.~''. Circulated clean and prepared to run casing. Mud 67 PC F. 8-24-68 (0) 1400 Ran 34 joints, 13-3/8" 54.5~, J-55,Buttress casing with a shoe at 1379' and s collar st 1339'. Cemenned with 800 sacks API Class "G" cement with 2%~ CaCl2 mixed with sea water. Good circulation~ but no cement returns. 8-25-68 (94) 14.94 8-26-68 (1168) 2662 Cemented the annulus through 1" pipe at 271' with 1~0 sacks of Class "G" cement with 2% CaC!p. Cement returns to surface. In- sta!ied-i3-3/8" casing pack-off, installed 13-5/8" 3000 psi BOPE (2 pipe, 1 blind & Hydril) -~= ~,~'~ested. Tested casing to 800 psi. Drilled out the collar and shoe and to 2127' with a ~-7/8" bit. Jumped a pin while drilling (3-~ stands down). Screwed into fish with a new joint and recovered fish. Mud 68 PCF. 8-27-68 (639) 3301 Drilling a 9-7/8" hole. Mud 71 PCF. 8-28-68 (130) 3431 Drilled a 9-7/8" hole to 3431'. Opening CEIVED 1969 Well History T-S Trading Bay Platform "A" Date & Depth Footage s-29-68 (0) 3431 8-30-68 (i00) 3531 8-31-68 to 9-7 -68 7077 (3546) Remarks [,~.~ile reaming the hole opener torqued up. Pulled out and ran in a 12-1/4" drilling assembly. Drilled_ 24' and stuck while drill- ing. Worked stuck pipe 4-1/2 hours. Ran free point and free 60' off bottom. Backed off leaving a monel anc~ 3 drill collars in the hole. Ran fishing tools and jarred loose. Recovered all of fish. Ran 9-7/8" drilling assembly to 3216'. 2io!e bridged. Reamed to 3431'. Pulled out and ran in with a 12-1/4" hole opener and opened to 3400'. Assembly torqued up. Pulled out and ran in a i2-1/-2" drilling assembly. ~lud 72 PCF. Drilling a 12-1/4" hole. Mud 72-77 PCF. 9-8 -68 to 9-14 -68 7702 (625) Drilling a 12-I/4" hole with directional difficulties. Mud 72-75 PCF. 9-15-68 7761 9-16-68 to 9-23-68 8465 (59) (704) Drilled to 7733'. Ran dynadrill ~6 with a 9-7/8" bit and lost a cone at 7761'. Ran a 12-1/4" bit and drilled on cone. Mud 74 PCF. Dynadrilling a 9-7/8" hole followed by a 12-1/4" bit run. Mud 73.-75 PCP. 9--24-68 8525 9-25-68 8525 (60) (o) Ran dynadrill ~12 to 8525 with a 9-7/8" bit. Ran Schlumberger DiL and HRD io9~s. Mud 74 PCP. Ran 12-1/4" bit and reamed to 8525'. Stuck TEXACO INC. Well History T-S ¢~3 Trading Bay Platform "A" Date & ~Qe Dtl~ Footaqe Remarks 9-26-68 to 10-3-68 9A93 (968) pipe while surveying' and jarred loose. Tight hole for 50 stands. Mud 76 PCF. Drilling' a 12-i/4~' hole. Badly keyseated 5000-6000~. Mud 76 PCF. i0-4-68 to 10-8 -68 9918 (425) 10 -9 -68 9958 (40) 10-10-68 to 10-12-68 10340 z0-13-6s !0458 10-14-65 10458 (382) (118) (0) 10-15'68 (P.D.) 5165 Drilled a 12-1/4" hole to 9916~. Ran 8-15/32" dis/aond head core assembly and cored from 9916' to 9918'. Recovered of core. Mud 77 PCF. Reran the core assembly and cored to 99A4~. Recovered 21' of core. Re~ed and drilling a 12-1/4" hole. Drilling a 12-1/4" hole. Tight hole first 10 stands and keyseats 3500-5500'. Mud 76-77 PCF. Drilled to !0458'. Ran Schlumburger DZL and HRD logs, and side-wall s~mp!es. Ran in open ended drill pipe to !0456~ and displaced 225 sacks of Class G cement mixed with inlet water. Pulled to i0i00' and displaced 300 sacks Class G cement mixed with inlet water. Pulled to 5389' and dis- placed 400 sacks Class G cement with t0 sacks of sand mixed with inlet water. Ran a i2-I/4.~' bit to hard cement at 51~5'. Cleaned to 5208" and circulated mud. Mud 76 PCF. RECEIVEI) MAR 1 ? 'i969 OIVI$1ON OF OIL AND GA~ ANCI-IO~.GE TEXACO ~eil History T-S ~3 Trading Bay Platform "A" Date & ~epth Footaqe 10-16-6s (56) 5264 10-17-68 (161) 5423 I0-!S-65 to 10-25-68 6858 10-26-68 to Ii-2 -68 8494 11-3-68 to 11-10-68 9700 11-11-68 9768 11-12 -68 9800 11-13 -68 9000 11-14-68 to 11-17-6oo 10250 {!435) (1636) (1206) (68) (92) (o) (290) Kicked off the plug at 5208' with a 12-I/4" turbo dr i ! !. Turbodriiled a 9-7/8" hole followed by a 12-1/4" bit run. Mud 74 PCF. Dri ~ ~ ' " - ~±mng a 12-1/4 hole with ~ntermittent 9-7/8" turbodril! runs. Mud 74-77 PCD'. Drilling a 12-1/4" hole with intermittent 9-7/8" turbodriil runs. Mud 76-77 PCF. Drilling a 12-1/4" hole. Mud 76-77 PCF. Drilled 12-1/4" hole to 9756'. Pulled 21 stands and the clamp came off 'the dead line.~ dropping the blocks i0' to the floor. Re- paired minor damages and continued operations. Mud 76 PCP. Drilled to 9860~. Driller pulled blocks into fne crown while pulling out of the hole. Lowered blocks to floor and unstrung the drilling line. Mud 77 PCF. Changed out crown .blocks. Resumed operation. Drilled a 12-1/4" hole to i0,250= T.D. ~an Scn±umberc~er Dz~, FDC, SNP, BCS, and H?S logs. Mud 76 PCF. RKE YED 17 969 DIVISION OF OiL ~1~ Well History Trading Bay Platform "A~'~ DIVISION OF OIL AND ANCFi~E ~'hh Footaqe P.~.narks iI-~°zo-~° (T.D.) 11-19-68 11-20-68 11-21-68 11-22 -68 $~ung i0 lines. Kan in and circulated 3 k~"." Mud 76 PCF. '~ 9--5/8'' ~ ~ ....... Ran 250 joints o~ , =~.~:~?m to 53....-~, LT&C and buttress, casing wi~ a shoe at 10242', float collar at 10195', stage collar and metal " ~ ' . pete± basket at 3212 wmth 20 cen- tralizers on the following joints: i, 2, 4, 6, 8, !0, i2~ !4~ 2!, 23, 25, 27, 31, 33, 179, 180, 216, and 217. Pumped through tine shoe with ii00 sacks of Class G cement with 1% D-31 retarder mixed with inlet water preceded with 100 cu. ft. of inlet water mixed With 4 sacks of acid pyrophosphate. Bumped the plug with 1800 psi. Opened the ~age collar and cemented with 1200 sacks Class G c~ment as above. Good returns but no cement to surface. Installed pack-off, wear bushing and tested B.O.P.E. Ran into stage collar at 3262', float collar at 10188'. Ran Dresser-Atlas bond log. Shot 4-1/2" holes at !0t13:. Set Baker squeeze %ooi at !0i37~. Pumped around through shoe with 2700 osi "~'~ ....... _ . ~.~ squeeze tool at 9940' down at 3000 psi. Put 1500 psi on annulus. Squeezed "~ wi~n 235 sacks Class G neat cement and : ~ ' __ ~ mzeakeow~: ~900 psi _.n±en water. ?';hal ~ ~ ~"' .... . Pulled out. Skor 4-1/2" holes at 9881'. P~'~ and set squeeze tool at 9770 down 8 cu. fi/min, at 2000 psi. Cemented as above with 125 sacks. 2800_psi at 2 cu~ ft./ min. Pu]_~=m:-~ the squeeze tool loose, moved 3' and stuck. Able to pump ~ - ~ e!O~i%G tOO!. 11-23-68 Ran Dialog. indicated free to tool. Backed T~XR, OO iNGo ?Yell Di¥1$1ON OF O~L AND ~A$ Date & p .... se~ '~ootage 11-25-68 t i ~26-68 Ii_2~ ~, off 60~ above noo±. Ran in wz~n jars bumoer-sub. S '~ ..... ~ ' ' -- · c.~;~ mn~ jarred !0 times jars stopped woricing. '.~acked off 60 ~ up. 'C~ o-1/2" Ran 3 joints 8-1/8" wash over pipe wi'-~ tungsten scailo~o t. ype shoe. m',~-,nger cf cement 24: ~so~e %ool. Milled i~ over top of tool. Pulled out. Shoe worn .... Ran ir. with ju. rs sczewee into fish and ~ ......... ~ 7 hours. -~ressured annulus 'ho 2500 and jarred loose° Recovered fish and ti:in ~e~m inside packer Ran a flat pieces' o'f ....... ~ . 8-1/2" omi an~ ~.~..~g scraper. Drzzze~ cemenm from 9796' to 9936~. ~.~u~ed clean and tested casing. B d pumped away 5 cu. ft./min, at 2900 psi. Ran in a Baker model. "K~ retainer %o 9736~ squeezed wi'Lb 4 cu. ft~/min, at 3000 psi. Pinai rate 1 cu. ft./min, at 5000 psi. Estimated top of cement 9829~ with 19 cu. z-c. ~z~ lng. Ran a 8-1/2" bit and drilled out the retai, n:2r at 9,00 . Cement at 9746~ s~ccessG-~l I~' e -~.- ~.~ - --3 ~oueu eno caszng to 3000 Ran to i0010~ and drilled hard Ran to iOlos $.no again tes%ed cas~ng. lated clean and ~ou!led ou-h. -- Ran in 8-1/2" bit and casing scraper to i0i69~ Circulated for 2 hours. Spotted 75 barrels of IMC oil base mud. Pulled built mud fromoo~' to 7! PCF. Ran Baker oiu~x on wireline and se% am zo~oe pulling out, running %ool hung up at 2!50~ and oar'ted tlne line in the derrick. Pish con-- sists of running tool and 2150' of 7/16" wire- line. ANcHotiAGE il-29.-.88 12-1-68 -o ,~ · wire i'~-'-' . S[:>~}ared ,_.:~ at .~,a.. lt..' _.~,s spear 9i5a~ 'o~,'~!ed 26 stands with ~a~'~ ~os~" z~'=~ :~)'~ z:u~ ied out and found _~orox~is_ mis~ing~ ~ '~_ ~ ~r ~- ed .... ~oel and reran Speared fish at 92%s~. Pu!iea out and re- ceverea about 500~ ef wire line. Reran spear and ens~g~d -${ s'i': e-c 9330 ~ '~uI ~ cd out f~ ' '~' with '~ 0~ 000-i4- 00~ ~,~-.c' Re de'- of wir~ li,~} ie-Ft ~ ....... r',.tnnincf and Dr~s~Attas collar locater ' assembly hole. Rigged wire line and tagged bet%om ?~'~ ceslng scraper and tagged 10186 ~ Back "" ...... ~ ~ ~ s,.u~ied ho~ czean and spotted - ~'--' ~ ~ ~'~i On bottom. magnesium bridge plug ;and set at i0!76 %-1/2 ~' homes ..... ~. r'C ~ {Konesno'6 ~,'.s2'-:._ carrier guns .... a~' znterva~_s' ' Srorfi- 977n:~ 'ho i0 E-Log dep{:hs, iran Oresser-A%las stab-in {tillable ..... ~ .......... ?roctu:c~o~z packer, model ~,~': ..... , line at 9890' ~-~os ..,~ ..... set on ,,~ .o ~- c, ',-~?~,,--', Pul'" bowl pro'cec'~or, installed 2-7/8" rams and' rigged accessories. ~"-- Running leal o accessorzes. in.'-'~-~iied~,~., Kms~s tree and 'res%ed xe,areived dez,~u,! s.~tze._y valve in long ran in and ~h .... s,.zf~aeo sleeve open in trna sZring. ./. ? I96.9 DIVISION OF OIL AND GAS !36. :}th Poet a~: e 12-5-65 Changed over .... choke z!.8/64~.~ '!'.P. 55 psi. TS-3L 124. pure diesel. Skidded and winterized '"< o' ~'rcduc'tion ..u~, 0 oo/ is .o APZ .o,,,o emu ion, 36 '~-.~ ~ ~ ~ - r"~o Q? 0.3% wa'her 0 ~% ,,..~,~4~ ~:/ ~ ,,..~-.- ,-.., .,.-~ 7~ ps~, ~0/64. cno:e. Long S'hring: Otis Ball Valve Camco R]i~X Mandrel V? ~amco ..~ Camco 315 ft. 870 !''- 2882 ft i0~n.~- Z./_~.~ z~. ft .il~r, .... .-, .,::,. 5538 --~.~'.,.~:. 7637 987'~ ft i{{-2 Pkr 00110% o.,-.'.. ..... - .... Sleeve,., = ~-5/$¢ "A' Driiiable ~'~,~,.~. W/O i,'lapper 9679 ft. Otis Shear Sub. 2.50 Otis Ball Valve Camco iKBPi !landre! Camco H!SPi Mandrel Camco KBM Mandrel Camco 1~}4 Mandrel Camco XBM Mandrel Otis "OX" Sleeve 55 S 7 6606 9607 9659 MAR 1 ? ?969 DIVISION OF OIL AND GAS ANCFIO~AGE 'TEXACO INC. WELL HISTORY - NEW -WELL AREA: Trading Bay, Alaska WELL NO.: Texaco-Superior Trading BaY State TS TRM (~,~" OKG K,v HWK REL ~---., z..,, . FILE , - FIELD.: Trading Bay Field LOCATION: Surface: Trading Bay Platform "A", Leg lA, Pile Hi, or 618' South and 2068' West of the Northeast corner of Section 34, T10N-R13W, S.M. ELEVATION: K.B. is 92' above mean sea level. DATE: ~sst~ District Superintendent DRILLED BY: Loffland Bros. Drilling Co. DATE CO~qENCED DRILLING: 8-2 1-68 DATE CO~PLETED DRILLING: 11-16-68 DATE COMPLETED WELL: 12-5-68 RECEIVED MAR ! ? 196q ____ ~..,~iVI$1ON OF OIL AND GAl DATE OF OPEN FLOW POTENTIAL TEST: N.A. c ~ ~.(~'~' . ANCH~GE SUMMARY TOTAL DEPTH: 10,250' PLUGGED DEPTH: 10, 189 ' CASING: 13-3/8", 54.5~, J-55, Buttress from surface to 1379 9-5/8", 43.5~N, 47~ N&P, BUTT. & L.T.&C., 53.5~N, LT&C. from surface to 10,242'. %~EZJ~C O iNC. Well History ~3 T-S '~ Trading Bay Platform PERFORATIONS: (E-Log Measurements) 4-1/2" Dresser-Atlas perfs/ft. 10069-10124 9908-10058 9866-9876 9826-9856 9780-9800 9710-9770 WELL SURVEYS: Original Hole: Redriil: 1) Dual induction-L~terolog 1380-10456 2) High Resolution Dipmeter 1379-10456 1) Schlun%berger Dusi 2) Schlumberger 3) Schlumberger 4) Schlumberger Induct ion-L~, tez o log High Resolution Dipmeter Borehole Compensated Sonic Log Compensated Formation Density Log 5) Schlumberger Sidewall Neutron 5090-10250 5000-10246 8000-10240 8.990-10246 Porosity Log 8000-10246 NOTE: E-log depths - 17.0' = Pipe depths I CEIVED MAR ! 7 1969 Di¥1$10N OF 011. AND OAt 7-24-79 7-25-79 7-26-79 TRADING BAY ALASKA DRILLING REPORT T/S #_3 PLATFORM "A" Moved in and rig up. Displaced hole with 700 bbls. of 739/ft3. Removed wellhead. Installed 12"-900 series BOPE with double rams tested @ 1000 psi. Pulled out of hole with 20 jt$ of 2-7/8 tubing. I 2 EO[ .... 1 a' EOt I STAT I STAT TEC I CONFER~ '- FILF: 7-27-79 Pulled 2-7/8 tubing and Reda pump. Ran cnl log 10099' to 7049', perforated with 4-1/2" jet holes/ft 9263'-9248'; 9167'-9152'; 7-28-79 Perforated 9022'-9002'' 8875~-8870'. Made up Reda pump. 7-29-79 Ran in hole with 2-7/8" tubing landed Reda pump at 8712'. 7-30-79 Removed BOPE, installed'and tested tree to 600 psi Started up Reda pump and released rig and crew at 6:00 p.m. BFPD 1152, 99% cut with B.H. pressure at 3992 psi. 7-31-79 8-1-79 Reda pump 1128 BFPD, 99% cut, TP-325 psi, 225 amps, BHP-3390 psi. 8 AM report: Reda pumping at 1800 BFPD rate-100% water. TP-300 psi; CP-900 psi and increasing. 10:30 AM report: Well flowing thru casing annulus (oil, water gas) while Reda pumping thru tubing. Rate 1500 BFPD, no cut. Casing on 40/64" choke and heading bad. TP-1225 psi (on choke) CP-950 psi. Too muCh liquid and gas to go thru test separator. 7:30 PM report: Reda pump has been shut down but flowing well thru tubing and casing· Turned well into test' separator with 45/64" choke· Rate: · TP-250 psi 360 BPD with 95% water cut CP-1050 psi, , 1425 MCFPD gas, rate fairly stable but well still heading. ECEIVFD 8-2-79 8-3-79 8-4-79 8-5-79 8-6-79 8-20-79 8-21-79 8-22-79 8-23-79 8-24-79 8-25-79 8-26-79 Reda pumps shut down at 10 AM 8-1-79 due to gas heading and production rates overloading gas handling equipment. In test for 17 hours flowed 9 BOPD and 855 BWPD, 99% water cut, 1200 MCFPD, TP on 50/64" choke- 100 making preparations to kill well with salt water. Shut in tubing and pinch down choke on casing while flowing well. As of this AM TP-0 psi CP-175 psi while flowing only trace amount of liquids. Continuing to bleed off gas. Drop bar and circulate 70 pcf salt water down tubing and up casing annulus to kill well thru choke. Circulate 70 pcf salt water and killed well. Well dead. Circulate total 700 bbls. Well SI making preparations to pull well and test new perforations to shut off water and isolate gas zones. Drop from report pending start up Monday 8-28-79. Mixed and pump 200 bbls. 70 pcf salt water down tubing o Installed BP valve, removed tree, installed BOPE and tested with 1000 psi. Rigged up to pull tubing. Pulled out of hole with Reda pump. Ran in hole with 9-5/8" casing scraper. Tagged fill @ 9640'. Pulled out of hole. Laid down drill< collars and scraper. Ran in hole to 9500' with drillable bridluqg_R~_q_~_~ Pu~e. Ran in hole with a ievable bridge plug and set at 9210'. POH. Ran in hole with Halliburton DST 91 with inside and outside recorder and a 5/1 ' choke. Formation Test 91 (no cushion) Halliburton set packer @ 8805' tail to 8817', tested line to 1300 psi. Open~ DST 91 (8870'-8875' 9002'-22' 9152'-67") at 1:19 PM with strong blow, gas to surface 1:36 PM. Turn into test separator 1:45 PM 300 psi TP open to 1" choke at 2:00 PM, Tp !00 psi, unload 18 bbls. H O. Flow gas at 810 mci. ~ and 200 psi TP on l"choke2(5/16'' downhole choke). A~o 5:00 PM ~9wing dry~ gas ~at ~!850 mcr ~ on 1" choke 200 psi TP change to 1/4" choke TP 1050 psi 1320.~mcf.~y. gas. Shut in at 6:05 PM, reversed cir- culation until dead--no oil-- pulled packer loose at 6:30 AM 8-27-79. 8-27-79 8-28-79 POH and laid down test tools. RIH with retrieving tool to retrieve BP at 9210'. Pushed down hole 60'. Recovered and POH. Top inside recorder. IHP 4206 psi IFP 1598 psi, FFP 2351 psi, SIP--3862 psi. Bottom outside recorder. IHP--4240 p~~~-J-1600; FFP-2388 psi; SIP 3869.R~_~. Ran in hole with DST ~2 (9263'-9248') set packer @ 9210' tail @ 9222'. No cushion. Tested line to 1300 psi, open at 2:30 PM, strong blow then dead, at 4:00 PM. Reversed out tubing, recovered.328 bbls. of salt water. No oil. Pulled plug loose and circulated. Pulled out of hole. Top inside recorder: IHP 4396', IFPO-, FFP 4289', SI~P.~~' FHP 4396' bottom outside recorder: IHP 4396'. 8-29-79 Ran in hole with Halliburton Easy Drill Retainer. Set @ 9210' pressure tested line to 3400 psi breakdown 3BPM @ 1500 psi. Mixed and pumped with Halliburton equipment, 100 sacks class "G" cement, mixed with filter inlet water. Squeezed. to final pressure 700 psi. CIP at 5:50 PM, reversed out 5 SX cement. 8-30-79 Pulled out of hole. Descaling and drifting. 8-31-79 Finished pulling and cleaning scale out of 2-7/8" tubing. Ran in hole with 50. stands and shut down for the evening .. 9-1-79 Shut down. for Labor Day. 9-2-79 Idle. 9-3-79 Idle. 9-4-79 Ran Otis Packer, stop. at 6270'. Pulled out of hole. Ran in hole. with casing scraper to 8830' with no interference. Pulled out and shut down for the evening. 9-5-79 Ran 289 Jts' 2.-7/8" OD 8RD E.U.E. tubing with Baker FH hydrostatic packer set @ 8804', Otis XN nipple @ 8814 and Otis XA sliding sleeve @ 8767', Otis Ball Guide @~ 8819', with Otis XL Safety Ball Valve nipple @ 310'. Tested Ball valve up to 5000 psi, remove BOP. Installed Cameron. Series 900 christmas tree. Tested to 3000 psi.for 15 minutes. Ran Otis wire line tools. Pulled dummy valve and set Otis blanking plug in XA sleeve. 9-6-79 Tested tubings and christmas tree valve against -blanking plug to 3000 psi for 15 minutes. Recovered blanking plug. 9-7-79 Pumped 55 bbls. filtered water down tubings. 9-7-79 Dropped ball and pressured up to 2200 psi sheared (cont'd) seal or seat and pressured up to 600 psi. Set 3/8" Otis down hole choke, in Otis XN nipple @ 8814'. Well didn't flow. Open sleeve and pressured tubings to 1500 psi (gas compress) and closed sleeve. Installed ball valve. Well began to flow after 3 hours. Unloaded tubing. Shut in pressure @ 2900 psi. Closed ball valve and shut well in. 9-8-79 to 10-2-79 Idle. 10-2-79 Moved in and rigged up hydraulic line and pump for test. Bleed of tubing to 1000 psi. Pressured control line to 6000 psi. The ball valve equalized and open. Checked operation for safety tubing ~h~ in~r~.e~ssure @ 3236 psi. Flowed well for 1-1-~/~6~§r~~a 1/4" op-~-~%~'choke. The well flowed steady @ 1891 psi and 2851 mcf/d. Shut in for build up: 15 min. - 2565 30 min. - 3045 45 min. - 3178 60 min. - 3218 1 hr.40 min. - 3228 6 hr.40 min. - 3234 10-3-79 Tubing pressure @ 3234 psi (16 hr. SI). Flow period as flowing-. Flow period Choke size 2-1/2 hrs. 1/8" 4 hrs. 3/16" 4 hrs. 1/4" Stab. flow period tbg press, mcf/d rate 1 hr.. 282.2 1008 1/2 hr. 2210 1811 3/4 hr. 1750 2567 Remarks: First 3 hours intermittently dry to heavy medium and light mist. Last hours light mist to dry. Probably all completion fluid. Closed well in and moved off. 10-5-79. EGR mn: 1/4 PRESSURE SURVEY :,~ ~ . COMPANY _ ~.j~ - FIELD I LEASE COUNTY OR PARISH MEASURED DEPTH FROM K.B. (fi'.) DEPTH TVD ( FT. ) DATE AND/ OR TIME ~o O~oo EXTENSION (INCHES) W ~ ~ SA N~D PRESSURE (PSIG) PRESSURE CHANGE ( PSIG ) GRADIENT PSI/ft. · _To~ o INSTRUMENT NUMBER LAST CALIBRATION DATE DATE OF LAST SURVEY ~LAST MAXIMUM "-TI'~I~ MAXIMUM i,M CHANGE SINCE LAST SURVEY ~.LCULATED BY REMARKS GRADIENT BASED UPON TRUE VERTICAL DEPTH FEB 8... ~71 OiVIS~O*! OF Oft A,~!o GAS A~JCHORAG~ · ~.:::~j~~'~:~L.:, BoX '~ C'~O~O~'~Z'~LTE LE PHoN'E~Z?'"~O'~/J~r~'o~'~Z~'~"~" 0~" /~~~, p.O. 4-1276 (907)-279-4014 ANCHORAGE INDUSTRIAL CENTER ~ ........... ~\ AnChorage, Alaska 99509 274-3364 5633 B Street ~'LL I~O- COU~T~, WATER ANALYSIS REPORT Texaco, Inc. DAT.~ 9/20/79 ~ NO TS No. 3 LOCATION Platform A North Tradinq. Bay FORMATION Alaska INT!~RVAL S,~PL~ FRO~ .... lower test interval 1 538-1~ Sample taken Auqust 28, 1979. ,~ ...... 9629 41 8.87 s~m,~, ...... ~ 244 6.25 c~, ....... 2-6300 ~ .......... 6 R 22 ~ ~-i~:~ ..... 0 ~ ..... ~] n.~ ....... 2.63_ ~~m,~, ..... 523 L-~ ...... H.:nlroxt~ ..... - - - 141.66" ___ 17.42 759.50 · ~',~ ~ ~n,~ ~-..~n ..... 43349 ~C~ ~~.~, =..~,'~ qL-Sr2-53 ob,,~,~,,,~ ~t-] . . 6.3 %:Vi~T2:R ANALYSI3 PATTU, RN 200 N~ HCO, 20 C~ -- SO4 20 CO 3 2 0 F~ C1 HCO~ S04 CO~ CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 Anchorage, Alaska 99509 TELEPHONE (907)-279-4014 274-3364 ANCHORAGE INDUSTRIAL CENTER 5633 B Street Company. Well No. Field County State Line pressure______psig; Sample pressure_ p~ig Temperature Remarks Sample taken August 26 1979; , @ 1715 hours. GAS ANALYSIS REPORT Texaco, Inc. Date. 9/20/79 TS No. 3 .Location__ Plattorm A North Trading Bay Formation Depth .. Alaska .Sampling point 3 upper zones __o F; Container number Lab. No. 1538-2 Mole % or Component Volume % Oxygen ........................................ 0 Nitrogen ' 0'6'?" Carbon dioxide ................................... Trace Hydrogen sulfide .................................. -- Methane. 93.33 Ethane..i&]ihlilg.'h.'elr.'iiiiiil][]iiiil]iil]i]]il]il]i' ffrace Propane ........................................ I$o-butane ...................................... N-butane ....................................... Iso-pentane ...................................... m-pentane ....................................... Hexanes ........................................ Heptanes & high_er ............................. Total ............. l 00.00 per MCF GPM of pentanes & higher fraction ........................ Gross btu cu. ft. @60© F. & 14.7 psia (dry basis) .............. Specific gravity (calculated from analysis) ................... Specific gravity (measured) ............................. Remarks: 943 .... o.582 0.582 CHEMICAL & GEOLOGICAL LABORATORIES OF ALASKA, INC. P.O. BOX 4-1276 Anchorage, Alaska 99509 TE LEPHON E (907)-279-4014 · 274-3364 ANCHORAGE INDUSTRIAL CENTER 5633 B Street Company, Well No., Field Count. State. GAS ANALYSIS REPORT Texaco, Inc. TSNo. 3 North Trading Bay _Formation ,Depth A1 aska Sampling point Date 9/20/79 Lab. Nd. L538-31 P"latfo~m A Location_ 3 upper zones Line pressureN--__psig; Sample pressure__, , psig; Temperature.__m Remarks Sample taken Auqust 26, 1979 (Samp16 NO. o F; Container number . 2') Component Mole % or Volume % Oxygen ..... 0 Nitrogen ......................................... 6.72 Carbon dioxide _T_j"a £ e Hydrogen sulfide ................................. --- Methane. 9 3.28 Ethane... ~. Ri.g.h.e.r .............................. Trace Propane ......................................... Iso-butane ....................................... N-butane ........................................ Iso-pentane ...................................... N-pentane ........................................ Hexanes H__eptanes ~ high_er ............................ Total ............. 1 00.00 Gallons per GPM of pentanes & higher fraction ........................ Gross btu cu. ft. L~60© F. & 14.7 psia (dry basis) .............. Specific gravity (calculated from analysis) ................... Specific gravity (measured) ............................. Remarks: 942 0.582 0.582 SYMBOL OF SERVICE REPORT of SUB-SURFACE DIRECTIONAL SURVEY TFXACO COMPANY _TS- 3 and .RF DRILL WELL NAME c".O~K INI FT. Al ARKA '--' '-" '--' , LOCATION JOB NUMBER _ REDRILL- AM10-2068 TYPE OF SURVEY DATE SINGLE SHOT OCT - SURVEY BY ANCHORAGE OFFICE NOV .'"~lll ~_ _. I aTl,.lr~ IV I: ICT["'r'"i lid Il ~_A. / - W E L L C 0 M P L E T !: 0 N R'E P 0 R I - PAGE L-..~.,,.,- . TEXACO [NC. T$-3 DECEM6ER 18,i968 PREPARED FOR E~STMAN 6Y SCS TANGENTIAL'~METHOD , MEASURED COURSE - - 0 E V ! A T ! 0 N - C 0 U R S E T 0 T A L .... DEPTH LENGTH ,ANGLE DIRFCTION AMOUNT V.DEPTH LATITUDE ....... :DEP, ARTURE ........... V_,DEPTH ......... LAIIT,UDE .... DEPARTLIJLF_~,. OKIGIN LOCATED AT MD = 0.00, TVD = 0.00, LATITUDE_= 0.00, ..... DEPARTURE = 0..00 41. 41, 0 O' N 0 E 0.00 41.00 0.00 N 0.00 E 41.00 0.00 0.00 75. 34. 0 35' N 82 W 0.34 33.99 0.04 N 0,34.W .............. 74,99 0.04 N . 0.34.W .......... 100. 25. 0 20' N 54 W 0,i4 24.99 0.08 N O.1i W 99.99 0.13 N 0.46 W 125.. ....... 25. 0 .... 1,5' ....N~3~,. W. . 0.10 24.99 .O, 08 N 0.06 W ....... 12,4.99 ...... 0,.22_,N ................. Q. 52,.,~/. 150. 25. 0 5' S 79 E 0.03 24.99 0.00 S 0.03 E 149.99 0.21 N 0.49 W ............ 17.5 .............. 2 5, ..... 0 ...... 15,.! ....... N __58 ,..,E .... 0 · 10 24 . 99 244. 69. 0 15' S 83 W 0.30 68.99 . ~ ...... 33.zt__. .......... .90_. ........ 0 .... 3,5~ .....N._~24_....E ..................... 0_. 91 .......... 89, 9.9 437. 103, 1 504. 35. 4 ........... 534_, ......... ~ .....30. .. 5 566. 32, 7 30' S 76 ........ 598 ....... 32 .... 8 45' .... S ~87__ 629. 3i. 9 O' S 89 ....... 692 ................. 63 755. 63. 13 O' N 85 837. 82. 12 Q' N 87 932. 95. 11 25' N 8~ i059. I27. 9 45' S 88 i177. i~8. IO t5' S 90 · 1400. 223. 11 45' S .80 1445. 45. 11 45' $ 83 1541- 96. 11 O' $ 80 1635.. .94. 11 O' $ 79 1730. 95. 12 O' $ 75 1825. 95. 13 15' $ 78 1920 · 2013. 93. 13 30' $ 76 210S- 95. 13 O' S 77 2203. 95. 13 30' S 76 ...... 0.,.05 N .... O.Q9 E ................ 17.~.9_9 .................... Q,27_N .................... 0.39_._.W ..... 0.03 S 0.29 W 243.99 0.23 N 0.69 '"~ 50' N 68 E 3.29 102.94 1.23 N 3.05 E 436.93 2.30 N 2.73 E 5' .2 ................ N,,.81 .... E ................ !,,.3~ .....31, 97, ..... O' S 78 E 2.44 34.91 0.50 S 2.38 E 503.82 2.00 N 6.4.5 E 1.5' S__82...E ............ 2.,7_..4... ........ 2_9.8.7 .............. 4.17 4..86 4.84 12 .,82 E 14.17 E 17.04 E 18.80 E 21.50 1 E 20.99 1 E 45.41 2 E 9.1,6 E 18.31 E I7.93 E i9.75 E 21.77 E 21.37 E 21.71 E 21.37 E 22.17 31.72 1.01 S 4.05 E 565.62 0.61 N 13.22 E .. 31 :. 62 ..........._0.o2 5 S .................... .~ ,_.8_6___E_ ............. ,,5_9__Z_..Q5 ................ 0 ,_~.6....__N .................. I~_._Q_8___E_ 30.61 0.08 S 4.84 E 627.67 0.27 N 22.93 E 6 L. 67 .................. 0 ,. ,4 zt ... N ............. 12....8Z~E .......... 6 ~9__. 3.5_ ............... O,,_7_J ..N_ .... _3_5.,,,75_F,_ .... 61.38 1.23 N 14.11 E 750.73 1.96 N 49.87 E 80.20 0.89_N 17.02...E ............. 830,9~ ......... 2,85.___N ..........~..89._~ ........ 93.12 1.31 N 18.75 E 924.06 4.16 N 85.65 E 25.16 0.75 S ....... 21_.49 E ..... 1049.23 ... 3.41. N ._107~_15._._~ 16.11 0.00 S 20.99 E 1165.34 3.41 N 128.14 E 18.32 7.88 S ..... 44.72 E ........ 1,38.3.6.7 , ., ~.47 S ....... 172~.83.,~E 44.05 1.11 S 9.09 E 1427.73 5.58 S 181.96 E 94.23 3.18 S 18.03 E . 1521..96 _8.76 5 200,00 ~.,_. 92.27 3.42 S 17.60 E 1614.24 12.19 S 217.61',E''~'~ 92.92 5.11 S 19.07 E 1707.16 17.30 S 236~69..E 92.47 4.52 S 21.29 E 1799.63 21.83 S 257.98 E 92.56 5.16 S . 20.73 E ............ 1892.20 27..00_.5 .... 278o72._E 90.43 5.25 S 21.06 E 1982.63 32.25 S 299.79 E 92.56 4.80.S 20.82 E 2075.19 37.06_S 320.61 .E 92.37 5.36 S 21.51 E 2167.57 42.42 S 34.2.13 E W E L L C O M P L E T I O N R E P O R T ' p-~'~'E 2 - ' TEXACO INC. TS-3 DECEMBER 18,1968 PREPARED FOR EASTMAN BY SCS TANGENTIAL METHOD MLASURED COURSE - - D E V I A T I 0 N - C 0 U R S DEPTH LENGTH ANGLE DIRECTION. AMO U NT., .,.~, D.E P I]H LATITUDE E - - - T 0 T A L DEPARTURE ..... V.DEPTH ........... ,LATITUDE. DEPAR. IURE 2298. 95, 14 1,5' S 75 E . ..23.38 92.07 6,05 S 2393, 95. 14 O' S 75 E 22.98 92.17 5.94 S 2489. 96. 14 O' S 75.].E ..23.22 93.14 6.01 S 2582. 93. 15 O' S 73 E 24.07 89.83 7.03 S ~__2678 ........ 96 ........ 14 45' S,.~,Z.,5,_E ........... 24.45 ...... 92,,83 6.32 S 2774. 96, 15 O' S 72 E 24.84 92.72 2.868. ........ 94 . ._ 1 ........... 6 0 ! S i._7_3..__ E ............ 25... 9.0. . 90 · 3.5 .......... 2963. 95. 15 45' S 71 E 25.78 91.43 22.58 E 22. i9 E 22.43 E _ 23.0I E 23., 60,. E 7.67 S 23.63 E 8.39 S 24.38 E 2259.64 48o.~7 .... S 364.71 E 2351.82 54.42 S 386.9I E 2444.97 _60..,~.3. S 409,35 E 2534,80 67,47 S 432.37 E 2720,37 81.47 S 479,60 E 2810.,23 ..... 89,05_$ .50~.,..38.~.~E 2902,16 97.44 S 528,76 E-., ...... 30. 59:, .............. ' 96 ......... 16 _ 1.5' ........ S 71 .. E .................... 2_6 ,.8.6 3154. 3344. 3440. 3535. 3629. 3724. 3819 ...... 9.~, ...... ~5 ~5'..N 3912. 93. 14 45' N 86 E 4005. 93. 14 ~5' N 88 E 4099. 94. 14 O' N 88 E 4193. 94. 13 O' N 90 E 4289. 96. I2 O' N 8~ E 4380. 91. 11 15' S 89,E 4474. 94. 11 30' S 89 E 4568. 94. I1 15~ S 89 E 4662. 94. 11 O' N 90 E 4756. 96. 10 30' N 89 E 4854. 96. 9 45' S 89 E 494~. 95. 10 O' N 90 E 5043. 94. 9 O' S 85 E 5138. -~5. 9.15' S 85 E. ~2.}6 ..... 8.74 S.. 25.,~0.E .......... 2994.32 95. 15 15' S 72 E 24.98 91.65 7.72 S 23,76 E 3085.98 113.91S 577.93 E 94, 15 15' S 80 E 24.72 90.69 4.29 S 24.34 E 3268.95 125.50 S 627.71 E ~.9~ ........ !.5_,~.5' _.N_.8g.~E ....... 25,25 ~92,,6~ .......... }.51 N ......... 2~.,00 E ...... ~6.~1,5.7 ............ 95, 15 15' N 84 E 24.98 91.65 2.61 N 24.85 E 3453.22 119.37 S 677.57 E 94. 16 O, N 83 E 25.90 90,35 3.15 N 25.71 E 3543.58 116.21 S 703.29 E 95. 14 45' N 84 E 24,18 91.86 2.52 N 24.05 E 3635.45 113.69 S 727.34 E 83... E ................. 24,98. ___9 ! ,,..65 ............ 3..-.0~ .~ N .......... .,24 . 80, E .......... ~_7,27 · 1 ~ ......... 1 lO..,.6h.._,S_, .......... 7,5..2,,. !5.,,,,E,.,,,./', .... 23.67 89.93 1.65 N 23.62 E 22.89 90.13 0.79 N 22.87 E 22.74 91.20 0.79 N 22.72 E 21.14 91.59 0.00 N 21.14 E 19.95 93.90 0.34 N 19.95 E ..... !%.75 89.25 0,30 S.. 17.75 E 18.74 92.11 0.32 S 18.73 E 18.33 92.19 0.32 S 18.33 E 17.93 92.27 0.00 N 17.93 E 17.49 9~.39 0.30 N 17.49 E 16.25 94.61 0.28 S 16.25 E 16.49 93.55 0.00 N 16.49 E 14.70 92.84 1.28 S 14.64 E 15.27 93.76 1.33 S 15.21 E 3817.04 108.99 S 775.76 5 3907.18 108.19 S 798.64 E 3998.39 107.40 S 821.37 E 4089.98 107.40 S 842.5I E s E 4273.i3 I0,7.,36 S , 880.22 E 4457.44 108.01S 917.30 4925.12 109.27 S 1000.12 E 5018.88 110.60 S 11015.34 E ' . .- W E L L C 0 M.P L E T I O N R E P O R T TEXACO INC. TS-3 DECEMBER 18,1968 PREPARED FOR EASTMAN BY SCS MEASURED COURSE - - O E ......... DEPTH ...... LENGTH .......ANGLE ' PAGE 3 - TANGENTIAL METHOD DIRECIION AMOUNI.~V,D. EPTH LATITUDE DEPA.RIURE V,DERIH ........ LATIIUDE ..DEPARTURE ....... 5256 ..... 118, 9 1.5' 5381, 125· ? 30' 5505 ...... 124, .5 ..... O' 5650. 145. 5 30' 5655 ....................... 4 ..... 5,.3~'_. 5778, 124. 5 O' 6030. 160. 4 15' S 84 E .... 18,96 116,46 1,98 S 18·86 E 5135,35 112,58 S 1034,20 E S 78 E 16.31 123.93 3.39 S 15.95 E 5259.28 115.97 S 1050.16 E S 67 E 10,80 123.5,2 4,22 S 9.94 E 538.2.81 120.19 S 1060.11 E S 65 E 13,89 I44,33 5.87 S I2.59 E 5527.I4 126.07 S 1072.70 E S 6.5, E ................ .._~,,38 ....... 3·98 ,..0,16 S 0,34 E 5.531,12 126,23 S 1073,.05 E S 68 E 10.80 123.52 4.04 S 10,02 E 5654.65 130.28 S 1083.07 E S._37_~E ..................... 6..0,1 .....91.80. _ 4.80 S 3.62 E. 5746..~5 .......... 1.35.08 S 1086.69 .E ........... S 12 E 11.85 159.56 11.59 S 2.46 E 5906.01 146.68 S 1089.16 8.51 S, 0 74 W 601.4.68. 155,20 S 1088.4i 14.31 S 3.83 W 6184.03 169.5i S I084.58 E S .... S 7.16 S .~,.20 S 19.11 S 15.26 , W ....~ ~................ 109. ......... &_3D ........ S_ ...... 5_ .................. a. 55_108_. 66 630'9. 170. 5 O' S 15 W 14.81 169.35 6350 ...... &l,,~ ...... .5 ........ D ............... 15,.W ................... 3,5? .......~0,84 ............. 3,45 6525, 175· 5 O' 6_609, ......... 8.~, ....... 6779, 170, 7 15' 6900 ...............121 6986. 86. 9 30' lO 73 ..................... .91- 7175· 98, 9 t5' ....... 72.6.7. ...... 92, 8._~5' 7390, 123, 9 O' 7477, 87, 9 ~5' 7501. 24. 9 15' ..... ~..532 ..... 31 .... 8 ~5' 7593. 61. 11 O' 7623. . 30. 11 O' 770~. ?g. 13 30' .,, 7733, 31.. 13,..30' 7761. 28. 14 O' ,,. 78Ig 53. I2. ,0' 7837. 23. i2 45' 7918. 81. 12 30' S 28 W 15.25 174.33 13.46 S,,._3. Q_~ ................... 8,,,,,.,4_1 ......... 83,_57 , 7.28 S 63 W 21.45 I68,64 g.73 S 68 W 14.19 84.82 S 71, ~ .............. 15.,_8D ........ 8~.61 S 7i W i5,75 96,72 S 75 W 13,99 90,92 S 80 W I9.24 i21.48 S 75 W 14.73 85.74 . S 75 W 3.85 23.68 S 85 W __ ~,71_ 30.63 N 69 W 11.63 59.87 N 67 W 5.72 29.44 N 7I W i8.44 76.8I N 73 W 7.23 30.14 N 75 W 6,7~ 27,16 N 75 W , 11.01 51,84 N 75 W 5.07 22.43 N 75 W 17.5.3, .79.07 7.11 5.31 5.14 5.12 3.62 3.34 3.81 0.99 0.41 4.17 2.23 6.00 2.ii 1.75 2.85 1.31 4.53 ....... 62.Z~,.87 ........ 172,96._S .... 6399,2i I86,43 S i076,49 E ..648.2,78 193,~2 .S 6651,43 203,46 S 1053,17 E W ....... 6771,25 ...... 210,58_S .... 1037,91...E....z__ S 13·16 W 6856,07 215,89 S ........l~.9~.W ....... 6945,69 ........ 22.1~04 S 14.89 W 7042.41 226.17 S S 13.51 W 7133.34 229.79 S S 18.94 W 7254.83 233.13 S S I4.23 W 7340.57 236.94 S S 3.72 W 7364.26 237.94 S S 4.69 W 7394.90 238.35 S N 10.86 W 7454.78 234.18' S N 5.26 W 7484.22 231.95 S N I?.43 W 7561.04 225.94 S N 6.92 W 759i. I9 223.83 S N 6.54 W 7618.35 222.07 S N I0.64 W . 7670.20 219.22 S N 4.g0 W 7692.63 21?.gI S N 16.93 W 7771.71 213.37 S S 1024.75 'E S ........ IO.Qg_.8,O_E 994.91E 981.39.._~ 962.44 E 948.2I E 944.48 E ,939,79 E 928,92 E 923.65 ) 906.21 899.29 E 892.75 E ,882.11. E 877· 2O E 860.27 E .- W E L L C O M P L E T I O N R E P O R T PAGE z~..~. TEXACO INC. TS-3 DECEMBER 18,1968 PREPAREO FOR EASTMAN 6Y SCS TANGENTIAL' METHOD MEASURED COURSE - - D E ¥ I A T I 0 N - C 0 U R S E T 0 T A L .... ........... DEPTH ......LENGTH ...... A. NG.LE DIRECTION ....... A.MO,UN T,. ,,..V~, DE P T H LATITUDE,.. DEPARIURE ............ V,..D EP.I.H ...... LAII IUDE ........ DERARI.URE ........ 8067. 149. 12 O' N 80 W 30,97 145,74 5,33~ N 30,50 W 7917,45 20?.,99 S . 829,76 E 8148. 8I, II 30' N 82 W i6,14 79.37 2,24 N 15.99 W 7996,83 205,74 S 813,77 E 8183. 35. li 45' N_.86~....~ 7.12 34.26 0.39 .N 7..ll,~W 8031.09 .2.05,24.5 806.66 E 8214. 31, 14 45' S 78 W 7.89 29.97 1,64 S 7,72 W 8061.07 206,89 S 798,94 E 8.229, .............. 1_5., .15 15., ......... ~,_j~,~.. 3.94 14.47 0,68 S 3.88 W 8.075.54 .2_0_7._,._~_,~ 795.05 ..... E 8253. 24. 17 15' S 84 W 7,11 22.92 0,74 S 7,07 W 8098,46 208.32 S 787.98 E ~.28.9 ........... 3,6,_ 19 .30' ..... ~__.88 ~ ........... 1.2.01 3~..,_93 ......... 0,.41. 8309. 20. 18 45' N 82 ~ 6.42 18.93 0.89 ~32_Q, ................. ~.,1.,. .... ~8~_~.5t ......... ~_..~.! ..... W ...................... ~,.4~ ..... ~0_~.~4 .................. ]0?53 8350. 30. 17 45' N 79 W 9.14 28.57 1.74 8425. 45. 14 15' N 75 W ii,07 43,61 2.86 N ..... 12,OQ .W 813,2,40 ..... 207,90 S ......77..5,97.._E N 6.36 W 8151.34 207.00 S 769.60 N 8.97 W 8190.36 204.72 S 757.22 E N IO.e9 w 8262.95 199.19 S 739.22 E 8442. 8469. 8525. 8560. 35. I? 45' N ........ 8692 ........... 1.32 .... 17 O' ...... N 8790. 98. 14 45' N 8908. 118. 13 15' N 8999. 91. 12 30' N 9146. 147, 11 45' N 9212. 66. 11 45' N 9359. 147. 10 O' N 9486. 127. 9 45' N 9565. 79. 8 15' N 9630. 65. 8 30' S 9733. 103. 7 15' $ 9784. 51. 7 15' S 9916. 132. 6 45' S 10085. 169. 7 O' S 10331. 246. 6 15' S _ !7 ..... !3 .......... O' ..... ~ .... 7b.._W ............ 3,8.2 .... 16.56 ................. 0.92 .N ......... },._7_!_,.W. ............. 8.27 9.., 5_.~1 ........ !9~._._27 $ 27. 15 45' N 71 W 7.32 25.98 2.38 N 6.92 W 8305.50 195.88 S 728.58 E ....... 56, .... 1.7 ......... _.0., ....... N .,69.. w ............. ! 6 ,..37 ..... 53 o 5,..5 .................. ..5 ...~6. N .............. .!._~.?_2.8...W. ............. ..8_..3..5..9.,_.0..5 ..... ! 90, 0.2 .... 67 W 10.67 33.33 4.16 N 9.82 W 8392.39 185.85 S 703.48 E ~_,_W ..... 38.59.126.23 ........... 1~,._83~ N ........ 3.6,D2_.~ ......... ~..~.!_~.,62 .......... !~2~D~..~ '_~!.,__~,._~ 70 W 94.77 8.53 N 23.44 W 8613.39 163.48 S 644.00 E 74 W 114.85 7.45 N 25.99_W ....... 8728.25 ~ ~.~6.03 S ............. 6..I~,.OQ.._E 73 u 88.84 5.75 N i8.83 W 8817.09 i50.27 S 599.17 E 73 W 143.91 8.75 N .28.62. W ..... 8961.01 141.52 S .57.0.54.E 76 w 64.61 3.25 N I3.04 W 9025.63 i38.27 S 557.50 E 78 W i44.76 5.30 N 24.96.W 9170.39 132.96 S., _532.53 E 77 W i25.16 4.83 N 20.95 W 9295.56 128.12 S 511.57 E 85 W 78.18 0.98 N I1.29 W ..... 9373.74 i27.13 S .. 500.28 87 W 64.28 0.50 S 9.59 W 9438.03 127.63 S ' 490.69 L 87 W i02.17 0.68 S I2.98 W 9540.20 i28.3i S 477.7I E · 86 W 50.59 0.44 S 6.42 W 9590.80 i28.76 S 471.29 E 83 W 131.08 1.89 S 15.39 W 9721.88 130.65 S .455.89_.E 77 W 167.74 4.63 S 20.06 W 9889.62 135.29 S 435.82 E 73 W 244.53 7.83 S 25.61 W I0134.16 143.I2 S 41~.2i E 24.95 27.04 . 19.69 29.93 13.44 25.52 21.50 11.33 9,60 12.99 6.43 i5.51 20.59 26.78 MEASURED COURSE ........ DEPTH LENGTH W E L L C 0 N P L E T ! 0 N R E P 0 R T ' PAGE 5 .. Sc ' TEXACO INC, TS-3 DECEMBER 18,1968 P~EP~ED FOR E~ST~AN BY E T 0 T ~ L -- D E V I A T I O N - C 0 U R S ANGLE DIRECTION AMOUNT V,DEPrT.H' LATITUDE DEPARTURE _'V.DEPTH 13,82 126.24 1.20 S 13.77..W 10260.41 TVD = 5018.88~ LATITUDE = -110.54, DEPARTURE = 12,11 95.23 0,21N 12.11E 5114,11 7.86 94.67 1.36 N 7.74 E 5208,78 7,9.4 95.67 4.09 N 6.81E 5304,45 9,10 94.56 6,87 N 5,97 E 5399,01 _10458. 127. 6 15' S 85 W LUGGED BACK TO MD = 5138.00, 234. 9b. 7 15' N 89 E 5329. 95. 4 45' N 80 E 5.425 .... 96 ...... 4 ~.4.5.' .. N 5,9., E. 5520. 95, 5 30' N 4i E LATITUDE. DE.PARTUEE 144.32 S. 396.43 1014.92 110.32 S 1027.03 E 108.96 S 1034.78 E 104~.86 S 1041.59~-E ...... 97,99 S 1047.56 E .....~ 5615, .........' 95, ..... 7 .... 15' ........ N 571i, 96, 7 O' N ..... 5806.. ...... ~5. ................ ~ ......... O' ........ N. 5899. 93. 7 O' N __..5995 ................. 9&, ......... 7 4_5' ....... N 6090, 95. 7 i5' N .......... 6184 ................ ~4 ........ 7...~5! .N 3.1E ............ 1.1,,.98__ 9.4,24 .......... 10,27 35 E 11.69 95.28 9.58 3.5..E ................. 11,57 .... 9&,_29 .......... 9.48 41 E 11.33 92.30 8.55 .3R...E ................ 12,,9~ .......95,1.2 ............. 10.06 39 E 11.98 94.24 9.31 3.5.E .......... 12.67,~ 93,1~.. 10,38 -6228. 44. 8 15' .... 6375. __147... 6 45' 6471. 96. 7 .0' ...... 6566 .......... 95 .... 6662. 96. 7 30' 6756. q4. 9 15' 6849. 93. 9 O' 6944. 95. 10 45' 7040. 96. 12 O' 7134. 94. 11 45' 7230. 96. 10 45' 7325. 95. 10 30' 7420. 95. 9 30' 7515. 95. 9 45' 7610, 95. 9 O' 7705, 95. 8 O' 7800, 95. 8 O' 7895, 95. 7 30' 7928, 33. 7 45' N 37 E 6.31 43.54 5.04 N_ 38 E. 17.27 !,~5.,.98 13.~61 N 38 E 11.69 95,28 9.21 N_ 25 ......... 11., .57 ....... 9 ~,2.9 ......... 1.0 , 49 N 39 N 49 _ N 57 _ N 78 N 79 ] N 79 l N 80 E N 79 E N 81 E N 82 E N 84 E N 82 E N 85 E N 85 E N 86 E 12.53 95,17 9.73 15.10 92.77 . 9.91 14.54 91.85 7.92 i?.7i 93.33 3.68 19.95 93.90 3.80 19.14 92.03 3.65 17.90 94.31 3.10 17.31 ~3.40 3.30 . 15.67 93.69 2.45 16.08 93.62 2.23 14.86 93.83 1.55 13.22 94.07 1.84 13.22 94.07 1.15 12.39 94.18 1.08 4.45 32.69 0.31 ._6.17..E 5493.25 87.71S 1053.74 E o.o, s E ,.s4 s, .so 40., s lo,o. 7.20 E 6342.45 2.46 S 1119.13 E N ..........~.89 E N 7.88 E 6531.92 N 11.40 E 6624,70 N 12.20 E 6716.56 N 17.33 E 6809.89 N 19.59 E 6903.79 N 18.79 E 6995.82 N 17.63 E 7090.14 N 16.99 E 7183.55 N 15-.48 E 7277.24 N 15.93 E 7370.87 N 14.77 E 7464.70 N 13.09 E 7558,78 N 13.17 E 7652,85 N 12.35 E 7747.04 N 4.43 E 7779.74 ..... 6436.,.7f, ......... 8.,.03_.hL .....11.2~4.. Q2.._.E 17.77 N 1131,91 E 27.68 N .1143.3!_ E 35.60 N 1155.51E 39.29 N 1172.84 E 43.09 N 1192.44 E 46.75.N I211.23 E 49.86 N I228.86 E 53.16 N 1245.86 55,61 N 1261.34 57.85 N 1277.27 E 59.4I N i292.05 E 61.25 N 62.40 N 1318.32 E 63.48 N I330.67 E 63.79 N I335.ii E ~ ' id E L L C 0 M P L' E'T ! 0 N R E.P 0 R T PAGE TE'XACO-'~-'~-~- TS-3 DECEMBER 18,1968 PREPARED FOR EASTMAN BY SCS TANGENTIAL METHOD MEASURED COURSE - - D E V ! A T I 0 N - C 0 U R S E T 0 T A L ........... .PEPT..H ......... LENG_T.H. ..... A. '~_ ...... DIRE£.IiQN ......... A[~3JJNT.....V..,.J~.ERI. H .LATI.TUDE .. DEPART. URE .... V,.D.E. PIH .... LAT!TUDE DEPARTURE..,.. 8027 ........ 99, ......... ?_._4_5! .... N. 8.8. E .................... 13.35 98.09. . 0.46 N 8].84. 157. 7 30' N 90 E 20.49 155.65 0.00 N __._8245. .... .. 61 ..... 7 0,. .... .~__9_O._..~E .......... 7.43. 6.0,:54 0.00 N 8306. 6I. 6 30' N 85 E 6.90 6Q.60 0.60 N __8~.6.9... ................. _i...6.~., ....... b.._ ~.._' .... ~.__~.Z_~, ........ 6.5..8 ....... 62.,.,,~.~ ...... t,.48 S ... 8433. 64. 6 O' S 83 E 6.68 63.64 0.8i S 13.34 E 7877,83 64,25 N i348.45 E ......... 20.49 E 8033.49 64.15 N 1368.g4 E 7.43 E 8094.04 '64.25 N I376.38 E 6.87 E 8154.64 64.86 N 1383.26 E 6.41 E ........... 8217..30 ..... ~~tLN .... 138.9.,67 .E 6.68 E 8280.95 62.56 N 1396.3I E 8554o 60. 5 30' S 78 E 5.75 59.72 1.19 S 5.62 E 8401.34 60.26 N 1408.22 ~ ...... 8_6.~..~ .......... ~ ...... [.~3'~ ...... ~5£~.~[ ........ _~..80__E ............. ~!_~..~.~._...~-.~ .................. ~.~95 S ............... ~.!.,.O..8..__E ................. 852.3,81 ............ 58.30_N .......14.!..9.,~.._~ ,~-~8792. 1.15. 4 30' S 83 E 9.02 114,64 1.09 S 8.95 E 8638.47 57.20 N 1428.26 E ~91~4. 156. 3 15' N 90 E 8.84 155.74 0.00 N 8.84 E 8989.80 55.86 N 1449.85 E 92~0. 96. 3 30' N 85 E 5.8~ ....... 9~.~.~2 ................. 0.5.1. N ............ 5.83 E .... g085,..6~ ........56.37 N ..... 145.5.6g...E ........ 9384. 144. B 15' N 82 E 8.16 14~.76 1.lB N 8.08 E 9229.3g 57.51N 1463.77 E ....... ~5.~, ........ - [28. Z..._~.[ ..... ~..._!~__[ .................... ~.~_.~.~.....!.Z.~,.87 ................. ~.,.~4_.N ......... 5.39...E ..... 9357.,_2.6 ..... 58.96_N 1469~[7.._E ............ 9650. I88. 2 BO' N 82 E 6,01 1~7.86 0.83 N 5.96 E 9495.1~ 59.79 N 1475.13 E 9860. 104. S O' N 84 E 5.44 10B.85 0.56 N 5.41 E 9704.84 60.S6 N 1486.09 E ___~.00~__1.. ................ ~_8~ ........... ~ .~ ......... N 9~.__E ............. ~_.4~.._180.775 0.00 N 9.47 E ..... 9.885~60 ..... 60.36.N 1495.56.._E ........ 10146. 105. 3 15' N 84 E 5.95 104.83 0.62 N 5.92 E 9990.43 60.98 N 1501.48 E 10250. 104. 3 30' N 89 E 6.34 103.80 0.11N 6.34 E 10094.23 61.09 N 1507.83 E.~.. ... . -,- - - i i ~ ' t - ' , ' ' ' ~ i ' ' i ~ .... , ..... i , . ,. ~ ; · , ~ · ~, . . . I~~'- ~ ; ~ : ~ ~ ~ : , , ~~ _' ~~-. ::~ ~, L ~ ~ ~ -- ~ - ~' ' ' ' - ~ ~ ' : ~ ; ' ......... · ' , i , , ~ i I , , , ~ , , I , , · .,, , ~. ~ I t I~t ~ ;~~~: ' ~ ~L ; ~2~-:~: '~' ~":'- ' - ; · i ' ' ' ' ' t Form No. P.--4 REV. 9-30-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WOR'KOVER opERATIONS SUBMIT IN DUPLICAT~ 2. NAME OF OPERATOR T~ACO Inc. AP1 NUA~ERICAL CODE 50-133-20133 6. LEASE DESIGNA~ON AND SEEIAL NO. ADL 17597 1, T.IF INDIA]~T, ALOTTEE O~{ TRIBE NANIE OIL [X----] GAS [] WELL WELL OTHER 8. UNIT,F.~M OR LEASE NAME State of Alaska 3. ADDRESS OF OPEP~TOR P.O. Box 664~ Amchorage~ Alaska 99501 4. LOCATION OF WELL Platform Leg lA, Pile 9. WELL NO. TS %3 10. FIELD A_ND POOL. OR WILDCAT Trading Bay 11. SEC., T., R., M,, (BOTTOM HOLE Sec. 34, T10N-R13W, 12. PERMIT NO. 68-65 S.M. 13. REPORT TOTAL DEPTH AT END oF MONTH, CI-I~%TGES IN HOLE SIZE, CASING ANT) CEMENTING JOBS INCLUDING DEPTH SET A/XrD VOLU/VIES USED, PERFORATIONS, TESTS A_N-D RESULTS. FISHING JOB~, JTJNK IN HOLE A_ND SIDE-TRACKED HOLE AND A3qY OTHER SIGNIFICA/qT CHANGES IN HOLI~ CONT)ITIONS. ~0,v,,e,~,, er,, 1.968 NOvember 1- 17 November 18 November 19 November 20 - 28 November 29 - 31 Directionally drilled in 12¼" hole to 10250'. Ran electric logs. Ran and cemented 9 5/8" casing through shoe at 10242' with 1100 sx. and' through stage collar at 3252' with 1200 sx. Squeeze cemented 4-1/2" holes at 10130' (E-Log) with 235 sx. and 9881 with 125 sx. Fishing wire line tools. I hereby certify t~at the f~ore~ng is ~ correct _~'~C~. _/~~~/~-- =~ ASS t. D ist, Supt. D^~ December 2, 1968 SIGNED KOTE--Report on this form. is required for each calendar month, regardless of the status of operations, anO must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Fon'n P~3 R,E~. Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATIO,Ni COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (]30 not use this form for proposals to drill or to deepen or plug back to a dlffierent reservoir, Use "APPLICATION FOR PEH2/IIT--" for such proposals.) 1, 0IL WZLL [] OAS WELL [] OTHER 2/NA~IE OF OPERATOR TEXACO Inc. 31 *DD~SS oF OP~*TO~ P.O. Box 664, Anchorage, Alaska 4. LOCATION. O,F WEbL *tsur~ace 618' South and 2068' West Northeast corner of Section 34. from the 13. ELEVATIONS (Show whether DF, RT, GlO, etc. KB = MSL + 92' 14. Check Appropriate Box To I~ndi,cate Nature of I~t[ce, Re NOTICE OF INTENTION TO : TEST WATER SHUT-OFF ~ PULL OR ALTER CASINO %. ATM NU1iEP/CAL CODE API 50-133-20133 6. L[EASE DESIGNATION A_ND SERIAL NO. ADL %17597 IF INDIA.H, A/J.~TH'EE OR TRIBE NA1VL~ 8. UNIT, FA/{1VI OR LEASE NAME State of Alaska 9. WELL NO. TS ~3 10. FI~r.O ~ POOL, OR WILDCAT Trading Bay 11. SEC., T., R., M' (BOTTOM HOI.~ OBJECTIVE) Sec. 34, T10N-R13W, 2. PEPJW/T NO. 68-65 SeM. ~ort, or O~her ,D,~I'~ EUB~EQUENT REPORT OF: REPAIRING WELL SHOOT OR ACIDIZE I [ ABANDON$ SHOOTING OR ACIDIZING ABANDONMENTs REPAIR WELL CHANGE PLANS (Other). (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including eetimated date of starting any proposed work. We propose to complete this well as a dual gas lift prOducer and separately produce the Trading Bay and Hemlock intervals. We plan to set a single packer at 9892' (top Hemlock 9908') and a dual packer at 8760' (top productive Trading Bay 8824'). There will be two strings of tubing to the surface to prevent commingling in accordance with the existing State-wide field rules. NOV £ FAW: jm 16.1 hereby cert[~"~hat ~the~r.~n~ i~.~e~nd correct %' (This s~ ce or Stat c e) ~ APPROVED BY CONDITiON~ O~' A~PROVAL, IF ANY: TZTL~ Asst. DiSt, Supt. TITLE D~Tm 11/20/68 See lnstrucfions On Reverse Side Form No, P---4 R,~. 9°3O-67 STATE OF ALASKA svBMrr IN r~tU-LmATI~ OIL AND GAS CONSERVATION COMMITTEE ~5. API NUA~ERICAL C~ODE 50-133-20133 6. LEASE DESIGNATION AND SERIAL NO. MONTHLY RE!PORT O'F :DRILLING AND WORKOVER OPERATIONS ADL 17597 1. 7. IF INDIA]~, ALOTTEE O1{ TRIBE NAME 0IL ~-~ GAS ~ WELL WELL OTHER 2. NAME OF OPERATOR 8. 13~'IT,FARA{ OR LEASE NAME TEXACO Inc. State of Alaska 3, ADDRESS OF OPEi~TOR 9. %VELL NO. P.O. Box 664, Anchorage, Alaska 99501 TS ~3 4. LOCATION OF WELL 10. FIELD A_ND POOL. OR WILDCAT Trading Bay Platform Leg lA, Pile 11. SEC., T., R., M., (BO'I~FOM HOLE OBJECTBrE) Sec. 34, T10N-R13W, SM 19-. PgR3/IIT NO. 68-65 13. REPORT TOTAL DIKPTH AT END oF MONTH, CHA2qGES IN HOLE SIZE, CASING ANT) CEMENTING JOBS INCLUDING DEPTH SET ~ VOLUiVIES USED. PERFOI{ATIONS. TESTS A/VD I~ESULTS. FISHING JOBS. JI/NK IN HOLE A-ND SIDE-TTtACKED HOLE AND A_NY OTHER SIGNIFICANT ~-GF~ IN HOL~ CONDITIONS. ...October 1968 Oc%ober 1- 13 Drilled 12¼" hole to 10458'. Ran electric logs and shot SWS. October 14 Laid plugs as follows: DP at Cement 10456 225 sx 10100 300 sx 5389 400 sx October 15 - 31 Kicked off at 5208 and drilled a directional well in 12¼" hole to 8184. Drilling ahead. 14. I hereby certi~y(h~l the ~o~~~... ' siGmm ~-~/~.-~-' ~ A ss't. Dist. Suot. n~. Nove~r 6. 1968 NO/--Report on this form is required for each calendar month, regardless of the status of operations, and must ~ filed in duplicate wit~ Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. your ~~ copy o,f Sundry ~lce abo~ reference~ ~e~. Form REV. 9-30-67 ~br~t '~Irfiet[ti~ls'~*l~ Triplicate R Et"~b l'::ll'~t,SCl 't ]J~p~" Lu g.plie, ste STATE OF ALASKA OIL AND GAS CONSERVATIOI~'~~t~' UN'DRY NOTICES AN: RE (Do not use this form for proposals ix) drill or to deepen or p'l//~ ~//ck to a diffierent reservoir. Use "APPLICATION FOR PEH2VIIT--" for such proposals.) 1. OIL ~. GAS ~] WELL WELL OTHER 2. NAME OF OPERATOR T~CO Inc. $i ADDRESS OF OPERATOR P.O. Box '~$64, Anchorage, Alaska 99501 4. LO'CATION. O,F WELL At surface Platform Leg lA, Pile #1 13. ELEVATIONS (Show whether DF, RT, GR, etc- 14. 5. API NtriVXE~CAL CODE API-50-133-20133 LEASE DESIGNATION AND SERIAL NO. ADL #17597 8. UNIT, FAR/VI OR LEASE NAME State of Alaska 9. %VELL NO. TS %3 10. FIELD ~ FOOL, OR WILDCAT Trading Bay 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) sec. 34, T10N-R13W S.M. 12. PEKM/T NO. 68-65 ~k APPropriate Box To I,ndi'ca~e Nlat'ure of NOti'ce, RepOrt, or Other 'Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF t ] PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACXDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Redrill BUBEEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMENT* (Other) NoTE: Report results of multiple completion on Well ompletion or Recompletlon 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. Pr..esent Condition TD: 10458 Location at TD: Slll, E401, VD 10258 Top Hemlock: 10180 Top "G": 9885 The well was bottomed about 800' west of the .oriqinal programmed ._location due to severe directional problems. It is, however, the same spacing unit. Both prospective zones are wet at the current location. in We Now Propose 1. To lay a cement plug from 10458' to 9835' 2. Lay a cement plug 5000' t° 5400' 3. Re-drill the well to its original programmed target (This confirms telephone conversation with your Mr. Vonderahe Sunday, October 13, 1968.) TITLE ASS ' t. SuperinteDdent CO~DITiO~ OF AF~ROYAL, IF AN~: 10/14/68, See Instructions On Reverse Side l~rm No. REV. 9-30-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF 'DRILLING AND WOR'KOVER OPERATIONS 1. [] G,. WELL WELL OTHER 2. NAME OF OPEI%ATOR TEXACO Inc. 3. ADDRESS OF OPERATOR P.O. Box 664, Anchorage, Alaska 99501 4. LOCATiON OF W Platform Leg iA, Pile SUBMIT IN DUPLICATE AP1 NUA'IERICAL CODE API-50-133-20133 $. LEASE DESIGNATION AND S~RIAL NO. ADL %17597 T. IF INDIA~, ALOTIEE OR TRIBE NAME 8. I/NIT,FA2{~I OR LEASE NA3~E State of Alaska 9. %VELL NO. TS ~3 10. FIELD A_ND POOL. OR WILDCAT Trading Bay 11. SEC., T., R., M., (BO~I'OM HOI-.E ommcTrvE) Sec 34, T10N, R13W S.M. '12, PEP. MIT NO. 68-65 13. REPORT TOTAL DEiPTH AT END oF MONTH, CHA_NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AATD VOLD-NIES USED, PERFOP~ATIONS, TESTS A/WI) RESULTS, FISHING JOB~, JUNK IN HOLE A/ND SIDE-TI~ACKED HOLE AND A/~Y OTH]ZR SIGNIFICANT CI~.a. NGES IN HOLI~ CONDITIONS. Sept ,,e.., ~ ~mb.er,,,., 1~.968 September 1 September 24 September 30 Drilling a 12¼" hole below 4352'. Drilled 12¼" hole to 8525' and ran D.I.L. dipmeter logs. Drilled a 12¼" hole to 9137'. and RECEIVED OCT DIVISION OF MINE5 & MINEP, ALS ANCHORAGE S~GN~D ' rZTLE ASs't. Dist. Supt. DAT~ October 1, 1968 E--Report~n this form is required for each calendar month, regardless of the status of operations, aha must ~ filed in cluplicate Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. ~p~ 20, :1968 Texaco ]:nc., operator ~~ :is 'your approved copy. of Sundry Notice (1'-3) for ~e ~ cap~ well. Karl L. Veuder~e ~e~eoleum F~tneer ~nc~e Form REV. 9-30-45 ,.STATE O,F ALASKA Submit "Intentions" in Tripticate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY N'OTICES AND REPORTS ON WELL~ (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERMIT~" for such proposals.) 1. 0IL ~. OAS ~--~ WELL WELL OTHER 2. NAME OF'OPERaTOR TEXACO Inc. 3' ADDRESS OF OPERATOR P.O. Box 664, Anchorage, Alaska 99501 4. LOCATION. O,F WELL At surface 618 ' South and 2068 ' West from the northeast corner of Sec.. 34,. T10N-Ri3W,. S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. Kelly Bushing 14. ~, API NUMERICAL CODE ' APT 50-133-20133 6. LEASE DESIGNATION A-ND SERIAJ~ NO. ADL ~17597 ?. IF INDIAN, ALLOTTEE OR TRIBE NA1VLE 8, UNIT, FA/{1VI OR LEASE NAME State of Alaska 9. WELL NO. Ts #3 10. FIELD AND POOL, OR WILDCAT Trading Bay 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, T10N-R13W, ~. pzRm~ ~o. (~B = MSL + 92') 68-65 Check Appropriate Box To [ndi'cate N~ture of N~°ti'ce, Report, or Other S.M. NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERINO CASING SH00TINOl 0R ACIDIZINO ABANDON,MEN'T* (Other) N oTE: RepOrt:results of multiple completion on Well ompletion Or Reeompletion RePort and L0~ form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. We now propose to drill 12¼" hole to 10, 000 '~ 'and run 9 5/8" 43.~ to 47~, N-80 & P-110, LT&C casing; this casing Will be cemented with ~00 sx. of cement (minimum). We also propose to drill 8½" hole to 11,200' MD (ll060!TVD) at the same bottom hole location' previOusly specified: 670' South and 550' West from the NE corner of Sec. 34, T10N-R13W, S.M. We anticipate encountering the top of the West Foreland Zone at 10360' MD (10240'TVD) at the above location. An intended completion program will be reported after we have logged the well. RECEIVED ',,., () 19g8 DIVISION OF MINES & MINERALS ANCHORAGE 16. I hereby c~4~y tha~ :-the, for.~_~oin~ is .t~ and correct FAW: jm TITLE DATE DATE See [nstrucfions On Reverse Side .-,9- ! 7-~8 f REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF :DRILLING AND WOR'KOVER OPERATIONS SUBMIT I/%1' DUPLICATE ~. AP1 NI/MERICAL CODE APl 50-133-20133 6. LEASE DESIGN'AT'ION AND SERIAL NO. ADL #17597 1. ?. IF INDIA]~, ALOTTEE OR TRIBE NAME OIL [] GAS ~ W,LL WELL OTHER 9. NAME OF OPEI%ATOR 8. I/NIT,FA3~M OF[ LEASE NAME Texaco Inc. State of Alaska 3. ADDRESS OF OPEI{ATOR 9. WELL NO. P.O. Box 664, Anchoraqe, Alaska 4. LOCATION OF W~3-~- Platform Leg iA, Pile #1 99501 10. FIELD AND POOL, OR WILDCAT _ Tradinq Bay 11. SEC., T., R., 1%I.~ (BO'i'rOM HOLE O BJF, CTrVF_D T10N, R13W Sec. 34, 1~-. PIgR1VIIT NO. 68-65 13. REPORT TOTAL DEPTH AT END oF MONTH, cHAI%GES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A2N-D VOLUIVIES USED, PERFOt{ATIONS, TESTS A/ND RESULTS. FISH/NG JOB~, JUNK I.N HOLE A_ND SIDE-TI~ACKED HOLE A_ND A_NY OTH~ER SIGNIFICANT CIiA/~GES IN HOL~ COI~DITIONS. Auqust, ..... 1968~ August 21 - 23: Spudded in, 8-21-68, drilled 12¼" hole, then opened to 17½", to 1400'. August 24 - 25: Ran 13 3/8" casing to 1379' and cemented with 800 sacks cement around shoe and with 1350 sacks cement in annulus. Drilled to 1494. August 26 - 29: Drilled 9 7/8":hole 1494 - 3431. Opened hole to 12¼" from 1400' to 3216'. Stuck pipe. Recovered fish. August 30 Opened hOle to 12¼" from 3216 to 3431. Drilled 12¼" hole to 3531. August 31 Drilled 12¼" hole 3531 to 4352. ANCHORAGE 14. I hereby certify that the foregoing is true and correct s~o~ fi' cYL ~~~ . ,,/r~... 'nT'LE Ass 't. Supt. D,"~ 9-6-68 VOTE--Report on this {orr, is required {or each calendar mo~th, regardless o~ the status o~ operation% ang most De with the DMs}on o{ ~i~es & Minerals by the I5th o~ the succeeding r.onth, un~ess othe~ise directeg. ~-~-~ is l~0ur approved ~ o~ S~ndr~ ~oCice 0~-3) for the .- r /r / ~i L. VenderAhe ~be~~ Alaska tlarl L, Vo~erAhe Pe~role~, ~l~er :may Er~l~re~ Form 1=--3 STATE O,F ALASKA SUbmit "Intentions" in Triplicate & :~Subsequent Reports" in Duplicate OIL AND GAS CONSERVATIO,Ni CO,MMI]-rEE SUNDRY NrOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoi~. Use "A/~PLIC~TION FOR PEi~NIIT~" for such proposals.) ;~' API N~CAL CODE ' ' API 50-133-20133 $. LEASE DESIGNATION AzND SERIA~L NO. ADL $17597 ?. IF INDIA.N, ALLOTTEE OR TRIBE NA/VLE 0IL [] (]AS ~--~ WELL WELL OTHER 2. NAME OF OPEB2%TOR 8. UNIT, FAB/VI OR ~SE NA/~IE TEXACO Inc. State of Alaska 3. ADDtLESS OF OPEI%ATOR 9.V¢~LL ~O. P.O. Box 664, Anchorage, Alaska 99501 TS ~3 4. LOCATION O,F WI~I.~L Atsur~ace Platform Leg lA, pile 10. FIELD AND 1=OOL, OR WILDCAT Tradin9 Bay 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Or' 618' South and 2068' West from the northeast corner of Sec. 34, T. 10N-R. 13W, · 13. ELEVATIONS (Show whether DF, RT, Gl{, etc. S~M, DF Sec. 34, T10N-R. 13W, 12. PER/VIIT 1~O. 68-65 (~elly BUshin9); KB = MLW + 92' Check Appropriate Box To I~nc{i,caSe Nlature of N~oNce, Report, or Other NOTICE OF INTENTION TO: TEST WATER SHUT-OFF II PULL OR ALTER CASING FRACTURE TREAT I~l MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZING ABANDONMEN'T$ · (Other) NOTE: RePort results of multiple completion on Well omp!etion or Recompletion Report and Log form.) S.S. 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including e~timated date of starting any proposed work. · We have found it necessary to change the surface location of this Well from Platform-Leg 3A, pile ~5 to Platform Leg lA, pile #1 to adequately utilize our two drilling rigs. ', // ANCJ.-'IOP~G E " FAW/ _/._-r~_ S~ _~rber (This ~ space for State 9ffice use) APPROVED BY/ '~ CONDITIONS OF APPROVAL, TITLE Ass 't Dist. SuperintendF~%~ DATE 8-21-68 See lnstrucfions On Reverse Side AtlanticRichfieldCompany North Amerip'~ Producing Division Alaska Distr Post Office BOx 360 Anchorage, Alaska 99501 Telephone 907 279 1411 July 17, 1968 Mr. Tom Marshall Alaska Department of Natural Resources Division of Mines and Minerals 3001 Porcup i ne Dr_i ve Anchorage, A I aska TEXACO APPLI CATI ON FOR PERM I T TO DR ILL WELL TS#3 - TRADING BAY PLATFORM "A" s, ECTlON, ,34, T, ION RI3W, SM~, ALASKA ...... Dear Mr. Marshall: This will confirm our telephone conversation in which I advised you that Atlantic Richfield Company has no objections to the proposed bottom hole location of the subject well. Very truly yours~ . Gordon Dav i s Di strict Landman RECEIVED c: Claude H. Brown Texaco, Inc. Box 664 Anchorage, Alaska 99501 J U L 1 ~, 1968 DIVISION OF MINES & MINEf<AL~ ANCHORAGE · GD: jh FORM SA - I B 125.5M 8/67 MEMORANDUM TO: F- FROM: State of Alaska DATE : SUBJECT: July ].7, 1968 FORM SA- 1 B 125.5M 8/67 MEMORANDUM State of Alaska FROM: DATE : SUBJECT: My 1,7, 1.968 Bay TS 13 Te=aeq Zue., Operm:or ~ ~~ for permit zo drLl.l., i the ~ of SM.O0 fer flltu8 fee. Very t:~'uXy yours, ~ R. 1,farmhalX, Jr. TEXACO P. O. BOX 664 ANCHORAGE, ALASKA 99501 ~ Offb sex ~ Claude H, Brown Form HEV. 9'30-67 SUBMIT IN TRI~ ATE (Other instructions on reverse side) STATE OF ALASKA OIL AND. GAS CONSERVATION ,CO,MMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK IR. TYPE OF WORK DRILL I'XI DEEPEN I-] PLUG BACK I-'l b. TYPE OF WELL 8INGLE ~ MULTIPLE ~ 0IL[] WELL OAS ~-~ OTHER ZONE ZONE WELL 2. NAME OF OPERATOR TEXACO Inc. 3. ADDRESS O~ OPERATOR Post Office Box 664~. Anchorage. Alaska 99501 4. LOCATION O~F WELL Atsurface P~atform %eg 3-A- Pile %.,.5. ?~ ,' ~.: 7, / ' At proDosedprod, zone 670' South and 550' West .of the Northeast qorner of Section 34,~ ?IJ~I'~R13W, SM 13. DISTANCE IN MILES AND DIRECTION F.%OM NEAREST TOWN OR-POST OFFICe* 27.3 miles South. 21° 10' _:East from!.Kenai,: Alaska I4. BOND INFOR/V~ATION: TYPEStatowideuretyand/orNo. B--17 dated J.m~uary ..18, 1962 15. DISTANCE FROM PROPOSED~''-: ":~ ' JiB: -NOi :OF'ACRES IN LEASE LOCATION TO NEAREST J PROPERTY OR =ASE LINE, FT.- ' 5,120 (AL~o to nearest drig, unit, if any) ' .... I ' ) 19, P~'OPOSEI)'DEPTH 10,300 ' Rotary AP] 50-133-20133 ~. LEASE DESIGNAT%ON ~ SEJ~IAJ~ NO. ADL ~17597 ?. IF INDIAN, ALLO~CEE OR TRIBE 8. UNIT~FAPdV[ OR LEASE NA~%~E State of Alaska 9. WELL NO. TS%3 10. FIELD AND POOL, OR WILDCAT Tradin9 Bay 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVEs) Section 34, T10N-R13W, SM ~o,,-, $100,000 l~. ~o: ACR'~S ^SSISNED ~. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING . COMPLETED. . - OR APPLIED FOR, FT. 1,175' -. MD 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) 22. APPROX. DATE WORK WILL START* DF (Kelly Bushing); KB=MLW+92' . August 1, 1968 23. - I:~OPOSED ~CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CKSmGI. WEiGH~PER ~O~- GRIEVE sETTING'DEPTH ' ' ' : '' ' QUANTITY OF CEMEN'I "17%" 13 3/8" 54.5% 'J-55 1,350' 810sx 9 7/8" 7" .. 23-26-29, , N-80 .... 10,300'. .. iL' ': '[-' . ' ' ' ' . ' ' ,, , Atlantic-Riff!eld Company is an affected operator, in accordance 1! ~ · :' * Ill with Section 2060--' ,Dev-~at~on- of the Conservation Regulations; they have. been furn'~she~ a copy of this application by Registered Mail. · .. · ,: ' ..:. _.~, _,. ~i;..:. ~. . FAW:--dV~ ABOVE SPACE DESCRIBE PROPosED-- PROGRA/~: If proposal is ~ dee~n or plug ~ck, give ~ on preen% p~du~tve ~d pressed ~w produ~ive ~e. If pro~ ~ W ~ill or d~n ~ect 2onally, give pe~en% ~ on subsu~ace ~at~ ~d meas~ ~d ~ue vert~al dept. Gi~ blo~ut preventer progra~m. 24. I he;e~y ce~-that the. For~gg~g is ~ ~ C .... ~ Assistant District S'GN~ ~'~' ~~~~ July 10, 1968 =~Super~tendent (This space for State office use) SANLPLES AND CORE CHIPS REQUII~ED [] YES ~ No [DIRECTIONAL SURVEY I:tEQ~ ~1 YES [] NO PERMIT NO_ CONDITIONS OF APPROVAL, IF ANY: tOTHER RE~U~S: A.P.I. NUME~CAL CODE 5' o - /33 - 2..0 / 3~ ~ /~/~~ l Executive Secretary APPROVED B~/' [; ~ . .TITI.,E.AIo-~ko Oil & Gas *S~ I.~.cti°% O~~~mmilt~ DATE 2O 27 26 9N Unim A*I4 o ,33 A.15 o A-6 0 A-8 A'2 O o 0A.IO 0A'9 OA*7 Monopod Texaco-Superior ,,.// Trading B~y .----.--.-~/'~ T,~ ,~ Platform "A" / ~ ~ ~ ~ / , / / , ,. / ,' / / ,. / / , / / / ,34 ,, / , // / /, / / / TS'2 3 ARCO "~ TBS no.I 35 +Unio~ TB.3 A,5 0 UM TB'I PLAT OF WELL LOCATIONS fOR TEXACO, INC. DATE; 14 MAY 1968 I EM. LINDSEY 8~ ASSOC. scar: ~", -ooo' I Land 8~ Hydrographic I 'Surveyors ' CC. I E~02 W. NORTHERN LleHT S BLVD.. DRWN* ICHKD' I ,,_~.~4 , SPENARD. BOX 4_O8, ALASKA DRILLING PROGRAM TEXACO - SUPERIOR TRADING. ..BAy STATE WELLS TS~3 AND TS~4 1. Drill a 12¼" hole to 1350'+ K.B. (36" Piling drive to + 300' K.B.) 2. Run electric log and other services. 3. Open hole to 17½" and run and cement 13 3/8" casing at 1350'+. 4. Install 13 5/8", 3000# Hydril and positive gates. 5. Drill 9 7/8" directional hole to TD. 6. Run electric log and other services. 7. Run and cement 7" casing. 8. Complete the well in accordance with existing field rules. MUD' PROGRAM: Depth ~ Viscosity ~ater Loss TyPe 0' - 1,350 ' 70-75 75-100 .... Gel-water 1,350 ' - 4,000 ' 70-80 40- 60 6-10 Gel-water 4,000' - T.D. 70-80 40- 50 4- 8 Low solids ~. Lignosul- fonate FAW: dvg 7/8/68
