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Home My WebLink About178-088Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov December 13, 2021 Mr. J. Edward Jones Plugging Inlet, LLC 6733 South Yale Avenue Tulsa, OK 74136 Re: Location Clearances Aspen 1 (PTD #2051110) Moquawkie 1 (PTD #2030690) Kaloa 2 (PTD #2040960) Moquawkie 3 (PTD #2050800) Lone Creek 1 (PTD #1980840) Moquawkie 4 (PTD #2070840) Lone Creek 3 (PTD #2050970) Simpco Moquawkie 1 (PTD #1780470) Lone Creek 4 (PTD #2070910) Simpco Moquawkie 2 (PTD #1780880) Dear Mr. Jones: On December 20, 2019, the Alaska Oil and Gas Conservation Commission (AOGCC) received the final Well Completion Reports for the plugging and abandonment of the following wells: Aspen 1, Kaloa 2, Lone Creek 1, Lone Creek 3, Lone Creek 4, Moquawkie 1, Moquawkie 3, Moquawkie 4, Simpco Moquawkie 1, and Simpco Moquawkie 2. On June 15, 2021, AOGCC waived witness of each location status and an environmental site assessment (ESA) was conducted by Environmental Management, Inc. on June 17, 2021. AOGCC received a copy of the ESA report along with accompanying photographs of each site on December 7, 2021. Each drill site was found to be in compliance with onshore location clearance requirements as stated in 20 AAC 25.170. The AOGCC requires no further work on the subject wells or locations at this time. However, Plugging Inlet, LLC remains liable if any problems were to occur with these wells in the future. Sincerely, Jessie L. Chmielowski Jeremy M. Price Commissioner Chair, Commissioner itCIRI January 14, 2020 James Regg, Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 71h Avenue, Suite 100 Anchorage, AK 99501 �T ons WrInVeColprwation RE: Onshore location clearance, Plugging Inlet Site located: T12 N R12W, T12N Ri1W, T11N R12W, T12N R11W SM Dear Mr. Regg: This letter is submitted to formally request that the Alaska Oil and Gas Conservation Commission (AOGCC) withhold the site clearance at the location formerly operated by Aurora Gas, LLC. Tyonek Native Corporation (TNC) and Cook Inlet Region, Inc. (CIRI) are the majority landowners within the area and did not have the opportunity to conduct an on-site inspection prior to the 2019 snowfall. CIRI and TNC will conduct an on-site inspection of the property in the spring to ensure the site is reclaimed to the satisfaction of both landowners. TNC and CIRI appreciate the AOGCC's continued cooperation during this process. If you have any questions, please contact Suzanne Settle at (907) 263-5150 or Connie Downing at (907) 272-0707. Sincerely, Tyonek Native Corporation 1 Connie J. Downing Chief Administrative Officer Cook Inlet Region, Inc. Suzanne Settle VP, Energy and Infrastructure Colombie, Jody J (CED) From: Regg, James B (CED) Sent: Monday, January 6, 2020 12:26 PM To: Colombie, Jody J (CED) Cc: Schwartz, Guy L (CED) Subject: FW: Site Clearance - Plugging Inlet See email from CIRI below. Looks like we received the 407s for these December 20 according to the 400 -Logs. Plugging Inlet dragged out the P&As so long this past fall that we were unable to get to locations for site clearance inspections before weather turned (actually had an Inspector and CIRI rep at the airport ready to fly over for site clearance inspections but flights were canceled for weather and there has been snow on the well sites since). Wells affected are: - Aspen #1 (PTD 2051110) - Kaloa #2 (PTD 2040960) - Lone Creek #1 (PTD 1980840) - Lone Creek #3 (PTD 2050970) - Lone Creek #4 (PTD 2070910) - Moquawkie #1 (PTD 2030690) - Moquawkie #3 (PTD 2050800) - Moquawkie #4 (PTD 2070840) - Simpco Moquawkie #1 (PTD 1780470) - Simpco Moquawkie #2 (PTD 1780880) Jim Regg Supervisor, Inspections AOGCC 333 W.7'^ Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.reggPalaska.eov. From: Colleen Miller <cmiller@ciri.com> Sent: Monday, January 6, 2020 11:09 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Connie Downing <cdowning@tyonek.com>; Suzanne Settle <SSettle@ciri.com>; David Kroto <dkroto@tyonek.com> Subject: Site Clearance - Plugging Inlet Good Morning Jim. I hope you had a great holiday! I'm writing to let you know that CIRI and Tyonek will be issuing a joint letter to request that the AOGCC withhold the site clearance on the Westside until CIRI and Tyonek have an opportunity to get boots on the ground in the spring. As always, please call me if you have any questions. Colleen 263-5117 The information contained in this CIRI email message may be privileged, confidential and protected from disclosure. If you are not an intended recipient, please notify the sender by reply email and delete the message and any attachments immediately. The use, disclosure, dissemination, distribution or reproduction of this CIRI message or the information in it or attached to it by any unintended recipient is unauthorized, strictly prohibited by the sender, and may be unlawful. Thank you. The information contained in this CIRI email message may be privileged, confidential and protected from disclosure. If you are not an intended recipient, please notify the sender by reply email and delete the message and any attachments immediately. The use, disclosure, dissemination, distribution or reproduction of this CIRI message or the information in it or attached to it by any unintended recipient is unauthorized, strictly prohibited by the sender, and may be unlawful. Thank you. 2 May 13, 2020 RECEIVED MAY 18 2020 Jeremy M. Price, Chair AOGCC Alaska Oil and Gas Conservation Commission 333 West 7"' Ave., Suite 100 Anchorage, Alaska 99501 RE: Request for Information 20 AAC 25.300 Docket Number: OTH-20-035 Costs to Plug and Abandon Wells on CIRI Leases Dear Mr. Price: Regarding your letter to me of May 1, 2020, the following information is responding to your request for costs incurred to plug and abandon the following wells on mineral interests owned by Cook Inlet Regional, Inc. (CIRI): • ASPEN 1 – API 50-283-20114-00-00 • KALOA 2 – API 50-283-20107-00-00 • LONE CREEK 1– API 50-283-20096-00-00 • LONE CREEK 3 – API 50-283-20112-00-00 • LONE CREEK 4 – API 50-283-20121-00-00 • MOQUAWKIE 1 –API 50-283-10019-90-00 • MOQUAWKIE 4 – API 50-283-20120-00-00 • SIMPCO MOQUAWKIE 1 –API 50-283-20060-00-00 • SIMPCO MOQUAWKIE 2 – API 50-283-20062-00-00 Plugging Inlet, LLC, was the operator of these wells and conducted plugging and abandonment (P&A) operations between October 2018 and November 2019. Costs were tracked on the basis of vendors, not by well or activity. Thus, while some costs, totaling about $1,007,000, were paid to vendors who worked solely on the P&A of the wells (e.g., Schlumberger, Pollard Wireline, and Halliburton), most of the vendor;/contractors also worked on DR&R, cleanup, and waste disposal operations. Thus, the costs of these vendors/contractors for P&A operations were estimated on the basis of the Summary of Operations, based on the daily reports—these include camp costs, air and marine transportation, supervision, welder and roustabouts, trucking, and equipment rental. It is estimated that another $595,000 were paid to these other contractors and vendors for services supporting P&A work for a total estimated cost to P&A the 10 wells of $1,602,000, or $160,200 per well. However, one well, the Lone Creek 1, was particularly problematic to P&A due to its original construction, and the cost to P&A that well is estimated at about $244,000, leaving the average cost to P&A the other 9 wells at $151,000. For clarity, the reported $1.6 million is for actual well plugging and abandoning costs only; in addition, Inlet Plugging LLC incurred approximately $3.4 million for associated lease remediation activities, including required deconstruction & removal of surface production equipment and restoration of the sites, cleanup of contamination (mostly compressor oil leaks under buildings and some small spills), disposal of waste (including historic drill cuttings and mud solids, contaminated gravel and soil, and used oil and glycol), required Mr. Jeremy M. Price 5/13/20 Page 2 surface use payments, transportation of salvaged equipment and waste, and associated expenses. If you have any questions or require additional information, please contact me at 713-899- 8103 or by email at jejones@aurorapower.com. Sincerely, �ZG 9!Edward Jones Operations Consultant for PLUGGING INLET, LLC 6733 South Yale Avenue Tulsa, OK 74136 CC: Suzanne Settle and Colleen Miller, CIRI Thomas Redman, Jim Sullivan, Mark Can, Plugging Inlet, LLC THE STATE "ALASKA May 1, 2020 GOVERNOR MICKNE•L I. DUNLEAFY J. Edward Jones Operations Consultant Plugging Inlet, LLC 6733 South Yale Avenue Tulsa, OK 74136 Re: Request for Information 20 AAC 25.300 Docket Number: OTH-20-035 Dear Mr. Jones: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov The Alaska Oil and Gas Conservation Commission (AOGCC) requests documentation of the actual costs incurred to plug and abandon the following wells: • ASPEN 1 —API 50-283-20114-00-00 • KALOA 2 — API 50-283-20107-00-00 • LONE CREEK 1 —API 50-283-20096-00-00 • LONE CREEK 3 —API 50-283-20112-00-00 • LONE CREEK 4—API 50-283-20121-00-00 • MOQUAWKIE 1 —API 50-283-10019-90-00 • MOQUAWKIE 4 — API 50-283-20120-00-00 • SIMPCO MOQUAWKIE 1 —API 50-283-20060-00-00 • SIMPCO MOQUAWKIE 2 —API 50-283-20062-00-00 The wells are located on mineral interests owned by Cook Inlet Regional, Inc (CIRI). In 2017, Plugging Inlet, LLC was designated operator of record for the wells. This request is made pursuant to 20 AAC 25.300. Should you have any questions about the information request, please contact Guy Schwartz at 907-793-1226. Sincerely, v Jeremy M. Price Chair, Commissioner cc: Suzanne Settle VP Energy, Land, Resources CIRI SFD 3/25/2020 C-061390 DSR-3/25/2020 xG 28. CORE DATA Conventional Core(s): Yes ❑ No ..R" Sidewall Cores: Yes ❑ No `t'" If Yes, list formations and intervals cored (MDfFVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. No cores were taken in P&A operations 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. See original 10-407 Formation at total depth: 31. List of Attachments: Summary of daily operations, Wellbore Diagram, and Photos of casing cut-off and maker ID plate. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, oaleontological reoort, oroduction or well test results er 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Ed Jones Contact Name: Ed Jones Authorized Title: _ Operatio s Consultant Contact Email: Authorizedj Contact Phone: 713-899-8103 \ f /l&-/ Signature: Date: INSTRUCTIONS General: Th form and the re fired attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only PLUGGING INLET, LLC SIMPCO MOQUAWKIE #2 (AOGCC PERMIT No. 178-088) (API No. 50-283-20062-00-00) PLUG AND ABANDONMENT DAILY OPERATIONS SUMMARY FORM 10-407 7/22/2017—Aurora Gas operation. RU Pollard Slickline (SL). RIH with gauge ring to 5280' and tag F profile. RIH with Baker FWG plug and set in F profile I sliding sleeve (SS) at 5280'. POOH. Bled off tubing—monitor pressure for 30 minutes—no buildup. RD SL. 10/23/2018—RU SL. Run 2.23" LIB to tag FWG plug at 5272' (WLM), FL at 280'. RIH and pull prong. RD. C,f(j P s > 10/24/2018—RU SL. RIH and pull Baker FWG plug at 5780'. Run LIB to 5600'. RD SL. RU Alaska E -line (AEL). RIH with CIBP for 2-7/8" tubing correlate, and set at 5336'_ RD AEL. RU Pollard Hot Oil Truck (HO). Pump down 1" heater string with returns up IA. Test IA to 1525 psi for 30 minutes—good. RU on 9-5/8" X 7" OA and pump 15 bbl water into formation at 3 BPM, 500 psi. SI -400 psi in 15 minutes. RU on tubing and test to 1650 psi for 30 minutes—good. RD HO. 10/27/2018—RU HO. With AOGCC inspector, test IA to 1550 psi for 30 minutes. OA -20 psi. Test tubing to 1600 psi for 30 minutes. IA -30 psi, OA -20 psi. Good tests. RU SL. RIH with shifting tool and open SS at 5280'. RD. Ready to cement. 11/5/2018—RU Schlumberger. Heat 3 loads (200 bbl) of water to 80°, add chemical. Test lines to 3150 psi. Open IA and pump 1 bbl water—no circulation. Pump down tubing -2000 psi with 4 0.3 bbl pumped—no circulation. RU SL. RIH and attempt to open SS at 5280'. No circulation. RU AEL, RIH with tubing punch perf gun, correlated, pressure tubing to 400 psi, and perforate tubing with 10 JS, top at 5208'.. Pump 10 bbl with returns up IA -400 psi at 4 BPM. SD. 11/6/2018—Heat water to 80°, 10 bbl to 100°. RU SLB. Test lines to 2000/2565 psi. Open OA and inject 1.5 bbl water at 400 psi. Pump into heater string in IA with good returns out IA. / Batch cement and pump 10 bbl 13.5 ppg Class G cement down OA at 1.5 BPM, 610 psi max (final PIP -300 psi). Pump down IA, up tubing—cement to surface after 190 bbL, Pump I bbl �,'►� down heater string. 193.6 bbl total pumped down IA and heater string. Total cement pumped 203.7 bbl Class G at 13.512pa. 1.70 cf/sk. Minimal diesel (original freeze protection) in returns. Wash outlines and RD. 11/8/2018—RU HO. PT tubing to 3000 psi -2900 in 15 minutes. PT IA to 3200 psi -3050 in 15 minutes. RD HO. 7/6/2019—Start cutting off wellhead and casings. 7/12/2109—Finish cutting off wellheads and casing T3" from top of pad. 7/15/2019—Level casing cuts. 7/16/2019—Finish leveling casing cuts. Added some cement to top off with casing cuts. 10/8/2019AOGCC inspector Lou Laubenstein inspected casing cut offs—OK._ 10/11/2019—Expand cellar excavation due to wet soil conditions and cave-in concerns. Weld ID marker plate on 13-3/8" conductor casing. 10/14/2019—Backfilled cellar, burying cut-off casings and marker. 11/1 - inspector Guy Cook unable to fly from Anchorage due to weather. ancelled site clearance inspection. - ,, 12/10/2019 Plugging Inlet, LLC Simpco Moquawkie No. 2 RKB 16' PTD: 178-088 AP1# 50-283-20062-00- 00 ACTUAL P&A WELLBORE DIAGRAM OCTOBER 2019 Bullhead 10 bbl (33 sx) Class G cement at 13.5 ppg, 1.7 cf/sk down 7"X9-518" annulus -0 to 3901. Prod Perfs: 5666- 5706' 7" 26# & 29# S-95 Casing set at 5739' and cemented w/ 250 sx at shoe (+ 315 sx thru DV) Prod Perfs: 5880-5900' 5888-5908' PBTD est. at 4090' TD @ 6727' MD • 2 7/8" 6.5# 8 Rd Tubing to 5920' 13-3/8" 61# K55 Conductor drilled 17-1/2" hole to 92ft cemented to surface w/ 100 sx 1.315" 1.8# 3-55 heater string R� to surface to 1103' Ay COMBINATION PLUG: Production perf plug, Surface casing shoe plug and surface plug from surface to 5350' in `.' annulus, tubing full of cement, and heater string full of cement. Circulate 193.7 bbl Class G cement at 13.5 ppg, 1.7 cf/sk down IA, including 1 bbl down heater string. 9 5/8" 43.5# & 47# N80 Surface Casing } set at 1105' • S? Cement w/ 535 sx cmt to surface - ; Good cement bond to 2250' by CBL of 2/2/79 DV tool at 3081' —cemented w/ 315 sx Set CIBP inside tubing in top of packer at 5336'. Perf tubing at 5208'. C' - •; Baker Model L Sliding Sleeve @5280' - r+ Clf3°(Closed) t Baker Model FBA Retainer Production r Packer, Seal Bore and Millout extensions, packer locator nipple @ 5,352' A Blast joints 2.44" ID @ 5653-5712' Baker model L Sliding Sleeve (closed) @ F •r `� 5712' (2.25" profile) Baker Model FAB 30 retainer production packer (� 5853' Cut tubing at +/- 5870' in 2013 _•,. Reperforated 5888-5908' in 2013 r r No go nipple R Profile 2.25" @ 5919', Mule Shoe @ 5920' +* 5" 18# N-80 Liner 5404-6090' cemented w/ 100 sx G ` • S/"VT Go /v1 d�t(AWk-1--- 2- D/, z ■ w r ; � � •,aT�#l4 r ,4 t ji { . g r ; � � •,aT�#l4 r ,4 t ji { %�oG� �tal�✓�� Z L414717, P,-J - loo'klnl SI YI� CO �DD� icy Alo-,A ` J 6733 South Yale Avenue Tulsa, OK 74136 Plugging Inlet, LLC Contact: Ed Jones, Consultant 713-899-8103 (C) email: jejones(cb.aurorapower.com December 17, 2019 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage AK 99507 RE: Form 10-407 Well Completion Reports for Plugging and Abandoning: Aspen 1 (WDSPL) PTD 205-111 Kaloa 2 PTD 204-096 Lone Creek 1 PTD 198-084 Lone Creek 3 PTD 205-097 Lone Creek 4 PTD 207-091 Moquawkie 1 PTD 203-069 Moquawkie 3 PTD 205-080 Moquawkie 4 PTD 207-084 Simpco Moquawkie 1 PTD 178-047 Simpco Moquawkie 2 PTD 178-088 Dear Commissioners: Enclosed are the Form 10-407 P&A Completion Reports for the above wells, formerly operated by Aurora Gas, LLC, now operated by Plugging Inlet, LLC, all on CIRI leases located on the west side of the Cook Inlet. All the wells have been plugged and abandoned as per AOGCC approved Sundry Application Form 10-403 or as revised approvals. Attached to each Form 10-407 are: 1) Summary of Daily Operations, 2) Final P&A Wellbore Diagrams, 3) Photos of the casing stubs before and after welding on ID marker plates, and 4) Four photos of each of the well (and facility, when appropriate) location pads at the end of the operations in November. Unfortunately, there remained a small amount of location work to do on 4 of the locations prior to being weathered out, but the landowner, Tyonek Native Corporation is aware of this work, and it will be completed by their subsidiary, Tyonek Contractors, when the weather and ground conditions allow. Please let me know if you need more information. Thank you. ..� Sincerely, dSdward (Ed) Jone Consultant CC: Colleen Miller, CIRI (electronic) David Kroto, Tyonek Native Corporation Tom Redman, Mark Carr, Jim Sullivan, Plugging Inlet, LLC MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg I z/`f t i DATE: 10/13/19 P. I. Supervisor FROM: Lou Laubenstein SUBJECT: Surface Abandonment Petroleum Inspector Simpco Moquawkie #2 Plugging Inlet LLC PTD 1780880' Sundry 318-344 10/8/19: 1 arrived on location for the surface abandonment inspection on Simpco Moquawkie #2. David Wallingford was the Company representative on location for the day's inspection. Solid cement was confirmed at surface in the cutoff well. The casing cutoff depth was only cut to 3-4 feet below the current pad grade and not the proper depth of 3 feet minimum below original ground level. Although this well was the deepest cut I am not sure it is deep enough. This was discussed with Mr. Wallingford. Inspection Supervisor Addendum: On 10/10/2019 Plugging Inlet was given approval by AOGCC to proceed with abandonment, leaving the well cut-off depth as is. Attachments: Photos (3) Email — Plugging Inlet Casing Cutoff Proposals 10/10/2019 2019-1008_Surface_Abandon_simpco_Moquawkie-2_11. docx Page 1 of 3 ?), q m 31 Rv -tvk '34, �NKWA •, a♦ l Itp I�.A�� •Y, / .�p��/ , �, �I Nay a*Y .� l�-�� !`� t a'Ziy :;� ) J Aw ' p'm Q , • tD r z yr m 00 k -j co ...egg4 No's cs V sI •�mi1 'i CA- Q CIC V 1�/\ 1 7M� � i �� .°M1.l,M1rj LtQlli[.f2�Z Regg, James B (CED) From: Regg, James B (CED) Sent: Thursday, October 10, 2019 9:39 AM To: Schwartz, Guy L (CED) Subject: RE: Plugging Inlet Abandonments I agree with what they have proposed. 48 hr notice after cutoffs for inspections. Jim Regg Supervisor, Inspections AOGCC 333 W.7t^ Ave, Suite 100 Anchorage, AK 99501 907-793-1236 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or i im.rezz(@alaska.gov. From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Thursday, October 10, 2019 9:07 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Subject: FW: Plugging Inlet Abandonments fyi Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv schwartz@alaska aov). From: J. Edward Jones <Jejones@auroraoower com> Sent: Thursday, October 10, 2019 8:44 AM To: Schwartz, Guy L (CED) <guy,schwartz@alaska eov> Cc: Regg, James B (CED) <lim.re¢Q@alaska.gov>; David Wallingford <david996@vahoo.com> Subject: RE: Plugging Inlet Abandonments Guy, Please see what we propose for cutoff depths of the wells and reason below (I have also attached a Word document of the same info and proposal). Please let me know if these proposals are acceptable, in particular Moquawkie 4 and Simpco Moquawkie 2. Lone Creek 1 needs more excavation for specific proposal. Please feel free to call if you need to discuss (713-899-8103). Thanks, Ed PLUGGING INLET CASING CUTOFF PROPOSALS (10/10/19) Aspen 1 WDW (PTD 205-111): Cutoff is now 4'2" below gravel pad; Typar is 2'2" above cutoff. Plan: Dig down 1' below cut-off and recut --will be 5' 2" from top of pad. Kaloa 2 (PTD 204-096): Now 3'9" to cut off from top of gravel pad. Typar is 2' above cutoff. Plan: Dig down 1' below cut-off and recut. Will be 4'9" from top of pad. Lone Creek 1 (PTD 198-084): Cutoff is 4'3" below top of gravel pad. Gravel to bottom of excavation. Plan: Dig down to see if can find bottom of gravel. Lone Creek 3 (PTD 205-097): Cutoff is now 4'5" below top of gravel pad. Typar is 2'1" above cutoff. Plan: Dig down 1' below cut-off. Will be 5' 5" from top of pad (now in water). Lone Creek 4 (PTD 207-091): Cutoff is now 3'2" below top of gravel pad. Typar is 1'8" above cutoff. Plan: Dig down 1'6" below cut-off and recut. Will be 4' 7" from top of pad (now in water). Moquawkie 1(203-069): Cutoff is now 4'8" below gravel pad. Debris (cement and drilling mud residue) around cellar excavation from drilling issues (blowout and fire) makes it impossible to see change in gravel/soil. However, Moquawkie #3 is on same pad at same level about 100' away, based on change in soil composition there, original GL appears to be about 3'10" below top of gravel pad—see #3 below. Plan: Dig down 2' 2" below cut-off. Should give new cut-off 6' 10" from top of pad. Moquawkie 3 (PTD 205-080): Cutoff is 3'10" from top of gravel pad. Soil composition changes from gravel to clay even with cutoff. Plan: Dig down so new cut off is 6' 10" from top of pad, which is 3' down below current cut-off (now in water). Moquawkie 4 (PTD 207-084): Cutoff is now 3"5" below top of gravel pad and is 6" below Typar with clay layer under it. Plan: If necessary, dig down 2' 6" below cut-off and recut, will be 6' from top of pad. However, note that this pad was built in a cut—the original GL was 19' above top of current gravel pad (as staked plat elevation vs. as built elevation). Would the current cutoff depth be acceptable for that reason? Simpco Moquawkie 1 (PTD 178-047): Cutoff is 5'2" below top of pad and 3'2" below change in composition of gravel/dirt. Plan: Cap and bury. Simpco Moquawkie 2 (PTD 178-088): Cutoff is 7'3" below top of old gravel pad. Debris (cement and drilling mud residue) around cellar excavation from drilling issues makes it impossible to see change in gravel/soil. However, the pad is about the same leve[ as the trees just off the pad closest to the well, so cutoff is believed to be at least 3' below original GL. Plan: Cap and bury if this assessment is acceptable. From: Schwartz, Guy L (CED)[mailto:8uy.schwartz@alaska.egyj Sent: Wednesday, October 09, 2019 1:31 PM To: J. Edward Jones <Ljgnes%aurorapower.com> Cc: Regg, James B (CED) <jirn. cggL0a1askr�ov>; David Wallingford <david996@yahoo.com> Subject: RE: Plugging Inlet Abandonments 2 [V- Cge Mcphee, Megan S (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, March 7, 2019 8:13 AM To: Mcphee, Megan S (DOA) Subject: FW: CIRI P & A well status Could you place this email letter in all of the well files listed below. There should be 8 wells listed. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended reciplent(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz@alaska gov). From: Ed Jones <jejones@aurorapower.com> Sent: Wednesday, March 6, 2019 1:53 PM To: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov> Cc: George Pollock <gpollock@aurorapower.com>; Tom Redman <TomR@kfoc.net>; Mark Carr <MarkC@kfoc.net>; David Wallingford (david996@yahoo.com) <david996@yahoo.com> Subject: RE: CIRI P & A well status Guy, Following is an update on the status of each of the CIRI wells, formerly operated by Aurora Gas: Aspen 1 (WDSPL)—PTD 205-111: An MIT was performed on the well on 10/14/18, the temporary tubing plug was pulled, and the well was cleaned out with slickline bailer. Produced water disposal was commenced soon thereafter, and 473 bbl of produced water was injected into the well for disposal in 3 days October. Another 2486 bbl of produced water, returned packer fluid (while cementing or testing), and cement rinsate were injected in 13 days in November. The well and injection facility was then winterized and shut-in pending commencement of plugging operations in the spring of 2019. Kaloa 2—PTD-204-096: A CIBP was set in the tubing at 2331' on 10/26/18. The tubing and IA were pressure tested to 1775 and 1700 psi, respectively on 10/31/18 (witnessed). On 11/7 35 bbl of cement were pumped of planned 49 bbl— ran out of cement. Shut down and tested in AM—tubing to 1650 psi and IA to 1700 psi. Submitted request for remedial procedure, which was approved. Barge delivered additional cement. On 11/10/18, cement was tagged in tubing at 373', perforated tubing at 370-373', and cemented down tubing with 11.7 bbl of cement, with cement to surface after 8.5 bbl. On 11/15/18, pressure tested tubing to 2175 psi and IA to 2300 psi. No further activity was performed pending cutting off casing this spring. Simpco Moquawkie 1—PTD 178-047: the pretest of the tubing and IA in late October indicated a casing leak. A temperature survey was performed while pumping down the IA, and a casing leak was indicated at 2122-46' (old squeeze perfs). A revised cementing procedure was submitted to the AOGCC and approved. On 11/3/18, the well was cemented by pumping 1 bbl down heater string, 112 bbl of cement down the tubing until cement returns at surface, then IA was shut in and 1 bbl of cement was squeezed into old squeeze perfs resulting in a squeeze pressure of 1700 psi. On 11/8/18, the tubing and IA were tested to 1800 and 2550 psi, respectively. No further activity was performed pending cutting off casing this spring. Simpco Moquawkie 2—PTD 178-088: Tubing and casing were pressure tested (witnessed) to 1600 and 1550 psi, respectively on 10/24/18, and the tubing was perforated at 5209' on 11/5, as sliding sleeve could not be opened. On 11/6, the well was cemented: 10 bbl were pumped down OA, then 193.6 bbl of cement were pumped down IA and up tubing to surface. The tubing, IA, and OA were pressure tested on 11/8 with final pressures of 2900, 3050, and 3050 psi. respectively. No further activity was performed pending cutting off casing this spring. Mobil Moquawkie 1—PTD 203-069: Pressure tests of tubing and IA were performed and witnessed on 10/15/18. The sliding sleeve at 2513' was opened and on 11/2/18 the well was cemented with 195.5 bbl of cement slurry pumped down the tubing with cement to surface out the IA. On 11/9, the tubing and IA were tested to 2450 and 4060 psi, respectively. No further activity was performed pending cutting off casing this spring. Moquawkie 3—PTD 205-080: The well was cleaned out with slickline between 10/17 and 10/22, and a CIBP was set in tubing at 1410'. On 10/27, the tubing and IA were pressured tested (witnessed) to 2000 and 1650 psi, respectively, and the tubing was perforated at 1380'. On 11/1, the well was cemented with 36 bbl of cement pumped down the tubing, with the IA shut in after 30 bbl pumped and 6 bbl was squeezed into open Beluga perfs at 1402-69'. On 11/8, the tubing and casing were pressure tested to 2225 and 1500 psi, respectively. No further activity was performed pending cutting off casing this spring. Moquawkie 4—PTD 207-084: Pressure tests of the tubing and IA were performed and witnessed on 10/30/18—the tubing to 1725 psi and the IA to 1750 psi. On 11/4/18 the well was cemented with 37.3 bbl of cement down tubing and out IA. On 11/8/18 the tubing and IA were pressure tested to 1450 psi and 2000 psi, respectively. No further activity was performed pending cutting off casing this spring. Lone Creek 1—PTD-198-084: Closed sleeves on 11/3/18 and set CIBP in tubing at 1780'. On 11/16/18, pretested tubing an IA, and pumped 15 bbl down OA at 1 BPM. On 11/18/18, tested tubing to 1780 psi and IA to 1700 psi (witnessed). Opened sleeve at 1745'. Prepared to cement as per approved procedure in Sundry, except will likely use light -weight cement to fill IA instead of viscous spacer. Lone Creek 3—PTD 205-097: 11/2-11/5/18 closed all sliding sleeves in the well (PX plug in bottom packer at 2841' from previous operations, so tubing is closed to all perforations). On 11/17/18, tubing and IA were pressure tested (witnessed), tubing tested to 2080 psi and IA to 1500 but dropped to 1225 in 30 minutes—packer leak is suspected. Revised procedure was submitted to AOGCC to add a second plug below top packer on 11/26/18, which was approved on 12/11/18. Lone Creek 4—PTD-207-084: All sleeves are closed and there is a PX plug from earlier operations at 2057'. On 11/17, the tubing and IA were tested (witnessed) to 2200 and 2100 psi, respectively. The tubing was perforated above and below the top packer at 1078-81' and 978-81' in preparation to cement as per procedure. The plan forward is to mobilize in late April or early May depending upon the Schlumberger cementers availability, barging access, and road conditions. At that time, the 3 Lone Creek wells will be submitted as per procedures (approved revised procedure of #3 and an additional 35 bbl of light -weight cement will be pumped in the Lone Creek 1 instead of viscous spacer), which should take 7-10 days, including West Side mobilization and set up. The Wach saw will be mobilized at about that time, the well heads removed and the casing cut off, any top -off of cement will be done, steel plates welded on, and the cellars backfilled. Please let me know if you need additional information. Thanks, Ed J. Edward Jones Petroleum Consultant 4645 Sweetwater Blvd., Suite 200 SugarLand,TX 77479 713-899-8103(C) 281-495-9957, ext 201 (0) 832-999-4382 (F) From: Schwartz, Guy L (DOA) [mailto:euv.schwartz@alaska.eov] Sent: Monday, March 04, 2019 1:30 PM To: Ed Jones <jelones@aurorapower com> Cc: George Pollock <> Subject: CIRI P & A well status Ed/George, I never received a final update on the work that was done on these CIRI wells .. last update was in first week of November. I recall you requested a temporary shutdown of operations until spring to finish the wellhead cutoffs. don't have an email or any documentation that I can find for this request. You are requested to provide an update on each of the wells current status and detail your plan to return and finish the P & A wellwork. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete if, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guy schwariz@alaska aov). Well Name SIMPCO MOQUAWKIE 2 API Well Number 50-283-20062-00-00 Inspector Name: Guy Cook Permit Number: 178-088-0 Inspection Date: 10/27/2018 MEMORANDUM State of Alaska Rel Insp Num: Alaska Oil and Gas Conservation Commission Packer Depth Pretest Initial DATE: Tuesday, November 13, 2018 TO: Jim Regg I-1 .P.I. Supervisor K l l ct' I fir f a SUBJECT: Mechanical Integrity Tests ( AURORAGAS.LLC TVD 2 FROM: Guy COOK SIMPCO MOQUAWKIE 2 Petroleum Inspector 30 - 30 ` Src: Inspector Reviewed By: /� l �Q--- P.I. Supry TBR— NON-CONFIDENTIAL NON -CONFIDENTIAL Comm Well Name SIMPCO MOQUAWKIE 2 API Well Number 50-283-20062-00-00 Inspector Name: Guy Cook Permit Number: 178-088-0 Inspection Date: 10/27/2018 Insp Num: mitGDC181106065852 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2 Type Inj N- TVD 5352 Tubing 0 30 30 - 30 ` PTD 1780880 Type Test SPT Test psi 1338 IA 0 1550 - 1550 - 1550 - BBL Pumped: 1 BBL Returned: 1 - OA 20 20 20 20 Interval OTHER P/F P Notes: MIT -IA. Tested pre P&A as per Sundry 318-344. ✓ we 1 5 fits QR��CC'c' �— SCANNED DEC 2 4 Tuesday, November 13, 2018 Page I of 1 Well Name SIMPCO MOQUAWKIE 2 API Well Number 50-283-20062-00-00 Inspector Name: Guy Cook Permit Number: 178-088-0 Inspection Date: 10/27/2018 MEMORANDUM State of Alaska Rel Insp Num: Alaska Oil and Gas Conservation Commission Packer Depth Pretest Initial DATE: Tuesday, November 13, 2018 TO: Jim Regg I��GG 1 Cl i%ji6 SUBJECT: Mechanical Integrity Tests P.I. Supervisor 30 25 (( AURORA GAS LLC BBL Returned: 2 FROM: Guy Cook SIMPCO MOQUAWKIE 2 Petroleum Inspector 20 20 Sre: Inspector Reviewed By: /' P.I. Supry yJ� NON -CONFIDENTIAL Comm Well Name SIMPCO MOQUAWKIE 2 API Well Number 50-283-20062-00-00 Inspector Name: Guy Cook Permit Number: 178-088-0 Inspection Date: 10/27/2018 Insp Num: mitGDC181106070633 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2 Type Inj N _ TVD 5352 Tubing 0 1600 1600 1600 PTD 1780880 Type TESL SPT Test psi 1500 IA 10 30 30 25 BBL Pumped: 0.7 BBL Returned: o OA 20 20 20 20 Interval oT ER P/F P Notes: MIT -T. Tested pre P&A as per Sundry 318-344. Tuesday, November 13, 2018 Page 1 of 1 THECTE GOVERNOR BILL WALKER George Pollock Consultant Plugging Inlet, LLC 6733 South Yale Avenue Tulsa, OK 74136 • Alaska Oil and Gas Conservation Commission SCA"Wp AUG 3 0 2018 Re: Moquawkie Field, Undefined Gas Pool, Simpco Moquawkie 2 Permit to Drill Number: 178-088 Sundry Number: 318-344 Dear Mr. Pollock: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Plugging Inlet, LLC is to provide a daily operational summary to the AOGCC by email to Guy Schwartz guy.schwartz@alaska.gov and Mel Rixse melvin.rixse@alaska.gov once plugging operations start on the wells. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED thisZ day of August, 2018. RBDMS�,�l AUG 2 91018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS .) 20 AAC 25.280 CI, AUG AUG 0 8 2018 ®GCS 1. Type of Request: Abandon Plug Perforations i Fracture StimulateEl Repair Wei I E] Operations shutdownO Suspend ❑ Perforaw El Other Stimulate ❑ Pup -rubing M Change Approved ProgramE] Plug for Redrill E] Perforate New Pool F1 Re-enter Susp Well ❑ After Casing M Other. Temporary Plug El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Plugging Inlet, LLC Exploratory E] Development Q stratigraptmc F] Service Ei 178-088' 3. Address: 6733 South Yale Avenue 6. API Number: Tulsa, OK 74136 1 50-283-20062-400 7. If perforating: 8. WeTJ Name and Number: What Regulation or Conservation Order governs well spacing in this pod? Sirrpco Moquawkie #2 Will planned perforations require a spacing exception? Yes 0 No El 9. Property Designation Lease Number): 10. Field/Pooqs): C -2§y 10i� 14, lg� 211 & ir"3ib 1 Moguawkie Undefined Gas - - i t . it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): 'Plugs (MD): Junk (MD): 6727'- 6727' 15"' 6000' 850 psi 52W & 60901 6040' Casing Length size MID TVD Burst Collapse Structural Conductor 92* 13 3/8"61* K55 97 97 3090 psi 1540 psi Surface 1105, 9 5/8" 43.5* N80 111,06 1106 3580 psi 1580 psi Intermediate Production 5721' 7" 209 K44 5721' 5721' 3740 psi 3270 psi Liner 5" 18# N80 6090' 6090, 10140 psi 10490 psi Perforation Depth MD (ft): Perforation Depth TVD Size: Tubing Grade: Tubing MD (ft): 5666- 5908' 1 5666'- 5908' 77 2 7/8" 6.5# 5908' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (tt): Baker FB and FAB 30 packers Baker FB @ 5352' and FAB 30 @ 5853' 12. Attachments: Proposal Summary Ej Wellbore schematic 13. Well Class after proposed work: Detailed OperationsPrograrn E/ 1 BOP Sketch E] Exploratory E Stratigraphic Development P) - Service E] 14. Estimated Date for TBD 15. Well Status after proposed work: Commencing Operations: OIL E, WINJ El WDSPL E] Suspended E GAS ❑ WAG L1 GSTOR E] SPLUG 11 16. Verbal Approval: Date: Commission Representative: GINJ El Op Shutdown E] Abandoned El 17.1 hereby certify that the foregoing is true and the procedure approved herein will 'not be deviated from without prior written approval. Authorized Name: George Pollock Contact Name: George Pollock Authorized Tide: Consults Contact Email: a gollock aurora power. com Contact Phone: 907-351-8286 Authorized Signature: Date: 6 -Aug -18 C*MAftSSlON USE ONLY Conditions of appr&val: Notify Commission so that a representative may witness Sundry Number. Plug Integrity BOP Test ❑ Mechanical Integrity Test 0 'Location C Other: ✓Alo-f%rf j jLA� ikai,,141X Post Initial 4njection MIT Req'd? Yes Ej No F] Spacing Exception Required? Yes El 'No Subsequent Form Required: It) -- APPROVED BY e Approved by: COMMISSIONER THE COMMISSION Date: 'RBDM&�\AUG 2 9s=Form and Form 10-403 Revised 4/2017 /AP;OMd/ af, ication of approval. • CURRENT CONDITONS: • F-1111 Z-010�Xcflsm WELL ABANDONMENT SIMPCO MOQUAWKIE #2 Cnr%*nmhnr i 147 .�..��..a...�«..�. sem.-._. -Version -1:0-(9/1-1/17) SITP-40 psi (well dead, but have seen pressures in excess of 1000 psi). KB=12 feet above GL CASING: 726 & 29# S-95 set at 5739'MD/TVD. DV Tool at 3084'. CBL cmt top at +/- 2250'. Collapse strength -7800 psi (26#). -PRODUCTION K##.N=S0 set- at- 6090'-w/--hangertop-at-5404'. TUBING: -2=7/8", 6.5#-N-80 (?)-8 rd-EUE, w/ diesel as packer fluid -in tbg-csg apnulus above top packer and with: Sliding Sleeves: Baker Model L sleeves at 5280' w/ Baker FWG plug set (5283') and 5712' (latter with 2.25" profile) Seating Nipple: w/ 2.25" F profile at 5315' Cut -Off at 5870'. Yaekers: -Baker-k'13=1 `Detainer Production Packer -at -5382'-w/ Locator Seal Assembly With -14 seal units and Baker -Model --_FAB -30 Retainer -Production -Packer at _5M' HEATER STRING: I" Nom. (1.315" 1.8# J-55 10 Rd assumed) set at 1103'. (See attached completion diagrams) CAPACITIES: 2-7/8" 6.5# Tubing: 0.00579 bbl/ft; Tubing -Casing Annulus 26#: 0.0302 bbl/ft & 29#: 0.0291 bbl/ft. 7 26#-C;asing:-0-092-bbl/tt. & 29#:-0:037`1--bbl/it. q. t -5" -194-Liner: -O.-CI-bbl/ft. + o�V Tubing Volume to top Packer --40.0 bbl, Annular Volume to top Packer= 161.7 bbl, assuming 26# casing; Volume to deepest Perfs= 34+ bbl g lit- Sfri� '7 (114 ) OPEN PERFS: Carya 2-9.1 at 5666-5706' -C;arya 1=9.2 -at tFS8U X9025' (See wellbore diagr NOTES: 1) Well is a straight hole. SUMMARY OF PLAN: RU slickline. RIH and pull prong and plug at 5283'. Kill well with heavy brine leftover from previous P&A's (well is likely dead, but will be sure that tubing and tubing -casing annulus-are-tull). DU cementer on surface casing= -production -casing annulus. -Pump-5 -10 -bbl -water down annulus to establish a pump -in rate and pressure, monitoring tubing -casing annulus and tubint pressures. Pump ("bullhead") 50 sx Class G shut in when all is displaced into annulus (do- not overdisplace—monitor for fall backif fall back occurs, WOC and mix and pump more. RU wireline 10V 3 ' so ME" A lut�ricator on°tree.-lsU°tutting-C:MP,R-tH°and set --m- or--nearrtop ot=packer at 5 t51'. `I`est (jtt3Y`to 150CJ 15�� psi. RIH with shifting tool on slickline aP .open sleeve at- 280'. RU ce.menters.on tree {thru wing valve). Establish circulation pressure with 5-10 bbl brine at 3 BPM, circulating out diesel packer fluid (catch in closed tank—volume of 160 bbl is expected). Pump 10 bbl spacer, then 190 sx (218.5 cf=40 bbl) Class G cement with additives (15.8 ppg, 1.15 cf/sk yield) with pump time of 4 hr at 75 degrees - 3% excess, followed by 118 bbl of weighted viscous spacer, followed by 180 sx Class G cement, and displace cement to surface—this will result in a balanced plug to meet the requirements of- 1) surface casing-shoe=and 2) the surtace-plug-(first -19U sx)-and-a second -plug on -the -top -packer -to -meet -the requirements of3) the plug above the perfs (including f lag tubing) witlr the second. -184 sx. Monitor 1. for flow or fall back. Wash out tubing casing annulus to 3-4' below GL. WOC 8 hrs, pressure test to 1500 psi. Bleed off pressure. MI crane. Remove tree. Cut off casing strings and tubing 34' below GL. Mix any cement needed to fill any casing sting or tubing to cut-off. Weld on permanent marker cap. Call inspector. Upon approval, remove cellar and bury marker. Remove surface equipment from location. Grade location. Take soil samples for confirmation of no contaminants. 1) Pick and move welthouse. Notify AOGCC'inspector of plans for plugging operations. 2) Move in cementer (pump truck/mixer), bulk cement (450 sx Class G), slickline/electric line combo unit, water tank with 100 bbl fresh water for cementing, mud "pit" open tank for returns, and 200 bbl closed tank for diesel packer fluid, and 150 bbl clean brine from previously plugged well (assuming this will be used for spacer—if not, we will need more fresh water for the 130 bbl of =spacer). •RU•eement_pump•to=surface casing valve (9-5/8"--surfacecasing X 7" production -annulus). 3) Pump 5-10 bbl water down annulus ("bullh d') to establish pump rate and pressure. Monitor casing and tubing pressures. Bullhead4Class G cement down surface X production casing annulus, shut down when all cement is in annulus (flush and close annulus valve)—this should result in a 380' surface plug in this annulus. Monitor level—if it falls back, WOC 6 hours and top off cement in annulus, as needed. 4) RTT slickline b1hrirator on tree RTT4 anci null Raker nhiu at S?.RI' KR Allow nressnre to emmli7e (expect maximum -ef_50_psi). `_Check_lubricator-andAree:forleaks. 5) RU cement pump truck to wing valve. bill well by puniping heavier brine packer fluid lgft over from a previous well. Allow tubing to stabilize, bleed off pressure. (Volume to deepest open perfs Riabout 34 bbl). un 2.25" gauge ring (GR) to check for fluid level and through packer to about 5360'. If restrictions are found, run bailer, brushes, etc. to cleanout to about 5360'. PU CIBP (running ID less r+1 . 7 11499 ,� 1,.. — . 7 7491 ;,, 11:A ,,..,. � —p— _+ 4)Q29'% DTT7 .7 + OTDD +... F«.....1. + -aicuit-,c..c,✓ u�-iu.�.vA.-u�...c.✓ -iri �i�uiit�,-�rw.v�.-uc-.s1.v.� _). te�it-iaiitt-Sa.� 5332' (must -be -set -below -sliding .sleeve at 32$3') POOH and -pressure test CIBP to5-00-psi. t� l.- , 7) RIH with shifting tool. Open Baker Model L slicking sleeves at 52$3'. POOAar �� Sto � PSS 8) COMBINATION PLUG: RU cement pumper on wing valve of tree. Open casing valve (tubing- casing annulus) and pump 10 bbl brine down tubing thru sliding sleeve and establish circulation and pressure at 3 BPM— NOTE: annular fluid is diesel --catch in closed tank. Pump 10 bbl spacer and (�1) mix and pump: 190 sx Class G cement (accelerated for 4 hours pump time at 75 degress,15.8 ppg, LW �� 60`' 4.4 D: ei/&k yielaj C10Wn7 tuning,- of owed -ay i-18 nbi weiglriea-viscous -spacer=(mosi-economic ,s 16 possible), followed by another 180 sx of Class G, circulating cement to surface -(3% excess). Take =returns Tram -both casing- (annulus) --valve: and°from°heater°string. °C atch°diesel,:bTme,°and spacer (separately -if possible), the -latter to use -.in subsequent wells. The upper plug -is to be a bdlanced plug -monitor for flow or fall back. (See proposed wellbore diagram for final location of plugs). 9) When cement top is stable, disconnect cementer. Wash out tubing, and tubing -casing annulus to 3- 4' below GL: � WOC 8 hours. Pressure test both sides (tubing and annulus)' to1506 psi. Release pressure. MI crane. Remove tree. Cut off conductor, surface, and production casing strings and tubing 3-4' below GL. Mix any cement needed to fill any casing sting or tubing to cut-off. Release cementers ° and: slicklineunits to=next-location. llwF_ Fabricate '/4" steel marker -plate cap fM.or-13-3/,8" conductor easing, not to extend beyond casing GD, _... __ . . >t'� ad-wel e ng information onto marker plate; Aurora Gas, LLC PTD # 178-088 Simpco Moquawkie No. 2 API # 50 -283 -20062 -OO -6a A r W l8 -ITY of owing-anynecessary inspections, -remove cellar-and:bur -marker. -Dispose of anywaste. Haul brine, tanks, and any support equipment to next -location. 12) Remove tree and casing/tubing cut-offs, surface production equipment, trash, and any other materials from the location. Clean up; grade and level location. Take soil samples and send to Iab to confirm no contamination. Ed Jones (9/11/2017) S'� )/- t,<c. I • Aurora Gas, LLC Simpco Moquawkie No. 2 RKB 16' PTD: 178-088 API# 50-283-20062-0000 / a1'z f Mt , 3z n 2013 Tubing -Casing Annulus Ned with diesel (for heater fluid) to top packer Prod Perls: 5666-5706' ' 7" 26# & 29# S-95 Casing set at 5739' and cemented w/ 250 sx at shoe (+ 315 sx thru D1) Prod Perfs: 5880-5900' 5888-5908' PBTD est. at —6090' 'I'D (ate 6727' MD 17J N ,A 2 7B" 6.S# 8 Rd Tubing to 5920' 13-31W'61# K55 Conductor drilled 17-1/2" hole to 92ft cemented to surface w/ 100 sx 1.315" 1.8# 3-55 heater string to surface to 1103' 9 5/8" 43.54 & 47# N80 Surface Casing set at 1105' Cement w/ 535 sx cmt to surface Good cement bond to 2250' by CBL of 2/2/79 DV tool at 3081' --cemented w/ 315 sx Baker Model L Sliding Sleeve Ca_;5280' (Closed) Baker Model FB -1 Retainer Production Packer, Seal Bore and Millout extensions, packer locator nipple-(4� 5,352' Blast joints 2.44" 10 Ca; 5653-5712' Baker model L Sliding Sleeve (closed) @ 5712' (2.25" profile) Baker Model FAB 30 retainer production packer J ; 5853' Cut tubing at +/- 5870' in 2013 Reperforated 5888-5908' in 2013 No go nipple R Profile 2.25" (q�) 5919', Mule Shoe "a 5920' 5" 18# N-80 Liner 5404-6090' cemented w/ 100 sx G U Aurora Gas, LLC Simpco Moquawkie No. 2 RKB 16' PTD: 178-088 AP1# 50-283-20062-0000 5ept2017 Bullhead 50 sx G cement down 7" X 9- 5(8" annulus -0 to 380'. Tubing -Casing Annulus filled with diesel (for heater fluid) to top packer Prod Perfs: 5666-5706' 7" 26# & 29# S-95 Casing set at 5739' and cemented w/ 250 sx at shoe (+ 315 sx thru DV) Prod Perfs: 5880-5900' 5888-5908' PBTD est. at -•6090' TD (a� 6727' MD • 2 7/8" 6.5# 8 Rd Tubing to 5920' 13-3/8" 614 155 Conductor drilled 17-1/2" hole to 92ft cemented to surface w/ 100 sx 1315" 1.8# 3-55 beater string to surface to 1103' 9 5/8" 43.5# & 47# N80 Surface Casing set at 1105' Cement w/ 535 sx cmt to surface Good cement bond to 2250' by CBI, of 2/2/79 DV tool at 3081' -cemented w/ 315 sx Baker Model L Sliding Sleeve @5280' (Closed) Baker Model FB -1 Retainer Production Packer, Seal Bore and Millout extensions, packer locator nipple @, 5,352' * Blast joints 2.44" ID *_ 5653-5712' Baker model L Sliding Sleeve (closed) @ 5712' (2.25" profile) Baker Model FAB 30 Y�' .a 5853' Cut tubing at +/- 5870' in 2013 Reperforated 5888-5908' in 2013 ;4 No go nipple R Profile 2.25" n 44 �• 5" 18# N-80 Liner 5404-6090' cemented w/ 100 sx G I �Y R V. 2 7/8" 6.5# 8 Rd Tubing to 5920' 13-3/8" 614 155 Conductor drilled 17-1/2" hole to 92ft cemented to surface w/ 100 sx 1315" 1.8# 3-55 beater string to surface to 1103' 9 5/8" 43.5# & 47# N80 Surface Casing set at 1105' Cement w/ 535 sx cmt to surface Good cement bond to 2250' by CBI, of 2/2/79 DV tool at 3081' -cemented w/ 315 sx Baker Model L Sliding Sleeve @5280' (Closed) Baker Model FB -1 Retainer Production Packer, Seal Bore and Millout extensions, packer locator nipple @, 5,352' * Blast joints 2.44" ID *_ 5653-5712' Baker model L Sliding Sleeve (closed) @ 5712' (2.25" profile) Baker Model FAB 30 retainer production packer .a 5853' Cut tubing at +/- 5870' in 2013 Reperforated 5888-5908' in 2013 No go nipple R Profile 2.25" n 44 �• 5" 18# N-80 Liner 5404-6090' cemented w/ 100 sx G �Y R A. �' 2 7/8" 6.5# 8 Rd Tubing to 5920' 13-3/8" 614 155 Conductor drilled 17-1/2" hole to 92ft cemented to surface w/ 100 sx 1315" 1.8# 3-55 beater string to surface to 1103' 9 5/8" 43.5# & 47# N80 Surface Casing set at 1105' Cement w/ 535 sx cmt to surface Good cement bond to 2250' by CBI, of 2/2/79 DV tool at 3081' -cemented w/ 315 sx Baker Model L Sliding Sleeve @5280' (Closed) Baker Model FB -1 Retainer Production Packer, Seal Bore and Millout extensions, packer locator nipple @, 5,352' * Blast joints 2.44" ID *_ 5653-5712' Baker model L Sliding Sleeve (closed) @ 5712' (2.25" profile) Baker Model FAB 30 retainer production packer .a 5853' Cut tubing at +/- 5870' in 2013 Reperforated 5888-5908' in 2013 No go nipple R Profile 2.25" n 5919', Mule Shoe (ie 5920' 5" 18# N-80 Liner 5404-6090' cemented w/ 100 sx G Schwartz, Guy L (DOA) From: George Pollock <gpollock@aurorapower.com> Sent: Thursday, August 23, 2018 5:32 PM To: Schwartz, Guy L (DOA) Subject: FW: Tyonek Native Corporation/Amaroq Surface Use Agreement Guy, The second paragraph below indicates that TNC agrees to have all gravel infrastructure, roads and pads, to remain in place after the wells are plugged and abandoned. This statement covers the sundry application for 10 wells that were submitted to AOGCC with Plugging Inlet, LLC as operator. Let me know if any further information is needed. George Pollock 907.351.8286 From: Rickhart Rowland [mailto:rrowland@tyonek.com] Sent: Thursday, August 23, 2018 4:21 PM To: George Pollock Cc: David Kroto Subject: Tyonek Native Corporation/Amaroq Surface Use Agreement Greetings George, Recently in a meeting with Jack Hively (Tyonek Contractors) and Connie Downing (TNC Chief Admin Officer) Jack explained that a Master Services Agreement was initiated some months ago. - This prompted Connie to ensure that the Surface Use Agreement is dated to the same date as the Master Services Agreement, with payment back dated for each month moving forward until November 2018. We are waiting for the TNC CEO signature. Also, related to the Kaiser Francis/Plugging Inlet Aurora Wells, TNC has notified CIRI and Kaiser Francis that TNC would like to leave all the roads and pads in place. Abandon the underground pipeline in place. Clean up all environmental spills and Remove all other items Sincerely, • . � Land & Natural Resources Manager Tyonek Native Corporation (907) 646-3121 Direct (907) 272-0707 Main rrowland@tvonek.com www.tvonek.com Confidentiality Warning: This e-mail contains information intended only for the use of the individual or entity named above. If the reader of this e- mail is not the intended recipient or the employee or agent responsible for delivering it to the intended recipient, any dissemination, publication or 1 Schwartz. Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, August 16, 201811:18 AM To: 'gpollock@aurorapower.com' Cc: Melvin G Rixse (DOA) (melvin.rixse@alaska.gov) Subject: Simpco Moquawkie #2 (PTD 318-344) P & A George, In reviewing the P &A plan there is no mention of how the I" heater string will be cemented. (I am assuming you are taking returns up the tbg x 7" annulus as well as the heater string during cementing) Can you clarify how this is being done during the cement pumping operation? There may be other wells with the same issue. Haven't gone through all the wells yet. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIAL17Y NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guy.schwartz@alaska.gov). RECEIVED STATE OF ALASKA • ALARA OL ANO GAS CONSERVATION COM ION JAN 2 3 2018 REST OF SUNDRY WELL OPERATIONS '1 Operations Abandon Li Pk g Perforations L Fracture Stimulate L1 Pull Tubing Lj AQp own u Performed: Suspend 0 Perforate 111 Other Stimulate LI Alter Casing Q Change Approved Program Q Plug for Redrrll C] Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well C] Temporary Plug D 2.Operator Aurora Gas,LLC 4 Well Class Before Work: 5.Permit to Drii NWnber: Name: Development 2 Exploratory Q 178-088 3.Address: 3705 Arctic:Blvd.#2114 Anchorage,AK 99503 k Stratigra{phic❑ Service 0;6.API Number: 283-20062-00 7.Property Designation(Lease Number): 8.Well Name and Number: C-061625 Simpco Moquawkie#2 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Moquawkie Undefined Gas 11.Present Well Condition Summary: otat3:3epttlmth easured.15 :feet mugs measured 83 :feet true vertical 6727 feet Junk measured 6046 deet Bffective)Dedth measured1000 'feet Packer measured 5352-X53 feet true vertical D feet true vertical 5352-S853 feet Casing LengSize MD TVD Burst Collapse Structural - ,Conductor -92 13.718 61#K55 -92 92 30.90 psi .1640 psi; Surface 1105 9 5/8 4311 N80 1105 1105 3580 pdsi 1580 psis r Intermediate Productions 5721 72011Ekt4G 5721. 5721% 3740 psi 3270 psi Liner 686 5 18*N80 6090 6090 10140 psi 10490 psi Perforation depth Measured depth 5666-5908 feet Arte•Vertical_dep h 6666-5808 Tubing(size,,grade,measraredand'true vertical depth) 2 718 5.5*N80 5908 5908 Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): <<NA5'. `NHL, ,•:•lei.3 ti t) Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or,Injectlort.Data, Oil-Bbl Gas-Mcf ` Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 85 Subsequent to operation: 0 0 0 14.Attachments(required per 20 MC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0Exploratory 0 Development Q Service 0 Stratigrapi is Copies of Logs and Surveys Run ❑ 16.Well Status alter work: Oil Q Gas C] WDSPL C] Printed and Electronic Fracture Stimulation Data CI GSTOR L f W1NJ 0 WAG -0 GINJ Q 3USP 0 SPLUG Li 17.1 hereby certify that the foregoing is true and correct to the best of my knc nviedge. +Sundry Number or WA if C.O.Exempt: 317-283 Authorized Name: George Pollock Contact Name: Authorized Title: Man rod Ops&Eng Contact Email: gpoilockAaurorapower.cr. Authorized Signature: ,t'+ Dab 1/2312018 Contact Phone: 907.351.8286 /1,26 d V Form 10-404 Revised 412017 R B D M S \i' JAN1 ? 1: 21i18 Submit Original Only I ` IMT • • Aurora=Gas llc Operations Summary—Set Temporary Plug Simpco Moquawkie #2 Well July_-27,_2017 1100hours Mob from SMI 1130 hours R/U WL, PT lubricator w/wellbore =1200=hours RIH=w=/2.33"_gauge=ri1g=to 5283'=KB,=tag profile,=POOH 1300 hours Modify packiing and,back up ring on Pte. 1330 hours RIH w/Baker FWG Plug to 5283',WT, set Plug, POOH 1400 hours Bleed off well, monitor pressure 30 minutes, Pass -1430-hours =R/D=WL,=mmb=to TMC • • Aurora Gas, LLC 2 7/8"6.5# 8 Rd Tubing to 5920' Simko Moquawkie No. 2 13-3/8"61#1(55 Conductor IRKS 16' drilled 17-1/2"hole to 92ft PTD: 178-088 API#50-283-20062-0000 • Revised:July 2017 I"heater string to surface to 1103' 4 95/8"43.50&47#NSO Surface Casing I set at 1105' Cement w/535 sx end to surface i"-20 K44 Surface Casing set at 5721' • Baker ModetL Sliding Sleeve*5280' 13aker FWiG Plug(a?5283' Baker Model FB-1 Retainer Production Packer,Seal Bore and Millout extensions, packer locator nipple @ 5,352' = 3 , Prod Perfs: 5666-5706' Blast joints 2.44"ID 5653-5712' Baker model L Sliding Sleeve(closed) a 5712' (2.25"profile) 5"18#N80 Production Liner—5404'to 6090' Baker Model FAB 30 retainer production packer �,_►, *5853' Prod Perfs: 5880-5900' Cit tubing at+1-5870in 2013 5888-5908' Reperforated 5888-5908' in 2013 No go nipple R Profile 2.25" +@ 5919', PBTD est.at—6090' °y r Mule Shoe*5920' TD 6727'MDr°„;' ,; *P k y or Titt • • 0,14,1', � 1yy,,sA THE STATE Alaska Oil and Gas � t, of T c Conservation Commission =: ALAS � isrx 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov George Pollock Manager Aurora Gas, LLC 4E N Q V 0 �'2 17 1400 W. Benson Blvd., Suite 410 Anchorage, AK 99503 Re: Moquawkie Field, Undefined Gas Pool, Simpco Moquawkie 2 Permit to Drill Number: 178-088 Sundry Number: 317-437 Dear Mr. Pollock: 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, LQ:c.C _ Hollis S. French Chair DATED this 2 day of September, 2017. RBDMS Lc: _-U ,; — J tiim7 RECEIVE STATE OF ALASKA C SEP 14 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon [✓ Plug Perforations❑ Fracture Stimulate Q Repair Well ,❑ Operations shutdown❑ Suspend ❑ Perforate ❑ OtherStimulate ❑ Puti Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other.Temporary Plug ❑ 2.Operator - 4.Current Wett Class: '5.Permit to Drill Number Aurora Gas,LLC Exploratory ❑ Development ❑, 178-088 ' 3.Address: 1400 W.Benson Blvd.Suite 410 Stratigraphic ❑ Service ❑ •6.API Number: Anchorage,AK 99503 50-283-20062-00' 7.If perforating: '8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Nr Simpco Moquawkie#2 r Will planned perforations require a spacing exception? Yes ❑ No lki P14,4 9.Property Designation(Lease`Number): '10.Field/Pool(s): C-061625 Moquawkie Undefined Gas 11. Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs(MD): Junk(MD): 6727' • 6727' . 6000' ° ,6000' 850 psi 5280'&6090° 6040' Casing Length Size MD 71/D Burst Collapse Structural Conductor 92' 13 3/8"61#K55 92' 92' 3090 psi 1540 psi Surface 1105' 9 518"43.5#N80 1105' 1105' 3580 psi 1580 psi Intermediate Production 5721' 7"20#K44 5721' 5721' 3740 psi 3270 psi Liner 686' 5"18#N80 6090' 6090' 10140 psi 10490 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(It): 5666'-5908' . 5666'-5908' 2 7/8" 6.5# 5908' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ftp Baker FB and FAB 30 packers . Baker FB @ 5352'and FAB 30 @ 5853'• 12.Attachments: Proposal Summary 2 Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program 3 BOP Sketch ❑ Exploratory ❑ StraGgraPhic ❑ Development❑• Service El 14.Estimated Date for TBD 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ , 16.Verbal Approval: Date: GAS ❑ WAG ® GSTOR Cl SPLUG ❑ Commission Representative: GINJ ® Op Shutdown ❑ Abandoned ❑• 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: George Pollock George Pollock Contact Name: Authorized Title: Manager-Pr Ops 8 g Contact Email: gpoHock(i:/.aurorapower.corn ,'.,, Contact Phone: 907-351-8286 Authorized Signature: _- ' �" Date: 14-Sep-17 COMMstSSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 /7- (37 Plug integrity' BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ►: Other: -K Rco3 0 00C.A,ItiEU c:ASttr?t.'* a G�+tT OFF `z �rfZ -R- t RTS Post Initial Injection MIT Req'd? Yes ❑ No El Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: `) — 401 RBD MS ( ' -Vu I - 3 2017 APPROVED BY Approved by: �_ COMMISSIONER THE COMMISSION Date: `� I2f it 1 714 7 /1 /?- 409/m�� t. t2s 1` 1 Submit Form and Form 10.403 Revised 4/2017 o t f p for 12 months frfr om the date of approval in pie • • AURORA GAS, LLC WELL ABANDONMENT SIMPCO MOQUAWKIE #2 September 2017 Version 1.0(9/11/17) CURRENT CONDITONS: SITP-40 psi (well dead, but have seen pressures in excess of 1000 psi). KB=12 feet above GL CASING: 7"26 & 29# S-95 set at 5739'MD/TVD. DV Tool at 3084'. CBL cmt top at+/- 2250'. Collapse strength-7800 psi (26#). PRODUCTION LINER: 5" 18#N-S0 set at 6090' w/hanger top at 5404'. TUBING: 2-7/S",6.5#N-80(?) 8 rd EUE, w/:diesel as packer fluid in tbg-esg annulus above top packer and with: Sliding Sleeves: Baker Model L sleeves at 5280' w/Baker FWG plug set (5283') and 5712' (latter with 2.25"profile) Seating Nipple: w/2.25" F profile at 5315' Cut-Off at 5870'. Packers: Baker FB-1 Retainer.Production Packer at 5382' w/Locator Seal Assembly with 14 seal units and Baker Model FAB 30 Retainer Production Packer at 5853' HEA LER STRING: r Nom. (1.315" 1.8#/J-55 10 Rd assumed)set at 1,103'. (See attached completion diagrams) CAPACITIES: 2-7/8" 6.5# Tubing: 0.00579 bbl/ft; Tubing-Casing Annulus 26#: 0.0302 bbl/ft & 29#: 0.0291 bbl/ft. 7"26#Casing: 0.0382.bbl/ft. &29#: 0.0371 bbl/ft. 5" 18#Liner: 0.0177 bbl/ft. Tubing Volume to top Packer=40.M bbl, Annular Volume to top Packer= 161.7 bbl, assuming 26#casing; Volume to deepest Perfs=34+bbl OPEN PERFS: Carya 2-9.1 at 5666-5706' Carya 2-9.2 at 5880-5908' (See wellbore diagram), NOTES: 1) Well is a straight hole. SUMMARY OF PLAN: RU slickline. RIH and pull prong and plug at 5283'. Kill well with heavy brine leftover from previous P&A's (well is likely dead, but will be sure that tubing and tubing-casing annulus are filL). RU cementer on surface casing-production casing annulus. Pump 5 -10 bbl water downannulus to establish a pump in rate and pressure,monitoring tubing-casing annulus and tubit t pressures. Pump(``bullhead") 50 sx Class G—shut in when all is displaced into annulus(do not overdisplace—monitor for fall back—if fall back occurs, WOC and mix and pump more. RU wireline • • lubricator on tree. PU tubing CIBP, RIH and set in or near top of packer at 5352'. Test CIBP to 1500 psi. RII-I with shifting tool on slickline and:open sleeve at 5280'. RU cementers on tree(thru wing valve). Establish circulation,pressure with 5-10 bbl brine at 3 BPM, circulating out diesel packer fluid (catch in closed tank—volume of 160 bbl is expected). Pump 10 bbl spacer, then 190 sx (218.5 cf=40 bbl) Class G cement with additives (15.8 ppg, 1.15 cf/sk yield)with pump time of 4 hr at 75 degrees- 3% excess, followed by 118 bbl of weighted viscous spacer, followed by 180 sx Class G cement, and displace cement to surface—this will result in a balanced plug to meet the requirements of: 1) surface casing shoe and 2)the surface plug(first 190 sx)and a second-plug on the top packer to meet the requirements of 3)-the plug above the perfs(including filling tubing)with the second 180 sx. Monitor for flow or fall back. Wash out tubing casing annulus'to 3-4'below OL. WOC'8 hrs,pressure test to 1500 psi. Bleed off pressure. MI crane. Remove tree. Cut off casing strings and tubing 3-4' below GL. Mix any cement needed to fill any casing sting or tubing to cut-off. Weld on permanent marker cap. Call inspector. Upon approval, remove cellar and bury marker. Remove surface equipment from location. Grade location. Take soil samples for confirmation of no contaminants. I Calla* . Lved C€45e0 I fsvki /rdo'ith m �'N Io/08 4.1- 44,d bele /V"were C Io0 *Ica) w,rt rekr,,,,0f 444 "I"' Oy ' ' 1 41ten16 to felfrm rbc PROCEDURE: veli 7a Pro,14.010//Ace Atli 7'm( &iv( frore4t to 4e vMf ;rilvl P 1-19-,y N.; welt i 'de i r, ,4 '? 97/ 1 Pick and move wellhous . Notify AOGCC insctor of plans for p uggingoperations. 2) Move in cementer(pump truck/mixer), bulk cement(450 sx Class G), slickline/electric line combo unit, water tank with 100 bbl fresh water for cementing, mud "pit" open tank for returns, and 200 bbl closed tank for diesel packer fluid, and 150 bbl clean brine from previously plugged well (assuming this will be used for spacer—if not, we will need more fresh water for the 130 bbl of spacer). RU-cement pump to surface casing valve (9-5/8"surface casing X 7"production annulus). 3) Pump 5-10 bbl water down annulus("bullhead")to establish pump rate and pressure. Monitor casing and tubing pressures. Bullhead 30 sx Class G cement down surface X production casing annulus, shut down when all cement is in annulus (flush and close annulus valve)—this should result in a 380' surface plug in this annulus. Monitor level—if it falls back, WOC 6 hours and top off cement in annulus, as needed. 4) RU slickline lubricator on tree. RIH and pull Baker plug at 5283' KB. Allow pressure to equalize (expect maximum of 50 psi). Check lubricator and tree for leaks. 5) RU cement pump truck to wing valve. Kill well by pumping heavier brine packer fluid left over from a previous well. AIIow tubing to stabilize,bleed off pressure. (Volume to deepest open perfs is about 34 bbl). 6) Run 2.25" gauge ring (GR) to check for fluid level and through packer to about 5360'. If restrictions are found, run bailer, brushes, etc. to cleanout to about 5360'. PU CIBP (running ID less than 2.25", as have a 2.25"in sliding sleeve at 5283'). RIH and set CIBP near top of packer at 5352' (must be set:below sliding sleeve at 5283'). POOH and pressure test CIBP to 1500 psi. 7) RIH with shifting tool. Open Baker-Model L°sliding sleeves at 5283'.. POOH.. 8) COMBINATION PLUG: RU cement pumper on wing valve of tree. Open casing valve(tubing- casing annulus) and pump 10 bbl brine down tubing thru sliding sleeve and establish circulation and pressure at 3 BPM—NOTE: annular fluid is diesel—catch in closed tank. Pump 10 bbl spacer and mix and pump: 190 sx Class G cement(accelerated for 4 hours pump time at 75 degress,15.8 ppg, 1.15 disk yield) down tubing, followed by 118 bbl weighted viscous spacer(most economic possible),followed by another 180 sx of Class G,circulating cement to surface (3%excess). Take • • returns from both casing(annulus) valve and from heater string. Catch diesel,brine, and spacer (separately if possible), the latter to use in subsequent wells. The upper plug is to be a baked plug—monitor for flow or fallback. (See proposed wellbore diagram for final location of plugs). 9) When cement top is stable, disconnect cementer. Wash out tubing, and tubing-casing annulus to 3- 4' below GL. WOC 8 hours. Pressure test both sides (tubing and annulus)to 1500 psi. Release pressure. MI crane. Remove tree. Cut off conductor surface, and production casing strings and tubing 3-4' below GL. Mix any cement needed to fill any casing sting or tubing to cut-off. Release cementers and slickline units to next location. � -'cc- Cwt Pair._ 3o tAct- 10)Fabricate 1/4"steel marker-plate cap for 13-3/8"conductor casing,not to extend beyond casing OD,. and bead-weld the following information onto marker plate; Aurora Gas, LLC s-cv ex �-e„ ay.; e, F ++.3s�"Lt PTD # 178-088 - wc.v NO-401 Simpco Moquawkie No. 2 API # 50-283-20062-00 N4/13' 'i )Zs I n 11)Following any necessary inspections,remove cellar and bury marker. Dispose of any waste. Haul brine,tanks,and any support equipment to next location. 12)Remove tree and casing/tubing cut-offs, surface production equipment,trash, and any other materials from the location. Clean up, grade and level location. Take soil samples and send to lab to confirm no contamination. Ed Jones (9/11/2017) • • • Aurora Gas, LLC 2 7/8"6.5# 8 Rd Tubing to 5920' Simpco Moquawkie No. 2 s, 13-3/8"61#1(55 Conductor RKB s' drilled 17-1/2"hole to 92ft RTD: 178-088 cemented to surface w!100 sx AP(#50-283-20062-0000 , "sect' 2013t 1,315"1.8#J-55 heater string to surface to 1103' 4, a. 9 5/8"43.5#&47#N80 Surface Casing set at 1105' Cement w/535 sx cmt to surface Tubing-Casing Annulus I filled with diesel(for "': heater fluid)to top Good cement bond to 2250'by CBL of packer 2/2/79 fi `ry P 1DV tool at 1'—cemented w/315 sx ):+ Baker Model L Sliding Sleeve @5280' (Closed) 3 Baker Model FB-1 Retainer Production Packer,Seal Bore and Millout extensions, F packer *5,352' Prod Perfs: 5666-5706' 7"26#&29#S-95 ,f, Blast joints 2.44"ID @ 5653-5712' Casing set at 5739'and )14 cemented w/250 sx atBaker model L Sliding Sleeve(closed)@ shoe(+315 sx thru DV) ' 5712' (2.25"profile) Baker Model FAB 30 retainer production packer PR♦ h @ 5853' Prod Perfs: 5880-5900' ' Cut tubing at+/-5870'in 2013 5888.5908' Reperforated n888-5908' in 2013 No go nipple R Profile 2.25"@ 5919',Mule Shoe @ 5920' 5"18#N-80 Liner 5404-6090' PBT!)est.at 6090' cemented w!100 sx G TD @ 6727'MA x,,3 > -' • 0 Aurora Gas, LLC 2 7/8"6.5# 8 Rd Tubing to 5920' Simpco jj. • pa Moquawkie No. 2 �., y : 13-3/8"61#1{55 Conductor RKB 16' +". " " ``' "' �, ' � drilled 17-1/2"hole to 92ft PTD: 178-088 ". . w ` «Ρ .+. cemented to surface w/100 sx API#50-283-20062-0000 r� 7 ,'44', # :: 7.. -.rawk �. Sept 201 ; 1.315"1.8#3-55 heater string to surface to 1103' x � 4 -' i * * Bullhead 50 sx G .«.`- .� 0,.a , ', cement down 7"X 9- ,. t,' ,, 5!8"annulus-0 to 380'. .,. 958"43.5#&47#N80 Surface Casing ,,` .x set at 1105' Cement w/535 sx emt to surface .4—T Good cement bond to 2250'by CBL of Tubing-Casing Annulus 2/2/79 filled with diesel(for € heater fluid)to top i packer L I DV tool at 3081'-cemented w/315 sx 1 Baker Model L Sliding Sleeve X280' (Closed) OR 5 Baker Model FB-1 Retainer Production _ Packer,Seal Bore and Millout extensions, 1 packer locator nipple @ 5,352' Prod Peds: 5666-5706' 7"26#&29#S-95 r Blast joints 2.44"ID @ 5653-5712' Casing set at 5739'and ` 1,1,,w cemented w/250 sx at $ Baker model L Sliding Sleeve(closed)@ shoe(+315 sx Rini DV) ; { 5712' (2.25"profile) 1 i Baker Model FAB 30 . - ,., retainer production packer 111.1,'. • @ 5853' Prod Perfs: 5880-5900' '# Cut tubing at+/-5870'in 2013 5888-5908' iI. - l Reperfarated 5888-5908' in 2013 I No go nipple R Profile 2.25"@ .-i 5919',Mule Shoe @ 5920' l' .1 5"18#N-80 Liner 5404-6090' P13TD est.at-6090' t filMiii TD a;6727'MD aeeuentedM/100 sx G o jy� THE STATE Alaska Oil and Gas 4.) .1;",=- �� oLAsKA Conservation Commission kit 1514_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o Q, Main: 907.279.1433 A : � Fax: 907.276.7542 www.aogcc.alaska.gov George Pollock Manager Aurora Gas, LLC WOW JJL„ 2 5 2017. 1400 W. Benson Blvd., Suite 410 Anchorage, AK 99503 Re: Moquawkie Field, Undefined Gas Pool, Simpco Moquawkie 2 Permit to Drill Number: 178-088 Sundry Number: 317-283 Dear Mr. Pollock: 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. The Alaska Oil and Gas Conservation Commission(AOGCC)approves the setting of a temporary plug in this well to provide isolation from the reservoir as a short-term barrier. This work does not meet AOGCC's regulatory requirements for suspension or plugging and abandonment of this well. Prior to relinquishing the lease back to the landowner, the operator is required by law to properly plug and abandon this well. 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, d4a—n Hollis S. French Chair DATED this day of July, 2017. RBDMS tAvJP!L 11 2017 g RECEIVED STATE OF ALASKA j Li N 16 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGGC 20 AAC 25280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other.Temporary Plug ❑ , _ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Aurora Gas,LLC Exploratory ❑ Development ❑i. 178-088 ' 3.Address: 1400 W.Benson Blvd.Suite 410 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99503 50-283-20062-00 . 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? /1/4 Srmpco Moquawkie#2 Will planned perforations require a spacing exception? Yes ❑ No ?/4?i 9.Property Designation(Lease Number): 10.Field/Pool(s): C-061625 Moquawkie Undefined Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): EffectiYeo oth MD: Effectiveeatt4TVD: MPSP(psi): Plugs(MD): Junk(MD): 6727' , 6727' , G pest. ?1 68ti ` Pgb 850 psi 6090 6040' Casing Length Size MD TVD Burst Collapse Structural Conductor 92' 13 3/8"61#K55 92' 92' 3090 psi 1540 psi Surface 1105' 95/8"43.5#N80 1105' 1105' 3580 psi 1580 psi Intermediate Production 5721' 7"20#K44 5721' 5721' 3740 psi 3270 psi Liner 686' 5"18#N80 6090' 6090' 10140 psi 10490 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5666'-5908' ' 5666'-5908' 2 7/8" 6.5# 5908' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker FB and FAB 30 packers Baker FB(fp 5352'and FAB 30 @ 5853' 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ ' Service ❑ 14.Estimated Date for TBD 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS WAG ❑ GSTOR ❑ SPLUG Li Commission Representative: GINJ D 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: George Polio./ George Pollock Contact Name. Authorized Title: Manager- ''•r O Eng Contact Email: qool lock(a7_aurorapower.corn Contact Phone: 907-277-1003 Authorized Signature: Date: 16-Jun-17 COMMISSION USE ONLY - Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 ( 7- 23 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: LMPCtZ.),V.4 'i-us OtS.�S t-'O tACCA— eliZrr M(=U't'S FGsZ.. ''''••‘`'7t-"e �\+err.: Oft- P k p Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBIDMS 1,,- JUL 1 1 2017 Spacing Exception Required? Yes ❑ No 12f Subsequent Form Required: t._ APPROVED BY ' l Approved by: (Lt0(1%"...........******---((� ( /iCOMMISSIONER THE COMMISSION Date: k L �/Jf1� g �J . 1111 ri SutmritForm and 1//`� orm 10-403 Revised 4/2017Orv (6PtcI&4nAvllid for 12 months from the date of approval Attachments in Duplicate • Aurora Gas, June 16, 2017 Ms. Cathy Foerster, Chair RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 JUN 1 6 2017 Anchorage, AK 99501 Re: Application for Sundry Approval—Set Temporary Plug Simpco Moquawkie#2 Well PTD #: 178-088 API#: 50-283-20062-00 Dear Ms. Foerster: Aurora Gas, LLC hereby requests approval to set a temporary plug to secure this onshore development well in the Moquawkie Undefined Gas Field on the west side of Cook Inlet, northeast of the Village of Tyonek. This well is currently shut-in, is capable of producing gas from multiple zones in the upper Tyonek sands and is mechanically sound. Aurora Gas is currently in Chapter 11 bankruptcy protection while attempting to reorganize and emerge with new owners/investors. This application is being submitted as part of our Reorganization Plan filed with the bankruptcy court if liquidation actions are ordered. Aurora Gas, LLC will provide all potential new owners/investors notice of the impending action before on-site activity begins. The proposed work involves setting a plug via wireline in the profile at a depth of 5280' above all open perforated intervals to mechanically isolate the reservoir. After the plug is set, tubing pressure will be monitored for 30 minutes to ensure isolation. A back pressure valve will be set and the master valve repaired and then will be closed providing double isolation and the wellhead secured. A follow up pressure reading will be obtained after 24 hours to ensure the integrity of the plug. Please find the attached information as required by 20 AAC 25.110 for your review: • Form 10-403 Sundry Application • Current wellbore diagram illustrating the current well configuration. • Slickline Temporary Plug Set—Generalized Procedure If you have any questions or require any further information,please contact me at (907) 277-1003. Sincerely, eorge Pollock Manager—Production Operations & Engineering 4645 Sweetwater Boulevard, Suite 200 * Sugarland,TX 77479 * (832) 939-8991 1400 W Benson Blvd, Suite 410 * Anchorage, AK 99503 * (907) 277-1003 . • S Aurora Gas, LLC 2 7/8"6.5# 8 Rd Tubing to 5920' Simpco Mo uawkie N 2 Y q o. � �� 13-3/8"61#K55 Conductor RKB 16' drilled 17-1/2"hole to 92ft PTD: 178-088 • API#50-283-20062-0000 = it N .0 * k 1"heater string to surface to } 1103' s r. 4 9 5/8"43.5#&47#N80 Surface Casing set at 1105' Cement w/535 sx cmt to surface 7"20#K44 Surface Casing set at 5721' I1F Baker Model 1.Sliding Sleeve X280' (Closed) , . Baker Model FB-1 Retainer Production Packer,Seal Bore and Millout extensions, packer locator nipple*5,352' r. Prod Perfs: 5666-5706' Ai-- ,> Blast joints 2.44"ID f@ 5653-5712': .11 . 66, Baker model I Sliding Sleeve(closed)@ 5712' (2.25"profile) 5"18#N80 Production Liner–5404'to 6090' Baker Model FAB 30 retainer production packer ...N.-074 * @ 5853' Prod Perfs: 5880-5900' ' ', 5888-5908' I No go nipple R Profile ' . 2.25"@5919', PBTD est at 6490' , . , Mule Shoe @ 5920' TD @ 6727'MD #,y. •.;« • ! AURORA GAS, LLC Slickline Temporary Plug Set - Generalized Procedure June 2017 SUMMARY: This procedure describes the steps taken to set a temporary plug in wells operated by Aurora Gas, LLC to secure the well for a short term shut in. RIH with drift for the appropriate sized tool for the tubing, in most cases 2 7/8"tubing with 2.312" or 3 1/2"tubing with 2.812"X landing nipple profile. Set PXX plug in uppermost landing profile. If a profile is not available, RIH with tubing stop pack-off plug and set above uppermost packer. After plug is set, a negative pressure test will be performed to ensure the plug has isolated the productive intervals from the surface. Upon passing the negative pressure test, the wellhead will be secured. PROCEDURE: 1) AG Operators to shut-in well and monitor pressure while rigging up. 2) RU Pollard Wire Line and lubricator on tree after removal of tree cap. Open well to pressure test lubricator—have pressure gauge on lubricator. 3) RIH with appropriate drift for X profile and sliding sleeves in upper profile. Pass through sleeve approximately 10' to insure safe operation of setting tool. POOH. 4) RIH with PXX Plug body on X-Line running tool. Set Plug body in upper most Sliding sleeve X profile above upper most production packer in well. 5) RIH with RB retrieval tool as running tool with prong. Set Prong in Plug body and POOH. 6) Record pressure and Bleed well bore to zero PSI, Monitor for 30 minutes recording pressure readings at 15 minute intervals. 7) Test successful if no pressure increase observed. If test fails, RIH and reset plug. 8) RDMO Pollard Wire Line. 9) Secure the wellhead. 10)Move to next well. 11)After 24 hours, a pressure reading will be obtained to ensure the integrity of the plug. .41e Sau49e(6/11/2017) • w )1' 7 THE STATE Alaska Oil and Gas ^y�� ofALASK A Conservation Commission g 1 GOVERNOR SEAN PARNELL 333 West Seventh Avenue �g 'Z� 1 g A nchora e Alaska 99501 -3572 F ALAS i ) SLOW) BAR Main: 907.279.1433 Fax: 907.276.7542 George Pollock Manager — Production Operations & Engineering Aurora Gas, LLC 1400 W Benson Blvd., Suite 410 Anchorage, AK 99503 Re: Moquawkie Field, Undefined Gas Pool, Simpco Moquawkie #2 Sundry Number: 313 -129 Dear Mr. Pollock: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1- 74 (-- r14' Cathy P. Foerster Chair DATED this �Z) day of March, 2013. Encl. • • 't.' �s 31 �( • STATE OF ALASKA f 5 1 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS r' Oi -IC C 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ r an g e Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ©- Pull Tubing ❑ 7 .0' Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well El Stimulate ❑ Alter Casing ❑ Other. 4 L ) �%u" Q• 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number Aurora Gas LLC Exploratory ❑ Development i0 • 178-088 - 3. Address: Stratigraphic ❑ Service ❑ 6• API Number: 1400 W Benson Blvd, Suite 410, Anchorage AK 99503 50-283-20062-00 • 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 20 AAC 25.055 (a) Simpco Moquawkie #2 - Will planned perforations require a spacing exception? Yes ❑ No i© 9. Property Designation (Lease Number): 10. Field /Pool(s): CIRI Lease # C- 061625 (old # C- 61389) Moquawkie (Undesignated Gas) - 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): 6,727' • 6,727' 6,000' 6,000' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 13 -3/8" 92' 92' 1,530 psi 520 psi Surface 1,087' 9 -5/8" 1,105' 1,105' 3,580 psi 1,580 psi Intermediate Production 5,721' 7" 5,739' 5,739' 3,740 psi 3,270 psi Liner 686' 5" 6,090' 6,090' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,666' - 5,706' & 5,880' - 5,900' 5,666' - 5,706' & 5,880' - 5,900' 2 -7/8" 6.5#, unknown 5,920' Packers and SSSV Type: Baker FB -1 Retainer, no SSV Packers and SSSV MD (ft) and TVD (ft): ' Prod Packer at 5,352' MD Baker FAB30 Retainer, no SSV • Prod Packer at 5,853' MD 12. Attachments: Description Summary of Proposal 12 • 13. Well Class after proposed work: Detailed Operations Program i0 • BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ©, Service ❑ 14. Estimated Date for 17- Mar -13 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ©' WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact George Pollock Email aDoIIock(a.auroraDower.com Printed Name George Pollock (90 277 -1003 Title Manager - Production Operations & Engineering Signature Phone Date 13- Mar -13 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test [] Location Clearance ❑ Other: RBDM MAR 1 810 144" I ' Spacing Exception Required? Yes ❑ No Subsequent Form Required: /Q - A( v' -( APPROVED BY Approved by: / COMMISSIONER / THE COMMISSION Date: 3 _l0 , / 3 y'^ . j • N -/,3 Submit Form and , S OR)-10Ge is / 2 Approved application is valid for 12 months from t e date of approval. A ments in Duplicate �\L • • - Aurora Gas, LL r e e F March 13, 2013 Cathy Foerster, Chair State of Alaska Oil and Gas Conservation Commssion 333 W. 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry Approval Simpco Moquawkie #2 Well Additional Perforations / Production Dear Ms. Foerster: Aurora Gas, LLC (Aurora) hereby requests approval to allow for the additional perforations and subsequent production from certain stratigraphic intervals for the Simpco Moquawkie #2 well and the undesignated Moquawkie gas field on the west side of Cook Inlet. Attached is the Application for Sundry Approvals. Specifically, Aurora seeks permission to perforate from 5,888' to 5,908' MD to allow production from the Carya 2 -9 sands. Aurora plans on continuing production from the other two perforations in the Tyonek " Moquawkie" intervals currently open. Accompanying the Sundry Application is supporting well and engineering data, which include the well completion diagram and the proposed perforation and testing procedure. Should questions arise in connection with this request, please contact either myself in the Anchorage office at (907) 277 -1003 or Mr. Ed Jones in the Houston office at (281) 495- 5799. Respectfully Submitt , orge Pollock Manager — Production Operations & Engineering Attachments 6051 North Course Drive, Suite 200 * Houston, TX 77072 * (281) 495 -5799 * (281) 495 -1473 1400 W Benson Blvd, Suite 410 * Anchorage, AK 99503 * (907) 277 -1003 * (907) 277 -1006 • • AURORA GAS, LLC SIMPCO MOQUAWKIE #2 PERFORATING PROCEDURE JANUARY 2013 VERSION 1.0 STATUS OF WELL: Live well (potential for 1780 psi SITP —now psi). Pollard tagged bottom at 5969' in Jan. CAPACITIES (bbl /ft): 2 -7/8" Tubing: 0.00579; 5" (18 #) Liner: 0.0177; 7" 29# Casing: 0.0371 PERFS: 5666 -5706' (40') behind sliding sleeve; and 5880 -5900' (20') Total net feet of perfs= 60' over 234' gross interval . PACKERS: 5352' (in 7 ") and 5853' (in 5 "). PBTD: 6000' SLIDING SLEEVES: Baker Model L @ 5280' (CLOSED) and Baker Model L @ 5713' (CLOSED) SEATING NIPPLES: `F' Profile (2.25" ID) @ 5315' `R' Profile (2.25" ID) @ 5919' EOT= 5920'. 1) RU perforator's boom truck and electric -line truck w/ 3000 -psi grease- injection lubricator (to 2 -7/8" 8 Rd flow tee. Will need cross -over to Expro lubricator— ???? connection). 2) PU APRC cut -off tool w/ CCL on electric line inside lubricator. Pressure test lubricator to 2500 psi w/ pressure -wash pump. 9) RIH w/ cut -off tool to tag no -go at 5919'. Run CCL strip log and correlate to Completion Record CCL strip of 11/3/07. Cut tubing stinger below deepest packer, at 5870' + / -. Confirm cut and tubing stub dropped. POOH w/ tubing cutter. 10) PU 20' 2 -1/8" gun with premium charges (14.5 g HMX charges, 6 SPF, 60 -deg phasing or 0 -deg phasing with decentralizing stand -off). RIH. a) Correlate to perforate 5888- 5908'. Obtain and record pressure on well. Perforate. Watch for any cfiange in pressure — record after perforating pressure. . b) POOH (under pressure) lay down spent gun. 11) SI well (master and swab valves). RD and release Expro. Reinstall tree cap. 12) Flow well to facility and test • • • 13) Perform SSV test (give notice to AOGCC to witness) and submit results to AOGCC. Ed Jones (1 /21/13) . • • Aurora Gas, LLC — 2 7/8" 6.5# 8 Rd Tubing to 5920' Simpco Moquawkie No. 2 y 13 -3/8" 61# K55 Conductor r44 RKB 16' t drilled 17 -1/2" hole to 92ft PTD: 178 -088 API# 50- 283 - 20062 -0000 Revised; Oct, 2010 4:1 : :16 ', 47 4tir i 1" heater string to surface to 1103' pil . ' - 9 5/8" 43.5# & 47# N80 Surface Casing set at 1105' Cement w/ 535 sx cmt to surface E V 4, ,,,b1 0.....k. e,,-i ... v '' ' 1 Baker Model L Sliding Sleeve @5280' _ I (Closed) Pi -- - _ Baker Model FB-1 Retainer Production 0 ,,--- Packer, Seal Bore and Millout extensions, packer locator nipple @ 5,352' Asp .1 Atio Prod Perfs: 5666-5706' 0 ....,,,,,,,, joints 2.44" ID @ 5653 -5712' I Baker model L Sliding Sleeve (closed) @ g r''''' 5712' (2.25" profile) Baker Model FAB 30 retainer production packer //Z0 : @5853' Prod Perfs: 5880 -5900' Cut tubing with Sehiubrnberger Goex jJ cutter at 5,868' but tubing did not fall off 1 No go nipple R Profile ek- 2.25" @ 5919', PBTD est. at 6090' Mule Shoe @ 5920' TD @ 6727' MD tlitirri - ,. ~~~ra Gas, L www.aurorapower.com Alaska Oil and Gas Conservation Commission 333 W. 7`~' Avenue, Suite 100 Anchorage, AK 9901 Attn: Mr. John Norman RE: Simpco Moquawkie #1 Simpco Moquawkie #2 Dear Mr. Norman: ~~~h~~~ ;JAt~ `~ 2DD$ January 4, 2008 This letter in duplicate originals transmits the data to you identified below, pursuant to Aarora Gas, LLC's obligation to you. This data is relative to operations at the Moquawkie Field, Cook Inlet, Alaska. The enclosed data consists of one hard copy and one CD. Enclosed herewith: SCHLUMBERGER COMPLETION RECORD Simpco Moquawkie #1 ~ ~~.(~ ~` i 5~3 ~ 2-1/8" Power Spiral ~ ~ ~~ SPF 45 Degree Pendulum SCHLUMBERGER COMPLETION RECORD Simpco Moquawkie #2 2-1/8" Goex Tubing Cutter ~~~-~~' ~~~~~ Please signify that you have received and accepted this data by signing in the space below and returning this letter to me at the Anchorage address below or by fax to me at 907-277-1006. If you have questions, please contact me, or Ed Jones at the Houston number below. Sincerely, Bruce D. Webb Manager, Land and Regulatory Affairs (,'U CJ s~ _ / q~ '- ~ 6 ~~ RECENED AND ACCEPTED ABOVE DATA This day of ~~. , 2008. TITLE: l~1.~.1„rr 1 j~~~e~ratCe..-' ~~~ 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 • Aurora Gas, www.aurorapower.com December 14, 2007 John K. Norman, Chairman State of Alaska Oil and Gas Conservation Commission 333 W. 7~' Avenue, Suite 100 Anchorage, AK 99501 Re: Report of Sundry Operations Simpco Moquawkie #2 Well Additional Perforations 1 Production Attempt Dear Mr. Norman: • LLC ~~i~~V~Q SEC ~. 4 2007 laslca Oil ~ Gas ans. Commission AnGht~~aa ~ DEC ~ ~ 200? Enclosed, please find the Report of Sundry Operations and form 10-404 far-the above referenced well. Unfortunately, the perforation attempts were unsuccessful, which resulted in no change in production. Should questions arise in connection with this request, please contact either myself or Mr. Ed Jones in the Anchorage office at 277-1003. Respectfully Submitted By, Bruce D. Webb Manager, Land and Regulatory Affairs 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 41 D • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 j~ ~`CJ~SfJ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~~~~~ V G~.l~ SEC ~ ~ 2007 A~ e 1. Operations Abandon Repair Wetl Plug Perforations Stimulate Other Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter Suspended Well ^ 2. Operator Aurora Gas, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory^ 178-088 3. Address: 2500 City West Blvd., Suite 2500 Houston, Stratigraphic^ Service^ 6. API Number: 7X 77042 50-283-20062-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 339' AMSL (DF) Simpco Moquawkie #2 8. Property Designation: 10. Field/Pool(s): CIRI Lease # C-061625 (formerly C-061389) Moquawkie (Undesignated Gas) 11. Present Well Condition Summary: Total Depth measured 6,727 ~ feet Plugs (measured) none true vertical 6,727 ~ .feet Junk (measured) cutting debris, 5,868' - 5,895' Effective Depth measured 6,000 feet true vertical 6,000 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 13-3/8" 92' 92' 1,530 psi 520 psi Surface 1,087' 9-5/8' 1,105' 1,105' 3,580 psi 1,580 psi Intermediate Production 5,721' 7" 5,739' 5,739' 3,740 psi 3,270 psi Liner 686' 5" 6.090' 6.090' Perforation depth: Measured depth: 5,666' - 5,706' and 5,880' - 5,900' True Vertical depth: 5,666' - 5,706' and 5,880' - 5,900' Tubing: (size, grade, and measured depth) 2-7/8" 6.5#, unknown 5,920' Packers and SSSV (type and measured depth) Baker FB-1 Retainer, no SSV Production Paker @ 5,352' MD Baker FA630 Retainer, no SSV Production Paker @ 5,853' MD 12. Stimulation or cement squeeze summary: none Intervals treated (measured): none Treatment descriptions including volumes used and final pressure: none 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 500 2 150 200 Subsequent to operation: 0 500 2 150 200 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run none Exploratory^ Development Q Service ^ Daily Report of Well Operations attached 16. Well Status after work: Oil^ Gas Q ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-334 Contact Ed Jones, VP Engineering Printed Name J. Edward Jones Title VP Engineering, Aurora Gas, LLC Signature rw~~~~ Hc_~L f.''D ~~,N~~ Phone (713) 977-5799 Date 11/7/2007 ion Form 10-404 Revised 04/2006 D~- \"3 (\c~ ~_/ Submit Original Only !/l...JJJiii ~'7f7~,/1~ IL . Pg',o'~ • • Aurora Gas, LLC SIMPCO MOQUAWKIE #2 REPORT OF OPERATIONS ATTEMPT TO ADD PERFORATIONS November 2-3, 2007 11(2/07: Move in Schlumberger electric-line unit, lubricator, and grease injection skid and crane truck. Spot crane truck, grease injection skid, and electric-line unit around the Simpco Moquawkie #2. Shut-in well. Close both Master Valves on tree. RU Schlumberger grease-injector lubricator on tree. RU fill and test pump. Fill lubricator with fresh water. Pressure to 2100 psi, pressure dropped to 1600 psi in 5 minutes and held for 5 minutes. (Needle valve stem on bleed line was source of leak). Replaced valve and pressured to 1600 psi-held. Pick up GR/CCL/Tubing Jet Cutter Tool string. Opened well-pressure had built to 1000 psi. Ran tool string in hole-tight in blast joints at 5680'. Ran in to 5920' (still inside tubing). Logged out of hole for several hundred feet, correlated GR with CNL/FDC open-hole logs of 1/16/79-about 2 feet deep. Packer appears to be about 20' shallow (vs. well bore diagram). Set Jet Cutter at 5868'and fire. Drop thru cut, pull up and hung up slightly at cut, at 5780' and at 5720'. POOH-tool covered with layer of hydrates/ice and 2" bottom piece of cutter missing. PU 1-11/16" sinker bars with GR/CCL and run in hole. SITP-1175 psi. Tag with bottom of tool. string at 5895' (Top of cutter piece stuck in No-Go Nipple?)-tubing stub did not drop off. Work sinker bars but could not get thru. POOH. Lay down tool string. Lay down lubricator. Install cap on lubricator hammer union and return well to production. SD operations for night. 1 lJ3l07: Call for cross-over to use slick line tools with electric line. W.O. cross-over. Get cross-over. SI well. PU 2-1/8" impression block and sinker bars. PU lubricator. Run in hole with impression block and CCL tool. Run CCL strip log and correlate-12' deep. Tag/make impression at 5895'. POOH. LD impression block-shows an impression on one side. PU Tubing Jet Cutter Tool and RIH. Run CCL strip log and correlate. Position cutter at 5868' and fire. Pull up, set down at cut, repeat. Pull up-tool dragged 1500# over as started off bottom. POOH and LD Jet Cutter. Tool missing 2" bottom piece. PU 2-118" impression block and re-run. Hit bottom (5868') at high speed to make impression. POOH. LD impression block-not definitive. Remove GR tool from string. PU blind box and additional 2" weight bars. RIH and hit fish repeatedly-no progress. Stuck tool string after 25 minutes. Work stuck tool. SD, leaving tension on tool string. Tool came free after 30-40 minutes. POOH and LD tool string. Decide to abort operation: DID NOT PERFORATE. RD and move to Simpco Moquawkie #1. ,,' Re-install tree cap. SITP--+/-1200 psi. Open well to Production. Ed Jones - 11/7!07 • ~~~ ~j ~~~~ C ~_~.x ~~ "~ ~ i~ t J~ ~.S SARAH PAL/N, GOVERNOR ~5~ ~~ ~ ~ 333 W. 7IhAVENUE, SUITE 100 CO1~T5~R~A7'I011T COMMI55IOrT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bruce Webb Manager, Land and Regulatory Affairs Aurora Gas, LLC ,a~`~ 2500 City West Blvd., Suite 2500 ~~ Houston, TX 77042 Re: Moquawkie Gas Field, Moquawl~e Undefined Gas Pool, Simpco Moquawkie # 2 Sundry Number: 307-334 ~~~~ NOV ~. 3 2Q0~ Dear Mr. Webb: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request far rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of October, 2007 Encl. Sincerely, STATE OF ALASKA ,/~~~ {{ ~ `J ALA OIL AND GAS CONSERVATION COMIl~SION /~` OCT 3 O 2007 APPLICATION FOR SUNDRY APPROVALS ~,I~g ~~' ~ Gas Cons. C 20 AAC 25.280 ORiCI11SSI0q 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^~ ~ Waiver Oth Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ ~y~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ " - ~Q~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: AURORA GAS LLC Development ^ Exploratory ^ ~ 178-088 3. Address: Stratigraphic ^ Service ^ 6. API Number: 2500 City West Blvd., Suite 2500, Houston, TX 77042 50-283-20062-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Simpco Moquawkie #2 F 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): CIRI Lease # C-061625 (old # C-061389 339' AMSL DF) ~ Moquawkie (Undesignated Gas) ~ 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured):. Junk (measured): 6727' ' 6,727' 6,000' 6,000' none Wane Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 13-3/8" 92' 92' 1,530 psi 520 psi Surface 1,087' 9-5/8" 1,105' 1,105' 3,580 psi 1,580 psi Intermediate Production 5,721' 7" 5,739' 5,739' 3,740 psi 3,270 psi Liner 686' S" 6,090' 6,090' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5666-5706' and 5880-5900' same 2-7/8" 6.5 #, unkn 5,920' Packers and SSSV Type: Baker FB-1 Retainer, no SSV Packers and SSSV MD (ft): Prod. Packer at 5,352" MD Baker FA630 Retainer, no SSV Prod. Packer at 5,853" MD 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development 0 ~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 31, 2007 Oil ^ Gas^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact J. Edward Jones (713) 977-5799 Printed Name Bruce D. Webb, Manager, Land and Regulatory Affairs Title Vice President, Engineering and Oper. Signature ~ Date ~G~~1/C~ 7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -. 3 Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ 1 Other: ~~Q\1C01~~~ 4:~~ e M~t'~T Ae ~ c~~ ps ~.a~ . a~S ` ~ ~`~_ ~v~V ~ ~ 2DD7 Subsequent Form Required: ~~ APPROVED BY Approved by: ISSIONER THE COMMISSION Date: ~.~/i Form 10-403 Revised 06/2006 ~~~'\, J'1~, { / ~~~ Submit in Duplicate ~„ J v I ~~ ~ ~~ ~o •~? oZ .~ • ---Aurrora Gas, www.aurorapower.com October 30, 2007 John K. Norman, Chairman State of Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry Approval Simpco Moquawkie #2 Well Additional Perforations /Production (5,885'-5,905' MD) Dear Mr. Norman: LLC ~~~~~~ OCT ~ ~ 2007 ~~lasica Oil & Gas Cons, Commission Anchorage Aurora Gas, LLC (Aurora) hereby requests approval to allow for additional perforations and subsequent production from certain stratigraphic intervals for the Simpco Moquawkie #2 well and the undesignated Moquawkie gas field on the west side of the Cook Inlet. Attached are Applications for Sundry Approval for the two intervals referenced above. 1 Specifically, Aurora seeks permission from 5,885' to 5,905' MD to allow production from the Carya 2-9 sands. Aurora plans on continuing production from the other two ~ perforations in the Tyonek "Moquawkie" intervals currently open. Accompanying the Sundry Application is supporting well and engineering data, which include well completion diagrams and the proposed perforation and testing procedure. Should questions arise in connection with this request, please contact either myself in the Anchorage office at 277-1003 or Mr. Ed Jones in the Houston office at (713) 977-5799. Respectfully Submitted By, ~. ~~ ~ft Bruce D. Webb Manager, Land and Regulatory Affairs attachments 10333 Richmond Avenue, Suite 710 • Houston, Texas 77042 • (713) 977-5799 • Fax (713) 977-1347 1400 West Benson Blvd., Suite 410 • Anchorage, Alaska 99503 • (907) 277-1003 • Fax (907) 277-1006 Aurora Gas, LLC SIMPCO MOQUAWKIE #2 ADD PERFORATIONS and TESTING PROCEDURE (Version 1.2) CAPACITIES (bbl/ft): 2-7/8" Tubing: 0.00579; 5" (18#) Liner: 0.0177; 7" 29# Casing: 0.0371 PERFS: 5666-5706' (40') behind sliding sleeve; and 5880-5900' (20') Total net feet of perfs= 60' over 234' gross interval . PACKERS: 5352'(in 7") and 5853' (in 5"). PBTD: 6000' SLIDING SLEEVES: Baker Model L @ 5280' (CLOSED) and Baker Model L @ 5713' (OPEN) NOTE: Opening the top sliding sleeve will dump packer fluid on the open perforations and kill the well-WE WANT TO AVOID THIS. SEATING NIPPLES: `F' Profile (2.25" ID) @ 5315' `R' Profile (2.25" ID) @ 5919' WELL STATUS: Producing well, producing 750 mcfpd. SITP-1730 psi. 1) Move in Schlumberger electric-line unit, lubricator, and grease injection skid and crane truck. 2) Hold pre-job Safety Meeting w/ all parties involved. 3) If possible, flow well until ready to rig up, so pressure will be as low as possible. Shut- in well. Close both Master Valves on tree. Bleed off pressure thru needle valve on bull plug on Flow Tee. RU Schlumberger grease injector lubricator on tree (to 2-7/8" 8 Rd flow tee-must first remove tapped bull plug. Will need cross-over to SLB lubricator- 3" Bowen connection). 5) Perforate as follows: a) PU Schlumberger Tubular Jet Cutter (TGC) w/ gun GR/CCL (If recommended by SLB, first run maybe GR/CCL log to correlate, then run only CCL tool w/ Jet Cutter). b) With tool in lubricator and lubricator flanged up, pressure test lubricator to well pressure (1000+psi) for 10 minutes-record test pressure and time. c) Open well (swab and master valves---wing valve to remain closed) and RIH w/ GR/CCL/jet cutter (or not, as recommended). Run correlation log from 6000' to 4400' (or as needed to correlate). Correlate to open-hole GR log on CNL/FDC Log of 1/16/79. (Lots of coals to correlate to-also should see old perfs on CCL). Maintain pressure on well. d) With Jet Cutter in hole (pull GR/CCL tool and run if not recommended to run w/ Jet Cutter) and cut tubing stinger below deepest packer at 5865' +/-. e) Confirm cut and tubing stub dropped. POOH w/jet cutter. g) PU 20' 2-1/8" gun with Power Spiral EnerJet (14.5 g HMX charges, 6 SPF). Pressure test lubricator to well pressure. RIH. • h) Correlate to perforate 5925-5905'. Obtain and record pressure on well- expected to be 1000-1200 psi. (Maximum long-term SITP has been about 1730 psig). Perforate. Watch for any change in pressure-record after perforating pressure. POOH. Lay down spent guns. e) PU 20' 2-1/8" Power Spiral gun w/ CCL, run in hole, and perforate the Carya 2-9 sand at 5905-5885', recording pressures before and after perforating. f) POOH (under pressure) lay down spent gun. 7) SI well (master and swab valves). RD and release Schlumberger. Reinstall tree cap. 8) Flow well to facility and test. Ed Jones 10/25/07 5'" liner taP of 5404 7'" cosine ~iotsded o 5 7 39' 5"" lln er landed o 6090' ATTACHMENT NO.• State of Alaska Fo ~! -7 SID4PC0 tioquawkie c~*e~_ No. 2 (For Safety Shut-inj Tubing Hanger 14. Heater String (I° nom.) Surf. to ; ~--~ 1103 ' • ! ~ , .. .. . " " rfs~ ~ NO'[E: ~•Minimum ID restrictions at and R the 80 tc 5900 : '~ ~ F rtipples nf'!'9919 S 5315 (2.25 ID) `~~ ~ : , ^~ SIM PC© i~++ttiC3UAWKIE Wat ~ ~- t Nc. 2 _ . " ~' 1Veltbore Schematic Tp: ~.3 ~,i'~ Sl~rt-in Stoics... 00" ~\:`•'~ Fsiaruory 25, i9T9 SCeie~ None. Completion Equipment Item Description Oepth (MD) Mule Shoe 5920 2. No-Go Nipple, R profile 5919 3. Baker Model FAB 30 retainer production ,packer 5853 4. Anchor Seal Nipple 5852 5. Baker Model L Sliding Sleeve (OPEN) 5. Blast Joints 5653 - 2.44° ID 5712 T. Seal Bore and Millout Extensions 8. Baker Madel FB-I retainer production packer 9. Seat Assembly (14 units. 8.72' inside w/locator at 10. Packer Locator Nipple 5348.5 Seating Nipple, F profile Blanking Plug in Ploee arts: for Shut-in Status 6Es6 to .5706' '~ 12. Baker Model L Sliding Sleeve (CLOSED) 5280 !3, OCT Bock Pressure Valve Ttf at 6727` MQ .~- ~`~IV f --~ ' : C.. ~~~ ' ,~.- ~ i ~ ~ ~D SS I ~~ ~ ~ 'C-~-fs Page 1 of 1 ~-~ th- ~z. e~°~~/" ?"~.- ~" +0~.,~~n ~l t S c.3 ~ ~~ rte o s-~` ~.. r ~ `--~ ~ ~ ~: avtz- O A-I' C. `~ -y~/'~1. ~ ~e+2t~s'no•~ S '7T~-t S `~ ~ , - f 7~ ~t-y~( i S 'T~ S'T/~'R-"~ Bruce ®V11ebb `S~r-'! OR.~~ f -7 ~ ~`GV __ _ _.~~~_ _ _..~. ~_~_ _ __ _ ~~_~~. ~. _~~._..n _.~~_ _ .... _ .._.~(.~_~_._~_. __,~ From: Ed Jones [jejones@aurorapower.com] `''"'`~ ~ ~- ~ p ~Q~~ Sent: Tuesday, October 30, 2007 11:43 AM To: 'Chad Helgeson'; 'Joe Dalebout'; 'Phil Smiley'; 'JON WEST' Cc: 'David Boelens'; jschultz@aurorapower.com; curton@aurorapower.com; agoperators@aurorapower.com; 'Bruce D Webb'; 'G. Scott Pfoff Subject: Simpco Moquawkie Perforating Schedules This is the plan, as it now stands, to reperforate the Simpco Moquawkie wells; ,`1t?tsi;~ f3i# Gos Cons. Ct~mrgis~i~ Anchorage Wednesday: Phil will move test unit from Simpco Moq. #2 up the hill to the Simpco Moq. #1 location and will set it out (with Johann's advice) to the West and North of the well (away from the approach to the pad from the Moquawkie yard). It will need to be mostly setup before Saturday AM, including flare stack (Bruce-please see that our permit is inn place for this). Thursday: Phil and Joe will meet in Beluga to access transportation of the Schlumberger equipment, and the Schlumberger equipment will be moved to Simpco Moquawkie #2 and set up by Friday noon. Frida --Schlumberger (SLB) crew to come in Friday AM and get set up. AG Operator to be on site to shut in well and help rig up lubricator. Wireline operations to start right after an early lunch on Friday: correlation run, cut off tubing, and perforate (3 or 4 total runs in hole). After perforating, rig down SLB and move to #1 well and rig up-- will perforate only if we have daylight (which is doubtful). Will flow back SM 2 ASAP and test to see any difference in rates and pressures. Leave on stream. Saturday--Perforate SM #1. Rig down SLB and demobe back to Beluga and fly home. As soon as SLB is rigged down, finish connecting test unit and start well test, as per Procedure. If well will not flow, leave SI overnight and try again on Sunday. If still won't flow, bring Pollard over to swab in, Well test will take minimum of 4 hours, probably more. Please let me know if you have questions, suggestions, or concerns. Thanks, Ed Ed Jones Vice President Engineering & Operations Aurora Gas, LLC 713-977-5799 {Houston) 907-277-1003 (Anchorage} e e ~Aurora Gas, LLC www.aurorapower.com RECEIVED )AN 3 1 2006 Alaska Oil & Gas Cons. C~ Anchorage January 27,2006 Mr. John Norman, Chair Department of Natural Resources 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Sundry Report and Operations Summary: Change of Well Status Simp co Moquawkie No.2 (PTD#: 178-088) Dear Mr. Norman: Aurora Gas, LLC hereby submits a Report of Sundry Well Operations for the change of status fo the Simpco Moquawkie No.2, from (long-term) Shut In to Gas Well. Well work (flow and pressure buildup testing) was completed on September 24,2005. Pertinent information included under cover of this letter includes the following: 1) Form 10-404 Report of Sundry Well Operations. 2) Summary of daily well work and operations 3) Well test record. If you have any questions or require additional information, ple~e contact the undersigned at (907) 277-1003. ';';:Ií- £"¡'.ïÄ¡~~" , ~:;;;!I\;;;:;I~,¡¡ ~i,~~~Lj 'j ,,:: " >Í J. dward Jones ice President Operations and Engineering Aurora Gas, LLC cc: Keith Sanders, CIRI 10333 Richmond Avenue, Suite 710· Houston, Texas 77042· (713) 977-5799. Fax (713) 977-1347 1400 West Benson Blvd., Suite 410· Anchorage, Alaska 99503· (907) 277-1003. Fax (907) 277-1006 STATE OF AI...4.SKA Al~ Oil AND GAS CONSERVATION COMr610N REPðftr OF SUNDRY WELL OPERAíl0NS RECEIVED .IAN 3 1 2006 a...1. ..... ~ 1, Operations Abandon U RepairWell U Plug Perforations U Stimulate U ~..._, L.:..J. sio Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension [}nChorage Change Approved Program 0 Opera!. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: Aurora Gas, llC Development 0 Exploratory 0 78-088 3, Address: 1400 W. Benson Blvd, Suite 410 Stratigraphic 0 Service 0 6, API Number: Anchorage, AK 99503 50-283-20062-00 7, KB Elevation (ft): 9. Well Name and Number: 339 SIMPCO Moquawkie NO.2 8, Property Designation: 10. Field/Pool(s): CIRI C-061389 MOQuawkie (Undesiqnated) 11, Present Well Condition Summary: Total Depth measured 6727 feet Plugs (measured) - true vertical 6727 feet Junk (measured) - Effective Depth measured 6000 feet true vertical 6000 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 13-3/8",61# K-55 92' 92' Surface 1087' 9-5/8", 43.5&47#,N-80 1105' 1105' Intermediate Production 5721' 7", 26&29#, S-95 5739' 5739' Liner 686' 5",18#, N-80 6090' 6090' Perforation depth: Measured depth: 5666-5706' and 5880 - 5900' -. True Vertical depth: (same) Tubing: (size, grade, and measured depth) 2 - 7/8" 6.5#, unkn 5920' Packers and SSSV (type and measured depth) Baker FB-1 Retainer Prod Pkr @ 5352' Baker FAB30 Retainer Prod Pkr @ 5853' (No SSSV) 12, Stimulation or cement squeeze summary: Intervals treated (measured): N/A RBDMS BFL FE8 1 5 2006 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: - 1850 - - 248 Subsequent to operation: - 1310 - - 1763 14, Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run N/A Exploratory 0 Development 0 Service 0 Daily Report of Well Operations X 16, Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, /sundry Number or N/A if C,O. Exempt: Contact Ed Jones Printed Name J, Edward Jones/'\ Title Exec. Vice President Signature ~./, ÁJn4. Phone (907) 277-1003 Date 1/26/2006 vr Form 1 o~evised 04/2004 (/ Submit Original Only e e AURORA GAS, LLC SIMPCO MOQUAWKIE #2 PULL PLUGS, TEST, AND PUT ON PRODUCTION DAILY REPORT SUMMARY 6/26/05- V etco Gray service man to Simpco Moquawkie #2 well site to inspect 1978- vintage FMC tree. Lubricate tree and install pressure gauge-SITP is 2250 psi-BPV is leaking. 7/5/05- Tyonek Contractors cleared brush from old well pad and leveled it. 7120/05-Mobilize Pollard Well Service slick line truck and rig up lubricator on well. 2250 psi on tree. Blew down pressure-very slow leak in BPV. Run tools in attempt to identify BPV type. Order retrieving tools from Kenai. Attempt to retrieve RBP from tubing hanger-21 unsuccessful attempts. 7/21/05-Attempt to latch onto to BPV multiple times-unsuccessful. 1800 psi on tree. Blow down slowly (15 minutes) and attempt to latch BPV -unsuccessful. RD and release Pollard. 7/28/05-Rig up blow down line on wing valve to vent gas away from well head. Mobilize fiber-optic video camera (1.75" OD) and operator (Westburg water well services). Blow down tree and leave venting thru wing. Run camera into tree down to BPV and record video. Pull camera and SI tree. View video. Demob to Anchorage. Video accidentally erased before copies were made. 8/17/05-Re-run Westburg video camera as above. Make copies of video for FMC and Pollard. Pollard to make up new retrieving tools. 8/27/05-Mobilize Pollard. RU slick line and lubricator on well. SITP-2250 psi. Pull BPV from hanger. RIH to 5310' to retrieve plug, FL at +/-5050'. Pull prong-pressure already equalized due to slow leak. Attempt to latch onto blanking plug at 5310' several times-unsuccessful. Run hydrostatic baler on slick line. SIFN. 8/28/05-Run hydrostatic baler and junk basket on slick line-no recovery. Run in hole and latch onto plug and jar until sheared. Repeat. Change tool to JUC-would not latch. Run baler-no fill. Modify tool (shorten prong 1"). RIH and retrieve blanking plug at 5310'. RD and release Pollard. e e 9/17/05-RU Aurora well test unit on well. Install SPIDR surface pressure recorder. SITP-2222 psia. Open well on 16164" choke and flow for 2.67 hours to condition. FFTP-1664 psia. Shut in well and allow to build up.. 9/18/05-15.5 hour SITP-2201 psia. Open well on 16164" choke. After 4 hours, well stable at 1310 mcfpd at 1763 psia. Open choke to 18/64". After 4-1/4 hours, well fairly stable at 1495 mcfpd at 1434 psi. Open choke to 20164". After 4-1/4 hours, well flowing 2054 mcfpd, wi pressure at 1119 psi and slowly dropping. SI well for build up at midnight. 9/19/05-9/24/05-well shut in for pressure build up. Final SITP-2240 psi after 131.4 hours. Remove SPIDR and send in for download. 10/27/05-11/20105-Set line heater, mini-sep, and 100-bbl produced water tank on Simpco Moquawkie #2 pad, and lay 2290' of3-inch coated XH line pipe back to tie in to the Mobil Moquawkie #1 production facility downstream of compressor I upstream of dehy. 12/14/05-SITP-2250 psi. First sales: open well to sales (free flowing) at 1400 mcfpd. 12/16105-S1 well due to low demand. FFTP-1380 psi, rate-1350 mcfpd. Ed Jones 1/27/06 e e SIMPCO MOQUAWKIE #2 PRESSURE BUILDUP AFTER FLOW TEST LOWER TYONEK PERFS SURFACE PRESSURES ONLY START TIME 0004:05 9/19/2005 (FSIP BUILD UP) BHT= 114 t= 11.0993 MID PERF= 5750 Suñace P CALC DATE TIME DELTA T SPIDR BHP SURF t+Delta tI COMMENTS (met) TIME ON REC HRS PSIA PSIA DEGF delta t CUM PRO[ 9/17/2005 Initial SIP survey 16:41:05 0.4181 2222.220 2480,8 62.7 Install SPIDR on SI well 17:21:50 1.0972 2220.980 2539.0 64.4 open well to condition Flow 2.67 hrs on 18/61 Est- 160 20:01 :20 3.7556 1664.289 49.8 SI well after flow 9/18/2005 Buildup after conditioning 11 :20:40 19.0780 2200.892 2521.0 55.2 11 :34:45 19.3125 2200.938 2518.0 61.1 open well to flow test 13:00:00 20,7333 1828.566 68.1 16/64" CHOKE 13:15:00 20,9833 1803,045 66.4 RA TE= 2076 MCFPD 182 13:30:00 21.2333 1790.727 67.2 RATE= 2028 MCFPD 203 13:45:00 21.4833 1790.795 67.1 RATE= 1563 MCFPD 219 14:00:00 21,73333 1775.515 65.4 RA TE= 1563 MCFPD 235 14:15 21.98 1713,517 63.0 RA TE= 1563 MCFPD 252 14:30 22.2333 1777.378 2030.400 67.2 RATE= 1563 MCFPD 268 14:45 22.4833 1755.490 70.0 RATE= 1563 MCFPD 284 15:00 22.73333 1741.615 68.4 RA TE= 1267 MCFPD 297 15:15 22.9833 1730.231 68,2 RA TE= 1310 MCFPD 311 15:30 23.2333 1762.650 2010.300 70.3 RA TE= 1310 MCFPD 325 15:33 23.2903 1766.237 72.1 OPEN TO 18/64" CHOKE 325 16:00 23,7333 1385.361 71.6 RA TE= 1690 MCFPD 342 16:30 24,23333 1508.129 73.2 RA TE= 1424 MCFPD 357 17:00 24.7333 1508.300 1720.200 66.4 RA TE= 1424 MCFPD 372 17:30 25.2333 1514.600 67.6 RATE= 1551 MCFPD 388 18:00 25.7333 1520.100 69.6 RA TE= 1510 MCFPD 404 18:30 26,2333 1467,100 61.2 RATE= 1469 MCFPD 419 19:00 26.7333 1448.700 55.6 RA TE= 1495 MCFPD 435 19:30 27.2333 1436.400 52.8 RATE= 1495 MCFPD 450 19:45 27.4833 1434.400 1640,400 51,9 RATE= 1495 MCFPD 466 19:47 27.51667 1433.500 78.3 OPEN TO 20/64" CHOKE 466 20:15 27.9833 1420.700 50.1 RATE= 1853 MCFPD 485 21:30 29.2333 1402.800 47.1 RATE= 2095 MCFPD 507 22:00 29.7333 1399.300 46,8 RATE= 2197 MCFPD 530 22:30 30.2333 1331.400 48.6 RA TE= 2080 MCFPD 551 23:00 30.7333 1292.800 47.8 RATE= 2068 MCFPD 573 23:15 30.9833 1280.400 46.7 RATE= 2054 MCFPD 594 23:30 31.2333 1252.700 48.6 RA TE= 2054 MCFPD 616 23:45 31.4833 1197.800 49.4 RA TE= 2054 MCFPD 637 24:00:00 31.7333 1119.100 1280.900 50.5 RA TE= 2054 MCFPD 659 9/19/2005 t+Delta tlDelta t 0:04 31.8 0 1106,100 1257.20 50.5 SI for buildup 31,85 0.05 1120.900 1274.3 50.4 222.99 31.9 0.1 1140.800 1297 51.5 111.99 31.95 0.15 1156.400 1315.2 50.7 75.00 32 0.2 1172.600 1334.2 49.8 56,50 32,05 0,25 1203.800 1370.5 49.2 45.40 e e 32.1 0.3 1239.600 1412.1 48.6 38.00 32.15 0.35 1263.400 1439.8 48.2 32.71 32.2 0.4 1284.600 1464.5 47,7 28.75 32.25 0.45 1304.100 1487.34 47,4 25,67 32.3 0.5 1318.500 1504 47.1 23.20 32.35 0.55 1331.900 1519.7 46.8 21.18 32.4 0.6 1336.900 1525.6 46.5 19.50 32.45 0.65 1340,900 1530.3 46.3 18.08 32.5 0.7 1342.600 1532.4 46.0 16.86 32.55 0.75 1346.400 1536.8 45.8 15.80 32.6 0,8 1348,200 1539 45.5 14.87 32.65 0.85 1350.600 1541.9 45,2 14,06 32.7 0.9 1352.200 1543.9 44.9 13.33 32.75 0.95 1355.200 1547.5 44,6 12.68 32.8 1 1358.700 1551.8 44.1 12,10 32,85 1,05 1362,900 1556.7 43.8 11,57 32.9 1.1 1366.400 1561.1 43.4 11.09 32.95 1.15 1368.600 1563.7 43.2 10.65 33.05 1.25 1380.600 1577.6 42.8 9,88 33.15 1.35 1385.400 1583.2 42,7 9,22 33.25 1.45 1388.400 1586.7 42.5 8.65 33.35 1.55 1402.600 1603.6 42.2 8.16 33.45 1.65 1413.700 1616.5 41.9 7.73 33.55 1.75 1438.1 1644.9 41.7 7.34 33.8 2 1474.100 1687.2 41.1 6.55 34.3 2.5 1517.600 1737.9 40.8 5.44 34.8 3 1545,900 1771.3 40,0 4,70 35,3 3,5 1594.000 1827,8 38,9 4,17 35.8 4 1653.500 1897.7 37.8 3.77 36.3 4.5 1738.200 1997 37.0 3.47 36,8 5 1848,900 2125.9 37.4 3.22 37,3 5,5 1952.800 2246.1 37.9 3,02 37.8 6 2056.800 7:12 37.4 2.85 38.3 6.5 2165.000 2491.7 37.5 2.71 38.8 7 2168.400 2495.7 38.4 2.59 39.8 8 2174,300 2501,7 39.3 2,39 40.8 9 2178.900 2504.18 43.0 2.23 41.8 10 2183.900 2507.2 46.7 2.11 42.8 11 2183.100 2502.2 52,8 2.01 43.8 12 2190,400 2508 56,8 1.92 44.8 13 2193.100 2509.2 59.6 1.85 45.8 14 2195.600 2511.7 60.5 1.79 46.8 15 2197.900 2511 66,0 1.74 48,8 17 2201,300 2516.7 62,9 1,65 50.3 18.5 2203.700 2521.1 60.3 1.60 52.3 20.5 2206.100 2532 48.0 1.54 55.3 23.5 2209.400 2537.2 46,2 1.47 59.3 27.5 2213.600 2545,6 41.4 1.40 64.8 33 2218.100 2550.8 41.3 1.34 69.8 38 2222.900 2549.9 80.6 1.29 75.8 44 2224.400 2551.7 50.1 1.25 81.8 50 2226.800 2563 35,7 1.22 87.8 56 2228.700 2570.5 30.5 1.20 90.8 59 2228.900 2558.9 47.2 1.19 90.9 91 91.015 95.8 105.8 110.8 120,8 130.8 140.8 150.8 160.8 163.1 11 :30 163.2333 9/24/2005 e 59.1 2230.100 59.2 2230.800 59,215 2233.700 64 2230.600 74 2233.100 79 2233.700 89 2235.600 99 2236.400 109 2238.200 119 2238.000 129 2238.100 131.3 2241.500 131.4333 2240.100 p*= 2579.00 psia m= 260.17 psi/cycle gravity= 0.56 Tc= 344 deg R Pc= 672 psia Tres= 574 deg R cg= 0.000697 -psi Cr= 3X10**-6 visu1= 0,0112 u/u1= 8g= 0,0075296 cf/scf s= delta Pskin= reality ck: Pwf w/o skin 2560.3 2561.1 2563.7 2564.4 2565.1 2565.6 2566,1 2565.5 2568.7 2569.5 2570.600 e 47.5 47.8 47.9 52,9 46.1 46,0 48.5 49.1 53.0 48.4 46.8 51.1 52.6 1.19 1.19 1.19 1,17 1.15 1.14 1.12 1.11 1.10 1,09 1,09 1,08 Max SITP Final Surface SITP Pwf= 1508.300 psia Q= 1424 mcf/d Z= 0.855 Tr= 1.67 Pr= 3.04 net pay= 60 (perfs) ct= 0.000317 -psi P1 hr= 2455 psia (from plot of log delta t VS. bt 1.15u= 0.01288cp kh= 14,94137 k= 0.25 md 3.08 696.27 psia 2204,57 p* at 5750'= 2590.197 psia assuming no water to 36QO' 79DSTs-- at 5880-5900'. FSIP was 2633 psi w/ recorder at 5371' at 5666-5706', FSIP was 2551 psi w/ recorder at 5660' Ed Jones 10/11/2005 NOTE--SURFACE PRESSURES ON SPIDR IN PSIA. Sundry Notices for Wellwork e e Suhject: Sundry ì\otices for Wellwork From: Thomas Maundcr <tom_lllaundcr@admin.statc.ak.lIs> Date: Tuc, 31 Jan 200614:12:28 -0900 To: Ed Jones <jejones@·.aurorapower.com> CC: Steve McMains <stcve__ITIemains:1.yadmin.stale.ak.us:>, Bob Fleckenstein <bob.. llcckenslein@admin.slate.ak.us> Ed, This note follows our phone conversations regarding submitting sundry notices for wellwork. We in particular spoke of the Simpco Moquawkie No.2 (178-088) which was recently put back in production after performing wireline work and testing. You mentioned that you had looked at the regulations and could not find a requirement to submit a sundry notice when a well is considered "SI". The true status of the well is somewhat confusing. It has been carried as SI (shut-in) since wellwork was completed February 25, 1979. Although the well did have live perforations they were not readily accessible since a WL plug had been set deep and a back-pressure valve installed in the tubing hanger. Equipped so, the well more resembled suspended rather than SI but the distinction is a fine one. Regardless, it is requested that Aurora file a sundry notice (Form 10-403) in advance of performing work similar to what was done here. If there is a question with regarding to the need to file a sundry, please contact me. Alternatively, you will not incur any penalty for filing a sundry request that might not be needed. Your attention to this request is appreciated. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 1/31/2006 3 :29 PM Jack, GUIDANCE? RECOMMENDATION? I have a problem with the well status on well SIMPCO MOQUAKIE No 2. Some how the well status, final and current status, were assigned the same date 2/25/79 and we have a dual date in the well history. There is no production reported from the well to the commission. How would you determine this well status or suggestion for the correct status? Remember the exercise we went through for the commissioners for their report to the legislature, duplicate well status and dates in the database. This shows a long term SI status without proper paper work. The only way I show SI (shut-in) status in the mainframe is if I receive a letter from the operator asking for the status and reason for the long-term status. I could delete the current status and date from the database and show the well as a gas producer like the paper work states. A3~ASKA INDIVIDUAL WELL PRODUCTION AS OF 02/16/99 ******** NO PRODUCTION FOUND FOR WELL: SIMPCO MOQUAWKIE 2 WITH API #: 2832006200 ALASKA OIL AND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD - Commission use only - 02/16/99 PERMIT API I WELL WELL LEASE I CONFID -~-~--I--~-~--~--I ....... ~-~- .......... ~-~-~-I~ ~'~ I ~o~, ......... 78-0088-0 2832006200 SIMPCO MOQUAWKIE 2 739 FEE TYONEK 13979 +- + OPERATOR 116550 COOK INLET REGION INC G~,OLOGIC ION-O~I~ CODE I ~EA I ~OREICMP 820 COOK INLET BASIN ON 0 FLDPOL FIELD AND POOL CODE I N/d~IE 000000 MULTIPLE POOLS 000000 000000 000000 000000 000000 UNIT 00000 + UNIT NAME CODE FEET CODE FEET MD TVD COD 6727 6727 18A + FEET DIR FEET DIR SEC TWP RNG MER FEET DIR FEET DIR SEC TWP RNG MER 0785 S 2046 E 01 lin 012W S 0785 S 2046 E 01 lin 012W S l~' 4 6.00 151 19 18.00 78 6161 79 566 INITIAL CLASSISTATUS EX P 1 - GAS +- DEV 1-GAS ~EV SI NO NO ~0 + 11/22/78 11/22/78 11/25/78 02/25/79 02/25/79 01/03/95 MEMORAILDUM TO: THRU: Lonnie C. Smith Con~ni s s loner FROM: Statt of Alaska AkASKA OIL AI~D GAS CONSERVATION COI~R~ISSION , /.' DATE: October 22, 1984 C. ~tterton Ch%~n~j/~-~ FILE NO: D 2I 45 TELEPHONE NO: Harold R. Hawkins ~ ~ ~ .-, Petroleum inspect or~¢~ ~' SUBJECT: Clean-up Inspection Simasko Production Co. Simpco Moquawkie No. 2, Surf. Loc. 785' FSL, 2046' FEL, Sec. 1, TllN,R12W,SM, Permit No. 78-88. ~October 17, 1984: I left Simpco Moquawkie No. 1, ~~0'~-h~ ~o~-~ to Simpdo Moquawkie No. 2 for clean-up inspection. The location was clean, level and free of debris. The well sign was on the ground when i arrived on the location, I wired up the sign to the well guard the best I could. -' All the well data on the sign was satisfactory. I took pictures to verify conditions to be attached to this report. I also filled out an AOGCC field report which is attached. In sun~ary, I inspected Simpco Moquawkie No. 2 for clean-up in- spection. This well is classified as a gas well. Attachment/pictures in file. O2-0,;1AfRev. 10/79~ Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION: ,. Operator ,.~//9,~ ~'/~ /~/~L)D,_ Z"~3 Date S-uspended.~-~6-~~ Add re s s Surface Location of Well Permit No. Sec. '/, T_// ~__, R~ ~). , _~__M. Unit or Lease Name Wel 1 No. Field & Pool ..... !~/~.D Condition of Pad Condition of Pits .~/, ~ Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard Attached to Information correct e~ No Ye s No No Cellar - Op~ned Yes No Fi 1 led Ye s No WaterWell - Plugged off .... _~._A~ T:-I~ u-'~' ~ , Ca p pe d Ope n Rat Hole Open Yes No Fi 1 led Ye s No Explanation ~ d ?~/~X-/~. ~_./_O ~ ~ Photographs taken to verify above conditions ~e's)No E x p 1 a n a t o n ~/~T~)_z?4:' ,r Work to be done to be acceptable .. This well and location is (acceptable) (unacceptable) to be classified as suspended for the period of 19... thru 19 . Inspected by: _ _ _ Date: / ' / Revised 8/24/82 simasko Production Company P. O. BOX 1515 · ANCHORAGE, ALASKA 99510 · (907) 277-5932 · 274-4591 · TELEX 26-338 February 16, 1983 Re: SIMPCO Moquawkie No. 2 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Attn: Mr. Harry W. Kugler Corem i s s io ne r Dear Mr. Kugler: Transmitted herewith are the following materials pertaining the SIMPCO Moquawkie No. 2 located in Section 1, TllN, R12W, S.M.: to Item No Pieces Log Interpretation System (LIS) 1 Please acknowledge receipt by signing this letter. and returning one copy of Sincerely, Simasko Production Company Keith W. Calderwood KWC: nk Enclosure as Received by: noted · An hor e February 4, 1983 ~,,-~r. v-~. R. Stewart Simasko Production Cor~pany P. O. Box 15i5 Anchorage, Alaska 97510 Dear ~-~r. Stewart: The Alaska Oil and Gas Conservation Co~?.~?ission has recently checked the records of wells con~p~eted ~ince January 1, 197~ ~'~!~ revie~ has revealed that the digitized data for certain lof{s run in a ~.~!1 is not on file with the Co~mission. The Oil and Gas Regulations require the operator to 'Si]e, ~ days after cor,~p!etion, susoension, or abaodon~ent of a dr~.~lin~. ' for ~.?ell, the digltizeq data, if available, for co?yi~l, rur~ iD. the ~ell e~:cept velocity~ survevs,~, e>:.peri~enta] ]o~:.. ~:~eter surveys. ~'~e ~ ~ h ,-~ ~go~:l~J request t~,.at you c~.ecK vo,~w recorc~s to ~ee if the data has been su~nitted to ~:he Com:Qission and, if nott, that you c°~'~o!v ~,ith '~ ~..~_ . .... ,,' ~ tn.~ reKu]ation ~-~_t:h re?:ar{~ to the [ol Thank you = ~ ~o~ your cooperation in this matter. Yes,rs very truly, Simasko Production Company P. O. BOX 1515 · ANCHORAGE, ALASKA 99510 · (907) 277-5932 · 274-4591 · TELEX 26-338 ~arch 28, 1979 Re: State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99 501 Attn: ~. Harry Kugler Chief Petroleum Geologist Gent leme n Transmitted herewith are 1 reverse sepia and 1 blue line print of each of the following logs pertaining to the SIMPCO ~4oquawkie ~2 located in Section 1, TllN, R12W, S.M.: Item .............. Scale Depth ~ual Laterolog MISFL L~al Laterolog ~:4-SFL ,/B HC- Sonic ~BHC- S on ic ~ormation Density '~/CNL-FDC 1/~r oximity Log-Microlog ;/Cement Bond Log ~'fRun I *[Run 3 ~un ~ F asing Collar Log asing Collar Log 2"=100 ' 1112-6625 ' 5"=100 ' 1112-6627 ' 2"=100 ' 1105-66 31' 5"=100 ' 1105-6631' 5"=100 ' 1105-6340 ' 5"=100 ' 1105-6340 ' 5"=100 ' 572 3-6291' 5"=100 ' 2200-2800 ' 5"=100 ' 5404-599 2' 5"=100 ' 2000-2733' 5"=100 ' 5400-6000 ' 5"=100' 540 4-572 0 ' Please acknowledge., re, ceipt by signing and returning one copy of this letter. Sincerely, %Keith W. Calderwood Alaska Regional Geologist KC/jm Enclosures~:~As noted above Received b~' './~ ~, x /~/m~/~ 'STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE ELL COMPLETION OR RECOMPLETION REPORT ~ND LOG*' uook Inle¢ Region, .~ ~%~L ~ g~ ~ E~':D [X%~.~ ~7~R. ~ Other ~8. UN'~ FARM OR LEASE NAME _ Inc. S IMPCO Moquawkie Simasko Production Company 3. ADDRESS OF OPERATOR · P.O. Box 1515, ~nchorage, AK 99510 4. LOCATION OF WELL (Report location clearly an~ i .... ordance with any State requirements)* ~~ "'~:'~-'~: -' Wi ldcat At;~Drface785'FSL, 2046' FEL, Sec 1, TllN, Rlg~, ....S.-~~'s[c''*''~''~''{~°*m~"°~o~c,,w~ At top Plod. interval reported below :~ ~ Same ~o~,~ Sec 1, TllN, R12W, S.M. Same ~z ~,~ ~o. (drilled as a straight hole) 78-88 ~]-?5-7~ ~ ]-5-7~ ', 2-25-79 1339' .KB (reference) I 321' I~.~OT~DEPT~ MD&T~ T19. PLDG BACK MD&TVDI20 IF MULTIPLECOMPL I INTER~ALS DRILLED BY ' / DEPTH J ' HOW MANY* " J 21. ROTARY TOOLS .... CABLE TOOLS 6727' MD &TVD / 6000' ~ & TVDI2(sin~le tbng) lsurf to 6727' ~ - 22. PRODUCING INTERVAL(S), OF THIS COMPLETION -- TOP, BOSOM, NAME (~D & TVD)* 23. WAS DIRECTIONAL SURVEY MADE SEE ATTACHED SHEET No 24. TYPE ELECTRIC AND OTHER LQGSRUN RFT/GR, DLL-MSFL/SP-GR, BHC Sonic/GR: 1ES; Proximitv-Microlo~. 25. CASING SIZE WEIGHT, LB/FT. 6!. 43' 5&47 26 ~ 99 26. HDT, FDC-CNL/GR, VDL-CBL, C~ING RECORD (Report all strings set in well) GRADE. I DEPTH SET (MD) HOLE SIZE I K55 I 92 17~ I 100 N80 I 1105 S95 ] 5739 LINER RECORD SIZE TOP (MD) I BOTTOM (MD) SACKS CEMENT* 5 5404 I 6090 100 I 28. PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) 5666 '-5706' (40' @SJSPF o£ 0.43" holes) 5880-5900' (20' @4JSPF of 0.34" holes & 4JSPF of 0.43" holes) CEMENTING RECORD AMOUNT PULLED sx to surface 12~. 535 sx to surface 27, TUBING RECORD - ~ 7 la ~9~n None None ~'~('~ n t~ PACKER SET (MD) I~l ~5357 ' (7'~) SCREEN (MD) SIZE DEPTH SET (MD) ~29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) ~AMOUNTAND KIND OF MATERIAL USED 30. PRODUCTION DATE FIRST PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) I WELL STATUS (Producing or .qEE ATTA~.HE~ D~TE~F ~ri~T~ .... T~6URg'I:E~-T~D CHOKE SIZE I PROD'N FOR OIL-BBL. GAS-MCF. WATER--BBL. IGAS--OIL RATIO / I TEST PERIOD [ I [ FLOW TUBING [CASING PRESSURE CALCULATED OIL-BBL. GAS--MCF. WATER-BBL. I OIL GRAVITY-APl (CORR.) 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) J TEST..W1TNESSED BY' Flared I None ~ZL,STOFATTACHMENTS Producing intervals, Production, Cement squeezed inte'~vals, DST data, Core description. Forms G-1 w/curves, & daily drillin~ sunnnar¥. 33. I hereby certify that the f~regoing a?..cl-~ac_~ ~'nformation ~s complete and correct as determined from all available records, - , . .';, , '. . ~ ~ S,GNED / //'~'£---':' TITLE Vice-President o;~ ::Z;. P_7. R. ~q~wart *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General' This form is ctesigned for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) fol-depth measurements given in other spaces on this form and in any attachments. Items 20, and 22' If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the pioducing ~nterval, c)~ ~ntervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a sel)alat~ repor~ (pa.qe) on th~s fo-'n adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement"' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28' Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPT SEE ATTACHED SHEET Beluga Fm 120' 120' (219 'MSL) Tyonek Fm 1143' ]_143' -804 'MSL) ~,loquawkie 2816' 2816 ' (- 2477' ~.iSL) ~qiddle Orounc 36. CORE DATA. ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS Shoal "A" 3470' 3470 ' AND DETECTED SHOWS OF OIL, GAS OR WATER. (- 3 1 3 1 '~'~S L) TD (Tyonek) 6727' 6727' (-6388 'MSL) SEE ATTACHED SHEET ATTACHMENT NO. 1 State of Alaska Form P-7 SIMPCO Moquawkie Well No. 2 Part No. 22 Producing Intervals: Tyonek Formation, ~iddle Ground Shoal Member "A" Unnamed Sand - 5666' (MD & TVD) Top 5708' (MD & TVD) Bottom (Perforated 5666-5706') Unnamed Sand - 5880' (MD & TVD) Top 5945' (MD & TVD) Bottom (Perforated 5880-5900') Part No. 29 Cement Squeezed Intervals: Interval (~D) Perforations 4 725- 4745 4JSPF 2900-2920 4JSPF 2847-2 86 7 4JSPF 2479-24 80 4JSPF 2272-2273 4JSPF 2514-2534 4JSPF 2336-2386 4JSPF Amount of Squeeze ~4aterial 50 Sacks Class G 25 Sacks Class G 25 Sacks Class G 75 Sacks Class G 75 Sacks Class G 25 Sacks Class G 125 Sacks Class G ATTACH~,~ENT NO. 2 State of Alaska Form P-7 SIMPCO Moquawkie Well No. 2 Part No. 30 Production: Interval 5880-5900' Date of First Production Production Method Well Status Date of Production Test Hours Tested Choke Size (64 Production for Test Period (oil) 1-19-79 (DST ~1) Flowing Shut-in 2-20-79 10.75 12 , 18, 24 (gas) 232 MCF (wa ter ) 0 Gas-Oil Ratio N/A FloWing Tubing Pressure* 577,_195,113 psig Casing Pressure (Packer) Calculated 2~-Hour Rate (oil) 0 (gas) 614 MCFD @24/64" (wa ter ) 0 Interval 5666-5706' and 5880-5900' Commingled 1-22-79 (DST ~2) Flowing Shut-in 2-24-79 14.25 12, 18, 24, 30 0 788 MCF 0 N/A 1385, 651, 36~, 248 psig (Packer) 113 0 1850 MCFD @30/6~" 0 Oil Gravity N/A N/A * Flowing Tubing Pressures reported correspond to the various choke sizes shown above. ATTACHMENT NO. 3 State of Alaska Form P-7 Part No. 34 SIMPCO Moquawkie #2 DST Reports DST #1 5880-5900' 1-18- 79 Set RTTS packer @ 5358. Swabbed to 1360'. Perf 4/spf enerjet. Immediate light blow decreased to very weak in 20 minutes, then increased to strong in 2 hrs. Well would not unload. Swabbed well in and flowed to separator. Flowed @ Tubing Pressure MCFD ¼" Choke 260 294 3/8" Choke 107 400 ½" Choke .69 440 Open 24 hrs. No shut in due to leak in tubing. IHP-2652, IFP-327, FFP-228% FHP-2635. (Recorder @5369') DST 9lA '~5880'~900' ~1-20-79 · Reperforated w/3 3/8 carrier gun w/4spf. 1000' water cushion. Packer set @ 5587'. Flowed @ Tubing Pressure MCFD 24/64 Choke 307 670 28/64 Choke 271 730 32/64 Choke 230 763 36/6~ Choke 225 770 1st Flow-Open 3 hrs 15 minutes, shut in-6hrs. 2nd Flow-Open 13 hrs, Shut in 21 hrs. IHP-2674, IFP-583, FFP-454, SIP-2597. 2nd period, IFP-750, FFP-204, FSI-2633. (Recorder @5371' ) DST # 2 5666-5706' 1-22- 79 Perf w/4 spf. Packer set at 5371, Tailpipe @ 5658. 1000' water cushion. Fluid to surface in 10 minutes - flowed well ~o clean upon 32/64 choke at 1.96 MMCFD @350 psi TP. Open 3 hrs. 10 minutes, shut in 9 hrs. IHP-2822, IFP-1139, FFP-616, FSI-2551, FHP-2853. (Recorder @5660') Unable to reopen tool. Killed well and reran test (DST 2A) SIMPCO Moquawkie #2 DST Reports Page Two DST ~A 5666-5706 '' 1-23- 7~9 Reran test due to tool failure. Packer set @ 5387, 1000' water cushion. Opened with immediate fair blow. Gas to surface in 25 minutes, fluid cushion to surface in 40 minutes. Flowed @ Tubing Pressure MCFD 16/64 Choke 925 1410 24/64 Choke 490 17 16 32/64 Choke 275 1750 40/64 Choke 172 1750 1st flow - open 6hrs 17 min., shut in 12 hrs.. 2nd flow - open 12 hrs, shut in 4 hrs. IHP-2912, IFP-639, FFP-429, ISI-2532 IFP-702, FFP-363, FSI-2354, FHP-2810. (Recorder @ 5645') DST ~.3 4725-4745' 1-26-79 Perforated w/4" carrier, 4spf. Packer set @4667', tailpipe @ 4688' Opened 21 hours -no shut in. Immediate strong blow for 1~ hrs then decreased ~ medium and weak blow. Started swabbing w/ fluid level @148'. Gas to surface in 10 hours. Recovered fluid w/ weight decreasing from 9.5 ppg to 8.6 ppg. Swabbed total of 47 bbls of completion fluid and formation water, 28,000 .ppm chlorides. IHP-2324, IF-415, FF-2085,. FHP-2257. (Recorder @4681') DST 94 2900-2920 1-28-79 Packer set @2853', tailpipe @2865'. Swabbed to 1450'. Per- forated w/4 enerjet spf. Open 8 hrs, 8 min., no shut in. Immediate medium blow. Gas to surface in 1 hr. Blow decreased to weak. Swabbed 19 bbls com- pletion fluid + 5 bbls formation water, 23,000 ppm chlorides. IHP-1387, IF-599, FF-179, FHP-1387'. (Recorder @2864') SIMPCO Moquawkie #2 DST Reports Page Three DST #5 2847-2867' 1-29-79 Packer set @2785'.,. tailpipe @2797'. Swabbed to 1475'. Per- forated w/4 enerj~t spf. Open 3 hrs 40 min. No shut in. Immediate medium blow; decreased to weak in 30 minutes, dead in 45 min. Swabbed 9.5 bbls completion fluid and 14.5 bbls water (3700 ppm chlorides) in 2 hrs. IHP-1343, IF-?6L FF-1127, FHP-1343. (Recorder @ 2864') DST #6_ 2514-2534' 2-2-79 Packer set @2447, Tailpip, e @2460. Swabbed to 1000' from surface and perforated 2514-2534 w/4 Enerjet spf. Open 5 hrs 43 min., closed in 3 hrs. 45 min. Open 5 hrs 0 min., No final shut in. Opened w/immediate weak blow, dead in 25 minutes. Blow commenced in 32 minutes and increased to medium. Gas to surface in 55 minutes. Recovered small amount of gas TSTM and fresh water 33,000 ppm chlorides. (Completion fluid 133,000 ppm chlorides). 1st flow- IHP-1246, IFP-676, FFP-130, ISI-569. 2nd flow- IFP- 373, FFP-192, No final shut in, FHP-1244. (Recorder @2460') DST #7 2336-2356' 2-4-79 Packer set @2255, tailpipe @2268. Swabbed to 1000' from surface and perforated w/4 Enerjet spfo Open 7 hrs 55 min., shut in 3 hrs 36 min. .Opened with weak blow, dead in 18 minutes. Blow commenced again zn 28 minutes and built to medium. Gas to surface in 50 minutes. TSTM. Swabbed well to 2200'. No fluid rise~ only slight increase in gas - still TSTM. IHP-1158, IFP-671, FFP-36, FSI-56, FHP-1146. (Recorder @2268') DST #8 2336-2386' 2-5-79 Perforated additional zone 2356-2386 w/4 spf. Ran hydrospring tester w/packer set @ 2253, no cushion. Immediate strong blow. SIb~CO Moquawkie #2 DST Reports Page Four Gas to surface in 20 minutes. TSTM. No fluid entry. Open 2 hrs, shut in 3 hrs, open 6 hrs, shut in 4 hrs. 1st flow- IHP-1207, IFP-151, FFP-147, SIP-516. 2nd flow- IFP-124, FFP-182, FSI-670, FHP-1175 (Recorder @2270') PRODUCTION TEST NO. 1 5880-5900' 2-20-79 Production packer set @ 5352' in 7" casing with 5" packer at 5853' in 5" liner. Swabbed to kick off well. Flowed on 3/8" and ½" Choke to clean up well. Initial shut-in pressure 2073 psi in 8 hrs 45 minutes. Flowed well at following rates: Tubing Choke Time P re s sure Rate 12/64" 6 hrs, 0 min. 577 psig 453 MCFD 18/64" 2 hrs, 15 min. 195 psig 588 MCFD 24/64" 2 hrs, 30 min. 113 psig 614 MCFD Final shut-in pressure 2177 psig in 15 hrs, 45 min. (Recorder @5666') PRODUCTION TEST NO. 2 5666-5706', 5880-5900' , Production packer set at 5352' in 7" casing with 5" packer at 5853' in 5" liner. Sliding sleeve at 5713' opened to comingle both zones. Shut in 10 hrs, 45 minutes. Tubing pressure 2200 psig. Opened well and flowed at following rates: Tub i ng Choke Time Pres sure Rate 12/64" 7 hrs, 30 min. 1385 psig 970 MCFD 18/64" 2 hrs, 45 min. 651 psig 1620 MCFD 24/64" 2 hrs, 15 min. 368 psig 1750 MCFD 30/64" 1 hr, 45 min. 248 psig 1850 MCFD (Recorder @5666 ' ) 12/22/78 12/23/78 12/24/78 12/25/78 12/26/78 12/27/78 12/28/78 12/29/78 12/30/78 12/31/78 1/1/79 1/2/79 1/3/79 1/4/79 1/5/79 1/6/79 Log. Trip in and condition hole. Continue logging. Complete logging. Trip in and condition hole. Trip out and rig up to run casing. Change rams. Ran 7", 26 and 29 lb/ft, S-95, LT&C casing and landed at 5739' KB. DV collar at 3084'. Pump water spacer with clay stabilizer. Mixed and pumped 250 sacks Class G with 0.17 gal/sack DS0 and 0.2 gal/sack D108. Dropped plug and displace with mud. Did not bump plug. Dropped opening bomb for DV. Opened DV collar and circulate. WOC 6 hrs. pumped water spacer with clay stabilizer. Mixed and pumped second stage of 315 sacks Class G with 2% CaC12 and 0.2 gal/sack D108. Dropped closing plug and displaced with mud. Bumped plug and closed DV. Set slips to hang casing. Cut off 7" casing. Install and test casing spool. Nipple up and test BOP' s. Change BHA and trip into DV at 3084'. Drill plug and DV. Trip out and change bit. Trip in and tag cement at 5494'. Drill float collar and cement to 5728'. Test casing to 3000 psi. Trip out for casing scraper. Run casing scraper. Circulate and condition mud. Trip out and~ run VDL Cement Bond Log. Change BHA and trip in. Circulate. Fly in test equipment. Trip out and change BHA. Trip in and drill out cement. Drill 6" hole. Drill to 5810'. Trip for bit and drill %o 5993'. Trip for bit. Trip in and drill to 6161'7. Trip for bit. Trip in and drill to 6233'. Trip for bit and drill ahead. Drill to 6282' and trip for bit. Drill to 6305' and trip for bit. Drill ahead. ._~? Drilling. Trip for bit at 6509'. Tight hole at.~6~.3'0'. Drill ahead Drill to~6727'..~... ?' Circulate-.and'~'~C°nd~tion hole. Ream tight spots. S~'~ trip. circulate and condition hole. Short trip, circulate and 1/7/79 1/8/79 1/9/79 1/10/79 1/11/79 1/12/79 1/13/79 1/14/79 1/i5/79 1/16/79 1/17/79 1/18/79 1/19/79 strap out to log. Ran three logs. Trip in to condition hole. Wash to bottom and circulate. Circulate. Trip out and continue logging. Logs stopped. Trip in and clean out bridges. Raise mud weight to 10 ppg to 10.3 ppg. ·Condition hole. Condition'ho!e and short trip. Circulate and trip out. Completed logging. Hole tight. Trip in and circulate. Circulate, short trip, and condition hole. Condition hole and prepare to run liner. Trip out and run liner. Ran 16 jts of 5", 18 lb/ft, NS0, ABC FL4S liner. Liner stopped at 734'. Pulled liner. Recovered 2 centralizers and lost ~3. Reran liner and stopped at 734'. Trip out and lay down liner. Ran fishing spear and recovered 3 centralizers. Trip in with BHA and condition hole. Trip out and ran 16 jts 5", 18 lb/ft, N80, ABC FL4S liner and hung with shoe at 6090' and top at 5404'. Pump water spacer with clay stabilizer then mixed and pumped 100 sacks Class G neat and displaced plugs' with water. Bumped plugs CIP at 9:00 a.m. Release from hanger and reversed out 3 bbls cement.' Run in with 6" bit and casing scraper to the liner top. Change BHA and clean out inside the liner to 6000' with 4 1/8" bit. Circulate. Circulate. Trip out and WOC. WOC. Trip in to 6000' and circulate. Trip out and run VDL Cement Bond Log. Complete CBL. Trip in and test casing to 3000 psi. Change mud system. Change rams. Pick up and rabbit tubing. Rabbit 2 7/8" tubing. Test BOP. Prepare to DST. Trip in with DST tools. Trip out and change sub and recorder charts. Trip in and set packer at 5358'. Swab down to 1360'. Test perforating lubricator. Ran thru-tubing perf gun. Misfired. Repaired. Run in and perforate 5880-5900 (revised depth) 4 JSPF. Slight blow. Pull gun and open to flow. Light to strong blow. Swab. Gas to surface and on flare at 7:30 p.m. Testing wel 1. DST No. 1. Kill well due to tubing leak. Trip out. Ran 3 3/8" casing gun and misfired. Reran perf gun and perforate 5.~0-5900' at 4JSPF. Run DST tools with 1000' water cushion. Set packer at 5387' with tailpipe at --5-- · 1/20/79 1/21/79 1/22/79 1/23/79 1/24/79 1/25/79 1/26/79 1/27/79 1/28/79 5876'. Open tool at 10:00 p.m. Immediate strong blow. Cushion to surface at 11:00 p.m. Flaring gas at 12:00 midnight. Running DST No. lA. Start initial shut-in at 1:15 a.m. Start final flow at 7:15 a.m. Start final shut-in at 8:20 p.m. Ran four-point test. Complete final shut-in at 5:00 p.m. Kill well and trip out. Lay down test tools and trip in with bit and casing scraper. Ran casing scraper to 5950'. Ran and set retainer at 5850' and test to 2000 psi. Ran 3 3/~" casing gun and perforate 5666-5706' (revised depths) with 4 JSPF. Run DST tools and 1000' water cushion. Set packer at 5371 with tailpipe at 5658'. Tool open for DST No. 2 at 7:20 p.m. Cushion to surface-in 10 minutes. Flow well through separator to flare. Start initial shut-in at 10:30 p.m. Attempt to reopen tool failed; disrupting DST. Kill well. trip out and change tools. Trip in with DST tools for DST No. 2A. Ran 1000' water cushion. Set packer at 5387' with~tailpipe at 5653'. Open tool at 9:50 p.m. Gas to surface in 25 minutes. Fluid to surface in 40 minutes. Flare. Test well at various choke settings. Shut well in for build up. Kill well. Pull and lay down test tools. Set retainer at 5574' and test to 2000 psi. Trip in with tubing and spot 40 sacks Class G with 2% CaC12 from 5352' to 5137'. Reverse out and trip out. Perforate 4725-4745' at 4 JSPF with 4" casing gun. Run DST No. 3. Set packer at 4667' and tailpipe at 4688'. Open at 1:00 p.m. Fair blow increasing to good blow by 2:30 p.m. Blow decreased and well shut-in by 4:15 p.m. Swab well to 2375'. Swab well. No flow. Kill well and trip out. Run and set retainer at 4640'. Test to 2000 psi. Squeeze below retainer with 50 sacks Class G. Final squeeze pressure was 3000 psi. Reverse out. Pick up DST tools and trip in. Set packer at 2852'. Swab well. Swab well to 1440'. Run thru-tubing perf gun. Misfired. Reran and perforated 2900-2920' at 4 JSPF. DST No. 4. Medium blow decreasing. Swab to 2775'. No gas. Recovered formation water. Well dead. Reverse out and pull DST tools. Run and set retainer at 2790' and test to 2000 psi. Squeeze 25 sacks Class G below retainer. Final 1/29/79 1/30/79 1/31/79 2/1/79 2/2/79 2/3/79 2/4/79 2/5/79 2/6/79 squeeze pressure was 3000 psi. Reverse out. Trip in with bit and drill out retainer. Clean out to 2875'. Run DST tools and set packer at 2790'. Swab 'down to 1475'. Perforate 2847-2867' at 4 JSPF thru-tubing. DST'~5. Fair blow decreasing. Well dead. Swab, Recover formation water and trace of gas. Reverse out. Run and set retainer at 2756' and test to 2000 psi. Squeeze below retainer with 25 sacks Class G. 'Final squeeze pressure was 3000 psi. Increase mud weight from 9.3 to 10.i ppg. Trip out and perforate four holes to 2479'. Set retainer at 2435'. Tested to 2000 psi. Squeeze 75 sacks Class G below retainer with final squeeze pressure of 1800 psi. Perforate four holes at 2272'. Run retainer and set at 2224'. Test to 2000 psi. Squeezed 75 sacks Class G below retainer with final squeeze pressure of 1000 psi. CIP at 9:30 p.m. WOC. WOC. WOC. Drill out upper retainer and clean out to 2271. Test perfs to 1200 psi. Drill out second retainer. Clean out %o 2750'. Circulate. Ran VDL Cement Bond Log without pressure on casing and repeated with 500 psi and 900 psi on casing. Run DST tools and set packer at 2447' tailpipe at 2460'. Swab down to 1000'. Perforate ,2514-2534' at 4 JSPF thru-tubing. with DST No. 6. Weak blow and died. Swab to 2400'. Recovered formation water. Reverse out. Pull tools. Set retainer at 2410' and test to 1200 psi. Squeeze 25 sack_s Class G below the retainer with final sq~leeze~pressure of 1600 psi. Run test tools and set Packer at 2255' with tailpipe at 2268 ' . Swab to 1000'. Perforate 2336-2356' at 4 JSPF thru-tubing. DST No. 7. Medium blow with well dead in 18 minutes. Swab to 2200'. Shut well in for 3 3/4 hours.' Open well with weak blow. Kill well and reverse out. Pull tools. Perforate 2~356-2386' at 4 JSPF with casing gun. Run DST tools. Set packer 2253'. No cushion. DST No. 8. Open tools with good blow. Gas to surface in 20 minutes. TSTM. Shut in for 2 hours. Reopen. Run swab to locate fluid. No fluid entry. Shut in for 3 hours. Reverse out and lay down DST tools. Run RTTS packer and set at 2253'. Pump 50 sacks Class G. Started to squeeze and packer failed. Reverse out. Close rams and braden head squeeze 25 sacks Class G. Trip out. Run bit and drill soft cement from 2330' to 2391'. Clean out to 2410'. Pressure test perfs to 1200 psi. Broke down. 50 sacks Class G. Reverse out. Run RTTS and set at 2210. Squeeze with Final squeeze pressure was 2000 psi. 2/7/79 2/8/79 WOC. Drill 10' of firm cement. WOC. Drill cement from 2310' to 2395'. Test perforations and broke down at 1300 psi. Run RTTS and set at 2210'. Squeeze with 50 sacks Class G. Final squeeze pressure was 2000 psi. Reverse out and pull one stand. Close rams, pressure up to 1800 psi and WOC 3 hours. Trip out, pick up bit and run in to 2100'. WOC. 2/9/79 WOC. Tag cement at 2236'. Drill firm cement to 2390'. Test perforations to 1500 psi, OK. Trip out and pick up mill. Mill out retainer at 2410'. Pick up bit and drill out cement. 2/10/79 Clean out to 2756'. Pick up mill and mill up retainer at 2756'. Trip for bit. 2/11/79 2/12/79 Drill cement and clean out 2920. Trip for mill and mill out junk. Clean out to retainer at 4640'. Mi il on retainer. bit and drill out retainer and clean out to 4687'. to clean out junk basket. Trip for Trip 2/13/79 Drill out cement and junk. Clean out %o liner top at 5404'. 2/14/79 Run casing scraper to liner top. Condition mud. Change rams. Change BHA and clean out inside liner. Milled out retainer at 5574'. Well kicked. Circulated out kick through choke. Open BOP and circulate. 2/15/79 Clean out to retainer at 5850'. Tight hole. to clear junk. Mill on retainer at 5850'. Short trip 2/16/79 Hole tight. Work pipe to clear junk. ~{ill on retainer at 5850 ' . 2/17/79 Milled out retainer and well kicked. Circulated out the kick through the choke. Push junk to 5975'. Work pipe and clear junk. Trip out and run casing scraper to 5975'. Perforate 5666-5706' at 4 JSPF. Run casing scraper to 5975' and circulate. 2/18/79 Make up lower packer assembly. Test to 3000 psi. Run and set packer at 5853' with mule shoe at 5920'. Make up and - ?- 2/19/79 2/20/79 2/21/79 2/22/79 2/23/79 2/24/79 2/25/79 tested upper packer assembly to 3000 psi. Run and stab into · lower packer. Set upper packer at 5352'. Lay down drill- pipe and collars. Pick up completion tubing. Ran, drifted, and tested completion tubing to 3000 psi. Pull test plug. Space out and stab into packer. Land tubing in hanger. Ran blanking plug. Open sliding sleeve at 5280' and circulate 10.4 ppg fluid in annulus above packer, close sliding sleeve. Pressure test failed. Found blanking plug 54' below landing nipple. Swab down fluid level and retrieve blanking plug. Attempt to set plug in "S" nipple - failed. Ran No-Go plug and set in "F" nipple. Test to 2000 psi. Test surface lines to 3000 psi. Swab well down and retrieve No-Go plug. Swab well to 1600'. Swab well down to 2100" Wireline parted. Well began unload~ing. Flowed well to flare. Shut in and ran compression block and located fish at 5280'. Ran overshot and recovered fish. Flow well to clean up from 8:00 p.m. to 8:30 p.m. Shut in for 3 hour buildup. Open well to flow from perfs 5880 to 5900'. Test well from perfs at 58 80' to 59 00'. Test well from perfs at 5880' to 5900. Open sliding sleeve at 5713'. Flow well from perfs 5666-5706' and 58 80-5900' to clean up. Test well commingled. Complete testing and shut well in for buildup. Pull Amerada pressure recorders. Set blanking plug in "F" nipple at 5315'. Bleed down pressure. Set OCT back pressure valve in tubing hanger. Ran 1" heater string to 1103'. Install tree and test to 3000 psi. Rig down. Final Report. Simasko Production Company P.O. BOX 1515 o ANCHORAGE, ALASKA 99510 · (907) 277-5932 ,, (907) 274-4591 ,, TELEX 26-338 ATTACHMENT NO. A~ State of Alaska Form P-7 Part No. 36 . SI~.~?CO MOQUAWKIE # 2 CORE DESCRIPTION Core No. 1 2831-2851 Cut 20' recovered 20' 2831-2836 2836-2838 2838-2843 2843-2846 2846-2851 SandStone, Light - reed gray, medium grain, subang- subround, loosely 'consolidated predom quartz with abundant dark gray to black metarock grains. Sandy clay matrix. Porosity and perm fair to good. No cut or stain. Sandstone, as above becoming medium to coarse grained with scattered small pebbles to 10 mm., firm, slightly calcareous. C~od porosity. Sandstone, light-meal gray, medium grain, subang- subround, loosely consolidated to friable. C~od P & P. Conglom, hard, with pebbles 1" t6 2" comprised of chert and dark metarocks, firmly cemented in calcareous medium grain sandstone .matrix. Poor P & P, bleeding gas. Sandstone, medium gray, medium-coarse grading to'- very coarse and pebbly in bottom 2 feet, poorly sorted, subang-subround, with approximately 40% dark gray-black metarock grains. Friable with good P & P. ATTACHmeNT ~0. 5 State of Alaska Form P-7 SIMPCO Moquawkie Well No. 2 Daily Drilling Report Summary 11/25/78 11/26/78 11/27/78 11/28/78 11/29/78 11/30/78 12/1/78 12/2/78 12/3/78 Drill rat hole and mouse hole. Spud at 4:00 p.m. drilling 12~" conductor hole. Drilling 12~" hole to 92'. Open hole to 17½" to 92'. Circulate and~ condition hole. Ran 13 3/8", 61 lb/f t, K55 casing and landed at 92' KB. Ran 1" tubing inside casing and spotted a 20 sack Class G + 2% CaC12 cement p 1 ug. WOC. WOC. Ran 1" tubing outside casing and pumped 80 sacks Class G + 2% CaC12 cement with cement to surface. CIP @1:45 a.m. WOC. Cut off conductor and weld on casing head~. Nipple up BOP's. Nipple up hydril. Pick up B~A. Drill out cement and drill 12¼" hole to 224'. Trip for bit. Drilling. Drill to 1100'. Circulate. Trip out (SLM). Trip in and drill to 1110'. Circulate and condition hole. Ran 27 jts of 9 5/8", 43.5 lb/ft and. 47 lb/ft, NS0, Buttress casing and land at 1105' KB. Ran duplex stinger on drillpipe and stab into the duplex float shoe and circulate. Pump 10 bbls water, 350 sacks Class G with 1.5% prehydrated gel followed by 185 sacks Class G with 2% CaC12. Full returns throughout. CIP @~:45 p.m. Set slips in hanger. Cut off casing. Nipple down hydril. Install packoff and test to 3000 psi. Nipple up BOP. Complete nipple up. Test BOP's. (Rams to 3000 psi and hydril to 2500 psi. ) L~y down 12~" B~_A and pick up 8%" BHA. Trip in and tag cement at 1095'. Change over mud system and circulate. Drill out shoe at 1105'. Drill to 1116' and conduct leakoff test. Pressure up to 199 psi and bled to 160 psi in 1 hour, 7 minutes. With 9.8 ppg mud, 160 psi is equivalent to 0.65 psi/ft or 12.6 ppg mud weight. Drill ahead. -2- 12/4/78 12/5/78 12/6/78 12/7/78 12/8/78 12/9/78 12/10/78 12/11/78 12/12/78 12/13/78 12/14/78 12/15/78 12/16/78 12/17/78 12/18/78 12/19/78 12/20/78 12/21/78 Drill to 2180' and trip for bit. Drill to 2421' and well kicked. Closed BOP. SIDP pressure, 40 psi. SIC pressure, 200 psi. Raised mud weight to 10.1 ppg. Circulate through choke one circulation. Open BOP. Well dead. Drill ahead. Drill to 2690' and trip for bit. Drill to 2831' and trip out to pick up core barrel. Cut core No. 1 from 2831' to 2851'. Cut 20' with full recovery. Trip in with bit and ream 7%" core hole to 8%" and drill ahead. Drill to 2984' and trip for bit. Drill to 3193'. Trip for bit. Tight hole. Ream back to bottom. While reaming at 2629', torqued up and drillpipe backed off at 1000' KB. Screw into fish and jar loose. Trip for bit. Ream to bottom and drill ahead. Drill to 3467 and trip for bit. Ream bridges, Drill to 3590' and trip for bit. Drill to 3674'. Trip for bit and drill ahead. Drill to 3923'. Trip for bit and drill ahead. Drill to 4206'. Trip for bit and drill ahead. Drill to 4398. Trip for bit and drill ahead. Drill to 4722'. Trip for bit and drill ahead. Drill to 4878'. Trip for bit and drill ahead. Drill to 5086'. Trip for bit. Trip in and drill to 5260'. Trip for bit and drill ahead. Drill to 5404'. Trip for bit and drill ahead. Drill to 5577' and trip for bit. Trip in and ream bridges at 5510'. Drill on junk to 5587' and trip out. Trip in and drill to 5682. Stuck pipe and worked free. trip out. SLM. Trip in and drill to 5739'. Circulate and condition hole for logs. Trip out to log. ATTACHMENT NO. 6 State of Alaska Fo-~' P-7 SIMPCO ~oquawkie [~e~± No. 2 5" Iiner t ap at 5404' ?" casing · landed at 5739' 5" I in er landed at ~ 6090' Perfs: 5666 to 5706' Parts: 5880 to 5900' IPBTD: ! '/z.*/,c'//c'/~°°° TD at 6727' MD Compl etlon E_q u_Lp men t Item Description D._~e p t__kh (MD) I. Mule Shoe 5920 2. No-Go Nipple, R profile 5919 Baker Model FAB 30 retainer production packer 5853 4. Anchor Seal Nipple 5852 . Baker Model L SI iding sleeve {OPEN) 5713 6. Blast Joints 5653 - 2.44" ID 57 12 7. Seal Bore end Mill out Extensions 5355 8. Baker Model FB-I retainer production packer 5352 9o Seal Assembly (14 units) 8.72' inside w/locater at 5349 I0. Packer Locator Nipple 5348.5 II. Seating Nipple, F profile Blanking Plug in Place for Shut- in Status 5315 12. Baker Model L Sliding Sleeve (CLOSED) 528O .13. OCT Back Pressure Valve (For Safety Shut-in) Tubing Hanger 14. Heater String (1" nom.) Surf. to .... .:: ~-;~ 1103 NOTE':'~' .Mi'nimum ID restrictions at the "R" and "'""" (2. ID) ' F n:i:lSP:les 0.f:~:5919' & 5315' 25" , 't ' '.':-." _ StMPCO MOQUAWKIE Well No. 2 ':' ~,:::' Wellbore Schematic Shut-in Status February 25, 1979 Scele: None Form No. G-1 RE'~, i0169 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE GAS WELL OPEN FLOW POTENTIAL TEST REPORT Mult~-POIXT TEST Test Initial. [~] Annual [~ Special Field I Reservoir Wildcat Tyonak F~rma ~ on, . ~c.S "A" Operator I Lease Simasko Production Company SI~]?CO Hoquawkie County t Location [ Completion Date [ Total Depth Kenai 785'FSL, 2046 'FEL, Secl, TllN, R!2W, S .M. 2-25-79 6727 Producing' Thru ] ltesen'oir I Wellhead { CSG. Size %Vt/Ft. I.D. [Set~ TBG. ~ CSG. Temperature I Temperature x 107 .~ IN/A '~ 5" 18 4.276 6090' MD & ~D Test Date 1-19-79 ~Vell Xo. 2 T/Pay1' Producing Interval · 58805880-5 900 TBG. Size 1%Vt/Ft.t O.D. I.D. [ Set @ I gasCravlty I Avg;Pr°d' I GL[I (Separator) I Length (L) 2.5"nom 6.5 2.875 2.441 5920 10.584 15920 3457 Gas-Liqnid Hydrocarbon Ratio .%IFF per Bbl. o Gravity, of ],lquid (Apl) one Pipeline Connection I Type Taps None [ Flanqe Multiple Completion (Dual or Triple) [ Type production from each zone Dua 1 I Dry Gas OBSERVED DATA Flow Data Time (Prover) I (Choke) Press. ~ Diff. Tubing Casing Flowing No. of Flow (Line) (Orifice) h Press. Press. Temp. Hours Size Size psig xv psis' psig s~_L__ .............. . N/A 0 a. 3_____.75 {6. 065 1. ,.25 ..... 43 04 , 307 Pa~.lcer@ 107 --- ....2. 2.50 ]6.065 ]..25 50 ..... 88 ..... 271 5q~7' ~. 5.00 i6.0'~5 1.25 45 1.04 230 (DST 1A~ 1.D~ ,o 1.,.~.'.51.. l,'6.06S 1,.25 ..... 47 ... 102 225 _. 102 __ FLOW CALCULATIONS Flow Temp. Gravlty Compress. Coeffl- __~/h ' P Pressure Factor Factor Factor Rate of ]Plow 1~o. cientV F F F Q MCF/D (24 Hr.) w m psta t g pv ,. ~'553' ["6'9.62 57.7 ,"0"29557' !.309_._.. '... i.od'2~..... 66-i .... _ x._ _ 7.5~3 .... ~'5'~6 ' 64.7,,, 0.9628 , 1.309, 1.0,0,31 721 .~. 7~553 ' 7~-~a0 59.7 0.96~2 1.309 1.0027 75Q !~_____7 · 55 3 79.33 61.7 0.9619 ].309 1.0029 757 PRESSURE CALCULATIONS w p~ p~ _ pa , Cal. w · p - (psla) P" F Q (F Q), (F Q)-" X 1-e'~ P :t C C C W e W W P ,. Static ~andfa(:e pre...~ sure ~as measured b'~ a b. Ottom hole pra~.qnre ....... ~.. . record.e:_" run vrith D.rT No,,: ,,,lA.., The clos,ad-in formation k__ ..... was det~_rmine(! by a pressure vs 10g ~+At/z~t plot. Flowina ~._ pressur~-...;i.P,s) was a].s0,,.measured by the. ~o.wnhc[le rec.~rder. ?f=270,~_7 :ia Absolute Potential 76 3 MCFD [ ~ 1.00 800 ~tcF/~{ 5. 14 ( thee re ti cal ) {measured~ ,, CERTIFICATE: I, the undersignea, state that I am the~ngineer of me Simasko Production Company (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein'are true, ,cor, l~ect~and complete to the best of my knowledge, qL.~ ~.__ ..~_)~~ -~~/~2,/~rf..~.,, <, .: . - ii Signature B. R. Allard INSTRUCTIONS This form is to be used for reporting multi-point back pressure, tests an--gas wells in Alaska, except those on which special orders are applicable. ~/ . The log log paper used for plotting the back pressure curve shall be of at least three inch cycles. NOMENCLATURE (P Q --__Actual rate of flow at end of flo~v period at W.H. working pressure w). MCF/da. @ 14.65 psia and 60oF. P _:72 hour ~vellhead shut-in casing (or tubing) pressure whichever is greater, psia c :_:Static wellhead working pressure as determined at thc end of flow period. (Casing if flowing thru tubing, tubing if flowing thru casing), psia Fl,)wing wellhead pressure (tubing if flowing through tubing, casing if flowing through casing.) psia P -.=Meter pressure, psia Differential meter pressure, inches water Gravity correction factor F :::Flr~w~.ng terc. perature correction factor t F -- Supercompress ability factor pv n --Slope of back pressure curve GL .-=G times average producing length of flow string mix Note: If P cannot be taken because of manner of completion or condition of well, then P w adding the pressure drop due to friction within the flow string to P . t must be calculated by -s F Q and 1-e are factors utilized in calculating the pressure drop due to friction. c Sim uawkie Well No. 2 tO ~ lOi c~ . ×oo ~ lO0 1o 3 4 5 6 7 8 9 2 Flow RO, te Q (MCFD) 3 4 5 6 7 8 9 2 3 4 5 6 7 8 910 Form No. G-1 RE-V. 10~69 ' STATE OF ALASKA OIL AND GAS CONSERVATION COMMIYrEE SUBMIT IN DUPLICATE GAS WELL OPEN FLOW POTENTIAL TEST REPORT Multi. POINT TEST Test Initial [~] Annual O Special Field Reservoir Test Date Wildcat Tyonek Formation, MGS "A" 1-19-79 Operator Lease %Veil .No. Simasko Production Company SIMPCO Moquawkie 2 ¢'ounty t Location C°rapleti°nDate I T°talDepth ~T/PaY ] l'r°ducinglnterval Kenai 785'FSL, 2046'FEL, Sec 1, T11n,R12W, S.M. 2-25-79 6727 880 5880-5900 Producln~ Thru [ ae~'ol~ I Wmhead I CSa Si~e J Wi/Ft. I I.]:). Set(q) TBG. [ CSG. Temperature J' Temperature _x 1..07 'F J N/ATM. .5',' 18 . 4.276. 6~90' MD & TVD (Separator) Length (L) Ralio ,IfF per Bbl. j l,lquid (Apl) 2.5"nom 6.5 2. 875 2. 441 5920 0. 59 20 3457 0 ~_ltQ/le ~_ Pipeline Connection J Type Taps None J Flanqe ~Multtple Completion (Dual or Triple) j Type production from each zone Dual J Dry Gas OBSERVED DAT~ Flow Data Time (Prover) (Choke) Press. Diff. Tubing Casing Flowing No. of Flow (Line) (Orifice) h Press. Press. Temp, Hours Size Size psig w pslg psig °F S~ < ' ? '- .... .................... N/,A~ 0 -- :~. ....... ,. -3 75' 6.065 ~".25 ... 43 "2'.a_.... 307 ~acker @. -- , ~. ~.~.~. 6.065 1.25 50 88 ~ 271 .5327., ...... 1.0~ ~. 5.00 ~ 6. 065 ...... 1.2~' 45 'i04 ...... .2....30 (DST ,!A) .... i. 1.75 { 6.065 1.25 47 102 ' 225 102 , , ., , ,~ , , , ,.. , ,~ , ,,. , .. FLOXV CALCULATIONS Coeffi- , Flow Temp. Gravity Compress. 1~IO. ctent Whw p Pressure Factor Factor Factor Rate of Flow (24 Hr.) m psta F F F Q MCF/D t g pv ,.__ 7.553 I 69.62 " -5":~ .'7 ' 0.9577 1.309 1.0026 ~. 7.553 75.46 64.7 0.9628 !.309 1.0031 ..... 72] .~.~. 7.553. ' 78.'80 59.7... 0.9602 1.3.09 .. 1.0027 750 ~. 7~'553 ~9 3 .~.3" 61.7 j 0.96 19" 1.309 1.0029 75.7 PRESSURE CALCULATION~ w (psla) P" F Q (F Q)' (F q)a X 1-e-s p~ pi _ p~ , Cal. w · p :t e c c ~v c w P w P t c ~._ 'Stati,,c,.,Sa~!'dfa'ce'.Pressrire was meas. ured bv a bo~,nm hol~ Dr~r~ ~. recorder :un wi :h DST No. 1~. The closed,in formation Bro~r~ (P~ ~. yas deter:nined t)y a p~'qssure vs ~g....t+a,t/.at Plot. Flowin~ i' pre~sure [Ps). , ,w~s.. . als~ measrred.. , by the do~nhole recorder. Pf=2.706] 7 n~ Al,solute Potential 763 MCFD n 1.00 (theoretical) 800 ~C~/D 5.14 (measured) ,, CERTIFICATE: I, the undersigned, state that I am m, Enqineer ct me ,Si.ma. sko .Production Company (company), and that I am authorized by said company to make this report; and that this report was pre- dire6tioh' an![';th!~t~the {acts stated therein are true,/q~rrect and complete to pared under my supervision and the best of my knowledge, i i' ..... B.R. Ailard INSTRUCTIONS This form is to be used for reporting multi-point back pressure, tests cn--gas wells in Alaska, except those on which special orders are applicable. 6, ' The log log paper used for plotting the back pressure curve shall be of at least three inch cycles. NOMENCLATURE (P Q ~_Actual rate of flow at end of flow period at W.H. working pressure w). MCF/da. @ 14.65 psta and 60°F. P --_72 hour wellhead shut-in casing (or tubing), pressure whichever is greater, psia c Static wellhead working pressure as determined at the end of flow period. (Casing ii flowing thru tubing, tubing if flowing thru casing), psta Fl)wing wellhead pressure (tubing if flowing through tubing, casing if flowing through casing.) psia pressure, psia .r)i?erentia] meter pressure, inches water --Gravity correction factor F _.FP..v,.'ng temperature correction factor t F = Supercompressability factor pv n _--Slope of back pressure curve GL _-~G times average producing length of flow string mix Note: If P cannot be taken because of manner of completion or condition of well, then P w adding the pressure drop due to friction within the flow string to P , t must be calculated by F Q and 1-e are factors utilized in calculating the pressure drop due to friction. c Sim uawkie Well No. 2: U ~= 10( ~ 7 3 4 5 6 7 8 9 100 Flow Rote , ' ':,"~ Q (MCFD) , , '~ · 3 4 5 6 7 8 910 For,:n No. ,.~v. ,o-s2 OIL AND GAS CONSERVATION COMMII-rEE GAS WELL OPEN FLOW POTENTIAL TEST Test Initial. ~] Annual [~] Special Field j Reservoir Wildcat Tyonek Formation, MGS "A" Operator J Lease Simasko Production Company SI~.~CO Moquawkie ¢'ounty [Location I compl0Uo,, Date [ ~ot.l De~m Kenai 785' FSL, 2046'FEL, Sec 1, TllN, R12W, S.M. 2-25-79 6727' Test Date 1-23-79 Well No. 2 i T/Pay t Producing Interval 5666 5666-5706 Proa,¢i,~Thru j ae~o,, JW~,head JCSO. Si~ {TBG. J CSG. , ,~,, '~"i ,, %Vt/Ft. I.D. x ; s 18 4.276 2.5"nora 6.5 2.875 2.441 5920 0.5771 Pipeline Connection None Multiple Completion (Dual or Triple) Dual JSet (9) 6090' MD & TVD Length (L) Ratio MCF per Bbl. 5713 ~29~ 0 J Type Taps Flange. j Type production from each zone Dry Gas OBSERVED DATA Flow Data Gravil y of I,lquid (Api) Time (Prover) (Choke) Press. Diff. Tubing Casing Flowing No. of Flow (Line) (Orifice) h Press. Press. Temp. Hours Size Size psig ~v psig psig °F s~ - ~ N/A 0 ,. '4..25 6.065 1.25 100 , ]92 ,,. 925 Packer @,. 110 2=___ 2.,0 6/'065 ,.. 1,25 102. 26d 4'90 5387' 105 s. '3 2 ..... !6.065 1.25 95 304 , 275 (DST 2A) 133 ........ ~. 1:7 . , J6. 065, !,- 25 80 352 ,, , 172, 1,31 ___ FLOW CALCULATIONS Coeffi- - Flow Temp. Gravity Compress. :No. cient ---~/h p Pressure Factor Factor Factor Rate of Flow (24 Hr,)VW m psia F F F Q MCF/D t g pv I. 7.553 J 148.4 114-7 0.9551 1.316 1.n~ . 1417 .7.553 175.52 ] 16.7 , 0.9594 1.316 , 1,0~59 1684 .7.553 182.62 109.7 0.9362 1.316 ].00~7 17~7 . . 7.55.3. ,, 182.58 , 94,7 ,, 0.9380 1.$1~. 1.0040 1709 .... PRESSURE CALCULATIONS w P': F Q (F Q)~ p~ p~ p~ , Cal. w (1)sla) (F Q)-" X 1-e-~ -- p :t c c c %v c w w P t c fa('e P , ].S~atic ,~;and reSsur, e was measured b'z a hnF~nm hnl~ nrp~11~ 1'~, run wi%]~ DST }'o. 2A The closed-in for'na~_~n nra~ra ~Pf) was de[erml'~zed by a pre~sure-~ Log ~+~t/~t plo~. Flowing saniiface ~ress~ (Ps) wa:~ also ,measuzed 'by the downhole ;ecorder. Pf=2571.7 ~sia~ , , , ,,,. ,, Lre Absolute Potential n 176 1 I%[CF/D 1.00 (Measured) ........ CERTIFICATE: I, the undersigned, state that I am the, .Enqineer.:~ .me. Siimasko: , , ~.Pr°duc~tion Company. (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true{ _O~ect atad complete to Signature B. R. Al'lard ' INSTRUCTIONS This form is to be used for reporting multi-point back pressure, tests cm gas wells in Alaska, except those on which special orders are applicable. Z/ ' The log log paper used for plotting the back pressure curve shall be of at least three inch cycles. NO ME N CLATURE (P Q --_Actual rate of flow at end of flow period at W.H. working pressure w). MCF/da. @ 14.65 psia and 60oF. P _~72 hour wellhead shut-in casing (or tubing) pressure whichever is greater, psia c P :_.Static wellhead ~vorking pressure as determined at the end of flow period. (Casing if flowing thru tubing, w tubing if flowing thru casing), psta - Fl,)wing wellhead pressure (tubing if flowing through tubing, casing if flowing through casing.) psia P -.=Meter pressure, psia .r)i?erential meter pressure, inches water ---Gravity correction factor F :..Fir)wing temperature correction factor t F _-- Supercompressabiltty factor pv n --Slope of back pressure curve GL _-~G times average producing length of flow string mix Note: If P cannot be taken because of manner of completion or condition of well, then P w w adding the pressure drop due to friction within the flow ~tring to P . t must be calculated by -$ F Q and 1-e are factors utilized in calculating the pressure drop due to friction. c Simpco Moquawkie Well No. 2 2 0 0 ~ 8 '-' 'o 7 I o 5 4 O m 100" xoO 9 7 . 6 4 10 100 3 4 5 6 7 8 9 1000 2 Flow Rate Q (MCFD) 3 4 5 6 7 "8 9 ~00~0, ~ 2 3 4 5 6 7 8 910 Form No. 10-404 SUBMIT IN DUPLICATE REV. 3_1.70 .................... ,~ STATE-~''- ALASKA OIL AND GAS CONSERVATION COMMITTEE .. APl NUMERICALCi)DE " API 50 -283-2 006 MONTHLY REPORT OF DRILLING 6' 'LEA~E DESIGNATION AND SI~RIAL AND WORKOVER OPE TIONS None. 7. ~F ~NmAN.~LOTTEE O. T~.. 8~ OIL ~ GAS ~ E~loratory C~ Tnl~e p~.~ '~ WELL WELL OTHER ~ Simasko Production Company ~T~CN Mns~x~ ~ ~ ~. ,~SS or or~,TO~ ~. w~ ~& ~ ........... P O Box 1515, Anchorage, AK 99510 ' ' 2 4. LOCATIO~ OF WELL 10. FIELD ~ND POOL, OR WI[~T - (As-built S~vey) Wildcat - CONFER, 11. SEC. T. ~. M. (BOSOM ItOLE 795' NSL, 2046 ' WEL oa~E~,v~ FILE: Section 1, TllN, R12W, S.M. Sec 1, TllN, R12W, 78-88 . . 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. FEBRUARY, 1979 2/1-2/2 Drilled out EZ drill and cmt to 2750' Ran Schlumberger CBL from 2000-2733'. ' 2/3 Ran DST #6, 2514-2534' (See attachment). Non-productive zone. Set Halliburton 7" EZ drill retainer @2410' & tested to 1200 psi. Squeezed perfs w/25 sx Class G cmt. Final squeeze pressure 1600 psi. 2/4 Ran DST #7, 2336-2356' (see attachment) . Non-productive zone. 2/5-2/7 Ran DST ~8, 2336-2386' (See attachment). Non-Productive zone. Squeezed perfs 2336-2386' w/50 sx Class G cmt. Resqueezed w/50 sx Class G cmt. Final squeeze pressure 20 00 psi. 2/8 Resqueezed perfs 2336-2386' w/50 sx Class G cmt. Final squeeze pressure 2000 psi. 2/9-2/13 Drilled out all Halliburton EZ drill retainers and cement from 2236 to top of 5" liner @5404. 2/14-2/17 Drilled out Halliburton EZ drill retainer to 5975'. 2/18-2/].9 Made up completion string and set 5" Baker production packer '~5853' w/mule shoe @5920'. Stabbed into lower packer and set upper packer in 7" casing @5352'. Tested to 3000 psi. 2/20-2/23 Ran production test #1 (perf 5880-5900') (see attachment for flow rates) ' 2/24-2/25 Ran production test #2. Opened sliding sleeve at 5713' and comingled production from lower zone (perfs 5880-5900) with upper zone (perfs 5666-5706). (See attachement for flow rates) _9/25 Set blanking plug in S nipple at 5315'. Bled down pressure and set OCT back pressure valves in tubing hanger. Ran 1" heater string to 1103'. Installed Xmas tree and tested to 3000 psi. Well shut in. FINAL REPORT. .... CONFIDEN'TIAL - ' Ti LE reSi ent . DAT~ "' ~'~ , ~. ~. ~.~war~ ' - NOTE-Report on thiJtorm is required lot ~ch calendar mo~th, regardle~ of the ~atus of o~eratiom, and mu~ be filed in ~licate with the oil and gas conservation committ~ by the l~t~ of the succ~ing month,unl~ otherwise direct~j ~ ~? // OIL AND GAS CONSERVATION COMMITTEE s. API NUMERICALCODE API 50-283-200 MONTHLY REPORT OF DRILLING None AND WORKOVER OPE TIONS ,, iFiNDiAN. LO EEORTRiBEN : j. "o,~ ~ ~s ~ Exploratory ~tt .~ Wgtt OIH~R Cook Inlet Re~z~ Z NAME OF OPERATOR 3. ADDR~ OF OPE~TOR 9. WELL NO. P.O. Box 1515, Auchorage, AK 99510 2 ~. LOC~,O~(As_bui~ c°F W~LC Survey) ' ~ ~ C ~ ~ ~ ~.,, ~ .f ~; ~ ~,.~/ IO.~FIELDdcacg~U ~OOL, O~ %'IL~AT 11. SE~ T. ~ bL (BOSOM HOLE 785' NSL, 2046' ~L ~' ~.~'~ ~ ,:~ Section 1, TllN, R12W, S.M. "'. , Sec 1, TllN, ,~ t-. 12. PE~ITNO. ~..,,-~ 78~88 , 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. JANUARy,, !?.79 111-1/5/79 Drilled 6" hole to 6727' !]6~1/8,/,79 Ran Schlumberger logs DLL & BHC from 5739-6'625'. Ran FDC/CNL f-rOm 573'9'-6360 where logging tools stopped. Oleaned out hole to 672? & ran dipmeter (HDT) from 5739-6710. 1/9-1/10/79 Condition hole - prep to run liner. · 1/1i--1/12:/79 Ran 16 its 686.22' of 17.93 lbs/ft N80 5"~liner from 5404 to 6090' ~/'ib0 'sx Class G Neat Cement. Plug back depth 6090. 1/13'1/15/79 Cleaned out cement and ran CBL. -i/16-1/'i'7].79 Picked up tubing and tested rams'& choke manifold to 3000 psi. ![!18~i/~'2-/'79 Ran DST #1 & lA (See attached) perf 5880-5900. Set 5" Hallib'6rton-EZ Drill retainer @5850' and tested to 2000 psi. 1/23-1/24/79 Ran DST #2 & 2A (See attached). Perf 5666-5706' 1/25/7-9-~ Set 5" Halliburton EZ drill retainer @5574' and tested to ~2000 p~i. Mixed 40 sx class G cement and placed 215' cement plug from 5137-5352'.. ' ' · ' ' ~ Ran DST #3 '(see attachment) Perf 4725-4745.. ~ Set 7" Halliburton EZ drill retainer @4640,and tested to 2000 ~z.~ixed 50 sx Class G cement and squeezed perf 4725-4745 below retainer. Final squeeze pressure 3000 psi. 1/28/79 Ran DST #4 '2900-2920 (see attached). Set 7" Halliburton EZ drilI-'~etainer @2790 and tested to 2000 psi. Mixed & squeezed 25 sx Class G cement' through perfs. Final squeeze pressure 3000 psi.. 1/29/79 Ran DST #5 2847-2867 (see attached). Non-productive zone. Set~ '7'~-Halliburton EZ Drill retainer '@2756 & tested to 2000 psi. Squeezed 'perfs w/25 sx class G cmt. Final squeeze pressure 3000 psi.~ 1/30./.79 Perf 2479 w/4 spf for block squeeze. Squeezed w/75 sx Class ~/final squeeze pressure @1800 psi. Perf 2272 w/4 spf for block squeeze.. Squeezed w/75 sx class G cmt. Final squeeze pressure 1000 psi. '1/31/79 WOC. · " ~~,~/~h-"~'~ ........ ~ Alaska Regional 14 I hereby c ~ ~b ~ ,he f tru a SIGNAL -~_~ -- '~/~~/~.. _~~/~ TITLE. ~0 ~ / ' NOT, E--R~,~ ~ this ~orm is required ~or each~ndar month, r~ardl~ of the ~atus of operation, and mu~ be ~iled in dupli~te with the oil amd 9as con~atiom committ~ by the 15th of the succ~ding STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUB.MFT L~ I~bq~LICA-'i~ ~,%ON'¥HLY REPORT OF DRILLING AND WORKOVER OPERATION5 Explorato~,y .. P.,.O, BOx 1515: 'Anchorage: Ag 9'95]0. ¢. LOC.~.~ON OF W~ (As-built Survey) 785' NSL, 20~:6' ~..~EL Sec 1-11N-12W S.H. C FID[NTIAt APl NU.AIERIC,kL CODE .APT 50-2~3-20062 ,. LEASE DES'G~ATION' A. ND SERIAL .NO None IF I."'JDIA)'~. AIX~//EE OR TRIBE NAME Cook .In. le.t Roqign~ .Inc- UNIT.FAFOI OR LEASE ~4AME ,S IHPCO..Moquawki e WEI~ N'O 2 10. FllC'-!.r~ .A-ND POOL. OH WILDCA? Wi ldca t ~. SEC.. T.. R.. :J.. ([~O~rO:,! HOL.!g OBJECTIVE) Sec .1, TllN, R12W, S.M. 12. PI~I~M I T 78-88 i'iE?~RT TOTAL D~-'~-°TI-I AT F.L'~D OF ~%IONTq-{. CHANGES I~ HOLE SIZE. CASING AN~ C~[EN~NG JOES INCLUDING DEP~ SET A~ VOLL~ US~. P~ORATIONS. ~qTS ~%~ ~SUL~. FISHIN'G JO~. JD~'K IN HOLE ~ND SIDE-~ACKED HOLE A%'D .~Y 0~ SiGNIFIC~T ~G~ ~ HO~ ~ITIONS. Dec 1-3, 1978 Installed BOP stack On 9 5/8" csg and tested, to 3000 psi.. .Dec 4-22, 1978' Drilled R½" hole to 5739. Ran logs. Ran 7" csg to 5739 and cemented with 565 sx Class "G" cmt. Dec 26-27, 1978 Clean out cement to 5738 and ran cement bond log (CBL) . Dec 2.8-31, 1978 Drilled 6" hole from 5739 to 6161. '~ 1 he.~eby c~'.i~' that the fo~go~g;~ t~e ~d ~ N~Report on this form is required for each cclendor ~th% regardless of the status of operations, and musl ~ filed In duplicate with the oil and ~os conservation commlffee bythe 15th of the &ucc~ding month.unle~ otherwise directed, Form 10-403 REV. ~- 10~73 Submit "Intentions" 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 proposals.) WELL Exp 1 o r a 2. NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR P.O. Box 1515, Anchorage~ Alaska 4. LOCATION OF WELL At surface 785' NSL, 2046' WEL, Section 1 TllN, R12W, SM 99510 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 327' GR 339'RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 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) Run 5" OD Liner 50-283-20062 { ..... ,-;--, ,, 6. LEASE DESIGNATION AND S~R]A.L-'N~ None- Fee Land~... . , 7. IF INDIAN, ALLOTTEE OR T~IB~ NAME Coot Inlet legio~- Inc-~~ 8. UNIT, FARM OR LEASE NAMe_ ...... SIMPCO Moquawkie 9. WELL NO. 10. FIELD AND POOL, OR WILD~__A.._T!.. Wildcat 11. SEC., T., R., M., (BOTTOM Sec. 1, TllN, R12W, SM 12. PERMIT NO. 78-88 )ort, or Other Data 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 Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Dertlnent ¢let&lls, and give pertinent dates, Including estimated date of starting any proposed work. Intend to run approx, 1200' of 5" OD, 17.93 lbs/ft, N-80 casing from ±5,500' to ± 6,700' TMD and cement with ± 65 sx class "G" cement with 2% CaC12. Will cement liner thru a Float Shoe using conventional Liner Hanger running - setting - cementin$ equipment. Additional cementing will be done as required for zone isolation and for Liner Lap sealing. 7" OD casing is set at 5739', Liner Lap to be ± 239'. Verbal Approval - Plan outlined above was discussed by Mr. Keith Calderwood, Simasko Production Company, and approved by Mr. Lonnie Smith, State of Alaska Oil and Gas Conservation Committee, on Janaury 5, 1979. 16. I hereby certify ;that true and correct w.K. ~ ~efear t TITLE Vice-President .. DATE 1/5/79 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form 20-403 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 · 5, APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIA None - Fee Lands 7. IF INDIAN, ALLOTTEE OR TRIBE Cook Inlet Region, 8. UNIT. FARM OR LEASE NAME (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL L-J OTHER Exploratory 2. NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR P.O. Box 1515~ Anchorage~ Alaska 99510 4. LOCATION OF WELL Atsurface 785' NSL, 2046' WEL, Section 1 TllN, R12W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 327' GR 339' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re STMPCO moq~,mw~i o 9. WELL NO. 2 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE O Sec. 1, T liN, R12W, SM 12. PERMIT NO. 78-88 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) Deepe~ Well PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS 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 ComlHetlon 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. New geological information received after logging well indicates potential for gas sands below current depths of 5739'TMD. Plan to drill 6" hole below 7" OD casing at 5739'TMD to + 6700' in order to fully evaluate gas potential of Tyonek formation in Prospect Area. Verbal approval - Plan outlined above was discussed 'by Mr. Keith Calderwood, Simasko Production Company, and approved by Mr. Harry Kugler, Chief Petroleum Geologist, State of Alaska, on December 29, 1978. 16. I hereby certif~TthatJJ~~g~is true and correct SIGNED ~~>' TITLE V'{ eo-Pro.~'~ don/- DATE I ? /gq/7R - . (This space for state office use) CONDITIONS OF ANY See Instructions On Reverse Side Form 10-403 REV~ 1-10~7'3. Submit "Intentions" 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 proposals.) 1. OW~ILg GAS D OTHER WELL EXp lo ra to r¥ 2. NAME OF OPERATOR Simasko Production Company 3. ADDRESS OF OPERATOR P.O. Box 1515, Anchoraqe, AK 99510 4. LOCATION OF WELL At surface 785' NSL, 2046' WEL, Section 1 TllN, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 32 7 ' GR _q 39 ' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re i_ Is, ^pi NUMERICAL CODE Cook Inlet SIMPCO Moquawkie [0. FIELD AND ~OL, OR WlLDCl ~-~'~: Wi ida at ................... , 11. SEC., T., R., M., (BOTTOM HOLE u~jFCTIVL:r) Sec 1, TllN, R12W, S.M. 12. PERMIT NO. 78-88 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other)~hR~cr~ i~ 'l-_C~i~l Depth (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. Well reached total depth of 5739' on December 21, 1978. Drilling be.¥ond - Permit Depth was necessary in order to fully evaluate gas potential of Tyonek Formation. certify that t~3e f el is t ue and correct S,GNED_/' / ?'/ W. R. St~war~ DATE De.e~mber 22: 1978 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side Simasko Production Company P.O. BOX1515 · ANCHORAGE, ALASKA99510 · (907) 277-5932 · (907) 274-4591 · TELEX26-338 December 21, 19 78 _Re: SIMPCO Moquawkie ~2 Permit ~78-88 ,: API ~.50-28 3-200 62 Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Harry Kugler Chief Petroleum Geologist Gentlemen: Simasko Production Company, as Operator of the captioned exploratory well, has conducted an As-Built Survey of the actual well location and elevation. A copy of the As-Built Survey Plat is enclosed for the completion of your files. Although not indicated on the plat, RKB elevation for this well is 339'. ~S/jm s nc W. R.'~Stewart Vice-President Enclosure: As noted above FILL LINE DRILLING NIPPLE BLO~A _+44" To Rolary Beams KILL LINE [ ) [,. HYDRIL ANNULAR PREVENTER I 0", 5000 I0", 5000 ] Ce~tor Floc)~ SHAFFER DOUBLE- GATE (Blend} (Pipe} ii I0,5000 I0", 5000 DRILLING SPOOL I0", 5000 7" CASING SPOOL 12", 3000 ,,,] 47¥4" CASING BO~L CONDJCT©R 33" 20" ;t I trooi T _+29" )UT PREVENTER · FOR 9 s/~' 1~ 7" PAD LEVEL KILL MANIFOLD Notes· CHOKE / MANIFO D OD CASING ~J LU I-- J 0 n I-- o z ·o z u o o o o ~ T 0 ~ o I, BOP STACK & DRILLING SPOOL SIZE-RATING 9s/s'' Casing- 10"-5000 Actual To Be Determined 7" Casing - )0"-5000 By Rig Equipment Available 2. KiLL MANIFOLD SIZE-RATING Z"-5000 3. CHOKE MANIFOLO ,SIZE-RATING Drilling Spool Outlets ;- 3"-5000 , - 3"' Exlension Spool Tee, Cross a Connected Valves 5000 · Chokes E~ Connected Valves- 2"-5000 Discharge Header- 4"-3000 . 4. HYDRAULIC CONTROL SYSTEM For BOP Stack & Choke Manifold To Include (4) Station Control Manifold On Rig Floor E~ At Remote Locotion~ 80 Gal. Accumulator ~ Reservoir Eoch~ Auxiliary System Charging Metbdd in Addition To Primary Chorging Pump. 5. The Specifications & Requirements Of Section K Of The I ADC Drilling Manual Are Applicable To This BOPE. <~ i-- Z ..J rro bio C3 3~ I-- 0 )- bJ x o_ o i ~ ~j u) o 4" Li ne CHOKE MANIFOLD 3,000 psi Open End Relief 'to Reserve Pit Pipe o o 5,000 psi o [ slm.pco] $imasko Production Company ANCHORAGE DENVER Simpco Moquowkie Well No. 2 BOPE For 95/~'' 8, 7" OD Casing SCALE ~o., DR. DATE ~ Oc, 'Te CK'D. I.~SiMF'CO MOQUAWK E J~LAT. : 6i °04' 05.56" LONG. :15l o t9' 1782:' X = 265,9i8 ~2 No, 2 Tt2N SCALE t" : i MILE: CERTiFiCATE OF SURVEYOR t hereby certify that iarn prc.,per!y registered dnd licensed to pr,.actice land su;'ve~ir:9 ;r: the State of qnd thq? fi-:is p!at represents o !oc,3f~on survey mode by me or under my sdpe. rvision~ (Jnd thL!t ..,j!! dimensions ,and other de'foils ::}re cc, rrect. ,.~-, Ddte Surveyor .... i i~i ir llIlI I I I I II III I Il I ..... I II I ......... ~_____~ L PROPOSE D SIMPCO MOOUAWKIE No.:> Located in Surveyed for SIMASKO PRODUCTION CO. __ I ........... S U f ~8 ~i," 'Ild b Y ......... F. M. LINDSEY 8[ ASSOC. I,.AND.; 8: HYI)ROGRAPHIC 2502 West Northern L~ghfs Boulevmrd Box 4 Anchormge A i i i i i ii i i ii ii .'J . ' ,12 IA" S UR FA C E HOLE BOPE ARRANGEMENT Fill -Up L i n e ----'~ ~ 3 "/." OD Drilling Spa, al ~ _+ 8 Long Starter I DIVERTER 12" - 3000 % GK HYDRIL Kill Line 500 psi WP FO Valve O-Let Pressure Gauge ,,..____..__~Both Lines to Slope From the Diverter Line Toward the Drilling Spool to Prevent Plugging. Notes' I. Hydraulic Control System For Diverter ~ (2) Hydraulic Valves To Include Accumulator I~ Reservoir With 80 Gal. Capacity Each With 1500 psi Operating Pressure. 2. Hydraulic Control Lines MUST Be Connected So That Shut-Off Valves OPEN Before Diverter CLOSES. 3. System Must Include Both Rig Floor & Remote Control Stations. 4. Provisions Must Be Made To Prevent Freezing Of Fluids In Either The Hydraulic Control System Or The Relief Lines. 5. Pressure Gauge With Remote Readout On Rig Floor Must Be Installed To Show Casing Pressure. 6. Cross-Sectional Area Of 8"OD Sch. 40 Line Pipe & 103/4"0D, 40.51bs/ft Casing Are Approximately Same. 7. The 103/4"0D Casing Relief Line I~ Seperator Will Be Connected To The Choke Manifold Used With Subsequent Casing Strings. Cellar Wall ?'.'. · ~T ' ,, -',' OD Relief Lines- (2) Required! ,.'.=,;-' ...... = L~ .,/~:;'.,,,.=,',;:,~',';'/,',','.--"~: Hydraulic Operated Shut-Off Valves 103/4'' OD Casing (Diverter Line) To Reserve Pit ---~ Simasko Production Company ANCHORAGE DENVER Simpco Moquawkie Well No. 2 BOPE For 12~/4'' Surface Hole SCALE '. None DR. , , , DATE' ~ oct.'?e CK'D. LONG. =151 o 19' 14,69" X : 266,070 ~2 ' ELEV.=32~.88'(TOPO(,.MAT,NE,COR.) ! TIZN , I .ES~RV*TJON ~ ~ i ~ ~', SCALE I'= I MILE CERTIFICATE OF SURVEYOR I hereby certify that'lam properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details are correct. Date Surveyor NOTE: Plat changed this date to show as-drilled location. AS- DRILLED SIMPCO MOQUAWKIE No.:> Located in _~_E__I~_~_P_R_D_T_RACT£D SEC~ !, ..__T_JJ N ,RI~.~[,~. ,~.,.~.,,AK Surveyed for SlMASKO PRODUCTION CO. i SurveYed by '- E M. LINDSEY E~ ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4--08i Anchorage Aiaska I I [i i II ~ Torm ~o, P--*4 ~'V. 3- 1-70 STATE O, ,.LASKA OIL AND GAS CONSERVATION COMMITi'EE A/IONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS W~;LL Exploratory 2. NA~ME OF OP]KI%&TOR Simasko Production. Compa'.ny 3 ADDRESS OF OPKt%ATOR P.O. Box 1515, Anchorage, Ali 4. lOCATION OF W~.I.L (A s Built Survey) 785' NSL, 2046' WEL Sec. 1-11N-1ZW SM 99510 Cook Inlet Region, Inc ~- i -5 ENc:- s'. ,~.~'ir.r.~m~ oa L~sk ~.~M~ "1 1 SIMPCO Moquawkie .... l'--5"- { .... ~ ~,, 10. FIE~ &X'D ~L. OR WILDCAT J DRAFT Wildcat ~] s~c FILE: ~ j Sec. 1, TllN, ~lZW- ~.~,-/ 11. PEI~MIT NO. 78 -88 I3.REPORT TOTAL DEPTH AT END OF .~IONTH. CHAR~GES IN HOLE SIZE.CASING AND C~L~iENTING JOBS INCLUDING DEPTH SET A~D VOLLrMES USED, PER~ORATIONS. TESTS A.N'D 1R_ESULTS. FISHING JOB~. JLrNK LN HOLE AND SIDE-T]~ACKED HOLE A~D A3~¥ OTHEt~ SIGNIFICANT CH_A3qGES IN HOI_~ CO~DITIONS. -. NOVEMBER 11 - 25 - 78'- 11 -26-78 11 -27-78 11 -28-78 11-29-78 ll -30-78 Spud well at 1600 hour s. Set 13 3/8" conductor at 92' RliB w/ 100' s~ Class "G"ceme'nt. I1 II II 11 II It 11 Il Drill 12 ¼"hole to 1110'. 11 Il I1 Set 9 5/8" casing at 1105' w/535 sx Class "G" cement.. RECEIVE[) ! '::,: !978 14. I hereby ceFti£y s~o~~~~~~ Alaska Regional Geol. ~A~ December 13, 1978 'oil ond gas conlervot;on commlffee bythe 15~ of the succ~d'ing mon~,unless otherwile directed. Ils|tapco] Simasko Production Company P.O. BOX1515 · ANCHORAGE, ALASKA99510 · (907) 277-5932 · (907) 274-4591 · TELEX26-338 December 4, 1978 Mr~ Ben LeNorman Alaska Division Oil & Gas Conservation 3001 Porcupine Anchorage, AK 99501 Dear Ben' As per our telephone conversation, listed below are B.O.P. Test Data on Our SIMPCO Moquawkie #2, conducted December 2, 1978. Blind Rams Pipe Rams Hydril Chock Manifold 9 5/8 csg Upper & Lower Kellycock Mud lines & Stand Pipe 3000 Psi 3000 Psi 2500 Psi 5000 Psi 1500 Psi 5000 Psi 3000 Psi BR/bd Conservation November 22, 1978 SIMPCO Moquawkie No. 2 Simasko Production Company Permit 78-88 Simasko Production Company Mr. W. R o Stewart P. O. Box 1515 Anchorage, Alaska 99510 Dear Mr. Stewart~ Enid ~p~ed appltcattma for permit to referenced at a location in Section. 1, I2W, Well sarape, core chips and a mud log .are not required, t directions survey is not req~. ~y rt~ers ~n Alaska and thor t~ ~ ~ sub~t ~ AS 16.5~.870 and ~~ns ~u my ~ ~cted by the Habitat ~na~s office, ~nt of ~ ~d Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, ~cle '7 and the reSu~ttons promul~ted ~nder (Title I~, Alaska Adminl~tra~ ChaPter 70) and by the Federal Water P~llutton Control Act. as amended, to commencing operations you may be contacted by a repeeaentative ~ t~ Department of' Environmental Con- 8.erva~. PU~nt to A.S 18.40, ~al ,Hire Under State ~s, the Alaska Depart- merit af ,Labor ia being r,~~ of the ~a.nce of 'this permit ~. d~. To aid us in scheduling field .work, we wo~d appreciate your this office within 48 hours after the well is spudded, We would ~d be notified so 'that a representative of the division may be. ~ent to ~tne~ss t.e~t~ng of blowout preventer equipment before ~rf~e ~g Shoe is drilled. In the event o£ suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, Hoyle H. Hm~rdlton ChMrman b, laska Oil ~ Gas Conservation Committee Enclosure cc: Departn~ent of Fish and Game, ~abitat ~ction w/o encl. Department of Environment~ Conservation w/o encl. Department of Laborl Supervisor, Labor' I,aw Compliance Division w/o encl. CO, NI:iDENllAL :-- Simasko Production Company P.O. BOX1515 · ANCHORAGF:, ALASKA 99510 , (907) 277-5932 * (907) 274-4591 · TELEX26-338 November 13, 1978 Re: SIMPCO Moquawkie ~2 Application for Permit to Drill Division of Oil and_ Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Harry t~ugler Chief Petroleum Geologist Gen tl emen: Simasko Production Company hereby makes application for a Permit to Drill an onshore exploratory well on the west side of Cook Inlet at a location in Section 1, TllN, R12W, S.M. Enclosed in triplicate are the following: (1) Completed and executed Form P-l, "Application for Permit to Drill, Deepen or Plug Back". (2) Supplemental Data Sheet attached to the Permit form providing detailed information on cementing program, anticipated geology, formation evaluation, and drilling fluids. (3) Proposed Location Plat prepared by F. M. Lindsey & Associates. (4) Blowout Preventer Equipment Drawings for both 12~" Surface Hole and for 9 5/8" and 7" OD Casing. (5) Operational Area Drawing upon which existing facilities are indicated together with lease boundaries. Also enclosed is the required fee in the amount of $100.00, payable to State of Alaska, Department of Revenue. This wellsite is located on a fee ].ease which has been entered into by and between Cook Inlet Region, Inc., as Lessor, and Simasko Production Company, as Lessee. The wells ite lease Division of Oil and Gas November 13, 1978 Page Two contains 13,273 acres and is indicated as "Area I" on the Operational Area Drawing. A Surface Use Agreement has been entered into with Tyonek Native CorporatiOn, owner of the surface estate, covering all surface activities including extraction of gravel and construction of drillpads, roads, and airstrips. As indicated on the executed application form, Simasko Production Company maintains a $100,000 Blanket Bond from Safeco Insurance Company of America bearing Bond ~2209296. This bond was submitted to your office on November 21, 1977 and covers any wells to be drilled by Simasko Production Company on this wellsite lease. We are targeting for a November 25, 1978 spud date on this test and will appreciate your early attention to review and approval of this application. Si nc erects, Vi c e-Pre s iden t WRS/jm Enclosures: As noted above STATE OF ALASKA CO SS VA. O APPLICATION FOR PERMIT TO DRILL; DEEP~te~ DRILL J'~ DEEPEN [] PLUG BACK W[I,I, ~'~LL ._ ZONE ZONE 2 NAME OF OPEKATOR Simasko Production Company ~. ADDR~ ~ P.O. Box 1515, Anchorage, AK 99510 4 LOCATION' OF %VELL At surface 900' FSL, 2200' FEL, Sec 1, TllN, R12W', S.Ni. A% proposed prod. zone 900' FSL, 2200' FEL, Sec 1, TllN, Ri2W,-S.M. 13. DISTANCE IN MXLF-S AND DIF[ECT!ON F.IOM NEAREST TOWN OR POST OFFICE* ~.~orox. 6 mi. WNW from Villaqe of TyOnek ' 14. BOND INFOP~MATION: Safeco Insurance Company of America ~z B lanke t s~y ~.~.~o~ ~o. 2209296 I.OCATION TO NEAREST 9 , 500 ' from j~. NO. OF ACR~ IN LEASE 1 15. DISTANCE FROM PROPOSED' ~OP~nTV OR ~ EASE L~X~. ~r. ,^l~ :o ne~e~t d~iZ. ~.it. it ~.y) We s t lease 1 ine 18 DISTANCE FROM PROPOSED LOCATION' TO NEAREST WELL DRILLING. COMPLETED. OR APPLIED FOR. FT. 2450±from Mobil Moquawkie 13,273' I19. PROPOSED DE'PI'I{ 5500' TVD' 5500 ' TMD 21. ELEVATIONS iShow whethcr DF. RT, CF[. etc.~ 350' GR-Estimated from USGS' Tope Sheet* C6N J:-i6 °° tlALN Pee I.,~ds 6. LEASE DF~I/iNA~ION A_NrD 5:-Q{IAL NO. I U No n e 7. IF iNDIAN. ALIX)'I"I'EE ¢)R TR. Ii3E NA."dE Cook Inlet Region, 10. ~IELD AND POOL. Oil %VII.DCAT Wi].dca t , 11. SEC., T.. R...M.. IBOTTOS! t~OLE O~ECTIVE~ T11N R12W Sec 1, , , 12. Kenai Borough ~o.~, $100,000 17. NC). ACRES ASsiGNED TO THi.~ WELL 640 20. HOTARY OR C,-~HLE '10i~L.q Rotary 22. APPROX. DATE %¥O:{K ',.%'11.1. -¢TAI,{T" November 25, 19 78 Inc S. M 23. PROPOSED CASING AND CEMENTING PROGRAM ~7%" ~13 3~8" _,6i~.. K55 80' .... ~10'0' S~ cla's's G W/i% Cae12 3-2%". 9 5/8" 43.5.~ ~.~7_~ ~-~8.0./ lib0~, .. ". ~350 sx class G w/prehy~ gel' S9.5- . ........ flwd .by~-185 sx clb G w/2%C~ ~" 7" 26'][ & 2 g ~ .... _....~ ......... ~ S95 .... 5500' S%age_l~ i 225 Sx dls G .................. Staqe 2: (D~3'i00)~3i5. sx.. C1 :hc12 w/2% CaC12 *Proposed Surface Location Plat endlosed' AszBuilt Survey Plat to be after setting conductor. . . See Attached Supplemental Data Sheet See Attached Operational Area Drawing wi'th lease boundaries Blowout Preventer program (see attached BOPE drawings) + From- 80' to +_ 1100' - 12", 3000 psi, SA Diverter Assembly From-+ 1100' to TD- 10", 5000 psi, SRP~A Assembly w/5000 psi ki 1! line submitted CONDITIONS OF APP1ROVAL0 IF ANY: choke manifold & IN' ABOVE. SPACE D~SCR/BE I~ROPOSED PROGRA/~: If p~l ~ ~ dee~n or plug ~ck. give ~ on present p~u~tve zone and p~ new produ~tivg/zone. If propel is ~ drill or d~n d~e~[o~lly.. Rive ~rt~ent ~ on subsurfa~ ~at~ns ~d meas'~d and ~ue Ve~ical dep~.~ive blo~ut preventer p~gra~. :~., M;~~~~ ...........~oi~ ,~ ~ ..~ co~ ........ = ' ' ~ 7 ....... . _ ~ , ~: ,,,,,C~ ,,,- . ,. ,.,,. _ ,.... , :. , .... ,, (This space for SAMPLES AND CORE CHIPS REQUi/~I:D [] YZS '~t2~L r,-o DIlq~ECTIONAL SUHVKY R~~ ~ y~ ~.NO OT'H]/2{ ~UIP,.~MENTS: ,,.,~m'~:ov'~ ¢,," ~ ' ' *S,e Inhere., On Reven, Side November 22, 1978 ~A'~ ......zz/22/78 Simasko Production Company P.O. BOX1515 · ANCHORAGE, ALASKA99510 · (907) 277-5932 - (907) 274-4591 · TELEX26-338 SUPPLE~4ENTAL DATA SHEET for APPLICATION for PERMIT TO DRILL SIMPCO Moquawkie #2 November 13, 19 78 I. CEMENT ING PROGPJ%M A. The 13 3/8" OD Conductor Casing will be cemented to the surface with-+ 100 sx Class "G" cement with 2% CaC12 B. The 9 5/8" OD casing will be cemented to the surface with + 350 sx Class "G" cement with 4% prehydrated gel followed by + 185 sx Class "G" cement with 2% CaC12. Duplex technique will be utilized. C The 7" OD Casing will be cemented in stages as follows: Stage 1: + 225 sx Class "G" cement with fluid loss and turbulance additives, preceeded by a clay stabilizer mud flush. Stage 2: ('through a DV collar at + 3,100') + 315 sx Class "G" cement with 2% CaC12 preceeded by a clay stabilizer and flush. II. ANTICIPATED GEOLOGY 0' - 300' 300' - 1,100' 1,100 - 5,590'TD Gravel Beluga Formation Tyonek Formation III. FOP~.LAT ION EVALUATION A. Standard mudlogging equipment will be installed prior to drilling below the 13 3/8" OD conductor. B. One or more full size cores will be taken at points to be determined by wellsite geologist. C. Wire!ine logs will be run including dual induction laterolog, sonic log, density log, and dipmeter survey. IV. DRILLING FLUIDS 0 - 1,100 ' 1,000 - 5,500 TD Cel/Ben-Ex Polymer/Brine TI2N TiIN-' CERTIFICATE OF SURVEYOR t hereby certify that I am proper',y registered and licensed fo practice land survey~n~'~ ir', the :!:';:t~}te of A!disk(_,' and that this plat represents a iOCdt~On Survey made by me or under my supervision, and tho* ali dimensions anJ otn~r details ore correct. , - ~,,,. , ,.,-~ .... . ~ Date Surveyor .U I I I II ........ P R 0 P 0 S E D SIMPCO MOQUAWKIE Locoted in Surveyed for SIMASKO PRODUCTION CO. __~l L .... JILL i i II III I ~ - ~ W .~urvey by E M. LINDSEY ~ ASSOC. LAND ~ HYDROGRAPHIC SLJRVEY'~',R¢ 2502 West Northern L~ght~ Bouievord Box 4 Anchorage , ., ,.~ .... _~, 12 S UR FA C E HOLE B 0 P, E A,RRAN G,EM ENT Fill-Up L i n e -----~, I 13 ~/~" OD Drilling Spool - _+ 8' Long 12" - 3000 GK HYDRIL ,M--Kill Line OOpsi WP FO Valve .~j~ Weld- O- Let - Pressure Gauge · . . ! r-, ~ \ v,,,..p, ,,.--Both Lines to Slope From the Diverter Line StarTer i-leaa ....._; ~,,.., ... ~t,iI, ..... , ~ ,._,_,~..,.~, ,;;~...../., ..... , .,.;.:~?..2 ? ~,'~--~, . .. .... ,,, ~,' ' ~ ~ · -.;-:. ~~ l~8 OD Relief L~nes- (2) Requ~red;-,,-,~,: _._..,..;;~;~;";"4~,'L~',,t;.?,;:.'.~,';~' ¢~-'" '~"''"'"/" ¢__~~ Hydraulic Operated ~hu~-Off Valves''' ~( ,03/4'' OD Casing (Diverter Line) To Reserve Pit Notes' 1. Hydraulic Control System For Diverter ~ (2) Hydraulic Valves To Include Accumulator ~ Reservoir With 80 Gal. Capacity Each With 1500psi Operating Pressure. 2. Hydraulic Control Lines MUST Be Connected So That Shut-Off Valves OPEN Before Diverter CLOSES. 3. System, Must Include Both Rig Floor & Remote Control Stations. 4. Provisions Must Be Made To Prevent Freezing Of Fluids In Either The Hydraulic Control System Or The Relief Lines. 5. Pressure Gauge With Remote Readout On Rig Floor Must Be Installed To Show Casing Pressure. 6. Cross-Sectional Area Of 8"OD Sch. 40 Line Pipe & 103/4"0D, 40.51bs/ft Casing Are Approximately Same. 7. The 103/4"0D Casing Relief Line 8~ Seperator Will Be Connected To The Choke Manifold Used With Subsequent Casing Strings. , ,, {sir.nPc;') Simasko Production Company ^NCHOR^OE OENVER Simpco Moquawkie Well No. 2 BOPE For 12~/4'' Surface Hole SCALE: None DR. DATE' 31 Oct.'Te CK'D. -- Ct-H~CK LIST t'OR NE~'J WELL PEFiMITS Ccm}.~onv ~'~ ~.~ Yes No Remarks 1 Is the t~rma t f .e at~ ached ..................... ~.z~.~ 3. Is a reuistered survey plat attached ................ 4. Is well located prq~r distea~ce from. prolmrty line .... ..... 5. Is well located proper distance from other wells .......... 6. Is sufficient undedicate{] acreage available in ~J~is pool ...... /~= Is well to be deviated ....................... 8. Is. operator ~lne ertl,: affected party ., ............... !~~ 9. Can permit }~e approved before ten-day wait ............. ~ I0. Do, es operator have a bond in force ................. 3_]_. Is a c©nservation order needed ' ' ........... ]_2. Is ad:ninistrative a~;prow~! needed ' 13. !s ceno>,~cnor string provided . . . - .......... 4~//z2 14. Is enough ce~.'.rant used to circulate on conductor and ~urface ~__ Will c~ment tie in surface ~nd inteA~ediate or production si:rin~s Will cenent cover all kno~ proxluctive horizons ....... .[7. Will surface casing ~rotect fresh water zones ........... f~_ 18 Will all casino ' ~.= ...... gl~:. -d~,~~-~--- safety in col_].apse, tension & b~nrst 19. ~es BOPE have sufficient Press~-e rating - Test te ~o~o psig 20. Has D}.Ndbi approved P!am ef O~ration ............ Additional Re~ire~nts~ = : Itc Jrt -(1) Fee .~7~_~~ __ (2) Loc..-fff~M C-~:o_-I..og}._, .~ · Fp:.{J.neerJ nc:. BVA ,/ ' - .... ]?J'> ~.~.': Revised 4./'.].,~. ", Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process · but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXl ,. No 'special'effort has been made to chronologically organize this category of information. o. -} v --1 ****************************** ALASKA COMPUTING CENTER ****************************** *----------------------------* *------- SCHLUMBERGER -------* *----------------------------* ****************************** COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO BP EXPLORATION Y-03 PRUDHOE BAY NORTH SLOPE ALASKA 500292041100 98448 7~ 02'2 ~ g~ ý)- R.ECEI\fED * SEP 24 1998 Alaska Oil & Gas Cons. Commission Anchorage ... --J LIS Tape Verification Listing Schlumberger Alaska Computing Center -1 10-SEP-1998 10:45 PAGE: 1 **** REEL HEADER **** SERVICE NAME EDIT DATE 98/09/10 ORIGIN FLIC REEL NAME 98448 CONTINUATION # PREVIOUS REEL COMMENT BP EXPLORATION, Y-03, PRUDHOE BAY, API #50-029-20411-00 **** TAPE HEADER **** SERVICE NAME EDIT DATE 98/09/10 ORIGIN FLIC TAPE NAME 98448 CONTINUATION # 1 PREVIOUS TAPE COMMENT BP EXPLORATION, Y-03, PRUDHOE BAY, API #50-029-20411-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD Y-03 500292041100 BP Exploration SCHLUMBERGER WELL SERVICES 10-SEP-98 98448 C. A. Yon Leng Phong 34 11N 13E 1250 548 80.60 79.60 50.90 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 8.500 ------------- --------- ---------- -------------- 9915.0 7.000 # CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) -1 LIS Tape Verification Listing Schlumberger Alaska Computing Center BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: # --1 10-SEP-1998 10:45 PAGE: 2 ----------EQUIVALENT UNSHIFTED DEPTH---------- BASELINE DEPTH GRCH TDTP -------------- 88888.0 88888.0 88888.0 9542.5 9542.5 9542.5 9523.5 9523.5 9523.5 9517.0 9517.0 9517.0 9511.0 9512.0 9512.0 9506.0 9506.5 9506.5 9486.0 9486.5 9486.5 9459.5 9459.0 9459.0 9459.5 9440.0 9440.0 9440.0 9412.0 9412.0 9412.0 9384.5 9384.5 9384.5 9371.5 9371.0 9371.0 9359.5 9361.5 9361.5 9350.0 9352.0 9352.0 9337.5 9339.0 9336.5 9339.0 9324.5 9325.0 9323.5 9325.0 9277.0 9278.5 9278.5 9259.5 9261.0 9261.0 9244.0 9245.0 9245.0 9231.5 9233.0 9233.0 9217.5 9218.0 9218.0 9199.0 9199.5 9199.5 9193.5 9194.0 9193.0 9194.0 9183.0 9183.0 9182.0 9183.0 9177.5 9178.0 9178.0 9171. 0 9172.0 9172.0 9158.5 9159.0 9159.0 9151.0 9151.0 9151.0 9147.5 9147.0 9147.0 9147.0 9142.0 9142.0 9142.0 9129.5 9130.0 9130.0 9121.5 9122.0 9122.0 9113.0 9113.5 9113.5 9109.5 9110.0 9110.0 9103.0 9103.0 9102.0 9103.0 9082.0 9082.0 9082.0 9076.5 9076.5 9076.5 9065.5 9066.0 ~ --1 -1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9046.0 9019.5 100.0 $ # REMARKS: 10-SEP-1998 10:45 3 PAGE: 9046.0 9021.0 101. 5 100.0 CONTAINED HEREIN IS THE TDTP DATA ACQUIRED ON BP EXPLORATION WELL Y-03 ON 15-MAY-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT THE TDTP BASELINE PASS GRCH TO THE GAMMA RAY PROVIDED BY THE CLIENT (GR. BCS) " AND THE TDTP BASELINE PASS SIGM TO GR. BCS. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ **** FILE HEADER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY LDWG TOOL CODE -------------- GRCH TDTP $ EDIT .001 FLIC 001C01 98/09/10 1024 LO 1 and clipped curves for each pass in separate files. 1 0.5000 START DEPTH STOP DEPTH ----------- ---------- 9551.0 9583.0 8994.0 8994.0 # CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: # BASELINE DEPTH -------------- $ # REMARKS: # LIS FORMAT DATA ----------EQUIVALENT UNSHIFTED DEPTH---------- GRCH TDTP THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE TDTP BASELINE PASS. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ ". -----.J. , LIS Tape Verification Listing Schlumberger Alaska Computing Center ---1 10-SEP-1998 10:45 PAGE: 4 ** DATA FORMAT SPECIFICATION RECORD TYPE SET TYPE - 64EB ** REPR CODE ------------------------------ VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 o 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 o o 88 1 0.5 FT 11 o FT 68 1 o ------------------------------ SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 1 1 1 4 68 0000000000 SIGM TDTP CU 1160737 00 000 00 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1160737 00 000 00 0 1 1 1 4 68 0000000000 SBHF TDTP CU 1160737 00 000 00 0 1 1 1 4 68 0000000000 SBHN TDTP CU 1160737 00 000 00 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1160737 00 000 00 0 1 1 1 4 68 0000000000 SIBH TDTP CU 1160737 00 000 00 0 1 1 1 4 68 0000000000 TRAT TDTP 1160737 00 000 00 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1160737 00 000 00 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1160737 00 000 00 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1160737 00 000 00 0 1 1 1 4 68 0000000000 TCAN TDTP CPS 1160737 00 000 00 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1160737 00 000 00 0 1 1 1 4 68 0000000000 TCND TDTP CPS 1160737 00 000 00 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1160737 00 000 00 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 1160737 00 000 00 0 1 1 1 4 68 0000000000 TSCF TDTP CPS 1160737 00 000 00 0 1 1 1 4 68 0000000000 INND TDTP CPS 1160737 00 000 00 0 1 1 1 4 68 0000000000 INFD TDTP CPS 1160737 00 000 00 0 1 1 1 4 68 0000000000 GRCH TDTP GAPI 1160737 00 000 00 0 1 1 1 4 68 0000000000 TENS TDTP LB 1160737 00 000 00 0 1 1 1 4 68 0000000000 CCL TDTP V 1160737 00 000 00 0 1 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ~ -~} '\ ---1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 5 ** DATA ** DEPT. 9583.000 SIGM. TDTP 12.288 TPHI. TDTP 18.280 SBHF. TDTP 71.026 SBHN. TDTP 82.929 SIGC. TDTP 0.194 SIBH. TDTP 116.679 TRAT. TDTP 1.472 SDSI. TDTP 0.215 BACK. TDTP 198.329 FBAC. TDTP 43.628 TCAN. TDTP 38927.766 TCAF. TDTP 20952.000 TCND. TDTP 25394.785 TCFD. TDTP 10050.098 TSCN. TDTP 7666.144 TSCF. TDTP 4126.131 INND. TDTP 3985.243 INFD. TDTP 580.550 GRCH. TDTP -999.250 TENS. TDTP 1853.000 CCL. TDTP 0.000 DEPT. 8994.000 SIGM. TDTP 42.489 TPHI. TDTP 57.066 SBHF. TDTP 57.486 SBHN. TDTP 57.937 SIGC. TDTP 1.794 SIBH. TDTP 77.621 TRAT. TDTP 1. 578 SDSI. TDTP 1.255 BACK. TDTP 180.805 FBAC. TDTP 40.902 TCAN. TDTP 25591.871 TCAF. TDTP 6964.240 TCND. TDTP 16257.342 TCFD. TDTP 4103.961 TSCN. TDTP 1333.378 TSCF. TDTP 422.500 INND. TDTP 3951.238 INFD. TDTP 409.590 GRCH. TDTP -999.250 TENS. TDTP 1782.000 CCL. TDTP 0.000 ** END OF DATA **** FILE TRAILER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE EDIT .001 FLIC 001C01 98/09/10 1024 LO **** FILE HEADER **** FILE NAME EDIT .002 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY LDWG TOOL CODE 2 and clipped curves for each pass in separate files. 2 0.5000 START DEPTH STOP DEPTH -------------- ----------- ---------- GRCH TDTP 9515.0 9547.0 9010.0 9010.0 , --1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6 $ -1 10-SEP-1998 10:45 PAGE: # CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 # BASELINE DEPTH -------------- 88888.0 9542.0 9522.5 9511.5 9504.5 9487.0 9469.5 9462.0 9459.5 9454.5 9440.5 9427.0 9417.5 9412.0 9405.5 9395.0 9394.0 9384.5 9376.5 9371.5 9359.5 9349.5 9337.0 9336.5 9329.0 9324.0 9323.5 9313 . 5 9310.5 9304.0 9302.0 9301.5 9296.0 9288.0 9287.5 9281. 0 9278.0 9277.5 9260.0 9259.5 9244.0 9243.5 9231.5 9227.5 9222.0 ----------EQUIVALENT UNSHIFTED DEPTH---------- GRCH TDTP 88888.5 88888.5 9542.5 9522.5 9512.0 9505.0 9488.0 9470.5 9463.0 9459.0 9454.5 9440.5 9427.5 9417.5 9412.0 9405.5 9395.5 9394.0 9384.5 9376.5 9371.0 9361.5 9351.5 9352.0 9338.5 9339.0 9330.0 9325.0 9325.0 9315.0 9311.0 9305.5 9304.0 9302.5 9297.5 9289.0 9289.0 9282.0 9279.0 9279.0 9261.5 9261.0 9245.0 9244.5 9233.0 9228.5 9222.5 -1 -----1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9217.5 9217.0 9209.5 9201. 5 9199.0 9193.5 9193.0 9183.0 9182.0 9175.5 9166.0 9165.0 9153.5 9150.5 9148.0 9141.5 9132.0 9131.0 9130.0 9126.0 9123.5 9121.0 9113.0 9111. 5 9103.0 9102.0 9082.0 9081.0 9077.5 9064.5 9044.5 9019.5 100.0 $ # REMARKS: # LIS FORMAT DATA 9218.0 9202.5 9199.5 9194.0 9183.0 9166.0 9153.5 9150.5 9141.5 9133.0 9130.0 9124.0 9113.5 9111.5 9103.0 9082.0 9077.0 9064.0 9044.5 9021.0 101.5 10-SEP-1998 10:45 PAGE: 7 9217.5 9210.5 9194.0 9183.0 9176.0 9167.0 9153.5 9147.5 9131.0 9126.5 9121.5 9113.5 9102.5 9081.0 100.0 THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR BORAX PASS #1. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #1' GRCH TO THE TDTP BASELINE PASS GRCH; AND BORAX PASS #1 SIGM TO THE TDTP BASELINE PASS SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE ------------------------------ VALUE ------------------------------ 1 2 66 66 o o --1 --~ , LIS Tape Verification Listing 10-SEP-1998 10:45 PAGE: 8 Schlumberger Alaska Computing Center ------------------------------ TYPE REPR CODE VALUE ------------------------------ 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ------------------------------ SET TYPE - CHAN * * --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 2 1 1 4 68 0000000000 SIGM TDTP CU 1160737 00 000 00 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1160737 00 000 00 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1160737 00 000 00 0 2 1 1 4 68 0000000000 SBHN TDTP CU 1160737 00 000 00 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1160737 00 000 00 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1160737 00 000 00 0 2 1 1 4 68 0000000000 TRAT TDTP 1160737 00 000 00 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1160737 00 000 00 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1160737 00 000 00 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1160737 00 000 00 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1160737 00 000 00 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1160737 00 000 00 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1160737 00 000 00 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1160737 00 000 00 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 1160737 00 000 00 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1160737 00 000 00 0 2 1 1 4 68 0000000000 INND TDTP CPS 1160737 00 000 00 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1160737 00 000 00 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1160737 00 000 00 0 2 1 1 4 68 0000000000 TENS TDTP LB 1160737 00 000 00 0 2 1 1 4 68 0000000000 CCL TDTP V 1160737 00 000 00 0 2 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 9547.500 SIGM.TDTP 13.306 TPHI. TDTP 23.411 SBHF. TDTP 43.713 SBHN. TDTP 51.012 SIGC. TDTP 1.059 SIBH. TDTP 59.370 TRAT. TDTP 1.679 SDSI. TDTP 0.282 BACK. TDTP 101.516 FBAC. TDTP 21.708 TCAN. TDTP 47022.250 TCAF. TDTP 21336.090 TCND. TDTP 33084.359 TCFD. TDTP 10929.611 TSCN. TDTP 9339.281 ----] --1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 9 TSCF. TDTP 4237.648 INND. TDTP 4134.621 INFD. TDTP 554.818 GRCH. TDTP -999.250 TENS. TDTP 1673.000 CCL. TDTP 0.000 DEPT. 9010.000 SIGM. TDTP 46.534 TPHI. TDTP 43.11 0 SBHF. TDTP 83.223 SBHN. TDTP 97.983 SIGC. TDTP 0.533 SIBH. TDTP 168.466 TRAT. TDTP 1.213 SDSI. TDTP 1.838 BACK. TDTP 150.764 FBAC. TDTP 31.150 TCAN. TDTP 8295.744 TCAF. TDTP 2611.259 TCND. TDTP 7875.799 TCFD. TDTP 2073.621 TSCN. TDTP 371.329 TSCF. TDTP 136.947 INND. TDTP 3926.772 INFD. TDTP 456.351 GRCH. TDTP -999.250 TENS. TDTP 1551.000 CCL. TDTP 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE EDIT .002 FLIC 001C01 98/09/10 1024 LO **** FILE HEADER **** FILE NAME EDIT .003 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY LDWG TOOL CODE 3 and clipped curves for each pass in separate files. 3 0.5000 START DEPTH STOP DEPTH -------------- ----------- ---------- GRCH TDTP $ 9515.0 9547.0 9012.0 9012.0 # CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 l --1 LIS Tape Verification Listing Schlumberger Alaska Computing Center -----) 10-SEP-1998 10:45 PAGE: 10 # ----------EQUIVALENT UNSHIFTED DEPTH---------- BASELINE DEPTH GRCH TDTP -------------- 88888.0 88888.0 88888.5 9541.5 9542.0 9522.5 9522.5 9512.0 9512.0 9498.0 9498.5 9489.0 9489.0 9487.0 9488.0 9470.0 9471.0 9459.5 9459.0 9459.0 9459.5 9454.5 9454.5 9441.0 9440.5 9427.5 9428.0 9417.5 9417.5 9400.0 9399.5 9397.5 9397.0 9394.0 9394.0 9387.5 9387.5 9384.5 9384.5 9375.0 9375.0 9371.5 9371.0 9359.5 9361.5 9356.5 9358.5 9349.5 9351.5 9352.0 9337.5 9339.0 9337.0 9339.0 9324.5 9325.5 9324.0 9325.0 9311.5 9313.0 9310.5 9311.5 9302.5 9304.0 9296.5 9297.5 9287.5 9289.0 9281.0 9282.0 9277.5 9279.0 9279.0 9260.0 9261.5 9259.5 9261.0 9251.5 9253.0 9248.5 9250.0 9244.0 9245.0 9243.5 9244.5 9236.5 9238.0 9227.5 9228.0 9217.0 9218.0 9217.5 9212.5 9214.0 9204.0 9205.0 9199.0 9199.5 9193.5 9194.0 9194.0 9183.0 9183.0 9182.0 9183.0 9177.5 9178.0 ~.,.. --i LIS Tape Verification Listing Schlumberger Alaska Computing Center 9175.5 9169.5 9165.5 9153.5 9153.0 9150.5 9141.5 9131.0 9130.0 9124.0 9121.5 9113.0 9109.5 9103.0 9102.0 9082.0 9081.0 9079.0 9076.5 9071 . 5 9049.0 9044.5 9032.5 100.0 $ # REMARKS: # LIS FORMAT DATA 9176.0 9170.5 9166.0 9167.0 9153.5 9153.5 9150.5 9150.5 9141.5 9131.0 9130.0 9124.5 9122.0 9113.5 9113.5 9109.5 9103.0 9102.5 9082.0 9081.0 9079.5 9076.0 9071.0 9048.5 9044.0 9031. 5 99.0 99.5 --1 10-SEP-1998 10:45 PAGE: 11 ** DATA FORMAT SPECIFICATION RECORD THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR BORAX PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #2 GRCH TO THE TDTP BASELINE PASS GRCH¡ AND BORAX PASS #2 SIGM TO THE TDTP BASELINE PASS SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 66 66 73 66 66 73 65 68 65 66 68 o o 88 1 0.5 FT 11 ) ----1 --1 LIS Tape Verification Listing 10-SEP-1998 10:45 PAGE: 12 Schlumberger Alaska Computing Center ------------------------------ TYPE REPR CODE VALUE ------------------------------ 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ------------------------------ ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 3 1 1 4 68 0000000000 SIGM TDTP CU 1160737 00 000 00 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1160737 00 000 00 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1160737 00 000 00 0 3 1 1 4 68 0000000000 SBHN TDTP CU 1160737 00 000 00 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1160737 00 000 00 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1160737 00 000 00 0 3 1 1 4 68 0000000000 TRAT TDTP 1160737 00 000 00 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1160737 00 000 00 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1160737 00 000 00 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1160737 00 000 00 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1160737 00 000 00 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1160737 00 000 00 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1160737 00 000 00 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1160737 00 000 00 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 1160737 00 000 00 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1160737 00 000 00 0 3 1 1 4 68 0000000000 INND TDTP CPS 1160737 00 000 00 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1160737 00 000 00 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1160737 00 000 00 0 3 1 1 4 68 0000000000 TENS TDTP LB 1160737 00 000 00 0 3 1 1 4 68 0000000000 CCL TDTP V 1160737 00 000 00 0 3 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA DEPT. 9547.500 SIGM. TDTP 13.220 TPHI. TDTP 22.772 SBHF. TDTP 43.381 SBHN. TDTP 55.178 SIGC. TDTP 1.120 SIBH. TDTP 67.394 TRAT. TDTP 1.637 SDSI. TDTP 0.289 BACK. TDTP 180.790 FBAC. TDTP 35.097 TCAN. TDTP 46371.852 TCAF. TDTP 21572.715 TCND. TDTP 31781.379 TCFD. TDTP 10870.045 TSCN. TDTP 9045.258 TSCF. TDTP 4207.958 INND. TDTP 3850.923 INFD. TDTP 500.981 GRCH. TDTP -999.250 TENS. TDTP 1347.000 CCL. TDTP 0.000 DEPT. 9011. 000 SIGM. TDTP -999.250 TPHI. TDTP -999.250 SBHF. TDTP -999.250 SBHN. TDTP -999.250 SIGC. TDTP -999.250 SIBH. TDTP -999.250 TRAT. TDTP -999.250 SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP -999.250 TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP -999.250 TSCN. TDTP -999.250 TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP 100.594 TENS. TDTP -999.250 CCL. TDTP -999.250 --1 -1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13 ** END OF DATA ** 10-SEP-1998 10:45 PAGE: **** FILE TRAILER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE EDIT .003 FLIC 001C01 98/09/10 1024 LO **** FILE HEADER **** FILE NAME EDIT . 004 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY LDWG TOOL CODE -------------- GRCH TDTP $ 4 and clipped curves for each pass in separate files. 4 0.5000 START DEPTH STOP DEPTH ----------- ---------- 9523.0 9555.0 9014.0 9014.0 # CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 # BASELINE DEPTH -------------- 88888.0 9542.0 9527.5 9523.0 9518.0 ----------EQUIVALENT UNSHIFTED DEPTH---------- GRCH TDTP 88888.0 88888.0 9542.0 9527.5 9522.5 9518.0 '1 -4 LIS Tape Verification Listing Schlumberger Alaska Computing Center 9512.0 9512.0 9504.5 9505.0 9487.0 9488.0 9470.0 9470.5 9459.5 9459.0 9459.0 9459.5 9454.5 9454.5 9447.0 9448.0 9440.5 9441.0 9435.0 9434.5 9427.5 9427.5 9417.5 9417.5 9412.0 9412.0 9399.0 9399.5 9397.0 9397.0 9384.0 9384.5 9379.5 9379.5 9371.5 9371.0 9359.5 9361.5 9361. 0 9350.0 9352.0 9349.5 9352.0 9337.0 9339.0 9336.5 9339.0 9324.0 9325.5 9323.5 9325.0 9310.0 9311.5 9303.5 9305.5 9305.0 9301.0 9302.5 9295.5 9297.0 9287.5 9289.0 9281.0 9282.0 9279.0 9280.5 9277.5 9279.0 9260.0 9261.5 9259.0 9261.0 9249.0 9250.0 9243.5 9245.0 9243.0 9244.5 9236.5 9238.0 9227.0 9228.0 9217.0 9218.0 9218.0 9193.0 9194.0 9194.0 9190.0 9190.0 9182.5 9183.0 9181.5 9183.0 9175.0 9176.0 9165.0 9166.0 9154.0 9154.5 9153.0 9153.5 9147.5 9147.5 9141.0 9141.5 9136.5 9136.5 9130.5 9131.0 9129.5 9130.5 9125.5 9126.5 --1 10-SEP-1998 10:45 PAGE: 14 "- -J LIS Tape Verification Listing Schlumberger Alaska Computing Center 9121.5 9120.5 9112.5 9102.0 9101.5 9081.5 9080.5 9077 .0 9065.0 9047.5 9031.5 9019.0 100.0 $ # REMARKS: # LIS FORMAT DATA 9122.5 9121. 5 9113.5 9102.5 9102.5 9082.0 9081.0 9077.0 9065.0 9048.0 9031.5 100.0 9019.0 100.0 -----) 10-SEP-1998 10:45 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR BORAX PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #3 GRCH TO THE TDTP BASELINE PASS GRCH¡ AND BORAX PASS #3 SIGM TO THE TDTP BASELINE PASS SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 o 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 o o 88 1 0.5 FT 11 o FT 68 1 1 ------------------------------ --J -----) LIS Tape Verification Listing 10-SEP-1998 10:45 PAGE: 16 Schlumberger Alaska Computing Center ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 4 1 1 4 68 0000000000 SIGM TDTP CU 1160737 00 000 00 0 4 1 1 4 68 0000000000 TPHI TDTP PU-S 1160737 00 000 00 0 4 1 1 4 68 0000000000 SBHF TDTP CU 1160737 00 000 00 0 4 1 1 4 68 0000000000 SBHN TDTP CU 1160737 00 000 00 0 4 1 1 4 68 0000000000 SIGC TDTP CU 1160737 00 000 00 0 4 1 1 4 68 0000000000 SIBH TDTP CU 1160737 00 000 00 0 4 1 1 4 68 0000000000 TRAT TDTP 1160737 00 000 00 0 4 1 1 4 68 0000000000 SDSI TDTP CU 1160737 00 000 00 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1160737 00 000 00 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1160737 00 000 00 0 4 1 1 4 68 0000000000 TCAN TDTP CPS 1160737 00 000 00 0 4 1 1 4 68 0000000000 TCAF TDTP CPS 1160737 00 000 00 0 4 1 1 4 68 0000000000 TCND TDTP CPS 1160737 00 000 00 0 4 1 1 4 68 0000000000 TCFD TDTP CPS 1160737 00 000 00 0 4 1 1 4 68 0000000000 TSCN TDTP CPS 1160737 00 000 00 0 4 1 1 4 68 0000000000 TSCF TDTP CPS 1160737 00 000 00 0 4 1 1 4 68 0000000000 INND TDTP CPS 1160737 00 000 00 0 4 1 1 4 68 0000000000 INFD TDTP CPS 1160737 00 000 00 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1160737 00 000 00 0 4 1 1 4 68 0000000000 TENS TDTP LB 1160737 00 000 00 0 4 1 1 4 68 0000000000 CCL TDTP V 1160737 00 000 00 0 4 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA DEPT. 9553.000 SIGM. TDTP 13.374 TPHI. TDTP 17.372 SBHF. TDTP 44.187 SBHN. TDTP 56.512 SIGC. TDTP 1.002 SIBH. TDTP 67.994 TRAT. TDTP 1.448 SDSI. TDTP 0.303 BACK. TDTP 216.262 FBAC. TDTP 48.612 TCAN. TDTP 42041.141 TCAF. TDTP 22322.023 TCND. TDTP 32073.660 TCFD. TDTP 11595.609 TSCN. TDTP 8460.111 TSCF. TDTP 4491.952 INND. TDTP 4121.678 INFD. TDTP 530.176 GRCH. TDTP -999.250 TENS. TDTP 1562.000 CCL. TDTP 0.000 DEPT. 9014.000 SIGM. TDTP 47.539 TPHI. TDTP 47.222 SBHF. TDTP 65.355 SBHN. TDTP 75.213 SIGC. TDTP 3.162 SIBH. TDTP 116.812 TRAT. TDTP 1.269 SDSI. TDTP 1.870 BACK. TDTP 209.954 FBAC. TDTP 41.841 TCAN. TDTP 13472.814 TCAF. TDTP 3726.741 TCND. TDTP 12182.502 TCFD. TDTP 2978.831 TSCN. TDTP 557.182 TSCF. TDTP 173.684 INND. TDTP 3842.476 INFD. TDTP 448.436 GRCH. TDTP 101.402 TENS. TDTP 1603.000 CCL. TDTP 0.000 ** END OF DATA ** ---1 -1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17 10-SEP-1998 10:45 PAGE: **** FILE TRAILER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE EDIT . 004 FLIC 001C01 98/09/10 1024 LO **** FILE HEADER **** FILE NAME EDIT .005 SERVICE FLIC VERSION 001COl DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY LDWG TOOL CODE -------------- GRCH TDTP $ 5 and clipped curves for each pass in separate files. 5 0.5000 START DEPTH STOP DEPTH ----------- ---------- 9505.0 9537.0 9014.0 9014.0 # CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 # BASELINE DEPTH -------------- 88888.0 9523.0 9519.5 9505.0 9498.0 9489.5 9487.5 9478.0 9470.0 9460.0 9459.5 ----------EQUIVALENT UNSHIFTED DEPTH---------- GRCH TDTP 88887.5 88887.5 9522.5 9519.0 9505.5 9498.5 9489.0 9488.0 9477.0 9471.0 9459.0 9459.5 --) LIS Tape Verification Listing Schlumberger Alaska Computing Center 9454.5 9455.0 9440.5 9440.5 9435.0 9434.5 9427.5 9428.0 9418.0 9417.5 9412.5 9412.0 9408.5 9408.0 9397.0 9397.0 9387.0 9387.5 9384.5 9384.5 9381.0 9381.5 9379.5 9379.5 9377.0 9376.5 9371.0 9371.0 9370.5 9371. 5 9359.5 9361.0 9361.0 9350.0 9352.0 9352.0 9337.5 9339.0 9337.0 9339.0 9329.5 9330.0 9324.0 9325.5 9325.0 9311.0 9313 .0 9311.5 9304.0 9305.5 9296.0 9297.0 9288.5 9289.0 9288.0 9289.0 9279.0 9280.5 9278.0 9279.0 9268.0 9269.0 9260.5 9261.5 9259.5 9261.0 9244.0 9245.0 9244.5 9236.5 9237. 5 9227.5 9228.0 9227.0 9228.5 9220.0 9220.0 9217.5 9218.0 9216.0 9216. 0 9210.0 9210.5 9199.5 9200.0 9194.0 9194.0 9193.5 9194.0 9183.5 9183.0 9182.5 9183.0 9175.5 9176.0 9171.5 9172.0 9165.5 9166.0 9161.0 9161.5 9159.0 9159.0 9150.5 9150.5 9150.0 9141. 5 9141.5 9130.5 9131.0 9130.0 9130.0 9125.5 9126.5 9121.5 9122.0 -1 10-SEP-1998 10:45 PAGE: 18 J LIS Tape Verification Listing Schlumberger Alaska Computing Center 9113.5 9103.0 9102.0 9082.0 9079.5 9076.5 9051.5 9044.0 100.0 $ # REMARKS: 9113.5 9114.0 9103.0 9102.5 9082.0 9079.5 9076.0 9052.5 9044.0 100.0 101.0 ----J 10-SEP-1998 10:45 PAGE: 19 THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR BORAX PASS #4. THE DEPTH SHIFTS SHOWN ABOVE REFLECT BORAX PASS #4 GRCH TO THE TDTP BASELINE PASS GRCH,. AND BORAX PASS #4 SIGM TO THE TDTP BASELINE PASS SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** TYPE ** SET TYPE - 64EB ** REPR CODE ------------------------------ VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 o 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 o o 88 1 0.5 FT 11 o FT 68 1 1 ------------------------------ SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM SIZE REPR CODE PROCESS (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 5 1 1 4 68 0000000000 SIGM TDTP CU 1160737 00 000 00 0 5 1 1 4 68 0000000000 TPHI TDTP PU-S 1160737 00 000 00 0 5 1 1 4 68 0000000000 -) ---1 LIS Tape Verification Listing 10-SEP-1998 10:45 PAGE: 20 Schlumberger Alaska Computing Center --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- SBHF TDTP CU 1160737 00 000 00 0 5 1 1 4 68 0000000000 SBHN TDTP CU 1160737 00 000 00 0 5 1 1 4 68 0000000000 SIGC TDTP CU 1160737 00 000 00 0 5 1 1 4 68 0000000000 SIBH TDTP CU 1160737 00 000 00 0 5 1 1 4 68 0000000000 TRAT TDTP 1160737 00 000 00 0 5 1 1 4 68 0000000000 SDSI TDTP CU 1160737 00 000 00 0 5 1 1 4 68 0000000000 BACK TDTP CPS 1160737 00 000 00 0 5 1 1 4 68 0000000000 FBAC TDTP CPS 1160737 00 000 00 0 5 1 1 4 68 0000000000 TCAN TDTP CPS 1160737 00 000 00 0 5 1 1 4 68 0000000000 TCAF TDTP CPS 1160737 00 000 00 0 5 1 1 4 68 0000000000 TCND TDTP CPS 1160737 00 000 00 0 5 1 1 4 68 0000000000 TCFD TDTP CPS 1160737 00 000 00 0 5 1 1 4 68 0000000000 TSCN TDTP CPS 1160737 00 000 00 0 5 1 1 4 68 0000000000 TSCF TDTP CPS 1160737 00 000 00 0 5 1 1 4 68 0000000000 INND TDTP CPS 1160737 00 000 00 0 5 1 1 4 68 0000000000 INFD TDTP CPS 1160737 00 000 00 0 5 1 1 4 68 0000000000 GRCH TDTP GAPI 1160737 00 000 00 0 5 1 1 4 68 0000000000 TENS TDTP LB 1160737 00 000 00 0 5 1 1 4 68 0000000000 CCL TDTP V 1160737 00 000 00 0 5 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- DATA ** DEPT. 9536.500 SIGM. TDTP 12.520 TPHI.TDTP 24.125 SBHF. TDTP 32.602 SBHN. TDTP 44.236 SIGC. TDTP 1.126 SIBH. TDTP 46.043 TRAT. TDTP 1.785 SDSI. TDTP 0.268 BACK. TDTP 184.364 FBAC. TDTP 39.726 TCAN. TDTP 55505.516 TCAF. TDTP 24017.027 TCND. TDTP 35827.305 TCFD. TDTP 11690.479 TSCN. TDTP 11297.549 TSCF. TDTP 4888.407 INND. TDTP 4102.223 INFD. TDTP 524.185 GRCH. TDTP -999.250 TENS. TDTP 1608.000 CCL. TDTP 0.000 END OF DATA **** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER **** EDIT . 005 FLIC 001C01 98/09/10 1024 LO -, --~ LIS Tape Verification Listing Schlumberger Alaska Computing Center 21 10-SEP-1998 10:45 PAGE: **** FILE HEADER **** FILE NAME EDIT .006 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER: EDITED CURVES Depth shifted PASS NUMBER: DEPTH INCREMENT: # FILE SUMMARY LDWG TOOL CODE -------------- GRCH TDTP $ 6 and clipped curves for each pass in separate files. 6 0.5000 START DEPTH STOP DEPTH ----------- ---------- 9521.0 9553.0 9014.0 9014.0 # CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 # BASELINE DEPTH -------------- 88888.0 9541.5 9522.5 9519.5 9519.0 9517. 0 9513.5 9506.0 9498.5 9487.0 9480.0 9469.5 9459.5 9459.0 9454.0 9441.0 9439.5 9428.5 9417.0 9412.0 9405.5 ----------EQUIVALENT UNSHIFTED DEPTH---------- GRCH TDTP 88887.5 88888.5 9542.0 9522.5 9519.0 9518.5 9517.5 9514.5 9507.0 9499.0 9488.0 9481.0 9470.5 9459.0 9459.5 9454.5 9440.5 9440.0 9428.5 9417. 0 9412.0 9406.0 -----1 --1 LIS Tape Verification Listing 10-SEP-1998 10:45 Schlumberger Alaska Computing Center 9397.5 9397.5 9395.0 9395.5 9387.5 9387.5 9384.0 9384.5 9379.0 9379.0 9374.5 9374.0 9371. 5 9371.0 9370.5 9371. 0 9367.0 9367.5 9359.5 9361. 5 9361.0 9358.0 9360.0 9356.5 9358.5 9356.0 9358.5 9349.5 9351.5 9352.0 9337.0 9338.5 9336.5 9339.0 9324.0 9325.0 9323.5 9325.0 9311.0 9312.5 9304.0 9305.5 9302.0 9303.0 9296.5 9297.5 9287.5 9289.0 9280.5 9282.0 9279.5 9280.5 9277.5 9279.0 9270.0 9271.0 9260.0 9261. 5 9258.5 9260.5 9248.5 9250.0 9244.0 9245.0 9243.5 9244.5 9236.5 9238.0 9232.0 9233.5 9231.0 9233.0 9224.0 9225.0 9217.0 9218.0 9216.5 9217.5 9198.5 9199.5 9193.5 9194.0 9193.0 9194.0 9189.5 9190.5 9182.5 9183. 0 9182.0 9183.0 91 77 .0 9178.0 9175.5 9176.5 9171.5 9172.0 9165.5 9166. 0 9167. 0 9153.5 9153.5 9150.5 9150.5 9147.5 9147.5 9146.5 9146.5 9141.5 9142.0 9137.0 9137.0 9137.0 9129.5 9130.5 PAGE: 22 LIS Tape Verification Listing Schlumberger Alaska Computing Center -l 9125.5 9112.5 9109.0 9102.5 9101.5 9085.5 9082.0 9079.0 9076.0 9074.0 9065.5 9058.5 9054.0 9022.5 100.0 $ # REMARKS: # LIS FORMAT DATA 9126.5 9113.5 9109.5 9102.5 9102.5 9084.5 9082.0 9079.0 9076.5 9073.5 9066.5 9058.5 9054.0 9023.5 101.0 ----) 10-SEP-1998 10:45 PAGE: 23 99.5 THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR THE FLUSHED PASS. THE DEPTH SHIFTS SHOWN ABOVE REFLECT THE FLUSHED PASS GRCH TO THE TDTP BASELINE PASS GRCH/ AND THE FLUSHED PASS SIGM TO THE TDTP BASELINE PASS SIGM. ALL OTHER TDTP CURVES WERE CARRIED WITH THE SIGM SHIFT. $ ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE ------------------------------ 1 66 2 66 3 73 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 ------------------------------ VALUE o o 88 1 0.5 FT 11 o FT 68 1 1 -) --ì LIS Tape Verification Listing 10-SEP-1998 10:45 PAGE: 24 Schlumberger Alaska Computing Center ** SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 6 1 1 4 68 0000000000 SIGM TDTP CU 1160737 00 000 00 0 6 1 1 4 68 0000000000 TPHI TDTP PU-S 1160737 00 000 00 0 6 1 1 4 68 0000000000 SBHF TDTP CU 1160737 00 000 00 0 6 1 1 4 68 0000000000 SBHN TDTP CU 1160737 00 000 00 0 6 1 1 4 68 0000000000 SIGC TDTP CU 1160737 00 000 00 0 6 1 1 4 68 0000000000 SIBH TDTP CU 1160737 00 000 00 0 6 1 1 4 68 0000000000 TRAT TDTP 1160737 00 000 00 0 6 1 1 4 68 0000000000 SDSI TDTP CU 1160737 00 000 00 0 6 1 1 4 68 0000000000 BACK TDTP CPS 1160737 00 000 00 0 6 1 1 4 68 0000000000 FBAC TDTP CPS 1160737 00 000 00 0 6 1 1 4 68 0000000000 TCAN TDTP CPS 1160737 00 000 00 0 6 1 1 4 68 0000000000 TCAF TDTP CPS 1160737 00 000 00 0 6 1 1 4 68 0000000000 TCND TDTP CPS 1160737 00 000 00 0 6 1 1 4 68 0000000000 TCFD TDTP CPS 1160737 00 000 00 0 6 1 1 4 68 0000000000 TSCN TDTP CPS 1160737 00 000 00 0 6 1 1 4 68 0000000000 TSCF TDTP CPS 1160737 00 000 00 0 6 1 1 4 68 0000000000 INND TDTP CPS 1160737 00 000 00 0 6 1 1 4 68 0000000000 INFD TDTP CPS 1160737 00 000 00 0 6 1 1 4 68 0000000000 GRCH TDTP GAPI 1160737 00 000 00 0 6 1 1 4 68 0000000000 TENS TDTP LB 1160737 00 000 00 0 6 1 1 4 68 0000000000 CCL TDTP V 1160737 00 000 00 0 6 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 9553.500 SIGM. TDTP 13.800 TPHI. TDTP 19.825 SBHF. TDTP 52.461 SBHN. TDTP 58.684 SIGC. TDTP 0.719 SIBH. TDTP 72.450 TRAT. TDTP 1. 509 SDSI.TDTP 0.341 BACK. TDTP 248.926 FBAC. TDTP 65.577 TCAN. TDTP 43728.109 TCAF. TDTP 22155.465 TCND. TDTP 31151.668 TCFD. TDTP 11466.773 TSCN. TDTP 8620.168 TSCF. TDTP 4367.530 INND. TDTP 3958.889 INFD. TDTP 524.633 GRCH. TDTP -999.250 TENS.TDTP 1624.000 CCL. TDTP 0.000 DEPT. 9013.500 SIGM. TDTP 47.105 TPHI. TDTP 74.904 SBHF. TDTP 50.716 SBHN. TDTP 58.735 SIGC. TDTP 0.000 SIBH. TDTP 79.432 TRAT. TDTP 1.848 SDSI. TDTP 1.404 BACK. TDTP 216.955 FBAC. TDTP 48.423 TCAN. TDTP 26665.270 TCAF. TDTP 6340.175 TCND. TDTP 17225.586 TCFD. TDTP 3901.488 TSCN. TDTP 1367.740 TSCF. TDTP 335.673 INND. TDTP 3819.765 INFD. TDTP 447.838 GRCH. TDTP -999.250 TENS.TDTP 1603.000 CCL. TDTP 0.000 END OF DATA · ~ -----, --) LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 25 **** FILE TRAILER **** FILE NAME EDIT .006 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE **** FILE HEADER **** FILE NAME EDIT. 007 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER: 7 A VERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT O. 5000 # PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS -------------- ------------ TDTP $ REMARKS: I, THE ARITHMETIC AVERAGE IS EQUAL TO THE BASELINE PASS SINCE ONLY ONE BASELINE PASS WAS LOGGED. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 2 3 4 5 6 66 66 73 66 66 73 o o 80 1 ---) ----1 LIS Tape Verification Listing 10-SEP-1998 10:45 PAGE: 26 Schlumberger Alaska Computing Center ------------------------------ TYPE REPR CODE VALUE ------------------------------ 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ------------------------------ ** SET TYPE - CHAN * * --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 7 1 1 4 68 0000000000 SIGM PNAV CU 1160737 00 000 00 0 7 1 1 4 68 0000000000 TPHI PNA V PU-S 1160737 00 000 00 0 7 1 1 4 68 0000000000 SBHF PNA V CU 1160737 00 000 00 0 7 1 1 4 68 0000000000 SBHN PNA V CU 1160737 00 000 00 0 7 1 1 4 68 0000000000 SIGC PNAV CU 1160737 00 000 00 0 7 1 1 4 68 0000000000 SIBH PNAV CU 1160737 00 000 00 0 7 1 1 4 68 0000000000 TRAT PNAV 1160737 00 000 00 0 7 1 1 4 68 0000000000 SDSI PNAV CU 1160737 00 000 00 0 7 1 1 4 68 0000000000 BACK TDTP CPS 1160737 00 000 00 0 7 1 1 4 68 0000000000 FBAC TDTP CPS 1160737 00 000 00 0 7 1 1 4 68 0000000000 TCAN PNAV CPS 1160737 00 000 00 0 7 1 1 4 68 0000000000 TCAF PNA V CPS 1160737 00 000 00 0 7 1 1 4 68 0000000000 TCND PNA V CPS 1160737 00 000 00 0 7 1 1 4 68 0000000000 TCFD PNA V CPS 1160737 00 000 00 0 7 1 1 4 68 0000000000 TSCN PNAV CPS 1160737 00 000 00 0 7 1 1 4 68 0000000000 TSCF PNA V CPS 1160737 00 000 00 0 7 1 1 4 68 0000000000 INND PNA V CPS 1160737 00 000 00 0 7 1 1 4 68 0000000000 INFD PNA V CPS 1160737 00 000 00 0 7 1 1 4 68 0000000000 GRCH TDTP GAPI 1160737 00 000 00 0 7 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 9591.000 SIGM. PNAV -999.250 TPHI. PNAV -999.250 SBHF. PNA V -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH.PNAV -999.250 TRAT.PNAV -999.250 SDSI. PNAV -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. PNA V -999.250 TCAF. PNAV -999.250 TCND. PNA V -999.250 TCFD. PNA V -999.250 TSCN. PNA V -999.250 TSCF. PNA V -999.250 INND. PNA V -999.250 INFD. PNA V -999.250 GRCH. TDTP 49.722 DEPT. 8935.500 SIGM. PNAV 39.873 TPHI. PNA V 47.914 SBHF. PNA V 57.074 SBHN. PNA V 57.780 SIGC. PNA V 2.948 SIBH. PNAV 77 _ 265 TRAT. PNAV 1.457 SDSI. PNAV 1.094 BACK. TDTP 178.436 FBAC. TDTP 37.492 TCAN. PNA V 25425.074 TCAF. PNA V 7296.932 TCND. PNA V 16290.586 TCFD. PNA V 4232.822 TSCN. PNA V 1347.380 ----1 ----J LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 27 TSCF. PNA V 482.850 INND. PNA V 3951.318 INFD. PNA V 425.374 GRCH.TDTP 80.633 ** END OF DATA ** **** FILE TRAILER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE EDIT .007 FLIC 001COl 98/09/10 1024 LO **** FILE HEADER **** FILE NAME EDIT . 008 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 8 ---------------- ----------- ---------- TDTP 9591.0 $ 8936.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 15-MAY-98 8CO-609 9570.0 9000.0 9565.0 1800.0 NO # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ----) ------) LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 28 ---------------- --------- ----------- GR TDTP $ GAMMA RAY THERMAL DECAY CGRS-A 862 TDT-P # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 9915.0 # BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): Injection Fluids # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 # BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): # BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): # REMARKS: This log was depth referenced to a SWS BHC log, dated 07-29-1980 All depth correlation and tie-ins witnessed by co. rep. Logging Procedure: TDT logging interval is 9565'-9000' with 120 BBL borax pumped, followed with 190 BBL seawater pumped at stages of 80-40-40-30 BBLS. A borax pass was made after each series pumpings. Then a final volume of 383 BBLS of seawater was pumped to displace the warmback passes. Baseline pass was made after flowing the well for 1 hour. Well Summary: CHOKE:48 PCNT, WHP:1029 PSI, WHT:147 DEGF, MAN PRESS:1006 PSI, MAN TEMP:147 DEGF. THIS FILE CONTAINS THE RAW TDTP DATA FOR THE BASELINE PASS. $ # --, -----) LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 29 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ------------------------------ ** SET TYPE - CHAN * * --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 8 1 1 4 68 0000000000 SIGM PSI CU 1160737 00 000 00 0 8 1 1 4 68 0000000000 TPHI PSI PU 1160737 00 000 00 0 8 1 1 4 68 0000000000 SBHF PSI CU 1160737 00 000 00 0 8 1 1 4 68 0000000000 SBHN PSI CU 1160737 00 000 00 0 8 1 1 4 68 0000000000 SIGC PSI CU 1160737 00 000 00 0 8 1 1 4 68 0000000000 SIBH PSI CU 1160737 00 000 00 0 8 1 1 4 68 0000000000 TRAT PSI 1160737 00 000 00 0 8 1 1 4 68 0000000000 SDSI PSI CU 1160737 00 000 00 0 8 1 1 4 68 0000000000 BACK PSI CPS 1160737 00 000 00 0 8 1 1 4 68 0000000000 FBAC PSI CPS 1160737 00 000 00 0 8 1 1 4 68 0000000000 TCAN PSI CPS 1160737 00 000 00 0 8 1 1 4 68 0000000000 TCAF PSI CPS 1160737 00 000 00 0 8 1 1 4 68 0000000000 TCND PSI CPS 1160737 00 000 00 0 8 1 1 4 68 0000000000 TCFD PSI CPS 1160737 00 000 00 0 8 1 1 4 68 0000000000 TSCN PSI CPS 1160737 00 000 00 0 8 1 1 4 68 0000000000 TSCF PSI CPS 1160737 00 000 00 0 8 1 1 4 68 0000000000 INND PSI CPS 1160737 00 000 00 0 8 1 1 4 68 0000000000 INFD PSI CPS 1160737 00 000 00 0 8 1 1 4 68 0000000000 TENS PSI LB 1160737 00 000 00 0 8 1 1 4 68 0000000000 GR PSI GAP I 1160737 00 000 00 0 8 1 1 4 68 0000000000 --) -----\ , LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 30 --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM SIZE REPR CODE PROCESS (HEX) --------------------------------------------------------------------------------------- CCL PSI V 1160737 00 000 00 o 8 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 9591.000 SIGM.PS1 -999.250 TPHI.PS1 -999.250 SBHF.PSl -999.250 SBHN. PSI -999.250 SIGC.PS1 -999.250 SIBH.PSl -999.250 TRAT. PSI -999.250 SDSI.PS1 -999.250 BACK. PSI -999.250 FBAC. PSI -999.250 TCAN. PSI -999.250 TCAF. PSI -999.250 TCND.PS1 -999.250 TCFD.PS1 -999.250 TSCN.PS1 -999.250 TSCF.PSl -999.250 INND.PS1 -999.250 INFD.PSl -999.250 TENS. PSI 1402.000 GR. PSI 49.722 CCL.PS1 0.019 ** END OF DATA ** **** FILE TRAILER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE EDIT . 008 FLIC 001C01 98/09/10 1024 LO **** FILE HEADER **** FILE NAME EDIT .009 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- TDTP 9556.5 8966.0 -1 '-'---ì LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 31 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 15-MAY-98 8CO-609 9570.0 9000.0 9565.0 1800.0 NO # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- GR TDTP $ GAMMA RAY THERMAL DECAY CGRS-A 862 TDT-P # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 9915.0 # BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (F'T): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): Injection Fluids # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 # BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): # BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): # REMARKS: This log was depth referenced to a SWS BHC log, -1 LIS Tape Verification Listing Schlumberger Alaska Computing Center ----:J 10-SEP-1998 10:45 32 PAGE: dated 07-29-1980 All depth correlation and tie-ins witnessed by co. rep. Logging Procedure: TDT logging interval is 9565' -9000' wi th 120 BBL borax pumped, followed with 190 BBL seawater pumped at stages of 80-40-40-30 BBLS. A borax pass was made after each series pumpings. Then a final volume of 383 BBLS of seawater was pumped to displace the warmback passes. Baseline pass was made after flowing the well for 1 hour. Well Summary: CHOKE:48 PCNT, WHP:I029 PSI, WHT:147 DEGF, MAN PRESS:1006 PSI, MAN TEMP:147 DEGF. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #1. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** TYPE ** SET TYPE - 64EB ** REPR CODE ------------------------------ VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 o 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 o o 88 1 0.5 FT 11 o FT 68 1 1 ------------------------------ NAME ** SET TYPE - CHAN ** SERV ID --------------------------------------------------------------------------------------- SIZE REPR CODE UNIT SERVICE API API API API FILE NUMB ORDER # LOG TYPE CLASS MOD NUMB SAMP NUMB ELEM PROCESS (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 9 1 1 4 68 0000000000 SIGM BXl CU 1160737 00 000 00 0 9 1 1 4 68 0000000000 TPHI BX1 PU 1160737 00 000 00 0 9 1 1 4 68 0000000000 SBHF BXl CU 1160737 00 000 00 0 9 1 1 4 68 0000000000 SBHN BXl CU 1160737 00 000 00 0 9 1 1 4 68 0000000000 SIGC BX1 CU 1160737 00 000 00 0 9 1 1 4 68 0000000000 SIBH BX1 CU 1160737 00 000 00 0 9 1 1 4 68 0000000000 ----OJ --1 LIS Tape Verification Listing 10-SEP-1998 10:45 PAGE: 33 Schlumberger Alaska Compu ting Cen ter --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- TRAT BX1 1160737 00 000 00 0 9 1 1 4 68 0000000000 SDSI BX1 CU 1160737 00 000 00 0 9 1 1 4 68 0000000000 BACK BX1 CPS 1160737 00 000 00 0 9 1 1 4 68 0000000000 FBAC BX1 CPS 1160737 00 000 00 0 9 1 1 4 68 0000000000 TCAN BXl CPS 1160737 00 000 00 0 9 1 1 4 68 0000000000 TCAF BXl CPS 1160737 00 000 00 0 9 1 1 4 68 0000000000 TCND BX1 CPS 1160737 00 000 00 0 9 1 1 4 68 0000000000 TCFD BX1 CPS 1160737 00 000 00 0 9 1 1 4 68 0000000000 TSCN BX1 CPS 1160737 00 000 00 0 9 1 1 4 68 0000000000 TSCF BX1 CPS 1160737 00 000 00 0 9 1 1 4 68 0000000000 INND BX1 CPS 1160737 00 000 00 0 9 1 1 4 68 0000000000 INFD BX1 CPS 1160737 00 000 00 0 9 1 1 4 68 0000000000 TENS BX1 LB 1160737 00 000 00 0 9 1 1 4 68 0000000000 GR BX1 GAPI 1160737 00 000 00 0 9 1 1 4 68 0000000000 CCL BX1 V 1160737 00 000 00 0 9 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 9556.500 SIGM.BXl -999.250 TPHI.BX1 -999.250 SBHF.BXl -999.250 SBHN. BXl -999.250 SIGC.BX1 -999.250 SIBH.BX1 -999.250 TRAT.BX1 -999.250 SDSI.BX1 -999.250 BACK.BXl -999.250 FBAC. BX1 -999.250 TCAN.BX1 -999.250 TCAF. BXl -999.250 TCND.BXl -999.250 TCFD.BX1 -999.250 TSCN.BX1 -999.250 TSCF.BXl -999.250 INND.BXl -999.250 INFD.BX1 -999.250 TENS.BXl 1849.000 GR.BX1 76.714 CCL.BXl 0.019 DEPT. 8965.500 SIGM.BX1 47.800 TPHI.BX1 42.799 SBHF.BX1 85.383 SBHN. BX1 99.442 SIGC.BX1 0.374 SIBH.BX1 171.776 TRAT.BX1 1. 196 SDSI.BX1 1.982 BACK.BX1 153.009 FBAC. BX1 30.679 TCAN. BX1 8286.391 TCAF.BX1 2610.890 TCND.BX1 7854.193 TCFD.BX1 2082.994 TSCN.BX1 364.870 TSCF.BX1 141.910 INND.BX1 3973.144 INFD.BX1 450.953 TENS.BX1 1536.000 GR.BX1 106.906 CCL.BX1 -999.250 ** END OF DATA ** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER **** EDIT .009 FLIC 001C01 98/09/10 1024 LO -"} ---1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 34 **** FILE HEADER **** FILE NAME EDIT .010 SERVICE FLIC VERSION 001COl DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- TDTP 9556.5 $ 8968.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 15-MAY-98 8CO-609 9570.0 9000.0 9565.0 1800.0 NO # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- GR TDTP $ GAMMA RAY THERMAL DECAY CGRS-A 862 TDT-P # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 9915.0 # BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): Injection Fluids .---) ---1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 35 FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 # BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): # BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): # REMARKS: This log was depth referenced to a SWS BHC log, dated 07-29-1980 All depth correlation and tie-ins witnessed by co. rep. Logging Procedure: TDT logging interval is 9565'-9000' with 120 BBL borax pumped, followed with 190 BBL seawater pumped at stages of 80-40-40-30 BBLS. A borax pass was made after each series pumpings. Then a final volume of 383 BBLS of seawater was pumped to displace the warmback passes. Baseline pass was made after flowing the well for 1 hour. Well Summary: CHOKE:48 PCNT, WHP:1029 PSI, WHT:147 DEGF, MAN PRESS:1006 PSI, MAN TEMP:147 DEGF. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #2. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** ------------------------------ TYPE REPR CODE VALUE ------------------------------ 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 ---, ---1 LIS Tape Verification Listing 10-SEP-1998 10:45 PAGE: 36 Schlumberger Alaska Computing Center ------------------------------ TYPE REPR CODE VALUE ------------------------------ 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ------------------------------ SET TYPE - CHAN ** --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 10 1 1 4 68 0000000000 SIGM BX2 CU 1160737 00 000 00 0 10 1 1 4 68 0000000000 TPHI BX2 PU 1160737 00 000 00 0 10 1 1 4 68 0000000000 SBHF BX2 CU 1160737 00 000 00 0 10 1 1 4 68 0000000000 SBHN BX2 CU 1160737 00 000 00 0 10 1 1 4 68 0000000000 SIGC BX2 CU 1160737 00 000 00 0 10 1 1 4 68 0000000000 SIBH BX2 CU 1160737 00 000 00 0 10 1 1 4 68 0000000000 TRAT BX2 1160737 00 000 00 0 10 1 1 4 68 0000000000 SDSI BX2 CU 1160737 00 000 00 0 10 1 1 4 68 0000000000 BACK BX2 CPS 1160737 00 000 00 0 10 1 1 4 68 0000000000 FBAC BX2 CPS 1160737 00 000 00 0 10 1 1 4 68 0000000000 TCAN BX2 CPS 1160737 00 000 00 0 10 1 1 4 68 0000000000 TCAF BX2 CPS 1160737 00 000 00 0 10 1 1 4 68 0000000000 TCND BX2 CPS 1160737 00 000 00 0 10 1 1 4 68 0000000000 TCFD BX2 CPS 1160737 00 000 00 0 10 1 1 4 68 0000000000 TSCN BX2 CPS 1160737 00 000 00 0 10 1 1 4 68 0000000000 TSCF BX2 CPS 1160737 00 000 00 0 10 1 1 4 68 0000000000 INND BX2 CPS 1160737 00 000 00 0 10 1 1 4 68 0000000000 INFD BX2 CPS 1160737 00 000 00 0 10 1 1 4 68 0000000000 TENS BX2 LB 1160737 00 000 00 0 10 1 1 4 68 0000000000 GR BX2 GAPI 1160737 00 000 00 0 10 1 1 4 68 0000000000 CCL BX2 V 1160737 00 000 00 0 10 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA DEPT. 9556.500 SIGM.BX2 -999.250 TPHI.BX2 -999.250 SBHF.BX2 -999.250 SBHN.BX2 -999.250 SIGC.BX2 -999.250 SIBH.BX2 -999.250 TRAT.BX2 -999.250 SDSI.BX2 -999.250 BACK.BX2 -999.250 FBAC.BX2 -999.250 TCAN. BX2 -999.250 TCAF. BX2 -999.250 TCND. BX2 -999.250 TCFD.BX2 -999.250 TSCN.BX2 -999.250 TSCF.BX2 -999.250 INND.BX2 -999.250 INFD.BX2 -999.250 TENS.BX2 1343.000 GR.BX2 131.618 CCL.BX2 0.000 ---1 -----1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 37 DEPT. SBHN.BX2 SDSI.BX2 TCAF.BX2 TSCF.BX2 GR.BX2 8968.000 97.931 2.212 2360.859 120.828 113.913 SIGM.BX2 SIGC.BX2 BACK.BX2 TCND. BX2 INND.BX2 CCL.BX2 50.597 0.090 195.259 7594.495 3945.064 -999.250 TPHI. BX2 SIBH.BX2 FBAC. BX2 TCFD.BX2 INFD.BX2 42. 617 168.348 34.792 1966.093 480.120 SBHF.BX2 TRAT.BX2 TCAN. BX2 TSCN.BX2 TENS.BX2 84.974 1.177 7626.311 316.132 1542.000 ** END OF DATA ** FILE FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE TRAILER **** EDIT .010 FLIC 001C01 98/09/10 1024 LO **** FILE HEADER **** FILE NAME EDIT . 011 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- TDTP 9563.5 $ 8970.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): 15-MAY-98 8CO-609 9570.0 9000.0 9565.0 ---1 -·-1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 38 LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 1800.0 NO # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- GR TDTP $ GAMMA RAY THERMAL DECAY CGRS-A 862 TDT-P # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 9915.0 # BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): Injection Fluids # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 # BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): # BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): # REMARKS: This log was depth referenced to a SWS BHC log, dated 07-29-1980 All depth correlation and tie-ins witnessed by co. rep. Logging Procedure: TDT logging interval is 9565'-9000' with 120 BBL borax pumped, followed with 190 BBL seawater pumped at stages of 80-40-40-30 BBLS. A borax pass was made after each series pumpings. Then a final volume of 383 BBLS of seawater was pumped to displace the warmback passes. Baseline pass was made after flowing the well for 1 hour. Well Summary: CHOKE:48 PCNT, WHP:I029 PSI, WHT:147 DEGF, ---) LIS Tape Verification Listing Schlumberger Alaska Computing Center ---1 10-SEP-1998 10:45 PAGE: 39 MAN PRESS:I006 PSI, MAN TEMP:147 DEGF. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #3. $ # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE ------------------------------ VALUE ------------------------------ 1 66 2 66 3 73 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 o o 88 1 0.5 FT 11 o FT 68 1 1 ------------------------------ SET TYPE - CHAN * * --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 11 1 1 4 68 0000000000 SIGM BX3 CU 1160737 00 000 00 0 11 1 1 4 68 0000000000 TPHI BX3 PU 1160737 00 000 00 0 11 1 1 4 68 0000000000 SBHF BX3 CU 1160737 00 000 00 0 11 1 1 4 68 0000000000 SBHN BX3 CU 1160737 00 000 00 0 11 1 1 4 68 0000000000 SIGC BX3 CU 1160737 00 000 00 0 11 1 1 4 68 0000000000 SIBH BX3 CU 1160737 00 000 00 0 11 1 1 4 68 0000000000 TRAT BX3 1160737 00 000 00 0 11 1 1 4 68 0000000000 SDSI BX3 CU 1160737 00 000 00 0 11 1 1 4 68 0000000000 BACK BX3 CPS 1160737 00 000 00 0 11 1 1 4 68 0000000000 FBAC BX3 CPS 1160737 00 000 00 0 11 1 1 4 68 0000000000 TCAN BX3 CPS 1160737 00 000 00 0 11 1 1 4 68 0000000000 TCAF BX3 CPS 1160737 00 000 00 0 11 1 1 4 68 0000000000 TCND BX3 CPS 1160737 00 000 00 0 11 1 1 4 68 0000000000 TCFD BX3 CPS 1160737 00 000 00 0 11 1 1 4 68 0000000000 TSCN BX3 CPS 1160737 00 000 00 0 11 1 1 4 68 0000000000 TSCF BX3 CPS 1160737 00 000 00 0 11 1 1 4 68 0000000000 --1 -----1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 40 --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) --------------------------------------------------------------------------------------- INND BX3 CPS 1160737 00 000 00 0 11 1 1 4 68 0000000000 INFD BX3 CPS 1160737 00 000 00 0 11 1 1 4 68 0000000000 TENS BX3 LB 1160737 00 000 00 0 11 1 1 4 68 0000000000 GR BX3 GAPI 1160737 00 000 00 0 11 1 1 4 68 0000000000 CCL BX3 V 1160737 00 000 00 0 11 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 9563.500 SIGM.BX3 -999.250 TPHI.BX3 -999.250 SBHF.BX3 -999.250 SBHN.BX3 -999.250 SIGC.BX3 -999.250 SIBH.BX3 -999.250 TRAT.BX3 -999.250 SDSI.BX3 -999.250 BACK. BX3 -999.250 FBAC. BX3 -999.250 TCAN. BX3 -999.250 TCAF. BX3 -999.250 TCND.BX3 -999.250 TCFD.BX3 -999.250 TSCN.BX3 -999.250 TSCF.BX3 -999.250 INND.BX3 -999.250 INFD.BX3 -999.250 TENS.BX3 1238.000 GR.BX3 81. 364 CCL.BX3 0.000 DEPT. 8969.500 SIGM.BX3 48.263 TPHI.BX3 46.375 SBHF.BX3 63.227 SBHN. BX3 71. 758 SIGC.BX3 2.960 SIBH.BX3 108.975 TRAT.BX3 1. 260 SDSI.BX3 2.038 BACK.BX3 211.733 FBAC. BX3 41.136 TCAN. BX3 13450.293 TCAF.BX3 3714.815 TCND.BX3 12099.637 TCFD.BX3 3005.051 TSCN.BX3 551.331 TSCF. BX3 174.205 INND.BX3 3900.433 INFD.BX3 460.448 TENS.BX3 1608.000 GR.BX3 117.313 CCL.BX3 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME SERVICE VERSION DATE MAX REC SIZE FILE TYPE LAST FILE EDIT . 011 FLIC 001C01 98/09/10 1024 LO **** FILE HEADER FILE NAME EDIT . 012 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE ---1 ---, LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 41 FILE HEADER FILE NUMBER RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 5 DEPTH INCREMENT: 0 . 5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 12 ---------------- ----------- ---------- TDTP 9550.0 $ 8969.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 15-MAY-98 8CO-609 9570.0 9000.0 9565.0 1800.0 NO # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- --------- ----------- GR TDTP $ GAMMA RAY THERMAL DECAY CGRS-A 862 TDT-P # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 8.500 9915.0 # BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): Injection Fluids # NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 # BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE '1j ----) LIS Tape Verification Listing Schlumberger Alaska Computing Center " ----1 10-SEP-1998 10:45 PAGE: 42 # TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): # This log was depth referenced to a SWS BHC log, dated 07-29-1980 All depth correlation and tie-ins witnessed by co. rep. Logging Procedure: TDT logging interval is 9565'-9000' with 120 BBL borax pumped, followed with 190 BBL seawater pumped at stages of 80-40-40-30 BBLS. A borax pass was made after each series pumpings. Then a final volume of 383 BBLS of seawater was pumped to displace the warmback passes. Baseline pass was made after flowing the well for 1 hour. Well Summary: CHOKE:48 PCNT, WHP:1029 PSI, WHT:147 DEGF, MAN PRESS:1006 PSI, MAN TEMP:147 DEGF. THIS FILE CONTAINS THE RAW TDTP DATA FOR BORAX PASS #4. $ REMARKS: # LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** TYPE ** SET TYPE - 64EB ** REPR CODE ------------------------------ VALUE ------------------------------ 1 2 3 4 5 6 7 8 9 11 12 13 14 15 16 o 66 66 73 66 66 73 65 68 65 66 68 66 65 66 66 66 o o 88 1 0.5 FT 11 o FT 68 1 1 ------------------------------ ------) ---ì LIS Tape Verification Listing 10-SEP-1998 10:45 PAGE: 43 Schlumberger Alaska Computing Center ** SET TYPE - CHAN * * --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 12 1 1 4 68 0000000000 SIGM BX4 CU 1160737 00 000 00 0 12 1 1 4 68 OOOOOOOOcJO TPHI BX4 PU 1160737 00 000 00 0 12 1 1 4 68 0000000000 SBHF BX4 CU 1160737 00 000 00 0 12 1 1 4 68 0000000000 SBHN BX4 CU 1160737 00 000 00 0 12 1 1 4 68 0000000000 SIGC BX4 CU 1160737 00 000 00 0 12 1 1 4 68 0000000000 SIBH BX4 CU 1160737 00 000 00 0 12 1 1 4 68 0000000000 TRAT BX4 1160737 00 000 00 0 12 1 1 4 68 0000000000 SDSI BX4 CU 1160737 00 000 00 0 12 1 1 4 68 0000000000 BACK BX4 CPS 1160737 00 000 00 0 12 1 1 4 68 0000000000 FBAC BX4 CPS 1160737 00 000 00 0 12 1 1 4 68 0000000000 TCAN BX4 CPS 1160737 00 000 00 0 12 1 1 4 68 0000000000 TCAF BX4 CPS 1160737 00 000 00 0 12 1 1 4 68 0000000000 TCND BX4 CPS 1160737 00 000 00 0 12 1 1 4 68 0000000000 TCFD BX4 CPS 1160737 00 000 00 0 12 1 1 4 68 0000000000 TSCN BX4 CPS 1160737 00 000 00 0 12 1 1 4 68 0000000000 TSCF BX4 CPS 1160737 00 000 00 0 12 1 1 4 68 0000000000 INND BX4 CPS 1160737 00 000 00 0 12 1 1 4 68 0000000000 INFD BX4 CPS 1160737 00 000 00 0 12 1 1 4 68 0000000000 TENS BX4 LB 1160737 00 000 00 0 12 1 1 4 68 0000000000 GR BX4 GAPI 1160737 00 000 00 0 12 1 1 4 68 0000000000 CCL BX4 V 1160737 00 000 00 0 12 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- ** DATA ** DEPT. 9550.000 SIGM.BX4 -999.250 TPHI.BX4 -999.250 SBHF.BX4 -999.250 SBHN.BX4 -999.250 SIGC.BX4 -999.250 SIBH.BX4 -999.250 TRAT.BX4 -999.250 SDSI.BX4 -999.250 BACK.BX4 -999.250 FBAC.BX4 -999.250 TCAN.BX4 -999.250 TCAF.BX4 -999.250 TCND.BX4 -999.250 TCFD.BX4 -999.250 TSCN.BX4 -999.250 TSCF.BX4 -999.250 INND.BX4 -999.250 INFD.BX4 -999.250 TENS.BX4 1409.000 GR.BX4 52.647 CCL.BX4 0.019 DEPT. 8969.000 SIGM.BX4 44.194 TPHI.BX4 66.494 SBHF.BX4 52.637 SBHN.BX4 63. 073 SIGC.BX4 1.403 SIBH.BX4 89.272 TRAT.BX4 1.683 SDSI.BX4 1.198 BACK.BX4 200.353 FBAC. BX4 37.612 TCAN.BX4 25966.301 TCAF. BX4 6393.086 TCND.BX4 171 00.965 TCFD.BX4 3964.359 TSCN.BX4 1331.265 TSCF.BX4 367.119 INND.BX4 3938.930 INFD.BX4 457.754 TENS.BX4 1596.000 GR.BX4 116.468 CCL.BX4 -999.250 END OF DATA "1 ----1 ---., LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 44 **** FILE TRAILER **** FILE NAME EDIT .012 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE **** FILE HEADER **** FILE NAME EDIT .013 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE FILE HEADER FILE NUMBER 13 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 # FILE SUMMARY . VENDOR TOOL CODE START DEPTH STOP DEPTH ---------------- ----------- ---------- TDTP 9562.0 $ 8970.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 15-MAY-98 8CO-609 9570.0 9000.0 9565.0 1800.0 NO # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER ---------------- ....-------- ----------- GR TDTP $ GAMMA RAY THERMAL DECAY CGRS-A 862 TDT-P # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 ---J -----1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 45 # DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 9915.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): # Injection Fluids NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): # BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): # REMARKS: # LIS FORMAT DATA This log was depth referenced to a SWS BHC log, dated 07-29-1980 All depth correlation and tie-ins witnessed by co. rep. Logging Procedure: TDT logging interval is 9565'-9000' with 120 BBL borax pumped, followed with 190 BBL seawater pumped at stages of 80-40-40-30 BBLS. A borax pass was made after each series pumpings. Then a final volume of 383 BBLS of seawater was pumped to displace the warmback passes. Baseline pass was made after flowing the well for 1 hour. Well Summary: CHOKE:48 PCNT, WHP:1029 PSI, WHT:147 DEGF, MAN PRESS:1006 PSI, MAN TEMP:147 DEGF. THIS FILE CONTAINS THE RAW TDTP DATA FOR THE FLUSHED PASS. $ ----) " LIS Tape Verification Listing Schlumberger Alaska Computing Center ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** ---) 10-SEP-1998 10:45 PAGE: 46 TYPE REPR CODE ------------------------------ VALUE ------------------------------ 1 66 2 66 3 73 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 o o 88 1 0.5 FT 11 o FT 68 1 1 ------------------------------ SET TYPE - CHAN * * --------------------------------------------------------------------------------------- NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) --------------------------------------------------------------------------------------- DEPT FT 1160737 00 000 00 0 13 1 1 4 68 0000000000 SIGM FLU CU 1160737 00 000 00 0 13 1 1 4 68 0000000000 TPHI FLU PU 1160737 00 000 00 0 13 1 1 4 68 0000000000 SBHF FLU CU 1160737 00 000 00 0 13 1 1 4 68 0000000000 SBHN FLU CU 1160737 00 000 00 0 13 1 1 4 68 0000000000 SIGC FLU CU 1160737 00 000 00 0 13 1 1 4 68 0000000000 SIBH FLU CU 1160737 00 000 00 0 13 1 1 4 68 0000000000 TRAT FLU 1160737 00 000 00 0 13 1 1 4 68 0000000000 SDSI FLU CU 1160737 00 000 00 0 13 1 1 4 68 0000000000 BACK FLU CPS 1160737 00 000 00 0 13 1 1 4 68 0000000000 FBAC FLU CPS 1160737 00 000 00 0 13 1 1 4 68 0000000000 TCAN FLU CPS 1160737 00 000 00 0 13 1 1 4 68 0000000000 TCAF FLU CPS 1160737 00 000 00 0 13 1 1 4 68 0000000000 TCND FLU CPS 1160737 00 000 00 0 13 1 1 4 68 0000000000 TCFD FLU CPS 1160737 00 000 00 0 13 1 1 4 68 0000000000 TSCN FLU CPS 1160737 00 000 00 0 13 1 1 4 68 0000000000 TSCF FLU CPS 1160737 00 000 00 0 13 1 1 4 68 0000000000 INND FLU CPS 1160737 00 000 00 0 13 1 1 4 68 0000000000 INFD FLU CPS 1160737 00 000 00 0 13 1 1 4 68 0000000000 TENS FLU LB 1160737 00 000 00 0 13 1 1 4 68 0000000000 GR FLU GAPI 1160737 00 000 00 0 13 1 1 4 68 0000000000 CCL FLU V 1160737 00 000 00 0 13 1 1 4 68 0000000000 --------------------------------------------------------------------------------------- "}' ..-) -1 ?' LIS Tape Verification Listing Schlumberger Alaska Computing Center 10-SEP-1998 10:45 PAGE: 47 ** DATA ** DEPT. 9562.000 SIGM. FLU -999.250 TPHI. FLU -999.250 SBHF. FLU -999.250 SBHN.FLU -999.250 SIGC. FLU -999.250 SIBH. FLU -999.250 TRAT.FLU -999.250 SDSI. FLU -999.250 BACK. FLU -999.250 FBAC. FLU -999.250 TCAN. FLU -999.250 TCAF. FLU -999.250 TCND. FLU -999.250 TCFD. FLU -999.250 TSCN. FLU -999.250 TSCF. FLU -999.250 INND.FLU -999.250 INFD. FLU -999.250 TENS. FLU 1573.000 GR. FLU 26.324 CCL. FLU 0.048 DEPT. 8969.500 SIGM.FLU 46.948 TPHI. FLU 75.086 SBHF.FLU 52.633 SBHN. FLU 60.966 SIGC. FLU 0.000 SIBH.FLU 84.492 TRAT. FLU 1.830 SDSI.FLU 1.237 BACK. FLU 214.107 FBAC. FLU 48.423 TCAN. FLU 26575.914 TCAF. FLU 6334.608 TCND. FLU 17032.141 TCFD. FLU 3866.908 TSCN. FLU 1348.637 TSCF. FLU 328.986 INND. FLU 3923.464 INFD. FLU 442.704 TENS. FLU 1569.000 GR. FLU 119.981 CCL. FLU -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME EDIT .013 SERVICE FLIC VERSION 001C01 DATE 98/09/10 MAX REC SIZE 1024 FILE TYPE LO LAST FILE **** TAPE TRAILER **** SERVICE NAME DATE ORIGIN TAPE NAME CONTINUATION # PREVIOUS TAPE COMMENT EDIT 98/09/10 FLIC 98448 1 BP EXPLORATION, Y-03, PRUDHOE BAY, API #50-029-20411-00 REEL TRAILER SERVICE NAME EDIT DATE 98/09/10 ORIGIN FLIC REEL NAME 98448 CONTINUATION # PREVIOUS REEL COMMENT BP EXPLORATION, Y-03, PRUDHOE BAY, API #50-029-20411-00 ~,)"': -;0 r-r1 t""" rn -- .c:. rT1 ø .-J LIS TAPE Y E RI FICAT1QNJiISTING * * *. ...***.***** ****.*. * * * * * * ** **,~**,~*,.~*~~~·*t*~.· *...~...__..ø..__..-.* *.. ·.~Ç!flJtfM~Eª~ EiR1!IIt"~"i. *.......--...--.....-* ************...f****** ¡ ~. 's...'.fÞlr:,~~;:~~~~#~JK 1& J. (gt~f;t(..·...·.·...1ðl~ .J¡tq/~¡' .0{ '.'- C~17\ m OJ t-" -.....1 tD ~ ~ pJ ~ g ~ ~CÏJ (')~ :::'C) go ~::J ~ rJ"'! (9 . (") o '3 :3 '(þ" ~. g PAGE VERIFICATION LISTING H02 . LVP 010 ** REEL HEADER SERVICE NAME DATE :83/02/14 ORIGIN : REEL NAME .REEL tD CONTINUATION # ;01 PREVIOUS REEL : COMMENTS :REEL CDMMENTS .* :SERVIC I i ~, ** :SERVIC :01 · .. COMMENTS ********** ** TAPE HEADER SERVICE NAME DATE :83/02/14 ORIGIN :6641 TAPE NAME : CONTINUATION I PREVIOUS TAPE COMMENTS :TAPE EOF .001 1024 ** · · RECORDS ** FILE HEADER ** FILE NAME :SERVIC SERVICE NAME I VERSION # : DATE : MAXIMUM LENGTH FILE TYPE : PREVIOUS FILE INFORMATION · · ** I -L 065 065 065 065 065 OtiS 065 065 065 008 020 010 002 002 002 012 006 006 CATE -.-. 000 000 000 000 000 ÒQO 000 000 000 000 .000 000 000 000 Qf)Q 000 OQO 000 UNI,T ..... CONTENTS .......... MNEM ..... #2 CN : SIMASKO WN : 5IMPCO MOQUAWKIE FN : MOQUAWKIE RANG: NA TOWN I NA S~CT I NA COUNt NORTH SLOPE STAT: ALASKA CTRY: TYON€K ** COMMENTS ** ***********************************....**************.****.******************** * SCHLUMBERGER' * .~ * ALASKA COMPutINGC!NTER * **********.************************..~*.**,.************************************ COMPANY = SIMASKO PRODUCTION COMPANY WELL . SIMPCOMOQUAWKIE t2 FIE.LD ~ MOQUAWKIE COUNTY ~ TYONEK STATE = A~A5KA PAGE H02 VERIFICATION LISTING . LVP 010 NUMBER AT ACCI 66413 #~GHDATE LOGGED: 26-JAN-79 JOB RUN LDP . . ************.********************.********************************************* J ** DATA FORMAT RECORD ** ENTRY BLOCKS RIPRCf.lDi: 66 j·3 65 66 SIZE 1 4 4 1 TYPE 4 8 9 o REPR CODE 68 68 68 68 68 fre 69 68 68 68 68 ~8 68 68 68 68 ~ PROCESS SAMPLE LEVEL o 1 o 1 o 1 o 1 o 1 o 1 o 1 () 1 o 1 o 1 o 1 .0 1 o 1 o " o 1 o 1 SIZE 4 .. 4 4 4 4 4 ;4 4 4- 4 4 4 4 4 4 API API API FILE TYPE CLASS MDDRO. o 0 0 0 o 0 .00 o 0 0 0 1 00. 0 31 32 0 0 52 32 0 () 31 32 0 0 28 3 0 0 000 0 26 2, 0 0 25 2 0 0 2830 0 68 2 0 0 44 0 0 Q 35 10 0 34 920 () API LOG o o o o o 60 60 60 21 21 21 21 42 42 42 42 DATUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT 1D ORDER # FT OHMM OHMM MV GAPI US/F GAP! IN OHMM OHMM OHMM IN PU G/C3 G/C3 DLL DLL DLL DLL SHC BHC BHC PRX PRX PRX PRX FON FDN FDN FON DEPT LLS LLD SP GR OT GR CALI PROX MNOR MINV CALI NPHI DRHO RHOB NCNL .~ -- -- ~ DEPT GR PROX NPHI rCNL DEPT GR PROX NPHI FCNI) DEPT GR PROX NPHI FCNr.l DEPT GR PROX NPHI FCNL DEPT GR PROX NPHI rCNt DEPT GR PROX NPHI rCNL DEPT GR PROX NPHI reNL DEPT GR PROX NPHI 6664,0000 Lt.S 90,6000 DT 1000000:0000 MNOR -99900,0000 DRHO -999,0000 CAllI 6600,0000 LLS 80,6000 DT 1000000,0000 MNOR -99900.0000 DRHO -999,0000 CALI 6500.0000 LLS 127 9000 DT 1000000:0000 MNOR -99900,0000 DRHO -999,0000 CALI 6400,0000 LLS 121.3000 DT 1000000.0000 MNOR -99900.0000 DRHO ""999.0000 CALI 6300.0000 LLS 82.1000 Dr 1000000,0000 MNOR 41.7!81 DRHO 43,7 80 CALI 6200,0000 LLS 55,4000 DT o 6128 MNOR 15'6040 DRHO 227:7990 CALI 6100.0000 LLS 85,7000 DT o 3830 MNOR 33:6644 DRHO 60.4890 CALI 6000.0000 LLS 51,100Q DT 0.4243 MNOR 21,6846 DRHO 10.7848 78.'7175 0,8645 Q.1240 12,6128 82.379.4 o .3115 0.1090 7,0832 19.2666 59..3196 0.5419 0.1170 7.3684 19.4449 7 5 . o BiS'7 -999.0000 0.t140 7.6536 13.9576 10ieooo -999,0000 -999,0.000 -999.0000 13.3294 81.4392 -999,0000 -999.0000 -999.0000 LLD GB MINV RHOS. GR LLD GR M IffY RHoa GR LLD Gft MINV RHOS GR LLD OR MINV RHGB GR LLD GR MINV Rlioe GR LLD GR MINV RHUS 12.9571 4<1.2461 0, 3129 2.4430 SP CALI CALI NCNL 33'~063S 6·'8000 8:Sb20 289,146.0 12.2604 83.,,1425 O~S561 2.}9<80 70,'000 SP CALI CALI NCNb NRAT 16.4681 6,6500 7~5456 200.7720 3,0400 23.3632 '6.6140. 0,'1739 2.4'2'0 50,6000 SP tAL.! 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O,.,OQ20 6.1327 27.3238 73.8161 3.9611 2.26'20 69,4000 LLD GR MINV RHoa GR . 14.7506 84.,6557 4.6434 0.1740 9,1764 CALI LI,a DT MNOR DRHO CALI LL5 DT MNOR DRHO CALI LLS DT MNOR DRHO CALI LVP 010.H02 VERIFICATION 123.5520 5900,0000 66,5000 1,0283 16.8523 205.9200 FCNL DEPT GR PROX NPHI rCNL 5800.0000 74.4000 2.2196 43.1.477 38.6100 DEPT GR PROX NPHI PCNL 103.5957 6i.5500 3,'7987 224;3670 2,2380 _l 98,8085 0,0000 6.4823 l' 6,3.0200 3,3360 SP CAliI CALI HCNL NRAT SP C.ALI CALI NCNL NRAT 2.5851 3'·.i.8.~1~ -0.0346 2i.t·3'70 37.9000 LLD GR MINV RHOS GR 81,1982 63.7%37 0.1271 -0.2990 6~4654 5700.0000 30 8000 1000000:0000 23.1946 97.3830 DEPT GR PROX NPHI rCNL ~ t.6923 ...t.OO·26 5.8720 2.5050 67.2000 44.5431 Oè'6309 4.6894 .(l.OQ30 6,5129 LLS DT MNOR DRHO CALI 5614.5000 61,8000 1.7555 .0.4832 46.7610 DEPT GR PROX NPHI FCNL ** FILE TRAILER ** FILE NAME ISERVIC,OOl SERVICE NAME : VERSION # I DATE : MAXIMUM LENGTH : 1024 FILE TYPE : NEXT FtIJE NAME : ********** EO'********** i ì ~. ** TAPE TRAILER ** SERVICE NAME ISERVIC DATE :83/02/14 ORIGIN :6641 TAPE NAME Z CONTINUATION # :01 NEXT TAPE NAME : COMMENTS :TAPE COMMENTS ** REEL TRAILER ** SERVICE NAME ISERVIC DATE :83/02/14 ORIGIM : REEL NAME =REE~lD -"~./ -~ LVP 010.H02 VERIFICATION LISTING PAGE 5 CONTINUATION # :01 NEXT REEIJ NAME : COMMENTS :REEL COMMENTS ********** EOF ****".*.* ********** EOF *****c***** ~ I -~ '..~ --,~