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Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov 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 DSR-3/25/2020 SFD 3/25/2020 xG 28. CORE DATA Conventional Core(s): Yes ❑ No N Sidewall Cores: Yes ❑ No ,2 If Yes, list formations and intervals cored (MD/TVD, 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 during P&A operations. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No d 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 cut-off casinq and marker ID plate. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, leon olo i al r ortroduction or well test results, er 20 AAC 25.070. 32. 1 hereby certify that the foregoinq is true and correct to the best of my knowledge. Authorized Name: Ed Jones Contact Name: Ed Jones Authorized Title: Operation Consultant Contact Email: Authorized Contact Phone: 713-899-8103 / Signature: Date: INSTRUCTIONS General: This rm and the rec(ui d 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 #1 (AOGCC PERMIT No. 178-047) (API No. 50-283-20060-00-00) PLUG AND ABANDONMENT DAILY OPERATIONS SUMMARY FORM 10-407 7/21/2017—Aurora Gas operations. RU Pollard slickline (SL). Run 2.4" wire brush to 2766'. Run Baker FWG plug and attempt to set in "F" profile at 2766'. Plug did not seem to set. Attempt to retrieve, but could not latch onto it. Plug not holding. RD. 7/22/2017—RU SL. TP -10 psi. Retrieve FWG plug. Redress and rerun to 2766' and set in F profile in sliding sleeve (SS). Monitor—no pressure buildup in 30 minutes. 10/25/2018—RU SL. RIH and pull prong from FWG plug at 2766'. RIH and pull plug. Run 2.23" gauge ring to 2774'. Run 2.33" gauge ring with knuckle joint to 2834'. RD SL. RU Alaska E -Line (AEL). RIH with CIBP for 2-7/8" tubing. Correlate and set at 2773'. Fill tubing with 5 bbl water. PT to 1200 psi. 10/26/2018—Overnight TP -800 psi, IA -450 psi. Heater string -0 psi (has check valve). RU Pollard Hot Oil truck (HO). Pump into IA at''/2 BPM tp 1250 psi—leaked off t 300 psi in 30 minutes. Test tubing to 1650 psi for 30 minutes. IA -160 psi. Bled TP to 0 and IA to 110 psi. RD HO. SL'kZ rZj, 10/31/2018—RU AEL to run temperature/pressure survey and RIH for static run—tool failed. RD AEL. Fly over temp/pressure memory tool. RU SL. RIH with temp/pressure memory tool for static run. T4g CIBP at 2773'. BHT -83°. Pump 20 bbl cold water done heater string at 0.5 BPM at 1700 psi, broke to 1550 psi. TP -70 psi. Shut down. 8 minute IA SIP -575 psi, 30 minute SIP -400 psi. Bled off and ran memory tool temp/pressure log. QAI$ perfs at 2122.-46' appear to be leaking taking fluid, RD SL. Called Guy Schwartz with AOGCC and discussed results of log. 11/1/2018—Submitted revised P&A procedure to remediate leaking sqz perfs to AOGCC by email—procedure was approved by email. RU SL. RIH and open SS at 2766'. POH. RD. 11/3/2018—MI, RU Schlumberger (SLB). Heat water to 80°. Mix 90 bbl of water and chemicals. Test lines to 1700/2500 psi. Pump 10 bbl water to circulate down heater string and IA and up tubing. Batch mix cement. Bullhead 1 bbl down heater string, open IA and pump 112 bbl 13.5 ppg Class G cement at 1.70 cf/sk with returns to surface. Shut in tubing and squeeze 1 bbl into leaking squeeze perfs-1700 psi. (272 sx G cement total). Held for 5 minutes, then shut in. Wash out lines. Bleed off IA. RD SLB. 11/8/2018—RU HO truck and PT tubing to 1950 psi --1800 in 15 minutes; IA to 2700 psi -2550 in 15 minutes. RD HO. 8/3/2019—Cut off tree, wellhead, and casing 5'2' below top of pad, 3'2" below apparent original GL. 10/8/2019—AOGCC inspector Lou Laubenstein inspected casing cut-off—good. 10/10/2019—Weld ID marker plate on 13-3/8" conductor casing. Clean out cellar and backfilled. 10/15/2019—Add gravel to backfilled to account for settling. 11/16-17/2019—AOGCC inspector Guy Cook unable to fly from Anchorage due to weather. Cancelled site clearance inspection. Ed Jones 12/10/2019 SIMPCO MOQUAWKIE NO. 1 PTD: 178-047 API# 50-283-20060-00 ACTUAL P&A WELL BORE DIAGRAM October 2019 2) Bullhead cement from surface into heater string (1 BBL) Test Perfs at 12-1/4" Hole to 847'+ 8-3/4" Hole to 3111'+ 924' 1.315" J-55 Heater String 1950-80' Sqzd w/75 sx G 2122-46' Sqzd w/ 25 sx G 2426-56' Sqzd w/ 25 sx G Tyonek "Moquawkie" Production Perfs 2847-2860' Old 2864-2868' 2860-70' new 2870-2877' 2873-83' -- Test Perfs at 2912-34', Sqzd w/ 20 sx G 2957-74' Sqzd w/ 50 sx G Test perfs at 3011-41' Sqzd w/ 33 sx G Test perfs at 3021-41' Sqzd w/ 50 sx G Sqzd perfs at 3000-02'w/ 40 sx G Sqzd perfs @ 3112-16'w/ 150 sx G Squeeze perfs at 3830-33' sqzd w/ 15 sx Squeeze perfs at 3917-20" sqzd w/ 25 sx Test Perfs at: 3850-60' (DST #2) Squeeze perfs at 4050-55" sqzd w/ 140 sx Test perfs at 5028-40' (DST #1) 1 I 6-1/8' Hole Drilled to TD of 6166' 300 sx G bulheaded down 7" X 9-5/8" annulus 13-3/8", 61#, J-55 Conductor driven to 81' 9-5/8", 32.3# H-40 Surface Casing set at 847', cemented to surface Est cement bottom: 1600-1900' 7" DV Tool at 1600' --not used, could not circ so top job r<s� 2-7/8" 6.5# N-80 EUE Tubing 1) Set CIBP in tubing at 2773' 3) Open sleeve at 2766' and circulate 112 bbl Class G cement at 13.5 ppg to surface. SI tbg and sqz 1 bbl into leaking sqz perfs at 2122-46' to 1700 Sliding Sleeve at 2766' f w/ 225" 'F profile Baker FB Packer at 2778' Btm of tubing Seals at 2786' 2.197" No -Go Seating Nipple at 2828' w/ 2.25" 'F profile Btm of Packer Seal Bore/Stinger at 2835' ESV Retainer at 2974'= PTD w/ 35 sx cement below 7", 20#, K-55 Production Casing set at 3110.76', cememted w/ 300 sx at shoe EZSV at 3792'w/ 15 sx G on top EZSV at 5013' 5" 18# Production Liner set 3050' to 5242' & cemented w/ 140 sx at shoe + Liner Lap sqzd with 25 sx G T Ti MCIt tai 3 ✓+ f, Y � � a� � jy' z ..ui GF +rA ....... ya 417o .ate tr is _ H. `S4 T Ti MCIt tai 3 ✓+ f, Y � � a� � jy' z ..ui GF +rA ....... .ate _ b, n � _ 6733 South Yale Avenue Tulsa, OK 74136 Contact: Ed Jones, Consultant Plugging Inlet, LLC 713-899-8103 (C) email: power. 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. 14 �i4 C" V�C � Thank you. Sincerely, dJ.dward (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 Oyc( I z-14 jK( DATE: 10/13/19 P. I. Supervisor FROM: Lou Laubenstein SUBJECT: Surface Abandonment Petroleum Inspector Simpco Moquawkie #1 Plugging Inlet LLC PTD 1780470; Sundry 318-335 10/8/19: 1 arrived on location for the surface abandonment inspection on Simpco Moquawkie #1. 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 v depth of 3 feet minimum below original ground level — this was discussed with Mr. Wallingford. The hole was filled with debris and trash that needs to be removed prior to backfill. Also, there is another piece of casing that was used during the drilling process that should be cut off to the proper depth. I departed location and communicated the ✓ deficiencies to AOGCC Inspection Supervisor Jim Regg. 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-1 11.docx Page 1 of 3 K _ y a °+ Y �� u .. + r �•i ar n J A��s x.99 "•s I! •.B ,fi \A . .�•or y �'` CD ✓ %� � ie f �Y :�./i� �•+/e� � � � ,. . � /meq � � I:E 4C.� r .. � 1l z, v_�• W� lx.. s.1 . K _ y a °+ Y �� u .. S Y(57curzLJ/-ae- t"1 P—/ -b (766+10 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.71h 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.ree¢@alaska.¢ov. 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 of 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.schwortz@oIaska aov). From: J. Edward Jones <ieiones@auroraoower.com> Sent: Thursday, October 10, 2019 8:44 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Regg, James B (CED) <jim.regg@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. Grave[ 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 leve[ 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 [eve[ 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:�uy.schwartz(alataska gov] Sent: Wednesday, October 09, 2019 1:31 PM To: J. Edward Jones <ones��aulor��rer.cam> Cc: Regg, James B (CED) <�im.regg(?alask�,gov>; David Wallingford <rlavid99iyahoo.com> Subject: RE: Plugging Inlet Abandonments 2 1 C'q7 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 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: 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 sljckline 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 i—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:euy.schwartz@alaska.eov] Sent: Monday, March 04, 2019 1:30 PM To: Ed Jones <jeiones(@aurorapower.com> Cc: George Pollock <RpollockPaurorapower com> 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. 1 recall you requested a temporary shutdown of operations until spring to finish the wellhead cutoffs. don't have an email or any documentation that 1 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 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 (907-7931226 ) or (Guy schwartz@alaska qov). lit �t rL 4J % 17 b -_ WY ^( Inlet Plugging LLC I Well: IlYloqualkie #1 Field: IShirelyville 10/31/2018 4.0 4) d t CL d I -W Pressure (psia) 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 0 -- 250 500 -- - -- Pressure -Temperature Profile 1. RIH Overlay 2. Static 750 1000 1� N Y ` 1250 1500 1750 2000 2250 S Z 2500 2750 3000 30 40 50 60 70 80 90 Temperature (Deg. F) SCANNED N0V U S tul0 Pressure 2 — Perfs x PKR Pressure - Basline Temperature 2 Temp - Baseline Report date: 11/1/2018 THE'RATE of A ,--,LAA SKA GOVERNOR BILL WALKER George Pollock Consultant Plugging Inlet, LLC 6733 South Yale Avenue Tulsa, OK 74136 %ANNEV Au(x 3 0 ?078 Alaska Oil a Conservation Co. Re: Moquawkie Field, Undefined Gas Pool, Simpco Moquawkie 1 Permit to Drill Number: 178-047 Sundry Number: 318-335 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 this day of August, 2018. RBDM0 AUs 2 9 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AUG 0 8 2018 AOGCC 1. Type of Request: Abandon Plug Perforations Q Fracture Stimulate El Repair Well Ej Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate El PUB Tubing ❑ Change Approved Program E] Plug for Redrill ❑ Perforate New Pool E] Re-enter Susp Well ❑ Alter Casing ❑ Other. Temporary Plug ❑ 2. Operator Name: 4. Current Weft Class: 5. Permit to brill Number: Plugging Inlet, LLC Exploratory 0 Development n, • Stratigraphic E] Service 178-047 - 3. Address: 6733 South Yale Avenue 6. API Number: Tulsa, OK 74136 50 -283 -20060 -00 -Ci-' I 5,13, ig 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Sinipco M*Wawkie #1 - Will planned perforations require a spacing exception? Yes EI No El 9. Property Designation (Lease Number): 10. Fieid/.Poogs): C-06':j'M 62-5- / s� .5, - ( S. / � I Moguawkie Undefined Gas - 11. PRESENT WELL CORMT[M SUMMARY Total Depth MD (ft): Total Depth TV0 (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 6166' 6166' 2974' 2974' 650 psi 2828'& 2974' None Casing Length size MD TW Burst Collapse Structural Conductor 81, 13 3/8*64* J55 81, 3090 psi 1540 psi Surface 847' 9 5/8" 320 H40 84r 84T 2270 psi 1400 psi Intermediate Production 3111' 7" 20# 144 3111' 3740 psi 3270 psi Liner 11 1 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2847'- 2974' 2847* -2974' 2 7/8" 16.5# N80 2835' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FB packer Baker FIR packer Q 2779 12. Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13. Well Class after proposed work: Detailed Operations Program 2 BOP Sketch El Exploratory 0 stratigraphic El Development [A' Service 101 14. Estimated Date for TBD 15. Well Status after proposed work: Commencing Operations: OIL E WINJ [:] WDSPL E] Suspended El GAS ❑ WAG L] GSTOR F1 SPLUG 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 17.1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: George Poft& —,o-, Contact Name: George Pollock Authorized Title: Consultant Contact Email: avoflock(&—aurora power.com Contact Phone: 907-351-8286 Authorized Signature: Date: 6 -Aug -18 COMMIISSM USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3N - 336 Plug Integrity BOP Test ❑ Mechanical Integrity Test E] Location Clearance Other: 426&CC, Mb Post initial Injection MITReqd? Yes M No F1 Spacing Exception Required? Yes E] No p" Subsequent Form Required: APPROVED BY 022Z Approved by: COMMISSIONER THE COMMISSION Date: efta Form 10.403 Revised 412017 Q RBDMS (,17\ Approved appheaba 1jhL4L datle of approva M&F_ 2 A4 "ff '41oo' and Ndiments ki Du0cate '.� '5� 13,- /g, =AURGRA SAS, -LLC WELL ABANDONMENT SIMPCO MOQUAWKIE #1 Cnnfnmknr gn47 Version 1:0 (9/8/-17) CURRENT CONDITONS: Max SITP-135 psi. KB= 15 feet CASING: 720# K-55 set at 311 l'MD/TVD. DV Tool at 1600' and EZSV Retainer set at 2974'= PBTD. Additional EZSV's set at 3792' (capped with 15 sx G cement) and at 5013'. `l UBINU: 2-7ftS", 6 # N-80 8 rd BUE,-w/ diesel as -packer tluid-in tbg-csg annulus above tap packer and with: Sliding Sleeve: Baker Model L at 2778' with Type F 2.25" NG profile (closed—with d with retrievable plug set in profile); Packer: Baker FB -1 Retainer Production Packer w/ Baker G-22 Locator Seal Assembly with 8 seal units and w/ 2.197" NG SN with 2.25" F profile at 2828' and Mule Shoe Guide with end at 2835' HEA1 EK -S1 E IN U: 1.31-5" '1:9# I S 10 Rd set at -924' -in dual ;(2-3/87) tubing Banger. (See attached completion diagrams) CAPACITIES: 2-7/8" 6.54 Tubing: 0.00579 bbl/ft; Tubing -Casing Annulus: 0:0325 bbl/ft; 7" 20# Casing: 0.0404 bbl/ft. Tubing Volume to Packer= 16.1 bbl, Annular Volume to top Packer= 90.3 bbl; Volume to deepest Perfs= 20.1 bbl -C)1'BN -PEKES: Carya 2-4 at 2847-83' (See wellbore diagram for the many test and squeezed perfs in the well, all of which have been squeezed with cement) NOTES: 1) Well is a straight hole. YJ� SQ �wwAf�4 TV -S1MMARY -OF PLANr �— or boom truck, release from ger (cut or unscrew), ons P;#��* r `� Grp r�rpr ^r, whichever is easier (probably dropped). -RU slick -line. RIH and pull prong and plug at 2766'. Kill well with heavy brine leftover from previous P&A's. PU tubing CIBP, RIH and set near top of packer at 2778'. Test CIBP to 1500 psi. RIH with shifting tool on slickline and open sleeve at 2766'. 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 90 bbl is expected). Pump 10 bbl spacer, then 530 sx (610 cf===109 bbl-)=Cla-s G=cement with additi=ves (15.8 ppg, 1.15 cf/sk yield)=with pump•time•of_4 hr at 75 degrees -3%o excess and displace to surface—this one balanced plug is to meet the requirements of: 1) plug for perforated intervals, 2) surface casing shoe, and 3) surface plug. Monitor for flow or fall • back. Wash out tubing casing annulus to 3 -4 -below -UL. VOC-8 hrs, pressuretest'to_1-500_psi. 'Bleed p tree. Cutoff casing strings and tubing -3-4' below G -L. Mix any off pressure. MI crane. Remove t - 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. PROEDU RE rN �e -+I�eQ.�"�'C" S 1K1G/ 1^ i LL w t'r"t+ WX 1) Pick and move w house. Notify AOGCC inspector of plans for plugging operations. 2) Dis ongt t 1.31 heater string in dual (2-3/8") hanger. Pick up string with loader or boom truck (wei944n air=16619, will be less as it is in diesel). Disconnect from hanger (or cut) and allow to dropANQp packer. Replace surface connection ("tree") and valve to close. 3) Move in cementer (pump truck/mixer), bulk cement (550 sx Class G), slickline/electric line unit, water tank with 100 bbl =fresh:water for eementin, mud "pit" ©pen tank for returns, and 1 flfl+bbl closed tank for diesel packer fluid, and 150 bbl clean brine from previously plugged well. RU cement pump to tree through wing valve. 4) RU slick -line lubricalor on.lree. RJH =4 pull plug at 2766' Imo. Allow pressure to equalize (expect maximum of 135 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 n nreviou-, well Allow tnhino to ctnhili7e bleed off nreccnre (Volume to deenect onen nerfc is-about20_bbl). 7 6) Run 2.25" gauge ring (GR) to check for fluid level and tag 2.197" NG S/N at 2828. If resirietions are found, run bailer, brushes, etc. to cleanout to about 2800'. PU CIBP (running ID less than 2.25;', as have a 2.25" NG in sliding sleeve at 2766'). RIH and set CIBP near top of packer at 27787 (set 7) RIH with shifting tool. Open Baker Model L sliding sleeves at 2766. POOH. Q\ C�4K11Ju:Vl7-1-1�si+-1-1s1J•%.1.-1V,✓a,a1111AiiL:Pu1111_�.i-vti:rvtia6 Lia,..=vip-IL%,"ati :rut-v�-��uvii - casing -annulus) and -pump 10_15151brine 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 530 sx Class G cement (accelerated for hours pump time at 75 degress,15.8 ppg,� 1.15 cf/sk yield) down tubing, circulating cement to surface (3% excess). Catch diesel, *ine, and spacer (separately if possible), the latter to use in subsequent wells. This is to be a balanced plug— monitor for flow or fall back. 9-) , -nen-cemeni iop is-siabie, a'isconneei-cemenier. Wash- tuning, and tubing -casing annulus to 3-- 4' below -GL. WOC-8 hours.- Pressure test. both sides (tubing and annulus): to 1-500 psi. . Release pressure. MI crane. Remove tree. Cutoff conductor,. surface, and, production casing strings and tubing 34' below GL. Mix any cement needed to fill any casing sting of tubing to cut-off. Release 1�' cementers and slickline units to next location. AoCrCL '� Lo 1rNVST S C T4&7^ 14 ANWV' 1 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 Cias, LLC; PTD ## -1-78-047 Simpeo Moquawkie No. 1 API 9 50-283-20060-00 --00 i4 o GC e- 'z,o w V-rP.WS15 —fie 15-00 RS= 7 • I l)Followmg any necessary -inspections, -remove cellar andburymarker. 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 lab to confirm no contamination. Ed Jones (9/8/2017) Test Perfs at • 12-1/4" Hole to 847'+ 8-3/4" Hole to 3111'+ 1950-80' 2122-46' 2426-56' Sqzd w/ 75 sx ( Sqzd w/ 25 sx ( Sqzd w/ 25 sx ( C Al}KIiRA UA -6, LLU SIMPCO-MOQUAWKIE NO. 1 PTD: 178-047 API# 50-283-20060-00 CURRENT WELL BORE DIAGRAM Sept 2017 Tyonek "Moquawkie" Production Perfs 2847-2860' Old 2864-2868' 2860-70' - new 2870-2877' 2873-83' Test Perfs at 2912-34', Sqzd w/ 20 sx G 2957-74' -Sqzd w/-50 sx G Test Perfs at 3011-41' Sqzd w/ 33 sx G Test perfs at 3021-41' Sqzd w/ 50 sx G Sqzd Perfs at 3000-02'w/ 40 sx G Sqzd perfs @ 3112-16'w/ 150 sx G Squeeze perfs at 3830-33'sqzd w/ 15 sx Squeeze perfs at 3917-20" sqzd w/ 25 sx Test .Perfs .at: .3850-60' (DST#2) Squeeze perfs at 4050-55" sqzd w/ 1.40 sx Test perfs at 5028-40' (DST #1) Drilled to TD of 6166' 300 sx G bulheaded down 7" X 9-5/8" annulus en ni�n i+e it i rc Conductor driven to 81' 311, 32.3# H-40 Surface Casing cat at 847' cemented to surface 1.315" J-55 Heater String to 924" Est cement bottom: 1600-1900' V Tool at 1600' --not used, could not circ so top job 2-7/8" 6.5# N-80—EUE Tubing Sliding Sleeve at 2766' w/ 97r," 'F' nrnfila Baker -FB Packer at 2778' Btm of tubing Seals at 2786' 2.197" No -Go Seating Nipple at 2828'w/ 2.25"'F' profile Btm of Packer Seal Bore/Stinger at 2835' ESV Retainer at 2074= PTD w/ 35 sx cement -below 7", 20#, K-55 Production Casing set at 3110.76', cememted w/ 300 sx at shoe EZSV at 3792'w/ 15 sx G on top EZSV at 5013' 5" 18# Production Liner set 3050' to 5242` & cemented w/ 140 sx at shoe + Liner Lap sqzd Test Perfs at SIMPCO MOQUAWKIE NO. 1 PTD: 178-047 API# 50-283-20060-00 PROPOSED P&A WELL BORE DIAGRAM August 2018 2) Bullhead cement from surface into heater string (0.5 12-1/4" Hole to 847'+ 8-3/4" Hole to 3111'+ 924' 1.315" J-55 Heat 1950-80' Sqzd w/ 7' 2122-46' Sqzd w/ 2; 2426-56' Sqzd w/ 2: Tyonek "Moquawkie" Production PE 2847-2860' Old 2864-2868' 2860-70' 2870-2877' 2873-83' Test Perfs at 2912-34', Sqzd w/ 21 2957-74' Sqzd w/ 5( Test perfs at 3011-41' Sqzd w/ 3; Test perfs at 3021-41' Sqzd w/ 51 Sqzd perfs at 3000-02'w/ 40 sx G Sqzd perfs @ 3112-16'w/ 150 sx C Squeeze perfs at 3830-33' sqzd w/ Squeeze perfs at 3917-20" sqzd w) Test Perfs at: 3850-60' (DST #2) Squeeze perfs at 4050-55" sqzd wi Test perfs at 5028-40' (DST #1) Drilled to TD of 6166' 300 sx G bulheaded down 7" X 9-5/8" annulus 13-3/8", 61#, J-55 Conductor driven to 81' B", 32.3# H-40 Surface Casing set at 847', cemented to surface Est cement bottom: 1600-1900' �V Tool at 1600' --not used, could not circ so top job 2-7/8" 6.5# N-80 EUE Tubing )pen sleeve at 2766' and circulate sx G cement to surface. et CIBP in tubing at 2778' Sliding Sleeve at 2766' w/ 2.25"'F' profile Baker FB Packer at 2778' Btm of tubing Seals at 2786' 2.197" No -Go Seating Nipple at 2828'w/ 2.25"'F' profile Btm of Packer Seal Bore/Stinger at 2835' / Retainer at 2974'= PTD w/ 35 sx cement below ?0#, K-55 Production Casing set at 3110.76', cememted w/ 300 sx at shoe >Vat3792'w/15sxGontop iV at 5013' 8# Production Liner set 3050' to 5242'& cemented w/ 140 sx at shoe + Liner Lap sqzd • 2) Drop heater string to 12-1/4" Hole to 847'+ 8-3/4" Hole to 3111'+ 0 AURORA GAS, LLC SIMPGO MOQUAWKIE NO. 1 PTD: 178-047 API# 50-283-20060-00--c-:, AP kJT , PROPOSED P&A WELL BORE DIAGRAM Sept 2017 packer. 300 sx G bull, 924' 1.315" J-55 Heater String Test Perfs at 1950-80' Sqzd w/ 75 sx G 2122-46' Sqzd w/ 25 sx G 2426-56' Sqzd w/ 25 sx G Tyonek "Moquawkie" Prod/dwol'5 rfs 2847-2860' Old 2864-2868' 2new 2870-2877' 2 Test Perfs at 2912-34', Ssx G 2957-74' S sx G Test perfs at 3011-41' Sqzd w/ 33 sx G Test perfs at 3021-41' Sqzd w/ 50 sx G Sqzd perfs at 3000-0 ' w/ 40 sx G Sqzd perfs @ 3112- 6' w/ 150 sx G Squeeze perfs at 3 30-33' sgzd w/ 15 sx Squeeze perfs at 17-20" sqzd w/ 25 sx Test Perfs at: 38 -60' (DST #2) Squeeze perfs a 4050-55" sqzd w/ 140 sx Test perfs at 5028-40' (DST #1) Drilled to TO of 6166' 7" 13-3/8", 6A, J-55 driven to 81' annulus 9-5/8", 32.3# H-40 Surface Casing set at 847', cemented to surface Z C ) r'L. Est cement bottom: 1600-1900' 7" DV Tool at 1600' --not used, could not circ so top job 2-7/8" 6.5# N-80 EUE Tubing 3) Open sleeve at 2766' and circulate 455 sx G.cement to surface. 1) Set CIBP in tubing at 2778' Sliding Sleeve at 2766' w/ 2.25—F profile Baker FB Packer at 2778' Btm of tubing Seals at 2786' 2.197" No -Go Seating Nipple at 2828'w/ 2.25"'F' profile Btm of Packer Seal Bore/Stinger at 2835' ESV Retainer at 2974'= RTD w/ 35 sx cement below 7", 20#, K-55 Production Casing set at 3110.76, cememted w/ 300 sx at shoe EZSV at 3792'w/ 15 sx G on top EZSV at 5013' 5" 18# Production Liner set 3050' to 5242'& cemented w/ 140 sx at shoe + Liner Lap sqzd 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, Rick Rowland Land & Natural Resources Manager Tyonek Native Corporation (907) 646-3121 Direct (907) 272-0707 Main rrowland@tyonek.com www.tyonek.com ,r T one 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 STATE OF ALASKA LIVED KA OIL AND GAS CONSERVATION CSION • REPORT OF SUNDRY WELL OPERATIONS " ` 2018 1:Operations Abandon Li Plug Perforations U Fracture Stimeate U Pull Tubing LI e-: ._ Pr " s dgwn U Performed: Suspend ID Perforate U Other Stimulate 11:1 Alter Casing Q Change Approved Program E Plug for'Redrill El Perforate New Pool El Repair Well El Re-enter Susp Well❑ Temporary Plug El , 2.Operator Aurora Gas,LIG 4.Wed Class Before Work: 5.Permit t Dolt fashber. Name: Dever 0 Ear D 178-047 3.Address: 3705 Arctic Blvd.#2114 Anchorage,AK 99503 Stratigraphic Q Service 9'.;6.API Number: 283-20060-00 7.Property Designation(Lease Number): 8.Well Name and Number: C-061390 Simpco Moquawkie#1 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: ."Totatflepth measured f66 feet ?,b gs .measured. f..OJ1:R.` 174 feet true vertical 6166 feet Junk measured None feet 'Efferitive Depth measured 2974 'feet 'Parker measured 2778 fleet true vertical 2974 feet true vertical 2778 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81 •13.7/8 61#:156 •81 :8t 3090 psi 1640 psi • Surface 847 9 5/8 32#H40 847 847 2270 psi 1400 psi . Intermediate Production 31111 7 2f4 K44; 31111 3111 3740 psi i 3270 psi Liner , Perforation depth Measured depth 2847-2974 feet cee Veu is i depth k7-_2971 Tit • Tubing(size,grade,measured and true vertical depth)h) 2 7/8 6.50 N180 2835 2835 }Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED i°, 3;, :03:6-s Treatment descriptions including volumes used and final pressure: ' NA 13. Representative Daily Average.Production or nnectien Data Oil-Bbl F Gas-Mcf ' Water-Bbl Casing Pressure i Tubing Pressure , Prior to well operation: 0 0 560 Subsequent to operation: 0 0 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory D Development El. 9 Stratigraphic 9 Copies of Logs and Surveys Run D 16.Well Status atter work: Oil D Gas 9 WDSPL D II Printed and Electronic Fracture StimulationData ❑ GSTOR WINJ 9 WAG C7 GINJD 3USP'U SPLUG U 17.1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry or N/A#C.O.Exempt p 317-282 Authorized Name: George Pollock Contact Name: Authorized Title: Prod Ops&Eng Contact Erna*:gpollock( aurorapower.ci .rte' Authorized Signature: /"`.`. �✓�-______.-� Dab 1/23/2018 Contact Phone: 907.351.8286 ,11— y1 ? Form 10-404 Revised 4/2017 ,r r, j!-,'! 2 t. 2010 Submit Original Only • • Autmta=Gas. ILC Operations Summary—Set Temporary Plug Simpco Moquawkie #1 Well July-71,2017 fr 15(10 hours R/LT WL,PT lubricator w/wellbore 1545 hours RIH w/2.4" brush to 2766' KB,brush profile, POOH 1630=hours -KM w/Baper=BWG-Klug=to 2766','NW,Shear-pin,= .g{au -i atr n=pl rset 1715 hours RIH w/2.5" SB to 2766', could not latch, POOH 1745 hours Bleed off well,shut in well overnight 1800 hours Mob to camp ju4y2Z42017 0600\hours Mob to location 0645 hours Well built up to 10 psi overnight,bleed & monitor 30 minutes 0715=hours Treasure=10 ps ,plug=nmt=holding,=RN WL 0730 hours RIH w/2" SB to 2766',WT, could not latch, POOH, OOH not sheared 0800 hours w/same w/knuckle K ins above to 2766',WT,latch Prong, POOH 0845 hours RIH w/same w/releasing Prong to 2766',WT, latch Plug, POOH, OOH =w—Pluu, observeadamaged paekin_g 0930 hours RIH w/Baker FWG Plug to 2766',WT,set Plug, POOH 1030 hours Bleed.off wet,inonitorimessinefor 30 minutes, Pass 1100 hours R/D WL,move to SM2 - ! II _sIMPco-lwOQUAWKIE NO.I WELL BORE DIAGRAM ;,,,,,,,I:Fi.:{4 ;',!i.. -,, i:::::i: ,t :,.: k 13-3/8", 61#, J-55 Conductor trivn-t 1' { 9-5/8", 32.3# H-40 Surface Casing set at 847', cemented to surface 1.315"J=56.Heater String to 924" 7"DV Toot at 1640"--300 sx cement 2-7 8"6:5#; F-80E_UE Tubing Test Pens at :jY 1950-80' (DST#9) � ' 2122-25'&2127-46'{DST#8) i.;!1.; , 2426-31' &2436-56' (DST#7) Slidinng Sleeve at 2766' (all squeezed w/25-75 sx cmt) w/2.25" 'F' profile Baker FWG-Plug r� 2770' t i may`: .. =Baker FB"Packer=at 2778' till witm of tubing Sea s of 2786' Tyonek"Moquawkie" Production Pedis �a 2.197" No-Go Seating Nipple 2847-2860! „',.,' ,,, . at 28287w/2.25" 'F' profile old 2864-2868 2860-70' new :. , R Btm of Packer Seal Bore/Stinger 2870-2877 2873-83' _ ry at 2835' Test Perfs at 2912-34', 2957-74' (.DST#5) {DST#4) ' (Squeezed w/2'.5&50 sx Gnat) ,2` .z,,� 'bSV Retainer•at 2974' 3011-41' (DST#3) p w/35 sx cement below k X44' 7”, 20#,K-44 Production Casing :F$4-11.1:, set at 3110.76', ranted w/ Multiple bridge plugs, cement plugs, ; �r 300 sx at shoe &sqz penis in 5" +junk ¢ Test Perfs at: 3850-60' (DST#2) 5" 18# Production Liner set 502840"-{DST-#1) 3Q5t?`_to- "-&cerenrfw/ -,,114, 4' �k ttMS: r. 445 sx <,t Drilled,to TD of 6166' 10/28/2007 VOF T,t • 91 \��� yy�� THE STATE Alaska Oil and Gas ti•—s Le cKA Conservation Commission tx 333 West Seventh Avenue k.'11 ei GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 �'_ Main: 907.279.1433 FALAS Fax: 907.276.7542 www.aogcc.alaska.gov George Pollock ��® NovU 6 2.017, Manager Aurora Gas, LLC 1400 W. Benson Blvd., Suite 410 Anchorage, AK 99503 Re: Moquawkie Field, Undefined Gas Pool, Simpco Moquawkie 1 Permit to Drill Number: 178-047 Sundry Number: 317-436 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, Hollis S. French Chair kl DATED this 21 day of September, 2017. RBDId9S L L OCT - 3 2017 III ,,,,ce� RECEIVED `SCi' ci\ial STATE OF ALASKA SEP 14 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATM FOR SUNDRY APPROVALS G CC 20 AAC 25.280 1.Type of Request Abandon ❑ Plug Perforations E Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate Q Pull Tubing ❑ Change Approved Program❑ srnPlug for Redril ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other.Temporary Plug ❑ 2.Operator Name: 4. Wen Class: 5.Permit to Drill N 1 1 15 ea T Aurora Gas,LLC , Exploratory ❑ Development ❑. /7$-'dye Aug-73 3.Address: 1400 W.Benson Blvd.Suite 410 roliftraPtlic ❑ Bence ❑ `6.API Number: Anchorage,AK 99503 50-283-20060-00 7.If perforating: 8_Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PI Pr Simpoo Moquawkie#1 ' Will planned perforations require a spacing exception? Yes ❑ No 6 'J 9.Property Designation(Lease Number): 10.Field/Pool(s): C-061390 I FF€ Moquawkie Undefined Gas - 11. PRESENT WELL C OMDCOOft SUMMARY .. Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6166' - . 6166' . 2974' • 2974' 650 psi 2828"&2974' None Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 13 3/&61#J55 81' 81' 3090 psi 1540 psi Surface 847' 9 518"3201140 847' 847' 2270 psi 1400 psi Intermediate Production 3111' 7"20#1(44 3111' 3111' 3740 psi 3270 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2847'-2974' . 2847'-2974' 2 7/8" 6.5#1180 2835' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker FB packer Baker FB packer @ 2778', 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ ❑ StroftgraPhic ❑ Development v Service 14.Estimated Date for TBD 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ Q WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS Q WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GHQ ❑ 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 Poftock George Pollock Contact Name: Authorized Title: Manager-P Ops Contact Email: gtool lock tc aurorapower.com ' Contact Phone: 907-351-8286 Authorized Signature: "..... i.�'°��--' Date: 9//14/2017 f4USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3f7-z/3 Cp Plug Integrity �1 BOP Test Q Mechanical Integrity Test ❑ Location Clearance Y`< Other: P `'t) e t- 0\CA 1-3e.• e...,.r C P ti I M t eil- P`A1 , Post initial%Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes ❑ No [( Subsequent Form Required: 10 —40-7 RBDIVIS i, Os,I — 3 20417 \'� , APPROVED BY Approved by: �'<, � R44L1 ? . .COMMISSIONER THE COMMISSION Date:Y1413FReed4/2017 Attadurents in Duplicate • • AURORA CAS LLC WELL ABANDONMENT SIMPCO MOQUAWKIE #1 September 2017 Version 1.0 (918/17) CURRENT CONOITONS: Max SITP-135 psi. KB=15 feet CASING: 7"20# K-55 set at 3111'MD/TVD. DV Tool at 1600' and EZSV Retainer set at 2974'=PBTD. Additional EZSV's set at 3792' (capped with 15 sx G cement) and at 5013'. TUBING: 2-7/8",6.5#N-80 8 rd EUE,w/diesel,as packer fluid in tbg-csg annulus above top packer and with: Sliding Sleeve: Baker Model L at 2778' with Type F 2.25"NG probe (closed—with d with retrievable plug set in profile); Packer: Baker FB-1 Retainer Production Packer w/Baker G-22 Locator Seal Assembly with 8 seal units and w/2.197"NG S/N with 2.25" F profile at 2828' and Mule Shoe Guide with end at 2835' HEATER STRING: 1.315" 1.8#J-55 10 Rd set at 924' in dual(2318") tubing hanger: (See attached completion diagrams) CAPACITIES: 2-7/8" 6.5# Tubing: 0.00579 bbl/ft; Tubing-Casing Annulus: 0.0325 bbl/ft; 7" 20# Casing: 0.0404 bbl/ft. Tubing Volume to Packer=16.1 bbl, Annular Volume to top Packer= 90.3 bbl; Volume to deepest Perfs=20.1 bbl OPEN PERFS: Carya 2-4 at 2847-833' (See wellbore diagram for the many test and squeezed perfs in the well,all,of which have been squeezed with cement) NOTES: 1) Well is a straight hole. SUMMARY OF PLAN: Unbolt heater string "tree"(in dual taking head),pick up with loader or boom truck,release from hanger,(cut or unscrew), and either drop to top packer or pull,whichever is easier(probably dropped).RU slickline. RIH and pull prong and plug at 2766'. Kill well with heavy brine leftover from previous P&A's. PU tubing CIBP, RIH and set near top of packer at 2778'. Test CIBP to 1500 psi. RIH with shifting tool on slickline and open sleeve at 2766'. 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 90 bbl is expected). Pump 10 bbl spacer, then 530 sx (610 cf=109 bbl) Class G cement with additives(15.8 ppg, 1.15 cflsk yield) with pump time of 4 hr at 75 degrees-3%excess and displace to surface—this one balanced plug is to meet the requirements of: 1)plug for perforated intervals,2)surface casing shoe, and 3) surface plug. Monitor for flow or fall • • back. Wash out tubing casing a .ulus to 3-4'below GL. WOC 8 Ins,pressuretest to 1500 psi. Bleed off pressure. MI,crane. Remove tree. Cut off casing,strings,and tubing 3-4'°below OL. 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. Co,.cuir. It( tveli bvc5 rlev.er 4vr 1'4h, SCC,e, 0K7 PROCEDURE: 1) Pick and move wellhouse.Notify AOGCC inspector of plans for plugging operations./ 2) Disconnect 1.315"heater string in dual (2-3/8") hanger. Pick up string with loader or boom truck (weight in air=1661#, will be less as it is in diesel). Disconnect from hanger(or cut) and allow to drop to top packer. Replace surface connection("tree") and valve to close. 3) Move in cementer(pump truck/mixer), bulk cement(550 sx Class G), slickline/electric line unit, water tank with 100 bbl fresh water for cementing,mud "pit"open tank for returns,and 100+bbl closed tank for diesel packer fluid, and 150 bbl clean brine from previously plugged well. RU cement pump to tree through wing valve. 4) RU slickline lubricator on tree. RIH and pull plug at 2766' KB. Allow pressure to equalize (expect maximum of 135 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. Allow tubing to stabilize,bleed off pressure. (Volume to deepest open perfs is about 20 bbl). 6) Run 2.25"gauge ring (GR)to check for fluid level and tag 2.197"NG S/N at 2828'. If restrictions are found, run bailer, brushes, etc. to cleanout to about 2800'. PU CIBP(running IIS less than 2.25", as have a 2.25"NG in sliding sleeve at 2766'). RIH and set CIBP near top of packer at 2778' (set below sliding sleeve at 2766'). POOH and pressure test CIBP to 1500 psi. 7) RIH with shifting tool. Open Baker Model L sliding sleeves at 2766'. POOH. 8) COMBINATION PLUG:RU cement pumper on wing valve of tree. Open casing valve(tubing- casing atikis)and pump LO bbl brine down tubing hin 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 530 sx Class 0 cement(accelerated for 4 hours pump,time at 75 degress,15.8 ppg, 1.15 cf/sk yield) down tubing, circulating cement to surface (3% excess). Catch diesel, brine, and spacer (separately if possible), the latter to use in subsequent wells. This is to be a balanced plug— monitor for flow or fall back. 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 casin sting or tubing to cut-off. Release cementers and slickline units to next location. CA.aI.-c -r; c . ® t,,,,p,, 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 n .mt�.�h PTD# 178-047 ` 4w ro arc��• CA3.w�� (7,‘A-r. e 'F Simpco Moquawkie No. 1Q a- P .AIX„ – �C �u.D� w�n r '-A-1 API# 50-283-20060-00 • • 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 (9/8/2017) • • AURORA GAS,LLC SMS 1VIOQU*WKKE';NO 1 PTD: 178-047 API#50-283-20060-00 CURRENT WELL BORE DIAGRAM Sept 2017 _ 300 sx G bulheaded down �� 7"X 9-5/8"annulus WI" k " 13-3/8 61#, 5-55 istv Conductor driven to 81.' • 12-1/4" Hole to 847'+ # 9-5/8", 32.3#H-40 Surface Casing �ti set at 847', cemented to surface 1.315"J-55 Heater String to 924" n Y; Est cement bottom: 1600-1900' 8-3/4" Hole to 3111'+ 7"DV Tool at 1600'--not used, could not circ so top job 2-718"6.5#N-80 EUE Tubing Test Perfs at "u 1950-80' Sqzd w/75 sx G 2122-46' Sqzd w/25 sx G 2426-56' Sqzd w/25 sx G Sliding Sleeve at 2766' w/2.25"'F'profile Baker FB Packer at 2778' -~ Btrn tubing Seals at 2786' Tyonek"MoquaWkie" Production?Pefs 2.197"No-Go Seating tstipple 2847-2860' at 2828'w/2.25"'F' profile Old 2864-2868' 2860-70' new Btm of Packer Seal Bore/Stinger 2870-2877' 2873-83' at 2835' Test Perfs at 2912-34', Sqzd w/20 sx G 2957-74' Sqzd w/50 sx G ESV Retainer at 2974'= PTD w/35 sx,cement beim Test perfs at 3011-41' Sqzd w/33 sx G k Test perfs at 3021-41` Sqzd w/50 sx G <..` 7", 20#, K-55 Production Casing, Sqzd perfs at 3000-02'w/40 sx G set at 3110.76', cememted w/ Sqzd perfs @ 3112-16'w/150 sx G 300 sx at shoe Squeeze perfs at 3830-33'sqzd w/15 sx EZSV at 3792'w/15 sx G on top Squeeze perfs at 3917-20" sqzd w/25 sx Test Perfs at: 3850-`60' ,(DST#2) Squeeze perfs at 4050-55"sqzd w/140 sx F7S'V at.5013' Test perfs at 5028-40'(DST#1) 5" 18#Production Liner set 6-1/8" Hole . 3050'to 5242'&cemented w/ Drilled to TD of 6166' 140 sx at shoe+ Liner Lap sqzd . . • AURORA GAS,LLC &MAPCO-MOQUAWKIE NO. 1 PTD: 178-047 API#50-283-20060-00 PROPOSED P&A WELL BORE DIAGRAM Sept 2017 2) Drop heater string to packer. 300 sx G butheaded down 7"X 9-5/8"annulus 13-3/8",61#,J-55 Conductor driven to 81' 12-1/4"Hole to 847'+ [ 9-518',, 32.3#H-40 Surface Casing set at 847',cemented to surface Est cement bottom: 1600-1900' 8-3/4"Hole to 3111'+ 7"DV Tool at 1600'—not used, could not circ so top job 924' 1.315"J-55 Heater String 2-7/8"6.5#N-80 EUE Tubing Test Perfs at _ 3)Open sleeve at 2766'and circulate 1950-80' Sqzd w/75 sx G 455 sx G cement to surface.. 2122-46' Sqzd w/25 sx G 1)Set CIBP in tubing at 2778' 2426-56' Sqzd w/25 sx G Sliding Sleeve at 2766' w/2.25"'F'profile Baker FB Packer at 2778' Btm of tubing Seals at 2786' Tyonek"Moquawkie"Production Perfs 2.197"No-Go Seating Nipple 2847-2860' at 2828'w/225"'F'profile Old 2864-2868' 2860-70' new Btm of Packer Seal Bore/Stinger 2870-2877' 2873-83' 2835' Test Perfs at 2912-34', Sqzd w/20 sx G 2957-74' Sqzd w/50 sx G ESV Retainer at 2974'=PTD w/35 sx cement below Test perfs at 3011-41' Sgzd w/33 sx G Test perfs at 3021-41' Sqzd w/50 sx G 7",20#,K-55 Production Casing Sqzd perfs at 3000-02'w/40 sx G set at 3110.76',cememted w/ Sqzd perfs.@ 3112-16'w/150 sx G 300 sx at shoe Squeeze perfs at 3830-33'sqzd w/15 sx EZSV at 3792'w/15 sx G on top Squeeze perfs at 3917-20"sqzd w125 sx Test Perfs at:3850-60' (DST#2) Squeeze perfs at 4050-55"sqzd w/140 sx EZSV at 5013' Test perfs at 5028-40'(DST#1) 5"18#Production Liner set 6-1/8"Hole . 3050'to 5242'&cemented wI Drilled to TD of 6166' 140 sx at shoe+Liner Lap sqzd IP yof T� • THE STATE Alaska Oil and Gas £ iel o e LAsKA Conservation Commission f1Z _ 333 West Seventh Avenue 1'�t J — Anchorage, Alaska 99501-3572 .� ., GOVERNOR BILL WALKER g ' Main: 907.279.1433 ALAS* Fax: 907.276.7542 www.aogcc.alaska.gov George Pollock Manager ® .JIJ+ 2 5Z , • Aurora Gas, LLC s�� 1400 W. Benson Blvd., Suite 410 Anchorage,AK 99503 Re: Moquawkie Field, Undefined Gas Pool, Simpco Moquawkie 1 Permit to Drill Number: 178-047 Sundry Number: 317-282 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, gp—Carf Hollis S. French Chair DATED this"4 day of July, 2017. RBDMS L\--JUL 1 1 2017 411 • RECEIVED STATE OF ALASKA JUN 16 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGGG, 20 AAC 25.280 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 Caswng ❑ Other Temporary Plug E. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Aurora Gas,LLC ' Exploratory ❑ Development ❑' 17 V- 01-i 7 ' 3.Address: 1400 W.Benson Blvd.Suite 410 Stratigraphic ❑ Service ❑ 6.API Number Anchorage,AK 99503 50-283-2906040 L. 7. If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? /u If- Sirnpco Moquawkie#1 , Will planned perforations require a spacing exception? Yes ❑ No 4Ns 9.Property Designation(Lease Number): 10.Field/Pool(s): C-061390 / Fa. Moquawkie Undefined Gas • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6166' - 6166' , 2974' , 2974' i 650 psi 2974' None Casing Length Size MD TVD Must Collapse Structural Conductor 81° 13 3/8"61#J55 81' 81' 3090 psi 1540 psi Surface 847' 9 5/8"32#H40 847' 847' 2270 psi 1400 psi Intermediate Production 3111' 7"20#K44 3111' 3111' 3740 psi 3270 psi Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 2847'-2974' , 2847'-2974' 2 7/8" 6.5#N80 2835' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ftr Baker FB packer Baker FB packer @ 2778' 12.Attachments: Proposal Summary ❑ Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0, 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 ❑ 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: Manager4.0rod Ops: ng Contact Email: abotiock aurorapower.com 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 l`7- 2.' 52. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: X I L MPt etkrt.f PtiAm.,7 QGr'S -' I,„t-; t,dl‘L`T CLU.kC2,CM1rv,ts FFy2. '� s►‘( ms iot-s Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS c '-JUL 1 1 2017 Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: 10_404 APPROVED BY �ry Approved by: COMMISSIONER THE COMMISSION Date: 't 1 01\(' i\/, FIs / O alGaLNAlialid mla 1111_7 , One i Setts i Form ane orm��L�eyrsgl�2017 for 12 months fro date of approval. gttachments;n Duplicate S • Aumra Gas, LL� June 16, 2017 CEI - Ms. Cathy Foerster, Chair JUN 1 6 211 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 AQGCC Anchorage, AK 99501 Re: Application for Sundry Approval—Set Temporary Plug Simpco Moquawkie#1 Well PTD #: 178-047 API #: 50-283-20060-00 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 not producing 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 2766' 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 r • SIMPCO MOQUAWKIE NO. 1 WELL BORE DIAGRAM • k 13-3/8", 61#, J-55 • 3, Conductor driven to 81' 1 9-5/8", 32.3# H-40 Surface Casing ;.:: : ,, set at 847', cemented to surface lorr WU 1.315" J-55 Heater String to 924" x Ve 7" DV Tool at 1600'--300 sx cement s 2-7/8"6.5# N-80 EUE Tubing Test Perfs at kr , 1950-80' (DST#9) : .. 2122-25' & 2127-46' (DST#8) 2426-31' &2436-56' (DST#7) F (all squeezed w/25-75 sx cmt) Slidinng Sleeve at 2766' ita kik fa wf 2.25"'F' profile PiP 10Baker FB Packer at 2778' . Btm of tubing Seals at 2786' Tyonek"Moquawkie" Production Perfs 2.197" No-Go Seating Nipple 2847-2860' for at 2828'w/2.25" 'F' profile old 2864-2868 2860-70' new t,t ,�, Btm of Packer Seal Bore/Stinger 2870-2877 2873-83' at 2835' Test Perfs at 2912-34', 2957-74' eli s (DST#5) (DST#4) (Squeezed w/25 & 50 sx cmt) 3�! 2i," - y a ESV Retainer at 2974' 3011-41' (DST#3) w/35 sx cement below 7", 20#, K-44 Production Casing ° set at 3110.76', cememted w/ Multiple bridge plugs, cement plugs, , 300 sx at shoe Pcg&sqz perfs in 5" +junk i r Test Perfs at: 3850-60' (DST#2) o- 5" 18# Production Liner set Ift-5028-40' (DST#1) � � �: . 3050' to 5242' &cemented w/ os-----,s,-,r _ 445 sx Drilled to TD of 6166' 10/28/2007 • 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 %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. .dyie Saua9e(6/11/2017) • • --- Aurora Gas, LLC 'i - ° i www.aurorapower.com C;S) May 27, 2011 ` `C1 1-1 Mr. Winton Aubert Alaska Oil and Gas Conservation Commission 333 W. 7"'Avenue, Suite 100 RECEIVE) Anchorage,AK 99501 MAY 2 6 2011 RE: Simpco Moquawkie#1 Maki ati&G Cow GefilMiSSI0/1 Ancnerage Dear Ms. Gay: This letter in duplicate originals transmits the data to you identified below, pursuant to Aurora 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 printed copy of each of the log identified below. Enclosed herewith: SCHLUMBERGER LOG Simpco Moquawkie#1 06-May-2011 (1 ea.) 1"=20' paper log and(1 ea.)PDS/LAS Graphic Data DC Reservoir Saturation Tool- Sigma GR/CCL/RST-Sigma 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, scow AUG 0 7 Bruce D.Webb Manager,Land and Regulatory Affairs RECEIVED AND ACCEPTED ;1:OVE DATA This_day of ,20_ BY: TITLE: 1400 West Benson Blvd.,Suite 410 •Anchorage,AK 99503 •(907) 277-1003 •Fax: (907)277-1006 6051 North Course Drive, Suite 200 •Houston, TX 77072 •(281)495-9957•Fax: (281)495-1473 XHVZE Imac. 'roject Well History File Cover This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. L ""~ ~' (~ 7./-~ Well History File Identifier Organizing ¢o,,;~ ~] [~Ac~lor ,tems~.,~'~) [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL~INDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) ~/ Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~)WINDY Scanning Preparation ,-~x 30 = ~;)~ BY: BEVERLY ROBIN VINCENT SHERY~INDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ~Z_~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: .~.~ YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPAN~CF~RE FOUND: BY; BEVERLY ROBIN VINCENT SHERYL MARIA FIN DYJ DATE; (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDI~:~.IAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO YES NO RESCANNEDB7; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /SI Quality Checked 12/10/02Rev3NOTScanned.wpd • • UNSCANNED, OVERSIZED MATERIALS AVAILABLE: ~~~FILE # ~~~Y "- / e~ ~ d ~ dGf C.d.!'~ ~~~C GC S~ ~. C~0 To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 !Fax (907) 276-7542 _ ~ ~ i.<, ~=%Au~ora C~aS, L _, www.aurorapower.com Alaska Oil and Gas Conservation Commission 333 W. 7"' Avenue, Suite 100 -, Anchorage, AK 99501 Attn: Mr. John Norman RE: Simpco Moquawkie #1 Simpco Moquawkie #2 Dear Mr. Norman: '~~~~ JQN '~ 200 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 d ~ ~_ ~~(~ d S~d'3 2-1/8" Power Spiral SPF 45 Degree Pendulu SCHLUMBERGER COMPLETION RECORD Simpco Moquawkie #2 2-1/8" Goex Tubing Cutter ; ~~f -D'~ ~f~fa 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 RECENED AND ACCEPTED ABOVE DATA ~(~~+.5e- t'~iuevkdO~-~ This ~ day of ~ , 2048. ~ ~ ~ L1,.t t ~~ '+- ~o~s ~ TITLE: f~a~v rc ( ~~°.-~ ~u!'C e.- ~- 1 6 ~ 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 ~~ t . _ ~, ', SARAH PALIN, GOVERNOR 1~isCli-7~ ®i~ij~A/l`~D~i~~~ST 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQA`rIO1~T Cli~it~~-~1111~ ;'~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bruce Webb Manager, Land and Regulatory Affairs Aurora Gas, LLC 2500 City West Blvd., Suite 2500 Houston, TX 77042 ~~~r~~~~~~ ~~~~ ~ ~ 20~~ Re: Moquawkie Gas Field, Moquawkie Undefined Gas Pool, Simpco Moquawkie # 1 Sundry Number: 307-333 R. Dear Mr. Webb: As discussed today, you have approval to clean out and test the above mentioned well. The production test shall be limited to under six hours. A spacing exception is needed to allow regular production from the planned perforations since the same interval is open in Moquawkie # 1 (203-069) at a lateral distance less than 3000'. See 20 AAC 25.055 (a)(4). 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 for 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. incerely, s Daniel T. Seamount, Jr. Commissioner DATED this 2nd day of November, 2007 Encl. ( ~ • tiAurora Gas, LLC www.aurorapower.com November 2, 2007 John K. Norman, Chairman State of Alaska Oil and Gas Conservation Commission 333 W. 7t1i Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry Approval Reconsideration Simpco Moquawkie #1 Well Additional Perforations /Production Dear Mr. Norman: ~~ Ala~lsa ~NI $~ Gas Con,, Ct~tr~missor~ Anchor~Q® Aurora Gas, LLC (Aurora) is in receipt of the conditional sundry approval for the above mentioned well. The approval allows Aurora to complete the perforating procedures outlined in the Plan dated October 30, 2007. However, the Commission has determined that a spacing exception is required and the approval restricts the ability of Aurora to clean-out or test the well, and does not allow for the completion and regular production. Based on additional supporting documentation and written arguments, Aurora respectfully requests reconsideration of the Commission's 20 AAC 25.055 (a)(4) determination dated November 1, 2007, and further requests a re-determination of the spacing exception requirement to allow the perforation, cleaning, flowing, testing, completing and regular production of the Simpco Moquawkie well.. The procedures proposed by Aurora for the Simpco Moquawkie #1 well are essentially identical to the procedures the Commission approved entirely on the Simpco Moquawkie #2 well, dated October 31, 2007. Because of the close proximity of the wells, the availability of the necessary equipment and the transportation and lodging of required personnel, it would be advantageous for Aurora to complete as much of the proposed procedures as possible on the Simpco Moquawkie #1 well, concurrently after the work on the Simpco Moquawkie #2 well.. Another important aspect for consideration is that in order to give the well the best possibility of being productive, it is necessary to clean out the perforating debris by flowing the well. If the perforating debris is not immediately cleaned out and the well is shut-in, we run the risk of having the perforations plug-up or the formation sands to be adversely affected. 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 • John Norman. AOGCC November 2, 2007 page two Lastly, because of the timing of the year, Aurora needs to flow test the well to determine if it has the potential to be commercially productive. If the well is commercially productive and additional equipment is required to be barged to the west side of the Cook Inlet for the installation of the production facilities, we will need to do so before the inlet starts being blocked by ice. If we are required to wait and test the well after the spacing exception is approved, it would result in the transportation of any barged equipment to be done in late December, and the Cook Inlet ice might prohibit such a delivery. Therefore, if the Commission is not able to grant a waiver of the spacing exception, Aurora alternatively requests the subject sundry approval to allow for the cleaning-out, flowing and testing of the well. If the well is determined to be commercial, we can then begin the installation of the surface production facilities while awaiting approval of the spacing exception needed to allow for the regular production from the well. Aurora appreciates the Commission staff's continued consideration of the proposed Simpco Moquawkie #1 well work. We hope the additional information, arguments and logistical considerations are adequate to compel the Commission to approve the sundry application without conditions, or alternatively, to approve everything in the sundry application except allowing for regular 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 ~~ ~ ~ ~ d~ ~~~i ~,~~ ~...:J ~ ~• ~( ~~`u ~ ~ SARA ~' 1.1 ` ~ ~ ~~ H PAUN, GOVERNOR COI~SLB~QA~,1'IOH n ~ I~-~ 333 W 7th AVENUE, SUITE 100 •~ ii l~o~~`~~•iiiiii~~`iiiiii---777 Q.-~ ANCHORAGE,.ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bruce Webb Manager, Land and Regulatory Affairs Aurora Gas, LLC 2500 City West Blvd., Suite 2500 Houston, TX 77042 ~~~~~ N 0 ~ ~ ~ 2007 Re: Moquawkie Gas Field, Moquawkie Undefined Gas Pool, Simpco Moquawkie # 1 Sundry Number: 307-333 ~µ~. 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. A spacing exception is needed to allow production from the planned perforations since the same interval is open in Moquawkie # 1 (203-069) at a lateral distance less than 3000'. See 20 AAC 25.055 (a)(4). Oral approval to proceed with the perforating was given by Commissioner Foerster on October 31, however NO PRODUCTION is authorized until the spacing exception is granted. 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 for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this lett or the next working day if the 23rd day falls on a holiday or weekend. A erson may not appeal a Commission decision to Superior Co:~~~~tr~s'' ighe ng has been requested. J~ DATED this ~ day of November, 2007 Encl. ~ ~~ ,c~ i STATE OF ALASKA "` ~~ ~ ~~~ u~~ ALA A OIL AND GAS CONSERVATION COM ION ~o (~~ ~ C T ~ ~~07 APPLICATION FOR SUNDRY APPROVALS~~~~., ~1 ~~~1~ 20 AAC 25.280 ~r__i._ na o. r__ n_. 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate0 Waive ~ Othe Altercasing^ Repair well ^ Plug Perforations ^ Stimulate^ Time Extension^ Ancharage Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: AURORA GAS LLC Development ^ Exploratory ^ 178-047 3. Address: Stratigraphic ^ Service ^ 6. API Number: 2500 City West Blvd., Suite 2500, Houston, TX 77042 50-283-20060-00 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 Q Simpco Moquawkie #1 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): CIRI Lease # C-061390 465' AMSL DF Moquawkie Undesi Hated 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): 6,166" 6,166' 2,974' 2,974' EZSV 2974', 3792', 5013' none Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 13-3/8" 81' 81' 1,530 psi 520 psi Surface 84T 9-5/8" 84T 84T 3,580 psi 1,580 psi Intermediate Production 3,111' 7" 3,111' 3,111' 3,740 psi 3,270 psi Liner 2,192' 5" 5,242' 5,242' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2847-2860', 2864-2868' and same 2-7/8" 6.5 #, unkn 2,834' 2870-2877 Packers and SSSV Type: Baker FB-1 Retainer w/ Sealbore asmbly Packers and SSSV MD (ft): 2,778' MD no SSV 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: October 31, 2007 Commencing Operations: Oil ^ Gas^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: ~ WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: ~ , l--pt~C~~c~~- \O ~ 3 \" ~ ~ ~ 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 l b /~ ~~"7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: V ~ -~ 3~ i Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~(t~~ C:Qr~~c'O~ ~V1 Q~`~fc.~~ ~ C a~ (~~~5 ~a~~ `~~RL~N~ ~X~~~ \ ~Q ` EE~E~ SF F COVQr ~cc~C r. ~ Subsequent Form Required: ~~~ APPROVED BY A roved b : COMMISSIONER THE COMMISSION Date: / ~ pp y V ~/ ./~~%°~~ ~ R I NA L ~~~t ~,i~.tf ~ ~~~ Form 10-403 Revised 06/2006 ~ Submit ~n Duplica IOt1 ~Aurrora Gas, LLC www.aurorapower.com October 30, 2007 John K. Norman, Chairman State of Alaska Oil and Gas Conservation Commission 333 W. 7~' Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry Approval Simpco Moquawkie #1 Well Additional Perforations /Production (2,873'-2,883' and 2,860'-2,870' MD) Dear Mr. Norman: ~~~~~ acr ~ o zoo? ~~as~ka pil Gas Cons. Corrmissio~t Anchorage Aurora Gas, LLC (Aurora) hereby requests approval to allow for additional perforations and subsequent production from certain stratigraphic intervals for the Simpco Moquawkie #1 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. Specifically, Aurora seeks permission from 2,873' to 2,883' MD and from 2,860' to r 2,870' MD to allow production from the Carya 2-4.2 sands. Aurora also plans on producing from the other three 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, :~ 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 #1 ADD PERFORATIONS and TESTING PROCEDURE (Version 1.2) CAPACITIES: 2-7/8" Tubing: 0.00579 bbl/ft and 7", 20# Casing: 0.0404 bbl/ft KB= 12.4' (all depths from KB). OPEN PERFS: 2847-60', 2864-68', 2870-77' PBTD: EZSV Retainer at 2974'. SQZD PERFS: 29T2-34', 2957-74' RESTRICTIONS 1N TUBING: Tubing ID=2.441" (2.347" drift dia.), Sliding Sleeve at 2766'-2.25" ID `F' profile (to annulus-DO NOT OPEN), No-Go Seating Nipple w/ `F' profile at 2828'-2.25" ID WELL STATUS: Non-producing well, currently shut-in (suspended). 1) MI and RU Aurora Gas test unit: connect to 2" LPT collar downstream of wing valve, flow tee, and cage nipple crossing over to 2" 1502 hard line to tie in choke skid, test separator, and flare stack, as per Note 1 below. When setting up test unit, leave plenty of room around wellhead for crane truck and perforating unit. 2)) Move in Schlumberger electric-line unit, lubricator, and grease injection skid and crane truck. 3) Hold pre-job Safety Meeting w/ all parties involved. 4) Obtain and record pressure on well-expected to be about 710 psi. 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 2-1/8" gun with Power Spiral EnerJet (14.5 g HMX charges, 6 SPF) w/ gun GR/CCL. b) With gun in lubricator and lubricator flanged up, pressure test lubricator, then flow line, and hard line to AG choke manifold to well pressure (700+psi) for 10 minutes-record test pressure and time. c) Open well (swab and master valves) and RIH w/ GR/CCL/10' perf gun. Run correlation log from 2974 to 2000'. Correlate to open-hole GR log on CNL/FDC Log of August 1978. (Lots of coals to correlate to-also should see old perfs on CCL). d) Pull guns up into tubing. Bleed off well pressure thru test unit to 500 psi. e) Drop guns/tool down, correlate to CCL, and perforate the Carya 2-4.2 sand at 2873.-83' (expected surface pressure w/o water in hole-710 psig); record pressures before and after perforating. f) POOH (under pressure) lay down spent gun. g) Pick up 15' gun (11' of charges) and repeat Steps 5. b (except to test only lubricator), 5. d-f above, except perforate the Carya 2-4.2 sand at 2860-70'. s • 7) SI well (master and swab valves). RD and release Schlumberger. 8) Prepare for test: a) Take and record initial measurements of brine level the tank, if any; b) Record test separator water meter reading; c) install new chart on Barton recorder; d) install fresh nitrogen bottle onto skid for instrumentation; e) install Pollard SPIDR surface pressure recorder near test head, isolated with needle valve (upstream from valve that will shut in well for buildup-will want it to record and show SI pressures), and f) confirm electric clock on chart recorder is on and set to 12 or 24 hrs and chart is appropriate for clock time. 9) Open well and flow test until clean and stable, as follows: a) if well does not kick off, RU Pollard and swab in, when well kicks off to flow and is flowing strong, RD and release Pollard ; b) when significant gas is at surface (whether swabbing or flowing) or the well is flowing, divert flow to test separator: i) shut down momentarily to light flare stack, then bring back on, adjusting choke size until well is flowing strongly to cleanup, but holding significant back pressure on it (probably start at 24/64's and adjust accordingly, target flow at 75% of SITP (expect SITP to be 700 psi, so target stabilized flowing tubing pressure above 525 psi). ii) Flow until rate and pressure have stabilized for 15 minutes (i.e., pressure on SPIDR changes less than 2 or 3 psi in 15 minutes, increasing slightly is OK, but dropping is not-wait until fluctuations tend to be up, not down) and water rate has stabilized . Flow for a minimum of 4 hours, depending upon water production and cleanup. iii) Test meter: If red chart reading is below 3, change to smaller orifice; if it is above 8 change to larger orifice. Orifices may be changed by experienced operator while flowing w/the Daniel Sr. orifice fitting. iv) Catch water samples (downstream of test separator) near end of test. c) SI for pressure buildup (at least 2 times longer than flow period or until pressure is building at less than 1 psi/15 minutes, on SPIDR). 10) SI and secure well. RD test unit and prepare to flow to facility. NOTE: 1)) RU AG test unit as follows: a) lay 2-inch AG 1502 hard line from 2" NPT well head connection downstream of wing valve to choke manifold to test choke skid-use 2" 1502 target tees upstream of choke skid; b) set choke manifold close to well head and insta1128 to 32/64" (smallest of these available) positive choke in manifold (left side); c) run AG 2" 1502 hard line from choke manifold to test separator; d) set flare stack 100' or more from the well and 100' of more away from trees and raise stack; and e) lay AG 3" 1502 hard line from separator skid to flare stack, and connect propane bottle to flare stack. Ed Jones 10!25/07 t SIMPCO MOQUAWKIE NO. 1 WELL BORE DIAGRAM • Conductor driven to 81' 8", 32.3# H-40 Surface Casing set at 847', cemented to surface 1.315" J-55 Heater String to 924" V Tool at 1600'--300 sx cement 2-7/8" 6.5# N-80 EUE Tubing Test Perfs at 1950-80' (DST #9) 2122-25' & 2127-46' (C 2426-31' & 2436-56' (C (all squeezed w/ 25-75 Tyonek "Moquawkie" Production Pf 2847-2860' 2864-2868' 2870-2877' Test Perfs a 2912-34', 2957-74' (DST#5) (DST#4) (Squeezed w/ 25 & 50 3011-41' (DST #3) Multiple bridge plugs, cement plugs & sqz perfs in 5" + junk Test Perfs at: 3850-60' (DST #2) 5028-40' (DST #1) Slidinng Sleeve at 2766' w/ 2.25" 'F' profile Baker FB Packer at 2778' Btm of tubing Seals at 2786' No-Go Seating Nipple at 2828' w/ 2.25" 'F' profile Btm of Packer Seal Bore/Stinger at 2835' ` Retainer at 2974' w/ 35 sx cement below !0#, K-44 Production Casing set at 3110.76', cememted w/ 300 sx at shoe 6# Production Liner set 3050' to 5242' & cemented w/ 445 sx ~d to TD of 6166' • Note to File Simpco Moquawkie No. 1 PTD 1780470 Request Aurora wishes to place additional perforations in the Simpco Moquawkie No. 1 well within the Carya 2-4.2 sand (Tyonek formation) from 2860' to 2870' MD and 2873' to 2883' MD. Aurora wishes to perforate these sands this weekend as a Schlumberger perforating unit will be available for a short time. Problem The Carya 2-4.2 sands are open in Simpco Moquawkie No. 1 and in Moquawkie No. 1, which lies 2800' to the south. Per 20 AAC 25.055 (a)(4), a spacing exception is required because Simpco Moquawkie No. 1 lies within 3000' of Moquawkie No. 1, and the Carya 2-4.2 sand will be open to both wells. Recommendation Because this is an "emergency" situation, the Commission should grant provisional approval under the following conditions: 1. Regular production from Simpco Moquawkie No. 1 shall not commence until a spacing exception is approved by the Commission. 2. Aurora bears all responsibility for any protests to the spacing exception that may occur. 3. All Aurora operations will be conducted in conformance with Commission regulations, including the spacing requirements of 20 AAC 25.055. O W QUAWKIE 1 MPCO E MOQU WKIE 1 ~-:;~,r~r~~ -®SIM CO M QUAWKIE 1 MOQUAW IE 4 O O U KIE 3 OQUAW MOQUAWKIE 2 SIMPCO MOQUA KIE ~` '" • • Discussion Aurora is the only operator and owner within the area affected by these operations. CIRI is the only affected landowner. The Moquawkie No. 1 well (PTD 1650120) was originally drilled during 1965, and completed in two zones, a upper one from 2735' to 2765' MD, and an lower one from 5345' to 5365' MD. The lower zone was not capable of sustained production because of hydrates and water production. However, the upper interval, the Carya 2-4.2 sand, was used as a source of gas for the village of Tyonek until February 1970, when the well was shut in due to excessive water production. Moquawkie No. 1 was plugged and abandoned during December 1970. The Commission reviewed the abandonment in 1995 and judged it to be adequate. Simpco Moquawkie No. 1 was drilled and completed during 19?8 (PTD 1780470). At that time, the Carya 2-4.2 sand was perforated, tested at a rate of 2.5 MMCFPD, and shut in. Aurora re-entered and re-completed Moquawkie No. 1 during the fall of 2003 (PTD 2030690}. At this time, they perforated the Carya 2-4.2 and several surrounding sands. My review of the permit to drill application mentions the nearby Simpco Moquawkie No. 2 well, and how a spacing exception is not required with reference to that well. But it does not mention the Simpco Moquawkie No. 1, which is an oversight on my part. Moquawkie No. 1 was placed an regular production in November 2003, and it continued to produce until July 2005, when it was shut in because sand plugged the surface facilities and damaged the compressor. Several attempts were made to put the well back on production through a sand filter, but failed when the well loaded up and died. During September 2004, Aurora conducted well test operations to evaluate the open perforations in the Carya 2-4.2 sand within Simpco Moquawkie No. 1 for pressure and for flow potential. The Commission's approval for these test operations was granted in Apri12003, and the Commission did not require a spacing exception. This was again an oversight on the part of the Commission. In January 2005, Aurora reported to the Commission that Simpco Moquawkie No. 1 is incapable of flowing commercial quantities of gas, and the well was shut in pending further evaluation. On the afternoon of October 30, 2007, Aurora submitted a sundry application to perforate the Carya 2-4.2 sands in Simpco Moquawkie No. 1 and begin production from that sand and several other nearby Tyonek sands that have existing perforations. On October 31, 2007, Aurora submitted arguments as to why a spacing exception should not be required to perforate and produce Carya 2-4.2 in Simpco Moquawkie No. 1. Their main points are: 1. Schlumberger perforating units rarely are available on the west side of the Cook Inlet. 2. The have a short time frame available for perforating the well. 3. The sands are currently open in both Simpco Moquawkie No. 1 and Moquawkie No. 1, and Aurora is simply adding additional perforations. 4. Casing damage in Moquawkie No. 1 precludes further production from the Carya 2-4.2 sand in that well. • 5. Tests of the Carya 2-4.2 in Simpco Moquawkie No. 1 were not commercial during 2004, but Aurora is trying to maximize recovery from the Carya 2-4.2 by using Simpco Moquawkie No. 1 since they cannot produce it in the Moquawkie No. 1 well. 6. If they can't perforate the sands now, they may never do it. It should be noted that this "emergency" is entirely due to the short time period between submittal of the application and the planned operation (application submitted yesterday afternoon, and approval is desired today). Conclusions 1. Approval will not result in the waste of hydrocarbon resources, and it will not jeopardize correlative rights. 2. A spacing exception must be acquired prior to regular production. Past mistakes don't justify further mistakes. 3. Conditional approval of the perforating operations will enable Aurora to take advantage of Schlumberger's perforating unit, which is available for only a short time. 4. Increased vigilance is needed at the Commission and within Aurora to ensure that all completion and perforating operations conform to 20 AAC 25.055. 5. This "emergency" would likely have been avoided if Aurora had submitted their Sundry App ' ion in a timely manner. Steve Davies October 31, 2007 MOQUAWKIE 1 MOQUAWKIE 3 SIMPCO MOQU.AVVKIE 1 2336 FNL 1704 FEL 2159 FNL 1728 FEL 424 FSL 1261 FEL TWP 11 N -Range 12 W - Sec. 1 TWP 11 N -Range' 12 W - Sec. 1 TWP 12 N -Range. 12 UU - Sec. 36 Produced Nov 2003 toJuly 2005 ~~~ Active producer since August 2005 a--~/,~ fi r ,~.,../z,~•~/a ,~. 4; .~I bwm Ycctvi '.ral ~1 ~ ~. I•III 4 ~fM.1' =m liin Hu ~ are _ . .,3 ;~11 Itl 1 :RT 1 Iw Irnu ~ IIII I~11 t INO ( {~, i ~ IWO ~` r G ~'~. .1771 ~ xm . :vo t - f ~ ~ - ~ ~ 1 ~7n y :+oo t.l ~ U=15611 ~V~ Tested non-commercial Jan 2005 .,1 ~~ ' I•~6fA (Itt1li ~IMI' , 11, ell no i,l W.v =n1 4 nlil l v u TLS:S AfA ., 1 ..1 1-• YII L ul• I(HII L 1111 11 II INO r [(`? - e 1 Pill `- y G _ ~~~ -~ 1 :no ~} c.~. ~~- T ~ f' } [ ~ :bo j7 l S ---_' i ~ ( ' -_'~ 1-. -- '7771 ~- i _~ ~ ~ ~_, r ~ _ c '1711 ~ _ ~ < ~ '~- '1 _ ~ ' c IQ~~ ~ 7' h,~~ ~ _..~ ~ r __ • `~y1 _1 • ~~ ~~~ id •3/• °? • • Page 1 of 1 Davies, Stephen F (DOAj From: Bruce D Webb [bwebb@aurorapower.com] Sent: Wednesday, October 31, 2007 11:23 AM To: Maunder, Thomas E (DOA); Davies, Stephen F (DOA) Subject: RE: SM #2 Tom and Steve, If there is something that I am not touching on in support of negating the spacing exception for the Simpco Moquawkie #1, and you think Ed may be able to clarify or furtherjustify this endeavor, he has indicated that he is available to discuss it at 713-977-5799. Thanks again, -Bruce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, October 31, 2007 10:20 AM To: Bruce Webb Subject: SM #2 Bruce, The sundry for this well is up front with the Commissioners. I gave Chas your cell # to call when ready. Steve is still looking at SM #1 to determine if there are any spacing issues. I understand that he has spoken with you. Tom Maunder, PE AOGCC 10/31 /2007 Page 1 of 3 Davies, Stephen F (DOA) From: Bruce D Webb [bwebb@aurorapower.com] Sent: Wednesday, October 31, 2007 11:18 AM To: Davies, Stephen F (DOA); Maunder, Thomas E (DOA) Subject: FW: Simpco Moquawkie wells Steve and Tom, In plotting out the Simpco #1 and Mobil Moquawkie #1 wells, it does appear they are only about 2800 feet apart However, as Ed has mentioned in # 2 below, although the same Carya 2-4 sands are open in the Mobil Moquawkie #1 well, there is casing damage that prohibits us from producing those sands in that well. Ed also states that we have no intention on producing those sands in that well, and that our most likely plan is to run a casing patch or liner and perhaps try producing the deeper Carya 2-7 sands sometime in the future. Aside from that, the perforations are already open in both wells for the Carya 2-4 sands, we are simply adding additional perforations in the same zone. Even if we did not add the additional perforations, the same sands in both wells would still be open, so adding additional perforations in the same sands really changes nothing that doesn't already exist. With that being said, we do not believe the Mobil Moquawkie #1 Carya 2-4 sands are "capable of producing from the same pool" [20AAC25.055 (a)(4)] as the Simpco Moquawkie #1 Carya 2-4 sands, even though both perforations are open, because of the casing damage. Additions-ly, we are stating for the record that we are not and do not expect to ever produce the Carya 2-4 sands in the Mobil Moquawkie #1 weN. Because we cannot produce the Carya 2-4 sands in the Mobil Moquawkie #1 well, we are attempting to maximize our recovery of that gas by adding perforations to the Simpco Moquawkie #1 well. Our goal is to try and increase production to help meet the winter gas demand of Anchorage... we just want to keep the lights and heat on. The Simpco Moquawkie wells are positioned in an opportune time because of the service equipment presently (and temporarily) on the west side. If we cannot do the work on this well now, we will likely never do it, as the Moquawkie #4 is a better candidate for next summer. Is the fact that the two wells are already open in the same sands, and have been for quite some time, and that there is casing damage prohibiting us from producing those sands in the Mobil Moquawkie #1 sufficient to negate the spacing exception requirement? If not, is an e-mail to the AOGCC requesting permission to do the well work, without production until the spacing exception is approved, sufficient application to the commission? We do want to take advantage of the limited window of opportunity for the service equipment. Thank you for your continued assistance and consideration -Bruce From: Ed ]ones [mailto:jejones@aurorapower.com] Sent: Wednesday, October 31, 2007 6:48 AM To: 'Bruce D Webb' Cc: 'G. Scott Pfoff; 'Chad Helgeson' Subject: RE: Simpco Moquawkie wells Bruce, You are on track. However, let me give you some additional considerations to mention to Steve: 1) The Schlumberger perforating unit has not been on the West Side of the Inlet since last Sept. or Oct.. It is there now; so we have a short window to do this work--it wilt be demobilized back to Kenai in a couple of weeks (after use by ConocoPhillips at Beluga). 10/31 /2007 Page 2 of 3 2} You correctiy state that the Simpc~Moquawkie #1's roposed erfs essentia e erforatin the same sand as now p p ( p 9 open in the wel#; a Carya 2-4 zone} are not open in the Simpco Moquawkie #2, which is open in and producing from 2 Carya 2-9 sands (we'll be just adding perfs to one of those currently producing sands in the #2). However, the ..obit oquawie 1 is open in the same sand s now open in the Si pco oawi 1. The 1, h®wever, has easing damage and has not produced or been tested since Irate last summer, nor do e expect t again produce that sand in it. ( e may run casing patch or liner and test the deeper, Carya .7 sand in it t Borne point in tune}, 3} This same Carya 2-4 sand, which is the original completion of the SM 1, was tested in 2003 or 2004 (the 4110103 Sundry) and was not commercial. No further work was done, except that the pressure of the well has been monitored. 4} 11Ve want to take this opportunity to test the SM 1 well, as we would like to have the gas to sell over the winter, since we did little other wark this year, However, if the tes# is successful, it will take some time to build the satellite facility and pipeline (we'll tie in to the Moquawkie facility--compressor and dehy}. If the test appears to be commercially successful, we can apply for the spacing exception with time for approval prior to being ready to produce (alternatively, we may want to classify the Mobil Moquawkie #1 as suspended or temporarily abandoned; if we can do so without any rig work). 5} The proposed Moquawkie #4 will not be drilled until next summer, It is expected to have lots of potential pay, including, probably, this same Carya 2-4 zone as in the Simpco Moq. #1. However, we have several optians there: a} we can not perforate the correlative sand in the #4, as we expect to have lots of other pay, and continue producing it in the Simpoo #1 (assuming it is commercial there), or b) if the 2-4 sand is of much better quality in the #4, after it is completed; we can shut-in the Simpco #1, as we do not expect to have a big investment in it and it's facilities (we could move them to #4) and only produce the #4. I hope that these are helpful in convincing thee AOGCC to allow us to do the work w/o an approved spacing exception Thanks, Ed From: Bruce D Webb [mailto:bwebb@aurorapower.com] Sent: Tuesday, October 30, 2007 8:55 PM To: Ed Jones Subject: FW: Simpco Moquawkie wells FYI From: Bruce D Webb [mailto:bwebb@aurorapower.com] Sent: Tuesday, October 30, 2007 5:53 PM To: Steve Davies (steve_davies@admin.state.ak.us) Subject: Simpco Moquawkie wells Hi Steve, I just got back to the office from a CIRI meeting and received your message regarding spacing exceptions 1n looking at the 20 AAC 25.055, it does not appear that (a) 2 would apply since we are not drilling a gas well -the well already exists and we are simply requesting to add additional perforations in the same strata that we already have perforations in, just expanding the vertical coverage. In (a) 4, it does appear that the Simpco Moquawkie #1 and #2 wells are closer than 3,000' (about 2,700' horizontally), but the closest perforations in the wells are 2,883' feet apart vertically and it is arguable that they are not capable of producing from the same sands. It should also be noted that the Simpco #1 had an approved Sundry Application to do repair work, perforate and test the well on 4/10/03 and that Sundry Application did not require a spacing exception. Also, welt work was done on the Simpco Moquawkie #2 (to pull plugs, test and put on production) that did not require a spacing exception and a report of Sundry Operations was filed on 1/26/06. Aurora is the lessee in all adjoining leases and the land and mineral owners are the same. There are no other lessees or other mineral or land owners within several miles of these wells. I believe a spacing exception application would bean inordinate waste of time and unwarranted, as there would be no benefit to any affecteded party in requiring one. 10/31 /2007 Page 3 of 3 If you disagree, and feel we must file~or a spacing exception because of the proxy of these producing and sus ended P welts, please let me know as soon as you get in (this morning of your receipt), as I need to let Ed Jones know and inform the field personnel. Thank you for your time and consideration on this. Respectfully, -Bruce 10/31 /2007 • ~ Page 1 of 1 Davies, Stephen F (DOA) From: Bruce D Webb (bwebb@aurorapower.comJ Sent: Wednesday, October 31, 2007 8:24 AM To: Davies, Stephen F (DOA) Subject: FW: Simpco Moquawkie wells Steve, Here are a few thoughts from Ed on our hopeful justification: -Bruce From: Ed Jones [mailto:jejones@aurorapower.com] Sent: Wednesday, October 31, 2007 6:48 AM To: Bruce D Webb' Cc: 'G. Scott Pfoff; 'Chad Helgeson' Subject: RE: Simpco Moquawkie wells Bruce, You are on track. However, let me give you some additional considerations to mention to Steve: 1) The Schlumberger perforating unit has not been on the West Side of the Inlet since last Sept. or Oct.. It is there now, so we have a short window to do this work--it will be demobilized back to Kenai in a couple of weeks (after use by ConocoPhillips at Beluga). 2) You correctly state that the Simpco Moquawkie #1's proposed perfs (essentially reperforating the same sand as now open in the well, a Carya 2-4 zone) are not open in the Simpco Moquawkie #2, which is open in and producing from 2 Carya 2-9 sands (we'll be just adding perfs to one of those currently producing sands in the #2). However, the Mobil Moquawkie #1 is open in the same sand as now open in the Simpco Moquawkie #1. The MM 1, however, has casing damage and has not produced or been tested since late last summer, nor do we expect to again produce that sand in it. (We may run a casing patch or liner and test the deeper, Carya 2-7 sand in it at some point in time). 3) This same Carya 2-4 sand, which is the original completion of the SM 1, was tested in 2003 or 2004 (the 4/10/03 Sundry) and was not commercial. No further work was done, except that the pressure of the well has been monitored. 4) We want to take this opportunity to test the SM 1 well, as we would like to have the gas to sell over the winter, since we did little other work this year. However, if the test is successful, it will take some time to build the satellite facility and pipeline (we'll tie in to the Moquawkie facility--compressor and dehy). If the test appears to be commercia{fy successful, we can apply for the spacing exception with time for approval prior to being ready to produce (alternatively, we may want to classify the Mobil Moquawkie #1 as suspended or temporarily abandoned, if we can do so without any rig work). 5) The proposed Moquawkie #4 will not be drilled until next summer. It is expected to have lots of potential pay, including, probably, this same Carya 2-4 zone as in the Simpco Moq. #1. However, we have several options there: a) we can not perforate the correlative sand in the #4, as we expect to have lots of other pay, and continue producing it in the Simpco #1 (assuming it is commercial there), or b) if the 2-4 sand is of much better quality in the #4, after it is completed, we can shut-in the Simpco #1, as we do not expect to have a big investment in it and it's facilities (we could move them to #4} and only produce the #4. l hope that these are he{pful in convincing thee AOGCC to allow us to do the work w/o an approved spacing exception. Thanks, Ed 10/31 /2007 • Page 1 of 1 Davies, Stephen F (DOA) From: Bruce D Webb [bwebb@aurorapower.com] Sent: Tuesday, October 30, 2007 5:53 PM To: Davies, Stephen F (DOA) Subject: Simpco Moquawkie wells Hi Steve, I just got back to the office from a CIRI meeting and received your message regarding spacing exceptions. In looking at the 20 AAC 25.055, it does not appear that (a) 2 would apply since we are not drilling a gas well -the well already exists and we are simply requesting to add additional perforations in the same strata that we already have perforations in, just expanding the vertical coverage. In (a) 4, it does appear that the Simpco Moquawkie #1 and #2 wells are closer than 3,000' (about 2,700' horizontally), but the closest perforations in the wells are 2,883' feet apart vertically and it is arguable that they are not capable of producing from the same sands. It should also be noted that the Simpco #1 had an approved Sundry Application to do repair work, perforate and test the well on 4/10/03 and that Sundry Application did not require a spacing exception. Also, well work was done on the Simpco Moquawkie #2 (to pull plugs, test and put on production) that did not require a spacing exception and a report of Sundry Operations was filed on 1/26/06. Aurora is the lessee in all adjoining leases and the land and mineral owners are the same. There are no other lessees or other mineral or land owners within several miles of these wells. I believe a spacing exception application would be an inordinate waste of time and unwarranted, as there would be no benefit to any affecteded party in requiring one. If you disagree, and feel we must file for a spacing exception because of the proximity of these producing and suspended wells, please let me know as soon as you get in (this morning of your receipt), as {need to let Ed Jones know and inform the field personnel Thank you for your time and consideration on this Respectfully, -Bruce 10/31 /2007 '~~ --~ '~C_~~~ ~~ i J ~' ~D~S l~L.~ ~ ~~ GiZ~:is Pa e 1 of 1 g ~-~ ~Z..'2 c'bt~~ ..! -~,~,~L `= /3~-iT~ "~-1 i S ~ l ~c_ /l~r o S~T" L I i` ~'Z- ~{ 3 C_ 6C~i2- G rl..(C. ~~ Y~~- ~ c~J~e~2-fit aN S '71~~t S ~~ ~ ~1~ C '~~.-~.i i S 'T~ S7'.~-- ~~~ Bruce D Webb '~~ o ~v~f ~ --7-~ ~ _ ~Ov ,~.m..u.,a.~W_~~,,, From: Ed Jones [jejones@aurorapower.com] 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; 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 set up 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. Friday--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) -Aurora Gas, LLC www.aurorapower.com October 30, 2007 John K. Norman, Chairman State of Alaska Oil and Gas Conservation Commission 333 W. 7~' Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Sundry Approval Simpco Moquawkie #1 Well Additional Perforations /Production (2,873'-2,883' and 2,860'-2,870' MD) Dear Mr. Norman: Aurora Gas, LLC (Aurora) hereby requests approval to allow for additional perforations and subsequent production from certain stratigraphic intervals for the Simpco Moquawkie #1 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. Specifically, Aurora seeks permission from 2,873' to 2,883' MD and from 2,860' to 2,870' MD to allow production from the Carya 2-4.2 sands. Aurora also plans on producing from the other three 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, Bruce D. Webb .Manager, Land and Regulatory Affairs attachments 10333 Richmond Avenue, Suite 71D • Houston, Texas 77042 • {713) 977-5799 • Fax (713) 977--1347 1400 West Benson Blvd., Suite 410 • Anchorage, A/aska 99503 • (907) 277-1003 • Fax (907) 277-1006 STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMi~N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate^/ Waive^ Othe^ Alter casing^ Repair well ^ P1ug Perforations ^ Stimulate^ Time Extension^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well^ ?.Operator Name: 4. Current Well Class: 5. Permit to Drill Number: AURORA GAS LLC Development ^ Exploratory ~ 178-047 3. Address: Stratigraphic ^ Service ^ 6. API Number: 2500 City West Blvd., Suite 2500, Houston, TX 77042 50-283-20060-00 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 Q Simpco Moquawkie #1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): CIRI Lease # C-061390 465' 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): 6,166" 6,166' 2,974' 2,974' EZSV 2974', 3792', 5013' none Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 13-3/8" 81' 81' 1,530 psi 520 psi Surface 84T 9-5/8" 84T 84T 3,580 psi 1,580 psi Intermediate Production 3,111' 7" 3,111' 3,111' 3,740 psi 3,270 psi Liner 2,192' 5" 5,242' 5,242' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 2847-2860', 2864-2868' and same 2-7/8" 6.5 #, unkn 2,834' 2870-2877 Packers and SSSV Type: Baker FB-1 Retainer w/ Sealbore asmbly Packers and SSSV MD (ft): 2,778' MD no SSV 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program Q BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 18. Well Status after proposed work: October 31, 2007 Commencing Operations: Oil ^ Gas Q 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 l ~ ~~ ~ "7 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: Subsequentform Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:. Form 10-403 Revised 06/2006 Submit in Duplicate • Aurora Gas, LLC SIMPCO MOQUAWKiE #1 ADD PERFORATIONS and TESTING PROCEDURE (Version 1.2) CAPACITIES: 2-7/8" Tubing: 0.00579 bbl/ft and 7", 20# Casing: 0.0404 bbl/ft KB= 12.4' (all depths from KB). OPEN PERFS: 2847-60', 2864-68', 2870-77' PBTD: EZSV Retainer at 2974'. SQZD PERFS: 2912-34', 2957-74' RESTRICTIONS IN TUBING: Tubing ID=2.441" (2.347" drift dia.), Sliding Sleeve at 2766'-2.25" ID `F' profile (to annulus-DO NOT OPEN), No-Go Seating Nipple wl `F' profile at 2828'-2.25" ID WELL STATUS: Non-producing well, currently shut-in (suspended). 1) MI and RU Aurora Gas test unit: connect to 2" LPT collar downstream of wing valve, flow tee, and cage nipple crossing over to 2" 1502 hard line to tie in choke skid, test separator, and flare stack, as per Note 1 below. When setting up test unit, leave plenty of room around wellhead for crane truck and perforating unit. 2)) Move in Schlumberger electric-line unit, lubricator, and grease injection skid and crane truck. 3) Hold pre-job Safety Meeting w/ all parties involved. 4) Obtain and record pressure on well-expected to be about 710 psi. 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 2-1/8" gun with Power Spiral EnerJet (14.5 g HMX charges, 6 SPF) w/ gun GR/CCL. b) With gun in lubricator and lubricator flanged up, pressure test lubricator, then flow line, and hard line to AG choke manifold to well pressure (700+psi} for 10 minutes-record test pressure and time. c) Open well (swab and master valves) and RIH w/ GR/CCL/10' perf gun. Run correlation log from 2974 to 2000'. Correlate to open-hole GR log on CNL/FDC Log of August 1978. (Lots of coals to correlate to-also should see old perfs on CCL). d) Pull guns up into tubing. Bleed off well pressure thru test unit to 500 psi. e) Drop guns/tool down, correlate to CCL, and perforate the Carya 2-4.2 sand at 2873-83' (expected surface pressure w/o water in hole-710 psig); record pressures before and after perforating. f) POOH (under pressure) lay down spent gun. g) Pick up 15' gun (11' of charges) and repeat Steps 5. b (except to test only lubricator), 5. d-f above, except perforate the Carya 2-4.2 sand at 2860-70'. • • 7) SI well (master and swab valves). RD and release Schlumberger. 8) Prepare for test: a) Take and record initial measurements of brine level the tank, if any; b) Record test. separator water meter reading; c) install new chart on Barton recorder; d) install fresh nitrogen bottle onto skid for instrumentation; e) install Pollard SPIDR surface pressure recorder near test head, isolated with needle valve (upstream from valve that will shut in well for buildup-will want it to record and show SI pressures), and f) confirm electric clock on chart recorder is on and set to 12 or 24 hrs and chart is appropriate for clock time. 9) Open well and flow test until clean and stable, as follows: a) if well does not kick off, RU Pollard and swab in, when well kicks off to flow and is flowing strong, RD and release Pollard ; b) when significant gas is at surface (whether swabbing or flowing) or the well is flowing, divert flow to test separator: i) shut down momentarily to light flare stack, then bring back on, adjusting choke size until well is flowing strongly to cleanup, but holding significant back pressure on it (probably start at 24/64's and adjust accordingly, target flow at 75% of SITP (expect SITP to be 700 psi, so target stabilized flowing tubing pressure above 525 psi). ii) Flow until rate and pressure have stabilized for 15 minutes (i.e., pressure on SPIDR changes less than 2 or 3 psi in 15 minutes, increasing slightly is OK, but dropping is not-wait until fluctuations tend to be up, not down) and water rate has stabilized . Flow for a minimum of 4 hours, depending upon water production and cleanup. iii) Test meter: If red chart reading is below 3, change to smaller orifice; if it is above 8 change to larger orifice. Orifices may be changed by experienced operator while flowing w/the Daniel Sr. orifice fitting. iv) Catch water samples (downstream of test separator) near end of test. c} SI for pressure buildup (at least 2 times longer than flow period or until pressure is building at less than 1 psi/15 minutes, on SPIDR). 10) SI and secure well. RD test unit and prepare to flow to facility. NOTE: 1)) RU AG test unit as follows: a) lay 2-inch AG 1502 hard line from 2" NPT well head connection downstream of wing valve to choke manifold to test choke skid-use 2" 1502 target tees upstream of choke skid; b) set choke manifold close to well head and install 28 to 32/64" (smallest of these available) positive choke in manifold (left side); c) run AG 2" 1502 hard line from choke manifold to test separator; d) set flare stack 100' or more from the well and 100' of more away from trees and raise stack; -and e) lay AG 3" 1502 hard line from separator skid to flare stack, and connect propane bottle to flare stack. Ed Jones 10/25/07 • • SIMPCO MOQUAWKIE NO. 1 WELL BORE DIAGRAM Test Perfs at 1950-80' (DST #9) 2122-25' & 2127-46' ([ 2426-31' & 2436-56' ([ (all squeezed w/ 25-7~ Tyonek "Moquawkie" Production Pe 2847-2860' 2864-2868' 2870-2877' Test Perfs a 2912-34', 2957-74' (DST#5) (DST#4) (Squeezed w/ 25 & 50 3011-41' (DST #3) Multiple bridge plugs, cement plug; & sqz perfs in 5" + junk Test Perfs at: 3850-60' (DST #2) 5028-40' (DST #1) Conductor driven to 81' 3", 32.3# H-40 Surface Casing set at 847', cemented to surface 1.315" J-55 Heater String to 924" V Tool at 1600'--300 sx cement Z-7/8" 6.5# N-80 EUE Tubing Slidinng Sleeve at 2766' w/ 2.25" 'F' profile Baker FB Packer at 2778' Btm of tubing Seals at 2786' No-Go Seating Nipple at 2828' w/ 2.25" 'F' profile Btm of Packer Seal Bore/Stinger at 2835' + Retainer at 2974' w/ 35 sx cement below ?0#, K-44 Production Casing set at 3110.76', cememted w/ 300 sx at shoe 8# Production Liner set 3050' to 5242' & cemented w/ 445 sx ed to TD of 6166' • • ~~~C ~~P~~,~1~j~S~~~1 _J~J iw Fes rhs ft7~~Pf:93~'1®tr s3~'t3iJr°.d in this fax is ranfs~e~rtla/ and/O~ pPyy~da9ed. ~~TfS r3~ » ,r,._r,^-~~ .- -- ra~sieyvec/ irrrteadlr/ /iy on/s the individual'rr~ rr,sd dente fed r ~ ~ ~~¢° ythis transr~ri±~al ,oa~e is nt9 o~ are hare6y n~~i~ed that ¢he irr~erded rscipier~¢ or a seprasantat»_ of .~z in of fhis fax mr the infarmagdon con¢ainsd fss~ein >> and raview, dissemir~ate~n ®r copy ~ ., 9rrar. pl9ase ima~ediata/y noti~~ tars s_r~rde~ b~ pPOh#.bites~. !f ~s~ liars ~sceived this fax i, ~_,__~.....~ »,~a return t~ras fax to the ssnda~ a` Ctrs a~~a~s add~ss'. ~ha'nk y~~. -., ~~~ ~3X `~' ~~~~ ~~ rom : ~1 ~1 c ~t,one ~~ ~a-~ ~c~~c ~ ~c~~1 ~~ Subject: _~~-` Gate: Pages (sn~tuding Message ~ ~~~ ~ ~ ~~ ~~~ ~ S ~ ~ v~ ~ ~C~ G~6.~ G. C~ ~~ `~aQ` ~` ~ E'er "~ C:~~~~C~J~.~ ~'~ ~ ~' ~ - 5 ®~2~~ ~~~ ,~~ 5~~~ ~S ~~~~ !~ ______~ .~~ :.,~~~ ~J ,-~~ r~Cet~t° 3~1r,,'-'Z ~3C~33 J~ ..3,<3 3'~y t7~~~;a' ,~ .... ~'~:s pax. ptaasz a~E nor assista,,::° a` 90T) X93-9223-__ ~~~~ JOB STATUS REPORT TIME 10/31/2007 16:36 NAME AOGCC FAX# 9072767542 TEL# SER.# BRO2J2502370 DATE,TIME 10/31 16:35 FAX NO./NAME 2771006 DURATION 00:01:07 PAGE4S) 03 RESULT OK MODE STANDARD ECM ) ) - ~ ... - ~- - II1II I."'^'" - - I. RECEIVED JAN 1 9 2005 Alaska Oi' & Gas Cons. Commission Anchorage -- - ....- - -.... E & P SERVICES, INC. January 10,2005 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Report of Sundry Well Operations: Simpco Moquawkie No.1 (PTD# 178-047) Dear Mr. Norman, On behalf of Aurora Gas, LLC, Fairweather E&P Services Inc. hereby submits the final well report which covers the current status of the Simpco Moquawkie No.1 gas exploration well. Well test operations were completed on Sept 14th, 2004. Please note that no well work-over operations were performed as approved under Sundry Approval # 303-115. A basic analysis was performed on the well for pressures and flow potential only. The well is incapable of flowing commercial quantities of gas at this time and is shut in pending further evaluation of results. Pertinent information included under cover of this letter includes the following: 1) 2) Form 10-404"Report of Sundry Well Operations" - 2 copies. Summary of daily well work and operations. If you have any questions or require additional information; please contact the undersigned at (907)258-3446, or Mr. J. Edward Jones, Executive Vice President of Engineering and Operations for Aurora Gas, LLCat (907)277-1003. Sincerely, F..Kf'rweather E&P~ervices, Inc. /7--- '\\/ i ¡ ,,/~ o/{\ i {"~MtL,.U,~~ Duane H."'V';~gen \ Project Engineer att: cc: J. Edward. Jones, Andy Clifford s (' Ú ~'\ Þ ~.. H::.: [; r: r, C, r",} F~ l., ') ['J n S, ' M/;-y.,J" ~6,," r C b tf t* c_, ,,¡,.; 2000 East 88th Avenue. Anchorage, Alaska 99507 . (907) 258-3446 . FAX (907) 279-5740 650 North Sam Houston Parkway East, Suite 505 . Houston, Texas 77060 . (281) 445-5711 . FAX (281) 445-3388 . ) STATE OF ALASKA ') ALASM OIL AND GAS CONSERVATION COMMI~SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED 1. Operations Abandon U Suspend U Operation Shutdown U Perforate U WaJ.v.e[ Other l:J Performed: Alter Casing D Repair Well D Plug Perforations D Stimulate D Time E~tM1:>r2=9 2005 Change Approved Program D Pull Tubing D Perforate New Pool D Re-ent"ffl~eDlri.~ell D ',"" ,. 2. Operator Aurora Gas, LLC 4. Current Well Class: 5. Permit ~o 1jrit7~r\1eå~. t..lJmmU~SlOn Name: Development D Exploratory 0 178-047 Anchorage 3. Address: 1400 West Benson Boulevard, Suite 410 StratigraphicD ServiceD 6. API Number: Anchorage, Alaska 99503 50-283-20060-00 7. KB Elevation (ft): 9. Well Name and Number: 465' RKB, Csg head 450' AMSL Simpco Moquawkie NO.1 8. Property Designation: 10. Field/Pool(s): C-61389 Exploratory 11. Present Well Condition Summary: Total Depth measured 6166 true vertical 6166 feet feet Plugs (measured) EZSV's 2974',3792' & 5013' Junk (measured) Effective Depth measured 2974 true vertical 2974 feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size MD TVD Burst Collapse 81' 3090 psi 1540 psi 846.94' 2270 psi 1370 psi 3110.76' 3740 psi 2270 psi 5242.05' 10140 psi 10500 psi 133/8" 61# J-55 9 5/8" 32.3# H-40 81' 846.94' 7" 20# K-55 5" 17# N-80 3110.76' 5242.05' Perforation depth: Measured depth: 2847' - 2860',2864' - 2868',2870'- 2877', 1/2" holes @ 2spf True Vertical depth: same Tubing: (size, grade, and measured depth) 2 7/8" 6.5# @ 2834' Packers and SSSV (type and measured depth) Baker FB-1 wI Sealbore assembly @ 2777.87' 12. Stimulation or cement squeeze summary: Intervals treated (measured): None, well was tested as is only. Well not commercial at this time. Treatment descriptions including volumes used and final pressure: R8DMS BFL JAN 2 0 2005 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 0 NIA 0 NIA 15. Well Class after proposed work: Exploratory D Development 0 ;>' '-4. ,,^-i'V'o~ ' Aft....A...J... 16. Well Status after proposed work: G OilD Gas 0 WAG D GINJ D WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: Contact A~~ J/. d.J<- h.,~...e.di.o- rd ~ ,.J IÏ!>, Printed ~" ~u.. . I/. d Title ~" I / "" ' " - , )r ~e. &. -.Ie. - j' -, - ¡/ '" c.:.... Sig~ure <k-I/ Ò.-.. r:~ E.f:r-"$-''', Phone Q07-.:ls-e-]'t4' ~ ~.:'\." ~vJ"....- "" C...-....~ '~ OR\G\NAL Oil-Bbl Tubing Pressure Prior to well operation: NIA Subsequent to operation: NIA 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service D Date I 0 - j~ '" -.1 ..::> ~S- Form 10-404 Revised 12/2003 ') '_.~ "=L-.. :"":~:~.:$.~.-. ) , SIMPCO MOQiUAWKIE, No., 1 Flow T'est Rep:ort Operator: AURORA GAS, LLC Anchorage, Alaska Prepared By: -- 1""\ ,"""I ~ - f"- ~ ~ ---1 . "7"~ . ~-4 : l,~ - -- l E & P SERVICES, INC. \1C!J' ótf1 I ) ') Background Information: In lieu of performing a well workover procedure on the Simpco Moquawkie NO.1 well as originally planned and approved in the Sundry Approval # 303-115, Aurora elected to first test the well in its current configuration to evaluate current pressures and flow potential to get a better idea on the best course of action should a work-over be performed at a later date. The following well work summary details the testing work performed this fall. Work Summary and Dailv Activities: August31,2004 RU containment and test tanks September 1, 2004 Continue RU flow lines and prepare for testing ops. September 2, 2004 Finish RU, mob in slickline, pressure I integrity test tree, pull BPV at surface, pressure test tubing. RU slickline and attempt to pull blanking plug in tubing. (2) runs made, unsuccessful, shut down for night. September 3, 2004 September 4, 2004 September 13, 2004 Attempting to pull blanking plug, modify prongs and tools, no luck. CIO for different tools, again attempt to pull plug. Unsuccessful. RIH wI LIB, spud on top of object at 2775', when pulled had impression indent of plug. Modify pulling tool and again RIH and attempt to pull plug. Unsuccessful, shut down for night. RIH wI slickline, latch onto plug and jar until pins shear. POOH and redress tool. RIH, and attempt 3 more times. POOH and LD extraction tool, PU and RIH wI tubing punch perforating gun, tag obstruction at 60 ft. POOH and RIH wI 2.3" gauge ring, tag up on sleeve. Abort operation, shut down and wait on orders. RD and release slickline Mob in and RU slickline. Researched archives and found better data on downhole equipment. RIH wI Type A prong, latch onto plug and POOH wI blanking plug. Well immediately flowed and recovered 8 bbls of diesel then well dead. RU to swab in well. Swabbed 6 runs, recovered 17 bbl diesel total to date, shut in well and watch pressures. Pressure build to 240 psi in 1 % hrs. RIH and swab, 5 gal recovered, RIH to 2974 ft, no fluid encountered. POOH wI swab and allow well to flow. No fluid and slight blow. RD and release slickline, shut in for night. ') ) September 14, 2004 Test well, see attached flow report wI time, pressure, choke setting. Well deemed non-commercial at this time, well shut in pending further evaluation and possible future stimulation work. Well was left in original configuration, no modifications made to down-hole or surface configuration. ) ) 11~/'O4-1 Fluid Time Pressure Choke R TOT.REC Comments 7:05 0 Closed 0 17 bbl Opened Well on 10/64 Choke 7:10 965 5/32 0 17 bbl Choke Freezing Off-Opened to 7:20 900 5/32 0 17 bbl 18/64 7:35 615 9/32 0 17 bbl 7:40 491 9/32 0 17 bbl 7:50 304 9/32 0 17 bbl 8:00 189 9/32 0 17 bbl Closed In Well 8:10 237 Closed 0 17 bbl 8:20 275 Closed 0 17 bbl 8:30 316 Closed 0 17 bbl 10:30 710 Closed 0 17 bbl 12:00 841 Closed 0 17 bbl 1400 918 Closed 0 17 bbl 16:00 948 Closed 0 17 bbl 18:00 959 Closed 0 17 bbl Opened Choke to 12/64 18:10 782 3/16 0 17 bbl Throttling Choke to Prevo Freezing 18:20 671 3/16 0 17 bbl 18:30 506 3/16 0 17 bbl 18:40 368 3/16 0 17 bbl 18:50 292 3/16 0 17 bbl Recalibrated Choke 18:55 186 3/16 0 17 bbl Close Choke to 8/64 19:00 168 1/8 0 17 bbl 19:10 129 1/8 0 17 bbl 19:20 110 1/8 0 17 bbl Close Choke to 7/64 19:25 117 7/64 0 17 bbl 19:30 117 7/64 0 17 bbl 19 :40 118 7/64 0 17 bbl Well Stabilzed & Flowing @ 117 psi Through 7/64 Choke Estimated Flow = -37 mcfd dhv 091504 Re: Sundry App--Simpco Moquawkie No.1 well (PTD# 178-047) Subject: Re: Sundry App--Simpco Moquawkie No.1 well (PTD# 178-047) From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Thu, 01 Jul 2004 08:06:35 -0800 To: duane vaagen <duane@fairweather.com> Duane, I have looked at the sundry you refer to and it is still valid. At the present time, sundries do not have an expiration date although it is likely in the future that lIun-actioned" sundries will expire 2 years after approval. The work you are planning does indeed need a sundry. It appears that your initial steps are essentially the same as proposed last year albeit with out the rig over the well. Based on plans listed in your message and the approved sundry, you have the approval you need to proceed. We appreciate you notifying us of the change in how you will accomplish the plans. I will place a copy of this message in the well file. Call with any questions. Tom Maunder, PE AOGCC duane vaagen wrote: Tom: Last year we (Aurora Gas, LLC) submitted a Sundry application to work on and recomplete the Simpco Moquawkie No.1 well (PTD# 178-047). That Sundry has since expired (approval 303-115). At this time we have decided we want to test the well as completed and if commercial, put on line as is since we now have a gathering line within ~ mile of the site. Our intent is to test the tree and tubing; and if ok, pull the backpressure valve and profile plug at depth and swab the well in with a slickline unit. We do not intend to have a rig at the site. Unless I am missing something here, it is my understanding that we do not need a Sundry to perform these activities? In the event the well cannot be produced as is, we will look at our options and then submit a new Sundry application for any rig work we deem necessary which will be performed at a later date. Please let me know if this is acceptable. Regards Duane I of I 7/1/20048:06 AM Aurora Gas, LLC www. a u rorapower, com March 31, 2003 Commissioners Alaska Oil & Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Application for Sunary Approval to perform testing and well work-over procedures on the Simpco Moquawkie No. 1 gas well. Dear Commissioner(s): Aurora Gas, LLC is at this time seeking Sundry Approval of its plans to perform we~ testing, well work-over and re-completion procedures as required to evaluate the commercial potential of the Simpco Moquawkie No. 1 gas w~e Simpco Moquawkie No. 1 was d01ttt,~ested and completed as a gasC~ by the Simasko Production Company i 19~~.. The well was subsequently s~l~ut in and has remained in / this state ever since with-tut being produced. It is Aurora's intent to perform various operations on the well to determine the economic feasibility of building surface production facilities and a gas gathering line to the site. These operations will help Aurora determine whether the well can be produced commercially, needs to be P&A d, or the well can be salvaged for some other use such as a Class II oilfield waste disposal well.'/The AOGCC will be notified at the conclusion of well testing on what the intended course of action will be. Work-over and testing operations may require, perforating, cementjngah.~l new completion installation. The anticipated operations start date is,~e~003. Attac~en~ include the following: 1) 2) 3) Form 10-403 Application for Sundry Approval 3 - Copies A summary of the intended well work procedure and operations plan A sketch of BOPE equipment that will be used ORIGINAL RECEIVED APR 0 9 2003 Alaska Oil & Gas C~ns. C,mmissi,fl Anchorage 10333 Richmond Avenue, Suite 710 · Houston, Texas 77042 · (713) 977-5799 ° Fax (713) 977-1347 1029 West 3rd Avenue, Suite 220 ° Anchorage, Alaska 99501 · (907) 277-1003 · Fax (907) 277-1006 Page 2 Commissioner(s) cored... If you have any questions or require additional information, please contact the undersigned at (713) 977-5799, or Duane Vaagen at (907) 258-3446. Sincerely, J. Edward Jones Vice Presidem of Operations and Engineering Aurora Gas, LLC CC: Andy Clifford Duane Vaagen Att: RECEIVED APR 0 9 ?.003 Alaska Oil & Gas Cons. C~mmission Anchorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [ ] Abandon [ ] Suspend [ ] Alter Casing [X] Repair Well [ ] Change Approved Program [ ] Operation Shutdown 2. Name of Operator Aurora Gas, LLC. Address 1029 West Third Avenue Suite 220 Anchoraae. AK 99501 Location of well at surfaco 424' FSL, 1261' FEL, S36, T12N, R12W SM At top of productive interval Same At effective depth ~~~JE[;) Same At total depth Same 12. Present well condition summary ] Plugging ] Pull Tubing ] Re- Enter Suspended Well 5. Type of well: [ 1 Development i/-~/-a~' J)q Exploratory [ ] Stmtigraphic [ ] Service ] Time Extension [X] Perforate ] Variance [ X] Other ] Stimulate Workover as necessary 6. Datum Elevation (DF or KB) RKB 465' AMSL Cs9 Head 450' AMSL 7. Unit or Property Name Simpco Moquawkie 8. Well Number 9. Permit Number 178-047 10. APl Number 50-~---q~20060-00 11. Field and Pool Total depth: 6166' MD // feet 6166' TVD feet Effective depth: 2974' MD ./' feet 2974' TVD feet Casing Length Slmctural Conductor Surfaco Intermediate Production Liner 2192 Plugs (measured) Junk (measured) EZSV 2974', EZSV 3792' EZSV 5013' Size Cemented MD TVD 13 318" Driven 81' 81' 9 5~8" 330 sks surface 846.94' 846.94 7" 850 sks 3110.76' 3110.76' 5" 445 sks 5242.05' 5242.05' Perforation depth: measured True vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 2847-2860', 2864-2868', 2870- 2877', 1/2" holesREIC E IVE D same APR 0 9 ZOO3 2 7~8" 6.5 # @ 2834' Alaska Oil & Gas Cons. Commission Baker FB-1 WI Sealbore assembly ~ 2777.87' Anchorage 13. Attachments 14. Estimatedj:~e'~/'commen~ing operation ~d'~ne 1/~ .003 16.' If prop~_~"~e~'bally aPproVed [ XJ Description of Summary Proposal ] Detailed Operations Program [X ] BOP Sketch 15. Status of well classification as: [ X] Gas [ ] Suspended [ ] oi~ Service Name of approver Date Approved Contact Engineer Name/Number: J. Edward Jones I (907)277-1003 Prepared By NamelNumber: Duane Vaagenl(907)258-3446 17. I hereb, y,c rtify t the foregoing' Signe%l.-rt-i ~/~~.~} and cOrrect tO the best Of my knOwledge , ? ~;~ Title ~/~<~ '/~-.J"/~-E'~?~/~ Date-~~--~' r~ Commission Use Only Conditio Approval: Not~/~'mmission so representative may~itness [APproval No. ~O Plug integrity _m~ BOP Test _~_ _ Location Clearance .... Mechanical ~ntegrity Test ' Subsequent form required 10- ,,~'~_ . , Approved by order of the Commission ~. ~ ~s~-----z..e_ ~ Co mmissi~oner Date ¢~ Form 10-403 Rev. 06115188 ' ,/' ' Subn~j(In Tr~licate ORtGtNAL ~BOM~ EIFL Simpco Moquawkie No. 1 Re-Entry and Re-completion Background Information and Present Condition . All depths herein are referenced to original RKB at 465' AMSL. The Simpco Moquawkie No. 1 was drilled as a vertical gas well in 1978. The well was cased, performed and tested extensively before being co .,,~pleted and shut in. Current PBTD is 2974', withq~en perforations from 2864 - 2877' in the Moquawkie Sand, a member of the~.Y°ne~rmation. The well is completed with a packer and seal assembly at 2777', wi~~inking plug reported as being installed in the tubing tail at 2834'. The well is tied back to surface with a string of 2 7/8" production tubing. A complete production tree has been installed as well. Site Access Access will be off existing road system.""The original access road and well site will be cleared of brush and utilized. Other then general maintenance, no new construction or disturbance is anticipated. Rig Used for Project Aurora Well Service, Rig No. 1 (AWS #1) will be used. This is the same rig used last year for the Nicolai Creek well work. Configuration of pits, and solids equipment will be similar to that used last year. Working floor elevation -~ 14' AGL. Simpco Moquawkie No. 1 Proposed Operations Plan In order to evaluate the potential of the Simpco Moquawkie No. 1 as a commercially viable gas production well, to plug and abandon, or to utilize the well as a potential Class II oilfield waste disposal well, the following work will be done. 1. Pressure test tree and tubing, pull blanking plug. 2. Swab in well and test as currently completed. 3. Based on testing in Step #2, decide on next course of action. o If decision made to pull completion, kill well with filtered KCL brine, set blanking plug, .ND production tree. MI and RU AWS Rig No. 1. Install and test BOPE. Ensure 9.2 ppg kill weight brine with'5%"~nimUm~6hcentration. ~'~ ~C>h This will likely be recycled and filtered from another project. /v[~ ~ ~ 5 ~ I p ~'. . Pull blanking plug, pull tubing, drill out Baker production packer, and fish out tubing tail. 8CANNJ~D l~P~ g $ 2003 I"ah'weaiher ,l':(~: l> Services. inc. Rev. 1.3 Page .! 2 7-Mat'-2003 . Drill out bridge plug at 2974' to access the wellbore from 2974 - 3 792' for testing and evaluation. . Log, re-perforate and test based on new logging information. Based on review of original logs, potential zones of interest are 3008' - 3040' and 3590' - 3626'. /t/t,¢l) Others may be discovered with new logs. /' . Based on discoveries in above steps, a decision will be made on whether it would be commercially viable to complete the well for production, permanently plug and abandon the well, or utilize the wellbore for a Class II disposal well. Please see expansion of these options below. Option Determinants and Final Well Configuration Option I In the event the well is deemed capable of producing gas in commercially feasible quantities, the well will be completed with a sand exclusion pre-pack screen assembly hung across any open production perforations on a permanent / retrievable type packer with sealbore assembly. The 2 7/8" production tubing will be run, the production tree installed and AOGCC will be notified with Form 10-407 of the final status of the well. Well test results and final completion report will be submitted at that time. Option II If, after testing operations it is decided to permanently plug and abandon Simpco Moquawkie No. 1, a verbal request will be made to AOGCC for permission to ~-'" immediately plug and abandon the well using guidelines laid out in Alaska Administrative Code 20 AAC 25.112 and 20 AAC 25.120. Upon receiving permission, an inspector will be called out to witness the plugging operation. A Sundry Application will be submitted outlining the intended plug and abandonment procedures and a new 10- 407 will be submitted detailing the final configuration of the Simpco Moquawkie No. i wellbore. Option III The final option listed in Step 7, is the conversion of the Simpco Moquawkie No. 1 into a Class II Oilfield Waste disposal well. The well may have utility for use in the disposal of drilling waste and produced fluids generated by the development program Aurora Gas, LLC is currently operating on the Northwest side of the Cook Inlet. The permitting process for this conversion is time consuming. If the decision is made to use the well for this purpose, the following will occur: AOGCC will be notified, produced water samples will be collected for salinity determination, injection / fracture testing will be performed to test suitability for the intended function and the well will be completed, killed and shut in until the re_.~~it.,Es are obtained for~l conversion. At present, Aurora Gas, LLC has applied for and received the required permits to re-enter and use the Nicolai Creek Unit No. 5 for use as a disposal well for the area. The NCU 5 well was permanently abandoned many years ago. The locations of the Simpco 8CANNE APR 2003 l;"aii"wealher li~ P Services. Inc. Ret,. 1.3 o./'3 27-Mar-2003 1'//6 · Aurora Gas, LLC. $impco ~uawkie No. 1 Work-over Moquawkie No.(s) I and 2 wells with respect to the ongoing development plans make them both superior candidates for this purpose over the NCU 5 well. A Sundry Application is being Submitted under separate cover for the testing and workover of Simpco Moquawkie No. 2 this summer also. Depending on the outcome of the testing and work-overs, one well may be selected over the other for production, disposal or plug and abandonment. Though unlikely at this time, depending on discoveries made in the course of testing and work-overs, both wells may be P&A'd. Simpco Moquawkie No. 1 Pre~sure Considerations Because of the numerous flow tests and large amount of informati~)n collected, pressure data for the Simpco Moquawkie No. 1 is fairly complete. Testing operations revealed an initial static bottom hole pressure of-1283 psi at 2877'. This would equate to a pore pressure gradient of .45 psi / fi. The maximum anticipated surface pressure (MASP) can be calculated by subtracting the gas gradiot~t from the pore pressure and multiply by the TVD depth. Using this approach, MASP = (.45 - .11) * 2877' = 978 psi.~The maximum flowing robing pressure recorded at surface while flow testing was 948 psi. Based on the above, a kill weight brine of 9.2 ppg should be sufficiem for well control and well kill operations. An 11" (3M) BOP system will be used, BOP tests will be performed to 3000 psi. Please see attached diagram of BOP system Workover Fluid Properties: A recycled, filtered 5% KCI based brine system will be used for workover and well kill operations. Drillina Fluid System: Shale Shaker, Desilter, Centrifuge, Ditch Magnets, PVT monitors SCANNED APE :~ 3 2003 Fairweather E&P Services, Inc. Rev. 1.3 Page 3 of 3 27-Mar-2003 Proposed Asis IKaBL 450' t 465' x Anticipated Pressure 1277 ps t perforations) 12 114" Hole 1.315" 1.8# J-55 "Heater String" to 923'. Hung off at surface. Gas, [.LC 300 Sks "G" bullheaded down 7" X 9 518" csg 13 318"61#-~1:55 COnd~ven to refusal at 81.9' ~ 9 518" 32.3# H-40 ST&C @ 846.94' Cmtd wi 330 sks "G" Top Tyonek 1143' 8 314" Hole Stage Collar at 1600', not used, could not establish circulation. -- Test Perfs 1950 - 1980' Squeezed w/75 Sks "G" 2 718" 6.5# Production Tubing Displaced wi Diesel to packer Prior to stab in and hang-off __ Test Perfs 2122-2146' Squeezed w/25 Sks "G" Perfs 2426 - 2456' Squeezed w/25 Sks "G" Top Moquawkie 2816' 2 718" Tbg tail {~ 2834' ~ Blanking plug installed? PBTD ~ 2974' tSqueezed Perfs 3000 - 3002' 40 Sks "G" 5" Liner Top @ 3050' Liner Lap squeezed wl25 Sks "G" ~ Squeezed Perfs 3112 - 3116' 150 Sks "G" Baker FB-1 WI Seal assembly @ 2777.87' Production Perforations 2847 - 2860', -- ~2864 - 2868', 2870 - 2877' 1/2" holes @ 2spf Test Perfs 2912 - 2934' Squeezed WI20 Sks "G" ~ -----Test Perfs 2957 2974' Squeezed WI50 Sks "G" EZSV @ 2974 / --Test Perfs 3011 - 3041' Squeezed WI33 Sks "G" ~ -- Test Perfs 3021 - 3041' Squeezed WI20 Sks "G"~ 7" 20# K-55 ST&C @ 3110.76 Cmtd w/300 sks "G" around shoe Top MGS (A) 3470' 6 118" Hole Squeezed Perfs 3830 -3933' 15 Sks "G" ~l~k Squeezed Perfs 3917 - 3920' 25 Sks "G" Squeezed Perfs 4050 - 4055'140 Sks "G" 5" 17.96# N-80 @ 5242' MD CMT'D W / 140 Sks "G" TD @ 6166' MD 15 Sks "G" on top of EZSV EZSV ~3792' Test Perfs 3850 - 3860' EZSV @5013' Test Perfs 5028 - 5040' .. Aurora Well Service Rig No. 1: Proposed 3M BOP Configuration for well re-entry, work-over and Drilling System designed to work in reverse circulation mode, where returns taken up workstring and through power swivel to pits, dudng re-entry procedures. Grant rotating head to be replaced with standard flow nipple when OH drilling commences. Washington Rotating Head for 2 7/8" Tbg. 3" 3M Manual Valve on spool for either pumping into or taking returns above rams. ~.. Schaffer Annular Preventer ~,,,-. Pipe Rams sized to work string. ''~ ,~ 11'~'~ouble Gate ~pe n'"-'] I ~.~ 11- 3M Mud Cross I I I Blind Rams ~ I I I . ' ' 3" 5M Manual Valve (Choke Line) 3 5M Manual Valve (Kill Line) ~~"~ I 3" 5M Hydraulic Valve "~ ~" ' , , , ,, (Kill Line) I , '. I ~ ~ i~ .. ~ 3-5M Hydraulic Valve ~ ~ , ~ ~ (Choke Line) Fluid flow direction --~ - -- -'~ ~]~L~'---' I ' i ' ' I ~ - while reverse circulating I , , I. I 7" x,," 3M OSA 11"3M Braden Head "X 7" 3M Tubing Spool 2" 3M Manual Valves On Wellhead 9 5/8" Surface casing Aurora Well Service #1 BOP System I' Fairweather E&P Services, Inc. Rev. 03 DHV 25-Feb-2003 Drawing Not to Scale Aurora Well Service Rig No. 1 Proposed Choke / Kill Manifold Configuration Ail valves are 3" rated at $000 psi. ..... · .. Inlet from Power Swivel (Reverse Circulation Mode) Output to Pits Hydraulic Remote Activated choke 2" 5M Rated Valves Inlet from BOP Choke Line 3" 5M Rated Valves 3" 5M Rated Valves 3' 5M Rated Valves Bleed Flare Line to Open Flare Pit Manual Choke 2" 5M Rated Valves To Gas Buster "Atmospheric Degasser" I,Aurora Well Service #1 Choke Manifold J Fairweather E&P Services, Inc. Rev. 03 DHV 25-Feb-2003 J Drawing Not to Scale MEMORA OUM Stat of Alaska TO: ALAS~/~IL~ A~ GAS CONSERVATION C0~IISSION C. V J C~Ya~terton Chai~~/ " Cotmissioner DATE: October 22, 1984 FILE NO: D. 2I. 44 TELEPHONE NO: FROM: Harold R. Hawkins -- .~ Petroleum Inspector-~'W~. SUBJECT: Clean-up Inspection Sim_~sko Production Co. Simpco ~loquawkie No. '1, Surf. Loc. 424' FSL, 1261 ' FEL, Sec. 36, T12N,R12W,SSI, Permit No. 78-47. Wednesday, October 17, 1984: · I left Simpco East Moquawkie No. 1, ~ub~ect of another report, to Simpco Moquawkie No. 1 for clean-up inspection. The location was clean and free of debris, but there was not a well sign on location. The well is a completed gas well, nippled up as per Form No. P-4, dated October $1, 1978. A well guard is set up around well. took pictures to verify conditions to be attached to this report. also filled out an AOGCC field report which is attached. In s;,mmary, I inspected Simpco Moquawkie No. 1 for clean-up This well classified as a gas well. I found the location was clean and free of debris, the well sign was the only requirement that was not satisfied. Attachment/pictures in file. 02-00IA(Rev. 10179) ~-p~--~ad Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION Operator _ .$/~/~3~ Addre s s Date Suspended Surface Location of Well ~'.2.~ Ft. F ~ L, .;2~/_ Ft. Sec.~, T il ~___, R/I ~, $ M. Permit No. ~ ~',9~ 7_ F. ~ L API No. 50 3%,,~'~ '-2 ~ ~- Unit or Lease Name 3~4/~&.~D _~m_d~;A~zf~ Well No. _ ~_ Field & Pool _a~/~9 !.-~/- . Condition of Pad Well head - Ail outlets plugged Ye(yes)' No Well sign - Attached to well head Yes No Attached to well guard Yes' No .attached to Information correct Yes No Cellar - Opened Yes No Rat Hole 'Fi 1 led Ye s No WaterWell - Plugged off capped Open · ,~'.m-,..7/3 ~' ' ' '" . . . . ,,,,.~-.ZL ,'2 z..; ¢., ?'"~', Explanation Ope n Ye s No Fi 1 le ~ Ye s No ' cover~d~) ,~,, ,~ : /_ _,f,,.,z;, i ~:3~,T,,~.,,.,.~ ~ ~,... Photographs taken to verify above ~conditions(Yes~. No Exp!anaton )~j~.~.",k~ . .7'/%~i?~ .~.. ?. ?,4. ~ ~ ~ ~ ~,.'c" <~,~,~:~/. 7~-,/~ ~.,; f ~,z ~~ ~ ' Work to ~ done to ~ acceptable , ~ '~ ~ . ,~ .~ ~' ,~. ~ _ .~ ~. '~ , This we~l and location is (accegtable) (unacceptable) to ~ classified as sus~nded for the period of 19 thru 19 . . Revised 8/24/82 t ti AMERICAN S?RATIGRAPHIC P.O. BOX 2127 · ANCHORAGE. ALASKA · TRANSMITTAL COMPANY Dear Sir: We have transmitted this date via samples from the: Please acknowledge receipt by returning one copy of ~J~is transmittal. ~/ Very truly yours, American Stratigraphic Co. R e c eipt acknowled ged Remarks: OIL AND GAS CONSERVATION COMMITTEE 50-283-20060 5 ~ 'rv~,s OF CO,~'LS'nOS: Cook Inlet Region, Inc. ~,~ ~ nzzP- ~ ~t. cu ~ m~r. ~ her ..~, , ~ · ~a. UNtT,F~L~I O~ ~S~ ~tE S I MASKO PRODUCT I ON COMPANY D)Vi-~b" cf CJl ,,,u P.0. Box 1515, Anchorage, Alaska 99510 · ~,~,~, ~2~' FSL 126~' rfL, Sec 36, T12N, R12W Seward Meridian, Alaska A~ top prod. tnce~&l reported below $ame At total dep~ ~m~ 9. W~I., NO. 1 10. FLEf. D A.ND POOL. O~ W~C.~T Wi ldcat Xi. S~C.. T., ~. ~.. tDO~O~X ~O~ O~V~) Sec 36, T12N, R12W Seward Meridian, AK. t2. ~IIT ~O. 78-47 ~&US; OF. A~q~.. 1~ ,-~V.i. TION$ ~DF, ICh%l~, /~I,~17, ~J.~V. '-~~,~,r lq78 I 465' RKB above.~Ab°ye MSa_ Jul 197 ,s~.~,.^:., p~ ::.~ ,,pm ~.~ ' '-- - .,~i ~"~IO1~' TOP BO'I~'OM NAME (MD AND ~ ' ' ~UCT,'I~Y I'IADE ~ pP. ODIJCING ll~EIiVAL,(:~;, OF Ti'IlS CO~i~- -- , ' ' Tyonek Formation; Moquawkie Sand Member. Completed for Production Thru I No Peri:orated I nterva~ ~-- ~ ~yp~.~:c,-~:~c~no~,,tr.a~,oosau~ BHC-GR, CBL, FDC-GR, ML, DIL-SFL, Temperature, Hiqh Resolution Continuous Dipmeter~ , ~, ~ · 9 I -- ~ ,il { C~L'Iii..%iTING I{ECOI%D ~ -'-'~ .... . . ..:. ! ....... LB'FT t~ GI~%.D~ ~ D-PTH~ S~T (~LE b"--~ '. ~ ~ :7. TL'BI~G RE--. O F.D ~ pE"~FORA-"O-~S ~pw_~l TO pKODU'CTIO~ lln%crval size anti numDer) :19 ACiD $:.CT, f'il,%::% Jllr'', C~''.IE-~T SQU-'EZ, E, intervals Peri:orated: 2847'-60': 2 spt: w/ 0.34" jets 3Oq0' Liner Lap_~ 2g Sx Cla~s G Cement 2364'-68': 2 spf w/ 0.34" jets ~ql7'-?O' Pert:si 2g ix Clns~ a Cemant 2870'r77': 2 spf w/ 0.34" jets ~8~0'-~' perF.{ 1~ $x Cla~ G Cement Pi%OD LICTION -yA', -. ;:i~:'J :' Pl;~ ~ODUCTION ~il~i (IOD (Fiowi,'II, ~'a~ h~. p.tnpin~iz~ "n'~ ~..vpu o£ p~mP-7"~'---'~; ~:LL b'rA'l'U~ ' p:-.uu~ ..'.~; ~,. .......... ' Shut- I n 16 September 197a{ Flowing- DST No's. 6 & 6A / ' 9/ 6/7S [ None 970' .... --~~~ lc^i,_c:k_'~k~ ow--nar-. ~--'~'<,~c~.' ~~'wr'r'~'z ~""'~"' 300 PKR Set !-'-~_~...).None ~, '2516 [ None '. N.one ~"~'~"'~'~'~') . 1 None Flared . ~: armation est · ate eel; · (See Instructions and Spaces for Additio General: This form is designed for-submitting a complete and correcl well complelion reporl and leg on all types o! IdnJs and leases in Alaska. Item: 16: Indicale which elevalion is used as reference (where not olherwise shown) for depth measure- menls given in tiber spaces on Ibis form and in any allachrnenls. Item~ '~0, ~,J ~'~:: If lhis well is compleled for separate prcduction from more than one interval zone- (mulliple complelion), so slale in item 20, and in item 22 show the p~cJucing interval, or intervals, lop(s), bollom(s) and name (s) (if andy) for only lhe interval reporled in ilem 30. Subrnil a separale report (page) on this form, adequately identified, for each addilional i~te~val to be seperalely produce.t, show- lng the acklilional data per~.inent to such interval. II.mi6: "Sacks Cement": Attached supplemental records for this well shoulJ show lhe details of any mul- tiple stage cementing and lhe location of the cementing tool. Item ]8: Submit a separate complelion report on this form for each inlerval to be separately produced. (See inslruction for items 20 and 22 above). ' ..... ~4. SUMMA](~' '01.' i.'OItMATION 'FE.s'I'S INt'LUI)IN¢; INTEItVAL T~TED. PIIF~UR~ DATA ~ ~OVEI{I~ OF OIL. OAS. WAT~ AND MUD SEE ATTACItED SUMMARY OF FORMATION TESTS PART 29: (Continued) Gravel O' - 260' O' - 260' 4050'-55'; Perfs 25 Sx Class G Cemen~ Beluua Format{or 260' - 260' - {221~' ~3011'-41'; Perfs 33 Sx Class G Cement. {220' ~2912'-34'; Perfs 25 Sx Class G Cement ~2426'-56'; Perfs 25 Sx C{ass G Cement Tyonek Formatior 1220' - 1220' - 6166' ',2122'-46'; Perfs 25 Sx Class G Cement 6166' ~1950'-80'; Perfs 75 Sx Class G Cement 3000'-02'; Perfs 35 Sx Class G Cement Moquawk{e Sand 2845' - 2845' - 29] "~3021'-41'; Perfs 20 Sx Class G Cement Member 2975' ... :l~. {'OH~ DATA, A'I'I'A('II IIlIIg~' D~qL'IIIPI'~ON~ OF LITIIOLOOY, POIIOSII'Y, FIIAc~I{E~, APP~N~ DI{~ .- .. .. AN[{ i}~'I'KCT}~I) SII(>WS OF O11,, GAS Oft ~V.~T~{. ~ ~ ,,, ,, , ,_ , , i ,, ......... ~ - . Core ~l 2885-2~05 Cu~ 20' Eec. 20' -. Sandstone, It. gy, fn=med grn, sub=ang to rnd, pred. qtz wht ~ clr, w/blk and green meta-rock grns, {oose{y consol, bent clay maWr{x, occ {oose pb{s. Good poros, but clays sens{t}ve to fresh wtr. some carbonaceous .la,n{nae at 28~'. No cut or flourescence. ........ .C O./f PLETION REP(. 3 T SUMMARY OF OPERAT IONS Attachment To Alaska O & G Conservation Committee Form P-7 WELL COMPLETION REPORT & LOG SIMPCO MOQUAWKIE NO. 1 SIMASKO PRODUCTION COMPANY P. O. Box 1515 Anchorage, Alaska 99510 START OF OPERATIONS 1 April 1978 thru 30 June 1978 1 July 1978 thru 22 July 1978 Re-build access road. Construct drillsite and install cellar. Wait on Drilling Rig. Repair drillsite and roads from effects of breakup. RIGGING UP DRILLING EQUIPMENT 23 'July 1978 thru 25 July 1978 Move Brinkerhoff Signal Company Drilling Rig No. 60H from Simpco Kaloa No. 1 drillsite to the Simpco Moquawkie No. 1 drillsite and rig-up. Set in and prepare to rig-up Cement Mixing Equipment, Gas Buster and other rig auxiliary equipment. INSTALLATION OF 13 3/8"OD CONDUCTOR CASING 26 July 1978 Pick up Delmag Model D-22 Diesel Pile Driving Hammer. Drive (2) joints of 13 3/8"OD, 61 lbs/ft., J55 Grade Casing to refusal @ 81.90 ft. RKB. Distance from ground level to RKB = 12.40 ft.' Drive Rathole and Mousehole. DRILLING 12¼" HOLE AND SETTING 9 5/8"OD CASING 27 July 1978 Install 12"-3000 x 13 3/8"OD Casing Wellhead. Nipple up 12"-3000 Hydril Annular BOP. Rig-up Kill Line and Relief Lines to Gas Buster. Pick up 12~" Drilling Assembly and clean out 13 3/8"OD Conductor Casing to 82' RKB. Drill 12¼"hole to 113'. Spudded @ 2015 hrs. this date. Deviation: ¼o @ 102'; . Mud: 8.6 ppg; Vis: 42. Operator SIMASKO PRODUCTION COMPANY -W ell Name Page 1 C6./IPLETION REP .RT ALASKA O & G CONSERVATION COMMITTEE FORM P-7 28 July 1978 thru 29 July 1978 ..* 30 July 1978 thru 31 July 1978 Drill 8%" hole from 113' to 861'. Deviation: ¼o @ 200'; ¼o @ 400'--, 1© @ 614'-, 1© @ 735'. Mud: 8.7 ppg; Vis: 80; WL: 1i. 0. Rig-up and run Schlumberger Dual Induction-SFL and Bore- hole Compensated Sonic Wireline Logs from 85' to 860'. Open 8%" hole to 12¼" from 113' to 846'. Deviation: 1© @ 860'. Mud: 9.6 ppg; Vis: 48; WL: 15. Open 8%" hole to 12¼" to 849'. Condition hole for run- ning casing. Rig-up and run (21) joints 9 5/8"0D, 32.30 lb/ft., H40, ST&C Casing equipped with Float Collar and Float Shoe. Casing landed @ 846.94' RKB. Cement 9 5/8"OD Casing to the surface with (330) sacks of Class G Cement. Circulated (16) sacks of Cement. Nipple down 12"-3000 BOPE and remove 13 3/8" Casinghead. Install 10"-3000 x 9 5/8" Casinghead. Nipple up 10"- 5000 Double Ram hydraulic operated BOP. Nipple up 10"- 5000 Annular hydraulic operated BOP. Install Kill and Choke Manifolds to BOP. Pressure test 9 5/8"OD Casing to 1000 psi. Pressure test Blind Rams, Pipe Rams, Annular BOP, Choke and Kill Manifolds to 1000 psi. All pressure tests satisfactory. Clean out inside of 9 5/8"OD Casing. Drill Cement, Float Shoe and Float Collar. DRILLING 8 3/4" HOLE AND 'SETTING 7"0D CASING 1 August 1978 thru 2 August 1978 3 August 1978 4 August 1978 thru 5 August 1978 Drill 8 3/4" hole to 867'. 'Conduct Formation Leak-off Test and establish a 0.70 psi/ft, gradient without leak- off. Drill 8 3/4" hole to 2223'. Deviation: 1 3/4© @ 1067'; 1 3/4© @ 1249'; 2© @ 1580'; 2~© @ 1899'; 1~© @. 1993'; 1 3/4© @ 2182'. Mud: 9.8 ppg; Vis: 48; WL: 5.0. Pressure test Blind Rams, Pipe Rams, Upper and Lower Kelly Valves, Drillpipe Safety Valve, Drillpipe Inside BOPE, Choke Manifold and Kill Manifold to 3000 psi. Pressure test Annular BOP to 1500 psi. All pressure tests satisfactory. Pressure testing witnessed by Alaska Oil and Gas Conservation Committee Field Inspector Mr. B.H. LeNORMAN. Drill 8 3/4" hole to 2739'. Deviation: 1 3/4© @ 2336'; 2© @ 2585'-, 1 3/4© @ 2677'. Mud: 9.9 ppg-, Vis: 45-, WL: 5.0. Drill 8 3/4" hole to 2885'. Condition hole for coring. Core with 7%" x 2 13/16" Corehead from 2885' to 2905'. Recover 20' of core. 'Operator SIMASKO PRODUCTION COMPANY W ell Name SIMPCO MOOUAWKIE NO. -- Page 2 C ..MPLETiON REP,JRT ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 6 August 1978 7 August 1978 thru 8 August 1978 Ream core hole. Drill 8 3/4" hole to 3115'. Deviation: 1%o ~ 2823'; 1%© @ 3007'; 1 3/4© @ 3115'. Mud: 9.8 ppg; Vis: 45; WL: 5.5. Condition hole for logging. Rig-up and run the following Schlumberger Wireline Logs from 845' to 3109': Dual Induction-SFL; Borehole Compensated Sonic Log-GR; Com- pensated Formation Density Log-CNL; Proximity Log-Micro Log; and Four-Arm High Resolution Continuous Dipmeter Survey. Run Schlumberger Reservoir Fluid Test Tool and conduct Formation Pressure Test and Formation Sample Tests at selected locations between 1950' and 3050'. Condition hole for Casing. Rig-up and run (74) joints of 7"OD, 20.0 lb/ft., K55, ST&C Casing. Casing equipped with Float Shoe, Float Collar and Multiple Cycle Stage Cementing Tool. Casing landed-@ 3110.76' RKB. Cement 7"OD Casing through Plug Container Head and Float Shoe with (300) sacks of Class G Cement. Open Multiple Cycle Stage Cementing Tool located @ 1600' and attempt to break circulation. Unsuccessful. Closed Stage Cementing Tool and pressure tested Casing to 2000 psi. Pressure test satisfactory. Cement through 9 5/8" Casinghead Side Outlet and down 7"OD Casing/9 5/8"0D Casing Annulus with (300) sacks of Class G Cement. Final shut-in pressure 100 psi. DRILLING. 6b" HOLE &' SETTING 5"OD LINER 9 August 1978 Clean out inside of 7"OD Casing. Drill Cement, Float Shoe and Float Collar. Drill 6b" hole to 3112'. Conduct Formation Leak-off Test and establish gradient of .080 psi/ft, without leak-off. Drill 6b" hole to 3228'. Deviation: 1© 30 min. @ 3191'. Mud: 9.6 ppg; Vis: 49; WL: 5.9. 10 August 1978 thru 18 August 1978 19 9 thru 21 August 1978 Drill 6b" hole to 5367'. Deviation: lb© @ 3280'; lb© @ 3468'-, 3/4© @ 3756'-, b© @ 3928'-, %o @ 4138'-, 1%© @ 4253'; 2 3/4o @ 4451'; 3© @ 4533'; 4b© @ 4626'; 3 3/4© @ 4718'; 5 3/4© @ 4933'; 6© @ 5124'; 5° @ 5312'. Mud: 9.6 ppg; Vis: 43; WL: 5.0. Drill 6%" hole to 6166' Deviation- 4© @ 5500'- 2° @ ~ ' , 5689'', 4o @ 5887'', ~ 6123'. Mud: 9.6 ppg; Vis'. 42; WL: 4.8. 22 August 1978 thru 23 August 1978 Condition hole for logging. Rig-up and run the following Schlumberger Wireline Logs from 3110' to 6110': Dual Induction-SFL; Borehole Compensated Sonic Log-GR; Com- pensated Formation Density Log-GR; and Four Arm High Resolution Continuous Dipmeter Survey. 24 August 1978 thru 26 August 1978 Condition hole and Mud for running Liner. Rig-up and run (52) joints of 5"OD, 17.96 lbs/ft., N80, ABC/FL4S Casing Liner. Run Liner on 3048' of 3½"OD Drillpipe and set Liner with top @ 3050.0' and bottom @ 0pe~ator ell Name SIMASKO PRODUCTION COMPANY .qTMPCO MOOT]AWKTF. NO. Page 3 CC,VIPLETION REP .,RT ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 5242.05'~ Liner equipped with Liner Setting Sleeve, Landing Collar.and Setting Shoe. -Cement 5"OD Liner through Drillpipe Wiper Plug Container' Head, 3½"OD Drillpipe and Liner Set Shoe with (140) sacks of Class G Cement. WOC 20 hours. Run Schlumberger Wireline Temperature Survey from 5090' to 2510'. Apparent cement top @ 4050'. Perforate in- terval of 4050' to 4055' with (5) 0.38" holes using Dialog 1 11/16" Expendable Jet Perforator run on Schlumberger Wireline. Cement through 3½"OD Dril!pipe, Liner Setting.Tool and perforations @ 4050' with_(ll5) sacks of Class G Cement. ,Pull Liner Setting Tool out of Setting Sleeve and reverse circulate top of Liner clean. 27 August 1978 Clean out 7"OD Casing to top of 5"OD Liner @ 3050' with '6~" Bit. Clean out 5"OD Liner with 4 1/8" Bit, 3½"OD Drill Collars, and 2 7/8"0D Tubing. Pressure test 7"OD Casing/5"OD Liner Lap to 1200 Psi. Pressure leaked off. Squeeze cement 7"OD Casing/5"OD Liner Lap through 3½"OD Open-ended Drillpipe hung @ 3048'. Squeeze with (25) sacks of Class G Cement to final squeeze pressure of 2000 psi. 28 August 1978 thru 30 August 1978 Clean out 7"OD Casing with 6¼" Bit and drill 20' of hard cement to 3049'. Clean out 5"OD Liner with 4 1/8" Bit and drill hard cement from 3049' to 3056'. Pressure test Liner Lap to 1500 psi. Pressure test satisfactory. Clean out 5"OD Liner and drill cement from 3980' to 4080'. Pressure test perforations @ 4050' to 4055' to 1500 psi. Pressure test satisfactory. Drill cement from 5088' to 5144' in 5"OD Liner. Run Schlumberger Wireline Variable D~ensity Cement Bond Log from 5132' to 700'. 31 August 1978 1 Sept. 1978 Run Schlumberger Hollow Carrier Casing Perforator loaded with (1) shot per ft. and perforate 5"OD Liner from 3917' to 3920'. ~~~ 1 u 1 g D i 8 u e a o (25) sacks of Class G Cement to maximum squeeze pressure of 2000 psi. Run Schlumberger Hollow Carrier Casing Perforator loaded with (1) shot per ft. and perforate interval 3830' t~ ~~ 3833'. ~ Run Halliburton RTTS Squeeze Tools and set Packer @ ~' Oper-ator W ell Name SIMASKO PRODUCTION COMPANY SIMPCO MOQUAWKIE NO. 1 Page 4 C(,,VIPLETION REP .,RT ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 2 Sept. 1978 thru 4 Sept. 1978 5 Sept. 1978 thru 7 Sept. 1978 8 Sept. 1978 thru 10 Sept. 1978 3760'. Squeeze perforated interval with (15) sacks of Class-G Cement with maximum squeeze pressure of 1800 psi. Mud: 9.9-ppg; Vis: 36; WL: 18. Drill cement out of 5"OD Liner from 3783' to 3838'. Mill EZ Drill Bridge-Plug @ 3880' and drill cement to 3921'. Clean out 5"OD Liner to 5144' and drill cement to '5200'. Mud: 9.1 ppg; Vis: 37; WL: 18. Change Fluid in Hole and Surface Circulating System from Mud to Calcium Chloride Brine Water treated with Clay Inhibitor. Run Halliburton 7" RTTS Test Tool Assembly With Pressure/ Temperature Recorder Carrier Bundle on 2 7/8"0D Tubing- Set Packer @ 3010' with bottom of Tailpipe @ 5000'. Attempt to swab Brine Water out of 2 7/8" Tubing and find leak in Test Tool Assembly. Pull Test Tool Assembly and replace internal seals in Tools. Re-run Test Tool Assembly on 2 7/8"0D Tubing and set Packer @ 3012'. Swab CaC12 Brine fluid level down to 1200'. Perforate through Lubricator with Schlumberger Thru-Tubing Expendable Jet Perforator loaded with (4) shots per ft. Perforate interval 5028' to 5040'. Conduct Drill Stem Test No. 1. See attached Drill Stem Test Data Sheet. Release RTTS Packer and reverse circu- late to kill Well. CaCl2 Brine: 9.1 ppg; Vis: 28; Cl-: 71,000. Run Halliburton EZ Drill-SV Bridge Plug on 2 7/8"0D · Tubing and set @ 5013'. Pull out of Bridge Plug and spot (15) sacks of Class G Cement on top of Bridge Plug. Run Halliburton 7" RTTS Test Tool Assembly with Pressure/ Temperature Recorder Carrier Bundle on 2 7/8"OD Tubing and set Packer @ 3014' with 2 7/8" Tubing Tailpipe @ 3814'. Swab CaCl2 Brine fluid level down to 1450' in 2 7/8"0D Tubing. Run Schlumberger Thru-Tubing Expendable Jet Perforator loaded with (4) shot~ per ft and prepare to perforate interval 3850' to.3860'. Find fluid entry into 7"OD Casing or 5"OD Liner prior to perforating. Remove ' Perforator and Test Tool Assembly from Hole. Run Halliburton 5" RTTS Squeeze Tool Assembly on 2 7/8"OD Tubing. Pressure test Bridge Plug @ 5013' with Cement Plug on top, in 5"OD Liner. Pressure test satisfactory. Pressure test 7"OD Casing/5"OD Liner Lap. Pressure test satisfactory. Find squeeze perforations @ 4050' -to 4055' leaking. Run Halliburton EZ Drill-SV Bridge Plug on 2 7/8"OD Tubing and set @ 4011i. Squeeze (25) sacks of Class G Cement through Bridge Plug into perfs @ 4050' to 4055'. Run Halliburton 7" RTTS Test Tool Assembly with Pressure/ Temperature Recorder Carrier Bundle on 2 7/8"OD Tubing. Set Packer @ 3014' with bottom of 2 7/8"0D Tubing Tail- pipe @ 3814'. Swab CaCl2 Brine fluid level down to 1400' in 2 7/8"OD Tubing. Operator SIMASKO PRODUCTION COMPANY W ell Name SIMPCO MOQUAWKIE NO. 1 5 Page C G,/iPLETiOI I REP .,R T ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 Run Schlumberger Thru-Tubing Expendable' Jet Perforator loaded with (4) shots per ft. through Lubricator and perforate interval 3850' to 3860'. Conduct Drill Stem Test No. 2. See Attached Drill Stem Test Data Sheet. CaC12 Brine: 9.1 ppg; Vis: 28; ClU: 65,000. Pull Halliburton 7" RTTS Test Tool Assembly out of Hole. Run Halliburton EZ Drill-SV Bridge Plug on 2 7/8"0D Tubing and set 8 3792' Pull Setting Tool out of Bridge ~ Plug. Mix and spot (1~) sacks of Class G Cement on top of Bridge Plug in 5"OD Liner. 11 Sept. 1978 thru 12 Sept. 1978 Run Halliburton 7" RTTS Test Tool Assembly with Pressure/ Temperature Recorder Carrier Bundle on 2 7/8"OD Tubing. Set Packer 8 2951' with bottom of Test Tool Assembly 8 2963'. Swab CaC12 Brine level down to 1300' in 2 7/8"OD Tubing. Run Schlumberger Thru-Tubing Expendable Perforator loaded~ with (3) shots per ft. Perforate interval 3011' to 3041' through Lubricator. Perforating Tools stuck in Tubing .8 2885'. Pull Wireline loose at Weak Point on top of tools. Perforating tools fell free of Tubing and down to Cement Plug in 5"OD Liner. Conduct Drill Stem Test No. 3. See attached Drill Stem Test Data Sheet. CaCl2 Brine: 9.1 ppg; Vis: 28; Cl-: 68,000. Complete DST #3 and release Packer to kill'Well. Hole will not stand full. Pump fresh water into 2 7/8"OD Tubing/7"OD Casing Annulus until hole stays full. Pull Drill Stem Test Tool Assembly out of Hole. Run Halliburton 7" EZ Drill-SV Bridge Plug on 2 7/8"OD Tubing and set 8 2992'. Squeeze (33) sacks of Class G Cement through Bridge Plug and into perforated interval with maximum squeeze pressure of 2250 psi. Run Halliburton 7" RTTS Test Tool Assembly with Pressure/ Temperature Recorder Carrier Bundle on 2 7/8"OD Tubing. Set Packer 8 2885'. 13 Sept. 1978 Swab CaCl2 Brine fluid level in 2 7/8"OD Tubing down to 1300'. Run Schlumberger Thru-Tubing Expendable Perfor- ator loaded with (2) shots per ft. Perforate interval 2957' to 2974'. Conduct Drill Stem Test No. 4. See attached Drill Stem Test Data Sheet. Release Packer. Reverse circulate to recover Fluid Sample. Pull Test Tool ~ssembly out of Hole. Run Halliburton RTTS Packer with Halliburton Hydro-spring Test Tool Assembly on 2 7/8"OD Tubing. Set Packer 8 2922'. Conduct Drill Stem Test No. 4A. See attached Drill Stem Test Data Sheet. CaCl2 Brine: 8.9 ppg; Vis: 28; Ci-: 50,000. Pull Hydro-spring Test Tool Assembly out of Hole. Run Halliburton 7" RTTS Squeeze Tool Assembly on 2 7/8"OD Ope~tor Well Name SIMASKO PRODUCTION COMPANY SIMPCO MOQUAWKIE NO. 1 Page 6 C ,RPLETION REP .RT ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 14 Sept. 1978 thru 15 Sept. 1978 16 Sept. 1978 thru 18 Sept. 1978 Tubing. Set Packer @ 2916'. Pump CaCl'2 Brine down 2 7/8"0D Tubing to open perforations and treat form- ation. Pull Halliburton RTTS Squeeze Tool Assembly out of Hole. Run Halliburton EZ Drill-SV Bridge Plug on Schlumberger · Wireline and set @ 2950'. Run Halliburton 7" RTTS Test Tool Assembly with Pressure/ Temperature Recorder Carrier Bundle on 2 7/8"0D Tubing. Set Packer @ 2824'. Swab CaC12 Brine fluid level in 2 7/8."0D Tubing down to 1300'. .!Run Schlumberger Thru-Tubing Expendable Perforator loaded -~with (2) shots per ftC', Perforate interval 2912' to ~ ~ 2934' through Lubricator. ~ Conduct Drill Stem Test No. 5. See attached Drill Stem Test Data Sheet. CaC12 Brine: 8.9 ppg; Vis: 28; Cl-: 44,000. Pull Drill Stem Test Tool Assembly out of Hole. Run Halliburton EZ Drill-SV Bridge Plug on 2 7/8"0D Tubing. Set Bridge Plug @ 2946'. Run Halliburton 7" RTTS Test Tool Assembly with Pressure/ Temperature Recorder Carrier Bundle on 2 7/8"0D Tubing. Set Packer @ 2823' with.Tailpipe @ 2838'. Swab CaC12 Brine fluid level in 2 7/8"0D Tubing down to 2000'. Conduct Drill Stem Test No. 5A. See attached Drill Stem Test Data Sheet. Pull Drill Stem Test Tools out of Hole; after releasing Packer & reverse circulating Fluid Sample out. Run Halliburton EZ Drill-SV Bridge Plug on 2 7/8"0D ~ Tubing and set @ 2900'. Squeeze (20) sacks of Class G Cement through Bridge Plug and into perfs with maximum Squeeze pressure of 3000 psi. Run Halliburton.7" RTTS Test Tool Assembly with Pressure/ Temperature Recorder Carrier Bundle on 2 7/8"0D Tubing. Set Packer @ 2793' with bottom of Test Tool Assembly @ 2808'. Swab CaCl2 Brine fluid level in 2 7/~"OD Tubing down to 1800'. Run Schlumberger Thru-Tubing Expendable Perforator loaded with (2) shots per ft.. Perforate interval 2847' ~% to 2877' through Lubricator. Conduct Drill Stem Test No. 6. See attached Drill Stem . Test Data Sheet. CaC12 Brine: 8.8 ppg; Vis: 28; Cl-: 41,000. Pull Drill Stem Test Tools out of H01e. Find (72) Hour Pressure Recorder Clock had failed to function. Re-ran same test tool assembly on 2 7/8"OD Tubing and set Packer @ 2795' with bottom of Test Tool Assembly @ 2810'. Swab CaCl2 Brine fluid level in 2 7/8"OD Tubing down to 950". operbtor SIMASKO PRODUCTION COMPANY W ell Name SIMPCO MOQUAWKIE NO. 1 Page 7 . C O tPLE TIOI' I REP(,R T ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 19 Sept. 1978 thru 20 Sept. 1978 21 Sept. 1978 thru 23 Sept. 1978 Conduct Drill Stem Test No. 6A. See at~ached Drill Stem Test Data Sheet. Release Packer, kill Well and pull Drill Stem Test Tool Assembly out of Hole. Run Halliburton EZ Drill-SV Bridge Plug on 2 7/8"0D Tubing and set @ 2793'. Pull out of Bridge Plug with Setting Tool. Spot (25) sacks of Class G Cement on top of Bridge Plug. Run Halliburton 7" RTTS Test Tool Assembly with Pressure/ Temperature Recorder Carrier Bundle on 2 7/8"OD Tubing. Set Packer @ 2385' with Tailpipe @ 2400'. Swab CaC12 Brine fluid level in 2 7/8"OD Tubing down to 1330'. Run Schlumberger Thru-Tubing Expendable Per- forator loaded with (2) shots per ft.. Perforate inter- val 2426' to 2456' through Lubricator. Perforator mai- functioned and perforated only 2426' to 2431'. Re-ran perforator and only one shot fired. Re-ran Perforator and perforated 2436' to 2456' successfully through Lub- ricator. Conduct Drill Stem Test No. 7. See attached Drill Stem Test Data Sheet Swab CaCl~ Brine fluid level down to 2000' in 2 7/8"6D Tubing ann continue testing. CaCl2 Brine: 8.8 ppg; Vis: 28; Ci-: 41,000. Release Packer; reverse circulate to kill Well and pull Drill Stem Test Tool Assembly out of Hole. Run Halliburton EZ Drill-SV Bridge Plug on 2 7/8"0D Tubing and set Bridge Plug @ 2381'. Squeeze (25) sacks of Class G Cement through Bridge Plug and into P..erforated Interval with maximum squeeze pressure of 1100 psi. Run Halliburton 7" RTTS Test Tool Assembly with Pressure/ Temperature Recorder Carrier Bundle on 2 7/8"OD Tubing. Set Packer @ 2040' with bottom of Tailpipe @ 2055'. Swab CaCl2 Brine fluid level in 2 7/8"OD Tubing down to 1300'. Run Schlumberger Thru-Tubing Expendable Perfor- ator loaded with (2) shots per ft.. Perforate Interval to 2146' through Lubricator. 2122' Conduct Drill Stem Test No. 8. See attached Drill Stem Test Data'Sheet. Swab CaC12 Brine fluid level down to 1820' and continue Test. Release Packer; reverse cir- culate and pull Drill Stem Test Tools out of Hole. Run Halliburton EZ Drill-SV Bridge Plug on 2 7/8"0D Tubing and set Bridge Plug @ 2072'. Squeeze (25) sacks of Class G Cement through Bridge Plug and into Perforated Interval with maximum squeeze pressure of 1000 psi. Run Halliburton 7" RTTS Test Tool Assembly with Pressure/ Temperature Recorder Carrier Bundle on 2 7/8"OD Tubing. Set Packer @ 1878' with bottom of Tailpipe @ 1893'. Swab CaCl2 Brine fluid level in 2 7/8"OD Tubing down to 1330'. Run Schlumberger .Thru-Tubing Expendable Perforator Operator Well Name SIMASKO PRODUCTION COMPANY SIMPCO MOQUAWKIE NO. 1 Page 8 k. 1. ~:illit., &' c,.',.',,'ictc.,, inc./37.',,.9 ,:t.t,!r:~c ci~'i,.'a..wl:,,,~:.r,r .. c:l~:,ta .9!~.~O.'dl,houe C O,VIPLE TiOt' ! REPUR T 24 Sept. 1978 thru 26 Sept. 1978 27 Sept. 1978 thru 30 Sept. 1978 ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 loaded with (2) shots per ft.. Perforate Interval 1950' to 1980' -through Lubricator. Conduct Drill Stem Test No. 9. See attached Drill Stem Test Data Sheet. Swab CaC12 Brine fluid level in 2 7/8"0D Tubing down to 1815'-. Release Packer; reverse circulate and pull Drill Stem Test Tools out of Hole. CaCl2 Brine: 8.8 ppg; Vis: 28; Cl-: 41,000. Run Schlumberger Hollow Carrier Jet Casing Perforator loaded with (2) shots per ft.. Re-perforate Interval 1950' to 1980'. Run Halliburton 7" RTTS Packer with Hydro-spring Test Tool Assembly on 2 7/8"0D Tubing. Set Packer @ 1927' with bottom Recorder Carrier @ 1949'. Conduct Drill Stem Test No. 9A. See attached Drill Stem Test Data Sheet. Release Packer and pull Hydro-spring Test Tool Assembly out of Hole. Re-run Halliburton 7" RTTS Packer with Hydro-spring Test Tool Assembly on 2 7/8"0D Tubing. Set Packer @ 1927' with bottom of Pressure Recorder Carrier @ 1949'. Con- duct Drill Stem Test No. 9B. See attached Drill Stem Test Data Sheet. Swab fluid level in 2 7/8"0D Tubing -'down to 1900'. Recover CaC12 Brine changing to Drilling Mud. Release Packer and pull Test Tools out of Hole. Recovered 150' of Drilling Mud from Test String. Run Halliburton RTTS Squeeze Tool Assembly on 2 7/8"0D Tubing. Set Packer @ 1897' with Tailpipe @ 1937'. Squeeze (25) sacks of Class G Cement through Bridge Plug and Perforated Interval. Maximum squeeze pressure 900 psi. Change fluid in Surface Circulating System and Hole from CaCl2 Brine.to Drilling Mud. Clean out and drill Cement from 1920' to 1980'. Pressure test Perforated Interval 1950' to 1980'. Pressure test unsatisfactory. Run Halliburton 7" RTTS Squeeze Tool Assembly on 3½"OD Drillpipe. Set Packer @ 1811' with bottom of Tailpipe @ 1845'. Squeeze Perforated Interval 1950' to 1980' with (50) sacks of Class G Cement with maximum squeeze pressure of 2000 psi. Release RTTS Squeeze Tool Assembly and pull out of Hole after 12 hours WOC. Clean out and drill Cement from 1860' to 1980'. Clean out 7"OD Casing to 2072' With 6¼" Bit. Mill EZ Drill Bridge Plug @ 2072' with Flat Bottom Mill. Clean out and drill Cement with 6~" Bit in 7"OD Casing to 2146'. Clean out to 2381'. Pressure test Perforated Interval 2122' to 2146' to 1000 psi. Pressure test satisfactory. Mill EZ Drill Bridge Plug @ 2381' with Flat Bottom Mill. Drill Cement with 6¼" Bit to 2456' and clean out to 2732'. Operbtor W ell Name SIMASKO PRODUCTION COMPANY SIMPCO MOQUAWKIE NO. 1 Page 9 C P L E T I O REPORT ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 1 Oct. 1978 2 Oct. 1978 3 Oct. 1978 thru 7 Oct. 1978 Pressure test Perforated Interval 2426' to 2456' with 1-000 psi~ Pressure test satisfactory. Drill hard Cement from 2732' to 2793'. Mill EZ Drill Bridge Plug @ 2793' with Flat Bottom Mill. Wash to 2900' and clean out junk. Mill EZ Drill Bridge Plug @ 2900' with Flat Bottom Mill. Drill Cement with 6%" Bit to 2946'. Mill (2) EZ Drill Bridge Plugs from 2946' to 2952'. Clean out 7"OD Casing with 6%" Bit' to 2986'. Mill and clean out junk to 2992'. Run Halliburton RTTS Squeeze Tool Assembly on 3½"OD Drill- pipe. Set Packer @ 2900'. Squeeze Perforated Interval 2957' to 2974' with (50) sacks of Class G Cement. Final squeeze pressure: 1500 psi. Release RTTS Squeeze Tool Assembly and pull out of Hole after 12 hours WOC. Drill hard Cement from 2903' to 2974'. Clean out to 2986' with 6¼" Bit. 'Mill on junk to 2992' with Flat Bottom Mill. Mill on Bridge Plug and drill Cement to 2995' with Flat Bottom Mill. Drill hard Cement to 3008'.with 6~" Bit. Run Halliburton 7" RTTS Squeeze Tool Assembly on 3½"OD Drillpipe. Set Packer @ 2900'. Pressure test Interval 2900' to 3008' to 1400 psi. Perforated Intervals 2912' to 2934' and 2957' to 2974' held pressure OK. Pull 7" RTTS Tools out of Hole. Run Schlumberger 4" Hollow Carrier Casing Perforator loaded with (2) shots per ft.. Perfora.te Interval 3000' to 3002'. . . Run Halliburton 7" RTTS Squeeze Tool Assembly on 3½"OD Drillpipe. Spot (25) sacks of Class G Cement in Drill- pipe and set RTTS Packer @ 2936'. Pump Cement below Packer through Perforated Interval 3000' to 3002' using Hesitation 'Squeeze Procedure. Get no pressure build-up. Pull Squeeze Tools out of Hole. Clean out and drill medium hard Cement with 6%" Bit from 2966' to 3008'. Run Halliburton 7" RTTS Squeeze Tools on 3%" Drillpipe. Set Packer @ 3006' and pressure test 'below-Packer to 1500 psi. Pressure test satisfactory. Re-set RTTS Squeeze Tools @ 2991'. Pressure test below 2991' and attempt pressure test to 1500 psi. Pressure test failed. Release RTTS Squeeze Tools and hang @ 3006'. Spot (15) sacks of Class G Cement out bottom of Squeeze Tool Assembly by Balanced Plug Method. Set RTTS Squeeze Tools @ 2891' and squeeze with maximum squeeze pressure of 1500 psi. Release Packer and pull Squeeze Tools out of Hole after 12 hours WOC. Clean out soft Cement with 6%" Bit from 2907' to 2942'. Drill medium hard Cement to 3008'. Run Halliburton 7" RTTS Squeeze Tool Assembly on 3½"OD Operator W ell Name SIMASKO PRODUCTION COMPANY SIMPCO MOOUAWKIE NO. 1 Page 10 CO-/ IPLETION REPORT ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 8 Oct. 19-78 thru 9 Oct. 1978 Drillpipe and set Packer @ 2925'. Pressure test Perfor- ated Intervals below Packer to 1000 psi. Pressure test satisfactory. 'Clean out 7"OD Casing to top of 5"OD Liner @ 3050' with 6%" Bit and Casing Scraper. Clean out 5"OD Liner with 4 1/8" Bit to 3175'. Run Schlumberger 3 3/8" Hollow Carrier Jet Casing Per- forator loaded with (1) shot per ft.. Perforate Interval 3112' to 3116'. Run Halliburton 7" RTTS Squeeze Tool Assembly on 3½"OD Drillpipe. Spot (50) sacks of'Class G Cement below Squeeze Tools. Set Packer @ 3045' and squeeze through Perforated Interval with maximum pressure 1700 psi. Get pressure leak-off to 1000 psi. Release Squeeze Tool Packer and reverse circulate tools clean. Spot (50) sacks Class G Cement below Squeeze Tools and re-set Packer. Displace Cement through Perfor- ated Interval 3112' to 3116' with maximum pressure of 1700 psi. Pressure leaked off to 800 psi. Release RTTS Packer and pull out of Hole after 2 hours WOC. Dress Squeeze Tools. Clean out 7"OD Casing to 3050' with 6%" Bit and 7" Casing Scraper. Re-run 7" RTTS Squeeze Tool Assembly. Spot (50) sacks of Class G Cement. Set Packer @ 3046' and squeeze with maximum squeeze pressure of 1500 psi. Clean out 7"OD Casing with 6¼" Bit and 7" Casing Scraper. Clean out 5"OD Liner with 4 1/8" Bit and 5" Casing Scraper. Drill medium soft to hard Cement from top of 5"OD Liner @ 3050' to 3094'. Run Halliburton 7" RTTS Squeeze Tool Assembly on 3½"OD Drillpipe. Set Packer @ 3047'. Pressure test below Packer to 1000 psi. Pressure test satisfactory. Change flUid in Hole and Surface Circulating System from Drilling Mud to CaCl2 Brine. Run Schlumberger 4" Hollow Carrier Casing Perforator Loaded with (2) ½" shots per. ft.. Perforate Interval 3021' to 3041'. Run Halliburton 7" RTTS Packer with Hydro-spring Tester & Dual CIP Valve as Test Tool Assembly on 2 7/8"OD Tubing. Set Packer @ 2975'. Conduct Drill Stem Test No. 10. See a{tached Drill Stem Test Data Sheet. Swab CaCl2 Brine fluid level down to 2500' in 2 7/8"OD Tubing. Release Packer and pull Drill Stem Test Tool Assembly out of Hole. Clean out 7"OD Casing to top of 5"OD Liner @ 3050' with 6¼" Bit. Run Halliburton 7" RTTS Packer Test Tool Assembly with Operator Well Name SIMASKO PRODUCTION COMPANY SIMPCO MOQUAWKIE NO. 1 Page 11 COMPLETION REP .IRT ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 10 Oct. 1978 thru 12 Oct. 1978 13 Oct. 1978 thru 16 Oct. 1978 Pressure/Temperature Recorder Carrier BUndle on 2 7/8"0D Tubing. .Set Packer @ 2976'. Conduct Drill Stem Test No. 10A. See attached Drill · Stem Test Data Sheet. Swab CaCl2 Brine fluid level down to 2500' in 2 7/8"0D Tubing. Release Packer and reverse circulate Fluid Sample out. Pull Test Tool Assembly out of Hole. CaC12 Brine: 9.0 ppg; Vis: 28; Cl-: 58,000. Run Halliburton 7" EZ Drill-SV Bridge Plug on 3½"OD Drillpipe. Set Bridge Plug @ 2974'.. Squeeze (20) sacks of Class G Cement through Bridge Plug and into Perforated Interval 3021' to 3041' 'with a maximum, squeeze pressure o~f 1500 psi. Run Schlumberger 4" Hollow Carrier Casing Perforator loaded with (2) ½" shots per ft.. Re-perforate the following Intervals-. 2847' to 2860'-, 2864' to 2868'; 2870' to 2877'. Run Baker Model FB-1 ProdUction Packer on 2 7/8"0D Tubing. Set Packer in 7"OD Casing with top of Packer @ 27~7.~.~3~L-- and bottom of Production Tube @ 2834.36'. CaCi'2 Brine: 10.0 ppg; Vis: 28; CI-: 60,000. Blanking Plugs installed in bottom of Production Packer Production Tube. Pressure test 2 7/8"0D Tubing/7"OD Casing Annulus above Packer to 2000 psi. Pressure test satisfactory. Release Packer Setting Tool and pull out of Hole. Wait on delivery of Tubing Spool, Tubing Hanger and Christmas Tree. Remove BOPE from Well. Prepare Rig for rigging down. Demobilize rental equipment. Receive and install 10"-3000 x 6"-3000 Tubing Spool. Run 2 7/8"0D Tubing Production String with Stab-in Seal Units on bottom of Tubing with Blanking installed in Profile Nipple. Pressure test entire string of 2 7/8"OD Tubing to 2000 psi. Pressure test satisfactory. Remove Blanking Plug from Profile Nipple on bottom of 2 7/8"OD Tubing. Displace CaCl2 Brine from 2 7/8"0D Production Tubing with Arctic Heating Oil. Stab Seal Assembly on bottom of 2 7/8"OD Production Tubing into Production Packer and hang Tubing in Tubing Head. Pressure test .2 7/8"OD Production Tubing String, Seal Assembly and Blanking Plug in bottom of Production Tube to 2000 psi. Pressure test satisfactory. . Run (30) joints of 1.315"OD; 1.80 lb/ft.; J55; EUE Tubing Open-ended. Total length of 1.315"OD Tubing String is 923.96 ft.. Hang Tubing in Tubing Head with bottom end set @ 936.08 ft. RKB. The 1.315"OD Tubing to function as Heater String during Well Production. Displaced CaC12 Brine out of 7"OD Casing through 1.315"OD Tubing to 75' while running Tubing in the Hole. .. Operator SIMASKO PRODUTION COMPANY W ell Name SIMPCO MOOUAWKIE NO. ] -- Page 12 COMPLETION REPURT ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 17 Oct. 1978 'thru 28 Oct. 1978 Wait on Christmas Tree. Install Back Pressare Valves in each Seal Nipple in the Tubing Hanger for each 2 7/8"0D Production Tubing String. and the 1.315"0D Heater Tubing String. Install Christmas Tree. Pressure test'Christmas Tree Seals and Valves to 2000 psi. Pressure test satisfactory. Well compieted 28 October 1978 and left in a suspended -status. Operator SIMASKO PRODUCTION COMPANY Well Name SIMPCO MOQUAWKIE NO. 1 13 Page C6,,/IPLETION REPORT ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 FORMATION TEST DATA DST #1 9/6/78 Perf .5028-5040 w/4 shots/ft. 3800' cushion Dead initially, increased to weak blow in 10 minutes. Fluid cushion to surface in 1 hour, 35 minutes. Gas %o surface in 5 hours, 30 minutes. Flowed on 3/4" choke at rate of 325.8 MCFD w/100 psi. Tubing pressure. 8 hour test. Pressures: 1st flow period IFP - 258, FFP - 578, SIP - 1269 2nd flow period IFP - 224, FFP - 358, SIP - 2115 DST #2 9/9/78 Perf 3850-3850 w/4 shots/ft. 2450 cushion Strong blow immediately. Fluid cushion to surface in 25 minutes. Gas to surface in 41 minutes. Flowed on %" choke @.602 MCFD + 38 bbls H20/day w/300 psi tubing pressure. 5 hour test. Water tested 5200 ppm chlorides. Pressures: 1st flow period IHP - 1406, IFP - 241, FFP - 202, SIP - 1465 2nd floWperiod IFP - 429, FFP - 364, SIP - 1432, FHP - 1406 DST #3 9/11/78 Perf 3011-3041 w/3 shots/ft. 1700 cushion Strong blow immediately. Fluid cushion to surface in 17 minutes. -Gas to surface in 35 minutes; Flowed on 3/4" choke @ 392 MCFD + 45 bbls H20/hr w/72 psi tubing pressure. 3 hour test. Pressures: 1st flow period IHP - 1372, IFP-- 692, FFP - 486, SIP - 1236 2nd flow period IFP - 585, FFP - 589, SIP - 1274, FHP - 1372 DST -#4 2957-2974 9/12/78 RTTS Packer set @ 2885 1600' cushion Opened well @ 1140 hrs. Good blow, immediately decreased to dead in 15 minutes. Reversed out, recovered completion fluid only - no formation water. Approximately 1000 feet of fillup on test. IHP - ~349, IFP - 812, FFP - 845, FHP - 1337 OPerafor W ell Name SIMASKO PRODUCTION COMPANY Page 14 · CC, PLETiON REP,.,RT ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 FORMATION TEST DATA Con't. DST #4A 2957-2974 9/13/78 'Tested w/Hydrospring Tester Packer set @ 2922' Open 3% hrs. Strong blow in 2 minutes. Continued for 45 minutes then decreased to very weak to dead for remainder of test. Recovered 180' of com- pletion fluid which was diluted by formation water from 8.9 ppg w/58,000 ppm chloride, to 8.8 ppg w/44,000 ppm chloride. No pressure charts in tool. Attempted to pump completion fluid (CaCl2 and Cla-Sta) into formation to open plugged perforation. Unable to pump in at 1500 psi. Allowed fluid to stand on formation 1 hr. Pumped 2 bbls fluid into formation at 1550 psi. DST 95 2912-2934 9/14/7.8 RTTS Packer set @ 2824'. Bottom of tail pipe @ 2870'. 1560' cushion. Slight blow observed in blow bucket which died. After 30 minutes perf csg w/2 spf. No blow. Ran Schlumberger Casing Collar Locator thru perforated interval and found gun had fired. Found fluid level @ 350' (1000' rise). Swabbed well to recover fresh fluid from forma- tion. After swab 20.5 bbls. chloride were 41,000 ppm, after 22 bbls. 37,000 ppm, after approximately 35'bbls. 2050 ppm. IHP - 1326, IFP - 814, FFP - 1179, IFP - 1182, FFP - 1205, FHP - 1326 Discontinued test. Test charts indicated 1000' fluid rise occurred prior to perforating. Bridge plug @ 2950' - did not hold. Set second bridge plug at 2946" and retested. DST #5A 2912-2934 9/15/78 RTTS Packer set @ 2823'. 900' cushion. Fluid began to enter hole thru perfs. -3 additional BF. IHP - 1295, 'IFP - 293, FFP - 523, FHP - 1295 Swabbed 16'BF & reversed out DST #6 9/16/78 2847-2860, 2864-2868, 2870-2877 Packer set @ 2-795, cushion 1050. Perf w/2 enerjets/ft. Immediate strong blow, fluid cushion to surface in 4 minutes. to surface in 6 minutes. choke to clean Up. Flow Rates Time 3 hrs Gas Flowed 4 'hours through separator on %" Choke FTP Rate MMCFD -16/64 948 .98 Operator Vd' ell Name SIMASK0 PRODUCTION COMPANY SIMPCO MOQUAWKIE NO. 1 Page . 15 . CO,,/IPLETION REPORT ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 FORMATION TEST DATA Con't. Flow Rates (Con't.) Time Choke FTP Rate MMCFD 2 hrs. 24/64 480 2.30 2 hrs. 32/64 300 2.52 3 hrs. 48/64 180 2.72 1st flow period: IHP - 1283, IFP - 803, FFP - 331, SIP - 1193 2nd flow period: IFP - 295, FFP - 366, SIP - , FHP - . (72 hour clock failed) DST %6A 9/18/78 Retest due to clock failure to obtain bottom hole pressure. IF 5 hrs, ISI 1 hr. 2nd flow 6 hrs, 20 minutes, final shut in 4 hours. 1st flow period: IHP - 1277, IFP - 955, FFP - 121, SIP - 1102 2nd flow period: IFP - 221, FFP - 281, SIP - 1159 3rd flow period: IFP -'1022, FFP - 1045, SIP - 4th flow period: IFP - 791, FFP - 889, SIP - 1179, FHP - 1276 Time Choke FTP Rate MMCFD hrs. 32/64 252 1.95 hrs. 16/64 990' .75 hrs. 18/64 726 1.50 DST %7 2426-2431, 2435-2448, 2451-2456 9/19/78 Swabbed to 1200'. (Approximately 1200' cushion) Packer set at 2385'. Only top 5' of gun fired. Weak blow, increased to medium in 20 minutes. GIH perforated middle and bottom intervals. Blow increased to strong. Gas at bubble hose, w/insufficient volume to unload fluid cushion. No water entry. 1st flow period: IHP - 1078; IFP - 546, FFP - 524, SIP - 556 2nd flow period: IFP - 295, FFP - 320, SIP - , FHP - 1087 DST %8 2122-2125, 2127-2146, W/2spf 9/20/58 Swabbed to 1300'. (822' fluid cushion) Packer set at 2040'. Strong blow from bottom of bucket in 2 minutes. Insufficient volume to unload fluid cushion. Pumped in 7 bbls of completion fluid to clean perfs and treat formation. Swabbed to 1800'. Slight increase in gas blow (approximately 2' flame) still insufficient to unload cushion. IHP - 916, IFP ' 374, FFP - 355, swabbed.. IFP -'208, FFP - 231, pumped in 7 bbls completion fluid and swabbed to 1800'. IFP - 209, FFP - 237, FHP - 919 Operator W ell Name SIMASKO PRODUCTION COMPANY SIMPCO MOQUAWKIE NO. 1 16 Page j ALASKA O & G CONSERVATION COMMITTEE FORM P-7 FORMATION TEST DATA Con't. DST -%9 19.50-1980 ' Perf w/2 spf (enerjet) Pac.ker set @ 1883' - Tail @ 1898 Swabbed fluid to 1330' (620 fluid cushion) Opened w/immediate strong blow. GST in 52 minutes. TSTM (2' flare) 1st flow period: IHP - 849, IFP - 377, FFP - 403 (3 hrs) Swabbed to 1800. 2nd flow period: IFP - 74, FFP - 148 (7% hrs) Swabbed to 1800'. ' 3rd flow period: IFP - 75, FFP - 110 (5 hrs) No shut in pressures obtained. DST -%9A 9/22/78 1950-1980' Re-perf w/4" casing gun w/2 hyper-jet spf. Ran hydrospring tester"(Dry tubing opened w/immediate strong blow from bottom of bucket. GTS in 5 minutes. (2' flare) TSTM. Recovered 315' fluid 35,000 ppm chloride @ top and 26,000 ppm @ bottom. IHP - 886, IFP - 76, 'FFP - 113, sIP - , FHP - 886. (2 hrs 30 minutes) DST -%9B 9/23/78 1950-1980' Retest w/hydrospring tester w/dual CIP valve. Packer set @ 1927', Tail @ 1949'. Opened with immediate strong blow from bottom of bucket. GTS in 14 minutes. (2' flare) TSTM. IF - 2 hrs, SI - 2 hrs, 2nd F - 11% hrs, FSI - 3 hrs. 1st flow .period: IHP - 883, IFP - 90, FFP - 198,'ISI - 667 '2nd flow period: IFP - 213, FFP - 77, FSI - 595, FHP - 840 DST #10 10/8/78 Perf 3021-3041 w/hyperjet spf Ran hydrospring tester w/packer set @ 2975'. Tool open 4 hrs. 15 min. No shut in. Immediate strong blow decreased to weak in 10 minutes. Dead in 35 minutes. Charts indicate tool plugged. IHP - 1355, IFP - 1314, FFP - 1315, FHP - 1356 DST -%10A 10/.9/78 Retest 3021-3041 ' RTTS'tool. Fresh water 'cushion to surface. Packer set @ 2976'. Opened tool with very weak bubble, then %" diameter stream of cushion water. Open Operator Well Name SIMASKO PRODUCTION COMPANY SIMPCO MOQUAWKIE NO. 1 I~age 17 CO./IPLETION REP ..RT ALASKA 0 & G CONSERVATION COMMITTEE FORM P-7 FORMATION TEST DATA Con't. DST #10A Con't. 19% hrs. with intermittent swabbing. Recovered 55 bbls water and CaCl2 completion fluid and small flow of gas. TSTM. Reversed out fluid w/18,000 ppm chloride. 1st flow period: IHP - 1407, IFP - 1309, FFP - 1311, No shut in. 2nd flow period: (After swabbing) IFP - 1236, FFP - 1277, No shut in. Formation Test Data Prepared By: Keith CALDERWOOD Regional Geologist Simasko Production Company Operator Well Name SIMASKO PRODUCTION COMPANY SIMPCO MOQUAWKIE NO. 1 Page., 18 I~e.¥ ,'0-69 STATE ~F ALASKA OIL AND GAS CONSERVATION COMMIT'TEE ¢ ',' W~ LDCAT GAS WELL OPEN FLOW POTENTIAl. TEST REPORT Mult~-POI.~T TEST T,..~t ,,,Il ,,,I F_.XJ ., ..... ,,,l '--J_"'] :'.,,~,,:h,., Reservoir Tyonek Format Ton 9/6/7~ lena i Lease S'MASKO PRODUCT!ON COMPANY t ~.o~,,ti,,, 424' FSL, 1261 ' FEL, Sec 36 T12N, R12W, S.M., Alaska Re~en'olr J Wellhead J CSG. Size J %Vt/Ft. Temperature 'Temperature I ,5I NA .r i NA °r mOD 17.96 %¥t/Ft. ~ J ~ O.D. I.D. 5.50 ' j 2.875" 2.441" 'l JSet $ )I;ooo ?~peUne Connection None .%Fultlple Completion (Dual or Triple) Th~s Zone Not Completed For Product Ton SIMPCO MOQUAWKI E Completion Date i Tot:~! Depth T/.?P.Y '. "? ." v ,'l, 9/8/78 j 6166 , 5028 I.D. Set@ Liner: Top 8 3050 '°,:<9 & 3Otl~-'?-, 4.276' (a q?h9= n5, . R_KB Cas 0rarity I Avr. ~rod~ J GL CasILt,.id Hydrocarbon : Or'v. ......... (Separator) ~ Length (L) i j Ridio 31CF p,r I~bl. ',i,,uid ' ti, ' '0.58q } 5OOO J 29h5 I O0 ~ None . J T~peTa~, Daniels Senior Fitti.ng w/Flange maps & Downstream Static ConnectTon Type production from each zone Dry Gas OBSERVED DATA Flow Data (]~) (~1~ Press. Diff. Tubing j Casing h Press. Press. (Line) (Orifice) { W I psig j psi~ .......... jP~r ..... ~ .. -- 6.0_65 o.7~o .4~ 148 { N~ ~~et ~ '=,, 7~. - 6.06q o.7~o 48 I 132 { . ~5 ~tnln' ' .S~ . 6-0_65 o. qoo ; o0 324 i 600 { =-- ..,.,, , { t FLOW CALCULATIO3~ Flomv Temp. Or~vlty { Compress. b p Pre~sure Factor Factor i w m psla F F { F Q ~.C:~ ,.~ ~ t ~ I ._.>_.~/~ 90,97 62 7 O, 9859 1.3_029_9 j 1. oo28~ I ~,.Y.5 . :: 5.78 { 192 78 114 7 0 9732 1 30299 I 1 00365 130~ ,.~' ; ' · ,, · · ; · _ i ,--} --,,,- ..... , { -- ' -- ~ , FI~.ESSU RE CALCULATIONS ,' , 1 P !' Cai. i w P" F Q (~ Q)~ (F Q)-~ X 1-e's p: pm _ p~ , p i p (pslu) ,t c c c , w c w .,,. ' Bottom Hole Format on Pressures; (Ps) while flowi)g was ~btained from Bottom ~ ,qol~Pr~-~'re Reco,.der. S.hut-ln formation Pressute (Pf) was obtained f-~_'~m' !!=_.: extrapOlate Hornel ~lot.cf BHP R,.~corder Data. Al}solute t"otential n 33 0 >~CF/~ O. 916 CERTZFZCATE: I, the undersigned, state that I am the Engineer of the Sima§ko 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, correct and complete to the best of my knowledge. .~/~/~//~__~~ Signature DR)LLSTEM TEST NO. 1 ',,0-69 Field , '~ STATE OF ALASKA ' OIL AND GAS CONSERVATION CONg~ITTEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT Multi-POINT TEST Test Initial. [~ Annual [~] Special E3 Reservoir W ! LDCAT 8UBM, IT IN Test Date 9/9/78 Gl)er;trot Tyonek Formation Lease SIMASKO PRODUCTION COMPANY SIMPCO MOQUAWKIE ('oun%y { LocaUon 424' FSL, 1261 ' FEL, Sec 36 Kenai [ T12N, R12W, S.M. Alaska · si,e I Wt/Ft. ] z.D. cs°~"0D 17.96 4.276 i%Vell .No. i 1 Completion Date { Total Depth T/Pay ~ Pro¢lucin~ 9/10/78 { 6166 3850 {3~i~60' lset@ Liner: Top @ 3050' RKB & Bottom @ 5242.05' RKB GL t Gaq-Ltfluid Hydrocarbon I Gratify of Ratio MCF per Bbl. Liquid iApi) 2212 00 Non~ Pipeline Conneetloh I Type Taps Daniels Senior Fitting with Flange None T~ g. D~wn~tr~arn Stat l'a Ennn~r.t{nn ' I Multiple Completio'n (Dual or Triple) TYPe production from each zone This Zone Not Completed For Product,ion . t ' Dry Gas OBSERVED DATA Flow Data , , Time ! (l~r~) (~<~)(~ Press. Diff. Tubing Casing Flomvlng No. of Flow (Line) (Orifice) h Press. Press. Temp. Hours Size Size pslg w pslg pslg *F ,.' 1...25 6.065 1.250 40' { 62 270. S_et' .@ 114 .. ~. 0.75 6.065 1.250 43 ... 88 192 3014' .115 ,~. Bottom Hole Pressu'es Not Com'?letely s.ta)ilized. I / FLOW CALCULATIONS I ~ Flow Temp. Gravity Compress. I Coeffi- Factor Factor Factor l~ate of Flow NO. I elent hw p Pressure F F F Q lV/CF/D (24 Hr.) m psla t g pv { · ~., ,. 9.760 '58.23 561.7 0.96028 1.31il 1.O0281 5_68 2. 9:760 71.26 454.'7 0.9602.8 1.3131 1.00281 69~5 ~, , PRESSURE CALCULATIONS , p P Cal. 'w W · p.~ p Q (P Q)' (F Q)-' X 1-e-~ y-* p~ -- y~ , p (psi,,) ,t c c w c W p c . .. w P t ~ ,, , , , ~.. Bottoin Hol,~ Forma {on Pressures 'tPs) while flow} m.q was ~bta{ned from Bottom ~.. Hole.,p. ress~re gec'~,rder. Sbut-{n{Format{on Press~lre (Pr was obtained fcom .!_ extrapolated Horm:r Plot on BHP ~ecorder Data. Abs,,lu%e Potential 760 MCF/D I" 1. 0000 Theorect i cal 940 ~CF/DI 3.73 Measured _ _ 'CERTIFICATE: I, the undersigned, state that I am th- Engineer of thesimask° ProduCtion Company (company), and that ! 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, correct and complete to the best of my knowledge. ,~'~ '~/,~ Signature DRILLSTEM TEST NO. 2 Form .~oo ~'leld STATE OF ALASKA OIL AND GAS CONSERVATION COMMIWrEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT MultJ-POI.~t TEST Test Tnltlal ~] Annual r~ special WILDCAT j l~eservoir Tyonek Formatlon jTest Operator ('ounty Kena i Prnducln~' Thru TBG. Size J 2½" S lMASK0 PRODUCTION COMPANYil Lease SlMPC0 MOQUAWKIE I Location 424' FSL, 1261' FEL, Sec 36 T12N, R12W, S.M. Alaska · CSO, SJze %Vt/Fi, J T.D. J60456 J Wellhead J J ~,.,.0,, T"P~'~"'"r 7"0D 20.0 Temp. etJtture NA 1Vt/Ft. O.D. J I.D. J Set "6.50 2.875" 2.441" 2963 jWell ×o. 1 t JComplet~onDate J Total Depth 9/1~/75 61i6 jT/Pay i Productn~ · 3007 ~T~-41' Set @ 3110.76 C.q-Llq.id Hydrocarbon jCravit ~* of ~Jquid (Apl) : INone . I"lpellne Connection None TypeTaps Daniels Senior Fitting with Flange Taps & Downstream Static Connection. ,~Iul[lple Completion (Dual or Triple) This Zone Not Completed Fs'r Production St 1, 4. , , Type production from each zone OBSERVED DATA FIo~v Data Time j (~ j (0(~ Press. of Flow (Line) (Orifice) Hours.. Size . Size pslg 4.25 I -- ' 3.75 J 6.065j 1.250 I 40 No' Addijt ional Dalai Reported H~re because' Diff. h %v 32 d not stabilize to I FLO~V CALC'ULATIONS other fi,low rates dJi provide, valid data.J Tubing Press, psig 384 Dry Gas Casing j FlowinK Press, Temp. pslg Packer j Set @ J 65° 295~' i Coeffi- i._ /~; Flow Tempi Or.vii7 Compress. ~o, clent~V,,w P Pressure Factor . Factor Factor Rate of Flow (24 I-Ir.) m psla F F F Q t g pv ,... ~ 9.867 41.84 54 7' 0.9850 J 1.3019 1 00265 { 413 2. J ~ · , t PRESSURE CALCULATIONS ., , %%. P · Cal. w · p' (p.~la) P-" F Q (F Q)* (F Q)-' X I-e'~ P: P~ -- P= ' 1m ., .'t ~ C %V C %V t " c .. w P ~. Bottom Hole FOrmation,Pressure ~Ps) while flow~rq was cbtained from Bo~ tom J 2. Hole Pres~.ure Recorder. Shut-I Formation PresSure (Pr') was obtained ~rom i a~,., extrapola ed Hornet Plot of BHP Recorder Data j J ~. I I' - ~,te Potential n 700 ,%[CF/D 1. 000 Assumed Clm'RTZFZCA/'E: L the undersigned, state that I am th~ Engineer _ of ~e S Jmas'ko Product ion Company (company). and ~at I am au~or~ed by said comply to make ~ts rep0~': and that th~ report was pre- pared ~der my supe~lsion and direction and that the fae~ stated there~ are true, correct ~d complete to ~e best of my ~owledge. Si~ature LLSTEH TEST NO. ~ e¶¥ :0-69 ~' STATE OF ALASKA OIL AND GAS CONSERVATION COAAJ~AII'TEE OT,Jer;~.t of' GAS WELL OPEN FLOW POTENTIAL TEST REPORT Multt-POl:~t TEST Test % ['~ Annval g lnttlal ~ j W! L¢C~T J Tyon~k Format i on j ~e=~e , PANY S IMPCO MOaUAWKI E [~o,,~,,,- T1ZN, R12W, S.M., A 10/28~78 J 6166 ~ %Ve',1 No. Kena i i aVt/Ft. J LD. J Set @ CSG. Size '' TV~ J CSO J tem~U~ J t,m~?~t, j 7"0D T~C-. Si~e I "',-" I -- II II , ' ~,, j 6.5o J z.~75 I z.44; ~ .., , jt~;o;~p~ Daniels Senior Fitting with Plunge :,!ultt,le Compleiion (Dual or T~ Z D j Type p~duction from e,ch ) ~nw ~em~. ~r~J t Y ' Compress. 4. , pR~MSU RE CALCULATIONS J <~'"'~) I ,t I ~ I ~ I ~ ' I · t ~(bsol:~e Potential . n 2700 ~icwn ~0.8~ ~FI~: l, the ~dersi~. state ~at I am th~ ~ ~e ~ Company p~red ~der my su~lston ~d ~tJon and ~at' ~e lac~ stat~ ~erm~ are ~e. corr~ ~d complete to Si~ature DRILLSTEM TEST NO. 6 STATE OF ALASKA OIL AND GAS CONSERVATION COMJ~ITTEE GAS WELL OPEN FLOW POTENTIAL TEST REPORT .~Iult~-POI.~T TEST Test Tn. m~. ~ ,~nnu~ J-"J specmi F!e!d W 1LDCAT IReservoir .Tyonek Format {on S:MASK0 PRODUCTION COMAPNY j Lo~:,ti,,n 424' FSL, 1261' Test Da:e 9/!8/78 V,' e:J NoI Kenai I T12N, R12W, S.H~; ^lasl<a T~'S. ~ CSG. j T~m~r~:ure Temperature X , I '~3 'F J NA?J 7"0D ~ 20.0 , 2~" ', 6.50 ~ 2.875 2.441 Connection None :'.::'.*.,..-:'-e Comple:ion (Dua! or Triple) S!nc!e Completion - This Zone Time of F:ow { (Line) ~ou:s I Size ! .83 i 6.065 _ 2.30 .~ 6.065 I (Orifice) Size ~.75o ' ~.75o I.D. J Se+. ~ 6.456 ~ ($epar~or) Le::gth (~) ' R.',tio .',ICF per Bbl. Ll,:..,.[d ' .tpi; 2834 0.5i50 28~4 1644 O0 "Ne~_e ' I TrpeTaps Daniels Senior Fitting w{th Flange Taps & Downstream Stat i_ c~.n t Type produotion from e~oh zone ~ · ur_z_~s_ OBSERVED DATA Flow Data Press. I Dill h ~ -- 67 { 16 70 ! 72 FLOW CALCUT,ATJONS 1 I Flow Temp. Factor :Pressure F psla, t Tubing T Casing Press. I Press. psig J psig , -- 1008 ! S~.t @ 726 J 2735' Te.m,,p. 'F o5 81.7,0 J 0.7680 84.7 J ' 0.9636 Gravity 'Factor g 1.]1~1 1.3131. Compress. Factor : Rate of Flow F 1. oo4 ! 6_2_3 , { A',s,,lute Potential 2350 PRESSURE CALCULATIONS . p , J Cal. w (psla) 1~ P Q (F Q)" X 1-e'w P" P~ -- P~ P ' ' ,t c c J ' ...... ,-i -~~+'~n Pdessure j(Ps) while flowi~q wms ~btained from Bdttom ex~~',ed Hormer Plo~ of BHP~RQcorder Data. MOW~ I 0. B1 6~ CERTIFICATE: I, the undersigned, state that I am th,, Engineer , of the Sima~ko Product'ion Company (company), and that ! 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. correct and complete, to the best of my knowledge. Signature DRJLLSTEM TEsT NO. 6A Simasko Production Company P.O. BOX1515 * ANCHORAGE, ALASKA99510 * (907) 277-5932 · (907) 274-4591 · TELEX26-338 November Z8, 1978 State of Alaska Department of Natural P~esources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 At-tn: Mr. Harry Kugler Gentlemen: Transmitted herewith are the follbwing materials pertaining to the SIMi~CO Moquawkie #1 well located in Section 36, TlZN, i{lZW, S.M.: Item ................... No :..of~ Pi.ece .s Depth,. /DIL, Z" ~ 'DIL, 5" ~'"'BHC, Z" /BHC, 5!' ,- FDC , 5" ~FDC/CNL, 5" -' PML, 2" - PML, 5" ,..HDT, 5", Run ~1 - HDT, 5" .P~un #2 .... Temperature Log .... Mud.Log, 2" 1 blueline, .1. sepia 85-6146' 1 blueline, 1 sepia 85-6146' 1 blueline, 1 sepia 85-6117' ! blueline, 1 sepia 85-6117' 1 blueline, 1 sepia 845-6110' 1 blueline, 1 sepia 845-6110' 1 blueline, 1 sepia 845-3113' 1 blueline, 1 sept.~i 845-3113' 1 blueline, 1 sepia 845-3114' 1 blueline, 1 sepia 3.110-6090' I blueline, i sepia 2510-5090' I blueline, I sepia ! 100-6166' !/ one copy of this letter. Sincerely, ~ I~1~0I' Keith W. Calderwood Alaska Regional Geologist Please acknowledge receipt by signing and returning Enclosures: As Noted above Received by:.,~ ..... '~/'- - ,.~ ' Date, t ti AMERICAN STRATIGRAPHIC P.O. BOX 2127 · ANCHORAGE. ALASKA TRANSMITTAL COMPANY Dear Sir: We have transmitted this date via - ____samples from the: .. Please acknowledge receipt by returning one copy of this transmittalJ ',/>~/:~ Very truly yours, Receipt acknowledged American Stratigraphic Co. date Reffi'arks: 1'~rm l','o. P---4 REV. IN' DUPLICATE OIL AND GAS CONSERVATION COMMI'i-i'EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS %h,,'" so-28 -2oo o ..=. NONE ~ '"' INDIA~ A~T~ O~ TRIBE NA~E' Cook Inlet ~gion wz,.,. Exp 10 ra to ry ~. ~.,.,x~E OF OPZaATOR Simm. sko 'Production Company ~.' ADDR_FS$ OF OP~T~ATOR ' P.O. BOX 1515, Anchorage, AK 99510 '4. LOCATION OF W~t.~."~.t.! "' 424' F~L, 1261' FEL, Section 36, T12N, R12W, S.M. S. L~-'IT.F.a,I~I OR LEASE NA, ME . SIMPCO Moquawkie 9, WELL NO 1 Inc. I 10. FIF-T.~ A-%'D POOL. OR WILDCAT . ':" I. __! Wildcat '.'.',,.-'i ~' , ,l. sec.. T.. R...~,.. morro'.~, ~o~ " o~~ ~ :',-:C . ~. ...... Section 3~, T1~y.':'A12_~L~ s..~ ~ .... .~: 11 P~IT ~O. ' ..... 78-47 REPO.~T TOTAL D~H AT F--ND OF MONTH, CHANGES IN HOLE SIZE, CASING A/~D C~-%~F2~TIN~ JOBS INCLUDI.~'G DEPTH SET A,N"D VOLLrlgt'ES L'SED. PERFECTIONS. 'rESTS A.1%"D ]RESULTS. FISHING JOI~. JUNK IN HOLE A_ND SIDE-TRACKED HOL,E AND A~NY OT~r~R SIGNIFICANT CHANGES IN HOL$ CONDITIONS. 1 10-1-78 10-2-78 lg.-3-7 8 .10- 5-.78 ' 10-6-78 10-7-78 10-8-78 10-9-78 10-10-78 OCTOBER' Squeezed perf. 2957-2974 w/50 sx.Class G cement. Drilled cement and mi.lled bridge plugs t0.·3008 ft. Perf 3000-3002 w/2 hyperjet spf. Squeezed perfs W/25 sx Class G cement. Cleaned' out cement and junk to top of 'liner. @3050. Cleaned out 5" liner,from 3050 to 3175.. Perf 3112-3116. w/1 hyper.~et spf. Squeezed perf 3112-3116 w/50 sx class G .cement.. ReS'qUeezed w/~'0 sx.class G cement.' 'Changed drilling, fluid to CaCl2 completion fluid. DST %10 Perf 3021-3041 w/2 hyperjets spf. Packer set @29.75' · No. cushion. Immediate strong blow decreased to' weak in 10 min. Dead in 35 min. 'Tool plugged. DST %10A Retest perf' 302.1-3041. RTTS packer @2976. Filled tubing with fresh water. Opened tool wi'th very weak blow swabbed to strong blow. Recovered 55' bbls completion'fluid and water plus small amount of gas, .TSTM.' Set bridge plug.@2'974 and squeezed 'perf 3021-3041 thru bridge plug w/25 sx class G cement. ~perf 2847-.2860, 2864-2868,.. 2.8..70-2877 w/ .2 hyperjets Spf. Set .production packer @2778 w/tailpipe @2834. Ran 2 7/8" OD tubing.. . . Ran 30 joints (923.96') 1.315" OD J55.EUE tubing. WO x'mas tree· Installed X-mas. tree and pressure tested to 2000 psi-held OK. completed well October 28, 1978' RECEIVED 10-11-78 10-15-78. 10-16-78 10-2"8-78 . NOV o F tut,~i~_, ef 0tl & Gas ~ns~rvation ' · . ~,'~ ..... /- I .... ~..-- -[:...~ ' ~ - ~ .... , ~ . / Ill . L J I I I I J I LIII IIIII III LII Il II III _ I NOTl--Report on this form il required for tach oolendgr ~nthI regardless of tho Status of operations, Qnd must ~ filed Jn duplicate with the ~il end gas conservation oommiffee by the IB~ of the suoc~ding mon~. unle. otherwise directed. · IMPCO Moquawki e #.1 Test Data C'ON-FIDENTI/ L 5 DST #1 9-6-78 Perf 50 28-50 40 w/4 shots/ft. 3800' cushion Dead initially, increased to weak blow in 10 minutes. Fluid cushion to surface in 1 hour, 35 minutes. Gas to surface in 5 hours, 30 minutes. Flowed on 3/4" choke at rate of 325.8 MCFD w/100 psi. Tubing pressure. 8 hour test. Pressures: 1st flow period: IFP-258, FFP-578, SIP-1269 2nd flow period IFP'224, FFP-358, SIP-2115 · . . .. DST #2 9-9-78 .' ,. Perf 3850-3860 w/4 shots/ft. 2450. cushion · . Strong blow immediately.. Fluid cushion to surface in 25. minutes. Gas %o surface in ~.1 minutes.. Flowed on %" choke @602 MCFD + 38 bbls H20/day w/300 psi tubing, pressure. '5 hour test. Water tested 5200 ppm Chlorides.' .. Pressures: lst' flow period: IHP-1406, IFP-241, .FFP-202, SIP-146'5 2nd flow period:' IFP-429, FFP-364, SIP-1432, FHP-1406 · ..~i~ .... , . DST #3, 9-11-78 . .. ., Perf 301i-3041 w/3' 'shots/ft' 1700' cushion. " Strong blow immeaiately. Fluid ·CuShion.to surface in 17 '. . ' minutes. Gas to surface in 35' minutes. FloWed on 3/4" choke '. ., @392 MCFD +. est 45 bbls H20/hr w/72 psi tubing pressure. ~ 3 hour test. · Pressures: .lst flow period: IHP-1372, IFP-692, FFP-486, SIP-1236 . 2nd flow period: IFP-585, FFP-589, SIP-1274, FlIp-1372 DST ~ 4 2957-74 9-12-78 RTTS Packer set @ 2885 1600' cushion. Opened well @1140 hrs. Good blow, immediately decreased Go dead in 15 minutes. Reversed out, recovered completion fluid only - no formation water. Approximately 1000 feet of fillup on test. IHP-1349, IFP-812, FFP-845, FHP-1337. · · , DST ~4A .. 29 57-2974 9-13-78 RECEIVED Tested w/hydrospring tester. !978 Packer· set .@2922' '. Open 3% hfs. DlvI~I{)fl (~ Oil & ~'as Ar~:l'~r~g~ ',' St=o~g' blo~ '&~ 2 m%~utes. Co~t&~ue8 ~o= 45 m~utes tbe:' 8ec=ease8 to ~e=~a~ to'~ea~ ~o= =ema~Se= o~ test. ~eco~e=e~ 180 ~ o~ com~letio: ~1ui~ whit5 ~as 8ilute~ by ~ate= ~=om 8.9 ~g ~/58,000. ~m 'cblo=~Se., to 8.8 ~9 ~/~,000 ~m cblo=&~e. ~o ~=essu=e cba=ts ~ tool. ~ttem~te~ to ~ com~let&o~ ~lu&d (~a~12 a~8 Cl~-Sta) .&nto ~o=mat~o~ 'to op~ Blu99e8 9e=~o=atio~;.'. D~able to 9m9 ~ at. 1500 ~si. ~11o~e~ ~lu~d to sta~8 o~ ~o=mat~o~ 1 b=. ~um~ed 2 ~s zlu~ &~to ~o=mat&o~ at 1550 ~s&. " .. . , , . ,, ., , , ,. ., ,, , , ,, DS~ ¢5 2912-2934' 9-~-78 '. '" RTTS Packer set @ 2824". 'Bott@m of tail pipe @ 2870' 1560' cushion. ' ' · · , . Slight blow observed in' blow bucket which died, After 30 minutes perf' csg w/2 spf.' No blow. Ran Schlumberger casing collar loca'tor thru perforated interval· and .found gun had .. fired.'. Found fluid level @' 350' (1.0'00' rise). 'Swabbed well to recover fresh fluid from formation. After swab 20.5 bbls, " chloride were 41,000 ppm, after 22 bbls. 37,000 ppm,. after' approximately 35 bbls 2050 ppm. ,.. IHP-1326, IFP-814,. FFP-1179,..IFP-1182,FFP_120'5,FHP_1326. ".,. . ' . · Discontinued test. Test charts indicated 100'0" ..fluid ~ise' ocurred prior to perforating. Bridge plug @ 2950'.- did not hold. Set second bridge "plug at 2946' and retested. DST %5A 29122934 9-15-78 RTTS Packer set @2823. 900' cushion. Fluid began to enter hole thru perfs. Swabbed 16 BF & reversed out 3 additional BF. IHP-1295, IFP-293, FFP-523, FHP-1295 k_';'~t TM ... DsT %6 9-16-78 2847-2860, 2864-2868, 2'870-2877 Packer set.@2795, cushion 1050.'·Perfw/2 enerjets/ft · T. mmediate strong blow, fluid cushion to surface in 4 min. Gas to. surface 'in 6 minutes. Flowed 4 hours through seperator on 2. choke to clean up. Flow Rate s Time " FTP 3hrs 2 hrs 2 hrs 3 hrs Choke '.' 16/64 24/64 32/64 ·48/64 Rate MMCFD :, 948 .98 '480 2.30 . 300 '2.52 180 · '2.72' 1st flow period: 'IHP-1283., IFP-803, FFP-331, SIP-1193 2nd flow period: IFP-295, FFP-366, SIP- , FHP- ,, (72-hour clock ·failed) DST %6A 9-18-78 .' Retest due.to Clock failure to.obtain bottom hole pressure. 'IF 5 hrs, ..ISI.1 'hr. 2nd.flow 6 hrs, 20 'minutes,. final shut in 4 hrs." ' ,. '. ., 1st flow period: IHPr1277,'. IFP-955, FFP-121, SIP-1102 " '2'nd' flow' period: "iFP-221, FFP-281', 'ST..P-1159 '" ' :' ..'3rd 'flow. period: ' IFP-1022, FFP-1045, SIP- ""..' ..... 4th flow period: IFP-791, FFP-889, 'SIP-iI79, FHP-1276 Time ,'. Choke FTP 'Rate MMCFD 4% hfs 32/64 2 hrs .. 16/6.4 2 hrs 18/64 '252' 1.95 990 ' .75 726 1.50 'SI/VIPCO 1V!oqUawkie ~/1 CONFiDENI"IAL DST #7 2426-31', 2435-48', 2451-56' 9-19-78 Swabbed to lZ00'. (Approximately 1200' cushion) Packer set at 2385'. Only top 5' of gun fired..Weak blow, increased to medium in 20 minutes. GIH perforated middle and bottom intervals. Blow increased to strong. Gas'at'bubbleihose, w/insufficient volume to unload fluid cushion. No water entry. 1st Flow Period: IHP 1078, IF 546, FF 522t, SI 556 2nd Flow Period: IF ?.95, FF 320, SI -, FHP 1087 DST ~8 . 2'122-25', 2127-46', w/Z spf 9"Z0 -78 Swabbed to 1300'. (822' fluid cushion) Packer set at 2040' .. Strong blow from bottom of bucket 'in 2 minutes. Insufficient volume to unload fluid cushion.. Pumped in 7 bbls of completion fluid to clean'peris and. treat formation. Swabbed to 1800'. Slight increase in gas blow (approximately 2' flame) still insufficient to unload cushion. .. IHP 916, It' 374; FF 355, swabbed. ' · . IF 208, FF 231, pumped in 7 'bbls completion fluid and swabbed IF 209,'FF 237, FHP 919 to .1800'. . C'ONFIDEN-I'IAL DST #9 9-21-78 ' · 1950-80 Perf w/2 spf (enerjet) ' Packer @1~83 -Tail @1898 Swabbed fluid to 1330' (620 fluid cushion) Opened w/immed strong blow. GST in 52 min. TSTM (2' flare) let flow period: IHP-849, IFP-3'77, FFP-403 (3 hfs) Swabbed to 1800' 2nd flow period: IFP-74, FFP-148 (7% hrs) Swabbed to 1800' , . 3rd flow period: IFP-75, FFP-110 (5 hrs) No shut in pressures obtained. DST ~.9A 9-22-78 . 1950-1980 Re-perf w/4" casing gun %~2 .hyper jet spf. Ran hydrospring tester (Dry tubing opened w/immed strong blow from bottom of bucket. GTS in 5' minutes. (2' flare) TSTM. Recovered 315' fluid 35,000 ppm chloride @ top. and 26,000 ppm @ bottom ..... . . IHP-886, 'IFP-76,'FFP-i13, SIP-, FHP-886.. 2 hrs 30'_mim~es flow Period. ~'~ C ~ I V' !~',: ,, DST #9B 9-23'~78 ~'~' '4 i~'.~ ~;1~!} .. . ~! ~:~ ,, . . .19 50 - 1980· ' . ,,1.~,~.~. . ' ': '" ¥;¥'~',:i~:~ ' ' Retest w/hydrospring tee%er w/dual CIP valve. P~$~.."~01927', Tail .~19.49'. Opened with i~odiate strong blow from hot.tom ., of bucket. ' GTe in 1~ minutes 2' flare IF 2 h'rs, SI 2hrs, 2nd F 11% hrs, FSI .3 hrs. . 1st flow period: -IH~-883~ I~-90~ ~'198~ 2nd flow'period: I~-213~ ~P-77~ ~8I-5~5~ ~H~-8~0 ".. ,.. . ,. DSg ~10 10-8-78 . . '" ' ~erf ~021-3041 w/hyperjet 8P~ .. .. ". ' ... , , ,. .... '~n hydr°sprin~ tester w/packor.set 029.75.,.,. 'gool".open'~ hr~ ,... . ., '.' .....'..:.~.'.'..'.15. m~n..' .. ~0. Shut '~n. :: "I~ed'~ate'-.S~on'~: blow docroased 'to weak ' '"" .'~ ." .' . . . . . . , , ,' .. , .... '.......:.'~...... in 10 'min'' Dead .in ~5' '~n.' j. char~s..'~indicaee tool' .plu~ed.' .:~......: ........?':.:..'::.:... . ... ', .. , ,. ,.,... ,..~, . ,~ ..., .. - ,, ,., . ..., " . . ~ . ,.,'-.. . ,., IH~-].~55 ~ .I~-131~ '~p-1315~ ~H~-1356. .DST 910A 10-9-'78 Retest 3021- 3041. RTTS tool. Fresh water cushion' to surface. Packer set @2976'. Opened tool with very weak bubble, then ¼" diameter stream of cushion water. Open 19¼ hrs with intermittent swabbing.. Recovered 55 bbls water and CaCl2comple.tion' fluid and small flow Of gas. CONFIDENI'iAL DST 10A (Continued) TST~. Reversed out fluid w/18,000 ppm chloride. 1st flow period: IHP-1407, IFP-1309, FFP-1311, No shut in. 2nd flow period: (After swelling) IFP-1236, FFP-1277, No shut in. R, ECEIV,E.D i Form .~0. ~L-'%r. 3-1-70 1. O,L [] G*, ~ OTRZ, Exploratory ~K:L wELL ',. ~A. ME OF OPEI%ATOR 6 LgASE DESiGNATIO~ AND MONTHLY REPORT OF ._. , . AND WORKOVEROPEl A.~.~T ' . ,, - .... .., ~..,.:~ ~' ' Cook Znlet ne~'-~?.,,~n~ ~ ~ -, , ,, 3 ADDRZSS OF OPEP,.ATOI% " '~ ~..0. Box 1515, Ancho. raqe, .AK 9q510 4. LOCATION OF ............ ~, t~,II g ~.~t,~ ~L~i:l:::~J!'V,?:;.ii'>i] _ 7 8-47 s~? A~'~m VOLU'~r~S US~. Pm~'O~AT,O~S. U'~STS A~,7~B~ia}im. ~'mmNo Jo~s. ;u'~ m HO,.~- A~D S~D~-r~¢~-D HO~ AND ANY OT"z.r~P.. SIGNIFICANT CF~2kNUF_,S IN I'{OX.~ CONDITIONS. . SEP TE~.~BER 9-1-78 to 9-5-78 9-6-78 9-8-78 9-9-78 9-J.0-78 9-11-78 9-12-78 9-14-78 9-15-78 9-16-78 9-18-78 9-19-78 Perf 3830-33 w/ l s ho t/ f t .. Squeezed w/15 sx class "G" cement. Cleaned out to 5242 PBTD. Perf 5028-5040 w/& JSPF. Packer set @3018.w/ tailpipe @ 5000' (See attached DST data). DST #1 Set EZ' drill SV Cement 'retainer @5013 .and spotted 1~ sx Class "G" neat cement on top of retainer. Pressure test found leak in.perfs @4050-55. Set EZ Drill cment, retainer @4011 a~d sq.us.ezed, w/25 sx Class "G" Cement. DST 92, Set RTTS.packer 83014' w/tailpipe. @3813. Perf 3850-3'860 w/4 jspf. Set Halliburton EZ Drill .SV retaTner @ 3792 and _Spotted. 15 sx Class "G" ne:at.',~:ement on. top of retainer. DST 93, .Perf 3011-3041 w/3 enerjet spf. Set Halliburton E'Z Drill SV retainer @2992 and squeezed .perfs 3011-3041 w/33 sx Class "G" cement.. DST. 94,.'Perf' ~957-2974 w/enerjet spf. Set Halliburton EZ' Drill SV 'bridge plug on Schlumberge.r wi.reline @2950. .DST 95 , .Perf. 2912-2934 W/2'ener~et spf. ~ST charts indica'ted leak from wireline bridge plug @2950'. Set HallibnntOn EZ Drill' bridge plug @2946. Swabbed &tested· Set EZ Drill bridge plug at 2900. Stabbed into bridge plug and Squeezed perfs 2912-'2934 'w/25' sx Clhss "G" cmt.. DST 96, P. erf-2847-2860, ·2864-2868, & 2870-2877 w/2 ene. rjet spf.. Flow.tested. Set Halliburton EZ Drill SV bridge plug @2793'. Spotted 25 sx Class "G" cmt on top of bridge plug. DST 97, Perf 2426-2456 w/2 energet spf. Gas flow TSTM. Set Halliburton EZ Drill SV bridge plug @2381. SZGWSD~'~~',~7~'~~~-'"';~"gi~ Alas.ka G.eglogist ~X~ 10-16-78 NOTE~Rep0rt on this form t~ required for much colend~r ~th% r~gordless'of the Itatus of operations, ond must ~ flied ~n duplic"ale with the oil mhd gum c~nmervot~n comml~ee bythe mm of the lucc~din9 mon~, unle~ otherwise directed. tCONFIDENTIAL MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS (Continued) SEPTEMBER SIMPCO MOQUAWKIE 9-20-78 9-21-78 9-22-78 9-24-78 9-25-78 9-26-78 to 9-30-78 Squeezed perf 2426-2456 thru bridge plug w/25 sx Class "G" cmt. DST 98 , perf 2122-2125, 2127-2146. Set packer @2004 w/2 enerjet spf. I~ediate medium blow increased to strong after swabbing. Flowed gas @rate TSTM. No fluid entry. Set Hallibnnt~n EZ Drill bridge plug @2072. Squeezed perfs 2122-2146 w/25 sx Class "G" cement. DST 99, Perf 1950-1980 w/2 enerjet spf. Packer set @1883. Fluid cushion 620'. Immediate strong blow. Gas to surface in 52 min. TSTM, Killed well. DST 99A, Re-Perf 1950-1980 w/2 hyperjet spf. Packer set @1924. No cushion. Immediate strong blow. Gas volume TSTM (2' flare). DST 99B, Restest 1950-1980. Packer set @1927'. No cushion. Immediate strong blow. Gas flow TSTM. Squeezed perf 1950-1980 w/25 sx Class "G" cement. Replaced CaCl, completion fluid with X-C p~ymer drilling fluid. Prep to drill out bridge plugs and retest intervals 3021-3041. "" Milled out bridge plugs and drilled cement to 2986. RECEIVED ........ ~ ...... j,~,. REV. 3- I-?0 STATE ( .LASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Exploratory SUBMFT IN DUPLICATE 2. NA~ME OF OP~.~TOI:t Simasko Production Company 3. ADDRESS OF P.O. Box 1515, Anchorage, AK 99510 4. LOCATION OF WF-.LL 424' FSL, 1261 FEL, Section 36, TiZN, R12W, S.M. 8~1-78 to 8-4-78 8-5-78 C AP1 NL/~iETLICAt. CODE 50 -283 -20060 LEASE DF~IGI~ATION AND SgI~IAL NO. NONE 7. IF INDIA)~ AI,OTTEE OR TRIBE NAME Cook Inlet P~egion, Inc. 8. L.~IT.F.~R. NI:OR LEASE N.-~ME SIMPCO' Mo quawkie 9. WELL NO 1 10. FIELD A_ND POOL. OR WILDCAT W ildc at Sec. 36. T12N, 1%12W, S.M. 12. P~RMIT NO. '/8-47 13. REPORT TOTAL DEPT~ AT F--ND OF MONTH. CHA.X'GE~ IN HOLE SIZE. CASING A/~rD C~WIF~NTING JO~S ~NC~I,L;..D_ING D~ Ah'D ~Y O~ SIGNIFIC~ ~G~ ~ HO~ ~ITIONS. .. AUGUST 1978 Drill 8 3/4" hole from 860' t° 2885' ..OiWSjOl}. Cut.core ~1 Z$$5-Z~05', recovored.ZO~. Drilled 8 ~/4'hole to 3115'. 8-6-78 8-'/-78 Ran wireline logs. DIL, BHC, FDC/CNL, Micro-p~.o~i~ty and HDT from 850-3115'. Ran Schlumberger RFT wireline tester (8 test., attempted. ) , . Ran 7" OD 20 lbs/ft casing to 3110.76' and cemented w/ 600 sacks class "G" cement. 8-9-78 to 8-21-78 Drilled 6~'.' hole from 3111' to ,6166'. 8-22 -78 ,8-Z4-78 Ran Schlumberger wireline logs: DIE, BHC, FDC/CNL, and HDT to 6166' total depth. (Driller) ., Ran 5" OD liner (17.96~lb/ft} from 3050-5Z4Z' and cemented'wit'h 140 sx Class "G" cement (lst stage) and 115 sx class "G" cement throu~l~, perforations 4050-55' w/ 1 spf. (Znd. stage). 8-3o-78 Gleaned out hole to 5144' and ran Schlumberger Cement Bond. log in 5" and 7" casing. 8-31 -78 , , , , ,../7".,_/". _, ........ NOTE--Repo,t on this fern 18 required fo, each calendpr ~.tht regardless of the status of operations, and must ~ flied i. dupli~te with 'the oil and gas conBervatbn commi~ee by the 15~ of the succ~dlng mon~, unle~ otherwise directed. Perforated 5"liner 3917-20' w/1 spf and squeezed i~.!/Z5 sx class "G" STATE ( ALASKA OIL AND GAS CONSERVATION COMMIYrEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS =~-_-_ [] G,S=zL,. [~ aT.". Exploratory .N'A~-- OF OP~TOR Simas,ko Production Company .~DD~-_--SS OF OP~TOI~ P.O. Box 1515t Anchora.q~,r' AK LOC&~ON OF 99510 SUBMIT L~ DL~PL1CATE 424' FSL, 1261 FEL, Section 36, T12N, R12W, S.M. AP1 NUAiERIC~J. CODE 50-283-20060 6 LEASE DESiGI%IA~--ION .~.ND S~IAL ~O NONE IF INDIA)~'. ALOTTT_,E OR TRIBE NAME Cook Inlet Region, 8. L.~IT.F.,%.,':~2,! OR LEASE NAME SIMPCO Moquawkie 9 WELL 10. FIELD A-ND POOL. OR WILDCAT Wildcat II. S~.C.. T.. R...",I.. (BO'FI'OII HOLE oB, rF-,cr n,w_D Sec 36, T12N, R12W, 12. PEP~MIT NO. 78-47 . .~.EPC, RT TOTAL D~-i~H AT F_/N'I~ OF l%iON'r~, CHA. NGES IN HOLE SIZE. CASING AND C~%{ENTING JO~.S INCLI:DING DEPTH SET A.~'D VOLL'~,IES USED. PERFORATIONS. TESTS AND P, ESULTS. FISHING JOBS. JD,'~,'K IN HOLE A.ND SIDE-TRACKED HOLE A.\'D A~*¢¥ OTHi/;R SIGNIFICANT CHA~GES IN HOI~I CONDITIONS. SoM, JULY, 19 78 7-23478 Move in rig from SIMPCO Kaloa '7- 24" fihr%%::..-:...-:. 7- 26 Rigging up 7-27-78 7'29-78 7-30-78 7-~1-78 #1 Spud well afl 2015 hrs. Drilled 8'%" hole to 861'. Ran .Schlumberger Dual Induction and Sonic Logs to logger. depth of 864'. O. pen 8%" hole to 12¼." to 849 ft. '. Ran 9 5/8" csg to 847 ft cemented with 330 sacks Class "G" cement.. PresSure tested BOP Equipment. Prep to dr~il ahead. '.RECEIVED ! '? t97§ Division ~f 0[[ & ~ ~'e'~ilit~ation . ~ ~ - ~..~z~/~ ~ z~.~m~""~t t~_~.o.,~ ~ t~ ~ ~ ' Aia6ka ..... ' s,~=~~Y~~~~:~ Regional 6eoloqist ~,, 8-16-78 aport on this form is required for eo~ calendgr ~nth~ regardless of the status of operations, and must ~ filed ~n duplicate with the oil and gas conservation Commlffee bythe 15~ of the su=c~ding mon~,unle~ otherwise directed. CON'FJDiEN'II,A/ ,,, DEP~ OF NATURAL ~ Divisicm of Oil and C~;~ Ocmservation Lonnie C. Sm/th Chief Petrole~n Engineer Ben LeNoxman ~ Petrole~ ~pector ~8, 1978 BOPE Test - Simpco' s M0quawkie #1 Wednesday,. August 2, 1978 - I departed the office at 9:00 AM for a 9:30 AM showup and 10:10 AM departuze via Simpco chartered Cessma 404 frcm Merrill field to old Tyonek airstrip across Cook Inlet, arriving there at 10:35 AM. We were mst at the airstrip by Max Johnstooe, Brinkerhoff r~ %60-H toolpusber, and proceeded to the up was in progress. Temperature was +70v F, clear skies and no wind. Tests began at 10:20 PM with shoe cm 9-5/8" at 847'. Pressuring was with t~o stage ~~ pump and clear water. Blind ra~s, ~o wing valves 1/ne tested to 3000 psig. Seven valves and fourteen flan~ in the choke manifold tested to 3000 psig. Both manual adjustable ~kes open and fully closed. Annular prevemter tested to 1500 psig. However, attempts to test the pipe rams failed because a tool joint was in exactly the wrumg place just above the ~t plug. Tests were suspen~ at 11:40 PM. An~age ~d Kenai at~x=~ we~ ~~/ng below mh~h~s. Z t was decided to weld a flat p/ate, atop the test plug ~nd then weld the box end of a joint of drill pipe to the plate. While fahricatiom of the tes~.plug assembly was ~y, I toured the locaticm which was well .organized, reserve pit well built, and rig in good repair. However, the ~11 sign bad not been received. Dart type floor valve was in place befcxe the drawworks. Tests resumed at 2:00 AM with. kelly cock and lower kelly valve testing to 3000 psig. Accumulator pressure was 1500 psig and N2 backup bottles tested 1900, 2000, and 2100 psig. We then turned the af~umula~ tmmp off and closed both pipe. rams and annular pre%m~ters simultaneously. August 8, 1978 A~maklatDr pressure ~ to 950 psig an~ ~ steady for five ~s. Aecumula~ pump was ~ ~ ~ an~ aocu~zla~ ~essure built back ~o 1500 psig in five minutes. Finally, the pipe ra~ ~est~d to 3000 psig and t~sts were oo~cl~ at 4:00 ~M. A field in~c~ report ~s p~ with a copy given to Merle I~ng, original to this mp to I de~ Tyonek ~strip via regularly scheduled Cessna 404 at 11:15 AM arriving in Anchorage via Kenai at 11:55 AM and at my ~ at 12:25 ~M. o. .'.. t a Oil and Gas Conservation Comml~ .~.e " Field Inspection Report Drlg. Permit No.~~? - - ~ _ - Well/~-~L-F~n Sec~T~___R/~l~,~,~ M Operator ~'~/~-_~.~N~ Represented bYL-'~/.~./~-A~_~ame & Number~~-~_~/ Satisfactory Type I n'~s p~~ Yes No Item (~f'r_ocation,General ( ) (~)~ 1. Well Sign (~l~ ( ) 2. General Housekeepin~ (~)~- ( ) ~. Reserve Pit-( )open( )filled (~ ( ) 4. Rig ( ) Safety Valve Tests ( ) ( ) 5. Surface-No. Wells ( ) ( ) 6. Subsurface-No. Wells ( ) Well Test Data ( ) ( ) 7. Well Nos. , , , ( ) ( ) 8. Hrs. obser , , , () () 9. BS&W _,--,--,-- ( ) ( ) 10. Gr. Bbls., , ( ) Final Abandonment 11. P&A Marker () () () () () () Yes (~)~ ( ) (~() (~Y~ ( ) (~)~ ( ) (~() (~)~ ( ) (~)~ ( ) (~)~ ( ) (~)~ ( ) (~r~ ( ) (~() (~() (~() No Item (~BOPE Tests .15. _~'Casinq set 0~~'~ 16 TesL fluia-(~tr.----~-( )mud ( ) oil 17. Master Hyd. Control Sys.-/~,~.p. sig 18. N2 btl s ~,~-~_~ ps i 9 19 Remote Controls 20. Drilling spool-~"outlets 21 Kill Li~e-(~)~'Ch~c~ valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs_~__flas/~/" 24 Chokes-(~/i~emote( )Pos.(-~;~dj: ~-~-' 25. Test Plug-(~)~'ellhd( )cs.q( )none 26. Annular PreventerF'_~F_~psi.a 27. Blind Rams~.~Slm 28. Pipe Rams_~~Dsiq lZ. Water well-( )capped( )plugged (.~l~, ( ) 13. Clean-up (~ ( ) ( ) ( ) 14. Pad leveled (~() Total inspection observation time.?'_'~hrs/dm~j~ Total number leaks and/or equip, failures Remarks 29. Kelly & Kelly-cock ~,psig 30. Lower Kelly valve 31 Safety Floor valve,S(' )BY (~)i)art cc:~z__. ~_,~.?4Notify in days or when ready Inspected by' June 26, 1978 Pe~ No. 78-47 P. o. Bo~ ~ An~, Alaska 99510 Dear S~r: olmxa~ms ~o= m~ ~e ~ by the ~F~bifat Ooez4JZmte~"s offios, Punsu~t t= As. 38.40, 'Local F~e ur~= S~ate .,Leases, the Alaska ~t of nabor is ~ r~ified of tbs issuan~ of th~s ~t ~o t~s~ of '~ ~t~ ~ befc=e surfac~ casing shoe is -2- June 26, 1978 In the event of suspe~s~m ~r aba~kmment please give this off~ce adequa%e advance notificatic~ so that w~ m~y ha~e a witness present. Depa~-¥~t of Fish and Gam~, _~bitat Sectic~ w/o eric1. Divisic~ w/o encl. ., .. .o STATE OF ALASKA SUBMIT IN 7' (Other instr~J API No. 50-283-20060 OIL AND GAS CONSERVATION COMMITTEE' APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK in. TYPE OF WORK DRILL JX"I DEEPEN J-] PLUG BACK J-] b. TYPE or WELL I'%1 I.r"~ O&8 SINGLE -'.~,. ,, --.,-L r-J OT.ER Exploratory .o.~E J--J .,.,..,r,..._,,.E FI_ 2 N A ,%1EOF OPEP. ATOR SIHASK0 PRODUCTION COMPANY 3. ADDRE~SS O~ OPF,.R.A"~DR 4 LOCATION OF WELL At surface P.O. Box 1515 Anchor. age, Alaska 99510 750'FSL, 1350' FEL, Sec 36, T12N, R12W, S.M. At proposed prod. zone 750' FSL, 1350' FEL, Sec 36, .T12N, I3. DISTA.NCE IN MILES AND DIRECT!ON F.~OM NEAREST TOWN OR POST OFFICE* Approximately 6 Miles West - Northwest of Tyonek I4. ~OND INFOI~MATION: Private Lands R1 2W, S.M. I..F-~SE DI~ili;NATION AND ii,RIAL NO. None ?. IF INDIAN. AJ, LOTTEE OR' Cook InJet Region, Inc. 8. UNI'I'dFA~%I OR LEA~ SIMPC0 H00UAWKIE 9. WF_.LL NO. 1 '10. FIELD AND POOL. OR WILDCAT Wi I dcat !!. SEC.. T.. R.. .%1.. !BOTTOA! HOLE OBJECTIVE) Sec 36, TI2N, R12W, S.M. 12. Kenai Borough SAFECO INSURANCE CO. OF AMERICA TYPE BLANKET S-re,~'and,o,~o. 2209296 15. DISTANCE FROM PRO'POSED' 118. NO. OF ACRF_~ IN LEASE LOCATION TO NEAREST 9500' From J. " PI:~OPERT¥ OR 1. EASS L1N~. ~. . ,Al~tonearestdrig. unit. ifany). W~t Lease Line . 13,27~ 1~ DIS'rANCZ 7~O~ PROPOS[D LOCA~ON' Ils. Y~OI~S~D D~ TO ~A~S~ ~SUL ~ILL~O. COMPLETe. I OR ,~,~ ~o~. ~. 1000'+ .' ' '6,000'"TVD "" From 9est Hoquawkie No.' I -- 6,000 THD 21. ELEVATIOHS IShow ~'hethcr DF. RT. ~R. etcJ bT0' GR- Estimated from USGS T0Po 'Sheet* P.ROPOS~ CASING AND CEME~NO PROGRAM A~o,,,,t $100~000 17. N(}. ACRES A$<:GNED TO THoR WELL 6~0 20. ROTARY OR C.~,F.I~¥ 'IO¢)LS Rotary 22, APPI~¢XX. DATE WOFtK WII.I, .-;TART' I July 1978 _ SIZE OF ]~OLE SIZE OF CASL.%TG WEIGHT PER FOOT GRAD~ SETTING DEPTH QL'ANTITY OF CI~MEN= -- 13 3/8"0D 54. 50 K55 60' Driven '. 12~" q ~/8"OD . 32.30 K55 850' To---~qurface _ 195 Sx '-- R 3/.~,, 7" nn ?n.nn ~55. q000' To Surface - 560 Sx 6¼" r~'OO L.tne,' ~R.0n NRn ~nnn,.. Zooe Isolat.ion- I00 Sx __ *Proposed Surface Location Plat' Enclosed. As-Built Survey Plat to be submitted .after Setting Conductor. .' . . . See Attached Supplemental Data Sheet. , REC'EIVED · See Attached Blowout P'reventor Equipment Drawings'. "' '. .: .. ., JUN 2 $ 1978 See Attached 0perational Area Drawing with Lease Boundries. Division of.0il arid Gas An~herag~ IN ABO~ SPA~ D~BE ~OPgS~ ~R~: If p~l ~ ~ dee~n or plug ~ck. give ~ on present p~u~ive zone ~d pro~. new productive zone. I} pr~l is ~ drill or d~n d~e~:o~lly. ~lve ~rt~ent da~ on subsu~a~ ~at~ns ~d meas~d ~nd ~ue ve.~kal dept. Give~ preventer pro,ram. ' 24. I here~y .~'f~' ~t the~n~ ~e an~ Corr.~ ' , . sm~' ~~ ' .*~ ~'~< '~a ,e,~ ~-,',-~ V,ce-Pres,dent ISAMPL~ AND CO~K CHIPS ~U~ ~ ~U~~: ~ ~ D so ~ [~ A.P.I. NUMJI2IHCAL COD~ 50-283-20060 June .26, 1978 ~ A~PROVAL D A"rl~- *S,. ln~ucti~, On Revere Side -June 26, 1978 Simasko Production Company P.O. BOX 1515 · ANCHORAGE, ALASKA99510 · (907) 277-5932 · (907) 274-4591 · TELEX 26-338 June 22, 19 78 Re: "SIMPCO Moquawkie 91" Application for Permit to Drill Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. Tom Marshal 1 Gentlemen: Simaskx) 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 36, T12N, R12W, S.M. Enclosed are the following: (1) Three executed copies of form P-l, "Application for Permit to Drill, Deepen or Plug Back"",, (2) (3) Three copies of a Supplemental Data Sheet attached to the Permit form providing detailed information on cementing program, anticipated geology, formation evaluation, and drilling fluid; .' Three copies of a Proposed Location Plat pre- pared by F.M. Lindsey & Associates; (4) Three copies of BOP equipment drawings for both 17%" hole and for drilling below 13 3/8" OD casing; (5) Three copies of an Operational Area Drawing upon which existing facilities are indicated together with the lease boundary; (6) Filing fee in the amount of $100.00, payable to State of Alaska, Department of Revenue. This wellsite is located on a fee lease which has been entered into by and between Cook Inlet Region, Inc., as Lessor, and Simasko Production Company, as Lessee. The wellsite lease 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 Corpora- tion, owner of the surface estate. As indicated on the executed application form, Simasko Pro- duction Company maintains a $100,000 Blanket Bond from Safeco Insurance Company of America bearing bond 92209296. 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 July 15, 1978 spud date on this test and will appreciate your early attention to review and approval of this application. Sincer~Y~ Vice-President WRS: emm Enclosures: As noted.above SUPPLEMENTAL DATA SHEET FOR APPLICATION FOR PERMIT TO DRILL SIMPCO MOQUAWKIE NO. I SIMASKO PRODUCTION COMPANY P.O. Box 1515 Anchorage, Alaska 99510 15 June 1978 I · I!. III. IV. CEMENTING PROGRAM A. The 13 3/8" OD Conductor Casing will be driven to refusal with.pile driving hammer. B. The 9 5/8" OD Casing will be cemented' to the surface thru a Float Shoe, Flat Collar utilizing a Plug Container Cementing Head. C: The 7" OD Casing will be cemented to the surface and thru a Multiple Cycle Cementing Collar if required. D. The 5" OD Liner will be cemented thru a Float Shoe using conventional Liner Hanger running-setting-cementing equipment; to 1OO0'+ above the Float Shoe. Additional cementing will be done as required-for zone isolation and Liner-Lap sealing as required. E. The 5" OD Liner will be cemented thru a Float Shoe using conventional Liner Hanger running-setting-cementing equipment. Additional cementing will be done as required for zone isolation and for Liner-Lap sealing as required. ANTICIPATED GEOLOGY O' - 300' 300' - 1100' 1100' - 6000' TD Gravel Beluga Formation Tyonek Formation FORMAT I ON EVALUAT I ON . A. Standard Mud Logging Equipment will be installed prior to drilling below the 9 5/8TM OD C.asing Shoe.. B. Full Size Cores will. be taken at points to be determined by Wellsite Geologist. C. Wireline Logs.including; Dual-Induction Laterolog, Sonic Log, Density Log and .Dipmeter Survey will be run. DRILLING FLUIDS Depth O--850I 850' - 6,000' Type Gel-Fresh Water Lignosulfonate System Density 9.5 - 10.O ppg 10.O - 10.5 ppg k. 1. willits & associates, inc./3740 mt. blanc circle/anchorage, alaska 99504/phone 272-0312 T r- -- z . To Cement ~ Pump __.--~ir k_..~ 2" Line Pipe '! ~z~ j Q~ o o -- ~ I- i-~ ~,.~~., oo- i ~000 0~ O~ ~ m 0 ~ I I N I g o[ g o , ~ < o ~ I o EXTENSION o o ~ SPOOL Pump DRILLING SPOOL HYDRAULIC OPERATED REMOTE CONTROLLED REMOTE C O-I~TJ:~ 0 L_L E D .......... CHOKE 5,000 psi 5,000 psi O - 5,000 p S i Pressure Guoge ADJUSTABLE CHOKE To ATMOSPHERIC u~ MUD - GAS ~o o SEPERATOR o .0 '~ ~oZ -Nm '1' 0 0 r- To RESERVE PIT fill-Up Line HOLE: BOPE ARRANGEMFNT S) - (i 'I--Vent To Burn Pit I / 500 MSP or ! J Larger I ~o" o~ I i i ,o ~ ~ D~,c~o,~, To / t ~~ ~n Shop I C ~ ~[ ~ ,~-- ' / ~ ~Weld-O-Lef . ~ 1 '~'~;-Z'~.~'-- ~;... -. ,%, ~ ~ ~,-. ~ .~ - ~ ~_,., R ~-,C ,.,-;- Provide .,-, F I I ' ~ ~ ~on. t J3;~?~':'/ Into Mud Tank rZ; ~ .................... . ~'...' - .,'~/.:~',~'2',~.: ...... .:.' ..... ~-,.,7,.~,L,<,;L'. . '; ~.,"'.~ ~':. '.','~-~,;;~,{-'-~-~'~,~%,.~-,-.~-,., .,. · .U~_L~:II '1 / !1-' .... ,,.,...--. ,,-.' .-- .... .. . .... -,.-,.-,,- ..... --':,~,.-., _'~'~ ~ -. ~ , ,. ,,. .... _-., · , _. ...... .,, .~..:~, .................. ,,.-,, .,,,-,, -., ....... . .......,,--.,,.. .-~.. , ,- .,,~ ~;,..] ,.,. ;/2~l.;~.~,:. ~. ...... n OD ~1.=~ ' .,es - ~?~ ~eau~red J-."-/ ~,'I-.'-~':,:.',-~-,",?.'.';' .-.".; , -;:,.'-,X-''Z~-'[~;~-:;,5':.'~; .'~ ' · .~< /-~/,',',,-.~ ..... or (h) ~e OD L~ne -' ,-' · ,.,': .-,~:~;',:':,~',~;,',,;-,,-.~',,,' ,',-':.;~.,,/;-',-,-',-,'~,,'~'. .... ~,?J;?. . ,. _,., , ........ ..-,~'~ ,;,. ~ 'Ss~" OD Cos'ng S~From Diverter or Choke Monifold ~ .- Notes: I. Re:et System downstream ~rom O.verler w,',, oe totally atmospheric 2. No vo!,es ..11 be ,ncluded between Conduclor Cos.rig ORCl Burn Pd Control of flow from Conductor Co:,ncj ,nra the Mud- Gas Seperotor w,II be Dy 3,fference ,n elevat,on only 3. T~e 13.3,~"0D Cos:ng ;~elief Line and Mud-Gas Seperotor will be connected to the Choke Mainfold used w,th subsequent Casing Strings. i/IS ~ os$.'~c/ole$, /nc .3"4c~ m° /)/c/nc c/~c/& anchorage, o/osko 995~34 ph 907-272-0..~/2 'SIMPCO MOOUAWKIE NO. I BOPE FOR 17Y2" HOLE SIMASKO PRODUCTION CO. I' 77-5-A 27 23 I 24 I 35 36 iii IllI I I ~' . i I i I ~I PROPOSED LOCATION ~SIMPCO MOQUAWKIE ~r LAT. : .61° 04' 56.076" ~ f I~, ~o~.~oo ~s' oo.~" I f I X: ~66,870 ~ f ' Y : ~,589,857 I No. I I 5 4 INDIAN RESERVATION I I, 12 7 SCALE I": I MILE TI2N TIIN CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska end that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details ore correct. Dote Surveyor . I .ui i I [ _.. I i I II I . I . . I . I "' ' PROPOSED SlMPCO MOQUAWKIE No. I Loc,et.ed in SE I/4 PROTRACTED SEC. 36:TI2N,RI2W_,S.M.~AK. Surveyed for SIMASKO PRODUCTION CO. Surveyed by F.M. LINDSEY & ASSOC. LAND I& HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-081 Anchorage Alaska II III JUl III IIIL . ]. IJ I ,11 I CHECK LIST FOR NE~q WELT. PER~TS · Yes No Remarks ,, Lease & Well No. Item. /Approve ~ Date 1. Is the permit fee attached ............. . ........ /~_ , 2. Is well to be ldcated in a defined pool ..... . ......... _~L~,< 3. Is a registered survey plat attached ................ 4. Is well located proper distance frcm property line .... · .... _~ 5. Is well located proper distance frcm. other wells ........... -~..,,. .... :':.-'., '.' "T :' - "'.; -- 6-":""IS SUfficient undedicated acreage available in'this pool ...... 7.' Is well to be deviated ....................... ~°'(' .s operator the o'nlv affected party ...... . .... /~ ,..,'~ ' · -- · · · · · · · ,,. 9. Can permit be approved .before ten-day ~ait .......... · . 0. Does operator brave a bond in force . .. .............. .. .. 1. Is a conservation order needed . . ' .................. ~. · 2. Is' adm~is~a~ve approval needed o . ...... '. , ,. · ,. , . 3. I's. conduCtor s~ing' .p~ovided ........... . ' ~ . · · 4, · e · · i, ~ , , 4. Is'.enough cement used to circulate on cOnductor and surface .... ~ ,,, 5. Will cement tie in ~rface and intermediate or Droduction strings' . ~/~., . ~'i'".{'" 11 ..~t cover .all' khown productive horizons· . . . . · ..... 7. Will. 'surface Casing protec% fresh water, zones ........... ~D' 8. Will a'll casing give adequate safety in collaPse, tension & burst . :~/~' .. 9; Does BOPE have sufficient' pressure 'rating - Test to '~O~ psig . ~ ,.__ [2) Loc. /~/~ [4) sg. -(5') BOPE /~/~2 0. Has DMEM approved Plan of .Operation . . .: ............. ~ditional Requirements': " Approval Recc~mended: ~./2~/2 W Geology: . EngJ3aeering: . l~mvised 4/14/78
