Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
160-041
STATE OF ALASKA ALASKA OIL AND GAS CONSFRVATInN Cn MMIGRInN �n Lars's.s"% tr.�s uV E Lost/ SEP 2 0 Hqq WELL COMPLETION OR RECOMPLETION REPORT AN.I?i- IQ 1a. Well Status: oil ❑ Gas E] SPLUG ❑ Other ❑ Abandoned 0 • Suspended❑ 20MC 25105 20MC 25.110 GINJ ❑ WINJ ❑ WAGE] WDSPL ❑ No. of Completions: 1b. Well Class:" ` Development ❑✓ Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: Hilcorp Alaska, LLC 6. Date Comp., Susp., or band:: 8/26/2019 14. Permit to Drill Number / Sundry: • 160-041 / 318-410 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. pudded: 6/21/1961 15. API Number: 50-133-10142-00-00 4a. Location of Well (Governmental Section): Surface: 2400' FEL, 860' FSL, Sec. 15, T8N, R9W, SM Top of Productive Interval: Total Depth: 2400' FEL, 860' FSL, Sec. 15, T8N, R9W, SM 8. Date TD Reached: 7/29/1961 / 16. Well Name and Number: Swanson River Unit (SRU) 234-15 - 9. Ref Elevations: KB: A'52' GL: J,2.7ryvq BF: i44 17. Field / Pool(s): Swanson River 2' Hemlock Oil - Tyonek Undef Gas 10. Plug Back Depth D/TVD: 0' MD / 0' TVD 18. Property Designation: FEDA-028384 . 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 350723.4 y- 2477868.1 • Zone- 4 TPI: x- y- Zone- 4 Total Depth: x- 350723.4 y- 2477868.1 Zone- 4 11. Total Depth MD/TVD: 11,190' MD/ 11,190' TVD 19. DNR Approval Number: N/A 12. SSSV Depth MD/TVD: N/A 20. Thickness of Permafrost MD/TVD: N/A 5. Directional or Inclination Survey: Yes LJ (attached) No Submit electronic and printed information per 20 AAC 25.050 13. Water Depth, if Offshore: N/A (ft MSL) 21. Re-drill/Lateral Top Window MD/TVD: N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A -- 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM PULLED 24. Open to production or injection? Yes ❑ No If Yes, list each interval open (MDfrVD of Top and Bottom; Perforation Size and Number; Date Perfd): GOMPLEfm ❑A TE �M1 VERIA D 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) N/A N/A N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during com 20 AAC 25.283 (i)(2) attach pletion? Yes No Per electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A N/A 27. PRODUCTION TEST Date First Production: N/A Method of Operation (Flowing, gas lift, etc.): Date of Test: N/A Hours Tested: Production for Test Period Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing P Casing Press: I Calculated 24 -Hour Rate Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity -API (c orr): Form 10-407 Revised 5/2017/y 9 CONTINUED ON PAGE 2 Submit ORIGINIAL only BBDMS-_ ocr 0 9 2019 �� ,_�� ,. f_I 28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cared (MD/TVD, FromfTo), 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. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Operations Summary, Schematic, MIT -IA, Photo document casing cut-off/cement top/welded plate. Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Bo York 907-777-8345 Contact Name: Ted Kramer, Operations Engineer Authorized Title: Operations Manager Contact Email: tkrameKoihilcoro.com Authorized T.0or V' Cll Contact Phone: 907-777-8420 Signature:c7 ,0 / J I 9 �u trr K Date: /Z INSTRUCTIONS General: This form and the required 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 41b: 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 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 234-15 50-133-10142-00 1 160-041 10/26/18 8/26/19 Daily Operations: 10/26/2018 - Friday Move in rig and support equipment, lay out herculiner, spot and rig up rig, continue spatting and rigging up support equipment. 10/27/2018 -Saturday Reviewed JSA, Discussed daily work plan, reviewed associated hazards and mitigations. Start equipment and lights, prepare to begin Nipple around. Removed blind flange from well head, installed hanger and set 2 way check valve, nippled up BOP'S, continued spotting and rigging up rig and support equipment. Perform McCoy Power Tongs Torque Test. Start mixing Brine to achieve 10 PPG NACL Brine, continued to service equipment and rig up in preparation for BOP Test. 10/28/2018 -Sunday Reviewed JSA, discussed daily operation and associated hazards, reviewed mitigations. Prep equipment to begin Initial BOP test (AOGCC witness was waved). Performed Initial BOP pressure test tested gas detection system. Rig up floor and tubing handling equipment and prepare to RIH to attempt retrieval of retrievable bridge plug. RIH with a 2-7/8" T2 Overshot for on off tool, tagged up on plug at approx. 500', attempted to latch but unsuccessful, POOH and change over to a 3-1/2" T2 overshot for on off toll and attempt to latch, unsuccessful, TOH. Secure well and location, SDFN, notify Engineer and wait for return calls for new tools, plan for tomorrow another attempt at latching plug with new tools. 10/29/2018 - Monday Reviewed JSA, Discussed daily operations and associated hazards, reviewed mitigations for the hazards. Start and prep equipment to RIH with BHA and attempt and latch plug. RIH with Short Catch Overshot 5-7/8" OD, with 3-3/4" Catch_ _ Grapple, tagged up on top of plug, sat down to neutral weight, rotated 1/4 turn and picked back up, latch was good, worked up and down several times and made several rotations, unable to get plug to release, made multiple attempts by trying different rotation patterns and weight patterns, with no success, rotated off of plug and POOH. POOH, shut in well with Blind rams, secured well and location, released tool hand and rig crew, made plans for drilling out plug, waiting for tools to arrive in from Weatherford, plan for early morning start up on 10/31/2018. I 10/30/2018 -Tuesday Fish ing/DrilIingjob planning and coordination. N Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 234-15 50-133-10142-00 1 160-041 10/26/18 8/26/19 Daily Operations: 10/31/2018- Wednesday Review JSA, discuss daily operations and associated hazards, reviewed mitigations and discussed new team members and safety culture. Start equipment and prepare rig floor, catwalk and pipe racks to receive new equipment in preparation of fishing operations, received BHA equipment, strapped and measured all dimensions and recorded, transfer tubing to racks and Tallied all tubing and BHA Prepared equipment to begin RIH with BHA. RIH with 3-3/4" short catch overshot, grapple, jars and accelerator, added 4ea 4-3/4" drill collars, shut down for lunch. Break for lunch. Change out tubing handling equipment from drill collars to 2-7/8" PH6 tubing, resumed RIH with fishing tools to latch up on fish, latched up on fish overpulled to 45,000 jars fired, no movement, overpulled to 45,000 again and had movement but was obviously dragging, continued to move up hole, stopped to break out and lay down one joint of PH6 tubing, continued up hole mid way through nextjoint hit what appeared to be Casing collar, over pulled to 70,000 fired jars and pulled free. Made several attempts to relatch but could not latch up, proceeded to POOH, once at surface found that the off and was up inside the overshot. Secured well, serviced and fueled equipment, SDFN. 11/01/2018 - Thursday Reviewed JSA, discussed daily operation, reviewed hazards and mitigations. Rig up floor and handling equipment, prepare to make up BHA and RIH. RIH with BHA and start of PH6 tubing, tagged up on Joint 9, at approx. 473'+/-, performed weight check up and hanging weight. Secured well and gathered crew to review plan for drilling and associated safety hazards and mitigations, discussed plan for rigging up equipment and safety controls for equipment, discussed weight checks and pump rates, ability to circulated and taking returns. Start rigging up handling equipment and pumping equipment in preparation to begin drill out, found liner wash and power end oiler system to have a broken chain on the pump drive, made repairs to system after acquiring necessary parts. RIH an tag up at 479', started pumping to establish circulation and began to wash over plug with shoe and mud motor, we were to able to work our pipe up and down and made approximately 6". Shut down, secure well, winterize equipment, SDFN. 11/02/2018 - Friday Review JSA, Discuss daily work plan and associated hazards, review mitigations. Start equipment and prepare to start TIH to resume drill out, found accumulator to be to cold to operate correctly, outside temps were around 5 degrees. Put heater trunks inside of accumulator building and started warming process, once oil began to warm then accumulator was ready to operate correctly. TIH and tag up at 478+, resumed drill out, plug dropped, TIH with a single joint and tagged up again at 500', resumed drilling out, picked up and made up next connection. Resumed TIH and milling, chasing plug down continuously, at 12 joints in above BHA we were no longer tagging up and proceeded to TIH with no tags, TIH with a total of 20 joints above BHA for a total depth of 816'. Shut down, secure well, shut down and service equipment, fuel up equipment, winterize equipment and place heater trunks on equipment that is most susceptible to cold start up problems. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 234-15 50-133-10142-00 1 160-041 10/26/18 1 8/26/19 Daily Operations: 11/03/2018 -Saturday Reviewed JSA, Discussed daily work activities and associated hazards, reviewed hazard mitigations. Inspect and start all equipment, start prepping to TIH. Tally tubing, break circulation and circulate full tubing and annular volume (40 bbls). Resume TIH operations to reach PBTD of 5,711', starting from 816', running BHA and 2-7/8" PH6 tubing,. TIH with 176 Joints of 2-7/8" PH6 work string and BHA, stopped 200' above PBTD to avoid running into plug and risking the potential of plugging up the shoe eliminating the ability to circulate the well bore with Brine. Circulate the well with 200 bbfs of 10 PPG NACL Brine, shut down secure the well and winterize equipment. "! A rtk,7 11/04/2018 -Sunday Reviewed JSA, discussed daily work plan and associated hazards, reviewed risk mitigations, planned the daily OP's. Inspect and start all equipment, prepare floor and tubing handling equipment to begin TOOK TOOH with 2-7/8" PH6 standing back 49 stands (2,985.07'). Prep catwalk, beaver slide and pipe racks to begin TOOH laying down singles. TOOH laying down 2- 7/8" PH6 singles, laid down a total of 35 (1,067') Singles, shut down TOOK Prep BOP stack, choke manifold, hanger, landing joint, FOSV and IBOP, to begin 7 day BOP Test, made up X -Overs and tubing hanger, landed out tubing and locked down lock down pins, installed FOSV and IBOP, filled BOP stack and flooded all lines, performed shell test and inspected for leaks, ready to begin 7 day BOP test. Begin 7 Day BOP Test—witnessed by AOGCC Inspector Lou Laubenstein, completed all test steps successfully with no Fails. Drain and blow down all equipment, winterize equipment, SDFN. 11/05/2018 - Monday Reviewed JSA, discussed daily work plan, reviewed associated hazards and mitigations. Start equipment and prepare floor and handling equipment to begin TOOK Finish POOH tubing and BHA, all BHA assembly components were accounted for and appeared to be in good shape without damage. Rig down tubing handling equipment and prepared floor and catwalk to run E -Line equipment. Rig up E -Line equipment and prepare to run CBL. Run CBL equipment, Log from 5,500' up to surface. RIH and set CIBP at 3,000'. RIH with perforating guns and perforate at 2,976' to 2,979' and 2,776' to 2,779'. Rig down and release crew, closed blind rams and secured well, SDFN. 11/06/2018 -Tuesday Review JSA, discussed daily work plan and operations, reviewed associated hazards and mitigations. Start equipment and prepare equipment to TIH with tubing. Trouble getting Rig to run due to extreme low temperatures -1 and lower. TIH with 47 stands of 2-7/8" PH6 Tubing. Upon testing the water for cement found that our chlorides were to high and had to have new water brought in for the cement. Started pumping, pumped 3 bbls ahead of cement, pumped 12 bbls of 15.8 ppg cement, followed by 1.5 bbls of displacement. Pull 12 joints of tubing laying down. Pumped 13 bbls tubing displacement, shut down and shut in 7" casing valve, resumed pumping to attempt to squeeze cement into perfs, after 7 bbls away, had not caught pressure, decision was made to shut down and allow cement to fall and set. Blow down lines and drain up, winterize equipment and insure extra steps were taken to prevent start up issues in AM. Discuss next days work plan and notify Engineer and BUM Engineer. ?1 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SRU 234-15 50-133-10142-00 1 160-041 10/26/18 1 gk26A9 Daily Operations: 11/07/2018- Wednesday S Reviewed JSA, discussed daily work plan, associated hazards and their mitigations. Start equipment and prepar to pump pressure verification tests on 11-3/4" X 7" Annulus. Pump pressure test on 11-3/4" X 7" Annulus, pumped unmea urable amount of fluid and pressured up to 700 psi, initial pressure loss at shut down was 200 psi, then stabilized, held for 1 minutes no pressure loss noted, bled back pressure and rigged off the pumping equipment, drain up pumping equipment and winterize, spot in and rig up E -line to perform PBTD Tag. RIH with CCL and weight bar to perform tag on TOC, tagged up at 2,487', (EOT located at 2,507'), POOH and rig down E -line. Attempted to POOH with tubing and found that tubing was stuck and unable to move. Notified engineer of situation, Ordered free point equipment and cutters from town, performed pipe stretch calculations and estimated free point to be at approx. 2,411'. Sent forward plan to Engineer and BLM Engineer for approval, with approvals for forward plan granted, proceeded with necessary steps while waiting for free point tools and cutters to arrive from town. Performed 7" X 21" Annulus pressure test to 1,200 psi held and charted for 10 minutes, pressure held solid and only dropped to 1,150 pressure tested the 2-7/8" tubing, pressured up immediately to 500 psi, held for 10 minutes. RIH with free point tools, along with rig and personnel, began calculating free point by working pipe and running tools, free point was estimated to be at 2,350'80% Free pipe, everyone agreed that that depth would likely be free pipe. RIH with 2-1/16" Jet Cutter, picked up to 25,000 overpull, and made cut at 2,350', cut was unsuccessful. Made up new cutter and RIH, picked up to 30,00(�over pull and made additional cut at 2,320', cut was unsuccessful. Ordered new cutters from town, while waiting for cutters to arrive, we had to release Halliburton for cement job on 169 rig, performed additional free point runs to get better determination of free point, new free point depth determined to be at 2,110'. RIH with new cutter (Chemical Cutter), pulled up to 30,000�made cut, wireline jumped once cut was made, tubing unloaded approximately 20 gallons of fluid then flow stopped, did not get weight back, pulled up to 40,000 still stuck, started pulling towards 50,000 at 46,000 tubing pulled free, laid down 1 full joint, shut in and secured well, rigged down E -line, winterized equipment and SDFN. 11/08/2018 -Thursday Reviewed JSA, discussed daily work plan, associated hazards and mitigations. Start equipment and prepare tubing handling equipment and rig floor to begin TOOH with PH6 tubing POOH laying down PH6 tubing, once out of well, shipped to town 177.5 joints, 12.5 joints left in well and CIP. TIH with 2-7/8 EUE 8rnd 6.5# to 2067_5 Measured depth, circulated well bare full of clean fluid in preparation of cementing. Prep rig floor and other equipment to begin cementing operations. Spotted in Halliburton cementing equipment and prepared to begin cementing. Began cementing operations, pumped 5 bbls of fresh water spacer ahead of cement, pumped 6.7 bbls of 15.9 PPG cement, pumped 10 bbls of fresh water behind. POOH at 30 feet per minute, laid down 4 joints = 2 stands, stood back 12 stands, leaving EOT at 1177 measured depth difference of 890' above previous EOT before cementing at 2067.5, circulated the well with 150%+ volume to insure clean tubing and annulus. Prepare and mix 75 bbls of 10 PPG NACL Brine, secure well, drain up equipment and winterize, SDFN. rhe Hilcorp Alaska, LLC Well Operations Summary Well Name Rig AN Number Well Permit Number Start Date End Date SRU 234-15 50-133-10142-00 1 160-041 10/26/18 1 8/26/19 Daily Operations: 11/09/2018 - Friday Reviewed JSA, discussed daily operations, reviewed associated hazards and mitigations. Start equipment and prepare floor and handling equipment to begin tubing running operations. TIH with 12 Stands of 2-7/8" 6.5# EUE 8rnd Tubing to tag TOC, tagged up on stand 12 with 21.12 in on lastinont.TOC tag wag at 1,917,86' KB sat down 2,000#'s on TOC, Tag was witnessed and verified by BLM Rep and Co -Rep agreed that cement job was effective and acceptable. Circulate well bore with 75 bbls of 10 ppg NACL Brine. POOH laying down tubing, leaving 2 stands and a single 159.72' for top job on the rack. Waiting for Wireline to arrive, fuel their equipment and prepare to RIH. RIH with CIBP, during run generator shut down, had to reboot computers, POOH and re zero tools, run back in hole, attempted to set plug at 160', plug did not set POOH to rearm, but plug was not there, it had unscrewed itself from setting tool and fell down hole. Waiting for wireline to bring in another plug from town. New plug arrived, made up tools, RIH with CIBP and set at 169' (Collar at 160') below ground level. POOH and rig down E -line. Prep Halliburton to begin pumping cement on top plug, Pumped 5.94 bbls of 15.9 ppg Class G Neat Cement Slurry. POOH with tubing, install wash up joint and wash up Halliburton and BOP stack to evacuate any residual cement, Verified TOC was visible near top of tubing head. Begin rigging down rig support equipment. 11/10/2018 - Saturday Reviewed JSA, discussed daily work plan associated hazards and mitigations. Start equipment and prepare for rig down. Checked TOC, found TOC to 12' below the top of tubing head, mixed up 15 gallons of 15.8 ppg Class G near cement and brought level up to bottom of 7" Casing head. Rig down and begin moving equipment off of location. 08/26/2019 - Monday BLM/AOGCC Inspectors onsite, upon verification of cured cement to surface the wells abandonment plate was welded in accordance with BLM/State of Alaska requirements. I I TP ,�! SCHEMATIC,O �/ '-`t Swanson River Unit Well SRU 234-15 PTD: 160-041 API: 50-133-10142-00 PBTD = 0'- TD = 11,190' Updated by DMA 09-10-19 SRU 234-15 Wellhead Removed/Cemented to Surface A 1 121:1 1 1 1 1.7 Mill NIO " S�A kAor " LU z z w ro CansuLti Inc IvicLANE Well S.R.U. 234-15 Plug & Abandon Memo Via email Date: 25 October 2018 To: Hilcorp Alaska LLC....................................................Attn: Cole Bartlewski From: Stan A. McLane, PLS Project: Swanson River Unit 234-15 Well Plug & Abandon Survey Re: Project Summary This memo represents the plug and abandon survey performed by McLane Consulting Inc. (McLane) for Hilcorp's Swanson River Unit 234-15 well located in Section 15, T8N, R9W Seward Meridian, Alaska. The survey was performed on October 25, 2018. The scope of work consisted of providing accurate field elevations so the well could be plugged and abandoned per State requirements. Existing survey control was recovered and positional accuracy was confirmed by comparing (2) check shots on hard targets to existing data. To establish original ground elevation near the well casing, (2) survey measurements were observed at the perimeter of the pad in opposite positions from the well location. These elevations were averaged and assumed to fairly represent original ground in the absence of historical data. A top of pad elevation was also recorded adjacent to the well casing then a reference grade stake was set with measurements to the proposed cutoff elevation from an X on top of cellar. Enclosed is Exhibit A which includes pad asbuilt data from 2018 and a well casing cutoff detail with pad, original ground and proposed casing cutoff elevations. • Mean pad surface grade in vicinity of well casing: 289.0'± (2018) • Original ground elevation in vicinity of well casing: 288.0'± (2018) • Cutoff depth requirement: 3.0' below original ground elevation • Minimum casing cutoff elevation: 285.0' • Casing cutoff elevation as staked in field: 284.0' The cutoff mark elevation of 284.0', as referenced in the field, exceeds the required minimum cutoff elevation of 285.0'. P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email SaMclane@mclaneg.com Consul{i Inc tvIcLANE Please feel free to contact me if you have any questions or comments. Sincerely, Stan A. McLane, PLS McLane Consulting, Inc. OF AL4 I #t .................. TAN A. Ma 7—SLANEc 70 0 Page 2 of 2 P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email SaMclane@mclaneg.com w z J w o_ a 0 w x v _W 0 GRAPHIC SCALE 0 30 60 120 1 inch = 60 ft. EVE ACCESS ROAD F- 0 O 2 ^ N 0 O Z N O � 0 CJ 00 J N Z II Xw J O w x ONE U NOTES 1. BASIS OF HORIZONTAL; NAD83 US FEET POSITION (EPOCH 2010) AND VERTICAL CONTROL (NAVD88) IS AN OPUS SOLUTION FROM NGS STATIONS TBON, TSEA AND ANC2 TO ESTABLISH CP -2. THE ALASKA STATE PLANE COORDINATES NAD 83 ZONE 4 IN FEET ARE: N = 2458384.578 / E = 1483669.444 / ELEV. = 212.690 (NAVD88) rpr LE 111 11'11 IL Luwm VOICE: 11 Hilcorp Alaska, LLC J > Q GV 0 O PAD 234-15 J WELL CASING CUT-OFF DETAIL WELL CASING TO BE REMOVED PAD ELEV = 289.0' t O.G.ELEV _ 288.0' — — — — i ! 4.0' REFERENCED WELL CASING CUTOFF AT ELEV = 284.0' HROJECT HILLCORP ALASKA, LLC SWANSON RIVER FIELD WELL SRU 234-15 PLUG AND ABANDON EXHIBIT -A NAD 83, ASP ZONE 4 LOCATION SECTION 15, T8N, R9W SEWARD MERIDIAN, ALASKA REVISION: - DATE: 10252016 DRAWN BY: JAH SCALE: 1=60' PROJECT NO. 187036 BOOK NO. 1807 SHEET SRU234-15 P&A ASP NAD83, ZONE 4 N: 2,477,635.8 ^ E: 1,490,754.3 ELEV = 289.0 L X < Q 0 O Z o ®SRU 24-15 _ 00 '0) F- O O Z v oz II ®SRU 11-22 o N N > Orn 0 ao QJ J N D_ w Q II z c� > J O w WELL CASING CUT-OFF DETAIL WELL CASING TO BE REMOVED PAD ELEV = 289.0' t O.G.ELEV _ 288.0' — — — — i ! 4.0' REFERENCED WELL CASING CUTOFF AT ELEV = 284.0' HROJECT HILLCORP ALASKA, LLC SWANSON RIVER FIELD WELL SRU 234-15 PLUG AND ABANDON EXHIBIT -A NAD 83, ASP ZONE 4 LOCATION SECTION 15, T8N, R9W SEWARD MERIDIAN, ALASKA REVISION: - DATE: 10252016 DRAWN BY: JAH SCALE: 1=60' PROJECT NO. 187036 BOOK NO. 1807 SHEET Schwartz, Guy L (CED) From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, November 7, 2018 1:55 PM To: Schwartz, Guy L (DOA) Cc: Donna Ambruz Subject: SRU 234-15, PTD 160-041, Sundry 318-410 Guy, While setting our 200' cement plug across the surface Shoe, we managed to cement our tubing in the hole. We are free pointing but by calculations it looks like we have 2,476' of pipe in the well and the bottom 96.11' are stuck. The good news is that the inside of the pipe is clear and we were able to tag TOC at 2,487' which means that we did get a good plug set. We are still investigating how we got cement up behind us setting a balanced plug. For a plan forward, Hilcorp proposes the following: • Pressure up 7" X 2.875" Annulus to 1000 PSI, to verify integrity • Run E -Line Free Point tool to verify stuck pipe depth • Run Jet cutter to cut tubing above stuck pipe depth • Pump 150' Balanced Cement Plug above the cut point of the tubing • Wait on Cement (Halliburton Engineer Report is a 9 hour cure time) • Tag TQC • Run and set CIBP at 160' • Spot balanced plug from 160' to surface • Plugging operations are complete Please let me know if this is acceptable to the AOGCC. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ��z� t( � II� ,q DATE: August 28"' 2019 P. I. Supervisor FROM: Brian Bixby SUBJECT: Surface Abandon Petroleum Inspector SRU 234-15 - Hilcorp Alaska Inc. PTD 1600410; Sundry 318-410 8/26/2019: 1 arrived at Swanson River Field and met up with Mike Erstrom (Hilcorp Construction Foreman). We went to the well location and I verified there was good hard cement to surface and all the correct information was on the marker plate. The cut off is over 4 feet below grade. I also took pictures of the hard cement, marker plate, marker plate after welded on and the depth of the cutoff. Attachments: Photos (4) 2019-0826_Surface_Abandon_SRU_234-15_bb.docx Page 1 of 3 Surface Abandon — SRU 234-15 (PTD 1600410) Photos by AOGCC Inspector B. Bixby 8/26/2019 2019-0826_Surface_Abandon_SRU_234-15_bb.docx Page 2 of 3 2019-0826_Surface_Abandon_SRU_234-15_bb.docx Page 3 of 3 DATE 11/19/2018 Oth Nolan Hilcorp AlaskaoC GeoTech II 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8308 E-mail: snolan@hilcorp.com To: Alaska Oil & Gas Conservation Commission Abby Bell Natural Resource Technician II 333 W 7th Ave Ste 100 Anchorage, AK 99501 CD: Final Well Data SRU 234-15 CBL 11-5-13.pdf �+ SRU 23415 CBL MAIPJ PASS 11-5-18.1as SRU 23.1-15 P&A 11-5-18.pdf 11/12/2018 9:39 AM 11/12/2018 9:40 AM 11/12/2013 9:33 AM SCANNED Nov z 9 Cul6 Please include current contact information if different from above. RE cE�� E° u 2o�a N0V2 AOGCC Adobe Acrobat Doc... 3,063 KB LAS File 2,206 KB Adobe Acrobat Doc... 1,238 KB 160041 30020 Please acknowledge rgceipt by signingland, returning one copy of this transmittal or FAX to 907 777.8337 Received By: (�nkfa��Date: I 1 10�I� Regg, James B (DOA) From: Holly Tipton <hotipton@hilcorp.com> _ Sent: Friday, November 9, 2018 3:16 PM'/'j To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Wallace, Chris D (DOA); DOA AOGCC Prudhoe Bay Subject: SRU 234-15 11-3-2018 Casing Pressure Test Attachments: SRU 234-15 11-3-2018 Casing MIT .pdf; SRU 234-15 AOGCC 10-403 Approved 2018-09-25.pdf, Form 10-426 For SRU 234-15 Casing Pressure Test 11-3-2018 (005).xlsx Hi all, Please see the attached pressure test chart for SRU 234-15. The inspection was waived by Jim and the approved P&A procedure for this gas well states to pressure test the casing with results recorded on a chart. A copy of this test chart will be submitted with the 10-407 to close out this Sundry. Thanks! Holly SCANNED O, E: G 3 u • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: ii m.regg(Walaska.gov: A0GCC.Insoectors0alaska.gov: phoebe.brooks(ccOalaska.gov chds.wallace0alaska.gov OPERATOR: Hilcorp Alaska LLC. FIELD / UNIT / PAD: Swanson River, SRU 234-15 DATE: OPERATOR REP: AOGCC REP: McPherson Well TYPE TEST Codes INTERVAL Codes Result Codes Pressures: Pretest Initial 15 Min, 30 Min. 45 Min, 60 Min. O = Other (describe in notes) PTD 1600410 Type Inj N Tubing Form 10-426 For SRU 234-15 Casing Pressure Test 11-3-2018 (005) I I I I Type Test P Packer TVD 5711 BBL Pump 200.0 IA NA 2250 2230 2220- Interval 0 Test psi 2000 BBL Return 200.0 OA I Result P Notes: Casing pressure test prior to beginning plugging operations for the PBA, approved procedure asked for a 2000 PSI, 30 min charted test, witness was waived by Jim Regg, Fluid pumped was 200 BL's of 10 PPG NACL Brine B Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD��BBL Tubing Type Test Packer TVDp IA Interval Test psirn OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P=P .... ure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Form 10-426 (Revised 01/2017) Form 10-426 For SRU 234-15 Casing Pressure Test 11-3-2018 (005) THE STATE °fALASKA GOVERNOR BILL WALKER Chad Helgeson Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.olaska.gov Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil and Tyonek Gas Pools, SRU 234-15 Permit to Drill Number: 160-041 Sundry Number: 318-410 Dear Mr. Helgeson: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this 2d1ay of September, 2018. Sincerely, T � Cathy P Foerster Commissioner 0""o w 4111" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 E C E �VEEE SEP 18 2018// AOG�CC /00 1. Type of Request: Abandon ❑Q • Plug Perforations ❑ Fracture Stimulate ❑ Repair Well p ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development • ❑Q Stratigraphic ❑ Service ❑ 160-041 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-10142-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑Q Swanson River Unit (SRU) 234-15 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028384 Swanson River / Hemlock Oil - Tyonek U of 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): 11,190' 11,190' 5,711' 5,711' -0 psi 500' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 28 22" 28' 28' Surface 2,876' 11-3/4" 2,876 2,876' 3,070 psi 1,510 psi Intermediate Production 11,190' 7" 11,190' 11,190' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubin g MD (ft): See Attached Schematic See Attached Schematic N/A N/A N/A Packers and SSSV Type: Baker Model "HS" Pkr; Packers and SSSV MD (ft) and TVD (ft): 5,746' MD/TVD SC -1 8 F-1 Pkrs; N/A 6,346 MD/TVD; 6,450' MD/TVD; N/A; N/A 12. Attachments: Proposal Summary ❑Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑Q Exploratory ❑ Stratigraphic ❑ Development ❑Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: October 5, 2018 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned Q. 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: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkra� Contact Phone: 777-8420 Authorized Signature: Date: �[ � /8 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 319- 19 I /-1' Plug Integrity BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ (❑ /� Other: �0 "T iL+ ftya- ,T � / 4 S ti .C. ccJtt•-.Y t / ct 1 �'�`� tf �j RyD•'-c�.%�L� n •7 Post Initial Injection MIT Req'd? Yes No ❑ E]r ,,11 [� . 1 U Spacing Exception Required? Yes E] No 2/ Subsequent Form Required: 10—q APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: il6 7 0 �rl R Mdtr�r�Attachments .�— Form and Submit Form a' Form 10A03 Revised 4/20 Approved applica n s a s r the date of approval. Attachments in Duplicate n Hilwrp Alaska, LL - Well Prognosis Well: SRU 234-15 Date: 9/18/2018 Well Name: SRU 234-15 API Number: 50-133-10142-00 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: October 5, 2018 Rig: Rig 401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-041 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: — 0 psi (No open Perforations) Maximum Expected BHP: — 2,497 psi @ 5,711' (Using .437 psi/ft normal gradient) Max. Potential Surface Pressure: — 0 psi (No open Perforations) Brief Well Summary The SRU 234-15 well was drilled and completed as a Hemlock oil well in the H4 and H5 intervals in August, 1961. Hemlock benches H1 and H2 were added in July 1971 in preparation to convert the well to gas injection. The well was produced until November of 1972, when it was converted to a gas injector. The next year, water was injected down this well bore and the name was changed to SRU 434-15. The well was SI from October 1976 until March of 1980 when the well was returned to production on gas lift. The well produced only water and was again SI December 1980. In March of 1983, the well name was changed again to SRU 34-15. And its status was changed back to6producer/ The Hemlock benches H-2, 3, and 4 were abandoned in August 1991 by setting a cement retainer on coil and squeezing 18-1/2 bbls of 15.9# Class G cement through a cement retainer. The H1 was then perfed from 10,733 —10,744'. These perfs were later abandoned and the well was recompleted to a gas well. Gas intervals perforated and later abandoned include the 77-3, 68-0, T-61-3, T59-2 and lastly the T54-5 sand. In 2013 Hilcorp placed a PX plug in the Baker HS packer at 5,746', cut and removed the tubing and placed 37' of cement on top of the packer (TOC @ 5,711'). Hilcorp then ran a tubing retrievable plug and set it at 500'. The purpose of this Sundry work is to P&A the well. A 1 Pre -work 1. MIRU E -line unit. Pressure test Lubricator to 3,000 psi. Q� 2. PU RIH with a downhole camera to the top of the Tubing Retrievable Bridge plug at 500'. POOH W/ Camera. RDMO E -line. y Rig Procedure MIRU Rig 401. Notify AOGCC and BLM that P&A activities are commencing (48 hour notice). Insure no pressure is on the well. K Rd.,p Alaska, M Well Prognosis Well: SRU 234-15 Date:9/18/2018 4. Set Back pressure valve. ND wellhead, NU BOP and test 250 low 3,000 psi high, annular to 250 psi Low/ 2,500 psi High. Record accumulator pre -charge pressures and chart tests. (Note: Notify AOGCC and BLM 24 hours in advance of test to extend the opportunity to witness). a. Perform Test. b. Test VBR rams on 2-7/8"" test joint. c. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Copy to BLM. 5. PU WS and tools, RIH to 500' and engage and pull bridge plug. (If plug is identified by the camera 3 } run in pre -rig work Step # 2.) POOH W/ Same. If plug is not identified, pick up mill or shoe W/ drill " collars and mill / burn over plug and push it to bottom. �y r i1 6. While on bottom (+/-5,700'), Change fluid to 10# brine. �° 1 7. Pressure test casing to 2,000 psi for 30 minutes (on Chart). 8. POOH W/ 2-7/8" PH -6 WS. 9. RU E -line. PU CBLtool and RIH to 5,700'. 10. Place 1,000 psi on well. Log to Surface or top of cement. POOH, RD E -line. Note: Old CBL shows Cement up to 4,500'. Log only goes to 4,000' so we need to run new CBL. J 11. PU 7" CIBP, RIH W/ Same on E -line and set @ 3,000'. Note: The next steps of the procedure will be determined by the results of the CBL. dpi If the CBL determines that there is cement behind the 7" to surface then cement plugs will be 1i placed as follows: a. A cement plug will be placed on top of the CIBP @ 3,000' up to 2,750' using 15.8#/ gal. cement. b. A second CIBP will be placed @ 160'. 15.8 #/gal. cement will be placed on the CIBP to surface. If the CBL determines that there is cement present behind the 7" casing up past the 11-3/4" p surface casing shoe ( 2,876'), but not up to 160' from surface, then cement and plugs will be placed as follows: a. A cement plug from the top of the CIBP at 3,000' up to 2,750'. b. A CIBP will be set at 160'. Holes will be punched in the 7" casing at 150' and cement circulated down the 7" X 11-3/4" annulus, through the holes punched in the 7" and up the 7" casing to surface. If the CBL determines that there is not cement present behind the 7" casing up past the 11-3/4" surface casing shoe ( 2,876'), then cement and plugs will be placed as follows: 3 a. Holes will be punched in the 7" casing 100' below the Surface casing shoe( 2,976' — 2,980'). The back side valve will be opened and an attempt to establish circulation 5�y y down the 11-3/4" X 7" annulus through the punched holes and up the 7" casing to p+� surface. ' S i. If there is circulation to surface, then Hilcorp will circulate cement down the backside, through the casing punches, and up the 7" casing to surface. Down hole plugging operations are complete. K Hil.m A].J., Lb Well Prognosis Well: SRU 234-15 Date: 9/18/2018 b. If there is no circulation to surface, then additional perforations will be shot 100' above the surface casing shoe ( 2,776'— 2,780'). L Cement will be placed from the CIBP up to 2,500'. Pressure will be applied and a braden head squeeze will be used to squeeze cement behind the 7" casing isolating the surface casing shoe and setting a 200+ foot cement plug across it. WOC. RIH and tag TOC to insure TOC is above 2,776' (if not, place a second plug of cement to bring the level up to this point. c. A CIBP will be set at 160'. Holes will be punched in the 7" casing at 150' and cement circulated down the 7" X 11-3/4" annulus, through the holes punched in the 7" and up the 7" casing to surface. 12. Place dry hole tree on well. 13. RDMO Workover Rig. Post Rig Abandonment Procedures: �14. Excavate cellar, cut off casing 3' below natural GL. NDS 15. Notify AOGCC and BLM 48hrs in advance. �^ 1 16. Create well abandonment marker per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G.10. The following must be bead -welded directly to the marker plate: 17. Hi c' s <a, LLC 18. PTD: 160-041 19. Well Name: SRU 234-15 20. API:50-133-10142-00 21. Set marker plate per 20 AAC 25.120 and BLM Onshore Order No. 2 III.G 22. Photo document casing cut-off and Welded Plate install. 23. Backfill excavation, close out location. ` hot S, k Attachments: hot Actual Schematic Proposed Schematic BOPE Schematic 10, collect GPS coordinates. . -roof I/e7 K Hilcom Alaska LLC 22" 11-3, Poel roc @ DVT RKB = 16.96' PBTD = 7,038' W LM - TD = 11,190' ACTUAL SCHEMATIC CASING DETAIL Swanson River Unit Well SRU 234-15 Last Completed: 02/17/13 PTD: 160-041 API: 50-133-10142-00 Size Wt Grade Conn ID Top Btm 22" - 10,615' Hanger, 9" Shaffer AGO 79L, 2-'/.", Butt Top & Btm 1 28' 11-3/4" 47 - 8rd 11.00 Surface 2,876' 10,692' 29 N-80 6.184 Surface 290' Baker Model"HS" Pkr 26 N-80 - 6.276 290' 1,190' 5 23 N-80 - 6.366 1,190' 4,890' 7„ 26 N-80 6.276 4,890' 6,690' 4.00 29 N-80 6.184 6,690' 8,490' 4.75 29 P-110 6.184 8,490' 11,190' JEWELRY DETAIL No Depth ID" OD" Item Retainer 16.96' Tubing Cut, 3-1/2" EUE Tubing 10,615' Hanger, 9" Shaffer AGO 79L, 2-'/.", Butt Top & Btm 1 500' 10,640' 5.437 Tripoint tubing retrievable bridge plug 2 10,675' 1 Tubing Retainer 10,692' Packer, Baker Mod. "FH" 3 5,746' 2.441 5.875 Baker Model"HS" Pkr 4 5,753' 2.313 3.187 Nipple, 'X', 2.3131.D. (PX plug in nipple) 5 5,762 2.347 3.5 WLEG MS 6 6,346' 4.00 5.937 Baker Model "SC -1, 70B40 GP Pkr 7 6,351' 4.00 5.75" Gravel Pack 51dg Slve Ext w/ 16' Lwr Ext. 8 1 6,375' 1 3.50 1 4.75 1 Baker KOIV 9 6,377' 4.00 4.625 Baker GPR-24 SOS1 10 6,380' 3.550 4.0 Blank Pipe, 38' 11 6,417' 3.550 4.590 4"x 12ga Bakerweld 140 Screen, 30' 12 6,448' 3.00 4.875 Baker S-22 SLSA 13 6,450' 4.00 5.75 Baker Model "F-1", 85-40 Sump Pkr. Correlated w/ E/line ABANDONED Depth Item 7,075' PosiSet Plug w/ 37' Dump Bailed Cement Plug 8,148' Retainer 10,200' Tubing Cut, 3-1/2" EUE Tubing 10,615' 2-7/8" x 3-1/2" Crossover 10,620' Tubing Retainer 10,640' Tubing Perf 10,648' Mandrel, Camco "MM" 10,675' 1 Tubing Retainer 10,692' Packer, Baker Mod. "FH" 10,730' Nipple, Otis "S" 10,733' Tubing Perf 10,795' Mandrel, Camco "MM" 10,818' Tubing Retainer 10,840' Nipple, Camco "D" 10,842' Packer, Baker Mod."F" 10,880' Tubing Tail PERFORATIONS Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Date Comments 5,820' 5,856' 5,820' 5,856' 36' 6 1/10/2002 2" HC @ 60deg 6,268' 6,280' 6,268' 6,280' 12' 6 1/6/2002 Abandoned 6,432' 6,442' 6,432' 6,442' 10' 6 7/9/2001 Abandoned 7,120' 7,156' 7,120' 7,156' 36' 4 1/15/1995 Abandoned 8,035' 8,063' 8,035' 8,063' 28' 4 11/27/1994 Squeezed 10,793' 10,797' 10,793' 10,797' 4' Abandoned 10,802' 10,812' 10,802' 10,812' 30' Abandoned 10,818' 10,837' 10,818' 10,837' 19' Abandoned 10,850' 10,892' 10,850' 10,892' 42' Abandoned Downhole Revised: 2/17/13 Updated by STP 12/06/13 K Flilmm Alaska. LLf. RKB= 16.96' 22" J TOC±2,776' 11-3/4" TOC @ 5,711' Possible ag dam3g- across geacr ss pedintsrva1 12 TOC @ 7,038' WLM DV Tool @ 7,978' PROPOSED SCHEMATIC 7 Ip PBTD = 7,038' W LM - TD = 11,190' rAUNQ DFTAII Swanson River Unit Well SRU 234-15 Last Completed: 02/17/13 PTD: 160-041 API: 50-133-10142-00 Size Wt Grade Conn ID Top Btm 22" - - Hanger, 9" Shaffer AGO 79L, 2-Y..", Butt Top & Btm 1 28' 11-3/4" 47 - 8rd 11.00 Surface 2,876' 10,692' 29 N-80 6.184 Surface 290' Baker Model"HS" Pkr 26 N-80 - 6.276 290' 1,190' 5 23 N-80 - 6.366 1,190' 4,890' 7„ 26 N-80 6.276 4,890' 6,690' 4.00 29 N-80 6.184 6,690' 8,490' 4.75 29 P-110 - 6.184 8,490' 11,190' JEWELRY DETAIL No Depth ID" OD" Item Retainer 16.96' Tubing Cut, 3-1/2"EUE Tubing - Hanger, 9" Shaffer AGO 79L, 2-Y..", Butt Top & Btm 1 ±150' 10,640' Tubing Perf CIBP @ 150'cement to surface 2 ±2,985' Tubing Retainer 10,692' CIBP w/±209' of cement 3 5,746' 2.441 5.875 Baker Model"HS" Pkr 4 5,753' 2.313 3.187 Nipple, ')C, 2.3131.D. (PX plug In nipple) 5 5,762 2.347 3.5 WLEG MS 6 6,346' 4.00 5.937 Baker Model "SC -1, 70B40 GP Pkr 7 6,351' 4.00 5.75" Gravel Pack Sldg Slve Ext w/ 16' Lwr Ext. 8 6,375' 3.50 4.75 Baker KOIV 9 6,377' 4.00 4.625 Baker GPR-245051 10 6,380' 3.550 4.0 Blank Pipe, 38' 11 6,417' 3.550 4.590 4"x 12ga Bakerweld 140 Screen, 30' 12 6,448' 3.00 4.875 Baker S-225L5A 13 6,450' 4.00 5.75 Baker Model "F-1", 85-40 Sump Pkr. Correlated w/ E/line ARANDONFD Depth Item 7,075' PosiSet Plug w/ 37' Dump Bailed Cement Plug 8,148' Retainer 10,200' Tubing Cut, 3-1/2"EUE Tubing 10,615' 2-7/8" x 3-1/2" Crossover 10,620' Tubing Retainer 10,640' Tubing Perf 10,648' Mandrel, Camco "MM" 10,675' Tubing Retainer 10,692' Packer, Baker Mod. "FH" 10,730' Nipple, Otis "S" 10,733' Tubing Perf 10,795' Mandrel, Camco "MM" 10,818' Tubing Retainer 10,840' Nipple, Camco "D" 10,842' Packer, Baker Mod."F" 10,880' Tubing Tail PFRFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Date Comments T54-5 5,820' 5,856' 5,820' 5,856' 36' 6 1/10/2002 2" HC @ 60deg T59-2 6,268' 6,280' 6,268' 6,280' 12' 6 1/6/2002 Abandoned T61 -3A 6,432' 6,442' 6,432' 6,442' 10' 6 7/9/2001 Abandoned T68-0 7,120' 7,156' 7,120' 7,156' 36' 4 1/15/1995 Abandoned T77-3 8,035' 8,063' 8,035' 8,063' 28' 4 11/27/1994 Squeezed 10,793' 10,797' 10,793' 10,797' 4' Abandoned Hl 10,802' 10,812' 10,802' 10,812' 10' Abandoned H2 10,818' 10,837' 10,818' 10,837' 19' Abandoned H3/H4 1 10,850' 1 10,892' 1 10,850' 10,892' 42' Abandoned Downhole Revised: 2/17/13 Updated by DMA 01-17-18 HILCORP ALASKA 7-1/16" 5M BOPE 7-1/16" 5M HYDRIL GK ANNULAR 32" TALL, FLANGE TO FLANGE SM LWS DBL GATE BOP DRESSED W/VARIABLE RAMS IN TOP DRESSED W/BLIND RAMS IN BOTTOM 26-3/4" TALL, FLANGE TO FLANGE 7-1/16" SM DRILLING SPOOL W/2-1/16" 5M OUTLETS 18" TALL, FLANGE TO FLANGE —77" TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: - 3.30 gallon open chamber volume - 3.86 gallon close chamber volume GATE STYLE BOP SPECS: - 1.45 gallons to close per gate -1.18 gallons to open per gate - 5.45:1 closing ratio - 1.93:1 opening ratio Roby, David S (DOA) From: Chad Helgeson <chelgeson@hilcorp.com> Sent: Friday, September 21, 2018 1:08 PM To: Roby, David S (DOA) Cc: Schwartz, Guy L (DOA); Davies, Stephen F (DOA); Boyer, David L (DOA); Benjamin Siks; Daniel Taylor; Ted Kramer Subject: RE: [EXTERNAL] Sundry application to P&A SRU 234-15 (PTD 160-041) Attachments: 20171030 BLM SRU 234-15 Future Plan NOI DUE 12-31-17.pdf Dave, We received the attached letter from the BUM last year forcing us to take action with this well. So we evaluated the well and potential targets this well could be used for. We have learned a lot of new information since this well was suspended in 2013, particularly we drilled 2 new wells from this pad, the SRU 11-22 and SRU 24-15 which provided us new logs in the area and we drilled 2 gas wells to the North of this location (SRU 213-15 and SRU 21313-15), that also provided us new information that we did not have in 2013 when this well was suspended, and feel that we have or are testing the shallower horizons in the wells to the north in a better part of the reservoir. Our preference is to keep suspended wellbores in Swanson River for future sidetracks, as we are continuing to learn new things about our fields and reservoirs in the cook inlet. We learn new analysis techniques and have different people working the fields with different experiences and allow us to find things that others might have missed. As far as saving the well for a future sidetrack, our geological team determined that the use of this well for a side track for the North fault block gas potential was going to be difficult due to the current well geometry. The probability of using the well for a sidetrack this year was unlikely with our limited budget and gas demand this year in the Cook Inlet. We determined that since we could not realistically use the well as a sidetrack this year or return the well to production, we should move forward with the P&A. Let us know if you need any additional information on this or have more questions on our thought process through this. Chad From: Roby, David S (DOA) [mailto:dave.roby@alaska.gov] Sent: Tuesday, September 18. 2018 5:36 PtV To: Chad Helgeson <chelgeson@hilcorp.com> Cc: Schwartz, Guy L (DOA) <guy.schwartz@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Boyer, David L (DOA) <david.boyer2@alaska.gov> Subject: [EXTERNAL] Sundry application to P&A SRU 234-15 (PTD 160-041) Chad, In the February 12, 2013, application to suspend the subject well Hilcorp stated: "The purpose of this workover is to temporarily suspend this well and plug back existing perfs to make room on the surface location for the drill rig to drill the SRU 24-15 and 22-22 wells in Spring of 2013. We believe that there is additional zones that may have future gas potential and the current zones do not have any economic reserves left in them." The well was suspended effective February 17, 2013, and has remained in a suspended status ever since. Why has the temporary suspension that was necessary for drilling operations now turned into a P&A instead of reentering the well and testing the shallower zones for gas potential as stated in the sundry application to suspend the well? Regards, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907)793-1232 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 Dave Roby at (907)793-1232 or dove cony,, clasxa_uuv. United States Department of the Interior BUREAU OF LAND MANAGEMENT IV Alaska State Office 222 West Seventh Avenue, #13 Anchorage, Alaska 99513-7504 http://www.blm.gov/ak October 26, 2017 In Reply Refer To: 3160(AK932) Certified Mail No: 7006 0810 0000 6317 6362 Return Receipt Requested Hilcorp Alaska, LLC Chad Helgeson, Operations Manager 3800 Centerpoint Dr., Suite 1400 Anchorage, AK 99503-5826 Re: Swanson River Field SRU 234-15 [API# 50-133-142001 Order to Return Well to Production or Permanently Plug and Abandonment Dear Mr. Helgeson, This letter is in regards to the SRU 234-15 well at the Swanson River Unit. The SRU 234-15 well has not produced since 2001. It was stated in Hilcorp's 53rd Plan of Development (POD) that this well is a candidate for a shallow gas sidetrack. In the Sundry Notice submitted to renew the Temporary Abandonment (TA) status of this well, Hilcorp stated "This well was plugged back several thousand feet above the Hemlock and has a 7 inch production casing, making as standard sidetrack with a 4.5 inch liner impossible to drill" The tree for this well was removed during the drilling of the SRU 11-22 and SRU 24-15 wells and has not been re -installed since drilling operations were completed in January 2014. BLM believes at this time that there is currently no future utility for this well bore and it should be permanently plugged and abandoned. Per 43 CFR 3162.3-4(a), "The operator shall promptly plug and abandon, in accordance with a plan first approved in writing or prescribed by the Authorized Officer, each newly completed or recompleted well in which oil or gas is not encountered in paying quantities or which, after being completed as a producing well, is demonstrated to the satisfaction of the Authorized Officer to be no longer capable of producing oil or gas in paying quantities, unless the Authorized Officer shall approved the use of the well as a service well for injection to recover additional oil or gas or for subsurface disposal of produced water." Hilcorp must submit a plan for the future of the SCU 24313-4 well via Form 3160-5, Sundry Notices and Reports on Wells, Notice of Intent. The plan must include procedure to either bring the well onto production, convert the well to a service well, or to permanently plug and abandon the well. These plans must be submitted to BLM no later than 60 days after the receipt of this letter. If you have any questions or concerns regarding this matter, please contact Amanda Eagle, Petroleum Engineer, at (907) 271-3266 or aeaglena blm.gov. Sincerely, 640 Robert Brumbaugh Acting Chief, Branch of Energy and Minerals Cc: Andy Loranger, Refuge Manager Kenai National Wildlife Refuge P.O. Box 2139 Soldotna, AK 99669 Bonnie Million, Field Manager Anchorage Field Office 4700 BLM Road Anchorage, AK 99507-2599 1,000,000 100,000 10,000 1,000 100 10 Jan -1960 HILCORP ALASKA LLC, SWANSON RIV UNIT 234-15 (160-041) SWANSON RIVER, TYONEK GAS Monthly Production Rates Jan -1965 Jan -1970 Jan -1975 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 1,000,000 100,000 10,000 1,000 100 10 Jan -2005 SPREADSH E ET_P rod -I nject_Cu rves_W e II_V 115_1600410_SRU_234-15_Tyonek_ Gas_20180918.xlsx 9/18/2018 HILCORP ALASKA LLC, SWANSON RIV UNIT 234-15 (160-041) SWANSON RIVER, HEMLOCK OIL Monthly Production Rates 1,000,000 100,000 t s= O 10,000 - a iy 1,000 - u 100 - e Produced Gas(MCFM o Produced Oil (BOPM) e Produced Water IBOPM) ---... _ -- — _ Cum. Prod Oil (bbls): 577,501 Cum. Prod Water(bbis): 1,368,701 Cum. Prod Gas (mcf): 714,853 Lie4o AP 8 ° s y Q� e o -- Yt ---------------------------------------------------------- -_ — — - s o p e — — - — — — - — --- --- — -- -- _ — -- --- -- --- — —--- 1,000,000 100,000 W 01 10,000 m 0) 1,000 3 0 3 100 S 10 10 Jan -1960 Jan -1965 Jan -1970 Jan -1975 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 1,000,000 100,000 L C 0 10,000 d ° 1,000 U 100 10 Monthly Injection Rates ------------------------------------------------------------ ---------------------------------------------------------- -_ e — ---. e —--------------------------------------------------------- -- ------------------------------------------— --- — --- - Cum. Ini Liquid (bbls)::4,643,J530 2,056Injected Cum.InjGas(mcf): e Injected Gas (MCFM) Water (BOPM) 100,000 w v rD 10,000 n O 1,000 Jan -1960 Jan -1965 Jan -1970 Jan -1975 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 SPREADSHEET _Prod -I nject_Curves_W ell_V115_1600410_SRU_234-15_Hemlock_Oil_20180918.xlsx 9/18/2018 STATE OF ALASKA ALODA OIL AND GAS CONSERVATION COMI.ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ] Plug Perforations H Fracture Stimulate _] Pull Tubing A Operations shutdown ❑ Performed: Suspend ] Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspended Well Inspection ❑✓ 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: Hilcorp Alaska,LLC Name: Development LIExploratory ❑ ' 160-041 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 - 50-133-101420-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028384 ' - Swanson River Unit(SRU)234-15 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field/Hemlock Oil-Tyonek Undef Gas 11. Present Well Condition Summary: Total Depth measured • 11,190 feet Plugs measured 500 feet CE I V E true vertical . 11,190 feet Junk measured N/A feet 5,746; L_P 1 1 2015 Effective Depth measured 5,711 feet Packer measured 6,346;6,450 feet true vertical 5,711 feet true vertical 5,746; feetoGCC 6,346;6,450 �w Casing Length Size MD TVD Burst Collapse Structural Conductor 28' 22" 28' 28' Surface 2,876' 11-3/4" 2,876' 2,876' 3,070 psi 1,510 psi Intermediate Production 11,190' 7" 11,190' 11,190' 6,340 psi 3,830 psi Liner Perforation depth Measured depth See Attached Schematic SCANNED DEC 1 5 2015 True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) N/A N/A N/A Baker HS; 5,746'; 5,746'; Packers and SSSV(type,measured and true vertical depth) SC-1 &F-1 Pkrs; N/A 6,346';6,450'MD 6,346';6,450'TVD NA; N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 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 ❑ Exploratory❑ Development❑✓ , Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ - SUSP❑✓ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Joe Kaiser Email jkaiser@hilcorp.com Printed Name Lk-4r` lyt��,� Joe Kaiser Title Operations Engineer Signature z"/_, l��G� fZ,,,� Phone 907-777-8393 Date yAll`5- 7f RBDMS SEP 15 2015 Form 10-404 Revised 5/2015 �(-(7"i't Submit Original Only ,f t/,J, • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/26/15 Inspector: Jeff Jones Operator: Hilcorp Alaska Well Name: Swanson River Unit 234-15 Oper. Rep: Rick Musgrove PTD No.: 160-041 Oper. Phone: 907-283-2551 Location Verified? Yes Oper. Email: rmusgrove@hilcorp.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 02/17/13 Date AOGCC Notified: 08/04/15 Sundry No.: 313-074 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 7 Photos Taken? Yes IA N/A OA N/A Condition of Wellhead: No production tree, Blind flange. Condition of Surrounding Surface Location: Good condition,gravel pad. Follow Up Actions Needed: None Comments: Location verified by well sing. Lat.60.779699035487 Long.-150.83522238374 Attachments: REVIEWED BY: Insp.Supry Comm PLB 12/2014 SRU 234-15 Suspended Well Inspection Form • H . • Swanson River Unit Well 5 ACTUAL SCHEMATIC Last Completed:SRU234-102/17/13 PTD: 160-041 Hihurp Alaska,LU API: 50-133-10142-00 RKB=16.96' CASING DETAIL V Size Wt Grade Conn ID Top Btm 22" 1 22" - - - 28' U 11-3/4" 47 - 8rd 11.00 Surface 2,876' 29 N-80 - 6.184 Surface 290' _ 26 N-80 - 6.276 290' 1,190' 7„ 23 N-80 - 6.366 1,190' 4,890' 11-3/4" - - 26 N-80 - 6.276 4,890' 6,690' 29 N-80 - 6.184 6,690' 8,490' 29 P-110 - 6.184 8,490' 11,190' TOC @ 5,711' JEWELRY DETAIL 37'cement plug No Depth ID" OD" Item i- I 3 16.96' - - Hanger,9"Shaffer AGO 79L,2-%d',Butt Top&Btm 1 500' 5.437 Tripoint tubing retrievable bridge plug : 111 ` 2 a • 4 3 5,746' 2.441 5.875 Baker Model"HS"Pkr 5 = T54-5 sand 4 5,753' 2.313 3.187 _ Nipple,'X',2.3131.D.(PX plug in nipple) 5 5,762 2.347 3.5 WLEG MS r'-;'• 6 6,346' 4.00 5.937 Baker Model"SC-1,70B40 GP Pkr T59-2 sand 7 6,351' 4.00 5.75" Gravel Pack Sldg Sive Ext w/16'Lwr Ext. "'!".':1„'?" w 8 6,375' 3.50 4.75 Baker KOIV 9 6,377' 4.00 4.625 Baker GPR-24 SOSJ "- 6 10 6,380' 3.550 4.0 Blank Pipe,38' -T61-3 11 6,417' 3.550 4.590 _ 4"x 12ga Bakerweld 140 Screen,30' 1•1•1[41 7 12 6,448' 3.00 4.875 Baker S-22 SLSA 13 6,450' 4.00 5.75 Baker Model"F-1",85-40 Sump Pkr.Correlated w/E/line 9- 10 �" "'~ ABANDONED Pti aaossle csg perfint interval - _�11 Depth Item 4.-,+-r ,1 7,075' PosiSet Plug w/37'Dump Bailed Cement Plug 12 _i �i 8,148' Retainer �_ 13 10,200' Tubing Cut,3-1/2"EUE Tubing 10,615' 2-7/8"x 3-1/2"Crossover TOC @ 7,038'WLM 10,620' Tubing Retainer 10,640' Tubing Perf 10,648' Mandrel,Camco"MM" T68-0 10,675' Tubing Retainer DV Tool @ 7,978' I I 10,692' Packer,Baker"Mod."FH" 10,730' O Nipple,Otis"S" Moi---- _- T77-3 10,733' Tubing Perf Will 10,795' Mandrel,Camco"MM" 10,818' Tubing Retainer i.=_ 10,840' Nipple,Camco"D" El10,842' Packer,Baker Mod."F" 10,880' Tubing Tail oilmio ►m■►�� IN PERFORATIONS I H1 Top(MD Am sp ►���►�� Zone ) Btm(MD) Top(TVD) Btm(TVD) t f Date Comments 154-5 5,820' 5,856' 5,820' 5,856' 36' 6 1/10/2002 2"HC @ 60deg T59-2 6,268' 6,280' 6,268' 6,280' 12' 6 1/6/2002 Abandoned D H2 T61-3A 6,432' 6,442' 6,432' 6,442' 10' 6 7/9/2001 Abandoned H3/H4 168-0 7,120' 7,156' 7,120' 7,156' 36' 4 1/15/1995 Abandoned T77-3 _ 8,035' 8,063' 8,035' 8,063' 28' 4 11/27/1994 Squeezed 10,793' 10,797' 10,793' 10,797' 4' Abandoned Hl 10,802' 10,812' 10,802' 10,812' 10' Abandoned 7" ' H2 _ 10,818' 10,837' 10,818' 10,837' 19' Abandoned H3/H4 10,850' 10,892' 10,850' 10,892' 42' Abandoned PBTD=7,038'WLM-TD=11,190' Downhole Revised:2/17/13 Updated by STP 12/06/13 • • f''''"si///j//f 11111111 f iiiiiiiiiiiiit //it' . II riii //Ili r //it'll riiiiiiiiiiii , 1 Viiiiiiiiiiiii . . +f _. . , , ..11.. „..,. .. ..,. ...., . ,, ,,,,. ' ' ....r. . ... . ,, , . •r . . „, . .,. I`Nilcorp Alaska,LLC , 1 = ,, �r.�s.NRiveRUNi123415 sRu234151 .�,¢; �t''" 'M it ya s of API P.50-133-10142-00.00 ,:.-1:: . ,4'4,t x•p " r 1 PTO#160-047 .y4 a `q • m "4 LEASE#A028384 ^ W �� a SURFACE LOCATION "� .„.1• t tt.,,se , SWV4,SE1/4,SEC 15,TBN,R9W,SM,AK it' WO '"�' q '*� � ; .. 4,„;i41% ,,:^ 1r,` „t,',1, t as op ..., � .�✓' ;may„ y ,� A_ • s, 4 fly a. TA! 1 _ :46 S= �f 4' Ix �L, .";. 4 T � !L / y' ' tr4J X • • ..y r K , Wit t�. ��, -,.,,,,-.,., .--, ,,:rep,,,,,- ; 4 ,,,, ,,,,..A . 3X � r d ` ag -, s S � 4_ti ' e. b 1” k .:,iL � ..�,,n r — ...}i« ,":�'t .7)"..�':..��� --..t Ac..i. . ;.,"6. • • , �! ,.! ' 4i, - r v f F A1� 0 7a t��r "� 6 .7.4'. ,�� 1, r i } tk',^`) 1�4 " ,/fist .1:�..;::•-•'2:':;.•7,;'' '-4•4:-':';''''''''':''''''''' .�� 5+i et e L c t, ,4•#ar,4 - ` . �, ,A1 r X R I { 7 014 N ,i �� .i:4,-',": _1,'-':. Nrt y ,� r, t ��\\\!!!• • St _ `�' , • r +t i. Ct \� ( t �Sr t . .„: ,1 ••','.4.;,,,';'—`,'" 1 •;6.•-•;,.-.••-•-•'-'.• Tl, • � � 1. €.". :fie ,, j • 'i a. n ,� ,• tiF! t d'M 4.N4 . c. Sys L ,i'- , ,'ev I S .'c . x or$ • 'i„s:,.a f..�r• :z,�r.�i:�.A - ,��r.•. .N. ,,,...f,,,,:.,., • ,'� .s,. ,,ava•a..tx, ., �. a • ill .1,:., .... , ' '',:i_. ....•.'- ' ..- . ' „.....:: yl v -t" .1;.. 411/2„, /.,,4 ,1 ' t, . ' e4iii''''';"':' ---1' ' -, ,.., 4 , \` A` Y shy'' r w • Hforp Alaska SRU 34-10 ( #1) Suspended Well Location SRU 211-15 Quarter Mile Radius Map Xn� SRU 234-15 SRU_21-15 0 1,000 2,000 FEET SRU 31-15 -1 6 POSTED WELL DATA Well Label • • WELL SYMBOLS SRU 12-15 S RU41A-15 Abandoned Well Gas Well SR 212B-15 o Location Only • Oil Well I 4- Shut-in Well 1 � lT 5RU 213-15 September 2,zo,5 SRU_32C-15 • SRU_43B-15 O SRU43-15RD SRU 23-15 RU_213B-15 SRU_43-15 SRU_234-15 SRU 24-15 1_14-15 (#4) SRU 21-22 • • SRU 11-22 SRU 32-22 SRU 412-22 SRU_22-23 ( 4 0 OSRU 23-22 PETRA 91220159:42:43 AM • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/26/15 - Inspector: Jeff Jones Operator: Hilcorp Well Name: SRF 234-15 Oper. Rep: Rick Musgrove PTD No.: 1600410 - Oper. Phone: 907-283-2551 Location Verified? Yes Oper.Email: musarove(cahilcorp.com If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 02/17/13 Date AOGCC Notified: 08/04/15 Sundry No.: 313-074 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 7 Photos Taken? Yes -- IA IA N/A OA N/A • Condition of Wellhead: Good condition,no production tree,no visible leaks. Blind flange on surface casing. No flow line connected. - Condition of Surrounding Surface Location: Good,clean gravel pad, Follow Up Actions Needed: None Comments: Lat/Long taken from well sign Attachments: Photos(2) REVIEWED BY: Well Schematic Insp.Supry t ZIZ,j Comm SCANNED SEP 0. 7 2016 PLB 06/2014 2015-0826 Suspend_SRU_234-15Jj.xlsx • . • p '...I i i i i , _ ...... . . .. , . . . .. .., Nos ., . .... i w , .,4„, ,_, ,.. .„ illop,,,, . . . 0,7 ,.• . ill" ,, II ': ` r WIN 1111111 4 S •, , .,p 77FY ` •g1 :,,.. in .w. a 1 3 ,.., ,,, ,......:;1 G> ' . t • Cel CI) cll U k. '"� -d "al CA G> © V) o• <e ' .o 'r y -- co 0 N tilit4 w ' 4C t O .—. CA ` Ai till N Z [—, .. N ' " 1� x o c N A. CA A-1 A-1 oo . , . 11 • • ACTUAL SCHEMATIC Swanson River Unit Well SRU 234-15 Last Completed: 02/17/13 PTD: 160-041 Hileorp Alaaka,LLC API: 50-133-10142-00 RKB=16.96' CASING DETAIL Size Wt Grade Conn ID Top Btm 22".- 1 22" - - 28' LI - 11-3/4" 47 - 8rd 11.00 Surface 2,876' 29 N-80 - 6.184 Surface 290' 26 N-80 - 6.276 290' 1,190' 23 N-80 - 6.366 1,190' 4,890' 7" 11-3/4" _..... .„. 26 N-80 6.276 4,890' 6,690' 29 N-80 - 6.184 6,690' 8,490' 29 P-110 6.184 8,490' 11,190' JEWELRY DETAIL TOC @ 5,711' 37'cement plug No Depth ID" OD" Item 3 16.96' - - Hanger,9"Shaffer AGO 79L,2-%",Butt Top&Btm MUM Lit 1 500' 5.437 Tripoint tubing retrievable bridge plug 2 4 3 5,746' 2.441 5.875 Baker Model"HS"Pkr 5 ._-._ T54 5 sand 4 5,753' 2.313 3.187 Nipple,'X',2,313 ID.(PX plug in nipple) 5 5,762 2.347 3.5 WLEG MS 6 6,346' 4.00 5.937 Baker Model"SC-1,70640 GP Pkr T59-2 sand 7 6,351' 4.00 5.75" Gravel Pack Sldg Sive Ext w/16'Lwr Ext. 5111.1,10 8 6,375' 3.50 4.75 Baker KOIV 9 6,377' 4.00 4.625 Baker GPR-24 SOSJ 6 10 6,380' 3.550 4.0 Blank Pipe,38' 7-7- -7r---;1 0 i P.a T61-3 ;Li', al 7=Mil io 12 6,448'11 6,417' 13 6,450' 3.550 4.590 Cx 12ga Bakerweld 140 Screen,30' 3.00 4.875 Baker S-22 SLSA 4.00 5.75 Baker Model"F-1",85-40 Sump Pkr.Correlated w/E/line 9 1 Atfr ABANDONED Possible csg damage i4 .. g,ii Depth Item across perf interval 44,.. ..f 7,075' PosiSet Plug w/37'Dump Bailed Cement Plug 12 411.1••••itli 8,148Retainer 13 10,200' Tubing Cut,3-1/2"EUE Tubing 10,615' 2-7/8"x 3-1/2"Crossover -roc @7,038'WLM 10,620' Tubing Retainer , 10,640' Tubing Perf 10,648' Mandrel,Camco"MM" T68-0 10,675' Tubing Retainer "i DV Tool @ 7,978' 1 10,692' Packer,Baker Mod."FH" - _ 10,730' Nipple,Otis"S" - - T77-3 10,733' Tubing Perf 10,795' Mandrel,Camco"MM" -f 1- 10,818' Tubing Retainer 10,840 Nipple,Camco"D" K:. 10,842' Packer,Baker Mod."F" Kr = 10,880' Tubing Tail ,..-- -C PERFORATIONS ,,,• H1 Top(MD Am sp Zone ) Btm(MD) Top(TVD) Btm(TVD) t f Date Comments .,,„,...11.. ...a._ T54-5 5,820' 5,856' 5,820' 5,856' 36' 6 1/10/2002 2"HC @ 60deg T59-2 6,268' 6,280' 6,268' 6,280' 12' 6 1/6/2002 Abandoned P t H2 T61-3A 6,432' 6,442' 6,432' 6,442' 10' 6 7/9/2001 Abandoned Z.,--- T68-0 7,120' 7,156' 7,120' 7,156' 36' 4 1/15/1995 Abandoned -- H3/H4 T77-3 8,035' 8,063' 8,035' 8,063' 28' 4 11/27/1994 Squeezed H1 10,793' 10,797' 10,793' 10,797' 4' Abandoned 10,802' 10,812' 10,802' 10,812' 10' Abandoned H2 10,818' 10,837' 10,818' 10,837' 19' Abandoned H3/H4 10,850' 10,892' 10,850' 10,892' 42' Abandoned PBTD=7,038'WLM-TD=11,190' Downhole Revised: 2/17/13 Updated by STP 12/06/13 • UNSCANNED, OVERSIZED MATERIALS AVAILABLE: /�O LO `f ( FILE # To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission i333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 0 • ! UNSCANNED, OVERSIZED MATERIALS AVAILABLE: A0 ©c((' FILE # 1- £ v ef 1 1 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 DATE 04/22/2013 Landon Ellison Hilcorp Alaska, LLC GeoTech II 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8339 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Makana Bender Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 Prints: RST CD: Final Well Data RST LAS RST PDF SCMMOCT 0 2 20A Please include current contact information if different from above. �(00-OZAt 2'7,_xSG� APR 2 3 2013 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8337 Received By: Date: A6� &ar4��' 5 \t3 STATE OF ALASKA ALMA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 0 lb.Well Class: 20AAC 25.106 20nnc 25.110 • Development 0 ' Exploratory ❑ GINJ 0 VMNJ 0 WAG Ei WDSPL El No.of Completions: Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date Comp.,Susp.,or 12.Permit to Dri Number: Hilcorp Alaska,LLC Aband.: 2/17/2013 160-041 ' 3/3 -.074 3.Address: 6.Date Spudded: 13.API Nu r 3800 Centerpoint Drive,Suite 100,Anchorage,AK 99503 6/21/1961 50-133-10142-00 `!00 e 4a. Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: — 905'FSL,2380'FEL,Sec.15,T8N,R9W SM • 7/29/1961 ,, SRU 234-15 • Top of Productive Horizon: 8.KB(ft above MSL): )$:96 15.Field/Pool(s): 905'FSL,2380'FEL,Sec.15,T8N,R9W SM GL(ft above MSL): 3' ,3P r e 0 Total Depth: 9.Plug Back Depth(MD+TVD): Swanson River Field/Hemlock Oil- 905'FSL,2380'FEL,Sec. 15,T8N,R9W SM • 5,711'MD/ 5,711 TVD . Tyonek Undefined Gas 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x- 350723.4 . y- 2477868.1 ' Zone- 4 1 11,190'MD/11,190'TVD• FEDA028384 TPI: x- 350723.4 y- 2477868.1 Zone- 4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x- 350723.4 y-2477868.1 Zone- 4 N/A N/A 18. Directional Survey: Yes ❑ No 151 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21.Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MC/TVD: RST N/A 23. CASING,LINER AND CEMENTING RECORD WT.PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE HOLE SIZE CEMENTING RECORD FT TOP BOTTOM TOP BOTTOM PULLED 22" Surf 28' Surf 28' ; 11-3/4" 47# 8RD Surf 2,876' Surf 2,876' "' 7" 23 26 29# N80 P110 Surf 11,190' Surf 11,190' AO( C 24.Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom;Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): N/A Cast Iron Bridge Plu set @ 500' " - 5 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. d2ti ? Was hydraulic fracturing used during completion? Yes❑ No p • t Y� 'Z i3 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 5,711' Class G Cement 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: N/A N/A Test Period m..► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. N/A 24-Hour Rate —4 28. CORE DATA Conventional Core(s)Acquired? Yes❑ No❑ Sidewall Cores Acquired? Yes❑ No❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. SCANNED AUG 0 2 Z013 RSDMS APR 0 9 701j c - I Form 10-407 Revised 10/2012 CONTINUED ON REVERSE 74 7.1.13 S org only 59 .∎� . 0 • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS 1 NAME MD ND Well tested? ❑ Yes 0 No If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sterling A9 2,639' 2,639' Sterling B6 3,476' 3476' Top of Lower Beluga 4,602' 4602' Beluga 52-9 5,242' 5,242' Tyonek 54-5 5,818' 5,818' Tyonek 59-2 6,253' 6,253' N/A Formation at total depth: Tyonek 31. List of Attachments: Final Schematic, Daily Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Chad Helgeson Email: chelgeson nhilcorp.,Com Printed Name: Chad Helgeson Title: Operations Manager 07/Signature: Phone: 7 7 `(O i Date: j INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. Item 1 b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.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 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level 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 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well 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. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. 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. Form 10-407 Revised 10/2012 * • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 234-15 50-133-10142-00 160-041 2/14/13 2/17/13 Dairy Operations: 2/13/2013-Wednesday No activity to report. 2/14/2013 -Thursday MIRU SL, RIH w/2.31" GR, RIH set PX plug in x-nipple @ 5,753'. RIH. pulled GLV, RDMO SL. Test plug/packer to 2,500 psi for 30 mins. Test good. MIRU EL, RIH and cut TBG @ 5,736'. Laid contaiment and start RU WOR. 2/15/2013-Friday Finished RU WOR and installing winterization kits. Tested BOPE pre AOGCC/BLM regulations. (250 psi low-3,000 psi high - Witness waived by Jim Regg,AOGCC 2/15/13) 2/16/2013-Saturday Finished BOPE test. TOOH w/179 jts of 2-7/8". SOOH 500'. MIRU SL, made 5 runs w/5.58" dump bailer and dumped 37' of cement on packer. MIRU SLB EL, Logged from 5,700' to 2,700'. RIH and tag cement at 5,711'. 2/17/2013-Sunday .. .................... Tested cement plug to 2,500 psi (charted for 30 mins). Tested good. Set CBP at 500',tested to 2,000 psi (charted for 30 mins). Tested good. LD 16 jts of 2-7/8" tbg. RDMO WOR and winterization kits 2/18/2013- Monday No activity to report. 2/19/2013-Tuesday No activity to report. 0 • • • Swanson River Unit • Well SRU 234-15 SCHEMATIC Last Completed: 02/17/13 PTD: 160-041 Hilcorp Alaska,LLC API: 50-133-10142-00 RKB=16.96' CASING DETAIL Size Wt Grade Conn ID Top Btm 22" 1 22" 28' Ll 11-3/4" 47 - 8rd 11.00 Surface 2,876' 29 N-80 - 6.184 Surface 290' 26 N-80 - 6.276 290' 1,190' 23 N-80 - 6.366 1,190' 4,890' 7„ 11-3/4" 26 N-80 - 6.276 4,890' 6,690' 29 N-80 - 6.184 6,690' 8,490' 29 P-110 - 6.184 8,490' 11,190' TOC @ 5,711' / 37'cement plug ✓ JEWELRY DETAIL I IA I No Depth ID" OD" Item _-- 3 16.96' - - Hanger,9"Shaffer AGO 79L,2-%",Butt Top&Btm 1 500' 5.437 Tripoint tubing retrievable bridge plug 2 4 3 5,746' 2.441 5.875 Baker Model"HS"Pkr 5 E T54-5 sand , 4 5,753' 2.313 3.187 Nipple,'X',2.313 I.D.(PX plug in nipple) 5 5,762 2.347 3.5 WLEG MS +`•• '97 6 6,346' 4.00 5.937 Baker Model"SC-1,70B40 GP Pkr T59-2 sand 7 6,351' 4.00 5.75" Gravel Pack Sldg Sive Ext w/16'Lwr Ext. t SCr 8 6,375' 3.50 4.75 Baker KOIV 9 6,377' 4.00 4.625 Baker GPR-24 SOSJ r=, 6 10 6,380' 3.550 4.0 Blank Pipe,38' T61-3 11 6,417' 3.550 4.590 4"x 12ga Bakerweld 140 Screen,30' 7 12 6,448' 3.00 4.875 Baker 5-22 SLSA 111 11 13 6,450' 4.00 5.75 Baker Model"F-1",85-40 Sump Pkr.Correlated w/E/line 9 N 10 ABANDONED Possible csg damage L-; ❑11 Depth Item across pert interval 'y 7,075' PosiSet Plug w/37'Dump Bailed Cement Plug 12 i Ill 8,148' Retainer 13 10,200' Tubing Cut,3-1/2"EUE Tubing limi 10,615' 2-7/8"x 3-1/2"Crossover TOC @ 7,038'WLM 10,620' Tubing Retainer m 10,640' Tubing Perf u 10,648' Mandrel,Camco"MM" T68-0 10,675' Tubing Retainer DV Tool @ 7,978' II 10,692' Packer,Baker Mod."FH" 177-3 10,730' Nipple,Otis"S" -�- 10,733' Tubing Pert 10,795' Mandrel,Camco"MM" I 7 10,818' Tubing Retainer 10,840' Nipple,Camco"D" 10,842' Packer,Baker Mod."F" 10,880' Tubing Tail ►�I►�'4 PERFORATIONS iwit H1 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Date Comments _ _ T54-5 • 5,820' 5,856' 5,820' 5,856' 36' 6 1/10/2002 2"HC @ 60deg ►�� ��14 T59-2 6,268' 6,280' 6,268' 6,280' 12' 6 1/6/2002 Abandoned T61-3A • 6,432' 6,442' 6,432' 6,442' 10' 6 7/9/2001 Abandoned P H2 T68-0 '7,120' 7,156' 7,120' 7,156' 36' 4 1/15/1995 Abandoned T77-3 -8,035' 8,063' 8,035' 8,063' 28' 4 11/27/1994 Squeezed H3/H4 •10,793' 10,797' 10,793' 10,797' 4' Abandoned H1 10,802' 10,812' 10,802' 10,812' 10' Abandoned H2 •10,818' 10,837' 10,818' 10,837' 19' Abandoned 7" AMMIN H3/H4 • 10,850' 10,892' 10,850' 10,892' 42' Abandoned PBTD=7,038'WLM-TD=11,190' Updated by DMA 03/28/13 • • e 1 1 4, THE STATE Alaska Oil and Gas Conservation 11Commission ^ � ®11S� Vet lO � ® GOVERNOR SEAN PARNELL 333 West Seventh Avenue r,4 OF ALAS '"P' { Anchorage, Alaska 99501 -3572 MAR � �3 e9 L� L 3 Main: 907.279.1433 SCANNED t� Fax: 907.276.7542 A Chad Helgeson !� Operations Engineer Hilcorp Alaska, LLC � � d LC 3800 Centerpoint Drive, Suite 100 - Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil — Tyonek Undefined Gas Pool, SRU 234 -15 Sundry Number: 313 -074 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, CV/ Cathy P. Chair DATED this /? day of February, 2013. Encl. IV ED • III STATE OF ALASKA � 20 ALASKA OIL AND GAS CONSERVATION COMMISSION 21i� / APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend 151 Plug Perforations IN Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development 0 160 -041 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99503 50-133-10142-00 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Swanson River Unit (SRU) 234-15 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028384 Swanson River Field / Hemlock Oil - Tyonek Undef Gas 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,190 11,190 7,038 7,038 7,038' None Casing Length Size MD ND Burst Collapse Structural Conductor 13' 22" 28' 28' Surface 2,876' 11 -3/4" 2,876' 2,876' 3,070 psi 1,510 psi Intermediate Production 11,190' 7" 11,190' 11,190' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 2 -7/8" Tubing Grade: 6.4# / L -80 Tubing MD (ft): 5,720' See Attached Schematic See Attached Schematic 1-2/3" 3.02# / -- 2,521' Packers and SSSV Type: Baker Model "HS" Pkr Packers and SSSV MD (ft) and TVD (ft): 5,746' MD / 5,746' ND N/A N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 02/14/13 Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chad Helgeson Phone: 907 - 777 -8405 Email chelgesonnhilcoro.com Printed Name Chad Helgeson Title Operations Engineer J Signature (,, Phone 907-777-8405 Date j I zit COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 6- 0-7 , ` Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: ;E 3000 I w s� 1� �} P /, � _ A f'-(-- . ` / � t 41h.. -aC. GS t . Al- 7e-r • P 1 0 G Cc.c�..,i— p�✓ r `° Z S 1� o (7t) Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: //` L i O 7- R9 5 FEB lVJ 1 201 APPROVED BY Approved by: � COMMISSIONER THE COMMISSION Date: 2 - ( S /3 16 I 1\1rp S Form 10 - 403 (R t application is valid for 12 month rom the date of approval. ia. � Attachmen ts in DuForm plica to • • Hilcorp Alaska, LLC Post Office Box 244027 Anchorage, AK 99524 -4027 3800 Centerpoint Drive Suite 100 Anchorage, AK 99503 Phone: 907 /777 -8405 February 12, 2013 Fax: 907/777 8510 Mr. Guy Schwartz Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 Re: Swanson River Unit 234 -15 Workover Dear Mr. Schwartz: Please find enclosed a 10 -403 request to workover the Swanson River Unit 234 -15 Well (PTD # 160 -041). The purpose_ of this workover is to temporarily suspend the well and _plug back existing perfs to make room on the surface location for the drill rig to drill the SRU 24 -15 and 22 -22 wells in the Spring of 2013. We believe that there is additional zones that may have future gas potential and the current zones do not have any economic reserves left in them. The attached procedure requests the abandonment of the lower zones and leave the well in a condition we can bring a rig back in and complete for gas, when the drilling rig is completed with the drilling of the two aforementioned wells. Please consider this in an expedited manner as we would like to move onto this well ASAP to be in front of the drilling rig and moved off location before they are ready to move onto this well. If you have any questions regarding this work, please contact me via email (chelgeson @hilcorp.com) or via phone (777 -8405 office, 229 -4824 cell). Sincerely, HILCORP ALASKA, LLC Chad A. Helgeson Operations Manager — North Kenai Team Attachments: 10 -403 for 234 -15 H • • Well Prognosis Well: SRU 234 -15 Hilcor ) Alaska, LLC Date: 2/12/13 Well Name: SRU 234 -15 API Number: 50- 133 - 10142 -00 Current Status: Oil Producer Leg: N/A Estimated Start Date: February 14 2013 Rig: illiams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 160 -041 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) AFE Number: 1212877 Current Bottom Hole Pressure: - 2,480 psi @ 5,820' (static fluid level @ 127 w/ 8.4 ppg Water) Maximum Expected BHP: - 2,480 psi @ 5,820' Max. Allowable Surface Pressure: -0 psi (Based on current conditions on the Well SI since 2002.) Brief Well Summary Swanson River Unit 234 -15 was originally drilled and completed as an oil well in the Hemlock 1961. In January 1995, the well was converted to a development gas well completing in the Tyonek 68 -0 Sandi. In 1998 the 68 -0 sand was abandoned and moved up the hole to the 61 -3A Sand. Had trouble flowing this sand and shut -in well. In 2001 a rig workover was completed to gravel pack the 61 -3 sand with a 20/40 gravel pack. In 2002 the 61 -3 was abandoned and the 59 -2 sand was perforated, zone failed and was abandoned. In 2002 the 54 -5 sand was perforated. The well has been SI since 2002. Notes Regarding Wellbore Condition • Well has a single packer with a possible gas sand above the packer in the well. Work needs to be done on the well as 2 new grass roots drill wells will be drilled from this pad and the wellhead needs to be removed for the rig to fit on location. The plan is to abandon the lower completed part of the well and suspend the well to allow for new drill well and a future workover to complete the well in shallower ga sand at approximately 5,250'. Brief Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing and tubing. X_n�i 2. RU Slickline, RIH and set a tubing plug in i3e remove gas lift valve at 4,871'. 3. Circulate tubing and casing with PW with hot oil truck. Pressure test plug & packer to 2500 psi. (Jug test), chart for n. 4. RU e-line, PT lubricator, RIH and cut tubing at 5,736' (10ft above the packer) with a jet cutter. 5. RD eline. '�- 6. MIRU Williams 405 WO Rig 7. Set TWC, ND tree, NU BOPE and test to 250psi low /3,000psi high, annular to 250psi low /1,500psi high (hold each valve and test for 10 -min). Record accumulator pre- charge pressures. a. Notify AOGCC 24hrs in advance to witness, be ready to test when /if inspector arrives b. Ensure winterization package is completely installed 8. Remove TWC, pull tubing hanger and tubing. 0ve ,,,6 e ,. 20O / 4 ,, _ well 4a5 �1bT f ( '-CUr• � d n / G ,d) / 10K /W J- rf� uve it CI, 'ed, ,Le ve i) /70 VII', H S • Well Prognosis Well: SRU 234 -15 Hilcorp Alaska, LLC Date: 2/12/13 9. Pull 2 -7/8" 8rd EUE tubing, rack back 500ft of tubing and LD the rest. 10. RU e-line, RIH and dump bail 35.4 of cement on top of packer. 11. RU RST tool and RIH and log well from bottom (approx. 5,710') to 2,710' (don't tag bottom) 12. RIH with gauge ring and tag cement. 13. PU tubing retrievable bridge plug and RIH and set at approx. 500ft. 14. PU off bridge plug, test plug to 2000 psi. ctie •/3° 15. If good test, LD tubing string. 16. ND BOP, set dry hole tree. (ensure that tree is below grade for the Doyon rig to fit over well.) 17. RD Williams #405. Attachments Existing Schematic Proposed Schematic BOP Schematic Swanson River Unit ,ll 0 SCHEMATIC • Well SRU23415 Last Completed: 07/12/01 PTD: 160 -041 Hilcoru Alaska, LL(: API: 50- 133 - 10142 -00 RKB = 16.96' CASING DETAIL Size Wt Grade Conn ID Top Btm 22" 28' 11 -3/4" 47 8rd 11.00 Surface 2,876' 22" 29 N -80 6.184 Surface 290' 26 N -80 - 6.276 290' 1,190' 7 „ 23 N -80 - 6.366 1,190' 4,890' 1 26 N -80 - 6.276 4,890' 6,690' 11 -3/4" 29 N -80 6.184 6,690' 8,490' 29 P -110 6.184 8,490' 11,190' TUBING DETAIL 2 -7/8" 6.4 L -80 AB Mod. Butt 2.441 15' 5,720' 2 �Lt� 1 -2/3" 3.02 - CS Hydril 1.278 15' 2,521' I 449 & JEWELRY DETAIL 1 till ( No Depth ID" OD" Item 3 16.96' - - Hanger, 9" Shaffer AGO 79L, 2 - % ", Butt Top & Btm 1 2,470' 2.347 5.437 Chemical Injection Mandrel, SF -01 CF K Q 4,871' 2.347 4.750 Gas Lift Mandrel, SF -01 3 5,746' 2.441 5.875 Baker Model "HS" Pkr T54 -5 sand _ CJ 5,757' 2.313 3.187 Nipple, 'X', 2.313 I.D. 5 5,762 2.347 3.5 WLEG MS L`7<i' ,> 6 6,346' 4.00 5.937 Baker Model "SC -1, 70B40 GP Pkr IllaE T59 -2 sand 7 6,351' 4.00 5.75" Gravel Pack SIdg Sive Ext w/ 16' Lwr Ext. " 8 6,375' 3.50 4.75 Baker KOIV 9 6,377' 4.00 4.625 Baker GPR -24 SOSJ �� = 6 10 6,380' 3.550 4.0 Blank Pipe, 38' i � T61 -3 11 6,417' 3.550 4.590 4 "x 12ga Bakerweld 140 Screen, 30' 7 itozolic 12 6,448' 3.00 4.875 Baker 5 -22 SLSA 13 6,450' 4.00 5.75 Baker Model "F -1 ", 85-40 Sump Pkr. Correlated w/ E /line 9 =� 10 _ ABANDONED across cs8dervage 11 Depth It 7,075' PosiSet Plug w/ 37' Dump Bailed Cement Plug 12 1 '_ H 8,148' Retainer - _ 13 10,200' Tubing Cut, 3 -1/2" EUE Tubing 10,615' 2 -7/8" x 3 -1/2" Crossover TOC @ 7,038' WLM 10,620' Tubing Retainer n __� 10,640' Tubing Perf ' u 10,648' Mandrel, Camco "MM" T68 -0 10,675' Tubing Retainer DV Tool @ 7,978' C 1 10,692' Packer, Baker Mod. "FH" L T77 -3 10,730' Nipple, Otis "5" 10,733' Tubing Perf 10,795' Mandrel, Camco "MM" 10,818' Tubing Retainer 10,840' Nipple, Camco "D" 10,842' Packer, Baker Mod. "F" 10,880' Tubing Tail MI ROMS PERFORATIONS H1 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Date Comments _ T54 -5 5,820' 5,856' 5,820' 5,856' 36' 6 1/10/2002 2" HC @ 60deg MI ��� T59 -2 6,268' 6,280' 6,268' 6,280' 12' 6 1/6/2002 Abandoned T61 -3A 6,432' 6,442' 6,432' 6,442' 10' 6 7/9/2001 Abandoned P H T68 -0 7,120' 7,156' 7,120' 7,156' 36' 4 1/15/1995 Abandoned T77 -3 8,035' 8,063' 8,035' 8,063' 28' 4 11/27/1994 Squeezed H3 /H4 H1 10,793' 10,797' 10,793' 10,797' 4' Abandoned «* , 10,802' 10,812' 10,802' 10,812' 10' Abandoned H2 10,818' 10,837' 10,818' 10,837' 19' Abandoned 7" H3 /H4 10,850' 10,892' 10,850' 10,892' 42' Abandoned PBTD = 7,038' WLM - TD = 11,190' Updated by DMA 02/07/13 • Swanson River Unit SCHEMATIC • Well SRU23415 Last Completed: 07/12/01 PTD: 160 -041 Hilcorp Alaska, LLC API: 50 - 133 - 10142 - RKB = 16.96' CASING DETAIL yv►1 Size Wt Grade Conn ID Top Btm � C P 0 22" - - - 28' 11 - 3/4" 47 8rd 11.00 Surface 2,876' 22 ii 29 N -80 - 6.184 Surface 290' 26 N -80 - 6.276 290' 1,190' 23 N -80 - 6.366 1,190' 4,890' 1 7 26 N -80 - 6.276 4,890' 6,690' 11 -3/4" - 29 N -80 - 6.184 6,690' 8,490' 29 P -110 - 6.184 8,490' 11,190' TUBING DETAIL 1 2 - 7/8" 6.4 L -80 AB Mod. Butt 2.441 15' 5,720' 35 1 -2/3" 3.02 - CS Hydril 1.278 15' 2,521' .2sffcement plug 1 JEWELRY DETAIL ) 1 1 No Depth ID" OD" Item 3 AS r4� 16.96' - - Hanger, 9" Shaffer AGO 79L, 2 - % ", Butt Top & Btm _* i retrievable bride lu m a _ 5.437 Tripoint tubing -�,:,' 1 500' P g bridge plug ith 2 4 3 5,746' 2.441 5.875 Baker Model "HS" Pkr 5 = T54 sand 4 5,757' 2.313 3.187 Nipple,'X', 2.313 I.D. (PX plug in nipple) 5 5,762 2.347 3.5 WLEG MS tylk*7 *,./ 6 6,346' 4.00 5.937 Baker Model "SC - 1, 70840 GP Pkr T59 - sand 7 6,351' 4.00 5.75" Gravel Pack SIdg Sive Ext w/ 16' Lwr Ext. `? rf 8 6,375' 3.50 4.75 Baker KOIV 9 6,377' 4.00 4.625 Baker GPR -24 SOSJ _ 6 10 6,380' 3.550 4.0 Blank Pipe, 38' T61 -3 11 6,417' 3.550 4.590 4 "x 12ga Bakerweld 140 Screen, 30' IL•JNJ[ •x 7 ill : 12 6,448' 3.00 4.875 Baker S -22 SLSA 13 6,450' 4.00 5.75 Baker Model "F -1 ", 85 -40 Sump Pkr. Correlated w/ E /line 9 10 _ ABANDONED ac int rvale;� 11 Depth Item . 7,075' PosiSet Plug w/ 37' Dump Bailed Cement Plug 12 ? I. 8,148' Retainer - �_ 13 10,200' Tubing Cut, 3 -1/2" EUE Tubing 10,615' 2 -7/8" x 3 -1/2" Crossover TOC@ 7,038' WLM 10,620' Tubing Retainer 10,640' Tubing Perf u 10,648' Mandrel, Camco "MM" W. T68 -0 10,675' Tubing Retainer DV Tool @ 7,978' L 10,692' Packer, Baker Mod. "FH" L T77 -3 10,730' Nipple, Otis "S" 10,733' Tubing Perf 10,795' Mandrel, Camco "MM" 10,818' Tubing Retainer 10,840' Nipple, Camco "D" 10,842' Packer, Baker Mod. "F" 10,880' Tubing Tail Z1 1►Z� LH PERFORATIONS H1 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Date Comments =, �, T54 -5 5,820' 5,856' 5,820' 5,856' 36' 6 1/10/2002 2" HC @ 60deg T59 -2 6,268' 6,280' 6,268' 6,280' 12' 6 1/6/2002 Abandoned T61 -3A 6,432' 6,442' 6,432' 6,442' 10' 6 7/9/2001 Abandoned U H2 T68 -0 7,120' 7,156' 7,120' 7,156' 36' 4 1/15/1995 Abandoned H3 /H4 T77 -3 8,035' 8,063' 8,035' 8,063' 28' 4 11/27/1994 Squeezed H1 10,793' 10,797' 10,793' 10,797' 4' Abandoned or, r .. 10,802' 10,812' 10,802' 10,812' 10' Abandoned ... .f'' L- „• H2 10,818' 10,837' 10,818' 10,837' 19' Abandoned 7" H3 /H4 10,850' 10,892' 10,850' 10,892' 42' Abandoned PBTD = 7,038' WLM - TD = 11,190' Updated by CAH 02/12/13 • • • . n Swanson River SRU 234 -15 02/12/2013 IIIlrorp %I.s.ki;. I.IA.. Swanson River Williams BOP 2013 1i1 ili tit r�r 1 II iii 3.46' Shaffer 11" 5M lit 111 111 111 111 Shaffer LWS 2.75' U c : 11 "5M '. . • 0 2 1/16 10M Choke and Kill ' 0 '' Valves lill!!'1 1 1 �T '_ G. . I 0 * +II i .: J 2.00' 7 �' i 161 H1 111111 1e1 ° " I III 181181 1!1 111 X 2. 9" 5M 1 �i 1 III M III ii 101 _ h ; E l i e t . ll 111 In lit n 11. I I III CI 1 an Ilk 411 111 — 1�1 �1 11111111107 'I NO' August 3, 2009 Dale A. Haines Manager, Oil & Gas Operations Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, Union Oil Company of California 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com AUG 0 h 2009 E IcF, oil & 0os C-Onth Commigfiior, Re: 20 AAC 25.300 (Request for information) dated June 23, 2009— Status of Oil and Gas Wells This is Union Oil Company of California's response to your letter dated June 22, 2009 seeking the status of certain oil and gas wells. We have reviewed and revised the list of wells inactive for more than five years you provided us. Attached is an updated list with our comments. Please note that nearly a third of the list you provided is comprised of wells on the Baker and Dillon platforms. We are currently conducting operations to prepare both of those platforms for abandonment. We expect the actual well abandonment work to commence in 2010. Our long range well abandonment plans for our other fields are currently being developed. The current strategy is to group/sequence well abandonments by platform over the next several years. Please also note the following corrections to your list: (1) added G-30 to the Commission's list of wells (shut-in date of 6/02); (2) removed from your list SCU 21A-04 (which has been shut in for less than five years); and (3) removed from your list SCU 312-09 (now in Operational Shutdown status). Thank you for the opportunity to respond with the revisions to the list. If you would like to discuss our long range abandonment plans please let us know and we can set up a time to discuss them with the Commission. If you have any further questions regarding this response please contact Larry Greenstein at 907-263-7661 Sincerely, �) "'e,1Jctk�_ Dale Haines Alaska Area Operations Manager DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN Br 5-87 1680240 Apr -88 No known damage Gas - No Production Phase I Abandon abandon at end of platform life An -3RD 1941490 Sep -97 No known damage. Low oil production. Phase I Abandon abandon at end of platform life Br 1442 1790330 Dec -00 No known damage Produced water Phase I Abandon abandon at end of platform life Br 16-42 1670770 Feb -87 Abandoned Phase I Abandon abandon at end of platform life Br 1842 1680120 Apr -89 Collapsed Casing 100% water production Phase I Abandon abandon at end of platform life GP 31-14RD#2 1002660 Jul -98 No known damage High Water Cut Phase I Abandon abandon at end of platform life D-6RD 1820200 Dec -00 Tubing -to -casing communication Failed MIT Possible restore injection abandon at end of platform life D-18 1690040 Dec -03 No known damage Made too much sand and water Phase I Abandon abandon at end of platform life D-30RD2 1880980 Nov -91 Perforations covered Will not flow Currently used as volume bottle for gas abandon at end of platform life D-40RD 1820830 Se -01 Shallow hole in tubing near #2 GLM Stopped producing Phase I Abandon abandon at end of platform life G-8RD 1780450 Sep -02 E -Line wire in LS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-24 1760320 Mar -03 No known damage High Water Cut Phase I Abandon abandon at end of platform life G-30 1690470 Jun -02 Slickline fish in SS. Low oil production from LS. Phase I Abandon abandon at end of platform life G-34RD 1790130 Sep -02 No known damage Low oil production from LS. Phase I Abandon abandon at end of platform life K-6RD 1880280 Sep -98 Tubing and casing full of sand No Flow Phase I Abandon abandon at end of platform life K-9 1680380 Oct -96 Full of sand, Holes in casing. No Flow Phase I Abandon abandon at end of platform life K-20 1690660 Jun -02 Tubing sanded up No Flow Phase I Abandon abandon at end of platform life K-21RD 1790160 Jun -79 Tubing integrity in question High water cut Phase I Abandon abandon at end of platform life K-23 1780040 Sep -97 Tubing full of sand High water cut Phase I Abandon abandon at end of platform life Ba -5 1650380 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -6 1660030 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -11 1670170 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -13 1670490 Jun -03 No known damage Platform shut-in -- uneconomic Phase 1 Abandon abandon at end of platform life Ba -18 1760750 Oct -94 No known damage Gas well that watered out Phase I Abandon abandon at end of platform life Ba -20 1851350 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba-25RD 1830720 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -28 1931190 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -29 1931180 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -30 1931200 Jun -03 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Ba -31 1951990 Dec -97 No known damage Produced water Phase I Abandon abandon at end of platform life Di-2RD 1750070 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -3 1670280 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di4 1670580 Jul -98 Hydraulic pump failure No production Phase I Abandon abandon at end of platform life Di -13 1750440 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -14 1750660 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -15 1760450 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -16 1940570 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life Di -17 1940560 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platforrn life Di -18 1940980 Dec -02 No known damage Platform shut-in -- uneconomic Phase I Abandon abandon at end of platform life SCU 12A-10 1750570 Jan -97 milled through csg during plug removal rocks to 7000' Possible P&A 2010-2013 SCU 134 1750150 Jul -03 no known damage no flow Possible WO for T onek 2011-2014 SCU 13-9 1810980 Nov -01 no known damage no flow Possible G -Zone RTP 2011-2014 DATE Mechanical Condition Why well was Shut -In Future Plans Timeframe WELL PTD # SHUT-IN SCU 21-8 1620190 Aug-9parted tbg high water (Hem) no flow (G Zone) Possible P&A 2010-2013 SCU 21A-4 1801050 Dec -0 no known damage no flow Possible shallow gas Remove due to SI date SCU 2113-16 1852550 Se -0 no known damage no flow Possible shallow gas 2011-2014 SCU 2313-3 1840100 Apr -9 punched hole in tbg high water Possible shallow gas 2011-2014 SCU 24A-9 1750220 Se -0 no known damage no flow Possible WO for T onek 2012-2015 SCU 31-8 1810990 Nov -0 no known damage no flow Possible Sidetrack to G-Zone/Hemlock 2012-2015 SCU 312-9 1600280 Nov -0 no known damage cemented drill pipe in well Attempted recom letion to G -Zone - Ops Shutdown Remove due to Ops SD SCU 314-3 1610230 Mar -9 no known damage no flow Possible WO for T onek gas 2011-2014 SCU 3213-9 1002670 Nov -0 no known damage no flow Possible T onek oil 2011-2014 SCU 34-8 1610430 Jan -9 no known damage no flow Possible P&A 2010-2013 SCU 41B-9 1002690 Nov -9 no known damage no flow Possible WO for Tyonek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 44-4 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct4 no known damage high water Possible Beluga gas 2010-2013 SRU 212-27 1610330 Dec -0 no known damage tight sand - no flow Possible other shallow gas 2011-2014 SRU 234-15 1600410 Dec -Ono known damage no flow Possible shallow gas or gas storage 2011-2014 Monopod A-10 1670760 Apr -8 Collapsed casingProducin Coal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 Jun -8 Collapsed casingProducingCoal Phase I Abandon abandon at end of platform life Mono od A-30 1730140 Oct -9 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life f W" i i, 0 ' �U� 2 L i AIALSKA ®IL AND GALS / CONSERVATION CQ)EMUSSION June 22, 2009 - 64A SARAH PALIN, GOVERNOR i' 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276.7542 Dale Haines SWOEV UNOCAL 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: 20 AAC 25.300 (Request for Information) – Status of Oil and Gas Wells Dear Mr. Haines: The records of the Alaska Oil and Gas Conservation Commission (Commission) indicate that the oil and gas wells on the attached list that are operated by UNOCAL have been inactive for five years or longer. If, for any listed well, UNOCAL believes the Commission's information is not correct, by August 3, 2009, please indicate the status of the well—i.e., in production, plugged and abandoned, suspended, converted to a water well, or converted to an injection well—and provide all documentation relevant to the well's correct status. If, for any listed well, UNOCAL agrees that the Commission's information is correct, by August 3, 2009, please identify the plans, including the schedule, to plug and abandon the well, suspend the well, return the well to production, or convert the well to a water well or injection well. This request is made pursuant to 20 AAC 25.300. Responding does not relieve UNOCAL of the obligation to comply with any legal requirements or mean that the Commission will not take any additional action, such as an enforcement action under 20 AAC 25.535. If you have questions regarding this request for information, please contact Mr. Winton Aubert, Senior Reservoir Engineer, at 907-793-1231 or winton.aubertnalaska. ,ov. Sincerely, Cathy . Foerster Commissioner Enclosure Operator Company Permit No. Well Name UNOCAL Union Oil Company of California 168-024 Granite Pt St 17587 5 Union Oil Company of California 194-149 Granite Pt St 18742 03RD Union Oil Company of California 179-033 Granite Pt St 18742 14 Union Oil Company of California 167-077 Granite Pt St 18742 16 Union Oil Company of California 168-012 _ Granite Pt St 18742 18 Union Oil Company of California 100-266 Granite Pt St 31-14RD2 Union Oil Company of California 182-020 Trading Bay Unit D-06RD Union Oil Company of California 169-004 Trading Bay Unit D-18 Union Oil Company of California 188-098 Trading Bay Unit D-30RD2 _ Union Oil Company of California 182-083 Trading Bay Unit D-40RD _ Union Oil Company of California 178-045 Trading Bay Unit G-08RD _ Union Oil Company of California 176-032 _ Trading Bay Unit G-24 _ Union Oil Company of California 179-013 _ Trading Bay Unit D-06RD Union Oil Company of California 188-028 _ Trading Bay Unit G-34RD _ Union Oil Company of California 168-038 Trading Bay Unit K-06RD _ Union Oil Company of California 169-066 _ Trading Bay Unit K-09 Union Oil Company of California 179-016 Trading Bay Unit K-21 RD Union Oil Company of California 178-004 Trading Bay Unit K-23 _ Union Oil Company of California 165-038 _ MGS St 17595 05 Union Oil Company of California 166-003 MGS St 17595 06 Union Oil Company of California 167-017 MGS St 17595 11 _ Union Oil Company of California 167-049 MGS St 17595 13 Union Oil Company of California 176-075 MGS St 17595 18 Union Oil Company of California 185-135 MGS St 17595 20 Union Oil Company of California 183-072 MGS St 17595 25RD Union Oil Company of California 193-119 MGS St 17595 28 Union Oil Company of California 193-118 MGS St 17595 29 Union Oil Company of California 193-120 MGS St 17595 30 Union Oil Company of California 195-199 MGS St 17595 31 Union Oil Company of California 175-007 S MGS Unit 02RD Union Oil Company of California 167-028 S MGS Unit 03 Union Oil Company of California 167-058 S MGS Unit 04 Union Oil Company of California 175-044 _ S MGS Unit 13 Union Oil Company of California 175-066 S MGS Unit 14 Union Oil Company of California 176-045 S MGS Unit 15 Union Oil Company of California 194-057 S MGS Unit 16 Union Oil Company of California 194-056 S MGS Unit 17 Union Oil Company of California 194-098 S MGS Unit 18 Union Oil Company of California 175-057 Soldotna Ck Unit 12A-10 Union Oil Company of California 175-015 Soldotna Ck Unit 13-04 Union Oil Company of California 181-098 Soldotna Ck Unit 13-09 Union Oil Company of California 162-019 Soldotna Ck Unit 21-08 Union Oil Company of California 180-105 Soldotna Ck Unit 21A-04 Union Oil Company of California 185-255 Soldotna Ck Unit 21 B-16 Union Oil Company of California 184-010 Soldotna Ck Unit 23B-03 Union Oil Company of California 175-022 Soldotna Ck Unit 24A-09 Union Oil Company of California 181-099 Soldotna Ck Unit 31-08 Union Oil Company of California 160-028 Soldotna Ck Unit 312-09 Union Oil Company of California 161-023 Soldotna Ck Unit 314-03 Union Oil Company of California 100-267 Soldotna Ck Unit 32B-09 Union Oil Company of California 161-043 Soldotna Ck Unit 34-08 Union Oil Company of California 100-269 Soldotna Ck Unit 41 B-09 Union Oil Company of California 162-031 _ Soldotna Ck Unit 43-09 Union Oil Company of California 174-066 _ Soldotna Ck Unit 44-04 Union Oil Company of California 160-018 _ Swanson Riv Unit 212-10 _ Union Oil Company of California 161-033 Swanson Riv Unit 212-27 Union Oil Company of California 160-041 Swanson Riv Unit 234-15 Union Oil Company of California 167-076 _ Trading Bay St A-10 _ Union Oil Company of California 172-020 _ Trading Bay St A-23DPN _ Union Oil Company of California 173-014 _ Trading Bay St A-30 Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager 9/14/01 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Subsequent Well Work Report; SRU 234-15 Workover Swanson River Field, Alaska Dear Commissioner Heusser: Unocal Alaska Resources hereby submits its subsequent report of wellwork operations for the subject well. Please find enclosed a Report of Sundry Operations (Form 404), a Workover Summary Report and an updated wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 258-3446. Drilling Manager ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: X Alter casing: Repair well: X Other: Install gravel pack 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) UNOCAL Development: X 15' KB feet 3. Address Exploratory: 7. Unit or Property name P.O. Box 196247 Anchorage, Alaska 99519-6247 Stratigraphic: Swanson River Unit Service: 4. Location of well at surface 8. Well number 860' FSL, 2400' FEL, Sec. 15, T8N, R9W, SM SRU #234-15 At top of productive interval 9. Permit number/approval number Same ~r At effective depth Same 50- 133-10142 At total depth 11. Field/Pool Same Swanson R. / Tyonek Gas Sands 12. Present well condition summary Total depth: measured 11,190 feet Plugs (measured) 7,038' (TOC, 37' of cmt on bridge plug) true vertical 11,190 feet Effective depth: measured 7,038 feet Junk (measured) None true vertical 7,038 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 13' 22" From 28' to surface 28' 28' Surface 2863' 11-3/4" From 2846' to surface 2876' 2876' Intermediate Production 11177' 7" 1900 sx in 2 stages 11190' 11190' Liner Perforation depth: measured 6432' - 6442' true vertical 6432' - 6442' Tubing (size, grade, and measured depth) ~ · .~,~ ' :~ ~ ..:;'/~]i' 2-7/8", 6.4# L-80 Tubing to 5763' Packers and SSSV (type and measured depth) Baker Model 'HS' Packer @ 5746' S~'P 2 ,~ ? n.~ 13. Stimulation or cement squeeze summary - ~' u u ! NA ~l~s?.~ Oil ~ O~$ Con~. ~';~ ~ ~ Intervals treated (measured) ,:t,qc~r~;-;.~-~,:, ~ .... ~,, NA Treatment description including volumes used and final pressure NA 14. Representative Daily Averaqe Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 4/01 0 0 0 2200 2200 Subsequent to operation 9/01 0 0 0 50 2000 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: DanWilliamso~ ,~AJ~~j~,~//~ j Title: Drilling Manager Date: ¢/~ Form 10-404 Rev 06/15/88 ORIGINAL SUBMIT IN DUPLICATE ',.~ Unocal Alaska Drilling Workover Summary Report SRU 234-15 61/27/01 to 7/13/01 6/27/01 Accepted H&R Rig #9 at 14:00 hrs. Bleed down annulus and tubing and monitor well. RIH w/slick line to retrieve tbg plug. Sat down 55' high. Ran impression block - indicated sand. 6/28/01 M/U a 2.0" bailer and bail sand in tubing from 5,631' to 5,680' where no more progress could be made. Pump 9.6 ppg brine down 2-7/8" tubing, taking returns out the annulus. Monitor well - static. N/D tree, N/U BOPE. 6/29/01 Finish installing BOPs, modify mud cross orientation. Test BOPE to 250/3000 psi. POH w/1.66" heater string.. 6/30/01 7/1/01 Finish POH w/heater string. Attempt to rotate long string to release from anchor at packer - no good. RIH w/chemical cutter and cut tubing at 5,838', just above packer. POH w/2-7/8" long string and jewelry. Change rams, P/U kelly. Start testing rams and kelly valves. Finish testing BOPE. Repair ram carrier bolts. RIH w/overshot on 3-1/2" drill pipe. Latch tubing stub and rotate anchor loose from packer. Circulate well, POH and L/D fish. M/U packer-milling BHA and RIH. 7/2/01 Finish RIH w/ packer mill. Tag up on packer at 5,639' and commence milling. Circulate out gas. Finish milling packer. Circulate well and chase packer to 6,375' where it sat down solidly. POH w/packer mill. 7/3/01 Finish POH w/packer-milling assy. M/U packer fishing assy and RIH. Latch fish and POH slowly. M/U 6" clean-out bit and 7" csg scraper and RIH to 6,375'. Circ and reduce brine weight to 9.0 ppg. Wash fill from 6,375' to 6,434'. Tag junk. Rotate on junk. 7/4/01 Wash from 6,434' to 6,465'. POH to check bit. segments. M/U milling assy and RIH w/same. 6,719'. Circulate and filter brine. Scraper had lost 4 of six scraper Mill and chase junk from 6,436' to 7/5/01 Finish cleaning pits and filtering brine to 20 NTU. Displace well to filtered 8.8 ppg brine. Attempt to run sump packer on wireline - would not pass perforated interval. Run GR/CCL across perfs and pkr-setting interval. M/U pkr on drill pipe and RIH. 7/6/01 Tie in and set pkr at 6,450'. POH and test BOPE. M/U and RIH w/tubing-conveyed perforating assy and DP. 7/7/01 RIH w/TCP assy. Tag high on sand on pkr. POH w/TCP assy. RIH w/string mill and stinger. Locate on pkr and circulate sand out of wellbore. 7/8/01 Continue to circulate and polish csg w/mill. POH slowly. P/U and RIH w/TCP assy. Tag up on sump pkr and space out. Rig up surface manifolding. 7/9/01 Finish rigging up surface lines. Drop bar, fire guns (re-perf interval 6,432'- 6,442'). Retrieve firing bar w/slickline. POH w/perfing assy - all shots fired. P/U and RIH w/ string mill clean-out assy as above. Tag up on pkr and circ hole clean. POH slowly. 7/10/01 7/11/01 7/12/01 M/U gravel pack assy and RIH w/same. Stab into sump packer and set gravel packing packer. Pickle tubing. Change out choke manifold. Perform circulating and injection test. Pump first stage of gravel pack. Pump second and third gravel pack stages. Screen out OK. Test pack to 1500 psi - calculated sand across all of screen plus 17.6' of blank. R/D Dowell and POH w/ running tool and tail pipe. Run 2-7/8" completion. Circulate inhibited brine into annulus. Set pkr w/ 3500 psi tubing pressure. Test annulus to 1500 psi. L/D drill pipe from derrick. 7/13/01 N/D BOPE, N/U tree and test to 5,000 psi - OK. Release rig at 0600 hrs, 7/13/01. UNOCAL RKB - 16.96, Possible csg damage across perf interval 12 6 7 10 11 13 TOC @ 7,038' WLM DV Tool @ 7,978' SRU 234-15 7-12-01 dwg .,wanson River Well SRU 234-15 Actual Re-Completion 7/12/01 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOI) BTM. 22" _ 28' 11-3/4" 47 8rd 11.00 Surface 2,876' 7" 29 N-80 6.184 Surface 290' 7" 26 N-80 6.276 290' 1,190' 7" 23 N-80 6.366 1,190' 4,890' 7" 26 N-80 6.276 4,890' 6,690' 7" 29 N-80 6.184 6,690' 8,490' 7" 29 P-110 6.184 8,490' 11,190' Tubing 2-7/8" 6.4 L-80 Imp Butt 2.441 15' 5,762' JEWELRY DETAIL NO. Depth ID OD Item 16.96 - Hanger, 9" Shaffer AGO 79L, 2-Yg", Butt Top & Btm 1. 2470' 2.347 5.437 Chemical Injection Mandrel, SF-01 CF 2. 4871' 2.347 4.750 Gas Lift Mandrel, SF-01 3. 5746' 2.441 5.875 Baker Model "HS" Pkr 4. 5757' 2.313 3.187 Nipple, 'X', 2.313 I.D. 5. 5762 2.347 3.5 WLEG MS 6. 6346' 4.00 5.937 Baker Model "SC-l, 70B40 GP Pkr 7. 6351' 4.00 5.75" Gravel Pack Sldg Sire Ext w! 16' Lwr Ext. 8. 6375' 3.50 4.75 Baker KOIV 9. 6377' 4.00 4.625 Baker GPR-24 SOSJ 10. 6380' 3.550 4.0 Blank Pipe, 38' 11. 6417' 3.550 4.590 4"x 12ga Bakerweld 140 Screen, 30' 12. 6448' 3.00 4.875 Baker S-22 SLSA 13. 6450' 4.00 5.75 Baker Model "F-I", 85-40 Sump Pkr. Correlated w/ E/line Abandoned Depth Item 7,075' PosiSet Plug w/37' Dump Bailed Cement Plug 8,148' Retainer 10,200' Tubing Cut, 3-1/2" EUE Tubing 10,615' 2-7/8" x 3-1/2" Crossover 10,620' Tubing Retainer 10,640' Tubing Perf 10,648' Mandrel, Camco "MM" 10,675' Tubing Retainer 10,692' Packer, Baker Mod. "FH" 10,730' Nipple, Otis "S" 10,733' Tubing Perf 10,795' Mandrel, Camco "MM" 10,818' Tubing Retainer 10,840' Nipple, Camco "D" 10,842' Packer, Baker Mod. "F' 10,880' Tubing Tail PERFORATION HISTORY Interval Accum. Date Zone Top Btm ---~k~ ...... ~f-'- Ciimments 7/9/01 61-3A 6,432' 6,442' ____19'- ..... ~__ T_CP_ ...... 1/15/95 68-0 7,120' 7,156' 36' 4 Abandoned 11/27/94 77-3 8,035' 8,063' 28' 4 Squeezed H 10,793' 10,797' 4' Abandoned H 10,802' 10,812' 10' Abandoned H 10,818' 10,837' 19' Abandoned H 10,850' 10,892' 42' Abandoned Total Interval: 808' Total Open: 10 Last Workover = 7/12/01 PBTD = 7,038' WLM, TD = 11,190' PBTD = 7,038' WLM, TD = 11,190' DRAWN BY: slt REVISED: 8/28/01 FW: Swanson Workover Program Subject: FW: Swanson Workover Program Date: Thu, 3 May 2001 08:47:11 -0800 From: "Bill Penrose" <bill~fairweather.com> To: "Tom Maunder \(E-mail\)" <tom_maunder@admin.state.ak,us> Tom, For your information and records: This is the same e-mail I sent you on 511/01 except that I've changed the discussion of BOPE to be used when running rods in the rod pump conversions. Please dispose of that previous message as the BOP discussion was gdeviously in error. Thanks! Bill ---Original Messagem-- From: Bill Penrose [mailto:billL"~.fairweather. com] Sent: Tuesday, May 01, 2001 8:57 AM To: Tom Maunder (E-mail) Subject: RE: Swanson Workover Program Tom, Following each question that you posed is the answer, preceded with an A: One big question. What rig is proposed? A: H&R Rig #9, being imported from Canada. SRU 14-15... -What are the BHPs of the old interval and the new? Unless there is a possibility of a high pressure zone (there are a few out there), 3000 psi sounds appropriate. A: BHP of the old interval is 4,900 psi and will only flow water. The BHP of the new interval is 3,000 psi and is expected to flow gas. The request for testing the BOPs to only 3,000 psi as well as not installing an SSV is an artifact from one of the other programs. Please disregard it. It is our intention to test the BOPs to 5,000 psi. -You request not to have a SSV since the well will not flow unassisted, but this is a gas well. Is the SSV request an artifact from another program? A: Yes, as stated above, the SSV request is an artifact. Please disregard it. -Do you plan to do a casing test in the pre dg work or prior to perfing? A: We will perform a casing test after plugging the presently perforated interval. -How the well will look after workover is not too difficult to imagine, but a drawing will help as I move it up the line. A: I will generate proposal drawings ASAP and get them to you. -What gas rate is expected? Will 2-3/8" tubing limit the production? A: The gas rate is expected to be ~2MMSCFD which will not be limited by the 2-3/8" tubing. 1 of 4 5/3/01 10:05 AM FW: Swanson Workover Program -What zone/sand is the new completion in? A: The Tyonek 62-5 Sand SRU 234-15... -This plan is pretty straight forward. You have the BHP of the intended zone. Am there any others of concern? A: No, we'll just mperf the existing perforeated intervals. -The present packer is a fair distance above the PBTD. Fill is mentioned, has it been tagged? A: No tag run has been made since this interval was perforated. However, the well makes sand so there is probably some amount of fill. -Do you plan to do a casing test in the pre rig wOrk or prior to reperfing and gravel packing? A: No. The perforations am open and the producing pressure will be very Iow. -Although you have larger.tubing planned for this well, will it limit production? A: No. Them will not be enough rate from this well to see the tubing as a limitation. SRU 14A-33... -As ! indicate in my comments...is there any intent or need to clean out the deeper intervals? A: No. We'll just acidize the existing perfs. -You are requesting not to. have a SSV on a gas lifted completion. As noted above, will adding the G perfs make the well capable of flowing? A: No. The BHP in.the G-Zone is 1600 psi and Will not allow the well to flow. -If the request for no SSV is apprOved, is there some shutdown mechanism on the gas lift? A: There am 2. manual valves at the surface for shutting in the gas lift. While discussing this question, the field supervisor and i decided that we are uncomfortable With the possibility of a line leak occudng some time before somebody notices and tums off the gas lift gas supply. We therefore withdraw the request to eliminate the SSV. -What am the BHPs. A: Hemlock BHP = 1500 psi, G Zone BHP = 1600 psi I would appreciate some detailed information regarding the downhole equipment and the surface pumping unit. A: Photos and diagrams attached to this message, i can provide more technical data if you'd like. SCU 33A-8... How high will the tie back be? A: The casing leak is suspected t° be at the port collar at 7,332'. The tie-back linerwill extend up to cover it, making the tie-back ~2500' long. If the leak is found elsewhere, it will effect the length of the liner as the intent is to tie back from the existing TOL to just above the leak. 2 of 4 5/3101 10:05 AM I-W: ~wanson wolxover I.,rogram Will it be fully cemented? A: Yes. BOP and contingencies when using crane? A: We plan to use a 2-ram stack consisting of: Top: 2-7/8", t500 psi WP, 0 - 1-1/2", variable rod rams Btm: 2-1/2", Model LP-15, 0 - 1-1/2", variable rod rams Each well will use both rams while running the rods, with the bottom set being left on the well as a permanent part of the wellhead equipment (i.e., when it's all done, each well will have an LP-15 BOP left on it and the top ram will be left over for future use in running and pulling rods.). is there any iiklihood that the Hemlock could flow after reperfing? A: No, the BHP is only 1500 psi, not enough to lift the oil column. Need BHPs A: BHP = 1500 psi, Will tubing be anchored? A: Yes, see the attached gas anchor schematic. Will gas be produced out of a casing valve? A: Yes. SCU 33-33 Why base oil on this one? ^: Base oil is being used because the G-Zone is very water-sensitive. Any plan to test the casing? A: No, the perforations are open and the producing pressure will be very Iow. SCU 13-34 BHP = 1500 psi. Please call or write with any additional questions or comments. Regards, Bill Name: 1100SIDE&FRTVIEWBELTOUT.jpgt I~ 1100SIDE&FRTVIEWBELTOUT.jp,qEncoding:Type: JPEGbase641mage (image/jpeg) J i Name: 1100SIDE&FRTVlEWBELTOUT.jpgt ~-~ 1100SIDE&FRTVIEWBELTOUT. iD.q Type: JPEG Image (image/jpeg) Encoding: base64 i~ame,ir i 100SIDE~/IEw.Jpg ....... Type: JPEG Image (image/jpeg) l Encoding: base64 3 of 4 513/01 10:05 AM FW: Swanson Workover Program Name: 900FOLDEDSHIPMENT.jpgI ~900FOLDEDSHIPMENT. iD~ Type: Image (image/jpeg) Encoding' base64 I Name: 900WEIGHTBOX.jpg ~'~900WEIGHTBOX.jp.q Type: JPEG Image (image/jpeg) 1 Encoding: base64 SwansonGas Anchor. doc Name: Swanson Gas Anchor. doc Type: WINWORD File (application/msword) Encoding- base64 4 of 4 5/3/01 lO:O5 AM Gas breaking out of production Production Production Production Swanson River "Poor Boy" Gas Anchor Casing 2-7/8" Tubing Rods RXBC Rod Pump Seating Nipple, 2-7/8" Cup Type w/2.280" ID 2-7/8" Ported Sub I 1.660" Dip Tube w/10 rd Box x ½ MS btm 3 jts of 2-7/8" Tail Pipe 2-7/8" Otis "R" type Profile Nipple w/plug, 2.188" ID 2-7/8" Ported Sub [ LocSet Packer w/o Element JPEG image 768x1024 pixels I of 2 513101 10:09 AM SWanson Workover Program I of 2 Subject: Swanson Workover Program Date: Wed, 25 Apr 2001 03:02:30 EDT From: STMaunder@aol.com To: bill@fairweather, com ~' ~ ' · CC: tom_maunder@admin.state.ak.us Bill, Doing a little homework. Funny, the phone doesn't ring near as much here. But the new office doesn't have plumbing problems either. But I digress... I have some questions with regard to the programs. I'll start off with my cryptic diary notes and expand on them. One big question. What rig is proposed? C, j3,~~.~,'~-~ ~ ~ ~ SRU 14-15...(191-237) .... (301-106)...proposal is to clean out the well, abandon the existing perforations and recomplete...request to test BOP to 3000 psi and also not to havea SSV...say that the well won't flOw...plan to recomplete as a gas well...might need proposed drawing -What are the BHPs of the old interval and the new? Unless there is a possibility of a high pressure zone (there are a few out there), 3000 psi sounds appropriate. -You request not to have a SSV since the well will not flow unassisted, but this is a gas well. ts the SSV request an artifact from another program? -DO you plan to do a casing test in the pre rig work or prior to parting? · -How the well will look after workover is not too difficult to imagine, but a drawing will help as I move it up the line. -What gas rate is expected? Will 2-318" tubing limit the production? -What zone/sand is the new completiOn in? ~& Zo~ ~- .~ SRU 234-15...(160-041)...(301-102)... proposaI' is to clean out the well, reperf and gravel pack the interval and run tubing...BHP stated at 2785 psi...request 3000 psi BOP test...need a new drawing...no mention of deleting SSV -This plan is. pretty straight forward. You have the BHP of the intended zone. Are there any others of concern? -The present packer is a fair distance above the pBTD. Fill is mentioned, has it been tagged? -Do you plan to do a casing test in the pre rig work or prior to reperfing and gravel packing? -AlthOugh you have larger tubing planned for this well, will it limit production? SRU 14A-33...(162-017)...(301-103) .... proposal is to cut tubing above top packer and clean out the well, not necessary or possible to clean out deeper...run tubing shallower, acidize the existing perfs and add G zone perfs...this is.an oil.well and presently will not flow unassisted...request is to not have a $SV...how do they propose to Sl...will adding the G perfs make the well flow? -As I indicate in my comments...is there any intent or need to clean out the deeper intervals? -You are requesting not to have a SSV on a gas lifted completion. As noted ~.~_Wt:ll I~iUll VVOI'KUVUI I"-fU(~l'~l~ll above, will adding the G perfs make the well capable of flowing? -If the request for no SSV is approved, is.. there some shutdown mechanism on the gas lift? -What are the BHPs. The proposed red pump wells have similar comments~ I did talk with Steve Tyler regarding this proposal some time ago. I would appreciate some detailed information regarding the doWnhole equipment and the surface pumping unit. I have just copied my notes regarding these wells. I don't think they are too cryptic. If you need further clarification, please call $CU 33A-8...(172-017)...(301-103)...proposal is to clean out the well, repairing a.7-5/8" casing leak by runing a 5" tie back and equipping with a red pump...makes same request to omit SSV...probably more appropriate on this well type...how high will the tie back be?...will .it be fully cemented?...BOP and contingencies when using-crane?...is there any liklihood that the Hemlock could flow after reperfing?...need BHPs...will tubing be anchored?...will gas be produced out of a casing valve? SCU 33-33...(176-056)...(301-105).,.somewhat similar to 33A-8, plan to clean the well out and complete with rod pump...request relief on SSV as before.. . plan to use base oil for workover fluid...no reperf...why base oil on this one?...Hemlock and G zones already open in this well...any plan to test the casing? SCU 13-34...(unsure of permit number)...(301-104)...cleanout and equip with pump...plan to add G zone perfs...similar requests as before...plan to use 6% KCI for fluid Bill, thanks in advance for looking at these comments/questions. Please call to discuss. Tom 2 of 2 4/25101 9:49 AM Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7677 Dan R. Williamson Drilling Manager UNOCAL ) Tuesday, April 17, 2001 '~:~o,~,~'~" c;., .... ',. ?~,.~.,.. MS. Julie Heusser, Commissioner AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Application for Sundry Approval; SRU 234-15 Workover Swanson River Field, Alaska Dear Commissioner Heusser, Unocal Alaska Resources hereby submits an Application for Sundry Approval for its plan to re- complete Well SRU 234-15 in the Swanson River Field on the Kenai Peninsula. SRU 14-15 is a shut-in gas well that produces excessive sand from the 10' perforated interval. The proposed workover will consist of pulling the old completion, cleaning out the fill to PBTD, re- perforating the existing 10' perforated interval, gravel pack!ng the perfs and running a new completion. L.~' Because the reservoir pressure in this well is 2,785 psi, Unocal requests approval to test BOPE to a maximum of 3,000 psi. The anticipated commencement of this workover is approximately May 21. Please find enclosed an Application for Sundry Approval (Form 403), a summary workover procedure and a wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 258- 3446. Dan Willi~m'm~n Drilling Manager Enclosures cc: Bill Penrose · STATE OF ALASKA 2~', ~:'' ~__---,,:/~ ce-¢ , ALASKA OIL AND GAS CONSERVATION COMMISSION ~l~lu' ..~ "' APPLICATION FOR SUNDRY APPROVAL 1. Type 0f Request: [ ] Aband°n [ ] Suspend [ ] Plugging [ '] Time Extension [X] Perforate [ ] Alter Casing [X] Repair Well IX] Pull Tubing [ ] Variance [X] Other* [ ] Cha.nge Approved Program [ ] Operation Shutdown [ ] Re- Enter S, usPended Well I ] Stimulate *Gravel Pack 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) UNOCAL ALASKA RESOURCES [X] Development 15' RKB , [ ] Exploratory ....... 3. Address [ ] Stratigraphic 7. Unit or Property Name 909 W. 9th Avenue, P.O. Box 196247, Anchorage, AK 99519-6247 [ ] Service Swanson River Unit 4. Location of well at surface ' 8. Well Number 860' FSL, 2400' FEL, Sec. 15, TSN, R9W, SM 234-15 At top of productive interval 9. Permit Number Straight Hole 60-41 At effective depth 10. APl Number Straight Hole 50-133-~0'I,6~ I0 t~- At total depth ~ 1. Field and Pool Straight Hole Swanson River: Tyonek Gas Sands 12. Present well condition summary depth: measured 11,190 ~:I~/~ Plugs (measured) 7,038' (TOC, 37' of cmt on brige plug) Total true vertical 11,190 Effective depth: measured 7,038 feet Junk (measured) None true vertical 7,038 feet Casing Length Size Cemented M D TVD Structural N/A Conductor 13' 22" From 28' to surface 28' 28' Surface 2,863' 11-3/4" From 2,876' to surface 2,876' 2,876' Intermediate N/A Production 11,177' 7" 1,900 sx in 2 stages 11,190' 11,190' Liner N/A Perforation depth: measured 6,432'-6,442' , /~/~/~ ~ True vertical 6,432' - 6,442' 41aS/ca 0il ~A?.s Cons. Tubing (size, grade and measured depth) 2-718", L-80 at 5,719' (Also a 1.66" heater stdng to 2,521') . ,ChOrzFe , Packers and SSSV (type and measured depth) 7" Baker Model SB-3 permanent packer at 5,649' 13. Attachments [X] Description of Sumary Proposal [ ] Detailed Operations Program [ ] BOP Sketch 14. Estimated date for commencing operation 15. Status of Well classification as: 5/21/01 16. If proposal was verbally approved [ ] Oil [X] Gas [ ] Suspended Name of approver Date Approved Service i Contact Engineer Name/Number: Bill Penrose, 258-3446 Prepared By Name/Number: Bill Penro S e, 258-3446 17. ' I hereby certify that the fore[ping is true and correct to the best of m.y 'knowledge .... . _ ,,.e ,,.,., - Conditions of Approval: Notify Commission so representative may witness ~q3~ ~)~ ~:~C3~' .k-r~5'~- IApproval No.,_~t- Plug integrity . BOP Test ~{~ Location Clearance Mechanical Integrity Test . Subsequent form required 10- ~4~,-~ / / Approved by order of the Commission ORIGINAL SIGNED BY ....... ~ .~ ~.~ .... Commissioner Date Form 10-403 Rev. 06/15/88 Subm~ cate Unocal Alaska Bus~ness Unit Swanson River Field Well #SRU 234-15 AFE # Prepared by: WJP Date: 3/01 Estimate for Non-drilling AFEs (Cap Recomp, SWR, Abandonment) No'.Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) i Prep Well For Workover Test Wellhead Use Slickline Unit to Pull Dummy Valve from GLM ~ 5,575' Kill Well w/9% KC1 i ' W0rkover . 1 MIRU Workover Rig ~..~. 72 72 3.0 2 Set BPV, N/D Tree, N/U and Test BOPE 15 87 3.6 3 R/U APRS, Cut Tbg ~ 5,620', R/D APRS 4 91 3.8 4 M/U Landing Joint, Pull Tbg Hgr to Floor, Circulat_e Well 3 94 3.9 5 POH, L/D Tbg and Jewelry (Dual: Heater String and Production Tbg) 18 112 4.7 6 P/U 3-1/2" Drill Pil~e w/Overshot, RIH to Tbg Stub 24~ 136 5.7 7 Engage S_mb, Rota___t_e Anchor Off of Pkr, POH 4 140 5.8 8 RIH w/Pkr Mill & PRT on Drill Pipe to Pkr ~ 5,778' 51 145 6.0 9 Mill Pkr and POH 12 157 6.5 10 Run 6" Cleanout Bit and 7" Csg Sgraper to 7,038' PBTD 5 162 6.8 .. 11 Filter Brine for Re-Perfand Gravel Pack, POH 24 186 7.8 12 R/U APRS, Run and Set Sump Pkr ~ 7,000', R/D APRS 4 190 7.9 13 R/U SWS for DP-Conveyed Perforating, RIH (Dry) w/Guns 6 196 8.2 14 Re-PerfInterval 6,432'-6,442'.: POH, R/D SWS 6 202 8.4 15 RIH w/Bit and Scraper to PBTD . 5 207 8.6 16 Re-Filter Brine for Gravei Packing~ POH 12 219 9.1 17 RIH w/Wire-Wrapped Screen and Gravel Packing Tools 12 231 9.6 18 R/U Dowell Pumping Equipmeut, Pump Gravel Pack, R/D Dowell 18 249 10.4 19 M/U and RIH w/2-7/8" Completion to 5,700' 14 263 11.0 20 Land Out, set-Pkr, Pressure Test Completion 4 267 11.1 21 Set BPV, N/D BOPE, N/U Tree, Test Tree 12 279 11.6 22 RDMO Workover Rig 0 279 11.6 IT Subtotal (Days) 11.63 I Loss/Trble Time (11%) 1.28 otal Project Days '~. 12.90 Loss, Trouble, Unplanned is based on 11%. Also, the risged troubled costs were included in the AFE costs. Note: SRU 234-15 AFE Est Page i of i 4/9/0I UNOCAL II I A DV Tool 7,978' B G . RKB = 15' I 2~ E F L M I ~K N 0 Ill SIZE WT Swanson River '~'~Well SRU 234-15 Actual Re-Completion 12/17/98 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 22" 28' 11-3/4" 47 8rd 11.00 Surface 2,876' 7" 29 N-80 6.184 Surface 290' 7" 26 N-80 - 6.276 290' 1,190' 7" 23 N-80 - 6.366 1,190' 4,890' 7" 26 N-80 - 6.276 4,890' 6,690' 7" 29 N-80 - 6.184 6,690' 8,490' 7" 29 P-110 - 6.184 8,490' 11,190' Tubing 2-7/8" 6.4 L-80 . AB Mod.. Butt 2.441 15' 5,720' 1.66" 3.02 - CS Hydril 1.278 15' 2,521' JEWELRY DETAIL ' ..NO. Depth I_D_D OD . !te,m 1 15' - Dual Tubing Hanger, Type 79, 2-7/8" Mandrel, Buttrcs~ Lift and Suspension, Type H BPVP; 1.60" Mandrel, 1- 1/2" 10rd Lift and Suspension, Shaffer BPVP 2 19.31 ? 2.441 2.875 Crossover, 2-7/8" EUE 8rd Pip x Pin 3 27.31 ? 2.441 2.875 Crossover, 2-7/8" EUE 8rd Box x Butt Pin 4 5,575' 2.347 4.703 Mandrel, Camco, 2-7/8" KBMG, l"Dummy, BK-2 5 5,615' 2.313 2.625 Nipple, 'X', 2.313 I.D. 6 5,648' 2.406 4.625 Anchor, Mod. 'K' 7 5,649' 3.250 5.687 Packer, Permanent, Baker Mod. SB-3 8 5,686' 2.313 2.625 Nipple, 'X', 2.313 I.D. 9 5,719' 2.437 3.875 Shear Out Sub,WLEO Abandoned No; Denth Item A 7,075' Posiset Plug wi 37' Dump Bailed Cement Plug B 8,148' Retainer C 10,200' Tubing Cut, 3-1/2" EUE Tubing D 10,615' 2-7/8" x 3-1/2" Crossover E 10,620' Tubing Retainer F l 0,640' Tubing Peri O 1'0,648' Mandrel, Chmco "MM" H 10,675' Tubing Retainer I 10,692' packer, Baker Mod. "FH" J 10,730' Nipple, Offs "S" K 10,733' Tubing Perf L .10,795' Mandrd, Camco "MM" M 10,818' Tubing Retainer N 10,840' Nipple, Camco, "D" 0 10,842' Packer, Baker Mod. "F" P 10,880' Tubing Tail PERFORATION HISTORY iatet~al ' Acco_re. ' ,, Date Zone , 'Top Btm Amt, spf Comments 12/17/98 61-3A 6.432' 6.442' '10' 6 2-1/g" Pl. O den. 1115195 68-0 77120' 7,156' 36' ,4 Abando..n.ed ,., .._11/27/94 ... 77.-3 %035' 8,.06. 3' 28' 4 Squ~zed H 10,793' .10,797' 4' Abandoned H 10,802' ,10,812' !0' Abandoned H 10,818' 10,837' .1..9' Aban. doned · H 10,,850' ,10,892' 42' Abandoned ,. Last Workover = 11/13/94 PBTD = 7,038' WLM, TD = 11,190' PBTD = 7,038' WLM, TD = 11,190' 234-15_12-17-98 Completion DRAWN BY: tcb REVISED: 12/21/98 234-15 10000 1000 100 10 1 0.1 10000 1000 100 10 0.1 0.01 0.001 Cum Oil Prod ( Mbbl ) Cum Gas Prod ( MMcf ) Cum Water Prod ( Mbbl ) Oil Rate (PD) ( bbl/d ) Gas Rate (PD) ( MMcf/d ) Water Rate (PD) ( bbl/d ) Gas / Oil Ratio ( Mcf/bbl ) ~""- STATE OF ALASKA ALASKA OIL/~ND GAS CONSERVATION CO~w'MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: X Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 306' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247, Anchorage, AK 99519 Service: Swanson River Unit 4. Location of well at surface 8. Well number 860' FSL, 2,400' FEL, Sec. 15, TCN, R9W, SM SRU 234-15 At top of productive interval 9. Permit number Same 60-41 At effective depth 10. APl number Same 50- 133-10160-00 At total depth 11. Field/Pool Same Swnason River Field / Tyonek 12. Present well condition summary Total depth: measured 11,190' feet Plugs (measured) 7,516' Cement true vertical 11,190' feet PosiSet Bridge @ 7,075' / Cement @ 7,038' Effective depth: measured 7,038' feet Junk(measured)ORIGINAL true vertical 7,038' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 20" 28' 28' Surface 2,876' 11-3/4" 1,800 sx 2,876' 2,876' Intermediate Production 11,190' 7" 1,900 sx 11,190' 11,190' Liner Scab Liner Perforation depth: measured Open: 6,432'-6,442' Abandoned: 8,035'-8,063'; 10,793'-10,797'; 10,818'-10,837'; 10,802'-10,812'; 10,850'-10,982'; 7,120'-7,156' true vertical Open: 6,432'-6,442' Abandoned: 8,035'-8,063'; 10,793'-10,797'; 10,818'-10,837'; 10,802'-10,812'; 10,850'-10,982'; 7,120'-7,156' Tubing (size, grade, and measured depth) 2-7/8", 6.4#, L-80, Buttress SC @ 5,720'; 1.66", L-80, 2.27#, CS Hyddl @ 2,521' (Heater String) Packers and SSSV (type and measured depth)J J ( FIVED Baker Mod. "SB-3" @ 5,649' 13. Stimulation or cement squeeze summary N/A JAN 20 1999 Intervals treated (measured) N/A~a~b 0il & Gas Cons. Commission Treatment description including volumes used and final pressure Arlchorage N/A 14. Representative Daily Avera.qe Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 250 Subsequent to operation 1/12/98 0 2,998 0 300 2,400 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~/~~i Da~n ~on Title: Drilling Manager Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Work Summary Swanson River Unit, Well 234-15 12/14/98- 12/17/98 DAY 1 (12/14198) MIRU SCHLUMBERGER E-LINE. MU POSISET AND RUNNING TOOL. TEST LUBRICATOR. OK. RIH SET POSISET PLUG AT 7,075' ELM. POOH. RIH W/2-1/8" E-LINE BAILER RUN NO. 1. TAG POSISET PLUG AT 7,075' DUMP. PERFORM 1 ADDITIONAL RUN. (2 RUNS FOR DAY) SHUT DOWN FOR NIGHT. DAY 2 (12115/98) RESUME OPERATIONS. RIH WITH 2-1/8" E-LINE BAILER TO 7,066' (FIRM CEMENT), DUMP BAILER. PERFORM 5 ADDITIONAL RUNS. (6 RUNS FOR DAY, 8 TOTAL) RIG DOWN SCHLUMBERGER. DAY 3 (12117198) PRESSURE TEST PLUG TO 1,800 PSI FOR 15 MIN. (NOTIFIED BLAIR WONDZELL THAT TEST WOULD BE TO 1,800 PSI AS OPPOSED TO 2,500 PSI IN SUNDRY DUE TO CASING AGE, OK.) BLED 110 PSI (6%) IN 30 MIN. TEST O.K. BLEED TUBING TO ZERO. RU SCHLUMBERGER. ARM 10', 2-1/8" POWER JET, 6SPF, 0 DEG PHASED GUNS. PRESSURE TEST LUBRICATOR TO 2,500 PSI. OK. RIH AND TAG CEMENT AT 7,038' FOR A TOTAL PLUG LENGTH OF 37'. PERFORATE TYONEK 61-3A SAND 6,432'-6,442'. POOH. UNABLE TO FLOW WELL DUE TO FROZEN LINE AT TANK SETTING. (1112199) WELL PRODUCTION: 2,998MCF, 2,400PSI FTP, 300PSI CSG, 0 OIL, 0 WATER. ' UNOCAL DV Tool 7,978' A G H I L M J K N 0 234-15 12-17-98 Draw.doc 7,038' ~anson River ,,ell SRU 234-15 Actual Re-Completion 12/17/98 CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 22" - 28' 11-3/4" 47 8rd 11 o00 Surface 2,876' 7" 29 N-80 - 6.184 Surface 290' 7" 26 N-80 - 6.276 290' 1,190' 7" 23 N-80 - 6.366 1,190' 4,890' 7" 26 N-80 - 6.276 4,890' 6,690' 7" 29 N-80 - 6.184 6,690' 8,490' 7" 29 P-110 - 6.184 8,490' 11,190' Tubing 2-7/8" 6.4 L-80 AB Mod. Butt 2.441 15' 5,720' 1.66" 3.02 CS Hydril 1.278 15' 2,521' JEWELRY DETAIL NO. Depth lD OD Item 1 15' Dual Tubing Hanger, Type 79, 2-7/8" Mandrel, Buttres: Lift and Suspension, Type H BPVP; 1.60" Mandrel, 1- 1/2" 10rd Lift and Suspension, Shaffer BPVP 2 19.317 2.441 2.875 Crossover, 2-7/8" EUE 8rd Pip x Pin 3 27.317 2.441 2.875 Crossover, 2-7/8" EUE 8rd Box x Butt Pin 4 5,575' 2.347 4.703 Mandrel, Camco, 2-7/8" KBMG, l"Dummy, BK-2 5 5,615' 2.313 2.625 Nipple, 'X', 2.313 I.D. 6 5,648' 2.406 4.625 Anchor, Mod. 'K' 7 5,649' 3.250 5.687 Packer, Permanent, Baker Mod. SB-3 8 5,686' 2.313 2.625 Nipple, 'X', 2.313 I.D. 9 5,719' 2.437 3.875 Shear Out Sub,WLEG Abandoned NO. Depth Item A 7,075' PosiSet Plug w/37' Dump Bailed Cement Plug B 8,148' Retainer C 10,200' Tubing Cut, 3-1/2" EUE Tubing D 10,615' 2-7/8" x 3-1/2" Crossover E 10,620' Tubing Retainer F 10,640' Tubing Perf G 10,648' Mandrel, Camco "MM" H 10,675' Tubing Retainer I 10,692' Packer, Baker Mod. "FH" J 10,730' Nipple, Otis "S" K 10,733' Tubing Perf L 10,795' Mandrel, Camco "MM" M 10,818' Tubing Retainer N 10,840' Nipple, Camco "D" O 10,842' Packer, Baker Mod. "F" P 10,880' Tubing Tail PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 12/17/98 61-3A 6,432' 6,442' 10' 6 2-1/8" P J, 0 deg. 1/15/95 68-0 7,120' 7,156' 36' 4 Abandoned 11/27/94 77-3 8,035' 8,063' 28' 4 Squeezed H 10,793' 10,797' 4' Abandoned H 10,802' 10,812' 10' Abandoned H 10,818' 10,837' 19' Abandoned H 10,850' 10,892' 42' Last Workover = 11/13/94 PBTD = 7,038' WLM, TD = 11,190' PBTD = 7,038' WLM, TD = 11,190' DRAWN BY: tcb ,JAN 20 1999 Alaska 0il & Gas Cons. Commissior~ Anchorage REVISED: 12/21/98 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: X Time extension: Stimulate: Change approved program: Pul'l tubing: Variance: X Perforate: X Other: 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 306' RKB above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519 Service: Swanson River Unit 4. Location of well at surface 8. Well number 860' FSL, 2,400' FEL, Sec. 15, T8N, RDW, SM SRU 234-15 At top of productive interval 9. Permit number Same 60-41 At effective depth 10. APl number Same 50- 133-10142-00 At total depth 11. Field/Pool Same Swnason River Field / Tyonek 12. Present well condition summary Total depth: measured 11,190' feet Plugs (measured) 7,516' Cement true vertical 11,190' feet Effective depth: measured 7,516' feet Junk (measured) true vertical 7,516' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 20" 28' 28' Surface 2,876' 11-3/4" 1,800 sx 2,876' 2,876' Intermediate Production 11,190' 7" 1,900 sx 11,190' 11,190' Liner Perforation depth: measured Open: 7,120'-7,156' Abandoned: 8,035'-8,063'; 10,793'-10,797'; 10,818'-10,837'; 10,802'-10,812'; 10,850'-10,982' true vertical Open: 7,120'-7,156' Abandoned: 8,035'-8,063'; 10,793'-10,797'; 10,818'-10,837'; 10,802'-10,812'; 10,850'-10,982' Tubing (size, grade, and measured depth) 2-7/8", 6.4#, L-80, Buttress SC @ 5,720'; 1.66", L-80, 2.27#, CS Hydril @ 2,521' (Heater String) Packers and SSSV (type and measured depth) Baker Mod. "SB-3" @ 5,649' 13. Attachements Description summary of proposal: X Detailed operations program: X BOP sketch: . ~ 14. Estimated date for commencing operation 15. Status of well classification as: 16. If proposal well verbally approved: Oi1: Gas: X Suspended: Name of approver Date approved Service: 17' I hereb t~'tifY that~ ~e~,~ ling is true and c°rrect t° the best °f mY kn°wledge' 0RI( INAL Signed.~~ /~[~Williamson F oTl~le(~ oD rMiII~?sgsMi ~ njgesrE O N Ly Date: Conditions of approval: Notify Commission so representa~ve may witnessI ~.--~~~~'IAppr°Val N_o. ~.,~?, ,,.~ /,~ Plug integrity ~./" BOP Test ~ Location clearance _ Mechanical Integrity Test Subsequent form required 10- ~{~ ,,~(~ ~,~g~nai Signed By Approved by order of the Commissioner 0avid W. Johnston Commissioner Date /,~, ' D Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Unocal Alaska Business Unit Swanson River Well No. SRU 234-15 Prepared by: Tim Brandenburg Plug Back and Reperforate UNOCALe No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) Plug Back 1 MIRU Schlumberger E-Line. 4.0 4 0.2 2 Pressure test Lubricator to 4,000psi. 1.0 5 0.2 3 Pick up PosiSet Plug for 7", 29# Casing. 1.0 6 0.3 4 RIH with CCL/PosiSet Plug. 2.0 8 0.3 5 Set Plug at 7,070' MD. 2.0 10 0.4 6 POOH. 0.5 11 0.4 7 MU 2-1/8" Bailer/Mix Cement. 2.0 13 0.5 8 RIH making runs as requires to dump bail 35' of cement. 12.0 25 1.0 9 Allow cement to cure for 24 hours. 24.0 49 2.0 10 Pressure test plug to 2,500 psi. 1.0 50 2.1 11 Perform Wireline Tag prior to perforating. 1.0 51 2.1 Perforate 12 Swab well to achive 300# underbalance. 3.0 54 2.2 13 Perforate Tyonek (61-3A) 6,432'-6,442' 1.0 55 2.3 14 POOH. 1.0 56 2.3 15 Rig Down. 3.0 59 2.4 i Cons. Commissi~r~ An~or~Je 234-15 Reperf Attach.xls Page 1 of 1 11/18/98 DV Tool 7,978' F G H K L M N 7,516' I SIZE WT ~'~, Swanson River Well SRU 234-15 Actual Completion 1/15/95 CASING AND TUBING DETAIL GRADE CONN ID TOP BTM. 22" - - 28' 11-3/4" 47 8rd 11.00 Surface 2,876' 7" 29 N-80 - 6.184 Surface 290' 7" 26 N-80 - 6.276 290' 1,190' 7" 23 N-80 - 6.366 1,190' 4,890' 7" 26 N-80 - 6.276 4,890' 6,690' 7" 29 N-80 6.184 6,690' 8,490' 7" 29 P-110 6.184 8,490' 11,190' Tubing 2-7/8" 6.4 L-80 AB Mod. Butt 2.441 15' 5,720' 1.66" 3.02 CS Hydril 1.278 15' 2,521' JEWELRY DETAIL NO. Depth ID OD Item 1 15' - - Dual Tubing Hanger, Type 79, 2-7/8" Mandrel, Buttres: Lift and Suspension, Type H BPVP; 1.60" Mandrel, 1- 1/2" 10rd Lift and Suspension, Shaffer BPVP 2 19.317 2.441 2.875 Crossover, 2-7/8" EUE 8rd Pip x Pin 3 27.317 2.441 2.875 Crossover, 2-7/8" EUE 8rd Box x Butt Pin 4 5,575' 2.347 4.703 Mandrel, Camco, 2-7/8" KBMG, l"Dummy, BK-2 5 5,615' 2.313 2.625 Nipple, 'X', 2.313 I.D. 6 5,648' 2.406 4.625 Anchor, Mod. 'K' 7 5,649' 3.250 5.687 Packer, Permanent, Baker Mod. SB-3 8 5,686' 2.313 2.625 Nipple, 'X', 2.313 I.D. 9 5,719' 2.437 3.875 Shear Out Sub,WLEG Abandoned NO. Depth Item A 8,148' Retainer B 10,200' Tubing Cut, 3-1/2" EUE Tubing C 10,615' 2-7/8" x 3-1/2" Crossover D 10,620' Tubing Retainer E 10,640' Tubing Perf F 10,648' Mandrel, Camco "MM" G 10,675' Tubing Retainer H 10,692' Packer, Baker Mod. "FH" I 10,730' Nipple, Otis "S" J 10,733' Tubing Perf K 10,795' Mandrel, Camco "MM" L 10,818' Tubing Retainer M 10,840' Nipple, Camco "D" N 10,842' Packer, Baker Mod. "F" O 10,880' Tubing Tail PERFORATION HISTORY Interval Accum. Date Zone Top Btm Amt spf Comments 1/15/95 68-0 7,120' 7,156' 36' 4 1-11/16" Pivot Guns, 22g 11/27/94 77-3 8,035' 8,063' 28' 4 Squeezed H 10,793' 10,797' 4' Abandoned H 10,802' 10,812' 10' Abandoned H 10,818' 10,837' 19' Abandoned H 10,850' 10,892' 42' Abandoned PBTD = 7,516' WLM, TD = 11,190' MAX HOLE ANGLE = Vertical 234-15Draw.doc DRAWN BY: tcb REVISED: 11/11/98 UNOCAL A DV Tool ~ ] 7,978' B C D G H I L M I 7,516' I J K N O Swanson River Well SRU 234-15 Proposed Completion CASING AND TUBING DETAIL SIZE WT GRADE CONN ID TOP BTM. 22" - - 28' 11-3/4" .47 8rd 11.00 Surface 2,876' 7" 29 N-80 - 6.184 Surface 290' 7" 26 N-80 - 6.276 290' 1,190' 7" 23 N-80 - 6.366 1,190' 4,890' 7" 26 N-80 - 6.276 4,890' 6,690' 7" 29 N-80 6.184 6,690' 8,490' 7" 29 P-110 6.184 8,490' 11,190' Tubing 2-7/8" 6.4 L-80 AB Mod. Butt 2.441 15' 5,720' 1.66" 3.02 - CS Hydril 1.278 15' 2,521' JEWELRY DETAIL NO. Depth ID OD Item 1 15' - - Dual Tubing Hanger, Type 79, 2-7/8" Mandrel, Buttres~ Lift and Suspension, Type H BPVP; 1.60" Mandrel, 1- 1/2" 10rd Lift and Suspension, Shaffer BPVP 2 19.317 2.441 2.875 Crossover, 2-7/8" EUE 8rd Pip x Pin 3 27.317 2.441 2.875 Crossover, 2-7/8" EUE 8rd Box x Butt Pin 4 5,575' 2.347 4.703 Mandrel, Camco, 2-7/8" KBMG, l"Dummy, BK-2 5 5,615' 2.313 2.625 Nipple, 'X', 2.313 I.D. 6 5,648' 2.406 4.625 Anchor, Mod. 'K' 7 5,649' 3.250 5.687 Packer, Permanent, Baker Mod. SB-3 8 5,686' 2.313 2.625 Nipple, 'X', 2.313 I.D. 9 5,719' 2.437 3.875 Shear Out Sub,WLEG Abandoned NO. Depth Item A 7,070' PosiSet Plug w/35' Dump Bailed Cement (Proposed) B 8,148' Retainer C 10,200' Tubing Cut, 3-1/2" EUE Tubing D 10,615' 2-7/8" x 3-1/2" Crossover E 10,620' Tubing Retainer F 10,640' Tubing Perf G 10,648' Mandrel, Camco "MM" H 10,675' Tubing Retainer I 10,692' Packer, Baker Mod. "FH" J 10,730' Nipple, Otis "S" K 10,733' Tubing Perf L 10,795' Mandrel, Camco "MM" M 10,818' Tubing Retainer N 10,840' Nipple, Camco "D" O 10,842' Packer, Baker Mod. "F" P 10,880' Tubing Tail PERFORATION HISTORY lnterval Accum. Date Zone Top Btm Amt spf Comments 61-3A 6,432' 6,442' 10' 4 Proposed New 1/15/95 68-0 7,120' 7,156' 36' 4 iPropose Abandon 11/27/94 77-3 8,035' 8,063' 28' 4 Squeezed H 10,793' 10,797' 4' Abandoned H 10,802' 10,812' 10' Abandoned H 10,818' 10,837' 19' Abandoned H 10,850' 10,892' 42' Abandoned PBTD = 7,516' WLM, TD = 11,190' MAX HOLE ANGLE = Vertical 234-15Draw.doc DRAWN BY: tcb REVISED: 11/11/98 ARCO Alaska, Inc. ? Post Office Be'-. 00360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 March 31, 1995 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston, Re: Suspended Well Update ARCO Alaska Inc. ("ARCO") has compiled data pertaining to the 25 suspended wells described in your August 19, 1994, letter. Any additional suspended wells which were discovered during our research are also included in this update. I have attached an update on each well and grouped the wells by geographic area. If you have any questions, please call the ARCO Contact indicated for each geographical area or me at 265-6914. Sincerely, /- /,,.~,..am.es .FI. Wine~ 'Senior Land~,~ JRW:hb Enclosures CC: M. L. Bill L. D. Brown H. R. Engel R. M. Lance T. W. McKay G. K. Phillips M. J. Reisterer ATO 1528 LAO 466 ATO 1918 ATO 1420 ATO 1202 ATO 496 ATO 1439 RECEIVED APR 14 1995 Alaska 0il & Gas Cons. C(~mmisslon Anchora. ',, ARCO Alaska, Inc. is a Subsidiary of Atlanlic Richfield Company ARGO hereby' requests extensions of "suspended" status ior the loll#wing wells. West Mikkelsen State #1, APl # 50-029-20278-00, Permit # 78-0017-0 This well was Certified Capable of Producing in Paying Quantities on February 15, 1979. Hemi Springs State #1, AP! fl 50-029-21056-00, Permit fl 83-0181-0 This well was Certified Capable of Producing in Paying Quantities on June 4, 1984. Birch Hill 22-25, Permit # 65-1 This well was Certified Capable of Producing in Paying Quantities. Falls Creek #1, This well was Certified Capable of Producing in Paying Quantities on February 18, 1944. The following wells are scheduled to be plugged and abandoned: Delta State #1, APl # 50-029-20004-00, Permit # 68-0095-0 Delta State #2, APl # 50-029-20150-00, Permit # 74-0056-0 Put River State 01, APl # 50-029-20017-00, Permit # 69-0036-0 Kavik Unit #3, APl # 50-179-20004-00, Permit # 73-0027-0 ,Highland State #1, APl # 50-029-20199-00, Permit # 76-0017-0 Ravik State #1, AP! # 50-029-20888-00, Permit # 82-0218-0 Sag River State #1, APl # 50-029-20002-00, Permit # ? Nodhwest Eileen State #1, APl # 50.029-20013-00, Permit # ? R££I IVED APR 1 4 1995 Alaska Oil & Gas Cons. C0mmissl0n Anchora. ~ The following well is no longer operated by ARCO: ,¥,~wans0n River Unit #34qS;API # 50-133- ! 0142-00, Permit # ~f004t-0~; and held in abeyance pending a determination to either complete the well as a service or pro- ducible well or to abandon the well; · - STATE OF ALASKA · ALA~' OIL AND GAS CONSERVATION COIV'~'~SION WELL COMPLETioN OR RECOMPLETION .EPORT AND LOG 1. Status of Well Cbum#icatk)n of ~ Well OIL ~-] GAS [~ SUSPENDED0 ABANDONED0 SERVlCEF~ _ 2. Name of Operator 7, Permit Numbe~ UNION OIL COMPANY OF CAMFORNIA (UNOCAL) 60-41 3, Address 8, APl Number P.O. BOX 196247 ANCHORAGE, AK 99519 50-133-10142-00 4. Location of well at surface ~~_. ~ .. 9. Unit or Lease Name 860' FSL, 2400' FEL, SEC. 15, T8N, R9W, SM.r u'~i~$; SWANSON FINER At Top Producing Interval| ~-__jII V{~'~tED " 10. Well Number OLD NAME (SRU 34-15) SAME ;.i~l~~, NEW NAME ($RU 234-15) At Total Depth ~ ~ ~ 11. Field and Pool SAME ~'~ ..... SWANSON RIVER FIELDrrYONEK 5, Elevation in feet (indicate KB, DF, etc,) 16. Lease Designation and Serial No, 306' KBI A-028384 12, Date Spudded 13. DateT. D. Reached 114. Date Comp., Susp. orAband. 115. Water Depth. itoffshore 116. No. of Compietion~ N/A N/A J 11/14/94 N/A Feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set 121. Thickrmaa of Perma~ 11190¥11190' 8143'/8143' lYES ~--~ NO ~I NIA feet MDJ NIA 22. Type Electric or Other Logs Run N/A 23. CASING, ENER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP I BOll'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20' O' 28' 0 11-3/4' O' 2876' 1800 SX 0 7' O' 11,190' 1900 SX 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE I DEPTH SET (MD) I PACKER 8ET (MD) 7120'-7156' MD, BENCH 68-0 4 SPF 2-7/8" 5720' 5649' 7120'-71 56' TVD 1,66" 2521' 8035'-8063' MD PERFS SQUEEZED 26. ACID~ FRACTURE, CEMENT $QUm=Tw~ ETC. 8035'-8063' 7VD DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED 8180'-8182' MD PERFS SQUEEZE[ 8180'-8182' 110 SX ASHGROVE CMT 8180'-8182' 7VD 8035'-8063' 75 SX CLASS G CMT 27 PRODUCTION TEST Date First Production I Method o! Operation (Flowing. gas lift, etc.) I N/A Date of Test Hours Tested PRODUCTION FOr OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 1/26/95 8 TEST PERIOD 0 266 0 N/AI N/A FlowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVrrY-API (corr) Press. 2800 900 24-HOUR RATE 0 1998 0 NIA 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A RECEIVED FEB 1 3 1995 At~st~ u~i & Gas Cons. Commission Anch0ra:? Form 10-407 Submit in duplicate rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS I FORMATION TEST8 NAME i Include intewal tested, pressure clMa. ail fluidll recovered and gnlMty, I ..MEA$. DEPTH TRUE VEIRT. DEPTH IGOR, and time of each phase. NONE RECEIYEI) FEB 1 5 1995 ~u~ uu & Gas oons. ,31. L~T OF ATrACHMENT~ DAILY REPORT~, WEll SCHEMATIC 32. I hereby cerlify Umt Um foregoing i~ b~Je and correct^to Um best o~ my knowledge Signed O. RUSSELL SCHMID NO MANAGER Date 02/07/95 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on ali types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (murdple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate 'none'. SRU 234-15 Spud Jun~ 1961 ACTUAL~COMPLETION Recomplt a 11/14/94 KB. ELEV. 152' KB-- 15' 1-3/4" ~ 2876' 1.25" HXATER STRINO TAIL ~ 2,521' 2-7/8""X" NIPPLE ~ 5,686' PRODUCTION TAIL @5,720. DV 7978' PBTD 8,143' CEMENT RETAINER AT g, 14g' BAKER 'FIE' PACKER. 10,692 wso @ 1o,73o' PERF 10,793'-797' PEltY 10,g02'-g12' PERF 10,gig'-g37' PE3~F 10,g$0'-g92' TOC 11,090' a,,,,oo r, auO'OL~ @ 5,575' sa-3 ~'ACI<~Ra TYONEK ?ERFS 7120'-7156' 3-1/2' ELrE 'I'BG W/AB~ COLLAEI~ TO 10,586' XO 2-7/8" - 3-I/2" E'OE TBO ~ 10,615' TUBINO RETAINER. ~ 10,620' Mid MANDREL 10,648' TBO PERF 10,640'..650' TUBR40 RE'T~ 10,675' TBO PERF 10,733'-744' MM MANDREL 10,795' TBO RETAI~'ER 10,818' CAMCO "IY' PROFILE 10,840' BAKER"F" PROFILE 10,842' TUBXNO TAIL 10,g80' RECEIVE FEB 1 ;5 1995 AlaSk~ .Oil .& Gas Cons. Commission '_Anchora 3415CDG2.DOC 2/3/95 SRU 34-15 10,337' TD DAY 1 (11/03/94) MIRU. ALASKA WELL SERVICE RIG #5. CONDUCT RIG INSPECTION. ACCEPT RIG @ 11:30 HRS. NU BOP. 10,337' TD DAY 2-4 (11/04-06/94) CONT NU BOP. ENGAGE HANGER & WORK TUBING, TUBING NOT FREE. RIH W/UNDERSIZED CUTTER & SET DOWN AT 3931', COULD NOT WORK THROUGH. ATTEMPT (2) 900 GM JUNK SHOTS AT 9982', NO SUCCESS. ATTEMPT CUT AT 4221' W/UNDERSIZED CUTTER, NO SUCCESS. ND BOP. PU HANGER & SET SLIPS BELOW. REMOVE HANGER & SET TUBING ON BOTTOM. NU & TEST BOP. 10,175' TD DAY 5 (11/07/94) CONT NU & TEST BOP, Oi~ RIH & ENGAGE TBG W/LANDING JT. WORK PIPE FREE AT 130,000~. POH LD 10,160' 3-1/2' TBG. 10,175' TD DAY 6 ( 11/08/94) ND BOP. ND 13-5/8" 3M X 7-1/16 5M TBG SPOOL. NU & TEST 13-5/8" 3M X 9" 5M TBG SPOOL. NU & TEST BOP. RIH. PU 3-1/2" DRILL PIPE. 10,212' TD DAY 7 ( 11/09/94) CONT. RIHW/3-1/2' DRILL PIPE. TAGGED TBG CUT AT 10,212' DPM. CIRC HOLE W/11.5 PPG MUD. 10,212' TD DAY 8 (11/10194) LAY DN BHA. RIH WIOEDP 3-1/2" TO 7800'. RU SCHLUM & RIH THRU DP Wl2-1/8" PERF GUN ASSY. PERF CSG AT 8180' & MONITOR WELL. POOH W/WL. RECEIVED FEB ~ ~ 1995 Alaska 0il & Gas C~n_. 8147' PBTD DAY 9-11 (11/11-13/94) RU CIRC LINES. ESTAB INJ RATE OF 1/2 BPM @ 2300 PSI. POOH W/DP. SET EZSV ON WL @ 8148'. TIH W/STINGER ON DRILL PIPE. TAG RETAINER @ 8150' (DPM). EST RATE & PRESSURE ~ 1.5 BPM & 3600 PSI. SQUEEZE PERFS @ 8180' WI100 SX (~ 15.8 PPG. FINAL RATE & PRESS I BPM & 3100 PSI. STING OUT OF RETAINER & REVERSE DRILL PIPE CLEAN. POOH LD DRILL PIPE. RIH W/2-7/8' COMPLETION. TUBING TAIL @ 5716', PACKER @ 5646'. RIH WI1.66' O.D. HEATER STRING W/TAIL @ 2538'. 8147' PBTD DAY 12 (11/14/94) LAND DUAL STRING, DROP BALL & SET PACKER. PRESSURE TUBING TO 3300 PSI. ND BOP. NU & TEST TREE TO 300 PSI/5000 PSI, O1~ BREAK OUT RIG & SET AWAY F/WELLHEAD. WINTERIZE RIG F/STACKOUT ON PAD. RIG RELEASED AT 23:59 HRS 11/14/94. 8147' PBTD WAITING ON FLOWLINE. DAY 12 (11/14/94) PERFORATED 11/27/94. WELL CURRENTLY BEING UNLOADED. (1/06-1/09/95) RU CTU & SUPPORT EQPT. RIH W/1.65" WASH NO77LE ON 1-1/4' COILED TUBING. RIH TO 5000' & STARTED CIRCULATING OUT MUD, LCM AND SAND. WASH F/5000' TO 8133' W/6% KCL SWEEP HOLE W/VISCOUS FLUID. RU NITROGEN SERVICES. UNLOAD WELL W/NITROGEN @ 7900'. UNLOAD 184 BBLS CLEAN FLUID. POH. WELL DIED IN 1 HOUR. SHUT WELL IN. RECOVERED +/- 35 BBLS SAND. RU ADDITIONAL NITROGEN ~ 00:00 HRS (1/10/95). RECEIVED F£1~ 'l 3 1995 Gas Cons. Comalssior~ 8147' PBTD (~/~0/95) RIH DRY W/COILED TUBING. TAG @ 2700'. BEGAN TO JET W/NITROGEN. RIH TO 3500'. CIRCULATING PRESSURE SIGNIFICANTLY INCREASING. POH TO 2800'. SHUT OFF NITROGEN AND POH. WELL SANDED OFF CHOKE AND CUT OUT GAS BUSTER. SHUT DOWN F/REPAIRS. (1/11195) REPAIR GAS BUSTER AND PREPARE FOR RESTART OF OPERATIONS. THAW COIL AND GAS BUSTER. PREPARE TO RIH. (1/12/95) RIH WI1-114" COILED TUBING WASHING @ 1 BPM. CLEAN OUT SAND TO 7500' IN 500' INCREMENTS. SHUT DOWN SEVERAL TIMES TO HAUL CONTAMINATED FLUID. ON ao3-rOM @ o6oo HRS (1/13/95). 7516' PBTD (1/13-15/95)) SPOT 75 SX CLASS "G" & ADDITIVES @ 8100'. POH TO 7500' AND CIRCULATED WELL W/DIESEL HOLDING 650 PSI BACK PRESSURE. POH. FREEZE PROTECT FLOWLINE. CLEAN PITS AND WOC. RIH W/2.0' GAUGE RING AND TAG (~ 7498' (WLM). RD CTU AND SUPPORT EQUIP. RU SCHLUMBERGER AND TEST LUBRICATOR. RUN CCL/GR F/7516' WLM-TUBING TAIL PERFORATE TYONEK F/7120'-7156' W/1-11/16' PIVOT GUN. RECEIVE FEB '1 5 1995 u~l & Gas Cons. Commission Unocal Energy Resourc=, lsion 909 West 9th, P.O. BOX 196247 Anchorage, AK 99519-6247 Telephone (909) 276-7600 Fax (907) 26.3-7828 ', : Debra "i. Clerk ,, . . L : : .:' Childers UNOCAL DATA TRANSMITTAL #6 Larry, Grant:'~;~i~!i: ~i', :': ,'. 3001 Porcupine .~r~Ch0rage,, .AK~~ 99501 ,Alaska Oil & Gas i , , , February 7, 1995 From: Debra Childers 909 W. 9th Avenue Anchorage, AK 99519-6247 U o,,ca, ', ,, ':" ii i ILl I I III I One blueline and sepia of the following Soldotna Creek Unit 41A-8 I. Perforating Record $oldotna Creek Unit 41A-8I Cement Evaluation Log Swanson River Unit 34-15 I.C0mpletion Record j Tapes .a. nd q!sting I RECEIVED F£B 0 7 1995 ~,li~l~ 011 & Gas Cons. Commissl~.n Anchorage Please acknowledge receipt by signing and_p ~uming o_.ne copy of this transmittal or FAX to (907) 263-7828. ~~'"~ idac: STATE OF ALASKA ALA~. ~, OIL AND GAS CONSERVATION COMM~. ,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ _ Alter easing__ Change approved program Suspend __ Operations shutdown __ Re-enter suspended well__ Repair well _ _ Plugging __ Time extension __ Stimulate RE-ENTER Pull tubing Vmiano. Perforate X ot~er X .~WELL 6. Datum elevation (DF or KB) 2. Name of Operator UNION OIL COMPANY OF CAMFORNIA (UNOCAL) 3. Address P.O. BOX 196247 ANCHORAGE, AK 99519 J5. Type of Well: Development X_ Stratigraphle __ Location of well at surface 860' FSL, 2400' FEL, SEC. 15, T8N, R9W, SM At top of productive interval At effective depth ORISINAL At total depth 860' FSL, 2400' FEL, SEC. 15, T8N, R9W, SM 306' KB feet 7. Unit or Property name Swanson River Unit 8. Well number SRU 34-15 9. Permit number-~'~,-~ 1 SA (10-403) 91 - 238 10. APl number 50-133-10142-00 11. Field/Pool Swanson River Field/Tyonek 12. Present well condition summary Total depth: measured true vertical 11,190' feet Plugs (measured) 11,190' feet Effective depth: measured 10,337' feet Junk (measured) true vertical 10,337' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 28' 20' 28' 28' Surface 2876' 11-3/4' 1800 sx 2876' 2876' Intermediate Production 11,190' 7" 1900 sx 11,190' 11,190' Liner Perforation depth: measured 10,850'- 10,982' (Sqzd) 10,802'- 10,812' (Sqzd) RECEIVED true vertical Same Tubing (size, grade, and measured depth) 3-1/2", 9.2#, Surf-10586' $ EP 2 '~ 1994 · 2-7/8', 6.5#, 10586'-10880' 93~aska, 0ii & Gas Cons. Commission Packers and SSSV (type and measured depth) Baker 'F' @ 10935', Baker "FH" @ 106 ' 't~llshora~i9 13. Attachments Description summary of proposal x _ Detailed operations program_ _ BOP sketch x _ 14. Estimated date for commencing operation ASAP I5. 16. If proposal was verbally approved Status of well classification as: Oil__ Gas x_ Name of approver Date approved Service 17. I hereby cer~ t~ the f(~i~ ~te-a[{~reot to the best of my knowledge. Signed G. Russell Schmidt Title Drilling Manager FOR COMMISSION USE ONLY Suspended __ Conditions of approval: NOtify Commission so r~j~presentative may witness Plug Integrity BOP Test "' Location clearance _ Date 09/15/94 Approval No. Mechanical Integrity Test__ S--~bsequent form required 10- _~m 'T Approved by the order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W. Johnston Copy Re[urned Commissioner Date SUBMIT IN TRIPLICATE PROPOSED WORKOVER PROCEDURE SWANSON RIVER UNIT 34-15 1. Prepare location. 2. Move in and rig up workover rig. 3. Install and test BOP and choke manifold to 5,000 psi. . . Rig up wireline and cut tubing at 10.Lq,gl)0'. Circulate well clean. 6. POOH laying down tubing string. . RIH with bit and 7" casing scraper to tubing stub. Circulate well with weighted completion fluid. POOH. 8. Perforate T' casing at 8,080' with 4 JSPF. 9. Run and set 7" retainer on wireline at 8,050'. 10. RIH and sting into retainer. Cement squeeze 7" annulus. POOH. 11. RIH and drill out retainer and clean out to 10,200'. 12. POOH laying down 3-1/2" workstring. 13. RIH with completion. 14. Remove BOP and install and test tree TO 5,000 PSI. Rig down and move out workover rig. 15. Install production lines. 16. 17. Achieve draw down and wireline perforate Tyonek. Change over annulus to propelyne glycol and install heater equipment. RECEIVED SEP 2 1 1994 Ataska Oil & Gas Cons. Commission Anchorage SRU 34-15 Current Status Spud June 1961 22'@28' DV 1359' 11-314' @ 2876' DV 7978' TOC @ 11,090' 7' @ 11,190' 'ID @ 11,190' VVSO @ 10,730' Pelf 10,793-797' Pelf 10,802-812' Perf 10,818-837' Pelf 10,850-892' K~ elev. 152' KB = 15' Tubing cut 10,200' 3-1/2" EUE tbg w/ABC collam to 10,586' XO 2-7/8" - 3-1/2" EUE tbg @ 10,615' Tubing retairmr 10,620' MM mandrel 10,648' 'rbg pelf 10,640.6S0' Tubing retainer 10,675' Baker 'FI-I' packer 10,692' OTIS 'S' profile p~oition ~3 10,730' Tbg pelf 10,733'-744' MM mandrel 10,795' Tubing retainer 10,818' Camco "D' pmfll® 10,840' Baker "P profile at 10,842' RECEIVED Tubing tall 10,880' SEP 2 1 1994 Alaska Oil & Gas Cons. Commission Anchorage GRB 9-g-94 SRU 34-15 Proposed Spud June 1961 22'@28' DV 1359' 11-3/4" @ 2876' DV 7978' TOC @ 11,090' 7' @ 11,190' TD @ 11,190' WSO @ 10,730' Peff 10,793-797' Perf 10,802-812' Perf 10,818-837' Perf 10,850-892' KB elev. 152' , KB-- 15' Annulus to be filled with propelene glycol 2-3/8' heater string tail at 2000' Packer at 2100' Packer at 6100' 2-7/8" production string tail at 6200' Potential perioratiorm as high as 6262' Proposed Tyonek 77-3 perl"s 8035'-83' Proposed cement equseze at 8080' Tubing cut 10,200' 3-1/2' EUE tbg w/ABC co#ara to 10,586' XO 2-718' -3-1/2' EUE tbg @ 10,815' Tubing ratairmr 10,620' MM mandrel 10,648' Tubing retainer 10,675' Baker "FH" packer 10,692' OTIS "S" proale posaion d~3 10,730' Tbg perf 10,733'-744' MM mandrel 10,795' Tubing retainer 10,818' Camco "D' proale 10,840' Baker 'F' prof~ at 10,842' Tubing tail 10,880' RECEIVEI SEP 2 1 1994 Ai~sk~ 0il & Gas Cons. Commission Anchor~e GRB 9-12.94 FILL UP LINE ANNULAR BOP 11" 3,500 psi FLOW LINE KILL LINE 3" 5,000 psi PIPE RAMS 11" 5,000 psi BLIND RAMS 11" 5,000 psi DRILLING SPOOL 11" 5,000 psi 'fl CHOKE LINE HCR 3" 5,000 psi PIPE RAMS 11" 5,000 psi BOP STACK 11" 5,000 psi RECEIVED SEP 2 7 1994 Alaska Oil & Gas Cons. Commission Anchor~ LU 0 0 0 uo!;i!mmoo 'suo,9 ~;e~ ~,. I!0 ~seiV ~l L ~ cl35 I I I #000'~ ,,~; #000'~ ,,g -frO00' ~ ,,~ 0 0 0 0 0 0 #000'~ ,,g 2" 5,000# 0 0 0 ~ ALASKA OIL AND GAS · CONSERVATION COMMISSION · WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 19, 1994 David Sutter, Land Manager /LRCO Alaska Inc. ? O Box 100360 Anchorage, AK 99510-0360 Re: Suspended Wells Compliance with regulations Dear Mr. Sutter: ARCO Alaska Inc. has 25 suspended Wells as shown on the attached lists: ARCO SUSPENDED. WELLS PRIOR TO 1980 and ARCO SUSPENDED WELL SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 sUsPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have· future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above or advise as to yoUr plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as required by 20 AAC 25.110(e), must have well site inspections this year prior to snow covering the locations. Chairman encls c: Blair Wondzell bew/llarsusp ARCO SUSPENDED WELLs SINCE 1980 AS OF AUGUST 1994 PW. RMIT 6D- 0041- 0 82 -0038-0 82-0218-0 83 - 0181 - 0 84 -0156-0 84 -0205-0 86-0056-0 89 -0013-0 89 -0041-0 90 -0036-0 91 -0069-0 92 -0065-0 93 -0174-0 93 -0179-0 94-0043-0 API NUMBER 133-10142-00 029-20727-00 029-20888-00 029-21056-00 029-21181-00 029-21221-00 029-20138-01 029-21912-00 029-21937-00 029-22027-00 029-22173-00 029-22261-01 029-22419-00 029-22423-00 029-20614-01 WELL WELL WELL NA~IV/E CLASS STATUS _~.~SON RIV U2qIT 34-15'~ DEV SUSP KUPARUK RIV %TNIT 1M-05 DEV SUSP ~AVIK ST 1 EXP SUSP HEMI SPRINGS ST i EXP SUSP PRUDHOE BAY UNIT DS18-il DEV SUSP PRUDHOE BAY UNIT DSl1-15 DEV SUSP W BEAC~{ ST 1-A SER SUSP PT MCINTYRE P1-03 EXP SUSP PT MCINTYRE P3-01 DEV SUSP ~PARUK RIV~IT 1L-20 DEV SUSP ~PARUK RIV ~IT 1L-26 DEV SUSP PT MCINTYRE P2-504 DEV SUSP KUP~UK Rmv ~IT 2E-17 DEV SUSP ~PARUK RIV ~IT 2E-05 DEV SUSP PR~HOE BAY ~IT DS12-134 DEV SUSP STATUS DATE 8/21/91 5/18/82 4/03/83 4/03/84 9/17/84 2/14/91 5/06/86 4/26/89 7/03/89 3/3m/91 6/09/91 8/30/92 4/25/94 4/25/94 4/03/94 SECT 15 33 32 12 19 33 25 16 22 29 32 14 36 36 18 TWP 08N 12N 091~ 10N 11N 11N 12N 12N 12N 11N 11N 12N 11N 11N 10N R/qG 009W 010E 009E 011E 015E 015E 014E O14E O14E 010E 010E 014E 009E 009E 015E MER S U U U U U U U U U U U U U U ARCO SUSPENDED WELLS PRIOR TO 1980 AS OF AUGUST 1994 PE~IT 00-0242-0 68-0095-0 69-0036-0 73-0027-0 74-0056-0 74-0057-0 76-0013-0 76-0017-0 76-0034-0 78-0017-0 API NUMBER 029-21821-00 029-20006-00 029-20017-00 179-20004-00 029-20150-00 029-20151-00 029-20195-00 029-20199-00 029-20205-00 029-20278-00 WELL WELL WELL NAME CLASS STATUS PRUDHOE BAY UNIT OWDW-C SER SUSP DELTA ST I EXP SUSP PUT R~V ST I EXP SUSP KAVIK U~IT 3 DEV SUSP DELTA ST 2 EXP SUSP GULL IS ST I EXP SUSP GULL ISST 2 EXP SUSP HIGHLAi~D ST I DEV SUSP W BEACH ST 3 EXP SUSP W MIKKELSEN ST I EXP SUSP STATUS DATE 6/23/73 2/27/69 7/01/69 5/02/74 5/17/75 4/01/76 4/22/77 4/12/76 7/26/76 ll/ll/TS SECT 11 10 07 08 35 28 28 24 25 32 TWP 10N 10N 1 ON 03N 11N 12N 121~ 11N 12N 101~ P~NG 014E 016E 014E 023E 016E 015E 015E 011E 014E 019E MER U U U U U U U U U U Uneeal North Am~"'~ Oil & Gas Division Unocal Corporation "' 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region March 31, 1994 Re: Mr. Joseph A. Dygas -.- Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 1994 Sundry Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1994 to March 31, 1995. Two information sheets are attached with this Sundry Notice request. Attachment I lists the proposed TA wells using the same-format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field biowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned List. Three wells SCU 24A-9, SCU 33-5, and SCU 21-3 were removed from the list while two wells SFIU 12-15 and SRU 21- 33WD were added to the list. RECEIVED APR - 1 1994 ~ask~ Oil & Gas Cons. Commission Anchorage Mr. Joseph A. Dygas March 31, 1994 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. DLG:dma 'Yours very truly, Dennis L. .ske Petroleum Engineer Attachment CC: L. R. Dartez, Marathon Oil Company D. W. Johnston, Chairman, AOGCC Form 3160- 5 (JUNE 1990) UNITL ,~TES DEPARTMENT OF THE INTERIOR .BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reenlnj to a different reservoir. Use 'APPMCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLICATE 1. Type of Well Oil Gas [] Well [] Well [-] Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or 'Survey Description) Swan River Unit --- 19 wells Soldotna Creek Unit --- 11 wells FOFIM APPROVED Budget Bureau No. 1004-0135 Ex#rea: Mm, eh 31~ 1993 5. Lease Deelgnation and Serial No. 6. If Indian, Allottee or Tribe Name · , · o, 7. If Unit or CA, Agreement Deeignation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Reid and Pool, or Exploratory Area Swanson River Field 11. County or Parbh, State Kenal, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent !-'1 Subsequent Repo~ Final Abandonment r"l Abandonment E] Recompletion I-'] 1--] Plugging Back r"l I-i Casing Repair 1-] I-'] Altering Casing ~ Other Temporarily Abandon Change of Plans New Construction Non-Routine Fracturing Water Shut-Off Conversion to Injection Dispose Water (Note: Flelxxt requite oi' mulUple ~onmpletfoa oa W~ 13. ~ ~ ~~ o~ (c~ s~ ~~b,~ ~~~, ~u~ ~ ~~g~~ ~ As described in attached letter, Unocal requests that the folbwing wells have a temporarily abandoned status for the twelve month period, April 1994 to March 31, 1995: Soldotna Creek Unit '~ !' * SCU 23B-3 SCU 243-8 ~ I SCU 13-4 SCU 341-8 <J I * SCU 21A-4 SCU 13-9 ~l SCU 34-4 * SCU 34-9 5' I * SCU 43A-4 SCU 14-34 / -.o/Z..* SCU 21-8 *High GOR wells that may be produced Intermittently. Swanson River Unit ~ SRU 212-10 ./-"SRU 14-22 $ I SRU 43-28 SRU 12-15 I 14A-33 5usF 14-15 ~/-~l~oRU S 8RU 5~ SRU 23-15 al SRU 23-22~;uSpSRU 24-33 ~u~I~SRU 34-15 ~1 SRU 23-27.. ~ SRU 32-33WD % 1. SRU 41A-151r~I~SRU 212-27 SRU 21-33WD ~as~ SRU 43A-15G~ SRU 331-27 ~ U..~0 SRU 432-15 ~ ~ SRU 34-28 Conditions of approval, if any: RECEIVED APR - 1 1994 T'~e 18 U.$.C. Section 1001, makes ira crime for any person knowingly and willfully to make to any deparl3nent or agency o~ the United ~a/~§~[fa~,~ll$' C0mmissi0r frauduler~ statements or representations as to any melter within ils jurbc~tion. *See Instruction on Reverse Side Anchorage Attachment No, I Swanson River Field Proposed Temporarily Abandoned Wells: Total 30 Wells Twelve Month Period: April 1, 1994 to March 31, 1995 Shut-in Wells under Evaluation for Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A "/5-t5 SCU 13-4 u~-- t~ SRU 212-10 /.~-~SCU 34-4 L~[-o5 SRU 23-15 ~-'~.,SCU 341-8 u~.-5o SRU 41A-15 (~;~-'7 SRU 34-28 ez,-5~{ SRU 14-22 ~t-~ SRU 43-28 ~-t~SRU 23-22 ~o~'t~r> SRU 32-33WD al-55SRU 212-27 (~%--b~ SCU 243-8 ~o-~ SRU 331-27 (07_-Z SRU 21-33WDa0-ZZ. SRU 12-15 Ioo-~&SCU 14-34 ~0-qc/SRU 23-27 SRU 14A-33 Shut-in Wells during Field Blowdown Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned SCU 21-8' ~l~t~ SRU 14-15 SCU 13-9 (t0-u~[ SRU 34-15 SCU 34-9' SRU 43A-15 SCU 23B-3' %5-bb SRU 432-15 SCU 43A-4' -~_-o-~SRU 24-33 SCU 21A-4' 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells *High GOR wells that may be produced intermittently RECEIVED Alaska Oil & Gas Cons. Commission Anchorage .o Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change Additions to 1994 Temporarily Abandoned Status · SCU 12-15' Shut-in gas lift producer with casing communication, Evaluate for repair or abandonment. · SCU 21-33WD' Shut-in due to wireline fish in tubing. Workover candidate. Removed from 1994 Temporarily Abandoned Status · SRU 24A-9: · SRU 21-3: · SRU 33-5' Returned to full time production after workover. Returned to full time production due commencement of Biowdown in field. Returned to full time production after workover. to RECEIVED a, PR - 1 1994 Gas Cons. Commission Anchorage Alaska Region Oil & Gas Division ~-'% Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 ?OMM_ ~N~SST I ~o,'~' l March 24, 1993 ~ILE Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1993 Sundry Notice Request for TA Wells in S,wanson R.,iver"Fielct Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon ('i'A) 31 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1993 to March 31, 1994. These concurrent time periods will greatly simplify future TA Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells using the same format as submitted last year by ARCO. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field blowdown. Attachment 2 gives a brief explanation for each well that has been added or removed from the proposed Temporarily Abandoned Ust. Two wells, SCU 243-8 and SCU 21-8 were added to the list while three wells, SRU 21-22, SRU 12A-14 and SRU 211-15 were removed from the list. RECEIV'ED MAR 2 5 1995 Alaska 0il & Gas Cons. 60mm~s¢O~ Anchorage Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. Yours very truly, Petroleum Engineer DLG:sr Attachment cc: L.C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company RECEIVED' MAR 2 § 199,~ Alaska 0il & Gas Cons. Comrnissto~ ;Anchorage Form 3 I (June 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals FOR~ APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1~3 5. l.,earm Designation and Serial No. 6. If Indian, Allotlee or Tribe Name SUBMIT IN TRIPLICATE I. Type of Well IX']Oil G~ Well r'Xl F"'l Other Well 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone No. P. O. Box 196247, Anchoraqe, Alaska 99519 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) (907) 276-7600 Swanson River Unit Soldotna Creek Unit .......... 17 wells 14 wells 12. TYPE OF SUBMISSION TYPE OF ACTION 7. If Unit or CA, Agrr~mcnt Designation Swanson River/ Soldotna Creek Units 8. We. Il Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field I1. Count~ or Parish, State Kenai ~ Alaska CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA -X] Notice of Intent [--] Sub~uent Report --]Final Abandonment Notice [-=l Abandonment --"] Recomplction "-]Hugging Back -"]Casing Repair [-~ Altering Casing [~] Omer Temporari 1 y Abandon -"] Change of Plans O New Construction --]Non-Routine Fracturing F"I Water Shut-Off O Conversion to Injection "-]Dispose Water (Note: Report r~suh$ of multiple complction on Well Completion or Re,completion Report and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is dircctionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1, 1993 to March 31, 1994' Swanson River Unit / OR SCU 21-3 SCU 21-8*/ SRU 212-10 SCU 23B-3t~ SCU 243-8~ SRU 14-15' SCU 13-4 ~ SCU 341-8' SRU 23-15/ SCU 21A-4 SCU 13-9/ SRU:34-15: SCU 34-4 J SCU 24A-9~ SRU 41A-15¢ SCU 43A-4 SCU 34-9'~ SRU 43A-15 SCU 33-5¢' SCU 14-34L.-' SRU 432-15 SRU 14-22~ * High GOR wells that may be produced intermittently. Signed ~/V~/'/{/~X~~,, · Title Petroleum Enoineer ~ ~ for F~ or Swanson River Unit SRU 23-22~'' SRU 23-27 ~ SRU 212-27~' SRU 331-27 SRU 34-28v SRU 43-28 ~ RECEIVED SRU 24-33~ SRU 32-33WD~ MAR t 5 199 Alaska 0il& Gas Cons. Comd~SS~°r Anchorago Date · · Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 31 Wells Twelve Month Period: April 1, 1993 to March 31, '1994 Shut.in Wells under Evaluation for Shut-in Wells until the Field Blowdown Rate Potential P & A~ Shallow Gas Potential and 'Hemlock Only' P & A Hemlock Producers Future Shallow Gas Producer with the Hemlock Abandoned SCU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-5 SRU 341-8 SRU 34-28 SRU 43-28 SCU 32-33WD SCU 243-8 SCU 21-3 SRU 212-10 SRU 23-15 SRU 41A-15 SRU 14-22 SRU 23-22 SRU 212-27 SRU 331-27 SCU 14-34 SRU 23-27 SRU 14A-33 11 Wells 7 Wells 3 Wells 5 Wells SCU 21-8" SCU 13-9 SCU 24A-9 SCU 34-9" SCU 23B-3" SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 SRU 24-33~2~ 5 Wells '~ Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 c2~ Scheduled 'Hemlock Only' P & A in March-April, 1993. · High GOR wells that may be produced intermittently. RECEIVED Alaska Oil & Gas Cons. Commission ~nch0mge Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1992's TA Status - December 27, 1991) Additions to 1993 Temporarily Abandoned Status · SCU 243-8: Shallow gas producer (Tyonek). Shut-in due to mechanical problems. Workover candidate. · SCU 21-3: Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Temporarily Abandoned Status · SRU 21-22: · SRU 12A-4: Returned to production after flowline repair. Returned to full time production in 1992. · SRU 211-15 Scheduled for full P & A March-April, 1993. Waiting on personnel and rig. RECEIVED MAR ~ ,5 199;~ Alaska 0il & Gas Cons. oommiss~O" Anchorage ORIGINAL ~'"~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well GAS ~1 SUSPENDED ~l~.¢~t.~ ABANDONED [] SERVICE r-'l OIL r-'] Classification of Service Well 2 Name of Operator ARCO Alaska, Inc 3 Address P.O. Box 100360, Anchorage, AK 99510-0360 4 Location of well at surface 860' FSL, 2400' FEL, SEC 15, T8N, Rgw, SM At Top Producing Interval At Total Depth 860' FSL, 2400' FEL, SEC 15, T8N, Rgw, SM 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 306' KB 12 Date Spudded 13 Date T.D. Reached 17 Total Depth (MD+TVD) 11,190' MD, 11,190' TVD 18 Plug Back Depth (MD+TVD) 10,337'MD, 10,337' TVD A-028384 14 Date Comp., Susp. o~ Aband. I 08/21/91. 19 Directional Survey 20 7 Permit Number SA(10-403) 01-238 (13 0" O 4 I 8 APl Number 50-133-10142-00 9 Unit or Lease Name SWANSON RIVER UNIT 10 Well Number SRU 34-15 11 Field and Pool SWANSON RIVER FIELD HEMLOCK OIL POOL 15 Water Depth, if offshore NA feet MSL116 No. of Completia Depth where SSSV set I 21 Thickness of permafrosl NA feet MDI NA 22 Type Electric or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD CASING SIZE 22" 11-3/4" 7" WT, PER FT. 24 Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) SETTING DEPTH MD BOTTOM TOP HOLE SIZE CEMENTING RECORD AMOUNT PULLED SURF 28' SURF 2,876' SURF 11,190' 25 TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDI 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Flow Tubing Press. Ho~rs Tested ~asing Pressure IPRODUCTION FOR TEST PERIOD CALCULATED 24-HOUR RATE OIL-BBL OIL-BBL GAS-MCF GAS-MCF WATER-BBL WATER-BBL iCHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-APl (corr) 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. MAR 1 6 1992 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 31. LIST OF ATTACHMENTS REPORT OF DAILY OPERATIONS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ___j~_~____~__~. Title AREA DRIllING ENG~IEER Date _'.~7~~ ~-- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), "so state' in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21'~- Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. SRU 34-15 (P & A SUMMARY OF Lease Designation/Serial No. oPERATIONS) A.028584 os/ta/gt , beat down to 7200'i aT00- hfs ---~ttne @ 6856.'k ooo, POH, ran 2.00~ ' - .......ge, hit asp~,~__,, .... ge to io,o?~, ._ ~n 882', ran 2 2~ _g~'Z~ 1 ,-Jo g~ ,tcner w .v, 0 dead, ran - 2, POH, ran · - ' ran scra ' ran 2.0 MiRU-well..n,, ~au~e to 10,_8_8, .~., down W 800~0L~, aown to 10,882, __ ~. cut pOH, ran · --~ttne ~ 720 -, _-~-~atcher x -~-, -an 2.10 ~au~e, ~ ~ ~,~a~-10,~ - -~tcher to ~-~=, ran samP ~. o I kU,wv COUkU ~' auge & cut ,/ n scratcher g --, ~000, ra --.~, fl~ do~. --- & do CTU f/720o ? ---al~es f/B~v' ~ ,- wt~roducuu'' recovered asp~,~ .... nreSS, ~11 COnSUlt Do not appear to be ~ng cleanout tomo~OW- ' , xylene tn 10 bbl s 8570, pumP 0 de ees F 0700 hr ol~d @ @ 20 gr & tag s bi, umP w o en t Rift oral 45 b P H RIH / P _ ~.., ,,ressure tes., . = on minutes, t __,. ~own hole, PO .,_~ +~ surface, .U ~ l u, ~ SOaK ~o--,-- or Wa~ "~ il lug ',-',' MIR low to ot make H draggt g P fi well, tncremen_~ & aI 1 BPM, _c. oul,d n rid e-sticky,. PO~ ~c~8', POH & rig o hot lease .wat_~ RIH to 8200' ?,goob~9.' i'o hard, tag' '~'~- ended m__u~e ~"';~l'~and bridges RIIt, wash sere secure well. 08116191 o7oo-,ooo ~g up ~c~c Recoil pump & ~e ' 0 pst-g~d test. ~R W/ 1/2 BPM ~ 800 psi & 1 BPM O.E. coil tbg-sat do~ ~ 8740'. 1000- l 130 Wash thru bridge f/ 8740' to 8750', RIH to 8886', cftc @ 1-l/4 BPM @ 4000 pst. 1130-1600 ' tn GLM ~ 10,795' 10,700 & set u 1600-1700 Attempt to work thru GLM-no results. 9565', 9600', 10,200', 10,625', RECEIVED MAR 1 6 1992 AJaska OJ{ & Gas Cons. Oommissior' Anchorage 700-1900 SRU 34-. (P & A) Page 2 Summary of Operations POH, remove inJecWr head & close wen tn until a.m. 0/t/17/91 0700-2000 hrs Rig up Precision Wireltne, RIH w/ 2" OD GR, stopped @ 10,839', unable to make hole., POH w/2" GR, make up 1-3/4' GR, RIH w/ 1-3/4' GR-stopped ~ 10,839', POH, rig down WL, rig up Arctic Coil tbg, RIH w/gas lift mand by pass tool on 1- 1/2" coil tbg, wash down f/10,897' to 11,066 coil tbg measure f/ tbg head, circ btms up-than pump drlg mud sweep(56 bbls) to clean hole, POH w/ coil tbg. Rig down coil tbg, secure well. 0~/18/91 0700-0900 hrs Rig up Atlas Wireline Service, run 2,250 O.D. collar Loc. & gauge ring to 10,840'- no restrictions. POH, make up & run 2-7/8" Baker cmt retainer, locate pkrs, glms, ect.-set retainer @10,818', POH, Rig up Arctic recoil, RIH w/cmt ret. stinger to 10,786'-break circ. w/ Haliburton-RIH to 10,893' coil tbg measure(10,818' WLM set by original tbg string), circ rate & psi= 3800 ~ 1 bpm, break formation down w/4 bbls lease water @ I BPM rate @ 3800 psi, pull out of retainer, Haliburton batch mixed 104 ft3(18-1/2 bbls 15.9 slurry)class G cmt w/ additives .2% CFR-3 + .35% Halad 344 & .2% Hr 5, displaced thru cmt retainer ~ 10,818' w/23 bbls lease water(C.?. Vol), Pull out of retainer C.I.P. 3:45 p.m. 8- 17-91. Disp press 3/4 BPM ~ 4250 psi-after cmt @ perfs 3/4 BPM @ 4500 psi, POH w/ coil tbg, rig down, rig up Atlas Wireline Service, RIH w/ 3-1/8' carrier w/ 4 spf & perf f/ 10,733'-10,744', POH, all shots fired, make up 2-7/8' Baker cmt retainer, RIH, loc glm & pkr, set retainer @ 10,675, POH, rig down & secure well. 08/19/91 0700-0900 hrs Rig up coil tbg unit, RIH w/ Baker cmt retainer stinger to 10,650' CTU measurement, rig Haliburton, break circ rate I BPM ~ 3250 psi, sting into retainer, break form down @ 1/2 BPM @ 4900 psi, pumped 5 bbls ,batch mix 60 ft3 cla~ G cmt w/2% CFR-3 + .35% Halad 344 + .2% HR-5(52 ax) mixed @ 15.9 ppg, p, mp cmt into coil tbg + 3 bbls H20, sting into retainer & displace cmt below retainer w/ total of 23 bbls H20-before stinging into retainer, press was 4500 psi @ 1/2 BPM, after stinging into retainer, press increase to 5,000 psi @ 1/2 BPM-flow cont on 1-1/2 x 3-1/2 ann, close ann tn & continue pumping, did not get press increase on 3-1/2 x 1-1/2" ann, but did get 350 psi increase on 3- 1/2' x 7" ann indicating top tbg pkr failed, cont disp cmt, final disp press 4900 psi @ 1/2 BPM, PO retainer, circ btms up, POH w/ coil tbg(no cmt returns) Rig down & secure well. RECEIVED MAR 1 6 199~ Alaska Oil & Gas Cons. Commission ~'-"--, SRU 34-: ~P & A) Page 3 Summary of Operations 0830-2300 hrs RU Arctic Recoil, RIH w/ 1-1/2" coil tbg, tag down 11' high 0 10,639' CT mea, RU Haliburton, pump down coil tbg, determined setting on cmt, POH w/ coiled tbg, RU Arias Wireline Ser., nm temp survey, log f/ 10,300' to tag 0 10,665' WLM corrected to tbg string-log showed steady increase in temp, but no indication of cmt behind 3-1/2" tbg, POH, lay down tools, RIH w/ 2-1/8" carrier-4 spf & perf tbg f/ 10,640'-10,650', POH, RU Haliburton to tbg, bleed 500 psi off ann & pump down tbg, disp 70 bbls crude out ann, no restrictions, RD Haliburton, pick up 2- 7/8" cmt retainer, RIH & set @ 10,620', POH & rig down Atlas, RU Arctic Recoil, RIH w/ Baker stinger, sting into pkr & circ thru cmt retainer & holes in tbg & out 3-1/2"x T' ann, batch mix $0 frs net class G cmt w/.2% CFR-3 +.35% Haiad 344 +.2% HR-5, 26 sx(5.34 bbls) net, 15.8 ppg slurry disp 4 bbls thru retainer & thru perfs & up 3-1/2" · 7~ ann, hold 500 psi on ann during displacement, PO retainer, dump 1-1/2 bbls slurry on top of retainer, ClP 2100 hrs 8/19/91, POH w/CT & secure well. 08/21/91 1230-1530 hrs Move in & RU Precision WL(slick), run 2-1/2" OD T.B. to top of cmt. tag @ 10,337'-solid tag, POH & RD 1530-1830 hrs RU Arias "E" line, make up 2-3/4" OD JRC jet tbg cutter, unable to get cutter thru well head, make up 2-19/32" undersize cutter, unable to get thru well head, check tree out, determined it is 2-9/16' 5,000 equip, 3-1/2" tbg ID 2.992', make up & run 2-1/4" OD JRC Jet tbg cutter to 10,200', monitor 100 psi csg press & shot tbg cutter, lost csg press & had good indication on tbg of communication. Note: New Plug back TD is 10,337' w/283' cmt on top of retainer. Shot undersize cutter, had very good indication tbg .has hole ff not severed @ 10,200'. Signature ~,~ Drilling Superint~d/~nt Date RECEIVED MAR Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 27, 1991 C©MM COMM SR GE( ~ ~tLE Mr. J. A. Dygas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 222 West 7th Avenue : Post Office Box 13 Anchorage, AK 99513-7599 SubjecV. 1992 Sundry. Notice Request for TA Wells in Swanson River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 32 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. All 32 wells are expected 'to be shut-in for a period of at least 30 days during 1992. Several information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: o rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only abandonment. RECEIVED DEC ,:,z 1 199t Alaska Oil & Gas Cons. CommiSsion Anchorage Mr. ]. A. Dygas Page 2 December 27, 1991 Shut-in wells until field bl0wdown, including: 4. Hemlock producers, and 5. wells with future shallow gas potential in which the Hemlock has been abandoned. The fifth category shown above is a new addition to this year's TA listing. This grouping is for the wells in which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last ye~'s TA list were moved into this category. Attachment 2 gives a brief explanation for each well that has been added to or removed from the 1991 Temporarily Abandoned List (Ref: our letter of 12/28/90). Eight wells, SCU 12A-4, SCU 21-8, $CU 23B-3, SCU 43A-4, SCU 13-9, $RU 212-10, SRU 21-22 and SRU 212-27, have been added while two wells, $RU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, $RU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4.107. Sincerely, J[ C. Winn Acting Regional Engineer JTZ:jlg:0025 Attachment L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation Alaska Oil 8, 6as Cons. com~Ss'tO° Anchorage (La eot ~ tMJ .. ~: ~:~' ~' ~V e r unit ....... 19 we~S SwanSon Form aPproved- t Bureau No. tOO4-Ot35 ', ldOtnacreek S-~~s°n ield _--13 wells · Soldotna creek unit--- Check. APP~°lmate ~x ~o indicate ~otu~ o~ ~oficl, R'~' ~ f: -: o~sc,,,' ':'L~ ~ ~ a ...... A~s~, ~c. ~~ t~t the ~- p~~ ~)* ~e a~~ m~o, ~CO 503 ?.3~3 5CU 21-'S * sKU 14-15 SKU Z~Z~ 5CU 12A4 5CU ~1~ sKU ~15 5~U ~27 ~ 134 ~ 1~9 s~U 3~15 SKU 21247 ~ 21A4 ~ 2~~ 5RU 211-15 SKU 331-27 ~ ~9 SKU 4lA-IS sKU ~ ~ ~A4 ~ l&~ 5~U 43A-~5 5~U ~ SKU 32-~ RECEIVEE DEC 1 1991 Alaska Oil & Gas Cons. CommL · ~ i.d,.C~o"s on Revere Side Attachment 1 Swanson River Field Proposed Temporarily Abandon Wells: Total 32 Wells Shut-in Wells under Evaluation for Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A SCU 12A-4 SRU 212-10 SCU 14-34 SCU 13-4 SRU 211-15 SRU 23-27 SCU 21A-4 SRU 23-15 SRU 14A-33 SCU 34-4 SRU 41A-15 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SCU 341-8 SRU 212-27 SRU 21-22 SRU 331-27 SRU 34-28 SRU 24-33 SRU 43-28 SRU 32-33WD o 11 Wells 9 Wel[~ 3 Wells Shut-in Wells until the Field Blowdown Future Shallow Gas Producer Hemlock Producers with the Hemlock Abandoned SCU 21-8 * SCU 13-9 SCU 24A-9 SCU 34-9 SCU 23B-3 * SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 5 Wells 4 Wells * -High GOR wells that may be produced intermittently. For. Temporarily Abandonment Sundry 12/27/91. t Attachment 2 RECEIVED Swanson River Field Wells with Tempor~ly Abandoned Status Change (Based on 1991's TA Status; our letter 12/28/90) DEC 1 199t Alaska Oil & Gas Cons. Commissi A~ct~orage Added to 1992 Temporarily Abandoned Status: · SCU 23B-3 & · SCU 21-8: High GOR wells, may be produced intermittently, otherwise shut-in until blowdown. · SCU 12A-4: High GOR well, may be produce intermittently, This well is also being considered as a workover candidate. · SCU 43A-4: Shut-in due to mechanical problems. Also being considered as a workover candidate for shallow gas. · SCU I3-9: High GOR well, shut-in until field blowdown. · SRU 212-10 & · SRU 212-27: High water rate shallow fuel gas well, currently not economic to produce based on current fuel gas needs. . · SRU 21-22: Well currently shut-in due to problems with the flowline. Well will be returned to production when repairs have been completed. Removed from 1991 Temporarily Abandoned Status · SRU 21-15 & · SRU 314,27: Wells are scheduled for full P & A in 1st Quarter 1992 as part of the '91-'92 SRF Plan of Development. Note: 'Hemlock Only' abandonments were performed on SRU 14-15, SRU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future ~l~alt~gas po~n~al'-~ a.nd r~main on. the TA'List for 1992. Attachment 3 Swanson River Field Shut-in Wells not on the 1992 TA Status List Wells with planned upcoming work: · SRU 21-15 & · -SRU 314-27: Wells are scheduled for P & A in first quarter 1992. Wells that are used seasonally · SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. RECEIVED DEC ,~ 1 1991 Alaska Oil & Gas Corl$. [,ummJssio~' Anchoraae -, ' STATE OFALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Stimulate _ Abandon Alter casing _ Repair well Plugging X Time extension _ Change approved program ~( Pull tubing_ Variance Perforate Other Hemlock 2. Name of Operator 5. Type of Well: --6. Datum elevatiOn (DF or KB) Development X ARCO Alaska. Inc. Exploratory _ 306' KB feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510' Service _ Swanson River Unit 4. Location of well at surface 8. Well number 860' FSL, 2400' FEL, Sec. 15, T8N, R9W, SM $RU34-15 At top of productive interval 9. Permit number Straight Hole At effective depth 10. APl number 50-133-10142-00 At total depth 11. Field/Pool Swanson River Field 12. Present well condition summary K ~~ I:V ~'U Total Depth: measured 1 1,190' feet Plugs (measured) true vertical 1 1,190' feet Effective depth: measured 11,090' feet Junk (measured) AU~ 0 7 !991[ Casing Length Size Cemented ~.'.u~T~e vertical depth Structural · Conductor 2 8' 22" Yes 28' md 28' tvd Surface 2,876' I 1-3/4" Yes 2,876' md 2,876' tvd Intermediate Production 11,190' 7" Yes 11,190' md 11,190' tvd Liner Perforation depth' measured 1 0,793'-10,797'; 10,802'-10,812'; 10,818'-10,837'; 10,850'-10,892' true vertical 1 0,793'-10,797'; 10,802'-10,812'; 10,818'-10,837'; 10,850'-10,892' Tubing (size, grade, and measured depth) 3-1/2" EUE to 10,615' and 2-7/8" EUE 8RD from 10,615'-10,890' Packers and SSSV (type and measured depth) Baker "FH" at 10,692'; Baker "F" at 10,892' 13. Attachments Description summary of proposal X Detailed operation program ~[ BOP sketch__ Wellbore Diagrams, Well History, Area Map 14. Estimated date for commencing operation 15. Status of well classification as: August '1e, 1991 Oil z~ Gas __ Suspended ~ 16. If proposal was verbally approved .~ 3:; Name of approver Date approved Service 17. I I araby ~if,~t the foregoing is true and correct to the best of my knowledge. n f'~ OJ~ J~/,~~ ~-.._ Title Area Drilling Engineer Date ~ I ~ -' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval N~.~ Plug integrity_ BOP Test__ Location clearance__ I-- °~'~ Mechanical Integrity Test_ Subsequent form require 10-~0'~-.'~ Approved by the order of the Commission Commissioner Date ~/~/ Form 10-403 Rev 06/15/88 SUBMIT ORIGINAL SIGNED BY RUSSELL A,' DOUGLA~ ir ~IPLICATE Apprpvec~ Copy Ret;u_rne~:L/ '- 34-15 Gener; l p&A Procedure . e MIRU slickline. RIH with gauge ring to PBTD. Confirm PBTD @ 11,090' ±. RD slickline. RU CTU and MU open ended nozzle. RIH with open ended nozzle to PBTD. Adjust odometer to match slickline depth. POOH w/CTU. 3. RIH w/wireline. Set cement retainer # 1 @ 10,800'. POOH w/wireline. . o . e . 10. 11. RU HOWCO and line cementers to pump down the coiled tubing unit. RIH w/CTU. Sting into retainer at 10,800'. Down squeeze 104 cuft. class "G" cmt. Unsting CTU from retainer and POOH. RIH w/wireline and perforating guns. Perforate tubing from 10,730' to 10,740'(below "S" nipple). POOH w/wireline. RIH w/ wireline. Set cement retainer # 2 @ 10,675'. POOH w/wireline. RIH w/CTU and sting into cement retainer @ 10,675'. Down squeeze 58 cuft. class "G" cmt. Unsting CTU from Retainer and POOH. RIH w/wireline and perforating guns. Perforate tubing from 10,655' to 10,665'. POOH w/wireline. RIH w/CTU. Pump 30 cuft. class "G" cmt. in Tbg.xCsg. annulus. POOH while laying 6 cuft. cement in Tubing. RD CTU and HOWCO. .. RIH w/wireline and dummy bar and tag cement top. POOH w/wireline and dummy bar. RU Tbg. cutter and RIH to 10,200'. Cut Tbg. @ 10,200'. POOH. RD and secure well. RE6EIVED AUG o 71991 SRU 34-15 Brief Well History SRU 34-15 was drilled and completed in the H4-H5 Sands in August 1961 for 493 BOPD. By November 1970, the rate had declined to 260 BOPD. In July 1971, a workover was performed t0 prepare SRU 34-15 for gas injection. The H1-H2 Sands were perforated and a selective single Completion was run. This well was intended to !~prove Central Fault Block sweep efficiency and provide additional injection capacity. Once the workover was complete, the well was produced until November 1972 before being placed on gas injection. In August 1971, the HI-I-I2 Sand was selectively tested and produced no flow. In August 1972, the H4-H5 was tested at 503 BOPD x 80o~ watercuL In November 1972, gas injection was initiated at an average rate of 10200 MCFD at 5500 psi. In November 1973, gas injection was termlr~ated and water injection was initiated. It was concluded that enough gas had 'been injected to saturate and swell the off in the area. Water injection was commenced to increase recovery. The well was shut-in from October 1976 until March 1980 when it was returned to production on gas lift. For the next nine months, the well · produced water at high rates with no off. In December 1980, the well was shut-in. A Chevron casing integrity test was performed in January 1986 and was not successful. Documentation of the CrT is not available. In April 1986, a 1.9" tool was run to 10,800' MD and heavy scale, sand and mud was found. Currently, the tubing indicates no pressure. The production casing pressure is 180 psi and the surface casing pressure is 15 psi. Since the SRU 34-15 produces at high water rates with no off, it offers no future utility in the Heml_~ck. As uphole gas may'be present in this well, only the Hemlock is recommended for abandonment at this time. This abandox~__m_ent will leave SRU 14-15 in a safer condition than its current configuration. UNIT BOUNDARY~ r.-~ -,,,.,, I I I I ! ! I I I I I w r-J I I SWANSON RIVER FIELD STRUCTURE MAI= HEMLOCK FORMATION ,m 1450 t · Ill' 't 15.C'0t Ov I$55' ?9'80 10,G48.~3" ..'TS. TOP TO 'E~'R. (8.09, /..08 & 1.65) · · I Jl', 2~m BI3l CJJCO ,~" )0(~ I Jl', 2or" :r, Iz TM. · · 11,0gO° '.---- TO!~ Cf ~ · 11, lcJO.'O0e I';D. · · I ,YT, 2]" %1~. TM. · · · · 1,1.10 ' ,11.C2' 6.69' 31.60' 1.6~' 13.W' .tl.71' 1.51~ 6.37 t · EXHIBIT B-2 I II I · SRU 334- 5 CASING ar TUBING DETAIL SECTION IS T, 8. N.,R. 9 W. i I i, 15oC'0~ 29,2/,e OV PUP JTS. fOP ?0 ~'1<. (8,Cq)~ /.08 & 1.6~) 13,1S2" · o 1,25o · 1,1,10l 31,C2e 6,69I 1,62i 63,2Di 1~,20t ,~1,71" · 1,~1' 6.37! ~ ,~0 ~ · EXHIBIT B-2 _ . _ _ i S R U 334-15 CASINO & TUBINO DETAIL SECTION I$ T. 8. N.,R.9 W. Cmt Vol for Hemlock P&A SRU 334-15 ~roc @ lO,5OO' Perfs @ 10,655' Packer @ 10,680' Packer @ 10,842' Retainer #2 @ 10,675' @ 10,730' Cement Retainer @ 10,800' Tubing tail @ 10,880' Cement to 10.500' Vol-1 = 248'*.2085 = 52 * 200% = 104 cuff. Vol-2 = 175'.03253 = 6 cuff VOl-3 = 175'.1634 = 29 * 200% = 58 cult Vol-4 = 180'.1634 = 30 cuft Plug @ 11,090' 7", 29#, P110 @ 11,190' ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMITTAL g419 T(k Commissioner COMPANY: A~ .DATE: Au[[. 8: 1~ FROM: Tom Wellman COMPANY: ARCO Alaska, Inc WELL NAME: Listed below Transmitted herewith are the following Blue Sepia Sepia Linc Folded Rolled M~,lar Tape SRU 34'I5 Dufl:~Burst TDT,P~Lo~ . 1 1 Receipt Acknowledgement: A U G - 9 1990 Return reciept to ARCO ALASKA, Inc. Alaska 0il & Gas Cons. commission ATrN: Judy Boegler ATO 1390A Anchorage Post Office Box 100360 Anchorage, AK 99510-0360' ARCO Alaska, inc; Post Office Bux 100350 Anchorage. ~'iaska 995 !.0-0360 Te,e~'~c~e ~07.3--3,. ' 2 ? 5 E~g:~eer:ng December 29, 1989 Mr. J. A. Dygas, Branch Chief Division of Minerals Bureau of Land Management 6881 Abbott Loop Road Anchorage, Alaska 99507 Dear Mr. Dygas: Attached is a Sundry Notice requesting approval to temporarily abandon 31 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.3-4, paragraph C of the Bureau of Land Management Regulations. All 31 wells are expected to be shut-in for a period of at least 30 days. The wells are separated into four categories: 1. Under evaluation for rate potential. 2. Under evaluation for P&A or future utility. 3. Inefficient producers. 4. Shut-in until blowdown. Several other items have been attached for your information. Brief explanations are given for each well that has been added or deleted from the temporarily abandoned status (Ref: your letters of 3/1/89 (3160 (984)) and 3/30/89 (3180 (984)) and our letter 12/28/88). In addition, a list of currently shut-in wells which have Planned upcoming work that will enable their remm to production is .attached. If you haVe any questions concerning this Sundry Notice request, please call Stacy Strickland at 263-4914. Sincerely, Tom Wellman TW:SLS:jt:0016 Attachment CC: C. V. Chatterton, Chairman AOGCC A. R. Kukla, Marathon Oil Company S.W. Ohnimus, UNOCAL Corporation RECEIVED D c2 1989 Alaska 0il & ~as Con8. Commissi~ Anchorage · ~'o,~ ~.,o-s (November ~o~.,~ ~-~a~) D~ARTMENT OF THE INTERIOR ~UREAU OF ~AND ~ANAGE~ENT . 'SUNDRY NOTIC~ AND RE~R~ ON 1. ~ 2. ~&MIS OF OP'II. ATOa ARCO Alaska, Inc. 3. &DDUl8 Of oI'RB.&~OS Post Offi*ce Box 100360 Anchroage, AK 99510 4. L~CATION se will, (Rel)ort location clearly and In accordance with &ay StAt~ See also IDlC'~ 17 blow.) $oldotna Creek Unit - 11 wells Swanson RiYer Unit - £0 well~ 14. PliM~ ~o. J ~S. IgVA~ONS (S~ Wb~r DF, ~, Form apgmved. IBudiat Bureau No. 10(~ 0135 F-x~DJ, reR AulL'uRt 31, tg~S ~. M OIII~N&%"IOll <d I~L&L as. 6, I~ IIDIAII~ &LLO~I'BB O~ ~IJBB R&al 10. fUBLO d~D POOL, 0S WILDCAT Kenai Alaska 16. Check Aom°jmate Box To Indicate Nature oJ Notice, Re0ort, or ~ ~ N~ICB ~f IN~BN~ON ~: REPAIR WaLL CHA~GE PLANS (Other) Temporar i i y abandon , mlo~rsNe om &CB'tINS &sdJoOisumr~ (Other) (No~B: Regort rflstlto ~ m~t~Mi #~lou om Completion or Reeomideuoa Be~rt and Loqr form.) I?. u):srRfu£ PROPOSED 08 CO.~fPLETED 0PERATIo.~s (Clearly state MI ~rtinP.t detlllu, and ;lYe ~rtlnent ~t~ Ineiud~ l~itd dim Ot_l~ U~ nenG ~ ~ia ~L) · As described in-thc attached memo, ARCO Alaska, Inc. requests' that thc following wells have a temporarily abandoned status' Soldotna Creek Unit Swanson River Unit SCU 13-3 SCU 13-4 SCU 21A4 SCU 34-4 SCU 24-5 SCU 33-5 SCU 33-8 SCU 341-8 SCU 34-9 SCU 31A-16 SCU 14-34 SRU 34-10 SRU 23-22 SRU 14-15 SRU 312-22 SRU 21-15 SRU 23-27 SRU 211-15 SRU 314-27 SRU 331-27 SRU 31-15 SRU 34-28 SRU 34-15 SRU 43-28 SRU 41A-15 SRU 14A-33 SRU 43A-15 SRU 24-33 SRU 32-33WD SRU 432-15 SRU 12-34 RECEIVEE 2 91989 Alaska Oil & Gas Cons. C0mmi~ Anchorage 18. I bere4)y cert~7 ~Ltt the goregomg lB t.r~e &nd correct TZTLE Cook Inlet Enginerring Managms~m (This al)act tar IPoderaI or State o~ce Rue) APPROVED BY CONDITXONS OIP APPROVAL. LF ANY: TITLE DATB '*See InmKflom on Revere Side T~tle l$ U.S.C. Section lOOl, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictttzous or fraudulent statements or representa~ons as to any matter wtthm tis jurisdictzo~ TEMPORARILY ABANDONED WELLS IN SRF Wells under Evaluation R_ate_ Potential Wells being evaluated for P&A/Future Utility Wells SI for Inefficient Producti, on Wells SI until B!owdown 13-4 34-4 24-5 33-8 341-8 34-9 41A-15 23-22 23-27 13-3 14-15 21-15 211-15 31-15 34-15 432-15 31A-16 312-22 34-28 14A-33 32-33WD 12-34 14-34 21A-4 33-5 34-10 43-28 24-33 43A-15 314-27 331-27 For: Temporarily Abandonment of 12/29/89 SWANSON RIVER FIELD Wells having Changed Temporarily Abandoned Status Added to Temoorarilv Abandoned Status: - _ SCU 21A-4: Well is temporarily abandoned due to inefficient production (high GOR). SRU 32-3,3 W D- Well is temporarily abandoned due to annulus communication problems. Removed from Temnorarilv Abandoned ~tatus: -- _ SCU 243-8' This shallow sands gas well has been returned production. SCU 13-9' A workover is planned for this well which will enable this well to be returned to an active status. SRU 212-10: This shallow sands gas well has been returned to production. SRU 23-15: This gas-lifted well has been returned to production. SRU 21-34: A sidetrack is planned which will enable this well to be returned to an active status. RECEIVED D C291989 Alaska Oil & ~3as Cons. Commission Anchorage For: Temporary Abandonment Sundry of 12/29/89 SWANSON RIVER FIELD WELL STATUS UPDATE Shut-in Wells with Planned Upcoming Work* SCU 32A-9: When on-line, this SI well produces gravel. A sidetrack is planned to return this well to active status. *Will not be placed on temporarily abandoned v~c ~ 91989 Oil & ~ss Cons. Co,mi Attcl~ord#e For: Temporary Abandonment Sundry of 12/29/89 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 T. Stewart McCorkle Engineering Manager Cook Inlet/New Ventures December 20, 1988 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached are Sundry Notices to change the status of seven Swanson River well from injector to producer. The wells are as follows: SCU 341-8,.6RU 34-15, SRU 432-15, SRU 312-22, SRU 314-27, SRU 331-27, and SCU 343-33. In changing their status, these wells no longer remain under the jurisdiction of the Swanson River Area Injection Order No. 13 for Class II wells. Please call Carol Baker at 263-4643 if you have any questions concerning this matter, Sincerely, T. S. McCorkle TSM:ch:0011 Attachments CC: G. A. Graham A~ 1~ Kukla UNOCAL Corporation Marathon Oil Company REEEIVED DEC 2 8 1988 Alaska 0il & Gas Cons. Commi;sioi~ NIchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3BI6279 . ~ ~ STATE OF ALASKA ALA,,,,.A OIL AND GAS CONSERVATION COMMISSION ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Perforate__ Wel I Status Change fr0r~ Pulltubing__ Alter casing __ Repair well __ Pulltubing__ Otherx I nj. to Producer 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510 4. Location of well at surface 2400' FEL, 860' FSL Sec. At top of productive interval ' S-I-ra i ght Ho ! e At effective depth 15, T8N, R9W At total depth 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 306 ' KB feet 7. U..nit or Prope~y. name bwanson K~ver Field 8. Well number SRU 34- 15 9. Permit number/approval number 10. APl number 50-- 133-10142-00 11. Field/Pool Hem lock 12. Present well condition summary Total depth: measured true vertical 11,190' feet Plugs(measured) 11,190' feet 13. Effective depth: measured true vertical Casing Conductor 28 ' Surface 2,876 .' Production LYly~XX Perforation depth: measured 10,850- 10,892' MD. true vertical 10,850- 10,892' TVD. Length 11,190' 11,090' ~ Junk(measured) 11,090' feet Size Cemented Measured depth True vertical depth 2'2" Yes 28' 28' 11-3/4" Yes 2,876' 2,876' 7" Yes 11,190' 10,793 - 10,797' MD; 10,802 - 10,812' MD; 10,793 - 10,797' TVD; 10,802 - I0,812' TVD; Tubing ('size, .qrade, and measured depth) 3-1/2~' EL'iE to 10,615' and 2-7/8" EUE 8RD from 10,615 - 10,890'. Packers and SSSV (type and measured depth) Baker "FH" at 10,692'; Baker "F" at 10,892'. Stimulation or cement squeeze Summary ' ' N/A Intervals treated (measured) Treatment description including volumes used and final pressure 11,190' 10,818 - 10,837' MD; 10,818 - 10,837' TVD; :c iVFD DEC 2 8 Alaska, Oil & Gas Cons. Commission ~ : ~chorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut- i n 80 Subsequent to operation ~; b u t- i n 15. Attachments 116. Status of Well classification as: Copies of Logs and Surveys run __ I P r o d u c e r Daily Report of Well Operations __ I' Oil __ Gas __ Suspended X__ 17. I hereby certify that the foregoing is true and cOrrect to the best of my knowledge. 8O 0 Service Signed Form 10-404 Rev 06/15/88 Title Cook I n let Engineer i ng Manager Date/.~-~;~ ~ SUBMIT IN DUPLICATE TABLE Wells under Evaluation for. Rate Potenti al 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B,3 14-3 33-5 34-4 Wells being Evaluated for P&A/Future Uti 1 i ty 212-10 21-15 31-15 34-15 432'15 312-22 212-27 14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Producti on 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 "~'343-33 3'~ z".4' ~;,~._~, .+i r,,,.~l~z.,~ ,',_} ........ ~ ~~' ~.-~ .... ~ ~-~ ~..., ~ ~-- ~ ~, ~-- __. ....... -~~ - ~ o ~, ,~4 % ~ _. , ~.. · , __ - .... , .- . ........ .... ATTACHMENT E~I Injection Well Data Water Disposal Wells SRU 31-33W SRU 32-33W SRU ~1-33W SRU 21-33W · Avg. Rate(BPD) 3271~ 651 125 2805 MaX. Rate(BPD) t+500. ~+500 4500 4500 ~4500 Ay§. Press(psi) 769 778 913 735 Shut In ~Aax. Press(psi) 1000 1000 1000 1000 1000 · Depth of .Ini.(~t.) 2100 2100 2J. 2_O 3100 Depth of Well(ft;) 2~61 2520 3000 6660 Gas Injection Wells Ave. Rate(MCFD) Max. Rate(MCFD) scu 31#-2 SCU 323-~ SCU 332-~$ 31~1-8 U 312-9 SCU 321-9 scU 323-9.. SCU 3~$3-33 SRU 332-15 SRU 312-22 SRU 31 ~-27 SRU 331-2_? 39,950 35,680 27,6~0 37,6#0 30,300 gg,O00 29,9g0 35,920 0 0 0 0 0 ~5000 #5000 ~5000 ~5000 ~5000 ~5000 ~5000 #5000 ~5000 ~5000 ~5000. ~5000 #5000 5075 5370 5095 5355 5160 5270 5155 5105 Shut In Shut In Shut In Shut In Shut In l 3 5800 '5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 10291 1039# 10870 10226 10256 1.0183 1029~ 10280 10695 11388 '1075~ 111~6 1080~ 11520 10773 11119 10850 1081# 10785 107~5 10730 10995 11982 11000 11~3~ 11620 ARCO Alaska, Inc. 1105OO ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY IN3ECTION REPORT 20 AAO 25.252 SWANSON RIVER FIELD - UNIT 051950 c)9-Sep-87 August 1987 Name of Operator Field and Pool Month and Year of Injection ~1. WELLI2. AP1 NUMBERIS. Cf4. FIELD~5. DAYSI TUBING PRESSURE ~ CASING PRESSURE IDAILY AVERAGE INJECTION:TOTAL MONTHLY INJECTION I NO. I 50- I LI & POOL ! IN ~ I I I I I I Al CODE I OPER ~&. MAXI7. AVERAGE~8. MAXIg. AVERAGE~lc). LIQUID Ill. GAS I 15. LIQUID I 14. GAS I ~ ~ SI I I PSIG I PSIG I PSIG I PSIG I (BBL) ~ (MCF) ! (BBL) ! (MCF) ~ : l___SI ~ 514-4 1133-10104-00 ]G ~ 772100 I 523-4 1153-101c)6-00 :G I 772100 : 332-4 I133-10107-00 :0 : 772100 : 541-4 1133-10109-00 IG : 772100 I 341-8 1135-10120-00:8 : 772100 ~ 312-9 1135-10123-0c) IG : 772100 I 323-9 1153-10126-00 IG I 772100 ~345-55 I133-10168-00 IG ] 772100 :412-10:135-2020&-00 IS I 772100 : 321-9 1135-10125-00 :G I 772100 143-4WD 1153-10111-00 :D I 772056 I I I I I I I I I I I I I I I ! I I I I I I I I I I. I I I I I I I I I I I : I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I | I I I I I I I I I I I I I I I I l' I I I I I I I I I I I I I I I I I I I I' I I I I ; I I I I ...... 30 15,450 I 4,958 15,500 0 I 0 I 0 I 0 30 15,500 I 5,005 11,040 50 15,550 I 5,141 12,8&0 0 I 0 I 0 I 0 I 50 15,350 I 4,~45 1.1,240 50 15,500 I 4,928 12,600 0 I 0 I 0 I 0 1 0 I 0 I 0 I 0 I 50 15,450 I 4,991 11,960 0 '1 '0 I 0 I 0 I I ! I I I I I I I I I I l I l I I I : I I I I I 59,259 I I 1,177,165 I 0 I I I. 31,652 I I I 57,120 I I 1,115,609 I 0 I I 0 I 40,485 I I 1,214,475 ~ 35,148 I I 1,054,428 I 0 I I 0 I 0 I I 0 I 25~706 I I 771,182 Ol I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I l 115. I I I I I' I I I I' I I I I I . I I I ITOTAL I 0 I 6,279,814 I I Submit in Duplicate 2,359 0 656 2,576 0 1,109 2,368 0 0 1,815 0 II hereby certify that the foregoing is true and correct to the best of my knowledge ITitle /~ .~.,c ~-"/,"J ~(~'z.~. K.-...~ Form 10-405 Rev. 12-1-85 Date ? //j- ~$7 INSTRUCTIONS ON REVERSE SIDE ALASKA OIL AND BAS CONSERVATON COMMISSION MONTHLY INJECTION .REPORT 20 AAC~5.232 : ARCO Alaska, Inc. 116)500 SWANSON RIVER FIELD - UNIT 051994 August 1987 : : Name of Operator Field and Pool Month and Year of Injection :1. WELL:2. API NUMBER:3. C14. FIELD:5. DAYS: TUBING PRESSURE I CASING PRESSURE :DAILY AVERAGE INJECTION:TOTAL MONTHLY INJECTION NO. | 56)- I LI & POOL I IN I I I I I I I Al CODE I OPER I6. MAXI7. AVERAGEI8. MAXIg. AVERAGEIIO. LIQUID Ill. GAS I I I SI I I PSIG I PSIG I PSIG I PSIG I (BBL) I (MCF) I (BBL) I (MCF) I I I___SI I I ...... I I ...... I I I I I 1312-22 1133-10147-00 18 I 772100 I - I I I I I I I I I 1314-27 1133-10154-00 IS I 772100 I - I I I I I I I I I I331-27 I133-10156-00 IO I 772100 I - I I432-15 I135-10141-00 IG I 772100 I - I I I I I I I I 121-35WDI133-101&2-O0 ID I 772036 I 29 I 875 I 754 I I I 2,675 I I 77,581 I I I31-35WD1133-20356-00 ID I 772036 I 29 I 820 I 746 I 0 I 0 I 2,770 I I 00,318 I I I32-35WD1133-10164-00 ID I 772036 I 50 I 875 I 759 I 0 I 0 I 2,071 I I 62,119 I 1 I41-33WDI133-10167-00 ID I 772036 I 30 I 850 I 731 I I I 145 I I 4,352 I I ~ I I I I I I I I I I I I I I I ' I I I I I I I I I t I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I : I I I | I I I I I | I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I | I I II hereby certify that the foregoing is true and correct to the best of my knowledge 115. I I I I I I I' I :Signed '~l~. 2.~ I I I I I I I I I I ITitle ~'l~ A~g ~ .... Date ~ ~'""/~7 ITOTAL I 224,370 I 0 I I I I I I Form 10~405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE I 13. LIQUID I 14. GAS Submit in Duplicate PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY PRUDHOE BAY UNIT S-11 IT T-1 UNIT T-7 UNIT UNIT U-~ UNIT UNIT U-9 UNIT U-lO UNIT X-6 UNIT X-ll UNIT X-23 UNIT X-2h bNIT X-26 UNIT Y-3 UNIT UNIT Y-6 UNIT Y-7 UNIT Y-11RD PRUDHOE BAY UNIT Y-18 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL SWANSON RIVER, HEHLOCK OIL POOL ARCO ALASKA INC SOLDOTNA CK UNIT 314-q SOLDOTNA CK UNIT 323-q SOLDOTNA CK UNIT 332-~ SOLDOTNA CK UNIT 341-4 SOLDOTNA CK UNIT 341-8 SOLDOTNA CK UNIT 312-9 SOLDOTNA CK UNIT 321-9 SOLDOTNA CK UNIT 323-9 ........ SOLDOTNA CK UNIT 412-10 SOLDOTNA CK UNIT 343-33 UNIT OR LEASE TOTAL 309~534 26q,q25 174,467 380,162 602,357 515,072 264,751 183,322 2~4,173 29q,661 149,980 173,54~ 262,057 282,3~4 76,~92 49,131 8h,323 22,223 43,679 306,~29 14,519,526 39,536,156 8~,~h5,002 39,536,156 88,810,140 SOLDOTNA CREEK UN IT SHUT-IN SHUT-IN 31 31 31 31 31 31 31 ,31 31 31 31 31 31 31 31 31 1,1~8,650 31 1,080,598 31 871,402 31 1,090,670 31 153,799 6 1,246,967 30 749,378 31 1,089,518 31 7, q30,982 - , - , 6,975,040 7,115,160 1,2~1,q72 2,275,741 2,727,957 2,791,~76 2,551,632 1,790,980 1,767,557 6,17~,166 5,618,096 3,530,3~2 5,273,083 3,169,181 3,942,403 1,968,753 2,653,~03 102,640 597,32~ 6,4O9,296 1,388,876 294,742,9'15 233,327,280 207,759,3b0 231,764,932 218,694,647 30~,044,302 33,033,8~2 170,911,513 111 ,./~13,676 - - ENHANCED RECOVERY - - WELL NAME AND NUMBER ARCO ALASKA INC SWANSON RIV UNIT 331-27 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL TRADING BAY, MICDLE KENAI C OIL POOL UNION OIL CO CF CALIFORNIA AOL-18T$1 TRADINGBAY ST. A-SRD-2 TRADING BAY ST A-12RD TRADING BAY ST A-26 TRADING BAY ST A-29 UNIT OR LEASE TOTAL POOL TOTAL TRADING BAY, MIDDLE KENAI D OIL POOL UNION OIL CO OF CALIFORNIA 2DL-18731 TRADING BAY ST A-SRD-2 TRADING BAY ST A-19 UNIT OR LEASE TOTAL POOL TOTAL .. FIELD TOTAL ALASKA INDIVIDUAL WELL PRODUCTION FOR MARCH, 1987 OIL(BBL) WTR(BBL) GAS(MCF) DAYS SWANSON RIVER UNIT SHUT-IN SHUT-IN-"~. SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN 7,~30,982 7,q30,982 .., &cz. ~. ':'"..' - ! " . , .. CUM. OIL CUM. WATER 413,934 15,582,616 h,498,822 6,267,061 7,348,684 21,618,136 CUM. GAS 28,263,659 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT ¢)51994 Field and Pool December 1986 Month and Year of Injection I NO. ~ 512-22 -: 514-27 :.,'.:~.i: ~ ~ .~51-27 '~:*i 432-15 I I' I I I ; . . il. WELLi2. API NUMBER~5. C14. FIELDi5. DAYSi TUBING PRESSURE I CASING PRESSURE {DAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION 50- I LI & POOL I IN I I ~ l I Al CODE I OF'ER 16. MAXI7. AVERAGEI8. MAXlg. AVERAGE~iO. LIQUID Ill. GAS I 15. LIQUID ~ 14. GAS I SI l___SI 135-10147-00 I G I 772100 155-10154-00 I G I 772100 135-10156-00 I G I 772100 15~-10141-00 I G I 772100 I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I' I I I I I I I I I I I I I I I I I I I l I I I I II hereby certif~ that the forego~i:ng is true and correct to the best of my knowledge I Si gned _ __+~.~_ _ __~ .................... Supervis~n~, New Ventures Compliance and Revenue I Ti t I e Date I (BBL) I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I , EECEI\, u I I I I ,- .~,; 115. | alasi~a Oil & Gas Cs;.,I :. An,sho~?-: I I I I I I I TOTAL I 0 1 I I (M~F) Submit in Duplicate I I I I I I I I I 1 I I I I I I I I I I ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 ARCO Alaska, Inc. 110500 Name o~ Operator SWANSON RIVER FIELD - UNIT 051950 Fi eld and Pool December 198& Month and Year of Injection 11. WELL NO. I I ! I 514-4 I 525-4 -! 552-4 <.~_*) 541-4 :~'l 541-8 I 512-9 I 525-9 1412-10 I 521-9 I I I I 1 I I I I -.--. I I. I 2. API NUMBERIS. CI4. FIELDIS. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION 50- I LI & POOL I IN I I I I I Al CODE I OPER 16. MAXI7. AVERAGEI8. MAXlg. AVERAGEllO. LIQUID 111. GAS ~ 15. LIQUID ~ 14~ GAS I SI I l___SI 155-10104-00 IG I 772100 I 50 155-10106-00 IG I 772100 I 50 I 155-10107-00 IG I 772100 !~-10109-00 IS I 772100 J 50 I 155-10120-00 IB I 772100 I 50 15,500 I 4,882 11,400 I 1,548 I I 25,121 I I 695,626 155-10125-00 IS I 772100 155-10126-00 IG I 772100 155-10168-00 I G I 772100 I 0 I 0 I 0 I 0 i 0 I I 0 I ~ 0 !55-20206-00 I G I 772100 I 0 I 0 I 0 I 0 I 0 I I 0 I I 0 155-10125-00 IS I 772100 I 50 I I I I I I I I I I I I I I I I I I I I I I I i I I I I I I I ~ I I I I I I I I I I I I I I i I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~.~i~ :~ 'i~ ~I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I" :-i <' -- v ili'.~ I I I I I I I | I II hereby certify that the for~;T~ is true.and correct to the best o~ my knowledge l~igned .......................... p ~ mpliance and Revenue ITi~le Date __ Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE I15. -,,..~,c lW,, ~ ........ c" i · I I' I I I I I I I TOTAL I 0 I 6~288~655 I I Submit in Duplicate LEASE NO. IENHANCED RECOVERYI COMP.DATE STATUS PRODUCT JAN FEB MAR ~X~ SHANSON RIVER, HEMLOCK ARCO ALASKA INC SOLDOTNA CK UNIT UNIT051950 OIL ALASKA INDIVIDUAL HELL%0DUCTION FOR 1986 APR MAY JUN JUL AUG SEP OCT NOV YEAR M DFC TOTAl CUM. 08/15/60 HTR ' 1GINJ GAS 1055857 1026390 1189909 1165806 1228646 1211657 1257286 1288552 1505704 1125075 1022953 975018 15808655 291785545 ~OL~OTNA C~ UNIT ~23-6 APl 133-lfl]o~-no UNIT051950 OIL 0'6/01/61 HTR " GINJ GAS 926806 895795 1014489 1021515 1095847 1095954 1110742 1160265 1165222 986857 950909 885785 12505942 250168775 ~OL~OTNA CK UNIT 33~-4 AP] ]33-]0]07-00 UNIT051950 0IL ) 06/05/60 1GINJ OAS 729520 696699 694'207 768554 848986 808659 855755 906629 908925 775879 755048 721155 9465572 205554813' SOLnOTNA CK UNTT . ~41-4 APT ~-ln]nq-nn UNIT051950 OIL 05/21/60 HTR 1GINJ GAS 964182 959897 1105510 1004702 1191650 1125455 1151894 1167267 1142665 98956? 104759? 898524 12728466 228845715 UNIT051950 0IL 07/14/61 HTR 1GINJ GAS 772050 721011 855765 795562 858795 851801 877466 885419 861454 802085 790782 695626 9761772 21711426~ SOLDOTNA CK UNIT 552-q .APT UNIT051950 0IL [0/09/60 HTR 1GINJ GAS 1150860 [1052~6 1275~68 1219454 [266462 1242821 [268188 1518592 ~OLDOTNA CK UNIT ~]-q AP] UNIT051950 0IL 07/19/61 HTR 1GINJ GAS 787999 770786 941516 857121 859651 824009 859794 852454 865441 701058 657884 629091 9546564 51111755 SOLDOTNA CK UNIT ~2~-9 AP! UNIT051950 0IL 07/17/6! HTR ° 1GINJ OAS 868162 887705 1057604 1002092 1041454 1027008 1054526 1105448 1110180 1002927 967125 450602 SOLDOTNA CK UNIT 412-10 API 133-20206-00 UNIT051950 Oil 06/11/72 HTR ' 1HINJ GAS SOLDOTNA CK UNIT UNIT051950 OIL 05/08/61 HTR ' 1GINJ GAS .,. SNANSON RIV UNIT UNIT051994 OIL 10/24/59 HTR ' 1GINJ GAS SHANSON RIV UNIT UNIT051994 OIL 08/04/61 HTR 1GINJ GAS 343-33 API API 133-10141-00 API 133-10142-00 13888. 111413676 4018206 9029539 2056925 4643530 LEASE NO. I ENHANCED RECOVERYI COMP.DATE + .......... + STATUS PRODUCT JAN FEB MAR ~~ SWANSON RIVER, HEMLOCK SWANSON RIV UNIT 512-22 API UNITOS]g94 OIL ALASKA INDIVIDUAL WELLiJ~'~ODUCTION FOR 1986 'APR MAY JUN JUL AU~ ~EP OCT NOV z 3-1o1 ?-o0 I YEAR DEC TOTAl. CUM. 08/11/62 HTR 1GINJ GAS SWANSON RIV UNIT UNITOSlq94 51q-27 API 153-10154-00 875988 24017269 06/14/60 HTR 1GINJ GAS SWANSON RIV UNIT UNIT051qq4 OIL 531-27 API 1S3-10156-00 78332178 02/17/58 HTR 1GINJ GAS - ARCO ALASKA INC OPERATOR TOTALS OIL HATER 8,537,995 POOL TOTALS GAS 7,041,527 7,852,406 8,187,502 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,596 8,115,868 8,$69,qq9 8,393,451 8,667,789 7,311,775 95,601,665 SklAN$ON RIVER. HEMLOCK OIL HATER 8,357,995 FIELD TOTALS GAS 7,041,527 7,852,406 8,187,502 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,596 8,113,868 8,569,449 8,5'93,451 8,667,789 7,511,775 95,601,663 SWANSON RIVER OIL HATER 8,357,995 GAS 7,041,527 7,832,406 8,187,302 8,680,226 7,499,819 6,288,655 1,929,187,0 7,215,596 8,115,868 8,$69,449 8,393,451 8,667,789 7,$11,775 95,601,665 SWANSON RIVER WELL ~-- SRU --SRU ~_ SRU .-'S~CU ..S6U ~SCU ~ SCU .~ sou .SCU ~ SCU 5r /~/7~ -SRU 312-22 314-27 331-27 323-4 332-4 341-4 341-8 312-9 321-9. 323-9 432-15 TYPE· GaS Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Gas Injector Water Injector STATUS AS OF 1/1/88 Shut-in Shut-in · Shut-i n Injecting Injecting Injecting Shut-in Injecting Injecting Injecting Shut-in GRU13/2c RECEIVED FEB25 ..... .'-' Alaska Oil & 6as Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 12!5 Cook Inlet/New Ventures Engineering August 19, 1987 Joseph A. Dygas, Branch Chief United States Bureau of Land Management Post Office Box 230071 Anchorage, Alaska 99523 Dear Joseph: Attached is a Sundry Notice requesting approval to temporarily abandon 39 wells in the Swanson River Field for a period of 12 months. This sundry is being submitted to comply with Chapter II, Sec. 3162.4, paragraph C of the Bureau.of Land Management Regulations. All 39 of the wells mentioned in the attached Sundry Notice are expected to be shut-in for a period of at least 30 days. The 39 wells listed in Table #1 we're identified during our recent review of the status of all wells in the Swanson River Field. These wells have been put into four categories: 1. Evaluate for rate potential 2. Evaluate for plug and abandon/future utility 3. Shut in- inefficient production 4. Shut in- save for blowdown Wells. in Categories #1 and #2 are currently under evaluation to determine their final disposition. Wells in Categories #3 and #4 are wells with little short-term usefulness, but wells that do have some long-term utility. If you have any questions about this Sundry Notice request, please contact me at 263-4299. Sincerely, · H, F, Blacker Regional Engineer Cook Inlet/New Ventures HFB: JWR: ch: 0006 Attachment cc: C.V. Chatterton, Chairman · Alaska Oil & Gas Conservation Commission Form 3160--5 {November 1983) (Formerly 9--331) UNITED STATES su,MxT m (Other leaSt, arises om DEPARTMENT OF THE INTERIOR ,e,se-'d.) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~ this form for proposals to drill or to de, pen or plug hack to a different r~rvolr. Use "APPLICATION FOR PERMIT--" for such pn2poaMm.) OrL ~ GAS ~ w ELL w aLL OTHER 2. NAME Or OPERATOR ARCO Alaska, Inc. ADDIgSB Or Soldotn~ 14. P. O. Box 100360 . Anchora~m. AK 99510-0~6t3 LOCATION or '&'ELL (Report location clearly and f5 a~cordance with any State requirements.· See also space 17 below.) At sq.rfaee Soldotna Creek Unit - 15 Swanson River Unit - 22 wells PaRE IT NO. 16. BLBVAT]ONS (Show whether Dr. IrT. mt. etc.) Form approved. Budget Bureau No. 1004--0135 Expires, August 31, 1985 LB&II DIIIO~(&TION AND IBllAL ~J. Ir I#DI&B, ALLOI~IIB OR TItlEm NAMg ?. UNIT &OBBBMBMT CreekTSwanson River Unit WILL MO, 10. ,IBLD AND POOL; OIt WILDCAT Swanson River Field il. IB~., 'Z., L, M., OR ELK. ArA ~UItVB! SIR A).BA IS. COUWTT OB i'tlllllJ 18, IT&YI Kenai [ Alaska 16. Check Appropriate Box To Indicate Nature si Notice, Report, or Other Data NOTICE Or INTENTION TO: FRACTURa TREAT MULTIPLE COMPI.ETE BH~T OR ACID~B ABAN~Ne REPAIR WaLL CHANGE PLAN~ (Other) Temporarily abandon IUBSB~UB]~ ami'eli'S Of: WATII IHUT-Orf ~--~ RBI'&IIIWO WILL ~'~ fRACTURE '[1,ATMBNT i~f ' AL~llItlMO (~AIINO 8BOOTINO OR ACIDIBll(O i i (Other) ..... (No,B: Report results of multiple completion on Well Completion or Reeompletlon Report and Loqr form.) 17. OEXCRIU£ f'ROVOSE0 OR COIIPLaTED OPERATION~. (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any prol)osed work. If well is dir~ctionMly drilled, five subsurface lo~tions and measured and true vertieftl depths for all markers and ~onem perti- nent to this work.) · As described in the attached memo, ARCO Alaska, Inc. requests the s~atus of the following wells be changed to Temporarily Abandoned. SOLDOTNA CREEK UNIT SWANSON'RIVERUNIT SCU 13-3 SCU243-8 SRU212-10 SRU 23-22 SCU12A-4 SCU 13-9 SRU 34-10 SRU 22-23WD SCU 13-4 SCU12A-10 SRU 14-15 SRU212-27 eCU323-4 SCU343-33 SRU 21-15 SRU314-27 SCU43A-4 SCU 14-34 SRU 31-15 SRU 23-27 SCU 24-5 SCU 14-3 SRU 432-15 SRU331-27 SCU 33-5 SCU23B-3 SRU 34-15 SRU 34-28 SCU341-8 SCU 34-4 SRU41A-15 SRU14A-33 SCU2 lA-4 SRU43A-15 SRU 24-33 SRU312-22 SRU 12-34 SRU 21-22 SRU 21-34 18. [ hereby certif~J~bat the forf~oing Is/t~rue and correct TITLE Regional Engineer (This space for Federal or State ogres use) APPROVED BY COI~IDITIOlqB OF APPROV~aT,, I~ ~: TITLE DATa *See Indnmtions on Revmse Side Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the .................. r ........ a ~ · -'-*--------* ,,+mtl,~e~e ne t~ me~v matter within its turisdictiott. Wel 1 s under Evaluation for Rate Potential 41A-15 23-22 23-27 34-28 21-34 323-4 13-9 341-8 24-5 13-3 13-4 23B-3 14-3 33-5 34-4 TABLE Wells being Evaluated for P&A/Future Util it~v 212-10 21-15 31-15 34-15 · 432-15 312-22 212-27 '14A-33 12-34 22-23WD 243-8 14-34 Wells SI for Inefficient Production 12A-4 43A-4 24-33 12A-10 34-10 14-15 21-22 21A-4 Wells SI until B1 owdown 43A-15 314-27 331-27 343-33 STATE Of ALASKA ALASKA ull AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WEL 1. DRILLING WELL I-1 COMPLETED WELL 83 OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 3. Address 8. APINumber P. O. Box 107839, Anchorage, Alaska 99510 50-133-10142-00 4. Location of Well 860' N & 2400' W'of the S.E. Cor., Sec. 15, T8N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 306' K.B. 6. Lease Designation and Serial No. A-028384 9. Unit or Lease Name Swanson River Unit 10. Well Number SRO 434-15 11. Field and Pool Swanson River Field 12. ' Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] - Perforations [] Altering Casing [-'] Stimulate [] Abandon i--] Stimulation F'I Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other J~ Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170):' The well number for SRU 434-15 has been changed to SRU 34-15. 14. I hereby certify t~.he~orrect to the best of my knowledge. Signed ~. Title Area Enq'±neer · The space below for Commission use Date ! Conditions of Approval, if any: Approved by COMMISSlON ER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate TRANSifflTTAL ,,'uND ACKi/"~)JEDG~fl;TqT OF RECEIPT OF MATERIA. ~ALASKA) DATE:L- . ~,.,,, M: ~ /gjT~L THE FOLLOWING IS A LIST OF ~SETERIAL ENCLOSED HEREWITH. CHECK AND ADVISE I~,R~DIATELY. PLEASE 41-9 ~?-U¥ - L.',-- 'k · Received and checked Form . - i~a. ~ "~antions" in Triplioate -/ '" & "~beeiiuent RepOrts" in Duplicate STATE, ,'OF AJ.~KA O[[ AND-GAS i CO-NSERVATIONi ,, , · . SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form £or proposals to drill or to deepen or plug back to a di£fierent reservoir. 5. API N~CAL CODE 6. LEASE DESIGNATION A-ND SERIAL NO. Use "APPLICATION FOR PER~dtlT--" for such prop. osats.) 1. 01L ~ OAS wE~L E~ OT. ER w~er ?.njoctien Well WELL ~ , ' 2. NAME OF OPEH2~TOR P.O. Box 7-839 Anchorage, Alaska 99510 ~. LOCATION O~ ~L A-028384 7. IF INDIA-N[, ALLOTTEE OR TRIBE NAiVLE 8. UNIT, FAR/VI OR LEASE NAME Swanson River 9. wELL No. SRU 4 34-15 " 10. FLELD AaNrD POOL, OR WILDCAT Atsurfaee 2400' West 'a~d 860' North from SE corner .~w~,.~nn of section 15, T-8N, R-9W, SB&M ll. SEC.. T., R,, Ma (BOTTOM HOLE. OB~.CT~VE) ~Section 15 T-8N, R-9W, SB&M 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. P~T NO. 306' KB . 60-41 14. A~riate ~x To [n~e NmtUre ~ ~,k'e, Re ~-, or NOTIC~ OF INTeNTiON ~: BUB~EQU~NT R~PORT OF: TEST WATER SHUT-OFF PULL OR ALTER CASING WATER 8HUT-OFF REPAIRINO WELL FRACTURE TREAT [ [ MULT~LE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ~ ABANDONs 8HOOTIN~ 0R ACIDIZING [ ~ ABANDONM~HT* Other Initiate W~ter Injection ~EPAIR WELL CHAN~E PLANS ( (NoT~: Re~rt results of multiple completion on Well (O:her) Completion or Recompletion Report and Lo~ form.) , 15~ DESCRIBE I'~POSED OR COMPLETED OPERATIONS (Clearly state all ~rtinent details, and give pertinent dates, including estimated date of starting any proposed wo=k. ' Water injection was initiated in .well sRU 334 15 on November//i3, 1973. The well will be red~signated SR~434-~while it is on water injection. SIGNED .... J (This space ~/ State office use) APPROVED B~ COi~DITIOi~ OF TITLE Area Supervisor DATE 11/.f&;Y' 73 TITLE DATE See ~nstructions On Reverse Side Form P--3 ,-~/' ~i~lJmmli "ls%J~ntions" in ~p~ ~. 9-~7 ~ "~q~nt ~po~s" ~ DUpll~te STATE ~ ~A OIL AND' GAS' CO'N~VATION C~I~EE SUN'~Y N'OTi~S ~;D REPORTS ~ W-~ (Do not use this ~o~ for propo~ls W dr~l or to deepen or Use "~PLIC~TIO'N FO~ P~IT~" ior 0IL ~. GAS wELL WEL~ [] OTHER Gas Injection Well 2. NAI~E OF OPEtL~TOR Standard_,Oil Company. of California, W0I . S. ADDRESS OF OPERATOR P.O. Box 7-839 Anchorage, Alaska 99510 4. LOCATION O,F WELL At surface 2400' West and 860' North from S~. Corner of Section 15; T-SN, R-9W SB&M. 13. ELEVATIONS (Show whether DF, I{T, GR, etc. 14. ~06' KB Clmck'Appropriate Box To I~te NJature of N~fice, Re -5. AP1 NUIiEt~CAL CODE 6. LEASE DESIGNATION ~uND SERIA/~ NO. - A-028384 ?. IF INDIAN, A3~LOTTEE OR TRIBE s. UmT, F~.a Swanson River 9. WELL . sRU 334-15 10. FIELD AAID POOL, OR WILDCAT Swanso~ River 11. SEC., T., R., ~i., (BOTTOM HOLE OBJECtiVE) Section 15: T-SN, R-9W, 12. PER/VI/T NO. 60-41 :or~, or Other 'Data NOTICE- OF INTENTION TO: TEST WATER 8HUT-0FF [ I PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI.ETE SHOOT OR ACIDIZE [ J ABANDONs REPAIR ~'ELL ] [ CHANOE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASINO SHOOTING OR ACIDIZING ABANDONMENTS (Other) Terminate Gas Injection (NOTE: Report results of multiple completion on Well" (Other) Completion or Recompletion Report and Log form.) DESCRIBE PROPOSED OR CoMpLETED OPERATIONS (clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. ~ · SB&M Gas i~jection in well SRU 334-15 was terminated on NoVember 1, 1973. 16. I hereby certiJ~at...the_ f/)re, o#~s true and correct APPROVED BY CONDITIONS OF APPROVAL, IF ANX: TITLE Area Supervisor DATE 11/~/73 TITLE DATE See Instructions On Reverse Side Form P--3 I~EV. 9-30-69 STATE OF ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FOR/)'E~i']?~-'' '~or such'p~o~osal~) O,LW.~.L j-~ ,~.,.sW,:LL J--] oT.ER Gas Injection 2. NAIME OF OPERATOR Standard Oil Company .of .Californiat WOI 3. ADDRESS OF OPERATOR P.O. Box 7-839, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 2400' West and 860' North from SE corner of Section 15, T8N, R9W, SB&M 13. ELEVATIONS (Show whether DF, RT, GR, etc. KB 306' 14. Check Appropriate Box To I,ndJcate Niature of N~tice, Re NOTICE OF INTENTION TO: TEST WATER SSVT-OF, PULL Ga ALTER C*S~NG FRACTURE TREAT MULTIPLE COMPI,ETE s~ooT o~ ~cmxz~ J J ~o~* REPAIR W~LL cHANOm PLANS ~Other) ~ ~ AP1 NU-NIF2IlCAL CODE 6. LEA~E DESgGNATION AND SERIAL NO. A-028384 7. IF INDIAN, ALLOT'f,~E OR TRIBE NAME 8. UNIT~ FAB/VI OR LEASE NAME Swanson River Unit 9. W~LL NO. SRU 34-15 10. FIP, LD A~D POOL, OR WILDCAT Swanson River Field 11. SEC., T., R.,'M., (BOTTOM HOL~ OBJECTIVE) Sec. 15, T8N, RPW, SB&M 12. PEP./~IIT NO. ~:~, or Other Data SUBSEqUeNT REPORT OF: WATER 8IiUT-0FF REPAIRING WELL FRACTURE TREATMENT J { ALTERING CASING SHOOTING 0R ACIDIZINO ABANDONMENT* (Other) Conversion to Gas In4ection (.NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form,) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an)' proposed work. On July 16, 1971, work commenced to convert SRU 34'15 to a gas injector well. This conversion was necessary to imp=ov~.isweep effi¢iea%¢¥ and injection Rapacity. The following intervals were perforated with 4-1/2" hyperjet holes per foot: 10,837 '-10,818'; 10,812'-10,802' and 10,797 '-10,793'. Ran 3-1/2" and '2-7/8" tubing to 10,880' with Baker model FH packer at 10,692' and Baker model F packer at 10,842'. Work was completed on July 22, 1971. The well was placed on production July 22, 1971, and remained at that status until November 27, 1972, when gas injection was initiated. The well has been on gas injection since that time and has been redesignated SRU 334-15. ~ 8IGI~ED _ /~3% - W. walker TITLE Area Superintendent March ~) , 1973 (This spacf/or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side t.'orm P - 7 SUBMIT IN DUYz, ICATE* STATE OF ALASKA (see (,tiler In- st ructions on OIL AND GAS CONSERVATION COMMITTEE .... evse side; WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF VqELL: W ELI. W ELL DR r Other b. TYPE OF COMPLE~ON: WELI, OVER EN BACK n~svm Other ,, 2. NAME OF OPERATOR 3. ADDRESS OF OPERATOR 5, AP1 NLrM.E~CAL CODE ~. L~S~, Dr, SIGNk~O~ m~D SER~. NO. ~. IF INDIAN, ALLOTTEE OR TRIBE NA~LE 8. UNIT,FA/IAI OR LF~kSE NAME 9, WELL NO. 10. FIELD AND POOL, OR WILDC&T 4. LOeaTION 0¥ WELL (Report location clearly and in accordance with any State requirements)* At surface 11. SEC., T., R,, M., (BOTTOM HOLE OBJECTIVE) At top prod. interval reported below At total depth 12. PE-'HNIIT NO. 18. TOTAL DEPTH, N~ & TVD[9, PLUG, BACK M & ~. ~ ~LT~LE CO~L., [ 21. INTERVALS DRILLED BY [ : [ HOW~Y* { ROTARY TOOLS I CABI,E TOOLS ~ ~' - , ', -~ O~- , O~O , NAM (~ AND ~)*' 23. WAS D!RE~ONAL ~ PRODUCING ;N~VAL~S) F ~TI N TOP M E SURVEY MADE I 24. Tt~PE' ELECTRIC AND OTHER LOGS RUN CASING RECORD (Report all strings set in well) 'GR~kDE. I DEPTH SET (MD) HOLE SIZE i J iii i i CEMLNTING RECO}LD A~/fOUNT PULLED 27. TUBING REC OFd) DEPTt-I SET ( MD ) 28.'~EI%FORAT[ONS Op¢_2~ TO PRODUC~OI~ (interval size and number) ' i i i i ii i PRODUCTION SCTLEEN (MD) [ SIZE , 1 29. ACID, St:OT, F;iAC't URE, CE&IENT SQUE_~Z~, ETC. ~ PA. CIf~ER SET (MD) G~%S--iViC F. WATEI'/~-B BL. GAS-OIL IIA. TIO WATER~EBL. [OIL GRAVITY-APl (CORR.) ,,, t TE~T WITNESSED BY "'33.'I hereby certify that the foregoing and attached information la complete and correct as determined from ali-available records 7- ~- ~'~ ........ *(See Instructions and Spaces I:or Additional Data on Reverse Side) 32. LIST OF ATTACHMENTS DATE FIRST PtiODUCTION [ PF~ODUCT1ON ME1HO'D (Flowimg. !~iaz lifL pump~lg--sizeand type of pump~ ~ [WELL STATUS (Producingor ~i U L- in ) C}IO!<E SIZE ]PEOD'N FO'~ OI~BDL. [d~V~"~TBiNG CA~m6 PRESSURE [CAL~TD OI~BBL. GA~-~,ICF. ' 1 ~1~ O~SP0S~TION OF CXS (Sold, used ]or Joel, v~ated, etc.) DEPI'Ii 1NTEtCtVAL (MD) AMOUN£ Z~'qD I.;AND OF MATE3~IAL USED INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all ty.,pes of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachme~ts. Items :20, and 22:: If this well is completed for separate, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~c. Jucing interval, or i~tervals, top(s), bottom(s) and name (s) (if any) for only the interv~l reported in ite~ 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produce.J, show- ing the ack:litional data pertinent to such interval. Ita, m26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately producsd. (See instruction for items 20 and 22 above). ii'/ OF FOH. MATION TE.~'I'S IN('LUI)IN(: INT~.RVAL T~.STED. pl~,~,sSUrtE DAT~ ~'~COVEltI~" OF O1~ GAS, WAT~ AND MUD HAME MiAS. ~t ~Ur V~T. ~ , DATA. 'Aq'I'ACI[ ~Hl~ D~~ONS OF LITIIOLOGY. PO~O~TY FRACAS. A~T ~IPS AND D~I~C~'EI) SIIt)WS OF OIL. G~ ~H IVA~I. ' Submit "Intentions" in Triplicate P~EV. 9-30-69 ~- & "Subsequent Reports"in Duplicate STATE OF ALASKA _ --- §. APl NUtVIERICAL CODE OIL AND GAS CONSERVATION COMMITTEE ' 6. LEASE DESIGNATION A_ND SEI~ SUNDRY NOTICES AND REPORTS ON WELLS use "AP~L~CAT~ON'FO~'/~'~P, iit't-~" '~or ~ue~ 'g~o~osal~0 A--028384 ...... 1. 0IL ~ GA8 Standard 0il Compan~ of California~ ~,O,l,, Swanson River Unit P.0. Box 7-839, Anchoraee~ ~aa~ gg~l~ SRU 34-15 ~t~.~ 2400' ~esc and 860' north ~r~ southeast co~ner S~anson River of Section 15, T8Ni R9WI SB&M 11. SEC., T., R., O~E~IVE) Sec. 15, T8N, R9W, 13 EI,EVATIONK I$haw whether DF. RT. GR. etc. 1~, P~T NO, KB 306' I 1, 41 t,~. Check Appropriate Box To I,ndicate Niature of N~tice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER 8HUT-OFF PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT OR ACIDIZE I I ABANDONS REPAIR WELL CHANOE PLANS ~Other) WATER SHUT-OFF J J REPAIRING WELL ~ s~OOT~NO o~ A~ID~'~INO I I ABA.~O~ME~TS (Other) In~t~at~oFof gas ~n]ect~on (No~: Report r~ult~ of multlpl, completion on W~ll Completion or Reeompletton R~port ~nd Bo~ form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Ga.s injec.tion into SRU 34'-15 was initiated on Novemb.er 27~ 1972. Initial gas injection rate was appr0xima~Iy 10200' MCF/D at 5500 psi,--tubing pressure. The well will be redesignated SRU 33'4'-15 while it is on gas injection. SIGNED (This speeder State office use) TITLE APPROVED BY CONDITIONS OF XPPROVAL, IF ANY: TITLE DAT~ /,Z -/ DATE See Instructions On Reverse Side Form P~3 /~'~ ~ubmJt "Intentions" in Triplicate STAT-~ OF ALASKA ~..A~ ~ O~',~-U¢~ co~.~ _'ir ...*--~'~'"" ..... .,,~_ ~ OiL AND GAS CONSERvATIoN COMMI~EE ' ,, ~!'" ~ ,~ .... SUND~Y NOTiCeS ~ND R~PORTS ON WEL~ (~ not u~e this form for proposals ~ dlil! or to dcepe~! or plug back to a diffierent re~, ,, ,,.. . , ~ d~ 'o~'ro~ ' ,. o~,~ o~ ~ss ~m i~-~OL ~ .... Standard Oil cOmpany of California~ W.'O.I. Soldotna Cre~ k { 2-GEOL-~' ~. w~ ~o. . P. O. Box 7-839~'Anchorage! .... Alaska 99510 SCU 34-15 ~ REV~' ~c.~:o~ o.~ ~,;,~b '~o. ~,.~ ~ ~oo~, o~ w~c.~ *t~ Swanson RiV~r [ ' -ul sec.. T.. ~.. ~.. (ZOTTOM HO~ CON~: ' 2400' West and 860' North from SE corner o~n~vm of Section 15, TaN, R9W, SB&M Section 15 ~[~: ' ~, . TaN, R9W, SB&M - , , ~EVAT1ON~ (Show whether DF, RT, GR, etc. [lZ. P~HT ~O. KB 306' 41 C~ck Appropriate ~x ~o ]ndi'~te Nalure o{ Notice, Re ~o~, or O[her Datm NOTICE OF INTENTION TO: Convert to gas injecto~ X i fUBSEqUENT REPORT OF: (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 1.5. DESCRIBE I'ROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estlmaled date of grafting an}' l;ropoaed work. Attached is a proposal to convert SCU well, to a gas injection well. These to accomodate a new 3400 hp compressor 34-15, a shut-in oil conversions are necessary currently being installed. Superintendent DATE See Instructions On Reverse Sido DATE ~oproved C,~i..,~, J~eturned WELL S6U 34-15 SWANSON RIVER FIELD MARCH 9, 1971 REMEDIAL PROGRAM PROPOSED WORK: Conversion to gas injection and test of sands i & 2. PRESENT CO~DITiONS: Total Denth: 11,190' Plugs: 11,090'-11,190' -Casing: 22" conductor cemented at 28' 11 3/4" 47~, J-5=~, SSrd, cemented at 2876' DV at 1359' casing cemented at 11,190' DV at 7978' Note: 13.5'. pup 10,745.5-10,759', E-log depth . 7" Casin? Detail (ProDose~ Detail) : ,,. Bottom 2,700' (11,190'-8,490') 29~ P-110 LSrd 1,800' (8,490'-6,690') 29% N-80 Butt DV at 7978' 1,800' (6,690'-4,890') 26# N-80 Butt 3,700' (4,890'-1,190') 23~ N-80 Butt 900' (1,190'- 290') 26# N-80 Butt Top 290' (290'- 0') 29# N-80 Butt Total 11,190' Perforations: 5 - 1/2" holes at 10,730'; WSO. Through tubing with 4 - 2 1/8" capsule jet holes/foOt 10,850'-10,892'. Tubing: Ail 2 7/8" EUE 8rd tubing as per "Casing and Tubing Detail" dated ~ 22-63. Datum: 15' above ground level at original K.B. elevation 306'. Junk and Condition of C~sing: No junk or bad pipe reported. BOPE CONSIDEKATIO]qS: ~eservoir pressure could be as high as 5300 psig. Class III BOPE will be utilized. D},¥1~;,V. DN OF ©!l. /.>~D GAS ANcHORAGe, SCU 34-~15 REMEDIAL PROGRAM MARCII 9, 1971 PRO G RAM: 1. Move in contract rig and kill well with 76-77 pcf clay base mud. This provides a hydrostatic pressure of 5725-5800 psig at 10,850'. (top of' perforations) 2. Install Cosasco plug and remove x-mas tree. Install and test to 3000 psig a Class III BOPE consisting of 10" Shaffer LWS series Double Gate and 10" Hydril Gk series 1500 preventer. 3. Remove Cosasco plug. Rotate tubing to release Brown HS-16-1 packer at. 10,759'. Pull tubing and packer.' Note: Have a "CC" retrieving tool on hand in case the "CC" joint at 10,750' releases. *Pull tubing slowly to avoid swabbing action. 4. · Run saw tooth collar on 2 7/8" tubing and attempt to clean out to top of plug at 11,090'. Run 6" bit and tandem 7" casing scrapers to effective depth. Circulate hole clean. 5. Rig up Schlumberger equiDment. Measure from collars and per- forate the following intervals with four hyperjet holes per foot: Interval Feet Shots 10,793 ' - 10 ~ 797 ' 4 16 10 , 802 ' - 10,812 ' i0 40 ' 10,818'-i0,$37' 19 76 Total 33 132 -- · Note: Set lubricator in bag. Run perforation log before and after perforating. · . 6. Run tandem 7" casing on 2 7/8" tubing and scrape casing to 10,900'. Pull out laying down 2 7/8" tubing. -7. Run gauge ring on wireline junk basket with casing collar loca- tor to 10~950' - run collar locator to 10,700'. Set a Baker "F" packer on wirelinc at E-log depth of I0, ~42' ; measure fro], collars · 8. Make up jewelry with hydraulic packer at 10,750'± on 2 7/8" ABC tubing as per the "Proposed Tubing Detail" to be furnished. }~ydrotest tubing to 6500 psig. ANCHORAGB · SCU 3'4-15 REMEDIAL PROGR. AM MARCH 9, 1971 PROGRAM: 9. Stab through Baker "F" packer. When the stop sub contacts packer, pick up one foot and land tubing. Install Cosasco plug. Remove BOPE and install 10,000 psig injection tree. Test tree to 6500 psig with clean water. 10. ~emove Cosasco plug and displace clay base mud with crude oil as directed by Production Foreman. 11. Run Otis PS plug and set in "S" nipple at 10,758'±. Pressure tubing to set the hydraulic packer; 12. Pull "PS" plug and release rig. 13. Produce well from both zones. o/s C. W. Wilson W. H. Fairfield J. W. Walker B. E. WONDZELL - . . . UNITED STATES DEPARTMENT OF 'THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS. Tl, e followin~ i, a correct repor~ of operatio~rs a~:,d prodz~c'tior~ (includin,~* arzlhr~ and producir~ wells) for the mon, tl, of .............. ~~ ............... Phon. e ..... ~~7__T:~_ ................................................. J~en.t's ti ~ - { i -- I { I {{'-'i ...... {'" { ........................................... { S_~oN ~~_~l~.~:~ ¢2) ' yater (2) all fe - J. B. erry itterI ow~rd~ No~.--There were ........................................ hms or sales of oil; ............................................. M cu. fL of gas sold; ............................................ runs or ssles of gasoline during the month. (Write "no" where ~pplieable.) No~.~epo~ on th~ form is requked for ~oh calendar month, mg~dless of tho status of operations, aud mus~ be filed duplicate wi6h 6he superv~or by the 0Ih of the aueoeediug mouth, u~s o[herwise directed by the supervisor. COMPLETION ~EPORT - PACKER AND GAS LIFT INSTALLATION SWANSON RIVER UNIT 34-15 Section 15 T. 8 N., R. 9W-, Seward B & M ~TANDARD OIL ccMPA~Y' OF ~AL~FOR~'"'~f~N O~h~T1ONS, 'TNC'. Ope~ator January 19, 1963: Commenced rigging up at 8:00 AM. Conditioned Black Magic Mud. January 20, 1963: Killed well, removed x-mas tree and installed BOPE. Pulled tubing loose and tagg- ed bottom before pulling out of hole. Ran casing scraper. January 21, 1963: Circulated and conditioned mud. Reran 340 joints 2 7/8", 6.5~, N-80, EUE 8R Rg2 tubing equipped with packer and mandrels. Tubing Detail K. B. to landing Donut Three 2' 7/8" Rup 46 Joints 2 7/8" Camco MM Mandrel 46 Joints 2 7/8" Camco MM Mandrel 41 Joints 2 7/8" Camco MM Mandrel 33 joints 2 7/8" Cam£o MM Mandrel 29 Joints 2 7/8" Camco MM Mandrel 26 joints 2 7/8" Camco MM Mandrel 22 Joints 2 7/8" Camco MM Mandrel 47 joints 2 7/8" Camco MM N~ndrel 46 Joints 2 7/8" he~d joints tubing w/ O tubing w/ D tubing w/ D (#3) tubing w/ D (#4) tu~ng tubing ~bing tub~ Camco MM Mandrel w/CEV (#9) 1 Joint 2 7/8" tubing Brown CC Safety joint One 2 7/8". pup joint Brown 2 7/8" X 7" HS-16-1 packer 2 joints 2 7/8" tubing Camco "D" Nipple 2 Joints 2 7/8" tubing Venturi Shoe Tubing landed at Januar~ 22, 1963: ~-emo'ved BOPE, installed K.B.' Depth 15.00' .85' 15.85' 10.15' 26.00' 1454.46 ' .~ 1480.46 ' ~.'" 13.05~ 1493.51' 1448.19 ' 2941.70' 13.02 ' 2954.72 ' 1299.43 ' 4254.15' 13.07' 4267.22' 1038.54' 530~. 76 ' 13.02' 5318..78' 915.O1 ' 6233.79' 13.04' 6246.83 ' 819.05 ' 7065.88 ' 13.10' 7078.98' 691.74 ' 7770.72 ' 13.12' 7783.84' 1466.54' 9250.38' 13.11' 9263.49' 1442.82 ' 10, 706.31 ' 13.11 ' 10, 719.42 ' 30.76' 10, 750.18' 1.05 ' 10, 751.23 ' 7.96' 10,759.19' 6.02' 10,765.21' 61.54' 10,826.75' · 93' 10,827.68' 61.10 ' 10, 888.78 ' .65~_ 10, 889.43 ' 10,889.43" x-mas tree and displaced mud with oil. 15,759' and returned well to production. Set packer at Rig released at 9:00 AM. sat S. R. Hansen PRODUCING DEPARTMENT TELEPHONE BR, 7--6201 C. V. CHATTERTON DISTRIC~T SUPERINTENDENT P. O. BOX 7-839 · ANCHORAGE · ALASKA "RECEIVED' / "~ JAN 15;. ~ 1062 ~ C 9 ~ F I D ~. i',~ T I A, .~ ~ Pefroleum Brench //~l~sk~ Dept. of N~tur~J Resources Mr. D. D. Bruce State Department of Natural Resources Division of ~nes & ~nerals P. O. Box 148 Anchor~ge~ Alaska Dear Mr. Bruce: Attached~ he~with~ is the Completion Report for well Swanson River Unit 34-15 for your information and files. Very truly yours, C. V. CHATTERTON Attachment UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. Approval expires 12-31.Gk LANO OFF,CE _._&nc. borage LESSEE'S MONTHLY REPORT OF OPERATIONS The £ollowin~ is a correct report of operations and production (inchedi~,~ drilli~ and producin~ wells) for the mor~th of Au~st 1,9 61, Swanson River Unit ........................ ~ ......................... St~d~d Oil O5,-~"0~I~; .... ~e~,t's address ..... P- ._ .Q,___BP~ 7- 839. ....................... Co ntpa~y.__W~tern ~er, ti~,.---tno. ........ Pho~ ........................ BRo~~. 7-b201 ............................ ,f~ent's ¢,~tlc D~t.._Sent. ~..~! ~ ~k~ ~ _---. i{ANGE \VELL DAYS ] ~EC.1/i oFANDI/~ 'PWP. IVO' IBARF. EL8 OF OIL ' SY; (22) 1\' ATF~ (If I [ GALLONS (~U. FT. OF OAS G r. AV~I~' (In thousands) G^SOLIXE ~FCOVEiIEI) 15 IIEMARKS (If drilling, depth; ii M~uL dvwn, cause; date and reault el t~t for g~ollno coutont of gas) Ram Neu6ron - Collar Log 11,087~ - 9,OO0'. 11,O87~ - 4,O00~. ;Ran WSO Test ~5 10,730'. to bottom° Circulated eut mud with oil. Pulled uo and landed tubing ~ 10,741~o InStalled and tested %-mas tree to 3500 nsi. Held OK. Pe~"forated 4 - 1/2" holes/foot, the interval 10,~50' - 10,892'. Flew tested well. Representative ~low rates: 360 B/D oil, h7 iMCF/D Oas, 8/614" Bean, 1180# T.P., 1020# C.P., 55 Trap. Press. 1.~% total cut, 0.3% water, 0.7% emulsion, Corr. Ora .vity 32.4° Ri~ released 8-4-61o CC U.S!.C.S. - M. o o Richfield - C Ohi~ - GeO. S. UniOn - C. E. Filbs: Produ, Explo: Land H. SOyster ]C - O. D. Bruce! W. ~erry- R. ~ards I lng i .ation R. Ritte~ I Cement Bond Log WSO OK. Ran 2 7/8" tubing NoTe--There were ...................................... runs or sa]cs o.~ oil; ................................................. M cu. ft. of gas sold; ') (Wrh. c "'" . runs or s:~.lcs of gr~r~line duplicate with the ;qupezvi:;or l)y tim Oth ut' t, Jle succeeding ~;~tth, tmlcss o~hc,:wisc direct,,,l },v (January 1950) RECEIV[D STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. - OPERATOR AREA: Kenai Peninsula, Cook Inlet Area, Alaska PROPERTY: Swanson River Unit LAND OFFICE: Anchorage Lease No.: A-028384 WELL NO.: SRU 34-15 Section 15, T. 8 N., R. 9 W., Seward B & M LOCATION: 2400' west, 860' north from southeast corner of Section 15. ELEVATION: 306' K.B. DATE: December 18, 1961 K. B. is 15' above ground. · / s:~ : ,~.,. ,.. ;.' ,., ,.~ .' ../ ,..' ,. / z>" ",.';" ,' ...... - ..... :-~';~ .......'"' ~ ~ .... ,.,~ ' ~ ,,"z'~ j., ,~.;.~,-...' C~'¥.-'C~RTON, ~strict Supt. DRI~.T~D BY: Coastal Drilling Compan~ (Rig No. 4) DATE COMMENCED DRILLING: June 21, 1961 DATE COMP~ DRILLING: August 4, 1961 DATE OF INITIAL PRODUCTION: August 8, 1961 PRODUCTION: Daily Average 498 B/,D ....... .............. 60 Flowing Gra~rity .... 32.2° TP ......... 1000 psi Bean .... ... 10/64" SUMMARY TOTAL DEPTH: 11,190' PLUGS: 11,090 - 11,190' JUNE: None CASING: 22" conductor pipe cemented at 28'. 11 3/4" cemented at 2876' with 1800 sacks of cement. 7" cemented at 11,190' with 1900 sacks of cement. First Stage with 700 sacks around shoe. ~e-CO~d"~tage with 1200 sacks through DV Collar at 7978'. COMPLETION REPORT - PACKER AND GAS LIFT INSTALLATION STANDARD OIL COMPANY OF CALIFORNIA, ~TERN OPERATIONS, INC. - Operator AREA: Kenai Peninsula, Cook Inlet Area, Alaska PROPERTY: Swanson River Unit LAND OFFICE: Anchorage Lease No.: A-028384 WELL NO.: SRU 34-15 Section 15 T. 8 N., R. 9 W., Seward B & M LOCATION: Surface: 2400' West and 860' Nor%h from Southeast corner of Section 15. ELEVATION: 306 ' Ko B. DATE: June 28, 1963 BY: K.B. is 15' above ground. ,,"7/1 ... ! _ ~ i/, ,~~~.~~ o .~://~-~, C'~T~TON, DiStrict S~perintende~ -- CONTRACTOR: Santa Fe Drilling Company, Rig #35 DATE COMMENCED REMEDIAL WORK: January 19, 1963 DATE CGMPLETED REMEDIAL WCRK: January 22, 1963 TOTAL DEPTH: 11,190' CASING: 22" cemented at 28 ' 11 3/4" cemented at 2876' 7" cemented at 11,190' PLUGS: 11,090' - 11,190' COMPLETION F~PORT SWA~SO~ RZ~Fm roUT S~ S~A~ O~L c~A~ OF ~FO~, W. O. ~. - Page 2. PERFORATION RECORD: .iff · 5 ' 2 holes at IO,?SO' 4 -½" holes/foot, inerval 10,892 - 10,850'. WELL SURVEYS: 1. Schlumberger Induction-Electrical log, interval 100 - SO10' 2. Schlumberger Sonic Log, interval 100 - 3005' 3. Schlumberger Induction-Electrical log, interval 2876 - ll, 182' 4. Schlumberger Sonic log, interval 2876 - ll, 179' 5. Schlumberger Microlog-CaliDer, interval 10,182 - ll, 182' 6. Schlumberger Continuous Dipmeter, interval 2876 - ll, 185' 7. Schlumberger Neutron-Collar log, interval 9000 - ll, 087' 8. Schlumberger Cement Bond log, interval 4000 - ll~O~O' 9. Baroid Mud Log, interval 9000 - ll, 190' 'DRILL STEM TESTS: WSO Test on 5 ½" holes at 10,730'. (WSO) Page 3. Spudded at 10:45 P.M. Drilled 12-~'' ~ hole 0 - 78' June R2, 1961 . Drilled 12~" hole 78 - 1, 61~7' Opened 12~" hole to 17½" 0 - l, 647' Drilled 16" hole l, 647. - 3, Oll' Conditioned mud, prep. to log. June 24~ 1961 78' drilled l, 569 ' drilled l, 647' opened l, 364' drilled 78 per mud 78 per mud 78 p cf mud Ran Induction-Electrical Log, interval lO0 - 3, OlO'. Sonic log, interval 100 - 3,005 ' · Reamed 16" hole with Security 6 pt. reamer 1, 647 - 3,011' 1, 364' reamed Circulate and condition for surface casing. Cemented 11 3/4" casing at 2,876' in two stages with 1800 sacks of cement treated with O. 3% HR-4 using Halli- burton power equipment. Used 1 top and 1 bottom rubber plug. .lst' Stage~ around shoe with 500 sacks of cement. Pumped 50 bbls. of w~ter ahead, mixed 500 sacks of cement in 1~ rains, using Halliburton truck, displaced in 23 rains, using rig pumps. Average slurry weight 116~. Bumped plug with 1325 psi. Full circulation. COMPLETION REPORT SWANSON RrCER UNZT' SRU 3~-15 SECTION 15, T. 8 N., R. 9 W., SEWA~ B & M s~~ ~oi~ ~C~A~ "o~ '~~0~~' ~W, O' iix'.~' .i Page ~ through DV at 1, 359'- Dropped DV bomb, opened DV ports in l0 mine. Pumped 50 bbls. of water ahead, mixed l~ 300 sacks of cement in 34. mine. using Halliburton truck, displaced in 11 mine. using rig pumps. Average slurry weight 116~. Closed DV ports with 1750 psi. Cement in place at 3 A.M., June 25, 1961. Casing. Detail :. .: .. .~,lU . Full Circulation. 70 Joints or 2,874.02' Below K.B. 2 Casing landed at 2~876.02' 11 3/4.", 4.7':~, 8 R, equipped with' Baker guide shoe and Flexi-flow collar and Baker D.V. collar at 1359' · 539' drilled 4, 644' drilled Cut mud weight 95 - 88 pcf. 185' drilled Cut mud weight 95 - 84 pcf. 75 pcf mud 73 - 96 pcf mud 95 pcf mud Installed Bmroid Mud- June ~6i 19,61 Drilled lO 5/8" hole 3,011 - 3,652' Drilled 9 7/8" hole J.une 27._... July 12._1~61 Drilled 9 7/8" hole 4,191 - 8,835' Gas cut ~d at 8,721'. July 13,_ ~961 Drilled 9 7/8" hole 8~835 - 9,020' ~s cut ~dat 8,~'. lo.rig U~% a~ 9,000'. 641' drilled Installed casing landing head and tested to 3000 psi for 30 mine., OK. Tested BOPE and Kelly Cock to 1500 psi, OK. COMPLETION REPORT SWANSON RIVER UNIT SRU s~cT~9~ 15, ~. _8 N., ~.~ 9 w., STANDARD OIL CO~A~ OF cALI~0~ Page 5. O~lled 9 7/8" hole 9,020 -. 9,285' Gas cut mud at 9,250'. July 15 -.July 22, 1961 Drilled 9 7/8" hole 265' drilled -Cut mud weight 95 - 91 pcf. 9,285 - 10,293' 1,008' drilled 15' drill pipe measurement correction 10, 211 to 10,196' ~uly 2L 196~ Drilled 9 7/8" hole 10, 293 - 10,425 ' 132' drilled July ~,~.!96~ Drilled 9 7/8" hole 10, 425 - 10,440' 15' drilled Started losing Mixed l0 sacks Drilled 9 7/8" hole 10,440 - 10,567' 127' drilled Lost approximately 30 bbls. mud on P .M. Tour. 15 bales Cell-o-Seal. July 25,~ Drilled 9 7/8" hole 10,567 - 10,594' 95 pcf mud 96 - 98 pcf mud 97 pcf mud 97 pcf mud circulation at 10,440'. Lost approximately 75 bbl. mud. Micatex and 14 bales Cell-o-Seal. Regained .circulation. 97 pcf mud Mixed 20 sacks Micatex and 97 pcf mud 27' drilled 96.5 pcf mud Mixed lost circulation material and regained Lost circulation at 10,594'. partial circulation. Ran in with bit and broke circulation mt 4, 557' and 7400'. Circulated at 10,594! with 94 pcf mud. Gas returns from 7,000' at 1500 units, gas returns from bottom at 1800 units. COMPLETION REPORT SWANSON RIVER m1IT SRU 34-i5 STANDARD OiL COMPANY OF CALIFORN~, W. O, i ~ ~ OPERATOR Page 6. Drilled 9' 7/8" hole 10, 59~ ' 10,625' 31' drilled July .26, 1961 Drilled 9 7/8" hole 10,625 - 10,807' 182' drilled July 27,_ !961 Drilled 9 7/8" hole 10,807 - 10,935 ' 128' drilled Gas returns from 10,824' at 1300 units. uly 28, 1961 Drilled 9 7/8" hole 10,935 - 11,050' 115' drilled July 29,. 1~6! Drilled 9 7/8" hole 11,050 - 11,190' T.D. 140' drilled .Conditioned mud to run logs. Juk¥ 30, _1961 95 pcf mud 95 pcf mud 95 pcf mud 95 pcf mud 95 p cf mud Ran Schlumberger Induction-Electrical Log, interval 2,876 - 11,182'. Ran Schlumberger Sonic Log, interval 2,876 - ll, 179'. Ran Schlumberger Microlog-Caliper, interval 10,182 - ll, 182'. Circulated and conditioned mud for Dipmeter Survey. Ran Schlumberger Con- tinuous Dlpmeter, interval 2,876 - ll, 185'. Released Baroid Mudlogging Unit, logged to ll, 190'. CoMpLETION REPORT SWANSON ~IVER U~IT SRU. 3~-15 S~~ OiL C~~ 'OF ~FO~' W~.'.-0. I. - O~TOR Page 7. Completed Dipmeter Survey. Laid down drill pipe. · Cemented 7'" casing at ll, 190' in two stages with 1900 sacks of cement treated with O. 3~ HR-4 using Halliburton power equipment. Used i top amd i bottom rubber plug.. lstS~ around shoe with 700 sacks of cement. Pumped 50 bbls. of water ahead, mixed 700 sacks of cement in 25 rains, using Halliburton truck, dis- placed in 60 rains, using rig pumps. Average slurry weight 116~. Bumped plug with 2500 psi. Partial circulation. 2nd_~ through DV at 7978'. Dropped DV bomb, opened DV ports in 40 rains. Pumped 50 bbls. of water ahead, mixed 1200 sacks of cement in 33 rains, using Halliburton truck, displaced in 26 rains, using rig pumps. Average slurry weight 116~. Closed DV ports with 2500 psi. Full circulation. Cement in place at 5:15 A.M. August 1, 1961. Hookload weight of casing before cementing 210,000, after cementing before landing casing 200,000, and at time of landing casing 200,000. August 1,. 1961 Installed and tested tubing head to 3000 psi, OK. Reinstalled and tested BCPE to 2000 psi, OK. Picked up 2 7/8" tubing. Drilled out DV collar and tested DV to 2000 psi, OK. Circulated and condi- tioned mud to run logs. Ran Cement Bond Log, interval ~000 - 11,080'. Ran Neutron Collar Log, interval 9000 - 11,087'. Shot 5 - ~" holes at 10,730' for WS0 Test ~1. Halliburton WS0 Test ~1 on 5 ½" holes at 10,730'. Tool Assembly: 2 outside BT recorders, 6' of perf'd tail pipe, 7" Type "C" hookwall packer, VR safety Joint, hydraulic ~ars, 2 inside BT recorders~ . hydrospring tester and T.C. valve. Used 2744' of W.C. Ran on 10,665' of 2 7/8" E~E tubing. Set packer at 10,681', with 17' of tail to 10,698'. No Initial Shut-in pres- sure. Opened tool to surface at 6:20 A.M. for 60 min. flow test. Faint blow to dead in 20 rains. Dead ~0 rains. Shut in tool at 7:20 A.M. for 30 min. FSI pressure. Pulled packer loose at 7:50 A.M. Recovered 20' net rise, all drilling fluid. STANI~ OIL CO~PA~'~CF CA~FORN~" '~w:~O.I'. "oPERAToR Page 8. Pressure Data: (Final Pressures) Depth IF FF FSI FH .Top inside (10,676') 7019 1249 1249 Bottom inside (10,681') 7018 1251 1251 Top outside (10,694') 7087 1258 1258 Bottom outside (10,699') 7018 1235 1235 ~355 7o19 138o 7o18 1387 7087 1365 7018 August 3~ 1961 Ran 2 7/8" tubing to 11,090'. Displaced mud with oil. of water. Landed tubing at 10,742'. Preceded with 50 bbls. Tubing Detail: 341 joints 2 7/8" tubing Marker pup $ joints 2 7/8" tubing Landing joint In cellar 10, 599. ~6' ~+,00' 123. Ob~ ' 2.00' Landed at 10,741.60 ' Removed BOPE. August, i~,I 196~ Installed X-mas tree. Ran Schlumberger capsules and perforated with 4 - ~" holes/foot through tubing, the interval: 10,892 - 10,850'. Installed X-mas tree and tested with 3500 psi for 5 mins., OK. Commenced dis- placing mud with oil. Pumped 50 bbls. of water ahead, followed by crude oil. Formation oil to surface at ll:00 A.M. Flowed oil to tank until 1:45 P.M. Started flowing to trap at 1:~5 P.M. Representative flow rate and cuts as follows: Flow Rates Bean Tbg. Csg. Trap Flow Period oil : :ks Size Press. Press. Press. 1. 3/4 Hrs. 768 B/D 121 MCF/D 16/64" 60C$ 50C$ 2. 3/~ Hrs. 360 B/D 47 MCF/D 8/6~" 118o~ lO2~ ~ Total .Cut ~_Mat~eT ~._~E~mu!si~n ~ Sand..& ~ud Corr. Gravity 1. 1.6 0.8 0.8 Trace 31.6° 2. 1.0 O, 3 0,7 Trace 32.b~o COMPLETION REPORT S~kNSON RIVER UNIT SRU 34-15 SECTION 15, T. 8 N., R. 9 W.~ SEWARD S~A~~ 0~ ~'Co~A~0F'"~~0m~,~ w-~ Page 9' Shut well in at 3:30 P.M. Shut in pressures; Tbg. press. 1450 psi, Csg. press. -.1300 psi. Produced estimated 1~ bbls. formation oil. Flowed 212 bbls. to tank. Installed Cosasco plug. Rig released 4:00 P .M., August 4, 1961. SRE: lo COMPLETION REPORT SWANSON RIVER UNIT SRU 34115 SECTION 15, T. 8 N., R. ~ W., SEWARD B & M ~~~ ~OiL' cOMPA~ ~'OF' ~FO~ 'W~ 'o~ i'-~' ' OPERATbR Page 10. DEVIATION DATA 831' 1,640' 4,180' 4, 600 ' 4,909 ' 5,370' 5,904" 6,8~4' 8, 805 ' Degrees _ 0° 30' 0° O0 ' 0° 15 ' 0° 30' 0° 10' 0° 50 ' 0° ~0' 0° 25 ' 1° 10' 1° 45' 5 UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY f~.~ Budget Bureau No. 42-R356.5. Approval expires 12-31-60. L^No Omc~.... ~,nchp_r..a_ge u.,'r ............... _Sj.'~.a..n. ~_o_.n.. _ ~%.v. ~..r_ _ LESSEE'S MONTHLY REPORT OF OPERATIONS State ........ _A_i_a__s_k_a_ ............... Coz~n, ty_ Ke_n_ _0£_ _ _P_e_ _ai~_,_~_a ..... Field .......... _~._~._~.Qg__i~iY.~_F. ............................ ~7~e followin~ is a correct report of operations and production (incl~din~ drillin~ and producin~ wells) for the ~o~th of ........... J_~Y ...................... ~9_ ~'~_ .......... ?,'_~nsp~) ._R~V.~_~._lJ_~_t ............................. Pho~ BRoadway 7-6201 ..................... ~,~nt'~, ~/ ................................................ S~c. Axv ] ~ [ [ i , I~EMARI(~ . i W ~[~ (If [ (lf',lrillir:,~. ,l,~tI: f~ ut d.wn, cauee; ~VEI,L D~S [ ]~A~RELS OF OIL .~RA¥ITY "" ~ ~ '~'t - ~ ~ f.~..t:Ol :.:E ~,,~ ~ I ~'~' ~:o. ~ .......... ".":k_L:l'~:~ I .......... ............ ~ .... ] .................................. 15 8~ ~ ~3i!lod 9 7/~" hole 65~9~ - 11190' T.). Ran ~icr6 Log ~ o*~r i~erval 11182' - ~0132q. R~ I-~ ~og II182~ - 2~76'. SW~ S~nic Log 11179' - 2876~. Contiauous Diameter !1i28~ - 2876'. SE~ ~ ~ cemented 7, casin~ at lll90' witb~lqO0 saoks of cement, sa~s around Shoe md 1200 t~ough D.V. at 7978~. ce: U.S.G.S. - M~rwin :.. Soyster (2) Alaska 0 & ~CC -~D.D. Bruce Richfield Oi~ Cor~. - C. W. Perry J I ] R.R. Ritter OHio Oil Co. - Ge6rge Sowards Union Oil C~. - Ci E. Smitht F!les: Pro~ctng ] g:op~orati~n I NorE.--There were ...................................... runs or sales of oil; ............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during thc month. (Write "no" where applicable.) NoT~.~Repor~ on ~his form is required for each calendar month, regardless of thc status of operations, and must be filed in duplicate with thc supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) 16--25766'-8 u, s. aOV£[~h~EN'r OnlY?lNG OFFIC£ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. 42-R350.5. Approval expirvs Anc ho~ age .' LESSEE'S MONTHLY REPORT OF OPERATIONS State ....... _A__I_.__a~_._~_ .............. Co ~r~ ty __K_ea_a__i. __P. eninrul a_ .... Field .............. ~l~liJ~.ozi _tl:kYe~- ......................... T/,e followi~o~ is a correct report of operat~o~zs a~d prod~ct~o~ (f'~cl~dl~ drfllf~ a~d producfn~ wells) for the mo~,th, oJ'_ ......... ~0 .......................... 19_~1, ........... a~on.~wr._~ ..... ................. ....... . 'lEO A';D I ' P ~ ~ ~"Ei - ~':'~ ~ ....j ~RREL3 U~ ~ ~i~--~Y (1'~ '"6TM v.'lg~ I ' , I , 1 g ~ ~'1II') ' "':' ~ ";~ .t~ ~ , ' i ' 1W I I~AN~ *~ I~[o --, ~ I ,t,. u .... , . ir(~ VEIl' D 15 8N ~[ Sgudded J~e 21. Drilled 12-{* hole 0 - 1647'. ~ened 12-}" ~ h01e to 17-}" $ 1647~.~ Dril~d 16" hole 1647 SW~ ; I*~ Log 3010' - l~',~and So~c.Log 3005 - 1,~o Ce~nted SE~ ~ 11-3/4" casing ~ 2876' with 18~ sacks in two stageso 500 ~ sacks aro'~d shoe~ and L300 sacks t~o~h p.V. ~ 1259'o Tested ' h~ad w/3000 psi - OK. Tested BO~ ~d Kelly Cook - OK. Drilled 9.7/8" hole 3011 ', - 65~.~9 '. O0 ! U.S.O.S. - MIrwin tt. Soyster~, (2) Al~_~ka 0 &_/}, CC - ~ ~ ', R.R. ~it~r Ohio Oil_ Coo ~- Ge&ge S~dS U~on Oil Col - Files: Pr ~hc~gl ExplOratiOn NoT~..--There were ....................................... runs or sales of oil; ............................................... M cu. ft. of gas sold; ....................................... runs or sales of gasoline during the month. (Write ":m" whcre apt)licable.) No~E.~Report on this form i's required for each calendar month, regardless of the sw~tu, of operations, and must. be filed in duplicate with t. tle supervisor by ~he 6th of the succeeding month, unless otherwise directed by ~he supervisor. ~orm 9-329 ~ 16---25706-$ U. S, GOVERNMENT pPlNTING orrlcg (Jauuary 1950) Go. of ~. (¥~. BudvK Bureau No. ~3-Ra~IL4. Approval expire~ l~-$1-fl0. , ~--~ ..... ~ (SUBM~ IN TRIPLICATE) { ~ ~ ~ ~ DEPARTMENT OF THE INTERIOR 0., __.S~~~ ..... ~ , 1 61 SUNDRY NOTICES AND R PORTS ON ~QU~ ~RT NOTJc~TICE ~ ,N~NTiONIN~T~ TOTo C~ WA~"~$~T~FF ........................ .............. JJ'-'t ..... ~. SOLVENT .~ ~ ~1~ ~1~ ...................... J ...... ~Ti~ OF mT~TIO. TO ~~ W~ ........................ j ....... ~ ............................................................................... .............................................................................J (INDICAT~' ABOVE IY C:HIK:K MARK NATURE OF REPOET, NOTICE, O~ OTHER ENIk"FA) Well mo.S__~. ~._~.~_~__ {s locate~_ _86__0_ __ ~. from__ {~} '~ne and .~h~ ~ ~, ~a ~. No.) (Twp.) (R~e) (M~dl~) Sw~son ~yer K~ Pentn~a Alaska ............................................................................................................................................................ (F~) (Coon~y or Subdivision) The elevation of" ~- ~ ~-~ -- -- m~-~.~mxa~ve s~ level is .... ~__ ft. DETAILS OF WORK ~intt, a~ ~l ot~ [m~nt ~ 1. D~ril! to 3OO0', leg and cement 11 3/}t" casing. Bring oement t~ 8~rface. 2o In~%all and test Olass III BI~o~t Prevention Equipment. 3. Drill ahead t~ approximately 11,200'~ leg and cee~n% 7" easing. 4. Reinstall BOPE ~ establish water mhut-offs a~ reqaire4. 5. Selectively Jet perforate attractive samds ar~ oomplete ~ith 2 7/8" tubing. (This ~tice wab~i%te~ ~ y~a N~vember 1, 1960, and va~ approved #owmber 4, 1960. However, n~tiee ex~ired prior to time ~11 is to be 4tilled. ) APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK 'APPLICATION. T& DRI'LL.~. DEEPEN [] PLUG BACK [] NAME OF ~0MpAN~ . ..... ':- ' ' : .... · ~ : ~ Dt]SCRIP~PI01~" OF ~VELL AND LEASE . - ' '~_:. , ". .'~c Name of lease ~ W State Elevation (ground) , ~Vell location (give footage from section lines) Section--township--range or block & survey Distance, in miles, and direction from nearest town 6r Dost office Nearest distance f~'0m-~vo~;se~ 5~ad;~n .......... ~- ~istance from proposed location to nearest drilling. to property or lease line: completed or a9plied--for well on tho same lease: Proposed depth: Number of acres in lease: Rotary or cable'toolg Approx. date work will starl Number of wells on lease, including thi8 well. completed in or drilling to this reservoir: If lease, purchased with one or more wells drilled, from whom purchased: Name Address Status of bond Remarks: (If this is an application to deepen or plug back, briefly describe work to be done, giving present producing zone and expected new producing zone) CERTIFICATE: I, the undersigned, state that I am th~,~.~_ of the --- -~:~-- -- - - -' -" -~i~ ~' (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 ar~ true, eaq'ect the best of my knowledge. Permit Number: ~ 1 Approval Date: Approv~d~,.~_l~OV 4 ~.Qg~ ........ N°Uce ' seaeBnneej~[~irmu~u~c~io~na ~e~iO.:~o~sa;Ns~dmerao~ ~oerSomurces and complete to Signature Alaska Off and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. I Effective October 1, 1958 (Feb. SUNDRY (S{~tlMIT 1.¥ TRIPLICATE) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY NOTICES AND REPORTS ON WELLS NOTICE OF INTLNTiON TO DRILL NOTICE OF INTENT ION 70 CHANGE P! ^NS NOTICE OF INTENT ION TO TF~T WATL~ gf:Ll T-Of r NOTICE OF IN]ENI:ON ~O R[ DqILL L:u REi A!:~ '&ELL NOTICE OF INTENI'ION lO SH(/~; ~. :," IDiZE NOTICE OF INTENTION IO PULL OP ALTE~ CASING NOTICE OF INTENTION TO ABANDON ~ELL SUBSEQUENr RFPORT OF WATER SHUT o{ ~ SU.qSEQI~E:,T REPORT OF L, HGOIING OR ACIDI.L;N6 SUBSEQUENT REPORT t; Al TERIkG CASING .. SUBSEQdENT KEf'ORT , [ RE-DRiLlING OR REPAIR : SUBSLQiJENT REt'3~<~ O~ ABANDONMENT SUPPLEN~ENTAR; ~ELL hiSTG~Y .:%DICATF'AHC) vEB{Ctd[('~ I~.'~.~,. fiATU~E OJ: t;I:PONI' 1'40' C~ C)tr'~ OTHER DATA ~ovember 1 Well NoEi~/ 31t-15 is L.,-:,t, / 8(~ ft. ,,(,n., .cJ~I~ !i,,~e and :L:~ ft. [rom ~ ~,~-o.,~,~ ~e. ].5 T. 8 I. a. 9 w. ~'.~,~..Is & a ,L , ¢ ~ . - , . · - .,,: ~.~. Ti~e devation of ti,, ~ ~bove ~ca levd is ~5 v} NOV 10 1980 DETAILS OF WORK Oil & Cas Section Division of M/nes and MineraI$ (Stat 2. I~stall a~l test Cla~s III Blo~ut Prevention Bqull~nt. k. ~eleetivel~ Jet ~erforate attractive ~ a~A ~eat a~ aeces~ary. | underetand that thi~ plan of wo, k n,ust reces,e approve| in writing by ;ha L. eoiogi, vi :'ursey {Before operahon. ,,, ,y be cun,rnenr, ed. Compan~ S~ 0LI. C~A~ OF CALIFOBI~A, ~ C~ATIO~, I~Co Address P. o. ~ox 7-839 An~ora~, Alazka ,,3
