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Home My WebLink About160-028STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑� ' Suspended❑ 20AAC 25.105 20A C 25.110 GINJ ❑ WINJ ❑ WAG[-] WDSPL ❑ No. of Completions: ib. Well Class: Development Q 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: • 160-028 / 319-138 3. Address: 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 7. Date Spudded: 8/16/1960 15. API Number: 50-133-10123-00-00 ' 4a. Location of Well (Governmental Section): Surface: 1865' FNL, 745' FWL, Sec. 09, T7N, R9W, SM • Top of Productive Interval: N/A Total Depth: 1865' FNL, 745' FWL, Sec, 09, T7N, R9W, SM 8. Date TO Reached: 9/29/1960 fl6. Well Name and Number: Soldotna Creek Unit (SCU) 312-9 9. Ref Elevations: KB: 1, . GL: j�U, 7 BF: 17. Field / Pool(s): Swanson River Hemlock Oil / Tyonek Gas 10. Plug Back Depth MD/TVD: VMD / 0' TVD 18. Property Designation: FEDA028997 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 343077.7 • y- 2454132.0. Zone- 4 TPI: x- y- Zone- 4 Total Depth: x- 343077.7 y- 2454132.0 Zone- 4 11. Total Depth MD/TVD: . 10,785' MD / 10,785' 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 L (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 MDITVD: 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 AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" Surf 37' Surf 37' 13-3/8" 54.5 K-55 Surf 2,980' Surf 2,980' 17.5" 1000 sx+600 sx 7" 23, 26, 29 N80 P110 Surf 10,785' Surf 10,785' 9-7/8" 750 sx+ 750 sx 24. Open to production or injection? Yes ❑ No ❑✓ If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): rA Ilpa4l& DA TE I7Aig _32-41VERIFIED -tom- 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 completion? Yes No � Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 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 (corr): Form 10-407 Revised 5/2017 �er F7 ., /J �/117`� CONTINUED ON PAGE 2 RBDMS A4/OCT 0 9 2019 Submit RIGI/NyIAL only 28. CORE DATA Conventional Corals): Yes ❑ No ❑� . Sidewall Cores: Yes ❑ No Q If Yes, list formations and intervals cared (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 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. I 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: tkramer*hilcom.com Authorized 7a) 1,, o'6&& / Contact Phone: 907-777-8420 Signature: r P o. r, DateS 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 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only D River Well S SCHEMATIC Well CU 312-09 Hilco- Alask -LLC C a s i n a & T u b in g RKB =17.20' TM. 31>�g 2 \& 3,125'- 3,329' i) Tac 41E0' 4 Ca C. 4]14' 5 r w. 7 1 x Tam cmt get @ rate' TD -/0,785' PBTD-0' Max Deviation = Y Q 5,931' Size Type NN't Grade Thrd LD Top Btm I I Hole colt Cmt To 20" Conductor I Surf 37' CIBP w/ 160' cement to surface 4/29/19 Yes Surf. 13 3/8" SurfCsg 54.5 K-55 12.615 Surf 1509' 17.5" 1000 sx Surf DV Collar 1509' 1512' 3/8" Surfcsg 54.5 K-55 4,181'— +/- 6,723' 12.615 1512' 2980' 600sx (Cal00�ed) 7" Prod Cs 8 29 N-80 Butt 6.184 Surf 250' 9- 7/8" 750 sx Th. DV ® 8504' 5700' CBL 7" 26 6.276 250' 1179' 7" 23 6.366 1179' 4798' 7" 26 6.276 4798' 5756' 7" 29 5756' 7238' 6.184 7238' 7242' 7242' 7284` 7" 29 Butt x 8rd 7" 29 8rd 7" 26 P-110 6.276 7284' 8504' DV Collar 4.5 8504' 8507' 7" Prod Csg 26 P -I 10 6.276 8507' 9315' 750 sxs 8187' Calculated 7„ 29 6.184 9315' 1Q785, Tubin Kill Stria 1220' RKB to Tbg Hngr 2 7/8" Bun 6.4 N-80 IBT1 2.441 Sort 3,757' Fish Detail NO. Depth ID OD Item 1 160' AIH CIBP w/ 160' cement to surface 4/29/19 2 3,120' 72717 CIBP .1420' cement on to OC 2 700' 427/19 3 +/-4160' 7,775 8" Piece of casing recovered durin fishin o rations 4 4,181'- +/- 4,418' Squa ed 17/04 Cement 5 4,181'— +/- 6,723' 4.875" 4" XT39 drill pipe w 14-718" tool'oiots & 1-1/4" cement stinger 6 +1-6,140' 55 Milling shoe fragments, 1-7/16"x6" shot rod hanger w/ 3/8"x8' shot rod attached Fish in Drib i e 7 7203' 6.0" Cement retainer 81 7,325' 6.0157" 7" HES FasDrill composite Bride Plug PERFORATION DETAIL, I I Arxmm TOP Btm AIH spf Comments 7,264' 72717 6 6 Sgld &isdated 1021/08 7,775 7295 20 6.0 Squa ed 17/04 10,165 IQ166 1' 5.5 P&A'd 10,183 10,238 55 4.5 P&A'd 10244' 10,255 11' 4.5 P&A'd 10275 10,337 57 4.5 P&A'd 10,344' 10,403 59' 1 4.5 P&AA 10,408 1 10,421' 13' 1 4.5 JP&Nd 10,425 10,444' 19 4.5 P&Ad 10,460' 10,5X1 60 4.5 P&A'd 10,526 10,546 20 4.5 P&Nd IQ557 10,558 1' 5.5 P&A'd Updated by DMA 09-06-19 Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 312-09 50-133-10123-00 1 160-028 4/25/19 1 8/26/19 Daily Operations: 04/25/2019 - Thursday PJSM. Location walk around. Rig down HAK 401 from SCU 24313-04. Fold up Pit liner. Rig up Hak 401 on SCU 312-09. Slip and cut drill line. Change contactor switch on Accumulator electric pump control box. Fill wellbore with 5bbls of KCL. 04/26/2019 - Friday PJSM. Location walk around complete. Fire equipment. Check well 0 psi tubing 0 psi IA. Wellhead tech on location. Set BPV and blanking sub. Nipple down Tree. Nipple up 7" BOPE stack. Change out slip inserts to 2-7/8". Locate MYT elevators. Continue nipple up 8' riser and stack. Install choke and kill lines. Ru rig floor and install wind walls. PJSM, Troubleshoot test joint not making up to blanking sub, Break bottom flange on stack and lift out of way, Remove blanking sub and BPV install TWC, Nipple stack back up and fill lines. PJSM, Test BOP 250/2,500 PSI for 5 min each, Test witnessed by state rep Austin Mcleod. Good BOPE test. PJSM, Pull TWC, close blind rams and secure well. 04/27/2019-Saturday PJSM. Location walk around. Ensure 0 psi on well. Pick up landing joint and thread into hanger. Back out hanger lock d bolts. Pick 21K no overpull. Lay down landing joint and hanger. Ru slips and MYT elevators. RU 1502 and TIW valve. 0 L irculate bottoms up. 750 psi @ 60/min. trip OOH with 3,757' of 2-7/8" IBT tubing. Rack back in derrick. Pressure test 2,500 psi for 30 minutes and chart. od pt. 100 psi loss over 30 minute test. Good test. E-line spotting and rigging up. RU 7" CIBP. RIH. Log strip. 9' CCL to top of plug. Park at 3,121'. puts top of CIBP in middle of casing joint. CIBP set at 3,130' RKB. 656 bis of tension. After set tension was 663 lbs. Pick up 100'. RIH tag top of CIBP at 3,130'. POOH to surface. Make up pack off head to bowen , pump in sub, x over to TIW valve and 8' joint of 2-7/8" tubing. Make up 4' casing punch. Loaded 3 spf. RIH with casing punches. Tag top of CIBP at 3,130'. Punch casing from 3,129'-3,125' No U-tubing of fluid or pressure. POOH to surface. Confirm casing punches fired. Make up 2nd set of casing punches. RIH to punch casing from 2,826' to 2,830'. Punch holes from 2,826' to 2,830'. POOH. Rig down E-line. 04/28/2019-Sunday PJSM. Location walkaround complete. 0 psi tubing, 0 psi OA. Hold tailgate meeting for Circulation attempt through casing punches. Rig up return hose on OA (13-3/8"). Attempt to pump down 7" casing and take returns up OA. Pumped 4 bbls. No communication. Pressure increased to 1,500 psi and held for 5 minutes. Fire equipment. Function test LEL, H2S monitors, PVT system, Trip in hole with 2-7/8" tubing. Tag top of CIBP. Tubing tally puts CIBP at 3,120' RKB. 10' off CIBP E-line set depth of 3,130'. HES cement crews on location 10 am. Make up x over, TIW valve, 1502 sub. Rig up HES cement equipment. Hold SIMOPS pre job safety meeting with AAO crew and HES cement crew, Cruz Vac Truck operators. Pump 3 bbls of fresh water ahead. PT cement lines to 250/3,000 psi. batch up cement. Cement required 15.8 ppg class G. Cement weight 16.1. Cement wet 1300 hrs. pump 19 bbls of class G. Displace with 15 bbls of fresh water. Trip OOH at 40 ft/min with 2-7/8" tubing. PU 400' out of cement top. Circulate bottoms up to clean tubing. Continue to Trip tubing OOH laying down. OOH with 3,130' of 2-7/8 tubing. Lay out 97 joints and 1 partial joint. Close blind rams. Location walk around complete. SDFN. C4: �0 a Ci8(; 3�� Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 312-09 50-133-10123-00 160-028 4/25/19 1 8/26/19 Daily Operations: 04/29/2019 - Monday PJSM. Location walk around complete. Fire equipment. Rig up chart recorder. Pressure up 7" casing. Pressure test CIBP and cement placed across casing shoe to 2,000 psi for 15 minutes and chart. HES E-line on location. SIMOPS and pre job. Bleed off pressure. Rig up E-line with junk basket and 3.5" gauge ring. Zero at ground level. RIH to tag TOC. Hard tag on cement top at 2,700'. OOH with E-line. No green cement in junk basket. Make up 7" CIBP. RIH and log strip from 200' up to 140'. RIH and log and stop CCL at 151'. CCL to top of CIBP 9'. Attempt to set CIBP at 160'. CIBP will not drop voltage and set. Trip OOH to investigate. At surface lay down tool string. firing head pin not contacting setting charge. RU back up firing head. RIH. Log back up to CCL depth of 151'. Top of CIBP at 160' Set CIBP Line tension dropped from 350 lbs to 75 lbs. Pick up 50'. RIH tag top of CIBP at 160'. Trip OOH to surface. BLM Rep Amanda Eagle on location. Make up 4' casing punch loaded with 3 spf. Trip in hole. Tag TOP of CIBP. Pick up line tension. Shoot 7" casing from 154'-158'. POOH. to surface. Close blind rams. Rig down E-line. Line up pumps down 7" casing. RU return line to 7" x 13-3/8" casing. Online 3 bbls/min returns to surface. Returns are crude oil. Continue to circulate until returns clean up. Pumped 260 bbls of fresh water. Peak vac truck skimming oil off top of pits. Haul crude to tank setting and push into gauge tank. Cement crews on location rigging up. Hold SIMOPS and pre job safety meeting with HES, AAO, and Cruz. Mix up 15.8 PPG class G cement. Confirm weight with mudd scale. PT lines 250/3,000 psi. Online with cement down 7" casing tanking returns up 7" x 13-3/8". 23.8 bbls cement to surface. Seems light. continue to pump cement. 27 bbls pumped. 15.8 ppg cement at surface. Shut down cement pumps. Clear lines and clean cement truck. Rig down HES cement equipment. Close IA and OA gate valves. Start rigging down HAK 401. SDFN. Location walkaround complete. 04/30/2019-Tuesday PJSM. Rig down HAK 401. Nipple down BOPE stack. Install dry hole tree. Mobilize Equipment and 401 carrier to SRU 21A- 34. 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. A 2ft _ r. '� Iii ` FL•. 4e• -(.'i -57.80, • 061N61-€ 1-084mits TRUE, mac+ 4s•' a` i� y, •� , .' �` 030 060 E. 71 �061l %: 150:87838 -35 w { 30.3`. ,T -30 ,., k J � ,. , n•+' a,. � Ali, t' 027 N27€ 0481Cnils TRU.{( te f4 . I .w= + (131.' �� i •'° 'Te �+ ~ �`as! •'1. _ � Si 5h h 4 Consulti Inc McLaNE Well S.C.U. 312-09 Plug & Abandon Memo Via email Date: 7/18/2019 To: Hilcorp Alaska LLC .................................................... Attn: Cole Bartlewski From: James A. Hall, PLS Project: Swanson Creek Unit — SCU 312-09 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 Creek Unit SCU 312-09 well located in Section 9, Township 7 North, Range 9 West, Seward Meridian, Alaska. The survey was performed on July 3, 2019. 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) original ground survey measurements were observed at the perimeter of the pad in opposite positions from the well location. A prorated original ground elevation at the well was computed from the (2) pad perimeter original ground shots. A top of pad elevation was also recorded on or adjacent to the well casing. A measurement and an "X" to the proposed cutoff elevation was marked on the cellar. Enclosed is Exhibit A which includes well casing cutoff detail with pad, original ground, and proposed casing cutoff elevations. • Mean pad surface grade in vicinity of well casing: 118.7'± (2019) • Original ground elevation in vicinity of well casing: 118.7'± (2019) • Cutoff depth requirement: 3.0' below original ground elevation • Minimum casing cutoff elevation: 115.7' • Casing cutoff elevation as staked in field: 114.7' The cutoff mark elevation of 114.7', as referenced in the field, exceeds the required minimum cutoff elevation of 115.7'. Please feel free to contact me if you have any questions or comments. Sincerely, //nom C t�-�f" James A. Hall, PLS McLane Consulting, Inc. *7491H JAMES A. HALL . s P.O. Box 468 Soldotna, Alaska 99669 (907) 283-4218 Fax (907) 283-3265 Email jhall@mcianecg.com 4 Go j6 Q XORIGINAL GROUND SHOT ELEV.=119.4 (2019) Q SCU 312-09 P&A ASP NAD83 ZONE 4 N: 2453892.0 4407S E3102.9 LEV.8118.7' CA'A ORIGINAL GROUND SHOT ELEV.=117.5' (2019) JAMESAHALL .� 1) BASIS OF HORIZONTAL, NAM 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 ZONE4 ARE: N = 2458384.5781 E = 1483669.4441 ELEV = 212.690 Consulting Inc md-mr-i icwEtwM9,Maewrc � 9wvErnW , rE9nnG VOILE: (9011�9 FA (i]])al3 EM L: 9M14M1E®MLWIEW CCM llilcorp Alaska, LLC GRAPHIC SCALE 0 50 100 200 I inch = 100 ft. HELL CASING CUT-OFF DETAIL WELL CASING ✓✓ TO BE REMOVED I PAD ELEV =118.7' f _ O.G. ELEV = 118_7_t I 4.0' REFERENCED WELL CASING CUTOFF AT FI FV = 114.7 SWANSON CREEK UNIT DAM 71mm19 WELL SCU 312-09 °PA By BGe PLUG AND ABANDON EXHIBIT -A sLA E 111w nFmiEcrrq. 1979w NAD 83, ASP ZONE 4 `OCA� SECTION 9, TOWNSHIP 7 NORTH, E RANGE 9 WEST, SEWARD MERIDIAN ALASKA MEMORANDUM TO: FROM Jim Regg P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE Brian Bixby SUBJECT: Petroleum Inspector August 281h 2019 Surface Abandon SCU 312-09 Hilcorp Alaska PTD 1600280; Inc. Sundry 319-138 8/26/2019: 1 arrived at Swanson River Unit 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_SCU_ 312-09_bb.docx Page 1 of 3 Surface Abandon — SCU 312-09 (PTD 1600280) Photos by AOGCC Inspector B. Bixby 8/26/2019 2019-0826_ Surface _ Abandon_SCU_312-09_bb.docx Page 2 of 3 2019-0826_Surface_Abandon_SCU_312-09_bb.docx Page 3 of 3 THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W W W.aogcc.olaska.gov Re: Swanson River Field, Tyonek Gas and Hemlock Oil Pools, SCU 312-09 Permit to Drill Number: 160-028 Sundry Number: 319-138 Dear Mr. York: 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. Sincerely, �p OL 2:,ieelowski Commissioner DATED this l II day of April, 2019. W1 ANRI�t209 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS gn AAr. 95 9Rn RECEIVED MAR 21 019 Aon 1. Type of Request: Abandon [A Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend p 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 ❑ 160-028 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-10123-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Will planned perforations require a spacing exception? Yes El No No Soldotna Creek Unit (SCU) 312-09 9. Property Designation (Lease Number): FEDA028997 10. Field/Pool(s): yy .m c �` 3 Swanson River/ Hdfnlock Oil / .� 3 Z/e 11, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 10,785' 10,785' 4,181' 4,181' N/A 10,155' 6,140'(fish) Casing Length Size MD ND Burst Collapse Structural Conductor 37' 20" 3T 37' Surface 2,980' 13-3/8" 2,980' 2,980' 2,730psi 1,130psi Intermediate Production 10,785' 7" 10,785' 10,785' 6,340psi 3,830psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4# / N-80 3,757' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): Baker FH Pier; 2 Brown HS -16-1 Pkr; Baker F1 Pkr; :N/A 10,150' MD/ND; 10,260' MD/ND; 10,335' MD/ND; 10,449' MD/ND; N/A 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 2 Exploratory ❑ Strati ra hic g p ❑ Development Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 1, 2019 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: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer _ hiicorp com // Contact Phone: 777-8420 Authorized Signature:/ Date: 2.I J'1 a: Lf•'r Lul COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: v Plug Integrity BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 25b0 AS. �ZS� I-et.� Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes E]No Q Subsequent Form Required: l7 — `(C) w APR 1 1 2019 1 '�BDMSL�t APPROVED BY t Approved by: COMMISSIONER THE COMMISSION Date: q 11 Form 10x03 Revised 412017 � ` il( pro _/ Q Approved applicat f •� 2 L [] date Submit Form and 1 r v r rrrrrrF///TTTVVV a of approval. s �/�� achme sin Duplicate,,f, H Hll.p Alaska, Lb Well Prognosis Well: SCU 312-09 Date: 03/13/2019 Well Name: SCU 312-09 API Number: 50-133-10123-00 Current Status: Shut -In Gas Well Leg: N/A Estimated Start Date: May 1, 2019 Rig: Rig 401 Reg. Approval Req'd? 10-403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 160-028 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Bo York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Bottom Hole Pressure: N/A— No open perforations Maximum Expected BHP: N/A— No open perforations Max. Potential Surface Pressure: — 0 PSI Brief Well Summary: Soldotna Creek Unit 312-09 was drilled and initially completed (Jan. 1961) as a Hemlock oil producer. SCU 312- 09 flowed oil until November 1962 and then was shut-in until January 1997. From January 1997 to March 2003, the well produced Bas from the Hemlock formation In November 2004, the Hemlock perforations were abandoned and the well re -completed up -hole in the Tyonek 77-3 sa d. The 77-3 sand was perforated on two separate occasions, neither of which resulted in any gas production. In October 2008, the 77-3 perforations were squeezed off and isolated. Note that after the cementing operation to shut off the 77-3 sand, the drill pipe became cemented in the wellbore. All perforations were successfully isolated but attempts to recover the drill pipe were unsuccessful. The drill pipe was cutoff and a kill string run in the well. SCU 312-09 was then placed on the long term shut-in list. purpose of this Sundry is to permanently P&A the Pre - Rig Work: 1. Provide 24 hour notice to AOGCC that Plug and Abandonment of well will commence per AOGCC regulations 20 AAC 25.112 (h). Notify BLM of P&A as per 43 CFR 3160 G. to 2. RU Pump Truck. RU on tubing and casing and perform a combination pressure test to 2 50, 0 psi on ►` (v chart for 30 min. Bleed down pressure. "—� c_'zst oQ a �..� l6c ' 7 Rig #401: 3. MIRU Rig 401. 4. Notify AOGCC and BLM 24 hours in advance of test to extend the opportunity to witness. 5. Set back pressure valve. ? 56O 6. NO wellhead, NU BOP and test 250 psi low &Jr699'psi high, annular to 250 psi low & 2,500 psi �j high. Record accumulator pre -charge pressures and chart tests. a. Perform Test. b. Test VBR rams on 2-7/8" test joint. c. Submit completed form 10-424 to AOGCC within 5 days of BOPE test. Copy to BLM. 7. POOF / kill string standing back pipe. �C:<<5kv i 0 Hilcorp Alaska, LU Well Prognosis Well: SCU 312-09 Date:03/13/2019 Note: CBL's indicate that cement was not brought up past the surface shoe so running a new CBL is not necessary. Work scope will proceed assuming that there is no cement across the surface casing shoe, behind the 7" casing. (30 t- 8. MIRU E -line. 13 B 9. PU RIH w/ CIBP to 3,130' and set same. POOH. �yv 10. PU V set of casing punches and RIH to 3,129' (+/-). Punch casing from 3,129' to 3,125'. POOH. 11. PU 2ad set of casing punches and RIH to 2,830' (+/-). Punch casing from 2,830'- 2,826'. POOH. 12. RIH w/ 2-7/8" tubing (open ended) to plug at 3,130'. PU 5'. 13. RU Cementers and test lines. Spot a balanced plug of 15.8 ppg cement from 3,130' up to 2,700'. 14. Pressure up on well 500 psi for 30 mins. Bleed down and WOC. , K(s,r iso 15. RU E -line. Test Lubricator to 3,000 psi. RIH and tag cement. Make sure TOC is above 2,880', to ensure at least 100' of cement extends above the surface casing shoe. POOH. lo. ru, nm wi Uur to -Lou and set same. ruurt. 17. PU 3`d set of casing punches and RIH to 159'. Punch holes from 159' to 154'. POOH and RD E -line. lJ 18. Rig up cementers to back side. Establish circulation down the IA through the tubing punches and U✓y up the 7" casing. Circulate a 15.8 ppg cement plug from 159' to surface. RD Cementers, WOC. U 19. Place dry hole tree on well. 1 L 20. RDMO Workover Rig. �-7�;_e> Post - Rig Abandonment Procedures: 21. 21. Excavate cellar, cut off casing 3' below natural GL. 22. Notif A and BLM 48hrs in advance. 23. 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: b. PTD: 160-028 c. Well Name: SCU 312-09 d. API: 50-133-10123-00 24. Set marker plate per-2-0-AAC-25.120 and BLM Onshore Order No. 2 III.G.10, collect GPS coordinates. 25. Photo document casing cut-off and Welded Plate install. 26. Backfill excavation, close out location. Attachments: Actual Schematic Proposed Schematic BOPE Schematic RWO Sundry Revision Change Form Swanson River Well SCU 312-09 Current as of 11/10/2008 C a s 1 n pi T u b i n R1,11 -17.20' Size T e1 WI Grade Thrd ID To Btm Hole coot CmtI 20" Condu m, Surf 37' Yes Surf. 13 Surf Csg 54.5 K-55 12.615 Surf 1509' 3/8" 1000 sx Surf DV Collar 1509' 1512' 17.5" 13 Surf'Csg 54.5 K-55 12.615 1512' 2980' 600 sx 2010' = 3/8" Calwlao 7" 29 6.184 Surf 250' 7"1 26 6.276 250' 1179' U C Rd 10,177' TD=10,785' PBTD=4,181' Max Deviation = 2° @ 5,931' 23 Butt Prod Csg 3 N-80 8rd Rod Csg 29 1 P-110 (KillString) 17.20' RKB to The 6.184 Fich nnfoil 750 sx 5700' Th DV CBL 9-7/8^ 1 © 8504' 750 sxs 1 8187 NO. Depth ID OD 11101na L 3,757' 2.441^ 2.875" Mule Shoe 2, +/- 4,160' 7,270 8" piece of casing recovered during fishing operations 3, 4,181'-(+/-)4,418' 7,275 Cement 4. 4,181'—(+/-) 6,723' 4.875" 4" XT -39 drill pipe / 4-7/8" tool joints & 1-1/4" cement stinger 5, +/-6,140' 5.5 Milling shoe fragments, 1-7/16"x6" shot rod hanger w/3/8'xS'shot rod attached Fish in Drill i e 6. 7,203' 6.0" Cement retainer 7.1 7,325' 1 6.0157" 7" HES FmDrill composite Bridge Plug P F R Fn R A T T n N n F T d T T. IIBe" Alma TOP Btm Amt Spf Com Ate, 7,264 7,270 6 6 Sclem aced 102117 7,275 7295 37 6.0 SqLCC2Cd 11/04 10,165- IQ 166 1' 5.5 P&A'd 1QlU 1Q23$ 55- 4.5 P&A'd 10$44' IQ255 11' 4.5 P&A'd 10275' 1Q332 57 4.5 P&9'd Ig944' 1Q403' 93 4.5 P&A'd 10,40$ I 1Q421' 1 13 1 4.5 P&4'd 10,425 1Q444' 19 1 4.5 1P&A'd Ig46a IQ520' Ca 1 4.5 IP&IVd 10526 1Q546 1 21' 1 4.5 P&A'd 10557 1 1Q55$ I I' 1 5.5 P&A'd Updated by DMA 12-06-18 Swanson River PROPOSED SCHEMATIC Well SCU312-09 Current as of 11/10/2008 HilenrP Alaska, 1,1,1; C as in a & T u h i n a CML 4714' aBPn 10,1553. 1 \I PN 10,nI 10,146 DII, Cmt Ru a 10.1]7' RKB =17.20' - f.. Toc to Hole arrace 1 20" Conductor Surf 37' CIBP w/ 160' cement to surface Yes acne, � 13 3/8" 2154'-2359' 17.5" 1000 sx 13' ;_=• 22,826'- 1509' 1512' 22,830' 2 54.5 K-55 23,325'- 12.615 1512' 2980' t3,12T 20 Cakulam) 7" 3 4 TD-- 10,785' PBTD=4,181 Max Deviation = 2" @ 5,931' Size Tvve Ni't Grade Thrd ID Top Btm Hole colt Cmt To 20" Conductor Surf 37' CIBP w/ 160' cement to surface Yes Surf. 13 3/8" Surf Csg 54.5 K-55 12.615 Surf 1509' 17.5" 1000 sx Surf DV Collar 1509' 1512' 3/8„ Surf Csg 54.5 K-55 4,181'—(+/-)6,723' 12.615 1512' 2980' 600 sx 20 Cakulam) 7" Prod C 8 s5700, 29 N-80 Butt 6.184 Surf 250' 7/rd /8" 750 sx Th. DV @ 8504' Cat, CBL 7" 26 6.276 250' 1179' 7" 23 6.366 1179' 4798' 7" 26 6.276 4798' 5756' 7" 29 5756' 7238'_ 6.184 7238' 7242' 7242' 7284' 7" 29 Butt x S 7" 29 8rd 7" 26 P-110 6.276 7284' 8504' DV Collar 4.5 8504' 8507' 7" Prod Csg 26 P-110 6.276 8507' 9315' 750 sxs 8181 Calculated 7„ 29 6.184 9315' 10,785' Tu 2 7/8° it 7,2 ' h 11 r 1 3,7M ' Fieh P>+eit NO. Depth ID OD Item 1 ±1601 Amt CIBP w/ 160' cement to surface 2 f3,130' 7,270 CIBP w/-430' cement on to OC ±2,700' 3 +/-4,160' 7,275 8" piece of casing recovered during fishing operations 4 1181'- +/- 4,418' Scluxmd 12/04 Cement 5 4,181'—(+/-)6,723' 4.875" 4" XT -39 drib pipe w / 4-7/8" tool 'oiats & 1-1/4" cement stinger 6 +/6,140' SS Milling shoe fragments, 1-7/16"x6" shot rod hanger w/3/8"x8'shot rod attached Fish in Drill i e 7 7203' 6.0" Cement retainer 8 7,325' 6.0157" 7" HES FasDrill co n osite Bride Plug PERFORATION DETAIL hltetalr ACalla TOP Btm Amt SPf G(Mmenls 7,251 7,270 6 6 Sgtd&isolatedionla 7,275 7295 21Y 6.0 Scluxmd 12/04 10,165 1Q166 1' 5.5 P&A'd IQ183' 1Q239 SS 4.5 P&A'd 10,244' IQ255 11' 4.5 P&Vd 10275' 1Q332 57 4.5 P&Ad 10344' IQ403 59 4.5 P&A'd 10,408' 1 IQ421' 1 13 1 4.5 IP&Vd 10,425 IQ444' 1 19 4.5 P&A'd 10460 14520 dl 4.5 P&A'd 10,526' IQ546 27 4.5 P&A'd 10551 1Q559 I I' 1 5.5 P&Ad Updated by DMA 03-13-19 HILCORP ALASKA 7-1/16" 5M BOPE 7-1/16" 5M HYDRIL GK ANNULAR 32" TALL, FLANGE TO FLANGE 7-1/16" 5M LWS DBL GATE BOP DRESSED W/VARIABLE RAMS IN TOP DRESSED W/BLIND RAMS IN BOTTOM FLANGE TO FLANGE 7-1/16" 5M 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 ff Hilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SCU 312-09 (PTD 160-028) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N ----H—AK Prepared By (initials) HAK Approved By Initials AOGCC Written Approval Received (Person and Date) Approval: Prepared: Asset i earn Operations Manager Date first call Operations Engineer Date 10,000,000 1,000,000 L C C 100,000 LL v g o N 10,000 0 4- O wt LL 1,000 u 3 u M N 100 0 0 r 10 HILCORP ALASKA LLC, SOLDOTNA CK UNIT 312-09 (160-028) SWANSON RIVER, HEMLOCK OIL Monthly Production Rates V 10,000,000 Cum. Prod Oil (bbls): 511,833 Cum. Prod Water (bbls): 10,168 Cum. Prod Gas (mcf): 5,566,537) � I I e i e °e -- --- -- a r A pG I i ------ F - e me e _ p p e G I i I — e I 05 d 1,000,000 O M 100,000 O 3 S 10,000 O W d 1 1,000 O_ t m M 100 v' M 3 0 3 10 T 1 1 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 ° Produced Gas (MCFM) o GOR ti Produced Water (BOPM) —, Produced Oil (BOPM) SPREADSHEET_ Prod -inject Cuwes_Well_V 119_1600280_SCU-312-09_20190326.xlsx 3/26/2019 STATE OF ALASKA AIAS~IL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS 1~1 G ~-' ar~4~~ooq 1. Operations Abandon f2epair Well Plug Perforations Stimulate Other ~ Kill String Performed: Alter Casing ^ Pull Tubing [~ PerForate New Pool ^ Waiver Time Extension ^ Change Approved Program ^ Operat. Shutdown ~ Perforate ^ Re- ter Suspended Well ^ 2. Operator Union Oil Company of California 4. Well Class Before Work: Permit to Drill Number: Name: Development ^~ Exploratory 160-028 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic^ Service ^ API Number: 50-733-10123-00 Property Designation (Lease Number): . Well Name and Number: FEDA028997 [Swanson River] Soldotna CK Unit (SCU) 312-09 . Field/Pool(s): ~n~ ~ ~ ~~Q~ u Sw nson River / Tyonek Undefined Gas 11. Present Weli Condition Summary: ~~~as~Ca ~AI ~a Gas ~ans. Com ' ~,zoa, ~,325, & pnchorage Total Depth measured 10,785 feet Plugs (measured) 10,155 feet true vertical ~ 10,785 feet Junk (measured) +/- 6,140 feet Effective Depth measured +/- 6,140 feet Packer (measured) N/A feet true vertical +/- 6,140 feet (true vertical) N/A feet Casing Length Size MD ND Burst Collapse Structural ~ Conductor 37' 20" 3T 37' Surface 2,980' 13-3/8" 2,980' 2,980' 2,730 psi 1,130 psi Intermediate Production 10,785' 7" 10,785' 10,785' 6,340 psi 3,830 psi Liner Perforation depth: Measured depth: No open perFs "~~~9~~~~ ~~,r ;1 ~~~~~~ True Vertical depth: No open perfs Tubing (size, grade, measured and true vertical depth): 2-7/8" 6.4# L-80 3,757' MD 3,757' ND Packers and SSSV (type, measured and true vertical depth): N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: 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 psi 0 psi Subsequent to operation: 0 0 0 0 psi 0 psi 14. Attachments: 5. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory^ Development ^Q Service ^ Daily Report of Well Operations X 6. Well Status after work: Oil Gas ~ WDSPI GS OR ^ WAG ^ GINJ ^ WINJ ^ 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: 308-298 & 308-410 Contact Steve Tyler 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276-7600 Date 11/3/09 - p~~ f ~ b ~ ~ ~SI0~1 Form 10-404 Revised 7/2009 Submit Original Only ~ ~ • • Swanson River Well SCU 312-09 VN~CA~ 76 Current as of 11/10/2008 C a s i n & T u b i n RKB =17.20' Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt To Conductor Surf 3T i Yes Surf. Surf Csg 54.5 K-55 12.615 Surf 1509' 1000 sx SurF Collar 1509' 1512' 17.5" Surf Csg 54.5 K-55 12.615 1512' 2980' , 600 sx ZO10' Calculate~ 29 6.184 Surf 250' 26 6276 250' 1179' 23 Butt 6366 1179' 4798' 26 N-80 6.276 4798' S756' 750 sx ' Prod Csg 29 5756' 7238' Thru DV 5700 CBL 29 Butt x Srd 6.184 7238' 724Y 9-7/8" @ 8504' 29 7242' 7284` 26 P-110 6.276 7284' 8504' Collar 8rd 8504' 8507' 26 6.276 8507' 9315' 750 81AY Prod Csg 29 P-I10 6.184 9315' 10 785' ~ sss ('alculated bIR Kill Strin U10' RKB to Tbg Hngr 4°, Butt 6.4 N-80 IB'C 2.441 Surf 3 757' Fish Detail NO. De th ID OD Item ~, 3,75T 2.441" 2.875" Mule Shoe 2, +/- 4,160' 8" piece of casing recovered during fishing operations 3, 4,181'- (+/-) 4,418' Cement q, 4,181' -(+/-) 6,723' 4.875" 4" XT-39 drill pipe w/ 47/8" Pool joints & 1-1/J" cement stinger g, +/- 6,140' Milling shae fragments, 1-7/16"x6" shot rod hanger w/ 3/8"x8' shot rod attached Fish in Drill i e 6, 7,203' 6.0" Cement retainer 7, 7,325' 6.0157" P' HES FasDrill composite Bridge Plug PERFORATION DETAIL Lrierval Actum T Btm Amt s f Comrer~ 7,264 7,270 6 6 Sc~d & iu~laai l0/21p8 7_27S 7~)~' 31' 6.0 S~ i~t~ixl I?J(k1 1o,16S 1q166 1' S.5 PNrA'd 10,1ffi' IQ238 SS 4.5 P&A'd 10~44' 1Q25S 11' 4.5 P&1'd 10~75 1Q332' ST 4.5 P&~'d 10~44' 1Q403' 4~' 4.5 P&~'d IQ408' 1Q421' 13' 4.5 P&-~'d 10,425 IQ444' 19' 4.5 P&4'd 1Q460' 1Q520 60' 4.5 P&r1'd 1Q52b' 1Q546 a7 4.5 P&A'd 10,55T 1Q55% 1' S.5 P&rA'd SCU 312-09 Current Schematic with drill pipe.doc Drawn: 11/10/2008 by CVK 'ID= 10,785' PB1D= 10,700' Max DeNaUOn =2° (a~5,931' Chevron __ . _ ~ ~ ~ • Chevron - Alaska Daily Operations Summary li iSC~U 312-09 ~SOL OTNA CK UNIT 312-09 -- -- FEDA028997 . ^- ~50~13310123 (3A5267 :•~ 17 O tRy ~w~er oe~, ~R~ ), ~Primary ,Wtr Type Job Category Objedrve Actuat Start Date iActual End Oate :Completion - Reconfa~ure Major Rig 1Recomplete in the Tyonek G zone (G1 and G2), to develop 75.3 MBO of 8Y20/20Q8 ~ I Work Over i probable reserves. ~ (MRWO) ( _ _ _ .. _ _... __ .._~___.___~ _ . _____ 4P.anary uve0oore Aneccea vifeiwan uVU! __. ~SCU 312-09 i 5013310123_00 _ `~ Dafly Operatfor~s r 8/20l2008 00:00 - 8/21/2008 00:00 __ -. --- Opera~ions Summary ~ Mobil"~ze Coil Fubinq and Slick line to pad RIH w/ slidcline and Fill at 9855' RKB, SLM ;8/21l2008 00:00 8/21J2008 00:00 _ ~~_._ _~_.e____.~._.._..,, _, ___ ___ __--- _ _ _ ~__ O'perations Summary - _. __ ;; Rig up Coil Tubing and begin to Mix kill weigM brine to 1 l.6 ppg _ _ _ ___ _ , _ _. _. _ _ a~2ti2ooa oo:~ - e~x~rsoos oo:oo _ --~ __ __ _ _ _- - ~ ~ -- -- ---- ~ -- ~~~ei~ s~;;m~y _ Finish mixing 11.6 ppg brine, Bottom kiN well with t L6 ppg ( 38°k CaCl2) brine _- -- -- __ _ _ __ _...._ _ _. _- -- _.__ _. .___ _. 8/23/2008 011:00 - 8/24/2008 00:~ . _ _--------- --____ _ _.__ ____._ _ - - Operatans Swnmary ~ Mob Wireline and open Sliding steeve at 6,619' SLM. Rigged up to filI annulus w/ KWB, Pumped 274 bbls KWB. ..__._ ._.._~__.._. ___..____..__ . _ __ _ _. -- ! 812U2008 00:00 - 8/25/2008 00:00 ~___.__. Operations Summ~r - _ __._._. __ __ . .-- - ....__ I Prep equipment for demob and load trailers that are available. ~ 10M0/2008 00:00 -10111I2008 ODI;00 °- - --- _ ~ ._ _ _ ~.__ -_~ _ __ _ ~ --- _- Operetions Summary ' Mobilizing rig from SRU 41-33. --_ __.._ ___- - _... 10H1/2008 00:00 -10/7 2/2008 00:00 M~» - - -- 10H3/4008 00:00 -10/7M2008 00:00 _ - -- -.__. ope.stiaw summan -- ---- ~~ ~ - - - --- Mobilizing rig. Notified Jim Regg of AOGCC and Tim Lawlor of BLM of upcoming BOP test. BLM waived witness. -- --- _ ._ ~ - - --- ~ -- - ~a~a~zoos oo:oo - ~a~~oos oo.oo ~_ ~__ __ ____ o~~ s~m~y _ . _ _ - Mobilizing rig. Contacted AOGCC Jeff Jones to witness upcoming 80P test. -- ---- - .. ---_ _ _- __ _. _ _ - - 10115/2008 ~;00 -10/1612008 00:00 ___ _ ___ - __- - Operations S~snmary -- NU 80PE. Conduct Certification test on Accumulator, Charted 5 min 4000 psi, 4500 psi 15 min. Good Test. Unable to MU test joint in tbg hngr. ND BOPE. _.___. ._ ----_..~ _ - -- __._ 1~1E/2008 00:00 -10/17/1008 D0:00 __.__. -- __~ __.__ Operations Sunmary Clean cmt debris off tbg hngr. NU BOPE. Repair VBR's. Jeff Jones with AOGCC witnessed BOPE test as folbws: Test #1: Annular, Choke valves, Check Valve, Dart Valve - 250 psi 1ow/2000 psi high. Tesi #2: Upper Pipe Rams, Choke Valves, Check Vafve, Dart VaHe - 3000 psi. Test #3: Upper Pipe Rams, Kill HCR, Safety Valve, Choke Vahres - 250 psi Iow/3000 psi high Chedc all Gas Alarms, Press up 1000 psi Flow Check Super Choke, Pressure up 500 psi Flow check Manual Choke. Test #4: Upper Pipe Rams, Safety Vafve, Choke Valves - 250 psi low / 3000 psi high. Test #5: Upper Pipe Rams, Upper IBOP valve, Choke Valves, kill line valve on stand pipe ; 25fl psi low / 3000 psi. Test ~J&: Kitl line check vatve, lower IBOP vaNe, choke line HCR - 250 psi low / 3000 psi high. ~ Test #7: Manual inside choke line valve - 250 psi low/ 3000 psi high. Test #8: lower pipe rams (2 7/8") - 250 psi low / 3000 psi ngh. ~ _ ___ _ _-. .- ---. ._. . _ _ _ _ - ------ - -- - _ ------------ 10l17J2008 00:00 -10H 8/2008 ~:00 __~___. ____ __ ---___~_~._..~_~..a _ ~_. _.,_._ ,.- _ _ _ _ Operations S~mmary - t0/17l08 ~ 1900 hrs. BUN waived witness of upcoming BOP testing after ram change. Contacied AOGCC of upcoming BOP test, witness was waived. Perform iCoomey test: Systern press 3000 psi, after closure 1500 psi, 200 psi attained ~ 50 sec 8 full press ~ 3:15. N2 bottles 4~ 2525 psi. Unland tbg hanger ~ 100K. Shear & relsase Baker FH Pkr ~ 85K & pull hanger to rig floor. CBU 340 bbls total. BuiM brine wt badcup to 11.8 ppg. POOH lD tbg. ' _. _ . _..~_ - ___ - _ ~ 1011812048_00:00 _1011812008 00:00 -- - ___.. _ __~ _ _ _ Operations S~mmaq' ~ + Conti~ue to LD tbg 8 Completion equip. Change-out upper pipe rams. ° _._ _ - -- . _.. . .~._ _ . _ - ; - _-- -- - _ _ _ _~ _. _ _ ~ WeR Permit Number _._ _... _. . . _.. ... _.._~._. ~~6~0280 ~ ! _--__-__-- _ _ _ _---__ ...__..--- ____ , ___ _ _---- ; Chevran ~ ~ ~ ~ Chevron - Alaska { ~ Daily Operations Summary Well Nams --~ ~-- -- -~ Lepsl WaM Name ~ lease ~ SuAace iJ1M ~~ ChevNo Qrigioal RKB (R) Water Dep1A (ft1 ~~ SCU 312-09 ~ SOLDOTNA CK UNIT 312-09 FEDA028997 ~5013310123 ~G1A5267 ~ 17.20 i Dail Operationa ~ ' ia~sizooe oo:oo - ~asousooa oo:oo __~_ _ __.___________ _ _---- --- ove~e~~«,g s~m~ _ _ ' Change upper pipe ram. Test BOPE 250 psi bw 3000 psi high. land Wear Bushing. PU/RIH w/ fishing BHA. __ _-- -- ---- ---- - -_ 10/20/2008 00:00 -10/2112008 40:00 _..~~~ --- - -- ~ _ __ -- ---- ---- -__.~ _-- ~ovwatbnasunmaiy ____.. __ Cont. RW w/ Fishing BHA on 4" pP. CBU ~ 8500'. Tagged fiU ~ 982T. WasMciraiiated fill out to 10,037'. Set down ~ 10,037'. Saw 100 psi increase in circ pressure. POOH. LD Tbru-Tbg BP Fish. PUMU FasDriq BP & Setting Tool. . _ ____r ------ _~_ _. - -- _ ------- k1012112008 00 00 10J21J2008 ~ 00 . . ___.- set FasDrill bridge piug ~ 7325' RKB. POOH. PUMU FasOrili Ret. RIH Set ~ 7203. Perform Injection test, .5 bpm = 440 psi /1 bpm =1000 psi ! 2 = 1725 psi ! 4 bpm, 25~ psi, Pumped 45 bbls total, unsting from retainer, Circulated bottoms up and bring weight of brine up to 11.6 ppg. 2/2008 00:00 -10123f2008 00:00 ~ ~ _ _ - - - _ iuons summary - - __- - _ - - - - iped 40 bbl 15.8 ppg cement squeez finishing at 3.4 bpm, 2,800 psi. Bled pressure to 1,OOQ psi and unstung from retainer. POOH 7 stands (+!- 480'). attempted to circulate drill pipe clean. Lost suction on pumps. SGck drill pipe, attempt to work free. Rig up wireline and nm 1.69" gauge ring run le driA pipe to 6,721' WLM. POOH and prep to run freepoint. -- --- - _ _ ~_.._ ___ _ _ _ _. 3/2008 00:00 -10/2M2008 00:00 ~_~ ..- ------------__._~_..__ ___..__ ...,... e..__..... -- - -- __ _. Run free poi~t, found free pipe at 3956'. 12U etine. Run string shot and fire. RD eline. Twist off drill pipe POOH w/123 jts of 4" OP. Test 90Ps 250 fow, 3000 high. AOGCC Jim Regg & 8LM Tim lawlor nofified and waived witness. 00:00 ' Finished BOP test. RU tools and PU wash pipe assembly. ---._._ - -- __ . _. __.._r._... .__._ _. _ . _.- ___. ._ _ ---- - 1~2512008 QO:dO -10/26J2008 00:00 __ _ __ _ _----- OperatwnsSummary _. _,.~ ~ __ _ .__. '. RIH w/ drillpipe wash over BHA (saw tooth shoe, washpipe extensions, wash pipe, sub, bumper su6, fishing jar, drNf collar) Tag top of fish at 3948' RKB. !; Mill over fish to 4108' Srop making progress. POOH w/ washover assembly. -10/2T12~8 00:00 MU/PU screw in BHA. TIH and screw into fish top. Jar on fish. Jars stop working. Trouble shoot. RU wireline. Attempt to run in hole (max OD on taols is 1-11/16"). Can't get past 3934' RKB. Pull oui of hole with wiretine. --- - 10/27/2008 00:00 -10/28/2008 00;00 -_m_ - . ---- - -- _ __ ~--- - -- - - -- - Operatbns S+mmary Change out wireline tools (Max OD=t"). Run in hale with string shot. Fired at 3951' RKB WLM. Pull out of hole. Rig down eline. Trip out of hole with drill pipe. MU/PU new bumper sub in BHA. Run in hole with bumper sub, fishing jars, drill collars, intensifier. Screw into fish. RU wireline a~d run in hole. Tag stringers of cement at e~d of drill pipe at 6724' RKB WLM. Pull out of hoie. RU free point tools. _ _ _ _ - --- _ _ --- -- __ _ ----_ ,'._ __.. _-- _ __ . '<10128/Z008 00:00 - 90/28/2008 00:00 ~ ~ _____._. ~Operatiora Summary ~_.._ _ -- -- - - --~ - _,T __. `Run in hole with free point taols. Pipe free to wash over depth. RU string shot. Shoot at 4077' RKB WIM. Pull out of hole. Run CCL. Pull out of hole: RD wireline, Run in hole with drill pipe. Pull out of hole. Lay down 4 joints. Top of fish at 4076' RKB. Pick up wash over assembly, milJ extension, wash pipe, jars, ddll collars, and iniensifler. Run in hole and attempt to mill over fish. No progress. Tnp out of hole. 7rip out of hols to get new mill. Lay down saw tooth shoe. Shoe wom out and cracked. Pick up ocean wave shoe. Trip in hole to 4018' RKB (BHA = mill, wash pipe, bumper sub, d~i11 collars, and intensifier). Wash down to 4074' RKB. Wash to 4137" RK8. Stop making progress. Pull out of hole with BHA. MU/PU flat bottom mill (carbide), wash pipe, drill cotlars and jars. - --- ---.._.. _ _ _. - -- --- _ - - - 10/30/2008 00:00 -10/31/2008 p0:00 ____..__ _ ..__._._ ___--- _ __ _ --- - - Operaiwns S~mary ~ TIH wikh fishing BHA. MilUwash to 4170'. BHA started bouncing. GBU. TOOH. Found bottom part of shce b~oken off and left in hole. Tesi BOPs 250 psi low and 3000 psi high. Pre test contact made with BLM 7im Lawlor and AOGCC Chutk Sheve. Witness waived by AOGCC Chudc Sheve. __. ~ - -- -- -_ _ _ . . _ ___ --- - - 10J31/2008 00.00 -11/7I2008 ~:00 _ . _ _... _. _ __.._ . __._ _. --- - -- Operatans Summary __ _--.--- - _--- - . Finished BOP test. PU and screw in B1iA, XO, lBS, fishing ja-s, DC, intensifier. RiH to top of fish. Screw in. RU slickline and attempt to run swedge inside drill pipe. Finally get through and tag ~6140'. RD slidcline. RU efine. PU CBL tools. _. _ . __ _._ . __.. __. _ __. _._ _ _____,. ._.._. ._. _ --- 11H/2008 00:00 -11/2/2008 00:00 Reconfigure CBL tool. Run back in hole and lag from 6035' - 3800'. TOC ~ 4062' - 441 S' with stnngers to 4500'. MU and RIH with stnng shot fire at 4141 POOH with fishing BHA. PU new flat bottom shce milling BHA. ___ ~ _ --~ -- ____ 11/2/2008 00.00 -11I312008 00:00 ~ ___ _r -- RIH with Nat bottom milling BHA. Work down to 4167'. Mill on junklcement. Progressed 3' to retum to 4170'. Circulated the hole clean. TOOH. LD BHA. PU 6" x 5" washpipe. RIH. Wash to 4170". Begin milling, making no progress over taol joint. ~ _.__ _. _ _ Chevron ~ ~ Chevron - Alaska Daily Operations Summary ~ WeN Name -- - teqal WeM Neme ~SCU 312-d9 (SOLDOTNA CK UNIT 312-09 CJ FEDA028997 I 5013310123 I GtA5267 I 17.20 11/3l2008 00:00 -11i4l2a08 00:00 operations summaary ~. __ _ _ _ __ ----- Con6nue milling ~4170'. No progress. TOOH. Find metal parts from previous BHA and 10" section of 7" buttress collar wedged inside. PU 6"x475/1 mill shoe with drili collars. RIH to top of fish Q 4137`. Wash over to 4170'. Mili artd make oniy haH a foot of progress. Mill appears worn out. ~ 11/4/2008 00:00 -17I512008 00:00 ITOOH. LD BHA. Bottom worn off shoe. Outside cutright gone, inside cutright shows no wear. TIH with screw in sub BHA. Attempt to screw into top of ss fish ~ 4138' RU etine. RIH with string shot, fire at 4181'. POOH with string shot. RD eline. POOH w~h BHA, no fish recovered. ` ----- -- ` 11/5lZ008 00:00 11/6/2D08 00:00 . ~ _ __ .r _ _ _- -___ _____. _..__. __. __ . - ---- --- ,,._ ~ __ ___ Operations Summary ; PU 283' BHA with bumper sub, jars, drill collats, intensifier, TIH. Screw into fish Work torque into pipe. RU eline. RIH correlate deptfi with CCL to €5000'. PQOH. Arm string shot, RIH, torque pipe and fire shot at 4181 . No backoff. POOH w~h stnng shot. RIH with sinker bars arul CCL. POAH. `I RIH with string shot and set at 4181', apply torque to dnll pipe. Fire shot and note back off. unscrew pipe, pipe free. PQOH with string shot (bst 8" x ' 1-7/16" hange~ and shot rod down pipe. RD wireline. TOOH with screw in sub. Inspect threads. Good. RIH with screw in sub. Tag top of fish at 4t37", ' jsuew in, pressure up and set torque. __. _ _ - - -- _ 41/6/2048 00:00 -11l712008 00;00 ---- --~ . __y___ _ . _~ Operelions Summary _ RIH w! 2-1/16" GR to 5,~0". POOH Load 1-9/16"x10` perf gun. RiH 8 correlate! shoot 4,173.5'-4,177.5'. POOH LD guns. PU radial cutter. RIH to 4,174', fi~e, POOH, LD, RD E line. RIH retrieve 24' of DP. PU millout BHA assembly. TIH Tag at 4,161.5'. Begin milling. Received extension from AOGCC Lou Grimaldi to test BOPs when mill is POOH. _.. _ - -- - 11/7t2008 00:00 -1118/2Q08 Q0:00 - -^ Operations Surt+mary ____ _ _ _ _ ~_ ~ _ ~~__._ _ _ Continue ro mill on fish, Make 7' to 4,170'. Recovering metai shavings on surfaca, no cement. CBU. Test casing to 1500 psi wJ pressure bleeding to zero i ! in Smin. No pressure in 7"x9-5/8" annutus. RD testing equipment. POOH wi 4" DP. RU to test 7" paclcoff. Contac[ed AOGCC Lou Grimaldi of upcoming ~ BOP test ~ ~~~~zoos oo:oo - ~ira~s~e oo:oo - _~ =~ _ ____..___ .w ~ __._ _ ---- _ __ __. _ ____. _ ___~_.__ ___~.~___ ;OparetionsSummary __ . __.. kTest packoff on wellhead to 1500 psi, goad fest. Attempt retest of casing to 1500 psi, no good. POOH lD milling BHA. Test BOPs 250 psi low! 3000psi ' high. AOGCC waived witnessed. r ..-- -.__. _ _ ._ .. 111l9l2008 00:00 -11l10l2008 00:00 - -- __ _ _ ___ -- ~ - - - - - -- -- Operetbns Summery -. ~ ~._~_ m ~RIH w! RTFS packer on 4" DP, set at 3952' Pressured up 4"x7" annulus to 150dpsi, chaR for 30 mins, good test. No cfiaage in 7"x9-5/8" casing annulus. Pumped down drill pipe, established injection rate of 1 bpm at 1720 psi. Release RTTS padcer. Circulate well. LD RTTS paGcer and DP. Pull wear bushing. Rig up tubing rumm~g equipment. PU mule shce & RIH w/2-7/8" 6.b1! 1-80 tubing for kill siring. ! __ __.~~,~ __. ~ _ _ --- 11110/2Q08 00:00 -19H1/2008 Q0:00 ;OperationaSummary _ _.~ .._ ~_ ------ Ran 2-7/8" tubing kill string and land at 3,757'. Circulated well corrosi~n inhibitor, biocide, 8 oxygen scavenger down annulus. Begin demob of rg to SRU ~ 211-33, :._ __. • Dale A. Haines Union Oil Company of California ' Manager, Oil & Gas 3800 Centerpoint Drive, Suite 100 Operations Anchorage, AK 99503 Tel 907 263 7951 Fax 907 263 7607 Mobile 907 227 0761 Email daleah@chevron.com August 3, 2009 AUG 0 5 2000 Cathy Foerster Commissioner Al;isk , Oil & Gzs Cont, Gr4mrrli&ginn Alaska Oil & Gas Conservation Commission Anr.hom-p; 333 W. 7th Avenue Anchorage, Alaska 99501 Dear Commissioner Foerster, 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, (� 1 J Ctkl- Dale Haines SC"ED OCT 022014 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 1 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 iniection 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 D40RD 1820830 Se -01 Shallow hole in tubing near #2 GLM Stopped producing Phase 1 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 Hieh 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 I 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 platform 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 13-4 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 -9 parted 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 T onek gas 2011-2014 SCU 43-9 1620310 May -9 punched hole in tbg high water Possible P&A 2010-2013 SCU 444 1740660 Oct -0 no known damage no flow Possible T onek oil 2012-2015 SRU 212-10 1600180 Oct -9 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 no known damage no flow Possible shallow as or as storage 2011-2014 Monopod A-10 1670760 Colla sed casingProducingCoal Phase I Abandon abandon at end of platform life Monopod A-23 1720200 qJun-8 Colla sed casin Producin Coal Phase I Abandon abandon at end of latform life Mono od A-30 1730140 No known damage Water production due to WF breakthrough Phase I Abandon abandon at end of platform life a �T�+ g am` ALASKA �®t 11L AND GAS June 22, 2009 k1_�G—C32-%-' SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 F ANCHORAGE, ALASKA 99501-3539 % PHONE (907) 279-1433 FAX (907) 276-7542 Dale Haines SCMHID OCT 0 2 2014 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.gvv. 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 21B-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 Union 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 ~h@~l'POI't F-rancisco Castro Chevron North Ar-Tierica Exploration and Production Technical Assistant 3800 Centerpoint Dr. Suite 100 Anchorage, AK 99503 Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com DATE January 13, 2009 To: AOGCC Mahnken, Christine R ;. r~ ~~ i:a,+~-y ~~ ~ ; ~~~~ 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 ~ ~ ! ~ ~ I i WELL LOG TYPE SCALE LOG DATE RUN tt 6-LINE I INTERVAL CD ~ LOGGED PJOTES-LAS PDS, ~ DLIS i ~~ r~ <, CEMENT MAPPING TOOL SRU 312-09 SCMT-GR 5" 1-Nov-08 1 1 1 3650-6000 PDS, DLIS -'`fi ,j=-~~~ "~~ TBU M-32RD RST -SIGMA 5" 26-Nov-08 1 1 1 50-9300 DLIS, PDS =r:' ¢ TBU M-32RD RST -SIGMA ND 5" 25-Nov-08 1 1 1 50-9300 LAS, DLIS, PDS _J~ i 3 tf~;:.~ HV B-13 RST - GR -CCL 5" 12-Nov-08 1 1 1 3600-7685 LAS, DLIS, PDS ______.- - : ~~~ ~ ~'~~ -~ HV B-12 RST - GR -CCL 5" 12-Nov-08 1 1 1 3700-10313 LAS, DLIS, PDS ~~`i HV A-8 PLUG SETTING RECORD 5" 7-Dec-08 1 1 1 6077-6301 DLIS, PDS ~(~% =1~ j HV A-8 PSP -WATER ENTRY 5" 10-Dec-08 1 1 1 4836-6160 LAS, DLIS, PDS I ~ j ~ HV A-8 PSP -DEFT 5" 22-Nov-08 1 1 1 4900-7300 PDS, DLIS `--I Lf ~ IRU 13-31 USIT 5" 2-Dec-08 1 1 1 50-6250 LAS, DLIS, PDS L1 ~ r IRU 13-31 PRESSURE TEMPERATURE 5" 10-Dec-08 1 1 1 100-6192 LAS, DLIS, PDS Please acknowledge receipt by signing and returning one copy of this tra' PA5~C07 263 7828. '~ Received ~~ ~ _ Date: ~:'';~1 ~ ~ 11~" 3 ~ ~'~ X; - _ a~x'~at~ - ~~ _. __ -~.~~:~~ .~ • AI.~SFi~ OIL A1~TD G~.S COI~TSERQ.~~'I011T CO1rII-IISSIOIQ Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage AK 99519 Re: Swanson River F Sundry Number: Dear Mr. Brandenburg: • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~~ J ~`~ (eld, Tyonek Undefined Gas Pool, SCU 312-09 308-410 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely ff it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ,day of November, 2008 Encl. 'r~l ll~'3'~6 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION ;~ APPLICATION FOR SUNDRY APPROVALS '~ 20 AAC 25.280 r,~~~. ,~,s~~ < <! i;i ~ ~~, t 1~ ~,°~ _ a 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ~ ~ Perforate ^ Waiver0 OtherO Alter casing^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Run Kill Strin Change approved program^ Pull Tubing^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development a Exploratory ^ 160-028 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10123-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number; property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No Q Soldotna CK Unit SCU 312-09' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): '1 FEDA028997 Swanson River 17.2' Swanson River / I k II R onek Undef Gas 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft}: Plugs (measured}: Junk (measured): 10,785' , 10,785' +/-6,140' +/-6,140' 7,203', 7,325', 10,155' +/-6,140' Casing Length Size MD TVD Burst Collapse Structural Conductor 37' 20" 37' 37' Surface 2,980' 13-3/8" 2,980' 2,980' 2730 psi 1130 psi Intermediate Production 10,785' 7" 10,785' 10,758' 6340 psi 3830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): No open perfs No open perfs 2-7/8" 6.4# N-80 3,757' Packers and SSSV Type: Packers and SSSV MD (ft): N/A N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ~ Exploratory ^ Development^~ Service ^ 15. Estimated Date for 11/11/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^~ ~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: ~ t.9 WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: L =~t`'~tc~ j 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ' __ ~• ~ Phone. 11/11/2008 276-7600 Date • ~ , _y ~ -~ _.._... t ' _~ .~. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~f ~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Require ~ •~ ~ U~~„` ~~,~~ ~ ~~~~ ,~ c~~ ~ ~t~ t~i~® a ~\ APPROVED BY Approved b : COMMISSIONER THE COMMISSION Date: /•/~~ Og y c 1~ ^.. i1t14' ~ ~ Form 10-403 Revised 06/2006 ~ ,.,,,, ~ A ~ ~ ~~~ Submit in Duplicate ...~'r" 1..~ • • Swanson River Well SCU 312-09 UNOCAL 76 Current as of 11/10/2008 C a s i n g & T u b i n p RKB =1710' Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt To ~ Conductor Surf 37' Yes Surf. Surf Csg 54.5 K-55 12.615 SurF 1509' 1000 sx Surf Collar 1509' 1512' 17.5" Surf Csg 54.5 K-55 12.615 1512' 2980' 600 sx 2010' Calculate 29 6.184 Surf 250' 26 6.276 250' 1179' 23 Butt 6.366 1179' 4798' P d C 26 N-80 6.276 4798' 5756' 750sx ' ro s 8 29 5756' 7238' ThruDV 5700 CBL 29 Butt x 8rd 6.184 7238' 7242' 9-7/8" @ 8504' 29 7242' 7284` 26 P-110 6.276 7284' 8504' Collar 8rd 8504' 8507' P d C 26 P 110 6.276 8507' 9315' 750 8187' ro sg 29 6.184 9315' 10,785' sxs Calculated nln Kill Strin 17.20' RKB to Tbg Hngr N". Butt 6.4 N-80 IBT 2.441 Surf 3,757' Fish Detail NO. De th ID OD Item I, 3,757 2.441" 2.875" Mule Shoe 2, +/- 4,160' 8" piece of casing recovered during fishing operations 3, 4,181'- (+/-) 4,418' Cement 4, 4,181' - (+/-) 6,723' 4.875" 4" ?CT-39 drill pipe w / 4-718" tool joints & I-I/4" cement stinger g, +/- 6,140' Milling shoe fragments, l-7/16°x6" shot rod hanger w! 3/8"x8' shot rod attached Fish in Drill i e 6, 7,203' 6.0" Cement retainer 7, 7,325' 6.0157" 7" HES FasDrill composite Bridge Plug PERFORATION DETAIL Itt6erval Acatm T Btm Amt f Comrrellls 7,~ 7,27a 6 6 Sgld & iwlaed 1(Y2L08 7 _'?~ 7 x)i' 3Y 6.0 Sgtee~d 12/04 1Q16S 1Q 166 1' S.5 P&.1'd 10,183' 1Q23$ SS 4.5 P&~'d 1044' 1Q25S 11' 4.5 PSrA'd 1075' 1Q332' S7 4.5 P&4'd 1044' 1Q403' S9' 4.5 P&Ad 10,40$ 1Q421' 13' 4.5 P&Ad 10,425 1Q444' 19' 4.5 P&A'd 10,460' 1Q520' ED 4.5 P&rA'd 10,526 1Q546 2(I 4.5 Pfd 10,55T 1Q55$ 1' S.5 P&~'d SCU 312-09 Current Schematic with drill pipe.doc Drawn: 11/10/2008 by CVK 'ID=10,785' PBTD= 10,700' Max Deviation =2° (u) 5931' Chevron ~ • Swanson River Field Well #SCU 312-09 11/10/08 OBJECTIVE: • Clean out and isolate 77-3 sand. Recomplete, perf, and produce G-zone sands. PROCEDURE SUMMARY: (Actual) (Not Performed) • RU slickline. RIH tag fill. POOH. RD. • MIRU CTU. RIH to top of fill. Circulate/ change well over to 11.6 ppg KWM. POOH. RD CTU. • MIRU Nabors Rig 106. Test BOPE's to 3000 psi. Built KWM volume in pits. PU release pkr. CBU. POOH w/ completion. • PUMU fishing BHA. CO fill to fish. Swallow fish. (at 10,037). POOH LD thru-tubing bridge plug fish. • PUMU RTTS pkr w/ ret BP. RIH. Set BP @ 7300' 7,325'. Spot sand plug on same. PU set pkr @ 7240' 7,203'. Test same. • Mix 10 bbls of LXT cmt. Circulate cmt to pkr. Squeeze/inject cmt into zone. Reverse circulate excess. • Stung out of cement retainer (up 480'). Circulated cement the long way. Lost suction of pumps. Stuck drill pipe. Deviated from plan and attempt to fish cemented in drill pipe for 2+ weeks. • POOH. WOC 12 hrs. • PUMU Drill Bit CO assy. RIH CO to BP @ 7300'. Pressure test sqz perfs. POOH. • PUMU RTTS. RIH above sqz perfs. Negative test perfs to 8.5 ppg EMW. POOH. RIH retrieve BP @ 7300'. • PUIVIU fishing BHA. RIH to top of fill. Change well over to 8.5 ppg. CO fill to fish. CBU. Swallow fish. POOH wl fish. • PUMU csg scrapper. RIH while reciprocating tbg to PBTD. CBU. POOH. • PUMU TCP guns. RIH on DP. Correlate guns on depth. Perforate G-1 sand. CBU. Monitor well. POOH. • RIH w/ Lower completion pkr on Eline. Set same @ 10,076'. POOH. RD Eline. • PUMU Upper completion pkr and tail assy onto setting tool. RIH on DP. Stab into Iwr pkr. Set pkr @10,040'. POOH. • PUMU 50' csg patch assy. RIH set csg patch from 7255' to 7305'. POOH. Jug test well to 3000 psi. • PU RIH w/ Completion GL string w/ Chemical injection line. Stab into pkr. Land tbg. • Pressure test tbg x csg annulus to 3000 psi • ND BOPE. NU tree. Pressure test same. Release rig. • RU slickline. RI open upper Bldg sleeve. Pump/circulate pkr fluid. Displace tbg with N2. Close sldg slue. RD slickline. • RU Eline. RIH perforate G-2 sands. RD Eline. • Turn well over to Production. SCU 312-09 REVISED BY: CVK 11-10-08 Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SCU 312-09 SOLDOTNA CK UNIT 312-09 FEDA028997 5013310123 QA5267 17.20 Jobs Primary Job Type Job Category Obiective Actua{ Slart Date Actual End Date Completion -Reconfigure Major Rig Recomplete in the Tyonek G zone (G1 and G2), to develop 75.3 MBO of 8/20/2008 Work Over probable reserves. (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SCU 312-09 - - 5013310123-00 1600280 ----- - Dail Qperations 8/20/2008 00:00 - 8121_/2008 00:00 _ Operations Summary Mobilize Coil Tubing and Slick line to pad RIH w/ slickline and Tag Fill at 9855' RKB, SLM -- - - - 8/21/2008 00:00 - 8/22/2008 00:00 - -- Operations Summary Rig up Coil Tubing and begin to Mix kill weight brine to 11.6 ppg 8/22/200800:00-8/23/2408 00:00 Operations Summary Finish mixing 11.6 ppg brine, Bottom kill well with 11.6 ppg (38% CaCl2) brine 8/23/2008 00:00 - 8/24/2008 OOs00 _ - _ _- Operations Summary Mob Wireline and open Sliding sleeve at 6,619' SLM. Rigged up to fill annulus w! KWB, Pumped 274 bbls KWB. 8/2412008 00:00 -8/25/2008 00:00 ____ __ _ - Operations Summary Prep equipment for demob and load trailers that are available. 10110/2008 00:00-10/11/2008 00_:0.0 Operations Summary Mobilizing rig from SRU 41-33. __ _ 10/11/2008 OOc00 -10/12/2008 00:00 _ _ _ _ _ Operations Summary Mobilizing rig -- -- __ _ 10/12/2008 00:00.10/13/2008 00:00 Operations Summary Mobilizing rig - - - -- _ - --- _ __ _ 10113/2008'00:00 - 10/14/200800:00 - _ Operations Summary Mobilizing rig. Notified Jim Regg of AOGCC and Tim Lawlor of BLM of upcoming BOP test. BLM waived witness. 10/14/2008 00:00 - 10/15/200800:00 --- --- _ Operations Summary Mobilizing rig. Contacted AOGCC Jeff Jones to witness upcoming BOP test. 10/1512008 00:00-10/1S/200$ OOc00 __ _ ---- Operations Summary NU BOPE. Conduct Certification test on Accumulator, Charted 5 min 4000 psi, 4500 psi 15 min. Good Test. Unable to MU test joint in tbg hngr. ND BOPE. 10/1$/2008 00:00 -10/17/2008 00:00 _ Operations Summary Clean cmt debris off tbg hngr. NU BOPE. Repair VBR's. Jeff Jones with AOGCC witnessed BOPE test as follows: Test #1: Annular, Choke valves, Check Valve, Dart Valve - 250 psi low/2000 psi high. Test #2: Upper Pipe Rams, Choke Valves, Check Valve, Dart Valve - 3000 psi. Test #3: Upper Pipe Rams, Kill HCR, Safety Valve, Choke Valves - 250 psi low/3000 psi high Check all Gas Alarms, Press up 1000 psi Flow Check Super Choke, Pressure up 500 psi Flow check Manual Choke. Test #4: Upper Pipe Rams, Safety Valve, Choke Valves - 250 psi low / 3000 psi high. Test #5: Upper Pipe Rams, Upper IBOP valve, Choke Valves, kill line valve on stand pipe 250 psi low / 3000 psi. Test #6: Kill line check valve, lower IBOP valve, choke line HCR - 250 psi low / 3000 psi high. Test #7: Manual inside choke line valve - 250 psi low! 3000 psi high. Test #8: Lower pipe rams (2 7/8") - 250 psi low / 3000 psi high. 10/17/2008 00:00 -10/18/2QQ8-00:00 _ _ Operations Summary 10/17/08 @ 1900 hrs. BLM waived witness of upcoming BOP testing after ram change. Contacted AOGCC of upcoming BOP test, witness was waived. Perform Koomey test: System press 3000 psi, after closure 1500 psi, 200 psi attained @ 50 sec & full press @ 3:15. N2 bottles 4 @ 2525 psi. Unland tbg hanger @ 100K. Shear & release Baker FH Pkr @ 85K & pull hanger to rig floor. CBU 340 bbls total. Build brine wt backup to 11.6 ppg. POOH LD tbg. _._ - _ - 1 Q/18/7 Q8 00:00 - 10/19/2Q08 OOc00 _ _ ___ __ _, _ _ Operations Summary Continue to LD tbg & Completion equip. Change-out upper pipe rams. chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SCU 312-09 SOLDOTNA CK UNIT 312-09 FEDA028997 5013310123 QA5267 17.20 __ __ Dail O rations _ __ 10/18/2008 00:00 -10/2012008 00:00 __ - -- ~ __-- Operations Summary - -- --- - -- - Change upper pipe ram. Test BOPE 250 psi low 3000 psi high. Land Wear Bushing. PU/RIH w/ fishing BHA. 10/20/2008..00:00 -10/211_2008.00:00 , ___ _ _ ___ Operations Summary Cont. RIH w/ Fishing BHA on 4" DP. CBU @ 8500'. Tagged fill @ 9827'. Wash/circulated fill out to 10,037'. Set down @ 10,037'. Saw 100 psi increase in circ pressure. POOH. LD Thru-Tbg BP Fish. PUMU FasDrill BP & Setting Tool. -__ - _ 10/21/2008 00:00 -1.0/22/2008 00:00 Operations Summary RIH set FasDrill bridge plug @ 7325' RKB. POOH. PUMU FasDrill Ret. RIH Set @ 7203. Perform Injection test, .5 bpm = 440 psi / 1 bpm =1000 psi / 2 bpm = 1725 psi / 4 bpm, 2500 psi, Pumped 45 bbls total, unsting from retainer, Circulated bottoms up and bring weight of brine up to 11.6 ppg. 10/2212008 00:00. -10/23/2008`00:00 ' --- _ Operations Summary Pumped 40 bbl 15.8 ppg cement squeez finishing at 3.4 bpm, 2,800 psi. Bled pressure to 1,000 psi and unstung from retainer. POOH 7 stands (+/- 480'). and attempted to circulate drill pipe clean. Lost suction on pumps. Stick drill pipe, attempt to work free. Rig up wireline and run 1.69" gauge ring run inside drill pipe to 6,721' WLM. POOH and prep to run freepoint. 10/23/2008 00:00.-.10/24/2008 00:00 _ -- - _ ...- -- Operations Summary Run free point, found free pipe at 3956'. RU eline. Run string shot and fire. RD eline. Twist off drill pipe POOH w/123 jts of 4" DP. Test BOPs 250 low, 3000 high. AOGCC Jim Regg &BLM Tim Lawlor notified and waived witness. -- 10/24/2008 00:00 -10/2512008 00:00 _ Operations Summary Finished BOP test. RU tools and PU wash pipe assembly. T_. -- _ - 10125/2008 00:00 -10/2672008 00:00 Operations Summary RIH w/ drillpipe wash over BHA (saw tooth shoe, washpipe extensions, wash pipe, sub, bumper sub, fishing jar, drill collar) Tag top of fish at 3948' RKB. Mill over fish to 4108' Stop making progress. POOH w/ washover assembly. 10/26/2008 00:00-1.0/27/2008 00:00 _ _ __ _ _ _ _ _ _ _ _ -- _ _ Operations Summary MU/PU screw in BHA. TIH and screw into fish top. Jar on fish. Jars stop working. Trouble shoot. RU wireline. Attempt to run in hole (max OD on tools is 1-11/16"). Can't get past 3934' RKB. Pull out of hole with wireline. - _. _ __ -- 10/27/2008 00:00 -10/2872008 00:00 ___ Operations Summary Change out wireline tools (Max OD=1 "). Run in hole with string shot. Fired at 3951' RKB WLM. Pull out of hole. Rig down eline. Trip out of hole with drill pipe. MU/PU new bumper sub in BHA. Run in hole with bumper sub, fishing jars, drill collars, intensifier. Screw into fish. RU wireline and run in hole. Tag stringers of cement at end of drill pipe at 6724' RKB WLM. Pull out of hole. RU free point tools. .10!28/2008 00:00 -10/2912008 00:00 Operations Summary Run in hole with free point tools. Pipe free to wash over depth. RU string shot. Shoot at 4077' RKB WLM. Pull out of hole. Run CCL. Pull out of hole. RD wireline. Run in hole with drill pipe. Pull out of hole. Lay down 4 joints. Top of fish at 4076' RKB. Pick up wash over assembly, mill extension, wash pipe, jars, drill collars, and intensifier. Run in hole and attempt to mill over fish. No progress. Trip out of hole. 10/28/2008 00:00 -10730!2008 00:00 __ - - - --- Operations Summary Trip out of hole to get new mill. Lay down saw tooth shoe. Shoe worn out and cracked. Pick up ocean wave shoe. Trip in hole to 4018' RKB (BHA = mill, wash pipe, bumper sub, drill collars, and intensifier). Wash down to 4074' RKB. Wash to 4137' RKB. Stop making progress. Pull out of hole with BHA. MU/PU flat bottom mill (carbide), wash pipe, drill collars and jars. 10/30/2008.00:00 -10!31/2008 00:00 _ - - - - Operations Summary TIH with fishing BHA. Mill/wash to 4170'. BHA started bouncing. CBU. TOOH. Found bottom part of shoe broken off and left in hole. Test BOPS 250 psi low and 3000 psi high. Pre test contact made with BLM Tim Lawlor and AOGCC Chuck Sheve. Witness waived by AOGCC Chuck Sheve. -__-- -- - 10/31/2008 00:00 -111172008 00:00 Operations Summary Finished BOP test. PU and screw in BHA, XO, LBS, fishing jars, DC, intensifier. RIH to top of fish. Screw in. RU slickline and attempt to run swedge inside drill pipe. Finally get through and tag @6140'. RD slickline. RU eline. PU CBL tools. 11/1/2008 00:00 -11/2/2008-00:00. _ _ _ Operations Summary Reconfigure CBL tool. Run back in hole and log from 6035' - 3800'. TOC @ 4062' - 4418' with stringers to 4500'. MU and RIH with string shot, fire at 4141'. POOH with fishing BHA. PU new flat bottom shoe milling BHA. 11/2/2008 00:00 -11/372008.00:00 _ Operations Summary RIH with flat bottom milling BHA. Work down to 4167'. Mill on junk/cement. Progressed 3' to return to 4170'. Circulated the hole clean. TOOH. LD BHA. PU 6" x 5" washpipe. RIH. Wash to 4170'. Begin milling, making no progress over tool joint. Chevron Chevron -Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) SCU 312-09 SOLDOTNA CK UNIT 312-09 FEDA028997 5013310123 QA5267 17.20 Dail O rations _ - -~- _ ___ __ 11/3/200800:00 -17/4/2008 00:00 _ _ _ ___ ___ __ _ _ - - Operations Summary Continue milling @4170'. No progress. TOOH. Find metal parts from previous BHA and 10" section of 7" buttress collar wedged inside. PU 6"x4-1b/16" mill shoe with drill collars. RIH to top of fish @ 4137'. Wash over to 4170'. Mill and make only half a foot of progress. Mill appears worn out. 11/4/200800:00 -111512008 00:00 Operations Summary TOOH. LD BHA. Bottom worn off shoe. Outside cutright gone, inside cutright shows no wear. TIH with screw in sub BHA. Attempt to screw into top of fish @ 4138' RU eline. RIH with string shot, fire at 4181'. POOH with string shot. RD eline. POOH with BHA, no fish recovered. 11/5/2008 00:00 -11/512008 00:00 _ _ _ _ _ ___ - _____ _ _ - - Operations Summary PU 283' BHA with bumper sub, jars, drill collats, intensifier, TIH. Screw into fish. Work torque into pipe. RU eline. RIH correlate depth with CCL to 5000'. POOH. Arm string shot, RIH, torque pipe and fire shot at 4181'. No backoff. POOH with string shot. RIH with sinker bars and CCL. POOH. RIH with string shot and set at 4181', apply torque to drill pipe. Fire shot and note back off. unscrew pipe, pipe free. POOH with string shot (lost 8" x 1-7/16" hanger and shot rod down pipe. RD wireline. TOOH with screw in sub. Inspect threads. Good. RIH with screw in sub. Tag top of fish at 4137', screw in, pressure up and set torque. ___ _. 1U6l2008 00:00 -..11/7/2008 O11t00 _ _ Operations Summary RIH w/ 2-1116" GR to 5,000'. POOH Load 1-9116"x10' perf gun. RIH & correlate/ shoot 4,173.5'-4,177.5'. POOH LD guns. PU radial cutter. RIH to 4,174', fire, POOH, LD, RD E line. RIH retrieve 24' of DP. PU millout BHA assembly. TIH Tag at 4,161.5'. Begin milling. Received extension from AOGCC Lou Grimaldi to test BOPs when mill is POOH. 11 RI2008 00:00 -11/8/2 08 00:00 _ Operations Summary Continue to mill on fish. Make 7' to 4,170'. Recovering metal shavings on surface, no cement. CBU. Test casing to 1500 psi w/ pressure bleeding to zero in 8min. No pressure in 7"x9-5/8" annulus. RD testing equipment. POOH w/ 4" DP. RU to test 7" packoff. Contacted AOGCC Lou Grimaldi of upcoming BOP test. 11/8/200800:00 - 11/9/2008 00:00 -- - - Operations Summary Test packoff on wellhead to 1500 psi, good test. Attempt retest of casing to 1500 psi, no good. POOH LD milling BHA. Test BOPS 250 psi low/ 3000psi high. AOGCC waived witnessed. -_ _- 11/9/2008 00:00 -_ 11/10/2008.00:00 _ _ _ __ _ __ Operations Summary RIH w/ RTTS packer on 4" DP, set at 3952' Pressured up 4"x7" annulus to 1500psi, chart for 30 mins, good test. No change in 7"x9-5/8" casing annulus. Pumped down drill pipe, established injection rate of 1 bpm at 1720 psi. Release RTTS packer. Circulate well. LD RTTS packer and DP. Pull wear bushing. Rig up tubing running equipment. PU mule shoe &RIH w/ 2-718" 6.4# L-80 tubing for kill string. 11!1012008 00:00 -11/1112008 00:00 _ __ _ Operations Summary Ran 2-718" tubing kill string and Land at 3,757'. Circulated well corrosipn inhibitor, biocide, & oxygen scavenger down annulus. Begin demob of rig to SRU 211-33. Page 1 of 1 • ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, November 11, 2008 8:16 AM To: 'Walsh, Chantal [Petrotechnical]' Cc: Tyler, Steve L; Kanyer, Christopher V; Bonnett, Nigel (Nigel.Bonnett) Subject: RE: SCU 312-09 Operational Shut Down filing o`~~ ~~/ Hi Chantal, The correct form to file is a 403. The 404 is the report of the activity. The office is closed today for Veteran's Day so no one is here to receive the document. Best to send tomorrow. Tom Maunder, PE AOGCC From: Walsh, Chantal [Petrotechnical] [mailto:WalshC@chevron.com] Sent: Monday, November 10, 2008 5:14 PM To: Maunder, Thomas E (DOA) Cc: Tyler, Steve L; Kanyer, Christopher V; Bonnett, Nigel (Niget.Bonnett) Subject: SCU 312-09 Operational Shut Down filing Tom, Please find attached the 10-404 filing for SCU 312-09 (permit to drill #160-028 and sundry #308-298}, detailing our operational shutdown on the well to allow us time to assess a forward plan. Chantal Chantal Walsh PRA Petroleum Engineer, P.E. walshc@chevron.com Anchorage, AK Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7627 l=ax 1 907 263 7884 Mobile 907 227 0952 Mail Confidential Footer Privileged/Confidential Information maybe contained in, or attached to, this message. If you are nat the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7892. 11 /16/2008 Page 1 of 1 • • Maunder, Thomas E (DOAj From; Maunder, Thomas E (DOA) Sent: Friday, November 07, 2008 3:52 PM To: 'Walsh, Chantal [Petrotechnical]' Cc: Harness, Evan; Brandenburg, Tim C; Tyler, Steve L; Bonnett, Nigel (NigeLBonnett); Winslow, Paul M Subject: RE: SCU 312-09 (160-028) Chantal, et al, 1 have apprised Commissioner Foerster of the proposed plans and she has given her oral approval for you to proceed. Please have a sundry to us on Monday. This should be considered an operational SD. Tom Maunder, PE AOGCC From: Walsh, Chantal [Petrotechnical) [mailto:WalshC@chevron.com] Sent: Friday, November 07, 2008 3:42 PM To: Maunder, Thomas E (DOA) Cc: Harness, Evan; Brandenburg, Tim C; Tyler, Steve L; Bonnett, Nigel (Nigel.Bonnett); Winslow, Paul M Subject: SCU 312-09 Tom, We are currently on 5CU 312-09 (permit to drill #160-028 and Sundry #308-298) working at milling out the drill pipe that was inadvertently cemented into the well, after we squeezed off the 77-3 sands. The sands were cemented with 40 bbls of cement. We had stung out of the cement retainer and moved uphole prior to getting stuck. We ran a cement bond log an the welt and have the pipe cemented for approximately 250'. We have been milling/fishing on the drill pipe for more than 2 weeks. There are no open perfs in the well at this time. We would like to suspend operations to assess our forward plan. Our proposed suspension is: o Pressure test the casing to 1500 psi for 30 minutes o Swap out the 11.8 ppg CaCL brine for akinder/gentler 8.5 ppg water with corrosion inhibitor. Find attached the current schematic depicting were we are and a summary of operations to date. Please advise. Chantal Walsh PRA Petroleum Engineer, P.E. walshc@chevron.com Anchorage, AK Chevron North America Exploration and Production MidcontinentlAlaska SBU 909 W. 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7627 Fax 1 907 263 7884 Mobile 907 227 0952 Mail Confidential Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message aRer notifying me immediately by replying to the message or contacting me at (907) 263-7892. 11/16/2008 Page 1 of 1 Regg, James B (DOA) ~ ~~~ ~d' From: Regg, James B (DOA) ,~ ~ [~~~~, (~~ Sent: Wednesday, October 22, 2008 1:01 PM Ill To: 'Walsh, Chantal [Petrotechnical]' Cc: Tyler, Steve L; tzelenka@blm.gov; DOA AOGCC Prudhoe Bay Subject: RE: BOP test for SCU 312-09 request to delay BOPE test is acceptable to the Commission Jim Regg 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Walsh, Chantal [Petrotechnical] [mailto:WalshC@chevron.com] Sent: Wednesday, October 22, 2008 11:46 AM To: Regg, James B (DOA); tzelenka@blm.gov Cc: Tyler, Steve L Subject: BOP test for SCU 312-09 On the current Swanson River operation for SCU 312-09, while cementing off the 77-3 perforated interval in the. well, the drill pipe work string was cemented into the hole. Our forward plan is to run a string shot and attempt to back off the "un-cemented" portion of the work string, or go in with a cutter if this is to prove unsuccessful. The scheduled time for the next BOP test is tomorrow October 23rd. We are requesting a postponement of this test until we free the drill pipe currently in the well. Please advise. Chantal Walsh PRA Petroleum Engineer, P.E. ~valshc~ che~~ron.coYn Anchorage, AK Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, AK 99501-3322 Tel 907 263 7627 Fax 1 907 263 7884 Mobile 907 227 0952 Mail Confidential Footer Privileged/Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263-7892. 10/22/2008 r ~~~a~Vl~ ~"u' ~o~fs~~~~~{i~~ ALASiSA OIL AHD GA5 COH5ERQA'1'IOH COM1~II551OH Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 ~.~~~~ A~J G ~ ~ 2~G8 SARAH PAIIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ib~ Re: Swanson River Field, Tyonek Undefined Gas Pool, Soldotna CK Unit 312-09 Sundry Number: 308-298 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager) . As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cath P. Foerster Commissioner ~l DATED this day of August, 2008 Encl. ~E~~i°~~~ ~~ STATE OF ALA l~0:~-08' ALASKA OIL AND GAS CONSERVATIQ ~M I N APPLICATION FOR SUNDRY ~~P~~LS ~~~~~t„Jll ~,~ ~ 20 Aac e ^ Waiver^ Other^ 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ~111C~~ ~ Alter casing^ Repair well ^ Plug Perforations L~ Stimu ate ^ Time Extension ^ Change approved program^ Pull Tubing^ Perforate New Pool^ ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development a, Exploratory ^ 160-028 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10123-00 ~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property Tine where ownership or landownership changes: Spacing Exception Required? Yes ^ No 0 Soldotna CK Unit SCU 312-09 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): FEDA028997 ~ Swanson River 17.2' Swanson River /Hemlock Oil /T onek Undef Gas 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10, 785' ~ 10, 785' 10,155' 10,155' 10,155' 10,155' Casing Length Size MO TVD Burst Collapse Structural Conductor 37' 20" 37' 37' Surface 2,980' 13-3/8" 2,980' 2,980' 2730 psi 1130 psi Intermediate Production 10,785' 7" 10,785' 10,758' 6340 psi 3830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.4# N-80 6,753' Packers and SSSV Type: Packers and SSSV MD (ft): Baker Model "FH" Retrivable packer / N/A 6,642' / N/A 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development^ Service ^ 15. Estimated Date for 9/1/2008 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas^ ~ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~~ one X276-7600 Date 8/18/2008 ~~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~\~S~ S~n~~ ~b~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ~~~,,, h - ` Other: '~~©~ QS ~ ~~ ~ ~~~ . ~Ah~GC~~~S p ~~~~ . ~ W ``~i~~SS ~ST, Subsequent Form Required: ~~~ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~'v!J ~- Form 10-403 R vised 06/2006 Submit in Duplicate Page 1 of 4 Maunder, Thomas E (DOA) From: Tyler, Steve L [tylerst@chevron.com] Sent: Friday, August 22, 2008 12:24 PM To: Maunder, Thomas E (DOA) Cc: Walsh, Chantal [Petrotechnical]; Kanyer, Christopher V Subject: SCU 312-09 Revised Proposed Workover Summery & Dwg Attachments: Tyler, Steve L.vcf; SCU 312.09 PROPOSED Schematic Rev#2.doc; SCU 312-09 AOGCC Revised Procedure 8-22-08.doc Tom Here is a revised workover summery and drawing of SCU 312-09. let us know if you need anything else. ..,.~ Alaska Wellbore Maintenance Team Leader Chevron North America Exploration and Production Midcontinent/Alaska SBU 909 W. 9th Avenue Anchorage, AK 99501-3322 ~i Office: (907) 263-7649 Cell: (907) 350-6295 Home: (907) 696-1837 1~Fax: (866) 244-1439 ~Emait: tylersl a~chevron.com 8122/2008 Chevron Swanson River Field Well #SCU 312-09 8/14/08 OBJECTIVE: • Clean out and isolate 77-3 sand. Recomplete, perf, and produce G-zone sands. PROCEDURE SUMMARY: • RU slickline. RIH tag fill. POOH. RD. • MIRU CTU. RIH to top of fill. Circulate/ change well over to 11.6 ppg KWM. POOH. RD CTU. • MIRU Nabors Rig 106. Test BOPE's to 3000 psi. Built KWM volume in pits. PU release pkr. CBU. POOH w/ completion. • PUMU RTTS pkr w/ ret BP. RIH. Set BP @ 7300'. Spot sand plug on same. PU set pkr @ 7240'. Test same. • Mix 10 bbls of LXT cmt. Circulate cmt to pkr. Squeeze/inject cmt into zone. Reverse circulate excess. • POOH. WOC 12 hrs. • PUMU Drill Bit CO assy. RIH CO to BP @ 7300'. Pressure test sqz perfs. POOH. • PUMU RTTS. RIH above sqz perfs. Negative test perfs to 8.5 ppg EMW. POOH. RIH retrieve BP @ 7300'. • PUMU fishing BHA. RIH to top of fill. Change well over to 8.5 ppg. CO fill to fish. CBU. Swallow fish. POOH w/ fish. • PUMU csg scrapper. RIH while reciprocating tbg to PBTD. CBU. POOH. • PUMU TCP guns. RIH on DP. Correlate guns on depth. Perforate G-1 sand. CBU. Monitor well. POOH. • RIH w/ Lower completion pkr on Eline. Set same @ 10,076'. POOH. RD Eline. • PUMU Upper completion pkr and tail assy onto setting tool. RIH on DP. Stab into lwr pkr. Set pkr @10,040'. POOH. • PUMU 50' csg patch assy. RIH set csg patch from 7255' to 7305'. POOH. Jug test well to 3000 psi. • PU RIH w/ Completion GL string w/ Chemical injection line. Stab into pkr. Land tbg. • Pressure test tbg x csg annulus to 3000 psi • ND BOPE. NU tree. Pressure test same. Release rig. • RU slickline. RI open upper Bldg sleeve. Pump/circulate pkr fluid. Displace tbg with N2. Close Bldg slue. RD slickline. • RU Eline. RIH perforate G-2 sands. RD Eline. • Turn well over to Production. SCU 312-09 REVISED BY: CVK 8-14-08 Chevron OBJECTIVE: • Clean out and isolate 77-3 sand. Recomplete, perf, and produce G-zone sands PROCEDURE SUMMARY: • RU slickline. RIH tag fill. POOH. RD. • MIRU CTU. RIH to top of fill. Circulate/ change well over to kill wt mud. POOH. RD CT • MIRU Production hoist. Test BOPE. Built mud volume in pits. PU release pkr. CBU. C • PUMU fishing BHA. RIH to top of fill. CO fill to fish. CBU. Swallow fish. POO /fish. • PUMU RTTS pkr w/ ret BP. RIH. Set BP @ 7300'. PU set pkr @ 7240'. Tes ame. Swanson River Field Well # SCU 312-09 8/14/08 w/ completion. • Mix 10 bbls of LXT cmt. Circulate cmt to pkr. Squeeze/inject cmt into e. Reverse circulate excess. °~ • PooH. woc 12 hrs. ~~ ~.~ ~- ~ ~c~3v~c~V~~3 ~ < • PUMU csg scrapper. RIH while reciprocating tbg to PBTD. C .POOH. • RIH w/ completion pkr. set same @ -~-9,960'. POOH. RD ine. • PUMU 50' csg patch assy. RIH set csg patch from 7 ' to 7305'. POOH. Jug test well to 3000 psi. • RIH w/ 2-7/8" workstring to PBTD. CBU/ Chan well over to completion brine. POOH. • ND BOPE. NU adapter spool. NU Tension gr Bowl. NU BOPE. Shell test sam • PU RIH w/ Completion GL string w/ C mical injection line. Stab into pkr. Land • Pressure test tbg x csg annulus to 0 psi • ND BOPE. NU tree. Pressure st same. Release rig. • RU slickline. RI open sl sleeve. Pump/circulate pkr fluid. Displace tbg with N2. Close Bldg slue RD slickline. • RU Eline. RIH perf to G-zone sands. RD Eline. • Turn well over 312-09 REVISED BY: CVK 8-14-08 Swanson River Well SCU 312-09 As Completed 12/30/04 RKB =17.20' CIBP o CmIN 10,177 Inflatable Bridge Plug JEWELRY D E T A I L NO. De th ID OD Item 17.20' 2.441 7.0325 Schaffer 7-1/16" 75AJ0 Tb Hn r w/ 2-1/2" H BPV Prorle A, 2500' 2.441 4.50 Chemical Injection Mandrel B, 6628' 2.31 3.74 BOT Model "CMU" Sldg Slve („ 6642' 2.42 5.968 BOT 47 B2 Model "FH" Retrievable Pkr w/ 30k shear ring p, 6692' 2.25 3.510 XN Profile Nipple E, 6735' 2.441 5.75 WLEG 10,153' CIBP set in kr F, 10,150' Tbg Cut 3' above pkr. found pkr (a~ 10,153'. 5. 10,150' 2.42 BOT "FH" kr, 7", 29# x 2-7/8" 6. 10,217' 2.374 5.50" x 4.593" Cameo "MM" Mandrel 7. 10,260' 2.50 Brawn HS-16-1 kr, 7", 29# x 2-7/8" 8. 10,296' 2.374 5.50" x 4.593" Cameo "MM" Mandrel 9. 10,335' 2.50 Brown HS-16-1 kr, 7", 29# x 2-7/8" 10. 10,372' 2.313 3.668 Otis "S" Profile Ni le, Position #3 11. 10,404' 2.374 5.50" x 4.593" Cameo "MM" Mandrel 12. 10,448' Locator Seal Ass 13. 10,449' BOT "Fl" Pkr 14. 10,454' Cameo "D" Ni ~ de 15. 10,547' 45° cut on tb 'oin[ PERFORATION DETAIL C a s i n & T u b i n size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt To Conductor Surf 37' Yes Surf. Surf Csg 54.5 K-55 (2.615 Surf 1509' 1000 sx Surf Collar 1509' 1512' 17.5" Surf Csg 54.5 K-55 12.615 1512' 2980' 600 sx 2010' Calculated 29 6.184 Surf 250' 26 6.276 250' 1179' 23 Butt 6.366 ] 179' 4798' P d C 26 N-80 6.276 4798' 5756' 750 sx ' ro s g 29 5756' 7238' Thru DV 5700 CBL 29 Butt x 8rd 6.184 7238' 7242' 9-7/8" @ s5o4' 29 7242' 7284` 26 P-110 6.276 7284' 8504' Collar 8rd 8504' 8507' d 26 6.276 8507' 9315' 750 8187 Pro Csg 29 P 110 6.184 9315' 10,785' sxs Calculated bID 17.20' RKB to Tbg Hngr 9", Butt 6.4 N-811 Butt 2.441 Surf (,73~' Interval Accum Top Btm Amt s f Comlr-ents 7,264' 7,270' 6' 6 77-3 sand - 2" gwu 7,275' 7,295' 20' 6.0 ueezed 12/04 10,165' 1Q 166' 1' S.5 P&A'd 10,183' 10,238' S5' 4.5 P&A'd 10,244' 10,255' 11' 4.5 P&A'd 10,275' 10,332' ST 4.5 P&A'd 10,344' 10,403' S9' 4.5 P&A'd 10,408' 10,421' 13' 4.5 PBcA'd 10,425' 10,444' 19' 4.5 P&A'd 1Q460' 10,520' 6lY 4.5 P&A'd 10,526' 10,546' 20' 4.5 P&A'd 10,55T 10,558' 1' S.5 P&A'd SCU 312-09 CURRENT Schematic_12-04.doc REVISED: 8/26/2004 by SLT 02/14/2005 by CRW Max Deviation = 2° (a7 5,931' Swanson River Well SCOT 312-09 PROPOSED as of 8/22!08 f_ncinn R Tnhine RKB =17.20' C,R P J O'a: 7260' Size T e Wt Grade Thrd ID To Btm Hole Cmt Cmt To Conductor Surf 37' Yes Surf. Surf Csg 545 K-55 12.615 Surf 1509' 1000 sx Surf Collar 1509' 1512' 17.5" Surf Csg 54.5 K-55 12.615 1512' 2980' 600 sx 2010' Calculated) 29 6.184 Surf 250' 26 6.276 250' 1179' 23 Butt 6.366 1179' 4798' 26 N-80 6.276 4798' 5756' 750 sx 5700' Prod Cs g 29 5756' 7238' Thru Dv CBL 29 Butt x 8rd 6.184 7238' 7242' 9-7/8" @ ssoa' 29 7242' 7284` 26 P-110 6.276 7284' 8504' Collar 8rd 8504' 8507 26 6.276 8507' 93]5' 750 ~~~ 8187' Prod Cs g 29 P-110 6.184 9315' 10,785' (alaJmal bin 17.20' RKB to Tbg Hngr 3",Butt 6.4 \-80 IB'f 2.411 Surf 10,0011' __-__ _ _IFWF I.RY' rIF.TAiI. cla 10.1. ~• a., Pkr ~~ 10,1 JI Cml 10,1 \O. De th ID OD Item 17.20' 20325 Schaffer 7-1,16" 75:WO T Nn r, w! 2•lR" H BP\' Profile TB:\ GIJI #I. 2-7i8" SFO GL'tl 'rBA Gl.~l #2. 2-7/8" sec) GL~I TB:\ GL~I #3. 2-718" SFO GL.~1 TBA (:1.11 #4. 2-718" SFO GLSt 1. TB:\ GL~1 #5. 2-718" SF(} GLM TBA Gl.~l #6. 2-718" SFO (:LEI TBA GL~1 #7. 2-78" SFO G[.1[ TBA GL~I #8. 2-718" SFO GLDI 10,018' 2.313 Sld~ Sleeve j, IO,U23' 2.111 Chemical Conventional 1'ie-In Mandrel, 2-718" j, 10,039' 2.985 BOT "E" Anchor Seal Acsv, Size SO-10 _5. 10,040' 4.0 ROT `F-1" Retainer Pkr, Size 8_,-:t0 6, 10,053' 2.313 Sld~ Sleeve 7, 10,075' 2.106 BOT Seal Asst', Size 80.32 $, 10,076' 3.25" BOT `DB" Retainer Pkq Size &1-32 w/ 6' SBE 9, (0,086' 2.25 3.510 \\ Profile \ipple 10. IU,089' 2.411 5.75 Half CIS 10,153' Tbg Cut 3' above pkr. found "FH" p1Q @ 10,153' in 12/04. Btm of com letion ewe! fish 10,547' PERFORATION DETAIL I ttteval Top Btm Amt Accum spf Comtlat~ 7,264' - 7,270' 6' - 6 - ~ 1'ivpoxrl to be s~'d & Mated --- - 7,275 - 7,29? ~ 20' 6A Sglleued 12N4 -- 1Qt160' ~ 11),071' II' 6A Fb~dGl 10,1})4' _10,107 I 13' 611 ;Ib~dG 2 - - 10.115 N1,134' 19' 60 fU ~edG2 lU.ld3' 10,1~K' ~ 2' 6A Ippo~dG2 IQIfiS' 10,168 1' ~ S5 ' P&\'d _ 10,1 ffi' 1038 } _ ~SS' 45 P&A' d 10,244' 1054 1', I ~ ~ 45 P&a'd 1Q275' 10332 ST 45 P&A'd 10,344' 10,403 4)' 45 P&a'd 1Q406' 10,421' 13' 45 P~1' d 10425' 10444 19' ~ 45 P&A'd 1Q,SST 10558 1' S5 PS~r\'d SCU 312-09 PROPOSED Schematic Rev#2.doc Drawn: 6/5/2006 by SLT TD= 1Q785' PBTD= 10.700' Max Deviation =2° nn 5,931' NABORS 106E BOP DATA Stack: Size 13-5/8 in Pressure Rating 3000 psi Nace Trim Yes Annular: Make/Model Shaffer Spherical Pressure Rating 5000 psi Closing Volume Opening Volume Ram: Make/Model Shaffer SL VBR Pressure Rating 5000 psi Closing Volume Opening Volume Ram: Make/Model Shaffer SL Blind Pressure Rating 5000 psi Closing Volume Opening Volume Ram: Make/Model Shaffer SL Pipe Pressure Rating 5000 psi Closing Volume Opening Volume Kill line: Line size 2 inch Valve (1st) Manual Valve (2nd) HCR Choke line: Line size 3 inch Valve (1st) Manual Valve (2nd) HCR GL Job - Plug & Abandonment Location - SCU 312-09 Rig - Nabors #106E ) ) I (ß'o - o~) ¡Ie¡ () .... IS- è 11ò~ 111 Unocal Alaska 909 W. 9th A venue Anchorage, AK 99501 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com UNOCAL Debra Oudean G & G Technician Date: March 10, 2005 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 jJ;~;l~l~fu li~~~ f¡t1~~f$j~j:~;h~~æ:i~~í¡:~~:iti)Œ:i[~~J 1i¡~j:r~~b~~~ ~IJj ~j~~ j SCU 24A-05 Schlumberger SLIM CEMENT MAP TOOL 5 INCH ; 12/7/2004;4300-7700, 1 l' l' , ]SCU 24A-05 . rSchl~~bergedG"AMMA RAY LOG TO SPOT TCP GUNS . 15' INCH ¡12/12/20041230o~7510 f' 1 t 1 :[' 11' . 1.lsëlT3i 2-09 "sChlu;';bêriìör i ~~~:LE:¡-ïÓN REcORD iÑFLÃTABŒSRIDGE" ·-¡s iNëHr1iiiì2óõ4F3ÕÖ:74õOT"iT u 'il~Ñôë:D I / SCU 312-09 S~hlu~berger COMPLETION RECORD 2 HSD POWERJET 6 SPF, 5 INCH '12130/2004'6790-7306 '; . '1" ... 1'1' . .. ",I 60 DEGREE PHASED ' / SCU 438-08 SChlUmbergerlCOMPLETION RECORD 2.5 POWERSPIÀAL 5 INCH: 11/27/2004;.5857-5867 '; 1- 1 1 V '__'.. _.'" .."_...._.,,._ ..~__.~_, __ .,,_ _.__..~~ERJET_...__....._,.~.. ,.'" ~. ._....__ '" ~.._"..' __.... _. _ . ". ,. _ __....1____...,... ,'-"__....,.. ,o_.___..~ __..0__.,... _ _........"......., ._-,-,_~.---" ,..,,'..__ _'" SCANNED JUN 1 6 2005 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Rty7µ¡ ~ Date: :3/15 -,STATE OF ALASKA ALASKA 1 AND GAS CONSERVATION COMMIS~. 1 i';;,",':'",,(:'.>lI E:, E:, WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: OilD GasD Plugged U Abandoned[1] SuspendedD WAGD 1b. Well Class: ~~··t~~B 1. 3 2005 20AAC 25.105 20AAC 25.110 Development[p .. .' ", . ...~~f?~,?,~î~P~,C1r GINJ 0 WINJ 0 WDSPL 0 No. of Completions 2 11] Other Recomplete Service 0 t\,i::'::;..Stratigraþ'ff¡t -rJistO; 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: (:;')'(:t¡W .¿:~ Union Oil Company of California Aband.: 12/30/04 60-28 ~1..~t./1 3. Address: 6. Date Spudded: 13. API Number: PO Box 196247, Anchorage, AK 99519 n/a 50-133-10123 4a. Location of Well (Go~ernmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1865 F_L, 745 F,l, Sec. 09, T7N, R9W n/a SCU 312-09 Top of Productive Horizon: d vIJ 8. KB Elevation (ft): 15. Field/Pool(s): 1865 FØ-, 745 filL, Sec. 09, T7N, R9W 9' v 17.2' Swanson River Field 9. Plug Back Depth(MD+ TVD): Hemlock, Tyonek 10,155' 10. Total Depth (MD + TVD): 16. Property Designation: 10,785'/10,785' Soldotna Creek Unit 11. Depth Where SSSV Set: 17. Land Use Permit: n/a 19. Water Depth, if Offshore: 20. Thickness of Permafrost: n/a feet MSL n/a Total Depth: 1865 FiL, 745 RIl, Sec. 09, T7N, R9W 4b. Location of Well (State Base Plane Coordinates): Surface: X = 343,075, Y = 2,454,140 TPI: X = 343,075, Y = 2,454,140 Total Depth: X = 343,075, Y = 2,454,140 18. Directional Survey: Yes 0 No 11] Straight Hole 21. Logs Run: SCMT, GR-CCL 22. CASING WI. PER GRADE FT. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): Flowing Oil-Bbl: -+ 0 Oil-Bbl: ...... 20" o o o 37' 2,980' 10,785' 13-3/8" 54.5# K-55 23-29# N-80 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 7,264'-7,270' 6' 6 SPF 77-3 sand - 2" guns 7,275'-7,295' 20' 6 SPF Squeezed 12/04 10,165'-10,166' l' 5.5 SPF P&A'd 10,183'-10,238' 55' 4.5 SPF P&A'd 10,244'-10,255' 11' 4.5 SPF P&A'd 10,275'-10,332' 57' 4.5 SPF P&A'd 10,344'-10,403' 59' 4.5 SPF P&A'd 10,408'-10,421' 13' 4.5 SPF P&A'd 10,425'-10,444' 19' 4.5 SPF P&A'd 10,460'-10,520' 60' 4.5 SPF P&A'd 10,526'-10,546' 20' 4.5 SPF P&A'd 10,557'-10,558' l' 5.5 SPF P&A'd 26. Date First Production: December 30,2004 Date of Test: Hours Tested: Production for Test Period Calculated 24-Hour Rate Flow Tubing Press. Casing Press: o o o 37' 2,980' 10,785' 17.5" 9-7/8" See Schematic for Detail See Schematic for Detail 24. TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 6,735' 5,968'; 10,150'; 10.260; 10,335; 10,449' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED SIZE 2-7/8" Gas-MCF: o Gas-MCF: Gas-Oil Ratio: Water-Bbl: Produced Water Water-Bbl: Choke Size: Oil Gravity - API (carr): 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". none SCHN~EC JUt 2 5 2005 L Form 10-407 Revised 12/2003 o F~ 1 G \ !\J A L RBDMS BFL FEB 24 2005 tf '(.1 CONTINUED ON REVERSE 28. GEOLOGIC MARKERS ) NAME M[' TVD Sterling_B _MJ F 1648 1648 Sterling_A_MJ F 2961 2961 Beluga 3309 3309 Mid_Beluga_MJF 4480 4480 Tyonek_MJF 5312 5312 Tyonek 5314 5314 Base_Tyonek 10179 10179 Hemlock_MJF 10180 10180 TD 10785 10785 29. {ORMATION TESTS Include and briefly sun.Jze test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". none 30. List of Attachments: Schematic, Daily Operations Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Tyler 263-7649 Printed Name: Neil MaQee Title: Acting Drilling Manager Signature: '-1/). ~r Phone: 907-276-7600 Date: ::2. /¡ (¿; /ó 6 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 a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, 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 elevation in feet above mean low low water. 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: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 UNOCALe RKB =17.20' Size 20" 13- 3/8" DV Collar 13- 3/8" ,- - $t ~ .. ü ~ ~~ ~~ @ u o ¡.. - - ~ ( .\ I A , ~ :¡ . ~ 7" 7" 7" 7" 7" 7" 7" 7" Q ..~ <:> . ~ :-.", @ ~! u ... :t'" ~ e ~~'f. .."\" ;~~ ~ ~;; ~~".;; )~, ~ ~~t ~ ~ :..~ '- l:j;¡;I ;,1·',·'~.. , I , ~. ro·.:'.; >/, .1; ~)-~ ~ ~ C DV Collar I 7" 7" Tubin~ 2 7/8", Butt .rated 11' off detph . ) Type Conductor Surf Csg Surf Csg Prod Csg Prod Csg Wt ) Swanson River Well SCD 312-09 As Completed 12/30/04 Grade Casing & Thrd ID Tubing Top Btm Surf 31' 54.5 K-55 54.5 K-55 ~ -1L- 23 Butt 26 N-80 ~ ~ Butt x 8rd 29 26 P-110 ~ f29I P-110 8rd 17.20' RKB to Tbg Hngr I 6.4 I N-80 I Butt 12.615 Surf 1509' 1509' 1512' 12.615 1512' 2980' 6.184 Surf 250' 6.276 250' 1179' 6.366 1179' 4798' 6.276 4798' 5756' 5756' 7238' 6.184 7238' 7242' 7242' 7284' 6.276 7284' 8504' 8504' 8507' 6.276 8501' 9315' 6.184 9315' 10,785' 2.441 Surf I 6735' Hole Cmt Cmt Top Yes Surf. 1000 sx Surf 600 sx 2010' (Calculated) A. B. C. D. E. Depth 17.20' 2500' 6628' 6642' 6692' 6735' 10,153' 10,150' 10,150' 10,211' 10,260' 10,296' 10,335' 10,372' 10,404' 10,448' 10,449' 10,454' 10,547' ID 2.441 2.441 2.31 2.42 2.25 2.441 2.42 2.374 2.50 2.374 2.50 2.313 2.374 ~ , '¡¡J.> PERFORATION DETAIL .:., \ i- ..~ Interval Accum ~." ~ '.~ " Top Btm Ant spf Comœnts ~;:,¡ .. ""''l.I'IW''''~" 'II,' ti. 7,264' 7;1.70' 6' 6 77-3 sand - 2" guns ) ,. ;t.\ 7;275' 7;295' 20' 6.0 Squeezed 12/04 ~~( .. 10,165' 10,166' l' 5.5 P&A'd ~\ .' '\ 10,183' 10,238' 55' 4.5 P&A'd ' ;j -{ 14~. '.' .....'~. i...· .~ . ',.' .., 10,244' 10,255' 11' 4.5 P&A'd -:~. I;~··~~;r~~ 1.... .., .' 10,275' 10,332' 57' 4.5 P&A'd '. ~ þ,..,..: »,..' ~ AOo ¡ \~~'~~~i.. 10,344' 10,403' 59' 4.5 P&A'd .~ '}¡.;.;~'Ir:' ~., , 6,..·. 10,408' 10,421' 13' 4.5 P&A'd ~~~~~a~· ~..,; f' ."...~ ". 1 0,425' 10,444' 19' 4.5 P&A'd 'Io~ '- 10,460' 10,520' (jJ' 4.5 P&A'd TD= 10,785' PBTD= 10,700' 10,526' 10,546' 20' 4.5 P&A'd Max Deviation = 20 @ 5,931' 10,557' 10,558' l' 5.5 P&A'd SCU 312-09 CURRENT Schematic 12-04 17.5" 750 sx 5700' Thru DV CSL 9-7/8" @ 8504' 750 sxs 8181' Calculated ~Inflatable Bridge Plug JEWELRY DETAIL OD Item 7.0325 Schaffer 7-1/16" 75AJO Tb~ Hn~r, w/2-1/2" H BPV Profile 4.50 Chemical Injection Mandrel 3.74 BOT Model "CMU" Sldg Slve 5.968 BOT 47 B2 Model "FH" Retrievable Pkr w/ 30k shear ring 3.510 XN Profile Nipple 5.75 WLEG CIBP set in pkr Tbg Cut 3' above pkr. found pkr @ 10,153'. BOT "FH" pkr, 7", 29# x 2-7/8" 5.50" x 4.593" Cameo "MM" Mandrel Brown HS-16~1 pkr, 7", 29# x 2-7/8" 5.50" x 4.593" Cameo "MM" Mandrel Brown HS-16-1 pkr, 7", 29# x 2-7/8" 3.668 Otis "S" Profile Nipple. Position #3 5.50" x 4.593" Cameo "MM" Mandrel Locator Seal Assy BOT "FI" Pkr Camco "D" Nipple 450 eut on tbg joint NO. F. 5. 6. 7. 8. 9. 10. tt. 12. 13. 14. 15. REVISED: 8/26/2004 by SL T 02/14/2005 by CR W 9/25/04 ) ) PJSM. RU slickline and lubricator. Pressure test to 1500 psi. RIH with 2.25" GR down to 10,324'. Tool set down. Picked up tools and had no spang action and a 400 Ib overpull. RD Pollard and secured well. 9/26/04 PJSM and prime pump truck. Pumped 60 bbls of lease water down tubing. Tubing had 150 psi, annuli had 1200 psi and surface had O. Pumped 1 bpm rate with pressure at 150 psi. After 5 bbls pressure went to 100 psi. Tubing went on a vac after 12 bbls wlrate at 3 bpm. Raised rate to 4 bpm and pumped 60 bbls total. Annuli pressure started dropping slowly after 20 bbls was pumped and was at 950 psi after 60 bbls. Surface casing 0 psi. Pumped 65 more bbls of lease water down tubing at 4 bpm with tubing on vac, annuli pressure 900 psi and steady and 0 on surface. Bled annuli down to 0 psi. RU to pump down annuli. Pumped at 1 bpm rate: at 1 bbl pressure 0; 2 bbl pressure 210 psi; 3.6 bbls pressure 700 psi; 4.5 bbls pressure 1500psi. Shut annuli in at 1500 psi. Lost no pressure, test good. Left 1500 psi on annuli. Rigged pump truck for standby and secured well. 9/27/04 PJSM, RU Pollard slickline and pressure test to 1500 psi. RIH w/2.3T' brush down to 10,200' KB. Pulled tools up to 10,000' KB and waited on vac truck. RU vac truck and pumped 30 bbls of lease water down tubing. Went back down and brushed tubing from 10,200' up to 10,100' 8 times. Pulled up to 10,000' and pumped 30 more bbls of lease water down tubing. POOH and RD Pollard slickline. PJSM, rig up APRS wireline and pressure test to 1500 psi. RI H with 2.18" OD Halliburton easy drill bridge plug down to 10,177' KB (20' from bottom of packer) and set plug at 10,177' KB. (Had 900 Ibs on wt indicator when fired. After 3 minutes wt dropped off to 800 Ibs). POOH Rig down APRS and secure well. Annuli had 1725 psi and tubing 0 psi. 9/29/04 No Operations PJSM, rig up hard lines, prime pumps, pressure test lines to 3000 psi; and insert wiper ball locked out by 2 valves. Pumped 5 bbls of lease water down tubing followed by 20 bbls of G neat cement. Cement was 15.7 density. Pumped cement at 2 bpm while tubing on vac. Launched Halliburton foam wiper ball and pumped 5 bbls of Biozan at 2 bpm with tubing on vac. Followed this by pumping 119 bbls at 4 bpm with tubing on vac. Wiper ball never bumped up. Call town. Told to pump tubing volume. Started pumping tubing volume and 70 bbls into it had a 1500 psi spike. Continued to pump until 200 bbls total, after cement, of lease water was pumped down tubing. Tubing was still on vac. Suspended operations, RD pump truck. 10/2/04 PJSM, RU Schlumberger pump truck, hard lines and valves to launch Wiper Dart & 4" Halliburton wiper ball. PT lines to 3000 psi. Pump 15 bbls of lease water to clear pipe. Pump 20 bbls of G neat cement (100 sx) at 4 bpm, launch nerf ball and dart, pump 5 bbls of biozan polymer and 115 bbls lease water. Well on vac and after 111 bbls of lease water pressure spiked to 800 psi and then went back on vac. Shut in, RD, secure well. 10/4/04 RIU Run 2.25 Gauge Ring to 10,175' WLM RD. Operations on hold 10/9/04 PJSM. RU and test Pollard. RIH with bridge plug. Tie in to Otis XO Sliding Sleeve at 10116' RKB and top of BOT FH packer at 10150' RKB. Unable to get CCL down into packer as bridge plug kept setting down in tubing just below packer bottom. Pulled back up and tied into 3' sliding sleeve at 10116' RKB and packer top several times. Dropped back into packer and set top of Halliburton 2 7/8" EZ-Drill Bridge Plug at 10153' RKB. Plug set --100# weight loss on set. Set in place for five minutes, picked up above plug free & RIH and set on plug.) POOH POOH LD APRS. Finished RU Schlumberger pump truck and test hard lines. RU Pollard. SCU 312-09 morning report summary, CONFIDENTIAL: last revised 2/16/2005 Page 1 Lu~ricate and bleed 98 Bbls of le"Jwater into tbg & test to 1500#.6 each 5 ITIII/ute readings as follows; 1500#, 1480#, 1465#, 1440#, 1440#, 1435# and 1435#. Test on bridge plug good. Bleed tubing down to 650# RIH with 2.25" GR on Pollard set down on bridge plug at 10153' RKB. POOH. RIH with 2.5" BO shifting tool to 10116' RKB and work XO sliding sleeve open tubing. Dropped to 130# when sleeve opened. POOH Circulate lease water down tubing and up production casing. Gas and oil returns for 60 bbls. Pumped a total of 285 bbls and getting oil & gas free returns. Shut in annulus and jug test well. To 1500#, 5 minute readings 1500#, 1495#, 1495#, 1490#, 1490#. Holding solid -- test good. RIH with 2 1/2" BO shifting tool and close XO sliding sleeve with 1490 on well. Bleed casing off and tubing went to 1140#. Pump tubing back up to 1600#. 5 minute readings 1540#, 1540#, 1540# and 1540#. Rock solid good test. Bleed pressure off well & POOH with wire line. RO Pollard wireline and Schlumberger. 10/18/04 RU, Spot and hook up choke manifold. Charge pump manifold. Spot koomey and run koomey lines. Attempted to scope derrick-unsuccessful. 10/19/04 RU guy wires. ND tree. NU BOP and related equipment. RU work platform. Make up test joint, function test and shell test BOP. Continue RU. Test BOP and related equipment 250 psi low and 3000 psi high. RU landing joint and pull tubing hanger free. Rig up APRS. RIH with 2 1/4" jet cutter, locate and cut 2 7/8" tubing 3' above packer at 10150', POH and rig down APRS. Pull hangar to floor and break off same, RU Weatherford, spot catwalk and pipe racks. LD liner. 10/20/04 Change out Weatherford tongs 2X. LD 9236' 4" tubing. MU tubing hangar, land in well head, change ram's from 4" to 3 1/2", test door seals to 3000 psi, LO hangar and 4' handling equipment. LO 3 1/2" and 2 7/8" tubing. RO Weatherford equipment. Set new tubing hangar, test blind rams to 250 psi and 3,000 psi. Change rams from 3 1/2" to 27/8", test same to 250 and 3000 psi. Load pipe rack with 98 joints and strap. MU casing. Scrapper and run 8 joints, of 2-7/8 tubing. 10/21/04 RIH with casing scraper picking up 2 7/8" tubing, drifting every joint. Circulate 1 hole volume at 3 bpm. POOH lay down scraper assembly. RU Schlumberger, run SCMT log 7350' to 4300'. RD Schlumberger RU to run 2 7/8 completion. PJSM. PU Baker production assembly. RIH W /2 7/8 tbg. 14 stands. 10/22/04 RIH with 2 7/8" completion. PU chemical injection mandrel, hook up stainless steel tubing, test line to 2000 psi. RIH with 2 7/8" completion banding stainless tubing to pipe. RIH with 2-7/8" completion banding stainless tubing to pipe. PU hangar and landing joint, hook up stainless tube to hangar, land completion. Waiting on Pollard crew RU Pollard. RIH set plug in x-nipple. Pressure up on tubing, packer set at 800 psi continue pressuring up to 4200 psi, held same for 5 minutes. Pollard POOH, did not have plug, sheared off, run # 2. RIH retrieve plug. PU tubing. To 750psi. Pressure test annulus to 4200 psi. hold 10 min. Bleed off RD. Test equipment. Set BPV. RD. NO BOP Change out lower annulus valves, Set tree. Press test void to 5,000 psi. Press test body to 5,000 psi. RD. 10/24/04 RU wire line to open sleeve @ 6654'. PJSM, RU pump truck and nitrogen. Choke skid and Johnson tank. RU and test new annulus valves 3,000 psi. Test lines to 5,000 psi. Pump 50 bbls of lease Water with 1 % CRW-132, Pump 50 bbls lease water 1% CRW-132 & 8 bbls diesel, Pump 20 bbls Lease water CIW -132, Pump nitrogen, Get 33 bbls returns. Stop RIH with wireline tag fluid @ 5600' Pump Nitrogen, get 5 more bbls returns, RIH W/ wireline tagged @ 6,612'WLM 6,629 KB. Close sleeve @ 6,654' PU tubing from 2,200 to 2,500 psi with no returns. SIW 2,500 on tubing. POOH. RD Sclumberger, secure well. 11/2/04 SCU 312-09 morning report summary, CONFIDENTIAL: last revised 2/16/2005 Page 2 PJ~M. RU. PT lubricator 300# 10"_ )nd 4000# high (OK). RIH, tie in and attemJL~O fire guns (no go). POOH, trouble shoot and find firing head leaked on first gun run. Rebuild same. RIH to bottom. Tie in to (77-3 sands 7275' to 7295') using Gamma Ray correlated to Schlumberger SCMT Log ran 10/21/04. Fired gun (20' of 2" HDS Power Jet 6 SPF) with good indication of shot. Got 60 psi tubing pressure increase in first three minutes after shot (from 2464# prior to shot & 2524# after.) POOH. RD. 11/13/04 PJSM/RU. Pressure test hard lines to 4500 psig (OK). Pump 1.8 Bbls into production annulus to get 2000#. Found well with 1980 # tubing pressure and bleed gas cap off to Johnson tank. Got fluid at 500# while flowing to tank. Lined up pump to tubing. Pumped 60 bbls down tubing at 2 BPM rate. Pressure stabilized at 1846 psig from 55 bbls to 60 bbls during this 2 BPM rate. Increased rate to 3 bpm for 7 bbls. Pressure stabilized at 2145 psig during 3 bpm rate. Increased pump rate to 3.8 bpm and pumped 10 bbls and pressure stabilized at 2428 psig at 3.8 bpm. SD pump. Monitored pressure drop for five minutes (1675#, 1525#, 1454, 1419 & 1388# at fifth minute reading.) 11/17/04 MU Baker running tools for through tubing inflatable bridge plug. Stab lubricator and PT to 2,500 psi with methanol. RIH with IBP - Tie in to Schlumberger SCMT log dated 10-21-04. Spot IBP on depth -Inflate IBP RO. 11/18/04 PJSM. RU Coil, PT coil tubing BOP Equipment. MU open wash nozzle and dual flapper type check valves. Open well up 1, 180psi tubing pressure - RIH to 1,723. RIH very slow from 7,300 to 7,386 Electronic counter 7,383 Manual Ftg counter - Had a clear tag with 2,000# at this point - Pick up for spotting of Sand Plug. Start Displacement 11/19/04 Cont with displacement of sand max rate = 1.25 BBLlmin at 2,800psi - Displaced Sand to CT nozzle - Slowed rate to 1 Bbl/min - Pumped sand at 1 bbl/min while pulling coil at 26bbl/min - Displaced the 8bbl of sand slurry out + one extra bbl. Cont POH with Coil while pumping a corresponding -volume. Secure well and blow down equipment. Make up Straight through Wash nozzle & 4' of straight bar - Stab up injector head and shell test same to 250psi low & 5,000 psi high. Open well (1 ,270psi on tubing) and RIH with 1 3/4" coil. RIH to 7,300 to 7,328 where we tagged up (58' of Fill on top of IBP). 11/20/04 Batch up 20 bbls Class "G" Cmt Spot end of coil at 7,308' and Pump 20 bbls cmt at 15.8 ppg dn coil at .8 bpm at final circ pressure of 3658 psi and holding 1450 psi on choke Displace cmt with 14 bbls lease water at 1.2 bpm at 3040 psi while holding 1450 on choke. Continue displacement and lay in cmt and pooh coil to 6776' at 1 for 1 rate and holding 1450 psi on choke. Shut in choke and squeeze 6 bbls dn coil at 1 bpm at 3800 psi final squeeze rate. Shut dn pump for hesitation squeeze 2760 psi to 2591 psi in 15 min and switch cmt pump to coil X tbg annulus. Pump dn and squeeze 4 bbls dn coil X tbg annulus with choke shut in at 1 BPM at 3490 psi final squeeze rate Shut dn pump for hesitation squeeze 2902 psi to 2640 psi in 15 min. Pump dn and squeeze 2 bbls dn coil X tbg annulus with choke shut in at 1 BPM at 3540 psi final squeeze rate. Shut dn pump for hesitation squeeze 2930 psi to 2531 psi in 30 min. Pump dn and squeeze 2 bbls dn coil X tbg annulus with choke shut in at .5 BPM at 3200 psi final squeeze rate. Shut dn pump for hesitation squeeze 2939 psi to 2490 psi in 30 min. Pump dn and squeeze 2 bbls dn coil X tbg annulus with choke shut in at.5 BPM at 3250 psi final squeeze rate swap valves to circ log way - Pooh to EOT pump dn coil with "G" pump 12 bbls biozan -D - followed by lease water - RIH and planed biozan to be at end of coil when reached TOC holding choke at 2700 psi. Start wash at 3-1 f/7200' tag up firm at 7231'. Work pipe and circ Biozan and attempt to wash by tag (no-go) shut choke and attempted to squeeze away tag and pressured up well pore to 4200 psi (no-go). CIP at 06:00 hrs. Circ annulus clean and pooh holding 2700 psi on annulus - ooh and shut in well with 2500 psi. RD. Pump down tbg and pressure test tbg and csg from 4360 psi to 4170' psi in 30 min. 12/13/04 SCU 312-09 morning report summary, CONFIDENTIAL: last revised 2/16/2005 Page 3 ~~. Put heat on well head and p,-",~ methanol to assure that tubing is open. ~~l BPV after confirmation that Tbg is open and bleed off. Continue with service lines while thawing BOP valves and making up riser spool below stack. Got BOPs hanging in derrick and clean up for tour change. 12/14104 NU BOP. Continue RD. RU test joints. 12/15/04 RU test pump and test BOP. Test BOPs to 250 PSI low and 4500 PSI high. RU floor to pull tubing. Pull BPV, install landing joint with TIW and head pin, BO all but 4 LDS in preparation of pulling pipe. 12/16104 RU methanol pump at tank setting and trying to sweep line back to rig with methanol. Manifold gas line to take returns to 200 BBL horizontal tank. Continue to pump methanol from tank setting, finally broke through pumped a total of 750 gallons. Cleared and purged Fuel gas I flow line with gas from tank setting taking returns into horizontal tank. Connect gas back to line heater and fire same. Pulled 71 K to unseat hanger. Up weight 40K RU head pin and hose to circulate. Circulate 3700 Strokes (83.25bbl), started to pack off at hanger (paraffin), bleed off and pull hanger to floor and resume circulating. At 4200 strokes (94.5 BBL) had gas bubble at surface 2 bbl gain well shut in. 150 PSI on casing 0 PSI on tubing. Bleed T/100 PSI monitor for 10 minutes, pressure returned to 150 PSI, bleed pressure back down to 100 PSI monitored for 10 minutes, pressure again returned to 150 PSI. Bled pressure to 0 PSI wI full open choke, circulate through choke to 5200 strokes (117 BBL). Monitor well open annular and blow down choke. Begin circulating had heavy gas bubbles 3 bbl gain, shut well in 5480 strokes (123.3 BBL) 25 PSI on casing and 0 PSI on tubing, bleed off pressure and circulate through choke, continue to CBU, 11000 strokes (247.5 BBL) had some gas but not much. Shut down and monitored well. Blow down stand pipe, disconnect guide wire and spot tiger tank for returns. Pump dry job and monitor well. Pull hanger to floor remove chemical injection line, break landing joint and hanger with pup laying down same. 12/17/04 Prep to pull tubing. POOH with 2 718" IBT L-80, 6.4PPF tubing standing back in derrick. Spool chemical injection line until stand #40, LID chemical injection mandrel, monitor well, continue to POOH and LD packer. Monitor well. RID Tubing handling equipment from rig floor. P/U rig tongs for 4 3/4" DC. PJSM P/U motor, bit and 2 D.C. P/U BHA. RIH to stand 31. RIU and circulate, test mud motor and blow down. RIH to stand 65. Break circulation, and blow down. 112 SPM 346 PSI. RIH to stand 85. RIH to stand 104. Break circulation, blow down 112 SPM 415 PSI. PIU singles RIH, on joint 15 with 6.70' in hole (7127.11) tagged cement stringer set down 7000 LBS, picked up and set down again with same results. PU and LD joint 15. PJSM on fluid change over. Install head pin and RU break circulation, and blow down. (66 strokes 125 PSI SPR) 12/18/04 Change over from lease water to 12.7 PPG mud taking returns into tiger tank @ 98 SPM (2.2 BPM) & pumped 289 bbls thru choke line starting psi 200# ending Psi 750 # and worked pipe - w/11.2 ppg returns swap lines & blow down same. RU to clean out cement with (M-343) 6" PDC bit & BHI M1XL 3-1/8" mud motor. Clean out solid cement with bag shut taking return thru kill line from 7127' to 7281' @ 3-5 minutes per foot. Drilling broke from 7281" to 7289' Ratty +- 1-1/2" min/ft. RU and circulate 14000 strokes. Drill cement from 7289' - 7294' Firmed up and drilled solid cement from 7294' - 7304' @ + - 3-5 min ft. 12/19/04 Continue drill firm cement 7304" - 7334", continue drill tJ 7340 ratty drilling, drill from 7340' - 7342' (No weight) Circulate and check for sand (none visible). RU and test well bore to 3150 PSI had 50 PSI loss in 30 minutes Condition mud & circulate, stage in treating cement. Mix and pump dry job. RD circulating head blow down Kelley hose RU fill line. PJSM LD 21 joints tubing. POOH with 104 stands, pulled wet from stand 76. RD and PU BHA handling equipment. LD BHA. PU completion BHA. 12/20/04 SCU 312-09 morning report summary, CONFIDENTIAL: last revised 2/16/2005 Page 4 ~ '" ) ) RIH to stand 65, lay down single. PU and install chemical injection mandrel RU Pollard to run chemical injection line. RIH with 2 7/8" tubing, banding chemical Injection line. (2 bands per joint). MU hanger and landing joint install chemical injection line and test to 5000 PSI. Land hanger RI LDS. RD Pollard chemical injection line running equipment. RU to displace mud with lease water. Start displacement 70 SPM at 300 PSI. Reverse 12.7 PPG mud out with inhibited lease water. Blow down kill line, pump, and suction lines. RU and pump 3 BBL diesel down annulus with test pump, blow down return line and RD. PU Pollard WL lubricator and test to 4500 PSI RIH with N test tool and set tool. Using test pump pressure up to 1000 PSI and set packer could see definite indication of packer shifting and setting. Continue to pressure up to 4500 PSI to test tubing. Held for 20 minutes with 50 PSI loss. Bleed pressure off and RD pump from tubing. Pressure test annulus and packer to 4200 PSI, held pressure for 30 minutes with less than 50 PSI loss. RD test pump and hoses 12/21/04 RD. Remove BPV and install TWC test tree to 5000 PSI monitoring chemical injection line. Chemical injection line is dummied and was pressured to 5000 PSI. All held good. Pulled TWC and installed BPV Removed BPV. 12/22/04 MI/RU Pollard, pressure test lubricator to 1500 psi. RIH with Daniels 2 1/2" kick over tool to 2493' KB Slick line measurements. Pull dummy from injection mandrel. Pull out of hole & recovery dummy valve. RIH with 2 1/2" Daniels & RK R/T With 1" Gas lift valve to 2493' KB. Set valve in mandrel and POOH. Pressure up on tubing to 300 psi. With annulus valve open RIH with 2 1/2" BO shifting tool to 6650' KB. Slickline displacement increased tubing pressure to 700 psi. Close annulus valve latch CMU sleeve. Jar open, pressure equalized to annulus. RD/SDFN. 12/23/04 RU WLU, PJSM. Test lubricator to 5000 psi. RIH with 6.5' long 2" OD Dummy gun to 7332' with no problems. POOH make up shifting tool. Pump 7 bbls diesel down tubing, RU Schlumberger nitrogen services and test line to 5000 psi, PJSM. Displace from tubing 33 bbls of fluid with nitrogen taking returns via annulus to Johnson tank. Strap same. RIH with shifting tool and tag fluid @ 5860' pick up and pump nitrogen and displace out 3 more bbls of fluid. Tag fluid with shifting tool @ 6200', pick up & pump nitrogen & displace out 1.5 more bbl of fluid. RIH, tag fluid @ 6410'. Continue RIH and latch CMU sleeve @ 6650' shift sleeve shut. Pressure up on tubing from 2300 psi to 2600 psi & monitor 7" x 2 7/8" annulus. Pressure up on tubing with nitrogen to 3600 psi. Pooh wire line. RD Pollard and Schlumberger. SDFN. 3600n psi nitrogen on tubing 12/30/04 RU on well, Arm 6' - 2" 6 spf hsd. 60 degree phased gun. Test lubricator & test manifold to 3500 psi with nitrogen. (good test) RIH and tie into Schlumberger SCMT Log Dated 10/21/04. (confirm tie in with Anchorage office) Bleed down pressure to 2917 psi. Perforate 77-3 Sand F/7264' - T0/7270' Saw no noticeable change in pressure. POOH. Shut in well and bleed down lubricator. LD gun all shots fires. Turn well over to production. Production monitored pressure and started flowing well; Production took down pressure to 1000 psi, with no gas to surface. SCU 312-09 morning report summary, CONFIDENTIAL: last revised 2/16/2005 Page 5 ') rloo- () 2- g ) Subject: Operational Variance Request on SCU 312-09 Sundry #304-341 From: "Tyler, Steve L" <tylersl@unocal.com> Date: Wed, 08 Dec 2004 07:49:55 -0900 To: Winton Aubert <winton_aubert@admin.state.ak.us> CC~ "Harness, Evan" <eharness@unocal.com>, "Brandenburg, Tim C" <brandenburgt@unocal.com>, 'Walsh, Chantal -Petrotechnical" <walshC@unocal.com> Winton We are requesting an operational variance to our approved Sundry #304-341. Attached is the work summary to date, a current and proposed drawing(s). Below is a brief proposed, work description. Work Description: MIRU Production Hoist. ND Tree. NU BOPE. Test BOPE's. ( PUMU land joint. PU unset FHpkr. CBU wI lease water. LD tbg hngr. POOH wI completion LD same. /..' PUMU Drilling/Cleanout BHA. RIH to TOC. CO to 12.0 ppg mud. Drill/Cleanout cmt to top of sand. CBU. Pressure test well bore to 4200 psi. POOH LD BHA. PU tailpipe assy, FH pkr and CMU sldg slve. RIH on 2-7/8" tbg. Space-out, land tbg. Set pkr. Release rig. Spot packer fluid in csg x tbg annuli. Dry tbg wI N2. I Eline Perforate 77-3 sand @ 7264' to 7270' wI 6' x 2" 6spf HC. Thank You SCANNED DEC 1 4 2004 yler Workover Foreman I Engineering 1 r. r" Unocal Alaska ',:~" (Office: (907) 263-7649 (Cell: (907) 350-6295 (Home: (907) 696-1837 Content-Description: SCU312-09MRSummary_AFE162935-162938.doc SCU312-Q9MRSummary_AFE162935-162938.doc . Content-Type: application/msword Content-Encoding: base64 C t t D . t. SCU 312-09 CURRENT , on en - escnp Ion: . SCU 312-09 CURRENT Schematic_10-22-Q4.doc Schematlc_10-22-04.doc Content-Type: application/msword PJSM. RU. PT lubricator 300# 10 ),d 4000# high (OK). RIH, tie in and attel1 )0 fire guns (no go). POOH, trouble shoot and find firing head leaked on first gun run. Rebuild same. RIH to bottom. Tie in to (77-3 sands 7275' to 7295') using Gamma Ray correlated to Schlumberger SCMT Log ran 10/21/04. Fired gun (20' of 2" HDS Power Jet 6 SPF) with good indication of shot. Got 60 psi tubing pressure increase in first three minutes after shot (from 2464# prior to shot & 2524# after.) POOH. RD. 11/13/04 PJSM/RU. Pressure test hard lines to 4500 psig (OK). Pump 1.8 Bbls into production annulus to get 2000#. Found well with 1980 # tubing pressure and bleed gas cap off to Johnson tank. Got fluid at 500# while flowing to tank. Lined up pump to tubing. Pumped 60 bbls down tubing at 2 BPM rate. Pressure stabilized at 1846 psig from 55 bbls to 60 bbls during this 2 BPM rate. Increased rate to 3 bpm for 7 bbls. Pressure stabilized at 2145 psig during 3 bpm rate. Increased pump rate to 3.8 bpm and pumped 10 bbls and pressure stabilized at 2428 psig at 3.8 bpm. SD pump. Monitored pressure drop for five minutes (1675#, 1525#, 1454, 1419 & 1388# at fifth minute reading.) 11/17/04 MU Baker running tools for through tubing inflatable bridge plug. Stab lubricator and PT to 2,500 psi with methanol. RIH with IBP - Tie in to Schlumberger SCMT log dated 10-21-04. Spot IBP on depth -Inflate IBP RD. 11/18/04 PJSM. RU Coil, PT coil tubing BOP Equipment. MU open wash nozzle and dual flapper type check valves. Open well up 1, 180psi tubing pressure - RIH to 1,723. RIH very slow from 7,300 to 7,386 Electronic counter 7,383 Manual Ftg counter - Had a clear tag with 2,000# at this point - Pick up for spotting of Sand Plug. Start Disp lacement 11/19/04 Cont with displacement of sand max rate = 1.25 BBLlmin at 2,800psi - Displaced Sand to CT nozzle - Slowed rate \ to 1 Bbl/min - Pumped sand at 1 bbl/min while pulling coil at 26bbl/min - Displaced the 8bbl of sand slurry out + one extra bbl. Cont POH with Coil while pumping a corresponding -volume. Secure well and blow down equipment. Make up Straight through Wash nozzle & 4' of straight bar~. Stab up injector head and shell test same to 250psi low & 5,000 psi high. Open well (1,270psi on tubing) and RIH with 1 3/4" coil. RIH to 7,300 to 7,328 where we tagged up (58' of Fill on top of IBP). 11/20/04 Batch up 20 bbls Class "G" Cmt Spot end of coil at 7,308' and Pump 20 bbls cmt at 15.8 ppg dn coil at .8 bpm at final circ pressure of 3658 psi and holding 1450 psi on choke Displace cmt with 14 bbls lease water at 1.2 bpm at 3040 psi while holding 1450 on choke. Continue displacement and lay in cmt and pooh coil to 6776' at 1 for 1 rate and holding 1450 psi on choke. Shut in choke and squeeze 6 bbls dn coil at 1 bpm at 3800 psi final squeeze rate. Shut dn pump for hesitation squeeze 2760 psi to 2591 psi in 15 min and switch cmt pump to coil X tbg annulus. Pump dn and squeeze 4 bbls dn coil X tbg annulus with choke shut in at 1 BPM at 3490 psi final squeeze rate Shut dn pump for hesitation squeeze 2902 psi to 2640 psi in 15 min. Pump dn and squeeze 2 bbls dn coil X tbg annulus with choke shut in at 1 BPM at 3540 psi final squeeze rate. Shut dn pump for hesitation squeeze 2930 psi to 2531 psi in 30 min. Pump dn and squeeze 2 bbls dn coil X tbg annulus with choke shut in at .5 BPM at 3200 psi final squeeze rate. Shut dn pump for hesitation squeeze 2939 psi to 2490 psi in 30 min. Pump dn and squeeze 2 bbls dn coil X tbg annulus with choke shut in at .5 BPM at 3250 psi final squeeze rate swap valves to circ log way - Pooh to EOT pump dn coil with "G" pump 12 bbls biozan -D - followed by lease water - RIH and planed biozan to be at end of coil when reached TOC holding choke at 2700 psi. Start wash at 3-1 f/7200' tag up firm at 7231'. Work pipe and circ Biozan and attempt to wash by tag (no-go) shut choke and attempted to squeeze away tag and pressured up well pore to 4200 psi (no-go). CIP at 06:00 hrs. Circ annulus clean and pooh holding 2700 psi on annulus - ooh and shut in well with 2500 psi. RD. Pump dn tbg and pressure test tbg and csg , ) from 4360 psi to 4170' psi in 30 min. J SCU 312-09 morning report summary, CONFIDENTAL: last revised 12/8/2004 Page 3 9/25/04 ') ') PJSM. RU slickline and lubricator. Pressure test to 1500 psi. RIH with 2.25" GR down to 10,324'. Tool set down. Picked up tools and had no spang action and a 400 Ib overpull. RD Pollard and secured well. 9/26/04 PJSM and prime pump truck. Pumped 60 bbls of lease water down tubing. Tubing had 150 psi, annuli had 1200 psi and surface had O. Pumped 1 bpm rate with pressure at 150 psi. After 5 bbls pressure went to 100 psi. Tubing went on a vac after 12 bbls w/rate at 3 bpm. Raised rate to 4 bpm and pumped 60 bbls total. Annuli pressure started dropping slowly after 20 bbls was pumped and was at 950 psi after 60 bbls. Surface casing 0 psi. Pumped 65 more bbls of lease water down tubing at 4 bpm with tubing on vac, annuli pressure 900 psi and steady and 0 on surface. Bled annuli down to 0 psi. RU to pump down annuli. Pumped at 1 bpm rate: at 1 bbl pressure 0; 2 bbl pressure 210 psi; 3.6 bbls pressure 700 psi; 4.5 bbls pressure 1500psi. Shut annuli in at 1500 psi. Lost no pressure, test good. Left 1500 psi on annuli. Rigged pump truck for standby and secured well. 9/27/04 PJSM, RU Pollard slickline and pressure test to 1500 psi. RIH w/2.37" brush down to 1 0,200' KB. Pulled tools up to 10,000' KB and waited on vac truck. RU vac truck and pumped 30 bbls of lease water down tubing. Went back down and brushed tubing from 10,200' up to 10,100' 8 times. Pulled up to 10,000' and pumped 30 more bbls of lease water down tubing. POOH and RD Pollard slickline. PJSM, rig up APRS wireline and pressure test to 1500 psi. RIH with 2.18" OD Halliburton easy drill bridge plug down to 10,177' KB (20' from bottom of packer) and set plug at 10,177' KB. (Had 900 Ibs on wt indicator when fired. After 3 minutes wt dropped off to 800 Ibs). POOH Rig down APRS and secure well. Annuli had 1725 psi and tubing 0 psi. 9/29/04 No Operations PJSM, rig up hard lines, prime pumps, pressure test lines to 3000 psi; and insert wiper ball locked out by 2 valves. Pumped 5 bbls of lease water down tubing followed by 20 bbls of G neat cement. Cement was 15.7 density. / Pumped cement at 2 bpm while tubing on vac. Launched Halliburton foam wiper ball and pumped 5 bbls of Biozan at 2 bpm with tubing on vac. Followed this by pumping 119 bbls at 4 bpm with tubing on vac. Wiper ball never bumped up. Call town. Told to pump tubing volume. Started pumping tubing volume and 70 bbls into it had a 1500 psi spike. Continued to pump until 200 bbls total, after cement, of lease water was pumped down tubing. Tubing was still on vac. Suspended operations, RD pump truck. 10/2/04 PJSM, RU Schlumberger pump truck, hard lines and valves to launch Wiper Dart & 4" Halliburton wiper ball. PT / lines to 3000 psi. Pump 15 bbls of lease water to clear pipe. Pump 20 bbls of G neat cement (100 sx) at 4 bpm, launch nerf ball and dart, pump 5 bbls of biozan polymer and 115 bbls lease water. Well on vac and after 111 bbls of lease water pressure spiked to 800 psi and then went back on vac. Shut in, RD, secure well. 10/4/04 RIU Run 2.25 Gauge Ring to 10,175' WLM RD. Operations on hold 10/9/04 PJSM. RU and test Pollard. RIH with bridge plug. Tie in to Otis XO Sliding Sleeve at 10116' RKB and top of BOT FH packer at 10150' RKB. Unable to get CCL down into packer as bridge plug kept setting down in tubing just below packer bottom. Pulled back up and tied into 3' sliding sleeve at 10116' RKB and packer top several times. Dropped back into packer and set top of Halliburton 2 7/8" EZ-Drill Bridge Plug at 10153' RKB. Plug set -- 100# / weight loss on set. Set in place for five minutes, picked up above plug free & RIH and set on plug.) POOH POOH LD APRS. Finished RU Schlumberger pump truck and test hard lines. RU Pollard. SCU 312-09 morning report summary, CONFIDENTAL: last revised 12/8/2004 Page 1 Lubricate and bleed 98 Bbls of 16,) water into tbg & test to 1500#.6 each 5, )ute readings as follows; 1500#, 1480#, 1465#, 1440#, 1440#, 1435# and 1435#. Test on bridge plug good. Bleed tubing down to 650# RIH with 2.25" GR on Pollard set down on bridge plug at 10153' RKB. POOH. RIH with 2.5" BO shifting tool to 10116' RKB and work XO sliding sleeve open tubing. Dropped to 130# when sleeve opened. POOH Circulate lease water down tubing and up production casing. Gas and oil returns for 60 bbls. Pumped a total of 285 bbls and getting oil & gas free returns. Shut in annulus and jug test well. To 1500#, 5 minute readings 1500#, 1495#,1495#, 1490#, 1490#. Holding solid -- test good. RIH with 2 1/2" BO shifting tool and close XO sliding sleeve with 1490 on well. Bleed casing off and tubing went to 1140#. Pump tubing back up to 1600#. 5 minute ,/ read ings 1540#, 1540#, 1540# and 1540#. Rock solid good test. Bleed pressure off well & POOH with wire line. RD Pollard wireline and Schlumberger. 10/18/04 RU, Spot and hook up choke manifold. Charge pump manifold. Spot koomey and run koomey lines. Attempted to scope derrick-unsuccessful. 10/19/04 RU guy wires. ND tree. NU BOP and related equipment. RU work platform. Make up test joint, function test and shell test BOP. Continue RU. Test BOP and related equipment 250 psi low and 3000 psi high. RU landing joint and pull tubing hanger free. Rig up APRS. RIH with 2 1/4" jet cutter, locate and cut 2 7/8" tubing 3' above packer at 10150', POH and rig down APRS. Pull hangar to floor and break off same, RU Weatherford, spot catwalk and pipe racks. LD liner. / 10/20/04 Change out Weatherford tongs 2X. LD 9236' 4" tubing. MU tubing hangar, land in well head, change ram's from 4" to 3 1/2", test door seals to 3000 psi, LD hangar and 4' handling equipment. LD 3 1/2" and 2 7/8" tubing. RD Weatherford equipment. Set new tubing hangar, test blind rams to 250 psi and 3,000 psi. Change rams from 3 1/2" to 2 7/8", test same to 250 and 3000 psi. Load pipe rack with 98 joints and strap. MU casing. Scrapper and run 8 joints, of 2-7/8 tubing. 10/21/04 RIH with casing scraper picking up 2 7/8" tubing, drifting every joint. Circulate 1 hole volume at 3 bpm. POOH lay down scraper assembly. RU Schlumberger, run SCMT log 7350' to 4300'. RD Schlumberger RU to run 2 7/8 completion. PJSM. PU Baker production assembly. RIH W /2 7/8 tbg. 14 stands. 10/22/04 RIH with 2 7/8" completion. PU chemical injection mandrel, hook up stainless steel tubing, test line to 2000 psi. RIH with 2 7/8" completion banding stainless tubing to pipe. RIH with 2-7/8" completion banding stainless tubing to pipe. PU hangar and landing joint, hook up stainless tube to hangar, land completion. Waiting on Pollard crew RU Pollard. RIH set plug in x-nipple. Pressure up on tubing, packer set at 800 psi continue pressuring up to 4200 psi, held same for 5 minutes. Pollard POOH, did not have plug, sheared off, run # 2. RIH retrieve plug. PU tubing. To 750psi. Pressure test annulus to 4200 psi. hold 10 min. Bleed off RD. Test equipment. Set BPV. RD. NO BOP Change out lower annulus valves, Set tree. Press test void to 5,000 psi. Press test body to 5,000 psi. RD. 10/24/04 RU wire line to open sleeve @ 6654'. PJSM, RU pump truck and nitrogen. Choke skid and Johnson tank. RU and test new annulus valves 3,000 psi. Test lines to 5,000 psi. Pump 50 bbls of lease Water with 1 % CRW-132, Pump 50 bbls lease water 1% CRW-132 & 8 bbls diesel, Pump 20 bbls Lease water CIW -132, Pump nitrogen, Get 33 bbls returns. Stop RIH with wireline tag fluid @ 5600' Pump Nitrogen, get 5 more bbls returns, RIH WI wireline tagged @ 6,612'WLM 6,629 KB. Close sleeve @ 6,654' PU tubing from 2,200 to 2,500 psi with no returns. SIW 2,500 on tubing. POOH. RD Sclumberger, secure well. 11/2/04 SCU 312-09 morning report summary, CONFIDENTAL: last revised 12/8/2004 Page 2 ""' RKB =17.20' ~ B ~e~i .~,::,D,;~,~ ( ~ ~~/ ,...., ":) fa - - L . . Size 20" 13- 3/8" ~ 13- 3/8" 7" 7" 7" 7" 7" 7" 7" 7" ) Type Conductor SurfCsg SurfCsg Prod Csg ') S~vansonRiver \Ven SCU 312-09 As Completed 10/22/04 PROPOSED Wt 54.5 54.5 29 26 23 26 29 29 29 26 7" 7" Tubing 27/8", Hutt erforated 11' off detph <~; ~~::~~/: CIBP@10'lSS'.~,'>:-" ~.. F ".",.-i1ìír:',,-;-<: 5 ':.:~ ,mnm "m.'.. 'n :~1~~;1.~ {.; ',> - -;- "..- Cmt R~t @ :'., ". . fl'f==: '''" ~~;~~; ',?'. :~~ ~ ¡~£ '.~~, .~". ~~~~~;;. ~;.:'~~,f:t ~?~~i~'f€ . :.;~.t:~ ...I.~!!rl!f,.. ~ "'''''''¡r;;.'\'-' ,.-::;;~~¡~ Þi~Ü~¡~ ~ '''~:..~,¡.I1''';¡;r':~..-f:AL ,'-, "1~" ~". ~.. ~" '17 :'..<: ;.~- I TD= 10,785' PBTD= 10,700' Max Deviation = r @ 5,931' NO. 17.20' RKB to Tbg Hngr I 6.4 I N-80 A. ß. C. n. E. Deoth 17.20' 2500' 6666' 6679' 6729' 6776' 10,153' 10,150' 10,150' 10,217' 10,260' 10,296' 10,335' 10,372' 10,404' 10,448' 10,449' 10.454 ' Grade K-55 K-55 N-80 P-II0 P-110 Casing & Tubing Thrd ID Top Htm Surf 37' Hole F. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 12.615 1509' Surf 17.5" 12.615 2980' 250' 1179' 4798' 5756' 7238' 7242' 7284' 8504' 9-7/8" Butt 6.184 6.276 6.366 6.276 1512' Surf 250' 1179' 4798' 5756' 7238' 7242' 7284' Butt x 8rd 6.184 6.276 8rd 6.276 6.184 8507' 9315' 9315' 10,785' Cmt Cmt Top Yes Surf 1000 sx Surf 600 sx 2010' (Calculated) 750 sx 5700' Thru DV @ 8504' CBL 750 sxs 8187' Calculated I Butt 6776' I 2.441 Surf I JEWELRY DETAIL 00 Item 7.0325 Scharrer 7-1/16" 75A.l0 Tbg Hngr, w/2-l/2" H BPV Profile 4.50 Chemicnllnjection Mandrel 3.74 BOT Model "CMtJ" Sldg Slve 5.968 .BOT 47 B2l\'1odel "FH" Retrievable Pkr wi 30k shear ring 3.510 XNProfi!e Nipple 5.75 WLEG CIBP set in pkr Tbg Cut 3' above pkr. found pkr@ 10,153'. BOT "FH" pkr, 7", 29# x 2-7/8" 5.50" x 4.593" Cameo "MM" Mandrel Brown HS-16-1 pkr, 7", 29# x 2-7/8" 5.50" x 4.593" Cameo "MM" Mandrel Brown HS-16-1 pkr, 7", 29# x 2-7/8" 3.668 Otis '.S" Protilt' Nipple, Position #3 5.50" x 4.593" Cameo "MM" Mandrel Locator Seal Assy BOT "Fl" Pkr Cameo "Ð" Nipple II> 2.441 2.441 2.31 2.42 2.25 2.441 2.42 2.374 2.50 2.374 2.50 2.313 2.374 PERFORATION Interval Accum. Top Btm Amt spf 7.).75' 7.).95' 20' 6.0 10,165' 10,166' I' 5.5 10,183' 10,238' 55' 4.5 10,244' 10,255' 11' 4.5 10,275' 10,332' 57' 4.5 10,344' 10,403' 59' 4.5 10,408' 10,421' 13' 4.5 10,425' 10,444' 19' 4.5 10,460' 10,520' 60' 4.5 10,526' 10,546' 20' 4.5 10,557' 10,558' l' 5.5 seD 312-09 Proposed Schematic _11-04 .doc DETAIL Comments Perf Tie-in Log 11' deep to DIL P&A'd P&A'd P&A'd P&A'd P&A'd P&A'd P&A'd Ip&A'd Ip&A'd iP&A'd REVISED: 8/26/2004 by SLT ) ) Swanson River Wen SCU 312-09 As Completed 10/22/04 C as i n g & T u b i n 9 RKB =17.20' Size Type Wt Grade Thrd ID Top Btm Hole =r -t - ~ 20" Conductor Surf 37' r 13- !; SurfCsg 54.5 K-55 12.615 Surf 1509' f, . . 17.5" ~I 13- Surf Csg 54.5 K-55 12.615 1512' 2980' ~) ~ 3/8" u A 7" 29 6.184 Surf 250' ~ 7" 26 6.276 250' 1179' 7" ~ Butt 6.366 1179' 4798' 7" Prod Csg 26 N-80 6.276 4798' 5756' 7" 29 5756' 7238' ~ I 7" 29 Butt x 8rd 6.184 7238' 7242' 9-7/8" .,; @) ?o~ :~' :~~æ 7" 29 7242' 7284' 1:5 j{~~' (' 7" 26 P-IlO 6.276 7284' 8504' ... u .:£ 8rd " '" .an .~; 7" P-110 6.276 8507' 9315' <-Þ r 7" 6.184 9315' 10,785' Tubing 17.20' RKB to Tbg Hngr 27/8", Butt I 6.4 I N-80 I Butt I 2.44) Surf I 6776' ~, ~.'" "':.iJ IBP ,ã 7.18(.01\1 @ 738'" ELM . . -1 ~ CIBP @ 10,155' .: ~ :\'1" 5 '-¡'" ~ ~., Cmt Ret @ 10,177' :ft: ~ '~. ,~~:;~ ~: }+~ ';.. . '. ":~l;'¿ i'~ ;1.~~~13 i~ i~,:'~Ii{;I~;: . ~""''''''''?í~14'~'' '. ~ ...,.. ,"'{:"., '#;= ~~'. ">1~~~"":.;;~;~~-~ ~~,;:.:-~~ ~.~'~~~ ~ "-(:,,,... ,¡~i I ."" ~ ~~: ~~:f: ~~.~~.!Ë .;r-~~~.,., ......c- 5.' :..;.*(:....~~~~: ,T5,~~:..F;1~' .~~ '>'I"t~~ ~¡~ ..çt..... ':.':'~ y>.~. TD= 10,785' PBTD= 10,700' Max Deviation = ZO @ 5,931' NO. DCDth n) 17.20' 2.441 A. 2500' 2.441 ß. 6666' 2.31 C. 6679' 2.42 D. 6729' 2.25 :E. 6776' 2.441 10,153' F. 10,150' 5. 10,150' 2.42 6. 10,217' 2.374 7. 10,260' 2.50 8. 10,296' 2.374 9. 10,335' 2.50 10. 10,372' 2.313 11. 10,404' 2.374 12. 10,448' 13. 10,449' 14. 10,454' 15. 10,547' PERFORATION Interval Accurn. Top Btm Amt spf 7,275' 7;1.95' 20' 6.0 10,165' 10,166' I' 5.5 10,183' 10,238' 55' 4.5 10,244' 10,255' 11' 4.5 10,275' 10,332' 57' 4.5 10,344' 10,403' 59' 4.5 10,408' 10,421' 13' 4.5 10,425' 10,444' 19' 4.5 10,460' 10,520' 60' 4.5 10,526' 10,546' 20' 4.5 10,557' 10,558' I' 5.5 SCU 312-09 CURRENT Schematic 10-22-04.doc Cmt Cmt Top Yes Surf. 1000 sx Surf 600 sx 2010' (Calculated) 750 sx 5700' Thru DV CBL @ 8504' 750 sxs 8187' Calculated JE\VELRY DETAIL on Item 7.0325 Scbaffer 7-1I16" 75A,10 Tbg Hngr, wi 2-112" H HPV Profile 4.50 Cbemical Injection M.andrel ' 3.74 BOT Model "CMU" Sldg Slve 5.%8 BOT 47 H2 Model "HI" Retrievàble .Pkr w/30k sbear ring 3.510 XN Profile NippJe 5.75 WLEG CIUP set in pkr Tbg Cut 3' above pkr. found pkr@ 10,153'. BOT "FH" pkr, 7", 29# x 2-7/8" 5.50" x 4.593" Cameo "MM" Mandrel Brown HS-16-1 pkr, 7", 29# x 2-7/8" 5.50" x 4.593" Cameo "MM" Mandrel Brown HS-16-1 pkr, 7", 29# x 2-7/8" 3.668 Otis "S" Profile Nipple, Position #3 5.50" x 4.593" Cameo "MM" Mandrel Locator Seal Assy BOT "FI" Pkr Cameo "D" Nipple 450 cut on tbg joint DETAIL Comments Perf Tie-in Log 11' deep to DlL P&A'd P&A'd P&A'd P&A'd P&A'd Ip&A'd P&A'd P&A'd P&A'd Ip&A'd REVISED: 8/26/2004 by SLT I ~ 0 "' 02 ,g ~o4-~4i seD 312-09 Workover Summary . Slicklinc GR to 10,550'. POOH. ])one. . MIT Csg to 1500 psi. MIT tree. ¡Jane. . MIRU Elinc. RIH wi 6' tbg punch gun. Perf@ 10,180' . Did not do. . RIH wi 2 7/8" Cmt Ret wi cheek valvc. Set ret @ 10,170'. POOH. RD Eline.Done. . RU cemcnters. Mix/bullhcad 20 bbls (100sx) cmt, launch \viper plug, 5bbls biozan post pad. Displace HES variablc wiper ball to retainer @ 10180'. Did twice. . RIH set CIBP @ 10,155' (in "FH" pkr @ 10,150') . Lubricate/Fill tbg wi lease water. Pressure test tbg to 1500 psi. . MIRU slickline. Rill open sldg slve. Circulate/fill Wellbore wi lease water. Jug test wellbore to 1500 psi. . MIRU production hoist. . ND tree. NU BOPE. Test same . MU Land joint. RU Rill wi tbg cutter. Cut tbg @ 10,149' Gust above FH pkr @ 10,150') . POOH & LD tbg string. . RU Eline. RIH wi SCMT to 6700'. POOH logging. . PU csg scraper. RIH to 6700'. POOH. . PUMU Completion pkr & jewelry. Rill. MU Chern mandrel @ 2500'. Rill threading Chern inj line. Land tbg in hanger. Set pkr @ 6660'. . ND BOPE. NU tree test same. RD Demobe rig. . MIRU SlickIine. Open sldg sIve. Pump annular volume of pkr fluid. RU N2. Blow tbg dry. Trap pressure. . RI Close sldg slve. . MIRU Eline Rill perf 77-3 sand. RD. (01 IP/wot, Ar proved II E- ''lCt.<' ( \;J~ ~~ OCT 0 9 2004 Casing & Tubing RKB =17.20' Size Type Wt Grade Thrd ID Top Btm Hole r 20" Conductor Surf 37' 13- K-55 17.5" 13- Surf Csg 54.5 K-55 12.615 1512' 2980' 3/8" 7" 29 6.184 Surf 250' u 6.276 250' 1179' 0 7" 26 ~ 7" 23 Butt 6.366 1179' 4798' 7" Prod Csg 26 N-80 6.276 4798' 5756' ! I-.It.:. 7" 29 5756' 7238' 7" 29 Butt x 8rd 6.184 7238' 7242' 9-7/8" 7" 29 7242' 7284' 7" 26 P-110 6.276 7284' 8504' 8rd 7" P-I10 6.276 8507' 9315' 7" 6.184 9315' 10,785' Tubin2 17.20' RKB to Tbg Hngr 27/8", EUE Srd I 6.4 I N-80 I 8rd I 2.441 I Surf I 6690' "~ . I. J..~1_~I¥~ UNOCAL u'u I I I II 5 Cmt Ret @ 10,177' . - - " TD= 10,785' PBTD= 10,700' Max Deviation = 2° @5,931' PERFORAT1ON Interval Accurn. Top Btm Amt spf 10,165' 10,166' l' 5.5 10,183' 10,238' 55' 4.5 10,244' 10,255' 11' 4.5 10,275' 10,332' 57' 4.5 10,344' 10,403' 59' 4.5 10,408' 10,421' 13' 4.5 10,425' 10,444' 19' 4.5 10,460' 10,520' 60' 4.5 10,526' 10,546' 20' 4.5 10,557' 10,558' l' 5.5 NO. seD 312-09 Proposed Schematic_09-04 #4.doc A. B. Co D. E. Ðepth 17.20' ,~2000' ~654' -6660' A.()676' ~69(}' 10,155' -10,165' 10,150' 10,217' 10,260' 10,296' 10,335' 10,372' 10,404' 10,448' 10,449' 10,454' F. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. Swanson River Well SeD 312-09 PROPOSED Completion Cmt Cmt Top Yes Surf. 1000 sx Surf 600 sx 2010' (Calculated) 750 sx 5896' Thru DV Calculated @ 8504' 750 sxs 8187' Calculated m JE\VELRY OETAIL oq Item Tubing Hanger, w/ Drilled out Cosasco BPV thrd. Cbel11kallnjection Mandrel Sldg Slve Hydraulic SetlRetrievablePkr Profile Nij)ple \-VLEG CIBP set in pkr Tbg Cut BOT "FH" pkr, 7", 29# x 2-7/8" 5.50" x 4.593" Camco "MM" Mandrel Brown HS-16-1 pkr, 7", 29# x 2-7/8" 5.50" x 4.593" Cameo "MM" Mandrel Brown HS-16-1 pkr, 7", 29# x 2-7/8" 3.668 Otis "S" Prome Nipple, Position #3 5.50" x 4.593" Camco "MM" Mandrel Locator Seal Assy BOT "Fl" Pkr Cameo "D" Nipple 2.313 2.42 2.374 2.50 2.374 2.50 2.313 2.374 DETA1L Comments WSO Reperf on 2/03/200 Reperf on 2/03/200 Reperf 10,278' to 10,322' on 1/21/( Reperf 10,348' to 10,400' on 1/21/( WSO REVISED: 8/26/2004 by SL T S \Vanson River 'Veil SeD 312-09 Completed on 8/20/71 ICurrent Schematic as of 1 O/4/0~ Casing & Tubing RKB =17.20' Size Type Wt Grade Thrd ID Top Btm Hole Cmt Cmt Top 20" Conductor Surf 37' Yes Surf 13- Surf Csg 54.5 K-55 12.615 Surf 1509' 3/8" 1000 sx Surf 17.5" il 13- Surf Csg 54.5 K-55 12.615 1512' 2980' 600 sx 2010' 3/8" (CaJcuJated) ~ 7" 29 6.184 Surf 250' u 7" 26 6.276 250' 1179' 0 7" 23 Butt 6.366 1179' 4798' ¡-. 7" Prod Csg 26 N-SO 6.276 4798' 5756' 750 sx !I 7" 29 5756' 7238' Thru DV 5896' Calculated 7" 29 Butt X 8rd 6.184 7238' 7242' 9-7/8" @ 8504' 0 . 7" 29 7242' 7284' ~ 7" 26 P-I1O 6.276 7284' 8504' 8rd 7" P-110 6.276 8507' 9315' 750 sxs 8187' 7" 6.184 9315' 10,785' Calculated Tubin2 17.20' RKB to Tbg Hngr 4", EUE 8rd 11.0 N-80 Srd 3.476 Surf 9236' '1; 3-1/2", EVE 8rd 9.3 N-80 8rd 2.992 9236' 10,053' 27/8", EVE 8rd 6.4 N-80 8rd 2.441 10,053' 10,547' t t JE\VELRY DETAIl. 1 ;; .... NO. I)cpth H) 00 Itt~m II 17,20' Tubing Hanger, wI Drilled out Cosasco BPV thrd. 1. 9236' 2.5" 5.0" Crossover, 4" EUE 8rd x 3-112" EUE 8rd 1 2. 10,053' 2.441 4.5 Crossover, 3-112" EUE Srd x 2-7/8" EUE 8rd 3. 10,085' 2.313 3.668 Otis "S" .Profile Nipple, Position #4 4. 10,116' 2.313 3.668 Otis "XO" Sldg Stye (Clost,d) 5. 10,150' 2.42 BOT "FH" pkr, 7", 29# x 2-7/8" 6. 10,217' 2.374 5.50" x 4.593" Camco "MM" Mandrel 7. 10,260' 2.50 Brown HS-16-1 pkr, 7", 29# x 2-7/8" 8. 10,296' 2.374 5.50" x 4.593" Cameo "MM" Mandrel 9. 10,335' 2.50 Brown HS-16-1 pkr, 7",29# x 2-7/8" 10. 10,372' 2313 3.668 Otis "8" Profile Nipple, Posì.tion #3 11. 10,404' 2.374 5.50" x 4.593" Camco "MM" Mandrel 12. 10,448' Locator Seal Assy 13. 10,449' BOT "Fl" Pkr 14. 10,454' C¡tml~O "I)" NiJ)J)!e 15. 10,547' 45° cut on tbg joint 10/60 9/62 8/72 9/27/04 9129/04 10/2/04 Brief Historv , Originally drilled and completed as a Hemlock producer. WO recomplete as a gas injector. WO Tbg CO Set Cmt Retainer @ 10,177' (20' below bottom of pkr. Bullhead 20 bbls of G Neat. Chased wI Wiper Ball. Tbg on vacuum. Bullhead 20 bbls ofG Neat. Chased wI Wiper Dart & Ball. Tbg on vacuum. PERFORATION Interval Top Btm 10,165' 10,166' 10,183' 10,238' 10,244' 10,255' 10,275' 10,332' 10,344' 10,403' 10,408' 10,421' 10,425' 10,444' 10,460' 10,520' 10,526' 10,546' 10,557' , 10,558' ,_.. --."'0;'''-." ..'----- - TD= 10,785' PBTD= 10,700' Max Deviation = 20 @ 5,931' seu 312-09 Actual Schematic 71208.doc Amt 1 ' 55' 11' 57' 59' 13' 19' 60' HISTORY (OIL Accurn. spf 5.5 4.5 4.5 4.5 4.5 4.5 4.5 4.5 4.5 5.5 Depths) Comments WSO Reperf on 2/03/200 Reperf on 2/03/200 Reperf 10,278' to 10,322' on 1121100 Reperf1O,348' to 10,400' on 1121/00 20' l' WSO REVISED: 8/20/2004 by SL T ) ') Unocal Alaska 909 W. 9th Avenue Anchorage, AK 9950 I Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: oudeand@unocal.com r _1" ',' hir""Ç)~ !, I(j}f¡jii:1 I UNOCAL Debra Oudean G & G Technician Date: November 29, 2004 To: AOGCC Helen Warman 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 SCALE' lOG DATE INTERVAL L'IBN-E' CD , LOGGED . .000...ot>t "KGSF-7A'" !PEÄFÓÄ'ATïÑÓÄ'ËëoÄÒ33ï8'HSDGUN '.. ,,,.,,,,, 5It·JCH 110/2~/200.J16100·6~50 I 1 11 -" / Isëu"'2 4A~'Ö5 -'¡ PLUG 's Ër R ËëÖ ÄD "2"'7/8" H ALii BU Äï-ÓN" EZS V"............ "....... ............]!5..Ù~'C'H'........·..·..r···..1..ôi2..1'I~£õÒ419·6·35~9'6·35 ......·....T..·.." ··1·..··.. '''1'''''1' .....¡ I qo 1.1;'-\ " ;SCU 24A-05 ISOUEEZE PERFORA nON RECORD2 HSD 2006 P J 6spl 15 It JCH I 10/29/200417626- ì800 I 1 11, ~-: ,; L J~~~~:~~: _I~~I~I~~~~~~~Ä~~~~~ETA~NE~ -- - -- - -- .. - --.. - -I~ :;~~~ - i: ~;~~;~~~~ i:~~~: ~~~~ -1- :-!- H /CqO ~oZ<ð ê_~U 312-~_r..COMP~T@N R~~O~D 2 HSD ~O~E~~~_=-=--=-~'I~I~..~8=r-~2(2/20_04-~99~63~~_J. 1 __QJ - 'f.' SCU 32-08 : COMPLETION RECORD 2.5 HSD POWERET 6 SPF 60 ! 5 INCH ¡ 10/3/2004 10200-10565, 1 _ 1 ,I ~ ~~ 5 ~ jscu 43B-081~~~~~~~~~S:~CORD 2.5 HSDPOI¡'JERJETS _ - _ - -Is INCH [ 11/3/200415~5 ì .586711 p J 1 : I~ -0 dq.i,SRU 23-27 HALLIBURTON GUNCORRELATION LOG RESERVOIR '5INCH 1011 ì/2004 5100-7760 1, 1 .¡ \VU 1 \. ¡ SATURATION TOOL I 1QfJrI o~á. ]S'RU 32A-15 ICEME-NT Top"rËMP"SURVEY GR/CCL' ,- 1/5INCH·.'''· 9i2~i2-0~4Jo-9?00 . --", I '-1 -"r 1i ¡qq~Oø~¡SR~ 32A-15 g~~~~~T~~~S~CORD 2 HSDPOWEHJET6SPF 60 __ 5 INCH __ _9/30/20047280-7600 _.- -1 1] ~ lt~C ~~~~:~~.~i:~·':~~r~~~~~~~~~~~~~~l~~~;~;~~~·6S::··:'.··::~'·5'iÑ·CH·"~."~::~Î372õõ4·6~~~~~~~~:'~::~:·:·~] ", 't ,', '. .. iI.~::;; .. WELL LOG TYPE SC.ÀNNE() ,~PH 1 ~ 2JJ05 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. Date: /Z/~~ ( AIfASIiA OIL AND GAS CONSERVATION COMMISSION Iht)-O;)? ~ì Î ¡~\l.r ~ íITul1 ~ ¡X\ ~ ÍÅ\ ~ W ¡?~\ @ U[J=;jJ ~ ~u L1ULSUlJCt'lu~LJU FRANK H. MURKOWSKI, GOVERNOR 333 W. "fTH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 22,2004 Mr. Philip J. Krueger Drilling Manager D nocal Alaska PO Box 196247 Anchorage AK 99509-3330 RE: Swanson River Field W orkover HOPE Configuration Dear Mr. Krueger: Per 20 AAC 25.285 (h), the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants Dnocal Alaska ("Dnocal")'s request for variance from the workover blowout prevention equipment ("BOPE") requirements of 20 AAC 25.285 (c) and ( e), during operations on wells in the subject field. This variance is applicable to Swanson River Field wells SCD 32-08, SCD 33-33, SCD 312-09, SCD 24A-05, SCD 21-03, SRD 23-27, and SRU 32A-15. AOGCC finds that Dnocal's requested variance provides at least an equally effective means of ensuring well control as that required by regulation. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered 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 h<1Qday or weekend. A person may not appeal a Commission decision to Superior Court yt'llesj,rehearing has been requested. ( / SCANNED OCT 1. 0 2004. r-- ~ ~~!Æ~! (ill F £6\~ffi~~~!Æ AI,A.SIiA ORAND GAS CONSERVATION COMMISSION / I / / i j / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 3,2004 0b- ÖO:yß Philip Krueger Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage, Alaska 99519 Re: Swanson River SCU 312-09 Sundry: 304-341 Dear Mr. Krueger: 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Enclosure r-- V'-'qF\ 'f/3/ZPCJ4 Dv:! il.~/~ STATE OF ALASKA ~ ALA~ \ OIL AND GAS CONSERVATION COM~II....dION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U Waiver U Annular Dispos. U Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 P&A and Recomplete 2. Operator Name: 4. Current Well Class: vJ6k 5. Permit to Drill Number: Union Oil Company of California Development ~ Exploratory 0 60-0028-0 /' 3. Address: Stratigraphic 0 Service ,.-% 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-10123-00 / 7. KB Elevation (ft): 9. Well Name and Number: 133' SCU 312-09 / 8. Property Designation: 10. Field/Pools(s): / Soldotna Creek Unit Swansopn River Field/Hemlock, Tyonek 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,785' 10,785' 10,700' 10,700' 10,700' Casing Length Size MD TVD Burst Collapse Structural Conductor 37' 20" 37' 37' Surface 2,980' 13-3/8" 2,980' 2,980' 2,730 psi 1,130 psi Intermediate Production 10,785' 7" 10,785' 10,785' 6,340 psi 3,830 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,165' TO 10,558' 10,165' TO 10,558' 4"; 3-1/2", 2-7/8" N-80 9,236'; 10,053'; 10,547' Packers and SSSV Type: BOT "FH" packer; Brown HS-16-1 packer; BOT Packers and SSSV MD (ft): 10,150'; 10,260'; 10,449' F-1 packer 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0/ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/20/2004 Oil 0 Gas 0 / Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 907-263-7649 Printed Name Philip J. Krueg}r Title Drilling Manager Signature '-. þ;./ //u~ ~ Phone 907-276-7600 Date 9/2/2004 / t ,. COMMISSION USE ONLY r Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3DL.¡~3Lf ) Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 RECEIVED Other: SfP - 2 2004 RØDMS BF l SEPO8 ?on4 Allaka Oil & Gas Cons. COlTll1Ìsaio ~ S"~,q"'ëit7Ì - 40 1 OR f Gf N~LDEROF Anchorage J'i3/dt/ ~ Approved by., ./'" COMMISSIONER THE COMMISSION Date: '-"............. - INSTRUCTIONS ON REVERSE Sub1 nit ilouPIi!ate Form 10-403 Revised 12/2003 r-- ~ seD 312-09 Workover Summary . Slickline GR to 10,550'. POOH. . MIT Csg to 1500 psi. MIT tree. / . MIRU Eline. RIH wi 6' tbg punch gun. Perf@ 10,180'. ,// . RIH wi 2-7/8" Cmt Ret w/~hec alve. Set ret@10,170'.POOH.RDEline.""- . RU cementers. Mixlbullhe 20 bls (100sx) cmt, launch wiper plug, 5bbls biozan post pad. Displace HES var e wiper ball to retainer @ 10180'. . WOC . MIRU slickline. RIH wi GR. Tag cmt ret. RIH open sldg slve. Circulatelfill Wellbore wi lease water. Jug test wellbore to 1500 psi. ./ . MIRU production hoist. . ND tree. NU BOPE. Test same . MU Land joint. PU unseat hngr. RU RIH wi tbg cutter. Cut tbg @ 10,165' .....-- . PU 30k over to unset FH pIa. POOH & LD tbg string. / . RU Eline. RIH wi SCMT to 6700'. POOH logging. . PUMU CIBP on Eline setting tool. RIH set CIBP @ 10,160'. POOH. RD. / . PUMU Completion pIa & jewelry. RIH. MU Chern mandrel @ 2500'. RIH threading Chern inj line. Land tbg in hanger. Set pkr@ 6660'. ,/ . ND BOPE. NU tree test same. RD Demobe rig. . MIRU Slickline. Open sldg slve. RU N2. Blow tbg dry. . RI Close sldg slve. . MIRU Eline RIH perf 77-3 sand. RD. / ~ r-- Swanson River Well SCU 312-09 UNOCALf) As Completed on 8/20/71 Cas i n RKB =17.20' Size T e Wt Grade Thrd Hole Cmt Cmt To 20" Conductor Yes Surf. 13- SurfCsg 54.5 K-55 12.615 Surf 1509' 3/8" 1000 sx Surf DV Collar 1509' 1512' 17.5" 13- SurfCsg 54.5 K-55 12.615 1512' 2980' 600 sx 3/8" 7" 29 6.184 Surf 250' 7" 26 6.276 250' 1179' 7" 23 Butt 6.366 1179' 4798' 7" Prod Csg 26 N-80 6.276 4798' 5756' 750 sx 7" 29 5756' 7238' Thru DV 5896' Calculated 29 Butt X 8rd 6.184 7238' 7242' 9-7/8" @ 8504' 29 7242' 7284' 26 P-IIO 6.276 7284' 8504' 8rd 8584' 8587' 6.276 8507' 9315' 6.184 9315' 10,785' Tobin 4", EVE 8rd 3-1/2", EVE 8rd 27/8" EVE 8rd ! ! ... . . @ u 0 .. 7 {01l.0 TO: 10,785' PBTO: 10,700' Max Deviation = 2° @ 5,931' seD 312-09 Actual Schematic 71208 JEWELRY DETAIL NO. O~h m 00 Item 17.20' - - Tubing Hanger wi Cosasco BPV thrd. 1. 9236' 2.5" 5.0" Crossover, 4" EVE 8rd x 3-1/2" EVE 8rd 2. 10,053' 2.441 4.5 Crossover, 3-1/2" EVE 8rd x 2-7/8" EVE 8rd 3. 10,085' 2.313 3.668 Otis "S" Profile Nioole, Position #4 . 4. 10,116' 2.313 3.668 Otis "XO" Sid.. Sive ¡Closed) 5. 10,150' 2.42 BOT"FH"okr,7", 29# x 2-7/8". 6. 10,217' 2.374 5.50" x 4.593" Cameo "MM" Mandrel 7. 10,260' 2.50 Brown HS-I6-1 Dkr, 7", 29# x 2-7/8" 8. 10,296' 2.374 5.50" x 4.593" Cameo "MM" Mandrel 9. 10,335' 2.50 Brown HS-I6-1 Dkr, 7", 29# x 2-7/8'" 10. 10,372" 2.313 3.668 Otis "S" Profile NiDole, Position #3 11. 10404' 2.374 5.50" x 4.593" Cameo "MM" Mandrel 12. 10,448' Locator Seal Assv 13. 10,449' BOT "FI" PIer 14. 10,454' Camco "0" Nioole 15. 10547' 45° cut on tbg ioint PERFORATION HISTORY (DIL Deoths) Interval AccURL Top 8tm Amt sof Conunents 10,165' 10,166' I' 5.5 WSO 10,183' 10,238' 55' 4.5 Reperf on 2/03/200 10,244' 10,255' II' 4.5 Reperf on 2/03/200 10,275' 10,332' 57' 4.5 Reperf 10,278' to 10,322' on 1/21/00 10,344' 10,403' 59' 4.5 Reperf 10,348' to 10,400' on 1/21/00 10,408' 10,421' 13' 4.5 10,425' 10,444' 19' 4.5 10,460' 10,520' 6(1 4.5 10,526' 10,546' 2(1 4.5 10,557' 10,558' I' 5.5 WSO REVISED: 8/20/2004 by SL T ~ r-- Swanson River Well SCU 312-09 UNOCAL8 PROPOSED Completion Cas i n RKB =17.20' Wt Grade Thrd Hole Cmt Cmt To Yes Surf. SurfCsg 54.5 K-55 12.615 Surf 1509' 1000 sx Surf 1509' 1512' 17.5" SurfCsg 54.5 K-55 12.615 1512' 2980' 600 sx A 7" 29 6.184 Surf 250' 7" 26 6.276 250' 1179' 7" 23 Butt 6.366 1179' 4798' 7" Prod Cog 26 N-80 6.276 4798' 5756' 750 sx '" 7" 29 5756' 7238' Thru DV 5896' i: Calculated .,¡ 7" 29 Butt X 8rd 6.184 7238' 7242' 9-7/8" @ 8504' @ g 7" 29 7242' 7284' 7" 26 P-110 6.276 7284' 8504' 8rd 8584' 8507' 7" 6.276 8507' 9315' 7" 6.184 9315' 10,785' Tobin I ~ . § CIBP@ / 10,160' TO: 10,785' PBTD= 10,700' Max Deviation = 2° @ 5,931' seD 312-09 Proposed Schematic _09-04 #3 JEWELRY DETAIL NJ}. O~h ID 00 Item 17.20' - - Tubin2 Han2er wi Cosasco BPV thrd. A. -2000' Chemical Injection Mandrel B. ~54' Sldg give C. ~O' Hydraulic Set/Retrievable Pkr O. ~76' 2.313 Profile Nipple E. ~90' WLEG 10 160' CIBP F. -10,165' Tbg Cut 6. 10,217' . 2.374 5.50" x 4.593" Cameo "MM" Mandrel 7. 10,260' 2.50 Brown HS-I6-1 pkr, 7", 29# x 2-7/8" 8. 10,296' 2.374 5.50" x 4.593" Cameo "MM" Mandrel 9. 10,335' 2.50 Brown HS-I6-1 okr, 7", 29# x 2-7/8" 10. 10,372' 2.313 3.668 Otis "S" Profile Nioole, Position #3 II. 10,404' 2.374 5.50" x 4.593" Cameo "MM" Mandrel 12. 10,448' Locator Seal Assv 13. 10,449' BOT "Fl" Pkr 14. 10,454' Cameo "0" Nioole 15. 10,547' 45° cut on tb2 joint PERFORATION DETAIL Interval ACCUDL Too Btm An spf Comments 10,165' 10,166' l' 5.5 WSO 10,183' 10,238' 55' 4.5 Reperf on 2/03/200 10,244' 10,255' 11' 4.5 Reperf on 2/03/200 10,275' 10,332' 57' 4.5 Reperf 10,278' to 10,322' on 1/21/00 10,344' 10,403' 59' 4.5 Reperf 10,348' to 10,400' on 1/21/00 10,408' 10,421' 13' 4.5 10,425' 10,444' 19' 4.5 10,460' 10,520' (JJ 4.5 10,526' 10,546' 21] 4.5 10,557' 10,558' l' 5.5 WSO REVISED: 8/26/2004 by SLT MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Cammy O. Taylor ~' DATE: July 25, 2002 Chair SUBJECT: Mechanical Integrity Tests Tom Maunder ~/~~ Unocal Petroleum Engineer~2'U~' ~ ' ( swanson River Field ,~O'1~)(-'~"3~- Swanson River Unit Lou Grimaldi Soldotna Creek Unit Petroleum Inspector NON- CONFIDENTIAL 'WellI 312-9 P.T.D. I 160-028 Notes: WellJ 314-4 P.T.D. J - 160.021 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. I Typelnj.I G I 101501Tubingl' 900 950 920 I lntervall 4 ~oI I I Type testI P J TestpsiI 2538 I CasingI 1450I 2640 I 26201 26201 P/F I E:'~ I I I J Type,nj. I ® ! T.V,D. I ~o~ I Tubing I ~oo I ~?o I ~o I ~o J lntervalJ 4 Type testJ P . J TestpsiJ 2548 J'CasingJ 1950 J 2700 J 2700 I 2700 J PIF J~ _.pt, I we,I 243-4 J Type,nJ.I WO I T.V.D. I ~""~ I Tubing IVacu~mlVacuumlVacuumlVacuumIlnterval I 4 P.T.D.I 161-029,mypetestI P ITestpsil 1500 ICasingI 1000I 1640 I. 16401 16401 PIF Notes: Ori~linal PTD # we,,1 31-33WDIType,nj.I WD I T.V.D. I~,~ I mubingl 900 I ,00 I ~00 I ~00 I,nterva, I 4 P.T.D.I 180-114,TypetestI P. ITestpsil 1500 I CasingI 50 1163011570115201 PIE I _P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING WD -- Water Disposal Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V=, Required by Variance W= Test during Workover O= Other (describe in notes) I arrived at Swanson River Field and met with Ken Cassidy (Lead Operator), we reviewed the test procedures and tested the wells noted above. All wells tested "OK" with the exception of 31-33WD which had to be pressured up twice. This well was on injection when I arrived and the tubing and annulus were pulsing in concert due to the close proximity of the pump and small annulus area (5 1/2" inside 7"). This required the injection to be halted, the casing was pressured up and was declining faster than allowed. We waited for approximately one hour for the well to stabilize and repressured the well, thiS time the~decline was within allowable limits and passed the MIT. The pans of the field I was in were very clean and presentable, the roads were well maintained and travel was easy. M.I.T.'s performed: Four Attachments: None Number of Failures: None Total Time during tests: $ hours cc: Doc HeRon (Unocal Foreman) MIT repOrt form 5/12/00 L.G. MIT Swanson River 07-25-02 LG.xls 8/26/2002 MEMORANDUM .._,~ TO: Cammy O. Taylor L/J) Chair State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 25, 2002 - -- SUBJECT'. Mechanical Integrity Tests THRU: Tom Maunder~"~/~l(~d~ Unocal Petroleum Engineer-~J~'c~5~o~ Swanson River Field Swanson River Unit FROM: Lou Grimaldi Soldotna Creek Unit Petroleum Inspector NON- CONFIDENTIAL · Packer Depth Pretest Initial 15 Min. 30 Min. I "We, i'I 312-9 I Type,ni.I I~.V.o:! ~0'~0 I Tub,n~l 950'i 900 ! 95b I '920 I'n'{ervall 4I P.T.D.I 160-028 J,Ty.'pe{estl. P ,IfestPs, i'l '2538' ICasingl" 1450 I ,2~,0I ?'620I 262,oI P/F '1" P.E"I Notes: ' we,,'I 31,~ IType,nj.I ::~:I -.v.o.i I"¥u,,.,I ,,ooI I~,o I,nterva, l'4' P.T.D.! 160.021 I'Typetestl' ..P ITestpsil 2.548 I,Casingl 1950I 2700'I ,2700 ,I 2700,1 pIF I -P, Notes: ' WeilI' '243-4' T~'Peinj. I WD "1 T.V.D. [ 2892 ITubing'lVacuumlVac'uumlvacUUmIVacuumllntervall 4 P,.'~.O.I 161'-029 '1 ................ Type testI P,I Testpsil1500 .I Casing[ ooo I I I, ,I "'" I, e Notes: Original PTD # WellI 31-33WD I Type Inj. I WD I T'V'D' I 19:17 ! Tubing I .oo I ooo' I "*°° I .oo I lntorval'l' 4 ' P.T.D.'I '180-114 'lTypetestl ,"P 'lTest~)sil 1'5oo I casing I. 50 I t6~ I .'~570 I 1520 ! PIE ,I, =.P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G= GAS IN J. S = SALT WATER INJ. N = NOT INJECTING WD = Water Disposal Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) I arrived at Swanson River Field and met with Ken Cassidy (Lead Operator), we reviewed the test procedures and tested the wells noted above. All wells tested "OK" with the exception of 31-33WD which had to be pressured up twice. This well was on injection when I arrived and the tubing and annulus were pulsing in concert due to the close proximity of the pump and small annulus area (5 1/2" inside 7"). This required the injection to be halted, the casing was pressured up and was declining faster than allowed. We waited for approximately one hour for the well to stabilize and repressured the well, this time the decline was within allowable limits and passed the MIT. The parts of the field I was in were very clean and presentable, the roads were well maintained and travel was easy. MI.T.'s performed: Four Attachments: None . Number of Failures: None Total Time during tests: 5 hqu~ cc: Doc Helton {Unocal, Foreman) MIT report form 5/12/00 L.G. MIT Swanson River 07-25-02 LG.xls 8/5/2002 Unocal Alaska Resources Unocal Corporation 909 West 9th Ave. Anchorage, AK 99519-6247 Tele: (907) 263-7889 Fax: (907) 263-7828 E-mail: childersd@.unocal, com UNOCAI. Debro Childers Geotech Assistant DATA TRANSMITTAL April 4, 2000 To: Lori Taylor 3001 Porcupine Anchorage, AK 99501 Alaska Oil & Gas From: Debra Childers 909 W. 9th Avenue Anchorage, AK Unocal 99519-6247 Transmitting the 'following items: ~ .......... ~,*,'~¢ ...... e ........ *~'~ ....... ,.'-' ......... , ..................... '.'.DA E ............. EO GED · '" ~' ~ .=:~ .... ~ ...... =~, ,.. ~.:. , ,~, .- · ..... ~..~ .,... .... . .. ~.~:,;~ .¢,,-,.~ ...... ~,. ~.~.~~;~,~. ~;:~;~..=. ~_._~_~ ' .' ...... -"~'¢- .'¢ *,' ."" · .,'~ '- ." ', .... '. ' . O~S~u 1~9 ~ l'hermal Decay T me Log 5 in'ch ~ 9/6/99~6400-10714' ~ ! B..Line ~ ......................... l.,~ ........................................... ~.. ........................... · ...................... . ............... t ................................. ~ .................................... ~ .............. ; ................. ...................... ~ ........................................... ............................................................... %~SCU 1~ j Thermal Decay Time Log ~5inch j' 9/6/99!6400-10714 1 Film ...................................................... SOU 12-9 ~ Pedoratln~; ................................................................................................................ Record ~ .......... 5 mch; .............................. ~. ............................................. ~3/00,I ........................................................................ 10150-10330 ~ ............................................................................. 1 ~t B-Line; .......................... S'80'"'~"2':9 ................. ~"¢'e'~'~{i~'"'~'~8 ........................................................................ ~"5'"'i'~'~'h ............. ~ ................. ~0~'["~"0'i"~'~':'~"~'8 ................ ~ .......................................................................... i"?Fii'~ ........................... .............................................................................................................................................................................. ~ ............................... . ................................... , .................................................... ~ ....................................................................... ~ ............. ; ............................. [..S~:~ ....... .~,~.~,9r~i_n~g_~.¢~or~c~f~l~ti_~g_..~ i~c_~. .............. ~!./.~0_~1ooo0-105oo . 1 Film t~[o,, ~.o ~ ~CU 12A-3 Perforating Record/Correlation Log 5 inch i 3/15/00!10200-10550 1 B-Line I - F~-0-'iv~.~;-§'-~''~;~&~i~'~'-¢i~r~ir~a~-[~'~-'~;%'~ ............ T ...... ~'~6~*"~b'~ ................... ~* ~i'~' / i'S*CU I~X:~ 'fi0~&i~'~¥"P~'~"5'"~'~'~{- ................................... ~'"'i'~'~'R ................ ~ ............. ~¥~0'8'""~*'8'~88:'~"~ .......................................................................... ~"'?~;'E'in'~ ~ ~scu 12A-3 'Possiset Plu 5Cement; .................................................................. ','5 ......................................... inch ' ........................................... 3/11/00i10200q0545 ~r .......................................................................................... 1 Rim ~ .................................................... ) .......................... ; ......... g ............................ : .......................... ~ ....: .............................................................................................................. ~ ................................................................................. , ................ : ............................. ~o,.o ~f ..~C~ 14-~ ...... Pedorat~ng Recor¢Correlat~on Log 5 ~nch i 1/14/00 10000-10610 1i B-bne ,~.~¢¢"~'~'0-~'~"~:8 .......... ['~;'~-~';'~'i'i'~'g"'~'~';8'' ................................................... i"~'"i~ .............. ~] ............... '9'~'Tb~8¥~"8'~'Sb':¥8'¢58 .............. ~ ..................................................................... ~"j"~':[in~ I~1 ~O ~ ..................................................................................................................................................................................................... ~ .................................................................................................................................................................................................................................................... t ~ SCU 22-4 MD Composite Field Print j 5 inch L 10/8/99~ 10340-11140 ~ 1 i Film ~ SCU 22-4 ~TVD Composite Reid Pnnt 5 tach 10/8/99 i 10340-11140 ~ 1 ! Rim ~ .................................................... ~ ................................. E,. ............................................................ ~ ................................................ ~ .................................................................................................................................. ~ .................. ~0.~qq iscU24A'5 lCom~let~on Record 5 tach 3/13/00 10200-10640 I 1 B-Line I ~ _. ,ISCU ........................................................................................................................................................................................................................................................... 24A-5 !Completion Record j5 inch ~' ...................................................................................................................... 3/13/00 10200-10640 '] ................................................................................ l lFilm' ............................................... lifo .os '~i t ........................................................................................ ~ i .............................................................................................................. ~ LSCU43B-8tCom~letion Record JSinch i 1/14/00110200-10570 ! l~Film ~ 'i SCU 43B-8~ ........................................ Perforating Recor~Correlation Log ! 5 inch' ................ ~i 3/16/00 10200-10500"'"'" ................................. ~ ................... ~~' ~. ] ~ ~ine' Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) /bo- o~--E Dan Williamson Drilling Manager Wednesday, March 29, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Soldotna Creek Unit Well SCU 12-9 APl No. 50-133-10123-00 10-404 Perforate H1,2, 3, 4, 5 & 7 benches Dear Mr. Christensen: Please find enclosed in duplicate Form 10-404 for the perforation of the H1,2, 3, 4, 5 & 7 benches in well SCU 12-9. The following intervals were perforated on 2/3/00: Bench Top Bottom Feet H 1 10,184 10,203 19 H2 10,228 10,237 9 H3 10,244 10,252 8 H4, 5 10,278 10,322 44 H7 10,348 10,400 52 Total: 132 ORIGINAL RECEIVED 10 2 000 If you have any questions, please contact Ralph Holman at 263-7838. ~011&GMCoes. ColTtmisaion Sincerely, Dan Williamson Drilling Manager 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: Alter casing: Repair well: Othe~i 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 133' KB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: Soldotna Creek Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 1860' S, 730' E, NW Ocr., Sec. 9, T7N, R9W, SM SOU 12-9 At top of productive interval 9. Permit number/approval number 1860' S, 730' E, NW Cor., Sec. 9, T7N, R9W, SM 60-28/92-092 At effective depth 10. APl number 1860' S, 730' E, NW Cor., Sec. 9, T7N, R9W, SM 50-133-10123-00 At total depth 11. Field/Pool 1860' S, 730' E, NW Cor., Sec. 9, T7N, R9W, SM Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10785 feet Plugs (measured) true vertical 10785 feet Effective depth: measured 10700 feet Junk (measured) true vertical 10700 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 37' 20" Yes 37' 37' Surface 2998' 13-3/8" Yes 2998' 2998' Intermediate Production 10785' 7" Yes 10785' 10785' Liner Perforation depth: measured 10183-10238, 10244-10256, 10275-10332, 10344-10403, 10408-10421, 10423-10444, 10469-10520, 10526-10544 true vertical 10183-10238, 10244-10256, 10275-10332, 10344-10403, 10408-10421, 10423-10444, 10469-10520, 10526-10544 Tubing (size, grade, and measured depth) 4" EUE, 8 rnd @ 9235'; 3-1/2" EUE, 8 rnd 9235'-10053'; 2-7/8" EUE, 8 rnd 10053'-10547' Packers and SSSV (type and measured depth) Baker "FH" pkr @ 10149', Brown "HS-16-1" pkr @ 10259' and 10334, Baker"F" @ 10449' 13. Stimulation or cement squeeze summary ~=,,,~ ~,,,,I V Intervals treated (measured) ORIGINAL z00 Treatment description including volumes used and final pressure Ala . OI & Cons. Caamis n 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 6410 7 300 1250 Subsequent to operation 0 5763 0 450 1300 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: Gas: X Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: ~-~~/~ ~A~ ~~~~ Title: A~V~ .~,4/~t/'~, Date: Form 10-404 Rev 06/15/88 SUBMIT In DUPLICATE K.B, · i ii .. · Top of Cellar to IB Top of Col/er to TubJ~g Hang~- ?ub:l~ H--~ger , (TOP to BOl~Cli) 9199,22~ ~ X-OVeR, 3~'EUE 8rd z /," O.D./I.Do 2.~" 1 .I0~ · I 1 Jt ~" i~ . [ ~ ~. ~. ~ 8~ ~. ~o,~.~,~ ~ ra ~c~, ~. = ~. 2~ .. ,o.sr ~1 ~1~1 PAC~ x Y" 2~ 2~," 10,3 1. ~ ~ "5" H~P~, ~s~tion f3 (E~) ' , ~/ 1J~2a" ~ .,o..o,' . 10,~ ~ ~':0 ~3~ ~L - 10,~9,~1: ~ STOF 5U~ ~ ~ for 27 Jt. 3~u EU~ 8rd Tb¢. 816.6~' 30.920\ 1.59" 30.18' 30.~" 6.63e 29.91 :' 6.00* 30.09I 8.~0e 29.. ~71' ~l~C)? I ..... 31.~" . ~.%, " 0.~0 , , _ II III I I II I I I CA;SIN TUBINO DETAIL SECTION 9 T. 7N.R.9W. _ I ii i i I~ mil I ii i ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering September 16, 1992 Commissioner Leigh Griffin Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for SCU 312-9 Mechanical Integrity Test. Dear Commissioner Griffin: Attached is a Report of Sundry Well Operations for a successful, state witnessed, Mechanical Integrity Test on SCU 312-9 The Well Service Report is included for reference. If you require further information, please call Jim Zernell at 263 4107. Sincerely, J. C. Winn Acting Regional Engineer JCW:JLB:0184 Attachment CC: Mr. L. R. Dartez, Jr. Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED S E P 2 1 1992 AJaska .OJl & Gas Cons. ~mroisston ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA 0 R 161 A ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown . Stimulate Plugging Perforate Pull tubing ~ Alter casing ~ Repair well ~ Pull tubing Other X MIT Z. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorat~e, AK 99510 4. Location of well at surface 1860' S, 730' E, NW Comer, Sec. 9, T7N, R9W, SM At top of productive interval Straight Hole At effective depth 5. Type of Well: Development Exploratory Stratigraphic Service At total depth 6. Datum elevation (DF or KB) 133' KB 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 312-9 9. Permit number/approval number (~0-28 / 92-092 10. APl number 50-133-1012~5-00 11. Field/Pool Swanson River-Hemlock feet 1 Z. Present well condition summary Total Depth: measured true vertical 10785' feet Plugs (measured) 10,700' 10785 feet 13. 14. Effective depth: measured 10,700' feet Junk (measured) true vertical 10,700' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 37 20" Yes 37' MD 37' TVD Surface 2998' 13-3/8" Yes 2998' MD 2998 TVD Intermediate Production 10785 7" Yes 10785' MD 10785' TVD Liner Yes Perforation depth: Current: measured 10183'-10238', 10244'-10256', 10275'-10332', 10344'-10403', 10408'-10421', 1042Y-10444', 10469'-10520', 10526'-10544' MD Current: true vertical 10183'- 10238', 10244'- 10256', 10275'- 10332', 10344'- 10403', 10408'-10421', 10423'-10444', 10469'-10520', 10526'-10544' TVD Tubing (size, grade, and measured depth) 4" EUE 8RD @ 9235', 3-1/2" EUE 8RD 9235'-10053', 2-7/8" EUE 8RD 10053'-10547' Packers and SSSV (type and measured depth) Baker "FH" Pkr @ 10149', Brown HS-16-1 @ 10259' and 10334', Baker "F" @ 10449' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure Reoresentative Daily Average Production or Injection Data '~-~,L I V LL S E P 2 1 1992 Alaska Oil & Gas Cons. Corer Prior to well operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0 48550P/D 0 1150 5050 Subsequent to operation 0 49625P/D 0 1930 5300 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed j[i,,,~/,~~ Title Cook Inlet Regional Engineer Date * Note: Pressure is being maintained on production casing to assist in" seating" the sealant material, The pressure will be bled off after an indeterminent period of time. Service Gas Iniector · iissio ~ 08-~6-1992 1:~:41 907 ~8~ 10~0 ARCO Alaska, SWANSON R l VER PRODUCT l ON P. 01 WELL SERVICE REPORT I~ 40 __z~ · lO 5'z. liSo ., I~Z~ 0'~ 5~50 [] (:;HICK THIS BLOOK IF SUMMARY CONTINUED ON BAOK Wemlh'r 1 Temp' [ ChllllF'°t°r t Vl'lblllty IWlnd V'I'R.l~rt 'F " mlle. Il ... , SEP 2-1 lg~Z Alaska 0il & Gas Cons. GommiSsto ~Signe~ Anchorage ~,ot,/. ~V.~C, ~ .......... TYPE OF ~JLUS FLUID HECtI~ICAL IKIE/~IIY IF. ST = - __ · _ _ -. : -. PKR CA, SING $ IZE/ln/GIIADE ._ TBC REQ TES! ~RE~ Field TBG CSG ,PRESS. Title TBG C~ Pl~.SS TINE ' 30 .... TIHE- P ) COFliENTS: *IUBING ItLIE£TIOtl FLUIDs P '- PROIXIC~ WAIER IflJ AlelUL~ FLUID: G_I~)IENT: #ELL TEST: Inil:lal= = 4-year~ tlorkover____ ~-xplaln DIESEL ARCO Alaska, Inc. Post Office Box ;U0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering April 13, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Application for Sundry Approval for SCU 312-9 Mechanical Integrity Test. Dear Mr. Smith: Attached is an Application for Sundry Approval for a Mechanical Integrity Test on SCU 312-9, to comply with UIC Rule No. 6, to test tubing-production casing integrity. Also a proposed operations plan and well schematic for SCU 312-9 is included for reference. If you require any further information in this regard, please do not hesitate to call Jim Zernell at 263-4107. Sincerely, J. C. Winn Acting Regional Engineer TW:DRH:czm: Attachment CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation RECEIVED APR 1 6 199 Alaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. is a SubMdlary of Atlantic Richfield Company ORIGINAL STATE OF ALASKA ALASKA OIL AND O~S CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well _ Change approved program _ Operation Shutdown_ Re-enter suspended well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate __ Other X (MIT) 2. Name of Operator ARCO Alaska, In(~. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 1860' South, 730' East of NW corner, Sec- 9~TcR~v~ At top of productive interval Straight Hole At effective depth APR 1 992 At total depth AJaska 0JJ & Gas Cons. C0mmiss[0n 6. Datum elevation (DF or KB) 133' KB 7. Unit or Property name Swanson River Field 8. Well number SCU 312-9 9. Permit number 10. APl number 50-133-10123-00 11. Field/Pool Swanson River/Hemlock foot 12. Present well condition summary Arlc~i0rage Total Depth: measured 1 0785' feet Plugs (measured) true vertical 10785' feet Effective depth: measured 10700' feet Junk (measured) true vertical 1 0 70 0' feet Casing Length Size Cemented Structural Conductor 3 7' 2 0" Yes Surface 2 9 9 8' 1 3 - 3 / 8" Yes Intermediate Production 1 0 7 8 5' 7" Yes Liner 10,700' Measured depth True vertical depth 37' 37' 2998' 2998' 10785' 10785' 13. Perforation depth: measured 10183'-10238' ; 10244'-10256' ; 10275'-10332 ; 10344'-10403' ; 10408'-10421' ; 10423'-10444' ; 10469'-10520' ; 10526'-10544'MD true vertical 10183'-10238' ; 10244'-10256' ; 10275'-10332 ; 10344'-10403' ; 10408'-10421' ; 10423'-10444' ; 10469'-10520' ; 10526'-10544' T V D Tubing (size, grade, and measured depth) 4" EUE 8RD @ 9235'; 3-1/2" EUE 8RD 9235'-10053' ; 2-7/8", EUE, 8rd 10053'-10547' Packers and SSSV ( type and measured depth ) Baker "FH" Pkr.@10149'; Brown HS-16-1 @ 10259' and 10334'; Baker "F"@ 10449' Attachments Description summary of proposal _ Detailed operation program X BOP sketch _ 14. Estimated date for commencing operation May, 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas _ Suspended Service ;~ (Gas Injection) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR ~MlSSlON USE ONLY Date ~tr/~ ,~'~ L Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Mechanical Integrity Test ~ /- Approved by the order of the Commission Form 10-403 Rev 5/03/89 IApproval,,~o.~ __ Location clearance __ ,, Co,~ I ~, ~- dP ~,.~7.. Subsequent form require 10-zf/o/-} , ,,~.; ORIGINAL SIGNED BY ~--~.~ SUBMIT IN TfllPLIOATE S. DeJarnett March 31, 1992 Page 4 SCU 312-9 To load PCxSC annulus and TbgxPC annulus and to verify mechanical integrity of TbgxPC. W ~._~.e~_~]~: A vertical well; a gas injector SC: Capacities: Top pkr. depth: Current Pressure: Injection Rate: SC testing Pressure: Procedure: Xe 4' to 9236' MD; 3-1/2" to 10,053' MD; 2-?/8" to 10,150' MD · 7"; N-80 and P-110; 23, 26 and 29 lbs/ft to 10,785' MD; wall thickness=0.317" 13-3/8' 54.5 lbs/ft to 2998' MD TbgxPC= 0.0238 bbl/ft PCxSC= 0.1070 bbl/f~ 10,150' MD Tbg= 5350 psi; PC = 2250 psi; 46 MMSCFPD 2600 psi SC = 10 psi RECEIVED APR 1 6 199~ Alaska Oil & Gas Cons. (;ommissiO~ Loading of TbgxPC and PCx~C with lease water Anchorage Instnll a two-pen recorder to monitor SC and PC pressures. . Shoot fluid levels on Tb F. PC and PCxSC. Calculate needed load volumes and prepare the fluid. If no loading is needed, skip to step 11. . Monitor Tbg, PC and SC pressures throughout the Job. 4. Hold a safety meeting. 5. RU choke and gas buster to SC, as needed. . Blow down SC pressure without allowing fluid production. e Hook up the pump truck to SC and pressure test lines to 4500 psi. . Load PCxSC with lease water containing 0.25% WR676 corrosion inhibitor and a 5 bbl crude cap. Do not exceed SC pressure of 300 psi when pumping. 15. DeJarnett March 31, 1992 Page 5 SCU 312-9 (continued) ® 10. Repeat steps 5 through 8 for the PC, as needed. Do not exceed the injection pressure of 3000 psi for PC in Step 8. Contact the Anchorage office to verify that sundry approval has been obtained before proceeding with the MIT. 11. 12. 13. 14. 15. 16. 17. PreSSure test TbgxPC Record the pressure of Tbg, PC, and SC. Leave well on normal.injection. Pressure Tbgx~ in steps up to 2600 psi. Hold for 5 minutes in each step, observing pressures on Tbg, PC, and SC. Limit the SC pressure to 300 psi. Hold the final testing pressure of 2600 psi for 30 _minutes. Observe the initial and final pressures on TbgxPC. Pressure decline should be less than 10%. RDMO. Notify the AOGCC and BLM at least 24 hours in advance. Repeat the test for AOGCC and BLM. RECEIVED APR 1 6 1992 Alaska Oil & Gas Cons, ~;ommissiO[t Anchorage · ~op or Cedar ~o ?ubL~ 4. Fur, ;t.. 4," o.~. (8;~,6.~,2.1o;1.~) (TOP +.o Sm'T~t) 18,6C)" 9199.22* I I II II I ¥op or Plu~ 20o~00e APR 1 6 199~ Alaska'0il & Gas Cons. 6ornmissiOn · .. ~chorage I s U,u CA$1N BING DETAIL SECTION 9 T. 7N.R.9W. ,so ,0.,,¢ a Jr, 2~" 13~ 8hi TbS. 59.95" '0."" 10,216.55'- ~ ~ m( i,o.,,*' " ~ 1J.05' i,u4.' I ~ 2~" E~ ~ Tbs. 29.91:* 10,259;51t- ~o,2~.~,- ~ ~ m ~P~ (~) 8.~, ~ usu f to,~:~&~ STOP S~ ~u P~. .0.~, '"" RECEIVE .~o~ IO~.M m~ ' · STATE OF ALASKA ~ ;" ALA,-c~'''' OIL AND GAS CONSERVATION COI~/~-'"~SION ' ' REPORT OF SUNDRY WELL OPERATIONS _ 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other I~ Hechanical Integrity Test 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360 Anchorage, AK 99510 . Location of well at surface 1,860' S and 730' E from NW corner, Sec. 9, T7N, Rgw 5. Datum elevation (DF or KB) 133' KB 6. I,~nit or Prolzerty narJ3e bwanson River ~-~eld 7. Well number SCU 312-9 At top of productive interval Straight Hole At effective depth At total depth 8. Approval number 8-491 9. APl number 50-- 133-10123-00 10. Pool Hem lock Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Production Perforation depth: 10,183 - 10,544' 10,785 ' feet Plugs (measured) 10,785 ' feet 10,700 ' feet Junk (measured) 10,700 ' feet Length Size Cemented Measured depth True Vertical depth 37' 20" Yes 37' 37' 2,998' 13-3/8" Yes 2,998' 2,998' 10,785' 7" Yes 10,785' 10,785' Tubing (size, grade and measured depth) 4" EUE 8RD 9,235'; 3-1/2" EUE 8RD 9,235 - 10,053'; 2-7/8" EUE 8RD 10,053 - 10,547' Packers and SSSV (type and measured depth) Baker "FH" at 10~149'; Brown HS-16-1 at 10,259' 12. Stimulation or cement squeeze summary 13. Intervals treated (measured) N/A Treatment description including volumes used and final pressure Representative Daily Average ~t~;t~ Injection Dat~!S~!-:: ~' ....... ~" 10w334'; Baker "F" at 10,449'. JUL :1. ;':: Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure TU'brng Pressure 45,986 2,200 5,100 44,200 1,925 5,100 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge . /~,.~L_7~]-~.~/~ . ~ 'i:~ ~.- ~%]~ Signed ~ LC~z--~_ ~ Title Senior Area Engineer Date Form 10-404 Rev. 12-1-85 Submit in Duplicate~ ARCO Alaska, Inc. 8ul~lClt~ of AIi~IIG Riohf~l , ~ / Z-' ~ I WELL CONTRACTOR REMARKS TEL NO: 13,~3:--~,, IFIEM;) - DISTRICT - 8TA'I'E OPERATION AT REPORT TIME ~627 P03 WELL SERVICE REPORT [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W-..mh.,. I Tmmr,. I Chill ~a~lor I Vlmlbllltv I WInd VeL ARCO Alaska, Inc. : Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering June 21, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: 1987-88 UIC Pressure Testing - Swanson River Field Wells SCU 312-9, SCU 341-4, and SCU 323-4 Dear Mr. Chatterton: Attached are Application for Sundry Approvals to pressure test three subject injection wells in compliance with the Swanson River Field Area Injection Order No. 13. These three pressure tests comply with the requirement to test 25 percent of the gas injection/water disposal wells each year. All efforts will be made to complete testing by June 30, 1988. Sincerely, ~ t~2,~ Tom Wellman Senior Area Engineer TW:MLE:ch:0009 Attachments cc: J.A. Dygas, Bureau of Land Management J. Coltart, Chevron USA D. Jones, Marathon G. Graham, UNOCAL 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 [] ~.,Pressl Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other ~Test 2. Name of Operator ARCO AlaSka, Inc. 3. Address Post Office Box 100360 Anchorage, AK 99510 4. Location of well at surface 1860' S & 730' E from NW Corner, Sec. 9, T7N, R9W 5. Datum elevation (DF or KB) KB 133' feet 6. Unit or Property name Swanson River Field 7. Well number SCU 312-9 At top of productive interval Straight Hole At effective depth At total depth 8. Permit number 9. APl number 50-- 133-10123-00 10. Pool Hem Iock 11. Present well condition summary Total depth: measured true vertical 10,785 ' feet Plugs (measured) 10,785 ~ feet Effective depth: measured 10,700 ' feet Junk (measured) true vertical feet 10,700' Casing Length Size Cemented Measured depth True Vertical depth Conductor 37' 20" yes 37' 37' Surface 2,998' 13-3/8" yes 2,998' 2,998' Production 1 O, 785 ' 7" yes 1 O, 785 ' 1 O, 785 ' Perforation depth: 10,183 - 10,238'; 10,244 - 10,256'; 10,275 - 10,332'; 10,344 - 10,403'; 10,408 - 10,421' 10,423- 10,444'; 10,469- 10,520'; 10,526- 10,544'. Tubing (size, grade and measured depth) 4" EUE 8RD 9,235'; 3-1/2" EUE 8RD 9,235 - 10,053'; 2-7/8" EUE 8RD 10,053 - 10,547' Packers and SSSV (type and measured depth) Baker "FH" at 10,149'; Brown HS-16-1 at 10,259', 10~334'~ Baker ".F"-at 10,449', 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation Testing to be completed by 7/1/88. · .... - JUPl ~ ~ z~oo 14. If proposal was ver;~,c,~[l~[~.~r.~ ]~.epm. te(] Name of a~,~rover 1;'orl~ No.~ Dated-fi-2//£ -~1~ .OJJ & Gtl~ COILS, CiNl~llJ~a~tlle ~,~, .... ~ ARC,._._h~_~? approved 15~ I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ L,~/~-,,,,---~ ,,Title Sen i or ,Ar~ E nai neet Date Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity E} BOP Test [] Location clearanceI /7 Approved Copy ,Beturned u#IGINAL SIGNED by order of BY LONNIE C. SMITH Commissioner the commission Date ~e Form 10-403 Rev 12-1-85 Submit in triplicate/~ SCU 312-9 LOAD PRODUCTION AND SURFACE CASING AND PRESSURE TEST PRODUCTION CASING Loading 1. 2. 3. 4. . . PC and SC Annulus RECEIVED Record pressures on the tubing, production casing and surface casing. .{UN 2 3 1988 Blow down PC to 1,000 psi, recording all pressures. Blow down SC, recording all pressures. Naska Oil & Gas Cons. Commission ~ Anchorage Shoot fluid levels for pump-in volumetrics. (Annular capacity (Bbls/ft.): SC = 0.1070, PC = 0.0227). Load SC with lease water containing 10 gal./100 Bbls WT 676 corrosion inhibitor and a 5 Bbl crude cap. Do not exceed 300 psi surface pressure during pump-in. Monitor all pressures. Load PC with lease crude. Do not exceed 2,500 psi during pump-in. Do not bleed PC below 1,000 psi during pump-in. Pressure NOTE: NOTE: . . 10. 11. Testing Production Casing 24 hours prior to initiating pressure testing procedure, contact the Alaska Oil and Gas Conservation Commission at 279-1433 and the BLM at 267-1240, and inform them that a pressure test will be conducted as per Rule 6 of Swanson River Field Injection Order No. 13. During pressure tests of production casing, closely monitor PC/SC packoff to insure no communication to the surface casing. If any communication is noted, cease pressure test and notify Engineering in town. Install two pen chart recorder for tubing and production casing. Inject into tubing at usual rate. Pressure test PC/SC packoff to 3,000 psi. Pressure production casing to 2,000 psi. Hold for five minutes, observing pressures on tubing, production casing and surface casing. If initial pressure is akeady at or above 2,000 psi, proceed to Step 10. If no significant pressure changes occur within five minutes (>50 psi), increase production casing pressure by 500 psi. Hold pressure for five minutes. Repeat Step 10 until a pressure of 3,700 psi is reached. Hold pressure for 30 minutes, noting initial and final pressure on all strings. [[[ [ [ Ill [ Il II .' ~ DYG 2~98' 17.20' II I I I I ' ' Top o£ Ce]~e: ~o IB i~op o£ Ce]~er ~o TubLA~ Haap~* rUbXAg lioN, er . zap ,,Tr.. {. o.:). (TOP t,o 15.00' 18.t0, 29~ ;ts &s 0,D. 9199.22' c~235.5T'-4~. X-OV"g,R, .3%"ET~-. 8Fd x ~.u O.:)./X.D. 2.5' 1.10' 10~C)5J.32i ~7 .T%s ~' EU~ 8rd Tbg. 816.65' T Z-OV~ ~' z 3~' 0.~0' lO,Ott.?~'-J,,._ 0'1'~ '$' liXJ~L~, Position #/. (k~a~T~',) 1.59' w$O ,O.t4 I* .,o.,--' 10.216.55' - . I,o.,,' .... ,--- ti,T.O lt.[ ]"J:~i'tZL .,0..4.' [J IJt2~' ETJE 8rd Tb,. i~.zsr _. lO,259:51 2-" atto,i:, Hs-16-1 PJ~.~, 2%. · ?. 29dl $ .~t 2~u EUS 8z~t Tbg, 10,33/.~?'-~' ~(r~.l !1s-.16;-1 ?~¢x3;R, 2~, x T'. 29f ,,.,--*" "* ' $*' Jt 2~.' Z;~ Ib~ 10, .e.4ik' "~"": lo~Jt6.68 · -,. 4M) t~~O,,,4 AJ,PP'L~-s s'r,oT.,$ As ~; -- i _ _ I I .3 ~. aL' z.~ a~ TM. v~m RECEIVED JUN 2 3 1988 Alaska Oil &'Gas Cons. Commission' -. . hi"_~ , I, ! ..NO. 18m 3.02' ,1::).~' 6.63' ~9.95' 13.0~' 29.~)1 :' 6.00' 29, ~/' 31 '.-~' t.60' X).:~' 1.N.20' .0.~2' SC U 312-9 CASING ii TUBING DETAIL SECTION 9 T. TN.R.9W. - TABLE I 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 Wells being Evaluated for P&A/Future UtilitN 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 owd own 43A-15 314-27 331-27 343-33 .J ATTACHMENT E- 1 Injection Well Data Water Disposal Avg. Wells Rate(BPD) SRU 31-33W 3274 SRU 32-33W 651 SRU/+1-33W 125 SRU 21-33W 2805 scu/+3- K .... MaX. Rate(BPD) /+500 gSO0 /+500 Avg. Press(p.s!) 769 778 913 735 Shut In Max. Press(psi}. 1000 1000 lO00 1000 1000 DePth o f 2100 2100 3100 Depth of Well(ft.) 2/+61 2520 3000 3JQ~ 6660 Gas Injection Ave. Wells Rate(MCFD) Max. Rate(MCFD) SCU SCU SOU $CU $CU SCU SRU SRU SRU 314-2 39,950 323-/+ 35,680 332-/+ 27,6/+0 341-~ 37,6q0 3/+1-8 30,300 312-9 ~,000 321-9 29,9/+0 323-9j~ 35,920 3/+3-33 0 332-15 0 312-22 0 3t~=27 0 0 SRU 331-2_7 q SO00 /+5000 /+5000 /+5000 /+5000 q SO00 /+5000 /+5000 ~5000 /+5000 /+5000 0.5000 45000 5075 5370 5095 5355 5160 5270 5155 5105 Shut In Shut In Shut In Shut In Shut In 6 7 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 5800 10291 1039/+ 10/+70 10226 10256 10183 1029/+ 10280 10695 11388 1075/+ 111/+6 10800 11520 10775 i1119 10850 10810 10785 107/+5 10750 10995 11982 11000 11620 ARCO Alaska, Inc. 110500 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.232 SWANSON RIVER FIELD - UNIT 051950 August 1987 O~-Sep-87 Name of Operator Fi eld and Pool Month and Year of Injection 11. WELLI2. AP1NUMBERIS. C~4. FIELD : NO. I 50- : LI & POOL I I I Al CODE I I I SI 5. DAYSI TUBIN8 PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION IN I I I I OPER 16. MAXIT. AVERAGEIS. MAXI~. AVERAGEIIO. LIQUID Ill. BAS I 13. LIQUID I 14. GAS l___SI 314-4 1133-10104-00 IG I 772100 323-4 1133-1010&-00 IG I 772100 332-4 1133-10107-00 IG I 772100 341-4 1133-10109-00 IG I 772100 341-8 1135-10120-00 IG I 77~-100-- 312-9 1133-10123-00 IG I 772100 323-9 1135-1012&-00 18 I 772100 1345-33 1133-101&8-00 IB I 772100 12-10 1133-2020&-00 18 I 772100 · 521-c~ 1133-10125-00 IB I 772100 43-4WD 1133-10111-00 ID I 7720.5& I I I I I I I I I I I I I I I I I I I 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 PSIS I PSIS I PSIS I PSI8 I (BBL) I ...... l I I 30 15,450 I 4,958 15,300 I 2~359 0 I 0 I 0 I 0 I 0 30 15,500 I 5,005 11,040 I 656 30 15,550 I 5,141 12,8~0 I 2,37~ 0 I 0 I 0 I 0 I 0'I 50 15,350 I 4,~45 tl,240 I lw109 30 15,300 I 4,928 12~&O0 I 2,3&8 0 I 0 I 0 I 0 I 0 0 I 0 I 0 I 0 I 0 30 15,450 I 4,991 ll,g&O I 1,815 0 I '0 I 0 I 0 I 0 I I I I I t 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 1 I I I I 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 INSTRUCTIONS ON REVERSE SIDE I (MCF) I I 39~239 I Ol I 31,632 I 37,1201 I OI I 40,483 I 35~148 I Ol I Ol I 25,70& Ol I I I I l I I l I I I 1 I I I I I 1 I I ITitle x~ ~,c ~/~'J /~¢;~'~. Form 10-405 Rev. 12-!-05 115. I I I I' I I I TOTAL I (BBL) I (MCF) I I 1,177,1&5 I C I 948,955 I 1,113,b09 I 0 I 1,214,475 I 1,054,428 I Ol I 0 I 771,182 0 i I I I I 1 0 I 6,279,814 I Submit in Duplicate ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTIONREPORT 2O AAC 25.232 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051994 Fi eld and Pool August 1987 Month and Year of Injection :1. WELL:2. AP1 NUMBER:3. CI4. FIELD~5. DAYS I NO. | 50- I I I I I I 1512-22 1153-10147-00 1514-27 1133-10154-00 IG I 772100 1531-27 1133-1015&-00 IG I 772100 1432-15 1133-10141-00 IG I 772100 121-35WDI133-101&2-O0 ID 131-33WD1133-20356-00 ID I 772036 132-35WDI.133-10164-00 ID 141-33WD1153-10167-00 ID I 772036 I I I I ' I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I : : LI & POOL I IN Al CODE I OPER SI 1 SI 1 29 30 30 TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION I I I I I 6. MAXI7. AVERAGEI8. MAXIg. AVERAG£110. LIQUID Ill. GAS I 13. LIQUID I 14. GAS PSIG I PSIG I PSIG I PSIO I (BBL) I (MCF) I (BBL) I (MCF> I ...... I I ...... I I I I 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 875 I 734 I I I 2,675 I I 77,581 I I 820 I 746 I 0 I 0 I 2,770 I I 80,518 I I 875 I 759 I 0 I 0 I 2,071 I I 62,119 I I 850 I 731 I I I 145 I I 4,352' I I f I I I I I I r I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 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 I' I II hereby certify that the foregoing is true and correct to the best of my knowledge ->?, , I I lSigned I I l ITitle I Form 10-~05 Rev. 12-1-85 at. INSTRUCT IONS ON REVERSE SIDE -115. I I I I I I' I I I I I I I I I I I I I I I I I I I I ITOTAL I 224,370 I 0 I I I I I Submit in Duplicate PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUOHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUDHOE PRUOHOE PRUOHOE PRUDHOE PRUDHOE BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY BAY UNIT UNIT UN T Ut` IT Ut` IT Ut` IT UI~ IT Ut` IT UN T Ut` IT UN T UN T Ut` IT bN T Ut` IT UN T Ut, IT UN T Ut, IT S-11 S-14 T-1 T-7 U-3 U-5 U-9 U-10 X-6 X-ll X-23 X-24 X-26 Y-3 Y-~ Y-6 Y-7 Y-11RD BAY UN T Y-18 UNIT OR LEASE TOTAL POOL TOTAL FIELD TOTAL S~/ANSON RIVER, HEMLOCK OIL POOL ARCO ALASKA INC SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT SOLDOTNA CK UNIT ...... SOLDOTNA CK UNIT SOLDOTNA CK UNIT 314-4 323-4 332-4 341-4 341-6 312-9 321-9 323-9 412-10 343-33 UNIT OR LEASE TOTAL 309;534 174,467 380,162 602,357 515,072 26h,751 183,322 244,173 294,661 149,980 173,544 262,057 282,344 76,492 49,131 84,323 22,223 43,679 306,~29 14,519,526 39,536,156 84,445,002 39,536,156 88,810,140 SOLDOTNA CREEK UNIT SHUT-IN SHUT-IN 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 31 1,148,650 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 7,430,982 6,975,040 7,115,160 1,241,472 2,275,741 2,727,957 2,791,476 2,551,632 1,790,980' 1,767,557 6,174,166 5,618,096 3,530,342 5,273,083 3,169,181 3,942,403 1,968,753 2,653,403 102,640 597,32q 6,409,296 1,388,876 294,742,915 233,327,280 207,759,340 231,764,932 218,694,647 304,044,302 33,033,842 170,911,513 111,h13,676 - - 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 ADL-18731 TRADING BAY 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 O OIL POOL UNION OIL CO OF CALIFORNIA ADL-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 7,430,982 7,430,982 CUM. OIL CUM. WATER ~13,934 15,582,616 4,498,822 6,267,061 7,3~8,684 21,618,136 CUM. GAS 28,263,659 ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.232 ARCO Alaska, Inc. 110500 Name of Operator SWANSON RIVER FIELD - UNIT 051994 Fi eld and Pool December 1986 Month and Year of Injection II. WELL~2. API NUMBER~5. C:4. FIELD : NO. I 50- I LI & POOL I I I Al CODE I___SI 1512-22 1155-10147-00 I G I 772100 514-27 1155-10154-00 I G I 772100 ~:~.!:..~51-27 I I I I I I I I I I l I I I I I I . . 1 155-10156-00 I G I 772100 155-10141-00 I 8 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 I I' I I I I I I I I I I I I I I I I I l I I I I 5. DAYSI TUBING PRESSURE I CASING PRESSURE IDAILY AVERAGE INJECTIONITOTAL MONTHLY INJECTION IN I I I OPER 16. MAXI7. AVERABEI8. MAXIg. AVERAGEIIO. LIQUID Ill. 8AS PSIS PSIS (BBL) (MCF) II hereby certif~ that the forego~i:ng is true ~d c~rrect to the best of my knowledge I Title ..... Date ......... I Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE I PSIS I I PSIS I I I I I I I I I I I I I I I I I I I I I I I I I I I I. I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 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 I15. I I I I I I I I I I I I I I I I TOTAL I 0 I 0 I I I Submit in Duplicate ALASKA OIL AND GAS CONSERVATON COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.252 I ARCO Alaska, Inc. 110500 SWANSON RIVER FIELD - UNIT 051950 December 1986 ~ Name o~ Operator Field and Pool Month and Year o~ Injection ~1. NELL|2. API NUMBER~5. CI4. FIELD~5. DAYS~ TUBING PRESSURE I CASING PRESSURE ~DAILY AVERAGE IN3ECTION~TOTAL MONTHLY IN3ECTION I NO. I I- I I 50- 514-4 1155-10104-00 525-4 1155-10106-00 552-4 1155-10107-00 · ~..-ti']541-4 1155-10109-00 541-8 1155-10120-00 512-9 ~155-10125-00 525-9 ~155-1012&-00 :545-53 1155-10168-00 1412-10 1155-20206-00 521-9 1155-10125-00 I LI & POOL I IN I I I ~ Al CODE I OPER i6. MAXI7. AVERAGEi8. MAXI9. AVERAGEllO. LIQUID :11. GAS f 81 I i PSIG I PSIG I PSIG I PSIG i (BBL) I___Sl I I 772100 I I 772100 I I 772100 1 I 772100 I I 772100 I I 772100 I I 772100 I 772100 I I 772100 I I 772100 I ...... I I ...... I I 50 15,500 I 5,015 I2,500 I 1,560 I 50 15,650 I 5,278 15,250 I 1,976 I 50 15,500 I 5,071 I 700 I 594 I 50 15,550 I 5,157 11,200 I 849 I 50 15,500 I 4,882 11,400 I 1,548 I 50 15,000 I 4,697 12,850 I 1,267 I 17 15~200 I 5~140 11,600 I 1~588 I 0 I 0 I 0 I 0 I 0 0 I 0 I 0 I 0 I 0 I 50 15~540 I 5,150 11,600 I 1,089 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I .-. ~ I I I I : I I I _.. I I I I I I I I I I I I 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 115. I I I I I I I TOTAL I I ...... I I II hereby certify that thee ~or~going is true.and correct to the best o~ my knowledge ' Si gnld __I _ ..................... . G uperV~sor, Ne. Ventures Compliance and Revenue Ti ~l e Date __ Form 10-405 Rev. 12-1-85 INSTRUCTIONS ON REVERSE SIDE I 15. LIQUID I 14. GAS I (MCF) I I 52,501 I 29,526 I 24~058 I 29,951 I 25,121 I 55,165 I 25,550 I I 450,~02 0 I I 0 0 I I 0 20,970 I I 629,091 I I I I I | 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 J I I I I I I 0 I &~288~&55 I I Submit in Duplicate (BBL) I (MCF) 975,018 885,785 721,155 898~524 695,626 1,054,878 I LEASE NO. I ENHANCED RECOVERYI COMP. DATE + ~ YEAR STATUS PRODUCT JAN FFR MAR APR MAY JUN JUL AIlg SFP neT NOV DEC TOTAl CHH_ ~~m~ SWANSON RIVER, HEMLOCK ARCO ALASKA INC ~OLDOTNA CK UNIT 516-4 AP! 153-10104-00 UNIT051950 OIL 08/15/60 HTR I$INJ GAS 1055857 1026590 1189909 1165806 1228646 1211657 1257286 1288552 1505704 1125075 1022955 975018 15808655 291785545 SOL~OTNA CK UNIT 32~-4 APl UNIT051950 OIL 0'6/01/61 HTR GINJ 6AS 926806 895795 1014489 1021515 1095847 1095954 1110742 1160265 1165222 986857 950909 885785 UNIT051950 OIL 06/05/60 HTR 1GINJ GAS 729520 694699 694207 768354 848986 808659 855755 906429 908925 775879 755048 721155 9465572 205554815 SOLnOTN~ CK HNTT . ~61-6 APl ~-~n~nq-nn UNIT051950 0IL 05/21/60 HTR 1GINJ GAS 964182 959897 1105510 1004702 1191650 1125455 1151894 1167267 1142665 989567 1047597 898524 12728466 228845715 SOLDOTNA CK UNIT ~4]-~ APT UNIT051950 0IL 07/14/61 HTR 1GINJ GAS 772050 721011 855765 795562 858795 851801 877466 885419 861454 802085 790782 695626 9761772 217114264 SDLDDTNA CK UNIT 3]~-q APl l~-]n]~-nn UNIT051950 0IL ]0/09/60 HTR 1GINJ GAS 1150860 1105246 1275468 1219454 1266~62 1242821 1268188 1518592 1512222 1120415 1159677 1054878 SOLDDTNA CK UNIT 3~]-q API UNIT051950 0IL 07/19/61 HTR I. GINJ GAS 787999 770786 941516 857121 859651 824009 859794 852454 865441 701058 657884 629091 9546564 51111755 SOLDOTNA CK UNIT 325-9 AP~ UNIT051950 OIL 07/17/61 HTR 1GINJ GAS 868162 887705 1057404 1002092 1041454 1027008 1054526 1105448 1110180 1002927 967125 450602 11552455 168145955 SOLDOTNA CK UNIT ~]2-10 AP1 UNIT051950 0IL 06/11/72 HTR ° 1HINJ GAS SOLDOTNA CK UNIT UNIT051950 OIL 03/08/61 HTR ' 1GINJ GAS -,. SHANSON RIV UNIT UNIT051994 0IL 10/24/59 HTR ' 1GINJ GAS SHANSON RIV UNIT UNIT051994 0IL 08/04/61 HTR IGINJ GAS 343-33 432-15 34-15 AP! API 133-10141-00 AP! 133-10142-00 138887,. 111413676 4018206 9029539 2056925 4643530 !!! LEASE NO. IENHANCED RECOVERYI COMP.DATE 4 + STATUS PRnnUCT JAN FFR MAR ~~ SWANSON RIVER, HEMLOCK SHANSON RIV UNIT $12-22 UNITO51q94 OIL AP1 ALASKA INDIVIDUAL HELL~0DUCTION FOR 1986 'APR MAY JUN JUL AU~ .. SFP OCT 133-101q7-00 NOV YEAR TOTAl CIIM. 08/11/62 HTR 1GINJ GAS SHANSON RIV UNIT UNITOSlqgq OIL 51q-27 API 133-1015q-00 87~988 24017269 06/lq/60 HTR 1GINJ GAS SWANSON RIV UNIT UNITOSlq94 Oil 331-27 API 153-10156-00 7BS32178 02/17/$8 HTR 1GINJ OAS ARCO ALASKA THC 28265t OPERATOR TOTALS OIL HATER 8,537,995 POOL GAS 7,041,527 7,832,406 8,187,$02 8,680,226 7,q99,819 6,288,655 1,929,187,012 7,215,596 8,115,868 8,569,~q9 8,395,451 8,667,789 7,511,775 95,601,665 SNANSON R~VER. HEMLOCK TOTALS OIL HATER 8,337,995 FIELD . TOTALS OAS 7,041,527 7,852, q06 8,187,50Z 8,680,226 7,499,819 6,288,655 1,929,187,012 7,215,596 8,113,868 8,369,449 8,395,~51 8,667,789 7,311,775 95,601,663 SNANSON RIVER OIL HATER 8,337,995 GAS 7,041,527 7,852,406 8,187,502 8,680,226 7,499,819 6,288,655 ~;~929,187,0~' i) 7,215,596 8,115,868 8,569,qq9 8,393,q51 8,667,789 7,51'1,775 95,601,6 q SWANSON RIVER WELL ~ I~/~ .___ SRU __q 81 --SRU .51 ~/Sf ~_m_ SRU · ~'S~C U iSCU ~ SCU ~ SCU ... SOU ,.SCU -~ SCU 5r /~/~ -SRU 312-2~ 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-in Injecting Injecting Injecting Shut-in Injecting Injecting Injecting Shut-in GRU 13/2 c RECEIVED F E B 2 5 ;.!;.i:;..7 Alaska Oil & ~as Con=. Commission Anchorage ARCO Alaska, Inc. f Post Office b,.,,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 265 6369 John C. Havard Engineering Manager Cook Inlet/New Ventures July 14, 1987 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Re: Swanson River Unit: Gas Injection Well Production Casing Pressure Tests Dear Mr. Chatterton- Attached are seven (7) Well Service Reports documenting the results of the recent pressure tests conducted on Wells SCU 314-4, SCU 323-4, SCU 332-4, SCU 341-4, SCU 312-9, SCU 321-9, and SCU 323-9. The other active gas injection well, Well SCU 341-8, is currently loaded with kill weight fluid in anticipation of a late-September workover to repair a packer leak. Of the seven gas injection wells tested, only one (Well SCU 323-4) did not meet the criteria stated in Rule 6 of the AOGCC Area Injection Order No. 13. The remaining six wells held their calcu- lated test pressure (within 10%) for 30 minutes. The test pressure for each well was calculated to generate a differential pressure gradient across the casing of 0.25 psi/ft at the vertical depth of the uppermost packer. The surface pressures in Well SCU 323-4 have stabilized at acceptable levels (PC +_!500 psig, SC +_I00 psig). We will be retesting this well for integrity in the near future. AOGCC and BLM representatives will be notified 24 hours in advance of this test, should they wish to be onsite. Until that time, we propose to continue injection into this well. If you need additional information, please contact H. F. Blacker at 263-4299. Very truly yours, JCH:JWR:cI:0004 Attachments cc: Mr. Joseph A. Dygas - Bureau of Land Management ARCO Alaska. Inc ;s a Sub$~dlar~ of AllantlcRichfieldCompar~y [:~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report 'F "FI mull[ '~FO~ 3160--5 (November 1983) (Formerly 9--331) U. .!ED STATES sus=I? ~a ~:' ~. (Other Instruetle Ja re- DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT Form approved. Budget Bureau No. 1004-0135 Expires. August 31, 1985 §, LIAll DESIGNATION AND aml, wJL NO. SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~e this form for proposals to drill or to deepen or plug back to a different reservoir. Use *'APPLICATION FOR PERMIT--" for such propomMt) (J. Il' iNulAN, ALLOt'rIB OIt TIIBI NAMe 2. NAME OF OPERATOI ARCO Alaska, Inc. ADDEEaR OF OPERATOR O,L*WELL ~] GXSWEL*L* ~' STEER Soldotna Creek Unit 8. B'AItM 0e LBAIB NAMa P.O. Box 100360, Anchorage, AK 99510 4. LOCATION OF IVELL (Report location clearly and in accordance with any 8tats requirements.· See also space 17 below.) At surface Soldotna Creek Unit - 7 wells 16. ELEVATIONS (Show whether Dr, RT. Git, etc.) 14. PERMIT NO. O. WBLL 1~0. 10. FIELD AND POOL) 01 WILDCAT Swanson Rivmr Field IUItVBY OB JmmA Sec. 4, 9, T7N, R9W Kenai I Alaska Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICe O/~ INTENTION TO: TEST WATER SHUT*OFF J ] PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPI.ETE SHOOT OR ACIDIT-B ABANDON* REPAIR WELL, CHANGE PLANS (Other) X Pressure Test IOBIBQUBHT I]l~OU~ OB' .* WATER BHOT*OrW ~ naPAlmINO WeLL FRACTURe TREATMENT ALTIRINO CASINO 8H~TINO OR ACIDI~INO ABAN~NMBBTe (Other) (NOTE: RePort results of multiple completion on Well Completion or Reeompletlon RePort and Log form.) T. !,E.~('it',llM I'ROI'OSED OR COMPLETED OPERATIONE- (Clearly state all pertinent details, and give pertinent dates, IncludlDg estimated date of starting any proposed work. If well is directlonally drilled, sire subsurface locations and measured and true vertical depths for oil markers and Sones perU- nen~ to this work.) * The AOGCC has issued Area Iniection Order No. 13, applicable to Swanson River Field~ effec- tive Hatch 16, 1987. To comply with Rule No. 6 - Demonstration of Tubin~/Casing Annulus Mechanical Integrity, ARCO Alaska, Inc. is planning on pressure testin~ the production casing annulus of e,ach active gas injection well at Swanson River to a surface pressure sufficient to generate a differential pressure of 0.25 psi/It between the uppermost packer and the formation. The wells included in the program are wells 314-4, 341-4, 312-9, 323-9, 321-9, 323-4, and 332-4. The attached procedures outline the steps that will be taken to conduct the test. The wells are currently being loaded with fluid in the production casing and surface casing annulS. The pressure testing is expected to occur in the last two weeks of June, 1987. RECEIVED JLIN .... ~:'., !9~7 Ataslm 0il & Gas Cons. Commission Anchorage, 1~. I hereby cert~fy~hat the foregOnE is tr~e and correct Regional Engineer TITLE ,, · (This space for Federal or State ofliee use) APPROVED BY , CONDITIONS SlY APPROVAL, II~ ilq~: TITLE DAT~ *See Inwucfions on Reverse 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 ~-;.~-~ ~,o~e ,~,,,. L~i_~e. fictitious or fraudulent statements or representations as to any matter within its jurisdiction. SCU 312-9 - LOAO PRODUCTION AND SURFACE CASING AND PRESSURE TEST PRODUCTION CASING Loading PC and SC Annulus 1. Record pressures on the tubing, production casing and surface casing. 2. Blow down .PC to 1000 psi, recording all pressures. 3. Blow down SC, recording all pressures. . Shoot fluid levels for pump-in volumetrics. Estimated volumes from most recent fluid level data are noted below. ® Load SC with lease water containing 10 gal/lDO0 gal WT 676 corrosion inhibitor and a 5 bbl crude cap. Do not exceed 300 psi surface pressure during pump-in. Monitor all pressures. . Load PC with lease crude. Do not exceed 2500 psi during pump-in. not bleed PC below 1000 psi during pump-in. PreSsure Testing Production Casing Note: 24 hours prior to initiating pressure testing procedure, contact the Alaska Oil and Gas Conservation Commission at 27g-1433 and the BLM at 267-1240, and inform them that a pressure test will be conducted as per Rule b of Swanson River Field Area Injection Order No. 13. Note: During pressure tests of production casing, closely monitor PC/SC packoff to insure no communication to the surface casing. If any communica- tion is noted, cease pressure test and notify Engineering in town. 7. PreSsure test PC/SC packoff to 3000 psi. . Pressure production casing to 2000 psi. Hold for five minutes, observ- ing pressures on tubing, production casing and surface casing. If initial pressure is already at or above 2000 psi, proceed to Step q. ge If no significant pressure changes occur within five minutes (>50 psi), increase production casing pressure by five hundred psi. Hold pressure for five minutes. 10. Repeat Step g until a pressure of 3700 psi is reached. Hold pressure for 30 minutes, noting initial and final pressure on all strings. Volumetrics Surface Casing Production Casing Fluid Level Recently loaded Recently 1 oaded · Annular Capacity (bbls/ft) .1070 .0227 Estimated Fluid to surface (bbls) TRANSMITT,"'~;A__ND ACKNO~L,E:DGEMEN.T OF RECE]:P~ ~,TER'[AL - (ALASKA) THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHECK AND ADVISE IMMEDIATELY. lEA. ~,/ELL :~ gCq 3"ll-fl FOL~~ l~E:v'. 5ap iA ~ I ZA. l~Lde.~ sz .q ii 31-2.,fl~/ ,i __ i- ,11 RECEIVED BY REMARKS ON OTHER SLOE, THIS SHE"ET ~ON U.S.A. INC. BOX 7.839 'ANCHORAGE, ALASKA 99510 TRANSMITTAL/'--'1D ACKNO~fLEDGEMF, NT OF RECEIPT O--'~, \TERIAL - (ALASKA) DATE FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. I Ill · I Z ii[ Il I I ! i i _ ~ [ [ i 4 // /, .-- 33z_ S/ · REMARKS ON OTHER SIDE, THIS SHL~ET AN~-tOI~AGE, ALASKA 99510 'fRANS~TTAL AND ACKN~.EDCMENT OF RECEIPT OF MATERIA __~_ ........... . .. , _. ~., ,. 6tare. of Alaska ])EPT=~ Division of OII & Gas ': ~)01 Porcupine Drive .' LAnch°rage' Alaska 995O4 . - . THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREWITH. PLEASE . CHECK AND ADVISE IMMEDIATELY. .-. . o . . · · · Remarks: ..... (~UJMIT IN TIOPUCA~ UNITED STATES DEPARTMENT OF THE INTERIOR GEOLO~iCAL SURVE'Y . SUNDRY NOTICES AND REPORTS ON WELLS Well No. SCU_12.-_9._ is located :.1865.__ ft. from._ line and ___7_k5 .... ft. from line of sec ...... 3. .... .s~.___.~. ,_~t,o.~,__~t,__9 ..... __~_-~- ................ --~-"- .......... ~..~_...B..~_.M_ _. (.~ flee. m,:i Bee. No.) (~.) (Rlu~e) (Mertdi&n) ...11~_.~1~3~ ............... '_. j.~_ll~;t__~...~...u.~ ................. (ridd) ~ (cowry or stii~af;~l~h'~ ......... '(5/.~,'~:¥;/fi~Y)' ............. . The-elevation of .the ~ abOve, sea .level is _!33 ..... ft. DETAILS OF WORK . (Bate name. d and o=pe~ted depths to obj~ctiv. '~.mi.j .hqw..dn~., w:ifhta~and ionlth. ? Iw?Toud .udnfo; indium muddln~ job~ ' Inw p6ints, and &ii oth4~ important prop4M4m 1. lmitiat~l ~s injection November 23, 1962. . .......... . ............ In/t/al-injectiOn rste :1:3,~20 M/D _ e Petroleum Branch Division of Mines and Minerals Alaska Dept. of Natural ResourceS UNITED STATES GEOLOGI~L SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS T,~ fOllowi:~ is a correc~ report of operation,s a'~d prod~ctior~ (i?~c~udin.?.. dri~Hno~ and prod~oi~ ' ,- ' Packer ~ at !0~1~ ', 10~336' ~ 10~44~ ~ o ~mo~d BOPE, Instal.ed ~ teatea ht~ pres$~e gas inJectioa x-~s :~',' tree. Dis ced ~' ' Set pa~kera. Fl~ea ~ ~ e~, ~ned 11 t o pr~ucti . ..... RECEIVFD ~nd~omge~ Alas~ .. State -Do B. · g. ~ ~$~r ~ask Dept. '. No~.--There were ...................................... runs or sales of oil; ' M cu. ft. of gas sold; ............................................ runs or sale~ of gasoline during ~he month. (Write "no', where applicable.) NoTw..--Repm-~ on this form is required, for each calendar month, regardless of the status of operations, and must be filed in d.ul~.~lilca~te with' the supervisor by the 6th of,' the succeeding moath, unless otherwise directed bS the supervisor. UNITED STATES' DEPARTMENT OF'THE INTERIOR GEOLOGICAL SUR~EY -,~ LESSEE'S MONTHLY REPORT OF OPERATIONS . . _ ~ l'ollowi~-ig 'a.:e°rieot.-report of operations and production (inelu, di,~ drilling and prodeoi.4 -'..~-~.~,~ro;~.~o~ o&;:_.~ ........ :_~s~ .............. , ~o.6a ......... .~~ ~~ o~.,_ .......... :...' ..... ,. ..... -' -,....:~,,~,, ,~,.~.:__: ........... ~-,_~p,... ~___7_~ ....................... oo~.~,~ :~~ :- .~~~4~.. o.~. ......... ~ ...................... .._):_.~~,,. .~~,_ ................... . .. , _ . ,. ,......., ,.... - ~AS~ ] WA~ER (~ (If drllHn[, ~h; ii ~hut down, Black. ,~tc ~ t I u.s.G.sL - M, Cu. F~. o, Gas (In tho~) i , tud. Pulle i' " b : State.-iD. D; ~raoe · { Files -, Prod~e~ Killed well with t¥ d:'" "' NOTz.:--'[~er~ ~,re ............................... ;__.. runs or s~les of off; .............................................. M ou. ft. of i~ sold; ........... , .......... . .................... r~ns or ~'of gasoline d~n$ the month. :'...::([.: :: ','.' : "~.,~~ ~ ~his f~ ~'~r~uir~..~r ~ch cal~d~ month, reg~ess of the stat~ of o~mtlons, and m~t be ~led tn .... :,~,[:~i~.~:.th~.~~ b~ ~ ~ ~ lh~ ~u~~ mon~, ~ ome~ di~ed by ~he supervisor. ~:.':. .: . . . UNITED STA'FE~ DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY' sUNDRy NOTICES AND REPORTS ON WELI.~ ,, _ (INDICATE ABOVE. BY CHE~K MARK NATIJIqE OF RIBIq3NT, NOTI4::L ~ OTHIN DATA) e,,° 0,#7, . '. · . },'m'm P -. 7 SUBMIT IN DU-, ~gCATE* STATE OF ALASKA (See other In- St rllct ions on OIL AND GAS CONSERVATION COMMITTEE I I I I II III I IL I WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. ' o-, "'--S i3' ' ' W ELI. IV ELL DR Y Other b. TYPE OF COMPLETION: v,' F, L I. OVER EN flICK , nESVR. Other __ 2. NAME OF OPERATOR ADDRESS OF OPERATOR ._ . 4. LOC^TION OF WELL (Report location clearly and in accordance with any State requirements)* 5. APl NU1VLEKICAL CODE ,.5',~-/$$- / o/.23 6. LEASE DESIGNATION AND SERIAL NO. At surface At top prod. interval reported below At total depth 13. DATE SPUDDED [14. DATE ~r.D: IiF-~CHED Itl. TOTAL DEPTH, NLD & TVD~9, PLUG, BACK ! 22, PRODUCING INTERVAL(S). OF 'CHIS COMPI.,ETIOINI--TO,P, BOTTOM, NAME (MD AND TVD)* 24. TY-PE ELF-CTRIC AND OTHER LOGS RUN 7. IF INDIA. N, ALLOTTEE OR TRIBE NA1ViE 8. UNIT,FAAllVI OR LEASE NAME 9, WELL NO, 10. FIEI. dD A.ND POOL, OR WILDC iT 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) [15;: DATE CO'M.P SUSP 0l~ ABAND. MD & TVD[20. IF 1ViULTI~LE COM~L., I-I O'~V 1V/ANY* 12. PERMIT NO. i ELEVATIONS (DF, RKB, RT, GR, ETC)* ]17. ELEV. CASINGtlEAD 21. INTER'VALS DRILLED BY ROTARY TOOLS [ CABI,E TOOLS ,23. x, VAS DIRECTIONAL ! SURVEY MADE I i i , 25. CASING RECORD (Report all strings set in we{l) II I I [I I I / Ill I I I I 20. LINE~ RECO~ [ 27. 28. PEaF6R.ATiOHS OP~ TO P~ODUChO~' ~'~nterval, Size and number} i iii i i i ~ lUll 30. PRODUCTION DATE FIRST PRODUCTION [ ~oDucT1ON MEII{O.D (Clowii~C, gaz Ii/i, p~mping~size and type of pump) 9aT~ or T~S~, [HOURS TEST~~ '[CI-tOXE SIZE '[PP. OD'N ~O.~ OI~BEL. Gz%~CF. FLO~V, ~TBING JCAS~'G PRES'SURE IcAL~~ OI~BBL. GA~IXCF. 31. DISPOSITION OF CAS (gold, used ]or tuel, Cented, etc.)' 32. LIST OF ATTACHMENTS CEMLNTING RECOILD ,, [ 1 ACID, S~!OT, F;~AC'iOEE, CF2,IENT SQUE-'E'ZE, ETC. /Y~AOUNT PULLED II I TUBING RE~0 PJ~ t D EPTH SET 11%~D) ] PACKER SET (MD) , AMOUN£ Z~ND I'2!ND OF MA~I~P,J. AL USED J VvELL STATUS (Producing or WATEI't~BBL. J GAS-OIL IL~.TIO , W&TER--BBL. JOIL GRAVITY-API (CORR.) ITEST \";ITNESSED BY 33. I hereby certify that the foregoing and attached information is complete and correct as determined from all-available records *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on ell types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in clher spaces on this form and in any att,~chmer~ts. Items'~0, and 22:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show thc.. p~cJuci~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv,~l reported'in iten~ 30. Submit a separate report (page) on this form, adequately identified, for each additior~al interval to be seperately produce. J, show- ing the ackJitional data pertinent to such interval. Item'/& "Secks 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 produced. (See instruction for items 20 and 22 above). FORMATION TESTS' INCLUDIN(; INTEI~VAI. TESTED, PHE?~UR~ DATA. A.ND P,~ECOVERIES O~ OIL GAS, WAT~I AND MUD 35 MARK~ . . , · . ~, ,., ...... ~. . .... .. ........ ..... . ..... .. ............. ~N6 i;E:i,~t~Eii ~i~6ws or OiL. ~ On ' ' ECEIVED' i · AREA: Kenai Peninsula, Cook Inlet Area, Alaska PROPERTY: Soldotna Creek Unit LAND OFFICE: Anchorage Lease No.: 028997 WELL NO.: SOU 12-9, Section 9, T. 7 N., R. 9 W., Seward B & M LOCATION: 1865' S. and 745' E. from NW Corner Section 9 (Proj.) T. 7 N., R. 9 W., Seward B & M ELEVATION: 133' K.B. DATE: December 21, 1962 E.B. is 15' above 'ground. BYe' V' C]F~a.~~,- bis~rtct- Superintendent CONTRACTOR: Santa Fe Drilling Company, Rig ~35 DATE COMMENCED REMEDIAL WORK: August 27, 1962 DATE COMPLETED REMEDIAL WORK: September 9, 1962 DATE BETURNED TO PRODUCTION: September 9, 1962 SUMMARY TOTAL DEPTH: 10,785 ' PLUGS: 10,785 - 10,700 ' JUN~: None CASING: 20" conductor cemented at 37' 13 3/8" casing cemented at 2998' in 2 stages: 1st Stage around shoe with 600 sacks. 2nd Stage through DV at 1488' with 1000 sacks .~ 7" casing cemented at 10,785' in 2 stages: 1st Stage around shoe with 750 sacks 2nd Stage through DV at 8504' with 750 sacks % COMPLETION REPORT SOLDOTNA CREEK UNIT 12-9 SECTION.9~..T. 7 N.~ R. 9 W.~ SEWARD B & M ~TA~DARD OIL COMPANY OF CALIFORNIA, W.O.I. - OPERATOR Page 2. PERFOBATION RECORDS: Jet holes 10,165 - 10,166' jet holes 10,557 - lO, 558' Jet holes/_ft. 10,536 - 10,546' 10' 41 shots jet holes/~ft, lO, 536 - 10,526' 10' 41 shots jet holes/.ft. 10,520 - 10,460' 60' 2~1 shots jet holes/ft. 10,441- 10,425' 16' 65 shots jet holes/ft. 10,421 - 10,408' 13' 53 shots jet holes/~ft. 10,403- 10,344' 59' 237 shots jet holes/~ft. 10,332- 10,275' 57' 229 shots jet holes/,ft. 10,255- 10,244' ll' 45 shots jet holes/ft. 10,238 - 10,183' 55' 221 shots Commenced rigging up at 10:30 A.M., August 27, 1962. Cleaned out Baker mud tank to mix Black Magic mud. AUO~T ~8,: 196~ Cleaned out Baker mud tank. Mixed Black Magic mud. Au, oUST 29, 1962~ Mixed Black Magic Mud. AUGUST 30, ~1962 Conditioned Black Magic mud. Pumped 320 bbls., 83 pcf, Black Magic through annulus and 60 bbls. through tubing, using Halliburton pump truck. Well dead at 7:00 P.M. Removed X-mas tree and installed BOPE. AUGUST, 34 ~,96~, Tested BOPE with 2000~ psi - O.K. Picked up Kelly and ran to bottom with tubing. Pulled 2 7/8" tubing out of hole. 83 pcf mud ....SEPTEMBER l& 1962 Ran Schlumberger Cement Bond log 10,200' - 830'. Ran 7" casing scraper on ~ 7/8" tubing. while coming out of hole. Waited on casing scraper. 82.5 - 83 pcf mud Changed collars on 2 7/8" tubing COMPLETION REPORT SOLDOTNA CB~F~.K ~T 12-9 : rS~NDARD OIL 00'~PA~ OF"~AI~F°RNIA, "W,O~I. ' '0PERA~R Page 3- Pulled casing scraper. Changed collars on 2 7/8" tubing. Pulled casing scraper. Changed collars on 2 7/8" tubing. P~n Schlumberger Cement Bond log 10,491' - 8800'. Ran Agnew and Sweet wireline to check bottom. Pulled. Started running 2 7/8" tubing equipped with accessories for gas injection. SEPTEMBER 5,,, 196~ Ran 2 7/8" tubing to 9891'. Ran Schlumberger Depth Determination log inside 2 7/8" tubing. Log showed base of Venturi shoe at 9893.50'. Ran remainder of 2 7/8" tubing. Base of Venturi shoe on Depth log dated 9-5-62 2 7/8" tubing ran in hole after Depth log' dated 9-5-62 K. B. (Orig.) to landing head Depth Correction Depth log to I-ES Tubing landed at(I-ES dePth~ 9,893.50' 639.76' 17.20' iO,~50.46' -4. OO ' TUBING DETAIL (Based on Tally) K.B. to landing flange 2 7/8" X 6" Shaffer do-nut 2 J~ '! Pup joint, 7/0 , 6.5~, N-80, EUE, 8 R, Rg. 2 2 ~"'8" Pup joint, ~/ , 6.5~, N-80~ EUE, 8 R, Rg. 2 Pup joint 2 7/8", 6.5~, N-80~ EUE, 8 R, Rg. 2 1 joint 2 7/8", 6.5~, N-80, EUE, 8 R, Rg. 2 2 7/8" Otis "S" nipple in ~4 position 322 joints 2.7/8", 6.5~, N-80, EUE, 8 R, Rg. 2 2 7/8" Camco Sleeve Valve 1 joint 2 7/8", 6.5~, N-80, EUE, 8 R, Rg. 2 2 7/8" Brown CC Safety joint i joint 2 7/8", (as above) 2 7/8" X 7" Brown HS-16-1 packer i joint 2 7/8", (as above) 2 7/8" Otis "S" landing nipple in position i joint 2 7/8", (as above) 2 7/8" Brown Expansion joint i joint 2 7/8" (as above) 2 7/8" Brown CC safety joint 2 joints 2 7/8" (as above) 2 7/8" Camco MM M~ndrel w/C~ installed 17.20' 3.94' 8.26' 6.00' 4.00' 61.9~' ~.56' 961- 92 ' 2.18' 30.90 ' 1.04' 30.9o' 6.00' 30 · 11 ' 1.15' 31. O0 ' 3.78' 31. O0 ' 1.08' 62.2~' 13.00' 17.20' 21.14' 29.40' 35.40' 39.40' 101.34' 102.90 ' 10,064.82 ' 10,067. O0 ' 10,097.90 ' 10,098.94' ' 10,129.84 ' 10,135.84' 10,165.95' 10,167.10 ' 10,198.10 ' 10,201.88' 10, 232 · 88 ' 10,233.96' 10, 296.21' 10, 309.21' COMPLETION REPORT SOLDOTNA CREEK UNIT 12-9 STA~RO OIL COMPANY OF CALIFORNIA, W.O.I. - OPERATOR Page 4. SEPTEMBER 5, 1962 Continued I joint 2 7/8" (as above ) 30.54' 10, 2 7/8" X 7" Brown HS-16-1 packer 6.00' 10, Pup joint, 2 7/8" (as above ) 6.28' 10, 2 7/8" Otis, Type "S" landing nipple in position ~fi 1.60' 10, Pup joint, 2 7/8" (as above ) 8.10' 10, 2 7/8" Brown Expansion joint 3.78' 10, Pup joint, 2 7/8" (as above ) 8.15' 10, 2 7/8" Brown CC Safety Joint 1.10' 10, i Joint, 2 7/8" (as above ) 29.80' 10, 2 7/8" CamCo MM Mandrel w/CEV installed 13.65' 10, i joint, 2 7/8" (as above ) 30.90' 10, 2 7/8" X 7" Brown HS-16-1 packer 5-97' 10, 1 joint,. 2 7/8", (as above ) 30.90' 10, 2 7/8" Otis "S" landing nipple, position ~l 1.60' 10, 2 joints 2 7/8", (as above ) 61.68' 10, 2 7/8" Venturi Shoe .67' 10, 309.21' 339.75' 345.75' 352.03' 353.63' 361. ? 3 ' 365.51' 373.66' 3?4.56' 404.56' 455.08' 485.98' 48?. 58' 549.26 ' 549.93' Tubing Landed at (Tally Depth) lO, 549.93' Landed tubing at 10, 550'. Removed BOPE. Installed high pressure gas injection X-mas tree. SEPTEMBER 6, 1962 Tested X-mas tree with 8000~ psi for 15 min. - O.K. Displaced Black Magic mud with oil, using Halliburton pump truck. Ran Agnew & Sweet wireline and attempted to set packers. SEPTEMBER 7...&, .8.~ 1962. Attempted to set packers. SEPTEMBER 9~ 196.2.. Agnew & Sweet Wireline Service and attempted to set packers. Rig Released at 5:00 A.M., September 9, 1962. Agnew & Sweet Wireline Service set packers at 10,136', 10,340' and 10,449' after rig moved off location. S. R. HANSEN .Shall be filed mo lat,~ t~ t~ loth ~y of ,tt~e; ~r~th 3. APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK NAME OF COMPANY OR OPERATOR DATE 2tandard tit Co~ of ~llf~rn~a, ~ester~ OperatXons, Inc. Address City State ~. o. ~o~ ?-83~ Ane~~ A~s~ DESCRIPTION OF %VELL AND LEASE Name of lease 1%Vell number Elevation (R'round) Well location (give footage from section lines) ....... ~ .................... ~ection--township--rang'e or block & survey 1B65' $. & T*5' ~. of ~ ~r ~J. ~c. 9~ ~...7 ~., ~. 9 w., ~~ ~ & ~ Field & reservoir (If wildcat, so state) ] County ~~n ~r ~eld ~~ ~ ~ ~ Pe~u~ Distance, in miles, and direction from nearest town or post office Nearest distance from proposed location Distance from proposed location to nearest drilling, to property or lease line: completed or applied--for well on the same lease: fee t Proposed depth: [ Rot~try or cable tools Number of acres in lease: Approx. date work will start Number of wells on lease, including this well. completed in or drilling to this reservoir: 'REC[IVElY If lease, purchased ~vith one or more wells drilled, from whom purchased: Name Address --- JUL 10 1962 Status of bond Petroleum Brench {~JO~ iFi~I~%%~, Division of Mines and' Minerals Remarks: (If this is an application re deepen or plug back, briefly describe work to be done, giving present producing zone and expected new producing zone) CERTIFICATE: I, the undersigned, %tate that I am the ~t.e ~;~of the (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 st.,t/ed therein are t~ue, correct and complete to · // ~ · .~ // ,/. ,,,.r. , ~,,- the best of my knowledge. L/i'i:5/r/~/~/:, ~/ Permit Number: Notice: Before sending in this form be sure that you have given all information requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 (Feb. 1061) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS NOTICE OF INTENTION TO CHANGE PLANS ....................... J-~ ..... JJ SUBSEQUENT R~PORT OF SHOOTING OR NOTICE OF-INTENTION TO TEST WATER SHUT-OFF .............. / ...... II SUBSEQUENT REPORT OF ALT~RllqG GASiNG NOTICE OF INTI~rl'ION TO RE-DRILL OR REPAIR WELL ......... I .....ii $UI~EOUENT R[PORT OF Rf[-DRIt t IN~ OR REPAIR ................ / ..... l~tce ~.~_a~e~-~[~n to coa~e~ I ×ii ....................................................... ~ ..... (INDICATE ABOVE BY CHECK MARK NATUI~E OF RIDiOf~T. NO~*ICE, O~ OT~ff3q DATA) .......... ~h-,~ ........................ ~G~i~W~ ................ ~e elevation of,the d~ a~ve s~ level is ____~33 .... DETAI~ OF WORK Petroleu~..Br~ int ~nts, J~ ~i otb im~nt Con~e~ ve11 ~ ~s ~gee¢~on ~. P~ntton Equlp~nt. ~. hll tubi~ and ~ ~difiet tubi~ ~ packers ~d accessories sui~b~ for selecti~e in~ection. ]. ~~ Bio, ut P~ntion iquip~nt and ins~ll 10,~ ~.t. ~s ~e. ~. ~tu~ ~11 to p~ductlOn pen~ i~lhtio~ of ~s Injection ~ci~tie~. ! unde~ta~d tlmt thio plan o~ ~ muot roodvo &~;~ in ~fl~ ~ ~ ~~ S~ ~ ~~ ~Y ~ ~~ ~m~y .... Q~_. ~_~__ ~_~ _ _~_~ _ _~~~ ~ r .. ~_~_. ~_T~_~Z___~. L ................ ................ :____~_~-~_~.,_..~ ~.~ ................. B ............ Title _~$ ~~._~~~A~_ .... GPO 9 ! 497 4 PRODUCING DEPARTMENT TELEPHONE 4'/001 J. T. CROOKER DISTRICT SUPERINTENDENT P. O. BOX '7-839 · ANCHORAGE · ALASKA PRODUCING DEPARTMENT TELEPHONE 4760! J. T. CROOK£R DISTRICT SUPERINTENDENT :/ P. O. BOX 839 · ANCHORAGE · A LA S K A Ja~uaz~r 3, 1961' CONFIDENTIAL Mr. R. V. Murphy A2aska Oil & Gas Conservation Commission 329 Second Avenue Anchorage, Alaska Dear Sir: Enclosed, herewith, is the Completion Report for Soldotna Creek Unit Well 12-9 (4) for your information and files. Very truly yours, STANDARD 0IL COMPANY OF CALIFORNIA Western Operations, Inc. Enclosure J. T. CROOKER OIL C(~PANY OF CALIFORNIA - WES~EI~N OPEitATIONS INC. AEF~: Kenai Pe~insula, Cook Inlet Area, Alaska PROPERTY: Soldotna Creek Unit IAND OFFICE: Anchorage Lease No.: 0~8~97 ~ELL NO.: SCU 1~-9 ~ection 9, T. 7 N., R, 9 W., Seward L0~ATION: 1860' S, and 7~0' E. from NW Corner Section 9 (ProJ.) T. 7 N., R. 9 W., Seward B & M EIEVATION: 133' K.B. DA~E: December 5, 1960 D~ILLED BY: Coastal Drilling Company DA~E COMMENGED DP~,T:TNG: August 16, 1960 DATE COMPI~ DRILLING: October 9, 1960 DA~E OF INI~ PRODUCTION: Shut in pending installation of Production facilities. SUMMARY TO~L I~: 10,785' PLUGS: 10,785 - 10,700' CASING: 20" Conductor cemented at ~7' 1st Stage around shoe 13 3/8" Casing cemauted at 2998' in 2 Stages: with 600 sacks 2nd Stage through DV at 1488 with 1000 sacks 7" Casing cemented at 10,785' in 2 Stages: 1st Stage around shoe ~ with 750 sacks 2nd Stage through DV at 8504' with 750 sacks 19:8.'i PERFOPATION EECORB$: 1. 5 - ~et holes 10,165 - 10,166' 5 - "' Jet holes .10,557 - 10,558' ~ - "' Jet holes/ft. 10,5~ - 10,546' 10' 41 shots 4. ~- ." Jet holes~. 10,5~- 10,526' 10' $1 s~ts ~- ." ~et holes~. 10,520- 10,~' ~' 241 Shots 6. 4- Jet ho~s~. 10,~1- 10,~5' 16' 65 shots 7. 4- ." ~et holes~ft. 10,421- ~,~' 13' 53 shots 8. 4- ." Jet ~les~. 10,~3- 10,3~' 59' 2~ shots 9. 4- ." Jet ~les~. 10,3~- 10~5' 57' 229 shots 10. 4- ." Jet holes~. ~,255- 10,2~' 11' 45 shots 11. 4- "Jet ~les/~. 10,2~- 10,~3' 55' 221 shots WELL SURVEYS: 1. Schlumberger I-ES Log interval 2977 - 63' 2. Schlumberger Sonic Log interval 2977 - 63' 3. Schlumberger I-ES Log interval 10,787 - 2998' 4. Schlumberger Sonic Log interval 10~785 - 2998' 5- Schlumberger Micro Log interval 10,787 - 2998' 6. Schlumberger Neutron Log interval 10,696 - 7000' 7. Baroid Mad Log interval ~000 - 10,785' DRILL S~ ~EST~: 1. HOT WSO on parr' d. interval 10,165 - 10,166' WSO 2. HOT WSO on perf'd. ~nterval 10,557 - 10,558' WSO 3. HOT Prod. Test perf'd, interval 10,5~6 - 10,546' 00MPLETION REPORT SOLDOTNA ¢~ UNIT 12-9 Section 9, T. Page 3. Spudded at 3:~0 PM, August 16, 1960. Drilled 12~" hole ~7 - 38' 1' drilled Circulation broke out in cellar. cement, 3 sacks sand, treated with calciu~ chloride. Drilled 12~" hole ~8 - 2,051' AUgust !8,. 1960 Drilled 12~" hole. Cemented with l0 sacks of construction Cement in place at 10:~0 PM. 013' drilled 2,051 - 3, 000' 949' drilled Ran Schlumberger I-ES and Sonic Logs interval 2977 - 63'. Opened 12~" hole to 17}" hole 37 - 210' 173' 6u ~ust !9,. 1960 210 - 2, 373' 2,163' opened 2, 373 - 3,000' 627' opened 2ondJ. tioned mud. Ran 13 3/8" casing 70 p cf mud 80 pcf mad 80 p cf mud 84 pcf mud 83 pcf mad Cemented 13 3/8" casing at 2998' in 2 stages with 1600 sacks of construction cement treated with O. 3% HR-~ retarder, using ~lliburton power equipment. Used 1 top szEI 1 b~tom rubber plug. SOLDOTNA ¢~EE~ UNIT 12-9 Section 9. T.. 7. N.,_..R. 9.. W.,. Se ~wa~rd B .&...M Page First.....Stage around shoe with 6OO sacks. Pumped ~0 bbls. of water ahead, mixed ~ Sacks of cement in 35 rains, using Halliburton truck, displaced in 30 rains. using rig pumps. Average slurry weight 1175 pcf. Circulation broke out in cellar. Good circulation. ~econd s~ge through D~ collar at 1488' with 1OOO sacks. Pumped ~0 bbls. of ~a~e'r:ahead, mixed 10OO sacks of cement in 55 mins. using Halliburton truck, displaced in 20 mina. using rig pumps. Average slurry weight 117~ pcf. 2000 psi final pressure. Good circulation and cement returns. Ail 74 Joi~ts or 2980' Ail 74 Joints or 2980' Below KB - 18' z3 3/8" & tm OW ; quipped with Baker float shoe, Baker flexiflow float collar at 2956', and Halliburton DV collar at 1509'. Centralizers at 2956 and 1~67'. at 2998' Installed casing head, tested with 2000 psi. Installed BOPE, tested to 15OO psi. OK. Drilled out DV collar~ tested with 2000 psi for 15 rains. OX. Cleaned out cement 2906-30OO'. Drilled 12~" hole 3, O00 - 3,~B6' 5~6' drilled logging equipment commenced operations. 81 pcf mud A..Ugust .2.~..,.....September D~illed 9 7/8" hole 3,536 - 10,037' 6,501' drilled Changed to lime base mud at 6~OO' on 8-27-60. 80 - 100 pcf mud Drilled 9 7/8" 10, O~7 ' 10, O84' 47 ' drilled so~ ¢~EEX UNI~ 12-9 Section ~ T. 7 N., R. 9 W., Seward Page 5. ~ptembeE 21 - 22, 1960 0ored 7 5/8" hole 10,~ - 10,109' 25' Cored 25' Recovered c0~ ~OP 5' Next 4'- Next 4' Next 3' Next 7' Next 10" Bottom Siltstone light gray V KD Mic Num Oarb. Incl. few V thin coal lams SS M Gry ~G SA well cern. firm It. tn. Stn. even Yel. gold Flsnt Mild Pet. odor Strks. Dk. Gry. Sltstn. bleeding apots oil upon STDG Mic poor sort. SS as above with Stks. CG SS As above Blms. Pred. MG. SS as above poss. more Perm. SS S & P MG Calc. Ti NO SF SS as a~ove poss. more Perm. Opened 7 5/8" hole to 9 7/8" hole 25' opened hole 10,109 - 10,207' 98' drilled 99.5 pcf mud 10,207 - 10,252' drilled Cored 7 5/8" hole 10,252 - 10,262' t0' cored 10' Recovered ext 2 Bottom Oil stained sand V fine grain, clayey, silty Mic. 0arb. Good Pet. odor Golden Flsnt. Ory. Lime cemented SS ~ine Gr. Mass. salt & pe~per Mic Car~. Stks. lime cemented. Drk. Gry. Silty locally sandy. Siltstone with common Carb. & Mlc. larvae. hole to 9 7/8" 10,252 - 10,262' 10' opened CC~PLETION ~EPORT SOLDOTNA CREEX U~IT Section 9.. T- _7_ N_..., R, .9. ~~"Oz~ co,~ OF'~FO~, W'O:~. Page 6. 10,262- 10,281' 19' drilled Cored 7 5/8" hole CO~ ~ 10,281 - 10,~1' ~c0~ 20 ' cored 20' Recovered 99.5 - 100 pcf mad Top 7' Next 3' Next ~' Next 1' Next 6" Next 2~' Bottom 3' SS M Gry. FG SA Firm well sort Mic. even Lt.. Bm. STN ~ld-Yel. Flsnt. mild Pet. odor Mic ely. I~lams. $S AA Blms. MG SS M Gry. MG-CG CG~ crumbly Chert Pebs to ~" dia. even oil Stn. ~old Flsnt. SS AA BOMS CG SS M. Gry. FG even oil Stn. SL Fri. not broken. SS AA BOMB CG CGL ~ Gry. Peb~. to ~" dia. Matrix SS ~G V Calc. Pred. T1 Tn. oil Stn. dull ~old Flsnt. O~ened 7 5/e" hole ~ 9 ?/e" ~le 10,281 - 10, ~O1' 20' opened 10, ~01 - 10,~10' 109' drilled LOS~ circulation at 10,~06'. Drilled ahead to 10, ~10'. Pulled out. Ran back with 240' of ~" aluminum tubing en ~" IS. Hung tubing at 10,~0~', mixed and pumped in 100 sacks of construction cement treated with HR-~ retarder. Circulated in stages to top of cement. Drilled out cement to Bottom. 99 pcf mud Located top of cement at 10,228'. Drilled 9 7/8" ~ole 10,~10 - 10,~97' 87' drilled 97 per mud COMPLETION ~ORT SOLDOTNA C~ U~IT 12-9 Section 9__T? ?.N., R. ~..W.~ Seward .B & M Page 7. 98.5 - 99 pcf ma Drilled 9 7/8" hole 10,721 - 10,785' 64' drilled Ran Schlumberger LES and Micro log interval 10,787 - 2998', Sonic log interval 10,785 - 2998'. M~d logging equipment released. 99 pcf mud S .eptember 30, Circulated and conditioned mad. Laid down drill pipe. 99 pcf mud Ran 7" casing. oe~.n..ted 7,' casing at~j!0.~..7...8..5' in two stages with 1500 sacks of construction Cement treated' with-O; 3~' ~'~ retarder, using Ealliburton power equipment. Used one top and one bottom rubber plug. Fil___rs._t .Stage. with 750 sacks around shoe. Pumped 40 bbls. of water ahead, mixed 750 s~ck-s-in 40 rains, using Hallib~on truck, displaced in ~5 rains, with rig pumps. Average slurry weight 1175 pcf. 600 . 1000 psi working preas. 2000 psi final press. Full circulation. se_cond stage through DV collar at 850~' with 750 sacks. Pumped 20 bbls. of ~ter ah~a(1,' mixe~ 750 sacks in ~5 rains, using Halliburton truck, dis~lace~ in 27 rains. With rig pum~s. Avere~e' slurry weight 117~ pcf. 500 - 800 psi working pressure. 2000 Psi final pressure. Full circulation. Casing. _Detail Top 6 Joints or 260.35' 7", 29~ B.T. N-80 Next 23 Joints or 929.15' 7",26~ B.T. N-80 Next 89 Joints or ~619.62' 7", 2~ B.T. N-80 Next 22 Joints or 957-98' 7",~ B.T. N-80 Next 3~ Joints or 1481.~3' 7", B.T. N-80 Next 1 Joint or 4.75' 7", 295 8 R to BT N-80 X-over Next 1 Joint or ~1.76' 7",29~ 8 R N-80 Next 50 Joints or 2030.48' 7", 26~ 8 R P 110 Bottom ~6 Joints or 1~70. B9' 7", 29~ 8 R P 110 All 262 Joints or 10795.71' Above K.B. ...... 1077!' Landed at 10785.00'. 00MPLETION ~EPORT SOLDOT~A 0REEE UNIT 12-9 Secti.,o,n '9 ,,7 9 Seward Page 8. Equipped with 7.55 ' pup marker ~7~.1~' to 9981.72'. DY collar at 8504.5~' with 1 centralizer above and 1 Below. Centralizers on first 19 Joints. Scratchers in intervals: 10, 545 - lO, 4~0 - 10, 315 - 10,250 - 10,190 - 10,145 - Picked up 2 7/8" D.P. psi for 15 rains., OK. Drilled out DV collar at 850~'. Tested DV with ~000 Drilled out baffle plate 10,698 - 10,700'. 95- 5 pcf mud Ran Schlumberger Neutron-Collar log 10,696 - 7000'. Ran Schlumberger jet gun I · -- 111 ........ . ................................ _ _ and Perf d ~ ~ holes 10,165 - 10,166". :~ WSO on ~ ~" holes 10,165 - 10,16~'. Used ~1' W.C. Tool assemble~ as follows:-:'-~2 outside ~T rec0r~ers, 5 perf's., Junk catcher, hook wall packer, VR safety Joint, h~ulic Jars, 2 outside BT recorders, hy&rosping tester, and dual shutin valve. Set packer at 10,125', tail to 10,145' at 1.'.14 AM. Opened tool at 1:17 AM. Slight puff. Shut tool in at 1:18 AM for 34 min. ISI pressure. Opened tool to surface at 1:53 AM for one hr. BO min. flow test. Very slight blow of air decreasing to dead e~er 25 rains. Dea~ for balance of test. Closed tool at 2:53 AM for ~1 minute FSI pressure. Recovered 50' rat hole drilling m~d. Charts indicate tester o~en. PEESSU~E DA~A: IH ISI IF FY FSI FE Top inSide BT Bottom Inside BT Top Outside BT Bottom Outside BT 6734 ~ 586 1399 1394 l ~o 6685 6707 1568 138~ 1375 1421 668a 6892 1668 11;82 148a 152o 6799 6835 162o 11~37 1437 11+75 6735 OK. ' 96.5 pcf mad Ran Schlumberger Jet gun and perf'd. 5 ~" holes 10,557 - 10,5~8'. Conditioned ¢OMPLE~ION REPOR~ SO~ C~EEX U~I~ 12-R Seetiom R ~.. 7 N~..,.. R.. 9 .~:, seward S~~D OIL CO, OF CALIFORNIA, W.O~I' Page Ran ~0 ~. HCT.on.. ~. ~" .holes...~O,.~57 -. !O, 5~8_'. Tools assembled as before. Used 2991' W.O.~' 'Set packerat iO, 5i~",- tail-to 10,5~6' at 3:27 PM. Opened tool at 3:~0 PM. Sh~t dual shutin valve for ~1 min. ISI pressure. Opened tool to surface at %:O1 PM for one hr. flow period. No blow. Dead for entire test. ~hut in at 5:O1 PM for ~0 min. FBI pressure. Pulled packer loose at 5:31 PM. Recovered net rise ~O' mmddy water. Charts indicate tester PEESSUEE ~A~A: IH ISi IF FF 'FSI X ide 1 86 13 7 1336 1 35 6972 Bottom Inside BT 7021 1566 1324 1324 1412 7000 Top Outside BT BT 7114 1599 1360 1360 1~1 7068 Bottom Outside 7071 1562 13~6 13~6 lb2~ 6926 Oc.tob.er ~,_.. 1960 Ran Schlumberger Jet gun and perf'd. 4 }" holes per ft. interval 10,5~6 - 10,546'. EFT ~!..o~inte~.lO, 5~6 - 10,5~.46~'. Tool assembled as before. set packer at'10'487" tail to lO, 5O7'. Opened tool at 2:48 PM. Strong blow of air to surface. Closed dual shut in valve mt 2:51 PM for ~5 min. ISI pressure. Opened tool to surface at 3:36 PM for 6 hours 59 min. flow test. Immediate strong blow of air. W.C. to surface at 4:02 (or in 26 rains. ). 600 psi tubing pressure. ~" surface bean. Oil to surface at ~:18 PM (or in 42 rains. ). Tubing pressure 1000 psi increasing to 1600 psi flowing. Changed to 20/6b" bean at 4:~0 PM. Well cleaned up. Took first sample at 5:15 PM. Tool open 6 hours 59 rains. Closed tool at 10:35 PM for 57 min. FSI pressure, and baekscuttled. pulled packer loose at 11:32 PM. Charts indicate partial plugging. Surface Bean waxed up intermittently. Test conclusive. Flowed oil at estimated 2000 B/D, ~6° gravity, O.2~ total cut, 0% water, 0.2~ emulsion; 0% sand and mud. DATA IH ISI IF FF FSI FH Top Inside BT Bottom Inside BT Top Outside BT Bottom Outside BT Clock broke when tool opened. 6864 5545 2713 5057 5543 6856 6907 5550 2701 5040 55~1 68~7 96 p cf mud Conditioned mud. Ran Schlumberger Jet gan and perf'd. 4 ~" holes per foot. (for production) over following intervals: COMPLET'£ON ~ I:~PORT SOL~OTNA Section 10,520- 10,460' 10,~l- 10,$25' lO, 4~1- 10,403 - 10, 344' 10,25~ - 10,2~' 10,2~- 10,~3' Ran ~8 Joints plus a 2' pup Joint of 2 7/8" tubing. 95 pcf m~d Landed tubing at 10,457' 9~ pcf mad Removed BOPE. Installed X_m~s tree. Started .displacing oil down tubing at 10.05 PM 10/8/60. Casing oil to surface at 1.~0 AM lO,R/60. Stopped circulating at 1:55 AM. 0pe~ed tubing at 1:55 AM. Tur~e~ d oil to trap at 2:~0 AM. Stabil- ized one hour flow rate with 16/64" beau, 1800 B/D oil, 1600 psi tubing pressure. 1200 psi casi~ng pressure 710 MCF/D gas. Stmbilized ~ hour flow rate with 8/64", 1000 B/D oil, 1800 psi tubing pressure, 1~)0 psi casing pres~sure, 400 ~CF/D gas. Stabili.zed cut 3.~,.0.2~ water, 3.~ emulsion. ~7.6~ gravity. Shut well in at 5.55 AM. At 6.40 AM (~5 min. shutin p_r~,ssure) casing pressure 1~50 psi, tubing pressure 1980 psi. Flowed total of 266 bbls. to tank. Installed Cosasco. Cleaned out mad tanks. 6~5o' 6603 ' 6889' 7a6o' 7556' 7950' 9693' 2° -15' o° -50' 0° -30' 0° - 0° - 0° - 10' 0° - 0o . 1°- 30' l°- ~5' 2°- p_o . 4.5' Z°.~, 1°- O' 2°- 30' 2°- 1°- 15' 1°- O' .. UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No. Approval expires 12-31-60. LAND OFFICE __~Q~ge .............. LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a eorree~ report of operatior~s arid prod~ctior~ (inch~din~ drillinff and produein~ wells) for t~e mo~t~ of .... ~~.~r ...................... , Ig..~_Q, ~~ P~o .. .................. 3S~'. ~6~. ............... ~ ........................... J~e~t's title~a~ ~ Or ~ t ' I I NO. I Pao~uoa. i - · I [ txn ~nou~n~) I ~ECOVERgD I I)02~/ date ~d r~ult of ~$ for g~ol~e s~ ~~ed ~ ~/8 ho~ 7,~ - XO,~. Co~ ? 5/8 So~ ~0,0~ - ~ XO,~'.t ~ma 715/8" hoXe ~ 9 7/8" ho~e [~,~; [0,~'. -- ~~'97/8" ~4 XO,~. - ZO,eS~'.,, Co~d. ? 5/8" ao~e ~o,~se, - 10,E62'.; ~d 7 ~5/8".~ole ~ 9 7/8 ~le 10,252 - 10,~2 . m-~ma 9~7/8" ~,~fo,~ - ~o, eSx,. co~ 7 ~/8" ~e ~0,28~ - ~( ~[.~-~d7~5/8 ~oXe ~97/8 ho~ ~0,~ ~0,~. i~ 1~ ea~ ce~t. b~ed out c~nt 10,2~ - 10,~10'. .Xed 9 7/8" hoXe 10,~0 - 10,78~' T.D. Rs~ :lES, recto, Sonic oreF LutervaX .lO,?b~'j - 2998'. Eo ~8~yster (3) ~tijn RECFJWO ODT ~ Now,~..--Thcre were ...................................... runs or sales of oil; .............................................. M cu, ft. of gas sold; ............................................. runs' or sal~s' of gasoline during the month. (Write "no" where applicable.) No~.--Report on ~his form is required for each calend~r month, regardless of the status.of operatiurs, and mus~ be filed i~ duplica~ with the supervisor by ~he 6th of ~he succeeding month, unless otherwise directed by ~hc supervisor. (January 1950) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS 9 State ........ __A_~.__~.~.__ ............. Oou~ty _K._e_ .ri_a___ _1:.. _ P_ eni ns ula ..... Fi, eld ....... __S... _vans°ri. _.River The followin~= is a correct report of operations and production (incl~din~ drillin~ and produ, cin~ wells) for the mor~th of ........ October ........ A060_ ....... ~_Oll Ri~rer , S RD 0 L CO OF FORNIA ................................ A~cl:t.o__r~_g., Ala,ka .................... Si_~r~e~, _. ....... _ .'~2~t~,~~..~_ ' ~'r-'~"~. . PAone ..................... t~R_ 7_,620__1_ .................... ,--_; .................!m:,,t s iit/,, ~=~r'letBu, erlntendent'Alazka ~7~ 9~ soo ~-9 (~) Cemen~d 7" casi~ at 10,785'. Ins~lled ~E and tested to ~500 psio R~ neutron log 10,696 - 7~0'. Es~bllsh~d ~O's at 10,165' ~ at 10,557', ~0 Jet perf'do hole~ per ~to 10,536 - 10,5~'. F~d oil a~ est, 2000 B/D ~6.2~ ~ty. jet perf'd, follo~ng in%e~ls. lo, 536- lo,526' 10,520., 10,1~60' 10,1~1-, lO,kal - 10,1<~8' lO,kOB - 10,310,' lo,332- ~o,275' 10~255 - 10,24&' 10~238- 10,183~ Landed 2 7/8" tubing mt Dls~lace~ mud with ~il. '10,1t57'o I~Stalled christmas tree. Flowed oil 1800 B/i~ 16/64" bean. { U.S.G.S. -M. Ho Soyster (3) oil on,; - c. wi- M. Lo Hi,Il W. Co BlZh~ R. J. ~sbeek ~le ~lo~tion , P~duclng { i Nori~.--There were ...................................... runs or ,.<ales of oil; ............................................ M cq. ft. of :.;as sold; ................................................ runs o? shies et' g.q._~:oline d,:rin~ Nor~.--E. eport on this form is rcq~iir0d for each duplicate with tho supervisor }~y t, he 6.th of the s;uccec,li,:g ~;,,oni 5. unlc.,? o~ ~'~:rwiso d~rect:-~l ~,v '1 ..... '.~;.. r :i :~:'. (January 1950) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Budget Bureau No..J2-RJ56.5. Approval expires 12-31-~. LAND OFFICE _....~3~. ~h..Q_.?age U,,T ....... So~~. C~ek LESSEE'S MONTHLY REPORT OF OPERATIONS State ...A].~}i~t .................. County j~e...I~..~._pOL~_~..]~_. ..... ~ield __.~9~__~Yq~ ...................................... The followi~ lsa correct report of opcration, s a~d prod~ctio~ (g~ch~di~ drillf~ a~d prod~cg~ wells) for the mo~th of .............. AU~ ............ 19__~_ ...... , S~~ O~~~ ~~,_ .A~ ~ho~e .................. .~__7~ ...... __ .............. .i~cT, t ~' t~t~~ s~ ~ spuaaea at 3:30 PM ,S-16-~. 22" ~n~ctor ove~ xnte~ ~78~ ~ 63'o ~e~a ~" ~o c~en~a ~3 3/8" ~s~a~ 2~'o ~ns~ea ~ ~ ~zt~ ~ 15~ psi. D~lled cc- UoSiu. , M. ff. ~Fs~r (3) A~ o a o c ~ - a, v. ~~ ~~eld Oil :o~.'- C. W. , M. L. ~ . I R. J. ~sb~k ~le: ~lom ion ' ' r~duc~ NoTE,--There were .......................: runs or sales of oil; ............... - ................................ M cu. ft. of gas sold; ................................................ runs or sales of gasoline during the month. (Write "no" where applicable.) NoTt, L 'Report on this form is required for each calendar month, regardless of the si:al, us of nperations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise dircctcd L,v the s~pervisor. (January Igf~) "' ~t": ;"[' ' ." .~ _ . -'+~ ' , .,~. .... . ~ :~. ~..o. 1~8~7 .... ~::'. .... !----4~--I ...... ~ ...... UNITED STATES I-~ ~--:.--~-.. L-:-- D~ARTMENT;~F-THE INTERIOR : I : GEO~ICAL SURVEY ' su %v notices NOT~:OF INTENTION TO DRILL ....................... ': .... ~ 8U~ou~. RE~R~ OF WATER SHUTOFF .............. 1 .... ~tC~ OF.I~TENTIO~ TO CHANGE PLANS ._~:_ ........... ~BS~QUENT-'~T OF $~OTING OR ACLDIZING ............. ~TICE ~,I~ENTION 'TO TEST W~TER SHUT-O[F-; ' ._~ '_ .... SU~FQU~ REP~ OF ALTERING CASING ....... N~ICE OF INTENTION TO ~E-D~ILL ~ aEP~'~LL ........ I _ ' SU~B~ODE~ RE~RT OF RE-DRILLING OR REPAIR ' ~ SUaSEOUE~ REtoRT OF A~NO~MEN~ NOTICE OF IN~NTION TO PU~ OR ~TER CAS~G ............... :~. SUPPLEMENTARY WE~ HIDTORY .............................. ... ' ~rN~ATE ABOVE BY CH~ ~K NATUR~OF E~, NOTICE, OR OTHER - 'Well No.~U ....... I2'9 b }~ated 1~. ~: ,rom. '[NJl= line and'' _ ,_8~.... ft. from {~, line oi sec ......... i ..... ....... ~ ....... (Twp.) ..... (~e) ... , - -' (Meriflion) ...... . '~on~ty-or Sub Iix'isM ) ' (Sl~ or T~i~ry} ~ '-' ' " [.B. ' ' ~"' .": The elevati°n'Of the ~ above sea level ~.._~0 ' U[T 'OV wor ~:~inta, and all other impar~-t 'pr~os~ work}(... :~ ~efer to at~e~ ~~ ' ,. _ . ~ ~ '~s . ~mpan~ .... ~ .~.._O~ ~_O~.~~.~mm.:~a~s, ~O, ............... "; GPO 8 6?040 PROPOSAL FOR WELL OPERATIONS PRO 316-1 DRILLING PROGRAM FIELD: Soldotna Creek Unit PROPERTY AND WELL NO.-12-9 LOCATION: Surface Location: Approximately 800' easterly along N line and 1800' southerly at right angle from NW corner projected Section 9, T7N, Rgb, Seward B&M. BOWOUT PREVENTION EQUIPMENT: Class III OBJECTIVE SAND': Hemlock Zone WELL CORRELATIONS: K.B. elevation approximately 130'. Marker _ _ Estimated Sub-sea Depth Estimated Drilled Depth E point 6,700' 6,830' Top Hemlock Zone (H-A) 10,290' 10,420' Total Depth 10,990' 11,120 ' PROGRAM 1o Cement 20" I.D. conductor pipe 5-10' below cellar floor. 2. Drill 12~" hole to 3000' and run Induction Electrical Log and Sonic Log. ao Install mud logging unit at 500' and log as directed by engineer. · bo Obtain ~ gallon sample of drilling fluid prior to pulling out for logging run. c. Potential scales 0-100 millivoltso Resistivity scale 0-50 ohmmeters. d. Utilize lime base high PH mud as per drilling fluid program. 3o Open hole to 18 5/8" and cement 13 3/8" casing in selected sand near bot- tom as designated by engineer. Use guide shoe with Baker flexiflow fillup collar one joint above. Cement in two stages with Halliburton DV collar at 1500'+- with sufficient construction cement to fill to surface. (Esti- mate 750 sacks per stage.) 4. Install and test Olass III blowout prevention equipment. Test to 1500 psi with clear water for 15 minutes to be witnessed by Drilling Foreman. 5. Drill full hole for 7" casing to a point equivalent to 10,230' in well SCU 14-4 (estimated drilled depth of 10,300' ). a. Drill 10 5/8" hole as directed. b. Maintain sufficient mud weight to overbalance gas entry as required (at least 95 pcf below E Horimon.) August 10, 1960 c. Maintain viscosity 40-60 seconds API as directed. d. Maintain water loss of § ml or less below 6000' and 5 ml or less below ?500'. 6o Run Induction Electrical Log. a. Obtain ½ gallon sample mud prior to 'pulling for log run. b. Use same scales as in Run #1. 7. On basis of correlation obtain 30' core within interval equivalent to 10,200' to 10,280, in well SCU "14-4. 8o On basis of correlation drill ahead-to penetrate "I" E log point. Obtain 30' spot core within H2 to ~ interval° 9. Run Induction Electrical Log, Microlog-Caliper, Sonic Log and continuous dipmeter surveys as directed by engineer. Limit CDM survey to intervals ef interest and avoid logging long washed out interVals. 10. Condition hole and lay down drill pipe. 11. Run 7" casing to below all indicated productive intervals. Casing to be equipped with centralizers and scratchers as necessary to insure effective cement bond where critical. Install Halliburton DV collar below possible gas sands (8500,-+). Casing to be equipped with float shoe and float collar two joints above. 12. Cement casing in two stages. 600 .sacks of retarder treated cement around shoe .and 600 sacks retarder .treated Cement through DV collar, 13. After 16 hours land casing according to standard practice and reinstall Class III blowout prevention equipment and test to 1000 psi with clear water. 14. Make up 2 7/8" drill pipe and cIean out as required and run Neutron- Colla~ log as directed by engineer. Limit log run to interval from top of cement above shoe to 9000'° 15. Establish WSO's as directed by engineer. Obtain. initial shut in and final shut in pressures. 16. Selectively Jet perforate attractive sands as designated by engineer. 17. Run 2~ tubing and complete as directed: t ? APPLICATION FOR PERMIT TO DRILL, DEEPEN O~ PLUG BACK APPLICATION TO DIIILL~] DEEPEN [] PLUG BACK [] NAME OF COMPANY OR OPERATOR DATE ~~£il C~i~ny_.o£ Cal2fornia: %~stern O~3erations; Inc. Address City State DESCRIPTION OF WELL AND LEASE Name of lease F~ ~. A~O~ f,j.S. I:'ublic Domain ]w~n.number Elevation (~round) %Veil location (give footage from section lines) Section~township--rana'e or block & survey Fh)ld & reservoir (If wildcat, so state) County Distance, in miles, and direction from nearest town or post office Nearest distance from proposed location Distance from proposed location to nearest drilling, to property or lease line: completed or applied--for well on the same lease: Appr~,.... ~.0.~_ ....................... feet ...... Ap'¢r~, 2450 ~ Proposed depth'. ~ Rotary or cmble tool~ 11:120 ' [ H.o%~ Number of acres in lease: If lease, purchased with one or more wells drilled, from whom purchased: feet IAI)prox. date work will stare Number of wells on lease, including this well, completed in or drilling to this reservoir: 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 nemv producing zorle) Fr,oducini,~:;, ,~,.,n~.,~pt.m ~ S.O, Go.of CaL CERTIFICATE: I, the undersigned, state that I am th~)q ~.- ,qlr~'~._ of the ~o.~.~J,l~ ['!¢~a _ ~ ~l~ · (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein are true, c~rrect and complete to Al'2Xoved .......... .~. ................. CQr"i,:%'i~',~'~ ~i,'~ :v~:;c~ the best of my ~owledge.A ~'~- "~........ '' ; T~ ~ ~:j Petroleum Oeolooist Signature ............. ~., Pct ~ _= District ,$a'~rinteadeni~,~$~t Permit Number: Approval Date: Approved By: Division of Mines and Minerals Resources Notice: Before sending in this form be sure that you have given all information requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. Authorized by Order No. 1 Effective October 1, 1958 R£C£1VE AUG I Oil a Gas Section Division of Mines and Minerals ~Alaska Dept. of blatuxal Resouxces Peno W~EW: lo copies Bec: C. W. ?er~~, :~tlchfteld 0ii Compor~tion J. E. Tous~ain-~ -