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Home My WebLink About181-023Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240107 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # END 2-72 50029237810000 224016 11/16/2024 HALLIBURTON TEMP END 2-74 50029237850000 224024 12/5/2024 HALLIBURTON MFC24 END 2-74 50029237850000 224024 8/13/2024 DarkVision HADES (Down hole camera) KGSF 1A 50133101600100 220063 12/5/2024 HALLIBURTON EPX-MFC40 MPU F-13 50029225490000 195027 12/22/2024 HALLIBURTON WFL-TMD3D PU F-40 50029222150000 191117 11/9/2024 READ CaliperSurvey MPU I-04A 50029220680100 201092 11/22/2024 HALLIBURTON COILFLAG MPU J-02 50029220710000 190096 12/22/2024 READ CaliperSurvey PBU L-04 50029233190000 206120 11/23/2024 HALLIBURTON WFL-TMD3D PBU L-221 50029233850000 208031 12/11/2024 HALLIBURTON WFL-RMT3D PBU Z-ϯϰ 50029234690000 212061 12/15/2024 HALLIBURTON WFL-RMT3D PBU Z-2ϯϱ 50029237600000 223055 9/24/2024 READ InjectionProfile PBU Z-ϮϮϯ 50029237200000 222080 11/24/2024 HALLIBURTON WFL-TMD3D SCU 42-05Y 50133205700000 207082 12/7/2024 HALLIBURTON EPX-MFC24 TBU D-16RD 50733201830100 180110 12/19/2024 READ CaliperSurvey TBU D-17RD 50733201680100 181023 12/21/2024 READ CaliperSurvey Please include current contact information if different from above. T39915 T39916 T39916 T39917 T39918 T39919 T39920 T39921 T39922 T39923 T39924 T39925 T39926 T39927 T39928 T39929TBU D-17RD 50733201680100 181023 12/21/2024 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.07 15:26:55 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Ran Kill String Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,800 feet N/A feet true vertical 10,078 feet See schematic feet Effective Depth measured 10,121 feet See schematic feet true vertical 9,444 feet See schematic feet Perforation depth Measured depth 9,595 - 10,490 feet True Vertical depth 8,952 - 9,788 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6 2,606 (MD) 2,503 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Middle Kenai G Oil & Hemlock Oil 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3,090psi 7,020psi 3,090psi 5,750psi 8,160psi 2,497 2,404 Burst Collapse 1,540psi measured TVD Liner Liner 8,145 2,951 1,560 Casing Structural 7,579 10,077 4-1/2" 8,145 10,800 9,440 8,808 2,497 Conductor Surface Production 13-3/8" 9-5/8" 8,430psi 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 181-023 50-733-20168-01-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018729 McArthur River / Middle Kenai G Oil & Hemlock Oil Trading Bay Unit D-17RD Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 9,596 - 10,120 456 Size 0 00 0 10894 0 324-329 Sr Pet Eng: 7,500psi Sr Pet Geo: Sr Res Eng: WINJ WAG 35 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Rupert Ryan.Rupert@hilcorp.com 907 777-8503Operations Manager 65.5 BBL OilSafe AR / 1100 psi. Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:55 pm, Nov 01, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.11.01 11:48:18 - 08'00' Dan Marlowe (1267) _____________________________________________________________________________________ Updated by: JLL 10/15/24 SCHEMATIC McArthur River Field, TBU Well: D-17RD Last Completed: 09/23/24 PTD: 181-023 API: 50-733-20168-01 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8 61 K-55 Butt. LT&C 12.515 Surf 2,497 9-5/8 40 N-80 Butt 8.835 Surf 4011 43.5 N-80 Butt 8.755 4011 5498 47 N-80 Butt 8.681 5498 7025 47 S-95 8rd 8.681 7025 8145 7 32 N-80 Butt 6.094 7,849 7884 29 N-80 Butt 6.184 7884 9523 32 N-80 Butt 6.094 9523 10,800 4-1/2 12.6 L-80 Hydril 503 3.958 7,880 9,440 TUBING DETAIL 4-1/2" 12.6 3.958 Surf 2,606' FISH/FILL INFO FILL: Tagged w/ a 2.65 GR on 9/25/96 @ 10,122 WLM FISH: OM-1 Arm & (3) Springs 4/8/95 10,126 WLM 17 Strip Gun 8/23/90 10,533 WLM 22 Strip Gun 6/29/92 10,538 WLM RKB to TBG Head = 41.05 TD = 10,800 PBTD = 10,676 Tree Connection: 4-1/6, 5,000# 1 1 9-5/8 Tagged Fill 10,121 MD 2/25/14 Casing Damage 9320-9340 3 4 2 13-3/8 HK-1 Max Angle=27°, KOP @ 600 HK-3 HK-4 HK-5 G-2 G-3 G-4 G-5 G-6 HK-2 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Perf Date G-2 9,596' 9,628' 8,952' 8,982' 32' 6 02/27/14 G-3 9,658' 9,673' 9,010' 9,024' 15' 6 02/27/14 G-4 9,701' 9,735' 9,050' 9,082' 34' 6 02/27/14 G-4 9,794' 9,798' 9,137' 9,141' 4' 6 02/27/14 G-5 9,854' 9,859' 9,193' 9,198' 5' 6 02/27/14 G-5 9,882' 9,890' 9,219' 9,227' 8' 6 02/27/14 G-5 9,924' 9,935' 9,259' 9,269' 11' 6 02/27/14 G-6 9,965' 9,969' 9,297' 9,301' 4' 6 02/27/14 HK-1 10,052' 10,081' 9,378' 9,405' 29 36 11/21/1992 HK-2 10,096' 10,120' 9,419' 9,442' 24 18 7/27/1992 HK-2 10,178' 10,192' 9,496' 9,509' 14 4 2/2/1987 HK-3 10,214' 10,232' 9,530' 9,547' 18 12 11/29/1992 HK-4 10,260' 10,292' 9,573' 9,603' 32 8 1/30/1987 HK-4 10,330' 10,380' 9,638' 9,685' 50 28 11/29/1992 HK-5 10,405' 10,490' 9,709' 9,788' 85 20 12/3/1992 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 7,872 7,316 4.00 7 26-32# Hydraulic Permanent Packer 2 7,880 7,324 3.958 4.5 12.6# Hydril 503 3 9,421 8,790 3.958 Swell Packer 4 9,440 8,807 4.000 Wireline Re-entry Guide CEMENT DETAILS 13-3/8"17-1/2 Hole: Cemented with 2000sxs 14.8ppg class G. had cement returns to surface. ToC at Surface. 9-5/8 12-1/4 Hole: Cemented with 1667sxs of class G cement. (no cement back to surface when opened DV tool). 5/14/81 VDL showed Cement back to at least 8000 MD (didnt log above there). 2nd Stage: Pumped 1780sxs class G cement through DV at DV collar at 6655 MD. (no cement back to surface)5/14/81 VDL shows ToC at 2070 MD. 78.5 Hole: Cemented with 900sxs class G cement. 80 sxs reversed out from off liner top. 6/12/81 VDL confirms ToC at ToL. Well Name:MRF D-17RD API #:50733201680100 Field:McArthur River Field Start Date:6/15/2024 Permit #:181023 Sundry #:324-329 End Date:10/3/2024 6/15/2024 6/16/2024 7/14/2024 7/27/2024 9/6/2024 Daily Operations: Mobe crews to Dolly, PJSM and orientation. Work boat, circulate well till clean with 797bbl FIW. SD circulation, T/IA on a vacuum, install BPV. ND tree, install blanking sub. NU riser and BOPEs. Well Operations Summary Well Operations Summary Start pumping at 2.0bpm. Pressure increased from 1410 to 1635psi over 20minutes. 68bbls pumped (269 total FIW) Bumped rate up to 2.5bpm. IAP started at 1600 and ended at 1775psi after 3 minutes. Pumped 18 additional barrels (287 bbls FIW total pumped). No Flow Test complete. State witnessed PJSM and PTW T/IA 100/425psi, bleed tubing and IA to are PT lines to 250psi/2000psi - Test good Come online with FIW, Tubing goes on instant vacuum. SD pump and feed FIW at 80psi from supply water. Bleeding gas off IA, watching for uid. Pump 4.3BPM @ 0psi for 190BBL, well caught pressure SDFN PJSM and PTW, Fire up Triplex, pump at 1BPM for 23BBL. Pressure steadily climbed to 1600psi, instant T/IA communication on pressures. SD pump. Well bled to T/IA 650/720psi and is holding steady. Pressure held steady at 700psi for 1hr, bleed T/IA to 20psi. Pump with triplex, after 4BBL pressured up to 1200psi, broke over. Pumped 1BBL, pressured up to 1500psi, broke over. Pumped 1BPM at 1300psi for 23BBL. SD Pump well fell to 500psi quickly then slowly bled down over 2hrs. Right when well hit a vacuum, vacuum feed 65.5BBL of OilSafe AR. Kick on Triplex pump and chase pill with 60BBL of FIW. Fluid pumped easier was able to get 2BPM at 1,100PSI. Secure well, RD pumping equipment. Page 1 of 5 Well Name:MRF D-17RD API #:50733201680100 Field:McArthur River Field Start Date:6/15/2024 Permit #:181023 Sundry #:324-329 End Date:10/3/2024 9/7/2024 9/8/2024 9/9/2024 9/10/2024 9/11/2024 9/12/2024 Well Operations Summary Daily Operations: Continue to work the boat, offloading work stirng & back load equipment, lay out and drift 7 tally string., continue with slick line ops recovering rubber and cable each run, made it down to 7848 with 6.5 junk basket. no recovery clean basket on last run, Rig down slick line, rig up work bsket, p/up BHA 8.5 bit , 9-5/8 scraper , bit sub, x/o.x/o= 13.37 ft. continue in hole picking up 3.5 PH 6 work string. depth at rpt time at 1665/ Continue to lay down ESP assembly, recovered all pieces, clean up work basket and window, Lay out and tally 51 joints of 3.5 ph 6 work string, unable to work M/v Titan due to wind and Tide, Rig up slick line, run 8.25 junk basket, tagging up at 2000, 4,300,'4,280', 4,260 ft; & 4,260 ft. recovered rubber and metal each run, ran a 4.5" magnet set down at 7,809 slm, recovered cup of metal chunks , rig down slick line, remove ESP cable sheave from work basket, Off loading work string from M/v Titan. Continue torquing and securing BOPEs, RU jack and work basket, RU accumulator and function test same, fluid pack and attempt shell test slow bleed observed. No leaking on surface. POOH of hole laying down 3-1/2 9.2# L-80, super max tbg to pump and motor assembly, lay out 5" ESP assembly. IFO, preform shell test, mob out state inspector, test TSI BOPE to Hilcorp and AOGCC specs to 250 & 2500 psi, had two fail pass, rig down test equipment, pull blanking sub and two-way check, circulate well with 304 bbl. of FIW, Got back clean water shut down pump well on slight vacuum, back out lock down pins on hanger, pick up spear and landing joints Make up spear,engage hanger work hanger, hanger came off seat at 125k ,pick up to work window Terminate ESP penetrations thru hanger, lay out hanger, Rig up summit tools, held PJSM and held bare pipe shut in drill, pooh laying down 3.-1/2 9.2# super max tbg, total laid down at rpt time 2403 ft. Page 2 of 5 Well Name:MRF D-17RD API #:50733201680100 Field:McArthur River Field Start Date:6/15/2024 Permit #:181023 Sundry #:324-329 End Date:10/3/2024 9/13/2024 9/14/2024 9/15/2024 9/16/2024 9/17/2024 9/18/2024 Continue to pooh with 8.25 bit, laying down work string, lay down BHA, Fluid pack well, attempted MIT the 9-5/8 cag against the junk in hole at 7,850. pump 24 bbls FIW, at 4 bpm at 1400 psi, stopped pumping, bleed off and returned 15 bbls monitor well ( static), rigged up slick line made multiple runs with 10' x 3-1/2 " bailer start tagging depth 7,850' slm to 7,883' swap to a 8" x 3-1/2 bailer start tagging depth at 7,883' to 7,888' at rpt time, recovering sludge with small chunks of rubber, metal & scale. Daily Operations: continue in hole with 9-5/8 csg scraper f/ 1,565' to 4,019', repaired Hydraulics on HWO slips Continue in hole with 9-5/8 csg scraper tagging up at 4,304 dpm with 3k down, forward circulate attempt to wash down at 4,304' ( no joy getting deeper), Rig up and reverse circulate at 3 bpm at 300 psi ( no fluid loss) rotating at 50 rpm at 2600 ftlbs torque, with 2k down on bit. reamed down to 4,308' dpm, circulate bottom up at 4308 ( 32 bbls ) with reverse circulating, , prep to come out of hole, Pooh to change BHA, lay down work string. L/D 9-5/8" scraper and 8.5"OD roller cone bit. Swap BHA to 8.25OD roller cone RIH picking up singles of 3.5" 12.95# PH6 workstring t/'4,308' (previous tag spot) took 3k weight then fell off. Worked BHA through tight spot 3X with no drag. Pipe moving feely. Continue in hole t/7,849'. Tag, fwd circ 30bbl, attempt to rotate and go down. Liner top seen, shut down rotation and begin circ surface to surface in reverse. Small rubber chunks observed in returns. Complete circulation total pumped 635bbl FIW. 1:1 returns, POOH f/7,749' t/4,370' LD singles, Reverse circulate and rotate 2-3x through 4,370'-4,270'. Continue POOH f/ 4,270 t/4,195'. Test BOPE's per AOGCC and Hilcorp standards 250/2,500psi. Slow leak past test plug, coming out of IA valve troubleshoot leak. Pull test plug, change out o-ring seal. Re-land test plug, leak continues. Continue trouble shooting slow leak. Continue RIH with slick line running a 3" x 8' pump bailer tagging at 7888 ft. recovering scale rubber, and metal chunks. , perform injectivity test , stage pump up to 4.5 bpm at 950 psi pump total of 160 bbls shut down pump, holding 800 psi, bled back 50 bbls , sent data to town, made run with slick line with 2" x 8 ft. bailer barrel tagging at 7888 worked bailer to 7916 ft. pooh, rig down slick line , prep deck and pick up 8.22 od, JS# TEST packer RIH picking up 3-1/2 super max. tagging at 4412 ft. worked down to 4417 ft. setting down solid. ,space out and rig up and attempt to pump and push packer thru tight spot / No joy, Held PJSM rigging up to do MIT on 9- 5/8 casing at 4405 f.t Well Operations Summary Pull test plug, rubber O-ring had chunk missing, replace O-ring. Pull 2 way check, clean and reinstall , flush hanger seat out with 10 bbls of FIW, Reland test plug, Attempt to shell test, had very slow leak, pull test plug change O-ring seal, change two way check add 4-1/2 IF blanking sub, reland test plug, Fluid pack BOPE, Test 13-5/8 5m BOPE to Hilcorp and AOGCC specs, with 3-1/2 test joint, test made with water and held 5 minutes on chart, no failures, , Rig down test equipment, pooh laying down 3-1/2 work string. Page 3 of 5 Well Name:MRF D-17RD API #:50733201680100 Field:McArthur River Field Start Date:6/15/2024 Permit #:181023 Sundry #:324-329 End Date:10/3/2024 9/19/2024 9/20/2024 9/21/2024 9/22/2024 9/23/2024 9/24/2024 Well Name:MRF D-17RD Well Operations Summary Cleaning decks, mobe out TSI crew, continue cleaning with a Skeleton crew Rig down HWO unit and set on deck and secure same, rig down work window, nipple down BOPE, install tree, nipple up same test void and tree to 5000 psi for 15 minutes, pull back pressure valve, back load boat and lay HWO unit over in skid and prep to ship to town, clean pits and pump cleaning decks. Set 8.22 JS-3 test packer at 4400 ft. test 9-5/8 csg to 1750 psi, for 30 minutes, ( good test ) bleed off pressure, release packer, Pooh laying down 3-1/2 super max tbg , Lay out test packer, Pick up 7" test packer, with a 7" scraper on top of packer, RIH picking up 3-1/2, 9.2# L-80 super max tbg. to 5846 ft. ( no problems at 4400 ft.) Up wt at 56k down wt at 37k, transfer 65 joints of PH6 work string to pipe deck and strap same. Continue RIH picking up 3-1/2 W/S to 7,880 ft. tagged with 3k dn, pick up 10 ft. retag with 5k dn, space out , Held PJM with crews, set 7" packer @ 7,770' with 15k dn ( OA pressure at 51 psi) pressure up on IA to 400 psi held for 5 minutes, increased pressure to 800 psi attempted to increase pressure pumping at .5 bpm for 5 bbls, stopped pumping pressure stable at 700 psi held for 5 minutes, pump at 1.0 bpm for 25 bbls pressure at 900/950 psi, shut down pump, monitor IA for 15 minutes holding at 700 psi, bled off pressure recovered 17.5 bbls. Tested surface lines to 500/2000 psi, pump down tbg , pumped 1.4 bbls of FIW, pressured up to 1,875 psi, monitor IA/OA 0/51 psi, Verified no communication from packer to IA OA pressure increased from 51 psi to 53 psi,, monitor tbg pressure for 30 minutes after 15 minutes 1850 psi after 30 minutes 1825 psi sent town results, attempted second injection test down tbg with the same results as first test.bled off sent town results, release packer, Pooh laying down 3-1/2 ph 6 w/s and 3-1/2 super max tbg, Note: Received approval Via E-mail from AOGCC Bryan McLellan to run Kill string to 2500 ft & R/dn and mobe out HWO unit. Continue Pooh laying down 3.5 super max tbg, lay out BHA, work boat, back load excess pipe & equipment, On load kill string, Swap HWO unit to 4-1/2 handling equipment, Rig up HWO gin pole, Pick up hanger and prep same, land hanger in well head, test the VBRs with 4-1/2 test joint to 250 psi low and 2500 psi high, good test, lay down test equipment ,RIH picking up 4-1/2, 12.6# L-80 IBT tbg, to 525 ft. MD, JIC fitting on HWO unit Hydraulic slips broke, releasing 5 gallong of Marine BIO degradable Hydraulic oil in second containment area, shut down power pack, secure well , clean up Oil, make repairs to slips, Continue in hole picking up 4-1/2, 12.6#, L-80, IBT tbg to 2,564' md, P/up hanger & hanger pup; torque same Finish cleaning decks in the second containment area, Make repairs to HWO unit hydraulic slips, continue RIH picking up 4-1/2, 12.6# L- 80, IBT TBG ( KILL STRING) ran total of 83 joints to 2564 md. PIck up hanger and hanger pup, make up same, orientate hanger with well head, land same with 28k down wt. depth at 2606 md, RILDs, lay down landing joints, arrange decks to make room, rigging down support equipment, unable to rig down HWO unit due to HI winds, Wait on weather wind 35 to 45 mph gust to 50 mph, housekeeping cleaning decks Daily Operations: Page 4 of 5 API #:50733201680100 Field:McArthur River Field Start Date:6/15/2024 Permit #:181023 Sundry #:324-329 End Date:10/3/2024 9/25/2024 9/26/2024 9/27/2024 10/3/2024 State inspector Adam Earl witnessed No Flow test. Verval approval PASS. Daily Operations: Held PJSM with crews, Arrange remainingTSI equipment on deck and cleaning under same, move Conne's on East side and continue to clean underneath same, shut down for the night Finish cleaning rig, wait on boat, back load transfer equipment to steel, off load at steelhead, off load remaining TSI equipment onto Boat, Mobe skeleton crew in. Cont Page 5 of 5 2024-1003_No-Flow_TBU_D-17RD_ae Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10-4-2024 P. I. Supervisor FROM: Adam Earl SUBJECT: No Flow Test Petroleum Inspector TBU D-17RD Hilcorp Alaska LLC PTD 1810230 10-03-2024: I traveled to Dolly Varden Platform to witness a No-Flow Test after a failed rig workover. TBU D-17RD was packed off, fluid packed, and a kill string installed. The well had been opened to bleed for 48 hours before shutting in for the test. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 1:30 0 / 0 / 90 Shut in to start 1:45 0 / 0 / 90 2:00 0 / 0 / 90 2:15 0 / 0 / 90 2:30 0 / 0 / 90 0 0 Open to bleed through meter; completely dead at surface 2:35 0 / 0 / 90 2:50 0 / 0 / 90 3:05 0 / 0 / 90 3:20 0 / 0 / 90 3:35 0 / 0 / 90 0 0 Open to bleed through meter; completely dead at surface 3:50 0 / 0 / 90 4:05 0 / 0 / 90 4:20 0 / 0 / 90 4:35 0 / 0 / 90 0 0 Open to bleed through meter; completely dead at surface 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Passing no-flow test as per State guidelines. Attachments: Test Equipment Certifications 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.11.15 10:27:56 -09'00' 2024-1003_No-Flow_TBU_D-17RD_ae Page 2 of 2 No-Flow Test – TBU D-17RD (PTD 1810230) Photos by AOGCC Inspector A. Earl 10/3/2024 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Juanita Lovett; Darcy Dunbar - (C); Dan Marlowe Subject:RE: D-17RD (PTD#181-023) Date:Monday, September 23, 2024 11:55:00 AM Ryan, Send me the NFT results and then we can make a decision on how to proceed. Thanks Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: McLellan, Bryan J (OGC) Sent: Friday, September 20, 2024 4:58 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com>; Darcy Dunbar - (C) <Darcy.Dunbar@hilcorp.com>; Dan Marlowe <dmarlowe@hilcorp.com> Subject: Re: D-17RD (PTD#181-023) Ryan, Hilcorp has approval to proceed with the plan below. Regards Sent from my iPhone On Sep 20, 2024, at 4:39 PM, Ryan Rupert <Ryan.Rupert@hilcorp.com> wrote: Bryan- We just completed our casing test on D-17RD, and the results were a fail. See attached for my current schematic and annotations. We have a 7” test packer set on a workstring at ~7870’ MD. See below for results. Injection down the work string and into the perfs is very tight, and injection down the workstring x 9-5/8” annulus indicates a casing leak. Given these results, Hilcorp asks permission to suspend RWO operations on this well. See below for proposed path forward. Please let us know if we have approval for this path forward. Well status: 1. Pressure up to down work string to 1875psi. Pressure bleeds down to 1850/1825psi after 15/30 minutes. No pressure response on IA 2. Injection down workstring x 9-5/8” Inner Annulus of 1bpm at 900psi. Injected for 25bbls. No pressure response on work string, nor OA. 3. Can bleed IA and workstrings down to 0psi, and well remains dead Proposed path forward: 1. Run kill string to 2500’ MD 2. RDMO rig HWO rig 3. Evaluate / diagnose path forward 4. By 10/1/2025 1. Submit sundry for resume HWO or 2. Set plug in 7” liner or 4-1/2” liner for secure or 3. Pass another no flow test. (last passed NFT 7/27/24) Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only forthe use of the individual or entity named above. If you are not an intended recipient or if you have received thismessage in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited.If you have received this email in error, please immediately notify us by return email or telephone if the sender's phonenumber is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. <20240920_163439.jpg> CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:AOGCC Records (CED sponsored) Subject:Fwd: D-17RD (PTD#181-023) Date:Friday, September 20, 2024 4:59:42 PM Please add this email to wellfile Bryan McLellan Sent from my iPhone Begin forwarded message: From: "McLellan, Bryan J (OGC)" <bryan.mclellan@alaska.gov> Date: September 20, 2024 at 4:58:27 PM AKDT To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Cc: Juanita Lovett <jlovett@hilcorp.com>, "Darcy Dunbar - (C)" <Darcy.Dunbar@hilcorp.com>, Dan Marlowe <dmarlowe@hilcorp.com> Subject: Re: D-17RD (PTD#181-023) Ryan, Hilcorp has approval to proceed with the plan below. Regards Sent from my iPhone On Sep 20, 2024, at 4:39 PM, Ryan Rupert <Ryan.Rupert@hilcorp.com> wrote: Bryan- We just completed our casing test on D-17RD, and the results were a fail. See attached for my current schematic and annotations. We have a 7” test packer set on a workstring at ~7870’ MD. See below for results. Injection down the work string and into the perfs is very tight, and injection down the workstring x 9-5/8” annulus indicates a casing leak. Given these results, Hilcorp asks permission to suspend RWO operations on this well. See below for proposed path forward. Please let us know if we have approval for this path forward. Well status: Pressure up to down work string to 1875psi. Pressure bleeds down to 1850/1825psi after 15/30 minutes. No pressure response on IA Injection down workstring x 9-5/8” Inner Annulus of 1bpm at 900psi. Injected for 25bbls. No pressure response on work string, nor OA. Can bleed IA and workstrings down to 0psi, and well remains dead Proposed path forward: 1. Run kill string to 2500’ MD 2. RDMO rig HWO rig 3. Evaluate / diagnose path forward 4. By 10/1/2025 a. Submit sundry for resume HWO or b. Set plug in 7” liner or 4-1/2” liner for secure or c. Pass another no flow test. (last passed NFT 7/27/24) Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and isintended only for the use of the individual or entity named above. If you are not an intended recipientor if you have received this message in error, you are hereby notified that any dissemination,distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. <20240920_163439.jpg> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:McLellan, Bryan J (OGC) To:Ryan Rupert Subject:RE: [EXTERNAL] Re: D-17RD(PTD#181-023) HWO acid Date:Friday, September 6, 2024 9:08:00 AM Ryan, Hilcorp has approval to make the change outlined below to sundry 324-329. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Thursday, September 5, 2024 4:41 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: [EXTERNAL] Re: D-17RD(PTD#181-023) HWO acid Just pumping the acid on the rig instead of before it Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) From: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Sent: Thursday, September 5, 2024 4:40 PM To: Ryan Rupert <Ryan.Rupert@hilcorp.com> Subject: [EXTERNAL] Re: D-17RD(PTD#181-023) HWO acid Ryan, What’s different? CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. Thanks Bryan Sent from my iPhone On Sep 5, 2024, at 11:42 AM, Ryan Rupert <Ryan.Rupert@hilcorp.com> wrote: Bryan- We are about to begin operations on the attached D-17RD hydraulic workover. Hilcorp intends pump some acid on the rig per below. I believe this is already covered within our existing sundry approval (acid stim section #1-7). Just wanted to clarify with the agency. Thanks 1. MU 9-5/8” test packer 2. Isolate lower completion by setting packer at ±7849’ MD 3. MIT of 9-5/8” casing to 1850psi 4. Establish injectivity down tubing into liner/perfs below test packer 5. Pump acid to treat liner 1. RU pump and treating lines 2. Pressure test all to 250psi low and 2500psi high 3. Pump Mutual solvent/Xylene pre flush if needed followed by acid pill (5-15% concentration HCL, or Oilsafe AR-Synthetic acid) 4. Displace pill and spot across perfs with FIW keeping treating pressure <2000psi during displacement 5. RD pumping equipment 6. Let acid soak (duration per OE) 7. Overdisplace acid into formation with FIW 8. Unseat and POOH with test packer Can produce for no more than 14 days before a new NFT will be needed Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phonenumber is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient toensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect itssystems or data. No responsibility is accepted by the company in this regard and the recipient should carry out suchvirus and other checks as it considers appropriate. <10-403 Trading Bay Unit D-17RD PTD 181-023_Sundry_324- 329_Approved_061724.pdf> The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________TRADING BAY UNIT D-17RD JBR 11/25/2024 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Annular flange leaked , CMV 7 leaked, both passed retest after tightning and servicing. Test Results TEST DATA Rig Rep:Munoz/RobsorOperator:Hilcorp Alaska, LLC Operator Rep:Kozub/Hooter Rig Owner/Rig No.:Team Snubbing TSI 102 PTD#:1810230 DATE:9/8/2024 Type Operation:WRKOV Annular: 250/2500Type Test:INIT Valves: 250/2500 Rams: 250/2500 Test Pressures:Inspection No:bopAGE240917102630 Inspector Adam Earl Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 5 MASP: 2065 Sundry No: 324-329 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.NA Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 9 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13 5/8"FP #1 Rams 1 2 7/8x5 VBR P #2 Rams 1 Blind P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3 1/8"P HCR Valves 2 3 1/8"P Kill Line Valves 2 3 1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1800 200 PSI Attained P23 Full Pressure Attained P172 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P4@2350 ACC Misc NA0 NA NATrip Tank P PPit Level Indicators NA NAFlow Indicator P PMeth Gas Detector P PH2S Gas Detector 0 NAMS Misc Inside Reel Valves 0 NA Annular Preventer P27 #1 Rams P8 #2 Rams P8 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1 9 9 9 999999 9 9 9FP FP Annular flange leaked CMV 7 leaked Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov August 22, 2024 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit D-17RD PTD 1810230 Dear Mr. Marlowe: On July 27, 2024, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-17RD located on the Dolly Varden Platform in Cook Inlet. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 21-001. The test procedure employed was a 1 hour shut in period to monitor pressure build up followed by a short flow period through the test equipment to an open top tank – repeated two additional times. There was no oil flow rates observed during the no-flow test. Gas rates were less than the allowed 900 scf per hour during all flow rate checks. Trading Bay Unit D-17RD may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-17RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter on the Dolly Varden Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2024.08.22 08:47:26 -08'00' 2024-0727_No-Flow_TBU_D-17RD_gc Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 7/27/2024 P. I. Supervisor FROM: Guy Cook SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit D-17RD Hilcorp Alaska LLC PTD 1810230; Sundry 324-329 7/27/2024: I arrived on the Dolly Varden platform and met with Jon Loomis (Hilcorp), and we briefly talked about the job. The rig up was appropriate, and the digital gauges and flow meter have current calibrations. No issues with the job and the well passed easily showing a slight decline in the very small amount of buildup pressure. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 10:00 am 0 / 0 / 115 Shut in well for buildup. 10:15 am 0.03 / 0.02 / 115 10:30 am 0.06 / 0.04 / 115 10:45 am 0.08 / 0.06 / 115 11:00 am 0.13 / 0.09 / 115 500 0 Open to bleed. Bled to zero in 45 seconds. 11:15 am 0.02 / 0.01 / 115 11:30 am 0.06 / 0.05 / 115 11:45 am 0.08 / 0.07 / 115 12:00 pm 0.11 / 0.09 / 115 400 0 Open to bleed. Bled to zero in 45 seconds. 12:15 pm 0.02 / 0.01 / 115 12:30 pm 0.05 / 0.03 / 115 12:45 pm 0.08 / 0.05 / 115 13:00 pm 0.11 / 0.07 / 115 400 0 Open to bleed. Bled to zero in 30 seconds. 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Attachments: None 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.08.21 14:47:48 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Ryan Rupert Cc:Juanita Lovett; Karson Kozub Subject:RE: D-17RD (#181-023) Date:Wednesday, June 12, 2024 4:27:00 PM Ryan, Hilcorp has verbal approval to execute the acid stimulation portion of the sundry submitted on 6/4/24 for this well. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Ryan Rupert <Ryan.Rupert@hilcorp.com> Sent: Wednesday, June 12, 2024 3:15 PM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Juanita Lovett <jlovett@hilcorp.com>; Karson Kozub <kkozub@hilcorp.com> Subject: D-17RD (#181-023) Bryan- Sorry to bug you about a sundry that I did not prioritize this week. We have an opportunity to go pump the pre-rig acid job on D-17RD this weekend, if the AOGCC is in agreement. Do you know how that sundry is going through the process? If not on track for a Friday 6/14 approval, can Hilcorp please request a verbal approval to execute the acid stimulation procedure (steps #1-7)? Thank you, Ryan Rupert CIO Ops Engineer (#13088) 907-301-1736 (Cell) 907-777-8503 (Office) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,800 See schematic Casing Collapse Structural Conductor Surface 1,540psi Intermediate Production 3,090psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: HWO - Replace ESP CO 228A 6/13/2024 10,800'2,951' 3-1/2" & 4-1/2" 10,077' See schematic See schematic 8,145' Perforation Depth MD (ft): 9,596 - 10,490 8,145' 7" 8,952 - 9,788 7,579'9-5/8" 13-3/8"2,497' MD 3,090psi2,404'2,497' Length Size Proposed Pools: L-80 TVD Burst 7,611 & 9,440 5,750psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018729 181-023 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20168-01-00 Hilcorp Alaska, LLC Trading Bay Unit D-17RD AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY McArthur River Middle Kenai G Oil & Hemlock Oil Same 10,078 10,121 9,444 2,065psi N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 11:11 am, Jun 04, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.06.04 10:59:55 - 08'00' Dan Marlowe (1267) 324-329 10-404 SFD 6/5/2024 Initial BOP test to 5000 psi RWP. Initial Annular test to 2500 psi. Subsequent BOP tests to 2500 psi. BJM 6/17/24 CDW 06/04/2024 X DSR-6/4/24 Yes, for acid job only 6/12/24 Bryan McLellan *&:JLC 6/17/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.06.17 14:39:44 -08'00'06/17/24 RBDMS JSB 061824 ESP Swap HWO Well: Dolly Varden D-17RD Well Name:D-17RD API Number:50-733-20168-01-00 Current Status:Failed ESP Oil Producer Leg:A-2 (NW) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:181-023 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:3,000 psi @ 9,350’ TVD Max from offsets Max. Potential Surface Pressure: 2065 psi Using 0.1 psi/ft Brief Well Summary Dolly Varden D-17RD is a G-zone / Hemlock oil producer. It had been SI since 2007 due to scaling off. Hilcorp successfully returned the well to production in 2013 with several non-rig scale remediations and got gross fluid up to ~1000bfpd. In 2014 a RWO was performed, and the well was converted to ESP. A scab liner was set as part of this RWO over the lower casing to cover damage. The well produced consistently above 5000bfpd for ~1.75years until the ESP died in December-2015. The well has been lifted on poorboy GL through a tubing punch ever since. Well D-17RD sits on the NW leg of the Dolly Varden Platform.This leg’s configuration and deck layout precludes our Hilcorp owned RWO rig (#404) from rigging up on this leg’s wells. Given that we plan to utilize Team Snubbing’s Hydraulic Workover unit with a smaller footprint to workover well D-17RD. The goal of this project is to pull the failed ESP and replace with a new ESP completion to restore full production HWO Conditions x Operations shall be 24hrs continuous x Traditional well control approach will be implemented x Filtered Inlet water (FIW) will be used as kill weight fluid (8.4ppg or greater) x KWF will be a barrier at all times x No snubbing operations will be conducted x Team Snubbing’s BOP stack will be used for this operation (see attachment) ESP Swap HWO Well: Dolly Varden D-17RD Pertinent wellbore information: - Max inclination: 28 degree sail angle from 1700 – 5300’ MD - Pertinent History o 7/20/20: Well had died SL diagnostics show that GL punches are scaled off Repunch GL and inflow punches Production restored, but to <150bfpd o 1/2/16: Tubing punches shot at 7590’ for inflow, and 4000’ for poorboy GL. Well produces at ~1000bfpd o 1/1/16: Current ESP dies after ~1.75 years. Production was 5000+ bfpd prior o 10/20/15: Most recent No-Flow Test Passed o 10/6/15: 15%HCL acid job increases PI from 2.8 to 3.5 bfpd/psi drawdown o Feb-2014 RWO Remove 4-1/2" production tbg & GLM's Burn over packer at 9280'. Recover packer Recover fish / packer from 9920' as well Can't get past 10,122' MD (mid H-2) Casing caliper from 9270' to surface. Severe corrosion observed from 8800' - 9300' TCP G-zone Set scab liner (uncemented) from 7872 - 9421' MD MIT of 9-5/8" casing and top packer from 7872' and above to 1500psi PASS ESP installed Acid Stimulation Procedure 1. RU pump and treating lines 2. Pressure test all to 250psi low and 2000psi high (pump limitation = 2000psi) 3. Pump Mutual solvent/Xylene pre flush followed by acid pill (5-15% concentration HCL, or Oilsafe AR- Synthetic acid) to stimulate perforations 4. Displace pill and spot across perfs with FIW keeping treating pressure <2000psi during displacement 5. RD pumping equipment 6. Let acid soak (duration per OE) 7. Produce well a. NFT will be invalidated at this point b. Can produce for no more than 14 days before a new NFT will be needed c. Or can SI well awaiting HWO ESP Swap HWO Well: Dolly Varden D-17RD HWO Procedure: 1. MIRU PESI Hydraulic Workover (HWO) Unit (Snubbing International, Alberta, Canada: DBA PESI) 2. Circulate well to production: a. Work over fluid will be filtered inlet water (8.4ppg) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing volume = 116bbls d. IA + Liner volume = 505bbls 3. Set BPV/TWC, ND tree, NU Hilcorp BOP stack (see attached) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOP’s will be closed as needed to circulate the well 4. Pull BPV/TWC through BOP stack 5. BOLDS and unseat hanger 6. POOH laying down 3-1/2” ESP completion 7. MU 9-5/8” test packer (or SL plug. TBD) 8. Isolate lower completion at ±7849’ MD (or lower) 9. MIT of 9-5/8” casing to 1850psi (0.25 x 7316’ TVD = 1829psi) 10. POOH with test packer / plug Contingency if cleanout is needed 11. PU 3-1/2” workstring 12. MU 9-5/8” casing cleanout assembly 13. RIH and mill/cleanout 9-5/8” casing to target depth = 7,849’ MD 14. POOH and lay down cleanout BHA and workstring 15. Pickup 3-1/2” ESP completion a. Bottom ESP to be set at ±7,775’ MD b. No packer nor SSSV are planned 16. Set BPV/TWC, ND BOP, NU tree and test, pull BPV/TWC, and RDMO HWO crew and equipment 17. Conduct NPT post-rig per attachment after ~10 days of production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current/Proposed Wellhead Diagram (no changes) 4. TSI BOP Drawing 5. Modified fluid flow diagram to include HWO equipment 6. NFT Procedure 7. RWO Sundry Change Form _____________________________________________________________________________________ Updated by: JLL 05/31/24 SCHEMATIC McArthur River Field, TBU Well: D-17RD Last Completed: 03/08/2014 PTD: 181-023 API: 50-733-20168-01 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8” 61 K-55 Butt. LT&C 12.515 Surf 2,497’ 9-5/8” 40 N-80 Butt 8.835 Surf 4011’ 43.5 N-80 Butt 8.755 4011’ 5498’ 47 N-80 Butt 8.681 5498’ 7025’ 47 S-95 8rd 8.681 7025’ 8145’ 7” 32 N-80 Butt 6.094 7,849’ 7884’ 29 N-80 Butt 6.184 7884’ 9523’ 32 N-80 Butt 6.094 9523’ 10,800’ TUBING DETAIL 3-1/2” 9.2 L-80 Supermax 2.992 Surf 7,611’ 4-1/2” 12.6 L-80 Hydril 503 3.958 7,880’ 9,440’ FISH/FILL INFO FILL: Tagged w/ a 2.65” GR on 9/25/96 @ 10,122’ WLM FISH: OM-1 Arm & (3) Springs 4/8/95 10,126’ WLM 17’ Strip Gun 8/23/90 10,533’ WLM 22’ Strip Gun 6/29/92 10,538’ WLM RKB to TBG Head = 41.05’ TD = 10,800’ PBTD = 10,676’ Tree Connection: 4-1/6”, 5,000# 11 7 9-5/8” Tubing Punch on 1/2/16 @ 7,590’-7,603’ Tagged Fill 10,121 MD 2/25/14 Casing Damage 9320-9340 6 9 10 8 2 5 3 4 13-3/8” Tubing Punch on 1/2/16 @ 4,400’ HK-1 Max Angle=27°, KOP @ 600’ HK-3 HK-4 HK-5 G-2 G-3 G-4 G-5 G-6 HK-2 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Perf Date G-2 9,596' 9,628' 8,952' 8,982' 32' 6 02/27/14 G-3 9,658' 9,673' 9,010' 9,024' 15' 6 02/27/14 G-4 9,701' 9,735' 9,050' 9,082' 34' 6 02/27/14 G-4 9,794' 9,798' 9,137' 9,141' 4' 6 02/27/14 G-5 9,854' 9,859' 9,193' 9,198' 5' 6 02/27/14 G-5 9,882' 9,890' 9,219' 9,227' 8' 6 02/27/14 G-5 9,924' 9,935' 9,259' 9,269' 11' 6 02/27/14 G-6 9,965' 9,969' 9,297' 9,301' 4' 6 02/27/14 HK-1 10,052' 10,081' 9,378' 9,405' 29’ 36 11/21/1992 HK-2 10,096' 10,120' 9,419' 9,442' 24’ 18 7/27/1992 HK-2 10,178' 10,192' 9,496' 9,509' 14’ 4 2/2/1987 HK-3 10,214' 10,232' 9,530' 9,547' 18’ 12 11/29/1992 HK-4 10,260' 10,292' 9,573' 9,603' 32’ 8 1/30/1987 HK-4 10,330' 10,380' 9,638' 9,685' 50’ 28 11/29/1992 HK-5 10,405' 10,490' 9,709' 9,788' 85’ 20 12/3/1992 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 41.05’ 41.05’ Tubing Hanger 2 7,611’ 7,065’ Bolt on Discharge 3 7,613’ 7,067’ Pump - SG7300 (x 4) 4 7,690’ 7,141’ Intake 5 7,710’ 7,160’ Motor – (x 2) 6 7,774’ 7,220’ Bottom of ESP 7 7,872’ 7,316’ 4.00 7” 26-32# Hydraulic Permanent Packer 8 7,880’ 7,324’ 3.958 4.5” 12.6# Hydril 503 9 9,421’ 8,790’ 3.958 Swell Packer 10 9,440’ 8,807’ 4.000 Wireline Re-entry Guide CEMENT DETAILS 13-3/8"17-1/2” Hole: Cemented with 2000sxs 14.8ppg class G. had cement returns to surface. ToC at Surface. 9-5/8” 12-1/4” Hole: Cemented with 1667sxs of class G cement. (no cement back to surface when opened DV tool). 5/14/81 VDL showed Cement back to at least 8000’ MD (didn’t log above there). 2nd Stage: Pumped 1780sxs class G cement through DV at DV collar at 6655’ MD. (no cement back to surface)5/14/81 VDL shows ToC at 2070’ MD. 7”8.5” Hole: Cemented with 900sxs class G cement. 80 sxs reversed out from off liner top. 6/12/81 VDL confirms ToC at ToL. _____________________________________________________________________________________ Updated by: JLL 06/03/24 PROPOSED McArthur River Field, TBU Well: D-17RD Last Completed: Future PTD: 181-023 API: 50-733-20168-01 CASING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8” 61 K-55 Butt. LT&C 12.515 Surf 2,497’ 9-5/8” 40 N-80 Butt 8.835 Surf 4011’ 43.5 N-80 Butt 8.755 4011’ 5498’ 47 N-80 Butt 8.681 5498’ 7025’ 47 S-95 8rd 8.681 7025’ 8145’ 7” 32 N-80 Butt 6.094 7,849’ 7884’ 29 N-80 Butt 6.184 7884’ 9523’ 32 N-80 Butt 6.094 9523’ 10,800’ TUBING DETAIL 3-1/2” Surf ±7,610’ 4-1/2” 12.6 L-80 Hydril 503 3.958 7,880’ 9,440’ FISH/FILL INFO FILL: Tagged w/ a 2.65” GR on 9/25/96 @ 10,122’ WLM FISH: OM-1 Arm & (3) Springs 4/8/95 10,126’ WLM 17’ Strip Gun 8/23/90 10,533’ WLM 22’ Strip Gun 6/29/92 10,538’ WLM RKB to TBG Head = 41.05’ TD = 10,800’ PBTD = 10,676’ Tree Connection: 4-1/6”, 5,000# 11 3 9-5/8” Tagged Fill 10,121 MD 2/25/14 Casing Damage 9320-9340 5 6 4 2 13-3/8” HK-1 Max Angle=27°, KOP @ 600’ HK-3 HK-4 HK-5 G-2 G-3 G-4 G-5 G-6 HK-2 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Perf Date G-2 9,596' 9,628' 8,952' 8,982' 32' 6 02/27/14 G-3 9,658' 9,673' 9,010' 9,024' 15' 6 02/27/14 G-4 9,701' 9,735' 9,050' 9,082' 34' 6 02/27/14 G-4 9,794' 9,798' 9,137' 9,141' 4' 6 02/27/14 G-5 9,854' 9,859' 9,193' 9,198' 5' 6 02/27/14 G-5 9,882' 9,890' 9,219' 9,227' 8' 6 02/27/14 G-5 9,924' 9,935' 9,259' 9,269' 11' 6 02/27/14 G-6 9,965' 9,969' 9,297' 9,301' 4' 6 02/27/14 HK-1 10,052' 10,081' 9,378' 9,405' 29’ 36 11/21/1992 HK-2 10,096' 10,120' 9,419' 9,442' 24’ 18 7/27/1992 HK-2 10,178' 10,192' 9,496' 9,509' 14’ 4 2/2/1987 HK-3 10,214' 10,232' 9,530' 9,547' 18’ 12 11/29/1992 HK-4 10,260' 10,292' 9,573' 9,603' 32’ 8 1/30/1987 HK-4 10,330' 10,380' 9,638' 9,685' 50’ 28 11/29/1992 HK-5 10,405' 10,490' 9,709' 9,788' 85’ 20 12/3/1992 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 1 41.05’ 41.05’ Tubing Hanger 2 ±7,610’ ±7,065’ Bolt on Discharge Pump Intake Motor ±7,775' ±7,220 Bottom of ESP 3 7,872’ 7,316’ 4.00 7” 26-32# Hydraulic Permanent Packer 4 7,880’ 7,324’ 3.958 4.5” 12.6# Hydril 503 5 9,421’ 8,790’ 3.958 Swell Packer 6 9,440’ 8,807’ 4.000 Wireline Re-entry Guide CEMENT DETAILS 13-3/8"17-1/2” Hole: Cemented with 2000sxs 14.8ppg class G. had cement returns to surface. ToC at Surface. 9-5/8” 12-1/4” Hole: Cemented with 1667sxs of class G cement. (no cement back to surface when opened DV tool). 5/14/81 VDL showed Cement back to at least 8000’ MD (didn’t log above there). 2nd Stage: Pumped 1780sxs class G cement through DV at DV collar at 6655’ MD. (no cement back to surface)5/14/81 VDL shows ToC at 2070’ MD. 7”8.5” Hole: Cemented with 900sxs class G cement. 80 sxs reversed out from off liner top. 6/12/81 VDL confirms ToC at ToL. Dolly Varden Platform D-17RD Current 07/9/2013 5000 psi BOP stack per Ryan Rupert. -bjm For recently worked over wells 1. Well produced on artificial lift for ~10 days 2. Shut down artificial lift and leave well lined up to production and monitor until fluid level is stable. 3. Notify AOGCC to witness test (48hr notice to AOGCC) 4. Bleed well (TBG and IA) to 0 psi 5. Rig up test equipment (low pressure gauge, flowmeter, etc.) 6. Let well bleed through flow meter until inspector arrives but do not exceed 48 hrs. of total bleed time 7. Begin No Flow Test No-Flow Test Option A – Fluid Flow Rate (Flow Meter Procedure) 1. Record tubing (T), inner annulus (IA), and outer annulus (OA) pressures prior to 2. shut in to start the No-Flow Test 3. Shut in well to monitor pressure build up – record T, IA, and OA pressures at least 4. every 15 minutes 5. At 1 hour, open to flow through the meter and document flow rates and well pressures (T, IA, OA) at 5-minute increments until the rate declines to less than the acceptance criteria, not to exceed 30 minutes 6. Repeat the shut-in/flow monitoring steps at least 2 times Test acceptance: flow rates not exceeding 6.3 gallons per hour liquid and 900 standard cubic feet per hour gas demonstrated by at least 2 consecutive flow monitoring periods Option B – Pressure Discharge (Pressure Gauge Procedure) 1. Open the well to flow for at least 1 hour prior to starting the test 2. Record T, IA, and OA pressures immediately prior to shutting in the well 3. Shut in the well and chart T, IA, and OA pressures at least every 15 minutes for 3 hours 4. Open the flowline to an atmospheric tank or vessel and record pressures at 1-minute increments for 5 minutes Test acceptance: pressure discharged (0 psi) within 5 minutes Test procedure as directed by AOGCC inspector. -bjm Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Trading Bay Unit D-17RD (PTD 181-023)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC 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 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/15/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231115 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU D-01A 50029200540100 197078 10/31/2023 HALLIBURTON RBT TBU D-07RD2 50733201170200 192155 11/5/2023 READ Caliper Survey TBU D-17RD 50733201680100 181023 11/5/2023 READ Caliper Survey TBU D-47 50733201950200 191011 11/4/2023 READ Caliper Survey Please include current contact information if different from above. T38136 T38137 T38138 T38139 11/21/2023 TBU D-17RD 50733201680100 181023 11/5/2023 READ Caliper Survey Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.21 10:31:56 -09'00' • \,, OF T1.1 Alaska Oila1� Gas I 1/77y, THE STATE W — nf t ®1ZSe1'Va$1®11 Commission gc.Or l ASKA. '9`Ds'°� 333 West Seventh Avenue Anchorage, Alaska 99501-3572 GOVERNOR BILL WALKER Main: 907.279.1433 \ *` Fax: 907.276.7542 AL�9�� www.aogcc.alaska.gov November 30, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 fi RE: No-Flow Verification scoNED Trading Bay Unit D-17RD PTD 1810230 Dear Mr. Golis: On October 20, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-17RD located on the Dolly Varden Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Trading Bay Unit D-17RD prior to the test. The well performance was monitored for three hours with no discernable flow of liquid or gas observed. The well may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-17RD demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Dolly Varden Platform. Sincerely, Reg( James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • STATE OF ALASKA AIL OIL AND GAS CONSERVATION COMM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate D (Acid) Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 181-023 • 0,..1 L:,{ gum 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: ilk L,'.gam. 'f` Anchorage,AK 99503 50-733-20168-01 7.Property Designation(Lease Number): 8.Well Name and Number: I]L r 2 0 2015 ADL0018729 • Trading Bay Unit D-17RD 0 r 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): , 't N/A McArthur River Field/Middle Kenai G&Hemlock Oil Pools o 11.Present Well Condition Summary: Total Depth measured 10,800 • feet Plugs measured N/A feet true vertical 10,077 r feet Junk measured 10,126, 10,533& feet 10.538 Effective Depth measured 10,122 feet Packer measured 7,872&9,421 feet true vertical 9,444 feet true vertical 7,316&8,790 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,497' 13-3/8" 2,497' 2,404' 3,090 psi 1,540 psi Intermediate Production 8,145' 9-5/8" 8,145' 7,579' 5,750 psi 3,090 psi Liner 2,951' 7" 10,800' 10,077' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet semou True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 7,611 (MD) 7,065(TVD) Hyd.Perm.Pkr 7,872(MD)7,316(ND) Packers and SSSV(type,measured and true vertical depth) Swell Packer 9,421 (MD)8,790(ND) SSSV: N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9596-10120' Treatment descriptions including volumes used and final pressure: 191 bbls FIW, 1320 gallons preflush(330 gallons Baker Petrolite WAW-5206 mixed with 990 gallons Xylene),107 bbls 15%HCL acid, 100 bbls FIW displacement,final treatment pressure 1217 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 102 33 4897 121 120 Subsequent to operation:, 6 111 5779 140 120 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations D Exploratory❑ Development D ' Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil Q Gas El WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ NINJ ❑ WAC❑ GINJ❑ • SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-576 Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature4il Phone (907)283-1329 Date 10/19/2015 140-a,, � ��" tit.,f (ICI 212015 Form 10-404 Revised 5/2015 �� RBpMS* Submit Original Only • • Well:McArthurD-17RD River Field,TBU II SCHEMATIC Last Completed: 03/08/2014 PTD: 181-023 1-lilcorp Alaska,LLC API: 50-733-20168-01 RKB to TBG Head=41.05' Tree Connection:4-1/6",5,000# CASING DETAIL 1 SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 13-3/8" 61 K-55 Butt.LT&C 12.515 Surf2,497' 9 5/8" 40 N-80 Butt 8.835 Surf 4011' 9-5/8" 43.5 N-80 Butt 8.755 4011' 5498' 9-5/8" 47 N-80 Butt 8.681 5498' 7025' 9-5/8" 47 S-95 8rd 8.681 7025' 8145' 7" 32 N-80 Butt 6.094 7,849' 7884' 7" 29 N-80 Butt 6.184 7884' 9523' 7" 32 N-80 Butt 6.094 9523' 10,800' TUBING DETAIL 3-1/2" 9.2 L-80 Supermax Surf 7,611' JEWELRY DETAIL No Depth Depth (MD) (ND) ID Item 1 41.05' 41.05' Tubing Hanger 2 7,611' 7,065' Bolt on Discharge 3 7,613' 7,067' Pump-SG7300(x 4) 4 7,690' 7,141' Intake 2 5 7,710' 7,160' Motor-(x 2) 3 6 7,774' 7,220' Bottom of ESP 9-5/8" 3 4 7 7,872' 7,316' 4.00 7"26-32#Hydraulic Permanent Packer 5 8 7,880' 7,324' 3.958 4.5"12.6#Hydril 503 6 9 9,421' 8,790' 3.958 Swell Packer Uti ■ 10 9,440' 8,807' 4.000 Wireline Re-entry Guide 1111 7 Casing Damage A 8 9320-9340 d 9 FISH/FILL INFO FILL:Tagged w/a 2.65"GR on 9/25/96 @ 10,122'WLM � 10 FISH: OM-1 Arm&(3)Springs 4/8/95 10,126'WLM G-2 17'Strip Gun 8/23/90 10,533'WLM -G-3 22'Strip Gun 6/29/92 10,538'WLM G-4 6-5 G-6 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Perf Date HK-1 G-2 9,596' 9,628' 8,952' 8,982' 32' 6 02/27/14 G-3 9,658' 9,673' 9,010' 9,024' 15' 6 02/27/14 HK 2 G-4 9,701' 9,735' 9,050' 9,082' 34' 6 02/27/14 `' . k+.= HK-3 G-4 9,794' 9,798' 9,137' 9,141' 4' 6 02/27/14 " er' G-5 9,854' 9,859' 9,193' 9,198' S' 6 02/27/14 „..,...0..,.. , 7 Y # *, G-5 9,882' 9,890' 9,219' 9,227' 8' 6 02/27/14 0.:17.71",4S4,':.>0 HK-4 G-5 9,924' 9,935' 9,259' 9,269' 11' 6 02/27/14 "74! 1'+b t!.'"rG-6 9,965' 9,969' 9,297' 9,301' 4' 6 02/27/14 i" ¢ �`it` HK-5 HK-1 10,052' 10,081' 9,378' 9,405' 29' 36 11/21/1992 # ' 'tt`t HK-2 10,096' 10,120' 9,419' 9,442' 24' 18 7/27/1992 *.kq x '"1y„ HK-2 10,178' 10,192' 9,496' 9,509' 14' 4 2/2/1987 /-"- `Y~' ° HK-3 10,214' 10,232' 9,530' 9,547' 18' 12 11/29/1992 HK-4 10,260' 10,292' 9,573' 9,603' 32' 8 1/30/1987 TD=10,800'PBTD=10,676' HK-4 10,330' 10,380' 9,638' 9,685' 50' 28 11/29/1992 Max Angle=27°,KOP @ 600' HK-5 10,405' 10,490' 9,709' 9,788' 85' 20 12/3/1992 Updated by:AL 04/08/14 • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-17RD 50-733-20168-01 181-023 10/6/15 10/6/15 Daily Operations: 10/06/15 -Tuesday Shut-in ESP. Rig up pumping equipment. Pressure test to 2,000 psi. Fill wellbore with 191 bbls FIW. Pump 1320 gallons preflush (330 gallons Baker Petrolite WAW-5206 mixed with 990 gallons Xylene) @ 1.5 bpm, 500 psi max tubing pressure. Pump 107 bbls 15% HCL acid @ 1.5 bpm, 500 psi max tubing pressure. Displace with 100 bbls FIW @ 1.4 bpm, 1,200 psi max tubing pressure. Shut-in well for 4 hour soak. Return to production. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Ir-fi DATE: 10/20/15 P. I. Supervisor FROM: Brian Bixby SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit D-17RD Hilcorp Alaska LLC PTD 1810230 10/20/2015: I traveled to the Trading Bay Unit Dolly Varden Platform with Johnnie Hill to witness a no-flow test on Well D-17RD. This well is a packerless ESP completion. Upon arrival we met with Jon Loomis and John Lee. We discussed escape route if needed and what was happing on the platform. We listened in on their safety meeting prior to heading to the wellhead. I observed the well rigged up as follows: - Tubing and tubing-casing (inner) annulus were piped to be in communication prior to the no-flow test measuring equipment. I verified the Master, Swab and IA Valves to be fully opened; - Pressure and flow measurement devices have recent calibrations; - Flow from the meter outlet transitioned back to a 1-inch bleed hose which terminated in barrel outside. The following table shows test details: Time Pressures' Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 10:20 0/0/195 0 0 Verify all valves open on WellHead and test equipment 10:25 0/0/195 0 0 Closed valve down stream of test gauge to monitor for 1 hr 10:55 0/0/195 0 0 View Gauges 11:25 0/0/195 0 0 Open Valve to flow meter, Gas unmeasurable 11:30 0/0/195 . 0 0 Closed valve down stream of test gauge to monitor for 1 hr 12:00 0/0/195 0 0 View Gauges 12:30 0/0/195 0 0 Open Valve to flow meter, Gas unmeasurable 13:00 0/0/195 0 0 Closed valve down stream of test gauge to monitor for 1 hr 13:30 0/0/195 0 0 Open Valve to flow meter, Gas unmeasurable 1 Pressures are T/IA/OA Summary: TBU D-17RD exhibited the characteristics for a no-flow determination Attachments: Photos (2); Test Procedure; Well Schematic; Test Measures Calibrations 2015-1020 No-Flow TBU D-17RD bb.docx Page 1 of 2 SCANNED AUG 2 2 2016 • • No-Flow Test— TBU D-17RD (PTD 1810230) Photos by AOGCC Inspector B. Bixby 10/20/2015 kT`"' F -nk*wrs, *l- R V .. Ove$ I { f: Y h« F. ,amu may. tr s.- awe+$ Ari ',k t i ' � ' . '' Flow meter .r 1114115-- ."'''' - - .7:4111=, Illiffir . r. �, ... am '4, rrniiiiviar � t v aid 41 w ��K i{egg A Test gauges attached on swab valve 1 IF 1 a,. 1 111« j Ili '..":._ a ry 2015-1020 No-Flow TBU D-17RD bb.docx Page 2 of 2 S D-17RD No Flow procedures D-17RD is an ESP completion with no packer to the 9 5/8"casing Shut down the ESP pump Close the SSV(isolation from production) Bleed down the tubing and inner 9 5/8" casing Verify the C-section valves are open to have tubing/casing communication Rig up no flow equipment as suggest in Appendix A in AOGCC guidelines with calibrated gauge with 1 psi divisions and calibrated no flow meter If valve has been open! Close valve for 1 hour and record the pressure Open gauge and record flow meter volume, record time it takes to bleed off 1st time Close valve for 1 hour and record the pressure Open gauge and record flow meter volume, record time it takes to bleed off 2nd time Close valve for 1 hour and record the pressure Open gauge and record flow meter volume, record time it takes to bleed off 3rd time Close valve Test is complete. 0 • McArthur River Field,TBU Well:D-17RD C PTD:Last om llet d: 03/08/2014 • IIH.ikorp Akaaka,LLC API: 50-733-20168-01 RKB to TBG Head=41.05' Tree Connection:4-1/6",5,0004 CASING DETAIL. 1 lb.. SIZE WT GRADE CONN ID TOP BTM. 13 318" 13-3/8" 61 K-55 Butt.LT&C 12.515 Surf 2,497 9-5/8" 40 N-$0 Butt 8.$35 Surf 4011' 9-5/8" 43.5 N-80 Butt 8.755 4011' 5498' 9-5/8" 47 N-80 Butt 8.681 5498' 7025' 9-5/8" 47 S-95 8rd 8:681 7025' 8145' 7" 32 N-80 Butt _ 6.094 7,849' 7884' 7" 29 N-80 Butt 6.184 7884' 9523' 7" 32 N-80 Butt 6.094 9523' _ 10,800' TUBING DETAIL 3-1/2" 9.2 L-80 Supermax Surf 7,611' JEWELRY DETAIL Depth Depth No Item (MD) (TVD) ID 1 41.05' 41.05' Tubing Hanger 2 7,611' 7,065' Bolt on Discharge 3 7,613' 7,067' Pump-SG7300(x 4) 4 7,690' 7,141' Intake 2 5 7,710' 7,160' Motor-(x 2) 3 6 7,774' 7,220' Bottom of ESP 9-5/8" j'AL 4 i 7 7,872' 7,316` 4.00 7"26-32#Hydraulic Permanent Packer 8 7,880' 7,324 3.958 4.5"12.6#Hydril 503 5 9 9,421' 8,790' 3.958 Swell Packer MO 6 ( 10 9,440' 8,807 4:000 Wireline Re-entry Guide - 7 Casing Damage ' 9320-9340 FISH/FILL INFO 1. FILL Tagged w/a 2.65"GR on 9/25/96 @ 10,122'WLM 10 FISH: OM-1 Arm&(3)Springs 4/8/95 10,126'WLM G-2 17'Strip Gun 8/23/90 10,533'WLM _-,G-3 22'Strip Gun 6/29/92 10,538'WLM G4 _ G5 = G6 PERFORATION DETAIL Zone Top(MD) Btm(MD) 1 Top(ND) Btm(TVD) Amt SPF Perf Date 4K-1 0-2 9,596' 9,628' I 8,952' 8,982' 32' 6 02/27/14 G-3 9,658' 9,673' 9,010' 9,024' 15' 6 02/27/14 HK-2 G-4 9,701' 9,735' 9,050' 9,082' 34' 6 02/27/14 QHK-3 G-4 9,794' 9,798' 9,137' 9,141' 4' 6 02/27/14 G-5 9,854' 9,859' 9,193' 9,198' 5' 6 02/27/14 G-5 9,882' 9,890' 9,219' 9,227' 8' 6 02/27/14 41<-4 0-5 9,924' 9,935' 9,259' 9,269' 11' ( 6 02/27/14 ; '. 6-6 9,965' 9,969' 9,297' 9;301' 4' 6 02/27/14 e ??: HK-5 HK-1 10,052' 10,081' 9,378' 9,405' 29' 36 11/21/1992 : HK-2 10,096' 10,120' 9,419' 9,442' 24' 18 7/27/1992 HK-2 10,178' 10,192' 9,496' 9,509' 14' 4 2/2/1987 ." � HK-3 10,214' 10,232' 9,530' 9,547' 18' 12 11/29/1992 HK-4 10,260' 10,292' 9,573' 9,603' 32' 8 1/30/1987 TD=10,800'PBTO=10,676' HK-4 10,330' 10,380' 9,638' 9,685' 50' 28 11/29/1992 Max Angle=27°,KOP @ 600' HK-5 10,405' 10,490' 9,709' 9,788' 85' 20 12/3/1992 Updated by:iLL 04/08/14 . . "440 1 N a c HI a ;-1: CD on 6 C --1 gi) ..., za -- 0) n 61 '44 a cl s. = <3 = a n . m073 0 C6 CD a 11 Z tir) el,LC Cil 0 0 a) CD. 0 TOQ 11) 01 0 st) -01 2.4 11) 0) 0.. = 0 _ 5- 5: 0 -. z i•-4* CD 11:3 0-' ,../. 0 z " 0 C„ SI) < a 0 ET --p,• "It -- c 3 °.-....t = ....1 Z0 F,-; 0 0 Iii .`< F = , = :7_4. 03 0 .... 0 7.7.44 c... ,p- - < 0 al 0 CD %ti 01 —. ctl = cZe ...4 tt• F • 5' 1 N1/4 co ••• co SD ,- = ..4- = tiall7a 0 0 0. 5 0 co .A., 0 "1 c 0 ,s., il) ,,,. ,•• 5. u.) co c° 73 = 01 Z (10 ill ev,Z C C q Tali* tn Si i..)‘•; • .0. ... et - 0. ...I a` C C 0 20 SI) CP 0.0 9,. 2 o CI- n ft CO = 13) 0 o•-0 2) = — 0-1. aco 0 .... of) -1 6, p • • HLCORP CALIBRATION CFRTIRCATF. Test Equiphient Traceable to NIST Pressure range: — 4--k 1'7!,mber: ,; Date: --\LAk TEST PRESSURE INDICATiON 7 r ; I . ,•.C1 ,--- _ Test equipment SiN: I This cerfficate expires in .90 d ys on For recertification, contact Gina Bogart or Cathy Marsha!! at KGF 776-6825. •• voFa� • �<"\�\ i//7,- ",,s,\ A THE STATE Alaska Oil and Gas / •:" of .LASKA. Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 (34-'ALASI43' Fax: 907.276.7542 �� N0\ 22M5 www.aogcc.alaska.gov L Dan Marlowe Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G and Hemlock Oil Pools, TBU D-17RD Sundry Number: 315-576 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, coniticvic, Cathy P. Foerster Chair 1/1 DATED thiai day of September, 2015 RBDM 5& 2 5 2015 Encl. • 0RECEIVED • STATE OF ALASKA SEP 1 8 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate 0(Acid) Alter Casing ❑ Change Approved Program ❑ Plug for Redril El Perforate New Pool ❑ Repair Well El Re-enter Susp Well ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development 0' 181-023 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20168-01 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 Trading Bay Unit/D-17RD 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 McArthur River Field/Middle Kenai G&Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): - 10,800 . 10,077 1 10,122 - 9,444 N/A 10,126', 10,533'&10,538' Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,497' 13-3/8" 2,497' 2,404' 3,090 psi 1,540 psi Intermediate Production 8,145' 9-5/8" 8,145' 7,579' 5,750 psi 3,090 psi Liner 2,951' 7" 10,800' 10,077' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 3-1/2" 9.2#/L-80 7,611 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Hyd Perm Packer,Swell Packer&N/A d 7,872'(MD)7,316'(ND)/9,421'(MD)8,790'(ND)&N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ welopment 0' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/2/2015 OIL 0 • WINJ ❑ WDSP❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOO SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarloweehilcorp.com Printed Name Dan Marlowe Title Operations Engineer Peet-r `las"l.i' F'1G Signature./ 6' � - Phone (907)283-1329 Date 9/18/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 316 '' S/Le ' -ic.. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: /0 6`'f APPROVED BY Approved b : Q�nJ t.-' ( YCOMMISSIONER THE COMMISSION Date: (a-r I 1✓ ORIGINAL A orA��3 1 r"Submit Form and SEtt�� 5 Form 10-403 Revised 5/2015 Approved application i ''.. �� - r611S'the dat xoff approval. �� Attachments in Duplicate • • Well Work Plan Well: D-17rd llileorp Alaska,LL Date:09/17/2015 Well Name: D-17rd API Number: 50-733-20168-01 Current Status: ESP Lifted Producer Leg: A-2 (NW Corner) Estimated Start Date: 10/2/15 Rig: N/A Reg. Approval Req'd? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 181-023 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Current Bottom Hole Pressure: 2,535 psi @ 7,220' TVD ESP Intake Gauge SIBHP Maximum Expected BHP: 2,535 psi @ 7,220' TVD (ESP intake Gauge). Well SIBP of 4,535 psi plus 2000 psi pump pressure. Max. Anticipated Surface Pressure: 000 psi treatment pump pressure limit .i CASI 54-` '�t /5 PS 4, - O(Lt)O • Well Summary Jr The D-17rd is an oil well producer which is currently on ESP artificial lift. Total fluid production from this well has declined since the March 2014 work over. This decrease is believed to have been caused by scale formation in the well bore and perforation tunnels. Well Objective Hilcorp plans to pump an acid soak down the production tubing and across the perforations to clean up any scale deposition. Procedure: 1. MIRU pumping equipment. 2. Shut down ESP. 3. Pressure test surface lines to 2,000 psi (treatment pump relief valve limit). 4. Mix chemicals and pump in the following sequence: a. Open back side, pump FIW down tubing taking returns up the annulus. Pump 1320 gallons of pre-flush (330 gallons WAW-5206 mutual solvent blended with 990 gallons of Xylene. ?,y -c. Pump up to 4,500 gallons of±15% Hydrochloric Acid closing the 9-5/8" casing return line after the first 2.5_1:01s and bullhead the chemical pills across the perfs with >_100 barrels of FIW for displacement. 3, 5. Shut down pump and let acid soak for >_4 hours. 6. RD Pumping equipment. 7. Return well to production. 8. Schedule a No-Flow test within 14 days of stable production. 3th 6`'6)- 00/ Attachments: 1. As-built Schematic oo�2' • ti McArthur River Field,TBU 110 Well: D-17RD SCHEMATIC Last Completed: 03/08/2014 PTD: 181-023 Ililcorp Alaska,LLC API: 50-733-20168-01 RKB to TBG Head=41.05' Tree Connection:4-1/6",5,000# CASING DETAIL 1 SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 13-3/8" • 61 K-55 Butt.LT&C 12.515 Surf 2,497' 91 5/8" 40 N-80 Butt 8.835 Surf 4011' 9 5/8" 43.5 N-80 Butt 8.755 4011' 5498' 9-5/8" 47 N-80 Butt 8.681 5498' 7025' 9-5/8" 47 S-95 8rd 8.681 7025' 8145' 7" 32 N-80 Butt 6.094 7,849' 7884' 7" 29 N-80 Butt 6.184 7884' 9523' 7" 32 N-80 Butt 6.094 9523' 10,800' TUBING DETAIL 3-1/2" 9.2 L-80 Supermax Surf 7,611' JEWELRY DETAIL No Depth Depth (MD) (TVD) ID Item 1 41.05' 41.05' Tubing Hanger 2 7,611' 7,065' Bolt on Discharge 3 7,613' 7,067' Pump-SG7300(x 4) 4 7,690' 7,141' Intake a2 5 7,710' 7,160' Motor-(x 2) H 3 6 7,774'8 '/ 7,220' Bottom of ESP 9-5/8" 4 7,316' 4.00 7"26-32#Hydraulic Permanent Packer I- 6 8 7,880' 7,324' 3.958 4.5"12.68 Hydril 503 9 9,421' 8,790' 3.958 Swell Packer 10 9,440' 8,807' 4.000 Wireline Re-entry Guide . 7 Casing 7 Damage 8 /L'L-'t > 9320-9340 Mi 9 FISH/FILL INFO FILL:Tagged w/a 2.65"GR on 9/25/96 @ 10,122'WLM 10 FISH: OM-1 Arm&(3)Springs 4/8/95 10,126'WLM G-2 17'Strip Gun 8/23/90 10,533'WLM G-3 22'Strip Gun 6/29/92 10,538'WLM G-4 G-5 '--- - G-6 PERFORATION DETAIL 3V S6✓ Zone Top(MD) _ Btm(MD) Top(ND) Btm(TVD) Amt SPF Pert Date c G-2 9,596' 9,628' 8,952' 8,982' 32' 6 02/27/14 HK-1 G-3 9,658' 9,673' 9,010' 9,024' 15' 6 02/27/14 - HK-2 G-4 9,701' 9,735' 9,050' 9,082' 34' 6 02/27/14 ' '72.- HK-3 G-4 9,794' 9,798' 9,137' 9,141' 4' 6 02/27/14 G-5 9,854' 9,859' 9,193' 9,198' 5' 6 02/27/14 G-5 9,882' 9,890' 9,219' 9,227' 8' 6 02/27/14 HK-4 G-5 9,924' 9,935' 9,259' 9,269' 11' 6 02/27/14 G-6 9,965' 9,969' 9,297' 9,301' 4' 6 02/27/14 'i W : HK-5 HK-1 10,052' 10,081' 9,378' 9,405' 29' 36 11/21/1992 HK-2 10,096' 10,120' 9,419' 9,442' 24' 18 7/27/1992 HK-2 10,178' 10,192' 9,496' 9,509' 14' 4 2/2/1987 .`, ' \ HK-3 10,214' 10,232' 9,530' 9,547' 18' 12 11/29/1992 HK-4 10,260' 10,292' 9,573' 9,603' 32' 8 1/30/1987 TD=10,800'PBTD=10,676' HK-4 10,330' 10,380' 9,638' 9,685' 50' 28 11/29/1992 Max Angle=27°,KOP @ 600' HK-5 10,405' 10,490' 9,709' 9,788' 85' 20 12/3/1992 Updated by:JLL 04/08/14 XHVZE Ima~:~roject Well History File Coveri~Ige This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizing RESCAN Well History File Identifier DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: BY: [] Other, No/Type BEVERLY ROBIN VINCENT~~MARIA WINDY Project Proofing BY: ~~~i~OBIN VINCENT SHERYL MARIA WINDY Scanning Preparation z x 30 = . BY: BEVERLY ROBIN~HERYL MARIA .WINDY Production Scanning Stage I PAGE COLI NT FROM SCANNED FILE: BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THIS POINT UNLE88 SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAY$CALE OR COLOR IMAGES) Other items scannable by large scanner OVERSIZED (Non-Scannable) [] [] DATE'~,~/~ / Logs of various kinds Other ~si Isl TOTAL PAGES PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: / YES BEVER V, NO NT S.ERYL MA.,A W,NDY °ATE: IF NO IN STAGE t, PAGE(S) DISCREPANCIES WERE FOUND: YES BEVERLY ROBIN VINCEN~ MARIA WINDY NO NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12/10/02Rev3NOTScanned.wpd STATE OF ALASKA , ALS;._ A OIL AND GAS CONSERVATION COMMIaSION / .°r. • REPORT OF SUNDRY WELL OPERATIONS `- r 1.Operations Abandon 0 Repair Well 0 Plug Perforations 0 Perforate❑ Other❑ Install ESP Performed: Alter Casing❑ Pull TubingE Stimulate-Frac 0 Waiver 0 Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development❑l Exploratory 0 181-023 i 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20168-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 Trading Bay Unit/D-17RD . ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Hemlock Oil Pool 11.Present Well Condition Summary: Total Depth measured . 10,800 feet Plugs measured N/A feet true vertical 10,077 feet Junk measured 10,126', 10,533'&feet 10.538' Effective Depth measured ' 10,122 feet Packer measured 7,872&9,421 feet true vertical 9,444 feet true vertical 7,316&8,790 feet Casing Length Size MD ND Burst Collapse Structural Conductor Surface 2,497' 13-3/8" 2,497' 2,404' 3,090 psi 1,540 psi Intermediate 8,145' 9-5/8" 8,145' 7,579' 5,750 psi 3,090 psi Production Liner 2,951' 7" 10,800' 10,077' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet SCANNED JUL :i 6 2014 True Vertical depth See Schematic feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 7,611'(MD) 7,065'(ND) Hyd Perm.Packer 7,872'(MD)7,316'(ND) Packers and SSSV(type,measured and true vertical depth) Swell Packer 9,421'(MD)8,790'(ND) SSSV:N/A 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDMA MAY 14 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 27 163 879 440 252 Subsequent to operation: 149 13 6363 122 142 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development0 a Service ❑ Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil, El Gas [] WDSPL❑ GSTOR 0 WINJ 0 WAG ❑ GINJ 0 SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-549 Contact Dan Marlowe Email dmarlowe@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature ft-- Phone (907)283-1329 Date 4/8/2014 Form 10-404 Revised 10/2012 7 - 5/2 V f y ~ Submit Original Only McArthur River Field,TBU Well: D-17RD • fli SCHEMATIC Last Completed: 03/08/2014 PTD: 181-023 Hilearn Alaska,LLC API: 50-733-20168-01 RKB to TBG Head=41.05' Tree Connection:4-1/6",5,000# CASING DETAIL 1 SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 13 3/8" 61 K-55 Butt.LT&C 12.515 Surf2,497' 9-5/8" 40 N-80 Butt 8.835 Surf 4011' 9-5/8" 43.5 N-80 Butt 8.755 4011' 5498' 9-5/8" 47 N-80 Butt 8.681 5498' 7025' 9-5/8" 47 S-95 8rd 8.681 7025' 8145' 7" 32 N-80 Butt 6.094 7,849' 7884' 7" 29 N-80 Butt 6.184 7884' 9523' 7" 32 N-80 Butt 6.094 9523' 10,800' TUBING DETAIL 3-1/2" 9.2 L-80 Supermax Surf 7,611' JEWELRY DETAIL Top Depth No (MD) ID Item 1 41.05 Tubing Hanger _ 2 7,611' Bolt on Discharge 3 7,613' Pump-SG7300(x 4) 2 4 7,690' Intake 11 3 5 7,710' Motor-(x 2) • 9-5/8" 4 66y 7,774' Bottom of ESP 5 G.7%" 7,872' 4.00 7"26-32#Hydraulic Permanent Packer 6 8 7,880' 3.958 4.5"12.6#Hydril 503 111 ■ G). 9,421' 3.958 Swell Packer 7 (,, 174 �°� 10 9,440' 4.000 Wireline Re-entry Guide Casing Damage A 8 9320 9340 9 SL Cif p�tiI 1 ,Y - FISH/FILL INFO FILL:Tagged w/a 2.65"GR on 9/25/96 @ 10,122'WLM 10 FISH: OM-1 Arm&(3)Springs 4/8/95 10,126'WLM G-2 17'Strip Gun 8/23/90 10,533'WLM -G-3 22'Strip Gun 6/29/92 10,538'WLM - G-4 G-5 - G-6 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(TVD) Amt SPF Perf Date HK-1 G-2 9,596' 9,628' 8,952' 8,982' 32' 6 02/27/14 G-3 9,658' 9,673' 9,010' 9,024' 15' 6 02/27/14 44� HK-2 G-4 9,701' 9,735' 9,050' 9,082' 34' 6 02/27/14 6b--44, G-4 9,794' 9,798' 9,137' 9,141' 4' 6 02/27/14 HK-3 G-5 9,854' 9,859' 9,193' 9,198' 5' 6 02/27/14 4~ $fHK-4 41 G-5 9,882' 9,890' 9,219' 9,227 8' 6 02/27/14 ' G-5 9,924' 9,935' 9,259' 9,269' 11' 6 02/27/14 " >.it G-6 9,965' 9,969' 9,297' 9,301' 4' 6 02/27/14 M.. 1 $.0: •,, HK-5 HK-1 10,052' 10,081' 9,378' 9,405' 29' 36 11/21/1992 aJ HK-2 10,096' 10,120' 9,419' 9,442' 24' 18 7/27/1992 ' x a HK-2 10,178' 10,192' 9,496' 9,509' 14' 4 2/2/1987 *• ti 4..!.` \ HK-3 10,214' 10,232' 9,530' 9,547' 18' 12 11/29/1992 / HK-4 10,260' 10,292' 9,573' 9,603' 32' 8 1/30/1987 TD=10,800'PBTD=10,676' HK-4 10,330' 10,380' 9,638' 9,685' 50' 28 11/29/1992 Max Angle=27°,KOP @ 600' HK-5 10,405' 10,490' 9,709' 9,788' 85' 20 12/3/1992 Updated by:JLL 04/08/14 Hilcorp Alaska, LLC HikoipAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-17RD 50-733-20168-01 181-023 1/18/2014 3/8/2014 Daily Opetatia =- tlr �s 01/18/14-Saturday Rigging up. 01/19/14-Sunday Continued N/U BOP's,choke&kill lines,installed Koomey lines and functioned rams.R/U test equipment&test BOP'Pipe Rams Hydril,manifolds G choke and kill lines&safety valves to 250 psi low/2500 psi high on chart for 5 mins each with 3-1/2"&4-1/2"tbg. All test done from main controls, 1i,cP remote functioned.Witness of test waived by Jim Regg,AOGCC. R/D test joint. Install 2 way check and test blind rams to 250 psi low/2500 psi high. X51/ Pull 2 way check,back out hgr hold down pins.Clean rig floor.P/U Power Swivel.M/U and replace connections on hydraulic lines&repair control box air line connections&torque gauge lines for same. 01/20/14-Monday Continue repairing hoses and connections on power swivel&test run same.M/U power swivel to landing jt,pull hanger up 1'out of hanger spool, rotate pipe to the right with 4 to 5 k torque while working pipe,attempting to release hanger with out success.R/D power swivel. R/U e-line. MU and test lubricator to 2500 psi,RIH with chemical cutter and tagged at 7,850'ELM. Unable to work deeper.POOH&reduced tension on centralizer, ran in hole and worked cutter from 7,850'to 8,060'unable to get deeper.P/U and cut tbg at 8,020'ELM. POOH with e-line.Cut made with 15k over pull on tbg.Pulled hanger to surface,attempted to circulate well clean with 120 bbls of FIW w/o success while rigging down e-line. Broke out and laid out hanger and landing jts.Performed general maintenance while taking on 3-1/2"PH-6 work string from MV Resolution.POOH B/O&L/0 4-1/2 IBT production tbg and GLM strapping and checking same for NORM.Total fluid lost to well in past 24 hrs=38 bbls. At 06:00 4,500'of tbg&2 GLM laid out. 01/21/14-Tuesday Service rig and continue POOH with 4-1/2"production tbg&GLM's. L/0 same. Rig down 4-1/2"handling tools and rig up 3-1/2"handling tools. Continue out of hole with 3-1/2"production tbg.Total tbg recovered=245 jts 4-1/2",8 jts 3-1/2",1 cut jt of 3-1/2",12 GLM's,total length=8,015'. Clean rig floor,BOP area and pipe rack.Lay out and strap BHA#1. Install pollution pan under rig floor.PU and MU landing jt for wear bushing and install same.L/0 landing jt. R/U 4-3/4"handling tools&started picking up BHA#1.PU&MU BHA#1-5-3/4"over shot with 3-1/2"grapple,bumper &oil jar,(4)4-3/4"drill collars,accelerator jar,3-1/2"PH-6 box X 3-1/2"IF pin x-over,total length=159.28'. RIH with BHA#1 picking up 3-1/2"PH- 6 work string from rack,strapping ad rabbiting same. Depth at report time=2,910'.48 bbls fluid lost to formation in last 24 hrs. Total fluid lost to formation=80 bbls. 01/22/14-Wednesday Service rig and hold JSA picking up tbg from v-door.Continue in hole with BHA#1 picking up 3-1/2"PH-6 tbg from V-Door to 8,000'.RU circulating head and lines to tbg.Rigged up to take returns to well clean tank. Circulate 620 bbls until returns clean at 3 BPM sending returns to well clean tank. R/D circulating head.Ran in hole to 8,022'DPM and tagged top of fish.P/U&R/U power swivel,sat down ilk on fish and attempted to rotate anchor latch and seal out of packer without success.R/U e-line and ran in hole with 2.14"OD gauge ring to 8,184'ELM and tagged up. Unable to work gauge ring deeper. POOH with e-line. Talked to Engineer and decided not to cut tbg at 8,184'.R/D e-line.P/U 150 ton elevators performed derrick inspection&prep to jar on fish. Jar on fish with 40 to 80k over P/U wt. attempting to break seals free from packer bore. Rotate pipe with 3-5k torque,pulled fish up hole 15'. POOH with 3-1/2"PH-6 work string and BHA#1 w/20-50 K drag for the first 350'. 24 hr fluid loss=48 bbls.Total fluid lost to formation=136 bbls. 01/23/14-Thursday Continue POOH with 3-1/2"PH-6 work and BHA#1 to surface.B/O&L/0 over shot and 1 cut jt of 3-1/2"tbg. Continue POOH.B/0&L/O 3-1/2" production tbg and GLM's. Recovered 1 cut jt&33 jts of 3-1/2"IBT tbg,3 GLM's&1 anchor latch seal assy.Total length=1,247'.Wash down rig floor.Prep burning shoe assy. Slip&cut 93'of drill line.Calibrate block HMI,set Crown-O-Matic,crown saver&rig floor saver&test same. P/U& M/U 5-3/4"burning shoe BHA#2. RIH with same. Swap handling equipment to 3-1/2". BHA#2=5.3/4"burning shoe,bumper&oil jar,(4)-4-3/4" drill collars,acc jar,3-1/2"PH-6 box x 3-1/2"IF pin x-over total length=159.28'.Continue in hole with BHA#2&3-1/2"PH-6 work string to top of liner @ 7,849'.Install 11"X 7-1/16"DSA and stripping head. 14 Hilcorp Alaska, LLC HikorpAlaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-17RD 50-733-20168-01 181-023 1/18/2014 3/8/2014 Daily Operations 1,114AdidIMISIAC 01/24/14-Friday Service rig. N/U 11"X 7-1/16"adapter spool and stripping head.Center up BOP stack. Continue RIH with BHA#2&3-1/2"PH-6. Set crown&floor saver,upper&lower limits.P/U 3-1/2"PH-6 out of V door,continue in hole checking for fill to 9,012'.R/U circulating equipment&Reverse circ @ 3 bpm 500 psi pumped 95 bbls until returns clean. Getting scale back in returns.P/U and M/U power swivel.Wash down in reverse from 9,043'to 9,263' pumping @ 3 bpm 260 psi. RD&LO power swivel. L/O a single&start out of hole.24 hr fluid loss=18 bbls. Total fluid loss=154 bbls. 01/25/14-Saturday Service rig.Continue POOH with 3-1/2"PH-6 work string&BHA#2,using mud bucket due to pipe being plugged. Last stand of 3-1/2"PH-6,4 DC's& jars plugged with sand and large chunks of scale,washed out each jt at rig floor and racked back in derrick. Cleaned rig floor. ND pollution pans&7- 1/16"x 11"DSA. Pull wear bushing. MU test plug and land same. R/U BOP testing equipment. Test BOP rams,safety valve,manifolds,&chokes to 250 psi low/2500 psi high on chart for 5 mins.-2-Failures,Hydril&valve#8 on circulating manifold,functioned both and retested ok.Witness waived by Jim Regg on 1/24/14. Install wear bushing. NU 11"X 7-1/16"DSA.Install pollution pans. Clean rig floor. P/U and MU 3-1/2"mule shoe. RIH with 3-1/2"mule shoe.24 hr.fluid loss=10 bbls. Total fluid loss to formation=164. 01/26/14-Sunday Continued in hole to 9,209'DPM with 3-1/2"work string.Installed stripping head&rubber.M/U circulating head&equipment.Wash down while reversing from 9,209'to 9,279'DPM,pumping @ 3-1/2 BPM,500 psi,circulated bottoms up at every connection. Shut down pumps,lined up to displace well with FIW sending returns to Trading Bay. Pumped a total of 840 bbls. RID circulating head&POOH with 3-1/2"PH-6 work string& mule. P/U&M/U BHA#3=5-3/4"burning shoe,bumper&oil jar,(4)-4-3/4"drill collars,3-1/2 PH-6 box x 3-1/2"IF pin x-over total length= 151.812'.R/U circulating head and pumped thru BHA to make sure it was not plugged.R/D circulating head and RIH with BHA#3 and 3-1/2"PH-6 work string. 01/27/14-Monday Continued in the hole with BHA#3 to 9,263'.P/U and M/U power swivel&install stripping rubber.Rotate and wash down from 9,263'to 9,279'DPM, pumping 2-1/2 bpm,220 psi,80 rpm,6-7k torque. Mill on packer pumping 2-1/2 bpm.220 psi,80 rpm,6-7k torque 5-10k down on mill.Total footage made=1'. R/D power swivel.POOH w/3-1/2"PH-6 work string.Change out hyd hose on tongs.Continue POOH with 3-1/2"PH-6 work string.B/O and L/0&inspect shoe/shoe about 40%worn.Part of top seal bore 8-1/2"long hung in shoe,also had part of the left hand square threads in shoe. P/U and M/U new shoe.RIH with BHA#4,5.94 OD x 4"ID burning shoe,bumper and oil jars,(4)-4-3/4"drill collars 3-1/2"ph-6 x 3- 1/2"if xover,total length=151.92'. 24 hr fluid loss=-10. Total fluid loss to well=174 bbls. 01/28/14-Tuesday SERVICE RIG AND SAFETY COMPLIANCE CHECK.CONT TIH W/3-1/2"PH6&BURNING SHOE BHA TO 9,263'DPM. P/U,M/U AND R/U POWER SWIVEL.MAKE CONNECTION.TIH &TAG FISH @ 9,280'DPM.START MILLING ON PKR @ 3BPM,325 PSI. RPM=80,WOB=4-SK,TORQUE=6-7K.PKR FREE,PUSH PACKER DOWN HOLE 15'TO 9,295'.REVERSE OUT @ 3BPM,300 PSI UNTIL RETURNS CLEAN.TOTAL PUMPED=150 BBLS. MONITOR WELL WHILE R/D POWER SWIVEL AND L/D SAME(WELL TAKING 2 BBLS PER HR.)POOH W/3-1/2"PH6 AND BHA#3. B/O and L/0 burning shoe,30% worn,P/U and M/U BHA#5---5-3/4"overshot,with 4"grapple,bumper and oil jars,(4)4-3/4"drill collars,3-1/2 PH-6 box X 3-1/2 IF pin x-over. Total length=146.67'.RIH with BHA#5 to 9,295'DPM and latched packer mandrel with 5 k down on fish.P/U wt=125k, S/O 96k. P/U and jarred on fish 4 times with 40k over P/U wt(165K)fished moved and hung up,jarred on fish with 30K over P/U fish moved up hole 4'hung again jarred with 40K over fish came loose. Continue POOH with fish jarring it thru each casing collar with 20 to 25K over PU wt. Depth at 06:00= 8,600'. 24 hr fluid loss 40 bbls. Total fluid loss=238 bbls. Hilcorp Alaska, LLC flavor])AIa.ka, Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-17RD 50-733-20168-01 181-023 1/18/2014 3/8/2014 Daily Operations: 01/29/14-Wednesday Continue POOH with BHA#5 and SAB-3 packer body and tail pipe.100%of fish recovered.SAB-3 packer body,3-1/2 pup,x-.nipple w/I guide=22.62'. P/U&M/U BHA#6- 5.97 OD wave shoe,(5) 5-1/2"wash pipe,bumper&oil jars,(4)drill collars x-over,total length=304.87'. RIH to 9,318'DPM& tagged.P/U&M/U power swivel and attempted to mill down thru tight spot at 9,318'w/o success.RPM 80,3bpm,275 psi,each time weight applied (1k-2K down)pipe would torque out and pump would increase to 400 to 500 psi. 01/30/14-Thursday Service Rig.Perform safety meeting. Rig down power swivel stripper rubber from Halls Head.Install wiper rubber&slip plate. Pooh w/3.5 W/S.Lay out jars, rack back 2 stds wash pipe. B/O shoe,L/O single jt washpipe. Clear and clean rig floor.Make up BHA#7 W/5.50 JUNK MILL,5.969 STRING MILL,BIT SUB,BUMPER JAR,OIL JAR,(4)4-3/4" DRILL COLLARS,X/0 SUB. Trip in hole w/workstring. R/u power swivel. Make up connection,brk circ,81 spm,3 bpm,430 psi,5500 to 7k torque,wob 2 t/5k tagged up at 9,319'dpm.Milling f/9,319'to 9,325'dpm. Reverse circ at 2 to 3.5 bpm, having to stop and blow down line due to plugging off. 01/31/14-Friday Service rig.Held JSA and prejob meeting.Rig down power swivel.Circ thru surface lines,blow down surface lines. Pooh to inspect mills. Continue to pooh to BHA. Pooh w/BHA drk and lay down mill and string mill. M/U 5.97"OD X-bar,BHA=(5.97X BAR mill,JAR,OILJAR,(4)4-3/4" DRILL COLLARS, X/O SUB=147.10')TIH to 9,321'. Rigging up power swivel,Brk Circ wash down to 9,323'dpm at 3 bpm,81,300 so.5 to 6 k on bit,80 rpm.Return line plugged off. P/U off btm&clean out surface lines.Continue to mill to 9,332'.Reverse circ 1 tbg 2000 stks 728 psi. Make connection,brk cir,rev at 3 bpm,81 spm,5 to 6k torq,wob"0". Milling f/9,332'to 9,335'. 02/01/14-Saturday Continue milling f/9,335'dpm to 9,478'dpm-80 spm,400 psi,5300 torq,1-2 wob. Tbg plugging off. Circ down.Continue milling f/9,478'dpm to 9,539'dpm -80 spm,400 psi,5300 torq,1-2 wob. Tagging top of fish at 9,539'. Reverse circ 3 tbg volumes at 4 bpm 700 psi. Rigging down power swivel. Pooh(had tight spot at 8,568'dpm)22k over pull up and 14k down. Fluid lost for 24 hrs-30 bbls with 22 lbs metal off magnets. 02/02/14-Sunday Pooh w/mills. Brk out and lay down mills(30%)worn. Unbolt and remove stripper head f/stack. Pull wear bushing and rig up to test Bop's w/3.5 pipe. Test BOP'S and related surface equipment to 250 psi low and 3000 psi high.Mr.Jim Regg with AOGCC waived witness on 1-31-14 at 513 pm. Finish cleaning fluid pits and filling same.Rigging down test assembly. Install wear bushing. R/U pack off head&adapter spool.P/U BHA- 6"string mill. BHA#9 W/5.50 JUNK MILL,5.969 STRING MILL,BIT SUB,BUMPER JAR,OIL JAR,(4)4-3/4" DRILL COLLARS,X/O SUB=152.31'.Trip in hole w/ 3.5 ph 6 work string 8,563'.Rigging up power swivel,milling on tight spot at 8,568'. 02/03/14-Monday Held JSA.Rig down power swivel and remove stripper rubber.Continue TIH tagged obstruction at 9,329'dpm,set 10k down on same,unable to work past.P/u power swivel.Ream up and down thru tight spot at 9,329'dpm several times until clear while reverse circ at 2.5 bpm 280 psi.Continue RIH picking up singles f/v door on power swivel tagged TOF at 9,539',no fill.Reverse circ one tbg volume at 9,539'dpm at 3 bpm 330 psi w/very little back on btm up.Rig down power swivel and remove stripper rubber.POOH.Had 2k over pull at 9,329'dpm&no over pull at 8,568'dpm.Continue POOH. Brk down BHA 6"string mill and 5.5 junk mill.Slip and cut drill line 107'.Reset limits function C.O.M.w/drill line.P/u BHA 5.5' wash pipe rotary shoe 5.5 KHT conn,5 jts 5.5 WP 5.5 KHT conn,top bushing,bumper jar,oil jar,(4)4-3/4"drill collars x/o sub=306.511.Trip in hole w/3.5" work string tagged up at 9,329'dpm unable to work past same. 02/04/14-Tuesday Service rig.Held prejob meeting.Continue 5.5 Wash pipe(BHA- rotary shoe 5.5 KHT conn,5 jts 5.5 WP 5.5 KHT conn,top bushing,bumper jar,oil jar,(4)4-3/4"drill collars x/o sub=306.51')on 3.5"work string Tagging up at 9,329' D.P.M. Attempt to work thru tight spot unable to work thru. POOH w/3.5"DP. Rack back WP assembly. P/u BHA#W/5.50 JUNK MILL,5.969 STRING MILL,BIT SUB,BUMPER JAR,OIL JAR,(4)4-3/4" DRILL COLLARS,X/O SUB=152.31'.TIH w/assembly on 3.5"work string. Rig up power swivel and pack off. Dress off tight spot at 9,329'dpm,80 rpm,5 to 7 k torque able to work thru tight spot. Continue TIH making connection on power swivel tag TOF t 9,539'. P/u 1 jt off fish and circ out the long way at 2.5 bbls per min 260 psi. Pumped total of 1000 bbls. R/D power swivel and pack off. Hilcorp Alaska, LLC Llikorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-17RD 50-733-20168-01 181-023 1/18/2014 3/8/2014 Daily Operations: 02/05/14-Wednesday Held pre job meeting and JSA.Pooh w/3.5 work string.Lay down mills and make up mule shoe.Trip in hole to 9,311'. Rigging up E-line sheaves in derrick space out pipe. RIH with down hole camera on 1-11 16"tool strin: takin:video an. .i - . . ..• .i - .• • 9,311'to 9,455'-sat--- down at 9,455'on a ball of metal,pick back up to the bad spot at 9,327'and Pooh w/E-line and set aside. Pooh w/work string f/9,311'to 8,558'. Rigging up E-line-RIH W/1-11/16"down hole camera. 02/06/14-Thursday Running EV down hole camera inspecting 7"csg at 8,558'to 8,750',did not see any damaged pipe at this depth_Rig down E-line and set aside. Pooh w/3.5 work string.Remove E-line sheave from crown. Pooh w/3.5 work string L/d mule shoe. P/up BHA (5.97 XBar mill,bumper jar,oil jar,(4)4- 3/4"drill collars,x/o 147.08'.)Mill Assembly trip in hole to 2,313'. Pick up power swivel,Brk circ,at 67 spm 2.5 bpm 170 psi,continue in hole slow f/ 9,313'to 9,341'without tagging anything at this depth. Pick up back thru same did not have any over pulls.Blow down lines. Continue in hole making connections on power,unable to keep hyd hoses from getting wrapped around swivel due to winds blowing 60+mph. WOW. Circ hole clean. 02/07/14-Friday Waiting on weather due to high winds.P/u pipe f/v-door f/9,478'to 9,539' dpm tagged top of fish at 9,539'set 2k down on same.Milling f/9,539' to 9,543'dpm 80 rpm,6 to 7k torque,3 bpm,130 psi,3 to 8k wob. Pipe stuck at 9,543'dpm hit jars 8 times f/160 to 180k pull free at 180k. Change out pack off rubber. Continue milling f/9,543'to 9,548' dpm,pack rubber leaking. Change out pack off rubber.Continue to mill -made"0"footage pressuring up each time mill tagging btm,mill looks to be cored. Rigging down power swivel. Pooh laying singles.Had no over pulls coming thru spot at 9,329'. Recovered 85 lbs metal off magnets,lost 50 bbls to formation. 02/08/14-Saturday POOH w/workstring lay down mill. Cont POOH w/3.5"ph-6 work string. POOH LD BHA.Mill cored,had impression of rope socket in center of mill. Made up 2 jts wash pipe and shoe.TIH making up BHA(RTY shoe,(2)5-1/2"wash pipe,Top Bushing,Bumper jar,it jar,(4) 4-3/4"drill collars x/o= 214.05'. TIH w/BHA#13 tag tight spot at 9,329",set 10k do on same unable to work past. Pick up power swivel and pack off. Brk reverse circ at 3 bpm,250 psi,set down 2k turn p/s 1/4 turn weight falling off,continue to work down having to turn p/s 1/4 turn for 5 ft.then able to slack off having 3 to 5k down drag for 60 ft,then back to normal down drag. Continue in hole picking up single on power swivel tagging TOF at 9,548'dpm,Brk circ at 81 spm,285 psi.Washing over f/9,548' to 9,606'pumping at 81 spm,300 psi,80 prm,6 to 7k torq,wob"0", the last 2 ft.f/9,606'to 9,608' had very erratic torque but"0"wob.Circ hole clean,had a lot of scale,sand&small pieces of coal coming back over shaker. Rig down power swivel and pack off. POOH w/3.5"ph 6 DP and wash pipe had 7 to 8k over pull coming thru tight spot. Recovered 70 lbs of metal&lost 60 bbls fluid to formation. 02/09/14-Sunday Pre job meeting&JSA. Continue POOH to BHA. Work BHA-shoe 30%worn. Pull wear bushing.Rig up test equipment and fill stack.Perform shell test on BOP's. AOGCC inspector, Mr.Jones arrived at location at 1330 hrs,witnessed shell test and the testing on the H2S&Methane alarms all OK. Mr.Jones suspended testing of BOP's and issued a 3 item work list 1)clean oil from BOP stack,2)Install strobe light so it would be visible from the Drillers console 3)Turn target tee on choke line at choke manifold. Mr.Jones departed location at 1530 hrs.Installing strobe light on rig floor and cleaning rig floor and BOP's,turned target tee on choke manifold,change out tarps around BOP's cleaning decks. Hole to 12.5 bbls in 12 hrs. 02/10/14-Monday Continue working on the work list issued by Mr.Jeff Jones.Remounted strobe light on derrick beam and cleaning deck below BOP's.AOGCC Inspector,Mr.Jeff Jones arrived at 1130 hrs&witnessed testing of BOPS&related surface equipment 250 psi low and 3000 psi high.Test made from remote station,tested the added strobe lights and alarms on H2S&Methane System-All Pass. Had 1 failed pass on choke manifold(greased and function same-Ok).Lower Kelly valve failed to test,tested Koomey unit&pit alarms passed. Received lower Kelly valve from Granite Point Platform, installed on power swivel,failed to test,broke and laid out same. Installed rental valve-failed to test,break out same. Waiting on rental valve to arrive from town. Hilcorp Alaska, LLC HMMrorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-17RD 50-733-20168-01 181-023 1/18/2014 3/8/2014 Daily Operations: ;111 11i 02/11/14-Tuesday Continue change out lower Kelly valve on power swivel.Rig up and test power swivel lower Kelly valve to 250 low and 3000 psi high.Sent E-mails and made phone call to inform AOGCC inspector Mr.Jeff Jones on completing the test on the lower Kelly valve.Received verbal approval from Mr.Jeff Jones At 08:45 hrs to continue with our fishing ops. Rig down test equipment.Install DSA and LD jars.PU new jars and MU on 5.5"wash pipe assy and 5.97"OD rty shoe BHA=5.97'. RTY Piranha shoe,3 jts 5.5"wash pipe,top bushing,bumper jar,oil jar,(4)4-3/4"drill collar,xo sub=248.58'. Trip in hole w/work string,tagged spot in casing at 9,329'with 10k wt dropped. Continue running in hole thru spot in casing with 2 to 3k extra down drag,once past spot,had normal drag.Tagged TOF at 9,548'.Pick up power swivel and brk circ.Wash&ream f/TOF F/9,548'to 9,608'w/2/3k wob, 60 rpm,at 4900 ft/lbs-reverse circ at 3 bpm 300 psi with small amount of sand back shaker while W&R to bottom. Wash&Ream f/9,608'to 9,615' very firm, getting small amounts of scale back in shaker. Broke thru and wash and ream f/9,615'to 9,621'with no problems. Reverse circ a tbg volume getting back sand and scale,making connection. 02/12/14-Wednesday Continue washing and reaming to 9,643'dpm.Circ well clean.R/D Power swivel and R/d lines. L/D 3 jts&pooh w/3.5"work string.Work BHA/lay down shoe-100%worn out. P/U 5-5/8" outside mechanical cutter,3 jts wash pipe,washpipe drive sub,x/o=102.68. TIH w/3.5 work string to 9,528'.P/up power swivel. Work over top of fish 9,548'dpm,rotate down slowly to 9,641'.P/u locate collar and shear dogs. Make cut on fish at 9,633'dpm 60 rpm,5200 ft/lbs pumping 1 bpm. R/d power swivel.Pooh w/3.5"ph6 work string. 02/13/14-Thursday Pooh w/cutter assembly (5-5/8 outside mechanical cutter,3 jts wash pipe,washpipe drive sub,x/o=102.68). Work BHA,(cut and Lay out 83.18 ft of 3.5 buttress production tbg.)continue to work BHA. M/U BHA (Ocean wave 5.5 shoe,4 jts 5.5 wash pipe,drive sub,bumper jars,oil jar,4 4.75 drill collars,x/o=278.03). Trip in hole with work string to 9,606'.P/u power swivel.Wash over f/9,631'to 9,735'circ at 3 bpm 300 psi,80 rpm,3500 to 5500k torq,1/2k wob. Continue to wash over f/9,735'to 9,745',Est top of fish 9,631 ft./181 ft from GLV&290 ft from packer.Hole took 25 bbls of FIW 60 3 metal off magnets. 02/14/14-Friday Continue to wash over fish f/9,745'to 9,759',Cir hole clean. Rig down power swivel.POOH to BHA.Work BHA(5.625 mechanical cutter,4 jts 5.5 wash pipe,drive sub,x/o=133.31).Make up cutter (5.625 mechanical cutter,4 jts 5.5 wash pipe,drive sub,x/o=133.31). WOW(high winds 75 mph+).Trip in hole w/cutter assembly,2-3k drag at spot in csg at 9,329'dpm. Continue in hole to 9,622'dpm normal drag. R/u power swivel. Work over top of fish at 9,631'dpm,continue in hole rotating slow,tagged btm at 9,759'dpm. P/u up and locate collar,sheared cutter w/10 over. Made cut on 3.5 buttress production tbg at 9,758'dpm. Rig down power swivel.POOH. 02/15/14-Saturday POOH w/3.5 work string. Work BHA. Lay down 125.21 ft of 3.5 buttress production tubing.Tubing in good shape but plug w/oil and sand.Clean rig floor and installed hand rail around the tbg set back area.M/u new BHA(Ocean wave 5.5 shoe,3 jts 5.5 wash pipe,drive sub,bumper jars,oil jar,4 4.75 drill collars,x/o=247.72).Trip in hole to 9,736'dpm,had 6 to 8k drag at tight spot at 9,329'.P/up power swivel and pack off. Washing over fish f/9,736'rev circ at 3 bpm,300 psi,wob"0"w/2700 ft lbs of torq tag GLM at 9,802'dpm,Circ hole clean at 3 bpm 395 psi had sand and scale back at shaker.R/d power swivel.POOH w/work string. 02/16/14-Sunday Continue to POOH. Work BHA,lay out burning shoe. Slip and cut 107 ft of drill line.Reset and test C-O-M. Make up new BHA 19(overshot/3.50 nominal catch basket grapple,bumper jar,oil jar,4 drill collars,slinger jar,x.o=162.94).Trip in hole w/work string to 9,746'. Rig up pump in sub and Kelly hose. Tag top of fish at 9,758'dpm,circ at 370 psi,81 spm,set 20 k down.P/u bleed jars,picked up to 210k in stages monitoring wt,5 minutes each time,weight dropped off to 134k. Continue picking up to next tool jt w/10k drag over normal p/u. Rigging down Kelly hose and L/D 4 jts of Ph6 w/s. POOH w/ph-6 work string. Hilcorp Alaska, LLC Hi!cog) Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-17RD 50-733-20168-01 181-023 1/18/2014 3/8/2014 Daily Operations: r }hp i " i �,� 9 ids�u 02/17/14-Monday Continue to POOH w/3.5 workstring.Work BHA,lay down 175.59 ft of tbg,seals,nipples,glm,wig,shuck fish from overshot. Make up BHA(Rotary shoe packer type,wash pipe ext,drive sub,bumper jar,oil jar,(4)4-3/4"drill collars,x/o=176.18').TIH.Rig up power swivel,and pack off. Reverse circ at 4 bpm,55 psi,rot at 80 rpm,3500 torq,3 bpm 81 psi 2 t/5k wob.Made total 26"over packer-not making any more hole. 02/18/14-Tuesday Held JSA.Rigging down power swivel.Monitor well while service crown hole taking 1.5 bbls p/hr.POOH w/3.5 work string.Change out brake band on power tongs.Continue POOH w/work string. Change out dies on power tongs.Continue POOH w/work string.POOH w/BHA.Pull wear bushing.Rig up to test BOP's,Test BOP's and related surface equipment to 250 low and 3000 psi high.Test made with water,held each test 5 minutes.Witness was waived by Mr.Jim Regg with AOGCC. Rig down test equipment and rig up dsa and stripper head. Make up BHA#21-Ocean wave shoe,wash pipe,Drive sub,bumper jar,oil jar,drill collar,slinger jar,x/o=175.20'.Trip in hole with workstring. 02/19/14-Wednesday Held safety meeting and JSA.Continue TIH w/finger basket and burning shoe BHA#21 Ocean wave shoe,wash pipe extension,drive sub,bumper jar, oil jar,4 4-3/4 drill collars.x/o=175.20'.Rig up power swivel,make connection&install stripper rubber.Brk circ,rotate&wash down at 5 bpm 510 psi,60 rpm 3/4k torq. Tagged at 9,910'dpm work up and down several times,attempting to clean junk from top of packer,reverse circ until)return are clean.Rig down&Lay out power swivel. Pooh w/3.5 workstring.Work bha(only had small piece of junk in finger basket). Pick up BHA#22 Packer shoe w/piranha cut,Wp extension,drive sub,Bumper shoe,oil jar,4 4-3/4 drill collars,x/o=176.15'.Trip in hole w/work string to 9,888'. Pick up power swivel.Milling on packer. 80 bbls total bbls fluid lost 1039 bbls. 02/20/14-Thursday CONT MILL ON PKR FROM 9,912'DPM,PUMPING 3 BPM 350 PSI,RPM=40-45,TORQ=5-6K,WOB=5K.PKR FREE at 9,914'DPM. P/U SINGLES OUT OF V- DOOR&CONTINUE ROTATE AND PUSH PACKER DOWN HOLE TO 9,934'DPM.UNABLE TO GET DEEPER DUE TO PIPE TRYING TO PLUG AND TORQUING UP.CIRCULATE BTMS UP @ 5 BPM 650 PSI. MONITOR WELL W/BLOWING DOWN CIRCULATING LINES AND RIGGING DOWN POWER SWIVEL.WELL TAKING 3 BPH. POOH W/3-1/2"PH6 AND BURNING SHOE BHA. SERVICE RIG. CONT'TO POOH W/3 1/2"PH6 DP&BURNING SHOE / BHA. B/O&L/0 BHA#22 FOUND SHOE 30%WORN. P/U 5.75"OVERSHOT,W/4.50"GRAPPLE&GRAPPLE CONTROL 4-3/4"DRILL COLLARS&JARS BHA#23=167.25'. RIH WITH BHA#23. FLUID LOSS FOR LAST 24 HRS=85 BBLS TOTLA FLUID LOSS=1124 BBLS 02/21/14-Friday SERVICE RIG AND SAFETY COMPLIANCE CHECK.BREAK CIRCULATION,ROTATE DOWN AND TAG PKR @ 9,934'DPM.SHUT DOWN PUMP AND LATCH FISH.SET DOWN 30K,P/U TO 8K OVER TO VERIFY FISH LATCHED.BLOW DOWN CICULATING LINES.RIG DOWN AND LAY DOWN POWER SWIVEL. POOH,SLOW W/3-1/2 PH6,OVERSHOT BHA AND FISH.BREAK DOWN BHA AND LAYDOWN FISH.FULL RECOVERY-PACKER BODY,SEALBORE EXT, BELL GUIDE. WASH AND CLEAN RIG FLOOR.PREP RIG FLOOR TO TIH W/MILL ASSY.M/U BHA#24--5.50"BLADED JUNK MILL,5.69"STRING MILL, JARS AND(4)4-3/4"DRILL COLLARS.RIH W/3 1/2"PH6 DP T/9,910'.R/D WIPER/SLIP PLATE&AIR SLIPS.P/U POWER SWIVEL&R/U SAME.P/U SINGLE JT OF DP OUT OF V-DOOR&INSTALLED RUBBER IN STRIPPING HEAD.BROKE CIRC REVERSE CIRCULATING @ 3 1/2 BPM WI 340 PSI. RECORDED DRILLING PERIMETERS.P/U=107K,S/O=106K WHILE ROTATING.R/W=106 W/3500 FT/LBS TORQ @ 81 RPM.ROTATED DWN T/9,942' DPM,MADE CONNECTION&ESTABLISHED CIRC RATE.ATTEMPTED TO WASH/MILL WHILE REVERSE CIRC&PLUGGED OFF.L/U&CIRC DOWN TBG TO UN-PLUG PIPE.ESTABLISHED CIRC RATE OF 4 BPM W/500 PSI THE LONG WAY.WASH/MILLED F/9,942'-T/1,020'DPM IN 16'(1/2 A JT) INCREMENTS.THEN L/U&REVERSE CIRC 100-120 BBLS(BTMS UP+AMOUNT CIRC LONG WAY)OR UNTIL RETURNS CLEANED.Total fluid lost in last 24 hrs=50 bbls.Total looses=1174 bbls. Hilcorp Alaska, LLC Hihorp Alaska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-17RD 50-733-20168-01 181(-023 1/18/2014 3/8/2014 Daily Operations: 02/22/14-Saturday CONT ROTATE AND WASH DOWN F/10,036'-10,122'DPM,PUMPING 3-1/2 BPM,380 PSI.WASHING DOWN THE LONG WAY AND REV/OUT 1 TBG VOL OR UNTIL RETURNS CLEAN.UNABLE TO GET DEEPER DUE TO BHA TORQING UP AND STICKING.HAD TO PULL 40 TO 50K OVER P/U WT TO GET FREE 6 TIMES. P/U TO 10,100',REV/OUT AND CLEAN UP WELL @ 2-1/2 BPM 200 PSI UNTIL RETURNS CLEAN. BLOW DOWN CIRCULATING LINES.R/D AND LAY DOWN POWER SWIVEL.POOH W/3-1/2 PH6 AND MILL ASSY BHA.B/O&L/0 SAME.MILL,FOUND 5-1/2"JUNK MLL 50%WORN,OUTSIDE EDGES OF CUTTING SURFACE TAPPERED IN INDICATING POSSIBLE COLLAPSED CASING.CLEANED/CLEARED RIG FLOOR,DISASSEMBLED&REPAIRED VALVE ON CIRC MANIFOLD,&CLEANED SUCTION SCREEN ON PUMP,P/U BHA 26----5.50"BLADED JUNK MILL,OIL&BUMPER JARS,4 3/4"DC BHA LENGTH=163.10'.RIH WITH 3-1/2"PH-6 TBG AND MILLING BHA TO 10,092'. P/U POWER SWIVEL,FLUID LOST IN LAST 24 HRS=162 BBLS.TOTAL FLUID LOST TO FORMATION=1346 BBLS. 02/23/14-Sunday Service rig and continue rigging up power swivel,make connection,wash and rotate down to 10,122'pumping at 3 bpm,350 psi.Tagged up and unable to get deeper due to torquing up and sticking. P/U to 10,100'and attempted to rev out and pipe plugged.Attempted break plug w/o success. R/D power swivel and pooh to 9,490'. Shut down generator,mechanic adjusted valves,repaired hyd block on drillers console,cleaned and repaired all valves on circulating manifold. Continue pooh with 3-1/2 PH-6 tbg slow.B/O and L/O drill collars,jars and mill,found same plugged with rocks up to 1"in size. Clean rig floor&R/ll E-line. Test lubricator to 1000 psi and hold JSA on running a-line and caliber tools. RIH with Expro 2.750"caliber tool to 9,300'.Log casing from 9,270'to surface. 02/24/14-Monday Cotinued logging to surface with casing caliber. R/D a-line and RIH to 10,060'with mule shoe and 3-1/2"PH-6 working string,rabbiting pipe to 10,060'.R/U lines to displace well with FIW with all returns going to Trading Bay. Displace well with FIW pumped a total of 1283 bbls. R/D lines and RIH from 10,060'to 10,117'and tagged fill.PU to 10,113'and pumped 50 bbls at 1 bpm.R/D lines and pull up to 9,995'. R/U a-line. PU bottom and side view camera&ran hole with same.Fuild was clear down to 4,800',at 4900'fluid was black due to oil feeding in,continued in hole while pumping down tbg and cleaned up fluid in tbg.Fluid lost last 24 hrs 63 bbls.Total fluid loss=1447 bbls. 02/25/14-Tuesday CONTINUE RIH W/E-LINE&CAMERA TO 9,995'ELM.UNABLE TO SEE W/CAMERA DUE TO DIRTY FLIUD.POOH W/ELINE AND R/D SAME.P/U 3-1/2" PH6 OUT OF V-DOOR AND CONT TIH TAG @1,010'DPM. R/U E-LINE AND RIH W/CAMERA,CIRCRULATE DOWN TBG @1BPM 45 PSI AND ATTEMPT TO SEE THRU FLUID W/CAMERA.NO SUCCESS.POOH W/E-LINE AND R/D SAME. M/U KELLY JT&BREAK CIRC.REVERSE WASH DOWN F/10,103'TO 10,115' @2BPM 90 PSI.PIPE PLUGGING OFF. R/D KELLY JT AND POOH 200'ABOVE PERFS.MONITOR WELL FOR 1 HR. TIH W/3-1/2 PH6 AND MULE SHOE TAG @ 10,100'DPM. APPROX 21'OF FILL TO TD(10,121'DPM). POOH W/3-1/2"PH 6 AND MULE SHOE.N/D CIRCULATING HEAD AND DSA. P/U 3 1/2"TEST JNT&WEAR BUSHING R/R TOOL.PULL WEAR BUSHING&M/U TEST PLUG.RIH&SET SAME.R/U BOP TESTING EQUIP.TEST 11"X 5M BOPS&SURFACE VALVES AS PER A.O.G.C.0&HILCORP SPECS 250 LOW/2500 HIGH ON CHART,TESTED W/3 1/2"PH6 DP. WITNESS OF TEST WAIVED BY JIM REGG,AOGCC.POOH&L/D TEST PLUG.P/U WEAR BUSHING.RIH&SET SAME.L/D TEST ASSY.AND R/D EQUIP. Fluid lost last 24 hrs =102 bbls. Total fluid loss=1549 bbls. 02/26/14-Wednesday SERVICE RIG AND SAFETY COMPLIANCE CHECK.CONT GENRAL RIG MAINTENANCE AND HOUSE KEEPING.M/U 373',4.50",5 SPF TCP ASSY ASPER EXPRO REP(18 GUNS TOTAL LOADED AND BLANKS).TIH W/3-1/2"PH-6 AND TCP ASSY DRIFTING PIPE OUT OF DERRICK. R/U E-LINE EQUIP. P/U 1- 11/16"CCL/CORRELATING TOOL&RIH W/SAME T/9,516'&LOGGED UP T/9,457'WLM.POOH W/E-LINE. P/U(1)JNT OF 3 1/2"DP&SLACKED OFF 30'. R/U E-LINE&RIH W/SAME TO CORRELATE DEPTH.POOH W/E-LINE.POOH 97'(1 STND+1 SINGLE)TOP OF BHA @ 9,486',BTM OF BHA @ 9,975' .---. DPM.R/U E-LINE&RIH W/1-11/16"CCL TO CORRELATE DEPTH.LATCH ONTO PIPE AND P/U 5'TO PUT GUNS ON DEPTH (RA SUB @ 9,487'WLM). I C. r POOH W/E-LINE&R/D SAME.PREP TO DROP BAR&FIRE TCP GUNS Hilcorp Alaska, LLC HiieorpAla ka,Lt.( Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-17RD 50-733-20168-01 181-023 1/18/2014 3/8/2014 Daily Operations: 02/27/14-Thursday CONT POOH WI E-LINE.UNABLE TO R/D SHEAVE IN DERRICK DUE TO CRANE BEING DOWN.TIE E-LINE CABLES OUT OF WAY IN DERRCIK.DROP BAR &FIRE GUNS-PERFORATE F/9,596'-9,969'ELM @ 5SPF MONITOR WELL FOR 10 MINS.WELL STATIC.R/D CIRCULATING EQUIPMENT&POOH ABOVE PERFS W/GUNS TO 9,347'DPM. MONITOR WELL WHILE R/D E-LINE SHEAVE OUT OF DERRICK.(WELL TAKING 7 BBLS HR). CONT POOH W/3-1/2" PH6 AND TCP ASSY.C/O PHE AND LAY DOWN TCP ASSY.P/U 7"26-32#HYDR.PERM.PKR&5"TIE BACK SLEEVE&TIH W/SAME ON 3 1/2"PH6 DP TO 8,591'DPM. SET 4K DWN @ 8,591'DPM. ATTEMPT TO P/U(+5K-8K)WINO SUCCESS.(ORG.WT 102K P/U,74K S/O). R/U CIRC EQUIP ON W/S. L/U &BROKE CIRC DWN B/S.REVERSE CIRCULATED 16 BBLS @ 1-3/4 BPM W/40 PSI.S/D&ATTEMPT TO PULL W/NO SUCCESS(+20K).L/U&PUMPED 10 BBLS DWN TBG @ 1-1/2 BPM 45 PSI.ATTEMPT TO PULL W/NO SUCCESS(+25K).S/D PUMP WORKED PIPE DWN(-5K)&P/U TO 132K(+30K)& PIPE PULLED FREE. ATTEMPT TO S/0 BUT TAGGED AT SAME DEPTH OF 8,591'DPM(PKR DEPTH=8,573'DPM).P/U TO CHK FOR OVERPULL. R/D CIRC EQUIP FROM W/S.POOH W/3 1/2"DP&PKR ASSY.Fluid lost in last 24 hrs 170 bbls.Total fluid lost to formation=1769 bbls. 02/28/14-Friday SERVICE RIG.CONT TO POOH W/3-1/2 PH6,PKR ASSY&TIE BACK SLEEVE.B/0 AND L/0. FOUND OD X-OVER BETWEEN TIE BACK SLEEVE AND PACKER TO BE 6.05"(DIRIFT OF CSG=5.97")SENT TO TOWN FOR REPAIRS.CLEAR ALL MISC EQUIPMENT FROM RIG FLOOR.R/U SPOOL TO ROLL UP DRILL LINE FROM DWKS,SPOT NEW DRILL LINE SPOOL IN PLACE AND RIG UP SNAKE TO OLD DRILL LINE&REVIEWED JSA.STRING UP BLOCK W/NEW DRILL LINE. ROLL UP OLD DRILL LINE ON SPOOL,CALIBRATE DRWKS,RE-SET C-O-M AND TEST RUN DWRKS.RE-SET CROWN/FLOOR SAVERS,C.O.M., &TESTED SAME.TEST RUN DWKS TO ENSURE DRILL LINE SPOOLED CORRECTLY ON DRUM.P/U(4)JNTS OF 4-3/4"DC'S&R/B SAME WHILE WAITING ON STRING MILL TO ARRIVE ON HELICOPTER.P/U 5.50"JUNK MILL,(2)5.969"WATERMELLON/STRING MILL BHA&TIH WI SAME TO 7,837'DPM TOTAL BHA LENGTH=170.15'. POOH&L/D 880'DPM(14 STNDS).TIH W/3-1/2"DP&BHA TO 8,556'DPM. P/U POWER SWIVEL&R/U SAME. CHANGE OUT 3-1/2"IF BOX X 3-1/2"PH-6 PIN X/O SUB.TOTAL FLUID LOST PAST 24 GRS=150 BBLS. 03/01/14-Saturday CONTINUED IN HOLE AND FOUND TIGHT SPOT AT 8,570'. PUSHED TANDEM MILLS THRU TIGHT SPOT FROM 8,570'TO 8,576'.PULLED BACK UP TO 8,565'STARTED ROTATING AT 60 RPM WHILE PUMPING AT 2 BPM,55 PSI,TORQUE=2600 TO 2800 FT/LBS. WORKED STRING MILLS FROM 8,565'TO 8,580'SEVERAL TIMES,STARTING TORQUE=3000 TO 5500 FT/LBS,FINAL TORQUE=2600 TO 2900 FT/LBS. CONTINUED FROM 8,602'TO 9,329' WITH OUT ROTATING. FROM 9,329'TO 9,339'NEED 5 K TO SLIDE THRU HOLE IN CASING.WORKED MILL THRU HOLE UNTIL DRAG=2-3K, CONTINUED IN HOLE TO 9,596'W/O ANY PROBLEMS. REVERSE BOTTOMS UP AT 3 BPM 115 PSI. R/D POWER SWIVEL. POOH WITH 3-1/2"WORK STRING AND L/0 BHA. CLEAN RIG FLOOR AND PREPARE TO P/U PACKER. P/U&M/U PERM PKR ASSY AND RIH WITH SAME ON 3-1/2"PH-6 WORK STRING,DEPTH AT 06:00=9,200'. 03/02/14-Sunday CONT TIH SLOW W/7"26-24 PERM PKR.TAG @9,331'WITH PACKER.SET DOWN 10K,NO SUCCESS. P/U TO 17K OVER,ATTEMPTED TO WORK PACKER THRU HOLE IN CASING SEVERAL TIMES W/O SUCCESS. POOH SLOW TO TOP OF LINER PACKER DRAGGING 5K OVER FOR THE FIRST 250'. CONTINUED OUT OF HOLE B/0,L/0 AND CLEANING 3-1/2"PH-6 WORK STRING. B/0&L/O PACKER ASSY.M/U 3-1/2"PH-6 MULE SHOE AND RIH WITH 49 SIDS OF 3-1/2"PH-6 WORK STRING. POOH B/0&L/0 WORK STRING&CLEAN SAME.FLUID LOST IN 24 HRS=100 BBLS.TOTAL FLUID LOST=1900 BBLS. 03/03/14-Monday SERVICE RIG. CONT POOH W/3-1/2 PH6 WORK STRING AND LAYDOWN SAME.WASH OIL RESIDUE FROM INSIDE AND OUTSIDE OF PIPE.RIH W/ DRILL COLLARS OUT OF DERRICK.POOH&B/0,L/0 SAME. STRAP 3-1/2 SUPER MAX PROD TBG.DRIFT SAME AND RIH WITH 236 JTS (7,820'). POOH WITH 3-1/2 PROD TBG. Hilcorp Alaska, LLC H►4.orpA►uska,LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-17RD 50-733-20168-01 181-023 1/18/2014 3/8/2014 Dai ratio „„e��1�1i�6N5, ��' � o �ii�i7-'1= �i 3 iii 'I�IOi 03/04/14-Tuesday SERVICE RIG AND CONT POOH W/3-1/2"SUPERMAX PROD TBG.RACKING BACK IN DERRICK. REMOVE 11"X 7-1/16"5M ADAPTER AND STRIPPER HEAD.P/U POWER SWIVEL&C/O KELLY VALVE.L/D SAME.PULL WEAR BUSING,SET TEST PLUG AND R/U BOP TEST EQUIPMENT.TEST 11' X 5M BOPS,RISER AND SURFACE EQUIPMENT AS PER HILCORP AND AOGCC SPECS,250 LOW/2500 HIGH ON CHART DATED 3-4-2014.SEE CHART AND DETAIL SHEET FOR INDIVIDUAL TEST.WITNESS OF TEST WAIVED BY JIM REGG,AOGCC.TEST FROM REMOTE&FUNCTION MAIN.PULLED TEST PLUG &L/D TEST ASSY.R/D TEST EQUIP.N/U 11"SPOOL ON RISER.SWAP ALL PHE TO 4-1/2"&PREP TO P/U PKR ASSY. P/U 4-1/2"SWELLABLE PKR ASSY &(51)JNTS OF 4-1/2"HYDRIL 503 CSG OUT OF V-DOOR&TIH W/SAME STRAPPED&DRIFTED EACH JNT.P/U&ASSIST SERVICE REP RE-INSTALL SEAL NIPPLE&ON/OFF TOOL IN 9-5/8"RETRIVABLE PKR.&SWAP TO 3-1/2"PH.CONT TO TIH W/3-1/2"SUPERMAX PROD TBG OUT OF DERRICK. FLUID LOST LASR 24 HRS=100 BBLS. TOTAL FLUID LOST 2000 BBLS. 03/05/14-Wednesday SERVICE RIG AND SAFETY CHECK.CONT TIH W/3-1/2"SUPER MAX TBG AND PKR ASSY.SLOW AS PER TRI-POINT REP.TAG UP W/3K DOWN EOT @ 5,915'DPM.BTM OF PKR.@ 4,291'DPM. TOP OF PKR @ 4,282'DPM. P/U TO 50K OVER&PULLED FREE. POOH SLOW W/3-1/2"SUPER MAX TBG TO TRI-POINT 9-5/8"PACKER &LAY OUT SAME. FOUND PACKER LOWER SLIPS SHEARED AND IN RELEASE POSITION.CONTINUE OUT OF HOLE WITH 4-1/2"LINER&INSPECT 4-1/2"SWELLABLE PKR AND REMOVE BALL SEAT FROM PUMP OUT PLUG.RIH WITH 4-1/2"SWELLABLE PKR,4-1/2" HYDRIL 503 ISOLATION TBG,7"PERM.PACKER&3-1/2"SUPER MAX TBG. R/U CIRC EQUIP&PUMPED 5 BBLS OF DIESEL AND CHASED IT W/95 BBLS OF 8.6 FIW @ 1-1/2 BPM W/100 PSI TO SPOT DIESEL ON BACKSIDE AROUND SWELLABLE PKR.R/D CIRC EQUIP&P/U POWER SWIVEL.DROPPED 1-7/16" BALL IN TBG&M/U POWER SWIVEL TO TBG.P/U TO SETTING DEPTH.TOP 7"PERM PKR @ 7,872'DPM&BTM SWELLABLE PKR @ 9,420'DPM_LLU& PRESSURE UP ON TBG TO SET 7"PERM PKR.WITH 3000 PSI,PUSH ON PACKER WITH 10K DOWN,PULL ON PACKER WITH 20K OVER P/U WT.L/U MANIFOLD TO PUMP DOWN CASING AND TESTED PKR TO 1500 PSI ON CHART FOR 30 MIN. RELEASE SETTING TOOL FROM PACKER PULL 1 JT AND R/D POWER SWIVEL. 03/06/14-Thursday SERVICE RIG. MONITOR WELL WHILE FINISH R/D AND LAY DOWN POWER SWIVEL.WELL TAKING 3.5 BPH.POOH W/3-1/2"SUPER MAX TBG AND PACKER RUNNING TOOL.L/D RUNNING TOOL.CLEAR RIG FLOOR OF ALL UNECESSARY EQUIPMENT AND WASH SAME. R/U SUMMIT ESP EQUIPMENT AND HANG SHEAVES IN DERRICK. P/U AND MAKE UP SUMMIT ESP EQUIPMENT. SPLICE ELECTRIC POWER CORD.TESTED THE ELECTRICAL INTEGRITY OF THE MOTORS&POWER&INSTALLED CLAMPS ON SAME.P/U(1)STND OF 3-1/2"SUPERMAX PROD TBG&M/U TO ESP.SPLICE CONTROL LINE TEST CHEMICAL LINES&FLATPACK T/2500 PSI&RE-TESTED ELECTRICAL INTEGRITY OF MOTORS,&POWER CORD.RIH WITH 3-1/2"SUPER-MAX TBG AND SUMMIT ESP. FLUID LOSS FOR PAST 24 HRS=36 BBLS.TOTAL FLUID LOSS=2200 BBLS. 03/07/14-Friday SERVICE RIG AND CONT RIH W/ESP PUMP,3-1/2"SUPERMAX TBG.,FLAT PACK CTRL LINE&ARMOUR COATED ELECTRICAL CABLE.SUMMIT REP TESTING ELECTRICAL CABLE EVERY 1,000'.TO 4,079'. SUMMIT REP MAKE SPLICE IN ELECTRICAL SPLICE IN CABLE AND TEST SAME"OK".CONT RIH W/ESP PUMP,3-1/2"SUPERMAX TBG.,FLAT PACK CTRL LINE&ARMOUR COATED ELECTRICAL CABLE.SUMMIT REP TESTING ELECTRICAL CABLE EVERY 1,000'.TO 4,200'. CONT RIH W/ESP PUMP,3-1/2"SUPERMAX TBG.,FLAT PACK CTRL LINE&ARMOUR COATED ELECTRICAL CABLE.SUMMIT �J" REP TESTING ELECTRICAL CABLE EVERY 500'.TO 7,766'. L/D(1)JNT OF 3-1/2"TBG.P/U&MAKE UP 11"HANGER&4-1/2"LANDING JT. ORIENTATE HANGER&ASSIST SUMMIT ESP REPS&CAMERON REP SPLICE ELECTRICAL CABLE/CONTROL LINES THRU HANGER. PRESSURE UP ON CONTROL LINES TO 2500 PSI.CONNECT UMBILICAL CORD&PREP TO LAND SAME.FLUID LOSS PAST 24 HRS=80 BBLS.TOTAL FLUID LOST TO WELL=2280 BBLS. Hilcorp Alaska, LLC Hilcorp AIJk.I,LL( Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-17RD 50-733-20168-01 181-023 1/18/2014 3/8/2014 G x 111 51 P M1 til 7 pii 1i 03/08/14-Saturday CONTINUE ASSSIT SUMMIT AND CAMERON REP CONNECT ELECTRICAL CABLE AND DUAL CTRL LINE INTO HGR PUTTING BOTTOM OF PUMP @ 7,772' &TOP OF PUMP @ 7,611'. NOTE:HAD TO CHANGE OUT PENATROTOR CONNECTION DUE TO SETTING DOWN ON SAME WHILE SLACKING OFF PIPE. CAMERON REP RAN IN HGR PINS.R/D SUMMIT ESP RUNNING EQUIP&REMOVE SHEAVES FROM DERRICK.CLEAR ALL MISC EQUIPMENT FROM RIG FLOOR. REMOVE DECK PLATE AND BEAMS FROM RIG FLOOR.BLEED OFF KOOMEY LINES AND PREP RIG FLOOR TO NIPPLE DOWN BOPS. UNSECURE STACK,REMOVE KOOMEY LINES&N/D 11"X 5M BOPS,RISER'S ABOVE ANNULAR.N/D 11"X 5 M HYDRIL,11"X 5M CAMERON DBL BOP. CONT'TO N/D CHOKE/KILL VALVES F/DRILLING SPOOL.N/D RISER F/WELL HEAD&SET ON PIPE RACK.ASSIST CAMERON REP PREP CONTROL LINES&ESP CABLE FOR PROD TREE. N/U PRODUCTION TREE.PULL B.P.V.&SET 2-WAY CHECK VALVE.R/U TEST PUMP&TESTED VOID&SECONDARY SEALS TO 250 PSI LOW&5000 PSI HIGH.TESTED TREE TO 250 PSI LOW/3250 PSI HIGH.PREP TO SKID RIG. R/D MISC HYDRALIC HOSES,ELECTRICAL WIRES, TARPS,&HEATERS AROUND RIG TO PREPARE FOR RIG SKID.MOVED/SET CHOKE MANIFOLD IN PLACE.RE-LOCATED DRILL LINE SPOOL&OTHER MISC RIG EQUIPMENT.SECURED MISC HOSES/WIRES&PREP TO R/D&MOVE COMPRESSOR/DOG HOUSE.N/D 18"SPOOL F/RISER. v w,, �j��s� THE STATE - Alaska Oil and Gas � ®f SJ(A Conservation Commission I' GOVERNOR SEAN PARNELL 333 West Seventh Avenue *h: OF o. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 H�� No\' X2413 Dan Marlowe Operations Manager � I � 2 .Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, Trading Bay Unit/D-17RD Sundry Number: 313-549 Dear Mr. Marlowe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, `4' Cathy P. F erster Chair, Commissioner DATED this 2i day of October, 2013. Encl. • . RECEIVED . tO STATE OF ALASKA „, 15 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION l I APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool El Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing I] Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other: Install ESP II 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development p• 181-023 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20168-01. 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A Will planned perforations require a spacing exception? Yes ❑ No G Trading Bay Unit/D-17RD. 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 • McArthur River Field/Hemlock Oil Pool• 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): 10,800 .- 10,077 • 10,122 9,444 N/A 9,541';10,126';10,533' &10,538' Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,497' 13-3/8” 2,497' 2,404' 3,090 psi 1,540 psi Intermediate 8,145' 9-5/8" 8,145' 7,579' 5,750 psi 3,090 psi Production Liner 2,951' 7" 10,800' 10,077' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic ' See Schematic 4-1/2"&3-1/2" 12.6#N-80&9.2#N-80 7,739'&9,276' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Pkr:Hyd.Perm Pkr,Otis"WD"Pkr and SSSV:N/A Pkr 9,277'(MD)8,657'(TVD);9,923'(MD)9,258'(TVD)and SSSV:N/A 12.Attachments: Description Summary of Proposal p ' 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch G • Exploratory ❑ Stratigraphic❑ Development G■ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 10/21/2013 Commencing Operations: Oil 0 , Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarloweahilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signatud� Phone (907)283-1329 Date 10/14/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number:3\..2. _ C Lk.ok Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ RBDMS O(' 2 5 204 Other: ilv 1. 1 /VD Spacing Exception Required? Yes ❑ No Subsequent Form Required: 1 0 - 11 O' APPROVED BY j r 2 Approved by: COMMISSIONER THE COMMISSION Date: /Q- 2J— J (�� /fj /o-/6-I3 the date 4�e, Submit Form and 3141�'(b Form 10-403(Revised 10/2012) Appro pct v I f mo hs from the date of approval. Attachments in Duplicate 1 Well Work Prognosis Well: D-17RD Hileorp Alaska,LLC Date: 10/14/2013 Well Name: Trading Bay Unit D-17rd API Number: 50-733-20168-01 Current Status: Producer(Gas Lift) Leg: Leg#A-2 (NW corner) Estimated Start Date: 10/21/2013 Rig: HAK#1 ✓ Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 181-023 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Ted Kramer Office: 907-777-8420 Cell: 985-867-0665 Current BHP: 3,500 psi @ 9,583'TVD/10,217 MD .37 psi/ft.,(7.0 ppg)at mid-perf of all perfs Max.Expct'd BHP: 3,500 psi @ 9,418'TVD/10,095'MD .37 psi/ft.,(7.0 ppg)No new zones Max.Possible SP: 0 psi Using 0.45 psi/ft back to surface Brief Well Summary • UNOCAL worked the wellover in 2003 in a failed attempt to convert the well to an ESP.The production packer and lower tubing was left in the well which over time plugged off with production dropping dramatically from ^'5,000 bfpd. The well was shut-in April 2007 when scale and fill plugged the well. A subsequent wireline tag was conducted on 8/23/07 with a 3.70" GR to 7728'with notes of scale. A 2.0" GR was run below the X-over to 8640'. Scale was broached to 8646'. • In March of 2013 after rocking the well repeatedly with gas-lift pressure production was restored at ^' 230 bfpd. Wireline bailing was conducted in April of 2013 and production levels increased to —1,000 bfpd. • This well will be completed as a G-Hemlock ESP:producer expected to make 5000-7000 bfpd at 10-15% oil cut. Notes Regarding Current Wellbore Condition • Last wireline tag 04/07/13 8491'with 2.25 DD Bailer full of sand. Procedure: 1. At least one day prior to rig move, stop lift gas to well and bleed down tubing and casing. 2. Skid rig and RU HAK Rig 1 over D-17rd well slot. 3. Rig up E-line and punch tubing above packer or pull lowest gas lift valve possible. 4. Plumb filtered inlet water(FIW) lines to circulate down the annulus and up the tubing, or vice versa, through the tree, make sure there is no gas in the tubing or annulus. 5. Notify AOGCC 24 hours before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to psi LOW and_2,500 psi HIGH.__. 6. Circulate FIW to ensure tubing and casing are full. Un-seat tubing hanger and pull tension on tubing. RU E-line and cut tubing as deep as possible—ideally in the middle of the first full joint of tubing just above the upper packer(-9,250'x. 7. RD E-line. POOH laying down tubing and GLMs. 8. MU Overshot assembly and latch onto and pull the seals by releasing from the K-Anchor. POOH, LD cut tubing joint and seal assembly. 9. Mill and remove packer at 9,277'.There is a millout extension just below the packer. 10. Remove lower packer,and fish, cleanout to at least 10,620'.Swap out fluids to clean FIW. • Well Work Prognosis Well: D-17RD Hilcorp Alaska,LLC Date: 10/14/2013 11. Make casing scraper run to 9,500'.Swap out fluids to clean FIW. 12. PU retrievable test packer. RIH and set at (+/-) 9400'. Pressure test casing to 1500 psi and chart. POOH with same. 13. PU TCP Guns and RIH. 14. RU E-line and place Guns on depth tying into Log. Fire Guns. 15. Monitor fluid level after firing of TCP guns by shooting fluid levels until well stabilizes. POOH with TCP guns. 16. PU, RIH with ESP completion. 17. PU, RIH with ESP completion. 18. ND BOP, NU wellhead and test. 19. Turn Well over to production. 20. Conduct a no-flow test within 2 weeks after stabilized flow and water cut is achieved. Attachments: 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Current Wellhead Diagram 5. New Wellhead Diagram 14 McArthur River Field,TBU SCHEMATIC Well: D-17RD Hilcorp Alaska,LLC As Completed: 2/24/2003 RKB to TBG Head=41.05' CASING DETAIL Tree Connection:4-1/6",5,000# SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt.LT&C 12.515 Surf 2,497' 1 13-3/8" 9-5/8" 40 N-80 Butt 8.835 Surf 4011' 99--55//88'''' -5/8" 43.5 N-80 Butt 8.755 4011' 5498' ® 2 9-5/8" 9-5/8" 47 N-80 Butt 8.681 5498' 7025' 47 5-95 8rd 8.681 7025' 8145' 7" 32 N-80 Butt 6.094 7,849' 7884' III7" 29 N-80 Butt 6.184 7884' 9523' 7" 32 N-80 Butt 6.094 9523' 10,800' IIITUBING DETAIL al4-1/2" 12.6 N-80 IBTC 3.958 41.05 7,739' -..�,.-.N.:. 3-1/2" 9.2 N-80 IBTC 2.992 7,739' 9,276' JEWELRY DETAIL No Depth ID Item 1 41.05 CIW DCB-FBB Tbg Hanger 11"x 4-1/2"IBTC top/bottom III 2.867"& 4 x 3 Y"slimhole SPMs(BST)w/R-1 GLVs&BK-2 latches @ 9107',8684', 3 2 various 3.833" 8263'&7842'.8 x 4 Y"SPMs w/R-2 GLVs&RK latches @ 7418',7002', .....! 6584',6134',5649',4952',3826'&2481'. 3 7,739' 2.992 Crossover,4-1/2"IBTC X 3.1/2"IBTC 3 4 9276' 3 K-22 anchor seal assembly(right hand release)I 9-5/8" 7"SA8-3(29 ppf)hydraulic set perm.packer w/5.50'M.O.Ext.,6'x 3 Y" 3 5 9277' L 3.25 pup jt,3':"'XN'nipple,6'x3'h:"pup jt,3Y"WLEG 6 9,302' 3 E.O.T.(3'h:"WLEG) k'• 7 9,541' Top of old tubing fish–partially burned over–potential substantial junk barrier 4 Original GLM#9. 3- I 5 8 9,814' 2.813 1/2"Otis RW w/McMurry 1R 3/8"orifice w/BK-2 Latch 6 9 9,923' Otis"WD"Pkr.w/5'Seal bore ext.and Bell guide. Set on E/line @ 9909'CBL 10 9,945' 2.75 Otis"X"Nipple,2.75 7 11 9,977' 2.992 Otis 1/2 cut Mule Shoe 8 FISH/FILL INFO L F. 9 .rL ?is FILL:Tagged w/a 2.65"GR on 9/25/96 @ 10,122'WLM FISH: 10 11 3'/:"tubing,one 3 Y"GLM,Otis WD packer&3 Y:"tail pipe(see above items#7 thru#9) 9541'top,9977'bottom TOF partially burned over,significant mechanical obstruction,refer to wellfile for details. OM-1 Arm&(3)Springs 4/8/95 10,126'WLM — —B-1 17'Strip Gun 8/23/90 10,533'WLM 22'Strip Gun 6/29/92 10,538'WLM —B-2 B-3 a PERFORATION DETAIL Last Perf Zone Top Btm Amt SPF B-4 Date -... B-1 10,052 10,081 29' 36 11/21/1992 +i,, :,7 8-5 8-2 10,096 10,120 24' 18 7/27/1992 Q 10,178 10,192 14' 4 2/2/1987 .. 8-3 10,214 10,232 18' 12 11/29/1992 Z B-4 10,260 10,292 32' 8 1/30/1987 TD=10,800'PBTD=10,676' 8-4 10,330 10,380 50' 28 11/29/1992 Max Angle=27°,KOP @ 600' B-5 10,405 10,490 85' 20 12/3/1992 McArthD-ur River 17RD Field,TBU II Last PROPOSED Well:181 0123 d: Future PTD Hilcorp Alaska,LLC API: 50-733-20168-01 RKB to TBG Head=41.05' Tree Connection:4-1/6",5,000# CASING DETAIL 1 SIZE WT GRADE CONN ID TOP BTM. 13-3/s'" 13-3/8" 61 K-55 Butt.LT&C 12.515 Surf 2,497' A j 9-5/8" 40 N-80 Butt 8.835 Surf 4011' 9-5/8" 43.5 N-80 Butt 8.755 4011' 5498' 9-5/8" 47 N-80 Butt 8.681 5498' 7025' 9-5/8" 47 S-95 8rd 8.681 7025' 8145' 7" 32 N-80 Butt 6.094 7,849' 7884' 7" 29 N-80 Butt 6.184 7884' 9523' 7" 32 N-80 Butt 6.094 9523' 10,800' TUBING DETAIL 4-1/2" I 12.6 I L-80 I IBT-M 1 3.958 41.05 I ±7,800' JEWELRY DETAIL Top No Item (MD) ID ,F] 1 41.05 4-1/2"Hanger Assy. 9-5/8„ 2 ±7,800' Bottom of ESP l= 2 .." ■� PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) Btm(ND) Amt SPF Peri Date G-2 ±9,596' ±9,628' ±8,952' ±8,982' 32' 6 Proposed G-3 ±9,658' ±9,673' ±9,010' ±9,024' 15' 6 Proposed G-4 ±9,701' ±9,735' ±9,050' ±9,082' 34' 6 Proposed G-4 ±9,794' ±9,798' ±9,137' ±9,141' 4' 6 Proposed G-5 ±9,854' ±9,859' ±9,193' ±9,198' 5' 6 Proposed G-5 ±9,882' ±9,890' ±9,219' ±9,227' 8' 6 Proposed G-5 ±9,924' ±9,935' ±9,259' ±9,269' 11' 6 Proposed G-2 G-6 ±9,965' ±9,969' ±9,297' ±9,301' 4' 6 Proposed G-3 HK-1 ±10,048' ±10,077' ±9,375' ±9,402' 29' 6 Proposed 0-4 HK-1 10,052' 10,081' 9,378' 9,405' 29' 36 11/21/1992 l G-5 HK-2 10,096' 10,120' 9,419' 9,442' 24' 18 7/27/1992 0-6 HK-2 10,178' 10,192' 9,496' 9,509' 14' 4 2/2/1987 HK-3 10,214' 10,232' 9,530' 9,547' 18' 12 11/29/1992 HK-3 ±10,214' ±10,246' ±9,530' ±9,560' 32' 6 Proposed HK-1 HK-4 10,260' 10,292' 9,573' 9,603' 32' 8 1/30/1987 HK-2 HK-4 ±10,261' ±10,376' ±9,574' ±9,682' 115' 6 Proposed HK-3 HK-4 10,330' 10,380' 9,638' 9,685' 50' 28 11/29/1992 HK-5 ±10,395' ±10,516' ±9,699' ±9,812' 121' 6 Proposed HK-4 HK-5 10,405' 10,490' 9,709' 9,788' 85' 20 12/3/1992 1 HK-6 ±10,555' ±10,593' ±9,849' ±9,884' 38' 6 Proposed t HK-5 HK-6 TD=10,800'PBTD=10,676' Max Angle=27°,KOP @ 600' Updated by: JLL 09/26/13 Dolly Varden Platform D-17RD Current 07/9/2013 HBrnrp,U4t4 j.l.I.t, Dolly Varden Tubing hanger,CIW-DCB- D-17RD FBB,11 X 4 A IBT X 4'A IBT 13 3/8 X 9 5/8 X 41/2 susp,w/4"type H BPV,1/8 non continuous control line, 7"extended neck prep BHTA,CIW,w/internal knockup cap,41/16 5M FE iiiiiiiimmm " I, A AMP- icr, (M1 0 00 .,. , --;.- I wewr• Tree,Block,CIW-F,115M X 111 0 �i �� 1 0 41/165M run X31/85M ' _ win g,double master and n wing valve,EE trim prepped amor for 7"FBB type hanger neck, *' - p • w/A control line exit ♦ /C t;r414 III III e-Nr-- 1--- -1:110P1m"."' Tubing head,CIW-DCB, '...ii • s I�.■= 135/83MX115M,w/2 IeI — Ill Valve,WKM-M,2 1/16 5M 2 1/16 5M 550,X bottom FE,HWO,AA trim ® _ � ' Qty 2..110.4 svi. - ' .4( 1 li -110 41Ik , ,I>tl. : .ICI -a_.,:.: • s It Casing head,CIW-WF, •1. 13 5/8 3M X 13 3/8 casing I -� •, Valve,CIW F,2 1/16 5M FE, HWO,AA trim thread bottom,w/2-2 1/16 ,� 5M EFO Ill Ill 10-1111'°,.�s1_z��I 11.-i.. i ) If E-f ' . Dolly Varden Platform II D-17RD Proposed 07/9/2013 Ililrnrp Maar.1.IA Dolly Varden Tubing hanger,CIW-DCB-ESP, D-17RD 11 X 4%IBT lift and susp,w/ 13 3/8 X 9 5/8 X 3 1/2 4"type H BPV profile,5'/.EN, 2-3/8 continuous control line ports,prepped for BIW penetrator BHTA,Bowen,4 1/16 5M FE X 7" stub acme I III t II l I vilaal"' Valve,swab,WKM-M, � Cross,stdd,4 1/16 5M X .�, 4 1/16 5M FE,HWO, _ 31/85MX21/165M T-24 A 1.1 . Valve,wing,WKM-M, ��:I� °�II l O Valve,WKM-M,3 1/8 SM FE,w/ 2 1/16 5M FE,HWO, ��o� ° T-24 "ii `�°`` 1 MA-16 operator o, Valve,lower master,WKM-M, �_ }�'�� 6 4 1/16 5M FE,HWO,T-24 0$ 1 IAdapter,CIW-Toadstool,11 5M Stdd X 4 1/16 5M FE,prepped for r 5'/.ESP neck,2-'/2 npt continuous IF control line ports II—r=2i Tubing head,CIW-DCB, _.._� ;._ 13 5/8 3M X 11 5M,w/ 2-2 1/16 SM 55O, �� gill 1/ Valve,WKM-M,2 1/16 5M FE, X bottom ; HW O DD Qty III I elm Casing head,CIW-WF, wt. I� Valve,CIW F,2 1/16 5M FE, 13 5/8 3M X 13 3/8 casing III V III HWO,AA trim thread bottom,w/2-2 1/16 r '�, SM EFO 1110 611.111�I\ I11112i" 0P' M lir Dolly Varden Platform 2013 BOP Stack(HAK#1) 06/20/2013 Ililrnrp:tlaMka.1.1.4 Hydril • 4.54' GK 13 5/8-5000 iii iii iii 11 111 Shaffer SL 0 0-- —. 2.83' _ 13 5/8-5000 _. 1 `_ Iii III 111 iii 11I _�. ; 1 i �:�NY N} a 50R. { J1}I a I 2.00' v'I 1 ' = iii iii ii, Iii !ill' ` Choke and Kill Valves 2 1/16 5M w/Unibolt ilaiiiii connections for hoses III I 111 1e1 III II Riser 13 5/8 5M#13 API hub X 13 5/8 5M FE 17.00' Dolly Riser CO , T Xover 13 5/8 5M API#13 hub X 1.75' 11 5M Flange STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pulltubing: X Variance: Perforate: X Other: Install ESP 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X KB above MSL 106 feet 3. Address "~ .......... Explo'r~t'(~: ' 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface 8. Well number Dolly Varden Platform, Leg A-2, Cond #2, 759' FSL, 1127' FWL, Sec 6-8N-13W-SM Dolly Varden D-17Rd At top of productive interval 9. Permit number 1052' FSL, 4360' FWL, Sec. 6-8N-13W-SM ~~i~N~~ ~¥ ~ ~ 2003 ""'~ ~ !81-23 At effective depth 10. APl number 1118' FSL, 4592' FWL, Sec. 6-8N-13W-SM 50- 733-20168-01 At total depth 11. Field/Pool 1125' FSL, 4517' FWL, Sec. 6-8N-13W-SM McArthur River/Hemlock 8, G-Zone Pool 12. Present well condition summary Total depth: measured 10,800' feet Fishes: 22' strip gun @ 10,538'ELM & 17' stdp gun in fill @ 10,533'ELM true vertical 10,077' feet Effective depth: measured 10,122' feet Fill: Last tagged @ 10,122' ELM on 9/96 true vertical 9,444' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2453' 13-3/8" 2000 sx 2,497' 2,404' Intermediate 8103' 9-5/8" 1667 sx 8,1 45' 7579' Production Liner 2951' 7" 200 sx 10,800' 10,077' Perforation depth: measured 10,052'- 10,081' ' 10,096' - 10,120'; 10,178'- 10,192" 10,214'- 10,232" 10,260'- 10,292'; 10,330' - 10,380' · 10,405' - 10,490' true vertical 9,377' - 9404' · 9418' - 9441' · 9495' - 9508'; 9529' - 9546' · 9572' - 9602'; 9638' - 9684' · 9708' - 9788' Tubing (size, grade, and measured depth) 4-1/2" 12.6 ppf L-80 ASL & 3-1/2" 9.2 ppf L-80 ASL set @ 9,978' Packers and SSSV (type and measured depth) Otis WD pkr @ 9,922' & Otis 4-1/2" Otis Tubing Retrievable Ball Valve Type DC @ 306' Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 82 1548 3498 994 245 Subsequent to operation 5 -367 96t 1249 150 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: MA Y'I 5 2003 II DMS BFL § . a, ' &OasCo s.C,Jrnmis n Signed: Jerry F. Bower~ _.~ __ Title: Consulting Drilli? Engineer Date: //~ (/3 .2 ~)3 _ Form 10-404 Rev 0¢ ORIGINAL SUBMIT IN DUPLICATE ~. UNOCAL ) RKB to TBG Head = 41.45' Tree connection: 4-116" 5,000# Trading Bay Unit Well # D-17RD Completion Schematic 2/24/03 CASING AND TUBING DETAIL SIZE WT GRADE CO~ 1D TOP BTM. 13-3/8' 61.0 K-55 Butt. LT&C 12.515 Surf 2,497' 9-5/8" 40 N-80 Butt 8.835 42.4 4011' 9-5/8" 43.5 N-80 Butt 8.755 4011' 5498' 9-5/8" 47 N-80 Butt 8.681 5498' 7025' 9-5/8" 47 .... S-95 8rd 8.681 7025' 8145' 7" 32 N-80 Butt 6.094 7,849' 7884' 7" 29 N-80 Butt 6.184 7884' 9523' 7" 32 N-80 Butt 6.094 9523' 10,800' Tubing: 4-1/2" 12.6 N-80 IBTC 3.958 41.05 7,739' ,:3~-1~12:'~ .... 9~'20~a~ 4 '~N.-',8~i'r~, IBTC 2.992 7,739' 9,276' 8 7 10 --~ B-3 -- ~ B-4 PBTD = 10,676'TD = 10,800' MAX HOLE ANGLE = 27°, KOP (~ 600' JEWELRY DETAIL NO. Depth ID Item 1 41.05 CIW DCB-FBB Tbg Hanger 11" x 4-1/2" IBTC top/bottom 2 various 2.867" 4 x 3 ~" slimhole SPMs 0IST) w/R-1 GLVs & BK-2 latches ~ & 9107', 8684', 8263' & 7842'. 3.833" 8 x 4 ½" SPMs w/R-2 GLVs & RK latches ~ 7418', 7002', 6584', 6134', 5649', 4952', 3826' & 2481'. 3 7,739' 2.992 Crossover, 4-1/2"IBTC X 3.1/2" IBTC 4 9276' 3.000 K-22 anchor seal assembly (right hand release) 5 9277' 3.250 7" SAB-3 (29 ppf) hydraulic set perm. packer w/5.50' M.O. Ext., 6' x 3 ½" pup it, 3 ½" 'XN' nipple, 6' x 3 ½" pup jt, 3 ½" WLEG 6 9,302' 3.000 E.O.T. (3 ½" WLEG) 7 9,541' ?? Top of old tubing fish - partially burned over - potential substantial junk barrier 8 9,814' 2.813 Original GLM/19 3-1/2" Otis RW w/McMurry JR 3/8" orifice w/BK-2 Latch 9 9,923' Otis "WD" Pkr. w/5' Seal bore ext. and Bell guide. Set on E/line ~ 9909' CBL 10 9,945' 2.75 Otis "X" Nipple, 2.75 11 9,977' 2.992 Otis 1/2 cut Mule Shoe Fill Tagged w/a 2.65" GR on 9/25/96 (~/10,122' WLM FISH: 3 ½" tubing, one 3 IA" GLM, Otis WD packer & 3 ½" tail pipe (see 9541' top, 9977' above items//7 thru/19) TOF partially burned over, significant bottom mechanical obstruction, refer to wellfile for details. OM-I Arm & (3) Springs 4/8/95 10,126' WLM 17' Strip Gun 8/23/90 10,533' WLM 22' Strip Gun 6/29/92 10,538' WLM PERFORATION DATA Accum. Last Perf. ZONE TOP BTM AMT SPF DATE B-1 10,052 10,081 29' 36 11/21/92 B-2 10,096 10,120 24' 18 7/27/92 10,178 10,192 14' 4 2/2/87 B-3 10,214 10,232 18' 12 11/29/92 B4 10,260 10,292 32' 8 1/30/87 B-4 10,330 10,380 50' 28 11/29/92 B-5 10,405 10,490 85' 20 12/3/92 O:\OOE\OOEFields\Tbu\Dolly\Wells~D- 17XD- 17RD\Schematics~D- 17RD Schm 2-24-03.doc REVISED: 5/5/2003 DRAWN BY: JFB Operations Summary D-17RD ESP WO AFE # 149470 2101/03 RU lines to pump down tbg and PT. Circ down tbg taking returns on Annulus. RD circ lines and prep to set BPV. ND tree. Reconfigure choke and kill line valves to fit mud cross and dolly cellar. RU choke and kill lines. 2~2~03 NU BOP, choke and kill lines, bell nipple. Install 2 7~8" to 5" VBRs in top and bottom ram cavities. Install blind~..S...hea_r~r_a.ms in._rni__dd_!e. Install bell nipple. PT annular preventer, top and bottom VBRs, mud cross valves, choke manifold, and 3 1/2" floor valves to 250 psi Iow and 3000 psi high. Pull BPV, install 2-way check, test shear blind rams to 250 psi Iow and 3000 psi high. Test top VBRs and 4 1/2" floor valves to 250 psi low and 3000 psi high. Tested 4 1/2" Floor Valves to 250 psi Low & #000PSI !~N.NE~ ?.~¥ ~ ~ 200~ 2~3~03 Circulate down tbg. POH w/tbg.LD landing joint and CX, well U-tbg. RU to LD pipe. Lay hanger, pup joints 4 1/2" ASL tbg. 1353' layed down at 17:00 hrs includes SSSV. Lay down tbg. Pipe in good shape, no scale. ( 700 FPH average) 2~4~O3 Continue L/dn & chk 4-1/2" ALS tbg. L/dn & chk 3-1/2" ALS tbg Total recovery = hanger + SSSV + 229 jts 4-1/2" tbg + 2 pups + 6 GLM w/pups + XO + 26 jts 3- 1/2" tbg & split collar = 8462.95') All pipe chk for norms no norms detected above back ground. T.O.F 3-1/2" pin @ 8504'. R/dn tbg equipment & r/up to p/up bha. Continue fishing. R/up & test top pipe rams w/5" dp t/250~3000 psi (ok). R/UP to p/up 3-1/2" tbg P/UP & M/UP BHA #1 and P/UP & rabbit & strap 3-1/2" 9.2# butt tbg (chk & discovered that storm prk was dressed for 47-53.5# csg. Continue p/up rabbit & strap 3-1/2" butt 9.2# tbg fishing string (total 30 jts p/up see bha #1) RID tbg tools & r/up t/p/up 5" dp. P/up Kelly & replace "O" ring in swivel & make all connections & hook up kelly hose & test kelly, valves & hose to 250/3000 psi (ok) Continue P/up rabbit & strap 5" S-135 19.5# DP 2~5~03 Continue P/up rabbit & strap 5" dp (average 650 FPH) Set dn 15k @ 7066'. Circ 1/2 DP volume & work pipe fl 7045' t/7090' w/no sign of drag either direction (10 bbls loss while circ). Continue P/up rabbit & strap 5" dp t/8432'. Space out & Last revised 5/13/2003 (DED) install head pin & wash f/8432' t/8490' w/total dp volume (5 bbl loss while circ). Engage fish @ 8490' & pull fish into tension 12k over. R/up APRS from crown & perf safety meeting & chk list with all involved on safe system. Arm 2.70" jet cutter, RIH t/set dn@ 9088' work & manipulated tools, unable to pass 9088' Pooh. Re-arm 2.70 jet cutter & rih & set dn@ same 9088' Place cutter on depth & sever pipe @ 9073' (15' above set Dn & middle of jt) Pooh. RD APRS. Pooh slow w/7k extra up weight 2~6~03 Cont POH with Cut tbg. Change Slips & Elevators for 3 1/2" Tbg. Cont POH standing back the New 3 1/2" Tbg. Lay down Over Shot (bha #1), Lay down recovered tbg 16jnts + Cut off Recovery = 554.50' new cai top of fish = 9072 Recovered tbg. Measurements & chk for norms (25-30 MR/HR.) Cont RIH picking up Cutter BHA #2..Co.~ith 5"-.D,P.-- Stopped at 8900'. Establish circ and check pressures 30spm little to no pressure. Cont RIH tagged top of fish at 9074' work over fish t/9149' & install head pin. Brk circ & continue to work over fish. unable to pass 9149'. Cut Tbg @ 9145' DPM. Pooh using care to assure catch. 2~7~03 ~{;~NE~ [~J~¥ ~ ~' 200~ Continue Pooh w/5" dp. Change handling equipment to 3 1/2" & pooh & std back 3-1/2" dp & 4-3/4" dc's. Change handling equipment to 5-3~4" & pooh & std back 2 std WP & L/dn 5 jts WP to recover Fish. L/dn fish - Recovered 80.56' (Never cut tbg, tbg was twisted off & stuck in guide by a split collar around other Collar & pack w/sand like substance & chk for norms (25-30 MR/HR) New T.O.F @ 9145'. M/up Bha #3. RIH t/9140'. Engage Fish (TOF at 9145) - Jar on same hit 3 times with 50k over pull & one time with 65k overpull. Parted fish (Short piece). Circulate. Lay down Recovery 15.08' (New TOF - 9,160) - Lay Down BHA. 2~8~03 Continue Rih wi 4-3/4" DC's & 3-1/2" DP. Rih w/5" dp t/9125'. P/up single, Kelly up & brk circ. Tagged T.O.F @ 9155'. Work overtop offish at 9,155, washed dn t/9190'. Pooh t/9130' with over pulls getting up t/30k over. Pump out of hole fl 9120' t/9025' w/5-25k over pulls. Pooh fl 9025' t/7710' w/10k over pulls w/ wash pipe in 9-5~8" csg. Continue pooh. Work bha t/fish. Extract fish pieces from wash pipe & I/dn P/up & M/up Bha #5 2~9~03 P/up rabbit & strap 15 jts 3-1/2" dp - RIH with 3 1/2" D.P out of derrick. RIH with 5" D.P. T/9407' dpm - established parameters - Rig up to reverse cir Last revised 5/1312003 (DED) Swallow Fish f/9,428' t/start of taking weight @ 9442' Start Reversing out & work pipe wi max rate of 6 bpm @ 700 psi. R/dn reversing lines & Kelly up & attempt to wash over. Circulate. Pooh. Work & chk Bha. Recovered fish. M/up 5" test jt & set test plug. Test Bop 250/3000 psi (ok see bop test sheet) & function test bop deluge system (ok). Pull test plug & I/dn 5" test jt & m/up 3-1/2" test jt & re-seat test plug. Test Bop 250/3000 psi (ok) Install whip chks on koomey lines & pull test plug - brk/dn test jts & blow dn lines. P/up & M/up Bha # 6. 2110103 L/dn Bad 4-3/4" drill collar & p/up jt 3-1/2" dp. Continue Rih & swap to 5" handeling equipment. Rih w/5" dp t/9427'. Kelly up - Brk circ. T.O.F @ 9428'. At 9492.5'- wash over with resistance.f/.. 9~5_t/944._4_'~.(~5 mins) continue wash over fl 9444' t/9493' w/little resistance. Pooh to chk. Brk Chk & L/dn wash pipe - no recovery. M/up bha #7. Rih t/9437'. R/up & reverse circulate. Circulate. Wash over Est T.O.F @ 9428' with no indacation of top & continue to wash t/9494' with very little resistance. Pooh to chk tools & SLM. 8CANNE~. ~,~.Y ~ 6 2003 211t/03 Continued pooh. Brk/dn & chk bha. M/up bha # 8 & rih t/9438'. P/up space out pups & kelly up & brk circ & established parameters & work over fish wi no rotation t/resistance. At 9494' Tap dn twice & p/up w/possible 5k over pull. POH. Work BHA. Chk norms <30 MR/HR, Wrap up recovered fish in absorbent and shrink wrap same. (73.37' = 6' stub + jt + pup + GLM + pup + 22' stub (missing jt from top of glm acording to Run tally) Est T.O.F @ 9526'. Make up BHA #9. RIH to 9453'. Pick up Kelly, wash down from 9453'. Worked down to 9521'. Set down solid. Pumping at 2.6 BPM @ 100 psi. Unable to get deeper. Pooh. 2112/03 Continue POH to BHA. Break down fishing BHAWash floor and BOP stack,- monitor well 1.5 BPH loss rate. Make up BHA # 10. RIH to 7728'. Pick up Kelly, break union and twist Kelly hose to get proper lay. RIH to 9508'. Rotate down 9508' to 9519'. Took weight at 9519'. Wash over fish 9519' to 9521.5'. Pump pressure gradually increased to 750 psi. POH. Work BHA. Make up shoe, continue picking up Washpipe and running Washpipe from derrick. Bha #11 .' RIH with DCs. 2113/03 RIH t/9500'. Kelly up - Brk circ & established parameters. Wash dn f/9500 t/tag @ 9518'. Finish bottoms up circulation and skim oil off of pits. POH with 5" DP. POH with 3 1/2" DP and 4 3/4" DCs. POH with washpipe. Work on break out cathead. Pick up BHA. RIH, took weight at 9504'. Pick up Kelly, break circulation, establish parameters, wash down to 9537'. POH. Last revised 5/13/2003 (DED) 2114103 POH to 5" DP, change to 3 1/2" handling tools. POH with 3 1/2" DP and DCs. RIH with DCs and 3 1/2" DP to 9479'. Wash down 9479' to 9546'. POH. Work BHA, lay down 15.60' tbg fish with slickline GLM. Pick up BHA. RIH, set down at 9501'. Rotate string fall through, RIH set down at 9539'. RU to reverse circulate. 2/15/03 RU to reverse circulate. Pick up Kelly, Mill down from 9539' to 9541'. Set back Kelly. POH, pulled tight at 9503' pulled 70K over to free. POH to 3 1/2" DP. Change over to 3 1/2" handling equipment, POH with 3 1/2" DP and 4 3~4" DCs, lay down Jars and Bumper sub. Make up 3 1/2" dressing mill and basket overshot BHA, pick up Jars and Bumper sub. RIH with 4 3~4" DCs and 3 1/2" DP, change to 5" handling equipment. RIH to 9512'. Wash down to top of fish at 9540'. Set back Kelly. POH with 5" DP change to 3 1/2" handling equipment. POH with 3 1/2" DP and 4 3~4" DCs. Lay down fishing assembly, no recovery. 2116/03 RU to pick up tbg. PU 24 jts 3 1/2" 9.2# tbg. RIH WI3 stands of 4 3/4 DC, Baker Retrieve-omatic wi equal!zing valve, and set @ 251'w/tbg tail @ 1264'. Test Storm Packer to 500 PSI for 15 min Test OK. Retrieved Storm packer. RIH to 251' set PKR, POH attempt to test. No test. RU head pin & tested equalizing valve t/800 psi for 10 min (ok). RIH & set Baker Retrieve-omatic w/equalizing valve, and set storm Prk @ 160' w/tbg tail @ 1172' Pooh & Test t/500 psi for 15 min ok. ND bops & remove Tbg spool 2117/03 Install new Cameron 13 5~8" 3M x 11" 5M DCB tbg spool, energize secondary seal and test to 2000 psi. Install new 2 1/16 5M annulus valves. Install riser. NU BOP, choke and kill hoses, bell nipple, install turnbuckles. Test BOP and related equipment to 250 psi Iow and 3000 psi high. 2118/03 Finish BOP test. LD test joint, blow down lines. RIH w/storm packer retrieving tool to 165', engage packer, equalize same, unseat and POH, lay down Storm Packer. Stand back 4 3~4" DCs and 3 1/2" tbg. PU BOT "SAB" 7" packer, RIH on 3 1/2" tbg from Derrick, picking up GLMs. Lay down 7 extra joints. Drift tbg with 2.874" rabbit Butt Tbg. RU to run 4 1/2" tbg. RIH with gaslift completion Drift tbg wi 3.80 rabbit Make tbg up to mark w/2800 ft lbs. Continue running 4 1/2" Gas lift completion. Last revised 5/13/2003 (DED) 2/19102 Continue running 4 1/2" Gas lift completion. Land 4 1/2" completion string. Up wt 125 kip, down wt 102 kip. Tbg tail @ 9302' verify hanger is landed. (ok). RU to circulate & take returns to production & pack off hanger. Pump in one drum CRW 132 into pump suction while pumping 40 bbls, chase with one tubing volume. RU SLU, test lubricator to 5000 psi. RIH, N-Test tool set in XN Nipple @ 9294' per completion Tally. Rig up pumping hoses, pressure up on tubing to 3500 psi, observed packer setting at 1750 psi. Pressure test annulus to 1500 psi. (ok). POOH Slick line & RD. LD landing joint & set BPV. ND BOPS & NU Tree, install production flow line, gas lift line, tree cap & safety valve. RU & shell test tree to 3000 psi. tested tubing hanger neck seals & ring gasket to 5000 psi. (ok). RD/MO ~.uuJ Last revised 5/13/2003 (DED) STATE OF ALASKA ! ALASKA OIL AND GAS CONSERVATION COMMISSION ~._/ ~c~ APPLICATION FOR SUNDRY APPROVALS 1: Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well: Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pulltubing: X Variance: Perforate: X Other: Install ESP 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X KB above MSL 106 feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface 8. Well number Dolly Varden Platform, Leg A-2, Cond #2, 759' FSL, 1127' FWL, Sec 6-SN-13W-SM Dolly Varden D-17Rd At top of productive interval 9. Permit number 1052' FSL, 4360' FWL, Sec. 6-8N-13W-SM 81-23 At effective depth 10. APl number 1118' FSL, 4592' FWL, Sec. 6-8N-13W-SM 50- 733-20168-01 At total depth 11. Field/Pool 1125' FSL, 4617' FWL, Sec. 6-8N-13W-SM McArthur River/Hemlock & G-Zone Pool 12. Present well condition summary Total depth: measured 10,800' feet Fishes: (1) S-line tools LIH 9/96 stuck in tubing @ 9525' SLM true vertical 10,077' feet (2) OM-1 Arm & 3 springs LIH 4/95 in fill @ 10,126' SLM (3) 22' strip gun @ 10,538'ELM & 17' strip gun in fill @ 10,533'ELM Effective depth: measured 10,122' feet Fill: Last tagged @ 10,122' ELM on 9/96 true vertical 9,444' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2453' 13-3/8" 2000 sx 2497' 2,404' intermediate 8103' 9-5/8" 1667 sx 8,145' 7579' Production Liner 2951' 7" 200 sx 10,800' 10,077' Perforation depth: measured I0,052'- 10,081" 10,096'- 10,120'; 10,178'- 10,192" 10,214' - 10,232'; 10,260' - 10,292'; 10,330' - 10,380' ' 10,405' - 10,490' true vertical 9,377' - 9404'; 9418' - 9441' · 9495' - 9508'; 9529' - 9546'; 9572' - 9602'; 9638' - 9684'; 9708' - 9788' Tubing (size, grade, and measured depth) 4-1/2" 12.6 ppf L-80 ASL & 3-1/2" 9.2 ppf L-80 ASL set @ 9,978' Packers and SSSV (type and measured depth) Otis WD pkr @ 9,922' & Otis 4-1/2" Otis Tubing Retrievable Ball Valve Type DC @ 306' 13. Attachments Description summary of proposal: Detailed operations program. X BOP sketch: X Current wellbore schematic X Planned wellbore schematic X 14 Estimated date for commencing operation 15. Status of well classification as: 2/1/2003 ~' 16. If proposal well verbally approved: Oil: X Gas: Suspended: Name of approver Date approved Service: ESP Conversion 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed:~/'_~ ~.~_~(~/zu.-~,_-Jerry F. Bowen, P.E. Title: Consulting Drilling Engineer Date: 2/1/2003 ,~' // FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representa, tive may witness -Z,~l[~:)%,--~ ~..~(~:> ~..~?_~_~.,~lApprovalNo. Plug integrity.__ BOP Test Mechanical Integrity Test 'S~bse~quent form recluired 10- - JAN 10 2005 ORIGINAL SIGNED BY _ Alaska 0il & Gas Cons. C0mm, issio~ Approved by order of the Commissioner _ Form 10-403 Rev 06/15/88 EBDN$ BFL J~N 3 0 AFE #149454 SUBMIT IN TRIPLICATE Dolly Varden D-17RD Workover to Add G-Zone Perfs & Convert to ESP Unocal Alaska requests Sundry Approval to add G-zone perforations to the existing Hemlock perforations during the upcoming ESP conversion workover of Dolly Varden Well D-17RD. Specifically, Unocal Alaska requests permission to run a 3 t/=, x 4 1/=, ESP completion without a; 1. subsurface safety valve (20 ACC 25.265) 2. production packer (20 ACC 25.200). Justification: 1. The current gas lifted Hemlock completion passed a No-Flow test on July 25, 2002. 2. The G-Zone is known to be partially depleted and is expected to be a thief zone with a SlBHP of 3017 psi at -8850'SS. m The well is expected to produce +9000 BFPD with a high watercut (+/- 90 to 95%) after the ESP is installed. Therefore, reservoir pressure in the vicinity of the subject wellbore is predicted to decline, thus the potential for unassisted flow is predicted to decrease. UNOCAL ) RKB to TBG Head = 41.45' Tree connection: 4-116" 5,000# Trading Bay Unit Well # D-17RD Completed 6/81 CASING AND TUBING DETAIL ~81ZE WT GRADE CONN [ ID TOP BTM. 13~3/8" 61.0 K-55 Butt. LT&C[ 12.515 Surf 2,497' 9-5/8" 40 N~80 Butt 8.835 42.4 40l l' 9-5/8" I 43.5 N-80 Butt 8.755 4011' 5498~' 9~5/8"I 47 __ N-80 Butt 8,681 5498' 7025' 9-5/8" 47 S-95 8rd 8,681 7025' 8145' 7" 32 N-80 Butt 6.094 7,849' 7884' 7" 29 N~80 Butt 6.184 7884' 9523' T' 32 N-80 Butt 6.094 9523' I 0~00' Tubing: 4-1/2" 12.6 N-80 ASL 3.958 $uri' 7,709' 3-1/2" 9.20 N-80 ASL 2.992 7,709' 9,978' 13 PBTD = 10,676'TD = 10,800' MAX HOLE ANGLE = 27°. KOP @ 600' D-17rd Scan 6-81.doc JEWELRY DETAIL NO~ ~el~ !h ID Item ' 41.45 CIW F / FBB Hanger 4-1/2" ASL X 4-1/2" A~ I 299' 3.813 4-1/2" Otis Tubing Retrievable Ball V~pe DC 2 2,116' 3.833 GLM #1 4-l/2" Otis RL w/1-1/2" Camco Valve w/RA Latch 3 3,769' 3.833 GLM #2 4-1/2,' Otis RL w/ 1-1/2" Camco Valve w/RA Latch 4 5,237' 3.833 GLM #3 4-1/2,' Otis RL w/ 1-1/2" Camco Valve w/RA Latch 5 6,275' 3.833 GLM 84 4-1/2,' Otis RL w/I-1/2" Camco Valve w/RA Latch 6 7.148' 3.833 GLM #5 4-1/2" Otis ILL w/1-1/2,' Camco Valve w/RA Latch 7 7,659' 3.833 GLM #6 4-1/2" Otis RL w/1-1/2" Camco Valve w/RA Latch 8 7,709' 2.992 Crossover, 4- l/2"A~-X 3 1/2" ASL 9 8,842' 2.813 GLM #7 3-1/2" Otis RW w/McMurry JR 3/8" orifice w/BK-2 Latch 10 9,495~ 2.813 GLM #8 3-1/2" Otis RW w/McMurry JR 3/8" orifice w/BK-2 Latch 11 9,814' 2.813 GLM #9 3-1/2,' Otis RW w/McM urry JR 3/8" orifice w/BK-2 Latch 12 9,920' Otis 4" Locator Seal Assy 13 9.923' Otis "WD" Pkr. w/5' Seal bore ext. and Bell guide. Set on E/l/ne ~ 9909' CBL 14 9,94~7- -- 2.75 Otis "X' Nipple, 2.75 15 ~9,97T 2.992 Otis 1/2 cut Mule Shoe FiB Tagged w/a 2.65" GR on 9/25/96 FISH: OM-I KOT 6' long LIH on 9/27/96. Ret SL tools on 7/09/02 9,552' WLM_ OM-1 Arm & (3) Springs 4/8/95 10,126' WLM 17' Strip Gun 8/23/90 10,533' WLM 22' Strip Gun 6/29/92 10,538' WLM PERFORATION DATA ~cum, Lest Perf. ~ TOP BTM AMT SPF pATE B-I 10,052 10.081 29' 36 11/21/92 B-2 10,~096 10,120 24' 18 7/27/92 10,178 10,192 14' 4 2/2/87 B-3 10,214 10,232 18' 12 11/29/92 BM 10,260 10,292 32' 8 1/30/87 B-4 10,330 10,380 50' 28 11/29/92 B-5 10,405 10,490 85' 20 12/3/92 FEB 0 2003 REVISED: 1/10/2003 " DRAWN BY: SLT RKB to TBG Head = 41.45' L000# --'~ B-4 PBTD = 10,676'TD = 10,800' MAX HOLE ANGLE = 27°, KOP @ 600' Trading Bay Unit Well # D-17RD Proposed Completion CASING AND TI BING DETAIL SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61.0 K-55 Butt. LT&C 12,515 Surf 2.497' 9-5/8" 40 N-80 Butt 8.835 42.4 40l I' 9-5/8" 43.5 N-80 Butt 8,755 4011' 5498' 9~5/8" 47 N-80 Bun 8.681 5498' 7025' 9-5/8" 47 S-95 8rd 8.681 7025' 8145' 7" 32 N,780 Butt 6.094 7 849' 7884' T' 29 N-80 Butt 6.184 7884' 9523' 7" 32 N-80 Butt 6,094 9523' 10 800' Tubing: 4-1/2" 12.6 N-80 Butt 3.958 Surf 7.670' ESP Cable I/0$OLBC 3.37 5KV 90 FB 185 GAL w/(2) 0.375" SS lUBES-GAL- SURF 7,670' 1.611' X 2.361" R JEWELRY DETAIL NO. DeDth ID Item 41.5 CIW F / FBB Hanger 4-1/2" ASk X 4-I/2" ASL Fill Tagged w/a 2.65" GR on 9/25/96 ~ 10,122' WLM FISH: OM-I Arm & (3) Springs 4/8/95 10,126' WLM 17' StripGun 8/23/90 10,533' WLM 22' Strip Gun 6/29/92 10,538' WLM PERFORATION DATA Accum, Last PerL ZONE TOP BTM AMT SPF DATE G~2 9595 9625 3(/ 6 Prop<~sea REVISED: 1/10/2003 D-17RD Ese Prop Schm 1-10-03.doc ~5~i~ED rib 0 ~: ~0,~ DRAWN BY: SLT Dolly Varden Stack up D -17RD Table A 4 1116" 5M Foster HCRVatve B 4 1/16" 5M Manual gate valve C 3 1116" SM Manual gate Kill line D 3 t/t6" 5M Manual gate Kill line Btm of Trolly beam 1.15 Top of drill deck 18.60 to tbg Spool 2.0 spacer spool 2.0 spacer spool 1.5' 13 5/8" x 11" xo spool SCANNED FEB 0 A 2003 UNOCAL (Version 1) Dolly Varden Platform Well #D-17 ESP Conversion Workover Procedure 1/6/06 OBJECTIVE Recover the original gas lift completion, change tubing head spool, TCP perforate the G-Zone, and install a 600 hp 725 series ESP. WELL HISTORY & STATUS Well D-17 was plugged back and re-drilled in 1981. A section mill was used to section the 9 5/8" casing below 8145' and an 8 ~A" hole was drilled to 10,800' before running the 7" liner. The 4 ~" x 3 ~" gas lift completion which was run in 1981 remains in the well today. Although the overall condition of the tubing is unknown, the string appears to be intact based on S-line results. The well has a documented scale problem, although gauge rings have recently been run to the top of the S-line fish. Scale inhibitor is currently injected with the gas lift gas. Coil tubing was used successfully to clean-out scale down to 10,500' in 1986. There is a non- recoverable S-line fish in the tubing at +/-9525', with a broken off (flow-cut) fishing neck. The well produces around the fish with no significant pressure restriction. The Hemlock currently produces approximately 3660 BFPD with a 95% watercut (183 BOPD) on gas lift. Currently, there are no G-zone perforations. One objective of this workover is under-balanced TCP of the G-zone, for commingled Hemlock/G-zone ESP production in the range of 9000 BFPD. The reservoir pressure of the Hemlock and G-zone are estimated to be 3841 psi at -9350' SS and 3017 psi at -8850' SS, respectively. The pressure gradients are estimated to be +0.40 and +0.33 psi/ft BRT, respectively. However, the pressures and gradients in each sub-layer are not likely to be uniform. Since the G-zone has not been produced at this location, it is possible that the G-zone will have a relatively high oil-cut with higher than expected reservoir pressure. SPECIAL HAZARDS The mixture of produced gas and gas lift gas coming from well D-17RD has an H2S concentration of 750 ppm. The Dolly Varden Platform is designated as an H2S facility. The site-specific Dolly Varden H2S Drilling & Workover H2S Contingency Plan should be reviewed during the pre-spud meeting. NORM contamination may be present on Well Components. Sealing thread protectors will be utilized on the used tubing, and wooden boxes will be available to transport joints having corrosion holes, to prevent spills. A No-Flow Test witnessed by the AOGCC in July 2002 resulted in AOGCC approval to produce without a SSSV or packer. This No-Flow Test will no longer be valid once the G-zone perforations are added. Extra care should be taken to maintain a fluid level and monitor the well after perforating the G-zone. '~ Injection Well D-34ADPN is completed in the Hemlock approximately 1300' away from the subject well. Additionally, there are six other injectors located between 2000' and 4500' of the subject well. ,SCANNI D FEB 0 2009 D-17 ESP Conv WO Proc.doc 1 01/10/03 UNOCAL (Version 1) Dolly Varden Platform Well #D-17 ESP Conversion Workover Procedure 1/6/06 WELLHEAD CONDITION The wellhead has not been inspected sin March/April 2002. At that time, it was determined that the existing Cameron type 'F' tubing head spool and Cameron block 5m X-mas tree (refer to diagram) would be changed out with H2S trimmed Cameron equipment during this workover. The following new Cameron H2S trimmed equipment is in inventory: 1.) 13 5/8" 3m x 11" 5m tubing head spool w/4" Type 'H' BPV profile w/ IBTC threads top/bottom, 2.) 11" 5m Cameron DCB-FBB eccentric ESP tree adapter spool, 3.) conventional flanged 4 1/16" 5m flanged single-master X-mas tree (refer to diagram). The tbg hanger seals were successfully tested to 5000 psi in March 2002. The 4" type 'H' BPV profile was cleaned out (chased w/tap) in April 2002 and is expected to function as designed. The current hanger reportedly has ASL threads on top/bottom. The 9 5/8" seals have leaked periodically. Plastic was injected to effect a seal in early 2002. Be aware that partial communication between 9 5/8" and 13 3/8" strings at the surface is possible. The 13 3~8" casing had t30 psi on it on 1/7/03, and must be bled to 0 psi and confirmed dead before nippling down the THS. There is no information in the wellfile, but based on observations, it appears that the Otis type DC TRSV (ball valve) is either locked or stuck open, or has been removed. The control line has been isolated, and full gauge tools have been run on numerous occasions. PRE-WORKOVER PREPARATION Production Four days prior to skidding rig, shut off gas lift gas and slowly bleed casing to 0 psi. After 9 5~8" pressure is 0 psi, bleed 13 3/8" casing to 0 psi and monitor build up rate. It is recommended that injection wells D-34, D-45, D-9 & D-1 be shut-in approximately one week prior to nippling down the X-mas tree. Centrilift All Centrilift supplied equipment, including all of the primary and back-up ESP equipment, all required protectolizers, flat cable guard, flat cable, centralizer and anode, should be pre- assembled at Centrilift's Anchorage warehouse at least two weeks prior to the start of the workover (scheduled for January 17th). The back-up and primary equipment should then be clearly labeled, disassembled into convenient sections (which can be handled safely and without risk of damage), and loaded into the aluminum transport basket. The back-up equipment should be placed on bottom and the primary equipment of top, to avoid confusion on-site. SCANNED FEB 0 A 2003 D-17 ESP Conv WO Proc.doc 2 01/10/03 UNOCAL (Version 1) Dolly Varden Platform Well #D-17 ESP Conversion Workover Procedure 1/6/06 The fully loaded basket should be available at OSK at least one week prior to the start of operations to allow convient shipping of the equipment offshore without an extra dock worker call-out. Drilling Prior to starting the workover, the X-mas tree and the tubing head spool bolts should be worked (or replaced one at a time) to minimize the risk of critical path downtime. The lock down pins should also be worked. The following Unocal Alaska Drilling Depadment Standard Operating Procedures have been prepared to minimize HES risks, streamline operations and ensure job quality. The Drilling Foreman must verify compliance with the following documents pertaining to ESP workovers: 1. SPS 7.24 Simultaneous Operation Policy & Checklist 2. Management of Change (MOC) For Drilling Operations Procedure A.) MOC Form 5 Unexpected Change or Occurrence at the Well Site Checklist (only if required) B.) MOC Form 6 ESP Workover Checklist 3. SPS 7.11 H2S Facility Requirements & Drilling Department's Site-Specific Steelhead Drilling & Wbr~_ver H2S Contingency Plan 4. Drilling 5. Drilling 6. Drilling 7. Drilling 8. Drilling 9. Drilling Dept. SOP~ ESP Workover Pre-Rig Arrival Procedure Dept. SOP - ESP Workover Pill Setting Procedure Dept. SOP - ESP Workover Rig Startup Procedure Dept. SOP - ESP Workover NU BOPE Procedure Dept. SOP - ESP Workover Tripping Pipe & Cable Procedure Dept. SOP - ESP Workover Emergency Shut-In Procedure PROCEDURE 1. Mobilize crews & activate rig as per Standard Operating Guideline - ESP Workover Rig Startup Procedure. 2. Skid over & prep well D-17RD as per Standard Operating Procedure - ESP Workover Pre-Rig Arrival Procedure. Note: Refer to attached ESP Workover MOC Checklist. The well should be bled to 0 psi & confirmed dead prior to ND/NU operations. Reverse circulate hydrocarbons oout of well through gas lift valves and/or holes in tubing to well clean tank w! 3% KCI. Determine loss rate to Hemlock perfs. If loss rate is manageable, no CaCO3 LCM pill will be spotted at this stage. 3. Install 4" 'H' BPV. NU & test 13 5/8" 5m BOPE to 250/3000 psi as per attached diagram & as per Standard Operating Procedure - ESP Workover NU BOPE Procedure. Note: Although only a 3m double ram configuration is required, a 13 5/8" 5m triple ram stack will be utilized, with a 3000 psi test (refer to dia~gram). Make certain Sundry Notice is approved prior to starting well work. ! SCANNED FEB 0 A 200:) D-17 ESP Conv WO Proc.doc 3 01/10/03 UNOCAL (Version 1) Dolly Varden Platform Well #D-17 ESP Conversion Workover Procedure 1/6/06 Install landing joint with TIW valve. Reverse circulate well to well clean tank w/3% KCI as required (i.e. bottoms up, complete well volume, etc.) to verify well dead and, if possible, hydrocarbon free. High rate >4 BPM is recommended, but do not exceed 1500 psi on 9 5/8" casing. 5. Verify well dead. Unland hanger & attempt to pull seal assembly out of packer. Note: Do not exceed 70% of tubing yield strength without first discussing with Superintendent. Tail pipe is part of tubing string and must also come back thru packer. If seal assembly comes loose, jump to step #7. If necessary to cut tubing, pull 20k over string weight (reportedly 148k lbs up & 95k lbs down weight when landed). Set slips. RU & test APRS lubricator on top of landing joint & full opening TIW valve. RIH wi 2.7" jet cutter & cut 3 %" tubing in middle of first full exposed joint above fish (fish at 9525' SLM). RD APRS E-line unit. 7. POH & L/D 4 %" x 3/12" gas lift completion. Note: Check for NORM while POH as per attached guidelines. Install sealing thread protectors. If NORM above maximum guideline detected, seal joints with corrosion holes in crates. Send in pipe ASAP. Note: Send in SPMs and/or pup joints for possible refurbishment. If tbg was jet cut, RIH w/overshot-jar BHA to recover tbg stub out of packer. P/U tapered 3 %" x 5" drill string. Install 8 3/8" smooth OD integral blade stabilizer to drift 9 5/8" casing at 3 %" x 5" crossover, positioned in string to be 60' to 90" from liner top when fish is engaged. Stop RIH at 5000'. Note: It will be necessary to dress flared jet-cut tbg stub before overshot can seal. Note: If seal assembly was recovered from packer with tubing. RIH wi 8 318" smooth OD integral blade stabilizer on 5" DP to liner top. POH 100'. 9. M/U storm packer on top of 5000' fishing string. RIH to 100'. Set packer. ND BOPs & change out tubing head spool. NU & body test BOP. Recover storm packer. 10. Either FIH w/fishing string & jar tbg stub out of packer or POH w/stabilizer. 11. M/U & RIH w/Halliburton TCP assembly, champ packer & FastFill valve as per attached TCP diagram to approximate firing depth. Position packer to be 30' above max depth reached with 8 3~8" stabilizer. 12. RU APRS E-line & run GR strip across RA sub to space out TCP guns. 13. Make final space out & set packer. Pressure test annulus ~~. , 14. Install TIW valve & pressure test piping to choke manifold & to well clean tank. RU acoustic recorder. Pressurize annulus to 1500 psi to fire guns. Verify guns fired. D-17 ESP Conv WO Proc.doc 4 01/10/03 UNOCAL ) (Version 1) Dolly Varden Platform Well #D-17 ESP Conversion Workover Procedure 1/6/06 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. Unset packer and circulate well dead. Circulate any hydrocarbons to well clean tank. Determine rate of losses. If loss rate is manageable, jump to step #18. Circulate 25 bbl CaCO3 down tbg into annulus. Close annular before pill exits tubing and bullhead base of pill to top G-zone perf. Stop pumping and keep hole full. Monitor rate of losses over time. Spot second pill if necessary. Verify loss rate is manageable and circulate hole clean before proceeding with step#18. POH w/TCP assembly. M/U new ESP assembly as per attached diagram, and in accordance with ESP QA/QC Checklist. RIH w/ESP assembly & refurbished SPMs (refer to attached gas lift design & proposed completion schematic) on new 4 ~" 12.6 ppf L-80 IBTC x 3 ~" 9.2 ppf L-80 IBTC tubing string as per Standard Operating Procedure - ESP Workover Tripping Pipe & Cable Procedure. Position base of ESP between 7815' & 7785' (within 0.50 to 0.61/100' DLS interval). Make up tubing hanger. Splice ESP cable to BIW hangar penetrator pig tail. Make up chemical injection lines to upper check valves and to hanger. Monitor conductivity of the ESP cable while landing hanger in tbg head. Note: Be aware of final ESP cable & hanger orientation with respect to gas lift inlet valve, and work ESP cable & cable clamps to opposite side of tubing near surface if possible, to avoid rotation of hanger and string. Install BPV. ND BOPE & NU X-mas tree as per Standard Operating Procedure - ESP Workover NU BOPE Procedure. Recover BPV and set TWC valve. Pressure test tree, hanger body and neck seals, and ring gasket to 3000 psi. Recover two way check. Install flowline and surface facilities & turn well over to Production. The Asset Team will provide a procedure to bring well on-line. $CANNEB FEB 0 2003 D-17 ESP Conv WO Proc.doc 5 01/10/03 ~[ipulatlons tor U-1 filL) ~unary Not~ce Subject: Stipulations for D-17RD Sundry Notice Date: Wed, 29 Jan 2003 08:08:25 -0800 From: "Bowen, Jerry -Alaska" <jbowen@unocal.com> To: <tom_maunder@admin.state.ak.us> CC: "Buster, Larry W" <lbuster@unocal.com> Tom; Per our discussion concerning the D-17RD Sundry Notice, Unocal will pressure test the 9 5/8" casing to 1500 psi immediately prior to adding the G-Zone perforations. The test will be recorded on a chart and can be submitted with the form 10-404, if required. Additionally, Unocal will contact the AOGCC to witness a No-Flow test after no more than 60 days of ESP production. In the event the well fails the No-Flow Test, Unocal will immediately evaluate options, and will develop a course of action which meets AOGCC approval. Potential corrective actions could include, but are not limited to; (1) shutting in one or more injection wells until D-17RD will pass the No-Flow test, (2) installation of a downhole storm choke or a 'K' valve, (3) continued production while monitoring the BHFP (via the Phoenix sensor) to verify a downward trend, or as a last resort, (4) working the well over to install a packer and/or a TRSV. It should be noted that since the platform is manned 24 hours/day with continuous monitoring of the wells, and since both the tubing and casing outlets will be piped through a SSV, the net risk, to personnel and the environment, of an ESP well which will not pass a No-Flow test is relatively Iow. Thanks. ..... Original Message ..... From: Bowen, Jerry -Alaska Sent: Monday, January 27, 2003 3:51 PM To: "rom Haunder - AOGC (tom_maunder@admin.state.ak.us)' Cc: Buster, Larry W Subject: RE: Koomey unit on Dolly Varden Tom, Per your request, the Oil Team provided the No-Flow info contained in the attached spreadsheet. I will give you a call in a few minutes. << File: No-Flow Wells.xls >> ..... Original Message ..... From: Bowen, Jerry -Alaska Sent: Friday, January 24, 2003 4:25 PM To: Tom Maunder-AOGC (tom_maunder@admin.state.ak.us) Subject: Koomey unit on Dolly Varden Tom, Hope your trip was enjoyable. Winton told me that the D-17RD Sundry Notice appeared to be "approvable" but would not be approved before your return on Monday, and that there would be one or two stipulations. This should be fine with us. FYI. We have decided to purchase a second set of 2 7/8" x 5" VBRs. Therefore, we will have VBRs in the uppermost and lowermost BOP as per the attached amended stack diagram. This provides an increase in well control capability since we will now have the ability to shut-in either pipe ram on any string we intend to run or pull through the rotary table (i.e. 3 1/2" tbg, 4 1/2" tbg, 3 1/2" DP & 5" DP). As per our earlier correspondence, we will also have the blind/shear rams in the middle BOP. << File: Dolly Stack.xls >> There is one somewhat unusual issue which we want to disclose before your inspector arrives on location to witness the BOP test on or about February 2nd. We will not be able to operate the SCANNED FEB 0 2003 1 of 2 1/29/2003 9:45 AM ~[ipula[ions Tot u-1/l-~U ~unary NOtiCe lowermost rams from the drillers remote console. However, the Koomey unit is also located on the rig floor and is behind a firewall about 15' from the drillers console. Other than the fact that the driller would have to move about 15' to operate the lower single BOP (with the 2nd set of VBR), the system will be normal. It's our position that this is within compliance since the third BOP is technically not required in a normal 3000 psi stack. Please call anytime. Thanks. Jerry F. Bowen, P.E. Consulting Drilling Engineer Office: 907-263-7640 Cell. 907-360-2490 Home: 907-688-2278 Fax: 907-263-7884 BCANNED FEB 0 A 2DO3 2 of 2 1/29/2003 9:45 AM Sundry Notice for D-17RD ESP Conversion 1 of 1 Subject: Sundry Notice for D-17RD ESP Conversion Workover Date: Tue, 14 Jan 2003 16:29:37 -0800 ' From: "Bowen, Jerry -Alaska" <jbowen@unocal.com> To: "Tom Maunder - AOGC (tom_maunder@admin.state.ak.us)" <tom_maunder@admin.state.ak.us> Tom; We received an e-mail from Jody Colombie informing us that the Commissioners will be unavailable the week of January 20th through the 26th. Unocal intends to start the D-17RD workover on or about February 1st. This Sundry for D-17RD was submitted late last week, so you obviously haven't had time to look at it. However, this is the first in a series of four or five Dolly Varden ESP conversion workovers, which involve perforating the G-zone prior to running the ESP, which will technically invalidate the No-Flow status. Therefore, the Sundry Notice includes a request for an exception to regulations concerning No-Flow status and downhole com~uipment ~ana packer). Needless to say, we are anxious to obtain AOGCC approval of this Sundry (hopefully prior to January 20th) because a last minute problem (i.e. after January 27th) would cause a costly delay in our Dolly Varden workover program. I am available to discuss this issue at any time which is convenient for you, although ypu might have to call on my cell phone if I'm not in my office. Thanks. Jerry F. Bowen, P.E. Consulting Drilling Engineer Office: 907-263-7640 Cell: 907-360-2490 Home: 907-688-2278 Fax: 907-263-7884 SCANNED FEB 0 4 20[}:2 Dolly Static BHPs from Platform Shut Down Beginning 9/22/01 G-Zone Pressures Hal Martin 10/19/200t Pressure Gradient Rate of b Pressure Between Bottom Two Wells G-Zone Benches Shut In Period Datum Pressure at End of Survey D-3RD2 G-2, 3, 4 13 Days 2518 psia 1.16 psi/hr D-4RD G-2, 3, 4, 5, 6 16 Days 3017 psia 0.40 psi/hr D-5RD No Pressure Taken Yet 4, D-26 G-2, 3, 4 11 Days 2520 psia 0.34 psi/hr D-31RD G-2, 3, 4 12 Days 2595 psia 0.78 psi/hr D-32 G-2, 3, 4 12 Days 3225 psia 0.26 psi/hr D-46 G-2, 3, 4 15 Days 2984 psia 0.50 psi/hr Survey Points 0.325 psi/ft 0.360 psi/ft 0.428 psi/ft 0.325 psi/ft 0.349 psi/ft 0.427 psi/ff Notes: Datum at -8850' SS. Dolly Commingled wells Completion Well Zone D-2ARD GIHK D-8RD GIHK D-12RD GIHK D-25RD GIHK D-27 G/HK D-28 GIHK D-40RD GIHK D-43RD GIHK FES e 4 2003 2001 Summary by Month: Individual Well Production Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Days Oil Wtr Gas 2001 2002 Gas Lift Gas Lift Gas Lift Gas L~ft Gas Lift Gas Lift Gas Lift Gas L~ft Gas Lift Gas L~ft Gas Lift Gas Lift 26 15 28 8 19 27 30 31 22 29 30 29 1,251 1,428 3,001 713 2,324 3,377 3,794 4,081 3,052 3,727 5,248 4,125 83,223 46,196 91,869 21,652 65,183 83,825 113,857 129,230 81,989 119,699 137,594 119,969 9,777 6,940 17,304 5,596 12,131 11,884 12,684 11, 128 6,217 8,383 10,510 10,966 Totals: Oil 36,121 Water 1,094,286 Gas 123,520 Cum Oil 1,321,540 CumWtr 10,782,780 Cum Gas 2,809,168 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Days Oil Wtr Gas 2002 Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 31 28 31 26 31 30 30 31 30 31 30 ~. ,~, ,,~,. ,~?~'" ,:~i~'-?4~'g~; ?~;':, ~',',"~,.~,?,~',~', .......... ,,~,~,,;', :4;3~'~'''' ~' ,,",~,~5,~-~,~. ?,,,,,, ,,, ,~4,r~.~,, ,'~,: ','?','~:~75:~, ,,', ~,,,,, .... ,,~ ,5,~2, ',~,,?~,",?~,'5,3~2,~",·, ,',,~i '~&~9~;,' ..... ~,,~,,"~6,0~iv,~ 122,046 124,683 138,247 122,341 137,374 116,495 116,491 114,369 116,240 15~8,~3-~-- 107,432 6,218 7,671 8,524 6,517 12,827 9,616 7,285 5,766 6,016 4,918 5,217 Totals: Oil 54,960 Water 1,334,675 Gas 80,575 Cum Oil 1,376,500 Cum Wtr 12,117,455 Cum Gas 2,889,743 FEB 0 zl 2003 Wednesday, January 15, 2003 Page 6 Summary by Month: 1997 Jan Feb Mar Apr May Individual Well Production Jun Jul Aug Sep Oct Nov Dec Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Days 31 28 31 30 30 29 30 31 29 Oil 4,655 3,915 4,763 4,625 3,950 3,897 5,524 4,405 3,561 Wtr 101,049 84,345 100,054 96,966 84,033 90,647 91,165 96,705 88,673 Gas 19,919 17,839 27,158 21,085 21,458 20,223 22,616 23,915 20,076 1997 Totals: Oil 52,425 Water 1,122,577 Gas 256,757 CumOil 1,139,024 CumWtr 6,452,112 1998 Jan Feb Mar Apr May Jun Jul Aug Sep Gas Lift Gas Lift Gas Lift 30 29 31 3,896 5,040 4,194 90,226 101,388 97,326 18,007 17,105 27,356 Cum Gas 1,988,302 Oct Nov Dec Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Days 31 28 31 29 31 30 31 31 30 Oil 4,635 2,900 3,906 3,131 4,306 4,059 4,744 4,372 4,105 Wtr 97,388 73,804 87,009 66,742 89,153 75,587 93,335 95,685 87,898 Gas 25,563 17,237 26,896 18,047 l 7,218 19,245 23,742 35,674 35,015 1998 Totals: Oil 46,866 Water 1,018,401 Gas 309,543 Cum Oil 1,185,890 Cum Wtr 7,470,513 1999 Jan Feb Mar Apr May Jun Jul Aug Sep Gas Lift Gas Lift Gas Lift 31 30 31 4,229 2,882 3,597 85,832 82,458 83,510 30,512 31,866 28,528 Cum Gas 2,297,845 Oct Nov Dec Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Days 31 28 31 30 31 30 31 31 29 31 30 30 Oil 3,666 3,319 3,856 4,110 4,142 4,092 4,188 3,688 3,434 3,767 3,842 4,397 Wtr 91,956 77,149 87,918 100,781 96,672 100,971 100,712 99,963 92,466 94,577 89,546 85,808 Gas 15,585 21,184 21,381 18,396 16,069 20,993 19,866 26,159 20,633 19,136 17,839 15,975 1999 Totals: Oil 46,501 Water 1,118,519 Gas 233,216 Cum Oil 1,232,391 CumWtr 8,589,032 Cum Gas 2,531,061 2000 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Days 31 29 31 30 31 30 31 30 28 29 30 30 Oil 6,342 4,495 3,603 3,800 4,093 5,629 5,914 4,258 2,705 3,919 3,991 4,279 Wtr 105,037 97,651 96,546 73,423 72,792 86,159 94,505 90,563 75,973 97,373 111,087 98,353 Gas 19,750 13,554 15,506 11,843 12,911 9,443 7,477 10,087 9,799 16,351 13,793 14,073 2000 Totals: Oil 53,028 Water 1,099,462 Gas 154,587 Cum Oil 1,285,419 Cum Wtr 9,688,494 Cum Gas 2,685,648 ,.SCANNED FEB 0 4, 2003 Wednesday, January 15, 2003 Page 5 1993 Jan Feb Summary by Month: Mar Apr May Individual Well Production Jun Jul Aug Sep Oct Nov Dec Meth Gas Lift Gas L~ft Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Days 31 28 31 30 31 30 31 Oil 7,505 7,526 7,997 7,871 7,165 5,062 3,570 Wtr 36,934 39,611 55,219 58,778 49,668 37,737 36,092 Gas 25,036 25,355 26,538 26,939 32,207 7,997 2,597 1993 Totals: Oil 79,875 Water 663,124 Gas 233,831 Cum Oil 906,014 1994 Jan Feb Mar Apr May Jun Jul Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 13 30 31 30 31 6,584 8,948 8,186 4,572 4,889 27,565 82,758 78,401 78,344 82,017 11,817 30,998 23,867 9,493 10,987 CumWtr 2,449,974 CumGas 1,283,300 Aug Sep Oct Nov Dec Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Days 31 28 31 30 31 30 31 Oil 5,014 4,894 5,836 6,235 6,582 5,911 5,631 Wtr 75,980 69,974 81,312 84,320 85,734 76,771 68,893 Gas 9,472 9,606 8,776 5,174 5,089 5,030 7,621 1994 Totals: Oil 68,237 Water 918,048 Gas 108,109 Cum Oil 974,251 1995 Jan Feb Mar Apr May Jun Jul Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 31 30 25 27 31 6,144 5,513 6,318 4,224 5,935 81,984 80,660 60,497 75,116 76,807 10,711 8,554 5,696 12,742 19,638 CumWtr 3,368,022 CumGas 1,391,409 Aug Sep Oct Nov Dec Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas L~ft Days 3 l 28 27 24 26 27 31 Oil 5,541 5,587 2,767 6,077 5,389 5,785 8,076 Wtr 75,306 57,180 29,972 99,807 90,567 96,285 86,837 Gas 13,408 4,454 10,930 19,099 13,369 31,407 27,701 1995 Totals: Oil 66,400 Water 1,012,178 Gas 184,583 Cum Oil 1,040,651 1996 Jan Feb Mar Apr May Jun Jul Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 31 30 31 30 31 8,472 4,965 4,608 4,780 4,353 106,723 89,734 89,184 96,426 94,157 26,936 5,960 5,110 15,824 10,385 CumWtr 4,380,200 CumGas 1,575,992 Aug Sep Oct Nov Dec Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Days 31 28 30 29 31 30 31 29 26 30 30 23 Oil 4,846 3,652 4,086 3,368 3,718 4,322 4,424 3,915 4,104 3,682 3,773 2,058 Wtr 86,118 84,000 86,183 84,704 84,977 82,843 83,862 72,916 67,356 64,755 92,181 59,440 Gas 17,146 12,644 13,652 15,698 13,595 9,828 13,693 9,061 11,226 9,970 16,642 12,398 1996 Totals: Oil 45,948 Water 949,335 Gas 155,553 Cum Oil 1,086,599 Cum Wtr 5,329,535 Cum Gas 1,731,545 ,SCANNED FEB 0 4. 2003 Wednesday, January 15, 2003 Page 4 1989 Jan Feb Summary by Month: Mar Apr May Individual Well Production Jun Jul Aug Sep Oct Nov Dec Meth Gas Lift Days 31 Oil 6,385 Wtr 16,493 Gas 2,521 1989 Totals: Oil 1990 Jan Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 26 31 30 31 25 13 31 30 5,432 7,306 7,166 6,960 6,016 2,519 5,659 6,236 16,326 21,626 25,242 23,714 19,947 8,478 18,250 21,138 2,439 4,715 4,283 4,967 2,608 1,238 4,037 2,764 71,279 Water 238,338 Gas 36,542 CumOil 587,972 CumWtr 919,666 Feb Mar Apr May Jun Jul Aug Sep Gas Lift Gas Lift Gas Lift 29 30 31 5,582 5,586 6,432 21,202 23,416 22,506 934 3,494 2,542 Cum Gas 403,527 Oct Nov Dec Meth Gas Lift Days 15 Oil 2,737 Wtr 11,186 Gas 483 1990 Totals: Oil 1991 Jan Gas Lift Gas Lift Shut-h~ Shut-In Gas Lift Gas Lift Gas Lift Gas Lift 17 7 0 0 20 31 30 30 3,543 2,158 0 0 4,106 5,007 4,375 6,176 13,508 5,973 0 0 27,414 31,476 23,552 28,948 1,009 499 0 0 2,024 1,475 1,681 18,603 47,796 Water 253,938 Gas 86,690 Cum Oil 635,768 Cum Wtr 1,173,604 Feb Mar Apr May Jun Jul Aug Sep Gas Lift Gas Lift Gas Lift 29 30 31 4,831 7,229 7,634 29,510 46,207 36,164 17,498 21,888 21,530 Cum Gas 490,217 Oct Nov Dec Meth Gas Lift Days 31 Oil 12,445 Wtr 54,102 Gas 24,392 1991 Totals: Oil 1992 Jan Meth Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 28 30 29 31 28 30 31 30 31 30 31 7,014 8,643 8,388 9,298 8,386 8,548 8,434 10,357 8,526 8,282 11,139 26,688 27,320 29,055 33,745 27,594 29,141 30,174 29,100 30,389 27,771 30,058 23,080 18,781 24,863 23,273 30,101 25,584 19,908 23,549 30,576 30,375 30,822 109,460 Water 375,137 Gas 305,304 CumOil 745,228 CumWtr 1,548,741 Cum Gas 795,521 Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas L~ft Gas Lift Days 31 Oil 10,109 Wtr 28,241 Gas 18,756 1992 Totals: Oil 29 29 30 26 29 31 30 28 31 30 30 9,046 8,924 8,800 7,952 7,638 5,923 4,559 4,947 4,011 3,027 5,975 22,747 24,316 25,476 23,210 25,715 15,433 8,984 18,414 8,948 8,588 28,037 21,508 23,547 19,096 25,702 19,744 19,148 15,867 22,395 28,597 22,347 17,241 80,911 Water 238,109 Gas 253,948 Cum Oil 826,139 Cum Wtr 1,786,850 Cum Gas 1,049,469 SCANNED FEB 0 ,i. 2003 Wednesday, January 15, 2003 Page 3 1985 Jan Feb Summary by Month: Mar Apr May Individual Well Production Jun Jul Aug Sep Oct Nov Dec Meth Gas Lift Gas Lift Days 31 27 Oil 5,464 1,646 Wtr 4,501 2,887 Gas 1,191 836 1985 Totals: Oil 38,081 1986 Jan Feb Gas Lift Gas Lift 22 23 2,049 2,008 2,831 3,062 412 751 Water 53,992 Mar Apr Gas Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 31 29 24 25 28 2,385 4,477 3,539 3,156 4,325 4,271 5,609 5,763 3,869 6,939 664 1,801 1,563 1,294 1,343 13,510 Cum Oil 350,396 CumWtr 243,694 May Jun Jul Aug Sep Gas Lift Gas Lift Gas Lift 22 26 19 2,628 4,140 2,264 4,218 6,491 3,551 1,061 1,603 991 Cum Gas 279,529 Oct Nov Dec Meth Gas Lift Gas Lift Days 28 28 Oil 4,960 5,996 Wtr 6,331 7,653 Gas 2,012 2,190 1986 Totals: Oil 42,754 1987 Jan Feb Gas Lift Gas Lift 31 30 3,931 4,282 6,446 6,395 1,801 2,007 Water 58,541 Mar Apr Gas Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 31 30 31 31 29 4,047 2,979 2,247 2,163 2,269 5,788 3,969 3,013 3,005 3,326 1,687 1,535 897 1,303 1,277 21,747 CumOil 393,150 CumWtr 302,235 May Jun Jul Aug Sep Gas Lift Gas Lift Gas Lift 31 30 31 2,578 4,214 3,088 3,454 5,477 3,684 1,792 3,173 2,073 Cum Gas 301,276 Oct Nov Dec Meth Gas L~ft Gas Lift Gas Lift Gas Lift Days 31 28 31 30 Oil 1,961 9,360 8,853 6,618 Wtr 2,285 18,685 23,087 19,481 Gas 1,219 4,255 5,034 3,648 1987 Totals: Oil 71,085 Water 211,164 1988 Jan Feb Mar Apr Gas Gas Lift Gas Lift Gas Lift 31 30 31 6,493 5,138 6,570 25,437 20,147 21,416 3,037 3,326 2,594 36,689 Cum Oil 464,235 May Jun Jul Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 31 30 31 29 30 7,187 6,971 3,926 4,200 3,808 17,738 17,207 17,476 16,426 11,779 3,949 1,884 2,457 2,199 3,087 CumWtr 513,399 CumGas 337,965 Aug Sep Oct Nov Dec Meth Gas Lift Gas Lift Gas Lift Gas Lift Days 23 26 29 30 Oil 2,993 2,835 3,168 3,453 Wtr 20,803 8,525 10,083 11,993 Gas 2,032 2,536 2,681 2,764 1988 Totals: Oil 52,458 Water 167,929 Gas Gas Lift Gas Lift Gas Lift 31 3O 31 4,342 4,387 3,639 14,319 13,799 11,997 2,270 1,569 1,745 29,020 Cum Oil 516,693 Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 31 29 30 30 26 3,443 4,448 9,431 5,432 4,887 13,823 11,966 19,943 16,425 14,253 1,647 2,409 2,454 2,734 4,179 CumWtr 681,328 Cum Gas 366,985 SCANNED FEB 0 zl 2003 Wednesday, January 15, 2003 Page 2 Summary by Month: Individual Well Production Well Name: Field/Pool: 1981 TRAD~G BAY UNITD-17RD MCARTHURRIVER, HEMLOCK Jan Feb Mar API: 50-733-20168-01-00 Permit to Drill: 1810230 Sales Cd: 50 Acct Grp: 1 Final Status: 1-OIL Apr May Jun Jul Aug Operator: UNION OIL CO OF CALIFORNIA Current Status: 1-OIL Sep Oct Nov Dec Meth Days Oil Wtr Gas 1981 1982 Totals: Oil 108,032 Water 32,475 Jan Feb Mar Apr Gas 58,844 May Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 11 31 31 30 31 30 31 7,395 21,801 18,477 18,670 13,290 14,910 13,489 2,173 6,329 4,619 4,668 4,! 97 4,708 5,781 2,434 10,211 7,618 7,803 8,914 11,573 10,291 Cum Oil 108,032 CumWtr 32,475 Cum Gas 58,844 Jun Jul Aug Sep Oct Nov Dec Meth Gas Lift Gas Lift Gas Lift Gas Lift Days 31 28 31 30 Oil 12,660 10,306 11,191 11,257 Wtr 8,266 5,965 6,477 7,505 Gas 8,138 7,027 7,632 5,691 1982 Totals: Oil 107,912 Water 68,868 1983 Jan Feb Mar Apr Gas Gas Lift Gas Lift Gas Lift 3l 30 30 9,680 10,087 10,831 6,189 6,725 7,221 10,771 12,255 5,461 153,098 Cum Oil 215,944 May Jun Jul Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 31 30 31 30 31 11,528 3,428 7,711 1,643 7,590 7,685 2,192 4,726 1,265 4,652 5,702 14,614 4,634 18,383 52,790 CumWtr 101,343 CumGas 211,942 Aug Sep Oct Nov Dec Meth Gas Lift Gas Lift Days 29 25 Oil 6,456 4,668 Wtr 4,870 3,819 Gas 3,441 2,117 1983 Totals: Oil 58,568 1984 Jan Feb Gas Lift Gas Lift 20 24 2,83-0 3,520 2,315 2,880 1,207 1,307 Water 52,273 Mar Apr Gas Gas Lift Gas Lift Gas Lift 24 30 31 3,416 6,409 4,801 3,217 5,139 3,696 1,867 3,009 8,871 44,327 Cum Oil 274,512 May Jun Jul Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 29 30 31 30 29 3,603 3,989 7,528 7,683 3,665 3,811 4,308 7,041 7,205 3,972 9,170 7,434 2,407 2,439 1,058 CumWtr 153,616 Cum Gas 256,269 Aug Sep Oct Nov Dec Meth Gas Lift Gas Lift Gas Lift Gas Dft Days 30 29 30 30 Oil 6,540 7,124 2,688 3,237 Wtr 3,678 4,007 2,926 3,525 Gas 1,990 1,658 506 877 1984 Totals: Oil 37,803 Water 36,086 Gas Gas Lift Gas Lift Gas Lift 24 30 30 2,546 1,862 1,779 2,773 2,235 2,135 668 550 437 9,750 Cum Oil 312,315 Gas Lift Gas Lift Gas Lift Gas Lift Gas Lift 27 30 20 26 31 1,517 3,356 299 3,517 3,338 1,821 4,268 494 3,246 4,978 390 848 67 965 794 CumWtr 189,702 CumGas 266,019 Wednesday, January 15, 2003 Page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Camille O. Taylor, Chair Tom Maunder, P. I. Supervisor DATE: July 24, 2002 FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector No-Flow Test :Unocal Dolly Varden D-17 Mr.,Arthur River Field TBU PTD 181-023 NON-CONFIDENTIAL Wednesday, July 24, 2002: I witnessed a No-Flow verification on UNOCAL's Monopod platform well #A-6 in the Trading Bay field. Following is a timeline and well status during test. 1600 Flowing at <180 scf (no fluid), Shut-in well 1650 Shut-in @ 0 psi 1750 Flow @<180 scf, 0 psi. 1820 Shut-in @ 0 psi. 1850 Flow @ <180 scf, 0 psi. Note: The gauge used to check flow was incapable of measuring below 180 scf or above 2000 scf. 30 psi test gauge used to monitor pressure. This well exhibited inability to flow to surfa~ unassisted and I recommend it be granted No-Flow status. This well is presently without a SSSV due to repairs needed for its "K~ valve. If approval from the A:O.G:C~C. iS~forthcoming the approval should be expedited. I explained to Van Crowell (Platform Lead Operator) that any cleanout, perforating or other stimulation will require another No-Flow test. SUMMARY: I witnessed No-Flow verification on UNOCAL's Dolly Varden platform well #D-17 in the McArthur River field. NON-CONFIDENTIAL CC; Dwight Johnson/Johnny Santiago (Unocal) No-Flow UNOCAL TBU D-17 07-24-02 LG.doc ALASILA OIL AND GAS CONSERYA ION COP IISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 July 25, 2002 Dwight Johnson Chris Meyers UNOCAL Field Superintendents 260 Cavair Street Kenai, Alaska 99611 No-Flow Verification TBU Well D- 17RD Gentlemen: On July 24, 2002 AOGCC Petroleum Inspector Lou Grimaldi witnessed a "no-flow" test on Well D-17RD at UNOCAL's Dolly Varden Platform, Trading Bay Unit, McArthur River Field. Mr. Grimaldi arrived on Dolly Varden Platform and observed the well flowing at rate below the meter threshold (< 180 scf). The well was shut in and the tubing pressure was noted to be 0 psi as observed on a 30 psi gauge. The well remained shut in for 1 hour and did not build any pressure. The well was opened to flow with the same minor gas flow noted as before. Similar results were observed after a 3rd shut in and flow. Throughout the observation period, no liquid flow was observed and only a slight gas flow was noted. The observed performance of TBU well D-17RD (181-023) demonstrated that the well is incapable of unassisted flow of hydrocarbons to the surface. Therefore, this well need not be equipped with a commission approved fail-safe automatic surface-controlled subsurface safetY valve ("SSSV") system. However, the well must be equipped with fail-safe automatic surface safety valve ("SSV") system capable of preventing uncontrolled flow and maintained in proper working condition. If for any reason the well becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well file on board Dolly Varden. Sincerely, mas E. Maunder, PE Sr. Petroleum Engineer MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' THRU' Dan Seamount, Commissioner · Blair Wondzell, P. I. Supervisor FROM' John Crisp? ~ ~. SUBJECT: Petroleum In~ector DATE' June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be changed out during next Platform shut down due to header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden Platform in the McArthur River Field. 24 wells, 57 components tested, 3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; NON~:CONFIDENTIAL SVS Dolly Pit. 6-22-00jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: McArthur Rv. / Dolly Var& Separator psi: LPS 110 HPS 6/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE D-01 1670800, 110 80 85 P 4 OIL D-02ARD 1750380 110 80 65! P 5 OIL D-03RD2 1830810 110 80 80 P P OIL D-04RD 1820410 110 80 80 P P OIL D-05RD 1800650 110 80 100 P P 43 OIL D-07RD2 1921550 110 80 80 P P P OIL D-08RD 1740030 110 80 75 P P P OIL D-Il 1680730 110 80 80 P P P OIL D-12RD 1800820 110 80 75 P P 43 OIL ,,~n~l~' 1810230 110 80 80 P P 43 OIL D-18' 1690040 800 700 700 P P P GAS D-20 1690950 110 80 90 P P OIL D-25RD 1780870 110 80 100 P P OIL D-26RD 1981290 110 80 75 . P P OIL D-27 1750240 110 80 60 P P OIL D-28 1760360 110 80 100! P P OIL D.30RD2 1880980 D-31RD 1760740 110 80 70 P P 43 OIL D-32 1700370 110 80 '75 P P P' OIL D-40RD 1820830 110 80 80 P P OIL D-42 1830530 .110 80 70 P P OIL D-43RD 1853110 110 80 70 P P P OIL D-46 1890610 110 80 60 P P P OIL D-47 1910110 110 80 70 P P 9 OIL , D-48 1921540 ll0i' 80 80 P P P OIL Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% [--] 90.Day Remarks: 'Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 Page I of 1 SVS Dolly Plt. 6-22-00jc 1 Unocal North Ameri/ :' Oil & Gas Division % Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 (5 Alaska Region UNOCAL RE£EIYED APR 2. 0 199~ Alaska Oil & Gas Cons. Commission Anohorage DOCUMENT TRANSMITTAL April 16, 1993 TO: Larry Grant FROM: Kirk Kiloh LOCATION: 3001 PORCUPINE DRIVE LOCATION: P.O.BOX 196247 ANCHORAGE, AK 99501 ANCHORAGE AK 99519 ALASKA OIL & GAS CONSERVATION COMM. UNOCAL' --- £ __ I _ _ ,1 il , IL , i , Li ,,i[U L L, ILI, · L[_L_ , , i _ , I,,, , _ I U , I, I, I , U_I_LL ............. J_LIJ~L___ TRANSMrlWING AS FOLLOWS ' TRADING BAY UNIT 1 blueline and 1 sepia Logs from specified wells listed below perforating Record 7 7--~Z-- --D-7RD Perforating Record Perforating Record 'Perforating Record · Perforating Record .Perforating Record Completion Record Completion Record 10-18-92 10-19-92 11-30-92 11-22-92 11-29-92 12-04-92 6-29-92 6-16-92 ql--' I~cl F --$111 O-lq D-25 D-43RD D47 G-1RD M-3 M-7 .. . . .. Completion Record ' '6-20-92 Perforating Record Perforating Record 11-21-92 11-25-92 Perforating Record 10-17-92 Perforating Record 124)3-92 Perforating Record 12-18-92 .. Continuous Gyro Tool Cement Bond Tool 7-24-92 7-24-92 M-28 Perforating Depth Control 8-12-92 M-29 TUbing Patch Record 11-13-92 PLEASE ACIGWOWLEDGE RECEIPT BY SIGNINGAND RETURNING ONE COPY OF THIS DOCUMENT TRA~SMlrr~. THANK YOU RECEIVED BY: .,~'~~..~z,_- DATED: ' ~ STATE OF ALASKA '"J¢ A KA bi L AND GAS CONSERVATION COM o~ON ~'~ · 1. 'P/pe of Request: Abandon __ Suspend __ Ooerat,on shutdown __ Re-enter suspended well '~' ,¢~ A Alter casing __ Repair we~l __ Plugg,ng __ Time extens,on __ v~imutate __" Change approved program __ Puli tubing __ Var,ance __ Perforate AA Other .__V/~,.~ 2. Name of Operator ' I 5. Type of Well: , 6. Datum elevation ,,,.,+ Development ^ ,,,,,nC,~.L IH: .... n~l r~ _ ~,,h nno.~e~r) Exmloratorv-- lr)fi' KB above M'~I~ 3. ddress ) Stratigraphic 7. Unit or Property name P f~ Rnv 1Qn247 Anchoraoe. AK ggE]~ Service__ Trading Bay Unit 4. Location of well at sudace Leg A-2, Cond. #2 Dolly 758' FSL, 1,127' FWL, Sec. 6-SN-13W-SM At top of productive mterval Varden A .1. 052' FSL, 4,360' FWL, Sec. t effective depth 1,!18' FSL, 4,592' FWL, Sec. At total depth 1,125' FSL, 4,617' FWLt Sec. 12. Present well condition summary Total depth: measured 10,800 ' true vertical 10,079' 6-8N-13W-SM 6-8N-13W-SM 6-8N-13W-SM feet feet P1 atform 8. Well number D-17RD 9. Permit number 10. APl number 5o-733-20168-01 11. Field/Pool I Hemlock i Plugs (measured) feet 10,676' - 10,800' cement Effective depth: measured 10,676 ' true vertical 9,958 ' Casing Lengm Structural Conductor Surface intermediate 2,497 ' Production 8, ].45' Liner 2,951' Perforation depth: measured Size true vertical 13 3/8" 9 5/8" 7" feet feet See Junk (measured) Cemented None 2,000 sx 3,385 sx 900 sx Measured depth True vemcal depth Attachment #1 2,497' 8,145' 10,800' 2,404' 7,850' 10,079' Tubing (size. grade, and measured depth) 4 1/2" N-80 e 7,709', 3 1/2" N-80 e 7,709' Packers and SSSV (type and measured depth) Otis "WU" Packer 0 9,923', Otis "DC" TRBV 13. Attact~ments Description summary of proposal X_.. DEC 2 2 199 - 9,978' Alaska Oil & Gas Cons. Commission Anchorage e 306' Detail~ operaPons program ~ BOP sketch ~ 14. Estimated date for commencing operation' ! 15; ~atus of well classification as: ' 11/27/92 16. if .prqpos~l., was, verb~ly appr~ " Oil X Gas Suspended ~]iKe r,d naer 11/25/92 Name of appr~er Date appr~ Se~ce i7. J hereby ce~y ~hat the foreg0i'~'~ i's true an~ corr~t to the ~ of my kn~edg~ ' Signed ~~ ~, ~~ ~tle' ~~~ ~~ Date ~" ~ ...... .' ':., , FOR coMMisSIONU~ONL~ ~ ' ¢ , ' Conditions of ap~l: ~ Commi~on so represen~five may ~tne~ ~ Appr~ No.,~ Plug integri~ ~. BOP Test ~ ~ion ~e~an~ ~ ~. I M~hanical Int~n~Te~__ Su~quentform r~uir~ 10- ~ .... ..~. <:;<~g~¢ "' ,, b J. Appr~ ~ order ~ the Commi~ Form 1~ R~~88 I David W. Johnston Commissioner I sUBMiT IN 'I'¢IIPLICATE Bench Attachment #1 Well D-17RD Perforations MD (DIL) TVD 10,052 10,096 10,178 10,214 10,260 10,330 - 10,081 - 10,120 - 10,192 - 10,232 - 10,295 - 10,380 10,405 - 10,490 9,377 9,419 9,496 9,530 9,572 9,638 - 9,403 - 9,442 - 9,509 - 9,547 - 9,605 - 9,685 9,708 - 9,787 41A/DVP PROCEDURE D- 17RD le . . . RU E-line unit. Hook up platform PA system in unit. Pressure test lubricator and BOPE to 2500 psi. Apply 4000 psi control line pressure to the TRBV (SCSSV) with the auxiliary pump and monitor for any leak off prior to RIH. Pump to be located near lower wellroom entry door. NOTE 1: Prior to arming guns and until guns are 1000' in the hole, notify logistic support & establish communication black-out. Re-establish the communication black-out when guns are 0 1,000' when POOH. NOTE 2: SI well to RIH and POOH. RIH and perforate the following intervals underbalanced (well flowing). Open choke & stabilize flow prior to perforating. RUN BENCH INTERVAL (DIL) FOOTAGE i HB-3 10,214' - 10,229' 15' 2 HB-4 10,363' - 10,378' 15' 3 HB-5 10,435' - 10,465' 30' Flow well for clean-up approximately 15-20 minutes after perforating each interval. Prior to POOH, shut in well. RD E-line. Return well to production and obtain a well test. H: \wp\WLPRO\D 17RD DOLLY VAliD'E" P(~-ATFOFIM Wireline Lubricator w/Associated BOPE ,, GREASE HEAD (Hydra.llcally Activated) LUBRICATOR MANUALLY OPERATED BOP CHISTMAS TREE -- POSITIVE CHOKE ---- 2' 5000 p.I t. ]:2" 3000 13 3/8' CASING i3-3/j 2,497' Liner ~ 7,849' 9-5/8"@ 8,145' ),, Cii: Yb'.=. H'ar. 4-;./2" .'~$L :: --i.,,. .:.SL 3G6' Otis 7ubin~ i~etrievab±e gall Valve T?'pe DC iD = ]3.813" ~ ~25' I-1/2" Otis RL GL'..! (1-6) ID = 3.g33" ~'Icllurr'; VR-STD Vaive w/RA La,cra 3,778' ~.-~ 5,246' ~$3 6,285 ' :~4 7,157' 7,668' 7,709' ~,849' 9,501' 9,821' 9,920' :.-: 6 XO 4-!/2" ASL :< 3-i/2" ASL 3-1/2" Otis RW GLI.i (7) ID = 2.813" McMurrv JR Orifice w/BK-2 Latch 3-1/2" Otis RW GL)i (8-9) ID = 2.813"' ~IcMurry Dummy Valve w/BK-2 Latch ~:9 Dummy valve as above Otis 4" x 3" Loca~or and Seal Assy. 9,922' Otis WD Packer w/5' Seal Bore Extension & Bell Guide 9,947' Otis 2.75" ID X-Nipple 9,978' O~is 1/2 cue Muleshoe ID ==. ~ 992" Perforations (DIL) Bench 1 10,052' - 10,080' Bench 2 10,096' - t0,120' Bench 3 10,178' - 10,192' Bench 3 10,214' - 10,232' Bench 4 10,260' - 10,295' Bench 4 10,330' - 10,360' Bench 4 10,366' - 10,378' Bench 5 10,405' - 10,490' Fish - 22' Strip gun 6/29/92 Tagged Fill @ 10,538' WLM 6/20/92 PBTD @ 10,676' TD @ 10,800' EVO - 7/24/92 ( ( ORI STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. ODerat~ons oenormea: ODerahon snutOown m Stm, tutate ~ Plugging ~ Perforate X Pull tulmng ~ Alter camng ~ Reoar well .._._ 2. I~ame of O~)erator t "'5. Type ct Well: , ~ Develooment ;. IIMrtPAI ,,/Mnv,=+hnn A~I rn - q,,h Cln~r~f F) Exl3oratory__ P.O. Box 190247. Anchoraae. AK 9951(} Sen.ce~ 4. Locat~onawe, atsurface Leg A-2, {;ond. #2 Dolly Varden Platform 758' FSL, 1,127' FWL, Sec. 6-SN-Z3W-SM At top of productive interval 1,052' FSL, 4 360' FWL, Sec. At effective aepm ' 1,II8' FSL, 4,592' FWL, Sec. At total cleptn 1.125' FSL. 4.617' FWL, Sec. 12' Present well conamon summary Total aeom. measurea 10,800 ' true vertlca; 10,079' Eftect~ve aeDtr, measured true vert]cai l_0,676' 9,958' Casing · Length Structural Concluctor Sudace Intermeamte 2,497 ' ProctuctIon 8,145 ' Liner 2,951' Perfora[~cn CleDtr~ measurerJ 6-8N- 13W-SM 6-8N-13W-SM 6-8N- 13W- SM Size 3/8" 5/8" 7" feet Ptugs (measurecl) feet feet JunK {measured) feet [rue vertical Cemented GINA 6. Datum e~evatlon (DF or KB) ].06' KB above MSL 7. Umt or Property name Trading Bay Unit 8. Well number D-17RD 9. Perm~ numDer/aDDroval numoer 10. APl number 50-733-20168-01 11. Field/Pool Hem] ock 10,676' - 10,800' cement None Measurect depth True vertical depth 2,000 sx 2,497' 2,404' 3,385 sx 8,145' 7,850' 900 sx 10,800' 10,079' See Attachment #1 leet Tubing {s~ze, grade, and measured oepm} 4 1/2" N-80 @ 7,709', 3 1/2" N-80 (a 7,709' - 9,978' PacKers ant SSSV (type and measured cleoth) 0t.i~ "WP" Packer 0 9.923', 0ti. s..."DC" TRBV 0 306' ~3. Stimulation or cement soueeze summary i ntervats treated (measured) RECEIVED Alaska 0il & Gas Cons. CommiSs~o~ 'Anchorage Treatment description including volumes usecl and final pressure Reoresentauve Daily Average Proaucaon or tniem~on Da~a Oii-Bbl Gas-Md Water-Bbl Casing Pressure Pr,or to we, ooeration 146 1074 335 1100 Tubing Pressure 140 Subseauem to o~)erm, on 142 .-"~"' 999 315 1040 15. Attachments t 16. Status of welt c~assdicat~on as: Copies of Logs anM Surveys run I Daily Report of Well Operaaons ~ 17. I nereoy cen,h)tnat me'toregomg ,s true and correct to me I:~a pt my Know~eage~ " Service , S,!c.!nec %~.~ Form 1(:~404 R 140 ,,, Bench 1 2 3 3 4 4 .5 Attachment #1 Well D-17RD Perforations 10,052' - 10,081' 10,096' - 10,120' 10,178' - 10,192' 10,214' - 10,232' 10,260' - 10,295' 10,330' - 10,380' 10,405' - 10,490' TVD 9,377' - 9,403' 9,419' - 9,442' 9,496' - 9,509' 9,530' - 9,547' 9,572' - 9,605' 9,638' - 9,685' 9,708' - 9,787' 41A/DVP _~.. RECEIVED DEC 2 2 1992 AJlaska Oil & Gas Cons. Commission Anchorage DAILY WELL OPERATIONS D- 17RD Hold safety meeting. lubricator to 2500 psi. gun. 4SPF. 180 deg phased. 90 deg offset, 22 g. DP charges. RIH. to obtain underbalance and perforated the following intervals: RUN #1 HB-1 10,065 - 10,080 DIL Fired #2 HB-1 10,050 - 10,065 DIL Fired RD. Return well to production and test.' Install auxiliary pump at 4000 psi on SCSSV. Pressure test Test good. Establish CBO and arm 15' of 1-11/16" pivot F 1 owed we 11 H:\wp\WELLOPS\D17RD RECEIVED DEO 2 2 1992 Alaska Oil & Gas Cons. Commissior~ Anchorage 1. Operations performed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ODerat,on snu!clown m St,mutate ~ Plugging ~ Pull tub, rig ~ Alter casing t ReDa~r well ~ 2. Name of Operator / 5. Type of Well: Develooment IIl~lt3PAI (U~v.=-I-hnn F1~1 Cn- R,,h (1,n~r~f r) '3. Aad~'~ ...................... / Ex,oloratory Stral~graohic P.0. Box ]0(3247 Anchoraoe, AK 0~)51 Sauce__ 4. Location of well at surface Leg A-2, Cond. #2 Doll.y Var'den Platform 758' FSL, 1,127' FWL, Sec. 6-eN-Z3W-SM Perforate ~ Other IN 6. Datum elevation (DF or KB) 106' KB above MSL ,, 7. Unit or Property name Trading Bay Unit 8. Well number D-17RD feet At top of productive ~nterval 1,052' FSL 4,360' FWL Sec. At effective depth ' ' 1,118' FSL, 4,592' FWL, Sec. At total depth 1.125' FSL, 4,§17' FWL, Sec. 12. Present well condition summary Total clepth, measured 10,800 ' true vemcai 10,079' 6-8N-13W-SM 6-8N-13W-SM 6-8N-13W-SM 9. Permit number/approval number ,81-23 10. APl number 5o--733-20168-01 11. Field/Pool Hem] dC k feet feet Plugs (measured) 10,676' - 10,800' cement Eflecuve depth Casing Structural measurec~ true vertical 10,676' 9,958' Length Size feet feet Junk (measured) Cemented None Measured depth True vertical depth Conductor Sudace Intermediate 2,497' 13 3/8" Production 8,145' 9 5/8" Liner 2,951' 7" Perfora[~cn depm' measured 2,000 sx 3,385 sx 900 sx 2,497' 8,145' 10,800' 2,404' 7,850' 10,079' See Attachment #1 true vemcal Tubing Is]ze, grade, an(] measured depth) 4 1/2" N-80 0 7,709', 3 1/2" PacKers and SSSV (type and measured depth) ~l~ "WD" Packer @ 9,923', Otis 13. Stimulation or cement squeeze summary intervals treated (measured) N-80 0 7,709' - 9,978' "DC" TRBV 0 306' Treatment description ~ncluamg volumes used and final pressure RECEIVEI) G~s Cons, Anchorage 14. Representative Daily/Averaae Proaucaon or Iniecuon Dat~ Oii-Bbl Gas-Md Water-Bbl Casing Pressure P rior to we, operation 142 999 315 Subseduent to operation 171// 1166 522 15. Attacl3ments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations X 17. I nerel3y certify that the toregang ~s true and correct to the best bt my l~owtedge. 1040 1280 Oil X Gas ,. Suspended, SerV~ce Tubing Pressure 140 150 ii SUBMIT IN DUPLICATE Bench Attachment #1 Well D-17RD Perforations MD (DIL) TVD 10,052 10,096 10,178 10,214 10,260 10,330 - 10,081 - 10,120 - 10,192 - 10,232 - 10,295 - 10,380 10,405 - 10,490 9,377 9,419 9,496 9,530 9,572 9,638 - 9,403 - 9,442 - 9,509 - 9,547 - 9,605 - 9,685 9,708 - 9,787 41A/DVP RECEIVED DEC 2 2 1992 Alaska Oil & Gas Cons. r~ommissiot'~ Anchorage DAILY NELL OPERAT]ONS D- 17RD 11/29/92 Hold safety meeting. Lock out SCSSV with auxiliary pump. Pressure test lubricator to 2500 psi. Test good. Establish CBO and arm 15' of 1-11/16" pivot gun 4SPF. 180 deg phasing, 22 gr charges. RIH. Flowed well to obtain underbalance and perforated the following intervals: RUN #1 HB-3 10,214 - 10,229 DIL Fired HB-4 10,363 - 10,378 DIL Fired RD. Secure well & return to production. 12/1/92 Hook up auxiliary pump to SCSSV @ 4000 psi. MU RS, 8' stem, KJ, OJ, spangs, and 2.70" gauge ring. PT lubricator to 2500 psi. Test good. RIH. Tag fill 0 10,474' WLM. POOH. RIH w/ RS 8' stem, KJ, OJ, spangs, and tubing end locator. Locate EOT at 9974' WLM. Secure cap and. return well to production. 12/3/92 Safety briefing. R/U lubricator. Pressure test to 2500 psi. Test good. Established CBO. MU & armed 30' gun. RIH w/ 30' EJ III, 4SPF, & 0 degree phased -o-ffset 30 deg right. Perforated HB-5. Underbalanced from 10,435 - 10,465 DIL. POOH. OOH w/ strip. All shots fired. RD. Return well to production. H: \wp\WELLOPS\D 17RD RECEIVED DEC '2 2 1992 Alaska Oil & Gas Cons. IJummissio~'~ Anchorage STATE OF ALASKA AL - AOILANDGASCONSERVATIONCOMMI : N APPLICATION FOR SUNDRY APPROVALS !. Type oi Request: Abandon __ Suspend __ Alter casing __ Repair welt __ Change aPl3rovea program __ Operation slqutdown __ Re-enter suspended well __ Plugging __ Time extension __ vStimulate __ Pull tubing __ Variance __ Perforate ~ Other 2. Name of Operator / 5. Type of Well: ,,,,nrA, /u-,,,,,,+N,,,,, r~.; 1 rn _(;:ljb Op~ratNr) Development X . ,.,,,..,,., ..................... Exploratory- 3. Address ' f Stratigraphlc __ P_0_ Bn_× 1_902a7 Anchnrane. AK 99~]g Service__ 4. Locatlon of well at sudace Leg A-2, Cond. ,f2 Do]]y Varden Platform 758' FSL, 1,127' FWL, Sec. 6-SN-13W-SM 6. Datum elevation (DF or KB) ]06' KB above MSL Z Unit or Property name Trading Bay Unit 8. Well numOer D-17RD At top of productive ~nterval .1.052' FSL 4 360' FWL Sec At effective depth ' ' ' ' 1,!18' FSL, 4,592' FWL, Sec, A[ total depth 1,12§' FSL, 4,617' FWL, Sec. 12. Present well condiUon summary Total depth: measured 10,800 ' true vert,cal 10,07 9' 6-8N-13W-SM 6-8N- 13W-SM 6-8N-13W-SM 9. Permit numl3er R1-2~ 10. APl number so-733-20168-01 11. Field/Pool Hemlock feet Plugs (measured) feet 10,676' - 10,800' cement E.r'f. ect,ve depth: measured 10,676 ' true vertical 9,9581 Casing Lengm Structural Conductor Surface 2,497' intermediate Production 8,145 ' Liner 2,951' Perforation depth: measured Size true vertical 13 3/8" 9 5/8" 7" feet Junk (measured) feet Cemented 2,000 sx 3,385 sx 900 sx See Attachment #1 None Measured depth True vertical depth 2,497' 8,145' 10,800' 2,404' 7,850' 10,079' RECEIVED Tub,rig (size, grade, ano measurea depth) D E C - 7 4 1/2" N-80 e 7,709', 3 1/2" N-80 e 7,709' - 9,978' Packers and SSSV (type and measured depth) Alaska 0ii & Gas Cons. Otis "WD" Packer @ 9,923' Otis 'IDC" TRBV @ 306' Anchorage 1~. Attac.~ment~ Des'cnption summary of propOsal __ Detailed operati'0ns program X_.. ' BOP sketch'X__' 14. Estimated date for commencing operation I 11/21/92 16. If proposal was verbally apP~ov~ Mike Minder 11/20/92 Name of approver Date approved ! Service 17. I here0y certify that the fore'~ing is true and correct to the best of my knowledge, ~1~, ~ ' FOR COMMISSION USE'ONLY Conditions Of ap~,bval: Notify CommiSSion so representative may witness Plug integrity ~. BOP Test __ Location clearance ~ Mechanical Integnty Test ~ Subsequent form required 10- ¥{~ ,Y Approved by order of the Commission Form 10-403 Rev 06/15/88 Original g' c,!gned By David W, Johnston 15; Staius of weli Iclassification as: Oil ~ Gas __ Suspended __ 'Mobil Oil Corporation MOBIL CRUDE O!L PRICE BULLETIN WEST COAST BULLETIN NO. 318 ONE WORLD TRADE ~~ LONG BEACH, CALIF~ Effective T:O0 A.M., December 1, 1992, subject to change without notice, subject to the terms and conditions (:f its division orders and other contr~cts, arid subject to required certifications, Mobil Oil Corporation ~;i[l pay the posted prices listed belo~ per 42-gallon barrel of marketable crude oil, not to exceed 7,5# Reid Vapor Pressure, of the fol!.o,wing types arxt grades purchased by it fr~m, the field designated. The prices ,~F~iy' to quantities of cr'u~e dcrivea fro,,i~, the use of 'iC,'O perce:-..~ tank, tables or as ~easured by approv~ automatic custody [r~nsfer f~cilities with full deduction for basic sediment a.~ ua~er, ~nd ocr'reeled for' t~hq~pe:'ature to 60°F. Posted Price FIELDS °APl S/Barrel ge~ridge S, (under 28) 13.0 12~75 Belridge S, (28 & above) 3!.0 ~5.55 Br'ea-Oi. ind~ 19.0 14.60 Cat Ca~yon ~es'[ ~4,0 11.90 CoaL~nga !5.0 13.05 (~_)Cook Inlet Area 35,~. 15,~5 ~E ~0 ~2.~,0 De[ Valle 2! 0 ~3,95 Edison 18.0 13.50 Greeley 32.0 ~5.~0 Huntin~!te~ ~each 16.0 Ker~ F!'o~t/Ker~ River 13,0 i2.75 Kettleman ~iiL[ 3~.0 !5.90 Lon9 Beach (Signal Hi[|) 26,0 15.15 Lost Ni~ls (u~der 28) 18.g 13.50 Lost Hills (28 & above) 31.0 !5,55 McKittrick !3.0 12,75 Midway-Sunset 13.0 12,75 Posted Price FIELDS °API S/Barrel Placer'~t~ !2.0 I2.60 Pt, Pedernates (Onshore} !6.0 11.20 Pyramid Hills 18.0 13,50 Ramona , 20.0 13..80 Richfield !9.0 1~.10 Rjncon 28.0 !4,70 R~o Bravo ~2.0 15.25 San Afdc 12,0 11.55 Santa Fe Springs 31.0 15.90 Santa Maria Valley. 13.0 1:1.65 Saticoy 33,0 15.55 South El~wood Offsh9re ~2.0 10.60 ~ra~ev~n~ ~6,0 13.20 Tejon Hills 28.0 15.10 Torrance !9~0 Ventura Avenue 2B.O 14.90 Wi tmihgton 17.0 13 ~$0 All prices ~isted are subject to the fo~[ouing increases and decreases for each tenth degree of gravity respectively above or betow the base posted gravity: ~.,ICE ADJUSTMENT GRAVITY RANGE °APl $/BBL/TENTH °AP! Above 40 =APl 0.000 34.0 to 40.0 °APl 0.0!0 20.0 to 34,0 °AP! 0.015 * Bei~w 20 ~APl 0.015 * * Indicates a change, RECEIVED DEC - 7 t992 Alaska 0il & Gao Cons. CommiSSiO~'~ Anchorag~ MOBIL Oil CORPORATION WEST COAST CRUDE OIL SUPPLY PROCEDURE D- 17RD Reperforate HB- 1 · · · · · Obtain a 24-hour well test with a minimum of four (4) WC's. Conduct safety meeting. Ensure adequate lighting for night operations. Skid Rig over well D-17RD. (Leg A-2). RU E-line unit. Hook up platform PA system in unit. Pressure test lubricator and BOPE to 2500 psi. Apply 4000 psi control line pressure to the TRBV (SCSSV) with the auxiliary pump and monitor for any leak off prior to RIH. Pump to be located near lower wellroom entry door. NOTE 1: Prior to arming guns and until guns are 1000' in the hole, notify logistic support & establish communication black-out. Re-establish the communication black-out when guns are @ 1,000' when POOH. NOTE 2: SI well to RIH and POOH. RIH w/ 1-11/16" pivot gun 4 SPF, 180 degree phasing, and perforate the following intervals underbalanced (well flowing). Open choke & stabilize flow prior to perforating. RUN BENCH INTERVAL (DIL) FOOTAGE i HB-1 10,065' - 10,080' 15' 2 HB-1 10,050' - 10,065' 15' Flow well for clean-up approximately 15-20 minutes after perforating each interval. Prior to POOH, shut in well. RD E-line. Return well to production and obtain a well test. H:\wp\WLPRO\D17RD RECEIVED DEC - ? 1992 Alaska Oit & Gas Cons. Oommissio~ Anchorage (oOLLY VARDEN PL' TFo. Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP · 4' ~1~.-1.$~. 5000 CHISTMAS TREE --- POSITIVE CHOKE R' C IVE. D DEC ' 7 19~2 ~,~asi(a Oil & 6as 6o~s. Anchorage ----- 2' 5000 psi --- 2' 3000 pal 13 3/8' CASING 13-3/8~ 2,497' iradin~_ Sa,.' 'Well D- 17RD CiW Tbs. H,zr. $-t/2" ASL :c ~-i/2" ASL 306' Otis Tubing Retrievable Bail Valve Type DC ID = 3.813" 125 ' 4-1/2" Otis RL GLM (1-6) ID : 3.833" .'lcl{urry VR-STD Valve w/RA Latch 3,778' ~2 5,246' #3 6,285' #4 Top of 7" Liner @ 7,849' 9-5/8" @ 8,145' 7,157' 7,668' 7,709' 8,849' 9,501' #5 #6 XO 4-1/2" ASL x 3-i/2" ASL 3-t/2" Otis RW GLM (7) ID = 2.813" McMurry JR Orifice w/BK-2 Latch 3-1/2" Otis RW GLM (8-9) ID = 2.813"' McMurry Dummy Valve w/BK-2 Latch 9,821' #9 Dummy valve as above 9,920' Otis 4" x 3" Locator and Seal Assy. 9,922' Otis WD Packer w/5' Seal Bore Extension & Bell Guide 9,947' Otis 2.75" ID X-Nipple 9,978' Otis 1/2 cut Muleshoe ID = 2.992" Perforations (DIL) Bench 1 10,052' - 10,080' Bench 2 10,096' - 10,120'RECEIVED Bench 3 10,178' - 10,192' Bench 3 10,214' - 10,232' DEr' 7 '~g Bench 4 10,260' - 10,295' Alaska 0ii & Gas Cons, Co~,ntnissi Anchorags 5erich 4 10,330' - 10,360' Bench 4 10,366' - 10,378' Bench 5 10,405' - 10,490' Fish - 22' Strip gun 6/29/92 Tagged Fill @ 10,538' WLM 6/20/92 PBTD @ 10,676' TD @ 10,800' EV0 - 7/24/92 A~KA OIL AND G~ CONSERVATION RF_POFrr OF SUNDRY WELLOPEFIATIONS 1. Operations 13eriormea: Operat,on snutclown __ Stimulate m Pluggl~ ~ Perforate L L Pull tubing ~ Alter c_~.~ng ~ Repmr well __ Other 2. Name of Operator I 5. Type ot Well: 3. Add~'j~' .... ' .................... ~' .... l-' St~rapt~ic P_d_ Rn¥ lql3947 Anchnran~.. AK qq~l(:l Service~ 4. Locat,on of well at sudace Leg A-2, Cond. #2 Dolly Varden Platfom 759' FSL, 1,127' FWL, Sec. 6-SN-13W-SM At top of productive interval 1,052' FSL 4,360' FWL Sec. 6-8N-13W-SM At effective depth ' 1,118' FSL, 4,592' FWL, Sec. 6-8N-13W-SM At total depth 1.125' FgL. 4.617' FWL. Sec. 6-SN-13W-SM 12, Present well condition summary Total depth: measured 10,800 ' feet Plugs (measured) true vertical 10,079' feet 6. Datum elevation (DF or KB) 1tAR, VD =h~,,-, MC, I ~7.-0nit (:;F ~ ro~::~t~ n-ar~e- - Tradino Ba_v Unit 8. Welt nu-mDer D-Z7RD 9. Permit number/approval num~3er i 1-O~-Afii-n~u~Ger--- 50--733_20~RR_~ 11. Field/Pool Hemlock 10,676' - 10,800' cement feet Effective depth: measured feet true vertical 10,6 7 6 ' feet 9,958' Casing Length Size Cemented Structural Junk (measured) None Measured depth True vertical depth Conductor Surface Intermediate 2,497' 13 3/8" 2,000 sx 2,497' 2,404' Production 8,145' 9 5/8" 3,385 sx Liner 2,951' 7" 900 sx Perforation depth: measured See Attachment #1 8,145' 7,850' 10,800' 10,079' true vertical Tubing (size, grade, and measured depth) 4 1/2" N-80 g 7,709', 3 1/2" N-80 e 7,709' - 9,978' Packers and SSSV (type and m~sured depth) flf'i~ "WI)" Parlour 0 q.q23'. Otis nDC" TRBV 0 36)6' 13. Stimulation or cement squeeze summary Intervals treated (measure(i) RECEIVED Treatment description including ~olumes used and final pressure 14. Representative Daily A~'acje Procluction or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 178 1211 349 1!10 140 Subsequent to operation 239 1089 459 !150 15. Attachments ' 11~ Status of well classification as: Copies of Logs and Surveys run "-- I Daily Report of Well Operations ~ Oil _..~X. ~ ~ Suspended ~ 17. I hereby certify that the foregoi~ is true and correct to the best of my ~eclge. Signed ~ .c~..~.~ ~, Form 10-404 Fle(~/l~ ,~rvice 140 I Bench Attachment #1 Well D-17RD Perforations MD (DIL) TVD 10,052' - 10,081 10,096' - 10,120 10,178' - 10,192 10,214' - 10,232 10,260' - 10,295 10,330' - 10,380 10,405' - 10,490 9,377' - 9,403 9,419' - 9,442 9,496' - 9,509 9,530' - 9,547 9,572' - 9,605 9,638' - 9,685 9,708' - 9,787 41A/DVP DAILY ~/ELL OPERATIONS D- 17RD 7/27/92 Safety meeting. R/U and tested lubricator to 2500 psi. OK. RIH w/ 2-1/8" st,rip gun offset 30 degrees. POOH. All shots fired. RIH. Perf 10,360'-10,380' DIL. POOH. All shots fired. RIH. Perf 10,096' - 10,120' DIL. POOH. All shots fired. 7/28/92 RIH. Perforat,ed 10,052' - 10,081' DIL. POOH. production. R/D. Put. well back on H:\wp\WELLOPS\D17RD ALASKA el L AN D GAS CONSERVATION COM MIsSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Pull tubing __ Alter casing m Repair well __ 2. Name of Operator ! 5. Type of Well: Development ~ UNOCAL (Marathon 0il Co - Sub Operat r) Exploratory__ 3. Address ! Stratigraphic __ P.O. Box 190247 Anchorage, AK 9951~ Service__ 4, Location of well at surface Leg A-2, Cond. #2 Dolly Varden Platform 759' FSL, 1,127' FNL, Sec. 6-SN-13N-SH At top of productive interval 1,052' FSL, 4,360' FWL, Sec. 6-8N-13W-SM At effective depth Operation shutdown __ Stimulate __ Plugging __ Perforate Other __ 6. Datum elevation (DF or KB) ].06' KB above MSL 7. Unit or Property name Trading Bay Unit 8. Well number D-17RD 9. Permj number/app~val number · 81~-23 / 10. APl humbler 1,118' FSL, 4,592' FWL, Sec At total depth 1,125' FSL, 4,617' FWL, Sec 12. Present well condition summary Total depth: measured 10,800 true vertical 10,079 Effective depth: measured true vertical 10,676 9,958 Casing Length Structural Conductor Surface Intermediate 2,497 ' Production 8,145' Liner 2,951' Perforation depth: measured · 6-8N-13W-SM . 6-8N-13W-SM feet , feet feet I feet I true vertical Tubing (size, grade, and measured depth) 13. Size 5°-733-20168-01 11. Field/Pool Hemlock Plugs (measured) 10,676' - 10,800' cement Junk (measured) None 13 3/8" 9 5/8" 7" Cemented Measured depth True vertical depth See 2,000 sx 2,497' 2,404' 3,385 sx 8,145' 7,850' 900 sx 10,800' 10,079' Attachment #1 p4.1/2" N-80 e 7,7,09', 3,1/2" N-80 0 7 709' - 9 978' acKers and SSSV (type and measured d~pth) ' I~c mmwr)lm D~b~ .Gl O O~)qm StFm'ula~tion ~F'cer~e~'~l'~;ge~e s~r~-a'Fy ' ............... RECEIVED A U6 1 199 R)aska Oil & Oas Gan. ..--- feet. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 6/28/92 304 ',~' 1232 789 1150 Subsequent to operation 7/1/92 337 -'"' 1378 751 1150 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run ~ I Daily Report of Well Operations ~ Oil X_~ Gas __ SuSpended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Signed Form 10-404 Rev 0~/88 Tubing Pressu re 135 ;140 Date "( J~ t [ ~') ~-'' SUBMIT IN DUPLI~3ATE :~ Bench Attachment #1 Well D-17RD Perforations MD (DIL) TVD 10,052' - 10,081' 10,096' - 10,120' 10,178' - 10,192' 10,214' - 10,232' 10,260' - 10,295'j 10,330' - 10,360' 10,366' - 10,378' 10,405' - 10,490'~/ 9,377 9,419 9,496 9,530 9,572 9,638 9,671 - 9,403 - 9,442 - 9,509 - 9,547 - 9,605 - 9,666 - 9,683 9,708 - 9,787 41A/DVP RECEIVED AUG 1 ? 199~ Alaska Oil & Gas Cons. Commission Anchorage DAILY NELL OPERATIONS D-17RD 6/29/92 Hold Safety/Operational meeting. SWS reload lines, RU. Lock open SCSSVw/ aux. pump. Hold pre-pressure test meeting w/SWS, operator #1, production foreman. Bleed tree cap, RU lubricator on wellhead. RU communication {portable PA) in unit. PSI test lubricator & BOPE to 2500 psi. Slight leak. c/o one o-ring, repressure test -- GOOD TEST. Establish CBO. Arm 30' 2-1/8" strip guns; enerjet III's, 4SPF0 0 degrees phase affect 30 degrees to left looking downhole. SI flowline, gas lift, open swab valve g RIH w/'perf guns. Out tbg tail w/ guns. Flow well to obtain underbalance. Correlate. Fire gun to perforate HB-5 10,460' - 10,4g0' DIL. GOOD INDICATION GUNS FIRED. SI flow line. Start POOH w/guns. Establish CBO w/ guns at 1000' Finish POOH. Bleed lubricator. B/O guns. All shots fired. 22' of strip lift in hole. Arm 30' 2-1/8" strip gun, 4 SPF 0 degrees phase, offset 30 degrees to left looking downhole Open swab, RIH w/well SI. Out of tbg tail. Flow well to obtain underbalance. Correlate. Fire gun to perforate HB-5 10,420' - 10,460' DIL. GOOD INDICATION GUN FIRED. SI well. Start POOH w/ gun. Establish CBO w/ guns at 1000' Finish POOH. Close swab, bleed lubricator, B/O guns. All shots fired. Ful{ recovery of strip. SWS RD. TURN WELL OVER TO PRODUCTION. H = \wp\WE L LOPS\D 17RD 13-3/~ 2,497' Top of 7" ~ Liner @ J 7,849' /~ 9-5/8" @ 8,145' iradin~ Sa,.' UnL? Well 'D- I'7RD~~ CtW Tbn. Hzr. 4-l/2" ASL x 4-1/2" ASL 306' Otis Tubing Retrievable Ball Valve Type DC ID = 3.813" o 125' 4-1/2" Otis RL GLM (I-6) ID = 3.833" lIcHurry VR-STD Valve w/RA Latch 3,778' ~2 5,246' ~3 6,285' P4 7,157' 7,668' 7,709' 8,849' 9,501' 9,821' 9,920' XO 4-1/2" ASL x 3-1/2" ASL 3-1/2" Otis ~ G~M (7) ID = 2.813" McMurry JR Orifice w/BK-2 Latch 3-1/2" Otis RW GLM (8-9) ID = 2.813"° McMurry Dummy Valve w/BK-2 Latch #9 Dummy valve as above Otis 4" x 3" Locator and Seal Assy. 9,922' Otis WD Packer w/5' Seal Bore Extension & Bell Guide 9,947' Otis 2.75" ID X-Nipple 9,978' Otis 1/2 cut Muleshoe ID = 2.992" Perforations (DIL) Bench 1 10,052' - 10,080' Bench 2 10,096' - 10,120' Bench 3 10,178' - 10,192' Bench 3 10,214' - 10,232' Bench 4 10,260' - 10,295' Bench 4 10,330' - 10,360' Bench 4 10,366' - 10,378' Bench 5 10,405' - 10,490' Fish - 22' Strip gun 6/29/92 Tagged Fill @ 10,538' WLM 6/20/92 PBTD @ 10,676' TD @ 10,800' EVO - 7/24/92 STATE OF ALASKA ( ' 0 I1 I G IN ALASKA OIL AND GAS CONSERVATION COMMISSION - APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casmg __ Repair well __ Change approved program __ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ . Stimulate __ Pull tubing __ Variance __ Pedorate X Other __ 2. Name of Operator / 5. Type of Well: UNOCAL (Marathon Oil Co - Sub Operate)r) De..ve/,°_P__m. ent-- , ! ~-xpmora[ory_ 3. Address . ! Stratigraphic __ P.O. Box 190247 Anchorage, AK 9951~9 Service__ Lug A-2, Cu.d. #2 Do-Fly Varden Piatfonmm 4. Locat~'~nfl we.J.I Rt sur'facR 759' ]:ST_, 1-,'127' FWL, Sec, 6-8N-13W-SH 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-ZTRD 9. Permit number 81-23 10. APl number 50- 733-20168-01 11. Field/Pool Hemlock At top of productive interval 1,052' FSL, 4,360' FWL, Sec. 6-8N-t3W-SM At effective depth 1,118' FSL, 4,592' FWL, Sec. 6-8N-13W-SM Attoti,d~t~' FSL, 4,617' FWL, Sec. 6-8N-13W-SM 12. Present well condition summary Total depth: measured true vertical 10,800' feet 10,079' feet Effective depth: measured true vertical 10,676' feet 9,958' feet Casing Length Structural Conductor Surface 2,497' Intermediate Production 8,145 ' Liner 2,951' Perforation depth: measured 13 9 true vertical Plugs (measured) Junk (measured) Size Cemented 3/8" 2,000 sx 5/8" 3,385 sx 7" 900 sx See Attachment #1 Tubing (size, grade, and measured depth) 4 1/2" N-80 0 7,709', 3 1/2" N-80 O 7,709' - 9,978' Pa~.~e. rs ar~ ~V.{typ~ and rDe&su [e_cLd~epthl "DC" ut;is 'wu'- PacKer La 9,923 , Otis TRBV ~ 306' 10,676' - 10,800' cement None Measured depth True vertical depth 2,497' 8,145' 10,800' 2,404' 7,850' 10,079' RECEIVED AUG 1 ? 199~ Alaska 0il & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal __ Detailed operations program X BOP sketch 14. Estimated date for commencing operation 7/24/92 16. If proposal was verbally approved 7/23/92 Oil X' Name of approver Mi ke Mi nder Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~ ~ ~ (~ ~ Title ~. ~ · FOR OOMMi~8~ION USE ONLY Conditions of ap~)val: l~ify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- 15. Status of well clasSification as: Gas __ Suspended__ Original Signed By Approved by order of the Commission David W, Jei~nston ~~, Date "TI%t o)~.. IApproval No.c] ~. ~ 0 ,kpproved Copy Returned Commissioner Date %/,2 O/~' .~ SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 Bench Attachment #1 Well D-17RD Perforations MD (DIL) TVD 10,052' - 10,081' 10,096' - 10,120' 10,178' - 10,192' 10,214' - 10,232' 10,260' - 10,295' 10,330' - 10,360' 10,366' - 10,378' 10,405' - 10,490' 9,377 9,419 9,496 9,530 9,572 9,638 9,671 - 9,403' - 9,442' - 9,509' - 9,547' - 9,605' - 9,666' - 9,683' 9,708 - 9,787' 41A/DVP RECEIVED AUG 1 ? 199~ Alaska Oil & Gas Cons. Commission Anchorage gELL D- 17RD · ® Be Obtain a 24-hour well test with a minimum of four (4) WC's. Conduct safety meeting. Ensure adequate lighting for night operations. Skid Rig over well D-17RD. (Leg A-2). RU E-line unit. Hook up platform PA system in unit. lubricator and BOPE to 2500 psi. Pressure test Apply 4000 psi control line pressure to the TRBV (SCSSV) with the auxiliary pump and monitor for any leak off prior to RIH. Pump to be 1 ocated near lower wel 1 room entry door. NOTE 1: Prior to arming guns and until guns are 1000' in the hole, notify logistic support & establish communication bl ack-out. Re-establ i sh the communi cati on bl ack-out when guns are ~ 1,000' when POOH. NOTE 2: SI well to RIH and POOH. RIH w/2-1/8" strip guns 4 SPF, 0 degree phasing, offset 30 degrees and perforate the following intervals underbalanced (well flowing). Open choke & stabilize flow prior to perforating. RUN BENCH I HB-4 2 HB-2 3 HB-1 INTERVAL (DIL) 10,360'- 10,380' 20' 10,096' - 10,120' 24' 10,052' - 10,081' 29' FOOTAGE Flow well for clean-up approximately 15-20 minutes after perforating each interval. Prior to POOH, shut in well. 6. RD E-line. Return well to production and obtain a well test. 13-3/1 2,497' Top of 7" Liner @ 7,849' ~/ 9-5/8" @ 8,145' Tradin~ -Jay ~:'~ Well 'D- I ~RI,~ CIW Tb'4. Hzr. 4-1/2" ASL x 4-1/2" ASL 306' Otis Iubing Retrievable Bali Valve Type DC ID = 3.813" 2,125' 4-1/2" Otis RL GLM (1-6) ID = 3.833" ~'[c.'iurry VR-STD Valve w/RA Latch 3,778' 5,246 ' 6,285' 7,157' :~5 7,668 ' :.-'6 7,709' XO 4-1/2" ASL x 3-1/2" ASL 8,849' 3-1/2" Otis RW GLM (7) ID = 2.813" McMurry JR Orifice w/BK-2 Latch 9,501' 3-1/2" Otis RW GLM (8-9) ID = 2.813"' McMurry Dummy Valve w/BK-2 Latch 9,821' ~}9 Dummy valve as above 9,920' Otis 4" x 3" Locator and Seal Assy. 9,922' Otis WD Packer w/5' Seal Bore Extension & Bell Guide 9,947' Otis 2.75" ID X-Nipple 9,978' Otis 1/2 cut Muleshoe ID = 2.992" Perforations (DIL) Bench 1 10,052' - 10,080' Bench 2 10,096' - 10,120' Bench 3 10,178' - 10,192' Bench 3 10,214' - 10,232' Bench 4 10,260' - 10,295' Bench 4 10,330' - 10,360' Bench 4 10,366' - 10,378' Bench-5 10,405' - 10,490' Fish - 22' Strip gun 6/29/92 Tagged Fill @ 10,538' WLM 6/20/92 PBTD @ 10,676' TD @ 10,800' EVO - 7/24/92 Wireline Lubricator w/Associated BOPE , GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP CHISTMAS TREE POSITIVE CHOKE REEEIVED. AU G 1 7 1992 Alaska Oil & Gas Cons. CommiSsion Anchorage 2' 5000 psi 2' 3000 psi 3/8' CASING ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging __ Time extens,on __ .,Stimulate ~ r Change approved program __ Pull tubing __ Variance __ Pedorate .iL Ct e __ 2. Name of Operatqr ! 5. Type of Well: UNOCAL (Marathon Oil Co - Sub OPerati~r) Development X_~_ m Exploratory __ 3'Address. 0. BOX '90247, Anc~h~ra~e,.4AK.~,.,9~5!~l ,, ..,Strat',~C~___..., ,_cg .-,-, ,.ct,,.,. ~r. ,.,0, ,.y' ,a;-,.,an , ,c,,.,c,,m w t su c 4. Locat~q:j){ ~l~t_, dla' ~27' EWE, Sec. 6-8N-13W-SM At top ofproductive interval 1,052' FSL, 4,360' FWL, Sec. 6-SN-13W-SM Ateff~c~ti~qPt~sL, 4,592' FWL, Sec. 6-8N-13W-SM Attot~l,d~, FSL, 4,617' FWL, Sec. 6-8N-13W-SM 6. Datum eleva, tion (DF or KB) ,06' KB above MSL .UniI or Prol~erty raalng Nay ~nCt feet ~_V~e~lj:~m ber 9. Permit number 10. APl number 5o-733-20,68-01 l'J, Fie4d/Pool Hem I OCK 12. Present well condition summary 10,800 ' Total depth: measured 10,079 ' feet true vertical feet Effective depth: measured 10,676 ' feet true vertical 9,958' feet Plugs (measured) Junk (measured) 10,676' - 10,800' cement None ~,U~, ~/'~! Casing Length Structural Conductor Sudace 2,497' Intermediate Production 8,145 ' Liner Perforation depth: measured Size 13 3/8" 9 5/8" 7" See Cemented 2,000 sx 3,385 sx 900 sx Attachment #1 true vertical Tubing (size, grade, and measured depth) 4 1~2" N-80 ¢ 7,709', 3 1/2" N-80 Ca 7,709' - 9,978' e u I~pth Pa~.kc%r~aq~l~Vl~tc~Pc~:~,nr,d r~ aC, ~3¢ , ~)t i S "DC" TRBV Ca 306' 13. Attachments Measured depth True vertical depth Description summary of proposal __ 2,497' 8,145' 10,800' 2,404' 7,850' 10,079' RECEIVED JUL 0 199 - Alaska 0il & Gas Cons. 'Anchorage Detailed operations program ~ BOP sketch X 14. Estimated date for commencing operation 6/28/92 15. Status of well classification as: Oil ~ Gas __ Suspended Approved by order of the Commission Original Signed By David W. Johnston Returned _ Commissioner Form 10-403 Rev 06/15/88 Date '7/~2/c/~ SUBMfT IN TRIPLICATE 16. If proposal was verbally approved ~ 6/26/92 Name of.afCpro~er Mi ke MeTqler Date approved Service 17' I he'~ce'~that t~'~/~g~ys true and c°rrect t° the best °i~ Y kn°wledge'/~//~' Signe/ ~ / J //~ /"" Title ~ ," "' '/I ~' .'¥ FOR COMMISSION USE ONLY Conditions of approval: N~ti~ Commissior/s~ representative may witness Plug integrity ..iL BOP TCs~ Location clearance ~. . Mechanica Integrity Test ~ L/ Subsequent form required 10- .¥_¢~/ Approved Copy Datel--/~' -'-' ¢ Z... ! Appr°va' N°?~_/¢~ Bench Attachment #1 Well D-17RD Perforations MD (DIL) 10,052 10,096 10,178 10,214 10,260 10,330 10,366 - 10,081 - 10,120 - 10,192 - 10,232 - 10,295 - 10,360 - 10,378 10,405 - 10,490 TVD 9,377 9,419 9,496 9,530 9,572 9,638 9,671 - 9,403 - 9,442 - 9,509 - 9,547 - 9,605 - 9,666 - 9,683 9,708 - 9,787 41A/DVP RECEIVED d U L ~ 0 1992 · · e e REPERF HB-5 RU E-line unit. HU platform communication system in unit. Pressure test lubricator to 2500 psi. Apply 4000 psi control line pressure to the SCSSV with the portable test unit and monitor for leakoff prior to RIH. Test unit to be located near lower wellroom entry door. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify logistic support & establish communication black-out. Re-establish the communication when guns are @ 1000' when POOH. RIH w/2-1/8" strip guns 4 SPF, 0 degree phasing, offset 30 degrees and perforate the following intervals underbalanced. RU___~N BENCH INTERNAL (DIL) FOOTAGE 1 HB-5 10,460' - 490' 30' 2 HB-5 10,430' - 460' 30' RD E-line. Return well to production and obtain a well test. H: \wp\REPER F. HB5 RECEIVED J U L 0 199 Alaska Oil & Gas Cons. Commission Anchorage Top of 7" /b~j Liner ~ j . 7,849' ~-~×~ 9-5/8 ~. 8,145' J , ' [i2" Otis RL GL>[ (1-6) iD = 2.833" ".cHurrv VR-SYD Valve w/R.% larc:~ 3,773' "~ .-~ 5,246' ::3 6,2S5' "' .-~ 7,157' 7,668' 7,709' 8,849' 9,501' 9,821' 9,920' ::5 :.: 6 XO 4-t,, ASL x 3-t/0'' ASL 3-1/2" Otis RW GI2.[ (7) ID = 2.813" McMurr7 JR Orifice wlgK-2 Latch 3-1/2" Otis RW GLM (8-9) ID = 2.813" McMurry Dummv Valve w/BK-2 Latch Otis 4" x 3" Locator an~ Seal Assv. 9,922' Otis WD Packer w/5' Seal gore Extension & Bell Guide 9,947' Otis 2.75" ID X-Nipple ~_,.a78' Otis i/2 cut Muleshoe iD = ~.~ 992" Perforations (DIL) Bench 1 10,052' - 10,080' Bench 2 10,096' - 10,120' Bench 3 10,178' - 10,192' genci~ 3 10,214' - 10,232' Bench 4 10,260' Bench 4 10,330' Bench 4 10,366' Benci~ 5 10,405' _ RECEIVED - 10,360' - o,378' JUL 20 1992 ~AJ{~ska Oil & Gas Cons. CommisSiOn 10, 4 Anchorage Tagged Fill 0 10,570' PBTD @ 10,676' TD @ 10,800' DIL) 2/2/87 NEF 6/12/87 ("jOLLY VAFIDEN P~_"~TFORM Wireline Lubricator w/Associated BOPE GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP · 4':1/.-'1.6~.5OO0 pal CItlSTMAS TREE --- POSITIVE CHOKE RECEIVED JUL201992 '--- ~ias~ :Oil & Gas Cons. Commission ~nchorage ---- 2" 5000 pal -.-- 2" 3000 pal 13 3/8' CASING APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing m Repair well N Ctnange approved program __ Puli tubing M Variance __ 2. Name of Operator 15. Type of Well: Development ~ IIl~lFtC'AI (M~v,~+hrm ~-;1 ¢'~ _ ~,,h ~+~ Exploratory~ 3. Address I Stratigraphic ~ P,fl, B~x lqfl247 flnchn~O~; flK qq~l~ Service__ "4. Location of well at sudace Leg A-2, Cond. ¢2 Dolly Varden Platfom 759' FSL, ~,~27' F~L, Sec. 6-8N-[3~-SH At top of productive interval Operation shutdown __ Re-enter suspended well __ Plugging m Time extension m Stimulate ~ Perforate .Z__ Other __ Reperf 6. Datum elevation (DF or KB) 7. Unit or Property name 8. Well number D-17RD 9. Permit number 1,052' FSL 4 360' FWL Sec. 6-8N-13W-SM At effective depth 1,118' FSL, 4,592' FWL, Sec. 6-8N-13W-SM At total depth 1~125' FSL, 4,617' FWL, Sec. 6-8N-13W-SM 12. Present well condition summary Total depth: measured 10,800 ' feet Plugs (measured) true vertical 10,079 ' feet Effective depth' measured 10,676 ' feet true vertical 9,958 ' feet Casing Length Structural Conductor Surface 2,497' Intermediate Production 8,145 ' Liner 2,951' Perforation depth: measured true vertical '¥2 A"PTnumber 11. Field/Pool Hemlock Junk (measured) 10,676' None 10,800' cement Size Cemented Measured depth True vertical depth 13 3/8" 2,000 sx 2,497' 2,404' 9 5/8" 3,385 sx 8,145' 7,850' 7" 900 sx 10,800' 10,079' See Attachment #1 RECEIVED feet Tubing (size, grade, and measured depth) DEC 2 0 1991 4 1/2" N-80 0 7,709', 3 1/2" N-80 e 7,709' - 9,978' Al~kaOll&GasCons. Commisslen Packers and SSSV (type and measured depth) Ntch0rage Otis "ND" Packer' 0 9.923' f3f. i_~ "D£" TRRV 0 3f)6' · 13. Attachments 1 ~ 2 ~ Description summary of proposal ..Z. Detailed operations program M BOP sketch ~ &3 14. Estimated date for commencing operation December 9, 1991 16. If proposal was verbally approved Russ Douglass Name of approver / 15. Status of well classification as: Oil ~ Gas__ Suspended __ December 6, 1 91 Date approvedI Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~(~x.,-*. ~. (~~ Title ~', ,'%-~. ~'r~.',~, COnditions of ap~oval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ ~ation clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ~ Approved by order of the Commission Date ORIGinAL :SIGNED BY LoNNIE 'C. SMITH Commissioner IApproval No. Date /¢2~~ / Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Bench Attachment #1 Well D-17RD Perforations MD (DIL) TVD 10,052 10,096 10,178 10,214 10,260 10,330 10,366 - 10,081 - 10,120 - 10,192 - 10,232 - 10,295 - 10,360 - 10,378 10,405 - 10,490 9,377 9,419 9,496 9,530 9,572 9,638 9,671 - 9,403 - 9,442 - 9,509 - 9,547 - 9,605 - 9,666 - 9,683 9,708 - 9,787 41A/DVP RECEIVI D DEC 20 1991 Alaska Oil & Gas Cons. ~ltll~ Anchorage Attachment #2 ( 1) 2) D-17RD PROCEDURE Obtain a 24-hour test with a minimum of four (4) WC's. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi Ensure control line pressure does not bleed off. · RU E-Line unit. Hook up platform PA system in unit. Pressure test lubricator and BOPE to 2500 PSI. 4) NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT & ESTABLISH COMMUNICATION BLACK-OUT RE-ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE 0 1000 WHEN POOH. ' , SI WELL TO RIH & POOH. RIH with 2 1/~'' .... do .... ~_._ ' 4u >srlp guns, 4 SPF, O-Phase, offset 30-degree right looking -, ,u~e aha pertorate the following intervals underbalance: RUN BENCH INTERVAL (DILl FOOTAGE 1 HB #4 2 HB #1 10,360' - 10,380' 10,055' - 10,080' 20 25 5) RD E-Line unit. Return well to production and obtain several 12-hour well tests obtaining 3 WC's per 12-hour test. \oe60\86.doc RECEIVB'D DEC 0 '1991 Alaska 011 & Gas Cor~. Anchora~ 13-3/8~ 2,497' \ Attachment ~'3 'rradin-_ Sa:' Uni: ( Well D-/TRD (Currul~) CIW Tbu. H.~r. &-[/l" ASL x 4-[/2" ASL 306' Otis Tubin~ Retrievable Ball Valve Type DC {D : 3.813" 2,125' 4-t/2" O~is RL GLM (I-6) ID = 3.833" Hcllurrv VR-STD Valve w/~% Latch 3,778' #2 5,246' ~3 6,285' :;4 TOp of 7" Liner @ 7,849' 9-5/8" @ 8,145' 7,157' 7,668' 7,709' 8,849' 9,501' 9,821' 9,920' #5 ~6 X0 4-1/2" ASL x 3-1/2" ASL 3-1/2" Otis ~ GLM (7) ID = 2.813" McMurry JR Orifice w/BK-2 Latch 3-1/2" Otis RW GLM (8-9) ID = 2.813''' McMurry Dummy Valve w/BK-2 Latch #9 Otis 4" x 3" Locator and Seal Assy. 9,922' Otis WD Packer w/5' Seal Bore Extension & Bell Guide 9,947' Otis 2.75" ID X-Nipple 9,978' Otis 1/2 cut Muleshoe ID = 2.992" Perforations (DIL) Bench 1 10,052' - 10,080'. Bench 2 10,096' - 10,120' Bench 3 10,178' - 10,192' Bench 3 10,214' - 10,232' Bench 4 10,260' - 10,295' Bench 4 10,330' - 10,360' Bench 4 10,366' - 10,378' Bench 5 10,405' - 10,490' Tagged Fill @ 10,570' (DIL) 2/2/87 PBTD @ 10,676' TD @ 10,800' NEF 6/12/87 Attachment Wireline Lubricator w/Associated BOPE · GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP · 4.~.s-'-.-Sooo ..~ CHISTMAS TREE POSITIVE CHOKE 2 6000 ]_-- 2' 3000 psi 13 3/8' CASING ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Pull tubing Operation shutdown __ Stimulate Plugging Alter casing m Repair well 5. Type of Well: Jr) Development _~X Exploratory __ Stratigraphic __ Service ~ 2. Name of Operator UNOCAL (Marathon 0il Co- Sub 3. Address P.O. Box 190247 Anchorage, AK 9951~ 4. Location of well at surface 759' FSL, 1,127' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,052' FSL, 4,360' FWL, Sec. 6-8N-Z3W-$M At effective depth 1,118' FSL, 4,592' FWL, Sec. 6-8N-t3W-SM At total depth 1,125' FSL, 4,617' FWL, Sec. 6-8N-13W-SM Plugs (measured) 12. Present well condition summary Total depth: measured true vertical 10,800' feet 10,079' feet Perforate ~ Other m 6. Datum elevation (DF or KB) 7. Unit or Property name Trad Unit 8. Well number D-17RD 9. Permit number/approval number 10. APl number 5°~33 - 20168-01 11. Field/Pool Hemlock 10,676' - 10,800' cement feet Effec!ive depth: measured true vertical Casing Length Structural Conductor Surface 2,497' Intermediate Production 8,145 ' Liner 2,951' Perforation depth: measured 10,676' feet 9,958' feet Size true vertical 13 3/8" 9 5/8" 7" See Tubing (size, grade, and measured depth) 4 1/2" N-80 e 7,709', 3 1/2" N-80 e Packers and SSSV (type and measured depth) Otis "WD" Packer @ 9,923', Otis "DC" 13. Stimulation or cement squeeze summary Junk (measured) Cemented None Measured depth True vertical depth 2,000 sx 2,497' 2,404' 3,385 sx 8,145' 7,850' 900 sx 10,800' 10,079' Attachment #1 7,709' TRBV - 9,978' e 306' Alaska 0ii & Gas Co~ls. OommisSio[~ Anc~0rage Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 8/21/90 152 Subsequent to operation 9/19/90 216 Tubing Pressure 520 649 1150 150 1024 778 1130 160 15. Attachments~ 2 Copies of Logs and Surveys run ~ Daily Report of Well Operations _~X 16. Status of well classification as: Oil X__ Gas __ Suspended Service 17. I hereby certify that the foregoing is true and correct tothe best of my knowledge. Signed ~,C~.~ ~'~, (~4,~ Title ¢,e.~, ~)~c~, Form 10-404 Ret/,~6/15YS~ Date SUBMIT IN DUPLICATE Bench Attachment //1 Well D-17RD Perforations MD (DIL) TVD 10,052 10,096 10,178 10,214 10,260 10,330 10,366 - 10,081 - 10,120 - 10,192 - 10,232 - 10,295 - 10,360 - 10,378 10,405 - 10,490 9,377 9,419 9,496 9,530 9,572 9,638 9,671 - 9,403 - 9,442 - 9,509 - 9,547 - 9,605 - 9,666 - 9,683 9,708 - 9,787 41A/DVP Attachment #2 TBU Wel 1 D-17RD Daily Summary of Operations 8/23/90 RU Electric line and PT lubricator to 25~0 psi, OK. RIH w/ 2-1/8" Enerjet strip guns, 4 SPF, 0° phasing, offset 30v. Correlate and perforate HB-1, 10,052' - 10,081'. Flow well for cleanup. SI well, POOH. 8/24/90 RIH with same guns as above. Correlate and perforate HB-2, 10,096' - 10,120'. Flow well for cleanup. SI well, POOH. Place well back in production . \docs\dvp\d17rd STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well ~ Alter casing ~ Repair well ~ Plugging __ Time extension __ Stimulate ~ Change approved program ~ Pull tubing __ Variance ~ Perforate -X- Other 2. Name of Operator UNOCAL (Marathon 0il Co - Sub 0peratr r) "'3. Address P.O. Box 190247 Anchorage, AK 9951(. 4. Location of well at surface Leg A-2, Cond. ~z UOl ',y 759' FSL, 1,127' FWL, Sec. 6-8N-13W-',;M At top of productive interval 5. Type of Well: Development Exploratory Stratigraphic Service Varuen I~ lattorm 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit 8. Well number D-17RD 9. Permit number 1,052' FSL, 4,360' FWL, Sec. 6-8N-13W-SM At effective depth 1,118' FSL, 4,592' FWL, Sec. 6-8N-13W-SM At total depth _- 1,125' ESL, 4,617' EWE, Sec. 6-8N-13W-SM 81-23 10. APl number 5of-33-20168-01 11. Field/Pool Hemlock 12. Present well condition summary Total depth: meaS'ured true vertical 10,800' feet 10,079' "feet Effective depth: ·measured 10,676' true vertical 9,958 ' Casing Length Structural Conductor Sudace 2,497 ' Intermediate Production 8,145 ' Liner 2,951 ' Perforation depth: measured 13 9 Plugs (measured) 10,676' .. feet Junk (measured) None feet 10,800' cement Size Cemented Measured depth True vertical depth true vertical 3/8" 2,000 sx 2,497' 2,404' 5/8" 3,385 sx 8,145' 7,850' 7" 900 sx 10,800' 10,079' See Attachment //1 -- RECEIVED Tubing (size, grade, and measured depth) AUG 2 71990 4 1/2" N-80 g 7,709', 3 1/2" N-80 [a 7,709' - 9 978' Pack~rs aD,d. S~SV~(typ, e and measur~cl_ depth ' ~J~:~-J~ 0,il ~ Gas C0rl$, Otis "WD" PacKer g 9,923', ~tis "DC" TRBV e 306' 13. Attachmen[s 2 & 3 Description summary of proposal .Z.. Detailed operations program __ BOP sketch _.Z. 14. Estimated date for commencing operation ~ 15. Status of well classification as: 8/22/9O 16. If proposal was verbally approved Oil X__ Gas __ Suspended ~ Name of approver Date approved Service rtify that the foregoing is true and correct to the best of my knowledge. 17. I hereby c,,~e Signed[l,(~_,_ %, (~,...~ Title ~.e~,'o,~,.o~.. "~.,~.\,.~,~ ~"-~,r~ Date /'~ F \ FOR COMMISSION USE ONLY ca,,ono,e.ano __ 1 Mechanical Integrity Test __ Subsequent form required 10- 4(;,~- GoP'~ ' - ' ~o'~e6 e8 ORIGINAL SIGNED BY Approved by order of the Commission LONN IE C. SMITH Commissioner Form 10-403 Rev 06/15/88 Date S~ IBMIT IN TRIPLICATE Bench Attachment #1 Well D-17RD Perforations MD (DIL) 10,052' - 10,080' 10,096' - 10,120' 10,178' - 10,192' 10,214' - 10,232' 10,260' - 10,295' .10,330' - 10,360' 10,366' - 10,378' 10,405' - 10,490' TVD 9,377' - 9,403' 9,419' - 9,442' 9,496' - 9,509' 9,530' - 9,547' 9,572' - 9,605' 9,638' - 9,666' 9,671' - 9,683' 9,'708' - 9,787' 41A/DVP RECEIVED AUG 2 71990 ~ :Oil & Gas Cons. Attachment #2 TBU Wel 1 D-17RD Reperforating Procedure le 2, ® , , Obtain a 24-hour well test. Install a two pen recorder to monitor tubing and casing pressure. Skid Rig # 77 over Well D-17RD. RU E-line, RU platform PA in E-line unit. Pressure test BOPE and lubricator to 2500 psi. Disconnect S¢SSV from system manifold and lock open SCSSV at 4000 psi with a hand pump. Hand pump should be located near the wellroom entry door. Monitor control line pressure to ensure no bleed off occurs. Prior to arming guns and until guns are 1000' in the hole, notify logistic support and establish the~.communications blackout. SI well. RIH with 2-1/8" strip guns, 4 SPF, 0° phasing, offset 30o and perforate the following intervals underbalanced (well. flowing). The well can be returned to production once the perf gun is below the tubing tail at 9,978'. RUN BENCH INTERVAL DIL FOOTAGE I HB-5 10,405' - 40,415' 10 2 HB-2 10,096' - 10,120' 24 3 HB-1 10,052' - 10,081' 29 Flow well for clean-up approximately 30 minutes after each perforating run. Flow well to group separator during and for 12 hours after perforating. -Begin flow at a reduced rate, slowly opening the choke over about 4-6 hours after perforating is complete. 7. RD E-1 ine. 8. Obtain a well test. \ docs \ DVP\ d 17 rd. doc Attachment #3 (' ~3LLY VARDEN PL{ rFORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP .----- GREASE HEAD (Hydraulically Activated) LUBRICATOR 4' ~-11~1,"6~. '50 0 0 pal CHISTMAS TREE POSITIVE CHOKE 2' 5000 psi ..--. 2' 3000 pal 13 3/8' CASING STATE OF ALASKA COM MIS'(.,.' AL/~. ,A OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging __ Pull tubing __ Alter casing m Repair well __ 2. Name of Operator [ 5. Type of Well: UNOCAL (Marathon Oil Co - Sub Operator) Developmental_ Exploratory 3. Address ! Stratigraphic P.O. Box 190247 Anchorage, AK 99~19 Service~ 4. Location of well at surface ~'eg a-z, t, ono. f~z uO.t.Ly varden 759' FSL, 1,127' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,052' FSL, 4,360' FWL, Sec. 6-8N-13W-SM At effective depth 1,118' FSL, 4,592' FWL, Sec. 6-aN-13W-SM At total depth 1,125' FSL, 4,617' FWL, Sec. 6-8N-13W-SM Perforatex'''' Pull tubing ~ Other 6. Datum elevation (DF or KB) 106' KB above MSL Unit or Property name Trading Bay Unit 8. ~Well]r~u~be r 9. Permit number/approval number 8-649 10. APl number 50-- 733-20168-01 11. Field/Pool Hemlock feet 12. Present well condition summary Total depth: measured true vertical 10,800' feet 10,079' ~et Plugs (measured) 10,676' - 10,800' cement Effective depth: measured true vertical Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: 10,676' ~ 9,958' feet Junk (measured) Length Size Cemented 2,497' 13 3/8" 2,000 sx 8,145' 9 5/8" 3,385 sx 2,951' 7" 900 sx measured See Attachment #1 true vertical None Measured depth True vertical depth 2,497' 8,145' 10,800' 2,404' 7,850' 10,079' Tubing (size. grade, and measured depth) 4 1/2" N-80 @ 7,709', 3 1/2" N-80 @ 7,709' Packers and SSSV (type and measured depth) Otis "WD" Packer @ 9,923', Otis "DC" TRBV 13. Stimulation or cement squeeze summary Intervals treated (measured) See attachment #2 Daily Summary of Operations Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 205 67 513 1190 120 Subsequent to operation 3 42 114 723 ll 71 15. Attachmentm: ¢/,2 116. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations _,~ Oil ~ Gas ~ Suspended ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 133 Signed ~~~J~-/~~"~ Form 10-404Rev06/15/88 Ro~ D. Roberts Title Enviro~tal Engineer Date 11 SUBMIT IN DUPLICATE Bench Attachment #1 Well D-17RD Perforations ~m (~L) TVD 10,052' - 10,080' 10,096' - 10,120' 10,178' - 10,192' 10,214' - 10,232' 10,260' - 10,295' 10,330' - 10,360' 10,366' - 10,378' 10,405' - 10,490' 9,377' - 9,403' 9,419' - 9,442' 9,496' - 9,509' 9,530' - 9,547' 9,572' - 9,605' 9,638' - 9,666' 9,671' - 9,683' 9,708' - 9,787' 41A/DVP Attachment #2 TBU Well D-17RD Daily Summary of Operations 10/1/88 RU E-line & PT to 2500 psi, OK. Made two perforating runs using 2-1/8" Enerjet II strip guns w/ 13.5 gm charges, 4 SPF, 0° phasing. Perforated Bench 2 from 10,096' - 10,120' CBL and Bench 1 from 10,052' - 10,080' CBL. Flow well, RD, put well in test. 10/3/88 RU E-line & PT to 2500 psi, OK. Made three perforating runs using 2-1/8" Enerjet II strip guns w/ 13.5 gm charges, 4 SPF, 0° phasing. Perforated Bench 5 from 10,460' - 10,490' CBL, and 10,440' - 10,460' CBL; Bench 3 from 10,214' - 10,232' CBL. Flow well, RD, put well in test and prepare for XFE treatment. 10/26/88 RU pumping unit to well and PT to 5000 psi, OK. Mix up 20 bbls at a time of 18% XFE-D and FIW. Pump solution @ 1-1/4 BPM @ 1200 psi tubing, 1180 psi casing. After 116 bbls of XFE-D/FIW were pumped, tubing pressure dropped to 650 psi and casing pressure increased to 1400 psi. Displaced XFE-D/FIW across perfs with 40 bbls FIW @ 1/2 BPM. Tubing pressure increased to 750 psi, casing pressure to 1460 psi. Closed swab valve and allow treatment to soak for 4 hours. 10/27/88 Pump 68 bbls FIW @ 1/2 BPM displacing XFE-D two feet into perf interval. Allow to soak for 9 hours. Pump 5 bbls FIW @ 1/2 BPM, tubing pressure 1425 psi, casing pressure 1380 psi. SI well, RD pumping equipment, put well in test. em/41A/DVP APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown, ~ Re-enter suspended well ~ Alter cas,ng El Time extension Change approved program Plugging "~ Stimulate ."~: Pull tubing Amend order r. Perforate f~ Other 2 Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3 Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surface~eg A-2, uond. #2 Dolly Varden Pl~tfuvm 759' FSL, 1,127' FWL, Sec. 6-8N-13W-SM At top of productive ~nterval 1,052' FSL, 4,360' FWL, Sec. 6-8N-13W-SM At effective depth 1,118' FSL, 4,592' FWL, Sec. 6-8N-13W-SM At total depth 1,125' FSL, 4,617' FWL, Sec. 6-8N-13W-SM 5. Datum elevation (DF 106' KB above MSLB) Qr__K 6. U ito Prop t n e 7. VV~I/~er 8. Permit number 81-23 9. APl number 50-- 733-20168-01 10. Pool · Hemlock feet 11. Present well condition summary Total depth: measured true vertical 10,800' feet 10,079' feet Plugs (measured) 10,676' - 10,800' cement Effective depth: measured 10,676 ' true vertical 9,958' feet Junk (measured) feet None Casing Length Size Structural Conductor Surface 2,497' 13 3/8" Intermediate Production 8,145' 9 5/8" Liner 2,951 ' 7" Perforation depth: measured true vertical Cemented 2,000 sx 3,385 sx 900 sx See Attachment #1 Tubing (size, grade and measured depth) 4 1/2" N-80 @ 7,709', 3 1/2" N-80 @ 7,709, - 9,978' Packers and SSSV (type and measured depth) Otis "WD" Packer @ 9,923', Otis "DC" TRBV@ 306' Measured depth True Vertical depth 2,497' .8,145' 10,800' 2,404'. 7,850' 10,079' Anch0rags 12.Attachments 2, 3, Description summary of proposal .~. Detailed operations program C.; BOP sketch &4 13. Estimated date for commencing operation August/September, 1988 14. If proposal was verbally approved Su'bsc:;;';;e:~':t ~?,'-,-'~" '~'~:h~, ........ " . ,~' Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Environmental Enqineer ~ D./Rober~s' · Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. F_J Plug integrity ~ BOP Tep~t....~,,[RAi.,w,,.,,,.,,..c~'~clearanceI ~emj ,,=,., .4-~,Returned ORIGINAL SIGNED BY ~ LONNIE C. SMITH Approved by Form 10-403 Rev 12-1-85 Date 8/23/88 Commissioner by order of the commission Date Submit in triplicate Bench Attachment #1 Well D-17RD Perforations MD (DIL) 10,052' - 10,080' 10,096' - 10,120' 10,178' - 10,192' 10,214' - 10,232' 10,260' - 10,295' 10,330' - 10,360' 10,366' - 10,378' 10,405' - 10,490' TVD 9,377' - 9,403' 9,419' - 9,442' 9,496' - 9,509' 9,530' - 9,547' 9,572' - 9,605' 9,638' - 9,666' 9,671' - 9,683' 9,708' - 9,787' 41A/DVP Attachment # 2 ~ D-17RD Procedure A. Reperforate & Stimulate 1. RU wireline. PT to 2500 psi. 2. RIH w/ 2.7" gauge ring to establish baseline tubing ID. 3. POH. RD wireline. 4. RU E-line. 5. Perforate the following zones w/ 2-1/8" or 2-5/8" perf gun, 4 SPF, 0° phasing, underbalanced. Run Interval Feet Bench 1 10,366' - 10,378' 12 2 10,260' - 10,287' 27 3 10,052' - 10,080' 28 Test for 12 hours. 4 10,460' - 10,490' 30 5 10,178' - 10,192' 14 6 10,214' - 10,232' 18 Test for 12 hours. 7 10,432' - 10,460' 28 8 10,405' - 10,432' 27 9 10,330' - 10,360' 30 6. RD E-line. Note: Bring well on slowly and obtain a stabilized production test. Produce well for 3 days before stimulating. 7. RU pumping unit to tree. PT to 5000 psi. 8. Mix Scalesolv XFE - 18% in FIW (380 gal of XFE in 95 bbls FIW). 9. Displace XFE slowly across the perforations. Allow XFE to remain static for 4 hours. 10. Displace XFE 2' into formation. Allow XFE to remain static for 12 hours. XFE should be displaced across/into perfs as slowly as possible. 11. Pump an additional 5 bbls FIW and allow XFE to remain static for 12 hours. Attachment # 2 {? D-17RD Procedure (Continued) 12. Bring well back on slowly over a 24 hour period. 13. RD pumping equipment. Note: Well should flow a minimum of 6-10 days prior to being placed on an ESL 19P scale inhibition program. Obtain stabilized production test. B. Scale Inhibition Treatment 1. SI well. RU pumping unit to D-17RD tree. PT to 5000 psi. 2. Mix and pump scale inhibitor as follows: Stage 1 Stage 2 Stage 3 Stage 4 Stage 5 50 bbl FIW (establish injection rate) 52 bbl FIW w/ 2.5% phosphonate preflush (55 gal of West/Scale 46) 25 bbl FIW (spacer) 120 bbl FIW w/ 10% inhibitor (550 gal ESL 19P) 675 bbl FIW overflush Treatment to be pumped at 2 BPM max. Surface pressure to be kept below 3000 psi to avoid fracturing the reservoir. 3. RD pumping equipment and shut in D-17RD for 24 hours. 4. Bring well on slowly to test. Start lift gas at lowest rate necessary to lift well. Work up to a full lift gas rate over 24 hours. 5. A Western Wellchem engineer will take fluid samples hourly for the first 24 hours to monitor residuals. Two to four samples will be taken for the remainder of the week. After one week, sampleS will be taken once a week for the remainder of the month. After one month, a fluid sample should be taken monthly and sent to Wayne Cissell. 6. A gauge ring will be run every 4 months to monitor inhibitor effectiveness. Note: Maximum anticipated SBHP is 3600 psi. Note: Coiled tubing will be used to inject XFE/ESL 19P if an emulsion problem is apparent. 41A/DVP Attachment #3 ~JLLY VARDEN PLA(' FORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP .... GREASE HEAD (Hydraulically Activated) LUBRICATOR 4 1/16; 5000 psi CHISTMAS TREE POSITIVE CHOKE ---- 2' 5000 psi D---- 2' 3000 psi 13 3/8' CASING Attachment #4 DOLLY VARDEN PLATFORM Coiled Tubing Lubricator w/Associated BOPE DOUBLE BOP w/1 1/4' Rams 5000 psi WP HYDRAULIC RAMS 4 1/16" 5000 psi CHISTMAS TREE 1 POSITIVE CHOKE 2' 5000 psi .... 2' 3000 psl~ 13 3/8' CASING A(_~ STATE OF ALASKA ~' AL A OIL AND GAS CONSERVATION CO .~SSION REPORT OF SUNDRY WELL OPERATIONS 1.' Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] · Alter Casing [] Other I~ 2. Name of Opera[or UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. LocationofwellatsurfaceLeg A-Z, ~ond. #2 uoiiy varden Piatfor~ 759' FSL, 1,127' FWL, Sec. 6-8N-13W-SM Attop of productiveinterval 1,052' FSL, 4,360' ;E'I~E, Sec. 6-8N-13W-SM Ateffective depth 1,118' FSL, 4,592' FWL, Sec. 6-8N-13W-SM Attotaldepth 1,125' FSL, 4,617' FWL, Sec. 6-8N-13W-SM 5. Datum elevation(DF or KB) 106' KB above MSL 6. UnitorPropertyname Trading Bay Unit 7. Wei~l_qj.~'nl~e r 8. Approval number 7-387 9. APl number 50-- 733-20168-01 10. Pool Hemlock Feet True Vertical depth 2,404' 7,850' 10,079' Date ]0/'!4/87 Submit in Duplicate 11. Present well condition summary Total depth: measured true vertical 10,800' feet 10,079' feet Effective depth: measured 10,676 ' feet true vertical 9,958 ' feet Plugs (measured) 10,676' - 10,800' cement Junk (measured) None Casing Length Size Cemented Structural Conductor Surface 2,497' 13 3/8" 2,000 sx Intermediate Production 8,145' 9 5/8" 3,385 sx Liner 2,951' 7" 900 sx Perforation depth: measured See Attachment ~fl true vertical Measured depth 2,497' 8,145' 10,800' Tubing (size, grade and measured depth) 4 1/2" N-80 @ 7,709', 3 1/2" N-80 @ 7,709' - 9,978' Packers and SSSV (type and measured depth) Otis "WD" Packer @ 9,923', Otis "DC" TRBV @ 306' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment .descriPtion including volumes used and final pressure Alaska Oil & Gas Cons. Commissio Anchorage 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 9/2/87 166 53 664 1100 psi operation9/17/87 162 49 736 1200 Subsequent psi to Tubing Pressure 120 psi 200 psi 14. Attachment~ 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 * Marathon Oil Company - Sub Operator Signed j~;~_.,~,~ .'R~erts Title Environmeptal D Engipeer Form 10-404 Rev. 12-1-85 Bench 1 2 3 3 4 4 4 5 Attachment #1 Well D-17RD Perforations ~MD (DIL) -- 10,052' - 10,080' 10,096' - 10,120' 10,178' - 10,192' 10,214' - 10,232' 10,260' - 10,295' 10,330' - 10,360' 10,366' - 10,378' 10,405' - 10,490' TVD 9,377' - 9,403' 9,419' - 9,442' 9,496' - 9,509' 9,530' - 9,547' 9,572' - 9,605' 9,638' - 9,666' 9,671' - 9,683' 9,708' - 9,787' 41A/Sundr2 Gas Corm. CommissJ~r~ Ar~chorage Attachment #2 Daily Report of Well Operations WEll D-17RD 9~9~87 Rig up slickline on D-17RD, pressure test lubricator. RIH and cut scale. POOH, RD slickline and move equipment. 9/11/87 Ran production logs and pressure buildup survey. 9/12/87 Continued PBU survey. Mix scale inhibition chemical w/FIW. Finish RU pumping unit and pressure test surface equip and lines to 4,500 psi. Bled down tbg press from 1,400 - 1,000 psi. Pump scale inhibition treatment as follows: Stage 1 - 50 bbls FIW @ 3 BPM & 1,200 psi (FBS @ 10,060' CBL) 2 - 50 bbls FIW & 194/4 @ 2 BPM & 900 psi 3 - 25 bbls FIW @ 3 BPM & 900 psi 4 - 340 bbls FIW & FSL @ 4 BPM & 1,000 psi (initial) 3 PPM & 2,000 psi (final) 5 - 520 bbls FIW displacement @ 3 BPM & 2,000 psi (initial) 3 BPM & 2,850 psi (final) 9/13187 Ran temp and pressure logs. POH and RD wireline. NEF/em/41A/Sundr3 APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Opera~tor UNOCAL 3. Address P.O. Box 190247 Anchorage, Al( 99519 4. Location of well at surfaceLeg A-Z, t;ond. #2 Doily Varden Pla~:fo~:m 759' FSL, 1,127' FWL, Sec. 6-SN-13W-SM At top of productive interval 1,052' FSL, 4,360' FWL, Sec. 6-SN-13W-SM At effective depth 1,118' FSL, 4,592' FWL, Sec. 6-8N-13W-SM At total depth 1,125' FSL, 4,617' FWL, Sec. 6-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. W~I/~er 8. Permit number 81-23 9. APl number 50-- 733-20168-01 10. Pool · Hemlock feet 11. Present well condition summary Total depth: measured true vertical 10,800' feet Plugs (measured) 10,079' feet 10,676' - 10,800' cement Effective depth: measured 10,676' feet Junk (measured) true vertical 9,958' feet None Casing Length Size Cemented Structural Conductor Surface 2,497' 13 3/8" 2,000 sx Intermediate Production 8,145' 9 5/8" 3,385 sx Liner 2,951' 7" 900 sx Perforation depth: measured See Attachment #1 true vertical Measured depth 2,497' 8,145' 10,800' True Vertical depth 2,404' 7,850' 10,079' Tubing (size, grade and measured depth) 4 1/2" N-80 @ 7,709', 3 1/2" N-80 @ 7,709' - 9,978' Packers and SSSV (type and measured depth) Otis "WD" Packer @ 9,923', Otis "DC" TRBV @ 306' 12.Attachments #2 & 3Description summary of proposal ~I~ Detailed operations program ~ BOP sketch [] 13. Estimated date for commencing operation June 1987 14. If proposal was verbally approved Name of approver Date approved is true and correct to the best of my knowledge Title F_zlvironn~tal Emgineer Commission Use Only Date 6/16/87 Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance * Marathon Oil Company - Sub Operator ~missioner Form 10-403 Rev 12-1-85 Approval No. ~ .,_~;) ~7 I :---.-,;;: . L by order of / ,_,, //)_.,J the oommission Date CoP '"'i/~/"-'(:~7' /J ~ .~.,~ Submit in triplicate Bench Attachment #1 Well D-17RD Perforations ~ (DIL) 10,052' - 10,080' 10,096' - 10,120' 10,178' - 10,192' 10,214' - 10,232' 10,260' - 10,295' 10,330' - 10,360' 10,366' - 10,378' 10,405' - 10,490' TVD 9,377' - 9,403' 9,419' - 9,442' 9,496' - 9,509' 9,530' - 9,547' 9,572' - 9,605' 9,638' - 9,666' 9,671' - 9,683' 9,708' - 9,787' Attachment #2 Well D-17RD Scale Inhibition Procedure 1. Rig up Otis Wireline and pressure test lubricator to 2,500 psi. 2. Make guage ring runs past Bench 1Perfs at 10,080 to determine minimum tubing ID. If minimum ID is less than 2.70", attempt to remove scale with gauge rings. 3. Rig down Otis. 4. Rig up Halliburton pumping equipment to D-17RD tree. Shut in well. 5. Pressure test surface equipment to 5,000 psi and pump treatment as follows: Stage 1 - 50 Bbls total volume FIW w/ 5 gals. ?hasetreat 1506 Stage 2 - 50 Bbls total volume FIW w/ 55 gals. Surftreat ESL Stage 3 - 50 Bbls total volume FIW w/ 55 gals. Scaletreat 194/4 Stage 4 - 170 Bbls total volume FIW w/ 715 gals. Scaletreat ESL Stage 5 - 2,330 Bbls FIW overflush Treatment to be pumped at 2-5 BPM if possible. Surface pressures to be kept below 3,000 psi to avoid fracturing the reservoir. 6. Rig down Halliburton and shut in D-17RD for 24 hours. 7. Bring well on slowly to test. Start lift gas at lowest rate necessary to lift well, then work up to full lift gas rate of 2,300 MCFID over a 24 hour period. 8. Western Well Chem and E&PT personnel will monitor fluid returns for one week to check inhibitor residuals. Monitoring after one week will be handled by Nikiski or platform personnel. 9. Gauge rings will be run every 2-3 months to monitor inhibitor effectiveness. NEF/em/41/Sundr2 ATTACHMENT #3 Trading Bay Unit Well D-17RD (Current) CIW Tbg. Hgr. 4-1/2" ASL x 4-1/2" ASL 306' Otis Tubing Retrievable Ball Valve Type DC ID = 3.813" 13-3/8~ 2,497' 2,125' 4-1/2" Otis RL ELM (1-6) ID = 3.833" McMurry VR-STD ~alve w/RA Latch 3,778' #2 5,246' #3 6,285' #4 7,157' #5 Top of 7" Liner @ 7,849' 9-5/8" @ 8,145' 7,668' #6 7,709' XO 4-1/2" ASL x 3-1/2" ASL 8,849' 3-1/2" Otis RW GLM (7) ID = 2.813" McMurry JR Orifice w/BK-2 Latch 9,501' 3-1/2" Otis RW GLM (8-9) ID = 2.813"' McMurry Dummy Valve w/BK-2 Latch 9,821' #9 9,920' Otis 4" x 3" Locator and Seal Assy. 9,922' Otis WD Pa~ker w/5' Seal Bore Extension & Bell Guide 9,947' Otis 2.75" ID X-Nipple 9,978' Otis 1/2 cut Muleshoe ID = 2.992" Perforations (DIL) Bench 1 10,052' - 10,080' Bench 2 10,096' - 10,120' Bench 3 10,178' - 10,192' Bench 3 10,214' - 10,232' Bench 4 10,260' - 10,295' Bench 4 10,330' - 10,360' Bench 4 10,366' - 10,378' Bench 5 10,405' - 10,490' Tagged Fill @ 10,570' (DIL) 2/2/87 PBTD @ 10,676' TD @ 10,800' NEF 6/12/87 ,. _ ~r' STATE OF ALASKA t ~ / ALASI~. ,)IL AND GAS CONSERVATION COM~ JION ~....~t~r~ ~; ,,.,,,...~'~,.,,/ REPORT OF SUNDRY WELL OPERATION ..';'_'"' ... W. i.~Cz~, .... 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing .~]--v...o,~,vvt.~..LA)~,~,, Alter Casing [] Other [] / ~ 5. Datum elevation (DF or KB) -- ~ 2. Name of Opera~or UNOCAL 106' KB above MSL Feet 6. Unit or Property name Trading Bay Unit 7. We~l_rj?)rn~e r 8. Approval number 742 9. APl number 50-- 733-20168-01 10. Pool Hemlock 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-Z, Cond. #2 Doily varden Piatfor~ 759' FSL, 1,127' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,052' FSL, 4,360' FWL, Sec. 6-8N-13W-SM At effective depth 1,118' FSL, 4,592' FWL, Sec. 6-8N-13W-SM At total depth 1,125' FSL, 4,617' FWL, Sec. 6-8N-13W-SM 11. Present well condition summary Total depth: measured true vertical 10,800' feet Plugs (measured) 10,079' feet 10,676' - 10,800' cement Effective depth: measured 10,676 ' true vertical 9,958' feet Junk (measured) feet None Casing Length Size Structural Conductor Surface 2,497' 13 3/8" Intermediate Production 8,145' 9 5/8" Liner 2,951' 7" Perforation depth: measured Cemented Measured depth True Vertical depth 2,000 sx 2,497' 2,404' 3,385 sx 8,145' 7,850' 900 sx 10,800' 10,079' See Attachment #1 true vertical ~bing(size, grade and measured depth) 4 1/2" N-80 @ 7,709', 3 1/2" N-80 @ 7,709' - 9,978' Packers and SSSV(type and measured depth) Otis "W9" Packer @ 9,909', Otis "DC" TRBV @ 306' RECEIVED 1 i !987 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Commission Anch0rcge 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf WateFBbl Casing Pressure 72 27 81 950 ps± 459 147 689 1100 psi ~bing Pressure 117 psi 140 psi 14. Attachments #2 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 ~* Marathon ~0il Company Signed Ro~D. Robe~ Form 10-404 Rev. 12-1-85 ~o\1// Sub-Operator TiHe Environmental Engineer Date 3/'6/87 Submit in Duplicate Bench Attachment #1 Well D-17RD Perforations MD (DIL) 10,052' - 10,080' 10,096' - 10,120' 10,178' - 10,192' 10,214' - 10,232' 10,260' - 10,295' 10,330' - 10,360' 10,366' - 10,378' 10,405' - 10,490' TVD 9,377' - 9,403' 9,419' - 9,442' 9,496' - 9,509' 9,530' - 9,547' 9,572' - 9,605' 9,638' - 9,666' 9,671' - 9,683' 9,708' - 9,787' Attachment #2 Well D-17RD Daily Report of Well Operations D-17RD was perforated and tested according to the schedule shown below with Schlumberger 2-1/8" Enerjets, 0° phasing, 4 SPF, underbalanced. Perforating Data Post Run Test Data Date Bench Interval (DIL) Feet BFPD WC% BOPD Comments 1/30/87 4 10,366' - 10,378' 12' None Reperf " 4 10,260' - 10,287' 27' None Reperf " 1 10,052' - 10,080' 28' 432 52% 208 Reperf 2/1/87 5 10,460' - 10,490' 30' 592 40% 355 New Zone 2/2/87 3 10,178' - 10,192' 14' None New Zone " 3 10,214' - 10,232' 18' 762 65% 267 New Zone 2/3/87 5 10,432' - 10,460' 28' None New Zone " 5 10,405' - 10,432' 27' None New Zone " 4 10,330' - 10,360' 30' 1148 60% 459 New Zone Rigged down Schlumberger. WLB/em/41B/Sundry STATE OF ALASKA ALAS('~ OIL AND GAS CONSERVATION COM~.-~SION APPLICATION FOR SUNDRY APPROVALS JAN 2 ! 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter ..... Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Oper{tor IJNOCAL 3. Address P.O. Box' 190247 Anchorage, AK 99519 4. Location of well at surfaceL'eg A-k, L;ond. #2 ])oily varden ~lanform 759' FSL, 1,127' ~7~, Sec. 6-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. W~II ~[~ber 8. Permit number 81-23 9. APl number 50-- 733-20168-01 Attop of productiveinterval 1,052' FSL, 4,360' FWL, Sec. 6-8N-13W-SM Ateffe~tive depth 1,118' FSL, 4,592' FWL, Sec. 6-8N-13W-SM Attotaldepth 1,125' FSL, 4,617' FWL, Sec. 6-8N-13W-SM 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 10,800 ' feet 10,079' feet Plugs (measured) 10,676' - 10,800' cement Effective depth: measured 10,676 ' feet true vertical 9,958 ' feet Casing Length Size Structural Junk (measured) None RECEIVED Cemented Measured depth JkN 2 2 1987 Conductor Surface 2,497' 13 3/8" Intermediate · Production 8,145' 9 5/8" Liner 2,951 ' 7" Perforation depth: measured true vertical ~a~,l~8~) & Gas Cons, Commission Sj~nch0rage 2,497' 3,385 sx 8,145' 900 sx 10,800' Bench 1 10,052' - 10,080' MD 9,377' Bench 2 10,096"- 10,120' MD 9,419' Bench 4 10,260' - 10,295' MD 9,572' 1.0,366' - 10,378' MD 9,671' ~bing(size, grade and measured depth) 4 1/2" N-80 @ 7,709', 3 1/2" N-80 @ 7,709' - 9,978' Packers and SSSV (type and measured depth) Otis "WD" Packer @ 9,909', Otis "DC" TRBV @ 306' True Vertical depth 2,404' 7,850' 10,079' - 9,403' TVD - 9,442' TVD - 9,605' TVD - 9,683' TVD 12.Attachment~ #1 Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 1-31-87 14. If proposal was verbally approved Name of approver Date approved 15. I hereb~erti~ th/a~t~ [be_ fgregoing is true and correct to the best of my knowledge Signed O ,fln Title Environmental Engineer ~/,,C/,,,. Commission Use Only Conditions of approval~'' Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearance I Date 1/21/87 * Marathon Oil Company - Sub-Operator Approved by BY. IL SJ~llii Form 10-403 ~ev 12:1-85 ~eturn~d Commissioner by order of the commission Date / Submit in triplicate ATTACHMENT #1 Well D-17RD Perforation-Procedure 1. Skid Rig #77 over Well D-17RD, 2. Test well for 12 hours. . 3. RU E-line w/2-1/8" guns, 4 SPF, 0° phasing. 4. Pressure test lubricator to 2,500 psi prior to each run. 5. Perforate as shown in the table below (perforate w/500-800 psi underbal- ance). Run Bench Depth (DIL) Footage I 4 10,366' - 10,378' 12' 2 4 10,260' - 10,292' 32' 3 2 10,096' - 10,120' 24' 4 1 10,052' -' 10,080' 28' Over a 4 hour period, bring well'on slowly bY adjusting gas lift and by opening flowline choke. Test wei1 for 12.hours and record time, CP, TP, lift gas, and watercut. 5 and if required: 6 5. "~10"4'60" - 10,49_0' '.30' 3 10,178' - 10,192' 14' 3 10,21'4' - 10,232' '18' ....... 6. Test well as"above~ 7. RD Ewline and test well for 48' hours as above--recording data every 4 hours. 8. RU slickline. 9. Pressure'test lubricator to 2,500 psi. 10. RIH w/single Amerada bomb to 10,129'--record FBHP for one hour. MDC/em/41B/Sundry RECEIVED JAN 22 1S87 Oil & Gas Cons, Commissi~ /~nchorage STATE OF ALASKA ALAS('-- OIL AND GAS CONSERVATION COM("-- ,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] DEC S 1986 Alter Casing [] Other [] 2. Name of Opera~tor UNOCAL C. W. LOCk~VOOD 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg A-Z, Uond. #2 Doily Varden Piacfo~ 759' FSL, 1,127' FWL, Sec. 6-SN-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 8. Approval number 534 9. APl number 50-- 733-20168-01 Attop ofproductiveinterval 1,052' FSL, 4,360' FWL, Sec. 6-8N-13W-SM Ateffective depth 1,118' FSL, 4,592' FWL, Sec. 6-8N-13W-SM Attotaldepth 1,125' FSL, 4,617' FWL, Sec. 6-8N-13W-SM 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 10,800' feet 10,079' feet Plugs (measured) 10,676' - 10,800' cement Effective depth: measured 10,676 ' true vertical 9,958 ' feet feet Junk (measured) None Casing Length Structural Size Cemented Measured depth True Vertical depth Conductor Surface 2,497' 13 3/8" 2,000 sx 2,497' Intermediate Production 8,145' 9 5/8" 3,385 sx 8,145' Liner 2,951' 7" 900 sx 10,800' 2,404' 7,850' 10,079' Perforation depth: measured true vertical Tubing (size, grade and measured depth) Bench 1 Bench 2 Bench 4 10,052' - 10,080' MD 10,096' - 10,120' MD 10,260' - 10,295' MD 10,366' - 10,378' MD 4 1/2" N-80 @ 7,709', 3 1/2" N-80 @ 7,709' - 9,978' Packers and SSSV(type and measured depth) Otis "WD" Packer @ 9,909', Otis "DC" TRBV @ 306' 9,377' - 9,403' TVD 9,419' - 9,442' TVD 9,572' - 9,605' TVD 9,671' - 9,683' TVD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Pro.duction or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 10/1'2/86 89 28 105 1000 psig Subsequent to operation 11/10/86 187 60 220 1150 psig Tubing Pressure 130 psig )0 14. Attachmentsx #1 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 * Marathon Oil Company - Sub Operator Signed D. Roberts Title Env i ronmenta 1 Form 10-404 Rev. 12-1-85 Engineer Date Submit in 'Dul~licate ATTACHMENT #1 Daily Report of Well Operations WEll D-17RD 11/1/86 1. RU coiled tbg unit and pressure tested equipment to 4,500 psi. 2. RIH w/down jetting and indexing tool. 3. Tagged @ 9,609' and worked down to 9,638' CTM. 4. POH & changed out jetting tool to side jet. 5. RIH and worked to 10,060' CTM. 6. POH w/coiled tbg. 11/2/86 1. RIH w/down jet tool. 2. Tagged @ 9,660' and worked to 9,748' CTM. 3. POH w/coiled tbg. 11/3/86 1. RIH w/side jet tool. 2. Tagged @ 9,721' CTM and worked to 9,900' CTM. 3. POH w/coiled tbg. 4. Return well to production. 11/9/86 1. RU coiled tbg unit and pressure test to 4,500 psi. 2. RIH w/down jet tool. 3. Tagged @ 9,662' and worked to 9,861' CTM. 4. POH w/coiled tbg. MDC/em/41A/Sundry Daily Report of Well Operations WEll D-17RD (Continued) 11/10/86 1. RIH w/Navi drill. 2. Drilled from 9,600' - 10,500' CTM. 3. Circulated hole clean. 4. POH w/coiled tbg. 5. Returned well to production. MDC/em/41A/Sundry STATE OF ALASKA ALAS :)IL AND GAS CONSERVATION COM .~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Oper~or UNOCAL 3. Address ?.0. :Box 190247 Anchorage, AY,, 99519 4. Location of well at surfaceLeg A-2, t;ond. #2 Uoiiy ~arden ?ia~:£or~ 759' FSL, 1,127' FWL, Sec. 6-8N-13W-SM At top of productive interval 1,052' FSL, 4,360' FWL, Sec. 6-8N-13W-SM At effective depth 1,118' FSL, 4,592' FWL, Sec. 6-8N-13W-SM At total depth 1,125' FSL, 4,617' FWL, Sec. 6-8N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. W~)I/ 8. Permit number 81-23 9. APl number 50-- 733-20168-01 10. Pool Hemlock feet 11. Present well condition summary Total depth: measured true vertical 10,800' feet Plugs (measured) 10,676' 10,079' feet - 10,800' cement Effective depth: measured 10,676' true vertical 9,958 ' feet Junk (measured) None feet Casing Length Structural Size Cemented Measured depth Conductor Surface 2,497 ' Intermediate Production 8,145 ' Liner 2,951' Perforation depth: measured true vertical 13 3/8" 2,000 sx 2,497' 9 5/8" 3,385 sx 8,145' 7" 900 sx 10,800' Bench 1 10,052' - 10,080' MD Bench 2 10,096' - 10,120' MD Bench 4 10,260' - 10,295' MD 10,366' - 10,378' MD - 9,978' , Otis "DC" TRBV @ 306' Tubing(size, grade and measured depth) 4 1/2" N-80 @ 7,709', 3 1/2" N-80 @ 7,709' Packers and SSSV(type and meaSured depth) Otis "WD" Packer @ 9,909' True Vertical depth 2,404' 7,580' 10,079' 9,377' - 9,403' TVD 9,419' - 9,442' TVD 9,572' - 9,605' TVD 9,671' - 9,683' TVD 12.Attachment~ Description summary of pro£9%§l~ Detailed operations program [] 13. Estimated date for commencing operation 14. If proposal was verbally approved ~¢ ~'~1 _~tober 1986 Name of approver ~f~l~ BOP sketch [] Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~'~ :i v:~~//%44( Title ~,~¢~~~~ Commission Use Only Conditions of pp o o~/commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI Approved by ~ '.~ ',- {/ ,, ~,_ 7~//~.~,r Form 10-403 Rev 12-1-85 Date . .. ": ..... ' " by order of '~,/ / / Commissioner t hecommission Dat~~/~ ~ . ~ub~im triplicate ATTACHYd~NT PROCEDURE TBU WEll D-17RD Scale Cleanout It is Marathon's intention to remove tubing scale restrictions using coiled tubing on Well D-17RD during October 1986 by the following procedure: 1) Rig up and pressure test coiled tubing and connections. 2) Run in hole with jet drilling tool using 1 1/4" coiled tubing. 3) Jet clean through tubing tail at 9,978', circulate clean. 4) Tag bottom w/coiled tbg. Circulate clean. 5) Pull out of hole with coiled tubing and rig down. 6) Return Well D-17RD to production. MDC/em/41/Sundry Union Oil and'~. Region Gas vision: Western Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union July 8, 1985 Mr. C.V. Chatterton AK. Oil and Gas Conservation Commission 3001Rorcupine Drive Anchorage, AK. 99502 ' Dear Mr. Chatterton: SUNDRY NOTICE INTENTIONS & SUBSEQUENTS Attached please find Sundry Notice Intentions for D-42 & D-7RD & Subsequents for D-29RD, & D-17RD, Trading Bay Unit, McArthur River Field. Please return t approved Sundry Notice of Intentions to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST. LOC/tj Attachments JUL 0 9 I~B~ Alaska Oi~ & Gas Cons. Anchor~.ge STATE OF ALASKA ALASKA IL AND GAS CONSERVATION C ~v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator Union Oil Company of California* 3. Address P. O. Box 6247 Anchorage, AK 99502 4. Location of Well Surface: Leg A-2, Cond. 759' FSL, 1127' #2, Dolly Varden Platform FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 6. Lease Designation and Serial No. ADL-18729 7. Permit No. 81-2~ 8. APl Number 5o-733-20168-01 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-[ 7RD 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). TBU WELL D-17RD SAND FILL CLEANOUT Coiled tubing operations to clean out sand fill began on June 14, 1985 and were completed on June 15, 1985. 1. Rig up CTU and lines. Pressure test to 5000 psi. 2. RIH w/ 2.70" mill on CT. Tag bridge at 10,056' CTM. 3. D~illed bridge from 10,056' CTM to 10,060'. 4. RIH with CT and tagged bottom at 10,672' CTM. 5. POH and RD CTU. 6. Returned well to production. ECEIVED JUL 0 9 1985 *Marathon Oil Company - Sub Operator Gas Cons. Commie,~ Anchorage SignL~W~ENCE O. CUTTING The space below for Commission use correct to the best of my knowledge. Title ENVIRONMENTAL SPECTALIST Date 07/08/85 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date ion Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Ga~..~ivision: Western Region Union Oil Compar~Y of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union July 8, 1985 Mr. C.V. Chatterton AK. Oil and Gas Conservation Commission ~OO1 Porcupine Drive Anchorage, AK. 99502 ~. Dear Mr. Chatterton: SUNDRY NOTICE INTENTIONS & SUBSEQUENTS Attached please find Sundry Notlce Intentions for D-42 & D-7RD & Subsequents for D-29RD, & D-17RD, Trading Bay Unit, McArthur River Field. Please return th pproved Sundry Notice of Intentions to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST. LOC/tj Attachments RECEIVED AlaSka Oil & Gas Cons. Oommission Anchorage A(t3 STATE OF ALASKA CC ALASK IL AND GAS CONSERVATION MMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Union Oil Company of California* 3. Address P. O. Box 6247 Anchorage, AK 99502 4. Location of Well Surface: Leg A-2, Cond. 759' FSL, 1127' #2, Dolly Varden Platform FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 7. Permit No. 81-23 8. APl Number 50-733-20168-01 9. Unit or Lease Name 12. Trading Bay Unit 10. Well Number D-17RD 6. Lease Designation and Serial No. ADL-18729 Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool McArthur River NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and gige pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). TBU WELL D-17RD REPERFORATION On June 19 and 20 4 SPF, 0© phasing , 1985, the well was perforated with 2-1/8" guns, , under drawdown at the following intervals: Bench 1 10,052' - 10,080' DIL Bench 2 10,096' - 10,120' DIL Bench<4 10,260' - 10,295' DIL 10,366' - 10,378' DIL (new interval) (new interval) Production before reperforating: 64 BFPD, 61% WC, 25 BOPD, 39 BWPD. Production after reperforating: 722 BFPD, 30% WC, 505 BOPD, 217 BWPD. *Marathon Oil Company - Sub Operator 14.1 hereby c~th~//~e~~nd correct to the best of my knowledge. LAWRENCE 0. CUTT/NG ENVIRONMENTAL SPECIALIST RECEIVED J U L 0 91985 Alaska 0il & Gas Cons. Commission Anchorage 07/08/85 Signed The space below for Commission use Title Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Gas Division: Western Region Union Oil Company o~, ,.;alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlen .June 20, 1985 Mr. C.V. Chatterton AK. Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton: Attached for your approval is a Sundry Notice of Intention for D-17RD & Well Completion for D-29RD, Trading Bay Unit. Please return the approved Sundry to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST LOC/ti Attachments RECEIVED' JUN 2 1 1985 AIasKa 0it & Gas Cons. Commission Anchorage ( STATE OF ALASKA CL ALASKA OIL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] Name of Operator Union Oil Company Address P. O. Box 6247 4. Location of Well Surface: Leg A-2, Cond. 759' FSL, 1127' Anchorage~ AK 995~2 92, Dolly Varden Platform FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 6. Lease Designation and Serial No. ADL-18729 7. Permit No. 81-23 8. APl Number 5o_733-20168-01' 12. 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-17RD 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] . Stimulation [] Abandonment [] Repair'Well (~ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give. pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). TBU WELL D-17RD SAND FILL CLEANOUT It is Marathon's intention to begin CTU sand fill cleanout operations on June 14,1985. 1. Rig up and pressure test CTU to ~000 psi. 2. RIH w/ CT to sand fill at 10,050'. 3. Pump FIW to wash sand from hole to PBTD @ 10,6~/~&e.~d . 4. POH w/ CT and rig down 5. ~i9 up to perforate as approved on Fo~m 10-403 dated ~/o~ February 25, 1985. Verbal approval for the CTU sand cleanout procedure was received from Russ Douglass of AOGCC on June 13, 1985 by W. J. Laverdure. *Marathon Oil Company - Sub operator 14.1 hereby ~at t~e~or~nd Signed The space below for Commission use correct to the best of my knowledge. Title Env i r0rlT~rr~ 1 Date 06/20/85 Conditions of Approval, if any: Approved by Approved By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Gas Djv!sion' Western Region Union Oil Company',.., California P.O. Box 6247, Anchorage, Alaska 99502 Telephone' (907) 276-7600 union May 10, 1985 Mr. Chat Chatterton AK. Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99504 SUNDRY NOTICE D-17RD Dear Mr. Chatterton: Attached is a Sundry Notice Subsequent for D-17RD, Trading Bay Unit for your information and file. LOC/tj Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST cc: Partners RECEIVED Oi~ & Gas Cons. Commission Anchorage ( STATE OF ALASKA ~u ALASKA OIL AND GAS CONSERVATION MMISSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] 2. Name of Operator Union Oil Company of California* 3. Address P.O. Box 6247 Anchorage, AK 99502 4. Location of Well Sur face: Leg A-2, Cond. #2, Dolly Varden Platform 759' FSL, 1127' FWL, Sec. 6-SN-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL COMPLETED WELL I 6 . Lease Designation and Serial No. ADL-18729 OTHER [] 7. Permit No. 81-23 8. APl Number 50- 733-20168-01 9. Unit or Lease Name Trading Bay Unit 10. Well Number D- 17RD 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [-] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state a'll pertinent details and give pertinent dates, inclUding estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). TBU WELL D-17RD Scale Cleanout Coiled tubing scale cleanout operations began on March 21, 1985, and were completed on March 30, 1985, as follows' 1. Rig up and pressure test CTU to 4000 psi. 2. RIH w/ 2.70" mill and mill scale to 9819' CTM. Could not get deeper. POH to repair coiled tubing unit. 3. RIH with coiled tubing unit and tagged obstruction at 9819' CTM. Drilled ~ard scale through tubing tail at 9964'. Tagged sandfill at 10,050'. POH. 4. Rig up and pressure test CTU and N2 pumpers to 2000 psi. 5. RIH and jetted well dry to 9950' CTU. 6. Began injecting foam .25 BPM w/ N2 at 4000 psi. 7. Heavy emulsion returns--no foam--foam would not lift sand. 8. POH, rig down CTU, return well to production, i~ E ¢ E IV E D *Marathon Oil Company, Sub Operator MAY ! $ ]985 ;',las~a Oi~ & t~as Cons. Commission A,";c,hora~e 14. I hereby ce. rtify.~at th~e fox__and correct t° the best of my knowledge. ~--"7, Signed L~,A/ranp~~~/C~~~,,++;ng ~,', Title ENVIRONMENTAL SPECIALIST The space below for Commission use Conditions of Approval, if any: Approved by Form 10-403 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate Union Oil and Gas D~i~ion: Western Region Union Oil Company o~" California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlen ~ebruary 14, 1985 Mr. C.V. Chatterton Ak. Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99502 Dear Mr. Chatterton: SUNDRY NOTICES D-17RD,_ D_-i!_,_D-8RD Attached please find Sundry Notice Intentions for the following wells. D-17RD, D-11, & D-BRD all Trading Bay Unit, McArthur River Field. Please return the approved Sundry Notice's to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST. LOC/tj Attachments RECEIVED FEB 2 1 1985 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASK/~" ,L AND GAS CONSERVATION C~("i,'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~" OTHER [] 2. Name of Operator Union Oil Company of California* 3. Address P.O. Box 6247 Anchorage, AK 99502 4. Location of Well Sur face: Leg A-2, Cond. ~2, Dolly Varden Platform 759' FSL, 1127' FWL, Sec. 6-SN-13W~$M 7. Permit No. 81-23 8. APl Number 50- 733-2'0168-01 9. Unit or Lease Name _ Tradin~ Ray lhSt 10. Well Number D- 1 ?RD 11. Field and Pool t 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB above MSL I APL-18729 McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate J~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~, Pulling Tubing [] (Note; Report multiple completions on Form 10-407 with a submitted Form !0-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is Marathon's intention to reperforate the well with 2-1/2" guns, 4 HPF, 0° phasing under dra~down. Bench 1 Bench 2 Bench 4 10,052' - 10,080' DIL 10,096' - 10,120' DIL (new perforations) 10,260' - 10,295' DIL (new perforations) 10,366' - 10,378' DIL The January, 1985, production test averages were: 310 BFPD, 45¢~ WC, 170 BOPD, '140 BWPD. Work Reported. ~ Fo~m No. RECEIVED *Marathon Oil Company, Sub Operator Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby~a~ f o~__~~[~u e Signed L~(. CutTing The space below for Commission use and correct to the best of my knowledge. ~Tit lo Envi ronmenta I Conditions of Approval, if any: Approved by Specialist Date 02-14-8 5 _ ~,pproved Cop7 Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA(.-- ,L AND GAS CONSERVATION C~,~r ,iMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of California* 81-23 3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 5o- 733-20168-01 4. Location of Well Surface: Leg A-2, Cond. #2, Dolly Varden Platform 759' FSL, 1127' FW~, Sec. 6-SN-13W-.qM 5. Elevation in feet (indicate KB, DF, etc.) 106 ' KB above MSL 6. Lease Designation and Serial No. ADL- 1872 9 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-17RD 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation i-]. Abandonment [] Repair Well C~ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). TBU WE.,LL D-17RD SCALE CLEANOUT It is Marathon's intention to use a coiled tubing unit to clean out scale beginning in February, 1985, as follows: 1. Rig up coiled tubing unit, lines and BOPE. Pressure test to 5000 psi. 2. RIH w/ 2.7" mill on coiled tubing to 8800' and circulate clean with FIW. 3. Mill out scale through tubing tail at 9978'. Circulate clean. 4. RIH and tag fill. 5. POH, return well to production. *Harathon 011 Company, Sub Operator RECEIVED F'EB 2 1 1985 AlaSKa 0il & Gas Cons. Commission Anchorage 14. I hereby c~rtif~at th_efor~ and correct to the best of my knowledge. Signed I~wrence d. CU'~] ng Title Envi ronmeni-a I The space below for Commission use Speicialist Date 02-14-85 Conditions of Approval, if any: Approved by Approved · R®turned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Gas ¢ision' Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlen February 4, 1985 Hr. Chat Chatterton AK. 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99504 Dear Mr. Chatterton: Attached are Sundry Notice Subsequents for D-gRD & ~D-17RD, Trading Bay Unit for your information and file. ~ LOC/ti Attachments Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST RECEIVED F E B o 5 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. Union Oil Company of California* 81-23 3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 50- 733-20168-01 OTHER [] 4. Location of Well Sur fac e: Leg A-2, Cond. ~2, Doll.v Varden Platform 759' FSL, 1127' ~L, Sec. 6-SN-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106 ' KB above PLRL 6. Lease Designation and Serial No. A~-18729 9. Unit or Lease Name Trading Bay [hit 10. Well Number D-17RD 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On January 10, 1985, an attempt was made to reperforate the well as approved in the Sundry Intent of October 10, 1984. The well was not reperforated because of an obstruction at 9908' WLM. Ak Environmental Group *Marathon Oil Company, Sub Operator 14. t hereby ce~ego~[~g is t~rue and correct t f my knowledge. S,gned L~v~rence 0~ Cutt'rng T,tle Envir0nmental Special 1st The space below for Commission use J ECEIVED FEB 0 5 ]985 Alaska Oil & Gas Cons. Commission Anchorage Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and C~ Division: Western Region Union Oil Company of California P,O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union October 2, 1984 Mr. Chat Chatterton Alaska Oil & Gas Conservation Commission 3001 Rorcupine Drive Anchorage, Ak. 9~502 DearMr. Chatterton: SUNDRY NOTICE - DOLLY VARDEN PLATFORM Attached, for your approval are Sundry Notices to perforate Marathon operated wells D-gRD and D-17RD. Rlease return the approved Notices to the undersigned. Very truly yours, Lawrence O. cuttin~ Environmental lechnician LOC:cwl Attachment RECEIVED OCT 0 919~14 Alaska OJ~ & Gas Cons. Commission Anchorage 1 STATE OF ALASKA ALAS . OIL AND GAS CONSERVATION(" JMMISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. Union Oil Company of California* 81-23 3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 50- 733-20168-01 4. Location of Well Surface: Leg A-2, Cond. ~2, Dolly Varden Platform 759' FSL, 1127' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 6. Lease Designation and Serial No. ADL 18729 9. Unit or Lease Name Trading Bay Unit 12. 10. Well Number D-17RD 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [:~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) The September, 1984, production test averages were 161 BWPD. SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105~170). It. is Marathon's intention to reperforate the well with 2-1/2" guns, 4 HPF, 0° phasing, under drawdown. Bench 1 10,052' - 10,062' DIL 10,070' - 10,080' DIL Bench 2 10,096' -10,120' DIL (New Perforations) Bench 4 10,260' - 10,295' DIL 10,366' - 10,378' DIL 288 BFPD, 56% WC, 127 BOPD, 14.1 here~ th~,~e forego inglis true and correct to~~y knowledge. Signed ~' 4,14,t,..,,...-%.,',' Environmental Tech. R£CE[VED at~t~au~t Worl¢..11! '". . OCT 0 9 *~ra~on Oil Co~ny - Sub ~ ~'o '~ Ala~ Oil & G~ ~ns. ~m~ The space below for Commission use Conditions of APproval, if any: BT LOI~,~I[ I~. SiliII Date 10/4/84 Approved by Approved Copy' COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Gas Di~i*ion: Western Region Union Oil Company o'f California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 DOCUMENT TRANSMITTAL unl, n 3anuary 5, 1983 Hand Delivered TO: Mr. William Van Alen LOCATION: 3001 Porcupine Drive Anchorage, AK 99501 FROM: R.C. Warthen LOCATION: Alaska District Transmitting: REFERENCE: TBU D-17 RD (corrected) One (1) magnetic tape elECt 1004 One (1) verification sheet CfECC 1004 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. RECEIVED BY: Alaska Oil & Gas Cons, CommisSion Anchorage Document Transmittal Union Oil Company of California unlen of; TRANSMITTING THE FOLLOWING: DATE SUBMITTED ACCOUNTING MONTH FROM TELEPHONE NO. Tan!~ential Directional su 2" and 5" DIL 5" FDC Rad. of Curv. Dir. Tang. Ave. Anlge Di Survey FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. Hr. Robert C. 'Warthen Union Oil Company of California P. O. Box 62t7 .Anchorage, Alaska 99502 April 22, 1982 Hissing Information - Completed Wells Dear Bob: We wish to bring to your attention that the below-indicated material on the following Union Oil Company wells has not yet been received by the Alaska Oil and Gas Conservation Commission: Well Granite Pt. ~33-14RD Co,mplet ion Date 3/6/81 His s in~ Material -DIL/SP & CBL/VDL Elec. Logs. Trading Bay Unit ~D-gRD 312182 -Digitized E. Log Tape Trading Bay Unit ~D-16RD Trading Bay Unit ~D-17RD Trading Bay Unit #K-3RD 518/81 6/22/81 5/22/81 -Directional Survey -Elec. Logs -Directional Survey -Well History Trading Bay ~.St. #A-gED 5/6181 -Directional Survey -Digitized E. Log Tape Trading Bay St. ~A-17RD 7/3/81 -Digitized E. Log Tape Cannery Loop Unit ~3 9/13/81 -Digitized E. Log Tape Kenai Unit #34-32 1/lS/SZ -Digitized E. Log Tape -Certified Survey Plat -Directional Survey -DST or Prod. Test Reports Trail Ridge Unit #1 12/13/80 -Certified Survey Plat Please submit the above material at your earliest convenience since you are now in violation of Title 20, Chapter 25 of the Alaska Admin- istrative Code. Very. t~.uly yj~urs, ,;i';,: ' William Van Alen Petroleum Geologist WVA:v~i Document Transmittal Union Oil Company of Califo~ unlsn tAND DELIVERY ~^TE SUSM,TTEO ^CCOUNT,NG MONT. 3--23--82 TO PROM William Van Allen R.C. Warthen AT AT State 0il and Gas C( PO Box 6247 Anchorage, Alaska Anchorage, AK 99502 TELEPHONE NO. TRANSMITTING THE FOLLOWING: 1 ea Magnetic tape of TBU D-17 UIFL, AU, GR, SP, CN, CDL 8100-1GE-S0 6-8-81 '~' PLEASE SIGN AND RETURN ON- COPY DATE' FORM 1-2M02 (REV. 1 t-72) PRINTED IN U.S.A. Robert T. Anderson District Land Manager Union Oil and ~.ison: Western Region Union Oil Company c,, California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union October 16, 1981 · Mr. Hoyle Hamilton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 STATE OF ALASKA 1981 Permits to Drill Correction of Bonding Information Dear Mr. Hamilgo~ It has been brought to my attention that we have been carrying incorrect bonding information on all Union operated Permits to Drill submitted to the Alaska Oil & Gas Conservation Commission since January 1, 1981. For each of the below listed wells, Item No. 12 on the Permit to Drill (Form 10-401) should be changed from United Pacific Insurance Company (B-55372) in the amount of ~100,000.00 to National Fire Insurance Company of Hartford (B-5534278) in the amount of ~200,000.00. WELLS PERMITED DATED PERMITED API NUMBER DATED APPROVED TBS A-9 Rd. 3/17/81 50-733-20062-01 3/24/81 CLU #3 4/20/81 50-133-20340 4/28/81 7?Rd~ ~ 5/12/81 50-733-20135-01 5/15/81 KDU #7 6/26/81 50-133-20341 7/27/81 KDU #8 6/26/81 50-133-20342 9/17/81 WD #1 7/14/81 Pending Pending KBU #31-7 10/8/81 Pending Pending KU #34-32 10/8/81 Pending Pending Tungak Creek #1 10/14/81 Pending RECE~vE~Pending 0C '? Alaska 0il. & (l;~s Cons. Commission Anchorage 1981 Permits to Drill Correction of Bonding Information -2- October 16, 1981 'We would appreciate your reflecting these corrections on your copies of the subject Permits and we will do the same on ours. We apologize for the oversite and any inconvenience this has caused. Ail future Permits submitted for your approval will have the current bOnding information on theTM. sk cc: Ann Lannin-LA Office Jim Callender Very Truly yours, Robert T. Anderson / OCT 2 o 198 Alaska Oi~ & Gas Cons. Commission Anchorage ~ ( .... STATE OF ALASKA ( ~" ALASI~-6, ~: AND GAS CONSERVATION 'bo~.....~!_SSION WELL COMPLETION OR RECOMPLE:TION REPORT ANI:)LOG- -%~-Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Union Oil Company of California* 81-23 3. Address 8. APl Number Post Office Box 6247, Anchorage AK 99502 50-733-20168-01 4. Location of weH at surface Dolly Varden Platform, Leg A-2, Cond 9. unitor LeaseName 759.4'FSL, l127.4'FWL, Sec. 6, T8N, R13W, ,SM #2 Trading Bay Unit At Top Producing Interval 10. Well Number 1052'FSL, 4360'FWL, Sec. 6, T8N, R13W, SM D-17RD At Total Depth 11. Field and Pool l125'FSL, 4617'FWL, Sec. 6, T8N, R13W, SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. McArthur River Field 106.2'KB MSLI ADL-18729 A-926 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore .I 16. No. of ComPletions 05-08-81 06-07-81 06-22-81 90 feet MSLI 1 ..17. TotalDepth(MD+TVO) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 100'MD;10,079'TVD 10,676'MD;9958'TVI YESJ~[ NO [] 301feetMD ___ 22. Type Electric or Other Logs Run Gyro~ CBL/VDL/CCL/GR, DIL/SP/GR, Density/Neutron/Caliper, Soni¢/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 7" 29#'. 32# N-80 7839, ]0. gO0, g-i/?" qnn .~ · ,. · _ 24. Perforations open to Production (MD?TVD of Top and BOttom and 25... TUBING RECORD interval, size and number) . SIZE DEPTH SET (MD') PACKER SET (MD) · Top Bottom ~-]/9"/4-1/~:" 9978 ' 9909 ' 10,052'MD (9377'TVD) 10,062'MD (9387'TVD) 10,070'MD (9394'TVD) 10,080'MD (9403'TVD) 26.' ACID, FRACTURE, CEMENT SQUEEZE, ETC. " 10,366'MD (9671'TVD) 10,378'MD (9683'TVD) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED MA Perfd w/ DA 2-5/8" Slim Kone gun, 8 HPF. · · 27. pRoDOcTI'oN TE~S~ Date First Production I Method of Operation (Flow!ng~ gas lift,.etc.) 06-20--8]~ ~ ' '"'" Gas T,Jft · .... : ., Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 06-24,-81., 24 . TEST PERIOD ~ 725 9,61 ' .,..-- Flow Tubing' Casing'Pr.e~sure ... CALCULATED I~ OIL-BBL ..GES-MCF .. W-/~'I:ER'-BBL "O I~.~,VITY-API (~'o~~ Press. 150 " 1060 :~4-HOUR RATE ._ : , 28. "' CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NA ,,.- .'. '.: ... :. RECEIVFD · ' · Marathon Oil Company - Sub-Operator Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ! '- · 29. 'GEOLOGIC MARKERS FORMATION TESTS _ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH ~ GOR,and time of each phase. None ,, , , 31. LIST OF ATTACHMENTS Well History, Liner and Tubing Details 32. I hereby cer/~that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other, spaces on this form and in any attachments. Item 16 and 24: If t..hJs well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval rePorted in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 2:3: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 r~'~e~ ~4e4 eEv. a-aa DATE June 23, 1981 MARATHON oIL, COMPANY HISTORY OF OIL OR GAS WELL FIELD McArthur Rvr WELL NO. D-17RD LEASE AI aska STATE Trading Bay Unit PARISH Kenai Penin- sula Borough COUNTY BLOCK SEC., 6 TWP. 8N R.!3W 106.2' ELEV. KB MEASUREMENTS TAKEN FROM IToP OF OiL STRING ELEV., TOP OF ROTARY TABLE__ ELEV. GRD. OR MAT.. ELEV.~ HISTORY PREPARED BY L. G. Haywood TITLE Secretary It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. D ~ J~ ~' ~ DATE 1981 05-08 05-09 05-10 05-11 05-12 05-13 05-14 05-15 05-16 05-17 05-18 05-19 05-20 05-21 ll,808'TD 10,666'PBTD 11,808'TD 10,666'PBTD 11,808'TD 10,666'PBTD 11,808'TD lO,666'PBTD 11,808'TD 10,666'PBTD 11,808'TD 10,666'PBTD ll,808'TD lO,666'PBTD 11,808'TD 10,666 ' PBTD 11,808'TD 10,666 ' PBTD 11,808 'TD 1 O, 666 ' PBTD 11,808 'TD 9,706 ' PBTD 11,808'TD 9,706'PBTD 11,808'TD 9,706'PBTD 11,808'TD 9,706'PBTD WELL HISTORY - WELL TBU D-17RD (Marathon AFE 4809) Moved eqpmt & RU on rig ~77 to begin ops on Well D-17RD. Had previously perfd holes in tbg @ 9902'. Circ w/ FIW, & killed well w/ mud from D-16RD. Presently activating rig. Cont moving eqpmt from rig 76 to 77. Activating rig. Cont activating rig 77. Fin activating rig 77. Circ well & cond mud. lnstld BPV. ND tree. NU BOPE. Fin NU BOPE & ts'td. Pulled pkr loose from 9959' w/ 42,000# pull. POH & LD .4-1/2" prod tbg & eqpmt. Presently chg 4-1/2" to 5" pipe rams. Instld 5" rams. Tstd BOP (witnessed by State DOG rep). MU BHA w/ bit & scraper. RIH. Washed out to PBTD @ 10,666'. C&C mud--mixed volume. Mixed mud, C&C mud. POH. Ran bond log across area of kickoff-- bond good. Ran log 2800' up to surf. Presently running gyro. Fin running gyro to PBTD. Reran CBL--no chg. RIH w/ OEDP & spotted 250 sx cmt across Hemlock perfs (10,094'-10,580') w/ est TOC @ 9990'. Pulled 10 stds & rev out slightly cmt contaminated mud. Presently C&C mud while WOC. WOC. POH w/ OEDP. Ran GR & junk basket on WL to 9725'. Set 9-5/8" perm BP @ 9706'WLM. MU BHA & RIH. Press BP to 20,000# & tstd to 2000 psi--OK. Circ & built visc. POH to PU section mill. POH w/ bit. MU section mill. RiH--tight @ 6100'. POH & chg BHA. RIH & began cutting window in.9-5/8" csg @ 8145'. Milled to 8151'. POH. ' Milling window. POH w/ mill #1. Chgd kelly from rig 76 to 77. MU mill ~2 & RIH. CBU. Milled from 8151'-8167'. (Total window cut @ 0700 hrs, 8145'-67'=22'.) POH w/ mill #2. Ran mill ~3 & milled 8167'-76'. POH for mill #4. PU same & RIH. (Total window--8145'-76'=31'.) Reamed thru Section area & cleaned hole. Milled section 8176'-8191'. (Total window--8145'-91'=46'.) Fin milling section in 9-5/8" csg. Total section 8145'-8205' (60'). Circ & POH. RIH w/ OEDP & spotted 125'sk cmt plug across section from 8242'-7955' (est TOC). Pulled 6 stds & circ & rec wtr. C&C mud to lower visc. POH. Well History - TBU D-17RD Page 2 REC'EIVt:f) 05-22 11,808 ' TD 8,030 ' PBTD Fin POH w/ OEDP. WOC, tstd BOPE, & WO rig~~ RIH & tagged TOC @ 7938'. CBU. Drld cmt 7928'-8030'. 05-23 8,178'TD 8,151'KOP Drld cmt 8080'-8151'. POH. RIH w/ DD #1. Oriented DD & drld 8151'-8178'. 05-24 8,325'TD 8,151'KOP Drld 8178'-8188' w/ DD. POH. Chgd BHA & RIH. Reamed 8148'-8188'. Ran fm leakoff test to 14.9 ppg equiv. Drld 8188'-8325'. Circ & surv. POH. NOTE: Surv no good--too close to csg stub. 05-25 8,348'TD Fin POH w/ bit #1. RIH w/ DD #2. RIH w/ WL to orient tools. DD stalling out on btm. POH w/ WL & DP. RIH w/ bit #3 & JB. Drld & worked on junk 8325'-8348'. 05-26 8,434'TD 05-27 8,620'TD Fin repairing RT. Drld 8348'-8363' to clean junk off btm. POH. Rec only 2 sml pieces of junk in basket. RIH w/ DD #3. RU steering tool & DD 8363'-8434'. POH. MU BHA. RIH & presently reaming DD #3 run to 8434'. Fin reaming to 8434' following DD ~3 run. Drld 8434'-8558'. Surv & POH. RIH w/ DD #4. RU steering tool & DD 8558'-8620'. POH. Presently RIH w/ follow-up assy. 05-28 8,752'TD RIH & reamed DD #4 run. Drld 8620'-8745'. Surv & POH. RIH w/ DD #5 & oriented w/ steering tool. DD 8745'-8752'. Cont'DD. 05-29 8,942'TD DD 8752'-8815'. POH. Tstd BOPE. MU BHA. RIH & reamed DD run ~5. Drld & surv 8815'-8942'. 05-30 9,116'TD Drld 8942'-9087'. Surv & POH. RIH w/ bit #lO--tight @ 6360'+ in 9~5/8'' csg. · Circ but could only get 1200 psi @ 57 SPM. POH looking for hole. Had 1 jet out of bit. RIH & reamed to btm. Drld 9087'-9116'. Drlg @ report time. 05-31 9,342'TD Drld 9116'-9287'. Surv & POH. Ran inspection log on 9-5/8" csg from 8050' to surf--no severe wewar. RIH w/ bit #11 on locked BHA, Reamed 60' to btm. Drld 9287 '-9342'. 06-01 9,525'TD Drld 9342'-9483'. Surv & POH. Hole tight 9200'-8900'. RIH w/ bit #12. Reamed 8800'-9483'. Drld 9483'-9525'. 06-02 9,753 ' TD Drld 9525'-9753' w/ bit trip @ 9680'. 06-03 9,890'TD Drld 9753'-9806'. Surv & tripped for bit #14. Drld 9806'-9890'. 06-04 IO,060'TD Drld 9890'-10,060' w/ bit trip @ 9946'. 06-05 10,307'TD Drld 10,060'-10,080'. Su.rv & POH. Tstd BOPE. RIH & drld 10,080'-10,307'. 06-06 10,643'TD 06-07 IO,800'TD Drld 10,307'-10,643' w/ wiper trip to 9-5/8" shoe @ 8145'. Surv & POH w/ bit #16. RIH w/ bit #17. Reamed 60, t° btm. Drld 10,643'-10,800'TD. Made short trip to 9-5/8". RIH. C&C hole to log. Surv & POH. 06-08 IO,800'TD Ran open hole logs: DIL/SP/GR, Density/Neutron/Caliper, and Sonic/GR/Caliper. All logs from 10,796' to 9-5/8" shoe @ 8145'. RD loggers & prep to cond hole for 7" Inr. 06-09 IO,800'TD RIH w/ bit to 10,800'. C&C hole for 7" Inr. POH. Ran 72 jts 7" Inr & hgr to 10,800'. Circ before cmtg. Had leak in cmtg manifold. Circ & reciprocate pipe whil'e waiting on new manifold. Well History - TBU D-17RD Page 3 06-10 IO,800'TD 06-11 IO,800'TD 10,676'PBTD 06-12 IO,800'TD 10,676'PBTD 06-13 IO,800'TD 10,676'PBTD 06-14 IO,800'TD 06-15 IO,800'TD 10,676'PBTD 06-16 IO,800'TD 10,676'PBTD 06-17 IO,800'TD 10,676'PBTD 06-18 IO,800'TD 10,676'PBTD 06-19 IO,800'TD lO,676'PBTD 06-20 IO,800'TD 10,676'PBTD 06-21 IO,800'TD lO,676'PBTD 06-22 IO,800'TD lO,676'PBTD Instld new cmtg manifold. Cmtd 7" Inr w/ 900 sx cmt. CIP @ 1100 hrs, 06-09-81. Released from Inr hgr & pul led DP. Rev out 80 sx cmt. POH. WOC & LD drlg tools. RIH w/ 8-1/2" bit & tagged TOC @ 7162'. Drld firm cmt to TOL @ 7843'. Made 9-5/8" csg scraper run. Circ. POH to PU test tools for dry test. Fin POH. MU test tools & RIH. Ran WSO test on 7" Inr lap--dry test. POH w/ test tOols. RIH & drld out cmt inside top of Inr. RIH & tagged cmt inside 7" Inr @ 10'452'. Drig cmt @ 0700 hrs. Drld out cmt in 7" Inr to top of landing clr @ 10,676'. Circ & POH. Ran CBL across 7" Inr--good bond. Ran gyro surv. Presently RIH w/ 5-7/8" bit & 7" csg scraper. RIH w/ bit & scraper to PBTD. Displ drlg mud w/ FIW. Spotted 50-bbl KCL pill. POH. Ran JB & gauge ring. Set prod Pkr on WL @ 9909'DIL. Began running prod tbg. Fin running prod tbg w/ GLM's hydrotesting to 4000#. Spaced out to land tbg. Stabbed thru pkr @ 9909' but could not get press test. Checked space out, seal assy not going into pkr. RU to POH w/ tbg. POH w/ tbg. Found oversized clr beneath seal assy. RIH w/ seal assy on DP--could only stab into pkr 4-1/2' but pkr tstd OK. POH. Sent seal assy to machine shop to measure OD. Found OD of seal units too large for pkr. Turn seal units dwn to correct size. RIH w/ seal assy on DP. Stung into pkr & tstd seals OK. POH LD DP. Fin LD DP. RIH w/ 3-1/2" & 4-1/2" tbg & GLM's. Landed tbg & instld BPV. ND BOPE. NU & tstd tree & prod lines. Unloaded 150 bbls FIW. Perfd 10,052'-10,062' and 10,070'-10,080' DIL w/ 8 HPF. Fin unloading FIW. B-1 perfs tstd 2-3 BPH @ 60%+--WC- Cont testing B-1 perfs--no chg. Shot 10,366'-10,378'DIL (B-4) w/ 8 HPF. Stab rate after perf--960 BFPD, 768 BOPD, 20% WC. 24-hr test: 985 BFPD, 768 BOPD, 22% WC. Released ri~ to D-3RD @ 1200 hrst 06-21-81. FINAL REPORT Eastman / A PETROLANE C, OVIPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY MARATHON OIL COMPANY COMPANY WELL NAME COOK INLET, KENAI, ALASKA LOCATI ON JOB NUMBER A681G0382 SURVEY BY David Pefferkorn TYPE OF SURVEY GYRO MULTI ALASKA DATE 6/13/81 Eastman June 15, 1981 P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-46?7 TWX 910-881-5066/Cable: EASTCO Marathon Oil Company P.O. Box 2380 Anchorage, Alaska 99510 Well Number: D-17 Location: Cook Inlet, Kenai, Alaska Type of Survey: Gyro Multi Shot Date: June 13, 1981 Method of Computation: Radius of Curvature Surveyor: D. Pefferkorn Job Number: A681G0382 Attn: Ken Toma Dear Mr. Toma: I am enclosing the original and one copy of the Gyro Multi Shot Survey run on the above mentioned well. WE wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, //. / District Surveyor Alaska District AH/kp enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide MARATHON"OIL.'COMF'ANY OOLLY VARDEN F'L. TFH, WELL NO~ D17 GMS JOB NO~ A681GOS82 KENAI, COOK INLET, ALASKA GMS, ...... O=I'O~50-MDi .... SURVEYOR~ F'EFFERKORN, DATE RUN; 13~UUN~81 SIGHTING TO GRAYLING; N17E ~ VERTICAL 5ECT-iON-CALCULATED?~N FLAKE oF ~¥~[ IRECT I ON o N 86 DEG. 54 MIN. E RECORD OF SURVEY T~N_~ENTIAL ME THOI_'I ~AtWA~HUN UiL UUI~'IP'AN¥ DOLL9 WARDEN PLTFM, WELL NO: KENAI, COOE INLET, ALASEA D17 GMS dOB NO; COMF'U]'AT ION PAGE NO, 1. A68tG0382 TIME DATE 15~05:31 15--JUN-81 ..................................... TRUE ~EASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD FEET - D M · D ........ FEEl', FEEl' FEEl' FEET R E C T A N G U L A R C L 0 S U R E DOGLEG C 0 0 R D I N A T E S DISTANCE DIRECTION SEVFRITY FEET FEET D M DG/iOOFT O, 0 0 100, .... 0-..15 200, 0 15 SO0, i 45 400, 2 0 0 O, 0,00 0,00 -106,00 0,00 0,00 ....... S ..t2--W ............ ~ .... 1-00., .............. t00,00 ............ 0,1-1 ................. 6,00 .... 0,43.--S ......... 0,09 W N 19 W 100, 200,00 -0,23 94,00 0,01S 0,23 W N 38 W 100, 299,95 -1,98 193,95 2,39 N 2,11W N-25 W ....... 100, ........ 399,89 ..... 3,28 .... 293,89 .... 5,56-N .......... 3.,59.W 500, 2 45 600, I 45 700, 1 45 800, I 45 -900, t- 0 1000 1100 1200 1300 1400 · i 30 , 5 30 , 9 15 ~ 11 15 ~ 13 15 N 67 W 100~ 499,78 -7,59 593,78 N 64.W ....... 100, ...... 599.,-73 -10,26 493,73 N 71 W 100, 699,68 -13,09 593,68 N 80 W 100, 799,64 -16,06 693,64 N"66-W .............. tO0'~ .......... 8'99'~62 ........ 17,62 793,62 N 50 W N -69 E .... N 71 E N 74 E N 72 E 7,43 N 8,00 W 8,77 N 10,75 W 9,76 N 13,64 W 10,29 N 16,64 W 11,00 N 18,24-W 12,69 N 20,24 W I6,12 N 1'1,30 W · ?1,35 N '3,90 E 26,73 N :22o66 E 33,81 N 44°45 E 1500 1600 1700 1800 1900 ~ 15 30 N 71 E 100, 1489,60 71,92 , 18 0 N 72 E 1.00, 15.84,71 101,78 + 2J. 0 N 70 E 100, 1678,07 136,07 · 2~ 30 N 71 E 100, 1769,77 174,42 °4 30 N 71E ........ lO0'i .......... 1'860~'77 '?14,30 1383,60 1478,71 1572,07 1663,77 1754,77 42,51N 69,72 E 52,06 N 99,11E 64,3?- N ~32,79 E 77,30 N 170,49 E 90,80 N 209,70 E °000 04 30 N 72 E 100, 1951,77 254,38 ??00~ '"'= 30 N 72 E t00, 213o,09 338,15 o 300 '> ~:' - =. ,, N /J E I00, m311,85 423 78 2500~ 25 45 N 75 E 100, 2401,92 466,29 ')600, ~°5 45. N ~9. E 100, 2491,99 509,32 ~ · 2700~ 25 45 N 80 E 100, 2582,06 552,45 2800, 25 45 N 85 E 100~ 2672,13 595,87 2900~ 26 30 N 87 E 100~ 2761i62 640,49 1845~77 1955,84 2026,09 2116,16 2205~85 ,:: 38,_,, 99 '-~476 · 06 2566,13 2655,62 103,62 N It6~32 N 129,62 N 141o60 N 153,0=. ~ N 164~27 N !v'' 58 N 180°12 N 183,91 N 186,25 N 249, ].4 E 290,69 E 331,63 E 373,39 E 416,11E 458,08 500,72 543,51 586.79 631,35 0,00 0 0 0,00 0,44 S 12 0 W 0,25 0,23 'S 86 30 W 0,48 3,19 N 41 27 W 1,52 6,61 N 32 51W 0,49 10,92 N 47 8 W 1"~'4 13,87 N 50 48 W t,01 16,77 N 54 24 W 0,21 19,57 N 58 16 W 0,27 21,~0 N 58 54 W 0,82 23,89 N 57 56 W 0,61 19,68 N 35 1W 6,36 21,71 N 10 21E 3,76 35,04 N 40 17 E 2°07 55,85 N 52 45 E 2,04 81,66 N 58 38 E 2.""/ 111,95 N 62 17 E '2.,52 147,54 N 64 9 E 3,07 187,20 N 65 37 E ~.'~',53_ 228,52 N 66 35 E t~'~WJ' 269,83 N 67 25 E 0,41 313,09 N 68 11 E t,32 356,06 N 68 39 E ' 0,50 399,34 N 69 14 E 0,90 443,37 N 69 48 E 0,66 486,65 N 70 16 E 0.50 529,63 N 70 59 E 1,74 572,58 N 71 40 E 0~43 614,93 N 72 36 E 2.17 658,24 N 7~ S4 E 1,16 JOLLY VARDEN F'LTFM, WELL ~ENAI, COON INLET, ALASKA D17 GMS JOB NO: A681G0382 COMPUTATION TIME DATE 15:05:31 15-JUN-81 PAGE NO. .............................................. TRUE' i~IEASURED DRIFT DRIFT COURSE VERTICAL DEPTH ANGLE DIRECTION LENGTH DEF'TH FEET ...... D .... M D ....... FEET' FEET VERTICAL SUBoEA R E C T A N G U L A R SECTION TVD C 0 0 R D I N A T E S FEET · FEEl' FEET 3000. 26 30 N 87 E 100. 2851.i2 685.11 2745,12 i 188.58 N i 675.90 .... ~100~ ...... 26"--:30---'~N':'86-E ........................ I00~ 2940~'-61 ~I'~69"'N'i' 720.42 S200. 27 0 N 88 E 100. 5029.71 S300. 26 45 N 87 E 100. 3119.01 3400. ....... 26'- 30 .... N'87 E ........ t00~- -'3208,"50' 5500. 27 0 N 86 E 100. 3297.60 ' 5600, 27 '0-' N'-86'E .... 1'00. 3386.70 5700. 27 0 N 87 E 100. 3475.81 3800. 27 15 N 86 E 100. 3564.71 3900. ...... 27 ..... 0 .... N--86---E ................. t00'. ......... 3653.81 E 775.12 2923.71 i i93.28 N } 765.79 E 820.13 30i3.01 [ 195.63 N i 8i0.74 E 864.-75 .... 3102i50 i-t97~'97-'N ! ..... 855.29 E 910,14 3191,60 I 201,14 N 900,58 955,54 3280,70 i 204~30 N .... 945,87 1000,93 3369,81 1046,72 3458,71 1092,11 35'47,-81 4000. 27 45 N 87 E 100o 37~2.51 i1~8.67'. ~6~6.,,~1 i215o48 N ..... 4-'1'0'0'7 : :" - 27':' :3~?'::-::"~':: 87 E ..... 1'-~6~'~3'i"~"~' ......... i'i~-4'l~'S-~?~ "-fT~:-~-~' N' 4200, 27 3u N 87 E 100~ 3919.71 1231,02 .'381.3'~-71 ~ 220,31 N 4300. · 27 15 N 87 E 100. 4008,61 1276~81 3902,61 ~ ooo.,.v~-~ -- N 1322.21 3991,7'1 ! 225,08 N 1367.6t 4080.81 i 227.46 N 1411,80 4170,50 ! 228,23 N ~ 24 4260,57 ~ °om 14~o. ~...75 N i499.07 4350.45 : 231.28 N 4400. - 27. 0 N-87.E 100. 4097-~71 4500. 27 0 N 87 E 100, 4186.81 4600, 26 15 N 89 E 100, 4276.50 4700, 25 45 N 88 E 100, 4366,57 4800, 26 0 N 88 E 100. 4456,45 4900. 26 0 N. 88-E ...... 100. 4546.33 !206.68 w 991.21 209.87 N 1036.88 213,04 N 1082.17 1128.67 -1174,78 1220.89 1266.62 1311.95 1357.29 1401.51 1444,93 i1488,74 232.81 N- i1532.55 234,36 N 1577.14 1542.90 4440-.33- 1.,~7 51 4529 82 5000. 26 30 N 88 E 100. 4635.82 CLOSURE DISTANCE FEEl' I 7 01.72 - i 745.48 789,80 834,00 877,91 OOGLEG DI~<ECTION SEVERITY D M DG/1OOF'T 922 ~ 967 11.012 .1057 ii102 .77 .68 .53 .91 .94 N 74 25 E N 75 6 E N 75 50 E N 76 26 E N 76 58 E 1149 1194 1240 1286 ].331 .05 .82 .61 .05 .12 .. N 77 25 E N 77 49 E N 78 13 E N 78 33 E N 78 52 E 1576 1419 i1463 ~1506 !1550 1594 .97 .08 .60 .13 .46 N 79 12 E N 79 30 E N 79 46 E N 80~ ~ E N 80 16 E 5100, 5200. 5300. 5400. 5500. 5600. 57'00. 5900. 26- 0 N 88- E - t00. 4725,70 24 45 N 88 E 100. 4816.52 23 45 N 86 E 100. 4908~05 25 0- N.87 E 100. 5000.10 23 0 N 86 E 100. 5092.15 23 30 N..86- E 100, 5183,85 3 15 N 87 E 100. ':'~'-"~"= '"~ .,.,~ ..~. .c.~ 45 N 87 E 100. 5367',26 23.45. .N 86 E 100, -5;458,79 t65!,54 4619,70 1673.°0= 4710,5?_ 1713,47 4802,05 1752,54 4894,10 1791,61 4986.15 1831,48 5077.85 1870,9~'~, 5169 ,73 1911."~3.- ,..,_~'761,26 195;1.50 5352.79 ! 235.89 N i1620.96 i °37.35.. N 1662.80 240.16 N ~:4° "~ 1 N 244.95 N ~:47.71 N 249, -'q 1702.97 1741,99 1780.97 1820.75 1860.17 i ~ ~:- ~1.89 N 1900.59 ~4,70 N i1940,56 1638 1679 1719 1758 .03 .65 .82 .75 N 80 29 E N 80 45 E N 80 58 E N 81 10 E N 81 22 E N 81 33 E N 81 43 E N 81 53 E N 81 58 E N 82 5 E 1797.73 N 82 10 E 1837.52 N 82 15 E 1876.86 N 82 21 E 1917.01 N 82 27 E 1957.21 N 82 51E 0.00 0.45 1.03 0.52 0.25 O.vO 0.45 0.52 0.25 0.88 0.25 0.00 0.25 0.°5, 0,00 1.17 0.66 0.'~5 0~ 0.50 0.50 ' 1.25 1.29 0.85 0.39 0.50 0.47 0.50 0.40 "i,:~h:AiHON OiL_ COHF'ANY OLLY VARDEN PLTFM, WELl_. NO; 017 GMS ~ENAI, COOK INLET, ALASKA JOB NO; A681GOS82 COMF'UTATION TIME 'DATE 15:05~1 15-JUN-81 F'AGE NO. 3 TRUE ~ ~'ilEASUREO DRIFT [~RIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E f';OGLEG DEF'TH ANGLE DIRECTION LENGTH DEF'TH SECTION TVD C 0 0 R D t N A T E S DISTANCE DIRECTION SEVERITY FEEl' - D D .... FEET ....... FEEl' .... FEET FEET ........... FEET FEET - D M DG/iOOFT 6200. 2S 0 N 89 E 100. 5734.08 2070.68 5628.08 I 260.97 N 2059,59 E 6~00, 22 15 N 88 E 100, 5826.64 2108.54 5720.64 . ~6~. N 2097.4~ E 6400. '21-.S0-- S~81E ....... 100. .......... 5919..,68 2144.58 581S,68 6500. 21 SO S 82 E 100. 6012.72 2180.S4 5906.72 6600. 21-15 S- 82 E ............ 100. ........... 61-05~.92 .... 22i5,-91 ...... 5999.92. 6700. 20 45 S 82 E 100. 6199o4~ 2250.67 609~.4~ 6800. 20 15 S 8~ E 100. 629S.25 2284.75 6187.25 ....... 6-900~ ......... 20 .....0 ..... S79E .............. 100r ........ 658-7.~-~2 ........ 2S~7~-92 ...... 6-28t,~22 7000. 19 SO S 80 E 7200,, i8 i5 S 78 E 7300, 18 0 S 78 E 7400, 17 50 S. 76 E 7500, 17 15 S 76 E 7600, 17 1='., S ?~.~ E 7700, 16 15 S 75 E 7800. 16 0 S 71 E 7900+' 15 SO S 71 E 100+ ..... F'S40~84 ...... 2604~46 72S4.8'4' 256.56.N ...... 2133,.63 E 251.46 N 2169.92 E 2184.44 N 83 23 E -246.41N .2205.81 E i2219053 N 83 ~8 E · 241.48 N 2240.89 E !o~.~_.87 N 83 51 E 237.27 N ~--~.o~S 25 E i~m7.59~.~ N 84 ~ E 2~0074~N. 2~08.82 E i~o~.0 ~2 N 84 18 E ..... · :"~.' ,...3.0,42::~.637o,49 ..~.4,94 N ..341,7Q E 100 i; ~:?,,~670 . 87 ....... '~2412;"Z8' 6564,87 i 212.71 N 2404.,80 E 100+ ::6755+34 ::::1~01 N 2464~20 E 100+ 6~56~84 24~.Y0 6850~84 : l~i+SS N ~'-~4~?~.~7 E 100~ 7052+.S5 ~'~":~ 89 6~46~$5 : 184+16 N 2521~62 E 100. 7148.S5 2554,16 7042.S5 175~98 N 2548,~8 E 100, 7244,48 2579,70 71S8.48 167.00 N 2574,44 E i~;R S0 N 2599 71 E 8000, 15 1=~ S 6o. E 100, 7437,32 2628,47 7331,32 8100. 14 45 S 6~ ~ ....... ~'60. -7524,02 2651.-71 7428.02 ~. ~ /o~4,69 8200. 15 0 S ~5 g 100. 76~0.62 o677.~4 ~=o ~ 1997,41 N 82 36 E 0,00 203~::~:~Y--~ N 82 40 E 0,25 2076,05 N 82 47 g 1.29 211S.76 N 82 52 E 0.84 .2149,00 N 83 9 E., 4,16 0.25 0.50 0,61 2352.47 N 84 31 E 2384.26 N 84 43 E 2414.18 N 84 57 E 2443.74 N 85 9 E 2472.22 N 85 2S E i48.88 N -76°4,~ .=o/ E 139.75 N 2648,03 E 157..,0 N 267S,82 E 1,40 8300, 14 15 S 64 E -8400, 15 0 S 73 E o..00. 1~ SO S_ 82._ E 8600. 16 30 N o~ 8700. 17 0 N 82 E 8800~ i7 45 N 70 E: 8900, ' 18 15 N 68 E ~4 698,85 7621,54 100, 7727,5 2 100,- 7824.t32723,15 7718,1S 100, 7920,50 2749,38 7814,50 100. 8016,38 -2777,77 7910,S8 100. 811~01~ 2806,90 8006,01 100, 8207,25 28~6,07 8101.25 100, ' 83020~°~- 2865.70 8196,°°~ 0,60 0,25 1,19 0,25 0,79 O,SO I · 1.~:,.., 0,61 2500.34 N 85 36 E o~ 33 N 85 49 E ~o~.45 N 86 S E 2579.85 N 86 17 E 2604.52 N 86 S1 E ~o.8.48 N 86 45 E 0*5© 2651.72 N 86 59 E 0.50 2677.35 N 87 3 E "4.10 2,42 3.45 1,26 3,65 0,79 126,71N 2695,94 E 2698.92 N 87 19 E ~7~.30 N 87 SO E: 119,14 N ~.~,°7°~ 69 E o o- 115.42 N 2747.15 g 2749.58 N 87 ~6 E 117,40 N ~7/~. 49 E i2777,97 N 87 S5 E 121,47 N 2804,44 E i2807,07 N 87 31E 131,90 N 2833.09 E i2836,16 N 87 20 E 143.63 N 2862.12 E i2865.72 N 87 8 E i ~ARAfhUN OiL. COMPANY i~OLLY VARf. IEN'PLTFM, WELL NO~ D17 GMS :ENAI, COOK INLET, ALASKA COMPUTATION .JOB NO~ A681GOJ82 TIME DATE 15~05:31 15-JUN-81 PAGE NO. 4. ~:EASUREI) DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C l_ 0 S U R E DOGLEG DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE r_ilt~<ECTION SEVERITY FEET ......... D -M .... f_t .... FEET FEET ...... FEET'- ....... FEET FEET .............. FEET D' M [~G/iOOF'T 9000. 21 30 N ~Z_~ ................ ~q: ....... ~.*~ ......... ~~_~ ........ ~?.t_~A ..... 157.95 N 2895.86 E i 2900,16 N 86 53 E 3,27 ..... 9'100; ....... 21 .... 30 ...... N'"67 "E ............. I ................ ~ ........ ~ ~ ............ o ....... . - - 00, 848~,~0 ~9~4,63 838~,30 172~'27-'N--"i-2929,-~0 E I 2934 66 N 86 38 E 0,00 9200, 21 45 N 67 E 100, 8581,18 2969,47 8475,18 186,75 N 2963,71E ! 2969,58 N 86 24 E 0,25 9300. -~ 30 N 68 E 100, 8673.57 3005,67 8567,57 201.08 N 2999.19 E i S005,92 N 86 10 E 0,84 ..... 9'400~ ....... 22--'-30 N"-66- E - 100-~ ..... 8765,-96 5041-v42 ...... 8659-~96 ..... 216~65---N ..... S034~-'1'5 E-!-3041,87 N 85 55 E . 0.77 9500.__~ 0 N 67 E 100. 8858.68 3076,65 8752,.68 ~ ~31.~9~ .. N' 5068,63 E 5077,~3 N 85 41 E ...... 9600, ..... 21 .... 0 ..... N--67 E 100.- 8952,'0'4 31i0~35 '8846-~-04 i 245,29 N'-i 3101,62 E 3111,30 N 85 29 E 9700. ~1. 0 N 73 E 100, 9045,39 S145.13 8939,39 ~5.77°~ N 9800. 20 45 N 70 E 100. 9138.91 S179.03 9032,91 267.88 N ..... 9900~ .......... 21 ....... 0 ..... N'-71 ....E .................... o...~..--.~ - 100, 9,.3~,,.? ........~2t3~'50 .... 9126~"27 079,55 N . 00. ~0 4¢ N 71 E 100. 93~.78 ....~:~7,-~/ · 9~19.,78 291.08 N '10100. .... 20 S0 N 70' E ' 100, 9419.4o-. ~281o-08-: -9315~;'45 ~'-~';~-'~ .... 10~00. ~0 4~ N 73 E _00, '9o1~.96 331¢.47.-:~406,96 315.42 N ].0300. 20 SO N 76 E 100.' :):9606.63 3549:.86'?:~9500:,.65 ~21.,89 N --1-0400,- -'20 4~~ N- 76 E 100,' '97'0-~'14:?::'-3384~:65: :959~1~ 330°46 N 10500. ~ ~0 45 N 75 E 10600, 20 45 N 73 E t0650. 20 SO N 72 E 100. 9793.65 S419.32 9687.65 100. 9887.17 3453,71 9781.17 50. 9934.00 3470,63 9828.00 FINAL CLOSURE - DIRECTION~ N 84 [lEGS 8 MINS E DISTANCE~ 3.474,69 FEET S135.89 E 3146030 N 85 20 E S169,18 E 3180,48 N 85 10 E 3203-.07 E 3215.24 N-85 i E 5236,57 E S249.63 N 84 52 E 3269,47 E S283,49 N 84 42 E 3303,36 E 3318.19 N 84 35 E S3~7,34 E S352.82 N 84 29 E 3371071 E 3387.-87 N 84 24 E 339.63 N 3405.93 E i S422,83 N 84 18 E 349 99 N 3439 8'~ E~ 3457.~:' .... ,7 N 84 11 E 355.40 N 3456.47 E : 3474.69 N 84 S E: '~ 15 0,44 0.43 1.09 1.09 0.25 0.35 0.71 0.86 Check Form for timely cc~apli~ce witt~ our r-c~}ulations. Operator, Well hame and Numbe . Completion Report Wel 1 History Sanl}les Mud Log, Core Chips Core Description Reports and Materials to he received by: R~]uired J Date Received Yes Yes i_,y// Remarks 0 Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Logs Run Yes Digitized Log Eata DX' .... STATE OF ALASKA ~' ALASKA(,~,L AND GAS CONSERVATION C ,~IMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~( Redri 1 1 Workover operation [] Name of operator 7. Permit No. Union Oil Company of California* 81-23 3. Address 8. APl Number P. '0. Box 6247, Anchorage AK 99502 so- 733-20168-01 4. Location of Well at surface Dolly Varden Platform, Leg A-2, Cond //2 .759.4'FSL, l127.4'FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106.2' KB HSLI A-~)26 ADL-1872~ 9. Unit or Lease Name Trading Bay Unit 10. Well No. D-17RD 11. Field and Pool McArthur IRiver Field For the Month of MAY ,19 81 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks DEPTH AT END OF HONTH: 9342'MD FOOTAGE DRILLED: 1191' REDRILL.OPERATIONS BEGAN: 05-07-81 REMARKS: Pulled & LD 4'1/2" prod tbg. Spotted cmt across Hemlock perfs 10,094'-580' w/ TOC @ 9990'. Perm BP @ 9706'. Milled section in 9-5/8'l csg from 8145'- 8205'. Spotted cmt plug across section 8242'-7955'. Directiona]ly drld 8,1/2" hole from KOP @~.~151' to 9342I. 13. Casing or liner run and quantities of cement, results of pressure tests NA 14. Coring resume and brief description NA i 15. Logs run and depth where run CBL/VDL/CCL/GR from 8400'-8000' and 2800' Gyro survey from surf to 10,665'WL PBTD. to surf. .1 6. DST data, perforating data, shows of H2S, miscellaneous data NA 17. I here~fy that the foregoing is true and correct to the best of my knowledge. (J Form 10-404 Submit in duplicate ;',-M~.~-I~n (3; 1 ('nrnn~n~/ - ~;I,h-(3nP rRtnr Thru: ALASKA OIL AND GAS CONSERVATION COMMISSION Hoy le H. Hami lton/fJ~ chairman Lonnie C. Smith ~ Commissioner Doug Amos ~ Petroleum Inspector May 14, 1981 Witness B.O.P.E. Test on Marathon ' s Dolly Varden Platform Well D-17RD Sec. 6, T 8N, R13W, SM Permit %81-23 on Parker Rig No. 77. Monday May 11, 1981~ I traveled this date to the Dolly Varden plat~f~'~ to witness the B.O.P.E. test on well D-17RD. The B.O.P.E. test commenced at 4~30 p.m. and was concluded at 3~30 p.m. on 5-12-81. There were four failures all of which were corrected and restested during the course of this test. I filled out an A.O.G.C.C.B.O.P.E. test report which is attached. In s~mary, I witnessed the B.O.P.E. test on the Dolly Varden Platform. There were four failures all of which were corrected and retested during this test. I filled out an A.O.G.C.C. B.O.P.E. test report which is attached. ~&G #4 4/81 "~ STATE OF ALASKA ALASKA OIL & CAS O0NSERVATION C(/~MJ~SION B .0. P.E. Inspection Report well fl)- / 7,~ Z:) Operator /~/~/~ T/~O/J ~PJ& ~, Representative. /~ Well ~ -/7/~/~ Permit # 8/' 1/ Location: Sec ~ T~A/R/3WM ~,/~ ~ Casing Set @ ~Z3~ ft. Drilling Contractor. ~~/~ Rig # 77 Representative Location, General_ ~' Wel 1 Sign C~neral Housekeeping ~_~ ~eserve pit Rig. BOPE Stack Annular Preventer Blind Rams __/_ Choke Line Valves... H.C.R. Valve.. Kill Line Valves~ Check Valve Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure ~~ psig Pressure After Closure /~5~ psig Pump incr. clos. pres. 200 psig. Full Charge Pressure Attained: N2 ~/J~ ,4t&P ,.~¢.,4r~-= psig Controls: Master Remote ~/~f Blinds switch cover ~ ~ sec. min 2~ sec. Kelly and Floor Safety Valves- Upper Kelly. ~'~/~ Test Pressure ~r Kei ly ;'~/= Test Pres sure Ball Type__ / Test Pressure Ins ide BOP / Test Pres sure Choke Manifold / Test Pressure No. Valves__ / ~ /! No. flanges. ~djustable Chokes. / Hydrauical ly operated choke / Test Results: Failures_ ~ Test Tim~' g~ ~ hrs O0 Repair or Replacement of failed 'equipment to be made within, days and Inspector/Ccmmission office notified. Distribution orig. - AO&CCC " cc - OperatOr . cc - Supervisor Inspector February 24, 1981 Mr. R. T. Anderson Distract Land Manager Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Trading Bay Unit D-17RD Union Oil Company of California Permit No. 81-23 Sur. Loc.~ 759.4'FSL, 1127.4'FWL, Sec 6, TSN, R13W, SM. BottomhOle Loc.~ 963'FSL, 368'FEL, Sec 6, TSN, R13W, SM. Dear Mr. Anderson~ Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information sbmll be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter survey s. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Wa~er Pollution Control Act, as amended. Prior to Mr. R. T. Anderson Trading Bay Unit D-17RD -2- February 24, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation.. Pursuant to AS 38.4D, Local Hire 'Under State Leases, the Alaska Department of.Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded, we would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please gave this office adequate advance-notification so that we may have a 'witness present. Very truly yours, H. ~ami Iron Alaska Oil & Gas Conse~eation Commission Enclosure cc~. Department of Fish. & Game, Habitat Section w/o encl. Department of Enviro. nmental Conservation w/o/eno1. Depa.rtment of Labort Supervisor, Labor Law Compliance .Division w/o eno1. ALASKA OIL AND OAS CONSERVATION COMMISSION J,4Y $. HA¥¥OND, 300I PORCUPINE DRIVE-ANCHORAGE, ALASKA 99501 February 19, 1981 ADMINISTRATIVE APPROVAL NO. 80.38 Re: Application of Union Oil Company of California, operator of the Trading Bay Unit, to redrill, complete and produce the Tr ' a ' ~ well as a part of the pressure main- tenance project approved by Conservation Order No. 80. Mr. Richard J. Boyle La ndma n Union Oil Company of California P. O. Box 6247 Anchorage, Alaska 99502 Dear Mr. Boyle: The referenced application was received on February 18, 1981 and stated that the drilling, completion and production of the Trading Bay Unit D-17RD well will provide a crestal final with- drawal point in ~the Hemlock Pool. The Alaska Oil and Gas Conservation Commission hereby authorizes the drilling, completion and production of the referenced well pursuant to Rule 5 of Conservation Order No. 80. Yours very truly, Harry W. Kugler/ Commissioner BY THE ORDER OF THE COMMISSION Union Oil and Ga~'"'-~ivison: Western Region Union Oil Compar~'Y' of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unll, n L /- Robert T. Anderson District Land Manager · February 16, 1981 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 TRADING BAY UNIT State of'Alaska McArthur River Field Application to Complete Trading Bay Unit D-17 Rd. Gent lemen: Union Oil Company of California, as operator of the Trading Bay Unit, hereby requests approval to complete and produce the subject well to be completed in .the Hemlock Formation at a crestal final withdrawal point, pursUant to Rule 5 of Conservation Order No. 80. The subject well will be drilled from the D-17 location on the Dolly Varden Platform by Marathon Oil Company, suboperator. Very truly yours, Richard J. Boyle Landman sk Union Oil and Gas~ivison: Western,Region Union Oil Compare) of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager · ebruary 16, 1981 Mr. Hoyle Hamilton State of Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: TRADING BAY UNIT. State of Alaska Permit to Drill TBUS D-17 Rd., Dolly Varden Platform, McArthur River Field. State Lease No. ADL-18729 (8-86-71-5575-601351) Enclosed for your further handling are three (3) copies of the above captioned Permit to Drill. Also enclosed isour check #19097 in the amount of $100.00 to cover the filing fees. Very truly~yours, Richard J. Boyle Landman 'sk Enclosures (4) STATE OF ALASKA (~.., M ALASKA ~L AND GAS CONSERVATION C ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL ~ DEVELOPMENT OILS SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Union 0il Company of California* 3. Address Post Office Box 6247, Anchorage AK 99502 4. Location of well at surface 9. Unit or lease name 759.4'FSL, 1127.4'FWL, Sec 6-8N-13W-SM, Leg A-2, Cond 2 Trading Bay Unit · At top of proposed producing interval 10. Well number 950'FSL, 600'FEL, Sec 6-SN-13W-SM D-17RD At total depth 11. Field and pool 963'FSL, 368'FEL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. McArthu r Ri ve r Fie Id 106 ' KB M'S L ADL- 18729 A-926 12. Bond information (see ~0 AAC 25.025) Type Blanket Drlg Bond Surety and/or number B-2-165-724-1 Amount $200,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 21 mi . NW of Kenai miles 4300 feet well 925 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 10766 ' MD; 10080 ' TVDfeet 3085 Oj~_mJ.5~81 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures f ~,~%~ psig@ -- Surface KICK OFF POINT 8234 feet. MAXIMUM HOLE ANGLE 1 8 o (see 20 AAC'25.035 (c) (2) ~ 49?7 ) Psig@ 10080 ft. T.D (TVD) Proposed Casing, Liner and Cementing Program~-~ ~Ir~' SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT' Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 8-1/2" 7,, 29# N-80 Butt 1400' I I 8-1/2" 7" 32// N-80 Butt 1350' 8034' I 17478' 10766'110080" Appro× 750 ~ I ~ I I I I ~ I I 22. Describe proposed program: Plug existing wellbore and sidetrack at 8234' in 9-5/8" casing. Drill 8-1/2" hole to projected TD at 10,766'MD; IO,080'TVD. Run and cement 7" liner (top at 8000'). Run gas lift assembly and complete as Hemlock producer. FEB 1 8 1981 Alaska 0il & ~G~:, Cons. *Marathon Oil Company - S~b-Operator . 23. I hereb_¥..~e_rtify that the foregoing is true and correct to the best of my knowledge · -,u~u~cl~ SIGNED ':q,~ TLE Dist. Land Mgr. DATE 2/16/81 Thespace below for Commission use Richard ~. Boyle for R. T. Anderson CONDITIONS OF APPROVAL Samples required Mud Icg required Directional Survey required APl number []YES ,~O [~YES J~O ,~-,Y E S []NO ~' ~ ~._ ~/~ Permit number Approval date ~/"~'~ 02/2~/81 I SEE COVER LETTER FOR OTHER REQUIREMEINTs APPROVED BY_ ,COMMISSIONER DATE ~1~,,,., .... o~ 1 ~o~ .. by order of the Commission "'"'"~'"'"~'~ "-=~ '~"/~"'" ' 10-401 Submit in triplicate Form Rev. 7-1-80 ~'-' ' ' ' ' .... ' ' ' *' ' ' J j' ''' : ' ~i~ -,.~...:.* ,~.¥-,= ..... ..,-..,.; .,.. .... ,..,, - .... J ,-. , .. DOLLY V~ RDEN PLAT,FORM ': '- ' ~- ...... · 'Jl'sJlll ' i Iii" ; '~ I :. .... __.,_,._ ~' ' ' : .', i-; i '~'l '~' 'J" i I f ' ,'. I . · - ~ , , · :: ........ ...- .. ..-:: .. : J., ..... , WELL. NOD-I?RD -., .... .-: ................ . , ~ ' . .. ; , ] , . t ~ . I ~ ' , - '' :" ' ' ,-'F""'~';" , ,-;-,-,- -:-,-~- ..; , . - ........ ,wvv 1'''~ ; '1" ..... . ...... , .... : · :..I ...' j , , ,-~ jJ i .... I .... · ;] I - ; I ' I : ! L J , ' , , ' . ] , I NOVEMBER m,~O .' ': j I .- - ' ' ,--,-'--,.- , ..... , ,, , . ,,. I .~ , ... ..... _ ...... ..... .... .:, ........ . .:.....,....: ,.. ,. , ..... . .... .......... -'..: :-- · ,, ' :!i,_i !!;i.Ji. '" .'' : , :'' ; ' ' . - : , ' I"- ~ J '-' : ~1 ' , I ' 'FOR ; . : ' J . ' ~ ' · ' ; ' - .... --:: ' '."i.'. !:o;' ""' :' ! ]'[u~'~'~'":~' !' '~-:i;I'~IB'ODE~Ag-X~DIRECTIOJ~ALI'DRIL:LI~G''':' : :. ~: ~.~ ~... .- , : ..: , '~ ' , :. i .'. t i I : : .i .i '_i.1 .J ~. ~~~ ~ .'__..~?,..~_ - .... ' , ' ' " . : · ' * / .... : ·; i . . .,~- _ ..-_! '.-:=.:~]..- ..... · - ~.L-:..?:~.':::.T..,-:~:.-.-..; · .: ....... r'~ ;' - ' · '-:- '¥[:~:~-:-":'.:~-:-': ~.-~'--..-T. ~:--.- -:-;-~,.: .- -:---.: 'i" · .-'.. '-:-'- :i.':_.,..-.? Ci?.??:: · ' ..... "~ .-' .."::"::.. '.:::':.'-i"". :'..::"!!:': i; .- .- '. . . . ; .-' . . ' -Z.",' ' ~-. Z >'. .',. .; _! -~ . ....... 4,000- · :;: :,.:.;.~..-~ -:..¥,~..,'-... ," ............... · . · ....... . .. ' !.I. ' ~*" '"~' :-~"~>': ...... ° ...... ~'~ ~ i'~~' 'i"' -:" ' .'?. .... .'.:~ .. :. ..' !..I. ..... - · -' . .. '-."'i · . . ':.- ii.!',', --.-?, .". · ;.,-'.~-:-. '.'.'i.?.:" "-' :'' ~ i .- .. -:. ,.....:.,.. ::-. .,..'. -. - ---..-....,- . :- .. . · "i. ' .... :-. -'..' ..... '..: ': ':::4'.~,,..,. · :: ,. "'- ~ - !.: ...- ....... · .-...-,,.,. ,,,L,..~ - .... ~- .-~--~-,'.' , ~ ,.-."- ~._~.,~ ,- ~, - '- -; ":' !"i ... I - ·. ..... :._ .,.. , ..... .. ,.., .. ,,. -,.,-_,,~.,.-,-.... 6 ;-,1';, i' 'i TVD = 7678' '. Ti/ID = 8234 :.i .; DEP '-2658 ~.1 ; '$..~ I. 'EOC~ !.'.J !..;. TVD ;' 7848 , .-TMD--- DEP = 2709 ,' ,ooo,,~ i.; ' i':'~ ";,'t~',':i' ~': '; ~ ~ .. , y. ; :" ~EANGL~"IS°Sar",~""i',:..ii.,i" --4.- .l_-..' :_;.: -.;- ":":"~:C'~'-'~:'-~'~::~:~:'''?~'''T~'~''::::~:'~:-~:~:~- 90~)0 ~ ':: ~ ..... ~ ': ........ ~',. '-, ...... " ' - ' '--'""";':' :': '" ' "-: · ~ ' ~'l I ~ ~' NEW HOLE 2554 ET, · '. ~ TOP HEM~CK ( . .... ' ' ' · : · ~ ' . '. I . ' . TVD =~90 : ' ', ' ' : - ' :'.'~: ',~,. ', · ; : : .t' ~ ', : ; I '"~ ' I~OOTMD ' ~ -I~0~8 : " .. ' -.-... '--, ' -''~ ·' ', ~ ' :, ' .'.,. . . · ,.,,,~-,v ·" .' ....: .-- '..-...- . :.: _*':."': : . -i ~ J'' , "~ :' ; J ' ~ ~ , ' ~ ' ; : J ' ~ · DEP =;3227 I;. · ' -' '.-~.. "- * ' ; I 'rI ~'~ ' ' ' I ~ ~ ' * I , · ~ · . .... · ?.'-' '...:' ' ."' :' "~ '. " .'1:" ' ; ~'.' ~ ~ '~ ~' I," '~ ' · ' ' * ' - '.' "' : ' ' ' ' ' '' · I ' ~ ".' : , I ,. [ : I , ; , ; ' J'~' · ... ' ~-'" :' '-' '* --.''.'-.'.," ""t . ' - :.{; * · '~ : ' I':-~'j '~ :':'J · ~ '. ~1 '.'~ . '" ' '" - . - "' I0~'. l ..... :.-.:._~.L --~-~.= ~-: ..... ~-~!.~.~:-': .... J-4 ~ -~ --.:.-TVD =i0080:-.-;-. . · · · I , ~ .... ; · ~ J , . . TMD=10766 ~ . · ' " ~ ' · : t ' ' ' ' : ,-. : : ' : ~ ~ ': ; [ t" : "' DEP = ~459, ~ ' . . . j::~` :',:~ :,=.,,: .:: , :.;j.:,"-~'~ .t~.. .':: ~ ' I : ,: ~, :":.:.~ ; ..'*: ,~ J~ ' ';~ '1 ~' : · ; _ .' ... '* 'J_ ...... '--. * . '. ' t ' ' ' .' : ~ ; j .... : ' .., . ~ .', : .. . j , . f;', ; ~ ~ ~· , ,] , . ~,. .................... ..... ": ....... =' . 'l' : , ~ : . t :" .I' ~' ~ .~ .z .......... i ~ I I ' I , ' ~ :', ~ ; ' I ~ , : i : i t t · . j , , . ~' ~':':?:"~:"~:~?~::~::.3:?.:~ . ~ '~1'.~ ~'.~',J: ~'..: ~,~'.t ".. i~ ' , · ~. ""e -.-:....,: :- · ...:._'"~ .::.." ·-.'.: .-. c~. · --- ~ ....... ; :....':.- ..:'.:. · .:. . · : ..; ': v.'' .. "· ' .' '.-' . .. ."% .. · .. ,. . i5rd D'20 "_,'~O-3~ ~., D-41 D-2A ,D-2~A D-14 1~-25 ~rd .s~,,: D-14rd 2000' MARATHON I I 4000' 6000' 8 OIL COMPANY ~,t:CHOR AGE OIVISION TRADING BAY UNIT McARTHUR RIVER FIELD TOP HE MLOCK BENCH- I CCNTO;JR INT£RVAL ~ ICO i ARATHO · O [L GO.- - DOLLY VARDEIq PLATFORM-- L U Mull Por, ..,, - Driilins Nipple- Prcvc,~f cr - (~yar~t). -. ' ' '''(~'P~' ~~)' ' w~aw~.°~~= .. '.· ' (51i~a R~).. .. '." ,.'. 5,000~-~ill Lih~,. x. -: ~- '.._~.~O~o~a k~e-~; p~illin~~From ghd~r 1~16'l ',e ~:-.,., ,., '' ' ~.. Surface O~sin~ To T.D.--.'. ' .--.---- . ":.-~'~C':" ?.";:',... '. ..... . _ A~:~I;~ 0;'.~ '-" . -' ,-v .... · , . I _- ..... N 2 Ff. ooi . . . '~: ":~ ? ~ ~ ~ :- r-. .. :'. ...... ~"i "' "~:'" -o o [ ' " ,... ~ · · . ~ ., .~. . · ,. ~Eg'Z ~ ]~] _ · I ' ~sNa Oil & Gao Cons. Commiss~tm .... ~ ol I O ~ ... [ 2W*II ~co~ FI~r~~ ...........~'2 .... ~.' ......... 20" "- - ' o~ U or CHECK LIST FOR N~4 WELL PERMITS T tern (I) Fee %-/F"~/ 1. Is the permit fee attached .......................................... / : 2. Is well to be located in a defined pool 3. Is a registered survey plat attached ................................. 4. Is well located proper distance frcm property line .................. / 5. Is roll located proper distance frcm other wells .................... '~__ / 6. Is sufficient undedicated acreage available in this pool ............ ~. 7.. Is well to be deviated .............................................. Lease & Remarks (3) m:tn~i_n. ~~. 8. Is operator the only affected party ................................. 9. Can permit be approved before ten-day wait .......................... ? 10. DOes operator have a Ir>nd in force .................................. /~_ 11. Is a conservation order needed ...................................... 12. Is administrative approval needed .................................... 13. Is conductor string provided ..................... ................... ~_ 14. Is enough cement used to circulate on conductor and surface ......... (4) Ca_~~ ( 5 ) BOPE ~/~/ 15. Will cement tie in surface and intermediate or production strings ...~F · / - ' ~.6. Wil 1 c~t cover all known productive horizons ..................... ~ 17. Will surface casing protect fresh water zones ....................... <~~ 18. Will all casing give 'adequate safety in collapse, tension and burst. ... 19. Does BOPE have sufficient pressure rating-Test ~~~~g .~ : Approval Reccmmended: ' ~o, · I , Geoloqy: ina~er lng: rev: 03/05/80 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPE .NDIXi ,. No special'effort has been made to Chronologically organize this category of information. LIBRARY TAPE CURVE SPECIFICATIONS Company MARATHON OIL COMPANY Well TBU D-17 RD (CORRECTED) Field McARTHUR RIVER County, State KENAI, ALASKA Date 6-8-81 Curve Name (Abbrev.) Standard Curve Name Logs Used Scale RFOC Resistivity Focused DIFL .2 - 2000 RILM " Medium " " , , RILD " Deep " " SP Spontaneous Potential " 0 - 150 ,,, GR1 Gamma Ray 1 " 20-170, 170-320 AC Acoustic BHC/AL 150- 50 GR2 Gamma Ray 2 " 20-120, 120-220 CALl Caliper 1 ,, 6 - 16 GR Gamma Ray CDL- CD/CN 20-120, 120-220 CAL Caliper " " 6 - 16 , , , DEN Density CDL 2- 3 CORR Correction " -. 5 - . 5 , CN Compensated Neutron CD/CN 60 - 0 DENP Density Porosity " " CFOC Conductivity Focused DIFL 0 - 1000 CILM " Medium " " CILD " Deep " " , , EcC HUi~ir]E R 100~+. O0 ~AF~ATt~ON OIL COHPA~,JY TBu 'D'17 RD 17 CURV£8 : CFdC CILN CILD RFOC RILN RILD GR Sp AC GR2 CaL CORR DEN GR1 tALl CN ='ROM 8'i00,'00 .... _E\tEL SPACING O,bO00 ~'2, SANP'LES PER RECORD J'qN o l PAGE I ~R^Tt-I'ON OIL COMPANY BU 0-17 RD IS RU~.t WiTH DIFL,GR2 IS DFPTH GR1 RFOC RILM RILD FT. API RtJN WITH RHC/AL. SP Ar GR2 CALl GR MV AP1 IN APT DEN CORR G/C CN OE~IP CAL % % IN alO0, 20, 0.0 0,0 0.0 O. ~IlO. 20. 0.0 0.0 0.0 O. ~120. 20; 0,0 .... 0.0 0.0 O, 8150, Gl. 0.4000.0 ~.4 ~1'~0, 66; 0',5000.0 6.~ 57, &150, 85' 6,6 2.1 1.8 70, 8i'60", i26'"' 6,5 g,"l 6.9 67. Al'70. ~05, 7,2 ......?;2 7.8 7~. O.n O. O. O. 0.o O. O. O. 0.~ O. O. O. 62.~ 32. 8. 41. 62.? $2. 8. 91.0 ~5. 9. 57. 82.~ 58. 11. 94.~ 74. 10. 83. 77. 10. 62. !0. 7~. 9, 6~. 11. 99. 109. 9'2. 7,'1 ~;'"9 ....5.~ 77. 85.~ A1'2'10""; 1i'2'; ....... B.6 ~,3 ~.5 72.12]..a 0.0 0.0 0.0 0.0 1.9 2.~ 1.9 1.~ 1.7 1.7 1.7 1.8 2.0 1.7 2.~ 2.~ 2.5 2.1 1.9 I ' 8 1.5 0.0 O. O.O O. 0.0 O. 0.0 ~2. -0.5 28. 0.2 2~. 0.2 3~. 0.1 ~2. 0.1 3.1. 0.1 ~1. 0.1 42. 0.1 2~. 0.0 29. 0.0 51. 0.1 28. 0.0 30. 0.2 ~0. 0.2 29. O.1 41. 0,0 ~8. 0.2 ~5. 0,0 56. ~I. 35. ~2. 29. 2.2 -0.1 25. 1.7 -0.5 24. 2.4 0.1 21. 0160 G 0. 0160 6 O, 0160 6 O, 0160 6 · ~ 47 9 -9, 1. 19 8 11. 7 43: o 7 62'.9 9. 2 57; q 9. 9 59: ~, · 0 57.1 g. · % 52.9 9. 0 40.1 9, . 5 17:a 1.0. 5 18.7 I 1. 1. 18.9 1 · 4 32.5 12. 3 43 0 · ~ 56.3 1~. 9 48 ~ 12. . 9 66.8 I 3. 0 23.0 1 , 0 18 ..1. 10. ., g 18 6 9. 8 24 1 · 9 27.5 1 5~-9 · ~ .9 ........ 7'3~ 77.~ 44. 9. 59. 2.~ 0.0 17.8 15-0 g. ......... 9; ~i. 2'4 o.i 2o',s'1~':0 ~ ~. ";'"'2""'"~"~,7 6,8 7~, 8A,k ~6. 9. 68. 2.4 0.1 23.6 15.~ 9. .......................................... 9.7: 7.I ~'9: 7~. ~7.A: 54. 9. 62. 2.~ 0.i 20.~ 13~4 g. .............. ........ :,,8: ........ ............. .............. o. 81.q 93. 10. 82. 2.5 0.1 22. 3. 2.~ 0.0 . 8'.6 7.0 5;'5 74.'8'~ g'2. 9. 61. 2.4 0.0 21. ...... :'B':";:6-1': ........ :7':;" 9' 55. 2.4 0.021. 2 9. .~ 54. 9. ~4. 2.~ 0.0 22. ............... : .......... A52'0'; ......... 86;; l:OgI: ....... ?;6: .......... 75'?:"ig"5;-~ ........ 5'~'. 9. 62. 2.4 A'5'3"0'"'; .................... 76; ................... 9'";"~ .................... 7;3 .............. 5"~'~ 7'~; 8~.~ 49. 9, 61. 2.4 9. 53. 2.5 A5'5'0 , ~2;2 ?'~'~ 6,8 80, 78.~ 42. 10. 8a. 2.2 A560';"'I3'8'; .........8;'~ ....... 8"';-6: ........... 7~6 ........ 79"~'"'-'~,~ 7i' 11. 102. 2.3 ~57'0; .....i"09'"; ....... 2"0";9 ...... 1'%.I'""'i5~'2 79. 85.p 9~. 12. I01. 1.6 ........ A'58'0'"; ....... ~5; 2I~;7"-"I'i;2":-'28;9 76;~:-~ 35. 18, 131. 1.6 A5'9"0'; 62"; t6';2 ....... I"~.7~'5'~3 74.152.~. 34. 18. 104. 1.9 0.0 21. 0.0 20. 0.0 17. 0.1 24. 0.3 25. o.O 42. 0.0 59. 0.1 30. 65" 0 I 0 · 11 9 18 3 g, 1~ 9 9. 16'~1 g. 16.9 9. 16:5 9. 12.1 g. 29.5 1.1. i8:6 :'t:t. 6," 6 .2 16. PAGE 2 'ARATHON OIL COFiPAr'JY 3U D-17 RD ql IS RLJ~J WITH DIFL,GR2 IS R!IN DEPTH GR1RFOC RILM RILO FT, API WITH pHC/AL. SP AC GR2 CALl GR MV API IN APT DEN CORR CN DEI\tP G/C ,% ?~; CAL IN ~600. i13. 14.3 9.7 11.5 81. 96.~ A6io" i24. 9.4 8.6' 8.5 80. a'620" 126. 8'2 ..... 7.7 7.'5' 7'3'95.~ a630. 121. 26.0 14.0 15.6 7~.119.n A'640, i'~'9,' i2,'8 10,8 10.7 7'4. 88.q a65'0, i56, 10.8 9.5 9.2 78. A660'~ ....... 1'3"3', 9.9 8.0 6.'5 72. A67'0. 7'9. 9,"5 ~.'1 ~.8 70. AG'80. 87. 9";"'8 .......... g~"8 ..... 5'~"~ ........ 7'0"~ .... ~"690"; 80', i'0.2 7.5 5,6 7~.,' A7'O0.:":'72', ....... ~'~,"'0'"9'~'I 7','5 6~..70.~ ~%710. '73. 11.1 7.8 5.9 70. 82.~ .................................. AT~O"; ............ :"79; A"7"5'"~ ......... A 73. 13. 90. 69. 11. 72. 71. 11. 66. 10. 119. 85. 11. 112. 107. 10. 126. 108. 10. 8O. 5q-. 10. 6~. 61. 10. 55. ~. 10. 51.. ~6. 10. 55. ~6. 10. 63. ~ ~, 10. 53. . ' 7~%. a 43. 10, 55. 3 7~. 7'~"~"A 50. 10. 77. ~'~'2, A ........... ~"6. 19. 115. 9. 76, r~ 61. 1~.0 ! · ......... 7'3. 82. 50. 10' lOg. I ~0' ?"~~ 0-, 8 ~. 5"9'~ i0. 10 3. 0 ....... 7"7~ ~A.A 68. 10. 95. ':~2:~'2:"'":"7'9~:'"6~,A ......... :59, 10. 60. 2.2 0.0 28.1 30;0 2.1 0.2 31.8 33:7 2.1 0.2 42.0 33;9 2.3 0.3 47.7 24;0 2.1 0,2 33.1 2.5 o.1 3~.o 7:0 2.4 0.0 2P.q- 17~1 2.~ 0.0 20.a 15:2 2.~ 0.0 16.7 15%5 2.~ 0.0 1~.9 2.3-0.0 ~9.0 20%Z 2.~ 0.0 1~.2 13L2 2.~ 0.1 20.9 t.7 0.0 qS.7 59~ 2.4 0.0 26. ~ 2.6 0.0 26.9 .6 0.0 30.7 Z'6 -0.0 5q.7 ~6'.~ Z.9 O.Z 36.9 ~7%0 2.2 0.2 28,9 27'.3 '1 62. 2,4 0.0 2,~ 0.1 2,1 0.2 2.5 0.2 2.3 -0.0 2.5 0.2 1,5 0.0 2.4 0.1 2,4 0.1 2.~ 0.1 so.~ ~o 28.0 17 20.7 16 ~.0 21.~ 10.2 25.6 190 27.8 8.2 51.5 2g.6 16.3 .... i'1'I'"~"5 ............. 8'0~ 83®~ 6'~ ...... lo" 1i'2' 2.0 0.1 23.5 4i', 7 · ~ ......... I'0'' 112, .I 7'7'~ ....... 8"7'~'"~'"'"I'~. 11. 112. .................. ....... ::9"'00 ;"'"'7:'9:'~":'~:'"'"109'~11. 12~. 90"I' ; 7";"5'""10";'2 ~]'i~'q I'i3, 11. 119. g'0:2"'O"; ........... ............ 78:";'""'79";""A 8'9. I1. 98. ................. · 9'0'30'"'; ............ i'52'"; .......... 8"'0, ........ il. i19. 9~ ~ 79.~ ~6. 1,.0. 57. ........... ~ .............. ~ s . 90'60'; 7 . Iu.5 ~g.2 I6.i '79~ ...... ~."~ ....... 9'"07'0" 76~ 60. 77.7 9080. S'5'; ...... ........ 8"~. 77'~7 5g. 10. 579. q'09~; 90; ...... 27';7 I6;'5'""!9.I 8~' 8'1.~ 61. 10. 129. 2.0 0.1 23.5 41.7 2.0 0.1 2.0 0.2 23.5 41.7 1.9 0.2 38.1 48:0 e.O 0.1 34,.2 40:2 0.2 2~.5 i8'.0 0.o 19.a 15:2 o.1 20.5 16',5 0.1 17.7 2.3 O.l 15.2 2.5 O.Z 38.~ 10, 12. 12. 12. 10. 9. 9. 9. 9. 9. q. 9. 9. 10. 11. 10. 13. 1,3. 10. 9. 12. 1~. 10. ~0. 10. 12. 1.~. 16. I ~.~ ~0. ~0. 1.0. O. O. 9. 11. 1~. 12. 10. 10. 10. 10. 10. PAGE 3 ARATHON OIL COMPANY BU D-17 RD RI IS RUN WITH DIFL,GR2 IS RuN WITH OFPTH GR1RFOC RILM 'R'ILD 'SP FT. AP1 MV RHC/AL. GR2 AP1 CALl GR DEN CORR IN API $/C CN OENP CAL ~ % IN 91'00' I3~. 21'8 2i;1 17.2 83. 64.7 105. _ 9'I'10', 156"'' 1.3',2 lP,O '11.5 83" 75.~ 111. gI2'O'. I0'6' ...... 83.-12'1'.~ 87. 9130. lq'5" 11,'8 10.3 i0.'5 Sq. 79,~ I1~. ~I~0', 136', 1'2¥7 ........ 8,8 9;I ..... 8~',"8~"n I06. 9i'50' 1~3"' 13";'1 I~1~'"~'"1 10:6 81. ~1'-60; ....... 1"~3"; I~;5 ....... 1I-;6"'"I1"1 .......... 8i; ?3;._p 1'1~. ~ I70-"; 79"; ........5'2"~'3'~-3i . '6' "33";'8 .............. 85', '~-3~','~ 46. ............ 9'I'90 8 77.9 83. 920"01 ;"" "I'I'l'; ................. g2IO'"; ......... IUO""; .............. 5;0 28'0 11. 11. 11. 11. 11. 11. 11. ~3. 11. 10, 1.0o 128. 2,5 0.1 122, 2.5 0.2 111. 2.1 0.2 1~. 2.6 0.0 10~. 1.8 0.2 142. 2.6 -0.0 1~, 2.6 0.2 72. 1.8 -0.1 161. 2.~ 0.1 119, 120. 74. ~3~i ...... iI~ ..... 72. 49. 10"; 6~. O; 62. O. 10, 5'7. 2.5 0.1 2.5 0.1 2.5 0.i 2.5 0'.1 2'q 0.0 2',~ 0.1 2.~ 0.0 23.4 11 4 12. 2~.~ 7'.~ ~. 4~.~ 32:8 ~.~. 25.9 5 2 lB. 48.~ 52:7 ~. 29.9 15~3 27.9 6 ~ 12. 22.0 6~8 ~1. 22.5 8~ 11. i~.~ 12'.~ ~.o. 8 .............. 8"0 85. 1 10' 59. 'fO,'GA, 10. 7~. ........ 95'7'0"; 9'8'"; ...... i'2;1 .... 7'1 ..... 5,6 7'9. 73.~ 61. 9. .... : 9'58'0', 1"2'3"; :1I'";"ff":'""'9";:"3 ........... '7;"~'"': .......... 77'; 7'g';g 1'03, Il. 9"5"9"0. i'5"2, ......I"q:'";5 ........ i'~"'0 11,1 77. 71.~ 114, 10. · 0.2 22.1 12,2 15.2 ! 22.~ 37.9 2.4. 0,0 20.5 .0 l&.O 2.5 0.1 18.2 2,3 0.1 26,.1 2,5 0.2 2~.9 '2,5 0'.i 20.7 2.5 0.2 22.4 11 3 10. 55 2 lA. 15,5 1.3. 16.2 9. 11 7 19~ 1.~. . ~ 11.1 11. 8.8 11, 2,6 0.3 19.8 ~.8 11. 2.~ o.o i8.~ 2,~ 0.0 18.9 i2L9 9. 2,~4 0,1 i8,,?'13%0 1_0. 1.6-0.0 52"~5 'G6:1 ~. 2.6 0'2'2~,~ 5'~2 2.5 0.2 25.9 ~7 1~. 1,6 -0.0 ~7.7 G6~l 2.6 0.2 2~.~ 3 1 12. ~B; i,6 o.o 52.2 6;,':6 :rS, 8~. 2.5 0.1 19.8 ll.& 9. 57. 2.~+ 0.1 19.0 15:9- g. 63. 2.5 0.1 15.1 1.0'.q 9. 9~. 2.0 0.2 2~.7 37:3 11. 117. 2.5 0.1 23.1 7'.9 9. PAGE 4 ~ARATHON TBU D-17 OIL COF!PANY a D GRi IS RUNWITHDIFL'GR2 ISRUN WITH pHC/AL. DEPTH GR1R'FOC RiLM RILD' Sp AC GR2 CAL! GR DEN Fl. API MV API IN APT G/C CORR CN DENP CAL ?~ ~ IN 9600' 7~, 25,I 16,'6 17,0 63. 78.n 5~. 9. 77. 2.4 9610' 73, 33S'5' ~0,8 29,7 7i, 70,A 5~' 9. 59. 2.6 96'20:'$ 92', i'~"~8 10' 9A. 2.5 9630, ii0, 16,7 i2~0 il,9 79' 75,~ 100, 10. 122. 2.5 966'0, i52'; 12';-4 9'~a 9,2 7'6, 75',AI ' 02. 10. 107. 2.0 935 i9'~9 1~,9 i6'~0 80, 87,A 68' 10. 110. 2.5 2.5 2.5 2.3 2.~ .8 78. 79.z 6~ 9 . 7q..A 50. 9 ...................... ........... 988:0'; 98.9.0...; 87; ............ 8 ;9 ...... 1"0";'-9 .......... 9"'~"0 ................. 6'7"; ?'~. n IO0'10, 9'8"~ .............. 9';7 ;8 4~ . 72. ~ GG. ................................. I""[~'0"2"0";": ...... 85; ............. E;'4" ....5'~'2 ............ 5':~0'" ......... 5i ' 7'2'S-"A ......52, 100'5'0, 77'; ..... 2"8';5" '22'. 6'"'2'~"'~"'G 5"7~ ....... ~'; A ~6. 69. 10. 70. '6'~"' i0' 67. 56. 10. 55. .... "9"6 '; i ~ ~05 . p 69. 10. 10~. ~"~ ........... 7'5'~ 1'o. 7 Q. ~2':"'1""'"'~"~"; .......... 69";'h' ...... 9'9, ....... i"0, i 0'4. ; 7'7.~ 9~. 10. 129. .- .0~. 10. 11~. 9', 'i'07;, 9. 64.. 9. '71. 9. 97. .................... I"O'OqO'; ............. I'"~'~"; .......... I'I";"O~' ;~"'"I"0-5'~ i0",' il 9. I0'05'0', 10'9, 1'5"~5 ~7 50. 7g.n 77. 9. 79. I0'0'6'0'"; .............. '8'7'"; 28";'6""'I7';7"'-"I5'";'"'~ ......... 50'; ....... ?7 , ~ .... Gl . 9 . 52 . I 007"0 ' 817'I '112'2'~'8 '2'5 ~ 7 ~'8. 7g. I 69. 9. 72 . 1009'0. lq:"B; 19;7 I9,'"'3""I9;8 .......... 5'~. 69."~ II.'~. 10, 115. 0.0 17.7 1~12 9. 0.2 1~.~ 3:0 9. 0.1 2B.5 7:9 11. 0.2 2~.7 6:7 12. -0.0 31.~ ~017 0.1 17.2 7:z ~. o.1 lg.o 9:6 g. 0.0 la.9 za',5 0.0 20.~ ZT's 2.5 ' 0.! 2'7,5 ~o. ~,1~ 2.5 o.1 2'~.a 10. '72' 2.5 0.1 20.0 7.9 ..2, : :2,5 0,1 ig.S 2,5 0.1 24.5 9:8 12, o.o z9.7 1,~2 · 21.7 9~7 2 9.9 1.2 9. 11.q 12 ~ 9, 25.6 ~6.~ 10. 2.~ 0.0 19.0 18.0 10, 2,~ 0.0 19.2 17 2 10, 2.5 0.0 9.8 8.2 2.5 0.2 27.2 7.2 2.2 0.1 29.9 25'.2 · 2.5 0.1 16.1 2.4 0.0 15.2 15'.6 2°5 0.1 21.7 lOLa 2.G o.1 2~.o 5'.~ 2.6 0.l 21.5 2.5 o.z 2v.a zola 2.5 o.l 21.9 2.5 o.z ta.9 2.6 o.z 12.9 5La 2.6 0.1 22.9 5~a a.a o.z 21.9 0.1 19.8 15~7 2.5 0.1 Z~.9 0.0 ~7.2 15~2 2.2 o.Z 5~.5 2.5 0.2 20.7 7'.7 10. 11. 11. 11. 12. 11. 1.1.. 11. 1.2. ll. 11. ll. 10. 9o 9. 9. 9. 10. 9. PAGE 5 MARATHON OIL COMPANY TBU 0-17 RD GRi IS 'ROFi WI'TH DIFL,GR2 IS RUN WITFi DEPTH GRI RFOC RILM R'ILD SP FT. AP1 MV HHC/AL. AC GR2 CALl GR DEN API IN APT G/C CORR CN DE~IP CAL % ~ IN 10100, 95. 25.8"24,7'22'.7 65, G7,4 52, I0110. 75. 3q,8 26'3"22.q 122. 72.'5 40. _ 10120. 70. 26;1 ...... i'5',2 I2,~-g~'3. 7i,P ~8. 10130. 79' 21,'0 12,~ 1.0.6 -2q.. 7~.~ 53. I0140, 94,'17-,8 12,"3'-1I",3";15. 7A.n 57. I0150' 81. 12'2 '11.5 10.~ -15. 77.~ 50. 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