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Home My WebLink About194-0981a. Well Status:Oil SPLUG Other Abandoned Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development Exploratory GINJ WINJ WDSPL No. of Completions: _0 Service Stratigraphic Test 2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry: Aband.: 3. Address: 7. Date Spudded: 15. API Number: 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s): GL: N/A BF: N/A Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- y- Zone- 4 TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- y- Zone- 4 5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic information per 20 AAC 25.050 102' (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 32"83 18-5/8" X-56 1,132 13-3/8" K-55 3,987 9-5/8" L-80 9,581 7" L-80 9,979 24. Open to production or injection? Yes No 25. 26. Was hydraulic fracturing used during completion? Yes No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. Date First Production: Method of Operation (Flowing, gas lift, etc.): Hours Tested: Production for Gas-MCF: Test Period Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr): Press. 24-Hour Rate If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date perf'd or liner run): ACID, FRACTURE, CEMENT SQUEEZE, ETC. CASING, LINER AND CEMENTING RECORD List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion, TUBING RECORD 13,638 9,948 (LS) 11,369 / (SS) 11,360 11,275 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 6/9/2023 194-098 / 322-420 & 322-540 & 322-585 50-733-20460-00-00 S MGS Unit 18 ADL0018746 687' FSL, 1877' FWL, Sec 35, T8N, R13W, SM, AK N/A 7/22/1994 13,730 / 9,979 Surface 127' 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 229323.2114 2463858.7186 N/A 630' FNL, 2016' FEL, Sec 10, T7N, R13W, SM, AK CASING WT. PER FT.GRADE 8/31/1994 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2457353.6190 TOP HOLE SIZE AMOUNT PULLED N/A 225284.2723 TOP SETTING DEPTH MD suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. N/A BOTTOM SIZE DEPTH SET (MD) 11,261 / 9,286 PACKER SET (MD/TVD) 2" CT 11,49129 Surf 47 Surf Surf 1,133Surf Surf 68 11,677 Surf Surf 97 83 Surf 4,118 N/A N/A Gas-Oil Ratio:Choke Size: Per 20 AAC 25.283 (i)(2) attach electronic information Sr Res EngSr Pet GeoSr Pet Eng Middle Ground Shoal / MGS Oil N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Flow Tubing Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 3:12 pm, Feb 22, 2024 Originally Received on 6/30/2023 Abandoned 6/9/2023 JSB RBDMS JSB 022324 xG DSR-2/28/24 Conventional Core(s): Yes No Sidewall Cores: 30. MD TVD N/A N/A N/A N/A Top of Productive Interval N/A N/A N/A N/A 31. List of Attachments: Wellbore schematic, Well operations summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Aras Worthington Digital Signature with Date:Contact Email:Aras.Worthington@hilcorp.com Contact Phone: 907 564-4763 Operations Manager General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: Yes No Well tested? Yes No 28. CORE DATA If Yes, list intervals and formations tested, briefly summarizing test results for each. Attach separate pages if needed and submit detailed test info including reports and Excel or ASCII tables per 20 AAC 25.071. NAME Permafrost - Top Permafrost - Base 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS INSTRUCTIONS Formation Name at TD: If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. Authorized Title: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. Authorized Name and Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment; or 90 days after log acquisition, whichever occurs first. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. TPI (Top of Producing Interval). Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2023.06.30 09:08:12 - 08'00' Dan Marlowe (1267) Di 18 Schematic, 2023-06-27.doc AJW 07-2022 Offshore Dillon Platform Di-18 S Middle Ground Shoal Cook Inlet Basin, Alaska Middle Ground Shoal Last Completed: 10/23/98 Size Type Wt/ Grade/ Conn ID Top Btm Cement Sacks CMT Top 32” Structural .5” Wall 29 Surf 83’ 18-5/8” Surface 97, X56, QTE60 17.653” Surf 1133’ 2285 cu ft (407 bbls)Surf/ 3.5° 13-3/8” Intermediate 68, K55, BTC 12.415 Surf 4118’ 36° 2846 cu ft (507 bbls) TOC at Surface 9-5/8” Production 47, L80, Buttress 8.681 Surf 11677’ 2318 cu ft (412 bbls) Calc TOC 8236’ 7” Liner 29, L80, TKC-BTC 6.184 11491 13638’ 1107 cu/ft (197 bbls) CBL 11,700’ Completion Long String 3-1/2 Prod Tubing 9.2, L80, SCBTC 2.992 39.43 11369 Short String 3-1/2 Prod Tubing 9.2, L80, SCBTC 2.992 39.43 11360 Coiled Tubing 2 Coiled Tubing HS-80, 0.156” wall 1.688 39.43 11275 Completion Jewelry Detail # Depth Length ID OD Item Short String A 11360.5 11305 2.992 3.5 3-1/2”, 9.2#, L-80, BTC, Tbg B 11360.5 0.88 2.0 3.87 Crossover, 3-1/2” BTC box X 2-3/8” EUE pin C 11361.4 7.97 1.99 2.88 2-3/8” Pup Jt. Long String 1 11254 11254 1.688 2.00 2” HS-80 Grade, 0.156” Coil Tbg 2 11254 6.86 1-1/2” Oil Master Jet Pump Cavity Assembly 2a 11254 1.57 1.875 2.553 Baker CT Connector, w/ Hydril 511 Pin down 2b 11256 0.87 1.625 2.440 Crossover, Hydril 511 x 1.9 NU pin 2c 11257 4.42 1.393 2.26 1-1/2” Oil Master Jet Pump Cavity w/ 2-3/8” Hydril 511 box X 1.9 NU 10rd pin 3 11261 14 1.375 2.765 Baker “FA-1” Packer, size 35FA20, with 10” seal bore extension and 10’ seal assy on top of packer 4 11369 27.52 2.687 7.25 Kobe Cavity, 3”, ‘D’ Parallel w/ XO Body, SN #94-8-31 5 11397 1.25 2.55 5.25 Trigger Housing Assy. 6 11429.56 1.48 2.562 4.35 Otis Model “R” Landing Nipple 7 11441.72 2.23 3.00 4.30 3-1/2” Van Balance Isolation Tool, w/ 4 ports, 7.02 in 2 8 11454.82 0.86 Tbg and Van Equipment 8a 11454.82 0.86 No ID 4.70 2-7/8” Pressure Transfer Sub Solid, NO ID 8b 12025.29 0.86 1.49 4.70 2-7/8” Pressure Transfer Sub 8c 12026.15 13,635’8.85 3.375,3 .70, 4.625 Van Model “K-11” Firing Head, Van Model “APF-C” Firing Head, Van Guns (4-5/8” w/1,597’ 4spf, 32gm charges) FISH Stuck BHA Top @ 13,638’Stuck BHA and string shot Assy LIH. 7” liner and cemented above BHA. Perforation Data Top(MD) Btm(MD)Status 12,035ƍ 13,632ƍ OpenMAX HOLE ANGLE = 91.16O @ 13600’ 5 32” 83’ 2 3 4 CBL TOC 11700’ G&G Top Oil 11,910’ MD RKB: MSL = 127’ Mudline= 229’ Water Depth=102’ 9-5/8” 11677’ Perfs 12035’ – 13632’ 1 6 7 8TOL 11,491’ 18-5/8” 1133’ 13-3/8” 4118’ 7” 13635’ ’ PBTD =13635’ TD = 13730’ B A C Calc TOC @ 8236’ KB: MSL Mean Sea Level Mud Line ADL: 18746 PTD: 194-098 Leg 2, Slot 5 API: 50-733-20460-00 Notes: x 08/2011 Well circulated with 9.8 ppg KWF. Pumped a total of 32 bbls LCM pill and attempted to squeeze into perfs. Freeze protected and shut in leaving low pressure on LS, SS, 9-5/8. x CT – 10/6/2008 – Static survey to 11,200’ x CT – 8/16/2005 – RIH w/1.45” GR to 11,245’ KB (no tag). x SS – 6/17/1998 – RIH w/2.7” GR to 11,361’ KB. x 1998 had readings of 290 ppm H2S B 2 3 C A1A Cement Plug #3: OOA: 410’ MD to surface OA: 410’ MD to surface IA: 410’ MD to surface LS: 410’ MD to surface CT: Cut and removed to ~450’ MD SS: 410’ MD to surface Cement Plug #1: CT x LS annulus & IA: 11,254’ to ~4000’ MD (Est’d) CT 11,254’ to 6840’ MD (Tag 8/31/22) Cement Plug #2 (laid in w/ CT): SS: 11,268’ to 5100’ MD (Tag 10/24/22) B Rig Start Date End Date SL 8/22/22 6/10/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 18 50-733-20460-00-00 194-098 08/24/22 - Wednesday Held PJSM, and approve PTW Serviced and warmed eq. Arrange deck space, R/d circulating lines off Di-18 and R/u lines to injected in Di-17. Housekeeping around platform. Walk thru platform with Hilcorp Safety Reps. D-17- Injected 675bbls of returns from Di- 18 circulation. Filled upright w/FIW, built 100bbls of 9.8ppg Brine. Work boat arrived, off solos and emptied, load empties back on boat and sent to beach. R/d flanges off Di-18, R/u flanges on 08/23/22- Tuesday Held PJSM and approve PTW Serviced and warmed eq. Loaded cement form transport solos in tanks, back load solos on workboat and sent to beach, well pressures CT/LS/SS/IA=0/0/0/0. AAO crew change, platform walk through with new AAO crew. Held PJSM, Lined up to pump down CT returns up IA, verify circ with cement pump, PT lines t/3000psi, pumped 50bbls of mud wash @ 1.5bpm/1200psi, lost returns after 5bbls away and catch returns after 40bbls, pumped 247bbls of 9.8 brine @ 2bpm/1500psi, monitored returns .25bpm losses, mix and pumped 14ppg cement @ 2bpm/1500psi, with cement on bottom returns @ 1/1. Continued pumping cement 2bpm/1500psi, @ 341bbls of cmt away swapped return up LS and pumped 30bbls, @ 371bbls of cmt away swapped to take returns up SS, no returns pump pressure increased dropped rate f/2bpm t/.2bpm pressure fell 500psi, Increased rate to 1bpm/1600psi, monitored SS no returns, opened IA with 1/1 returns, FCP 1500psi pumped total of 413bbls of 14ppg cement. Dropped wiper ball and pumped 14bbls of 9.8 brine displacement. SD pump, Performed sheen test (no sheen Cleanup cement pump and eq. Assist crane arranging deck space. Work boat, off loaded mixing plant and transport solos and empty cement in tanks, back load solos on boat and sent to beach. 08/22/22 - Monday Held PJSM approved PTW Serviced and warmed eq. Housekeeping and R/d circulating lines and eq. from Di-4. With crane assisting, R/u circulating lines and eq. to Di-18, Well pressures CT/LS/SS/IA= 0/0/0/0 verified circulation. Filled uprights with FIW. Filled mix pit w/FIW, troubleshot issues with mix pit, built 100bbls of 9.8 brine. Work boat arrived back load solos and sent to beach. R/u hoses and transfer brine from mix pit to H3 Tank, built second batch of 9.8 Brine. Rig Start Date End Date SL 8/22/22 6/10/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 18 50-733-20460-00-00 194-098 10/06/2022 - Thursday Wait on chopper for Jet cutter sub and PT logging tools. Move E-line over to Di-18. Make up dummy run with weight bars. RIH to 580' clean. Make up cutter. Run in hole and get on depth at 450'. Went to fire and no indication of fire. Pooh and swap detonator's. Make up cutter. RIH for second attempt at 450'. No amperage when fired. POOH lay down and work boat. 09/23/22 - Friday R/U test Eq. Fluid pack IA MITIA Pretest pressure Tubing-0, IA-0, OA, 100 Pump 3.8bbls Initial pressure - Tubing's 0,OA 155, IA 2802 15 min Pressure- Tubing's 0, OA 155, IA 2714 30 min Pressure- Tubing's 0, OA 150, IA 2652 45 min Pressure- Tubing's 0, OA 150, IA 2600 Bleed back 2.9bbls 08/30/22- Tuesday R/u SL on SS, PT Lubricator 2500psi, RIH w/1.75” DD Bailer and tagged @ 11,268’ w/t POOH, no sample. R/u on CT string, RIH w/1” Bailer tag TOC @ 6840’slm. POOH, R/d SL 10/04/2022 - Tuesday Rig up test pump to Long string and CT string. Pressure up 2785 psi and record pressure with crystal gauge . 15 minutes pressure -70 at 2715 psi, 30 minutes pressure dropped -28 psi at 2687 psi. Send graph into town. Good test. 10/11/2022 - Tuesday Rig up lubricator and 1.375" jet cutter. Stab on well. PT stack 250/3500 psi. AAO crew rig up pump lines to pump down CT taking returns up CT x LS annulus. Open swab. RIH with with 3x 1.44" WT bars, bow spring centralizer, x over, and 1.375" jet cutter. OAL =17.5', OAW= 110 lbs, Max O.D. 1.44". Cut 2" x .156" wall CT at 450'. POOH to surface. AAO crew Pumped 25 bbls 3x bottoms up down CT and return up CT x LS tubing annulus. Good 1:1 returns. Prep tools and equipment for pulling 450' of 2" coil. Rig Start Date End Date SL 8/22/22 6/10/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 18 50-733-20460-00-00 194-098 10/12/22 - Wednesday ON weather hold, fly out to Dillion. Orient Crew and Discuss operations. Check DI 18 well pressures CT/L/S/SS/iA/OA, = "0". Conduct a no flow test on the CT/ LS/SS/iA/OA = NO flow from well, well static. Nipple down valve above CT hanger, remove hoses from DI 17 and remove thru hatch openings, remove deck plate, lay out upper master valve from above CT hanger and lay out same, install deck plate set up bowl and slips. Pull 2" coil tubing with crane cutting and laying out in ~ 60 ft sections, secure long string. Rigging up coil tubing on SS. 10/13/22 - Thursday Held PJSM with crews, swap out box on sewerage system, hook up injection hoses Di 17 well. Check well pressure L/S = "0" with slight vacuum, SS = 3800 psi, I A = 475 psi, OA = 25 psi. Rig up bleed hose to SS bleed off press f/ 3800 psi to 150 psi in 15 minutes, bleed back two gallons of OIL, then dry gas, IA pressure bleed f475 to 400 psi, shut in SS monitor pressure for 5 minutes, pressure increased f/ 150 to 400 psi. Injecting fluid from R4R tank pump total 289 bbls at 1.4 bpm at 2550 psi, maintaining 2250 psi on I A. Finish rigging up Coil tbg injector and lines. Test coil tbg Bops and all components to 250 low and 4000 psi hi, test bop's valves choke manifold, test made with water all test good (no failures) test witness waived by AOGCC Jim Regg. Set injector and riser on deck to free up crane. Working work boat offloading dumpsters and totes and Air compressor. 10/14/22 - Friday Held PJSM with crews. Rig up Schlumberger Coil tbg, stab on lubricator test breaks to 250 low and 4000 psi. Open well (SS "0" psi) RIH with coil with wash nozzle tagging at 11,262 ft CTM check pulling parameters pull at 115 ft/ min & 85 ft/ min vs engine rpm for cmt job. Held PJSM with crews. Break Circulation down coil tbg with 5 bbls fresh water at 1 bpm at 2148 psi, pressure test line to 4656 psi (good test). Mix & pump 205 sxs CL "G" cmt 55 bbl slurry with 1.52 yld mixed at 14.0 ppg pumped at .8 bpm at 2356 psi holding 250 psi on choke, displace cmt 1 bbl out the end of coil tbg, pooh at 85 ft/min pumping at 3/4 bpm holding 250 psi on choke. With end of coil tbg at 4930 ft. water out end of tbg, continue to pooh with Coil tbg at 115 ft/min displace SS tbg with 44 bbls of 9.8 ppg brine pumping at 1 bpm, with coil tbg at, surface getting 9.8 ppg back return tank. Secure well rig down injector and set on deck. Rig Start Date End Date SL 8/22/22 6/10/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 18 50-733-20460-00-00 194-098 10/30/22 - Sunday Move e-line over from Di-16, R/u on SS w/ 2" x 6' gun, 60Deg Phasing. PT lubricator 250/2500 good. RIH log up correlate CCL (2.6' from top shot) @ 407.4', placing shots @ 410-415', to miss tubing collar, fire shot, good indication on surface gun fired. POOH, r/u ciirc lines, check circulation on SS t/LS 2.4 BPM 300 psi good, SS-IA 2.4 BPM 300 psi good, SS-OA 2.4 BPM 300 psi good, SS-OOA CBU 1.5x, 3.5BPM 650 psi good. R/D e-line move over to DI-09. AOGCC witnessed By Inspector Brian Bixby, CMIT SS, LS, CT, IA Pass Initial 2790 15 min 2758 30 min 2745 OA pre-test - 9 Initial 9 15 min 9 30 min 9 BBLS in 3.2 BBls out 3.2. R/U W/L with 2 1/4" bailer, PT lubricator t/2500psi good, RIH tag cmt at 5100', Tag witnessed by AOGCC inspector Brian Bixby, POOH r/d W/L for leg move. Secure well. Recover 2 cups cmt interface. 10/23/22 - Sunday 11/11/22 - Friday R/u circulating eq. Freeze protected well with diesel to 120' below wellhead. R/d circ eq. Rig Start Date End Date SL 8/22/22 6/10/23 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 18 50-733-20460-00-00 194-098 Confirmed good cement at surface in OOA, OA, IA, SS and LS. 06/09/2023- Friday Held PJSM and discussed daily activities. Built manifold on the return side of the gas buster tank to route cement to a cutting box when at surface. Break circ down LS @ 2bpm and fluid packing lines across WH to return tank. SI at return tank, PT lines t/1250pi good test. Lined up to Pump down LS taking returns up OOA. Pumped 3.2 bbls of FIW and pressured up t/600psi. S/d pump monitored, pressure leaked off t/525psi in 15mins. Swapped lines to PD the OOA returns up LS, pumped .2bbls and pressured up to 500psi. Held 5mins and bled off. Swapped back to PD the LS returns up OOA, started pumping @ .5bpm/150psi and with instance returns form OOA, worked rate up t/2.4bpm/490psi. continued CBU 2x (108bbls). Swapped returns to OA and CBU 2x (48bbls) @ 2.5bpm/400psi. Swapped return to IA and CBU 2x (40bbls) @ 2.5bpm/390psi. Mix and pumped 14bbls of surfactant wash down LS returns up OOA. Lined up and pumped 10bbls of surfactant wash down LS returns up OA. Lined up and pumped 10bbls of surfactant wash down LS returns up IA. Lined up and pumped 6bbls of surfactant wash down LS returns up SS. Crew S/d for lunch. Held PJSM, lined up to pump down the LS returns up the OOA, mixed and pumped 14ppg slurry @ .8bpm/300-500psi. Early returns of 9ppg cement at 30bbls away (calculated 56bbls), swapped returns to cutting box continued circulating monitoring and weighing returns. After 120bbls cement returns was 12.8ppg. Captured sample of cement. Decision made to SI OOA move on the OA. Lined up to pump down LS and returns up OA, broke circ with returns of 12.8ppg cement, pumped 5 more bbls with returns the same verifying communication with OA and OOA. SI OA. Swap to take returns from IA, mix and pump 20bbls slurry @ 14ppg, with good cement returns at surface. SI IA. Swap to take returns from SS mix and pump 4bbls slurry @ 14ppg, with good cement returns at surface. SI IA. Pressured up on LS to 480psi and secured well. Performed sheen test-all good. Washed and cleaned up cement eq. SDFN. Work boat arrived off load cement pods and salt. SDFN. 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Chmielowski Digitally signed by Jessie L. 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State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 35 Township: 8N Range: 13W Meridian: Seward Drilling Rig: N/A Rig Elevation: N/A Total Depth: 13730 ft MD Lease No.: ADL 0018746 Operator Rep: Suspend: P&A: XXX Conductor: 18 5/8" O.D. Shoe@ 1133 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 4118 Feet Csg Cut@ Feet Production 9 5/8" O.D. Shoe@ 11677 Feet Csg Cut@ Feet Liner 7" O.D. Shoe@ 13368 Feet Csg Cut@ Feet SS Tubing: 3 1/2" O.D. Tail@ 11360 Feet Tbg Cut@ Feet LS Tubing: 3 1/2" O.D. Tail@ 11369 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Balanced 11254 ft 5100 ft 9.8 ppg Wireline tag Pre-Test Initial 15 min 30 min 45 min Result Tubing 0 2790 2758 2745 IA 0 2790 2758 2745 OA5999 Remarks: Attachments: Harold Soule Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): P Long and Short Tubing strings were twinned in with the IA for the test. Pressure loss was -32 psi / -13 psi. 3.2 bbls in, 3.2 bbls returned. September 23, 2022 Brian Bixby Well Bore Plug & Abandonment S MSG UNIT Dillon 18 Hilcorp Alaska LLC PTD 1940980; Sundry 322-540 none Test Data: Casing Removal: rev. 11-28-18 2022-1023_Plug_Verification_SMGS_Di-18_bb 9 9 9 999 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. 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RQZDUGWUDQVPLVVLRQRSHQLQJRUXVHRIWKLVPHVVDJHDQGDQ\DWWDFKPHQWVZLOOQRWDGYHUVHO\DIIHFWLWVV\VWHPVRUGDWD1RUHVSRQVLELOLW\ LVDFFHSWHGE\WKHFRPSDQ\LQWKLVUHJDUGDQGWKHUHFLSLHQWVKRXOGFDUU\RXWVXFKYLUXVDQGRWKHUFKHFNVDVLWFRQVLGHUVDSSURSULDWH Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/18/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes AOGCC Eset # MGS D1-06 50733200420000 167052 07/03/2022 Read LEAK + Report MGS D1-18 50733204600000 194098 07/04/2022 Read LEAK + Report MPU L-48 50029235520000 215120 06/27/2022 READ IPROF + Report Please include current contact information if different from above. 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They are available in the original file and viewable by direct inspection. LI _ 0c~(::~File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beved cent TO RE-SCAN Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is/ ) ) ~7~~E C} fÆ~fÆ~~«fÆ AIIAS&.& OIL A1Q) GAS CONSBRVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage, AK 99516~624 7 \~~1Øq~ Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: This letter confinns your conversation with Conunission Engineer Tom Maunder last week regarding the multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively. Attached, please fmd the Sundry Applications, which are being returned without approval'j because the relief you request needs to be sought through a different procedure. The intent of submitting sundry notices for each well was to establish a monthly pressure and general monitoring frequency for all wells on Dillon and Baker. There is a requirement in place. for some of the water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the platforms are unmanned and not operating, it is not possible to obtain daily information. When operations were curtailed, a monthly monitoring frequency was established in the Plans of Development (POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring scheme is accepted by the Commission. As noted in the conversation, changing the monitoring frequency where presently in place and establishing a monthly monitoring frequency in general is not an action that is best accomplished with multiple sundry notices. A letter application requesting the desired monitoring schedule should be made under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter applications. If prior monthly monitoring information has not been submitted to the Commission, that information should be ubmitted forthwith. . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this _day of November, 2004 Ene!. SCANNED NO\f 2: 42001¡ Abandon U Alter casing D Change approved program D 2. Operator Name: Union Oil of California aka Unocal ; . 1 . Type of Request: 3. Address: 7. KB Elevation (ft): KB 127' above MSL 8. Property Designation: Dillon Platform 11. Total Depth MD (ft): 13,730' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 12035 to 13632' Packers and SSSV Type: ") STATE OF ALASKA .) RECEIVED ALASr,A OIL AND GAS CONSERVATION COMMIS::;ION. .. .... . APPLICATION FOR SUNDRY APPROVAL OCT 122004 20 AAC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Suspend U Repair well D Pull Tubing D Perforat~lDka UII ~ G_i~ (;Q(OOÙ~it)ßpos. U Stimulate D Time EAm6b611a~ Re-enter Suspended Well D Monitor Fr 5. Permi\\o Driil Number: /.. er: / Exploratory D 94-98 / J Service D 6. API Number: ! 50-733-2046 P. O. Box 196247 Anchorage, Ak. 99519-6247 Development Stratigraphic 0 D 9. Well Name and Number: Di-18 10. Field/Pools(s): MGS/E,F&G Pools PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 9,972' Length Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13,635' 9,975' Size MD Burst Collapse 1,133' 4,118' 11,677' 18-5/8 " 13-3/8 " 9-5/8 " 1,132' 2,250' 630 psi 3,987' 3,450 psi 1,950 psi 9,583' 6,870 psi 4,760 psi 9,449'-9,555' 8,160 psi 7,020 psi ITUbing Grade: ITUbing MD (ft): 3-1/2" ,9.2#, L-80 @ 13369',2" HS-80, .156" wall coil tubing @ 11,275' Packers and SSSV MD (ft): 1,133' 4,118' 2,147' 7" Perforation Depth TVD (ft): 9805 to 9975' 11,275' 12. Attachments: Description Summary of Proposal Detailed Operations Program D 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D Abandoned WDSPL D D 16. Verbal Approval: Commission Representative: 0 Service D D D Plugged WINJ 17. I hereby certify that the foregoing is true Printed Namj2e .... ~. A Ie Signature ~ // ru /A . d correct to the best of my knowledge. Contact Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY 28-Sep-2004 Phone 30 I_{ - Lf 01:-7 Conditions of approval: Notify ommission so that a representative may witness Sundry Number: Plug Integrity Other: Subsequent Form Required: Approved by: D Mechanical Integrity Test D Location Clearance D RBDMS BFL NOV 222004 ORIG\NAL APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION COMMISSIONER BY ORDER OF THE COMMISSION Date: ~ Form 1 O~ Revised 12/2003 Submit in Duplicate ,~",...¡. $'.,'" #""I¡. );'" ~ f"~ ~~ l ø""~ ~ "'" ,J'c'.'~. ,,: ,~..,-" . STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION ,rES 2 6 2004 REPORT OF SUNDRY WELL OPERATIO~~\;=¡ fN? 1. Operations Abandon Performed: Alter Casing 0 Change Approved Program 0 2. Operator Union Oil of California Name: aka Unocal 3. Address: Suspend Repair Well 0 Pull Tubing 0 P. O. Box 196247 Anchorage, Ak. 99519-6247 7. KB Elevation (ft): KB 127' above MSL 8. Property Designation: Dillon Platform 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 13,730 true vertical 9,972 measured 13,635 true vertical 9,975 Length Size 210' 32" 1,133' 18-5/8" ' 4,118' 13-3/8" 11 ,677' 9-5/8" 2,147' 7" I'" l.1 ) , '.: ~ ~'~ Operation Shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 Perforate Waivér Other" Stimulate 0 Time Extension 0 Shut in and secure Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory 0 94-98 Service 0 6. API Number: 50-733-20460 9. Well Name and Number: Di-18 10. Field/Pool(s): MGS/E,F&G Pools feet feet Plugs (measured) Junk (measured) feet feet MD TVD Burst Collapse 83' 1,133', 4, 118~ 11 ,677' 11,491'-13,638' 83' 1,132' 3,987' 9,583' 9,449'-9,555' Measured depth: 12035'-12442',12483'-12508', 12564'-12892', 12947'-13079', 13272'-13314', 13330'-13384, 13566'-13632' True Vertical depth: 9805'-9951', 9957~-9960', Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9964'-9972', 9974'-9977' 9978'-9978', 9978'-9978', 9976'.9975' 55: 3 1/2" 9.2# L-80 @ 11,360' LS: 31/2" 9.2#, L-80 @ 13,369',2" H5-80, .156" wall coil tubing @ 11,275' Baker 2" x 3-1/2" FA-1 Perm Packer @11,275' Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation: 53 19 60 90 Subsequent to operation: This well shut in subsequent to operation 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development 0 Daily Report of Well Operations 16. Well Status after proposed work: Oil0 Gas 0 WAG 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Contact Printed Name P. M. Ayer Signature Form 10-404 R~~ç~~~ú~f.~f~~' Mj~R 1 @ 2004 Tubing Pressure 80 Service 0 GINJ D WINJ 0 WDSPL 0 Sundry Number or N/A if C.O. Exempt: Title Petroleum Engineer Phone 263-7620 Date 18-Feb-2004 _aft 32" @ 83' 18-518",97#, X-56, aTE @ 1,1 13-3/8",68#, K-55 @4 TOL@ 9-5/8",47#, L-8 @ 7", 29#, L-80, T @ Dillon Di-18 Actual Completion, 10/23/98 RKB- 55.35' Completion Equipment Proposed Equipment in Blue ~ t. No. Depth Len~th ID OD Description 1 ' ; :: A 1 11,369' 11,369' 2.992 3.50 3-112" SCBTC Thg i. ! ; ~ 2 11,254' 11,254' 1.688 2.00 2" HS-80 Grade, .156" Coil Tbg. ... . ,: .... ' 3 11,254' 6.86' 1-112" Oil Master Jet Pump Cavity Assembly : ' 1 : . 11.261 ' 60 ¡ , 3a. 11,254' 1.57' 1.875 2.553 Baker CT Connector, wi Hydril 511 Pin down 33:~ 2...,; ~ 11.256' , ~ 1 ¡ 3b. 11,256' 0.87' 1.625 2.440 Crossover, Hydril 511 x 1.9 NU pin 11,257' : : 3c. 11,257' 4.42' 1.393 2.26 1-1/2" Oil Ma.<;ter Jet Pump Cavity w/2-3/8" i ) 11.261' Hydril 511 box X 1.9 NU lOrd pin 4 11,261' 14' 1.375 2.765 Baker "FA-I" Packer, size 35FA20 , BT~ J. ~ 11,275' With 10" seal bore extension éUld 10' seal ,118' assy on top of packer 5 11,369' 27.52' 2.687 7.25 Kobe Cavity, 3", 'D' Parallel w/ XO Body, SN 11,397' #94-S-31 6 11,391' 1.25' 2.55 5.25 Tliggt'r H()usin~ Assy. ;¡ 11,;'98' .1 7 11,39S.01' 31.55' 2.992 3.50 3-112",9.2#, L-SO, BTC Tbg Jt. 3 11,429.56' 1 8 11,429.56.' 1.48' 2.562 4.35 Otis Model "R" Landing Nipple 11,431.04' B 9 11,431.04' 10.02' 2.992 3.5 3-112" x 10' Pup Jt. 4 C 11,441.06' 9a. 11,441.06' .66' 3.00 4.25 Crossover, 3-112" BTC box X Srd pin 11,441.72 10 11441.72 2.23' 3.00 4.30 3-112" Van Balance Isolation Tool, 11,443.95 w/4 ports, 7.02 in2 .1 11 11,443.95' 587.53 Tbg and Van Equipment 5 12,031.48 lb. 11,443.95' 9.87' 2.992 3.50 3-112" ;It 10' Pup It. 11,453.82' t ¡ ." lIb. 11,453.82' 1.00' NolO 4.50 Crossover, 3-112" Srd X 2-7/8" 8rd, Solid 11454.82' 11 ,491' I 6 l1c. 11,454.82 .86' NolO 4.70 2-7/8" Pressure Transfer Sub, Solid no lD 11,455.68 7 lId. 11,455.68 .35' NolO 3.10 Crossover, 2-7/8" 8rd box X BTC pin O,BTC 11,456.03 8 11,677' ~ ~ lIe. 11,456.03 568.58' 2.441 2.875 2-7/8",6.4#, BTC Thg 9 12,024.61 ! 10 tH. 12,024.61 .68' 2.50 3.50 Crossover, 2-7/8" BTC box X 8rd pin t: ~ ~1 12,025.29 ~ llg. 12,025.29 .86' 1.49 4.70 2-7/8" Pressure Transfer Sub J ~ 12,026.15 11h. 12,026.15 1.63' 3.375 Van Model "K-ll" Firing Head i' : : 12,027.78 ,~ : : IIi. 12,027.78 3.70' 3.70 Van Model "APF-C" Firing Head 12 .. - : : 12,031.48 .' : : I1j. 12,031.48 3.52' 4.625 Van Guns, 4-5/8", w/l,597' 4spf, 32gm charges - - : .. 13,635.00 KC-BTC ,f,~", ' 13,638' Short String ETD 13,635' A. 11,360.5' 11,305.15' 2.992 3.5 3-112",9.2#. L-80, BTC, Tbg B. 11,360.5' .88' 2.0 3.87 Crossover, 3-1/2" BTC box X 2-3/S", EUE pin 11,361.4' . C. 11 ,361.4' 7.97' 1.99 2.88 2-3/8" PupIt. 11,369.4' Well DI-18 DATE COMPLETED 1977 6/28 1992 3/15 1996 12/6 1997 1/14 1998 2/8 5/9 5/10 DILLON PLATFORM API # 50-733-20296-00 MGS. ST. 18746 # 18 WELL HISTORY EVENT Completed as an Oil Well. Completed as an Gas Well. WL -. Equalized and pulled standing valve @ 11,369' RKB. Well went on vacuum. Ran in hole with redressed standing valve, fluid level @ 86501 RKB stop @ 8,800' shake off standing valve. POOH RD. Could not tag bottom because TCP Perf Guns were in the way. Perf, mill out pressure WL - PULLED SV @ 11 ,4081KB. RERAN SV TO 65001KB. SHAKE OFF. GL - (Pull and re-run SV. SV still bleeding by.) RIH wI 311 kobe equalizing prong. SID at 11,424' Jar down, well went on vacuum. POOH. RIH wI 311 Kobe pulling tool. SID at 11,4241, latch valve, POOH. RIH wI redressed SV w/screen. Find fluid at 1,1001. Stop at 1,5001 shake off valve. POOH. Lay down lubricator and standby. Production unable to pressure up on SV. Pumped app. 100 bbls. Decide to make sure SV is on seat. RIH with 311 kobe pulling tool top sub (2.25110D). Sat down at 11,4231. Jar down. Appeared to move down 1 foot. 11,424'. POOH WL -(Pulled SV , ran bailer, scratch cavity and re-ran SV) RIH wI 311 kobe pulling tool. SID @ 114241KB. Jar down. Well went on slight vacuum. POOH. RIH wI 311 kobe pulling tool. SID at 114241 KB. Latch SV. Jar up to get free. POOH no SV. Change out pulling tool. RIH wI 311 kobe pulling tool. SID at 11424'KB. Latch, jar up. Appeared to move 10' up hole and stop. Jar up came free. POOH. Have SV. RIH wI 2.25 drive down bailer wI flapper bottom. SID at Di# 18 Hist.doc, last revised 2/18/2004 page 1 6/15 6/17 6/18 10/2 10/19-20 10/21-23 114241KB. Pass through. Sat down at 11 ,484IKB. Unable to pass. POOH. Make up B/L scratcher. RIH wI scratcher and scratch area from 11 ,4001 to 11 ,4501 KB. Production pumped power oil while scratching. Make 25 up and down passes. POOH. RIH wI SV. Stop at 20001, shake SV off POOH. WL - LS (Pulled standing valve. Ran LIB, set standing valve.) RIH wI EQ Prong, jarred down, well on vacuum, POOH. RIH wI Standing valve Pulling tool, Latched standing valve @ 11,397, POOH. RIH wI 2.8 LIB, jarrd down, POOH. Couldnlt tell if landing sleeve was damaged from LIB. RIH wI standing valve assembly, shake off @ 31001 @ fluid level, POOH. RIH wI 2.8 Blind Box, beat down on standing valve to set 0- Rings, POOH. WL - SS (Ran GRls to clear tubing. Ran plug, pressured up tubing, held 1700# 30 min.) RIH wI 2.70 GR, sat down @ 57001, jarred down, broke free, worked tools to 64001 pick up to 50001 , let junk fall, RIH to 11,3601 KB, POOH. RIH wI 2.868 GR to 11,3611 KB, POOH. RIH wI 3 Y2 WO Circulating plug (2840 00) wI 2.70 GR on 2.5 JOG- To 11,3611 KB, jarred down for 1 ~ hours, plug wonlt set, tools won't sheer because of deviation. POOH. Put smaller pin in JOG - Check plug, stand by for crane - RIH to 300', set plug, sheer pin, POOH. Repin JOG, RIH to 300, latched plug. RIH To 44001, set plug, sheer pin. Repin JOG - RIH to 4400', latched plug, RIH to 11,361' KB, set plug, POOH. WL - (SS) RIH wI JOG pulling tool to 11,360' KB - Jarred down, can1tlatch plug, POOH Tool Sheered, full of rubber. Repin pulling tool, RIH wI 2.5" JOG wI 2.7" centralizer to 11,360', latched plug, POOH. Left part of the rubber seal from the WO plug in hole. WL - Pulled pump from 11,427', pulled standing valve from 11,454'. WO - APRS E-line unit on Di-18. RIH with Baker FA 3-1/2" packer. Set packer at 11,275'. POOH and RD APRS. NU spacer spool, coil tubing hanger spool, 4" master valve, riser spool and adapter spool for coil tubing BPs. Test to 5000 psi. WO - RU coil tubing unit. Test CT BOPs to 250 psi/4500 psi. MU jet pump BHA with isolation sleeve and Baker anchor with upper PBR on bottom of 2" coil. RIH and latch anchor in top of packer at 11,222' CTM. Fill 3-1/2" tubing x 2" coil annulus and pressure test to 1000 psi to confirm latch up. PU and shear out seal assembly from upper PBR. RI H and tag seals in bottom of PBR. Pressure test annulus to 1000 psi. Calculate space out and pick-up 22.70' for hanger installation. Close pipe and slip rams. Break riser above BOPs. Cut coil and install coil tubing hanger. Di#18 Hist.doc, last revised 2/18/2004 page 2 1 0/24-27 11/3 11/9 RIH and land hanger. Test annulus and hanger to 1000 psi. RD coil tubing unit. WO - RU slickline. RIH and pull isolation sleeve from coil tubing jet pump cavity. Run standing valve. RD slickline unit. Drop jet pump, unable to seat pump. Reverse circ jet pump out. RU slickline and run 1.56" gauge ring to 11 ,262' with no problem. Trim down cups on top of jet pump and remove fishing neck extension bar. Drop jet pump and pump seated properly. Begin coil tubing jet pump production. WL - (Pulled 1 Y2" pump, pulled 1 Y2" standing valve.) Note: Pump was collapsed. Latched 4' pump @ 11,225', beat up wI 1 1A" oil jar @ 1100#, 5 times, pump came free, POOH. RIH wI equalizing pulling tool to 11,230', latched, beat down, didn't equalize, had 500# pull on line, pulled free, POOH. RIH wI equalizing pulling tool to 11,230', beat down several times, Well started on vacuum. Vacuum stopped, pulled standing valve, POOH. WL - (Pullèd 1 Y2" pump, pulled 1 %" standing valve.) Note: Pump was collapsed. RIH wI Trico pulling tool to 11,225', hit three oil jar hits, came free, POOH wI pump. RIH wI equalizing pulling tool to 11 ,230', beat down a few times, well went on vacuum, waited 20 min., pulled standing valve. 2002 12/-8/2002 This well was shut in and isolated at the surface with multiple flanges to isolate the well from surface flow lines. Di# 18 Hist.doc, last revised 2/18/2004 page 3 Don Sta dual lEG ROOM #1 ~ 13 3/8" x 9 5/r 9 5/r x 3 1/~ 01-2 I bbIs 28bb1s 22 bbIs 01-4 4 bbIs 15.5bb1s 30 bbIs ~ ~ 01.'3 lEG ROOM #2 E 01-18 2QbbIs 01-17 15.5bbIs 20 bbIs DI-16 15 bbIs 20bbIs DI-l1 7;4bÞII DI-8 DI-7 ABN-6 ~ lEG ROOM #4 DI-5 -::: ¡abbls ~ DI-3 12 bbIs 25 bbls 20 x 13 SI8 0.1815 300 54.45 3 1/2 tbg. 0.0087 300 18 5/8 x 133/8 0.1291 300 38.73 27/8 tbg. 0.00579 300 13 3/8 x 9 5/8 . 0.0671 300 20.13 I~ 856 334 9 5/8 x dual 3 1/2 0.0507 300 15.21 355 9 518 x dual 2 7/8 0.0571 300 17.13 - - - pump limit 21 psi 9 5/8 x 3 1/2 0.0626 300 18.78 well 82 wel.14 we.. H WeI. # 10 We.1 #13 Well #7 Well #8 Well #11 well #16 Well 17 Well II 18 well n Well :15 Well II 12 Well 1114 we" #15 WELL BAY # 1 Pumped down tbg.tbg on vac, bled down 9 5/8 x tbg. Pumped 28 bbls. Gas still at surface. Pumped down 2Ox135/8 2bbls 100 psi. 20 bbls in 133/8, Try to pull eclipse paker with wire line could not get out. Well had 180 on annulus and 150 on tbg would not bleed down, Tryied pumping down short side old pump in hole could not pump. Put 30 bbls of 9.8 in annulur 9 5/8x tbg. Pumped down I.s. tbg. Retumed up short side 100 bbls. Put 15 bbls In 13 5/8x9 5/8. 4 bbls in 20" ann. Hook up to 20" took approx 1 bbl with charge press on ann. 13 3.81( 9 5/8 RumP and bleed 3 ~s I~ an~. 9 5/8xtbg fluid packed with oil. 14.4 bblsln tbg. well 1 0 Is abondoned Fill 20" ann 2 bbls, tbg on vac 7bbls in 13318 x 9 5/828 bbls 9 5/8 x tbg. 51.5. 5 s.s.bbls down short side did tbg. And ann same time WELL BAY # 2 20" fluid packed, 13 3/8 x 9 5/8 2 bbls and started getting diesel fluid back to sul1ace. Pumped Sbbls in tbg.' 20 bbls In 9 5/8 ann.Annulus and tbg. Have oil retums 0 press on well. 20" fluid packed,13 3/8 x 9 5/8 2 bbls and started getting diesel fluid back to sul1ace. Pumped Sbbls in fbg.' 20 bbls in 9 5/8 ann.Annulus and tbg. Press up to SOO psi. on both tbg. Strings had oil to top no press on tbg. Pumped and bled 7bbls in tbg. Annulus. When annulus was fluid packed. Oil at sul1ace.5 bbls In 13 5/8 x 9 5/8 press limit. .5 bbls in 20" Well had SOps!. On 13 3/8x 9518 bleed down to 20psi put bbls of 9.8 fluid, 95/8onn. 20 bbls fluid, tbg.5bbls each, wells 185/8 has 110 psi. bled off and fluid packed with press limit of SO psi..75 of a bbl. Well had l00psi. On 13 3/8x 9 5/8 bleed down to 20psi put 1Sbbls of 9.8 fluid, 95/8onn. 20 bbls fluid, tbg.5bbls each, wells 185/8 has 60 psi. bled off and fluid packed ann with .75 bbls. Well had 1SOpsi. On 13 3/8x 9 5/8 bleed down to 20psl put20bbls of 9.8 fluid, 95/8onn. 20 bbls fluid, tbg.SbbIs each, wells 185/8 has25 psi bled off and fluid packed with 9.8 salt took 1.2 bbls. WELL BAY # 4 Rig up pump 4 bbls 1.5. 4 bbl s.s. 9 5/8 x tbg. 25 bbls, 13 3/8 x 9 5/8 fluid packed w 112 bbls, 20" ann. 2 bbls. Auid packed Pumped 4 bbls I.s. tbg. 4 bblss.s.R/u to 9 5/8 x 3112 ann. Pumped 15 bbls fluid packed 011 to sul1ace. Pumped 4bbls down tbg Is, 4 bbls $.S. both went on vac. Pumped 15 bbls 95/8 x31/2. WdhSO psi press limit 0 bbls In 13 3/8x 95/8 Auld packed 20x 133/82 bbls, Auld packed 13 3/8x9 5/812 bbls press up to 200 psi and held. Rig up pump 5 bbls 1.5. 25 bbl s.s. & 9 5/8 x tbg. 8 bbls fluid packed 011 to sul1ace 13 5/8x9 5/8, R/U to 20" ann fluid pack 5 bbls. Press limit 20 psi. .... - STATE OF ALASKA } ALASKA O,,-AND GAS CONSERVATION ,.,0MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: Pull tubing: Alter casing: Repair well: Other: X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Unocal Development: X KB 127' above MSL feet 3. Address Exploratory: 7. Unit or Property name P. O. Box 196247 Stratigraphic: Chakachatna Anchorage, AK 99519-6247 Service: Dillon Platform 4. Location of well at surface 8. Well number 694' FSL, 1874' FWL, Sec. 35, T8N, R13W, SM Di-18 At top of productive interval 9. Permit number/approval number 705' FSL, 1018' FEL, Sec. 3, T7N, R13W, SM 94-98 At effective depth 10. APl number 50-733-20460 At total depth 11. Field/Pool 4661' FSL, 2024' FEL, Sec. 10, T7N, R13W, SM Middle Ground Shoals/E,F&G Pools 12. Present well condition summary Total depth: measured 13730 feet Plugs (measured) true vertical 9972 feet Effective depth: measured 13635 feet Junk (measured) true vertical 9975 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1133' 18-5/8" 2285 cuff 1133' 1132' Surface 4118' 13-3/8" 2846 cuff 4118' 3987' Intermediate 11677' 9-5/8" 2318 cuff 11677' 9583' Production Liner 2147' 7" 1107 cuff 11491 '-13638' 9449'-9555' Perforation depth: measured 12035'-12442', 12483'-12508', 12564'-12892', 12947'-13079', 13272'-13314', 13330'-13384, 13566'-13632' true vertical 9805'-9951', 9957'-9960', 9964'-9972', 9974'-9977' 9978'-9978', 9978'-9978', 9976'-9975' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 @ 13369', 2" Ha-80, .156" wall coil tubing @ 11,275' Packers and SSSV (type and measured depth) Baker 2" x 3-1/2" FA-1 Perm Packer @11,275' 13. Stimulation or cement squeeze summary . . Intervals treated (measured) ORIGINAL "": Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 140 3500 jet pump Subsequent to operation 134 58 140 3500 jet pump 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: t ' '~ /~ 1/f~r/~/ Title: Sign /~/,~ i ~'/~ "'~ I Drilling Manager Date: ' ' . Form 10-404 Rev 06/15/88 SUB'MIT IN DUPLICATE 10/19/98 10/20/98 10/21/98 10/22/98 1 O/23/98 10/24/98 10/25/98 10/26/98 10/27/98 Dillon W ell Di- 18 Daily Summary of Operations RU APRS E-line unit on Di-18. RIH with Baker FA 3-1/2" packer. Set packer at 11,275'. POOH and RD APRS. NU spacer spool, coil tubing hanger spool, 4" master valve, riser spool and adapter spool for coil tubing BPs. Test to 5000 psi. RU coil tubing unit. Test CT BOPs to 250 psi/4500 psi. MU jet pump BHA with isolation sleeve and Baker anchor with upper PBR on bottom of 2" coil. RIH and latch anchor in top of packer at 11,222' CTM. Fill 3-1/2" tubing x 2" coil annulus and pressure test to 1000 psi to confirm latch up. PU and shear out seal assembly from upper PBR. RIH and tag seals in bottom of PBR. Pressure test annulus to 1000 psi. Calculate spaceout and pick-up 22.70' for hanger installation. Close pipe and slip rams. Break riser above BOPs. Cut coil and install coil tubing hanger. RIH and land hanger. Test annulus and hanger to 1000 psi. RD coil tubing unit. RU slickline. RIH and pull isolation sleeve from coil tubing jet pump cavity. Run standing valve. RD slickline unit. Drop jet pump, unable to seat pump. Reverse circ jet pump out. RU slickline and run 1.56" gauge dng to 11,262' with no problem. Trim down cups on top of jet pump and remove fishing neck extension bar. Drop jet pump and pump seated properly. Begin coil tubing jet pump production. Di-18 daily summary, doc Page #1 11/05/98 Dillon 18 Cavity Replacement, 10/23/98 2" Coil Tubing, ITS-80 grade, .156' wall, 1.688" ID, 0.00277 bbl/ft, 3.08///t/, yield = 63,300 lb (new) L-80. SCBTC Loag String ~, 9.2#, L-80. SCBTC Short String 1-UT' 'Y)ilmasler" Jet Pump Cavity 2.26" OD X 53" Length w/1.393" Min 1D (,~ Standing Valve Seat ~v/1.90" 10rd NU Box up X 1.90" 10rd NU Ph~ down w/2.18'OD x 1.62'ID Amchor Seal Assy to seal in standing valve 0.85" ID thru isolation sleeve E-line Set l'acker Baker Model "FA-l" Perm Packer set @ 11,275' ELM With K-22 Anchor Seal Assy 10' Seal bore Exlension on top of anchor 10' seal assy 1.375"' Min 1D thru P~ 2.765" max rtmning OD on packer · ,( Dan'taged Cavity @ 11,369' - 11,397' 2.55 tD Through Trigger Housing Assy. ,430' 2.562 ID Through 3-1/2" "R" Lm~ding Nipple Ported Balance Isolation Tool, 7,02 in2 Flow Area 12,035' - 13,632' 4-5/8" TCP, 4spf guns TOL @ 11,491' 47#, L~80, BTC @ 11,677' RKB- 55,35' ETD 13,635' Dillon DJ-18 Actual Completion, 10/23/98 Completion Equipment Proposed Equipment in Blue No. - Depth Lengt[a ID OD De_scription / t369' [ [,369' 2,992 3~50 3-1~" SCBTC 'Pog ._ 11,254' 11,254'~ L688 2.00 2" HS-80 Grade, .156" Coil Tbg, ~ 11,254' 6.86' 1-1/2' Oil Master Jet Pump Cavity Assembly 11~2_61' 3a. 11,254' l-g7' 1.875 2.553 ] Baker CT Connector, w/nydri1511 Pin do~m 11,275' With 10" seal bore extension and 10' seal _ assy on top of packer __ _...__12,031.48 Short String F-:'ERMZT "-"AC'GCC .... ~ ZI ~u i' V'i dua'i We'i I Cie ~F~i'i' ca i ....... :' ....... klatch' i a i s .l:nveF'rtor'y DATA T DATA_PLU S 9/+---.098 ~6 9a---098 ~t~7 ---098 ~F' · ---098 ~ ~4J RVE Y 9a-,-098 ~/~.c, HC/'AC/GIR/CAL 9;¢~---098 ~BHC/'AC/GIR/CAI~ 9/~ ---0,98 ~CDL/CNL/GR/CAL 9~-.'098 ~ DZFL/GR 9~--~098 ~,ZFL/GR T 20--13650 OH/FINAI_S~CH/CN R COMP DATE* 08/'12/97 0'?/22..--09/12/9h. R 0'--13730 ANADRILL L 9000-,- i3632 ~'~ L 9000--136:}2 ~ L 1000-~i1695 L O-1.S6S2 J L 0--- 1-.3632 ¢ 9z~.--098 ~2, L 5500~--.13730 9a.---098 ~BT/CN/'GR L I0~00--lS610 Ar'e dr'y di'tch sampies r'equir'ed';" yes~~d r'eceived"'? ~ Was the wei'i cor'ed? yes (2~-~'d~'iys~'s &. descr'~'p't'i'on r"ece'Y~ed? Ar'e we'l'i tests r'equi'r'ed?l~,.yes~cei'ved? ~ We'i 'i 'Y s '¥ n comp'l '¥ ance _~ I' "' "n i' t i' a 'i ,3C4,~HENTS II,L) Unocal Energy Resou, i Division Unocal Corporation 909 West 9th Avenue, RO. Box 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL DOCUMENT TRANSMITTAL Alaska November 14, 1994 TO: Larry Grant FROM: Debra Childers LOCATION: 3001 PORCUPINE DRIVE LOCATION: P.O.BOX 196247 ANCHORAGE, AK 99501 ANCHORAGE AK 99519 ALASKA OIL & GAS CONSERVATION COMM. UNOCAL .~...:::_-_-_-_-_-: ............................ ._-_._ ...... ~::.-.-_~.._*_-_ ............. ~-.-.-.-.-:-_-_-_-_-~~:~-_~-_~.-_-:------_--_-:.-_----:~---~----------. TRANSMITTING AS FOLLOWS 1 blueline and 1 sepia of each of the following .~ MGS DILLON 18 Mudlog RECEIVED DATED: Unocal Energy Resources ~ i-'~ion Unocal Corporation ' 909 West 9th Avenue, P.O. Box ~96247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL~ DOCUMENT TRANSMITTAL Alaska September 16, 1994 TO: Larry Grant FROM: Vince LeMieux 3001 PORCUPINE DRIVE ' ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMI'I-rlNG AS FOLLOWS 1 Blueline and sepia each MIDDLE GROUND SHOAL - ~"'~ SBT / GR / Neutron ~/~.~ ..-- Tape. and lis. ting./~(_¢~'~ MIDDLE GROUND SHOAL '~£C~/~ DILLON 16 oco_ FO DILLON 18 DIFL/GR2"~'5" ~Z' '"~- ,..~,,../~ SBT/GR/Ne~mn _// Ta~ and l,.,ng PL~SE AC~OWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT T~NSMI~AL TO: DEBRA CHILDERS CIO UNOCAL P.O. BOX 196247, A~CI~OP~GE, AK 99519 . .~~, //.// ~ci~v~:. -/ ////~ ~ STATE OF ALASKA ~ ALA.~ ~-~" OIL AND GAS CONSERVATION COM, ~ SION WELL COMPLETioN OR RECOMPLETION RizPORT AND LOG 1. Status of Well Classification of Service Well OIL r~ GAS ~-~ SUSPENDED{--} ABANDONED 2. Name of Operator 7. Permit Number UNION OIL COMPANY OF CALIFORNIA (UNOCAL) 94-98 3. Address 8. APl Number P.O. BOX 196247 ANCHORAGE, AK 99519 50-733-20460 4. Location of well at surface Dillon Platform, Leg #2, Slot #5 9. Unit or Lease Name ' 694' FSL & 1874' FWL Section 35, TSN, R13W, SM AtTop Producing Interval 12035' MD/9805'TVDt¢ (;07,~,:; :~':'~?'~ I ¥1r~lFfl~) 10. Well Number At Total Depth 13730' M D/' 9972' TVD i i$~r 11. Field and Pool i i~:'~!: ~ Middle Ground Shoal 4661' ESL & 2024' EEL SECTION 10, T7N, R13W, SM. E, F, & G Pools 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 127'KBI ADL 18746 12. Date07/22/94Spudded 13. Date08/31/94T. D. Reached 14. Date Comp.,09/12/94Susp. or AZ)and. 15. Water 102Depth' ifFeetOffshoreMSL 16. No. of 1 Completions 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'I'VD) 19. DirectionaJ surv?_~Vbj,i2°' Depth where SSSV set,[21' Thickness of Permafrost 13730' / 9972' 13635' / 9975' YES [~ NO NA feet MD N/A 22. Type Electric or Other I.~gs Run DIFL/BHC - AC/GR/S P/C HT/C N/S BT/SAT 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT. GRADE TOP ~ BO'i'rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 18- 5/8" 97 X-56 69' 1133' 24" 2285' cu. It. 13- 3/8" 68 K-55 68' 4118' 17-1/2" 2846' cu. lt. 9- 5/8" 47 L- 80 68' 11677' 12-1/4" 2318 cu. ft. 7" 29 L-80 11491' 13638' 8-1/2" 1107 cu.ft. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE I DEPTH SET (MD) I PACKER SET (MD) 3-1/2". 9.2#, L-80 @ 13369' (Top of Kobe BHA) 12035'-12442' MD / 9805'-9951'TVD 12483'- 12508' MD / 9957'-9960' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12564'-12892' MD/ 9964'-9972'TV DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED 12947'-13079' MD / 9974'-9977'TV 13272'-13314' MD / 9978'-9978' TV NA 13330'- 13384' MD ! 9978'-9978' TV 13566'-13632' MD / 9976'-9975' TVD 27 PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) ..N/A I Date of Test Hours Tested PRODUCTION FOP OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ......... FlowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE ............ 28. CORE DATA Brio' descripfi°n °1' 'il~h°l°gy' P°r°sity' fractures' apparent dips and presence °f °"' gas °' water' SE~c¢~=,eI~I~P~ ~/... 1[~). N/A A~3s~a 0ii & Gas Cons. Commission knch0ra¢~ Form 10-407 Submit in duplicate rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. i 30. GEOLOGIC MARKERS FORMATION TESTS ! NAME Include intervaJ teated, pressure data, all fluids recovered an¢' MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. · 31. LIST OF A'I-rACHMENTS 32. I hereby/~erlJfy~o~~ct to the best of my knowledge · · ~.~/-'/'-, . Signed G. RUSSELLSCHMIDT TrUe DRILUNG MANAGER Date 09/16/94 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report an¢ all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air inject' 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 measL given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (~ completion), so state in item 16, and in item 24 show the producing intervals for only the interval r in item 27. Submit a separate form for each additional interval to be separately produced, sho data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage ¢ lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, W jection, Gas Injection, Shut-in, Other-explain. It,'.m oR. If nn ~.nrp.~ t~k~.n, indic,~te 'none'. I KOBE Bi-lA 3 4 32' Structural @ 83' BLM 18-5/8" Surface @ 1133' · 97#, X-56, QTE60 13-3/8" Intermediate @ 4118' 68#, K-55, BTC COMPLETION DESCRIPTION 1) Dual 3-1/2", 9,2#, LB0, SCBTC 2) Kobe BHA F/11369'-11397' 3) 3-1/2' "R" landing nipple @ 11430' 4) 4-5/8' TCP guns @ 4 spf F/12035'-13632' RKB = 127' TOL @ +/-11491' 9-5/8' Production @ 11,677' 47#, L-80, BTC 13635' ETD 7" L @ 13638' 29#, L80, TKC-BTC Hemlock Perfs 12035'-12442' 12483'-12508' 12564'-12892' 12947'-13079' 13272'-13314' 13330'-13384' 13566'-13632' Refer to tubular detail of 9/9/94 for more info. DILLON 18 ACTUAL COMPLETION UNOCAL ENERGY RESOURCES ALASKA DRAWN' CLL DATE: 9-16-94 FILE: DILl 8.drw DILLON PLATFORM DILLON #18 1156'/1156' DAY 1-3 (7/22-24/94) 30" @ 270' 9.4 PPG (WBM) ACCEPT RIG AT 1900 HRS 7-22-94. NU 30" FLOW RISER. PU CENTER PUNCH BHA & RIH, TAG FILL AT 255'. DRLD 17-1/2" HOLE F/255'-367'. RUN GYRO. POOH, LAY DN BHA & MU MOTOR DRLG BHA. DRILLED 17-1/2" HOLE F/367'-1156'. POOH, MU 24" HO BHA & RIH. OPEN 17-1/2" HOLE TO 24" F/300'-1143', CBU. POOH. MU 18-5/8" WH & RIH, LAND HOUSING, OK. POOH. RU TO RIH W/CSG. DAY 4 (7/25/94) 18-5/8" @ 1132' 9.4 PPG (WBM) RIH W/18-5/8" CSG 97#, X-56. MU RUNNING TOOL & RIH W/CSG, CBU AND LAND SAME. REL RUNNING TOOL & POOH. RIH WI5" INNER STRING & PREP TO CMT 18-5/8" CSG. M&P 293 BBLS LEAD CMT AT 13 PPG FOLLOWED W/114 BBLS TAIL CMT OF 15.8 PPG. CIP 0800 HRS. POOH W/DP. ND 30" RISER & NU 20" BOP, TEST SAME. DAY 5 (7/26/94) 18-5/8" ¢___. 1132' 9.4 PPG (WBM) MU DRLG BHA. RIH, TAG TOC @ 1080' & CLOUT CMT TO 1096'. PRESS TEST CSG TO 2000 PSI F/30 MINS, OK. CLOUT CMT, FLOAT EQUIP & DRLD NEW HOLE TO 1166', CBU, PREP F/LOT. PERFORM LOT TO 15.9 PPG EMW. DRILLED 17-1/2" HOLE F/1166'-2056'. DAY 6 (7/27/94) 18-5/8" ¢__. 1132' 9.4 PPG (WBM) DRILLED 17-1/2" HOLE F/2056'-2874'. UNOCAL DILLON #18 PAGE 2 DAY 7 (7/28/94) 18-5/8" @ 1132' 9.6 PPG (WBM) DRILLED 17-1/2" HOLE F/2874'-3259'. POOH F/BHA & BIT CHG. RIH. DAY 8-10 (7/29-31/94) 18-5/8" @ 1132' 9.7 PPG (WBM) DRILLED F/3259'-3458'. DRILLED 17-1/2" HOLE F/3259'-3948'. POOH F/BIT CHG. DRILLED F/3948'-4138'. CHG RAMS TO 13-3/8". RUN 13-3/8" 68~ K-55 CSG. M&P 432 BBLS OF 12.9 PPG LEAD CMT FOLLOWED 75 BBLS OF 15.8 PPG TAIL CMT. ClP 0940 HRS 7-31-94. INSTALL CSG PACKOFF & TEST SAME, OK. ND 20-3/4" BOP & INSTALL "B" SECT OF WELLHEAD, TEST SAME, OK. NU 13-5/8" BOP. DAY 11 (8/01/94) 18-5/8" (~ 1132' 13-3/8" @ 4118' 9.7 PPG (WBM) NU 13-5/8" BOP & TEST SAME, OK. MU BI-IA. SHOE. PERFORM LOT TO 14.6 PPG EMW. F/4148'.-4684'. DRILLED FLOAT EQUIP & DRILLED 12-1/4" HOLE DAY 12 (8/02J94) 18-5/8" @ 1132' 13-3/8" ¢_, 411S' 9.4 PPG (WBM) DRILLED 12-1/4" HOLE F/4684'-5920'. DAY 13 (8/03/94) 18-5/8" @ 1132' 13-3/8" @ 4118' 9.4 PPG (WBM) R F CT_.IV SE? ;~.'l 1994 oil & 6as 6ohs. Commission DRILLED 12-1/4" HOLE F/5920'-6279'. DRILLED TO 6435'. POOH F/BIT & BHA CHG. UNOCAL DILLON #18 PAGE 3 DAY 14 (8/04/94) 18-5/8" ¢__, 1132' 13-3/8"@ 4118' 9.4 PPG (WBM) DRILLED 12-1/4" HOLE F/6435'-7340'. POOH F/BIT & BHA CHG. DAY 15-17 (8/06/94) 18-5/8" @ 1132' 13-3/8" @ 4118' 9.4 PPG (WBM DRILLED 12-1/4" HOLE F/7340'-7769'. POOH F/BIT & BHA CHG. DRILLED F/7769'- 8403'. POOH F/BIT AND BHA CHG. DAY 18 (8/08/94) 18-5/8" ¢__, 1132' 13-3/8" @ 4118' 9.4 PPG (WBM) DRILLED 12-1/4" HOLE F/8403'-.8794'. POOH F/BIT & BHA CHG. DAY 19 (8/09/94) 18-5/8" ¢___, 1132' 13-3/8" ¢__, 4118' 9.4 PPG (WBM) PERFORM BOPE TEST. MU Bi-IA & RIH. DRILLED 12-1/4" HOLE F/8794'- 8979'. DAY 20 (8/10/94) 18-5/8" @ 1132' 13-3/8"@ 4118' 9.4 PPG (WBM) DRILLED 12-1/4" HOLE F/8979'-9555'. UNOCAL DILLON #18 PAGE 4 DAY 21 (8/11/94) 18-5/8" ¢___.. 1132' 13-3/8" @ 4118' 9.4 PPG (WBM) DRILLED 12-1/4" HOLE F/9555'-9788'. POOH F/BHA & BIT CHG. RIH. DAY 22-24 (8/12-14/94) 18-5/8" ¢___, 1132' 13-3/8" @ 4118' 9.4 PPG (WBM) DRILLED 12-1/4" HOLE F/9794' - 10,386'. DRILLED F/10386' - 10780' POOH, CHG BHA & BIT. DAY 25 (8/15/94) 18-5/8" @ 1132' 13-3/8" @ 4118' 9.4 PPG (WBM) DRILLED 12-1/4" HOLE F/10780' - 10,960'. PERFORM DOPE. POOH, CHG BHA & BIT. DAY 26 (8/16/94) 18-5/8" ¢___., 1132' 13-3/8" @ 4118' 9.4 PPG (WBM) RIH, DRILLED TO 11,218' DAY 27 (8/17/94) 18-5/8" ¢____.. 1132' 13-3/8" @ 4118' 9.4 PPG (WBM) Gas Cons. Commissior~ DRILLED 12-1/4" HOLE F/11,218' - 11,336'. POOH F/BIT CHG. LAY DOWN & REPLACE HWDP & DP AS REQUIRED UNOCAL DILLON #18 PAGE 5 DAY 28 (8/17/94) 18-5/8" @ 1132' 13-3/8" @ 4118' 9.4 PPG (WBM) RIH, REAM F/11,016' - 11,310' AS REQUIRED. DRILLED F/11,336' - 11,615'. DAY 29-31 (8/19 - 21/94) 18-5/8" @ 1132' 13-3/8' @ 4118' 9.4 PPG (WBM) DRILLED TO 11,695', 9-5/8" CSG. PT. CBU. PREP F/E-LINE OH LOGS. POH. RAN CHT, CN, CDL, AC, DIFL. RIH F/WIPER RUN. CH. POH F/9/8" CASING. R&C 9-5/8" CASING AT 11,677' W/2016 SKS. TEST BOP'S. DAY 32 (8/22J94) 18-5/8" @ 1132' 13-3/8" @ 4118' 9-5/8" @ 11,676' 9.3 PPG (WBM) RIH W/BHA #18. DRILL OUT CMT. AND FIE TO 11,640'. TEST 9-5/8" CASING TO 3500 PSI/10 MIN., OK. CLEAN OUT CMT. AND DRILL NEW HOLE TO 11,705'. PERFORM LOT, EMW = 15.3 MWE. DRILL F/11,705 - 11,975'. DaY 33 (8/23/94) 18-5/8" @ 1132' 13-3/8" @ 4118' 9-5/8" @ 11,676' 9.3 PPG (WBM) DRILL F/11,975 - 12,028'. POH TO 11,676' FOR RIG REPAIRS. RECEIVED SEP 21 i99q. Alaska. 0ii & Gas Cons. Commission Anchor~_;,~ UNOCAL DILLON #18 PAGE 6 DAY 34 (8/24/94) 18-5/8" ¢__, 1132' 13-3/8"@ 4118' 9-5/8" ¢__, 11,676' 9.4 PPG (WBM) COMPLETE RIG REPAIRS. DRILL F/12,028 - 12,201'. POH FOR BIT. RIH, REAM TO BOTTON. DRILL F/12,201 - 12,207'. DAY 35 (8/25/94) 18-5/8" @ 1132' 13-3/8"@ 4118' 9-5/8" @ 11,676' 9.4 PPG (WBM) DRILL F/12,207' - 12,483'. POH F/BIT & MOTOR. DAY 36-38 (8/26 - 28/94) 18-5/8" @ 1132' 13-3/8" @ 4118' 9-5/8" @ 11,676' 9.4 PPG (WBM) RIH W/NEW BIT, MOTOR & MWD. HOLE IN GOOD SHAPE. F/12,483' - 12,908'. CBU & POH. RIH W/NEW BIT & MOTOR. F/12,908' - 13,270'. CBU & POH F/NEW BIT. DRILL DRILL DAY 39 (8/29/94) 18-5/8" @ 1132' 13-3/8" @ 4118' 9-5/8" @ 11,676' 9.4 PPG (WBM) DRILLED 8-1/2" HOLE F/13,270' - 13,515'. RECEIVED 0il & 6as Cor~s. Comrnissiorl UNOCAL DILLON #18 PAGE 7 DAY 40 (8/30/94) 18-5/8" @ 1132' 13-3/8"@ 4118' 9-5/8" @ 11,676' 9.4 PPG (WBM) DRILLED 12-1/4" HOLE F/13620'-13714'. DAY 41 (8/31/94) 18-5/8" @ 1132' 13-3/8" @ 4118' 9-5/8"@ 11,676' 9.4 PPG (WBM) DRILLED TO 13730'. STUCK BHA IN COAL SEAM F/13722'-13730'. PUMP HI-VlSC SWEEPT & JAR ON FISH W/O SUCCESS. RU WL & PREP F/STRING SHOT. RIH W/STRING SHOT TO 12460' UNABLE TO MOVE DEEPER. POOH, ADJUST S.S. ASSY * RIH TO 12596'. POOH, ADJUST S.S. ASSY AND RIH TO 13638'. PERFORM BACKOFF AT 13638'. TOF AT 13638', FISH REMAINING IN HOLE IS (MOTOPJSTAB/DC/HWDP) APPROX 92' IN LENGTH. ATTEMPT TO POOH WNVL STRING SHOT, UNABLE TO PASS THRU JARS. PULL WL OUT OF ROPE SOCKET. POOH. DAY 42 (9/01/94) 18-5/8"@ 1132' 13-3/8" @ 4118' 9-5/8"@ 11,676' 9.4 PPG (WBM) CMPT POOH W/WL, LOST STRING SHOT ASSY IN HOLE. RIH W/BHA & TAG TOF, CBU. POOH. RU ATLAS WL F/DP CONVEYED LOGGING CPS. RIH W/DIFL/BHC-ALJGR/CHT F/13632'-11335'. POOH. RECEIVED SF_-P 2 '1 i994 Ai~,ska 0il & Gas Cons. Commission UNOCAL DILLON #18 PAGE 8 DILLON #18 13635' ETD DAY 43-46 (9/02-05/94) 18-5/8"@ 1132' 13-3/8"@ 4118' 9-5/8" @ 11,676' 9.4 PPG (WBM) 7" F/11501 '-13638' RIG DN WL LOGGING. MU C/OUT BHA & RIH. CONT RIH TO 13638', CCM. POOH. RU & RIH W/7" 29# LB0 CSG & TIW HGR W/TOP PKR TO 13638'. M&P 197 BBLS OF CMT @ 15.8 PPG. BUMP PLUG WI4000 PSI Fi5 MINS, OK. CIP 1715 HRS 9-3-94. SET HANGER & LINER TOP PKR, O1( REV OUT SPACERS & 99 BBLS CMT ABOVE TOE ATTEMPT TO PRESS TEST TOL TO 3300 PSI, NEG. POOH, LAY DN EXCESS DP & TOOLS. PERFORM BOPE TEST. MU CLOUT BHA & RIH TO TOL AT 11505', CONT RIH TO LC @ 13586'. ATTEMPT TO PRESS TEST LINER LAP TO 3300 PSI, NEG. ELECT NOT TO DISPL MUD TO H20. DRILL LC & FC F/13586'-13635' DPM. ATTEMPT TO CIRC CLEAN, NEG DUE TO PRESS LOSS. POOH, FOUND BIT JET POCKETS WASHED OUT. RU ATLAS WL & RIH WISBTICNIGR VIA DP CONVEYED TOOLS. LOG F/13626'-13100', ELEC SHORT IN SYSTEM. POOH, LOCATED DAMAGED WIRE ABOVE SIDE DOOR SUB. REPAIR SAME. LOG F/13430'-10430' DPM. POOH W/WL & DP CONVEYED TOOLS. DAY 47 (9/06/94) 18-5/8" @ 1132' 13-3/8" ¢__,, 4118' 9-5/8" @ 11,676' 9.4 PPG (WBM) 7" Fi11501'-13638' CONT POOH. RU SCHLUM WL FNELOCITY SURVEY. RIH W/SAT LOGGING SYSTEM. PERFORM SURVEY F/12000'-3000' WLM W/(29) RECEIVER LOCATIONS & (11) BOAT POSITION. MU POLISH MILL & 9-5/8' CSG SCRAPER & RIH. DRESS TIE-BACK Fi11501 '-11509'. CBU. POOH. . RECEIVED SEP 2 '1 Aiaska 0il & Gas Cons. Commission Anchor~ UNOCAL DILLON #18 PAGE 9 DAY 48 (9/07/94) 18-5/8"@ 1132' 13-3/8"@ 4118' 9-5/8" @ 11,676' 9.4 PPG (WBM 7" F/11491'-13638' MU LINER TOP PKR & RIH W/SAME. SET PKR IN TIE-BACK ON TOL. PRESS TEST LINER THRU DP & BACKSIDE TO 3800 PSI Fl30 MINS, OK. POOH. MU 6" MILL & 7" CSG SCRAPER. RIH TO 13635'. DISPLACE DRLG MUD TO RIG FOLLOWED W/HI-VIS SWEEPS. DISPL RIW TO DRILL WATER FOLLOWED W/3% KCL WATER. POOH, LAY DN DP. DaY 49 (9/08/94) 18-5/8" @ 1132' 13-3/8" @ 4118' 9-5/8" @ 11,676' 9.4 PPG (WBM) 7" F/11491'-13638' LAY DN ALL 5" & 3-1/2" DP. PU & STD BK 3-1/2" COMPLETION TBG. DAY 50-52 (9/09-11/94) 18-5~8"@ 1132' 13-3/8"@ 4118' 9-5~8" @ 11,676' 9.4 PPG (WBM 7' F/11491'-13638' CMPT'D PU 3-1/2" TBG. CHG RAMS & TEST BOPE. RIH W/4-5/8" TCP GUNS, KOBE BHA & DUAL 3-1/2" TBG COMPLETION. DRIFT ALL TO 2.852 ~ & HYDRO-TEST SAME TO 5000 PSI,OK" TAG BTM AT 13635' ETD, BREAK ClRC & SPACE OUT F/TBG HANGER. LAND HANGER & TBG COMPLETION W/TCP BMT SHOT AT 13632' & TOP SHOT AT 12035'. TEST BHR SEALS TO 5000 PSI Fl30 MINS, OK. SET BPV'S & TEST TREE TO 5000 PSI, OK. INSTALL PROD. FLOWLINES AS REQ'D. DISPL ANNULUS & TBG TO PWR OIL (CRUDE). INSTALL STD VALVE & JET PUMP. PUMP DN ANNULUS FLUID LEVEL AS RECEIVED SEP 2'1 '199~[ Gas Cons. Commission Anchor~ UNOCAL DILLON #18 PAGE 10 DAY 53 (9/12/94) 18-5/8" @ 1132' 13-3/8" @ 4118' 9-5/8" @ 11,676' 9.4 PPG (WBM) 7" F/11491 '-13638' D.C. $ 25,134 CUM: $ 3,934,601 AFE $ 4,550,000 AFE #741502 DETONATE TCP GUNS AT 0135 HRS. PERF HEMLOCK AT INTERVALS; 12035'-12442', 12483'-12508', 12564'-12892', 12947'- 13079', 13272'-13314', 13330'-13384', 13556'-13632'. MONITOR WELL, FLUID LEVEL INCREASE 759' IN ONE HR. BEGIN TO PRODUCE WELL & MONITOR SAME. PREP RIG F/SHORT TERM SHUT DOWN. RELEASE R428 AT 1200 HRS 9-12-94. RECEIVED SEP 2 1 1994. 0il & 6as Cons. Oorr~mission Anchor~ :,:¢ Anadrill Schlumberger Client .... Field ..... : Well ...... : Section at: Engineer..: Units ..... : UNOCAL CORPORATION MIDDLE GROUND SHOAL DI-18 217.30 TOM DUNN FEET ~'~" C: .... 5 ~ RECORD OF SURVEY Computation...: Survey Date...: KB Elevation..: Reference ..... : Magnetic Dcln.: 09/02/94 MINIMUM CURVATURE 09/02/94 127.00 ft JOB35206/AFE~741502 22. 714 E Pg: 1 S MEAS INCLN DIRECTION C DEPTH ANGLE AZIMUTH 3 0 0.00 0.00 N 100 0.00 0.00 3 200 0.00 0.00 N 300 0.59 290.00 N 400 1.24 234.86 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RELATIVE-COORDINATES FROM-WELL-HEAD 0.0 -127.0 -0.0 0.0 N 0.0 E 100.0 -27.0 -0.0 0.0 N 0.0 E 200.0 73.0 -0.0 0.0 N 0.0 E 300.0 173.0 0.2 0.2 N 0.5 W 400.0 273.0 1.3 0.3 S 1.8 W CLOSURE DISTNCE AZIMUTH DL /lOO 0.0 0.00 0.00 0.0 0.00 0.00 0.0 0.00 0.00 0.5 290.00 0.59 1.9 261.55 1.03 N 500 1.95 220.34 499.9 372.9 4.1 2.2 S 3.8 W N 600 1.99 210.01 599.9 472.9 7.5 5.0 S 5.8 W N 700 2.00 178.94 699.8 572.8 10.6 8.2 S 6.6 W N 800 2.22 155.60 799.8 672.8 12.9 11.8 S 5.8 W N 900 2.32 144.30 899.7 772.7 14~4 15.2 S 3.8 W 4.4 240.22 0.81 7.7 229.29 0.36 10.6 218.86 1.07 13.1 206.30 0.88 15.6 194.16 0.46 N 1000 3.06 140.54 999.6 872.6 15.6 18.9 S 0.9 W N 1100 3.25 139.13 1099.4 972.4 16.8 23.1 S 2.6 E N 1200 3.54 138.51 1199.2 1072.2 18.0 27.5 S 6.5 E N 1300 1.37 154.22 1299.2 1172.2 19.1 30.9 S 9.1 E N 1400 0.34 166.33 1399.1 1272.1 19.8 32.3 S 9.7 E 18.9 182.87 0.76 23.2 173.55 0.20 28.3 166.71 0.29 32.2 163.66 2.25 33.7 163.35 1.04 N 1500 2.47 220.80 1499.1 1372.1 22.2 34.2 S 8.3 E N 1600 3.11 224.17 1599.0 1472.0 27.0 37.8 S 5.0 E N 1700 2.53 226.46 1698.9 1571.9 31.9 41.2 S 1.5 E N 1800 0.86 215.73 1798.8 1671.8 34.8 43.4 S 0.5 W N 1900 0.67 184.35 1898.8 1771.8 36.0 44.5 S 1.0 W 35.2 166.33 38.1 172.42 41.3 177.86 43.4 180.65 44.6 181.26 2.29 0.66 0.59 1.69 0.45 ^Station Types: 3/MWD N/INTERPOLATED ***Grid and magnetic corrections have been applied to these surveys*** (Anadril (c)94 DI18D B1.52 11:11 AM 3) DI-18 Page 2 09/02/94 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE N 2000 1.04 N 2100 1.74 N 2200 3.72 N 2300 6.01 N 2400 7.38 DIRECTION AZIMUTH VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RELATIVE-COORDINATES FROM-WELL-HEAD 188.83 1998.8 1871.8 37.3 46.0 S 1.2 198.84 2098.8 1971.8 39.5 48.4 S 1.8 210.66 2198.7 2071.7 44.2 52.6 S 3.9 213.60 2298.3 2171.3 52.6 59.7 S 8.5 215.23 2397.6 2270.6 64.3 69.3 S 15.1 N 2500 8.25 214.22 2496.7 2369.7 77.9 80.5 S 22.8 N 2600 9.68 211.89 2595.4 2468.4 93.4 93.6 S 31.3 N 2700 11.00 208.16 2693.8 2566.8 111.2 109.1 S 40.2 N 2800 11.93 207.66 2791.8 2664.8 130.8 126.7 S 49.5 N 2900 12.90 206.90 2889.5 2762.5 152.0 145.8 S 59.4 N 3000 14.03 207.18 2986.7 2859.7 174.9 166.5 S 70.0 W 3 3100 16.00 210.10 3083.3 2956.3 200.5 189.2 S 82.4 W N 3200 17.84 212.89 3179.0 3052.0 229.4 214.0 S 97.7 W N 3300 19.65 211.14 3273.7 3146.7 261.4 241.3 S 114.7 W N 3400 21.77 212.06 3367.2 3240.2 296.6 271.4 S 133.2 W N 3500 24.73 213.16 3459.1 3332.1 335.9 304.6 S 154.5 W N 3600 26.17 212.50 3549.4 3422.4 378.8 340.7 S 177.8 W N 3700 28.72 211.53 3638.1 3511.1 424.7 379.8 S 202.2 W N 3800 32.45 211.07 3724.2 3597.2 475.3 423.3 S 228.6 W N 3900 33.42 212.07 3808.1 3681.1 529.4 469.6 S 257.1 W N 4000 34.88 213.16 3890.9 3763.9 585.3 516.9 S 287.3 N 4100 35.78 217.50 3972.5 3845.5 643.1 564.0 S 320.8 N 4200 37.66 216.17 4052.6 3925.6 702.9 611.9 S 356.6 N 4300 39.23 214.39 4130.9 4003.9 765.0 662.7 S 392.5 N 4400 39.87 213.22 4208.0 4081.0 828.5 715.6 S 427.9 N 4500 41.43 211.49 4283.9 4156.9 893.4 770.6 S 462.8 W N 4600 42.18 209.69 4358.5 4231.5 959.6 828.0 S 496.7 W N 4700 42.18 209.06 4432.6 4305.6 1026.1 886.5 S 529.6 W ^Station Types: 3/MWD N/INTERPOLATED ***Grid and magnetic corrections have been applied to these surveys*** CLOSURE DISTNCE AZIMUTH DL /lOO 46.0 181.44 0.37 48.4 182.12 0.74 52.7 184.27 2.05 60.3 188.08 2.31 70.9 192.27 1.38 83.7 195.83 0.88 98.7 198.49 1.47 116.3 200.24 1.48 136.0 201.36 0.93 157.4 202.16 0.98 180.6 202.79 1.13 206.4 203.54 2.11 235.3 204.53 2.01 267.1 205.42 1.90 302.3 206.14 2.14 341.6 206.89 384.3 207.55 430.3 208.03 481.1 208.37 535.4 208.70 591.4 209.07 648.9 209.63 708.2 210.23 770.2 210.64 833.8 210.88 898.9 210.99 965.5 210.96 1032.7 210.86 2.99 1.48 2.58 3 . 74' 1.11 1.59 2.67 2.03 1.93 0.98 1.92 1.42 0.43 DI-18 Page 3 09/02/94 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE N 4800 42.80 N 4900 43.25 N 5000 43.58 N 5100 43.41 N 5200 43.62 DIRECTION VERTICAL-DEPTHS SECTION AZIMUTH BKB SUB-SEA DISTNCE RELATIVE-COORDINATES FROM-WELL-HEAD 208.38 4506.3 4379.3 1092.9 945.7 S 562.1 W 207.26 4579.4 4452.4 1160.2 1006.1 S 593.9 W 206.17 4652.1 4525.1 1227.8 1067.5 S 624.8 W 205.24 4724.6 4597.6 1295.2 1129.5 S 654.7 W 204.68 4797.1 4670.1 1362.5 1191.9 S 683.7 W N 5300 43.95 204.45 4869.3 4742.3 1430.0 1254.8 S 712.5 W N 5400 43.63 204.81 4941.5 4814.5 1497.5 1317.7 S 741.3 W N 5500 43.89 204.48 5013.7 4886.7 1565.0 1380.6 S 770.2 W N 5600 43.03 205.06 5086.3 4959.3 1632.1 1443.1 S 799.0 W N 5700 42.81 205.61 5159.5 5032.5 1698.7 1504.6 S 828.1 W N 5800 42.96 205.19 5232.8 5105.8 1765.3 1566.1 S 857.3 W N 5900 43.81 205.01 5305.5 5178.5 1832.5 1628.3 S 886.5 W N 6000 43.71 205.57 5377.7 5250.7 1900.1 1690.8 S 916.0 W N 6100 43.17 205.84 5450.3 5323.3 1967.5 1752.8 S 945.8 W N 6200 42.61 205.94 5523.6 5396.6 2034.2 1814.0 S 975.6 W N 6300 41.49 206.36 5597.8 5470.8 2099.9 1874.1 S 1005.1 W N 6400 40.75 206.77 5673.2 5546.2 2164.5 1932.9 S 1034.5 W N 6500 40.31 208.27 5749.2 5622.2 2228.5 1990.6 S 1064.5 W N 6600 40.43 207.91 5825.4 5698.4 2292.5 2047.7 S 1095.0 W N 6700 40.87 208.17 5901.2 5774.2 2356.8 2105.2 S 1125.6 W N 6800 40.72 209.14 5977.0 5850.0 2421.3 2162.5 S 1156.9 W N 6900 40.80 209.02 6052.7 5925.7 2486.0 2219.6 S 1188.7 W N 7000 40.69 209.68 6128.5 6001.5 2550.6 2276.5 S 1220.7 W N 7100 40.35 210.42 6204.5 6077.5 2615.1 2332.7 S 1253.2 W N 7200 40.02 210.94 6280.9 6153.9 2679.2 2388.2 S 1286.1 W N 7300 39.82 211.24 6357.6 6230.6 2743.0 2443.2 S 1319.3 W N 7400 40.63 209.83 6433.9 6306.9 2807.1 2498.8 S 1352.1 W 3 7500 39.90 210.30 6510.2 6383.2 2871.2 2554.7 S 1384.4 W ^Station Types: 3/MWD N/INTERPOLATED ***Grid and magnetic corrections have been applied to these surveys*** CLOSURE DISTNCE AZIMUTH 1100.2 210.72 1168.3 210.56 1236.9 210.34 1305.5 210.10 1374.1 209.84 1443.0 209.59 1512.0 209.36 1580.9 209.16 1649.5 208.97 1717.5 208.83 1785.4 208.70 1854.0 208.56 1923.0 208.45 1991.7 208.35 2059.7 208.27 2126.6 208.20 2192.3 208.16 2257.3 208.14 2322.1 208.14 2387.2 208.13 2452.6 208.15 2517.9 208.17 2583.1 208.20 2648.1 208.25 2712.5 208.30 2776.6 208.37 2841.1 208.42 2905.8 208.45 DL /lOO 0 .76 0.89 0.82 0.67 0 .44 0 .36 0.40 0.34 0.95 0.43 0.32 0.86 0.40 0.57 0.57 1.16 0.79 1.07 _ 0.27 0.47 0.65 0.11 0.44 0.59 0.47 0.28 1.22 0.79 DI-18 Page 4 09/02/94 RECORD OF SURVEY S MEAS INCLN DIRECTION VERTICAL-DEPTHS SECTION C DEPTH ANGLE AZIMUTH BKB SUB-SEA DISTNCE N 7600 39.18 210.72 6587.3 6460.3 2934.4 N 7700 38.37 211.62 6665.3 6538.3 2996.7 N 7800 39.94 211.22 6742.8 6615.8 3059.5 N 7900 41.18 210.81 6818.8 6691.8 3124.1 N 8000 41.27 209.54 6894.0 6767.0 3189.5 RELATIVE-COORDINATES FROM-WELL-HEAD CLOSURE DISTNCE AZIMUTH 2609.6 S 1416.8 W 2969.4 208.50 2663.2 S 1449.2 W 3031.9 208.55 2717.1 S 1482.1 W 3095.0 208.61 2772.8 S 1515.6 W 3160.0 208.66 2829.8 S 1548.7 W 3225.8 208.69 N 8100 42.18 208.86 6968.7 6841.7 3255.4 2887.9 S 1581.2 W N 8200 42.03 208.88 7042.9 6915.9 3321.7 2946.6 S 1613.5 W N 8300 42.44 207.39 7116.9 6989.9 3388.1 3005.8 S 1645.2 W N 8400 43.22 206.64 7190.2 7063.2 3455.0 3066.4 S 1676.1 W N 8500 43.16 205.42 7263.1 7136.1 3522.1 3127.9 S 1706.1 W 3292.4 208.70 3359.4 208.71 3426.7 208.69 3494.6 208.66 3563.0 208.61 DL /lOO 0.76 0.99 1.58 1.27 0.84 1.02 0.15 1.09 0.92 0.84 N 8600 43.20 205.07 7336.1 7209.1 3589.0 3189.8 S 1735.3 W N 8700 42.51 206.24 7409.4 7282.4 3655.6 3251.1 S 1764.8 W N 8800 42.21 207.37 7483.3 7356.3 3721.9 3311.2 S 1795.1 W N 8900 44.20 207.20 7556.2 7429.2 3789.3 3372.1 S 1826.5 W N 9000 45.44 205.99 7627.1 7500.1 3858.5 3435.1 S 1858.1 W 3631.3 208.55 3699.2 208.49 3766.5 208.46 3835.0 208.44 3905.4 208.41 0.24 1.05 0.82 2.00 1.50 N 9100 45.51 206.22 7697.2 7570.2 3928.5 3499.2 S 1889.4 W N 9200 45.23 205.66 7767.5 7640.5 3998.2 3563.1 S 1920.6 W N 9300 45.21 207.59 7837.9 7710.9 4068.0 3626.6 S 1952.4 W N 9400 45.87 207.00 7907.9 7780.9 4138.3 3690.0 S 1985.1 W N 9500 45.42 207.09 7977.9 7850.9 4208.6 3753.7 S 2017.6 W 3976.7 208.37 4047.8 208.32 4118.7 208.30 4190.1 208.28 4261.6 208.26 0.18 0.49 1.37 0.78 0.46 N 9600 44.63 207.92 8048.5 7921.5 4278.3 3816.5 S 2050.3 W N 9700 43.22 209.45 8120.6 7993.6 4346.9 3877.3 S 2083.6 W N 9800 42.10 210.10 8194.1 8067.1 4414.1 3936.1 S 2117.2 W N 9900 42.04 210.07 8268.3 8141.3 4480.6 3994.1 S 2150.8 W N 10000 41.53 209.71 8342.9 8215.9 4546.7 4051.9 S 2184.0 W 4332.3 208.25 4401.7 208.25 4469.4 208.28 4536.4 208.30 4603.0 208.33 0.98 1.76 1.21 0.06 0.56 N 10100 40.56 209.03 8418.3 8291.3 4611.7 4109.1 S 2216.2 W N 10200 40.05 208.17 8494.6 8367.6 4675.6 4165.9 S 2247.2 W N 10300 39.47 207.07 8571.4 8444.4 4738.7 4222.6 S 2276.8 W ^Station Types: N/INTERPOLATED ***Grid and magnetic corrections have been applied to these surveys*** 4668.7 208.34 4733.3 208.34 4797.3 208.33 1.07 0.76 0.91 DI-18 Page 5 09/02/94 RECORD OF SURVEY S MEAS INCLN DIRECTION C DEPTH ANGLE AZIMUTH N 10400 39.40 207.53 N 10500 39.75 208.73 N 10600 40.63 209.55 N 10700 41.59 209.90 N 10800 41.68 210.36 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RELATIVE-COORDINATES FROM-WELL-HEAD 8648.7 8521.7 4801.2 4279.0 S 2306.0 W 8725.8 8598.8 4864.1 4335.2 S 2336.0 W 8802.1 8675.1 4928.0 4391.5 S 2367.4 W 8877.5 8750.5 4993.2 4448.6 S 2400.0 W 8952.2 8825.2 5059.1 4506.1 S 2433.4 W N 10900 41.46 211.50 9027.0 8900.0 5125.0 4563.0 S 2467.5 W N 11000 42.99 212.35 9101.1 8974.1 5191.9 4620.0 S 2503.0 W N 11100 45.12 212.74 9173.0 9046.0 5261.2 4678.7 S 2540.4 W N 11200 45.46 212.53 9243.3 9116.3 5332.1 4738.5 S 2578.8 W N 11300 44.79 211.48 9313.9 9186.9 5402.6 4798.6 S 2616.3 W CLOSURE DISTNCE AZ IMUTH 4860.8 208.32 4924.5 208.32 4989.0 208.33 5054.8 208.35 5121.2 208.37 DL /lOO 0.30 0.84 1.03 0.99 0.32 5187.5 208.40 0.79 5254.5 208.45 1.64 5323.9 208.50 2.15 5394.8 208.56 0.38 5465.5 208.60 1.00 N 11400 45.25 211.10 9384.6 9257.6 5473.0 4859.0 S 2653.1 W N 11500 44.75 210.15 9455.3 9328.3 5543.2 4919.9 S 2689.1 W N 11600 43.64 209.14 9527.0 9400.0 5612.3 4980.5 S 2723.6 W N 11700 45.45 208.84 9598.2 9471.2 5681.7 5041.8 S 2757.6 W N 11800 49.62 209.17 9665.7 9538.7 5754.7 5106.3 S 2793.3 W 5536.2 208.63 0.53 5606.8 208.66 0.84 5676.5 208.67 1.32 5746.7 208.68 1.82 5820.4 208.68 4.18 N 11900 52.43 210.52 9728.6 9601.6 5831.7 5173.7 S 2832.0 W 5898.1 208.70 3.00 N 12000 56.94 211.52 9786.4 9659.4 5912.8 5243.6 S 2874.1 W 5979.6 208.73 4.59 N 12100 61.37 211.51 9837.7 9710.7 5998.2 5316.8 S 2918.9 W 6065.3 208.77 4.43 N 12200 66.20 212.17 9881.9 9754.9 6087.5 5393.0 S 2966.3 W 6154.9 208.81 4.87~ ) N 12300 72.13 214.12 9917.4 9790.4 6180.7 5471.2 S 3017.4 W 6248.1 208.88 6.20 N 12400 78.13 215.45 9943.1 9816.1 6277.2 5550.5 S 3072.5 W N 12500 83.81 215.91 9958.8 9831.8 6375.9 5630.7 S 3130.1 W N 12600 88.51 216.03 9965.5 9838.5 6475.6 5711.4 S 3188.7 W N 12700 89.03 218.26 9967.6 9840.6 6575.6 5791.1 S 3249.0 W N 12800 88.50 216.86 9969.7 9842.7 6675.5 5870.4 S 3310.0 W 6344.2 208.97 6442.2 209.07 6541.2 209.17 6640.3 209.29 6739.2 209.42 6.13 5.71 4.69 2.29 1.50 N 12900 87.51 216.28 9973.2 9846.2 6775.5 5950.6 S 3369.5 W N 13000 89.20 216.33 9976.1 9849.1 6875.4 6031.2 S 3428.7 W N 13100 88.89 218.78 9977.8 9850.8 6975.4 6110.4 S 3489.6 W ^Station Types: N/INTERPOLATED ***Grid and magnetic corrections have been applied to these surveys*** 6838.4 209.52 6937.6 209.62 7036.7 209.73 1.15 1.69 2.47 DI-18 Page 6 09/02/94 RECORD OF SURVEY S MEAS INCLN DIRECTION C DEPTH ANGLE AZIMUTH N 13200 89.76 218.45 N 13300 90.45 220.60 N 13400 90.04 220.29 N 13500 90.62 219.72 N 13600 91.16 220.26 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RELATIVE-COORDINATES FROM-WELL-HEAD 9978.9 9851.9 7075.3 6188.6 S 3552.0 W 9978.8 9851.8 7175.3 6265.7 S 3615.7 W 9978.3 9851.3 7275.1 6341.8 S 3680.5 W 9977.8 9850.8 7375.0 6418.4 S 3744.8 W 9976.2 9849.2 7474.9 6495.0 S 3809.1 W N 13700 91.75 220.85 9973.7 9846.7 7574.7 6570.9 S 3874.1 W 3 13730 91.80 220.90 9972.7 9845.7 7604.6 6593.6 S 3893.7 W ^Station Types: 3/MWD N/INTERPOLATED ***Grid and magnetic corrections have been applied to these surveys*** CLOSURE DISTNCE AZIMUTH DL /lOO 7135.5 209.85 0.93 7234.1 209.99 2.26 7332.4 210.13 0.51 7431.0 210.26 0.81 7529.5 210.39 0.77 7628.0 210.52 0.82 7657.5 210.56 0.25 (Anadril (m~4 DTI~D Pl ~7 11-11 AM t~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: August 31, 19994 TtlRU: FROM: Blair Wondzell, ~ P. I. Supervisor 9/7 John Spaulding¢¢~ z''/ Petroleum Insp. Monday August 29, 1994: FILE NO: AVDLH2BD.doc SUBJECT: BOP Test Pool Rig 428 Dillon Platform Uno~al I traveled to Unocal's Dillon Platform to witness the BOP Test on Pool Rig 428. The AOGCC BOP Test Report is attached for reference. As noted in the test report no failures were observed and an excellent test was performed by Pool personnel. The rig is in very good shape and was quite clean. Summary: I witnessed the BOP Test on Pool Rig 428, no failures,2.5 hour test time. Attachment: AVDLH2BD STATE OF ALASKA OIL AND GAS ~-,o=~,~,~k,,.,,.,,,,o~,,,,.,.,,~,,, COMMISSION .n.l: T,~,~, Report OPERATION: Drig: XX Orlg Contractor: Operator: We!! Name: Casing ,,,,_~.qiT-" 9- 5/8" Test: Initial Workover: Pool Rig No. 428 PTD # 94-98 Unocal Rep.: _ _ Dillon 18 Rig Rep.: Set @ 11,666' Location: Sec. 35 T. Weekly XX Other DATE: 8/28/94 Rig Ph.# 776-6687 D.o_ug Nienhous Don Byrnes 8N R. 13W Meridian Seward MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK Test Quan. Pressure P/F I 250 t3000 P 1 250/5000 P 1 250/5000 P 1 250/5000 P I 250/5000 P 2 250/5000 P I 250i5000 P N/A NtA N/A BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Methane Gas Det. OK OK H2S Detectors OK OK FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250 / 5000 P 1 25O~5OOO P 1 25O/5OOO P 1 250/5000 P CHOKE MANIFOLD: No. Valves 8 ~ No. Flanges 23 Manual Chokes 2 Hydraulic Chokes 1 Test Pressure P/F 250 / 5000 P 250/5000 P P Func~oned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 12 Ea. 11 ~2100 1 14oo YES 3000 ] P 1650 P minutes 23 sec. minutes 28 sec. Remote: YES Psig. Number of Failures 0 Test Time 3 Hours Number of valves tested 16 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: odg-Weii File c- Open/Rig c- Database c - Trip Rpt File c - Inspector F1-021L (Rev. 2/93) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: AVDLH2BD.XLS John H. Spaulding ALASKA OIL AND GAS ~ CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 22, 1994 G Russell Schmidt, AK Bus Unit Drlg Mgr Unocal P O Box 196247 Anchorage, AK 99519-6247 Re: Well # Company Permit # Surf Loc Btmhole Loc Chakachatna Dillon #18 Union Oil Company of California 94-98 694'FSL, 1874'FWL, Sec 35, T8N, R13W, SM' 617'FNL, 2120'FEL, Sec 10, T7N, R13W, SM Dear Mr Schmidt: Enclosed is the approved application for permit to ddll the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl ALAS~ STATE OF ALASKA AND C-~S CONSERVATION CC .... MISSION PERMIT TO DRILL' 20 AAC 25.005 la. Type of won< Drill [] Reddll E~ 1 lb. Type of well. Re-Entry E] Deepen i--]I Service E] Exploratory I--] Stratigraphic Test E] Development Gas I~ Single Zone Development Oil Multiple Zone 2. Name of Operator Union Oil Comapny of California (UNOCAL) 3. Address P.O. Box 196247, Anchoraqe, AK 99519-6247 4. Location of well at surface Dillon Pit. Leg #2, Slot #5 694' FSL& 1874' FWL SECT1ON 35, TSN, R13W, S.M. At top of productive interval 11738' MD / 9600' 'FVD 922' FSL& 1016' FEL SECTION 3, '17N, R13W, S.M. At total depth 13760' MD / 10127' TVD 617' FNL & 2120' FELSECTION 10, T7N, R13W, S.M. 12. Distance to nearest i 13. Distance to nearest well property line I 4600' feet I 4' @ SURFACE feet 16. To be completed for deviated wells Kickoff depth 2014 feet 90 Maximum hole anqle ' 18. Casing program size Hole !Casing 24" i 18-5/8" 17-I/2" ! 13-3/8' 12-1/4· ! 9-5/8" 8-1/2" I 7' Specifications Weight !GradeiCoupling ! Length 5. Datum Elevation (DF or KB) 127' RKB ABOVE MSL feet 6. Property Designation ADL 18746 7. Unit or property name CHAKACHATNA 8. Well number Dillon #18 9. Approximate spud date July 25, 1994 14. Number of acres in property 10. Field and Pool Middle Ground Shoals E,F & G Pool 11. Type Bond (S~.E 2o~c2~.0'~ UNITED PACIFIC INS. CO. Number U62-9269 Amount $2O0,OO0 3200 13760' / 10127' 17. Anticipated Pressure(., ~o,,~::25.~.~ Mmdmum aurface 911 psi~ At total dept~ (TVI:~ 4557 Setting Depth Top Bottom Quantity of cement MD I TVD t MD TVD , (include stage data) 97 i X56 i QTE60 I 1031 j 69 ~ K55 i BUTT i 4431 68 47 i L80 ! BU'Fi' i 11669 29 ', L80 I TKCBUTI 2260 t69 11100 measured true vertical 69 45OO 69 11738 9424 13760 I69 69 11500 15. Proposed depth feet -19. To be completed for Recldll, Re-entry, and Deepen Operations Present well condition summary Total depth: 317 feet 317 feet Plugs (measured) 1100' J 2300 cu.fl. 4267 3200 cu.ft. 9600 1200 cu.ft. 10127' 650 cu.ft. psig Effective depth: measured 317 feet true vertical 317 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Uner Perforation depth: measured true vertical Length Size 259 30' Cemented DRIVEN Measured depth 317 RKB (88' BML) True vertmat depth RECEIVED JUL '~ 5 1994 Alaska uu & Gas Cons. Commission Anchorage 20. Attachments Filing fee ~: Property plat E~ BOP Sketch~: Dive.er Sketch ~ Drilling program E~ Drilling fluid p.rogram E~: Time vs depth plot ~ Refraction analysis E] Seabed report E] 20 AAC 25.050 requirements E] 21..,;~_/.hereby O~/,, ~~correct to the best of my know,edge ~"~t~' Signed G. RUSSELL SCHMIDT Title Alaska Business Unit Ddlling Manager Date Commission Use Only Permit Number APl number IApproval date I See cover letter ? ?.-- ~ 50- ,~.~ $ -- _Z c::3 ~/g~:::3 I ?" ,& 2- -" ?~./ I for other requirements Oanditions of approval Samples required ~ Yes ~ No Mud log required I_] Yes ~ No Hydrogen sulfide measures U Yes -{~ No Directional survey requirecl ,~ Yes I--] No IRequiredworkiog pressure forBOPE I~ ~.M; ~ 3M; {~ 5M; E~ 10M; ~ 15M Other: O~ve,'~., v',,l~' ~'e~'~' ¢ ~ Original Signed By by the order of I Approved by David W Inhno~'nn Commissioner the commission Date ~//'~_ Form 10-401 Rev. 12-1-85' ............. Submit in triplicate Memorandum State of Alaska Oil and Gas Conservation Commission To: Commission Fm: J. Hartz~)~/ Subj: Unocal Request for Diverter Waiver Middle Ground Shoal Platform Dillon Well 18 July 21, 1994 Unocal has requested a waiver of diverter requirements on the subject well. They propose to drill the conductor hole to 1100' with a flow nipple then drill the surface hole to +/-4500' with a 20 3/4", 3000 psi. BOPE system. They state in their application letter that the fracture gradient anticipated at the surface and intermediate casing shoes are .80 psi/foot and the rock is competent enough to shut in the well and circulate a kick rather than divert. The fracture gradients are based on recent leak off tests done in the Cook Inlet area and Dillon wells drilled recently. I reviewed 5 wells which offset the subject well. There were no shallow gas kicks, abnormal pressure or lost circulation noted in the wells reviewed. Platform Dillon is in the southern portion of the field at the structural low point. Unocal states that there is no gas above 4500' in the vicinity of the Dillon platform based on the information available to them and after drilling Dillon 16 & 17. Regulation 20 AAC 25.035 (b) (3) and (c) (2) authorizes the Commission to waive diverter requirements if drilling experience in the near vicinity indicates a diverter system is not necessary. The same approach and arguments were the basis of the diverter waiver granted on Dillon wells 16 & 17 in April, 1994. The proposal to drill the surface hole to 1100' with a drilling nipple means there is no annular preventer to divert the well and returns go straight to the shakers and pits. For the hole sections from 1100-4500', their permit application shows a 20 3/4" BOP system with a 2000 psi annular preventer and a diverter spool which will be blinded off and not used. Unocal believes the diverter is not appropriate and would rather use positive control measures and shut in on kicks where the formation is competent. In summary, a review of AOGCC well histories on five wells in the vicinity of the 2 proposed wells indicated no shallow gas, kicks or lost circulation zones. These findings were confirmed by recent drilling at Dillon 16 & 17 according to Unocal. The section of hole drilled from the structural pipe to the conductor depth of 1100' RKB will be done without any means to divert. Hole drilled from 1100' RKB to total depth will be accomplished with BOP equipment. Recommendation: Absent shallow gas and other notable drilling problems in the vicinity of the well to be drilled, I recommend approval of the waiver of diverter requirements. If there are other circumstances which the Commission thinks would cause a need for diverter use, Unocal should be allowed to address those circumstances. Dillon Well #18 July 07, 1994 Time Est. Preliminar~ Procedure: 1 1 1 1.5 5 1. MIRU, Leg #2, Conductor #5, Install 30" flow riser system. 2. Drill 17-1/2" hole to 18-5/8" csg point of±Il00'. 3. Open hole from 17-1/2" to a 24" section. 4. Run and cement 18-5/8" casing. Install 20" BOPE. 5. Drill 17-1/2" hole to 13-3/8" csg point +4500' (ROP 700) KOP DLS Angle Range 2000' 1.75 0 -43° 2 20 1.5 1.5 6. Run and cement 13-3/8" casing. Install 13-5/8" BOP 7. Drill 12-1/4" hole to 9-5/8" csg. point (11750' MD) at the top of the Hemlock; (ROP 275') 8. Run open hole logs. 9. Run and cement 9-5/8" casing to 11750' MD. 10. Drill 8-1/2" hole to 13775' TD (ROP 225') KOP DLS Angle Range Tot. Dogleg TD 10 ±11750' 4.38 43-90° 90° ±13775' 1.5 1 2 1.5 1.5 1 1.5 1 1.5 1 11. Run open hole drill pipe conveyed logs. 12. RIH, CCH for 7" liner. 13. Run and cement 7" liner from TD to 11,500' MD. 14. Clean out inside liner. 15. Run SBT/NEU/GR log from ETD to TOC in 9-5/8" casing. 16. Change well over to 3% KCL fluid. 17. RIH with retrievable 4-5/8" TCP guns, perforate the Hemlock as required. 18. RIH with 9-5/8" packer and tubing tail assembly, set same above TOL. 19. Run dual 3-1/2" tbg completion with KOBE BHA. 20. Set BPV, Rem BOPE, Install tree and surface equipment. 21. Release Rig. 58 days total time Filename:Dill on~rocedur\dillon 18~018.doc RECEIVED JUL. 5 1994 Alaska Oil & Gas Cons. Commission Anchora~j~ Depth 0 Dillon 18 Depth vs. Days July 07, 1994 (2,000) (4,000) (6,000) (8,ooo) (10,000) (12,000) Run 18-5/8" Csg. Avg ROP 700 FPD Run13~/8"Csg. Avg ROP 275 FPD Log & Run 9-5/8" Csg. Avg ROP 225 FPD (14,000) 10 i I 20 Di 18 Est. J i J 3O 4O Days Run 7" Liner & Completion 50 60 70 Di 17 Di 16 RECEIVED JUL 1 5 1994 A~aska u~i & Gas Cons. Commission Anchorage 32" Structural @ 83' BLM 18-5/8" Surface @ 1100' 97#, X-56, QTE60 13-3/8" Intermediate @ 4500' 68#, K-55, BTC COMPLETION DESCRIPTION 1) Dual 3-1/2", 9,2#, L80, SCBTC 2) Kobe BHA 3) 3-1/2" "RA" sleeve 4) 3-1/2" "RA" sleeve 5) Otisr 3-1/2" $SSV 6) Otis "VS'P' Packer 7) 3-1/2" "R" landing nipple 8) 3-1/2" Re-entry guide 9) 1/4" SS control line RKB = 127' TOL @ +/-11500' 9-5/8" Production @ 11,750' 47#, L-80, BTC Hemlock Perfs 7" L @ 13775' k 29#, L80, TKC-BTC RECEIVED JUL. 1 $ Alaska 0ii & Gas Cons. C0mmi.~ Anchora~/~ DILLON 17 PROPOSED COMPLETION UNOCAL ENERGY RESOURCES ALASKA DRAWN' CLL DATE: 7-07-94 FILE: DILl 8.drw ;ior~ INOCA i i Structure : DILLON Platform Well : 18 iField · Middle Ground Shoals Location ' Cook Inlet, AIosko I iCreoted by : jones For: L LOHOEFER Dote plotted : 7-Jul-94 Plot Reference is 18 Version #5. Coordinates ore in feet reference slot #2-5. i True Vertical Depths ore reference wellhead. 8 1500 25O0 IO~X~O zuuiiQQ Begin SouthEast Nudge End of Build Begin Angle Drop End of Nudge KOP 3.50 7.00 10.50 14.00 17.50 21.00 24.50 28.O0 31.50 35.00 38.50 AVERAGE ANGLE 42.55 DEG End of Build & Turn 15 5/8 Csg Pt Point ~ie on IEnd of Turn End of Build iEnd of Hold End of Drop KOP ?nd of Build ITarget ~orget Target WELL PROFILE DATA MD Inc Dir 'P4D North East Beg/lO0 0 O.00 0.00 0 O 0 0.00 500 0.00 180.00 500 0 0 0.00 800 5.00 180.00 800 -8 0 1.00 1100 3.00 180,00 1099 -24 0 0.00 1400 0.00 0,00 1599 -.31 0 1,00 2014 0.00 0.00 2015 -51 0 0.00 4445 42.55 209.95 4227 -778 -450 1.75 11758 42.55 209,95 9600 -5052 -2890 0.00 S 29.77 DEG W 7704' (TO TD) *'*PLANE OF PROPOSAL**' 12557 77.97 216.26 10000 -5634 -5278 4.58 13761 10127 -6591 -3994 1.00 TARGET #1 LOCATION: 922' FSL, 1016' FEL SEC. 5, T7N, R13W Scale 1 : 200.00 4000 5600 5200 2800 2400 2000 1600 1200 800 400 0 II II II II II II II II I I I I I I RECEIVED SURFACE LOCATION: 694' FSL, 1874' FWL SEC. 55, TSN, R15W 1600 18 T/ JUL ~ $ 1994 Alaska Oil & Gas Cons. [;ommission Anchora,~¢ I IARGET #3 LOCATION: (~ ~a £~it 6-1 I 617' FNL, 2120' FEL [ SEC. 10, 'fTN, R15W Target #1 - T/ 01 / g 5/8 Csg Pt ~ - ~ Target ~3 - Exit G1 0 500 1000 15 0 2000 50 0 ~ 4 50 0 5500 6000 6500 75 0 8000 Scale 1 : 250.00 Vertical Section on 209,77 azimuth with reference 0.00 N, 0,00 E from slot #2-5 FINAL ANGLE 89.9 DEG UNOCAL DILLON Platform 18 slot #2-5 Middle Ground Shoals Cook Inlet, Alaska CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 18 Version #5 Our ref : prop960 License : Date printed : 7-Ju[-94 Date created : 4-Jan-94 Last revised : 7-Jul-94 Field is centred on n60 50 4.803,w151 29 11.941 Structure is centred on n60 44 0.841,w151 31 22.418 Slot location is n60 44 7.674,w151 30 44.728 Slot Grid coordinates are N 2463865.753, E 229321.012 Slot local coordinates are 694.00 N 1874.00 E Reference North is True North Main calculation performed with 3-D Minin~zn Distance method Object wet[path PMSS <1237-???'>,,D-16,DILLON Platform PMSS <9763-11484'>,,D17st1,D[LLON Platform PMSS <123~-10242'>,,D-17,DILLON Platform GMS <O-10508'>,,D-11,DILLON Platform MSS <1958 - 2466'>,,D-lO,DILLON Platform MSS <2020-10550'>,,D-4,DILLON Platform MSS <7122-10900J>,,D-9,DILLON Platform PGMS <O-10554'>,,D-9Rd,DILLON Platform MSS <6770 - 10401'>,,D-2,DILLON Platform PGMS <O-10304'>,,D-2Rd,DILLON Platform PGMS <1280-10000'>,,D-13,DILLON Platform MSS <7205-10537'>,,D-8,DILLON Platform PGMS <3200-10505'>,,D-SRd,DILLON Platform MSS <1930 - 10750'>,0D-7,DILLON Platform MSS <1245-10942'>,,D-6,DILLON Platform GMS <0-13133'>,,D-15,DILLON Platform PGMS <0-10500'>,,D-14,DILLON Platform MSS <2150-10500'>v,D-3,DILLON Platform MSS <0-12000'>,,D-12,DILLON Platform MSS <3407 - 11325'>,°D-5,DILLON Platform Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 7-Jul-94 7.3 200.0 11060.0 8-Jun-94 4.0 0.0 10060.0 21-May-94 4.0 0.0 9740.0 30-Mar-94 10.0 300.0 11160.0 30-Mar-94 78.8 100.0 200.0 30-Mar-94 75.5 200.0 200.0 30-Mar-94 67.7 550.0 550.0 30-Mar-94 67.7 550.0 550.0 30-Mar-94 65.9 600.0 600.0 30-Mar-94 65.9 600.0 8480.4 30-Mar-94 75.2 400.0 1720.0 30-Mar-94 10.8 100.0 10380.8 30-Mar-94 10.8 100.0 10380.8 30-Mar-94 3.3 500.0 500.0 30-Mar-94 9.7 100.0 1880.0 30-Mar-94 111.6 100.0 13250.0 30-Mar-94 86.1 2500.0 2500.0 30-Mar-94 101.2 700.0 4000.0 30-Mar-94 112.7 300.0 8260.0 30~Mar-94 106.8 1440.0 1440.0 RECEIVED ,J d I_. 1 5 1994 ~.~K. u. & Gas Cons. Comr~issiorl Anchorage 50 40 50 20 10 0 10 ?"51 O0 ~, 3300 53500 500 600 800 9O0 1000 1100 1200 1300 2100 700 800 )0 2O I 3O 9OO 1000 1 lO0 2500 RECEIVED JUL I 5 1994 Alaska Oil & Gas Cons. Commission Anchora.~r: UNOCAL Structure : DILLON Platform Well : 18 Field : Middle Ground Shoals Location : Cook Inlet, Alaska 4O 2O 10 10 2O 3O 4O 5O 6O 7O 8O 9O 450 4.00 ,350 I I I I I .300 250 200 ! I I I I I I 6500 1500 9O0 150 700 3900 100 50 I I 1500 1700 0 170( )0 1900 0 50 lO0 150 1 O0 700 tO0 4300 4500 O0 4100 3500 1500 3300 2100 2300 5100 1900 300 lO0 4700 2100 7OO 2500 450 3900 2500 2300 RECEIVED JUL ] 5 1994 Alaska Oil & Gas Cons. Commissi, Anchorage; _5OO _55O _600 700 I I 65O I 6OO I 4500 550 500 450 400 I I I I I ! I 4300 lO0 4100 5500 35O I 300 27OO 5300 I00 31 oo RECEIVED JUL 1 5 1994 Alaska Oil & (}as Cons. ~mmission Ar~ora~, 25O I 55O _ 600 _ 650 _ 700 _ 750 _ 800 _ 850 _ 900 _ 950 _1000 _1050 _1100 DEPTH CASING SIZE HOLE SIZE MUD TYPE UNOCAL DILLON PLATFORM WELL #16, #17, & 18 _+ 1,100' 18-5/8" 17-1/2" Open Hole 24" F.I.W./Generic Mud #2 Notes- ANTICIPATED MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss API pH 8.8 - 9.4 ppg 45 - 100 sec/qt 10 - 15 cps 10 - 30 #/100 ft2 8 - 20 N.C. 8.5 - 9.5 Use bentonite prehydrated in freshwater and filtered inlet water. DEPTH CASING SIZE HOLE SIZE MUD TYPE _+ 3,500' 13-3/8" 17-1/2" F.I.W./Generic Mud #2 Notes: ANTICIPATED MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels Fluid Loss API pH 9.0 - 9.6 ppg 40 - 70 sec/qt 10 - 15 cps 10 - 20 #/100 ft~ 6 - 12 N.C. 8.5 - 11.0 Treat for cement contamination. RECEIVED JUL. I ,5 1994 At~ska Ull & Gas 0ohs. Commission Anchora~ DEPTH CASING SIZE HOLE SIZE MUD TYPE i 9,800' 9-5/8" 12-1/4" F. I.W./Generic (with PHPA) Mud #2 Notes: ANTICIPATED MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels API Fluid Loss HPHT Fluid Loss 9.5 - 10.5 ppg 40 - 60 sec/qt 10 - 15 cps 10 - 25 #/100 ft~ 4 - 12 8 20 Build new PHPA Generic Mud #2. DEPTH LINER SIZE HOLE SIZE MUD TYPE _+ 11,800' 7" 8-1/2" F.I.W./Generic Mud #2 (with PHPA) Notes: ANTICIPATED MUD PROPERTIES Mud Density Funnel Viscosity Plastic Viscosity Yield Point Gels API Fluid Loss HPHT Fluid Loss 9.5 - 10.5 ppg 45 - 80 sec/qt 10 - 15 cps 15 - 30 #/100 ft2 6 - 12 5 10 Treat for cement contamination. Increase yield point and gels in horizontal section. Add lubricants for torque and drag. RECEIVED JUL 1 5 1994 Alaska Oil & Ga~ Co.s. Commission A~chorauo Rotary Kelly Bushing (RKB) Drill Deck Level Production Deck Level Elev. 127' Elev. 87' Elev. 69' Sea Level (MLW) Elev. O' Mud Line Elev. -102' 30" Structural @ 317' RKB (88' BLM) 18-5/8" Surface @ 1100' ~ 97#, X-56, QTE60 13-3/8" Intermediate @ 3500' 68#, K-55, BTC 9-5/8" Production @ 9800' 47#, L-80, BTC 7' Uner @ 11800' 29#, L-80, BTC RECEIVE JUL 1 5 199~ Alaska Oil & Gas Cons. Anchorau~ DILLON PLATFORM ELEVATION DIMENSIONS "TYPICAL" UNOCAL ENERGY RESOURCES ALASKA DRAWN: CLL DATE: 3-21-94 FILE: DILELEV.drw ~missi0n FILL- UP ~D> ~ 3"- 10M CHECK VALVE KILL LINE I ~ FLOW I MSP ANNULAR BOP 203/~'Z0001 Isi SPOOL II ~4"3ooo PlSi I I t PIPE RAMS 20a/~'' 3000 psi BLIND RAMS DIVERTER SPOOL BLIND FLANGED DURING BOP OPERATIONS 20%" 3000 psi _~ HCR I I HCR ~ MANUAL'I DRILLING I' MANUAL ~ ~ ~<'-~]~~~~~o~,3ooo p~~ CHOKEs~°°~' ~*~ v~v~ [ ~ ~~ 1~o,~, ~ooo ~ ~,~ v~v~ LINE~ RECEIVED dUL. 1 5 1994 Alaska Oil & Gas Cons, Commission Anchora~ I I RISER 20 ~/,~'' 3000 psi CHAKACHATNA RIG 428 BOP/DIYERTER STACK 21 %1' 2000psi/20%~' 3000psi FILL- UP ~> 6 3"- 10M CHECK VALVE KILL LINE ANNULAR BOP 135/s"5000 psi PIPE RAMS 135/~'',5000 psi BLIND RAMS FLOW, 135/~"5000 psi HCR HCR MANUAL DRILLING MANUAL SPOOL --~-~1~ '~11~~%'5ooo ps~ ~[2J..~~-~ CHOKE 3,,_10M///'/ ['] , 1%~4"-10M GATE VALVES [ PIPE RAMS ]GATE VALVES135/I'5000 psi I RISER 13 ~" 5000 psi RECEIVED ,JUL '~ 5 1994 Alaska 0ii & 6as Cons. Commissior, Anchorau~ CHAKACHATNA RIG 428 BOPE STACK 13 %" 5000 psi g~t ~t Wd ~S~V Ol&O~V ' I ~..~ 39~01S GO~ ~ ~00 ~SOS ~80~d ~08~ / 01 3Nh ~ d~d 00~ I ~ gl 0~-~ I I I 3069~10510 S~NILb~3 bl~ddOH O[lPl 83GN~L~O~ OOg-S bL?,2,NOM r ............................................. ?-' .......................... ~. I I I I I r ' -- "x i r- ....................... -gd/t~fl-- " 30fl.~lltlJ~O 30fltl81100 (i~ ~ ]88 Og 308~10S10 'S300~S 3NI1 ~?J82Nfl O! ONIN~I83d ¥~15v-I¥ OIJ. OUV -lOOd V- V ~5IIA i i, PLAN VIEW ON SOUTHWEST LUG VIEW A-A ISSUED lv1,!',i-I ;2 4 1994 POOL ARCTIC ALA~ ~:~ PLAN VIEW - TYP. 130TI[ EAST [,ECS SHOWN ON NORTHEAST LEG FOR INFOI~A l'lU~ "~ ONLY iSSUED hb\R 2 4 1994 POOL ^RCTIC ALASKA lg'-g':4" V6~S 5'-0';1T-0' W~S 14'-6';1~'-7 11J1ff';I I 18'-3 1'¥1r ~ la'-O §/16' I UOC PLkTTOR~ ~ DILLK)N, PM RK} 4.28 R£C£1v£D JU[? 5 ~994 !aska Off & Gas Cons. Cor~mission AnChora~ VENT OUTSIDE OF WlNDWALLS ,~" PANIC LINE 4' 5,000 PSI BALL 4 ~/~-~ ac. 5M TARGET BLIND HUB t5 c~wP ~/ Bx!~5 E 3' RELI~ SET AT 40 PSI 10' VENT LINE BLIND HUB EIUJS ADJ. CLAYP HUB CONNECTION BUFFER TANK 10, 000 PSI HYD. CHOKE TO PRODUCTION SEPARATOR 1o" 15o lb. BUNO FL~E ff~.] 10' 150 lb. FLANGE MUD SEI:'E'RATOR SIPHON LINE 150 ~. FLANGE --I TO MUD RETURN UNE UNOCAL CFtOKE t,L~IIFOLfl COOK INLET DWC. 04-1:12592 CASING DESIGN WELL: DILLON ~18 1. MUD WT. I 8.8 PPG 2. 9.4 PPG 3. 9.3 PPG FIELD: MIDDLE GROUND SHOAL DATE: JULY 07, 1994 WEIGHT TENSION MINIMUM W/ BF -TOP OF STRENGTH -- INTERVAL DESCRIPTION W/O BF X SECTION TENSION -- CASING SIZE BOTTOM TOP LENGTH WT. GRADE THREAD LBS LBS 1000 LBS 1. 18-5/8" 1100' 69' MD 1031 97#, X-56, QTE 60 100,000 SAME 1594 1100' 69' TVD 2. 13-3/8" 4500' 69, MD 4431' 68#, K-55, BTC 301,308 SAME 1069 4267' 69' TVD 3. 9-5/8" 11738' 69' MD 11669' 47#, L-80, BTC 548,443 SAME 1086 9600' 69' TVD 4. 7" 13760' 11500' MD 2260' 29~, L-80, BTC 65,540 SAME 676 10127' 9429' MD TDF 15.94 DESIGN BY: COLLAPSE PRESS @ BOTTOM PSI* C.L. LOHOEFER M.S.P. 385 psi 792 psi 911 psi COLLAPSE RESIST. BURST MINIMUM TENSION PRESSURE YIELD PS__I CDF PSI** PSI 315 960 3.05 960 2630 3.55 1220 1.98 2746 10.40 2896 1950 1.60 2160 3450 4750 1.73 2279 6870 BD__F 2.74 1.59 3.01 7020 2.42 2279 8160 3.58 NOTES: See attached for calculation of M.S.P. including assumptions & estimates. * Collapse Pressure is calculated; Differance between w/two cmt slurries (i.e. Avg of a 15.8 ppg (tail) & 12 ppg (lead) = 14 ppg, subtract a mud of 9.5 ppg = 5.5 ppg = .286 psi/ft, gradient x TVD of the csg string). ** Burst pressure is calculated; (BHP @ depth next csg x TVD next csg) x (0.5 half evacuated). RECEIVED ~mska Oil & Gas Cons, Anchora(~¢ Well # Date Baker Platform Ba 28 10-10-93 Ba 30 10-24-93 Ba 30 10-28-93 Ba 28 11-17-93 Ba 29 12-17-94 Ba 29 12-29-93 Ba 30 01-27-94 Ba 28 03-01-94 Grayling Platform G-40 01-24-90 G-40 Monopod Platform A-ltd 04-04-91 A-8rd 07-01-89 A-20rd 03-30-90 A-20rd 04-13-90 A-28rd 11-20-89 A-28rd 11-27-89 Granite Point Platform 11-13rd 02-14-92 51 08-07-92 51 O7-28-92 51 08-25-92 50 05-27-92 50 06-04-92 50 06-27-92 Dillon Platform Leak Off Test (LOT) Data Cook Inlet, Alaska Unocal Energy Resources Alaska Csg Size Shoe Depth (TVD) Frac Grad. (osi/ft.) EMW 24" 802' 0.94 18.10 24" 803' 0.83 15.90 18-5/8" 2011' 0.94 18.10 18-5/8" 2135' 0.75 14.50 18 -5/8" 2054' 0.76 14.61 13-3/8" 5869' 0.85 16.33 13-3/8" 5467' 0.93 17.96 13-3/8" 3509' 0.75 14.40 16" 1926' 0.96 18.46 13 -3/8" 4977' 0.86 16.54 9-5/8" 1132' 1.07 20.57 9-5/8" 3760' 1.02 19.61 13-3/8" 755' 0.95 18.20 9-5/8" 1931' 0.85 16.30 20" 240' 0.75 14.42 13-3/8" 1140' 0.97 18.65 9-5/8" 9966' 0.96 18.40 13-3/8" 3803' 1.00 19.20 18-5/8" 1010' 0.87 16.80 9-5/8" 9592' 1.05 20.20 18-5/8" 982' 0.91 17.50 13-3/8" 4208' 0.84 16.20 9-5/8" 9877' 0.93 17.90 16 04-22-94 18-5/8" 1131' 16 06-16-94 13 -3/8" 3640' 16 07-04-94 9-5/8" 9469' 17 04-27-94 18-5/8" 1142' 17 05-01-94 13-3/8" 3560' 17 05- 9-5/8" 921Y 1.12 0.82 NA 1.01 0.83 NA FIT-Formation Integrity Test Filename AOGCC~Lotdata. doc 21.72 15.80 14.2 (FIT) 19.47 15.90 16.5 (FIT) R £CF..!¥ F-D JUL '~ 5 1994 &~aska oil & Gas Cons. Commission Anchorage, Dillon Platform Well # 18 South Middle Ground Shoals (SMGS) July 7, 1994 Hole Section 1 Depth Interval: 0 - 1100' 17-1/2" & 24" hole size 18-5/8" casing to 1100' Mud Weight: Shoe depth (18-5/8"): Est. fracture gradient of 18-5/8" shoe: BlIP gradient: 8.8 ppg = 0.46 psi/ft. 1100' MD / 1100' TVD 0.90 psi/ft. 0.35 psi/ft The maximum surface pressure cannot exceed the maximum bottom hole pressure; MSP = 1100' x 0.35 psi/fi. = 385 psi Hole Section 2 Depth Interval: 1100' - 4500' 17-1/2" hole size 13-3/8" casing to 4500' Mud Weight: Shoe depth (13-3/8"): Est. fracture gradient of 13-3/8" shoe: Depth of next hole section (12-1/4"): BI-IP gradient: Gas gradient (assume worst case) 9.4 ppg = 0.49 psi/ft. 4500' MD / 4267' TVD 0.80 psi/ft. 11738' MD / 9600' TVD 0.45 psi/ft 0.0 psi/ft. Gas kick situation in the wellbore, assume; 3/4 mud & 1/4 gas. MSP = BlIP - Hydrostatic Pressure MSP = BlIP - (3/4 mud + 1/4 gas) MSP = (9600' x 0.45 psi/R) - ((0.75 (9600' x 0.49 psi/fi)) + (0.25 (9600' x 0.0 psi/ft.))) MSP = 792 psi Therefore, the hydrostatic pressure at the 13-3/8" shoe (HPsh) is the greatest when the gas (kick) bubble reaches the 13-3/8" shoe, if a constant BlIP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 13-3/8" casing depth (HPcsg). HPsh = MSP + HPcsg HPsh = 792 + (4267' x 0.49) HPsh = 2882 psi This (HPsh = 2882 psi) is less than thc fracture pressure at the same shoe (FPsh) and thus adequate to handle thc well kick scenario. HPsh= 2882 psi < FPsh = 0.80 psi/ft x 4267' ='3414 psi. R [ C ~ IV ~ D dUL 5 1994 Alaska Oil & Gas Cons. Commission Anchors[jo Dillon Platform Well #18 Pressure Calculations Hole Section 3 Depth Interval: 4500'- 11738' 12-1/4" hole size 9-5/8" casing to 11738' Mud Weight: Shoe depth (9-5/8"): Est. fracture gradient of 9-5/8" shoe: Depth of next hole section (8-1/2"): BHP gradient: Gas gradient (assume worst case) 9.3 ppg = 0.48 psi/fl. 11738' MD / 9600' TVD 0.85 psi/fi. 13760' MD / 10127' TVD 0.45 psi/fi 0.0 psi/ft. Gas kick situation in the wellbore, assume; 3/4 mud & 1/4 gas. MSP = BlIP - Hydrostatic Pressure MSP = BHP - (3/4 mud + 1/4 gas) MSP = (10127' x 0.45 psi/fi) - ((0.75 (10127' x 0.48 psi/fi)) + (0.25 (10127' x 0.0 psi/ft.))) MSP = 911 psi Therefore, the hydrostatic pressure at the 9-5/8" shoe (HPsh) is the greatest when the gas (kick) bubble reaches the 9-5/8" shoe, ifa constant BI-IP is applied. A conservative estimate would be the MSP plus the hydrostatic pressure at the 9-5/8" casing depth (HPcsg). HPsh = MSP + HPcsg HPsh = 911 + (9600' x 0.48 psi/fi) HPsh = 5519 psi This (HPsh = 5519 psi) is less than the fracture pressure at the same shoe (FPsh) and thus adequate to handle the well kick scenario. HPsh = 5519 psi < FPsh = 0.85 psi/fi x 9600' = 8160 psi. Additionally, HPsh - Pore Pressure at shoe < Internal Yield of the 9-5/8" casing 5519 - (9600' x 0.45 psi/ft) < 6870 psi 1199 psi < 6870 psi Filename:AOGCC~Dil 8calc. doc RECEIVED JUL 1 5 1994 Alaska Oil & Gas Cons. Commission Anchora~j~ Unocal North American Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region July 7, 1994 Mr. David JohnSon Commissioner Alaska Oil & Gas Conservation Commissioner 3001 Porcupine Drive Anchorage, AK. 99501-3192 Dear Mr. Johnston: Please find enclosed applications for a Permit to Drill (Form 10-401) for the Dillon Platform well #18. The timing to spud this well is approximately late July upon completion of the current well Dillon #16. As part of this continued development drilling program UNOCAL is again requesting that the AOGCC waive the diverter system requirement on both the (30") structural and (18-5/8") surface casing strings for this well. This waiver request is identical to our April 1994 request for wells #16, & 17 at the Dillon Platform which was subsequently approved by the AOGCC. As outlined in the well procedure, UNOCAL is intending to drill out the 30" structural casing to +1100' with a flow nipple then install a 20-3/4" 3M BOPE stack on the 18-5/8" casing that will be cemented at +1100' to surface. The 18-5/8" casing will then be drilled out to a depth of +4500' and 13-3/8" intermediate casing will be cemented from that depth to surface. UNOCAL has selected thc casing points for thc 18-5/8" at +1100' and the 13-3/8" at +4500' to be areas of competent formations. No gas bearing zones are evident above +4500', based on offset well data from Dillon #16 & 17. It is anticipated that the minimum formation fracture gradients at both shoe depths to be 0.80 psi/ft. UNOCAL's recent experience in the Middle Ground Shoals Field at the Baker Platform and elsewhere in the Cook Inlet (see Leak Off Test Data) has demonstrated tree fracture gradients ranging from 0.75 - 0.94 psi/ft. In both wells at Dillon the maximum surface pressure 0VISP) expected while drilling below the 18-5/8" surface casing will be far less than the anticipated fracture pressures. Since the casing shoes will not break down in a well kick situation and the setting depths are in competent formations, UNOCAL believes these are prudent casing designs and warranted operations. Mr. David Johnston July 7, 1994 Page - 2 UNOCAL plans to complete Dillon #18 with a hydraulic pumping completion that includes a downhole packer and safety valve; this well is expected to require artificial li~ for production of oil reserves. Additionally, hydrogen sulfide gas is known to be produced in existing wells at Dillon. Drilling operations at Dillon will be conducted in compliance to AOGCC regulation 20 AAC 25.065 and API RP 49. If you should have any questions regarding these permits please contact C. Lee Lohoefer (Senior Drilling Engineer) assigned to this project at 263-7642. Thank you for your attention to these matters. Sincerely, G. Russell Schmidt Drilling Manager CLL/cll enclosure: Filename:AOGCC~Dil8waiv. doc RECEIVED JUL 1,5 1994 Alaska Oil & ~las Cons. Commission Anchorage Unocal MGS Dillon - 18 IWELL PERMIT WORK SHEET IINPUT AREA hole csg csg csg size size wt. grd 7/21/94 csg csg top top bot t&c Igth md tvd md UMGSDI18.XLS bot design mud tvd cmt, cfr grd, ppg 24 18.625 97 x56 ~e60 1031 69 69 1100 1100 2300 8.8 17.5 13.375 68 k55 btc 4431 69 69 4500 4267 3200 9.4 12.25 9.625 47 180 btc 11669 69 69 11738 9600 1200 10.5 8.5 7 29 180 tk~c 2260 11500 9424 13760 10127 650 10.5 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I Input Pressure/Depth Max bhp, psiI 4557 I tvd, ft I 10127 I grd.,psi/ft 0.36 default 0.10 I csg csg csg csg size wt. grd t&c 18.625 97 x56 ~e60 13.375 68 k55 btc 9.625 47 180 btc 7 29 180 tkbtc Input Csg Paramenters coll. burst yeild pres. pres. stgth 860 1970 1928 1950 3450 1069 4750 6870 1122 7030 8160 718 Design Factors Using Various Assumptions I I. Worst Case Design: Evacuated Pipe/Evacuated Annulus + 100K# overpull max coll. max burst wt yield csg coll. mud design burst fm design yeild of csg design size pres. press factor pres. press factor stgth +100k# factor 18,625 860 503 1.7 1970 495 4.0 1928 200 9.6 13.375 1950 2086 0.9 3450 1920 1.8 1069 401 2.7 9.625 4750 5242 0.9 6870 4320 1.6 1122 648 1.7 7 7030 5529 1.3 8160 4557 1.8 718 166 4.3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 II. Practical Case · Formation Pressure at Shoe- gas to surface w/mud in or outside casing. No overpull mud coll. max(res) burst ax(mud burst wt yield csg coll. less gas design burst surface design surface design yeild of csg design size pres. press factor pres. press factor press factor stgth +0k# factor 18.625 860 393 2.2 1970 911 2.2 493 4.0 1928 100 19.3 13.375 1950 1659 1.2 3450 911 3.8 1926 1.8 1069 301 3.5 9.625 4750 4282 1.1 6870 911 7.5 4383 1.6 1122 548 2.0 7 7030 4517 1.6 8160 911 9.0 4578 1.8 718 66 11.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 II1. Cement Volumes and Heights Surf csg Surf csg csg csg ann cmt ht of csg/Inr top of w.r.t. Est'd cmt cmt size shoe vol,cft vol,cfi cmt length cmt g.I. Fillup collapsel collapse 18.625 1100 1288 2300 1841 1031 741 above 1.8 diff'l prescdf 13.375 4500 3078 3200 4607 4431 107 above 1.0 na na 9.625 11738 3654 1200 3832 11669 -7906 below 0.3 7 13760 287 650 5126 2260 -8634 below 2.3 0 0 0 0 0 0 0 0 Page 1 WELL PERMIT CHECKLIST UNIT# PROGRAM: exp [] dev ~ redrll [] serv [] ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. . 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. . 13. Can permit be approved before 15-day wait ....... ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... .~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate ........... Y 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~d~~psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... Y 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY APPR 30. Permit can be issued w/o hydrogen sulfide measures...~/NN~Y}Y ~ ~ ~ 31. Data presented on potential overpressure zones ..... ~Y N 32. Seismic analysis 9f shallow gas zones .......... ~ ~ 33. Seabed condition survey (if off-shore) ......... 34. Contact name/phone for weekly progress reports .... [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: ! Comments/Instructions: u,",~Vnn. A:~FORMS~:heklist rev 03/94 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 APPENDIX. No special effort has been made to chronologically organize this category of information. UNOGAL ,, DILLON 18 RECEIVED MIDDLE GROUND SHC_A~ 5 1994 Alaska 0il & Gas Cons. Commission KENAI ~chora~.~ ALASKA LOGGED: RUN 1 - 19 AUGUST 1994 RUN 2- 01 SEPTEMBER 1994 RUN 3- 05 SEPTEMBER 1994 RUN 1 & 2 OPEN HOLE RUN 3 CASED HOLE CN LIBRARY TAPE LISTING ATLAS WIRELINE SERVICES Anchorage, Mi'CIiOFILMED Tape Subfile 2 is type: LIS **** FILE HEADER **** .000 1024 CN : UNOCAL WN : DILLON #18 FN : M.G.S. COUN : KENAI STAT : ALASKA LIS COMMENT RECORD(s) : OPEN HOLE RUN 1 & RUN 2 DATA SPLICED AS FOLLOWS: DIFL @ 11682 GR @ 11650 BHC/AC @ 11660 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 AC AC 68 1 US/F 2 CAL AC 68 1 IN 3 CHT AC 68 1 LB 4 SPD AC 68 1 F/MN 5 TTEN AC 68 1 LB 6 GR AC 68 1 GAPI 7 RFOC DIFL 68 1 OHMM 8 RILD DIFL 68 1 OHMM 9 RILM DIFL 68 1 OHMM 10 SP DIFL 68 1 MV 11 CN 2435 68 1 PU-L 12 CNC 2435 68 1 PU-S 13 CNCF 2435 68 1 PU-S 14 LSN 2435 68 1 CPS 15 SSN 2435 68 1 -CPS 16 CORR CDL 68 1 G/C3 17 DEN CDL 68 1 G/C3 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 48 852 89 1 4 94 885 22 5 4 95 558 30 1 4 61 094 30 1 4 95 558 30 1 4 06 969 49 6 4 27 515 24 6 4 04 903 06 0 4 06 213 78 0 4 53 419 67 0 4 52 326 75 5 4 98 211 23 1 4 98 211 23 1 4 84 023 70 1 4 83 368 34 1 4 34 168 75 6 4 59 047 24 5 * DATA RECORD (TYPE# 0) 1014 BYTES * 68 Total Data Records: 3906 Tape File Start Depth = 13650.000000 Tape File End Depth = -20.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 984259 datums Tape Subfile: 2 3911 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS **** FILE HEADER **** .001 1024 CN WN FN COUN STAT : UNOCAL : DILLON ~18 : M.G.S. : KENAI : ALASKA LIS COMMENT RECORD(s): CASED HOLE RUN 3 CN DATA SPLICED AS FOLLOWS: 11495 13100 13450 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 CCL 2435 68 1 4 2 CN 2435 68 1 PU-L 4 3 CNC 2435 68 1 PU-S 4 4 CNCF 2435 68 1 PU-S 4 5 GR 2435 68 1 GAPI 4 6 LSN 2435 68 1 CPS 4 7 SSN 2435 68 1 CPS 4 8 SPD 2435 68 1 F/MN 4 9 TEN 2435 68 1 LB 4 4 90 640 78 6 4 52 326 75 5 4 98 211 23 1 4 98 211 23 1 4 08 501 10 0 4 84 023 70 1 4 83 368 34 1 4 54 376 29 5 4 19 912 29 5 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 522 36 Tape File Start Depth = 13630.000000 Tape File End Depth = 10370.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 130411 datums- Tape Subfile: 3 527 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes