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Home My WebLink About167-052David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/22/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221122 Log Print Files and Log Data Files: Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-14B 50133205390200 222057 11/5/2022 Yellowjacket SCBL HVB-16A 50231200400100 222070 7/30/2022 Yellowjacket SCBL NCI B-03A 50883200950100 222048 9/22/2022 AK E-Line CBL PAXTON 6 50133207070000 222054 7/23/2022 AK E-Line CBL S MGS Unit 6 (DI-06) 50733200420000 167052 10/6/2022 AK E-Line CBL SRU 12-15 50133101380000 160022 09/25/2022 AK E-Line CBL Please include current contact information if different from above. By Meredith Guhl at 12:59 pm, Nov 22, 2022 T37288 T37289 T37290 T37291 T37292 T37293 S MGS Unit 6 (DI-06)50733200420000 167052 10/6/2022 AK E-Line CBL Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.22 13:28:54 -09'00' 1a. 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 92 (ft MSL) 22.Logs Obtained: N/A 23. BOTTOM 33"258 20" B 601 13-3/8" J-55 2,019 9-5/8" N-80 10,519 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 18152-7/8" BOTTOM Surf 40#, 43.5#, 47# Surf Surf 602 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp Alaska, LLC WAG Gas 10/9/2022 167-052 / 322-411 & 322-549 50-733-20042-00-00 S MGS Unit 06 ADL0018746 693' FSL, 1870' FWL, Sec 35, T8N, R13W, SM, AK 913' FSL, 1518' FWL, Sec 35, T8N, R13W, SM, AK N/A 9/20/1967 10,942 / 10,931 Surface 100 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 229315.9815 2463865.048 N/A CASING WT. PER FT.GRADE 10/26/1967 CEMENTING RECORD N/A N/A SETTING DEPTH TVD 2464092.9059 TOP HOLE SIZE AMOUNT PULLED N/A 228969.5483 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 Surf Surf Per 20 AAC 25.283 (i)(2) attach electronic information 54.5# & 61# 10,530 Surf Surf 85# 259 Surf 2,020 SIZE DEPTH SET (MD) N/A PACKER SET (MD/TVD) Flow Tubing N/A N/A Gas-Oil Ratio:Choke Size: Sr Res EngSr Pet GeoSr Pet Eng Middle Ground Shoal / E,F and G Oil, Middle Grnd Shoal Oil N/A Oil-Bbl: Water-Bbl: Water-Bbl: PRODUCTION TEST N/A Date of Test: Oil-Bbl: Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment By James Brooks at 2:48 pm, Oct 27, 2022 Abandoned 10/9/2022 JSB RBDMS JSB 110722 xGBJM 11/9/23 SFD 11/15/2022 DSR-11/10/22 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 Manger 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: 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. 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 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. Authorized Title: 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. 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. 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). Authorized Name and INSTRUCTIONS 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. 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), ou=Users Date: 2022.10.27 13:37:08 -08'00' Dan Marlowe (1267) Top perf 5,672’ Zone Top Btm ft / SPF Date Gas 5,672' 8,962' G-1 thru G-4 9,240' 9,830 4 Isolated Comments Isolated Size Type Wt/Grade/Conn I.D. Top Shoe Cmt sx TOC 33" Structural Surf 259' Drive n/a 20" Conductor 85# "B" 19.186" calc Surf 602' 1,250 sx calc. surf 13-3/8" Surface 54.5 & 61# J-55 12.459" Surf 2,020' 1,200 sx 22' MD 9-5/8" Intermediate 40,43.5,47#, N-80,butt&BTC 8.755" Surf 10,530' 1,550 sx Calc 7,883' 20” shoe 602’ PBTD = 10,215’ MD & 10,204’ TVD TD = 10,942’ MD & 10,930’ TVD Max Hole angle = 5.0Û @ 10,006’ MD MSL 102’ 118’ 34’RKB - Tbg Hgr Calc TOC = 7,883’ SCHEMATIC Lease: SMGS 18746 Well: Di-06 API #: 50-733-20042-00 PTD: 167-052 Leg 2, Slot 8Casing Detail Completion Jewelry Detail –2-7/8”, 6.4#, L-80 item # Length I.D. O.D. 1 1.5'? 2.992" 2 .4' 2.441" 3 1,815' 2.441" 42,016' 2-7/8" tubing 9-5/8" Retainer 3-1/2" 8rd tubing hanger 3-1/2" x 2-7/8" XO TOC is marked on a CBT as 8,556' Description Fish & other in the hole: Perforations: JLL 10-27-22 13-3/8” shoe 2,020’ @ 2϶ Item Depth Length O.D. Description A +/- 1,913' ELM +/- 14' Starguide stinger B +/- 2,041' Retainer and TCP guns C +/- 2,601' 2,934' 2-7/8" Tubing D 10' 1-1/2" Cemented in drop bar Retainer 10,480’ Btm perf 9,810’ Retainer 5,750’ 2 3 1 Open hole to 10,942’ Retainer 10,141’ Milled Retainer 10,137’ Retainer 9,115’ TOC 8,556’CBT 9-5/8” shoe 10,530’ 8/2011 – Well circulated with 9.8 ppg KWF. Well Dead. Confirmed communication between 9-5/8, 13-3/8”, and 20” @ 34’ MD. TbgCmt tag @ 430’ SLM Top perf 2,054’ ELM 2-7/8” Tubing 1,815’ ELM TOC 1,918’ ELM TOC 5,535’ A 4 B C D Cement Plug #2: OOA: Cemented to 22’ MD, squeezed from 400’ MD to surface OA: 400’ MD to surface Tubing: 400’ MD to surface Cement Plug #1: IA: 1815’ MD to 150’ MD (TOC 36’ above Mudline via CBL of 10/6/22) Tubing: 1815’ MD to 430’SLM Rig Start Date End Date HCU 8/6/22 10/9/22 PJSM fill out permits, rig up slick line, testing lubricator to 250 low and 3000 psi hi. RIH with 2.25 gauge ring tagging at 136 ft. slm work gauge to 250', pooh make up a 2.25 drive down bailer. RIH work bailer from 250' slm to 266' pooh, bailer full had soft contaminated cmt. RIH with 2.25 DD bailer work bailer from 266 to 277 ft. pooh, no recovery flapper broken. RIH with 2.25 DD bailer, work bailer to 276 ft. pooh. Bailer full had 2 cups of soft contaminated cmt. Make up 1-3/4 bailer and load lubricator. Secure well for night. Cleaning well bays and making repair on HOWCO valves. 09/13/22- Tuesday IFO PJSM RIH with 1.75 x 4 ft DD bailer to 271' slm, work to 273 ft. Wire damage by jumping sheave, repair, had full bailer, soft grey cmt, and 6 cup of chuck of solids. Cut and test line ( 21,22) 350' of wire, Rerun 1-3/4 bailer to 273' slm, work to 273' pooh with 3/4 full, slurry and solids. Make up and RIH with 2.25 x 4' DD bailer to 273 ft worked to 276 ft. pooh with 1/2 full bailer of soft cmt and chunks of solid. RIH with 1.75 DD bailer to 275 ft worked to 278 ft. slm, pooh with full bailer with soft cmt and hard chunks. RIH with 2.25 DD bailer to 277' slm worked to 280 slm, got stuck, work free, pooh had 3/4 full bailer soft cmt and 1/4 full of firm cmt. RIH w/ 1.75 DD bailer to 280 ft. worked to 283'. Pooh bailer 1/2 full of solids and 1/2 full of soft cmt. RIH with 2.25 DD bailer to 280' slm got stuck, work free, pooh. RIH with 3/4 full of solids & soft cmt. RIH with 2.24 gauge ring to 280 ft. worked to 284 ft. pooh. RIH with 2.25 DD bailer to 283 ft. slm worked bailer to 285' pooh with solids and soft cmt, solids getting harder. Rerun 2.22 bailer to 285 slm worked bailer to 286 ft. slm, POOH bailer 1/2 full of chunky solids. Make up and RIH with 2.25 star bit to 286' slm worked to 289 ft. pooh. RIH with 2.25 BB bailer to 286 ft. slm worked to 288 ft. pooh with bailer, had 1/4 bailer of hard solids. Lay down lubricator and cut 30 ft. of damage wire ( test at (21.22) prep to move to DI 11 well. 09/12/22 - Monday 08/31/2022 - Wednesday Ak E-line crew arrived, orientate crew and PTW. Service check EL unit. R/u EL, re-head and assembly tool string. SDFN 09/01/2022 - Thursday Held PJSM, approve PTW Service and warmed eq. M/u wt/b, ccl and 6' puncher loaded w/production shots, RIH w/2" puncher and tag @ 250', could not work thru, POOH. L/d gun. RIH w/1.69' ccl and tagged hard @ 250'. POOH, L/d tools. Estimated TOC @ 600'. 08/06/22 - Saturday R/U circulating lines to tubing & IA, check pressures T 70, IA 0, OA 0, fluid pack well. PJSM, fill lines from HCU, PT lines 700/2700 good. Pump 10 bbls Pre flush, mix and pump 118 bbls (425 sx) 14 PPG CMT @ 5bpm, 500-760psi, holding 200 psi back pressure. Launch wiper ball, chase with 3.5bbls 9.8 Brine. Shut down, monitor & check pressures, T 0, IA 0, OA 0. R/U pump 10 bbls FIW down IA out OA, good. Shut down pressure 0. Shut in well, cleanup CMT unit & r/d. Prep for loadout to boat for Rig 169 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 06 50-733-20042-00-00 167-052 Rig Start Date End Date HCU 8/6/22 10/9/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 06 50-733-20042-00-00 167-052 10/06/2022 - Thursday PTW, JSA with platform crew. Wait for E-line crew to show up. E-line crew on location. Hold Safety meeting. Spot equipment. Rig up "Minnie Me" e line unit and CBL tools. Stab on well. Pt stack 250/4000 psi. RIH with CBL and tag toc in tubing at 430'. Log OOH with CBL. Find TOC @ 146'. POOH to surface. Lay down CBL and make up production punchers. 3.7' CCL to top shot. RIH. Log on depth park CCL at 396.3'. Perforate 400'-405'. Saw bobble on OA gauge. IA gauge no change. POOH to surface. Rig down from Di-06 and move to Di-18 to cut coil. Rig up to circulate down tubing and take returns from OA to open top return tank. Circulate 7 bbls of FIW @ 1 bpm 600 psi. Good 1:1 returns. IA gauge didn't move during circulation. PTSM, Fuel Eq. & warm up same. Unload boat, fill Diesel tank, Backload boat. P/U IH make up lubricator, (SS) M/U CTC & test t/3500psi good, Pu BHA- 2.3' 3 blade mill. xo,2 1/8" Mud motor, circ sub, Disconnect, Jars, check valve, CTC = 21.68' Stab IH, Function test M & M good, Test Break & lubricator, 250/4000 good. RIH t/ 305', up wt 3000, dn wt 2500, , POOH t/ 250', Break circ. 1.2BPM, 2400 psi. Wash down t/340', taking minimal weight & differential pressure getting back cmt in returns, @ 340' rop stopped & pump pressure increase. Continue milling down to 405', wipe hole 100', continue Milling f/405' t/450'. CBU, wipe hole up t/ 250', RIH t/ 450' s/d pump & set down 10k solid, Pump OOH t/ surface. S/d pump & shut in well. Break off IH, breakdown & L/D BHA. N/D BOPE & riser, secure well. 09/27/22- Tuesday Mobe Coil crews to Platform & orientate same. PTSM. R/U function test BOPE, shell test BOPE 250/4000, repair leaks as needed. Test BOPE as per sundry 250/4000, witness waived By AOGCC inspector Jim Regg. Full body test, blind/shears, test pipe/slips. Cont. R/U circulating lines, N/U riser & BOPE, stab pipe to injector. SDFN 09/28/22 - Wednesday PTSM, Check & fuel coil eq. r/u for testing. Start to test BOPE, had test pump issues, diagnose issue. P/U injector head, install CT connector Pull test 10 & 25k good, stab onto BOPE & secure. Fill CT reel & surface eq w/ water. Test BOPE 250/4000, Test all components, BOP stack valves, chokes, accumulator Drawdown test, accumulator bottle pre-charge. Rack back injector head, install night cap, prep BHA, SDFN. 09/29/22 - Thursday Mobe out coil crew. PJSM, unload boat & spot Eq. Spot spool toward Di-06. R/u dog house & gen, run control lines from power pack, run electrical lines, start r/u circ. Lines 09/25/22 - Sunday PTSM, continue rigging up CTU 1. Finish rigging up lines, install Gooseneck, function test EQ. function test BOPE Good. De- mobe coil crew 09/24/22 - Saturday Rig Start Date End Date HCU 8/6/22 10/9/22 Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name S MGS Unit 06 50-733-20042-00-00 167-052 Rigged up to pump cement down DI-08 OA, IA and short string. Took returns up Long string of Di-08 and pumped Into Di-06 Tubing taking returns up Di-06 OA and OOA into Di-07 IA, OA and up production tubing to return tank. Hold pre job safety meeting. Pumped 5 bbls ahead. Shut in and PT lines 250/3500 psi. Online to establish returns. Pump 2x bottoms up of 207 bbls. Total 300 bbls of FIW followed by 110 bbls of mudd push. Pressured up all OOA's to 500 psi. Di-07 and Di-08 didnt have communication. Di-06 had communication on the OOA. Mixed mudd flush and pumped 110 bbls. Cement wet 2000 hrs. Pumped 250 bbls of cement. Returns to surface good cement at 207 pumped. Pumping down Di-08, up Di-06 and out Di-07. After cement to surface close all valves and work cement through each annuli and confirm cement returns to surface through bleed/sample port. Pump cmt down Di-8 SS, IA, OA. Return up Di-08 LS. After 53 bbls pumped confirmed cement returns at LS with sample port. Start to isolate annuli one at a time and confirmed cement returns at return line or LS sample port. All annuli cemented in Di-08. Di-08 Cemented Continue pumping cement from LS of Di-08 into tubing of Di-06. 102 bbls or 155 total pumped close in OA valve and confirm cement at surface in OOA sample port. Open OA valve close OOA valve and confirm cement at surface with sample port. Checked IA valve with no flow. IA previously cemented off. Di-06 OA return lined tied into Di-07 OA. Di-06 OOA tied into Di-07 IA. Di-07 OOA no communication. Pump cement in Di-07 through IA and OA lines. Pump 53 bbls or 209 total bbls pumped. Cement returns at surface near a bbl or two of calculated displacement. Continue with an additional 40 bbls of excess cement. Isolate IA valve and cement up OA good returns at surface. Open IA valve and Isolate OA valve . Good cement returns at surface. Shut down. Ensure all Valves are open except Di-6 OOA valve. Pressure up on all annuli to 500 psi. No break over. Attempting squeezes on OOA. Shut in wellhead valves with 488 psi SITP. Total cement pumped 250 bbls. Di-08, Di-06, Di-07 all cemented in one pump job.. Clean up pump and lines to cuttings box. No overboard. 10/09/2022 - Sunday Di-06 had communication on the OOA. Pressured up all OOA's to 500 psi. Di-08 Cemented Continue pumping cement from LS of Di-08 into tubing of Di-06. Took returns up Long string of Di-08 and pumped Into Di-06 Tubing taking returns up Di-06 OA and OOA into Di-07 IA, OA and up production tubing to return tank. Pumped 250 bbls of cement. Returns to surface good cement at 207 pumped. Pumping down Di-08, up Di-06 and out Di-07. Pressure up on all annuli to 500 psi. No break over. Attempting squeezes on OOA. S 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW0RQGD\2FWREHU30 7R+DUROG6RXOH& &F5HJJ-DPHV%2*& 6XEMHFW5(6FKOXPEHUJHU&78 $WWDFKPHQWV6FKOXPEHUJHU5HYLVHG[OV[ ƚƚĂĐŚĞĚŝƐĂƌĞǀŝƐĞĚƌĞƉŽƌƚĐŚĂŶŐŝŶŐƚŚĞƐƵŶĚƌǇηƚŽϯϮϮͲϱϰϵĂŶĚŵŽǀŝŶŐƚŚĞďŽƚƚůĞƉƌĞĐŚĂƌŐĞƚŽƚŚĞƌĞŵĂƌŬƐ;ƐŝŶĐĞ ƚŚŝƐŝƐĂWͬ&ĨŝĞůĚŽŶůǇͿ͘WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗,ĂƌŽůĚ^ŽƵůĞͲ;ͿфŚƐŽƵůĞΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗dŚƵƌƐĚĂǇ͕^ĞƉƚĞŵďĞƌϮϵ͕ϮϬϮϮϭϭ͗ϬϲD dŽ͗ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖KK'WƌƵĚŚŽĞĂǇфĚŽĂ͘ĂŽŐĐĐ͘ƉƌƵĚŚŽĞ͘ďĂǇΛĂůĂƐŬĂ͘ŐŽǀх͖ ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх Đ͗:ƵĂŶŝƚĂ>ŽǀĞƚƚфũůŽǀĞƚƚΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗^ĐŚůƵŵďĞƌŐĞƌdhϭϵͲϮϴͲϮϬϮϮ dŚĂŶŬƐ Harold Soule Office 907-776-6681 Dillon Platform Cell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ll BOPE reports are due to the agency within 5 days of testing* SSu bm itt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:1 DATE: 9/28/22 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #1670520 Sundry #322-549 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/4000 Annular: Valves:250/4000 MASP:3304 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 0NA Permit On Location P Hazard Sec.NA Lower Kelly 0NA Standing Order Posted P Misc.NA Ball Type 0NA Test Fluid Water Inside BOP 0NA FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 1 1.75"P Trip Tank NA NA Annular Preventer 0 NA NA Pit Level Indicators NA NA #1 Rams 1 blind/shear P Flow Indicator NA NA #2 Rams 1 pipe/slip P Meth Gas Detector NA NA #3 Rams 0 NA NA H2S Gas Detector NA NA #4 Rams 0 NA NA MS Misc 0NA #5 Rams 0 NA NA #6 Rams 0 NA NA ACCUMULATOR SYSTEM: Choke Ln. Valves 2 2"P Time/Pressure Test Result HCR Valves 0 NA NA System Pressure (psi)2950 P Kill Line Valves 2 2"P Pressure After Closure (psi)2150 P Check Valve 1 2" 1502 P 200 psi Attained (sec)12 P BOP Misc 1 EQ Ports P Full Pressure Attained (sec)54 P Blind Switch Covers: All stations YES CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): NA NA No. Valves 5P ACC Misc 0NA Manual Chokes 2P Hydraulic Chokes 0NA Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 0 NA #1 Rams 11 P Coiled Tubing Only:#2 Rams 6 P Inside Reel valves 1P #3 Rams 0 NA #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:6.5 HCR Choke 0 NA Repair or replacement of equipment will be made within NA days. HCR Kill 0 NA Remarks: AOGCC Inspection 24 hr Notice YES Date/Time 9/24/22 03:44PM Waived By Test Start Date/Time:9/27/2022 12:00 (date) (time)Witness Test Finish Date/Time:9/28/2022 16:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Jim Regg Schlumberger Tested BOPE Full body, B/S, P/S on 9-27 12:00-14:30, Resumed testing on 9-28 had test pump issues, tested f/12:00-16:30, re- tested all. Bottle Precharge - 1400 psi. Albert Tietje Hilcorp Alaska Harold Soule S MGS Unit 06 Test Pressure (psi): Atietje@slb.com hsoule@hilcorp.com Form 10-424 (Revised 08/2022) 2022-0928_BOP_Schlumberger1_SMGS_Dillon-6 9 9 9 9 9 9 991$9 9 9 MEU - 5HJJ Full body, B/S, P/S on 9-27 Resumed testing on 9-28 From:McLellan, Bryan J (OGC) To:Aras Worthington Subject:SMGS-06 (PTD 167-052) Coiled Tubing work Date:Friday, September 23, 2022 12:13:00 PM Aras, Hilcorp has verbal approval to perform the CT portion of the work on SMGS 6 as described in the sundry that was received by AOGCC on 9/15/22, with the following condition: CT BOP test to 4000 psi, if test is due. After cleaning cement from tubing to 450 ft MD, push down max safe and practical weight with CT to confirm hard cement. FYI, this sundry number is 322-549. 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¾ 0L[RQWKHIO\DQGSXPSH[FHVVFHPHQWDVQHHGHGWRJHWJRRGFHPHQWUHWXUQV DFURVVDOODQQXOL 9ROXPHV ¾ 7XELQJIURP¶WRVXUIDFHESI ¶ EEOV ¾ 22$IURP¶WRVXUIDFHESI ¶ EEOV ¾ 2$IURP¶WRVXUIDFHESI ¶ EEOV 7RWDO&HPHQW9ROXPHEEOV $WWDFKPHQWV &XUUHQW6FKHPDWLF 3URSRVHG3 $6FKHPDWLF &7%23('LDJUDP )OXLG)ORZ'LDJUDP 3 $6XQGU\ :HOO'L 37' 'L&XUUHQW 3 $6XQGU\ :HOO'L 37' 3URSRVHG6FKHPDWLF 3 $6XQGU\ :HOO'L 37' 3 $6XQGU\ :HOO'L 37' By Samantha Carlisle at 8:35 am, Jul 21, 2022 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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Operations Abandon 11 Repair Well U • Plug Perforations 11 Stimulate U Other U Seal surface csg annulus Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 s Exploratory ❑ 167 -052 -• 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic Service ❑ 6. API Nu rnber: 50- 733 - 20042 -00 • 0 0 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018746 [Dillon Platform] S MGS Unit 06 j 9. Field /Pool(s): Middle Ground Shoal Field/ E, F and G Pool 10. Present Well Condition Summary: Total Depth measured 10,942 • feet Plugs measured 1,815 feet true vertical 17 . feet Junk measured ±1,913 feet /0 3 /P tz. -`)'� r Effective Depth measured 5,535 feet Packer measured N/A feet true vertical 5,534 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural 259' 33" 259' 258' Conductor 602' 20" 602' 601' Surface 2,020' 13 -3/8" 2,020' 2,019' 2,730psi 1,130psi Intermediate 10,530' 9 -5/8" 10,530' 10,387 5,750psi 3,090psi Production RECEIVED Liner Perforation depth Measured depth N/A feet True Vertical depth N/A feet Alaska Oil & Gas Cons. Commission Antct>!otatga Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.4#/ L -80 1,815' (MD) 1,814' (TVD) Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A ' 49t «tj 7' ' :' = 4 ''LI' Treatment descriptions including volumes used and final pressure: N/A 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development 151 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil ISI Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -281 Contact Nigel Bonnett Phone: 263 -7853 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature C .411t._ ,' Phone 276 -7600 Date 1 d 16, /20 i ‘ Form 10-404 Revised 10/2010 RBDMS DEC 0 8' 241(7r72 Submit Original Only ' [ Z,. (rte! �� • • st ACTUAL SCHEMATIC Chevron 102' MSL W 1 '' 134'RKB- TbgHgr Lease: SMGS 18746 7 118' 1 1 Well: Di -06 4 2 1 API #: 50- 733 - 20042 -00 Breach @ 54.5' per ______/ a I� PTD: 167 -052 caliper log Casing Detail Leg 2, Slot 8 10/23/2011 Size Type Wt /Grade /Conn I.D. Top Shoe Cmt sx TOC 33" Structural Surf 259' Drive n/a 20" shoe 602' 4 a. 20" Conductor 85# "B" 19.186" calc Surf 602' 1,250 sx calc. surf 54.5 & 61# talc TOC 687' 3 13-3/8" Surface J55 12.459" Surf 2,020' 1,200 sx Ca lc 687' 40,43.5,47#, 9 -5/8" Intermediate N 80,butt &BTC 8.755" Surf 10,530' 1,550 sx Calc7,883' 2 -7/8" Tubing 1,815' ELM Completion Jewelry Detail - 2 - 7/8", 6.4 #, L -80 A A 4 item # Length I.D. O.D. Description 1 1.5'? 2.992" 3 - 1/2" 8rd tubing hanger TOC 1,918' ELM 2 .4' 2.441" 3 - 1/2" x 2 - 7/8" XO 4 L . 3 1,815' 2.441" 2 -7/8" tubing e. 13 - 3/8 " shoe t 4 2,016' 9 -5/8" Retainer 2,020' @ 2° A TOC is marked on a CBT as 8,556' Top perf 2,054' ELM .* ;, _r: B s Perforations: A: - Zone Top Btm ft / SPF Date Comments fl A 1.4 Gas 5,672' 8,962' Isolated C VIP G- lthruG -4 9,240' 9,830 4 Isolated TOC 5,535' Top perf 5,672 Retainer 5,750' Fish & other in the hole: ## , `, -,. ,.. ` Item Depth Length 0.D. Description r '" - A +/- 1,913' ELM +/- 14' Starguidestinger Calc TOC = 7,883' 1 f ',.. * 1 ! • " B +/- 2,041' Retainer and TCP guns �,''',, " •� ." •.y 4 , C +1- 2,601' 2,934' 2 Tubing ^+ � �. D 10' 1 -1/2" Cemented in drop bar TOC 8,556'CBT 1 s /4 /4 X ",1" I + *13$ , Retainer 9,115' --- - ** No Eline /Slickline work documented since 2 -7/8" kill string ran in Btm perf 9,810' , 1988. D 8/2011- Well circulated with 9.8 ppg KWF. Well Dead. Confirmed Milled Retainer 10,137 1 - - - - - _ communication between 9 -5/8, 13 -3/8 ", and 20 ". Freeze protected w /diesel. Retainer 10,141' - -_- Retainer 10,480' - - _- .a PBTD = 10,215' MD & 10,204'TVD r TD = 10,942' MD & 10,930' TVD ■ Max Hole angle = 5.0' @ 9 -5/8" shoe 10,530' 10,006' MD Open hole to 10,942' TDF 11 -3 -2011 Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) DI -06 S MGS UNIT 06 ADL0018746 5073320042 AR4244 100.00 Jobi Primary Job Type Job Category Objective Actual Start Date Actual End Date Abandon Well - Suspend Abandon 10/7/2011 l_ Primary Wellbore Affected Wellbore UWI Well Permit Number DI -06 507332004200 1670520 10/7/2011 00:00 - 10/812011 00:00 Operations Summary RU wireline. PT lubricator to 250psi low/ 2,500psi high. RIH w/ 2 -1/4" GR junk basket to 3,046'. RIH w/ 2 -1/4" jet cutter and cut 2 -7/8" tubing at 2,523', good indication of successful cut. POOH and RD Eline. 10/10/2011 00 :00 - 10/11/2011 00:00 Operations Summary No operations. 10/11/2011 00 :00 - 10/12/2011 00:00 Operations Summary No operations. 10/12/2011 00:00 - 10/13/2011 00:00 Operations Summary No operations. 10/13/2011 00:00 - 10/14/2011 00:00 Operations Summary No operations. 10/14/2011 00:00 - 10115/2011 00:00 Operations Summary No operations. 10/15/2011 00:00 - 10/16/2011 00:00 Operations Summary No operations. 10116/2011 00:00.10/11/2011 - 00:00 Operations Summary No operations. 10/17/2011 00 :00 - 10/1812011 00:00 Operations Summary No operations. 10/18/2011 00:00 - 10/19/2011 00:00 Operations Summary No operations. 10/19/2011 00 :00 - 10/20/2011 00:00 Operations Summary Mobilize RU equipment. Notified AOGCC of upcoming BOPE test. 10/20/2011 00:00 - .10/21 /2011 00:00 Operations Summary ND tree, begin NU BOPE. 10/21/2011 00:00 - 10/22/2011 00:00 Operations Summary Continue to NU to BOPE. Test annular to 250psi low /1500psi high. Jeff Jones of AOGCC waived witness of upcoming BOPE test. 10/22/2011 00:00 - 10/23/2011 00:00 Operations Summary Continue BOPE test 250psi low/ 2,500psi High. Unseat tubing hangar and lay down same. Begin POOH of 2 -7/8" tubing from 2,481'. 10/23/2011 00 :00 - 10/24/2011 00:00 Operations Summary Complete pulling 2 -7/8" tubing from 2,481'. RU Eline. RIH with 8.5" GR unable to work past 61'. RIH with 5.5" junk basket to 2600'. RIH with multi -arm caliper log to 2,500', RIH with 8" LIB to 2,100'. MU 9 -5/8" EZSV cement retainer with 5' of TCP guns below, RIH and set retainer at 2,050' ELM, TCP guns placed 2,054' to 2,059', POOH. R/U cement stinger and begin RIH with 2 -7/8" tubing. 10/24/2011 09:00 - 10/25/2011 00:00 Operations Summary Complete RIH w/ 2 -7/8" tubing and sting into EZSV at 2,025', verify plug set with 10K set down, pick up to close sliding valve. fire perf guns. Slack off 6' to tag retainer, no retainer found. Circulate well, RIH and push retainer to 2,041'. POOH UD tubing and stinger. R/U Eline and RIH with EZ -SV cement retainer to 2,040'ELM and set same, POOH and R/D wireline. RIH w/ cement stinger and tag cement retainer at 2,040'. 10/25/2011 00:00 - 10/26/2011 '00:00 . Operations Summary Space out and sting into retainer and set down with 10K. Circulated down tubing stung into retainer with no returns up 9 -5/8" annulus. RU cement equipment. Mix & pump 25bb1 15.3ppg cement below retainer, no returns up 9 -5/8" annulus. Unsting from retainer, circulate, pull up hole to 1,852'. Wait on cement. Pull up hole, MU tubing hanger with BPV installed and land same with starguide stinger bottom @ 1,829. Back out landing joint and LD same. ND BOPE and begin NU dry hole tree. Chevron • • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name ( Lease Surface UWI ChevNo Original RKB (ft) (Water Depth (ft) DI -06 S MGS UNIT 06 I ADL0018746 5073320042 AR4244 100.00 ^*:r.�- ;;� °,::�.? °,�v : : w`a::._ ;.� rdi�'��'. ;•,'.�:� >x*;,y,,.c ,..�z, ;p 15ifi 9 VjlYF,NUMEEV 10/26/2011 00:00 - 10/27/2011 00:00 Operations Summary Pressure test tree 250psi low /5000psi high. Circulate well with 9.8ppg brine down tubing taking returns on 9 -5/8" annulus. RU Eline, RIH with jet cutter, tie -in and cut tubing at 1815'ELM, dropping star guide stinger ( +1 -14'). RIH with gauge ring and tag TOC at 1918' ELM, AOGCC Lou Grimaldi witnessed tag of cement. RD Eline. Pressure test 9 -5/8" casing to 305psi, bled to 263psi in 30min. 13 -3/8" & 20" mimic pressure up & bleed off during test, witnessed by AOGCC Lou Grimaldi. Pump diesel down tubing & 2- 7/8 "x9 -5/8" annulus for freeze protection. Begin RD equipment. 10/2712011 00:00 - 10/26/2011 00:00 Operations Summary Pump diesel down 20" & 13 -3/8" annuli for freeze protection. RD & demobe equipment. • • Page 1 of 2 Schwartz, Guy L (DOA) From: Quick, Mike [ASRC] [MQuick @chevron.com] Sent: Friday, October 21, 2011 2:03 PM To: Schwartz, Guy L (DOA); DOA AOGCC Prudhoe Bay Cc: Hammons Jr, Darrell James; Brumley, Rick D. [Nabors]; Bonnett, Nigel (Nigel.Bonnett); Fouts, Tom [EMC Engineering] Subject: RE: Dillon Di -06 Sundry 311 -281, PTD 167 -052 Guy — Per our discussions, we will not be able to do either of the steps outlined below. 1 have found summary details of when the set the cement plug at 5535': they tagged the plug with a bit and pressure tested the plug and casing to 1,150 psi for 30 minutes. This was in July, 1988, prior to running the 2 -7/8" tubing kill string. It may take some time next week to try to locate the original reports for this work. Please give me a call if you would like to discuss in further details. Regards, Mike l) }.` 1 ‘0 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Friday, October 21, 2011 12:42 PM To: Quick, Mike [ASRC]; DOA AOGCC Prudhoe Bay Cc: Hammons Jr, Darrell James; Brumley, Rick D. [Nabors]; Bonnett, Nigel ( Nigel.Bonnett); Fouts, Tom [EMC Engineering] Subject: RE: Dillon Di -06 Sundry 311 -281, PTD 167 -052 Mike, Thanks for the additional information ... you have approval as per the sundry 311 -281. Please add the steps below to your procedure. Essentially you will be suspending the well and the bottom cement plug has to have a verified tag and pressure test before you move uphole to continue the suspending operation, 1)Tag top of cement at 5235 ' with E -line before cutting the tubing. (verify cement top in casing ). Please submit a E -line log of the tension /depth curve to the Commission. 2) Pressure test 9 5/8" casing below retainer at 2050' before firing the TCP guns. We don't have any record of this Pressure test of the cmt cap. Test to 1500 psi for 30 min and chart. (TCP gun firing pressure is 2500psi per our conversation) Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Quick, Mike [ASRC] [mailto:MQuick @chevron.com] Sent: Friday, October 21, 2011 9:32 AM To: Schwartz, Guy L (DOA) 10/21/2011 • • Page 2 of 2 Cc: Hammons Jr, Darrell James; Brumley, Rick D. [Nabors]; Bonnett, Nigel (NigeLBonnett); Fouts, Tom [EMC Engineering] Subject: Dillon Di -06 Sundry 311 -281, PTD 167 -052 Guy — Thanks for the discussion today around UOCC approved plans on the Di -06 well under sundry 311 -281. Per our discussion, from our well data from the Middle Ground Shoal field, the Tyonek formation had a virgin pressure of less than 8.7 ppg mud weight equivalent (0.4521 psi /ft) at depths deeper than 4200' TVD, and less than 8.4 ppg mud weight equivalent (0.4338 psi /ft) at depths shallower than 3200' TVD, as outlined in the details of the approved sundry application for this well. We will be perforating at +/- 2050' TVD. Inlet water will serve as a kill weight fluid if needed. For long term abandonment stability, UOCC has chosen to Toad the well with a 9.8 ppg brine as the well is currently sitting. Additionally, we have +/- 19,600 pounds of NaCI salt on location to weight up if needed. We are not planning on circulating extensively to perform this work scope, but we do have two 400 bbl tanks on board, in addition to the 100+ bbl Cudd tank, to take returns as needed. Please give me a call if you would like to discuss any further details. My cell is best (317- 2969), as I do not have full time access to email. Regards, Mike Mike Quick Project Manager / Drilling Engineer MidContinent /Alaska SBU Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Direct 907 - 263 -7900 Fax 1- 866 - 480 -5398 mquickAchevron.com 10/21/2011 Amoco Pot coon Company • ii 0DB Completion or Repair Report lien Roou,re for Denver flagon input OtrhrtLogo t , . drat. T 4,r t H,o ,:- ria+t tree C } i z l ! , yd w 6ti4 S:.b 7:grs 6titue - v 7 4 �,�„ � ' II '. ,.� .. . Ca 1 rl. rid 4,4.4 N,mt sno WNt rip. nt,a67sr N- a tort w 4 too Ir 1n �a r J. .'grit twnt cote," Days Wares() ...,..22,... , A tltit TO._......._ ,. -Last CA SON ■_,_ Dtarn y - 7' 1,1* t^ ' e v / ,asant ralrOpt -° " on s6xscts i t .ea� 5 • S. -- - -- - -A °- P4tt,ret es '' •• , o . .4 ..<. n •rt. rn.p :N;4 .a odes. .tt fJri • saKn0va 04:4 . r...•.t4d Doe .np Smct vt r...e�t � . A a9 .'SO. 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'0 14 In 8 I e e e . . I 1 (// � 1 _ I _ .00 U.!f Uri .. __ ... _, _._. _. r . ,. ._. ..__........._._ 99 _..... _.._- S L LS' _# 4 •a t' '''Vc �a �, S • - -- ....._..._.._... �_.. __.. .. _ . _ -. •. -. • . f .. _._.- • - - ..- ._..._�__. ...__._._ r ... .............. -.. • 4 At e l ' # *a S ! s � 1 1 4lad ahhat. v° • • ' W I 0 rd • • • l t _ - w • • No. 1 • ','' DAILY DRILLING _PORT •PORT NO. LEASE I WELL NO. 1API WELL NUMBER WATER DEPTH! DATE 1 - 1 OPERATOR tCON _ TRACTOR . - i RIG NO. I kY1C,On il il PiZies.,ER _2..i,e.:. I, LLio_G Co. SIGNATURE OF OPERATOR'S REPRESENTATIVE ' 'i SIGNATURE OF CONTRACTOR'S TOOL PUSHER i // t n_10:7 ,,,„,,_:_,' D.P. SIZE WT./FT. I GRADE TOOL JT 0.0. I TYPE THREAT STRING NO. PUMP NO. 7 PUMP MANUFACTURER r--- TYPE i 1 STROKE i- ---- - - ----- ---L-- -- _ 3 _i_.3 ', .5 ,.../ -..4,, 1 3 ,.. _ 1 1 i . I TIME DISTRIBUTION - HOURS I NO. DRILLING ASSEMBLY BIT RECORD MUD RECORD I tat enci tovr1 : 1 I , NO. - OPERFTION i NIGHT DAY BIT FT. BIT NO. TIME , 7TAr.A__ 1 2. DRILL ACTLAL 6 CORING I 1 5 * TC7C 7 rA l lt i r ', / YZ, , i / A, 1 -1- 7. LUBRICATEIRm J 8. REPAIR RIG! 0 CUT OFF , " DRILLING LINE IC, DEVIATION SURVEY 11. WIRE LINE LOGS i / 1 ..5 2-.. s.,. . — 7 1, 1 ! — STB RMR Q% STB RMR D.C. ID STB RMR 00 OD OD; I 0o f — 1231 001 SIZE FT. MFG. FT. TYPE FT. JETS 1 37' FT. SER. NO. FT. DEPTH OUT DEPTH IN TOTAL FTG. TOTAL HRS. RUN COND. UV s FT. T 8 GAGE 1 7' i T _ -, I WEIGHT PRESSURE GRADIENT 3. REAMING VISC. --SEC. 1 PV TP [ i [ A J 6. TRIPS / ---, 1_, wt. -CC'S. pH SOLIDS % . , .... : I 7 ---: . 7 - 7- -- ./ ! / - i _......: 1 1 , 5 . . Type MUD & CHEMICALS ADDEt STANDS DP AMT. TYPE -- 1 AMT. RUNCASING&CEMENT l 112 I. I SINGLES DPI FT. GPM,' PD-PSI // I I 1 I r 13. WAIT ON CEitIENT S 1 I-TT , ..-----.-_ _I / I-H-1 KELLY DOWN FT. , 1 14. NIPPLE UP t1.0.P. 4_ 1_ __A. I TOTAL FT. 15. TEST B.0"; _t_- ,---- 1 16. DRILL STEM TEST WT. OF STRING LBS. -- i . 5 ' 1 I ----- 1 17. PLUG BACKI . REMARKS I -- 1 10. SQUEEZE CEMENT , II 19. FISHING _ , 11 20. DI P. WORK DRILLER/ 23. R --- ' NO. DRILLING ASSEMBLY 11 I I (At 0401 tost) BIT RECORD 1-- T MUD RECORD A. PEF , B. TBILT_RIPS 2 IC. TRKAT1NG c, !—_.___ E ! 1 1 I ; , H i BIT ' -- )_5 - FT. BIT NO. SIZE STB RMR , 00 TIME _ wEIGHT PRESSURE D. Sw+B1NG R FT MFG. GRADIENT f • -- ---j 1 1 , if. 1 ESITING , 1 I 1 -,ci--y+ ocALL4....„ TYPE V1SC -SEC U F. ADOIT'N'L STB I RMR OC FT JETS 1/32" PWYP / / / 1c, I 1 D- F12 OD FT SER. NO. • GELS. / / / 1 1 1 1 1 I 1 STB R6113 00 FT DEPTH OUT WL -CC'S. TOTALS , / 2- 12- I DEPTH IN PH . 1 L DI SUMMARY I t • TOTAL FTG. SOLIDS IS 4 ; MRS. w CONTRI D.P. — TOTAL HRS. HRS. w/OPR. DIP. t RUN MRS. WO OP 1 5 STANDS DP .. ,-,..-..,/ 1 4 96 FT. 7 D O ' ' :A.E . MAT. I 1 I i. TYPE MUD &CHEMICALS TYPE J' __,_ I I HRS. STANDBY] I SINGLES OP 3 / t, FT. GPM PD-PS1 / / 1 f 1 KELLY DOWN 47 ._ TOTAL ..... .. 5 FT. -- , I 1 • wT. OF STRING , g7 . 9 0 0 0 LB i I - i J i REMARKS TOTAL DAY Wi)RK NO. OF DAYS I FROM SPUD ; CUMULATIVE , ROTATING HRs . • ( 1 TOTAL MUD C r A T DRILL E • H .,.....- / . I i PRINTED IN U.S.A. i APPROVED IADC - #1 OFFICIAL DAILY DR 11 ' ‘'i APPROVED ,..,.. ... ..4 \ . i . i . I • • I • ; I 'IELD oi COUNTY STATE - 7 - _.:_. • ...- 17;--.1 1 1 <.- .7 I .7, I, AL t5kA !WIRE LINE RECORD REEL NO. ---- II SIZE MAKE WT. 8 G . R. I 6iii. FEET ; da; i .j o; ; SET AT L = L-.• 1 / .._,-• L ___Z r i 1 ! t , ; FTCUT OrP — I PRESENT aird -- ----- - 1 z - oir - CAl — , I _4, _.:1. 1___ L _,... I -, ti.p..TA... Tu.. , TON MI. OR TRIP OR LINER Il I i j 1 1 SINCE LAST CUT --- — I CUMULATIVE _ _FOOTAGE I T ,,,,.. 7 1 --"D CORE FORMATION 1 , ROTARY r C1 . 1 PUMP i "111? ' 43. PtimP IPI2I t ; .0 MER7144°° ICrE NC' (SHOW CORE RECOVERY) RPM I - PRESS 11 iNER I R .1 FROM I ; TO 1 , i LiNE0 SIZE 1 ''' 1 L SIZE .. 1 -P-m- IPAPJ P I I 1 1 I ; el 1 I 1. - I. r - - . _ i I / 1 DEPTH DEV. DIRECTION #EPTH DEv. DIRECTION 1 DEPTH DEv. ;DIRECTION 1 DEVIATION ----t RECORD - t 1 TIME LOG TO FROM i CODE NO. DETAILS OF OPERATIONS IN SEQUENCE AND REMARKS I ' I ___+__ — .1_, 4 —/ 7 i / ..72,.(2 4d. A fZ-. 1 7, 7 - e%. /. Liz ' 1 1 x I ?1C22 1 1 r)g6P ocii_z_- 4 ati • /._, 0 7 _e_7044.11 — _16 / • _____ _ _ .... __. _ . _ _ . .. . _ 1;1 i // . / I ( i' g_l_le_t_d a.176_14E, , , . 2 , ,,/.. O. I I. 1, 1 , - c)ff 3z> I L k - f' -- 7 - 7 - 272, 4 5 - f7zr._ 2-7 'Ve•r-i, ,f "V /. 40X!5 ' _..-t_ 4 14 #_2.4 DA-) - / ..62 _,--7"Ty ‘..)4A. _ . . im• / /Z. 1 , , .•='/..1,/, /.4D,{? 1 . _ 1 1 , 'L _ .... ..._L I , 1 ! i _ _ i L1 1 ± _i T , FO.TAGE ( f:11 CORE FORMATION ROTARY ? T , PUMP PUMP NO. PUMP NO; . imETHoo I RUN — -4 CC kHO. I (SHOW CORE RECOVERY) ' RPM ; 1(Q0z I PRESS 1- ; 7m. LINERT S. (III _ PROM TO , 1 I 1 , (. iNER - S.P SIZE i SIZE I ; 1 460 1-31G-1 3e ;_ i ;;_ i , _ 1-- — I --, I I I j_._. , I 1 I DEPTH I DEV. DIRECTION DEPTH OEv. DIRECTION DEPTH DEV, DIRECTION ' DEVIATION — f - ------ RECORD , 11 TIME LCS ELAPSED CODE NO. DETAILS OF OPERATIONS III SEQUENCE AND REMARKS TIME PROM i ) TO 1... _ 20 C 1 )2$ A C' k, / 1-i. /D, P. "7 -." / o f'Citi fr:A _1 yo i 1 1 H 4 z ie. -7 // Je ---: -5 r-,7■,s__e- "cl ._s-,..< . gril7": ri 0 & 0.‹ ., .- 1 .-,- z • _L-) .1,4` / /Z /- lb , Do 7 e:/ge . / - Do H'00 2.. 6., fo. 0, hi. 4ft /if? to '2, 6. ec0/) - 1 5 • . / /-7. 72 -5" ' _._4fergAt c-2,ec- / goo i3 co I 2 ' ..2- ?. .3 0 Y4 .2- i 7■ ..)71.-,r..5 /4,4s5vAL- ??3 4k<oc ,z... 6 "Of( g.O ..f /), A _ — t - , - I ] . .ING RiPORT FORM 1 IC. • API WELL NUMBER I WATER DEPTH i 'ATE 11 1 _.... I _ CONTRACTOR 1 RIG NO. , STATE " ' 7FET_D ,Th I--MST. . 1 :' AL A.S PIR4/ 2 ), C: 1...C.. ) ....a:/SZC.? CC' • i:, ..-1.. °, .. — -... .-- - 7-- I__ _, K:,- A i ,...... L RK SIGNATURE OF CONTRACTORS TOOL PUSHER : SIM I MAKE wl. & GEL 1 JOINTS FEET i c , ! i i LAST , ___ -- .i -4-_- E 1.--__--t__. ___ -. il PUMP NO. 1 PUMP MANUFACTURER -- 7 TYPE ----r— sTiotir - CEO I I 1 LENGTH ( .. ) r Fz utz R ;1 - I __I .1 FOOTAGE 1 DR..0 c m ---- ORMATION 8)T RECORD MUD RECORD ; , RM-R N, lSHOt CORE RECOVERY ICORE-C I i: '',, FROM 1 TO T I NO, 1 TIME i- WE/GHT I i 4 I PRESSURE , 1 ' GRADIENT _ 1 1_,____ ..._ _ _ ._ v/SC. -SEC / 1 I ',I DEPTH , DEv. DIRECTION i DEPTH ■ I _ / - I .' It DEVIATION 7— , 7 r - 7 I lii PV' 7 4_ i / / J 1 , 1 - RECORD / 1 7 NO. GELS. i___ _ / __I, / TIME Lao - . ELAPSED . .. NO Wt. -CC'S. 1 j ) CODE . DETAILS OF DEER TIONS IN SEQUENC H OUT 1 : , FRom TO TIM.. , _ ._ _ ■ : ,-- — i i 1 HIM . HRS. I ■ i , I- ■ ------ ----4 I : i h x i , I 0 ' ,--- 21,0„,. 7 / " L I WI) 8. CHEMICALS ADDED TYPE 4 T AMT._1, 0 c .... / /0 , I (. IC23* 0 2 - I I _ i I ; ! , ' I . ; " k_ .- 7 ' ii _ 4 I i I ; i 1 1 1 1 1 ! 7— I I III III , I ; T-- ...._ I ' --- ; 1 BIT RECORb f MUD RECORD FOOTAGE 08 ra:ii I CORE FORMATION ' I , coRr_. NO. (SHOW CORE RECOVERY) 1 i 1 ' FROM 1 TO TImE 1 t t .1._ I 1 1 WEIGHT .... - 1 I i I- 1 i ' I PRESSURE GRADIENT . _ VISC_ -SEC DEPTH OEM, DIRECTION 1 I l DEPTH r DEVIATION 1--- I L III III PWYP All ' RECORD TIME LOG ELAPSED CODE NO. DETAILS OF OPERATIO IN SEQUENCE Arc T alel 1 , FROM TO TIME i 1 ' 1 I , , El SOLIDS % 1 r2 ! iy 0 , - ,.) - 441. - C ,1 el i____ gfvi "I 4)& .8/ii4 MUD & CHEMICALS ADDED I 0 /7z / Z 1 007 e/A /-ye0 / ‘ 2 .0c 2 i I ' 1 i ,i 5 er 1-. 6, _ _ i , . 4 ' 00 ,._. 0 , ..5 — .15 I 1 0 0 0 -?-: 0 • 1/2. 2 ( 704 L.,-/-7-- ___ ______ 1 3f.i z_ 6 'OA{ 1 , I i , _ — ..._ 1 ,‘ IADC ,,1 OFFICIAL DAILY DRILLING REPORT FORM 1 • • 102' PLANNED SCHEMATIC Chevron Oftuit ,41110110 ,r , ..:: :.';... _ _.. Lease: SMGS 18746 = ma - -� f-. 34' RKB - Tbg l lgr * ice . 118' I ( Well: Di -06 ' k. I 2 1 API #: 50- 733 - 20042 -00 PTD: 167 -052 Casing Detail Leg 2, Slot 8 Grade /Conn Site Type Wt / W. Top Shoe Cmtsx TOC ni2 I 33" Structural Sur 259' Drive i 20'shoe602' �-- 26' Conductor 854 1" 19,186'eale Surf 602' 1,250 sx ealc,surf Cale TOC 687' 3 1"s•3/8" Surfa 54.5 & 614 J -55 12.459" Sur" 2,020' 1,200 sx Cale 687' . 40, 435, 47;1, N -80, butt 9 -5/8' Intermediate 8.755' Surf 10,530' 1,550 sx Cal( 7,883' & BTC Co mpletion Jewelry Detail - 2 -7/8", 6.4#, t. item ft Length ID. 0.D. Description 1 1.5'? 2.992' 3.1/2 tubing hanger 2 .4' 2.441" 3-1/2" x 2 -7/8" X0 3 1900' 2.441" 2 -7/8" tubing 13-3/8" shoe 2,020' e 2° ®. , - Retainer 7,050' ' . I lop perf 2,055o TOC is marked on a CDT as 8,556' i Perforations: //' 7 Zone Top Btm ft /SPF Date Comments Gas 5,672' 8,962' Isolated , G-1 thru G-4 I 9,240' 9,830 4 Isolated lop Retainer 5,750' . Fish & other in the hole: Retainer 5,750' Drop bar 10' 1 -1/2" - cemented in -, +1- 2500' of 2.7/8" tubing (3035' to 5535') Cale TOC = 7,883' #'., fe. TOC8,556'CBT 1 • • °° No Eline /Slickline work documented since 2 -7/8" kill string ran in 1988. • 8/2011- Well circulated with 9.8 ppg KWF. Well Dead. Confirmed communication between 9-5/8, 13-3/8", and 20 ". Freeze protected ' w /diesel. Retainer 9,115' Btm perf 9,810' : " Mired Retainer Itt,1 / :. Retainer 10,141' _ ,, Retainer 10,480' PBTD= 10,215' MD & 10,204' ND -- - - TD= 10,942' MD & 10,930' TVD 9 -5 /8' shoe 10,530' Max Hole angle = 5.0" @ 10,006' MD Open hole to 10,942' MQ 09- 122011 • • - --ie 1 le 102' Lease: SMGS 18746 Chevron I._ . - Well: Di -06 ___ MSL � I . , 34' RKR - Thg Hgr 118' 1 ; 1 t t ,( l API #: 50-733-20042-00 I l 2 i lk i 1 PTD: 167 -052 [ ! Casing Detail Leg 2, Slot 8 3 I Size Type Wt /Grade /Cain ID. Top Shoe Gnt sx TOC 33' Structural ? ? Surf 259' Drive n/a 20' shoe 602' 41 s .. 20` Conductor 858 "B" 19186 calc Surf 602' 1,250sx ca lc. surf CaIc TOC 687' i3 -318' Surface 54.5 & 618 J -55 12.459' Surf 2,020' 1,200 sx Ca lc 687 48 435, 47,1, ti - &3, butt 9.5/8' Intermediate &BTC 8.755 Surf 10,531 1,550sx Celt 7,883' 4 1 Completion Jewelry Detail — 2 -7/8 ", 6.44, L -80 item # Length I.D. - 0.D. Description 1 1.5'? 2.992' 3 -1/2" 8rd tubing hanger _ 2 .4' 2.441" 3 -1/2" x 2 -7/8" XO , , 3 446.75' 2.441 14 'Fs of 2 -7/8" tubing 13 -3/8" shoe 4 .4' 2.441" 2 -7/8" butt x 2 -7/8" 8rd XO 2,020' @ o S ! 5 4,969.79' 2.441" 151 its of 2.7/8" 8rd tubing 6 .4' 2.441" Mule shoe @ 5,415' TOC is marked on a CBI as 8,556' 6 Perforations: Mule shoe 5,415' Zone Top Btm ft /SPF Date Comments tttt Gas 5,6/2' 8,952' Isolated PBTD = 5,535 ` G -1 thru G -4 9,240' 9,830 4 Isolated Top pert 5,672'. • _ ` Retainer 5,750' _ Fish & other in the hole: Drop bar 10' 1 -1 /2' - cemented in 10C 8,556'CBT •. 1 • "" No Cline /Slickline work documented since 2 -7/8" kill string ran in 1988. • : ' 8/2011— Well circulated with 9.8 ppg KWF. Well Dead. Confirmed communication between 9-5/8, 13-3/8", and 20 ". Freeze protected w /diesel. Retainer 9,115' — " _ Btm perf 9,810' Milled I eta,ner lo,l5r - - --- 7- , ...: Retainer 10,141' ._ `_° Retainer 10,480' _.... PBTD = 10,215' MD & 10,204' TVD " TO= 10,942' MD & 10,930' TVD Max Hole angle = 5.0 @ 9 5/8" shoe 10,530' 10,006' MD Open hole to 10,942' MGB 08 -24 -2011 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 05, 2011 3:14 PM To: 'Quick, Mike [ASRC]' Cc: Fouts, Tom [EMC Engineering]; Bonnett, Nigel ( Nigel.Bonnett) Subject: RE: Dillon Di -06 PTD 167 -052, Sundry # 311 -281 Mike, et al, From our conversation, I understand that the primary difference is size (13 -5/8 vs 11"). Our requirement is to have a BOP stack, minimum pressure rating is specified but size is not. Thanks for the notice of change. Be sure a copy of this message is available for the Inspector on the platform. Good luck with the operations. Tom Maunder, PE AOGCC From: Quick, Mike [ASRC] [mailto:MQuick @chevron.com] Sent: Wednesday, October 05, 2011 3:02 PM To: Maunder, Thomas E (DOA) Cc: Fouts, Tom [EMC Engineering]; Bonnett, Nigel (Nigel.Bonnett) Subject: Dillon Di -06 PTD 167 -052, Sundry # 311-281 Mr. Maunder — UOCC has an approved sundry # 311 -281 dated 9/21/11 for Dillon well Di -06, PTD # 167 -052. Due to timing conflicts, we are needing to change out the 11" BOP stack in the approved sundry to an 13 -5/8" BOP stack per the attached BOP drawing. Please let me know if I can provide any further details on the change request. Best regards, Mike Mike Quick Project Manager / Drilling Engineer MidContinent /Alaska SBU Chevron North America Exploration and Production 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Direct 907 - 263 -7900 Fax 1- 866 - 480 -5398 mquick@chevron.com 10/5/2011 Chevron • Dillon Platfo• Di -06 09/30/2011 Dillon Platform Di -06 Nordic BOPE 4.54' • Hydril • Nordic owned I n ri'n , 1 E . Shaffer SL 13 5 - Nordic owne/8 d 1.4 ,.. , 0 I. 2 1/16 5M choke and i kill lines unibolt ends We'Ill 111 111 `'fib O H + ij r 1.74ii - - -Z' . e AIM 111 111 111111 111 r SL 13 5/8 ' - Nordic owned _ 1.44' 111 111111 111 1 .56' Drill deck Riser 11.00' 13 5/8 5M X 13 5/8 5M III Ili III Iii Ill it f _, I- 111 III 111 !MU Crossover spool 1.41' 13 5/8 5M Flanged end X 11 5M Flanged end Ill Ill Ili lii Ill .4 "i me i iiii te r:.. '.II �] 1 g milI;[ a�i II' IIIII s EITET[E oF ALA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSIOIQ ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy C. Brandenburg Drilling Manager �, Union Oil Company of California 7 _ P.O. Box 196247 Anchorage, AK 99519 Re: Middle Ground Shoal Field, E, F, and G Pool, S MGS Unit 06 Sundry Number: 311 -281 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approv NM a t i ng to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 9 / Daniel T. Seamount, Jr. Chair DATED thisZ / day of September, 2011. Encl. I III to- , ogizo(2o61 CP 11 '/E STATE OF ALASKA , C EP 'I 4 20 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPRO q� & Gas Cons. Co 20 AAC 25.280 mmiss 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 • Anearitgepproved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ O Sdc r .:l sa�i it 4 .Fnte t it ru g 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Weak Union Oil Company of California Development 15 • Exploratory ❑ 167 -052 . 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20042 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 S MGS Unit 06 - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0018746 • Middle Ground Shoal Field/ E, F and G Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,942 10,930 , 5,535 5,532 N/A N/A Casing Length Size MD , TVD Burst Collapse Structural 259' 33" 259' 258' Conductor 602' 20" 602' 601' Surface 2,020' 13 -3/8" 2,020' 2,019 2,730psi 1,130psi Intermediate 10,530' 9 -5/8" 10,530' 10,519' 5,750psi 3,090psi Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Development El • Service ❑ 14. Estimated Date for • 15. Well Status after proposed work: Commencing Operations: 1 /1/2i 11 Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: // Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Quick Phone: 263 -7900 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature C --� c Phone 276 -7600 Date 9/12/2011 /''- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 td l Plug Integrity ❑ BOP Test R Mechanical Integrity Test ❑ Location Clearance ❑ Other: t -' * 309 E to 25"0 0 p s.i . Subsequent Form Required: 1 0 LI O y. . ' APPROVED BY Approved by: ai COMMISSIONER THE COMMISSION Date: 9 /2 l 1 1 tiBDMS SEP 2 2 A' RIGINAL /i , `I Form 10 -403 Revised 1/2010 - . Submit in Duplicate i ,� v =" ° Lease: SMGS 18746 Chevron 102' MSL W I - "'__`..... .' . ...... .I .:*x'"134' RKB -Tbg Hgr Well: DI -06 118' i API #: 50- 733 - 20042 -00 1%0 2 1 PTD: 167 -052 Leg 2, Slot 8 Casing Detail 3 Size Type Wt/Grade/Conn LD, Top Shoe Cmtsx TOC 33" Structural ? ? Surf 259' Drive n/a 20" shoe 602' ■ 20" Conductor 850 "B" 19.186 "calc Surf 602' 1,250sz ca lc. surf Caic TOC 687' 13 -3/8" Surface 54.5 &61 #1.55 12.459" Surf 2,020' 1,200 sz Calc687 40, 43.5, 470, N -80, butt 9.58" Intermediate &0,N 8.755' Surf 10,530' 1,550sz Calc7,883' BTC 4 ii i Completion Jewelry Detail — 2 -7/8", 6.4 #, L -80 item # Length I.D. 0.D. Description 1 1.5'? 2.992" 3 -1/2" 8rd tubing hanger 2 .4' 2.441" 3 -1/2" x 2 -7/8" XO 3 446.75' 2.441" 14jts of 2 -7/8" tubing 4 .4' 2.441" 2 -7/8" butt x 2 -7/8" 8rd XO 13 - 3/8 " shoe 2,020' @ 2 5 5 4,969.79' 2.441" 152 jts of 2 -7/8" 8rd tubing 6 _ .4' 2.441" Mule shoe @ 5,415' TOC is marked on a CBTas 8,556' 6 q Perforations: Mule shoe 5,415' Zone Top Btm ft / SPF Date Comments Gas 5,672' 8,962' Isolated PBTD = 5,535' j( G -1 thru G -4 9,240' 9,830 4 Isolated Topperf 5,672' -' -' Retainer 5,750' Ill= Fish & other in the hole: Drop bar 10' 1 -1/2" - cemented in r TOC 8,556'CBT ,' I • ** No Eline /Slickline work documented since 2 - 7/8" kill string ran in I • 1988. • • 8/2011— Well circulated with 9.8 ppg KWF. Well Dead. Confirmed I communication between 9 -5/8, 13 -3/8 ", and 20 ". Freeze protected . w /diesel. Retainer 9,115' - la Btm pert 9,810' • Milled Retainer 10,137' ' _ - Retainer 10,141' _ ,'. 0 , Retainer 10,480' — ...- PBTD= 10,215' MD & 10,204'TVD -- :* TD = 10,942' MD & 10,930' ND 9 shoe 10,530' L. Max Hole angle = 5.0 © 10,006' MD Open hole to 10,942' '.. MGB 08 -24 -2011 s'� °' PLANNED SCHEMATIC Chevron 102'" 1 MSL ' = p "'' .. 4 - .M """" 134'RKB-Tbg Hgr Leas SMGS 18746 18 I I . 711 .. Well: Di -06 100 '" 2 1 API #: 50- 733 - 20042 -00 PTD: 167 -052 Casing Detail Leg 2, Slot 8 Size Type Wt/Grade/Conn ID. Top Shoe Cmt sx TOC 33" Structural Surf 259' Drive nia 20" shoe 602' 4 ■ 20" Conductor 8511"B" 19.186" ca lc Surf 602' 1,250 sx ca lc. surf Calc TOC 687' 3 13.3/8" Surface 54,5 & 6181.55 12.459" Surf 2,020' 1,200 sx Ca lc 687' 40, 43.5, 478, N -80, butt 9 -5/8" Intermediate &BTC 8.755" Surf 10,530' L550 sx Calc7,883' Completion Jewelry Detail - 2 -7/8 ", 6.4 #, L -80 item # Length I.D. 0.0. Description 1 1.5'? 2.992" 3 -1/2" 8rd tubing hanger 2 .4' 2.441" 3 -1/2" x 2 -7/8" XO 3 1900' 2.441" 2 -7/8" tubing 13 -3/8 " shoe 2,020' @ 2° A Retainer 2,050' - - -- Top perf 2,055' � ci TOC is marked on a CBT as 8,556' a Perforations: Zone Top Btm ft / SPF Date Comments Gas 5,672' 8,962' Isolated G 1 thru G-4 9,240' 9,830 4 Isolated Top perf 5,672' Retainer 5,750' Fish & other in the hole: K Drop bar 10' 1 -1/2" - cemented in CaIc TOC = 7,883' +/- 2500' oft- 7/8 " tubing (3035'to5535') . TOC 8,556'CBT I - ** No Eline /Slickline work documented since 2 -7/8" kill string ran in • 1988. I I 8/2011 circulated with 9.8 ppg KWF. Well Dead. Confirmed communication between 9 -5/8, 13 -3/8 ", and 20 ". Freeze protected I w /diesel. I Retainer 9,115' - __ .- Btm perf 9,810' Milled Retainer 10,137 - _ Retainer 10,141' Retainer 10,480' _ - PBTD= 10,215' MD & 10,204'TVD - = TD= 10,942' MD & 10,930' TVD Max Hole angle = 5.0' @ 9-5/8" shoe 10,530' 10,006' MD Open hole to 10,942' MQ 09 -12 -2011 Chevron South Middle Ground Shoal . 1100 Dillon Platform %.1 MGS ST 18746 06 (Di -06) 9/14/2011 OBJECTIVE: Abandon the 9 -5/8" x 13 -3/8" annulus at +/- 2000'. All perforations were previously abandoned in 1988. - CURRENT WELL CONDITION: Well bore was circulated with 9.8 ppg brine on 8/12/2011. During pressure test operations, a leak developed in the 9- 5/8" casing and the 13 -3/8" casing, and direct communication from the 9 -5/8" casin 20" x 13 -3/8" 4gnulus was confirmed. The suspected depth of the leak, based on time for fluid returns, is +/- 550'. t o k - , — A . � 1.--,e d p. . Current BHP: 2820 psi @ 5535' TVD (based on wellbore full of 9.8 ppg brine). Max Downhole Pressure: 2502 psi @ 5535' TVD (Based on known pore pressures from Tyonek sands). The Tyonek gas sands have an original pore pressure equal to or Tess than a 8.7 ppg MWE (0.452 psi /ft pressure gradient); based . on the three wells listed below that were completed, tested, and flowed to depletion. Ba -14 — Tyonek 31 -1 sand Original Pressure TVD MWE Pressure Gradient 1392 psi 3209' 8.34 ppg 0.4338 psi /ft Ba -18 — Tyonek 40 sand Original Pressure TVD MWE Pressure Gradient 1928 psi 4265' 8.69 ppg 0.4521 psi /ft Ba -32 — Tyonek 40A sand Original Pressure TVD MWE Pressure Gradient 1922 psi 4258' 8.68 ppg 0.4514 psi /ft MASP: 6psi (Based on stabilized shut in tubing pressure, there are no open perforations in the well) PROCEDURE SUMMARY: 1. Rig up E -line. Pressure test lubricator 250psi low / 2500psi high. 1 2. RIH and cut 2 -7/8" tubing at ( + / -) 2,500'. Rig down E -line. 3. Nipple up 11" 3,000 psi BOP stack and pressure test to 250psi low /2500psi high. 4. Rig up work platform; pull ( + / -) 2,500' of 2 -7/8" 6.4 #/ft L -80 tubing with crane. 5. Rig Up E -line. RIH with cement retainer with TCP gun on bottom of retainer and set at ( + / -) 2050'. Rig down E -line. 6. RIH with ( + / -) 2,050' of 2 -7/8" 6.4 #/ft L -80 tubing with crane, stab into retainer. / 7. Fire TCP guns to perforate 9 -5/8" casing from ( + / -) 2,055' to 2,060' with ( + / -) 6 spf. . 8. Rig up and squeeze + L bl s of 15.3 ppg class G cement through retainer. Unsting from retainer and spot ( + / -) 50' of c t ( +/- 4 bbls) on top of retainer. p e ; 0,,,.J 1 R 9. Land tubing hanger, rig down. MGS ST 18746 -06 (Di -06) REVISED BY: MQ 9 -14 -2011 • Chevron Dillon Platform Di -06 09/12/2011 11111 11 111 III 111111 ill 3.45' Shaffer 11" 5000 111 1111,11 Shaffer LWS 11" 5000 ` Blind rams 2.75' ® __ 2 7/8 X 5 Vanable rams - Choke and Kill lines 2 1/16 5M I11 I II I11 I11 I11 w/ unibolt connections 2.00' 'fit, I ti} { t ; I 1 ! I , I , I' li lil III lil lii ° M ` ' I' AIL Drill deck 1.1. 1111111 1 WFT owned Riser 11 5M flange X 10.00' flange 111111111 III 1 II iII'I 2.00' Spacer spool 11 5M flange UOCD X flange nu RI III11Lli1.111.1 2011 July's Baker /Dillon Producti.Well Report • Page 1 of 1 Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Monday, August 08, 2011 3:42 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Cole, David A; Ross, Gary D; Tyler, Steve L; Quick, Mike [ASRC] Subject: 2011 July's Baker /Dillon Production Well Report Attachments: Master Well List TIO Report 2011 08 01.xis Hi Tom & Jim, ( O ' 0 5 Here is July's monthly report for the Baker and Dillon monitored production wells. The Ba -25RD continues to show some increasing pressures in one tubing string and the inner casing. The Ba -5 & 11 wells are still showing slowly climbing pressures (one tubing string on Ba -5 and one tubing and the inner casing on Ba -11). The general pattern of stable or slowly rising pressure trends continued this month. Besides the wells mentioned above, the only other pressure anomaly relates to the seasonal trend in pressures apparent in Di -6 & Ba -32 (before it was killed). Larry Aliki' 46 «Master Well List TIO Report 2011 08 01.xis» 8/9/2011 Plot Oessure & Rate vs Time - Well Di -06 • 400 •9 5/8" 133/8" 350 —• -20" _ I . Tubing 300 -- j 250 v :n 200 'L 1 150 — 100 50 0 — 0 a o a a a a a a a a a o 0 0 0 0 0 0 0 0 0 0 0 o o 0 0 0 0 0 0 0 0 0 0 N O O O) aD N r,: r CO U) r t0 t0 O U) Q C) C) N N O N i i O O 12 O O O C) C) M N N (V N N fV N N N N N N N N N N N N N N N N N N) V 2) ') t0 8 aD 2 O N 2 C) 8 )[) c0 N- O 0) O N N C) 8 U) i0 8 O O O O O O O O O •- O O O O O O O O O O O O O O O O Date 9 5/8" 13 3/8" 20" Tubing TIO Report 06/10/11 250 30 0 315 06/09/1 230 30 0 320, Data Sheet 06/08/11 240 20 0 310 06/07/11 240 20 0 310 06/06/11 240 35 0 310 Di -06 06/05/11 230 30 0 320 06/04/11 225 30 0 315 06/03/11 250 25 0 320 BOT HOLE HYD PUMP 06/02/11 245 30 0 315 06/01/11 240 30 0 310 05/31/11 240 30 0 310 Permit # 1670520 05/18/11 240 30 0 310 04/27/11 240 30 0 300 03/12/11 220 30 0 280 API # 50- 733 - 20042 -00 02/15/11 210 30 0 280 01/05/11 220 30 0 280 12/14/10 210 30 0 280 01/31/2009 to 08/01/2011 11/17/10 220 30 0 280 10/29/10 240 30 0 300 10/09/10 230 30 0 300 08/11/10 250 30 0 320 07/14/10 240 30 0 310 06/16/10 240 30 0 300 05/19/10 220 30 0 300 04/21/10 220 30 0 290 03/24/10 210 30 0 280 02/17/10 200 30 0 280 01/20/10 200 30 0 270 12/20/09 200 30 0 260 11/25/09 210 30 0 270 10/31/09 220 30 0 10/25/09 220 30 0 290 10/16/09 240 30 0 300 10/10/09 240 20 0 300 10/02/09 240 30 0 300 09/25/09 240 20 0 300 8/9/2011 2:36 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 08 01.xIs Di - 2011 March's Baker /Dillon Product Well Report Page 1 of 1 • Maunder, Thomas E (DOA) From: Greenstein, Larry P [Greensteinlp @chevron.com] Sent: Friday, April 15, 2011 1:32 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Cole, David A; Ross, Gary D; Tyler, Steve L; Quick, Mike [ASRC] Subject: 2011 March's Baker /Dillon Production Well Report Attachments: Master Well List TIO Report 2011 03 31.xls Hi Tom & Jim, Here is March's monthly report for the Baker and Dillon monitored production wells. The pressures on the Baker 11, 25RD & 28 wells continue the unexpected increases mentioned last month. Both 11 & 25RD look to be increasing slowly, but 28 may have leveled off. Drilling is aware of these pressures and are making sure the abandonment plans for the Baker wells address any wellbore concerns. All the other wells are still showing the same general up trend or seasonal trend (like Di -6) in pressures and appear to show no other pressure anomalies. The general pattern of stable or slowly rising pressures for the Dillon wells continued this month and most of the Baker wells have stabilized. Larry «Master Well List TIO Report 2011 03 31.xis» ? 1 8 ).1` 4/18/2011 • • Plot Pressure & Rate vs Time - Well Di -06 400 - 350 9 5/8" 13 3/8" ---20" 300 Tubing 250 E 3 200 u�i ._.__..__ N a` 150 100 50 0 I 8 8 8 8 8 8 8 8 8 8 8 8 8 rn 8 8 o o 0 0 0 0 0 0 0 o O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CB N m N CO r t0 N NI N NI N N O N 7 N N N N N O N N ,1 O CB W r c0 __ N N N N N N N N N N N N N N N N N N N N N N � m O N N 8 8 8 O 8 8 O O a N 8 8 N O 8 8 8 O N N 8 O � O O O O O O O O Q � � O O O O O O O O O � O O O Date ,. 11 13 3/8" 20" TIO Report 03/12/11 '` 30 0 02/15/11 '> 210 30 0 Data Sheet 01/05/11 20 30 0' 12/14/10 > 210 30 0 11/17/10 =-. 220 30 0 Di -06 10/29/10 30 0 10/09/10 30 0 08/11/10 250 30 0 320 BOT HOLE HYD PUMP 07/14/10 240 30 0 310 06/16/10 240 30 0 300 05/19/10 220 30 0 300 Permit # 1670520 04/21/10 220 30 0 290 03/24/10 210 30 0 280 02/17/10 200 30 0 280 API # 50- 733 - 20042 -00 01/20/10 200 30 0 270 12/20/09 200 30 0 260 11/25/09 210 30 0 270 09/29/2008 to 03/31/2011 10/31/09 220 30 0 10/25/09 220 30 0 290 10/16/09 240 30 0 300 10/10/09 240 20 0 300 10/02/09 240 30 0 300 09/25/09 240 20 0 300 09/12/09 250 30 0 320 09/10/09 240 30 0 320 09/09/09 240 20 0 09/08/09 240 30 0 320 08/29/09 230 30 0 08/28/09 250 20 0 08/27/09 250 20 0 08/26/09 230 20 0 08/25/09 230 20 0 08/24/09 260 20 0 08/23/09 260 20 0 08/22/09 260 20 0 08/20/09 260 30 0 320 4/18/2011 5:02 PM - TIO Reports 7e.xls J J Dolan Master Well List TIO Report 2011 03 31 (6).xls Di -06 ') .., " .; ~~l~E :'~ fÆ~!Æ~~fÆ ATfASKAOILA5D GAS CONSERVA.TION COMMISSION Mr. Dave Cole Oil Team Manager UNOCAL P.O. Box 196247 Anchorage,. AK 99516-6247 Re: Middle Ground Shoal Unit Platforms Dillon and Baker Dear Mr. Cole: ) FRANK H. MURKOWSKI, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ",...,."'t::~.~. t ...... ;(il1}'79 ~"'1. This letter confirms your conversation with Commission EngLl1eer 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~ 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 (Ala 7 for Baker and Ala 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 llbmitted forthwith. ,~' smcere~~ . No an Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ilday of November, 2004 Encl. SCANNE[) NO\/ 2 3 2004 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): 110' RKB MSL 8. Property Designation: Dillon 11. Total Depth MD (ft): 10,942' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 5,672 to 8,962 Packers and SSSV Type: ) STATE OF ALASKA ') ALASKA Oil AND GAS CONSERVATION COMMI::,,,ION APPLICATION FOR SUNDRY APPROVAL 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 OCT 1 2 2004 Perforate U Af~{ieQiLt)i @;m1~ BiSt<f¡~,.U . n . Stimulate D Time Extension D AIEU'¡f~"Jr"'II]""Oth~~t~r.?!QO ¡h.Vc:eu ~~~~: Re-enter Suspended Well D Monitor Frequency 5. Permit to Drill Number: P. O. Box 196247 Anchorage, Ak. 99519-6247 Exploratory D 67-52 / Service D 6. API Numbe/: /" / 50-733-20042 / / / / Effective Depth MD (ft): Effective Depth TVD (ft): 'Plugs (measured): Development Stratigraphic 0 D 9. Well Name and Number: Di-06 10. Field/Pools(s): SMGS/Hemlock PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Junk (measured): 10,931' Length Collapse 5,535' 5,532' Plug @ 5,532' Burst Size MD 563' 1,983' 20 13-3/8 95/8" 603' 2,021' Service D 10,499' 10,519' Perforation Depth TVD (ft): 5,669 to 8,954 Tubing Grade: Tubing MD (ft): 5,650' 2-3/8" Packers and SSSV MD (ft): 6.5# N-80 12. Attachments: Description Summary of Proposal Detailed Operations Program D BOP Sketch 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 GasD WAG D GINJ D WDSPL 0 Date: Plugged WINJ D D Abandoned D D 17. I hereby certify that the foregoing is true and co ect to the best of my knowledge. Contact Printed Nam:a- D~A. le....- Signature -' / / /' / /¿ //., r¿I.J?,i:.(/ U~ Title Oil Team Supervisor 907-263-7805 Date COMMISSION USE ONLY Phone 28-Sep-2004 Conditions of approval: Notify Commissi so that a representative may witness Plug Integrity D Other: Subsequent Form Required: Sundry Number: ..3 C> tf- Lf'J-1 Location Clearance D D Mechanical Integrity Test RBDMS BFL NOV 222004 APPLICATION RETURNED 11/17/04 NOT APPROVED BY COMMISSION COMMISSIONER BY ORDER OF THE COMMISSION Date: Approved by: t(p~ Form 1 O~ Revised 12/2003 R~GINAL Submit in Duplicate STATE OF ALASKA 'T..~ C C',.\ L: ''1 I ""..",~ ALASKA OIL AND GAS CONSERVATION COMMISSION ¡ <: [:~ , c 1\, f:: [,I REPORT OF SUNDRY WELL OPERATIONSFEB 262004 1. Operations Abandon U Suspend U Operation Shutdown U Perforate []: ~¡: t, ri n .!~', VYF,iv~!,D .. ' c'''." '~c .~ 111 Other L::J \ ~\ ,} ~ l Performed: Alter Casing 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Time E~n,$:i(mD" Shut in and secure Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Union Oil of California 4. Current Well Class: 5. Permit to Drill Number: Name: aka Unocal Development 0 Exploratory 0 67-52 3. Address: P. O. Box 196247 Stratigraphic 0 Service 0 6. API Number: Anchorage, Ak. 99519-6247 50-733-20042 7. KB Elevation (ft): 9. Well Name and Number: 110' RKB MSL Di-06 8. Property Designation: 10. Field/Pool(s): Dillon SMGS/Hemlock 11. Present Well Condition Summary: Total Depth measured 10,942' feet Plugs (measured) cmt plug@5,535'-10,137' true vertical 10,931' feet Junk (measured) retainer@5,750' Effective Depth measured 5,535' feet true vertical 5,532' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 563 20 603 603 Surface 1,983' 13-3/8 2,020 2,019 Intermediate Production 10,499' 95/8" 1 0,530 10,519 Liner Perforation depth: Measured depth: 5,672-5,702 6,230-6,250 7,892-7,928 8,192-8,208 8,310-8,330 8,640-8,654 8,952-8,962 9,240-9,270 9,315-9,390 9,455-9,480 9,495-9,655 9,680-9,830 True Vertical depth: 5,669-5,698 6,226-6,246 7,885-7,921 8,185-8,201 8,303-8,323 8,632-8,646 8,944-8,954 9,232-9,262 9,307-9,382 9,447-9,472 9,472-9,447 9,672-9,821 Tubing: (size, grade, and measured depth) 2-7/8" 6.5# N-80 @ 5415' Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: This well was shut in prior to and subsequent to operations 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 0 Development 0 Service 0 Daily Report of Well Operations 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¡Sundry Number or N/A if C.O. Exempt: Contact ""--' '" . Printed Name P. M. Ayer Title Petroleum Engineer Signature fv1L~ Phone 263-7620 Date 18-Feb-2004 rl v Form 10-40\~~~~1".\11~~~{;:¡¡~ 1 () 2004 0 RIG I ~, A I IØ)US 8ft FEB 2 7 21Jo~ ~~ >ø ~ ~ 50 ....., 0 ro = ~ (J') Q . C) 0 3 3. D ~. ':j ? ."" ü'") ^" ~) Q Pertinent Data: Spud Date Surface location South Middle Ground Shoal ADL 18746 Well NO.6 Hemlock Conglomerate Platform Dillon 9/20/67 Leg 2, Slot S 701' FSL, 1867' FWl, Sec. 35, TSN, R13W, S.M. Top of Cement @ 5535' MD Elevation Subsurface location TO. 904' FSL, 153&' FWL, Sec. 35, T8N, R13W, S.M. 110' KB TO PBTO Casing Perforations , --' ;;0 m () m . , ¡, a <..Q "'"--' u:> '-.:::;} ~ £'~ -~ r~TI 0 Initial P<*ntlal Initial StImulation Reservoir Data: Cored Intervals CST Intervals and Results Log Inventory 10,942' MD 10,931' TVD Completion Record: 1) 3 1f28 8 RND tubing hanger 2) 31f28 8 RND X 2 7/S" Butt. X-over 3) 14 jta. 2 7/S" Butt. tubing 4) 27/8" Butt. X2 7/S" S RND X-over 5) 162 jts. 2 7/S" S RND tubing 6) Mule shoe @ 5415' 10,137' MD 10,128' TVD 20" 85# 13 3/S" 54.5# " 9 5/S" 40#,43.5#, 47# 603' MD 202O'MD 1250 ax cmt 1200 ax cmt 1550 sx cmt 10,530' MD G.1 G.2 9240'.9270' 9315'.9325' 0-3 9350'.9390' 9455'.9480' 9495'-9555' 957S'-9638' G-4 9645'-9655' 9680'.9765' 9780'.9830' 5721 BOPD, 0 BWPD, 1316 MCFD Nine 10,533'.10,555', cut 22', recovered 14' 10,530'.10,555', ISIP 5220 Psi, IFP 197 Psi, FFP 1459 Psi, IHP 5442 PSI FHP S442 Psi, recovered 15 Bbls oil, 9 Bbls mud, 105 Bbl. GCW IEL-SP, BHCGR, 10/13-17/67; GR- Temp., 6112/76 J W [ 20.,85# @ 603' MD 13 3/8., 54.5# @ 2020' MD 5620' 5672'-5702' Retainer @ 5750' 5775' 6230'-6250' 7892'-7928' 8192'-8208' 8310'-8330' 8640'-8654' 8952'-8962' 9240'-9270' 9315' 9390' 9455'-9480' 9495' ,. ~9~ 9680' 9830' TO 10,942' MD ETD 10,137' MD DILLON PLATFORM API # 50-733-20042-00 S. MGS UNIT # 6 WELL HISTORY Well #6 DATE COMPLETED EVENT 1968 9/16 Sup. # 1 pull tubing and Kobe pump 1982 10/7 Return to Production 1983 8/5 Pull and Replace BHA 1988 2/5 Abandonment 1989 8/1 I nitiation of gas production 2002 12/09/2002 This well was shut in and isolated at the surface with multiple flanges to isolate the well from surface flow lines. Di#6 Hist 11-6-67 .doc, last revised 2/18/2004 page 1 DI-S _.5bb1S ¡abtft ¡'S'bblS - DI-3 2 bbls 12 bbIs 25 bbls 20 x 13 Sf8 0.1815 SOO 54.45 31/2 tbg. 0.0087 300 2.61 18 518 x 13 3/8 0.1291 SOO 38.73 27/8 tbg. 0.00879 300 1.737 13 3/8 x 9 518 0.0871 300 20.13 depth 656 334 9 5/8 x dual 3 1/2 0.0807 300 15.21 355 9 518 x dual 2 7/8 0.0871 300 17.13 pump limit 21 psi 9 5/8 x 3 1/2 0.0826 300 18.78 Don Sta dual LEG ROOM.1 185/8x 133/8 13 3/88 X 9 5/8" 95/88 X 3 1/2- 22 bbIs 30 bbIs I I ~ ABN-1 0 DI-13 LEG ROOM '2 DI.18 1.2bb1 20bbIs DI-17 0.75 bbls 15.5bbIs 20 bbIs DI-16 15 bbIs 20bbII DI-l1 7;4bÞIs DI-8 25 bbIs DI-7 ABN-6 ~ LEG ROOM '4 we" .2 well 14 we" 89 We" " 10 We" 813 We" #7 We" #8 We" 811 we" 816 We" 17 We..818 we" #3 We" #5 We" " 12 We" .14 we" 815 WELL BAY # 1 Pumped down tbg.tbg on Yac. 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 1.5. tbg. Returned up short side 100 bbIs. 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 3.8)( 9 5/8 RumP and bleed 3 bþ~s i~ an~. 9 5/8xtbg fluid packed with oil. 14.4 bblsin tbg. well 10 Is abondoned Fill 20" ann 2 bbls, tbg on yac 7bbls In 13 3/8 x 9 5/8 28 bbls 9 5/8 x tbg. 5 I.s. 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 surface. Pumped Sbbls in tbg.' 20 bbls in 9 5/8 ann.Annulus and tbg. Have oil returns 0 press on well. 20" fluid packed. 13 3/8 x 9 5/8 2 bbls and started getting diesel fluid back to surface. Pumped SbbIs In tbg.' 20 bbls in 9 5/8 ann.Annulus and tbg. Press up to 500 psi. on both tbg. Strings had oil to top no press on tbg. Pumped and bled 7bb1s In tbg. Annulus. When annulus was fluid packed. Oil at surface.5 bbls in 13 5/8 x 9 5/8 press limit. .5 bbls In 20" Well had SOps!. On 13 3/8x 9 5/8 bleed down to 20psi put bbls of 9.8 fluid. 95/Sann. 20 bbls fluid, tbg.5bbls each, wells 185/8 has 110 psi. bled off and fluid packed with press limit of SO psl..75 of a bbl. Well had 100psl. On 13 3/8x 9 5/8 bleed down to 20psi put TSbbIs of 9.8 fluid, 95/8ann. 20 bbls nUld, tbg.5bb1s each, wells 185/8 has 60 psi. bled off and fluid packed ann with .75 bbls. Well had ISOpsl. On 13 3/8x 9 5/8 bleed down to 20psl put 20bbls ot 9.8 fluid. 95/Sann. 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 5.5. 9 5/8 x tbg. 25 bbIs, 13318 x 9518 fluid packed wI 12 bbls. 20" ann. 2 bbIs. Ruid packed Pumped 4 bbls 1.5. tbg. 4 bblss.s.Rlu to 9 5/8 x 3 1/2 ann. Pumped 15 bbls fluid packed on to surface. Pumped 4bbls down tbg Is, 4 bbls 5.5. both went on Yac. Pumped 15 bbls 95/8 x3112. Wdh50 psi press limit 0 bbls In 13 3/8x 95/8 Fluid packed 20x 133/8 2 bbls, Ruld packed 13 3/8x9 5/8 12 bbls press up to 200 psi and held. Rig up pump 5 bbls 1.5. 25 bbl 5.5. 8t 9 5/8 x tbg. 8 bbls fluid packed 011 to surface 13 5/8x9 5/8, RIU to 20" ann fluid pack 5 bbls. Press limit 20 psi. ' '""'" STATE OF ALASKA AL .~, OIL AND GAS CONSERVATION COMM,, ~ON APPLICATION FOR S'UNDRY APPROVAL 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Pull tubing __ Variance __ 2. Name~f Operator._ .... j 5. Type. p~f W_e. ll.L , union Mil Company of Ca±i~orn~a [UN~ent.~ .............. -{ ExploratOry__ 3'Addre~.o. Box 196247, AnCh., AK, 9~519-6~.tj~rap.hic- service __ 4. Location of well at surface Leg # 2, Operation shutdown ~ Re-enter suspended well __ Plugging ~ Time extension ~ Stimulate ~ Perforate ~ Other. Slot 8, Platform Dillon 6. Datum el~g (%~]~B~sT, 7. Unit or Pr~a~i t 8. Well number 699' FSL, 1872' FWL, Sec. 35, T8N, R13W, SM At top of productive interval 856' FSL, 1605' FWL, Sec. 35, T8N, R13W, SM At effective depth 742' FSL, 1739' FWL, Sec. 35, T8N, R13W, SM At total depth 910' FSL, 1530' FWL, Sec. 35, T8N, R13W, SM 12. Present well condition summary Total depth: measured true vertical 10942' feet 10931' feet Plugs (measured) 9. Permitnumber 67-52 10. APInumber 50-- ~33-20042 11. Field/Pool SMGS/Hemlock See attached schematic feet Effective depth: measured true vertical 5535' ~et 5532' ~et Junk (measured) Casing Length Size Cemented Structural Conductor 563 ' 20" 1250 SX Surface 1983 ' 13-3/8" 1200 sx Intermediate Production 10499 ' 9-5/8'' 1550 SX Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) See.attachment Measureddepth ~ueve~icaldepth 603' 603' 2020' 2019' 10530' 10519' 2-7/8" 6 5# N-80 @ 5415 13. Attachments Description summary of proposal ~ Detailed operations program .~ BOP sketch 14. Estimated date for commencing 'operation Date approved October 28, 1991 16. If proposal was verbally approved 15. Status of well classification as: Oil ~ Gas __ Name of approver Service 17. I hereby cerlY~th at the foregoing is true and correct to the best'of my knowledge. Signed %°"-~T S~. ~,f~-~"~' Title RRGTO.~T. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Suspended .__ ¢?--% Approval No. Commissioner Date / SUBMIT IN TRIPLICATE ORIGINAL o~uN',:D BY LONNIE C. SMITH DRILLING MA _N[A~m~R ~ - a°~ - ~ ~ ............................................................................................................................ :::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::: .:.:.:..:.:-:-:.:,:.:.:.:.:.:.:-:.:.::.:.:.:.:.:.:.?.:.:.:.: .:.:.:.:.:.:-r.:.:.:.:.'.:.:.:.:.r.:.:.:.:.:.:.:.;.:.:.:.r.:.:.: :.:.:.:.:':.;:.:.:.r.:.:.:.:.:.:.;.:.:.:.:.;.;.;.;.;.;':.: :.:.:.:.:.:.r.:.:.:.:.:.:-:.:.:.:.:.:.r.:.:..:.:.:.:.:.:.:.:.: ,-,-,.,.,.,.,-.,.,-.,.,.,.,.,-...,-.,.....--........... I ECEIVED Gas Col~s. Commission ltnchorage Pertinent Data: Spud Date Surface Location Suimurface Location Elevation TI) PBTD Ca~ing Perforations ~--.-- JflitJal~ntJal c) Initial Stimulation Reservoir Data: Cored Intervab DST Interval~ and Re~uit~ South Middle Ground Shoal ADL 18746 Well No. 6 Hemlock Conglomerate Platform Dillon 9/20/67 leg 2, Slot 8 701' FSI., 1867' FWL, Sec. 35, T8N, R13W, S.M. TD - 904' FSI., 1538' FWL., Sec. 35, TSN, R13W, S.M. 110' KB 10,942' MD 10,931' TVD 10,137' MD 10,128' TVD 28' 65# 13 3/8" 54.5# 9 5/8" 40#,43.5#, 47~ 0-1 9240'-9270' G-2 9315'-9325' 9350'-9390' (;I-3 9455'-9480' 9495'-9555' 9378'o9638' G-4 9680'-9765' 9765'-9830' 5721 BOPD, 0 BWPD, 1316 MCFD 603' MD 1250 Jx cmt 2020' MD 1200 8x cmt 10,530' MD 1550 ex cmt Top of Cement @ 5535' MD Completion Record: 1) 3 1/2' 8 RND tubing hanger 2) 3 1/2' 8 RND X 2 7/8' Butt. X-over 3) 14 its. 2 7/8' Butt. tubing 4) 2 7/8' Butt. X 2 7/8' 8 RND X-over S) 162 its. 2 7/8' 8 RND tubing 6) Mule shoe @ 5415' Nine 10,533'-10,555', cut 22', recovered 14' 10,530'.10,555', ISIP 5220 F~, IFP 197 Psi, FFP 1459 Psi, IHP 5442 PSI FHP 5442 Psi, recxwerud 15 Bbb oil, 9 Bbb mud, 165 Bbb GCW IEL. SP, BHC.GR, 10/13.17/67; Gl:l-Temp., 6/12/76 11) 10,942' MD ETD 10,137' MD @ 6O3' MD 13 3/8", 54.5# @ 2020' MD 5672'.5702' Retainer @ 5750' 5775' 6230'-6250' 7892'-7928' 8192'-6208' 8310'-6330' 8952'-6962' 9315' 9390' 9455'-9480' 9495' 9655' 9 5/8", 40, 43.5 47#@, 10,530' MD South Middle Ground Shoal ADL 18746 Well No. 6 Procedure for suspending and freeze protecting well: 1) 2) 3). Circulate power oil down tubing taking returns from the tubing X 9 5/8" annulus. Tubing and 9 5/8" X tubing-annulus will be freeze protected at this point. Close all valves on the well head. Install gauges on the tubing and 9 5/8" casing X tubing annulus. RECEIVED D ~C - 9 199'~ Alaska Oil & Gas Cons. Commission Anchorage 1. Operations performed: Operation shutdown __ Stimulate ~ Plugging ~ Pull tubing ~ Alter casing ~ Repair well ~ Pull tubing 2. Name of Operat0UNOCAL) ' ' . ' j/45 Type of Well: ~r ion Oil. Company of California Development x..~- Exploratory __ 3. Address Stratigraphic ~ P.O. Box 190247, Anch.,-AK, 99519 Service__ 4. Location of well at surface Leg #2' conctucl:or" ' 1989' FNL & 588' FWL, Sec 31, T9N, R12W,.SM At top of prod~9~ in~al "A" Zone at 5300' MD 1929' FNL & 676' FWL, Sec 31, T9N, R12W, SM Ateffectivede~_T Retainer at 5770' 1915' FNL & 685' FWL, SeC 31, T9N, R12W, SM 768' FWL, Sec 31, T9N, R12W, SM STATE OF ALASKA "~'~ o," REPORT OF SUNDRY WELL OPERATION Perforate ~ Other __ 6. Datum elevation (DF or KB) 101 ' RKB ABOVE MLWeet 7, Unit or Property name MGS STATE 17595 8. Well nur~1,1 No. 6 '10. APl'nun[l~_10073 50-- il. Fiell~/f~lle' Ground Shoal 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7" See 7,4 0 0 ' feet Plugs (measured) 7,396' feet feet Junk (measured) 6,750' feet 6,747' Size Cemented 20" 1192 sxs Measured depth 612' Casing Length Structural 612 ' Conductor Surface 2010 ' Intermediate Production Liner 7397 ' Perforation depth: measured 13-3/8" 1300 sxs ji~.~.!~C. ~' 2010' attached sheet ~e~-~¢~ o~ True vertical depth 612' 2010' 7393' at 5149' at 5075'. safety valve @ 51( true vertical ~,e~... Tubing (size, grade, and measured depth) LS: 2-7/8", 6.4#, N-80 Buttress SS: 2-3/8", 4.6#, N-80 Buttress Packers and SSSV (type and measured depth) Baker Model "D" pkr @ 5745'; Baker SC-iL pkr @ 5129'; Baker "FVLE" 13. Stimulation or cement squeeze summary 14. Intervalstreated(measured) See attached history Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Dat~ OiI-Bbl Gas. Mc, Water-Bbl Casing Pressure 0 0 - 715 ll~. Status:of Well classification as: Oil .×. Gas Suspended Service Drilling Manager Tubing Pressure SUBMIT IN DUPLICATE Prior to well operation 0 Subsequent to operation 210 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Gary ~~ Regional ned , ~ ,...,,_~ ~,,~ Title Form 10-404 Rev 0~/8~ ' 5' TUBULAR DETAIL DATE 4 FF~TGt_~991 PAGE ON~ WELL TUBING CASING FACILITY BAKER STRING LONG ~IZE ~ 7/8 WT ~NL]. IDESCRIPTION ~6 ~0 IIdULE SHOE 3 15/16 X 3.00 IB~KER SEALS 4.00 X 3.00 ILUCATOR GOB 4.25 X 3.00 tXO 2 5/8 EU >,-> 3 1/~ EU 13.~5 X i~UiDE SUB 2 3/8 EU )-> ~ 3/8 lEU GUIDE FIN OD 6.00 BODY OD 1~.00 ID 2.0625 BODY H~ 4 FIN~ IA[ 90 DEG Z; 3/8 EU OTIS "XN" NIPPLE WI-I-I-t COLLAR 2.625 X 1.7~1 2 3/8 EUE 4.~# N-80 PUP 3.00 X 1.875 ~ 3/8 EU 4.6# N-80 PUP BAKER 2 ~/8 EU ~UB SURFACE SAFETY VALV~ MODEL FVLE THERE IS A EXTURNAL YRANMIBGION LINE FROM TH~ BU]"TOM OF THE KOBE CAVITY TO 1.5' ~LUW ['HE TOP OF THI~ ITEM. THE LIN~ IS TU fi..~E OD OF TOOLS IN BETWeeN UDs 0 -1.5 ~.0625 / 1.5 - 6.7~ 3.00 / ~.72 - 7.22 4.00 / 7.~2 / 8.~2 3.50. ID 1.875 lXO ~ 7/8 EU )-)2 ~/8 EU ~.625 X 1.995 2 7~8 EU ~.4# N-80 PUG' OTIS 2 7/8 EU "AA" SLEEVE ~.9~7D X 2.313 KOBE CAVITY. ~E ATTAGHED DRAWING Xb 2 7/8 BUTT )-> 2 '7/8 EU 3.90 × ~ 7/8 6.4# N-80 BUTT PUP 2 7/8 6-4~ N-BO BUTT TBG 2 '7/8 6.4~ N-80 BUTT PUP 2 7/8 6.4# N-80 BUTT TBG 2 7/8 6.4~ N-80 BUTT ~'UP ~ '7t8 6.4# N-80 BUTT TBG .,1o ~ 7/8 6.4ff N--~O DUTT PUP ............. ,. 6.4# 8RADE N-80 THD bU'IT L~NGTH ITOP .30 151~9.46 10.76 15138.70 .82 1513'?.88 1 .96 1~136.92 I I I 2.85 15134.0'7 I 1.28 1513~.79 12.10 ~1.20.69 ! ~.~5 15117.44 4.07 .84 4.14 J~.21 21. 7~ 1.34 1~.1'? 8.13 2044.93 931.~9 BO'r TOPI 5149.7G 514~.46 5138.7~ 5137.88 ~136.9~ 5134.~'? 5152.79 5120.69 I ~104.41 1b105.25 ~100.27 15104.41 I 50~?.06 15100. 27 5~75.32 i 5097.06 507~. 98 t 507~. ~ 5061.81 ~5073.98 4~67.5~ 15061.81 4~61.~6 14967.59 291~.53 14961.46 1979.$1 12911.50 19/d.~l J1979.~1 ........... + .................. TUBULAR DETAIL DATE PAGE FOUR WELL ~ 'I'UBIN£~ SlUiNG ~IZE I Nu. IDESCRIP'¥ION + ....... + .... KEY SUB FA~ILII'Y 1.50 I I < .... 5,0615 OD I I I I I I 5.'.:":'i~ I ( .... 3.50 OD I I I I i I --+,,~ I ++< .... 4,00 OD I l'O ODs ON BAKER FVL~ SURF'ACE ~AFETY VALVE GRADE LENGTH TOP ]HD I BOTTOM ,+ TUBULAR DETAIL DA-[E .,,fi FEB 1991 PAGE THRE~ WELL, ~ 6 TUB I N(.-'~ ._.X.'__ FRCILI1-Y BAKER STRIN~ SHORT SIZE 2 5/@ WT 4.6# CA5 I I Nu. I DEECRIi;'TION KOB~ CAVITY. ~ ATTACHED DETAIL X~ 1 1/~ NU 10 RD (-) 1 1/4 ~.U 10 RD I 1~/16 X I 1/4 COLLAR 1 1/4 NU 10 RD 1 1/4 ~.~# N-80 1 1/4 10 RD PUP XU 2 ~/~ BUTT )-) 1 1/4 NU 1~ RD ~.87~ X 1,28 2:J/8 4,6~ N-80 BUTT TBG 2 ~/~ 4.6# N-~O BUFT PUP ~ 3/8 4.~ N-80 BUTT ~ ~/8 4,6# N-80 BUFT PUP 2 ~/8 4.6# N-80 BUTT PUP ~ 8/8 4.6~ N-80 BUTT PUP ~ 3/8 4.6# N-80 BUTT PUP J ~/~ 4,6# N-~O BUTT PUP 2 3/~ 4.~ N-80 BUTT PUP ~:: ~/8 4.6# N-'80 BUTT PUP 1/2 6" UIW DUAL 't~ HANGER 2 3/8 BUTT )-.< ~ 3/8 £~ HYDN~L '[ O'TAL JOINT~ I FOTAL HANGING L~NGTH I ALL ~ J~/8 BUTT PU~'5 CAME FROM I I I I l l I 161 GRADE. ..... ,.N..F_8.~ '[HD BU'["[' LENG T H 81.74 1.78 · 29 10.10 TOP' I BOT'TOh'I i ,,i, 4,, 5075.32 ~073,54 ~073.25 506~.1~ 5097.06 ~075,~ D073.54 507~.' .... 1.41 5061.74 5063.15 95.19 4968.55 5061.'74 3. i2 4965.4~ 4906.94 58.49 4965.43 5-02 53,4'7 58.49 5.08 48.39 53.47 5. 1"~ 4~.'27 48.39 ~.10 41.17 43.27 ~, 1~ ~.~ 41. 17 5.18 ~2.84 ~8.02 0.67 30.7~. 5066.34 30, 7~. 0.00 31. 39 ~0. 72 TUBULAR DETAIL DATE 4 FEB 19~1 ~GE TWO WELL. ~ 6 [L~BING X ~iitRING LONG SI ZE ~ 7/8 INO. IDESCRIPTION 21 41 161 FACILITY BAKER WT 6.4# GRADE N-80 7/8 6.4~ N-80 BUT¥ TBG 7/8 6.4~ N-80 BUTT PUP 7/8 8.4~ N-80 BUTT TBG '718 6.4# N-80 ~UTT ~Uk' 7/8 6.4# N-80 BUI"T PUP 7/8 6.4# N-80 BUTT PUP 7/8 6.4# N-80 BUTT PUP 7/8 6-~# N-80 BUTT PUP' 7/8 6.4~ N-80 BUTT PUP 1/~ CIW DUAL ]BG HANG~R 7/8 BUTr )--.( 2 7/8 CS HYDRIL TU'TAL ~OINTS TOTAL HANGING LENGTH LENGTH 641. 99 5.12 1266. 71 10. 10 5.10 '::'. L ~.10 1,53 0.67 ~0. '72_ LANDED LOCATOR SUB 1,5' ABOVE P'AGKER, PKR DEPTH DIL ~129.54 PKR DEPTH TBG 5140.20 USED 10 PUPS FROM RA~K (THE TOP 10 IN THE STRING) THD BU'I"r' TOP 1331.2~ 13~6,10 59.39 45.~9 44.19 4~.14 BOTTOM 1975.21 1331. ~2 1326. 10 59. 39 44. 19 31.3,9 ~0.7~ 0.00 4~. 14 39.02 38. '~ 31.39 3g, 7'~ m .. o]~ 5~A'''"' ,! IZI.'.q-,H -- 1~-~/~" 54.5# 2010' BAKER SC-1 PKR O 5123' DIL 3-1/2" 9,2# N-80 0,012" WIRE WRAPPED BAKER WELD SCREEN GRAVEL PACK 20-40 MESH OTTAWA SAND BAKER SUMP PKR @ 5745' DIL 7" 23 &: 26# ~ 7397' 2, B 3 C 7 18 13 'Iai 12 ED TUBING DETAIL ILONG STRING (POWER FLUID) 1) ClW HANGER, BUTI~ESS e 30.72' 2) 2-7/8 BUTT PIN x 2-7/8 BUTT PiN PUP r3) 2--7/8" 6.4~ N--80 TBO, aUTI' W/ SP CL CPLGS 4) 2-7/8 sm"r BOX ,, 2-7/8 ,:'U 8RD P~. X-OVER · 5074' 5) KOBE 2-1/2" MODEL "D" BI-IA e 5075' SHORT STRING (PRODUCTION) A) CN/ HANGER, BUTTRESS · 30.72' B) 2-3/8 BIJTT PIN x 2-:3/8 BIJ1T PIN PUP C) 2-3/8" 4.6# N-SO TBO, BuTr W/ SP CL CPL(~S D) 2-;3/8 BUTt BOX x 1-1/4 NU lORD PIN X-OVER · 5062' E) 1-1/4" 2.3# N-80 PUP NU lORD · 5063' TAIL ASSEMBLY e) 2-7/8- gU m~O ohs '~- SLEEVE · 5097' 7) 2-7/8" 6.4# N-80 EU 8RD PUP · 5100' 8) 2-7/8" EU 8RD BOX x 2-3/8" EU SRO PIN X-OVER · 5104' 9) 2-;3/8" BAKER FLVE TUBING SAFEW VALVE · 5105' 10) 2-3/8" 4.6# N-80 £U aRD PUP · 5113' 11) 2-3/8" gU aRD O~S '"/~" SLEEVE · 5117' ~2) 2-3/8" 4.~ N-SO £U aRD PUP · 512~' ~3) 2-3/8' EU 8RD OhS '"XN" N~PLE · 5133' 14) 2-3/8# EU 8RD BOX x PIN CENTRALIZER SUB · .5134' ;) BAKER SEN. ASSY W/ 2-3/8" EU aRO BOX UP · 5138' ;6) UULE SHOE · 5150' "A" ZONE INTERVAL 5300'- 5330' 5444'- 5481' 5522'- 5548' 5570'- 5635' 5644'- 5720' CMT RET W/ BP KIT @ 5770' PERFS F/ 5782'- 6607' @ INTERVALS CAST IRON BP @ 6750' PERFS F/ 7092.5' - 7131.5' @ INTERVALS ADL 17595 WELL NO. 6 COMPLETION SCHEMATIC UNION OIL COMPANY OF CALIFORNIA (dba UNOCAL) DRAWN: DAC SCALE: NONE DATE: 3-8-91 Baroid Drilling Fluids, Inc. March 5, 1991 Mr. Don Chudanov Unocal Oil & Gas Division P.O. Box 190247 Anchorage, Alaska 99519-0247 Re: Workover/Completion Fluids Recap Baker Platform BA-6 Dear Mr. Chudanov: Enclosed is the material usage and cost associated with the above referenced well. Please refer to the recap for specific details in reference to the operations involving the completion fluid. The costs are broken down as follows: Ammonium Chloride Calcium Chloride Sodium Bromide Sodium Chloride Total Salt Cost 60 Barrel Litesal Pill Technical Service Miscellaneous Total Well Cost $ 5,987.52 $ 5,956.80 $ 89,554.40 $ 14,919.45 $116,418.17 $ 8, 175.38 $ 8,505.00 $ 4,016.99 $137,115.54 The base formulation and cost of the 78 pcf fluid is as follows: Filtered Inlet Water .926 Barrels (63.5 pcf) 3% KC1 12 ppb NaC1 60 ppb Yields 1 barrel 71.8 pcf (9.6 ppg brine) Cost per barrel $11.88 2000 West Int'l. Airport Road, Suite A-10 * Anchorage, Alaska 99502 (907) 248-3511 · Fax (907) 248-5390 Page 2 Mr. Don Chudanov Unocal Oil & Gas Division Re: Workover/Completion Fluids Recap Baker Platform BA-6 March 5, 1991 71.8 pcf (9.6 ppq) brine .965 Barrels Sodium Bromide 48 ppb Yields 1 barrel 78 pcf NaBr/NaC1/KC1 Brine Cost per barrel $86.57 If you require any additional information or have any questions please do not hesitate to contact me. Sincerely, BAROID DRILLING FLUIDS, INC. T. Jay Olive Technical Sales Representative cc: Bush Neve' File Attachments Unocal Oil & Gas Division Material Usage and Cost BA-6 Workover MATERIAL Ammonium Barazan Calcium Chloride Dirt Magnet FL-? Liteplug Liteplug-F Liteplug-X Litesal-XCP Plugsal Salt SDI Defoam Sodium Bromide TOTAL PRODUCT COST Technical Service Roundtrip Airfare Rework Charges Kenai Borough Tax UNIT USAGE COST/UNIT 66 LBS 126 $ 4?.52 50 LBS 2 $ 3?8.42 80 LBS 170 $ 35.04 500 LBS 1 $1,600.00 50 LBS 1 $ 68.50 50 LBS 30 $ 65.50 50 LBS 30 $ 65.50 50 LBS 30 $ 65.50 50 LBS 26 $ 86.63 50 LBS 28 $ 32.27 80 LBS 1,365 $ 10.93 50 LBS 5 $ 94.37 55 LBS 1,040 $ 86.11 21 $ 405.00 1 $ 111.00 1 $ ?3.?4 10 $ 10.00 AMOUNT $ 5,98?.52 $ ?56.84 $ 5,956.80 $ 1,600.00 $ 68.50 $ 1,951.50 $ 1,951.50 $ 1,951.50 $ 2,252.38 $ 903.56 $ 14,919.45 $ 471.85 $ 89,554.40. $128,325.80 $ 8,505.00 $ 111.00 $ ?3.74 $ 100.00 TOTAL WELL COST $137,115.54 Unocal Oil & Gas Division BA-6 Workover Order Document Numbers: Charges: Z34669 Z34673 Z34674 Z34676 Z34688 Z34696 Z34697 Z34705 Z34713 Z34724 Z34743 Z3474 Z34748 Z34759 Z34749 Credits: Z34702 Z34717 Z34718 Z34719 Z34753 Z34754 Z34755 Amount: $ 8,426.10 $16,725.36 $31,447.51 $68,898.00 $14,619.55 $ 5,712.40 $ 5,638.95 $26,378.80 $ 4,981.00 $ 2,440.00 $ 9,821.20 $20,540.07 $11,640.81 $ 1,225.00 $18,171.92 Total Charges $14,815.26 $10,785.07 $17,545.11 $12,754.64 $19,283.12 $11,640.81 $22,727.12 $246,666.67 Total Credits - $109,551. 13 Total Well Cost - $137,115.54 4792 BUSINESS PARK BLVD. BUILDING F, SUITE 3 ANCHORAGE, ALASKA 99503 TELEPHONE (907) 563-0825 FAX NO.(907) 563-0385 BIAKEIt SAND CONTROL A Baker Hughes company February 21,1991 Unocal Oil & Gas Division P.O. Box 190247 Anchorage, Alaska 99519-0247 Attn: Don Chudanov Re: Completed Gravel Pack Summary Platform Baker's MGS 17595 # B-6 Baker Sand Control is pleased to submit this summary of the completed gravel pack on platform Baker's MGS 17595 # B-6. Enclosed is a detailed job report with steps and procedures that were implemented on the job. PRE-PACK LOWER "A" ZONE INTERVAL Perfs:' ~102': 5522' - 5548'; 5570' - 5635'; 5644' - 5655' Guns: 4-5/8" OD TCP guns, 8 SPF, 25 gram Big Hole Charges Sand Plug Depth: 5655' Retrievable Packer Depth: 5500' Volume Placed Outside Perfs: 138 cubic feet Pump Rate: 9 BPM Pump Pressure: 4200 PSI Pre-Pack Sand: 20-40 Baker Low Fine Gravel PRE-PACK UPPER "A" ZONE INTERVAL Perfs: 67': 5300' - 5330'; 5444' - 5481' Guns: 4-5/8" OD TCP .guns, 8 SPF, 25 gram Big Hole Charges Sand Plug Depth: 5500' Retrievable Packer Depth: 5275' Volume Placed Outside Perfs: 37 cubic feet Pump Rate: 15 BPM Pump Pressure: 4500 PSI Pre-Pack Sand: 20-40 Baker Low Fine Gravel SINGLE ZONE GRAVEL PACK Perfs: 234': 5300' - 5330'; 5444' - 5481'; 5522' - 5548'; 5570' - 5635'; 5644' - 5720' Sump Packer: 5745', Model "D" Size 84-32 Lower Tell Tail: 10' 3-1/2" 0.012 Gage Bakerweld Screen screen Length: 451' 3-1/2" 0.012 Gage Bakerweld Screen G.P. Packer: 5123' Calculated Volume: 67 cubic feet Actual Volume Placed: 74 cubic feet Gravel Pack Sand: 20-40 Baker Low Fine Gravel Fluids: Filtered with a D.E. press to a 2 micron absolute Polymers: A HEC Baker Clean Gel was mixed to yield a 350 cp viscosity. The gel was then cycled through a hydraulic hydrator to remove any micro-fisheyes. It was then filtered through a 25 Whatman filter paper. BAKER SAND CONTROL CONCLUSION Overall the Single Zone Gravel Pack with the High Volume Pre-Pack Fracs was successful. By Pre-Pack fraccing the zones separately a larger percentage of excess gravel was placed prior to gravel packing thus increasing the effective inlet area radially over the entire interval. Baker Sand Control would like to thank you for your business and we look forward to providing you with quality service and products in your upcoming gravel packing and perforating completions. Sincerely, Baker Sand Control, a Division of · Baker Hugh~s Pr~oduction Tools Inc. Darryl Sn9~ Alaska Sal~s Representative DS:rr BAKER SAND CONTROL UNOCAL ALASKA MGS 17595 #B-6 * TOOLS ( SALEABLE ): TOOLS ( RENTAL ): FILTERING: PUMP ING: $ 65,967.00 11,300.00 30,928.48 188,844.69 TOTAL: $297,040.17 UNOCAL BAKER B-6 FILTRATION RE~T 1/25/91 100 00 .............. .:'-:-:- .-_._._:_..~_ ............................................ .............................................................. -.-.-...~:..::.:.. FILTERIN~t HOLE BEFC3:~E FI~:~T PERF :~TA~iE Tilde IN HOUR~ ~--WELL OR UNOCAL BAKER B-6 FILTRATI~ REPOR~ 1/27/91 NILrS, O-'~gC CO00 Oi~O~t 011'00 000~t TIME IN H~ FIL~ R~ ~ UNOC..A,L BAKER B-6 FILTRATION REPO~ 1/26,27/91 :':.------_-_:.;_.: ............................................................... Tilde IN HOUR'~ WELL, ~ PIT III~TUFI~6 ~ Pi~I~ I)lGCflk~E UNOCAL BAKER B-6 FILTRATION REPORT 1/28/91 NIU"6 I~;ODIUM BROMIDE 7~ PPCF t~ ~=:::::-.:_-: ........................................................... ~03 .................... :=._::::.::._- ........................................ ~ ............................... T.-='..-__~.==_. ............................ m .......................................................... FILTERIN~ HOLE FOR :~ECOND ~a .................... P'E'R'FbF~'hb't;i' '.J~3~ .......................... OlgCC QlICO TildE mN HOUR~ WELL OFt PI1' I~IUFtI~ ~- Pi~l~ DIS(INAFI~E I:ILTI~I RI. lit ~f4 UNOCAL BAKER B-6 FILTI:;b~TION RE~T 1/29/91 '~ .... :SODIUM I&qOMIl:~ 79 PPCF I0131 ......=-'---~--::: ....................................................... ~ .......................... :::: ..... ~:~ ............................... ~ ..................................................... ~L ............ ~ ............................................................... ~::~_ P E~FO~N~ JOE TIME IN HOU~ "-'~WELi. OR Pi[ I~'TUFEID -"--PR~:I~ DIS,I3HkFOE FiLT~i #~4t A'~ UNOCAL BAKER B-6 FILTRATION REPORT 1/31/91 UNOCAL BAKER B-6 FILTRATION REPORT 1/30/91 --'-WEll, ~ Pi[ I~'I'UFIH~ --'-- PRINI~ ~I~E FILI'Dt !1/~1 ~ UNOCAL BAKER B-6 FILTRATIC~ REPORT 1/31/91 2/1/91 --'-WEll. QR PI1 HLTERRUNdlq FIL'TRATIONllaN,IRt. UNOCAL BAKER b-6 FILTRATION REPORT 2/1/91 3 2.5 2 1.5 0.5 0 0800 NTU'S AMMONIUM CHLORIDE SODIUM BROMIDE FILTERED 65 BBLS FOR GRAVEL PACK FLUID I 0900 TIME IN HOURS 1000 PRESS DISCHARGE FILTER RUN #9 Drilling Mud Record Baroid Petroleum Services COMPANY Unocal 0il & Gas Division STATE Alaska CASING PROGRAM inch at _,._ ft. WELL DA-6 Workover COUNTY Kenai inch at ft. CONTRACTOR Baker Platform LOCATION Cook Inlet SEC TWP RNG inch at ft. STOCKPOINT Rig Tenders Dock DATE 2/6/91 BAROID ENGINEER Wal 1 ace, Thomas TOTAL DEPTH ft. DATE DEPTH C/EIGHT VISCOSITY Yp GELS FILTRATION RETORT SAND CEC pH FILTRATION ANALYSIS feet lb/gal Sec APl PV 10 sec/ mi HTHP Cake Solids Oil Water % Mud Strip ~ Pm Pr/ p,/p~ CI CA REMARKS AND TREATMENT 19 91 °F _°F 10 min APl °F 32nds % % % , me/mt Meter .'-: Mf ppm ppm (See Operations Sheet) 1-19 MOVE ~IG F~[OM #7 to ~6 1-20 DISPL/ICE #, W/FIJI/ND TREI~./NU BOI AND T1-'ST SALVE 1-21 PULL f'RODUI.TION --UBI iG/M~, X LITEi;AL PILI./FIW 19000 1-22 2100 63 FIW 7.5 19000 1-23 2100 63 FIW 7.5 19000 1-24 5170 63 FIW 7 5 19000 1-25 5170 72 FIW t~ND rlaC1 I 7 5 19000 1-26 5579 76 FIW ~nd rlaC1 and Na~r 7.5 145000 1-27 5519 76 FIW ~nd ~laC1 and Na~r 7.5 . 140000 1-28 ! 5519 78 FIW ~nd llaC1 and Na~r 7.5 140000 1-29 5487 78 FIW ~nd llaC1 and Nadir 7.0 148000 1-30 5487 78 FIW ind llaC1 and Nadir ' 7.0 145000 1-31 5470 77 FIW itnd llaC1 and Natr . 7.0 160000 2-1 5768 76 FIW ~tnd llaC1 and Natr 7.5 L72000 ~2-2 5768 75 FIW ~nd llaC1 and Natr 7.0 L62000 2-3 5768 74.8 FIW ~nd llaC1 7.0 L57000 2-4 5130 74 FIW ~lnd rlaC1 7.0 L58000 2-5 5130 74 FIW .nd llaC1 7.0 L58000 2-6 5130 70 FIW .nd llaC1 7.0 /41000 2-23 5134 75.2 7.5 138000 2-24 5134 74.9 8.0 153000 2-25 5134 FIW NITIH Nal¢o 3900 Unocal Oil & Sas Division OPERATIONS Baker BA-6 DATE OPERATION~ 1-19 1-20 1-21 1-22 1-24 1-25 1-26 1-27 1-28 1-29 1-30 Move rig from #7 to #6, rig up wireline and pull pump and standing valve. Displace #6 w/FIW, ND tree, NU BOP, rig up to test same. Test BOP, RU and pull one string production tubing, circulate prepare to mix and spot sized salt pill. RIH w/bit and scraper for clean out run. Had to change out tubing spool, casing seat bad, pulled casing up and cut off, put on BOP's, will run in and retrieve plug after testing. Ran bond logs, RIH w/bridge plug. Set plugs' and tested casing, mixed one drum Dirt Magnet, circulated around, shipped returns to production, mixed 400 bbls of 72 lb/ cu. ft. NaC1/FIW, displaced hole, sheet tested returns and discharged overboard. Mixed 240 bbls of HH4C1, 3% FIW to add fracing fluid, weighted up active system to 76 pcf w/NaBr built additional 120 bbls 72 lbs NaC1/FIW. POH w/drill pipe, RIH w/tubing, spotted sand plugged circulated bottoms up. Mixed fracing fluid. Frac job got approximately 90 bbls of sand pumped into formation before pressing up, needed to bring brine weight up to 78 lbs/cu, ft. to kill well after frac., POH w/tubing, RIH with drill pipe, circulate and filter fluid. RIH w/perf tools, perforate, reverse out, circulate TOH, RIH open, pump sand plug, WO sand to settle, tag sand ~ 5487', circulate and filter tool. TOH, pickup RTTS, TIH, packer failed to test, TOH, pick up new RTTS< TIH, packer failed to test, TOH clean and break RTTS, TIH, test Okay, establish flow rate for frac. BAROID DRILLING FLUIDS, INC. Page 2 Unocal Oil & Gas Division Operations BA-6 Workover DATE OPERATIONS 1-31 2-1 2-2 2-3 2-4 2-5 2-6 Reverse out after pressure pack, caught sample for discharge circulate, TOH, lay down tools, RIH open, clean out sand, circulate and filter TOH. POH w/bit and scraper, RIH w/sump packer, POH, RIH w/slotted liner assembly, pump gravel pack, reverse out wait 3 hours and test, lost 86 bbls to hole last 24 hours. Pressure test gravel pack, TOH, WO tubing, RIH with tubing. Run KOBE assembly and dual string tubing, lost 61 bbls volume to hole. Finish running dual string tubing, unable to test seat. Wait on seal for well head. Test well head, move to well #27. Skid rig over well, NU and circulate well. Built 70 bbls 73 pcf NaC1 fluid, add 70 bbls NaC1 to circulating volume 75 to 77 pcf. Well still flowing with 74 pcf fluid, built 75 pcf CaC12 to kill well, pull tubing. Changed out tubing spool , tubing hangers, running tubing. Rigged up Halco wireline, retrieve plugs, tested tubing hangers, etc., displaced well with Nalco 3900 packer fluid. DAROID DRILLIN6 FLUIDS, INC. TOP DF SCREEN AT 5282d7' 12 EQUIPMENT and SbRVICE$ LOCATION: DP£~TOR UNOCAL ALASKA ~MPANY R~. PH~ DON CHUDANOV / LARRY GRAHAN MIDDLE GRDUN]] SFIDAL B-6 b*TATE LEASi~ ALASKA .OADING D,O~K qlG NAME PH,~ PLATFFIRM BAKER )ATE SUBMrFCED JOB ~ FEBRUARY 2, 1991 PR£PARED 8Y DARRYL SNO~ 5123.54 4,18 5127,72 4,81 5337 5.50 5138,53 1,66 5,812 5134,19 1,49 5.562 5135.68 2t,80 5157.48 .25 5,00 %00 5157.73 3[.12 3.50 5188.85 31.10 3.50 5219,95 31,10 3.50 5251.05 31,12 3,50 5282,17 30.07 4,11 5312,24 30,11 4,11 534a.35 30.05 5372.40 3011 4,11 4.11 5402,5] 30,07 4,11 5432,58 30,[0 4,11 5462,68 30,[1 5492,79 30.10 5522.89 30.09 5552,98 30.07 5583,05 30,10 5613.15 30.07 4,11 ~H~ 563-0825 4,11 4,11 4,11 4,11 4,11 5643,22 30,09 4,11 5673.31 30,ll 5703,42 30,08 5733.50 .58 5734.08 10.08 5744.16 .84 5745.00 3.45 4,11 4,11 4.85 4,11 4,685 5.63 PERFORATION INTERVALS, 5300'-5330' 5444'-5481' 5522'-5548' 5570'-5635' 5644'-5780' SIZE WEIG.T . .GRADE THREAD" CASING 7, a6" J55 LINER TUBING ~ 7/8' 6,5~ Nso 9UTTRESS WKSTRG LISTE9 ~ELDW BAKER MODEL SC-1L GRAVEL PACK PACKER SIZE 70B4-40 UPPER EXTENSION SLIDING SLEEVE SEAL BORE SOWER EXTENSION CROSSOVER SUB 3 1/2' 9,2# NSO BLANK PIPE · 124,44' BLANK 3 1/2' ,012 GAGE BAKERWELD SCREEN 45t,33' SCREEN O-RING SEAL SUB 3 1/2' BAKERWELD LOWER TELL TALE SCREEN ,012 GAGE BAKER SNAP LATCH SEAL ASS¥. SIZE 80-38 BAKER MBDEL 'D' SUMP PACKER SIZE 84-38 J. D. Hamrick Division Production Manager July 28, 1988 Amoco Production Company Northern Division 1670 Broadway P.O. Box 800 Denver. Colorado $0201 303-830-4040 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99503 File: JMA-753-WF Application for Sundry Approval Operation Shutdown SMGS Unit Well 96 Platform Dillion - Cook Inlet, Alaska This is to confirm verbal approval on 7-19-88 of an "operations shutdown" on the subject well. Verbal approval was obtained by Amoco's Robert Brooks from Mike Minder, acting on behalf of Lonnie Smith, from your office. We very much appreciate your cooperation in this situation. BAF:at ' ~ STATE OF ALASKA ' '~ ALASI~A OIL AND GAS CONSERVATION COMMr;SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend ' ' Operation Shutdown ~ Re-enter suspended well i'3 Alter casing E1 Time extension Change approved program ~ Plugging ~ Stimulate 2] Pull tubing.' Amend order r'! Perforate £' Other il;] 2. Name of Operator Amoco Production Company 3. Address P.O. BOX 800 Denver, CO 80201 P.O. Box 100779 Anchorage, Alaska 99510 4. Location of well at surface Leg 2, Slot 8, 701' FSL, At top of productive interval 1867' At effective depth At total depth 904'FSL 1538'FWL Sec. 35-T8N-R13W FWL, Sec. 35-T8N-R13W 11. Present well condition summary Total depth: measured true vertical 10942' feet Plugs (measured) 10931 ' feet 5. Datum elevation (DF or KB) 110' KB feet 6. Unit or Property name South Middle Ground Shoal Ur 7. Well number 8. Permit number 9. APl number 50-- 7332004200 10. Pool Hemlock Conglomerate Lease Designation Serial No, ADL 18746 Effective depth: measured 101 37 ' feet Junk (measured) true vertical 10]26' feet Casing Length Size Cemented Measured depth Structural Conductor 20" · ,i ~ ~85# 1250SX 603' Surface I,'5'3/8" 54.5# 1200SX 2020' Intermediate Production q- 5/8" 1 5505X -10530' Liner Perforation depth: measured Refer to wellbore diagram attached true vertical True Vertical depth Tubing(size, grade and measured depth) Z-7/8" 8 RD TO 5400' Packers and SSSV(type and measured depth) None 12.Attachments Description summary of proposal )D Detailed operations program Ui BOP sketch 13. Estimated date for commencing operation 7/20/88 14. If proposal was verbally approved Su'oseq_u~t Fo~m No._ - Dated~/----/--- Name of approver Mi ke Minder for Lonnie Smith Date approved 15. I h~'~e~,ti-fy)tha, t-- ,,~~~the/f~reg°ing' is true and correct to the best of my knowledge Signed~~'~;;~li~~v~'~Title Di vi si on Engi neeri ng Manager (Dwi ght~ '~D. W~,~dsc~l ag) /; Commission Use Only Conditions of approval Notify commissida'"so representative may witness I Approval No. [] Plug integrity [] BOP Test ~ Location clearanceI 7/19/88 Date 7/27/88 ~, ~~~i~ Approved Copy Returned Approved by Commissione~- Form 10-403 Rev 12-1-8---5 - ~ / / the commission Date it Su6mit~n triplicate,~' Summary of Proposal Shutdown Well Operations On to SMGS No. 6 Platform Dillon /~ By the displacement method, set a continuous cement plug ~ / from 100 feet below the lowest perf (5875) to 100 feet ~ ..... above the upper perf (5520~). 2. Run 2 7/8" tubing to 5400~ and fill tubing and annulus w/ ,,packer"-fluid consisting of 2% KCL, 02 scavenger, and corrosion inhibitor. 3. Rig downs BOP's and rig up well head. 4. Shutdown well operations awaiting further study for use as a kick out well for Hemlock oil flank development. SOUTH MIDDLE GROUND SHOAL ADL 1874,6 WELL NO. 6 HEMLOCK CONGLOMERATE PLATFORM DILLON SHUTDOWN OF WELL OPERATIONS 8,5 C~ eO~[' ~'10~0 SX CsA 2o2o' WZt2oo sx 2 7/8" TUBINQ O 5420' KILL STRING PBD 101 ;~7' TD 109~2o 2~ KCL W/O2 SCAVANaER X CORROSION INHIB. 5520' ] ~ROX 5875' j ~ 0~ DST t PLUe~ ~00' C~T ~0~ UP~ X ~O0 C~T ~ (~ ~OSS) LO~ P~ e ~/8" 40. 40,5 a: 47~t CS& 105~0' W/1550 SX FN:SMOS-..6SD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend '; Operation Shutdown ~ Re-enter suspended well F~ Alter casing E1 Time extension Change approved program ' Plugging ~ Stimulate Z] Pull tubing . Amend order r'! Perforate [' Other 2. Name of Operator Amoco Production Company 3. Address P.0. Box 800 Denver, CO 80201 P.0. Box 100779 Anchorage, Alaska 4. Location of well at surface Leg 2, Slot 8, 701' FSL, At tOp of productive interval At effective depth 99510 1867' FWL, Sec. 35-T8N-R13W At total depth 904'FSL 1538'FWL Sec. 35-T8N-R13W 5. Datum elevation(DF or KB) 110' KB feet 6. Unit or Property name South Middle Ground Shoal Ur 7. Well number 8. Permit number 9. APl number 50-- 7332004200 10. Pool Hemlock Con91omerate 11. Present well condition summary Total depth: measured true vertical 10942' feet 10931' feet Plugs (measured) Lease Designation Serial No. ADL 18746 Effective depth: measured true vertical feet Junk (measured) feet Casing Length Structural Conductor 20" Surface t~u-~/8'' Intermediate Production ¢~. 5/8" Liner Size Cemented Measured depth ~85# 1250sx 603' 54.5# 1200sx 2020' 1550sx -10530' Perforation depth: measured Refer to we] ]bore diagram attached true vertical True Vertical depth Tubing (size, grade and measured depth) Z-7/8" 8 RD TO 5400' Packers and SSSV (type and measured depth) None 12.Attachments Description summary of proposal ~ Detailed operations program C.] BOP sketch [] 13. Estimated date for commencing operation 7/20/88 14. If proposal was verbally approved ~u~sequent 'Wbr]c J~eDotted oa Form No. Dated._J__./__ Name of approver Mike Minder for Lonnie Smith Date approved 7/19/88 15. I he~b~/'~esti.fy.;that theFeregoing, is true and correct to the best of my knowledge Signed~[ l~~~~Title Division Engineering Manager · ~ ~1 %' ' (Dwight D. W~dschlag) -A) Commission Use Only Conditions of approval Notify commissi(:h~so representative may witness I Approval No. [] Plug integrity [] BOP Test I~ Location clearanceI ~) --;~ / Date 7/27/88 Approved b~; Approved Copy Returned Commissioner by order of the commission Date it Form 10-403 Rev 12-1-85 Submit in triplicate Summary of Proposal Shutdown Well Operations On to SMGS No. 6 Platform Dillon 1. By the displacement method, set a continuous cement plug from 100 feet below the lowest perf (5875) to 100 feet above the upper perf (5520~). 2. Run 2 7/8" tubing to 5400i and fill tubing and annulus w/ "packer"-fluid consisting of 2% KCL, 02 scavenger, and corrosion inhibitor. 3. Rig downs BOP's and rig up well head. 4. Shutdown well operations awaiting further study for use as a kick out well for Hemlock oil flank development. PEID 101 ;~?' 'rD 109~.2' ~ 60~' W/1050 SX 13 3/8" 54.5~ CSA 2020' W71200 SX SOUTH MIDDLE GROUND SHOAL ADL 1874.6 WELL NO. 6 HEMLOCK CONGLOMERATE PLATFORM DILLON SHUTDOWN OF WELL OPERATIONS ........ ~ 2 7/8" TUBING ~ 5420' KILL STRING ~ ./ 2~ KCL W/O2 SCAVANGER X CORROSION INHIB. APPROX 5520' ]~ SQZ PERF 582o' 5 672' 5760' ~[ SQZ PERF' 5775' i~ ~oo, APPROX 5875' APPROX 61~0' x ~oo' c==~ ~,=.c~ ~=~, ~.oss> uo~, FN:$UGS--.~SD RWB/f~ 7/28/88 MEMORANDb'M' State of Alaska .f:ALASKA OIL ~D GAS CONSERVATION COMMISSION :.-~:_ TO: Lonnie C Smith //~ DA/E: July 13, 1988 Commissioner mL~ NO: D. BDF. 125 THRU: FROM: Sr Petroleum Engineer Bobble D. Foster ~ Pe trole%;~ Inspector TELEPHONE NO: SUBJECT: BOP Test AMOCO- SMGS UNIT #6 Permit No. 67-52 MGS Oil Pool Tuesday, Ju~ne 21, 1988= t traveled this date to AMOCO's Dillon Platform t°'witn~ss~the_upcoming BOP Test. Wednesday, June. 22, 1988: The test began at 12500 p.m. and was '~om~Ietea a~ "4:00 p.m-, ~-As the attached BOP Test Report shows there were three failures. The pipe rams were repaired and tested. The upper kelly valve and the floor safety valve will be replaced and tested when the tubing' is pulled out of the hole. The blind rams will be tested at this time also and the AOGCC Office notifed. Attached is a copy of AMOCO BOP Test sheet after the upper kelly valve, floor safety valve and blind rams were tested. Attachment 02-001A (Rev. 8/85) 5184 .' STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report ~: .'.' Loca~ion: Sec ~ Drilling Contractor ~/~ Ri~ # Date Permit # Representative Location, General ,~-'" Well Sign--~ ACCUMULATOR SYSTEM General Housekeeping ~,/ Rig. L/ Reserve Pit . _/~/./_~ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor 'v'"' Gas Detectors BOPE.Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure / -5'00 1 / Test Results: Failures Full Charge Pressure ~-'~ ~ psig Pressure After Closure /~57~-' psig Pump incr. clos. pres. 200 psig - Full Charge Pressure Attained: Controls: Master RemOte ~f=_ Blinds switch cover;~_~ / ,, Kelly and Floor Safety Valves Upper Kelly Lower Kelly Ball Type Inside BOP Test Pressure Test Pressure Test Pressure Test Pressure Choke Manifold ~._~ Test Pressure No. Valves ~ No. flanges ~ ~ minA/~s ec. ,, min) ~- sec. Adjustable Chokes ~ Hydrauically operated choke / Test Time hrs. Repair or Replacement of failed equipment to be made within ~ day~ and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc - Operator CC - Supervisor Inspector~~ L~ ~~~ (. A~OCO PRODU(3~TION OOMPANY' ..... ' . ,.'- -OFF,HORS S. O, P. AND EQUIPMENT It ............... £': 7 ......... ";.~---- ..... - ......... NO. ' ~ ANNULAH B.O.P. ,, /, ....... '-- .'" ..... · ~1 ..... ktl[" T:=~7-- f II .~ ,.. -~- iii ~ ~j~r'L'- '"*"~"~'- 3 UPPER PIP, E..iRAM$,., ..... ' ........ ~"""" ~" "~ ~ '~' '4'~""" "-' .... ____ ~~____.~__~..~...____., ~__~.____~~.__~, .~-,--~.--..-~.-,-~'~---"~'$ =.MIDDLE PIPE ~~4 ~LOWER PIPE HAM8 ' ? te~,~. =-. ',~, ...... ~ ..... . .......... ~ .... ,,, .:..: ..... iiii .... . .... . ............. ).' ..... ~' ' .... . ' ' '' - ..~ ALT~H.N_AT~ OHOK~. ........ ' ~ .(~,~"~ ...... , -.. ....... . .................... i: ' . ~ ...... 11 ..... '' ...... ._~ , -- II Jlti ........ , ...... ' ..... ~ ~i KILL LINE & V~.~.VE8' ' .... _~ 3~$ ~" -~ I I---'~ ...... Ir .. ' ' ' I ~.h ,. ._Jj ..... ~ I I , ~,~ ~ , H. ~' i ......... ' ........... 14]D,P. ~-AFETY VALVE ..... II .... .,r ,, ,,~}~. __. · · aAFETY VALVE ...... ..... i i ..... I ...... I ...... -- .-- "" -- '--' ' .... -~... IT~:IN~IDE 8.0,P, VALVE ...... .:__. ......... ,.. .-== .......... ' ...... ...... '- l'e STANDPIPE & 'F ...,, . ...... . . ~ .~~ .......... . ....... . ....... ...... ~ ~'~" "- ..... . . ., ....... ~ .. _ ,=. ,, - _ ]1.1.. I Il. II [ . ii III .._ i .... ._~ ......... ] 1 .. ,~ 9 h ._ . ~_4~_~ , ........ .......................... ' ............... .................. =~ ........ ,,~. -... ......... .. . ......... ,~¢~~-~.,~,;~ ,, .... , ,,.: ..... ' .... _ ....... iii i - i ........ ?. , i .k .... __. Z'' ....... '.'.."""" '" ~-' .~ ~' ~ ~ ' ~U..N___O?ION TEST REMOTE El, O. P. (]ONTROI. , YES NO ........ I Il ,_ ' ........ II _ I ..... L_II ........... ~ ,, ........ · .. i _ - · ~1/ <3ONTRAC'? J~ ~ JUN 08 '88 14:51 AMOCO P~ DNVR J. D. Hamrick Divia,~. Production Man0~er June 8, 1988 Amoco Pr.duction Company Northern D~vi slot, 1870 Broactwav P,O, 8ox 800 Denver, Color ado 80201 303-830-40,~O P.1 Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99503 File: GLH-SBS-WF Application for Sundry Approval Recompletion of South Middle Ground Shoal Well No. 6 platform Dillon - Cook Inlet - Alaska To oonfirmyour telephone conversation with Bruce Frye of this office on June 8, 1988, we are forwarding you state Form 10-403 detailing Amoco Production Company's intent to ~e sub eot well fr~m the ~emlock Ho~£zon uD~ole recomple=~ J ect~on with =his to Tyone~/S=a~e gas sands. ~n corm recomple=ion we will abandon the present horizon, Hemlock. we woula like to begin this work on WednesdaY, June 15, 1988. Therefore, your imme~la=e attention and approval of isAoolica~ion for Sun~rY .Approvals wpu~d bm. g~ea=ly precepted, please return your approval Dy facsimile. O~r facsimile operator's phone'number is 303-830-4223. If'it would be more expedient you could call Bruce Frye or Bob Brooks of this office with your approval. BAF: at RECEIVED JUN 8 1988 Alaska 011 & Gas Cons. Commission '-..L. ~m~Jh0rage · STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS P.P Type of Request: Aban~tort ~ Suspend g Opetalign Shutdown O Re-enter suspended welt C Alter casing 2. Name of Operator ~ ~ : ~ 1~: m~., ,)~ 0 Produc_t.!on Compan_j6_ .... . _ 3. Address P,0, Box '100779, Anchor'age, Aiaska 995]0 . iii ..J,~ 4, Locafton of well at surface Log 2 Slot 8 701'FSL, 1867'FWL, :Sec 35-TSN-R13W At top el' produclive interval At effective depth At lcfii depth 904'FSL, 'i538'F~, Sec 35-TSN-R13W 1!. Present welt condition summary Tot~ depth: measured 10942' feet true vertical 10931 ~eet Plugs (measured) Da{urn etevafion (DF or KB) 110* KB fee,_~. ,J Unit or Property nome / So~h Middle ~round Shoal Unib 7. We]i number 8, Permit ~umber APl number 50- 733Z004Z00 _?~.~.. ~ .:. .__.,_. . ,~.:-_:=. ~ ~..;.~--.-..-...~..~___==_.;_.--~,~--:. 10, Pool Hem) ock Conc.~ omerate ~e Des ..... ADL 18746 Effective dept h: measurecl 10137 ' feet Junk (measured) C~slng Structural Conductor Surface Intermediate Production Liner Per(oration depth: measured Length true vertical ,Size Cemen(ed Measured depth 20" 85// 12505X 603' 13 3/8" 54.5~ 1200ax 2020' 9 5/8" 1550SX 10530' Refer to wellbore diagram attached, ,Tu0ing (size, grade and measured depth) 3{" Buttress tp 9199' Packers and $S$V {type and measured depth) Baker Model D e 9218' i2,Attachments Description summary of proposa~ I~ -{~=~slime'ted de'te for commencing oP~'ra¢i'0n' jUN 8 1.gBB , .~ '~ DetaUed operetions program .~3 5OP sketch 14. I~ proposaJ was verbally approved Name of approver Yo~ No. . Dated~--/~ Date approved · (G.L, Ha~per) o:mm~ion U~e o.ly ~' A~proved g~PY Approved by 10-403 Rev 12-1~5 Form summary of PropoBal of Workover SNG$ No. 6 P,.la.tform Dillon 1. Dig up BOPs and Test. 2. Kill well ~nd puli tubing and miilout packer. ~%-~r~:~ Set cement from 100 fee~, by dispiac~ment method below ~ to 100 fee~. 4. Tes~ c~ent top. 5. Set 9 5/8" ~ridge Plug on top of cement, plug. 6. Perf 9 5/8"' casing for cement s~ee~e a= approximately 8,~00 feet and cement . 5 Ca,ed Hole Drill S~em Test swd inte~ai~ at ~proxi- ~~9~ . Run a= get production pkr at 7,400 feet. 10. 1I. 12. 13. 14. Run 3 1/2" tubing and seal assembly. Hydrotest. Rig down BOPs and rig up wellhead. PerfOrate wi~h wireline guns. \ Place well, on production as flowing gas well. ZAF/lmm 050588 LTR699 SOUI~ MIDDLE ~ROUND SHGN. ADL 18'746 WEU. HO. 6 HEMLOCK CON~~ PtATFORkt t~LLOK I~lpth 0174' 91~g' J 2.020' 57~1 B~P~. Q BIJIP~. ;31~B klC:FD k. 3 1,~2' Ik~tree~ tublag run 9/1 t/a3) ~ ~ O laocluer POD tO13~ 11) 10~4~' 94~-e4~o. ._TUH OB '88 '~4:,.,=3 F-:iHOCO ,'~'N-) DH'v'R llTS/nef 9/29/83 SOUTH t. tIDDLE GROUND SHOAL We)lbore Diagram 18746 Nell No. 6 (As Run g-83) Casing Record 20" 85# casing 13-3/8" 54.5# casing 9-$/8': 40, 43.5 & 47,~ ,¢aslng 603' 2020" 10,530o Baker Model 'D' Packer (4-3/4" Bore) set 9 g218' PBD 10,131' ( 1 O, 1 ~0' TVD) TD 10,g42' (10 , 32' Tv ) Compl.e_ti on Record' Lon_g.~ Stri n.g Oua! Cameron Hanger DC-B pept h_ 35' 2) 3-1/2" Butt. Pup 3) 3-1/2" Butt. Pup 49' 4) 294 Joints 3-112" Butt. Tbg. 5) 3..1/2" Butt, Pup ~' 9174' 9178' 6) ' 3-1!2" Butt, x 3-1/2" 8RD XO · 9178' 7) Kobe 3" Type 'E' BHA sn/223B 9198' 8) 3-112" 8RD Pup 9) 3-ii2': Blast Joint ~0) Baker Seal Locat,~r 9202' 9214' 11) Baker 4-3/4" OD Seal Assy. 9235' 12) 1 Joint $-I/2" Thg. g267' 13) 3-i!2" Butt. x 2--718" 8RD XO 9268' '14) Baker Underbaiancin9 Disc' )~ssy. ,926g' 15) 2-7/8" 8RD Muleshoe $_h. ort .StrJ__n_g_ 16) 3-1/2" Butt, Tbg, 9269' · · D...epth. ?e rf orA t, .i._o_~n ) ,',.. ,~,~,-~c,v (to0 9232 TVD G-2:. 93i$-93g0~ (too 9307' TVD G-3a' 9455-9480" ltop 9446' TVD}-Squeezed Tested to G-3b: 9495~9655: (top 9486: ?VD}" G-4: 9680-9830~ (top, 9671' TVD} ._TUN 08 ',98 14:.54 ~r'loco/~''~'''D DHVR P.6 P_e. rt i_nent Data: Spud Date' Surface Location: Subsurface Lo.cation: Elevation." PBD: Casing: Initial Perforations: Initial Potential: Initla 1 Stimulation: Reservoir Daf, a: i Cores: DST: Selective Tests: Log Inventory: South Hiddle Ground Shoal ADL 18746 Well No. 6 Hemlock Conglomerate September 20, 1967 Leg 2, Slot 8 904' FSL, 1538' FWL, Section 35, T8N, R13W, SM IlO' KB, flSL GL 10,94Z' TvU ilJ,931' 10,I37' TVD 10,126' 20", 85# csa 603' x i;~50 sacks 13-3/8'*, 54.5# csa 2020° with lY. O0 sacks g-5/8", 40, 43.5 x 47~ S-g5 x N-80 csa 10,530' with 1550 sacks g~45.55' 931§-~0' 9350-60: 9~75-8$' 9465-75' 9500-10', 9540-50;,, 9580-g600'. 9625-35', g645-55', 9500-90', g710-20°, g756-65', 9790-9810', in water base mud at 4 JSPF using casing gun. 572! BOPD, 0 BWPD, 1316 MCPD, flowing November Z, 1967. None 1) 10,$33-10,555', cut 22' , recovered 10.$30-55', ISIP 5220, IFP 197, FPP ~ re.:overed !$ BO, 1459, IHP 5442, ,-HP 5442, 9 bbls mud, 105 bbls GCW. None !EL-SP, 8HC-GR, October 13-17. ig67; GR-Temperature, June t2, 1976 · · · South Middle Ground Shoa! (Continued) ADL 18746 Well No. 6 Hemiock Cong I omera te w_o?_kove r Hi stOyy: 11/6/67. · Init(al Completion. 8/6/68: Run BHP, Perforate 9240-70', 931~-25', 9495-0~5~', 9578-9638', 9645-~$', 9680-9760', 9280-9830', in diesel with 4 JSPF using Schlumberger 4 in. ca~ing gun. Put on Kobe pump. BWO: 1187 BOPD, 25 BWPD, 352 MCFD AWO: 2840 80PD, 88 BWPD, 3.2 MMCFD 8/27/68: Pull BHA to retrieve pump. clean out to i0,.~06 with diesel. BWO: 1059 BOPD, ig BWPD, 352 MCFD AWO: 2962 BOPD, 18 BWP~, 869 MCFD 9/23/68: Pull BHA to retrieve pump, workover with diesel. BWO: ~OgO BOPD, 16 BWPD, 402 MCFD AWO: 2049 BOPD, 4 BWPD, 594 MCFO 4/70: Run BHP. 1I/5/74: 6/10/75: 6/2/76: Workover to clean out casing and diCferentially pressure stimulate. ?est G1 (9190-9300') ~29 BOPD, 79 BWPD. Test G-~ {9204-9420'} 205 BOPD, 270 BWPD Test G-3A (9400-9485') !00 BOPD, ~24 BWPD Test G-3B (9485-9563') 236 BOPD, 139 BWPD Test G-3B & G-4 (9565-9770') 424 80PD, 120 BWPD Actdize G-4, 9780-9850', with ~ bbls diesel, 3000 gal. HCl, 5 gal, W-35 + 4 gal. A-130/i000 gal. Displace at i-~ BPM at 3500 psi, broke down to 2200 psi. Acidize G-4, 9680-9760', with 5 bbis diesel, 3000 gal. 15% HCl, $ gal. W-35 + 4 gal. A-130/I000 gat. Displace at i-{ BPM at 1500 psi. Cement squeeze perfs 9455-9480' with 150 sacks. Clean out to 10,137'. BWO: 1095 BOPD, 1095 8WPD, 555 MCFD AWO: 1144 BOPD, 856 BWPD, 306 MCFD Change BHA, workover with oil base mud. BWO: 0 BOPD, 0 BWPD, 0 MCFD AWO: 854 BOPD, I064 BWPD, 173 MCFD Shut-in due to high WOR, producing 0 ~O~D. i571~SW'PD, 46 MCFD. South Middle Ground Shoal (Continu~H', AD[. 1$746 Welt ~o, Hemlock Congl ome rate Workovqrm._H. i story: g/26/77: Workover to pull tubing and Kobe ~NA and run 2-7/8" kill string. Well left shut-in. Kii)edwith inhibited fresh water. il/7/82: Workover to return well to production, Pulled tubing and cleaned out to I0,078~ ~et p~cke~ at 9~72' aad r,~n 3" Kobe Type "E" BHA and tubinj. Workover with 9.6 ppg treated filtered Inlet wat~, Ca¢l. RWCI: Shut.in. AWO; 64 BOPD, 1584 BWPD~ 1-5 MCFD g/11/83: Workover~ l;O replace Kobe 8HA. Ra~ Kobe 3" Type 'E"BHA, Displaced tubing'with Nitrogen to back surge perfonations, When d~opped ba~ to b~eak underbaianc~ng disc, bar we~t hnttnm of hole and could not be w~et~ned ou~, Workov~r with teeated filtered Inte~ Tagged fill at 1 10'066'.200- BWPD O MCFD BWO: 0 BOPD ~ , AWO: 23 BOPD, i362 BWPD, 8 MCFD JUM 08 "88 14:51 AMOCO PROD DMVR ' '- STATE OF ALASKA · AL.AL~.~ OIL AND GAS CONSERVATION COMN,,JSION APPLICATION FOR SUNDRY APPROVALS 1. Ty~ Of Request: A~an~Pfi2 ~.__S~e~ Q Opetati~on Shutd~n ~ R~nter Time extension ~ ~ange ~p~ p~gram ~ ~ugging ffi 811mu~te ~ Pull lu~ing 2. Name of Operator Amoco Product.ion 3. Address P,0, Box 100779, Anchora(je,. Alaska 99510 ... 4.. Location of well at surface Log 2 Slot 8 701'FSL, 1867'F~, Sec' 35-TSN-R131d-'- At top of productive interv3t .. ," At effective depth At fetal depth 'gIM'FSL, 1538'F~, Sec 35.TSN-R13H ti. Present wett condition summary - Total depth: measured 1Qg42 true verticaI:~,10931 feet Effective depth: measurecl 10137' (PBD) true verLic~ai' 10126' feet Plugs (measured) dunk (measured) 5. Datum elevation (OF: or KB) :_ .... _. 1lO'KB feet 6. Unit or Property name $ouCh M;Lddle Ground ~hoal Uu:L 7. Well., number '8. Permit number? f. ~., A~ number ~o- 7332004200, '".,' Hemlock Conc,l.o~ra~e L~ase-'Designa~ton/Se~tal No. ~L 187~6 Casing Structural Conductor Surface Intermediate PrOdUCtion Liner Perforation depth: measured Length Size Cemented Measured depth 20" 85f 1250SX 603' 3/8" 54.~ 1200SX 2020'' 5/8" 1550SX 10530' True Vertical depth true vertical .Tubing (size, grade and measured depth) 3~" Bu'dress tp 9199' ' Packers and SSSV (type and measured depth) Baker Node1 13 e 92!8' 12.Attachments Description summary of proposal JUN 8 1988 Oil & Gas Co.s. Commlssloa """,,.t~, J~lehorage al ii Detailed ooerations program BOP sketch 13. Eslimated date for commencing operation ,Tune 15, 1988 Aec, nmpleCe uphole from Homlo~ 14. ff pm~sal was ~rbally approved Sub~~t W~k Name of appm~r F.~ N._ _ ~ 7. Y ........ Oat~ approved 15, I h~reby foregoing is true and correct to the best of my ~nowledge Slgn~ Title (G. L. Harper) ~mmtssion Use Only ~ftlons of a~pr~al Approved by Notify commission so repreaentattve ~ay wdness J Approval Approvea uopy Retu~ed~ ORIGINAL SIGNED BY: ' L0,,,E c. Commissioner the commission Date Form t0.403 Rev 12.1-85 Submit in triplicate ~UM 08 '88 14:~2 AMOCO PROD DMYR le . 7~ 10. 11. 1~-. 13. ~4. SUmmary of Proposal of Workover SMGS No. 6 platform D_ il,!on Rig. up BOPs and Test. Kill well and ~ull tubing =nd millout packer. Set cement from 100 fee=, by displacement me,nod below to 100 feet. Tes= c~en= top. Se~ 9 5/8" ~ridge Plug on top of cement plug. Perf 9 5/8" casing for cement s~eeze at approximately 8, ~00 feet and cement s~eeze. Dri!l ou~ Cased Hole Drill S~ Test swd tnte~als at ~proxi- ma=ely 8,200 feet. R~ a~ get produc~ion p~ a~ 7,~00 feet. .. R~ 3 1/2" t~ing ~d seal ass~ly. ~ Hydro,st. ..,. ~g do~ BOPs ~d rig up wellheads. Perforate wl~ wireline ~s. Place well on production as flowing' gas well. 050588 LTR699 ' RECE.IVED JUN 8 988 Alaska Oil & 6as Cons. commission ,.,.. Anchorage - SOUTH MIDDI~ ~ROUND SHOAL Ant. 18746 ~ NO. 6 HF. MLOCK CONOt.OMERATE: ~ PLAIFO~M DILLON ilO' KB Ioe42- ~ 109:3t' 10157t 1'VD 10124r ;. Du,I,I C4mmm~ KB tubing Iwnpr .. ~ t~2"-8.ur...,,id 3 V2" end XC) a. 3 ~t- nmi pup L 3 U2" ff, a~t Joint Sf). Ikdud' SiM IMmMr 1 I. 13. 3 14. Bnker Umk~n 1~ 2 ?,~lr* MID IdukuhM] hpU~ g~74' OtT7* 9178' 02o2* o2t 4' 926~ J .. o ~-~ 0 13 ~" .~ } ~ 202i~ ~ I: Pc, tQnUol: ~ R~uitm: 0-1: 6-4: 96M)-t?LS' ~721 BClaD. 0 BtM;ID, 1318 IdC:FD 10SJ0-1056S: ISiP ~ StP 117, FPP 14,1i. 14P 044~ F14P ~44Z. E3.--:SP. IBHC-4R MI-T~ .A. 3 1/2' Bu'.b~es ~ul~g run a/lt/~) 8aiMr Uo4~ O Poch4r PUD 'ID 7 I~t2 1'1 g 4~)5-0480' · II t.',d' JUM 88 '88 14:53 RMOCO PROD DMVR P.5 llTS/nef 9/29/83 iq.... 13"-i 15 SOUTH MIDDLE GROUND SttOAL Wellbore Diagram 18746 Nell No. 6 (As Run 9-83) Casing Record ~ _ , · 20" 85~ casing . 13-3/8" 54.5# casing g-5/8" 40, 43.5 & 47,4 ,casing , Compl e. tt on Record: Long String · . · '1) Dual Cameron Hangar DC-B , ~) 3-1/~" But~. Pup 603' 2020" 10,530 ° pept_h__ 35' '"Jg' 3) 3-1/2" Butt. Pup ' 4g' 4) Z94 ~oints 3-1/2" Butt. Tbg. , $)' :)-1/2" Butt. Pup "' · O) ' 3-1/2" Butt. x 3.-1/~" 8RD XO 9174' g[78' 9178' Baker Model 'D' Packer (4-3/4" Bore) set 0 9218' ' 7) · Kobe 3" Type 'E' BHA sn/2238 8) 3-1/2" 8RD Pup · g) 3-1/~" Blast Joint , Baker Seal Locat,~r 11) Baker' 4-3/4" OD Seal Assy. 12) 1 Joint 3-1/2" Tbg. g).98' 0202' 9214' g235' g257' 13) 3-I/2" Butt. x 2-7/8" 8RD XO · 14) Bake~ Underbalancing Disc')~ssy. ' 92~8' · . 9269' ' ' 15) 2-7/8" 8RD Muleshoe , $_h. ort String ·" · 16) 3-I/2" Butt. Tbg, , PBD 10,137' ( 10, ~26' TVD) TD 10,g42' ( 10 ,g32' TVD) .. 9269' . · ~ . , DaP.th. · 08' Perforations ..",' .. - m '', ' G-l: 9240-9270' (too 9232' TVD) . G-2: 931$-9390~ (;to~ 9307' TVD) G-Jo: g455-g480' (top g446' TVD).$queezed Tested to 2000 psi-held-~l/$/74 ., $-3b: g495-g655' (top 9486' TVD)" G-4: g680-g830' {top, 9671' TVD ) JUH 08 '88 14:54 AMOCO PROD DHVR P.6 Pertinent Data: Spud Date: Surface Location: Subsurface Location: · Elevation:' TO: PBD: Casing: Initial Perfo ra ti OhS: Initial Potential: Initial Stimulation= Cores: DST: Selective Tests: Log Inventory: South Middle Ground Shoal ADL 18746 Well No. 6 Hemlock Conglomerate September 20, 1967 Leg 2, Slot 8 904' FSL, 1538' FWL, Section 35, TSN, R13W, SM 110' KB, MSL GL 10,94Z' TvU 1U,931' 10,I37' TVD 10,126' 20", 85# csa 603' x 1250 sacks 13-3/8", 54.5// csa 2020' with 1200 sacks 9-5/8", 40, 43.5 x 47f S-95 x N-80 csa 10,530' with 1550 sacks 9~45.5~' 9316-~0, 9350-60' 9375-85' 9465-75' 9500-10', 9540-50~, 9580-9500', 9625-35', 9645-55', 9580-90', 9710.20', 9755-65'," 9790-9810', in water base mud at 4 dSPF using casing gun. 5721 BOPD, 0 BWPD, 1316 MCFD, flowing November 1967. None 1) 10,$33-10,555', cut 22' recovered 14' 1) 10.530-55', ISIP 5220, IFP 197, FFP 1459, IHP 5442, FHP 5442, Pecovered 15 BO, 9 bbls mud, 105 bbls GCW. None IEL-SP, 8HC-GR, October 13-17, 1967; GR-Temperature, dune I2, 1976 JUM 08 '88 14:54 AMOCO PROD DMVR P.? South Middle Ground Shoal (Continued} ADL 18746 Well No. 6 Hemlock Conglomerate w_o~.r, kover Hi st~o?y: 11/6157: 8/6/68: Init(al Completion. .Run BHP, Perforate 9240-70', 9315-25', 9350-90', 9455-80', 9495-9~55i, 9578-9638', 9645-$8', 9680.9760', 9280-9830', in ~iesel with 4 JSPF usingSchlumberger 4 in. casing gun. Put ' on Kobe pump. BWO: 1~87 BOPD, 25 BWPD, 35Z HCFD AWO: 2840 BOPD, 88 BWPD, 3.2 Mt4CFD 8/2.7/68: Pull BHA to retrieve pump, clean out to 10,[06'. workover with diesel. BWO: 1059 BOPD, lg BWPD, 352 MCFD AWO: 2962 BOPD, 10 BWPO, 869 MCFD 4/70.' 1I/5/74: Pull BHA to retrieve pump, workover with diesel. BWO: 2690 BOPD, 16 BWPD, 402 MCFD AWO: 2049 BOPD, 4 BWPD, 594 MCFD Run BHP, Workover to clean out casing and differentially pressure stimulate. Test G1 (9190-9300') 129 BOPO, 79 BWPD. Test G-2 (9304-g420I) 205 BOPD, 270 BWPD Test G-3A (9400.9485')' I00 BOPD, $:~4 BWPD .....' Test G-3B (9485 9'563'} 236 BOPD, 139 BWPD Test $-3B & G-4' (9565-9770') 424 BOPD, 120 BWPD Acfdize G-4, 9780-9850', with 5 bbls diesel, 3000 gal. 15% HCl, 5 gal. W-35 + 4 gal. A-130/1000 gal. Displace at 1-t BPM at 3500 psi, broke down to 2200 psi. Acidize G-4, 9680-9760', with 5 bbls diesel, 3000 gal. 15% HCl, $ gal. W-35 + 4 gal. A-130/1000 gal. Displace at ~L-t BPM at 1500 psi. Cement squeeze perl's 9455-9480' with 150 sacks. Clean out to ]L0,[37'. BWO: 1095 BOPD, 1095 BWPD, 555 MCFD AWO; 1144 BOPD, 855'BWPD, 306 MCFD 6/10/75: Change BHA, w°rkover with oil base mud. BWO: 0 BOPO, 0 BWPD, 0 MCFD AWO: 854 BOPD, I064 BWPD, ).73 MCFD 6/2/76: Shut-in due to high WOR, producing 0 ~OPD, i57i'8W~D, 46 MCFD. · · South Middle Ground Shoal (Continued) ADL 18746 Wol] NO, $ Hemlock Conglomerate Workover History: ;/25/77: Workover to pull tubing and Kobe BHA and run 2-7/8" kill string. Well left shut-in. Killed with inhibited fresh water, 11/7/82: g/II/83= Workover to return well, to production Pulled tubing and cleaned out to 10,078~ Set packer a~ g~.'72' a~d ran 3" Kobe Type "£" BHA and tubing, Workover with 9,6 ppg treated filtered Inlet water with CaCl, RWC): $ hut · t n, AWO: 64 BOPD, 1584 BWPD, 1'5 MCFD Workove~' tO. replace Kobe BHA. Ran Kobe 3" Type "E!' BHA, Displaced tubing'with Nitrogen to back surge pe~fonattons, When dropped' baP to bneak underbalanctng disc, baP we~t bo hnttnm o? hole and could not be w~Pel~ned ou~. Workove~' with teeated filtered Inle~ water. Tagged' fill at I0,066' .BWO: 0 BOPO, .',~00 BWPO, 0 MCFO .... AWO: 23 BOPO, 1362 BWPD, B MCFO L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 October 7, 1983 File' LAD-915-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Subsequent Noti ce SMGS Unit Well No. 6 Platform Dillon, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, subsequent to the repair work done on SMGS Unit Well No. 6. The repairs were made and the well was returned to production. The well is currently producing 28 BOPD, 1,316 BWPD, and 10.7 MCFD of gas. Very truly yours, L. A. Darsow District Superintendent Attachments MTS/seh A}aska 0ii G. Gas Cons,, Anchorage ~-'~-' STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COi~,,vllSSION SUNDRY NOTICES AND REPORTS ON W_ELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 3. Address P. 0 Box 100779, Anchoraqe, Alaska 99510 4. Location of Well Surface Location- Leg 2, Slot 8, SMGS Platform Dillon Subsurface Location. 904' FSL, 1,538' FWL, Sec. 35, T8N, R13W, S.M 5. Elevation in feet (indicate KB, DF, etc.) 110' KB, HSL I 6. Lease Designation and Serial No. 12. ADL 18746 7. Permit No. 67-52 8. APl Number 50- 733-20042 9. Unit or Lease Name SMGS Unit 10. Well Number 6 11. Field and Pool South Middle Ground Shoal Heml cc k Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made ]~ Other [] Pull Tubing [] Other [] Pulling Tubing ~] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company performed the following work: 1. Determined wellhead pressure, mixed, brine, and killed well. 2. Set back-pressure valves, nippled-down tree, nippled up BOP's and tested to 2,500 psi. Pulled back-pressure valves. 3. Pulled tubing and bottomhole assembly. 4. Ran in underbalancing 'disc assembly, new bottomhole assembly, and tubing. Mule shoe set at 9,269' and bottomhole assembly set at 9,198'. Packer previously set at 9,218' during workover performed in November 1982. 5. Displaced 262 barrels of fluid from the annulus using nitroqen. 6. Dropped bar to break underbalancing disc assembly and surge perforations. 7. Returned well to production. ~[~iVE~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use~~' Conditions of Approval, if any: Title District Superintendent Approved by Form 10-403 By Order of COMMISSIONER the Commission Date Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 August 16, 1983 Fi 1 e' LAD-837-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation COmmission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Notice of Intent SMGS Unit Well No. 6 Platform Dillon, Cook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of our intent to replace the bottomhole assembly in SMGS Unit Well No. 6. The well tested at 64 BOPD, 1,584 BWPD, and 15 MCFD of gas when it was returned to production in November 1982. Recently, production has fallen to 0 BOPD, 200 BWPD, and 0 MCFD of gas due to a suspected damaged bottomhole assembly. The Kobe 3-inch Type 'E' bottomhole assembly will be pulled and replaced, utilizing the existing packer in the new completion. The well is expected to produce approximately 50 BOPD, 1,500 BWPD, and 15 MCFD of gas when put back on production. We plan to perform this work at our earliest convenience. Any questions concerning this project can be directed to Mike Schwein in our Anchorage office. Very truly yours, L. A. Darsow Di stri ct Superintendent Attachment MTS/seh AUG 1 9 i983 Alaska 0ii & Gas Cons, Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator A_moco Production Company 3. Address P. 0. Box 100779, Anchorage, Alaska 99510 Location of Well Surface Location' Leg 2, Slot 8, SMGS Platform Dillon Subsurface Location- 904' FSL, 1,538' FWL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 110' KB, MSL I 6 . Lease Designation and Serial No. ADL 18746 12. 7. Permit No. 67-52 8. APl Number 50-733-20042 9. Unit or Lease Name SMGS Unit 10. Well Number 6 11. Field and Pool South Middle Ground Shoal Hernl0ck Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [~ Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company plans to' le e Determine wellhead pressure, mix brine, and kill well. Set back-pressure valves, nipple down tree, nipple up BOP's, and test to 2,500 psi. Pull back-pressure valves. Pull tubing and bottomhole assembly. Run in new bottomhole assembly and tubing. Return to production. RECEIVED r e~t Work l~epo~te& Alaska 0il & Gas Cons. Commission ~ F~ ~o. ~ 14.1 hereby ~oing is true and correct to the best of my knowledge. ~f~ Signed ~' /~~ Title District Superintendent Date The space below for Commission use Conditions of Approval, if any: Approved Copy Returned By Order of _._~. ~5 . i1~ 3 Approvedby. BY }l~:,~i~t'! YI.[UGLER COMMISSIONER the Commission Date Form 10-403 ReV. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate L. A. Darsow District Superintendent November 18, 1982 Amoco Production Company Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 File' LAD-1199-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Noti ce SMGS Unit Well No. 6 Platform Dillon, Cook Inlet, Alaska Attached in duplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, subsequent to the repair work done on SMGS Unit Well No. 6. Yours very truly, L. A. Darsow Di stri ct Superintendent Attachment MTS/klt RECEIVED NOV 2 982 Alaska 0il & Gas Cons. Com~is.~iot~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL;I~] OTHER [] 2. Name of Operator 7. Permit No. Amoco Production Compan~v 67-52 3. Address 8. APl Number P. O. Box 779, Anchorage, Alaska 99510 5o- 133-20042 4. Location of Well Leg 2, Slot 8, SMGS Platform Dillon 699" FSL, 1872' FWL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) llO' KB: MSt I 6 . Lease Designation and Serial No. ADL 18746 9. Unit or Lease Name SMGS Unit 10. Well Number 6 11. Field and Pool South Middle Ground Shoal Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [j~] Other [] Pull Tubing [] Other [] Pulling Tubing [~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25. t05-170). Amoco Production Company performed the following work: 1. Determined wellhead pressure, mixed brine, and killed well. 2. Set back-pressure valves, nippled down tree, nippled up BOP's, and tested to 2500 psi. Pulled back-pressure valves. 3. Pulled tubing and cleaned out to 10,078'. 4.Set packer at 9,218' and ran bottomhole assembly and tubing. Mule shoe set at 9,272' and bottomhole assembly set at 9,220'. 5. Returned well to production. NOTE: The initial test on the well was 64 BOPD, 1584 BWPD, and 15 MCFD of gas. RECEIVED NOV 2 3 1982 Alaska Oil & Gas Cons. CommD 14. I hereby certify that~he.?o~regoing is true and correct to the best of my knowledge. Signed ~,._/ ~--~~ Title District Superintendent The space below for Commission use Date ~,iOn 11/18/82 Conditions of Approval, if any: By Order of - Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate AmOco Production Company (USA) Post Office Box 779 Anchorage, Alaska 99510 907 - 272-8471 L. A. Darsow District Superintendent October 20, 1982 Fi 1 e' LAD-1083-WF Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r: Notice of Intent SMGS Unit Well No. 6 Platform Dillon, Cook Inlet, Alaska Attached in triplicate for your approval is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to notify you of our intent to return the subject well to production. The well has been shut-in since June 1976 due to a high water cut. Yours very truly, L. A. Darsow District Superintendent Attachment MTS/klt RECEIVED OCT 2 2 i982 Alaska Oil & Gas Cons. Ccmmission Anchorage STATE OF ALASKA ALASKA L,,~L AND GAS CONSERVATION CO,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Amoco Production Company 3. Address P. 0. Box 779, Anchorage, Alaska 99510 4. Location of Well Leg 2, Slot 8, SMGS Platform Dillon 699' FSL, 1872' FWL, Section 35, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) llO' KB, MSL I 6 . Lease Designation and Serial No. ADL 18746 7. Permit No. 67-52 8. APl Number 5o-~/.1<J3-20042 9. Unit or Lease Name SMGS Unit 10. Well Number 6 11. Field and Pool South Middle Ground Shoal Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco Production Company plans to' 1. Determine wellhead pressure, mix brine, and kill well. 2. Set back-pressure valves, nipple down tree, nipple up BOP's, and test to 2500 psi. Pull back-pressure valves. 3. Pull tubing and clean out. 4. Run in packer, bottomhole assembly, and tubing. 5. Reperforate the G-l, G-2, G-3B, and G-4 zones. 6. Return to production. ~b¢cque::l Work Repor~ecl RECEIVED OCT 2 2 ]982 Alaska 0il & Gas Cons, Commission Anchorage 14. I hereby certify tha~_t,~oregoing is true and correct to the best of my knowledge. Signed /~ix_.,_ Title District Superintendent The space below for Commission use Date 10/20/82 . Conditions of Approval, if any: Rev. 7-1-80 Approved Copy Returned By Order of the Commission D~te/O..'_E.&r_,¢¢' Z~- Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~orm ~0 - 403 8~abrnlt "Intentions" irt Triplicate & "Sul:~equent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS- (Do not use this form for proposals to drill or to deepen use "APPLICATION 'FOR PERMIT-L`' 'for such 'proPosals.) · W£LL WELL OTHER 2. NAME OF OPEH~ATOR Amoco Producti-on Company 3. ADDRESS OF OPERATOR P. 0. Box 779, Anchorage, Alaska 99510 4. LOCATIONOFWELL Atsurface Leg 2, Slot 4, MGS Platform Baker, 1989' FNL, 588' FWL, Sec. 31, T9N, R12W, S.M. 5. APl NIfIVlF_,IIlCAb CODE 50-133-10073 6. I.,EASE DEIKIGNAT1ON AND SERIAL NO. ADL-17595 7. IF INDIA.N, AJ..LOII-J.']~ OR TRIBE NA~IE 8. UNIT, FARNI OR LEASE NAME MOS 17595 9. ~VELL NO. 6 10. FIELD A~D POOL, OR WILDCAT Middle Ground Shoal 11. SEC.. T,. R.. M., (BOTTOM HOI.~ OBJECTIVE) Sec. 31, T9N, R12W, S.M. 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PEI:LlVIIT NO. · RKB 71.36' above MSL ~4. Check Appropriate Box To Indicate Nature of NOtice, Re }orb or Other Data NOTICE OF INTENTION 'IL'K): FRACTURE TREAT MULTIPLe COMPI,ETE 8H00T OR ACIDIZe ABANDONs REPAIR WeLL CHAN0e PLAN8 ,~ ~ Other) FRACTUR[ TREATMINT ALTERINO CASINO ~HOOTINO O~ ACIDIZINO ABANDONM~HT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE I'I10POSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, includin~ estimated date of starting an)' proposed work. The fOllowing procedure is intended to inhibit future scale formation. 1. Acidize Well with 8000 gallons 15% HCi. 0 o Inject 5 drums scale inhibitor into formation (Arcohib S-239 polymer inhibitor). Shut-in well for 12 hours. 16. I hereby ~tt~y that the fore$otnl\la true and correct t--,/, TITLE Area Superintendent September 7,, 1976 (This space for S't~te office,.use) -~ APPROVED BY .... CONDITIONS 'O~'-~PROVAL, IF ANI; TITLE See Instructions On Reverse Side App~ Copy llelumed State of Alaska Form P-4 Amoco Production Company SMGS Unit Well No. 6 September 9, 1974 Page 2 (continued) August 12-14: Acidized the G-4 zone with the following volumes: Zone Perforations Treatment Bottom 9780-9830' G-4 Top G-4 9680-9765 ' 3000 gallons of 15% HC1 acid 3000 gallons of 15% HC1 acid Retested perforations 9680-9765'. Recovered 20 barrels acid cut mud, 9 barrels of water and 100 barrels of oil base mud. August 15-18: Set packer and bridge plug at 9420-9488'. Cement squeezed perforations 9455-9480' with 150 sacks of Class G cement. August 19: Retrieved packer, drilled out cement and milled over and pulled bridge plug. August 20: Ran dual 3-1/2" Buttress tubing and Kobe 3" OPO BHA. Tested cavity to 3000 psi and installed tree. Tested tree to 5000 psi. Tested okay. August 21: Dropped pump and pumping, N.G. l~)rm ~o. P--4 R~V. 3-1-70 STATE C,. ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DU~LICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ~gLL 2. NAME OF OP~I~ATOR Amoco Production Company ,3. ADI~'RESS OF OP]~ATOR P. 0. Box 779, Anchorage, Alaska 99510 4 LOCA~ON OF WELL Leg 2, Slot 8, SMGS Platform Dillon, 699' FSL, 1872' FWL, Sec. 35, T8N, R13W, S.M. ~P! NL~EP-ICAJ~ CODE 50-133-20042 LF~%SE DESIGNATION A.~D SE1RIAL NO. ADL-18746 7 IF INDIA]~. ALOt lk~ OR TRIBE NAME 8. L~IT FAi~ OR LEASE SMGS Unit 9 WEIJ~ NO 6 10 FLFJ~D AND POOL. OR WILDCAT South Middle Ground Shoal II SEC, T.. R. M. (BOil'OM HOI~ o~ Sec. 35, T8N, R13W, S.M. 12 PEP~M IT 67-52 13. REPORT TOTAL DEPTH AT END OF MONTH. CHA~NGES IN HOLE SIZE, CASING AND CI~MENTING JOBS INCLUDING DEPTH SET AN~ VOLUMES USED, PERFORATIONSi TESTS AND i~ESULTS FISHING JOl~S JL~NK IN HOLE AND SIDE-T~tACKED HOLE AND ~Y OTHER SIGNIFICANT CH.A-~GI~ IN HOL~ C~DNT)ITIONS S~ary. 0~..0Perations During August 1974: August 1-5: Retrieved pump and removed tree. Cut the short string and long string, pulled and laid down. Milled over and pulled packer. August 6-11: Set straddle packer and bridge plug and tested the follow- ing intervals for 3 hours. Test No. Zone Tested Perforations Results 1 Bottom of G-4 9780-9830' 2 Top of G-4 9680-9765' 3 Top of G-4 9680-9765 4 Bottom G-3 & 9578-9638' Top of G-4 9645-9655' 9680-9765' 5 Middle of G-3 9495-9555' 6 G-3A 9455-9480' 7 G-2 9315-9325' 9350-9390' 8 G-1 9240-9270' Recovered 10 gallons of water. No recovery. No recovery. 68 barrels of fluid, 22% water. 47 barrels of fluid, 37% water. 78 barrels of fluid, 84% water. 65 barrels of fluid, 52% water. 26 barrels of fluid, 38% water. (continued) 14. , hereby ~~ ~oreg0ing~ true and e0rre~ ~.~~.~/ ~ Area Superintendent r~A'rt~ September 9, 1974 SlO~ .. ~ _ _ _ NOTE--Report off this fo~ Is required for .~ch GOlindor ~nth% regordless of tho Itotus Of operotlens, Grid mu~t ~ fil~d io dupli~tl, with the oil and gos conlervatbn Commiffee bythe 15~ of the SuQcNding mon~, ~leM otherwil~ d~r~cted. Amoco Production Company P. O. Box 779 Anchorage, Alaska 99510 August 19, 1974 File: GJR-565-W'F Mr. Homer L. Burrell, Director Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Re- Sundry N ' ' ot~ces and Reports on Wells South Middle Ground Shoal Well No. 6 Attached is a State of Alaska Form 10-403 requesting permission for a workover of SMGS 18746 Well No. 6 as described herein. Yours very truly, John C. Schiilereff Supervisor in Charge Attachment AU8 2 2 ~974 DNISION OF OIL AND GAS ~C~O~ Form 10-403 REV. '1 - t0-73 ~ubmit "Intentions" in Triplicate "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATIO'N COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FOR [~'ER/N~IT-2' ~or such 'p[o~osal~.) · . OIL 0AS [] w ELL WELL OTHER 2. NAME OF OPERATOR Amoco Production Co~pany 3. ADD~ESS O~ OPERATO~ ?. 0. Box 779, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface Leg 2, Slot 8, 699' FSL, 1872' FWL, Sec. 35, T8N, R13W, S.M. 13. ELEVATIONS (Show whether DF, RT, G-R, etc. Check Appropriate Box To [ndir. ate N~ture of NOtice, Re AP1 N~CA~L CODE 50-133-20042 L,F-,ASE DI/ISIGNATION A.ND SERIAL NO. ADL-18746 7. IF IITDIA.N, A. LLO'i'ri~E OR TRIBE NA.M.E 8. UNIT, FARNI OR LEASE NAME SMGS Unit g. WEI.,L NO. 6 10. FIEI2) A~D POOL, OR WILDCAT South Middle Ground Shoal 11. SEC,, T., R.. M., (BOTTOM HOLE OBJECTIVE) Sec. 35, T8N, R13W, S.M. 12. PERIVIIT N'O. 67-52 )orr, or Other Dal'~ ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPL~ COMPI,ET~ ABANDON° CHANO~ PLANS liUBSJQUENT RBPORT OF: SHOOTING OR ACIDIZING , ABANDONMENT* (Other) (NOTE: Report results of multipls completion on Well i Other)., Completion or Recompletion Report and LoS form.) V~:SCRIn£ I'nOP0SED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, tncludin~ estimated date of starting any proposed work. Propose to pull tubing and Kobe pump, mill'out'packer, circulate the wellbore clean with oil base mud, test the producing zones, cement squeeze zone G-3A from 9420-9488' with 100 sacks Class G cement, and acidize the G-4 zone from 9770-9870' with 3000 gallons 15% HC1 acid. Will reinstall open power oil Kobe pumping system. Anticipate work to begin August 2, 1974. Authorization obtained August 16, 1974 per telecon between Richard Sloan and Hoyle Hamilton. 61 fo OfL ANCH011t APPROYED B~ ,, t/~'%''~'~'~ ' TITI,~ CONDITION80F~/~PPBOYAL, II~A~'X: ~ DawzAugust 19, 1974 DATE .... Soe Instructions On Reverse Side Approved Copy _? Returned/ SMGS Unit 18746 No. 6 Workover Well History 8/11-12/68 8/13-16/68 8/17-19/68 8/20-23/68 8/24/68 PBTD 10,480'. Pulled and reran tubing and Kobe equipment. Released rig. Attempted to pump with new BHA. Could not reverse out pump. Moved on rig, pulled tubing and Kobe equipment. Reran same and released rig. Pump tested. PBTD 10,480'. Workover completed as a pumping oil well. DIVISION OF MINES ~ -~ Petroleum Branch INDiViDUAL ~LL RECORD I s sued LaS 2~ Slot ¥ Oioerator Pan ;'"~ ..... 4 ......Pet Core Location (Surface) ,c;o~ 'r,'~L :. ~°72~ Or Ow'~Ae~J ................. Unit Loc. (Bottom) , .... 30 !:7(~: Sea ?[eli NO~ 5 Area S~ud ~te ~9~.~ Drilling ceased Su o~-'~ n ~', ,:~ ~20 andon e d -- IP 5~°~ '~as 13!6 " '- '" ~CP/D, Bean 124.5__/64 CP psi e~ ~.~ Depth S-: Cmt Pelf: Casing ~ ~,_~ ........ 9245 :,u-'-',:35.)%' 602' to sur:c i3 3/0~5/. ~:"~ 2020~ ~200 ....... ~.,.,t, '~'O0 ~9.3 ]3 ~[;D ~.,:..-:p - ~"' ~io~'°"'"40:43.5& 75~95''~uu -!0:~9540:-50'; /'~> !0 530~ 1550 9580'-°600: -;:. . 37f~' tbg. 9,827' Plugs PRODUCTIVE EORiZOilS Dep-'ch Co'..:~%e n t: . r,,,PE L L STATUS .. ~ .~ ~ OCt DeC v,_~ ar J~:,;~ Feb Mar A~ ~'~V June July Aug o .... Nov SUBMIT IN DUPL!} ~.* '~'TATE OF .~,LASKA ,, S~e otli0r lm structions on OIL AND GAS CONSERVATION COMMITTEE r~v~,.~ ~d~ WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* - , , ~ la. TYPE OF WELL: on, ~s's WELL WELL DaY Other . b. TYPE OF COMPLE~ON: 1VELL OVER EN ' BACK n~sva. Other NAME OF OPERATOR Pan American Petroleum Corporation ADDRESS 0~' OPERATOR "-.. . ' ~ '" P. 0. Box 779.-Anchorage, Alaska 99501 L~CATION OF wELL (---Report location Clearly and'in accordance with any State requirements)* At surface At top prod. interval reported below At total depth 13' DA'TE St:~UDDED ¥4' D'~T'E T'D' RF~CHED [15' DA'TE CO1V/~ SUSP OR ABAND'8-24-68 r ~W ~* ROTARY TOOLS PRODUCING ~~(S), OF ~S COM~TIO~, BOOM, N~E (~ AND ~)* 5. AP1 NtIllF2flCAL CODE 50-133- 20042 ADL- 18746 ?. IF INDIAN, ALLOTTEE OR TRIBE NAM~ : 81 UNIT ,Fa OR LEASE NAME ~ SMGS Unit 9. WELL NO. ~ 6 10. F~,~ ~ P~L; OR W~T · '24. TYPE ELECTRIC A~ID OTHER LOGS RUN ~5. ,._ SOuth Middle Ground Shoal 11. ~SF.~C., T., R., M., (BO'I'i~OM HOLE OBJECTIVE) Sec 35, T8N, R13W, S.M. '12, PEP,,NLIT N'O. 67-52 16. ELeVATiONS (DF, RKB, RT, GR, .~rc)* ]17. ELEV. CASINGHEAD INTERVALS DRILLED BY " CABLE TOOLS WAS DIRE~ONAL · 23. SURVEY MADE i I i ii · i CASING RECORD (Repo_rt all strings set in well) CASING SIZE WEIGHT, LB/FT. DEPTH SET (MD) HOLE SIZE CI~IY_~. NTIi~G RECOP~D ~VIOU1N'T PULLED . iii I i i i~i I 26. LINER RECO'I%D 27.. TUBING 28. P~O~TIONS OP~ TO PRODU~O~" ;inte~al. si%e ~d ~umber) '1 ~, AC;D. S~O ~,i ~'~. ~ ~DU~O~ 8- 25- 68 Pumping ~'~> Produc ~ng DATE OF T~ST, [~S T~ '[~OXE SIZE [PROD'N FOR OI~BBL. GA~CF. WA~B~. [ G~-O~ ~o 8 24' 6~ 24 64/64" ~ ~ '~ , I G I~S~G P~S~ ]C~~~ OI~BBL. ' GA~g~. W~B~. lOlL GRAVITY-~I (C~.) 1 3100 i ] > t 2962 I 869 I 18 I 34'30 , DISP081TION OF OAS (801d, used ]or ]uel, vented, etc.) ........ t TEST ~ITNESSED BY Used for fuel and flared ~orkover ~ell , ./f /0~."// . wi,~m' .Area Admin. Supervisor D*TE 9-12-68 > INSTRUCTIONS C-,-~nerali This form is designed for submitting a complete and correct wel completion report end log on : all types Of lands and leaSes in Alaska. · Item: l&: indicate., which elevation is used as reference (where not otherwise shown) for depth .measure- ments given in other spaces on this form and in any attachments: .~ . ' -. : Items 20, and 22:: If this well is completed for sepb¥'ato 'pr6-d0ctior~ .from more than one.: interval zone .(multiple completion), so state in item 20, and in item 22 show the prcducing interval or intervals, ':.top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) .on thiS:form, adequately identified, for e~ch add, itional inie~val to be seperately produced, show- -lng the. adlditional data Pertinent to such interv&l. '" ~ . item26: ."Sacks Cement":' Attached '~upplemental' reCbi~ds for this well should show the details of any~'"r~Ul:' .-tiple stage cementing and' the location of the cementing tool. ? : , ~ . Item 28: Submit a separate completion report on:. this. f~o~.rn .fo_r... each interval to be separe, tely produced. (See instruction for items 20 and 22 above). ., ....... i ~ " ' -~4. SUMMARY OF I~O~'VIATION TESTS INCLUDING INTEHVAI.,'TESTED, P~URE DATA'A.N'D ~OV~ OF OIL, G~.. _ "'~ ~0. CORE DAT~.:.: A~CH BR1E~ D~CRIPi~ONS OF LITHOLOGY, POROSITY, FRA'C~R~. APP~NT, DIPS ,: - ,.. ,: ::' :' AND DE'FECU'E1) sHOws OF'OIL, GAS OR ~i~:. ~'<: : ' ¢ ' ....... . Form No. REV. 9-~.67 STATE OF ALASKA OIL AND GAS CONSERVATION CON~AITTEE MONTHLY REPORT O'F DRILLING AND WORKOVER OPERATIONS 1. o,L 1!9: °" I-I WELL OTHER 2. NAME OF OPERATOR Pan American Petroleum Corporation 3. ADDRESS OF OPERATOR APl NU~IE~CAL ~ODE 50-133- 20042 LEASE DESIGNATION AND SERIAL NO. ADL- 18746 7. IF INDIAN, ALOTTEE OR TRIBE NAME 8. UNIT,FARM OR LEASE NAME SMGS Unit 9. WELL NO. P. O. Box 779 - Anchorage, Alaska 99501 6 4. LOCATION OF WELL Leg 2, Slot 8, SMGS Platform 'D'; 699' FSL, 1872' FWL, Section 35, T8N, R13W, S.M. 10. FIELD AND POOL. OR WILDCAT South Middle Ground Shoal 11, SEC., T., R., M.. (BO'I"POM HOI_.E O~mCTrV~ Sec. 35, T8N, R13W, S.M. 1~. PERMIT NO. 67-52 13. REPORT TOTAL DEPTH AT END oF MONTH, CHA~N'GES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUlVfES USED, PERFORATIONS, TESTS ANT) RESULTS, FISHING JOBS, JU'NK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTI-IER SIGNIFICANT CHANGES IN HOLI~ CONDITIONS. 8/24 8/11-12 8/13-16 8/17-19 8/20-23 PBTD 10,480'. Recompleted as a pumping oil well. Moved on rig, pulled and reran tubing and Kobe equipment. Released rig. Attempted to pump with new BHA. Could not reverse out pump. Moved on rig, pulled and reran tubing and Kobe equipment. Released rig. Pump tested. ~ -.': / ANCHORAGE mG~D I~' ~'_' ~--~/~'~ TITLE Asst. Area Admin. Supvr. ~A~ 9-12-68 ' d NOTE--Report on this form required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. For~ No. 1:'---4 STATE OF ALASKA susMrr IN ~m~LZCA~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF 'DRILLING AND WORKOVER OPERATIONS WELL WELL 2. N~E OF OPm~TOR Pan American Petroleum Corporation APl NUA~iERICA. L ~ODE 50-133-20042 LEASE DESIGNATION AND SERIAL NO. ADL- 18746 ?. IF INDIAIg, ALOTTEE OR TRIBE NAME 8. IY~IT,FAi:~ OR LEASE NA~E SMGS Unit 3. ADDRESS OF OPI~TOR 9. WELL NO. P' 0. Box 779- Anchorage, Alaska 99501 6 4. LOCATION OF WELL Leg 2, Slot 8, SMGS Platform 'D'; 699' FSL, 1872' FWL, Section 35, T8N, R13W, S.M. 10, FIELD AND POOL, OR WILDCAT South Middle Ground Shoal n. SEC., T., R., M.. (BOSOM HO~ om,mCUUV~ Sec. 35, T8N, R13W, S.M. PERMIT NO. 67-52 REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISI-LING JOBS. JD-NK IN HOLE AND SIDE-TRACKED HOLE ~klXrD A~NY O'FI-IER SIGNIFICA/XIT CI-IA3~GES IN HOL~ CONDITIONS. 7/31 - PBTD 10,215'. Pump testing. 7/16-17 7/18-30 - Pulled tubing, perforated 9240-70' 9315-25' 9350-90' 9455-80' 9495-9555' 9578-9638' 9645-55' 9680-9760' 9780-9830'; set packer at 9183' and tubing at 9808'. - Pump tested. S~GN~ ~TLE Asst. Area Admin. Supvr. OA~r 8-8-68 NOTE--Report on tl~is.form is r d for each calendar month, regardless of the status of operations, anti must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. "-" CONFIDENTIAL // %;/ATE OF ALASKA ',See ~ structions on 5. API ~CAL CODE %.~ ._~'" OIL AND GAS CONSERVATION COMMITTEE rever~e side~ _~ 50-133 20042 ~.~ WELL cOMPLETiON OR RE¢OMPLiT~ON R£P~)iT ,AND LOG* · ADL - ~8746. b. TYPE OF COMPLETION: __ ~ .. NEW ~ WORK PLUG OVER E~]ENDEEP- E~ hACK E~]P. ESVR.DIFF' ~ Other 8, iINIT,FAlh'VI OR LEASE NAME WELL . ~. s~-. o~ o~o~ ', SMGS "Unlt Pan American Petroleum Corporation y ~. W~.L ~o. 3. ADDRESS OF OPERATOR -~ 6 " P. O.' Box 779· .~ Anchorage. ... ~. LOCATION OF WELL .(Report:~locatio~ c~early a~d".i~ ~cord~Ce wit!~ a~y~tate r~quirement,)* South Middle Ground Shoal at .~r~ac, Leg'Z, $1ot 8, SMGS P..lat£~.r'miD; 1872' FWL, ~Section 35, TSN, R13W,-: S.M. oa~r~nv~.) A~'top prod. interval reported below 856, FSL,"1605'~'FSL, Section 35,_.TSN,-.R13V~, S.M. Sec. 35, TSN, R13W, S.M. At total depth. 910' FSL, 1530' FWL, Section 35, TSN, Ri3W, S.M. '~.~.mT~O. , 67-5g 9/20/6?. [ 1~0/26/~67 :11/6/67 I RKB 100' MSL 59. ~4' MSL 10,942," MD [ 10,215' MD , i," ; ' I ,: ~ 22. PRODUCING LN'.'AL~VAL(S), OF THiS C{~MFLE- TI0~-ifI~P, BOTTOM, I~AM~.._. (lVrD AND TVD)* 23, 'WAS DIR~..CTIONA/~ SURVEY MADW. 9245'9810" State "G" Unit LOwer Kenai Cor~lomA~e ; Yes 24, TYPE EIM~C'FIt. IC AND OTI-iE~% LOGS RUN . ~.~;~ 1ES, OR-SOnic,. Dipmeter ~ :' ~- CASIi~G RECORD all ~trings set in well) . C~SiNG SIZE WEIGHT, DEPTH SET (AriD) SInE CEASe. NTI1VG I:LECOI:{~ PUL 1L~D 20" 85# 0 sx '-:~ 2020' 0 sx , ~'i- 9- 5 ,43. 1 sx · 9.8. LIN~I% i~EC'O,~,/D TUBLI~G ~' 9827' 9155' 3-1/2" 9166' 9.8. P~.lq~ORATIONS OPV.-L~ TO (Interval, size and number) ~.9. ~CID, St~OT, Fii~a~-~I'~/lq]E, CF~¥iENT SQU~ZE, ETC. 9245- 55', 9315220', 9350 - 60', 9375- 85' D]~I~I IATT]SRVAL.(1VLD) I A!%~[OUAFr ~ ZlND O'F 1VI~=~ USED 9465-75' 9500-10','9540-50' 9580-9600',, ' ' 1!.. ,~i, 9625-35' 9645a55' 9680;90 9710-20' 9755-65' 9790-9.810' all with 4 jspf. '' ~0. -~ ~ PRODUCTION 11/2/67 Flowing : ~'~ Producing ~ o~ ~. |aouas ~rm~ |~o×~ sm~. lm~oD'~_ ~oa om--~.. O~S---~CF. w~ama-.-~.~., l~.s-om a~a~o ..... ~- ' 10 '124 ~"64 ,~sT ~O~ · · I 'i i '-- i' 125/200 I I ~_ [ 57z~ I, ~3~6 ; I ,J 33.5o' al. DISPOSITION OF GAS (8old, used Sot/ueg, vented, etc.)' . , TEST witNESSED BY Flared lES, Well History, Directional Data 33. I hereby certify that the for_egoing and~Lttached iniormation is complete and correct as determined from aIUavallable records ~ Area Admin. Supvr. / 67 · i ·(See Instructions and Spaces [or-Additional Data on Reverse Side) _: INSTRUCTIONS General: This form is designed for submitting a complete and correct well cor'hpletiqn report and log on all types of lan-:Js" and leases in Alas. ko ..... ' < '~e v Item: 16: Indica'te which elevation is u~ d as reference (where not otherwise ~ho~wn) f-c~r depth measure- ments'given in other spaces on this form and in any attachments. :m Items lO, ~'nd 12:: If lhis well is completed for separate production from more than one interval zone (multiple completion),)so state in item 20, and in item 22 show the prcducing interval, or intervals, top(s); bottom(s) and name (s) (if any) for only the interval, reported in item 3'0: Submit a separate report (page) on this fbrm, adequately identified, for each additi_Or~al interval to be sep~eratelY~; produced, show- ing the additional data pertinent to such interval. ~ . . It®m26: "Sacks Cement": Attached supplemental records f~r' this well should show.~ tile details of any mul- ) t~ple ~stage Cementing~ and the location of the cementing t~ool. - . · Item tS: Submit a separate completion ~eport on this forth "for~ each interval to be separately produc~i. (See instruction for items 20 and 22 above). ~n~mn~nm~~q~.9"~H. lVIATlON TESTS INCLUDING IN~TEI{VAI-, TESTED, pRESSURE DATA. A.N'D p,.F, CO~E~ OF OIL. GAS. WATEH AND MUD - - .. . DST #1 - 10,530-55', Good no fluid to surface.-Reversed 8500 ft. fluid, 15 BO, 9 bls mud, 105 bls GCW, isip-52Z0, fsip 5ZZ0, ifp 197, FFP 1459, IHP 5442, FHP 5442. DONFIDENTIAL 3/~.. CORE DATA. ATTACtI BRIEF DESCRIPITIOI~S OF LITHOLOGY. POROSITY. FRAt~URES. APPARENT DIPS AND DE'PECTED SHOWS OF OIL. GAS OR WATER. . ore #1'~ 10, 53.3-10, 555t, cg~ ss, gry t~o brn, unconsolidated, particles angular tO]'!subangular, F poro~sit?, slight fluorescence, no struct. _. evidence. ~ 35. 1ViGS Sand Mbt. State A State B State C State D __ State E State F State G Siltstone G~D,I..OG IC M A.RliliiP~ MEAS. D E'~TI{ 6520 7372 7743 8096 1 8380 8683 8918 9230 I0010 DEl=TH 8/11-12/68 8/13-16/68 8/17-19/68 8/20-23/68 8/24/68 SMGS Unit 18746 No. 6 Workover Well History PBTD 10,480'. Pulled and reran tubing and Kobe equipment. Released rig. Attempted to pump with new BHA. Could not reverse out pump. Moved on rig, pulled tubing and Kobe equipment. Reran same and released rig. Pump tested. PBTD 10,480'. Workover completed as a pumping oil well. Chronological Well History ~I-' ;I-' '" ...... ;I-' ;I-' ~I'- '" SMGS Unit Well #6 912o167 9/zz/67- 9/23/67 to 10119/(~7 10/23/67 10/24/67 to 11/01/67 11/02/67 to n/05/67 Spud below 20" casing with drilling rig; 20" casing had been set 7/29/67 at 603' with 1250 sx. Drilled 17-1/2" hole to 2045' and set 13-3/8" casing at 2020' with 1200 sx. Drilled 12-1/4" hole to 10,530', logged and set 9-5/8" casing at 10,530' with 1550 sx. Cut core 10,530-10,555'. Set packer at 10,462' and ran DST #1 10, 530-10,555'. Drilled 8-1/2" hole 10,555-10,942' and logged. Set retainer at 10,480' with 50 sx plug to 10,360'. Switched to workover rig, perforated intervals between 9245' and 9810', and ran dual tubing strings. Flow tested. 11/06/67 - Completed as flowing oil well. l~rrn I¢o. 1:'---4 t%EV. 9-30~67 .STATE OF ALASKA suBMrr IN D~LmAam OJL'AND GAS CONSERVATION COMMITI'EE AP1 NUMERICAL CODE 50-133-20042 6.LEASE DESIGNATION A.N'D SEHIAL NO. MONTHLY REPORT OF 'DRILLING AND WORKOVER OPERATIONS ADL - 18746 1. 7.IF INDIAN, ALOTTEE OR TR1BE .NASIE 0IL t~ GAS ~ WELL WIiLL OTHER 2. HA/ViE OF OPI~q. ATOR 8, 13'NIT,F.~M OR LEASE NA..ME Pan American Petroleum Corporation SMGS Unit ~, Ar~a~ss oF O~rOR 9. wELL .~o. P. O. Box 779 - Anchorage, Alaska 6 4'.LOCATION O,F WELL Leg Z, Slot 8, SMGS Platform D; 699' FSL, !872' FWL, Section 35, T8N, R13W, S.M. 10. FIELD A.ND POOL, OR WILDCAT _South Middle Ground Shoal 11. SEC., T., R., M.. {BOTTOM HOLE OB.rECTIVE ~ Sec. 35, T8N, R13W, S.M. PEP.MIT NO. 67-52 13. REPORT TOTAL DEl>TH AT EAID OF MONTI-I, CHA~NGES IN HOLE SI~E, CASING A.ND CE/VIENTING JOBS INCLL'DING DEPTH SET AND VOLU1VIES USED, PEB. FOMTIONS. %'ESTS AIq'D RESULTS, FISHING JOBt~, JUNK LN HOLE A_ND SIDE-T'I~CKED HOLE ~.ND 7kN¥ OTI-IEII SIGNIFICANT CtlA~ES IN PIOLJ~ CONI)ITIONS. 11/6 11/1 n/z-5 PBTD 10, Z15'. Completed as flowing oil well. Set dual tubing strings at 9827' and 9166' with dual packer at 9155' and released workover rig. Flow tested. RECEIVED DE0 1 3 19 7 DIVISION OF MINES & MJNER^Lg ANCHORAGE 14. I hereby certify that the foregoin~g'}is ianae~r~d ~orrec~ smws~ __C' ~'('~. ~/~ ' . ..... =T~A_ss~t_,-A-reaAdm_in. Supvr.~A.,.,.. 12/11/67 Il ,llll 111 I II II ; .... NOTE--Report on this form J~' required for each calendar month, regardless of the status of operations, and must I~e filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, un[ess otherwise directed. Form No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 1964 u~,uE Anchorage NuM~ ADL - 18746 o~ ~N,~ N^M~ SMGS Unit LESSEE'S MONTHLY REPORT OF OPERATIONS The folloWinff is a eorreot report of operations and production (inel~di~ drillinff and prod~ein~ wells) for ~he rno~th of .................. _ _O_ _c_ _t_ Q _b_ _ _e_ _r_ _ , ..... , 19_~__7__, ............................................................................ .4~enffs address P.O. Box 779 ~ ...... __Pan American Pf~troleum Corp. ...................................................................Anchorage, Alaska .~;'~.'-'~ ....... ~ ............... ).~Y ¥'::-~ .................... ~_+,~ +:+,. Ass t. Area Admitrf'. Supvr. ................................................................................... .~,,,,, o ,~,~,~,~ ........................................ _'_ .............. SEC. AND BARRELS OF OIL GRAVITY I Cu, FT. O~ GAS GALLONS O~ BAREELS O{ REMARKS ~ OF ~ r~WP. RANGE WELL D~YS OASOLINE WATER (If No. ~ao~c.~ (~'tho~) RECOVERED none, so s~te) date ~d r~ult of ~t for ~o~e e~t of ~) ...... W ]~ 8N i~W~ 0 0 0 0 0 0 API ~0-1~-2004~ 10:/~1 PBTD ]0,21~,~, se~ting tubing, 10~/1-1(,/18, dri.led ~47~-10,~0' an([logged. /20, cut Cor~ ~1 10,~-10 .;~', recovered 14~. 10/21-~0/2~, T) 10, ~' DST ~1 1,),~0-10, 10t24-10/27, d:ille~ 10, ~-10, 942' and 10/28, plu;~ged back to 10,21~~ with Model K r;~ta~ner ~t 10,480 plug ~0 sx at~ove. 10129-10/~, ~:BTD 10,21~; p(~rfors.ted in~erv'~ls betw.~en 924~ -9810~. W ~ 8N [3W 4 0 0 0 0 0 0 API 50-1~-20047 10/~1 - TD 700 . Op.~ning hole from 17-1/2" tc 20". 10/28, mo~'e or driling rig and spuJ ~rom Le~ 1, Slo~ 2, SMG[~ Platform D. 10~29 [0/~, d::ille~ to 700' a~.d op(ned hole f~om 12-1/4" to 1]01/2". ........... BHL SE S~ SE NW See NOTE--There were ..:?...r...°..d...u...c..t..i...°...n.....P...a..g.e. .... runs or sales of oil'. ................ .N...o ......................... M cu. ft. of gas sold- ..................... .~.N...~. ................................ runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.~Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 6th of the succeeding month, II~rtl~ss/~t~r~vj~ directed. . 1967 OIVISION OF MINES & MINEEAi,~ Form P--3 STA~ )F ALASKA SUBMIT IN TRIP' (Other instruction, ~ re- OIL AND GAS CONSERVATION COMMITTEE verse side) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) AP1 50-133-20042 Effective: July 1, 1964 LEASE DESIGNATION AND SERIAL NO, ADL- 18746 6, IF INDIAN, ALLOTTEE OR TRIBE NAME 1. 7, UNZT AGREEMENT NAME WELL WELL 2. NAME Or OrERATOR Pan American Petroleum Corporation 8, ADDREEIB OF OFERATOR P. O. Box 779 - Anchorage, Alaska 99501 LOCATZON OF WEtL (Report location clearly and in accordance with any State requirements,s See also space 17 below.) At surface Leg 2, Slot 8, SMCS Platform D; 699'FSL, 1872~ FkrL, Section 35, T8N, R13W, S.M. 14. PERMIT NO, 67-52 15. E,.mVA?XONS (Show whether Dy, s?, oR, eta,) Estimated RKB 105' above MSL South Middle Ground Shoal Uni SMGS Unit 9. W~LL NO, 6 10, FIELD AND POOL~ OR WILDCAT South Middle Ground Shoal ll, EEC,, ~,, R,, M. OB RL~. AND eUuVET OR AREA SectiOn 35, TSN, R13W, S.M. 12, BOROUGH { I8. STATE Kenai { Alaska Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER S~UT-OFF J I PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR wz~r~ CHANOE PLA~S (Other) Plug Back IUBIEQUENT REl'OI''e OF: WATER SHUT-OFF ~'~ REPAIRING WELL FRACTURE TREATMENT [__{ ALTERING CARING SHOOTZNG OR ACZDZZXNO L__-J AEANDoNMEN!r* (Other) ~ ~ [ I (Norm: Ee}o~ ~emult~ o{ multi}le, oom~letioa on Well Com}letion or Eeeom}Letion Ee~or~ snd ~o{ {orm,) DESCRIBE PROPOSED OR COMPLY&TED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, ineludin~.fltim&ted .date of.starting an~, proposed work. If well is direotionallF drilled, sire subsurface locations and measured and true vertical depths ~or all markers aha zones perti. nent to this work,) · Approximate TD 10,760'. 9-5/8" casing set at 10,530' with 1550 sx. Well will be plugged back to 10,200' or 10,300' with a bridge plug and cement above, or an open-hole plug plus a bridge plug, depending upon log interpretation. Verbal approval given by Mr. VonderAhe to Mr. Eaton, 10/25/67. 18. I he~ebF ceftin7 thst the foFel~oinf SXO~D ~ ' , : (This mpaoe foF Fodera~ ~ o~ee use)~ CONDITIONS ~/~PPBOVA~, TZ?Z,E Ass ' t. Area Admin. Supvr. *See Instructions on Reverse Side mATE 10/25/67 RECFIVFO OC'] 28 1961 DIVISION OF MINE~ & MtN~IIA!,~ Form No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE Effective: July 1, 19~4 ~° ~'~-~ Anchorage LESSEE'S MONTHLY REPORT OF OPERATIONS Tke followin~ is a eorreot report of operations and prod~etior~ (i~el~di~ drilli~ and produein~ wells) for tke month, of .............. _S__e._p_t_.e__m___b___e__r._ ....... 19_~_7__, ............................................................................ .fl~e~,t's address P. O~ ~_o_x___.7_7_9_ ................. Corn-an,, Pan American Petroleum Corp. ................................... A -r~- -C- _ -h- P _r_ _ _~g _e_ ~_ _ _ _ _A_ ! _~_ _s_ _ _k_ _~_ /~' ~~ ~e- ~--~,~,~'~ ...... ~ ..... ~ ....................... ............................................... ........ .... ................. l'~o~e .................................... _z__7___z_:_§__4__7_!_ ............................. ~/~ent's UUe __A_._s__s_.._t:___A__r_e__a__._.AZ'._d_..mi.n.:_.__S..u_~.y__r:~ :,.; SEC. AND BARRE~S o1. Om OaAVrr¥ i Cu. FT. O1. GA8 GALLONS O~ BARRB~ or RE~ARKS ~ OF ~ ~WP. RANGE WELL D~s GASO~E WATER (If (If ~ln~, devth; t~ shu~ down, NO. Pao~c~v (~ thomaS) RECOVERED ~ono~ 8o 8~tO) da~ ~d rmul~ of ~t for eon~t of ,. , ..... W ~ 8N I~W 6 0 0 0 0 0 0 API 50-1~-2004; 10~ 1 - TD (,47~' drilling ~head 9/]9 . TD ~00~. Move on drilling rig and tag cement at 54~~. 20"leasing~ hadbee~ set ~t 602' and cemented to surface on 7/~1/67. 9/~',0 - ~/22 - [rilledto ~'.050' and set 1~-~/8" ca ing at 202( ' wit[~ 1200 sx. 9/~;~ - ~/~ - [tilled 20~0' to 647~'. BHL SE See :Page 1 No ....................... NOTE.--There were ................. : .............................. runs or sales of oil'. ........................ M cu. ft. of gas sold' ......................... ..N..©. ............................. runs or sales of gasoline during the month. (Write "no" where applicable.) NOTE.--Report on this form is required for each calendar mqnth, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Mine~l~s~bsfft~th~ ~tl~f~h~succeeding month, unless otherwise directed. ' , OCT 9 19i~1' r~g~ z of z DIVISION Of: MINES & MtNEItAI~ A~OI~AC41~ MEMORANDUM / / 'TO: FROM: State of Alaska DATE SUBJECT~ FORM SA 50M 1/67 M~EMORAN~D~UM .- TO: r' . ~ FROM: St,ate of Alaska DATE : ~JjJ!~JJ~ ~ ~JJJ~ SUBJECT: ~'~~111~:~: ~ %, Form]P--1 SUBMIT IN .P~CATE* sTATE OF ALASKA (Other instructions on reverse side) APl 50-133-20042 Effective: July 1, 1964 OIL AND GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO ,DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRILL [~ DEEPEN I-] PLUG BACK [-'1 b. TYPE OF WELL OIL I~ OAS [2 SINGLE E] M~LTIPLE ~ WELL WELL OTHER ZONE ZONE NAME OF OPERATOR Pan American Petroleum Corporation ADDRESS OF OPERATOR : 1~. O. Box 779 - Anchorage, Alaska 99501 4. LOCATION OF .WELL (Report location clearly and in accordance with any State requirements.*) At surface Leg 2, Slot 8, 699' ESL, 1872' FWL, Sec. 35, TSN R13W At proposed prod. zone Same as above - well will be drilled vertically 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICEs 15-1/2 miles NNW of Kenai LEASE DESIGNATION AND SERIAL NO ADL - 18746 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME 8. FARM OR LEASE NAME South Middle Ground Shoal 9. WELL NO. Unit 10. FIELD AN~ POOL, OR WILDCAT South Middle Ground Shoal 11. SEC., T., R., M., OR BLK. AND SURVEY OR AREA BHL: SE/4 SW/4, Sec. 35, T8N; R13W 12. BDROUGH SH[ 13. STATE Kenai [ Alas ka DISTANCE FROM PROPOSEDe Ar'~t,-~-r LOCATION TO NEAREST PROPERTI~ OR LEASE LINE, FT. (Also to nearest drlg. unit line, if any) mS~*~C~ ~aOM ~aOpOS~v UO~le~ON* TO NEAREST WELL~ DRILLING, COMPLETE~ 16. NO. OF ACRE8 IN LEASE 4160 19. PROPOSED DEPTH 11, 000' 17, NO, OF ACRES ASSIGNED TO THIS WELL 80 20, ROTARY OR CAIiI,E TOOLS Rotary il. EmVAm0NS (Show whether DF, RT, GR, etc.) 105' above MSL (Est.) 23. PROPOSED CASING AND CEMENTING PROGRAM 22.' APPROX. DATE WORK WILL STARTe SIZE OF HOLE 26" SIZE OF CASING WEIGHT PER FOOT SETTING DEPTH 20" 79.6# 600' 17-1/2" .... I3-3/8" ,,, 54.5f 12-1/4" 9-5/8" 40# & 43.5~ Z000' 11000' QUANTITY OF CEMEN~ Circulate to surface Circulata tn .qurf~_ce . . Minimum of 500' above shoe; additional cement may be used depending upon interpretation of electric log. Well will be drilled as a straight hole. There are no affected operators. Intervals of interest will be perforated and may be stimulated. BOP arrangement attached. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone, If proposal is to drill or deepen directionally, give..pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program, if any. : ' ~ ~.- 24. ! hereby~t~fy thtat~e F~eg'oin~~s T;Ue and Correct. ' ~o ~ ~. ~ ~,,~, Ass't. AreaAdmin Supvr. ~,,, 9/13/67 CONDITIONS aP APPI~OVAL, I~ ANY; AP1. 50-133-. 20042 Subject to Conservation Order #53 APPROVAL DATE THOMAS R. MARSHAL. Li JR. TITLE [xacutiv~ .~cr~tnry .... Alaska Oil & Gas Conservation Committo~ *See In~truction, On Rever~e Side RECEIVED ,4 c,.,,~:.~..,~( DIVISION OF MINES & MINI~JiAL.~ 34 34 3 26 35 1765' SEWARD MER 26 35 T8N IDIAN ALASKA T 7 N SCALE' 35 I"= I000' 2 2'5 36 LEG. NO. I LAT. 60044' 0~16" LONG. 151° 30' 45.85" Y = 2,463,917 X = 229,266 FROM S.W. COR. 745' NORTH ~ 1818' EAST LEG. NO. 2 LEG. NO. 3 LAT. G0o44' 07.72" . LAT. 60° 44' 0.'7;.08" · LONG. 151° 50' ~4,78" LONG. 151° 30' 45.86" Y = 2,463~871 Y = 2,46;5,807 X = 229,:519 X = 229,263 FROM S.W. COR. FROM S.W. COR. 699' NORTH ~ 655' NORTH ~ 1872' EAST 1818' EAST LEG. NO. 4 LAT. 60°44' 0752" LONG. 151° 30' 46 94" Y = 2~463~$55 X = 229,211 FROM S.W. COR. CERTIFICATE OF SURVEYOR 678' NORTH 1765' EAST I hereby certify that ! am properly registered, and licensed to practice land surveying in the State of Alaska and that this' plat represents..o location survey'made by me or under my-supervision...~and thai all dimensions and other details are correct. D~te' '-' Surveyor , .. SURVE'YORS NOTE '? The location of S.M.G.S. Platform "D" wes accomplished · by use of U.'S.C. & (3 S. stations st", "East Fore,and Light", .... . -and Boulder and C.ET. 18 (Offset 2) FINAL PLAT OF S.M.G.S. PLATFORM "D" LOCATED'IN SE I/4 SW I/4, PROTRACTED SEC. 35, T$N~RISW,S.M. .SURVEYED FOR PAN AMERICAN PETROLEUM CARP· BO. BOX 779 ANCHORAGE, ALASKA SURVEYED BY E M. LINDSEY 8~ ASSOC. LAND SURVEYORS 15. CIVIL ENGINEERS 3201 ARCTIC BLVD. ANCHORAGE, ALASKA · RECEIVED ~ SEP 13~1967 Di¥1SION OF MINES & MINERALS -~I~/~I~INIW ~ ~;:::INiW JO /.9611 I 8.7S C13Ai333B x,'-p'/,"-,,,a,,'~xx,,'---'/ · -"~',,,,'~,,,,Ii FLJr-L, i \ ,.L._.% /,o'" ' \ H !~,'~ -r',~/ II I I" '. · 3OOOli'v! R (6OOO¢'t'TEST) I . - , .. ' ~ ~ 8LO;tOUT PREVENTI~R · ' III ' INSTALLATION WHEN ' ' I'! ~OUBLE PREVENTER ~ ' ': % - · ' '~///a t///u~ //~ WITH SIDE OUTLET IS SINGLE PREVENTORS WITH ,-" DRILLING SPOOL AR-F' '"' ? SATISFACTORY 7. 9. 10. 11. 12. 13. 15. h'OTE$ . · Blo~.~ut preventers, master valve, plug valve~ and all fittings must be in good condition. Use new API Seal Rings. All fittings (gates, valves, etc.) ~o be of equivalent presoure rating as preventers. Valves to be flanged and at least 2". Valves next to BOP to be plug type and nominal 3". Equipment through which bit must pass shall be at least as large as the inside diameter of th~ easing that is being drilled through. Nipple above· BOP shall be split so it can be easily removed.. Full opening Bafety valve (Om~co or equivalent) must be available on rig floor at all timzs an~ with proper connections. Kelly safe~y valve installed, sams working pres- sure as BOlt'S. - . All lines and controls to preventers must be connected and tested before drillins out of surface pipe. BOP's must be fluid operated with controls on derrick floor and Hydril complete with accunula- tot and 1 (one) remote cDntr, ol s~ation. · If fillup line iS' tied to drilltns nipple, ~ne connection mu~ bz belcw and approximately 90° Co the flow line. Guase :,ay be left out uhile drilling. Side outlet must be below bottom ram. Ca~inghead and caslnghead fittings to be fur- nished by PAN A/~ERICAN ?ETEOLEIR4 CORPORATION. Chokes may be either adjustable or positive. · . Drilling spool with choke outlet below BOP'~ '' is satisfactory.. · Castn~heads furnished by PAN A~[ERICAN PETROI~Eh~ CORPORATION will be 12" Series '900 and 10" Serie~ 1500, WIIEN DRILLLNG USE --- Top preventer 'idrill pipe ram~ ~ottom preventer-blind rams or ma~ter valve. R~NING CASING USE --- Top preventer -- casing rams Bottom preventer-blind rams or master valve BLOWOUT PREVENTER ARRANGEMENT "D" ',,, 1';"";. ~ ,. l"'~.o.',. 1'" ,.o 4°"'''''~:7-~ ~ PAN At~'£RICAcN PETROL£U;.; ¢ORPORATIO~ PAN AMERICAN PETROLEU~ CORPORATION DIRECTIONAL CONTROL .~ .... Direction ! . Depth Lat. Def. M. ~ ..... ~_. _(.Cor.) . Cou~r~se .Factor A TVD TVD Factor Factor zk N L~x S Z~ W N , S W Dog L~ , , ,L~- . · ~ ' ' ~, '~ ~ ' __ ,. ~ , · 7~-o., ~ .:/":~ ' '" ............ , "-~'-' '=' ' c~?' .... 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' ..... ~' "' '~'~", yq ,;:.; ' ; / ,..,..>// .,' "' .... ~-~..:., 1, _?'x 4x--.'c".~:~.-' ,.'7,;';'".... , 442 4--~.-, ~ ...... . /, ,.-, ,':. ,:...,- .-,47,,~.':. x~ , ~., o- /14 ::o:~1 ~ 7 ~ ~ ~ z ,. ~74..>>7 - .' ,.'.: ~.. . .... ....... , .... ,: - > ~x'''pz~ Z ,_~:/~ J. ,.. ....... . . .... ,... RECEIVED DEC 21 I~B7 I~I¥IJlON Ot~ N~INE$ & ANCHORAGE ,~- ......... PAN AMERICAN PETROLEUM cORPORATION L' N,~E ' ~ ~- Direction ~ I Depth I I Lat. I Def. I I I t I I ' ~ t ' .D._ t Dev. I Cor Course 'l Factor /k TVD I TVD I Factor Factor i'~ N I .~.y I,~-- 4.'.:..:~ ~ ~: I . !~.~ , '1~ , . ~ _ " ' ~ - . ~ , , .~ ........ ~ ..... ~ .... ....~ , ~ _~,,. · .,, I ~~ . ,.~ ~ . ~ · ........ ' ~[1~ ~ ' " ! __ ...... ~ . ~ - - [ .......~ i . ,, i l,i i ~ - . ! I ..... ,,~/ i i~: , ..... ptms~' ~' -~o~o~- ] ~.. ,., , ........ ,~ , ...... .. _ ,, . .. ........., . ...... ~i '', ... ~ - .. , . ~ ~ . ~ .... -- [ ' '' i ' ' ' .... ' ~ ...........