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179-031
1a. Well Status:Oil Gas SPLUG Other Abandoned Suspended GINJ WINJ WAG WDSPL No. of Completions: 2. Operator Name: 3. Address: 4a. Location of Well (Governmental Section): 4b. Location of Well (State Based Plane Coordinates, NAD 27): 5. Directional or Inclination Survey: 6. Date Comp., Susp., or Aband.: 1b. Well Class: 7. Date Spudded: 14. Permit to Drill Number / Sundry: 15. API Number: 16. Well Name and Number: 17. Field / Pool(s): 18. Property Designation: 19. DNR Approval Number: 20. Thickness of Permafrost MD/TVD: 21. Redrill/Lateral Top Window MD/TVD: 8. Date TD Reached: 9. Ref Elevations: KB: 10. Plug Back Depth MD/TVD: 11. Total Depth MD/TVD: 12. SSSV Depth MD/TVD: 13. Water Depth, if Offshore: GL: BF: Development Service Exploratory Stratigraphic Test 20AAC 25.105 20AAC 25.110 Surface: Top of Productive Interval: Total Depth: Yes No(attached) Surface: TPI: Total Depth: x- x- x- y- y- y- Zone- Zone- Zone- Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: 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 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. CASING WT. PER FT.GRADE TOP BOTTOM TOP BOTTOM HOLE SIZESETTING DEPTH TVDSETTING DEPTH MD CEMENTING RECORD AMOUNT PULLED CASING, LINER AND CEMENTING RECORD23. Yes No Yes No 24. Open to production or injection? If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd or liner run): 25. TUBING RECORD SIZE DEPTH SET (MD)PACKER SET (MD/TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED 27.PRODUCTION TEST Date of Test:Hours Tested: Flow TubingPress. Casing Press: Oil-Bbl: Oil-Bbl: Gas-MCF: Gas-MCF: Water-Bbl: Water-Bbl: Choke Size: Gas-Oil Ratio: Oil Gravity - API (corr): Production for Calculated 24-Hour Rate Test Period Method of Operation (Flowing, gas lift, etc.): WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7/11/1979 50-029-20369-00-00 PBU WGI-01 179-031 8100' / 7632' PRUDHOE OIL ADL 0028302 74-949335' / 8639' 8100' / 7583' ~1900' N/A 0 3/4/2024 N/A 07/28/1979 ASP4 ASP4 ASP4 5972003 5974175 5974582 684986 684262 684266 DIL , SP , BHCS , CAL , GR , FDC , CCL 2942' FNL, 1863 FEL, T11N , R14E, Sec 11 UM 3349' FNL, 1877 FEL, T11N , R14E, Sec 11 UM 258' FNL, 1209 FEL, T11N , R14E, Sec 11 UM 20"94#H-40 Surface 111'Surface 111'30"330 sx Arctic Set 13-3/8"72#N-80 Surface 2735'Surface 2735'17-1/2"4760 sx Arctic Set II 9-5/8"47#N-80 Surface 8314'Surface 7822' 12-1/4"500 sx Arctic Set I 7" 29#N-80 8019'9338'7566'8641'8-1/2"355 sx Class G 7-5/8" 29.7# L-80 7799'7802' / 7374' see attachment 8695' - 8725' 8138' - 8162' 8725' - 8745' 8162' - 8177' 8745' - 8785' 8177' - 8209' 8785' - 8797' 8209' - 8218' 8813' - 8853' 8231' - 8262' 8853' - 8907' 8262' - 8304' 8907' - 8917' 8304' - 8312' 8934' - 8954' 8325' - 8341' 8954' - 8983' 8341' - 8364' 8983' - 9003' 8364' - 8380' 9008' - 9018' 8384' - 8391' 9024' - 9034' 8396' - 8404' 9040' - 9048' 8409' - 8415' 9048' - 9058' 8415' - 8423' 9074' - 9082' 8435' - 8442' 9082' - 9102' 8442' - 8457' Not on Production Surface 49 323-036 PRUDHOE BAY Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Date First Production: Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov By Meredith Guhl at 12:47 pm, Apr 19, 2024 Abandonded 3/4/2024 MDG RBDMS 4/19/2024 MDG xG MGR16MAY2024 DSR-4/23/24 28. CORE DATA Conventional Cores(s): Yes No Sidewall Cores(s): Yes No If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and persence of oil, gas or water (submit separate pages with this form if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered)30. FORMATION TESTS Well tested? Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this for, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. MD TVDNAME Permafrost - Top Permafrost - Base Top of Productive Interval Formation Name at TD: 31. List of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071 Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. TPI (Top of Producing Interval). 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). 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. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. 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, whichever occurs first. 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). 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 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. 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. 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. 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: INSTRUCTIONS Bo York Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com (907) 564-4891 Wellwork Summary Reports, Wellbore Schematic, Well photos Top of Sadlerochit Base of Sadlerochit 8680' 9248' 8130' 8576' Kavik 9259 8531 Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.04.19 10:53:06 - 08'00' Eric Dickerman (4002) WELL NAME: WGI-01 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used Surface -Control Line Pump 3 gallons of FINECEM to 3600 psi Surface -Balance Line Pump .25 gallons of FINECEM to 3800psi Tubing punches 7787' - 7792' Tbg / IA Pump 451 bbls of14.0 ppg Class G cement 1514' AOGCC witnessed Tag TOC Tbg / IA punches 495' - 500' Tbg / IA/ OA Pump 65 bbls of 15.8 ppg Class G @ 1390 psi Tbg x PC Annulus 56 gallons of 15.8 ppg AS-1 cement Conductor Top Job 11 gallons of 15.8 ppg AS-1 cement ACTIVITYDATE SUMMARY 3/12/2023 ***WELL S/I ON ARRIVAL*** PICK UP TOOLS & EQUIPMENT, TRAVEL ***CONTINUE 3/13/23*** 3/13/2023 ***CONTINUE FROM 3/12/23*** DRIFTED W/ 5.75" CENTRALIZER & 4.55 x 5' WRP DRIFT TO RN NIPPLE @ 7,814' MD (all clear) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 3/14/2023 T/I/O = 900/300/0. Temp = SI. Cement C&B lines (P&A). No wellhouse, flow line, S- riser, dry hole tree installed.. Drilling scaffold installed. C&B lines show 750 psi. Pumped HYD fliud down lines to verify communication with TBG Approx 3 gal each. Mix cement and attempt to pump down control line. Both pumps failed. Flush control with hydraulic oil to ensure its clear. Rigged down job to re-evaluate. SV, MV = C. IA & OA = OTG. 12:30 3/20/2023 T/I/O = SSV/300/0. Temp = SI. Cement C&B lines (Incomplete) (pre P&A). No welhouse, flow line, S-riser. Drilling scaffold installed. Balance line reading 800 psi, control line reading 0+ psi. Opened Control line to bleed to bucket, small amount of hyd fluid and what looks like cement. Pumped into Control line with hyd fluid, line pressured up to 2000 psi after pumping 1.25 gal. Control line pressure slowly bleeding off, bled to 0+ psi in 1 hour. Attempt to purge Balance line, pumped 1 gal of fluid and line pressured upto 2500 psi, stopped pumping. Balance line bled back to 2400 psi in 1 hr. Bled balance line to 0 psi, returned gased up hyd oil. SV, SSV, WV = C. MV = O. IA & OA = OTG 17:40. 3/31/2023 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(tubing punch) PRESSURE TEST 300L/3000H. PUNCH TUBING FROM 7787'-7792' USING 2", 0 DEG PHASED, 4 SPF HSC LOADED W/ 7 GR CHARGES. CCL TO TOP SHOT OFFSET: 4.5'. CCL STOP DEPTH: 7782.5'. PRE PUNCH T/IA/OA: 1000/360/0, POST PUNCH T/IA/OA: 830/655/0. CORRELATED TO TUBING TALLY RECORD DATED 10-AUG-1997 ***JOB COMPLETE, WELL SECURE AND TURNED OVER TO DSO*** 3/31/2023 ** Assist E-Line** T/I/O= 468/286/0 Pumped 1 bbl diesel down Tbg. to pressure up Tbg to 1000 psi. SL on well at time of departure. FWHP's=397/234/0 4/20/2023 T/I/O = SSV/300/0. Temp = SI. Hold open bleed on C&B (pre cement). C/B = 6/720 psi. Wellhouse, flowline, and scaffold removed. Rig scaffold installed. Bled CP to 0 psi in <1 min (gas). Bled BP to 0 psi in <1 min (gas followed by fluid ~ 1/8 teaspoon). Held open bleed for 4 hrs. Monitored for 1 hr. CP/BP unchanged. Final WHPs = SSV/300/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 00:30 Daily Report of Well Operations PBU WGI-01 Pumped into Control line with hyd fluid, liney pressured up to 2000 psi after pumping 1.25 gal. PUNCH TUBING FROM 7787'-7792' USING y pumped 1 gal ofgg fluid and line pressured upto 2500 psi, stopped pumping Daily Report of Well Operations PBU WGI-01 4/21/2023 T/I/O = 470/1410/Vac. Temp = SI. Cement C&B lines (P&A). C/B = 0/400 psi. Wellhouse, flowline, & scaffolding removed. Rig scaffolding installed. Apply heat to tbg head/tree. Pressure up balance line to 3600 psi with gas from WGI-09. Broke back and fell to 600 psi. Pressure up control line w/ 3600 psi gas. Monitor while LRS heated annulus. No hange. Control line is plugged. Balance line dropped to zero while LRS heated annulus. Disassemble control jewelry. Completely plugged w/ cement. Mix up cement and pump 0.25 gallons of 15.8 PPG FINECEM down Balance line. pressured up to 3800 psi. Pressure up on control line to 5500 psi w/ hydraulic oil - plugged. w/ cement. LRS in control of the well upon departure. 16:00 4/21/2023 T/I/O= 470/310/0 (PLUG AND ABANDONMENT) Circ-out IA with 200* fresh water to thaw balance and control lines. Circulated 33 bbls of diesel from IA into open-top tanks using a 3 bbl spear of 60/40, 33 bbls of fresh water, followed by 1 bbl tail of 60/40 to flush to surface lines. Pumped 156 bbls of 200* fresh water down IA for two hours, taking returns through the TBG, to thaw the B & C lines. Achieved return temp 0f 180F. Pumped an additional 443 bbls of 110* fresh water to continue circing-out the well. Pumped 138 bbls of diesel down the TBG and U-tubed TxIA to freeze protect. FP to 2200'. Monitored TxIA for 1 hour. Freeze protected surface lines to each open-top tank with a total of 8 bbls of diesel. Bled TxIA down to 0 psi. Bled back ~0.3 bbls of diesel. Valve positions - SV/WV/SSV: Closed, MV/IA/OA: Open FWHPs= 0/0/0 4/26/2023 T/I/O = Vac/Vac/0. Temp = SI. PT Balance line to 2500 psi, drift Control line / OP to pump cement Target pressure. No wellhouse, flowline, drilling scaffold installed around well head. Attempt to PT Balance line, cement is not cured at this time. Remove globe valve from control line (uncured cement once valve was removed, clean out) & replace with full port hoke valve. Inserted bailing wire 11" into stainless tubing. Increased Control line pressure using MEOH to 4500 psi & bled to 0 psi multiple times to attempt to get injectivity into control line with no success throughout day & night shift. SV, WV, SSV = C. MV = O. IA, OA = OTG. 18:00 4/27/2023 T/I/O/=0/0/0 (PLUG AND ABANDONMENT) Pumped 2 bbls 60/40 down IA, Pumped 4 bbls diesel Down IA to reach 2000 Psi. Bleed back 6 bbls to starting pressure.v FWHP=0/0/0 RD 4/27/2023 T/I/O = Vac/Vac/0. Temp = SI. PT Balance line to 2500 psi, Pressure up Control line (pre P&A). No wellhouse, flowline, drilling scaffolding installed around wellhead. PT'd Balance line to 2500 psi w/ hydraulic fluid (PASS). Increased IAP to 2000 psi with LRS, while holding open bleed on Control line with no returns for 1 hr the Control line. SI Control line bleed & held pressure on the IA with no pressure build up on the control line. SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:00 5/9/2023 **ASSIST CEMENT CREW** (1st stage cmt) Pumped 5 bbl 60/40 for meth spear. HES pumped 451 bbls 14.0 Class G cement. Pumped 59 bbls 9.8 brine down tbg taking returns up the IA to tanks & 10 bbls 60/40 for freeze protect to space cement down to 1500' in tbg (Cement ready to tag and test in 3 days) Applied 893# on tbg to keep cement in place Pumped 5 bbls 60/40 to flush surface lines to tanks ****Job complete**** HES pumped 451 bbls 14.0 Class G cement. Daily Report of Well Operations PBU WGI-01 5/19/2023 T/I/O= 86/0/0. Temp=SI. LRS 72 Assist Slickline (PLUG AND ABANDONMENT). AOGCC (Guy Cook) MIT-T to 2500 psi PASSED at 2600 psi (2750 psi max applied) TBG lost 111 psi during the first 15 minutes and 37 psi during the second 15 minutes. TBG lost 148 psi during the 30 minute test. Pumped 0.8 bbls of 84*F diesel to achieve test pressure. Bled back 0.7 bbls to final T/I/O= 85/0/0. 5/19/2023 ***WELL S/I ON ARRIVAL***(aogcc tag toc) PRE-TAG TOP OF CEMENT W/ 2.65" CENT, 1-3/4" SAMPLE BAILER @ 1,557' SLM LRS CONDUCTS PASSING PRE-MIT-T TO 2500 PSI (see lrs log) TAG TOP OF CEMENT W/ 2.65" CENT, 1-3/4" SAMPLE BAILER @ 1,561' SLM / 1,514' MD (good sample, correction off kb-flange, AOGCC Witnessed by Guy Cook) LRS CONDUCTS PASSING MIT-T TO 2500 PSI (see lrs log) TAG TOP OF CEMENT W/ 2.65" CENT, 1-3/4" SAMPLE BAILER @ 1,561' SLM / 1,514' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED*** 6/5/2023 ***START WSR*** RIG UP E-LINE PERFORATE 5' GUN AT 495' - 500' PRESSURED UP TO 1000PSI AND AFTER FIRING GUN PRESSURE DROPPED TO 800PSI AFTER 5 MINUTES PRESSURE DROPPED TO 600 PSI PUMPED BACK UP TO 1000 PSI AND WAIT FOR 10 MINUTES, 900 psi ND LUBRICATOR, SECURED SWAB CAP, TESTED WITH WELL PRESSURE. PRESSURE DOWN TO 125 PSI WELL SECURED FINISH RIG DOWN CLOSE PERMIT WITH DSO ***END WSR*** 6/7/2023 T/I/O = 17/0/0. Bled pressure to 0 psi. Removed Upper Tree. Installed Dryhole tree. PT low (350 psi) Passed. PT High (5000 psi) Pased) FWP = 0/0/0 6/13/2023 T/I/O= 17/0/0. LRS 72, Injectivity Test (PLUG AND ABANDONMENT). Pumped 35 bbls of diesel into the TBG with OA returns to OTT. TBG pressured up to 1850 with 0.4 bbls of diesel. Slowly increased the rate as the TBG pressure decreased. Started getting OA returns after pumping 4 bbls. Pumped the last 10 bbls at 1.7 bpm and 1980 psi with 1 for 1 returns. Final T/I/O= 2/0/0. 6/21/2023 T//O=0/0/0 Arctic pack flush (PLUG AND ABONDMENT) Pump down TBG w/ 65 bbls 130* DSL taking returns up IA to OTT. Flush w/ additional 45 bbls @ 3 BPM (100 BBLS Total) DSL. Flush w/ 77bbls 9.8# Brine FWHP=0/0/0 Casing valves OTG. Turn well over to DSO 6/22/2023 T/I/O=0/0/0 Assist Cement Crew (PLUG AND ABONDMENT) spear into TBG w/ 10 bbls 100* DSL. Cement crew pumped 80 bbls Surfactant, 10 bbls of Fresh Water, and 65 bbls of 15.8 ppg class G cement down TBG, taking returns up OA to open- top tanks. HES flushed equipment with Fresh Water. LRS Flushed surface lines/choke with 3.2 bbls of Diesel. HES In control of well upon departure. FWHPs= 0/0/0 ) nt, 10 bbls of Fresh Water, and 65 bbls of 15.8 ppg class G cement down TBG, (g g ) PRE-TAG TOP OF CEMENT W/ 2.65" CENT, 1-3/4" SAMPLE BAILER @ 1,557' SLM LRS CONDUCTS PASSING PRE-MIT-T TO 2500 PSI (see lrs log)(g) TAG TOP OF CEMENT W/ 2.65" CENT, 1-3/4" SAMPLE BAILER @ 1,561' SLM /@ 1,514' MD (good sample, correction off kb-flange, AOGCC Witnessed by Guy Cook) PERFORATE 5' GUN AT 495' - 500' Daily Report of Well Operations PBU WGI-01 6/23/2023 T/I/O = 0/0+/20. Temp = SI. WHPs (post cement P&A). No AL. Wellhouse removed, FL disconnected, Dry hole tree (no flowcross, SSV or WV). Hardline RU to T & OA. SV, MV = C. IA, OA = OTG. 02:00 12/10/2023 *** P&A In Progress *** Conduct ACWR PJSM with FS-1 DS lead and safety rep. Pad Elevation = 18.3'. Tundra Elevation = 9.3'. Excavate to 9' below pad grade behind and on either side of the wellhead, see water entering excavation. Will need to hydro- excavation to expose blowdown line in front of wellhead. Cover excation with rig mats. LDFN. 12/11/2023 *** P&A In Progress *** Hydro-excavate the blowdown line. Cover excavation with rig mats. RDMO and allow water in excavation to freeze. 12/25/2023 **P&A In progress**. Rmoved rig mats to expose excavation. The excavator encountered fluid as soon as the ice was broke. Cover excatation backover with rig mats and place barriers to allow the ground/water to freeze more. Job In progress. 2/5/2024 *** P&A In Progress *** Pad Elevation = 18.3'. Tundra Elevation = 7.3'. Remove rig mats and expose excavation. Excavate to 13' below pad grade behind and to either side of the wellhead. See tundra line 11' below pad elevation. Will need a smaller bucket to excavate between the front of the wellhead and the blowdown line. Barricade and cover excavation. LDFN. 2/6/2024 *** P&A In Progress *** Pad Elevation = 18.3'. Tundra Elevation = 7.3'. Remove rig mats and expose excavation. Excavate to 17' below pad grade behind and to either side of the wellhead. Excavate to 14' below pad grade between the front of the wellhead and the blowdown line. Barricade and cover excavation. LDFN. 2/7/2024 ***P&A In Progress*** Pad Elevation=18.3'. Tundra Elevation=7.3'. .Removed rig mats and exposed excavation. There is a definate tuntra line in the excavation, photoes taken to document tundra line depth. Continue to excavate between the blodown line and wellhead. very slow going because of minimal clearance. Barricade and cover excavation. Return tomorrow. Job In progress. 2/8/2024 ***P&A In Progress*** Pad ELevation=18.3'. Tunra Elevation=7.3'. Remove rig mats and continue to excavate between the blowdown line and wellhead down to 17' below pad grade. Job in progress. 2/10/2024 ***P&A InProgress*** Pad Elevation=18.3'. Tundra Elevation=7.3'. Remove mats and expose excatation. Assemble shoring box and install inside of excavation. Place mats around shoring box to cover any possible gaps and place barricades Prep for confined space entry tomorrow morning and having to remove cement from oround the conductor. Job In Progress. 2/11/2024 ***P&A InProgress*** Pad Elevation=18.3'. Tundra Elevation=7.3'. Remove mats and expose excatation. Used jack hammers to clear cement from around conductor. Marked pad grade, tundra and cut depths on conductor. Strapped saw to conductor and prep to cut tomorrow morning. Place barricades around shoring box/excation. Job In progress. 2/12/2024 ***P&A InProgress*** Pad Elevation=18.3'. Tundra Elevation=7.3'. Remove mats and expose excatation. Made 2 attempts at cutting wellhead off at 4'6" below tundra. During the cuttting proccess heard pipe movement and broke two different blades. Crew will return in the AM. Job in progress. Daily Report of Well Operations PBU WGI-01 2/13/2024 ***P&A InProgress*** Pad Elevation=18.3'. Tundra Elevation=7.3'. Remove mats and expose excatation. Cut wellhead off 3' 6" below tundra (14' 6" below pad grade). TBG dropped ~6" during the cut. IA cement top ~ 80' below cut. Conductor had flaky/dry powder cement. Cleaned/ removed flaky cement down to hard/dry granular cement. Void in Conductor 14". Pictures taken to document. Due too the lack of availability of the excavator and operators in the next week, I will take the equipment over to DS13 to get that excavation completed. Will have AOGCC inspect both wells at the same time. Job in progress. 3/3/2024 ***P&A In Progress*** AOGCC Inspector Brian Bixby verified cut-off casings cut depth and cement top voids in the tubing x production casing annulus and conductor. Performed tubing x PC annulus cement top job with 56 gallons of 15.8 ppg AS-1 cement. Performed conductor cement top job with 11 gallons of 15.8 ppg AS-1 cement. LDFN. 3/4/2024 ** P&A Complete *** AOGCC Inspector (Brian Bixby) verified cement top job, verbiage on marker plate and welding of marker plate. Photo document marker plate installation. Pull shoring box and backfill excavation 2024-0304_Surface_Abandon_PBU_WGI-01_bb Page 1 of 5 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: March 6, 2024 P. I. Supervisor FROM: Brian Bixby SUBJECT: Surface Abandonment Petroleum Inspector PBU WGI-01 Hilcorp North Slope LLC PTD 1790310; Sundry 323-036 03/03/24: I arrived at location and met with Rob Bryan (Hilcorp Wellsite Leader) to look at the post cut and the voids prior to them doing a top job. There is a 14-inch void in the conductor, 80-foot void in the tubing-casing annulus. I was told the tubing dropped 6 inches during the cut. I gave him approval to proceed with filling all void to the surface with cement. 03/04/24: I returned to PBU WGI-01 and met with Cody Applehans (Hilcorp Wellsite Leader) to verify hard cement in all strings which there is. I looked over the marker plate and verified it has all the correct information (with mis-spelled “NORTH”). I also verified the cut off is 3 feet below tundra level. I approved for them to weld the marker plate on the well and back fill the location. Attachments: 7 Pictures 2024-0304_Surface_Abandon_PBU_WGI-01_bb Page 2 of 5 Surface Abandonment – PBU WGI-01 (PTD 1790310) Photos by AOGCC Inspector B. Bixby March 3-4, 2024 3/3/2024 post cut annular cement levels 2024-0304_Surface_Abandon_PBU_WGI-01_bb Page 3 of 5 3/3/2024 - Post cut conductor cement level 2024-0304_Surface_Abandon_PBU_WGI-01_bb Page 4 of 5 3/4/2024 cement to surface 2024-0304_Surface_Abandon_PBU_WGI-01_bb Page 5 of 5 3/4/2024 marker plate installation From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:20230428 1510 APPROVAL Higher Cement 2nd plug WGI-01 (PTD# 179031) Sundry # 323-036 abandonment Rev1 Date:Friday, April 28, 2023 3:11:38 PM Attachments:image001.png From: Rixse, Melvin G (OGC) Sent: Friday, April 28, 2023 3:10 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: [EXTERNAL] RE: WGI-01 (PTD# 179031) Sundry # 323-036 abandonment Rev1 Oliver, Hilcorp is approved to bring second cement plug top to 1500’ MD. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, April 27, 2023 2:18 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: Re: [EXTERNAL] RE: WGI-01 (PTD# 179031) Sundry # 323-036 abandonment Rev1 Mel, We were able to cement and PT the balance line, but were unable to cement the control line on WGI-01. We ended up getting no real volume away, but some cement in the jewelry and control line right at surface. We have been unable to get injection down the control line or gain communication when pressuring up on the Tubing/ IA. We would like to revise the sundry to bring the tubing cement top up to 1500’ MD ( from the previously approved tubing cement top at 2531’ MD) and bury the SSSV nipple at 2182’ MD, and then proceed with the originally planned surface cement job from 500’ MD to surface. This will eliminate the risk of the control line being connected with any appreciable volume of fluid when the wellhead is cut off. Attached is the Rev 1 Sundry Let me know if you have any questions. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Sunday, March 26, 2023 11:55 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: WGI-01 (PTD# 179031) Sundry # 323-036 abandonment Oliver, Change approved. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Saturday, March 25, 2023 5:34 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: WGI-01 (PTD# 179031) Sundry # 323-036 abandonment Mel, The approved sundry had DHD cementing the control and balance lines prior to eline punching the tubing for the lower plug. DHD attempted to cement the lines, but had some pump issues and didn’t get any volume away. They went back a couple days later to try again and had trouble injecting into the C&B lines and suspect that due to the wellhead being at ambient temps the water in the microfine cement flash froze near surface. Due to this I would like to change the order of a couple of the steps and push cementing the C&B lines out after the tubing punch, such that we can circ warm fluid around, resolve the line blockage and then cement the C&B while it is warm. Let me know if you approve. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you arenot an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If youhave received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:11 Township:11N Range:14E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:9335 ft MD Lease No.:ADL0028302 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 111 Feet Csg Cut@ Feet Surface:13 3/8"O.D. Shoe@ 2731 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:9 5/8"O.D. Shoe@ 8314 Feet Csg Cut@ Feet Liner:7"O.D. Shoe@ 9334 Feet Csg Cut@ Feet Tubing:7 5/8" x 7"O.D. Tail@ 7923 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Open Hole Bottom 9334 ft 1561 ft 15.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2748 2637 2600 IA 0 0 0 OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Halliburton Slickline was used for the cement tag. They used a 2-1/8 inch toolstring with a 2 inch drive down bailer. The bailer had a mule shoe bottom with a ball type valve. The first tag was at 1558 ft MD wireline and drove it down to 1561 ft MD. The sample was of good cement. The 2nd cement tag after the MIT-T was at 1561 ft MD wireline. A Little Red Services pump truck and calibrated gauges were used for the MIT-T. 0.8 bbls were pumped during the MIT-T and 0.7 bbls were returned after the testing was completed. May 19, 2023 Guy Cook Well Bore Plug & Abandonment PBU WGI-01 Hilcorp North Slope LLC PTD 1790310; Sundry 323-036 none Test Data: P Casing Removal: Steve Soroka Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2023-0519_Plug_Verification_PBU_WGI-01_gc 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 179-031 50-029-20369-00-00 ADL 0028302 9335 Conductor Surface Intermediate Production Liner 8639 79 2704 8285 1313 8100 20" 13-3/8" 9-5/8" 7" 7632 32 - 111 31 - 2731 29 - 8314 8019 - 9334 2500 32 - 111 31 - 2731 29 - 7818 7562 - 8641 none 520 2670 4760 7020 8100 1530 4930 6870 8160 none 7-5/8" 29.7# x 7" 29# L-80 27 - 7923none Structural 7" BKR SAB No SSSV 7795 / 7368 Date: Bo York Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 PRUDHOE BAY 3/1/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov PBU WGI-01 By Samantha Carlisle at 2:02 pm, Jan 23, 2023 323-036 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.01.23 09:48:16 -09'00' DSR-1/23/23 DLB 01/24/2023 X * AOGCC to witness slick line tag (TOC ~2,531' MD) and pressure test (to 2500 psi) of reservoir abandonment plug. * AOGCC to confirm cement quality in all annuli before welding marker plate. * Photo document TOC in all annuli before welding plate and then with welded plate in place. 10-407 MGR10FEB23GCW 02/13/23 JLC 2/13/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.13 14:14:39 -09'00' RBDMS JSB 021423 P&A Well: WGI-01 PTD: 1790310 API: 50-029-20369-00 Well Name: WGI-01 Permit to Drill: 179031 Current Status: Suspended API Number: 50-029-20369-00 Estimated Start Date: 3/1/2023 Estimated Duration: 14 days Regulatory Contact: Carrie Janowski First Call Engineer: Oliver Sternicki 907-350-0759 Second Call Engineer: David Bjork 907-440-0331 Current Bottom Hole Pressure: Perfs cemented, hydrostatic at cement top (7910’ MD, 7467’ TVD)= 3002 psi Max. Anticipated Surface Pressure: 2500 psi Max treating pressure Last SI WHP: 370 psi Min ID: 4.845” 7” shearout sub @ 7920’ MD Max Angle: 33 deg @ 3675’ MD Well History: WGI-01 was drilled and completed in August 1979, with a workover in August 1997 replacing 7” tubing with 7- 5/8” plastic coated tubing to increase injection capacity. Significant integrity issues surfaced, including a leak in the 9-5/8” casing at 6430’, slow IAxOA communication, and IA repressurization due to control and balance line issues. As a result the decision was made to reservoir abandon and suspend the well in 2006. Reservoir abandonment work was completed on 8/28/2006 where 46 barrels of cement was pumped into the 7” production liner with coil tubing from 9182’ to an estimated TOC at 8100’. A slickline drift tagged TOC at 7984’ MD on 9/2/2006. A MIT-T to 3500 psi passed on 9/6/2006 verifying the cement plug to be holding. Objectives: Perform a full P&A on the well placing cement to surface in the 7-5/8” x 9-5/8” annulus with cement from 2531’-7785’ MD in the tubing. Place a cement plug across all annuli from surface to ~500’ MD. Excavate and cut casings 3’ below original tundra level and install marker plate. Procedure: AOGCC Witness: All AOGCC witnessed operations require a minimum of 24-hour notice to AOGCC inspectors of the timing of the operation so they can be available. SL: 1. Drift to tubing tail at 7823’ MD. Pull DSSSV. DHD : 1. Cement control and balance lines. 2. WOC 3 days, PT to 2500 psi target pressure. EL: 1. Punch 7-5/8” tubing from ~7785-7790’ MD. Adjust depth to punch across a tubing collar. A. Use 0° phase, decentralized, oriented to low side, rated for 7-5/8”, 29.7#, L80 tubing. B. Apply 1000 psi to 7-5/8” prior to perforating, record before/after pressures C. Note any pressure changes FB : 1. Confirm circulation through tubing punch holes. P&A Well: WGI-01 PTD: 1790310 API: 50-029-20369-00 FB Cement: 1. Pump the following down the tubing, up the IA. Max pressure while pumping= 2500 psi. A. 5 bbls MeOH B. 75 bbls hot (160degF) fresh water + surfactant C. 10 bbls fresh water D. 403 bbls (20 bbls over calculated volume) 14-15.8 ppg Class G cement E. 5 bbls fresh water F. Foam ball G. 101 bbls 9.8 ppg brine H. 10 bbls 60/40 for freeze protect. I. Confirm cement at surface in IA. a. Cement plug in IA will be from tubing punches to surface. b. Cement in tubing will be from tubing punches to 2531’ MD FB : 1. Wait on cement 3 days, AOGCC witnessed MIT-T to 2500 psi target pressure. SL : 1. Drift and tag to TOC in 7-5/8” tubing @~2531’ MD- AOGCC witnessed. Pull DSSSV. EL: 1. Perforate 7-5/8” tubing and 9-5/8” casing at 495-500’ MD. A. Perforate 7-5/8” tubing and 9-5/8” casing at 495-500’ MD to establish circulation point for cementing. B. Apply 1000 psi to 7-5/8” prior to perforating, record before/after pressures C. Note any pressure changes FB : 1. Confirm circulation through perforation holes. CT: Contingent step if fullbore is unable to get circulation to the OA due to arctic pack. 1. Circulate well with hot seawater to thaw the 9-5/8” x 13-3/8” annulus. 2. Pump the following to flush the arctic pack out of the 9-5/8”x13-3/8” annulus A. 5 bbls MeOH B. 200 bbls 160 F diesel C. Allow diesel to soak for 12hrs prior to FB circ to break up arctic pack. FB : 1. Circulate the following down the tubing and up the 9-5/8”x 13-3/8” annulus to prep for cement. A. 5 bbls MeOH B. 25 bbls hot diesel (min 120 degF) C. 60 bbls hot (160degF) fresh water + surfactant (2 gal/ mgal F103 and 2 gal/ mgal U067) D. 60 bbls of 9.8 brine (80-100 degF) 2. Circulate the following down the tubing to cement the tubing and 9-5/8”x 13-3/8” annulus from surface to 500' MD A. 5 bbls MeOH B. 10 bbls fresh water P&A Well: WGI-01 PTD: 1790310 API: 50-029-20369-00 C. 67 bbls (15 bbls over calculated volume) 14- 15.8 ppg Class G cement or until uncontaminated cement is seen at surface. D. Max pressure while pumping 1500 psi. E. Top of cement will be at surface in the tubing and 9-5/8”x13-3/8” annulus. Confirm cement at surface in OA. DHD: 1. Assist fullbore with cement job and pump N2 across the wellhead to remove excess cement from valves. 2. Bleed all wellhead pressures to 0 psi. 3. Monitor wellhead pressures 24 hours after pressures were bled to 0 psi. Special Projects: 1. Excavate and cut off all casings and wellhead 3’ below original tundra level. 2. AOGCC witness of cut-off casings before any top job commences. 3. AOGCC witness cement tops in all annuli. Top off with cement as needed. 4. Bead weld marker cap on outermost casing string. Photodocument all steps and AOGCC witness of installed cap. Marker cap to read as follows: Hilcorp North Slope, LLC PTD # 179-031 Well: PBU WGI-01 API # 50-029-20369-00 P&A Well: WGI-01 PTD: 1790310 API: 50-029-20369-00 Figure 1: Current WBS P&A Well: WGI-01 PTD: 1790310 API: 50-029-20369-00 P&A Well: WGI-01 PTD: 1790310 API: 50-029-20369-00 Figure 2: Proposed P&A WBS Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:179-031 6.50-029-20369-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 9334 8100 7632 7795, 7902 None 8100 7368, 7460 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20" 32 - 111 32 - 111 1530 520 Surface 2704 13-3/8" 31 - 2735 31 - 2735 4930 2670 Intermediate 8285 9-5/8" 29 - 8314 29 - 7818 6870 4760 Liner 1315 7" 8019 - 9334 7562 - 8638 8160 7020 Perforation Depth: Measured depth: None feet True vertical depth:None feet Tubing (size, grade, measured and true vertical depth) 27 - 7483 7795 7368Packers and SSSV (type, measured and true vertical depth) 7" Baker SAB Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 0000 00 0 0 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Holt ryan.holt@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:907-659-5102 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8639 Sundry Number or N/A if C.O. Exempt: 7" SB-2 Packer 7902 7460 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Suspended Well Inspect Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028302 PBU WGI-01 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations No SSSV installed 7-5/8" 29.7# L-80 x 7" 29# L-80 7" 29# N-80 27 - 7928 7902 - 7921 7460 - 7477 By Samantha Carlisle at 9:05 am, Aug 05, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.08.04 21:51:27 -08'00' Bo York RBDMS HEW 8/5/2020 9335 MGR10AUG2020 SFD 8/5/2020 SFD 8/5/2020DSR-8/6/2020 ACTIVITY DATE SUMMARY 6/28/2020 T/I/O = 370/270/0. Temp = S/I. SU well inspection (AOGCC witnessed by Bob Noble). No flowline, scaffolding ladder or wellhouse. Pictures taken. TBG pressure taken from wing valve (could not reach swab). SV = ?. WV, SSV = C. MV = O. IA, OA = OTG. 1030. Daily Report of Well Operations PBU WGI-01 Suspended Well Inspection Review Report InspectNo: susRCN200630143647 Date Inspected: 6/28/2020 Inspector: Bob Noble Type of Inspection: Well Name: PRUDHOE BAY UNIT WGI-01 Permit Number: 1790310 Suspension Approval: Sundry 9 306-246 - Suspension Date: 8/28/2006 Location Verified? O If Verified, How? Other (specify in comments) - Offshore? ❑ Subsequent , Date AOGCC Notified: 6/28/2020 Operator: BP Exploration (Alaska) Inc. Operator Rep: Ryan Holt Wellbore Diagram Avail? O Photos Taken? Well Pressures (psi): Tubing: 370 Fluid in Cellar? ❑ IA: 270 BPV Installed? ❑ OA: 1 VR Plug(s) Installed? ❑ Wellhead Condition No flow line. Wellhead in good condition, protected with a guard rail. Condition of Cellar good clean gravel Surrounding Surface Condition Good clean gravel Comments Location verfied with a pad map. Supervisor Comments Photo (1) attached, 7("!(Z0w Tuesday, July 21, 2020 Suspended Well Inspection — PBU WGI-01 PTD 1790310 AOGCC Inspect # susRCN200630143647 Photos by AOGCC Inspector B. Noble 6/28/2020 2020-0628_Suspend_PBU_WGI-01 bn.docx Page 1 of I STATE OF ALASKA OALASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other:Sus Well Inspection Rpt I3 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 179-031 3. Address: P.O.Box 196612 Anchorage, Development El Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ® 6. API Number: 50-029-20369-00-00 7. Property Designation(Lease Number): ADL 0028302 8. Well Name and Number: PBU WGI-01 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 9335 feet Plugs measured 8100 feet NOVt true vertical 8639 feet Junk measured feet N 14 2016 Effective Depth: measured 8100 feet Packer measured 7802 feet true vertical 7632 feet Packer true vertical 7373.62 feet G CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"94#H-40 32-111 32-111 1530 520 Surface 2703 13-3/8"72#N-80 31-2735 31 -2735 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1313 7"29#N-80 8024-9338 7566-8641 8160 7020 Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet SCANNED MAR 3 12017 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical 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-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service RI Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP RI SPLUG 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature J"" ,— Phone +1 907 564 4424 Date 11/14/16 Form 10-404 Revised 5/2015 p T L -7--/Re ` i S O q --4/77RB®� l/1" NOVf 6 2016 Submit Original Only • • N c � O >- E • Q E a) i Q _ oma 5 C9 O r o a 0. 0 I ccs a) CI (/) -0 a) a) 0- � -0 d a) U) 5 Q L_ cn 0 U) Z W H Q 0 >_ O O — m i= O • Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Drill Site WGI No 01 Field/Pool: Prudhoe Bay/Prudhoe Bay Pool Permit#(PTD): 1790310 API Number: 50029203690000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 8/28/2006 Surface Location: Section 11 Twsp: 11N Range: 14E Nearest active pad or road: WGI-Pad Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good, Clean Active Pad Pad or location surface: Clean Level Gravel Location cleanup needed: Mitigate Rat Hole, and Material covering Rat Hole Pits condition: Frozen Water, No Hydrocarbons or discoloration Surrounding area condition: Good, Clean Water/fluids on pad: None-Dry Pad Discoloration, Sheens on pad, pits or water: none Samples taken: None Access road condition. Good Gravel Road Photographs taken(#and description): 1 Photo of Rat Hole Condition of Wellhead AOGCC requires: 1)a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good Condition some corrosion, Leaking grease fitting on IA valve leaking onto OA valve. No Flowline with outlet blinded, Production Tree Cellar description, condition, fluids: No Cellar, slight contamination from leaking grease fitting. Rat Hole: Rat Hole present with metal plate cover and marker-needs to be filled Wellhouse or protective barriers: Pipe Barrier around well, no well house Well identification sign: Yes Tubing Pressure (or casing if no tubing): SSV Closed no hydraulics Annulus pressures IA=400psi. OA=Opsi Wellhead Photos taken (#and description): 2-Photos of wellhead and tree, 1-. oto leakin. erease fittin. Work Required: Repair leakin• IA valve crease fitting Operator Rep(name and signature) Joshua Stephens AOGCC Inspector: Jeff Jones Other Observers: Inspection Date: 10/10/2016 AOGCC Notice Date: 0/9/2016 Time of arrival: 10 30am Time of Departure: 10:41am Site access method' Pickup Truck • • 0.1 0 0 0 0.1 Miles bp ✓WGt-G' Legend Pipelines(General) Buried Pipelines(Detailed) —Oil 'LI-!CAPS' -Gas —MI —WAG —Water —Relief --1 tility nknown sdceted Pipelines V G1-o8 wG+-o7 Author: 14 November,2016 BP1\catrgl ©BP Exploration(Alaska)Inc.weights reserved.This map is informational in nature and is presented without representations or Product of BPXA Atlas Enterprise GIS. alaska- is.b web.b .com ties as to accuracy completeness,or use for any purpose P 9 P P TREE= GRAY WELLHEAD= GRAY • AlITY NOTES: ,ACTUATOR= AXELSON WG 1-01 KB.ELEV= 49' BF.ELEV= WELL NO LONGER IN USE; WGI-09 NOW USING FLOWLINES (12/2006) KOP= 3500' Max Angle= 39 @ 9200' 11 Datum MD= ? Datum TVD= 8800'SS 2' 7"X 7-5/8"XO 7"TBG,29.0#, L-80,0.0371 bpf, ID=6.184" H 2' 2182' —7-5/8"X 7"XO 7-5/8"TBG-IPC,29.7#, L-80, .0459 bpf, ID=6.875" I 2182' TOP OF 7"TBG 2182' 2183' —7"CAM BAL-O SSSV NIP,ID=5.937" 7"TBG,29#,L-80,.0371 bpf, ID=6.184" H 2187' TOP OF 7-5/8"TBG —1 2187' 2187' 7"X 7-518"XO 13-3/8"CSG,72#, N-80,ID=12.347" H 2731' , Minimum ID =4.845" @ 7920' BAKER SHEAROUT SUB \ 7795' - 9-5/8"X 7"BKR SAB PKR 7-5/8"TBG-IPC,29.7#, L-80, .0459 bpf, ID=6.875" H 7801' 7801' -17-5/8"X 7"XO TOP OF 7"TBG —I 7801' —' I 7814' —17"HES RN NIP, ID=5.5" 7"TBG,29#,L-80, .0371 bpf, ID=6.184" — 7823' / \ 7823' --17"TUBING TAIL WLEG TOP OF 7"TBG H 7902' 7902' H 9-5/8"X 7"BKR SB-2 PKR 7920' —17"BKR SHEAROUT SUB 7"TBG,29#,N-80, .0371 bpf,ID=6.184" —I 7921' (NO TAILPIPE)ID=4.845" TOP OF 7"LNR 8019'elm 7910' —I ELMD TT LOGGED 08/07/79 , tgln 9-5/8"CSG,47#, N-80,ID=8.681" — 8314' , , '1.1.1.18100' ESTIMATED TOC 44.1 111111111 PERFORATION SUMMARY 401 1.0 REF LOG:BHCS ON 07/29/79 1111111 ANGLE AT TOP PERF:38 @ 8695' ►1111111 1111 Note:Refer to Production DB for historical perf data 11111111 SIZE I SPF INTERVAL Opn/Sqz I DATE 1i1111� 11111111 See Perforation Data on Page 2 (1111111 100 11111111 ►1111111 1111/1111 111i11 1111111 ►1111111. 111111111 111111111 PBTD — 9292' I 0.11. W.V. 111111111 7"LNR,29#,N-80,.0371 bpf,ID=6.184" H 9334' ' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/07/79 ORIGINAL COMPLETION 12/31/05 TWS/TLH TTP PLUG PULLED(12/19/05) WELL: WGI-01 08/11/97 LAST WORKOVER 08/28/06 SRB/PAG P&A;SQZ PERFS PERMIT No: 1790310 11/03/01 RN/TP CORRECTIONS API No: 50-029-20369-00 03/22/03 JM/KAK PULL IBP SEC 11,T11N, R14E, 1795.18'&FEL 2926.14'FNL 12/11/05 ???/TLH SET TTP 12/13/05 RPH/TLH WAIVER SFTY NOTE DELETED ® BP Exploration(Alaska) i • WGI-01 ) , PERFORATION SUMMARY , , REF LOG:BHCS ON 07/29/79 ANGLE AT TOP PERF:38 @ 8695' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE Z 3-3/8" 4 8695-8725 S 08/28/06 3-3/8" 4 8725-8745 S 08/28/06 3-3/8" 4 8745-8785 S 08/28/06 3-3/8" 4 8785-8797 S 08/28/06 3-3/8" 4 8813-8853 S 08/28/06 3-3/8" 4 8853-8907 S 08/28/06 3-3/8" 4 8907-8917 S 08/28/06 3-3/8" 4 8934-8954 S 08/28/06 x 3-3/8" 4 8954-8983 S 08/28/06 3-3/8" 4 8983-9003 S 08/28/06 3-3/8" 4 9008-9018 S 08/28/06 3-3/8" 4 9024-9034 S 08/28/06 3-3/8" 4 9040-9048 S 08/28/06 3-3/8" 4 9048-9058 S 08/28/06 3-3/8" 4 9074-9082 S 08/28/06 I k 3-3/8" 4 9082-9102 S 08/28/06 4•' •4 8100' --I ESTIMATED TOC 3-3/8" 4 9102-9122 S 08/28/06 1111111 3-3/8" 4 9122-9142 S 08/28/06 111111111 3-3/8" 4 9143-9151 S 08/28/06 111111/ 3-3/8" 4 9156-9162 S 08/28/06 .0 3-3/8" 11111111 3-3/8" 4 9162-9182 S 08/28/06 1111 3-3/8" 4 9208-9228 S 08/28/06 ►111111 .111111 #111111 11111111 411/111 4111111 ►1111111 ►111., ►111/114' *111111 ►1111111 .11111.1 ►11111111 awed WO 1.1.1.1.4 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/07/79 ORIGINAL COMPLETION 12/31/05 TWS/TLH TTP PLUG PULLED(12/19/05) 1 WELL: WGI-01 08/11/97 LAST WORKOVER 08/28/06 SRB/PAG P&A;SQZ PERFS PERMIT No:'1790310 11/03/01 RN/TP CORRECTIONS , API No: 50-029-20369-00 03/22/03 JM KAK PULL IBP SEC 11,T11N,R14E, 1795.18'&FEL 2926.14'FNL 12/11/05 ???/TLH SET TTP 12/13/05 RPH/TLH WAIVER SFTY NOTE DELETED BP Exploration (Alaska) • • Q o 0 0 0 0 0 0 0 N CO CO N O) N N - CO O N- O N- O O G N LC) N- U y 0 0 0 0 0 0 0 0 i CO CO IC) ti O C)) CO CO CO N- V CO CO CO CO 00 CO L0 N N N- CO CO N V N- C) CO ti CO 00 CO M M V N N N- CO N- N- H N (0 N CO N '- CA '- O N- r-- CO CO CO N CO IC) N CO NY N N- N- r-- CD QD 10N N- CO (A ()) 00 M CO M CA N N I� CO CO CO CO O N N CO O) a 4co .0 — O QN � O) C)) '^ •— C) - N N- O) O co`J co co N O N N- 6) C N CO N- a LO O \ � M6coc. 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' !« ... ♦{8.�; b f '-.>" �� � x �{ fit"'��r. f �,a«,..'•„,,,%.,. .r � �,1 h. '�` 'hi�'tl ,t., ". A` `e.,,',.',', �P4+ , ..x. 14 a rA j , _ ,.: it - «. � --07 a ti3 `fir, wy l, % x . 4! �.. t 0 -, ', a 4111.111111" II' ' kir .iv tO * i. — 70, < S o- WELL: WGI-01 OtNE 2* 7s OPER _'t "'� .' . . . ' �' �•+�qi SUR.LOCATION NE t 4,SEC.it TY1N.RWE .'' ,..+ w"+.,.. DRILUNO PERMIT 179-031 j 6 r • . • . * v • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 10/10/16 Inspector: Jeff Jones Operator: BPXA Well Name: PBU WGI-01 Oper.Rep: J.Stephens PTD No.: 1790310 Oper.Phone: 659-5766 Location Verified? Yes Oper.Email: ioshua.stephensl7a bo.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 08/28/06 Date AOGCC Notified: 10/09/16 Sundry No.: 306-246 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing N/A - Photos Taken? Yes IA 400 OA 0 Condition of Wellhead: Good condition,some corrosion, slight hydraulic fluid leak @ IA companion valve grease port.Outlet is blinded,no flowline. Condition of Surrounding Surface Frozen level gravel pad with road access.No hydrocarbon residue visible.No well house,wellhead encloseded with pipe barrier,well - Location: sign attached to wellhead.There is a rat hole near the gravel cellar with a plywood and metal covering. Follow Up Actions Needed: Remove/mitigate rat hole. Comments: Well identified by permanent well identification sign on well.Mr.Stephens took pictures at my direction and they are attached to his report. SCANNED JUN 0 820r/ Attachments: none REVIEWED BY: Insp.Supry ,i/2. UVl0l� iv Comm PLB 12/2015 2016-1010_Suspend_PBU_WGI-013.xlsx OF Th cw���\1%%i s THE STATE Alaska Oil and Gas A of Conservation Commission LASKA 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 p Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Daniel CANOR NOV 'd 7 2015. Alaska Wells Integrity& Compliance Team Leader BP Exploration(Alaska), Inc. 03 1 P.O. Box 196612 ) 7 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool,PBU WGI-01 Sundry Number: 315-587 Dear Mr. Daniel: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Approval is granted contingent on development of a P&A plan for suspended wells with no future utility which brings these wells closer to abandonment prior to pad decommissioning. This plan must be developed and approved through the Commission by 12-31-2016. Failure to comply with this requirement will invalidate this sundry. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this 0- of October,2015 Encl. 3V RBDMSNOV 0 2 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROVALS ` 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations o Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 121 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 .,.� Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 5 vSrth 56° ?1'. 1�1-- ri-11GGr/dt-l 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 179-031 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service ®. 6' API Number: 50-029-20369-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? RECEIVED Will planned perforations require a spacing exception? Yes ❑ No 0 PBU WGI-01• c7I f 9. Property Designation(Lease Number): 10. Field/Pools: SEP 2 1 2015 ADL 0028302 • PRUDHOE BAY,PRUDHOE OIL• 015 So 1-24ris 11. PRESENT WELL CONDITION SUMMARY A®GCC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk((measured): 9335 . 8639 • 8100 7632 8100 Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20"94#H-40 32-111 32-111 1530 520 Surface 2703 13-3/8"72#N-80 31 -2735 31-2735 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1313 7"29#N-80 8024-9338 7566-8641 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal H 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development 0 Service II. 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended EL • 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is t, e an. o ect to the best of my knowledge. Contact Daniel,Ryan Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan / / / Title Alaska Wells Integrity&Compliance Team Leader Signature r/,� Phone +1 907 564 5430 Date p 4771 2e1, '` COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 315 51 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: App ro i.—a-1 15 cJ r a k feel cl e o fit'.-- `/rh r .0.--, clr re l oho /-vi r 1-1in F I'4,A-` p 14 t-) For1-v5p-rvlclyd r..rc{IS L.,., 1.1-1.-1 - f'r.,7't1`C ufl‘l'f, wh;cii br,',.,95 f"-i, c w�1S d I e,5 C v i---, 4.64%-x d o vi hi cvi") r),--,,,,- 'fo p q ci dr C o ,-...-L r-rt"S S 1`ci I.2 C 4 r`e to e-ej vt. l app e•0/ 1`hro % 12-131/IF J 3 /F`c� fa GJ ( � o v �j � the �o� ,Mr :SS�an b� CZ Spacing Exception Required? Yes 0 No Ili' Subsequent F6rm Required:'loft-14 Fa i t vrc 1`0 e o v,n ply w i/1-7 t-1-7r'- p u 1), c,,-t r,,f w r l 1 t � ,-li 1I Ida.fa /-7- ' c rrs p rrv,' 1 - APPROVED BYTHE Approved by: diet, COMMISSIONER COMMISSION Date:/&_2g.... /.5- if L /077,6/6 5- RIGINALRBOM � s Nov 0 2 2015 A (o Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate i -� 2e...� • • O• 0 Co 0 0 0 0 co N N 00 CO N (A (-81 N O O ti O N- 0 N CO I" (` U 0 0 0 0 0 0 0 0 I. 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O N 00 = LO O (0LC) 00 O N d' d' N M O N V LO CO O O CO r- r- h a0 Oo CA CA O) M CDCDCDCDCD0 r- r- r- r- r- N M p a0 Oo OO Oo Oo Oo Oo ao a0 ao CA O O) CT CA C) O O CA CA C) C)) W y 03aa) Y 0 0 u) L 0 c~n U)i vai ai ca C a 0 0 N N N N N N N N N N N N N N N N N N N N N N fi, 00000000000cr0000000000 0 a) a °� H m Cfl O Cfl Cfl CO CO CO CO Cfl CO CO CO CO CO CO CO CO CO CO CO CO CO 0 00000000000000000000000 ❑ O c O O O O O O O CD O O O O O CD CD CD CD CD CD CD CD CD W - Z O N N N N N N N N N N N N N N N N N N N N N N ZZ W W V N LL - M M co co 00 a) a) co co a) a) a) a) co a) a) a) co co M co co W w ❑ J i N_ _N N_ N_ N_ N_ _N N_ N N N N N_ N_ N_ N_ N_ N_ N_ N_ N_ _N ❑ 0_ j W U W 110 W W LL w a 00 M 00 CO CO MCOCoCoa0 CoCOOO COOO 00 OO 00 OO 00 00 00 00 00 < 0 J H J J J D O m ❑ Y 0 w J J D Q 0 w w ▪ < m a U) E U n LL co a cc m E m r- r- r- r- r- . . . . . . . . . r r r r r r r r Z O O O O O O O O O O O O O O O O O O O O - III 1111 I 11111111111111 5 0 0 0 0 0 0 0 U U U 0 0 0 0 C7 0 0 0 0 0 0 0 w a cn 0 w N CC w i i Packers and SSV's Attachment PBU WGI-01 SW Name Type MD TVD Depscription WGI-01 PACKER 7801.7 7373.62 7" Baker SAB Packer WGI-01 PACKER 7909.08 7466.47 7" Baker SB-2 Packer • • E 6 / \ ) \/ » - I \ / a z \ / ƒ ƒ \ 5 a \ \ \ / \ \ ra in a a | . co \ N 0 < q - f + + g G \ + +ƒ § 9 . . + + g ° 0 - 0 ,-, 0 ‘' z -‘,1 f / ' \ $ Z \ z � Z CO / / ) ) § k , t } \ § + z 4 m 3 $ ) . \\ . $ , \ \ § % k \ ) \- \ ` k, \ ` }( ° ° �. 7 - . . . . . . :. } » , !N - _v } ^ \8 \e % )t$ 2 }| ` , } ! \ — ƒ` ( . © . ; ( fa } } g § TREE= GRAY 410 WELLHEAD= GRAY S NOTES: ACTUATOR= AXELSON WG 1-0 1 KB.ELEV= 49' BE ELEV= WELL NO LONGER IN USE; WGI-09 NOW USING FLOWLINES (12/2006) KOP= 3500' Max Angle= 39 @ 9200' Datum MD= ? Datum TVD= 8800'SS 2' 7"X 7-5l8"XO 7"TBG,29.04.L-80,0.0371 bpf, ID=6.184" — 2' 2182' -17-5/8"X 7"XO 7-5/8"TBG-PC,29.7#: L-80, .0459 bpf,ID=6.875" —I 2182' TOP OF 7"TBG —j 2182' 2183' —17"CAM BAL-O SSSV NIP,ID=5.937" 7"TBG,29#,L-80. .0371 bpf,ID=6.184" H 2187' f_94 TOP OF 7-5/8"TBG — 2187' 2187' R 7"X 7-5/8"XO 13-3/8"CSG,72#, N-80, ID=12.347" — 2731' Minimum ID =4.845" @ 7920' BAKER SHEAROUT SUB ' \ � 7795' —9-518"X7"BKR SAB PKR 7-5/8"TBG-IFC,29.7#,L-80, .0459 bpf,ID=6.875" H 7801' / 7801' —7-5/8"X 7"XO TOP OF 7"TBG — 7801' F- . ' 7814' —7"HES RN NIP, ID=5.5" 7"TBG,29#,L-80, .0371 bpf, ID=6.184" —I 7823' / \ 7823' —7"TUBING TAIL WLEG TOP OF 7"TBG H 7902' 7902' —19-5/8"X 7"BKR SB-2 PKR 7920' 7"BKR SHEAROUT SUB 7"TBG,29#,N-80, .0371 bpf, ID=6.184" --� 7921' J— (NO TAILPIPE)ID=4.845" .,, 7910' —ELMD TT LOGGED 08/07/79 TOP OF 7"LNR — 8019'elm 9-5/8"CSG,47#,N-80, ID=8.681" — 8314' '1.1.1.1 8100' H ESTIMATED TOC 11111111 ►1111 PERFORATION SUMMARY 11111111 1 REF LOG: BHCS ON 07/29/7911/1111 ANGLE AT TOP PERF:38 @ 8695' 1111111 1111 Note: Refer to Production DB for historical perf data 1111111 SIZE I SPF I INTERVAL I Opn/Sqz DATE 11/1� 11111111 1111 See Perforation Data on Page 2 1111 401 11111111 11111111 1111111' 1111 ►1111111 ►1111111. 111111111 ►1111 PBTD — 9292' Y1V1 '1'1'1'1' 111111111 7"LNR,29#,N-80. .0371 bpf,ID=6.184" — 9334' 14441 DATE REV BY " COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/07/79 ORIGINAL COMPLETION 12/31/05 TWS/TLH TTP PLUG PULLED(12/19/05) WELL: WGI-01 08/11/97 LAST WORKOVER 08/28/06 SRB/PAG P&A; SQZ PERFS PERMIT No: 1790310 11/03/01 RN/TP CORRECTIONS API No: 50-029-20369-00 03/22/03 JM/KAK PULL IBP SEC 11,T11N, R14E, 1795.18'&FEL 2926.14'FNL 12/11/05 ???/TLH SET TTP 12/13/05 RPH/TLH WAIVER SFTY NOTE DELETED BP Exploration(Alaska) • • • WG I-01 J 0 PERFORATION SUMMARY REF LOG:BHCS ON 07/29/79 ANGLE AT TOP PERF:38 @ 8695' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE g F.1 3-3/8" 4 8695-8725 S 08/28/06 3-3/8" 4 8725-8745 S 08/28/06 3-3/8" 4 8745-8785 S 08/28/06 3-3/8" 4 8785-8797 S 08/28/06 3-3/8" 4 8813-8853 S 08/28/06 3-3/8" 4 8853-8907 S 08/28/06 3-3/8" 4 8907-8917 S 08/28/06 3-3/8" 4 8934-8954 S 08/28/06 3-3/8" 4 8954-8983 S 08/28/06 3-3/8" 4 8983-9003 S 08/28/06 3-3/8" 4 9008-9018 S 08/28/06 3-3/8" 4 9024-9034 S 08/28/06 3-3/8" 4 9040-9048 S 08/28/06 f 3-3/8" 4 9048-9058 S 08/28/06 3-3/8" 4 9074-9082 S 08/28/06 4 3-3/8" 4 9082-9102 S 08/28/06 4.11 8100# --I ESTIMATED TOC 3-3/8" 4 9102-9122 S 08/28/06 11111111 3-3/8" 4 9122-9142 S 08/28/06 1111 3-3/8" 4 9143-9151 S 08/28/06 111111111 3-3/8" 4 9156-9162 S 08/28/06 .11. .11/111, 3-3/8" 4 9162-9182 5 08/28/06 1111 3-3/8" 4 9208-9228 S 08/28/06 111/i1 1111 1111 1111 4O 1111 1111 1111 111*: 1111111 111111 111* 11111 11111111 '1♦1�1�1�1 tAti DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/07/79 ORIGINAL COMPLETION 12/31/05 TWS/TLH TTP PLUG PULLED(12/19/05) WELL: WGI-01 08/11/97 LAST WORKOVER 08/28/06 SRB/PAG P&A;SQZ PERFS PERMIT No: 1790310 11/03/01 RN/TP CORRECTIONS AR No: 50-029-20369-00 03/22/03 JM/KAK PULL IBP SEC 11,T11N,R14E, 1795.18'&FEL 2926.14'FNL 12/11/05 ???/TLH SET TTP 12/13/05 RPH/TLH WAIVER SFTY NOTE DELETED BP Exploration (Alaska) • bp BP Exploration (Alaska) Inc. Douglas A. Cismoski, P.E., BPXA Wells Intervention Manager Post Office Box 196612 Anchorage,Alaska 99519-6612 August 19, 2015 Ms. Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well WGI-01 (PTD # 1790310) Application for Renewal of Existing Suspension (10-403) Dear Ms. Foerster, BP Exploration (Alaska) Inc. completed an AOGCC witnessed suspended well inspection of Prudhoe Bay Unit well WGI-01 on 4/13/2014 (20 AAC 25.110 (h). This recently submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: • Wellbore diagram illustrating the current configuration of the well • Suspended Well Site Inspection form documenting the pressures and site condition • Pad map and aerial photo showing well location and other wells within one- quarter mile radius of the surface location. Prudhoe Bay Unit well WGI-01 was suspended on 8/28/2006. It is located on a pad with active wells and/or service wells. The strata through which the well was drilled is - neither abnormally geopressured or depleted. The well is secured with cement across - and above the perforated interval. The well is mechanically sound as proven by a • pressure test after the cement was placed. Based on these conditions and the inspection on 4/13/2014 Prudhoe Bay Unit well WGI-01 meets the provisions required in 20 AAC 25.110 (a)(1). Based on this information, BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Prudhoe Bay well WGI-01 is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 564-4303 or Whitney Pettus/ Kevin Parks at 659-5102. • Sincerely, DouglasPP.E. Cismoski, BPXA Wells Intervention Manager Attachments Technical Justification 2014 Suspended Well Site Inspection form Wellbore Schematic Well location plat and aerial photo Cc: Doug Cismoski Pettus/ Parks Ryan Daniel • • Prudhoe Bay Well WGI-01 (PTD 1790310) Technical Justification for Renewal of Suspended Status August 19, 2015 Well History and Status Prudhoe Bay Unit well WGI-01 (PTD 1790310) was suspended effective 8/28/2006 when the completed perforation interval was plugged in preparation of drilling WGI-01A PTD 206-117. This well was not drilled and the permit expired on 8/4/2008. WGI-01 has remained with the same barriers in place. The well is secured with cement across the perforated interval and —600' of cement above the top set of perforations. Prior to the well being suspended a tubing and production casing leak were found at 6430' and the control/ balance lines were shown to be in communication with the IA. In the current state the well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, is secure, safe and not a threat to public health The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of Wellhead and Surface Location Prudhoe Bay Unit well WGI-01 is located on an active, well maintained pad with clean gravel. The surrounding area is in good condition and there is no discoloration and no sheen on the pad, pits or in nearby water. The well pressure readings are T/I/O= NA/400/0 psi recorded on 4/13/2014 and are stable. Request BPXA requests approval for renewal of the existing suspension status for WGI-01. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. • S Suspended Well Site Inspection Form 10 Year Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name Prudhoe Bay Unit WGI-01 Field/Pool: Prudhoe Bay/Prudhoe Oil Permit#(PTD) 1790310 API Number: 50029203690000 .... . . .. .. Operator: BP EXPLORATION(ALASKA)INC Date Suspended. 8/28/2006 Surface Location: Section: 11 Twsp 11N Range 14E Nearest active pad or road: Prudhoe Bay WGI-Pad Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges,fittings,tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires 1)a description of the condition of the surface location,including discoloration,fluids or sheens visible on the ground or in any nearby water, 2)photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed, None Pits condition. Good snow covered Surrounding area condition: Good Water/fluids on padNo/but snow covered Discoloration,Sheens on pad,pits or water: No Samples taken No Access road condition Good Photographs taken(#and description); None Condition of Wellhead AOGCC requires; 1)a description of the condition of the wellhead,2)well pressure readings,where practicable, 3)photographs showing the wellhead condition Wellhead/tree/valve description,condition Wellhead and tree in good condition.All valves have handles, IA and OA valves functioned good Cellar description,condition,fluids: good snow in cellar Rat Hole. None Wellhouse or protective barriers cattle quard Well identification sign: yes Tubing Pressure(or casing if no tubing). No platform to access swab and SSV was closed Annulus pressures: IA=400 psi OA=0 psi Wellhead Photos taken(#and description): (2)of the wellhead and(1)of the sign Work Required: None Operator Rep(name and signature): Jack Disbrow `\ _ AOGCC Inspector: Bob noble Ot . ervers: Kevin Parks Inspection Date. 4/13/2014 Apr C Notice Date: 4/12/2014 Time of arrival; 2:30 PM Time of Departure: 2.50 PM Site access method Access road I • TREE= GRAY WELLHEAD= GRAY SAFETY NOTES: ACITJA TOR= AXELSON WGI-01 KB.FIEV= 49' BF ELEV= WELL NO LONGER IN USE;WGI-09 NOW USING FLOWLINES(1212006) KOP= 3500' Akix An*= 39 @ 9200* Dalian SC= 7 2' 7"X 7-548-X0 Celan TVD= 88017 SS 7"TBG 29.021-80,0.0371 hot 10=6.184' H z 1 7-548-TEG-IFC,29.7#,L-83,.0459 bp92 i,ID=6.875' H 21 ' 1. / 2187 7-sx 7'XC e I TOP OF 7'TBG H 2187 I 2183 Hr CAM BAL-O SSSV NIP,ID=5.937' I 17"TBG,29P 1-80,8371 WI,ID=6.184' H 218T 1 I I 2187 7"X 7-5,8"X0 I TOP CF 7-518'TBG H 2187 I I 13-318'CSG,73#,N-80,ID=12.347" H 2731' 1\41 k Minimum ID =4.845"@ 7920' BAKER SHEAROUT SUB X 7795' H 3-58'X r BKR 5A8 PKR I 7-5rIT TBG-IRT,29.7#,L-80,.9459 bpi,ID=6.875' H 7991. I-- 7801' 7-508"x r X0 [TOP OF r TBG H 7801 F-------1 1 1 781¢ H 7-FES RN NP,ID=5.5' 1 17'TBG,290,1_430,.0371 bpi,ID=6.184' H 7923' I i \ I 7823' H 'n 883 TAL .LE(3 I ITOP OF 7'TBG H 7907 I >< ><-I Thoz H --or X 7'EIKR SET-2 PKR I II 7920 7'BKR SHEAROUT SLO T T8G,29*,N-80,.0371 NI,ID=6.184' H 7921' 1 ,M110 TA'PPE'ID=4.845' 1 I 7910' FIELTAD TT LOGGED 360773 I 70,{),r int/040100m I 9-5AC CSG,470,N-BE,ID 8.681' H 14314' I-Allh WO' 8100 H ESITAATED TOC I 04.11 4 4.* 4144 .44. FERFORATION SIALLARY 40,1 #$## REF LOG:BHCS ONE 7,2911E I#### #### /### ANGLE AT TCP PERF:38 ft 8695' 41141 0401 Mt :Refer to Produckan LB for historical fl13 0 data •.41 4.4 SEE I SW I INTERVAL I Ctsrs'Sqz I ###1 #11. ### # See Rail uraton Data on Rage 2 1### 0444 P 44.t .11•4 0.04 .1•I P441 44.1 04.41 644. 04.1 1114 114. 41.4 4.4 14 4 4' 14.14 .14. 444. PBTD 9297 YO'ff 04.44 77 1M529*,N-BE,.0371 bpl,ID=6.184' 9hrn 11414 CtA TE REV BY COMMENTS DATE REV BY C(2#IR-lTS PRUDHOE BAY UNIT 00/07179 ORIGINAL COMPLETION 12.11.115 Tina-TIN TTP FL UG PULL ED 12199511VELL WGI-11 0611197 LAST 1NORKOVER 01128128 SREVPAG RSA.SOZ PEWS PBZMIT Na:in 700312 11193001 RNTP CORRECTIONS API No: 50-029-2 a369-Jo 232.393 .1A21<AK RAI BP SEC 11,T11 N,R14E, 1795.18&FEL 2926.14 F1& 1.2:11:95 '1"1'1,TL H SET TIP 121335 RPI-171H WAIVER SFTY'NOTE DELETED EIP Exploration(AlaskaI I • WG1-01 i 0 PERFORATION SLNIARRY REF LOG:BRCS ON 07/2979 A k ANGLE AT TOP FERF:38 @ 8595 Nkte:%tiff t PrQduc bun Eg3 kw his tadCai past data SIZE 5PF INTIM'AL C4fittSq.c DATE 3-3..8' 4 595-87925 S 98/28/105 3-319 4 8725-8745 5 08/71106 3-3.8• 4 9 745-8 785 5 08/28/05 11 3-3/8' 4 9 755-8 797 5 511.129/06 3-3/8- 4 581 3-0853 5 98,0196 3-3/8- 4 985 3-89457 5 28.,213/111. 3-3/8" 4 991)7-89 17 5 38/211.05 3-W 4 8934-8854 5 3-3/8" 4 9954-8983 5 M/28:06 3-318. 4 9 98.3-92C3 5 38;28/06' 3-.W 4 9.9138-90 1.9 5 08.280015 3-3/8" 4 524-9,334 5 08;25;06 3-3/8" 4 3040-9946 5 31121101:16 3-343' 4 3048-9058 5 08+29o06 3-318" 4 .3.a74-90EQ s 38/28/4 I ' 3-3113' 4 3052-9102 5 38.,2r0E, 40.41 8100' ES 71.4A-ED TOC 3-3/8' 4 3102,9122 5 ,38128.06 10/1 1104 3-303" 4 3122-9142 5 .118/28:1313 .111 1114 111* 3-3013" 4 514.3-9151 5 38106 *104 1011- 3-3011' 4 3156-9182 S 38123;05 110. 0144 3-318" 4 3162-91E2 5 08129036 ....44' 3-3/r 4 3218-9228 s 38o213,316 1111 1104 /1141 110, 1111 411• 101 *114 .111 0111. 111! 410. 1111 * C 00 110, 4.4./.1 1111 0.... 4111 1414 1114 114* itiatt • -"Pr 19t1S1411 1.0.0 5A-E FEV B Y -M./0E1.r 5 DA-1_. RR' BY C....1109.1EN-13. PHLICI.0 E BAY LW 08.07179 ORM I NA L C OM P LET 10 N 12:3 1.:.t. "PA'SiT111 TIP FL UG Ptl L EC 12.I 10:151 W ELL. W3I-01 D 81 1.,97 LAST WCRKOV ER 311,2806 5 RaPAG F6A;SOZ PERF SPERIAT NW rl 7 903 1 1"/ 1 1 3/21 RTP CORRELIIONS API No: 50-C129-2:13.69-...0 3 3,2 2..133 14.1.1(A.K PILL BP SEC 11,T1 IN,RI4E,1795.1 Er&FEL 23245.14 F NE 12/1 1.C5 'T.111,T1 H SET TIP 121 105 PPt-VTLII WAIVER SF 1 Y NOTE CEL ET ED 3P a ploration(Alas k4 • • • 4 4 s A 4 .. ' .... ' s..-. Ca5(z.4Y..,=,(-7,?a'1)•--,.",;c•8,.9,li,•,..'....t..16q„.., 1t:$r.1,1'1„:*,-1',4,,.7;,''1',4,•„,4...1„,..'',,”,1',,.,',,,1'.','„ri.it•i'„,t,4t,,,.,.,',..i,.,,...,..;,....7,..".,.--P,,'''A'1 •:t-.-.F i.e4.'...1 •t.'',,4.,.,•'4A '•-i•,t,- 4 V,,.„. v' — , tik "4i ,,,,,,,'•..'',,..'';''„`.,...,,,1,*.,.':y.,„4:'„,,t'„„,,r'•.,t'4„ *'• •, . - , slipe. %*•',°",:t.,. .'4,74. ,. 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I.4 .__ ,,,.< . 411LAt: di- , -1 ..... _ „.„ .„, ---# - - - 1 p , r e .‹ W 0 ts _ 1 1 I 1 1,. i .2,.7, 1 8 4 1 .,1 A . - - _,.. ,,, ,. ----- '''' '*.*‘.' 44, t..t --- --•- , ,,,,,..",.. - __- J,jt,„ w ..„, --- — ---..-nLr - ___ ..__ ,, , ...... _ . _ • • Loepp, Victoria T (DOA) From: Daniel, Ryan <Ryan.Daniel@bp.com> Sent: Thursday, October 22, 2015 9:01 AM To: Loepp, Victoria T (DOA) Cc: Sternicki, Oliver R Subject: FW: PBU Suspension Renewal Wells Good Morning Victoria, Thanks for the conversation this morning. BPXA currently have 59 suspended status wells,of which many would not have *future utility today. My view for the business and from a risk perspective is to leave these wells "as is" until pad level decommissioning.The SU wells on pads with trees are monitored daily and pose minimum risk to our operations. Any wells,that are determined to have a higher risk associated with communication, re-pressurization etc will certainly be given priority for intervention and mitigation. *Additionally,as the business starts to realign from oil to gas over the next 10-15 years we would want to preserve various options (wells and surface locations)for the future. Let me know if you have any other questions Rgds Ryan From: Loepp, Victoria T(DOA) [mailto:victoria.loeppOalaska.gov] Sent: Wednesday, October 21, 2015 3:56 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells Oliver, At what point will these wells with no future utility be brought closer to abandonment?Approximately how many suspended wells are in this category? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaalaska.Qov CONFIDENTIALITY NOTICE: Ihis e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCCI,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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@olaska.gov 1 Loepp, Victoria T (DOA) Subject: From: Daniel, Ryan [mailto:Ryan.Daniel@bp.com] Sent: Tuesday, October 20, 2015 4:25 PM To: Loepp, Victoria T(DOA); Sternicki, Oliver R Cc: Regg, James B (DOA); Julian, Jennifer Y; Bill, Michael L(ASRC) Subject: RE: PBU Suspension Renewal Wells Hello Victoria, Negative. BP and its working Interest owners are developing some longer term options for"decommissioning" work scope which includes some wells and surface kit.These are screening opportunities only(potential future activities) and still in the very early scoping stage. They are not funded or approved yet,and as such it would be premature for BPXA to comment any further. The Observation well P&A program which I discussed recently with Jim,and the Suspended well renewal applications submitted by Oliver are also separate(discrete and unrelated)activity plans for well stock management and as such have different timelines and rational. We are happy to discuss the Suspended wells further id necessary. If you could use Oliver as the single point of contact for this work that would be much appreciated. Thanks Ryan From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, October 20, 2015 2:16 PM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, Do you have any information to share with us on the sustained P&A program and where these suspension renewal wells fit in the program? Thanx, Victoria 1 • • From: Sternicki, Oliver R [mailto:Oliver.Sternicki@ bp.corn] Sent: Thursday, October 08, 2015 4:03 PM To: Loepp, Victoria T(DOA) Cc: Daniel, Ryan Subject: PBU Suspension Renewal Wells Victoria, This is the response from Base Management for the 9 suspended wells renewals and if the fall under A or B of 20AAC 25.110(a)(2). 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory,development,or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. WGI-01: no current sidetrack plans 02-30B: no current sidetrack plans G-13A: no current sidetrack plans, but may use surface equipment for another well V-201: no current sidetrack plans S-14A: no current sidetrack plans W-09A: no current sidetrack plans E-18B: evaluating several sidetrack options NK-14A: evaluating a sidetrack option Y-25A: no current sidetrack plans Let me know if you have any other questions. Regards, Oliver Sternicki WO Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907)350 0759 oliver.sternicki(cr�.bp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp(aalaska.gov] Sent: Monday, September 28, 2015 3:10 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells So no well listed below,with the exception of 1-100 has future utility as an exploratory, development, or service well and no well listed below is a viable candidate for redrilling? I understand the wells are all located on active pads. Victoria Victoria Loepp Senior Petroleum Engineer 2 • State of Alaska • . Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCatalaska.aov CONFIDENTIALRY 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Sternicki, Oliver R [mailto:Oliver.Sternicki(abp.com1 Sent: Monday, September 28, 2015 2:41 PM To: Loepp, Victoria T(DOA) Cc: AK, D&C Well Integrity Coordinator; Daniel, Ryan Subject: RE: PBU Suspension Renewal Wells Victoria, The below wells that you have listed fall under the category; (C) is located on a pad or platform with active producing or service wells. 1-100 which you did not list is the only well that BPXA sent for renewal of suspended status that falls under the category. (A) has future utility as an exploratory,development,or service well; no wells meet the (B)criteria. Regards, Oliver Sternicki Ca gilobsi BOO Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternickibp.com From: Daniel, Ryan Sent: Monday, September 28, 2015 9:26 AM To: Sternicki, Oliver R Cc: AK, D&C Well Integrity Coordinator Subject: FW: PBU Suspension Renewal Wells Oliver, Can you please reply to Victoria on this question, Copy me,or come and discuss if we have an issue. Thanks Ryan 3 • , From: Loepp, Victoria T(DOA) [mailto:victoria.loeppOalaska.gov] Sent: Monday, September 28, 2015 9:25 AM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, PBU 02-30B 200-126 PBU V-201 201-222 PBU E-18B 204-139 PBU G-13A 200-163 PBU S-14A 204-071 PBU W-09A 204-102 PBU WGI-01 179-031 PBU Y-25A 208-140 PBU NK-14A 206-031 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. Which wells meet the criteria of(A)and/or(B)? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppf alaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 04/13/14 Inspector. Bob Noble Well Name: PBU WGI-10 PTD No.: 1790310 Location Verified? Yes If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 08/28/06 Sundry No.: 306-246 Well Pressures (psi): Tubing unknown IA 400 OA 0 iition of head: Condition of Surrounding Surface Location: Follow Up Actions Needed: Operator: BPX Oper. Rep: Kevin Parks Oper. Phone: 659-5766 Oper. Email: Date AOGCC Notified: 04/12/14 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Photos Taken? Yes The wellhead was in good condition with all valves blinded with oauoes. Valves all had handles. SSV was closed. No leaks or Photos (2) "NED OCT! 3 2014 EWED BY: Supry J�/L PLB 08/2010 2014-0413_Suspend_PBU_WGI-01_bn.xlsx Suspended Well Inspection — PBU WGI-01 PTD 1790310 Photos by AOGCC Inspector B. Noble PBU WGI Suspended Well Inspection 4-13-14 bn STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon LJ Repair Well H Plug Perforations Perforate Other Suspend Inspection Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension[] Report - 10 yr Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name. BP Exploration (Alaska), Inc Development❑ Stratigraphic❑ Exploratory ❑ Service ❑ 179-031-0 3 Address. P.O. Box 196612 6, API Number: Anchorage, AK 99519-6612 50-029-20369-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028302 PBU WGI-01 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10 Field/Pool(s) PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 9335 feet Plugs measured None feet true feet Junk None feet MAY 2 2 2014 vertical 8639.21 measured Effective Depth measured 8100 feet Packer measured See Attachment feet & OGCG true vertical 7632.17 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H-40 30-110 30-110 1530 520 Surface 2703 13-3/8" 72# N-80 28-2731 28 - 2730.93 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner 1313 7" 29# N-80 8021 -9334 7563.55 - 8638.44 8160 7020 Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 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-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments. 15. Well Class after work: Copies of Logs and Surveys Run Exploratory] Development ❑ Service ❑ Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work. OliGas L WDSPLLJ Ten Year Suspended Well Inspection Report & Photo's X GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 17 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O. Exempt: N/A Contact Garry Catron Email Garry.Catron2BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 5/22/2014 Farm 10-404 Revised 10/2012 vt,l �, l[g 114 ,00 Submit Original Only RBC NIS MAY 2 3 20 Packers and SSV's Attachment ADL0028302 SW Name Type MD TVD Depscription WGI-01 PACKER 7798 7370.4 7" Baker SAB Packer WGI-01 PACKER 7906 7463.82 7" Baker SB -2 Packer Casing / Tubing Attachment ADL0028302 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 30 - 110 30 - 110 1530 520 INTERMEDIATE 2283 9-5/8" 47# SOO-95 26 - 2309 26 - 2308.95 8150 5080 INTERMEDIATE 6005 9-5/8" 47# N-80 2309 - 8314 2308.95 - 7817.72 6870 4760 LINER 1313 7" 29# N-80 8021 - 9334 7563.55 - 8638.44 8160 7020 SURFACE 2703 13-3/8" 72# N-80 28 - 2731 28 - 2730.93 4930 2670 TUBING 2161 7-5/8" 29.7# L-80 24 - 2185 24 - 2184.96 6890 4790 TUBING 5608 7-5/8" 29.7# L-80 2189 - 7797 2188.96 - 7369.54 6890 4790 TUBING 29 7" 29# L-80 7797 - 7826 7369.54 - 7394.72 8160 7020 TUBING 18 7" 29# N-80 7906 - 7924 7463.82 - 7479.34 8160 7020 AB ABANDONED MIR Perforation Attachment APF ADD PERF MIS MECHANICAL ISOLATED BPP ADL0028302 MILK MECHANICAL LEAK BPS SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base WGI-01 8/28/2006 SQZ 8695 8725 8138.05 8161.67 WGI-01 8/28/2006 SQZ 8725 8745 8161.67 8177.4 WGI-01 8/28/2006 SQZ 8745 8785 8177.4 8208.78 WGI-01 8/28/2006 SQZ 8785 8797 8208.78 8218.17 WGI-01 8/28/2006 SQZ 8813 8853 8230.69 8261.96 WGI-01 8/28/2006 SQZ 8853 8907 8261.96 8304.1 WGI-01 8/28/2006 SQZ 8907 8917 8304.1 8311.92 WGI-01 8/28/2006 SQZ 8934 8954 8325.25 8341.01 WGI-01 8/28/2006 SQZ 8954 8983 8341.01 8363.86 WGI-01 8/28/2006 SQZ 8983 9003 8363.86 8379.61 WGI-01 8/28/2006 SQZ 9008 9018 8383.55 8391.43 WGI-01 8/28/2006 SQZ 9024 9034 8396.16 8404.03 WGI-01 8/28/2006 SQZ 9040 9048 8408.75 8415.05 WGI-01 8/28/2006 SQZ 9048 9058 8415.05 8422.91 WGI-01 8/28/2006 SQZ 9074 9082 8435.49 8441.78 WGI-01 8/28/2006 SQZ 9082 9102 8441.78 8457.49 WGI-01 8/28/2006 SQZ 9102 9122 8457.49 8473.18 WGI-01 8/28/2006 SQZ 9122 9142 8473.18 8488.83 WGI-01 8/28/2006 SQZ 9143 9151 8489.62 8495.87 WGI-01 8/28/2006 SQZ 9156 9162 8499.77 8504.46 WGI-01 8/28/2006 SQZ 9162 9182 8504.46 8520.05 WGI-01 8/28/2006 SQZ 9208 9228 8540.27 8555.82 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MILK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Suspended Well Site Inspection Form 10 Year Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Prudhoe Bay Unit WGI-01 Field/Pool: Prudhoe Bay/Prudhoe Oil Permit # (PTD): 1790310 API Number: 50029203690000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended 8/28/2006 Surface Location: Section: 11 Twsp: 11N Range: 14E Nearest active pad or road: Prudhoe Bay WGI-Pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None Pits condition: Good snow covered Surrounding area condition: Good Water/fluids on pad: No/ but snow covered Discoloration, Sheens on pad, pits or water. No Samples taken: No Access road condition: Good Photographs taken (# and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Welthead/tree/valve description, condition: Wellhead and tree in good condition. All valves have handles. IA and OA valves functioned good. Cellar description, condition, fluids: good snow in cellar Rat Hole. None Wellhouse or protective barriers. cattle guard Well identification sign: yes Tubing Pressure (or casing if no tubing) No platform to access swab and SSV was closed Annulus pressures: IA= 400 psi OA = 0 psi Wellhead Photos taken (# and description). (2) of the wellhead and (1) of the sign Work Required: None Operator Rep (name and signature): Jack Disbrow r\ AOGCC Inspector: Bob noble Ot r Observers: Inspection Date: 4/13/2014 AO C Notice Date: Time of arrival. 2:30 PM Time of Departure. Site access method: Access road Kevin Parks 4/12/2014 2:50 PM WELL: W.. GF01 '#WNER Prudhoe OPERATOR i •Exploration(Alaska) Inc. 1 • NUMBER50-029-20369-00-00 • LOCATION 1# • DRILLING • - 179-031 \` .. '' s \` s �u ..� a. a��t� � ''�" E',..._.. ��� _...F -,,.� . �!� E - U -- � ■ � �r�✓ — '� � �...� � lF � � � � ��� �, �_ i ��.. �s w�, a '� .:,3. -*K �" .,� ''., � .�:� , -� .� , '�=� � f 0% 0 TREE = GRAY WELUIEAD -' GRAY CT•ATOR= AXELSON KB. CLEV = 49' BF. ELEV = 12/31/05 TWS/TLH TTP PLUG PULLED (12/19/05) KOP = 3500' Max Angle = 39 @ 9200' Datum MD = ? Datum TV D = 8800' SS W �' -0 � SAFETY NOTES: WELL NO LONGER IN USE; WGI-09 NOW USING FLOWLINES (12/2006) 7" TBG, 29.0#, L-80, 0.0371 bpf, ID = 6.184" 2• 7-5/8" TBG -IPC, 29.7#, L-80,.0459 bpf, ID = 6.875" 2182' TOP OF 7" TBG2182' 7" TBG, 29#, L-80-0371 bpf, ID = 6.184" 2187' TOP OF 7-5/8" TBG 2187' 13-3/8" CSG, 72#, N-80, ID = 12.347"2731' Minimum ID = 4.845" @ 7920' BAKER SHEAROUT SUB 7-5/8" TBG -IPC, 29.7#, L-80,.0459 bpf, ID = 6.875" 7801' TOP OF 7" TBG 7801' 7" TBG, 29#, L-80,.0371 bpf, ID = 6.184" 7823' TOP OF 7" TBG 1-1 7902' 7" TBG, 29#, N-80,.0371 bpf, ID = 6.184" 7921' TOPOF 7" LNR 8019' elm 9-5/8" CSG, 47#, N-80, ID = 8.681" 1 8314' PERFORATION SUMMARY REF LOG: BHCS ON 07/29/79 ANGLE AT TOP PERF: 38 @ 8695' Note: Refer to Production DB for historical pert data SIZE I SPF I INTERVAL I Opn/Sqz I DATE See Perforation Data on Page 2 PBTD 9292' 7" LNR, 29#, N-80_0371 bpf, ID = 6.184" 9334' 2' 1--17 X 7-5/8" XO 2182' 1.17-5/8" X 7" XO • 2183' -17" CAM BAL-O SSSV NIP, ID = 5.937" 2187' 4TT X 7-5/8" XO 7795' -1 9-5/8" X 7" BKR SAB PKR 7801' 7-5/8" X 7" XO 7814' 7" HES RN NIP, ID = 5.5" 7823' 7" TUBING TAIL WLEG 7902' 119-5/8" X 7" BKR SB -2 PKR 7920' 7" BKR SHEAROUT SUB (NO TAILPIPE) ID = 4.845" 7�1—W-1ELMD TT LOGGED 08/07/79 8100' ESTIMATED TOC DATE REV BY COMMENTS DATE REV BY COMMENTS 08/07/79 ORIGINAL COMPLETION 12/31/05 TWS/TLH TTP PLUG PULLED (12/19/05) 08/11/97 LAST WORKOVER 08/28/06 SRB/PAG P&A; SQZ PERFS 11/03/01 RN/TP CORRECTIONS 03/22/03 JM/KAK PULL IBP 12/11/05 1 ???/TLH I SET TTP 12/13/05 RPH/TLH I WA V ER SFTY NOTE DELETED PRUDHOE BAY UNIT WELL: WGI-01 PERMIT No: 1790310 API No: 50-029-20369-00 SEC 11, T11 N, R1 4E, 1795.18' & FEL 2926.14' FNL BP Exploration (Alaska) P PERFORATION SUMMARY REF LOG: BHCS ON 07/29/79 ANGLE AT TOP PERF: 38 @ 8695' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8695-8725 S 08/28/06 3-3/8" 4 8725-8745 S 08/28/06 3-3/8" 4 8745-8785 S 08/28/06 3-3/8" 4 8785-8797 S 08/28/06 3-3/8" 4 8813-8853 S 08/28/06 3-3/8" 4 8853-8907 S 08/28/06 3-3/8" 4 8907-8917 S 08/28/06 3-3/8" 4 8934-8954 S 08/28/06 3-3/8" 4 8954-8983 S 08/28/06 3-3/8" 4 8983-9003 S 08/28/06 3-3/8" 4 9008-9018 S 08/28/06 3-3/8" 4 9024-9034 S 08/28/06 3-3/8" 4 9040-9048 S 08/28/06 3-3/8" 4 9048-9058 S 08/28/06 3-3/8" 4 9074-9082 S 08/28/06 3-3/8" 4 9082-9102 S 08/28/06 3-3/8" 4 9102-9122 S 08/28/06 3-3/8" 4 9122-9142 S 08/28/06 3-3/8" 4 9143-9151 S 08/28/06 3-3/8" 4 9156-9162 S 08/28/06 3-3/8" 4 9162-9182 S 08/28/06 3-3/8" 4 9208-9228 S 08/28/06 WGI-01 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/07/79 ORIGINAL COMPLETION 12/31/05 TWS/TLH TTP PLUG PULLED (12/19/05) 08/11/97 LAST WORKOVER 08/28/06 SRB/PAG P&A; SQZ PERFS 11/03/01 RN/TP CORRECTIONS 03/22/03 JM/KAK PULL IBP 12/11/05 ???/TLH I SET TTP 12/13/05 RPH/TLH WAIVER SFTY NOTE DELETED PRUDHOE BAY UNIT WELL: WGI-01 PERMIT No: 1790310 API No: 50-029-20369-00 SEC 11, T11 N, R14E, 1795.18'& FEL 2926.14' FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other 0 INSPECT Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ WELL Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^ Exploratory ^ ~ 179-0310 3. Address: P.O. Box 196612 Stratigraphic^ Service Q 6. API Number: Anchorage, AK 99519-6612 ` 50-029-20369-00-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ~, ADLO-028302 PBU WGI-01 10. Field/Pool(s): z PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 9335 feet Plugs (measured) 8100' TOC feet true vertical 8639.21 feet Junk (measured) None feet Effective Depth measured 7984 feet Packer (measured) 7795 7902 true vertical 7536 feet (true vertical) 7368 7460 Casing Length Size MD ND Burst Collapse Structural Conductor 103 20" 94# H-40 SURFACE - 103 SURFACE - 103 1530 520 Surface 2731 13-3/8" 72# N-80 SURFACE - 2731 SURFACE - 2731 4930 2670 Intermediate 8314 9-5/8" 47# N-80 SURFACE - 8314 SURFACE - 7822 6870. 5080 Production Liner 1315 7"29# N-80 8019 - 9334 7566 - 8643 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ ..,~ `7 ~ ~; _ F_ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 7-5/8" 29.7# L-80 21 - 2182 21 - 2182 7~~ P9# L-80 2182 - 2187 2182 - 2187 7-5/8" 29.7# L-80 2187 - 7801 2187 - 7373 7" 29# L-80 7801 - 7823 7373 - 7392 7" 29# L-80 7902 - 7921 7460 - 7477 Packers and SSSV (type, measured and true vertical depth) 7" Baker SAB Packer 7795 7368 7" Baker SB-2 Packer 7902 ~~ al.l 7460 12. Stimulation or cement squeeze summary: ~ ' ~' ^' _° +. ` Q j(~ 30 o p sue:, ~~ -~ Intervals treated (measured): ~ 1~~~'fi~{~ ~ ~~ ~a ~ Treatment descriptions including volumes used and final pressure: ~af.It tr. ~~;;: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ ~ velopment ^ Service ^/ Daily Report of WeII Operations X 16. Well Status after we SUSPENDED Oil Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date rOrm lU-4U4 K2VIS60 //ZUUy v n v iyniai vnry R6DMS AU6 2 5 20~~ ~'•/-/~ Z/o WGI-01 179-031 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd De th To Tvd De th Base WGI-01 8110180 PER 8,695. 8,725. 8,138.05 8,161.67 WGI-01 8110/80 PER 9,208. 9,228. 8,540.27 8,555.82 WGI-01 8/10/80 PER 9,162. 9,182. 8,504.46 8,520.05 WGI-01 8110/80 PER 9,122. 9,142. 8,473.18 8,488.83 WGI-01 8/10/80 PER 9,048. 9,058. 8,415.05 8,422.91 WGI-01 8/10/80 PER 9,024. 9,034. 8,396.16 8,404.03 WGI-01 8/10/80 PER 9,082. 9,102. 8,441.78 8,457.49 WGI-01 8110/80 PER 8,934. 8,954. 8,325.25 8,341.01 WGI-01 8/10/80 PER 8,907. 8,917. 8,304.1 8,311.92 WGI-01 8/10/80 PER 8,813. 8,853. 8,230.69 8,261.96 WGI-01 8/10/80 PER 8,745. 8,785. 8,177.4 8,208.78 WGI-01 8/10/80 PER 8,983. 9,003. 8,363.86 8,379.61 WGI-01 311/87 APF 9,074. 9,082. 8,435.49 8,441.78 WGI-01 311187 APF 9,156. 9,162. 8,499.77 8,504.46 WGI-01 3/1/87 APF 9,143. 9,151. 8,489.62 8,495.87 WGI-01 3/1/87 APF 9,102. 9,122. 8,457.49 8,473.18 WGI-01 3/1/87 APF 9,040. 9,048. 8,408.75 8,415.05 WGI-01 3/1/87 APF 8,785. 8,797. 8,208.78 8,218.17 WGI-01 3/1/87 APF 8,954. 8,983. 8,341.01 8,363.86 WGI-01 311/87 APF 8,853. 8,907. 8,261.96 8,304.1 WGI-01 3/1/87 APF 8,725. 8,745. 8,161.67 8,177.4 WGI-01 311/87 APF 9,008. 9,018. 8,383.55 8,391.43 WGI-01 11/26/02 BPS 8,093.5 8,106.5 7,626.54 7,637.8 WGI-01 2/8/03 MLK 6,408. 6,409. 6,163.85 6,164.69 WGI-01 3122103 BPP 8,093.5 8,106.5 7,626.54 7,637.8 WGI-01 8/28/06 SQZ 0. 9,228. 0. 8,555.82 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • Prudhoe Bay Unit Well WGI-01, PTD 1790310 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of PBU WGI-01 on 08/04/10. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC inspector Bob Noble witnessed the inspection. • Wellbore diagram illustrating the current configuration of the well • Pad map showing the well location and other wells within one-quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • PBU WGI-01 was suspended on 08/28/06. • PBU WGI-01 is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The well is secured with cement across and above the perforated interval. • The well is mechanically sound as proven by a pressure test after the cement was placed. MLB 08/23/10 • Suspended Weli Side lnspectian Form Notify AOGCC inspectors at least 10 days prior to inspection to allow witness Wefl Name: faermit I# (PTD): Operator: Surface Location: I'RUDI-IOB BAY UNIT WG1-01 Field/Pool: PRUDI-i0~ BAY / PRUDI~-fOE OiL 179-031 API Number: 50029203690000 8P EXPLORATION (ALASKA} INC Date Suspended: Section: 11 Twsp: 11 N Range: 14E Nearest active pad or road: Prudhoe Bay WGI-Pad Tale to Location Digifal camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2} pha#ographs showing the condition of the location surrounding the well General location condition: Good B/2F3/2005 Pad or location surface: Good Location cleanup needed: Cleaned small stain in well cellar Pits condition: Good Surrounding area condition: Good Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (# and description): None Condition of Wellhead AOGCC requires: 1 } a description of the condition of the wellhead, 2}well pressure readings, where practicable, 3} photographs showing the wellhead condition Wellhead/tree/valve description, condition: Grey gen 1 tree. No handle on master valve. IA & OA valves functioned good. Wellhead and tree in good condition. Cellar descript'son, condition, fluids: No fluids, small, old stain in well cellar of unknown origin. Called SRT & cleaned up. Rat Hole: None Wellhouse or protective barriers: Cattle guard Well identification sign: None Tubing Pressure (or casing i# no tubing): SSV, no scaffolding to access swab valve Annulus pressures: 300 psi on IA, 0 psi on OA Wellhead Photos taken (# and description): 2 -both wellhead. AOGCC Inspector took 6 photos ~_~~ Work Required: Put on master valve handle. Ordered wellhouse sign Operator Rep (name and signature): Jerry Murphy `~. 1~~--.~~ '7 r~:u~i~~.>~r:- ~r.~~ .k'~crr iYi;r.,rg~i,.. ~/?_, AOGCC Inspector: Bab Noble Other Observers: Ryan Nolt ' Inspection Date: 8/4/2010 AOGCC Notice Date: 713 1 12 0 1 0 Time of arrival: 10:00 AM Time of Departure: 10:15 AM Site access method: Access road TREE = GRAY WELLHEAD - GRAY ACTUATOR= AXELSON KB. ELEV = 49' BF. ELEV = KOP = 3500' _. Max Angle = 39 @ 9200' Datum MD - Datum TVD = 8800' SS ~ WG I-01 sA~~s: WELL NO LONGER IN USE; WGI-09 NOW USING FLOWLINES {12/2006) 7" TBG, 29.0#, L-80, 0.0371 bpf, ID = 6.184" ~-I 2• 7-5/8" TBG-IPC, 29.7#, L-80, .0459 bpf, ID = 6.875" 2182' TOP OF 7" TBG 2182' 7" TBG, 29#, L-80, .0371 bpf, ID = 6.184" 2187' TOP OF 7-5/8" TBG 2187' 13-3/8" CSG, 72#, N-80, ID = 12.347" 2731' Minimum ID = 4.845" @ 7920' BAKER SHEAROUT SUB 7-5/8" TBG-IPC, 29.7#, L-80, .0459 bpf, ID = 6.875" 7801' TOP OF 7" TBG 7801' 7" TBG, 29#, L-80, .0371 bpf, ID = 6.184" 7823' TOP OF 7" TBG ~-~ 7902' 7" TBG, 29#, N-80, .0371 bpf, ID = 6.184" ~ 7921' TOP OF 7" LNR 8019' elm 9-5/8" CSG, 47#, N-80, ID = 8.681" 8314' PERFORATION SUMMARY REF LOG: BHCS ON 07/29!79 ANGLE AT TOP PERF: 38 @ 8695' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE See Perforation Data on Page 2 PBTD 9292' 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 9334' 2' ~-i 7" X 7-518" XO 2182' -17-5/8" X 7" XO 2183' 7" CAM BAL-O SSSV NIP, ID = 5.937" 2187' 7" X 7-518" XO 7795' -I9-518" X 7" BKR SAB PKR 7801' 7-5/8" X 7" XO 7814' 7" HES RN NIP, ID = 5.5" 7$23' 7" TUBING TAIL WLEG 7902' --~ 9-5/8" X 7" BKR SB-2 PKR 7920' 7" BKR SHEAROUT SUB (NO TAILPIPE) ID = 4.845" 7~ 910' ~ ELMD TT LOGGED 08/07/79 8100' ESTIMATED TOC DATE REV BY COMMENTS DATE REV BY COMMENTS 08/07/79 ORIGINAL COMPLETION 12/31/05 TWS/TLH TTP PLUG PULLED (12!19/05) 08/11/97 LAST WORKOVER 08/28/06 SRB/PAG P&A; SOZ PERFS 11!03/01 RN/TP CORRECTIONS 03/22/03 JM/KAK PULL IBP 12/11/05 ???/TLH SETTTP 12(13/05 RPH/TLH WAVER SFTY NOTE DELETED PRUDHOE BAY UNIT WELL: WGI-01 PERMff No: 1790310 API No: 50-029-20369-00 SEC 11, T11N, R14E, 1795.18' & FEL 2926.14' FNL BP Exploration (Alaska) ~ WGI-01 ~ PERFORATION SUMMARY REF LOG: BRCS ON 07/29!79 ANGLE AT TOP PERF: 38 @ 8695' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8695-8725 S 08/28/06 3-3/8" 4 8725-8745 S 08/28/06 3-3/8" 4 8745-8785 S 08/28/06 3-3/8" 4 8785-8797 S 08/28/06 3-3/8" 4 8813-8853 S 08/28/06 3-3/8" 4 8853-8907 S 08/28/06 3-3/8" 4 8907-8917 S 08/28/06 3-3/8" 4 8934-8954 S 08/28/06 3-3/8" 4 8954-8983 S 08/28!06 3-3/8" 4 8983-9003 S 08/28/06 3-3/8" 4 9008-9018 S 08/28/06 3-318" 4 9024-9034 S 08/28/06 3-3/8" 4 9040-9048 S 08/28/06 3-318" 4 9048-9058 S 08/28/06 3-3/8" 4 9074-9082 S 08/28/06 3-318" 4 9082-9102 S 08/28/06 3-3/8" 4 9102-9122 S 08/28(06 3-3/8" 4 9122-9142 S 08/28/06 3-318" 4 9143-9151 S 08/28/06 3-318" 4 9156-9162 S 08!28/06 3-3/8" 4 9162-9182 S 08!28/06 3-318" 4 9208-9228 S 08/28/06 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/07/79 ORIGINAL COMPLETION 12/31/05 TWS/TLH TTPPLUGPULLED(12/19/05) 08/11/97 LAST WORKOVER 08/28/06 SRB/PAG P&A; SOZ PERFS 11/03!01 RN/TP CORRECTIONS 03/22/03 JM/KAK PULL IBP 12/11/05 ???/TLH SETTTP 12113/05 RPH/TLH WAVER SFTY NOTE DELETED PRUDHOE BAY UNIT WELL: WGF01 PERMff No: 1790310 API No: 50-029-20369-00 SEC 11, T11 N, R14E, 1795.18' & FEL 2926.14' FNL BP Exploration (Alaska) • • Enter/Exit ' (-~ 237' _ _ _~ ,,`J ~`` ~- -= - ', a 9 ~l __ -- , -- ~ _ II ___ i , 2 - . , ~ `. _ , ~ ,~ ~, i •.-~. -_ I r ~,r_~'-- C _ - ~ ~3 ~4 -~ i X~~~. ,i I __ ~ I .... _._ J I ~( ~ ~. 1 ~~ _ ~~, --;. - l.- i 4 (~ I _~ i ~~_ ~ I'`-- if, : - ,1~~~ ~ ! Enter/Exit ~~, ~ O +( T ~ t8 ' .~.~-- i5 ~~ ;- 0 O N T i., .l ~En erJExit '.v.z v~_co~ ~ DATE : C1iC~6~2;X'i9 SC/ILE: 1' = 154 hMP D/1TE: 2vv' PBV - WG~ b91~~5.tl~1 ~GI my 14, 2009 ,~ ., Approximate Scale: 1 "=200' x ~~ ~~ x 2009-18c-5-23 ~} °, , A~TtO-t11~TRIC ~~ ~~ ~~ ~~ ~ 4" -. -~ r ~;.. 1 : ~ ., ; ~ , ~ ~ ~ ~ ~ ~ ' ~. .. 1 S ~t '~',~ 4 #' - Y ~ `°` } Y ~ ~t k ,~ T ~~ ~ ~. ~°. r ji .. &• ' ~ .`,. i # i y, .'` ~ ~ ' r e, s s WGI-01 Tree/Welihead ~! # • MEMORANDUM State of .Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~p~ ~ (lz~~~ DATE: Aug 9, 2010 P. I. Supervisor ~~ FROM: Bob Noble SUBJECT: Suspended Well Inspection Petroleum Inspector PBU WGI-01 r BPXA PTD - 179-031 ,, Auq 5t" 2010: AOGCC Phoebe Brooks and I met with BPX Ryan Holt at WGI-01 to perform a suspended well inspection. The general location condition and the wellhead looked pretty good. There was a protective barrier around the wellhead. All lines were blinded. SSV was shut and there was no handle on the master valve. A small old oil stain was in the cellar area. T/I/0=?/300/0. We did not get the tubing pressure because there was no master handle and the SSV was closed. I ask Ryan Holt got get a master valve handle and to do something about the old spill. He told me he would get a handle and that he would call SRT to clean up the spill. Auq 9t" 2010; I did a follow up inspection and there was a handle on the master valve and the , small oil stain had been cleaned up. Attachments: none 7~ `) [~11~ ~~~~ ,-~b, 4 .. ~ r. Suspended PBU WGI-OI 8-9-10 SARAH PALIN, GOVERNOR sKA 011L AND GS 333 W. 7th AVENUE, SUITE 100 CGIVEERVA.LIOX COMUSSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 29, 2009 FAX (907) 276-7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7004 1160 0001 3621 1878 Harry Engel BP Exploration Alaska Inc. PO Box 196612NN 0C I Y 214 Anchorage AK 99519-6612 Re: Request for Verification of Suspended, Shut -In and Observation Well Information Dear Mr. Engel: This letter supersedes our correspondence of January 28, 2009. Enclosed are lists of suspended, long term shut-in and observation wells operated by BP Exploration Alaska Inc. and BP Alaska Inc. For each list, please verify the information for each well, and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, /17�� Cathy. Foerster Commissioner Enclosures 1 v , V V CERTIFIED MAIL,,., RECEIPT (Domestic Mail Only; No Insurance Coverage Providec ru NONAGE AX 295-6612iE rn Postage $ $0.59 J QS POST a O Certified Fee $2.70 SZ N C3 CO Return Reciept Fee Za (Endorsement Required) $2.20 nVYC3, Restricted Delivery Fee (Endorsement Required) $0.00 �Op m Total Postage & Fees $ $5.44 Ol! 4C r\ O Sent To E3 /---�------------------- ----- Street, Apt. No.; , / �/� or PO Box No. / Y ! / Cify, State, ZIPr4 PS Form :r0 June 2002 ■ Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: .gpx/Y A. Signatu X �W Agent Addressee B. Re eiv by ( Printed (Name) C. Date of Dewey D. Is delivery ardress dint from item 1? ❑ Y40 If YES, enter delivery address below: ❑ No 3. Se ice Type Q certified Mail ❑ Express Mail ❑ Registered )213eturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service label) 7004 116 0 0001 3621 1878 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 Operator Suspended, Shut In and Observation Wells BP ALASKA INC Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... PRUDHOE BAY 169-068-0 50-029-20036-00-00 PUT RIV 01-10-14 OBSW 9/19/1975 555 FNL 710 FEL Sec 11 T ION R 14E UM 169-069-0 50-029-20037-00-00 PUT RIV 02-10-14 OBSW 9/19/1975 555 FNL 820 FEL Sec 11 T ION R 14 E UM 169-070-0 50-029-20038-00-00 PUT RIV 11-10-14 OBSW 9/19/1975 555 FNL 930 FEL Sec 11 T ION R 14 E UM 169-059-0 50-029-20033-00-00 PUT RIV 13-10-14 OBSW 9/19/1975 650 FSL 555 FWL Sec 13 T ION R 14 E UM 169-062-0 50-029-20034-00-00 PUT RIV 14-10-14 OBSW 9/19/1975 430 FSL 555 FWL Sec 13 T ION R 14 E UM 169-081-0 50-029-20043-00-00 PUT RIV 17-10-15 OBSW 9/19/1975 755 FNL 600 FEL Sec 19 T ION R 15E UM Thursday, January 29, 2009 Operator 50-029-20133-00-00 Suspended, Shut In and Observation Wells 1536 FNL BP EXPLORATION (ALASKA) INC T 11 N R 15E UM 175-059-0 50-029-20177-00-00 GETTY STATE 1 OBSW Field 1388 FSL 887 FWL Current Date of T ION R 13E UM 180-092-0 50-029-20504-00-00 PBU MP 11-33-11-12 1 Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... *EXPLORATORY R 12 E UM 198-035-0 50-029-22866-00-00 PRUDHOE BAY UN BORE 02-01 SUSP 4/22/1998 453 FSL 198-252-0 50-089-20027-00-00 RED DOG 1 SUSP 4/2/1999 1682 FSL 4508 FEL Sec 34 T ION R 21 E UM ENDICOTT 3945 FEL Sec 20 T 12 N R 11 E UM 189-075-0 50-029-21959-00-00 PRUDHOE BAY UN LIS 1-3-01 SUSP 196-022-0 50-029-22644-00-00 DUCK IS UNIT MPI 1-59/024 SUSP 2/21/1996 3083 FSL 2202 FEL Sec 36 T 12 N R 16E UM MILNE POINT 12/8/1994 2426 FSL 2176 FEL Sec 24 T 11 N R 15E UM 202-002-0 196-009-0 50-029-22642-00-00 MILNE PT UNIT KR B-24 SUSP 3/3/1996 827 FSL 4289 FEL Sec 18 T 13 N R 11 E UM 199-091-0 50-029-21373-01-00 MILNE PT UNIT KR C -12A SUSP 7/13/2003 496 FSL 2027 FEL Sec 10 T 13 N R 10E UM 185-110-0 50-029-21364-00-00 MILNE PT UNIT KR C-16 SUSP 10/27/1993 610 FSL 2063 FEL Sec 10 T 13N R 10E UM 196-032-0 50-029-22650-00-00 MILNE PT UNIT KR K-25 SUSP 3/23/1996 3592 FSL 2078 FEL Sec 3 T 12 N R 11 E UM 197-080-0 50-029-22766-00-00 MILNE PT UNIT KR L-34 SUSP 12/1/2008 3285 FSL 5106 FEL Sec 8 T 13N R 10E UM 201-109-0 50-029-22768-01-00 MILNE PT UNIT KR L -35A SUSP 10/12/2002 3177 FSL 4937 FEL Sec 8 T 13 N R 10E UM 201-075-0 50-029-23012-00-00 MILNE PT UNIT SB 1-13 SUSP 8/19/2001 2346 FSL 1253 FWL Sec 33 T 13 N R 10E UM NORTHSTAR 200-211-0 50-029-22996-00-00 NORTHSTAR UNIT NS -26 SUSP 2/1/2001 1298 FSL 648 FEL Sec 11 T 13 N R 13E UM 206-138-0 50-029-23325-00-00 NORTHSTAR UNIT NS -33 SUSP 4/26/2007 1369 FSL 650 FEL Sec 11 T 13N R 13 E UM PRUDHOE BAY 174-006-0 50-029-20133-00-00 E BAY ST 1 OBSW 10/6/1986 1536 FNL 635 FWL Sec 15 T 11 N R 15E UM 175-059-0 50-029-20177-00-00 GETTY STATE 1 OBSW 5/11/1980 1388 FSL 887 FWL Sec 2 T ION R 13E UM 180-092-0 50-029-20504-00-00 PBU MP 11-33-11-12 1 SUSP 4/29/1981 1966 FNL 1380 FEL Sec 33 T 11 N R 12 E UM 198-035-0 50-029-22866-00-00 PRUDHOE BAY UN BORE 02-01 SUSP 4/22/1998 453 FSL 4553 FWL Sec 19 T 12 N R 11 E UM 205-010-0 50-029-23245-00-00 PRUDHOE BAY UN BORE 1-100 SUSP 4/17/2006 3219 FSL 3945 FEL Sec 20 T 12 N R 11 E UM 189-075-0 50-029-21959-00-00 PRUDHOE BAY UN LIS 1-3-01 SUSP 9/13/1994 287 FNL 550 FWL Sec 22 T 11 N R 15E UM 189-104-0 50-029-21978-00-00 PRUDHOE BAY UN LIS 1-4-02 SI 12/8/1994 2426 FSL 2176 FEL Sec 24 T 11 N R 15E UM 202-002-0 50-029-22789-01-00 PRUDHOE BAY UN NIA NK -11A SUSP 2/22/2002 1312 FSL 1021 FEL Sec 36 T 12 N R 15E UM 206-031-0 50-029-22668-01-00 PRUDHOE BAY UN NIA NK -14A SUSP 5/4/2007 1358 FSL 944 FEL Sec 36 T 12 N R 15 E UM 197-158-0 50-029-22778-01-00 PRUDHOE BAY UN NIA NK -41A SUSP 11/2/1997 1474 FSL 717 FEL Sec 36 T 12 N R 15E UM 202-052-0 50-029-23072-00-00 PRUDHOE BAY UN NWE 04-01 SUSP 4/7/2002 3203 FSL 4003 FEL Sec 20 T 12 N R 11 E UM Thursday, January 29, 2009 Operator Suspended, Shut In and Observation Wells BP EXPLORATION (ALASKA) INC Field Permit API Number Well Name Current Date of Status Status Surface Location .................................................... Lease(s)................................... 201-222-0 50-029-23054-00-00 PRUDHOE BAY UN ORIN V-201 SUSP 1/25/2008 4838 FSL 1775 FEL Sec 11 T 11 N R 11 E UM 191-037-0 50-029-22146-00-00 PRUDHOE BAY UN PTM 12 SUSP 4/30/1991 1359 FSL 980 FEL Sec 16 T 12 N R 14 E UM 192-082-0 50-029-22283-00-00 PRUDHOE BAY UN PTM P2-55 SUSP 10/12/1992 565 FNL 4052 FEL Sec 14 T 12 N R 14E UM 176-034-0 50-029-20208-00-00 PRUDHOE BAY UN WBH WBST-03 SUSP 7/26/1976 70 FSL 2000 FWL Sec 25 T 12 N R 14E UM 170-040-0 50-029-20076-00-00 PRUDHOE BAY UNIT 01-05 SUSP 5/25/2007 547 FNL 1420 FWL Sec 8 T 10 N R 15E UM 200-126-0 50-029-22202-02-00 PRUDHOE BAY UNIT 02-30B SUSP 7/6/2007 154 FNL 774 FWL Sec 36 T 11 N R 14 E UM 195-024-0 50-029-20096-01-00 PRUDHOE BAY UNIT 04-04A SUSP 4/17/1995 916 FNL 382 FEL Sec 34 T 11 N R 15E UM 187-082-0 50-029-21744-00-00 PRUDHOE BAY UNIT 07-27 SUSP 9/4/1994 952 FNL 497 FWL Sec 34 T 11 N R 14 E UM 182-207-0 50-029-20878-00-00 PRUDHOE BAY UNIT 13-98 OBSW 1/17/1983 1405 FSL 361 FWL Sec 13 T 10 N R 14E UM 201-148-0 50-029-20764-01-00 PRUDHOE BAY UNIT A -25A SUSP 11/22/2001 2651 FNL 1703 FEL Sec 35 T 11 N R 13E UM 178-054-0 50-029-20321-00-00 PRUDHOE BAY UNIT B-10 SUSP 4/10/2008 2070 FNL 1611 FEL Sec 31 T 11 N R 14 E UM 204-139-0 50-029-20654-02-00 PRUDHOE BAY UNIT E -18B SUSP 5/2/2008 1853 FNL 501 FEL Sec 6 T 11 N R 14 E UM 200-163-0 50-029-20600-01-00 PRUDHOE BAY UNIT G -13A SUSP 10/6/2008 2224 FNL 2368 FEL Sec 12 T 11 N R 13E UM 197-190-0 50-029-20487-01-00 PRUDHOE BAY UNIT H -10A SUSP 11/24/1997 1982 FNL 1264 FEL Sec 21 T 11 N R 13E UM 180-067-0 50-029-20484-00-00 PRUDHOE BAY UNIT H-12 SUSP 7/22/1994 1762 FNL 1264 FEL Sec 21 T 11 N R 13E UM 181-061-0 50-029-20591-00-00 PRUDHOE BAY UNIT H-15 SUSP 10/22/2004 1432 FNL 1265 FEL Sec 21 T 11 N R 13E UM 169-046-0 50-029-20026-00-00 PRUDHOE BAY UNIT J-04 OBSW 9/19/1975 970 FNL 1245 FEL Sec 9 T 11 N R 13E UM 100-242-0 50-029-21821-00-00 PRUDHOE BAY UNIT OWDW-C SUSP 6/23/1973 651 FNL 1048 FEL Sec 11 T 10 N R 14E UM 194-144-0 50-029-22522-00-00 PRUDHOE BAY UNIT R-36 SUSP 11/1/2000 782 FSL 3629 FEL Sec 32 T 12 N R 13E UM 191-123-0 50-029-20765-01-00 PRUDHOE BAY UNIT S -10A SUSP 11/6/1991 1644 FNL 1745 FWL Sec 35 T 12 N R 12E UM 204-071-0 50-029-20804-01-00 PRUDHOE BAY UNIT S -14A SUSP 12/18/2007 1651 FNL 2185 FWL Sec 35 T 12 N R 12E UM 180-108-0 50-029-20511-00-00 PRUDHOE BAY UNIT TR 18-11-12 SUSP 12/24/1980 809 FSL 3893 FEL Sec 7 T 11 N R 12E UM 180-066-0 50-029-20483-00-00 PRUDHOE BAY UNIT TR 3-10-12 SUSP 10/11/1980 1993 FNL 1479 FEL Sec 33 T 11 N R 12E UM 169-104-0 50-029-20047-00-00 PRUDHOE BAY UNIT TR PR 33-12-13 SUSP 12/20/1969 683 FNL 755 FEL Sec 33 T 12 N R 13E UM 178-102-0 50-029-20356-00-00 PRUDHOE BAY UNIT TW -C SUSP 4/25/1979 1320 FSL 1321 FEL Sec 3 T 11 N R 12E UM 192-011-0 50-029-22244-00-00 PRUDHOE BAY UNIT U-01 SUSP 3/16/1992 5134 FNL 2498 FEL Sec 18 T 11 N R 13E UM 204-102-0 50-029-21947-01-00 PRUDHOE BAY UNIT W -09A SUSP 8/7/2006 1437 FNL 1194 FEL Sec 21 T 11 N R 12 E UM 179-031-0 50-029-20369-00-00 PRUDHOE BAY UNIT WGI-01 SUSP 8/28/2006 258 FNL 1209 FEL Sec 11 T 11 N R 14E UM 188-115-0 50-029-21558-01-00 PRUDHOE BAY UNIT Y -22A SUSP 10/29/1988 1394 FNL 132 FEL Sec 33 T 11 N R 13E UM 208-140-0 50-029-21883-01-00 PRUDHOE BAY UNIT Y -25A SUSP 11/14/2008 1403 FNL 169 FEL Sec 33 T 11 N R 13 E UM 202-046-0 50-029-22403-01-00 PRUDHOE BAY UNIT Y -37A SUSP 3/31/2002 1425 FNL 276 FEL Sec 33 T 11 N R 13E UM Thursday, January 29, 2009 Operator Suspended, Shut In and Observation Wells BP EXPLORATION (ALASKA) INC Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... 169-014-0 50-029-20011-00-00 SAG DELTA 31-11-16 SUSP 4/28/1969 1102 FNL 1743 FEL Sec 31 T 11 N R 16 E UM 186-056-0 50-029-20138-01-00 W BEACH ST 1-A SUSP 5/6/1986 70 FSL 1880 FWL Sec 25 T 12 N R 14 E UM PT THOMSON 196-008-0 50-089-20026-00-00 SOURDOUGH 3 SUSP 4/24/1996 2245 FSL 5068 FEL Sec 29 T 9 N R 24 E UM Thursday, January 29, 2009 \`lei -C)3\ 1J j SARAH PALIN, GOVERNOR i l AllfIF= � ALASEL OIL AND � 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM2'►►IISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 January 28, 2009 FAX (907) 276-7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 5951 Harry Engel BP Exploration Alaska Inc. SWNRD OCT 1 3 2014, PO Box 196612 Anchorage AK 99519-6612 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Engel: Enclosed ate the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed are a list of suspended wells and a list of long term shut-in wells operated by BP Exploration Alaska Inc. For each list, please verify the information for each well, and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Tom Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, Cathy P. oerster Commissioner Enclosures K Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. ■, Print your name and address on the reverse so that we can return the card to you. E Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: Harry Engel BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 A. Sigr X Agent \ 0 Addressee B. Reeerved b �ame) Cate of De kery D. is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No rvice Type Certified Mail 0 Express Mail 0 Registered Return Receipt for Merchandise 0 Insured Mail 0 C.O.D. 4. Restricted Delivery? (Extra Fee) 0 Yes 2. Article Number (Transfer from service label) 7005 1820 0001 2499 5951 PS Form 3811, February, 2004 Domestic Return Receipt 102595-02-M-1540 Postal Service— CERTIFIED MAIL- RECEIPT Cr(Domestic Ln L V V E. ru poop $ $0.59 E3 C~1i 02.70 o a 1:3 $2.20 m ch a ®Owy Fee c� wa+.4 $0.00 �9c C2 CO rU S atop., r -q Pnst o. a w• $5.49 0 Ln Harry Engel a rtiriesiAvt Na;'� BP Exploration Alaska Inc. pPp eox Na _ PO Box 196612 �j; Mats, IJP+1. Anchorage AK 99519-6612 Operator Suspended and Shut In Wells BP EXPLORATION (ALASKA) INC Fleld Current Date of Permit API ]Number Well Name Status Status Surface Location .................................................... Lease(s)................................... *EXPLORATORY 198-252-0 50-089-20027-00-00 RED DOG 1 ENDICOTT 196-022-0 50-029-22644-00-00 DUCK IS UNIT MPI 1-59/024 MILNE POINT 196-009-0 50-029-22642-00-00 199-091-0 50-029-21373-01-00 185-110-0 50-029-21364-00-00 196-032-0 50-029-22650-00-00 197-080-0 50-029-22766-00-00 201-109-0 50-029-22768-01-00 201-075-0 50-029-23012-00-00 NORTHSTAR 200-211-0 50-029-22996-00-00 206-138-0 50-029-23325-00-00 PRUDHOE BAY MILNE PT UNIT KR B-24 MILNE PT UNIT KR C -12A MILNE PT UNIT KR C-16 MILNE PT UNIT KR K-25 MILNE PT UNIT KR L-34 MILNE PT UNIT KR L -35A MILNE PT UNIT SB I-13 NORTHSTAR UNIT NS -26 NORTHSTAR UNIT NS -33 SUSP 4/2/1999 1682 FSL 4508 FEL Sec 34 T 10 N R 21 E UM ADL0377013 SUSP 2/21/1996 3083 FSL 2202 FEL Sec 36 T 12 N R 16E UM ADL0312828 SUSP 3/3/1996 827 FSL 4289 FEL Sec 18 T 13N R 11 E UM ADL0047432 SUSP 7/13/2003 496 FSL 2027 FEL Sec 10 T 13N R 10 E UM ADL0047434 SUSP 10/27/1993 610 FSL 2063 FEL Sec 10 T 13N R 10E UM ADL0047437 SUSP 3/23/1996 3592 FSL 2078 FEL Sec 3 T 12 N R 11 E UM ADL0375133 SUSP 12/1/2008 3285 FSL 5106 FEL Sec 8 T 13N R 10E UM ADL0025514 SUSP 10/12/2002 3177 FSL 4937 FEL Sec 8 T 13 N R 10E UM ADL0025514 SUSP 8/19/2001 2346 FSL 1253 FWL Sec 33 T 13N R 10E UM ADL0025517 SUSP 2/1/2001 1298 FSL 648 FEL Sec 11 T 13N R 13E UM ADL03 12799 SUSP 4/26/2007 1369 FSL 650 FEL Sec 11 T 13N R 13E UM ADL0321798 180-092-0 50-029-2:0504-00-00 PBU MP 11-33-11-12 1 SUSP 4/29/1981 1966 FNL 1380 FEL Sec 33 T 11 N R 12E UM ADL0047A52 198-035-0 50-029-22866-00-00 PRUDHOE BAY UN BORE 02-01 SUSP 4/22/1998 453 FSL 4553 FWL Sec 19 T 12 N R 11 E UM ADL0047446 205-010-0 50-029-23245-00-00 PRUDHOE BAY UN BORE 1-100 SUSP 4/17/2006 3219 FSL 3945 FEL Sec 20 T 12 N R 11 E UM ADL0047446 189-075-0 50-029-21959-00-00 PRUDHOE BAY UN LIS 1-3-01 SUSP 9/13/1994 287 FNL 550 FWL Sec 22 T 11 N R 15E UM ADL0034631 189-104-0 50-029-21978-00-00 PRUDHOE BAY UN LIS 1-4-02 SI 12/8/1994 2426 FSL 2176 FEL Sec 24 T 11 N R 15E UM ADL0028323 202-002-0 50-029-22789-01-00 PRUDHOE BAY UN NIA NK -11A SUSP 2/22/2002 1312 FSL 1021 FEL Sec 36 T 12 N R 15E UM ADL0034629 206-031-0 50-029-22668-01-00 PRUDHOE BAY UN NIA NK -14A SUSP 5/4/2007 1358 FSL 944 FEL Sec 36 T 12 N R 15E UM ADL0034625 197-158-0 50-029-22778-01-00 PRUDHOE BAY UN NIA NK -41A SUSP 11/2/1997 1474 FSL 717 FEL Sec 36 T 12 N R 15E UM ADL0312827 202-052-0 50-029-23072-00-00 PRUDHOE BAY UN NWE 04-01 SUSP 4/7/2002 3203 FSL 4003 FEL Sec 20 T 12 N R 11 E UM ADL0047446 201-222-0 50-029-2.3054-00-00 PRUDHOE BAY UN ORIN V-201 SUSP 1/25/2008 4838 FSL 1775 FEL Sec 11 T 11 N R 11 E UM ADL0028240 191-037-0 50-029-22146-00-00 PRUDHOE BAY UN PTM 12 SUSP 4/30/1991 1359 FSL 980 FEL Sec 16 T 12N R 14 E UM ADL0375136 Wednesday, Jan«aty 14, 2009 ADL0034630 ADL004744 ,7 Operator :suspended and Shut In Wells BP EXPLORATION (ALASKA) INC Field Permit. API Number Well Name Current Date of Status Status Surface Location .................................................... Lease(s)................................... 192-082-0 50-029-22283-00-00 PRUDHOE BAY UN PTM P2-55 SUSP 10/12/1992 565 FNL 4052 FEL Sec 14 T 12 N R 14E UM ADI -0034622 176-034-0 50-029-20208-00-00 PRUDHOE BAY UN WBH WBST-03 SUSP 7/26/1976 70 FSL 2000 FWL Sec 25 T 12 N R 14 E UM ADL0034627 170-040-0 50-029-20076-00-00 PRUDHOE BAY UNIT 01-05 SUSP 5/25/2007 547 FNL 1420 FWL Sec 8 T 10 N R 15E UM ADL0028328 200-126-0 50-029-22202-02-00 PRUDHOE BAY UNIT 02-30B SUSP 7/6/2007 154 FNL 774 FWL Sec 36 T 11 N R 14E UM ADL0028308 195-024-0 50-029-20096-01-00 PRUDHOE BAY UNIT 04-04A SUSP 4/17/1995 916 FNL 382 FEL Sec 34 T 11 N R 15E UM ADL0028324 187-082-0 50-029-21744-00-00 PRUDHOE BAY UNIT 07-27 SUSP 9/4/1994 952 FNL 497 FWL Sec 34 T 11 N R 14 E UM ADL0028309 201-148-0 50-029-20764-01-00 PRUDHOE BAY UNIT A -25A SUSP 11/22/2001 2651 FNL 1703 FEL Sec 35 T 11 N R 13E UM ADL0028286 178-054-0 50-029-20321-00-00 PRUDHOE BAY UNIT B-10 SUSP 4/10/2008 2070 FNL 1611 FEL Sec 31 T 11 N R 14 E UM ADL0028313 204-139-0 50-029-20654-02-00 PRUDHOE BAY UNIT E -18B SUSP 5/2/2008 1853 FNL 501 FEL Sec 6 T 11 N R 14 E UM ADL0028304 200-163-0 50-029-20600-01-00 PRUDHOE BAY UNIT G-1 3A SUSP 10/6/2008 2224 FNL 2368 FEL Sec 12 T 11 N R 13E UM ADL0028304 197-190-0 50-029-20487-01-00 PRUDHOE BAY UNIT H -10A SUSP 11/24/1997 1982 FNL 1264 FEL Sec 21 T 11 N R 13 E UM ADL0028283 180-067-0 50-029-20484-00-00 PRUDHOE BAY UNIT H-12 SUSP 7/22/1994 1762 FNL 1264 FEL Sec 21 T 11 N R 13E UM ADL0028283 181-061-0 50-029-20591-00-00 PRUDHOE BAY UNIT H-15 SUSP 10/22/2004 1432 FNL 1265 FEL Sec 21 T 11 N R 13E UM ADL0028283 100-242-0 50-029-21821-00-00 PRUDHOE BAY UNIT OWDW-C SUSP 6/23/1973 651 FNL 1048 FEL Sec 11 T 10 N R 14 E UM ADL0028311 194-144-0 50-029-22522-00-00 PRUDHOE BAY UNIT R-36 SUSP 11/1/2000 782 FSL 3629 FEL Sec 32 T 12 N R 13E UM ADL0028279 191-123-0 50-029-20765-01-00 PRUDHOE BAY UNIT S -10A SUSP 11/6/1991 1644 FNL 1745 FWL Sec 35 T 12 N R 12 E UM ADL0028257 204-071-0 50-029-20804-01-00 PRUDHOE BAY UNIT S -14A SUSP 12/18/2007 1651 FNL 2185 FWL Sec 35 T 12 N R 12E UM ADL0385193 180-108-0 50-029-20511-00-00 PRUDHOE BAY -UNIT TR 18-11-12 SUSP 12/24/1980 809 FSL 3893 FEL Sec 7 T 11 N R 12E UM ADL0028262 180-066-0 50-029-20483-00-00 PRUDHOE BAY UNIT TR 3-10-12 SUSP 10/11/1980 1993 FNL 1479 FEL Sec 33 T 11 N R 12E UM ADL0047454 169-104-0 50-029-20047-00-00 PRUDHOE BAY UNIT TR PR 33-12-13 SUSP 12/20/1969 683 FNL 755 FEL Sec 33 T 12 N R 13E UM ADL0028278 178-102-0 50-029-20356-00-00 PRUDHOE BAY UNIT TW -C SUSP 4/25/1979 1320 FSL 1321 FEL Sec 3 T 11 N R 12E UM ADL0028261 192-011-0 50-029-22244-00-00 PRUDHOE BAY UNIT U-01 SUSP 3/16/1992 5134 FNL 2498 FEL Sec 18 T 11 N R 13E UM ADL0028283 204-102-0 50-029-21947-01-00 PRUDHOE BAY UNIT W -09A SUSP 8/7/2006 1437 FNL 1194 FEL Sec 21 T 11 N R 12E UM ADL0047453 179-031-0 50-029-20369-00-00 PRUDHOE BAY UNIT WGI-01 SUSP 8/28/2006 258 FNL 1209 FEL Sec 11 T 11 N R 14 E UM ADL0028302 188-115-0 50-029-21558-01-00 PRUDHOE BAY UNIT Y -22A SUSP 10/29/1988 1394 FNL 132 FEL Sec 33 T 11 N R 13E UM ADL0028288 208-140-0 50-029-21883-01-00 PRUDHOE BAY UNIT Y -25A SUSP 11/14/2008 1403 FNL 169 FEL Sec 33 T 11 N R 13E UM ADL0028287 ADL0028282 202-046-0 50-029-22403-01-00 PRUDHOE BAY UNIT Y -37A SUSP 3/31/2002 1425 FNL 276 FEL Sec 33 T 11 N R 13E UM ADL0028287 ADL0047471, 169-014-0 50-029-20011-00-00 SAG DELTA 31-11-16 SUSP 4/28/1969 1102 FNL 1743 FEL Sec 31 T 11 N R 16E UM ADL0028343 186-056-0 50-029-20138-01-00 W BEACH ST 1-A SUSP 5/6/1986 70 FSL 1880 FWL Sec 25 T 12 N R 14E UM ADL0034628 PT THOMSON Wednesday, Amman- 14, 2004 Operator Suspended and Shut In Wells BP EXPLORATION (ALASKA) INC Field Current Date of Permit API Number Well Name Status Status Surface Location ................................................... Lease(s)..................... ..... . 196-008-0 50-089-20026-00-00 SOURDOUGH 3 SUSP 4/24/1996 2245 FSL 5068 FEL Sec 29 T 9 N R 24 E UM ADL0343112 Wednesday, January 14, 2009 °~~~k ~ ~ ~ ~-_ ~~ C01~5~RVA ATIO C01- II5SIp1S~T Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 r-- 4;r:1 ( t ~ 1 : r. FE. SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool; PBU WGI-01 BP Exploration Alaska Inc. Permit No: 179-031 ~Ir--- Well Status Change Dear Mr. Hobbs: Permit to drill 206-117 for WGI-0lA was issued by the Commission on August 4, 2006. Since drilling operations were never begun, this permit expired on August 4, 2008 in accordance with 20 AAC 25.005 {g). In anticipation of drilling WGI-OlA, the completed interval within WGI-O1 was plugged effective August 28, 2006. The Well Completion and Recompletion Report (Form 10-407) that BP filed to document that work listed the status of the well as Plugged and Abandoned; however this status is in error since the redrill never occurred. Accordingly, the status of WGI-Ol has been changed from Plugged and Abandoned to Suspended with the effective date of August 28, 2006. If you have any questions regarding this matter, please contact Tom Maunder, P.E., at 793-1250. G 9~C~ ~ ` Sincerely, ~~ ~ Daniel T. Seamount, Jr. ~, J Chair DATED this ~~ day of October, 2008 cc: Ms. Terrie Hubble, BP Exploration ~ ~~; f~ ~:. 1 ~ 2008 life; lðl06/~ RECEIVED . STATE OF ALASKA _ ALASKAOILANDGASCONSERVATIONCOM~ION SEP 27 2006 WELL COMPLETION OR RECOMPLETION REPORT AND AIAfft. Oil & Gas C C '. ons. ommlsslon An .L 1 a. Well Status: DOil DGas D Plugged ~ Abandoned D Suspended DWAG 1 b. Well Class: - 20AAC 25.105 20AAC 25.110 D Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic ~ Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 8/28/2006 179-031 306-246 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 07111/1979 50-029-20369-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 07/28/1979 PBU WGI-01 258' FNL, 1209' FEL, SEC. 11, T11N, R14E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 1945' FSL, 1811' FEL, SEC. 02, T11N, R14E, UM 49' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 2352' FSL, 1796' FEL, SEC. 02, T11N, R14E, UM 7984 + 7536 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ TVD) 16. Property Designation: Surface: ' x- 684986 y- 5972003 Zone- ASP4 9335 + 8643 Ft ADL 028302 TPI: x- 684328 y- 5974191 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 684332 y- 5974599 Zone- ASP4 N/A MD DYes ~No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey N/A MSL 1900' (Approx.) 21. Logs Run: OIL, SP, BHCS, CAL, GR, FDC, CCL 22. CASING, LINER AND CEMENTING RECORD > >("/.2. ) . , ." SSTTINGDspT!i MD SETTING DÈPTHrVlÌ ........ .} ·······!;·j>S»;;{?j·j?>;/ ...... >;>0S~'> . ......;... ··iw.r,PEI'{FE>· IGFW,E .. lOP> BOTtoM Top BOTTOM ·isii¡;!·· ." .!...;................... ·.>..Z ...;;.!;.!.> ........ >;.;:2"77 . '..} I.} } 20" 94# H-40 Surface 103' Surface 103' 30" 330 sx Arctic Set 13-3/8" 72# N-80 Surface 2731' Surface 2731' 17-1/2" 4760 sx Arctic Set II 9-5/8" 47# N-80 Surface 8314' Surface 7822' 9-5/8" 500 sx Class 'G' 375 sx Arctic Set I 7" 29# N-80 8019' 9334' 7566' 8643' 8-1/2" 355 sx Class G 23. Perforations open to Production (MD + TVD of Top and 124. .; ........;..>·Z!.>/· ." . '" .»;; .>;·Y.>;!>'.W!> ;;> >... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 7" x 7-5/8",29# x 29.7#, L-80 7823' 7795' MD TVD MD TVD 7",29#, N-80 7902' - 7921' 7902' [25. . Ãêlp,r·· ..... }}. ;'. ..;·;Y> (>};..;;.?;.;..; .)' ..... ;i .' H/Z..·;};<; GC/~f~·t~f:f¡ <, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED l,:; 7984' P&A with 46 Bbls Class 'G' 26. PRODUCTION TEST Date First ProductiQn,' 'ft' ',~~~ --"'~-->""'-' Method of Operation (Flowing, Gas Lift, etc.): Not on Injection N/A Date ofT est Hours Tested PRODUCTION FOR OIL -BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED OIL -BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE'" 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RBDMS 8Ft 0 C1 fI 3 2006 None Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE OR\G1NÞ,.L. G 28. GEOLOGIC MARKER 29. RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Sadlerochit 8680' 8130' None Base of Sadlerochit 9248' 8576' 30. List of Attachments: Well Schematic Diagram and a Pre-Rig Summary. 31. I hereby certify that the foreg~ing_i~,.true and correct to the best of my knowledge. Signed Sondra _, Title Technical Assistant PBU WGI-01 Well Number Date l'-~f=i ll- t,) roval No. Prepared By NameINumber: Sondra Stewman, 564-4750 Drilling Engineer: INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Digital Wellfile . Page 1 of 1 . Well Events for SurfaceWell - WGI-Ol Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> FS1 -> WGI -> WGI-01 Date Range: 14/Aug/2006 to 27/Sep/2006 Data Source(s): DIMS, AWGRS Events Source AWGRS AWGR5 AwGRS AWGRS AWGR5 AWGRS AWGRS Well WGI-01 WGI-01 Date 09/06/2006 09/05/2006 WGI-01A 09/03/2006 WGI-01A 09/02/2006 WGI-01 WGI-01 WGI -01 09/02/2006 08/30/2006 08/28/2006 AWGRS WGI-01 08/28/2006 AWGRS WGI-01 08/27/2006 AWGRS WGI-01 08/25/2006 AWGRS AWGRS AWGRS WGI-01 WGI-01 WGI-01 08/20/2006 08/19/2006 08/14/2006 Description ** WELL SHUT IN UPON ARRIVAL ** {pre rwo} NOTE: KNOWN PC LEAK leak @ 6430' (2/9/03) SET DSSSV @ 2169' SLM (OVERSIZED PACKING ON EACH SIDE OF 0- RING) MIT-T 3500 PSI, PASSED. T/IA/OA=3500/650/150. LOST 15/25/0 -15 MIN, 65/50/0 -30 MIN, 0/35/0 -45 MIN. FINAL 3420/490/150 BLED TBG TO 500 PSI & PULLED DSSSV FROM 2169' SLM. ** TURNED WELL OVER TO DSO, LEFT T/I/O= 1000/1020/180 Temp= 5/1 MIT T** FAILED** to 3500 psi (RWO PREP) Pressured up Tbg w/4 bbls 60/40 meth water to reach 3500 psi. 2ndtest results- 1st 15 min lost 220 psi, 2nd 15 min lost 160 psi with a total of 380 psi in 30 min test. Bled back 5 bbls 60/40 meth. Final WHP's= 800/500/160 ***WSR CONTINUED FROM 9-02-2006***(Pre Sidetrack) ATTEMPTED TO DO A 3,500 PSI TEST ON CEMENT PLUG ONLY GOT TO APPROX. 1,SOOPSI ON TUBING DUE TO TRIPLEX FAILURE NOTE:----TAGGED TRIPLEX W/ INFO & NOTIFIED 813 OF PROBLEM W/ TRIPLEX ****LEFT WELL SHUT-IN, NOTIFIED DSO OF WELL STATUS**** **** WELL SHUT IN **** (Post Sdtrk) ASSIST FIELD CREW ON PULLING 7" BPV. DRIFTED WITH 3.50" CENT., T.E.L., AND SAMPLE BAILER TO CEMENT TOP. LOCATED TUBING TAIL @ 7,878' SLM. (32' HIGHER THAN ELMD @ 7,910' SLM) AND TAGGED CEMENT TOP @ 7,952' SLM (+32 = 7984" CORRECTED TD) (SAMPLE BAILER WAS FULL OF CEMENT) DRIFTED WITH 7" PRS (5.65" O.D.) FOR CHEM CUT & TAGGED RN NIPPLE @7,800' SLM. (14' HIGHER THAN MD) (TARGET DEPTH OF CUT IS +-6500') TUBING IS CLEAR OF OBSTRUCTIONS. ****JOB STILL IN PROGRESS, WSR CONTINUED ON 9-03-2006**** PULLED BPV FOR SLICKLINE SET BPV, PRE RIG CTU #6, P&A; Continue from WSR 8-27-06 ... Lube and bleed IA to fluid pack. Load and kill well with 1% KCL. RIH with BDN assy. Could not get into 7" liner. POOH. Re-configure BHA, RBIH. Tagged PBTD at 9192' ctmd. Based on previous run referenced to liner top, CT depths are within l' of ELMD. Flag pipe at 9182' and continue pumping KCL down coil to stabilize BHT. Well goes on slight vac when pumping is shut down. Pump 215 bbls of diesel down backside to establish positive WHP of 150 psi. Pump 46 bbls of 15.8 ppg cement. Lay in cement from 9182'. Good returns. Estimate 3 bbls lost to perfs, putting TOC at approx. 8100'. POOH maintaining 300 psi WHP. Circulate in 50/50 meth for freeze protect from 2500'. Left well shut in with 300 psi WHP. Lube and bleed additonal 5 bbls of diesel into IA. *** Job Complete *** T/I/0=1800/1900/50 Assist coil tbg (RWO prep) Pump as directed. Pump 30 bbls of 1% KCL followed by 10 bbls of 50/50 methanol, followed by 73 bbls of 1 % KCL and a 5 bbls 50/50 methanol cap down the IA. Final WHP's = 0/700/200 CTU #6 Pre Rig P&A Safety meeting, PT surface equipment. Change-out 2 block valves on reverse-out skid #78073. *****Continue on WSR 8-28-06***** TIO = ??/2400/160. Temp = SI. WHPs, TBG & IA FL (pre-CTU). IA FL @ 4070' (?? bbls). Unable to get TBGP or TBG FL as the well house and climbing platform have been removed from the well; the tree cap platform remains and is 14' off of the ground with no ladder attached. The master valve is locked SI. The SSV is stroked closed (SSV can be accessed with a temporary ladder). *** CONT FROM 08-19-06 WSR *** (pre p&a/sdtrk) PULLED 7" PRN PLUG BODY FROM RN NIP @ 7803' SLM, DRIFTED W/ 4.50 CENT, TEL & SAMPLE BAILER, UNABLE TO LOC TI, LOC BOTTOM OF 7" SHEAR OUT SUB @ 7898' SLM +12' CORR= 7910' ELMD, TAG STICKY BOTTOM @ 9127' CORR ELMD ( BTM PERF- 9228' - 101' FILL).M/T BAILER. *** DSO NOTIFIED OF WELL STATUS, WELL LEFT SI *** ***WELL S/I ON ARRIVAL *** SSV BLOCKED IN @ TREE (pull ttp, p&a/sdtrk) PULLED PRONG FROM PRN PLUG BODY @ 7797' SLM, MADE ONE ATTEMPT W/ GR TO PULL PLUG BODY @ 7803' SLM, ( TOOL SHEARED), RIH TO PULL W/ GS @ REPORT TIME. *** JOB IN PROGRESS/ CONT ON 08-20-06 WSR *** T/IA/OA = SI/O/O (Pre Rig Inspection) PPPOT-IC = PASSED PPPOT-T = PASSED Bled inner casing hanger packoff void to 0 psi. Torqued lockdowns to 550 ft/lbs. Rigged up test equipment and tested to 3,800 psi. for 30 mins. - Passed. Bled tubing hanger void to 0 psi. Torqued lockdowns to 550 ft/lbs. Rigged up test equipment and tested void to 5,00 psi. for 30 mins. - Passed. http://digitalwellfile. bpweb. bp.comIW ellEvents/Home/Default.aspx 9/27/2006 TREE = WB...LHEAD '¡' ACTUATOR = KB. B...EV = BF. B...EV = KOP = 3500' Max Angle = 39 @ 9200' Datum MD = ? Datum TVD = 8800' SS IT' TBG, 29.0#, L-80, 0.0371 bpf, 10 = 6.184" . WGI-01 GRAY GRAY AXB...SON 49' 17-5/8" TBG-IPC, 29.7#, L-80, .0459 bpf, 10 = 6.875" TOP OF 7" TBG I 17" TBG, 29#, L-80, .0371 bpf, 10 = 6.184" I I TOP OF 7-5/8" TBG I 113-3/8" CSG, 72#, N-80, 10 = 12.347" I Minimum ID = 4.845" @ 7920' BAKER SHEAROUT SUB . 17-5/8" TBG-IPC, 29.7#, L-80, .0459 bpf, 10 = 6.875" I TOPOF 7" TBG I 17" TBG, 29#, L-80, .0371 bpf, 10 = 6.184" I I TOP OF 7" TBG I 7902' 17" TBG, 29#, N-80, .0371 bpf, 10 = 6.184" I 7921' 8019' elm 19-5/8" CSG, 47#, N-80, 10 = 8.681" I 8314' ÆRFORA TION SUMMARY REF LOG: BHCS ON 07/29/79 ANGLEATTOPÆRF: 38 @ 8695' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE See Perforation Data on Page 2 9292' 9334' 17" LNR, 29#, N-80, .0371 bpf, 10=6.184" I DATE 08/07/79 08/11/97 11/03/01 03/22/03 12/11/05 12/13/05 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER RN/TP CORRECTIONS JM'KAK PULL IBP ???/TLH SET TIP RPH/TLH WAIVER SFTY NOTE DB...ETED 2182' 2' -i 7" X 7-5/8" XO I -i 7-5/8" X 7" XO I 2183' -i 1" CAM BAL-O SSSV NIP, 10 = 5.937" I 2187' -i 1" X 7-5/8" XO I 7795' 7801' 7814' -17" TUBING TAIL WLEG I 7902' -i 9-518" X 7" BKR SB-2 A<R I 7920' 7" BKR SHEA ROUT SUB (NO TAILPlÆ) 10 = 4.845" 7910' H B...MD TI LOGGED 08/07/79 8100' -iESTIMATEDTOC I DA TE REV BY COMMENTS 12/31/05 lWS/TLH TIP PLUG PULLED (12/19/05) 08/28/06 SRB/PAG P&A; SQZ ÆRFS PRUDHOE BA Y UNIT WB...L: WGI-01 ÆRMIT No: '1790310 API No: 50-029-20369-00 SEC 11, T11 N, R14E, 1795.18' & FB... 2926.14' FNL BP Exploration (Alaska) . ÆRFORA TION SUMMARY REF LOG: SHCS ON 07/29/79 ANGLEATTOPÆRF: 38 @ 8695' Note: Refer to Production DS for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8695-8725 S 08/28/06 3-3/8" 4 8725-8745 S 08/28/06 3-3/8" 4 8745-8785 S 08/28/06 3-3/8" 4 8785-8797 S 08/28/06 3-3/8" 4 8813-8853 S 08/28/06 3-3/8" 4 8853-8907 S 08/28/06 3-3/8" 4 8907-8917 S 08/28/06 3-3/8" 4 8934-8954 S 08/28/06 3-3/8" 4 8954-8983 S 08/28/06 3-3/8" 4 8983-9003 S 08/28/06 3-3/8" 4 9008-9018 S 08/28/06 3-3/8" 4 9024-9034 S 08/28/06 3-3/8" 4 9040-9048 S 08/28/06 3-3/8" 4 9048-9058 S 08/28/06 3-3/8" 4 9074-9082 S 08/28/06 3-3/8" 4 9082-9102 S 08/28/06 3-3/8" 4 9102-9122 S 08/28/06 3-3/8" 4 9122-9142 S 08/28/06 3-3/8" 4 9143-9151 S 08/28/06 3-3/8" 4 9156-9162 S 08/28/06 3-3/8" 4 9162-9182 S 08/28/06 3-3/8" 4 9208-9228 S 08/28/06 DATE 08/07/79 08/11/97 11/03/01 03/22/03 12/11/05 12/13/05 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER RN/TP CORRECTIONS JM1KAK PULL IBP ???/TLH SET TIP RPH/TLH WAr-/ER SFTY NOTE DELETED WGI-01 . DA TE REV BY COMMENTS 12/31/05 TWS/TLH TIP PLUG PULLED (12/19/05) 08/28/06 SRB/PAG P&A; SQZ ÆRFS . 8100' -i ESTlMA TED TOC I PRUDHOE BA Y UNIT WELL: WGI-01 ÆRMIT No: "1790310 API No: 50-029-20369-00 SEe 11, T11 N, R14E, 1795.18' & FEL 2926.14' FNL BP Exploration (Alaska) - \.- .- - -, ~~'.h_~"\' ._ . .-"""'/) Winton, Jim and Bob, Please see the attached MIT forms for the following wells: ,"'. ,/ PBU 03-10: CMIT-IAxOA for Waiver compliance'¡ !-etý / 7 '"' ) PBU 04-08: MITIA to evaluate the well for an IAxOA AA and waiver ~PBU R-25A: MITIA Pre-dewatering G ~Z!4<5-, /a55 /~PBU 04-13: MITIA Pre MI swap ¡ Zé~c; ) y/PBU P1-25: MITIA Pre MI swap (t ¡ "i I" c( .~... ',r)a.::;.:s /PBU $-101: MITIA Pre MI swap 1\(-Z3 lCC3' :;:..'> ¡_A"BU NK-13: M!TIA for UIC Compliance, Chuck Scheve witnessed ·~/2''"\_'J:. /' ,./ihe MIT form for PBU X-36 (PTD #1961670) was emailed by Anna Dube on 9/10/06. If you need an additional copy or did not receive the email, I will gladly send it again. Thank you for your patience, «MIT PBU $-101 11-23-03.xls» «MIT GPMA P1-25 09-06-06.xls» «MIT PBU 04-13 08-10-03.xfs» «MIT PBU 04-08 08-04-05.xls» «MIT PBU R-25A 06-12-05.xfs» «MIT PBU 03-10 09-30-05.xls» «MIT PBU NK-13 09-19-06.xls» Andrea Hughes (Filling in for Joe Anders) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~CA~NE~J; SEP 2 ~ 2005 Hi Jim, Thank you for the note. To update you on MITs that are _ 1) PEU 04-13; due 1/8/2006 /2) PBU S-101; due 2/25/2006 3) PEU NK-13; due 5/4/2006 ...4) PBU X-36; due 5/20/2006 ,5) PEU R-25A; due 7/24/2006 past due: Completed Completed Completed Completed Completed 8/10/03 11/23/03 9/Ð/06 9/5/06 - 6/12/05 Sent in earlier e-mail We agree to schedule MITs on the following wells once on injection: Iof4 9/25/2006 9: 15 AM __ ._,.._ ..,__.v/,v. _~\'.~ "~v,v.'~~"\. 'L/"'./... 1) MPU H-06¡ due 2/28/2006 (SI since 7/2002) returned to injection 2) PEU WGI-01¡ due 4/22/2006 (SI since 12/12/2005) Sidetrack later this year 3) MPU F-41¡ due 5/14/2006 (SI since 5/2005) returned to injection 4) PBU S-31A¡ due 6/1/2006 (SI since 12/2004) Workover _ 5) PBU P1-01¡ due 6/4/2006 (SI since 6/2006 for workover) A patch to restore integrity is planned. Scheduel when returned to injection . Schedule when Schedule post Rig Schedule when Schedule post Rig j 6) PEU Pl-25¡ due 7/2/2006 (SI since 6/2006) 7) PEU GC-02C¡ due 7/22/2006 (81 since 4/2006) returned to injection, estimated some time in '07. Completed 9/6/06 Schedule when Others /1) PBU 03-10; MIT 9/30/2005 (CMIT IAxOA) 2) PEU 04-08¡ MITs (IA and OA) doneper monthlyinjector rpt¡ date unknown- ',' this well is currently 81 with an AA and Waiver being drafted. I apologize for this office dropping the ball on these wells. Thank you for your patience in this matter, Ron Wilson WI Tech 659-5524 ------------------------------ We have recently completed a mid year review of MIT data from our inspection database to see how many injection wells may be in question regarding MIT timing. Results of our review relating to BP-operated fields are as follows: MITs are past due for the following wells (injecting as of 7/31/2006) 1) PBU 04-13¡ due 1/8/2006 2) PEU S-101¡ due 2/25/2006 3) PBU NK-13¡ due 5/4/2006 4) PEU X-36¡ due 5/20/2006 5) PEU R-25A¡ due 7/24/2006 The following shut in wells are past their due date for MIT 1) MPU H-06¡ due 2/28/2006 (81 since 7/2002) 2) PEU WGI-01¡ due 4/22/2006 (81 since 12/12/2005) 3) MPU F-41¡ due 5/14/2006 (SI since 5/2005) 4) PEU 8-31A¡ due 6/1/2006 (81 since 12/2004) 5) PBU P1-01¡ due 6/4/2006 (81 since 6/2006 for workover) 6) PEU P1-25¡ due 7/2/2006 (81 since 6/2006) 7) PEU GC-02C; due 7/22/2006 (81 since 4/2006) A MIT for each well injecting on the list should be conducted as soon as practical¡ please notify the Commission for an opportunity to witness. Regarding 81 injectors, the Commission suggests deferring testing (at least 20f4 9/25/2006 9: I 5 AM ..,.." . .....".. ..,. w....".."""" ,~.". . the Commission's witnessed test) until injection is recommenced and well conditions have stabilized. There's also two wells with MITs that have apparently been done (not witnessed) that we would like to have for our database: 1) PBU 03-10; MIT 9/30/2005 (CMIT IAxOA) 2) PBU 04-08; MITs (IA and OA) done per monthly injector rpt¡ date unknown As with all operating companies, the Commission is willing to work with you to take advantage of operating efficiencies in scheduling MITs (perform multiple MITs per pad¡ perform tests during the more temperate months; etc.). Feel free to call if you have any questions, and thank you in advance for your prompt attention to those MITs that are past due. Jim Regg AOGCC Content-Description: MIT PBU 8-101 11-23-03.xls MIT PBU S-10111-23-03.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT GPMA Pl-25 09-06-06.xls MIT GPMA Pl-25 09-06-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 04-13 08-1O-03.xls MIT PBU 04-13 08-10-03.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU 04-08 08-04-05.xls MIT PBU 04-08 08-04-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: MIT PBU R-25A 06-12-05.xls MIT PBU R-25A 06-12-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 3 of 4 9/25/2006 9: I 5 AM V.J I V \.1. I. '-' , , /v"'''' vj, v.,.-vv \. . 1./ 'n I VV 1 v."-.....In \. ,1./ ""' Y... . Content·Description: MIT PBU 03-10 09-30-05.xls MIT PBU 03-10 09-30-05.xls Content-Type: application/vnd.ms-excel Content·Encoding: base64 Content-Description: MIT PBU NK-13 09-19-06.xls MIT PBU NK-13 09-19-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 4 of 4 9/25/2006 9: I 5 AM e e FRANK H. MURKOWSKI, GOVERNOR ALASIiA. OIL AND GAS CONSERVATION CO.MMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU WGI-01 Sundry Number: 306-246 SCANNED "IUL 2 4: 2005 Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ Cathy P. Foerster Commissioner . Zlsf DATED this_ day of July, 2006 Encl. r70¡ -03/ . , 2 5.28 AI"" ,,, nil R., r,~!: r.nns. 10 1. Type of Request: 181 Abandon / o Suspend o Operation Shutdown o Perforate o Time ExtensioAnchorage o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development o Exploratory 179-031 / 3. Address: o Stratigraphic ~ Service 6. API Number: / P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20369-00-00 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: PBU WGI-01 / Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028302 49' Prudhoe Bay Field / Prudhoe Bay Pool ~4'/' ./> ·.'x /i//x,;/// ./ ..... '. ., '. ................. .../</// <;xFF<;).,·· ···..«..<.;·../«;/x// //>.. Total Depth MD ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9335 8643 9292 8610 None None Casino Lenoth Size MD / TVD Burst Collaose Structural Conductor 103' 20" 103' 103' 1530 520 Surface 2731' 13-3/8" 2731' 2731' 4930 2670 Intermediate 8314' 9-5/8" 8314' 7822' 6870 4760 Production Liner 1315' 7" 8019' - 9334' 7566' - 8643' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: /' Tubing Grade: Tubing MD (ft): 8695' - 9228' / 8142' - 8560' 7",29# & 7-5/8",29.7# L-80 & N-80 7823' & 7902' - 7921 Packers and SSSV Type: 9-5/8" x 7" Baker 'SB-2' packer; I Packers and SSSV MD (ft): 7902' /' 9-5/8" x 7" Baker 'SAB' packer 7795' 13. Attachments: 14. Well Class after proposed work: / ~ Description Summary of Proposal o BOP Sketch o Exploratory o Development ~ Service o Detailed Operations Program 15. Estimated Date for JUI"A006 16. Well Status after proposed work: Commencing Operations: o Oil o Gas o Plugged ~ Abandoned 17. Verbal Approval: [)àfé: o WAG OGINJ OWINJ o WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phil Smith, 564-4897 Printed Name D9)le Wesley Title Senior Drilling Engineer Lr..,-.I"'1 SlUR Signature ,,/Þ';,. /ß LÇ!- Date ?¡{'7~~ Prepared By Name/Number: Phone 564-5153 Terrie Hubble, 564-4628 ~...... -j( . Commission Use On Iv I Sundry Number: ê:OúJ - ~ Conditions of approval: Notify Commission so that a representative may witness ~Plug Integrity œ-BOPTest o Mechanical Integrity Test o Location Clearance Other: T -e.. s t- ISO eE +0 4liOO JOtA. At) p WJ \.I ~ d ~ "/.A.A- to - 4-01 ~M~d ~I -Ç.; k fv~i¿ ¡,v../! II \.t.Jt:¡I - DIIt-. Subsequent Form Required: lo- 4-01. Approved Bv: /J.It.. ¡J ~J.e--. APPROVED BY Date 7 -2/ -{)h COMMISSIONER THE COMMISSION Form 10-403 Reviseçt' 06/20Ó6 Submit In Duplicate OV;9 ì/q /6 !<f¿ 7/)1/c6 II,I()~ . STATE! ÒF ALASKA . fY'. ~ ALATKA OIL AND GAS CONSERVATION C~M_SION APPLICATION FOR SUNDRY APPROVAL o AAC 2 0 \N6A- 1/l'/2-C> O!.f; RECEIVED / JUL 1 9 2006 n OR\G\NA\- RBDMS BFl JUb » 1 2006 e e Obp GI3J..~~ To: Winton Aubert - AOGCC Date: July 17, 2006 From: Phil Smith - BPXA GPB Rotary Drilling Subject: Reference: WGI-01 A Application for Sundry Approval - P&A for Sidetrack Operations API # 50-029-20369-00 Approval is requested for the proposed P&A of PBU well WGI-01. Due to casing leaks and the requirement for large diameter tubing the well will be sidetracked rather than worked over. The sidetrack will kick off from just below the surface casing after cutting and pulling the existing 9 5/8" casing. / The sidetrack is currently scheduled for Nabors 27E, beginning around August 20th 2006, after completing DS15-39A sidetrack. The pre-rig work for this sidetrack will begin at the Well's Group earliest convenience after sundry approval. Scope * Notify the field AOGCC representative with intent to plug and abandon * Pre-Rig Work: 1. Pull Tbg Tail Plug @ 7,814'. 2. Fluid pack the IA and tubing. 3. MIRU service coil and P&A current perforations from 9228' to 8695'. Planned TOC 8200' MD. 4. Jet cut 7" tbg @ 6,500'. 5. If necessary, level the pad and prepare location for rig move. 4S bL[s ~t. kJ61\- '- ci i Rig Operations: ~ 1. MIRU Nabors 27E. d 2. Circ out freeze protect and install TWC. 3. ND Tree and adapter flange. NU BOP and test to 4,000 psi. / 4. Pull TWC. 5. POOH wi 7-%" tbg from pre-rig cut @ 6,500'. PU 5" DP and stand back. / ( 6. MIRU Schlumberger. Run gauge ringl JB to 3000'. Run USIT 2900' to surface. C 7. Set CIBP @ 2,900'. Test csg to 4,000 psi. ...... 8. TIH wi Multi string mechanical cutter. Spot 300' of 18 ppg mud pill on top of CIBP. ,JI 9. Make initial cut @ 2,830'. Circulate through cut. Make second cut if necessary. .:1 10. POOH wi cutter. Change over to 9-%" rams and test BOPE. / 1_ 11. POOH w/9-%" casing and make 13-%" clean out run. tJt12. TIH w/ cmt stinger and spot 17.0 ppg kick off plug from 5.0' below 9 5/8" stub to 100' into 133/8" casing. 13. POOH and LD cement stinger. 14. Test the 13-%" casing to 4,000 psi for 30 minutes. / -15. MU 12-14" drilling assembly with Dir/GR/PWD and RIH to TOC. Circulate and dress cement plug down to KOP. Displace over to new LSND mud. 16. Drill new formation to 20' below 13-%" shoe and perform LOT. tv) J. 40 hbl ~ 1N6Jt- ~t. WGI-01A Application for Sundry e e 17. Drifl to ± 200' above the HRZ, ensure mud is conditioned and weighted to 9.6 ppg. Ensure pre-reservoir meeting is held highlighting kick tolerance and detection prior to entering the HRZ. 18. Drill ahead to target TD at 8,646' MD, (Top set Sag). 19. Circulate and condition hole, POOH to run casing. Perform wiper trip ONLY if hole conditions dictate. 20. Run and cmt the 9-%" intermediate casing in two stages. Ensure 500 psi compressive on first stage prior to pumping second stage. Displace with seawater during cementing operations. Bump plug and ensure that float holds. Install 9-%" casing packoff and test per FMC rep. Freeze protect the 13-%" x 9-%" annulus. 21. MU 8-W' drilling assembly with MWD I GR I PWD and TIH to ES cementer. Drill out ES cementer and TIH to float equipment. 22. Test casing to 4,000 psi. Drill out Float equipment and displace to clean Flo-Pro SF. 23. Drill shoe and 20' of new formation. Perform FIT. 24. Drill to Proposed TD @ 9,210'. Short trip as required; condition hole to RIH wiT' slotted liner. POOH. 25. Run 7" 26 ppf slotted liner. There will be 150' of overlap into the 9-%" intermediate casing. Set liner top packer. Release from liner, displace well to filtered seawater and POOH. 26. RU Schlumberger wireline and run US IT from liner top packer to TOC. 27. Run 7-%" 26 ppf, VamTop HC completion. Gator Hawk all connections. RILDS. Install TWC and test. 28. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. Remove TWC. 29. RU LRHOS. Reverse in SW and CI. Pump freeze protect and allow to U-tube. Set packer @ 8,433'. 30. Test tub and annulus to 4,000 psi. 31. Install BPV in tubing hanger. Install a VR plug in the 9-%" x 7" annulus valve and secure the well. Ensure that IAlOA are both protected with two barriers. 32. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod I RHC. 2. Pull VR plug. TiminQ: This sidetrack is scheduled for spud in mid August 2006. Estimated Pre-rig operations start date: Estimated Rig operations / spud date: 07/26/06 08/20/06 Phil Smith Operations Drilling Engineer 564-4897 WGI-01 A Application for Sundry TREE = WB...LHI;AD = ACTUA TOR = KB. B...EV = BF. B...EV = KOP'" 3500' Max Angle = 39 @ 9200' Datum MD = ? Datum TVD = 8800' SS 17" TBG, 29.0#, L-80, 0.0371 bpf, ID = 6.184" GRAY GRAY AXB...SON 49' e WGI-01 17-518" TBG-IPG, 29.7#, L-80, .0459 bpf, ID = 6.875" I TOP OF 7" TBG I 17" TBG, 29#, L-80, .0371 bpf, ID = 6.184" I TOPOF 7-5/8" TBG I 113-3/8" CSG, 72#, N-80, ID = 12.347" I Minimum ID = 4.845" @ 7920' BAKER SHEAROUT SUB DA TE REV BY COMMENTS 12/31/05 1WsrrLH ITP PLUG PULLED (12/19/05) I 7-5/8" TBG-IPG, 29.7#, L-80, .0459 bpf, ID = 6.875" I I TOP OF 7" TBG 17" TBG, 29#, L-80, .0371 bpf, ID = 6.184" I I TOP OF 7" TBG I 7902' 17" TBG, 29#, N-80, .0371 bpf,/D=6.184" I 7921' TOPOF 7" LNR I 8019' elm I 9-5/8" CSG, 47#, N-80, ID = 8.681" I 8314' ÆRFORATION SUMMARY REF LOG: BHCS ON 07/29/79 ANGLE AT TOP ÆRF: 38 @ 8695' Note: Refer to A-oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE See Perforation Data on Page 2 I PBTD I 9292' 9334' 17" LNR, 29#, N-80, .0371 bpf, ID = 6.184" I DATE 08/07/79 08/11/97 11/03/01 03/22/03 12/11/05 12/13/05 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER RNlTP CORRECTIONS JMlKAK PULL IBP ???rrLH SET TTP RPH/TLH WAIVER SFTY NOTE DB...ETED NOTES: 2' -j7"X 7-5/8" XO 2182' -j 7-5/8" X 7" XO I . 2183' -i 7" CAM BAL-O SSSV NIP, ID = 5.937" I 2187' -j 7" X 7-5/8" XO I 7795' 7801' 7814' 7902' "'9-5/8" X 7" BKR 8B-2 PKR I 7920' 7" BKR SHEA ROUT SUB (NO TAILPlÆ) ID = 4.845" 7910' H B...MD IT LOGGED 08/07/79.1 PRUDHOE BA Y UNfT WELL: WGI-01 ÆRMfT No: "1790310 API No: 50-029-20369-00 SEC 11, T11 N, R14E, 1795.18' & FB... 2926.14' FNL BP Exploration (Alaska) e PERFORA TION SUMMARY REF LOG: BHCS ON 07/29/79 ANGLEATTOPÆRF: 38 @ 8695' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8695-8725 0 08/10/80 3-3/8" 4 8725-8745 0 03/01/87 3-3/8" 4 8745-8785 0 08/10/80 3-3/8" 4 8785-8797 0 03/01/87 3-3/8" 4 8813-8853 0 08/10/80 3-3/8" 4 8853-8907 0 03/01/87 3-3/8" 4 8907-8917 0 08/10180 3-3/8" 4 8934-8954 0 08/10/80 3-3/8" 4 8954-8983 0 03/01/87 3-318" 4 8983-9003 0 08/10/80 3-3/8" 4 9008-9018 0 03/01/87 3-3/8" 4 9024-9034 0 08/10/80 3-3/8" 4 9040-9048 0 03/01/87 3-3/8" 4 9048-9058 0 08/1 0/80 3-3/8" 4 9074-9082 0 03/01187 3-3/8" 4 9082-9102 0 08/10/80 3-3/8" 4 9102-9122 0 03/01/87 3-3/8" 4 9122-9142 0 08/10/80 3-3/8" 4 9143-9151 0 03/01/87 3-3/8" 4 9156-9162 0 03/01/87 3-3/8" 4 9162-9182 0 08/10/80 3-3/8" 4 9208-9228 0 08/10/80 DATE 08/07/79 08/11/97 11/03/01 03/22/03 12/11/05 12/13/05 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER RNITP CORRECTIONS JIWKAK PULLIBP ???/TLH SET TIP RPH/TlH WAIVER SFlY NOTE DELETED WGI-01 DA TE REV BY COMMENTS 12/31/05 lWS/1LH TIP PlUG PULLED (12/19/05) e PRUDHOE BA Y UNrT WELL: WGI-01 PERMrT No: "1790310 API No: 50-029-20369-00 SEC 11, T11N, R14E, 1795.18' & FEL 2926.14' FNL BP Exploration (Alaska) TREE = WE1.,LHLõAD = ACnJA TOR = KB. ELEV = ,. BF. ELEV = KO~ Max Angle = Datum MD = Datum TVD = 13-3/8" CSG, 72#, I, N-80, ID = 12.347" Cut 9-5/8" CSG IHES 9-5/8" CIBP I Cut 7" TBG GRAY GRAY AXELSON 49' Ii I I i I i I I I I I I I I I I I I I I I I I I I i , i I I I I I i I I I I I I I I WG 1-0 1 A ~NOTES: e 2800 35 @4019' 2183' H 7" A 1 INJECTION VALVE SEA TEO IN CAMCO OB6 NIPPLE (10 = 6") 1 2731' H 2830' I H 2900' I 6920' H HES ES CEMENTER I H ~ I 7-5/8" 29.7#, L-80, VAMTOPHC,IPC, 0.04591 bpf, ID = 6.875" H 7" x 9-5/8" S-3 PKR, 10 = 6.05" I HHES R Nipple, ID = 5.963" I HHES RN Nipple, ID = 5.770" I H 7" 26#, L-80, TC-II, IPC, 0.03826 bpf, 10 = 6.276" FLEXLOK LINER HANGAR WI ZXP LINER TOP PKR, ID = 6.25", 12' TBS w 17.5" ID H 9-5/8" 47#, N-80, TC-II, 0.07321 bpf. 10 = 8.681 " ~ 9124' 7" SLOTTED LNR, 29#, N-80, BTC-M. 0.0371 bpf, ID = 6.184" I PBTD H 9292' I G 7" LNR, 29#, N-80, .0371 bpf,ID=6.184" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/06/06 STG ORIGINAL COMPLETION PRUDHOE BA Y UNrr WELL: WGI-01A ÆRMrr No: API No: 50-029-20369-01 SEC 11, T11N, R14E, 1795.18' & FEL 2926.14' FNL BP Exploration (Alaska) e e ö BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage. Alaska 99519-6612 January 30, 2006 RE,CE\VED FEB () 6 '2006 Comm\Ss\oR k'l I'a 0;\ 9~ !1as Cons. t\ as... ';I ,~ ' þ.nchOr8ge .....¡ Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: WGI-01 (PTD 1790310) Application for Cancellation of Sundry #303-106 Dear Mr. Aubert: Attached is Application for Sundry Cancellation form 10-404 to cancel sundry number 303-106. The sundry was for continued gas injection with IA by formation communication. The well will remain shut-in in preparation of a rig work over. With the cancellation of the sundry, the well will be removed from the Monthly Injection Report. If you require any additional information, please contact Anna Dube or Joe Anders at (907) 659-5102. ::Þ~ ~ Anna Dube, Well Integrity Coordinator ijt'" -' I>í" II"" , ,. . . 1,1 ~'I';í\,,>": L ,...y 1~,"" .0:,' "~"_n_ ~' Attachments Application for Sundry Cancellation form 10-404 Kt:\"'1::.1 v I::U FEB 0 6 2006 STATE OF ALASKA ALAe OIL AND GAS CONSERVATION COM_ION REPORT OF SUNDRY WELL OPERATIONS o o o Oil & Gas Cons. Commission Stimulate 0 Other C3\rIP.~hSundry WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 179-0310 6. API Number: 50-029-20369-00-00 9. Well Name and Number: 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic Exploratory Service P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 49 KB WGI-01 8. Property Designation: 10. Field/Pool(s): Field/ Pool ADL-028302 11. Present Well Condition Summary: Total Depth measured 9335 true vertical 8643.49 feet feet Plugs (measured) Junk (measured) 7806 None Effective Depth measured 9292 true vertical 8609.95 feet feet Casing Conductor Surface Production Liner Length 80 2709 8293 1315 Size 20" 94# H-40 13-3/8" 72# N-80 9-5/8" 47# N-80 7" 29# N-80 MD 23 - 103 22 - 2731 21 - 8314 8019 - 9334 TVD Burst Collapse 23 - 103 1530 520 22 - 2731 4930 2670 21 - 7822 6870 4760 7566.08 - 8642.71 8160 7020 Perforation depth: Measured depth: 8695 - 8797 9040 - 9058 True Vertical depth: 8142.33 - 8222.45 8413.03 - 8427.19 8813 - 8917 9074 - 9142 8234.97 - 8316.2 8439.77 - 8493.11 8934 - 9003 9143-9151 8329.53 - 8383.89 8493.9 - 8500.15 9008 - 9018 9156 - 9182 8387.83 - 8395.71 8504.05 - 8524.33 9024 - 9034 9208 - 9228 8400.44 - 8408.31 8544.55 - 8560.1 Tubing: (size, grade, and measured depth) 7-5/8" 29.7# & 7"29# 7"29# L-80 N-80 21 - 7823 7907 - 7921 Packers and SSSV (type and measured depth) 7" Baker SAB Packer 7" Baker SB-2 Packer 7795 7902 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft {) 6 7006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 270434 1100 o 0 0 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG QîI-Bbl o o Tubing pressure 3904 o Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service x WINJ I'? WDSPL 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: 303-106 Contact Anna Dube / Joe Anders Printed Name Anna Dube Title Well Integrity Coordinator Signature Date 1/30/2006 Form 10-404 Revised 04/2004 Submit Original Only 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: '\ STATE OF ALASKA '\ ALA~. .Å OIL AND GAS CONSERVATION COMIVI,__"SION REPORT OF SUNDRY WELL OPERATIONS o D D RECEIVED P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic r JAN 2 4 2006 Stimulate D OthE!r ~ Waiver D TirAl~MJij, . éI~ Cbus. Commissior Re-enter Suspended Well nchorage 5. Permit to Drill Number: Exploratory r] 179-0310 Service R' 6. API Number: 50-029-20369-00-00 3. Address: 9. Well Name and Number: 49 KB WGI-01 8. Property Designation: ADL-028302 11. Present Well Condition Summary: 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Bay Oil Total Depth measured 9335 true vertical 8643.49 feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 9292 true vertical 8609.95 feet feet Casing Conductor Surface Production Liner Length 80 2709 8293 1315 Size 20" 94# H-40 13-3/8" 72# N-80 9-518" 47# N-80 7" 29# N-80 MD 23 - 103 22 - 2731 21 - 8314 8019 - 9334 TVD 23 - 103 22 - 2731 21 - 7822 7566.08 - 8642.71 Burst 1530 4930 6870 8160 Collapse 520 2670 4760 7020 Perforation depth: Measured depth: 8695 - 9228 True Vertical depth: 8142.33 - 8560.1 Tubing: (size, grade, and measured depth) 7-5/8" 29.7# 7" 29# 7-5/8" 29.7# 7" 29# 7" 29# L-80 L-80 L-80 L-80 L-80 21-2182 2182 - 2187 2187 - 7801 7801 - 7823 7902 - 7921 Packers and SSSV (type and measured depth) 7" Baker SAB Packer 7" Baker SB-2 Packer 7795 7902 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft .iAN 2 5 2006 Treatment descriptions including volumes used and final pressu.re: E .. J ~~.I: ßì¡ ~; t. n n b ~CANN. W) . ¡-,oj li~: (.1 d . " 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf I Water-Bbl I Casing Pressure SHUT-IN SHUT-IN 15. Well Class after croposed work: Exploratory r Development C 16. Well Status after proposed work: Oil r Gas C WAG r Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Service w x GINJ El WINJ r WDSPL r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: NIA Contact Sharmaine Vestal Printed Name Sharmaine Vestal ~ , / . _ . Signat~lÍd~ 7j/1£,7 UR1G\\~AL Title Data Mgmt Engr Phone 564-4424 Date 1/23/2006 Form 10-404 Revised 04/2004 Submit Original Only .... ) ) WGI-O 1 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 12/16/2005 T/I/O=1550/1600/490. Temp=SI. TBG & IA FL (Secure Well). TBGP increased 210 psi, lAP increased 1220 psi, OAP increased 10 psi from 12-14- 05. TBG FL @ 3700'. IA FL @ 3300'. 12/18/2005 *** WELL SI ON ARRIVAL *** START TO RIG UP SURFACE EQUIP *** JOB IN PROGRESS/ CO NT ON 12-19-05 WSR *** 12/19/2005 *** CO NT FROM 12-18-05 WSR *** (rebuild /salvage plug) PULLED 7" PRN PLUG BODY & PRONG FROM RN NIP @ 7806' SLM. RDMO *** DSO NOTIFIED, WELL LEFT SI *** 12/27/2005 *** WELL SHUT IN UPON ARRIVAL*** {secure well,set Up} LRS LOAD TUBING. BEGIN TO RIH W/ PLUG BODY. ** CONTINUED ONTO 12-28-05 WSR** 12/27/2005 T/I/O=2600/2620/750 Assist Slickline. Load tubing with 5 bbls 60/40 meoh, 580 bbls 1 % KCL, 90 bbls 60/40.***Continued on 12-28-05 WSR*** 12/28/2005 ** CONTINUED FROM 12-27-05 WSR** SET 7" RN PLUG BODY (30" OAL) @ 7804' SLM. SET PRONG (1 3/4" FN, 1.875" BODY 00,94" OAL, 2'9" BELOW FN IS 4.562" CENT W/ 2.31" FN) @ 7797' SLM. MAX PSI ON TUBING WHEN PLUG SET WAS 300 PSI. TESTED PLUG TO 2500 PSI, GOOD TEST. ** TURNED WELL OVER TO DSO, LEFT SHUT IN** FLUIDS PUMPED BBLS 2 Diesel 2 TOTAL .. STATE OF ALASKA . ALA~ OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS Ht::CEn DEC 1 (; 2005 ,Alaska Oil & G;,¡¡" : '. 1. Operations Abandon 0 Repair Well 0 Plug Perforations [2] Stimulate 0 Other 0 AR^¡'~f~" "'q..-,'" Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0' I""" '''.' Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 179-0310 3. Address: P.O. Box 196612 Stratigraphic Service Pi 6. API Number: Anchorage, AK 99519-6612 50-029-20369-00-00 7. KB Elevation (ft): 9. Well Name and Number: 49 KB WGI-01 8. Property Designation: 10. Field/Pool(s): ADL-028302 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 9335 feet Plugs (measured) 7806 true vertical 8643.49 feet Junk (measured) None Effective Depth measured 9292 feet true vertical 8609.95 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 23 - 103 23 - 103 1530 520 Surface 2709 13-3/8" 72# N-80 22 - 2731 22 - 2731 4930 2670 Production 8293 9-5/8" 47# N-80 21 - 8314 21 - 7822 6870 4760 Liner 1315 7" 29# N-80 8019 - 9334 7566.08 - 8642.71 8160 7020 Perforation depth: Measured depth: 8695 - 8797 8813-8917 8934 - 9003 9008 - 9018 9024 - 9034 9040 - 9058 9074 - 9142 9143-9151 9156 - 9182 9208 - 9228 True Vertical depth: 8142.33 - 8222.45 8234.97 - 8316.2 8329.53 - 8383.89 8387.83 - 8395.71 8400.44 - 8408.31 8413.03 - 8427.19 8439.77 - 8493.11 8493.9 - 8500.15 8504.05 - 8524.33 8544.55 - 8560.1 Tubing: (size, grade, and measured depth) 7-5/8" 29.7# & 7"29# L-80 21 - 7823 7" 29# N-80 7907 - 7921 Packers and SSSV (type and measured depth) 7" Baker SAB Packer 7795 7" Baker SB-2 Packer 7902 12. Stimulation or cement squeeze summary: Intervals treated (measured): <it:.;¡~\\\'!~[t.;;V·' ß':¡, ¿¡ 20m: {~ "i,.' (';;::'o,.....J l þ' ;U;J Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 270434 1100 3904 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Exploratory Development Service P" Copies of Logs and Surveys Run ""j Daily Report of Well Operations X 16. Well Status after proposed work: Oil D Gas D WAG Di GINJ P' WINJ D WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¡SUndry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal ;~.BDMS BFl DEC :t 9 2005 Printed Name Sharmaine Vestal I Title Data Mgmt Engr . - ~ Signat~~ Phone 564-4424 Date 12/13/2005 Form 1 0-404 Revised 04/2004 u GII~AL Submit Original Only e e WGI-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1~~~~I¡JITYjjÂ:n: I SUMMÄ~Y 12/10/2005 *** WELL INJECTING ON ARRIVAL *** (secure well, ttp) DRIFTED WI 6.03 G-RING TO TOP OF MCX @ 2161' SLM, PULLED 7" MCX ON CAMCO CARRIER (SER# BP-707), BRUSHED RN NIP WI 7" BLB & 5.25 G-RING @ 7814' MD, DRIFTED WI 4.50 CENT, TEL & SAMPLE BAILER, LOC TT @ 7897' SLM- 7910' ELMD, TAG TD @ 9187' CORRECTED ELMD (492' OPEN PERFS, 41' FILL). STANDBY FOR PUMP TRUCK. *** JOB IN PROGRESSI CONT ON 12-11-05 WSR *** ~:-:;2:~(-:> :~I 12/11/2005 *** CONT FROM 12-10-05 WSR *** (secure well, ttp) PUMP TRUCK LOADED WELL WI 580 BBLS OF KCI & 115 BBLS OF 60/40 METHANOL SET 7" PRN PLUG BODY & PRONG (PLUG BODY 32" OAL WI (4) 1/4" PORTS, PRONG 92" OAL, 1.75 F.N, PRONG BODY 1.875 0.0, 3.55 CENT 43" BELOW F.N) IN RN NIP @ 7806' SLM.RDMO. NOTE: PLUG BODY HAS HEAVY WALL F.N, PULLS WI 51/2" GS *** DSO NOTIFIED, WELL SECURE *** FLUIDS PUMPED BBlS 575 1 % KCl 130 MeOH 1 Diesel 706 TOTAL RE: WGI-01 & WGI-03 Cancel Waiver e e fït:ti:- lr-zq - 03ì Subject: RE: WGI-Ol & WGI-03Cancel Waiver Frolt1: "NSU, ADW Well Integrity Engineer" <NSUADWWel1IntegrityEngineer@BP.com> Date: Mon, 12 Dec 2005 20:36:42 -0900 TJ~;:NSl5;; ADW Wpll ~.ations SupervisÓ'i, DWWellOperatiqJ)sS' "Rb~sberg~,R Steven<:Ro~,~þeRS@BP.cö:rñ>" 1/Stp/STPAteåð', <GPå P.c';, i'G~B, Wells Opt En', WellsOptEng@BP.c m>, ']PcB, ;;1;' OptiìÞ "'" 'GptimizationEngr@BP om>, "Schmoyer, AI" <SchmoyAL@BP:com>, flGP~, s Lêåd" <GPBfS1DSGpsJ:,ead@BP.com>, jim Jegg@~dmÌJ:Hstate.ak.us, wiP:,~ dmin,.state.ak.tis'" ; '" ,', <,\",\""",'" ~\ .~~~~~r;ç~~:@;¡" F "Fraz't , olasB" <NlCholas.Fraz., ( .,J ~ t)¿~1 1'& 110'.> Hello all. WGI-01 and WGI-03 have been reclassified from Waiver to Trouble. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom 8C^N~~fi.[ 4f n 'if;n;; \¡J t:' L ~ :..,.:>.j From: NSU, ADW WI Tech Sent: Monday, December 12, 2005 4:55 PM To: NSU, ADW Well Integrity Engineer Subject: WGI-01 & WGI-03 Cancel Waiver Joe, WGI-01 is a gas injector with a PC leak that can no longer be operated under the current waiver. WGI-01 requires an annual MIT-OA to 1.2 times estimated injection pressure, which is greater than 80% of the surface casing's rated burst pressure. WGI-03 is a gas injector with slow IAxOA communication that can no longer be operated under the current waiver. WGI-03 requires an annual MIT-OA to 1.2 times estimated injection pressure, which is greater than 80% of the surface casing's rated burst pressure. Thanks, Ryan Holt Well Integrity Tech. Pager 4236-786 Office 659-5524 1 of 1 l2/l3/2005 12:56 PM MEMORANDUM TO: ') Jim Regg 1<tdc) 4\111/0( P.I. Supervisor t ( State of Alaska Alaska Oil and Gas Conservation Commr) DATE: Wednesday, Aprill3, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORA TrON (ALASKA) INC WGI-OI PRUDHOE BAY UNIT WGI-O 1 ?J\" (},'O': \1;. , FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: , P.I. Suprv'JBfZ.. trlz.:7)W{ Comm Well Name: PRUDHOE BAY UNIT WGI-OI Insp Num: mitCS050412l31029 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20369-00-00 Permit Number: 179-031-0 Inspector Name: Chuck Scheve Inspection Date: 4/11/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI-OI Type Inj. N TVD 7371 IA 400 2000 1820 1660 P.T. 1790310 TypeTest SPT Test psi 1842.75 OA 40 40 40 40 Interval OTHER P/F F Tubing 280 300 300 300 Notes: MITrA failed, after repressuring the IA several times a leak rate of approximately 1 bbl per hour was established. S'Cl"N~ED Mj~Y :3 1 2005 Wednesday, April 13, 2005 Page 1 of 1 MEMORANDUM State of Alaska TO: ) Jim Regg 'v ' { I ..- P.I. Supervisor "~¿ill £{ 17, 05 Alaska Oil and Gas Conservation Comm; )" FROM: Chuck Scheve Petroleum Inspector DATE: Wednesday, April 13, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-OI PRUDHOE BAY UNrT WGI-OI a,v3t ,1:::-, Src: Inspector Reviewed B)': ,~() IJ .- P.I. Suprv..... lDJ,--- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT WGI-01 Insp Num: mitCS050412130220 Rei Insp Num: API Well Number: 50-029-20369-00-00 Permit Number: 179-031-0 Inspector Name: Chuck Scheve Inspection Date: 4/11/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well WGI-O 1 Type Inj. N TVD 7371 IA 900 1540 1740 1780 P.T. 1790310 TypeTest SPT Test psi 1842,75 OA 40 60 60 60 Interval OTHER P/F F Tubing 320 4270 3850 3630 Notes: MITT failed, there appeared to be a leak by the dummy sssv as the control and balance line pressured up with the tubing. ", ""'A" '~H~wET' IMJA' Y '>]ì 1: ?()Or.: ~tJ r hn~ .J) IV! , ~» f._ .) Wednesday, April 13, 2005 Page 1 of I MEMORANDUM State of Alaska TO: ) Jim Regg V ( I P .1. Supervisor 'r--.t?t{C¿ 1 ~ î 0:)' Alaska Oil and Gas Conservation Comm; J FROM: Chuck Scheve Petroleum Inspector DATE: Wednesday, April 13, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC WGI-O 1 PRUDHOE BAY UNIT WGI-OI ,1,.,q, ,,031 \' Src: Inspector Reviewed By: J.r.:J"~" P.I. Suprv , ~ Comm Well Name: PRUDHOE BAY UNIT WGI-OI Insp Num: mitCS050412125752 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-20369-00-00 Permit N um ber: 179-031-0 Inspector Name: Chuck Scheve Inspection Date: 4/11/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I WGI-OI Type Inj. N TVD 7371 IA 1320 1380 1300 1280 P.T. I 1790310 TypeTest SPT Test psi 1842.75 OA 40 4280 4260 4260 Interval OTHER P/F P Tubing! 300 320 320 320 Notes: MITOA for waiver evaluation. SC.ANNE~] MAY 3 1 200fj Wednesday, April 13,2005 Page I of I Re: WGI 90-day retest / 7 C' - ()2)/ Subject: Re: WGI 90-day retest . From: J ~es Regg <jim _regg@admin.state.ak.us> 'e{l¿q I ~ I ,,;/ ù4- Date: Fn, 15 Oct 2004 08:53:50 -0800 . . . (. . ~~k~rÞ~~àer:J=~~~~~~~~~1~~ì~¡)~~~~~1~~~~~~~~t ) {;(l ~ t~Pt,.,fj):7f Gilbert - When the Commission places a pad on 90 day test cycle, the intent of our letter is that ALL wells on the pad are tested at a 90 day cycle until you have demonstrated a failure rate that is acceptable «10%). If you have tested only those that failed, you have not satisfied our intent. What BP has done for WGI (as described) would be appropriate if we were looking at individual well failures, which is not the approach that was adopted for determining an acceptable failure rate for SVS. You should schedule a retest of WGI pad wells to be in compliance with our August 25 letter. Note that this has been copied to our inspectors to clarify any misunderstanding on their part. Jim Regg Inspection Supervisor AOGCC GPB, Ops Supt wrote: Jim Last week, one of our step -up DS Leads contacted John Crisp and arranged for the 90 day retest of WGI per your letter dated August 25, 2004 to Bruce Williams. John's understanding was that only the devices that failed (i.e., the SSSV on WGI-01and WGI-04) needed a retest, and not the entire pad. Our DS Lead complied with this. Please confirm that we have met the requirements per your August 25th letter. Thanks, Gilbert Wong SCANNEn NOV 1 6 2004 1~1 10/15/20048:54 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: VARIANCE GAS INJECTION Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate_ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 258' FNL, 1209' FEL, Sec. 11, T11N, R14E, UM At top of productive interval 3330' FNL, 1812' FEL, Sec. 02, T11N, R14E, UM At effective depth 3035' FNL, 1798' FEL, Sec. 02, T11N, R14E, UM At total depth 2927' FNL, 1797' FEL, Sec02 T11N, R14E, UM 5. Type of Well: Development __ Exploratory _ Stratigraphic __ Service_X (asp's 684986, 5972003) (asp's 684327, 5974195) (asp's 684333, 5974491) (asp's 684332,5974599) 6. Datum elevation (DF or KB feet) RKB 49.0 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number WGI-01 9. Permit number / approval number 179-031 10. APl number 50-029-20369-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 75' Surface 2703' Intermediate -,, 8286' Liner 1410' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 9335 feet Plugs (measured) BP Set @ 8100' (11/26/2002). 8643 feet Tagged TD @ 9164' WLM (11/25/2002). 9164 feet Junk (measured) 8510 feet Size Cemented Measured Depth True vertical Depth 20" 330 sx Arcitc Set 103' 103' 13-3/8" 4760 sx Arcitc Set II 2731' 2731' 9-5/8" 375 sx Arcitc Set I, 500 8314' 7822' sx Clas~ 'G' 7" 355 sx Class 'G' 7924' - 9334' 7483'- 8642' Open Perfs 8695'-8797', 8813'-8917', 8934'-9003', 9008'-9018', 9024'-9034', 9040'-9058', Open Perfs (continued) 9074'-9142', 9143'-9151', 9156'-9182', 9208'-9228'. Open Perfs 8142'-8222', 8235'-8316', 8329'-8384', 8388'-8396', 8400'-8408', 8413'-8427', Open Perfs (continued) 8440'-8493', 8494'-8500', 8504'-8524', 8544'-8560'. 7", 29#, L-80 TBG @ 2'. 7"x 7-5/8" XO @ 2'. 7-5/8", 29.7# L-80 TBG @ 2182'. 7-5/8" x 7" XO @ 2182'. 7" 29#, L-80 TBG @ 2187'. 7"x 7-5~8" XO @ 2187'. 7-5/8 29.7#, L-80 TBG @ 7801'. 7-5/8" x 7" XO @ 7801'. 7" 29#, L-80 TBG @ 7823'. 7" 29# L-80 TBG Isolaton Assembly from 7902' - 7921'. 9-5/8" x 7" Baker SAB Packer @ 7796'. 9-5/8" x 7" Baker SB-2 Packer @ 7902'. 7" Camco BAL-O SSSV Nipple @ 2183' MD. 13. Attachments Description summary of proposal __X Detailed operations program 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date"approved 15. Status of well classification as: Oil __ Gas __ Service Gas Injection Well BOP sketch _ RECEIV S B s.p.e. Qded 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S ig nedjotnd~ers ~~"'~"/, PE Title: Well Integrity Engineer FOR COMMISSION USE ONLY Questions? Date March"20, 2003 Prepared by DeWa?ne R. Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness Approva!~.~5 Plug integrity __ BOP Test__ Location clearance _ Approved by order of the Commission ~__ ~ ~~~ - Commissioner .... ~ ~-- --~N L ...... Date Form 10-403 Rev 06/~ 5~88 SUBMIT IN TRIPLICATE WGI-01 Description Su mmary of Proposal 03~20~03 Problem: Gas Injector with Slow Production Casing Leak Well History and Status Well WGI-01 (PTD 1790310) is a gas injector that failed an MIT-IA on 08/20/02. A LLR of 1.5 GPM @ 3500 psi has been established and a production casing leak has been identified at ~6430'. The well has been SI since 8/21/02. Recent events: > 08/20/02: > 08/21/02: > 10/31/02: > 11/07/02: > 11/13/02: > 11/25/02: > 11/26/02: > 02/09/03: > 03/15/03: > 03/16/03: > 03/17/03: > 03/18/03: MITIA Failed on pressure stabilization, 200-600 psi/15 min. SL set TTP, loaded well. MIT-T Passed to 3500 psi, MIT-IA Failed, LLR 1.6 GPM @ 3000 psi. MIT-T Passed to 3500 psi. MIT-IA Failed, LLR 0.8 GPM @ 3000 psi. PPPOT-T Passed to 5000 psi. SL pulled the TTP. IBP set @ 8100', below tubing tail. LDL indicates temp anomaly at 6430'. LLR 1.5 GPM @ 3500 psi. No-flow test on IA Passed. MIT-OA Passed to 4300 psi. TTP set. MIT-T Passed to 4300 psi. The balance line appears to leak into the IA and IA repressurization can occur through the balance line when the lower packing stack on the SSSV leaks. Replacement of the SSSV has su(~cessfully restored tubing integrity. This'sundry request is to allow for continued injection of gas. The following supports the request: · 2 levels of protection are demonstrated by the MIT-Tubing passing to 4300 psi on 3/18/03 and the MITOA passing to 4300 psi on 3/16/03. · Pressures and injection rates will be monitored and recorded daily and checked for indications of a tubing leak. · An MIT-OA will be conducted every year and an MIT-Tubing will be conducted every 4 years to confirm 2 levels of protection. Proposed Action Plan 1. Allow well to continue gas injection. 2. Record wellhead pressures and injection rates daily. 3. Submit a monthly report of daily pressures and injection rate. 4. IA fluid level will be monitored to ensure adequate IA fluid loading. 5. Perform MIT-OAevery year. 6. Perform MIT-Tubing every ~'-years. 7. Stop injection and notify the AOGCC if there is any indication of loss of tubing integrity. TREE = GRAY W ELL FEA D = GRAY ACTUATOR = AXELSON KB. ELEV = 49' BF. ELEV = KOP = 3500' Max Angle = 39 @ 9200' Datum IVD = ? Datum '[VD = 8800' SS I 7"TBG, 29.0~, L-80, 0.0371 bpf, ID:6.184" I--~ 2' WGI-01 7-5/8" TBG, 29.7#, L-80, .0459 bpf, ID= 6.875" Id 2182' ITOPOF7" TBG Id 2182' 7" TBG, 29#, L-80, .0371 bpi=, ID = 6.184" I--[ 2187' ITOP OF 7-5/8" TBG Id 2187' I 13-3/8" CSG, 72~, N-80, ID= 12.347" Id 2731' !Minimum ID = 4.845"@ 7920' I BAKER SH EAROUT SUB I 7-5/8" TBG, 29.7#, L-80, .0459 bpf, ID =6.875" I--~ 7801' ITOP OF 7"TBG H 7801' 17" TBG, 29#, L-80, .0371 bpf, ID = 6.184" Id ITOP OF 7" TBG TBS, 29#,, N-80, .0371 bpf, ID = 6.184" I TOP OF 7"LNR I 9-5/8" CSG, 47#, N-80, ID = 8.681" 7823' H I I-I : I-{ 8019' elm I, ~l J~~, H 8314' I I PERFORATION SUMMARY REF LOG: BHCS ON 07/29/79 ANGLEATTOPPERF: 38 @ 8695' Note: Refer to Production DB for historical perf data SIZE I S.:l INTERVAL I°pn/sqz I DATE See Perforation Data on Page 2 SAFETY NOTES: 2' 1--17,I 2182' Id 7-5/8" X 7" XO I 2183' Id7"CAMBAL-OSSSVNIP, ID=5.937"I 2 sz,. I-I , I 7795' 7801' 7814' 7823' I 7902' I 7920' 7910' I--19-5/8" X 7" BKR SAD PKR I I~ 7-5/8" X 7" XO I Id7" HES RN NIP, ID= 5.5" H7" TUBNGTAL WLEG I Id 9-5/8" * 7" BKR SD-2 PKR I Id7" BKR SHEAROUT SUB (NO TAILPPE) ID = 4.845" IdELMD TT LOGGED08/07/79 I { 8100' HBPSB'11/26/02 I DATE REV BY COMrvlENTS DATE REV BY COIVlVlENTS 08/07/79 ORIGINAL COMFLETION 08/11/97 LAST WORKOVER 01/26/01 SIS-MD FNAL 11/03/01 RNffP CORRECTIONS 11/26/02 JB/TP SET IBP PRUDHOE BaY UNIT WELL: WGI-01 PERMIT No: 1790310 APl No: 50-029-20369-00 SEC 11, T11N, R14E 1795.18'& FEL 2926.14' FNL BP Exploration (Alaska) WGI-01 PERFORATION SUIVIVIARY REF LOG: BHCS ON 07/29/79 ANGLE AT TOP PERF: 38 @ 8695' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8695-8725 O 08/10/80 3-3/8" 4 8725-8745 O 03/01/87 3-3/8" 4 8745-8785 O 08/10/80 3-3/8" 4 8785-8797 O 03/01/87 3-3/8" 4 881 3-8853 O 08/10/80 3-3/8" 4 8853-8907 O 03/01/87 3-3/8" 4 8907-8917 O 08/10/80 3-3/8" 4 8934-8954 O 08/10/80 3-3/8" 4 8954-8983 O 03/01/87 3-3/8" 4 8983-9003 O 08/10/80 3-3/8" 4 9008-9018 O 03/01/87 3-3/8" 4 9024-9034 O 08/10/80 3-3/8" 4 9040-9048 O 03/01/87 3-3/8" 4~ 9048-9058 O 08/10/80 3-3/8" 4 9074-9082 O 03/01/87 3-3/8" 4 9082-9102 O 08/10/80 3-3/8" 4 9102-9122 O 03/01/87 3-3/8" 4 9122-9142 O 08/10/80 3-3/8" 4 9143.9151 O 03/01/87 3-3/8" 4 9156-9162 O 03/01/87 3-3/8" 4 9162-9182 O 08/10/80 3-3/8" 4 9208-9228 O 08/10/80 DATE REV BY COMMENTS DATE REV BY COMIVENTS 08/07/79 ORIGINAL COIVPLETION 08/11/97 LAST WORKOVER 01/26/01 SIS-IVI:) FINAL 11/03/01 RN/TP CORRECTIONS 11/26/02 JB/TP SET IBP PRUDHOE BAY UNIT WELL: WGI-01 PERMIT No: 1790310 AR No: 50-029-20369-00 SEC 11, T11N, R14E, 1795.18' & FEL 2926.14' FNL BP Explo ratio n (Alas ka) BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-24 Anchorage, Alaska 99519-6612 bp March 20, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: WGI-01 (PTD 1790310) Application for Sundry Approval Dear Mr. Aubert: Attached is the Application for Sundry form 10-403 for well WGI-01. This request is for approval to continue gas injection into a well with a slow production casing leak. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact Harry Engel at 564-4194, or John Cubbon or me at (907) 659-5102. Sincerely, Joe Anders, P.E. Well Integrity Engineer Attachments ORIGINAL MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor/~oT' DATE: August 25, 2001 Chair t. SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder t~ BPX P.I. Superviso(~J]~ ' ~ -~1~.~_~ \-~::::~X, NGI & WGI NGI-01& 02 WGI-01,05 & 08 FROM: Chuck Scheve PBU Petroleum Inspector Prudhoe Bay NON- CONFIDENTIAL ,., WellI P.T.D.I #ores: I Packer Depth Pretest Initial 15 Min. 30 Min. we, J NG~-O1 JTypelnj. J ~ IT-v-D- I 7~ I TubingJ 33501 33.~1 33.~1 335o I~n~.~l 4 J P.T.D.J 1750480 JTypetestJ P JTestpsiJ 1827 I Ca~ngl, ~0 I 22OO I 2~o J.21eo J P/F I I w~'! "~'~ l~'"e'nJ'l ~ I,'v'~' I ~ I~u~"~ I ~oo i ~ I ~oo I ~ I'~v~'l p.T.D.J 1750610 JTypetestJ P JTestpsiJ 1843 J CasingJ 0 I ~200 I 21S0 I 2180 I P~F I #ores: w~,~, I,,,e,nJ.i ~ I ,.v.o. I ~ !,u~n~ I ~ I ~ I ~°°1 ~ I'~va'l 1790310 JTypetestJ P JTestpsiJ 1843 J CasingJ 92O I 2100J 2080J 2060J P~F I _.P .. w~,I w~,~ i,,,e,nJ.I ~I T'V,D' I ~ ITuang I ~00 i ~ I ~ I ~ I'"te~a'l V P.T.D.I 1900250 Typetesti PITestpsil 1950 I CasingI ,400 I 22OO I 21S0 I 2140 I P/F, I _P · w~,I w~,~, I T~pe,.J.I ~ I T.V.o.'l ,~ J Tubing J35oo J. 35ooI ~ I ~ J,nt~a,J o P.T.D.I 1900490 JTypetestJ P JTestpsiJ 1915 J CasingJ 700 I 22~0 I 22,4O I 2240 I P/F I _P Notes: Annual MIT Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs NGI & WGI locations in the Prudhoe Bay field and witnessed the MIT on wells NGI-01, NGI-03, WGI-01, WGI-05 and WGI-08. The pretest pressures were observed and found to be stable. A standard annulus pressure test was then performed with all 5 wells demonstrating good mechanical integrity. M.I.T.'s performed: _5 Attachments: Number of Failures: _0 Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. MIT PBU NGI, WGI 8-25-01 CS.xls 8/30/01 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU: TO: Julia Heusser, ~-~ DATE: Commissioner Tom Maunder, P. I. Supervisor~ FROM: John Crispl SUBJECT: Petroleum Inspector January 15, 2000 Safety Valve Tests Prudhoe Bay Field WGI Pad January 15, 2001: I traveled to BP's Prudhoe Bay Field to witness Safety Valve System testing on WGI Pad. BP representative Bill Preston was in charge of SVS tests on WGI Pad. Testing was conducted in a safe & efficient manner. Two failures were witnessed. WGI 06 surface & sub-surface valves failed to hold DP. This well was shut in until repaired & re-tested. The AOGCC test report is attached for reference. I inspected wellhouses on WGI Pad during SVS tests. All are clean & in good shape. SUMMARY: I witnessed SVS tests on PBU WGI Pad. 8 wells, 24components tested. 2 failures witnessed. 8.3% failure rate. 8 wellhouses inspected. Attachments: SVS PBU WGI Pad 1-15-01jc cc; NON-CONFIDENTIAL SVS PBU WGI Pad 1-15-0 ljc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Bill Preston AOGCC Rep: John Crisp Submitted By' John Crisp Date: Field/Unit/Pad: Prudhoe Bay Field WGI Pad Separator psi: LPS HPS 1/15/01 3400 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN.I, Number Number PSI PSI Trip Code Code Code Passed (;^S or CVCLE WGI-01 1790310 3400 2900 2440 P P P GINJ WGI-02 1790430 3400 2900 2650 P P P ' GINJ WGI-03 1790490 3400 2900 2350 P P P GINJ WGI-04 1790500 3400 2900 2350 P P P GINJ WGI-05 1900250 3400 2900 2500 P P P GINJ WGI-06 1900300 3400 2900 2460 P 4 9 GINJ V~GI-07 1900400 3400 2900 2480 P P P GINJ WGI-08 1900490 3400 2900 2620 P P P GINJ~ ...... Wells: 8 Components: 24 Failures: 2 Failure Rate: 8.3% [] 90 Day Remarks: WGI-07 shut in untill repaired & re-tested. 1. Operations performed: ~'-' STATE OF ALASKA -- ALASKA ,.,IL AND GAS CONSERVATION CC... ¥11SSION REPORT OF SUNDRY WELL OPERATIONS [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] PulI Tubing []Alter Casing [~ Repair Well []Other rb. 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 258' SNL, 1209' WEL, SEC. 11, T11 N, R15E, UM At top of productive interval 1949' NSL, 1812' WEL, SEC. 02, T11N, R14E, UM At effective depth 2278' NSL, 1799' WEL, SEC. 02, T11 N, R14E, UM At total depth 2355' NSL, 1798' WEL, SEC. 02, T11 N, R14E, UM Type of well: 6. [] Development F-I Exploratory 7. [] Stratigraphic [] Service 8. 9. 10. 11. Datum Elevation (DF or KB) RKB = 49' Unit or Property Name Prudhoe Bay Unit Well Number WGI-1 Permit Number / Approval No. 79-31 397-126 APl Number 50-029-20369 Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9335 feet true vertical 8643 feet Effective depth: measured 9213 feet true vertical 8548 feet Casing Length Size Structural Conductor 75' 20" Surface 2703' 13-3/8" Intermediate 8286' 9-5/8" Production Liner 1410' 7" Plugs (measured) Junk (measured) ORIGINAL Fill at 9213' Cemented MD 330 sx Arctic Set 103' 4760 sx Arctic Set II 2731' 375 sx Arctic Set I, 500 sx Class 'G' 8314' 103' 2731' 7822' 355 sx Class 'G' 7924'-9334' 7483'-8642' Perforation depth: measured 8695' - 8797', 8813' - 8917', 8934' - 9003', 9008' - 9018', 9024' - 9034', 9040' - 9058', 9074' - 9142', 9143' - 9151', 9156' - 9182', 9208' - 9228' true vertical 8142' - 8222', 8235' - 8316', 8329' - 8384', 8388' - 8396', 8400' - 8408', 8413' - 8427', 8440' - 8493', 8494' - 8500', 8504' - 8524', 8544' - 8560' Tubing (size, grade, and measured depth) 7-5/8", 29.7#, L-80, ST-L Mod to 2183'; 7", 29#, 2183' - 2188'; 7-5/8", 29.7#, L-80, ST-L Mod 2188' - 7801'; 7", 29#, 7801' - 7823'; 7", 29#, N-80, 7902' - 7921' Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker SAB Packer at 7796'; 7" Camco SSSV at 2183' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation: 1 5. Attachments I16. Status of well classifications as: [] Copies of Logs and Surveys run I ~1 Oil [-q Gas r~ Sus'-'ended [] Daily Report of Well, JJ~rations I ~ ' ' ' ' ~' 7. I hereby certify that/~e foregoing is/tt~e,cnd ):~rrect to the best of my knowledge Signed ~ ~', ~ /'/'//~ Dan Stoltz~~ ~E;=""~Jl~~ ..... Title Senior Drilling Engineer Prepared By Name/Number: 'Service Water & Gas Injector ~ ~n ~u-u~lioate ~:~ Form 10-404 Rev. 06/15/88 Facility Date/Time 06 Aug 97 07 Aug 97 08 Aug 97 09 Aug 97 10 Aug 97 11 Aug 97 WGI Progress Report Well WGI-01 Page 1 Rig Doyon 16 Date 16 October 97 07:00-09:00 09:00-14:00 14:00-14:30 14:30-15:00 15:00-17:30 17:30-18:00 18:00-18:30 18:30-20:00 20:00-01:00 01:00-05:00 05:00-05:30 05:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-09:00 09:00-12:30 12:30-14:00 14:00-18:00 18:00-18:30 18:30-02:00 02:00-04:00 04:00-06:00 06:00-06:30 06:30-12:45 12:45-13:00 13:00-13:30 13:30-14:30 14:30-18:00 18:00-18:30 18:30-20:30 20:30-22:00 22:00-03:00 03:00-03:15 03:15-06:00 06:00-06:30 06:30-10:00 10:00-15:30 15:30-16:30 16:30-18:00 18:00-18:30 18:30-20:00 20:00-20:15 20:15-06:00 06:00-06:30 06:30-14:00 14:00-15:00 15:00-15:15 15:15-18:00 18:00-18:30 18:30-19:00 19:00-02:00 02:00-04:00 04:00-04:30 Duration 2 hr 5hr 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 5hr 4hr 1/2 hr 1/2 hr 1/2 hr 1 hr lhr 1/2 hr 3-1/2 hr 1-1/2 hr 4hr 1/2 hr 7-1/2 hr 2hr 2hr 1/2 hr 6-1/4 hr 1/4 hr 1/2 hr lhr 3-1/2 hr 1/2 hr 2hr 1-1/2 hr 5hr 1/4 hr 2-3/4 hr 1/2 hr 3-1/2 hr 5-1/2 hr lhr 1-1/2 hr 1/2 hr 1-1/2 hr 1/4 hr 9-3/4 hr 1/2 hr 7-1/2 hr lhr 1/4hr 2-3/4 hr 1/2 hr 1/2 hr 7hr 2hr 1/2 hr Activity Rig moved 100.00 % Fill pits with Brine Held safety meeting Removed Lubricator Circulated at 7879.00 ft Installed Hanger plug Held safety meeting Removed Surface tree Rigged up BOP stack Tested BOP stack Rigged down Lubricator Installed Tubing handling equipment Held safety meeting Pulled Tubing on retrieval string to 7815.00 ft Circulated at 7815.00 ft Laid down 115.00 ft of Tubing Installed Casing hanger & seal assembly running tool Circulated at 7700.00 ft Laid down 2400.00 ft of Tubing Held safety meeting Laid down 5300.00 ft of Tubing Tested Bottom ram Ran Drillpipe in stands to 100.00 ft Held safety meeting Ran Drillpipe in stands to 7846.00 ft Held drill (H2S) Worked toolstring at 7846.00 ft Circulated at 7820.00 ft Pulled out of hole to 3000.00 ft Held safety meeting 'Pulled out of hole to 54.00 ft Laid down 54.00 ft of Tubing Ran Drillpipe in stands to 7887.00 ft Held drill (Fire) Circulated at 7887.00 ft Held safety meeting Circulated at 7887.00 ft Pulled out of hole to 0.00 ft Installed BOP stack Installed Tubing handling equipment Held safety meeting Tested Top ram Held drill (H2S) Ran Tubing to 5570.00 ft (7-5/8in OD) Held safety meeting Ran Tubing to 7823.00 ft (7-5/8in OD) Reverse circulated at 7823.00 ft Held drill (Fire) Functioned Permanent packer Held safety meeting Installed Hanger plug Rigged down BOP stack Tested Tubing hanger Installed Lubricator Facility Date/Time WGI Progress Report Well WGI-01 Rig Doyon 16 Page Date 04:30-05:30 05:30-06:00 06:00-06:30 06:30-10:00 10:00-13:00 13:00-18:00 Duration 1 hr 1/2 hr 1/2 hr 3-1/2 hr 3hr 5hr Activity Serviced Block line Removed Handling equipment Held safety meeting Removed Fluid system Rig moved 10.00 % Rig waited: Production facilities 2 16 October 97 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 258' SNL, 1209' WEL, SEC. 11, T11 N, R15E, UM At top of productive interval 1949' NSL, 1812' WEL, SEC. 02, T11N, R14E, UM At effective depth 2278' NSL, 1799' WEL, SEC. 02, T11N, R14E, UM At total depth 2355' NSL, 1798' WEL, SEC. 02, T11 N, R14E, UM Type of well: [] Development [] Exploratory I--] Stratigraphic [~Service 6. Datum Elevation (DF or KB) RKB = 49' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number WGI-1 9. Permit Number 79-31 10. APl Number 50-029-20369 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 9335 feet true vertical 8643 feet Effective depth: measured 9213 feet true vertical 8548 feet Casing Length Size Structural Conductor 75' 20" Surface 2703' 13-3/8" Intermediate 8286' 9-5/8" Production Liner 1410' 7" Plugs (measured) Junk (measured) Fill at 9213' Cemented MD ':' ;~ :': TVD 330 sx Arctic Set 103' 4760 sx Arctic Set II 2731' 375 sx Arctic Set I, 500 sx Class 'G' 8314' 355 sx Class 'G' 103' 2731' 7822' 7..,2~J~'-9334' 7483'-8642' Perforation depth: measured true vertical 8695'-8797', 8813'-8917', 8934'-9003', 9008'-9018', 9024'-9034', 9040'-9058', 9074'-9142', 9143'-9151', 9156'-9182', 9208'-9228' 8142'-8222', 8235'-8316', 8329'-8384', 8388'-8396', 8400'-8408', 8413'-8427', 8440'-8493', 8494'-8500', 8504'-8524', 8544'-8560' Tubing (size, grade, and measured depth) 7", 29#, N-80, ABM 8rd to 7898' Packers and SSSV (type and measured depth) 9-5/8" Baker SD-2 Hydro Packer at 7909'; Otis RPB at 2189' 13. Attachments [] Description summary of proposal I--I Detailed operations program [] BOP sketch 14. Estimated date for commencing operation 115. Status of well classifications as: July 31, 1997 I 16. If proposal was verbally approved I [-] Oil I-] Gas [] Suspended Service ~as Injector Name of approver Date approved Contact Engineer Name/Number: C. pri~ Brown, 564-5582 ,, Prepared By Name/Number: 17.1 hereby certify thai t..h/e~fCe~)ing is Ce, cl'nd/~rrect to the best of my knowledge Signed Dan Stoltz ~,~/'~ ~,~~ Title Senior Drilling Engineer Commission Use Only ORIGINAL Terrie Hubble, 564-4628 Conditions of Approval: Notify Commission so representative ~.y witness Plug integrity __ BOP Test Location clearance Mechanical Integrity Test ~ Subsequent form required 10- ./-fc:)~ dngina~ Signed By Approved by order of the Commission David W. Johnston Form 10-403 Rev. 06/15/88 Returned Date 7-'C~-" ~,i Submit In Triplicate~ WGI-01 WORKOVER SUMMARY Objective The objective of this rig workover is to increase the well's lagging injectivity by replacing the existing 7" tubing with 7-5/8" internally plastic coated tubing. The seals will be pulled from the existing packer and a new completion run to _+60' above the existing packer. Jewelry will remain 7" in size. Critical Well Information Existing 7", 29#, N80 Tubing I.D. = 6.184" 7" SSSV Landing Nipple: 2,187' MD Minimum ID (4.845" ID): 7,921' MD (Baker shear out sub) 7", 29#, N80, Liner I.D. = 6.184" PBTD (7"): 9,292' MD Perforations: 8,695'-9,228' MD New 7-5/8" 29.04#, NT95HS ST-L Tubing I.D. = 6.875" 7" SSSV Landing nipple: 2,187' MD 7" Packer, XN nipple, 5.75" No-go Pre-Riq Procedure 1. Test annulus to 3,500psi if not recently tested. 2. R/U slickline and drift tubing down to 8,600'. 3. R/U coiled tubing and bullhead a 100bbl sized salt pill to the perforations (preceded by 50bbls 10ppg hi-vis NaCI brine spacer), followed by 50bbls 10ppg hi-vis NaCI brine spacer and 9.6ppg kill weight brine. 4. RIH with chemical cutter on wire-line and cut tubing at first full joint above the packer seals at _+7,879' MD. . Circulate well to 9.6ppg KCI brine (zero pressure on tubing and IA). Freeze protect to _2,200 MD (if necessary). Estimated BHP at 8,146TVD is 3,550psi (8.4ppg EMW). Note that at this point, the well will be theoretically overbalanced by 196psi provided the brine column is not reduced by fluid moving into the formation after the well has been killed. 6. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar. Summary Ri.q Procedure 1. Test 9-5/8" packoff to 5000psi, and function lock down screws. 2. MIRU. Circulate well with 9.6 ppg NaCI brine. Set and test BPV. ND tree. NUBOP's. Set test dart (TWCV). Test BOP's. Pull test dart and BPV. 3. Pull 7" tubing from chemical cut made in pre-rig. Replace 9-5/8" pack°ff if necessary while pulling tubing. 4. M/U fishing assembly. RIH, retrieve seals, and POOH. If seals cannot be pulled, an overshot guide will be run as a contingency. WGI-01 Sundry Workover Procedure Page 2/2 . M/U and run new 7-5/8" NT-95HS ST-L completion with 7" SSSV, 9-5/8"x7" packer, 7" tailpipe with XN nipple configuration and a 7" WLEG. This will be set _+60' above the existing packer. No GLM's are required on this completion. NOTE: If the seals cannot be pulled, the completion will include an overshot guide instead of the WLEG. Drift tubing to maximum OD required post-rig. 6. Circulate well to NaCI brine/freeze protect tubing/annulus to _+2,200' MD. Land completion and test tubing to 4,200psi. 7. Set BPV/test dart and test from above. N/D BOP's. N/U and test tree. Pull test dart and BPV. Check well for flow. 8. Set BPV and RDMO. Prepared by: /D0-~On 16 Ops Drlg Engr Chris Brown Doyon 16 Operations Drilling Engineer (Office) 564-5582 (Home) 346-3773 (Pager) 275-1835 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OII [--I GAS' SUSPENDEDE~ ABANDONED[~] SERVICE~ Gas Injection 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 79-31 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20369 4. Location of well at surface 9. Unit or Lease Name 258'FNL & 1209'FEL, Sec. 11, TllN, R15E~ UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1957'FSL & 1812'FEL~ Sec. 2, Ti]N, R14E, UM WGI-1 (33-2-11-14) At Total Depth 11. Field and Pool 2355'FSL & 1798'FEL, Sec. 2, TllN, R14, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 49' RKB I ADL 28302 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116' No. of Completions 07/11/79 07/28/79 08/07/79 I N/A feet MSLI Single 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9335'MD, 8643'TVD 9292'MD, 8610'TVD YES ~ NO [] I 9158 feet MD 1900' (Approx.) 22. Type Electric or Other Logs Run DIL/SP/BHCS/CAL/GR, FDC/CNL/CAL/OR, CNL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 94~ Weld H-40 Surf 103' 30" 330 sx Arcticset 13-3/8" 725~ Butt N-80 Surf 2731' 17~" 4760 sx Arctic Set II Cmt 9-5/8" 475~ Butt N-80 Surf 8314' 12~" 500 sx Class G & 375 sx Arcticset I Cmt & SOO- 95 ~ ~ ~ ! ~.F'.~ .!,. ..... 7" 29~ N-80 7924' 0 , 355 sx Class G Cmt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8695-8797', 8813-8917', 8934-9003', 9008-9018', 7" 7921' 7902' 9024-9034', 9040-9058', 9074-9142', 9143-9151', 9156-9182', 9208-9228'MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8142-8222', 8235-8316', 8329-8384', 8388-8396', N/A 8400-8408', 8413-8427 ', 8440-8493', 8494-8500 ' , 8504-8524', 8544-8560'TVD 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Gas Injection Well Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 3/5/87 24 TEST PERIOD I~ __ 187,2zd+ ...... I . Flow Tubing Casing Pressure CALCULATED,~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 3794 -- 24-HOUR RATE "IK __ 187~244 .... 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. AUG 2 6 Alaska 0il 8, Gas I:;ons. Gommissio~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Sadlerochit Base Sadlerochit GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 8131' 8577' 30. 8681' 9250' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to ~he best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, .steam injection, air injection, sa:It water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ..... STATE OF ALASKA ALA,_.,A OIL AND GAS CONSERVATION COk..,/llSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~q Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska~ Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 258'FNL & 1209'FEL, Sec. 11, T11N, R15E, UM At top of productive interval 1949'FSL & 1812'FEL, Sec. 2, T11N, R14E, UM At effective depth 2278'FSL & 1799'FEL, Sec. 2, T11N, R14E, UM At total depth 2355'FSL & 1798'FEL, Sec. 2, T11N, R14E, UM 5. Datum elevation (DF or KB) RKB 49' 6. Unit or Property name Prudhoe Bay Unit 8. Approval number 669 9. APl number 50-- 029-20369 10. Pool Sadl erochi t 11. Present well condition summary Total depth: measured true vertical 9335 feet Plugs (measured) 8643 feet Effective depth: feet Junk (measured) feet None 9213' - Fill Liner 1410' 7" 7483'-8642' measured 9213 true vertical 8548 Casing Length Size Cemented Measured depth True Vertical depth Conductor 75' 20" 330 sx Arctic Set 103' 103' Surface 2703' 13-3/8" 4760 sx Arctic Set II 2731' 2731' Intermediate 8286' 9-5/8" 375 sx Arctic Set I 8314' 7822' +500 sx Class G 355 sx Class G 7294-9334' 8695-8797' 8813-8917, 8934-9003' 9008-9018' 9024-9034' Perforation depth: measured 9040-9058', 9074-9142', 9143-9151' , 9156-9182' , 9208-9228' true vertical 8142-8222' 8235-8316' 8329-8384' 8388-8396' 8400-8408' 8413-8427' 8440-8493' 8494-8500' 8504-8524' 8544-8560' Tubing (size, grade and measured depth) II I Packers7an~ ¢2S~V, N-80, ABM, 8rd @ 7898 (type and measured depth) o_~/~,,~ v,.. Baker SB-2 Hydro Packer @ 7909'/Otis RPB @ 2189' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2/25/87 -- Subsequent to operation 3/5/87 -- 14. Attachments Daily Report of Well Operations 146,104 .... 3798 187~244 .... 3794 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Copies of Logs and Surveys Run il;i - / ¢ ..... Form 10-404 Rev. 12-1-85 Operations En.qineerin.q Manager Date Submit in Dupli.cate Feet WGI-1 Daily Report of Well Operations Add Perfs 2/28/87 PT BOP/Lub to 4000 psi. OK. RIH w/7" G.S. Pull SSSV. RIH w/3-3/8" dummy gun/bailer. Very sticky - POH. PT hardlines to 4000 psi. OK. Pump in diesel/xylene wash. PT l ub to 4000 psi. OK. SD injection. RIH w/GR/CCL/Dummy gun. Tag PBTD @ 9213/log up. POH. 2/29/87 PT. OK. RIH w/select fire (6'btm, 8'top) gun #1, 3-3/8" 4 SPF, 120° phasing. Shoot 9156' to 9162 (6'), 9143' to 9151' (8'). POH - all shots fired. PT. OK. RIH w/gun #2, 20', 3-3/8", 4 SPF, 20° phasing. Shoot 9102' to 9122 (20'). POH - all shots fired. PT. OK. RIH w/select fire, gun #3, 3-3/8", 4 SPF, 120° phasing. Shoot 9074' to 9082 (8'), 9040' to 9048' (8'). POH - all shots fired. PT. OK. RIH w/select fire gun #4, 3-3/8", 4 SPF, 120° phasing. Shoot 9008' to 9018 (10'), 8974' to 8983' (9'). ...~. POH - all shots fired. PT 3500 psi. OK. RIH w/gun #5, 3-3/8", 4 SPF, 120° phasing. Shoot 8954' to 8974 (20'). POH - all shots fi red. PT 3000 PSI. OK. RIH w/gun #6, 3-3/8", 4 SPF, 120° phasing. Shoot 8885' to 8907 (8'). POH - all shots fired. PT 3000 PSI. OK. RIH w/gun #7, 3-3/8", 4 SPF, 120° phasing. Shoot 8863' to 8886 (22'). POH - no shots fired. PT 3500 PSI. OK. RIH w/gun #7 again. WGI-1 (cont.) Page Two Shoot 8863' to 8885' (22'). POH - all shots fired. PT 3500 PSI. OK. RIH w/gun #8, select fire, 3-3/8", 4 SPF, 120° phasing. Shoot 8853' to 8863' (10'), 8785' to 8797' (12'). POH - all shots fi red. PT 4000 PSI. OK. RIH w/gun #9, 3-3/8", 4 SPF, 120° phasing. Shoot 8725' to 8745'. POH - all shots fi red. ARCO ALas'ka, Inc. I::',.0. Box ~(-)0S60 Anchorage, ALaska 995~0 DA"f'Ei: March 24, ~ 98",;' R E F:' If.':' R E N C E: RC[ C'a s'ed % N C; I :~:..4, "~...."~ 8- R 7 F:'I::' C, I... o .."J N ('.-; :[ ~l: 9 2'"' 27 '"' 87 F:' F:' C L. o g '~-~'- W C; I :~: t '3 .... t - 87 F' F:' CI... o g W (]. I -,.'"'.::,";" 3"- i .... 8'7 F:' F:'CL. o g I.-to I. e F:'ina L E v a L u. a t.. i o n R un i , ':5" S c h DY r.' .'..; .'..;' I)~" e .s' .s' D r e ~..-. Dy' 'f' F;.'. A N. S .,,- '"' :!il '7 t 8 t /57 A F:' i::' I" 0 v e d ..................................................................................... D 1,57 T R I B IJ 'f' I 0 N '"' C e n t: '~'- a L t::' i I.r..:, s' '"' C h e v r o 'n '11' D & M · 11: E x i' .r..: n s' i o n E x I:, !. c,'~" a t: i c, n · ,,.-'" i_.'!: x x o n H .:'..'~ 'r' a 't' h ,::.', n · "' H c, b i L '11' STATE OF ALASKA ALASr,~ OIL AND GAS CONSERVATION COMIv,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [i_X Other feet 2. Name of Operator ARCO Alaska: ];nc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 258' S & 1209' W of NE cr, Sec. 11, T11N, R14E, UN At top of productive interval At effective depth At total depth 2355' N & 1798'W of SE cr, Sec. 11. Present well condition summary Total depth: measured true vertical 2~ T11N, R14E, UM 9335 feet Plugs (measured) 8643 feet Effective depth: measured true vertical 9292 feet Junk (measured) 8610 feet 5. Datum elevation (DF or KB) RKB 49' 6. Unit or Property name Prudhoe Bay Unit 7. Well number WGI-1 (33-2-11-14) 8. Permit number 79-3] 9. APl number 50-- f)29-?(1369 10. Pool Sadl erochi t None None Casing Length Size Conductor 75' 20" Su~ac~ 2703' 13-3/8" Intermedi ate 8286' 9-5/8" Liner 1410' 7" Cemented Measured depth 330 sx Arctic Set 4760 sx Arctic Set II 375 sx Arctic Set I +500 sx Class G 355 sx Class G True Vertical depth 103' 103' 2731' 2731' 8314' 7822' 7294-9334' 7483'-8642' Perforation depth: measured 8695-8725' 8745-8785' 8813-8853' 8907-8917' 8934-8954' 8983-9003' 9024-9034' 9048-9058' 9082-9102' 9122-9142' 9162-9182' 9208-9228' true vertical 8142-8166', 8181-8213', 8235-8266', 8308-8316', 8329-8345', 8363-8383' , 8400-8408' , 8419-8427' , 8446-8462' , 8477-8493' , 8508-8524' , 8544-8560' Tubing (size, grade and measured depth) 7", 29#, N-80, ABM, 8rd @ 7898' Packers and SSSV (type and measured depth) 9-5/8" Baker SB-2 Hydrn Packc_r fa 79flq'/flf. i~ RPR fa ?lRq' 12.Attachments Description summary of proposal I~ Detailed operations program ii BOP sketch 13. Estimated date for commencing operation December 20, 1986 14. If proposal was verbally approved Name of approver Date approved Signed 4,~~~~//¢/'////×'~ Title Operations En.cjineerin.q Manager Commission Use Only Date Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test I "°' [] Location clearance /~ -~ ~ ~ by order of ..... ~0mmissioner the commission Date Form 10-403 Rev 12-1-85 WJP (263-4511) Submit in triplicate WGI-1 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations within the Sadlerochit interval in Well WGI-1. The proposed perforation intervals are as follows: Existing Perforations 8695-8725 (30') 8745-8785 (40') 8813-8853 (40') 8907-8917 (10') 8934-8954 (20) 8983-9003 (20) 9024-9034 (10) 9048-9058 (10) 9082-9102 (20) 9122-9142 (20) 9162-9182 (20') 9208-9228 (20') TOTAL - 260' Proposed Perforations 8725-8745 (20') 8785-8797 (12') 8853-8907 (54') 8954-8983 (29) 9008-9018 (10) 9040-9048 ( 8 ) 9074-9082 ( 8 ) 9102-9122 (20) 9142-9150 ( 8 ) 9156-9162 (6') TOTAL - 175' Reference BHCS of 7/27/79 A 500 psi WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. The well will be loaded with an appropriate fluid, the perforating performed, and gas injection resumed with the wellbore load fluid being displaced into the formation. No flaring 'is anticipated. I 4 3 /i '1 i I iI II I I i I 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) ,3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF W I REL I NE BOP EQU I PMENT · ARCO Oil and Ga '-'ompany North Ala.~ District Post Office dox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District OperaTions Engineer October 1, 1980 Reference- ARCO Pressure Surveys ~!~OI-l..~, 8/10/80 Pressure Survey WCI-2 8/13/80 Pressure Survey ease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering TRanSMITTAL #655 D~STR~BUT~ON North Geology R & D Drilling Eng. Manager D & M Geology State of Alaska ARCO Oil and Gas Company ~ a Division of AtlanhcR~chl~eldCompan¥ Exxon Mobil Getty Phillips Sohio Marathon Chevron ARCO 0il and Gas :mpany Post Office ~?x ~:~-~i September 9, 1980 Mr. Hoyle Hamil ton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Subject~(Permit no. 79-31) (Permit no 79-43) ~aI - 3 (Permit no. 79-49) ~aI - 4 (Permit no. 79-50) FILF'. Dear Sir: Enclosed please find our Sundry Notices of Subsequent Report, for.the subject wells, d~tailing the individual well perfor- ating procedures. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/sp Enclosures ,, Form 1'0-403 REV. 1-10~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OI L 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---" for such proposals.) WELL I.--J OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 258' FNL, 1209' FEL, Sec. ll, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 49' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20369 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI - 1 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 2, TllN, R14E, UN 12. PERMIT NO. 79-31 )ort, or Other Data NOTICE OF INTENTION TO.' FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* mt,er) Perforate for injection (NOTE-' Report results of multiple completion on Welt Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Began perf.operations. August 8, 1980. NU tree & choke manifold and test same. Install wireline BOP's and test w/5000 psi. Install and test lubricator. Pull ball valve.. Perf'd following intervals w/4~,.spf, correlated to GR/BHCS,log 7/27/79' 9206 - 9226, 9160-~9180, 9120 '~ 9140, 9080 - 9100, 9046 Z' 9056, 9022 :' 9032, 8972 - 9002, 8932 - 8952, 8906 ~' 8916, 8874 - 8884, 8812 - 8852, 8744 -8784, 8694 - 8724. P~tpd total of 171 .~ Bbls diesel between gun runs. Install tree cap. F1 owed well. Set and tested safety ball valve. Bled balance and control lines. Bled tbg press, safety valve held ok. Install tree cap and test w/5000 psi, ok. Secure well. Released well to CCP 0230 hrs 8/12/80. " TITLE District Drillin§ En.q. (This space for State office use) APPROVED BY CONOITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form 10-403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" In Duplicate STATE OF 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--" for such proposals.) WELL L--J OTHER GAS INJECTION 2. NAME OF OPERATOR Atlantic Richfield company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 258'S & 1209'W of NE cr Sec. 11, T11N, R14E, UM rs. APl NUMERICAL CODE '50-029-20369 6. LEASE DESIGNATION ANO SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI - 1 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 49' RKB 14. Sec. 2, T11N, R14E, UM 12. PERMIT NO. 79-31 Check Appropriate Box To Indicate Nature of Notice, Re 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [_._.J PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Perforate for Injection SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTER lNG CAS lNG SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all 13ertlnent dstalls, and give pertinent dates, Including estimated date of starting any proposed work. ARCo Oil and Gas Company proposes to perforate selected intervals within the sadlerochit for injection of produced gas. The perforated intervals will be reported on a subsequent report. A 5000 PSI WP BOP/lubricator, tested to working pressure, will be used on all wireline work. The Downhole safety valve will be installed and tested upon conclusion of the job. The well will be flared to burn pit for clean up only after perforating. Estimated Start 8/6/80 16. I hereby certify_that the fo_regolng is true and correct TITLE District Drillin9 EngineerDATE 8/1/80 (This space for State office use) CONDITIONS OF~APPROVAL, IF~NY.. TITLE COMMIS$ION~i~ See Instructions On Reverse Side Approved Returned ALASKA OIL AND GAS CONSERVATION' COMMISSION t{oyle H. Hamilton Chairman/Commissi~ Thru: Lonnie C. Smith '~ Commissioner Bobby Foster~'~.~7.- Petroleum Inspector August 19, 1980 Witness Test of the SSSV on ARCO's W.G.I. #1. Monday August, !!, 1980 Mr. Chuck Sevcik, Arco drilling foreman, contacted me on August 10, and requested that I witness the test of the SSSV on W.G.I. #1 which I did. As the attached report shows the valve tested OK. In summary, I witnessed the SSSV test on Arco's W.G.I. #1. Plt/f,cc i ;'c 1 i ] ~om, arks - ARCO Oil and Gas~. ,npany August 1, 1980 Hoyle Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: WGI 1 - Permit No. 79-31 WGI 2 -" " 79-43 WGI 3-" " 79-49 WGI 4 -" " 79-50 Dear Sir: Enclosed please find Sundry Notices detailing work and start dates planned for the above mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV:ruo Form 10-403 REV. 1-1(%73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF 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--" for such proposals.) Ow~L~LE]WELLGAS [~ OTUER GAS INOECTION 2. NAME OF OPERATOR Atlantic Richfield company 3, ADDRESS OF OPERATOR P. O. Box 360, Anchorage, 4. LOCATION OF WELL At surface Alaska 99510 258'S & 1209'W of NE cr Sec. 11, T11N, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 49' RKB 14, Check Appropriate Box To Indicate Nature of Notice, Re J COMM ...... j COMM~--' I coMM .... t RES ENG./ 5. APl NUI~'ERICAL CODE --'1~] ENG_~'- 50-029-20369 ADL 28302 ~-4 ~E~b-~ Prudhoe Ba~ Unit J STATTEC~ ,. ,,, 9. WELL NO. ~GJ - 1 CONFER: ~o. m~o A.o .oo~. o. w~,~F' "" P~udhoe Ba~ Field-Prudhoe Ull-~c 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE* Sec. 2, TllN, R14E, UM 12. PERMIT NO. 79-31 )ort, or Other Data NOTICE OF INTENTION TO.' FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Perforate for Injection SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE; Report results of multiple completion on Well ComlHetlon or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting airy proposed work. ARCo Oil and Gas Company proposes to perforate selected intervals within the sadlerochit for injection of produced gas. The perforated intervals will be reported on a subsequent report. A 15000 PSI WP BOP/lubricator, tested to working pressure, will be used on all wireline work. The Downhole safety valve will be installed and tested upon conclusion of the job. The well will be flared to burn pit for clean up only after perforating. Estimated Start 8/6/80 SIGNED / ' ~. · _ TITLE District Drilling EngineeroATE 8/1/80 (This space for State office use) APPROVED BY .. ~~L, I'F~N:~' ~ CONDITIONS OF APP~.OV Y: See Instructions On Reverse Side 4&.pp roved Copy 'Returned Norlh Alas!~- D~'*:~dc~ Post O~fic~. x 360 Anchora~:e, Al3ska ~9510 Telephone 907 277 5637 November 7, 1979 Reference: Enclosed are },lagnetic Tapes for the following ARCO wells: ~~ 7/Z7/79 Tape #57005 Schlumberger ~i-10 8/31/79 Tape I~"57011 ': ~/~lease sign and return the attached copy as receipt of data,. K,. J,_ S'Mqlstrom North Engineering TR:~NSMITTAL # 464 DISTRIBUTION North Geolo~' Dr i 11 ing -Eng. Manager R&D Geolo~r State of Alaska ~XXOT1 Mobil Getty Sohio Marathon Phillips Chevron AnchorF A!a s!,:a 09510 Te!epho,,,; Dj72775G37 Cr~tober 16, 1979 ]Reference' Enclosed are Cased Hole Logs 'for the following ARCO wells' D.S.. 4-15 9/31/79 CNL Run 2 5" D.S. 12-3 8/29/79 TDT Run 1 . , l~ 5' D S ~/.-3 8/29/79 TDT Rum 2 D.S. 12 -3 9/9/79 CBL ~un 1 5" ~?..~._~.22 - 3 ~9/79 'CBL Rrm,2 5" .?~' .... 27/79 ~L. ~1 5" F Please si~ and ~etu~ the attached copy as ~ece~pt o~ data. K. J. Sahlstrom North Engineering T_KANS~'!ITfAL # 410 D [ S']'R []F l'[' I' OX I)F5 t 1 · iX ~l~ c~Of R & I3 Goo] o,.~ v State o~ Alaska blob i ] (;etty Sohio Phil 1 C}]C:\r FOIl /;, North Alaska Diskict Post O~'fic: Anchorase,_ Te ' lep,,ome 907 °77 5S37 October 16, 1979 Reference' Enclosed are Open Hole Logs for the following ~LRCO wells' ,/¢~¢WGI ;q~b 7'/2'7/79 EDC/CNL 2"6 S" " " BHCS 2" & 5" " " DIL 2" & 5" " " CPL 5'~ D,¢S. 5-10 8/51_/79 RFT ease sign az:d return the attached copy as receipt of data. K. J, Sahlstrom North Engineering TP&NSMITTAL # 408 Eng. ~[anager (]etty R ~, I) Sohio Geology blaratt State of Alaska Phillips D & ~,I Chevron -.,~.r4.?e Norlh Alaska Post Office gox Anchoraga, Alaska 99510 Telephone 907 277 5637 September 20, 1979 Ee£er'ence' Enclosed are magnetic tapes for the following ARCO ~vells. CPF-1 9/14/79 R~m 1 Dresser #651 tt It !t 2 tt t~t tl t! ,I10/79 Run .1 Dresser #644 CNL/GR/CCL · g/Please sign and return the attached cop), as receipt of data, ~ ,,~-, ' A' , Very truly yours, CAL, CDL-C~LOG,DIFL-AL If It K. J. SM~lstrom North Engineering TP4tNSI¥IITFAL # 355 North Geology Drilling Geology State of Alaska Fxxon ~ lob i ]. (.;etty Sohio Marathon Phi 11 ips Chevron ARCO Oil and Ga~¥ Company Alaska Post Office ,.,ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 7, 1979 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska '99501 Subject' DS 3-9, Permit No. 79-22 ~-12..z~, Permit No.' 79-32 ? ' WGI #1 ~'~Permit No. 79-31 Dear Si r' Enclosed please fi nd a Completion Report along wi th the Drilling History and Gyroscopic Survey for each of the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'jh Attachments ARCO 011 and Gas Company is a Division of AtlanticRichfieldCompany Form P--7 SUBMIT IN DUPLIC~ TE* STATE OF ALASKA (see other in- structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: OIL GAS r--] WELLE] WELLI I DRYF-1 OtherGas Injection b. TYPE OF COMPLETION: NEW WORK DEEP- F--I PLUG [~l DIFF. WELL[~] OvER E~] EN I I BACKI I RESER.[~] Other 2. NAME OF OPERATOR ARCO 0il and Gas Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, AK 99510 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* 5. APl NUMERICAL CODE 50-029-20369 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI #1 (33-2-11-14) ?1~, FIEI~) AND ~,OOL, ¢ZR.WILD~AT vruanoe ~av ~i Prudhoe Oi'l Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) ~2~f"~ & 1209'W of NE cr Sec ll, TllN, R14E, UM At top prod. interval reported below I948'N & 1812'W of SE cr Sec 2, TllN, RI4E, UM At total depth 2355'N & 1798'.W of SE cr Sec 2, TllN, R14E, UM Sec 2, TllN, R14E, UM 2. PERMIT NO. 79-31 13. DATE SPUDDED ]14. DATET.D. REACHED i15. DATECOMP, SUSP, ORABAND. Im. ELEVATIO~S]BF RKB RT, 7/11/79 I 7/28/79 I 8/7/79 I 18. TOTAL DEPTH, MD & TVD 19. PLUG BACK MD & TVD 20 IF MULTIPLE COMPL .... '"~' ,i 9335'MD 8643ITVD 9L)§~MD 861-'---U ,VD I''HOWMA.N¥*s]ngle_" /121' ROTARY TOOLSAl l 22. PRODUCING INTERVAL(S), OF THIS COMPLETION --TOP, BOSOM, NAME (MD & TVD)* Top Sadlerochit 8681'MD 8131'TVD Base Sadlerochit 9250'MD 8577'TVD GR, ETC)* 117. ELEV. CASINGHEAD I INTERVALS DRILLED BY CABLE TOOLS 23. WAS DIRECTIONAL SURVEY MADE Yes 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP/BHCS/CAL/GR, FDC/CNL/CAL/GR, CNL/CCL/GR 25. 26. CASING SIZE j WEIGHT, LB/FT. 20" ]94# Nel ded 13-3/8" 172# Butt 9-5/8" 147# Butt CASING RECORD (Report all strings set In well) H-40 I 103' 3Q" 330 sx Arcticset N-80 I 2731' 17-1/2" 4760 .~x Arcticset IT omi IN-80& I 8314' 12-1'/4" I .Ell(1 ~× C. la~s g & _t7.:; sx 1s00-951 'I - - AMOUNT PULLED ~rctirset ! cmt SIZE 1, ITOP (MD) ?7924' LINER RECORD BOTTOM (~) 2165' 28. PERFORATIONS OPEN TO PRODUCTION . N/A SACKS CEMENT* 3555x Clas~ (Interval, size and number) 27. SIZE 5-l/Z" TUBING RECORD SCREEN (MD) DEPTH SET (MD) PACKER SET (MD) 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ..... N/A PRODUCTION DATE FIRST PRODUCTION IPRODUCTION METHOD (Flowing, gas lift, pumping~ize and type of pump) PROD'N FOR OIL-BBL. GAS--MCF. ITEST PERIOD > I I OIL--BBL. GAS--MCF. DATE OF TEST. HOURS TESTED CHOKE SIZE FLOW TUBING CASING PRESSURE CALCULATED PRESS. 24-HOUR RATE 31. DISPOSITION OF GAS (Sold, used for fuel vented, etc.) 32. LIST OF ATTACHMENTS Drilling History and Gyroscopic Survey I WELL STATUS (Producing or shut-In) WATER-BBL. I GAS-OIL RATIO WATER-BBL. IOIL GRAVITY-APl (CORR.) ITEST WITNESSED BY 33, I hereby certify that the foregoing anJ~ attache~,d information is complete and correct as determined from all available records. SIGNED ,'~~, ~~~' TITLE District Drilling Engi *(See instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item' 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Items 20, and 22' If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing 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 each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 35. GEOLOGIC MARKERS ,,. NAME MEAS. DEPTH TRUE VERT. DEPTI None Top Sadl erochi t 8681 ' 81 31 ' ~ase Sadlerochit 9250' 8577' 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. ._ None , DS WGI #1 Drilling History API 50-029-20369, ADL 28302, Permit No. 79-31 Spudded well @ 1900 hrs 7/11/79. Drld 17-1/2" hole to 3~639'. Ran 13-3/8" csg w/FC @ 2645' & shoe @ 2731' Cmtd w/4760 sx Arcticset II cmt. Installed & tstd pkoff. Did 122 sx top job. Tst~ BOP & csg. Drld shoe & cmt + 10' new hole. Tstd form to 12.5 ppg MW equiv. Drld 12-1/4" hole to 8~2~_~!'. Ran multishot. Tstd BOP. Ran 9-5/8" csg w/shoe @ 8314'. Cmtd w/500 sx Class G cmt. ~~x__.Ar~£~.t~i, cse~. I .cmt into 9-5/8" x 13-3/8" a~nn thru lower FO. Pumped 280 bbls Arcticpk thru upper FO followed by 75 sx Arcticset I cmt. Drld shoe, cmt, & 10' new hole. Tstd form to .65 psi/ft grad. Drld to 9~33Q' Ran DIL/SP/BHCS/BAL/GR, FDC/CNL/CAL/GR & CNL/CCL/GR. Ran & cmtd 7" lnr w/ 355 sx Ciass G cmt. Top of lnr @.-8021~', shoe @ 9334'. Chgd over to CaC12 & tstd csg to 3000# psi. Ran gauge ring & jnk bskt. Ran gyro sur. Ran 7" tbg w/pkr 7909'. ND BOP. Installed & tstd Xmas tree to 5000 psi. Displ tbg w/diesel. Set & tstd pkr. Pulled dummy valve & ran GR/CNL/CCL logs. Ran & set Otis ball valve, tstd cntrl lns to 5000 psi. RD wireline, began,long term tbg tst. Released rig @ 1500 hrs 8/7/79. COHPLETION REPORT ARCO OIL AND GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COHPUTATION COMPUTED FOR SDC BY F N LINDSEY & ASSUCIATES 15 AUG 79 WELL WGI-! K B ELEV 49 FT D~CLINATION 31 DEG EAST RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY ! B N ELECTRONIC COMPUTER TRUE AS0 DRIFT VERTICAL DEPTH ANGLE DEPTH D H SUB DRIFT SEA DIREC DEG. 0 0 0 0,00 100 0 0 100000 200 0 0 200,00 300 0 0 ' 300000 400 0 0 400,00 500 0 0 500.00 600 0 0 600,00 700 0 0 700,00 800 0 0 800.00 900 0 0 900,00 1000 0 0 1000.00 -49.00 N O.OOE 51.00 N 0,00£ 151,00 N O,OOE 251.00 N O,OOE 351,00 N O.OOE 451,00 N O,OOE 551.00 N O.OOE 651.00 N O.OOE 751.00 N O.OOE 851,00 N O,OOE 951000 N O,OOE 1100 0 0 1100,00 1051000 N O.OOE '~00 0 0 1200.00 1151,00 N O.OOE .300 0 0 1300,00 1251.00 N O,OOE 1400 0 0 1400000 1351.00 N O,OOE 1500 0 0 1500.00 1451,00 N O.OOE 1600 0 0 1600.00 1551000 N O,OOE 1700 0 0 1700.00 1651,00 N O,OOE 1800 0 0 1800.00 1751.00 N O,OOE 1900 0 0 1900.00 1851000 N O,OOE 2000 0 30 1999,99 1950,99 S85.00E 2100 0 0 2099099 2050,99 N O,OOE 2200 0 0 2199,99 2150.99 N O,OOE 2300 0 30 2299,99 2250.99 S61,50E 2400 0 30 2399,99 2350.99 S22,00E TOTAL COORDINATES 0,00 0~00 0,00 0,00 0,00 0,00 0.00 0.00 0.00 0,00 0,00 0,00 0,00 0,00 0,00 0.00 0.00 0.00 0.00 0.00 0,26 0,52 0,52 0,70 0.07 0.00 W 0.00 W 0.00 W 0.00 W 0~00 W 0,00 W 0,00 W o,0o W 0000 W' 0.00 W 0.00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 w 0,00 W 0,00 W 0.00 W 0,00 W 0.28 E 0.57 E 0057 E 0,88 E 1.45 E CLOSURES D I STANCE ANGLE D M S 0.O0 $ 0 0 O w Oe00 $ 0 0 0 W O.O0 $ O 0 O W 0,00 S 0 0 0 W 0,O0 S O 0 0 W 0.00 $ 0 0 0 W 0,00 $ 0 0 0 W 0.00 S 0 0 0 W 0,00 $ 0 0 0 W 0000 S 0 0 0 W 0.00 $ O 0 0 W 0,00 S 0 0 O W 0.00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 5 0 0 0 W 0,00 S 0 0 0 W O.O0 S 0 0 0 W 0.00 S 0 0 0 W 0,00 S '0 0 0 W 0.00 $ 0 O: 0 W 0.38 N 47 30 0 E 0.77 N 47 30 O E 0,77 N 47 30 0 E 1,19 N 51 14 6 E 1.45 N 87 11 I E DOG LEG SEVERITY DEG/IOOFT 0,000 0,000 0,000 0,000 0,000 0,000 0,000 0,000 0.000 0.000 0,000 0,000 0,000 0.000 0,000 0,000 O,OOO 0.000 0,000 0,000 0,500 0,500 0,000 0.5OO 0.335 SECTION DISTAaCE 0.00 0,00 0,00 0.00 0,00 0.00 0,00 0,00 0,00 0.00 0,00 0,00 0,00 0,00 0.00 0,00 0,00 0,00 0o00 0,00 0,19 0,3~ 0,38 0.49 -0,24 'ARCO O/G WGI-1 GYROSCOPIC SURVEY 15 AUG 79 RECORD OF SURVEY ALL CALCULATIONS PERFORHED BY ! B M ELECTRONIC COHPUTER TRUE MEAS. DR!FT VERTICAL DEPTH ANGLE DEPTH D iv, SUB DRIFT SEA DIREC DEG. 2500 0 0 2499.99 2450,99 N O.OOE Z600 0 30 2599.98 2550.98 N 1.25E 2700 0 0 2699.98 2650.98 N O.OOE 2800 0 30 2799.98 2750.98 S19.50E 2900 2 0 2899.96 2850.96 N46.00E 3000 0 30 2999.93 2950.93 H 4,00E 3100 4 30 3099.81 3050.81 N16.00W 3200 5 0 3199.47 3150.47 N26.00W '3300 5 0 3299.09 3250.09 N 5.0OW' 3400 6 30 3398.58 3349.58 N 2.00E 3500 9 45 3497.57 3448.57 N O.OOE 3600 10 30 3596.01 3547.01 N 9.00W 3700 12 30 3694.00 3645.00 NiO.OOW 3800 12 15 3791.67 3742.67 N23.00W 3900 14 0 3889.06 3840.06 N28.00W 4000 15 0 3985.87 3936.87 N24.00W 4100 18 0 4081.74 4032.74 N22.00W ~200 21 30 4175.84 4126.84 N22.00W +300 24 0 4268.06 4219e06 N21.OOW 4400 25 30 4358.87 4309.87 N22,OOW 4500 25 30 4449,13 4400,13 N21.OOW 4600 24 30 4539.76 4490.76 N21.00W 4700 24 15 4630.84 4581.84 N21.OOW 4800 23 15 4722.37 4673.37 N20.OOW 4900 23 15 481~+.25 4765,25 N20.OOW 5000 22 45 4906.30 4857.30 N20.OOW 5100 22 30 4998.61 4949.61 N20.OOW 5200 23 30 5090.66 5041.66 N18.00W 5300 24 0 5182.19 5133.19 N17.00W TOTAL COORDINATES 0.13 N 1.75 E 0,56 N 1.76 E 1,O0 N 1,76 E 1.05 N 2,07 E 0.63 N 3.85 E 2.56 N 4.75 E 6,88 N 4.30 E 14,60 N 1.34 E 22.95 N 0.97 W 32.96 N 1.23 W 47.09 N 0..98 W 64.60 N · 2,36 W 84.26 N 5.65 W 104.76 N 11.73 W 125.25 N 21.50 W 147.75 N 32.47 W 173.89 N 43.57 W 205.21N 56.22 W 241,19 N 70.40 W 280.14 N 85.74 W 320.20 N 101.52 W 359.65 N 116.66 W 398-18 N 131.45 W 435.90 N 145.56 W 473.00 N 159.06 W 509.72 N 172.42 W 545.87 N 185.58 W 582.81N 198.30 W 621,22 N 210.41 W C L 0 S U R E $ DISTANCE ANGLE D M 1,76 N 85 44 48 ~ 1,85 N 72 10 15 E 2.03 N 60 25 23 E 2,32 N 62 59 29 E 3,90 N 80 39 33 E 5.40 N 61 39 10 E 8.11 N 32 1 43 E 14.66 N 5 14 59 f 22.97 N 2 25 48 W 32.98 N 2 ~ 52 ~ 47.10 N 1 12 14 W 64.64 N 2 5 56 W 84.49 N 3 50 29 W 105.42 N 6 23 21W 127,08 N 9 44 29 W 1~1.28 N 12 23 46 W 179,26 N 14 4 1W 212,78 N lb 19 22 W 251.26 N 16 16 17 W 292.97 N 17 1 3 W 335.91 N 17 35 29 W 378.10 N 17 58 20 W 419,32 N 18 16 12 W 459.57 N 18 27 55 W 499.03 N 18 35 12 W 538.09 N 18 41 22 W 576.55 N 18 46 36 W 615.62 N 18 47 27 W 655.88 N 18 42 42 W DOG LEG SEVERITY DEG/iOOFT 0,500 0,500 0,500 0.500 1.506 1.500 4,002 0,506 1,820 1.503 3.251 0.~07 2.001 0.636 1.774 1.035 3.006 3,500 2.505 1.511 0,431 1,000 0.250 1~012 0.000 0.500 0.250 1,049 0,527 SECTION OISTANCE -0,25 0,16 0,59 0,57 -0,22 1,46 5,77 13,95 22,~1 32.43 46,16 63.55 83.45 104.79 126,92 151,27 179.21 212.55 250.75 292,12 334.66 376,47 417,~0 457,20 496,35 535,10 573,26 612.09 652.22 'ARCO O/G WGI-! GYROSCOPIC SURVEY 15 AUG 79 RECORD OF SURVEY ALL CALCULATIONS PERFORNED BY I B N ELECTRONIC CONPUTER TRUE NEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES C L 0 5 U R E 5 DISTANCE ANGLE D M 5 DOG LEG SEVERITY DEG/IOOFT 5400 24 45 5273.27 5224,27 N17,OOW ~500 22 30 5364.88 5315,88 N18,00W 5600 22 30 5457,27 5408,27 N19.00W 5700 24 0 5549,15 5500,15 N18,00W 5800 27 0 5639.40 5590.40 NXT,00W 5900 28 15 5728.00 5679,00 N15,00W 6000 29 0 5815,77 5766,77 N15,00W 6100 29 30 5903,02 5854,02 N16,00W 660,68 N 698.90 N 735,19 N 772.62 N 813.68 N 858,25 N 904,52 N 951,61N 6200 32 0 5988,96 5939,96 N20,OOW 1000,22 N 6300 32 0 6073,76 6024,76 N18,00W 1050,32 N 6400 32 0 6158.57 6109,57 N16.00W 1101.00 N 6500 32 0 6243,37 6194,37 N16.00W 1151.93 N 6600 32 15 6328,06 6279,06 N17,00W 1202.92 N 6700 30 0 6413,66 6364,66 N19,00W 1252,08 N 6800 30 0 6500,26 6451,26 N19.00W 1299,85 N 6900 30 0 6586,86 6537,86 N19,00W 1346.63 N 7000 BO 0 6678,47 6624,47 N19,00W 1393.90 N vlO0 29 30 6760,29 6711,29 N20,OOW 1440,68 N .200 28 30 6847,75 6798,75 N19.00W 1486,38 N 7300 27 30 6936.04 6887,04 N19.00W 1530.77 N 7400 28 0 7024.54 6975,54 N19.00W 1574,79 N 7500 28 30 7112,63 7063,63 N17,00W 1619.80 N 7600 29 0 7200.30 7151,30 N18.00W 1665.68 N 222,48 234,53 246,67 259,19 272,14 284,92 297,32 310.37 326,17 343,42 358.91 37~.52 388,62 697,14 N 18 36 37 W 737.20 N 18 33 0 W 775.47 N 18 32 51W 814,94 N 18 32 43 W 857,98 N 18 29 34 W 904,~1N 18 21 54 W 952,13 N 18 11 45 ~ 1000,94 N 18 3 51 W 1052,06 N 18 3 40 W 1105,04 N 18 6 22 W 1158,02 N 18 ~ 20 W 1210,98 N 17 57 56 W 1264,14 N 17 54 14 W 404,59 W 1315,82 N 17 54 28 W 420.87 W 437.15 W 453,43 W 469,99 W 486,18 W 501,46 W 516,62 W 531.25 W 545,71W 1365.82 N 17 56 52 W 1415,81N 17 59 5 W 1465.80 N 18 1 10 W 1515,40 N 18 4 4 W 1563.87 N 18 ~ 44 W 1610,81N 18 8 17 W 1657,37 N 18 9 45 W 1704.70 N 18 9 28 W 1752.79 N 18 8 23 W 7700 29 0 7287,76 7238,76 N17.OOW 1711,91N 560.29 W 7800 29 15 7375,12 7326,12 N15,00W 1758,70 N 573,70 W 7900.29 30 7462,26 7413,26 NII,OOW 1806.48 N 584.73 W 8000 29 15 7549,40 7500,40 NIO.OOW 1854.71 N 593,67 W 8100 30 0 7636.33 7587,33 N 9,00W 1903,46 N 601,83 W 8200 29 45 7723,04 7674,04 N 6.00W 1952.84 N 608,3~ W 1801.27 N 18 7 21W 1849.91N 18 4 0 W 1898,76 N 17 56 10 W 1947,41N 17 44 57 W 1996,34 N 17 B2 45 W 2045.40 N 17 18 8 W 0,750 2.255 0,383 1,509 3,007 1,3Z~ 0,750 0,556 2,741 1,060 1,060 0,000 0,379 2,305 0,000 0,000 0,000 0.b56 1,026 1,000 0,500 0.676 0,552 0,485 0.539 1.002 0,346 0.791 0,780 SECTION DISTANCE 693.37 733.30 771,37 810.63 ~53.52 899.81 9~7.68 996.48 1047,37 1100.03 1205.77 1258.83 1310,29 1359,9~ 1409,67 1459,87 1~08,6~ 1556,77 1603,43 1696,~3 1744,75 1793,06 1841,64 1890,69 1939,70 1989,06 203~,66 )s, RCO O/G 1,','G I-1 GYROSCOPIC SURVEY AUG 79 RECORD OF SURVEY ALL CALCULATIONS PERFORHED BY I b H ELECTRONIC CONPUTER TRUE HEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES R3OO 30 0 7809.75 7760,75 N 3,00W 2002.50 N 3400 30 O 7896.36 7847,36 N O.OOE 2052.47 N 8500 32 45 7981,72 7932.72 N 4,DOE 2104.49 N 8600 34 0 8065.23 8016.23 N 6.00E 2159,29 N 8700 38 0 8146,12 ~097,12 N 3,00E 2217.87 N 8800 38 30 8224,65 8175,65 N 3,ODE 2279,69 N 8900 38 45 8302,77 8253.77 N 3,00E 2342,03 N 8948 38 0 8340,40 8291,40 N 2.00E 2371,80 N 9000 38 0 8381.38 8332.38 N 1.ODE 2403.80 N 9100 38 15 8460,05 8411,05 N 3,ODE 2465,50 N 612.24 613,55 611,73 606,94 602,33 599,09 595,82 594.52 593.68 591,5~ 9200 39 O 8538.17 8489.17 N O'00E 2527.89 N 589.89 W 9293 38 45 8610.57 8561.57 N 1,00E 2586.26 N : '589.39 W 9335 38 45 8643.33 8594,33 N 1.00E 2612.54 N 588.93 W BOTTOM HOLE CLOSURE 2678,10 FEET AT N 12 42 12 W CLOSURES DISTANCE AiNGLE D M S DOG LEG SEVERITY DEG/IOOFT 2094,00 N 17 0 1W 2142.22 N 16 38 3~ W 2191.60 N 16 12 29 W 2242.97 N 15 41 59 W 2298,20 N 15 11 38 W 2357.10 M 14 43 26 W 2416,63 N 14 16 24 W 2445.18 N 14 4 19 W 2476.03 N 13 52 2] W 25~.47 N 13 29 29 W 2595.81N 13 8 6 W 2652.57 N 12 50 16 W 267~,10 N 12 42 12 W 0.791 1,500 2,989 1.398 4.158 0.500 0,250 1.751 1,184 0,806 ~405 0,500 0,000 SECTION Ol&TANCE 2087,97 2137.02 2187,~7 2239,79 2295,94 2355.55 2~15.66 2444,42 2475~46 2~35,19 2595,71 2692,55 2678.10 ARCO O/G WGI-1 GYROSCOPIC SURVEY HEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTh. 15 AUG 79 TRUE ~IEASURED VERTICAL SUB ND-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 149 149. 100 0 0 249 249. 200 0 0 349 349. 300 0 0 449 449. 400 0 0 549 549. 500 0 0 649 649. 600 0 0 749 769, 700 0 0 849 849. 800 0 0 949 949. 900 0 0 1049 1049, 1000 0 0 1149 1149, 1100 0 0 1249 1249. 1200 0 0 1349 1349. 1300 0 0 1449 1449. 1400 0 0 1549 1549. 1500 0 0 1649 1649. 1600 0 0 1749 1749. 1700 0 0 1849 1849. 1800 0 0 1949 1949. 1900 0 0 2049 2049. 2000 0 0 2149 2149. 2100 0 0 2249 2249. 2200 0 0 2349 2349. 2300 0 0 2449 2449. 2400 0 0 2549 2549, 2500 0 0 2649 2649, 2600 0 0 2749 2749. 2700 0 0 2849 2849, 2800 0 0 2949 2949. 2900 0 0 3049 3049, 3000 0 0 3149 3149. 3100 0 0 3250 3249, 3200 1 1 3350 3349. 3300 1 0 3451 3449. 3400 1 0 3552 3549. 3500 3 2 0.00 S 0.00 S 0.00 S 0.00 0.00 $ 0.00 $ 0.00 5 0.00 5 0.00 5 0.00 5 0.00 0.00 5 0,00 5 0,00 S 0.00 $ 0,00 $ O.O0 0.00 0,09 N 0,36 N 0.52 N 0.61 N 0,44 N 0.07 5 0,23 N 0.86 N 1.07 N 0,57 N 1.76 N 10.62 N 18.64 N 27.69 N 39,44 N 56,06 N 0,00 W 0.00 W 0.00 W 0,00 w 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 W 0,00 ~ 0.00 W O,O0 W 0.00 W 0.00 W 0,00 W 0,00 W 0,04 E 0,58 E 0,57 E 0.62 E 1,21 E 1.71 E 1,75 E 1,76 E 1.82 E 2,59 E 4,66 E 4,95 E 3,05 E 0.19 W 1.23 ~ 1,06 W 0,62 W 'ARCO O/G WGI-1 GYROSCOPIC SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 15 AUG 79 TRUE MEASURED VERTICAL SUB MD=TVD VERTIEAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 3654 3649, 3600 4 3756 3749, 3700 7 3 3859 3849, 3800 9 3962 3949, 3900 12 3 4066 4049, 4000 16 4 4171 4149, 4100 22 6 4279 4249. 4200 30 8 4389 4349. 4300 40 10 4500 4449, 4400 51 11 4610 4549, 4500 61 10 4?20 4649, 4600 71 10 4829 4749, 4700 80 9 4938 4849, 4800 89 9 5046 4949, 4900 97 8 5155 5049, 5000 105 8 5264 5149, 5100 114 9 5373 5249, 5200 124 5483 5349, 5300 134 10 5591 5449. 5400 142 8 5700 5549, 5500 150 8 5811 5649, 5600 161 5924 5749, 5700 174 13 6038 5849, 5800 189 15 6153 5949, 5900 204 15 6271 6049, 6000 222 18 6389 6149, 6100 240 18 6507 6249, 6200 257 17 6625 6349, 6300 276 19 6741 6449, 6400 292 16 6856 6549, 6500 307 15 6972 6649, 6600 323 16 ?087 6?49, 6700 338 15 7201 6849, 6800 352 14 7315 6949, 6900 365 13 7428 7049e 7000 378 13 74,80 N 4,03 W 95,96 N 8,50 W 116,58 N ~?,ll W 138,90 N 28,38 W 164,36 N 39,64 W 195,59 N 52,34 W 233,31 N 67,~5 W 275,76 N 8~,98 W 320,14 N 101,50 W 363,52 N 118,15 W 405,79 N 134,36 W 446.65 N 149,47 W 486,96 N 164,14 W 526,39 N 178,49 W 565,81 N 192,62 W 607,16 N 206e06 W 649,92 N 219,18 W 692,5~ N 232,48 W 731,93 N 245,55 W 772,56 N 259,17 W 818.37 N 273,56 W 869,19 N 287,85 W 922,35 N 302,16 W 977.07 N 318,19 W 1035,63 N 338,56 W 1095,25 N 357,25 W 1155,31 N 374,49 W 1215,40 N 392.50 W 1271,37 N 411,24 W 1325,83 N 429,99 W 1380,55 N 448,83 W 1434,66 N 467,81W 1486,83 N 486,~ W 1537,15 N 503,66 W 1587.14 N 520,81 W ARCO O/,b :,;GI-X ('~YR(J$COPXC c.,uRVLY ,;.,~..A.C, tJR[.D ()':-.'PTH AN00THLR DATA FL~i'~. LVER¥ r:'.¥h'N 100 Ft. LT OF' $lj~] 5£A bLblrt, TRuE I.'.[-A SURE D VERTICAL SUP, ;4D-TVD YE,~T 1CAL DEPTH DEPTH SEA DIFFLRrzI'~CE CORRECTION TOTAL CL~ORO ItiATE~ 7541 7149. 7100 392 14 7656 72~9. 7200 407 15 7770 73~9. 7300 421 14 7B85 7469, 7400 4~5 7999 7549. 7500 &50 15 $115 7649. 7600 ~66 16 6230 7749, 7700 6HO 14 83~5 7849. 7800 496 8~61 79~9. 7900 512 B580 ~049, 6000 531 19 8704 81~9, 8100 554 23 ~831 ~249. 8200 5~2 28 g959 83~9, g300 610 26 9(;96 8449, 8400 6~6 26 921,4 8~4g, 8bO0 665 163~.55 N 1691,39 h 1799,13 ti 165~,23 N 1910.6~ N 1967,63 N 2220.11N 229B,9~ N 537,05 593,59 609,77 613,15 612,88 ~91,96 ARCO GYaOSCOP IC 5U~VEY AUG 79 VALUES 'FOb EVLN TRUE ,VEASURED VEgT ICAL DEPTH DEP IOL)O 10~0, 2000 1999, 3000 2999, ~.OOO 3965, 5000 ~,906, 6000 rialS, 7()00 6673. 8090 75/.,9. 9000 8~Sl, 1000 SU~ SEA F'LLT OF ~'~LASURED [~EPTi-t. TOTAL COORD INATE5 951, 0,O0 S 0 1950. 0.26 fi 0 2950. 2,56 N 4 3936, 1~,7,75 a ~2 4857. 509,72 N 172 5766. 904.52 N 297 662~. 1~9~.90 N ~53 8332, 2~03,~0 N 593 cOO ~ ,7fi E .~7 W ,32 m .................. VERTICAL SECTION ' . . ARCO OIL 8~ GAS W,G. 1. I 400 __. RADIUS OF CURVATURE ............... GYROSCOPIC SURVEY --- SCALE I": 1000' 800 - AUG. 16, 1979 · _ 1200 ................ 1600 2000 ........................................................................................................................ · 2800 .......... 3200 ' ~00-~ ...... - ' ' ' I ARE TVD. ........... 6ooo~,~ .................................. ' ........ _- ............................. .......... ................. ""°X T~-:~; ..... :.~.-':'---:"': ........ TMD = 9~35 ' .. HORIZONTAL VIEW..' ............................ ARCO OIL & GAS - .............. W.G.t. I - - ................... GYROSCOPIC SURVEY ............ ............................. SCALE: 1"= 1000' .............. AUG. 16, 1979 ALL DEPTHS SHOWN ARE TVD ...... ; ......................... TMD: 93;55 ................................... 8400 ....... : ................. 8000 0 ................. ................ 7200 ~~ ......................................... ................... 6800 .................... 6400 ['\~ .............. 6000 ...................................... ..................... ~oo .. ,~oo ...... ,~ooo.. .......................................... 5600-~- COHPLETION REPORT ARCO OIL AND GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR $DC BY F N LINDSEY & ASSOCIATES 15 AUG 79 WELL WGI-1 K B ELEV 49 FT DkCLINATION 31 DEG EAST RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE ._AS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIRE( DEG. 0 0 0 0,00 100 0 0 100,00 200 0 0 200,00 300 0 0 300,00 400 0 0 400,00 500 0 0 500,00 600 0 0 600,00 700 0 0 700,00 800 0 0 800,00 900 0 0 900.00 1000 0 0 1000,00 -49.00 N O,OOE 51.00 N O,OOE 151.00 N O.OOE 251.00 N O,OOE 351.00 N O.OOE 451.00 N O.OOE 551.00 N O,OOE 651,00 N O,OOE 751.00 N O,OOE 851,00 N O,OOE 951,00 N O,OOE 1100 0 0 1100.00 1051.00 N O,OOE { 200 0 0 12,00,00 1151,00 N O,OOE 1300 0 0 1300.00 1251.00 N O,OOE 1400 0 0 1400,00 1351.00 N O.OOE 1500 0 0 1500.00 1451.00 N O.OOE 1600 0 0 1600.00 1551,00 N O,OOE 1700 0 0 1700.00 1651,00 N O,OOE 1800 0 0 1800.00 1751.00 N O,OOE 1900 0 0 1900.00 1851.00 N O.OOE 2000 0 30 1999.99 1950,99 S85.00E 2100 0 0 2099.99 2050e99 N O,OOE 2200 0 0 2199.99 2150.99 N O,OOE 2300 0 30 2299,99 2250,99 561,50E 2400 0 30 2399,99 2350,99 S22.00E TOTAL COORDINATES 0.00 S 0.00 W 0,00 S 0.00 W 0,00 S 0.00 W 0,00 $ 0.00 W 0.00 & 0.00 W 0.00 S O.OOW 0.00 S i! 0,00 W 0.00 s o,0o w 0.00 S 0.00 W 0.00 S 0,00 W 0.00 S 0.00 W 0,00 S 0.00 W 0,00 S 0,00 W 0.00 S 0.00 W 0.00 S 0.00 W 0,00 S 0,00 W 0,00 S 0,00 W 0.00 S 0.00 W 0.00 S 0,00 W 0,00 S 0,00 W 0,26 N 0.28 E 0.52 N 0,57 E 0,52 N 0.57 E 0,70 N 0.88 E 0.07 N 1,45 E C L 0 S U R E S DISTANCE ANGLE D M S 0.00 ~ 0 0 0 w 0,00 $ 0 0 0 0.00 $ 0 0 0 W 0.00 S 0 0 0 W 0,00 $ 0 0 0 W 0,00 $ 0 0 0 W 0,00 S 0 0 0 0.00 S 0 0 0 0.00 $ 0 0 0 W 0.00 S 0 0 0 W' O,OOS 0 0 0 W 0.00 $ 0 0 0 W 0.00 S 0 0 0 0.00 S 0 0 0 W 0.00 5 0 0 0 W O.O0 S 0 0 0 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 $ 0 0 0 W 0.98 N 47 30 0 E 0,77 N 47 30 0 E 0,77 N 47 30 0 E 1.13 N 51 14 6 E 1,45 N 87 11 I E DOG LEG SEVER I TY DEG/iOOFT 0,000 0,000 0.000 0,000 0,000 0,000 0,000 0.000 0.000 0.000 0,000 0,000 0,000 0.000 0.000 0,000 O,OOO O.O00 0.900 0,000 0,500 0.500 0.000 0.500 0.336 SECTION DISTAaCE 0,00 0.00 0,00 0.00 o~oo 0,00 0.00 0,00 0,00 0.00 0.00 0,00 0,00 0.00 0.00 0.00 0,00 0,00 0.00 0.00 0,19 0.38 0.38 0.49 -0,24 COMPLETION REPORT' ARCO OIL & GAS MAGNETIC MULTI-SHOT RADIUS OF CURVATURE METHOD OF COMPUTATIONS COMPUTED FOR SD.C BY F H LINDSEY & ASSOCIATES 31 JULY 79 WGI 1 K B ELEV 49 FT DECLINATION 31 DEG EAST RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTLR TRUE ,..,-AS. DRIFT VERTICAL DEPTH At'dOLE DEPTH .SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES DOG LEG C L 0 ,.c.c.q U R F $ SEVERITY DISTANCE ANGLE DEG/iOOFT D M S SECTION DISTANCE 0 0 0 0,00 295 0 0 295,00 386 ,3 0 386,00 477 0 O 477,00 568 0 30 567.99 659 0 30 658.99 750 0 30 749,99 841 0 15 840.98 932 0 0 931.98 1023 0 0 1022.98 -49,00 N O.0OE 246,00 N O,OOE 337,00 N 0,00E 428,00 N O,0OE 518.99 S29.00E 609.99 S34,00E 700,99 S53,00E 791,98 S37,00E 882,98 N O,OOE 973,98 N O.OOE 1114 0 15 1113,98 1064,98 S73,00E 1205 0 3(; 1204,9~ 1155,98 S13,00E '~296 0 0 1295,98 1246,98 N O,OOE 1387 0 0 1386,90 i337,98 ~,10,OOE 1478 0 0 1477,98 1428,9~ N 1569 0 0 1568,9B 1519.98 N O,OOE lO60 0 30 1659.98 1610.98 S~7.00E 1751 0 S& 1750,98 1701.98 $65.00E 1843 C 45 164Z,97 1793,97 S76,00E 1934 0 45 ' 1933,96 1884.96 S62,00E 2027 0 45 2026.96 1977.96 S79.00E 2120 0 30 2119.95 . 207~.95 S74.00£ 221S 0 30 2212.95 2163,95 S54.OOE 2306 0 30 2305.94 2256.94 $63.00E 2399 0 30 2398.94 2349,94 ~54,00E O,OO S O,OO W 0,00 $ 0,00 W Q~O0 S 0,00 W O.O0 S 0,00 W 0,07 N 0~28E 0,'60 S 1.17 S 1,24E 1.59 S 1,66E 1,54 S 1,80 E i.54 $ 1,80 E le44 S 1.94 E 1,86 S 2.32 E 1.8~ S 2,59 E 1,83 S 2.59 E 1.83 S 2.59 E 1,d3 S 2.59 1,73 S 2,88 E 2.23 S 3,49 E 2,56 S 4.44 E 2e99 S 5.54 E 3.39 S 6.69 E 3,63 S 7,67 E 3,98 S 8.40 E 4,41 $ 9.09 E 4.83 S 9,7B E 0,00 $ 0 0 0 W 0,00 S 0 0 0 W 0o00 S 0 0 0 W 0.00 $ 0 0 0 W 0,29 N 75 ~0 0 E 0,92 S 49 $ 21E 1.71S 46 ~1 8 E 2.30 S 46 7 39 E 2.37 S 49 21 1E 2,37 S 49 21 1E .2,42 S 53 17 47 E 2,98 S 51 20 37 E 3.17 S 54 48 15 E 3,17 S 54 48 15 E 3,17 S 54 48 i5 3,17 S 54 48 15 h 3,36 S 58 56 44 E 4,14 S 57 26 38 E 5.12 ~ 59 58 ~5 E 0,30 S 61 40 4 E 7.50 S 83 ~ 23 E 8,49 S 64 40 34 E 9.30 S 64 37 3 E 10.10 $ 64 7 40 i 10.91S 63 42 ~ E 0.000 0.000 0.000 0.000 0.550 0.048 0.181 0.275 0,275 0,000 0,275 0,275 0,549 O,O00 0.000 0,000 0,550 0.272 0.201 0.238 0,269 0.187 0,084 0.084 0.00 0.00 0,00 0.00 -0,00 -0,77 -1.47 -le99 -1,9~ -1,98 -1.93 -2,43 -2.48 -2.45 -2.48 -2.48 -2,47 -3,11 -3.69 -4e~l -5e62 -6,16 -6.76 -7e36 ARCO O/G WGI 1 ,V~AGINEIlC ~.iULTI-SHOT 31 JULY 79 RECORD OF SURVEY ALL CALCULATIONS PERFO2,?,ED BY I B Fi ELECTRONIC COFiPUTER TRUE ¢~EAS, DRIFT VERTICAL DEPTH AI';GLF DEPTH SUB ORIFT SEA DIRLC DEG. TOTAL COORDINATES 7492 0 30 2491,94 2442,94 329,00E 2584 O 45 2583,93 2534.93 S13.00E 2676 0 45 2675,92 2626,92 S 9,00E 5,43 S 10,32 E 6,37 S 10,67 E 7,b5 S 10,90 E USING SINGLE-SHOT DATA 2754 0 45 2753,92 2704,92 S 9,00E 3000 4 15 2999,64 2950,64 S 3091 5 0 3090,35 3041,35 N19,GO~ 5210 5 30 3208,65 ~159,85 N28,00W 3397 7 30 3394,63 3345,63 N 5,00W 3517 9 45 3513,27 3464,27 N 4,00W 3770 14 30 3760,56 ~711,56 N16,00V~ 3830 14 BO 3818,64 3769,64 N25,00W 3984 14 45 3967,65 3918,65 N25,00W 4143 19 30 4,119,56 4070,56 N24,00W 4253 24 0 4221,70 4172,70 N26,00W ~472 25 30 4420,58 4371,58 N25,00W 4777 24 30 4697,00 4648.00 N24.00W 8,56 S 11,06 E 19,22 S 12,18 E 20,19 S 7,20 E 10,22 S 2,~6 E 9e93 N 3,10 W 27,87 ~i *,51 W 80,10 N 13,72 W 94,15 N 18,97 W 129,39 N 35,41 W 171,99 N 54,82 W 208.92 N 72.04 W 291,67 N 111,51 W 408,96 N 164,96 W BACK TO CURRENT MULTI-SI-IOT I,~PUT 4904 24 0 4812,80 4763,80 N27,00W 456,03 N 4996 23 30 4897,00 4848,00 N27,OOW 5087 23 0 4980,61 4931,61 N26,00W 5181. 22 0 5067,46 5018,46 N25,00W 5273 22 0 5152,76 5103,76 N27,OOW 5367 22 30 5239,76 5190.76 N25,00W 5460 23 0 5325,52 5276,52 ~24,00W 489,05 N 521,19 N 553,66 N 584,63 N 616,62 N 649,35 N 187,41 W 204,24 W 220,26 w 235,75 W 250,86 W 266,46 W 281,37 W CLOSURES DI STAi'iCE ANGLE D M S 11,66 S 62 12 56 E 12,43 S 59 10 38 E 13.26 S 55 18 0 E 13,99 S 52 16.35 22,76 S 32 22 25 21,44 S 19 38 9 10,61 S 15 40 35 10,41 N 17 20 22 28,24 N 9 11 58 81,26 N 9 43 18 96,05 N 11 23 46 134,15 N 15 18 18 180,51N 17 40 46 220,99 N i9 1 33 ~12,26 N 20 55 R2 440,98 N 21 ~8 4 W 493,04 N 22 20 28 W 529,98 N 22 40 0 W 565.83 N 22 54 35 W 601,76 IN 23 3 52 W 636,18 N 23 13 24 W 671,73 N 23 22 14 W 707,69 N 23 25 40 W DOG LEG SEVERITY DEGIiOOFT 0.233 0.272 0.057 0.000 1,42~ 1,598 0,426 1.090 1,~75 1,901 3,752 0,162 2.988 4,102 0.690 0,333 0,555 0,543 0,574 1,074 0,814 0,562 SECTION DISTANC~ -8,09 -9,09 -i0,2~ -11.30 -21,85 -21,40 -10.61 10.41 28,03 80,75 95,72 134.14 180,45 220,71 311,17 438.70 490,17 526,56 561,89 597,39 631.34 ~66,41 701.99 ;..RCO O/G WGI I MAGNETIC kULTI-SHOT .$1 JULY 79 RECORD OF' SURVEY i,...,ED BY I B M ELECTRONIC COMPUTEF~ ALL CALCULATIONS TRUE MEAS. DRIFT VERTICAL DEPTH AN&L£ DEPTH D H 5552 22 0 5410,52 5545 23 0 5496,44 5736 24 0 5579,89 5827 26 0 5562,36 5920 27 0 5745.59 6012 27 30 5827.38 6105 29 0 5909.30 6198 29 0 5990.64 6239 30 0 6069.84 6383 33 0 6149.98 6475 32 0 6227.57 6566 31 30 6304.95 6658 31 0 6383.60 6751 31 0 6463.32 6844 30 0 6543.45 6936 29 45 6623.22 7028 29 0 6703.39 7120 29 0 6783.86 7211 28 0 6863.83 7303 27 30 6945,25 7396 27 0 7027.93 7491 27 0 7112.57 75~6 28 30 7196.64 7680 29 0 7279.06 7775 29 0 7362.15 7870 29 30 7445.03 7965 29 30 7527,72 8060 29 0 7610.60 8154 29 0 7692.82 SUB DRIFT TOTAL COORDINATES C L O S U R E S SEA DIREC DISTANCE ANGLE DEG, D M b361.52 N25.00W 681.~9 N 295.97 W 742.89 N 23 28 Q3 w 5447,44 N24.00W 713.77 N 310.73 W 778.47 N 23 31 31 W 5530.89 N24.00W 746.92 N 325.49 W 814.76 N 23 32 47 W 5613.36 N24.00W 782.05 N 341.13 W 853.21 iN 23 34 1W 5696.59 N21.OOW 820.38 N 357.01 W 894.70 N 2~ 31 3 W 5778.38 N21.OOW 859.71 N 372.10 W 936.78 N 23 24 15' W 5860.30 N20.OOW 900.94 N 387.52 W 980.75 N 23 16 26 W 5941.64 N21.OOW 943.17 N 403.31 W 1025.78 N 2~ 9 7 W 6020.84 N20.OOW 985,14 N 419.00 W 1070.55 N 23 2 2~ W 6100.98 N23.00W 1030.83 N 437,00 W 1119.63 N 22 ~8 25 W 6178.57 N19.00W 1076.97 N 454'71W 1169.0~ N 22 53 24 w 6255.95 N19.00W 1122.2~ N ! 470.30 w 1216.81N 22 44 14 W 6334.60 N21.OOW 1167.09 N 486,6~ W 1264.48 N 22 38 2 W 6414,32 N19.00W 1212.10 N 503.00 W 1312.32 N 22 32 16 W 6494.45 Fi20.OOW 1256.59 N 518.76 W 1359.46 N 22 25 56 W 6574.22 N22.00W 1299.37 N 535.18 W 1405.27 N 22 23 8 W 6654.39 N22.00w 1341.21 N 552,09 W 1450.40 N 22 22 25 W 6734.86 N23.00W 1382.42 N 569.15 W 1495.00 FI 22 22 ~9 W 6814.83 N23.00W 1422.39 N 586,12 W 1538.42 N 22 23 42 W 6896.25 NZO.OOW 1462.24 iq 601.82 W 15~i.24 N 22 22 15 W 6978.93 N23.00W 1501.~5 It 6i7.42 W 1623.82 N 22 ~0 52 W 7063.57 N20.OOW 1541.98 N 633.23 W 1666.94 N 22 19 33 W 7147.64 N19.00W 1583.67 N '647.99 W 1711.12 N 22 15 10 W 7230.06 N19.00W 1626.42 N 662.71 W 1756.26 N 22 10 9 W 7313.15 N19.00W 1669.97 N 677.71 W 1802.25 N 22 5 18 W 7396.03 N15.00W 1714.~5 N 691.28 W 1848.48 N 21 57 38 W 7478.72 N15.00W 1759.54 N 703,3~ W 1894.92 N 2i 47 21W 7561.60 N12.00W 1804.67 N 714.22 W 1940.86 N 21 35 30 W 7643.82 N 9.00W lb49.47 N 722.52 W 1.985.60 N 21 20 20 W DCG LEG SEVERITY DEG/1OOFT 1.098 1.088 1.099 2.198 1.264. 0.543 1.633 0.521 1.133 3.329 1.o35 0.549 0.792 1.108 1.10~ 0.600 0,81~ 0.527 1.099 0.582 0,~55 1.~34 1.597 O,532 0.000 1.149 0,000 0.910 1.547 SECTION DISTANCE 736.82 772.03 807.98 ~46.07 887.31 929.2~ 973.17 1018,13 1111,70 11~0.94 1208.77 1256.39 1304.i7 1351.29 1395.95 1441.85 1456.17 1529,29 1571.93 1614.32 16'57,26 170i.41 1746.57 17')2.57 1838.97 1885,75 1932.11 1977.46 ARCO O/G WGI i ;4AGNETIC HULTI-sriOT 31 JLILY 79 ~.a.,=D OF <URVEY ALL CALCULATIO;~iS PERFORMED RY I ~ ;4 ELECTRONIC COI'-iPUTER TRUE .~EAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D SUB DRIFT SEA DIREC DEG, TOT.~L COORDINATES S248 29 0 7775.03 7726.0~ iq 8,00w 1894,54 8374 32 15 7883.~4 78~4,4~ N 3,00W 19~8,~0 B469 33 15 7963.34 7914.34 N 1.OOW 2009.76 8564 34 0 8042.44 7993.44 N 3.00E ~ a062.35 8658 37 15 8118.84 8069.84 N 2.00E 2117.04 8752 38 15 8193.17 8144.17 N 2.00~ 2174,56 8847 qO 0 8266.86 B217e86 N 1.OOE 2234~4B 894.2 39 0 8340.16 8291.16 N 2.00E 2294,88 9036 39 30 8412.96 8363.96 N 3.00E 2354.30 9131 38 30 84B6.79 8437.79 N 3.00E 2414.00 729,26 W 735,41 W 737,20 W 7~6,28 W 733,90 W 731,89 W 730,52 W 728,74 W 726.14 W 723.0t W 9225 37 45 8560.73 B511.73 N 1.OOE 2472.00 N 720.99 W 9252 37 45 8582.08 U533.08 N 1.OOE 2488'53 N 720.70 W BOTTOM HOLE ..LO.SURF 2590,79 FEET AT N 16 9 5 W CLOSURES D I STAhCE ANGLE D M S 2030.05 N 21 3 11W 2091.93 N 20 34 54 W 2140.70 N 20 6 57 W 2159.84 N 19 B8 50 W 2240.64 N 19 7 10 W 2294.42 N 18 B6 6 W 2350.80 N 18 ~ 58 W 2407,81 N 17 37 2 W 2463.74 N 17 8 29 W 2519.95 N 16 40 24 W 2575.00 N 16 15 36 W 2590.79 N 16 9 5 W DOG LEG SEVERITY DEG/iOOFT 0.516 2.816 1.228 1.535 3.~79 1.064 1.132 0.684 1.053 1.128 0,000 SECTIO?,~ O I S TA[~CE 2022,62 2065.67 2t35,50 2185.7.5 2237,63 2292,32 2349,44 Z407.o2 2453.37 2519,85 2574.99 2590.79 ARCO O/(} wGI i !-,iAG~ETIC I-1ULTI-S,~iOT ~.,~JU,-,~:J~ . "lid OTHER DATA FCR CVLRY LVEt'.~ Z.]r~ FE~_T OF SU~ bLA DLF'Th, 31 JULY 79 -r RUE :'.iCASUR E D 'VERTICAL SU[~ i','I D-T VD V:RT ICAL DEPTH DEPIH SEA DIFFEREF~CE CORRECTIOi'..~ TOTAL CdORD IiiATES 149 149 · lO0 © 0 249 249 · 200 G 0 349 349- 300 0 0 4'49 449. 4.00 0 O 549 549. 500 0 0 649 649, 600 0 0 749 749. 700 0 0 849 849, 800 0 0 949 949, 900 0 0 1049 1049. 1000 0 0 1149 1149, llOO 0 0 1249 1249, 1200 0 0 1349 1349. 1300 0 0 1449 1449. 1400 0 0 1549 1549. 1500 0 0 1649 1649. 1600 0 0 1749 1'749. 1700 0 0 1849 1849. 1800 0 0 1949 1949, 1900 0 0 2049 2049, 2000 0 0 2149 2149, 2100 0 0 2249 2249. 2200 0 0 2549 2349, 2300 0 0 2449 2449, 2400 0 0 2549 2549, 2500 0 0 2649 2649 · 2600 0 0 2749 2749. 2700 0 0 2849 2849. 2800 0 0 2949 2949. 2900 0 0 3050 3049. 3006 0 0 3150 3149. 3100 0 0 3250 3249, 320(.) 1 1 3351 3349. 330(') 1 0 3452 3449, 3400 2 1 355'2~, 3549, 3500 4 2 O,C0 S 0,00 S 0,00 S O,OC S O, 10 0,53 S 1,17 .5 1,62 S 1,54 S 1,53 1,53 S 2,02 S 1,83 S 1.83 S 1,63 S 1.?1 S 2.22 S 2.58 S 3.08 S 3,45 S 3.'71 3 4.16 S 4.59 S 5.13 S 5.96 S 7.20 ~.49 S 10.90 15.78 S 21.81 S 15,29 S 6.62 4.21 17.50 34.16 N O,OO W 0,00 W O,O0 W 0,00 W O. 17 E 0,64 E 1,23 E 1.68 E 1.80 E 1.80 E 2.10 E 2,54 E 2.59 2,59 E 2,59 Pi 2,82 E 3,47 E 4,51 5.72 i 6.96 E ?.91 8,66 E 9.42 E 10,10 E 10,55 E 10.85 E 11,05 g 11.39 E 11.90 9.88 5,30 E 1.15 ,. 2.19 W 3.74 W 5,05 W APZ',} O/G WSI 1 f~EASUFcED OdPTH A,4D OTkJER DATA FOb :.IASNETIC ?'iULTI-SHOT LVzRY LVLiN 100 FL.£T OF DLPTH, ..41 J(JLY 79 TRUE MEASURED VERTICAL DEPTH DEPTH SUd t. iD-TVO SEA DIFFLRL. LCt VIRT I CAL TOTAL C(,)OI~ D I ;'.4A T E S 3555 3b49, 3758 3749, 3B61 3849, 3965 3949, 4059 4049, 4174 4149, 4283 4249, 4393 4349, 4503 444~, 4614 4549, 4724 4649, 4834 4749, 4944 4849, 5053 4949, 5161 5049, 5269 5149, 5377 5249, 5485 5349, 5594 5449. 5702 5549, 5812 5649, 5924 5749, 6036 5849, 6150 5949, 6265 6049, 6382 6149, 6500 6249. 6617 6349, 6734 6449, 6850 6549, 6966 6049, 72)80 6749, 7194 6849. 7~07 6949, 7420 7049. 3600 6 3700 9 3800 12 3900 15 4000 19 4100 25 4200 33 4300 43 4400 54 4500 65 4600 75 4700 85 4800 95 4900 104 5000 112 5100 120 5200 127 5300 136 5400 144 5500 153 5600 163 5700 174 5800 187 5900 201 6000 215 6100 232 6200 25], 6300 268 6400 285 6500 301 6600 317 6700 331 6800 345 6900 358 7000 371 2 3 4 8 10 11 11 10 10 10 9 8 7 9 8 9 10 11 13 14 14 17 19 17 17 16 16 14 14 13 54,10 77.22 101,20 124,95 1~0,70 181.72 219,93 261.20 303,75 346.70 388,82 430,34 470.3Z 509,09 546,~4 583,28 620.10 658.21 695,66 734,38 77~,08 822.00 870,13 921,41 97~,P2 1030,25 1089,47 1147,25 1203,83 1259,4i 1312.96 1364.54 1415.02 1463,97 1511.76 7,87 12.96 22,26 53,33 45,22 59,21 77,40 97,18 117.13 136,90 155.96 174.79 194.69 214.31 232,56 250,17 265.07 285.34 302.56 319.91 338,47 357.63 376,08 395.07 414.89 436.75 459.01 479,19 500,12 519,79 540.67 561.65 582.99 602,45 621.55 W W W w W w W V~ W W W W W W w W ARCO O/G wG! 1 i',',AG~'~ET!C ~'iULTJ-SHOT ?~EASURED DEPTH AND OTrlER DATA FGR EVERY EVE'.?t 10,0 FEET OF SUB bEA D~!PTrto JULY 79 TRUE NEASU2ED VERTICAL SUB ;,ID-TVD VERTICAL DEPTH DEPTH SEA DIFFERE/,~CE CORRECTIuN TOTAL C. Uui~D I,'~ATE S 7532 7149, 7100 382 11 7645 7249. 7200 395 14 7760 7349. 7300 ~11 15 7874 74~9. 7400 q25 14 7989 75~9° 7500 ~0 15 8104 75~9~ 7600 ~55 ~5 82~8 77~9. 7700 469 14 8333 78~9, 7800 ~8~ ~5 8~52 79~9. 7900 502 18 8572 8049. 8000 522 20 8696 81~9° 8100 546 24 882~ 8249. 8200 574 28 8953 8349. 8300 604 30 9082 8449. 8400 633 29 9210 8549. 8500 661 28 1559.09 1610.7~ 1663°08 171&.25 177U.95 ~25.5~ 18~0.t5 193o.92 2000.39 2066,83 2140.14 ~219.61 2301.81 238~.37 2462.80 639.60 ~57.31 675,33 691.79 706.36 718,39 727.19 733.93 737.01 736.05 733.09 730.61 728.~9 ?24.62 721.17 AR(iO O/G WGI 1 FiAC. i'.~ETIC NULTI-SHOT 21 JUL'~ 7~.~ INTERPOLATED VALUES FOk TRUE NEASURED VERTICA DEPTH DEPTH 1000 999 20(;0 19W9 3000 2999 4000 3983 5000 4900 6000 5816 7000 6678 8000 7558 9000 8385 EVEN 1000 SUB 950. 1950, 2950. 3934. 4851, 5767, 6629, 7509, 8336, FEET OF MZASURED D~FTH. TOTAL COORDINATES 1,54 S 3,31 S 19,22 S 133.15 N 490.47 N 854.54 N 1328,58 N 1776.18 N 2331,48 N ~.gO E 6,34 E 12,18 E 37,15 W 20~.98 W 370,12 W 546,98 W 707.67 W 727,26 W 40O 60O 1200 1600 240O 2600 3200 3600' ARCO OIL. 8~' GAS WGI -I -*' MAGNETIC MULTI-SHOT RADIUS OF CURVATURE SCALE I": I000' AUG. 27 1979 JARE_ TVD. -' , $600 .~ - 6000 "'~ . 6400 ARCO OIL. & GAS WGI- I MAGNETIC MULTI- SHOT RADIUS OF CURVATURE SCALE I'"= 500' AUG. ~-~ 1979 84oo TVO = 8582" TldO = 9252' i i ALL DEPTHS SHOWN ARE TVD 8000 7&O0 7200 6800 6400 6000 5600 5 ~00 4800 4400 4.000 $~00 $200 ARCO O/G WGI-1 GYROSCOPIC SURVEY 15 AUG 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B N ELECTRONIC COHPUTER TRUE NEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 2500 0 0 2499,99 2450.99 N O.OOE 2600 0 30 2599,98 2550,98 N 1,25E 2700 0 0 2699.98 2650,98 N O,OOE 2800 0 30 2799,98 2750.98 519,50E 2900 2 0 2899.96 2850,96 N46,00E 3000 0 30 2999,93 2950.93 N 4.00E 3100 4 30 3099,81 3050,81 N16,00W 3200 5 0 3199,47 3150,47 N26,00W 3300 5 0 3299,09 3250,09 N 5,00W 3400 6 30 3398.58 3349.58 N 2,00E 3500 9 45 3497,57 3448,57 N 0.OOE 3600 10 30 3596,01 3547,01 N 9.00W 3700 12 30 3694,00 3645,00 NIO,OOW 3800 12 15 3791.67 3742e67 N23,00W 3900 14 O 3889e06 3840,06 N28.00W 4000 15 0 3985,87 3936,87 N24,00W 4100 18 0 4081e74 4032,74 N22,OOW 4200 21 30 4175.84 4126,84 N22,00W 4300 24 0 4268,06 4219e06 N21.OOW 4400 25 30 4358.87 4309.87 N22.00W 4500 25 30 4449.13 4400e13 N21,OOW 4600 24 30 4539e76 4490,76 N21,OOW 4700 24 15 4630,84 4581,84 N21.OOW 4800 23 15 4722,37 4673e37 N20.OOW 4900 23 15 4814,2.5 4765e25 N20,OOW 5000 22 45 4906e30 4857,30 N2OeOOW 5100 22 30 4998,61 4949,61 N2OeOOW 5200 23 30 5090.66 5041,66 N18,0OW' 5300 24 0 5182,19 5133,19 N17,00W TOTAL COORDINATES 0.13 N 1,75 E 0.56 N 1,76 E 1,00 N 1,76 E 1.05 N 2,07 E 0.63 N 3,85 E 2,56 N 4,75 E 6,88 N 4,30 E 14.60 N 1.34 E 22,95 N 0.97 W 32,96 N 1.23 W 47,09 N 0,98 W 64.60 N - 2.36 W 84.26 N 5.65 W 104,76 N 11.73 W 125.25 N 21.50 W 147.75 N 32,47 W 173.89 N 43,57 W 205,21 N 56,22 W 241.19 N 70e40 W 280.14 N 85.74 W 320,20 N 101,52 W 359.65 N 116.66 W 398.18 N 131.45 W 435.90 N 145,56 W 473.00 N 159,06 W 509,72 N 172.42 W 545,87 N 185,58 W 582.81N 198,30 W 621,22 N 210.41 W C L 0 5 U R E S DISTANCE ANGLE D M 5 DOG LEG SEVERITY DEG/iOOFT 1.76 N 85 44 48 k 1,85 N 72 10 15 f 2.03 N 60 25 23 E 2,32 N 62 59 29 E 3.90 N ~0 39 33 E 5,40 N 61 39 10 E 8,11 N 32 1 43 E 14,66 N 5 14 59 E 22.97 N 2 25 48 W 32,98 N 2 ~ 52 ~ 47.10 N 1 12 14 W 64.64 N 2 5 56 W 84.45 N 3 50 29 W 105,42 N 6 23 21W 127.08 N 9 44 29 W 151,28 N 12 23 48 W 179,26 N 14 4 1W 212.78 N 15 19 22 W 251,26 N 16 16 17 W 292.97 N 17 1 3 W 335,91N 17 35 29 W 378.10 N 17 5B 20 W 419.32 N 18 16 12 W 459.57 N 18 27 55 W 499,03 N 18 35 12 W 538,09 N 18 41 22 W 576.55 N 18 46 36 W 615,62 a 18 47 27 W 655,88 N 18 42 42 W 0.500 0.500 0.500 0.500 1.506 1.500 4.002 0.506 1,820 1.503 3.251 0.807 2,001 0,636 1.774 1.O35 3~006 3.500 2,505 1.511 0.431 1,O00 0,250 1.012 O,O00 0,500 0.250 1,049 0,527 SECTION DISTANCE -0,25 0,16 0,59 0,57 -0,22 1,46 5,77 13,95 22,61 32,43 46.16 63,55 83,45 104.79 126,92 151.27 179.21 212.55 250.75 292.12 334.66 376,47 417.30 457,£0 496,35 535.10 573,26 612,09 652,22 ARCO O/G WGI-1 GYROSCOPIC SURVEY 15 AUG 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I 8 M ELECTRONIC COMPUTER TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 5400 24 45 5273,27 5224,27 N17.00W J500 22 30 5364.88 5315,88 N18,00W 5600 22 30 5457,27 5408,27 N19,00W 5700 24 0 5549,15 5500,15 N18,00W 5800 27 O 5639,40 5590,40 N17,00W 5900 28 15 5728,00 5679,00 N15.00W 6000 29 0 5815,77 5766,77 NIS,00W 6100 29 30 5903,02 5854,02 N16,00W 660,68 N 698.90 N 735.19 N 772.62 N 813.68 N 858.25 N 904~52 N 951,61 N 6200 32 0 5988,96 5939,96 N20,OOW 1000,22 N 6300 32 0 6073,76 6024,76 N18,00W 1050,32 N 6400 32 0 6158.57 6109,57 N16,00W 1101.00 N 6500 32 0 6243,37 6194,37 N16,00W 1151J93 N 6600 32 15 6328.06 6279,06 N17,00W 1202,92 N 6700 30 0 6413,66 6364,66 N19,00W 12~2.08 N 6800 30 0 6500,26 6451,26 N19.00W 1299,35 N 6900 30 0 6586.86 6537.86 N19,00W 1346,63 N 7000 30 0 6673,47 6624.47 N19,00W 1393.90 N 7100 29 30 6760,29 6711,29 N20,OOW 1440,68 N I200 28 30 6847.75 6798.75 N19,00W 1486,38 N 7300 27 30 6936,04 6887.04 N19.00W 1530,77 N 7400 28 0 7024.54 6975.54 N19,00W 1574,79 N 7500 28 30 7112.63 7063.63 N17,OOW 1619.80 N 7600 29 0 7200,30 7151.30 N18.00W 1665,68 N 7700 29 0 7287.76 7238,76 N17.00W 1711,91N 7800 29 15 7375.12 7326.12 N15,00W 1758,70 N 7900 29 30 7462,26 7413,26 Nll.OOW 1806,48 N 8000 29 15 7549,40 7500.40 NIO.OOW 1854,71 N 8100 30 0 7636,33 7587,33 N 9,00W 1903,46 N 8200 29 45 7723,04 7674,04 N 6,0OW 1952,84 N 222.48 W 234,53 W 246.67 W 259.19 W 272.14 W 284,92 W 297.32 W 310.37 W 326.17 W 343,42 W 358.~1 W 373,52 W 388,62 W 404,59W 420.87 W 437.15 W 453,43 W 469.99 W 486.18 ~ 501,46 W 516,62 W 531.25 W 545.71 W 560.29 W 573.70 W 584.73 W 593.67 W 601,83 W 608,33 W C L 0 `5 U R E .5 DISTANCE ANGLE D M S 697.14 N I'8 36 ]7 W 737.20 N t8 33 0 W 775.47 N 18 32 51W 814.94 N 18 32 43 W 857,98 N 18 29 34 W 904.31N 18 21 54 W 952.13 N 18 1X 4~ W 1000.94 N 18 3 51W 105Z.06 N 18 3 AO W 1105.04 N 18 6 22 W 1158.02 N 18 ~ 20 W 1210.98 N 17 57 56 W 1264.14 N 17 54 14 W 1315,82 N 17 54 28 ~' 1365.8~ N 17 56 ~2 W 1415,81N 17 59 5 W 1465.80 N 18 1 10 W 1515,40 N 18 4 4 W 1563,87 N 18 6 44 W 1610,81N 18 8 17 W 1657,37 N 18 9 45 W 1704.70 N 18 9 Z8 W 1752.79 N 18 8 23 W 1801,27 N 18 7 21 W 1849.91N 18 4 0 W 1898,76 N 17 56 10 W 1947,41N 17 44 57 W 1996,34 N 17 32 45 W 2045,40 N 17 18 8 W DOG LEG ,SEVERITY DEG/IOOFT 0.750 2.255 0.383 1.509 3.007 1.328 0.750 0.556 2,741 ~060 1,060 0,000 0.379 2.30~ 0,000 0,000 0.000 0,b56 1.026 1.000 0,500 0,676 0,552 0.485 0,539 1.002 0.346 0.791 0.780 SECTION DISTAf¢CE 693,37 733-30 771.37 810.63 853,52 899.81 947.68 996.48 1047,37 1100,03 1152.87 1205,77 1258.83 1310,29 1359.98 1409.67 1459,~7 1~08,63 1556.77 1603.43 1649,70 1696.~3 1744,75 1841,64 1890.69 1939,70 1989.06 20~8e66 ARCO O/G WG GYROSCOPIC SURVEY 15 AUG 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I b M ELECTRONIC COMPUTER TRUE HEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES 8300 30 0 7809.75 7760.75 N 3.00W 2002.50 N 3400 30 0 7896.36 7847.36 N O.OOE 2052.47 N 8500 32 45 7981.72 7932,72 N 4.00E 2104.49 N 8600 34 O 8065.23 8016,23 N 6.00E 2159.29 N 8700 38 0 8146.12 8097.12 N 3.00E 2217.87 N 8800 38 30 8224.65 8175.6'5 N 3.005 2279.69 N 8900 38 45 8302.77 8253,77 N 3.OOE 2342~03 N 8948 38 0 8340.40 8291,40 N 2,00E 237i,80 N 9000 38 0 8381.38 8332.38 N 1.OOE 2403,80 N 9100 38 15 8460.05 8411.0'5 N 3.00E 2465.50 N 612.24 W 613,55 W 611,73 W 606.94 W 602,33 W 599.09 W 595,82 W 594,52 W 593,68 W '591,,53 W 9200 39 0 8538.17 8489,17 N 0,OOE 2.527.89 N .589,89 W 9293 38 45 8610.57 8561.57 N 1.OOE 2586-26 N : 589,39'W 9335 38 45 8643.33 8594.33 N 1.OOE 2612.54 N '5~8.93 W BOTTOM HOLE CLOSURE 2678,10 FEET AT N 12 42 12 W CLOSURES DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/IOOFT 2094.00 N 17 0 1W 2142,22 N 16 38 35 W 2191.60 N 16 12 29 W 2242,97 N 15 41 59 W 229~,20 N 15 11 98 W 2357.10 N 14 43 26 W 2416.63 N 14 16 24 W 2445e18 N 14 4 19 W 2476.03 N 13 52 23 W 2535.47 N 13 29 29 W 2595.81 N 13 ~ 6 W 2652.57 N 12 50 16 W 267~.10 N 12 42 12 W 0.791 1,500 2.989 1,398 4.158 0°500 0.250 1,751 1.184 0.806 0,500 0.000 SECTION ~ISTANCE 2087,97 2137.02 2187.37 2239.79 2295.94 2355,55 2~15.66 2444,42 ~475.46 2535.19 259b.?1 26D2,55 2678.10 ARCO O/G WGI-1 GYROSCOPIC SURVEY HEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. 15 AUG 79 TRUE NEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORD [NATES 149 149, 100 249 249, 200 349 349. 300 449 449. 400 549 549. 500 649 649. 600 749 749. 700 849 849. 800 949 949. 900 1049 1049, 1000 1149 1149, 1100 1249 1249. 1200 1349 1349. 1300 1449 1449. 1400 1549 1549. 1500 1649 1649. 1600 1749 1749. 1700 1849 1849. 1800 1949 1949. 1900 2049 2049. 2000 2149 2149. 2100 2249 2249. 2200 2349 2349. 2300 2449 2449, 2400 2549 2549, 2500 2649 2649, 2600 2749 2749. 2700 2849 2849. 2800 2949 2949. 2900 3049 3049, 3000 3149 3149. 3100 3250 3249, 3200 3350 3349. 3300 3451 3449. 3400 3552 3549, 3500 0,00 S 0o00 0,00 0,00 0.00 0.00 0,00 0.00 $ 0,00 0o00 S 0,00 S 0°00 $ 0.00 S 0.00 0,00 $ 0.00 0.00 S 0.00 0,09 N 0.36 N 0,52 N 0.61 N 0,44 N 0.07 0.23 N 0,86 N 1,07 N 0,57 N 1.76 N 3,81 N 10.62 N 18,64 N 27.63 N 39.44 N 56.06 N 0,00 W 0,00 W 0.00 W 0.00 W 0,00 W 0.00 W 0.00 W 0.00 W 0.00 W 0,00 W 0,00 W 0,00 W 0.00 W 0.00 W 0,00 W 0.00 W 0.00 W 0.00 W 0 ,.04 E 0.58 E 0,57 E 0.62 E 1.21 E 1.71 E 1,75 E 1,76 E 1,82 E 2,59 E 4.66 E 4.95 E 3,05 E 0.19 W 1.23 ~ 1,06 W 0,62 W ARCO O/G WG[-1 GYROSCOPIC SURVEY MEASURED DEPTH AM, D OTHER DATA FOR EVERY E~EN 100 FEET OF ,SUB SEA DEPTH, 15 AUG 79 TRUE IqEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES' 3654 3649, 3600 4 1 3756 37490 3700 7 3 3859 3849, 3800 9 2 3962 3949, 3900 12 3 4066 4049, 4000 16 4 4171 4149, 4100 22 6 4279 4249, 4200 30 8 4389 4349, 4300 40 10 4500 4449, 4400 51 4610 4549, 4500 61 10 4?20 4649, 4600 71 10 4829 4749, 4700 80 9 4938 4849, 4800 89 9 5046 4949. 4900 97 8 5155 5049, 5000 105 8 5264 5149. 5100 114 9 5373 5249, 5200 124 lO 5483 5349, 5300 134 10 5591 5449, 5400 142 8 5700 5549, 5500 150 8 5811 5649, 5600 161 ll 5924 5749, 5700 174 13 6038 5849, 5800 189 15 6153 5949, 5900 204 15 6271 6049, 6000 222 18 6389 6149, 6100 240 18 6507 6249, 6200 257 17 6625 6349. 6300 276 19 6741 6449, 6400 292 16 6856 6549. 6500 307 15 6972 6649, 6600 323 16 7087 6749. 6700 338 15 7201 6849. 6800 352 14 7315 6949. 6900 365 13 7428 7049, 7000 378 13 74.80 N 4.03 95.96 N 8,50 116.58 N 17.11 138.90 N 28,38 164.36 N 39.64 195.59 N 52,34 233,31 N 67,35 275.76 N 83.98 320014 N 101,50 363.52 N 118,15 405,79 N 134,36 446.65 N 149.47 486.96 N 164,14 526.39 N 178,49 565.81 N 192.62 607.16 N 206,06 649.92 N 219,18 692.58 N 232,48 731.93 N 245,55 772.56 N 259,17 818.37 N 273,56 869.19 N 287,85 922.35 N 302.16 977,07 N 318.19 1035063 N 338,56 1095.25 N 357,25 1155.31 N 374,49 1215.40 N 392,50 1271.37 N 411.~4 1325.83 N 429,99 1380.55 N 448,83 1434.66 N 467.81 1486,83 N 486.33 1537.15 N 503.66 1587014 N 520,81 ARCO 0/(:~ ',';Gl-! GYROSCOPIC SURVEY /.,~.ASURED [)Ef~TH AND OTHER DATA FUR LVERY EVCN JO0 FLET OF SUB SEA 1.5 AUG 79 TRUE t:,'~, ['~ A S UR E I) VERTICAL .5U[~ MD-TVD VE~T ICAL PL'P TH DEPTH .SEA D l FF~R~t'.,iCE CORRECTION TOTAL COORD JNATE.5 7541 7149. 7100 392 76%6 7249, 7200 kO7 15 7770 7349, 7300 42! 7885 7449. 7400 435 7999 7549, 7500 ~50 15 8115 7649. 7600 ~66 16 5230 7749, 7700 680 14 8345 78fl9. 7800 g96 16 ~61 7949. 7900 512 16 ~SBO ~0~9, 8000 531 19 8704 8149, 8100 554 23 ~31 8249, 6200 5~2 28 ~959 8349, B300 610 9096 84~9, 8400 636 26 921~ 8540, 8500 665 ~9 1799,1~ 1~5~,23 1910,6~ 1967,63 2024,98 208j.7~ 21~u.20 2220.11 229~.9U 2536.6~ 593,59 602,95 609e77 612,88 608.0b 602,2! 589.b8 A~:tco o/o w~!-l GYROSCOPIC INT~Li;:POLATE:D VALUES FOK EVLN 1OO0 FLLT OF ~,~LASURED DEPTH, TRuE b<EASURED VERT lC. AL SUB ~,. ,=,," T H DEP 1'11 SEA TOTAL COORD l ;',~A TE 5 1000 lOOO, 951. 2000 1999, 1950, 3000 29990 295Oe ~000 39~5e 39360 5000 ~906, ~857, 7000 6673, 6624, 8000 75~9, 7500, 9000 83~1, 8332, O.O0 S 0,00 0.26 ,N O.2~ 2.56 N 4.75 147.75 N 32.47 509,72 N 172,~2 906.52 N 297,32 139~e90 N ~53,43 1656e71 N 593,~7 2~03,d0 N 593,68 400 800 1200 1600 ..................... VERTICAL SECTION ARCO OIL &GAS W,G. I. I RADIUS OF CURVATURE . GYROSCOPIC SURVEY - - SCALE ["=1000' "" _ ..... AUG. [6~ 1979 · .. .......................... ARCO OIL & GAS _ ........................................... W.G.I. I ...... -~ ~-' .._~.-.-.'__~_ ....... ~_.~'.~.~.-_~.~.'-~.'-'~.__.~_. _.RADIUS OF CURVATURE ........ '.~i ..... ............................... GYROSCOPIC SURVEY -. ......................................... SCALE 1"= 1000' ...... ......................... AUG. 16, 19'7'9 ......... HORIZONTAL VIEW. ' ...... _ ....... ............. ALL DEPTHS SHOWN ........................... . ...................... ARE TVD · · ................................................. TVD 8645' ....................... .................. : ............................... TMD = 9535~ ........................ .................................. 8400 ........................... 1' ~'~..~ _~-_' __i'. "... _--_-. ~-i '_" 7~ .-_" . .- .-.-_ -_'_-/2 ~.. Z~°° ~ - ~" '_-'£~.'L' .......... - i i .... ' ~_ "_'_ ..... ' .... /~' .. '~.7~oo _ '- ~-i _ _' '_. -_- ~ .... ................................ 6800 ............ .............................. 6400 [' \-~, _ _ ......................... 6000 ........................ ~6oo '~ \ ~ ..... ................... ~ .... - .................. 48oo-~,". .... -_ .......... ;-,-:-'-~ '_ ......... 44.00 ~'~ - - 4000 ~ ....... ..................................... ~60_9"P' ........................ . SC It;[.~TiFIC DRILLING CONTf:!OLS 700 v~EST 41st ST. ~fROSCOeIC DIRECTIONAL SUPVDY ******************** * Al{CO OIL AND GAS * ******************** LoCA'i' iOt~: PRU DliO£ DAY 5ORVEY ~.a'i'E: U-1-79 S(JRVEY Ei4GiNtiL]I.;: FitlL GRAFr"i l',.~iiTilOo Ut' CALCULATIO~-i: RADIUS OF CUI{VATORg ***DEPTti ~iEA~3iJI-(I~D I['.i FEET*** CO["!~'lt~[~'i'L: ~'ii~LD DATA AND FILbi [3!.iCLtJSED v~I'i'll COf,IPLE'I'ION ********************************* *'PHIS SURVEY IS CORRECT TO THE * *BEST OF MY KNO'NLEDGE AND IS * *SUPPORTED BY \ACTUAL FIELD DATA.* ~ CO?IPA~Y PEPRES~N'I'~TI ~E ~ COMPLETION REPORT ARCO OIL AND GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY F M LINDSEY G ASSOCIATES 15 AUG 79 WELL WGI-1 K B ELEV ~9 FT DECLINATION 31 DEG EAST RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 0 O 0 0.00 100 O 0 100.00 200 O 0 200,00 300 O 0 300,00 400 O 0 ~00.00 500 O O 500.00 ~O0 O 0 600.00 700 O O 700.00 800 O O 800.00 900 O 0 900.OO 1000 0 0 1000,00 -49.O0 N O.OOE 51.OO N 0.00£ 151.00 N O.OOE 251.O0 N O.OOE 351,00 N O,OOE ~51,00 N O.OOE 551,00 N O.OOE 651.00 N O.OOE 751,O0 N O.OOE 851.OO N O.OOE 951.00 N 0.OOE '100 0 0 1100.00 1051.00 N O.OOE I00 0 0 1200.00 1151.00 N O.OOE 1300 0 0 1300.00 1251,00 N O.OOE 1gO0 0 0 1400.00 1351.00 N O.OOE 1500 0 0 1500.00 1451,00 N O.OOE 1600 0 0 1600.00 1551,00 N O.OOE ~?00 0 0 1700.00 1651.00 N O.OOE O0 0 0 1800,00 1751,00 N O.0OE 1900 0 0 1900,00 1851,00 N O,OOE 2000 O 30 1999.99 1950.99 S85.00E 2100 O 0 2099,99 2050,99 N O.00E 2200 O 0 2199.99 2150.99 N O.0OE 2300 O 30 2299.99 2250.99 SG1.50E 2400 O 30 2399.99 2350.99 522.00E TOTAL COORDINATES 0.00 S 0.00 W 0,O0 5 0.OO W 0~O0 5 0.00 W 0~O0 5 0.00 W OJO0 5 0,00 W 0.00 5 0.00 W O.O0 $ O.00 W 0.O0 & O.00 W 0,00 5 0.00 W 0,00 5 0.00 W 0.00 $ 0.00 W 0.O0 5 0.00 W 0.00 $ 0,00 W O.00 S 0.00 W 0.O0 5 0.00 W 0.00 S O.00 W 0.O0 S 0.O0 W 0.00 5 0.00 W 0.O0 5 0.00 W 0.00 5 0.00 W 0.26 N 0.28 E 0.52 N 0.57 E 0.52 N 0,57 E 0.70 N 0,88 E 0,07 N 1.45 E C L 0 $ U R E S DISTANCE ANGLE D M S 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 S 0 0 0 W 0.O0 S 0 0 0 W 0,00 S 0 0 0 W 0.00 $ 0 0 0 W 0,00 S 0 0 0 W O.OO 5 0 0 0 W 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0,00 5 0 0 0 W 0,00 S 0 0 0 W 0,00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 5 0 0 0 W 0.38 N 47 30 0 E 0.77 N 47 30 0 E 0,77 N 47 30 0 E 1,13 N 51 1~ ~ E 1,45 N 87 11 1 f DOG LEG SEVERITY DEG/iOOFT 0.000 0,000 0,000 0.000 0,000 0,000 0,000 0,000 0,000 0,000 0,000 0,000 0,000 0,000 0,000 0,000 0,000 0,000 0,000 0,000 O.500 0.500 0.000 0.500 0.338 SECTIO~ DISTANCE 0.00 0,00 0.00 0.00 0,00 0.00 0,00 0,00 0.00 0,00 0.00 0.00 0,00 0,00 0,00 0,00 0.00 0.00 0,00 0.00 0,19 0,3~ 0.38 0,49 -0.24 ARCO 0/6 WGI-1 GYROSCOPIC SURVEY 15 AUG 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS. DRIFT VERTICAL 'TH ANGLE DEPTH D M SUB DRIFT SEA D[REC DEG, _~00 0 0 2499.99 2450,99 N O.OOE 2600 0 30 2599.98 2550.98 N 1.25E 2700 0 0 2699,98 2650.98 N O.OOE 2800 0 30 2799.98 2750.98 $19.50E 2900 2 0 2899.96 2850.96 N46.00E 3000 0 30 2999.93 2950.93 N 4.00E 3100 4 30 3099.81 3050.81 N16.00W 3200 5 0 3199.47 3150.47 N26.00W 3300 5 0 3299,09 3250.09 N 5.00W 3400 6 30 3398.58 3349.58 N 2.00E 3500 9 45 3497.57 3448,57 N O,OOE 3600 10 30 3596,01 3547.01 N 9.00W 3700 12 30 3694.00 3645,00 NiO.OOW 3800 12 15 3791.67 3742.67 N23.00W 3900 14 0 3889.06 3840.06 N28.00W 4000 15 0 3985.87 3936.87 Na4.00W ~100 18 0 4081.74 4032,74 N22.00W O0 21 30 4175.84 4126.84 N22.00W 4300 24 0 4268.06 4219.06 N21.OOW 4400 25 30 4358,87 4309.87 N22.00W 4500 25 30 4449.13 4400.13 N21.OOW 4600 24 30 4539.7~ 4490e76 N21eOOW ~700 24 15 4630,84 4581.84 N21.OOW O0 23 15 4722.37 4673,37 N20.OOW 4900 23 15 4814,25 4765,25 N20,OOW 5000 22 45 4906.30 4857.30 N20.OOW 5100 22 30 4998.61 4949,61 N20.OOW 5200 23 30 5090.66 5041.66 N18.00W 5300 24 0 51~2,19 5133.19 N17.00W TOTAL COORDINATES 0.13 N 1.75 0.56 N 1,76 1.00 N 1.76 1.05 N 2.07 0.63 N 3,85 2.56 N 4.75 6~88 N 4,30 14.60 N 1,34 22~95 N 0.97 32,96 N 1.23 47,09 N 0,98 64.60 N 2.36 84.26 N 5.65 104.76 N 11.73 125.25 N 21,50 147.75 N 32,47 173,89 N 43.57 205.21 N 56,22 241.19 N 70.40 280.14 N 85.74 320.20 N 101,52 359.65 N 116.66 398,18 N 131.45 435e90 N 145,56 473.00 N 159,06 509.72 N 172.42 545,87 N 185.58 582,81 N 198.30 621.22 N 210.41 C L O 5 U R E 5 DISTANCE ANGLE D M $ 1,76 N 85 44 48 E 1,85 N 72 10 15 E 2,03 N 60 25 23 E 2,32 N 62 59 29 E 3.90 N 80 39 33 E 5.40 N 61 39 lO E 8.11N 32 1 43 E 14,66 N 5 14 59 E 22.97 a 2 25 48 W 32.98 N 2 8 52 W 47.10 N 1 12 14 W 64.64 N 2 5 56 W 84.45 N 3 50 2~ W 105.42 N 6 23 21W 127.08 N 9 44 29 W 151.28 N 12 23 48 w 179.26 N 14 4 1 W 212.78 N 15 19 22 ~ 251.26 N 16 16 17 ~ 292,97 N 17 1 3 W 3~,91N 17 35 29 W 378,10 N 17 58 20 W 419.32 N 18 16 12 W 459.57 N 18 27 55 W 499.0~ N 18 ~5 12 W 538,09 N 18 41 22 W 576.55 N 18 4~ 36 W 615,62 N 18 47 27 W 655,88 N 18 42 42 W DOG LEG SEVERITY DEG/iOOFT 0.500 0.500 0,500 0,500 1.506 1.500 4.002 0.506 1,820 1.503 3.251 0.807 2,001 0,636 1,774 1.035 3.006 3,500 2.505 1.511 0,431 1.000 0.250 1,012 0.000 0.500 0,250 1~G49 0~b27 SECTION DISTANCE -0.25 0.1 0.59 0.57 -0,22 1,4~ 5,77 13,95 32,43 46,16 63.55 83.45 104.79 126e92 151.27 179,21 212.55 250.75 292e12 334,66 370,47 417.30 496,35 535,10 573026 612,09 6~2,22 ARCO O/G WGI-1 GYROSCOPIC SURVEY 15 AUG 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEA$, DRIFT VERTICAL [ ~TH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES . ,00 24 45 5273,27 5224,27 N17,00W 5500 22 30 5364,88 5315,88 N18,00W 5600 22 30 5457.27 5408.27 N19.00W 5700 24 0 5549,15 5500,15 Ni8,00W 5800 27 0 5639,40 5590,40 N17,00W 5900 28 15 5728,00 5679.00 N15,00W 6000 29 0 5815,77 5766,77 N15,00W 6100 29 30 5903,02 5854,02 N16,00W 660,68 N 698.90 N 735.19 N 772,62 N 813,68 N 858.25 N 904152 N 951~61N 6200 32 0 5988,96 5939,96 N20,OOW 1000,22 N 6300 32 0 6073.76 6024,76 N18,00W 1050,32 N 6400 32 0 6158.57 6109.57 N16.OOW llOl,O0 N 6500 32 0 6243,37 6194,37 N16eOOW 1151,93 N 6600 32 15 6328e06 6279e06 N17.00W 1202,92 N 6700 30 0 6413e66 ~364.66 N19eOOW 1252,08 N 6800 30 O 6500e26 6451.26 N19.OOW 1299.35 N 6900 30 0 6586,86 6537e86 N19,0OW 1346.63 N 7000 30 0 6673,47 6624,47 N19eOOW 1393.90 N .O0 29 30 6760,29 6711,29 N2OeOOW 1440,68 N 7200 28 30 6847,75 6798e75 N19eOOW 1486.38 N 7300 27 30 6935.04 6887,04 N19.00W 1530.77 N 7400 28 0 7024,54 6975,54 N19e0OW 1574.79 N 7500 28 30 7112,63 7063.63 N17eOOW 1619,80 N v600 29 O 7200,30 7151,30 N18.00W 1665.68 N O0 29 0 7287.76 7238e76 N17,00W 1711.91 N 7800 29 15 7375,12 7326,12 N15.00W 1758.70 N 7900 29 30 7462.26 7413e26 NlleOOW 1806,48 N 8000 29 15 7549,40 7500.40 NiO.OOW 1854,71 N 8100 30 O 76~6e33 7587,33 N 9,DOW 1903,46 N 8200 29 45 7723,04 7674,04 N 6.00W 1952.84 N 222,48 W 234,53 W 246.67 W 259,19 W 272,14 W 284,92 W 297,32 W 310,37 W 326,17 W 3~3,42 W 358,91 W 373,52 ~ 388,62 W 404,59 W ~20,87 W 437,15 W 469,99 W 486.18 W 501.46 W 516,62 W 531.2) W 545,71 W 560,29 W 573.70 W 584.73 W 593,67 W 601.83 W C L 0 S U R E S DISTANCE ANGLE D M S 697,14 N 18 36 37 W 737.20 N 18 33 0 W 775.47 N 18 32 51W 814.94 N 18 32 43 W 857,98 N 18 29 34 W 904,31N 18 21 54 W 952,13 N 18 11 4~ W 1000.94 N 18 3 51W 1052,06 N 18 3 40 W 1105,04 N 18 6 22 W 1158.02 N 18 3 20 W 1210.98 N 17 57 56 W 1315.82 N 17 54 28 W 1~65.82 N 17 5~ 52 W 1415.81N 17 59 5 W 1465.80 N 18 i 10 W 1515.40 N 18 4 4 W 1563,87 N 18 ~ 44 W 1610.81N 18 8 17 W 1657.37 N 18 9 4~ W 170~.70 N 18 9 28 W 1752.79 N 1~ 8 23 W 1801.27 N 18 7 21W 1849.91N 18 4 0 W 1898.7~ N 17 56 10 W 1947,41N 17 44 57 W 2045,40 N 17 18 8 W DOG LEG SEVERITY DEG/iOOFT 0.750 2.255 1.509 3,007 1.328 0,750 2.7~1 1,060 1,060 0,O00 0.~79 2.~05 0.O00 0.000 0.000 0,55~ 1.026 1.000 0.500 0.676 0.552 0.485 0.539 1,002 0,346 0.791 0.780 SECTION DISTANCE 693.37 771.37 810.63 853,52 899.81 9~7.6~ 1047.37 1100.03 11~2,87 1205,77 1258,83 1510.29 1359,98 1409,67 1459,37 1508,63 1556,7 1603.43 16~9,70 1696.83 1744.75 1793.0~ 1841,64 1890.~9 1939.70 19~9,06 2068.66 ARCO O/G WGI-1 GYROSCOPIC SURVEY 15 AUG 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS. DRIFT VERTICAL f ~TH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES ...00 30 0 7809.75 7760.75 N 3.00W 2002.50 N 8400 30 0 7896.36 7847.36 N O.OOE 2052,4`7 N 8500 32 45 7981.72 7932.72 N 4.00E 2104.49 N 8600 34 0 8065,23 8016.23 N 6.OOE 2159.29 N 8700 38 0 814'6.12 8097.12 N 3,00E 2217.87 N 8800 38 30 8224`,65 8175.65 N 3.00E 2279.69 N 8900 38 4`5 8302.77 8253.77 N 3.00E 2342~03 N 8948 38 0 8340.40 8291.40 N 2,00E 2371~80 N 9000 38 0 8381,38 8332.38 N 1.00E 2403,80 N 9100 38 15 8460.05 8411.05 N 3.00E 2465.50 N 9200 39 0 8538.17 8489.17 N O,OOE 2527,89 N 9293 38 4`5 8610.57 8561,57 N 1.OOE 2586.26 N 9335 38 45 8643.33 8594,33 N 1.00E 2612.54, N 612,24 613.55 611.73 606,94 602 · 33 599.09 595.82 594' · 52 593 · 68 589,89 589.39 588 ~ 93 BOTTOM HOLE CLOSURE 2678.10 FEET AT N 12 4`2 12 W C L 0 S U R E $ DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/iOOFT 2094.00 N 17 0 1W 214,2.22 N 16 38 3~ W 2191.60 N 16 12 29 W 224`2,97 N 15 4'1 59 W 2298.20 N 15 11 38 W 2357.10 N 14 43 26 W 2~16.63 N 14' 16 24` ~ 24'45.18 N 1~ 4 19 ~ 24`76,03 N 13 52 23 W 2535.47 N 13 29 29 W 2595.81N 13 8 6 ~ 2652,57 N 12 50 16 W 2676.10 N 12 ~2 12 W 0,791 1,500 2.989 1.398 4,158 0,500 0.250 1.751 1.184 0.806 1,405 0.500 0.000 SECTION DISTANCE 2087.97 2137.6 ) 2187.37 2239.79 2295,94 2355,55 2415.66 2444.42 24`75.46 2535,19 2595,71 2652,55 2678,10 ARCO O/G WGI-1 GYROSCOPIC SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH. AUG 79 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 149 149, 100 0 0 249 249. 200 0 0 349 349. 300 0 0 449 449. 400 0 0 549 549, 500 0 0 649 649. 600 0 0 749 749. 700 0 0 849 849. 800 0 0 949 949. 900 0 0 1049 1049. 1000 0 0 1149 1149e 1100 0 0 1249 1249, 1200 0 0 1349 1949, 1300 0 0 1449 1449. 1400 0 0 1549 1549. 1500 0 0 1649 1649, 1600 0 0 1749 1749. 1700 0 0 1849 1849. 1800 0 0 1949 1949, 1900 0 0 2049 2049e 2000 0 0 2149 2149, 2100 0 0 2249 2249. 2200 0 0 2349 2349. 2300 0 0 2449 2449, 2400 0 0 2549 2549, 2500 0 0 2649 2649. 2600 0 0 2749 2749. 2700 0 0 2849 2849. 2800 0 0 2949 2949. 2900 0 0 3049 3049, 3000 0 0 3149 3149. 3100 0 0 3250 3249. 3200 1 1 3350 3349. 3300 1 0 3451 3449. 3400 1 0 3552 3549. 3500 3 2 0,00 $ 0,00 S 0.00 S 0,00 S 0.00 0.00 S 0.00 S 0.00 S 0.00 $ 0.00 S 0.00 S 0.00 S 0.00 S 0,00 S 0.00 S 0.00 S 0.00 S 0.00 S 0.09 N 0.36 N 0.52 N 0.61 N 0.44 N 0.07 0.23 N 0.88 N 1.07 N 0.57 N 1.76 N 3.81 N 10.62 N 18.64 N 27.63 N 39.44 N 56.06 N 0,00 W 0.00 W 0.00 W O.OO W 0.00 W 0.00 W O,OO W 0,00 W 0.00 W 0.00 W 0,00 W 0.00 W 0.00 W O.OO W 0.00 W 0.00 W 0.00 W 0.00 W 0.04 E 0,58 E 0,57 E 0.62 E 1.21 E 1.71 E 1,75 E 1.76 E 1,82 E 2,59 E 4,66 E 4,95 E 3,05 E 0,19 W 1.23 W 1.06 W 0,62 W ARCO O/G WGI-1 GYROSCOPIC SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB Sba DbPTH. 15 AUG 79 TRUE MEASURED VERTICAL SUB HD-TVD VERTICAL DEPTH DEPTH SEA D[FFERENCE CORRECTION TOTAL COORDINATES 3654 3649, 3600 4 1 3756 3749, 3700 7 3 3859 3849, 3800 9 2 3962 3949, 3900 12 3 4066 4049. 4000 16 4 4171 4149, 4100 22 6 4279 4249, 4200 30 8 4389 4349. 4300 40 10 4500 4449. 4400 51 11 4610 4549, 4500 61 10 4720 4649, 4600 71 10 4829 4749, 4700 80 9 4938 4849, 4800 89 9 5046 4949, 4900 97 8 5155 5049, 5000 105 8 5264 5149, 5100 114 5373 5249, 5200 124 10 5483 5349, .5300 134 10 5591 5449, 5400 142 8 5700 5549, 5500 150 8 5811 5649m 5600 161 11 5924 5749, 5700 174 13 6038 5849, 5800 189 15 6153 5949. 5900 204 15 6271 6049, 6000 222 18 6389 6149, 6100 240 18 6507 6249, 6200 257 17 6625 6349, 6300 276 19 6741 6449, 6400 292 16 6856 6549, 6500 307 15 6972 6649, 6600 323 16 7087 6749. 6700 338 15 7201 6849, 6800 352 14 7315 6949, 6900 365 13 7428 7049, 7000 378 13 74,80 N 95,96 N 116,58 N 138,90 N 164,36 N 195,59 N 233,31 N 275.76 N 320,14 N 363,52 N 405,79 N 446.65 N 486,96 N 526,39 N 565,81 N 607.16 N 649,92 N 692°58 N 731,93 N 772,56 N 818,37 N 869,19 N 922,35 N 977,07 N 1035,63 N 1095,25 N 1155,31 N 1215,40 N 1271,37 N 1325,83 N 1380,55 N 1434,66 N 1486~83 N 1537,15 N 1587,14 N 4,03 W 8.50 W 17.11 W 28,38 W 39,64 W 52,34 W 67.35 W 83.98 W 101,50 W 118,15 W 134,36 W 149,47 W 164.14 W 178.49 W 192,62 W 206,06 W 219.18 W 232,48 W 245.55 W 259,17 W 273,56 W 287,85 W 302.15 W 318.19 W 398.56 W 357.25 W 374,49 W 392.50 W 411.24 W 429.99 W 448,83 W 467.81 W 486,33 W 503,66 W 520.81 W ARCO 0/6 WGI-1 GYROSCOPIC SURVEY MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 15 AUG 79 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 7541 7149, 7100 392 14 7656 7249. 7200 407 15 7770 7349. 7300 421 14 7885 7449. 7400 435 14 7999 7549. 7500 450 15 8115 7649. 7600 466 16 8230 7749, 7700 480 14 8345 7849. 7800 496 16 8461 7949, 7900 512 16 8580 8049. 8000 531 19 8704 8149. 8100 554 23 8831 8249. 8200 582 28 8959 8349. 8300 610 28 9086 8449. 8400 636 26 9214 8549. 8500 665 29 1638,55 N 1691.39 N 1744,57 N 1799,13 N 1910.69 N 1967,63 N 2024.98 N 2083,74 N 2148.20 N 2220,11N 2298,98 N 2378,51 N 2456,80 N 2536.65 N 537,05 W 553,93 W 569,84 W 583.26 W 593,59 W 602,95 W 609e77 W 613,15 W 612,88 W 608e06 W 602.21 W 598,08 W 594,30 W 591,96 W 589e88 W ARCO O/G WG!-I GYROSCOPIC SURVEY INTERPOLATED VALUES FOR EVEN ].000 FEET OF MEASURED DEPTH. ].,5 AUG 79 TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORD :[NATE5 1000 1000, 951, 2000 1999, 1950, 3000 2999. 2950. ~000 3985. 3936. 5000 ~906, 4857. 6000 5815. 5766. 7000 6673. 6624. 8000 75~9. 7500, 9000 8381. 8332. 0.00 S 0.00 W 0.26 N 0.28 E 2,56 N ~.75 E 1~7.75 N 32.~7 W 509,72 N 172.42 W 904.52 N 297.32 W 1393.90 N 453.43 W 1854.71N 593.67 W 2403.80 N 593,68 W 400 1200 1600 2OOO VERTICAL SECTION ARCO OIL & {;AS W.G. 1. ! RADIUS OF CURVATURE {~YROSCOPIC SURVEY SCALE I"= I000' AUG. 16~ 1979 ALL DEPTHS :SHOWN ARE TVD. TVD = 864~5' TMD = 9:5~55 ' CO'.'IPLETION Rh!PORT A2CO ()IL & GAS ;.'iAGN~TIC ;~ULTI-SHOT RADIUS OF CURVATURE XETHOD OF COr'.IPUTATiC~,:S COi4PUTFD FCR SDC BY F ~,'~ LINDSEY & A&.SOCIAI'~.S 3i JULY 79 v.,GI 1 K ~ ELLV 49 FT DECLI,,'.,ATIOF. 31 bEG EAST RECORD OF SUkVEY ALL CALCUL,a, TIONS PERFOI:i'.iED BY I B M LLECTRONIC COMPUTER TRUE ,,:_AS. DRIFT VERTICAL i)2~ TH ANGLE DEPTH D M SUB D~IFT SEA DIREC DEG, 0 0 0 0,00 295 0 0 295,00 388 0 0 386.00 q77 0 0 ~77.00 56~ 0 30 567,99 659 0 30 658.99 750 0 30 749.99 8~1 0 15 8~0.99 932 © 0 931,95 1023 O 0 1022.98 -~9.00 N O.OOE 296.00 N O.OOE 337.00 N O.OOE q28.00 h O.OGE 518.99 S29.00E 609,99 S34,00E 700,99 853,00E 791,98 S37.00E 862,98 N O,OOE 973,98 1114 0 15 1113,98 !064,98 S7B,OCE 12C5 0 30 1204,98 1155,98 S13,COE 295 0 0 1295,98 1246.98 N O.OOE 1357 0 0 1386.95 1337,98 N O.OOi 1473 0 0 1477,98 1428,98 ?~ O,OOE 156'~ 0 0 1568,93 1519,98 N O.OGE 1060 0 30 1659,98 1610,98 S37,00E 1751 0 30 1750-98 1701,98 S65,00E 1~!43 0 45 18a2,97 1793,97 $76.00E 193~ 0 45 ' 1933,96 18U4,96 S62.00E 2027 0 45 2026.96 1977,96 S79.00E 2120 0 30 2119,95 207C,95 S74,00E 2213 0 30 2212,95 2i63.95 S54,00E 23,36 0 30 2305,94 2256,94 363.00E 2399 0 30 2398.94 2349,94 S54.00E TOTAL CGORDI,NATES O,OC S O,OU W 0,00 5 0.00 W 0,00 S 0,00 W 0,00 S 0,00 W 0.07 N 0,28 E 0,60 S 0,69 E 1,17 S 1,24 E 1,'59 ¢ !,66 E 1,54 S 1,80 E 1,54 $ 1,80 E 1,44 S 1,94 E 1.U6 S 2.32 E 1,83 S 2,59 E 1.83 S 2,~9.. E t,83 S 2,59 E t,53 S 2,59 k 1.73 S 2.8S El 2.23 S 3,49 i 2.56 S 4,44 E £,99 S 5,54 E 3,59 S 6.69 E 3,63 $ 7.67 E 3.98 S 8,40 E 4.41 S 9,09 E 4.83 $ 9.78 E C L G S U R E S D I SI'Ar~C E ANGLE D iv, S G,CO S 0 0 0 W 0,00 S 0 0 0 W 0.00 S 0 0 0 W G,O0 S 0 0 0 W 0,29 N 75 30 0 E 0,92 S 49 6 21 E 1,71 S 46 31 8 F 2.30 ...% 46 7 39 E 2.37 S 49 21 1 E 2.37 S 49 21 1 E 2.42 S 53 17 47 i 2.98 S 51 20 37 i 3,17 S 54 48 15 E 3.17 S 54 48 15 E 3.1.7 S 54 3,17 S 54 48 15 E 3,36 S 58 56 44 E 4,14 S 57 26 38 5,12 S 59 58 25 E 6,30 $ 61 40 4 E 7,50 S 63 :5 23 E 8,49 S 64 40 34 E 9.30 S 64 37 3 E 10,10 S 64 7 40 i 10,91 S 63 42 38 i DOG LEG SEVERI TN' DEG/iOOFT O,O00 0,000 0.~50 0 *048 0,181 0.275 0,275 0.000 0,275 0,275 0,549 0,000 0.000 0 · O 0 C G.272 0,201 0,238 0,~69 0,187 O,OU4 0.084 SLCT ION ~ISTANCE 0.00 0,00 0,00 -0,00 -0,77 -1,47 -1,99.. -1,95 -1,98 -1,93 -2,43 -2,48 -2,4~ -2,48 -2,48 -2,47 -3,tl -3,69 -5,12 -5,62 -6,16 -6,76 -7,36 ARC() O/G WG! I MAGNET!C F.'iULT!-SHOT JULY ?9 RECORD OF SURVEY ALL CALCULATIONS PE.~"'-~'-'FORF, IE[.) BY I B H ELECTRONIC COMPUTER TRUE HEAS, DRIFT VERTICAL DEPTH AhGLE DEPTH O M SUB O~IFT SEA DIREC DEG. }492 0 30 2491,94 2442,94 S29,009 2584 0 45 258B.93 2534,93 S13,00E 2676 0 45 2675,92 2626,92 S 9,009 USINC SINGLE-.SHOT DATA 2754 0 45 2753.92 2704,92 S 9,009 3000 4 15 2999,64 2950,64 S 3.009 3091 5 0 3090,35 3041,35 N19,GOW 5210 5 30 3208,85 3159,85 N28,00W 3397 7 30 3394,63 3345.63 N 5.00W 3517 9 45 3513,27 3464,27 N 4.OOW 3770 14 30 3760.56 ~711,56 N16.00W 3~30 14 30 3818.64 3759,64 N25.00W 3984 14 45 3967,65 3918,65 N25,00W 41~3 19 30 ~119,56 4070,56 N24.00W ~253 24 0 4221,70 4172.70 N26,0UW ~72 25 30 4420.58 4371.58 N25.00W 4777 24 30 4697,00 4648,00 N24.OOW BACK TO CLJRRENT ,"'4ULTI-SHOT INPUT 4904 24 0 4812,80 4763,80 N27,00W 4996 23 30 4897.00 4848,00 N27,00w 5087 23 0 4980.61 4931.61 N26.00W 5181 22 0 5067.46 5018.46 N25.0OW 5273 22 O 5152,76 5103.76 N27,OOW 5367 22 30 5239,76 5190.76 N25.00W 5q60 23 0 5325.52 5276,52 1.~4.'~ OOW TOTAL COORDINATES 5,43 S 10,32 E 6.37 S 10.67 E 7,55 $ 10.90 E 8,56 S 11.06 E 19.22 S 12.18 E 20,19 S 7.20 E i0.22 $ 2~6 E 9,93 t~ 3,10 W 27,87 N ~.51 W 80.10 N 13,72 W 94.15 N 18.97 W 129.39 N 35.41 W 171.99 N 54.82 W 208.92 N 72.04 W 291.67 N 111,51W 408.96 N 164,96 W 456.03 N 187,41 W 489,05 N 204,24 W 521,19 N 220,26 w 553.66 N 235.75 W 584.63 N 250.86 W 616.O2 N 266.46 W 649.35 N 281.37 W CLOSURES DI STANCE ANGLE D M S 11.66 S 62 12 56 E 12.43 S 59 10 38 E 13.26 S 55 18 0 E 13.99 S 52 16 35 E 22.76 S 32 22 25 g 21.44 S 19 38 9 E 10.61 S 15 40 35 E 10.41 N 17 20 22 W 26.24 N 9 11 58 W 81.26 N 9 43 18 W 96.05 N 1! 23 46 W 134.15 FI 15 18 18 W 180.51 N 17 40 46 W 220,99 N 19 1 33 W 312,26 N 20 55 22 W 440.98 N 21 58 4 W 493.04 N 22 20 28 W 529.98 N 22 40 0 W 565.83 N 22 54 35 W 601.75 i'~ 23 3 52 w 636.18 N 23 13 24 W 671,73 N 23 22 14 W 707,69 N 23 25 40 W DOG LEG SEVERITY DEG/iOOFT 0.233 0.272 0.057 0.000 1.423 1.59~ 0.426 1.090 1.~75 1.901 3.752 0.162 2.988 *,102 0,690 0.555 0.543 0.574 1.074 0.B14 0.°16 0.562 SECTION DISIANC~ -8.09 -9.09 -10.28 -11.30 -21.8b -21.40 -10.6i 10.41 28.03 80.75 95.72 13~.14 160.45 220,71 311,17 43~,70 490.17 526.56 961.89 D97,39 631.34 ~66e41 701.99 ARCO O/G WG! i MAG,NETIC i'V!ULTI-.SHOT JULY 79 RECORD OF SURVEY ALL CALCULATIONS PERFOF<>IED BY I B M ELECTRONIC COMPUTER TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D H SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 552 22 0 5410,52 5361,52 N25.00W ~645 23 0 5496,44 5447,44 N24.00W 5736 2~ 0 5579,89 5530,89 N24,0OW 5827 26 0 5662,36 5613,36 N24.00W 5920 27 0 5745.59 5695,59 N21.OOW 6012 27 30 5827.38 57?8,38 N21.OOW 6105 29 0 5909,30 5860,30 N20,OOW 619~ 29 0 5990.64 5941,64 N21.00W 62B9 30 0 6069.84 6020.84 N20,OOW 681,39 N 295,97 W 713.77 N 310,73 W 746.92 N 325,49 W 782,05 N 341,13 W 820.38 N B57.01 W 859~71N 372.10 W 900'9~ N 387,52 W 943,17 N 403.31W 985,14 N 419.00 W 437,00 W 454.71 W 638~ 33 0 6149,98 6100,98 N23.00W 1030,83 6475 32 0 6227,57 5178,57 N19,00W 1076,97 6566 31 30 6304.95 6255,95 N19.00W 1122,24 N 470.30 W 6658 31 0 6383.60 6334.60 N21.OOW 1167,09 N 486.62 W 6751 31 0 6463,32 6414,32 N19,00W 12i2,10 N 503,00 W 6844 30 0 6543,45 6494,45 ii20,OOW 1256,59 N 518,76 W 6936 29 45 6623,22 6574,22 N22,00W 1299,37 N 535,18 W 7028 29 0 6703,39 6654,39 N22,00W 1341,21 N 552,09 W v~20 29 0 6788.86 6734,86 N23,00W 1382,42 N 569,15 W 11 28 0 6863,83 6814.83 N23,OOW 1422,39 N 586,12 W 7303 27 30 6945,25 6896,25 N20,OOW 1462,24 ~ 601,82 W 7396 27 0 7027.93 6978.93 N23,00W 1501.~5 N 617.42 W 7491 27 0 7112.57 7063,57 N20.OOW 1541.98 N 633,23 W 7586 28 30 7196,64 7147,64 N19.0OW 1583,67 N '647,99 W 7775 29 0 7362.15 7313.15 N19.00W 1669.97 7870 29 30 7445,03 7396,03 N15.0L'W 17i4.~5 7965 29 30 7527.72 7478.72 N15.00W 1759.54 8060 29 0 7610,60 7561.60 N12,00W 1804,67 8154 29 0 7692,82 7643,82 N 9,00W lb49,47 677.71 69i,~8 703.3~ 714.22 722,52 CLOSURES DISTANCE ANGLE D M S 742.89 N 23 28 43 W 778,47 N 23 31 31 W 814,76 N 23 32 47 W 853,21 N 23 34 1 W 894,70 IN 23 31 3 W 936.78 N 23 24 15 W 980.75 i'i 23 16 26 W 1025.78 N 23 9 ? W 1070,55 N 23 2 2~ W 1119.63 N 22 ~8 25 W 1169.03 N 22 53 24 w 1216,81 N 22 44 14 W 1264.48 N 22 38 2 W 1312.32 N 22 32 16 W 1359.46 N 22 25 ~6 W 1405.27 N 22 23 8 W 1450.40 N 22 22 25 W 1495.00 N 22 22 39 W 153a.42 N 22 23 42 W 151~1.24 N 22 22 15 W 1623.82 N 22 20 52 W 1666.94 N 22 19 33 ~N' 1711.12 N 22 15 10 W 1802.25 N 22 5 18 W lh48,~+b N 21 57 38 W 1894,92 N 21 47 21 W 1940,56 I"~ 21 35 30 W 198b,60 N 21 20 20 W DOG LEG SEVERITY DEG/iOOFT 1,098 1,088 1,099 2,198 1.264. 0,543 1,633 O,b21 1,133 5,329 i,o35 0,549 0,792 1,108 1,10~ 0.600 0,81~ 0,527 1,099 0.882 0,~55 1.434 1.597 0,000 1,149 0.300 G,910 1.547 SECTION DISTANCE 736,82 772,03 807,98 ~4~,07 887,31 929,2~ 973,17 1062.81 1111,70 11~0,94 1208.77 1256.39 1304,17 i351,29 1398.95 1441.85 1486,17 1529,25 1571.93 1614,32 1657.26 1701.41 17')2.57 1885,75 1532.11 1977,46 ARCO O/G WGI 1 FiAGNETIC MULTI-SHOT 31 JULY 79 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B ~ ELECTRONIC CONPUTER TRUE ~,~EAS. DRIFT VERTICAL DEPTH Ah~GLE DEPTH D ,H SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES ~248 29 0 7775.03 7726.03 iN 8.00W 1894.54 N c$374 32 15 7883.44 7834,44 N 3,00W 1958,40 N 8469 33 15 7963,34 7914,34 N 1.OOW 2009.76 N 8564 34 0 8042.44 7993,44 N 3,00E 2062,35 IN 8658 37 15 8118.84 8069,84 N 2,00E 2117,04 N 8752 38 15 8193.17 8144,17 N 2.00E 2174,56 N 8847 40 0 8266.85 8217.86 ~ 1.OOE 223~,4B N 894.2 39 0 83~0,16 8291,16 N 2.00E 2294~88 N 903& 39 30 8412.96 83~3,96 N 3.00E 235~,30 N 9131 38 30 8~B6.79 $437.79 N 3.00E 241~,00 N 9225 3? 45 8550.73 B511,73 N 1.00E 2472,00 N 9252 37 45 8582.08 ~533,08 N I.OOE 2488~53 N 729.26 W 735.41 W 737.20 W 736.28 W 733.90 W 731.89 W 730.32 W 728.74 W 726.1~ W 723,0'1 W 720.99 W 720,70 W C L 0 S U R E S DISTANCE ANGLE D M S 2030.05 ~ 21 3 11W 2091.93 N 20 34 5~ W 21~0.70 N 20 8 ~7 W 2159,84 N 19 ~8 50 W 22q0.6~ iN 19 7 10 W 229~.~2 N 18 36 6 W 2350,80 N 18 5 58 W 2~07.81N 17 37 2 W 24~3.74 Ii 17 8 29 ~ 2519.95 N 16 40 2q W 2575.00 N 16 15 36 W 2590,79 N 16 9 5 W DOG LEG SEVERITY DEG/IOOFT 0.516 2,816 .,228 ~,535 3,~79 1,~9~ 1,1~2 0.684 1,05~ 1,128 0.000 SECTIO,q DISTANCE 2022.62 2085.67 2135.50 21~5.76 2237~63 2292.32 23Li-9,44 2~07.b2 2~63,37 25t9,85 2574,99 2590,79 BOTTOH HOLE CLOSURE 2590.79 FEET AT N 16 9 5 W ARCO O/G WG! 1 ?,,':E,~,$UR[:~D DEPTH AND OTHER DATA FOlk r,iAGhET I C EVERY FtULT ! -S,~iO T i00 FEET OF SUB SCA DE P Th, 31 JULY 7~ TRUE ?.iEASUR ED VERT I CAL. DEPTH DEPI'H S U [3 i',t D- T V D SEA DIFFERENCE VERT I CAL CORRECTION TOTAL C,;,)O i;'. D I NATES 149 149, 249 249, 349 349, 449 449, 549 549. 649 649, 749 749, 849 849· 949 949, 1049 1049, 1149 1149, 1249 1249, t349 1349· 1449 1449 1549 1549, 1649 1649, 1749 1749. 1849 1849· 1949 1949, 2049 2049, 2149 2149, 2249 2249, 2349 2349, 2449 2449, 2549 2549· 2649 2649· 274q 2749· 2849 2849, 2949 2949, 3050 3150 3149 · 3250 3249, 3351 3349, 3452 3449, 3553, 3549, 100 0 2 () 0 0 3OO 0 400 0 500 0 600 0 700 0 800 0 900 0 1000 0 1'100 0 1200 0 1300 0 1400 0 1500 0 1600 0 17 0 0 0 1800 0 1900 0 2000 O 2100 O 2200 0 230O 0 2400 0 250O 0 26OO 0 2700 O 28C0 O 2900 0 300C 0 3 lOCi 0 320(') 1 330O 1 3400 2 3500 4 ().CO 0.O0 O.O0 0.00 O. lO 0.53 1,17 1.62 1,54 1,53 1.5~ 2,02 1·83 1,83 1,83 1,71 2,22 2.58 3,06 ~,45 3,71 4,16 4,59 5.13 5.96 7,20 ~,49 10,90 15.78 21.81 15,2c 0,62 4.21 17,5c'~ 34,16 0,00 W 0,00 W 0,00 W 0,00 W O. 17 E 0.64 E 1,23 E 1,68 E 1.80 E 1,80 E 2,10 E 2·54 E 2,59 E 2.59 2,59 E 2,82 i 3,47 E 4,51 l 5,72 E 6,96 E 7e91 E 8,66 9e42 E 10,10 E 10,55 E 10,55 E 11·05 11,90 E 9,8~ 5,30 E 1,15 E 2·19 W 3,74 5·05 W AP, CO O/G WGI 1 ?'IEASURED DEPTH Ai'tD OTHER DA TA FOR MAGNETIC ~'."~LJLT!-SHOT LVERY tLVEIx~ i00 FaF. iT OF SUB SLA DLPTH, JULY TRUE MEASURED VERTICAL D EP TH DEP TH 3655 3649. 3758 3749. 3861 3849. 3965 3949. 4069 4049. 4174 4149. 4283 4249. 4393 4349. 4503 4449, 4614 4549. 4724 4649, 4834 4749, 4944 4849. 5053 4949. 5161 5049. 5269 5149. 5377 5249. 5485 5349. 5594 5449, 5702 5549. 5812 5649. 5924 5749. 6036 5849, 615(3 5949 · 6265 6049, 6382 6149. 6500 6249. 6617 6349, 6734 6449, 6.~50 6549. 6966 6o49, 7080 6749, 7194 6849. 7307 6949. 7420 7049. SUB F',iD-TVU vERT I CAL SEA DIFFLRLNCE CORRmCT I Of'4 3600 6 3700 9 3800 12 3900 15 4000 19 4100 25 4200 33 4300 ':+3 4400 54 4500 65 4600 75 47OO 85 4800 95 4900 104 50O0 112 5100 120 5200 127 5300 136 5400 144 5500 153 5600 163 5700 174 5800 187 5900 201 6000 215 6100 232 6200 251 6300 268 6400 285 6500 301 660C) 317 6700 331 6800 345 6900 358 7000 371 2 3 3 4 6 8 10 11 11 10 10 10 9 8 8 7 9 8 9 10 11 13 14 14 17 19 17 17 16 16 14 14 13 13 TOTAL COORDINATES ,, 54, lO 77.22 101,20 124,95 150.70 1~1.72 219.93 261.20 303.75 346.70 388.82 450,34 470,32 509,09 546 , 84 563,28 620.10 656.21 695 · 66 734.38 77~,08 822, O0 ~70,1~ 921,41 97~. 92 1030,25 1089,47 1147,2b 120~,~3 1259.4i 1~12,96 1364.54 1415,02 1463,97 1511,76 7.87 W 12,96 W 22,26 W 33,33 W 45.22 Pi 59,21 W 77.40 W 97,18 W 117.13 W 136.90 W 155.96 w 174.79 W 194.69 W 214.31 W 232.56 W 250.17 W 26S.07 W 285.34 W 302.56 W 319e91 ~' 338.47 W 357,63 W 376.08 W 395,07 W ~14,a9 w 436,75 w 459.01 w 479.19 W 500,12 w 519.79 W 540.67 W 561e65 W 582.99 W 602,45 W 621.55 W ARCO O/G wG! 1 P~AGHET!C MULTI-SHOT !~4EASURED DEPTH AND OTHER DATA FOP, EVERY EVE/q 100 FEET OF SUB ,,%EA DEPTH. 31 JULY 79 TRUE .%EASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE COR,RECT I ON 7532 7149. 7100 382 11 7646 7249. 7200 396 14 7760 7349. 7300 411 15 7874 7449. 7400 425 14 7989 7549. 7500 440 15 8104 7649. 7600 455 15 8218 7749, 7700 469 14 8333 7849. 7800 484 15 8452 7949. 7900 502 18 8572 8049. 8000 522 20 8696 8149. 8100 546 24 8824 8249. 8200 574 28 8953 8349, 8300 604 30 9082 8449. 8400 633 29 9210 8549. 8500 661 28 TOTAL COORDINATES 1559.69 i".~ 639,60 1610.73 N 657.31 1663.08 N 675.33 1716.25 Iq 691.79 1770.95 N 706,35 1~25.54 N 7i~,39 1880.15 N 727.19 193~.92 N 733.93 2000.39 N 737.01 2066.83 N 736.05 2140.14 N 733.09 2219.61N 730.51 2301.81 i~ 728.49 238~.37 N 724.62 2462.80 N 721.17 A~CO O/G w'GI 1 I.,iAGF~ETIC F;ULTI-$HOT JULY 79 IFITERPOLATED VALUES FOR EVEN 1000 FEET OF [',,iZA.SUREt) DEPTH, TRLIE MEASURED VERTICAL :SUB DEP TH DEP TH TOTAL CO()RD iNATES 1000 999, 950, 2000 1999, 1950, 3000 2999, 2950. 4000 3983. 3934, 5000 4900, 4851, 6000 5816. 5767. 7000 6678. 6629, 8000 7558, 7509, 9000 8385. 8336, 3,31 S 19,22 S 133.15 N 490,47 N 854.54 N 1328,5B N 1776,18 N 2331,48 N 1.~0 E 6.34 E 12,18 E 37,15 W 204.96 W 370,12 W 546,98 W 707,67 W 727,26 W I~00 1600 240O 28OO ARCO OIL. 8i' GAS WGI -i MAGNF_.,"I'lC MULTI - SHO*I* RADIUS OF' CURVATURE SCALE I'*= I000' AUG. 2~ 1979 I-ALL~i DEPTHS 'SHOWN IARE. 'I'VO. · $~00 ~ 6000 '~ ?600 eOOO ~,~ AR CO OIL 8~ GAS WGI-I MAGNETIC MULTI- SHOT RADIUS OF CURVATURE SCALE I"= 500' AUG. 2~ 1979 TVO = 8582" TMO = 9252' Al.J_ DEPTHS SHOWN ARE TVO 840o 8000 7600 ._ 7200 6600 64,00 6000 5600 5 4800 4400 4000 3600 $200 Ea /htman / ipstock l A PETROLANE COMFY REPORT of SUB-SURF.4CE DIREC TIONA L SURVEY ARCO 0IL & GAS COMPANY W.G.I. 1 WELL NAME PRUDHOE BAY~ ALASKA LOCATION JOB NUMBER A779 D0372 TYPE OF SURVEY MAGNETIC SINGLE SHOT DATE 7-9-79 SURVEY BY Steve Ratcli£f & Jim DeMonia OFF~CE · COMPLETION REPORT ARCO OIL AND GAS MAGNETIC SINGLE-SHOT SURVEY RADIUS OF CURVATURE METHOD OF SURVEY ~MP.UTED F.O~ ~ASTMAN BY F M LINDSEY & ASSOCIATES ~ AUG 79 WELL WGI.?_i K B FLEV 4.9 FT DECLINATION 31 DEG EAST RECORD OF SURVEY ALL CALCULATIONS PERFORNED BY I B M ELECTRONIC COMPUTER- t TRUE· ii'MEAs, DRIFT VERTICAL DEPTH ANGLE DEPTH D M · · DOG LEG SUB DRIFT TOTAL CooRDINATES C L 0 $ U R E $ :; SEA DIREC DISTANCE ANGLE DEG/iOOFT DISTANCE DEG, D M S 1762 0 15 1761.98 1712.98 510,00E 4,67 S 2754 0 45 2753,94 2704,94 $ 9,00E ~3,20 S 9 ~OOW 197 ~ 7 3517 9 45 3513,30 3464.30. N 4*OOW 3770 14 30 3760.58 3711,58 N16.00W 42,46 N 94.69 N 2,49 E 5,29 S 28 5 15 E 0.001 3,92 E 13.77 $ 16 92 4 E 0,050 .... !,.-~7.1 . 0,544 1.54 W 42,49 N 2 5 9 W 1.875 10.75 W 92.30 N 6 28 /+7 W 1.901 4/+72 25 30 /+420.61 /+371,61 N25.00W 306,26 N 108.54 W 324.92 N 19 30 54 W /+777 24 30 4697.03 4648e0~ N24,00W 423,5~ N 161,99 W 453.47 N 20 55 ~9 W 0~00 - - -5,i5 -13.77 2 ~ 7 ~ - 41.45 94.30 0.333 450.86 ~2,~., 3 O: : 6~10 32 0 6076.~2 6027.~2 N19.00~ 10~0.86 N ~08.5~ W 1118.~7 N 21 25 ~7 W 1.179 1~10.65 6629 ~2 0 6346.95 6297,95 N19.00W 1200.70 N 463.57 W 1287.08 N 21 6 38 W O.OCO 1279.23 ?:: :.: : :: ) . · :: , ARCO O/G ~G I"' ]' :77" :' ' RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER MEAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C L O $ U R E $ SEVERITY SECTION DEPTH ANGLE DEPTH SEA DIREC DISTANCE ANGLE DEG/iOOFT DISTANCE . .... .... . ,.. ;... · ..... . :7700..~25:0:7280, 72~1,65 ~ N1 8026 29 ~0 7565,09 7516,09 N 9,00W 1851,6~ N 668,85 W 1966,7~ N 19 51 ~9 W 0,61~ 1961,00 8.509 3~ 0 7977,9~ 7928,9~ N 1,005 2101,2~ N 686,~1 W 2210,~8 N 18 5 17 W 0,950 2206,80 8733 37 30 8160,82 8111,82 N 2,00E 2230,4~ N 682~.92 W 2~Z,65 N l_Z .... ~ .g~_~_ ........ g~-l,~ ............ g.A~.Q.,..~..A ..... 89,8 W 2*58,86 N 16 0 ~5 W 0'698 2~58,29 :9252 D7 *5 ; 8567,98; ~5~8'98 N ~'OOE 2552,~ W 2639,45 N ~4 46 ~7 W 0,429 26~9,45 . . , ; ...~ . .... ..: ..... . . BOTTOM HOLE CLOSURE 2639.45 FEET AT N 14 46 47 W TRUE Tt ¢ C VD · COORDINATE$ i: 149 149. 100 0 249 249, 200 0 . .:: : . ..: 0 649 649. 600 0 749 749, 700 0 849 849, 800 0 1249 1249, 1200 0 1349 1349. 1300 0 1449 1449, 1400 0 · 1649 1649,' !600 1749 1749, 1700 0.09 N 0.03 E 0,21 N 0.13 E ~ 0.6 0.03 $ 1.26 E 0,38 $ 1,53 E 0,76 $ ~,73 E 2.46 S 2.11 E 2.89 S 2.18 E 3.32 S 2.26 E . 4.61 1849 1849, 1800 1949 1949, 1900 2049 2049. 2000 5.07 S 2.56 E 5.62 S 2.65 E 6.26 S 2.76 E 2149 2149, 2100 2249 2249. 2200 2349 2349. 2300 2449 2449. 2400 2549 2549e 2500 ~9 2649. 2600 2749 2749, 2700 6,98 $ 2,89 7,79 S 3,02 8.68 S 3.17 9.67 S 3,34 10,7~ S 3,51 11.,~._S .... _3~_7_0__.~ 13.14 S 3.91 2849 .2949 3049 3150 3250 2849, 2800 2949~. ,2900 3049. 3000 3149. 3100 3249, 3200 3349, 3300 3449, 3400 3549, 3500 3351 3452 3553 0 0 0 0 2 14.88 S 5,40 E 14.~_~ 9~ E 9,07 S 11,78 E 0.70 S 8,27 E 7.96 18.80 N 0.77 E 32.15 N 0,77 W 48,75 N 2.08 W TRUE 3655 3649, 3600 6 4069 ::::' 4( 4174 4149, 4283 4249, 2 68,69 N 4,90 W 4100 25 6 196,31 N 56,24 W 4200 33 8 234,52 N 74,43 W 4834 4.749, 4700 85 10 445,14 N 171,56 W 4944 4849, 4800 95 10 486,43 N 189,78 W 5163 527Z 5381 5049. 5.000 5149, 5100 5249, 5200 5490 5599 5349, 5300 5449, 5400 5820 5932 6046 6161 6278 639.5 6513 6631 6749 5649, 5749, 5849, 5949, 6049, 6!49, 6249, 6349, 6449, 6865 6549. 6981 6649. 7096 .... ~9, 7210 6849, 732¢ 6949, 7437 7049, 5600 5700 5800 .... 5900 60O0 6!00 6200 6300 6400 6500 6600 6800 6900 7000 114 141 150 60 171 183 197 212 228 24b 264 282 300 _ 316 332 ...... 361 374 387 688,16 N 276,82 727~98 N 29~42 7 6 ~_8~_~_~,~.lZ ~ 0 814,95 N ~29,70 862,84 N 347,63 967,98 N 383,66 1024,90 N 402,66 1142~58 N ~43,55 1ao1~70 N 463~9! 9 9 12 14 15 16 18 18 18 18 16 16 13 1316,88 N 503,57 W 13'71,93 N 522,53 W 1477,31N 559e59 W 1527,37 N 577,68 W 1577,~6 N 595,06 W WGI-1 MAGNETIC ,SINGLE'SHOT ,SURVEY AUG 79 ' J O/G _,ASURED DEETh AND oTHER DATA FO_~_,~R-_Y.,~N .,1,QQ__LF'EET iOF .~._E~.--~D~_P_iHm_--.~ .... ~ 7550 7149, 7100 400 13 1627,93 N 611,60 ::777 8 73~ 7 8123 76~9, 7600 ~7~ 16 1899.33 N 675.5~ 8239 77~9, 7700 490 16 1955.23 N 681.51 ....... 8356 ~g~ .... Z~..O 7 ~7~. 7900 ~2~ ': 8595 ' 80~9': 8000 5~6 : 2 88~5 82~9e 8200 595 26 2299,1B N 680,52 8973 83~9, 8300 62~ 29 2379,08 N 677.7~ 9228 85~9. 8500 679 ' · . : · : ' . · .' : : . INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH. TRUE 1000 999. 950. 1.39 S 1.9~+ E 2000 1999, 1950. 5.93 $ 2.71 E 7000 6665. 8000 7542.0 661.6. 1380.87 N 525.62 7493. ~,839e0]. N 666.77 · · HORIZONTAL VIEW ARCO OIL ~ GAS W,G. I. I RADIUS OF CURVATURE MAGNETIC SINGLE-SHOT SCALE I"= I000~ AUG. 16~ 1979 . . TVD --8568' TMD = 9252' IALL DEPTHS SHOWN I ARE TVD 1200 28OO $6OO VERTICAL SECTION. ARCO OIL 8~GA8 W.G.I. i RADIUS OF CURVATURE MAGNETIC SINGLE- SHOT SCALE 1%!000' AUG. 16~ 1979 ALL DEPTHS SHOWN ARE TVO TVD = 8568' TMD = 9252' Post O,~ic;~ .× 3GO Anchorsge, A!a.~,~a~" 9.~5!';] _September 11, 1979 Reference- Enclosed are magnetic tapes for the follo~¢ing ARCO wells' g./.~_._S~_3-~ 7/30/79 Tape # 5566'1 ~ ,l~? 8/22/79 Tape # 55662 data. VerY truly yours, K. J. SM~lstrom North Engineering T.~,~,~MI.TTAL ,4- .527 DISTRIBUTION North Ceology Drilling Eng. Manager Geology S~ate of Alaska bIobil Getty Sohio Harat:hon Phil. lii)s Chevron Post Office Box 390 .~. Anchora3~ ,,a~,<a g95i0 Tclephor~:: 595' 277 5537 August 28, 1979 Reference' Enclosed are Magnetic Directional Surveys of the following ARCO wells' ~7/31/79 ~lti-Shot ~. ~-t0 8/19/79 ~blti-Shot NGI-13 6/21/79 ~.~lti-Shot NGt-i3 6/7/79 Single-Shot .y,-I--1 7/9/79 Single-Shot ~PleaSe sign and return the attached cop), as receipt of data. Very tz~!y yours, R. A. Bellinger North Engineering TRANSMITFAL # 29q DISTR/B!.f['ION North Geology ])tilling Eng. Manager P~& i) Geology State of A].aska D6 I blobJ.1 Cetty So]~io Che\,' Telep!~o,,~. '"" - ;' August 28, 1979 Reference: Enclosed are Sub-Surface Directional St~rveys for the following ~CO wells: D.S. 12-2 8/15/79 Gyroscopic n.s. 3-9 8/lS/7 " D.S. 14-8 8/10/79 " D.S. lZ-1 7/10/79 " · D ..... 4-~5 7/28/79 " ~~'.i.%~ 8/1/79 " . ~/Please sign and return the attached copy as recei?t of data. Ve~T truly ),ours, R. A. Bellinger North F~tgineering TIb~NSMITTAL # 296 D1S]']d B[JTI()N Nc)'rtit Ceology I)ri 11 :i.ng Eng. Manager R & 1) Ce. elegy State off Alaska Alaska 997 277 5,_'337 August 17, 1979 Reference' FI1. F: I' Enclosed are the following Cased Hole logs' D.S. 9-17 9/25/78 Differential Temperature Log 9/25/78 D.S. 3-2 6/27/79 Spinner Flolog 6/27/79 ~ .... ~~2 6/27/79 Casing Collar Log 6/27/79 ~ .... WGI-1 ~ 8/7/79 Compensated Neutron 8/7/79 Please Sign and return the attached copy as receipt o:F (]lataG~// Very truly yours, R. A. Bellinger North Fmgineering TRANSMITTAL # 2 7 7 DISTRIBUTION North Geology Drilling Eng. Mamger R&D Geology State of Alaska D & ~I lT~x xo F1 Motel] Getty Sohio t'hil 1 Chevron ARCO Oil and G~-~"~mpany Alaska Re Post Office Box 360 Anchorage. Ai~ska 99510 Telephone 907 277 5637 August 2, 1979 Mr. HOyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 3-9 Permit No 79-22 D~ Permit No. 79-32 'Permi.t No 79-31 Dear Sir' Enclosed .please find a Monthly Report of Drilling Operations for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drill ing Engineer PAV' cs Enclosures ~ · , '. ~,/,.'l~ui;tjqi(jiI · . ~,, hof'E~[]O ARCO Oil and Gas Company Is a Division of AllanllcRichfieldCompany -, 'Form No. 10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 50-029-20369 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 WELL WELL OT.ER Gas Injection 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Atlantic Richfiel.d Company Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360 Anchorage, Alaska 99510 WGI #1 4. LOCATION OF WELL 258'5 & 1209'W of NE cr Sec ll, IllN, R14E, UM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec 2, TllN, R14E, UM 12. PERM1T NO. 79-31 13. 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 FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for July, 1979 Spudded well @ 1900 hrs 7/11/79. Drld 17½" hole to 2754'. Ran 13-3/8" 72# N-80 csg w/shoe @ 2731'. Cmtd w/4760 sx Arcticset II cmt. Installed & tstd pkoff. NU BOP. Did 122 sx top job. Drld shoe & 10' new hole. Tstd formation to 12.5 ppg equiv. Drld 12-1/4" hole to 8231'. Ran 9-.5/8" 47# N-80 csg w/shoe @ 8314'. Cmtd w/500 sx Class G cmt. Cycled & tstd FO's. Pumped 300 sx Arcticset I cmt thru lower FO. Did Arctic Pack job thru upper FO. Drld shoe & 10' new hole. Tstd formation. Drld 8½" hole to 9330'. Ran DIL/SP/BHCS/CAL/GR, FDC/CNL/CAL/GR & CNL/CCL/GR logs. Ran 7" 29# N-80 lnr w/top @ 8021' & btm @ 9334' Cmtd w/335 sx Class G cmt. Tstd lnr lap, ok. CO & tstd lnr to 3000 psi. ok. Ran ~/SO tst. Displ mud w/wtr & wtr w/lO.8 ppg CaC12. As of July 31, ran gauge ring & junk bskt to top of l nr. TITLE District Drilling Fngr: DATE 8/2/79 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed, Alaska Oil and Gas Conservation Cammission Hoyle H. Hamilton s<'~.~. Chairman of the ~s ibn Lonnie C. Stol'th /' ~ C~mr~ssioner ~ Ben Le/~onr~n Petroleum Inspector July 17, 1979 B.O.P.E. Test on ARO0' s ~'~I #1 Sec. 2, Ti/N, R14E, LT4 Prudhoe Bay. Unit Tuesday, July 10 - I departed my home at 8:00 AM for an 8:30 AM shc~up and. scheduled 9:30 AM departure via Sohio chazter for Deadhorse. Mechanical problemls witzh the aircraft delayed our departure until 10:35 Pm and we arrived in Deadhorse at 11.-55 AM. I proceeded to Sohio's R-3 for upccming B.O.P.E. tests, the subject of a separate report. Wed~y, July 11 - Standing by on R-3. .Thursday, July 12 - Mechanical displacement meter proving and calibration of 24" prover at Pump Station #1 compleX, the subject of a separate report. ~riday, July 13 - B.O.P.E. test on Schio's R-3 caM?leted. Saturday, July 14.- I proceeded to ARO0's ~I #1 where I met with Drilling ~Foreman Ben Davis and Parker Rig #141 Toolpusher Tcm Black. Tests began at 1:30 PM with the shoe on the 13 3/8" at 2732'. Kelly cock, upper pipe rams, check valve in the kill 1/ne, and three valves and six flanges in the chcke manifold tested to 5000 psig. Outside valve in the kill line, lower Kelly -~lve, and two valves ~.nd four flanges in the choke manifold tested to 5000 psig. Inside valve in the kill line, and the remaining three valves and six flanges in the choke man/fold tested to 5000 psig. The nmnual adjustable choke ~ms free noving and the Swaco superchoke was actuated both fully open and fully closed. Lower pipe rams, and inside valve and HCR valve in thee choke line tested to 5000 psig. Annular preventer then tested to 3000 psig. Acctm~lator pressure was 3000 psig. With the pturg off we simultaneously closed bothppe~i rams and the annular preventer and opened the t~CR valve. Accumm~lator pressure drop~ to 1200 psig and stabilized. The pump was then turned on and acct~ulator pressure built 200 psig in one minute, forty seconc~. N2 backup bottles tested 1825, 1850, 1875, and 1875 psig. ~ile backing out of test plug to test the blind rams I toured the location which was well organized, the rig in good repair, reserve pit ~11 built, and the well sign was in place. Blind rams then tested to 5000 psig. B.O.P.E. test ~RCD's I #I 2 July 17, 1979 Both ball and dart type floor val~es were in place and tests %~re concluded at 2:50 ~. -~ A field ~i~'r~port was prepared with a copy given to Ben Davis, a copy mailed to Bob Bines, and the original attached to. this report. S~y, July i5- stan~ by at ARCD's DS 12-2 for ~x~hng B.O.P.E. test, ~" ~j~-6f a separate report. ~y,~:~july___ 16 - B.O.P.E. test on ANO0's DS 12-2 c~pleted. I departed Deadhorse via Wien Flt. %20 at 9.-45 Pm arriving in Anchorage via Fairbanks at 11:50 ~ and at my bxx~e at 12~20 AM. In ~u~ary, I witnessed suocessful B.O.P.E. test on ARO0's WSI %1. ! ~Y~_~23.~,_~.~!979 - John Glaser with Panker Rig %141 advised low~_r Kelly valve 5000 Drlg. Permi t~No-_~. <~ Operator Satisfactory Type Inspection Yes No Item (~)~Location,General (~Y () (~() (~Y () () () () () () () () () () () () () () () () () I. Well Sign 2. General Housekeeping t. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells _ 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. ,__,__,~ 8. Hrs. obser ._,___, 9. BS&W , , 10. Gr. Bbls. ( ) Final Aban--a-O-~-ment A1 ';a Oil and Gas Conservation Commi Field Inspection Report Well/J~Nt~gt~F~ S e c ~____T .L~L~N/_RJ 5/~:, _/~/-M Represented bY~Name & Number Satisfactory Type Inspection Yes No Item (~/'BOPE Tests 15. /~]~?~/~asing set 16 Tes~ fluid-( )wt~-] (-)mud (~oil Master Hyd. Control Sys.~-~_o~=psia (..~ ( ) (~-() (.,.~g.- ( )17 (,.~ () 18 (,...)~ ( ) 19 (~() 2o (,-V ( ) 21 (~/)/ ( ) 22 (~() (~)~ ( ) (~() (~Y() (~Y () 11. P&A Marker (~97' ( ) 12. Water well-( )capped( )plugged (u);' ( ) N2 btl s./&'AJ', 12J~ ,~t~,?j~_ps i g Remote Controls DrillinQ spool- :~, "outlets Kill Li~e-(~Check valve Choke Flowline (~};~tiCR valve 23 Choke Manifold No. valvs_~__flgs/~ 24 Chokes-( )Remote( )Pog.(~g'Adj 25. Test Pluo-(~ellhd( )csg( )none 26. Annular Preventer,j~,psim 27. B1 ind Ramso~-~:,psiq 28. Pipe Rams ~f~opsiq 29. Kelly & Kelly-cock~~psig ( ) ( ) 13. Clean-up (~ ( ) 30. Lower Kelly valve,~~sio ( ) ( ) 14. Pad leveled (~ ( ) 31 Safety Floor valves-( )BV /~art Total inspection observation time/~hrs/~Nl~ Total number leaks and/or equiP, failures___~~ -- .~ .___ ~ ..... 2~ ~ ~~ ~~ ~_~- , ~ --- days or when ready~ I n spec ted by~Da te_~_~,/-_~Z~ June 27, 1979 Re: Prudhoe Bay Unit WG.-I #1 Atlantic Richfield Company Permit No. 79-31 Sur. Loc.: 258'S & 1209'~ of NE cr Sec 11, Tll~, R14E, UM. Bottomho!e Loc.: 2230'N & 2100'W of SE cr Sec 2, TllN, R14E, U~3. Mr. P. A. Van Dusen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Dear Mr. Van Dusen: Enclosed is the approved application for permit to drill tlle a~ve referenced well. Well samples, core chips and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information on all logs shall be submitted for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have helen classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any v;aters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal $~Yater Pollution Control Act, as amended. Prior to commencing operations you may be contacted, by a representative of the Department of Environmental Conservation. Mr. P. A. Van Dusen Prudhoe Bay Unit WGI #! -2- June 27, 1979 Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we 'would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dr il 1 ed. In the event of suspension or abandonment, please Give this office adequate advance notification so that we ma~ have a witness present. Very truly ..yours, Harry W. Kugler Cc~mmissioner ~sV O:.~ ©? ~ Alaska Oil & G Conservation Commission Eno losure cc.- Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Lak.~r Law Compliance Division w/o encl. ARCO Oil and Gas npany Alaska Region Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 20, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 12-2 WGI #1 Dear Mr. Hamilton' Enclosed herewith is our Application for Permit to Drill, the $100.00 filing fee, and the required survey plat for the above mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAY'cs Enclosures ARCO Oil and Gas Company is a Division of AttanticRichfieldCompany Form 10-401 ~ REV. 1-1-71 la. TYPE OF WORK DRILL [~[ DEEPEN [] b. TYPE OF WELL Z NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 9951 SUBMIT IN TRIP't E (Other instructions on reverse side) STATE OF ALASKA API 50-029-20369 OIL AND GAS CONSERVATION COMMITTEE ~i:~'.~-~ ~?-~. LEASE DESIGNATION AND SERIAL NO. PERMIT TO DRILL OR DEF~,/:.~N '~: ~ '~ .... :'"' ADL 28302 '%, 4. LOCATION OF WELL At surface 258'S f 1209'W of N/E-ce. Sec. ll, TllN, AtDroposed orod. zone 2230'N& 2100'W of S~E/cr. Sec. 2, TllN,. 13.' DISTANCE IN MILES AND DIRECTION I~OM NEAREST TOWN OR POST OFFICE 9 miles North of Deadhorse, A1 aska R14E, UM R14E, UM 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI #l lO.P rud hoeFIELD AND POOL,BayOR W~ILpCqT ,l_1 el Cl- {)}%-t~;~}~;, ,~ i] ii l l. ~'C.'~ ~.,"ff.,'~l.7~tldwYogl "'" ' HOLE OBJECTIVE) Sec. 2, TllN, R14E, UM 12. 14. BOND INFORMATION: T~EStatewide Suretyand/orNo. Federal Insurance Co. #8011-38-40 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 2100' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 1320' 16. No. OF ACRES IN LEASE 2560' 19. PROPOSED DEPTH 9660'MD, 8564' TVD 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 49' RKB Amount $10o,o0o 17. NO.ACRES ASSIGNED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START July 5, 1979 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 32" 20" 94 H-40 80 250 sx PF II to surfa£e 17-1/2" 13-3/8" 72 MN-80 2700 Circ to surface-approx. 5500 sx 12-1/4" 9-5/8" 47 80&95 8900 -+1000' cmt column on first stage plus 300 sx on second stage 8-1/2" 7" 29 N-80 9660 Aporox 350 sx Atlantic Richfield Company proposes to directionally drill this well to ±9660'MD (±8564'TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be used. The BOP equipment will be pressure tested each week & operationally tested each trip. A string of 7" 29# N-80 tubing, packer & necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Selected intervals within the Sadlerochit will be perforated and reported on a subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be used on all wireline work. The downhole safety valve will be installed and tested upon conclu- sion of the job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen 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. - Dar~, 6/16/79 ~TLE District Drlg. Engineer (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED =VES DIRECTIONAL SURVEY REQUIRED '~YES [] NO CONDITIONS OF APPROVAL, IF ANY: MUD LOG [] YES I O THER REQUIREMENTS: A.P.I. NUMERICAL CODE PERMIT NO. 7 '~ "~ ( APPROVAL DATE -r .... ~'~ , o',n APPOVED BY ~'~-~"~r+'- 4~ 2~: ~'~e TITLE.~lTlm'~ 88 iOner DATE ' / e Instruction On Reverse Side 6/27/79 Protracted Section Line 1209 1184 1159, No. 4 1154 AS- BUILT WELL No. I ! LAT 70° 19'4,2.634" J LONG. 148°29'58.597" J WELL No. 2 13°26' I LAT. 70° I 9'4 1.476" J LONG. 148°29'57.861'' c~ ! WELL No. 3 ~ ! LAT. 70° 19'40.321" LONG. 148°29'57.153" 2 112' - / WELL No.4 Ii iLAT' 70° i9'39.170'' L LONG'. 148°29'56.399'' Y ,5 972 002.90 X 684 985.72 Y 5971 885.82 X 685 OI 3~80 Y 5 971 769.08 X 685 04 Y 5 971 652.66 Y 685 06967 CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN. AS-BUILT SURVEY MADE BY ME OR UNDER MY SUPER- VISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. DATE m SURV~OR ~ m ARCO No. AFE HVL No. ATLANTIC RICHFIELD CO. AS- BUILT NORTH INdECTION SITE NO. 2 WELLS 1,2,3 8~ 4 LOCATED IN PROTRACTED SECTION I I, T II N, R 14 E, U.M., ALASKA ,,, PREPARED BY HEWi TT V. LOUNSBURY E~ ASSOC. 723 W. 6TH. AVE., ANCHORAGE, ALASKA DATE JUNE 1979 SCALE I "= 300' CHKD. BY GDD FLD BOOK No. 4. Protrected Section Line 13°26' ~"~ I! 12 ~t -- -- 1209 ~ 1184 1159~ 1134 CERTIFICATE OF SURVEYOR I HEREi~Y CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OFALASKA AND THAT THiS PLAT REPRESENTS AN. AS-BUILT SURVEY MADE BY ME OR UNDER MY SUPER- VISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. DATE " SuRviVOR AS-BUILT WELL No. I LAT 70° 19'42.634" Y .5 972 002,90 LONG. 148°29'58,597" X 684 985.72 WELL No. 2 LAT. 70°t9'41.476" Y 5971 885.82 LONG, 148029' 57,861" X 68501 WELL No. 3 LAT. 7'0°19'40.321'' Y 5971 769.08 LONG. 148°29'57.133" X 685 041.62 WELL No. 4 LAT. 70°19'39.170'' Y 5971 65;?..66 LONG'. 148029'56.399'' Y 685 069.67 ARCO No. AFE HVL No. ATLANTIC RICHFIELD CO. AS-BUILT NORTH INJECTION SITE WELLS 1,2.,3 8~4 LOCATED IN PROTRACTED SECTION II, TIIN, RI4E,U.M.,ALASKA PREPARED BY HEWITT V. LOUNSBURY 6 ASSOC. 723W. 6TH. AVE., ANCHORAGE, ALASKA DATE JUNE 1979 SCALE I "= 300' CHKD. BY GDD FLD BOOK ARCO Oil and Gas mpany A!aska Region Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 June 21, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' WGI #1 Dear Mr. Hamilton' Enclosed is a Sundry Notice outlining our changes for the above- mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV' cs Enclosure ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany Form 10-403 REV. 1-10-,73 Submit '*Intentions" in Triplicate & '*Subsequent Reports" in Duplicate STATE OF 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---" for such proposals.) WELL L--I OTHER Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Alaska 99510 4. LOCATION OF WELL At su trace 258'S & 1209'W of NE cr Sec 11, TllN, RI4E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 49' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. WGI #1 10. FIELD AND POOL, OR WILDCAT ?rudhoe Bay Field-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 2, TllN, R14E, UM 12. PERMIT NO. )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (other) Chanqes to Permit to drill SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ~letalls, and give pertinent dates, Including estimated date of starting any proposed work. Listed below are the changes which need to be made to our Permit to Drill Application for WGI #1. Item lb. should read gas injection instead of gas well. Item 10. should read Prudhoe Bay Field-Prudhoe Oil Pool Also enclosed is a copy of the diverter system which will be used. 16. I hereby certify that the foregoing is true and correct TITLE District Drilling Enginee,,r' DATE 6/21/79 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side SURFACE DIVERTER SYSTEH 3 o 2. 3. 4. 20" Bradenhead 20" 2000 psi drilling spool 20" 2000 psi annular preventer 6" butterfly valves Oc~pany CHECK LIST FOR Nt~q $~LL PERMITS Yes 1. Is the permit fee attached .......................................... 2. Is ~11 to be located in a defined pool ............................. &/5.,~:, ., 3. Is a registered survey plat attached ................................ 4. Is roll located proper distance frcm property line .................. / 5. Is well located proper distance frcm other %~lls .................... 6. Is sufficient underdicated acreage available in this pool 7 Is well to be deviated .... ....... ' 8. Is operator the only affected party ....................................... '}'~ .. 9. Can permit be approved before ~en-day wait .......................... 10. 11. 12. Remarks Lease & Well No. Item (1) Fee Approve Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... (3) Admin. ~?'.. / ,, <_ Is conductor string provided ........................................ ' - 14. Is enough cement used to circulate on conductor and surface ......... 15. Will cement tie in surface and intermediate or production strings ... Will cement cover all knc~n productive horizons ..................... 16. (4) Cas~. ' "; :!: :: ,? ,, 17. Will surface casing protect fresh water zones ........................ ,;'r::.: 18. Will all cash~9 give adequate safety in collapse, tension and kurst.. 19. Does BOPE have sufficient pressure rating - Test to ~'~,,,. - psig .. Approval Reconmended: (5) BOPE /:?: Additional Requirements: Geology: Engineering: hS',~< ...... ..' LCS BE%7 ,~'A ..... PAD :::2 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of.the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX.' .. No special'effort has been made to chronologically organize this category of information. 1ti. 111 .111ili It tl ii Ii 1I 11 11 I1 11111[ t 9- UC T- 19 19-UC1'-'79 22:12:51 10'107 ~ STO()b T A P g r~ t~; A ,!) g R E, t3 F 15 P, HC, D A T ~.;: '7 q / 11, 0 / i 9 i~VMBER :IS 50-029-2{)3e..9 I, F; j',,i ('; ] i~: F 1 F t. D: ~ I.,,C 1' j. u h;: S TA'['t~,: 1 AP1 APl. AP.I FII,I~ ,St. Zi~ ~.;×t-~ PF~tJC ;SAr,': REP DkltPi' SHJ. f'T 9300.000 9200.000 G R Gl-,' '-939 118 -999 2 109 100 ~6 "58 25 2 29 ' :35 24 2 28 20 2b -26 42 2 2 .5:5 2 55 1 ] 6 2 2i8 .8 .] . ] .0 .8 ,3 .2 ol .9 .5 .3 .3 .3 .2 . (i .O .O 25 50 7 o 50 75 59' 01 19 75 0 ] 0 b 7% II 0 '0 2'7 n o ~9 75 L [) ALI R A T 1 b D i) T tho C A B 1 i'~ .Fi A 'P .i b0 C A b i N k A T DT 1. i., D C h L, ! i 1, i.') OT C Al, 1 D"I' 1.1, [) C A b i t;' T 1 LD C A b I C~I VA -99 7 :I I) 7 17 9.250 7. 484 2.844 9. 250 4.559 9.260 2.584 1.. () 00 3.531 9.2;19 2 .~48 ~. 375 0.000 8.1.88 I. b79 8. 565 25O .{ 52 631 750 8.2'7 I .266 ,i. 750 5. O00 ,~.422 1.522 · :}. '? 50 f 8. ,t 05 1,. 520 1 {)~. 375 2 O. '? bo 8.234 2.330 9q. 150 4.180 9. 3.49~ 94. 750 5,020 9.789 3.412 1. 0 ?. t 88 D R ~ o DRHU 1) ~ rJ O NCN L G~ ii C t,~ b uP, riO N C ~,i L i L FY) N C N b V A b U t. -999.250 0.0 .] 0 2932. 000 -999. 250 4. t6t 0.0 '~ 2 27 J 2.000 -999.25{:) 8.9,?,0 0.048 :2098. 000 -999. 250 9..375 9.019 37~2.000 -999.250 -0.000 419~.000 -999.250 42.2i9 50bO.O00 -999.250 39.688 3936.000 -999.250 40.719 -0.004 4252.00O '99g.250 I i. 797 0.01 (i 26o8.000 -999. 250 3.905 u.oi0 22t)0.000 -999.250 ~. 7 g 8 n. 0 ..t 1 171 -99~.250 b b ~ d r,i P H 1 I]LSU t. C N b bbs U ~ P H i F C i'~ b bbs U b,b 8 U NPH 1 bUSU NPHi bbSd LG~U LLSU i'~PH1 L,b 8 L.' ~"~ P H J bb B O i~ P H 1 VAbU~ -9~9.250 3Z.715 950.500 5.95'7 2~.709 1022.500 12.250 27.7~4 7 i I. 500 lq. 0.000 14.453 1991.000 309.000 13.525 2422,000 124.938 8.154 3bOo.000 bl.~O0 il.810 2424.000 31g.250 11.914 zSo~.OOg 28.~91 24.110 112/.000 0.930 ~1.7~7 Ol4.0oU O.1il 39.990 ~31.7bO S 100. () 00 8 () 00. O 00 790 U . 000 7 @ 0 0 . 0 0 0 1700 · 000 7 h C, O o 00 0 7 5 ~,')0. C) 0 0 G t.~ G~ R tt 0 t::. C, R G F~ Gig ~..; ~ :~ ,~: 6P uP V A ,L, L:t t~; - 1 -92.8"75 b4.31 3 2. 704 7 g~. 5O0 -,.,1 '½5~. 000 '7 O. 250 2.45i 82.!88 9.00 U It. 25O 2.451 82.~88 -i 49.0()0 '7 ~. 250 82.188 '76.25 i) 2.451 82.188 9.00 76. 250 2.451 82.i8~ 49 76.250 2.451 82.1 88 qg,~)UO 76.25:) 2.451. 82,1g~ - l 4q. 900 2. '~51 S2.18~ 76. 250 2.451 25 0 451 t L, D OT C A i., 1 1, L, l~ C A L I iI~D .0 T 1 i,~ !) C A ]., ii. h~A'l 1 CAhI I b L) CALl CALl O T I I~ [} C A L i :",, F, A 'r D I~ V A b t,i ~ 20 U (5) . 00 () 3. q28 85.t75 5.219 72.3'75 5.219 4...~ 48 2. ] 75 5.219 4.34[! 72. 375 5.219 8.68O '72. ] 75 5.219 '72. t 7 5 5.219 8. 680 4. -~ 48 12.t75 '5.219 72.~75 5.21 8 .~80 72. ~ '7 .5.219 8. h 8 72. 5.21g 72,. 375 ihM i L, M DR,HO n C N b GR 1 L M bi C ~,,i b GA ,1 L P. i [J !'4 ihM DP:HO GR 1 h C h b D~IIL) r,l C i',t b D H ri u V aLUk 2000.000 ,,,0.1 41 1349.000 89.500 20O0. O00 -0.516 339.000 t~ 7,500 20OO, 000 .,,0.516 339.000 i O0.4,38 20O0.000 -0.5ih ]39.000 95.025 2000.000 -0.516 3~9.000 122,000 00 . 0 0 39.00 55.31 2000.000 ..~39.000 01.25u 2000.uO0 -0.51~ 3t9.000 b2.O00 20',')0. OOO 339. 000 2ouO. 000 -0.51 b 39.090 52.781 20u(). ~39.000 b L, '.8 U L L, 8 U i:,i P H i FC Nb i:,~ P H 1 J"C Nb b L 8 tj hi., 8 Ij 1. l.,., 8 U t~P HI eC ;qb FC i'.lb i~PHi bbSU r; P H J bUi~U 3.021 b0.~35 J07.500 3. ,1 e~ 0 3'72o5.b25 0.120 3.160 372~5.625 u.120 3.1o0 0.120 3.lb0 3'7205.625 0.120 3,160 37205.625 0.120 :).lbo 3 726b. b25 U. 120 3. lbo 3t2bb.625 0.12(; 3. ioO 37265.0Z5 u.i. 20 3.1e9 372t~b.b25 O. lZ0 3.tbU 372Ob.bZ5 O.lZ0 D k; 1::' '[ H 7 20 0.0 0 0 7 1 00 . 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LD CAb1 DT [ L D C A L, .t N F: ,h T N P A T DT 1 b D mRAT 0 T 1 L, D CALl b T i hO C Al, l CALl DT Ii:D CALl L) :1' Of 5.219 8. b~O 4. t-58 72. ~75 5.2i9 8. 4..;t 48 t 2. ?, 75 5.219 8.68O 2. ~ 75 5.219 12.375 5.219 8.680 4.348 72.375 5.219 4. 72. ] 75 5,219 8.68u ~.]4,8 72.375 5.219 72.375 5.219 R .bSO 4. ~8 72..!75 5.219 8.680 72. ,~75 5.219 8.b80 4.3 ~ 8 72. ~'75 D R H U i'~ C N b I b Ft i,)RdtJ 1i C N b Ui~HO N C t,l b GP {,) R H U 1 L i4 1 b i4 [)R~u r,~C N b i t,,~ M VAbU~- 2000.000 -0.516 339.000 47.650 2000.000 -O.b16 3,~9.000 52.969 2000.000 -0.516 ]39.000 56.15~ 2000.000 -0.516 339.000 48.655 2000. 000 -0,5lb 339,000 53.938 2000.000 -O.b16 339,000 ~8.315 2000.000 -0.510 ~39.000 5~.~38 20{.)0.u00 -0.51o ~39.000 4a.125 2 O 0 0.0 O 0 -O.5tb 339. 000 41.781 2000. 000 339.0 0 ~) 41.875 00.000 -0.516 39. OOO 35. ~4-~ b.b~U N P H 1 i.j L 8 U FC i~ b L., b 8 U b L, ~ U NPHI F C N b b h 8 U N p H i b b 8 U ~'CNb bLSU ~ P d i L, bhU NPH t. 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Ob3 2000.000 !9.891 M t',3 E M t) i'J i C bbs U N P ti i, ~ C,.~ b bbSU t'~ C r~ L [, L 8 U F C i"4 b bbSiJ NPHi FCNb bbSU bbSU bbSU *'4PHI bbSU !',a p ~. 1 ~ C ~ b bLciU t_,b8 U FCNb L,[JA U 1" C i',~ b 3.1o0 ~7265.~25 0.120 3.160 0.i20 3,160 31265.625 0.1,20 3.160 0.120 3.169 J'1265.625 u. 12 o 3.1 60 31265.b25 0.120 3.tho 312e5.b25 0.120 3.100 3 lZ~5.625 U. 120 37265.025 O.12U 3.1b0 0.120 ~/265.~25 0.12u P E P "T; H .5000.0 (} U 4900. 000 4800. 000 47 0 ti. 0 00 .4 ~ O 0. O 00 45 O 0.00 0 44UU. 000 ~1 G F: ~P GP G~ GR S P k.Ht SP k. i4 L] SP GF (.-,~ V A L, O E; - 1 ~ 9. O 00 7 e~. 250 k .451 ~.2.188 49,000 7b. 25'0 2.45 ! 82.1.88 49. it e. 2 :..50 2.451 82.!88 - 149. 000 7 e. 250 2. $5 ! 82.188 49. 000 ?e. 25o 2.451 82.188 9.00 t) 6.250 2.451 82.18~ - i 49. 000 76. 250 2. 6.25 u 2.451 '.d2.18~ -! 49. ()0¢~ le .25u 2.451 82.188 -' i 4~ 7~. 25O 2. 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OuO -0.51~ 339.O00 bbSU .j.loO r~Ph,t. 31205.~25 FC~,b O.lZO Lb8 O 3.1 bO i~iPHI 3/2e, b. 6:Z5 FOrth 0.1, 2(.) bbSU J. 1 O0 lqPHi 37205.b25 f'C t'~b U. 120 LbSU 3.1 O0 i'~Ptil 3'/2.05.~25 fCl',ib O. I 20 bbgU 3.100 ~Ci~b 0.120 L, b ~ U 3.160 NPH/ 312bb.b25 ["C N b 0.120 ~PHi .ii205.b25 kCNb U.lZO NPHI 3? 205. b25 .l~Cr, b U. 120 LL.,8 u 3. 100 ~,~PH i 312o5.025 CNn ,~. 120 t.~bN U 3.1 bt) i~PdI 3 t205.6Zb FCl'~b O. 120 bbsU 3.1 oO [- CNb U. 120 ]700. 000 ~ 600 . U 00 ~ 500 . 0 () {) ] 400 . 0 () 0 · 3 { 0 (,> . () 00 3200. {) 00 ~tUO.()(() 30 U 0.000 (~.P GP S P GB P, t-~ (J b SP ~P H,f!(Jb G b SP G ~ 6P V A L, 0 ,t - 149.0{.!0 76.25,2) 2 · :.~ 51 ~2.188 -! 49 1~. 25O 2.451 49.000 "1~, 25o 2.451 82.188 '"1 49.000 7 .b, 25O 2. ,'~51 - 149.000 2.451 82. I 88 -! 49.00n ? 6.250 2.45I 82.188 -1. 49.000 76.250 '2,45i -1.49.000 250 82.18~ 2.451 d2.1~8 - 1 4~J · ()0() 70.250 2.45! -14q.00O 2.451 CAi., DT t. bD CA h ] i',~ H A T I b !) 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