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Home My WebLink About169-014• STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APR 302013 WELL COMPLETION OR RECOMPLETION REPORT AND LO 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 20AAC 25.105 20AAC 25.110 ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero 1b. Well Class ,/ . ® Exploratory ❑ Stratigraphic ❑ Development ❑ Service 2. Operator Name: ✓ BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband.: f 4/5/2013 12. Permit to Drill Number: ✓ 169-014 ' 311-380 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 3/7/1969 13. API Number: ✓ 50-029-20011-00-00 4a. Location of Well (Governmental Section): Surface: 1102' FNL, 1743' FEL, Sec. 31, T11 N, R1 6E, LIM Top of Productive Horizon: N/A Total Depth: 1102' FNL, 1743' FEL, Sec. 31, T11 N, R1 6E, UM 7. Date T.D. Reached: 4/22/1969 14. Well Name and Number: ✓ SD311116 8. KB (ft above MSL): 27,40' GL (ft above MSL): 15. Field / Pool(s) ✓ Sag Delta Field /Wildcat Poop 9. Plug Back Depth (MD+TVD) Surface Surface 4b. Location of Well (State Base Plane Coordinates, NAD: Surface: x- 726671 ' y- 5951174 . Zone- ASP4 TPI: x- y- Zone- Total Depth: x- 726671 y- 5951174 Zone- ASP4 10. Total Depth (MD+TVD) 1* • 9094' 9094' 16. Property Designation: ADL 028343 11. SSSV Depth (MD+TVD) `' None 17. Land Use Permit: 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 18. Directional Survey: ❑ Yes ® No (Submit electronic and printed information per 20 AAC 25.050) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIL, Sonic/ GR 122. Re-Drill/Lateral Top Window MD/TVD: N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE I AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 30" 94# H-40 Surface 82' Surface 82' 36" 210 sx Fondu Fly Ash 13-3/8" 61# J-55 Surface 3173' Surface 3173' 17-1/2" 1650 sx Class'G' 825 sx Class'G' 9-5/8" 47# N-80 Surface 9088' Surface 9088' 12-1/4" 870 sx Class 'G' 1100 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SCANNED SEP 2 6 2013 25. TUBING RECORD SIZE DEPTH .SET MD PACKER SET MD TVD) None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION?[] Yes ® No DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED -31'- Surface 4.5 BUS Arctic Set -36" - Surface 1/2 yd Cement 27. PRODUCTION TEST Date First Production Not on Production Method of Operation (Flowing, Gas Lift, etc N/A Date of Test Hours Tested Production For Test Period OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No • Sidewall Core(s) Acquired? ❑ Yes ® No s If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS MAY -1201 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE t Submit Original Onlyl, 29. GEOLOGIC MARKERS (List all formations a rkers encounter 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No If yes, list intervals and formations tested, briefly summarizing test Permafrost Top results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top Schrader 6778' 6778' None Top HRZ 8674' 8674' Bottom HRZ 8853' 8853' Top Sadlerochit 8875' 8875' Formation at Total Depth: 31. List of Attachment! Summary Pre-Rig Work, Well Schematic Diagram, Photo of Welded Plate 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Email: Aras.Worthington@bp.com Contact: Aras Worthington, 564-4102 Drilling Technologist Printed Name:Title: astu7 nA Si nature. 6,Phone 564-4091 Date:4jN/6 \�JIVV\,\J.v INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for 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 and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only • • SD311116, Well History P&A Date Summary 03/02/13 T/I/O = ?/?/?. Temp = SI. Bleed IA & OA. Unable to bleed due to hardened snow encasing valves. Installed hooch around well with heater to thaw out snow. Job in progress. 03/12/13 T/I/O= ?/?/?. Temp= SI. Bleed IA & OA to 0 psi (P&A). Moderate ice has thawed. Called vac truck to vac out water. Plywood still frozen in place. May need guard rail around well moved before plywood can be moved. 03/14/13 T/I/O = VAC/VAC/440. Temp = SI. Bleed IAxOA. Bled OAP to 0 psi in 1 min (approx 1 quart fluid returns) and still weeping. Held open bleed for 6.5 hrs with a total of -1 gallonfluid returned. Monitor for 30 min OAP remained at 0 psi. See log for details. 03/15/13 1/0 = VAC/1. Temp = SI. Hold open bleed on OA (pre P&A). Bled OAP to 0 psi in <1 min(fluid -1/4 cup). Held open bleed on OA for 8 hrs (-2 cups fluid returned). Monitored for 1 hr. OAP unchanged. Final WHPs = VAC/0. SV, SV = C. IA, OA = OTG. 1600. 03/16/13 1/0 = VAC/0. Temp = SI. Hold Open Bleed On OA (P&A). OAP did not increase in 2 hrs since day shift. Held Open bleed for 9 hrs on OA getting - 1 cup fluid returns. Final WHPs = VAC/0. SV = C. OA = OTG. 04:30 hrs. 03/16/13 1/0 = 0/0+. Temp = SI. Open bleed on OA ( P & A). No change in OAP since night shift (3.5 hrs). Held open bleed for 8.5 hours on OA. - 1 cup returns, all fluid. SV = C. IA, OA = OTG. 1645 hrs. 03/17/13 I/O=Vac/0+. Temp=Sl. Open bleed on OA (P&A). No change in whps. Held open bleed on OA for 8.5 hrs. Approximately 13 Mililiters of fluid collected. Final WHP=Vac/0. SV, SV=C. IA&OA=OTG. 1630. 03/17/13 1/0 = Vac/0. Temp = SI. Open bleed OA (P&A). No change in WHPs since day shift (2 hours). Held open bleed for 8.5 hours. No liquid returns. SI, monitored for 1 hr. No change in OAP. Final WHPs = Vac/0. SV=C. IA, OA=OTG. NOVP. 04:45. 03/18/13 I/O=Vac/0. Temp=Sl. Open bleed on OA (P&A). No change in whps. Held open bleed on OA for 9 hrs. 1 Mililiter of fluid collected. Final WHP=Vac/0. SV, SV=C. IA&OA=OTG. 04:30 hrs. 03/18/13 I/O=Vac/0. Temp=Sl. Open bleed on OA (P&A). No change in whps. Held open bleed on OA for 3.5 hrs. No fluid, no pressure. Used bbl pump to evacuate fluid from OA to below 3'. Final WHP=Vac/0. SV, SV=C. IA&OA=OTG. 03/19/13 1/0 = VAC/0. Temp = SI. Open bleed OA (P&A). 9 5/8 tagged hard surface @ 18 feet 4 inches from treecap. Fluid is 11 feet 6 inches from treecap. Installed 4" lifting cap with sling and clevis = inspection current. Removed integral caps and jewelry. Removed plywood from cellar. 03/29/13 P&A: Cut off and remove wellhead 4' below tundra level with Goliath saw, took 5 blades to complete cut. Sent well head to valve shop to recover salvageable equipment. 03/30/13 P&A: Water wash diesel from the 13 3/8" x 9 5/8" annulus to hard bottom of 31' with hot fresh water, vac out water as deep as possible, 13'. 03/30/13 Assist DHD w/ plug & abandonment by water washing inside casing strings. Page 1 of 2 • • SD311116, Well History P&A Date Summary 03/31/13 P&A: Evaluate fluid in 13 3/8" x 9 5/8" annulus, appears diesel has swapped out with the water pumped yesterday. Re -cut casing fo facilitate welding cap plate. 04/01/13 Well work in progress. Continue casing re -cut. Cut complete, rig down & back haul equipment. 04/01/13 Assist DHD w/ plug & abandonment by water washing inside casing strings. 04/02/13 P&A: Repeat water wash of 13 3/8" x 9 5/8" annulus to remove all hydrocarbons, circulate warm fresh water in at 31' and remove fluids at surface with vac truck. 04/03/13 P&A: Pump aproximently 3.5 bbl's artic set cement into the13 3/8" x 9 5/8" annulus and 1 bbl into the 9 5/8" casing, brought both to surface. 04/04/13 P & A: Continue work on cement top job for State Inspection. Removed -1/2 yd of gravel & soil from conductor, found cement -36" down. Will top off with cement in AM. 04/05/13 P & A. Topped off the 30" x 13 3/8" conductor pipe with -1/2 yd cement. Final P&A inspected by (John Crisp) AOGCC. Weld on the 30" identification plate and cut off 5 1/2" rat hole pipe 4' below tundra level. AES to back fill the excavation next. Page 2 of 2 is l TREE DRY HOLE WELLHEAD= ACTLIATOk2= KB_ B a D r11 '11 . . . .. . ................ . BF. ELEV = ...... KOP= _ Max Angle-= Datum M7= _._.. Dahrm TVD - 115:8 ASI CRAE NT(4119112)I—I SURFACE - 30" CONDUCTORCEMENTED 1-4 ___ 82" w /210 SX FONDU/ FLY ASH 15.8 ASI CEMEW (TAGGED 04117112) --_ 948 - 949' 15.8 ASI CENEN T (TAGGED 04/15/12)—i 980" 1080' 15.8 ASI CEK494T(04105/12} DRILLING MUD 13 318' GSG, 61#, J-55, D 12.515" j—{ 3173' STAGETOOL 1—i 5500' ESTIMATEDTOC w 13o% wASHt OUT H —6740 CSG, 47#, N-80, ID = 8.681' I 9088' so,g, SAFETY NOTES: 470' - 478' -- PERFORATIONS (04/17112) 1 498" 9-518" C -BP w / 2.4" HOLE MILLS THRU MIDDLE (03/29/12) 910 ' 920' PERFORATIONS (04/17/12)....': V 980 ' 1 pp0'--�FORATIONS (04116/12) 1500`—�iFo�nT10r� (�41o5/1zj 2040' - 6520' TOC -15.8 PPG CLASS G (04/05/12 TAGGED) 2400' 1--) EST TOC w 130% WASHOUT IN OH SECTION TOP OF SOLIDS 8875' 1-19-518- CIBP DATE REV BY C NS113- TS DATE REV BY COMMENTS 04/28/69 P&A COMPLETE 04/14/11 MSS/JM/D CANVAS FORMATTING 03123/12 Cil/ PJC SET COL MILLING GUIDE 04102112 PBSIPJC CEMENT 04120112' CS1 PJC P8A1 PERFORATE (04105-20112) PRUDHOE BAY UNTT WELL:. SD311116 PERMIT No_ 1690140 AR Na: 50-029-20011-00 SEC 31, T11 N, R16E 1101' FNL 81742' FH_ BP ExplGrafian (Alaska) • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, April 02, 2013 2:46 PM To: Worthington, Aras J' Cc: Spence, Clint J; Barnes, Thomas (NORTHERN SOLUTIONS LLC) Subject: RE: Sag Delta 31 -11 -16 (PTD 169 -014) Aras, The 31' ft surface cement plug in the OA will be acceptable. There.are seVeYal other cement barriers in the OA due to the multiple perforations and cement squeezes done during last year's wellwork. Guy Schwartz Senior Petroleum Engineer AOGCC WANED � Q 20� 907- 444 -3433 cell 907-7934226 office From: Worthington, Aras J [mailto:Aras.Worthington @bp.com] Sent: Tuesday, April 02, 2013 12:54 PM To: Schwartz, Guy L (DOA) Cc: Spence, Clint J; Barnes, Thomas (NORTHERN SOLUTIONS LLC) Subject: RE: Sag Delta 31 -11 -16 (PTD 169 -014) Mr. Schwartz, We've bled down the OA of Sag Delta successfully on this season's ice road campaign and have excavated and made our cut across all of the casings 3' below Tundra level. We have not been able to acquire a sample of the OA cement and have run a 3 /" pipe down the OA and tugged @ - 31'. We are currently circulating the diesel out of the OA and replacing with freshwater and propose to circulate our environmental cement plug into the OA from 31' to surface. Please advise if this is acceptable for the environmental plug on the OA. Aras Worthington Wells Intervention Engineer BP Alaska Inc Office: (907) 564 -4102 Cell: (907) 440 -7692 From: Worthington, Aras J Sent: Thursday, April 19, 2012 10:56 AM To: Schwartz, Guy L (DOA) Cc: Spence, Clint J Subject: RE: Sag Delta 31 -11 -16 (PTD 169 -014) Guy, When we cut off the casings we'll make every attempt to get a sample of the material in the OA to verify and get back with you 1 • • Thanks, Aras Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 From: Schwartz, Guy L (DOA) [ €na ltc:quv.sc hwartz 6 alask ,.. ov] Sent: Thursday, April 19, 2012 10:46 AM To: Worthington, Aras J Cc: Spence, Clint J Subject: RE: Sag Delta 31 -11 -16 (PTD 169 -014) Aras, As we discussed last night it does appear there is something more than just mud in the OA annulus. The proposal to fill the annulus (9 5/8" x 13 3/8" ) with cement from surface after the wellhead is removed and casing cut is approved. Keep me posted on what you find. It will be interesting to see a sample of what is actually in that annulus Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Worthington, Aras J [maiito:Aras.Worthingtor bp.coni] Sent: Thursday, April 19, 2012 9:20 AM To: Schwartz, Guy L (DOA) Cc: Spence, Clint J Subject: RE: Sag Delta 31 -11 -16 Guy, We punched holes in the 9 -5/8" casing @ 470' —478' MD but, as with the holes at 1500' MD and 1000' MD, could not establish free circulation between the 9 -5/8" casing and the OA (13 -3/8" x 9 -5/8" casing). Subsequently, in a review of my scant well records I found that one of the few line items describing the original 2 stage cement job on the 9 -5/8" casing (ca. 1969) read: "1100 sacks Class G with 10% Gel ". If "Gel" was bentonite, then the addition of 10% bentonite to the Class G cement would have effectively doubled the yield of class G from 1.15 Cu.ft. /Sack to 2.08 Cu. Ft/Sack. Unfortunately I missed picking up on this peculiarity of the significance of the 10% gel addition in my initial research of the well. With this revised cement yield, the 2 stage cement job, pumped through the stage tool @ 5500' MD would have been enough cement, even with 30% washout in the openhole section, to put cement all the way to surface in the OA (and then some). Unfortunately I do not have any records that verify cement returns from the OA, but the volume of cement would have been enough to do so with "10% gel" if indeed that gel were bentonite. Given our experience not being able to circulate at anything but extremely minimal rates between the 9 -5/8" casing and the OA with holes at 1500', 1000', and finally at 500' (and with many days of circulating hot water down the CT and up the 9 -5/8" casing) and the fact that 10% gel additive would have been enough cement to fill the entire OA, we feel we have ample evidence that the OA was fully cemented. We successfully pressure tested the OA to 1500 psi and then nippled down the OA valve. A plumb -bob stopped at 12.5' below the annular valve. 2 • Our proposal, as previously discussed and approved via phone call, is to lay in a cement plug from the TOC in the 9 -5/8" casing @ 920' MD to surface (this was accomplished last night). We will then PT that cement plug and then cut off all the casings and do a top -job on the OA to fill it completely with cement (or as deep as we can get with line- pipe). Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 CeII: (907) 440 -7692 From: Worthington, Aras J Sent: Monday, April 16, 2012 5:22 PM To: 'Schwartz, Guy L (DOA)' Cc: Cismoski, Doug A Subject: RE: Sag Delta 31 -11-16 Guy, As discussed via phone, we have been unsuccessful in establishing free circulation with the holes punched at 1000' MD. After two cement squeezes we got those perforations squeezed -off. We seek approval for the following plan forward: Punch holes in the 9 -5/8" casing at -500' MD just above the bridge plug that we milled a pilot hole through and establish circulation between the 9 -5/8" and 9 -5/8" x 13 -3/8" annulus and pump cement surface -to- surface via the holes at 500' MD (Arcticset 1 or the approved Class G blend). Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 CeII: (907) 440 -7692 From: Worthington, Aras 3 Sent: Sunday, April 08, 2012 9:44 AM To: Schwartz, Guy L (DOA) Subject: Sag Delta 31 -11 -16 Guy, As we discussed via phone yesterday, after over two days of working at it we have been unsuccessful in circulating out the 13 -3/8" x 9 -5/8" annulus with the perforations shot at 1500' MD. Our plan is to squeeze off the perforations © 1500' MD by laying in cement with CT from the current top of cement 2040' MD to -1100' MD with about 70 bbls of cement (either Arcticset I or the approved Class G blend). After tagging that cement top we plan to shoot perforations @ -1000' MD and attempt to circulate out the OA from that point to surface, then continue on with the job as planned by circulating cement from surface -to- surface down the 9 -5/8" casing, through the perforations @ -1000' MD and up the 13 -3/8" x 9 -5/8" annulus (Arcticset I or the approved Class G blend). Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 CeII: (907) 440 -7692 3 • • McMains, Stephen E (DOA) From: Lastufka, Joseph N (Northern Solutions) [Joseph.Lastufka @bp.com] Sent: Monday, June 18, 2012 3:42 PM To: McMains, Stephen E (DOA) Subject: 10 -407 Corrections X7 H Steve, I've been made aware of 2 corrections on 10 -407's that could use hand corrections... SD311116 — Surface X coordinate should be 726671 not 762671. F -08B — Total Depth coordinate should be 5970147 not 647174. Please let me know if you have any questions. Thanks!! Joe RBDMS JUN 192012 ,,. JU � �� 1 t STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned Suspended 1 b. Well Class: 20AAC 25.105 2OAAC 25.110 ❑ Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 5/14/2012 169 - 014 311 - 380 3. Address: 6. Date Spudded: 13. API Number: 1 P.O. Box 196612, Anchorage, Alaska 99519 - 6612 3/7/1969 50 029 - 20011 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 4/22/1969 SD311116 1102' FNL, 1743' FEL, Sec. 31, T11 N, R16E, UM 8. KB (ft above MSL): 27.40' 15. Field / Pool(s): Top of Productive Horizon: N/A GL (ft above MSL): Sag Delta Field / Wildcat Pool Total Depth: 9. Plug Back Depth (MD +TVD): 1102' FNL, 1743' FEL, Sec. 31, T11N, R16E, UM Surface Surface 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 762671 y 5951174 Zone ASP4 9094' 9094' ADL 028343 TPI: x- y- Zone- 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 726671 y 5951174 Zone- ASP4 None 18. Directional Survey: 0 Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/ VD: DIL, Sonic / GR N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM ToP I BOTTOM SIZE CEMENTING RECORD PULLED 30" 94# H -40 Surface 82' Surface 82' 36" 210 sx Fondu FIv Ash 13 -3/8" 61# J -55 Surface 3173' Surface 3173' 17 -1/2" 1650 sx Class 'G'. 825 sx Class 'G' 9 -5/8" 47# N -80 Surface 9088' Surface 9088' 12 -1/4" 870 sx Class 'G'. 1100 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): None MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. RE.c t \� �� DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED G Y 2040' 300 Bbls Class 'G' JUN U 1 2012 -1500' - Surface 70 Bbls AS II, 106.7 Bbls Cement, 71.9 Bbls AS I 27. AOGGC PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes 0 No Sidewall Core(s) Acquired? ❑ Yes No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None , . JUL 0 9 22 1J1 RBDMS JUN 01 20 � VI 4 qj, Form 10-407 Revised 12/2009 ONTINUED ON REVERSE o pC 4 �0 Original OnIJ'.1' •7 29. GEOLOGIC MARKERS (List all formations andkers • encountered): 30. • FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes IN No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Top Schrader 6778' 6778' None Top HRZ 8674' 8674' Bottom HRZ 8853' 8853' Top Sadlerochit 8875' 8875' Formation at Total Depth (Name): 31. List of Attachments: Summary Pre -Rig Work, Well Schematic Diagram 32. I hereby certify that t - • . • oing i tr - - • 4; • r ect to the best of my knowledge. 5/9 /12 Signed: Joe Lastufk: ` it Title: Drilli Technologist Date: SD311116 169 -014 311 -380 Prepared By Name/Number. Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Aras Worthington, 564 -4102 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for 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 and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 Submit Original Only 0 • Page 1 of 1 Lastufka, Joseph N (Northern Solutions) From: Worthington, Aras J Sent: Tuesday, May 22, 2012 2:36 PM To: Lastufka, Joseph N (Northern Solutions) Subject: Sag Delta Suspended well status verbiage Plug and Abandon operations commenced on Sag Delta 31 -11 -16 in February of 2012. In the course of the abandonment a cement plug was laid in the 9 -5/8" casing from 6520' MD to 2040' MD. This plug was tagged and pressure tested to 2500 psi and AOGCC Inspector witnessed on 4/5/2012. Subsequently the 9 -5/8" casing was perforated at 1500' MD, 1000' MD, and finally 500' MD in an attempt to circulate out the OA (13 -3/8" x 9 -5/8" annulus) and fill it with cement. Full circulation was never achieved and the evidence suggested that the OA was cemented fully since the original 2 stage cement job on the OA included enough cement volume to fill the OA with cement to surface and no circulation was ever achieved. The 9 -5/8" casino was s•ueezed several times from 1500' MD and u• and filled with cement from 1500' MD surface in several jobs. This cement plug was also tagged @ 23.5' MD and pressure tested to 2300 psi successfully. Before final P &A operations (excavating, cutting off the casings 3' below tundra, etc.) the OA showed some pressurization. Bleeding of the OA commenced and although very little volume was ever recovered (ca. 5 -100m1 of fluid per hour) some residual pressure remained (1 -2 psi when shut in for -6 hours). Final P &A operations had not been completed before the ice road season closed, so the well was left with the ✓ wellhead and tree intact for P &A operations to commence the following year. Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 Z bt 3 Fv/t.`"""1 `A G. 5/22/2012 • • SD311116, Well History Date Summary 02/24/12 Removed old 2 1/16 OA blind flange. Installed new 2 1/16 CIW OA valve w/ inergul. VR plug still set. Removed old 2 1/16 IA blinds. Installed new 2 1/16 CIW IA valve w/ inergul on existing IA valve on opposing side installed new 2 1/16 blind flange. 02/26/12 Prep WH for P &A: Torqued All new connections on IA/OA to 243 ft lbs. Pressure tested new IA blind against gate low 350 psi 5 min (PASS) then high 4000 psi 5 min (PASS). Pressure tested (opposing side) New valve against gate of existing valve low 350 psi 5 min (PASS) then high 4000 psi 5 min (PASS). Pressure tested OA valve against VR plug low 350 psi 5 min (PASS) then high 1000 psi 5 min (PASS). Removed inergul rigged up VR lubricator pressure tested lubricator /valve low 350 psi 5 min (PASS) then high 2000 psi 5 min (PASS) removed 2" VR plug. rigged down lubricator, reinstalled inergul and pressure tested low 350 psi 5 min (PASS) then high 3000 psi 5 min (PASS). 02/27/12 I/O = 1/1. Temp = SI. MIT 9 5/8" casing to 3500 psi & MIT -OA to 500 psi. No AL. IA & OA FL near surface. Pressured IAP to 500 psi w/ 68 gallons of neat. OAP tracked IAP. Assisted Cameron with leak path eval. Evacuated IA w/ N2 & bled WHPs to 0 psi. Installed heat to thaw overnight. Job incomplete. Final WHPs = 0/0. IA, OA = OTG. 2000. 02/27/12 T /I /O= na/0 /0, Temp =SI. PPPOT-IC (FAIL), for P &A. PPPOT -IC: Stung into 1/2" test port (0 psi). Single port, unable to pump through void. Unable to achieve 2500 psi test pressure. DHD pressured IA to 500 psi, test void tracking with IAP, OAP slowly increasing. DHD bled IAP /OAP to 0 psi. 03/02/12 T /I /O= na/0 /0, Temp =SI. PPPOT-IC (N /A), re- energize secondary seal. Stung into test port (0 psi). Verified 0 psi in IA and OA (bled hyd fluid from OA). Removed 1" PKG plug, internal plug, bled approx 1/2 gal of clear fluid (methanol ?). RU to PKG port and re- energized secondary Y seal. Pumped 5 1/2 J sticks of plastic. Unable to catch pressure. Did not PPPOT -IC. 03/06/12 T /I /O= na/0 /0, Temp =SI. LPE (IA x OA). Verified test port pressure (0 psi.). DHD pressured IAP to 3500 psi. Test void tracked with IAP to 3500 psi. DHD bled IAP to 0 psi. test void pressure bled to 0 psi. DHD pressured OAP to 500 psi. monitored for 30 min. Test void pressure did not track with OAP. DHD bled OAP to 0 psi. Verified test port pressure (0 psi.) RD test manifold. Appears primary seal is holding, secondary seal is bad. 03/06/12 I/O = 1/1. Temp = SI. MIT 9 5/8" casing PASSED to 3500 psi & MIT- 13 3/8" casing FAILED to 500 psi. No AL. IA & OA FL @ surface. Pressured 9 5/8" casing to 3500 psi with 38 gallons of methanol. 9 5/8" casing lost 161 psi in the 1st 15 mins and 64 psi in the 2nd 15 mins for a total loss of 225 psi during the 30 min test. Bled casing back to 3 psi (37 gals). 13 3/8 failed two similar tests. Pressured 13 3/8" casing to 583 psi with 8 gals. 13 3/8 casing lost 117 psi in the 1st 15 mins and 31 psi in the 2nd 15 mins for a total loss of 148 psi during the 30 min test. Bled 13 3/8 casing to 0 psi. (1 gal) Final WHPs = 0/0. 9 5/8 & 13 3/8 OTG. 15:00 03/12/12 T /I /O= 0/0/0 (Remove old THA x tree cap and install new THA x Dry hole tree) Well site leader verified the two barriers as no perforated tubing as well as shallow CIBP @ 500' Barriers which were tested to 3500 psi by DHD on 3- 06 -12. Held open bleed on Tree cap as well as I/A valves and O/A valves to verify 0 pressure build for 5 min (PASS). Removed THA x Tree cap and installed New THA x Dry hole tree. Torqued nuts on THA x tubing spool to spec (1890 ft Ibs). Pressure tested THA and Dry hole tree to 2400 psi for 5 min (PASS) lost 40 psi. Could not achieve 3500 psi test due to mechanical issues. Slickline will apply 3500 psi test for well site leader. Page 1 of 8 • • SD311116, Well History Date Summary 03/12/12 T /I /O= 0/0/0. Replaced gauge on I/A from 3000 psi to 5000 psi. Opened all valves and pressure tested thru tree cap. At 3200 psi noticed both inner I/A valves leaking thru stems. Also noticed fluid entering cellar box. Shut down pressure test and bled all pressure off wellhead. Notified CH2M dispatch (5104) to report fluid release. All annulii and tree valves shut before leaving location. 03/13/12 T /I /O= 0/0/0 Conducted PJSM; Well site leader verified two barriers, no perforated tubing as well as shallow CIBP @ 500', barriers tested to 3500 psi by DHD on 3- 06 -12.; Held open bleed on Tree cap as well as I/A & O/A valves to verify 0 psi build for 5 min (PASS).; Removed I/A valves on both sides & installed new CIW 2- 1/16" valves, piggy backing left side of I /A. 03/14/12 T /I /O= 0/0/0; Conduct PJSM; Shell test tree against down -hole barrier to 300 and 3500 psi for 5 min. (passed & charted) 03/15/12 TAG CIBP @ 486' SLM W/ 3.80" LIB, NO IMPRESSION. BAIL @ CIBP W /3.0" PUMP BAILER, RECOVER FLUID /GREASE. RAN PDS EXT 40 ARM CALIPER FROM 480' SLM TO SURFACE GOOD DATA, NO INDICATION OF COLLAPSED TUBING. 03/18/12 Slickline, E -Line And Ct Tags [TAG] - TAG ICE W/ 3.80" LIB @ 486' SLM. TWO RUNS W/ 3.0" PUMP BAILER, BAILING FROM 486' TO 487' SLM, RECOVERED ICE & MUD. BAIL W/ 3.50" PUMP BAILER @ 487' SLM, RECOVER 1/4 CUP ICE & MUD. TAG TOP OF CIBP W/ 3.80" LIB @ 487' SLM. STAB 8.5 CT MILLING GUIDE. RIH W/ 4.5" GS, 8.5" X 49" CT MILLING GUIDE. 03/20/12 REMOVE 4.5 TREE T O RIH W/ 8.5" COIL TUBING MILLING GUIDE , SD @ 484' SLM, SHEAR GS, POOH. GOOD SET, PT CAP, LEFT IA GATE CLOSED, MASTER & SWAB SHUT. R/D. 03/20/12 T /1 /O= 0/0/0 (Assist Slickline). Slickline held an open bleed on tree cap, I/A valves and O/A to verify 0 psi build up (5) min. (PASS). Cameron verified absence of fluid in dry hole tree to tubing head adapter pre removal. Nippled down Tubing spool by THA. Slickline rigged up equipment on tool string . Cameron nippled up and torqued dry hole /THA to spec 2583 FT.LBS and verified 3500 (30) min psi pressure test (preformed by Slickline). 03/23/12 CT -8 1 3/4" Scope of Work: P &A. Continue RU. Tree cap pressure test. BOP RU. Reviewing CT pump trailer connections, orienting for the job. Clarified the definitions of IA = 9 -5/8" even though there is not an IA present. Reviewed 1502 hardlines to mitigate risks and identify buffer zones and restraint requirements. Night cap installed on BOPs. Change out studs in choke trlr, CH2 moved iron RU to comply w /job requirements. Unit on safety stand down for mismatched 1502 fittings and review of buffer zones. 03/28/12 Slickline, E -Line And Ct Tags [TAG] - CTU 8, 1.75" COIL. JOB SCOPE: P AND A WELL WITH CEMENT. SAFETY STAND DOWN ENDED AT 1200 HRS. BOP FUNCTION TEST. PU INJECTOR. HAD ENGINE ISSUES SWAPPING FROM TRA. 03/28/12 CTU 8, 1.75" coil. Job Scope: P and A well with cement. Safety stand down ended at 1200 hrs. BOP function test. PU injector. Had engine issues swapping from tractor to pump, 1 hr NPT. Performed weekly BOPE pressure and function testing. Good tests. 03/29/12 Slickline, E -Line And Ct Tags [TAG] - C CTU 8, 1.75" COIL. JOB SCOPE: P AND A WELL WITH CEMENT. M/U 2.40" MILLING BHA. PT LUBRICATOR. RIH. SET DOWN AT 44'. CIRC HOT KCL. BHA PLUGGED UP AT 33 BBL KCL. Page 2 of 8 • • SD311116, Well History Date Summary 03/29/12 . CTU 8, 1.75" coil. Job Scope: P and A well with cement. M/U 2.40" milling BHA. PT Lubricator. RIH. Set down at 44'. Circ hot KCL. BHA plugged up at 33 bbl KCL. Lay out BHA. Circ coil back to 60/40 Meth. Insure all surface lines FP'd, pop off, MU nozzle assembly. 9.875' TOL, Fluid pack w /meth, PT 250/4000, good test. Negative test on DFC's 1500 psi, good. Equalize & open to well. RIH, Clean to 496' CTD tag, POOH. At surface, Pop off, LD nozzle assembly. M/U Baker CTC and pull test with 20 K. M/U Baker milling BHA. PT tools down to motor with 3500 psi. Good test. M/U motor and 2.40" milling BHA. BHA OAL = 35.5'. Stab on, PT down back side only to keep centralizer closed. Low /High = 300/3576 psi. Pass. Open well, RIH. Tagged at 49'. Retagged. RIH at 40 fpm, bounced thru. Tagged again at 492'. Swapped to GeoVis, full CT volume, begin RIH and milling. Started getting significant motor work -500'. Time mill at 1 fph, 1.2 bpm, Millled thru plug from 500 - 502.5'. Well was dead below plug. Ream plug 6 times up /down. Dry tag clean. POH. Circ coil to meth. Lay out milling BHA. Mill gauged at 2.39 / 2.38" Go- Nogo. M/U cold roll 1.9" CTC. 03/30/12 Slickline, E -Line And Ct Tags [TAG] - CTU 8, 1.75" COIL, JOB SCOPE: P AND A WELL WITH CEMENT. M/U SJN BHA. RIH. CIRC HOT KCL TO WARM UP COLD WELL. RIH AT 40 FPM, CIRC 3.0 BPM. RIH AT 6000' AT 0600'. 03/30/12 CTU 8, 1.75" coil, Job Scope: P and A well with cement. M/U SJN BHA. RIH. Circ hot KCL to warm up cold well. RIH at 40 fpm, circ 3.0 bpm. RIH at 6000' at 0600'. AGOCC gave approval for TD /Pluq back taq & MIT of casing not to be witnessed. Ta ed hard @ 6575', PU flag coil, circ gel marker sweep around. e ac 40 bbl's short of calc vol. Call in Vols for cement plug job. POOH, FP 800' casing & CT. Pressure test casing at 2550 psi for 30 min. Good casing pressure test. Change out packoff and check chains while preparing for 300 bbl cement plug job. Held Spill Drill. 03/31/12 Slickline, E -Line And Ct Tags [TAG] - . CTU 8, 1.75" COIL, JOB SCOPE: P AND A WELL WITH CEMENT. M/U SLICK CEMENT NOZZLE BHA. PT LUBRICATOR. RIG UP CEMENTING EQUIPMENT FOR LARGE 300 BBL CEMENT PLUG JOB. 03/31/12 CTU 8, 1.75" coil, Job Scope: P and A well with cement. M/U slick cement nozzle BHA. PT lubricator. Rig up cementing Equipment for large 300 bbl cement plug job. Wait on cement UCA testing. RIH to coil flag at 6519'. Circ hot KCI. PT cement line. Stg 10 bbl fresh water. Stg 300 bbl 15.8 ppg G cement. 150 bbl cement pumped by midnight. 1.0 bpm at 3800 psi. Lay in cement 1 for 1 at 15 fpm. Nozzle at 4850'. 04/01/12 Slickline, E -Line And Ct Tags [TAG] - CTU 8, 1.75" COIL, JOB SCOPE: P AND A WELL WITH CEMENT. LAY IN 15.8 PPG CEMENT 1 FOR 1 IN 9 -5/8" CASING UP TO 1990'. PULL TO SAFETY AT 1500'. CIRC 50 BBL 2# BIO. 04/01/12 CTU 8, 1.75" coil, Job Scope: P and A well with cement. Lay in 15.8 ppg cement 1 for 1 in 9 -5/8" casing up to 1990'. Pull to safety at 1500'. Circ 50 bbl 2# Bio to clean plug area at 500'. RIH and freeze protect casing to surface with 60/40 meth. POH with swab checks at 100'. Close swab and master valves. SIWHP = 0 psi. Lay out BHA. Install and PT swab cap. Finish rig down. Well secure. RDMO. 04/05/12 CTU 8 w/ 1.75" CT. Scope; P &A. Perform weekly BOP test. MU JSN BHA. RIH with 2.25" JSN to tag TOC. TOC @ 2040'. POOH. PT to 2500 psi with State Inspector on location. Good test. RIH with perforating BHA. Fired guns at 1500'. POOH. Saw pressure communication between 9 -5/8" and 13 -3/8 ". RIH BHA - ctc 1.9 "x.083', checks 2 "x1.083', stinger 2 "x3.5', stinger 2 "x3.5', X -over 2.15 "x.458', JSN 2.25 "x.583'. OAL- 9.208. to 1500'. attempted to circ down coil with nreturns from 13 3/8 ", saw pressure climb to 1600 psi @ .8 bpm. well appeared to be taking fluid. stopped @ 8 bbls away. pressures fell back to 740 psi and held. Bleed pressure back to zero. closed in 13 3/8 and come online down coil taking returns from 9 5/8" to warm up well. Page 3 of 8 • • SD311116, Well History Date Summary 04/06/12 CTU 8 w/ 1.75" CT. Scope; P &A. Perform weekly BOP test. MU JSN BHA. RIH with 2.25" JSN to tag TOC. TOC @ 2040'. POOH. PT to 2500 psi with State Inspector on location. Good test. RIH with perforating BHA. Fired guns at 1500'. POOH. Saw pressure communication between 9 -5/8" and 13 -3/8 ". RIH BHA - ctc 1.9 "x.083', checks 2 "x1.083', stinger 2 "x3.5', stinger 2 "x3.5', X -over 2.15 "x.458', JSN 2.25 "x.583'. OAL- 9.208. to 1500'. attempted to circ down coil with nreturns from 13 3/8 ", saw pressure climb to 1600 psi @ .8 bpm. well appeared to be taking fluid. stopped @ 8 bbls away. pressures fell back to 740 psi and held. Bleed pressure back to zero. closed in 13 3/8 and come online down coil taking returns from 9 5/8" to warm up well. 04/06/12 CTU 8 1/ 1.75" CT. Scope; P &A. RIH with JSN BHA: ctc 1.9 "x.083', checks 2 "x1.083', stinger 2 "x3.5', stinger 2 "x3.5', X -over 2.15 "x.458', JSN 2.25 "x.583'. (OAL- 9.208) @ 1500' circulating hot freshwater taking returns from 9 5/8 ". #1 - Swapped returns to 13 3/8" and attempt to circulate failed. Continue to circ hot water from 9 5/8 ". #2 - Swapped returns to 13 3/8" and attempt to circulate failed. Continue to circ hot water from 9 5/8 ". #3 - Swapped returns to 13 3/8" and attempt to circulate failed. Continue to circ hot water from 9 5/8 ". Unproperly bolted flange below BOP was found while walk around (one of bolts was short). POOH to surface and changed the bolt. Hot water plant shut -down for an hour. Lined up with McOH to IA and pressure up to 1000psi, pressure bled down to 100psi. RU LRS and started to pump hot diesel down to IA. Low sqeeze rates obtained. POOH to surface to check surface lines flowpath - p -sub had signs of freezing. Run back in hole to circulate hot water. 04/07/12 Slickline, E -Line And Ct Tags [TAG] - CONTINUED HOT WATER CIRCULATION DOWN CT TAKING RETURNS FROM CTX9 5/81N ANNULUS TO OT. RIGGED UP LRS TO PUMP HOT DIESEL DOWN 9 5/8X13 3/81N ANNULUS AT 0.1BPM RAT. 04/07/12 Pump 14.9 bbls 130 "f diesel into OA. Continued hot water circulation down CT taking returns from CTx9 5 /8in annulus to OT. Rigged up LRS to pump hot diesel down 9 5/8x13 3 /8in annulus at 0.1 bpm rate, annulus pressure was 1000psi. Poor infectivity obtained. Switched back to hot water and continued pumping down CT taking returns from CTx9 5 /8in annulus. Tried to inject hot water to 9 5/8x13 3 /8in annulus through perforations while pumping down CT. No response on the annulus gauge, no communication observed. Continued circulation hot water down CT. Spill response drill. Pumped hot diesel down annulus taking returns up casing at 0.2 bpm. Pumped 16 bbl warm diesel down annulus. Stop to heat more diesel. Unable to pump down ann again. Continue circulation hot water . 04/08/12 Assist CTU w /P &A well (Artic pack flush) Pumped 4.3 bbls 120" diesel into well ( total for job 19.7 bbls) . FWHP's =CTU /0 CTU still on well & in control of VLVs on departure. Continued pumping hot water down CT getting returnes from 9 5/8" casing. Freeze protected CT and tried to inject hot diesel down IA. IA pressure 2500psi, injection rate -0.1 bbl, totally injected 1.2bb1. Switch back to pump hot water down CT getting returnes from 9 5/8" casing. Circulated 173bb1 of 164degF water. Started second attempt to inject hot diesel. Pumped 1.5 bbls in IA. Rigged up LRS so that they can pump down IA while we circ in the 9 -5/8. POOH and FP. 21.5 bbls total diesel pumped into annulus over the last 2 days. RDMO LRS. POOH. Injector maintenance. Order cement. MU Cementing BHA and start RU Cementing surface lines. 04/09/12 RU and tested cementing equipment. Waited for cement preparation. Cement lab tests came in good. Cementers on location. RIH. PJSM. Pumped 70bbls of 15.72ppg AS2 cement. Applied 500psi pressure for 15min. Totally squeezed 1.2bb1. Well held pressure. Calculated TOC is 1100.2ft. POOH and meanwhile freeze protected well and CT. POOH and LD BHA. Install night cap and wait on cement. Page 4 of 8 • • SD311116, Well History Date Summary 04/10/12 Waited on cement. RIH and tag TOC @ 1094'. POOH. MU perforation BHA, RIH and perforated at 1000'- 980'. POOH. MU cementing nozzle BHA. RIH. Circulated hot water down coil and up the 9 -5/8" casing. Started to pump hot diesel down 9 5/8 "x13 3/8" annulus at minimum rate with 2500psi pressure simultaneously pumping hot water down CT taking returnes from 9 5/8" casing. Totally pumped 4.4bbls of diesel during the day, totally pumped during the job 25.9bbls. 04/11/12 Circulated hot water down CT up 9 5/8" casing while injecting hot diesel down 9 5/8 "x13 3/8" annulus with 2400psi. Closed 9 5/8" casing and pressured up 9 5/8 "x13 3/8" annulus - see pressure response in 9 5/8" casing - confirming open perforations. Fire Drill. Continued pumping diesel down annulus and circulating hot water down coil and up 9 -5/8" casing. Pumped hot diesel down coil and up 9 -5/8 ". Diesel to tanks. Shut in choke and lined up to take returns from 9 5/8 "x13 3/8" annulus, no returns. Loss of 1 bpm at 1045psi WHP. Pressured up 9 5/8" casing and monitored positive response on annulus gage, open annulus to take returns and pumped at 0.5bpm with 1000psi - no returns. Made another attempt at 1300psi 0.7bpm - still no returns, losses - 2.6bbls. Displaced diesel in the well with hot water and continued circulation hot water down CT taking returns from 9 5/8" casing and pumping hot diesel down 9 5/8 "x13 3/8" annulus. Pump rate to annulus 0.5gpm with 2400psi pressure. Total diesel pumped down 9 5/8 "x13 3/8" annulus after second perforation is 17bbls, and since the job started is 38.5bbls. 04/12/12 Circulated hot water down CT up 9 5/8" casing while injecting hot diesel down 9 5/8 "x13 3/8" annulus, injection rate -0.5 -1 gpm at 2400psi. Max achieved rate - 3.6gpm. Total volume of diesel injected down the annulus after second perforation - -41 bbl and for whole job - 62.5bbls. Took sample from return tank. Stopped pumping and injecting to the annulus, FP and POOH for weekly BOP test. 04/13/12 Did weekly BOP test. MU 1.75" JSN BHA and RIH. Started circulation down CT up 9 5/8" casing while injecting hot diesel down 9 5/8 "x13 3/8" annulus, injection rate -0.7gpm at 2400psi. Total diesel pumped down annulus is 61 bbls as of 7 AM. LRS stopped pumping diesel down 9 5/8 "x13 -3/8" annulus. Closed choke and pressured up WH to 1250 psi. This resulted in 2 bpm losses to the formation with no pressure communication to the annulus. POOH and FP coil and well. Total bbls of diesel pumped down the 9 5/8 "x13 -3/8" annulus - 64 bbls. PU and MU 1.75" JSN cementing BHA. Waited for cement equipment and cement lab test. 04/14/12 Waited for cement equipment and cement lab test. RU cement lines and PT. Pop on and PT lubricator and RIH, tagged TOC at 1095.q'. pull out to 950' and flag pipe. Started hot water circulatin. Pumped 69.5 bbls of cement, 58 bbls behind pipe. Layed in cement to 936'. Dressed off cement to 950'. Cleaned out well with biozan. FP well with diesel to 800'. Rigged up surface lines, circulation loop and PT. 04/15/12 Pressure tested cement plug monitoring annulus pressure. Pressure dropped from 1500 to 1200psi while pumping with 0.5bpm. Increased pump rate to 1 bpm. Pressure increased to 2100 dropped to 2000psi and stabilized. Injected 13bbls of diesel at 1 bpm with 2000psi. SD pumps and monitored for 30min - WHP bled down to -- 750psi and stabilized. Cement plug PT failed. Annulus pressure during whole test was remaining -Opsi. MU JSN BHA, RIH jetted and tagged at 960ft hard cement top. Injected another 2.8bbls of diesel at lbpm with 1400psi WHP. Annulus pressure remained Opsi. Trapped pressure in the well and monitored for 30 minutes - bled down to - 750psi and stabilized. Opened choke and bled down well pressure to Opsi, in 40 minutes pressure increased to 270psi. Bled down well pressure and continue monitor. Waited for cement and cement equipment. PT cement rigup. Circ out Diesel. Pump cement. 37.2 bbls of cement behind pipe. Clean out to 920' with biozan. Circ out well pulling at 80 %. FP with diesel down to 800'. POOH and wait on cement. Page 5 of 8 • • SD311116, Well History Date Summary 04/16/12 Pressure tested cement to 2500psi - good test. MU 1.56" perforation BHA and RIH. Perforated at 920.7ft. Perforated interval 920- 910ft. Good WHP and weight indication. No pressure response on the annulus. POOH. Night cap installed. RIH. Circ out diesel and warm well. Pump 9.8 ppg brine down coil and take brine returns to a 200 bbl recycle tank. Confirmed no communication between 9 -5/8 and 13 -3/8. POH. RIH, circing well. Rearranged surface piping to be able to recirculate directly through CTU. Pressured up the well to 1200psi to check communication with annulus - no communication. 04/17/12 MU 3.5" JSN BHA RIH and tagged bridge plug at 497.9ft. Flagged at 458.8ft. MU Perforation BHA, RIH and perforated. Perforated interval - 470 -478ft. Good response on weight and WHP sensors. No indication on the annulus gage. Pressured up casing to 1500psi. Lost 1000psi per 5 minutes. No pressure response on the annulus gage. POOH. Installed night cap. MU JSN BHA run below perfs and pumped hot brine, pressured up 9 5/8" casing - no pressure response on the annulus gage. Pressured up to 2500psi and bled the annulus few times. After researches in town was founded that 9 5/8 "x13 3/8" annulus was cemented to surface in 1969. Pressure tested the annulus to 1500psi - good test. Bled and monitored pressure in the annulus for 30min - no pressure build -up. Well support team arrived to location to ND the annulus valve. Decided to RD scaffolding. FP part of coil and WH, installed night cap, waited on scaffolding crew. 04/18/12 Waited for scaffolding crew. Looked for cement top in the annulus. State approved cementing up 9 -q/:t Planned cement job. MU Cementing BHA, RIH and tagged TOC at 951.7ft. Circulated out 9.8ppg brine from 95/8" casing. Cementers rigged up and started pressure test. $ 4732. bl5 /f . 04/19/12 RU and PT Cementing surface equipment. Laid 71.9bbls of AS -1 cement in 9 5/8" casing, 951' to surface. Jet surface equipment, RD, MOL to 09 -26. 04/21/12 T /I /0= VacNacNac. Temp = SI. CMIT -TxIA PASSED to 2300 psi. (P & A). T & IA FL @ 17' (1.21 bbl) Tagged Cement @ 23'3 ". LP & HP test passed. Pressured T & IA from Vac to 2300 psi w/55 gallons of diesel. T & IA lost 202 psi during the 15 minute test. Bled TP & IAP from 2098 psi to 0 psi, used N2 to blow down tree, N2 into treecap taking returns from the IA w /20 gallons of diesel returned. Final WHP's = 0/0/0. 04/23/12 T /I /0 = 0/0/290. Evacuate fluid in tubing above cement. (Plug & Abandon). Integals on IA & OA. Bled OAP to bucket from 290 psi 0 psi in 1 min (fluid, -1 quart). Evacuated Tubing to 22' 4" (TOC). OAP increased to 50 psi in -20 min. Bled OAP to 0 psi (fluid -1 cup). Monitor 30 min. OAP increased to 40 psi. Bled OAP to 0 psi (fluid, -1/2 cup). Final WHPs = 0/0/0 +. SV, SV = C. IA, OA = OTG. 12:50. 04/24/12 I /0= VAC /300. Temp= SI. Hold open bleed on OA (P &A). OA FL CO surface. Integrals installed on IA & OA. Bled OAP to 0+ psi in 1 min (1/4 gal of fluid). Held open bleed for 8.5 hrs to a bucket ( -2 gals. total fluid). OA consistently returned -1 quart of fluid per hour during bleed. Monitored for 45 min. OAP increased 2 psi. FWHPs= VAC /2. SV, SV = C. IA, OA = OTG. 16:30 04/25/12 I /0= VAC /300. Temp= SI. Hold open bleed on OA (P &A). OA FL @ surface. Integrals installed on IA & OA. Bled OAP to 0+ psi in 1 min (1/4 gal of fluid). Held open bleed for 8.5 hrs to a bucket (-2 gals. total fluid). OA consistently returned -1 quart of fluid per hour during bleed. Monitored for 45 min. OAP increased 2 psi. FWHPs= VAC /2. SV, SV = C. IA, OA = OTG. 16:30 Page 6 of 8 • SD311116, Well History Date Summary 04/26/12 I/O- VAC /570. Temp= SI. Hold open bleed on OA (P &A). OA FL @ surface. Integrals installed on IA & OA. OAP increased 568 psi overnight. Bled OAP to 0+ psi in 1 min (- 0.5 gal. of fluid; appears to be diesel). Held open bleed for 5.5 hrs to a bucket. (Returned additional 1.25 gals; appears to be diesel). Continued open bleed monitoring returns hourly. During the nine hour open bleed and monitoring period, rate of returns slowed from 615 ml (1.3 pints) per hour to 304 ml (0.64 pints) per hour. 04/27/12 Continued open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has decreased from 300 ml (0.63 pints) /hr to 87 ml (0.18 pints) /hr. Observed a couple of episodes of returns serging -1200+ ml /hr @ mid -day. 04/28/12 Continued open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has decreased from 90 ml (0.19 pints) /hr to 22 ml (0.04 pints) /hr. 04/29/12 Continued open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has decreased from 46 ml (0.097 pints) /hr to 20 ml (0.04 pints) /hr. 04/30/12 Continued open bleed on OA monitoring returns hourly. During a 12 hr open bleed and monitoring period, rate of returns has been steady @ 5 ml (0.01 pints) per hr, for 4/30/12. 05/01/12 Continued open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has increased from 14 ml (0.03 pints) /hr to 160 ml (0.32 pints) /hr, returns decreased to 82 ml (0.17 pints) /hr (after heater was installed). Put heater on WH @ 1400 hrs per Mel Iveson. 05/02/12 Continued open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has fluctuated (see log for details). Heater installed to heat SC. 05/03/12 Continued open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has fluctuated (see log for details). Heater installed to heat SC. 05/04/12 Continued open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has fluctuated (see log for details). Heater installed to heat SC, had cellar vacced out (thawed snow in cellar was keeping the heater from properly heating the SC). Final WHPs, I /O= Vac /0. IA &OA =OTG. NOVP. 09:25. 05/05/12 I/O = 2/0. Temp = SI. WHPs (P &A) post bleed. No change in OAP overnight. SV =C. IA, OA =OTG. NOVP. 05/06/12 I/O = 2/0. Temp = SI. WHPs (Post Bleed). Dry Hole Tree. No change on WHPs over nite. SV #1, SV #2 = C. IA, OA = OTG. 0800 05/07/12 I/O =2/1. Temp =Sl. WHPs (pre -P &A). SV, MV =C. IA &OA =OTG. NOVP. 1033. 05/08/12 I/O = 2/5. Held open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has fluctuated (see log for details). Heater on WH for thermal. Page 7 of 8 • • SD311116, Well History Date Summary 05/09/12 Continued open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has fluctuated (see log for details). Heater installed to heat SC. Final WHPs I /0= 4.5/0. 05/10/12 Continued open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has fluctuated (see log for details). Heater installed to heat SC. 05/11/12 Continued open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has fluctuated (see log for details). Heater installed to heat SC. 05/12/12 Open bleed continued from 5/11/12. Held open bleed for 9 hrs 10 min. Getting small returns checked hourly. SI bleed for 6 hrs 50 min. OAP increased 1 psi. Bled IAP to 0 psi -1/2 gal diesel recoved. Continue open bleed on OA. Heater installed to heat SC. 05/13/12 Continued open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has fluctuated (see log for details). Heater installed to heat SC. 05/14/12 I /0 =0 /0. Temp =S1. Continued open bleed on OA monitoring returns hourly. During a 24 hr open bleed and monitoring period, rate of returns has fluctuated (see log for details). Rigged down equipment and ,/ secured well. All valves SI upon departure. Page 8 of 8 • Sag Delta 31 -11 -16 S Permit No. 169 -0140 API No. 50- 029 -20011 Suspended Status 30" Conductor @ 82' MD Cemented w/ 210 sx Fondu/ /// Fly Ash 13 3/8" Stage Tool @ 631' MD Cement from —1500' MD to surface in 9 -5/8" and 13 -3/8" x 9 -5/8" annulus 13 3/8 ", 61 #, J -55 @ 3173' MD Cemented w/1650 sx Class G (primary) 825 sx glass G (stage #2) /� and top job w/ 50 sx Class G Cement plug laid in from 6520' MD to • j 2040' MD 9 5/8" Stage Tool @ 5500' MD j No Perforations Fresh Water Cement 10.0 ppg _m-- • Bridge Plug @ 8,875' MD Drilling Mud 9 5/8 ", 47 #, N -80 @ 9,088' MD Cemented w/ 870 sx Class G (1S stage) and 1100 sx class G w/ 10% gel (2 stage) • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, May 21, 2012 11:25 AM To: 'Worthington, Aras J' Subject: RE: Sag Delta Status Sundry # 311 -380 (PTD 169 -014) Aras, Thanks for update. I will pass this on to the Commissioners. Looks like final P &A will have to be next ice season , very odd to have that small fluid rate not go away. With cement to surface inside the 9 5/8" casing the well is plenty safe. Please submit a 10-407 with the normal reporting requirements and leave well status as suspended on the form. Guy Schwartz 3 Lri'L Senior Petroleum Engineer WOWED ` 2. AOGCC 793 -1226 (office) 444 -3433 (cell) From: Worthington, Aras J [mailto:Aras.Worthington @bp.com] Sent: Monday, May 21, 2012 11:01 AM To: Schwartz, Guy L (DOA) Subject: RE: Sag Delta Status Sundry # 311 -380 Guy, The bleed rate on Sag Delta OA fluctuated from 5m1 to 100 ml of diesel per hour over the last few days of bleeding (ending on 5/14/202). A shut in period lasting about 7 hours on 5/12/2006 yielded an OAP of 1 psi. Without time to finish bleeding operations and ensure 0 buildup of pressure before the ice road season was over, the decision was made to SI the well and resume operations next ice road season for final excavation, cutting -off of casings 3' below Tundra and welding on the marker plate. Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Ceti: (907) 440 -7692 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, May 17, 2012 5:11 PM To: Worthington, Aras J Subject: RE: Sag Delta Status Sundry # 311 -380 Aras, Probably need an email update and summary since last week. And to get verbal approval documented to move off the well without finishing the P & A . Thanks, 5/21/2012 Page2of2 Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Worthington, Aras J [mailto:Aras.Worthington @bp.com] Sent: Monday, May 07, 2012 3 :21 PM To: Schwartz, Guy L (DOA) Subject: Sag Delta Status Sundry # 311 -380 Guy, Over the weekend we removed heat from the wellhead and shut in the well. The OA stabilized at 2 psi of pressure. So we are back to bleeding on the OA until the pressure goes to 0 psi, or the ice road season is over, whichever comes first. Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 CeII: (907) 440 -7692 5/21/2012 Page 1 of 3 • • Schwartz, Guy L (DOA) From: Worthington, Aras J [Aras.Worthington @ bp.com] Sent: Thursday, April 19, 2012 10:56 AM To: Schwartz, Guy L (DOA) Cc: Spence, Clint J Subject: RE: Sag Delta 31 -11 -16 (PTD 169 -014) Guy, When we cut off the casings we'll make every attempt to get a sample of the material in the OA to verify and get back with you. Thanks, Aras 2 ■ 7 0, , , Aras Worthington i ° 1 . C Wells Intervention Engineer Me: BP Alaska Inc.� Office: (907) 564 -4102 Y / CeII: (907) 440 -7692 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Thursday, April 19, 2012 10:46 AM To: Worthington, Aras J Cc: Spence, Clint J Subject: RE: Sag Delta 31 -11 -16 (PTD 169 -014) Aras, As we discussed last night it does appear there is something more than just mud in the OA annulus. The proposal to fill the annulus (9 5/8" x 13 3/8" ) with cement from surface after the wellhead is removed and casing cut is approved. Keep me posted on what you find. It will be interesting to see a sample of what is actually in that annulus..... Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Worthington, Aras 3 [mailto:Aras.Worthington @bp.com] Sent: Thursday, April 19, 2012 9:20 AM To: Schwartz, Guy L (DOA) Cc: Spence, Clint J Subject: RE: Sag Delta 31 -11 -16 Guy, We punched holes in the 9 -5/8" casing @ 470' — 478' MD but, as with the holes at 1500' MD and 1000' MD, could not establish free circulation between the 9 -5/8" casing and the OA (13 -3/8" x 9 -5/8" casing). Subsequently, in a review of my scant well records I found that one of the few line items describing the original 2 stage cement job on the 9 -5/8" casing (ca. 1969) read: "1100 sacks Class G with 10% Gel ". If "Gel" was bentonite, then the addition of 10% bentonite to the Class G cement would have effectively 4/27/2012 • Page 2 of 3 • doubled the yield of class G from 1.15 Cu.ft. /Sack to 2.08 Cu. Ft/Sack. Unfortunately I missed picking up on this peculiarity of the significance of the 10% gel addition in my initial research of the well. With this revised cement yield, the 2 stage cement job, pumped through the stage tool @ 5500' MD would have been enough cement, even with 30% washout in the openhole section, to put cement all the way to surface in the OA (and then some). Unfortunately I do not have any records that verify cement returns from the OA, but the volume of cement would have been enough to do so with "10% gel" if indeed that gel were bentonite. Given our experience not being able to circulate at anything but extremely minimal rates between the 9 -5/8" casing and the OA with holes at 1500', 1000', and finally at 500' (and with many days of circulating hot water down the CT and up the 9 -5/8" casing) and the fact that 10% gel additive would have been enough cement to fill the entire OA, we feel we have ample evidence that the OA was fully cemented. We successfully pressure tested the OA to 1500 psi and then nippled down the OA valve. A plumb -bob stopped at 12.5' below the annular valve. Our proposal, as previously discussed and approved via phone call, is to lay in a cement plug from the TOC in the 9 -5/8" casing @ 920' MD to surface (this was accomplished last night). We will then PT that cement plug and then cut off all the casings and do a top job on the OA to fill it completely with cement (or as deep as we can get with line- pipe). Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 From: Worthington, Aras 3 Sent: Monday, April 16, 2012 5:22 PM To: 'Schwartz, Guy L (DOA)' Cc: Cismoski, Doug A Subject: RE: Sag Delta 31 -11 -16 Guy, As discussed via phone, we have been unsuccessful in establishing free circulation with the holes punched at 1000' MD. After two cement squeezes we got those perforations squeezed -off. We seek approval for the following plan forward: Punch holes in the 9 -5/8" casing at —500' MD just above the bridge plug that we milled a pilot hole through and establish circulation between the 9 -5/8" and 9 -5/8" x 13 -3/8" annulus and pump cement surface -to- surface via the holes at 500' MD (Arcticset 1 or the approved Class G blend). Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 From: Worthington, Aras 3 Sent: Sunday, April 08, 2012 9:44 AM To: Schwartz, Guy L (DOA) Subject: Sag Delta 31 -11 -16 Guy, 4/27/2012 • Page 3 of 3 As we discussed via phone yesterday, after over two days of working at it we have been unsuccessful in circulating out the 13 -3/8" x 9 -5/8" annulus with the perforations shot at 1500' MD. Our plan is to squeeze off the perforations @ 1500' MD by laying in cement with CT from the current top of cement @ 2040' MD to -1100' MD with about 70 bbls of cement (either Arcticset I or the approved Class G blend). After tagging that cement top we plan to shoot perforations @ -1000' MD and attempt to circulate out the OA from that point to surface, then continue on with the job as planned by circulating cement from surface -to- surface down the 9 -5/8" casing, through the perforations @ -1000' MD and up the 13 -3/8" x 9 -5/8" annulus (Arcticset 1 or the approved Class G blend). Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 CeII: (907) 440 -7692 4/27/2012 • Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, April 19, 2012 10:46 AM To: 'Worthington, Aras J' Cc: Spence, Clint J Subject: RE: Sag Delta 31 -11 -16 (PTD 169 -014) Aras, As we discussed last night it does appear there is something more than just mud in the OA annulus. The proposal to fill the annulus (9 5/8" x 13 3/8" ) with cement from surface after the wellhead is removed and casing cut is approved. Keep me posted on what you find. It will be interesting to see a sample of what is actually in that annulus Guy Schwartz M [ � . - I Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Worthington, Aras J [mailto:Aras.Worthington @bp.com] Sent: Thursday, April 19, 2012 9:20 AM To: Schwartz, Guy L (DOA) Cc: Spence, Clint 3 Subject: RE: Sag Delta 31 -11 -16 Guy, We punched holes in the 9 -5/8" casing @ 470' — 478' MD but, as with the holes at 1500' MD and 1000' MD, could not establish free circulation between the 9 -5/8" casing and the OA (13 -3/8" x 9 -5/8" casing). Subsequently, in a review of my scant well records I found that one of the few line items describing the original 2nd stage cement job on the 9 -5/8" casing (ca. 1969) read: "1100 sacks Class G with 10% Gel ". If "Gel" was bentonite, then the addition of 10% bentonite to the Class G cement would have effectively doubled the yield of class G from 1.15 Cu.ft. /Sack to 2.08 Cu. Ft/Sack. Unfortunately I missed picking up on this peculiarity of the significance of the 10% gel addition in my initial research of the well. With this revised cement yield, the 2nd stage cement job, pumped through the stage tool @ 5500' MD would have been enough cement, even with 30% washout in the openhole section, to put cement all the way to surface in the OA (and then some). Unfortunately 1 do not have any records that verify cement returns from the OA, but the volume of cement would have been enough to do so with "10% gel" if indeed that gel were bentonite. Given our experience not being able to circulate at anything but extremely minimal rates between the 9- 5/8" casing and the OA with holes at 1500', 1000', and finally at 500' (and with many days of circulating hot water down the CT and up the 9 -5/8" casing) and the fact that 10% gel additive would have been enough cement to fill the entire OA, we feel we have ample evidence that the OA was fully cemented. We successfully pressure tested the OA to 1500 psi and then nippled down the OA valve. A plumb -bob stopped at 12.5' below the annular valve. Our proposal, as previously discussed and approved via phone call, is to lay in a cement plug from the TOC in the 9 -5/8" casing @ 920' MD to surface (this was accomplished last night). We will then PT that cement plug and then cut off all the casings and do a top job on the OA to fill it completely with cement (or as deep as we can get with line- pipe). 4/19/2012 Page 2 of 2 Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 From: Worthington, Aras J Sent: Monday, April 16, 2012 5:22 PM To: 'Schwartz, Guy L (DOA)' Cc: Cismoski, Doug A Subject: RE: Sag Delta 31 -11 -16 Guy, As discussed via phone, we have been unsuccessful in establishing free circulation with the holes punched at 1000' MD. After two cement squeezes we got those perforations squeezed -off. We seek approval for the following plan forward: Punch holes in the 9 -5/8" casing at -500' MD just above the bridge plug that we milled a pilot hole through and establish circulation between the 9 -5/8" and 9 -5/8" x 13 -3/8" annulus and pump cement surface -to- surface via the holes at 500' MD (Arcticset 1 or the approved Class G blend). Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 From: Worthington, Aras J Sent: Sunday, April 08, 2012 9:44 AM To: Schwartz, Guy L (DOA) Subject: Sag Delta 31 -11 -16 Guy, As we discussed via phone yesterday, after over two days of working at it we have been unsuccessful in circulating out the 13 -3/8" x 9 -5/8" annulus with the perforations shot at 1500' MD. Our plan is to squeeze off the perforations @ 1500' MD by laying in cement with CT from the current top of cement @ 2040' MD to -1100' MD with about 70 bbls of cement (either Arcticset I or the approved Class G blend). After tagging that cement top we plan to shoot perforations @ -1000' MD and attempt to circulate out the OA from that point to surface, then continue on with the job as planned by circulating cement from surface -to- surface down the 9 -5/8" casing, through the perforations @ -1000' MD and up the 13 -3/8" x 9 -5/8" annulus (Arcticset I or the approved Class G blend). Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 4/19/2012 • Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, April 17, 2012 9:16 AM To: 'Worthington, Aras J' Cc: Cismoski, Doug A Subject: RE: Sag Delta 31 -11 -16 (PTD 169 -014) Aras, You have approval to perforate and circulate from 500' md. This meets regulatory requirements per 20 PP p AAC 25.112 (d) . Hopefully you can bust loose the drilling mud (or Arctic Pack) in the annulus at this depth and get some circulation going. Guy Schwartz Senior Petroleum Engineer APR ZI1'L AOGCC 793 -1226 (office) 444 -3433 (cell) From: Worthington, Aras J [mailto:Aras.Worthington @bp.com] Sent: Monday, April 16, 2012 5:22 PM To: Schwartz, Guy L (DOA) . Cc: Cismoski, Doug A Subject: RE: Sag Delta 31 -11 -16 Guy, As discussed via phone, we have been unsuccessful in establishing free circulation with the holes punched at 1000' MD. After two cement squeezes we got those perforations squeezed -off. We seek approval for the following plan forward: Punch holes in the 9 -5/8" casing at -500' MD just above the bridge plug that we milled a pilot hole through and establish circulation between the 9 -5/8" and 9 -5/8" x 13 -3/8" annulus and pump cement surface -to- surface via the holes at 500' MD (Arcticset 1 or the approved Class G blend). Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 From: Worthington, Aras J Sent: Sunday, April 08, 2012 9:44 AM To: Schwartz, Guy L (DOA) Subject: Sag Delta 31 -11 -16 Guy, As we discussed via phone yesterday, after over two days of working at it we have been unsuccessful in circulating out the 13 -3/8" x 9 -5/8" annulus with the perforations shot at 1500' MD. Our plan is to squeeze off the perforations @ 1500' MD by laying in cement with CT from the current top of cement @ 2040' MD to -1100' MD with about 70 bbls of cement (either Arcticset I or the approved 4/17/2012 • Page 2 of 2 Class G blend). After tagging that cement top we plan to shoot perforations @ -1000' MD and attempt to circulate out the OA from that point to surface, then continue on with the job as planned by circulating cement from surface -to- surface down the 9 -5/8" casing, through the perforations @ -1000' MD and up the 13 -3/8" x 9 -5/8" annulus (Arcticset I or the approved Class G blend). Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 4/17/2012 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 4 (ice DATE: April 5, 2012 p P. I. Supervisor / / FROM: Lou Grimaldi SUBJECT: Wellbore Plug Verification Petroleum Inspector Sag Delta 31 -11 -16 -- PTD 1690140 BP Exploration (Alaska) Inc. Prudhoe Bay Field Thursday, April 5th, 2012; I witnessed the verification of plug integrity for Plug and Abandonment in BPX's well Sag Delta 31- 11 -16. I traveled this morning to the ice pad and witnessed the Coil Tubing tag at 2040' (uncorrected). This was at the anticipated height. The Inner Annulus was pressure tested to 2620 psi and fell to 2572 psi (non- — linear) in thirty minutes. I left location at this time. Attachments: none 2012 - 0405_ Wellbore _Plug_Sag_Delta_31- 11 -16_1g 1 of 1 Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, March 30, 2012 11:26 AM To: 'Worthington, Aras J' Subject: RE: Sag Delta 31 -11 -6 Sundry #311 -380 (PTD 169 -014) Aras, As we agreed ... the high tag is likely Barite sag from the mud left in there the last 40 yrs...You have approval to lay in cement plug from the tag at 6675' to 2000' . Guy Schwartz Senior AOGCC Petroleum Engineer 5.U04 r � E's' WO'? 793 -1226 (office) 444 -3433 (cell) From: Worthington, Aras ] [maiito:Aras.Worthington ©bp.com] Sent: Friday, March 30, 2012 10:17 AM To: Schwartz, Guy L (DOA) Subject: Sag Delta 31 -11 -6 Sundry #311 -380 Guy, As discussed via phone, we have tagged up @ 6675' MD with a nozzle on CT. All of the diesel has been circulated out of the 9 -5/8" casing and we propose to complete the P &A from 6675' MD up. This would mean the deep cement plug will be laid in from 6675' MD to 2000' MD, then we proceed as per the original approved Sundry with circulating out Arctic Pack and cementing the surface plug from 1500' MD to surface. We request approval to start our deep cement plug @ 6675' MD. Respectfully, Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 CeII: (907) 440 -7692 • 3/30/2012 r ` / • • FE SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Doug Cismoski Well Intervention Manager BP Exploration (Alaska), Inc. '*! /`' I F . 2 3 > 0 P.O. Box 196612 Anchorage, AK 99519 -6612 t �' ©` + k::: Re: Sag Delta Field, Wildcat Pool, SD311116 Sundry Number: 311 -380 Dear Mr. Cismoski: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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, i Daniel T. Seamount, Jr. / Chair DATED this / day of December, 2011. Encl. y ATE OF ALASKA RI EI'VED ALASKA OIL AN IMAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL DEC 9 9 2011 20 AAC 25.280 1. Type of Request: Alaska Oil & Gas Cons. Commission ® Abandon • ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Appro lO 5 ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ® Exploratory 169 - 014 • 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 20011 - 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: SD311116 Spacing Exception Required? ❑ Yes No 9. Property Designation: 10. Field / Pool(s): ADL 028343 • Sag Delta Field / Wildcat Pool = 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9094' • 9094' • 8875' 8875' 500' None Casing Length Size MD TVD Burst Collapse Structural Conductor 82' 30" 82' 82' Surface 3173' 13 -3/8" 3173' 3173' 3090 1540 Intermediate Production 9088' 9 -5/8" 9088' 9088' 6870 4760 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None Packers and SSSV Type: None Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: is' Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ® Exploratory • ❑ Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 1, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ® Abandoned • Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564 -4102 Printed Name Doug Cismoski, P.E. Title Well Interventions Manager Prepared By Name /Number: Signature , _ ,;�� Phone 564 - 4303 Date Terrie Hubble, 564 -4628 /� Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Q( tneess (ZZ Sundry Number 3 1 1-- 3 Lg P LII lug Integrity ❑ BOP Test ❑ Mechanical Integrity Test LOcation Clearance g 4" f� 1 s in .4<d - el n /� �a f-t. Other: / /1 /� he 2 o r c. l� �c T r well":"? � P h.0f3 d 0C- "r' m- 1 . oN o t- C Subsequent Form Required: /b -110 APPROVED BY (2_ / / Approved By / COMMISSIONER THE COMMISSION Date ( Q / 1-,) ' Form 17" ;;• L ., , ,. steel i 9 ij i ORIGINAL S mit Duplic / , 1 1111 ?Ic■ (2-- / i( 0 R • • Summary of Proposed Work BP Exploration Alaska Inc (BPXA) P & A Program . Sag Delta 31 -11 -16 PTD 169 -0140 API No. 50- 029 -20011 Present Well Condition The well was drilled to a depth of 9094' MD, and is cased as follows: Casing Size Weight Grade Depth (MD) Cementing Record Conductor 30" 94# H -40 82' 210 sx Fondu Fly Ash Surface 13 -3/8" 61# J -55 3173' 1650 sx Class G, Top Job: 825 sx Class G Intermediate 9 -5/8" 47# N -80 9088' 870 sx Class G (1 stage) 1100 sx Class G (2' stage) Maximum Anticipated Surface Pressure (MASP) is 0 psi (all openhole and casing shoe is cemented and plugged providing hydraulic isolation) per 20 AAC 25.Oc.) The final operation to plug and abandon the well is scheduled to be performed approximately January • 2012 during the ice road season. With approval to complete the P &A from the AOGCC, it is desired that the sundry be approved until June 1, 2013. In April 1969, the well was suspended with the following plugs in the wellbore: 8,875' "� 9 -5/8" Bridge Plug 500' ✓ 9 -5/8" Bridge Plug The procedure below outlines the steps to perform the final operations to abandon the well and cut off all casings and conductor 3' below original tundral level. Procedure to Abandon Sag Delta 31- 11 -16: • • • 1. Service and pressure test wellhead. 2. NU 2 serviced valves on the existing dry hole tree. 3. PT wellbore (9 -5/8" casing) to 2500 psi. 4. RU SL and tag top of bridge plug (expected -500' MD) 5. RU CTU and mill hole through center of bridge plug. LL L n 3�� P. 1 . �V r 1- ".4255 6. Circulate out Drilling mud to PBTD @ -8875' MD and tag. C k a 4 F,5su.,^e, 7:s f 7. PT wellbore (9 -5/8" casing and retainer) to 2500 psi. -- c 30 8. Lay Class G cement in 9 -5/8" casing to 2000' MD. (Approximately 500 - bbls). (8175 260o)K.0 cseyp: 5Z/ $9L 9. Tag & PT cement plug to 2500 psi. P. It 10. Perforate 9 -5/8" casing @ -1500' MD. 11. Thaw and circulate out Drilling Mud. 12. Circulate Arcticset I cement down 9 -5/8" casing through perforations and up 13 -3/8" x 9 -5/8" annulus to surface. 13. Excavate around the well and prep to remove casing and wellhead. 14. Cut off and remove the casing and wellhead a minimum of 3' below original tundra. a. Notify Inspector of opportunity to witness cut off prior to welding plate. 15. Top off any unfilled annuli and tubing to surface with cement. 16. Place an abandonment plate on top of the cut off casing with the following information: BP Exploration Alaska, Inc. Sag Delta 31 -11 -16 PTD# 169 -0140 API# 50- 029 -20011 17. Backfill over Well. . • Sag Delta 31 -11 -16 Permit No. 169 -0140 API No. 50- 029 -20011 Current Status Surface 30" Conductor @ 82' MD / Cemented w/ 210 sx Fondu/ Fly Ash -_ 2,1 9 -5/8 Bridge Plug @ 500' MD Diesel to 2500' 13 3/8" Stage Tool @ 631' MD Drilling Mud Est. TOC w/ 30% washout in OH section: 2400' MD 13 3/8 ", 61#, J -55 @ 3173' MD Cemented w/1650 sx Class G (primary) 825 sx glass G (stage #2) and top job w/ 50 sx Class G j 9 5/8" Stage Tool @ 5500' MD Est. TOC w/ 30% washout: 6740' MD No Perforations Diesel Cement j II Drilling Mud Bridge Plug @ 8.875' MD 10.0 ppg Drilling Mud 9 5/8 ", 47 #, N -80 @ 9,088' MD Cemented w/ 870 sx Class G (stage #1) and 1100 sx class G (stage #2) • Sag Delta 31 -11 -16 Permit No. 169 -0140 API No. 50- 029 -20011 Proposed Status Surface 30" Conductor @ 82' MD / ///4i Cemented w/ 210 sx Fondu/ FIy Ash 13 3/8" Stage Tool @ 631' MD A" 9 Cemen from -1500' MD to -5/8" t and 13 -3/8" x 9-5/8" annulus in ulus 13 3/8 ", 61 #, J -55 @ 3173' MD Cemented w/1650 sx Class G (primary) 825 sx glass G (stage #2) and top job w/ 50 sx Class G / Cement from bridge plug @ -8875' MD to -2000' 9 5/8" Stage Tool @ 5500' MD No Perforations Sea Water Cement ■ Bridge Plug @ 8,875' MD Drilling Mud 11P, 10.0 ppg Drilling Mud 9 5/8 ", 47 #, N -80 @ 9,088' MD Cemented w/ 870 sx Class G (1 stage) and 1100 sx class G (2 stage) • . o[iF ALAEKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 - 3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Gary Preble Date Management Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Sag Delta Field, Wildcat Pool, SD311116 Sundry Number: 310 -438 SUANNED JAN 1 2 201 Dear Mr. Preble: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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, Daniel T. eamount, Jr. Chair DATED this S day of January, 2011. Encl. CA ■ \ RECEIVEire. 'r � 1�� • STATE OF ALASKA • W � ti ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 2 1 2010 `, APPLICATION FOR SUNDRY APPROVALS lasa; ;;as Cons. Clvmmis310f1 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redri11 ❑ Perforate New Pool❑ Repair Well ❑ Chang Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: RENEW SUSPENSION - 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory EL 169 -0140 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 - 6612 50- 029 - 20011 -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: ik Spacing Exception Required? Yes ❑ No ❑ SD311116 " 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028343 SAG DELTA Field / WILDCAT Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9094 • 9094 500 0 500 500' 8875' NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80 30" SURFACE 82 SURFACE 82 Surface 3173 13 -3/8" 61# J -55 SURFACE 3173 SURFACE 3173 3090 1540 Intermediate Production 9088 9 -5/8" 47# N -80 SURFACE 9088 SURFACE 9088 6870 4760 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): NONE- - NONE - Packers and SSSV Tvoe: NONE Packers and SSSV MD and TVD (ft): 12. Attachments: 13. Well Class after proposed work: Description Summary of Proposal Q Detailed Operations Program ❑ BOP Sketch ❑ Exploratory IS Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/4/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended M 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone Date 564 -4944 12/21/2010 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 ) 0.... -13 5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: A /krN 0,k io /u /0 /4C elli e a-i,r ro u O per 20 A/ Z5; /k C i. E;-1- 24 sic, y► vu S L /2- Z0/3 . Subsequent Form Required: (OK� aj -. -c.S r "-,-- • 4 J APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: //,.,51/ 118D , S JAN 06 Qt > - f • 3./, , N / , Form 10-403 Revised 1/2010 ® 1 1 16 Q ► L Submit in Duplicate • Sag Delta 31 -11 -16 Technical Justification for Application for Renewal of Suspension Status December 17, 2010 Well Status Sag Delta 31 -11 -16 (PTD 1690140) was suspended on 04/28/69 after drilling to TD, logging and cementing casing. The well is located within the Prudhoe Bay Unit on a single well inactive gravel pad not accessible from the PBU road system, about 3 miles east of PBU Drill Site 4 pad. BP Exploration (Alaska), Inc. (BPXA) completed a suspended well inspection of Sag Delta 31- 11-16 on 09/25/10. The results of that inspection were submitted with a Report of Sundry Well Operations (form 10 -404) on 10/06/10. Sag Delta 31 -11 -16 is secured with cemented casing and two bridge plugs. The well was not perforated. The well is mechanically sound based on cemented casing and the two bridge plugs. 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, and 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. The well is planned to be plugged and abandoned in 2013: There are no production facilities near this well and the Ivishak in this area has been developed from DS 4 and DS 9. Condition of the Wellhead and Surface Location Sag Delta 31 -11 -16 is located on an inactive pad with clean gravel. The pit and surrounding area are in good condition with some remaining debris. There is no discoloration and no sheens on the pad, pits, or in nearby water. The current well pressure readings are unavailable due to the current configuration of the tree. Request BPXA requests approval for renewal of the existing suspension status for Sag Delta 31 -11 -16 through 12/31/2_03 ,o allow time for the planed P &A to be completed. 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 be remain suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. MLB 12/17/10 • • - 4 • . • SAG DELTA (BP) 31 - - PRODUCER API # 5002920011 SURFACE LOCATION: 1102' FNL, 1743' FEL, SEC 31, T11N, R16E, UM SPUD: 3 - 7.89 , AT TOTAL DEPTH: 1102' FNL, 1743' FEL, SEC 31, T11N, R16E, UM COMPLETED: 4.28.69 DEPTHS: REFERENCED TO 0' RKB STATUS: SUSPENDED ALL DEPTHS MD -RKB (RKB -27') A A • A • • • A . • • 30'; 941; H-40 CSG @ 82' MD • DESB- A CEMENT: 210 SX FONDU - - 300' • • . .A CEMENT TO SURFACE : •:« . - BRIDGE PLUG SET AT 500' • w A • I A A ■ • A • w ■ • • • • • • A • • • A • A A • • A A A A ■ A A • A w • A . • • • • • A A • ` • A w A w . A A • A A • / COO ° A * •w A A A A A • 2500' • w • • • A :• :A /o I Ma) •A : • :• :4 13 -3/8'; 611; J -55 CSG • A • • A • w. ww "' A ' @ 3173'MD •AA • : w I • A A ■ w' " A • CEMENT: 2475 SX CLASS G • w w • • • ■ • A A • • A • • A • w • A • • • • A CEMENT TO 300' A ■ A A • • A w • A * A • DIESEL FROM 1500' TO SURFACE " • ` A • " • ` " A • ■ A A A w • A A A w • A • w A • A A A A • • A A A A KILL WEIGHT FLUID FROM 9094' -1500' = - • A . • • A A • A A A A • A • • A • • A • • • A • A A • • • • • • A • w • • A • • • • A • A • A A A A • • • ■ A A • • • A A • A A • - • w w A A A • A • • A A A A • • A • • • * A • A • ■ • ■ ■ ■ 0 A ■ A A A . A A • A • A * A ■ •. r A w 1 A A w• A A A , . • w ■ A ■ A • • • A A A * r A w • A� • A - • * • A 0 - A A A • • • A • A A A * A A A • A • A A • • A A A • 1 • A • A A A A w • • 0 • * A • ■ * . • w ■ A A A A A • A * A A • A A A • A ■ 1 A E A • a AA A * • w A • A A * A A • A . • w • • * ■ ■ A ± A A A � A ♦ A A r • A • A A A A A A A . • • • A * A w A ■ A r * A • w • w w A A • . • • • A • A• A �A * A A A • A • . A A 1 A A * A • A, r * A A AM 9 -5/8'; 478; N -80 CSG @ 9088' :A A : • BRIDGE PLUG SET AT 8875' CEMENT: 1970 SX CLASS G • w A • • A A w • A CEMENT TO 2500' • : • • " :A • • A A •♦ • c•.r w • A ♦ OPEN G• TWM TD: 9094' w • Vr0`fMG REVISION: 1/8/91 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other Q 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 ❑� \169 -0140 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 \ 50- 029 - 20011 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028343 SD311116 10. Field /Pool(s): 11. Present Well Condition Summary: Total Depth measured 9094 feet Plugs (measured) 500 8875 feet true vertical 9094 feet Junk (measured) None feet Effective Depth measured 500 feet Packer (measured) true vertical 500 feet (true vertical) Casing Length Size MD TVD Burst Collapse Structural Conductor 80 30" SURFACE -82 SURFACE -82 Surface 3173 13 -3/8" 61# J -55 SURFACE - 3173 SURFACE - 3173 3090 1540 Intermediate Production 9088 9 -5/8" 47# N -80 SURFACE - 9088 SURFACE - 9088 6870 4760 Liner Liner Perforation depth: Measured depth: NONE- _ _ _ Z. True Vertical depth: Tubing: (size, grade, measured and true vertical depth) NONE 0 Packers and SSSV (type, measured and true vertical depth) NONE Noy OCT 07 2 0 10 12. Stimulation or cement squeeze summary: O ftaM601 COOL Cofft I N 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: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ velopment ❑ Service ❑ Daily Report of Well Operations X 16. Well Status after USPENDED Oil Gas L WDSPL GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 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: NA Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer 1c Signature &4 q AN Phone 564 -4944 Date 16 Z 9 •!d 11 l lv ' • • Ili I I Exploration Well Sag Delta 31- 11 -16, PTD 169014 Suspended Well Inspection Report i BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of Exploration Well Sag Delta 31 -11 -16 on 9/25/10. 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 site condition. AOGCC inspector Jeff Jones accompanied BP personal to witness the inspection on 9/25/2010. • Wellbore diagram illustrating the current configuration of the well. • Exploration Well Sag Delta 13 -11 -16 was drilled from a remote gravel pad and is not located near active wells and /or service wells. See attached As Built survey. • Photographs showing the condition of the surrounding surface location. Additional pertinent information: • Exploration Well Sag Delta 31 -11 -16 was suspended on 4/28/1969. • Exploration Well Sag Delta 31 -11 -16 was drilled from a gravel pad about 3 miles east of PBU DS 4 and is not accessible from the PBU road system. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • _ The well was secured in April 1969 with two bridge plugs in the casing: • The well is mechanically sound with the placement of the bridge plugs at 500' and 8,875'. MLB 09/29/10 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Sag Delta 31 -11 -16 Field /Pool: PRUDHOE BAY Permit # (PTD): 69 -14 API Number: 50- 029 -20011 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: """�:-Q —?� 4 Surface Location: Section: 31 Twsp: 11N Range: 16E Nearest active pad or road: Drill Site 9 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 / Some trash wood / metal on site Location cleanup needed: Clean up metal / wood & pad Pits condition: N/A Surrounding area condition: Good Water /fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: N/A Photographs taken (# and description): 11; wellhead; pad and general location 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 valves shut in / not functional, seized up Cellar description, condition, fluids: clean / dry Rat Hole: 1; located approx 50 yds north of wellhead Wellhouse or protective barriers: Wooden barrier Well identification sign: Yes; faded e_e P c Tubing Pressure (or casing if no tubing): N/A Annulus pressures: N/A Wellhead Photos taken (# and description): 11; wellhead; pad and general location Work Required: None Operator Rep (name and signature): Jerry Murph AOGCC Inspector: Jeff Jones Other Observers: Ryan H I Inspection Date: 9/25/2010 AOGCC Notice Date: 9/2 Time of arrival: 10:30 AM Time of Departure: 10:45 AM Site access method: Fly SAG DATA (BP) 31- 11 * =16 PRODUCER API # 5002920011 SURFACE LOCATION: 1107 FNL, 1743' FEL, SEC 31, T11N, RI 6E, UM SPUD: 3 -7 -69 AT TOTAL DEPTH: 1102' FNL, 1743' FEL, SEC 31, T11N, R16E, UM COMPLETED: 4 -28 -69 DEPTHS: REFERENCED TO 0' RKB STATUS: SUSPENDED - ALL DEPTHS MD -RKB (RKB =27) w . w 30'; 94#; H -40 CSG @ 82' MD DIESEL CEMENT: 210 SX FONDU w - 300' CEMENT TO SURFACE - BRIDGE PLUG SET AT 500' A w . w _ A A A w . . A w ♦ w ' . w A "rA 2500' •Aw • w w w w w w ♦ww ° ' /��` •" 13.3/8'; 61 #; J -55 CSG @ 3173' MD A wAwA • ww" CEMENT: 2475 SX CLASS G • w • w " "ww " w w w CEMENT TO 300' • w A . • • w A DIESEL FROM 1500' TO SURFACE A • w w w w w w w . • w w • A w KILL WEIGHT FLUID FROM 9094' -1500' 10 � �46a A w w w • A • • A A A • r w w • w w" • • A w • . r w w r w • .w w . w w w w w r w w • . w A w w w w w w • w w • w w . . w w w w w w r w w w • • r . w • • A • w w w . w w • w w • w w w w r w w w w w w • w w w • w w w w w wi r w . w r • • w w • • w • w r w w w w w w • w • r w w w w w w w w • • w w w w w • • . w r w w w A w w OPENHOLE 9 -5/8'; 47 #; N -80 CSG @ 9088' CEMENT: 1970 SX CLASS G BRIDGE PLUG SET AT 8875' w w w CEMENT TO 2500' w " A " w w � 4 A A A • A T M A A ' `� m TD: 9094' A REVISION: 1/8/91 Oag Delta 31 -11 -16 July 26, 2010 Approximate Scale: 1" =200' 2010- 19c -5 -15 AMWOUM AM t' f{ - w 3 t f 0 r 3 a 1 r ' gy 6 r 1 1 1 14 13 18 ; 17 t I6 I IS 1 1 1 I 1 It i 23 24 19 i 20 s 21 22 ' 1 BP- 31 -11 - I 1 LAC 70° 6.63 I q 26 25 30 29 f LONG.i48 °1tP 0.+14 27 i Y s S,9'St,17444111 34 I 1�4 I X a 72$,67441 I 1 Tom ,. I 1 1 I 35 56 31 ` E 32 ; 33 34 T11 N T1OM 1 2 1 1 6 5 4 3 SCALE: 1"R iMiLE CERTIFICATE OF SURVEYOR 1 hereby certify that I am properly registered anti licensed to practice land surveying to the State of Alaska and that this plat represents a location survey nwde by me or ti � under my supervision, and that all dimensions and other details are correct, t � N0.1T58 —S i1 4% Dote SURVEY 8P 31 -11 -16 korwo*4 in At V.S. rworeAcT[! 1[ir10M i1�TM u� ff 1RR1 ...... JAN 3 G l`i ti 8 p EXPLORATION, USA, INC. 04v15F �tur,�w:� F. M. LINDSEY & ASSOC. 1 1 LAND a HYD1000 P"IC SURVEYORS ' 1 S n L 2307 Mott raorthote t+yin, i .I~d P.O. 99. . -061 1 v - { 4` t FF I1+[aetbgr F f�a1 a „,� �e . r t` � _ �, , � � Y - ,'w”, �► , *w..,, i ,R a "^- � � � �..,i.�. �•.. ka.:.. .r�.v. ,. a , r > m. r w F ° %'• LEE ti Ito IC jjjggq i , jj 6 1K A • # (} # # k r , � � r i V i 4t f 4 to " + " t } a � , �p a it x }fi ✓ 5 I y Y! ' w' s» ,f'a Pxa�„rppn �'"4SLc�'';'f!.:.:� , F •..._! "^""t��.�� ."+r _ r y4 E k k { ff ' f ;r t i �i i K+ r i >,�. y � r . . . ,, � � �� ««w� � � «..� » w : � © -�� :� a.� � © � :< w e� a: � ?�» �. ..� s w � , . �� © .� »d r« ©yam � � . :� : .« �. � «2�� y 2 »a�}. � .� . � .� , . . �w©w� .. .� � � � a. �� ». ~�� \,�� ^? � . . »� �� :. \� . « `: \ ° :��.: .. . . ..� : < � y .� \ .. . .dam � . \ / \� /�� « .© � � \ ~ ^. ».. *. .: :� «. . .. ,: � 2 ... © a � m.� .� � ? yy w � . .:� a�� .� y r ,. a . .. .� �� .�� 2 .� .. � :d =. ,. .� � � :� .z� , :: ww : a.»a«» . v � »�� x ` , T ? A O JI vlff + 3 n r q l rr „ z _ M== I �� ' �w �rs•,�ea. `I�� ... `* - ' 'Ilk AW O c , r ' M AF .• I t 4 ?" a t► t � + t 4 4� y. • iL t r - r r 1 , 1 r ,t. r tj 0.0 y� i t �f'y 1 A l rt A �/, *� ., �i � it t 4 ; fi t � 1. • �. � �� : ' . e "�' fi �.��, ir+ /1 I ' V ' s� w., AM 3 n. .•..., .,,,� .. _ .,,gib , .. - n. "a, .a r q 1 4 r z } / t t i i f i ^t a j , i r y gyp: '�'. .F � � { { • �..; i .{ SARAH PALIW, GOVERNOR L! LY ,r J �T �SKA 011L AND GAS 333 W. 7th AVENUE, SUITE 100 CGIVaSERRA►IONT COli MSSIO T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 January 29, 2009 FAX (907) 276-7542 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7004 1160 00013621 1878 Harry Engel BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Request for Verification of Suspended, SCANN 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. Enclosures Sincerely, /U Cathy. Foerster Commissioner r: CERTIFIED MAILM RECEIPT • (Domestic Mail Only; No Insurance Coverage Provided) raR Afi�ii~!(�tAK Ak 995 4-66;12 v r r: CERTIFIED MAILM RECEIPT • (Domestic Mail Only; No Insurance Coverage Provided) raR Afi�ii~!(�tAK Ak 995 4-66;12 m � Postage $ $0.59 PS POsr p Certified Fee $2.70 J .q N� E3 Return Reciept Fee (Endorsement Required) $2.20 Z n 9 O Restricted Delivery Fee `\ -13 (Endorsement Required) $0.00 \.p9 SON i PS Form 3800, June 2002 See Reverse for Instructions ■ 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: A. Sign atu X Agent Addressee B. Re eiv by ( Printed_Name) C. Date of Delivery D. Is delivery a�d-ress diffefent from item 19 ❑ `66j If YES, enter delivery address below: ❑ No 3. `Se ice Type [Certified Mail ❑ Express Mail ❑ Registered Meturn 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 10 N 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 10 N 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 10 N 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 10 N 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 10 N 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 10 N R 15E 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)................................... 'EXPLORATORY 198-252-0 50-089-20027-00-00 RED DOG 1 SUSP 4/2/1999 1682 FSL 4508 FEL Sec 34 T 10 N R 21 E UM ENDICOTT 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 12N R 16E UM MILNE POINT 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 13N 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 13N 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 13 N R 13E 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 15 E UM 175-059-0 50-029-20177-00-00 GETTY STATE 1 OBSW 5/11/1980 1388 FSL 887 FWL Sec 2 T 10 N 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 12N R 11 E UM 205-010-0 50-029-23245-00-00 PRUDHOE BAY UN BORE I-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 L3-01 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 L4-02 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 Current Date of Permit API Number Well Name 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 14 E 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 12N 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 13 E 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 13 E 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 13 E 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 14 E 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 13 E 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 12 E 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 12 E 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 13 E 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 13 E 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 t� `1 SARAH PALIN, GOVERNOR �....._ t� �L ALASKA OIL AND GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAx (907) 276-7542 January 28, 2009 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 5951 Harry Engel BP Exploration Alaska Inc. 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 Si n% 12GiQ Dear Mr. Engel: Enclosed are 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 A'i,rster Commissioner Enclosures K Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. R. 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 Lxploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 R. Slgn Sre Postal A, _Z) Agent Q Addressee 8.Rved b? ame) Del' ery C7-ate� D. Is delivery address different from item 1? Q Yes If YES, enter delivery address below: Q No rvice Type Ir Certified Mail Q Express Mail ti Q Registered -EdReturn Receipt for Merchandise Q Insured Mail 0 C.O.D. � 4. Restricted Delivery? (Extra Fee) Q 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 - sMAIL— Er (DomesticLn Mail Provided ,) -- Ln Ir WWI •L U S E. ti t po p = $0.59 � c«�ea F.. -o 62.94 a o Q plamasawfte o vJ 0 W Restricted oeaary Fee (e dorse"W t PA**04 9f 60.40 soar a�pY r -q TatdP~&F — 65.49 0 Ln rn ° Harry Engel a BP Exploration Alaska Inc. orPOBox "` PO Box 196612 Cky, Srare� paw - Anchorage AK 99519-6612 Operator Suspended and Shut In Wells BP EXPLORATION (ALASKA) INC Field Current Date of Permit API Numlxr Well Name Statue 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 r►`L�I:i�'6� 200-211-0 50-029-22996-00-00 206-138-0 50-029-23325-00-00 PRUDHOE BAY 180-092-0 50-029-20504-00-00 198-035-0 50-029-22866-00-00 205-010-0 50-029-23245-00-00 189-075-0 50-029-21959-00-00 189-104-0 50-029-21978-00-00 202-002-0 50-029-2.2789-01-00 206-031-0 50-029-2.2668-01-00 197-158-0 50-029-22778-01-00 202-052-0 50-029-23072-00-00 201-222-0 50-029-23054-00-00 191-037-0 50-029-22146-00-00 Wednesday, January 14. 2009 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 1-13 NORTHSTAR UNIT NS -26 NORTHSTAR UNIT NS -33 PBU MP 11-33-11-12 1 PRUDHOE BAY UN BORE 02-01 PRUDHOE BAY UN BORE 1-100 PRUDHOE BAY UN LIS 1-3-01 PRUDHOE BAY UN LIS 1-4-02 PRUDHOE BAY UN NIA NK -11A PRUDHOE BAY UN NIA NK -14A PRUDHOE BAY UN NIA NK -41A PRUDHOE BAY UN NWE 04-01 PRUDHOE BAY UN ORIN V-201 PRUDHOE BAY UN PTM 12 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 F_ UM ADL0047432 SUSP 7/13/2003 496 FSL 2027 FEL Sec 10 T 13N R 10E UM ADL0047434 SUSP 10/27/1993 610 FSL 2063 FEL Sec 10 T 13N R 10 E UM ADL0047437 SUSP 3/23/1996 3592 FSL 2078 FEL Sec 3 T 12 N R 11 E UM ADL0375133 SUSP 1211/2008 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 10 E UM ADL0025517 SUSP 2/1/2001 1298 FSL 648 FEL Sec 11 T 13N R 13E UM ADL0312799 SUSP 4/26/2007 1369 FSL 650 FEL Sec 11 T 13N R 13E UM ADL0321798 SUSP 4/29/1981 1966 FNL 1380 FEL Sec 33 T 11 N R 12 E UM ADL0047A52 SUSP 4/22/1998 453 FSL 4553 FWL Sec 19 T 12 N R 11 E UM ADL0047446 SUSP 4/17/2006 3219 FSL 3945 FEL Sec 20 T 12 N R 11 E UM ADL0047446 SUSP 9/13/1994 287 FNL 550 FWL Sec 22 T 11 N R 15 E UM ADL0034631 SI 12/8/1994 2426 FSL 2176 FEL Sec 24 T 11 N R 15 E UM ADL0028323 SUSP 2/22/2002 1312 FSL 1021 FEL Sec 36 T 12 N R 15E UM ADL0034629 SUSP 5/4/2007 1358 FSL 944 FEL Sec 36 T 12 N R 15E UM ADL0034625 SUSP 11/2/1997 1474 FSL 717 FEL Sec 36 T 12 N R 15E UM ADL0312827 SUSP 4/7/2002 3203 FSL 4003 FEL Sec 20 T 12 N R 11 E UM ADL0047446 SUSP 1/25/2008 4838 FSL 1775 FEL Sec 11 T 11 N R 11 E UM ADL0028240 SUSP 4/30/1991 1359 FSL 980 FEL Sec 16 T 12N R 14 E UM ADL0375136 ADL0034630 ADL00474Z Operator Suspended and Shut In Wells BP EXPLORATION (ALASKA) INC Held Permit. API Number Well Dame 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 14 E UM ADL0034622 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 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 14 E 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 -13A 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 13E 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 12 E 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 13 E 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 ADL0028288 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 14 E UM ADL0034628 PT THOMSOM Wednesday, January 14,42609 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 ff'erinesrlgy, JnnuarP 14. 2009 TONY KNOWLES, GOVERNOR DEPT. OF ENVIRONMENTAL CONSERVATION DIVISION OF SPILL PREVENTION AND RESPONSE Industry Preparedness and Pipeline Program 555 Cordova St. ,Anchorage. AK 99501 Phone (907)-269-7679 Fax (907)-269-7649 November i5, 1995 Letter No.' 95-9-JR.BPX File No.' 300.15.202 Mr. Steven D. Taylor BP Exploration (Alaska) Inc. P.O. Box 196612 Amchorage, ?AK 99519-6612 Re: Approval for Closure - Inactive Drilling Waste Disposal Site 31-11-16 Dear Mr. Tavlor: The Alaska Department of Environmental Conservation (ADEC) has received correspondence from Mr. Dave Lowe. dated September" .~I. 1995, requesting closure of the Sag Delta 31-11-16 disposal facility. The site was inadvertently omitted by ADEC from a list of closure approvals submitted to your office and dated January 12. 1995. Surface work is complete at the site; and the faciiitv was inspected by ADEC. ADNR. and ADF&G personnel on July 8. 1995. This correspondence describes our review procedures, puts forward the Department's findings, and takes action upon the closure recmest. The site has been reviewed in accordance with the ADEC Interim Site Assessment Guidance for Inactive Drilling Waste Sites. June 1991. The third draft of Alaska's new Solid Waste Regulations. 18 AAC 60. is currently under review, and this third draft contains a chapter on Inactive Reserve Pit closures. The closure criteria in this proposed r%m.tlation parallels the closure criteria in the 1991 Guidance Document. Closure under the !991 Guidance Document should constitute closure under the proposed Solid Waste Re~m.tlations. The review procedures include an evaluation of the risk screening assessment required in the ! 991 Guidance Document, and is summarized in our previous correspondence (Januar3' 12. 1995). Briefly, the significance of risk to local receptors is evaluated through study of contaminant 'release, exposure criteria, and consequence criteria. Mr. Steven D. Taylor BPXA Inactive Drilling Waste Disposal Facility. Closure Approval November 15, 1995 Full Site Closure: The approval granted by this letter is for the inactive drilling waste sites only. as required under 18 AAC 60.500 (d). Closure for the pad as a whole must be coordinated between the owner/operator and the appropriate state t'.M3NR..M3F&G. AOGCC), or federal. CBLM) agency. Additionally, should an.',, contamination from Nstoric spills be found on the Dad outside the drilling waste site (reserve pit area), notification needs to be made to the ADEC Contaminated Sites Section (269-7659). New Information: Should additional information concernino_ environmental conditions at the faciii~' make further actions necessarv to protect human health or the environment, the Department reserves the right to recmire additional investigation, assessment, monitoring, or remediation at the facility.. DuD' To Respond: Nothwithstanding any other provisions or requirements of this closure approval, a person causing or permitting the discharge of oil or other hazardous substances is required bv law' to immediately contain and clean,up the discharge. (AS 46.04.020: 46.09.020). If vou have am, further auestions, please feel free to contact Jim Chatham at 269-7679 of this office. x,,,.~ Sincerely, Tom Chapple Program Manager TC/J~RC CC: Dave Lowe. BPX/Anchoraee James Chatham. ADEC/Anchoraee AOGA/Anchorage Nancy Welch. ADNR/Fairbanks o Al Ott, ADF&G/Fairbanks Joe Saumer. ADEC/Anchorage Jim Haynes, ADN1L/Anchorage Keith Mueller, USFWS/Anchora~e Jessie Kaleak Sr.. Mavor NSB/Barrow TONY KNOWLE$, GOVERNOR DEPT. OF ENVIRONMENTAL CONSERVATION DIVISION OF SPILL PREVENTION .~ND RESPONSE Industry Preparedness and Pipeline Program 555 Cordova St. Anchorage. AK 99501 Phone t907)-269-7679 Fax (907~-269-7649 November 7, 1995 Letter No.' 95-8-JR.BPX FSe No.' 300.15.202 Mr. £teven D. Tavlor BP Exr~toration (Alaska') Inc. P.O. Box ~96612 Ancnora_~e. ,-',K 99519-6612 Re: Approval for Closure - Inactive Drilling Waste DiSposal Sites Dear Mr. Tavior: The Alaska Department of Environmental ConserYation {?d3EC) has received correspondence from Mr. Dave Lowe. dated January, '" _~, 1995, concerning a recent list of inactive reserve pit closures. The list was addressed to your office and dated January, 12. 1995. Four sites were inadvertently omitted by .&DEC 5om the list of closure approvals, and two additional omissions were identified by the Department whiie reviewing Mr. Lowe's letter. Furthermore, four sites received conditional closure shams contmeent ur~on surface rehabilitation: ~3.xree other locations were mentioned as candidates for fu,w. her remedial action. Surface work is complete or in pro~ess ar these latter sires and their status is now subject :o further review bv the Department. This correspondence describes our review procedures, puts forward the Department's findings, and takes action upon the closure requests. The sites have been reviewed in accordance with the )dDEC Interim Site Assessment Guidance for tnacrive Drillin,* Waste Sites. June t991. The third draft of Alaska's new Solid Waste Re~lations. 18 AAC 60. is currently under review, and this third draft contains a chapter on Inacuve Reserve Pit closures. The closure criteria in this proposed re_m.tlation parallels the closure criteria in the 1'991 Guidance Document. Closure under the 1991 Guidance Document should constitute closure under the proposed Solid Waste Regulations. The review procedures include an evaluation of the risk screening assessment required in the 1991 Guidance Document. and is summarized in our previous correspondence (Januar?' !2. 1995). Briefly. the sigmficance of risk to local receptors is evaluated through studv of contaminant release, ex¢osure criteria, and consequence criteria. Mr. Steven D. Taylor BPXA Inactive Drilling Waste Disposal Faciiits' Closure Approval SITES CONSIDERED FOR CLOSURE November '7,. 1995 Based uvon criteria from the June 1991 INTERLM SITE ASSESSMENT GU'TDANCE FOR iNACTIVE DRILLING WASTE SITES. ~e locations listed below have been reviewed for closure. The following sL'('sites were omitted from the original list of closure reauests: East Umiat East Umat #2 ~- 03 East U_~nu Unit #1 Sag Delta 3 i- t 0-16 s0- o6-5 Sat Delta 31- i 1-16 6~- o i -~ Reindeer ISland gl '"/B'= 8~r The followmo_ seven sites ,' w' ~ ' ' re..e, ea.~onmnona~ closure stares contingent ur)on surface re~biiimtion and/or r~vegetation: Shale Wall Unit; 1 i,3- 024" Kemik Unit.gl -qo.ot=o Kur)aruk Unit 1 & IA Itkillik Unit No. ! 6"/-o~8" Fin Creek Unit No. I ~l- oi Sat Delta Unit No. ~ c4-o,'~ Sag Delta Unit No. 2 !0-1i-16 Consideration of these sites for ciosure approval has been based (t) on a review of the submi~ inactive drilling waste site assessment :documents listed below bv the ADEC Solid Waste, Water Quality,, and Contaminated Site Staff. and (2) site visits bv ,4X)EC, A.DNR, and ADF&G staff during July of t995 along with the resultant recommended remedial actions by the Deparunent unden2aken at a certain number of :these sites. Title: Supporting Documents: Submitting Person: Covered Facilities: Inactive Rese~'e Pit Pro~rarn. Assessment and Closure BPXA Videomocumentation of Pit Closure/Site Restoration Comparative ,~'mlysis of Soil and Water Samples Dave Lowe. BP Exploration (Alaska) Above Name Facilities Synopsis of Closure Procedure: Closed as is. No further action is needed for the drilling waste facilities at these sites, except as noted below. Mr. Steven D. Taylor BPXA Inactive Driliin~ Waste Disr)osai Faciiitw Closure Armroval November 7, t995 CLOSURE .kPPROVXLS The De~arn'nent's decision ur~on me reauest for closure application submitted bv BP Exploration :: Alaskz: inc. is to approve for closure the below listed drilling waste disposal facilities, effective October 25. !995. This decision is supported by ADNR and ADF&G: the agencies agee wi~ and ex:ress no concern wi~ closure of ~e sites. Upon review of ~e subdued smpie resulB required under the 1991 Guidance, cemm remote sites e~bited metal concentratio~ ~d hvdroc~bom m me rescue mt surface waters and down ~radient waters in excess of the AI~ Driving Water Smnaards and Alaska Water Quaii~' Criteria ('AWQC). ~ile there is a basis for concern for mose sites where exceedanc~s occu~ed, there is also ne~!i2ible risk. and ~v co~ective action w~md at ~ese remote sites would nor be requ~ed, reai:mg ~at ~e ~pact ~o=e~,,ve action would be much greater ~an ~e benefi~ . These s re,~,5 ea ires. for ~e most para have revegemted and any coxective measures would ~vact me esmblishea pl=t s~cies at mese iocatio~. ~ese sites ~e 'Closed As Is' ~ere ~e ce~m sites where coxec~ve action is wa~anted, and 'Conditionai Closure' is granted, provided the coxective action moulations are zomoieted to me Deoa~em's satisfaction. CLOSED .~ t~ East Umiat Unit #1 East Umiat Unit #2 Reindeer Island gl Fin Creek Unit ~1 Itkillik Unit #1 Kemik Unit # 1 Kuparuk Unit t & lA Shale Wall Unit # 1 Sag Delta 31-10- t 6 CONDITION.ALLY CLOSED These closure conditions were placed on the below-named sites followin_~ the site v~sib'closure ~acka~e evaluation: East U~u Unit Remove trash and exposed portions of pilings. Push berms into reserYe :it. seed. and fertilize. Sag Delta 1 Reshape pad to naturai contour and cover pit. Mr. S~even D. Taylor BPXA !n~ctive Drilling Waste Disposal Faciiiw Closure Approval TC,,'YRC Dave Lowe. BPX/Anchora~e James Chatham. ADEC.',~-achora~e AOGA,'Anchora~e Nancy Welch. ADNtLfFa~banks .4.1 Orr..&DF&G/Fairbanks Joe Saumer. ADEC/Ancnora~,e Heather Stockard. ADEC,'Juneau Jim Havnes. ,&DNR/?anchoraze Keith Muetler. USFWS/.~chora~e Jessie Kaieak Sr.. Mayor NSB/Barrow November 7. 1995 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo~~ DATE: October 2, 1994 Chairma'n TI-IEU; Blair Wondzell, ..4~~ :FLEE NO: 2991jbbd.doc P. I. Supervisor '~/~"~ John Spaulding,~. Petroleum Insp. t)~l;,l~ 3~ FROM: SUBJECT: Suspended Wells Inspection North Slope, Alaska October 1,2&3, 1994: I accompanied Marian Sloan BPX representative on an inspection tour of BPX suspended wells at various North Slope locations. Travel was by pickup and helicopter. Marian Sloan Informed me that BPX is drafting a program with reasons for leaving wells listed below as suspended, this program will be available to the AOGCC in the very near future Oct. 1,1994 Y-22A/ PBU / PTD 88-115; well head on configuration, no pressure on tubing or annulus, area very clean, well is located on a producing drillsite. S-10A / PBU / PTD 91-123; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. U-01 / PBU / PTD92-11; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. Z-32A / PBU / PTD 93-113; wellhead on configuration, no pressure on tubing, 750 psi on inner annulus, 0 pressure on outer annulus, area clean, well is located on producing drillsite. Chevron 18-11-12 / PTD 80-108; wellhead on configuration, no pressure on tubing or annulus, area clean. MP 22-31-11-13 / PTD 81-10; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. MP 32-30-11-13 / PTD 80-152; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. Oct. 2, 1994: A-01 / MPU / PTD 79-40; wellhead is removed with casing hanger still on, area clean, well is located on a active drillsite. A-03 / MPU / PTD 83-01' wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a active drillsite. B-02 / MPU / PTD 81-142; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite, C-16 / MPU / PTD 85-116; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. N-01B / MPU / PTD 84-13;. wellhead on configuration, no pressure on tubing or annulus, area clean with timbers covering the cellar area and well guard around the wellhead. No Point #1 / MPU / PTD 94-27; wellhead on configuration, area clean, unable to land helicopter to check wellhead for pressures, No Point #1 is scheduled to become part of the F- pad construction at MPU. , NW Milne #1 / MPU / PTD 91-145; wellhead on configuration, area clean, island is suffering from severe-erosion on the North side. Oct. 3, 1994: Sag Delta 31-11-16 / PTD 69-14; wellhead on configuration, area clean, has wooden location marker, no pressure on tubing or annulus. Sa.q Delta #3 / PTD 76-80; wellhead on configuration, area clean no pressure on tubing or annulus. Sa.q Delta #4 / PTD 77-15; wellhead on configuration, area clean, no pressures on tubing or annulus. ...Sa.q Delta #2A / PTD 77-69; wellhead on configuration, no pressures on tubing or annulus, timbers and cellar box material, reserve pit open. Sa.(] Delta #5 / PTD 80-129; no wellhead; bell shaped affair was covering the supposed well surface location, area clean. .Sag Delta #8 / PTD 80-121; wellhead on configuration, timbers and well guard, island is eroding. Alaska Island #1 / PTD 81-119; unable to land, area appeared clean from the air, marker post visible on South side of island. Niakuk #4 / PTD 84-200; wellhead on configuration, concrete river weights, cellars open, island eroding. Niakuk #5 / PTD 85-27; wellhead on configuration, concrete river weights, cellars open, island eroding. Location Clearances; Niakuk #lA / PTD 76-28; area is clean, no visible marker post, island is eroding as planned. (;:Niakuk #2A / PTD 76-79; ...area -is-clean;-no--visible-marker-post; .island.-.is-eroding as planned. I recommend that the AOGCC consider Niakuk lA & 2A for final abandonment and location clearance. , Summary,: I inspected locations of 28 BPX suspended wells. I also inspected 2 wells for final abandonment and location clearances. BP EXPLORATION To: David W. Johnston Chairman Alaska Oil & Gas Commission From: Steve Horton, Drlg Mgr Shared Services Drilling ARCO Alaska, Inc. I~~'.~ Date: 09/31 ~--zp~'~ ~ Subject: Suspended wells Compliance with regulations In response to your letter dated August 15, 1994 regarding suspended wells attached are lists detailing well status and criteria for maintaining these wells in a suspended status. Plans for well inspections are in place for October 1 through October 3, 1994 as discussed with Blair Wondzell and John Spaulding. Updated reporting has been filed with the commission as listed. Yours Sincerely, Steve Horton Drilling Manager Bill Bredar Patrick Collins Jim Farnswor~h Mike Miller Bruce Policky Scott Sigurdson Marian Sloan REEEIVED ' OCT 1 4 1994 Alaska 0il & Gas Cons. Commission Anchor~a Suspended Wells, Request to retain suspension status The following wells are listed as suspended by the AOGCC under 20 AAC 25.110. These wells are requested to remain suspended for the reason(s) as indicated. Site inspections should be conducted as soon as possible. MPA-01; 029-20376-00 79-/¢'04 Potential recompletion in the Kuparuk C and/or B sand as a water injector. Decision hinges on 1994/95 development drilling results (E-13)in this area. MPB-02; 029-20662-00 81-/¢(142 This well is scheduled for initial completion in the Schrader Bluff late this year or early next year. MPA-03; 029-20891-00 83-~. 001 Future utility as a Schrader Bluff producer with producing utility when surface infrastructure is installed on A pad. MPN-01 B; 029-21053-02 84-0013 N-01B is a usable well in the Schrader Bluff, with producing utility when surface infrastructure is installed on N pad. The well should be retained in a suspended status until that time. MPC-16; 029-21364-00 85-0110 C-16 has recompletion potential in the Kuparuk "C" sand and/or the Schrader Bluff horizons. Although additional evaluation must be performed to quantify reserves and production potential, C-16 is believed to be a viable workover and/or sidetrack candidate. NWM#1; 029-22231-00 91-0145 Northwest Milne #1 should remain suspended until the Northwest Milne Point development is better defined. The weilbore is strategically located on a gravel island and may possess utility in either production or injection operations. DNR recently certified this well as capable of production. No Point #1; 029-22450-00 94-0027 No Point #1 will be utilized in the upcoming F- Pad development. Expectations are to complete the Kuparuk "A" zone and commence production 4Q95. Niakuk #4, 029-21217-00 84-0200 Niakuk #4 is requested to remain suspended until the viability of the well for monitoring is defined. Niakuk #5, 029-21290-00 85-0027 Niakuk #5 should remain suspended for observation purposes at this time. Sag Delta #33-12-16, 029-20176-00 75-0058 Area being drained by 1994 Alapah well NK-26 (HAW). Potential use as a monitor well for this new reservoir Would have to truck oil across winter ice road if resume production Produced 186 MBO in 1985 2 month production' test. Sag Delta #5, 029-20527-00 80-0129 Area being drained by L5-26 (high gas well), L5-28, and L5o36 from south to west. Well tests indicated fairly tight, but productive rock; perhaps inadequate stimulation? Costs prohibitive for eventual tie-in to L5 (? via Heald Point). Potential for gas cap monitor well Sag Delta 31-11-16, 029-20011-00 69-0014 Area being drained by L4-36, 80 Acre offset to NW. Potential for service well (water injection?) Well is capable of production, but most Lisburne in. water leg and costs likely prohibitive for tie-in to L4. Sag Delta #2A, 029-20234-01 77-0069 South of Sag Delta #1, in water leg of Alapah oil accumulation in NK-26 well. Remote potential for pressure monitoring of Alapah offtake and the effect on the Alapah aquifer; though, costs would likely be prohibitive. Sag Delta #8, 029-20519-00 80-0121 Z-32A, 029-21924-01 93-0113 S-10A, 029-20765-01 91-0123 Sag Delta #8 should remain suspended until the development plan for the area is better defined. This well may possess utility for production or as an observation well. Z-32 was shut in due to high water production in 1992. In 1993 it was sidetracked to a new location. The oil column at the new location was less than prognosed and was not considered economic and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. S-10 was sidetracked in 1992. Drilling difficulties were encountered while drilling through a fault in the Kingiak and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. The West Sak formation, a non unitized formation in the PBU license area, is reachable from this wellbore. Work in ongoing on a facility sharing agreement. In the case that a satisfactory agreement is reached, this wellbore could be used to access oil in this formation. Y-22A, 029-21558-01 88-0115 Y-22 was sidetracked in 1988. The sidetrack was suspended due to drilling difficulties. There is oil in the region that can be reached as a new sidetrack from this well. A location has not been worked on but we wish to retain this wellbore for a future sidetrack. U-01, 029-22244-00 92-0011 PR 33-12-13, 029-20047-00 69-0104 There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. The well penetrates The West Sak and Ugnu formations in the aquifer. Work in ongoing on a facility sharing agreement with subsequent appraisal of the formations. This well could be used to test the aquifer properties. These wells are listed as suspended, action items are detailed. Ak Island #1,289-20018-00 81-0119 Alaska Island #1 was abandoned in 1988. The completion notice has been refiled with AOGCC on 9/15/94. The site is ready for inspection (priority 1). Niakuk #lA, 029-20156-01 76-OO28 Niakuk #lA was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). Niakuk #2A, 029-20180-01 76-0079 Niakuk #2A was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). PBU H-01,029-20099-00 71-0015 The well was drilled in 1971 and hit a down thrown fault block with only 20ft of oil bearing Ivishak. This was not economic at the time. It was left suspended without tubing. Recent success in fraccing the Sag formation indicated that it might be an economic well. A rig workover was completed in April 1994 and the well was put on production 9/94. It is not necessary to inspect this site. Kemik Unit #1,223-20006-00 70-0060 Kemik Unit #1 is scheduled to be abandoned in the near future. Abandonment planning is now in progress, Site inspection will not be necessary at this time most likely should be scheduled for Spring of 1995. P2-59, 029-22096-00 90-0140 Arco Alaska Inc. is the operator of this well, they will be addressing the question of suspension. Sag Delta #3, 029-20233-00 79-OO8O Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. Sag Delta #4, 029-20245-00 77-0015 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. The following wells are not under BP Exploration ownership. A letter requesting the owners to respond regarding their wishes for these wells was sent on 9/30/94. MP 03-10-12, 029-20483-00 80-0O66 MP 33-11-12, 029-20504-00 80-0092 CHEV 18-11-12, 029-20511-00 80-0108 Term C 03-11-12, 029-20356-00 78-0102 MP 22-31-11-13, 029-20545-00 81-0010 MP 43-31-11-13, 029-20536-00 80-0139 MP 30-11-13, 029-20546-00 80-0152 ALASKA OIL AND GAS CONSERVATION COMMISSION August 15, 1994 ~WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Steve Horton, Drlg Mgr BP Exploration (Alaska) Inc P O Box 196612 (MB12-1) Anchorage, AK 99519-6612 Re: Suspended Wells Compliance with regulations Dear Mr. Horton: BP Exploration and the predecessor Sohio companies have several suspended wells as shown on the attached lists: BP SUSPENDED WELLS PRIOR TO 1980 and BP SUSPENDED WELLS SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon applicatiOn by the operator under 20 AAC 25.105(e), the commission, will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above, or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as .r~_equi~20 AAC 25.110(e), must have well site inspe~_n_s~~is~ y~f~?~now covering the locations. David W.{,,Johnston ~ "- Chairman '",~ \ Attachments c: Blair Wondzell bew/1 lbpsusp 8/lS/94 PERMIT 79-0040-0 80-0066-0 80-0092-0 80-0108-0 80-0121-0 80-0129-0 80-0139-0 80-0152-0 81-0010-0 81-0119-0 81-0142-0 83-0001-0 84-0013-0 84-0200-0 85-0027-0 85-0110-0 88-0115-0 90-0140-0 91-0123-0 91-0145-0 92-0011-0 93-0113-0 94-0027-0 API NUMBER 029-20376-00 029-20483-00 029-20504-00 029-20511-00 029-20519-00 029-20527-00 029-20536-00 029-20546-00 029-20545-00 089-20018-00 029-20662-00 029-20891-00 029-21053-02 029-21217-00 029-21290-00 029-21364-00 029-21558-01 029-22096-00 029-20765-01 029-22231-00 029-22244-00 029-21924-01 029-22450-00 BP SUSPENDED WELLS SINCE AUGUST 1994 1980 WELL WELL WELL NAME CLASS STATUS MILNE POINT UNIT A-01 EXP SUSP PRUDHOE BAY T/NIT 3-10-12 DEV SUSP PBU MP 11-33-11-12 I DEV SUSP PRIJDHOE BAY %INIT TR 18-11-12 DEV SUSP SAG DELTA 8 EXP SUSP SAC DELTA 5 EXP SUSP PRUDHOE BAY LrNIT 31-11-13 DEV SUSP PBU MP 32-30-11-13 I DEV SUSP PBU MP 22-31-11-13 2 DEV SUSP ALASKA ISLAND I EXP SUSP MILNE POINT UNIT B-02 DEV SUSP MILNE POINT U~IT A-03 DEV SUSP MILNE POINT UNIT N-01B DEV SUSP NIAKUK 4 EXP SUSP NIAKUK 5 EXP SUSP MILNE POINT UI~IT C-16 DEV SUSP PRUDHOE BAY UNIT Y-22A DEV SUSP PT MCINTYRE P2-59 EXP SUSP PRUDHOE BAY I/NIT S-10A DEV SUSP NORTHWEST MILNE I EXP SUSP PRUDHOE BAY I31~IT U-01 DEV SUSP PRUDHOE BAY I/NIT Z-32A DEV SUSP NO POINT I DEV SUSP STATUS DATE 4/15/80 10/11/80 4/29/81 12/24/80 4/15/81- 4/13/81' 2/20/81 1/18/81 2/14/81 6/08/82 5/27/82 12/lO/83 4/27/84 2/17/85 4/18/85 lO/27/93 lO/29/88 12/22/9o 11/o6/91 3/30/92 3./16/92 8/31/93 4/08/94 SECT 23 33 33 07 27 36 05 30 30 11 19 23 30 25 25 10 33 14 35 25 18 19 06 TWP llN 11N 11N 12N 12N 101%] 11N 11N 10N 13N 13N 13N 12N 12N 13N 11N 12N 12N 141~ 11N 11N 13N RNG 010E 012E 012E 012E 016E 01SE 013E 013E 013E 022E 011E 010E 010E 01SE 01SE 010E 013E 01AR 012E 009E 013E 012E 010E PAGE MER U U U U U U U U U U U U U U U U U U U U U U U s/15/94 PERMIT 69-0014-0 69-0104-0 70-0060-0 71-0015-0 75-0058-0 76-0028-0 76-0079-0 76-0080-0 77-0015-0 77-0069-0 78-0102-0 API NUMBER 029-20011-00 029-20047-00 223-20006-00 029-20099-00 029-20176-00 029-20156-01 029-20180-01 029-20233-00 029-20245-00 029-20234-01 029-20356-00 BP SUSPENDED WELLS PRIOR TO 1980 AUGUST 1994 WELL WELL WELL NAME CLASS STATUS SAG DELTA 31-11-16 EXP SUSP PRUDHOE BAY UNIT 33-12-13 DEV SUSP KEMIK I/NIT I DEV SUSP PRUDHOE BAY UNIT H-01 DEV SUSP SAG DELTA 33-12-16 EXP SUSP NIAKUK 1-A EXP SUSP NIAKUK 2-A EXP SUSP SAG DELTA 3 EXP SUSP SAG DELTA 34633 4 EXP SUSP SAG DELTA 28337 2-A EXP SUSP PRUDHOE BAY UNIT TERM C DEV SUSP STATUS DATE 4/28/69 12/20/69 6/17/72 6/22/71 4/28/76 4/30/76 3/30/77 3/23/77 3/22/78 12/27/77 4/25/79 SECT 31 33 17 21 04 26 26 35 10 03 TWP 11N 12N 01N 11N llN 12N 12N 12N 12N 11N 11N R~G 016E 013E 020E 013E 016E 01SE 015E 016E 016E 016E 012E PAGE MER U U U U U U U U U U U - .,... co.s ,v.T,O, co, ss,o, APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend'~, Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extensiOn~. Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other,~ 2. Name of Operator ARCO Alaska, Inc 3. Address P. 0. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface 1102' FNL, 1743' FEL, Sec.31, TllN, R16E, UM At top of productive interval 1102' FNL, 1743' FEL; Sec.31, T11N, R16E, UM At effective depth 11.02' FNL, 1743' FEL, Sec.31, T11N, R16E, UM · At total depth 1102' FNL, 1743' FEL, Sec.31, TllN, R16E, UM 5. Datum elevation (DF or KB) RKB 27 ' 6. Unit or Property name Sag Del ta 7. Well number BP 31 -11-16 8. Permit number 69-1~ 9. APl number 50-- 029-20011 10. Pool Wildcat feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3173' Production 9088' 9094'MD feet 9094'TVD feet 500'MD 500 ' TVD Size 30" 13-3/8" 9-5/8" Plugs (measured) feet Junk (measured) feet Cemented 210 sx Fondu 2475 sx Class G 1970 sx Class G Bridge plugs ~ 500' & 8875' None Measured depth True Vertical depth 82 'MD 3173'MD 9088'MD 82'TVD 3173'TVD 9088'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) None ackers and SSSV (type and measured depth) one 12.Attachments RECEIVED OCT O 7 1987 Alaska 0il & Gas Cons. Commission Anchorage Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation August, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~(/~/)~/~ /.~/-L/z//-/.,i Title Associ ate Enqi near Commission Use Only ( J G ) 5A2/104 Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearanceI /-- ~lit,ness reinspect,Jon prior 'co Sept. ember, 1988 'co check for removal ol- e)[~os iron post., rat. hole cover, and general pad cleanup. Approved by I~¥ l~lN~ll: ~ ~[~ .... .> .mmissioner Form 10-403 Rev 12:~-8~ .............. ~ by order of the commission Date / (~) "' Submit in triplicate~_ SAG DELTA BP 31-11-16 APPLICATION FOR SUNDRY APPROVALS On July 31, 1987, an AOGCC representative inspected this suspended well's location and found debris scattered around the site, the rat hole uncovered, and an iron post exposed on the east end of the pad. Therefore, ARCO Alaska, Inc., requests an extension of time to correct these deficiences. ARCO Alaska, Inc., also requests an extension of "suspended" status for the Sag Delta BP 31-11-16 well along with an exception to the surface plug requirements of 20AAC25.110(C). The well is presently scheduled for abandonment in 1988. RECEIVED SA2/IO4a 10/5/87 OCT 0 7 1987 Naska Oil & Gas Cons. Commission Anchorage Telecopy No. (907) 276-7542 Septe~mber 25, 1987 Mike Winfree ARCO Alaska, Inc P 0 Box 1~0360 Anchorage,~- AK 99510'0360 Re: Location clearance inspections Dear Mr Winfree: On July 31, 1987 a Commission representative inspected several locations for final clearance purposes. Six of the locations did not meet the requirements of 20 AAC 25.170(a). Since it is doubtful that the deficiencies can be corrected before the locations are uninspectable for this year, the Commission will require a form 10-403 for each location requesting a time extension per 20 AAC 25.170(b). Following is a summary of locations inspected and deficiencies noted: Debris still scattered around location. Rat hole uncovered and iron post exposed on east end of pad. West Mikkelsen State Debris still scattered around location and rat hole uncovered. West Sak River State BI0 Pits need to be filled. Mike Winfree ARCO Alaska, Inc September 25, 1987 Page 2 Area around marker post needs to be filled. Winter Trails.. ~.~.3 Area aroun, d marker post needs to be filled. Winter Tr'ai!p,~ ~4 Area around marker post needs to be filled. Sincerely, /? Lonnie C Smith Commissioner jo/A.RAD.50 M EM ORAN State )of Alaska ~. ALASKA OIL AND GAS CONSERVATION COMMISSION TO: i~ Cha£tmanC' V. Chatter,~R~ ~,,~"~ .{-~,, .....(~'C DATE: September 16, 1987 FILE NO: 'D. EWS. 67 TELE'PHQNE NO: THRU: Lonnie C. Smith ~ii ?" SU BJ ECT: Co~iss loner Edgar W Sipple, Jr Petroleum Inspector FROM: Location Clearance ARCO Sag Delta (BP 31-,11-16) Permit No. 69-14 Exploratory Sec 31, TllN, R16E, '?t987: I traveled this date wtth ARCO representative tee :to Delta BP 31-11-16 to 'inspect a suspended ~ell and location cleanup. There was trash around the well and along the river line. An iron post was,~sticking up on the east end of the pad. The well sign was correct and legible. The rat hole was not covered, Photographs attached to this report verify the above conditions. i filled out an AOGCC suspended well and location report which is attached; .... In summary, I recommend to the Commission that the above discrepancies be taken care of before approving ARCO's Sag Delta BP 31-11-16. ' ' ' Attachment 02-00IAi(Rev. 8~85) Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFOrmATION: Operator ~ ~o · Da%e Suspended -_~r_~~ Address Surface Location of Well Permit No. ~Ft. F ~ L, ~F . F ~' L AP1 No. 50 Sec. , T jJ.' e'., Unit or Lease Name Field a Pool' ~_~7~f~.~'(- - '- ' Condition of Pad . .~~ $~.£~ ~,~'~ Condition of Pits Well head - Ail outlets plugged Well sign - Attached to well head Attached to well guard Attached to Information correct ~ No ~ No Cellar - Opened Yes No Rat Hole Open Fil led Yes No Fil led Cove r ed Ye s No Cove red WaterWell - Plugged off Capped Open Explanation Ye S No Ye s No Ye s No Photographs taken to verify above condition~ No Explanaton Work o be done to be acceptable _ _.t _..'" / /~ _ _ _- -. ~.-,t *.'~ ,-, ~ 1':.> ', .~.~.. ,";'~ J L,-.",'_~' .L.'i,; .( ~ ~-'<' ~' '"~ "~ ~ '"': l - ~''' / ~'''/~ This well and 'location is (a~~~) (u. na..¢.ee.ptable") to be ~classified as suspended f.or the period~of ~ ~,.~ 19~ thru ... 7~ £~,__ 19. ~, ' Ins~cted by:~ :. ~., .: ~/" ' Date: 7/O~//~ _ Revised 8/24/82 STATE OF ALASKA ALASKA~',~;L AND GAS CONSERVATION COMMI[ ~WON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension~ Change approved, program ~ Plugging ~ Stimulate ~ Pull tubing ~, Amend order ~ Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. 27' RKB 3. Address 6. Unit or Property name P. O. Box ll]N.~N Anchnrag~; AI~ qq,~lN-N360 ~n ll~lt~ 4. Location of well at surface 7. W~II number 1102' FNL, 1743' FEL, Sec, 31, TllN, R16E, UM BP 31-11-16 At top of productive interval 8. Permit number feet Same as above - Straight Hole At effective dept, h Same as above - Straight Hole At total depth Same as above - Straight Hole 69-14 9. APl number 50-- 029-20011 10. Pool Wildcat 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3173' Producti on 9088' 9094 'MD feet 9094 'TVD feet feet 500' MD feet 500 'TVD Size 30" 13-3/8" 9-5/8" Plugs(measured) : Bridge plugs @ 500', 8875' Junk (measured) None Cemented Measured depth 210 sx Fondu 82'MD 2475 sx Class G 3173'MD 1970 sx Class G 9088'MD Wue Vertical depth 82'TVD 3173'TVD 9088'TVD Perforation depth: measured true vertical None None Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None Oil & G:s Cons. Commission 12.Attachments Description summary of proposal 'z~ Detailed operations program ~ BOP sketch Auqust, 1988 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~b~/~ .~~L, Title Associate Engineer Date /- - Commission Use Only (~G) 181 Conditions of approval Notify commission so representative may witness I Approval No, ~ Plug integrity ~ BOP Test ~ Location clearanceI This location was inspected by our representative on September 4, 1986. A general clean-up and a wel~ sign wilI be required before the summer, 1987 i~snection ,~,~,~,-ove~ co~. ~ ,~ ~ ,~ ~eturn~ by order of Approved by ~,,l~!,~,L ,~l~[[J 1//~"~ Commissioner the commission Date //~'~--'~F~ , Form 10-403 Rev 12-1-15~ [i]~[ ~ S~l'J'lJ~~" Submit in triplicate APPLICATION FOR SUNDRY APPROVALS SAG DELTA BP 31-11-16 ARCO Alaska, Inc., requests an extension of "suspended" status for the Sag Delta BP 31-11-16 well. The well is presently scheduled for abandonment in 1988. ARCO Alaska, Inc., also requests an exception to the surface plug requirements of 20AAC25.110(c). The well has 9-5/8" casing set at 9088' with 8-1/2" open hole below it to 9094' There is a bridge plug set at 8875'. The well has kill-weight fluid ~rom TD to 1500' and diesel from 1500' to surface. There is a bridge plug set at 500'. ARCO Alaska, Inc., requests this exception until the well can be plugged and abandoned. SA/181 'dmr 11-20-86 [xOV 2 i 1986 Oil & Gas Cons. Commission MEMORAN'3UM Stat ' of-Alaska CONSERVATION COl'~viI S~ ALASKA~ GAS Chairm n~/t/v--~ FILE NO' D.EWS.59 THRU: FROM: Lonnie C. Commissioner Edgar W. Sipple, Jr. Petroleum Inspector TELEPHONE NO.: SUBJECT: Location Inspection ARCO Sag Delta (BP 31-11-16) Permit No. 69-14 Sec. 31, TllN, R16E, UM Exploratory Thursday, September 4, 1986: I traveled this date wiChARCO r~preSe~'tattve Mike Wihfree to ARCO Sag Delta BP 31-11-16 to inspect a suspended well and location cleanup. There were old 55 gal drums around well, trash .along river line, an iron post sticking up, no well sign, and the rat hole was not covered. Photographs attached to this report verify the above conditions. I filled out an AOGCC Suspended Well and Location Report which is attached. In summary, I recommend to the Commission that the above discrepancies be taken care of before approving the well for suspended status another year. Attachments 02-001 A(Rev 10-84) Suspe .ed Well and Location Rep 20 AAC'25, ARTICLE 2 FILE INFORMATION: ~- ' 0-pe=~ator- ~ ~ ~/ ~_~~ _C ~/~C~ ;~: Date Suspended Address ~ 1o~.3~0 ~,~C~ ~ q~ ~ ~ Surface Location of Well Permit No. ~ / ~0~ FtJF~ _ ~L, ] 7~ Ft.~ '~ n aPI No. 50~t~- Sec.~l , T~ ~ , RI& ~, ~ M. Unit or Lease Name_ .~G Well No. Field & Pool _ Condition of Pad · · ,, _ Well head - Ail outlets plugged ~ No Well sign - Attached to well head Yes Attached to well guard Yes . Attached to ~, ~U O,., ~z~[ ~ --<'///u ... Information correct Ye s Cellar - Opened ~ No Rat Hole Fi 1 led Ye s ~~ Covered ~ No WaterWell - Plugged off Capped Open Exp la na ti on Ope n ~~ No Fi 1 led Ye s ~ Covered Yes Photographs taken to verify above conditions~No Expla naton Work to be done to be acceptable ~.~ ~~.~../.. ~:,~.,~ _ This well and location is (acceptable) (unaccep_ta~_~ble~ . ) to be ,suspended for the period of 19 thru Inspected by:_. ~/J~a~ \/' Date: ~/~: classified as 19 . Revised 8/24/82 Telecopy No. (907) 276-7542 August 22, 1986 ; Mr~ Randy Ruedrich Drilling Manager ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 Re: 'Suspended Well Location Inspections NW Eileen State No. 1 Put River State No. 1 Exxon Tract Well 19-11-15 W. Mikkelsen State No. 1 Kup River State No. 1 W. Sak River State No. 1 KRU W. Sak SWPT No. 1 W. Sak River State No. 2 Dear Mr. Ruedrich: Per our telephone conversation with .Mike Winfree on August 22, .1986, we are requesting a schedule for this summer when our ~nspectors can accompany your representatives to the above referenced well sites for suspended well location inspections. If you have any questions, please call Harold J. Hedlund at 279-1433. Sincerely, '~--~ Lonnie C. Smith Commissioner jo/A.HJH.26 . ': .. .... '7_.;.August 7 ,- 1986 "=~'~ Mr. Ran.,j Ruedrich - ~:~ Drilling Manager : ARCO Alaska, Inc. -;' P.O. Box 100360 Anchorage, AK 99510-0360 Re: Extension of Suspended Status Delta. State No. 1 Highland State No. 1 Kavtk Unit No. 3 Ugnu SWPT No. 1 NW Eileen State No. 1 Put River State No. 1 Put River BP No. 11-10-14 Put River BP No. 2.10-14 . - ..... Put River BP No. 1-10-14 _ · "f ...~:'.'3 ~ ' ' (907) 276-7542 West Beach State No. 1 West Beach State No. 3 W Mikkelsen State No. 1 W Sak River State No. l W Sak River State No. 2 West Sak No. 15 Exxon Tract Well I9-11-15 ' ~?'":. ~' Dear' Mr. 'Rue&rich: · ~" · ~ A-review of our records shows that the above referenced wells are · i.~;'..~ suspended, and do not have surface plugs. · · : . '~':i': .~- Sec~tion I10(a) of the regulations states the Co,~m.~ssion will, in '-~-: .. its discretion, approve the suspension of a well if the well is capable of producing hydrocarbons in paying quantities or is reasonably demonstrated to have future value as a service well. Section 105(e) states that "[e]ach well to be abandoned or suspended mst be plugged...to prevent the movement of fluid 'either into or between freshwater and hydrocarbon sources and to prevent all other fluid migration within the well bore." In compliance with Section 170(a) of the regulations, "[t]he location of an abandoned well onshore or upon a historically stable island must be cleared within one year following well abandonment .... " Sec:ion 170(b) provides the means for an extension of time if a valid reason exists, and the wellbore is properly plugged. Mr. Randy Ruedrtch August 7, 1986 Page 2 We are, therefore, requesting that you submit Form 10-403, Application for Sundry Approval, with a program whichwill bring the status of these wells~into compliance with the new regulations and provide a schedule for this summer when our field· inspectors can accompany your representatives to the well sites for location clearance inspection. Please call Harold J. Hedlund at (907) 279-1433 if you have any que s t ions. Sincerely, Commissioner - jo/A.HJH. 06/07 October 17, 1985 Ms. Jo Ann Gruber ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Submittal of Form 10-403, "Sundry Notices and Reports on Wells," to Request an Extension of Time for Suspended Wells. Dear Ms. Gruber: It is requested that the Form 10-403 for the extension of time for suspended wells under 20 AAC 25.270(b) be submitted at an early date. The request should include: 1. A request for a one year extension. 2. A reason for the extension of time. 3. A description of future clean-up plans, if applicable. The following wells are included under this request: Delta State No. 1 Delta State No. 2 East Bay State No. 1 Gull Is. State No. 1 Gull Is. State No. 2 Highland State No. 1 Kavik Unit No. 3 Ugnu SWPT-1 West Sak SWPT-1 Kuparuk River State No. 1 West Sak River No. 1 West Sak River State No. 2 West Sak River State No. 3 'Sag Delta 31-11-16 Hemi Springs State No. 1 NW Eileen State No. 1 Prudhoe Bay State No. 1 Prudhoe Bay Unit Term A Prudhoe Bay Unit TRT-3C Put River State No. 1 Ravik State No. 1 West Beach No. 1 West Beach No. 2 West Beach No. 3 W. Mikkelsen State No.'l Kuparuk 28243 No. 1. West Sak River State No. 5 West Sak River State No. 6 West Sak 25590 No. 15 East Ugnu No. 1 Sincerely,_ Lonnie C. Smith Commissioner dlf:A.HJH. 10 · ALASKA OIL AND GAS CONSERVATION COMMISSION ~ 3001 PORCUPINE DRIVE November 9, 1984 / ANCHORAGE, ALASKA 99501-3192 ~ TELEPHONE (907) 279-1433 ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Submittal of Form 10-403, "Sundry Notices and Reports on Wells," to Request an Extension of Time for Suspended Wells. Gentlemen: It is requested that the Form 10-403 for the extension of time for suspended wells under 20 AAC 25.270(b) be sUbmitted at an early date. The request should include: · A request for a one year extension. A reason for the extension of time. A description of future clean-up plans, if applicable. The following wells are included under this request: -- Delta State No. 1 Delta State No. 2 East Bay State No. 1 Gull Is. State No. 1 Gull Is. State No. 2 Highland State No. 1 Kavik Unit No. 3 Ugnu SWPT-1 West Sak SWPT-1 Kuparuk River State No. 1 N. Prudhoe Bay State No. 1 West Sak River State No. 1 West Sak River State No. 2 West Sak River State No. 3 West Sak 25631 No. 23 ~Sa§~iD~lta~31~II-!16!~ NW Eileen State No. 1 Prudhoe Bay State No. 1 Prudhoe Bay Unit Term A Prudhoe Bay Unit TR T-3C Put River State No. 1 Ravik State No. 1 West Beach No. 1 West Beach No. 2 West Beach No. 3 W. Mikkelsen State No. 1 Kuparuk 28243 No. 1 West Sak River State No. 5 West Sak River State No. 6 West Sak 25590 No. 15 East Ugnu No. 1 Yours very truly, Kugle~ Commissioner be:2.K.T BP O1l CorporaTiON P. O. BOX 4-1395 ANCHORAGE, ALASKA 99503 Suly 7, 1969 To: State of Alaska, Dept. of Natural l~sourcas Divis£on of 0tl & Gas Reference: Submission of ~aterial from Wells The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- v__u_t ~,__yver BP_._S~3-1_S:i~s: Dual induction Laterolog Runs 1, 2 and 3 Dual Induction Laterolog Run 1 Put IL~ver ~I: Core analysis data. River ~3: I set D~lll CuttinSs P_ut Ri____ver BP 33.11-13: Core chips BP OIL Corporation P. O. BOX 4-1395 aNchorage, alaska 995103 May 22, 1969 To: Oil & Gas Division Department of Natural Resources Reference: Sag Delta BP 31'11-16 The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- Baroid ppm log Schlumberger Gamma Ray Log Cuttings Samples (1 set) 1 sepia + 1 blue line print 2" = 100' 1 sepia + 1 blue line print RECEIVED DIVISION OF OIL AND GAS ANCHGi~AGE Received ...... _~__ ~__/~ BP Oil CORPORatioN P. O. BOX 4-1395 12I WEST FIREWEED LANE, SUITE 205 ANCHORAGE, ALASKA 991503 TELEPHONE 277-1422 May 27, 1969 0-00098 Mr. Homer L. Burrell, Director State of Alaska Department of NaturalResources Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Sir: In reply to your letter of May 21, 1969, we attach herewith a summary of casing and casing cementation data for wells Put River No. 1, Put River 33'11-13 and Sag Delta 31-11-16. Very truly yours, FGL:hw Enclosure BP OIL CORPORATION F. g. Larminie . Area Manager RECEIVED MAY g 9 I969 ANCtt~,A~E PUT RIVER NO. 1 RECEIVED 9 1969 DIVISION OF OIL AND GAS ANCHO~GE CASING WT/FT GRADE DEPTH STAGES DV 1st STAGE SLURRY 2nd STAGE SLURRY 20 94 H40 927 1 1800 sacks Fondu/Fly Ash 13-3/8 61 J55 1857 2 668 885 sacks 'G' 620 sacks 'G' 9-5/8 47 N80 797~. 2 56,75 660 ~sacks 'G' 695 sacks 'G' 10% gel 7 29 N80 92Q4 2 6589 712 sacks 'G' 18% salt 475 s~cks 'G' with 10% gel CASING WT/FT PUT RIVER BP 33-11-13 GRADE DEPTH STAGES DV 1st STAGE SLURRY 2nd STAGE SLURRY 30 Stove Pipe 70 1 - 150 sacks Fond~/Fly Ash --- 13-3/8 61 J55 3219 2 1272 1050 sacks 'G' Unable to cement - annulus froze 9-5/8 47 N80 8912 2 5483 865 sacks 'G' 18% salt ! 700 sacks 'G' 10% gel (Annulus) 2 29 N80 9822 2 6541 640 sacks 'G' 18% salt 470 sacks 'G' 10% gel CASING WT/FT GRADE DEPTH S 1st STAGE SLURRY 2nd STAGE SLURRY 30 Stove Pipe 82 1 - 210, sacks Fondu/Fly Ash --- 13-3/8 61 J55 3173 2 631 1650 sacks 'G' 825 sacks 'G' 9-5/8 47 N80 9088 2 5500 870 sacks 'G' 1100 sacks 'G' 10% gel OIL A~D GAS !lay 21, 19'59 .., Mr. F. C. Larman~e ~P Oil Corporation P. O. Box 4-1395 Anchorage, Alaska Dear Mr. Larmante: Ia revtevtna the records of ca, tag and cemenating procefl~res ~ your wells on the ~h ~lope it h~ been ~iced tha~ there ~e been where ~he ~un~ o~ ce~nt u~ed on a caaing w~ no~ reported. ~,.ere are other ~~ces where t~-~age j~b~ were perfo~d and no no'~a~ion was ~de ~ to the ~un~ through the .~e or ~h~ $~age collar, l~atiou of ~he stag~ colla' identified..: Item~ Z5 and 26 on £he Well Completion P~eport, Form P-7, spectfically r~ir~'~ht~ ~omti~ as ~lai~d ~ ~ht "in~c~ims'~ on the r~er~ Would you kindly furnish thia' office w~th a s~~ of casing and ca~ing cern/rating Jobs ~tth full details'for the follow~ wells: 1. Put Rlver lto. 1 2. Pu~ River 33-11-13 3. Sag lliver 31-11-16 Very truly yours, RBL:Jm l~mer L. Burrell D/rector /! STATE OF ALASKA : : ?ee o.thcrin-[ ,' HLB~'~ ~, WE~L COMPLETION OR RECOMP~ETION REPORT AND ~OG'* I . ...... ~ .... BACK . ' nESVR.,~ Other.· S :nded 8. UNIT,F~ OR ~$E N~~ EN WELL P. 0. Box A-1395~ ~chorage, Alaska 99503 : ' S e ction ::,3 i, ~ At ~otal depm )---- direCtional.survey to be run .... :.' ~ dur2ng future operations ' ~. ~t%~o. Mar 7 1969 I Apr.22,1969 ~ ~pr~l 28. 1969 IApprOx. CR.~ ;~'9~ KB '.27~ ~8~ .. 9.56' 18.,]T~ ~H, ~ & TVD~9. pLUG ~CK M & ~ ~. ~ ~LT~LE CO~., 121. ' INTERVALS DRILLED BY , ~.{~PRODUCING IN~VAL(S), O,F ~IS' CO~TIO~O~, B,O~OM, NAME (~ AND ~)* ,, ~ W~S DIRE~O,NAL :,. SURVEY HADE ~CK~ SET (MD) -- 28. PERORATIONS OPEN TO PRODUC~ON (Interval, size and number) 29. "ACID~ SHOT, FR~C'T'U~, C~T SQuE~ZE;?'~C; '.' ; . '. .:' : / DIVISION OF OIL AND OAT[ OF T~ST, IHO~S T~ · " ]l~°XE SiZE t~ST~IPROD'N FORIOI~BBL .... [G~CF' l WA~B~. .... '~G~'70~I ~O FLOW ~BING ~AS~G P~S~ [CAL~~ OI~BBL, GA~. WA~B~. IOIL GRAV~-~I (C~.) ~1. DISPOSITION OF GAS (Sold, ~ed lo'fuel, vented, etc.) ' I~ST WITNESSED B~ 32. LISt O~ ATTACHMENTS 33. I hereby certify that th/e~f.j;~egoing and,attached information is cOmplete and correct as determined from allVavailable records SIGNED ' ' TITLE Area Manager GATE May 13:1969 · , _~_ ,C_ l_~'n~nio ........ · (See Instructions and Spaces for Additional Data on Reverse Side) · INSTRUCTIONS General: Thi~*'"*forr~ is ~les~gned for submitting a complete and correct well completion report end log q9 ' i"~ .~ ~'. ~i~'~. all types of>lands.and I~a~es in Alaska. ,.~: .... , ~:.~. Item: ]~: I~d.~cat~ whi'C.~'elevation is used as reference (where not otherwise shown) for depth measure- ments give~ ih cf~er :~:~ .... s~es on this form ~nd in any attachments. -I~ms ~0, an~, 22:: If this well is completed for separate production from more than one interval zone ~t~,~.. (multiple completion), s'o state in item 20, ~nd in item 22 show the producing interval, or intervals, top(s), bottom(s) ~nd name (s) (if any) for only the interval reported in item 30. Submit a separate're~rt (page) on this form, adequately identified, for each additional interval to. ~ seperately' produc~, show- ing fhe a~itional data pertinent to such interval. :' :' ' It~m]f: "S~cks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing an~ the location of the cementing tool. J,,.. Item ~: Submit a separate completion re~rt on this form for each interval to ~ separately produ~. . (~ instruction for items 20 and 22 above)~ OF FORM'ATION TESTS INCLUDIN(I INTERVAL' TESTED, P~URE DATA AND'RECovERIES-- OF OIL, GAS. 34. SUMMARY 35. GEOLOGIC MARKERS ·~ i WATER AND MUD' . ~ · ' ' NAME · · ~ MEAS. DEP~I~[ T~RUI~ VlflRT,' , .. . . · .: .. , . ,, , , , , ' , Provision ti ., ' ' . Base Cretaceous 8910' · :; ,~ Base' Permo- ' ,, ' Triassic Shale 9050' ' ' MisS'issiplpian 9050 ' - .... ~ '., ; ~ ' ;,,· ' ,, , [ , "' ':' ' ' ' , . , · , : ,.. ', . ', , . .r ' ' ' } · ' ' ' ,, , ' 36; CORE DATA, A~'r~cI[ BRIEF DESCRIPITIOIffS OF LITHOLOGY, POROSITY, FHAC..TURESi APPARENT .DIPS ' · · ' '- AND:DETECTED SIIOWS ,OF OIL, GAS OR WATEi{. : ',- , ' , , , . ~ i i ! ~ ,. ~. . · ~ !. . , , , , , , . ' , " ' . , , , Nil ':: ' , i. , ,,~ . ,, , · . . , ,' , ; · ,, , , · , - · , ,, . . '/ STATE OF AI. ASKA SUBMrr IN DUPLICATE OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF :DRILLING AND WORKOVER OPERATIONS 1. O~L ~ GA8 WELL [] OTHER w~.~L Wi 1 d J, N~E OF OP~TOR BP 0IL C0~0~TION 3, kDDRESS OF P,~0.BOX 4-1395~ Anchora~e~ Alaska 99503~ 1102' SNL, 1743' WEL, Section 31, TllN, R16E, UPM -~. APl NUMEmCAL CODE 50--029--20011 6. LEASE DESIGNA~'i~ION AND SE1RIAL NO. ADL 28343 7. IF INDIA]~, ALOTTEE OR TRIBE NAME 8. LrNIT,FAIR~ OR LEASE NA3~E Sag Del~;~ ~ BP 31'1.1-16 10. ]fiEl~D A.ND POOL, OR IVILDCAT Wildcat 11, SEC., T., R., M.. (BO'I'TOM HOLE OBJECTIVE) Section 31', TllN, .R16E, IIPM 12. PERMIT NO. 69-14 --- , 13. REPORT TOTAL D~TH AT F2~D OF MON/~rI, CI~NGES IN HOLE SIZE, CASING ~2qI) C~2VIF2~/qNG JOBS INCLL'DING DEPTH SET A/krD VOL~ USED. PER~O~TIONS. TESTS A/ND RESULTS. FISHING JOB~. JUNK IN HOL~ A2~D SIDE-TRACKED HOLE ,~ND ANY OTHER SIGNIFICANT CI-tA~ IN HOLE CONDITIONS. April 1969 1st - 4th 5th - 22nd 23rd 24th - 27th 28th HLB TRM 70KG Nippled up. Repaired BOPs. ~/ FILE Drilled 12-1/4" to 9094'. Conditioned hole. Ran Schlumb~~-t~. to 0 8' cemented, with 1970 sacks~n two, Stages. ,~ippled up. Set bridge plugs at 8875'L a~d500' ~n~L~spended operations. Rig release~X~Z~O~~April 28. Rigging down and moving. 29th - 30th RECEIVED MAY 16 1969 DI¥1$10N OF OIL AND OAI 14. I hereby certify that is true and SXGN~D ~TL~ DA~ MAY 1 A _ 1 q 69 . NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in dupJJcatr: with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. C0NF DENT]AL BP .~SKA INC. API ~50-029-20011, Permit #69-14 Well History Spud 36" hole w/dry bucket 3/5/69. Drilled to 83'. Set 82' 30" conductor (welded). Drilled 12-1/4" hole to 842', opened to 17-1/2". Drilled 17-1/2" hole to 3279'. Ran and cemented 61# J55 13-3/8" casing to 3173'. Cemented 1st stage w/1650 sx of Class G. 2nd stage 825 sx Class G. Fitted and tested BOPs. Drilled 12-1/4" hole to 9094'. Ran Schlumberger logs FDC, DIL, BHC/GR, HRD, PML, and VS. Ran 47# N80 9-5/8" casing to 9088'. Cemented 1st stage w/870 sx Class G, 2nd stage 1100 sx Class G. 10% gel. Bridge plug set at 8875' and 500'. Well suspended. C.gring NIL Testing NIL Velocity Survey April 27, 1969 Rig released 2100 hours, April 28, 1969. ];)l¥11~lOlq OF OIL AND GAS Form P--3 B~EV. 9-30~67 & "Sub~equen~ Reports" in Duplicate STATE O,F ,~LASKA OIL AND GAS CONSERVATIONi COMMITTEE S.UNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PEH1VItT--" for such prol~osals.) OIL [~ OAS Wildcat WELL 2. NA1VIE OF OPEKATOR BP Oil. Corporation "Intentions" in Triplicate - ~CTLY CONFIDENTI~ /J HLB ~ ~I 50-029'20011 OKO ~ ~. ~sE m~NA~ON ~m SEmeN.. --~- ~ L~ HWK ~ ~L-28343 REL 3. ADDRESS OF OPERATOR P. 0. Box 4-1395, /~chorage, Alaska 99503 4. LOCATION O,F WELL At surface 1102' SNL, 1743' WEL, Section 31, TllN, R16E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc. Approx. GR 20' MSL- KB 36' MSL 8. UNIT, FAR~[ OR LEASE NA1HE : Sag Delta 9~ :. BP 31-11-16 ' i0. F~.~r__ZD A~TD FOO.L, OR WILDCAT Wildcat OB~:~CTIVE) SeCtion: 31 ~ TllN, R16E, UPM -_ Check Appropriate Box To I~nd;i,cate Nature af N~fi'cq~, Re~rt~,;or'~:Oflt,er ~Data :.f NOTICE OF INTENTION TO: SUBSEQUENT REP0a~ OF: FRACTURE TREAT MULTIPLE COMPLETE FRACTURE':iTRE'~TM'ENT , i ALTERING CASING ,~OOT oR AcI~,,E -- A,AN~0N' SHOOTING, RZP*IR WELL CHANO~ PLA~S (Other) (No~: :Re~0rt results, of multiple eom~?~tion on Well {Other) ComPletiOn,~r Recompl~tion R'4Port and~g form ) r ' I ' n'~'' ~5~ ~sc~mz [,noeosz~ o~ CO~LZ~ZV O~Z~X~[O~S (Clearly state all pertinent details, and give proposed work. Suspended ~o enable ~ ~o move o~ location before "~rea~-up~'". ~ The~ ~O~e ~,~:1s cased to within 6' of total depth and status is as follows.`=`. ':" ~D 9094~ ~n ~2 ~/4" ho~e. 9 5/8" ca~n~ 47 ~b/~ ~-80 Bu~ess ~o 9088~. ~;,~:Cemen~ed ' =" in two stages with Class G cement, Cleaned out wm~h 8 !/~ ..... Drillable bridge plugs set at 500' and 8875 , Fluid .~n. c~sing~: /'DieSel oil surface to 1500'; 10 lb/gal mud from 1500' to 9094', Wellhead: one 2" x 5000 psi side arm valve and flange ..... -- one side arm fitted with blank flange one 10" x 2 1/2" 5000 psi flange fitted with tree cap and needle valve DI¥1S~ON OF OiL AND GA5 16. Ihereby eer ~/~.~/g°ing l~'true and correct TITLE Area Manager April 30, 1969 See Instructions On Reverse Side Approved' Copy. Returned ,, Form P--$ REV. 9-30-67 STATE OF ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in. Duplicste OIL AND GAS CONSERVATION ,COMMITTEE SUNDRY NOTIC'ES AND REPORTS ON WELLS not use this form for proposa, l$ to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) OIL [-~ OJ~8 ['-] OTHER WELL WELL Wildcat 2. NAME OF OPERATOR BP Oil. Corporatip~ 3. ADDRESS OF OPERATOR P. O. Box 4-1395~, Anchorage, Alaska 4. LOCATION O,F WELL At surface 1102' SNL, 1743' WEL, Section 31, TllN, R16E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc. Aooroxqmntmlv GR 20' MST, 14. KB 36' MSL ,:iLE , , ~. IF INDIA_N, ALLOTT~ OR TRIBE NA2Vi.E - S. UNIT, FAm~ OR LEASE NA~E Sag Delta 9. WELL NO. 31'11-16 ' 10. FIELD A~,D POOL, OR WILDCA. T W~tdcat 11. SmC., T., R., ~., (B~M O~E~IVE) ' TllN.. Rt6E: UPM . P~T ~ ~ .~ 69.-14 - - ' Check Appropriate Box To Irnd:i,cate Niature of N~ofice, Report, or Other 'Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ] I ABANDONS REPAIR WELL ~ I CHANGE PLANS ~ Other) Suspend SUBSEQUENT REPORT OF: WATER SIIUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMENTs (Other) NOTE: RePort results of multiple completion on Well ompletion or Reeompletion Report and Log form.) 15, DESCRIBE PROPOSED 0R COMPLETED OPERATIONS (Clearly state all pertinent details, and give.pertinent dates, including estimated date of starting an~' proposed work. We propose to suspend our well BP 31-11-16 to enable the rig to be moved off this location before "break-up." We will case off the open hole section, leaving mud inside the casing to 1500' and diesel oil from this point to surface. The well will be capped with a blank flange complete with a pressure, measuring point. PIVi$1ON OF OIL AND GA~ CONDITIONS OF APPROVAL, IF A~: Area Manager DATE DATE April 18, 1969 See 1,nstrucfions On Reverse Side Form No. P--4 REV. 9-30-67 STATE OF ALASKA OIL AND GA8 CONSERVATION COIW~IIIEE MONTHLY REPORT OF ~DRILLING AND WORKOVEiR OPERATIONS OIL ~ GAS [~ WELL WELL OTHER 2. NAtVIE 'OF OPERATOR BP 0il Corporation 3. ADDRESS OF OPEIIATOR Wildcat P, O. Box 4-1395, AnchoraKe, Alaska 99509 'LO:CATION OF WELL 1102' SNL, 1743' WEL Section 31, TllN, R16E, UPM SUBMIT IN DEPLICATE 5. AP1 NUA{ERICAL CODE 50-029-20011 LEASE DESIGNATION AND SERIAL NO. ADL-28343 ?. IF INDIAN, ALOTTEE OR TRIBE NAAIE 8. U~'IT,FA/~M OR LEASE NA_ME Sag Delta 9. WELL NO, BP 31-11-16 10. FIFJ.r) S_ND POOL, OR WILDCAT Wildcat 11. SEC , T., R., M., (BOSOM HOLE OBJECTIVE) SectiOn 31 TllN, R16E, UPM 12. PERMIT NO. 69-14 REPORT TOTAL DEPTH AT END OF MONTH, CHA_NGES iN HOLE SIZE, CASING AND CEIViENTING JOBS INCLUDING DEPTH SET AND VOLLrNIES USED, PERFORATIONS, TESTS A/ND RESULTS, FISHING JOBS, JLrNK IN HOLE AND SIDE-TRACKED HOLE A. ND ANY OTHER SIGNIFICAl%TT CI4A~ES IN HOLE CONDITIONS. HLB ~ TRM . _ STRICTLY CONFIDENTIAL OKG .,,~ March, 1969 1st - 6th 7th - 28th 28th - 31st Rigging up Drilled 12 1/4" hole to 842' Opened hole to 17 1/2" Drilled 17 1/2" hole to 3279' Ran 13 3/8" casing, to 3172" and cemented with 2500 sacks (2 stages) KLV HWK REL _FILE Area Manager DATE April 8, 1969 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. CONFIDENTIAL TO: FROM: MEMO TO THE FILES O. K. Gilbreth, Jr.~ Re: Field Trip Sag Delta 31-11-16 On March 21, 1969, Homer Burrell and I arrived by State chartered aircraft at BP Petroleum Company's Sag Delta 31-11-16 location at approximately 3:20 p.m. The security man on duty met us at the plane and escorted us to see Mr. Bob Haskins the BP supervisor in charge. We told Mr. Haskins we wanted to look over his operation% with particular emphasis on checking blowout equipment. He advised that they had been s~dded only a short time and were having trouble in gravel. Surface casing had~een set and a preventer stack was not yet in place. We did not check further ex~'ept to ascertain that conventional high pressure lines with mud-kill as well as positive and adjustable bleed-offs would be installed. The BOP's were on location. There was no sign on the well. We were advised that ARCO (Lake State #1) was running about two weeks behind BP and had not yet set surface casing. They were having gravel troubles also. We left location at 4:15 p.m. for Dead Horse. OKG:jm Form No. P--4 lq;E-V'. 9°30-67 STATE O,F ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WORKOVE.R OPE:RATIONS 0IL ~-- GAS ~ WELL L__J WELL~ OTHER Wildcat 2. "NA2V[E OF OPEP~ATOR BP Oil Corporation ADDRESS OF OPER, ATOR Anchorame..Alaska 99503 P. O. Box 4-1395 '~. LOCA~ON O~ wFJ~L 1102' SNL, 1743' WEL, Section 31, TllN, R16E, UPM SUBMIT IN DEPLICATE ) ~--~I NIflViERICAL CODE 6 ~0~029-20011 · LEASE DESIGNATION AND SEiRIAL NO ADL'28343 7. IF INDIAN. AI-,OTT'EE OR TRIBE NAME 8. UNIT,FAI~¥I OR LEASE NAAIE Sag Delta 9. ~v~.L NO. 31-11-1~ 10. FIEJ~ A-ND POOL. OR WILDCAT Wildc~ 11. SEC., T., R., 1%{.. (BO/~POM HOLE OBJECTIVE~ Sec. 31, TllN, R16E, UPM 12. PEI~MIT NO. 69-14 //,4 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IANGES IN HOLE SIT--,E, CASING A/ND CE!ViF_~TING JOBS INCLUDING DEPTH SET AzNq) VOLU1VIES USED. PEEFORATIONS, T~STS AND 1R~ESULTS. FISHING JOB~. JUNK IN HOLE AND SIDE-TR~CKED HOLE AND A.NY OTt-IEI{ SIGNIFICANT CI-IA~N~F~ IN HOI.~ CONDITIONS, ~ February 1 - February 28 OKG Kt.V STRICTLY CONFIDENTIAL HWK ,. REL : Moving in and rigging up. FILE .--- 'Drilled 36" hole with dry bucket to 80 ft (b.r.t.). DIVISION OF Oi~ AND ANcI-:c,L~.:{ 9E GAS correct 14. I hereby certify that lng is true/md, · SIGlXTED · NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. February 11, 1969 Sag ~lta Noo 31-11-16 BP Oil Corporation, Operator ~. F. G. Larmante Area ~aaager BP Oil Corporation P. O. Box 4-1395 ~c~ra~e~ Alaska 99503 ~nclosed ts a copy o~ the Alaska ~par~n~ off Fish and G~ Very ~ruly yo~rs~ ~:ja Ho~er L. ~urrell Director FORM FG - 74[REV 2-67) MEMORANDUM TO: [-- Homer L. Burrell, Director Division of Oil and Gas 3OO1 Porcupine Drive Anchorage, Alaska 99504 State' of Alaska DEPARTMENT OF FISH AND GAME FILE NO: DATE : February 6, 1969 TRM ~ KLV .... ,?.? -- FROM: Robert J. Wienhold/~ Habitat Biologist ADF&G, Anchorage ! SUBJECT: Sag De 1 ta No. 31- 11- 16 B P Oil Corporation, Operator Sec. 31,TllN,R16E, UPM In reference to the subject well, the Alaska Department of Fish & Game requests the following wildlife stipulations be attached to the permit to drill .' 1. Prior to the begining of drilling, a sump of suffici.ent size to ~ontain all waste fluids will be constructed. The sump must be lined with material impervious to oil at all seasons during the year. 2. Prior to the begining of drilling, adequate ditching shall surround the area, taking advantage of the natural topography of the land to insure that any spill that might occur will be drained into the sump. 3. Prior to abandonment of the site, the sump must be cleared of ~ll oil and covered. 4. The operator must dispose of all' refuse, waste, debris, garbage, pallet board, visqueen, barrels, etc. by being burned and buried. 5. No stream or body of water will have any foreign material added to it. This includes vegetation, soil, petroleum products or refuse. 6. Failure to comply with the above conditions will result in revocation of this permit-and subsequent legal action. Statement: The foregoing provisions do not relieve the 'le~e and/or his contractors or assignees of any responsibilities or provisions required by law or regulations of the State of Alaska or the Federal government. RJ W: kh RECEIVED FEB ? 1969 DIVISION OF OIL AND OAS ANCI, IO&~E K, eiti~ i.',. M'ilter, Governor DIVISION OF ()IL AN~) GAS February 3, 1969 'P,e: Sag ~]elta :o. 31-Il.-16 GP 0il Corporation, operator I~r. F. G. Area BP Oi P. O. Box 4~1395 A~)chorage,. Al.aska 99503, Dear Sir: Enclosed pl. ease 'find the apt)roved applicatio~ for permit '~o drill the r~fere~ced well. .Well sa,mpl~s core c~')ips are require~. Alaska .Department of Fis~~) and Ga;~e stipulations, whe~'~'~ receivea, will be fo~tarded to you and will become co~di, tto~:)s o.f subject permit. Ir~ the event of abando~')me'nt, please ~ot. ify this office adequately ir~ adv.a~ce so that we may have a Nit,mss present. Yery 'tru 1,y yot~ r s, Homer L. ~'Jur'rel I ~Ji rect.or Thomas ¢~. lqarshall, Jr. Ac"'t~ng" ~''' u.i rector E.~'lc 1 osure FORM SA- ~ B ,, MEMORANDUM TO: ['- ~oe Blum Det~ar~t of Ftsh and Game State of Alaska DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL ANO GAS FROM: ttomer L. ~rrel 1 Director Thamas R. Marshal. l, . ', Acting Director ,.~ .,, DATE : SUBJECT: February Sag Delta ~. 31-11-16 BP 0tl Corporetton, operator Please ti:nd enclose~ an application for permit to drill a~ location. Plat for the above capttone~ well'..Please advise tf there are. any Fish aa~ Game sttpul, ations yea wish to have a~ar oe the permit. Please ret~er~ece ~r reply as, captioned above.. Enclosures FORM SA. ~ B 'MEMORANDUM TO: F- l.~lustrial Slfe~ I~sl~:t. or Depar~t of Labor FROM: t~jer L. Burro11 Director TNmi,~ R. i~rsha11, ~r.. State of Alaska D£PART~ OF ~IATUR~ RE~ES DIVISION OF OIL AND GAS DATE : SUBJECT: Febru~ 3, lg6g Sag Oelta go. 3'1-11-16 BP 0tl Corporation, operator Inclosed is a copy of the a, ppro~ed application to c)rtll for the above cap ti oned tee 11. FORM SA- I B ~,, MEMORANDUM TO: [-' Dale Wellington Deputy C:eeal ss Joker State of Alaska DEPAR~ OF NATU~L P-aE~U~ES DIVISION OF OIL AJJD GAS FROM: DATE : February 3, 1969 Homer L. Butte11 Director lbomms R. gars~ll, Jr. Acting Director -. SUBJECT: Sag Delta No. 31-11-16 BP '0tl Corporation, operator E.closed are the a,~ro, ved &ppltcatton for permit to drill, a plat, ami a check 'in the ama'ant of $50 for fi ling fee. T.~.~ E~¢l, osares US SD 31-11-16 BP OiL CORPORATION P. O. BOX 4-13~95 117 WEST FIREWEED LANE, SUITE 205 ANCHORAGE, ALASKA 99503 TELEPHONE 277-1422 January 28, 1969 State of Alaska Department of Natural Resources Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Thomas R. Marshall, Jr. Petroleum Supervisor Gentlemen: Sag Delta 31-11-16 Please find the following enclosed herewith: 1. Application for a permit to drill the above well on the Arctic SlOpe, Alaska 2. Four copies of the surveyor's plat showing the location of the proposed well 3. A check for $50 to cover the permit filing fee We should be obliged if you would process this application as quickly as possible as we propose to begin drilling operations on or about February 14, 1969. FGL:raw Enclosures cc: Mr. J. W. Martyr Yours very truly, BP OIL' CORPORATION · F. G. Larminie Area Manager Form REV. 9-30-67 ,' SUBMIT IN TRr~,~ATE '~'~ (Other instructions on`< reverse side) STATE OF ALASKA AP1 50-029-20011 5. OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR .PERMIT TO DRILL, DEEPEN, OR PLUG BACK IR, TYPE OF WORK DRILL D~ DEEPEN F-I PLUG BACK [--] b. TYP~ OF WELL W~LL 2. NAME OF OP~TOR BP 0~1 CorporatSon P. O. Box ~-1395, ~chorage, Alaska 99503 ~ 4. BOCATION O~ WgLL ~ surface 1102~ 8~L 17~3~ ~EL Sec 31, Tll~, R16E, ~ At proposed prod. zone Same 13. DISTANCE IN MILES AND D~ECTION F~OM NEAREST TOWN OR.POST OFFIC~ Approximately 117 miles N.E. of Umiat 6. LEASE DESIGNATION AND .~--~tiAL NO. 7. IF I1NTDLAI~, ~I~I~D~'i'EE OR TRIBE NAA~E 8. UNIT~FA~NI OR LEA~SE NA/VIE Sag Delta 9. WELL NO. 31-11-16 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC4 T., R., 1Vt., (BO%~rOM HOLE O~kIECTIV~.) Sec 31, TllN, R16E, UPM 1~. 14. BOND INFOKMATION: TYPE Surety and/or No. 15. DISTANCE FROM PROPOSED* 3537 ' from west~rn-i18- NO. OF'ACRF-S IN LEASE LOCATION TO NEAREST boundar - of lease ' PROPERTY OR LEASE LINE, FT. ' Y ' I " ' ' (Also to nearest drig, unit, if any) ' i 18. DISTANCE FROM PROPOSED LOCATION* ' ~19. PRoPOsED DEPTH TO NEAREST WELL DRILLING, COMPLETED, ~ OR APPLIED FOR FT I ' ~ 7.8 mi. from ARC0/Hubl Delta State #1! 10,000' A~nou~t ' r'/. -N-O/A6R~ ASSIGNED TO THiS WELL 20. RoTAR~ OR 'CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT. CR, etc.) 22. APPROX. DATE WORK WILL START' Approx. GR 20' MSL KB 36' MSL . February 14, 1969 23. PROPOSED 'CASING AND CEMENTING'PROGRAM SIZE OF HOLE l' SIZE OF CASINGt WEIGHT'PER FOOT ~ GRADER I S~jA~iiLNG DEPTH.. 5 :" ~UANTITY 36 30" S~ove oioe 40 To '~Urface - 26 20" 94# H40~. 250 To surface 12-1/4 9-5/8" A7~} ~gn ,., 9!00-r :- TO 250.0' SAG DELTA 31-11-16 PROGNOSIS Surf - 4600' Tertiary - Gravels, sands, clays:` 4600 - 8420' ' cret,/jUrassic - Shales 'with ~sa~ds decreasing dOWnwards 8420 - 8460' "Jurassic Sand" - FIRST RESERVOIR 8460 - 8510' Upper Triassic (Shublik) - Shales,.dense l&mestones 8~10 - 8970' . Trias (Sadlerochit) -Sands, minor shales- MAIN RESERVOIR 8970 - 9090' Trias (Permian) - Shale 9090- 10,000' Mississippian - Carbonates, ~nor shale (SEE 'KTTACHED) ~ ABO~ S~ D~B~ ~O~ P~R~: If ~1 ~ ~ dee~n or plug ~, give ~ on present p~u~ive ~ ~d proposed ~w produ~ive ~. If Pr~ ~ ~ ~ill or d~n ~e~2o~lly, give pe~ent ~ on s~bs~a~ ~.t~ ~d m~ ~d ~ue vert~l dep~% G~e blo~ut preventer program. 24. I hereby certify that.~g~~~~ ~ ~'/~~~' DA~ January 28, 1969 S!GN~ ~ ,. / - -- JAN 3 0 i969 DIVISION OF OiL AND GAS ANCHOP~,G E (This space for State office use) STPLES AND CORE CHIPS R.EQUIRI~:D YES [] NO DIRECTIONAL SURVEY REQUIRED [] YES 7 NO CONDITIONS OF APPROVAL, IF ANY: tOTHER REQUIREMENTS: .. A.P.L N-UMEH~CAL CODE ~"0- oz. ef_ 2_00 '~'¥~J~ DI~' ~A R S HA LL, JR. ExecUtive Secretary T~TL~. AJu~ka O~i & (3as *See Incubi°ns On ~~ti~ommiitee SAG DELTA 31-11-16 Dry bucket 36" to 40' and cement 30" conductor to surface. Drill 26" to 250' using brine/polymer mud. Run 20" casing and cement to surface with fondu/fly ash. Drill 17-1/2" to 3000' with brine/ polymer mud. Run 13-3/8" casing and cement to below 20" shoe in two stages. Drill 12-1/4" to 9100' using low fluid loss brine/ polymer or XP 20 spersene mud. Run 9-5/8" casing and cement in two stages back to 1000'. Drill 8-1/2" to TD at about 10,000'. Run 7" liner or full string and cement as required. A mud logging unit will be used and electric logs will be run at TD and inter- mediate depths. Significant oil and gas shows will be tested. Subsequent reports will be filed as required. Approximate spud date February 14, 1969. Blow out preventer program will be 3000 psi WP blind rams, pipe rams and Hydril from the time of running 13-3/8" casing. 3 0 ,DIVISION OF OiL AND GAS 14 23 26 13 24 25 36 18 19 $.0 17 2O 29 4 174~' 31 $2 6 , 5 I I I__ i 21 I 22 -31-11-16 L^T. 70o LONG. 145° I 0'~0,44' 27 Y = 5,951, 174..$4 l X= r26,671.141 33 34 4 ~ i I . SCALE' 1": IMILE CERT I F I CATE OF SURVEYO'R I hereby certify that I am properlY registered and licensed to practice land surveying ~n the State of Alaska and that this plat represents a location survey made byme or under my supervision/ and that all dimensions and other details are correct. Date "' sURvEYC~/ TII N T ION. BP-31'- II. I-6 Located i n NE I/4., PROTRACTED SECTION .Surveyed for B- P EXPLORATION,. USA, INC, Surve'ye.d- by F.M. LINDSEY & AS.S'OC. LAND & HYDROGRAPHIC SURVEYOR:S 2502 West Northern Lights' Boulevard. P.O. Box 4.081 Anchorage ...... PG I 14,47