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172-008
RE: 10-407 for well A-OS • ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Hubble, Terrie L jTerrie.Hubble@bp.com) Sent: Thursday, April 05, 2007 3:32 PM To: Eddy, Andrea (SAlC) Cc: tom_maunder@admin.state.ak.us Subject: RE: 10-407 for well A-05 Andrea, On this one, let's just pencil in the changes on your copy. I'll see that the other in-house copies get changed and request that the State change their copy as well. Thanks for catching these. So on the A-05 10-407, Permit #172-008: Change Box 1 b, Well Ciass to Service (only) Change Box 6, Date Spudded to 03/14/1972 Terrie From: Eddy, Andrea (SAIC) Sent: Friday, March 30, 2007 2:39 PM To: Hubble, Terrie L Subject: 10-407 for well A-05 ~:~l~p NaV ~ ~ 2007 Terrie, in the fast couple of weeks, l have gone over some 20 weft completion reports (from you and Sondra), mostly in order to update Finder. Most of the questions that came up for me I answered by doing some research on my own or by asking Gary Prebie or Dave Douglas. The report for weN A-05 still has two items l need your help on, however. On that 10-407, item 1 b, "well class," has two X's: Both "Development" (the initial class) and "Service" (the current class} are selected. is that intended? We did not know if it was okay to show two classes on a 10-407. Also, item 6, "date spudded," should be "03!14/1972" (not "...1979"). Andrea Eddy Petrotechnical Data Center 907-564-5035 10/10/2007 PBU A-05A (206-128) . Rob, Terrie, Andrew and Robin, Not sure who can best handle this. I am reviewing the completion report for PBU A-05A. A companion report was also sent for the abandonment of the original well A-05. Since A-05A is completed as an injection well an assessment of the primary cementing of strings in/near the reservoir is part of the review. Any available cement assessment logs are also examined. The log available in the AOGCC file is not the correct log. 2 USIT logs were run in the well. The copy I currently have looked at was run on January 4 prior to the major tubular replacements done in the well. Although the well name and API number listed on the log are for A-05A, I believe that the correct name and number should be A-05. The 7" casing examined by this log was either pulled or abandoned below the EZSV subsequently set at -8200'. New hole was not drilled until January 17. The correct log for A-05A was run on January 29 and examined the new 7" liner as well as the tieback string. It would be appreciated if a hard copy of that log could be submitted. Terrie and I recently exchanged messages regarding when work on an "old" well (in this case A-05) ends and the "new" well (A-05A) begins. The protocol used by the Commission is that the new well begins when the window is cut and new formation drilled. When drilling permits and sundry notices are reviewed, a "line" is usually drawn across the page with a notation made where the new permit to drill takes effect. It is recognized that the work scope of operations such as accomplished here is complicated. However it is requested that for labeling and naming purposes that work accomplished prior to actually making new hole be credited to the original wellbore. Although it is likely that there are a number of logs in the Commission files that do not conform to the protocol described here, it is not necessary to attempt to reconcile the naming. However, for the future your attention to this matter will be appreciated. Call or message with any questions. Tom Maunder, PE AOGCC _.It.lttl&:n MA'< 2 2 2007 $~""'" , ....... 1 of 1 3/13/20072:57 PM 02/22/2007 Schlumberger NO. 4158 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth r~ d -ro~ Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 U "Ie., Field: Prudhoe Bay Well Job# Log Description Date BL Color CD MPS-33A 11676926 CH EDIT US IT (PDC-GR) 01/31/07 1 1 W-35 11486088 RST 12/15/06 1 1 J-02B 10964121 RST 01/26/05 1 1 C-36A 11209600 MCNL 04/24/06 1 1 04-38 11477734 RST 12/02/06 1 1 A-05A N/A USIT (CEMENT EVALUATION) 01/09/07 1 A-05A 11626272 USIT (CEMENT EVALUATION) 01/30/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 5t?ANNED APR 0 3. Z007 Alaska Data & Consulting Services 2525 Gamoell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: I"JAR 2 ~ Z007 Received by: f\laska Oil & Gas Commission AnCÎlora¡)8 7 . . , ·./1;1 RECEIVED. STATE OF ALASKA . h-ll MAR 0 ~KA OIL AND GAS CONSERVATION COM~SION \\ c; WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ÇI~~~<-;" Alaska Oil & Gas Cons. Commission Revised 03/07/07 ~SCIlr'd. 10-407, dated 10/0412006) .......- 1 a. Well Status: DOil Plugged ~ Abandoned D Suspended DWAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ~ Development D Exploratory D GINJ DWINJ D WDSPL No. of Completions Zero Other , /1.#01 D Stratigraphic ~ Service 2. Operator Name: 5. Date Comp., ~p., or ~t ,..Q1 12. Permit to Drill Number BP Exploration (Alaska) Inc. 01/'!i'.£2007 'fJ4 172-008 I 306-284 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 03/14/1979 50-029-20116-00-00 ( 4a. Location of Well (Governmental Section): 7. Date 1.0. Reached 14. Well Name and Number: Surface: 04/10/1972 PBU A-OS .¡ 1896' FNL, 923' FEL, SEC. 35, T11N, R13E, UM - 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 3077' FNL, 525' FEL, SEC. 34, T11N, R13E, UM . 65.90' j Prudhoe Bay Field I Prudhoe Bay Total Depth: Pool ¡ 9. Plug Back Depth (MD+ TVD) 2966' FNL, 645' FEL, SEC. 34, T11 N, R13E, UM . 11259 ~ + 9245 > Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 654462 y- 5948551 Zone- ASP4 11370 ~ + 9349 > Ft ADL 028287 ~ TPI: x- 649605 y- 5947272 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 649483 y- 5947381 Zone- ASP4 NIA MD DYes ~No 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey NIA MSL 1900' (Approx.) 21. Logs Run: OIL I SP, BHCS I GR, LL-3, FDC I CAL, SNL I CAL, CBL I GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD .. AMóüNT HOLE SIZE Wr. PER FT. GRADE Top .' BottóM Tóp BOttOM SIZE D. PULLED 30" Conductor Surface 99' Surface 99' 36" Cemented to Surface with PF " 20" x 18-5/8" 133# 196.5# K-55 Surface 2278' Surface 2278' 26" 8700 sx PF " (MultiDle Staaes) 13-3/8" x 9-518" 68# 147# N-80 Surface 9814' Surface 7965' 12-1/4" 1625 sx Class 'G' 525 sx PF " 9-518" x 10-3/4" 47# 155.5# N-80 1839' 2015' 1839' 2015' Tieback 100 sx PF II (Top 3 jls 11-3/4" x 9-5/8" Thermocase) 7" 29# N-80 8300' 11360' 7529' 9339' 8-1/2" 485 sx Class 'G' "- 23. Perforations open to Production (MD + TVD of Top and 24. ., 0_: ...... .... ........ ..... Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 4-1/2", 12.6#, L-80 8669' - 10516' 9200',9348',10472' MD TVD MD TVD 25. . .' ÄCII),- iCEMENT .,.. ..... ETc. &::ANNED MAR 2 1 2007 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8770' P&A with 44 Bbls Class 'G' & 6 Bbls Class 'G' 2063' Cmt 13-3/8" Tieback wI 1878 sx Arcticset I 8206' Set EZSV (8230'), Whipstock on Top To Surface Top Job on 18-518" x 13-3/8" wI 2 Bbls AS I 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production NIA Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE+ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet,i!':IE!çE:!S~¡a¡:y~. Submit core chips; if none, state "none". " ~\l;¿'~:¡ ,;..;; l I Å¡;'~ , None \¿.. (t~~-f :~ ...,>,;; ,.A,. t'~f l ~: , trurí\...b3" 'fi;/.2· ¡ Form 10-407 Revised 12/2003 ORIGiNAL CONTINUED ON REVERSE SIDE G 28. GEOLOGIC MARKER 29. RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10802' 8819' None Shublik 10828' 8843' Ivishak 10910' 8919' 30. List of Attachments: Summary of Pre-Rig Work, Well Schematic Diagram Signed Terrie Hubble Title Technical Assistant Date °-107 D 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. PBU A-05 Well Number 172-008 306-284 Permit No. I A roval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mehrdad Nadem, 564-5941 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Digjtal Wellfile W~II Events for SurfaceWell - A-' Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC3 -> A -> A-OS Date Range: 02/Sep/2006 to 29/Dec/2006 Data Source(s): AWGRS Events Source Well AWGRS A-OS AWGRS A-OS AWGRS A-OS AWGRS A-OS AWGRS A-OsA AwCiRS A-OS AWGRS A-OS AWGRS A-OS AWGRS A-OS AWGRS A-OS AWGRS A-OS Date 12/29/2006 12/28/2006 12/24/2006 12/22/2006 12/22/2006 12/16/2006 12/15/2006 10/15/2006 10/04/2006 10/04/2006 10/03/2006 AWGRS A-OS 10/03/2006 AWGRS A-OS 10/02/2006 AWGRS A-OS 10/01/2006 AwGRS A-OS 10/01/2006 AWGRS A-OS 09/30/2006 AWGRS A-OS AWGRS A-OS 09/30/2006 09/27/2006 . Page 1 of 3 Description T/I/O/OO= N/A/O+/O+/O+. Temp= SI. WHP's (pre-rig, Bleed to 0 psi) call in. Well house, F/L, and scaffolding has been removed. T/I/O/OO = BPV/60/100/120. SI. No AL, No well house, rig scaffold over well. WHPs (pre-Rig) Bleed WHPs to 0 psi. Bleed lA, OA & OOAP to bleed trailer # 68-691 to 0+ psi (4 hrs), Fluid @ surface lA, OA, OOA. Final WHPs = BPV/O+/O+/O+ SET BPV PRE RIG API VALVE SHOP ***WHP: % /100/ PSI RIH TO WITH GYRO TOOL. TL = 27' , MAX. ID =1.8" LOGGED GYRO SURVEY FROM 8620' - 200' ***FINAL WHP: 0/0/100 PSI*** PAD OPERATOR NOTIFIED UPON DEPATURE PULL BPV PRE RIG WELL WORK NOT COMPLETED API VALVE SHOP *** WSR Continued form 12-15-06*** T/IA/OA/OOA= 0/80/150/250 CMIT-TxIAxOAxOOA PASSED (Updated AnnComm post Rig ST) BPV set in tubing unable to read tubing pressure, Pressured with 7.8 bbls. diesel, 1st. test annulus lost T=O psi., IA=20 psi., OA=20 psi., OOA=O psi., in 1st. 15 min., lost T=O pSi.,IA=O psi., OA=10 psi., 00A=10 psi., in 2nd. 15 min., Passed, Bleed back to starting pressures, FWHP's=0/ls0/180/1s0 T/I/OA/OOA = X/X/XIX CMIT- TxlAxOAxOOA (Updated AnnComm post Rig ST) BPV set in tubing unable to read tubing pressure, Open permit, Clear cellar, Job in progress, *** WSR Continued to 12-16 06*** SET BPV /PRE RIG T/I/O/OO = 110/70/140/130. SI. WHPs (post MITOOA). No well house Stand by for grease crew to rig off IA valve-- RDMO T/I/O/OO= 0/0/80/40 MIT OOA 1500 psi ** FAILED** on 4 attempts, would not show pressure stabalization, Bled OOAP. CMIT TxIAxOA 2000 psi **Failed** OAxOOA communication(RIG ST) CMIT TxIAxOAxOOA 1250 ** passed** on second attempt. Pumped 5 Bbls Neat,3 Bbls crude to pressure OOA to 1250 psi stopping every 250 PSI for 15 Min. Pumped 11 bbls Neat down IA to pressure T/I/O to 1240/1340/1250/1250 psi. bleed T/I/O = 0/0/80 T/I/O/OO = vac/vac/80/40. Temp = SI. Assist Little Red with MITOOA. During MITOOA, no evidence of conductor producing crude. No bubbling or audible gas. T/I/O/OO = vac/vac/I00/20. Temp = SI. Install Katch Kan (confined space). Installed 30" Katch Kan around conductor. T/I/O/OO = vac/vac/I00/20. Temp = SI. Eval for SC leak detection. OOA FL @ 110'. Cellar is 8'xI2'x6' deep with approx. 5" of fluid in the bottom. The open conductor is full of gravel and oily fluid. A fluid sample from the cellar will be taken to the lab. *** Job continued from 09-30-06 *** Post MIT OOA bleed pressures and rig down. FWP's = 0/0/40/10 T/I/O/OO = 0/0/100/20 Circ-out (Pre sidetrack) Pumped Sbbls meth, 668bbls seawater, 82bbls 60/40, down tubing, through cut, up lA, into A-40's flowline. FP IA w/ 44bbls 60/40 (displacing 44bbls 60/40 out of tubing). CMIT TxIA failed. TxIAxOA communication. MITOOA - Loaded OOA w/83.5 bbls crude and 30 bbls 60/40 meth water. Unable to test per gas and oil bubbling out conductor. FWP's = 0/0/80/20 *** NOTE: Oil in cellar, gas bubbling and oil leaking out of conductor, FO notified *** *** Job continued on 10-01-06 WSR *** T/I/O/OO = 0/0/100/20 Circ-out (Pre sidetrack) Pumped Sbbls meth, 668bbls seawater, 82bbls 60/40, down tubing, through cut, up lA, into A-40's flowline. FP IA w/ 44bbls 60/40 (displacing 44bbls 60/40 out of tubing). CMIT TxIA failed. TxIAxOA communication. MITOOA PASSED/FAILED to IS00psi. Lost xxpsi 1st 15min, xxpsi 2nd 15min for a total of xxpsi in 30 min. Bled pressures to zero. FP A-40's Flowline w/ SObbs 60/40. FWHP's = WELL SHUT IN ON ARRIVAL. SSV CLOSED. PUNCH TUBING FROM 8610' TO 8612' WITH 2" SMALL "PINK" PUNCHER LOADED 4 SPF. STRING SHOT TUBING WITH 2 STRAND STRING SHOT 10' ABOVE AND 2' BELOW PROPOSED CUT DEPTH FROM 8659' TO 8671'. CHEMICAL CUT THE TUBING AT 8669' WITH 3 3/8" SEVERING HEAD WITH 3 3/8" ANCHOR BODIES. MAX TOOLSTRING OD IS 3.375" AND IS RUN WITH 3 x 4" GEMCO CENTRALIZERS. MAX TOOLSTRING LENGTH IS 31.4'. DEEPER DEPTH REACHED ON EACH DESCENT. TAGGED AT 8742' WITH TUBING PUNCHER. TAGGED AT 8749 AND 8759' WITH STRING SHOT. RAN TO 8770' WITH CHEMICAL CUTTER WITH NO BOBBLES. DID NOT GO DEEPER TO AVOID BURYING TOOL IN CEMENT. WELL SHUT IN ON DEPARTURE. SSV CLOSED. Circ-Out http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 3/7/2007 Digital Wellfile AWGRS A-OS 09/27/2006 A.'JILGRS A-OS 09/26/2006 AWGRS A-OS 09/26/2006 AwGRS A-OS 09/26/2006 AIJ\IGR-.S A-OS 09/25/2006 AWGRS A-OS 09/24/2006 AWGBS A-OS 09/23/2006 AWGRS A-OS 09/21/2006 AWGRS A-OS 09/17/2006 AWGRS A-OS 09/16/2006 AWGRS A-OS 09/16/2006 AWGRS A-OS 09/16/2006 AwGBS A-OS 09/15/2006 8.'NGRS A-OS 09/15/2006 AWGRS A-OS 09/14/2006 AWGRs A-OS 09/13/2006 . ,Page 2 of 3 recommended to take place ASAP as to make sure ce. doesn't set up over chemical cut. *****JOB COMPLETE***** *** CONTINUE FROM 09-26-06 *** DRIFT TBG RUN 3.75" SWAGE. SLIGHT RESTRICTIONS FROM 8220' SLM DOWN TO 8400' SLM, WORKED SPOTS UNTIL TOOLS FALL FREELY TAGGED CEMENT BOTTOM @ 8720' SLM *** WELL LEFT S/I *** *** WELL S/I ON ARRIVAL *** (PRE SDTRK) RIG UP SLICKLINE UNIT TO RE-DRIFT FOR CHEM CUT *** CONTINUE ON 09-27-06 *** WELL SHUT IN ON ARRIVAL. SSV OPEN. RAN 3.65" POWERCUTTER. MAX TOOLSTRING LENGTH=16.5'. MAX OD=3.65 WITH 4.1" GEMCO CENTRALIZERS THAT WILL COMPRESS. SAT DOWN REPEATEDLY AT 8240'. DECISION MADE TO POOH. LOWER HEAD OF JET CUTTER RUBBED TO A SHINE. WELL SHUT IN ON DEPARTURE. SSV LEFT OPEN. Job Not Complete. Turn well over to Slickline to clear obstruction. Leaving Surface Rental Equipment on Location for Slickline *** CONT FROM 09-25-06 WSR *** (drift for chern cut, pre sdtrk) DRIFTED W/ 3.25 CENT & SAMPLE BAILER TO 8708' SLM... CEMENT IN BAILER, DRIFTED W/ 2.70 CENT & SAMPLE BAILER TO 8710' SLM- 8730' CORRECTED DEPTH ... CEMENT IN BAILER. PT CEMENT TOP TO 3000#.. GOOD TEST. RDMO *** WELL LEFT SI *** ***WELL S/I ON ARRIVAL*** (drift for chern cut) DRIFTED W/ 3.70 CENT & S-BAILER TO 8701' SLM... HAD TO WORK TOOLS FROM 8210' TO 8348' & 8633' TO 8701' SLM, MADE COUPLE PASSES FROM 8200' TO 8700' W/O ANY PROBLEMS... SAMPLE OF WHAT APPEARS TO BE CEMENT IN BAILER *** JOB IN PROGRESS/ CONT ON 09-26-06 WSR *** CTU #5. PT Cement Plug. *** Continuation of WSR 09/23/2006 *** Set Baker IBP at 8915' ctm. Attempted to PT cement cap twice. First 3000 psi PT attempt lost 272 psi over 30 minutes. Second attempt lost 240 psi over 30 minutes. Performed visual No-Flow test to insure pressure lose was not at surface. Released IBP and POOH. Recovered all rubber elements from IBP. MU BHA #2,3.0" BDN. RIH. Tag 9080'ctm. PUH to 9065'. Rig up and PT cementers. Pump 6 bbls 15.8ppg class G cement. Lay in from 9065' to 8616' ctm. PUH to safety. Hesitate squeeze to 3500psi. Drop 7/8" ball and contaminate with 1.5# biozan. Clean out to 8900'. POOH at 80% chasing to surface. RIH and freeze protect with 60/40 MeOH from 2500'. Trap 100 psi on wellhead at surface. RDMO CTU. Notified Pad Operator of well status. Final T/I/O/OOA = 110/20/0/0 *** Job Complete *** CTU #5. PT Cement Plug. MIRU.Perform weekly BOP test. MU Baker 3.38" IBP. RIH to 8915' ctm. Begin setting procedure on IBP. *** Job continued on WSR 09/24/2006 *** ***CTU #5 Standby on well flowback/safelty.....Road unit to M-pad***JOB INCOMPLETE*** *** JOB CONT. FROM 9/16/06*** RUN 2.30" CENT. 3' x 1 1/2 " STEM, SAMPLE BAILER, SD @ 9022' SLM, POSSIBLE TOC.HAVE SAMPLE OF CEMENT, APPEARS TO BE SLURRY TYPE MIXTURE, GOOD SAMPLE. ***WELL S/I ON DEPARTURE*** ( NOTIFIED PAD OPERATOR) *** WELL S/I ON ARRIVAL *** RU DC#6 FOR D&T W/SB. ***JOB IN PROGRESS, CONT. ON 9/17/06*** T/IA/OA/OOA = SI/O/O/O (Pre Rig Inspection) (Purge Plastic Pak from OOA Void) Unable to Purge Plastic from void OA bled to 0 psi. Removed internal check and installed alemite test fitting. Rigged up test equipment, unable to move plastic packing thru void to bleeder port. Test fluid leaking pass seals, pumped total volume of (1 1/2) gallons. Would not build pressure with bleeder closed. T/I/O/OO= vac/O/O/O Temp= 5/1 MIT T ***FAILED*** to 3000 psi. Pressured up tubing to 3000 psi w/ 2.7 bbls 60/40 meth water. 2nd test results- 1st 15 min lost 100 psi, 2nd 15 min lost 170 psi w/ a total of 270 psi in 30 min. Bled back 2 bbls. Final WHP's= 0/0/0/0 T/I/O/OO= Vac/80/50/105. Temp= S1. (WAG WELL). Bleed WHP's to 0 psi (pre-Cam, pre- RWO). TP unchanged, lAP increased 25 psi, OAP decreased 10 psi and OOAP increased 5 psi overnight. Bled WHP's to Vac/O/O/O psi in 4 hrs and 40 minutes. Monitored for 30 minutes. Final WHP's= Vac/O/O/O. NOTE: There are several studs on the SSV to Master flange that do not meet API spec for thread engagement. T/IA/OA = SI/O/O (Pre Rig Inspection) PPPOT-IC = Still in Progress PPPOT-T = Passed DHD Tech Grant Chiacchia bled IA and OA to 0 psi. Functioned and torqued lockdown screws to 550 ft/lbs. Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up tubing hanger void to 5,000 psi. for 30 mins. -(Passed) Functioned and torqued lockdowns too 550 ft/Jbs. on inner casing hanger. - Rigged up test equipment and pumped until clean fluid returns were achieved. Unable to pressure up, energized "YB seals thru packing port, unable to achieve returns, abandon test.(Failed). May test after future well work completed. T/I/O/OO= 130/390/450/360. Temp= 51. (WAG WELL). Bleed WHP's to 0 psi (pre-RWO). Bled WHP's to Vac/35/65/100 psi in 2 hrs and 30 minutes. Captured approximately 15 bbls of fluid from the IA during the bleed. Monitored for 30 minutes. lAP increased 20 psi and OAP decreased 5 psi. Final WHP's= Vac/55/60/100. JET CUT 4.5" TUBING. JOB CANCELLED DUE TO FAILED MIT OF TUBING. DID NOT RIG UP. http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Default.aspx 3/7/2007 Digital Wellfile AWGRS A-OS 09/13/2006 AWGRS A-OS 09/12/2006 AWGRS A-OS 09/11/2006 AWGRS A-OS 09/10/2006 AWGRS A-OS 09/09/2006 AWGRS A-OS 09/09/2006 AWGRS A-OS 09/08/2006 AWGRS A-OS 09/04/2006 AWGRS A-OS 09/03/2006 AWGRS A-OS 09/02/2006 . Page 3 of3 T/I/O/OO== 180/360/480/340. CMIT TxIA to 4000 pSiIILED) OA tracked w/ IA. CMIT TxIAxOA to 2000 psi. (FAILED) on 2 attempts. Pumped 21 bbls 60/40 meth to achieve test pressure. Lost 90/90/70/0 psi @ 15 mini 50/50/60/0 psi @ 30 mini and 70/60/50/0 psi @ 45 min. Bled down pressures. MIT T to 2000 psi. (FAILED) on 2 atternpts. Pumped 2.5 bbls 60/40 meth to achieve test pressure. Lost 70 psi @ 15 mini 80 psi @ 30 min, and 80 psi @ 45 rnin. MIT T to 3500 psi. (FAILED) Pumped 1 bbl to achieve test pressure. Lost 180 psi @ 15 min and 180 psi @ 30 mini and 160 psi @ 45 min. Bleed down pressure. Final WHP's == 20/450/520/340. T/I/O/OO = 10/370/450/350. Temp = 5/1. No AL to Well. T & IA FLs (pre CMIT). TBG FL @ 2136' (33 bbLs). IA FL Near Surface. *** WELL 5/1 ON ARRIVAL *** RIH W/ 3.7 CENT, SB, TAG CEMENT @ 9001' SLM. *** WELL LEFT 5/1 ON DEPARTURE *** CTU #6, P&A; Cont' from WSR 9/09/06 ... Kill well. RIH with 2.75" BDN. Mix and pump 44 bbls Class 'G' cmt at 15.8 ppg. Lay cement in from PBTD- 11093'. Est TOC at 9100'. Pump 20 bbl Biozan sweep. POH at 80% - FP well to 2500 with 50/50 meth - Trap 300 psi on well - RDMO. Notify PCC / PO of well shut in status. **** Cement Job Complete **** Pressures T 300 / IA 430 / OA 500 / OOA 300 CTU #6, P&A; MIRU - Weekly BOPE test - Good test - Notify AOGCC of P&A -(Jeff Jones w/AOGCC waived witness of P&A) MU/RIH with PDS CCL/GR/Temp. Tag TD at 11107' up- Park for BHT - PUH logging at 30 fpm from 11105' to 9100'. POH. Corrected PBTD found at 11093' elmd. MU 2.75" BDN assy. PT lubricator and squeeze skid valves to 250/4000 psig. Begin well kill / fluid pack with KCL. Cont' on WSR 9/10/06 ... T/I/0/OOA=SI/200/540/500, Assist coil. Load IA with 76 bbls of crude, left 570 psi. on IA per coil PE. FWHP=SI/570/860/500. T/I/O/OO= 790/220/520/520. Temp= 51. Tubing & IA FL (pre-CT). Tubing FL @ 2184' (33 bbls). IA FL @ 360' (8 bbls). ***JOB CONT. FROM 9/3/06*** DRIFTED TO 10505' SLM/TUBING TAIL W/ BLB AND 2.625" GAUGE RING DRIFTED TO 10505' SLM/TUBING TAIL W/ BLB AND 3.65" CENTRALIZER ***WELL TURNED OVER TO DSO*** ***JOB CONT. FROM 9/2/06***(pre-sdtrk) FINISH 8'X3" DRIVE DOWN BAILER DRIFT TO P- PRONG, BAILER BACK 1/4 FULL OF SHMOO PULLED P-PRONG FROM TOP LOADER PLUG @ 9312' SLM TAGGED PLUG BODY W/ 3.805" GAUGE RING @ 9317' SLM CLEANED OUT BODY OF TOP LOADER W/ 3" PUMP BAILER AND SNORKLE BTM HAVE TO MAKE 2 RUNS TO PULL TOP LOADER W/ 4.5" GR @ 9316' SLM. ***JOB CONT. ON 9/4/06*** *** WELL SHUT IN ON ARRIVAL*** (PRE SDTRK) RIH W/ 3.805" GAUGE RING AND 3" JDC TO PULL PRONG, SAT DOWN @ 29' SLM RIH W/ 8' OF 2-1/4" DRIVE DOWN BAILER, DIFFICULTY RUNNING THROUGH 650'-775' SLM, TAGGED PRONG @ 9318' SLM, BAILER HALF FULL OF SHMOO RIH W/ 8' OF 3" DRIVE DOWN BAILER, HAD TO WORK THROUGH 1000'- 1379' SLM, INTERMITANT TIGHT SPOTS THROUGHOUT TUBING, TAGGED PRONG ***JOB CONT. ON 9/3/06*** http://digitalwellfile. bpweb. bp.comIW ellEvents/Home/Default.aspx 31712007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-OS A-OS REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/25/2006 Rig Release: 2/9/2007 Rig Number: Spud Date: 3/14/1972 End: 2/9/2007 12/29/2006 14:30 - 16:30 2.00 MOB P 16:30 - 19:30 3.00 MOB P 19:30 - 21 :00 1.50 MOB P 21 :00 - 00:00 3.00 MOB P 00:00 - 12:00 12.00 MOB P 12:00 - 15:00 3.00 MOB N 15:00 - 18:00 3.00 MOB P 18:00 - 20:30 2.50 RIGU P 20:30 - 00:00 3.50 RIGU P PRE 12/30/2006 PRE PRE PRE PRE PRE PRE PRE WAIT PRE 12/31/2006 1.00 RIGU P 0.50 KILL P 1.50 KILL P 1.00 DHB P 2.00 KILL P 00:00 - 01 :00 01 :00 - 01 :30 01 :30 - 03:00 03:00 - 04:00 04:00 - 06:00 DECOMP DECOMP DECOMP DECOMP DECOMP 06:00 - 09:00 3.00 KILL P DECOMP 09:00 - 10:00 1.00 WHSUR P DECOMP 10:00 - 18:00 8.00 WHSUR P DECOMP 18:00 - 21 :30 3.50 WHSUR P DECOMP Hook up pits to truck. Pull pits away and stage on pad. Pull mats. Set top drive in slips. Bridle up blocks. Lower cattle chute. PJSM. Lower derrick. Secure rig. Prepare to move rig. Move rig from DS 15-12B to Pad A-05Ai. Move rig from DS 15-12B to Pad A-05Ai. Waiting on DSM to sand entrance leading into A Pad. PJSM. Move rig on location and spot sub on well. PJSM. Spot pits and cuttings box. Hook up interconnect. Spot and SHt shop, camp and out buildings. Build berms. Hook up power to shop, camp and pits. PJSM. Raise derrick and pin. Chink cracks. Raise cattle chute. PJSM. Bridle down. Pin up top drive and torque tube. Hang bridal lines. Rig flcm rigged up and cleaned. Rig accepted at 0000 hrs. Pre-spud safety meeting. PJSM. Rig up to kill well and pull BPV. Pull BIPV with DSM. Make up circulating lines. Install secondary annulus valves on the IA, OA. Test lines to 3500 psi. Had trouble securing proper crossover equipment for OOA secondary valves. Equipment found at Nabors yard and will be installed during NU of BOPE. Displace diesel and circulated 9.8 ppg brine around. Start displaGement with 0 psi lA, 50 psi OA, 25 psi OOA. Pumped down annulus with 30 bbls seawater at 168 gpm with 500 psi to displaGe diesel. Pumped down tubing with 405 bbls 9.8 ppg brine back to surface at 252 gpm with 500 psi. OA/1020 psi, OOA/ï'OO psi. Safety meeting with John Rose and Cleve Coyne for upcoming CMIT. Install TWC and test from above to 4000 psi. IA OA OOA o 700 600 500 1400 700 500 1300 800 400 950 0 o 650 0 TWC tested. Pressure up IA Shutdown Bleed DOA Bleed OA bbls Bleed OA 0 150 Bleed OA 0 0 Pack OOA with fluid. 0 Tr Retest for CMIT. Pump with 9.8 ppg brine. Time bbls IA OA 1~2 1~4 0 1W 1834 16.4 0 150 1836 18.5 0 150 1838 21.5 0 400 1840 22.5 0 500 1850 0 450 1852 23.5 100 500 1855 100 620 1858 24.5 300 800 1908 225 800 All Gas Gas + 14 o o Tr 50 bbls 20 bbls OOA 30 30 30 50 100 200 150 400 450 500 Printed: 2/1212007 10:13:15 AM . . legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-OS A-OS REENTER+COMPlETE NABORS ALASKA DRilLING I NABORS 2ES Start: 12/25/2006 Rig Release: 2/9/2007 Rig Number: Spud Date: 3/14/1972 End: 2/9/2007 12/31/2006 18:00 - 21:30 3.50 WHSUR P DECOMP 1910 25.3 450 1000 525 1915 400 1000 600 1917 25.9 600 1100 650 1922 525 1100 700 1925 26.3 700 1250 750 Held pressue for 15 minutes, held OK. 1945 650 1200 750 1945 26.7 750 1300 750 Held pressure for 15 minutes, held OK. Bled off OA to 0 psi, got back all fluid. Bled off OOA, got back all gas. All annulus bled to 0 psi and monitor for 30 minutes. All OK. 21 :30 - 23:00 1.50 WHSUR P DECOMP PJSM. Pick up cellar and build platform around tree. 23:00 - 00:00 1.00 WHSUR P DECOMP Nipple down tree. Bleed all voids as per Cameron. 1/1/2007 00:00 - 02:30 2.50 WHSUR P DECOMP ND tree and adapter. Inspect lifting threads on tubing hanger. Cameron hand ran the XO into threads and recommends we not try to lift tubing with the threads and use a spear instead. Remove tree from cellar. 02:30 - 06:00 3.50 BOPSU P DECOMP NU BOPE. Will test to 250 psi low, 4000 psi high as per AOGCC. Test witness waived by Chuck Sheve. Performed hazard assessment for Inclement Weather Equipment Operating Procedure due to ambient temperatures below -35 degrees. Temperature currently at - 36 ambient. 06:00 - 10:00 4.00 BOPSU P DECOMP PJSM. Rig up to test BOPE with 4-1/2" test joint. Test to 250 psi low, 4000 psi high as per AOGCC regulations. BOPE test witness waived by Chuck Sheve. Choke and blinds tested good. 10:00 - 12:00 2.00 BOPSU N SFAL DECOMP Pick up 4-1/2" test joint. Close top pipe rams. Bleeding off on low test. Trouble shoot and determine pressue leaking downhole. Possible TWC problem. OA at 10 psi, OOA at 50 psi. Bleed to 0, all gas. 12:00 - 12:30 0.50 BOPSU SFAL DECOMP Wait on DSM to remove TWC. 12:30 - 15:00 2.50 BOPSU SFAL DECOMP PJSM. Pick up lubricator. Wait on 4ft lubricator extension to pull TWC. Rig up rig tongs. OA at 8 psi, bleed to 0, all gas. 15:00 - 16:30 1.50 BOPSU SFAL DECOMP PJSM. Test TWC against blinds, kill, choke and both HCR's. Good test. Pick up test joint, test dart and top rams. Low test good. High test held and bled off 5 minutes into test. TWC failed again. 16:30 - 17:00 0.50 BOPSU N SFAL DECOMP Rig down test joint. Blow down and lay down all surface equipment. OA 10 psi, bled to O. All gas. 17:00 - 19:00 2.00 BOPSU N SFAL DECOMP Secure well. Safety stand down. 19:00 - 21 :00 2.00 BOPSU N SFAL DECOMP PJSM. Rig up DSM lubricator. Attempt to pull TWC with no success. Pump out stack to check for debris. OA at 10 psi, bleed to O. All gas. 21 :00 - 21 :30 0.50 BOPSU N SFAL DECOMP PJSM. Relaxed bag and pulled slips to center lubricator. Slipped pulling tool into hanger. Close bag. RIH and retrieve TWC. Pull and rig down lubricator. Pick up T-bar. RIH and set new TWC as per Cameron. Verified travel of 1-11/16" on plug as per Company Man. 21 :30 - 00:00 2.50 BOPSU P DECOMP PJSM. Pick up and run in 4-1/2" test joint. Test BOPE to 250 psi low, 4000 psi high. 1/212007 00:00 - 02:00 2.00 BOPSU P DECOMP PJSM. Test BOPE to 250 psi low, 4000 psi high as per AOGCC. Chuck Sheve waived witness of test. Rig up top drive and test. Tested Hydril to 2500 psi. Test OK. OA holding at 5 Pointed: 2/12/2007 10:13:15 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-OS A-OS REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/25/2006 Rig Release: 2/9/2007 Rig Number: Spud Date: 3/14/1972 End: 2/9/2007 psi. PJSM. Rig down and blow down test equipment. OA still at 5 psi. 02:30 - 04:00 DECOMP PJSM. Rig up DSM lubricator and pull TWC. Rig down lubricator. Pump 40 bbls 9.8 ppg brine over the top. No fluid show at top of tubing hanger. 04:00 - 07:00 3.00 PULL P DECOMP PJSM. Pick up spear as per Baker rep. Run in and spear hanger. Bleading IA with 10 psi, OA with 100 psi and OOA with 150 psi before pull hanger free. Back out lock down screws and pull hanger free with 115k 07:00 - 07:30 0.50 PULL P DECOMP PJSM Lay down spear, and tubing hanger 07:30 - 09:00 1.50 PULL P DECOMP PJSM. Circulate 9.8 ppg brine surface to surface. Took 73 bbls to fill hole. 164 GPM @225 psi, OA @ 400 pSi,OOA @ 50 psi. Bleed down OA to 200 psi,gas and fluid. 09:00 - 09:30 0.50 PULL P DECOMP PJSM. Rig up to pull 4 1/2" tubing. 09:30 - 19:00 9.50 PULL P DECOMP PJSM. POOH laying down 4 1/2" tubing from 8669',207 joints,1 pup joint,X nipple,and 20.63' cut joint. Monitor well for 10 minutes,dead. 19:00 - 20:00 1.00 PULL P DECOMP PJSM. Rig down tongs and 4 1/2" handling equipment. Clear and clean floor, bring test plug to floor. 20:00 - 22:30 2.50 BOPSU P DECOMP Install new flange, valve and gauges on OOA. 22:30 - 00:00 1.50 BOPSU P DECOMP PJSM. Pick up test joint and install test plug.Test annular preventer,top and bottom rams with 4" and 5" test joints. 1/3/2007 00:00 - 02:00 2.00 BOPSU P DECOMP Test Upper and lower rams with 4" & 5" test joints to 250psi low and 4000psi high. Test Annular to 250psi low and 2500psi high with 4" and 5" test joints. 02:00 - 03:00 1.00 BOPSU P DECOMP Pull test plug,and lay down test joints. Blow down surface equipment. 03:00 - 04:00 1.00 CLEAN P DECOMP Pick up tools to floor. 04:00 - 05:30 1.50 CLEAN P DECOMP PJSM. Make up 9 5/8" scraper and scrape top joint of 9 5/8" casing to 52'. Pull back to surface and lay down. 05:30 - 06:00 0.50 CLEAN P DECOMP PJSM. Install wear ring. 06:00 - 07:00 1.00 CLEAN P DECOMP Make up 7" casing scraper and run in hole to 120'. 07:00 - 10:00 3.00 CLEAN P DECOMP Run in hole picking up drill pipe from pipe shed, from 120' to 2928'. 10:00 - 13:00 3.00 CLEAN N RREP DECOMP Repair and function test pipe skate. 13:00 - 17:00 4.00 CLEAN P DECOMP Run in hole picking up 4" drill pipe from pipe shed, from 2928' to stump at 8669'. Tag stump, up wt. 147k,down wt. 118k. 17:00 - 20:00 3.00 CLEAN P DECOMP Establish rates for 162 GPM @460 psi, then 200 GPM @ 654 psi. Pump high vis sweep and circulate surface to surface. 20:00 - 22:30 2.50 CLEAN P DECOMP PJSM. Slip and cut drill line. Service draworks and top drive. Grease crown. 22:30 - 00:00 1 .50 CLEAN P DECOMP POOH from 8669' to 4421'. 1/4/2007 00:00 - 01 :00 1.00 CLEAN P DECOMP PJSM. POOH from 4421' to 1805'. 01 :00 - 03:00 2.00 CASE P DECOMP PJSM. Pick up and set RTTS at 35'. Test to 2000 psi. NOTE: All path-forward work as associated with replacing the tubing spool with a full-bore "spacer" spool and the wellhead/BOP pressure testing which will be associated with that work until such time as a new starter ring has been installed on the new 13-3/8" casing which will be run on this Printed: 2/12/2007 10:13:15 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-OS A-OS REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/25/2006 Rig Release: 2/9/2007 Rig Number: Spud Date: 3/14/1972 End: 2/9/2007 1/4/2007 01 :00 - 03:00 2.00 CASE P DECOMP well has been waivered to 2000 psi tests per AOGCC (L. Grimaldi/J. Rose) This waiver was requested on the basis that the lower-wellhead/out casing strings would not be sulitable to the 4000 psi testing currently permitted for this planned injector sidetrack. 03:00 - 03:30 0.50 CASE P DECOMP Pull wear ring. 03:30 - 08:00 4.50 CASE P DECOMP PJSM.Nipple down BOP and attempt to remove tubing spool. Primary seal on 95/8" pack off leaking by.Attempt to bleed OA and OOA off, would not bleed to O.Could not remove tubing spool. 08:00 - 10:00 2.00 CASE P DECOMP PJSM. Nipple up BOP and test 9 5/8" to tubing flange to 2500 psi with Cameron. Dispensation to not test to 4000 psi from AOGCC rep Lou Grimaldi. 10:00 - 10:30 0.50 CASE P DECOMP Test tubing flange to BOP with Rig to 4000psi. 10:30 - 11 :00 0.50 CASE P DECOMP PJSM. Install wear ring. 11 :00 - 14:00 3.00 CASE P DECOMP Screw into storm packer,release and pull to floor. 14 bbl. required to fill well after pulling packer. Lay down packer and POOH from 1805',lay down BHA. 14:00 - 17:30 3.50 CASE P DECOMP PJSM. Rig up wireline unit with pressure control head. Rig up US IT logging tools. 17:30 - 00:00 6.50 CASE P DECOMP Run in hole with US IT tool and log 7" casing from 8600'to surface. Top of cement @ 2040' E-line measurement.Rig down E-line and clear tloor. 1/5/2007 00:00 - 01 :00 1.00 CASE P DECOMP Rig down wireline. 01 :00 - 01 :30 0.50 CASE P DECOMP Make up RTTS and run in hole with collars. 01 :30 - 06:00 4.50 CASE P DECOMP Run in hole with RTTS to find 7" casing leak. 06:00 - 07:00 1.00 CASE P DECOMP PJSM.Set RTTS and test 7" casing below 8043' to 1000 psi. OA pressure increases to 1200 psi, failed test. Test above 8043' to 1500 psi. Good test, OA and OOA remain static. Run in hole to 8135' and test to 1500 psi above RTTS,good test. 07:00 . 09:00 2.00 CASE P DECOMP PJSM. Run in hole to 8669',tag stump. Pick up and set RTTS @8661'. Test below to 2000 psi for 30 minutes,good test. Lay down 2 singles and blow down top drive. Rig up to circulate OA. 09:00 - 10:30 1.50 CASE P DECOMP POOH from 8669' to 8135'. Set RTTS.Open OA to cuttings tank and bleed to 0 psi. 10:30 - 12:30 2.00 CASE P DECOMP Establish pump rates of 27 GPM @44 psi. Bring rate up to 1 BBUmin. @ 50 psi. Circulate 9.8 ppg brine displaceing OA. OOA = 120 psi open to bleed tank and bring rate up to 3 BBUmin @ 410 psi,continue bleeding OOA,mostly gas with small amounts of fluid (1/2 BBL). Circulate until 9.8 ppg brine all the way surface of the OA. 12:30 - 14:00 1.50 CASE P DECOMP Blow down line to cuttings tank. Rig up to circulate through secondary choke line and take returns to mud pits. Circulate at 2 BBUmin. @228 psi for full circulation, 6400 strokes. 14:00 - 14:30 0.50 CASE P DECOMP Pick up and release RTTS. Blow down top drive and choke line. Rig up OOA to cuttings tank and leave open. Well back flowing through drill pipe. 14:30 - 16:00 1.50 CASE P DECOMP PJSM. Circulate 9.8 ppg brine surface to surface. Monitor well for 15 minutes,blow down top drive and bleed 350 psi off OA. 16:00 - 17:30 1.50 CASE P DECOMP PJSM. Make up storm packer and set @ 35'. Test to 2000 psi for 5 minutes. Printed: 2/1212007 10:13:15 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-OS A-OS REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/25/2006 Rig Release: 2/9/2007 Rig Number: Spud Date: 3/14/1972 End: 2/9/2007 1/5/2007 17:30 - 18:00 0.50 CASE P DECOMP PJSM. Pull wear ring. 18:00 - 20:00 2.00 CASE P DECOMP Nipple down BOP and remove tubing spool. 20:00 - 22:00 2.00 CASE P DECOMP Nipple up spacer spool and BOP. 22:00 - 22:30 0.50 CASE P DECOMP Test spacer spool and lower mud cross & spacer spool x 9 5/8". flange to 2000 psi. Dispensation to not test to 4000 psi from AOGCC rep Lou Grimaldi. 22:30 - 23:30 1.00 CASE P DECOMP PJSM. Run in and screw into storm packer, release, pull packer to floor, and lay down. 23:30 - 00:00 0.50 CASE P DECOMP POOH from 8140' to 7768'. 1/6/2007 00:00 - 03:30 3.50 CASE P DECOMP POOH from 7768' to BHA @ 120'. 03:30 - 04:00 0.50 CASE P DECOMP Rack back drill collars and lay down RTTS.Clear Floor. 04:00 - 04:30 0.50 CASE P DECOMP PJSM. Make up 7" casing cutter BHA. 04:30 - 08:00 3.50 CASE P DECOMP Run in hole with 7" casing cutter to 8320'. Up wt. 142k,down wt. 115k. Install blower hose. 08:00 - 08:30 0.50 CASE P DECOMP Break circulation and bring pumps up to 105 gpm @ 350 psi. Locate collar at 8314' with casing cutter, pick up to 8300' and initiate cut on 7" casing. 157 gpm @ 756 psi,72 RPM,rotating wt. 130k,free torque 3700 ftIlbs,cutting torque 5-6000 ftIlbs. 08:30 - 09:00 0.50 CASE P DECOMP Remove blower hose and blow down top drive. 09:00 - 11 :30 2.50 CASE P DECOMP POOH from 8320' to 4586'.Up wt. 90k,down wt. 90k.torque off bottom 1100 ftIlbs. Bring pumps up to 184 gpm @ 800 psi. Start cut with 70 RPM,cut casing and confirm by slacking off. 11 :30 - 12:00 0.50 CASE P DECOMP Blow down top drive,remove blower hose. Well out of balance,make up top drive and circulate. OA=O psi OOA=15 psi. 12:00 - 13:30 1.50 CASE P DECOMP PJSM. POOH from 4586' to 1969'. 13:30 - 15:00 1.50 CASE P DECOMP PJSM. Install blower hose, break circulation and tag collar @ 1955'.Cut 7" casing at 1951'. Monitor welllA x OA is U-tubing.. 15:00 - 16:30 1.50 CASE P DECOMP PJSM. Pick up storm packer,set, and test to 2000 psi.Good test. 16:30 - 18:30 2.00 CASE P DECOMP PJSM. Change out 31/2" x 6" variables to 7" rams.Test door seals to 2000 psi. Requirement for 4000 psi body test waived by AOGCC rep. Lou Grimaldi. 18:30 - 19:30 1.00 CASE P DECOMP PJSM.Run in hole and screw into storm packer. Release,retrieve,and lay down packer. 19:30 . 20:30 1.00 CASE P DECOMP PJSM. POOH from 1969' to 97'. 20:30 - 21 :00 0.50 CASE P DECOMP PJSM. Lay down 43/4" collars and 7" casing cutter. 21 :00 - 21 :30 0.50 CASE P DECOMP Clean and clear rig floor. 21 :30 - 22:00 0.50 CASE P DECOMP Pick up spear to floor. 22:00 - 23:00 1.00 CASE P DECOMP Make up 9 5/8" casing spear assembly. Bleed down OA and OOA. 23:00 - 00:00 1.00 CASE P DECOMP PJSM. Run 9 5/8" casing spear in hole and engage. Pull up 5k to confirm engaged. Slack off and back out lock down screws. Pull casing free with 190k,string wt. 145k. Pull casing slips to floor and remove. 1m2007 00:00 - 00:30 0.50 CASE P DECOMP Fill hole after pulling 9 5/8",10 bbl. to fill. PJSM on breaking out 9 5/8" joint and laying down cut off & BHA. 00:30 - 02:00 1.50 CASE P DECOMP Rig up false bowl & break out Ilaydown 95/8"joint.Clear floor,rig down 9 5/8" handling equipment. Length of 9 5/8" joint 25.53'. 02:00 - 02:30 0.50 CASE P DECOMP PJSM Rig up 7" casing equipment. Printed: 2/12/2007 10:13:15 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-OS A-OS REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/25/2006 Rig Release: 2/9/2007 Rig Number: Spud Date: 3/14/1972 End: 2/9/2007 1m2007 02:30 - 11 :00 8.50 CASE P DECOMP POOH with 7" casing. Every joint hanging up until 30 joints out then intermittent snagging until out of hole. Cut in joint #46 not all the way through, some visible signs of cut on outside of joint. Pull and layout 107 joints and 1 x 39.28' cut joint. 11 :00 - 12:00 1.00 CASE P DECOMP Monitor well for 10 minutes. Rig down 7" casing equipment, clear and clean floor. 12:00 - 13:00 1.00 CASE P DECOMP PJSM. Pick up baker 7" spear up beaver slide. 13:00 - 15:00 2.00 CASE P DECOMP PJSM. Make up 7" spear assembly. 15:00 - 16:00 1.00 CASE P DECOMP PJSM. Run in hole to 324' picking up drill collars. 16:00 - 19:30 3.50 CASE P DECOMP Run in hole from 324' to 4598'. Assembly hung up at 133/8" x 9 5/8" liner lap and required rotation to pass through. 19:30 - 20:00 0.50 CASE P DECOMP Tag top of 7" casing and set down 25k to engage spear.Pull up to 200k and let jars open. Straight pull to 240k and casing comes free. String weight of casing 210k. 20:00 - 23:30 3.50 CASE P DECOMP POOH from 4598' to 324'. Casing collars started to hang up at 1610' and hanging up every 41' pulling 25k to 50k over to pull past. Stand back drill collars. 23:30 - 00:00 0.50 CASE P DECOMP PJSM. Lay down spear assembly and casing cut off. 1/8/2007 00:00 - 01 :00 1.00 CASE P DECOMP PJSM. Layout spear,casing cut off (3.24'), and one joint of 7"casing. 01 :00 - 07:00 6.00 CASE P DECOMP POOH laying down 7" casing from 3702'. Casing collars hanging up on every joint up to joint # 45 out. Pulled and layed down 86 full joints and 1 cut off 31.01'. Monitor well for 10 minutes. 07:00 - 08:00 1.00 CASE P DECOMP Rig down 7" handling equipment,clear and clean floor. 08:00 - 10:00 2.00 CASE P DECOMP PJSM. Set test plug, change out upper rams from 7" to 9 5/8". Test door seals to 2000 psi for 5 minutes,good test. Requirement for 4000 psi test waived by AOGCC rep. Lou. Grimaldi. 10:00 - 10:30 0.50 CASE P DECOMP Install wear ring, ID 12.5". 10:30 - 11 :00 0.50 CASE P DECOMP Break down spear assembly as per Baker rep. 11 :00 - 14:00 3.00 CASE P DECOMP PJSM. Make up 133/8" scaper assembly to 322'. 14:00 - 15:00 1.00 CASE P DECOMP Run in hole from 322' to 1853',tag top of 9 5/8" tie-back. 15:00 - 16:00 1.00 CASE P DECOMP Pump 50 bbl Hi-Vis soap sweep around,525 GPM @ 660 psi. 16:00 - 17:00 1.00 CASE P DECOMP POOH from 1853' to 322'. 17:00 - 18:30 1.50 CASE P DECOMP PJSM. Stand back drill collars, lay down 133/8" assembly. 5 Ibs. of scale recovered from boot baskets. 18:30 - 19:00 0.50 CASE P DECOMP Clear floor of 13 3/8" scraper BHA. 19:00 - 19:30 0.50 CASE P DECOMP PJSM. Bring 9 5/8" casing scaper assembly tools to floor. 19:30 - 21:00 1.50 CASE P DECOMP PJSM. Make up 9 5/8" casing scraper assembly and run in drill collars to 326'. 21 :00 - 00:00 3.00 CASE P DECOMP Run in hole from 326' to 6682'. 1/9/2007 00:00 - 01 :30 1.50 CASE P DECOMP Run in hole from 6682' and tag stump at 8301'.Make up top drive, break circulation. 01 :30 - 03:30 2.00 CASE P DECOMP Get slow pump rates. Circulate at 406 GPM @ 1378 psi,pump Hi-Vis soap pill. Increase rate to 470 GPM @1795 psi, and reciprocate pipe. Shut down and break off top drive,well out of balance,flowing out of drill pipe,screw in top drive and circulate while cutting Printed: 2/12/2007 10:13:15 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-OS A-OS REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/25/2006 Rig Release: 2/9/2007 Rig Number: Spud Date: 3/14/1972 End: 2/9/2007 1/9/2007 01 :30 - 03:30 2.00 CASE P DECOMP and slipping line. 03:30 - 05:30 2.00 CASE P DECOMP Cut and slip drill line. Service top drive,and draworks. 05:30 - 06:00 0.50 CASE P DECOMP Monitor well for 10 minutes,pump dry job and blow down top drive. 06:00 - 09:00 3.00 CASE P DECOMP POOH from 8300' to 1855',pulled 5k over at liner top. Worked scraper through until free. 09:00 - 09:30 0.50 CASE P DECOMP POOH from 1855' to 326'. 09:30 - 11 :30 2.00 CASE P DECOMP PJSM. Rack back drill collars and lay down BHA. 11 :30 - 12:30 1.00 CASE P DECOMP Pull wear ring,install test plug, and rig up to test BOPE. 12:30 - 17:00 4.50 CASE P DECOMP PJSM. Test BOP and related equipment to 250 psi low and 4000 psi high,test annular to 250 psi low and 2500 psi high,hold for 5 minutes, record and chart.Test witness waived by AOGCC rep John Crisp, Test witnessed by Nabors drilling rep Charlie Henley and BP rep John Rose. 17:00 - 17:30 0.50 CASE P DECOMP Rig down test equipment and blow down lines. 17:30 - 18:00 0.50 CASE P DECOMP Install wear ring. 18:00 - 19:30 1.50 CASE P DECOMP Bring logging tools to floor up beaver slide. 19:30 - 21:00 1.50 CASE P DECOMP PJSM. Rig up wireline,with shooting nipple. 21 :00 - 00:00 3.00 CASE P DECOMP Run CCL,GR,USIT log on wireline. 1/10/2007 00:00 - 05:30 5.50 CASE P DECOMP Run CCL,GR,USIT log on wireline. 05:30 - 06:30 1.00 CASE P DECOMP Lay down logging tools. 06:30 - 10:00 3.50 CASE P DECOMP PJSM.Rig up to run Fasdrill plug. Discuss depth placement of FASDRILL. Review USIT/CBL Logging Results. Blow down choke and kill lines. 10:00 - 12:30 2.50 CASE P DECOMP Make up plug and run in hole to 2179'. Pick up to 2085' and set plug. POOH from 2085' and lay down running tools. Rig down shooting nipple. 12:30 - 13:00 0.50 CASE P DECOMP Test Fasdrill plug to 1500 psi,for 15 minutes,good test. 13:00 - 14:30 1.50 CASE P DECOMP Load casing puncher and rig up shooting nipple. 14:30 - 16:00 1.50 CASE P DECOMP Run in hole with casing punch to 2063'. Fire and punch holes @ 2063'. 16:00 - 16:30 0.50 CASE P DECOMP PJSM. Establish circulation through holes @ 2063' to OA.Annulus broke at 310 psi, pump 6 bbl,500 gpm@ 30 psi. 29 bbl required to fill hole after circulating. 16:30 - 18:00 1.50 CASE P DECOMP PJSM. Rig up wireline with string shot and run in hole to 75'. Fire string shot across collar at 75'. 18:00 - 19:30 1.50 CASE P DECOMP Rig down wireline unit and shooting nipple. Clear and clean floor. 19:30 - 21:30 2.00 CASE N WAIT DECOMP Wait on trucks for displacing OA. 21 :30 - 00:00 2.50 CASE P DECOMP PJSM. Circulate oil out of 13 3/8" x 18 5/8"annulus. Pump 100 bbl hot water with soap, followed by 700 bbl. hot 9.8 ppg brine. 210 GPM @ 390 psi. 1/11/2007 00:00 - 01 :00 1.00 CASE P DECOMP Circulate OA clean with hot 9.8ppg brine and soap pill. 206 GPM @ 446 psi. Brine cleaned up after soap pill comes back to surface. Blow down all lines and rig down cellar. 01 :00 - 01 :30 0.50 CASE P DECOMP Pull wear ring. 01 :30 . 04:30 3.00 CASE P DECOMP Install blower hose,make up cutter assembly to 75'. Run in hole and tag casing collar at 80'. Pick up 20' and cut 13 3/8" casing. Free torque 1000 ftIlbs,cutting torque 3-4k ftIlbs.270 GPM @ 790 psi. Cut 13318" casing and shut down rotary and pump. Pick up 5' Printed: 2/1212007 10:13:15 AM · Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-OS A-OS REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/25/2006 Rig Release: 2/9/2007 Rig Number: Spud Date: 3/14/1972 End: 2/9/2007 1/11/2007 01 :30 - 04:30 3.00 CASE P DECOMP and bring pumps back up to 189 GPM,slack off to verify cut. 04:30 - 05:30 1.00 CASE P DECOMP POOH, lay down casing cutter BHA,clear and clean floor. 05:30 - 07:30 2.00 CASE P DECOMP PJSM. Remove mouse hole and drip pan. Suck fluids out of BOP with Vac truck,install 20" bell nipple to drip pan. 07:30 - 09:00 1.50 CASE P DECOMP Nipple down BOP and set back. 09:00 - 13:00 4.00 CASE P DECOMP PJSM. Bleed down all voids on wellhead, remove spacer spool, and 20" x 135/8" McEvoy casing spool. Casing was growing and pushing wellhead up. Install long studs to control upward movement. Remove spool, casing rose a total of 11 inches. Remove spacer spool and intermediate spools from cellar. 13:00 - 14:00 1.00 CASE P DECOMP PJSM. Pick up 13 5/8" casing spear from beaver slide. 14:00 - 15:00 1.00 CASE N RREP DECOMP Trouble shoot crown saver. 15:00 - 15:30 0.50 CASE P DECOMP Make up 133/8" casing spear assembly. 15:30 - 19:00 3.50 CASE P DECOMP Run spear into 133/8" and engage, pulled free with no overpull. Remove casing slips. 133/8" pack-off was in one piece and could not fit through rotary table. Release spear,remove pack-off and engage spear. Pull 13 3/8" casing and lay down. Recovered 21.51' of casing. 19:00 - 00:00 5.00 CASE P DECOMP PJSM. Nipple up 20" riser and clean cellar area. 1/12/2007 00:00 - 00:30 0.50 CASE P DECOMP PJSM. Fill riser and check for leaks. 00:30 - 03:30 3.00 CASE P DECOMP PJSM. Pick up wash pipe assembly to 70'. Hung up on stump, layed down jars. 03:30 - 04:00 0.50 CASE P DECOMP Make up top drive to single and wash down over stump to 90',47 GPM @ 4 psi. 04:00 - 07:00 3.00 CASE P DECOMP Lay down wash pipe assembly.Clear and clean floor. 07:00 - 08:30 1.50 CASE P DECOMP PJSM. Pick up back off assembly up beaver slide. 08:30 - 11 :00 2.50 CASE P DECOMP Make up back off assembly. 11 :00 - 12:00 1.00 CASE P DECOMP Set bottom anchor@ 95'and top anchor at 70'. Casing started to back off at 2500 psi. Back off casing 5 turns. 12:00 - 15:00 3.00 CASE P DECOMP Pull out back off tools and lay down. Clear and clean floor. 15:00 - 17:30 2.50 CASE P DECOMP Make up 133/8" spear and 2 singles of drill pipe to 60'. Spear casing stub and back out. Pull and lay down spear & 19.22' cut off. 17:30 - 18:30 1.00 CASE P DECOMP Rig up to run 13 3/8" casing. 18:30 - 20:00 1.50 CASE P DECOMP Make up 2 joints of 13 3/8" casing. Make up crossovers to top drive and screw into casing @ 80'. Torque to 13k and test with 50k overpull. Break out top drive and lay down crossovers. 20:00 - 20:30 0.50 CASE P DECOMP Rig down and lay down casing equipment. 20:30 - 22:00 1.50 CASE P DECOMP PJSM. Cut 133/8" casing off at drill floor. Rig up false bowl. 22:00 - 00:00 2.00 CASE P DECOMP Make up cement retainer and run in hole to 2038'. Set packer at 2035'. 1/13/2007 00:00 - 01 :00 1.00 CASE P DECOMP Break out top drive,set 25K down into retainer. Pull out false bowl & rig up circulating head pin. Break circulation,200 psi @ 3 BPM,460 psi @ 5 BPM. 01 :00 - 04:00 3.00 CASE P DECOMP PJSM. Pump 5 bbl. fresh water and pressure test lines to 2500 psi. Pump 5 bbl. fresh water with dye followed by 311 bbl. 15.71 ppg. ArticSet 1 cement. 4 BPM @ 1300 psi. Cement to surface. Displace with 20 bbl. 9.8 ppg brine. ' 04:00 - 05:00 1.00 CASE P DECOMP Rig up false bowl. Break out pup joint and head pin. Pick up single and rack back stand. Flush and pump out riser,flush Printed: 2/1212007 10:13:15 AM · . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-OS A-OS REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/25/2006 Rig Release: 2/9/2007 Rig Number: Spud Date: 3/14/1972 End: 2/9/2007 1/13/2007 04:00 - 05:00 1.00 CASE P DECOMP cement manifold. 05:00 - 06:30 1.50 CASE P DECOMP POOH with retainer running tool.Lay down crossover and stinger. 06:30 - 11 :00 4.50 CASE P DECOMP PJSM. Cut riser to acess & cut off 133/8" casing. Lay down cut off and finish cutting off upper section of riser, remove from cellar. Measure, mark, and cut lower section of riser. 11 :00 - 12:00 1.00 CASE P DECOMP PJSM. Rig up WACHS cutter and cut 13 3/8" casing,rig d~ cutter. 12:00 - 14:00 2.00 CASE P DECOMP Open cellar doors and bring in new well head. Perform dye penetrant test on 13 3/8" casing stub. Install,and level new well head. 14:00 - 15:00 1.00 CASE P DECOMP Wrap new well head with heat blanket to pre-heat. 15:00 - 18:30 3.50 CASE N SFAL DECOMP Generator would not pull the load for the heat blanket. Trouble shoot problem and call for new generator. Wait on generator. 19:00 - 22:00 3.00 CASE P DECOMP Heat wellhead to 500 degrees. 22:00 - 00:00 2.00 CASE P DECOMP Begin welding on starting head. 1/14/2007 00:00 - 05:30 5.50 CASE P DECOMP Weld starting head on to 133/8" casing. 05:30 - 12:30 7.00 CASE P DECOMP Welding complete, wrap, and heat to 900 degrees then cool to 100 degrees. 12:30 - 14:30 2.00 CASE P DECOMP Perform dye penetrant test,grind inside weld and inspect. Perform nitrogen test on wellhead. Test failed. 14:30 - 16:30 2.00 CASE N SFAL DECOMP Weld support gussetts from 20" conductor to wellhead for support, while ginding out inner weld. 16:30 - 17:30 1.00 CASE N SFAL DECOMP Rig up heat blanket and wrap wellhead. 17:30 - 20:30 3.00 CASE N SFAL DECOMP Heat wellhead to 500 degrees. 20:30 - 00:00 3.50 CASE N SFAL DECOMP Weld and grind inner weld. Perform nitrogen test.failed. 1/15/2007 00:00 - 02:30 2.50 CASE N SFAL DECOMP Re-weld and re-test wellhead. Passed. 02:30 - 09:00 6.50 CASE N SFAL DECOMP Complete heating and cooling cycles on wellhead. 09:00 - 14:00 5.00 CASE P DECOMP PJSM. Nipple up BOP,change out bell nipple flange. 14:00 - 15:00 1.00 CASE P DECOMP PJSM. Change top set of rams to 3 1/2" x 6" variables. 15:00 - 15:30 0.50 CASE P DECOMP Install secondary annulus valve. 15:30 - 17:00 1.50 CASE P DECOMP Rig up 4" test joint, install test plug. Test bottom flange & top 3 1/2" x 6" variable rams to 250 psi low and 4000 psi high. Pull test plug, install wear ring. 17:00 - 18:30 1.50 CASE P DECOMP Make up clean out BHA to 311'. Change out handling equipment. 18:30 - 19:30 1.00 CASE P DECOMP Run in hole from 311' to 1997',install blower hose. Tag cement at 2025'.- 19:30 - 20:00 0.50 CASE P DECOMP Test 133/8" casing to 2000 psi for 10 minutes,hold and chart. Blow down surface equipment. 20:00 - 00:00 4.00 CASE P DECOMP Drill cement from 2025' to 2035'. Drill EZSV at 2035'. Up wt. 75k,down wt. 70k,rotating wt. 80k. WOB 25k off bottom torque 950,on bottom torque 1500-3500. 1/16/2007 00:00 - 03:00 3.00 CASE P DECOMP Drill EZSV and cement from 2035 to 2072'. 03:00 - 04:00 1.00 CASE P DECOMP Test casing to 2000 psi,failed. Pressure bled 500 psi in 5 minutes. Bumped pressure up to 2000 pSi,bled 200 psi in 2 minutes then 250 psi more in 8 minutes. 04:00 - 04:30 0.50 CASE P DECOMP Re-test casing to 2000 psi. Wait on orders from town. Test passed,held 2000 psi for 10 minutes. Changed suspect sensor boot in cellar,possible reason for failed test. 04:30 - 06:30 2.00 CASE P DECOMP Drill cement and FasDrill plug from 2072' to 2091'.wOB Printed: 2/12/2007 10:13:15 AM " Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-OS A-OS REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 12/25/2006 Rig Release: 2/9/2007 Rig Number: Spud Date: 3/14/1972 End: 2/9/2007 1/16/2007 04:30 - 06:30 06:30 - 08:30 08:30 - 10:00 10:00 - 13:30 13:30 - 15:00 15:00 - 18:00 18:00 - 22:00 22:00 - 23:00 23:00 - 00:00 1/17/2007 00:00 - 03:00 03:00 - 07:30 07:30 - 09:00 09:00 - 12:00 19:30 - 20:30 20:30 - 21 :00 1/18/2007 2.00 CASE P DECOMP 2.00 CASE P 1.50 CASE P DECOMP DECOMP 3.50 CASE P 1.50 CASE P 3.00 DHB P DECOMP DECOMP DECOMP 4.00 DHB P DECOMP 1.00 DHB P DECOMP 1.00 STWHIP P WEXIT 3.00 STWHIP P WEXIT 4.50 STWHIP P WEXIT 1.50 STWHIP P WEXIT 3.00 STWHIP P WEXI 7.50 STWHIP P WEXIT WEXIT 0.50 STWHIP P WEXIT WEXIT WEXIT 2.00 STWHIP P WEXIT 20k-28k,RPM 60-100,flow rate 400-450GPM @ 500-600 psi. 9.8 ppg brine in and out. RIH and tag 7" stump at 8299'. Pump 35 bbl hi-vis sweep surface to surface at 540 gpm with 2700 psi. Pump dry job and blow down top drive. POOH to 311 '. Change out handling equipment. POOH and lay down BHA. Empty boot baskets. Clear floor. PJSM. Rig up SWS. RIH with junk basket and 8-1/4" gauge ring on wireline. POOH. Very little junk in baskets. No other run necessary. Make up running tools and 9-5/8" EZSV. RIH and locate collar at -8238'. Set EZSV at 8230'. POOH and rig down SWS. Test 13-3/8" x 9-5/8" casing to 2000 psi for 30 minutes. Pressure bled off 200 psi over 30 minutes, 150 psi in the first 10 minutes, then trending toward a flat line. Pumped pressure back up to 2000 psi and held for 10 minutes with pressue dropping 40 psi. Test passed. Blow down surface equipment. Pick up and make up 9-5/8" whipstock and milling assembly to 80'. MU BHA. Upload and surface test MWD. Pick up and MU whipstock slide. Bring up scribe line on way in. Make up bumper sub, drill collars, and XO to 389'. RIH with whipstock and mill assembly. Orient whipstock to 73 deg RHS. Install blower hose. Pick up single joint of DP and last stand. Tag EZSV at 8233'. Down weight 120k up weight 160k. Set 20k down and set whipstock anchor. Pick up and confirm. Set 35k down and shear off lug. Pick up and confirm free. Top of window at 8206' at 73 degrees right. -* Pump 45 bbl hi-vis spacer and displace well to 9.0 ppg LSND mud at 500 gpm with 1550 psi. Mill window from 8206' to 8210'. orque 4.5 to a 6 rpm. Pump at 495 gpm with 1600 psi. WOB 2-3k. RT weight Mill window and 20' of new formation to 8234' - (fr id point of window). Up weight 160k, down weight 1 ,T weight 140k. Rotate at 90 rpm with 5k torque ottom, 7k torque on bottom. WOB 8-10k. Pump at 4 pm with 1180 psi. TOW = 8206'. BOW = 8222'. Circulate sweep surf 0 surface at 495 gpm with 1650 psi. Work mill and n up hole. Mud weight 9.0+ ppg in and out. Recover 0 Ibs of metal from hole. A t FIT to 12.0 ppg EMW at 6767 TVD with 1060 psi. ressure deviated from straight line at 740 psi for a 11.1 ppg EMW leak off. FIT not obtained. Pressure dropped to 600 psi in minutes. Verified OK to drill ahead with LOT of 11.1 ppg EM per Mehrdad Nadem. AOGCC -rep Chuck Scheve was notifi the FIT test, and also left a message on Tom Maunders Voice 'I. An Email was sent to Tom Maunder on 1/18/2007 summarizin T discussions with him. Pump dry job. Remove blow ose. POH to 1210'. POOH with whipstock assembly to PJSM. Lay down DC's and bumper sub. nload MWD and lay down. Break mills. Mills in guage. LD HW lear floor. Pick up bit, stabilizer and circulatinÌ}sub. Change ou Printed: 2/1212007 10:13:15 AM TREE = 7-1/16"5MCIW WELLHEAD =13-5/8" MCEVOY -CONV A CTUA TOR = OTIS KB. ELEV = 65.89' BF,ELEV= 46.17' KOP = 2800' A-05A FROM DRLG - DRAFT 10852' 8800' SS 4-112" HES X NIP, 10 '" 3.813" 2190' Minimum ID = 3.725" @ 10673' 4-1/2" HES XN NIPPLE 13-3/8" CSG, 72#. N-BO -J 2018' I BTRS, 10 = 12.347" 20" CSG, 133#1ft, 2278' I K-55 BTRS, 10 = 18.730" ITop of Tie-back Cement H 2778' I TOP of 9-518' Vvindow H -MtMt'- ¡gzcr.; /7" liner cut @ H -H99=- 18300' 14-112",12,6#, l-80Thgcut@ H -&H9I- 18'-"'9 · /TOP OF 40' TMI PBR H 9272" 1 I Est top of P&A Cement H 9888' 18770 ' /9-518" X 7" TMllNR TOP PKRlHGR WI4f1 PBR H 9312' 19-518" TBG, 47#, L-80, .0732 bpf, 10 = 8,681" H 9814' 4-1/2" TBG, 12,6#.l-80 NSCT, -J 10516' .0152 bpf, 10 = 3.958" I PBm H 11259' 7" LNR, 29#, L-BO, .0371 bpf, 10=6.184" H 11360' DATE 10/29n7 08/08191 12/11/94 11/16/95 01/22101 03/02101 REV BY COWMENTS ORIGINA l COMPlETION ~ R\NO ~ SIS-MH CONVERTED TO CANVAS SIS-lG FINAL DATE 05109/01 11/17/02 02/09/07 02/12/07 REV BY CCWMENTS CHlKAK CORRECTIONS BM'KAK 9-518" TBG DEP11-I CORRECllO DllNBN Rig Sidetrack & Co~lelìon /PAG DRlG DRAFTCORRECllONS SAFETY N 5: **WARNING: RADIO TRANSMITTER IN WEATHER MONITORING SHACK MUST BE TURNED OFF BEFORE ANYWELLWORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PAD OPERATOR** 1,554' 1,750' 1839' 1846' 1857' 2018' 1-113-3/8" L-BO, 68#, I.D."12.415' I H 13-318" X 9-5/S" TMI PKR I H TOP OF 9-5/S" PBR (12') I H BOTTOM 9-518" SEA l ASSEMBLY 1 I BOTTOM 9-518" DUPLEX SHOE TOC in 7" Tieback H 7" x 9-5/8" BKR PKRlHanaer H 4-1/2" 12.6". L·80, TCII H4112" X Nipple (3.813" D) H 7" x 4 112" Baker S3 Packer H4112" X Nipple (3.813" 10) H41/2" XN Nipple (3.725" D) 5" X 7" BKR HGR PKR 4 1/2" VIIlEG 14-1/2",12.6#, l-SO, !BT-M Productìon Uner -J 14178' I PBm-14090' 9340' H4-112" CUTOFF TBG Sl1JB I 9341' H5-3/4" CUSTOM OVERSHOT, 10 = 4.655" 9348' Hr BKR SABL-3 PKR WI KBH-22 ANCHOR, 10 = 3.875" I 10516' H4-1I2"VIIlEGI 11259' 2 SLIPS OFF SCA B lNR ON BTM (11/16/95) PRUDHOE SA Y UNIT wal: A-05Ai PERMT No: 2Q6..128 API No: 50-029-20116-01-00 SEC 35, T11 N, R13E, 1S95' FNl & 922' Fa. BP Exploration (Alaska) A-05Ai ~ !7l--0tJj . Subject: A-05Ai From: "Nadem, Mehrdad" <NademM@BP.com> Date: Wed, 20 Dee 200615:05:07 -0900 To: wìnton_aubert@admin.state.ak.us Winton, I sent you a schematic of A-05Ai sometime ago, but it appears that 2ES will be moving on A-05 on Christmas day. The delay on getting on A-05Ai provided me with time to improve on the completion. This change includes cementing the entire 9-5/8"-13-3/8" x 20"-18-5/8" annulus. The previous plan would have left residual oil in part of the annulus. The existing plan is to decomplete about two joints of 13-3/8' casing. A new string of 13-3/8" will be run to above the ground level. A short stub of 20" conductor will be bolted to the existing 18-5/8" starter head, and will also be brought to the Pad level. This conductor will be cemented to surface as part of cementing the outer-outer-annulus. The new completion will allow bringing the A-5Ai cellar to grade with the rest of the Pad. Cementing of the annulus will be achieved by perforating circulation hole in the 9-5/8" casing. The original plan called for FIT of the 8-1/2" hole to 11.8 ppg EMW. We intend to perform this FIT to 12.0 ppg EMW. Please let me know if you need any additional information. Happy Holidays, Mehrdad Nadem Operations Drilling Engineer Phone: 907/564-5941 Cell: 907/440-0213 Email: nademm@bp.com §ÇJ\NNED 2 --.--.--,--..--..-.-'-,"---.'------.".- ~...__._.------,_.--_.---_._---_._.- ----.- -~---------...,-.-. -.- ------.~-~..- ----- -----_._------------~..._- From: Winton Aubert [mailto:winton_aubert@admin.state.ak.us] Sent: Tuesday, September 19, 20069:50 AM To: Nadem, Mehrdad Subject: Re: A-05Ai Please attach the schematic. Thank you, Winton Aubert AOGCC 793-1231 Nadem, Mehrdad wrote: Winton, As requested, I am sending the attached schematic for A-05Ai. Please let me know if you need any additional information. Thanks, Mehrdad Nadem Operations Drilling Engineer Phone: 907/564-5941 Cell: 907/440-0213 Email: nademm@bp.com F"."='~='~=-.o--'''-'-'- --,--==. .-=-..=='"===---=-~==> From: Winton Aubert rmailto:winton aubert@admin.state.ak.us] Sent: Friday, September 15, 2006 2:14 PM To: Nadem, Mehrdad Subject: Re: A-05Ai Mehrdad, 10f3 12/21/20066:51 AM A-05Ai.jpg (JPEG Image, 681x807 pixels) . . A-05Ai Proposed Completion 11' I" rQ.t~ H ~500' att:t:<¢i MA Cdut H 0000' j¡.$f¡"1!1",12J!i1l. L-«t,IIT-tHffliiIwtla lhr H 14,0$7' 1001S Ht-1tl'WlOO PIIO!»roe8AY t.II«T WELl; A.Q5 PI':!!IIIf 1+>: ff2l:lŒ!tl AI'11*': ~21n$4J sa::;:iØ.THII.!!13f. ~fNl."'UZ· œ. SIIl:lp!OI1IlIon (AlathS ì 1 of 1 12/21/20066:51 AM III ,....__. .. -- .~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMI\ìn;1SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commission Anchorage 1 b. Well Class: ~ Development 0 Expl~tory o Stratigraphic ~ S~ice 12. Permit to Drill Number 172-008 3~284 13. API Number / 50-029-2011~0-00 14. Well Nam and Number: 1 a. Well Status: 0 Oil 0 Gas 0 Plugged ~ Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1896' FNL, 923' FEL, SEC. 35, T11 N, R13E, UM Top of Productive Horizon: 3077' FNL, 525' FEL, SEC. 34, T11 N, R13E, UM Total Depth: 2966' FNL, 645' FEL, SEC. 34, T11 N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 654462 y- 5948551 Zone- ASP4 TPI: x- 649605 y- 5947272 Zone- ASP4 Total Depth: x- 649483 y- 5947381 Zone~ ASP4 18. Directional Survey 0 Yes 181 No OCT 0 5 2006 Zero Other 5. Date Comp., Susp., or Aband. 9/10/2006 6. Date Spudded 03/14/1979 7. Date T. D. Reached 04/10/1972 8. KB Elevation (ft): 65.90' 9. Plug Back Depth (MD+ TVD) 11259 + 9245 1Ft 10. Total Depth (MD+TVD) , 11370 + 93-9() 11. Depth where SSSV set V ~ A Dt1\J 19. Water depth, if ok: re ' ~ ~L 21. Logs Run: OIL / SP, BHCS / GR, LL-3, FDC / CAL, SNL / CAL, CBL / GR 22. CASING, LINER AND CEME I CASING SIZE 30" 20" x 18-5/8" 13-3/8" x 9-5/8" 9-5/8" x 10-3/4" GRADE Wr. PER FT. Conductor 133# / 96.5# 68# /47# 47# /55.5# 29# K-55 N-80 N-80 N-80 ~ 7" 23. Perforations open to Production (MD + TVD of To an Bottom Interval, Size and Number; if none,~' 0 "): MD TVD MP TV~ ~fp ~ t5CANNED NO\J {} 2 ¿üDß ~ SIZE 4-1/2", 12.6#, L-80 (Cut Tubing) PBU A-OS 15. Field Pool(s): P dhoe Bay Field / Prudhoe Bay 001 16. Property Designation: ADL 028287 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) Cemented to Surface with PF II 8700 sx PF II (Multiple Staaes) 1625 sx Class 'G'. 525 sx PF II 100 sx PF II (Top 3 jts 11-3/4" x 9-5/8" Thermocase) 485 sx Class 'G' DEPTH SET (MD) 10516' at 8669' PACKER SET (MD) 9200', 9348', 10472' (Pull Later w/ Rig) 26. Date First Productroh:- .. Not on Production Date of Test Hours Tes d PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Flow Tubing Press. 27. PRODUCTION FOR TEST PERIOD + Pressure CALCULATED 24-HoUR RATE+ OIL -BSL OIL-BsL DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED o· -:9001' P&A with 44 Bbls Class 'G' -8770' 2nd P&A Plug with 6 Bbls Class 'G' GAs-McF WATER-BsL CHOKE SIZE GAS-OIL RATIO GAs-McF WATER-BsL OIL GRAVITY-API (CORR) CORE DATA Brief escription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). mit core chips; if none, state "none". RBDMS BFL 0 CT (} 9 Z006 Form 10-407 Revised 12/2003 0 R \ G \ N A ~TINUEO ON REVERSE SIDE G 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10802' 8819' None Shublik 10828' 8843' Ivishak 10910' 8919' 30. List of Attachments: Summary of Pre-Rig Work, Well Schematic Diagram 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ) / Signed Terrie Hubble ~ QJ)fiig . ~ ~ Title Technical Assistant Date I 0; CI-{ !to PBU A-05 172-008 306-284 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mehrdad Nadem, 564-5941 Permit NO.1 Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Digital Welltïle Page 1 of 3 Well Events for SurfaceWell - A-OS Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC3 -> A -> A-OS Date Range: 24/Aug/2006 to 04/0ct/2006 Data Source(s): DIMS¡ AWGRS Events Source Well AWGRS A-OS A WGB5 A-OS Date 10/04/2006 10/03/2006 AWGRS A-05A 10/03/2006 AWGRS A-05A 10/02/2006 A~GBS A-OS 10/01/2006 AWGß~ A-05A 10/01/2006 AWGRS A-OS 09/30/2006 AWGRS A-OS 09/30/2006 A WGR5 A-OS 09/27/2006 AWGRS A-OS 09/27/2006 AWGRS A-OS 09/26/2006 AWGRS A-OS 09/26/2006 AWGRS A-OS 09/26/2006 A WGRS A-OS 09/25/2006 A WGRS A-OS 09/24/2006 Description Stand by for grease crew to rig off IA valve-- RDMO T/I/O/OO= 0/0/80/40 MIT OOA 1500 psi ** FAILED**, would not show pressure stabalization. CMIT TxIAxOA 2000 psi (RIG ST) Pumped 5 Bbls Neat¡3 Bbls crude to pressure OOA to 1250 psi stopping every 250 PSI for 15 Min. MIT failed 4 times¡ Bled OOAP. Pumped 11 bbls Neat down IA to pressure T/I/O to 1240/1340/1250/1250 psi, passed 2nd CMIT TxIAxOAxOOA bleed T /1/0 = 0/0/80 T/I/O/OO = vac/vac/80/40. Temp = S1. Assist Little Red with MITOOA. During MITOOA¡ no evidence of conductor producing crude. No bubbling or audible gas. T/I/O/OO = vac!vac/100/20. Temp = S1. Install Katch Kan (confined space). Installed 30" Katch Kan around conductor. *** Job continued from 09-30-06 *** Post MIT OOA bleed pressures and rig down. FWP's = 0/0/40/10 T/I/O/OO = vac/vac/100/20. Temp = S1. Eval for SC leak detection. OOA FL @ 110'. Cellar is 8'x12'x6' deep with approx. 5" of fluid in the bottom. The open conductor is full of gravel and oily fluid. A fluid sample from the cellar will be taken to the lab. T/I/O/OO = 0/0/100/20 Circ-out (Pre sidetrack) Pumped 5bbls meth, 668bbls seawater, 82bbls 60/40, down tubing, through cut, up lA, into A-40's flowline. FP IA w/ 44bbls 60/40 (displacing 44bbls 60/40 out of tubing). CMIT TxIA failed. TxlAxOA communication. MITOOA - Loaded OOA w/83.5 bbls crude and 30 bbls 60/40 meth water. Unable to test per gas and oil bubbling out conductor. FWP's = 0/0/80/20 *** NOTE: Oil in cellar, gas bubbling and oil leaking out of conductor, FO notified *** *** Job continued on 10-01-06 WSR *** T/I/O/OO = 0/0/100/20 Circ-out (Pre sidetrack) Pumped 5bb!s meth, 668bbls seawater, 82bbls 60/40, down tubing, through cut, up lA, into A-40's flowline. FP lA w/ 44bbls 60/40 (displacing 44bbls 60/40 out of tubing). CMIT TxIA failed. TxIAxOA communication. fvlITOOA PASSED/FAILED to 1500psi. Lost xxpsi 1st 15min, xxpsi 2nd 15min for a total of xxpsi in 30 min. Bled pressures to zero. FP A-40's Flowline w/ 50bbs 60/40. FWHP's = WELL SHUT IN ON ARRIVAL. SSV CLOSED. PUNCH TUBING FROM 8610' TO 8612' WITH 2" SMALL "PINK" PUNCHER LOADED 4 SPF. STRING SHOT TUBING WITH 2 STRAND STRING SHOT 10' ABOVE AND 2' BELOW PROPOSED CUT DEPTH FROM 8659' TO 8671'. CHEMICAL CUT THE TUBING AT 8669' WITH 3 3/8" SEVERING HEAD WITH 3 3/8" ANCHOR BODIES. MAX TOOLSTRING OD IS 3.375" AND IS RUN WITH 3 x 4" GEMCO CENTRALIZERS. MAX TOOLSTRING LENGTH IS 31.4'. DEEPER DEPTH REACHED ON EACH DESCENT. TAGGED AT 8742' WITH TUBING PUNCHER. TAGGED AT 8749 AND 8759' WITH STRING SHOT. RAN TO 8770' WITH CHEMICAL CUlTER WITH NO BOBBLES. DID NOT GO DEEPER TO AVOID BURYING TOOL IN CEMENT. WELL SHUT IN ON DEPARTURE. SSV CLOSED. Circ-Out recommended to take place ASAP as to make sure cement doesn't set up over chemical cut. *****JOB COMPLETE***** *** CONTINUE FROM 09-26-06 *** DRIFT TBG RUN 3.75" SWAGE.SLIGHT RESTRICTIONS FROM 8220' SLM DOWN TO 8400' SLM¡ WORKED SPOTS UNTIL TOOLS FALL FREELY TAGGED CEMENT BOlTOM @ 8720' SLM *** WELL LEFT S/I *** *** WELL S/I ON ARRIVAL *** (PRE SDTRK) RIG UP SLICKLINE UNIT TO RE-DRIFT FOR CHEM CUT *** CONTINUE ON 09-27-06 *** WELL SHUT IN ON ARRIVAL. SSV OPEN. RAN 3.65" POWERCUlTER. MAX TOOLSTRING LENGTH=16.5'. MAX OD=3.65 WITH 4.1" GEMCO CENTRALIZERS THAT WILL COMPRESS. SAT DOWN REPEATEDLY AT 8240'. DECISION MADE TO POOH. LOWER HEAD OF JET CUlTER RUBBED TO A SHINE. WELL SHUT IN ON DEPARTURE. SSV LEFT OPEN. Job Not Complete. Turn well over to Slickline to clear obstruction. Leaving Surface Rental Equipment on Location for Slickline *** CONT FROM 09-25-06 WSR *** (drift for chem cut¡ pre sdtrk) DRIFTED W/ 3.25 CENT & SAMPLE BAILER TO 8708' SLM... CEMENT IN BAILER¡ DRIFTED W/ 2.70 CENT & SAMPLE BAILER TO 8710' SLM- 8730' CORRECTED DEPTH ... CEMENT IN BAILER. PT CEMENT TOP TO 3000#.. GOOD TEST. RDMO *** WELL LEFT SI *** ***WELL S/I ON ARRIVAL*** (drift for chern cut) DRIFTED W/ 3.70 CENT & S-BAILER TO 8701' SLM... HAD TO WORK TOOLS FROM 8210' TO 8348' & 8633' TO 8701' SLM¡ MADE COUPLE PASSES FROM 8200' TO 8700' W/O ANY PROBLEMS... SAMPLE OF WHAT APPEARS TO BE CEMENT IN BAILER *** JOB IN PROGRESS/ CONT ON 09-26-06 WSR *** CTU #5. PT Cement Plug. *** Continuation of WSR 09/23/2006 *** Set Baker IBP at 8915' hUp:11 digi tal wellfile. bpweb. bp.com/W ellEvents/HomefDefault.aspx 10/4/2006 ctm. Attempted to PT cement cap twice. First 3000 psi PT attempt lost 272 psi over 30 minutes. Second attempt lost 240 psi over 30 minutes. Performed visual No-Flow test to insure pressure lose was not at surface. Released IBP and POOH. Recovered all rubber elements from lBP. MU BHA #2, 3.0" BDN. RlH. Tag 9080'ctm, PUH to 9065', Rig up and PT cementers. Pump 6 bbls lS.8ppg class G cement. Lay in from 9065' to 8616' ctm. PUH to safety. Hesitate squeeze to 3500psi. Drop 7/8" ball and contaminate with 1.5# biozan. Clean out to 8900'. POOH at 80% chasing to surface. RIH and freeze protect with 60/40 MeOH from 2500'. Trap 100 psi on wellhead at surface. RDMO CTU. Notified Pad Operator of well status. Final T/I/O/OOA = 110/20/0/0 *** Job Complete *** CTU #5. PT Cement Plug. MIRU.Perform weekly BOP test. MU Baker 3.38" IBP. RIH to 8915' ctm. Begin setting procedure on IBP. *** Job continued on WSR 09/24/2006 *** ***CTU #5 Standby on well flowback/safelty.....Road unit to M-pad***JOB INCOMPLETE*** *** JOB CONT. FROM 9/16/06*** RUN 2.30" CENT. 3' x 1 1/2 " STEM, SAMPLE BAILER, SD @ 9022' SLM, POSSIBLE TOC.HAVE SAMPLE OF CEMENT, APPEARS TO BE SLURRY TYPE MIXTURE, GOOD SAMPLE. ***WELL 5/1 ON DEPARTURE*** ( NOTIFIED PAD OPERATOR) *** WELL 5/1 ON ARRIVAL *** RU DC#6 FOR D&T W/SB. ***JOB IN PROGRESS, CONT. ON 9/17/06*** T/IA/OA/OOA = 51/0/0/0 (Pre Rig Inspection) (Purge Plastic Pak from OOA Void) Unable to Purge Plastic from void OA bled to 0 psi. Removed internal check and installed alemite test fitting. Rigged up test equipment, unable to move plastic packing thru void to bleeder port. Test fluid leaking pass seals, pumped total volume of (1 1/2) gallons. Would not build pressure with bleeder closed. 09/16/2006 T/I/O/OO= vac/O/O/O Temp= 5/1 MIT T ***FA1LED*** to 3000 psi. Pressured up tubing to 3000 psi w/ 2.7 bbls 60/40 meth water. 2nd test results- 1st 15 min lost 100 psi, 2nd 15 min lost 170 psi w/ a total of 270 psi in 30 min. Bled back 2 bbls. Final WHP's= 0/0/0/0 09/15/2006 T/I/O/OO= Vac/80/50/105. Temp= 51. (WAG WELL). Bleed WHP's to 0 psi (pre-Cam, pre- RWO). TP unchanged, lAP increased 25 psi, OAP decreased 10 psi and OOAP increased 5 psi overnight. Bled WHP's to Vac/O/O/O psi in 4 hrs and 40 minutes. Monitored for 30 minutes. Final WHP's= Vac/O/O/O. NOTE: There are several studs on the SSV to Master flange that do not meet API spec for thread engagement. 09/15/2006 T/1A/OA = 51/0/0 (Pre Rig Inspection) PPPOT-1C = Still in Progress PPPOT-T = Passed DHD Tech Grant Chiacchia bled IA and OA to 0 psi. Functioned and torqued lockdown screws to 550 ft/lbs. Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up tubing hanger void to 5,000 psi. for 30 mins. -(Passed) Functioned and torqued lockdowns too 550 ft/lbs. on inner casing hanger. - Rigged up test equipment and pumped until clean fluid returns were achieved. Unable to pressure up, energized "yn seals thru packing port, unable to achieve returns, abandon test.(Failed). May test after future well work completed. 09/14/2006 T/I/O/OO= 130/390/450/360. Temp= 51. (WAG WELL). Bleed WHP's to 0 psi (pre-RWO). Bled WHP's to Vac/35/65/100 psi in 2 hrs and 30 minutes. Captured approximately 15 bbls of fluid from the IA during the bleed. Monitored for 30 minutes. lAP increased 20 psi and OAP decreased 5 psi. Final WHP's= Vac/55/60/100. 09/13/2006 JET CUT 4.5" TUBING. JOB CANCELLED DUE TO FAILED M1T OF TUBING. DID NOT RIG UP. 09/13/2006 T/I/O/OO= 180/360/480/340. CMIT TxIA to 4000 psi. (FAILED) OA tracked w/ IA. CMIT TxIAxOA to 2000 psi. (FAILED) on 2 attempts. Pumped 21 bbls 60/40 meth to achieve test pressure. Lost 90/90/70/0 psi @ 15 min, 50/50/60/0 psi @ 30 min, and 70/60/50/0 psi @ 45 min. Bled down pressures. MIT T to 2000 psi. (FAILED) on 2 attempts. Pumped 2.5 bbls 60/40 meth to achieve test pressure. Lost 70 psi @ 15 min, 80 psi @ 30 minI and 80 psi @ 45 min. MIT T to 3500 psi. (FAILED) Pumped 1 bbl to achieve test pressure. Lost 180 psi @ 15 min and 180 psi @ 30 min, and 160 psi @ 45 min. Bleed down pressure. Final WHP's = 20/450/520/340. T/I/O/OO = 10/370/450/350. Temp = 5/1. No AL to Well. T & IA FLs (pre CMIT). TBG FL @ 2136' (33 bbLs). IA FL Near Surface. *** WELL 5/1 ON ARRIVAL *** RIH W/ 3.7 CENT, SB, TAG CEMENT @ 9001' SLM. *** WELL LEFT 5/1 ON DEPARTURE *** CTU #6, P&A; Co nt' from WSR 9/09/06 ... Kill well. RIH with 2.75" BDN. Mix and pump 44 bbls Class 'G' cmt at 15.8 ppg. Lay cement in from PBTD- 11093'. Est TOC at 9100'. Pump 20 bbl Biozan sweep. POH at 80% - FP well to 2500 with 50/50 meth - Trap 300 psi on well - RDMO. Notify PCC / PO of well shut in status. **** Cement Job Complete **** Pressures T 300 / IA 430 / OA 500 / OOA 300 09/09/2006 CTU #6, P&A; MIRU - Weekly BOPE test - Good test - Notify AOGCC of P&A -(Jeff Jones w/AOGCC waived witness of PM) MU/RIH with PDS CCL/GR/Temp. Tag TD at 11107' up- Park for BHT - PUH logging at 30 fpm from 11105' to 9100'. POH. Corrected PBTD found at 11093' elmd. MU 2.75" BDN assy. PT lubricator and squeeze skid valves to 250/4000 psig. Begin well kill / fluid pack with KCL. Cont' on WSR 9/10/06 ... DIgItal Wellfile AWGRS A-05 09/23/2006 AWGRS A-05 09/21/2006 AWGRS A-05 09/17/2006 AWGRS A-05 09/16/2006 8W~RS A-05 09/16/2006 AWGRS A-OS 8WGR5 A-OS AWGRS A-05 AWGRS A-OS AW~RS A-05 AWGR~ A-05 AWGR5 A-05 09/12/2006 AWGRS A-05 09/11/2006 AWGRS A-05 09/10/2006 AWGR5 A-05 Page 2 of 3 http://digitalwelJfile.bpweb. bp.com/W elJEventsfHome/Default.aspx 10/4/2006 Digital Wellfile p. WGRS A-OS 09/09/2006 AWGRS A-OS 09/08/2006 AWGRS A-05 09/04/2006 A WGR5 A-05 09/03/2006 Page 3 of 3 AWGRS A-05 T/I/O/OOA=SI/200/540/S00, Assist coil. Load IA with 76 bbls of crude, left 570 psi. on IA per coil PE. FWHP=SI/570/860/500. T/I/O/OO= 790/220/520/520. Temp= 51. Tubing & IA FL (pre-CT). Tubing FL @ 2184' (33 bbls). IA FL @ 360' (8 bbls). ***JOB CONT. FROM 9/3/06*** DRIFTED TO 10505' SLM/TUBING TAIL W/ BLB AND 2.625" GAUGE RING DRIFTED TO 10505' SLM/TUBING TAIL W/ BLB AND 3.65" CENTRALIZER ***WELL TURNED OVER TO DSO*** ***JOB CONT. FROM 9/2/06***(pre-sdtrk) FINISH 8'X3" DRIVE DOWN BAILER DRIFT TO P- PRONG, BAILER BACK 1/4 FULL OF SHMOO PULLED P-PRONG FROM TOP LOADER PLUG @ 9312' SLM TAGGED PLUG BODY W/ 3.805" GAUGE RING @ 9317' SLM CLEANED OUT BODY OF TOP LOADER W/ 3" PUMP BAILER AND SNORKLE BTM HAVE TO MAKE 2 RUNS TO PULL TOP LOADER W/ 4.5" GR @ 9316' SLM. ***JOB CONT. ON 9/4/06*** 09/02/2006 *** WELL SHUT IN ON ARRIVAL *** (PRE SDTRK) RIH W/ 3.805" GAUGE RING AND 3" JDC TO PULL PRONG, SAT DOWN @ 29' SLM RIH W/ 8' OF 2-1/4" DRIVE DOWN BAILER, DIFFICULTY RUNNING THROUGH 650'-775' SLM, TAGGED PRONG @ 9318' SLM, BAILER HALF FULL OF SHMOO RIH W/ 8' OF 3" DRIVE DOWN BAILER, HAD TO WORK THROUGH 1000'- 1379' SLM, INTERMITANT TIGHT SPOTS THROUGHOUT TUBING, TAGGED PRONG ***JOB CaNT. ON 9/3/06*** 08/24/2006 T/IA/OA/OOA= 51/400/490/400 Pre Rig well head inspection and ID. Note well at this time still has internal checks. FMC 20" 3m start head slips unknown with McEvoy 20" 3m X 13- 5/8"Sm YB casing spool, with McEvoy 13-5/8"5 2-step casing spool. Tubing spool has [2] 3- 1/8" 550 casing spool has [1] 3-1/8" 550 Adapter flange is a McEvoy 5 seal 625 inlay with McEvoy 6-3/8" model C tree Otis Act. type U AWGRS A-OS Refresh List I http://digitalwel1file.bpweb. bp.comIW eJ1Events/Home/Default.aspx 10/4/2006 TREE = 7-1/16" 5M CrYV · W8...LHEAD =13-5/8" MCEVOY -CONV SAFETY NOTES: 9-5/8" CSGSET ON EMERGENCY SLIPS. WARNING: RADIO TRANSMITTER IN WEATHER MONITORING SHACK MUST BE TURNED OFF BEFORE ANYWELLWORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PAD OPERATOR A-OS l ) ~ ~~ :~ 6~ NY OTIS 65.89' 46.17' 2800' 54' 10852' 8800' SS ACTUATOR = . ~~- - -- -- ---- KB. 8...EV = ~ --.- - .. - .- BF. 8...EV = ..- ._~-"-,~--~.~.~,,- KOP= Max Angle = ~- --- - --~~.. -- Datum MD = ~ -_. ~.- - Datum 1VD = 1-19-5/8" X 7" XO, ID = 6.06" 1 1-118-5/8" X 20" XO 1 1-113-3/8" X 9-5/8" TrYV A<R 1 1-1 TOP OF 9-5/8" PBR (12') 1 l-t BOTTOM 9-5/8" SEAL ASSEMBLY I 1-1 BOTTOM 9-5/8" DUPlEX SHOE I~ I~ 1-14-1/2" HES X NIP, IS = 3.813" 1 1-1 TOP OF CEMENT (S9/10/'Oð) 1Cf1{l,7/D<Þ 1-14-1/2" HES X NIP, ID = 3.813" 1 1-17" BAKER S-3 A<R, ID = 3.875" 1 1-1 BTM OF 7" TIEBA CK STINGER 1 44' :8 1554' 1839' 1846' 1857' 2018' 2065' 2146' 2213' ~ 9190' 9200' 9293' ~ 13-3/8" CSG, 72#, N-80 -I 2018' BTRS, ID = 12.347" Minimum ID = 3.725" @ 9328' 4-1/2" HES XN NIPPLE 20" CSG, 133#/ft, -I 2278' ~ K-55 BTRS, ID = 18.730" TBG AJNCH, 4 SPF (09/27/06) 1-1 8610 - 8612' I CHEM CUT (09/27/06) 1-18669'1 I ESTIMA TED TOP OF CEMENT 1-1 8800' 1 14-1/2" TBG, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" I TOP OF 40' TrYV PBR 1-1 9272' ~ ~ ~ NOTE: HOLES IN 7" LNR BETWEEN 7" BKR STRADDLE ~ PKRS (10420-10468). PROD LOG OF 03/03/96 FOUND LEAKS @ 9285' (BTM OF 7" SCAB LNR & 9336') (5-3/4" OVERSHOT ON 4-1/2" TBG) 9306' 1-14-112" HES X NIP, ID = 3.813" 1 9316' 1-I8...MD TT LOG NOT AVAILABLE 1 9328' 1-14-1/2" HES XN NIP, ID = 3.725" 1 9340' 1-14-1/2" CUT OFF TBG STUB 1 9341' 1-15-3/4" CUSTOM OVERSHOT, ID = 4.655" 1-17" BKR SABL-3 PKR W/ KBH-22 ANCHOR, ID = 3.875" 19-5/8" X 7" TrYV LNR TOP PKRlHGR W/40' PBR 1-1 9312' 19-5/8" TBG, 47#, L-80, .0732 bpf, ID = 8.681" 1-1 9814' NOTE: RWO OF 11/16/95 LEFT OLD 7" BKR SABL-3 STRADDLE PKRS IN W8...L. NEW 3.725" ID XN NIP PREVENTS W/L ACCESS FOR sm PlUG SETS ON LOWER NIPPLES. ÆRFORA TION SUMMARY REF LOG: BHCS 04/09/72 ANGLEATTOPÆRF: 23 @ 10806' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-1/8" 4 10806 - 10826 S 08/08/91 4" 4 10914 - 10924 S 08/08/91 4" 4 10932 - 10942 S 08/08/91 4" 4 10952 - 10964 S 08/08/91 4" 4 10974 - 10994 S 08/08/91 3-3/8" 6 10806 - 10826 S 09/10/06 3-3/8" 6 10912 - 10942 S 09/10/06 10449' 1-14-1/2" HES X NIP, ID = 3.813" I 10472' 1--i7" BKR SABL-3 PKR WI HYD SHEAR ANCHOR, ID = 3.875" 10486' 1-14-1/2" HES X NIP, ID = 3.813" I 10504' 1-14-112" HES XN NIP, ID = 3.725" 1 10516' 1--i4-1/2" WLEG I 10500' 1-1 8...MD TT LOGGED 03/03/96 10734' 1-1 MA RKER JOINT (20') 1 4-1/2" TBG, 12.6#, L-80 NSCT, -f 10516' .0152 bpf, ID = 3.958" I 11259' 1-12 SLIPS OFF SCAB LNR ON BTM (11/16/95) 1 I PBTD 1-1 11259' 17" LNR, 29#, L-80, .0371 bpf, ID=6.184" 1-1 11360' DA TE REV BY COMMENTS 09/10/06 JGrvVTLH P&A 09/27/06 RRD/PA G TBG AJNCH, CHEM CUT PRUDHOE BA Y UNrr WaL: A-05 ÆRMrr No: '1720080 API No: 50-029-20116-00 SEC 35, T11N, R13E. 1895' FNL & 922' Fa REV BY COMMENTS ORIGINAL COM PLETION RWO RWO RWO CHlKA K CORRECTIONS GJF/PAG PXN PLUG AJLLED DATE 10/29/77 08/08/91 12/11/94 11/16/95 05/09/01 09/03/06 BP Exploration (Alas ka) A-05Ai Subject: A-05Ai From: "Nadem, Mehrdad" <NademM@BP.com> Date: Fri, 15 Sep 2006 13: 13:26 -0800 To: winton_aubert@admin.state.ak.us CC: "Wesley, Dave E" <Dave.Wesley@BP.com> Winton, This Email is to apprise you of changes in the scope of work for A-05Ai. We have received an approved Sundry for A-05, and a "Permit to Drill" for A-05Ai. However, we plan and will cement it to surface. In addition to this task, we will would serve as the new casing starter head. We are in the final stages of finalizing the Drilling program, and would like your guidance on whether we need a new Sundry and/or a new permit to Drill? Please advise. I appreciate your assistance in advance. Mehrdad Nadem Operations Drilling Engineer Phone: 907/564-5941 Cell: 907/440-0213 Email: nademm@bp.com 1 of 1 9/19/200611:10 AM . . l i ! FRANK H. MURKOWSKI, GOVERNOR AItASIiA OILAlWD GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-05 Sundry Number: 306-284 ~CANNE.D A\JG 2 9 2.DDß Dear Mr. Wesley: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this~~y of August, 2006 Enc!. l'1d -oóß OP Ó 12Z...~ ¡(f'c.. g-J.!)...J I~.c ~6{~ f1' _- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVAL RECËlJËö/20Db 20 AAC 25.280 as â I Gas Cons. ,. I 1. Type of Request: 181 Abandon / o Suspend o Operation Shutdown o Perforate o Time ExtensionAnchorage o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: / 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development o Exploratory 172-008 ./ 3. Address: D Stratigraphic 181 Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20116-00-00 /' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU A-OS / Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028287 65.90' Prudhoe Bay Field / Prudhoe Bay Pool 12, PRESENTWELL CONDITION SUMMARY .... ..... , .'. Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): IEffective Depth TVD (ft): Plugs (measured): Junk (measured): 11370 9349 11259 / 9245 10504 11259 Casino Lenath Size MD / TVD Burst CollaDse Structural Conductor 90' 30" 90' 90' Surface 2278' 18-5/8" x 20" 2278' 2278' 930 870 Intermediate 9814' 13-3/8" x 9-5/8" 9814' 7965' 4930 2270 Production 11360' 9-5/8" x 7" 11360' 9339' 6870 4760 Liner Perforation Depth MD (J' I Perforation Depth TVD (ft): I Tubing Size: / Tubing Grade: Tubing MD (ft): , 10806' - 10942' 8823' - 8949' 4-1/2", 12.6# L-80 10516' /' Packers and SSSV Type: 7" Baker 'SABL-3' packer; 7" Baker 'SABL-3' packer; packers and SSSV MD (ft): 10472'; 9348' 9200' 7" Baker 'S-3' packer /' 13. Attachments: 14. Well Class after proposed work: / 181 Description Summary of Proposal o BOP Sketch D Exploratory D Development 181 Service D Detailed Operations Program 15. Estimated Date for AU9U~~006 16. Well Status after proposed work: Commencina ODerations: DOil o Gas D Plugged 181 Abandoned 17. Verbal Approval: ~~ DWAG DGINJ OWINJ o WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mehrdad Nadem, 564-5941 Printed Name DSl~ Wesley ./""'"'\ Title Senior Drilling Engineer Prepared By Name/Number: Signature fi~¿~ é/.£ £7 X- Phone 564-5153 Date Y/;7~Þ Terrie Hubble, 564-4628 " L, Commission Use Onlv T Sundry Number~~ð . ;t~L/ Conditions of approva~tify Commission so that a representative may witness æ(PIUg Integrity BOP Test D Mechanical Integrity Test D Location Clearance Other: Te s t BoP t fo 4-000 y? CA! . , ~ý ~~t~ vv--etl A-05Æ;-. A-Prwt.J(J r-:ov VV'- 10 - 4v[ "1w<N"d Subsequent Form Required: lo - ~~ en APPROVED BY gj.11 {h Approved By: T / 7V SIONER THE COMMISSION Date Form 10-403 Revised 06/2006 \..,../ \../ ubmit In Duplicate - ,4UG 1 8 200ó AI k 0"1 & on OR\G\NAL RBDMS BFl AUG 2 4 2006 . . Obp GL.a.ArAiT To: Winton Aubert - AOGCC Date: August 17, 2006 From: Mehrdad Nadem - BPXA GPB Rotary Drilling Subject: A-05 Application for Sundry Approval - P&A for Sidetrack Operations Approval is requested for the proposed P&A of PBU well A-05. Well A-05 is a Sag river and Zone 4B injector -- that is currently shut-in for inner annulus, and outer annulus (IAxOA) communication. The well failed MIT-IA on November 29, 2002. This well is currently secured with a PXN plug set at 9,28B' on October 16, 2002. Well A-05 began production in 1978 with initial oil rates of 4790 BOPD. A RWO was needed in March 1985 to replace the 7" tubing with 4-1/2" tubing and to provide GLMs. A RWO in August 1991 pulled the collapsed 4-1/2" tubing to install 5-1/2" tubing without GLMs to prepare the well for conversion to injection. The 13-3/8" x 9-5/8" packer at 1839'MD failed prior to a 1991 frac treatment. A RWO in December 1994 was needed to repair leaking 9-5/8" casing with a scab liner. However, the latest RWO on A-05 was needed a year later in November 1995, due to a failed 7-5/8" x 9-5/8" scab liner packer set to 2560'MD during the 1994 RWO. This scab liner was removed and replaced with a 7" scab liner from the top of the production liner (9727 'MD) to surface (1 joint of 9-5/8" was used to crossover for tree purposes). Following the 1995 RWO, the tubing below the packer was found to have a leak to the 7" x 9-5/8" annulus. On an LDL 3/3/96, a leak path can be seen from the tubing stub at 9340'MD that travels up to the 7" PBR at 9272'MD and into the 7" x 9-5/8" annulus. Because of the leak, the well was unable to inject MI, so the well is only a produced water injector. A caliper on 10/19/02 shows the tubing in good shape, with a maximum of 22% wall penetration. Evaluation of the pattern showed that the injector only had a small effect on A-14. A new well would be able to serve the surrounding producers more efficiently, and the new completion will justify a Very Favorable MI ranking. ...-- The plan is to exit the parent A-05 well bore at -8,200' MD. A whipstock will be run and an 8-1/2" window will be milled in the 9-5/8" casing. An 8-1/2" hole will be drilled to the Top of the Sag River formation. A 7" drilling liner with tie back to the surface will be run and cemented. Cement top will be at 2,BOO'. The 6-1/8" well bore /' will be drilled to Zone 4B. The planned 4-1/2" segment of this well runs for approximately -3,063'. A solid 4-1/2" liner will be run and cemented with 150' liner lap into the 7" drilling liner. The 4-1/2" liner will be perforated. A-05 Application for Sundry . . The A-05Ai sidetrack is currently scheduled for Nabors 2ES beginning the third week of October, 2006. The pre-rig work for this sidetrack will be scheduled after Sundry approval has been obtained. Estimated Pre-Rig Start: Estimated Spud Date: Mehrdad Nadem GPB Rotary Drilling Engineer Ph: 564-5941 cc: Well file Terrie Hubble / Sondra Stewman 08/20/2006 09/1 0/2006 A-05 Application for Sundry . . Operations Summary Pre-RiQ Work: 1. Rig up slick line. Drift 4-1/2" tubing to WLEG at 10516'. Do not RIH below WLEG due to slips being left in the hole. 2. Fluid pack the tubing and inner annulus. 6) 3. P&A perfs in 7" liner from the top of the fish (-11,259') to -9,200' MD. RIH with coil to PBTD. Lay i ",47.6 bbls of cement to -9,200' MD. Wash down to confirm TOC. POH with coil. ., a. Cement Calculations: · 743' of 7",29# liner, 11 ,259' -10'516'r:-~': BLS . 1,316' of 4-1/2",12.6# tubing, 10,516' _,9,200' = 20.0 BBLS . Total cement volume of 47.6 BBLS ' 4. Rig up slickline, drift 4-1/2" tubing. Tag TOC. /" 5. Chemical cut the 4-1/2",12.6#, L-80 tubing at - 8,700' MD. 6. Pressure test T X IA to 3,500 psi for 30 minutes. Pressure test the OA to 2,500 psi for 30 minutes. ""..- 7. Circulate the well to sea water through the Chemical cut. Freeze protect the IA and tubing with diesel to -2,200' . 8. Bleed OA, IA & TBG to zero. Test the 9-5/8" pack-off to 3,500 psi and tubing hanger seals to 5,000 psi. Function all lock-down screws. Repair or replace as needed. 9. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 10. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. - ..f\ RiQ Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protec8i d displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and tes OP. Pull TWC. 4. Pull 4-1/2" tubing from the pre-rig Ch . al cut -8,700'. 5. RIH and chem. cut the 7", 29# liner at 8,500'. 6. POOH, UD 7" liner. 7. RU e-line. Run Gauge Ring / Junk basket and Gamma Ray tool for 9-5/8",47# casing with CCL to tubing stub at - 8,500'. 8. RIH with 9-5/8" EZSV on e-line. Set EZSV at -8,224 or as required to avoid cutting a casing collar during Uindow milling operations. RD e-line. 9. Close rams and pressure test the 9-5/8" casing and bridge plug. If PT fails PU RTTS to find leak. If there is a leak a contingency plan will be sent to the rig. 10. PU 9-5/8" whipstock and bottom trip anchor with an 8-1/2" window milling assembly. RIH picking up 4" DP to EZSV. Orient and set the whipstock. Swap well over to 9.0 ppg milling fluid. Note: If MWD signals are too weak to obtain toolfaces, swap over to milling fluid before setting the whipstock. 11. Mill a window in the 9-5/8" casing at ± 8,200' MD plus 20' from mid window. Perform FIT to 11.5 ppg. POOH for Drilling BHA. Note: Verify that the mud weight is 9.0 ppg prior to cutting the window. . 12. MU the 8-1/2" drilling assembly with DIR/GR/PWD and RIH. Kick off and drill 8-1/2" intermediate interval to 7" casing point -10,770' top setting the Sag River. Mud weight will be increased to 10.9 ppg before drilling into the THRZ. 13. Run a 7", 26#, L-80 drilling liner with 150' liner lap inside the 9-5/8" casing. Fully cement the 7" liner. 14. RU and run 7" Tie-back liner to surface. Top 3,300' of 7" will have prèmium threads. Cement will be brought up to -2,800' MD. Remainder of 9-5/8" by 7" annulus will be freeze protected to surface. 15. MU 6-1/8" BHA with DIR/GR/RES and RIH to the 7" ti~-back landing collar. 16. Pressure test wellbore to 4,000 psi for 30 minutes. / 17. Drill tie-back cementing equipment and RIH to 7" drilling liner landing collar. 18. Pressure test wellbore to 4,000 psi for 30 minutes. 19. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT to 10.0 ppg. 20. Drill the 6-1/8" production interval as per directional; plan. 21. Run a 4-1/2", 12.6#, L-80 solid liner with 100' liner lap inside the 7" drilling liner. 22. Spot a perf pill inside the 4-1/2" liner and release. Displace well to clean seawater. 23. RU DPC perf guns, RIH and perforate. Perf intervals to be supplied by asset -- J ~ ~ ~ IV) ~ "'\:t- () :l \- A-OS Application for Sundry . . 24. Run the 4-1/2",12.6#, L-80 completion tying into the 4-1/2" liner top. 25. Set packer and individually test the tubing to 4,000 psi and annulus to 4,000 psi for 30 minutes each. 26. Set and test TWC. 27. ND BOPE. NU and test the tree to 5,000 psi. 28. Freeze protect the IA and Tubing to -2,200' and secure the well. 29. RDMO. Post-Ria Work: 1. Install well house and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. A-05 Application for Sundry rREE = 7-1116" 5M CPoN IIÆlI,.HEA D = 1-5l8" WCEVOY-CONV CTUA TOR = . OTIS æ. ELEV = . 65.89' SF. ELEV = 46.1T OP = 2800' lax Angle = 54' ) Hum IIID = 10852' )etum TVD = 8800' 55 113-318" CSG, 72#, N-8O H 2018' I BTRS, ID = 12.34T' 1- Minimum ID = 3.725" g 9328' 4-1/2" HES XN NIPPLE 120" CSG, 133#1ft, 1 K-55 BTRS, ID = 18. 73C1' 2278' 4-112" TBG, 12.8#. L-80 NSCT, .0152 bpf, ID = 3.958" ESTIMATED TOP OF CEMENT 8800' I · A-OS l ~ - ..4 ITOPOF 40' TW PeR 9272' ~ NOTE: HOLES IN T' LNR BETWEEN T' BKR STRADDLE! ~ PKRS (10420-10468). PROD LOG OF 03103I96 FOUND 1 LEAKS@9285'(BTMOFT'SCABLNR&9338') / ~ (5-314" OVERSHOT ON 4-112" TBG) 9-518" X 7" TftN LNR TOP PKRlHGR W/4(1 PeR 9312' r I R-!ilS" TRC:: ,4 7. I_An In=ARA1" 1-1 Q 14' PERFORA TION SlMMRY REF LOG: BHCS 04109/72 ANGLE AT TOP PERF: 23@ 10806' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 3-118" 4 10806-10826 5 08108191 4" 4 10914 - 10924 5 08108191 4" 4 10932 - 10942 5 08108I91 4" 4 10952 - 10964 5 08108I91 4" 4 10974-10994 5 08108I91 3-318" 6 10806 - 10826 C 09/19/91 3-318" 6 10912 - 10942 C 08/15191 ~ \ . " . " · I~ ~ ~ / L ~~ lP-~ ..~ ..,~ . .............. -........¡ I Ir-....__ ~ ~ SAfETY~: 9-5I8H CSGSET ON EMERGENCY SUPS. WARNI~O TRANSMITrER IN WEATHER MONITORING SHACK MUST BE TURNED OFF BEfORE ANYWaLWORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PAD OPERATOR 44' 9-518" X 7" XO. ID· 8.08" I 1554' 18-518" X 20" XO I 1839' 13-318" X 9-518" TW PKR I 1848' TOP OF 9-518" PeR (12') I 1857' BOTTOM 9-518" SEAL ASSEMBLY I 2018' BOTTOM 9-518" DUPLEX SHOE I 2065' FOe 2146' ~ 2213' 4-112" HES X NIP, IS· 3.813" I 9190' 1--14-112" HES X NIP, ID = 3.813" I --I 9200' 1--17" BAKER S-3 PKR, ID = 3.875" I - ~ I · I~ ~ · I"~~ ~~ ~..... ~ 9348' ~ 18 ~ ~ · ~ · I ..- ,r / 10516' r 14-112" TBG, 12.611, L-BO NSCT, I .0152 bpf, ID = 3.958" I PBTD I 11259' I.... , .... ""'"74 .... In _ .. 4 DA" -1 .. ........ I DA TE REV BY COMÆNTS 10121I77 ORIGINAL COMPlETION 01108II1 AINO 12/11/14 AINO 11/111II RINO 05109/01 CHlKAK CORRECTIONS 11/17102 BMKAK 9-518" TBG DEPTH CORRECTlQII 9293' BTM OF 7" TIEBACK STINGER I 1-14-112" HES X NIP, ID = 3.813" I HELMDTTLOGNOTAVAIlABLE I 1--14-112" HES XN NIP, ID = 3.725" I 4-112" CUT OFF TBG STUB I 5-3/4" CUSTOM OVERSHOT, ID = 4.655" I 9306' 9316' 9328' 9340' 9341' 7" BKR SABL-3 PKR WI KBH-22 ANCHOR, ID· 3.875" I NOTE: RWO OF 11116/95 LEFT OLD T' BKR SABL-3 STRAOOl.EPKRS IN WELL. NEW3.725"IDXN NIP PREVENTS WL ACCESS FOR STD PLUG SETS ON LOVIIER NIPPLES. . ~ ---i 10449' 4-112" HES X NIP, ID· 3.813" I 10472' 1-17" BKRSABL-3 PKR W HYDSHEARANCHOR,ID= 3.875' I 10486' 4-112" HES X NIP, ID· 3.813" I 10504' 4-112" HES XN NIP, ID· 3.725" I 10504' 4-112" PXN TTP (10/18102) I 10516' -14-112" WLEG I I 10500' H ELMD TT LOGGED 03103I96 I 10734' MARKER JOINT (2(1) I ~ - 11259' -12 SLIPS OFF SCAB LNRON BTM(11/18195) I DATE REV BY COIIIM:NTS 09122105 MRlTLH TIP SET (1 0/16102) PRUDHOE BAY UNIT WELL: A-OS PERMT No: '1j 720080 API No: 50-029-20116-00 SEC35, 111N, R13E, 1895' FNL & 922' Fa. BP E'aplorlltion (Alaska) TREE = Wß..qiEAD = ACTUA TOR = KB. a~ = BF. aEV = KOP= MIx Angle = Datum III) = Datum TVD = 7-1116" 5MCMI 1-518" WCEVOY -CONY OTIS 65.89' 46.1T 2800' . A-OS Proposed Completion SAFE1Y~:I-5I1" CSGSET ON EM ERGENCY SLIPS. WARNINGW!JIO TRANSMITIER IN WEATHER MONITORING SHACK MUST BE TURNED Off BEFORE ANY WB..LWORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACTPADOP~TOR 54' 10852' 8800'SS Minimum ID = 3.725" @ 10600' 4-112" HES XN NIPPLE 13-318" CSG, 721, N-80 -j 2018' BTRS, 10 = 12.347" 20" CSG, 133#1ft, K-55 BTRS, ID=18.73O" ~ 2,800' I Top of 9-518" Wndow H 17" liner cut.. H 14-112",12.61, L-80 Tbg cut. H ITOP OF 40' TIN PBR H 8200' 8100' 8700' 9272' ,/"", 1 Est top of P&A Cerrent H / " 900'þ' 2/ 9-518" X 7" T\W LNR TOP PKRlHGR W/4C1 PBR -1 9312' 19-5I8"TBG, 47#, L-80, .0732bpf,ID=8.681" H 9814' ÆRFORA TION SLU.M RY REF LOG: BHCS 04109I72 ANGLEATTOPÆRF: 23 0 10808' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 3-118" 4 10806 - 10828 S 08108191 4" 4 10914 - 10924 S 08108191 4" 4 10932 - 10942 S 08108191 4" 4 10952 - 10964 S 08108191 4" 4 10974 - 10994 S 08108I91 3-318" 6 10806 - 10826 0 09119/91 3-318" 6 10912 - 10942 0 08115191 4-112" TBG, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" I PBTD H 11251' I 17" LNR, 291, L-80, .0371bpf, D = 6.184" H 11380' REV BY cor..wENTS ORIGINAL COMA..ETK>N R\IVO R\IVO I ' / I I I 1 44' 9-518" X T' XO, ID.. 6.06" 1554' 18-518" X 20" XO 1839' H 13-318" X 9-518" TIW PKR I 1848' TOP OF 9-518" PBR (12') 1857' BOlTOM 9-518" SE:AL ASSEMBLY 2018' BOiTOM 9-518" CUPLEX SHOE 7" x 4 112" Baker S3 Packer 4 112" X Nipple (3.813" ID) 4112" XN Nipple (3.725" ID) 4112"WlEG 4 112" Hanger I liner top packer 7" 261 L-80 (6.276" ID) (' 19-514-112",12.61, L-80,IBT-M Fl'oduction Liner H 13833' I 9340' H4-112"CUTOFFTBGSTUB I 9341' H5-3I4" CUSTOM OVERSHOT, ID = 4.655" 9348' H 7" BKR SABL-3 PKR WI KBH-22 ANCHOR, ID = 3.875" I 10518' H4-112" WlEG I 11259' 2 SLIPS OFF SCAB LNR ON BTM (11/16195) DA TE REV BY cor..wENTS 05109I01 Cl-VKAK CORRECTIONS 11117102 BMKAK 9-518" TBG CEPTH COR PRUDHOE BAY UNIT WELL: A-OS PERMT No: 1720080 API No: 50-029-20116-00 SEe 35, T11 N, R13E, 1895' FNL & 922' Fa lIP Exploration (Alaska) ii'& ~ BAY. ffiUDl-ŒOL FaJ..,A 1(J(jJ) 100) 100 10 A-05 -- 01 Rate ) (bbl/d) Gas Rate (CQ (Wid) Gas Inj Rate (CQ (Wid) \l\èter Inj Rate (CQ ( bbl/d ) Q.¡m 01 Prod (1Ii1JbI ) Gas/OI Ratio ( cf/bI:JI ) \l\èterCu! 0,1 80 S-I 82 83 86 87 æ 90 95 96 98 2000 01 Dàe '-0§ FaileCl MITIA (PTLI / Subject: RE: A-05 Failed MITIA (PTD 1720080) Date: Sun, 13 Oct 2002 16:26:38-0500 From: "Barton, Kira" <kira.barton@bp.com> To: "'Tom Maunder'" <tom_maunder(~admin.state.ak.us>, "Barton, Kira" <kira.barton(~bp.com>, "NSU, ADW Well Integr'~y Engineer~' <NSUADWWelllntegrityEngineer@bp.com> CC: Jim Regg <jim_regg@admin.state.ak.us> Hi Tom. I have spoken with Joe and the plan is to keep well A-05 on injection. The plug and LDL have been given high priority. We will keep you informed of the results. Kira .... Original Message----- From: Tom Maunder [mailto:tom_ m .aunder~_.admin.state.ak.us] sent: Sunday, October 13, 2002 12:09 PM To: Barton, Kira; Joe Anders/Kevin Yeager Cc: Jim Regg Subject: Re: A-05 Failed MITIA (PTD 1720080) Kira, Joe and Kevin, Thanks for the report. It appears that it is your intent to keep the well on line, which is the normal practice. Will the CMIT, etc be conducted this week?? YOu have permission to keep the well in service pending further diagnostics. Keep us informed on the results and the sundry process. Tom Maunder, PE AOGCC "Barton, Kira" wrote: > Hello Tom and Jim. > Injection well A-05 (PTD 1720080) failed an MIT-IA. As part of the quarterly > review of injection pressures, the IA pressure was noted to have equalized > with the tubing pressure. On 10/11/02, an MIT-IA failed and the liquid leak > rate from the IA into the tubing averaged 8 GPM @1140psi. On ~0/12/02, the > leak rate test was repeated using a larger pump. This test established an > injection rate of.8 BPM ~ 2750 psi (2000 psi differential into the tubing). > Well is currently injecting produced water at 2400 BPD. Our plan is to set a tubing tail plug, pressure test the tubing and production casing, run a LDL, then evaluate pursuing a sundry. We'll keep you informed of evaluation progress. Please call me or Joe/Kevin if you have any questions. Thanks! Kira Kira Barton, for Joe Anders Engineer in Training BP Exploration, Alaska Inc. (907) 659-5710 ~ Work 1 of 2 10/14/2002 12:55 PM To: Blair Wondzell PI Supervisor Ref: Water & Gas to Surface @ BPX PBU A-Pad We got the gas sample analogous back from the lab and it was confirmed that the sample was Lift Gas and not MI. ,. 2/12/g6 ,n -7 ?.g-oqt _--- Lift gas was shut off in the five wells one at a time, when the LG in well A- 7 was shut-in and the IA bled off, the gas bubbling and water in all cellars subsided. It took about 3 hours for the water to evacuate the cellar in A-5. I went back to the Pad at about 6:00 PM, there was no water in any of the (:ellars however there was gas still bubbling up in A-5 & 40 cellars. The injection rate on well A-Si had been brought back up to 3350 psi, and all annuli were bled to 100 +/- psi. The gravel inside and outside of the cellars of A.~..5~4_.0 & 43 had subsided about 24' this subsidence extended about two foot around the ~-utside of the wellhouses. Tomorrow 12/13196 we will simulate the same condJtions that existed when the flow to surface commenced, if A-7 will continue to flow all night without LC, This should confirm or deny that A-~ the fault of this flow. i will write a real report to you and David after we have the final results of tomorrow's simulation. This is just a FYI to keep you up to speed on the issue. If you have any other questions you need answered please call me at 448-1227 or page me and I will do my best to.answer them for you. Doug Amos RECEIVED DEC 1 3 1996 Alaska Oil & Gas Cons. Commission M~mQrandum Production Supt. o,,~: 12/11/96 From: Subjact: Ken Smith, N.S.P.E A-p,~d...Fresh Water/Gas Prod.ucti°n in Cellars. The following is a chronological break down of events on A-Pad involving wells A-5, A-7, A-Si, A-40 and A-43. Date: I1¢'6-96 1¢¢8-96 1~9-96 1(~10-96 \ Daily events GC-3 produced water system was shut down for 18 hours for repairs in skid 301. SUbsidence was reported in well house of Well A-43. Well A-08i was converted from produced water(PW) to' ... miscible injection (MI). This is the flint time A-08i has been ' on miscible Injection. The following readings were on produced water. ": FVVHP:1050psig, FWRT: 140deg F, IA: 100psig, CA: 560psig A-pad & X-pad went down due to logic problems, all wells were down for 5 hours. A-08i well readings on MI; WHP:3350 psig, WHT: 130 deg F, IA: zero, CA: zero The night Pad Operator found standing water in the cellar in well A-7. The day Pad Operator found flooding with gas bubbling in well houses A-43, A-40, ~znd A-5 cellars. LEL readings are found to be as high as 30% in cellar but only a trace inches above cellar. Twenty four hour man watch initiated by Production Engineers. Samples of water taken by BPX lab and found to be fresh at 1000 ppm chlorides. Area has been roped off and access restricted. Peak vac truck brought on location and sucking down cellars as needed. N, ask~ Oil & G~s Cons. C0rr, m~ssmi; Anchcr['.ge Miscible Injection was shut in on well A-8i. No effect was found on offset wells. Well was brought back on at half rate to monitor well integrity. A-8i casing pressures remain at zero. 10-11-96 Night pad operator reported major subsidence plus water/gas in Well A-43 well house. Well A-5 has major gas/water production. Gas samples taken from Well A-5 cellar by BPX lab. Vac Truck recovered 1000 bbis of water from cellars. Water/gas production has ceased in Well A-7, Wells A-43 and A-40 have subsided by 30%. Well A-5 water/gas production continues unchanged. Waiting on gas analysis. Vac truck ceases liquid recovery but remains on location with man watch. Subsidence of wells in question since September 1996: A-07: None' A-05: 4 yards of gravel A-40: 10 yards of gravel A-43: 62 yards of gravel Note: Previous records could not be found by subsidence crew. Night Pad Operator reports conditions are improving, Area remains restricted and man watch continues. Please find attached the pad map, Pad Operator's daily readings and ' comments. Course of action and Interpretation. Continue to monitor wells and sample liquid and gas production for possible well integrity failure, At this time a suspected failure of well Integrity is not warranted. The source of the fresh water is assumed to be from known underground streams which were documented prior to pad construction in the early 1970's. The suspected cause of the problem is continued melting of the permafrost by each wells proximity and the migration of gases known to exist in and under the permafrost. E IL,/ Alask3 Oil & G:.s Cons. Artchr'r-.q~O ~- :~' . ~'"~ TO D PAD 1:3~'- ~ i *' ;34A .~-- L..SUMP t4 ~ 32 15 O 16 .~. 17 18A · 19 1"1 WELL AND 6' PRODUCTION UNE · ~ WELL, 0" PRODUCTION UNE, AND 3' GLT UNE WELL, 6" WSW LINE, AND 4' MI UNE WELL, 4' PRQDUOTION LINE, AND 3' GLTLINE SUBSIDENCE WELL GLT TWINS;WELLS A-41 & A-34A A-23 & A-9 & A..39 A-2 & A-4 MI TRUNK & LATERAL: WELLSA-3 & A-5 / A-11 & A-35 / AdO & A-31 ! A-21 & A-27 . 0 CELLAR ONLY I~ PRODUCTION & GLT TWIN: A-22 & A-42 '~' WSW TWIN R::! WELLHEAD AND CELLAR Alas.k~ 0il & Gas to~s. Ccmm~ss~or: Anchcmo. e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing__ Alter casing Repair well X Perforate Other 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1896' SNL, 923' WEL, SEC. 35, T11N, R13E At top of productive interval 2180' NSL, 492' WEL, SEC. 34, T11N, R13E At effective depth 2268' NSL, 599' WEL, SEC. 34, T11N, R 13E At total depth 2316' NSL, 645' WEL, SEC. 34, T11N, R13E 5. Type of Well: Development Exploratory Stratigraphic Service ORIGINAL 6. Datum elevation (DF or KB) KBE = 65.89 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-05i 9. Permit number/approval number 72-08/95-191 10. APl number 50- 029-20116 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 11370 feet Plugs (measured) 9348 feet BKB 11181 feet Junk (measured) 9171 feet BKB Size Cemented Measured depth True vertical depth 90' 30" 300 sx 110' 110' 2258' 20x18 8700 sx 2278' 2278' 9794' 13-3/8"x9-5/8" 1625 sx 9814' 7966' 9274' 7" 90 sx 9274' 7530' 2086' 7" 485 sx 9274'- 11360' 7530'- 9339' Open: 10806'- 10826' (Sag R.), 10912'- 10942' (Ivishak) Squeezed: 10914'- 10994' Open: 8823'- 8841', 8921'- 8948' Squeezed: 8922'- 8997' 4-1/2", 12.6, L-80, NSCTto 10516' Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) HES 'X' Nipple at 2213'; 7" Baker S-3 packer at 9200'; 7" Baker SABL-3 packer at 9348'; 7" Baker SABL-3 packer at 10472' 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED MAR 2 6 1996 ~./UI I~, Representative Daily Average Production or Injection D ska u. & C~a~ ,,,, ............. An~oraao OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tblbih~j Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run .. Daily Report of.~Vell Operations X 17.. hereby c,~'~t/~at th~ foX, nd Signed Form 10-40~4-j=l-e~3t~/t5/88 - - 16. Status of well classification as: Oil.. Gas Suspended correct to the best of my knowledge. Title Senior Drilling Engineer Service WAG In. iector Date~ z'/--~'~ ~ SUBMIT IN DUPLICATE.~.~ BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: A-05I BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 11/02/95 11:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 11/03/95 (1) TD:l1370 PB:11259 11/04/95 ( 2) TD:l1370 PB:11259 11/05/95 ( 3) TD:l1370 PB:11259 TESTED BOPE MW: 0.0 ACCEPTED RIG 11/02/95, 11:00 HRS. RETRIEVED HANGER PLUG. CIRC OUT FREEZE PROTECTION. INSTALLED HANGER PLUG, TESTED TUBING HANGER. REMOVED XMAS TREE. R/U ALL FUNCTIONS, TEST WELL CONTROL EQUIPMENT. TEST WITNESSED BY B. FOSTER, AOGCC. RIH IBP ON 'E' LINE MW: 0.0 TEST WELL CONTROL EQUIPMENT, WITNESSED BY B. FOSTER, AOGCC. REMOVED HANGER PLUG, RETRIEVED TUBING HANGER. CIRC AT 9340'. POOH LAYING DOWN COMPLETION STRING TO CHEMICAL CUT MADE AT 9340' THE CHEMICAL CUT WAS CLEAN. R/U ATLAS 'E' LINE LUBRICATOR, STUFFING BOX. RIH IBP ON 'E' LINE. PLAN TO SET IBP AT 9330', 10' ABOVE CHEMICAL CUT TUBING STUB AT 9340'. AT REPORT TIME WELL TAKING 5-7 BPH. BULLHEADING HOT WATER PILL TO IBP SETTING DEPTH NOT NECESSARY. POOH T/4082' WITH O/S ASSY MW: 0.0 CONT'D RIH W/BAKER 3-3/8" IBP ON ATLAS MONO 'E' LINE TO APPROXIMATE SETTING DEPTH. MADE CORRELATION RUN W/CCL. PUT IBP ON DEPTH W/ELEMENT AT 9325'. BAKER IBP TECH BEGAN PROCEDURE TO INFLATE IBP ELEMENT. TYPICAL INFLATION VALUES SEEN UNTIL ELEMENT CONTACTED CASING. COULD NOT GET FURTHER INFLATION. COULD NOT RELEASE FROM IBP W/PRESURE (TYPICAL). P/U MONO LINE. DRUG IBP UPHOLE T/9307', ELEMENT DEPTH. RUNNING STRING CAME LOOSE FROM IBP AT EMERGENCY STRAIGHT PULL. SET DOWN, CONFIRMED TOP OF IBP AT 9293'. COMPLETED MISRUN WITH BRIDGE PLUG T/9293'. RETRIEVED BORE PROTECTOR, INSTALLED BOP TEST PLUG ASSEMBLY, TESTED BOP STACK. INSTALLED BORE PROTECTOR. BHA #1, OVERSHOT W/GRAPPLE. RIH T/9248', TOP OF LINER. FISHED AT 9299', WASHED DOWN TO TOF AT 9299'. FISH CAME FREE. CBU AT 9265'. POOH T/4082' WITH O/S ASSEMBLY. RECEIVED MAR 2 S 1995 Alaska Oil & Gas Cons. Commission Anchorage WELL : A-05I OPERATION: RIG : DOYON 16 PAGE: 2 11/06/95 ( 4) TD:l1370 PB:11259 11/07/95 ( 5) TD:l1370 PB:11259 11/08/95 (6) TD:l1370 PB:11259 11/09/95 ( 7) TD:l1370 PB:11259 11/10/95 (8) TD:l1370 PB:11259 MONITOR ANNULI WHILE N/D MW: 0.0 BHA #1, POOH T/397', PULLED BHA. NO RECOVERY, FORMATION TYPE DEBRIS IN GRAPPLE, BUT NO INDICATION OF LATCHING THE FISH EVIDENT. BHA #2, RIH T/9322' WITH BRIDGE PLUG ASSEMBLY. SET BRIDGE PLUG, BOTTOM AT 9321', MID AT 9315', TOP OF FISHING NECK AT 9310'. RELEASED RUNNING TOOL FROM MECHANICAL SET BRIDGE PLUG, P/U TO 9280'. TEST BRIDGE PLUG, CIRC. HEAVY SLUG SPOTTED DOWNHOLE. PULLED BHA. SET STORM PACKER AT 27' RKB, TESTED. R/D WELLHEAD CONNECTOR, MONITORED ALL ANNULI WHILE N/D. BHA #3, RIH T/1500' MW: 0.0 CONT'D TO N/D BOP STACK AND CASING (TUBING) SPOOL. L/D TUBING SPOOL. INSTALLED 13-5/8" 5M SPACER SPOOL. N/U BOP STACK. TEST. PULLED CASING ON RETRIEVAL STRING T/14'. CBU, PULLED CASING. POOH L/D HANGER PACKER. P/U BAKER 9-5/8" RETRIEVABLE TEST PACKER. RIH T/3000'. SET PACKER, TEST, UNSEAT PACKER. MONITORED WELL, STATIC. POOH TO CHANGEOUT TEST PACKER. BHA #3, RIH T/1500' WITH BIT, CASING SCRAPER, TEST PACKER. MONITOR WELL, STATIC MW: 0.0 BHA #3, RIH T/3000'. SET RETRIEVABLE PACKER AT 3000' WITH 0 PSI. TESTED CASING - VIA STRING. POOH T/0'. SET PACKER AT 35' WITH 0 PSI. REMOVED CASING SPOOL. INSTALLED CASING SPOOL. INSTALLED SPACER SPOOL. R/D SUB-SURFACE EQUIPMENT, RETRIEVABLE PACKER. TESTED BOP STACK. BHA #4, RIH T/9297'. WASHED T/9302', CIRC AT 9275'. MONITORED WELL, STATIC. PREPARE TO POOH W/RCJB ASSEMBLY. RUN CASING MW: 0.0 RUN BHA #4. POOH T/ 400' WITH RCJB. PULLED BHA. RCJB LAYED OUT, DRILL COLLARS STOOD BACK. RUN BHA #5. PU TAPERED MILL. RIH T/9215'. RIH T/9283', AT TOP OF LINER. MILLED CASING @ 9305'. CBU @ 9215'. POOH T/4914'. POOH T/397'. PULLED BHA. LD TAPERED MILL ASSY. STOOD BACK DC'S. RUN 7", 9-5/8" TIE BACK CASING STRING T/3554' & CHECK FLOAT. INSTALLED CASING SPOOL MW: 0.0 RAN 7" CASING T/9293'. MIXED AND PUMPED CEMENT SLURRY. CHECKED FLOAT, MONITORED FLOW BACK, STATIC. FLOAT HELD. CIP AT 21:23 HRS. DRAINED BOP STACK, MONITORED ANNULUS. PULLED AND REMOVED SPACER SPOOL. MADE FINAL CUT ON 9-5/8" CASING USING PNEUMATIC SAW. PREPARED CUT FOR INSTALLATION OF TUBING HEAD. INSTALLED 9-5/8" CASING (TUBING) SPOOL. WELL : A-05I OPERATION: RIG : DOYON 16 PAGE: 3 11/11/95 ( 9) TD:l1370 PB:11259 11/12/95 (10) TD:l1370 PB:11259 11/13/95 (11) TD:l1370 PB:11259 RIH MW: 0.0 WELLHEAD WORK. INSTALL 9-5/8" CASING SPOOL & RU SECONDARY ANNULUS VALVE ON TUBING SPOOL & TEST. PULL 9-5/8" CASING & LD T/0'. LD LANDING JT & CUT OFF SECTION. RU 13-5/8" BOP STACK. RUN TEST PLUG & TEST BOPE. WITNESS OF TEST WAIVED BY D. AMOS WITH AOGCC. PULLED TEST PLUG. RAN WEAR BUSHING. RUN BHA #6. RIH T/2317'. CHANGE OUT KELLY & RD TO STAND BACK IN RT HOLE. RIH T/9117' TO CALCULATE TOC. SINGLED IN DP T/9237', @ FLOAT COLLAR. DRILLED UP FLOAT COLLAR. STOP ROTARY. ATTEMPT TO WASH DOWN. DRILLED CEMENT T/9300'. CBU @ 9255'. PUMP HIGH VIS PILL. CIRC OUT. HOLE SWEPT WITH SLUG. POOH T/401'. PULLED BHA. LD BIT & CASING SCRAPER. DRILL COLLARS STOOD BACK. TEST CASING. RUN BHA %7. RIH T/l150'. RIH MW: 0.0 RUN BHA %7. RIH T/9296', AT TOP OF FILL. REV CIRC @ 9300'. MU KELLY, BROKE CIRC, DROPPED BALL, WOULD NOT WASH OFF, BASKET FULL, FLOWCHECK WELL. POOH T/5386' POOH T/398' PULLED BHA. RUN BHA #8. RIM T/6734'. RIH ~/9300'. REV ~IRC @ 9307'. REST HOLE @ 9287'. POOH T/4000'. POOH T/402'. PULLED BHA. RUN BHA %9. RIH T/7417'. SLIPPED & CUT DRILL LINE. RIH T/9300'. POOH MW: 0.0 BHA %9, CONT'D RIH 9300' - 9309', 1' ABOVE STEM ON MECHANICAL BRIDGE PLUG. NO SAND EVIDENT, DROPPED BALL. CIRC DOWN. ACTIVATED THE RCJB. REVERSE CIRC IMMEDIATELY ON TOP OF MECHANICAL BP. FLOW CHECK WELL. POOH W/RCJB ASSY. BHA LAID OUT. RECOVERED LARGE METAL STRIPS FROM SCAB LINER HANGER/PACKER, PLUS PIECE OF HANGER SLIP FROM JB. BHA %10, RIH T/9308', 2' ABOVE STEM ON MECHANICAL BP. R/U SURFACE LINES. CLOSED ANNULAR. REVERSE CIRC TO TOP OF BP BODY AT 9313', SWALLOWED STEM. WORKED RD ASSY. REVERSE CIRC STRING CLEAN. HAND SAND W/PACKER RUBBER IN RETURNS. P/U TO 9308'. REST HOLE AND MONITOR. POOH T/402', BHA LAID OUT. RECOVERED 2 LONG METAL STRIPS OF BODY LOCK RINGS FROM SCAB LINER HANGER/PACKER, PLUS SEVERAL SMALL PIECES OF METAL HANGER JUNK. THERE WAS NO SLIP METAL RECOVERED. BHA %11, RIH T/9310'. WORKED OVER STEM ON RBP, COULD NOT LATCH AFTER SEVERAL ATTEMPTS. ONLY GETTING OVER STEM 1.7' INSTEAD OF REQ'D 3'. WORKED STRING VIGOROUSLY. LATCHED RBP. MONITORED WELL. RELEASED RBP. SOME JUNK REMAINED IN HOLE. CBU, MONITORED WELL. POOH T/7875' WELL : A-05I OPERATION: RIG : DOYON 16 PAGE: 4 11/14/95 (12) TD:l1370 PB:11259 11/15/95 (13) TD:l1370 PB:11259 11/16/95 (14) TD:l1370 PB:11259 11/17/95 (15) TD:11370 PB:11259 POOH MW: 0.0 RUN BHA #11. POOH T/399' WITH RBP RETRIEVING HEAD. PULLED BHA. RECOVERED RETRIEVABLE BRIDGE PLUG, STOOD BACK DC'S & JARS. RUN BHA #12. RIH T/9316', @ TOP OF FISH. FISHED @ 9329', LATCHED FISH. CBU @ 9300'. POOH T/8258'. POOH T/397'. PULLED BHA. RUN BHA #13. RIH T/9329' WITH BURNING SHOE, EXTENSIONS ASSY TO TOP OF TUBING STUB. REAMED T/9342', @ TOP OF UPPER STRADDLE PACKER. CBU @ 9342'. POOH T/5470'. RD KELLY. POOH T/1600'. RUN COMPLETED, HUNG UP AT 9342 MW: 0.0 BHA #13, POOH T/408'. PULLED BHA, R/U TO RUN COMPLETION. RAN 4-1/2" TUBING T/9330'. R/U HIGH PRESSURE LINES, CBU. CONDUCTED SLICKLINE OPERATIONS ON SLICKLINE EQUIPENT. RAN COMPLETION BUT TOOLSTRING HUNG UP AT 9342'. PREP TO TEST CASING & TUBING MW: 0.0 CONDUCTED SLICKLINE OPERATONS ON SLICKLINE EQUIPMENT. L/D TUBING T/40'. SPACED OUT TUBULARS. COMPLETED RUN WITH GUN ASSEMBLY, BLIND BOX AND OTHER SUB-SURFACE EQUIPMENT. FREEZE PROTECT TBG AND ANNULUS. SET PACKER AT 9200'. R/U AND TEST XMAS TREE. RIG RELEASE MW: 0.0 R/U HIGH PRESSURE LINES. TEST TUBING. INSTALL HANGER PLUG. FREEZE PROTECT TREE, SECURE WELL. RIG RELEASED 1200 HRS ON 11/16/95. SIGNATURE: (drilling superintendent) DATE: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 7 March 1996 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 CCL FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 1390.12 3316.07 4060.06 5627.11 5847'04 6078.05 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 A Anchorage, AK 99518 · X to (907) 563-7803 Date: ,a~aa Gil & ~ Cons. Ccmm/ssJcn LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK,. 99501. Date: 8 November 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WSLL q,~ ~ DESCRI~TIO~ · ~' ' G-16 (44-11-11-13) '- 'i PDK FINAL BL+RF' C-38 (41-18-11-14) 1 PLS FINAL BL+RF H-28 1 PLs FINAL'BL+RF G-08 (43-13-11-13) 1 CN FINAL BL+RF ECC No. Run # 1 '. 1130.05 Run # 1 3316.06 · Run # 1 5785.05 Run ~ 1 Run # 1 5858.08 Run $ 1 6007.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services Suite 201 Anchorage, AK 99518 %~$ Q0~5' Q0'""-$$%0~ Received by / ~~ Date: .. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. .Date: 31 October 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL · # DESCRIPTION 1 PLS FINAL BL+RF 1 CN/GR FINAL BL+RF 1 CCL FINAL BL+RF 1 CCL FINAL BL+RF R-04 (22-05-11-13)'' ~1 PFC/PERF FINAL BL+RF x-04 (43-06-10-14) P .s FINAL ~-12 (43-31-1-14) 1 PFC/PE~ FIN~ BL+~' G-04 (13-11-13) ~ ~-' ~1 1 CCL FINAL BL+RF 1 PLS FINAL BL+RF ECC No. Run' # 1 · 522.10 Run # 1 1341.02 Run # 1 3316.05 Run # 1 3861.04 Run ~ 1 4096.06 Run ~ 1 4515.07 Run ~ 1 · 5627.09 Run # 1 5753.04 Run # 1 57'91.05 Run # i 6022.07 Run ~ 1 6510.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services -.~" Suite 201 -- _ Anchorage, AK 99518 Received by:~ Date: ,, MEMORANDUM State ot Alaska Alaska Oil and Gas Conservation Commission TO: David Joh~~' DATE: Chairman---~ ~ THRU: Blair Wondzeli, ~/~(~,,_ FILE NO: P. I. Supervisor Petroleum Inspector November 3, 1995 AJIIKCCD.doc BOPE Test- Doyon 16 BPX - PBU - A-05i PTD# 72-0008 Prudhoe Bay Field Friday, Nove.m..ber 3, 1995: I received a call ~rom Bruce Cambeli, BPX drilling supervisor, informing me that they would be ready to test the BOPE at 1:00 AM. I arrived on location at 00:30AM and stoodby for the test to start. The test began at 3:00AM and did not go well due to various leaks. I decided to go to Nabors 28E and witness the BOPE on that rig, the subject of another report. After completing the BOPE test on Nabors rig 28E, I went back to Doyon rig 16. I arrived at the rig and Bobby Ingram, Nabors toolpusher, informed me that they had repaired all the items that was leaking and they would now begin the test. As the attached AOGCC BOPE Test Report shows 4 failures, all of which were repaired / replaced, before I departed the location. This _.rig_had just been moved from S pad to A ~ (14+ miles) and a lot of the flanges in the BOPE system had worked loose. The rig was clean and all equipment seemed to be in good working order. The location was clean and there was good access to all areas of the rig. ..Summary: I witnessed the BOPE test on Doyon rig 16 - test time 7 hours - 4 failures. Attachment: AJIIKCCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X App.//95-191 DATE: 11/3/95 DrigContractor: " DO YON ..... RigNo. 16 PTD# 72-0008 RigPh.# ' 65~46 ~ 0 /11 ' ~ , ,. Operator: BPX Rep.: BRUCE CAMPBELL Well Name: A-05i Rig Rep.' BOBBY INGRAM Casing Size: 7" Set ~ 1~,~5g' ~' ' Location: Sec. 35 T. 11N R. 13E Meridian Urn. Test: Initial X Weekly Other MISC. INSPECTIONS: Location Gen.' OK Well Sign OK Upper Kelly / IBOP Housekeeping: OK (Gen) Dri. Rig OK Lower Kelly / IBOP PTD On Location YES Hazard ,?~. yES' Bali Type Standing Order Posted YES Inside BOP Test FLOOR SAFETY VALVES: Quan. Pressure NO T~ 500/5, 000 NO T~ . 500/5,000 ' ~ ! 500/5,000 "1i .50W5,00° P/F - . BOP STACK: Ouan. Annular Preventer 1 , , Pipe Rams 1 Lower Pipe Rams NO~E' Blind Rams I Choke Ln. VaNes '/ HCR Valves Kill Line Valves 2 Check Valve ' N / A' Test Press. P/F 300/3,000 500/5,000 5oo/5,ooo MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Flow Indicator "YES' ' YES' Meth Gas Detector YES ~ES H2S Gas Detector i?E,~ '.. '. ~.E$, Test CHOKE MANIFOLD: Pressure No. Valves 14 I 500/5,000 No. Flanges .!6 ii 500/5,000 Manual Chokes .... Functioned Hydraulic Chokes Functioned P/F P P ,, P P ACCUMULATOR SYSTEM: System Pressure 2,850 I P Pressure After Closure 1,750 ! ,P , 200 psi Attained After Closure 0 minutes 20 System Pressure Attained 1 minutes 9 Blind Switch Covers: Master: YES Remote: ~, . Nitgn. Btl's: ,. 6 {~ 2000 Avg. Psig. sec. sec. YES _ Number of Failures: 4 ,Test Time: ?.0 Hours. Number of valves tested ~9 . Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to ithe AOGCC Commission Office at: Fax No. ' 276,7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. !. Supervisor at 279-1433 ........ .. I I IIIII IIIIJ I. II I I IIIL. I. IIII I _ I . II I I II I.I I I ' REMARKS: Fa#ures: 2 flan,ges leaked on the choke manifold-, t~g, htened and retested. A hub clampon the choke line leaked - tigh~tened and retested. The HCR valve on the kill line leaked ,,repla~d,,, w~,a, manual valve end tested OK. ............... :....~ :; · -: :::. :: ..... : .... , ,,,:~---,,: .... r~ .... :r,~,rr, ~ ~,, ,, ~ ,' , I, , ,,, ,~ , ' , NO TE: The upper and lower kelly v~. ves_and the lower pipe rams will be tested after the tubing ~is pulled out of the hole. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector FI-021L (Rev.12/94) ...... ST~,TE'wI'I:hE~S REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: AJIIKCCD.XLS . BOBBY D. FOSTER ~'-~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS~uN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Operation Shutdown __ Re-enter suspended well Alter casing __ Repair well X Plugging __ Time extension __ Stimulate __ Change approved program Pull tubing __ Variance __ Perforate ~ Other 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1896' SNL, 923' WEL, SEC. 35, T11N, R13E 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service x 6. Datum elevation (DF or KB) Plan RTE = 71.67 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-05i At top of productive interval 2180'NSL, 492'WEL, SEC. 34, T11N, R13E At effective depth 2268' NSL, 599' WEL, SEC. 34, T11N,.R13E At total depth 2316' NSL, 645' WEL, SEC. 34, T11N, R13E ORIGINAL 9. Permit number 72-08 10. APl number 50- 029-20116 11. Field/Pool Prudhoe Bay Field/Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 11370 feet Plugs (measured) 9348 feet BKB 10965 feet Junk (measured) 8969 feet BKB fill at 10965' MD (12/94) Length Size Cemented Measured depth 90' 30" 300 sx 11 O' 2258' 20x18 8700 sx 2278' 9794' 13-3/8"x9-5/8" 1625 sx 9814' 2560' 9-5/8"x 7-5/8" No 2560' 2086' 7" 485 sx 9274'- 11360' measured 10806'- 10826' (Sag R.), 10912' - 10942' (Ivishak) true vertical (subsea) 8757'- 8775', 8855'- 8883' Tubing (size, grade, and measured depth) 5-1/2" & 4-1/2" L-80 to 9348' with 4-1/2" tailpipe to 10516' True vertical depth 110' 2278' 7966' 2560' 7530'- 9339' RECEIVED 0CT 2 4 1995 Alaska 0ii & Gas Cons. Commissi, Packers and SSSV (type and measured depth) 7" Baker packers at 9348' and 10471~ 5-1/2" SSSV at 2114' Anchorage 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation October30, 1995 15. Status of well classification as: 16. If proposal was verbally approved Name of approver Date approved 17. I herebyz~hat the ~correct to the best of my knowledge.· Signed ~,/'~ ~ Title Senior Drilling Engineer Oil Gas Service Water Injector Suspended~ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test ~ Location clearance ~ Mechanical Integrity Test__ Subseq.ue..qt form r,~quired 10- ~or...~ 0rigina ignea David W. Johnston Approved by order of the Commission Approved Copy Returned - Co~nmis§ioneF ' Date /O//.-z~/'~&~-"- Form 10-403 Rev 06/15/88 SUBMIT I~1TRIFLICATE A-o$i Rig WOrkover The A-05i RWo is CUrrently SCheduled for Doyon This Well CUrrently has a fai 16 in late October Workover Will restor ~ ..... /ed 7 5/8" _o ~ , _ 1995. e '~,,u~us inteorih~ x~.~.,~/8 13aker 3D scab liner Packer · .., ou me Well can Continue injection, at 2560'. The Planned Rig I/Vor · 1. Remove 5 ~ ~,~,,k. tailpipe in hole · ,~ x 4.1/2. tubing an 2. Rem ). d latch Ove 9 5/ " (leave · . / ' ' ' ~!i~p~ed' ' packer and cern in place. , and re/ease rig ntpple and new latch. MOj 10/21/95 R rt. ~,.. F_, F..D OCT 24 1995 Ataska Oit & Gas Cons. Commission Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 11 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL -11 (08- 1-13) DESCRIPTION 1PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 CCL FINAL BL+RF 1PFC/PERF FINAL BL+RF 1PFC/PERF FINAL BL+RF 1PLS FINAL BL+RF 1 PLS FINAL BL+RF ECC No. Run # 1 954.06 Run ~ 1 3316.04 Run ~ 1 4077.01 Run # 1 4882.01 Run # 1 5858.07 Run # 1 6036.05 Run # 1 6163.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please slgn and PetT'otechnleal Dat~ Cente~ BP F×p].oratlon '(Alaska) 900 Last Benson Boulevard Anchorage, Alask~ 99508 Reoe~ved by Dat~ RECEIVED APR 2 0 1995 ..... -" -- ~k~ Oil.&.(~ Cons. Commission knchorago STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tUbing X 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Stimulate Plugging Alter casing Repair well x 4. Location of well at surface 1896' FSL, 923' FEL, Section 35, T11N, R13E, UM At top of productive interval 2180' FSL, 492' FEL, Section 34, T11N, R13E, UM At effective depth 2268' FSL, 599' FEL, Section 34, T11N, R13E, UM At total depth 2316'FSL, 645'FEL, Section 34, T11N, R13E, UM 12. Present well' condition summary Total depth: measured 11370 true vertical 9348 5. Type of Well: Development X Exploratory .... Stratigraphic ~ ORIGINAL feet Plugs (measured) feet BKB Perforate Other , WORKOVER 6. Datum elevation (DF or KB) KBE = 65.89 7. Unit or Property name Prudhoe Bay Unit ~.. Well number A-05 (43-34-I 1-13) PBU 9. Permit number/approval number 72-08 / N/A (Cons. Order #258) 10. APl number 50- 029-20116 11. Field/Pool Prudhoe Bay Field/Oil Pool Effective depth: measured true vertical 11181 feet Junk (measured) 9171 feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 2532' 9-5/8" 2441' 7-5/8" Cemented Measured depth True vertical depth 118' 118' 2559' 2559' measured 10914~10924~ 10932~10942~ 10952~10964; 10974510994'(Squeezed) 10806'-10826; 10912510942'(Open) true vertical 8922'-8932', 8939'-8948; 8958'-8969', 8978'-8997' (Squeezed) 8823'-8841', 8921 '-8948' (Open) Tubing (size. grade, and measured depth) 5-1/2" 17#L-80 to 9232'MD;4-1/2", 12.6#, L-80 to 10516'MD Packers and SSSV (type and measured depth) Baker "SABL-3" Packer @ 10472'MD; Baker 3-D Hanger/Packer @ 2515' MD; 5-1/2" Flow coupling @ 2117' MD feet 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure DEC 2 7 ]994 I...,i~,..,+i,..,,,,, r~w'~w~-'~ "'" "" ,,.,,,,w vv, i,e. wIIiIIIilIiiltlll 14. Representative Daily Average PrecluSion or 'Casing Pressure` ~~ipressure ii iig~,~[iui i iJ~;~t~;i ~. ! ~ OiI-Bbl Gas-Mcf Water-Bbl Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run ... Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service Water In. lector 17. I hereby certify that the fo, regoing is tr~he best of my knowledge. , Sicjned , Title Dr/fling Engineer Supervisor Form 10-404 Rev 06/15/88 ~ SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: A-5 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 2ES WO/C RIG: NABORS 2ES 11/27/94 ( 1) TD:l1360 PB:10942 11/28/94 ( 2) TD:l1360 PB:10942 11/29/94 (3) TD:l1360 PB:10942 MIRU MW: 0.0 MOVE T/WELL A-5. SEPARATE PUMP UNIT F/RIG UNIT. MOVE CAMP & PUMP UNITS FIRST. LD DERRICK. PREPARE MAIN MODULE F/MOVE. RAISE DERRICK, SETTING MUD UNIT & HOOKING UP. PREPARE & L/D 5.5" TBG MW: 0.0 RIGGING UP ON WELL A-5 RWO. SET IN MUD MODULE, LEVERL UP & HOOKUP. TAKE ON SEAWATER & FRESH WATER. R/U LUB. PULL BPV. CHK PRES. TBG. 300. ANNULUS 200. 9-5/8" ANNULUS 280 PSI. R/D LUBRICATOR. R/U TO CIRC. PUMP OFF DIESEL CAP. APPROX. 140 BBLS. CIRC. WELL 72 BPM. @ 1200 PSI. MONITOR WELL. OK. SET TWC. TEST TO 1000 PSI N/D TREE & ADAPTOR FLG. CHK. LDS. NIPPLE UP BOPE. TEST BOPE, TWO WAY CHK LEAKING. INSTALL LUBRICATOR, PULL BPV. P/U UP LANDING JT. MAKE UP INTO HANGER TEST UPPER RAMS & CHOKE MANIFOLD. 500-5000 PSI. ATTEMPTED TO TEST HYDRIL ANNULAR. WOULD NOT TEST PERFORM KOOMEY TEST. CLOSE BLIND RAMS & CHANGE HYDRIL RUBBER. TEST SAME NO VISIBLE CHANGE. STILL LEAKING IN HANGER AREA. BACK OUT LOCK DOWNS. PULL HGR. OFF SEAT. CIRC WELL. SAFETY MEETING. CONTROL LINES TO SPOOL. RIG UP TONG UNIT LAY DOWN 5.5" TBG. TIH W/FISH ASSY. P/U 4.5" DP MW: 0.0 PULL & L/D 5.5" 17# NT-80 NSCC TBG & SPOOL CONTROL LINE TO BALL VALVE. REC. 52 JTS. P/U BAKER 9-5/8" RETRIEV-OMATIC M/U ON 5.5" TBG & HANG-OFF @ TEST BOPE 5000/500 RAMS & 500-2500 ANNULUR PREVENTOR. TEST VALVES TO 5000 PSI. INSTALL WEAR BUSHING. P/U UP RETRIEVING TOOL LATCH INTO STORM PACKER PULL TO FLOOR & LAY DOWN SAME. PULL & L/D 5.5" COMPLETION STRING. RECOVERED. 20" TEFLON SLEEVE. 229 JTS TBG. 3.90" CUT OFF. 4-GLMS & SSSV. CLEAR FLOOR. P/U BAKER FISHING TOOLS. M/U FISHING STRING. TIH. PICKING UP 4.5" DP. WELL : A-5 OPERATION: RIG : NABORS 2ES PAGE: 2 11/30/94 (4) TD:l1360 PB:10942 12/01/94 (5) TD:l1360 PB:10942 12/02/94 (6) TD:l1360 PB:10532 TRIP OUT. L/D PBR & SPEAR ASY MW: 0.0 TRIP IN W/OVRSHOT ASSY. PICKING UP 4.5" DP. P/U KELLEY, BRK. CIRC. TAG FISH @ 9211' DPM. ROTATE & MILL TO 9215' NO P/U. NO TORQUE. (SPILL DRILL). SET KELLEY BACK. P/U l-J5 REVERSE CIRC. BOTTOM UP. NO RECOVERY SET ON BOTTOM W/30,000 NO PICK UP WT. TRIP OUT. TO CHK. TOOLS. (D-2 DRILL). HOLLOW MILL INDICATES SPINNING ON POSSIBLE TBG COLLAR. REMOVE HOLLOW MILL. TRIP W/BHA #2. SLIP & CUT DRLG LINE. TIH. KELLY UP, BRK CIRC. TAG FISH @ 9215 DPM. CIRC & ROTATE ON FISH WITH NO INCREASE IN TORQUE OR PRES. ASSUME PBR IS SPINNING. TRIP OUT TO CHK TOOLS. BRK OFF OVERSHOT. MILL GUIDE WORN OUTER EDGE. (IND. PBR SPINNING). P/U SPEAR TIH. P/U KELLEY, BRK CIRC. ENGAGE FISH @ 9215' P/U BLEED OFF JARS. ROTATE 6 RDS. JUMPED FREE. REENGAGE ROTATE 23 TURNS PBR CAME FREE. CIRC BOTOMS UP. TRIP OUT W/FISH. LAY DOWN PBR & SPEAR ASSY. POH MW: 0.0 MU BHA #4 & RIH TO 1600'. SLIPPED AND CUT DRLG LINE. RIH, TAGGED TOF AT 9225' MILLED PACKER F/9225-9230'. PU AND JARRED FISH FREE. &BU. SMALL AMOUNT OF GAS AT BOTTOMS UP. MONITORED WELL, WELL STABLE. POH W/FISH. RECOVERED PACKER REMNANT, MOE, TAIL PIPE ASSY. WILL INSPECT F/NORM PRIOR TO DISPOSAL. LD BHA #4. MU BHA #5 AND RIH. TAGGED TOC @ 10532'. DROPPED BALL AND CIRC OVER JUNK, CORED 1' INTO CEMENT. PREPARING TO POH @ REPORT TIME. POH MW: 0.0 POH, STOOD BACK 25 STANDS, LD 4-1/2" DP. D1 DRILL. RECOVERED 2 PIECES METAL F/JB. MU BHA #6 AND RIH TO 2040'. SET TEST PACKER AND TESTED BELOW TO 3000 PSI OK, WOULD NOT TEST TO 4000 PSI. SET PACKER AT 2155' (BELOW FO'S), ATTEMPTED TEST BELOW PACKER, CSG WOULD NOT TEST. LEAK IS SMALL, DID NOT ATTEMPT TO ESTABLISH INJECTION RATE. POH AND CHECKED PACKER, PACKER OK. CHECKED OUT ALL SURFACE EQUIP, ALL OK. MU BHA #7. RIH. ATTEMPTED TO TEST CSG @ 2155 AND AGAIN AT 3117', NO TEST. RIH PU DP TO TOL @ 9288'. ATTEMPTED TO INSERT SEAL ASSY INTO TIE-BACK SLEEVE WITHOUT SUCCESS. SET TEST PACKER @ 9273' AND TESTED BELOW, NO TEST. POH. WELL : A-5 OPERATION: RIG : NABORS 2ES PAGE: 3 12/03/94 ( 7) TD:l1360 PB:10532 12/04/94 (8) TD:11360 PB:10532 12/05/94 (9) TD:l1360 PB:10532 DRESSING TBE MW: 0.0 POH W/TEST PACKER. MU BHA #8, RIH, DRESSED OFF PBR. MILL TOOK WEIGHT AT TOP OF SLEEVE, FELL THROUGH AFTER 4', BOTTOMED OUT 31' INTO SLEEVE AS EXPECTED. CBU, RECOVERED SCALE @ BOTTOMS UP. POH. MILL WORN TO 7.00" OD. DECIDED TO ATTEMPT TO TEST SEAL ASSY. MU BHA #9 AND RIH. ATTEMPTED TO INSERT SEAL ASSY W/O SUCCESS. POH. SLIPPED AND CUT DRLG LINE. MU BHA #10 AND RIH. TAGGED TOL @ 9288' AND BEGAN DRESSING TIE-BACK SLEEVE. TORQUE 200 AMPS (6000 FT#) OFF BOTTOM, 280-350 AMPS (11000-15000 FT-#) ON BOTTOM W/1-2K# WOM. SEAL BORE ID OF PBR 7.375" AS PER TIW. LENGTH OF PBR 31'. POH W/TEST PACKER MW: 0.0 CONTINUED TO ATTEMPT TO DRESS OUT PBR, HIGH TORQUE, LOW WEIGHT ON MILL, UNABLE TO MAKE PROGRESS. POH. LD BHA #10. FIRST MARKS ON TAPER ON MILL, UNABLE TO MAKE PROGRESS. POH. LD BHA #10. FIRST MARKS ON TAPER OF MILL @ 7.0" O.D. REGROUPED AND EVALUATED DOWNHOLE CONDITIONS. CONDLUDED THAT PBR IS NOT CONVENTIONAL LINER TIE-BACK PBR (7.375" ID) BUT A PRODUCTION PBR WITH PROBABLE ID OF 7". DECIDED TO CONTINUE TESTING LINER, STRADDLE LAP AS REQUIRED. MU BHA #11 AND RIH TO 9400' 9-5/8" SCRAPER TO 9250'. POH AND LD BHA #11. MU BHA #12 AND RIH. SET PACKER @ 9331' AND TESTED BELOW, NO TEST. RESET PACKER @ 9362' AND TEST BELOW, NO TEST. TESTS SHOW 400-500 PSI LOSS IN <5 MIN. RIH, TAGGED OBSTRUCTION @ 10431'. PULLED UP TO 10372', SET PACKER, AND TESTED BELOW, NO TEST. IBP/SAND PLUG OR 7" LINER LEAKING BELOW 10372'. POH. POH MW: 0.0 POH W/BHA #12, LD TEST PAKCER. SLIPPED DRLG LINE. MU BHA #13, RIH. TAGGED OBSTRUCTION AT 10431', PU KELLY AND ATTEMPTED TO WASH THRU W/O SUCCESS, ROTATED WITH 5-8 WOB W/VARIABLE TORQUE F/180-220 AMPS, BIT FELL THRU AFTER <1'. REAMED THRU AREA UNTIL NO INDICATION OF TIGHT SPOT. RIH TO 10515' WASHED TO TOP OF SAND PLUG @ 10555' CIRC HOLE CLEAN, RECOVERED OILY SCALE & SMALL METAL S~AVINGS. POH AND LD BHA #13. MU BHA #14 AND RI TAGGED OBSTRUCTION AT 10431', WORKED RBP/TEST PACKER THRU W/10-15K DRAG. SET TEST PACKER @ 10468', TESTED BELOW TO 4000 PSI F/30 MIN, NO LOSS. RESET TEST PACKER @ 10420', TESTED BELOW, NO TEST. LEAK IN 7" BETWEEN 10420' AND 10468', CSG PROBABLY SPLIT @ 10431'. POH 12 STANDS TO LINER LAP. ATTEMPTED TO SET 7" BRIDGE PLUG AT 9370' UNABLE TO OBTAIN ST PREPARING TO · - POH @ REPORT TIME. WELL : A-5 OPERATION: RIG : NABORS 2ES PAGE: 4 12/06/94 (10) TD:l1360 PB:10532 12/07/94 (11) TD:l1360 PB:10532 12/08/94 (12) TD:l1360 PB:10532 RIH PU DP MW: 0.0 POH W/ BHA #14, LD TEST PACKER. DID NOT RETRIEVE BRIDGE PLUG. MU BHA #15 AND RIH. SLIPPED AND CUT DRLG LINE. RIH, ENGAGED PLUG AT 10550', SET BRIDGE PLUG AT 10360'. POH TO 6894' AND MU 9 5/8" TEST PACKER. PACKER HIT EITHER THE WEAR RING OR CASING STUMP WHEN ATTEMPTED TO RIH, DAMAGED ELEMENT AND SHEARED SETTING MECHANISM. CHANGED OUT PACKER, PWR. RIH AND SET PACKER AT 2350'. TESTED 9 5/8" CASING AND 7" LINER LAP F/ 2350 - 10360'. NO LOSS. RIH, ENGAGED AND RELEASED 7" BRIDGE PLUG. POH LD DP. LD 9 5/8" TEST PACKER. DID NOT RETRIEVE 7" BRIDGE PLUG. RIH PU DP TO FIND BRIDGE PLUG. ND TUBING SPOOL MW: 0.0 RIH PU DP, TAGGED BRIDGE PLUG AT 9360'. RELEASED BRIDGE, POH. LD BRIDGE PLUG AND RETRIEVING TOOL. RIH W/ 3 1/2" DP, LD SAME. LD 6 1/4" DC. SLIPPED DRILLING LINE. RIH W/ 4 1/2" DP, LAY DOWN SAME. MU 9 5/8" BRIDGE PLUG AND RIH. SET AT 2450'. POH. PWR, TESTED CASING W/ 9 5/8" X 13 3/8" ANNULUS CLOSED. HELD, ANNULUS PRESSURE TRACKED INNER PRESSURE AS EXPECTED. INSTALLED 1 JT 7 5/8" CASING IN STACK AND DUMPED 3000# SAND TO CAP BRIDGE PLUG. ND BOPE. ND TUBING SPOOL. RETRIEVING BRIDGE PLUG MW: 0.0 NU DRILLING SPOOL AND BOP STACK. BODY TESTED STACK AGAINST CASING. MU CASING CUTTER. CLEARED FLOOR. RIH TO 1810' CUT 9 5/8" CASING. CIRCULATED ANNULUS CLEAN. POH AND L~ CUTTER. MU 9 5/8" SPEAR AND ENGAGED CASING, BOLDS, UNSEATED CASING/SLIP ASSEMBLY, MONITORED WELL, WELL STABLE. PULLED CASING/SLIPS TO FLOOR, LD CUT JOINT AND SPEAR. RU CASING TOOLS AND LD 45 JTS 9 5/8" CASING. LOST 3 HOURS REPLACING WORN SLIPS. RD CASING TOOLS AND CLEARED FLOOR. PERFORMED STATE BOP TEST. MU 9 5/8" BRIDGE PLUG RETREIVING TOOL AND RIH. TAGGD CASING STUMP AT 1810'. ATTEMPTED TO WORK RETRIVING TOOL INTO LAP, UNSUCCESSFULLY. POH. WILL PU 8.5" TAPERED MILL AND DRESS OFF STUMP. WELL : A-5 OPERATION: RIG : NABORS 2ES PAGE: 5 12/09/94 (13) TD:l1360 PB:10532 12/10/94 (14) TD:l1360 PB:10532 12/11/94 (15) TD:l1360 PB:10555 RUNNING 7 5/8" TIEBACK LINER MW: 0.0 POH W/ BHA #19. MU BHA AND RIH. ENTERED STUMP W/ NO INDICATION. POH. MU BHA #21 AND RIH. ATTEMPTED TO ENTER STUMP AT 1810' W/O SUCCESS. TOOL IS CENTRILIZED, CASING PROBABLY OFF CENTER. POH. FABRICATED MULESHOE ONTO RETRIEVING TOOL. MU BHA #22 AND RIH. TAGGED STUMP AT 1810', ROTATED 1/2 TURN TO RIGHT AND ENTERED STUMP. RIH AND TAGGED SAND AT 2375'. REVERSED OUT SAND TO TOP OF BRIDGE PLUG @ 2450'. RELEASED BRIDGE PLUG AND CBU. POH. RECOVERED 46.6' LENGTH OF 9 5/8" CASING IN WHICH BRIDGE PLUG WAS WEDGED. RECOVERED BRIDGE PLUG, LD SAME. HAD 5 - 10K DRAG @ 1850' DURING TRIP OUT. EXPLAINS LEAK OFF CENTERED STUMP. MU 8 1/2" BIT AND RIH, TAGGED STUMP AT 1854', CONTINUED ON TO 2451' LD DP. CHANGED TOP RAMS TO 7 5/8". TESTED DOORS. RU N~S. PREPARING F/ BOP TEST MW: 0.0 RAN BAKER 3-D HANGER + 62 JTS 7 5/8" 29# NT95 STL LINER + XO + 3 JTS 9 5/8" 47# L-80 NSCC LINER. RU AND REVERSE CIRCULATED 180 BBLS DIESEL DOWN 9 5/8" X 13 3/8" ANNULUS. SET LINER HANGER/PACKER W/ 45K#, TESTED ANNULUS, OK. SET 9 5/8" RETREIVABLE BRIDGE PLUG AT 60'. ND DRILLING SPOOL, LIFTED STACK AND SET 9 5/8" EMERGENCY SLIPS W/ 40K#. MADE COLD CUT ON 9 5/8", DRESSED OFF STUMP, NU NEW TUBING SPOOL AND TESTED PACKOFF. NU BOP STACK. CHANGED OUT TOP RAMS TO 3 1/2 X 6" VBR'S. NU AND TEST TREE MW: 0.0 TESTED BOPE, D4 DRILL. RETRIEVED 9 5/8" BRIDGE PLUG. LD AND CLEARED FLOOR. FINISHED CLEANING AND STRAPPING 4 1/2" TUBING AND JEWELRY F/ STRADDLE. RU NCS. RAN COMPLETION. TOTAL 28 JTS 4 1/2" 12.6# L-80 NSCT, 120 JTS USED 5 1/2" 17# L-80 NSCC, 108 JTS NEW 5 1/2" 17# L-80, STRADDLE W/ TWO 7" SABL-3 PACKERS. MU HANGER, INSTALLED TWC, MU LANDING JOINT AND LANDED HANGER. RILDS. RD NCS. ND BOPE, NU ADAPTER FLANGE AND TESTED. NU TREE. WELL : A-5 OPERATION: RIG : NABORS 2ES PAGE: 6 12/12/94 (16) TD: 11360 PB:10532 RELEASE RIG MW: 0.0 NU TREE. ALIGNMENT W/ FLOW LINE SLIGHTLY OFF, REALIGNED TO FLOW FINE AND RETESTED ADAPTER FLANGE. TESTED TREE. RU LUBRICATOR AND PULLED TWC. RU AND DISPLACED CLEAN SEAWATER W/ 20 GAL/100 BBL COREXIT TO BOTTOM PACKER, FOLLOWED BY 95 BBLS 60/40 METHANOL WATER F/ FREEZE PROTECTION. ALLOWED FREEZE PROTECTION TO U-TUBE INTO TUBING. DROPPED 2 1/4" SETTING BALL/ROD, SET PACKERS. HELD SETTING PRESSURE F/ 30 MIN, LOST 400 PSI. REPRESSURED TO 4000 PSI AND LOST 100 PSI. BLED OFF TUBING PRESSURE AND TESTED TUBING/CASING ANNULUS. SOLID TEST. SUSPECT TUBING TEST TO REFLECT POOR SEAT ON RHC PLUG AND BAIL. BLED OFF PRESSURE, SET BPV. INSTALLED WELLHEAD GAUGES, SECURED WELL. RELEASE RIG @ .~ 1800 HRS ON 12/11/94. ~' SIGNATURE: (drilling superintendent) DATE: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 23 November 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION A-05 M-38 K-09 1 CCL FINAL BL + RF 1 PFC/PERF FINAL BL+RF 1 LDWG TAPE & LISTER 1 PDK FINAL BL + RF i'LDWG TAPE & LISTER 1 PFC FINAL BL + RF 1 PFC FINAL BL + RF i CCL FINAL BL + RF ECC No. Run # i 3316.03 Run # 1 Run # 1 Run # 1 3561.01 ~609.02 Run # 1 6012.02 Run # 1 6093.02 Run # i 6300.02 Run # 1 6304.00 Please sign and return to: ~las Wirelin~~ices 5~.0 B__S~ //' STATE OF ALASKA ~ Ai~.SKA OIL AND GAS CONSERVATION COMMI~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon~ Alter casing ~ Change approved program Suspend ~ Operation Shutdown ~ Repair well x Plugging 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Pull tubing X Variance 4. Location of well at surface 1896' FSL, 923' FEL, Section 35, T11N, R13E, UM At top of productive interval 2180' FSL, 492' FEL, Section 34, T11N, R13E, UM At effective depth 2268' FSL, 599' FEL, Section 34, T11N, R13E, UM At total depth 2316' FSL, 645' FEL, Section 34, T11N, R13E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5. Type of Well: Development X Exploratory ~ Stratigraphic ~ Service Re-enter suspended well Time extension ~ Stimulate ~ Perforate Other 6. Datum elevation (DF or KB) KBE = 65.89 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-05 (43-34-11-13) PBU 9. Permit number 72-08 10. APl number 50- 029-20116 11. Field/Pool Prudhoe Bay Field~Oil Pool 11370 feet Plugs (measured) 9348 feet BKB 11181 feet Junk (measured) 9171 feet BKB ORIG NAL feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 90' 30" 300 sx 110' 110' 2258' 2O' x ~a" 8700 sx 2278' 2278' 9794' ~3-3/8"x 9-5,,8" 1625 sx 9814' 7966' true vertical 8922'-8932', 8939'-8948', 8958'-8969', 8978'-8997' (Squeezed) 8823'-8841', 8921'-8948' (Open) 2086' 7" 485 sx 9274'- 11360' 7530'-9339' measured 10914'-10924', 10932'-10942', 10952'-10964', 10974'-10994'(Squeezed) 10806'- 10826', 10912'- 10942' (Open) RECEIVI]D Tubing (size, grade, and measured depth) 5-1/2" 12.6tt NT-80 @ 9266' Packers and SSSV (type and measured depth) Baker "SAB-3" Packer @ 9217'; Otis SSSV @ 2112' N0V 1 6 1994 Alaska 0il & Gas Cons, C0mmissl0~ Anch0ra~je 13. Attachments Description summary of proposal x Detailed operations program BOP sketch 14. Estimated date for commencing operation 11/22/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas .~ Service Water Injector Suspended I17. I hereby certify that the for_egojqg is true and correct to the best of my knowledge. Signed /~,'{~/~ 7,-~~ Title Drilling Engineer Supervisor ' - / ( ( ./ FOR COMMISSION USE ONLY Conditions of approval: Notify ~:=,orfimission so representative may witness Plug integrity_ BOP Test/,-' Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- ~ Approved by order of the Commission OI:IIG'IIIIAL SIGNED RUSSELL A. DOUGI~,.,e.~ Form 10-403 Rev 06/15/88 Date ? ? I Approval No. Approved Copy Returned I.I-. (Join missioner D,~te SUBMIT IN TRIPLICATE A-05 RIG WORKOVER Objective A rig workover of well A-05 is proposed to repair a shallow 9-5/8" casing leak to allow conversion from water to MI injection. The 9-5/8" is leaking past a 9-5/8" x 13-3/8" packer at 1839'. A 2300' 7-5/8" scab will be run to cover the leak. The existing 5-1/2" L-80 tubing will be rerun and stung into a new packer set in the 7" liner. GLM's will not be run. Timing: The workover will begin by mid-November but may be expedited to accomodate the rig schedule. This workover will require an estimated 11 days. A pad to pad move will be required by Nabors 2ES. Procedure Outline: Pre 1. 2. 3. 4. 5. 6. 7. Rig Work: Pull SSSV. Circulate well to kill weight fluid through deepest GLM. Install IBP + Sand with Cmt cap to cover peals. Bleed tubing and annuli pressures to zero. Freeze protect tbg & annulus. Cut 5.5" tbg just above the packer Install BPV tubing hanger. Remove wellhouse and flowlines, level pad, dig out cellar. Short Rig Work Summary: 1. Pull BPV. Circulate well. . 3. 4. 5. 6. 7. 8. 9. 10. 11. ND tree. NU BOPE. Test to 5000 psi Pull BPV. Pull 5-1/2" tubing. TIH w/PRT tool. Mill & fish packer. TIH w/RTTS & isolate 9-5/8" casing leak. Circ diesel from 2300' to surf Cut and LD top joint of 9-5/8" Run 7-5/8" scab with hydraulic-set packer. Run 5-1/2" completion w/new 7" packer. Set pkr. Test annulus to 4000 psi. ND BOPE. NU and test tree to 5000 psi. Freeze protect well. Set BPV. Release dg. u.,,'[l co ~,/c 7- ~.ff-e,- R££EIVEO NOV '~ 6 1994 0il & Gas Cons. Commission Anchoraje 11/16/94 Page 1 AFE Cost A'05 MATERIAL REQUIREMENTS Amount 3 1 2 2 2 4 2 25 1 1 1 6O Description 5-1/2" X Nipples Packer, 7" x 4-1/2" 5-1/2" 10' Pup 5-1/2" 6' Pup 5-1/2" 20' Pup 4-1/2" 10' Pup 5-1/2" Flow Coupling 5-1/2" Tubing, L-80 5-1/2" X Profile 5-1/2" K-valve 9-5/8" x 7-5/8" pkr for scab liner 7-5/8" 29# L-80 Total Tangibles Estimated Cost 40OO 20,000 1000 1000 1000 2000 3000 10,000 1000 2,00O 20,000 54,000 $119,000 Non-Rig Work Dummy mandrels, kill well Kill and F/P fluid Non-Rig Intangibles Estimated Cost 30,000 50.000 $80,000 Rig Work Rig Move Brine/Packer Fluids Test Packer & RBP Rental Fishing Cost Rig Cost- Nabors 2ES: Total Intangibles 14 days Rig Intangibles Estimated Cost 20,000 40,000 10,000 75,0O0 188.000 $333,000 RECEIVED NOV 1 6 1994 Alaska 0il & Gas Cons. Commission Anchoraje $413,000 11/16/94 Page 2 AFE Cost TREE: 7-1/16" 5M ClW WELLHEAD: 13-5/8 5M McEVOY -coNv. ACTUATOR: OTIS 1846 I Top 9-5/8" 12' PBR 1857 I Bottom 9-5/8" Seal Assy 2018 IBottom 9-5/8" Duplex Shoe Upper FO Cementer Lower FO Cementer 5-1/2" 12.6# NT-80S NSCC TUBING TUBING ID: 4.892" CAPACITY: 0.0232 BBL/FT KOP: 2300 MAX ANGLE: 54 4.5" L-80 tbg TOPOF I9272 7" LINER 9-5/8", 47#/ft, L-80, BTRS I 9814 I~ :i:i:i:i:::::::::::::::::::::i:i:i:i:i:i:{:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i:~:~:.~...~;:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:.~:i:i:i:i:i:i:i:i::.:is:i: PERFORATION SUMMARY REF. LOG: BHCS 4-9-72 ISIZESPF INTERVAL OPEN/SQZ'D 3 1/8 4 10806-10826 OPEN-8/8/91 i 4 10914-10924 SQZ'D-8/8/91 4 10932-10942 SQZ'D-8/8/91 4 10952-10964 SQZ'D-8/8/91 SQZ'D.8/8/91 4 10974-10994 4 11066- SQZ'D 13 3/8 6 10806-10826 Open-9/19/91 3 3/8 6 10912-10942 Open-8/15/91 A-05 KB. ELEV = 65.89 BF. ELEV = 46.17 -18-5/8" 96.5#/ft K-55 8RD 3-3/8" 72#/ft N-80 BTRS 5-1/2" K-Valve LANDING NIPPLE 2100' x20"X-Over ! ~SS~ I 9-5/8 x 13-3/8 TIW PKR I 1839 .... , 9-5/8" 47#/ft L-80 NSCC I" 1854 13-3/8" x 9-5/8" X-Over ~JD..1.LJ " 9-5/8 x 7-5/8 Scab Liner 3-D PKR Set @ 2400' MD 5.5" x 4.5" X/O just above the top of 7" liner X Nipple with 3.813" ID @ 9270' MD 7" x 4.5" Hud Baker Packer Set @ 9300' MD X nipple 3.813" ID @ 9315' MD XN Nipple with 3.725" No-Go @ 9325' MD MARKER JOINT I 10734 ,I Sand/Cmtl PLug @ 100' Above Perfs WARNING: RADIO TRANSMITTER IN WEATHER MONITORING SHACK MUST BE TURNED OFF BEFORE ANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN! CONTA CT PAD OPERA TOR. RECEIVED NOV I G 1994 klask~ Uti & Gas Cons. Commission Anchorage DATE 11/11/94 Prepared Z. Runje COMMENTS Post RWO Completion Schematic PRUDHOE BAY UNIT WELL: A-05 APl NO' ~0-029-20116 SEC 35 ,; TN 11N: RGE 13E BP Exploration (Alaska) STATE OF ALASKA '~'~'~-~ AI_~ .A OIL AND GAS CONSERVATION COMMISS. .~' REPORT OF SUNDRY WELL OPERATIONS Pull tubing ... Alter casing ..... Repair well Other x ~.. T--~'~'~'~ell: ~.. ~'e~on (DF or ~ -~d 1. Operations performed: Operation shutdown 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1896' SNL, 923' WEL, Sec. 35, T11N, R13E, UPM At top of productive interval 2180' NSL, 492' WEL, Sec. 34, T11N, R13E, UPM At effective depth 2268' NSL, 599' WEL, Sec. 34, T11 N, R 13E, UPM At total depth 2316' NSL, 645' WEL, Sec. 34, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical 11370 feet BKB 9348 feet Effective depth: measured 11266 feet true vertical BKB 9272 feet Development Exploratory Stratigraphi¢ Service KBE = 65.89 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-05 (43.34-11.13) PBU 9. Permit number/approval number 72-08 / 10. APl number 50- 029-20116 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Junk (measured) fill at 11266' MD (8/6/91) Casing Length Size Cemented Measured depth Structural -- Conductor 90 30 300 sx 110 Surface 2258 20xl 8700 sx 2278 Intermediate 9794 13 3/8 1625 sx 9814 Production -- ¢ 9 5/8 Liner 2086 7 485 sx 9274-11360 Perforation depth: measured 10806'-10826' (Sag R.) 10914'- 10924', 10932'- 10942', 10952'- 10964', 10974'- 10994 (Ivishak) True vertical depth BKB 110 2278 7966 7530-9339 true vertical subsea Tubing (size, grade, and measured depth) 5-1/2", 17#, NT-80S NSCC tubing to 9266'MD Packers and SSSV (type and measured depth) 5-1/2" Otis 'HRQ' BVLN, BTRS@2111' MD 13. Stimulation or cement squeeze summary 7/1/93 Converted Well from Producer to Injector Intervals treated (measured) Treatment description including volumes used and final pressure 9-5/8" Baker 'SAB-3' Permanent Paker NSCC @9215'MD, RECEIVED S E P 1,5 199~ Alaska 0il & Gas Cons, 14. Prior to well operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure **Converted Well from Producer to Injector** Anchorage Tubing Pressure Subsequentto operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas__ Suspended Service Water Injector 17. I hereby ;ertify that the foregoin..q is true apd correct to .the best of my knowledge. Signed ~~ ~,)_ ~:~~ Title Senior TechnicalAssistantl Form lO-404~Rev 06/15/88 / Date SUBMIT IN DLI'PLIC'ATE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/29/93 T# 84532 BP/PBU ,~)G Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well ~ecords at (907) 564-4004. A-05 CH 10/28/92 REF~ JEWELRY-CCL LOG CAMCO Information Services Well Records RECEIVED APR 1 2 199~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 DATE: 12/04/92 T# 84143 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. ~-o5 ?~--? SAs ~,~-~ suRvs¥ 10/28/92 #1 Z-04 ~¢-l~3 LEAK DET 10/28/92 #1 500.00- 9490.00 CAMCO 5 " 0.00- 9050.00 CAMCO 5 " Information Control Well Records EIVED DEC 1 8 1992. ,~,laska Oil & Gas Cons. Commission Anchorage AL. ~. OIL AND GAS CONSERVATION COMMI5 ,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska)/nc. '3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1896' SNL, 923' WEL, Sec. 35, T11N, R13E; UPM At top of productive interval 2180' NSL, 492' WEL, Sec. 34, T11N, R13E, UPM At effective depth 2268' NSL, 599' WEL, Sec. 34, T11N, R13E, UPM At total depth 2316'NSL, 645'WEL, Sec. 34, T11N, R13E, UPM 12. Present Well condition summary Total depth: measured true vertical Effective depth: measured true vertical Alter casing Stimulate 3( Plugging Repair well 5. Type of Well: Development X Exploratory Stratlgraphlc Service 113'70feet BKB 9348feet 11181feet BKB 9171feet Plugs (measured) Junk (measured) Pedorate × Other 3( 6. Datum elevation (DF or KB) KBE ,, 65.89 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-05 (43-34-11-13) PBU 9. Permit number/approval number 72-08/ 10. APl number 50- 029-20116 11. Field/Pool Prudhoe Oil Pool fill at 11181' MD (04/88) Casing Length Structural -- Conductor 90 Surface 2258 Intermediate 9794 Production -- Liner 2086 Perforation depth: measured Size Cemented Measured depth 30 300 sx 110 20x18 8700 sx 2278 13 3/8 1625 sx 9814 x 9 5/8 7 485 sx 9274-11360 10806'- 10826' (Sag R.) 10914'-10924', 10932'-10942', 10952'-10964', 10974'-10994 (Ivishak) True vertical depth BKB 110 2278 7966 7530-9339 true vertical subsea Tubing (size, grade, and measured depth) 5-1/2" 12.6# NT-80@9266' Packers and SSSV (type and measured depth) Baker "SAB-3" Packer @9217'; Otis SSSV 13. Stimulation or cement squeeze summary See Attachment 14. Intervals treated (measured) Treatment description including volumes used and final pressure MAY 2 9 1992 Alaska 0ii & Gas Cons. C0mmissio~ Anchorage Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 870 1303 400 925 4280 6247 1467 860 16. Status ~ wellclassification as: Oil X. Gas Suspended Service 17, I hereby oe~ify that the foregoing is true and oorrect to the best of my knowledge. Signed ~- Title Supervisor Watedlood/Miscible Flood Form 10-404 Rev 06/15/88 i~ 245 328 Date SUBMIT IN DUPLICATE WELL A-05 (43-34-11-13) REPERF/FRAC/REFRAC The following additional interval was reperforated on 08/15/91 using 3 3/8 gun diameter with 6 shot density, random orientation and 60 phasing. 10912' - 10942' MD Performed hydraulic fracture on 09/14/91 pumped a total of 60000# 16/20 and 36800# 12/18 of carbolite pumped. 5200# left in casing, 91600# left behind pipe. Final ISIP was 2200 psig, causing a net pressure increase of 500 psi. The following additional interval was reperforated on 09/19/91 using 3 3/8 gun diameter with 6 shot density, random orientation and 60 phasing. 10806' - 10826' MD Performed hydraulic fracture on 10/06/91 pumped a total of 128600# CL. 55100 # behind pipe, 73500# in liner. Screened out to the tub. 4/21/92 fjh RECEIVED MAY 2 9 1992 Alaska Oil & Gas Cons. Commission Anchorage ~ STATE OF ALASKA \ ~, -- - -- u # § / REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing X Alter casing Repair well ... Perforate Other X WORKOVER 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1896' FSL, 923' FEL, Section 35, T11N, R13E, UM At top of productive interval 2180' FSL, 492' FEL, Section 34, T11N, R13E, UM At effective depth 2268' FSL, 599' FEL, Section 34, T11N, R13E, UM At total depth 2316' FSL, 645' FEL, Section 34, T11 N, R 13E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11370 feet Plugs (measured) 9348 feet BKB 11181 feet Junk (measured) 9171 feet BKB 6. Datum elevation (DF or KB) KBE = 65.89 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-05 (43-34-11-13) PBU 9. Permit number/approval number 72-08 / N/A (Cons. Order #258) 10. APl number 50- 029-20116 11. Field/Pool Prudhoe Bay Field~Oil Pool Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 90' 30" 300 sx 2258' 2O'x la" 8700 sx 9794' 13.3/a"x~-.~'a" 1625sx 2086' 7" 485 sx measured None true vertical None Tubing (size, grade, and measured depth) 5-1/2" 12.6it NT-80 @ 9266' Packers and SSSV (type and measured depth) Measured depth True vertical depth 110' 110' 2278' 2278' 9814' 7966' 9274'- 11360' 7530'-9339' RECEIVED MAY 1 2 1992 Alas~ 011 & Gas Cons. CommisSlo~ Baker "SAB-3" Packer ~ 9217'; Otis SSS V ~ 2112' ;Anchorage 13. Stimulation or cement squeeze summary See Attached Activity Summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaoe Production or Iniection Data - Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run . Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~<~'/2~-,~._~.~,. ~ ~ ~' ~d.(~;:~ ~7( ~ Title Completion Engineering Supervisor Form 10-404 j~v 06/15/88 Date 4/6/92 SUBMIT IN DUPLICATE BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. M0nde, y, July 29. 1991 WELL: A-05 (43-~4-11-13} PRUDEIOE BAY UNIT Rig: Doyon Rig #16 Day: 1_ Expense AFE Number: Expense AFE Amount = 145056 Current Field Costs = Estimated Final Cost = Current Operation'.. Rig up wireline unit. Summary_ of Last 48 Hours Accepted rig @0001 hrs 7-28-91. ND tree, NU BOPE. Pulled 4-1/2" tubing. unit to pull stuck SSSV @ report time. Rigging up wireline RECEIVED MAY 1 2 1992 Alaska Oil & Gas Cons. Commission Anchorage Reviewed By' BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Tuesday. July 30. 1991 WELL: A-O5 PRUDHOE BAY UNIT, · Rig: Doyon Rig #16 Day: 3 Expense AFE Number: Expense AFE Amount = 145056 Current Field Costs = Estimated Final Cost = Current Ooeration: Jar on tbg. Summary_ of Last 24 Hours Circ thru SSSV. R/U Otis. RIH. Tag SSSV @ 60'. Cannot pull SSSV free. POOH. RIH w/new jars. Pull SSSV free. R/D Otis. RIH w/BHA. Jar on stuck tbg. Jar tbg free. RIH w/1 jt tbg. Well flowing. Circ. RIH w/tbg. Tbg stuck. Jar on stuck tbg. Reviewed By: BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT : As of 0600 Hrs. Wednesday, July 31, 1991 WELL: A-O5 ' Rig: Doyen Rig. #16 Day: 4_.. Expense AFE Number: Expense AFE Amount = ~ , 145056 Current Field Costs = Estimated Final Cost = Current Operati0n: Circ. Summary of Last 24 Hours Attempt to RIH w/4-1/2" tbg. Pull tbg. Stuck @ SSSV. Jar on tbg. Free. L/D jar ass'y, land tbg on rams. N/D flow line. N/U shooting flange. Move rig off hole. R/U Fmc Master CTU. Test lub. RIH w/coiled tbg to 11000'. Circ & R/U BJ cmt perfs. Reviewed By:/2.~t" BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Thursday, August 1. 1991 WELL: A-05 PRUDHOE BAY UNIT · Rig: Doyon Rig #16 Day: 5 Expense AFE Number: Expense AFE Amount = 145056 Current Field Costs = Estimated Final Cost = Current Operation: P/U csg spear & fish ass'y. Summary of Last 24 Hour8 R/U BJ. Pump 5 bbls water, 30 bbls 'G' cmt @ 15.8 ppg, 1.16 yield. Disp wi 29 bbls seawater. POOH 100' above cmt. Hold 200 psi on tbg. POOH w/Coiled tbg. R/D FracMaster. Move rig over well. R/D Shoot flange. N/U fiowline. Screw into TiW valve/tbg hung in BOPE. Pull TiW to floor. Test sqz to 1000 psi. OK. R/U Atlas. RIH w/jet cutter. Cut tbg above SSSV @ 70' (WLM). R/D Atlas. L/D tbg. Circ Arctic pack out. N/D BOPE. N/D tbg spool. NAJ mud cross. N/U BOPE. Test BOPE. P/U cso smear, fish ass'v. Reviewed By:/¢'~ ~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Friday. Auoust 2.1991 -- WELL: A-05 Day: 6 Expense AFE Number: 145056 Expense AFE Amount = PRUDHOE BAY UNIT Rig: D0y0n.,, Rig #16 Current Field Costs = Estimated Final Cost = Current Operation' POOH wIfish. Summary_ of Last 24 Hours Spear into csg. Jar free f/tieback sleeve. R/U Weatherford. L/D 3 its csg. Circ arctic pack out. L/D csg, seal ass'y. RIH w/FTA. Rev circw/5 bbis diesel, seawater. Tag TOF @ 2128'. Work over 4-1/2" tbg. Circ. POOH w/fish. Reviewed By: ¢?" BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Monday. Au_aust 5. 1991 WELL: A-05 pRUDHQ, E BAY UNIT Rig: Day: 9 ExpenSe AFE Number: Expense AFE Amount = 145O56 Current Field Costs = Estimated Final Cost = Doyon Rig #16 Current Operation: N/U BOPE. .. Summary of Last 72 Hours POOH w/fish. RIH w/FTA. Tag fish @ 9166'. POOH & L/D fish. RIH w/mill. Mill on pkr @ 9194'. Pkr free. POOH. RIH. Spear into pkr. POOH w/pkr. RIH. Set storm pkr @ 50'. Install new csg spool. POOH w/storm pkr. RIH. Tag PBR. Rev circ arctic pack. RIH w/9-5/8" csg. Sting into PBR. Set pin pkr. Test annulus @ 1000 psi. N/D & N/U BOPE. Reviewed By: .bF....~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Tuesday. Auclust 6, 1991 WELL: A-05 pRIJDHOE BAY UNIT Rig: D0yon Rig #16 Day: 10 Expense AFE Number: Expense AFE Amount = 145056 Current Field Costs = Estimated Final Cost = Current Operation: CBU. Summary_ of Last 24 Hours N/U BOPE.' Test BOPE. RIH w/FOC closing fingers. Test csg. POOH. RIH w/mill. Drlg cmt f/ 10250°-11030'. RIH to 11266' (PBTD). CBU. RECEIVED MAY 1 2 1992 A/asia 0il & Gas Cons. 6ommisslo[, :Anchorage Reviewed By: D~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday. August 7. 1991 WELL: A-05 Rig: D0yon #16 Day: 1 1 Expense AFE Number: Expense AFE Amount = 145O56 Current Field Costs = Estimated Final Cost = Current Operation' . POOH, LDDP. Summary_ of Last 24 Hours Circ. POOH. RIH w/bit, scraper to 9286' (TOL). POOH. RIH w/scraper. Wash f/11120'-11259'. Rev circ. Disp w/bdne. POOH. LDDP. Re~/iewed By' BP EXPLORATION (ALASKA), INc. DAILY WORKOVER REPORT: As of 0600 Hrs. Thursday. August 8. 1991 WELL: A-05 PRUDHOE BAY UNIT Rig: Doyon #16 Day: 1_~2 Expense AFE Number: Expense AFE Amount = 145056 Current Field Costs = Estimated Final Cost = Current Operation' R/U Otis. Summary_ of Last 24 Hours POOH. R/U Otis. RIH w/GR/JB. RIH w/5-1/2" tbg. Test cntrl lines. Land tbg. R/U Otis for W/L work. % Reviewed By: ~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Friday. Au(lust 9. 1991 WELL: A-05 PRUDHOE BAY UNIT Rig' Dovon #16 Day: 13 Expense AFE Number: Expense AFE Amount = 145O56 Current Field Costs = Estimated Final Cost = Current Operation' Rig released @ 24:00 hrs. Summary_ of La, st 24 Hours Pull SSSV, shear sub. Replace same. R/D Otis. N/D BOPE. N/U tree. Test tree. Set pkr. Test annulus. Shear out. Disp w/140 bbls diesel. Secure well. Rig released @ 24:00 hrs, ,.8/8/91. Move rig to A-15. RE{ EIVED MAY 1 2 1992 Alasl{a 011 & Gas Cons. L;ommissio~' Anchorage Re{/iewed By: 0,~-----~ STATE OF ALASKA ALA~cJ~ OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing x Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1896' SNL, 923' WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 2180' NSL, 492' WEL, SEC. 34, T11N, R13E, UPM At effective depth 2282' NSL, 603' WEL, SEC. 34, T11N, R13E, UPM At total depth 2316' NSL, 645'WEL, SEC. 34, T11N, R13E, UPM 12. Present well condition summary Total depth: measured 11370 feet true vertical BKB 9348 feet 5. Type of Well: Development Exploratory Stratigraphic Service Plugs (measured) 6. Datum elevation (DF or KB) KBE , 65.89 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-05 (43-34-11-13) 9. Permit number/approval number 72-08/Conservation order 258 10. APl number 50- 029-20116 11. Field/Pool Prudhoe Bay Field/Oil Pool Effective depth: measured 11266 feet true vertical BKB 9272 feet Junk (measured) Fill @ 11266 (8/6/91) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size true vertical Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 5-1/2", 17#, NT-80S NSCC tubing to 9266°MD RECEIVED MAY - 5 1992 Alaska 0il & Gas Cons. CommiSSi0~ ~nchorage Packers and SSSV (type and measured depth) 9-5/8"Baker 'SAB-3' Permanent Packer NSCC @ 9215'MD, 5-1/2" Otis 'HRQ' BVLN, BTRS @ 2111' MD 13. Stimulation or cement squeeze summary See attached Activity Summary Intervals treated (measured) 10806'-10994' Treatment description including volumes used and final pressure Squeeze perforated intervals 168 cu fl Class "G", final pressure ,= 200 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations x Oil x Gas Suspended 17. I hereby certify that the foregoing is true and correct to th~st of my knowledge. Si~ned /~g~'~ ~Title WorkoverEn~lineerSupervisor Form 10-404 Rev 06/15/88 Service Date ~,',~,~ ~//~:~ SUBMIT IN DU'PLI6ATE ACTIVITY SUMMARY for WELL pROjECT 145056 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : A-05 Page: 1 DRLG RIG : DOYON 16 WO/COMP RIG: DOYON 16 (COMP) NU ND: 6.0 -- 07/28/91 (1) TD:lll20 PB:11259 SUPV:SCALES TESING BOP MOVE RIG, NU/BOPE, TESTING BOPE. (145056) DAILY: $ 17,750 CUM: $ MW: 8.5 Seawater 17,750 EFC: $ 685,000 (COMP) NU ND: 4.0 07/29/91 (2) TD:lll20 PB:11259 SUPV:SCALES PL TBG: 20.0 RIG UP WIRELINE UNIT MW: 8.5 Seawater TEST BOPE,CHANGE PIPE RAMS, TEST SAME, RU TO PULL TUBING, RU OTIS TO PULL CONTROL LINE, LAY DOWN 6 JTS, JT 1 COLLAPSED, JT 2 THROUGH 6 CHRUSHED, HOOK UP CONTROL LINES TO PUMP OPEN SSSV, CIRC OUT GAS UNTIL WELL STABLE, LAY DOWN 45 JTS TUBING, LOST 12 CONTROL LINE PROTECTORS, LEFT 600' CONTROL LINE IN HOLE, CHANGE ELEVATORS TO 200 TON, TBG STUCK M/U FLOOR VALVE, PRESSURE UP ON TBG OPEN SSSV, CIRC, RU WIRELINE UNIT TO PULL SSSV (145056) DAILY: $ 22,437 CUM: $ 40,187 EFC: $ 685,000 (COMP) PL TBG: 21.0 WELL CTL: 3.0 07/30/91 ( TD:ll120 PB:11259 SUPV:SCALES 3) JAR DOWN ON STUCK TUBING MW: 8.5 Seawater CIRC WELL THROUGH SSSV UNTIL WELL STABLE, R/U OTIS WIRELINE UNIT, PULL SSSV FREE, M/U SURFACE JARS, JAR ON STUCK TBG, M/U 1 JT 4 1/2" TBG RIH, WELL FLOWING, CIRC OUT GAS & CRUDE, FISH CONTROL LINE, ATTEMPT RIH W/TBG, TBG STUCK JAR DOWN ON STUCK TBG. (145056) DAILY: $ 26,612 CUM: $ 66,799 EFC: $ 685,000 (COMP) PL TBG: 24.0 07/31/91 ( 4) TD:lll20 PB:11259 SUPV:EDP CIRC HOLE,RU TO CMNT PERFS MW: 8.5 Seawater ATTEMPT RIH W/TBGM TBG STUCK, JAR ON TBG, TBG FREE,CHG RAMS, LAND TBG, ND FLOW LINE, NU SHOOTING FLANGE, MOVE RIG OFF HOLE, R/U COILED TBG UNIT,TEST LUB, RIH TO 11000', CIRC, R/U TO CMNT PERFS. (145056) DAILY: $ 24,927 CUM: $ 91,726 EFC: $ 685,000 (COMP) PL TBG: 24.0 08/01/91 (5) TD:ll120 PB:11259 SUPV:EDP P/U SPEAR & FISHING ASSEM MW: 8.5 Seawater R/U CEMENTERS, PUMP 5 BBLS H20/30 BBLS CEMENT DISPLACED W/29 BBLS SEA WATER POH R/D COILED TBG, MOVE RIG OVER WELL, NU FLOWLINE,PULL TIW, TEST SQUEEZE, RU WL RIH W/JET CUTTER, CUT TBG, CIRC ARCTIC PACK, ND BOPS/TBG SPOOL,NU MUD CROSS/ BOPS,TEST BOP'S P/U CSG SPEAR & FISHING ASSEMB. (145056) DAILY: $ 30,752 CUM: $ 122,478 EFC: $ 685,000 (COMP) PL TBG: 24.0 08/02/91 (6) TD:lll20 PB:11259 SUPV:EDP POH W/ FISH MW: 8.5 Seawater SPEAR CSG & JAR FREE, LD 3 JTD 9 5/8" CSG, RU & CIRC CRUDE & ARCTIC PACK LD 10 3/4" CSG, WELL GIVING UP FLUID, LD 10 3/4" CSG, RD W/L, MU FISHING BHA RIH, REVS CIRC, TAG TOP OF FISH, CIRC, POH W/FISH. (145056) DAILY: $ 123,517 CUM: $ 245,995 EFC: $ 685,000 RE EIYED MAY - 5 1992 Alaska Oil & Gas Cons. ~mm~s$~oo Anchorage ACTIVITY SUMMARY for WELL PROJECT 145056 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : A-05 Page: 2 DRLG RIG : DOYON 16 WO/COMP RIG: DOYON 16 (COMP) PL PBR: 11.5 PL PKR: 2.0 PL TBG: 10.5 08/03/91 ( 7) RIH MW: 8.5 Seawater TD:ll120 POH W/FISH, CIRC, LD TBG, CHNG PIPE RAMS, MU FISHING BHA, PB:11259 TAG TOP OF SLICK STICK, CIRC GAS OUT, POH, LD SLICK STICK, SUPV:EDP RIH (145056) DAILY: $ 145,816 CUM: $ 391,811 EFC: $ 685,000 (COMP) CLN OUT: 1.5 08/04/91 (-- 8) TD:lll20 PB:11259 SUPV:EDP NU ND: 2.0 PL PKR: 20.5 ND BOP'S MW: 8.5 Seawater RIH W/MILL, MILL ON PKR, PUSH PACKER TO 9278', CIRC GAS OUT, POH W/MILL, RIH W/SPEAR, SPEAR INTO PACKER @ 9277', CIRC, POH W/ PKR & TAILPIPE, LAY DOWN SAME, RIH, REVS CIRC, SET STORM PKR ND BOP'S (145056) DAILY: $ 139,108 CUM: $ 530,919 EFC: $ 685,000 (COMP) CLN OUT: 4.5 08/05/91 ( 9) TD:lll20 PB:11259 SUPV:EDP NU ND: 7.5 PL PBR: 17.5 RUN CSG: 12.0 NU BOP'S MW: 8.5 Seawater INSTALL CSG SPOOL & TEST,NU BOP'S & TEST, LD STORM PKR, RIH, TAG PBR @ 1852' REVS CIRC,POH & LD DRILL COLLARS, RU TO RUN CSG, RUN MULE SHOE, 9 5/8" PKR & 9 5/8" CSG STING INTO PKR, REVS CIRC, SET PIN PKR @ 1861' ND BOP'S,SET SLIPS, NU TBG SPOOL, TEST SAME, NU BOP'S (145056) DAILY: $ 33,019 CUM: $ 563,938 EFC: $ 685,000 (COMP) RUN CSG: 24.0 08/06/91 (10) CIRC MW: 8.5 Seawater TD:lll20 NU BOP'S @ TEST RIH W/ CLOSING FINGERS RAN THROUGH FOC'S @ PB:11259 2076' @ 2157',TEST CSG, POH, RIH W/MILL, TAG CMT @ 10250, SUPV:EDP DRILL CMT F/10250 TO 11030' RIH TO 11266' PBTD, CIRC. (145056) DAILY: $ 44,950 CUM: $ 608,888 EFC: $ 685,000 (COMP) CLN OUT: 19.5 RUN CSG: 4.5 08/07/91 (11) POH LDDP MW: 8.5 Seawater TD:lll20 CIRC, POH W/MILL, RIH,W/BIT & SCRAPER, POH, RIH W/CSG PB:11259 SCRAPER, RIH TO 11120' WASH TO BTM 11120 TO 11259', REVS SUPV:EDP CIRC & DISPLACE HOLE W/BRINE, POH LDDP. (145056) DAILY: $ 15,694 CUM: $ 624,582 EFC: $ 685,000 (COMP) CLN OUT: 7.5 08/08/91 (--12) TD:lll20 PB:11259 SUPV:EDP RUN COMP: 16.5 RU W/L MW: 8.5 Seawater POH LDDP, RU W/L, RU & RUN 5.5 TBG, CONNECT & TEST CONTROL LINES, LAND TBG RD EQUIP, RU W/L. (145056) DAILY: $ 28,940 CUM: $ 653,522 EFC: $ 685,000 (COMP) NU ND: 12.0 RUN COMP: 6.0 08/09/91 (13) RIG RELEASED MW: 8.5 Seawater TD:lll20 PULL SSSV & SHEAR OUT SUB, RUN PERF GU TO 11244', REPLACE PB:11259 SSSV & SHEAR SUB RD W/L, ND BOP NU TREE,TEST SAME, SECURE SUPV:EDP WELL, RIG RELEASED 8/9/91 2400 (145056) DAILY: $ 63,558 CUM: $ 717,080 EFC: $ 685,000 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-6111 DATE: 01/09/92 T9 83169 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. PRODUCTION LOG 12/31/91 #1 10650.00-10965.00 SCH l! Information Control Well Records Adrian J. Martin BP EXPLORATION BP ExDtora[ion (Alaska) Inc. 900 Eas; 8enson Bouievarcl P.O. Box 196612 Anchorage. Alaska 99519-6612 (9o7) DATE: 12/13/91 T# 83093 BP CASED HOLE FINALS Enclosed is your copy of the materials lasted below. If you have any questions, Please contact BP Well Records at (907) 564-4004. PERF 12/09/91 ~'~ PRODUCTION LOG 12/08/91 PRODUCTION LOG.. 12/06/91 - 9300.00- 9388.00 SCM 10700.00-10925.00 SCM 9150.00- 9480.00 SCM Information Control Well Records Adrian j. Martin 'C'EIVED Y ./// / I Alaska 0,, & Gas oCOr~S§~ Corem,ssi0, BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 RECEIVED OCT I 8 1991 Alaska 0il & Gas Cons. Commission Anchorage BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. . DATE: 10/10/91 T# 82910 ~'%M-t6?G PITS 09/20/91 ~1 10860.00 ~-~ B-22/ PITS 09/07/91 91 10800.00 9t-tf Y-30u'" CCL 09/16/91 ~1 8650.000 .. ~0-~ Y-2'9u'/ CCL 09/16/91 #1 10131.00 ~3-3~N-t9 ~ CCL 09/25/91 ~1 9000.000 ~-~W-38/~ GAS LIFT SURVEY 09/15/91 #1 200.0000 ~I~B--21u' PROD-F 08/13/91 ~1 9550.000 ~1-90 Y~26--- GAS LIFT SUrVEY 09/16/91 #1 5400.000 ~'30 X-26~ INJ 09/24/91 #1 9150.000 ~~-05~ CL 09/07/91 #1 9100.000 ~9.~R-06~' INJ 09/11/91 #1 9800.000 %~oI~K-02A%/~ PROD-F 08/24/91 #1 11000.00 Fg-f~W-09~,/ GR 09/11/91.#1 14200.00 7~-&~"E--03/" P'ROD-F 09/25/91 #1 12450.00 ~-~ W-16~/ LEAK DET 09/19/91.#1 2000.000 ~'-~-~Z~-R-22~'' PROD-F 08/20/91 #1 10350.00 ~/-~O B-32u'/ TEMP 09/15/91 #1 10275.00 ~-~7C-04~ PROD-F 08/24/91 #1 10350.00 ~,-17~G-26~ CL 09/04/91 ~1 10200.00 ~g~B-20J LEAK DET 08/23/91 #1 7992.000 gD-I;-~P-20 / #1 11800.00 7~-~ R-04~ #1 3200.000 r~9/~-18~ #1 9250.000 %~'9~ W-37~ #1 9800.000 ~'[9~S-0'5,/ #1 9500.000 ¥3-1~F-24,/ ~1 11800.00 \~bM-16 ~1 10850.00 %.$~R-04J' ~1 2500.000 ~Go B-32~ #1 10240.00 ~9.~0W-26~ ?Go~(~ G-01~/ LEAK DET 08/23/91 GAS LIFT SURVEY 09/04/91 PROD-F 09/25/91 PROD-F 09/15/91 CL 09/15/91 TEMP 09/03/91 PROD-F 08/26/91 GAS'LIFT SURVEY 08/26/91 INJ 09/06/91 JEWELRY LOG CAMCO 5 JEWELRY LOG CAMCO 5 CAMCO 5 08/22/91 #1 08/21/91 #1 08/23/91 ~1 10900. 12550.00 9950.000 11444.00 CAMCO 11140.00 CAMCO 9240.000 CAMCO 12.500.00 CAMCO 9755.000 CAMCO 4000.000 CAMCO 9850.000 CAMCO 10986.00 CAMCO 9680.000 CAMCO '10941.00 CAMCO 10279.00 CAMCO 11480.00 CAMCO 15162.00 CAMCO 12685 . 00 CAMCO 11270 . 00 CAMCO 10720.00 CAMCO 10953.00 CAMCO 10660.00 CAMCO 10522.00 CAMCO 9062.000 CAMCO 12553.00 CAMCO 8639.000 CAMCO 9722.000 CAMCO 10100.00 CAMCO 10224.00 CAMCO 12175.00 CAMCO 11150.00 CAMCO 9821.000 CAMCO 10807.00 CAMCO 00 11758.00 13284.00 10120.00 5 5 5 5 5 2 5 5 5 5 5 5 5 5 2/5 5 5 5 5 5 5 5 5 5 5 5 5 2/5 5 BP EXPLORATION BP Explora;ion (Alaska) Inc. 900 ~=a~ genson 8ouievar~ I:~. 8ox ~966~2 Anchorage. Alaska 99519.6612 ~s~ sm.sm DATE: 09/30/91 T# 82877 BP CASED HOLE FINALS Enclosed is your Copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. '' .... ~'u~INS.CUTTsR "09/21/91 ~1 .......... .:~-,..9136 . OCT 0 8 1991 Alaska Oil a A%%Sh~rOang~ Commission BP EXPLORATION /-,% BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :08/26/91 T~82762 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP. Well Records at (907) 564-4445. ~. ...... ~.. a-05 A-01 H-18 N-15 TUBING CUTTER CL CCL/PERF CCL/PERF PLS 08120/91 #1 8984-9140 ATLAS 5" 08/15/91 #1 10700-11030 ATLAS 5" 08/18/91 #1 8600-8734 ATLAS 5" 08/19/91 #1 9250-9700 ATLAS 5" 08/14/91 #1 9500-10140 ATLAS 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES _. ~ ~ "~ MEMORANDUM State of Alaska ~SKA OIL MD GAS CONSERVATION COMMISSION TO: Commis s ioner DATE: August 15, 1991 FILE NO: HH815- 3 TELEPHONE NO: THRU: SUBJECT: RIG/BOPE Inspection P.B.D. PBU Pad A-5 Prudhoe Oil Pool FROM: Harold R. Hawkins Petroleum inspector Saturday Auoust'3. 1991: I performed a RIG/BOPE inspection on Do¥on rig 16 for P.B.D., PBU Pad A-5. I found no infractions. I filled out a RIG/BOPE inspection report which Is attached. In sum_marY: The RIG/BOPE inspection was performed satisfactorily on Do¥on 16, P.B.D., PBU Pad A-5. Attachment. 02-00lA (Rev. 6/89) 20/11fMEMO1.PM3 OPERATION: Drlg ...... Compl Wkvr u// UIC · Operator 7/~d4~ ~)/~V' ~J4~J~ Permit Location: Sec 'T R Drlg Location (gen'i)~ /.. d/(A~} Well sign .~' I N COHPL I ANCE; yes n~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Rig/BOPE Inspection Report Representative Well name, /O/~p Representative ) ) () ) 2 () 3.() 4.() 5. 6. 7. ( ) A. DIVERTER line sz & length line conn& anchored bifurcated & dwn wind 90° targeted turns vlvs: auto & simultaneous annular pack-off condi t:t on B. BOP STACK wellhead flg wkg press stack wkg press annular preventer pi pe rams bl i nd rams stack anchored chke/ki11 line sz 90° t:urns targeted (chke & kill ln) HCR vlvs (chke & kill) manual vlvs (chke & kill) connections (flgd, whd, clmpd) dr1 spool flow nipple flow monitor control lines fi re protected C. CLOSING UNITS wkg press fluid level oprtg press press gauges sufficient vlvs regulator bypass 4-way vlvs (actuators) blind handle cover driller control panel remote control panel 8.(~ () () 9. (~ ( ) ( ) 10 ( () () ~. (v)~ () () ~2 (~ () 13. (X ( ) ( ) 14 I~.( ) ( ) ~5 () () 16.(~ () () 17. ((~_/ ( ) ( ) ~8 () () 19. ('//)- ( ) ( ) 20. (~' ( ) ( ) 21 (~ () () 22 (vJ ( ) ( ) 23. I~ ( ) ( ) 25 ( ) ( ) 27 ( ) ( ) 28 ~/~ ( ) ( ) 29 (-~/ ( ) ( ) 30 (~ () () 31 (~')/ ( ) ( ) 32. (/) () () I N COMPL I ANCE ~ yes/ no n/,a 33. ('~.. (-7 (). 34 (~/~ () () 35. (~f () ( ) 36. (~/~ ( ) ( ) 37. (-)~ () () 38. (v~/ () () 39. ( () () ~°' It,~ ( ) ( ) 4~. () () 42. ( ) ( ) (~.)'" 43. (H' () () 44.(~ () 4s. (~/ () 46. (f/)~ ( ) 47. (~/ ( ) ~8.() () ~9. (~() 51. ( ) 53. ( ) 54..(a/ ( ) s5.(~ () 56. (v~" ( ) 57.(~ () 58. (~f' ( ) ftrewall nitrogen power source (back-up) condition (leaks, hoses, etc) D. MUD SYSTEM pit level floats installed flow rate sensors mud gas separator degasser separator bypass gas sensor chke In conn trip tank E. RIG FLOOR kelly cocks (upper,lower, IBOP) floor vlvs {dart vlv, ball vlv) kelly & floor vlv wrenches driller's console (flow monitor, flow rate indicator, pit level indicators, gauges) kill sheet up-to-date gas ~etect~on monitors (H-S & methane) hydr chke panel chke manifold F. MISC EOUIPMENT flare/vent line 90e turns targeted (dwn strm choke 1ns) reserve pit ~ personnel protective equip avail all dr1 site suprvs trained for procedures H2S probes rig housekeeping RECORDS: 6ate o~ last BOP inspection: ? ~_ · I Resulting non-compliance:, /~, Date of last BOP test: Non-compliances not corrected & why: i~/~ Date corrections will be completed: /~//~ BOP lest & results proper3y en[ered on daily record? ~/~j~ / Kill sheet: current? STATE OF ALASKA 0 ~ ~ G 1~ N A L ALAo,-,A OIL AND GAS CONSERVATION COMMISSION 'APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator 3. Address AbandOn ~ Suspend Alter casing ~ Repair well Change apprOved program ~ P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1896'SNL, 923' WEL, Sec. 35, T11N, R13E, UPM At top of productive interval 2180' NSL, 492' WEL, Sec. 34, T11N, R13E, UPM At effective depth 2268' NSL, 599' WEL, Sec. 34, T11N, R13E, UPM At total depth ~ 2316' NSL, 645' WEL, Sec. 34, T11N, R13E, UPM 12. Present well condition summary Operation Shutdown ~ Plugging . Pull tubing ~ Vadance X 5. Type of Well: Development x Exploratory Stmtigraphic Service RECEIVED FEB 1,5 t991 Alaska Oil & Gas Cons. Comm%sS't0t~ Re-enter suspended well Time extension Stimulate Perforate Other " 6. Datu'm elevation (DF or KB) ' KBE ,, 65.89 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-05 (43-34-11-13) PBU 9. Permit number 72-08 10. APl number 50- 029-20116 11. Field/Pool Prudhoe Oil Pool Total depth: measured 11370 feet Plugs (measured) true vertical BKB 9348 feet Effective depth: measured 11181 feet true vertical BKB 9171 feet Junk (measured) fill at 11181'MD (04/88) Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 90 30 300 sx 110 110 Sudace 2258 20x18 8700 sx 2278 2278 Intermediate 9794 13 3/8 1625 sx 9814 7966 Production .- x 9 5/8 , Liner 2086 7 485 sx 9274-11360 7530-9, "~'W/ Perforation depth: measured 10806'-10826' (Sag R.) 10914'-10924', 10932'-10942', 10952'-10964', 10974'-10994 (Ivishak) true vertical (subsea) 8757'-8775'(Sag R.) 8857'- 8931' (four lvishak intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 9193' with 4 1/2" tailpipe to 9324' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 9193'; 4 1/2" SSS Vat 2168' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation 15. Status of well classification as: August 1989 16. If proposal was verbally approved Oil X Gas . Suspended Name of approver Chatterton 8/4/89 Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ined FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity. BOP Test~ Location clearance Mechanical Integrity Test~ Subsequent form required 10- ~c4 Approved by order of the Commission Form 10-403 Rev 06/15/88 Title Supervisor Waterflood/Miscible Flood ~=,~11 I1 I~,, '~' '- Date 2.,/~'Z,/~ ! Approval No. Comm~ Date ~'.~..~,~-- ~, SUBMIT IN TRIPLICATE WELL A-05 PBU Request for Variance to Produce with Collapsed Tubing A-05 was scheduled to receive a hydraulic fracture treatment in early 1991. However, when pre-frac preparatory work began, a 25' WLM obstruction was found. Subsequent work has identified this obstruction as collapsed tubing. We propose to continue production from the well with the collapsed tubing until mid March, 1991, at which time a rig workover will be performed to replace the tubing as outlined below. If bleeding of the inner annulus pressure precipitates annular flow at the surface, the well will be shut in immediately and prepared for the rig workover. , . , . Rig Workover Procedure Pull existing 4-1/2" plastic coated tubing. Mill out the 9-5/8" packer at 9193' MD. Run new 5-1/2" tubing and tailpipe. Install new packer 50' above the liner top at 9222' MD. Install gas lift mandrels. CLL/cll 2/12/91 RECEIVED FEB 1 5 1991 Alaska 0{1 & Gas Cons. C0m~ss't0u Anchorage BP EXPLORATION TO: DiStribution BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Date: 09/26/89 Transmittal: 80404 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. A-05 Prod-F 09/16/89 #1 10700-11119 Sch C-30 Collar 09/23/89 91 9240-9643 Atlas 5" F-09 Perf 09/16/89 91 9700-10182 Sch F-22 Collar 09/22/89 81 9510-9834 Atlas R-09 prod-F '09/17/89 #1 9000-9599 Sch 5" W-32 Perf 09/16/89 91 9913-9955 Sch Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS RESERVOIR ~E OF ALASK~ ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 September 18, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-5 Gent lemen: Enclosed, in duplicate, is Form 10-404, Operations, for the above-named well. subsequent report of stimulating the well. Yours very truly, Manager Production Engineering JAM: JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File (43-34-11-13) PBU Report of Sundry Well This contains our STATE OF ALASKA ~. ~ *..$KA OIL AND GAS CONSERVATION COMML .,3N ., REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well . Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1896' SNL, 923' WEL, Sec. 35, T11N, R13E, UPM At top of productive interval 2180' NSL, 492' WEL, Sec. 34, T11N, R13E, UPM At effective depth 2268' NSL, 599' WEL, Sec. 34, T11N, R13E, UPM At total depth 2316' NSL, 645' WEL, Sec. 34, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical 11370feet BKB 9348feet 5. Type of Well: Development Exploratory Stratigraphic Service Plugs (measured) 6. Datum elevation (DF or KB) KBE ,, 65.89 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-05 (43-34-11-13) PBU 9. Permit number/approval number 72-08 / 9-7O8 10. APl number 50- 029-20116 11. Field/Pool Prudhoe Oil Pool Effective depth: measured true vertical 11181 feet BKB 9171feet Junk (measured) fill at 11181'MD (04/88) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length .. 90 2258 9794 measured true vertical Size Cemented Measured depth Tubing (size, grade, and measured depth) 30 300 sx 110 20x18 8700 sx 2278 13 3/8 1625 sx 9814 x 9 5/8 7 485 sx 9274-11360 10806'- 10826' (Sag R.) 10914'- 10924', 10932'- 10942', 10952'- 10964', 10974'- 10994 (Ivishak) (subsea) 8757'-8775'(Sag R.) 8857'- 8931' (four Ivishak intervals) 4 1/2" L-80 to 9193' with 4 1/2" tailpipe to 9324' True vertical depth BKB 110 2278 7966 7530-9339 Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 9193'; 4 1/2" SSSV at 2168' 13. Stimulation or cement squeeze summary see attachment 14. Intervals treated (measured) Treatment description including volumes used and final pressure .... ~,~'~;~ 0ii & (las C0ris.~ Comr~lis$io~. .~,rlchnr~nn Reoresentative Daily Average Produ~ion or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1010 745 278 934 283 Subsequent to operation 980 689 371 1140 295 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended Service 1'~. I hereby '..~ify that the foregoing is true and correct to the best of my knowledge. Signed /~~Z¢-~~~ ~ Title ManagerProduction Engineering ~//'/~/~ Date Form 10-404 Rev 06/15/88 ~' ~' / SUBMIT IN DUPLICATE WELL A-5 (43-34-11.13~ PBU SAG RIVER HYDRAULIC FRACTURE OPERATIONS A hydraulic fracture of the Sag River formation (perforated interval 10806' - 10826' MD BKB) was performed 8/13/89 as follows. . Isolated the Ivishak with an inflatable bridge plug set at 10887' MD. Rigged up fracturing equipment and pressure tested. Fractured the well as follows: Stage Volume Propp ant Rate (Mgals) PPG TYPE LB~ BPM Prepad 1.0 Establish injection 20 15% HC1 2.0 20 Prepad 10.0 20 Shut down to record ISIP then proceed with treatment. Pad w/OSR 2.0 0 .................. Pad"'W/OSR ..... 5.0 ..... 0.1- ' ' 100 mesh Pad w/OSR 1.0 0 1 0.2 1.0 20/40 CL 2 0.2 3.0 20/40 CL 3 0.3 5.0 20/40 CL 4 0.4 7.0 20/40 CL 5 0.5 9.0 20/40 CL 6 0.5 11.0 20/40 CL 7 0.5 12.0 20/40 CL Flush 0.2 12.0 20/40 CL Flush 8.2 0 Total 0 20 500 20 0 20 200 20 600 20 1500 20 2800 20 4500 20 5500 20 6000 20 2400 20 0 20 23,500 3. Left well shut-in overnight. . Cleaned out any fill left on top of the bridge plug, then retrieved with coiled tubing. Put the well back on production slowly and tested. jam 8/4/89 BP EXPLORATION BP Exploration (Alaska) Inc. '/~(--"'~) 900 East Benson Boulevard ~,~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 August 11, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-5 (43-34-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, Manager Production Engineering JAM: JAM Enclosures (9) cc: L. Burke (MB!2-1) Well File : ~ STATE OF ALASKA ~ A~.,-~SKA OIL AND GAS CONSERVATION COMMI~ .ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon~ Suspend Alter casing Repair well Change approved program ~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1896' SNL, 923'WEL, Sec. 35, T11N, R13E, UPM At top of productive interval 2180' NSL, 492' WEL, Sec. 34, T11N, R13E, UPM At effective depth 2268' NSL, 599' WEL, Sec. 34, T11N, R13E, UPM At total depth 2316' NSL, 645' WEL, Sec. 34, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Operation Shutdown ~ Plugging Pull tubing ~ Vadance 5. Type of Well: Development X Exploratory ~ Stratigraphio Service 11370 feet BKB 9348 feet 11181 feet BKB 9171 feet Re-enter suspended well Time extension Stimulate X Perforate Other 6. Datum elevation (DF or KB) KBE , 65.89 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A.05 (43-34-11-13) PBU 9. Permit number 72-08 10. APl number 50- 029-20116 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Junk (measured) fill at 11181' MD (04/88) Casing Length Size Cemented Measured depth True vertical depth structural .............. ,. · ..... BKB Conductor 90 30 300 sx 110 110 Surface 2258 20x18 8700 s x 2278 2278 Intermediate 9794 13 3/8 1625 sx 9814 7966 Production .. x 9 5/8 Liner 2086 7 485 sx 9274-11360 7530-9339 Perforation depth: measured 10806'-10826' (Sag R.) true vertical (subsea) 8757'.8775'(Sag R.) 8857'. 8931' (four Ivishak intervals) Tubing (size, grade, and measured depth) 4 1/2"L-80 to 9193' with 4 1/2" tailpipe to 9324' Packers and SSSV (type and measured depth) g 5/8" BOTpacker at 9193'; 4 1/2" SSSV at 2168' 13. Attachments Description summary of proposal 14. Estimated date for commencing operation August 1989 16. If proposal was verbally approved Name of approver Chatterton 8/4/89 Detailed operations program Alaska 0il & L~as ^r~chcrage BOP sketch Date approved I15. Status of well classification as: Oil X Gas Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~ ~//~~ Title Manac~lerProductionEr~lineerin~ Date ~,10.~ / / (/ ~ FOR COMMISSION USE ONLY Condjti6ns of approval: Notify Commission so representative may witness I Approval No. Plug integrity BOP Test Location clearance ___ _., c'.~,;' Mechanical Integrity Test SUbsequent form required 10- Yn*l /XP~°.ve.~u,.~'c~ "~. Approved by order of the Commission David W. Johnston ~Date ~"/~,' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE WELL ~.S (4~}-34-11-13~ PBU SAG RIVER HYDRAULIC FRACTURE PROPOSAL A hydraulic fracture of the Sag River formation (perforated interval 10806' - 10826' MD BKB) is proposed as follows. . Isolate the Ivishak with an inflatable bridge plug set 10-20' above the Ivishak perfs.. 2. Rig up fracturing equipment and pressure test. Fracture the well as follows: Volume Proppant Rate Stage (Mgals) PPG TYPE LBS BPM Prepad 1.0-5.0 Establish injection 20 15% HC1 2.0 20 Pr,pad 9.0 20 Shut down to record ISIP then proceed with treatment. Pad w/OSR 2.0 0 0 20 Pad w/OSR 5.0 0:1 100 mesh 500 20 Pad w/OSR 1.0 0 0 20 1 0.2 1.0 20/40 CL 200 20 2 0.2 3.0 20/40 CL 600 20 3 0.3 5.0 20/40 CL 1500 20 4 0.4 7.0 20/40 CL 2800 20 5 0.5 9.0 20/40 CL 4500 20 6 0.5 11.0 20/40 CL 5500 20 7 0.5 12.0 20/40 CL 6000 20 Flush 0.2 12.0 20/40 CL 2400 20 Flush 8.2 0 0 20 Total 23,500 3. Leave well shut-in overnight. . Clean out any fill left on top of the bridge plug, then retrieve with coiled tubing. 5. Put the well back on production slowly and test as soon as production stabilizes. 6. Run a spinner/temperature survey to evaluate Sag River production. jam 8/4/89 Gas gnch. ora.qe Coflcd Tubfng' ]Blow-Out-Prcventkrs · Coiled Tubing P a c k-O f? · BIMd Rams .... ~ ' ' Cut,er Rams ~2" Chk:ksan (KI[I Line) ('---~, . .I ~ ~ 'l ~ ~ '~ Pipe Rams .Pump-In Sub (ClrcuL~ te/R e turns W ell Head Swab Valve Standard Alaska ~ Production Company~ 900 East Benson Boolev~.,~ P.O. Box 196612 Anchorage, A)aska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION November 14, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-5'(43-34-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, J. A. Bragg Manager Production Engineering JAB:JAM Enclosures (4) L. Burke (MB12-1) Well Records (LR2-1) w/10 A-5 Well File NOV Anchora~a A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate X Plugging Alter ca~ing Repair well 5. Type of Well: Development X Exploratory Stratigraphic Service 1. Operations performed: Operation shutdown Pull tubing 2. Name of OPerator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1896'SNL, 923' WEL, Sec. 35, T11N, R13E, UPM At top of productive interval 2180' NSL, 492' WEL, Sec. 34, T11N, R13E, UPM At effective depth 2268' NSL, 599' WEL, Sec. 34, TllN, R13E, UPM At total depth 2316' NSL, 645' WEL, Sec. 34, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11370feet BKB 9348feet 11181 feet BKB 9171feet Size Plugs (measured) Junk (measured) 30 20x18 13 3/8 x 9 5/8 7 Casing Length Structural -- Conductor 90 Surface 2258 Intermediate 9794 Production -- Liner 2086 Perforation depth: measured Perforate Other 6, Datum elevation (DF or KB) KBE = 65.89 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-05 (43-34-11-13) PBU 9. Permit number/approval number 72-08 / 8-673 10. APl number 50- 029-20116 11. Field/Pool Prudhoe Oil Pool fill at 11181' MD (04/88) Cemented Measured depth True verticalde~h BKB 300sx 110 110 8700sx 2278 2278 1625sx 9814 7966 485sx 9274-11360 10806.-10826'(SagR.) 10914.-10924~ 10932~10942~ 10952~10964~ 10974.-10994 ~vishak) 7530-9339 true vertical (subsea) 8757'-8775' (Sag R.) 8857'- 8931' (four Ivishak intervals) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 9193' with 4 1/2" tallpipe to 9324' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 9193'; 4 1/2" SSSV at 2168' 13. Stimulation or cement squeeze summary see attachment 14. Intervals treated (measured) NOV 1 Treatment description including volumes used and final pressure AI~o~,~,°"~ 0;1 & ~.~,,~o"~ Cch::. Commission Representative Daily Average Production or Inie~ion D~a A,,~h~, OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X. 620 364 168 873 256 990 769 248 944 270 16. Status of well classification as: Oil X Gas . Suspended Service 17. I hereby ce~fy tha_t the foj:~oin~l is true and correct to the best of my knowledge. Signed "~~~' ~;~q Tltle Manager Production Engineering Form 10-404 Rev 06/15/88 /' SUBMIT IN DU'P~f'CATE WELL A-5 (43-34-11-13~ PBU STIMULATION OPERATIONS A 15% HCI perforation wash followed by a contingent scale inhibition treatment was performed on the following perforated intervals in Well A-5. 10914' - 10924' MD BKB 10932' - 10942' MD BKB 10952' - 10964' MD BKB 10974' - 10994' MD BKB An inflatable packer was set at 10865' to isolate the intervals to be treated from the upper Sag R. interval. The acid wash was pumped 9/25/88 via coiled tubing as follows: 9 bbls. diesel preflush 12 bbls. 15% HC1 9 bbls. OSR diverter 24 bbls. 15% HC1 9 bbls. OSR diverter 24 bbls. 15% HCI 10.5 bbls. OSR diverter 33 bbls. 15% HC1 11 bbls. diesel overflush w/mutual solvent Following the HC1 wash the inflatable packer was retrieved, then the well put back on production and tested. The scale inhibitiOn treatment was performed 10/13/88 utilizing an inflatable packer as above: 9 bbls. diesel preflush 12 bbls. EDTA solution 64 bbls. scale inhibitor solution 259 bbls. seawater The treatment fluids were displaced to the perforations with 176 bbls. dead crude and the inflatable packer retrieved. The well was left shut in for 24 hours, then returned to production and tested. jm 11/3/88 NOV 1 6 ~,lasl:a 0il & ~as Con:::. Commission Anchor~a Standord Alaska Production Company 900 Em.I 8¢ns. on PO~ Bo, 19661~ HOUSTON ARCO CH EVRON · N E..XXO~ TE>LaCO TO: NO B I L REFERENCE: PItILLIPS SrArZ' O~' A~SK~ GEOSC IENCES RES ERVOIR ARCHIVES SAPC CASED HOLE FINAL LOGS I NDEXEI) STANDARD ,',I_" "'"'" ..... ' ,,.,,.-.,? .,. ~,~-? ;['.)1 FI(iN Date: 10-21-88 T#: 79453 The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: A-05 A-20 N-09 Prod-F 10-10-88 10700-11170 ~1 Camco 5" Prod-F 10-05-88 11900-12300 #1 Camco 5" Temp 10'06-88 9648-9656 #1 Camco 5" Rece i ved Date I:ou-ded ,. Clevelo,',d. O~,o ,n 1870 Shirley R. McCurry INFORMATION CONTROL Wel I Records LR2-1 Standard Alaska Production Company 900 Fast Benson Bouleva,,. P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION September 1, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-5 (43-34-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB:JAM Enclosures (9) L. Burke (MB12-1) A-5 Well File ~4anager Production Engineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon [] Suspend [] Operation Shutdown [] Time extension [] Change approved program [] Plugging [] Stimulate [] 2. Name of Operator Standard Alaska Production Company Address P. O. _Rex 196612, Anchorage, Alaska 99519-6612 Location of well at surface 1896' SNL, 923'WEL, Sec. 35, T11N, R13E, UPM At top of productive interval 2180' NSL, 492' WEL, Sec. 34, T11N, R13E, UPM At effective depth 2289' NSL, 618' WEL, Sec. 34, T11N, R13E, UPM At total depth 2316' NSL, 645' WEL, Sec. 34, T11N, R13E, UPM 1. Present well condition summary Total depth: measured 11370 feet Re-enter suspended well [] Alter casing [] Pull tubing [] Amend order [] Perforate [] Other [] 5. Datum elevation (DF or KB) KBE = 65.89 AMSL feet S. Unit or Property name Prudhoe Bay Unit 7. Well number A-05 (43.34-11-13~ PBU 8. Permit number 72-08 9. APl number 5 0 - 029-2O 116 10. Pool Prudhoe Oil Pool Plugs (measured) true vertical BKB 9348 feet Effective depth: measured 1259 feet true vertical BKB 9245 feet Casing Length Size Structural -- Conductor 90 30 Surface 2258 20x18 5/8 Inte rmed i ate 9794 13 3/8 Junk (measured) , Cemented Measured depth 110 2278 9814 300 sx 8700 sx 1625 sx True Vertical depth BKB 110 2278 7966 P rod uction -- x 9 5/8 L i n e r 2086 7 485 sx 9274-11360 Perforation depth: measured 10806'-10826'(Sag R.) 10914'-10924', 10932'-10942', 10952'-10964', 10974'-10994 (Ivishak) true vertical (subsea) 8757'-8775'(Sag R.) 8857'- 8931' (four lvishak intervals) Tubing (size, grade and measured depth) 4 1/2"L-80 to 9193'with 4 1/2"tailpipe to 9324' 7530-9339 Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 9193'; 4 1/2" SSSV at 2168' 2. Attachments . Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation September 1988 4. If proposal was verbally approved Name of approver Date approved 5. I hereby cftC'fy_ that t~e foregoing, is true and correct to the best of my knowledge Signed ~' ~ ~;~ _.~/~ Title Manager Production Engineerin~l ~J"~: ~ / / Commission Use Only Conditions of approval Approved by Notify commission so representative may witness IApproval No. [] Plug integrity [] BOP Tes~p~~t~p~earance I Ret~u~ned~:) ORi61NAL SIGNED BY ~) ~-~ ~ J. ONNIE C. SMITH by order of Commissioner the commission ~orm 10-403 Rev 12-1-85 Date Submit in triplicate WELL A-5 (43-34-!!-13~ PBU STIMULATIO]~,,, OPERATIONS A 15% HCI pcrforation wash followcd by a COntingent scale inhibition treatment is proposed for thc following perforated intcrvals in Well A-5. 10914' - 10924' MD BKB 10932' - 10942' MD BKB 10952' - 10964' MD BKB 10974' - 10994' MD BKB An inflatable packer will be set between 10826' and 10914' to isolate the intervals to be treated from the upper Sag R. interval. The acid wash will be pumped via coiled tubing as follows: 500 gal. acid 1/3 of diverter stage 1000 gal. acid 1/3 of diverter stage 1000 gal. acid 1/3 of diverter stage 1500 gal. acid : 500 gal. diesel w/10% mutual, solvent Following the HC1 wash the inflatable packer will be retrieved, then the well put back on production and tested. Depending on the results of the HC1 wash, the following scale inhibition treatment will be performed utilizing an inflatable packer as above: 10 bbls. diesel preflush 12 bbls. EDTA solution 63-77 bbls. scale inhibitor solution 50 bbls. seawater The treatment fluids will be displaced to the perforations with seawater and the inflatable packer retrieved. The well will be left shut in for 24 hours, then returned to production and tested. jm 8/31/88 Coiled Tubing Blow-Out-Preventers Coiled Tubing Pack-Of~ ~1 ~..'~ j' ~ CutterRams ..... 2 Chicksan (Kill Line) I -~SlIps Pipe Rams Pump-In Sub ( C irc ula t e/R e turn s ) Well Head -~-L...-' Swab Valve /. DALLAS INDEXED ARCO CHEVRON EXXON TEXACO STANDARD ALASKA PRODUCTION Date: 06/07/88 TO: MOBIL TI: 78922 PHILLIPS STATE OF ALASKA GEOSC IENCES RESERVOIR REFERENCE: ARCHIVES -. *Drilling SAPC CASED HOLE FINAL LOGS The following material ls belng submitted herewlth. Please acknowledge receipt by signlng a copy of this letter and returnlng it to this office: ' A-5 Production'Temp 05/29/88 D-27 CH/CL 05/27/88 H-5 Spectroscopy(NGRS) 06/01/88 ', N-16 Spectroscopy(GST) 05/30/88 N-16 CNT-GR 05/25/88 U-2 Spinner/Temp 05/29/88 *Z-6 CET 05/31/88 *Z-6 CBT 05/31/88 Z-6 Pert/Record 05/31/88 #2 10700-11150 Sch 5" #1 8900-9685 " " #1 11381-11550 " " #1 10035-10411 " " #1 9600-10381 .... #1 9750-10250 " " #1 9245-10396 " " #1 9245-10374 .... #1 9395-10378 " " Rece I ved Dote Alaska Oil & Gas Cons. Commission Anchoragu A un;I ot ehe o¢;g;~l $1o~do,d C~I Co'~pony founded ~n Cle-elo~. ~. ~ 1870. ~~Jennifer Dietz I NFORMAT I Off CONTROL Wel I Records LR2-1 DAJ..I..AS INDEXED ARCO CHEVRON EXXON TEXACO STANDARD ALASKA PRODUCTION Date: 05/12/88 TO: MOBIL TI: 78830 PHILLIPS STATE OF ALASKA GEOSCIENCES ARCHIVES REFERENCE: sAPc CASED HOLE FINAL LOGS .. The following materlai Is being submll~ed herewith. Please acknowledge receipt by signing a copy of this letter and returning it to thls offlce: A-t4 A-15 A-21 A-22 A-22 M-4 R-09 R-20 X-04 PFC 03/31/88 91 7700-9167 Atlas 5" Collar 04/01/88 #1 9000-11000 Atlas 5" Collar 04/01/88 91 8600-9851 Atlas 5" Collar 04/19/88 91 10450-11000 Atlas 5" PFC 04/13/88 91 11150-12142 Atlas 5" Collar 04/13/88 #1 11050-11800 Atlas 5" Collar 04/15/88 #1 10700-11800 Atlas 5" Collar 04/04/88 #1 11100-11300 Atlas 5" Collar 04/14/88 91 8950-9400 Atlas 5" Collar 04/08/88 #1 11156-11441 Atlas 5" Collar 04/02/88 #1 9350-9620 Atlas 5" ldge we~ I Records LR2-1 Standard Alaska ~ Production Company 900 Eost Benson Boulevoro P.O. Box 196612 Anchoroge, Alasko 99519-6612 1907) 561-5111 STANDARD ALASKA PRODUCTION April 12, 1988 Alaska Oil & Gas Conservation Commission ~'~ 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton ~i~:~A~5~ ( 43-34-11 - 13) PB U Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. BJP:JAM~ Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 A-5 Well File Yours very truly, B J ~zcky, S~rvzsor Waterflood & Miscible Flood Al~S~ <;~! & G~S go~s. gommiss~oi~ A urn,! of the o~ ~,~oi 5londc]rd Od Compor~y ~ STATE OF ALASKA ~-'- ALASKA OIL AND GAS CONSERVATION C~iVlMISSlON REPORT OF SUNDRY WELL OPERATIONS Operation performed: Operation shutdown [] Stimulate [] Plugging [] Perforate E~ Pull tubing [] Alter casing [] Other [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 1896'SNL, 923' WEL, Sec. 35, T11N, R13E, UPM At top of productive interval 2180'NSL, 492' WEL, Sec. 34, T11N, R13E, UPM At effective depth 2289'NSL, 618' WEL, Sec. 34, T11N, R13E, UPM At total depth 2316'NSL, 645'WEL, Sec. 34, T11N, R13E, UPM 5. Datum elevation (DF or KB) KBE = 65.89 AMSL feet S. Unit or Property name Prudhoe Bay Unit 7. Well number A-05 (43-34-11-13) PBU $. Approval number 8-146 9. APl number 5 0 - 029-20116 10. Pool Prudhoe Oil Pool · Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length .. 2258 9794 11370 feet BKB 9348 feet 1259 feet BKB 9245 feet Size Plugs (measured) Junk (measured) Cemented Measured depth measured 30 300 sx 110 20x18 8700 sx 2278 13 3/8 1625 sx 9814 x 9 5/8 7 485 sx 9274-11360 10806'-10826' (Sag R.) 10914'-10924', 10932'-10942', 10952'-10964', 10974'-10994 (Ivishak) true vertical (subsea) 8757,-8775' (Sag R.) 8857'- 8931' (four IVishak intervals) Tubing (size, grade and measured depth) 4 1/2"L-80 to 9193' with 4 1/2" tailpipe to 9324' True Vertical depth BKB 110 2278 7966 7530.9339 Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 9193~ 4 1/2" SSSV at 2168' E E C Ei V E D 2. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure APR 1 /., lq~R Aiasl~ 0[1 & Gas Cons. Commissl~ ~ch0rage . Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 560 359 240 868 690 439 150 830 Tubing Pressure 231 234 4. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys that the foregoing is true and correct to the best of my knowledge 5. I hereby certify Signed Form 10-404 Rev.~[2 1-85 Title Supervisor Watedlood/Miscible Flood Subdiit in Duplicate Well A-5 (43-34-11-13) PBU Additional Perforating Operations The followlng Sag River interval was perforated Aprll 1, 1988 using Dresser Atlas 3 1/8" Jumbo~et II carrier guns at 4 spf: 1080§' - 10826' MD BKB (8757' - 8775' TVDss) Depths are referenced to BHCS, 4/11/72. A lubrlcator was installed and tested to 3500 psi for all well work. The well was returned to production immediately following perforating operations. R£C£1v£D APR 15 8 Alasl~ Oil & Gas Cons. Commi, Anchorage ~!o~ 4/8/88 0800Z Standard Alaska 7~,,: Production Company 900 East Benson Boulev~,,~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 2, 1988 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well A-5 (43-34-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. BJP:JAM Enclosures (9) cc: J. L. Haas (MB12-1) A-5 Well File Yours very truly, Anchorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA Oi'L AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon I'1 Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter ceJing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate I~ Other [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 1896' SNL, 923' WEL, Sec. 35, T11N, R13E, UPM At top of productive interval 2180' NSL, 492' WEL, Sec. 34, T11N, R13E, UPM At effective depth 2289'NSL, 618'WEL, Sec. 34, T11N, R13E, UPM At total depth 2316' NSL, 645'WEL, Sec. 34, T11N, R13E, UPM 5. Datum elevation (DF or KB) KBE , 65.89 AMSL feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number A-5 (43-34-11-13) PBU 8. Permit number 72-08 9. APl number 5 0 - 029-20116 10. Pool Prudhoe Oil Pool 1. Present well condition summary Total depth: measured true vertical Effective depth: 11370 feet BKB 9348 feet 1259 feet BKB 9245 feet measured true vertical Plugs (measured) Junk (measured) Casing Length Size Cemented Measured depth Structural -- Conductor 90 30 300 sx 110 Surface 2258 20x18 5/8 8700 sx 2278 I ntermed i ate 9794 13 3/8 1625 sx 9814 P rod uction -- x 9 5/8 Liner 2086 7 465 sx 9274-11360 Perforation depth: measured 10914'-10924', 10932'-10942', 10952'-10964', 10974'-10994 true vertical (subsea) 8857'- 8931' (four intervals) Tubing (size, grade and measured depth) 4 1/2"L-80 to 9193' with 4 1/2" tailpipe to 9324' True Vertical depth BKB 110 2278 7966 7530-9339 RECEIVED Packers and SSSV (type and measured depth) 9 5/8" BOTpackerat 9193'; 4 1/2" SSSVat 216~aska Oil & Gas Cons. C0mmlssl Anchorage 2. Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation February 1988 4. If proposal was verbally approved Name of approver _// Date approved 15. I hereby ce~fy tha/t~e~,~'/~, oi~ is true and correct to the best of my knowledge Signod~~~_~//'~-~ Title SupervisorWaterflood/Mis¢ibleFIood Date "-"/'~,/~_ Commission Use Only Conditions of approval Notify commission so representative may witness IApproval No.,. ~j ///_,/ [] Plug integrity [] BOP Test [] Location Approved Copy Returned ORIGINAL SIGNED B'~ ~- ~- ~-~/~ . by order of Approved by LONNIE C. SMIT~ ~3ommissioner the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate Well A-5 (43-34-11-15) ,PBU · _.ADDITIONAL PERFORATING PROPOSAL We propose to perforate the following Sag River interval during February 1988 at 4 spf: 10806' - 10826' MD BKB (8757' - 8775' TVDss) Depths are referenced to BHCS, 04/11/72 A lubricator will be installed and tested to 3500 psi for all well work. Following perforating operations, the well will be returned to production and tested. 0833Z 02/08/88 FLOW'TUBES & PACKOFF BOWEN PACKOFF HAND PUMP GREASE SEAL FLOWTUBE FL GREASE LINE FLOWLINE VALVE RISER GREASE '~MANIFOLD GREASE PUMP · ,,.-.GREASE RESERVOIR ! RECEIYED BOP TO: DAI]_,AS ARCO CttEVRON EXXON TEXACO MOBIL PHILLIPS "-~_~ATE OF ALASKA : STANDARD AL ASKA P~O{ )~J( 1 I(-)N Date: 01/20/88 TI: 78458 REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: A=51 Static Gradient 01/10/88 Camco X-5 .... 01/07/88 Camco Y-12 .... 01/09/88 Camco Alaska Oil ,~ Gas Cons. Pece I ved Date A ~,n,l ol the o~,(-t,n,~,t Sn".,(to,,I (~1 (o,,~p,~,,,~ Victoria AldrJdge I NFORMAllON CONIRO[ Wel I Records LR2-1 INDEXED TO: DALLAS A~CO CHEVRON EXXON TEY~CO MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES (Transmittal Only) STANDARD ALASKA PRODUCTION Date: 01/08/87 TI: 77647 Page 1 of 2!! REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by slgnlng a copy of ?his let-ret and returning it to *his office: ~A-1 Static Gradient 12/28/86 Camco -'~'A-5 " " 12/28/86 Camco ~-A-22 " " 12/25/86 " ~A-26 Static 12/22/86 GO ~A-29 Static " 12/26/86 Camco ~A-30 Static 12/23/86 GO ~A-32 " " 12/23/86 Camco ""A-35 " " 12/25/86 " ~-B-1 " " 12/27/86 " ~"~C-15 Static 01/02/87 GO -~'-C-32 " 01/02/87 GO ~D-9 " 12/30/86 " ~D-10 " 12/30/86 GO ~'~xG;30 " 11/24/86 Camco ~'~M-4 " " 12/11/86 Camco ~M-10 Static Survey 12/11/86 GO "'"M-16 Static Survey" 12/11/86 GO ~M-19 Static Gradient'" 12/12/86 Camco ~'M-21 Static Gradient 12/11/86 Camco ~N-7 " " 01/02/87 Camco ~N-9 " " 12/13/86 Camco ~N-15 " " 12/12/86 Camco "'-N-18 Static Survey 12/12/86 GO ~N-19 Static Su~rv~y. /z~ 12~12/86 GO - z-, . Received -' ~ -" - -~ ,'-; .... / /'~"~"- // Victoria Aldridge Date , [ ' ~ ~ J, _ ...... Well Records LR2-1 TO: DALLAS ARCO CHEVRON EXXON TEXACO INDEX£D STANDARD ALASKA PRODUCTION Date: 01/08/87 MOBIL -- TS: 77647 PHILLIPS STATE OF ALASKA Page 2 of 2!! REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following ma?e~lal Is being subml??ed herewi?h. Pleese acknowled9e receipt by signing a copy of ?his le~er end returning i? to this office: ~ R-I Static. Gradient 12/14/86 ~R-16 ,, ,, ~ R-19 ,, ,, 12/14/86 12/13/86 -~- R-23 " Survey 12/15/86 -~ S-i Static Gradient 12/17/86 ~S-2 ,, ,, 12/17/86 ~S-10 " S u'rve¥ I2/19/86 ~S-10. " Gradient 12/16/86 "' S-13~ Static Survey 12/14/86 ~"S-19 " Gradient 12/05/86 ~-S-20 " ,, ~X-2 ,, ,, 12/07/86 ~'X-5 ,, ,, 12/26/86 ¥-2 ,, ,, 12/20/86 ¥-8 Static 12/20/86 PLS-Pres. Survey Camco t! GO Ca~co Camco CO Camco GO Ca~co Camco Camco Camco Camco 11/04/86 Dres ~'1 , . . Victoria Aldridge I NFORHAT I ON CONTROL Well Records LR2-1 TO: DALLAS ARCO CHEVRON EXXON TEY~CO MOBIL PHILLIPS _ GEOSCIENCES INDEXED STANDARD ALASKA PRODUCTION Date: 06/09/86 Tt: 77104 Page 1 of 2!! REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The foiio~lng material Is being submll"ted herevlth. Please acknowledge receipt by signing a copy of thls lel-ter and reYurning It to Yhls office: A-1 Static Gradient 05/18/86 Camco A-5 " " 03/22/86 " A-31 " "& BHPD 04/08/86 Otis A-34A " "& " 04/09/86 Otis A-35 " "& " 05/17/86 GO A-35 Pres. BU Survey 05/15/86 GO B-1 Static Gradient 05/15/86 Otis B-2 " " 03/17/86 Camco B-23 " " 05/21-22/86 Camco D-6 " 03/14/86 GO D-19 " " 03/23/86 Camco D-19 BHPD & Survey 04/29/86 Otis D-23 Static Gradient 05/23/86 Camco E-1 " " 03/14/86 Camco F-4 BHP Survey 04/03/86 Otis F-10 Static Gradient 03/23/86 Camco F-24 BHP Survey 04/04/86 Otis H-26 Static Gradient 05/25/86 Camco H-27 " " 05/25/86 Camco K-8 Static Survey 03/26/86 GO M-5 BHP Survey 05/18/86 Otis M-17 Static' Gradient 05/06-07/86 Camco N-4A " " 03/20/86 Camco N-20 N-20 N-22 Race I ved BHP Survey 04/05/86 Otis Date ~ ....... "' ~ INF~TION C~ Wel I Records LR2-1 LR2-1 I. 06/09/86 T#77104 Page 2 of 2!! R-23 Flowing Gradient ~-~ ~ BHPD & PBU S-8 Flowing Gradient S-10 " " S-13 " " X-2 Static Gradient X-5 Flowing Gradient X-9 Static Gradient X-25 " " Y-2 BHP Survey Y-9 BHP Survey 05111186 05/15/86 03/13/86 05/17/86 03116186 05/26/86 03/26/86 05/19/86 05/14/86 04/07/86 05/15/86 GO Camco Camco Camco Camco Camco Camco Camco Camco Otis Otis Victoria Aldridge LR2-1 Standard Alaska Production Company 900 East Benson Bouleva~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 June: 3, 1986 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well A-5 (43-34-11-13) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the aboVe-named well. This contains our subsequent re~°rt of stimulating the well. Yours very truly, JAB:JAM Enclosures (4) cc: J. L. Haas, MB12-1 Well Records; LR2-1 A-5 Well File A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. . A~~. Bragg, Supervisor Production Operations STATE OF ALASKA ALASKA "/'--'~%N D GAS CONSERVATION COM M IS'~-''~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator STANDARD ALASKA PRODUCTION COMPANY 3. Address P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 1896' SNL, 923' WEL, Sec. 35, TllN, R13E, UPM At top of productive interval 22~5'. NSL, 524' WEL, Sec. 34, TllN, R13E, UPM At effective depth 2289' NSL, 618' WEL, Sec. 34, TllN, R13E, UPM At total depth 2316' NSL, 645' WEL, Sec. 34, TllN, R13E, UPM 5. Datum elevation (DF or KB) KBE = 65.89 6. Unit or Property name ~r%%dhQe Bay Unit 7. Well number A-5 (43-34-11-13) PBU 8. Approval number 64 9. APl number 50-- 029-20116 10. Pool Prudhoe Oil Pool Feet 11. Present well condition summary Total depth: measured true vertical 11370 feet Plugs (measured) 9348 feetBKB Effective depth: measured 11259 feet Junk (measured) true vertical 9245 feetBKB Casing Length Size Cemented Structural -- Conductor 44, 30" 300 sx Surface 2232' 18 ~ x 20" 8700 sx 3 5 ,, Intermediate 9768' 13 § x 9 ~ 1625 sx Production -- Liner 2086' 7" 485 sx Perforation depth: measured 10914' - 10994' (four intervals) true vertical (subsea) 8857' - 8931' Tubing (size, grade and measured depth) 4 1/2" L-80 to 9193' with 4 1/2" tailpipe to 9324' Packers and SSSV (type and measured depth) 9 5/8" BeT packer at 9193'; 4 1/2" Otis SSSV at 2168' Measured depth True Vertical depth BKB 90 ' 90 ' 2278' 2278' 9814' 7966' 9274 '-11360' 7530'-9339' RECEIVED JUN 0 5 1986 Alaska 0il & Gas Cons. Commission 12. Stimulation or cement squeeze summary Anchorage EDTA perforation wash followed by scale inhibitor treatment Intervals treated (measured) 10914' - 10994' Treatment description including volumes used and final pressure . 2000 gal. EDTA; 48 .bbl. scale inhibitor Final pressure = 1900 13. Representative Daily Average Production or I'.~jection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2070 1896 137 904 256 Subsequent to operation 1840 1424 143 884 239 14. Attachments Daily Report of Well Operations [] CopieS of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correCt to the best of my knowledge ~f~, ~'~' ~'"~'~ ' Form 10-404 (/ U Title Supervisor Production Operations Date (:::) · Z' ~, Submit in Duplicate Well A-5 (43-34-11-13) PBU STIMULATION OPERATIONS A 2000,gal. EDTA perforation wash of the following perforated intervals via cOiled tubing was performed on May 23, 1986. Coiled tubing unit BOP's were tested to 4000 psi. A 48-bbl. bullheaded scale inhibitor squeeze with a 261-bbl. seawater overflush was performed on May 27, 1986. The well was shut in for 24 hours, following the treatment. The SSSV was removed prior to the treatment and reset and tested in the ball valve.nipple at 2168' following the job. 10914' - 10924, MD BKB 10932' - 10942' MD BKB 10952' - 10964' MD BKB 10974' - 10994' MD BKB 5/28/86 RECEIVED JUNO 5 ^~aska Oil & Gas Cons. Commissior~ ~,nchorage · Standard Alaska ,.~..~ Production Company 900 East Benson Boulevard. P.O. Box 196612 Anchorage, Alaska 99,519-6612 (907) 564-5111 May 6, 1986 STANDARD ALASKA PRODUCTIONX/ '.. Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well A-5 (43-34-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB: JAM'~ Enclosures (9) cc: J. L. Haas, MB12-1 Well Records, LR2-1 A-5 Well File //~. A. Bragg, Supervisor Production Operations A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. ~ STATE OF ALASKA ALASKi '~IL AND GAS CONSERVATION COMM~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ,~ Suspend ~,' Operation Shutdown ~ Re-enter suspended well 2~ Alter casing ~ Time extension ~ Change approved program ~ Plugging [] Stimulate ~ Pull tubing Z Amend order ~ Perforate r-: Other 2. Name of Operator STANDARD ALASKA pRODucTION COMP.AN-~ 3. Address P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 1896' SNL, 923' WEL, Sec. 35, TllN, ~13E, UPM At top of productive interval 2205' .NSL, 524' WEL, Sec. 34, TllN, R13E, UPM At effective depth 2289' NSL, 618' WEL, Sec. 34, TllN, R13E, UPM At total depth 2316' NSL, 645' WEL, Sec. 34, TllN, R13E, UPM 5. Datum elevation (DF or KB) KBE = 65.89 6. Unit or Property name Prudhoe Bay Unit 7. Well number A-5 (43-34-11-13) PBU feet 8. Permit number 72-08 9. APl number 50--029-20116 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11370 feet 9348 feet BKB 11259 feet 9245 feet BKB Plugs (measured) Junk (measured) Casing Structural Conductor. Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measureddepth ~ueVerticaldepth -- BKB 44' 30" 300 SX 90' 90' 2232' 18 5/8 x 20" 8700 SX 2278' 2278' 9768' 13 ~8x9~8" 1625 SX 9814' 7966' 2086' 7" 485 SX 9274'-11360' 7530'-9339' measured 10914' - 10994' (four intervals) true vertical (SUbsea) 8857' - 8931' Tubing (size, grade and measured depth) 4 1/2" L-80 to 9193' with 4 1/2" tailpipe to 9324' Packers and SSSV (type and measured depth) 9 5/8" BOT packer- at 9193'; 4 1/2" Otis SSSV at 2168' 12.Attachments Description summary of proposal [] Detailed operations program BOP sketch 13. Estimated date for commencing operation May/June 1986 14. If proposal was verbally approved Name of approver .... ?..'.., /0 . -71u ~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'4~ ~/~'"'t~ .~'.'.~ Title Supervisor Production Operations Date y A. Bragg ~ U Commission Use Only Conditgons of approval Notify commission so representative may witness I Approval No. /. [] Plug integrity [] BOP Test [] Location clearanceI ~o ~ Approved by Ar~roved C~ Returned Commissioner by order of the commission Date ~,""-~ Form 10-403 Rev 12-1-85 Submit in triplicate Well A-5 (43-34-11-13) PBU STIMULATION PROPOSAL A 2000-gal. EDTA Perforation wash of the following perforated intervals Via cOiled tubing followed b~ a 47.5~bbl. bullheaded scale inhibitor squeeze with a 260-bbl. seawater overflush is proposed. 10914' - 10924' MD BKB 10932' - 10942' MD BKB 10952' - 10964' MD BKB 10974' - 10994' MD BKB The well will be shut in for 24 hours following the treatment. The SSSV will be removed prior to the treatment and reset and tested in the ball valve nipple at 2168' after the job. SOHIO ALASKA PETROLEUM PAGE COMPANY _OF_.------ ENGINEERING PETROLEUM SUBJECT: ,2~'~-~"~':"/~ ~ -~,,LJ 7'-/~o ~-- PREPARED BY: ~' APPROVED BY: '~ OPERATIONS MANUAL REVISION NO. DATE ~'-/~ 2~-q:7~' INDEXED SOHIO ALASKA PETROLEUM COMPANY TO: SFO/UNIT/STATE: (-Marathon) SFO ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE BPAE (Transmittal Only) 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE 19071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: T#: 09/16/85 76433 REFERENCE: SOHIO FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signir~g a copy of this letter and returning it to this office:-- ~A-11 - _-16- -17/ 27~' "--F-9-- ~H-9 ~' ~-6~ ~-9~ / ~U-5~ -8/ _9~ Static Static Static Static Static Pr es.. Drawd own Pres. Drawdown Static BHPD & PBU Static Static PBU & -BHPD PBU PBU & BHPD Flowing Gradient Step Rate Test Data Frac Static Static Static Static Static Flowing Gradient 08/21/85 Camco 09/02/85 Camco 07/09/85 Camco 09/05/85 Camco 08/22/85 Camco 08/07/85 Camco 07/12/85 Camco 09/09/85 Camco 09/01/85 Camco 08/26/85 Camco 08/28/85 Camco 08/12/85 GO 07/11/85 Camco 08/15/85 ~O 08/20/85 Camco 05/29/85 Sch 05/29/85 Sch 09/05/85 Camco 09/05/85 Camco 08/17/85 GO 08/30/85 Camco 09/04/85 Camco 08/27/85 Camco Static 09/07/85 Camco Flowing Gradient &'~HPD 08/26/85 Camco RECEIVED DATE Victoria Aldridge LR2-i Technical Doc%=nentation Records Management INDEXED To~SFO/UNIT/STATE: SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TEXACO (-Marathon) MOBIL PHILLIPS STATE BPAE (Transmittal Only) 3111 "C"STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: T#: 7-30-85 76344 REFERENCE: SOHIO FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-5 "~ M-17/ R-9 J R-22 /' R-24 ,' U-3o Y-3 7-17-85 7-12-85 7-13-85 7-10-85 7-18-85 7/4-5/85 7/1-3/8'5 7-22-85 Flowing Gradient Camco Static Gradient Camco Static Gradient Camco Flowing Gradient Camco Static Gradient Camco Flowing Gradient/BHPD Camco Flowing Gradient/BHPD Camco Static Gradient Camco RECEIVED PATE SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ~J,/. ANCHORAGE, ALASKA 99502-0612 April , 1985 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: WELL A-5 (43-34-11-13) PBU Enclosed in duplicate is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This subsequent report completes the workover of this well. Very truly yours, District Drilling Engineer RHR:IBG:ckg 32085/0044G Enclosure cc: Well File 17 I EC£1v£D 0 8 1985 Alaska Oil & G,~s Cons Commission Anchorage' STATE Of ALASKA ~ ALASKA ~,~L AND GAS CONSERVATION CC,,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Sohio Alaska Petroleum Company 3. Address P.O. Box 6-612, Anchorage, Alaska 4. Location of Well At surface: ~ 1896' SNL, 923' WEL, 5. Elevation in feet (indicate KB, DF, etc.) _KBE = 65.89" AHRTj 12. 99502 Sec. 35, TllN, R13E, UPM 7. Permit No. 72-08 8. APl Number 50- 029-201_1§ 9. Unit or Lease Name Prudhoe B~v Iln~ 10. Well Number A-5 (43-34-1]-1 11. Field and Pool Prudhoe Bay I 6. Lease Designation and Serial No. Prudhoe 0il Pool A~T. ?R787 Check Appropriate BoxTolndicate NatureofNotice, Report, orOtherData NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing r-] Stimulate [] Abandon [] Stimulation [] Abandonment I~ Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing ~ (Note: Report multiple completions on Form 10.407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following work was performed during the workover on Well A-5 1. Move in rig. Pulled BPV. Installed 2-way check. ND tree. NU and tested BOPE to 5000 psig. 2. Pulled and layed down 7" tubing. Recovered seal assembly. 3. Drilled out bridge plug and cleaned out liner to 11,259'. 4. RIH with RTTS. Tested 9 5/8" casing and liner lap to 2500 psig. 5. Ran 4½" tubing completion to 9324'. ND BOPE. NU and tested tree to 5000 psig. 6. set Packer:.at",9t.93':ft.:D±spl~c~d annUlUS.to 9~6'.ppg'.NaC1 and'.tuhing tO.diesel.;,' InStalled SSS¥. Installed BPV. Moved rig off. This work was completed on March 22, 1985. RECEIVED APR 0 8 1985 Alaska 0il & Gas Cons~ Cc,~;,nJssi0n Anchorage Signed ~ ~ ~ -~' ~ Title District Drilling E.gineer The space below for Commission use R H Reile~'- Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date t Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6.612 ANCHORAGE, ALASKA 99502-061 Jan~__~_~y 16, 1985 Alaska Oil & Gas Conservation ~ssion 3001 Porcupine Drive Anchorage, Alaska 99501' Attention: Mr. C. V. Chatterton Well A-5 (43-34-11-13) PBU Enclosed' in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This gives notice of intention to change tubing. Enclosure cc: Well File %17 Very truly yours, RECEIVED JAN 1 7 1985 ~,laska 0il & Gas Cons. Commission Anchorage ,.~, STATE OF ALASKA ALASKA C !AND GAS CONSERVATION CC"'"~ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator Sohio Alaska Petroleum Company COMPLETEI~,~L [] 3. Address P.O. ]~× 6612, Anchorage, Alaska 4. Location of Well At Surface: 1896' SNL, 923' ~,~L, sec. 35, T1LN, R13E, UPM OTHER r~ 7. Permit No. 72-08 8. APl Number 50-029-20116 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number A-5 (43-34-11-13) PBU 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 65.89' A~L ADL 2~2R7 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF 'INTENTION TO' SUBSEQUENT REPORT OF: 11. Field and Pool (Submit in Triplicate) Perforate [] Alter Casing r-] . Perforations stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This workover is scheduled for January 1984. It is proposed that a 4 1/2" tubing completion ,with gas lift mandrels be run in place of the present 7-inch tbg. !. Punch 7" tubing 3 its. above PBR. 2. Change 7" tbg. and 7" x 9 5/8" annulus over to 8.9 ppg NaC1. Install BPV. 3. ~ve in rig. N.D. tree. N.U. and test BOPE to 5000 psig. 4. Pull 7" tubing. 5. P~H with 6" bit, 7" csg. scraper, and 9 5/8" csg. scraper. Clean out to PBTD. 6. RIH with 9 5/8" R~TS. Pressure test 9 5/8" csg. to 2500 psig. POt{. 7. RIH w/4 1/2" tubing completion consisting of 9 5/8" production packer, 4 1/2" sliding sleeve, and 4 1/2" tubing to surface with 5 gas lift mandrels. 8. ~hange 4 1/2" x 9 5/8" annulus over to clean 9.6 ppg NaC1 and ~e 4 1/2" tbg. to diesel through the sliding sleeve. Install BPV. 9. Install and test tree to 5000 psig. Secure well. t4ove rig off. POH. Signed (,~ ~'"-~'/'"'~ L~~Title District Drilling Engineer cT~c~t~::sboelfO~VpfpO:ovCa~T~SnS;~n use R.H. t::~'1 Approved by COMMISSION ER Form 10-403 Rev. 7-1 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate INDEXED SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON ToSFO/UNIT/STATE: GETTY (-Marathon) REFERENCE: CENTRAL MOBIL PHILLIPS ~TATE BPAE (Transmittal Only) FILES (CC#'s - Transmittal Only) 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 10-10-84 CC#: 75799 __~__0 FINAL DATA - PRESSURE SURVEY DATA v ~he ~'~ate~ial ~-s/ being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-5 .....~' 10-4-84 Static Gradient Camco F-1''/' 9-2-84 PBU & DATA SHEET Sch Y-8-~ 10-8-84 Static Gradient Camco E-1~' '10-6-84 Static Gradient Camco Y-15 8-29-84 PBU & PBU DATA SHEET Sch Y-18/'8-31-84 PBU & PBU DATA SHEET Sch (4/82) Alaska 0il & Gas Cons. Commission Anchorage Carolyn Bishop Development Geology Well Records INDEXED A-5/ M-19 ~ M-21- M-22' E-1~ M-23 /° M-24 / N-7~ Q-3/ SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON ~o: SFO/UNIT/STATE: GETTY (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) , REFERENCE: 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 6-18-84 CC#: 75392 CENTRAL FILES (CC#'s - Transmittal Only~ SOHIO FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- Static Gradient 5-30-84 Otis Static Gradient 5-25-84 Otis Static Gradient 5-27-84 Otis Static Gradient 5-29-84 Camco Static Gradient 5-30-84 Camco Static 6-1-84 GO Static Gradient 6-4-84 Camco Static Gradient 5-31-84 Otis Static Gradient 5-31-84 Camco RECEIVED JUN2. ? I984 Alaska Oil &AGas Cons. Commission nChorage (4/82) Carolyn Bishop Development Geology Well Records ALASKA OIL AND GAS CO#SERVATION-COMMI$SION Hay 25, 1984 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 99501.1-3192 TEL EPHONE (907) 279,-1433 ADMINISTRATIVE APPROVAL NO. 192.2 Re: The application of Sohio Alaska Petroleum Company, to substitute bottomhole pressure surveys in lieu of transient pressure surveys for Prudhoe Bay Unit wells numbered A-5, E-l, H-8, N-7, and Q-3. Mr. A. E. Leske Manager Reservoir Development Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Dear Mr. Leske: The Alaska Oil and Gas Conservation Commission received your application, dated May 22, 1984, requesting an exception to Rule 6(c) of Conservation Order No. 165 which requires a tran- sient pressure survey for key wells in the reservoir pressure surveillance program. The application states that Prudhoe Bay Unit wells numbered A-5, E-l, H-8, N-7, and Q-3 have been shut-in either because of low productivity or reservoir management and request that a static bottomhole pressure survey on each well be substituted for the transient pressure survey. The Commission has examined the evidence available and concludes that the .static bottomhole pressure surveys will provide the data necessary for use in the reservoir pressure surveillance program. Therefore, by this letter, the Alaska Oil and Gas Conservation Commission hereby authorizes the taking of static pressure surveys in lieu of transient pressure surveys for Prudhoe Bay Unit wells numbered A-5, E-l, H-8, N-7, and Q-3 until the wells are returned to a producing status. This authorization is pursuant to Rule 2, of Conservation Order No. 192. Yours very truly, Harry W. Kugle~ Commissioner BY ORDER OF THE COMMISSION be SOHIO ALASKA PETROLEUM COMPANY SFO ARCO - CHEVRON 311 1 "C" STREET ANCHORAGE. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 EXXON ~o:SFO/UNIT/STATE: (-Marathon) GETTY MOBIL PHILLIPS STATE - BPAE (Transmittal Only) _ CENTRAL FILES (CC#'s - Transmittal Only) Date: 1/9/84 Trans.#: 74956 CC#: REFERENCE: fIO FINAL DATA - PRESSURE SURVEY DATA_ ollowing material is being submitted herewith. Please acknowledge receipt by signing a of this letter and returning it to this office:-- A-5" Static Gradient 11/5/83 Camco A-21~-~'~ Pressure Survey & BHPD 12/6/83 Camco C-2 '/ Pressure Survey &' BHPD 11/10/83 GO C-26/ Static Gradient 11/7/83 Camco C-26~ Pressure Survey & BHPD 12/8/83 Camco D-16/' Pressure Survey & BHPD 11/10/83 Otis D-22~ " " " " 11/13/83 Otis M-ii /~ " " " " 12/19/83 Otis N-17 ~ " " " " 12/11/83 otis N-19TM " " " " 12/7/83 Otis R-17/~ " " " " 12/30/83 Otis Y-2 / " " " " 11/5/83 Camco M-10 ~ " " " " 12/26/83 Camco X-14'/ Static Gradient 12/30/83 Camco (4/82) RECEIVED DATE ~/~/~~~k Victoria Aldridge TP1-5 ~r~~ J,~U Development Geology Well Records Anchorage SOHIO ALASKA PETROLEUM COMPANY o SFO ARCO CHEVRON EXXON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 ~o: SFO/UNIT/STATE: GETTY (-Marathon) MOBIL PHILLIPS STATE BPAE (Transmittal Only) CENTRAL FILES (CCt/'s - Transmittal Onl~y~) Date: CC#: 5/1'1/83 74441 REFERENCE: SOHIO FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- '~/ Pressure Survey GO 5/3/83 -29 ~ ,, B-l-'" ,, Otis 4/30/83 F_15~ ,, Otis 4/21/83 & BHPD GO 4/24/83 N-9 <~.~-Static Survey Camco 4/29/83 X-19 ? " ,, Camco 4/26/83 (4/82) RECEIVED MAY 1 3 .~cE,v~od' _.--./r,"_/~j"%,'""-- Anchorage Victoria Aldridge / ~ Development Geology '- /) '9~1~3 Well Records TP1-5 DATE ~ SOHIO ALASKA PETROLEUM COMPANY TO: SFO/UNIT/STAT,E: (-Marathon) CENTRAL SFO ARCO CHEVRON EXXON GETTY MOBIL PHILLIPS STATE OF AK BPAE (Transmittal Only) FILES (CC#' s-Transmittal Only) 311 I "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 11/17/82 Trans.#: 2855 CC#: 55855, REFERENCE: ' I0 CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-15 E-18 H-6 R-2 DDNLL/GR 8/16/82 #1 1055-11538 Pres 5" · Spinner 10/27-28/82 10800-11170 Camco 5" Temperature Survey 11/1/82 #1 9600-10005 Camco 5" Temperature Survey 11/5/82 #1 9300-10200 Camco 5" (4/82) RECEIVED DATE ~.~.~.. ~ RECEIVED Z,.L/~~.,,~---[~'f'~-,982,,,,, ,., V~ toria Aid ridge Development Geology TP1-5 ^ia$~Oii-&Gas C0.$. O~mm~ Records SOHIO ALASKA PETROLEUM COL1PANY SF0 ARCO CHEVRON EXXON 3111 "C" S1REET ANCHORAGE. ALASKA TELEPHONE {9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 GETTY SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) ,, CENTRAL FILES (CC#'s -- Transmittal Only), .Date: 10-20-82 Trans.#: 2753 CC#: _ 5S7~ REFERENCE: ., /~~OHIO FIN. AL~ DAT. A_- PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- E-21--_ Pressure Survey 9-22-82 Camco M-15j Pressure Survey & BHPD 9-1-82 GO E-17f Pressure Survey 9-4-82 GO E-18f Pressure Survey 9-17-82 GO E-17~' Pressure Survey & BHPD 9-24-82 Otis G-18~ Pressure Survey & BHPD 9-25~82 GO G-3 "- Pressure Survey & BHPD 9~23-82 GO Y-13j Pressure Survey & BHPD 9-20-82 GO C-10~ Pressure Survey & BHPD 9-14-82 Camco Y-3 ~' Pressure Survey 9 .~9~-82 Camco A-5 ~ Pressure Survey & BHPD 10~8~82 GO N-7~/ Pressure Survey & BHPD 10-11-82 Camco M-5 f Pressure Survey & BHPD 10.-11-82 Camco 4/82) _ RECEIVED DATE · , .,r)/,.,~,.,. Karen Mestas I982 Development Geology ~fm~fa r~,,;: · 19 . _ Well Records ~-"~ ~, Gas C~ns. Ccm~Nsc[~ SOHIO ALASKA PETROLEUf~A COMPANY SFO ARCO CHEVRON EXXON ANCHOHAGE ALASKA TELEPHONE 1907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 ~o:SFO/UNIT/STATE: (-Marathon) CENTRAL FILES GETTY MOBIL PHILLIPS BPAE (Transmittal Only) (CC#'s - Transmittal Only) Date: 4/13/82 Trans.#: 1496 CC#: '. 49496 REFERENCE: S/OHIO FINAL DATA - PRESSURE SURVEY DATA /.,/The herewith. Please acknowledge receipt by signing a following material is being submitted copy of this letter and returning it to this office:-- A-5 H-15 HP Pressure Analysis HP Pressure Analysis 4/4/82 (Camco) 4/4/82 (Camco) (4/82) RECEIVED 't -~,~ Oii & Gas ConS. · ~,nch0¢ap,,; O°'miJ~e ] o ].n e n t G eD 1 og y DATE 19 Wel 1 R'(,c ord s SOHIO ALASKA PETROLEUM COMPANY Commissioner, State of Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 3111 'C" STRE~[~:~-'-R'ES I~NG ANC.ORA~, ALASK~9{O~ April 28, 1980 ~ ~A,T TEC Dear Commissioner smith, Attached~j~find an 0il Spill Report concerning a small spillage a~in the Western Operating Area on 4/27/80.; The Alaska Department of Environmental Conservation has been informed by telex from Prudhoe Bay. 'If you wish any further information on this incident please contact the undersigned. Sincerely yours, P. G. Rennie Manager, Development Engineering PGR/JEC/sm Attachment CC#15,495 TO' FROM: Commi ss i oner, Alaska Oil & Gas Conservation Commission Manager, Development Engineering Sohio Alaska Petroleum Company SUBJECT: OIL SPILL REPORT Date & Time' 1800' 1805 Hours 4/27/80 Well Number' A-5 Estimated Spill Volume' 30 galls. (max.) Cause of Spill' During wireline operations a ½" grease connection on the lubricator broke, spraying oil into the wind. Action Taken' Swab valVe was closed, cutting wireline, to minimize spill. Comments: Oiled snow collected in reserve Pit;oil will be recovered during summer clean up. Estimated 10 percent of oil will r. each tundra. No navigable water threatened. No remedial action rqquired as this was an equipment failure. 02-O01B iRev STATE of ALAS KA TO j-- OIL & GAS CONSERVATION COMMISSION NOTIFICATION TO O&GCC Date & Time of Notification:_ 4_. Person ~.~otified: L,~C_,~ , Information zequired by 18 AAC 75.110 1. Date and time of discharge: '+A'~I~o ~ ~'~o (~'.~~' 2. Location of Discharge: ~r ~ 3. .Persor~ or Persons causing or responsible for the discharoe: 4. Type (s) and amount (s) of hazardous substance (s) discharged: , 5. Cause of Discharge: 6. Environmental damage ~ause by the discharge to the extent asce~- tainab le: 7. Cleaning actions undertaken: 8. Location and method of ultimate disposal of the hazardous substance and contaminated clean-up materials including data of disposal: 9. Actions taken to prevent recurrence of the discharge: SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION TO: STATE . , . Attn' Mr, ~' Ha. mi~ton 3111 "C"STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 STATE 11/30/79 REFERENCE: SOHIO WELL DATA following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office'- FDC/CNL 10/25/79 Run#3 5" DIL 10/11/79 Run 1 5" & 2" FDC 10/25/79 Run 3 5~' CPL 10/25/79 RUn 2 5" BHCS 10/25/79,10/20/79,&10/11/79 Runl,2&3 5" & 2:' RFT 10/25/79 Run 1 Din 10/11/79,10/20/79& 10/25/79 Runl,2&3 5" BHCS 10/11/79,10/20/79 &10/25/79 ~ Run 1,2&3 5" Above data previously sent 11/14/79. M-7 Mud Log 10/22/79-11/5/79 (as requested 11/14/79) Bottom-Hole Pres sure Data Form & Survey 11/4/79 " " " 11/6/79 " " " 11/12/79 " " " 11/4/79 ~,' " " 11/17/79 Carol Krieter Well Records SOHIO PETROLEUM C( Division of Sohio Natural Resource, SOHIO-BP ALASKA PRODUCTION DIVISION TO: State .of Alaska Alaska Oil & Gas 3001 Porcupine D AnChorage, AK Attn:~ Mr.. H. Ha: REFERENCE: Well Data T The following material is being su copy of this .letter and returning it G-3 Spectral J-6 Transient P " " MPANY Company 99504 .~ilton 3111 "C" STRI~ET ANCHORAGE, ALAS ~' August 22, 3.97;9 .... 'r"~ . CONFSR: . . FII. F: ransmission )mitted herewith. Please acknowledge receipt by signing a to this office:-- og run 1 resSure Data/Data Packet 8/2/79 ,, ,, " " 8/6/79 ,,' ,, " " 8/5/79 ,, ,, " " 8/5/79 RECEIVED DATE . Colette Tr'ac~ Well Records SOHIO PETROLEUM COMPANY Di'vision of Sohio NatUral ResourCes Company SOHIO-BP ALASKA'~PRODUCTION DIVISION TO: State of Alaska Alaska Oil & Gas 3001 Porcupine Dr. Anchorage, AK 99504 _._L_co~~ ~c~ -i-" ~c.o~, ,~s~-..._~ TELEPHONE (90: ANCHORAGE, A L6[~_~ J J ,.STAT TE~ J"F~L~ : ~ Attn: Mr. H. Hamilton REFERENCE: Well Data Transmission The following material is being submitted herewith Plea,s~-Fbknowledge receipt by signing a copy of this letter and returning it to this office:- ~ ~,~ '6 ~B-4 Gev. Sect. Well Transient Survey/Data Packet 7/14/79 ( N-7 Key Well Transient Survey/Data Packet 7/29/79 1 log and 1 print for the following Sohio operated wells: D-7 Spinner Run 1 6 Temperature Log Spinner Run 1 Temperature Log Run 1 Run 1 Colette Tracy Well Records SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION July 16, 1979 State of Alaska Department of Natural Resources Division of Oil & Gas Conservation 3001 Porcupine Drive Anchorage, AK 99509 3111 "C" STREE/~ ANCHORAGE, AL/~S TELEPHONE (907) 265 MAIL: POUCH 6-61 ANCHORAGE, ALASKA Attn: Mr. H. Hamilton Subject: Well A-5 (43-34-11-13) Gentlemen: Please find attached in duplicate Form 10-403, "Sundry Notices and Reports on Wells" and Form 10-404, "Monthly Report of Drilling and Workover Operations" for the above mentioned well. Very truly yours, S ~I O~E~M CO. District Field Engineer GJP:ys Attachments cc: M. J. Smith A. E. Leske Drilling File Forr~ 10-403 REV. 1-10~73 Sul3ml t "1 ntentlons" in Triplicate & "SubseQuent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for, proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) O,L I-3'1 GAS r-I WELL I.~ WELL I._--I OTHER NAME OFOPERATOR Sohio Pe'~'ole~[~. Co~y Division of Sohio Natural Resources Company 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, AK 99502 4. LOCATION OF WELL At surface 1896' SNL, 923' WEL, S~C. 35, TllN, R13E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KBE 65.89' AMSL 14. Check Appropriate Box To Indicate Nature of Notice, Rel 15. APl NUMERICAL CODE 50-029-20116 6. LEASE DESIGNATION AND SERIAL NO. ADL 28287 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit West 9. WELL NO. A-5 (43-34-11-13) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, TllN, R13E, UPM 12. PERMIT NO. 72.08 3orr, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE pLaNs (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) .... (NOTEs Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (ClearlY state all pertinent ~letelll, and give pertinent dates, Including estimated date of starting any proposed work. The following intervals in this well were reperforated @ 4 s.p.f, using 4" carrier , guns: 10,914 - 10,924 ft. BKB (Ref. BHCS/GR 4-11-72) 10,932 - 10,942 ft. BKB (" " " ) 10,952 - 10,964 ft. BKB (" " " ) 10,974- 10,994 ft. BKB (" " " ) The SSSVwas set and tested in the ball valve nipple. during July, 1979. This work was. completed jUL ~.~rUes iG N E ~,,~/ (This spa~-for State e~TJ~e use) TITLE District Field Engineer DATE APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side ~J Form I~o. 10404 STATE ~)F ALASKA OIL AND GAS CONSERVATION COMMITTEE REV. 3-1-70 SUBMIT IN DUPLICATE : .~ 5. AP! NUMERICAL CODE 50-029-20116 MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 6. LEASE DESIGNATION AND SERIAL NO. ADL 28287 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME OIL [] GAS [2] WELL WELL OTHER 2. NAME OF OPERATOR Sohio Petroleum Company 8. UNIT FARM OR LEASE NAME A Division of Sohio Natural Resources Company Prudhoe Bay Unit West 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6-612, Anchorage, J~ 99502 A-5 (43-34-11-13) 4. LOCATION OF WELL 1896' SNL, 923' WEL, Sec. 35, TllN, R13E, UPM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 34, TllN, R13E, UPM 12. PERMIT NO. 72-08 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK' IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. July 15, 1979 Pulled SSSV and insert sleeve. July 15/16, 1979 Perforated the following intervals @ 4 s.p.f, using 4" carrier guns. 10,914 - 10,924 ft. BKB (Ref. BHCS/GR 4-11-72) i0,932 - 10,942 ft. BKB (" " " ) 10,952 - 10,964 ft. BKB (" " " ) 10,974 - 10,994 ft. BKB (" " " ) Well flowed on small choke setting during perforating operations. July 17, 1979 Set and tested insert sleeve and SSSV in ball valve nipple. :~~a~: ~lkeCt~__ f..~.. -- 14'S -~1%_ -- TITLE District Field Engineer DATE oil and gas ¢onserYation committee by the 16th of the succeeding month,unl~ othsrwiss SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 SOHIO-BP ALASKA PRODUCTION DIVISION State of Alaska Department of Natural Resources Division of Oil & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99509 Attn: Mr. H. Hamilton Subj.: A-5 (43-34-11-13) Gentlemen: June 29, 1979 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 COMM I 3 ENO ~ 2 GEOL I 3 OEOL '-'-i--STAT T~ CONFER: FILF: Please find attached in triplicate Form 10-403, Sunday Notices and Reports on Wells, for the above mentionedwell. Very truly yours, SOHIO PETROLEI3M CO. District Field Engineer G~/ys Enclosures cc: M. J. Smith A. E. Leske Drilling file JUL. 3 1979 At~Ska 0ii ~ (~.~ ~ -,r,'.,. ,.~i~,;lllSS[0n Form 10-403 REV. 1-10-73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) OIL ~ GAS r-! WELLI~.CJ WELL L--.J OTHER 2. NAME OF OPERATOR SOHIO P~r~o~.~ A DIVISION OF SOHIO NATURAL RESOURCES COMPANY 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 99509 4. LOCATION OF WELL At surf ace 1896' SNL, 923' WEL, S~C. 35, TllN, R13E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KBE 65.89' AMSL 14. Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) [5.r~API NUMERICAL CODE 50-029-20116 i6. LEASE DESIGNATION AND SERIAL NO. ADL 28287 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME 9. WELL NO. A-5 (43-34-11-13) 10. FIELD AND POOL, OR WILDCAT PRb~DHOE BAY, PRUDHOE OIL POOL 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) S~C. 34, TllN, R13E, UPM 12. PERMIT NO. 72.08 )ort, or Other Data SUBSEQUENT REPORT OF= WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. The fo, llowing inte~als in this well will be reperforated @ 4 s.p.f using 4" carrier guns: 10,914 - 10,924 ft. BKB (Ref. BHCS/GR 4.-11-72) 10'932 - 10,942 ft. BKB (" " " ) 10,952 - 10,964 ft. BKB (" " " ) 10,974- 10,994 ft. BKB ( "~ " " ) The ,well will be left with SSSV in the nipple at CA. 2000 ft. BKB. [6o I hereby ¢~_~ thdhe~olng is true and correct ,~ (T.~",p ~ 'r'S'i ~dGdaAL SIGhtED' ~ ' .... ' .... District Field Engineer BY HARRY APPROVED BY,, CONDITIONS OF APPROVAL, IF ANY.' Instructions On Reverse Side ..- DATE -z-7 ? , Approved Copy SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION TO: State of Alaska ~nt of Natura.! ltcsourc,u, Division of. Oil & Cas 3001 Porcupi,,lc [ h',~ c, ~d~orage, Alaska b3,7~-1 A~N: MR. H. HAMiI.'V()N 2'- .. - '2.. 7 3111 "C" STREET ::~ - ANCHORAGE, ALASKA 4 ~N,'.~ . TELEPHONE (907) 265-0000 !;..~..~ t.. 2 ,.,:'~, MAIL: POUCH 6-612 ,?%.r:(DL~/'~"'"' ANCHORAGE, ALASKA 99502 _. , ST.AT.T -CO F R-: .... ---I FILF: ..... May 11, 1979 REFERENCE: Well Data Transmission The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-t//"~"f,--~ ~ -f-' -1 Logs for the following Sohio opera(ted wells: Q-3 BHCS Run 1,2,3 2" & 5" N-8 Spinner Run 1 5" Key Well Transient Survey/Raw Data 5/1/79 Gov. Section Transient Survey/Raw Data 4/15/79 Transient Pressure Survey/Raw Data 5/5/79 ,/ Colette Tracy Well Records SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA pRODUCTION DIVISION TO: State of Alaska Department of Natural Resources Division of Oil & Gas 3001 Porcupine Dr. Anchorage, AK 99504 Well Data Transmission REFERENCE: 3111 "C" STREE9 ANCHORAGE, ALA.( TELEPHONE (907) 26... MAIL: POUCH 6-61 ANCHORAGE, ALASKA .STATE March 12, 197' The following material is being submitted herewith. Please acknowledge receipt by signing a ~,/'/~"'~-~'~.~ ~.~- of this.letter and returning it to this office:- . /~f copy i sepia and 1 print for the 'following Sohio operated wells: /__ .~ B-2 Spinner Survey Run 1 5" JGC-3B Temp Log Dec. 6, 1978 .~.i~,,.,,,...,~¢ ransient Pressure Survey/Press-Temp Guage 2-15-79 ,~_---~ ~ ~/B-2 Key Well Transient Survey/Data Packet 2-14-79 ~,,j~0,,,,v~.,~. ~//~ A-7 Transient Pressure and Spinner Survey/Data Packet 2-26-79 ~ o 1 e--t-~-e Tra~y Well Records D ATE 19 -. SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: State of Alaska Department of Natural Resources Division of Oil & Gas Conservation 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Mr. H. Hamilton HKVP / ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAI L: POUCH 6-612 ANCHORAGE, ALASKA 99502 I DEV-PB-250/8 ! December 19, 1978 REFERENCE: Well Data Transmission Thefollowing materialisbeingsubmitt~ herewith. Pleaseacknowled~ receiptbysigninga copy of this letter and returning it to this office:- State form 10-412, Reservoi-r Pressure Report for the followin~ wells:,/ Initial Static Survey C-3 6-21-78 B-4 7-11-78 Initial Static After Reperforation A-4 Key Well Static Survey ~ Key Well Surveys C-2 Government Section Survey D-5 F-8 N-6 N-8 E-5 M-5 11-9-78 11-27-78 11-28-78 9-9-78 11-13-78 11-14-78 11-17-78 12-1-78 11-28-78 11-17-78 Colette Tracy Well Records RECEIVED DATE 19 '/,/ · $OH!O PETROLEUM COMPANY ~' :~esources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: State of Alaska Department of Natural Resources Division of Oil & Gas Conservation 3001 Porcupine Drive Anchorage, AK 99504 3111 "'3" ST£.EET .... .;i ,3 ...~-.~., ,:,LASF, A TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 DEV-PB-250/8 November 30, 1978 REFERENCE: Well Data Transmission The following material is being submitted herewith. Please acknowledge receipt by signing a ...copy of this letter and returning it to this office:- ('' ..1..print and 1 sepia for the following Sohio operated wells: ] B-7 CNL Run 1 5" ~ 51! "' ~, ~. B-2 CNL Run 3 : N-2 CNL Run 1 5" ~ GC-3B Engineered Production Log 1! Run - Production Profile Run 3 & 4 5" ~TranSient Pressure Survey 11-17-78 E-1 Transient Pressure Survey 11-02-78 Transient Pressure Surveys for the following wells enclosing pressure gradient survey data sheet, pressure gradient survey graph, pressure build-uF survey data sheet, field data, pressure and temperature: J-3 10-17-78 J-6 11-13-78 G-3 10-06-78 Colette Tracy .'~ Well Records " SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION TO: State of Alaska Division of Oil & Gas Conservation Department of Natural Resources 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Mr. H. Hamilton 3111 "C" STRE E'~ ~ "i~N;3 -'i---~ MAIL: POUCH -61g ANCHORAGE, ALA A October 13, I~}B-~:"" REFERENCE: The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- Transient Pressure Surveys for the following wells - enclosing Pressure 'G~adient SurveY .Data, Pressure Gradient Survey Graph, Pressure Build~~rvey, Field Data, Pressure and Temperature A-3, ( A-5/ A-7, B-2, B-3A, B-8, C-2, (2) C-3, H-8, J-6, N-1 Governmental Section'Well Transient Survey with the above enclosures for well M-3 Colette TraCy - ~ Well Records // 4' SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION 3111 *'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 TO: State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99502 DEV-PB-250/8 September 22, 1978 REFERENCE: The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- Government Sectional Survey - J-3 Initial Transi. ent Pressure Surveys A-7, C-6, ~.C-7'~. B-3A for the following wells: Key W~ransient M- 5 ,...~ ~,~ ' D 6'; Surveys for the following wells: B - 2~, C - 2', E- 1., J- fr; H- 8' Colette Tracy Well Records RECEIVED DATE 19 SOHIO PETROLEUM COMPANY [)ivi:,ion o'; ~oh~o .... · ' ~,~ ~u, ~ Resources .Company TELE?HONE (~o?] 2U5.0000 SOHIo-Bp ALASKA PRODUCTION DIVISION MAIL: POUCH 6.612 ANCHORAGE, ALASKA 99502 TO: State of AlaSka Department of Natural Resources Division of Oil & Gas Conservation 3001 Porcupine Dr. Anchorage, AK 99502 DEV-PB-250/8 September 12, 1978 Attn: Mr. H. Hamilton REFERENCE: .,.--'" The followin§ material is b~jr~g, submittacLbe~Lew[tlS'. Please acknowle~§e receipt by signin§ a copy of this let,:er and<~.~_t..u,r~jp§ [!:.t.? ..t~!? Transi.ent Pressure Surveys for. the following wells: A-i,~" A-2, ,./A-8}~' C-5,~-/C-1~/C-6 Governmental Section Well Transient Survey - J-l- initial Transient Pressure Survey - E-4 i sepia and 1 print for the following ~alts: GC-3B Salinity Log Run'l 5" ., C-1 A-3 D-3 B-6 GC-3D ~iPL Log Run 1,2 5" Saraband Run 1 5" Spinner Run 1 5" ',- L Spinner Spinner-Flowmeter Full Bore Spinner TDT DIL BHCS Run 1 Run 1 Run 1 Run 1 ~Run 1,2 Run 1,2 5~ 2" & 5" 2" & 5" 2" & 5" Colette Tracy Wall Records SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION TO: State of Alaska Department of Natural Resources Division of Oil & Gas Conservation 3001 Porcupine Dr Anchorage, AK 99509 Attn: Mr. H. Hamilton 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 DEV-PB-250/8 August 24, 1978 REFERENCE: Thefollowing materialisbeingsubmit~ herewith. Pleaseacknowledgereceiptbysigninga copy of this letter and returning it to this office:- B-1 Initial Transient Survey B-2 Key Well Initial Transient Survey .... ~ Key Well Initial Transient Survey C-2 Initial Transient Survey - Key Well N-7 Key Well Transient Survey N-3 Transient Pressure - Post Acidization ~o~e~e Tra6y Well Records RECEIVED DATE 19 ~ SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: State of Alaska Department of Natural Re:;ources ]gtvision of Off & Gas Conservz,t;on 8001 Porcupine Drive Anchorage, Alaska 99504 ~k'I"TN~ MR. II. HAMILTON 3111 "C" STREET ANCHORAGE, AhASt(A TELEPHONE (907) ~65-0000 MAIL: POUCH 6-612' . ANCHORAGE, ALASKA 99502 August 21, 1978 ~ · REFERENCE: The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and retUrning it to this office:- .K_ey Well Transient Survey for the following wells: N-7 G-3 /..~..~ell Initial Transient Pressure Survey for the following wells: (A- 5.." C-2 Initial Transient Pressure Survey for the following yells: C-8 A-1 A-2 A-3 A-8 B-4 C-1 C-5 Governmental Section Transient Pressure Survey for the followin.8 wells: N-8 N-2 E-2 D-4 D-1 E-3 E-4 E-5 G-2 H-4 H-5 J-5 M-3 M-4 H-6 J-3 J-1 D-3 H-3 D-4 Initial Static Surveys for the following well: B-3A C°lette Tra,cy,...,.. 1... ,/'/ CONFIDENTIAL SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. O. K. Gilbreth Director 3111 "C" STREET ANCHORAGE, AL/~ TELEPHONE (907)21~5-0~O0 March 15, 1~78 Gentlemen: Well A-5 (43-34-11-13) Enclosed, in duplicate, is Form P-7, Completion Report for the above-named Well, together with the Well History. Very truly yours, SOHIO PETROLEUM COMPANY P. R. Judd District Drilling Engineer PRJ:ja Enclosures cc: Well File #17 Colette Tracy ~b,i,:;'/~~-~::~.~;~: ' '. ..~:; .;,. · ' ~ ~' ."~'Z ' ' ,' ;- .';-":,~'. ~- ..... ~ . ,, ~ , ' } . { 50-029-20116 ' / ' ! ' I'll ' I ' ' I ' · '" ~ ' -'. ~ WEL.L~COMPLETION OR RECOMPLETION REPORT O I AnL 28287 '" ' la. TYPE OF. WELL: ,,-EL,. ~d~AS~ELL © ~R, I''! Ot~ " ]'bJ' TYPE OF ~.,~mr,-r.~u*',~""'"'~""'"'"': ' ~': ' ;' ' ' · . .,E. E1 woR.~ .EE,-E} P""~E3 "'"'E~ OVES ~.~,' ' BACK RESVR. Other~ · WELL '2. NAME OF OFKRATOR~ : · Sohio Petroleum Co., Div. off Sob±o-Natural ResoUree~ Company- _.. ,,. . .! :3. ADDRE88 OF OPERATOR P. 0. Box 6-1379, Anchorage, Alaska 99509 ,~. LOCATION OF WELL (Report location clearl# and in accordance with an~ 8tate requirements)* UNIT,FARM OR I.~kSE NA/~E ~.rud~oe BaY .~n~t) ' · t.Ul'fa.e 923' WEL, 1896" SNL, At top prod. interval reported below 526' WEL, 3074' SNL, At total depth 645' WEL, 2964' SNL, Sec. 35, TllN,'.-R13E, b-PM Sec. 34, TllN.,~ R13E, UPM Sec. 34, TllN, R13E, UPM 11. SEC., T., R., M., (~M HOI.~ - · O~JEC'I~VE) . , Sec 34, TllN, Ri3E':'.UPM' ., · 12. PER1VIIT NO. · 72-08 -'.. 13. 'D,a-TE SPUDD_E~-- I14.--DA~'E.T.D.--'~ [-1~'-DA~E COMP SUSP-O~ ~;' il~f ELEVATIONS (DF, RKB, RT, ~ .1~, .driVe ~ 17, ELEV, CASINGHEAD ~W ~Y* ROTARY TOOLS CABLE TOOLS 11370'~ 9348. . '~ [ ~1314. ... ~ 9296.. '~D[ None Total ~ .. Prudhoe 0il Pool ~. _~i. To~: 10914' ~ 8922' ~ ~ su~v~ ~ ~ Bdtt6m: 10994' ~ 8997' ~ ~ Yes 34. TYPE ELECTRIC AND OTI-1i:A IX)GS RUN DIL/SP, BHCS/GR, L~-3; ~FDC/Cal, '":' cxsmG SIZE 20"x18 5/8" 13 3/8"x9 5/8" 9 5/8" 26. LINF, R i~E C O'P~D - . SIZE''-. -[ [ TOP (MI)~ L t :BOTTOM (MD) [ SACI~S ~]~N-T* ~ 10914 '-10924~ B~ ~ 4 ~spf 0.5" (ref. BHCS/GR ~10932~-10942~ " ; ' '~ " 4/11/72) ~10974~_10994~ - ~' ,, ,, SNL/CAL, CBL/GR [- ~'~: 'i .C./~I~G l:l.lgC~l:lJ~ (Report a~ -. I W~G~, LB2~. ~ 'G~ I D~ ~. (~) ~O~ 1133/9~.S [': [E'55 ] 2270' 26" I 0700 sks [.68/47. :: IN-80 I 9814' 12 1/4'1 2150 sks [ 47#L .~'[N-80 I .2015'_ tieback~ith tod 3 its. 11 3/4"x9 ,8 ~/2'~ ,4~ ~- ,, ! I I ~. Pl%ODUCTION D~;¢"~ Or TEST. II-]:OU'RS TE~D' 'ICHO'.~iE SIZE. I~D'N MA . -,i AMOUNT pU~ ~'~0 5/8"Thermocase II DATE FIRST PRODUCTION [ ~ FRODUC~ION METHOD (Flowing, g~s lifE, pumping---size and t~pe °f pump)(..,,,~. d'/-/ /(.~ ./ 7 ] WELL STATUS (Producing or~llut.in). . OII.,~BBL. GAS~IV~CF.~ .. I O~- GRa. Vr~3r-AI~ r 971 (COP~.) . .. ~vislon ol Oil and Gas C0 Well History · ,, 33. I hereby certify that t~g~tng and attached lnfprmation Is complete and correct as determined from alVavailable records~ / .. ~(~ I.~.ctio.~ ~.d S~c{~ Io~ Adaitio.~l Dat. o. Rever~e Side) ~ DEPT~ SET (1VLD) [ PACKER SET (M'D) .)-. SCP,.EEN (MD) SIZE 't .cm, Si~OT, ~,-~-,~,s. cs~m~-r s~u=zs, ETc. D]ilPTH IHTERVAL (MD) ] AiVIOU'NT AND KIND OF MATE,RIAL US,ED 7" liner '. lap ] /~-~ ~ ' ') 1 /~.~x'~.,.'f., ,. ~,, 9272; I '" lO0 sks mass"a" .... 11066t [ 50 sks Class "G" INSTRUCTIONS General: This form is designed for submitting 8 complete and correct well completiOn report end' 10g on . all types of lan:Is and leases in ,~laska. Item: 16! Indicate which elevation is used as reference (where not otherwise shown) f~..:: .depth measure- mentsgiven in cther spaces on this form and in any attachments. Items 20, and 22:: if this well is completed for separatc production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the prcJucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produceJ,"show, ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should' show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for ea'ch interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAItY OF' Im'OR1VI'ATION T,~'~'I'S INL'LUDIN(i INTERVAl. TF~TET). PI.1E.~lJJR~- DATA ~ I:LP~'OVERI,~-.~c O'1~' OIL. OAS. ~s. O ~X:)i.;OO lC WA~_J'~ AND MUD NAIV~ BKB Spbsea Sag Kt~er SST '10802 } 8753 ~ . Shub. l..~¢ 108.28 ~' '" 8777'~ 1vSsh~k 10~1~ t, 8853 t . "~ ':'"' ' ' "~ ....... .'' ' ;.:"¢..-L.'...;~ : ,:~ ~ . .... :',~ ,,-~- -~ ~. ~fl.~ DATA. AI'~A~I{ ~fljE~ .... .~ ~[O~.. P~R~. ~~: 'A~~ ~ ... .I . - ---;--.- ......... ; ......... ; ...... , .-- .......................................... ..._.¢ ..................... ~ m, - ....... :"~ -"m" -~-'~ ................ r'~.... -.-' WELL HISTORY CONFIDENIIA BP WELL A-5 (43-34-11-13) DRILLING March, 1972 Spud well at Q230 hours, March 14, 1972, Drilled 17 1/2" hole to 2326t'. Opened hole to 26" to 2326'.. Ran 19 its-. 20"' 133# K~55 8rd casing and 41 its, 18 5/8" 96.5# K-55 Buttress casing. Shoe set 2278t, crossover at 1517~.. 1 1/4~ tubing strapped to 18 5/8" casing to 1492'~. Cemented with 250 sks-Permafrost II cement with 0,3% WG~.7, slurry weight to 14.3 ppg. Followed with 7250 sks-Permafrost li with the slurry weight at 14.8 ppg. Ran 2 strings 1 1/4" tubing to 183" and tagged top of cement, Cemented to surface, with 1200 sks Permafrost II, slurry seight 14,8 ppg. Nippled up and tested BOPEo Drilled 12 1/4" hole directionally to 9822~, Conditioned hole and ran logs. Ran 193 its. 9 5/8" 47# N~80 Buttress. casing and 51 its, 13 3/8" 68# N-80 Buttress casing. Shoe set at 9814', float collar at 9770%~ full opening cementers at 2146' and 2065' 13 3/8" ×9 5/8" crossover at 2015~ Cemented with 775 sks Class "G~ cement with 10% gel and 1.25% CFR~2, slurry weight 12.8 ppg. This was followed by 250 s~s- Class "G" cement with 1.25% CFR~2, slurry weight 15.8 ppg. Displaced with 880 bbls mud. Top of first stage cement at 5484'. April, 1972 Carried out second stage squeeze cementation with 600 sks Class '~G" cement with 10% gel .and 1.25% CFR-2, mix water with Ray Frac. Slurry weight 12,8 ppg. This was followed by 425 sks Permafrost II cement with 5# of pQzzolan per sack of cement. Slurry weight 14.8 ppg. Displaced drill pipe, 13 3/8" casing and 13 3/8" x 18 5/8"/20~' annulus to water. Swabbed casing,'cement job not holding. Sandline parted and dropped sinker bar and fluid locator in hole. Ran overshot and recovered fish, Circulated to clean 13 3/8" x 18 5/8"/20" annulus, Placed 100 sks Permafrost II cement with 5# pozzolan between lower and upper full opening cementers, Reverse circulated through upper full opening cementer. Tested squeeze job. Swabbed hole clean and pumped a total of 320 bbls residual oil into annulus. Closed cementer and tested. Ran in hole drilled float collar, cement and shoe and drilled ahead to 9962~ Drilled ahead to TD at 11370'. Conditioned hole and ran logs. Ran 48 its. 7" 29# N~80 Buttress casing shoe at 11360', landing collar at 11314' and top of marker joint at 10733', liner hanger at 9318', liner packer at 9312' and top of tie back receptacle at 9272~, Pumped 10 bbls water,'lO bbls MF-1 with Moreflo and 10 bbls B-J mud sweep, Cemented with 485 sks Class "G" with 1.25%, CFR-2 slurry weight 15.8 ppg. Displaced drill pipe and liner with a total of 240 bbls mud. Set liner packer. Circulated out 10 bbls excess cement and 40 bbls contaminated mud. Tested liner lap satisfactorily. Displaced hole to fresh water followed by 26% CaC12 completion fluid. Laid down drill pipe. Ran in to 2000' and displaced to diesel. Removed BOP'S and installed and tested well head cap. Realeased rig 1100 hours, April 15, 1972. i'x [ ~ ~ October, 1977 DMsion 0( 0ilal~d Gas t ....... ~ccepted rig at O001 hours, 10/13/77. Installed and tested ~07~. ~isplaced diesel to CaC12. Ran 4 its. 9 5/8" 47# controlled-yield N-80 Buttress casing with shoe and 12' PBR to crossover at 2015', cemented in place with 100 sks Permafrost cement, Ran dummy seal assembly unsuccessfully. Circulated out cement, recemented with 100 sks cement. Ran 2 jts. 9 5/8" 47# controlled-yield N-80 Buttress casing with FOC, 42 its. 10 3/4" 55.5# controlled-yield N-80 Buttress casing, and 3 its. 9 5/8" x 11 3/4" Therm- ocase II to PBR at 1846' Arctic Packed 9 5/8" x 13 3/8" annulus. Circulated well CONFIDENT/AL to CaC12:, Ran CBL/VDL log. Squeezed 7" liner lap with 100 sks cement. Ram DST tests on 7~' lap. Shot 4 perfs at 11066~', Squeezed 50 sks cement, Cleaned out to 11314'. Ran CBL log. Ran 235 jts. 7" 26# controlled-yield N-80 AB-IJ-4S tubing. Landed tubing in PBR at 9272t' with ball valve nipple at 2038~', Reversed well to diesel. Installed and tested wellhead and tree, Released rig 2400 hours, 10-29-77. pERFORATING , , March, 1978 Pressure tested tubing to 3000 psig and inner annulus to 1500 psig. Perforated the following intervals using Schlumberger 4" carrier guns Hyper Jet II, at 4 S,P.F, 10,914 - 10,924 ft,~ BKB (.ref, BHCS/GR 4-11-72) 10,932 ~ 10,942 ft.. BKB (ref. BHCS/GR 4-11-72) 10,952 - 10,964 ft. BKB (ref, BHCS/GR 4-11-72) 10,974 - 10,994 ft. BKB (ref. BHCS/GR 4-11-72) Following perforating operations a static bottom hole pressure survey Was recorded. Ran and set I.S. and SSSV. Tested SSSV, swab valve, master valve. END OF OPERATIONS. The well was left with the SSSV closed and with the well head valves closed (except the surface safety valve). SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907)265-0000 SOHIO-BP ALASKA PRODUCTION DIVISION State of Alaska Department of Natural Resources Division of Oil & Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99509 ATTENTION: Mr. O.K. Gilbreth' Jr. Gentlemen: A-1 (42-35-11,13) A-2 (41-36-11-13) _~__.~;~1.~ 3- 2 7-11-13) 34-11-13) March 7, 1978 MAI L: P, O. BOX 4-1379 ANCHORAGE, ALASK A-7 (12-26-11-13) A-8 (22-36-11-13) H-6 (21-11-13) GC-2B (16-11-13) D-5 (23-24-11.13R) Enclosed please find in triplicate form 10-403, Sundry Notices and Reports on Wells, and'in duplicate form P-4, Monthly Report of Drilling and Workover Operations, for the above wells. Very tru/y yours, Sohio P~troleum Company ~nDa;eTraF~i~d OpJ a~ GP :bs Enclosures cc: P.E. Well files Drilling well file's A-5 Form 3,0-403 REV. 1-]~ 0~73 43-34-11-13 Submit "I ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELL 5. APl NUMERICAL CODE 50-029-20116 6. LEASE DESIGNATION AND SERIAL NO. APL 28287 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 2. NAME OF OPERATOR SOHIO PETROLEUM COMPANY s. UNIT, FARM OR LEASE NAME A DIVISION OF SOHIO NATURAL RESOURCES COMPANY PRUDHOg BAY UNIT WEST 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 4-1379, Anchorage, Alaska 99.509 ....... ,~-~r~l A-5 (43-34-11-13) 4. LOCATION OF WELL ~ ~ ,:' ~ ~ \? i=~/~10. FIELD AND POOL, ORWILDCAT At surface ~ PRUDHOE BAY, PRUDHOE OIL POOL 1896' SNL, 923' WE~, SEC~ 35, TllN, R13E, U SEC. 34, TllN, R13E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 01¥[$i0~ gl gi; c:vo -~,~ .......... ~.2~ PERMIT NO. KBE 65.89' AMSL Ar:{~h:~r, *;':~ 72.08 ~.. Check Appropriate Box To Indicate Nature of Notice, Re )ort, or Other Data NOTICE OF INTENTION TO.' TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR AC ID IZI NG ABANDONMENT* (Other) (NOTE= Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all Pertinent detell~, and give pertinent dates, Including estimated date of starting any proposed work. The following intervals in this well were perforated (at 4 S.P.F.) for production: 10,914 - 10,924 ft. BKB (ref. BHCS/GR 4-11-72) 10,932-10,942 ft. BKB (ref. BHCS/GR '4-11-72) 10,952 - 10,964 ft. BKB (ref. BHCS/GR 4-11-72) 10,974 - 10,994 ft. BKB (ref. BHCS/GR 4-11-72) A static bottom-hole temperature survey was conducted prior to perforating. Immediately following the perforation operations a static bottom-hole pressure survey was recorded. The well was left with a SSSV in the nipple at CA. 2000 ft. BKB. (This space for Stat~Y-~ffice use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY; TITLE DATE See Instructions On Reverse Side A-5 Form ~o. P-4 REV. 3-1~0 43-34-11-13 /,% SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING . _ND WORKOVER OPERATIONS WELL *--- WELL 2. NAME OF OPERATOR SOHIO PETROLEUM COMPANY A DIVISION OF SOHIO NATURAL RESOURCES COMPANY 3. ADDRESS OF OPERATOR P..O. Box 4-1379, Anchorage~ Alaska 99509 4. LOCATION OF WELL 1896' SNL, 923' WEL, SEC. 35, TllN, R13E, UPM 5. APl NUMERICAL CODE 50-029-20116 6. LEASE DESIGNATION AND SERIAL NO. ADL 28287 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME PRUDHOE BAY UNIT WEST 9. WELL NO. A-5 (43-34-11-13) 10. FIELD AND POOL, OR WILDCAT PRUDHOE BAY, PRUDHOE OIL POOL 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) SEC. 34, TllN, R13E,,UPM 12. PERMIT NO. 72-08 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. 3 March 1978 Pressure tested tubing to 3000 psig and inner annulus to 1500 psig. 4/5 March 1978 Perforated the following intervals using Schlumberger 4" carrier guns Hyper Jet II, at 4 S.P.F. 10,914 - 10,924 ft. BKB (ref. BHCS/GR 4-11-72) 10,932 - 10,942 ft. BKB (ref. BHCS/GR 4-11-72) 10,952 - 10,964 ft. BKB (ref. BHCS/GR 4-11-72) 10,974 - 10,994 ft. BKB (ref. BHCS/GR 4-11-72) 6 March 1978 Following perforating operations a static bottom hole pressure survey was recorded. 7/8 March 1978 Ran and set I.S. and SSSV. Tested SSSV, swab valve, master valve. END OF OPERATIONS. The well was left with the SSSV closed and with'the well head valves closed (except the surface safety valve). 14. I hereb ~eand cOrrect . , ' NOTE~~hi~orm is requir~ for each calendar .month, regardle~ of the ~atUs of operation, an P oil and gas conservation committee by the 1§th of the succeeding month,unless otherwise directed. P. O. BOX 4 1379 3111 "C"STREET ANCHORAGE, ALASKA 99509 TELEPHONE (90'7) 278-2611 GEN-AK-083 February 13, 1978 B'P ALAS KA ! N C. TO: State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Attn: Mr. O. K. Gilbreth REFERENCE: The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- 3 copies of the form 10-403, Sundry Notice for the following wells: A-1 C-5 A-2 C-6 C-1 B-2 C-2 B-4 Colette Tracy Well Records RECEIVED DATE, 19 _ Form 10-403 /~'~. Submit "1 ntentlon$" in Triplicate REV. ~-'!0-73 & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proDosals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such Droposels.) ~' -O,L ~ GAS F--1 WELL{ '~''1 WELL OTHER 2. NAME OF OPERATOR SOHIO PETROLEUM, A FITVT.qT(3N f)]~ ROTqT(3 I~ATTT~AT. R~..qC~I'TRP.~_q P.C)MT)AM¥ . .. 3. ADDRESS OF OPERATOR 5. APl NUMERICAL CODE 50-029-20II6 6. LEASE DESIGNATION AND SERIAL NO. ADL 28287 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME 9. WELl. NO. . P.O. Box 4-1379_- AnchoraE~-:'Alm.~ka ,,,qqs~9 4. LOCATION OF WELL At surface 1896' SNL, 923' WEL, SEC. 35, TllN, R13E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, et~) KBE 65.89' AMSL 14. Check Appropriate Box To Indicate Nature of Notice, Re A-5 (43-34,11-13) 10. FIELD AND POOL, OR WILDCAT PRUDHOE BAY, PRUDHOE OIL POOL 1l. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) SEC. 34, TllN, R13E, UPM 12. PERMIT NO. 72.08 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULLOR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTEt Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS'(Clearly state all ~ertlnent details, and give pertinent dates, including estimated date of starting any proposed work. The following intervals in this well will be perforated (@ 4 S.P.F.) for production: Zone 4: Zone 4: Zone 4: Zone 4: 10,914- 10,924 ft. BKB (10') 10,932 - 10,942 ft. BKB (10') 10,952 - 10,964 ft. BKB (12') 10,974 - 10,994 ft. BKB (20') (52') (ref. BHCS/GR 4-11-72) (ref. BHCS/GR 4-11-72) (ref. BHCS/GR 4-11-72) (ref. BHCS/GR 4-11-72) A static bottom-hole temperature survey will be conducted prior to perforating. Immediately following the perforation operations a static bottom-hole pressure. survey will b~-recorded and the well will be back flowed to clean .up. The~l~ will be left with a SSSV in the nipple at CA. 2000' BKB. 36. I hereby certify that the foregoing is true and correct DATE,, (This space for State office use) CONDITIONS OF APPROVAL-~ IF AN~ Petroleum l~ng~neer DATE Februa~zT~ !6 ~ 1978 See Instructions On Reverse Side BP ALASKA INC. P. O. BOX 4 1379 :.3111 "C" '.q 11'3 [! [ ANCI I( ;IIA(iI', AI.A:;KA It'. I I_:PII()NI: (90/) GEN-AK-083 December 16, 1977 TO: State of Alaska P_gjle 1 of 2 Department of Natural Resources Division of Oil & Gas Conservation 3001 Porcupine Drive Anchorage, AK 99504 attn: Mr. O. K. Gilbreth Director REFERENCE: The following material is being submitted herewith. Please acknOwledge receipt by signing a copy of this letter and returning it to this office'- Cased Hole CNL's for the following BP operated wells: (1 sepia and 1 print') ~-1'1-13) B-2 (3'2-11-14) D-6 (23-11-13) TDT-K BG TDT-K TDT-K D-7 (14~11-13) CNL E-1 (32-12-14) CNL E-2 (06-11-14) CNL E-3 (32-12-14) CNL F-3 (12-11-13 CNL F-4 (01'11-13) CNL F-6 (35-12'13) CNL F-8 (10-11-13) CNL G-1 (01-11-13) CNL 5" 10-17-75 5" 11-10-77 5" 2-27-77 5" 11-09-77 2" & 5" 3-11-77 5" 5'28-77 5" 6-5-77 2" & 5" 5-3-77 2" & 5" 11-19-76 5" 11-15-76 5" 1'0-14-76 5" 10-22-77 5" 9-9-77 BPALASKA INC. 311 $ - C - STREET · TELEPHONE (907) 279-0644 MAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE, ALASKA 99,509 November 23, 1977 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. O. K. Gilbreth Director Gentlemen: PRJ:ja Enclosures cc: Well File #17 Regina McGaffigan BP we%l No. A-5 (43-34_11_!3) Enclosed, in duplicate, is Form P-7, Completion Report for the above-named well, together with the well history. Very truly yours, ' ~, R; Judd District Drilling Engineer RECEIVED l',!OV g- 9 Form SUBMIT IN DI3WL.fCiiTE* STATE OF ALASKA · · (Seeo~h~m- st ructions on OIL AND GAS CONSERVATION COMMITTEE reve,'se side, i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* 1,. TYPE O'F WELL: ' - ..... ~U, ~" dais' [~] [~] ' WELL WELL DRY Other: b. TYPE OF COMPLETION: .~EW [~ wo.,~E3 ~EE,-I--I .~ ~,,,. ~ WELL OVER ~N BaCK ngsva. Other !}. NAME OF OPiCRATOR BP Alaska, Inc. 3'. A,ORESS O~ Opz~A'To" '"' - '~" ' " " P. 0. Box 4-1379, Anchorage, Alaska 99509 LOCATION OF WELL (Report location clearly and in accordanOe with any State requirements)* Atsu~ace 923' WEL, 1896' SNL, Sec. 35, TllN,I R13E, UPM Attop prod. intervalreported below Top Sag River SST. 492' WEL, 3100' SNL, Sec. 34, TllN, R13E, UPM At total dep~ 645' WEL, 2964' SNL, Sec. 34,, TllN, R13E, UPM C0Nf:IOENT AP1 NU'M.F.,KICA~ CODE 50-029-20116 LEASE DESIGNATION A-ND SERL~L NO. ADL 28287 IF INDIA.N, AiJ.~OTTEE OR TRIBE NA/VL~ 8. UNIT,FA.RIVI OR LF_dkSE NAME Prudhoe Bay Unit 9. WELL NO. A-5 (43-34-11-13) 10. FIELD ,aND POOL, OR WILDCAT ?rudhoe Bay,Prudhoe Oil Pool 11. SEC., T., R., M., (BO'I'rOM HOLE OBJECTIVE) Sec. 34, TllN, R13E, UPM '12'. PlieR,MIT NO. 72-08 131 D~TE SPUDDED 3-14-72 ~a. TOTAL DZ~TH. l1370'MD 9348'TVD'~9' p'LUG'~B~CK MD & TVD~, I.~ 1VUJLTIPI.~ COMA:'L., [11314 .MD 9296'TVD ] ~ow~Y*None ] aOTA~ TOO~S Total ~.~ PRODUCING IN~VAL(S), OF : ~ None 24. TYPE ELECTRIC AND OTHER LOGS .RUN .. DIL/SP, BHCS/GR~ LL-3, FDC/Cal, SNL/Cal, CBL/GR ~20"x18-5/8" [ 133/96.51 ! K'55 ] 2278,' 13-3/8"x9-5/~" 68/47/ i: ] N-80 ] 9814' ' 9-5/8" I 47# ' -': / N-go I 2o]5' 7" [ 29# -! [ N-80 i 11360,' 26. LINER ILE CO~J~D .. SIZID TOP (I{Dj Bo~O~ (MD) SAriS CH~T' 28. PERFORATIONS OpELrq TO None INTERVALS DRILLED BY CABLE TOOLS 23, WAS DIRECTIONAL I SURVEY MADE Yes CASING P,I~-'ORD (Report all strings set in well) ' ' I 8700 sks 1 12k" [ 2150 sk$ . I .... tiahack[wi~h too 3 ~ts. 11-3/4"x9~5/8" Thermocase ss" I 4ss sks - ] ~ (MD) SIZE DE~ SET (MD) I PACI~ER SET (MD) 7" 9 304 ' ACID, Si!OT, size and number) PRODUCTION DATE FIRST Pi%ODUCTION [ 'PI{O:DUCTION METHOD (Flowh~g, gas lifL pumping--size and type of pump) HOURS TESTED ' [CHOI{E SIZE ]PROD'N FOR CASING PRF-~SUR~ [CALCULaTeD OIL--BBL. GAS (8old, Used for tuel, vented, etc.) I WELL STATUS (Producing or shut-in) OIL---BBL. GAS--MCF. WATER--BBL. ] GAS-OIL R~TIO GAS--iV[C'F. WATEI%--BBL. ] OIL GRAVITY-A~I (CO1R~.) ,1 1 DATE OF TEST, FLOW, TUBING ~ ~1. DI~POSITION OF TEST WITNESSED BY LIST 0~' ATT-ACHMENTS Well Histo~ SIGNED, P. R. ~Udd ; TITLE District Drilling Engineer DATE // *(See Instructions and Spaces [or AdditiOnal Data on Reverse Side) INSTRUCTIONS .~. General: This form is designed for submitting a complete and correct well completion report and log on: all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherw, ise shown) for depth measure- ments given in other spaces on this form and in any attachments. Items '90, and '9'9:: If this well is completed for separatc, production from more than one interval zone (multiple completion), so state in item 20, and in item 22 show the p~cJucing interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional inte, val to be seperately p:roduce,'J, show- ing the ac~itiona'l data pertinent to such interval. Itern2&:. "Sacks Cement": At'tached suppl'emental records ~o.r this wel'l should, show the details of any mul- tiple stage cementing a.nc~ the location of the cementing tool. Item 28: Submit a separate campletion report on this form for each interval to. be separately produced. (See instruction for items 20 and 22' above). 34. SUMMARY O1~ FORMATION T,~,~'I'$ I.NCLUI)IN(; 'INTERVAL TF_.STED. PHE. SSURE DATA ~-- ~OVERI~ OF OIL. GAS. 35. G~G'IC MAR~ WAT~ AND MUD , ..... BKB Subsea Sag R~uer SST 10802~ 8753~ ShublSk ""10828~ }' '8777' ' Iv~shak 10910 ~ 8853 ~ .i CONFtDE TiA. I. BP Well No. A-5 (43-34-11-13) WELL HISTORY DRILLING March, 1972 Spud well at 0230 hours, 3/14/72. Drilled 17-1/2" hole to 2326'. Opened hole to 26" to 2326'. Ran 19 jts. 20" 133# K-55 8rd casing and 41 jts. 18-5/8" 96.5# K-55 buttress casing. Shoe set at 2278', crossover at 1517'. 1-1/4" tubing strapped to 18-5/8".casing to 1492'. Cemented with 250 sks Permafrost II cement with 0.3% WG-7, slurry weight 14.3 ppg. Followed with 7250 sks Permafrost II with the slurry weight at 14.8 ppg. Ran 2 strings 1-1/4" tubing to 183' and tagged top of cement. Cemented to surface with 1200 sks Permafrost II-, slurry weight 14.8 ppg. ~ Nippled up and tested BOPE. Drilled 12-1/4" hole directionally to 9822'. Conditioned hole and ran logs. Ran 193 jts. 9-5/8" 47# N-80 Buttress 'casing and 51 jts. 13-3/8" 68# N-80 Buttress casing. Shoe set at 9814', float collar at 9770', full opening cementers at 2146' and 2065', 13-3/8" x 9-5/8" crossover at 2015'. Cemented with 775 sks Class "G" cement with 10% gel and 1.25% CFR-2, slurry weight 12.8 ppg. This was followed by 250 sks Class "G" cement with 1.25% CFR-2, slurry weight 15.8 ppg. Displaced with 880 bbls. mud. Top of first stage cement at 5484'. April, 1972 Carried'out second stage squeeze cementation with 600 sks Class "G" cement with 10% gel and 1.25% CFR-2, mix water with Ray Frac. Slurry weight 12.8 ppg. This was followed by 425 sks Permafrost II cement with 5# of pozzolan per sack of cement. Slurry weight 14.8 ppg. Displaced drillpipe, 13-3/8" casing and 13-3/8" x 18-5/8"/20" annulus to water. Swabbed casing, cement job not holding. Sandline parted and dropped sinker bar and fluid locator in hole. Ran overshot and re- covered fish. Circulated to clean 13-3/8" casing and 13-3/8" x 18-5/8"/20" annulus. Placed 100 sks Permafrost II cement with 5# pozzolan between lower and upper full opening cementers. Reverse circulated through upper full opening cementer. Tested squeeze job. Swabbed hole clean and pumped a total of 320 bbls. residual oil into annulus. Closed cementer and tested. Ran in hole drilled float collar, cement and shoe and drilled ahead to 9962'. Drilled ahead to TD at 11370'. Conditioned hole and ran logs. Ran 48 jts. 7" 29# N-80 Buttress casing shoe at 11360', landing collar at 11314' and top of marker joint at 10733', liner hanger at 9318', liner packer at 9312' and top of the back receptact~o at 9272'. Pumped 10 bbls. water, 10 bbls. MF-1 with Moreflo and 10 bbls. B-J mud sweep. Cemented with 485 sks Class "G" with 1.25%, CFR-2 slurry weight 15.8 ppg. Displaced drillpipe and liner with a total of 240 bbls. mud. Set liner packer. Circulated out 10 bbls. excess cement' and 40 bbls. contaminated mud. Tested liner lap satisfactorily. Displaced hole to fresh water followed by 26% CaC12 completion fluid. Laid down drillpipe. Ran in to 2000' and displaced to diesel. Removed BOP's and installed and tested wellhead cap. Released rig 1100 hours, 4/15/72. BP Well No. A-5 (43-34-11-13) WELL HISTORY COMPLETION October, 1977 Accepted rig at 0001 hours, 10/13/77. Installed and tested BOPE. Displaced diesel to CaC12. Ran 4 jts. 9-5/8" 47# controlled-yield N-80 Buttress casing with shoe and 12' PBR to crossover at 2015', cemented in place with 100 sks Permafrost cement. Ran dummy seal assembly unsuccessfully. Circulated out cement, recemented with 100 sks cement. Ran 2 jts. 9-5/8" 47# controlled-yield N-80 Buttress casing with FOC, 42 jts. 10-3/4" 55.5# controlled-yield N-80 Buttress casing, and 3 jts. 9-5/8" x 11-3/4" Thermocase II to PBR at 1846'. Arctic Packed 9-5/8" x 13-3/8" annulus. Circulated well to CaC12. Ran CBL/VDL log. Squeezed 7" liner lap with 100 sks cement. Ran DST tests on 7" 'lap. ' Shot 4 perfs at 11066'. Squeezed 50 sks cement. Cleaned out to 11314'. Ran CBL log. Ran 235 jts. 7" 26# controlled-yield N-80 AB-IJ-4S tubing. Landed tubing in PBR at 9272' with ball valve nipple at 2038'. Reversed well to diesel. Installed and tested wellhead and tree. Released rig 2400 hours, 10/29/77. bP ALASKA INC. 3111 - C - STREET · TELEPHONE (907) 279-0644 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. O. K. Gilbreth Director MAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE, ALASKA 99509 November 3, 1977 Gentlemen: BP Well No. A-5 (43-34-11-13) Enclosed, in duplicate, is Form P-4, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of October. Very truly yours, BP ALASKA, INC. District Dri±ling Engineer PRJ:ja Enclosures cc: Well File #17 Form No. P-4 gEV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 3. ADDRESS OF OPERATOR P. O. Box 4-1379, Anchorage, Alaska 4. LOCATION OF WELL CONFIDENTIAL 5. APl NUMERICAL CODE 50-029-20116 6. LEASE DESIGNATION AND SERIAL NO. ADL 28287 I. 7. IF IND1AN'ALOTTEE OR TRIBE NAME OIL [~ GAS [] WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME BP Alaska, Inc. Prudhoe Bay Unit 99509 At surface: 923' WEL, 1896' SNL, Sec. 35, TllN, R13E, UPM 9. WELL NO. A-5 (43-34-11-13) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay~ Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 34, TllN, R13E, UPM 12. PERMIT NO. 72-08 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. October, 1977 Accepted rig at 0100 hours, 10/13/77. Installed and tested BOPE. Displaced diesel to CaC12. Ran 4 jts. 9-5/8" 47# controlled-yield N-80'Buttress casing with shoe and 12' PBR to crossover at 2015', cemented in place with 100 sks Permafrost cement. Ran dummy seal assembly unsuccessfully. Circulated out cement, recemented with 100 sks cement. Ran 2 jts. 9-5/8" 47# controlled-yield N-80 Buttress casing with FOC, 42 jts. 10-3/4" 55.5# controlled-yield N-80 Buttress casing, and 3 jts. 9-5/8" x 11-3/4" Thermocase II to PBR at 1846'. Arctic Packed 9-5/8" x 13-3/8" annulus. Circulated well to CaC12. Ran CBL/VDL log. Squeezed 7" liner lap with 100 sks cement. Ran DST tests on 7" lap. Shot 4 perfs at 11066'. Squeezed 50 sks cement. Cleaned out to 11314'. Ran CBL log. Ran 235 jts. 7" 26# controlled-yield N-80 AB-IJ-4S tubing. Landed tubing in PBR at 9272' with ball valve nipple at 2053'. Reversed well to diesel. Installed and tested wellhead and tree. Released r~g :2400 hours, 10/29/77. 14. I hereby cer~orrect /~,~/ SIGNED TITLE.District Drilling Enginee~ATE' er/ 7 7 -~ . ~. O g-{J.'{J. ,,,, , NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 1§th of the succeeding month,unless otherwise directed. BPALASKA INC. 31 1 1 - C - STREET · TELEPHONE (907) 279-0644 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. O. K. Gilbreth Director MAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE, ALASKA 99509 September 20, 1977 ,. Gentlemen: BP Well No. A-5 (43-34-11-13) Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named Well. This report contains our proposal to re-enter the well to complete for production. The program is out- lined in the report. PRJ:ja Enclosures cc: Well File #17 Very truly yours, ~p.~wR. Jhdd District Drilling Engineer Fo~n ! 0-403 REV, 1-10-73 Subml t "1 ntentlons" In Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE D ? i' ~ ~ ~ ~' F' SUNDRY NOTICES AND REPORTS ON WELLS (DO not use this form for proposals ,o drill or to deepen SEP 2 ! 1977 Use "APPLICATION FOR PERMIT--" for such proposals,) O,L ITU' G^S i--] WELL,:::., WELLOTHER 2. NAME OF OPERATOR BP Alaska, Inc. 3. ADDRESS OF OPERATOR 4. LOCATION OF WELL At surface 923' WEL, 1896' SNL, Sec. .. 99509 35, TllN, R13E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KBE = 65.89' AMSL Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE r ] 50--029220116 [~. LEASE DESIGNATION ANE) LZRIAL NO. ADL 28287 7. IF INDIAN, ALLOTTEE OR TRIBE NAME Sb[v~hO,1 8. UNIT, FARM OR LEASE NA~E Prudhoe Bay Unit 9. WELL NO. A-5 (43-34-11-13) 10. FIELD AND POOL. OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 34, TllN, R13E, UPM 12. PERMIT NO. 72-08 }ort, or Other Data NOTICE OF INTENTION TO= TEST WATER SHUT-OFF [~ FRACTURE TREAT SHOOT OR AClDIZE REPAIR WELL (Other) Completion PULL OR ALTER CASING MU LT IPLE~COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE.. Report results of multiple completion on W/ell Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ¢letalls, and give pertinent dates, including estimated date of starting any proposed work. We propose to re-enter the above-named well approximately October 8, 1977, t.~ complete the well for production from the Prudhoe Oil Pool as per the following progr~m: 1. Install and test 5000 psi BOPE. 2. Change well over to CaC12 brine. 3. Cement in 9-5/8" 47# N-80 tieback liner and PBR from 1840-2015'. 4. Tie back to surface with 10-3/4" 55.5# N-80 Buttress casing and 9-5/8" x 11-3/4" Thermocase II. 5. Arctic Pack 13-3/8" x 10-3/4" annulus. 6. Run 7" 26# N-80 AB-I~-4S '~ubing with 7" seal assembly to 7" PBR @ 9272'. A subsurface safety valve~with dual-encapsulated control lines will be placed at 2000'±. Diesel will be left inside th~ tubing and non-freezing fluid will be left on the outside of the tubing through the permafrost. 7. Install and test Xmas tree. 8. Suspend well for perforating subsequent to rig release. Details of proposed perforation to be submitted by Sundry Notice to follow. TITLE District Drillin$ En$ineer DATE. TITLE · DATE See Instructions On Reverse Side ~i~13roved Copy Returned ( B P A LAS KA ! N C. ;;,~.,,,,_o~ ;;,,.,.~;~.,. . ^,,,,=.o.,~,.,=. -,-,=.,.-.o,.,,~ ,,,o,, ,O'uly 18, 1972 Sga~e o~ Alaska Department of Natural Resources Division of Oil and Gas Anchorage, Alaska 99504 Attention: Mr. Homer L. ,urreZZ, Director Gentlemen: Alterations to BP Well Records In the process of checking and updating our well records, we have found a number of discrepancies between figures zeported to you and figures in our records. Because of this, we are now submitting changes to be made to your records. The following set of figures shows the depth at which conductor pipe was set. Many of the figures were omitted from Form P-7, Completion Report, submitted to you and a few are corrections: Put River #1 (13-27-11-14) J-3 (23-04-11-13) (13-1o-14) (14-10-14) (o1-1o-14) (02-10-14) (ll-10-14) (19-10-15B) B-2 (23-32-11-14) A-1 (42-35-11-13) A-2 (41-36-11-13) A-3 (44-27-11-13) A-4 (23-25-11-13) LA-5 ¢43-34-11-13) A-6 (32-26-11-13) N-2 (22-17-11-13) N-3 (33'18-11-13) N-4 (23-07-11-13) N-5 (34-06-11-13) N-6 (34-05-11-13) F-2 (22-11-11-13) F-3 (21-12-11-13) F-4 (12-01-11-13) F-5 (14-36-12-13) F-6 (14-35-12-13) H-1 (41-28-11-13) H-3 (23-22-11-13) H-4 (33-15-11-13) H-5 (12-16-11-13) M-2 (42-12-11-12) M-3 (43-02-11-12.) M-4 (22-31-12-13) 77' 85' 70 ' approximately 68' 70 ' approximately 75 ' approximately 75' 73' 107' 89 ' '. 99' 99' 99' 99' I 89 ' 86' 98' 95' 91' 99' 92' 95' 96' 97' 100 ' 103 ' 100 ' 100 ' 99' 99' '97' 97' JUL 2 ? 1972 DIVISION OF OIL AND GAS B P ALASKA ! N C. A-10870 May 3, 1972 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Homer L. Burrell, Director Gentlemen: P.O. BOX 4-1379 31 1 1 - C - STREET ANCHORAGE. ALASKA 99503 TELEPHONE (907) 279-0644 Well Number A'5 (43-34-11-13) Enclosed in duplicate are: Form P-7, the Completion Report for the above named well along with the Monthly Report for March; magnetic and gyroscopic surveys; well history; and logs (all 2" 1 sepia - 1 print). Very truly yours, A. K. Howard Manager (Operations) klm Enclosures cc: Operations Coordinator, New York F(,rm P--7 {~,j_ i ,~ SUBMIT IN DU'~-~ZArE* STATE OF ALASKA (See other In- structions on reverse side~ OIL AND GAS CONSERVATION COMMITTEE I WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* "1,. TYPE OF WELL: On. .~ S~S ~ ~ WELL~ WELL DRY Other b. TYPE OF COMPLE~ON: w ELL OVER gx hACK RE~VR. Other 2. NAME OF OYERATO~ ' Put River BP ~S~ INC. ~. wm~ ~o. ~. ,~zss o~ oP~,~o~ A-5 (43-34-11-13) P. O. Box 4-1379 (3111 C Streeg) ~qhpra~e.' Alamkm .9050! ~. LOC~T~0~ 0~ W~L~ (Report location c~earl~ and ~n a~cordan~e Wit~ a~y State requirements) ~.~e 923' ~L, 1896' S~L, Sec, 35, Tll~, R13E' ~ At top~~ 010803' ~(8820'T~)492.'. mL, 3100' SNL, Sec. :34, Ti~, R13E, ~M~ At total dep~ 011,370' ~(9348' ~D) 645' WEL, 2964' SNL, Sec. 34, TllN,. ~3E, I~.P~ITNO. ~M* *by gyroscopic su~ey 72-08 ,*. ~ sPuoO~ 1,4.DA~IT.D. ~~'fl~.;;~*~ CO~ ~uSP ~ ~. !:~. ~v..o** ,~., ..~, **, ~., ~"!:~.' ~. c.s:.~.**. March 14, 72 [April' 10,':72 [ April 15, 72[ KBE 65.89' ~L 1 46.1Y'' ~SL ~OW~Y* ROTARY TOOLS CABLE TOOI.,8 C~ ' ~ Total 11,370~ (9348~ ' ~ 1,316 ~ ~ Yes 5. APl NUIW, FA~CAJ~ CODE 50-029-20116 6. LEASE DEF~IGN}k~Io'N AND SERIAL NO. ADL-28287 7. IF INDIA.N, AJ.J.~TTEE OR TRIBE NAME 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe 0il 11. SEC., T., R., M., (BOTTOM HOLE Pool OBJECTIVE) Sec. 34, TllN, R13E, UPM TYPE ELECTRIC ANDOTHER LOGS'RUN Intermediate: DIL/SP (2277'-7213' BKB) 7" Liner~ CBL/GR T.D. Suite: DIL/SP,. LL'_3, BHCS/GR, FDC/Cal~ SNL/Cal~ . C.~SI-NG SIZE 20" x 18~" 7" [10.733':/. [ 11,360'I· ~85 Sacks ~o~t.'~ __ ~ ~Class 'G' 28. PERORATIONS O C~ ~~,[~z~ ~d number) CASn~G RECORD (Report all strings set in well) 133/96.5 18R/K55.~_ '68/47, N-80 '9~.14' i , LINEI% RECOHI) ,' HOLE SIZE CF~%ILNTING RECOlq~ ! AiVIOUNT PULLED 26" ,8700 Sacks Pa~afrnsg TI 12~" . ~. 1625~ Sacks Cla~s '~' ,, 525~ Smak~ P~rm~frn~t IT 27. TUB~G ~CO~ ~CID, SHOT, F~U~'U~, C~5[E:~T ~~, DIilPTt-I INT~V~L (MD) IANIOUNF ;dWD KIND OF M/k~RIAL USED DATE FIRST Pi%ODUCTION I rI~0DUCTiON METHOD (Flowh3.g, gas lif ~, pumping--size and tyDe of pump) [ Vv'ELL STATUS (Producing orshut-in) DATm OF T~ST. IHOU!qS TESTED '[CItOXE SIZE [PROD'N FOR OIL---BBL. GAS~IViCF. WA~q~iR--BBL. [GAS-OIL I%A. TIO OW, TUBING [CASLNG P~S~ ]CAL~~ OI~BBL. GA~. WA~BBL. [OIL GRAVITY-~I (CO~.) 1 [TEST WITNESSED BY 82. LIST OF TTAC M ~ S ~ ' ~ ' " " ' . L Deviation supers[ 1 nrint. 1 s~n~_. ~ . DTI./SP_ M,--3. ~CS/C~ '~/C~ ~l ;e-~ CB ,/~R 33. I hereby cert~y'th~e foregoing-and attac%ed ihformation is'compete and cbrrect *(See Instruction, and Space, [or Additional Data on Reverse Side) INSTRUCTIONS GeneraJ: This form is designed for submitting a complete and correct well completion report end log on all types of lan'Js and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attach~.'r~er'~ts. Items 20, and 22:: If this well is completed for separate prcduction from r'nore than one interval zone (multiple completion), so state ~n item 20, and in item 22 show the prcJucir~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produce,d, show- ing the ack. Jitional data pertinent t° such interval. Ire, m26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing "anct the location of the cementing tool. Item 28: Submit a Separate completion report on this form for each interval to be separately pr'oduced. (See instruction for items 20 and 22' above). ' 34. SUMMAII¥ O1~ POI!MATION T~_,S'I'S IN('LUI)IN(; INq'EI'tV^L T~qTED. I'IIE~SIJI1E DATA ~'~COVERIF~ OF OIL. GAS. 35. G~GIC MARK~ WAT~ AND MUD Sub-Se _ "Top Coal" 4302' 4091~ L. Cret. Unc. 9524' '-.7661~ Sag ~ver (BP) 10,803' 8754~ Shub lik Fm. 10,828 8777' .......... ' ' ' ........................ ' ~ '"' ...... Sadlerochit ~ 10,909 ' 8852 ' ....... . . .. %y gyroscopic s u~ey , ., WELL HISTORY A'5 (43-34-11-13) llar'ch, 19 72 DIVISION O.~ ~->u._ ... ,.*;',?r ,., ~... .... ANCH¢~'~, .:, C ' Spqdded well at 0230 hfs;i, 'March"l~,1972. Drilled ~7~" ~o 2326 ft. ~ened hole to 26" to 2326 ft. ~n 19 joints 20" 133 lb/ft K-55 ~round casing and 4I joints 18{" 96.5 lb/ft. K-55, buttress casing. Shoe set at 2278 ft., crossover at 1517 ft. 1~" tubing strapped to 18{" casing to 1492 ft. Cemented ~th 250 sacks Pe~afrost II cement -~ 0.3% WG-7, Slur~'weight 14.3 ppg. Followed ~th 7250 sacks Pe~afrost II ~th the slur~ wt. at 14.8 ppg. ~n' two strings 1~" ~ing to 183 ft. and tagged top of cement. Cemented' to surface '1200 sac~ Pe~afros= II~ slu~ weight 14.8 ppg. Nippled' up and tested' 19. - 31 . Drilled 12~" hole directionally to 9822 ft. Conditioned Role:and ran logs. Ran 193 joints 9{",' 47 lb/ft, N-80 Buttress casing' and 51 Joints ..13at'', 68 lb/ft, N-80 Buttress casing. Shoe Set at 9814 ft., float collar at 9770 ft., full opening cementers at 2146 ft., and 2065 .ft.., 13]" x 9~" crossover at 2015 ft. Cemented with 775 sack~"class'G" cement with 101 gel and 1.251 CRF-2, slurry wt., 12.8 ppg. This was followed by 250 sacks class 'G' cement with 1.251 CFR-2, slurry ;15'.8 ppg. Displaced With 880' bbls mud. Top of first stage cement .at :5484 ft. '' · '~rtl~ 1972, 1-5 Carried out second .stage squeeze' cementation with 600 sacks Class 'g' cement with 10I gel and 1.25I CFR-2, mix water' with Ray Frac. Slurry weight 12.8 ppg. This was-followed by 425 sacks Permafrost II cement with 5 lbs, of pozzolan per sack of cement. Slurry weight' 14.8 ppg. Displaced' drill ~i~e, .13l." casing and I3{" x 18{/20" annulus to water. Swabbed' casing, cement Job not holding. Sandline parted amd dropped sinker bar and fluid locater in hole. Ran overshot and recovered fish. Circulated to clean 13{" casing and 13~" x 18{/20 annulus. Placed 100 sacks Permafrost II cement with 5 lbs pozzolan between lower and upper full opening cementers; Reverse circulated through upper full opening cementer. Tested squeeze job. Swabbed' hole clean and pumped a total of 320 " bbls residual oil into annulus. Closed cementer and tested. Ran in hole drilled float collar, aement and shoe and drilled ahead to 9962'. . 6 -,10 Drilled ahead to TD at 11,370'. Conditioned hole and ran logs. Ran 48 Joints 7", 29 lb/ft, N-80 Buttress casing shoe at 11,360', landing collar at 11,.314' and top of marker Joint at 10,733', liner hanger at 9318', Liner packer at 9312' and top of the back receptacle at .9272'. Pumped 10 bbls water, 10 bblS MF-1 with Moreflo and 10 bbls B-J mud sweep. Cemented with 485 sacks Class 'G' with 1.251, CFR-2 slurry weight 15.8 ppg. Displaced drill pipe and liner with a total of 240 ~bls. mud. Set liner packer. Circulated out 10 bbls. excess cement and 40 bbls. contaminated mud. Tested liner lap satisfactorily. Displaced hole to fresh water followed by 26% CaC12 completion fluid. . . Laid down drill pipe. Ran in to 2000' and-displaced to diesel. Removed BOP's and installed and tested wellhead cap. Rig released to ll00 hours April 15~ 1972_. y. FOR B P AL~,SKA~ INC. rfPZ OF SURVEY' GYROSCOPIC~LTISHOT SURVEY DEPTH: FROM S,~z'face , ,'.~FT. TO ~.A~£:, (4~'34-!1-13) 11,370 WELL NO. A-5 FIELD: PRUDHOE BAY NORTH SLOPE COUNTY/PARISH STATF AI~S~A. ' DATE OF SURVEY April 189 1972 ~OFFICE: Anchorage~ A~a ska -,oB NO. SU-3-16739 SPERRY~suN ~,~ELL suRVEyING COMPANY ANCHORAGE~ ALASKA !., P_ A.L~A. SKA, INC. DATE OF SURVEY 17 APRIL 1972 .,?,--5 (~-3,~-i l':'i:3'"~-'~! .................................................................. ' COMPUTATION DATE S'UR~'EL'- GYR°SC°P PRUDHOE BAY, 21 APRIL 1972 JOB NU~,IBER SU-B-167Bg TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL ' ;'~ EAS UB ED .......... ~. ER.T !C,Ak ............. VE PTI CAL ........ INC L ! NAT. I ON,...,,Q !~B.E C TI_ON ............ SEVEB I.T.~_~.L._ R.E C.T.6.N_GU..L.AB O~EPTH DEPTH DEPTH DEG MIN DEG DEG/100 NORTH/SOUTH EAST/WEST SECTION .. .... o ... o,oo - s,89 o o s o E..- o.oo. o,oo o,0o. __.,_.. o 200- 199.99 1~.10 - 0 15 S 52 E 0.09 0.29 S 0,41 E -0.34 ~00 399.99 33~.I0- 0 10 S 19 W 0.18 0,'77 S 0,73 E -0.56 500 499.99 z>34.10 0 25 S" 59 W 0,'.31 1.10 :S 700 699.99 63~.10 O- 20 S 69 W 0.0~. 1.58 S 0.75 ~ 1.06 800 799.99 734.'10 0 15 S 60:W 0.10 1.79 S 1.21 W 1.56 ............... 9 O0 ................. 899.99 .............. 8~-.!.0 .......................... 0...': ......... ! 5 .... S.' .... 70,...:W.] ........................... g-..~6 .................. !.~9_8_....~...~ ZOO0 ~99.98 93~.0.9 0 20. S 82 ~' O.ZZ 2.09 $ 1100 1099.98 1034.09 0 25 N 72 W 0.19 2.02 S 2.73 ....... z~oo ............ zz99.98 ........... zz3~.o9 .............. o .......... 25.., N ..... 8x,,W ...................... o)o7 ........................... ~,.85 .... s ......................... 3..,~3..,W ............................. 3,75 ..... 1300 ~299.97 ~23~.08 0 s5 N 62 U' 0.23 1400 1~99.97 1~B4.08 0 25 N 54 W 0.18, 1.10 S 4,99 W' 5.11 ............ 1500 ......... 149 9.97 ............... 1434,,.08 ................ ~ .............. 2 5 ...... N ....... ~7 ..W .......................... 0...1 & ................... 2800 2900 3000 · 3100 I600 1700 1800 1900 2000 2100 2200. 2300 -- 2z~O0 2500 2600 2700 1599.96 1534.07 0 30 N 15 W 0.19 0.10 N 5.83 W 5 ~,~ 1699.96 1634.07 O- 35 N 6 W 0.12 1,03 N 6.00 W 5 ,~ 1799.95 1734.06 0 40 N 23 E 0.32 2,07 N 5.82 W 5-.26 1899.95 1834.06 0 45 N 17 E 0.12 3.24 N 5.40 W 4.61 1999.9~ I934.'05 0 25 N II E 0.34 ~.22 N 5.I4 W 4. I5 2099.94 2034.05 O' 10: N 73 E 0.37 4.62 N 4.94 ~ 3.86 2199.94 2134.05 0 20 N 5~ E 0.18 4.83 N 4.56 W' 3.45 2299.92 2234.03 1 35 N 3 E 1.39 6.38 N 4.25 W 2.83 2399.87 .... 2333,98 ......... 1,_", ..... 45. N._ . 1..,,E ....................... 0.18 ................... 9-29.N ...................... ~..1.5,.W ....................... 2.1~ 2499.8~ 2433.95 1' 5 N 24 W 0.89 11.68 N 4.51W 1.91 2599.74 2533.85 ~ - 30 S 47 W 4.95 9.87 N 7.77 W 5.54 2699.02 2633.13 9 0 S 49 W 4.50 2.05 N 16.54 W 15.75 2797.53 2731.64 11 10 S 77 W 5.29 5.25 S 31.89 W 32.2') 2895.17 2829.28 13 40 S 79 W. 2.53 9.68 S 52.92 W 53.7~ 2991.99 2926.10 15 15 S 78 W 1.60 14.67 S" 77.39 W 78.74, 3088.0.4 3022.15 17 ' O. S 79 W 1.77 20.19 S 10~.60 ~ 106.5.{. SPERRY-SUN.. WELL SURVEYING COMPANY PAGE ANCHORAGE, ALASKA P ALASKA~.. INC.. . .............................................. DATE,..OE ...... SU.R,VE¥_!7..,APRIL .... 197.2 ,.--5 (4~~34-11,'1.3) CO~PUTA'TION DATE SURWEL GYROSCOPIC MULTISHOT SURVEY' ::'~'~UDHOE BAY. 2I.:.~APRIL I972 JOB NUMBER SU-3-I6739 ~.~ LA S K A ........ (BKB) : KE LLY.,B. USH!..NG,....E.L E V.- : ....... .6.5,' 8,.~._.,F.][, "0" POINT AT INCLINOI~TER & KBE TRUE SUB-.SEA COURSE COURSE DOG-LEG TOTAL ,cASU~..ED ......... VERT I CAL ............... Y.E,~T,I CAL ....... INCL INAT IO.N._.D. IR. ECT!O,N .......... S..E.V_ER_~_T~,,.~._.~EC?ANGULAR_ .....~OO~Q_I,.N~_T_~.,S ............. ;.)~2PTH . DEPTH DEPTH DEG MIN DEG DEG/IO0 NORTH/SOUTH EAST/~EST .: SECTION 3200- 3183.34 3117.45 18 15 S' 80 W.. 1,28 25.70 '.'S 131..37 W 136, ~00 ~71,92 ~306.0~ 20 50 S 82W 1.5~ - ~6.08 S 200.10 W 20~.22 3600 3556.88 ~490.-99 2~ 0 S 84 ]W 1.91 ' 45.95 S 275.43 W 278,95 3700 36~7.63 3581.74 25 ~0 S 85':W 1'71 ~9.96 S 317.23 W 320,67 3800 ................ 3736.77 3670.88 ...................... 28 ................. 10 S _,._,.,85 W ,]: ............................ 2.50_L ..................... 53.90,....,S .................. 362~.32,_,,W...,. .......................... 365,.59 ...... 3900- 3824. I5 3758.26 30 0 S 85 W .I'83 58.I4.S 410-73 W ~I3.82 40.00 3909.97 3844.08 31 45 S'" 84 W' 1.82 63.07 S 461',80 W 464.80 .......... 41.00 ............... 3994 -0 6._' .......... _3928, !72 .................. B~ ............... ~ 5 ....... S ........ 85.....W_ ......................... ~_2.,.Q.7_..' ............... _~.8.._2 ~_~.S_ ................. 515_,_~ ~_._ W ..................... 5.! 8~5.B _.~ 4200 4075.96 4010,07 ~6 15' S 85 W' 2.50 78.24 S 572.77 W 575.44 4300 4155.25 4089.36 38 50 4400 4232.50 ....... ~I66.61 40 0 4500 4308.25 4242-36 41 30 4600 4383°05 4317. I6 ~' 4I 45 4700 4457.96 ........... 4392.07 ............... ~I ...... I5 4800 4534.33 4468.44 39 4900 4612.74 4546.85 37 5000 4691.04 4625.15 39 5100 4766.51. 4700.65 42 5200 4839.07 4773. I8 44 5300 4.908.63 ...... 4842.71, 47 5400 4975.32 4909.43 5500 5040.82 4974.93 .5600 5106.I5 5040.26 . 5700 5171.37 5105.48 5800 5236.31 5170.42 5900 - 5301.26 5235.37 6000 5366.26 5300.37 6100 5431.26 5365.3.7 6200 5496.59 5430.70 6300 5562.58 5496.69 ..S 88 W' 3,16 76.91 S 633,57 W 635.67 $ .... '90 W.' ............... 1'72 ............... 78,01.,. S ................... 697.04~..,,w ..................... 697.97 ....... S 89'W 1'63 78.58 S 762.31 W 761.92 S' 81 W. 5.31 84.37 S 828.37 W .. 827.73 .. S ...... ?7...W i ......................... 2..69 ............... 97., O~__S..~ .............. 893_._._39__W .............. 15 S 69 W 5.53 115.77 S 955.09 W 35 S. 60 W 5.83 142,38 S 1011.08 W 1018, 20 S 61 W 1.85 172.99 S 1065,21 W 1077.85 35 S 6I ~' 3.25 204.'76 S ii22.53 W II40.55 25 S 62 W Io95 237.60 S 1183.02 W i206.56 25 S 62 W 3.00 271.32 S I246.1.1. W I275.62 48 55. S 49 15 S 49 10- S 1.9 25 S 49 35 S 49 25 S 49 30 S 49 25 S 49 0 S 48 25 S 64 65 W' 62 W 64 W 1.53 405.82 S 1516.29 W 65 W, 0.78 438.56 S 1584.92 W 68 W 2.28 468.87-S 1654.62 W 69 W 0.76 496.72 S 1725.33 W 70 W' 0.76 523.33 S 1796.51W 71 Wi 0.86 548.61S 1867.87 W 70 W. 0.95 573.68 S 1938.69 W 'W ' 2.11 305.12 S 1312.82 W 1347.59 0.82 337.65 S 1381.02 W 1421.08 2.27 371.42 ....S ........ 1448,75 .,.,W ............. 1494.37 1567.60 1641.55 1716~05 1791.01 1866.1'7 1941.24 2015.75 SPERRY-SUN WELL SURVEYING CO~PANY PAGE 3 ANCHDRAGE~ ALASKA :. P_. ALASKA,..INC DATE.._.O~...SUeVEY .....17..~APRIL ..... 197_2 <?5 {4~3.4-11.13) COMPUTATION DATE SURUEL GYROSCOPIC NULTISHOT SURVEY . ?RUOHOE BAY. 2I .'APRIL i972 ,JOB NUMBER SU.3-I6739 /~LAS.KA ......... (~KB) ~ KELLY BUSHING Et. EV. ~. ...... "0" POINT AT INC~INO~TER & KBE TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL i<!; E A SUg ED ...... 'V E RTI C AL ............... VE RTI C A L ......... I NC L I N A T! ON.,...D I R E CT. IQ N ............. ~,E VE RI ,T.. ~_ ....... _RE C,%A~.} GULAR ..... C.O.~.EO I.N 6,%.E.~ .............. .Y.E ~ T.I.C.A L OEPTH DEPTH DEPTH DEG MIN DEG - DEG/IO0 NORTH/SOUTH EAST/WEST SECTION . 6500 569'7.0'5 5631.16' 47 5 S' 71 :W' 0.99 623.71 S 2078.02 W 2162, ~ 6600 5764.33 5698.44 . 48 20 S 72 W 1.45 647.18 S 2148.16 W - 2235.93 ......... 67 00.: ............. 5829,4.3 ................ 5,763, 54_~..' ................ 50 .:: ............ 2 5 ......... S .~2~.:7.1'.=iW ........................ 2,21 _~i ................. 67!' 2.71 .S ............. .2220.-.12_.W.,..Z_ ........ 2311,. 3.3 6800 5891.96 5826.07 52 10 ' S 72~W~ 1.91 696.01 S 22'94,11 W 2388.86 6900 5951'.72 5885.83 54 25 S' 72 W 2.25 720-'78 S 2370.34 W 2z~68.58 7'100 6067.92 6002°03- 54 10 S' 72 W' .0,95 769.73 S 2525.58 W 2630-62 7200 6127.11 6061.22 53 15 S '72'W 0.91' 794-63 S 2602.23 ~ 2710-79 ........... 7300 ............. 6187,29 ............ 61.2.1- 40 .................. 52 .............. 45 ........ S.j.... 7. I_. W ............................... 0,9,~_~ .................. 819,.97__S ............. 267_%:97_._W .............. 279 0,.1_4.,__~ 7400 7500 7600 7700 7800 7900 8000 8100 8200 8300. 8400 8500 8600 8'700 8800 . 8900 9000 9100 9200 9300 9400 9500 62:~8oll 6182,21 52 20- S 71 W' 0.42 845.81 S 2753.02 W 2868.93 6309.56 6243.66 51 50 S 71 W' 0-50 871.50~S 2827.61 W 2947.24 6371,69 ........... 6305-80 ..... 51 .. 20.-- S .... 72 W ................ 0,93 ......... 896~36,. S ................ 2901.91,.W./ ............ 3025.09 6434.62 6368,73 50 40 S 71 N 1.02 921.02 S 2975,61 W 3102.31 6498.56 6432.67 49 50.- S 70 W 1o13 946.67 S 3048.08 W ~' 3178.5~ 6563.62 ..........6.49~°73 .............. 49 ................ O__.'..S ..... T1 W ......................... !,12 .............. 9.720.03 .... $ .............. 3119,66_..W ............ 3253084 6629.55 6563.66 48 30 S 71 W 0.50 ~ ~96o51 S 6695.92 6630'03 48 20- S 72 W 0.76 1020.24 S 6762.67 6696.78 47 55 S 73 W 0.85 1042.63 S 6830.01 6764.12 47 25 S 74 W- 0.89 1063.63 S 6898.21 6832.32 46 35 S' 74 W 0.83 1083.79 S 45 45 S 73 W 1.10 1104.27 S 6971.82 45 0 70~2.89 44 25 ._7114.72_ _ 43._. 45 7187.20 43 20 7260.29 42 45 6957.46 6901.57 7037.71 7108.78 7180~61 7253.09 7326.18 7399.66 7473.92 7549.86 7627.85 7707,49 S 7~ W 1.03 1124.48 S 3611.26 W 3766.44 S 741W 0.58 1143.88 S 3678.88 W 3836.62 S". 73.W ....................... 0.96 ..... 1163.63 .S [ ......... 3745,59,_..W .............. 3905.98 S 73 W 0.42 1183.77 S 3811.46 W 3974.61 S' 74 W 0.90 1203.16 S 3876.90 W 4042.65 .... 40'. S...76.'W.] ................ 1.36 ........... 1220o71.S ...........3942.41_W ........... ~110,38 - . 25 S 77 W 1.41 1236.35 S ~007.52 W 4177.3! ~5 S 79 ~ 2.11. 1269.89 S 4071o13 W 4242.3'~ S _ 82'.W ....... 2.74 ........1260.25 S ..... 4132.84 W ............ 4304.~ S' 82 W. 1.08 1268.67 S 4192.72 W 4365.1;: 7333.77 42 7408.03 41 7483.97 39 .7561.96 37 .... 45 764Io60 36 ~0 3190,75 W 3328'47 3261.68 W 340: '~ 3332'69 W .............. ~476~2 3403.56 W 3550.61 3473.86 W 3623.57 3543.Q3_W ........... 3695..49 · SPERRY-~SUN ~tELL SURVEYING COMPANY PAGE ANCHORAGE=, ALASKA P ALASKA,. INC. . ............................................ DA.'TE_._OF_..SURVEy ...... 17.__APB! L _~9.~_2 .'~--75 {%~-]4-11-13)' CO~IPUTATION DATE SURWEL GYROSCOPIC MULTISHOT '~RUDHOE BAY 21 APRIL 1972' JOB NUMBE~ SU-3-16739 'TRUE SUB-SEA COURSE COURSE DOG'LEG TOTAL ;~'~ ~] AS UR ED ....... YERTI C.A~ ............. V_ER T! CAL ........ I~!CL I NAT.I ON__DI._RECT !oN ............ S E V ER.I.TY..Z_. REC~ ANGU L.A.~__]C.Qg_~D_!.~.~ T.E ~ .......V~ R~T_I.Q~ L .... ~' ~L') E P'T H DEPTH DEPTH DEG ~IN DEG -- DEG/IO0 NORTH/SOUTH EAST/NEST: SECTION 96 O0 ............... 778 8..,43 ..................... 7722"i 5...z+ ..................... 35 ..................... 15 ............. S,.' ....... 83.?.,.,W ..= .................................. 1 '..53_: ............... !.2. 76' 3..zt..__S ................. ~250 ~':;93...,.~_. ......................... : .z+42.,~.; 9'700 9800 . ............. 9900, 10000 10100 10200 10300 7870.51 7804-62 34 25 S 86W' 1.90 1281,'83 S .4307.76 W 4480. 7953.69 7887.60 33 25 S 86~ W' 1.00 1285.72 S 4363o%2 W 4535.68 .............. 8036,80._: ......... 79~ 0,91__; ................... 33 ..... ] ........... 45 .......... S_..' .... 8.7.L.W...~ ................................. 0 ,.6~..Z ............ 1289'.-.09_.__.S.._.] ......... :_=$).~ 1.8_, 63._W__. ......... ~ 59.0.,_38__~: 8120018 805~.29 33 15 S 88 W: 0-74 1291,51 S 4473.77 W 4644.81 · 8204.17 8138'28 32 30 N 88 ~' 2.29 1291.52 S 4528.01 W 4697.86 8288,82 ............ 8222,92 .............. 31 ................. 50 ...... N ....... 86., W.~ .............................. 1,25 ................ 1288.75 ..S .............. ,4581,.17 L,W .................. ,47~,9, 27 8374.17 8308.28 31 ' 0 N 81 W' 2.73 1282.88 S ~632.92 W 4798.65 10%00 8460.33 ...... 10500 ............ 85~7o53 10600 8635.95 10-/00 8-/25.-/6 10800 8817,09 10900 8909039 11000 9002.16 .... 11100 ........ 9095. 11200 91880 11260 9245. _ 11370 ...... 9368. 839~o%4 30 O-N 77 W' 2026 1273.23 S %682.71'W 4845°33 8481.6~ ................ 28- 35 ...... N ........ ~3__~..= ........................... 2,5! ........ ] ...... 1260,6!._S ................ 5.729.~..95_._..~ ........... 58..8~.~.0__. 85.70.°06 27 10 N 67 W 3.14 1266.69 S 4773.8.5 W 4928.51 8659.87 25 0 N 63 VI' 2.78 1226°'17 S 4813.70 W 4963.61 8751,'20 ....... 23 .......... I0,,. N ..53 Wi .................... 6,46 ......... 1204,73 .... S .......... ~848,.26,...,W .................... %992,93 ...... 8843.50 22 5 N 52 W" 1.15 1181.32 S 4878.78 W 5017.89 8936.27 21 45 N 69 W 1.16 115'7.59 S 4907.57 W 50~1.10 33 ............ 9029,44' 20._.: ......... 50 .... N. . Z~8. VI ....................... 0°.98 ........... 1.133.5Z+__S ............. 4934.,.7.7__W ................. 5062.°_68 92 9123.03 20. 25 N 46 W' 0.81 1109.52 S 4960.53 14 5082.86 18 9179.29 20 15 N z+5 VI' 0.64 109~+.91 $ 4975°%0 W 5094 > 4% ...... 9282.55 .......... 20 ...... 5. ,. N z, 3 .VI ................. 0.64 ......... 106.7.64. S ............ ~500!.'77_~....W ................ 5.112t,:'.~2 ..... HORI-ZONTAL DISPLACEMENT : 511%.%Z FEET AT SOUTH, '/7 DEG. 57 MIN. WEST .... ~'E ...... C-~-[CULAT~-O-N- P-R~'CE-D-O-R~S'" ARE" 6~S"ED-'~N THE'-'U~E- O-F" SPERRY-SUN ~ELL SURVEYING COMPANY PAGE ANCHORAGE~ ALASKA .. ..B..P].ALASKA, INC DATE OF A-5 (~-~'4-11-.1~) COMPUTATION DATE SUR~EL GYROSCOPIC MULTISHOT SURVE PRUOHOE BAY 2I APRIL I972 JOB NU~qBER SU-~-I67~9 "0" ~OIN~ INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASURED VERTICAl. VERTICAL RECTANGULAR COORDINATES '~ MD-TVD VERTICAL ......... D,'E ?? H DE P,?H ...................................... D E-P_T H ........... NOR TH/SOUTH ........... E AS?/_,.WE ~oo~Oo.oo-~,.~ o,oo 0.01 ~ooo ~.~ ~,-~.o~~.~ ,~.~ , o.o,. o.o~ 5000 ~691.0~ 4625.15 172'99 SV 1065.21 .W ~ ~08.95 218.g~ 6000 5366.26 5300.37 696,72 'S~ 1725.33 ~ 633.73 324.77, 7000] 6009.73 5g~3.84 745-'27 $~ 2448,02 W~ 990.26 356 '5 8000 ~2~'.'~~ ................ 0~3'~ ~96.~ s ~ 9000 7B26.18 7260.29 I203.16 S~ ~876'.90 W ~ 1673.81 ~OB.~7 ~0000 ......8~20.18 .....805~.29 ................. ~29~.~ s~ ............ ~oo° 9oo2.~a- 89~a.z7 ~ ~57.'59 s ~'~--' ~9o7.57' w-~ 11370 93~8,4~ 9282,55 1067..6~ S ~--5001.7~ W 2021,'56 23,72' ....... TH E "'C AEC u~A ~N'-'~'R'6~'~'UR-~'S' --'AR E- B ~s~ D-6N' -T HE"---O-~'-~'-'-O'~"'~'~'H-~-E~--~I-~-E N-~'i ~N'A'~' 'RA'D'~' U $'"'"~F"--~-~'R'~Y'~ ~-~ ' ~iE'T ~'~ ...... ~- ..... ............................. SPERRY~'SUN '~tELL sUR'vEYING CO~!PANY i ANCHORAGE, ALASKA 3 P ALASKA , .. I NC ........ DA'[E.OF SURVEY 17...APR!L 19'72 A-5 (4~-34~-11-13) COMPUTATION DATE SURWEL' GYROSCOPIC MULTISHOT SURVEY PRUDHOE BAY 21 APRIL 1972 JOB NUMBER SU-3-16739 ALASKA (Bt(5) KELLY BUSHING ELEV. = 65.89 "0!! POINT'AT INCLINOMETER""& KBE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUS-SEA DEPTH TRUE SUB-SEA TOTAL ;~.~EASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL O. EPTH : DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION ' 0 0.00 -. -65'89 0-00 0'00 0.00 - ................ 6.5. .................... 65.88 ............... ' ..... ~0.00 ....................... ~ ...... 0-02 S ............................. O-.O~_::E ............................ 0.00_: ............................................ 0.00_..- .......................... ] .......... 165 165,89 100-.00: 0.20 S 0.29 265 265.89 200.00 0,46 S 0'61' 365 .........365.89 ......... 300.00 ............................... 0o68:S ........... 0.77 465 465'89 400.00' 0.97 S 0-59 565 565.89: 500.00 1'32 S 0-01 ................. 665 ............. 665,._89 .........600.00 ......................... 1.'51..S ..................... 0-.56. 765 765.89 700.00 1.72 S- 1,'08 865 865.89 800.00- 1.92 S 1.46 965 ,. , 965.89 ....... 900.00 ............... 2.06. S ....... 1.90 1065 1065.89 1000.00 2.10 S' 2.49 11.65 1165'89 1100.00 1.89 S 3.I9 E 0,00: 0.00 E 0.'00 0o'00 -- E ....................... 0..00. ~ .................. 0 ..00. ': E 0.00 0.00 W ' 0.00 0.00 ~ ............................ O. 0.0....:~. ............................... 0,.0_0 ._~ W 0.00 0,00 W 0o'00 0-00 · W ...................... O. 01 .......................... O. O0 W 0.01 0..00 W 0.01 ' 0.00 ............ 1265 ......... 1265.89 .............. 1 1365 1~65.89 1 1465 1465.89 1 1565 1565.89 1 .. 1665 1665.89 1 200..00_ ................... l. 72__S .................. 3.. 9~...W ......................... O. Ol ' O.OQ ............................................. 300.00 1.25 S z~.79 W 0.02 0.00 400.00 0.80 S" 5.35 W 0.02 0.00 500.00 ................ 0..17 S ........ 5.75..W .................... 0.02 600.00 0.69 N 5.96 W. 0.0~ 0.00 1765 1765.89 1700.00 1.71 N 5.98 W 0.03 0.00-- 1865 ........1.8_6.5: 8.9. ........... 1.80.0 ._00 ............... SPERR¥'-SUN''WELL S'URVE¥ING CoMPANy pAGE ANCHORAGEt- ALASKA ~ P ALASKAt .INC. . ............................ D.ATE...OF .SURVEy_~Iy.._.~AP.RI_L ..... 1972 i--5 (~-~-11-13) COMPUTATION DATE SURWEL GYROSCOPIC MULTISHO'T SURVEY ~)RUDHOE BAY 21 'APRIL 1972 JOB NUMBER SU-3-16739 ALASKA (B~B) ..... [ KELLy.,,~ BUSH I NG,~. ,,E, kE..V ~ ,_: 65'_89,_.. [,Y_~ "o" Point A~ Inclinometer & I NTERPOLAT'ED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL ?~EASURED VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL -x 1965 1965.89 1900.00 3.98 2065 ......... 20.6,51'.89 ............. 2000. O0 2165.89 2100o00 4,71 2265°89 2200-00 5.44 ....... 2365°89 ................ 2300.00 ............................ 8.25 2465.89 2400.,00 11,.'09 2565°89 2500.00 11.24 266.5' 89 .............. 2600.00 ............................ 5,,. 19 2765°89 2700.00 3.51 2865.89 2800.00 8.32 2965.89 2900.00 13° 19 3065.89 3000.00 18~90 3165.89 3100.00 24.70 3265.89 ......... 3200.00_= .................. 30.B5 3365.89 .35.76 3465.89 41"24 3565.89 . 3665.89 50.72 3765.89 55.26 ......... 39.~8 ...................... 60 2'165 2265 2365 2466 2566 2666 2767 2869 29"72 3076 ' 3181 _ . 3287 3393 3501 3609 3720 3533 3865.89 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 N 5.19 W 0.05 0.00 N ........................ :...5 o 0 3..:W_L .............. O. 0.5. ....................... N 4'72 'W" 0.05 0-00 N 4'30 ~W 0.06 0.00 ..N .............................. 4 -17_ .:'N.. :_.,; ............................ 0-.10 ............................................... 0 . N 4'25 W .. O. 14 0.04 N 6.13 W ' 0.18 0.03 N ........ 12'96__W.: ........................ 0.63 ..................................... 0..4.~. S 26.21 W 'l.gl 1.28 S 45.94 W' 3.97 2.06 .S ...... 70.42 W ........................ 7.05 ........................... 3.07 S 97.95 W 10.93 3.88 S 128.70 -W 15.72 4.78 S '. ..... 161.9.4....W_ ....................... 21.. 2.6 .............................. 5. S 197.82 W 27.65 6.39 S 236.84 W 35.14 7.49. S . , 279.42, W ................43.96.1 ................. 8.82 S 325.97 W 54.36 10.40 S . 377.85 W 67.13 12.76- ............................... S .............. 434. 88__ W__: ........... 8.2__? 3._? ................. .!.5.24 ELL SURVEYING Co mAN¥ ", ANCHORAGE, ALASKA P ALASKA~ INC~ DATE.OF. SURVEY l~..APRIL_.1972 ',,5 {~-34-11.13) COMPUTATION DATE SURWEL GYROSCOPIC MULTISHOT SURVEY ;~UDHOE BAY 21 APRIL 1972 JOB NUMBER SU-3-16739 · ~LASKA (B~.B) KELLY BUSHING ELEV. : 65'89 FT. .... TRUE SUB-SEA 'TOTAL ~,';EASURED VERTICAL VERTICAL RECTANGULAR-. COORDINATES MD-TVD VERTICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 4066 3965-89 3900.00 - 66.60 ~'S' 496"89 W 100.22 17,.84 ............... ~,187 ............... 4065::~' 89 ................. 4 O00,_O0 ............................. 72, 6.0,.:':S .ii .................. 565,41.,.,]W .................... i,_1,2,1,,,62:'Z ......................... 21, .3_~_;] 4313 4165.89 4100.00 ' 77,21 .S 6~2,1~ W' 147.76 26.1~ ~4q3 4265.89 ~200.00 78'0~ S 725.12 .'W 177.'7~ 29.96 ~57'? .......~365._89 ........ ~300. O0 ............... 82.25 S ....... 813.. 23 ~_W ...................... 211..12 ................................... ~3,38: 4465.89 4400.00- 98.64 S 900.08 W, 244'61 3~.49 ~565,89 4500-00 125.61 S' 978.5~ W 274.6~ 30.01 ........ ~66 5. 89 ..................... ~.60 O, O0 ............................. 163. O0._S ............... 1047 ,_18__.N ............ ] ......... 30.!, ~5_9 .................................. 2~.., 95_ ~700.00 204.47 S 1122.01 U 333.22 ~1.62 4710 4840 49~7 5099 4765..89 5Z~7 4865.89 .4800.00 250.18 5~85 4965,89 4900.00 300.3'7 5538 5065.89 5000.00 349.94 569I 5165.89 5100.00 403.02 5845 ....... 5265.8.9 ...... 5200.00 -. ........... 453.13 5999 5365.89 5300.00 496.57 6153 5465.89 5400.00 537.05 6304 5565.89 5500,00 574.96 645~ 5665.89 5600.00 612.75 S 1206,,70 W' 372.03 38.81 S, . 1303.09~.,W ................. 419.,74 ............................ 4,7..,71 S 1407.39 W 472.51 52,76 S 1510.53 W 525.68 53.16 S ...... 1616.42... W ................. 579.?1 .......................... 5_4.._ 03 S' 1724o92 W 633-53 53.82 S 1834.45 W 687.28 53.74 S 1942.20. W ........... 739..07 ...................... :5t.81 S 2046. BO W 788.31 49.21 6602 5765.89 5700.00- 647.72 S 2149.82 W 836.44 -' 48.13 675.1 ........ 5865:.89_ ........... ~_8.00-.00 ................. 685..64_ S ........ 226_2725__W. ........... 89!__-_ 65_ .............. _5._~., 20 ................................... SPERRY-~SUN~ WELL SUR-VEYING COMPANY ANCHORAGE~ ALASKA ALASKA, _ INC., OATE.,OE,._SURVE¥_. 17 .A.P.R.I L ..... 1..9_72 ............................. J~3/~-ll-13J COMPUTATION DATE SURWEL GYROSCOPIC MULTISHOT SURVEY ?RUDHOE BAY 2I .APRIL 1972 JOB NUMBER SU-~-I.67~g LLASKA (BZB) KELLY BUSHING ELEV. : 65,89 "O" POINT AT INCLINO~TER"-~"KBE '". ...................................... I NTERPOLATE~ VALUES FOR EVEN 1OO FEET OF SUB-SEA DEPTH- TRUE SUB-SEA TOTAL . ....................... ~EASURED VERTICA[ VERTICAL - RECTANGULAR COORDINATES ' MD-TVD VERTICAL ~>~ EPTH . DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 6924 5965.89 5900.00 ' 726'90 :S 2389.17 W 958.45 66.80 7096 ....... 6.065.89 .............. 600.0..00 .................... 768,,86_._S,..] ......... 2522.90.],,W_L ............... 1.030~63 ......................... ~.2.,,.18_':~. ..... ~26~ 6165.89 6100,00 :. 810,'81 'S. 2651.36 'W 1098.75 68-11 . 7-4'29 6265'89 6200.00 853.31 S 27.74.80 W 1163.20 6~.45 7.590 ,: ............... 6365. 89 ................. 6300. O0 ........................ 89~. 12_S 2895. OI_...W~.~ .................... 1224. 81 .................................... 61~.~.60 .............................................................................. 77~9 6465.89 6400-00. 933.46 S 3011.56'W. 1283'35 · 58.53 7903 6565'89 6500.00 972'88 S- 3122.13 W 1337.56 54.21 .... 805~ ...........6665.89 ....... 6600._00 .................... 1.009.77 _._S ............... 3229. 58 ._W .................. I3 88~_92 ............................ _51 -.3.5_ ....................................... 820~ 6765.89 6700.00 10.63..67 S " 3336.09 W 1438.90 49.98 8352 6865.89 6800.00- 1074.35 S ~440.95 W" 1487,02 48.1I 8497 ..... 6965.89 ....... 6900.00 ....... 1103.79 S 8639 7065.89 7000.00 1132.25 S 8779 7165.89 7100-00 1159.51S 8917 ......... 7265.89 ............ 7200..00 ................. 1187'30 S' -. _ 9054 7365.89 7300.00 1213.11 S 9189 7465.89 7400.00 1234.75 S 9320 .... 7565.89 7500.00 ...... 1252.34 S 94,48 7665.89 7600.00 1264.34 S 9572 7765.89 7700.00'. I274.40 S · 3541o48 3638.35 3732.11 3823.01 3912.22 4000.61 4084.13 .W ........ 1531.8~ .............................. 44.82 W 1573.95 42.10 W 1613.72 39.77 W- .... 1651,69 ................... 3~,96 ............................................. W' 1688.17 36.47' W' 1723-39 35.22' W 1754,89-. 31.'49 4235.11 W 1806.50 24,34. 9694 - 7865'89 7800.00 1281.61 S 4304.60 W 1828.50 22.00 ............................................................................................................... SpERRy2'sUN.' I'tEL'L" S'~JR'V~gi'D~G' "~0~'PANY ..................................................................................................................................... ANCHORAGE~ ALASKA (.~~-~=~3). COMPUTATION DATE SUR~EL' GYROSCOPIC NULTISH. OT SURVEY ~;'J~UDHOE BAY 2~ APRIL. ~72 JOB NUNBE~ SU-~-16739 ?'~LASKA (BKB) ' KELLY .BUSHING ELEV. = 65'89 ii'0" ~ P'0i'N~ ZNTE~OLnTED VnLUES'FO~ EVEN ZOO FEET OF SUB-SEn TRUE SUB-SEA TOTAL ~']~EASUREO VERTICAL VERTICA[ RECTANGULAR COORDINATES ' ND-TVD VERTICAL .., 981.~ 7965'89 7900.00 1286.29 S' ~71.58 W 1848.96 ' ............. 9,9 ~ ~ ................ 8065 -89. ............... 80.00. O0 ......................... 1290 .!.1 ....S ..... ~ ......... 44 ~ 8. O~ ..?. ................... 1869,.9 9 1005~ 8165'89 8100.00- 1292.27 .S 4503.60 W 1888'69 19.60 10173 8265.89 8200-00. 1289.7~ S 4566'97 W 1907.12 18.42 10290 ...................... 8365.89 ....................... 8300-00..:. ............... 1283.61,.~S ............ 4627.98,..~.W ......................... ! 92~.:," ~ ................................. 17~ 31,,.~ 10406 8465.89 8400.00 1272.50 S 4685.8~ W 1940.53 16,'08 10520 8565.89 8500.00 1257.60 S 4739.41 ',W 1954.97 14.44' 106 33 .............. 8665.89 .............. 8600 ._0~_ .................. 1238,62._.,..S .. ~. ........... .~ 787.- 68_.~ .............. 1.967,,.,~ ..................... 12 1074~ 8765.89 8700.00.- 1217.25 S 4829.69 W' 1978.21' 10-'57 10853 8865.89 8800.00 1192.21 S 486~'80 W' 1987.13 8.91 .... 10960 .................. 8965.8'9 ............. 8900.00, .............. 1167.08 S ...........~896' 65,.,W .................. 1995.05 .................................... 7~,92 11068 9065.89 9000.00 1I~1.03 S 4926'44 W 2002.60. 7.'54 11175 9165.89 9100.00 1115.~8 S ~954.36 W 2009.53 6.92' !! 282 ............. 9265,89 ........... ~ 200,.~O ................. 1089_,.51.._.S...L ......... ~ 980.80_.W ............... 2016"!.8. ......................... 11370 9348.~ 9282.55 1067.64 S 5001.7~ W 2021.56 THE CALCULATION._PROCEDURES THE NEAREST 20 FOOT MD USE A LINEAR INTERPOLATION BETWEEN ............................................ (FROM RADIUS OF CURVATURE) POINTS F-i----? I I I I I .) COMPLETIO.N REPORT BP ALASKA, INC, SUB SUR FA,CE DIRECTIONAL SURVEY WELL NO. A-5 (43-34-11-13) TYPE SURVEY SINGLE DATE APR. 15, 1972 SHOT CO~.PL.E¥'Z~"~i' REPORT '-'APRIL 14' 19'72 WE. gL,,_,A-5 (/+ 3,, 3~, !.l- 13} KELLY BUSHING ELEVATION 66 FT. R.A.D~US OF CURVATURE METHOD OF COMPUTATIONS ~,RgPAREP BY, F. H. L!N.DSEY AND ASSOC, RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC coMPUTER TRUE ME&5,,..DE../FT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. 2,500 0 0 .2500,00 2434.00 5 56 W 2600 2 45 2599.96 2533,96 5 56 W 2756 8,,.,45 2755.1'0 2689.10 5 50 W 2817 10 15 2815.26 2749.26 S 66 3020 15 0 3013.30 2947.30 S 79 W 3420 20 ~9 3393.83 3327.$3 $ 37.33 26 0 3681.04 3615.04 S 86 W 4108 .33 45 4005.96 3939.96 S 83 W ~.~04 ~0. 49 ..... 4320,98 4254,98 N 8~ ,~.~Z,.~8 0 ..... ~589.11 452~.11 S 70 W 4997 ~8 0 4667.91 4601.91 $ 64 W 9228'~ .0 4872,34 4806.34 S 6~ 56.7~_,~9,..~9 5179,83 9113.83 $ 66 W 5.861 50 0 5297,76 5231,76 5 68 .6!5.8.~9 15 5490,15 5~24,15 S 68 ~8~.0 53 0 5930.90 5864.90 S 71 7~ ~Z. 45 6208.54 6142.5~ S 71 89~½ 42 45 7337,33 7271.33 S 73 W 9~2~ 36 0 7793.74 7687.74 S 79 ,..~2.34.. O. 7933,13 7867.13 S 84 102.85 32 0 8388.50 8322.90 N .... ........ . TOTAL COORDINATE5 OeO0 S OeO0 1.34 S 1.98 10.73 $ 14,45 16.05 S 22.97 29.~6 S 65.18 48.56 S 186.37 60.~5 S 309,92 78,34 $ ~95.69 88.?8 S ?34.?6 92,52 S 820'54 106.38 S 903.33 122.80 S 960e60 146.85 S 1017.25 224,75 S 1176,98 363,49 S 1474,50 418.16 S 1603.30 502.92 S 1'8~3.08 591,02 S 2042,59 682,99 S 2301.19 802.00 S 264?.98 1038.18 S 3374.8.~ 1179.2½ S 3836.26 1~61.88 S 4167.70 1280e,44, S 4291.89 1289.60 S 4587.19 CLOSURES DISTANCE ANGLE D' N $ DOG LEG SEVERITY DEG/LOOFT 0'00 S 0 0 0 2,39 $ 56 0 0 W 18,01 $ 53' 2,3 58 W 28.02 S 55 2 42 W 71,49 S 65 44 50 W 192,59 S 75 23 4~ W 315.76 $ 78 57 42 W 501.84 S 81 1 6 ~ 740.11 S 83 6 36 825.74 S 83 33 58 ~ 909e58 S 83 17 0 W 968.42 S 82 ~2 52 W 1027.79 S 81 47 7 ~ 1198.2k S 79 11 20 W 1918.64 S 76 9 5 W 1656.94 S 75 22 55 ~ 1881.54 S 74 29 ~8 ~ 2400,30 $ 73 28 ~1W 2766,77 S 73 8 59 ~ 35.30,93 $ 72 54 3 W 4354.55 S 73 9 17 ~ 4478.82 S 73 23 16 H ~763.94 S 74 20 38 ~ - 0.000 2e750 ~,948 5.601 3.054 1,495 1.740 2.125 ~,569 2.567 5,867 3.693 2.214 1,326 0.850 0,253 0.5~6 . . 1,3~8 0.054 0,592 0.621 1,391 1.019 SECT I.O,,'~ ' DISTANCE 0.00 2.22 !6,40 25.84 69,91 192.42 ~1~.?0 501.06 736,95 82'i.59 905.44 96~,~~ 1025. )" 1197,90 1~.18.00_ , 1878,~8 2121.31 239~e41 2757.58 3998,74 ~3~0.12 ~7~5.17 RECORD OF SURVEY ALL CAECULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE M.~A'$" "DR IFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG. . TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M S 1071~ 25 ½5 8763,10 8697.10 N 61W 1227,39 $ ~783,70 W ~9~8,65. $ 75 35 ~4 W 11190 21 0 9200e8~ 913~,83 N ~9 W 1119,07 S ~9~8,~9 W ~O6~,bO $ 77 ~ 55 W 11370 21 0 9368,88 9302.88 N 69 W ~076.75 $ 6987,08 W 510~,99 $ 77 68 58 W BOTTOM HOLE CLOSURE 5101,99 FEET AT $ 77 48 58 W DOG LEG SE.VERITY DEG/LOOFT 2.711 [,287 0,000 SECTION DISTANCE 5101.99 ].NTERPOLATED TRUE VERTICAL DEPTHS, COORDXNATES AND CLOSURES FOR GIVEN D~PTHS TRUE CODE MEASURED VERTXCAL TOTAL COORDINATES C L 0 S U R E SUB NAME DEPTH DEPTH D!STANCE ANGLE SEA D M S MARKER 32 3723 TOP COAL 4302 PUC 9 6067 PUC [2 6970 SEN UNCON 92~+7 LNR TB 9272 .BULGE 9276 LNR PKR 9312 LNR HGR 93].B L,C,U, 9524 9 5/8 BAFF 9770 J-1 9790 9 5/8 SHOE 981~+ j-2 9886 J-3 10318 J-~+ 10458 J-5 10653 MKR JT TOP 10733 SAG IUNIT) 10802 SAG IBP) 10803 SHUBLZK FM 10828 .SAD.FM 1090.9 OWC 11060 OWC 11062 OWC 11066 O.WC 11068 OMC 11070 OWC 11072 OWC 11074 OWC 11076 OWC 11078 OWC 11080 OWC .11082 OWC 11084 3672,05 60,13 S 305,56 4163,94 87,75 S 607,81 5430,89 477,05 S 1749,06 6009,20 716,38 S 2399,31 7535,48 1225,54 $ 4002,81 7554,83 1229,34 S 4018,18 7557,93 1229,94 $ 4020,&3 7585,96 1235,21 S 4042,60 7590,65 1236,06 S 404'6,24 7754,55 1261,99 S 41,68,28 7956e35 1282e01 $ 4307e45 7972,96 1283,03 S 4318,54 7992,91 1284,17 S 4331,84 8052,88 1286o96 5 4371,59 8416,56 [284,09 $ 4504,50 8537,19 1271,70 5 4674,39 8?09,26 1240,02 S 4?60,34 $781,13 1223,16 S 4791,25 8843e56 1208,30 S 4816,60 8844,47 1208,08 S 4816,96 8867,18 1202,60 S 4825,87 89~1',06 1184,5~ S 4853,?3 9080e00 1149,79 S 4901,54 9081,85 1149,32 S 4902,14 9083,?0 11~8,85 S 4902,?4 9085,55 1148,38 S 4903,33 9087,~1 1147,91S 4903,93 9089e26 1147e45 $ ½904,52 9091mll 1146,98 S 4905el1 9092,96 1146e~1S 4905,71 9094e81 11~6e04 S 4906,30 9096,67 ~145,57 S 4906,89 9098,52 1145,10 S ½907,47 9100,37 1144,63 S 4908,06 9102,23 1144,16 S 4908,65 311,42 S 78 51 57 W 3606,05 614-11 S 81 47 5 W 4097,94 1812e95 S 74 ~4 37 W 53&4mS9 2503e98 S 73 22 ~l W 5943,20 4186,22 S 72 58 ~b W 7469,48 ~202,0~ S 72 ~9 19 W 7~88,83 4204,55 $ 72 59 26 W 7~91,93 ~227,10 $ 73 0 34 W 7519,96 4250,8~ 5 73 0 ~6 W 7524,65 4355e1~ S 73 9 20 W 7688,55 4~9~.18 $ 73 25 32 W 7890,35 4505.11 S 73 27 11 W 7906.96 ~518.18 S 73 29 15 W 7926,91 4557.09 $ 73 35 45 W 7986.88 4780.20 $ 74 25 2 W 8350.55 4919,20 S 75 23 58 W 8643.26 49~.4.92 S 7~ ~0 ~3 W 8715.13 ~96~,~5 $ 75 55 2 W 8777,56 4966,14 S 75 55 16 W 8778e47 ~97~,4~ S 76 0 24 W 8801.18 4996.18 S 76 17 6 W 887~,06 50~4,60' S 76 ~7 5~ W 9014,00- 5035,07 $ 76 48 18 W 9015,85 5035,54 $ 76 48 42 W 9017,70 .5036,02' $ 76 49 7 W 9019,55 5036,96 S 76 ~9 55 W 9023,26 5037,43 S 76 50 19 W 9025e11 5037,90 S 76 50 ~3 W 9026,96 5038,37 5 76 51 8 W 9028,81 5038,84 S 76 51 32 W 9030,67 5039,30 S 76 51 56 W 9032*52 5039e77 S 76 52 20 W 9034,37 50~0,23 $ 76 52 ~ W 9036,23 CODE NAME ) INTERPOLATED TRUE VERTICAL DEPTHS~ COORDINATES AN'D'.CLOSURE$ FOR GIVEN DEPTHS TRUE MEASURED VERTICAL TOTAL COORDINATES C L O $ U R E DEPTH DEPTH DISTANCE ANGLE D M $ SUB - SEA OWC 11086 LDG COLLAR 11314 ? INe SHOE 11360 TeD, 11370 9104,08 1143,69 S 4909,23 9316,59 1089,92 $ 4971,93 9359,54 1079e10 5 4984e37 9368e88 1076,75 5 4987,08 5040,7~ 5 76 53 8 W 9038,05 , 5089,99 5 77 38 7 W 9250.59 5099e85 $ 77 47 2 W 9293,54 ~101e99 S 77 ~8 58 w 9302e88 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN lO0 FEET OF SUB -SEA DEPTH. TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 2566 2566. 2500 0 0 2666 2666. 2600 0 0 2767 2766. 2700 I 1 2869 2866. 2800 2 2971 2966. 2900 5 3 3075 3066. 3000 8 3179 3166. 3100 13 5 3284 3266. 3200 18 5 3390 3366. 3300 2.4 3498 3466. 3400 31 7 3606 3566. 3500 40 9 3716 3666. 3600 50 . 3828 3766. 3700 62 12 3943 3866, 3800 77 15 4060 3966, 3900 94 17 4181 4066. 4000 115 21 ~305 a166. 4100 139 24 4432 a266. 4200 166 27 4563 4366. ~300 197 31 4696 4466. 4400 23'0 33 4827 4566. 4500 261 31 4954 4666. 4600 288 27 5084 4766, 4700 318 30 5219 4866, 4800 353 35 5360 4966, 4900 394 41 5506 5066. 5000 440 46 5657 5166. 5100 490 50 5811 5266. 5200 545 55 5967 5366. 5300 601 56 6121 5~66, 5400 655 54 6274 5566. 5500 708 53 6425 5666. 5600 759 51 6577 5766, 5700 811 52 5734 5866. 5800 868 57 6898 5966, 5900 932 64 0.58 5 0.86 4.01 $ 5,77 11.79 5 15.78 19,77 S 32.02 26.54 S 53,33 32.08 5 7~.53 37,19 5 108,71 ~2e27 S 140.90 ~7e2,0 $ 175e97.W 56,07 $ 256,65 59.90 $ 302,55 63,77 5 353,0~ 68.84 5 408.73 75,32 $ ~69e76 82,7~ $ 536,57 87.72 5 609e~8 89e~1 S 688.59 88.81 $ 773.36 98,24 S 8~0,25 116e79 $ 942e95 146e0~ S 1015,58 182,20 $ 108~,73 222e02 $ 1.171.39 265e16 $ 1260,96 310e05, 5 1356.86 356e96 S 1459e92 ~03.b~ 5 1567,88 448.48 S 1678,34 492.~0 $ 1787.04 535,19 5 1894.39 575,61 5 Z000,64 614,~6 $' 2107.~8 W 555,05 S 2221.98 W 697.&7 S 2344.98 W MEASURED DEPTH AND OTHER DATA ) FOR EVERY EVEN 100 FEET OF SUB ) SEA DgPTH. TRUE MEASURED VERTICAL DEPTH DEPTH SUB ND-TVD VERTICAL SEA DIFFERENCE CORRECTION TOTAL COORDINATES 7064- 6066, 7229 6166. 7394 6266. 7556 6366. 7714 6466, '7869 6566. 8022 6666, 8172 6766, 8319 6866. 8465 6966. 8607 7066e 8748 7166, 8886 7266, 9023 7366, 9156 7456, 9286 7566. 9414 7566, 9538 7766, 9661 7866. 9782 7966e 9902 8066, 10021 8166. 10140 8266. 10258 8366, 10376 8466e 10491 8566, 10604 8666e 10716 8766e 10827 8866e 10936 8966. 11045 '9066. 11153 9166, 11260 9266, 11367 9366, 6000 998 5100 1063 6200 1128 6300 1190 6400 12~8 65OO 1303 6600 1356 6700 1406 6800 1453 6900 1499 TO00 1541 7100 1582 7200 1620 7300 1657 7400 169'0 7500 1720 7600 1748 7700 1772 7800 1795 7900 1816 BO00 1836 8100 1855 8200 1874 8300 1892 8400 1910 8500 1925 8600 1938 8700 1950 8800 1961 8900 1970 9000 1979 910C 1987 9200 1994 9300 2001 65 65. 62 58 55 5O ~7 38 ~7 30 24 ZO 19 19 18 18 15 13 9 9 7 7 740,83 S 783,60 S 826,26 S 866,86 S 905,52 S 942,31 S 977.32 S 1010,62 S 10'42.3:3'$ 1073.07 $ 1102.87 $ 1131.76 $ 1159,78 S 1186e8~ S !2!0e97 1263.55 $ 127~.94 S 1282.61 S 1287,46 S 1289,69 S 1289,37 $ 1286,56 S 1280,18 S 1267,60 $ 12½9e48 1226,76 lZ02,89 $ 1178,38 S 1127,96 S 1102e66 S i077,~7 $ 2470,32 2594,53 2718,78 2839,00 2955,57 3068 · 64 3178.~I 3'388 '~+3 3488 · 98 3586.46 3680 · 96 377~ · 59 3861 .~2 39~6,38 4027,09 ~103,73 4176,~2 4246 e ~ i A~i3.89 ~380,~4 ~509 · 95 ~572 · 89 46~.07 ~690.05 ~74Q.46 4825 .~3 4862 · 80 ~897.06 ~928,24 ~997 · 27 ~986,24 ~[NTERPOLATED VALUES FOR EVEN 1000 FEET OF NEASURED DEPTH, TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 3000 2993. 2927. 4000 3915. 3849. 5000 4701. 4635, 6000 5387, 5321. 7000 6027. 5961. 8000 6651* 6585, 9000 7~49e 72~3, 10000 8148. 8082. 11000 902~. 8958. 28.25 S 71.80 S 158.57 S ~57,95 5 724,17 S 972.14 S 1182.40 $ i289.45 S 60.21 ~37.82 10~1.30 1701,77 2~2t.9~ ~83.19 ~L L~ ! BP ALASKA INC. A-10868 April 28' 1972 ~ State of Alaska Department of Natural Resources Division of Oil & Gas 3001 Porcupine Drive Anchorage, 'Alaska 99504. P.O. BOX 4-1379 31 1 I - C - STREET ANCHORAGE, ALASKA 99503 TF:LEPHONE (907) 279-0644 "~ "C. G~.O ~:'}j '1C'2 ENGENG[:NG J 3 ENG I DRAFT j CONFER: Gentlemen: · 'Well 'A-5 ' (34'11-13) Enclosed herewith PleaSe find in duplicate Form P'-4, Monthly RepOrt of Drilling and Workover' Operations for the above described' well, erY truly yours, i~~S I~ INC. Operations Manager klm Enclosure cc: Operations Coordinator, New York DIVISION OF O!L ,-'-',ND ¢':,'.- STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WKLL ___ W~-LL :2. NAME OF OPERATOR BP ALASKA INC. 3. ADDRESS OF OPEI~ATOR SUBMIT IN DUPLICATE OTHER P. O. BoX 4-1379 (3111 C Street) Anchorage,' Alaska 99510 4. LOCATiON OF WF.J.,L At surface: 923WEL, 1896' SNL, Sec. 35, TllN, R13E, UPM "'13. REPORT TOTAL DEPTH AT END OF MONTH. CHANGF~ IN HOLE SIZE, CASING AND CEMENt SET ~ VOL~ USD. P~O~TIONS. ~TS ~ ~SUL~ FISHING JO~ J~K ~ H ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ ~DITIONS April, 19 72 iPx NUA{EPdCAL CODE 50-209-20116 LEASE DESIGNATION AXD SERIAL NO. ADL-28287 8. L,~IT FA/tM OR LEASE NAME Put River 9 ~;LL NO A-5 (34-11-13) 10 FLELD A.ND POOL. OR %VI1.DCAT Prudhoe Bay, Prudhoe Oil Pool SEC. T.. 1~.. M. (~.O~I'OM HOI~ Sec .34, TllN, R13E, UPM . pi/Vi§toN 0(:. OiL ..n.., ,.,-' 1 - 5 Carried out second.stage Squeeze'. cementation with 600 sa~k~.~~- 'G' cement with 10%. gel'~and 1.25% CFR-2,1 mix water' with Ray'Frac. Slurry weight 12.8 ppg. This was ~followed' bY 4251 sacks permafrost II cement with 5 lbs. of pozzolan per' sack of cement. Slurry weight 14.8 ppg. Displaced' drill, bide, .13~" casing and .13}" x 18}/20" annulus to Water, Swabbed' casing, cement job not holding. Sandline Parted~ and'dropped sinker' bar and fluid locater'in hole. Ran overshot and recovered fish. Circulated' to clean .13~" casing and 13~" x 18}/20 annulus. Placed 100 sacks permafrost II cement with 5 lbs Pozzolan between lower and upper full opening cementers. ReverSe Circulated' through upper full opening cementer. Tested squeeze job. Swabbed' hole Clean and pumped a total of 320 bbls residual oil into ~ annulus. Closed' cementer and tested. Ran in hole drilled float collar, cement and shoe and drilled ahead to 9962'. 6 - 10 Drilled ahead to TD at 11,370'. Conditioned hole and ran logs. 11 - 13 Ran 48 joints 7", 291 lb/ft, N-80 ButtresS casing shoe at 11,360', landing collar at ll,314'.~and top of marker joint' at 10,733', liner hanger at 9318', liner packer at 9312'i~and top of the back receptacle at .9272". Pumped 10 bbls water, 10 bbls MF-1 with Mo re f lo ~ an d 10 bbls B-J mud sweep. Cemented with 485 sacks Class 'g' with 1.25%, CFR-2 slurry weight 15.8 ppg. Displaced drill pipe and liner with a total of 240 bbls. mud. Set liner packer. Circulated out 10 bbls. excess cement and 40 bbls. contaminated mud. Tested liner lap satisfactorily. Displaced' hole to fresh water followed by 26% CaC12 completion fluid. · 14 Laid down drill pipe. Ran in to 2000' and displaced to diesel. Removed BOP's ~d installed and tested wellhead capi''Rig'rileased to 1100 hours April 15~ 1972. certify, tFue an.d oon'e~ NOTE--Report on this form is required for ~ch calendar ~th% regardless of Iht stotu* of operations, and must ~ flied in dupli~tt wit~ the oil an4 gas aonmervatbn ~ommi~ee by the I~ of the suec~ing mn~, ~le~ otherwise directed. BP ALASKA INC. A-10860 April 10, 1972 State of Alaska Department of Natural Resources Division of Oil & Gas 3001 Porcupine Drive ~Anchorage, Alaska 99504 . P.O. BOX 4-1379 31 1 1 - C - STREET ANCHORAGE. ALASKA 99503 TELEPHONE (907) 279-0644 Gentlemen': Well'A-5':(43~34-11-13) Enclosed herewith PleaSe find in triplicate Form P-4, Monthly RepOrt of Drilling and Workover~ Operations for the above desCribed well. Very truly yours, A-. ~. Howard Operations Manager klm Enclosure cc: Operations. Coordinator, New York APR i 3 197~ DiVISiON OF OIL AND GAS STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT I~T DUI~LICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER 2. N~E OF OPm~TOa BP Alaska Inc. 3. ADDRESS OF OPER~TOB P. 0. Box 4-1379 .(3111 C Street) Anchora8e~ Alaska 99510 4 LOCATiON OF W~LL At surface: '923' WEL, '1896' SNL, Sec, 35, TllN, R13E' UPM API NUiVIERiCAL CODE 50-029-20116 LEASE DESIGNATION AND SERIAL NO. /U)L-28287 IF INDIA~ ALO7 iEr~ OR TRIBE NAME 8. L~IT FAIKM OR LEASE Put ~ver 9 WE~ NO 10 FIF~I.,D AND POOL. OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool n s~.c~ T., R., M. (BOTTOM HOL~ om.rmcrrv~ Sec..34, TllN, R13E, UPM 1~. PERMIT NO 72-08 13. REPORT TOTAL DEPTH AT END OF MONTH. CHA~'qGES IN HOLE SIZE. CASING AND CEMENTING JOBS INCLUDING DEPTH SET AN~ VOLLrNIES USED. PEB2'OHATIONS. TESTS ~ HESULTS FISHING JOB~ JLq~K IN HOLE AND SIDE-~CKED HOLE AND A.NY OTI-IER SIGNIFICANT C'H.A~ES IN HOLE CONDITIONS March, 19 72 14- 18 Spudded 'well ' at ' 0230 'hrs ', 'MarCh':14,i972. Drilled 17½" to 2326 ft. Opened'hole to 26" to .23261 ft. Ran 19 joints 20", 133 lb/ft, K-55, 8-round casing and.41 joints 18§" '96.5 lb/ft. 'K-55, buttress casing. . . ' . 1~" tubing strapped' to Shoe Set at '22'78 ft , crossover at .'1517 ft ~. . 18§" casing to 1492 ft. Cemented with '250 sacks permafrost II cement with 0.3% WG-7, slurry weight~ :14.3 ppg. Followed' with 7250 sacks Permafrost II with the slurry wt. at ~14.8 ppg. Ran two strings 1~" tubing to '183 ft. ~and tagged top of cement. Cemented~ to surface With 1200 sacks permafrost II, slurry weight'~14.8 ppg. Nippled' up and tested' BOPE. 19 31 Drilled 12¼" hole directionally to '98221. ft. Conditioned hole and ran logs. Rmn 193 joints 9~'''I 47. lb/ft, N-80 Buttress casing' and 51 Joints · 13~" '68 lb/ft N-80 Buttress casing. Shoe Set' at '9814 ft., float collar ~at 9770. ft., full opening CementerS .at 2146.. ft., 'and 2065 ft., _ Q~" 13~" x ~ crossover.at 2015 ft. Cemented'with 775 sacks class'G' cement with I0% gel ~ and 1.25% CRF-2, slurry wt., 12.8 ppg. This was followed by 250 sacks class '~' cement with 1.25% CFR-2, slurry wt., 15'.8 ppg. Displaced' with '880 bbls mud. Top of first stage cement .at :5'484 ft. AP R 1 1972 DIVISION OF OIL AND GAS NOTE --Report on this form is required for .each Galendar months regardless of tho status of operations, and must I~ filed in dupllGate with tho oil and gas aon$orvat/on committee bytha 15th of the suooeeding month, u~lel8 otherwise directed. P.O. BOX 4-1379 ~ BP ALASKA INC. 3111 - C- STRFET ANCHORAGE. ALASKA 99503 TELEPHONE {907) 279-0644 A-i0858 ApriI 4,' I972 State-Of Alaska Department of Natural ResOurces Division of Oil & Gas 3001 Porcupine Drive Anchorage,'Alaska 99504 Attention: Mr. Homer' Burrell Gentlemen: ' 'Well 'NUmber 'A~5 'I (43~.34~11~.i3) EnClosed'pleaSe find, in triplicate, FOrm P-3, Sundry Notices and RepOrts, for the' above named' well. Very truly yours, P ALASKA INC. A~. '~aye Howard Operations Manager klm Enclosures' cc: Operations CoOrdinator, New York Form P--3 P,_EV. 9-30-6 9 STATE O'F ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION 'FoR i°'EHi~iT-L~' 'for such 'p~o~osal~.) . . . . WELL WELL OTHER 2. NAME OF OPERATOR BP ALASKA INC. 3. ADDRESS OF OPERATOR P. 0. Box 4-1379 (3111 C Street) Anchorage~ Alaska 9951C 4. LOCATION OF WELL At surface 923' WEL, 1896' SNL, Sec. 35, TllN, R13E, UPM 13. ELEVATIONS (Show whether DF, RT, OR, etc. KBE 65.89 ft. AMSL Check Appropriate Box To I,ndicate Nial'ure of N~tice, Re AP1 NUMF, RICAL CODE 50-029-20116 6. LEASE DESIGNATION A-ND SERIAL NO. APL 28287 7. IF INDIA_N, A.LLOu-lu~E OR TRIBE NA/VLE 8. UNIT, FAI{JVI OR LEASE NAME Put River 9. WELL NO. A5 (43~34~11-13) 10. FIELD A~ID POOL, OR WILDCAT Prudhoe Bay~ Prudhoe 0il Pool 11. SEC., T., R., M., (BOTTOM ttObE OBJECTIVE) Sec. 34~ TllN~ R13E~ UPM 12. PERM_IT NO. 72-08 ~ort, or Other NOTICE OF INTENTION TO: TES~ WATER SH~T-Or~ I ] FR*CTVa~ TRE*T ~! SHOOT OR ACXDXZE REPAIR %VELL PULL OR ALTER CASINOJ MULTIPL1~ COMPLETE ABANDONs CHANO~ PLANS , Suspend {XX..] Other) SUBSmQU~NT REPORT OF: WATER SHUT-OFF [ I REPAXRINO WELL FRACTURE TREATMI[INT --] ALTERING CASINO SHOOTING OR ACIDIZIN0 ABANDONMENTs (Other) (NOTre: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) !5. U~:SCRIBE I'nOP0SZD OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, We propose to suspend our subject well pending design of 9roduction facilities and downhole completion. The well status will be as follows: Total Depth: Approximately 11,160 ft. M.D. in ~ hole. Last Casing: 7" OD, 29 lb/ft, N-80, Seal-Lock liner'from T.D. to approximately 9314 ft. M.D. This will provide an overlap of approximately 500 ft. inside the 9~" casing set at 9814 ft. M.D. Cemented With: Approximately 400 cu. ft. of Class 'G' cement. The 13~" x ~ casing string will contain diesel from 2500 + ft. to surface. The wellhead will be Capped'and filled with diesel. The7" line--twill not be Perforated. 16. I hereby cert t at the foregoing is tru? and correct SIGNED ~ ' TITLE (This space for ~e ~~) C0ND~T~0NS ~[P~g0~A~, ~ AFl: ~ TITLE Chief Pa%_,~0~_e,3m Eng!nccr See Instructions On Reverse Side Approved Copy Returned lie: PK l~l~ A-~ (4~3~11-13) ~ Al~ska Inc. Permft ~1~. 72-8 t~ Alaska Inc. P. O. Box .4-1379 Anchorage, Alaska it. Iq.. R. t~tler Operations Gent lemen: Ee. clesed is the app-~ application for pe.mtt to drill the ~ove ~fe~n~d uell, ~ or ~.~t Na~ 7, 19~, at a l~ati~, in ~t~ 35, Tmnshtp 11 N, ~. I3 e, u.& Well s~les and core ci~tps are not ~utred. A direct~lmal survey is required. ~ rivers ia Alaska a~d ~elr drainage systems have been classified t~t ~ ~ sp~tflg or mig~tt~ of ~~.~ fish. ~rattms tn these a~as a~ s~t ~ ~ I6..~.8~ ~ ~ ragula~s p~ulgaMd ~e~~r (Title 5, Al~ka ~nisc-ratl~ ~). P~or ~ ~ct,9 ~ratt~s y~ m~ be c~tac~ · b~ ~ H~I~ C~tnaCo~s offl~, ~~C of Fish and In t~e e~nt of suspe~stea or aband~t please 9i~e this office adequate vance notification so t~at ~e may have a witness present. £ncl~ure cc: ~pa~,t of Fish ~ ~, Habitat :~¢ttcm w/o ecl. ~pa~~t of En~roneental C~ervatten w/o en¢l. PLACID OIL COMPANY 2500 FIRST NATIONAL BANK BUILDING DALLAS, TEX~$ 75202 February 29, 1972 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 C ~NG ..... I ENG 2 ENG ...... 3- ENG'-~ 4 ENG .......... -,.5' ENG 1 GEOL ....... 2' GCOL ........ 3"GF:OL' REV DRAFT SEC "Co~FER: FILE: Re: BP Alaska, Inc. Put River A-5 (43-34-11-13) North Slope, Alaska Gentlemen: BP Alaska, Inc., in compliance with the State of Alaska's Oil and Gas Conservation Regulation Number 2060, has noti- fied Placid Oil Company as to its intentions to drill the Put River A-5 (43-34-11-13). It is our understanding this well is to be drilled from a surface location 922' WEL and 1900' SNL in Sec. 35, TllN, R13E, UPM, Alaska, and is expected to encounter the top of the Sadlerochit Sandstone at 2700' SNL and 400' WEL in Sec. 34, TllN, R13E, UPM Alaska. Placid, as an "affected operator", and as operator for the PLAGHM Group (Placid, Louisiana Land & Exploration, Amerada Hess, Getty, Hunt, and Marathon), speaking on behalf of the Group, has no objections to the location as proposed by BP Alaska, INC., for the Put River A-5 (43-34-11-13). MAR 2 1972 ¢iVISION OF OIL AND GAS JRS/sw Yours very truly, PLACID OIL COMPANY Jerry R. Sawyer Manager, Alaskan Operations cc: Messrs: B. R. R. Butler- BP Alaska, Inc. F. V. Ballard- Amerada Hess Corp. H. E. Berg - Getty Oil Company D. E. Sibley - Louisiana Land & Exploration G. R. Schoonmaker - Marathon Oil Company S. C. Sandusky - Marathon Oil Company BP ALASKA INC. A-10203 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 P.O. BOX 4-1379 3111 - C - STREET ANCHORAGE. ALASKA 99503 TELEPHONE {907) 279-0644 February 17, 1972 Attention: Mr. Homer L. Burrell, Director Gentlemen: Well Number BP A-5 (43-34-11-13) Please find the following enclosed herewith: 1. Application for Permit to Drill Well A-5 (43-34-11-13). e Our check in the amount of $100.00 to cover the permit .filing fee. 3. Three copies of surveyor's plat showing well location. We are also providing you with a copy of a memo giving specifications for 18-5/8" OD 109.35 lb./ft. K-55 Buttress casing and 13-3/8" OD 68 lb./ft. N-80 Buttress casing. These modifications represent a change in casing procedures for this Well, A-5, and future wells. vjp Enclosures cc: Operations Coordinator, New York Very truly yours, BP ALASKA INC. B. R. R. Butler Operations Manager. l~orm REV. SUBMIT IN TRIP~,. ~'ATE (O~her instructions on reverse side) STATE OF ALASKA OIL AND GAS CONSERVAIIO'N ,COMMITTEE IR. TYPE OF WOIK b. TYPm OF WELL OIL [] WI~LI, APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK DRILL X--I DEEPEN [-'-I PLUG BACK ]-] °" K1 "'NGL' Fl WELL OTHER ZONE ZONE 2. NAME OF OPEH~TOR BP Alaska Inc. 3. ADDRESS O~e OPERATOR P. O. Box 4-1379, Anchorage, Alaska 99509 4. LOCATION OF WELL At surface 922' WEL, 1900' SNL, Sec. 35, TllN, R13E, UPM At proposed prod. zone 400' I/EL, 2700' SNL, See. 34, TllN, R13E, UPM 13, DISTANCE IN MILES AND DIRECTION FAOM NEAREST TOWN OR POST OFFICE* 100 miles N.E. of Umiat APl No. 50-029-20116 ?///~ 6. LEASE D~SIGNAT1ON AN~ SERIAL NO. ADL 28287 7. IF INDIAN, A~OT'~EE OR TRIBE N,a~ME 8. UNIT, FARM OR LEASE NAMF, Put River 9. WELL NO. A-5 (43-34-11-13) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Prudhoe 0il Pool 11, SEC., T., R., M.. (BOTTOM HOLE OBJECTIVE) · Sec. 34, TllN, R13E, UPS 12. 14. BOND INFORMATION: State of Alaska DL-11 TYP~Blanket Surety and/or No Federal Insurance Co.. ,8016-77-14 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST 400 ' west of ADL PROPERTY OR LEASE LINE, FT. 28286 (Also to nearest drig, unit, if any) · 329~' 1'8. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL D~ILLING, COMPLETED. ft· OR APPLIED FOR. FT. from BP well A-3(43-27-11-13) NO. OF ACRF_~ IN LEASE .2560 Jlg. PROPOSED D~PTH 11,160' (9250' TVD) 21. ELEVATIONS (Show whether DF, RT, CR, etc.) Estimated KB Elevation 66 ft. AHSL 23. PROPOSEI~ CASING AND CEMENTING ~ROGRAM _ ~-~o,,-?. $100.00.0,,.00 17. NO. ACRES ASM;GNED TO THiS WELL 640 20. ROTARY OR CABLE TOOLS Rotary 22. APPHOX. DATE W.ORK WII,I, NTART* March 3, 19 72 26" 20"/18~" 133/96.5 'K-55 2300' 2306' 5500 cu. ft.'Pemmafrost II , , 12]" ~s,,/n~,, 68/47. N-80 10000' 8'480' 2000 cu. ft Class G + 450 cu. f , - - · Permafrost II ~'-- 81" 7"" 29) , NFS0'. 111~0~, 0250; AD0 au. ft. Class G .F///~ Reason for deviation: To minimize rig moves and to facilitate construction of take- off facilities. Forecast Top Coal Lower Cretaceous Unconformity Sag River Formation Shublik Formation Oil/Water Contact Sadlerochit Formation TVD-BKB 4220 7770 8760 8790 9100 8870 DIVISION OF OIL AND GAS IN ABOVE SPACE DIISCRIBE PROPOSED FlY.RAM: I! l~Opos~l is to deel~n or plug back, give d~a on pre~nt produ~ive zone and propose~l' new productive zor~e. If proposal is to drill or d~l~n direcllonall¥,, give p~rtlnent data on subsurfac~ locations and measured and true vertical depths. Give blowout preventer program. 24 I hereby certify that the Foregoing,-i~ True an(~ Corre~ ', ,"Z. S_G. ' ., ~' - ~ (This space for S~te offi~ ~) COND~ON~ O~ ~V~, '~ ~: zrnz OPerations Manager J SAMPLES AND CORE CHIPS [] YF, S ~ NO j DIRECTIONAL SURVEY RE~IfIRliD YES [] NO SEE TRANSMII-I'AL LETTER A.P.I. I~D3M~ICAL CODE 50-029-20116 PERMIT NO~ APPKOVF2) B~ 7 z8 ,, _ ' ' *See Inmudio.. On Reverse Side Pi~,,rql] 7, 1972 ~,~ Mar, ct] 7, 19 72 ........ Well A-5(43-34-11-13) Dry bucket 36" hole to about 85 feet below ground level and cement 30" conductor to surface using Permafrost II cement. Drill 17½" hole and open to 26" to about 2350' and cement 20" x 18~" casing to surface using Permafrost II cement. Drill 12¼" hole under directional conditions to approximately 8500 feet TVD. Cement 13~" - 9~" casing in stages with Class 'G'/gel and Permafrost II cement. Drill 8½" hole under directionaI conditions to T.D. at approximately 9250 feet'TVD, Cement 7" liner to apProximately 500 feet inside 9~" shoe with Class 'G' cement. Suspend for later completion. Blowout preventer program is 3000 psi pipe rams, blind rams and 2000 psi HydriI from 20" x 18§" casing point, and 5000 psi pipe rams, blind rams and Hydril from the 9~" x 13~" casing point. FEB 2, 3 197Z. DIVISION OF OIL AND GAS 2990 RICHKOND AVl:. GUlT[ 310 HOUSTON. TI:XAS 77006 AMERICAN_ Ijt. b J.d "" MANNEX CORPORATION · GENERAL AGENTS FOR MANNESMANN TUBE COMPANY LTD. · December 15, 1971 TELKPHONI:: ('71:3) 526-1:337 C~BLff: M,NNrSTUB[. HOUSTON WU T,'~.'rx: 077.376 Mr. Dennis-Maycock BP Alaska, Inc. 'P. O. Box 4-CCC Anchorage, Alaska 99503 Dear Mr. Maycock: We are pleased to Confirm our telexes #AM-176. dated November 30, 1971, and #AM-197 dated December 14, 1971, containing the dimensional and performance properties of 18-5/8" OD 109.35 lb/ft K-55 Buttress and 13-3/8" OD 68 lb/ft N-80 Buttress casing. The properties are listed as follows: 18-5/8" OD 109.35 lb/ft K-55 BTC Collapse Resistance Internal Yield Pressure Pipe Body Yield Strength Buttress Joint Strength - 1350 psi - 2930-psi - 1768 x 1000 lbs - 1846 x 1000 lbs Wall Thickness - .567" I.D. ' - 17.491" Drift' .- 17.303" Coupling O.D. - 20.000" _13-3/8" OD 68.00 lb/ft' N-80 BTC CollapSe Resistance Internal Yield Pressure Pipe Body Yield Strength Buttress Joint Strength Wall Thickness - .480" ID - 12.415" Drift - 12.259" Coupling O.D. - 14.375" - 2264 psi - 5024 psi - 1556 x 1000 lbs - 1585 x 1000 lbs We hope .this information will be helpful. DIVISIObl OF OIL AND GAS Sincerely, AMERICAN MANNEX CORPORATION Michael.D. Williams }fl)W: lb . , ~ 4~ / I t 400' (Pre oo~d) I 20 30 ~0 I0 = I I 26.._, -1 - I I (Pre ~osed) I I . 40 NE COR. OF SUMP 2oa' I (LOC. THiS SURVEY) LAT. ZO° 16' 04! 18" LONG. 14~°44' 53.59" Y= 5,949,104 _~ X 654,795 SECTIONS SCALE 1"=1/2 MILE 25, 26,27, 34,35 8~ 36 .'.'CAMP * . , ' PAD' ' 'oo · ' ~ . ~ . ,~ · . , d2 - 34 - I / - 13 MAIN SUMP 4$-..EY-//-/$ ~ 4/-$G-I1-15 I V£RT/CAL d~-~5-11-/$ ACCESS ~'~ P/L ROAD CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that all dimensions and other details are correct. ",3 ~t:"~-. ~-'~ Date SURVEYOR F E B 3 3 1972 TOP SAG RIVER FORMATION TOP SAG RIVER FORMATION TOP SAG RIVER FORMATION. TOP SAG RIVER FORMATION TOP SAG RIVER FORMATION TOP SAG RIVER FORMATION DIVISION OF OIL AND GAS A-§ , REVISED A-5 A-4~ REVISED A-I, A-2 A-3 A-I, REVISED NAME ~'- 3-7Z M.L.S. I - 13 - 72 bl.L.S. 12-4-71 M.L.S. II -11-7'1 M.L.S. 9-30-71 M.L.S, PAD DETAIL SCALE I"= $00' PAD "A" Located in Surveyed for [3. [?. ALASKA INC. M.I Surveyed by F M. LINDSEY & ASSOC. LAND ~ HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-081 Anchorege Alaska Yes No Remarkr I. Is well to be located in a defined pool ................. ~/C · 2. Do statewide rules apply ........................ $. Is a registered survey plat attached .................. ~x: u , 4. Is well located proper distance from property line ........... /~ ~x Is well located proper distance from other wells . . .......... ~: 6. Is sufficient undedicated acreage available in this pool ........ ~ 7. Is well to be deviated ......................... Y~ 8. Is operator the only affected party ................... 9. Can permit be approved before ten-day wait ............... bond i ...... 10. Does operator have a n force ................... i 11. Is conductor string provided ................... 12. Is enough cement used to circulate on conductor and surface . . . Will cement tie in surface and intermediate or production strings 14. Will cement cover all possible produ-c~i~ fmrizons ....... lB. Will surface casing cover all fresh water zones ........ 16. Will surface csg. internal burst equal .5 psi/ft, to next string .... 17. Will. all casing give adequate safety in collapse and tension ...... ~.~~ i8. Does BOPE have sufficient pressure rating ............... ~. Additional Requirements: Dm ,,~..~L,~~,~_. /~..¢-~'ev,,- $-3-7~_./ ~K,...._.._,-:r-~ .... Approval
