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Home My WebLink About195-128THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED · ON 'OR BEFORE JANUARY 03 '2001_ M PL. ATE IA L E U W N D E R THIS M A R K E R C:LO~ILM.DOC State of Alaska .ALASKA 0IL & GAS CONSERVATION C0MPIISSION F.',emcr=_n-d~.~ ~ Fii=..-.Pi Well }Tame Review the well file, and-comment on plugging, well head Well head Harker pos~ LocaUion Clearancm: Conclusions: sUa*.us,,~a~d !oca=~cn clearance ~ ~rovide. loc. clear, code. ~, ~~' ~ ~~~ , ~'~vg~' FoP Code RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIONPlug~Folr~l~elt~8 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska 0il & Gas Cons. C0mmi~' 1. Status of Well Classification of S~[~b Well Anchorage [~ Oil i--] Gas [--I Suspended [~ Abandoned [] Service i2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 95-128 398-148 i3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20633-01 4. Location of well at surface I ~ 9. Unit or Lease Name 3405' SNL, 3613' WEL, SEC. 32, T12N, R13E, UM ~ Prudhoe Bay Unit At top of productive interval!~ 10. Well Number 5236' SNL, 2828' WEL, SEC. 29, T12N, R13E, UM R-18A At total depth ~ 11 Field and Pool 856' NSL, 2151' WEL, SEC. 29, T12N, R13E, UM Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE -- 49.03'I ADL 028278 12. Date Spudded12/5/95 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' water depth' if Offsh°re 116' N°' °f c°mpleti°nsl 2/26/95 7/5/98 N/A MSLI Zero 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 11066 8885 FTI 11034 8884 FTI I-lYes [~NoI N/A MD 1900' (Approx.) 122. Type Electric or Other Logs Run Gamma Ray Log from11047' - 9738' MD 0~ [ 0!~.I J~ I 23. CASING, LINER AND CEMENTING RECORD ; "I ~ /'-\ L CASING SET-rING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" Insulated Conductor Surface 110' 36" 8 cu)/ds concrete 13-3/8" 68# NT80CYHE Surface 2700' 17-1/2" 3720 cuft Arcticset II 9-5/8" 47# NT80 Surface 9770' 12-1/4" 1335 cuft Class 'G', 130 cu ft Arcticset I 7" 26# L-80 9271' 9823' 8-1/2" 375 cu ft Class 'G' 2-7/8" 6.16# FL4S 9101' 11066' 3-3/4" Uncemented 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None 5-1/2", 17#, L-80 6978'-9196' 9055' MD TVD MD TVD i26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8200' P&A with 31 Bbls Class 'G' 6627' Set EZSV 6492' Kick Off Plug, 29 Bbls Class 'G', Sqzd 2000 psi 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Not on ProductionI N/A Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate ~' Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Subsea i Shublik A 9857' 8750' Sadlerochit 10018' 8823' 31. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is tru~;~and correct to the best of my knowledge Signed 4~.7~-~ ~-~ / ) Dan Stone Title Engineering Supervisor Date R-18A 95-128 398-148 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GEHERAb: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1.' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5-' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21.' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23.' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27': Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 R-18A DESCRIPTION OF WORK COMPLETED PRE-SIDETRACK CEMENT PLUG 07/05/98 A Cement Plugback was performed on the interval using the following fluids: SUMMARY Bull head kill well with 377 bbls of water. RIH to 9,115 CTMD and tagged liner top. Gas was coming in from IA. Circulated gas out of tubing by Bull head down backside and cracking IA. Got WHP back down and mixed cement. Gas continued to blow into tubing. Bull head 11 bbls of cement into liner with chokes closed and laid in remaining 20 bbls. Pulled out of hole while replacing pipe voidage. Left well SI with a 650 psig gas cap. Need to tag cement in morning and pull a circulation valve to sweep gas out of well and PT plug. Estimated TOC - 8,200' Fluids Pumped BBLS DESCRIPTION 31 Cement 604 Slick Sea Water 635 Total Bbls pumped 07/09/98 CHEMICAL CUT TUBING SUMMARY Rigged up SWS. Arm Cutter. Tie In. Malfunction in cutter head assembly. Cutter did not fire. Pulled out of hole. WO SWS to get new cutter head from shop. Arm new cutter. Rig in hole. Tie In. Successfully Cut 5 1/2" tubing. Cut Tubing at 7,000' MD. Pulled out of hole. Cutter anchors stuck in GLM #4 while POOH. Repeated attempts to dislodge anchors failed. Repeated attempts by HB&R to pump cutter assembly free also failed. Decided to pull off at weak point. Pulled off. RDMO. Pulled out of hole. Rig down moved off. Fluids Pumped BBLS DESCRIPTION 100 Filtered Sea Water 60 Diesel 160 Total Facility PB R Pad Progress Report Well R- 18B Rig Nabors 2ES Page Date I 27 August 98 Date/Time 25 Jul 98 26 Jul 98 27 Jul 98 28 Jul 98 01:00-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-09:00 09:00-12:00 12:00-12:30 12:30-13:30 13:30-16:30 16:30-18:00 18:00-18:30 18:30-23:00 23:00-00:00 00:00-00:30 00:30-02:00 02:00-02:30 02:30-04:00 04:00-06:00 06:00-07:00 07:00-09:00 09:00-10:30 10:30-12:00 12:00-12:30 12:30-14:30 14:30-16:00 16:00-18:30 18:30-21:00 21:00-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-02:00 02:00-02:30 02:30-06:00 06:00-07:00 07:00-11:30 11:30-12:00 12:00-12:30 12:30-13:30 13:30-15:00 15:00-17:00 17:00-17:30 17:30-18:30 18:30-19:30 19:30-22:00 22:00-00:00 00:00-00:30 00:30-04:30 04:30-06:00 06:00-07:30 07:30-09:30 09:30-10:00 10:00-12:00 12:00-12:30 Duration 3 hr 1/2 hr 1/2 hr 1 hr 3 hr 3 hr 1/2 hr 1 hr 3 hr 1-1/2 hr 1/2 hr 4-1/2 hr 1 hr 1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2 hr 1 hr 2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 2hr t- 1/2 hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 1 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1 hr 4-1/2 hr 1/2 hr 1/2 hr 1 hr 1-1/2 hr 2 hr 1/2 hr 1 hr 1 hr 2-1/2 hr 2 hr 1/2 hr 4 hr 1-1/2 hr 1-1/2 hr 2 hr 1/2 hr 2 hr 1/2 hr Activity Fill pits with Seawater Removed Accessories Rigged up High pressure lines Bleed down well Circulated at 7000.0 ft Flow check Held safety meeting Installed Accessories Removed Surface tree Installed BOP stack Installed High pressure lines Tested BOP stack Retrieved Accessories Held safety meeting Removed Tubing hanger Circulated at 7000.0 ft Removed Tubing hanger Set Retrievable packer at 40.0 ft with 0.0 psi Set Retrievable packer at 50.0 ft with 0.0 psi Removed Seal assembly Rigged down BOP stack Removed Seal assembly Held safety meeting Removed Seal assembly Rigged up BOP stack Installed Tubing head spool Installed Seal assembly Rigged up BOP stack Tested BOP stack Retrieved Tubing landing string Held safety meeting Circulated at 7000.0 ft Retrieved Tubing landing string Laid down 2000.0 ft of Tubing Retrieved SCSSSV Laid down 4600.0 ft of Tubing Rigged up Logging/braided cable equipment Held safety meeting Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Made up BHA no. 1 Tested Permanent packer Made up BHA no. 1 Singled in drill pipe to 3000.0 ft Serviced Swivel Held safety meeting Serviced Kelly Singled in drill pipe to 4200.0 ft Singled in drill pipe to 6632.0 ft (cont...) Circulated at 6632.0 ft Laid down 150.0 ft of 5in OD drill pipe Milled Casing at 6488.0 ft Held safety meeting Facility PB R Pad Progress Report Well R-18B Page 2 Rig Nabors 2ES Date 2-] August 98 Date/Time 29 Jul 98 30 Jul 98 31 Jul 98 01 Aug 98 12:30-20:00 20:00-21:30 21:30-23:00 23:00-00:00 00:00-00:30 00:30-01:00 01:00-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-06:45 06:45-07:30 07:30-08:00 08:00-08:30 08:30-10:30 10:30-12:00 12:00-12:30 12:30-14:00 14:00-14:30 14:30-15:00 15:00-15:30 15:30-17:30 17:30-17:45 17:45-18:00 18:00-20:30 20:30-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-02:30 02:30-06:00 06:00-06:30 06:30-10:00 10:00-10:30 10:30-12:00 12:00-12:30 12:30-13:00 13:00-00:00 00:00-00:30 00:30-01:00 01:00-06:00 06:00-07:00 07:00-20:00 20:00-21:00 21:00-21:30 21:30-22:00 22:00-06:00 06:00-08:00 08:00-08:15 08:15-12:00 12:00-12:30 12:30-18:00 18:00-19:00 Duration 7-1/2 hr 1-1/2 hr 1-1/2 hr 1 hr 1/2 hr 1/2 hr 3 hr 1 hr 1 hr 1/2 hr 1/4 hr 3/4 hr 1/2 hr 1/2 hr 2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2 hr 1/4 hr 1/4 hr 2-1/2 hr 2 hr 1 hr 1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 3-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 11 hr 1/2 hr 1/2 hr 5 hr 1 hr 13 hr I hr 1/2 hr 1/2 hr 8 hr 2 hr 1/4 hr 3-3/4 hr 1/2 hr 5-1/2 hr I hr Activity Milled Casing at 6488.0 ft Circulated at 6533.0 fl Pulled out of hole to 685.0 ft Pulled BHA Held safety meeting Pulled BHA R.I.H. to 6475.0 fl Washed to 6632.0 ft Circulated at 6632.0 ft Circulated at 6632.0 ft (cont...) Held safety meeting Mixed and pumped slurry - 29.000 bbl Pulled out of hole to 5500.0 ft Circulated at 5500.0 ft Held 2000.0 psi pressure on 2.000 bbl squeezed cement Laid down 1350.0 ft of 5in OD drill pipe Held safety meeting Pulled out of hole to 0.0 ft Washed to 0.0 fl Retrieved Wear bushing Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Installed Wear bushing Made up BHA no. 3 R.I.H. to 6100.0 ft Serviced Block line Rigged up Computer hardware Held safety meeting R.I.H. to 6349.0 ft Drilled cement to 6405.0 ft Wait on cement Drilled cement to 6405.0 ft Wait on cement Drilled cement to 6445.0 ft Wait on cement Held safety meeting Drilled cement to 6492.0 ft Drilled cement to 6538.0 ft Held safety meeting Drilled to 6583.0 ft Circulated at 6583.0 ft Circulated at 6583.0 ft (cont...) Drilled to 7493.0 ft Circulated at 7493.0 ft Pulled out of hole to 6450.0 fl R.I.H. to 7493.0 ft Drilled to 7960.0 ft Drilled to 8000.0 ft (cont...) Held drill (Kick while drilling) Drilled to 8221.0 fl Held safety meeting Drilled to 8509.0 ft Circulated at 8509.0 fl ' STATE OF ALASKA *" ALASKA ~_IL AND GAS CONSERVATION CO,,.,¢IISSION APPLICATION FOR SUNDRY APPROVAL ~ of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3405' SNL, 3613' WEL, SEC. 32, T12N, R13E, UM At top of productive interval 5236' SNL, 2828' WEL, SEC. 29, T12N, R13E, UM At effective depth 820' NSL, 2158' WEL, SEC. 29, T12N, R13E, UM At total depth 856' NSL, 2151' WEL, SEC. 29, T12N, R13E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [--]Service 6. Datum Elevation (DF or KB) KBE = 49.03' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number R-18A 9. Permit Number 95-128 10. APl Number 50-029-20633-01 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11066 feet true vertical 8885 feet Effective depth: measured 11034 feet true vertical 8884 feet Plugs (measured) Junk (measured) ORIGINAL Casing Length Size Structural Conductor Surface Intermediate Production Liner CT Sidetrack Liner Perforation depth: measured Cemented MD TVD 110' 20" 8 cu yds concrete 2672' 13-3/8" 3720 cu ft Arcticset II 110' 110' 2700' 2700' 9742' 9-5/8" 1335 cu ft 'G', 130 cu ft Arcticset I 9770' 552' 7" 375 cu ft Class 'G' 9823' 1965' 2-7/8" Uncemented ~ E ~'~, ~iV ~ D9101' - 11066' eo .... o1 11020'- 11030'; 11031'- 11041' "--" ,J( t'! I 0 true vertical 8933' - 8933', 8933' - 8933' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 9055' with 5-1/2" tailpipe to 9196' 8719' 8769' 8118'-8933' Packers and SSSV (type and measured depth) 9-5/8" BOT packer at 9055'; 5-1/2" SSSV (nipple) at 2167' 3. Attachments [~ Description summary of proposal 14. Estimated date for commencing operation June 16, 1998 16. If proposal was verbally approved Name of approver Date approved Contact Engineer Name/Number: Chris Brown, 564-5582 E] Detailed operations program [--I BOP sketch I15. Status of well classifications as: [] Oil I--] Gas [--1 Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~,,.... '~-~...~¢'~ Title Engineering Supervisor Commission Use Only Date I Approval No. Conditions of Approval: Notify Commis.si, p.n so representative may witness Plug integrity" BOP Test/'/" Location clearance__ Mechanical Integrity Test . Subsequent form r.e~l~ 1 ~o~e6 96 · · 0ri inal Si ned tx¢ Approved by order of the Commission g g ' ~ ~, I,~ ~-~/"~Commissioner Form 10-403 Rev. 06/15/88 0avid W. Johnston Submit In Triplicate R-18a P&A SUMMARY Objective This operation's objective is to squeeze and abandon existing perforations from 10,100' - 11,041'(.~ MD and circulate the well clean to seawater. The tubing is intact and hence a full bore squeeze will be used. The cement unit will bullhead sufficient cement to cover from the perforations at 10,100'- 11,041' and squeeze away cement. The top of the cement plug will be planned at a desired TOC of _+8,000', allowing the whipstock kick off at 6,495' to be completed. The cement will be displaced using seawater to ensure that the well is killed and circulated clean. Once the well is circulated clean on tubing, the tubing will be chemically cut at +7,000', and the annulus circulated to seawater. The well will finally be plugged with a BPV and prepared for the rig's arrival. Critical Well Information 5-1/2", 17#, L80 IJ4S IPC Tubing I.D. = 4.892" Capacity = 0.0232 bbl/ft SSSV Landing Nipple: 2,167' MD Minimum ID (2.372" I.D.): 9,101' MD 2-7/8", 6.16#, L80 FL4S, Liner I.D. = 2.372" Capacity = 0.00579 bbl/ft PBTD (2-7/8"): 11,066' MD Perforations: ([0,03_0'-11,041' MD (open) Proposed TOC: +8,000' MD-'% ~6~ ICo Maximum documented hole inclination is 90° at >9,101' MD (horizontal CT sidetrack). Angle at the proposed KOP inside the 9-5/8" casing (+6495' MD) is +39°. 1) No operations in this procedure are to be commenced without "Approval to Proceed" siqnatures 2) Notify an AOGCC representative prior to commencing P&A operations. Pre-Rig Work: NOTE: If any problems with the 9-5/8" packoff are observed during pre-rig work, contact the wellhead manufacturer to initiate repairs and inform the Operations Drilling Engineer. o R/U wireline and retrieve SSSV. Dummy off GLM's if required. Test 9-5/8" packoff to 5,000psi if not recently tested (<1 month). POOH. If tubing and annulus have not recently (<1 month) been tested, and tubing has integrity, pressure test to 3,000psi. , Perform a full-bore cement abandonment of the existing perforations at 10,100-11,041' Highest acceptable TOC is 8000' in order to leave room to section mill at required depth for kick-off. Let the plug set up, then pressure test to AOGCC requirements. o R/U electric line unit and chemical cutter for 5-1/2" tubing. RIH and tag cement plug at +/-8000'. Pull back and chemical cut 5-1/2" tubing at +/-7000', avoiding collars. Note that the tubing is plastic coated, and will therefore require that a double anchor system and acid cylinder is used. RD electric line unit. R- 18a Sundry P&A Procedure Page 2/3 4. Circulate seawater through the tubing cut until clean returns are obtained. Freeze protect tubing and annulus to 2,200ft with diesel. Bleed pressures on tubing/annulus. Zero psi on all annuli required. 5. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar. Rig Work: . Prior to rig move, test 9-5/8" packoff to 5,000psi, and function lock down screws (FMC wellhead representative to do this). If any problems with the 9-5/8" packoff are observed, contact the wellhead manufacturer to initiate repairs. 2. MIRU. Circulate the well to clean seawater. Pull BPV and set/test TWCV. ND tree, NU BOP's and test same. Pull TWCV. 3. Retrieve 5-1/2" tubing from chemical cut at 7000'. If tubing parts, RIH with fishing assembly and retrieve remaining tubing. . R/U wireline unit and set EZSV in 9-5/8" at +/-6635' (placed for window kick off at 6495'). R/D electric line unit. RIH with milling assembly and mill section in 9-5/8" casing from 6490'-6535'. POOH. RH-I with cementing stinger and lay cement kick off plug across section from 6290'-6635'. POOH. o RIH with 8.5" drilling assembly and dress cement to 6400'. Directionally drill ahead and kick off at 6495'. Drill ahead at least 20' before displacing well to drilling fluid (to avoid cement contamination of fluid). Drill section to TD of 9502' as per directional plan. 6. M/U and run 3157' of 7" solid L80 IBT liner to hang off depth in 9-5/8" of +6345'. Cement liner in place, and set liner hanger/packer. 7. RIH with 6" drilling assembly with 4 phase resistivity LWD and tag TD of new hole. Displace well to Quikdriln, and drill section to TD of 13367' as per directional plan. 8. RIH with DPC conveyed Platform Express logging string and log well from 7" liner shoe to TD. , M/U and run 2010' of 4-1/2" solid 13Cr80 NSCT liner with 2010' of 4-1/2" slotted 13Cr80 liner to hang off depth in 7" of 9346' (_+200' above Sag River). Cement liner in place with the Banzai cementing technique, and set liner hanger/packer. 10. R/U and run 5-1/2" x 4-1/2" 13Cr80 completion with 5-1/2" SSSV, 7"x4-1/2" production packer set at +9246', 5 GLM's, and standard WOA tailpipe stabbed into 4-1/2" liner top. Circulate freeze protection to _+2,200'MD. Land completion and set packer. R-18a Sundry P&A Procedure Page 3/3 11. Set and test TWCV, ND BOP, NU tree. Pull TWCV and set/test BPV. RDMO. Prepared by: llXra~rs 2ES Ops Drlg Engr Chris Brown Nabors 2ES Operations Drilling Engineer (Office) 564-5582 (Home) 346-3773 (Pager) 275-1835 R18A WELLHEAD: McEVOY m KB. ELEV = 49.03' BF. ELEV = 20.81' ACTUATOR: OTIS --T ~----- / ~1 -- -- -- SSSV LANDING NIPPLE I 103,8', 72 #~, ~ i:// ~GAS LIFT MANDRELS L-80, BTRS / ~ (OTIS W/RA LATCH) ,, / / s 3o~s' 2ess' I o.: I / .... ·· m ~l3 81~' 7242' ~~ ~ ~ ~ e~' 7~9o' ~ IJ4S TUBING (IPC)m OAPAOmTY: ,0~8~ BBU~ ~ ~ ~ m ~m ---Olm~ ~UDm~ ~V~ ) ~mm : 2 718" LINER' m ~ .... IN- --A .... Y I mI , FL4S FLUSH }T, S. lS~/~, ~ I ~ - -- ,uu u~ ~ . I ~0311 ' 2.372' MIN. ID. CAP 0 0-579 B--'FT ~ ~ ~-- ~-~/8' BOT PACKER I ,I / / TAILPIPE TOP OF 2 718" LINER AT 9,101 ~ -- -- BKB. LINER IS SETTING ON BTM -) -- -- 6 1/2' JXN"NmPPLE NOT CEMENTED 4' OD ENTRY , TLS,,44 , I ~l~,m U 3 ' , O , . 55" ID G roDE, [ ,12' mD] / ', ' ' ' TOP OF ~ __~ I~ ~ 5 1/2' TBG TAIL WLEG I 7" LINER ~ ~ ~ I g ~8", 47~/fl, (ELMD) I Qt~m L~0, BTRS ~ ~ k .... P;RFORAT,O. SUMMARY ~~ . ; S~z~ SPF' ~NTERWL OPEN/Sm'D ~ 1 : ~ [ NhTF. CTD SIDETRACK: 3,75" HOLE ~ I ...... DR,LL~D TO ~.0~ FT B~, ~ ~' . ~ .~.' SQZO/~.~ ~ ~ ,LO,T COLL*R*~ ~.0~= 98~' CMNT PLUG ~ ~ Top of cement plug ~ 9~4 ELMD-11/14~5 ~3 1~ 4 9~ 9878 SQZD/~4 91 , " ' ' ~ ~ Milled ~ndow ~n 9~6 and 9810 ~33~" 6 9922- 9952' SQZD11-15-9{ ~ ~ MD 11117195 4 9952 9968 SQZD/~91 ' ' ' ~ ~ Whi~t~k ~t ~ 9~3 ELM~11/1 CID ;HDET tACK PERFORAT ON SUMMARY ~ ~ m m mm m---- ~ARKER JOINT m 10 066'm 2' 4 iOiO0-iOi30 ~ ~ m m m 2' 4 iO~O-i~60 m ~ ~ mBP SET AT 9973' ON ~1-90', 2" 4 11~1-11041 ~ NOTE: TH S IBP WAS FOUND TO BE AT ~ ~ 10,0~' OORR WLM ON 7-28-91. (12" OF ...... ~ PRONG & FULL RUBBER ELEMENT WAS I RECOVERE~), p.TD 110.5601 IJ~ ' iii DATE REV. BY COMMENTS PRU~HOE BAY UNIT g'g~l INITIAl C~MPl ~TION ~S ~w~ WELL: R-18 A ~-~-12-1~) 12/~/~ RRW CTn HORIZ SIDETRACK. ~ 7/8" LINER APl NO: 60~2~ 206~ 1/14~ pJc ADD PERF 1/P~6 PPA Add Parrs SEC 32: TN 12N: RGE BP Exploration (Alaska) GAS LIFT MANDRELS OTIS W/RA LATCH) N~ MD(BKB) TVDss 6 3015' 2965' 5 5220' 4877' 4 6938' 6187' 3 8180' 7242' 2 8754' 7758' 1 8g02' 7890' ~BE: 6' McEvoy KB ELEV ~49 3' ~BLLNEAD U~voy R-18a (Pre-rig Status) OR,GN,AL KB ELBV = 4903' BF ELEV=2081' DIESEL FREEZE PROTECTION AT +/- 2200' MD SSSV LANDING NIPPLE @ 2~67' ( OTIS)(ID = 4562* ID) DV PACKER @ 2642' CUT @ +/-7000' OIL/GAS FLUIDS~ 7 34PPG TOP OF CEMENT @ +/-8000' SLIDING SLEEVE @ 8972' (OTIS XA) TUBING SBAL ASSY TD @ 11066' DATE ~'~EV BY ~ COMMENTS PRUDHOE BAY UNIT WELL: R-ISA APl NO: 50-029-20633-01 BP Exploration (Alaska) TREE: 6~ McEvoy WELLHEAD: McEvoy R:isb EHST (Pr°p0~d) ~ ORIGNIAL KB ELEV = 49 03' BF, ELEV=2081' 68PPG DIESEL SSSV LANDING NIPPLE @ 2200' ( BAL-O)(ID = 4562~ ID) DV PACKER @ 2642' CEMENT PLUG FROM 8290'- 6635, KiCK OFF @6495' SECTION MILLED 6490'-6535' FOR KICK OFF @ 6495' TUBING CHEMICAL CUT @ +/-7000' -- TOP OF CEMENT @ +/-8000' (OTIS XA) TUBING SEAL ASSY @ 9034' 2-7/8" 7* LINER HANGER 66345' 4-1/2" PRODUCTION PACKER @~9240' 4-1/2" LINER BANGER 6"'rD @ 13367' 69346' "BANZAi" ( ISOLATION PACKER @~11357' 8-1/2" TD @ 9502+ 4-1/2" X/X/XN WOA 13Cr-80 NSCT TAILPIPE@ ~9340' SLOTTED LINER TD @ 11068' 6-8-98 CJ~ Pre-dq Status __ PRUDHi;)j~ BAY UNIT WELL' -J~c.lJtb APl NO: 50-1329--2~632.,,f)2 BP Exploration (Alaska) hare. d .ry!ces '"l nll ng AlaSka ~ WELL NAME DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET IThe attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. I "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one category per cover sheet) DRILLING PERMIT Permit Documentation Prepared: ODE: Date: ~i Permit Application Reviewed: SDE/ES' Date: Permit Application Submitted: TA: Date: PRE-RIG WORK I~ Pre-Rig Memo Reviewed: SDE/ES: ~') ~-,~, .~ Date:f, lq'i~ ~ ere-Rig_~~ ._~ent to Slope: '' ODE7~~ ~_ Date: ~ Pre-~~ ~ Documentation Prep~d~ ~ODE: (¢~~ Date: ~~ Pre-~~[~ Application Reviewed: Pre-~u~d~ 6pplkc~ion Sub~~: SUNDRY NOTICE ,~, SouDnEd.. ry ~Lg, ~ntation Prep ar;~[e: ['~ Sundry/~plication Reviewed: SDE/ES: Date: [~ Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK~ USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply) Abandon Change Approved Program Alter Casing Operation Shutdown Suspend Re-enter Suspended Well Repair Well Time Extension Plugging Perforate Pull Tubing Stimulate Variance Other(Explain): I APPROVAL TO PROCEED I Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: ~ C()HPLETZON :(..:,,ATE 1~/'" )o /Cl ~,~,'" DAILY W E i... I.... ,,,',, dr'i/ dS'tch s,¢:~mp'ies W,5: s t h e v?,:r: 'i i c: c., r' e d ? We 'J i "i s we'ii l.:es'ts r"equ'ir"ed? l.)¢es 'i /] C 0 I'l~}.) '1 'i ,.~ i"/C E:'; ._~ ]: n 'i '-i: 'i' a 'i C ,'._'., H H E i'.] T S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR FIECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPEhDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 95-128 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 5o-029-20633-01 4. Location of well at surface 9. Unit or Lease Name 3406' SNL, 3613' WEL, SEC. 32, T12N, R13E ~ :.. i .ii?i:: ~i,;~-/~O6&'hC.~!~ Prudhoe Bay Unit At Top Producing Interval.: :~L,/~,, ~/',¢~ :'ti~ ~,~-'77'~'/~i~"~-'i~:~': }~. ~,, ~i. lO.R. 18AWOII Number 5236'SNL, 2828' WEL, SEC29, T12N, R13E ~; I1.~ ~ 11. Field and Pool At Total Depth : ~pj;!i; :! ~..::~.~~. ~ ,-- ~,.-~..._ .. '~' '-.-~ ............ Prudhoe Bay Field/Prudhoe Bay Pool 856'NSL, 2151' WEL, Sec.29, T12N, R13E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 49.03 KBI 028278 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 12/5/95 12/26/95 12/30/95I N/A feet MSL one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11066' MD 8885ss 11034 md; 8884 tvd YES [] NO []I 2167feet MDI 1900' (approx.) 22. Type Electric or Other Logs Run Gamma Ray Lo~l from 11047 to 9738'MD 23. CASING, LINER AND CEMENTING RECORD SE-FFING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Surface 110' 13 3/8" 68# NT8OOYHE Surface 2672 17 1/2" 3720 c.f. 9 5/8" 47# NT80 Surface 9742 12 1/4" 1465 c.f. 7" 26# L-80 9271 10625 8 1/2" 375 c.f. 2 7/8" 6.16# FL4S 9101 11066 3 3/4" Non cemented 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 11020'-11030'MD (10 ft, 4 spf) 8884' TVDss 11031'-11041'MD (10 ft, 4spf) 8884' TVDss 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Jan 16,1996 I GL Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SlZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. FEB 99G Aiaske. 0il & Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE Logging Services To: Pmdhoe Bay Log Recipients From: Rodney D. Paulson Subject: Re-release of R-18A SS TVD Plot Date: 7 February 1996 The SS TVD plot for R-18A as it was presented in the field was 49' shallow due to a double correction for KB height. Enclosed is a corrected copy of the blueline log. Please replace your exisiting Final Print with the one enclosed. I apologize for any inconvenience this may cause. Western Atlas International, Inc. 5600 B Street, Suite 201 Anchorage, Alaska 99518-1686 Tel (907)563-3233 Fax (907)563-7803 Thank you, Rodney D. Paulson Geoscience Center Manager LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE.: 7 February 1996 Transmittal of Data ECC #: 6554.00 Sent by: HAND CARRY Data: IEL Dear Sir/Madam, Reference: BP R-18A PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 CORRECTED SSVD BL+RF Run # 1 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FA~,to (907) 563-7803 ~~/ Date: i' bt:ivbD 30. GEOLOGIC MARKERS I-ORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Shub/ik A 9857 8750' ss Sa dlerochit 10018 8823' ss ,.' . .~ , .~ _ ~. · ~.~ G~.~s Cons. Com.mi~:.sion .AJa~ka 0it & ......... 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~v / / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Daily Operations Well: R- 18A Accept: Dec. 05, 1995 Field: Prudhoe Bay Spud: Dec. 14, 1995 APl: 50-029-20633-01 Release; Dec. 30, 1995 Permit:95-128 CTD Unit: 4985/4905 Date Day Depth 12/05/95 1 9831 BEGIN RIG UP CTU. SET BOP'S, FLOW CROSS, CHOKE MANIFOLD, SET SUBSTRUCTURE. PU TOWER SECTION #1. SPOT 985 TRAILER AND OPS CAB. SPOT BP GENERATOR, LIGHT PLANT, AND RADIUS TRAILER OFF TO SIDE. SHUT DOWN FOR NIGHT. 12/06-07/95 9831 UNABLE TO WORK DUE TO PHASE 2 WEATHER CONDITIONS. 1 2/0 8/95 2 9831 FINISH RIG UP OF TOWER AND INJECTOR. RIG UP HOSES. SPOT TRAILERS AND HOOP UP PWR, LUBRICATOR, LIGHTS, WIRE UP CAMCO BHA UPPER CONNECTOR 12/09/95 3 9831 CONTINUE TO MU CAMCO BHA. WO SQUEEZE UNIT. RU SAME. PERFORM FULL BOP TEST. PU MONEL. 12 10/95 4 9831 PRESSURE TEST BHA. CAMCO BHA LEAKING, ORIENTER PISTON SEAL BAD. MU OTHER BHA. CIRC COIL OVER TO 85° FSW TO WARM UP PRIOR TO PRESSURE TESTING. RADIUS TOOL SHORTING OUT WHILE CIRCULATING. ORIENTED OK. TOOL SHORTED. TROUBLE SHOOT SAME. SIGNAL STARTED COMING BACK (STEERING ONLY). ORIENTED. TOOL SHORTED AGAIN. RAN IN TO 4500 FT. DE-GASSED WELLBORE DOWN WING. TOOL SHORTED WHILE GOING IN HOLE. PULLED BACK OUT. BROKE OFF RADIUS COLLAR- RADIUS TOOLS WORKING FINE. CAMCO RADIUS WIRE SHORTED. LAY CAMCO TOOL IN TRAILER. BROKE UPPER CONNECTOR- WATER IN DIELECTRIC FLUID. RADIUS WIRE SHORTED 1 2/1 1/95 5 9831 WAIT ON 1ST BHA TO ARRIVE. MU BHA AND RADIUS TOOL. RETRIEVED MEOH AND WARMED COIL WITH SEA WATER. FUNCTION TESTED BHA AND CHECKED ELECTRICALS. EVERYTHING OK. MADE UP BENT MOTOR AND BIT. RAN IN HOLE. LOST RADIUS SIGNAL AT 5900 FT. PULLED BACK OUT. BROKE RADIUS AND CAMCO APART. RADIUS TOOL CHECKED OUT OK. CONNECTOR LOOKED OK. CAMCO THROUGH WIRE SHOWING DEAD SHORT AGAIN. LAY CAMCO BACK IN TRAILER. P/T BHA HYDRAULICS- NO APPARANT EXTERNAL LEAKS. BROKE OFF UPPER CONNECTOR AND FOUND WATER IN THE DIELECTRIC FLUID AGAIN. TRIED PUMPING OIL THROUGH THE ENTIRE CONTROL LINE TO CATCH OIL SAMPLE AND CHECK FOR WATER- NO FLOW. PLUG IN CONTROL LINE- PROBABLE ICE PLUG. DISCUSS WAYS OF FLUSHING WATER OUT OF CONTROL LINE. DECIDE TO MAKE END CONNECTOR FOR A'FI'ACHMENT TO UPPER CONNECTOR SO OIL CAN BE PUMPED THROUGH THE LINE AND INTO THE WELLBORE. 1 2/1 2/95 6 9831 WAIT ON REPLACEMENT BHA AND FLUSHING TOOL TO ARRIVE. ATTACH FLUSHING TOOL. RIG UP N2 AND HOT OIL UNIT. RETRIEVE MEOH AND WARM COIL W/200F WATER. DlSCPLACE CONTROL LINE W/ 45,000 SCF, 350 SCF/MIN, 6900 PSI. SWITCH TO FRESH DIELECTRIC FLUID AND RE-FILL CONTROL LINE. RIH PUMPING HOT WATER AND DIELECTRIC FLUID TO OVERFLUSH CONTROL LINE. GOT TO 5600 FT AND WT INDICATOR QUIT. INSPECTED CABLE AND REPAIRED SUSPECT WIRE BUT FIX DIDN'T WORK. DECIDE TO PULL OUT. CONTINUE PUMPING DIELECTRIC FLUID. FRZ PROTECT COIL., ,~,,~, .~ ,~,, ~ '~,¢ ~! ~.~¢~~'-~ ~"~" ( ~ ~'¢ '" ' " """" FEB 0 2 15 9S Oil & Ga..'~ Cons. Commiss. ion Anchorage 1 2/1 3/95 7 9831 FINISH PULLING OUT. REPAIRED DAMAGED WIRE ON WT INDICATOR PANEL. MU BHA. GO IN HOLE. WT INDICATOR QUIT AGAIN @ 2000 FT. CHECK OUT WT CELLS, CABLES, ETC. FOUND BAD GROUND WIRE TO WT METER CAUSING DRIFT. REPAIR SAME. RIH. TAG BTM @ 9833 CTD. PU TO ABOVE WHIPSTOCK. ClRCWATER TO MONITOR BHA- EVERYTHING OK. SWITCH TO 29 BBL HI-VIS SWEEP FOLLOWED BY FLOWPRO MUD. WITH 50 BBL OF MUD OUT THE COIL, BEGAN GETTING GAS CUT SEA WATER BACK. CONTINUED SWAP WHILE MONITORING GAS. GAS NOT DECREASING. RETURN DENSITY VARYING FROM 6.5-7.5 PPG. AT 108 BBL MUD PUMPED DECIDED TO ABORT MUD SWAP, NOT TO GAS CUT THE FLOWPRO. SWITCHED TO SEAWATER AND LAYED REST OF MUD IN THE COIL INTO THE HOLE. TOP OF HI- VIS PILL @ 4500 FT. CIRCULATED SEAWATER ABOVE MUD. GAS CUT WATER SLOWLY DECREASED. CALL OUT TRUCK TO LOAD IAAND CUT OFF SOURCE OF GAS. 1 2/1 4/95 8 10048 LIQUID PACK lAW/93 BBLS DSL, 112 BBLS SW. SWAP BACK TO MUD. SOME GAS ENTRAINED IN MUD RETURNS. TAGGED AND DRILLED 46'. BUILDING ANGLE. RUN GR TIE-IN (+27' CORRECTION). THIS PUTS THE WHIPSTOCK AT 9818', WINDOW FROM 9823'- 9829', PILOT HOLE TD AT 9841'. DRILLED TO 9930'. DRILLING BREAK. 50% LOST RETURNS AT 9950'. ("SMALL FAULT IN TOP OF IVlSHAK.") DRILL AHEAD. RETURNS IMPROVED TO 95%. PULLED MOTOR @ 9989 FT. RAN IN W/.5 DEG TANDEM MTR AND RE-RUN BIT. CORRECTED 12 FT. DRILLED FROM 9989 TO 10048. NEW MTR BUILDING AT 6 BEG/100. PICKED UP BRAG FROM IN THE NEW HOLE DUE TO THE BUILD RATE CHANGE. REAMED CHANGE OVER AREA TO REDUCE DRAG. 1 2/1 5/95 9 10217 REAM AREA BETWEEN 9970-10020 THEN TO TD. HOLE CLEANING UP. DRILL AHEAD TO 10157'. WIPER TRIP TO THE WHIPSTOCK. ENCOUNTERED TIGHT HOLE WHILE REAMING DOWN FROM 9945' - 9955'. (SMALL FAULT ENCOUNTERED HERE YESTERDAY). REAM UNTIL CLEANED UP. BHAWEDGING FROM 10033'- 10048'. DRILLED TO 10183'. UNABLE TO MAKE ANY MORE HOLE. CAN'T BUILD ANY MOTOR DIFFERENTIAL. RUN LOGGING PASS. GEOLOGY PICKING TSAD @ 9820' TVDSS. SLOW DRILLING OCCURRING IN PYRITE. ATTEMPT TO REAM BACK DOWN. PACKED OFF AT 9875'. POOH. CHANGED MOTORS. FOUND INJ HD BEARING BROKE AND REPLACED SAME. RAN IN. TAGGED FILL ON WHIPSTOCK- WASHED OUT SAME. TAGGED BRIDGE @ 9875 AND WASHED THROUGH. TAGGED LEDGE WITH BHA @ 10006 FT. WORKED PAST AND WASHED TO BTM. CONTINUED DRLG TO 10217FT. 1 2/1 6/95 1 0 10575 CONTINUED DRLG TO 10287'. SURVEY. PROBLEMS GETTING IT TO SLIDE AGAIN. WIPER TRIP TO THE LINER. PROBLEM AREAS: 9875' (PACKING OFF- SOLIDS SETTLING), 9950' (PACKING OFF - FAULT), 10030'- 10045' (CROOKED HOLE). DIFFICULT TIME GETTING THROUGH WINDOW. WASHED OFF. STILL SNAGGING WITH ANY PUMPING. ABLE TO GO THROUGH WITHOUT PUMPING. STILL STACKING OUT ON BOTTOM. PUMPED 25 BBL 3% LUBETEX SWEEP. STARTED DRILLING, HARD AND SLOW AT FIRST. PYRITE CUTTINGS? DRILLED TO 10328'. SURVEY. PROBLEMS GETTING STARTED AGAIN. WORK PIPE. BRIEFLY STUCK. PULLED FREE @ 80K#, 35K# OVER. WIPED HOLE. CLEAN. NO OVERPULL. TAGGED AT 10046' WHEN WASHING BACK TO BOTTOM. RAN GR LOG 1.5 BPM. SWEPT LINER W/70 BBL VIS PILL. WENT BACK TO DRLG. DRILLED TO 10570 (ACROSS FAULT). RAN GR CORRELATION. PULLED FOR MOTOR CHANGE TO BIGGER BEND. NEED MORE TURN. 1 2/1 7/95 1 1 10575 POOH. BIT BADLYWORN, BUT GAUGE IS 3.7". CAMCO BHA MISSING TEFLON SLEEVE AND BANDS. REPLACE SAME. CHANGE OUT TO 1° MOTOR. PT 2000. RIH. LOST ORIENTER NYLON COVER SLEEVE AND ITS TWO MOUNTING CLAMPS, TWO DISCONNECT COVER SCREENS, AND AN ORIENTER SET SCREW. PERFORMED WEEKLY BOP TEST. SWITCHED CAMCO BHA. PRE-WARMED BHA WITH SEA WATER, PRESSURE TESTED BHA TO 1500 PSI. ADDED MOTOR AND RAN BACK IN. 12/1 8/95 12 10575 FEB 02 1 9¢ ,~,Jas. ka Oil & G~m Corns, Commk-sio~ Ar~ch(~ra~qe WAIT IN 7 INCH LINER FOR MI GENERATOR TO BE REPLACED. RUN GR TIE-IN (+14'). SLOWLY REAMED/BACK REAMED HOLE TO 999O'. ClRC PRESSURES NOT INDICATING MUCH MOTOR WORK. SOME REAMING DONE BETWEEN 9935 - 9950'. STALLED AT 9970'. TAGGED AT 9990'. UNABLE TO ORIENT BACK TO HS. WHILE PUH, TIGHT AND PACKING OFF AT 9970, 9957, 9946, 9915 AND THE WHIPSTOCK. DIFFICULT TIME GETTING BACK THROUGH THE WINDOW. DRAGGING SOMETHING WITH US. ORIENTER STILL NOT WORKING. POOH. LD BHA. SEVERAL TEETH BROKEN ON THE BIT. RIGGED UP WL AND RAN 3.74" LIB. BOBBLED @ 9801 WLM AND CAME TO GENTLE STOP @ 9814 WLM. NO PICTURE. RAN 3.85 LIB AND TAGGED UP @ 9801 AGAIN. PICTURE LOOKS LIKE TOP OF WHIPSTOCK. TRIED ANOTHER RUN WITH 3.85 LIB AND COULD NOT GET INTO 7 INCH LINER THIS TIME. RD WL. GETTING XO SUB BUILT, WHILE WO WEATHER, TO RUN CAMCO UPPER CONNECTOR AND DISCONNECT WITH 2-7/8 MOTER AND MILL. WILL TRY TO MILL UP REMAINING JUNK IN HOLE BEFORE PROCEEDING WITH DRILLING. 1 2/1 9/95 1 3 10575 PHASE 3 WEATHER 1 2/20/95 1 4 10575 PHASE 3 WEATHER 1 2/2 1/95 1 5 10575 WAITED ON WEATHER TO BREAK. WAIT ON SNOW REMOVAL. DUG OUT LOCATION-BIG JOB. REPLACED DOWN HEATERS. MAKE UP CAMCO DISCONNECT. REPAIR DAMAGED BJ CABLES. WORK ON BJ AIR SUPPLY. FILL UPPER CONNECTOR WITH DIELECTRIC FLUID. WIND CHILL STILL -64F. TAKE XO BACK TO MACHINE SHOP AND OPEN ClRC HOLE TO 3/8" WHILE FINISH PREP WORK. 1 2/22/95 1 6 10575 MADE UP 3.72 MILL AND MOTOR. RAN IN HOLE. NO PROBLEM GETTING INTO OPEN HOLE. WASHED DOWN TO 9926 BEFORE STALLING. WASHED DOWN TO 10012 AND STALLED AGAIN. STALLED SEVERAL TIMES TRYING TO GET THROUGH DOGLEG AREA 9990-10030. COULD NOT GET AROUND DOGLEG AREA WITH MILLING BHA. TRIPPED TO WINDOW AND WENT BACK DWN. ACTED LIKE DRAGGING JUNK ON THE WAY UP. TAGGED UP HIGH AT 9918-ACTED LIKE THE TEFLON MATERIAL BUT NOT SURE. GOT IT MOVING DOWN AND CHASED IT TO 10028. COULD NOT GET AROUND KINK WITHOUT STACKING OUT. PULLED MILL TO INSPECT TOOLS. SLIGHT JUNK MARKS ON MILL BUT GAUGE HEAVILY WORN FOR SIDE LOAD WORKING THE MILL IN THE DOGLEG AREA. WILL PICK UP USED BIT AND WIPE OUT DOGLEG WITH FULL CAMCO/RADIUS BHA BEFORE PROCEEDING WITH MILLING/DRILLING. 1 2/23/95 1 7 10610 PU CAMCO BHA ¢2 AND RR BIT. PRESSURE TEST AND TIH. WASH AND REAM THRU DOGLEG SECTION AND GR LOG 10100'-9900' FOR CORRELATION. WASH AND REAM 9900'-10100' AT VARIOUS ORIENTATIONS TO SMOOTH DOGLEG. CONTINUE HAVING PROBLEMS AT 9965-9990'-WASH AND REAM THIS INTERVAL THEN WASH DWN TO BTM SLOWLY. TAGGED BTM @ 10580 CORR DEPTH. MILLED/DRILLED AHEAD TO 10610. PROGRESS SLOW DUE TO JUNK AND DAMAGED BIT. WILL DRILL A LITTLE MORE TO CHECK MTR BUILD THEN TRIP BIT. 1 2/24/95 1 8 10610 POOH. LD BIT, PU MILL W/CAMCOBHA#2. WORKED OPEN HOLE AND MILLED JUNK ON BTM. DRILLED 3 FT OF NEW FORMATION. PULLED OUT. SMALL SCARING ALONG EDGE OF MILL FACE. PICKED UP RR BIT AND 1 DEGREE BENT MOTOR. HAD TROUBLE GETTING INTO WHIPSTOCK THIS TIME. HAD TO ROTATE IN @ .75 BPM WITH 90R TOOLFACE. WASHED OUT SETTLED SOLIDS IN BUILD SECTION. WASHED TO BTM. STARTED ON JUNK IN HOLE- TRYING TO SPIN, BUT QUICKLY GOT BACK TO FORMATION DRLG. PROBABLY JUNK WAS MAINLY A PIECE OF TEFLON. 1 2/25/95 1 9 10968 CONTINUE DRLG FROM 10622 TO 10968. FINISH BUILD TO HORIZONTAL THEN TURN LEFT USING 65-85 LEFT MTR ORIENTATION. HAD TO COPE WITH SPINNING JUNK UNDER BIT FREQUENTLY, REDUCING DRLG EFFICIENCY. INCREASED LUBETEX FROM 2 TO 2.5% TO IMPROVE HOLE DRAG. NO HOLE PROBLEMS. 12/26/95 20 11072 CONTINUE DRILL AHEAD AND SURVEY. DRILL TO 11072', SURVEY AND GR LOG TO 9700. CIRCULATE AND CLEAN HOLE FOR OPEN HOLE LOGS. (PROJr:CTED CO-ORDINATES AT 1107'2' MD -INCLINATION = 87.8°, AZIMUTH - 10.8°, VERTICAL SECTION = 4514.8, N/S = 4277.0, E/W = 1447.1, DOG LEG/100' = 3.9°). BHA FLOODED JUST BEFORE PULLING OUT. FOUND UPPER CONNECTOR FLOODED W/ FLOW PRO. CLEANED UP AND RE-SOLDER SOME CONNECTORS. ALSO FOUND BEARING OFF ON INJ HEAD, SEIZED BEARING, AND BROKEN PIVOT BEARING BOLT. REPAIR SAME. FINISH CHECKING WIRE CONTINUITY. 12/27/95 2 1 11072 REPAIR BEARINGS ON INJECTOR HEAD. RE-WIRE UPPER CONNECTOR. PU ATLAS LOGGING TOOLS. PRESSURE TEST, RECOVER MEOH, TIH. RIH SLOWLY IN OPEN LOGGING PUMPING .5 BPM. NO PROBLEMS GETTING TO BTM. DID NOT TAG BTM WITH TOOL STRING. CIRCULATED CLEAN @ 2 BPM THEN LOGGED FROM 11038 TO 9592 ELMD. LOG TIED INTO BHCS DATED 9/5/81. CORRECTED WELL TD 11066 FT. REClPRICATED IN 7 INCH LINER FOR CLEANOUT THEN PULLED OUT. LAY DWN ATLAS TOOLS. PREPARE TO RUN CASING. 1 2/28/95 22 11072 LAY DOWN ATLAS LOGGING TOOLS. CHANGE OUT RAMS IN BOP. RUN HYD CONTROL LINES FOR WINCH. INSTALL ANNULAR PREVENTOR. PURGE HYD HOSES TO BOP'S. LAY OUT LUBRICATOR SECTIONS. INSTALL WINCH SHEAVES. PURGE WINCH HYD LINES, CHANGE OUT ONE PLUGGED HOSE. INSTALL 80 FT CHOKER LINE IN TOWER, SHACKLED TO MAIN WINCH LINE. 1 2/2 9/9 5 2 3 11066 (corr from Atlas GR/Ind. log) PRESSURE TEST BOP'S. RIG UP GBR POWER TONGS. RUN 63 JOINTS OF 2 7/8" FL4S TUBING USING WINCH IN TOWER. RIG DOWN GBR POWER TONGS. 1 2/30/95 24 11034 PBTD M/U BAKER DEPLOYMENT SUB AND GS RUNNING TOOL, PRESS TEST LUB, RIH WITH LINER, TAG TD 3 F-I- SHALLOW AT 11,063 FT CTD. ClRC HOLE CLEAN AND CONDITION FLOPRO. ClRC 20 BBL OF BLEACH AROUND LINER, RELEASE FROM LINER, POOH WITH CT, FREEZE PROTECT 5.5" TUBING FROM 1800 FT TO SURFACE. BOTTOM OF LINER IS AT 11,066 FT BKB, TOP OF LINER IS AT 9,101 FT BKB. 1 2/3 1/95 25 11034 PBTD FREEZE PROTECT 5.5" TUBING FROM 1800 FT TO SURFACE. DISPLACE CT WITH N2. DIG OUT AND RIG DOWN EQUIPMENT 1/0 1/96 26 11034 PBTD RIG DOWN CTD TOWER WITH 140 TON CRANE, DIG OUT EQUIPMENT FROM SNOW DRIFTS. LOAD OUT SUB- STRUCTURE, OPS CAB, AND REEL TRAILER. ND BOP, NU SWAB VALVE. MOVE OUT REMAINING CT DRLG EQPT. 1/17/96 WELL FLOWING THROUGH TRICO SEPARATOR. RU CT TO RUN DRIFT PRIOR TO PERFORATING. DRIFT STOPPED AT 9445'. RIG DOWN FOR NIGHT. ~t/~,~ t~,, ~ ~ 1/18/96 RIHWITH 1.75"TOOLS. JETTED FILL FROM9436' TAGGED HARD AT 11030'. POH JETTIN~.F_.B 02 1/20/96 RIH WITH 2" PERF GUN. COULD NOT GET BELOW 9536'. POH. CT UNIT DEVELOPED A PROBLEM WITH THE REEL SUPPORT. RD. MIRU CAMCO 4906. JETTED WITH BIOZAN TO CLEAN LINER TO 11035'. 1/21/96 COMPLETED CLEAN-OUT. MADE DRIFT RUN TO TD. RIH WITH 10' PERFORATING GUN. PERFORATED 11020 - 11030'. POH 1/22/96. PERFORATED 11031 - 11041. POH. RIG DOWN. TREE: 6" McEVOY WELLHEAD: McEVOY ACTUATOR: OTIS R-1 8A - completion DV 2642' 13 3/8", 72 #/ft, I I L-80, BTRS 2700' KOP: 2800' MAX ANGLE: 42° @ 5700' 5 1/2", 17#/ft, L-80, IJ4S TUBING (IPC) TUBING ID: 4.892" CAPACITY: .0232 BBL/FT PERFORATION SUMMARY Referance IEG-GR-SP LOG 12/27/95 SIZE ISPFI INTERVAL OPEN/SQZ'D 2" I 4 I 11020-11030 OPEN1/22/9~ 2" I 4 I 11031-11041 OPEN Top of 2 7/8" liner 9,101' 7" LINER 9253' 9 5/8", 47#/ft, L-80, BTRS I 9770' I 2 7/8" FL4S Liner Top of abandonment cement approx. 9860' 2 7/8" liner shoe @ 11066' PBTD @ 11034'. I 10,066'I MARKER JOINT %%% PBTD [10:560']- 7", 26#/ft, L-80, IJ4S 110~625'1 ~ KB. ELEV = 49.03' BF. ELEV = 20.81' SSSV LANDING NIPPLE ( OTIS)( 4.652" ID) GAS LIFT MANDRELS ( OTIS W/RA LATCH) Nm MD(BKB) TVDss 6 3015' 2965' 5 522O' 4877' 4 6938' 6187' 3 8180' 7242' 2 8754' 7758' 1 8902' 7890' OTIS SLIDING SLEEVE I TYPE "XA" (4.562" ID) 8972' 5 1/2 .... X" NIPPLE ( OTIS ) ( 4.562" ID) 5 1/2 .... XN" NIPPLE ( OTIS ) ( 4.455" ID) 5 1/2" TBG TAiL WLEG TUBING SEAL ASSY. 9031 '1 ~ 9-5/8" BOT PACKER I9055'J ( 3H ) (4.750"1D) 5 1/2", 17 #/ft, L-80 BTRS TAILPIPE 9105'1 9153'1 9196'] (ELMD) 9166'1 NOTE: TUBING TAIL IS ABOVE 7" LINER TOP. SAG R. SHUB. SADLER. PRUDHOE BAY UNIT WELL' R-18 (34-29-12-13) APl NO' 50-029- 20633 SEC 32; TN 12N; RGE 13E BP Exploration (Alaska) UnZLC^-~L~O~ UUl OO~ ~O~ Ul/U~/~ ZU:11 dOb 38 Page 2/8 DRILE Company : BP Exploration Inc, Well Name : R-18~Sidetrack Date : January 4, ~199~ Field : PBU (Prudhoe Bay Alaska) Drilling Engineer : Brock Williams, Tedd Stagg (BP) Operators : Bill Bland and Mike Murphy (Radius) Plane of Vertical Section: 20.43o Declination Magnetic to TrUe : 29.49 Grid Convergence to True : 1,03 Inteztoolated Point : None Whipstock/KOP : 9826' MD Tie In Point (Actual) : 9800' MD Comments : , George g~ban, Tom Tr~/nk, Philip ~4arwood Date_~~~~_~ Tese survey are corrected to True North and also the North/South & East West offsets are calculated relative to true North, ~D Ine Dir SS T~D Vseo N/(-S) E/(-W) Build Turn Dleg Comments 9800.0 22.00 35.23 8698.2 3416.8 3397.4 666.9 0.0 0.0 0.0 Tie in Point 9826.0 22.00 35.03 8722.3 3426.2 3405.4 672.5 0.0 -0.8 0.3 Whipstock 9854.0 29.50 35,03 8747.5 3438.0 3415,3 679.5 26.8 0.0 26.8 9869.0 34,40 37.53 8760,2 3445,6 3421.7 684.2 32,7 16.7 33.8 9891,0 44,50 47.03 8777.2 3458,5 3431,9 693.6 45.9 43.2 53.4 9921.0 55.40 51,03 8796.5 3478.6 3446,9 711.0 36,3 13.3 37.7 9951.0 67.40 57.23 8810.8 3500.4 3462.2 732.3 40.0 20.7 43.9 9971.0 77.00 57.33 8816.9 3~15.6 3472.5 748.3 48.0 0.5 48.0 9989,0 83.30 56.63 8820,0 3529.8 3482.2 763.2 35.0 -3,9 35.2 10019.0 85,50 58,23 8823.0 3553.6 3498.2 788.4 7,3 5.3 9.1 100~9,0 87.10 58.33 8824,9 3577.3 3514.0 813.8 5.3 0.3 5.3 10089.0 87.40 57.43 8826,8 3609.0 3535,2 847,7 0.8 -2,3 2,4 10139.0 87.20 54.83 8829.2 3649.5 35~3.1 889.1 -0.4 -5.2 5.2 10179.0 86.60 53.03 8831.3 3682,8 3586.6 921.4 -1,5 -4.5 4.7 10219.0 87.90 51.93 8833,2 3716.7 3610.9 953,1 3.3 -2.7 4.3 10269.0 87.80 49.53 8835.1 3759.8 3642,5 991.8 -0,2 -4.8 4.8 10310.0 87.50 49,53 8836.8 3795.6 3669.1 1022,9 -0.7 0.0 0.7 10348.0 85.40 49.93 8839.2 3828.6 3693.6 1051.9 -5.5 1,1 5.6 10398.0 83.40 50.13 8844,0 3871,9 3725.6 1090.0 -4.0 0.4 4.0 10462,0 80.70 49.33 8852.9 3927,1 3766.6 1138.4 -4,2 -1.2 4.4 10502.0 80,00 47.23 8859.6 3962.0 3792.8 1167.8 -1.7 -5.3 5.5 10533.0 79.90 47.33 8865.0 3989.2 3813.5 1190.2 -0,3 0.3 0.5 10575.0 79.70 47.43 8872.4 4026.1 3841.5 1220.6 -0.5 0.2 0.5 10587.0 80.40 47.43 8874.5 4036,6 3849.5 1229.3 5.8 0.0 5.8 10602,0 61.50 47.13 8876.9 4049,8 3859.6 1240.2 7,3 -2.0 7.6 10632,0 84.90 45.23 8880.4 4076.6 3880.2 1261.7 11.3 -6.3 13.0 10662.0 88.30 44.03 8882.2 4103.9 3901.5 1282.8 11.3 -4.0 12.0 Ol/U4/~rd 2.0;12 dOD ~8 Page 3/3 DRILE 10712.0 91.30 41.03 10771.0 88.90 34.23 10812 ,-0 87 .40 29.63 8882.4 . 8882.3 8883.6 10852.0 89.30 26.73 8884.7 10902.0 91.10 23.33 8884.6 '10942.0 91.10 19.93 8883.8 10982.0 90.40 16.53 8883.3 11022.0 88,70 13.53 8883,6 110~4.0 88.10 12.43 8884.5 11072.0 87.80 11.83 8885.1 I certify these surveys to be 4150.2 3938.3 1316.5 6.0 -6.0 8.5 4206.5 3985.0 1352.5 -4.1 -11.5 12.2 4246.7 4019,8 1374,2 -3.7 -11.2 11.8 4286.3 4055.0 1393.1 4.8 -7.2 8.7 4336.1 4100.3 1414.2 3.6 -6.8 7.7 4376,1 4137,5 1429.0 0.0 -8,5 8.5 4416.1 4175.5 1441.5 -1.7 -8.5 8.7 . 4455 · 9 4214 · 1 1451 · 9 -4,3 -7 · 5 8 . 6 4487.6 4245.3 1459.0 -1.9 -3.4':' 3.9 450B.4 4262.9 1462.8 -1.7 -3.3 3.7 TD true and correct to the best of my knowledge. Bimo Hadiputro (Drilex Services Inc.) C:\BP~R-lS~R-18ST01.WP LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE A~q, 99501. Date: RE: 8 January 1996 Transmittal of Data ECC #: 6554.00 Sent by: HAND CARRY Data: IEL Dear Sir/Madam, Reference: PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services Received by: 5600 B Street Suite 201 Anchorage, AK 99518 (907) 563-7803 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE Date: RE: Dear Sir/Madam, Reference: BP R-18A 4 January 1996 Transmittal of Data ECC #: 6554.00 A/~CHORAGE Sent by: HAND CARRY AK, 99501. ~//~/~ Data: IEL PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 IEL FINAL BL+RF Run # 1 1 SSVD FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street ~ Anchorage, AK 99518 Received b ~ ~_Or FAX tO (907) 563-7803 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 August 28, 1995 Brock Williams, Coil Tubing Engineer BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re' Prudhoe Bay Unit R-18A(41-29-12-13) BP Exploration (Alaska) Inc Permit No. 95-128 Surf Loc 3406'SNL, 3613'WEL, Sec 32, T12N, R13E, UM Btmhole Loc 4471'SNL, 1931'WEL, Sec 29, T12N, R13E, UM Dear Mr Williams: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling a new hole. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. Chairman ~ BY ORDER OF THE COMMISSION dlf/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrill EIIlb. Type of well. Exploratory[] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE=49. 03 f e et Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL = 28279 4. Location of well at surfaCe 7. Unit or property Name 11. Type Bond(se,, 20 ,,,Ac 25.025) 3406' SNL, 3613' WEL, SEC. 32, T12N, R13E Prudhoe Bay Unit At top of productive interval 8. Well number Number 5236'SNL 2828' WEL SEC. 29, T12N, R13E R-18A(41-29-12-13) 2S100302630-277 At total depth §. Approximate spud date Amount 4471' SNL, 1931' WEL, SEC.29, T12N, R13E 8/28/95 $200,000.00 112. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MO and TVD) property line ADL 028279 @ 1931 feet No Close Approach feet 2560 11132'MD; 8876 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 9a3~ feet Maximum hole angle 9o o Maximum surface 3330 pslg At total depth (TVD) ~00'/4~90 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) - 3.75 27/8" 6.16 L-80 FL45 11132 8876 90cu. ft. !,( t,..,, 19. To be completed for Redrill, Re-entry, and Deepen Operations.AUG 2,5 ]995 Present well condition summary Total depth: measured 10625 feet Plugs (measured) ~$~ t~i! & Gas C0rls. Co_m~_.~8. true vertical 9521 feet -'"---~. ~0ra.g.~ Effective depth: measured 9983 feet Junk (measured) true vertical 8918 feet Casing Length Size Cemented Measured depth True Vertical depth Structural -- Con ductor 110 20 x 30 8 c.y. 138 138 Surface 2672 13 3/8 3720 c.f. 2700 2700 Intermediate 9742 9 5/8 1465 c.f. 9770 8719 Production - Liner 1354 7 375 c.f. 9271 - 10625 8267 - 9521 Perforation depth: measured 9808'-9878',9922'-9932',9938'-9968',9976'-10012' true vertical 8706'-8771'~8811'-8896'(three intervals) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] ~21. I hereby_~;~_ ..~.. ,/certify th. at the forectoi, ng is true and correct to the best of my knowledge ~//~'~.///~.. Signed~d,,~/_ ~/h/~.~/~~ Title 0o,, T. Mn~ £n.,neer Date Commission Use Only Perr~t Number IAPI number tApprovsI date/ 1See cover letter F .2-0 ~ ~3- ~ / I ~/"Z..~//?,5'"' Ifor other requirements Conditions of approval Samples required [] Yes ~ No Mud Icg required []Yes ,~No Hydrogen sulfide measures ~ Yes [] No D~rectional survey requ~rea ~ Yes [] No Required working pressure for hOPE r-12M; E].3M; 1-15M; I-IIOM; []15M; '~- Other: Original Signed~y by order of ~"/~'//~ Approved by David W. Johnston Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit ir( cate R-18A Proposed Sidetrack Program Current Status Well R-18 is a high water cut producer. Existing Ivishak perforations will be abandoned and Sag R. perforations squeezed in preparation for sidetracking with coiled tubing. The sidetrack will be conducted in two phases with an operational shut down of 1 to 2 weeks between Phase 1 and Phase 2. Phase 1: Dill Window (planned for August 23 - 27, 1995) Existing Ivishak perforations will be abandoned and Sag R. perforations will be squeezed. A thru-tubing whipstock will be set on E-line at the top of the Sag R. formation and coiled tubing will be used to mill a window in the 7" liner at 9832' MD. Coiled tubing will then be rigged down and 1 to 2 weeks will lapse before drilling operations begin. Phase 2: Drill Sidetrack (planned for September 6- 16, 1995) A 3 3/4" hole will be drilled with coiled tubing to 11, 132' MD per the attached directional plan. A steering tool will be used for directional control and surveys will be taken every 25 ft. No gyro will be run. Drilling Fluid Program: Phase 1: Seawater with Biozan sweeps. Phase 2: Solids Free FIo-Pro (8.8 ppg to provide approx. 500 psi overbalance) Logging Program: A Gamma Ray Icg will be used in geosteering while drilling and will be run over the entire drilled section. A GR/Induction Icg will be conveyed on CTE prior to running a liner. Liner / Completion Program: A 2 7/8", FL4S, L-80 liner will be run to TD and cemented with 90 cu.ft cement. A PBR at the top of the liner will be located in the existing 5 1/2" tubing tail at approximately 9080' MD. The liner will be displaced to filtered sea water and perforated with CT conveyed thru-tubing guns. Well Control: BOPE schematics for Phase 1, Phase 2 and completion operations are attached. The full production tree will remain in place during all drilling and completion operations. AUG 2. ,5 1995 ~_as~ ~i! .& 6as Cons. Comm_issior~ .... -, ~chorage TREE: 6" McEVOY WELLHEAD: McEVOYR-18A - Proposed Sidetrack KB. ELEV=49.03' DF. ELEV = 20.81' ACTUATOR: OTIS SSSV LANDING NIPPLE O (s) (~D) OTI 4.652' DV ~.~'-- I~ USO, BTRS 2700' ~i k GAS LIFT MANDRELS (OTIS W/RA LATCH) N-° MD(BKB) TVDss 6 3015' 2965' KOP: 2800' 5 5220' 4877' MAX ANGLE: 42° @ 5700' I 4 : 6938' 6187' [ 3 8180' 7242' 2 8754' 7758' I 1 8902' 7890' 5 1/2', 17#/ft, L-80, ! IJ4S TUBING (IPC) TUBING ID: 4.892 ' CAPACITY: .0232 BBL/FT ~ I I OTISSLIDINGSLEEVE PERFORATION SUMMARy TYPE 'XA' (4.562' ~D) 8972' REF LOG= SWS-BHCS- 9-5-81 SIZE SPF INTERVAL OPEN/SQZ'D ~ ,~ TUBING SEAL ASSY. 9031' £ 33/8' 6 9922-9952' OPEN/8-7-91 X9055' " 4 9952- 9968' SQZD/8-4-91 ( 3H ) (4.750'1D) · 4 9976-10,022' SQZD/8-4-91 5 1/2', 17 #/ft, L-80 BTRS TAILPIPE " 6 10,038-10,042' SQZD/8-4-91 I I (51/2"0TIS 'X') (4.562"NIPPLEID) I 9105' 5 1/2" 'XN' NIPPLE I I I ( OTIS ) ( 4.455" ID) I 9153' TOPOF I I ' ' 7' LINER 9253' 2 ~ 5 1/2' TaG TAILWLEG (ELMD) 91 66' 9L.80,5/8",BTRS47#/ft, I 9770' I --'J k, NOTE: TUBING TAIL IS ABOVE 7" LINER TOP. ;,',,;,;,;,;t~k -.',',-,',-,-,-,-,-,.,,,,,.,,,,, ..... ,.. F -' '~'~'~'~'~'{J-¢-~ ............. , ~ ¢~ullm u. ~ ~. J ~, E ~ ,-,-,-,-,-,~ .............. or.v~, h- : ,..%,..""....%.,.%,.,%,., !. I _ . _ I _ ~._ "~1 I I , I I , i i i , i I I , I I I % % % % % i~--':-'-'-'-'-----'-'---~--- ........ _ ........ AUG 25 1995 "'" ............ ,,' ¢' ¢' / .." ~ ............................. ~-------------'-------'-:-:-:-:-:':;:2~ ,,',,',~,~,~! ~ ~¢as!~ ¢il & 6as Cons. Commission ' ' ' ' ' - - --~-: ............ ------:---:---------------'---------- ' ~ ~ ~ % ~'~~ZZ;Z;; ................ .... ~%¢%/~¢~ . _ ................ ;;_-_- ....... - ..... '~n ~, ,.,,._..c..rau,-' ,....%.%.% ~ ................ 0~066' ,,,,, ~ PaUDHOE ~a¥ uNrr PBTD I 10.560'1 ,;,;,;,;,;, WELL' R-18 (34-29-12-13) 7", 26~/ft, L-80, IJ4S 11o,625'1 .., APl NO: 50-029-20633 SEC 32;TN 12N;RGE13E BP Exploration (Alaska) GAS LIFT MANDRELS (OTIS W/RA LATCH) N~ MD(BKB) TVDss 6 3015' 2965' 5 5220' 4877' 4 6938' 6187' 3 8180' 7242' 2 8754' 7758' 1 8902' 7890' TREE: 6' McEVOY WELLHEAD: McEVOY ACTUATOR: OTIS R-18A - Proposed Completion KB. ELEV = 49.03' BF. ELEV = 20.81' DV 2642' 13 3/8', 72 #/ft, I L-80, BTRS 2700' IKOP: 2800' MAX ANGLE: 42° @ 5700' 5 1/2', 17#/ft, L-S0, IJ4S TUBING (IPC) TUBING ID: 4.892 ' CAPACITY: .0232 BBL/FT pERFORATION SUMMARY REF LOG: SWS-BHCS- ISIZE ! SPF I INTERVAL 9952- 9968' 9976 - 10,022' 10,038 - 10,042' 9-5-81 OPEN/SQZ'D SQZD/8-4-91 OPEN/8-7-91 SQZD/8-4-91 SQZD/8-4-91 SQZD/8-4-91 I LINER 9 5/8", 47#/ft, L-80, BTRS I 9770' I 2 7/8" FL4S Cemented Liner SSSV LANDING NIPPLE ( OTI S) ( 4.652' ID) GAS LIFT MANDRELS ( OTIS W/RA LATCH) N~ MD(BKB) TVDss 6 3015' 2965' 5 5220' 4877' 4 6938' 6187' 3 8180' 7242' 2 8754' 7758' 1 8902' 7890' OTIS SLIDING SLEEVE I TYPE 'XA' (4.562' ID) 8972' TUBING SEAL ASSY. I 9031' ( 3H )(4.750'1D) 9055' 5 1/2', 17 #/ft, L-80 BTRS TAILPIPE 5 1/2' 'X" NIPPLE ( OTIS ) ( 4.562" ID) 5 1/2' 'XN' NIPPLE ( OTIS ) ( 4,455" ID) 5 1/2' TBG TAIL WLEG (ELMD) 9105'1 9153'1 9166'1 NOTE' TUBING TAIL IS ABOVE 7' LINER TOP. Top of abandonment cement approx. 9860' ^ UG 2. 5 i995 .Nas~ ~ji & Gas Cons. C_o_mmissio. n 0,066'! MARKER JOINT %%%%%'~ %~%~%~%~,~ 3 3/4" Open Hole SAG R. SHUB. PBTD I 10;560'1 7", 26 #/ft, L-80, IJ4S I 10,625') PRUDHOE BAY UNIT WELL: R-18 (34-29-12-13) APl NO. 50-029- 20633 SEC 32;TN 12N;RGE13E BP Exploration (Alaska) 86OO 87OO 8800 8900 9000 R-18 3250 3500 Vertical Sectiol 3750 Departure (Feet] 4000 4250 45OO 475O Hole Angle @ K.O.= 22 deg TSHU DL 1= 32.O ncl Crv1= 88 deg CTSAD DL 2= 5.0 deg/100 Incl Crv 2= 88 deg Original Hole · TSAD-2 AUG 2,5 ~995 ¢il& Gas Cons. Commission -~--, ~nch0rage Marker Depths TSaR I TSHU ] TSAD ] Target J 8,7021ft TVD 8,7501ft TVD 8,81 11ft TVD 8,861 [ft TVD Kick Off Deprtr @KO I8,7281ft TVD 9~8321ff MD 3~488 ft IMD KO Pt MD New Hole Total MD TVD TD 9,832I 1 300I 11~132I 8~876~ Build Rt de~l/1 O0 MD (ft1 ~32.0 2(~: 0.0 370 0.0 722 Curve 1 Curve 2 Curve 3 Drawn: 8/1 7/95 16:39 Ft North Of Sfc Location 5,000 -- 4,800 - - 4,600 - 4,400 -- 4,200 -- 4,000 -- 3,800 -- 3,600 - - 3,400 - - 3,200 -- 3,000 Original Wellbore Ney 0 250 500 750 R-18 Plan View 1,000 ,~ Target Polygon ~as~ .Oil & Gas Cons. Commission "~ ~ch0ra_~e Ft East Of'Sfc Location 1,250 1,500 1,750 2,000 IWell Name R-18 I CLOSURE Distance 4,532 f t Az 21 dec~ NEW HOLE E/W (X) N/S (Y) Kick Off 673 3,407 Top Sad 71 1 3,463 State Plane 636,003 5,981,818 TD 1 ~591 4~244 State Plane 636,883 5,982,599 Surface Loc 635,292 5,978,355 ITSAD Step Out 35I MD of TSAD -> TD 1,1 91 Az Chq MD (ft) 0.(~ 2(~8 5.0 370 0.0 722 Curve 1 Curve 2 Curve 3 Drawn: 8/1 7/95 16:39 Plan Name: Case 2 CTDr '~ 3.2B ICoil Tubing BOPEI Blind/Shear Blind/Shear Pipe Rams Slip Rams I Pump-In Sub lI BCP Stack Type B To be used when no mud will be circulated Spacer Spools (as needed for Height) . / Manual Swab-Valve -~~ Exist ing FlowlineI I Hydraulic Act uat ed Valve Manual Mast er ValveI ~ I Manual Win, AUG 25 i995 Oil & Gas Cons. Commission Anchorage Lift Gas In (if applicable) IOoil Tubing BOPEI Blind/Shear Blind/Shear Pipe Rams Slip Rams CTDM:2.3.2A I Pump-In SubI BOP Stack Type A To be used for drilling wit h mud I Spacer Spools I(as needed for Height) I To Choke Manifold Mud Cross Hydraulic Act uated ValveI Manual Valve I Manual Swab Valve/ IIVlanual ValveI .~~ F. xist ing FlowlineI I Hydraulic Act uat ed Valve I ValveI I Manual Mast er I I Manual Win, I Lift Gas In [ [(if applicable) I ~-18A Liner BOP Configuration ICoil Tubing BOPEI I Pump-In SubI Annular, 5MI Lifting CollarI I Blind Rams, 5M I i Adaptor, 5M x 15MI (Rg-Rg) I Blin d/Shears, 15M I ~ IAdaptor, 5M x 1 5MI (Fig-Fig) SLIP I sip/Pipe Dbl 5MI ''~ , ~.~ PIPE Spacer Spool, 5MI Blind/Shear Blind/Shear Pipe Rams Slip Rams HYDRIL HYDRIL SCHAFFER HYDRIL HYDRIL 3,18 ft 2.0 10.14 11.32 1.22 1.22 2.35 2.50 Date: 8/18/95 ICTDM:1.2.23vq Site PlanTD / SEAWATER GREEN (DIVERT) TANK i~il \ ,,~ ~,.S I, DIVIAND DIV II WELL HOUSE~liiii!ii¢¢¢¢iii!iiiiiiiilliiii¢i~i'i?~'~'¢~'~ll~';~'~'~'~'~'~'~'~'~';~iil ~ ~ i:M:!:i:i:M:i:i:!:! !:!:!:!:!:!:i:!:i:!:!:!:!:! !:!:!:!:i:i:i:!:!:!:!:!:!:! ~ 0 o X E LAB MANIFOLD .I IIIc'Ass'' I xlx Ix .,* ~'FARM iA + · , ,so · CLASS I, DIV I* SQZ MANIFOLD GENERATOF~ ~+ E +·I CLASS I, DIV I~' l, · FIRST AID STATIONSMI VAN 3~r I e EMERGENCY ESCAPE PACKS sI· BJ PUMPER SCOTT AIR PACKS PRESSURIZED N2 BOTTLES OTHER FIRE HAZARDS- PAINT, LUBRICANTS, RAGS, CHEMICALS,... HALON DUMP/STORAGE EYE WASH STATION FUEL STORAGE '~,,~_'%~._'%~_'~ BOOM TRUCK '~PROX 120' H2S SENSORS OR WARNING LIGHTS H2S/LEL SENSORS OR WARNING LIGHTS I GLYCOL STORAGE · ESD + FIRE EXTINGUISHER'S AUG 25 1995 &las._ka [}ii & Gas Cons. Commission "'*' ~mchorag, WELLS SHOWN ON 50' CENTERS GENERATOR PAC~ LIFT HEATERe~ el~ ~ LIGHT ~ ~ CPS PLANT 'l~i~i] L~ ~AB GENERATOI~ s%N[~D ~ SOHIO TRAILER DIRECTIONAL DRILLERS FLUID FLOW SCHEMATIC (with Type 'A' BOP) CTDM:1,2,25V6 Seawa er MeOH Green Tank (DiveA) Charge Pump Dead Crude (vac trucks) Tank Farm CleanFl~pro I I i-~harge L~umps ! % Cosasco Valve Choke Manifold icm motion Cuttings~ MI Van 3 BJ Pumper Squeeze Manifold CTU AUG 25 1995 (jif & Gas Cons. Commission ~chorage Normal flow Gas Divert Fluid transfer from tank farm/upright tanks to B J/MI Manually operated valve WELL PERMIT 'CHECKLIST 'I .LD , 'OOL PROGRAM: exp [] dev [] redrll~ aery [] ~DMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary. . N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ............. . N 10. Operator has appropriate bond in force ........ ' N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval. 't N 13. Can permit be approved before 15-day wait ....... N ENGINEERING 14. Conductor string provided ................ Y i~ [~ ~ 15. Surface casing protects all known USDWs ......... Y 16. CMT vol adequate to circulate on conductor & surf csg.. Y 17. CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CMTwill cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B'& permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~.~N ~~ 21. If a re-drill, has a 10-403 for abndnmnt been approved~.~ 22. Adequate wellbore separation proposed .......... ~ 23. If diverter required, is it adequate ............ .~/~ 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate ..................... [~z' N 26. BOPE press rating adequate; test to ~~ psig~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ ~ ~/~- 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY APPR 30. Permit can be issued w/o hydrogen sulfide measures .... Y N~/_ 31. Data presented on potential overpressure zones ..... ~//N/ / /,,,,) ~ 32. Seismic analysis 9f shallow gas zones ......... ~/~ N /{.,-' ,~J , 33. Seabed condition survey (if off-shore) ....... /. Y N 34. Contact name/phone for weekly progress reports . ./W.. Y N [exploratory only] GEOLOGY: ENGINEERING: JDH<~ COMMISSION: DWJ ~ RAD Comments/Instructions: HOW/jo - A:~FORMS~heklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. R - 18A PRUDHOE BAY // / ~.-.- _f~. · :. .,~,' -~-~ ~ :..;. ~ ::. .... ~ ~ ..... · .. . . '_.. .--- 1995 ':-, --: ...... '"-'"~'~' IE~GR ...... --'-G--: :"' ' Pipe Conveyed 9832 '--.,. 11038 Date, WESTERN ATLAS Logging Services · 'ape Subfile 2 is type: ~-~-S TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CAS ING RECORD RUN 1 6554.00 BRAD ESARY SEE REMARKS R - 18A 500292063301 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 04-JAN-96 RUN 2 RUN 3 32 12N 13E 1874 1667 49.00 47.00 19.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 3.750 REMARKS: IEL/GR. LOGS WITNESSED BY: 7.000 9841.0 11072.0 C. PARKER & J. MELVAN. CIRCULATION STOPPED @ 17:00, 25-DEC-95. LOG TIED INTO BHCS (05-SEP-81/SWS) . WELL DRILLED BY CAMCO COIL TUBING. CHLORIDES = 42000 MG/L. REPEAT LOGGED DOWN 3 TO 10 FPM WHILE CIRCULATING 0.5 BBL/MIN. BEFORE LOG VERIFICATION PERFORMED AT 9870', AFTER LOG VERIFICATION PERFORMED ON BOTTOM AT 11045', AFTER REPEAT PASS. CONDUCTIVITY BEFORE AND AFTER LOG VERIFICATIONS ARE NOT WITHIN WESTERN ATLAS SPECIFICATIONS, RESULTS DISCUSSED WITH COMPANY REPRESENTATIVE. PRIOR TO LOGGING OUT, CIRCULATED 5 BBLS AND CIRCULATED 0.3 BBL/MIN WHILE LOGGING OUT. FILE HEADER FILE NI/MBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9832.0 - 11025.0 IEL 9832.0 11038.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH SN 9852.0 9871.0 10131.0 10135.5 10195.0 10233.0 10711.5 10987.5 11006.0 9871.0 10018.0 10071.5 10089.0 10097.0 10125.5 10128.5 10130.5 10135.0 10139.0 10146.5 10160.0 10162.5 10172.5 10193.5 10195.0 10200.5 10233.0 10531.5 10602.5 10630.5 10636.0 10640.0 10661.5 10674.5 10706.5 10711.5 10726.5 10750.5 10987.0 11006.0 11012.5 $ EQUIVALENT UNSHIFTED DEPTH MERGED DATA SOURCE PBU TOOL CODE GR IEL $ REMARKS: RT 9851.5 9871.0 10018.0 10071.5 10089.5 10097.5 10125.5 10129.0 all 10139.0 10146.5 10159.5 10162.5 10172.0 10193.0 10200.0 10233.0 10531.5 10602.0 10630.5 10636.0 10639.5 10661.5 10674.5 10707.0 10711.5 10726.5 10750.5 10987.5 11006.0 11012.0 RUN NO. PASS NO. 1 3 1 3 OPEN HOLE portion of MAIN PASS. MERGE TOP 9832.0 9832.0 runs merged; MERGE BASE 11025.0 11038.0 no case $P & TENS I~RE SHIFTED WITH SN. .-- CN WN FN COUN STAT / ? ?MATCH1. OUT / ? ?MATCH2. OUT $ : BP EXPLORATION (ALASKA) : R-18A : PRUDHOE BAY - : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR IEL 68 1 GAPI 4 2 SN IEL 68 1 OHMM 4 3 RT IEL 68 1 OHMM 4 4 SP IEL 68 1 MV 4 5 TENS IEL 68 1 LB 4 4 05 310 01 1 4 05 995 99 1 4 05 995 99 1 4 05 995 99 1 4 05 995 99 1 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 58 Tape File Start Depth = 11041.000000 Tape File End Depth = 9832.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 14515 datums Tape Subfile: 2 188 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: _kS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH $ BASELINE CURVE FOR SHIFTS: START DEPTH 9592.0 STOP DEPTH 9832.0 CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CASED HOLE portion of MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : R-18A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 2 TENS GR 68 1 LB 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 310 01 1 4 30 635 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 9832.000000 Tape File End Depth = 9585.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code .~coding summary: · Rep Code: 68 1486 datums Tape Subfile: 3 33 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile. 4 is type: diS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9585.0 IEL 9826.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCTU_J~TION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH 11025.0 11038.0 27-DEC-95 FSYS REV. J001 VER. 1.1 1700 25-DEC-95 116 27-DEC-95 11072.0 11047.0 9592.0 11040.0 2400.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY IEL INDUCTION ELECTROLOG $ TOOL NUMBER 1310XA 0811XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 3.750 9841.0 9832.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD 'PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MI/D FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: FLO-PRO 8.90 10.0 9.0 4.2 .0 .840 .000 .970 .000 .970 .000 76.8 .0 76.8 .0 76.8 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATR I X DENS I TY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (~KA) : R-18A : PRUDHOE BAY : NORTH SLOPE : ALASKA .000 .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR IEL 68 1 GAPI 4 2 SN IEL 68 1 OHMM 4 3 RT IEL 68 1 OHMM 4 4 COND IEL 68 1 MMHO 4 5 SP IEL 68 1 MV 4 6 TTEN IEL 68 1 LB 4 7 TEN IEL 68 1 LB 4 8 SPD IEL 68 1 F/MN 4 4 05 310 01 1 4 05 995 99 1 4 05 120 46 1 4 05 110 46 1 4 05 010 01 1 4 05 635 99 1 4 05 635 99 1 4 05 636 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 209 Tape File Start Depth = 11041.000000 Tape File End Depth = 9585.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 66941 datums Tape Subfile: 4 279 records... Minimum record length: 42 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: FILE HEADER FILE NI/MBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RI/N NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9900.0 IEL 9901.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCUTJtTION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY IEL INDUCTION ELECTROLOG $ STOP DEPTH 11027.0 11040.0 27-DEC-95 FSYS REV. J001 VER. 1.1 1700 25-DEC-95 2044 26-DEC-95 11072.0 11047.0 9592.0 11040.0 500.0 TOOL NUMBER 1310XA 0811XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 3.750 9841.0 9832.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: FLO-PRO 8.90 10.0 9.0 4.2 .0 .840 .000 .970 .000 .970 .000 76.8 .0 76.8 .0 76.8 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (~-'~'o TOOL STANDOFF '(IN): REMARKS: REPEAT PASS (LOGGED DOWN). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : R-18A : PRUDHOE BAY : NORTH SLOPE - : ALASKA .--°0 0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR IEL 68 1 GAPI 4 2 SN IEL 68 1 OHMM 4 3 RT IEL 68 1 OHMM 4 4 COND IEL 68 1 MM~O 4 5 SP IEL 68 1 MV 4 6 TTEN IEL 68 1 LB 4 7 TEN IEL 68 1 LB 4 8 SPD IEL 68 1 F/MN 4 4 05 310 01 1 4 05 995 99 1 4 05 120 46 1 4 05 110 46 1 4 05 010 01 1 4 05 635 99 1 4 05 635 99 1 4 05 636 99 1 32 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 164 Tape File Start Depth = 11044.000000 Tape File End Depth = 9900.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 5 42680 datums 232 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is type: 96/ ~/ 4 O1 **** REEL TRAILER **** 96/ 5 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 5 JAN 96 12:02p Elapsed execution time = 2.20 seconds. SYSTEM RETURN CODE = 0