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Home My WebLink About202-150 ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0:2 - J SOWell History File Identifier Organizing (done) ~Wo-Sided 1111111111111111111 '~scan Needed I - RESCAN ~Ior Items: 0 Greyscale Items: DI<}'TAL DATA tz(Oiskettes, No. ( 0 Other, NolType: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: BY: Helen CMaria) 0 Other:: ,¡ 1 Date: I í ~3 D5 Isl NOTES: Project Proofing BY: Helen~ I Date: Îð DG /s/ WtP Scanning Preparation BY: Hele~ I x 30 = (.~ () + 0 = TOTAL PAGES ~-;¡q . (Count dO'3~. not include cover sÌ1e~ 11) A~ Date: } I ~'='> os- Isl V v, r I Production Scanning Stage 1 Page Count from Scanned File: Lf- 0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES t Helen ~ Date: '. j if, YES If NO in stage 1, page(s) discrepancies were found: NO () S- /sf Vvt P NO BY: Stage 1 BY: Helen Maria Date: Isl I Scanning is complete at this point unless rescanning is required. ReScanned I BY: Helen Maria Date: Isl Comments about this file: Quality Checked 1111111111111111111 ~ .~U~ ~ ~ ~QA~ ~B~~ka QpR ~ G~~ ~~t~~, ~o~`kr~tissiar~ ~~ BP Exploration (Alaska) Inc. Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-8612 ~~at ~~"~°~~`~~'a,~ JUL ~OD ~ July 10, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB R-Pad Dear Mr. Maunder, Anc6tar~~~ ~.D ~,-- ~ S~ ~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB R- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Torin Roschinger, at 659-5102. Sincerely, Anna Dube, P.E. BPXA, Well Integrity Coordinator • ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) R-pad Date Revised 7/10/2009 Well Name API # PTD # Initiai top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al R-02 50029203540000 1781000 1.25 NA 125 IVA 6.8 5/11/2009 R-03A 50029203640100 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 50029203740000 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 50029203800100 1972500 0 NA 0 NA 3 5/13/2009 R-06A 50029203880100 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 50029205230100 2000100 2.25 NA 2.25 NA 43 5/11 /2009 R-08 50029205480000 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 50029206090100 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 50029206180000 1810930 2 NA 2 NA 14.5 6l22/2QQ9 R-11A 50029208930100 1982060 0.25 NA 0.25 NA 1.7 6/11/2009 R-12 50029209210000 1830350 0.25 NA 0.25 NA 1.7 6/12/2009 R-13 50029209290000 1830440 24 NA 24 NA 96.9 6/23/2009 R-14 50029209090100 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 50029209170100 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 50029206860000 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 50029206770100 1981380 4 NA 4 NA 27.2 5l15/2009 R-186 50029206330200 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 50029206370100 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 50029209970000 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 50029210050000 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 50029210130100 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 50029212320000 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 50029222780100 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 50029215470000 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 50029215570000 1860510 0.25 NA 0.25 NA 1.7 6/11/2009 R-29 50029222750100 1971070 20 3.9 1.25 NA 11.05 51i 4/2009 R-31 A 50029222770100 2021500 1.5 NA 1.5 NA 8.5 5/11 /2009 R-32A 50029224130100 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 50029224080000 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 50029224240000 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 50029225220000 1941440 3.25 NA 3.25 NA 442 5/14/2009 R-39A 50029225260100 1960840 2 NA 2 NA 22.1 5/11/2009 R-40 50029229260000 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 50029233990000 2081530 3.25 NA 325 NA 22.1 5(12/2009 • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 26, 2009 o~, ~ ~'- ~5~ Mr. Tom Maunder 31 ~ Alaska Oil and Gas Conservation Commission ~+ 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of R-Pad Dear Mr. Maunder, • JUL ~ ~ 2009 , ~ ~ ~, ~~~~~~ ~p~ ~ Ga~ Can~~ Co~n °~si~~ Anch~r~~ Enclosed please find a spreadsheet with a list of wells from R-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. ~ As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~-1 E•v/',w 4~`~G~t~ J ~ ~.. "9 , L. ~ ~ a8 Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date R-pad 6/25/2009 Well Name PTD # Initia( top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al R-02 1781000 1.25 NA 1.25 NA 6.8 5/11/2009 R-03A 1981710 1.5 NA 1.5 NA 7.65 5/13/2009 R-04 1790380 2.25 NA 2.25 NA 13.6 5/13/2009 R-05A 1972500 0 NA 0 NA 3 5/13/2009 R-06A 1981270 0.75 NA 0.75 NA 13.17 5/13/2009 R-07A 2000100 2.25 NA 2.25 NA 43 5/11/2009 R-08 1810010 0.25 NA 0.25 NA 1.7 6/12/2009 R-09A 1982330 3.25 NA 3.25 NA 17.85 5/14/2009 R-10 1810930 2 NA 2 NA 14.5 6/22/2009 R-11 A 1982060 0.25 NA 0.25 NA 1.7 6/11 /2009 R-12 1830350 0.25 NA 0.25 NA 1.7 6/12l2009 R-13 1830440 3.75 NA 3.75 NA 76.5 6/22/2009 R-14 2021560 0 NA 0 NA 0.04 5/18/2009 R-15A 1990360 0 NA 0 NA 1.7 5/18/2009 R-16 1811740 15 NA 15 NA 107.5 5/17/2009 R-17A 1981380 4 NA 4 NA 27.2 5/15/2009 R-18B 1981190 6.75 NA 6.75 NA 48.87 5/15/2009 R-19A 1971710 8.5 NA 8.5 NA 67.48 5/17/2009 R-21 1831200 0.25 NA 0.25 NA 3.4 6/13/2009 R-22 1831280 0.5 NA 0.5 NA 4.3 6/12/2009 R-23A 1972020 2.25 NA 2.25 NA 16.2 6/12/2009 R-24 1842160 9.5 NA 9.5 NA 37.4 6/12/2009 R-25A 1972300 0 NA 0 NA 1.7 5/18/2009 R-26A 1860370 0.75 NA 0.75 NA 4.3 6/22/2009 R-27 1860510 0.25 NA 0.25 NA 1.7 6/11 /2009 R-29 1971070 20 3,9 1.25 NA 11.05 5/14/2009 R-31A 2021500 1.5 NA 1.5 NA 8.5 5/11/2009 R-32A 1980090 0.75 NA 0.75 NA 8.5 6/11/2009 R-34 1931530 0 NA 0 NA 2.5 5/18/2009 R-35 1931810 0.25 NA 0.25 NA 1.7 5/11/2009 R-36 1941440 3.25 NA 3.25 NA 44.2 5/14/2009 R-39A 1960840 2 NA 2 NA 22.1 5/11 /2009 R-40 1982000 1.5 NA 1.5 NA 6.8 5/14/2009 R-41 2081530 3.25 NA 3.25 NA 22.1 5/12/2009 . . ~ .7 . ····r'···············, -' i:t .:.... ... if...;~:,'Þ ..,' . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marlœr.doc -G ld~ ~'1 DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Permit to Drill 2021500 Well Name/No. PRUDHOE BAY UNIT R-31A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22277-01-00 MD 12126 --' TVD 8697./ Completion Date 11/6/2002.;' Completion Status 1-01L Current Status 1-01L UIC N f" ---< ------------~~-~---~_._._-~- - ..~--------~----.-_._-~------ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Q --~-._-~---~.-~-~~- -~-----------_._~--~--- - DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~. Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 7/16/2002. A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 7/16/2002. - --~._--- .~---~---~~~- ~f5t ,../Directional Survey \..9' Dr/ Directional Survey ED C Tf 12075 LIS Verification ED C Pds 12075 I nd uction/Resistivity ßpg I nd uction/Resistivity ED C Pds 12075 I nd uction/Resistivity )ë6g 12075 Induction/Resistivity ---~----------~~-- 10083 12126 Open 11/15/2002 10083 12126 Open 11/15/2002 10089 12126 Open 4/14/2003 Primary Depth Control 25 Final 10089 12126 Open 4/14/2003 Vision Resistivity - MD 25 Blu Final ,\1\1) 10089 12126 Open 4/14/2003 Vision Resistivity - MD "~" 25 Final 10089 12126 Open 4/14/2003 Vision Resistivity - TVD 25 Blu Final rVD10089 12126 Open 4/14/2003 Vision Resistivity - TVD Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments Permit to Drill 2021500 MD 12126 TVD 8697 ADDITIONAL INFORMATION Well Cored? Y I~ Chips Received? VI N - Analysis Received? -y~ _._---~._-- ------- ----.- --~._--~ -- ~._-.-------- ----------~ Comments: - ~---~---~..-_.--~--------~-~---~- --- ----~- ----_.__.-----~ ._---~-~-<~-~----~ Compliance Reviewed By: - DATA SUBMITTAL COMPLIANCE REPORT 12/29/2004 Well Name/No. PRUDHOE BAY UNIT R-31A Operator ,.BP EXPLORATION (ALASKA) INC Completion Date 11/6/2002 Completion Status 1-01L Daily History Received? Formation Tops ~ Current Status 1-01L &N @N Date: API No. 50-029-22277-01-00 UIC N , } .~ ¿I Jcv....1 J~ S-".. Scblumbepgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well vre;Q.B ~æ-da ï.j 1..z:8. 9-35A \ q 3 -G 3 \ )/Ó.S. 9-28A \ q :~ ..~ L\ ~ ~ 18-05 \9, f.ç -O'ðn \/I).Sy1-14A è\ ~ '0'7:& ~~~)0:%f:!)..-~3[O ,.R.31A ~C~ '- \9":) vR-31A yR-31A Job# 23081 23050 22515 22411 23100 23078 23087 23087 23087 23087 Log Description CH EDIT MGR RST RST MCNL SCMT SCMT OH EDIT ARC & IMPULSE (PDC) MD VISION RESISTIVITY TVD VISION RESISTIVITY MD VISION RESISTIVITY (BHP) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ,. 'r-o,...:¡-"'.~ ~ I;¡-= '-... ,0 :k,.. ~ ,. f- ., ':\ ~ ;J=. I .1\ ~~ ~ ~.~~ ~:\~J il~ ~ :1 ;~ W Date Delivered: ~F,-, \" -~ c>t'\("\ 1~, 'SLù\ ~ ^~ hi ~ \ t ' ,-..~ v --.I ... V '- -.:.ia~~a C~) & Gas Cons. CorrnrJ:!...~n ¡,\tÍ({tlo~Je 04/02/03 NO. 2725 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott,Milne Pt. Color Date Blueline Prints CD 12/08/02 1 01/08/03 1 1 /BO 7;;" 11/10/02 1 1 f~2~~ 08/19/02 1 1 03/05/03 2 02/13/03 2 11/03/02 J fì.O i5 11/03/02 1 11/03/02 1 11/03/02 1 '---- -- Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ~) , ReceiveG;~QQp-.- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ') 1. Status of Well Œa Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 202-150 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22277-01 4. Location of well at surface -' , -',~., ~"":'~""",>":'~' 9. Unit or Lease Name 653' NSL, 1042' EWL, SEC. 32, T12N, R13E, UM ~""'.""'~'~.;.,~". ~'.:~~..'~.". Prudhoe Bay Unit At top of productive interval a " './, I' 4155' NSL, 1075' WEL, SEC. 31, T12N, R13E, UM 1~1J, -'-'-,:~ 10. Well Number At total depth ",,,:, ~,';~, ,.:Y R-31A 4227' NSL, 2903' WEL, SEC. 31, T12N, R13E, UM ~,r" :",,:,~ -'N :~, ,:' 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. 11. F~~~~~~ ~~~I Field I Prudhoe Bay Pool KBE = 51.92' ADL 028279 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 1 0/30/2002 ~ 11/3/2002 l 11/6/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12126 8697 FT 12126 8697 FT Œa Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES Classification of Service Well 15. Water depth, if offshore 16. No. of Completions NIA MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2092' MD 1900' (Approx.) ..,/þ.)~ /4,/O/'AlZ> %; ~if' 71/.b 23. CASING SIZE 20" 10-3/4" 7-518" 5-1/2" 2-7/8" WT. PER FT. Conductor 45.5# 29.7# 17# 6.16# GRADE H-40 NT -80 NT95HS 13CrFL4S L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 80' 30" Surface 3315' 13-1/2" 2086 cu ft AS III, 400 cu ft Class 'G' Surface 10068' 9-7/8" 1943 cu ft Class 'G' 9927' 10101' 6-3/4" 160 cu ft Class 'G' 9872' 12125' 3-3/4" Uncemented Slotted Liner AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-7/8" Slotted Sections 25. SIZE 4-1/2", 12.6#, 13Cr TUBING RECORD DEPTH SET (MD) 9923' PACKER SET (MD) 9833' MD TVD 10480' - 11296' 8744' - 8720' 11307' - 12091' 8720' - 8696' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH 27. Date First Production November 28, 2002 Date of Test Hours Tested 12/12/2002 4 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR OIL-BBL TEST PERIOD 852 Flow Tubing Casing Pressure CALCULATED Press. 200 24-HoUR RATE OIL-BBL GAs-McF 3,586 GAs-McF WATER-BBL 66 WATER-BBL CHOKE SIZE 1760 OIL GRAVITY-API (CORR) GAS-OIL RATIO 4,209 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED DEC 2 6 2002 "BOMS BFL OEC ,~' , No core samples were taken. Form 10-407 Rev. 07-01-80 Aiaska Oil & Gas GonSa CQmmission ~coorage Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Sag River (Original Well) 10082' 8701' Shublik 10143' 8745' Shublik 10460' 8748' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~AÌ1- ~ Title Technical Assistant Date J~. ^(p"O;;t R-31 A 202-150 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Ted Stagg, 564-4694 Permit No. / 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 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 ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-31 R-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 9/8/2002 Rig Release: 11/6/2002 Rig Number: N2 Spud Date: 7/8/1992 End: 9/8/2002 02:00 - 04:00 2.00 RIGD P DECOMP Rig Released from E-09B @ 02:00 9/8/2002. RID & store injector. 04:00 - 05:00 1.00 RIGD P DECOMP Prep to move off well. Due to poor road conditions (soft spots) on derrick-up route, rig will be moved with derrick down from E-Pad via K-Pad access road, thru twin towers onto Spine road to R-Pad access road. 05:00 - 06:00 1.00 RIGD DECOMP PJSM. Move off well. Pull rig off well. 06:00 - 07:00 1.00 RIGD P DECOMP Conduct post-operations pad inspection. Hang BOPs. 07:00 - 09:30 2.50 RIGD P DECOMP PJSM. RlU & UD windwalls. Scope down derrick. 09:30 - 10:00 0.50 MOB P PRE Pull rig to pad entry. 10:00 - 10:15 0.25 MOB P PRE Held pre-move safety meeting with Security, tool service all personnel. 10:15 - 13:00 2.75 MOB P PRE Move rig from E-09 to Price pad. 13:00 - 18:30 5.50 RIGU P PRE RlU derrick and windwalls on Price pad. 18:30 - 18:45 0.25 MOB P PRE PJSM on Rig move from Price pad to R-Pad. Discuss good communication, reponsibilities and caution with wet weather and soft roads. 18:45 - 21:00 2.25 MOB P PRE Move from Price pad to R-pad access road via Spine road. 21 :00 - 00:00 3.00 MOB N WAIT PRE Nordic 1 was centered on the R-pad access road approximately 50-100' off the spine road when the Drillers side front tire penetrated the road surface. The depth of the rut was 2-3'. Fortunately the Rig was able to back out of it, in the process, however, the off drillers front tire created another rut approximately 2' deep, 3' wide and 20' long. The two ruts are not on the outer edge of the road but directly underneath the rig tires. The rig is currently parked at the entrance to the R-pad access road, just off the spine Rd. Crews are working on the road and the situation will be reassesd in the daylight. 9/9/2002 00:00 - 07:30 7.50 MOB N WAIT PRE Poor road conditions. Currently parked at entrance to R-pad access road just off Spine rd. Waiting for daylight to reasses road conditions and possible options elsewhere. 07:30 - 09:30 2.00 MOB N WAIT PRE Discuss further options with town team. Plan on moving rig to J-10. Conduct pre-rig move inspection & request tool services to precautionarily plywood J-pad access. Request Wells group to remove J-10 wellhouse & disconnect electrical power. 9/10/2002 00:00 - 0.00 MOB PRE 10/28/2002 04:00 - 06:15 2.25 BOPSUR P PRE Accept rig 04:00 hrs 10/28/2002. NU BOPE. 06: 15 - 06:45 0.50 BOPSUR P PRE SafetyrrL meeting. 06:45 - 07:30 0.75 BOPSUR P PRE RU for BOP test. 07:30 - 08:15 0.75 BOPSUR P PRE Set TWC. 08:15 - 13:00 4.75 BOPSUR P PRE Perform initial BOPE test. Witness waived by AOGCC's John Crisp. 13:00 - 13:30 0.50 BOPSUR P PRE Pull TWC 13:30 - 14:30 1.00 STWHIP P WEXIT Check well- no pressure. Fill hole (7 bbls). 14:30 - 15:30 1.00 STWHIP P WEXIT MU milling BHA. Diamond mill only. 15:30 - 16:00 0.50 STWHIP P WEXIT PU inj. Rehead with new Baker CTC. Pull and PT. 16:00 - 18:30 2.50 STWHIP P WEXIT RIH to XN nipple tag 9894' +5' correction based on Eline TT log. 18:30 - 19:00 0.50 STWHIP P WEXIT Mill XN nipple. @.4 bpm 1500 psi off, 1575 psi on. 19:00 - 19:30 0.50 STWHIP P WEXIT Dress XN and make dry passes. OK.RIH Tag at 10090'. Show WOB and some motor work. Maybe on tray. 2.5 bpm,1950 psi. Research logs. Appears the correction to the TT log referenced in the wellbore diagram is incorrect. The Jewlery Printed: 11/1212002 10:36:24 AM ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-31 R-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 9/8/2002 Rig Release: 11/6/2002 Rig Number: N2 Spud Date: 7/8/1992 End: Date From '~.T() : Hours' Task. .' Code . N~T -Phasè ' . . p.~PripljÇ>~,:qf9Þør~*i():o~ 10/28/2002 19:00 -19:30 19:30 - 00:00 10/29/2002 00:00 - 04:00 04:00 - 06:00 06:00 - 07:30 07:30 - 09:30 09:30 - 10:30 10:30 - 12:30 12:30 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 - 20:00 20:00 - 22:20 22:20 - 22:30 22:30 - 23:45 23:45 - 00:00 10/30/2002 00:00 - 00:30 00:30 - 00:50 00:50 - 01 :25 01 :25 - 02:30 0.50 STWHIP P 4.50 STWHIP P 4.00 STWHIP P 2.00 STWHIP P 1.50 STWHIP P 2.00 STWHIP P 1.00 STWHIP P 2.00 STWHIP P 3.50 STWHIP P 1.00 STWHIP P 1.00 STWHIP P 2.00 STWHIP P 2.33 STWHIP P 0.17 STWHIP P 1.25 STWHIP P 0.25 DRilL P 0.50 DRILL P 0.33 DRILL P 0.58 DRILL N 1.08 DRILL P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 SFAl PROD1 PROD1 log has the WLEG at 9923' not 9912' as referenced in the well bore diagram. An additional correction of 11' was required. Correcting tag to 10101'. Mill window41K up, 22Kdn, FS=1747 psi. 2.5 bpm. Stall at 10,093.1' @ 2500 psi. Mill to 10103.6' WOB 2K,2.5 bpm. FS= 1750 psi, 1841 psi on bottom. Mill window to 10105' 2.4/2.4 bpm,2036 psi on, 1750psi off, WOB 2-3K. Pumping 4 ppb bio sweeps. Mill 1 01 06.5 2.4 / 2.4 bpm, 1923 psi on bottom. 1750 psi off, WOB 3k. At 10106.5'. milling break. Pressure bump, but no stall, followed by weight gain. Off window and in formation. This pressure and weight response is very common. Drill formation to 10116.5'. POOH. Add string mill above diamond mill. Diamond mill in gage, normal wear. RIH. Did not see nipple RIH dry. Bring pumps up 2.4/1980. RIH. Tag and stall 1 0089' CTM. PUH. RIH stall 10,084'. PU. Ease into it 10,085.4'. Stall. Creep into it (time mill). Stall 10,085.5'. Park 10085.2'. Set brake. E-counter jumped ahead 4' to 10089' with brake set???? Flag pipe. E-counter jumped ahead again 2' more, then 2' more -- again with brake set. It appears that raising and lowering level wind is sending noise or signal to encoder and adding footage. Reset depth and stry milling again. Stall 10085.6'. Stall 10085.9'. Work to 10089' over next 2-1/2 hours with four more stalls. Continue reaming down. Poor slide in chrome. Numerous stacks and stalls. Ream to 10,090.5'. Try dry tag. Tag 10,092.5'. Didn't slip by. Clean PU. Continue reaming down. Looks like jumped into formation at 10,091.2' Ream to TD 10100'. Correct to 10116.5'. Ream and backream 6 times. Run thru window dry, looks clean. Flag pipe at 9500' EOP. TOW= 10101, BOW= 10106 POH with window milling assembly. PJSM on LD milling tools and cutting CT. lD milling assembly. Wear on center of diamond mill and definite work done by string reamer. Both came out in gauge at 3.8". Hook up hydraulics for hydraulic CT cutter (same setup as Nordic 1). Rig hydraulics need to be shut down whilst performing job. Hook up hydraulics for hydraulic CT cutter (same setup as Nordic 1). Attempt to cut coil with new hydraulic cutter. The CT was cut but remaining end of the CT was pushed over and wedged against the cutter itself, making it difficult to move CT. Hydraulic CT cutter not functioning correctly. Cutters were assembled up-side down. Reassemble cutters. Continue cutting CT. Cut 100' of CT as per Dowell procedure (every 3 trips in Chrome tubing) Install new Baker CTC. Printed: 11/12/2002 10:36:24 AM ) ~, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-31 R-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 9/8/2002 Rig Release: 11/6/2002 Rig Number: N2 Spud Date: 7/8/1992 End: . HôurS- . Tåsk .edd~,. .NP;J;:-.Phåse ' .. ~~çrtpti~n;;~f:q~råti()n¡$. 10/30/2002 02:30 - 02:45 0.25 DRILL P PROD1 PJSM, discuss PU drilling BHA, pinch points, keeping floor clean/clear. 02:45 - 04:00 1.25 DRILL P PROD1 PU Drilling BHA for the build. New 3.75" M09, TORC and 2.5deg short radius Baker motor. Surface test TORC tool. Good test. 04:00 - 04:45 0.75 DRILL P PROD1 RIH with build assembly, BHA #3. Shallow hole test TORC and MWD at 3000'. 04:45 - 06:00 1.25 DRILL N DFAL PROD1 Difficulty getting tools to work on shallow hole test. Found out the signal transducer valve in reel house was closed. Tool still not accepting signals, only accepted one of three. Decide to change out tools. TORe failure. 06:00 - 06:45 0.75 DRILL N DFAL PROD1 POH to changeout TORe 06:45 - 08:30 1.75 DRILL N DFAL PROD1 C/O TORC tools. 08:30 - 09:15 0.75 DRILL N DFAL PROD1 RIH with BHA #4. 09:15 - 11 :30 2.25 DRILL P PROD1 Shallow test tools at 3000'. Good. RIH. Correct depth at flag (+20'). RIH. Tag TD 10122'. Will correct depth when we see RA. 11 :30 - 16:30 5.00 DRILL P PROD1 Bring up pumps. Send 45L TF command. Swap well to Flo-Pro mud. Drill. Repeat 45L TF command twice. TORe not excecuting commands while on bottom drilling. Try PU off bottom and send command. Worked. Drill high left to 10209'. Did not see RA. Losing charge pressure frequently. This off bottom time is contributing to not getting desired 40 deg DL, but we're OK directionally. Turn off centrifuge to help with charge pressure. 16:30 - 18:30 2.00 DRILL P PROD1 Drilling ahead 18:30 - 18:45 0.25 DRILL P PROD1 TECH LIMITS / SAFETY DISCUSSION. The centrifuge problem was due to not adding De-foamer to pits & pit level being low. Adding air into the system causing charge pump to cut out. May need a mod to keep air out of the system, should'nt have to rely on pit level being high to keep air out. Centriguges back on line, charge pumps working. Safety issues include: slippery stepslllandings, ice falling from derrick. 18:45 - 20:15 1.50 DRILL P PROD1 2.7/2.7bpm, 3900psi. Drill to 10327'. freespin= 3700psi Drillling shublik. Getting 35DLS, plan calls for 40DLS. On depth with plan but a bit outside of the curve azimuthally. Should not be a problem staying in polygon. 20:15 - 22:30 2.25 DRILL N DFAL PROD1 Attempt to get the TORC tool to accept commands. TORC TF seems to be following the hole, it will accept commands off bottom but rotate as we RIH near TD. Order out back-up TORC tool that we pulled last night, looks like that tool failed shallow hole test due to metal cuttings plugging the tool. 22:30 - 00:00 1.50 DRILL N DFAL PROD1 POH for failed TORC tool 10/31/2002 00:00 - 00:15 0.25 DRILL N DFAL PROD1 POH 00: 15 - 00:25 0.17 DRILL N DFAL PROD1 SAFETY MEETING: Prior to LD drilling assembly and PU new tools (Resistivity, DS49, motor for 12deg DLS). Discuss plan for getting injector back out of the way and LD tools. Also noted slick conditions around rig, especially on landings and stairs. 00:25 - 02:00 1.58 DRILL N DFAL PROD1 Stand back injector and LD build assembly. Kick drill. 02:00 - 03:45 1.75 DRILL N DFAL PROD1 PU new TORC tool, Used DS49 (3.74"gauge, SRL# 104116), 1.4deg motor & ARC tool. Surface test TORC tool. Stab Printed: 11/1212002 10:36:24 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-31 R-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 " ,,' Dåte:, From,~Tó "HÒÛfS,::t[ask, ,eøde'iN:Ptr: ','PbâSe' 10/31/2002 02:00 - 03:45 1.75 DRILL N DFAL PROD1 03:45 - 06:00 2.25 DRILL N DFAL PROD1 06:00 - 06: 15 0.25 DRILL N DFAL PROD1 06: 15 - 06:35 0.33 DRILL P PROD1 06:35 - 09:00 2.42 DRILL N DFAL PROD1 09:00 - 11 :00 2.00 DRILL N DFAL PROD1 11 :00 - 13:00 2.00 DRILL N DFAL PROD1 13:00 - 14:45 1.75 DRILL N DFAL PROD1 14:45 - 15:30 0.75 DRILL N DFAL PROD1 15:30 - 17:00 1.50 DRILL N DFAL PROD1 17:00 - 18:00 1.00 DRILL N DFAL PROD1 18:00 - 19:20 1.33 DRILL N DFAL PROD1 19:20 - 20:30 1.17 DRILL N DFAL PROD1 20:30 - 20:55 0.42 DRILL N DFAL PROD1 20:55 - 21 :15 0.33 DRILL P PROD1 21:15 - 23:15 2.00 DRILL P PROD1 23:15 - 23:25 0.17 DRILL P PROD1 23:25 - 00:00 0.58 DRILL P PROD1 11/1/2002 00:00 - 00:40 0.67 DRILL P PROD1 00:40 - 02:20 1.67 DRILL P PROD1 02:20 - 03:20 1.00 DRILL P PROD1 03:20 - 03:40 0.33 DRILL P PROD1 03:40 - 04:30 0.83 DRILL P PROD1 04:30 - 05:10 0.67 DRILL P PROD1 05: 1 0 - 05:45 0.58 DRILL P PROD1 05:45 - 06:05 0.33 DRILL P PROD1 06:05 - 10:20 4.25 DRILL P PROD1 10:20 - 11: 15 0.92 DRILL P PROD1 Start: 9/8/2002 Rig Release: 11/6/2002 Rig Number: N2 Spud Date: 7/8/1992 End: ~criptiQ:f1<Þ~QperatiQ~l~:' injector. RIH with lateral asembly, BHA #5. Shallow hole test TORC and MWD, good test. Start logging up for tie-in from 10070' md. GR to bit is 51.6'. Bit to survey is 48.64'. Plan to tie in to the two GR spikes just above the whipstock. TECH LIMITS / SAFETY meeting. Continue tie-in log. Poor MWD signals. Intermittent nature of the pulses or noisethat never cleaned up kept us down here longer than we should have been. POOH for MWD failure. OOH. Determined that fuse in battery blew 5 min after shallow hole test. Prep new probe -- batteries shot at low hours. Replace batteries. MU BHA. RIH. Shallow hole test. TORC not executing commands. POOH. Call for Weatherford orienter. LD TORC. Reprogram probe for delayed surveys (to get TF before long survey). Install Weatherford orienter and SLB bleed sub. RIH. Shallow hole test. Looks like Weathorford hydraulic orienter is working. RIH. Tech limits/Safety meeting. Pulling uphole outside window from 10160' for tie in. Add 7' for depth correction (including -3' for pipe stretch). PIP TAG = 10107' RIH to TO. Set down at 10106.3. Hole is ratty, sitting down in multiple spots from 10106 to 10240. RIH speed=10fpm. Freespin=2850psi 2.7/2.7bpm Tag TD at 10321 ORIENTING, TF=69L DRILLING. 2.7/2.7bpm 3000-3200psi. 50-70fph DRILL TO 10398' [FYI: SLlMPULSE FAILURE ATTRIBUTED TO A BATTERY FAILURE, TORC FAILURES STILL BEING I NVESTIGA TED] DRILLING, ROP slowing to 20-4Ofph, stacking wt to get drilling. 2.7/2.7bpm 3100-3400psi. ORIENTING. SHORT TRIP, to clean hole. Orienting, not getting 1:1, struggling. Also having to wait 5-10min for MWD to get TF info back to surface. Find TF at 67L. Drill to 10466', 2.7/2.7bpm 3100-3300psi, 50-60fph TF= 70L-45L Drill to 10472', 2.7/2.7bpm 3100-3300psi TF=45L Still climbing, looking for the base of the Sag. Orienting TF=150L Drill to 10575', ROP has been increasing (70-90fph) and we are seeing the GR marker at the base of the Sag. TF=150L-170R [GR is 52' back from the bit.] Plan to make 90deg inclination 6' below plan in the Sag. Orient to 90L, wipe hole 150' Wiper to window. Off bottom survey Drill Sag to 10770'. Only 3 off bottom clicks. Wiper to window. Some motor work 10237' - 10240' both Printed: 11/12/2002 10:36:24AM ") ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-31 R-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 ".Date FrOiTt7Tø' Hours: Tåsk';:;Code -NP'f:;~;-:F?håse' 11/1/2002 10:20 - 11: 15 11 : 15 - 11 :45 11 :45 - 12:30 0.92 DRILL P 0.50 DRILL P 0.75 DRILL P PROD1 PROD1 PROD1 12:30 - 14:30 2.00 DRILL P PROD1 14:30 - 14:40 0.17 DRILL P PROD1 14:40 - 16:00 1.33 DRILL P PROD1 16:00 - 16:20 0.33 DRILL P PROD1 16:20 - 16:40 0.33 DRILL P PROD1 16:40 - 17:40 1.00 DRILL P PROD1 17:40 - 18:20 0.67 DRILL P PROD1 18:20 - 19:25 1.08 DRILL P PROD1 19:25 - 19:45 0.33 DRILL P PROD1 19:45 - 20:10 0.42 DRILL P PROD1 20:10-21:15 1.08 DRILL P PROD1 21:15 - 21 :40 0.42 DRILL P PROD1 21 :40 - 22:20 0.67 DRILL P PROD1 22:20 - 22:30 0.17 DRILL P PROD1 22:30 - 22:40 0.17 DRILL P PROD1 22:40 - 23:20 0.67 DRILL P PROD1 23:20 - 00:00 0.67 DRILL P PROD1 11/2/2002 00:00 - 00: 15 0.25 DRILL P PROD1 00:15 - 02:45 2.50 DRILL P PROD1 02:45 - 02:50 0.08 DRILL P PROD1 02:50 - 03:45 0.92 DRILL P PROD1 03:45 - 04:50 1.08 DRILL P PROD1 04:50 - 06:30 1.67 DRILL P PROD1 06:30 - 06:45 0.25 DRILL P PROD1 06:45 - 09:00 2.25 DRILL P PROD1 09:00 - 09:45 0.75 DRILL P PROD1 09:45 - 10:30 0.75 DRILL P PROD1 10:30 - 12:30 2.00 DRILL N DFAL PROD1 12:30 -13:45 1.25 DRILL N FLUD PROD1 Start: 9/8/2002 Rig Release: 11/6/2002 Rig Number: N2 Spud Date: 7/8/1992 End: " . gesÞrj_pti9n-:9t;ppøråtiö-~~ . directions. Drill to 1 0796'. Orient around to 90L. While orienting, FS pressure went to 3600 psi at 2.75 BPM. Prior to orienting, FS was 2900 psi. Pressure is not steady. 600 psi pressure cycles off bottom. Then whatever was there looked like it got spit out. Back to 3000 psi free spin. Also, noted that we lost real time resistivity. Drilling. Resistivity still not working. Get 2 clicks to 90L Drill to 10905', no Resistivity. Orient for right turn. Drill to 10920'. Stacking. Still no resistivity Wiper to window, tight at 10290', just a bit of motor work. Drilling dropping at 90R TF. Drilling, stacking (Pieces of a rubber boot on the transmission shaft of the motor made its way to the shakers, likely the cause of the earlier pressures spikes we were seeing.) Drill to 11036', stacking Orient TF to 90R Drill to 11093', 2.7/2.7bpm 3200psi. Freespin= 3050psi Send new mud downhole. Short trip to 10,120'. Hole in good condition Drill to 11135', new mud on bottom. Clean PU off bottom. Freespin= 3000psi Orient, to make a slow right turn. Drill to 11139', stacking. Wiper to window. Drill to 11195'. 80-90 FPM 2.7/2.7 bpm 3250-3300psi. Drill to 11200'. POH to changeout Resistivtiy (ARC) tool, Motor, and Orientor. FLAG PIPE at 10,916'md ( EOP). SAFETY MEETING: Discuss LD of tools and cutting CT. LD drilling assembly: Weatherford orientor, BHI motor, ARC tool. Bit had some rubber jammed in one of the nozzles, otherwise in good shape. Discovered that ARC tool battery had ruptured. Foul smell. Move tool out of pipe shed and down wind. Cut off 133' of Coil. Dress end of CT. Install new Baker CTC. PU TORC, ARC tool, BHI HP motor, Used DS49. Crew C/O. Note: starting last night, TL meeting performed off tower. RIH. Shallow test good. Log tie-in at window. Correct depth +10'. RIH. Set down in 10,350' - 10,380' area. Medium amount of MW to clean up. RIH and tag TD 11205'. BU from working BHA in belly (Shublik) yielded quite a bit of sand - therefore, hole cleaning issue and not a Shublik falling apart issue. RT resistivity log (the stuff we missed from yesterday's failure) TD to 11000' at 600 FPH, 11000' - 10900' at 80 FPH, then to 10750' at 600 FPH. RIH to TD. Charge problems. Aired-up mud. Suspect feed pumps to centrifuge. TORC also not executing command (may be related). As charge pressure improved, we also switched from Printed: 11/1212002 10:36:24AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-31 R-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 9/8/2002 Rig Release: 11/6/2002 Rig Number: N2 Spud Date: 7/8/1992 End: 11/2/2002 12:30 - 13:45 1.25 DRILL N FLUD PROD1 operating TORe on pump rate to MM in rate -- and the TF command was executed. Not sure if we learned anything here. 13:45 - 16:30 2.75 DRILL P PROD1 Drill with RS TF to 11300', then drill with continuous rotation to 11360'. Stacking. 16:30 - 17:35 1.08 DRILL P PROD1 Wiper to window. 17:35 - 18:30 0.92 DRILL P PROD1 Drill to 11435' w/ continuous rotation. 18:30 - 19:05 0.58 DRILL P PROD1 Orient TF to high-side. Freespin= 3000psi 19:05 - 19:25 0.33 DRILL P PROD1 Drill to 11460' with high-side TF 19:25 - 21 :00 1.58 DRILL P PROD1 Drilling, back into continuous rotation mode, taking more weight to rotate?? 2.7/2.7bpm 3050psi. Stacking: Dowell WOB indicator=12000-16000bs (on CTDS drilling monitor). ROP=40-50fph. Inc=92deg, plan to hold 92-93deg inc for 100' and then drop back down. Hoping to see some change in Resistivity tool output which has flat-lined along with GR for the last 200' of drilling. See a bump in GR, possibly small silt layer in middle of Sag according to Geo. 21 :00 - 22:35 1.58 DRILL P PROD1 Wiper to window, pump 30bbl1 OOK+ LSRV pill to carry cuttings out of sump in the build section. 22:35 - 23:00 0.42 DRILL P PROD1 Weight transfer improved after wiper trip. 2.7/2.7bpm, 3100-3300psi, ROP=70-90fph Freespin= 3000psi Drill to 11552', Rap slowing, possibly second silt section in Sag. Stacking. Lets try drilling without continuous rotation. 23:00 - 00:00 1.00 DRILL N DFAL PROD1 Orient off bottom to 270L, short trip. TORC not accepting commands. Go back to continuous rotation. 11/3/2002 00:00 - 00: 15 0.25 DRILL P PROD1 Drill in continuous rotation mode. 00:15-01:15 1.00 DRILL N DFAL PROD1 Unable to get TORe tool to respond to signals. Try several different pump rates, and various other tricks. No good. 01 :15 - 02:00 0.75 DRILL N DFAL PROD1 POH for failed TORC tool. 02:00 - 02:30 0.50 DRILL N DFAL PROD1 Attempt to orient TORC inside casing. It worked! Looks like when the tool is in continuous rotation mode no stop command needs to be sent prior to sending a TF command. 02:30 - 03:15 0.75 DRILL N DFAL PROD1 RBIH 03: 15 - 04:35 1.33 DRILL P PROD1 Send ,Iowside TF command, TORC now accepting commands. Drill to 10660', 2.7/2.7bpm 3300-3450psi ROP=70-90fph. Plan to level out and drill at 91 deg Inc. 04:35 - 04:49 0.23 DRILL P PROD1 Short trip 04:49 - 05:30 0.68 DRILL P PROD1 Drill to 11 ,708'md. Seems to drill faster, smoother when not in rotation mode. Bleed IAlOA from 800psi to 250 and 60psi respectively. 05:30 - 06:30 1.00 DRILL P PROD1 Drill to 11800' 06:30 - 08:00 1.50 DRILL P PROD1 Wiper to window. Hole in pretty good shape. Some motor work at 10350'. 08:00 - 10:30 2.50 DRILL P PROD1 Drill to 11930'. 10:30 -11:30 1.00 DRILL P PROD1 Wiper to window 11:30-12:15 0.75 DRILL P PROD1 Tie in. Correct depth (+6'). 12:15 -12:30 0.25 DRILL N SFAL PROD1 PUH above window and fix hydraulic oil leak on power pack. 12:30 - 13:30 1.00 DRILL P PROD1 RIH to TD. 13:30 - 16:00 2.50 DRILL P PROD1 Drill to final TD 12126'. - 16:00 - 17:00 1.00 DRILL P PROD1 Wiper to window. Build 150k LSRV pill for sweeping belly. 17:00 - 17:30 0.50 DRILL P PROD1 Log tie-in. Correct (+2') 17:30 - 18:30 1.00 DRILL P PROD1 Sweep belly with 30 bbls 150k LSRV pill. Tag TD at 12,126'. RIH wt at TD= 15500 18:30 - 22:15 3.75 DRILL P PROD1 POH, Flag pipe at 4554' EOP. Apparently started losing fluid Printed: 11/12/2002 10:36:24 AM ) ) Legal Well Name: R-31 Common Well Name: R-31 Spud Date: 7/8/1992 Event Name: REENTER+COMPLETE Start: 9/8/2002 End: Contractor Name: NORDIC CALISTA Rig Release: 11/6/2002 Rig Name: NORDIC 2 Rig Number: N2 , From....Tó',Hours<'Task NPT;';;:Ptrsse " Date, ~Cod~ .~~çt;þtiØ~l':()f;.,QÞet~~ion~ 11/3/2002 18:30 - 22:15 3.75 DRILL P PROD1 at 3500' while POH. Losing 4.5bbls per 1000' as we POH at 12Ofpm. (per trip sheet) => losing approx 0.6 bpm = 36bph. Stopped losing fluid at 1000'. Hmm? Pump temporarily went down at about the same time we started losing fluid, apparent losses could possibly be tied to pump issue. 22: 15 - 22:25 0.17 DRILL P PROD1 PJSM on LD drilling assembly. Fill hole, took 1bbl to fill, hole not drinking fluids. 22:25 - 23:30 1.08 DRILL P PROD1 LD drilling assembly. Looks like transmission failed on the motor at some point, likely when we were performing the conditioning run 23:30 - 23:45 0.25 CASE P CaMP PU liner running equipment, prepare to run liner. Hole is full. 23:45 - 00:00 0.25 CASE P CaMP PJSM prior to PU liner. Review Lessons learned from previious wells on running liner. Review liner running procedure. Discuss good body positioning, staying out from under loads, and being aware of pinch points. Stop the job if an unsafe situation occurs. 11/4/2002 00:00 - 01 :00 1.00 CASE P CaMP PU 2-7/8" slotted/solid liner. ,.. 01:00 - 02:15 1.25 CASE N SFAL COMP Back-ups on Tongs not working properly, make some adjustments. Also, learning curve on using hydraulic back-ups (new to crew). 02:15 - 08:00 5.75 CASE P CaMP Continue PU, 2-7/8" slotted/solid liner. Drift each joint while PU. PU, Baker Hydraulic GS running tool. Stab inj. 08:00 - 10:00 2.00 CASE P CaMP RIH w/o pumps. Correct depth at flag (+5'). Continue RIH. Sat down but fell thru 10168' and 10188'. Sat down at 10282'. PU clean 43k. RIH tag same spot. Try different speeds and bouncing BHA. Same spot -- not a hint of an inch past. Max overpull 5k. Acts like ledge. Using Baker tapered guide shoe. 10:00 -12:15 2.25 CASE N DPRB COMP POOH 12:15 - 12:45 0.50 CASE N DPRB COMP Safety meeting 12:45 - 13:15 0.50 CASE N DPRB CaMP SB inj. Lay down Baker running tools. 13:15 -15:45 2.50 CASE N DPRB CaMP RU elevators, tongs. Stand back liner. No damage on guide shoe. When shoe was removed, dumped a bunch of much and solids on floors. Solids (about 5 gallons) were pieces of Shublik as big as 1-1/2" long, 1/2" wide, 1/2" thick. One excellent large sample of pyritized pelycapod fossil. Cute, but poor $/bbl investment. 15:45 - 16:15 0.50 CASE N DPRB CaMP Clean Shublik off floor. 16:15 - 16:45 0.50 CASE N DPRB CaMP Safety meeting. 16:45 - 18:15 1.50 CASE N DPRB COMP PU drilling BHA. 18:15 - 21:20 3.08 CASE N DPRB COMP RIH for cleanout run. 1.69deg Motor, used DS49, MWD, TORC. Shallow hole test, TORC not responding, switch pumps, possibly not getting signals to the tool. Good test, may be a software issue not sending the right signal to the TORC from the pumps. Talked to Jeff Jones and got a BOPE test waiver for the next two runs, clean-out and next liner running attempt. 21:20 - 22:40 1.33 CASE N SFAL COMP Hydraulic leak in power pack when shifting from high to low gear. Shut down pumps, park CT at 10089'. 22:40 - 23:00 0.33 CASE N DPRB COMP RIH to 1 0130'md 23:00 - 00:00 1.00 CASE N DPRB CaMP Tie-in 11/5/2002 00:00 - 00:20 0.33 CASE N DPRB COMP Tie-in. Add 12'. 00:20 - 01 :30 1.17 CASE N DPRB CaMP Set down at 10286'. PU off bottom and get TF signal, TF=41 L. 2.8/2.8 Freespin=3350 RIH wt=15500. RBIH, no set-downs, Printed: 11/1212002 10:36:24 AM ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-31 R-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 9/8/2002 Rig Release: 11/6/2002 Rig Number: N2 Spud Date: 7/8/1992 End: 1115/2002 00:20 - 01 :30 1.17 CASE N DPRB COMP min. motor work to 10286' , set down, come off pumps, PU. Set down again at 10286' RIH wI pumps off. Work past at 75fpm. Sit down at 10358', 200lbs motor work. PU. Shut down pumps, RIH at 60fpm, work past. (Seeing 1/2" pieces of Shublik over shakers) RIH to 10500'. PU, clean PU, pull back thru shublik at 8-1 Of pm , seeing med amt of motor work in spots. 10243', motor work, start packing off, pull 1 Ok over, pop free. RBIH to 10524' at 40L, 23fpm. minimal motor work. Backream thru sump at 40L. (pass #2) Med. amt of motor work, some overpulls. Areas where we see work are not consistent between passes. 01 :30 - 02:25 0.92 CASE N DPRB COMP RBIH to 10524' at 40L. Orient to 60R, backream up for pass #3. 2.9/2.9 3500psi. RBIH at 40fpm, 40-60R. No set downs. RIH to 10600', orient to 150R. Backream up for pass #4. Start losing returns, out rate slowly catching up wI in rate, losses seem to be healing. We have lost total 2 bbl in the last hr. Hole is a bit grabby as we backream but nothing really substantial. See 50-100psi motor work from 10260' up to 10235'md. 02:25 - 02:55 0.50 CASE N DPRB COMP RBIH at 150R, 60fpm. Set down at 10286', bounce past. Set down at 10337', motor work, PU, RBIH 75fpm. Cont RIH at 40fpm. RIH to 10550 Orient TF to 120L. Backream up for pass #5. Very litttle motor work. 02:55 - 04:00 1.08 CASE N DPRB COMP Attempt to orient to Highside TF, RIH. Lost MM out signal. Still getting returns over shakers. PU. Diagnose problem, looks like MM out is plugged. RIH. TORC is not responding to commands, TF is still 120L. Tag TD at 12128'md. Wait for new Flo-pro (80KLSRV, 5% Lube tex) to get to bit. 04:00 - 04:55 0.92 CASE N DPRB CaMP POH, 57fpm laying in new Flo-pro to Shublik/Sag intersection at 10450'. PU rate and backream sump with 3%KCL, followed by remainder of new mud in OH. Pull heavy 10330', RBIH to 10450'. POH at 3bpm across sump, no overpulls. 04:55 - 09:30 4.58 CASE N DPRB COMP POH at 3bpm, 60fpm, chasing cuttings. Shut down briefly at window. Losing 10bph based on pit straps. Start packing off inside tubing, RBIH to 10000', start getting back returns, POH. A few bigger chunks of rock coming over shakers. No mud losses. Packoff briefly in 5683' GLM. RIH. Pull back thru clean. At about 3000', slow down pulling speed (large quantity of rocks coming across). Continue at full rate to surface. RIH to 1000'. Circ two BU. Returns clean. POOH. 09:30 - 10:30 1.00 CASE N DPRB CaMP SB inj. LD drilling BHA. 10:30 - 13:30 3.00 CASE N DPRB CaMP MU 2-7/8" liner assembly. "f" 13:30 - 15:30 2.00 CASE N DPRB CaMP RU and run CSH wash pipe. Space out and sting into o-ring sub. 15:30 - 16:30 1.00 CASE N DPRB CaMP MU coil onto liner. Stab injector onto well. 16:30 - 19:20 2.83 CASE N DPRB CaMP RIH with liner assembly. Tagged at 10280' worked past this spot and continued working to 12126'. 19:20 - 20:45 1.42 CASE P CaMP Load and pump 5/8" ball for CTLRT. Ball on set sheared at 3200 psi. Pick up and confirm release from liner. (lost 10k weight) 20:45 - 21 :30 0.75 CASE P CaMP Swap to 2% KCL. Displace liner with same. 21 :30 - 23:30 2.00 CASE P CaMP TOH same time displace 41/2" tubing with 2% KCL. (returning Flo-Pro mud to MI for next well) Printed: 11/12/2002 10:36:24 AM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: R-31 R-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 - , '. . - " . . . . Erôrn<:;'To HOUfS',Tåsk." Códê:' 'NPm:}:'Phasê " 11/5/2002 23:30 - 00:00 0.50 CASE P COMP 11/6/2002 00:00 - 00:20 0.33 CASE COMP 00:20 - 03:00 2.67 CASE COMP 03:00 - 03: 15 0.25 DEMOB COMP 03: 15 - 04:00 0.75 DEMOB COMP 04:00 - 04:30 0.50 DEMOB CaMP 04:30 - 05:30 1.00 DEMOB COMP 05:30 - 07:00 1.50 DEMOB COMP 07:00 - 13:30 6.50 RIGD COMP Start: 9/8/2002 Rig Release: 11/6/2002 Rig Number: N2 Spud Date: 7/8/1992 End: . - - - ' - . ~~$q(iptigl:t:ø,e~perètipl1~ Pop off well and set back injector. PJSM review procedures for handling of CTLRT & 1.25" CSH tubing. UD liner running tools and stand back 1.25" Hydril inner string tubing. PJSM reveiw plan forward. Pick up injector. Install nozzle RIH to 2000' lay in MEOH 1: 1 to surface Pop off well. UD nozzle. Set back and secure injector for rig move. Haul off unused fluids. Clean pits. Clean cuttings tank. ND & secure BOPS. NU & test tree cap. Release rig at 1330 hours on 11/6/02 Printed: 11/12/2002 10:36:24 AM SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay Well. . . . . . . . . . . . . . . . . . . . .: R 31A API number...............: 50-029-22277-01 Engineer. . . . . . . . . . . . . . . . .: Flores RIG: . . . . . . . . . . . . . . . . . . . . .: Nordic 2 STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS. . . . . . . . . . .: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: Correlation Marker GL above permanent.......: -50000.00 ft KB above permanent.......: -50000.00 ft DF above permanent.......: -50000.00 ft ----- Vertical section origin---------------- Latitude {+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 276.00 degrees 4-Nov-2002 20:43:28 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 3 10-29-02 04-Nov-02 52 10083.79 ft 12126.00 ft '-' ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2002 Magnetic date..........;.: 29-0ct-2002 Magnetic field strength..: 1150.54 RCNT Magnetic dec (+E/W-).....: 25.97 degrees Magnetic dip.............: 80.82 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: R..............: Dip. . . . . . . . . . . . : of G...........: of R.. . . . . . . . . . : of Dip......... : Criteria --------- 1002.68 mGal 1150.54 RCNT 80.82 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec {+E/W-).....: 26.11 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr {+E/W-)....: 26.11 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type. . . : I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction ~ SCHLUMBERGER Survey Report 4-Nov-2002 20:43:28 Page 2 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type ( deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 10083.79 39.52 337.63 0.00 8650.64 2483.64 3503.30 -2129.11 4099.54 328.71 0.00 TIP None 2 10100.00 39.84 337.64 16.21 8663.12 2488.56 3512.87 -2133.05 4109.76 328.73 1.97 MWD M None 3 10142.00 49.89 330.70 42.00 8692.86 2504.28 3539.40 -2146.07 4139.20 328.77 26.59 MWD M None 4 10183.77 62.78 323.69 41.77 8715.99 2526.12 3568.44 -2164.98 4173.84 328.75 33.83 SP None 5 10217.50 72.48 317.29 33.73 8728.83 2548.38 3592.42 -2184.84 4204.64 328.69 33.68 MWD M None '~ 6 10249.00 82.16 312.23 31.50 8735.74 2572.32 3614.01 -2206.64 4234.42 328.59 34.49 MWD M None 7 10293.75 98.38 293.31 44.75 8735.53 2611.96 3638.05 -2243.97 4274.43 328.33 55.58 SP None 8 10327.50 107.88 283.15 33.75 8727.85 2643.98 3648.35 -2275.09 4299.60 328.05 40.61 MWD M None 9 10371.00 104.27 275.14 43.50 8715.79 2685.67 3654.96 -2316.32 4327.13 327.64 19.54 MWD M None 10 10400.50 100.76 271.87 29.50 8709.39 2714.44 3656.72 -2345.05 4344.06 327.33 16.08 MWD M None 11 10464.50 105.23 270.00 64.00 8695.01 2776.54 3657.75 -2407.39 4378.88 326.65 7.54 MWD M None 12 10499.94 99.33 264.99 35.44 8687.47 2810.76 3656.21 -2441.96 4396.71 326.26 21.67 SP None 13 10531.50 99.40 265.97 31.56 8682.34 2841.37 3653.76 -2473.00 4411.99 325.91 3.11 MWD M None 14 10575.00 88.66 261.48 43.50 8679.28 2883.70 3649.01 -2516.06 4432.36 325.41 26.74 MWD M None 15 10608.50 87.74 258.83 33.50 8680.33 2915.91 3643.29 -2549.04 4446.48 325.02 8.37 MWD M None 16 10641.50 87.70 254.27 33.00 8681.65 2946.99 3635.62 -2581.10 4458.68 324.63 13.81 MWD M None 17 10677.50 88.08 250.89 36.00 8682.97 2979.99 3624.85 -2615.42 4469.90 324.19 9.44 MWD M None 18 10709.00 89.11 247.05 31.50 8683.75 3008.04 3613.55 -2644.81 4478.03 323.80 12.62 MWD M None 19 10740.50 91.27 245.47 31.50 8683.64 3035.39 3600.87 -2673.64 4484.94 323.41 8.50 MWD M None 20 10772.50 93.91 239.49 32.00 8682.20 3062.03 3586.11 -2701.98 4490.09 323.00 20.41 MWD M None ~ 21 10805.50 95.91 230.49 33.00 8679.37 3086.81 3567.27 -2728.88 4491.35 322.58 27.84 MWD M None 22 10845.00 91.54 229.98 39.50 8676.80 3114.30 3542.06 -2759.17 4489.91 322.08 11.14 MWD M None 23 10885.00 90.48 225.73 40.00 8676.09 3140.98 3515.23 -2788.82 4487.13 321.57 10.95 MWD M None 24 10931.00 90.07 225.29 46.00 8675.87 3170.25 3483.00 -2821.63 4482.51 320.99 1.31 MWD M None 25 10962.50 89.07 231.21 31.50 8676.11 3191.42 3462.03 -2845.12 4481.12 320.59 19.06 MWD M None 26 10994.50 87.70 237.87 32.00 8677.01 3215.37 3443.49 -2871.16 4483.43 320.18 21.24 MWD M None 27 11036.00 88.32 244.55 41.50 8678.46 3249.42 3423.52 -2907.49 4491.55 319.66 16.16 MWD M None 28 11067.00 89.49 247.87 31.00 8679.05 3276.31 3411.02 -2935.84 4500.47 319.28 11.35 MWD M None 29 11134.45 94.95 257.69 67.45 8676.43 3338.15 3391.09 -3000.12 4527.72 318.50 16.64 MWD M None 30 11212.07 92.80 269.19 77.62 8671.17 3413.60 3382.26 -3076.92 4572.43 317.71 15.03 SP None SCHLUMBERGER Survey Report 4-Nov-2002 20:43:28 Page 3 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) ( deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 11250.50 91.89 271.01 38.43 8669.60 3451.80 3382.33 -3115.31 4598.40 317.35 5.31 MWD M None - 32 11305.50 92.09 281.31 55.00 8667.68 3506.69 3388.22 -3169.89 4639.85 316.91 18.72 MWD M None 33 11346.50 91.85 281.94 41.00 8666.27 3547.47 3396.47 -3210.02 4673.36 316.62 1.64 MWD M None 34 11389.50 90.72 281.84 43.00 8665.31 3590.23 3405.33 -3252.09 4708.76 316.32 2.64 MWD M None 35 11433.50 90.96 284.90 44.00 8664.66 3633.85 3415.50 -3294.89 4745.73 316.03 6.98 MWD M None ~ 36 11467.00 95.67 285.45 33.50 8662.73 3666.86 3424.26 -3327.16 4774.46 315.82 14.15 MWD M None 37 11499.00 95.39 284.03 32.00 8659.64 3698.34 3432.36 -3357.96 4801.77 315.63 4.50 MWD M None 38 11539.50 96.49 283.28 40.50 8655.45 3738.26 3441.87 -3397.10 4835.99 315.38 3.28 MWD M None - 39 11571.50 96.80 283.08 32.00 8651.75 3769.80 3449.12 -3428.05 4862.91 315.18 1.15 MWD M None - 40 11646.50 89.52 286.50 75.00 8647.61 3843.74 3468.22 -3500.39 4927.61 314.74 10.72 MWD M None 41 11683.00 89.62 284.40 36.50 8647.89 3879.75 3477.95 -3535.57 4959.47 314.53 5.76 MWD M None - 42 11714.50 89.72 279.49 31.50 8648.07 3911.07 3484.47 -3566.38 4986.04 314.33 15.59 MWD M None 43 11746.50 90.31 274.07 32.00 8648.06 3943.05 3488.24 -3598.14 5011.43 314.11 17.04 MWD M None 44 11780.00 90.14 268.31 33.50 8647.93 3976.42 3488.94 -3631.62 5036.01 313.85 17.20 MWD M None - 45 11811.50 90.34 267.72 31.50 8647.80 4007.61 3487.85 -3663.10 5058.00 313.60 1.98 MWD M None 46 11847.00 92.16 272.54 35.50 8647.02 4042.91 3487.93 -3698.58 5083.81 313.32 14.51 MWD M None 47 11904.00 94.81 280.00 57.00 8643.55 4099.76 3494.13 -3755.09 5129.29 312.94 13.86 MWD M None - 48 11942.00 93.95 280.11 38.00 8640.65 4137.55 3500.74 -3792.40 5161.15 312.71 2.28 MWD M None - 49 11979.00 90.17 284.51 37.00 8639.32 4174.29 3508.63 -3828.51 5193.07 312.50 15.67 MWD M None - 50 12015.00 87.36 292.35 36.00 8640.10 4209.40 3519.99 -3862.62 5225.92 312.34 23.13 MWD M None ~ 51 12060.50 87.36 301.36 45.50 8642.20 4251.83 3540.50 -3903.13 5269.69 312.21 19.78 MWD M None proyected Survey to TD. 52 12126.00 87.36 301.36 65.50 8645.21 4310.96 3574.56 -3959.00 5333.96 312.08 0.00 MWD M None [(c)2002 IDEAL ID8_0C_06] bp Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location LatILong: Location Grid NlE YIX: Grid Convergence Angle: Grid Scale Factor: R-31A Survey Report - Geodetic 4-Nov-02 Shared Services Drilling Prudhoe Bay Unit - WOA (Drill Pads) R-PAD / R-31 R-31 R-31A 500292227701 R-31A / November 4,2002 386.002° /6117.75 ft /6.516/0.700 NAD27 Alaska State Planes, Zone 4, US Feel N 70 20 43.528, W 14854 23.99€ N 5977123.300 ftUS, E 634693.480 ftUS + 1.02964821 ° 0.99992061 Station ID MD Incl Azim (ft) n (°) 10083.79 39.52 337.63 10100.00 39.84 337.64 10142.00 49.89 330.70 10183.77 62.78 323.69 10217.50 72.48 317.29 10249.00 82.16 312.23 10293.75 98.38 293.31 10327.50 107.88 283.15 10371.00 104.27 275.14 10400.50 100.76 271.87 10464.50 105.23 270.00 10499.94 99.33 264.99 10531.50 99.40 265.97 10575.00 88.66 261.48 10608.50 87.74 258.83 10641.50 87.70 254.27 10677.50 88.08 250.89 10709.00 89.11 247.05 R-31 A ASP Final Surveys.xls TVD (ft) 8650.64 8663.11 8692.86 8715.99 8728.82 VSec (ft) 2483.69 2488.60 2504.33 2526.17 2548.42 N/-S (ft) 3503.33 3512.90 3539.44 3568.48 3592.46 Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: Schlumberger Minimum Curvature / Lubinski 276.000° ! N 0.000 ft, E 0.000 f1 MSl 0.000 ft relative to MSL 25.97 1150.54 HCNT 80.82° 28-0ct-02 BGGM 2002 True North +25.97 Well Head ~ E/-W (ft) -2129.15 -2133.09 -2146.11 -2165.02 -2184.88 Grid Coordinates Northing Easting (ftUS) (ftUS) 5980587.52 632501.90 1.97 5980597.02 632497.79 26.59 5980623.31 632484.29 33.84 5980652.01 632464.87 33.67 5980675.63 632444.59 Geographic Coordinates Latitude Longitude N 70 21 17.979 W 148 55 26.234 N 70 21 18.073 W 148 5526.349 N 7021 18.334 W 148 55 26.730 N 7021 18.620 W 1485527.283 N 70 21 18.856 W 148 55 27.863 8735.73 2572.36 3614.05 -2206.68 34.49 5980696.82 632422.40 N 70 21 19.068 W 148 55 28.501 8735.52 2612.00 3638.08 -2244.01' 55.58 5980720.18 632384.64 N 70 21 19.304 W 148 5529.592 8727.84 2644.03 3648.39 -2275.13 40.61 5980729.93 632353.35 N 7021 19.406 W 148 55 30.502 ; 8715.78 2685.72 3655.00 -2316.36 19.54 5980735.79 632312.01 N702119.470 W1485531.707 .,-", 8709.39 2714.48 3656.'6 -2345.09 16.08 5980737.03 632283.25 N 70 21 19.488 W 148 55 32.547 8695.00 2776.58 3657.78 -2407.43 7.54 5980736.94 632220.91 N 70 21 19.498 W 148 55 34.370 8687.46 2810.80 3656.25 -2442.00 21.63 5980734.79 632186.38 N 7021 19.482 W 148 55 35.380 8682.32 2841 .42 3653.80 -2473.04 3.07 5980731.78 632155.39 N 70 21 19.458 W 148 55 36.287 8679.27 2883.74 3649.05 -2516.09 26.74 5980726.26 632112.43 N 70 21 19.411 W 148 55 37.546 8680.32 2915.95 3643.33 -2549.08 8.37 5980719.94 632079.55 N 70 21 19.355 W 1485538.510 8681.63 2947.03 3635.66 -2581 .14 13.81 5980711 .70 632047.64 N 7021 19.279 W 148 55 39.447 8682.96 2980.04 3624.89 -2615.46 9.44 5980700.32 632013.52 N 7021 19.173 W 1485540.450 8683.73 3008.09 3613.60 -2644.85 12.62 5980688.49 631984.34 N 7021 19.062 W 148 5541.309 Page 1 of 2 DLS (0/100ft) 11/11/2002-1 :12 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 10740.50 91.27 245.47 8683.63 3035.43 3600.92 -2673.68 8.50 5980675.30 631955.74 N 702118.937 W 148 5542.152 10772.50 93.91 239.49 8682.18 3062.07 3586.15 -2702.02 20.41 5980660.03 631927.68 N 70 21 18.792 W 148 5542.980 10805.50 95.91 230.49 8679.35 3086.86 3567.31 -2728.92 27.84 5980640.71 631901.12 N 7021 18.607 W 148 55 43.766 10845.00 91.54 229.98 8676.79 3114.35 3542.11 -2759.21 11.14 5980614.97 631871! .29 N 70 21 18.359 W 148 55 44.652 10885.00 90.48 225.73 8676.08 3141.03 3515.28 -2788.86 10.95 5980587.61 631842.14 N 7021 18.095 W 148 55 45.518 10931.00 90.07 225.29 8675.86 3170.29 3483.04 -2821.67 1.31 5980554.80 631809.91 N 7021 17.778 W 148 5546.477 10962.50 89.07 231.21 8676.10 3191.46 3462.08 -2845.16 19.06 5980533.41 631786.80 N702117.571 W1485547.163 10994.50 87.70 237.87 8677.00 3215.42 3443.53 -2871.20 21.24 5980514.40 631761.10 N 70 21 17.389 W 148 55 47.924 11036.00 88.32 244.55 8678.44 3249.46 3423.57 -2907.53 16.16 5980493.79 631725.14 N702117.192 W1485548.986 .~ 11067.00 89.49 247.87 8679.03 3276.35 3411.07 -2935.88 11.35 5980480.79 631697.02 N 7021 17.069 W 148 55 49.814 11134.45 94.95 257.69 8676.42 3338.19 3391.14 -3000.16 16.64 5980459.71 631633.12 N702116.873 W1485551.693 11212.07 92.80 269.19 8671.15 3413.65 3382.31 -3076.96 15.04 5980449.51 631556.50 N 7021 16.786 W 148 55 53.938 11250.50 91.89 271.01 8669.58 3451.84 3382.38 -3115.35 5.29 5980448.88 631518.11 N 7021 16.786 W 1485555.060 11305.50 92.09 281.31 8667.67 3506.73 3388.27 -3169.93 18.72 5980453.79 631463.44 N 70 21 16.844 W 148 55 56.656 11346.50 91.85 281.94 8666.26 3547.51 3396.53 -3210.06 1.64 5980461.32 631423.17 N 70 21 16.925 W 148 55 57.829 11389.50 90.72 281.84 8665.29 3590.27 3405.39 -3252.13 2.64 5980469.42 631380.95 N 70 21 17.012 W 148 55 59.059 11433.50 90.96 284.90 8664.65 3633.90 3415.56 -3294.93 6.98 5980478.82 631337.98 N702117.112 W 148 56 0.310 11467.00 95.67 285.45 8662.71 3666.91 3424.31 -3327.20 14.15 5980486.99 631305.56 N 70 2117.198 W 148 56 1.253 11499.00 95.39 284.03 8659.63 3698.39 3432.41 -3358.00 4.50 5980494.54 631274.62 N 70 21 17.277 W 148 562.154 11539.50 96.49 283.28 8655.43 3738.31 3441.92 -3397.14 3.28 5980503.35 631235.32 N 7021 17.371 W 148 56 3.298 11571.50 96.80 283.08 8651.73 3769.85 3449.17 -3428.09 1.15 5980510.04 631204.25 N 70 21 17.442 W 148 56 4.203 11646.50 89.52 286.50 8647.60 3843.79 3468.28 -3500.43 10.72 5980527.84 631131.58 N 70 21 17.630 W 148566.318 11683.00 89.62 284.40 8647.87 3879.79 3478.00 -3535.61 5.76 5980536.93 631096.23 N 70 21 17.725 W 148567.346 11714.50 89.72 279.49 8648.05 3911.11 3484.52 -3566.42 15.59 5980542.89 631065.32 N 70 21 17.789 W 148 56 8.247 11746.50 90.31 274.07 8648.05 3943.1 0 3488.30 -3598.18 17.04 5980546.09 631033.49 N 70 21 17.826 W 148 56 9.175 ~ 11780..00 90.14 268.31 8647.91 3976.47 3488.9~ -3631.66 17.20 5980546.19 631000.01 N 70 2117.833 W 148 5610.154 11811.50 90.34 267.72 8647.78 4007.66 3487.90.. -3663.14 1.98 5980544.53 630968.56 N 70 21 17.822 W 148 5611.074 11847.00 92.16 272.54 8647.01 4042.95 3487.98 -3698.62 14.51 5980543.97 630933.08 N 7021 17.822 W 148 5612.111 11904.00 94.81 280.00 8643.54 4099.80 3494.18 -3755.13 13.86 5980549.16 630876.48 N 70 21 17.883 W 148 5613.763 11942.00 93.95 280.11 8640.64 4137.60 3500.80 -3792.44 2.28 5980555.10 630839.06 N 70 21 17.948 W 148 56 14.854 11979.00 90.17 284.51 8639.31 4174.33 3508.68 -3828.55 15.67 5980562.34 630802.82 N 7021 18.025 W 148 5615.909 12015.00 87.36 292.35 8640.08 4209.45 3520.05 -3862.66 23.13 5980573.09 630768.51 N 70 2118.137 W 1485616.907 12060.50 87.36 301.36 8642.18 4251.88 3540.56 -3903.17 19.78 5980592.86 630727.64 N 70 21 18.338 W 148 56 18.091 12126.00 87.36 301.36 8645.20 4311.00 3574.61 -3959.04 0.00 5980625.90 630671 .17 N 7021 18.673 W 1485619.725 R-31 A ASP Final Surveys.xls Page 2 of 2 11/11/2002-1 :12 PM ) ) c3tOò>-lb6 MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No R-31 A Date Dispatched: 6-Nov-02 Installation/Rig Nordic 2 Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys Field Copy ASP (Alaska State Plane) 2 2 1 on floppy on floppy r~fOj ~~ P~~. ~~~. ~~ ~JY-'. ~~ ~ v RECE'VEC ~ NO\' 15 Z002 Alaska œ & Gas Cons. Commissim Anchorage Received By: ~¿.J)t20r' Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alàska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 bp R-31A Schlu puer Survey Report - Geodetic Report Date: 4-Nov-02 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: Shared Services Drilling Vertical Section Azimuth: 276.000° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 fl Structure I Slot: R-PAD I R-31 TVD Reference Datum: MSL Well: R-31 TVD Reference Elevation: 0.000 ft relative to MSL Borehole: R-31A UWI/API#: 500292227701 Magnetic Declination: 25.97 Survey Name I Date: R-31A I November 4,2002 Total Field Strength: 1150.54 HCNT Tort I AHD I DDII ERD ratio: 386.002° I 6117.75 ftl 6.516 / 0.700 Magnetic Dip: 80.82° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: 28-0ct-02 .~ Location LatlLong: N 702043.528, W 14854 23.99E Magnetic Declination Model: BGGM 2002 Location Grid N/E YIX: N 5977123.300 ftUS, E 634693.480 ftUS North Reference: True North Grid Convergence Angle: +1.02964821 ° Total Corr Mag North -> True North: +25.97 Grid Scale Factor: 0.99992061 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S E/-W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 10083.79 39.52 337.63 8650.64 2483.69 3503.33 -2129.15 5980587.52 632501.90 N 70 21 17.979 W 148 55 26.234 10100.00 39.84 337.64 8663.11 2488.60 3512.90 -2133.09 1.97 5980597.02 632497.79 N 70 21 18.073 W 1485526.349 10142.00 49.89 330.70 8692.86 2504.33 3539.44 -2146.11 26.59 5980623.31 632484.29 N 70 21 18.334 W 1485526.730 10183.77 62.78 323.69 8715.99 2526.17 3568.48 -2165.02 33.84 5980652.01 632464.87 N 7021 18.620 W 148 55 27.283 10217.50 72.48 317.29 8728.82 2548.42 3592.46 -2184.88 33.67 5980675.63 632444.59 N 70 21 18.856 W 148 55 27.863 10249.00 82.16 312.23 8735.73 2572.36 3614.05 -2206.68 34.49 5980696.82 632422.40 N 70 21 19.068 W 148 55 28.501 10293.75 98.38 293.31 8735.52 2612.00 3638.08 -2244.01 55.58 5980720.18 632384.64 N 70 21 19.304 W 148 55 29.592 10327.50 107.88 283.15 8727.84 2644.03 3648.39 -2275.13 40.61 5980729.93 632353.35 N 70 21 19.406 W 148 55 30.502 10371.00 104.27 275.14 8715.78 2685.72 3655.00 -2316.36 19.54 5980735.79 632312.01 N 70 2119.470 W 148 55 31.707 ~ 10400.50 100.76 271.87 8709.39 2714.48 3656.76 -2345.09 16.08 5980737.03 632283.25 N 70 21 19.488 W 148 55 32.547 10464.50 105.23 270.00 8695.00 2776.58 3657.78 -2407.43 7.54 5980736.94 632220.91 N 7021 19.498 W 148 55 34.370 10499.94 99.33 264.99 8687.46 2810.80 3656.25 -2442.00 21.63 5980734.79 632186.38 N 70 21 19.482 W 148 5535.380 10531.50 99.40 265.97 8682.32 2841 .42 3653.80 -2473.04 3.07 5980731 .78 632155.39 N 70 21 19.458 W 148 55 36.287 10575.00 88.66 261 .48 8679.27 2883.74 3649.05 -2516.09 26.74 5980726.26 632112.43 N 7021 19.411 W 148 55 37.546 10608.50 87.74 258.83 8680.32 2915.95 3643.33 -2549.08 8.37 5980719.94 632079.55 N 7021 19.355 W 148 55 38.510 ~ 10641.50 87.70 254.27 8681.63 2947.03 3635.66 -2581.14 13.81 5980711.70 632047.64 N 7021 19.279 W 14855 39.447 ~ 10677.50 88.08 250.89 8682.96 2980.04 3624.89 -2615.46 9.44 5980700.32 632013.52 N 70 21 19.173 W 1485540.450 10709.00 89.11 247.05 8683.73 3008.09 3613.60 -2644.85 12.62 5980688.49 631984.34 N 7021 19.062 W 148 55 41.309 - 8' R-31 A ASP Final Surveys.xls Page 1 of 2 11/11/2002-1 :12 PM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S EI-W DLS Northing Easting Latitude Longitude (ft) n (°) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 10740.50 91.27 245.47 8683.63 3035.43 3600.92 -2673.68 8.50 5980675.30 631955.74 N 7021 18.937 W 148 55 42.152 10772.50 93.91 239.49 8682.18 3062.07 3586.15 -2702.02 20.41 5980660.03 631927.68 N 7021 18.792 W 148 55 42.980 10805.50 95.91 230.49 8679.35 3086.86 3567.31 -2728.92 27.84 5980640.71 631901.12 N 70 21 18.607 W 148 5543.766 10845.00 91.54 229.98 8676.79 3114.35 3542.11 -2759.21 11.14 5980614.97 631871.29 N 7021 18.359 W 148 55 44.652 10885.00 90.48 225.73 8676.08 3141.03 3515.28 -2788.86 10.95 5980587.61 631842.14 N702118.095 W1485545.518 10931.00 90.07 225.29 8675.86 3170.29 3483.04 -2821.67 1.31 5980554.80 631809.91 N 7021 17.778 W 1485546.477 10962.50 89.07 231.21 8676.10 3191.46 3462.08 -2845.16 19.06 5980533.41 631786.80 N 7021 17.571 W 1485547.163 1 0994.50 87.70 237.87 8677.00 3215.42 3443.53 -2871.20 21.24 5980514.40 631761.10 N 70 21 17.389 W 14855 47.924 11036.00 88.32 244.55 8678.44 3249.46 3423.57 -2907.53 16.16 5980493.79 631725.14 N 70 21 17.192 W 148 55 48.986 11067.00 89.49 247.87 8679.03 3276.35 3411.07 -2935.88 11.35 5980480.79 631697.02 N 70 21 17.069 W 148 55 49.814 .~ 11134.45 94.95 257.69 8676.42 3338.19 3391 .14 -3000.16 16.64 5980459.71 631633.12 N 7021 16.873 W 148 55 51.693 11212.07 92.80 269.19 8671 .15 3413.65 3382.31 -3076.96 15.04 5980449.51 631556.50 N7021 16.786 W 148 55 53.938 11250.50 91.89 271.01 8669.58 3451.84 3382.38 -3115.35 5.29 5980448.88 631 518. 11 N 70 21 16.786 W 148 55 55.060 11305.50 92.09 281.31 8667.67 3506.73 3388.27 -3169.93 18.72 5980453.79 631463.44 N 70 21 16.844 W 148 55 56.656 11346.50 91.85 281.94 8666.26 3547.51 3396.53 -3210.06 1.64 5980461.32 631423.17 N 7021 16.925 W 148 55 57.829 11389.50 90.72 281.84 8665.29 3590.27 3405.39 -3252.13 2.64 5980469.42 631380.95 N 70 21 17.012 W 148 55 59.059 11433.50 90.96 284.90 8664.65 3633.90 3415.56 -3294.93 6.98 5980478.82 631337.98 N 70 21 17.112 W 148 560.310 11467.00 95.67 285.45 8662.71 3666.91 3424.31 -3327.20 14.15 5980486.99 631305.56 N702117.198 W 148 561.253 11499.00 95.39 284.03 8659.63 3698.39 3432.41 -3358.00 4.50 5980494.54 631274.62 N 70 21 17.277 W 148 56 2.154 11539.50 96.49 283.28 8655.43 3738.31 3441.92 -3397.14 3.28 5980503.35 631235.32 N 7021 17.371 W 148 56 3.298 11571.50 96.80 283.08 8651.73 3769.85 3449.17 -3428.09 1.15 5980510.04 631204.25 N 7021 17.442 W 148 56 4.203 11646.50 89.52 286.50 8647.60 3843.79 3468.28 -3500.43 10.72 5980527.84 631131.58 N 7021 17.630 W 148 56 6.318 11683.00 89.62 284.40 8647.87 3879.79 3478.00 -3535.61 5.76 5980536.93 631096.23 N 7021 17.725 W 148 567.346 11714.50 89.72 279.49 8648.05 3911 . 11 3484.52 -3566.42 15.59 5980542.89 631065.32 N 7021 17.789 W 148568.247 11746.50 90.31 274.07 8648.05 3943.10 3488.30 -3598.18 17.04 5980546.09 631033.49 N702117.826 W 148569.175 11780.00 90.14 268.31 8647.91 3976.47 3488.99 -3631.66 17.20 5980546.19 631000.01 N 70 21 17.833 W 148 5610.154 ~ 11811.50 90.34 267.72 8647.78 4007.66 3487.90 -3663.14 1.98 5980544.53 630968.56 N 70 21 17.822 W 148 5611.074 11847.00 92.16 272.54 8647.01 4042.95 3487.98 -3698.62 14.51 5980543.97 630933.08 N 702117.822 W 148 5612.111 11904.00 94.81 280.00 8643.54 4099.80 3494.18 -3755.13 13.86 5980549.16 630876.48 N702117.883 W1485613.763 11942.00 93.95 280.11 8640.64 4137.60 3500.80 -3792.44 2.28 5980555.10 630839.06 N 7021 17.948 W 148 56 14.854 11979.00 90.17 284.51 8639.31 4174.33 3508.68 -3828.55 15.67 5980562.34 630802.82 N 7021 18.025 W 148 5615.909 12015.00 87.36 292.35 8640.08 4209.45 3520.05 -3862.66 23.13 5980573.09 630768.51 N 7021 18.137 W 148 5616.907 12060.50 87.36 301 .36 8642.18 4251.88 3540.56 -3903.17 19.78 5980592.86 630727.64 N 7021 18.338 W 148 56 18.091 12126.00 87.36 301.36 8645.20 4311.00 3574.61 -3959.04 0.00 5980625.90 630671 .17 N 7021 18.673 W 148 5619.725 R-31 A ASP Final Surveys.xls Page 2 of 2 11/11/2002-1 :12 PM R-31a CTD sidetrack ) ) Subject: R-31aCTD sidetrack Date: Fri, 16 Aug 2002 17:34:22 -0500 From: "Stagg, Ted 0 (ORBIS)" <StaggTO@BP.com> To: "Winton Aubert (E-mail)..<Winton_Aubert@admin.state.ak.us> Winton, A 10-403 was approved for work on R-31 to prep it for a CTD sidetrack. That approval number is 302-219. The plan that was approved included the setting of an IBP above open Zone 4 perfs prior to downsqueezing cement past the whipstock. I am requesting that this procedure be modified as follows: 1. The IBP will not be used. 2. The whipstock will be set at 10,100', in existing Sag R. perfs, as originally planned. 3. A minimum of 20 bbls of 13.8 ppg cement will be downsqueezed past the whipstock in order to cement off the open Zone 4 perfs as well as the open Sag R. perfs. A pressure test of 1000 psi will be achieved. The cement job will be repeated if needed to achieve the pressure test. This change is proposed in order to more securely 4 perfs from the Sag R. sidetrack to be drilled. planned for the Sag R. sidetrack is an uncemented in the prep procedure will better insure that the isolated from the Sag R. sidetrack. isolate the existing Zone The primary completion slotted liner. The change existing Zone 4 perfs are Please call to discuss if there are any questions. A new Proposed Completion schematic is attached. Ted Stagg 564-4694 «R-31a Prop Comp.ZIP» r '" ----"-'-----"-"-----'''-----'---:'''---'--'-'N-~-;-;~R-:3''ï;~~-Comp:iiP ----, ' , " , -----'____h______- -- -- . J t ~R-31a Prop comp.zIP Type: Zip Compressed Data (application/x-zip-compressed)~ I - Encoding: base64 ! : ,"""''''''''''''""'W-:/"^,^,',W,'''''',WMW.....w''''W''''''''''''''''''"",,,,N~...WN-".....W""""'" ''''''''.lWMW.W,WMW.''''''''''''''''''''''''''''''''''''.."'''''''''W''',,,,',';.,w.w...W"',,,,,'''''''''''''''W''''''''N'oYoU'o'.>M.w,,,''''''.w.''''''''''''"""'''''V'''''''W.W&.r.W;.,"""W.''''WN'''W'.''''''''''''Yo''''''''''''''''''''WWN.W.W.'.W..,.,....w"'",'",'"'""""'"'W'''''.",,,,,,Ÿ',",''''''''W,,'='''........'~ ') TREE = 4-1/16" 5MCIW WELLHEAD = 11" 5M FMC ACTUAtOR =' . BÄKER KB, ELEV = 51.2' ¡:f' EL¿ : I'!:' ;-::;r:n;- ~, ~ :~, R -31 A I SAFETY NOTES 1..01. ~ I'SO Proposed CTD Sidetrack r 1~~ ~ I-I ,) Ir; : -~:':~:h.~:_~.~I_~ ..!t L'2durn r 1(" : II:I~ : I DatumTVD= 8800' SS 110-3/4" CSG, 455#, NT-80, ID = 9,953" H 3314' ~ ----1 Minimum ID = 3.725" @ 9910' I 4-112" PARKER SWN NIPPLE (milled out to 3.8") /7-5/8" CSG, 297#, NSCC, ID= 6,875" 1-\ 10068' g ';::S TOPOF5-1/2"LNR!-i 9920' 1 4-1/2"TBG.12,6#.13CR,,0152bpf,ID=3958" 1-1 9923' I IS-1/2" MechanicalWhipstock H 10100' Minimum 20 bbls cement to be --- downsqueezed past the vvhipstock ÆRFORATlON SUMMARY REF LOG: BHCS ON 08/16/92 ANGLE AT TOP PERF: 40 @ 10095' Note: Refer to Production DB for historical perf data SIZE SFF INTERVAL Opn/Sqz DATE 3-3/8" 6 10095-10135 0 04/24/94 3-3/8" 6 10253-10283 0 07/18/93 3-3/8" 4 10253-10320 S 12/17192 2092' H4-1/2" OTIS HXO SSSV NIP, ID = 3,813" I GAS LIFT MANCÆLS . ST MD TVD DEV TYÆ VLV LATa; S 3073 3020 3 MERLA BK-S 4 5683 5274 40 MERLA BK-5 3 787S 6968 40 MERLA BK-5 2 9498 8205 41 MERLA BK-5 1 9744 8390 41 MERLA BK-5 FORT DATE 9773' H 4-112" PKR SWS NIP, ID = 3,813" I 9832' H7-S/8" x 4-112" BKR SABL-3 FKR,ID= 3,875" I 9875' \-1 Top of 3-3/16" Liner I 9875' l-j Top of cement I 9894' H 4-1/2" PKR SWS NIP, ID = 3.813" I 9910' H 4-112" PKR SWN NIP, ID = 3,80" I 9920' H 7- 5/8" x 5-1/2" LNR TOP FKR I 9923' 1-14-112" WLEG, ID = 3.958"1 9912' -1 ELMDlT LOGGED 08/16192 I 10200' H 3-3/16" x 2-7/8" X-over 1 3-3/16" x 2-7/8" Solid/pre-drilled 000 0 oj) - 11900' I ~ f I ì I PBTD H 10668' 1 IS-1/2" LNR, 17#, 13CR .0232 bpf, ID = 4,892" H 10750' I ~ DATE REV BY COMMENTS 07/24/92 ORIGINAL COMPLETION 03/14101 SIS-SLT CONVERTEDTO CANVAS 03/15/01 SIS-1vD RNAL 09/24/01 RNITP CORRECTIONS DA TE REV BY COMMENTS NOTE: The sidetrack liner cement shown in this schematic will be used only if lost circulation is encountered. Otherwise, the completion will be uncemented solid and pre-drilled liner. PRUDHOE BA Y UNIT W8.L: R- 31 PERMT No: 92-0680 AR No: 50-029-22277-00 SEC 32, T12N, R13E B~ EXploration (Alaska) } ~ TONY KNOWLES, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99510 Re: Prudhoe Bay Unit R-31A BP Exploration (Alaska), Inc. Pennit No: 202-150 Surface Location: 653' NSL, 1042' EWL, Sec. 32, TI2N, RI3E, UM Bottomhole Location: 4237' NSL, 2896' WEL, Sec. 31, TI2N, RI3E, UM Dear Mr. Stagg: Enclosed is the approved application for pennit to redrill the above development well. The pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test perfonned before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, (BA),~.^, ~. ~ C7~~;~echsli Taylor Chair BY ORDER OF THE COMMISSION DATED this£day of July 2002. cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of work 0' Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 653' NSL, 1042' EWL, SEC. 32, T12N, R13E, UM At top of productive interval 4155' NSL, 1075' WEL, SEC. 31, T12N, R13E, UM At total depth 4237' NSL, 2896' WEL, SEC. 31, T12N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well / ADL 028257, 1970" MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10100' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weicht Grade Couplina 3-3/4" 3-3I16"x2-7/S" 6.2#/6.16# L-80 ST-L 0) STATE OF ALASKA- ALASKA C,.~ÄND GAS CONSERVATION COMMI~_)ON PERMIT TO DRILL 20 AAC 25.005 1b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 51.92' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028279 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number ('/ R-31 A 9. Approximate spud date 09/20/02 7 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12125' MD 18641" TVDss 0 17. Anticipated pressure {s,* 20 AAC 25.035 (e) (2)} 110 Maximum surface 1544 psig, At total depth (TVD) 8800" I 2600 psig Setting Depth Top Bottom Quantitv of Cement Lenath MD TVD MD TVD (include staae data) 2250' 9875' 8489' 12125" 8641" Uncemented Slotted Liner f"" ttJ6A:- 7/' ð! 0 L JIt 1(,-;(02- 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10750 feet 9185 feet 10668 feet 9128 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 80" 20" 3315" 10-3/4" 1 0068' 7-5/8" 823' 5-1/2" 2086 cu ft AS III, 400 cu ft Class "G' 1943 cu ft Class "G" 80" 3315" 10068" 80' 3313' 8690' Perforation depth: measured 10095" - 10135', 10253" - 10320" 160 cu ft Class 'R E C: E I \/ E D 9927' - 10750" JUL -1 6 2002 8581' - 9185' true vertical 8711" - 8742", 8831' - 8881' Alaska Oil & Gas Cons. CommiSSion Anchorage II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer NameINumber: Ted Stagg, 564-4694 Prepared By NameINumber: Terrie Hubble, 564-4628 21.~~:~:y ~~i~;a~:~~:~':~:':~:#~~S~~~;~i:;t~::/..;:,.;:.;;;.... Dat: ~~IJ?~ Permit Number API Number Aep~V~1 Rate See cover letter 2..ð 2.. .... /J; r.> 50- 029-22277-01 r¡ j' 5 f()~ for other reauirements Conditions of Approval: Samples Required 0 Yes 81 No Mud Log eqUlred 0 Yes ŒI No Hydrogen Sulfide Measures 9 Yes 0 No Directional Survey Required 131 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: T €--s t- 1S~ P E /-ð "S 5 c? 0 f? !,. ¿ . Ongloaì Signed By Cammy Oechsli T~ 20. Attachments Approved By Form 10-401 Rev. 12-01-85 ~ Cpmmi$S~ner r ) ¡; or': ;1 ~\ u ^ Þ"", ~ ,~"'''' " ~~, j ,\ ~ ~ \ \1 1, ) M 1 \,! J~\ ij"ij'~,",;~~',& 1}. by order of the commission Date '7/;' (/pd-. Submit In Triplicate -) ') BP R-31 a CTD Sidetrack Summary of Operations: A CrD through tubing sidetrack is planned for R-31. The coil sidetrack, R-31a, will exit the 51/2" liner in the Sag River formation and will target the Sag River. / R-31 is a high water cut, low oil rate fracced Zone 4 producer, currently shut in due to high GOR. Remedial options for R-31 are unattractive. The sidetrack will target high quality Sag River formation to the southwest of the current location. R-31a is expected to receive gas cap support from the southwest and injection ,/ support. /' The planned sidetrack completion is a 27/8" slotted and solid liner crossed over to a 3 3/16" solid liner. The liner will be uncemented unless lost circulation is encountered. In the event of lost circulation, the completion will be cemented from 100 ft beyond.the loss zone to the top of the line.r. The production interval will be uncemented slotted liner in any event. / The sidetrack will kick oft in the Sag River, build angle and invert in the Shublik then land in the Sag River for the production interval. One small fault will be crossed soon after landing the horizontal section in the Sag R. Losses are not expected at this fault. Phase 1: Prep work. Planned for between August 15 to Sept. 10, 2002. 1. Dummy all GLM's and perform an MIT-IA. 2. Set an inflatable bridge plug at approx. 10,240' (8736ss) to isolate existing Zone 4 perfs. 3. Set a flow through whipstock in the 5 V2" liner at approx. 10,100 (8663ss). 4. Service coil will pump a minimum of 20 bbls cement to squeeze Sag R. perfs and to add cement above the inflatable bridge plug. Phase 2: Mill window, Drill and Complete sidetrack: Planned for Sept. 20, 2002. Drilling coil will be used to mill the window in the 5 %" liner then drill and complete the directional hole as per attached plan. Maximum hole angle will be 110 degrees. Mud Program: . Phase 1 &2: Seawater and 8.6 ppg Flo-Pro / . Phase 3: Mill and drill with Flo-Pro (8.6 - 8.7 ppg) Disposal: . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: The production liner will be a 3 3/16" TC II x 2 7/8" ST-L solid and pre-drilled liner from TD to approx. 9,875' MD (8489'ss). The X-O between 3 3/16" x 27/8" will be at 10,200' MD (8739'ss). This liner will be uncemented unless unexpected losses need to be isolated by cementing the upper portion of the liner. In this case a cementing port will be run approx. 100 ft beyond the loss zone such that cement can be circulated from the cementing port to the top of the liner at 9875' MD. Well Control: . BOP diagram is attached. / . Pipe rams, blind rams and the CT pack oft will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan. Max. planned hole angle is 110 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. ) ') Logging . An MWD Gamma Ray will be run over all of the open hole section. Resistivity will be run over part of the open hole. Hazards . R-31 measured 50 ppm H2S on 3/18/02. The highest nearby well is R-30 at 100 ppm H2s. Lost circulation risk is considered to be minimal based on fault orientation and regional history. There is some lost circulation risk if the frac wing of the Zone 4 perfs is penetrated. Low reservoir pressure, 2000 to 2600 psi, may increase differential sticking risk. Extensive Shublik drilling, >350 ft, increases risk of sloughing shale trouble. . . . . Reservoir Pressure Res. press. is estimated to be between 2000 ~d 2600 psi at 8800'ss (ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 1544 psi. I ) TREE = 4-1116" 5MCIW Wa.LHEAD = 11" 5M FMC A CTUA TOR = BAKER KB. ELEV = 51.2' BF. ELEV = 19.2' KOP = 3386' Max Angle = 46 @ 10520' Datum MD = 10281' Datum TVD = 8800' SS '10-3/4"CSG,45.5#, NT-BO, ID =9.953" H 3314' ~ Minimum ID = 3.725" @ 9910' 4-1/2" PARKER SWN NIPPLE 1 TOP OF 5-1 r¿" LNR H 9920' 1 I 4-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" H 9923' 1 1 7-518" CSG, 29.7#, NSCC, D = 6.875" H 10068' I PERFORATION SUWMARY REF LOG: BHCS ON 08/16/92 ANGLE AT TOP ÆRF: 40 @ 10095' Note: Refer to Production DB for historcal perf data SIZE SPF INlERVAL OpnlSqz 06.lE 3-318" 6 10095-10135 0 04/24194 3-318" 6 10253-10283 0 07/18193 3-318" 4 10253-10320 e 12/17192 I PBTD H 10668' I 1 5-112' LNR, 17#, 13CR, .0232 bpf, ID = 4.892" H 10750' I Q6. TE 07r¿4192 03/14/U1 03/15/U1 09r¿4/U 1 COWMENTS ORlGINA.L COMPl..ETDN SIS-SL T CONVERlEDTO CANVAS S5-M) FINA L RNITP CORRECTIONS REV BY DATE F£V BY R-31 tit L :8 I ~ I ~ ~ ) I SAFETY f\()lES 2092' H4-1/2"OT5 HXOSSSV NIP, ID =3.813" I GAS LlFf MAf\DRa.S ~ ST MD lVD œv TYPE VLV LATCH FORT DATE 5 3073 3020 3 MERLA BK-5 4 5683 5274 40 MERLA BK-5 3 7875 6968 40 MERLA BK-5 2 9498 8205 41 MERLA BK-5 1 9744 8390 41 MERLA BK-5 . 9773' 1-14-1/2" PKR SWS NIP, ID = 3.813" I ~ 9832' H7-5I8"X 4-lIZ' BKR SABL-3 PKR, D =3.875" I J 9894' H4-1/2"PKRSWSNIP,ID=3.813" I 9910' H4-1/2" PKRSWN NIP,ID= 3.725" I ~ 9920' H7-5I8"x 5-lIZ' LI'RTOPPKR I 9923' H4-1/2"WLEG, ID =3.958" I 9912' H ELMD TT LOGGED 08/16/92 I .. :I ì COMM:NTS PRlDl-OE BAY lJ'oJIT WELL: R-31 PERMT I\b: 92-0680 AR No: 50-029-22277-00 SEe 32, T12N, R13E BP Exploration (Alaska) 1 TREE =' 4-1/16" 5M CIW WELLHEAD = 11" 5M FMC ÃCTUA TOR;;'" ... '" BAKER 'KRÊIêT';;---^'''-'----'Sf.2'' SF. RBi'; , ""'19:2; I<Õp,;;--,w~-^'-""'^WW,^,w''^''3386; 'Max' Angie';' '4Ef@'1 0520' '5âtum-M5W;;'"^W__M'_'~^^1õ2å1" 'DatûîTîT\ÏÖ ~U, "'sãoõí'sS ) r 10-3/4" CSG, 45.5#, NT-80, ID = 9.953" 1-1 3314' ~ Minimum ID = 3.725" @ 9910' 4-1/2" PARKER SWN NIPPLE (milled out to 3.8") I TOP OF 5-1/2" LNR 1-1 9920' 14-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" 1-1 9923' 17-5/8" CSG, 29.7#, NSCC, ID = 6.875" 1-1 10068' I 15-1/2" Mechanical Whipstock 1-1 10100' I Approx. 20 bbls cement to be /' - downsqueezed past the whipstock ÆRFORA TION SUMMARY REF LOG: BHCS ON 08/16/92 ANGLE A T TOP ÆRF: 40 @ 10095' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10095-10135 0 04/24/94 3-3/8" 6 10253-10283 0 07/18/93 3-3/8" 4 10253-10320 G 12/17/92 I PBTD 1-1 10668' I 15-1/2" LNR, 17#, 13CR, .0232 bpf, ID = 4.892" 1-1 10750' ~ DA TE REV BY COMfv18\ITS 07/24/92 ORIGINAL CO~ErION 03/14/01 SIS-SL T CONVERTED TO CANVAS 03/15/01 SIS-MD FINAL 09/24/01 RN/TP CORRECTIONS R -31 A SAFEfV')TES Proposed CTD Sidetrack' 8 2092' 1-14-1/2" OTIS HXO SSSV NIP, ID = 3.813" 1 L I i :8: ;;6 [C7~ ~ ~ .J GAS LIFT MANDRELS ~ ST MD 1VD DEV 1YÆ VLV LATCH PORT DATE 5 3073 3020 3 MERLA BK-5 4 5683 5274 40 MERLA BK-5 3 7875 6968 40 MERLA BK-5 2 9498 8205 41 MERLA BK-5 1 9744 8390 41 MERLA BK-5 l 9773' 1-14-1/2" PKR SWS NIP, ID = 3.813" 1 9832' 1--17-5/8" x 4-1/2" BKR SABL-3 PKR, ID = 3.875' 9875' - Top of 3-3/16" Liner I 9875' - Top of cement I r 9894' 1-14-1/2" PKR SWS NIP, ID = 3.813" 1 9910' 1-14-1/2" PKR SWN NIP, ID = 3.80" I 9920' 1-17-5/8" x 5-1/2" LNR TOP PKR I 9923' - 4-1/2" WLEG, ID = 3.958" I 9912' - ELMD TT LOGGED 08/16/92 I 10200' 1--1 3-3/16" x 2-7/8" X-over 1'/ ~.~I Ú.. ,,; 0 ~~Ol~ 0) ~ ~ , 3-3/16" x 2-7/8" Solid/pre-drilled 11900' I ~ /- 51/2" ì 10240' Inflatable r" Bridge Plug NOTE: The sidetrack liner cement shown in this schematic will be used only if lost /' circulation is encountered. Otherwise, the completion will be uncemented solid and pre-drilled liner. ~ DA TE REV BY COMMeITS PRUDHOE BAY UNIT WELL: R-31 ÆRMIT No: 92-0680 API No: 50-029-22277-00 SEe 32, T12N, R13E BP Exploration (Alaska) Azimuths to True North Plan: Plan #13 (R-31/Plan#13 R-31A) Magnetic North: 26.11° Created By: Brij Potnis Date: 6/26/2002 Magnetic Field Contact Information: Strength: 57523nT Dip Angle: 80.82° Date: 6/2512002 Model: BGGM2002 T ^M é LEGEND R-31 (R-31) - PIan#13 R-31A - Plan #13 BP Amoco bp P8røt w.ø",tlu Tie OIl MDI W8LLPAT/f D8TAlL' ,....u It-SfA 100212227701 1t-31 10083.78 IN'r6Q Direct: (907) 267-6613 E-mail: brij.potnis@inteq.com Baker Hughes INTEQ: (907) 267-6600 IU. N""" 1 ltef.lIIIg.... .1.3171111"200100 .1"m v.-~ ~~ c:= ::::~ 27'.00' 0.00 0.00 0.00 REFERENCE INFORMATION Co-ordinate (NlEI Reference: Well Centre: R-31, True North V~f¡¿~~) ~:¡:;:g:: ~~t~~; "òeg8N~~~)el Measured Depth Reference: 51 : 31 7/~/1992 00:00 51,92 Calculation Method: Minimum Curvature 8ec MD Inc t ,DOII.78 H.'I »7..a 2 .0100.00 D.'" Uf.'. I 10110.00 .,.11 IH.70 . '012&88 UD.OO 181... . 10.1.88110.31 27"" . '0888.17 81.00 11"'" , t0H8.OD M." au.a, . 'It""oo 81.1' "'.31 . UM8.00 .t." "'.11 fO tt1la-GO 81." :III." 1111811.00 81.41 "".'J 12 12""00 81.M "'.'17 81C11ON DITA'" TYD +tfoS .....w 8880... SIOI.H .Z128.11 ...s.,t U'I." .atSl.OI "'8.'1 an4.7. 8728... MD." .7N.Ø 1MI.1. HR." MU.18 ....... Hn.8. ....... M08." ..0.., MM." ..NH.4Z I8so.8O M71..3 .3188.47 1MI.48 N31.11 -31&1.12 IN1.28 Q88A2 -3.10.24 DL811 TF8e8 D.OO 0.00 1..7 1.11 .::: ~~::gg 1a.oø 17400 12.00 aoo.oo 1..00 110.00 ~=:= 21-::: 12.oø 80.00 ~~: 17'::: ¥See T...eet 2483.84 2....5. 2......2 m!:i! ==::: _AI :=::: üCl3.37 ANNOTATION' TW ND .........- ........ 10003.71 TI' "13.11 10100.00 KOP 117'.32 11120.00 1 '71'''' 10322." 2 .7....71030." , "72"3 11"3.37 . ....... 11_.00 I ...1..1 11....00 . "03"7 111113.00 7 """0 11703.00 . ....... 11'03.00 . "'1.2112128.00 TD +E1-W Shape =~~~~~13,1 &:gg =:~ ~n = :j~:~:~ ~:~ =.~ :::, ~ R-314 13 8646.00 3440.17 -3532.35 Point R-31A T2 8650,0[) 3329.10 -2&84,20 Point R-314 T1 8680.00 34201.59 .2632.43 Point 8100 8150 8200 8250 we- ;S 8300 ë 8350 !? .c 8400 I. . 8450 a 'ii 8500 U ! 8550 . > 8600 . i! 8650 I- 8700 8750 8800 8850 6/26/2002 1 : 56 PM ~ '-.,/ ) ') BP Baker Hughes INTEQ Planning Report '(;ompany.: ' F~ld: -- .Site: -WèD: W~I.patb. Field: --BP'ArnOØo Pn,¡dh<),eBclV ' PB,RPaØ, : R--31', - . Plari#13;:R~31k Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level PB R Pad TR,.12,.13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: R-31 R-31 Well Position: Well: 5975706.22 ft 637446.42 ft IN1'EQ j1~':~~':~~ðf?Q()?: '1'..öèf:1à;58:4~ ' .' . . })age: '.C~~~)2~~f~~ce:Wë1Þ~~~1iTIV~N°r1h. .' . - -,Y~~~¥p~J~~,~;, '§y~~Jj1;)JA~~rl~~~~'l~I.,,';'.." ~~ion..rr~)~(e~~n~: ,." - .' '\l'(I\)I~(9';99~;P;OÖ~.27'6;OOAt!) .,- '~~y'çaIÇqI.ti9PM~~;.- 'MiñimymCùrvature ' . Vb: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Latitude: Longitude: North Reference: Grid Convergence: 70 20 29.100 N 148 53 4.328 W True 1.05 deg +N/-S 1467.66 ft Northing: 5977123.53 ft Latitude: +E/-W -2726.86 ft Easting: 634693.33 ft Longitude: Position Uncertainty: 0.00 ft 31 70 20 43.530 N 148 54 24.000 W Wellpath: Plan#13 R-31A 500292227701 Current Datum: 51 : 317/8/199200:00 Magnetic Data: 6/2512002 Field Strength: 57523 nT Vertical Section: Depth From (TVD) ft 0.00 Targets DeseriptlQn, Dip~ Dir. R-31A Polygon13.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 -Polygon 11 -Polygon 12 -Polygon 13 -Polygon 14 R-31A Fault1 -Polygon 1 -Polygon 2 R-31A Fault2 -Polygon 1 -Polygon 2 R-31A T4 R-31A T3 TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Height 51.92 ft +N/-S ft 0.00 +N/-S , .ft 3483.66 3483.66 3531.39 3271.02 3317.94 3393.58 3403.12 3425.78 3671.13 3816.75 3579.67 3453.05 3743.80 3723.19 3612.76 +E/';W it -2200.01 -2200.01 -2457.20 -2986.10 -3417.35 -3615.01 -3698.86 -3898.49 -4187.06 -4055.36 -3726.63 -3039.78 -2695.36 -2225.63 -2094.62 Slot Name: Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 . M;ip - , M!'p , ~orthing )ijåsting ftft 5980566.82 632431.25 5980566.82 632431.25 5980609.92 632173.27 5980340.11 631649.17 5980379.27 631217.18 5980451.34 631018.21 5980459.37 630934.21 5980478.43 630734.22 5980718.54 630441.31 5980866.49 630570.36 5980635.37 630903.28 5980521.13 631592.24 5980818.00 631931.35 5980805.83 632401.33 5980697.78 632534.30 R-31 10083.79 ft Mean Sea Level 26.11 deg 80.82 deg Direction deg 276.00 1 Oracle <"":';.;:Latitude "~ <"';:''[,o~u4e.~ Deg~in."SeC ~g.Min"-.Sec 70 21 17.788 N 70 21 17.788 N 70 21 18.257 N 70 21 15.694 N 70 21 16.154 N 70 21 16.897 N 70 21 16.990 N 70 21 17.212 N 70 21 19.623 N 70 21 21.056 N 70 21 18.726 N 70 21 17.484 N 70 21 20.345 N 70 21 20.144 N 70 21 19.058 N 148 55 28.309 W 148 5528.309 W 148 55 35.828 W 148 55 51.285 W 148 56 3.891 W 148 56 9.670 W 148 56 12.121 W 148 56 17.957 W 148 56 26.396 W 148 56 22.549 W 148 56 12.936 W 148 5552.856 W 148 55 42.792 W 148 5529.060 W 148 5525.230 W 0.00 3560.67 -2908.77 5980631.08 631721.28 70 21 18.543 N 148 55 49.028 W 0.00 3560.67 -2908.77 5980631.08 631721.28 70 21 18.543 N 148 5549.028 W 0.00 3445.18 -2610.81 5980520.97 632021.24 70 21 17.408 N 148 5540.317 W 0.00 3269.03 -3096.16 5980336.14 631539.17 70 21 15.674 N 148 55 54.502 W 0.00 3269.03 -3096.16 5980336.14 631539.17 70 21 15.674 N 148 55 54.502 W 0.00 3351.76 -3516.75 5980411.30 631117.19 70 21 16.486 N 148 56 6.798 W 8640.00 3650.64 -4078.71 5980700.00 630550.00 70 21 19.423 N 148 56 23.229 W 8645.00 3440.77 -3532.35 5980500.00 631100.00 70 21 17.361 N 148 56 7.255 W R-31A T2 R-31 A T1 8650.00 3329.10 -2884.20 5980400.00 631750.00 70 21 16.266 N 148 55 48.307 W 8680.00 3424.59 -2632.43 5980500.00 632000.00 70 21 17.206 N 148 5540.949 W BP Baker Hughes INTEQ Planning Report ') ') C IN'TEQ C9lQpany: BPArn<x:o Field: Pruc1hoeBay Site:' PBRPad' w~n: R';31. . WèDpath: Plart#13R'!~1A Annotation MU TVD ft ft 10083.79 8650.64 TIP 10100.00 8663.11 KOP 10120.00 8678.32 1 10322.58 8728.66 2 10392.58 8704.47 3 10563.37 8672.93 4 10968.00 8666.68 5 11568.00 8655.68 6 11643.00 8653.87 7 11753.00 8650.80 8 11953.00 8645.49 9 12125.00 8641.28 TD Plan: Plan #13 Identical to Lamar's Plan #13 Principal: Yes Plan Section Information MD loèl' Azhn TV» +N/..S +EI-W J)LS' BUild Turn TFO T~l'get ft d~ deg ft ft ft . deg/100ft,dêg/100ftdElgf100ft deg - 10083.79 39.52 337.63 8650.64 3503.30 -2129.11 0.00 0.00 0.00 0.00 10100.00 39.84 337.64 8663.11 3512.87 -2133.05 1.97 1.97 0.06 1.15 10120.00 41.13 335.70 8678.32 3524.79 -2138.20 9.00 6.45 -9.68 315.00 10322.58 110.00 287.69 8728.66 3633.13 -2280.91 40.00 34.00 -23.70 315.00 10392.58 110.36 278.75 8704.47 3648.15 -2344.79 12.00 0.52 -12.77 274.00 10563.37 91.00 271.87 8672.93 3663.28 -2511.03 12.00 -11.34 -4.03 200.00 10968.00 90.66 223.31 8666.68 3513.62 -2873.96 12.00 -0.08 -12.00 270.00 11568.00 91.16 295.32 8655.68 3409.55 -3425.41 12.00 0.08 12.00 89.00 11643.00 91.61 286.33 8653.87 3436.18 -3495.42 12.00 0.61 -11.99 273.00 11753.00 91.57 299.53 8650.80 3478.93 -3596.47 12.00 -0.04 12.00 90.00 11953.00 91.43 275.53 8645.49 3538.71 -3785.72 12.00 -0.07 -12.00 270.00 12125.00 91.34 296.17 8641.28 3585.42 -3950.24 12.00 -0.05 12.00 90.00 Survey MD loci Azhn SSTVD NfS EIW MapN l\fapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft d~i1O()ft deg --.--- . . 10083.79 39.52 337.63 8650.64 3503.30 -2129.11 5980587.73 632501.78 2483.64 0.00 0.00 TIP 10100.00 39.84 337.64 8663.11 3512.87 -2133.05 5980597.23 632497.67 2488.56 1.97 1.15 KOP 10120.00 41.13 335.70 8678.32 3524.79 -2138.20 5980609.05 632492.31 2494.92 9.00 315.00 1 10122.24 41.77 334.76 8680.00 3526.13 -2138.82 5980610.39 632491.67 2495.68 40.00 315.00 R-31A T' 10125.00 42.56 333.61 8682.05 3527.80 -2139.62 5980612.04 632490.83 2496.66 40.00 315.71 MWD 10150.00 50.20 324.67 8699.30 3543.25 -2148.96 5980627.32 632481.22 2507.56 40.00 316.56 MWD 10175.00 58.39 317.58 8713.89 3558.99 -2161.73 5980642.82 632468.17 2521.90 40.00 322.75 MWD 10200.00 66.90 311.67 8725.37 3574.53 -2177.54 5980658.07 632452.09 2539.25 40.00 326.90 MWD 10225.00 75.61 306.46 8733.41 3589.41 -2195.91 5980672.62 632433.45 2559.07 40.00 329.63 MWD 10250.00 84.42 301.66 8737.74 3603.17 -2216.29 5980686.01 632412.83 2580.78 40.00 331.30 MWD 10275.00 93.27 297.00 8738.24 3615.39 -2238.05 5980697.84 632390.85 2603.70 40.00 332.14 MWD 10300.00 102.10 292.25 8734.90 3625.71 -2260.54 5980707.75 632368.18 2627.15 40.00 332.23 MWD 10322.58 110.00 287.69 8728.66 3633.13 -2280.91 5980714.81 632347.69 2648.18 40.00 331.60 2 10325.00 110.02 287.38 8727.83 3633.82 -2283.08 5980715.45 632345.51 2650.41 12.00 274.00 MWD 10350.00 110.20 284.20 8719.24 3640.21 -2305.66 5980721.43 632322.81 2673.54 12,00 273.89 MWD 10375.00 110.31 281.00 8710.58 3645.32 -2328.55 5980726.13 632299.84 2696.83 12.00 272.80 MWD 10392.58 110.36 278.75 8704.47 3648.15 -2344.79 5980728.67 632283.55 2713.28 12.00 271.69 3 10400.00 109.52 278.43 8701.94 3649.19 -2351.68 5980729.59 632276.64 2720.24 12.00 200.00 MWD 10425.00 106.70 277.36 8694.17 3652.45 -2375.22 5980732.42 632253.05 2743.99 12.00 199.89 MWD 10450.00 103.87 276.33 8687.58 3655.32 -2399.16 5980734.86 632229.07 2768.10 12.00 199.56 MWD 10475.00 101.04 275.32 8682.19 3657.80 -2423.44 5980736.90 632204.75 2792.51 12.00 199.29 MWD 10500.00 98.20 274.33 8678.01 3659.87 -2448.00 5980738.53 632180.16 2817.15 12.00 199.07 MWD .' - . Date:6I26120Ø:a, . .. Tiínè:';13;S8:45, . . . ç~r~ma~(NF;l~e(~"~~ce:.., WetJ:I3+31.T:ru&N°rth .~., . X~~~(1'~l~eferél1~: ' SY~IJ1;M~~S~aL~v~1 SeÇttòn (VS}~Rê{ërence: W~U.(O.()ON;'Q;00E.276;OO~i) ,~urV~(:åk"l8:tiøífMetbðfJ: MinimurnCÜNat~re' . Db:. Oracle Date Composed: Version: Tied-to: 6/25/2002 1 From: Definitive Path ) BP ') ... .... Baker Hughes INTEQ Planning Report ----,----'- INTEQ F BPAmòco l)ate:.612612002 . . Tùne: >13:58;45. Page; 3 I Company: Field; Prudhoe:Bay , ÇQ;.ôkcliPåti~):Iief'ere~Çe: . . Welí:R~~t True North Site: PBRPad . Vë",tal(TVJ»Jteferé!I~: - $ystCitrTJ:~eanSeaLeveJ WëB: R-31 SèçtiöÍl(VS)RerereQee~' . Wélr (0.ÖOf\J,O;OOE,276.00Aii) :- Well!~: Plan#13R.3c1A StlrVey'Ç~lc\lbltjèB;MetJ¡.,d: . MinimurnCurVäture Db: -OraCle Survey i MD Incl. Aiim SSTVD N/S.' ,EIW' MapN M:âPg'. VS DLS .'I:F'O, Tool ft - deg deg ft ft :ft ft. ft ft d~l~pQft deg 10525.00 95.36 273.35 8675.06 3661.53 -2472.77 5980739.75 632155.36 2841.95 12.00 198.90 MWD 10550.00 92.52 272.39 8673.34 3662.78 -2497.67 5980740.55 632130.44 2866.86 12.00 198.79 MWD 10563.37 91.00 271.87 8672.93 3663.28 -2511.03 5980740.81 632117.08 2880.19 12.00 198.72 4 10575.00 91.00 270.48 8672.73 3663.51 -2522.65 5980740.84 632105.45 2891.77 12.00 270.00 MWD 10600.00 91.00 267.48 8672.29 3663.07 -2547.64 5980739.94 632080.48 2916.58 12.00 269.98 MWD 10625.00 90.99 264.48 8671.86 3661.31 -2572.57 5980737.74 632055.59 2941.19 12.00 269.92 MWD 10650.00 90.98 261.47 8671.43 3658.26 -2597.38 5980734.24 632030.84 2965.54 12.00 269.87 MWD 10675.00 90.97 258.47 8671.00 3653.91 -2621.99 5980729.44 632006.31 2989.57 12.00 269.82 MWD 10700.00 90.96 255.47 8670.58 3648.27 -2646.34 5980723.37 631982.07 3013.19 12.00 269.77 MWD 10725.00 90.94 252.47 8670.16 3641.37 -2670.36 5980716.04 631958.18 3036.36 12.00 269.72 MWD 10750.00 90.92 249.47 8669.76 3633.22 -2693.99 5980707.47 631934.70 3059.01 12.00 269.67 MWD 10775.00 90.90 246.47 8669.36 3623.85 -2717.16 5980697.69 631911.71 3081.07 12.00 269.62 MWD 10800.00 90.88 243.47 8668.97 3613.28 -2739.81 5980686.71 631889.25 3102.49 12.00 269.57 MWD 10825.00 90.85 240.47 8668.59 3601.53 -2761.87 5980674.57 631867.41 3123.21 12.00 269.52 MWD 10850.00 90.83 237.47 8668.22 3588.65 -2783.29 5980661.30 631846.23 3143.16 12.00 269.48 MWD 10875.00 90.79 234.47 8667.87 3574.66 -2804.01 5980646.95 631825.77 3162.30 12.00 269.44 MWD 10900.00 90.76 231.4 7 8667.53 3559.61 -2823.96 5980631.54 631806.09 3180.57 12.00 269.3.9 MWD 10925.00 90.73 228.47 8667.20 3543.53 -2843.10 5980615.13 631787.24 3197.92 12.00 269.35 MWD 10950.00 90.69 225.47 8666.90 3526.48 -2861.37 5980597.75 631769.28 3214.31 12.00 269.31 MWD 10968.00 90.66 223.31 8666.68 3513.62 -2873.96 5980584.66 631756.92 3225.49 12.00 269.28 5 10975.00 90.68 224.15 8666.60 3508.56 -2878.80 5980579.52 631752.18 3229.77 12.00 89.00 MWD 11000.00 90.73 227.15 8666.30 3491.09 -2896.67 5980561.73 631734.62 3245.72 12.00 89.01 MWD 11025.00 90.78 230.15 8665.97 3474.57 -2915.44 5980544.88 631716.16 3262.66 12.00 89.05 MWD 11050.00 90.82 233.15 8665.62 3459.07 -2935.04 5980529.03 631696.84 3280.53 12.00 89.09 MWD 11075.00 90.87 236.15 8665.25 3444.61 -2955.43 5980514.20 631676.72 3299.30 12.00 89.13 MWD 11100.00 90.91 239.15 8664.86 3431.23 -2976.54 5980500.45 631655.85 3318.90 12.00 89.17 MWD 11125.00 90.95 242.15 8664.46 3418.98 -2998.33 5980487.82 631634.29 3339.28 12.00 89.22 MWD 11150.00 90.99 245.15 8664.03 3407.89 -3020.73 5980476.32 631612.10 3360.40 12.00 89.27 MWD 11175.00 91.02 248.15 8663.60 3397.98 -3043.67 5980466.01 631589.33 3382.18 12.00 89.32 MWD 11200.00 91.05 251.15 8663.14 3389.29 -3067.11 5980456.90 631566.06 3404.58 12.00 89.37 MWD 11225.00 91.08 254.15 8662.68 3381.84 -3090.96 5980449.02 631542.34 3427.53 12.00 89.42 MWD 11250.00 91.11 257.15 8662.20 3375.65 -3115.18 5980442.39 631518.25 3450.96 12.00 89.48 MWD 11275.00 91.13 260.15 8661.71 3370.73 -3139.68 5980437.04 631493.84 3474.82 12.00 89.54 MWD 11300.00 91.15 263.15 8661.22 3367.10 -3164.41 5980432.97 631469.18 3499.03 12.00 89.60 MWD 11325.00 91.17 266.15 8660.71 3364.78 -3189.29 5980430.19 631444.35 3523.53 12.00 89.66 MWD 11350.00 91.18 269.16 8660.20 3363.75 -3214.26 5980428.72 631419.40 3548.26 12.00 89.72 MWD 11375.00 91.19 272.16 8659.68 3364.04 -3239.25 5980428.56 631394.41 3573.14 12.00 89.78 MWD 11400.00 91.20 275.16 8659.16 3365.63 -3264.19 5980429.70 631369.45 3598.11 12.00 89.84 MWD 11425.00 91.20 278.16 8658.64 3368.53 -3289.01 5980432.15 631344.58 3623.10 12.00 89.90 MWD 11450.00 91.20 281.16 8658.12 3372.72 -3313.65 5980435.90 631319.87 3648.05 12.00 89.97 MWD 11475.00 91.20 284.16 8657.59 3378.20 -3338.04 5980440.94 631295.39 3672.87 12.00 90.03 MWD 11500.00 91.19 287.16 8657.07 3384.95 -3362.10 5980447.25 631271.21 3697.51 12.00 90.09 MWD 11525.00 91.18 290.16 8656.56 3392.94 -3385.78 5980454.82 631247.40 3721.89 12.00 90.15 MWD 11550.00 91.17 293.16 8656.05 3402.17 -3409.01 5980463.62 631224.01 3745.95 12.00 90.22 MWD 11568.00 91.16 295.32 8655.68 3409.55 -3425.41 5980470.72 631207.47 3763.05 12.00 90.28 6 11575.00 91.20 294.48 8655.54 3412.50 -3431.76 5980473.55 631201.07 3769.67 12.00 273.00 MWD 11600.00 91.35 291.49 8654.98 3422.26 -3454.77 5980482.89 631177.90 3793.57 12.00 272.98 MWD 11625.00 91.50 288.49 8654.36 3430.80 -3478.25 5980491.01 631154.27 3817.82 12.00 272.92 MWD 11643.00 91.61 286.33 8653.87 3436.18 -3495.42 5980496.08 631137.00 3835.45 12.00 272.84 7 11650.00 91.61 287.17 8653.67 3438.20 -3502.12 5980497.98 631130.27 3842.33 12.00 90.00 MWD 11675.00 91.61 290.17 8652.97 3446.20 -3525.79 5980505.55 631106.46 3866.71 12.00 90.02 MWD 11700.00 91.60 293.17 8652.27 3455.43 -3549.02 5980514.36 631083.08 3890.76 12.00 90.11 MWD 11725.00 91.59 296.17 8651.57 3465.86 -3571.72 5980524.38 631060.19 3914.44 12.00 90.19 MWD ') ') BP Baker Hughes INTEQ Planning Report INXß.Q çOlnf'anY: BP' ArMco Ðate:612612.002 ' ' " " ,XbQe:t3;58:45 , Fièld: erU<ß1()éB~y ,~rd~te@Qt)Refe..~n~.:: ,.,Well:'R;;~1;TrueNorth ' Site: PBRP~d 'Y~~~fr~r~efet~.~: 'Sy~tem:'f\.(~n$~~Le"e,l, ',' ' Well: R~31 'SeCtiôn(VS)R~èreQte': ' VVëU,(Œ.OQN;O.QoE;276iOOAii) W~Up~tb: Pfan#13R;;31A ;$II~y'Ç~lçUb1tiØn1\4e~; ",MióimömCurv~tlJre ' Db: Oracle Survey 1\1D Inel åzilll ' 'SS1'VD, "NlS EIW ,f\i9l'l M'aPE:", VS DLS TFO ft '<i~ , dég ft ft ff '~ 'ft " ft <legl100ft deg 11750.00 91.57 299.17 8650.88 3477.46 -3593.85 5980535.58 631037.86 3937.66 12.00 90.28 MWD 11753.00 91.57 299.53 8650.80 3478.93 -3596.47 5980537.00 631035.22 3940.41 12.00 90.36 8 11775.00 91.57 296.89 8650.20 3489.33 -3615.84 5980547.05 631015.66 3960.77 12.00 270.00 MWD 11800.00 91.56 293.89 8649.52 3500.04 -3638.42 5980557.36 630992.90 3984.34 12.00 269.93 MWD 11825.00 91.55 290.89 8648.84 3509.56 -3661.52 5980566.46 630969.63 4008.31 12.00 269.85 MWD 11850.00 91.54 287.89 8648.17 3517.86 -3685.09 5980574.33 630945.91 4032.62 12.00 269.76 MWD 11875.00 91.52 284.89 8647.50 3524.91 -3709.06 5980580.95 630921.82 4057.20 12.00 269.68 MWD 11900.00 91.49 281.89 8646.84 3530.70 -3733.37 5980586.30 630897.41 4081.98 12.00 269.60 MWD 11925.00 91.47 278.89 8646.20 3535.20 -3757.95 5980590.36 630872.76 4106.89 12.00 269.52 MWD 11950.00 91.44 275.89 8645.56 3538.42 -3782.73 5980593.13 630847.93 4131.88 12.00 269.45 MWD 11953.00 91.43 275.53 8645.49 3538.71 -3785.72 5980593.37 630844.94 4134.88 12.00 269.37 9 11975.00 91.43 278.17 8644.94 3541.34 -3807.55 5980595.60 630823.06 4156.86 12.00 90.00 MWD 12000.00 91.43 281.17 8644.32 3545.53 -3832.19 5980599.35 630798.36 4181.80 12.00 90.07 MWD 12025.00 91.42 284.17 8643.70 3551.01 -3856.57 5980604.39 630773.88 4206.62 12.00 90.14 MWD 12050.00 91.40 287.17 8643.08 3557.76 -3880.63 5980610.71 630749.71 4231.26 12.00 90.22 MWD 12075.00 91.39 290.17 8642.47 3565.76 -3904.30 5980618.28 630725.89 4255.64 12.00 90.29 MWD 12100.00 91.36 293.17 8641.87 3574.99 -3927.53 5980627.09 630702.51 4279.70 12.00 90.36 MWD 12125.00 91.34 296.17 8641.28 3585.42 -3950.24 5980637.11 630679.62 4303.37 12.00 90.43 TD . , ) All Measurements are from top of Riser s- eD en æ top of bag bttm of bag middle of slips Blind/Shears middle of pipes 2 3/8" combi ram/slips ,...--. middle of flow cross Mud Cross ~ middle of blind/shears variable bore pipe 3 1/2"'.2 7/S"' middle of pipe/slips , 2 3/8" combi ram/slips Flow Tee ""'''''''''''......." --,..,-// r-- '-- ...,........... /..,-......-,..- ') 7/16/2002 BAG TOTs Mud Cross TOTs H 206979 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 7/01/02 CK062602C PERMIT TO DRILL FEE ~. 3ì R-- THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC, P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 f! .>,:.,~ "'~. ~1~ -:",. DATE 7/01/02 CHECK NO. H206979 VENDOR DISCOUNT NET No.H.2(lS919 FIRST NATIONAL BAN( OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO CONSOLIDATED COMMERCIAL ACCOUNT PAY "',' , ... ..1"", ,....',. .;,i, C.'-.1I...:'....'...7..,...'l' ....'.'.i~.'.Q~}'cttûl¡,. ... ",.J. ". ,.11. i"... ....'þ,,'..,.I..., W, ,.,. .. .\i I' '. J .t ...' "'or' t'> ,...,. . ,. <..'~.j ....~.. , .' ....", UUl~n... JULY 1, 2002 TO THE ORDER OF ALASKA STJ\TE ALASKA OIL &'GAS CQNSERVATION COMMISSION 333. W 7THTA VE STE1:00 ANCHOR)\GE, AK. 99501 118 2 0 b q ? q 118 I: 0 l. ~ 2 0 :I a q 5 I: 0 0 8 ...... ~ q 118 56-389 412 ~~) ~ , I H .~ NOT VALID AFTER 120 DAYS ~.;\::. <.:;: :;:::: :::{:.::~::::.~. :>,:~:;" ~" '.: :~.~,:~ :~,:~:::: :~:'.~::~ ~.T~~~ :"",':":~"". ., "" ,'.,', '..,.',,'::...'..i:..,'-.~:."..':.:'".,"::',.,''''.,' ::~::\'{;'i':' ., ... .,. ...,..'.. ,/ ... / .., .' i") ..:~,:... .(';.': .-..;.::;:Ú ¿~:~:ú.~:: ::;:.:~:.::¡i. ...\if~:Wäi~~~Ö:'~::;~;~;;~;')~:~;;::~~::~~"s§ ~ R.E(E~\/ED JUL 16 2002 Alaska Oil & Gaß Gm¡s, LonHHíS~¡Oi AnchoraQH ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME f8ú ~-3/A PTD# 202.../ S r1 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE "CLUE" The permit is for a new wellbore segment of existing well , Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 . 70/80) from records, data and logs acquired for well (name on permit). The permit is approved ~ubject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ~ V¡J ~ . Rev: 07/10/02 C\jody\templates PROGRAM: Exp - Dev 2{.RedrllL Re-Enter - Serv - Wellbore sag - GEOl AREA ?1 c:J UNIT# /1 t;- r r1 ON/OFF SHORE oJ4) ~~ Y N Y N Y N Y N Y N Y N Y N Y N Y N ~N Y N Y N .-¥-N- -¥-N- ¥---* JJ / Ir 1=: S/.9tf~J @N Çj) N rÃh tÁ- ' ~~ ~ -¥=-N- f\I /" N N N N N N 60 ~ pM. -¥-N Nlk y~ Y N J ~ Y /(j), rl . WELL PERMIT CHECKLIST COMPANY ~/ X WELL NAM~ð& /::- 3M 'FIELD&POOL b~~/Ç~ - INITCLASS ¡Q~ /~J'/ 'ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. UniqueweU name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper d~stance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is weJlbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . (Service Well Only) 13. Well located wlin area & strata authorized by injection order #- (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. ENGINEERING APPR DATE 'IL~~ APPR DATE tdGA- 7/ ( ~I 0 l- (Service Well Only) GEOLOGY APPR DATE ß(" $ø.z /(Ë~Tora~OnIY) Rev: 07/12/02 15. Conductor string provided. . . . . . . . . . . . . . . . . . . 16. Surface casing protects all known USDWs. . . . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. . . . . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 19. CMT will cover all known productive horizons. . . . . . . . . . 20. Casing designs adequate for C, T, B & permafrost. . . . . . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved. . . 23. Adequate we II bore separation proposed.. . . . . . . . . . . . 24. If diverter required, does it meet regulations. . . . . . . . . . 25. Drilling fluid program schematic & equip list adequate. . . . . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . 27. BOPE press rating appropriate; test to '3500 psig. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 31. Mechanical condition of wens within AOR verified. . . . . . . . 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35~ Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. . . . . . . . UIC ENGINEER JBR GEOLOGY: RP~ PETROLEUM ENGINEERING: TEM RESERV R ENGINEERING JDH -~ SFD- WGA\J,61r G:\geology\permits\checklist.doc MJW COMMISSIONER: COT DTS Ô~/l.ð'/O< ) Commentsllnstructions: