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STATE OF ALASKA ',ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations Q Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ��❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 5c 7' " R P 1s1 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 202-220 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20563-02-00 7. Property Designation(Lease Number): ADL 0028260 8. Well Name and Number: PBU M-09B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12930 feet Plugs measured 10649 feet 4,4 true vertical 9016 feet Junk measured feet nn Effective Depth: measured 10649 feet Packer measured 10238 feet .)9 U.;j 1 9. 2016 true vertical 8713 feet Packer true vertical 8313.53 feet U Casing: Length: Size: MD: TVD: Burst: Collapse: C Structural Conductor 120 20"x 30" 38-158 38-158 Surface 2655 13-3/8"72#L-80 37-2692 37-2692 4930 2670 Intermediate Production 9216 9-5/8"47#L-80 35-9250 35-7708 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 12180-12591 feet 12630-12825 feet 10328-10333 feet True vertical depth: 8953-8952 feet feet 8954-8988 feet 8402-8407 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JAN 3 1202 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 353 374 7631 1774 218 Subsequent to operation: 166 285 5316 1496 189 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ 0 SUSP ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature .41".,1 et"- Phone +1 907 564 4424 Date 8/19/16 Form 10-404 Revised 5/2015 Aj .1/: �- RBDMS ,,V AUG 2 5 2016 Submit Original Only • • m 0• O O O O O M g 0 co O 0 0 O C N Tr U) LO U co C.) 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J J J J J J I— I— • • a� U co a c a) c c O Co a) aco as a m J G Y Y d a) Y co co 65mm C m CV CV 4 V RI Q O) CO LMC) S m > M M N- Cl)5 9 CO CO CO r2 CO co— 1, l, a C Lco(O CA -4- CI) Ci . r N N o O O a � W � W W c. a0 ~ < a H a) Emmm as rn rn rn ZOO O U) • • I_ % Cl) = / " § aIO I / � 0 c & & _ k � � - % W - 4* _j2 a k / q w �� . 0 0- 130 L E <• cD a- a � c z w wi' oO 0 I �_J < 0 U) 0 >- / / R b - / s_ ce / / CL CI & ( E ■ 7 _ - 0 m > -• o CL m Ce ƒ a0 . / _1 L ■ o u ® xm & & < 4 Ce • � < CL / � g o in co . E / 0 | < 2 > O � / E woo 5(O2 �� 0. -o I L & c o , @ 2 © ; 2 < 0 < Z R li k § ƒ Ce & ate m r >. < LO LL � a / S ® II . > / , R c % q ® 2 > CI ƒ c) ,_ 2ED \ wg2@ � < \ - 0 = o@ b R > w 2 „ E22o ® Q � Rc2R O G m 0 \ ., a. r 2 2 722 / & 0R � = R & A Lu@ N R o © 7 o -L —i c > E ---D (0 2 � f = � / 2 | k cc o_ 2 R LI i / k > ƒ b 2 o L < co c 0 G 8 m / q q d � � % \ w ¥ < SOfY NOTES:WELL WELLHEAD FMC M-09B H2 READINGS AVERAGE 125 ppm WHEN ON MI ' ACTUATOR= BAKER BEV= 'CHROME TBG&LNR*** KB.BF.ELEV= 27.76' KOP= 3050' 2168' —14-112"HES SSSV LAND NP,0=3.813" Max Angie= 94°@ 12203' Datum MD= 11201' Datum TV D= 8800 SS 1 2600' --1 FOC 13-3/8"CSG,72#,L-80,D=12.347" H 2684' GAS LFT MANDRELS ST MD TVD DEV TY FE VLV LATCH FORT DATE 6 3245 3139 26 TB DOME RM 16 09/04/10 9-5/8"X 7"LTP&HGR D=7.50" —{ 7076' i 5 4779 4470 35 TB DOME RM 16 09104/10 $ 4 6016 5489 34 TB SO RM 28 09/22/13 3 7056 6358 32 KBG-2LS DMY NT 0 03/19/97 2 8506 7253 58 KBG-2LS DMY NT 0 03/19/97 1 10160 8181 27 KBG-2LS DMY NT 0 03/19/97 9-5/8"CSG,47#,L-80,D=8.681" H 9249' • • 4* MLLOUT WNDOW(M-09A) - ' 4444 40 Minimum ID = 2.38" @ 10600' s•. 3-3/16"X 2-7/8" XO , 10229' H4-1/2"HES X NP,D=3.813" 11 C 10239' H7"X 4-1/2"BKR SABL PKR,D=3.875" 10264' —14-112"HES X NP,D=3.813" ' 10284' -14-1/2"HES X MP,D=3.813" 10328' H3.70"KBLTPw/5.8"SEAL ASSY,D=2.39' 10295'j-14-1/2'WLEG,D=3.958" k Tall OM 4-1/2'TBG,12.6#,13CR 80 NSCT, — 10295 • - _ 10296' —I 7"X 4-1/2"BKR LW,HGR&TDSK,D=4.438' .0152 bpf,D=3.958" ' 10333' 1-13.70'BKR DEPLOY SLV,0=3.00" 10352' —{3-1/2"HES XN NP,0=2.75" _ 10354' —I3-1/2"X 3-3/16"XO,D=2.78" 7'LNR 29#,L-80,13CR 80 NSCC, H 1048T .0371 bpf,D=6.184" 4-1/2'LNR,12.6#,13CR-80 NSCT, H —10515 , .0152 bpf,D=3.958' 4-1/2'WHPSTOCK H 10515' MILLOUT WIDOW(M-09B)10515'-10524' TORQUE MASTER PKR --I 10530' PERFORATION SURA 1FRY 10600- —13-3/16*X 2-7/8"XO,D=2.38' REF LOG: SWS VISION-RESISTWFTY FNAL on 12/12/02 10649' H2-7/8'WED WRP(07/22/16) ANGLE AT TOP Fes: 94°@ 12180' I Note:Refer to Prod '4 ` H uction DB for historical perf data PBTD12893' SIZE SPF INTERVAL OP'YSQZ SHOT Sn7 2" 4 12180-12591 C 12/24/02 3-3/16'LNR 6.2#,L-80, —{ 10600' 2' 4 12630-12825 0/C 12/24/02 .0076 bpf,D=2.80' .. . 2-7/8"LNR,6.16#,L-80, 0058 bpf,D=2.44' I 12927' DATE REV BY COM ENTS DATE REV BY COMETS FRUDHOE BAY UNIT r 1981 INITIAL COMPLETION 07/25/16 KFS/JK) SET WFD WRP(07/22/16) WELL: M-09B 03/22/97 D-14 SIDETRACK(M-094) PERMIT No:!`2027200 12125/02 JLM/KK CTD SIDETRACK(M-0913) API No: 50-029-20563.02 11/09/13 AU 1'PJC SET SPEAR N D.SLV(10/30/13) SEC 1,T11 N,R12E,2373'SNL&606'WE. 03/24/14 PG PJC PULL REL.SPEAR(11/202/13) 05/19/16 MB/JMD ADDED PEW REF LOG BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg 5gAtitte AUG f `}G! Alaska Oil and Gas Conservation Commission 333 West 7 Avenue a;,,002- a ao Anchorage, Alaska 99501 06/43 Subject: Corrosion Inhibitor Treatments of GPB M -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad M 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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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) M -pad Date: 04/14/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal M -01 1690780 50029200420000 Sealed NA NA NA NA NA M-03A 2011470 50029201020100 0.25 NA 0.25 NA 0.85 6/3/2009 M -04 1710230 50029201050000 0 NA 0 NA NA 4/14/2012 M -05A 1970810 50029201940100 0.5 NA 0.5 NA 2.6 6/3/2009 M-06A 1930930 50029203670100 0.25 NA 0.25 NA 0.85 6/3/2009 M -07 1790370 50029203730000 0.25 NA 0.25 NA 0.85 6/3/2009 M -08 1800860 50029204990000 1.75 NA 1.75 NA 10.2 6/24/2009 -3" M -09B 2022200 50029205630200 6.25 NA 6.25 NA 44.2 6/3/2009 M -10 1810290 50029205670000 0.25 NA 0.25 NA 2.6 6/4/2009 M -11 1810570 50029205890000 0.25 NA 0.25 NA 1.7 6/4/2009 M -12A 2001510 50029205930100 0.25 NA 0.25 NA 1.7 6/4/2009 M -13A 2011650 50029205220100 2.75 NA 2.75 NA 17 6/4/2009 M -14 1801090 50029205120000 1 NA 1 NA 5.1 6/4/2009 M -15 1810850 50029206120000 6.75 NA 6.75 NA 55.3 6/4/2009 M -16 1810860 50029206130000 0.25 NA 0.25 NA 1.7 6/4/2009 M -17A 2000320 50029206280100 0.5 NA 0.5 NA 2.6 6/3/2009 M -18B 1930540 50029208550200 10 NA 10 NA 73.1 6/24/2009 M -19B 2081980 50029208970200 Sealed NA NA NA NA 4/13/2012 M -20A 1971990 50029209120100 8 NA 8 NA 52.7 6/24/2009 M -21A 1930750 50029209230100 0.5 NA 0.5 NA 3.4 6/24/2009 M -22 1830540 50029209360000 16 NA 16 NA 117.3 6/23/2009 M -23 1830550 50029209370000 0.25 NA 0.25 NA 1.7 6/4/2009 M -24A 2011260 50029209390100 0.25 NA 0.25 NA 0.85 6/24/2009 M -25 1860650 50029215700000 8 NA 8 NA 55.3 6/3/2009 M -26A 1920280 50029220040100 2.75 NA 2.75 NA 18.7 6/3/2009 M -27A 1930860 50029219920100 0.25 NA 0.25 NA 2.6 6/24/2009 M -28 1860740 50029215780000 1 NA 1 NA 4.3 6/3/2009 M -29A 2000990 50029219040100 1 NA 1 NA 4.3 6/3/2009 M -30 1920300 50029222550000 0.5 NA 0.5 NA 3.4 6/3/2009 M -31 1920320 50029222560000 0.5 NA 0.5 NA 3.4 6/4/2009 M -32 1920330 50029222570000 0.25 NA 0.25 NA 0.85 6/4/2009 M -33 1941160 50029225040000 20 NA 20 NA 133.45 6/24/2009 M -34 1941330 50029225140000 6.25 NA 6.25 NA 25.5 6/3/2009 M -38A 2011320 50029225190100 21.3 NA 21.3 NA 210.8 11/26/2009 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs_ Inserts\Microfilm _ Marker. doc ). "1 J4-- ~ r DATA SUBMITTAL C)OMPLIANCE REPORT 1/6/2005 Permit to Drill 2022200 Well Name/No. PRUDHOE BAY UNIT M-09B Operator BP EXPLORATION (ALASKA) INC 5/1t.L¿ / Á f.k-~ Ôú ^ API No. 50-029-20563-02-00 MD 12930 -~ NO 9016 -' Completion Date 12/24/2002 ~ Completion Status 1-01L -~---~-----~. ------~--~-- REQUIRED INFORMATION Mud Log No Samples No -- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: MWD, GR, RES Logl Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No ----- Rpt Directional Survey ~' 0 Í-t1626 I:iSV~rlflcatl6n Gr\ ì CC-t- ED 0 Directional Survey téD C Tf ¿;r2127 LIS Verification l/ÉD C Pds L..-f2127 Induction/Resistivity L.-..!p~r. c/'1iiduction/Resistivity ----~ 25 25 Blu Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORMATION yQ Well Cored? Daily History Received? Chips Received? 'y I N Formation Tops Analysis Received? .¥n~ - -~--~.--_._---- Comments: Current Status 1-01L UIC N Directional surve~ (data taken from Logs Portion of Master Well Data Maint) ~.. Interval OH/ Start Stop CH Received Comments 10500 12930 Open 1/15/2003 10057 12812 Case 1/21/2003 10500 12930 Open 1/15/2003 10500 12296 Open 7/23/2003 LDWG Openhole Edit of Drilling & Measurement Resistivity & Gamma Ray 10500 12914 Open 7/23/2003 Vision Resistivity 10500 12914 Open 7/23/2003 Vision Resistivity Sample Set Number Comments ",-,. t})t N (Y)N DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2022200 Well Name/No. PRUDHOE BAY UNIT M-09B Opérator ... BPEXPLORATION (ALASKA) INC API No. 50-029-20563-02-00 MD 12930 TVD 9016 Completion Date 12/24/2002 ~ Completion Status 1-01L Current Status 1-01L UIC N Compliance Reviewed By: Date: ~7 J~.}ßJJ ---------------- -~-------,- ~' ~ Sablullbepgel' Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth ~. Well Job# Log Description Date M-09B M-09B M-09B 23027 OH EDIT RESISTIVITY & GR 23027 MD RESISTIVITY 23027 TVD RESISTIVITY 12/20/02 12/20/02 12/20/02 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 CEIV'.D Date Delivered: JUL 2. 3 2003 Ajaska O~¡ & Ga~ Conß. Commi~n Anchorage ~~'(\I\~~ Blueline xxxx d ad- - :!)B-êJ 07/03/03 NO. 2900 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Prints C\~)~ l' 1 1 1 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Received~Q'\~ ~ JY\..~ \..\J <f't~/Y\. .) ) ~ 0 éY- ;¿;)o MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No M-09B Date Dispatched: 2-Jan-03 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 ~ ~ úßJtQ dJJnn~ ~ ~.~~ ?:It 1/D3 ~L?~ ~ ~~~ I ~v~ Received~ L. OO~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 RECEIVEU JAN 1 5 2003 Ala. OH & Gas Cons. Commi8eion Andlorage ) c5?Od-¡;)é)O MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No M-09B Date Dispatched: 2-Jan-03 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 ~ (~Æ ~ed.- ~~ ~ ~ ~ 1J1/Dß 5-f) '. Ll ). '~If..,..'edJ UJ~ J 1J¡2CQ ~0-dÞ~;;Ø Received By: ~ uJJOop~ Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1 Dec '97 RECEIVED JAN 1 5 2003 Alaska or. & Gu Cons. Commillion Anct10rage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well all Oil 0 Gas 0 Suspended 0 Abandoned:",,,;:g:~"~~~~h~~ 2. Name of Operator 1 "A''':.~~:.~::.: hk~ ~í~~- 7. Permit Number BP Exploration (Alaska) Inc. :.f. .lz..:...!".'...£.'~:-.'!Lqi-. '+.. '" 202-220 3. Address ~ ,n-~';J'''IFD ""1 Vi. 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ;---~~-._.i ~~"H.~...., 50-029-20563-02 ~or¡>¡<,;w~.,,,,,,,,,,_....~,~...~~~.~,ð .,,~,~ """,,->;'J~"'~"'-':¡"'" ~,,~. 4. Location of well at surface 9. Unit or Lease Name 2373' SNL, 606' WEL, SEC. 01 ,T11 N, R12E, UM X = 628218, Y = 5973983 Prudhoe Bay Unit At top of productive interval 4521' SNL, 4329' WEL, SEC. 01, T11 N, R12E, UM X = 624532, Y = 5971772 10. Well Number At total depth 722' SNL, 407' WEL, SEC. 11, T11 N, R12E, UM X = 623200, Y = 5970270 11. Field and Pool . 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 61.76' ADL 028260 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 12/12/2002 . 12/20/2002 ' 12/24/2002 ' 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12930 9016 FT 12894 9006 FT all Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES Classification of Service Well M-09B 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 20" X 30" Insulated Conductor Surface 80' 36" 13-3/8" 72# L-80 Surface 2684' 17-1/2" 9-5/8" 47# L-80 Surface 7249' 12-1/4" 7" 26# 129# L-80 / 13Cr 7076' 10487' 8-1/2" 4-1/2" 12.6# 13Cr 10289' 10515' 6" * 8.81#/6.2#/6.16# L-80 10328' 12927' 3-3/4" 24. Perforations open to Production (MD+ TVD of Top and 25. Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 12180' - 12591' 8953' - 8954' 12630' - 12825' 8955' - 8989' 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2168' MD 1900' (Approx.) y/ ~,,~ c) /i:>¡Ç($ 'JIÞII> ~ S 2..7 ' 7"""D CEMENTING RECORD 8 cu yds concrete 3720 cu ft Permafrost II 1403 cu ft Class 'G', 130 cu ft PF 635 cu ft Class 'G' 125 cu ft Class 'G' 197 cu ft Class 'G' AMOUNT PULLED * 3.1/2" x 3.3/16" x 2.7/8" SIZE 4-1/2", 12.6#, 13Cr TUSING RECORD DEPTH SET (MD) 10295' PACKER SET (MD) 10239' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 30 Bbls MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 11, 2003 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BsL 1/29/2003 4 TEST PERIOD 498 Flow Tubing Casing Pressure CALCULATED OIL-BSL Press. 227 24-HoUR RATE GAs-McF 520 GAs-McF WATER-BsL 3,282 WATER-BsL CHOKE SIZE 96° GAS-OIL RATIO 1,045 OIL GRAVITY-API (CORR) 26.3 28. . CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips~ No core samples were taken. -~ G }- Form 10-407 Rev. 07-01-80 RBOMS BFl FEB ¡ 20m 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. Sadlerochit 10588' 8660' 42SB 10708' 8755' Zone 3 10915' 8822' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the fO~Oing. is true and correct to the best of my knowledge Signed Terrie Hubble '1~ ~ HiJ ~ Title Technical Assistant Date 0 ~. 07.03 M-09B 202-220 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Mary Endacott, 564-4388 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 (OF, 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 ') ) BP..EXPliORATION Operations Surnrnary Rèport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date M-09 M-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 12/9/2002 From.:, To HóÙrs Task Code I NPT Phase 10:30 - 16:00 5.50 MOB P PRE 16:00 - 23:00 7.00 MOB P PRE 23:00 - 00:00 1.00 MOB P PRE 00:00 - 00:30 0.50 MOB P PRE 00:30 - 03:30 3.00 BOPSUB P DECOMP 03:30 - 04:00 0.50 BOPSUB P DECOMP 04:00 - 10:00 6.00 BOPSUB P DECOMP 12/10/2002 10:00 - 12:00 2.00 BOPSUB N RREP DECOMP 12:00 - 15:00 3.00 BOPSUB P DECOMP 15:00 - 16:00 1.00 BOPSUB P DECOMP 16:00 - 16:20 0.33 STWHIP P WEXIT 16:20 - 17:00 0.67 STWHIP P WEXIT 17:00 - 19:00 2.00 STWHIP P WEXIT 19:00 - 21 :15 2.25 STWHIP P WEXIT 21 :15 - 23:30 2.25 STWHIP P WEXIT 23:30 - 00:00 0.50 STWHIP P WEXIT 12/11/2002 00:00 - 00:30 0.50 STWHIP P WEXIT 00:30 - 02:20 1.83 STWHIP P WEXIT 02:20 - 02:30 0.17 STWHIP P WEXIT 02:30 - 02:45 0.25 STWHIP P WEXIT 02:45 - 04:30 1.75 STWHIP P WEXIT 04:30 - 05:15 0.75 STWHIP P WEXIT 05:15 - 07:15 2.00 STWHIP P WEXIT 07:15 - 09:30 2.25 STWHIP P WEXIT 09:30 - 11 :30 2.00 STWHIP P WEXIT 11 :30 - 12:30 1.00 STWHIP P WEXIT 12:30 - 14:30 2.00 STWHIP P WEXIT 14:30 - 15:30 1.00 STWHIP P WEXIT 15:30 - 23:30 8.00 STWHIP P WEXIT 23:30 - 23:40 0.17 STWHIP P WEXIT 23:40 - 00:00 0.33 STWHIP P WEXIT 12/12/2002 00:00 - 01 :45 1.75 STWHIP P WEXIT 01 :45 - 03:25 1.67 STWHIP P WEXIT Start: 12/9/2002 Rig Release: 12/24/2002 Rig Number: 2 Spud Date: 5/9/1981 End: 12/24/2002 Déscri ptiÔribfOperations Continue to prep for move to M pad. Move rig from W pad to M pad. Spot rig rig over wellhead. (wellhead is leaning away from and to the right of the rig) Spot rig rig over wellhead. (wellhead is leaning away from and to the right of the rig) Continue to spot rig over well. Accept rig at 00:30 hrs 12-10-2002. Remove tree cap. Start nipple-up of BOPE. PJSM review test procedures. Pressure test BOPE 250 psi low, 3500 psi high. Annular too cold to test. Seal off poor fitting doors around flow line with plywood & herculite. Allow cellar to warm up. (need to figure out a better geometry for cellar doors) Seal off poor fitting doors around flow line with plywood & herculite. Allow cellar to warm up. (need to figure out a better geometry for cellar doors) Continue to test BOP equipment. Never heard back from AOGCC. Plan to email results to AOGCC. RU and pull bpv from tbg hanger. NO pressure on well. On a slight vacuum. PJSM . PU dummy whipstock assembly. Bring Dummy Whipstock into pipe shed. PU Baker tools. Call out Baker for 3" GS spear. MU MHA. RIH with dummy No Problems. Tag anchor. Flag coil at 10541'. POH. Set back injector. LD Dummy whipstock. PU Whipstock. RIH with whipstock. Latch Whipstock and shear off. Whipstock face oriented to 140 left. Displace coil to Bio H2O POH PU pilot mill RIH Tag ws at 10519'. Correct to e-line depth for pinch point of 10515'. Flag pipe (EOP). 2000 psi fs @ 2.4 bpm. Mill to 10516'. Some stalling. 1: 1 rtns POOH with pilot mill assy. Get off well. Remove pilot mill. MU Torque Master window mill and string reamer. Stab on well. RIH with window mill. Tag up on WS. Add 5' correction to bring depth to 10516'. Difficult to get started milling. Lots of stalls. 2000 psi fs @ 2.5 bpm. Mill ahead from 10516'. 2.5 bpm, 2000 psi fs/ 150 psi mtr work. WOB 2400#, Window 10,515 to 10,524'. Drill formation to 10,530'. Flow Pro circulated to bit. Trip throught window. Dry tag 10530'. OK POH POH with window mill. LD BHA cut 104' coil (chrome pipe, need to cut 100' every 3 runs). Mill 3.77". String mill 3.80". Printed: 2/7/2003 1:5116 PM ) ) ~. BPE.xPILORATION. Operatioos$ ummaryRe port Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-09 M-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 12/9/2002 Rig Release: 12/24/2002 Rig Number: 2 Spud Date: 5/9/1981 End: 12/24/2002 Date From>" Tö Hours Task Cöde NPT Phase pésCtiþtiOh Of Opèré:ltions 12/12/2002 03:25 - 04:00 0.58 DRILL P PROD1 Pull and pressure test coil connector. 04:00 - 05:30 1.50 DRILL P PROD1 MU BHA for KO. 2.57 deg mtr w/ M-09 bit. Three jts PH6 between mwd & motor assembly. 05:30 - 07:45 2.25 DRILL P PROD1 RIH. Shallow test mwd at +/- 3500'. Tools working ok. Continue in hole. 07:45 - 10:30 2.75 DRILL P PROD1 Log initial gr tie in from 10340'. Logged 50+' of hole. Never could find gr spike shown oncnl/gr tie in log. Add 10' correction bas~d on some "small" gr peaks. RIH. Tag TD at 10530', same depth as on mill run, so tie in is good. 10:30 - 12:30 2.00 DRILL P PROD1 Get tool faces in 10 deg hole section at 10300'. Orient to 30L. RIH to TO. CHeck tool face, get 30R. Repeat this process again to double check. 30L at 10300' becomes 30R at 10525'. 12:30 - 15:30 3.00 DRILL P PROD1 Drill ahead holding 30R TF. 2900 psi fs at 2.7 bpm. 200-500 dpsi. 1: 1 rtns. 39k# up, 15k# dn wt. 3-5k# WOB. 30-60 fph ROP. Drill to 10580'. 15:30 -17:15 1.75 DRILL P PROD1 POOH for gyro survey tool. Flag pipe 9500 EOP 17:15 -19:00 1.75 DRILL P PROD1 Get off well. LD drilling assembly. 19:00 - 20:00 1.00 DRILL P PROD1 MU BHA GYRO. Change out reel bushings. 20:00 - 20:45 0.75 DRILL P PROD1 RIH to 3000'. 20:45 - 20:55 0.17 DRILL P PROD1 Shallow hole test. 20:55 - 21 :50 0.92 DRILL P PROD1 RIH TO 9576' Correct to flag -13.9' 21 :50 - 23:20 1.50 DRILL P PROD1 RIH to 10,550'. Tie-in No correction 23:20 - 23:45 0.42 DRILL P PROD1 Gyro survey 8 surveys taken.1 0500, 10515,10525,10535,10545,10555,10565, and 10575'. 23:45 - 00:00 0.25 DRILL P PROD1 POH. 12/13/2002 00:00 - 01 :30 1.50 DRILL P PROD1 POH with memory Gyro. 01 :30 - 02:45 1.25 DRILL P PROD1 LD Gyro tool. bolttom survey @ 10,573' 16 degrees at 205 AZ. will run 2.57 degree motor again. 02:45 - 03: 15 0.50 DRILL P PROD1 MU drilling BHA (2.56 mtr with M-09 bit) 03:15 - 04:00 0.75 DRILL P PROD1 RIH to 3000 . Shallow hole test. O.K. 04:00 - 05:30 1.50 DRILL P PROD1 RIH to 10500'. Correct to flag -20ft. Tag TO correct -3'. 05:30 - 09:30 4.00 DRILL P PROD1 Directionally drill at 30R TF. 3150 psi fs @ 2.8 bpm. 100-200 dpsi on mtr. 1: 1 rtns. 2-3K# wob. Shublik drilling at 20-30 fph rop. Drill to 10675'. 09:30 - 10:00 0.50 DRILL P PROD1 Drilling break at 10675'. Partial lost returns. 2.7 in/1.0 out. Slowly recovered to 2.3 in/1.8 out. Order 300 bbls new mud (no used available). 10:00 -10:15 0.25 DRILL P PROD1 Short trip to window due to stacking problems. 10:15 - 10:30 0.25 DRILL N STUC PROD1 Differentially stuck at 10700'. Stop pumps and rest hole. Pull free at 55k# up. 10:30 - 11 :30 1.00 DRILL P PROD1 Drill to 10736'. Too low on fluid to continue. 11 :30 - 14:30 3.00 DRILL N DPRB PROD1 Pull into csg and circulate at minimum rate. 14:30 - 15:45 1.25 DRILL P PROD1 Mud on location. Begin loading pits. Drill ahead from 10736'. Mix 5 ppb Mix 2 fine (mostly fine cellulose fiber) for circulation down hole. Drill to 10746'. Loss rate improving to 2.6 in/2.2 out. 15:45 - 16:30 0.75 DRILL N FLUD PROD1 LCM causing mud to run over shakers. Pull to 10465' to change screens from 210 to 170. Did not help much. Have to by pass shakers with 25% of mud flow. 16:30 - 17:00 0.50 DRILL P PROD1 Drilling ahead. 3200 psi fs @ 2.5 bpm. 200-400 dpsi. 2.5 in/2.1 out. 100-150 fph when drilling. Tf:20L. Trouble with stacking weight (may be because mud contains no lubtex). Printed: 21712003 1:5116 PM ') / ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 12/13/2002 12/14/2002 M-09 M-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Page 3 of 11 Start: 12/9/2002 Rig Release: 12/24/2002 Rig Number: 2 Spud Date: 5/9/1981 End: 12/24/2002 From- Tò Hours Task COde NPT 16:30 - 17:00 0.50 DRILL P PROD1 17:00 - 18:00 1.00 DRILL P PROD1 18:00 - 18:40 0.67 DRILL N STUC PROD1 18:40 - 18:50 0.17 DRILL P PROD1 18:50 - 19:30 0.67 DRILL P PROD1 19:30 - 20:00 0.50 DRILL P PROD1 20:00 - 20:05 0.08 DRILL P PROD1 20:05 - 20:30 0.42 DRILL P PROD1 20:30 - 22:30 2.00 DRILL P PROD1 22:30 - 00:00 1.50 DRILL P PROD1 00:00 - 02:30 2.50 DRILL P PROD1 02:30 - 03:30 1.00 DRILL P PROD1 03:30 - 04:20 0.83 DRILL P PROD1 04:20 - 04:30 0.17 DRILL P PROD1 04:30 - 06:00 1.50 DRILL P PROD1 06:00 - 09:30 3.50 DRILL P PROD1 09:30 - 10:30 1.00 DRILL N DFAL PROD1 10:30 - 14:30 4.00 DRILL P PROD1 14:30 - 15:30 1.00 DRILL P PROD1 15:30 - 16:45 1.25 DRILL P PROD1 16:45 - 17:30 0.75 DRILL P PROD1 17:30 - 19:00 19:00 - 19:30 1.50 DRILL P 0.50 DRILL P PROD1 PROD1 19:30 - 19:50 0.33 DRILL P PROD1 19:50 - 20:00 0.17 DRILL P PROD1 20:00 - 20:30 0.50 DRILL P PROD1 20:30 - 21 :45 1.25 DRILL P PROD1 21 :45 - 23:30 1.75 DRILL P PROD1 DescriþtiQnof Operations Drill to 10790'. Drilling ahead 2.6/2.3 bpm @ 3350 psi, 2900 psi FS, Drill to 10,825' Stuck. Stop pump. rest hole. Pull free 55,000. Wiper trip to window. Drill Wiper trip 150'. Survey Circulate in 20#/bbl LCM Pill to bit.2.50/2.17bpm. POH.Lay in pill 1 :1. .6/.3 bpm. POH. Total losses on trip out 4 bbl. Changout BHA. RIH. Shallow test at 3000'. RIH to 9475 . Correction to flag -27'. RIH. Tie in with GR +8' correction. RIH tag bottom at 10,830', Directionally drill 2.8/2.77 bpm 3270 psi .FS= 3100psi ROP 120. drill to 10,874'. Loss rate increased to .8 to 1 bbl/min. Orient 30L. Had to PU off bottom to orient. Directionally drill 2.78 /2.0 bpm. @ 3200 psi, SP 3000 psi. (New mud to bit.) WOB 2-3K, ROP 130, Drill to 10920 Loss rate reduced to .5 bpm. Loss increase as a result of surveying but partially heal after. Drill ahead. Trickled in 6 sacks of G seal. Loss rate seemed to fall off from .5 to.2 bpm after turning corner. Drilled to 10930. 2.7/2.4 bpm. @ 3700 psi ROP 100+. Drill ahead. 3000 psi fs @ 2.5 bpm. 200-400 dpsi on mtr. 2.5 in/2.3 out. 2000-3000# wob. 75-125 fph rop. Drill to 11003' Difficulty with TORC orienter. Took many commands to get tool face to change. Drill ahead. 3000 psi fs @ 2.5 bpm. 300-500 dpsi on mtr. 2K-3K # WOB. 100 fph ROP. 90L. Drill to 11140'. Orient tool face. Some trouble getting desired tool face. Dave Smith trouble shoots same. Drill ahead. 2950 psi @ 2.5 bpm. 200-300 dpsi on mtr. 2k-5K# wob. 40-60 fph ROP. 2.5 in/2.3 out. ROP slowed from earlier, may be in top of Zone 3. Drill & orient to 11225'. Drill ahead. Signs of crossing fault. Survey at 11188' shows sharp 20 deg dogleg to left. Had some trouble pulling back up hole as though some junk/formation had fallen in behind BHA. Orient to 90R. 2.5 in/2.3 out. Wiper trip. Directionally drill 2.68/2.31 bpm at 3700 psi. FS= 3000 psi. Up 42K ON 10K. Stacking. ROP 100+, Drill to 11291. New mud added without G seal. Didnt see any change in loss rate without G Seal so stopped adding G seal to system. Wiper trip to 11,200. RIH. Survey 11,285'. Orient 120R. Directionally drill 11 ,327 PU to survey. Stacking trying to get to bottom. Back ream with 400 psi motor work to 11,200. RIH Stacking Wiper to window. No significant amount of cutting at bottoms up. Unable to get it to drill. Tried various rates to RIH and various Printed: 2/7/2003 1: 51 : 16 PM ) ) BPEXPLORATION OpêratiQ.tI$Summäry R~þ()..t Legal Well Name: M-09 Common Well Name: M-09 Spud Date: 5/9/1981 Event Name: REENTER+COMPLETE Start: 12/9/2002 End: 12/24/2002 Contractor Name: NORDIC CALISTA Rig Release: 12/24/2002 Rig Name: NORDIC 2 Rig Number: 2 Date From - Tö H ö u rs 12/14/2002 21:45 - 23:30 1.75 DRILL P PROD1 pump rates. Wiper trip to shoe. Back ream. Stacking at 11,312'. possible ledge. Back ream in continuous rotation mode. 23:30 - 00:00 0.50 DRILL P PROD1 Directionally drill 2.7/2.3 bpm @ 3670 psi FS =3000 psi.TORC in continuous mode. PICK UP to orient 90R TF. 300 psi motor work off bottom. RIH some thing at 11324. Bounce thru. Drilling at 103 ROP.4000 psiFS 3000 psi. 2.6/2.3 bpm. Top change tool face have to pull off bottom. Do not have enough pump left to increase the rate to 3 bpm and have motor work. PU at 11,324 1200 psi motor work off bottom. 12/15/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Directionally drilling 2.5/2.2 BPM, @ 3700 psi, FS=3000 psi. PU 40K ON 18K to 11 ,411'. 01 :00 - 01 :30 0.50 DRILL P PROD1 Wiper trip. Attempt to drill can't get weight to bit. 01 :30 - 04:30 I 3.00 DRILL N RREP PROD1 Generator failure overloaded system. Blackout. Restart one motor and pull into casing. Wait on electriction to trouble shoot and repair problem. 04:30 - 05:00 0.50 DRILL P PROD1 Spot LCM pill. 05:00 - 07:30 2.50 DRILL P PROD1 POH for ARC. 07:30 - 09:00 1.50 DRILL P PROD1 LD lateral BHA. Bit out of gauge (3.55" od, cutters 4-5 on nose, but cutters are intact). There is going to be a lot of under gauge hole to open up. 09:00 - 11 :00 2.00 DRILL P PROD1 PU resistivity tool, new motor & bit, 2nd TORC tool. Program mwd. 11 :00 - 12:30 1.50 DRILL N DFAL PROD1 TORC tool not communicating with rest of mwd. Change out same. 12:30 - 13:15 0.75 DRILL N SFAL PROD1 Unable to stab injector onto well due to injector angle. Well head crooked and pipe weight pulling injector forward tough to deal with. Cut o-ring on lubricator connection. Change out same. 13:15 -13:45 0.50 DRILL P PROD1 Get on well. RIH to 3500' for shallow test. 13:45 - 14:30 0.75 DRILL P PROD1 Trouble with mwd signal, a lot of noise. Check surface equipment. No problem found, but signal cleared up. 14:30 - 15:45 1.25 DRILL P PROD1 RIH to tie in point. 15:45 - 17:00 1.25 DRILL P PROD1 Log gr tie in from 10656' (up). gr 50' behind bit. -19' correction. 17:00 - 18:00 1.00 DRILL N DPRB PROD1 Begin reaming hole from 10930'. Very difficult drilling. Maintain original TF while reaming. 2800 psi@ 2.42 bpm. lots of stalling. 2.42 in/2.2 out. 18:00-21:15 3.25 DRILL N DPRB PROD1 Reaming at 2.45/2.18 bpm FS = 2750 psi. frequent stalls. Gamma shows shale 10910-10990. Tight at 10953, 10965,. Reaming at 11005. Back ream to 10,940 with TORC in continiuous rotation. 21:15 - 00:00 2.75 DRILL N DPRB PROD1 Ream stalling @ 11,025'. Work to 11050 many stalls. Ream from 11,050' to 11,191'. 2.59/2.26 bpm @ 3200 psi FS=3000 psi. at 275 ft/hr. 12/16/2002 00:00 - 02:00 2.00 DRILL N DPRB PROD1 Ream from 11,191' to 11,415'. 2.6/2.5bpm @ 3100 psi FS= 3000psi. 02:00 - 02: 15 0.25 DRILL P PROD1 Orient 90R. 02:15 - 02:30 0.25 DRILL P PROD1 Directionally drill to 11,450'. 2.6/2.28 bpm at 3,230 psi. FS = 3,000 psi. ROP 130 ft/hr ,WOB 3K, 02:30 - 02:45 0.25 DRILL P PROD1 Orient 270. 02:45 - 03:00 0.25 DRILL P PROD1 Directionally drill to 11,473' .2.7/2.4 bpm at 3,600 psi FS 3,280 psi. WOB 2k,ROP 150. Printed: 2/7/2003 1 :51 :16 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-09 M-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 12/9/2002 Rig Release: 12/24/2002 Rig Number: 2 Spud Date: 5/9/1981 End: 12/24/2002 Date From- To Hours Task Codè NPT Phase 12/16/2002 03:00 - 03:10 0.17 DRILL P PROD1 Orient 60L. 03: 1 0 - 03:45 0.58 DRILL P PROD1 Directionally drill to 11,561' 2.77/2.34 bpm at 3,530 psi FS 3,280 psi WOB 2K,ROP 140. 03:45 - 04:15 0.50 DRILL P PROD1 Wiper trip to 10,569'. 04: 15 - 05:30 1.25 DRILL P PROD1 Tie -in correction +4'. 05:30 - 06:15 0.75 DRILL P PROD1 RIH. Hole smooth. 06: 15 - 09:00 2.75 DRILL P PROD1 Drill ahead. 3300 psi fs @ 2.8 bpm. 200-500 dpsi on mtr. 1,000-3,000# wob. 75-125 fph rop. 2.8 in/2.4 out. TF:90L. Drill to 11,707'. 09:00 - 12:00 3.00 DRILL P PROD1 Wiper trip to window. Loss rate increased from 2.6 in/2.3 out to 2.6 in 1.6 out. Begin treating with G-seal. Drill to 11,764'. 12:00 - 16:30 4.50 DRILL N SFAL PROD1 Rig power pack down. Coupling between traction motor and main hydraulic pump failed. Bit at 11,749'. Continue to circulate at 0.5 bpm. No returns. Order out 2% kcl while waiting on repairs. Able to make temporary repair to coupling. 16:30 - 17:30 1.00 DRILL N SFAL PROD1 Pull OOH into liner at 10450'. Circulate 10 bbl 20 ppg Mixll fine, medium & coarse (7 ppb each) down coil. 17:30 - 22:00 4.50 DRILL N SFAL PROD1 Replace coupling on Power pack Circulate across top of hole 2.5 bpm. NO returns. Fill hole took 15 bbl. 22:00 - 00:00 2.00 DRILL N SFAL PROD1 Continue to replace coupling. Hubbs installed. Check alignment of hubbs. Install coupling. 12/17/2002 00:00 - 00:45 0.75 DRILL N SFAL PROD1 Trouble shoot control problem on mud pump #2. 00:45 - 01 :30 0.75 DRILL P PROD1 RIH Pumping 1 bpm no returns. tag 11,764'. 01 :30 - 01 :45 0.25 DRILL P PROD1 Orient. 90R 01 :45 - 03:30 1.75 DRILL P PROD1 Directionally drill at 2,6/1.7 bpm @ 3,520 psi., FS = 3,250 psi., WOB 2K, ROP 60 ft/hr. to 11,805'. 03:30 - 05:00 1.50 DRILL P PROD1 Continue directionally drilling at 90R. 2.55/1.67 bpm. @ psi, FS = 3,370 psi. Ratty drilling. Lots of stalls. Maybe fault #2. Lots of chert in sample. Drill 11 ,805 to 11,817 05:00 - 07:00 2.00 DRILL P PROD1 Continue directionally drilling at 30R. 2.66/1.84 bpm 3,800 psi FS 3,600 psi UP 43K, ON 16K. 07:00 - 08:30 1.50 DRILL P PROD1 Drilling ahead. Loss rate increased from 2.6/1.6 to 2.6 in/1.0 out. Apparently we are in Zone 3, near second fault. 3500 psi fs at 2.46 bpm. 0.9 bpm out. Plan to drill 1 00' across fault and treat losses. Drill to 11853'. 08:30 - 09:00 0.50 DRILL P PROD1 Survey and short trip (above suspected fault at 11800') 09:00 - 10:30 1.50 DRILL P PROD1 Total losses drill through the fault to 11,893'. 10:30 - 14:00 3.50 DRILL P PROD1 Lay in 50bbl LCM pill. Plugging off. Displaced out of coil. High Pressure bha partially plugged. POH to look at BHA. 14:00 - 15:00 1.00 DRILL P PROD1 POH. 15:00 - 15:15 0.25 DRILL P PROD1 Fill hole took 18 bbl. 15:15 - 20:15 5.00 DRILL P PROD1 Test BOP's. 20:15 - 21:15 1.00 DRILL P PROD1 Cut 100' coil. 21 :15 - 22:45 1.50 DRILL P PROD1 Install coil connector. Pull test 45K and PT to 3500 psi. O.K. 22:45 - 00:00 1.25 DRILL P PROD1 Bleed off, Fill 38 bbls and monitor well. 12/18/2002 00:00 - 01 :30 1.50 DRILL P PROD1 PU BHA. 01 :30 - 03:30 2.00 DRILL P PROD1 RIH to 3000'. Shallow hole test TORC and MWD. O.K. Continue Had been pumping .5 bpm without returns. 03:30 - 04:15 0.75 DRILL P PROD1 Tie-in -18' correction. 04:15 - 05:00 0.75 DRILL P PROD1 RIH. Very clean to TD. Tag bottom 11907'. 05:00 - 05:25 0.42 DRILL P PROD1 Survey bit depth 11,900'. 05:25 - 07: 15 1.83 DRILL P PROD1 Directionall drill. Took off running immediately -- 100+ FPH. Definitely in Z4 on bottom. Drill with full losses at 2.8 BPM; Printed: 21712003 1:51:16 PM ) ") BF>EXPLQRATION QþératiQ.r1sS urn nl~tyRØport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date M-09 M-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours Task Code NPT Phase 07: 15 - 08:00 08:00 - 10:30 10:30 - 11 :30 11 :30 -12:00 12:00 - 14:00 1.83 DRILL P 0.75 DRILL P 2.50 DRILL N 1.00 DRILL N 0.50 DRILL N 2.00 DRILL N PROD1 12/18/2002 05:25 - 07: 15 DPRB DPRB DPRB DPRB PROD1 PROD1 PROD1 PROD1 PROD1 14:00 - 16:15 2.25 DRILL N 16:15 - 16:45 0.50 DRILL N 16:45 -17:15 0.50 DRILL N 17:15 - 17:30 0.25 DRILL N 17:30 - 19:15 1.75 DRILL N DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 DPRB PROD1 19:15 - 21:00 1.75 DRILL N DPRB PROD1 21 :00 - 23:00 2.00 DRILL N DPRB PROD1 23:00 - 00:00 1.00 DRILL N DPRB PROD1 12/19/2002 00:00 - 01 :30 1.50 DRILL N DPRB PROD1 01 :30 - 02:00 0.50 DRILL N DPRB PROD1 02:00 - 02:20 0.33 DRILL N DPRB PROD1 02:20 - 02:30 0.17 DRILL N DPRB PROD1 02:30 - 03:30 1.00 DRILL N DPRB PROD1 03:30 - 04:00 0.50 DRILL P PROD1 04:00 - 07:30 3.50 DRILL N DPRB PROD1 07:30 - 08:30 1.00 DRILL N DPRB PROD1 Start: 12/9/2002 Rig Release: 12/24/2002 Rig Number: 2 Spud Date: 5/9/1981 End: 12/24/2002 2800 psi, but keeping hole full (slight trickle coming back). Drill to 12020'. Survey. POOH. LD drilling BHA. Bit 1-1. MU 3/4" hole nozzle and 2 jts PH6. RIH. Correct depth at flag (-18'). RIH to whipstock. Getting returns at 2.0 BPM in while RIH at 100 FPM. When parked, unable to get returns at 3.0 BPM; 1950 psi CTP. RU cementers. Safety meeting. Mix pre and post flush (100k LSRV Flo-Vis pill -- fresh water). PT lines to 7200 psi. Fill hole on backside with rig pumps (only took 5 bbls to fill after circ at min rate for a couple hours). Cementers pump 10 bbls preflush then FAP pill down coil. Continue to fill across stack with rig pump to keep hole full. Initial, 2.5/1900. With FAP at nozzle, 1.2/4600. SI filling backside and bullhead pill to loss zone 1.0/5000 psi (max rate -- pump cavitating?). Total FAP pill pumped = 80 bbls with last 15 bbls containing 1 ppb cello-flakes. Chase with 10 bbls post flush. With 8 bbls FAP into deepest loss zone (theoretical with upper loss zone taking nothing), started building WHP. Continue bullheading allowing WHP to climb. Max WHP = 800 psi at 2.5 BPM. Lower rate to 1.0 BPM near end. WHP stable at 570 psi. Stop bullheading as last of FAP exits nozzle (leaving 18 bbls FAP in OH). POOH at 1.0 BPM, bleeding WHP slowly to zero. Circulate another 30 bbls mud thru coil at wide open choke. POOH filling. Change out nozzle for Drilling BHA with resistivity. RIH. Shallow hole test at 3000'. RIH. Tie-in Correction -19'. RIH 2.78/3.02/bpm 36 ftImin. RIH to 10,935 -10,950 tight. PU to 10923. Stuck. Work pipe. Pull Free 20 Kover. Orient 60L. RIH. to 10,912' (Zone 3) losses started increase 2.77/1.72 bpm 3,013 psi. 2.77/2.33 bpm healing back. at 10,933' 2.74/2.5. at 11,200' 2.74/2.63bpm, at 11,800' 2.75/2.56 at 118802.77/.99. RIH to 119002.76/.57 bpm, Tag at 12015'. Directionally drill 90L 2.82/.3 bpm. 3700 psi. FS= 2950 psi, WOB 4K ROP 40, drill to 12048. High irradic pressures. BHA plugging. Overpulls off bottom. POH to 10,488. Coil plugged. Attempt to fill down the backside. Backside plugged off. Backside pressuring up with less than 1 bbl but broke down at 700 psi. Possible Form A Set cutting in backside. POH pumping down backside (closed choke). LD BHA. Did not find source of plugging. Download MWD. Anti-jamming feature was activated only from 03:45 to 05:55. Explains why we didn't find source of plugging. Suspect two things were going on downhole -- jammed (not plugged) MWD and packing off on backside (probably FAP). Will swap our Printed: 2f712003 1 :51: 16 PM ) ) OpérFltiØ.n$~lIJJlrn<lryR.e port Legal Well Name: M-09 Common Well Name: M-09 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From-To 12/19/2002 07:30 - 08:30 1.00 DRILL N DPRB PROD1 08:30 - 09:30 1.00 DRILL N DPRB PROD1 09:30 - 11 :30 2.00 DRILL N DPRB PROD1 11 :30 - 12:30 1.00 DRILL N DPRB PROD1 12:30 - 14:15 1.75 DRILL N DPRB PROD1 14:15 - 14:30 0.25 DRILL N DPRB PROD1 14:30 - 17:00 2.50 DRILL N DPRB PROD1 17:00 - 17:45 0.75 DRILL N DPRB PROD1 17:45 - 18:45 1.00 DRILL P PROD1 Start: 12/9/2002 Rig Release: 12/24/2002 Rig Number: 2 Spud Date: 5/9/1981 End: 12/24/2002 pesçriptionof Operations 18:45 - 19:00 0.25 DRILL P PROD1 19:00 - 19:20 0.33 DRILL P PROD1 19:20 - 19:40 0.33 DRILL P PROD1 19:40 - 20:40 1.00 DRILL P PROD1 20:40 - 21 :00 0.33 DRILL P PROD1 21 :00 - 22:30 1.50 DRILL P PROD1 22:30 - 23:00 0.50 DRILL P PROD1 23:00 - 23: 1 0 0.17 DRILL P PROD1 23:10 - 00:00 0.83 DRILL P PROD1 12/20/2002 00:00 - 00:40 0.67 DRILL P PROD1 00:40 - 03:00 2.33 DRILL P PROD1 03:00 - 04:30 1.50 DRILL P PROD1 04:30 - 06:30 2.00 DRILL P PROD1 06:30 - 07: 15 0.75 DRILL P PROD1 07:15 - 08:15 1.00 DRILL P PROD1 08:15 - 09:20 1.08 DRILL P PROD1 09:20 - 11 :00 1.67 DRILL P PROD1 surface system anyway (with exception of Class I LCM pill from yesterday that was not pumped -- still trying to figure out what to do with this). Cut 100' of coil. Rehead. Pull and PT CTC. Swap mud around in pits. Wait on empty truck for swap. Well taking about 10 - 15 BPH static. Offload used mud. Load and pump dart thru coil -- 58.2 bbls. Note: Cap on dart launcher packed with FAP. No significant debris recovered from coil. MU drilling BHA #11. RIH. Shallow test at 3500 ft. 2.7/2.0 and 2800 psi. Log tie-in up at 10,588' GR spike. Correct depth (-25'). RIH. Ratty with motor work 10930' - 10980'. RIH at 2.0 BPM with minimal returns, very clean the rest of the way to TO. Tag 12050' . Drill starting at 2.8/0.5 and 2700 FS. Within the first 30 feet, lost all returns, gradually lost about 400 psi of CTP, and saw gradual wt gain while drilling at 120 FPH ROP. Hit another loss zone?? Continue drilling, performing wiper trips to 11,800' for every 50' drilled. Drill to 12090'. Resistivity suggest additional faulting. 200' wiper. Drill at 2.80 1 0.00 @ 2700 psi FS = 2400psi. UP 50K, On 20K, WOB 1-2K, ROP 100+ drill to 12,150'. Wiper to 11,800'. Drill at 2.79/0.0 bpm, 2677 psi FS= 2400 psi WOB <1 K. ROP 140. DRill to 12255 Wiper to window. Wait on mud delivery. RIH . Set down at 10,965'. RIH to 12,100'. Survey. Directionally drill 2.69/0 bpm at 2500 psi. ROP 150+ Wiper to 11,800'. Directionally drill 2.731 0.0 bpm, @ 2550 psi. FS 2200psi WOB>1, ROP 100. drill to 12,500 Wiper trip to window. Drill 2.8 10.0 bpm @ 2230 psi 150+ ROP. Drill to 12,650'. Experiencing some stacking. Wiper to 11800'. Drill with negative weight to get thru tough spot 12650', then back to drilling with 10k - 15k string weight. Drill to 12750'. Wiper to window at 50k up. Pulled heavy 11900' - 11750' (BHA going across area of the big drinking fault), up to 75k. Slow down pulling speed. Absolutely no hint of motor work over this interval. Suspect cuttings buildup in this area, which is exaclty what we've seen on other wells with thief zones such as this; however, in the other wells, we were on KCL water. We were hoping that by staying on mud, the debris would be better carried into the fault. Doesn't appear this is happening. Uphole conditions good, just a little ratty in 10950' Z3 vicinity. RIH. Tag and stall 10910'. PU and RIH wlo pumps. Tag with bit 10980'. Work through. This Z3 area has been ratty the entire well. RI H. Slow down starting 11700'. Stop at 11800' Printed: 21712003 1:51:16 PM ) ) BP EXPLORATION Operations Summary Report Page 8 of 11 Legal Well Name: M-09 Common Well Name: M-09 Spud Date: 5/9/1981 Event Name: REENTER+COMPLETE Start: 12/9/2002 End: 12/24/2002 Contractor Name: NORDIC CALISTA Rig Release: 12/24/2002 Rig Name: NORDIC 2 Rig Number: 2 Date From - To Hours Task Code NPT 12/20/2002 09:20 - 11 :00 1.67 DRILL P PROD1 (very clean to here) and PUH for 20', clean. RIH slow to 12000' (very clean). PUH again thru fault area. VERY CLEAN PULL (FLATLlNE AT 47K) up thru fault area this time. RIH. Tag 12090' with motor work (the last fault -- so far), but fell thru. RIH tag with MW 12640' (shale) to 12650'. Try getting thru. Take small bites with backreaming. On backreaming, seeing overpulls to 65k with little motor work the whole way from 12660' - 12570', then stall and stuck at 12570'. Work free going down. RIH to 12710'. Back ream shale area again -- very little motor work, but lots of overpullin to 12565', then cleaned up. 11:00-12:15 1.25 DRILL N DPRB PROD1 Send continuous rotate command and ream shale again. Same as last trip thru -- pulling tight with negligible MW. Work BHA thru shale several times-- cleaned-up a lot. 12:15 - 12:45 0.50 DRILL P PROD1 RIH and tag TO 12740'. Looks like we stretched a little pipe. Drill to 12806'. 12:45 - 14:00 1.25 DRILL N DPRB PROD1 Wiper to 11750'. Not too bad thru 12650' shale. Pull heavy 12160' with slight bump in CTP. May be packing off with upper portion of BHA pulling thru 12090' fault. Hole is getting ugly. Work BHA up past fault. OP to 65k at 11950' (CTC coming thru next fault). Ratty with gradual increase in pulling weight w/o MW starting again at 11885'. Slack off and RIH when weight reaches 65k. Work pipe up at full pump rate. Stuck at 11775'. Work pipe down to free. PUH smooth thereafter to 11750'. Work back and forth across fault. Clean up and down. 14:00 - 14:45 0.75 DRILL P PROD1 RIH. Slight weight loss at 12090' fault. Shale at 12600' in good shape. 14:45 - 15:10 0.42 DRILL P PROD1 Drill to 12870'. 15:10 - 16:30 1.33 DRILL P PROD1 Wiper to window with continuous rotation. 12650' shale not too grabby. Same heavy pulling and stuck condtions across 11840' fault as seen above. Pull to window. 16:30 - 17:00 0.50 DRILL P PROD1 Log tie-in. Correct depth (+30'). 17:00 - 18:00 1.00 DRILL P PROD1 RIH. Hole in pretty good shape. 18:00 - 18:15 0.25 DRILL P PROD1 Orient to get out of continuous rotate mode. 18:15 -19:45 1.50 DRILL P PROD1 RIH. Tag TO. Drill to 12,930'. 19:45 - 21 :00 1.25 DRILL P PROD1 POH. Madd pass 11,400' to 10,550'. At 12,700' and 11,900' -11,800' over pulls but no motor work. Work through tight intervals. 21 :00 - 23:00 2.00 DRILL P PROD1 POH to surface. 23:00 - 00:00 1.00 DRILL P PROD1 LD BHA. Static loss rate 19 bbls per hour. 12/21/2002 00:00 - 01 :00 1.00 CASE P COMP RU liner running tools. PU float equipment. Belled box on Landing Collar. 01 :00 - 02:00 1.00 CASE N WAIT COMP Wait on replacement Landing Collar. 02:00 - 04:00 2.00 CASE P COMP MU liner first 66 joints. Belled box on Marker joint with 1400 ft Ibs. 04:00 - 05:00 1.00 CASE N WAIT COMP Wait on delivery of pup joint. 05:00 - 06:30 1.50 CASE P COMP Continue to MU liner. 06:30 - 07:00 0.50 CASE P COMP Safety meeting. 07:00 - 08:00 1.00 CASE P COMP MU liner. 08:00 - 08:45 0.75 CASE N WAIT COMP Wait on liner top location verification to ensure future liner top packer stays out of jewelry and to try and preserve X-Nipple above packer (incorrect WBD and also some ELMO vs DPM issues). Printed: 2rT12003 1:51:16 PM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 12/21/2002 08:45 - 09:30 09:30 - 10:15 10:15-10:30 10:30 - 13:30 13:30 - 13:45 13:45 - 15:00 15:00 - 16:30 16:30 - 17:00 17:00 - 17:30 17:30 - 18:45 18:45 - 21 :00 21 :00 - 21 :30 21 :30 - 22:00 22:00 - 00:00 12/22/2002 00:00 - 00:45 00:45 - 01 :00 01 :00 - 02:30 02:30 - 04:00 04:00 - 05:00 05:00 - 07:30 Op~rati 0 ns ..5 um<rI1Ç1rYR~p()rt M-09 M-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Hours Task Code NPT 0.75 CASE P 0.75 CASE P 0.25 CASE P 3.00 CASE P 0.25 CASE P 1.25 CASE P 1.50 CEMT P 0.50 CEMT P 0.50 CEMT P 1.25 CEMT P 2.25 CEMT P 0.50 CEMT P 0.50 EVAL P 2.00 EVAL P 0.75 EVAL P 0.25 EV AL P 1.50 EVAL P 1.50 EVAL P 1.00 EVAL P 2.50 EV AL P Start: 12/9/2002 Rig Release: 12/24/2002 Rig Number: 2 Spud Date: 5/9/1981 End: 12/24/2002 COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP Description of Operations MU CTLRT. Rehead. Pull and PT Baker CTC. Stab pipe. RIH filling coil, then filling backside. Correct depth at flag (-31 '). 51 k up at window. Hole in good shape until 12600' shale. Switch back to circ down coil at 0.5 BPM. Work up and down to get thru shale. Work pipe to TO 12916' CTM. This is bottom. PUH (up to 70k) and RIH and tag same depth four times. No packoff noted at 0.5 BPM. Stack wt down. Pump down coil 2.6 BPM/2700 psi. Reduce rate to 1.5 BPM/1300 psi. PUH about 3'. Looks like we're off liner at 40k up. Not a surprise. Also, saw breakover in pressure to 1000 psi. Sting back into same stacked depth. Circ pressure back to 1300 psi. Pump phenolic ball to shear ball seat, although not required. Seat at 54 bbls. Shear at 3200 psi. PU again to confirm clean. Stack down. Displace will to 2% KCL water. 2.5/2300 initial; 2.6/2000 with KCL at faults. No returns. Column of mud still on backside. Safety meeting with cementers. Finish RU of cementers. Phase 1. PT lines to 4000 psi with KCL water. Mix and load 35 bbls of 15.8 ppg Class G latex cement into coil. Fill backside with rig pump. Load dart past T and push into plug valve. Launch dart. Check to see if dart is gone by closing plug valve gently -- gone. Displace cement with 18 bbls of 2 ppb bio water at 4.0 BPM, then 2% KCL water. Took 21 bbls to catch the cement. Continue displacing. Saw cement turn corner at correct MM in. With cement lead at 12090' fault, pressure increased quickly from 2500 psi - 3500 psi at 2.5 BPM. Pressure building and breaking. Lower rate to 1.0 BPM at 2 bbls before latch-up. PU LWP at 58.6 bbls. Shear LWP at 3100 psi. Displace LWP to latch collar at 2.5 BPM, pressure still building and breaking. Bump at .3 bbls over theo. Pressure to 3,000 psi. NO RETURNS DURING ENTIRE JOB. Unsting with 3000 psi. Circulate. POH to surface pumping down backside with charge pump. To prevent swabbing due to the diameter of running tool 3.5" and viscosity of the mud the well was closed in and pumped down the coil by tubing annulus with charge pump at 40 psi. LD BHA. MU Logging tools. PU mill, motor, logging tools and 43 stands of 1-1/4" work string. Continue to pick up 43 stands of workstring. Stab injector. RIH to 10,400'. Log down at 30 ftImin. No motor work.Tag 12,860' uncorrected. Log up 60 ftImin. to 10,100'. RIH to spot perf pill. At 1.4/1700. Numerous pressure spikes and set downs starting at 10862'. Clean pickups. Acts like we're pushing debris ahead of us. Work to 12100'. BHA Printed: 21712003 1: 51: 16 PM ) OperatiQl1s.SummaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-09 M-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From- To Hours Task Code NPT Phase 12/22/2002 05:00 - 07:30 2.50 EVAL P COMP 07:30 - 09:30 2.00 EVAL N DPRB COMP 09:30 - 10:00 0.50 EVAL N DPRB COMP 10:00 - 10:45 0.75 EVAL N SFAL COMP 10:45 - 11:45 1.00 EVAL N DPRB COMP 11:45-12:15 0.50 EVAL N DPRB COMP 12:15 -13:00 0.75 EVAL N DPRB COMP 13:00 - 14:00 1.00 EVAL N DFAL COMP 14:00 -16:15 2.25 EVAL N DPRB COMP 16:15-17:45 1.50 EVAL N DPRB COMP 17:45-21:15 3.50 EVAL N DFAL COMP 21:15-22:00 0.75 EVAL N DFAL COMP 22:00 - 23:30 1.50 EVAL N DFAL COMP 23:30 - 00:00 0.50 EVAL N DPRB COMP 12/23/2002 00:00 - 03:00 3.00 EVAL P COMP 03:00 - 05:00 2.00 EVAL P COMP 05:00 - 05:30 0.50 EVAL P COMP 05:30 - 06:30 1.00 EVAL P COMP 06:30 - 09:30 3.00 EVAL N DFAL COMP 09:30 - 10:00 0.50 EVAL N DFAL COMP 10:00 - 12:30 2.50 EVAL N DFAL COMP 12:30 - 14:00 1.50 EVAL N DFAL COMP 14:00 - 15:30 1.50 EVAL N DFAL COMP 15:30 - 19:00 3.50 EVAL N DFAL COMP 19:00 - 20:00 1.00 EVAL N DFAL COMP 20:00 - 21 :00 1.00 EVAL N DFAL COMP 21 :00 - 22:00 1.00 EVAL N DPRB COMP 22:00 - 00:00 2.00 EVAL N DPRB COMP 12/24/2002 00:00 - 01 :30 1.50 EVAL N DPRB COMP Start: 12/9/2002 Rig Release: 12/24/2002 Rig Number: 2 Spud Date: 5/9/1981 End: 12/24/2002 Description of Operations plugging. Pressuring up to 2500 psi. POOH for apparent plugged BHA. SB inj. Pump 5/8" ball to open circ sub. Blow back coil. Broke hose on little jerks. Repair. Stand back CSH. Crew change safety meeting. Finish SB CSH. LD BHA. Battery in memory tool quit working before acquiring any log data. Reprogram for rerun. MU motor, mill, memory GR/CCL, 43 stands CSH. Stab inj. Well taking 10 BPH. RIH. Report on last motor -- no damage or plugging found. Don't know cause of the higher pressures that we saw. Log down from 10100' at 1.0/480. RIH pumping.5 bpm Set down at 12114, 12158, 12175 12181 12262 Tried various pump rates and ROPs. RIH at 8 ftlmin 1.08 bpm 960 psi. This combination working fine. TO 12854 uncorrected tag with and without pump. Log up 60 ft/min 8 bpm 250 psi. RIH .8 bpm 250 psi 46 ftlmin to spot perf pill. Tag bottom 12,854' Attempt to mill. Numerous stalls. Look like bottom. Lay in perf pill to liner top. POH to BHA. Stand back 1-1/4" RTS and laydown BHA. Memory Logging tool failed again suspect an internal short. Cut 100' of coil Rehead. Pull and PI. Discuss options. Call for PDS memory GR/CCL (will put inside SWS carrier). Safety meeting. RU PDS tools. MU logging tools in SWS carrier with nozzle. MU 43 stands CSH. RIH. Log down starting at 10100' at 30 FPM at minimum rate. Tag PBTD at 12852' (electronic counter) and 12877' (mechanical + BHA). Clean RIH. OP 15k off bottom. Log up at 30 FPM, laying in 18 bbls of 150k LSRV Flo-Pro. POH to BHA Standback RTS tubing and LD memory logging tools. Process logs and interput results.Corrected depth of TO Gunk / obstruction) 12,830' MD. Corrected depth of Liner Top 10,334 and liner top packer tie back sleeve 10,327'. MU Liner top packer. RIH. RIH with Baker KP liner top packer. Set and test liner top packer. Up wt 46,500 ON wt 17100. Stab into liner while pumping slow. Seen pressure rise at 10351' uncorrected. No Go at 10,354' and 10358.4' with 10K down. PU to drop ball keeping stung in to seals due to well loss rate. Didn't want to suck in a lot of air. Unsting and circulate 30 bbls. Shut down pump. While ball is falling, sting back in to liner set 10K down. Pick up to neutral wt +2'. Pressure to 2500 psi to set slips. Over pull 5K to test slips. Slack off 1 OK to 10,354.7 shallower Printed: 2/7/2003 1 :51: 16 PM QPérati.o ns 5 Ümma pý..Repó rt Legal Well Name: M-09 Common Well Name: M-09 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date I From - To Hòurs Task Code NPT Start: 12/9/2002 Rig Release: 12/24/2002 Rig Number: 2 Spud Date: 5/9/1981 End: 12/24/2002 12/24/2002 00:00 - 01 :30 DPRB COMP Description. of Operations 1.50 EVAL N 01 :30 - 04:00 2.50 EVAL N DPRB COMP 04:00 - 04:30 0.50 EVAL N DPRB COMP 04:30 - 05:30 1.00 PERF P COMP 05:30 - 09:00 3.50 PERF P COMP 09:00 - 09:45 0.75 PERF N HMAN COMP 09:45 - 10:15 10:15 - 12:45 0.50 PERF P 2.50 PERF P COMP COMP 12:45 - 13:30 0.75 PERF P COMP 13:30 - 15:45 2.25 PERF P COMP 15:45 - 16:00 0.25 PERF P COMP 16:00 - 20:30 4.50 PERF P COMP 20:30 - 21 :00 0.50 PERF P COMP 21 :00 - 00:00 3.00 PERF P COMP depth with 10 K down indicating that the slips are set. Test backside to 2000 psi for three minutes. Short test need to circulate coil for fear of freezing. Pressure to 3480 psi to shear packer free. Pick up. Circulate coil. Test system to 1154 psi for 10 min. O.K. POH. LD liner packer running tools. RU and test tubing, liner lap and liner to 2200 psi for 30 minutes. 2 psi loss in 30 min. O.K. PJSM for perforating held during pressure test. PU perforating guns and CSH. Because of shallow tag (debris) in liner at 12830' corrected compared with corrected latch collar depth of 12895', unable to perforate the bottom 55' as requested. Dickey and McCorkle agreed not to perforate this instead of proceeding with additional liner clean-out attempts. Also, because of the uncertainty as to the nature of the debris (even though it was immobile with a 2.3" mill), have decided to use a deep fluted fixed blade centralizer to no-go tag at the top of the liner for depth control. Space out CSH with pups to place bullnose of guns at 12828' when the centralizer no-gos the top of the liner top packer at 10327.5'. Then PU to perforate with bottom shot at 12825'. MU fixed blade centralizer to CSH. Break off to check drift. 3/4" ball (needed for disconnect) would not go thru -- tool should be 1" 10. Discuss with Baker -- OK to drill it out here at the rig. Drill it. MU MHA, stab inj. RIH. Tagged top of liner with "no-go", bottom of BHA at 12834'. Correct depth -6' to 12828'. Drop and pump .625" ball at 2 bpm. Pick up CT to put bottom shot on depth at 12825'. Slow pump rate to 1.15 bpm ball on seat but not staying on seat. Increase rate to 2 bpm guns fired at 3400 psi. Complete loss of circulation after firing guns. Perfs: 2" HSD PJ 2006 4spf @ 12180' ~ 12591',12630' -12825'. TOH to 1 1/4" CSH filling hole across top with charge pump. Set back injector Standback 1 1/4" CSH. UD perf guns. All guns fired. Freeze protect with 30 bbls MeOH. Nipple down BOPE install tree cap and test to 4k. Clean mud tanks. Rig Released at midnight 12-24-2002 Printed: 21712003 1:51:16 PM SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc Field....................: Prudhoe Bay Well.....................: M-09B API number...............: 50-029-20563-02 Engineer. . . . . . . . . . . . . . . . .: M. Brown 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. . . . . . . . . .: GR Tie In @ 10588 ft GL above permanent.......: -50000.00 ft KB above permanent.......: -50000.00 ft DF above permanent.......: -50000.00 ft ----- Vertical section origin---------------- La tit ude ( + N / S -) . . . . . . . . . : 0 . 00 f t Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- La tit ude ( + N / S -) . . . . . . . . . : - 999 . 25 f t Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 215.00 degrees 20-Dec-2002 20:14:29 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey.... ....: Page 1 of 3 12Dec-02 20-Dec-02 48 10500.00 ft 12930.00 ft ,~ ----- Geomagnetic data ---------------------- Magnetic model........ ...: BGGM version 2002 Magnetic date............: 11-Dec-2002 Magnetic field strength..: 1150.51 HCNT Magnetic dec (+E/W-).....: 25.89 degrees Magnetic dip.............: 80.81 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: H..............: Dip. . . . . . . . . . . . : of G...........: of H........... : of Dip.........: Criteria --------- 1002.68 mGal 1150.51 HCNT 80.81 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-). ....: 25.89 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.89 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 20-Dec-2002 20:14:29 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 10500.00 1.67 156.24 0.00 8511.61 3881.50 -2136.78 -3715.55 4286.16 240.10 0.00 TIP None 2 10515.00 1.39 162.19 15.00 8526.61 3881.72 -2137.15 -3715.41 4286.22 240.09 2.14 MWD M None 3 10545.00 8.25 220.28 30.00 8556.49 3884.09 -2139.14 -3716.69 4288.32 240.08 25.36 MWD M None 4 10575.00 16.13 203.54 30.00 8585.80 3890.33 -2144.62 -3719.75 4293.71 240.03 28.52 MWD M None 5 10602.73 24.48 222.99 27.73 8611.81 3899.82 -2152.37 -3725.22 4302.32 239.98 38.34 SP None 6 10632.64 33.58 229.12 29.91 8637.94 3914.01 -2162.34 -3735.73 4316.41 239.94 31.97 SP None 7 10663.90 41.28 235.74 31.26 8662.76 3932.07 -2173.83 -3750.81 4335.22 239.91 27.76 SP None .~ 8 10695.02 47.40 238.87 31.12 8685.00 3952.17 -2185.54 -3769.12 4356.93 239.89 20.87 SP None 9 10725.63 56.10 239.04 30.61 8703.94 3974.12 -2197.93 -3789.70 4380.95 239.89 28.43 SP None 10 10759.32 63.63 236.22 33.69 8720.84 4001.00 -2213.54 -3814.27 4410.03 239.87 23.50 SP None 11 10794.94 71.78 234.79 35.62 8734.34 4031.84 -2232.20 -3841.40 4442.87 239.84 23.17 SP None 12 10820.86 76.23 233.72 25.92 8741.49 4055.36 -2246.75 -3861.61 4467.66 239.81 17.59 SP None 13 10854.50 76.33 229.33 33.64 8749.47 4086.69 -2267.08 -3887.19 4499.99 239.75 12.65 MWD M None 14 10900.61 80.70 223.87 46.11 8758.66 4130.92 -2298.12 -3919.99 4543.97 239.62 14.98 SP None 15 10950.72 84.53 220.37 50.11 8765.10 4180.22 -2334.97 -3953.30 4591.37 239.43 10.31 SP None 16 10999.89 82.13 211.49 49.17 8770.82 4228.99 -2374.47 -3981.93 4636.15 239.19 18.59 SP None 17 11050.43 82.15 204.42 50.54 8777.74 4278.65 -2418.67 -4005.39 4679.00 238.87 13.86 SP None 18 11100.54 81.95 197.09 50.11 8784.68 4326.72 -2465.04 -4022.96 4718.12 238.50 14.49 SP None 19 11150.36 80.83 186.79 49.82 8792.16 4371.98 -2513.16 -4033.14 4752.08 238.07 20.57 SP None 20 11200.57 84.08 184.59 50.21 8798.77 4415.37 -2562.68 -4038.07 4782.61 237.60 7.79 SP None 21 11260.33 85.20 193.17 59.76 8804.36 4468.74 -2621.41 -4047.25 4822.04 237.07 14.42 SP None 22 11310.89 82.00 201.17 50.56 8810.01 4516.52 -2669.37 -4062.06 4860.65 236.69 16.95 SP None .~ 23 11370.42 81.75 207.59 59.53 8818.43 4574.42 -2723.02 -4086.37 4910.53 236.32 10.68 SP None 24 11412.24 80.60 213.17 41.82 8824.85 4615.59 -2758.66 -4107.26 4947.71 236.11 13.47 SP None 25 11452.26 79.58 217.02 40.02 8831.74 4655.00 -2790.91 -4129.92 4984.52 235.95 9.82 SP None 26 11507.20 79.50 209.14 54.94 8841.74 4708.95 -2836.14 -4159.38 5034.30 235.71 14.10 SP None 27 11553.71 82.00 202.94 46.51 8849.22 4754.27 -2877.36 -4179.52 5074.21 235.45 14.21 SP None 28 11603.36 84.78 196.84 49.65 8854.94 4801.85 -2923.72 -4196.28 5114.38 235.13 13.43 SP None 29 11653.29 83.63 188.44 49.93 8859.99 4847.75 -2972.14 -4207.14 5151.08 234.76 16.89 SP None 30 11702.66 79.20 183.39 49.37 8867.36 4890.40 -3020.67 -4212.18 5183.33 234.35 13.52 SP None SCHLUMBERGER Survey Report 20-Dec-2002 20:14:29 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 (degl tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type ( deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 11752.34 82.30 191.89 49.68 8875.36 4933.90 -3069.21 -4218.71 5217.05 233.96 18.00 SP None 32 11802.47 82.80 198.99 50.13 8881.87 4980.71 -3117.09 -4231.94 5256.00 233.63 14.08 SP None 33 11857.45 88.75 202.19 54.98 8885.92 5033.79 -3168.39 -4251.21 5302.03 233.30 12.28 SP None 34 11899.55 89.75 202.99 42.10 8886.47 5074.90 -3207.25 -4267.38 5338.26 233.07 3.04 SP None 35 11949.58 87.75 207.59 50.03 8887.56 5124.19 -3252.47 -4288.75 5382.55 232.82 10.02 SP None 36 12002.83 86.60 212.72 53.25 8890.19 5177.16 -3298.44 -4315.45 5431.65 232.61 9.86 SP None 37 12053.30 87.10 209.49 50.47 8892.96 5227.43 -3341.58 -4341.48 5478.56 232.42 6.47 SP None .~ 38 12103.17 89.60 211.39 49.87 8894.40 5277.12 -3384.55 -4366.73 5524.81 232.22 6.30 SP None 39 12152.77 93.20 215.07 49.60 8893.19 5326.66 -3426.02 -4393.90 5571.71 232.06 10.38 SP None 40 12202.65 94.10 220.74 49.88 8890.01 5376.36 -3465.28 -4424.47 5619.97 231.93 11.49 SP None 41 12252.73 90.55 225.49 50.08 8887.98 5425.87 -3501.79 -4458.65 5669.40 231.85 11.83 SP None 42 12354.00 89.28 233.99 101.27 8888.13 5523.72 -3567.17 -4535.86 5770.51 231.82 8.49 SP None 43 12447.98 88.85 244.54 93.98 8889.67 5609.26 -3615.13 -4616.51 5863.56 231.94 11.23 SP None 44 12552.95 90.45 254.62 104.97 8890.31 5695.57 -3651.70 -4714.76 5963.54 232.24 9.72 SP None 45 12652.62 84.63 265.87 99.67 8894.60 5765.55 -3668.56 -4812.69 6051.47 232.68 12.69 SP None 46 12753.49 78.00 275.59 100.87 8909.86 5821.66 -3667.37 -4912.22 6130.21 233.26 11.57 SP None 47 12878.80 73.88 287.34 125.31 8940.40 5870.20 -3643.37 -5031.11 6211.78 234.09 9.67 SP None Projection to TD 48 12930.00 73.88 287.34 51.20 8954.62 5885.12 -3628.71 -5078.06 6241.33 234.45 0.02 MWD M None ~ [ (c) 2002 IDEAL ID8 OC 06] - - bp M-09B Survey Report - Geodetic puep Report Date: 20-Dec-03 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: Shared Services Drilling Vertical Section Azimuth: 215.000° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: M-PAD / M-09 TVD Reference Datum: MSL Well: M-09 TVD Reference Elevation: 0.000 ft relative to MSL Borehole: M-09B UWIIAPI#: 500292056302 Magnetic Declination: +25.860° Survey Name 1 Date: M-09B / December 20, 2003 Total Field Strength: 57526.634 nT Tort 1 AHD 1 DDI 1 ERD ratio: 503.219° / 6935.85 ft / 6.702 / 0.775 Magnetic Dip: 80.816° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: January 13, 2003 '~ Location Lat/Long: N 70.33715333, W 148.95964502 Magnetic Declination Model: BGGM 2002 Location Grid N/E Y/X: N 5973982.000 ftUS, E 628219.000 ftUS North Reference: True North Grid Convergence Angle: +0.97970299° Total Corr Mag North -> True North: +25.860° Grid Scale Factor: 0.99991868 Local Coordinates Referenced To: Well Head 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) (° 11 OOft) (ftUS) (ftUS) 10500.00 1.67 156.24 8511.61 3881.50 -2136.81 -3715.50 5971782.15 624540.89 N 70.33131322 W 148.98977923 10515.00 1.39 162.19 8526.60 3881.72 -2137.19 -3715.35 2.14 5971781.78 624541.04 N 70.33131220 W 148.98977806 10545.00 8.25 220.28 8556.49 3884.09 -2139.18 -3716.64 25.36 5971779.77 624539.79 N 70.33130676 W 148.98978845 10575.00 16.13 203.54 8585.80 3890.33 -2144.65 -3719.70 28.52 5971774.25 624536.82 N 70.33129181 W 148.98981326 10602.73 24.48 222.99 8611.81 3899.82 -2152.41 -3725.17 38.34 5971766.40 624531.48 N 70.33127061 W 148.98985761 10632.64 33.58 229.12 8637.94 3914.01 -2162.38 -3735.67 31.97 5971756.25 624521.15 N 70.33124336 W 148.98994276 10663.90 41.28 235.74 8662.76 3932.07 -2173.86 -3750.76 27.76 5971744.51 624506.27 N 70.33121196 W 148.99006508 10695.02 47.40 238.87 8685.00 3952.17 -2185.58 -3769.07 20.88 5971732.49 624488.16 N 70.33117994 W 148.9902135? 10725.63 56.10 239.04 8703.94 3974.11 -2197.96 -3789.65 28.43 5971719.75 624467.80 N 70.33114608 W 148.9903803&~ 10759.32 63.63 236.22 8720.84 4000.99 -2213.57 -3814.22 23.49 5971703.73 624443.50 N 70.33110340 W 148.99057959 10794.94 71.78 234.79 8734.34 4031.84 -2232.23 -3841.35 23.18 5971684.61 624416.69 N 70.33105239 W 148.99079956 10820.86 76.23 233.72 8741.48 4055.36 -2246.78 -3861.57 17.62 5971669.72 624396.73 N 70.33101260 W 148.99096345 10854.50 76.33 229.33 8749.47 4086.68 -2267.11 -3887.14 12.68 5971648.96 624371.51 N 70.33095704 W 148.99117081 10900.61 80.70 223.87 8758.65 4130.92 -2298.15 -3919.94 14.98 5971617.36 624339.25 N 70.33087219 W 148.99143668 10950.72 84.53 220.37 8765.09 4180.21 -2335.00 -3953.26 10.31 5971579.95 624306.57 N 70.33077147 W 148.99170670 10999.89 82.13 211.49 8770.82 4228.99 -2374.49 -3981.89 18.59 5971539.97 624278.62 N 70.33066353 W 148.99193875 11050.43 82.15 204.42 8777.74 4278.64 -2418.69 -4005.34 13.86 5971495.39 624255.93 N 70.33054276 W 148.99212877 11100.54 81.95 197.09 8784.68 4326.71 -2465.06 -4022.92 14.49 5971448.72 624239.15 N 70.33041604 W 148.99227111 M-09B ASP Final Surveys.xls Page 1 of 2 2/7/2003-1:32 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) (° /1 OOft) (ftUS) (ftUS) 11150.36 80.83 186.79 8792.15 4371.97 -2513.19 -4033.10 20.56 5971400.44 624229.79 N 70.33028456 W 148.99235348 11200.57 84.08 184.59 8798.75 4415.37 -2562.71 -4038.03 7.79 5971350.84 624225.71 N 70.33014926 W 148.99239325 11260.33 85.20 193.17 8804.34 4468.74 -2621.44 -4047.21 14.42 5971291.97 624217.54 N 70.32998881 W 148.99246744 11310.89 82.00 201.17 8809.98 4516.52 -2669.40 -4062.02 16.95 5971243.77 624203.55 N 70.32985776 W 148.99258732 11370.42 81.75 207.59 8818.41 4574.41 -2723.05 -4086.33 10.68 5971189.72 624180.16 N 70.32971116 W 148.99278425 11412.24 80.60 213.17 8824.83 4615.59 -2758.68 -4107.22 13.47 5971153.73 624159.89 N 70.32961377 W 148.99295349 11452.26 79.58 217.02 8831.72 4655.00 -2790.93 -4129.88 9.81 5971121.10 624137.79 N 70.32952563 W 148.99313710 11507.20 79.50 209. 14 8841.71 4708.95 -2836.16 -4159.34 14.10 5971075.37 624109.10 N 70.32940202 W 148.99337585 11553.71 82.00 202.94 8849.19 4754.27 -2877.39 -4179.47 14.21 5971033.82 624089.68 N 70.32928937 W 148.99353892 11603.36 84.78 196.84 8854.91 4801.85 -2923.74 -4196.24 13.43 597'0987.19 624073.71 N 70.32916271 W 148.99367466~ 11653.29 83.63 188.44 8859.96 4847.75 -2972.17 -4207.10 16.89 5970938.59 624063.68 N 70.32903040 W 148.99376253 11702.66 79.20 183.39 8867.33 4890.39 -3020.70 -4212.14 13.52 5970889.98 624059.47 N 70.32889782 W 148.99380319 11752.34 82.30 191.89 8875.33 4933.90 -3069.24 -4218.67 18.00 5970841.34 624053.77 N 70.32876519 W 148.99385590 11802.47 82.80 198.99 8881.84 4980.71 -3117.12 -4231.90 (14.08 5970793.24 624041.37 N 70.32863436 W 148.99396294 11857.45 88.75 202.19 8885.89 5033.79 -3168.42 -4251.17 12.28 5970741.63 624022.97 N 70.32849420 W 148.99411903 11899.55 89.75 202.99 8886.44 5074.90 -3207.28 -4267.34 3.04 5970702.50 624007.47 N 70.32838799 W 148.99424998 11949.58 87.75 207.59 8887.53 5124.18 -3252.49 -4288.70 10.02 5970656.93 623986.89 N 70.32826445 W 148.99442299 12002.83 86.60 212.72 8890.16 5177.16 -3298.46 -4315.4 1 9.86 5970610.51 623960.97 N 70.32813882 W 148.99463934 12053.30 87.10 209.49 8892.93 5227.43 -3341.61 -4341 .44 6.47 5970566.94 623935.69 N 70.32802091 W 148.99485022 12103.17 89.60 211.39 8894.37 5277.12 -3384.58 -4366.69 6.30 5970523.54 623911 . 18 N 70.32790348 W 148.99505479 12152.77 93.20 215.07 8893.16 5326.66 -3426.04 -4393.85 10.38 5970481 .62 623884.73 N 70.32779016 W 148.99527486 12202.65 94.10 220.74 8889.98 5376.36 -3465.30 -4424.42 11 .49 5970441.85 623854.84 N 70.32768285 W 148.99552255 12252.73 90.55 225.49 8887.95 5425.87 -3501.81 -4458.61 11.83 5970404.76 623821.28 N 70.32758305 W 148.99579959 12354.00 89.28 233.99 8888.10 5523.72 -3567.20 -4535.82 8.49 5970338.07 623745.21 N 70.32740430 W 148.99642535 12447.98 88.85 244.54 8889.63 5609.26 -3615.15 -4616.47 11.23 5970288.75 623665.39 N 70.32727315 W 148.99707912 12552.95 90.45 254.62 8890.28 5695.57 -3651.73 -4714.71 9.72 5970250.50 623567.80 N 70.32717307 W 148.99787556'~ 12652.62 84.63 265.87 8894.57 5765.55 -3668.59 -4812.65 12.69 5970231.97 623470.18 N 70.32712684 W 148.99866961 12753.49 78.00 275.59 8909.83 5821.66 -3667.39 -4912.17 11.57 5970231.47 623370.65 N 70.32712992 W 148.99947664 12878.80 73.88 287.34 8940.36 5870.20 -3643.40 -5031.07 9.67 5970253.43 623251.38 N 70.32719527 W 149.00044085 12930.00 73.88 287.34 8954.58 5885.12 -3628.74 -5078.02 0.00 5970267.28 623204.19 N 70.32723523 W 149.00082165 M-098 ASP Final Surveys.xls Page 2 of 2 2/7/2003-1 :32 PM l-r3s ~ II' ") WELL LOG TRANSMITTAL 'roActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7t11Street Suite # 700 Anchorage, Alaska 99501 aDd-d~{) II (c;~ Co RE: Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 13G9 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 M-09b 12/23/02 Mech. CH 1 Caliper Survey iigned: c~-~~- Date: 'rint Name: PRoAcTivE DiAGNOSTic SERviCES, INC., ~ 10 K STREET SuiTE 200, ANCHORAGE, AK 99~0 I Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memorylog.com Website: www.memorylog.com Pennits for M-09B CTD Sidetrack ) Subject: Permits for M-09B CTD Sidetrack Date: Mon, 18 Nov 2002 18:27:18 -0600 From: "Sherwood, Alistair" <SherwooA@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> z,o L - 2. 'La Winton, We are experiencing some well scheduling / preparation problem for CTD drilling, e.g. Z-30 which has a significant tubing obstruction. M-09B is a well we would like to slot in to take the place of Z-30L 1. I believe the 10-403 and 10-401 permits were sent out just last week by Mary Endacott. Would it be possible for you to turn around these permits by the end of this week? We would like to be in a position to move Nordic 2 over this well in 10 to 12 days. Regards M~ 01,8 . f" ., Alistair Shorwood Coil Tubing Dr\lling Engineer Greater Prudhoe Bay BP Exploration (Alaska) 900 E. Benson Blvd. Anchorage. +(907) 5ß44:mJ +(907) 440 3301 ) ~~!Æ:¡ :1J fÆ:IÆ~[«!Æ AIfASIiA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit M-09B BP Exploration (Alaska) Inc. Permit No: 202-220 Surface Location: 2373' SNL, 606' WEL, SEC. 01,TIIN, RI2E, UM Bottomhole Location: 825' SNL, 398' WEL, SEC. 11, TIIN, RI2E, UM Dear Ms. Endacott, Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does. not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit 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 terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ð~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 1'1!: day of November, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~A it /; If/" ~L.. ~ '\ STATE OF ALASKA . ..., ALASKA 0,... AND GAS CONSERVATION COMMI5_,bN PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 61.76' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028260 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number M-098 /' 9. Approximate spud d~ 12/06/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12930' MD I 8950' TVDss 17. Anticipated pressure {se..e 20 MC 25.035 (e) (2)} 95 0 Maximum surface 2280 Ipsig, At total depth (TVD) 8800' / 3220 psig Setting Depth Top Bottom Quantitv of Cement Lenath MD TVD MD TVD (include staQe data) 2680' 10250' 8263' 12930' 89501 73 cu ft Class 'G' /' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work 0 Drill III 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 2373' SNL, 606' WEL, SEC. 01 ,T11 N, R12E, UM At top of productive interval 45121 SNL, 4320' WEL, SEC. 01, T11N, R12E, UM At total depth 8251 SNL, 3981 WEL, SEC. 11, T11 N, R12E, UM 12. Distance to nearest property line 13. Distance to nearest well/, ADL 047451,44551 MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10517' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weiaht Grade Couplina 3-3/4" 3-3116" x 2-7/S" 6.2#/6.16# L-80 TC III ST-L 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 11136 feet 9209 feet 1 0687 feet 8760 feet Length Plugs (measured) Sand plug with cement cap (05-99) Junk (measured) See Diagram Size Cemented MD TVD 80' 80' 2684' 26841 7249' 66111 80' 20" X 30" 26841 13-3/8" 72491 9-5/8" 34111 7" 847' 4-1/2" 8 cu yds Concrete 3720 cu ft Permafrost II 1403 cu ft Class IGI, 130 cu ft PF 635 cu ft Class 'GI 125 cu ft Class 'G' 7076' - 104871 6463' - 8560' R £tEt\fE D363' - 92091 NOV 1 4 2002 Open: 10590' - 10640' Below Sand and Cement Plug: 10795' - 10884' true vertical Open: 8663' - 87131 AlasRa Oil:& Gas Gons. Commission Below Sand and Cement Plug: 8868' - 8957' AnchoraQe III Filing Fee 0 Property Plat III BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mary Endacott, 564-4388 Prepared By NamelNumber: Terrie Hubble, 564-4628 21. I hereby certify that th.~/1.e. f.O. re. '0. in. g. i_s,tr,~nd cr, r.r~~::.. ct, t.O.t,h, b.e,st. .O,.,.f my.. .kn.o..~I,e"..dge". . l.l/". t,4./02- Signed Mary Eoo.cott l f f'J1t>'/Z lIi ~ l{l M(;~,::s;~T ==nglneer Date, Permit Number API Number Approval Date See cover letter .z. ð ..:2- - 2.. Z. 0 50- 029-20563-02 11 J I q¡ (': ;). for other reauirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log R~qUlred 0 Yes f81 No Hydrogen Sulfide Measures ŒI Yes 0 No Directional Survey Required 181 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: 're c..l- ÐBlSM<SlöÑI!ÞW ç ,,1 . M L. Bill (\ ~rl~~sri~nrr \..) {'\.. , tel ~ i \t Perforation depth: measured 20. Attachments by order of the commission L,. ! Date II I /'i/~ ;¡ Submit In Triplicate Approved By Form 10-401 Rev. 12-01-85 , TREE=' ' WELLHEAD = 'ÃC'fUÃTÓR:; KB. ÊLÊV= . BF. ELEV = 6"CrN FMC BAKER 60.26' 27.76' 1'1.')098 PROPOSED SAFer' . )TES: CHROM E LNRS AND TBG ~ 2168" 1-1 4-1/2" HES SSSV LAND NIP, 10 = 3.813" I Max Angle ~ Datum MD = Datum ¡YO = ". '.. ,." "". 8800' SS - - =>-i 2600" l-i FOC I Minimum ID = 3.813" @ 10229' 4-1/2" HES X NIPPLE L ~ ST MD 6 3245 5 4779 4 6016 3 7056 2 8506 1 10160 GAS LIFT MANDRELS ¡yo DEV TYPE VLV LATCH PORT DATE 3139 26 TB DV RA 07/28/00 4470 35 TB DV RA 07/28/00 5489 34 TB DV RA 03/19/97 6358 32 KBG-2LS DV INT 03/19/97 7253 58 KBG-2LS DV INT 03/19/97 8181 27 KBG-2LS DV INT 03/19/97 13-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 2684" ~ I TOP OF 7" LNR 1-1 7076" ~ ~ 7076" 1-1 9-5/8" x 7" BKR HGRlPKR 1 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 9249" L~ 8 . 19-5/8" SIDETRACK WINDOW I - ~ 9249' - 9294' PERFORA TION SUMMARY g x- ""'~ 1,:1::,,:,: ')':':"It' \¡:!'I;,:::',j"i:II':::I;li.' ':":"1,1", ,),'::111\::' l ,:,:,~,',:: i"l"!""!;:'l. 4-112" TBG. 12.6#, CHROME. 0.0152 bpI, ID = 3.958" H 10295' I 11 ~~ "~-. ~., 1\ 7" LNR. 29#, L -80, CHROfvE. 0.0371 bpI, ID = 6.184" H 10487'. ...JI ¡¡¡i: ~11¡ ~ 10310' H 7" X 4-112" BKR HGRlA<R I !:f't,~ \~ï I ~~,HH TO~:::S: II. . ."~~~:~;":~-7/:~~-~~:~:B~:S~i:~:1~~'\ I 10845' H 4-112" HES X NIP, ID = 3.813" I ~ I PBTO H 12950' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPNISQZ DATE 2-7/8" 4 10590 -10620 2-7/8" 4 10620 -10640 2-7/8" 4 10795 -10815 2-7/8" 4 10840 -10855 . 2-7/8" 4 10864 -10884 2-7/8" 4 10864 -10884 I . 10229" - 4-1/2" HES X NIP, 10 = 3.813" 1 10239" - 7" X 4-1/2" BKR SABL PKR, 10 = 3.875" I 10250" - ffiOPOSED TOP OF 3 3/16" LINER I 10260" - 31/2" XN I I III I I I..J 11136" 1 J}IlI 4-1/2" LNR, 12.6#, CHROME, 0.0152 bpf, 10 = 3.958" I 1-1 DATE 1981 03/22/97 02/27/01 03/15/01 02/06/02 REV BY SIS-lsl SIS-MD RN/TP COMMENTS ORIGINAL COMRETION SIDETRACK COMPlETION CONVERTED TO CANVAS FINAL CORRECTIONS DATE REV BY COMMENTS 11/08/02 MSE PROPOSED CTD SIDETRACK ffiUDHOE BAY UNIT WB..L: M-09B PERMIT No: API No: 50-029-20563-02 SEC 1, T11N, R12E BP Exploration (Alas ka) ) BP M-09b CrD Sidetrack ) Summary of Operations: /' A CTD through tubing sidetrack is planned for M-09a. The coil sidetrack, M-09b, will exit the 4 1/2" liner in the Shublik formation and target Zone 4, Ivishak. \ \ '2- -...- . \\ Phase 1: Eline to set whipstock and plug assy ,. "'''''...') ~ ovJ Phase 2: Mill window, Drill and Complete sidetrack: Planned for D{;;:bet,S{2002. Drilling coil will be used to mill the window then drill and complete \b.eC1ffêêtional hole as per attached plan. Mud Program: Mill with seawater/biozan, 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 3 3/16" TC II x 2 7/Pi' - solid/slotted liner from TD to approx. 10,250'MD (-8263'TVDSS). Linerbonsai cement volume will a minimum 13 b ., bottom of cement at approximately 12,200ft. Well Control: . BOP diagram is attached. / . Pipe rams, blind rams and the CT pack off 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 95 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging An MWD Gamma Ray, Resistivity will be run over all of the open hole section. Memory CNL will be run inside the liner. Hazards ~,...... . H2S on M-09a measured 0 m 10/99. Max recorded H2S on M pad is 150ppm (M-15, 12/94) . Two fault crossings expe , risk of lost circulation is low to moderate. . Either Zone 3 conglomerate (hard drilling) or Shublik (losses or hole deterioration) could be encountered apon crossing faults . Kick off point in Shublik, chance of deteriorating hole condition - mitigated by angle of kick off minimizing what is exposed. Reservoir Pressure Res. press. is estim~d to be 3220 psi at -8800'ss (7.03 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2280 psi. BP Amoco LN1"EQ LEGEND M-09 (M-09) - M-09 (M-09A) - Plan#9 M-09B - Plan #9 T ^M 4 Azimuths to True North Plan: Plan #9 (M-09/Plan#9 M-09B) Magnetic North: 25.96° Created By: Brij Potnis Date: 9/23/2002 Stre~~~~~~~;~~~ Contact Information Dip ~n9Ie: 80.81° Direct: (907) 267-6613 Date: 9/23/2002 E-mail: brij.potnis@inteq.com Model: BGGM2002 Baker Hughes INTEQ: (907) 267-6600 PaN..t Wellp.thl Tie on MOl WIILLPATH OITAlLS PIa.. M-OI, 500282058302 M008A 10500.00 bp 11181 Nordic 1 11.71" tt.f. Datuml M-08A ItKB V.Sectlon O:IJ ~ ~~= ::::'"-&0 AnI.. 215.00' 0.00 0.00 0,00 -2100 - -I~~-¡--- ~--=- I M -09B Polygon9 1 REFERENCE INFORMATION Co-ordinate (NIE¡ Reference: Well Centre: M-09, True North V~~~r~~~~ ~:¡:~:~:: ~r~t~~~ ~~g8N~~Õ~)el Measured Depth Reference: M-09A RKB 61.76 Calculation Method: Minimum Curvature -2200 - -2300 - 1 10100.00 1.87 188.24 : ii5~i 1~~ i~* 8 10788.70 70.78 230.37 8 10880.13 82.00 230.37 ~ ~~m:u ;::~~ ;:¡:t: . 111ðO.13 80.88 181.81 101UN11.33 1..00 201.24 ~~~~~::= ::: =:~ 13 12830.00 15.22 222.80 ..cnoN DETAILS +NI-8 +EJ-W' DLe, TF8C. V8ec Y.,get 8511.81 .2138.7' -3711.85 0.00 0.00 3881.110 :iñ:ä: :i~n:H :~;~;::i J:5 2:~ is:! 8722.88 .2220.13 .3813.9 30.00 0.00 4005.98 :~:::;~ :~:;: ::::= ~~gg .~gg :m::: 8834.... .2788.18 -4143.48 12.00 100.00 4888.11 ..88..7 .3070.87 -42.'.82 12.00 --80.00 .N8.48 8888.1. .3280.87 --4281.28 12.00 as.OO 5131A5 ::::::: :~;:::: ~~:~ ~~= 1:::: ==::: 88a.88 -3728.'" -S073.37 12.00 .81.00 5984.45 -2400 - ANNOTATIONS TVD MD An.oiatlo.. 1511..1 10100.00 TIP 1121.30 10511.70 KOP 1141.21 10131.70 1 1571.01 105".70 2 1722"1 107".70 3 1744.11 10110.13 4 1783.31 11210.13 I ..34.14 11_,13 I ""A7 11710.13 7 "".74 11811.33 I 1"1.10 12131.01 8 ..10..1 12131.01 10 1141"1 12830.00 TD TVD +N/-S +EJJ.N Shape ~!~~,1 =:~ ~~.~ ~1H¡ er M.o9BT71 8885.00 -3397.76 -4388.09 Point M.Q98 BSHU 8885.00 -308923 -4297-79 Point ~=~~2 ~g:~ ~.~ ~gH~ ~: 7900::: 9/23/2002 -1:26 PM ~ ~ ) ') bp BP Baker Hughes INTEQ Planning Report 'N'1'~Q Company: BP Amoco Field: Prudhoe Bay Site: PB M Pad Well: M.;09 Wellpath: Plan#9 M-09B Date: ...9/23/2002 nine:. 16:26:46 Co..ordina~e(NE)Re(erence: Well:. M-09; True:. North yertif.:al(TVD)i{eference: 5:ystem:MeanSea:Level Secti?~(VS)Referenee:.. .. VVell(0~00N¡0.09E:.215.00Azi) SurveyCalcnlation Method: Minimum Curvature Db: Oracle Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: PB M Pad TR-11-12 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: M-09 M-09 Well Position: Well: 5971246.37 ft 626262.80 ft +N/-S 2702.55 ft Northing: 5973982.01 ft +E/-W 2002.13 ft Easting: 628219.00 ft Position Uncertainty: 0.00 ft Wellpath: Plan#9 M-09B 500292056302 Current Datum: M-09A RKB Magnetic Data: 9/23/2002 Field Strength: 57521 nT Vertical Section: Depth From (TVD) ft 0.00 Targets Description Dip. Dir. M-09B Polygon9.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 Name M-09B TZ3 M-09B F1 TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Height 61.76 ft +N/-S ft 0.00 +N/'-S ft -2171.18 -2171.18 -3070.10 -3399.74 -3634.27 -3826.21 -3735.66 -3663.50 -2448.54 -2189.65 -2032.11 +E/~W ft -4230.08 -4230.08 -4305.4 7 -4506.15 -5180.31 -5127.58 -4865.97 -4289.61 -3978.76 -3676.27 -3764.60 Map Zone: Coordinate System: Geomagnetic Model: Page: Alaska, Zone 4 Well Centre BGGM2002 Latitude: Longitude: North Reference: Grid Convergence: 70 19 47.175 N 148 58 33.196 W True 0.96 deg Slot Name: 09 Latitude: Longitude: 70 20 13.752 N 148 57 34.722 W Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 l\tlp M:~P Northing Easting ft ft 5971739.00 624027.00 5971739.00 624027.00 5970839.00 623966.99 5970506.00 623771.99 5970260.00 623102.00 5970069.00 623158.00 5970164.00 623418.00 5970246.00 623992.99 5971466.00 624283.00 5971730.00 624581.00 5971886.00 624489.99 M-09A 10500.00 ft Mean Sea Level 25.96 deg 80.81 deg Direction deg 215.00 <:~-Latitude~-> ~.-,.LongiWde -~> Deg Mill < ~ec DegMJnSec 70 19 52.387 N 70 19 52.387 N 70 19 43.546 N 70 19 40.303 N 70 19 37.992 N 70 19 36.104 N 70 19 36.997 N 70 19 37.710 N 70 19 49.660 N 70 19 52.208 N 70 19 53.757 N 148 59 38.230 W 148 59 38.230 W 148 59 40.416 W 148 59 46.269 W 149 0 5.944 W 149 0 4.401 W 148 59 56.766 W 148 59 39.943 W 148 59 30.887 W 148 59 22.060 W 148 59 24.641 W 8790.00 -2452.04 -4124.86 5971460.00 624137.00 70 1949.625 N 148 59 35.153 W 8820.00 -2629.00 -4304.93 5971280.00 623960.00 70 19 47.884 N 148 59 40.407 W M-09B T7.1 M-09B BSHU 8885.00 -3397.76 -4388.09 5970510.00 623890.00 70 19 40.323 N 148 59 42.822 W 8885.00 -3089.23 -4297.79 5970820.00 623975.00 70 19 43.358 N 148 59 40.191 W M-09B F2 8895.00 -3098.29 -4352.96 5970810.00 623920.00 70 19 43.268 N 148 59 41.802 W M-09B T9.2 8950.00 -3745.94 -5084.20 5970150.00 623200.00 70 19 36.894 N 149 0 3.136 W Annotation MD ft 10500.00 10516.70 10536.70 TVD ft 8511.61 8528.30 8548.29 TIP KOP 1 ) BP ') Baker Hughes INTEQ Planning Report BP Amoco Date: 9/23/2002 Time: ..t6:26:46 Page: 2 Prudhoe Bay Co-ørdinate(NE).Reference: Well: M.;Q9,. True North PB M Pad V~~cal (TVD)Refe~nçe: Syst~ITI:M~nSeal~v~1 M-09 Section (VS) Reference: Welr(O~OON.O,00E.215;00Azi). Wellpath: Plan#9 M..098 Survey (;alcubltion Method: Minimum. Curvature Db: Oracle Annotation MD TVD ft ft 10566.70 8578.06 2 10766.70 8722.66 3 10860.13 8744.61 4 11210.13 8793.31 5 11460.13 8834.54 6 11760.13 8889.47 7 11961.33 8896.74 8 12139.06 8888.90 9 12539.06 8910.89 10 12930.00 8949.58 TO Plan: Plan #9 Date Composed: 9/23/2002 New TO & Polygon Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD loci Azim TVD +N/..S +E/..W DLS . Build Turn TFO Target ft deg deg ft ft ft degftOOtt deg/H)Oft deg/100ft deg 10500.00 1.67 156.24 8511.61 -2136.78 -3715.55 0.00 0.00 0.00 0.00 10516.70 1.62 152.25 8528.30 -2137.21 -3715.34 0.75 -0.30 -23.89 244.43 10536.70 2.96 184.00 8548.29 -2137.97 -3715.25 9.00 6.72 158.76 60.00 10566.70 10.79 230.37 8578.06 -2140.54 -3717.47 30.00 26.08 154.55 60.00 10766.70 70.79 230.37 8722.66 -2220.13 -3813.56 30.00 30.00 0.00 0.00 10860.13 82.00 230.37 8744.61 -2277.96 -3883.38 12.00 12.00 0.00 0.00 11210.13 82.73 187.98 8793.31 -2573.78 -4048.40 12.00 0.21 -12.11 -92.00 11460.13 78.71 218.12 8834.54 -2798.16 -4143.46 12.00 -1.61 12.06 100.00 11760.13 80.89 181.59 8889.47 -3070.97 -4241.62 12.00 0.73 -12.18 -90.00 11961.33 95.00 201.24 8896.74 -3266.57 -4281.26 12.00 7.01 9.77 55.00 12139.06 90.00 222.00 8888.90 -3416.87 -4373.87 12.00 -2.81 11.68 102.95 12539.06 84.06 269.72 8910.89 -3575.88 -4727.55 12.00 -1.48 11.93 98.00 12930.00 85.22 222.60 8949.58 -3728.84 -5073.37 12.00 0.30 -12.05 -91.00 Survey Incl Azim SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft .ft ft degl100tt deg 10500.00 1.67 156.24 8511.61 -2136.78 -3715.55 5971782.19 624540.82 3881.50 0.00 0.00 TIP 10516.70 1.62 152.25 8528.30 -2137.21 -3715.34 5971781.76 624541.04 3881.73 0.75 244.43 KOP 10525.00 2.10 170.23 8536.60 -2137.46 -3715.26 5971781.51 624541.12 3881.89 9.00 60.00 MWD 10536.70 2.96 184.00 8548.29 -2137.97 -3715.25 5971781.00 624541.15 3882.31 9.00 42.03 1 10550.00 6.04 218.92 8561.55 -2138.86 -3715.71 5971780.10 624540.70 3883.30 30.00 60.00 MWD 10566.70 10.79 230.37 8578.06 -2140.54 -3717.47 5971778.39 624538.97 3885.68 30.00 25.17 2 10575.00 13.28 230.37 8586.18 -2141.65 -3718.80 5971777.27 624537.66 3887.35 30.00 360.00 MWD 10600.00 20.78 230.37 8610.07 -2146.31 -3724.44 5971772.50 624532.10 3894.41 30.00 0.00 MWD 10625.00 28.28 230.37 8632.80 -2152.93 -3732.42 5971765.75 624524.23 3904.41 30.00 0.00 MWD 10650.00 35.78 230.37 8653.98 -2161.38 -3742.63 5971757.13 624514.17 3917.18 30.00 360.00 MWD 10675.00 43.28 230.37 8673.24 -2171.52 -3754.87 5971746.78 624502.10 3932.51 30.00 360.00 MWD 10700.00 50.78 230.37 8690.27 -2183.18 -3768.95 5971734.88 624488.23 3950.14 30.00 0.00 MWD 10725.00 58.28 230.37 8704.77 -2196.16 -3784.62 5971721.64 624472.78 3969.76 30.00 0.00 MWD 10750.00 65.78 230.37 8716.49 -2210.23 -3801.61 5971707.28 624456.04 3991.03 30.00 360.00 MWD 10766.70 70.79 230.37 8722.66 -2220.13 -3813.56 5971697.18 624444.26 4005.99 30.00 360.00 3 10775.00 71.78 230.37 8725.33 -2225.14 -3819.61 5971692.07 624438.30 4013.57 12.00 0.00 MWD 10800.00 74.78 230.37 8732.52 -2240.41 -3838.05 5971676.49 624420.12 4036.65 12.00 0.00 MWD 10825.00 77.78 230.37 8738.44 -2255.90 -3856.75 5971660.68 624401.69 4060.07 12.00 0.00 MWD 10850.00 80.78 230.37 8743.09 -2271.57 -3875.67 5971644.69 624383.05 4083.75 12.00 0.00 MWD 10860.13 82.00 230.37 8744.61 -2277.96 -3883.38 5971638.17 624375.44 4093.41 12.00 0.00 4 10875.00 81.94 228.57 8746.68 -2287.53 -3894.57 5971628.42 624364.42 4107.67 12.00 268.00 MWD 10900.00 81.86 225.54 8750.21 -2304.39 -3912.69 5971611.25 624346.60 4131.87 12.00 268.25 MWD 10925.00 81.80 222.51 8753.76 -2322.18 -3929.88 5971593.17 624329.71 4156.31 12.00 268.68 MWD ) BP ) .... -- Baker Hughes INTEQ Planning Report I~t'áij Company: BP Amoco Date: 9/23/2002 Tbne: .16:26:46 Page: 3 Field: Prudhoe Bay Ço-'ô..d¡nate(NE).R~fel'en(ë: Well:M~ TrueNQrth Site: PB M Pad Ve~c.1 ('I:VD);l{eference: $Y$~em:M~ri SeaLë.ÿel. Well: M-09 . Sec~ion(VS):Reference: Well {0,QQN;O,00E.?15.0QA2:iJ Wellp~th: Plan#9 M';09B Sürveý.CaJculatiou.Metbod: Minimtmi. CUrvature Db: Oraclé Survey MD IneI Azim SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft dèg/tOOft deg 10950.00 81.77 219.48 8757.33 -2340.86 -3946.11 5971574.22 624313.81 4180.91 12.00 269.11 MWD 10975.00 81.76 216.44 8760.92 -2360.36 -3961.33 5971554.46 624298.92 4205.62 12.00 269.54 MWD 11000.00 81.77 213.41 8764.50 -2380.64 -3975.49 5971533.94 624285.11 4230.36 12.00 269.98 MWD 11025.00 81.80 210.38 8768.07 -2401.65 -3988.56 5971512.71 624272.40 4255.06 12.00 270.41 MWD 11050.00 81.85 207.35 8771.63 -2423.32 -4000.51 5971490.85 624260.83 4279.66 12.00 270.84 MWD 11075.00 81.93 204.32 8775.16 -2445.59 -4011.29 5971468.39 624250.43 4304.09 12.00 271.28 MWD 11100.00 82.03 201.29 8778.64 -2468.41 -4020.89 5971445.42 624241.22 4328.29 12.00 271.70 MWD 11125.00 82.15 198.27 8782.08 -2491.71 -4029.27 5971421.98 624233.24 4352.18 12.00 272.13 MWD 11150.00 82.30 195.24 8785.47 -2515.42 -4036.41 5971398.15 624226.51 4375.70 12.00 272.54 MWD 11175.00 82.46 192.22 8788.78 -2539.49 -4042.29 5971373.99 624221.04 4398.79 12.00 272.95 MWD 11200.00 82.65 189.20 8792.02 -2563.84 -4046.90 5971349.56 624216.85 4421.38 12.00 273.35 MWD 11210.13 82.73 187.98 8793.31 -2573.78 -4048.40 5971339.60 624215.52 4430.38 12.00 273.74 5 11225.00 82.42 189.75 8795.23 -2588.35 -4050.67 5971325.00 624213.50 4443.62 12.00 100.00 MWD 11250.00 81.92 192.74 8798.64 -2612.64 -4055.50 5971300.63 624209.09 4466.29 12.00 99.77 MWD 11275.00 81.45 195.73 8802.25 -2636.61 -4061.58 5971276.56 624203.42 4489.41 12.00 99.36 MWD 11300.00 80.99 198.73 8806.07 -2660.21 -4068.90 5971252.84 624196.50 4512.94 12.00 98.93 MWD 11325.00 80.56 201.74 8810.08 -2683.36 -4077.43 5971229.55 624188.37 4536.80 12.00 98.47 MWD 11350.00 80.16 204.76 8814.26 -2706.00 -4087.16 5971206.75 624179.03 4560.93 12.00 97.99 MWD 11375.00 79.78 207.78 8818.62 -2728.07 -4098.05 5971184.49 624168.51 4585.25 12.00 97.49 MWD 11382.75 79.67 208.72 8820.00 -2734.80 -4101.67 5971177.71 624165.02 4592.83 12.00 96.96 M-09B F' 11400.00 79.43 210.81 8823.13 -2749.52 -4110.08 5971162.85 624156.85 4609.72 12.00 96.79 MWD 11425.00 79.11 213.84 8827.78 -2770.27 -4123.22 5971141.87 624144.08 4634.25 12.00 96.41 MWD 11450.00 78.82 216.89 8832.57 -2790.28 -4137.42 5971121.63 624130.23 4658.79 12.00 95.85 MWD 11460.13 78.71 218.12 8834.54 -2798.16 -4143.46 5971113.64 624124.31 4668.71 12.00 95.27 6 11475.00 78.72 216.30 8837.45 -2809.77 -4152.28 5971101.88 624115.70 4683.28 12.00 270.00 MWD 11500.00 78.75 213.24 8842.33 -2829.91 -4166.26 5971081.51 624102.06 4707.80 12.00 270.36 MWD 11525.00 78.82 210.18 8847.20 -2850.77 -4179.15 5971060.43 624089.53 4732.28 12.00 270.95 MWD 11550.00 78.91 207.13 8852.03 -2872.29 -4190.91 5971038.72 624078.14 4756.65 12.00 271.55 MWD 11575.00 79.04 204.07 8856.81 -2894.42 -4201.52 5971016.41 624067.92 4780.86 12.00 272.14 MWD 11600.00 79.20 201.02 8861.53 -2917.09 -4210.93 5970993.59 624058.90 4804.83 12.00 272.72 MWD 11625.00 79.39 197.98 8866.17 -2940.24 -4219.13 5970970.30 624051.10 4828.50 12.00 273.30 MWD 11650.00 79.60 194.93 8870.73 -2963.82 -4226.09 5970946.61 624044.54 4851.80 12.00 273.86 MWD 11675.00 79.85 191.89 8875.19 -2987.74 -4231.79 5970922.60 624039.25 4874.67 12.00 274.42 MWD 11700.00 80.12 188.86 8879.54 -3011.95 -4236.23 5970898.31 624035.23 4897.05 12.00 274.96 MWD 11725.00 80.42 185.83 8883.76 -3036.39 -4239.38 5970873.83 624032.50 4918.87 12.00 275.49 MWD 11732.47 80.52 184.93 8885.00 -3043.73 -4240.07 5970866.48 624031.93 4925.28 12.00 276.00 M-09B BS 11750.00 80.75 182.81 8887.85 -3060.98 -4241.24 5970849.21 624031.06 4940.08 12.00 276.15 MWD 11760.13 80.89 181.59 8889.47 -3070.97 -4241.62 5970839.22 624030.85 4948.49 12.00 276.50 7 11775.00 81.92 183.06 8891.69 -3085.66 -4242.22 5970824.52 624030.50 4960.86 12.00 55.00 MWD 11800.00 83.65 185.53 8894.83 -3110.39 -4244.07 5970799.76 624029.07 4982.19 12.00 54.78 MWD 11825.00 85.40 187.98 8897.22 -3135.10 -4247.00 5970775.01 624026.56 5004.11 12.00 54.47 MWD 11850.00 87.16 190.41 8898.84 -3159.73 -4250.99 5970750.32 624023.00 5026.56 12.00 54.24 MWD 11875.00 88.92 192.84 8899.69 -3184.20 -4256.02 5970725.77 624018.38 5049.50 12.00 54.08 MWD 11900.00 90.68 195.27 8899.78 -3208.45 -4262.09 5970701.42 624012.73 5072.84 12.00 53.99 MWD 11925.00 92.45 197.70 8899.10 -3232.41 -4269.18 5970677 .35 624006.05 5096.54 12.00 53.99 MWD 11950.00 94.21 200.13 8897.65 -3256.01 -4277.27 5970653.61 623998.36 5120.51 12.00 54.05 MWD 11961.33 95.00 201.24 8896.74 -3266.57 -4281.26 5970642.98 623994.56 5131.45 12.00 54.19 8 11975.00 94.63 202.84 8895.59 -3279.20 -4286.37 5970630.27 623989.66 5144.73 12.00 102.95 MWD 12000.00 93.95 205.77 8893.72 -3301.92 -4296.64 5970607.38 623979.79 5169.22 12.00 103.08 MWD 12025.00 93.25 208.70 8892.15 -3324.10 -4308.05 5970585.01 623968.75 5193.94 12.00 103.30 MWD 12050.00 92.55 211.62 8890.89 -3345.69 -4320.60 5970563.21 623956.58 5218.82 12.00 103.49 MWD 12075.00 91.84 214.53 8889.93 -3366.62 -4334.23 5970542.05 623943.31 5243.78 12.00 103.63 MWD BP ") 8ií8 -- Baker Hughes INTEQ Planning Report _...--.-----..-.----.~- IN}' EQ Company: BP.Amoco Dàte~ 9/23/2002 Time: 16:26:46 Page: 4 Field: Prudhoe Bay C(}.{)r(iinate(NE) J,tefereuce: "Yelt M"09, True North Site: PBM.Pad Vertical (TVD) Referellce: System:.Me~nSea Ll;}vel Well: M~09 ~eet:ion (YS)Refei'ence: Wéll(O.OON,0:gOE,215.00A?i) WeUpath: Plán#9. M~09B Surl'eyCalCtdatIoÏl Më~9d~ MioimumCurvature Db: Oracle Survey MD lucl Azim SSTVD N/S E/W MapN MapE. VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/1OOft des 12100.00 91.12 217.45 8889.28 -3386.84 -4348.91 5970521.59 623928.98 5268.77 12.00 103.74 MWD 12125.00 90.40 220.36 8888.95 -3406.29 -4364.61 5970501.87 623913.62 5293.71 12.00 103.82 MWD 12139.06 90.00 222.00 8888.90 -3416.87 -4373.87 5970491.13 623904.54 5307.68 12.00 103.86 9 12150.00 89.82 223.30 8888.92 -3424.92 -4381.28 5970482.96 623897.27 5318.53 12.00 98.00 MWD 12175.00 89.40 226.27 8889.09 -3442.66 ~4398.89 5970464.92 623879.97 5343.16 12.00 98.00 MWD 12200.00 88.98 229.24 8889.44 -3459.46 -4417.39 5970447.81 623861.75 5367.54 12.00 97.98 MWD 12225.00 88.57 232.21 8889.98 -3475.28 -4436.74 5970431.66 623842.68 5391.59 12.00 97.94 MWD 12250.00 88.16 235.19 8890.69 -3490.07 -4456.88 5970416.53 623822.80 5415.26 12.00 97.87 MWD 12275.00 87.76 238.16 8891.58 -3503.80 -4477.75 5970402.45 623802.17 5438.48 12.00 97.79 MWD 12300.00 87.36 241 .14 8892.64 -3516.42 ~4499.30 5970389.47 623780.84 5461.17 12.00 97.68 MWD 12325.00 86.97 244.12 8893.88 -3527.90 -4521.47 5970377.61 623758.87 5483.29 12.00 97.56 MWD 12350.00 86.59 247.10 8895.28 -3538.20 ~4544.20 5970366.92 623736.32 5504.77 12.00 97.41 MWD 12375.00 86.22 250.08 8896.85 -3547.31 -4567.43 5970357.41 623713.25 5525.56 12.00 97.24 MWD 12400.00 85.85 253.06 8898.58 -3555.19 -4591.09 5970349.13 623689.74 5545.58 12.00 97.05 MWD 12425.00 85.50 256.05 8900.47 -3561.83 -4615.11 5970342.08 623665.83 5564.80 12.00 96.85 MWD 12450.00 85.16 259.04 8902.50 -3567.20 -4639.44 5970336.29 623641.60 5583.16 12.00 96.62 MWD 12475.00 84.83 262.04 8904.68 ~3571.30 -4664.01 5970331.78 623617.11 5600.60 12.00 96.38 MWD 12qOO.00 84.52 265.03 8907.00 -3574.10 -4688.74 5970328.56 623592.43 5617.08 12.00 96.12 MWD 12525.00 84.22 268.03 8909.45 -3575.60 -4713.57 5970326.63 623567.63 5632.55 12.00 95.84 MWD 12539.06 84.06 269.72 8910.89 -3575.88 -4727.55 5970326.12 623553.66 5640.80 12.00 95.54 10 12550.00 84.04 268.40 8912.02 ~3576.06 ~4738.43 5970325.75 623542.78 5647.19 12.00 269.00 MWD 12575.00 84.01 265.39 8914.63 -3577.40 ~4 763.25 5970323.98 623517.99 5662.53 12.00 269.14 MWD 12600.00 83.98 262.37 8917.24 -3580.06 -4787.97 5970320.91 623493.32 5678.88 12.00 269.45 MWD 12625.00 83.98 259.35 8919.86 -3584.00 ~4812.52 5970316.54 623468.85 5696.19 12.00 269.77 MWD 12650.00 83.99 256.34 8922.48 -3589.24 -4836.82 5970310.89 623444.64 5714.42 12.00 270.08 MWD 12675.00 84.02 253.32 8925.09 -3595.75 ~4860.81 5970303.98 623420.77 5733.51 12.00 270.40 MWD 12700.00 84.07 250.30 8927.69 -3603.51 ~4884.43 5970295.81 623397.28 5753.41 12.00 270.71 MWD 12725.00 84.13 247.29 8930.26 -3612.50 -4907.61 5970286.42 623374.26 5774.08 12.00 271.03 MWD 12750.00 84.21 244.27 8932.80 -3622.70 -4930.29 5970275.84 623351.76 5795.44 12.00 271.34 MWD 12775.00 84.30 241.26 8935.30 -3634.08 -4952.41 5970264.08 623329.85 5817.45 12.00 271.64 MWD 12800.00 84.41 238.25 8937.76 -3646.61 -4973.90 5970251.19 623308.58 5840.04 12.00 271.94 MWD 12825.00 84.54 235.24 8940.17 -3660.26 ~4994. 70 5970237.19 623288.01 5863.15 12.00 272.24 MWD 12850.00 84.68 232.23 8942.52 -3674.98 -5014.77 5970222.13 623268.20 5886.72 12.00 272.53 MWD 12875.00 84.83 229.22 8944.81 -3690.74 -5034.04 5970206.04 623249.21 5910.68 12.00 272.81 MWD 12900.00 85.00 226.21 8947.02 -3707.49 ~5052.45 5970188.98 623231.08 5934.97 12.00 273.09 MWD 12925.00 85.18 223.20 8949.16 -3725.19 -5069.98 5970170.98 623213.86 5959.52 12.00 273.36 MWD 12930.00 85.22 222.60 8949.58 ~3728.84 -5073.37 5970167.27 623210.53 5964.45 12.00 273.61 TO .....,~.....,.~.., 114TurnLTValve I I'" I I' .. . .. "~,'::':':':':':':':""-""'r:t_.~.........^..........1 7 1/16" SCOOps; RX I ~ . . .. .........I":'f'þ'::41: ~ ............... ~ I~~~,:,I.. @ OJ IH;R [ . . ~ I \ I Kill Line I t ~ r ::::::::::: 1 l:t:/:§h9:~~A~~:ne I -- "', :~~j~~j~~j¡: :I~t: 1 I '11VBötéR~J~ 21/16"SOOOpsi,RX-24 I :II¡j . I : ~~~:~~I I 1I@ ~ 1 I I TOT. 7 1/16" 5000 psi (RX-46) or 'I' " , ..I .- 4 1/16" 5000 psi (RX-39) um::J::~:. ~ ~:¡~r J"~ 1 ') I ~~1I1t1-0~ql 1 Rig Floor I I I 13" 5000 Psi ....-_n....... ....... ~ Tree Size I BOP-Tree NORD,¿ 2-/ 1 I, WllJ ~~ I KB Elevation .. ~::::::,:::::::::::::::::::::::::::::::::::::::::I Lubricator 10 = 6.375" with 6" Otis Unions J:J¿)0m\~"J 17 1/16" 5000 psi BOP's. 10 = 7.06" I ~:~:i:~:i:~:i:~:::~r:::~:rrl.... 171/16" 5000 psi, RX-46 - ænd~ Swab Valve I - :t m. .: :.J, :FIoWTee,:~~- ... I -. .1../ l ": !". ..: "..LLu¡11~¡~~~L"IIJ 1-+ r; <r~-- ~~¿j I ssv . ~g I --m,m,,,,'II,.,J 1 Master Valve I I [()IJ1"_"m.",, ..... . . ]]OJ ~ """'-''-'"'' ""''''''''''''''-' .- ... ": I r------- Base Flange I Page 1 DATE CHECK NO. H 207129 INVOICE I CREDIT MEMO GROSS 9/20/02 VENDOR DISCOUNT H207129 DATE DESCRIPTION NET H 9/20/02 INV# CK091602E PERMIT TO DRILL FEE fA Jcfl8 RECE\VED NOV 1 4 2002 Atas\ta OU& Gas Cor s. comm\ss\Otì AnchOf&ge .~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND. OHIO No.H 207129 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 --¡.j2 -~ PAY 8 ft... .~. "'?"r.'" I.'.I.U~ 1."/11. .""1' .......~. Þ 'ii,- J .... . ¡J. f ~ .t..< 'tt~' ... . ........ . Ûû'" (tII' ¡liP .'mu flm., H'" AMOUNT "11:***$100.00**** TO THE ALASKA OID& GAS CQNSERVATION ORDER 333 W. 7th AVE ,iSTE100 OF ANCIIORAGE, AK 99501 ~1(t~~1'if:'~~~1.~~;:~i.:;\ZG: :uu':":.::1IÆ~~::~~';"'I'''''''«: .....::....~:..... 1;;{~{~::\¿¡~~;;';:;~::;2£ III 2 0 ? ~ 2 q III I: 0... ~ 2 0 j a q 5 I: 0 0 a ...... ~ q III ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /ß/Á l1-o'1¿ PTD# 202- - 2--2:-.0 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 Rev: 07110/02 C\jody\templates "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(1), 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 (SO 70/80) from records, data and logs acquired for well (name on permit). . The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate 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. WELL PERMIT CHECKLIST COMPANY ð/.Jc WELL NAME;f'Au /f -09/1 FIELD & POOL 6':7'(")/5 ð INIT CLASS Ó~u / - c:f),/ ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. . . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . ".)-1.. / 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . ~ ~2- 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 w/in area & strata authorized by injection order #- (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. ENGINEERING APPR DATE APPR DATE \#JG,A- tl/IC¡!t91- (Service Well Only) GEOLOGY APPR DATE /it ~/¿S¿ (ExploréÍtó'"rŸ Only) 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 wellbore 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; testto 3'5'00 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 wells 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. . . . . . . . PROGRAM: Exp - Dev £. Redrl~ Re-Enter - Serv - Wellbore seg - GEOL AREA ?/7/? UNIT# II C.> ð ON/OFF SHORE ~ fY'tN , ~J N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~ N .0 .l'AA, @N d)N .¥--N- Ai lit- G?~ ~~ cr Du..- Alovd t. *Q ~ ~~ fI1ÞJ 1l.7 ffj' ~~f11SP 't2ðO P!¡/o ~~ "iON ~tr:J ppWl. .~ I'I/¡f- Y~ n ) )- GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Comments/Instructions: RP~ TEM JDH JBR COT "I/~/o{c DTS 11/ I~ OZ WGA / MJW MLB IY/1- /,'2. Rev: 10/15/02 SFD- G:\geology\perm its\checklist.doc
