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Home My WebLink About201-218MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 04-19A PRUDHOE BAY UNIT 04-19A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 04-19A 50-029-21791-01-00 201-218-0 W SPT 7609 2012180 1902 1616 1616 1616 1616 171 392 385 382 4YRTST P Matt Herrera 6/4/2022 4 Year MIT-IA Performed to 2400 PSI Per Operations 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 04-19A Inspection Date: Tubing OA Packer Depth 372 2424 2365 2359IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220604121924 BBL Pumped:2 BBL Returned:2 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 16:50:50 -08'00' *tit 011-160 PM 26!Z03o Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep [AKOPSFFWellOpsCompRep @bp.com] Sent: Tuesday, June 04, 2013 12:01 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay 113 Subject: FW: PBU/East Area/FS2/04 defeated pilots � l% Mr. Regg, Here is the info you requested on the DS-4 water injectors that were temporarily SI yesterday for pigging operations. Well PTD 04-06 1760830 04-08 1760100 04-10 1760420 04-13 1780310 04-15 1780370 0419 2012180 SCANNED 04-20 1831190 04-25 1860490 04-27 1852950 04-45 1940340 I apologize for the time delay since the initial email was sent. I will have this data available for future notification emails since I now know it is required. Thank you, Lee Hulme From: AK, OPS FS2 DS Ops Lead Sent: Tuesday, June 04, 2013 8:35 AM To: AK, OPS FF Well Ops Comp Rep Cc: AK, OPS FS2 Facility OTL; AK, OPS FS2 OSM Subject: RE: PBU/East Area/FS2/04 defeated pilots Lee, All of the PWI wells are gagged during pigging operations in order to prevent inadvertent blocked flow and a stuck pig.— This is how we always pig and how we will always pig every week in the future. It is a manned operation. The wells gagged yesterday were DS4-6,8,10,13,15,20,25,27,19,45. Rpn White Ak, Ops FS2 DS Lead 907-659-5493 Alt: James Berndt From: AK, OPS FF Well Ops Comp Rep Sent: Tuesday, June 04, 2013 7:43 AM To: AK, OPS FS2 DS Ops Lead Cc: Regg, James B (DOA); Redmond, Randy; AK, OPS FF Well Ops Comp Rep 1 • Subject: FW: PBU/East Area/FS2/04 defeated pilots Importance: High Ron, Please supply me with a list of the water injectors on DS-04 that were defeated during the pigging operations yesterday so I can look up the PTD numbers and pass on to Mr. Regg. Thanks, Lee From: Regg, James B (DOA) [mailto:jjm.reggOalaska.gov] Sent: Monday, June 03, 2013 9:08 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU/East Area/FS2/04 defeated pilots Our approvsl only covers injectors. And yes, I want a record of the injectors involved. Particularly since it is DS 4. Sent from Samsung Mobile Original message From: "AK, OPS FF Well Ops Comp Rep" <AKOPSFFWellOpsCompRep @bp.com> Date: 06/03/2013 6:32 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg(_�alaska.gov> Subject: RE: PBU/East Area/FS2/04 defeated pilots Mr. Regg, I just called the FS2 Field Lead Tech and he told me the pigging operation is completed and the temporary defeat for PWI wells has been lifted. It will take some research to determine which wells were involved since the DSD log blanketed the whole pad. I can get this data tomorrow if you still want it. Please advise. Lee Hulme FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony-7187 (Alternate: Ryan J Hayes) From: Regg, James B (DOA) [mailto:jim.reggOalaska.gov] Sent: Monday, June 03, 2013 5:01 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU/East Area/FS2/04 defeated pilots Please identify wells and PTD for each. Jim Regg AOGCC 2 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWeIIOpsCompRep @bp.com] Sent: Monday, June 03, 2013 4:25 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Redmond, Randy; AK, D&C Well Integrity Coordinator; Bill, Michael L (ASRC); Starck, Jennifer L; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, RES GPB East Wells Opt Engr Subject: PBU/East Area/FS2/04 defeated pilots Dear Mr. Regg, Per AOGCC waiver dated 3/11/13, PBU Oil Pool Low Pressure Water Injectors, BPXA is providing notification that wells on DS-04 are now operating with its SVS defeated as of 6/3/13 for pigging operations. Per the wavier, BPXA has tagged and logged the defeated components, and will notify AOGCC once the SVS is returned to service. Please contact me with any questions. Thank you, Lee Hulme FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony—7187 (Alternate: Ryan J Hayes) 3 Schlumberger RECEIVED NO. 3980 OCT 0 4 2006 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 GambeU Street, Suite 400 Anchorage, AK 99503·2838 ATTN: Beth ~I<a OH & Gas ConS. Cc~$ÍCn Aslchcrage Field: Prudhoe Bay Well Job# Loa DescriDtion Date BL Color CD L5-28A 11320994 STATIC PRESSURE LOG 07/30/06 1 P2-50B 11212876 LDL 07/17/06 1 H-26 11225990 LDL 07/09/06 1 K-02D 11209593 SCMT 07/20/06 1 J-09A 11321005 LDL 08/29/06 1 D.S.04-19A N/A INJECTION PROFILE 08/02/06 1 J-06 11321006 PRODUCTION PROFILE 08/29/06 1 G-24 N/A SCMT 08/08/06 1 2-18/L-16 11225986 LDL 07/04/06 1 F·05A 11216212 MCNL 09/03/06 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Surte 400 Anchorage, AK 99503-2838 ATTN: 8eth "~r~NM ;:j~ft.~'\JEw, it I: u.:c c.. 'döl-é)I1Ç ,~ 10/02/06 . . . JIG r/:2-5/~ . RECE\VED STATE OF ALASKA 2006 ALASKA Oil AND GAS CONSERVATION COMMISSION SEP 2 2 REPORT OF SUNDRY WELL OPERA TAONS& Gas Cons. Commission . oft 1. Operations Performed: Abandon 0 Repair Well 0 Plus:¡ PerforationsD Stimulate 0 OtherD Alter CasingO Pull TubingD Perforate New PoolO WaiverO Time ExtensionO Change Approved Program 0 Operation ShutdownD Perforate 00 Re-enter Suspended WellO 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryD 201-2180 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceŒ] 50-029-21791-01-00 7. KB Elevation (ft): 9. Well Name and Number: 51.00 04-19A 8. Property Designation: 10. Field/Pool(s): ADL-028324 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 9430 feet true vertical 8933.0 feet Plugs (measured) None Effective Depth measured 9348 feet Junk (measured) None true vertical 8851.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 115 20" 91.5# H-40 31 - 146 31.0 - 146.0 1490 470 SURFACE 2954 13-3/8" 68# K-55 30 - 30.0 - 4930 2670 SURFACE 13-3/8" 72# L-80 . 2984 - 2984.0 PRODUCTION 3824 9-5/8" 47# L-80 29 - 3853 29.0 - 3853.0 6870 4760 LINER 5317 7" 26# L·80 3683 - 9000 3683.0 - 8504.0 7240 5410 LINER 1341 4-1/2" 12.6# L-80 8089 - 9430 7602.0 - 8933.0 8160 7020 Perforation depth: Measured depth: 9020-9036,9070-9110,9120-9138,9158-9170 SCANNED SEP 2 17 200ß True vertical depth: 8524-8540,8574-8614,8624-8642,8662-8674 Tubins:¡ ( size, s:¡rade, and measured depth): r 26# L-80 @ 27 - 3637 5-1/2" 17# L-80 @ 3637 - 7967 4-1/2" 12.6# L-80 @ 7967 - 8096 Packers & SSSV (type & measured depth): 9·5/8" Baker ZXP Packer @ 3691 7" Baker S-3 Packer @ 8039 7" Baker ZXP Packer @ 8096 7" HEX R Nipple @ 2184 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft SEP 2 6 200ff Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: -.- .-- 3500 240 933 Subsequent to operation: -.- --- 2738 10 708 14. Attachments: 15. Well Class after proposed work: ExploratoryO DevelopmentD ServiceŒ] Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ Oil 0 GasD WAG 0 GINJD WINJŒ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature A~ R Y./J ./ Phone 564-5174 Date 9/21/06 v ........ Form 10-404 Revised 4/2004 tJ ~i. I t:J I r~ ~~ i . . 04-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/20/2006 TestEvent --- Inj Press, psi: 1,659 Type: PW Vol: 3,197 08/04/2006 T/I/0=740/70/460 MIT IA to 2500 psi.**PASS** Temp=lnjecting (State AOGCC witnessed by Chuck Sheive) Pressured up IA w. 2.4 bbls neat, IA lost 40 psi in 15 min and 10 psi in second 15 min for a total 30 min pressure loss of 50 psi. Bled lAP. Final WHP's=750/175/460 08/04/2006 T/I/0=740/70/450. Temp=Hot. AOGCC MIT-IA PASSED to 2500 psi (for RlC). AOGCC State Witnessed by Chuck Scheve. Pumped 2.4 bbls Meoh to MIT-IA to 2490 psi. lAP decreased 40 psi in 1 st 15 mins, 10 psi in 2nd 15 mins, total 50 psi in 30 mins. Bled lAP to 175 psi (2.3 bbls returns). Final T/I/0=740/175/460. 08/03/2006 T/I/0=720/30/360 Temp=HOT IA FL (for MIT-IA for RlC). IA FL @ surface. 08/02/2006 LOG INJECTION PROFILE WITH PSP TOOL (CCL/GRlPRESS/TEMP/SPINNERS). WELL INJECTING AT 7500 BBLS/DAY AND 112 DEG F. 90% OF INJECTED PRODUCED WATER FLOWING INTO PERFS FROM 9020-9036'. 9.7% OF INJECTED PRODUCED WATER FLOWING INTO PERFS FROM 9070-9110'. 0.3% OF INJECTED PRODUCED WATER FLOWING INTO PERFS FROM 9120-9138' WITH BOTTOM OF INJECTION AT 9134'. CROSS FLOW DETECTED BETWEEN PERF FROM 9020-9036' AND PERFS FROM 9070' TO 9110' . SCHMOO BELOW PERFS AT 9110'. NO DESCENT MADE BELOW 9160' NO CHANNEL DOWN BELOW PERFORATIONS BASED ON FINAL TEMPERATURE DOWN PASS INTO SCHMOO. 08/01/2006 T/I/0=720/0/380. Temp=Hot. WHP's & IA FL. (Pre MIT-IA). IA FL @ Surface. 07/17/2006 PERFORATE INTERVAL 9158' - 9170' USING 3-3/8" HSD LOADED WITH 12' POWERJET HMX 3406. HAD TO WORK TOOLS DOWN PAST 9100'. PULLED 500 LBS OVER LOGGING BACK UP THROUGH 9100'. ***JOB COMPLETE*** 07/12/2006 *** WELL INJECTING UPON ARRIVAL *** RIH 3 3/8" DUMMY GUN & 1.5" S. BAILER TO 9109' SLM. JARRED DOWN. FELL THROUGH. TAGGED TD AT 9307' SLM. STICKY BOTTOM. MADE 3 PASSES THROUGH 9109' SLM AREA, NEVER COULD SET DOWN AGAIN, RECOVERED 2 CUPS OF SHMOO / MUNG BOTTOM SHOT (9170') FLUIDS PUMPED BBLS 3 Methanol --- PT Surface Equipment 2 Diesel --- PT Surface Equipment 2.4 Methanol--- MIT-IA 7.4 TOTAL Page 1 /9-5/8" CSG, 47#, L-80, ID = 8.681" I 6992' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" I 17" X 4-1/2" BKR ZXP PKR, ID = 4.938" I 17" X 4-1/2" BKR HMC HGR, 10 = 4.938" TREE = WB...LHEAD = ACTUA TOR = KB. B...EV = BF. B...EV = KOP= Max Angle = Datum MD - Datum lVD = 7-1/16" CPN FMC GB\l1V BAKERC 60' NlA 3970' 39 @ 4687' 9356' 8800' SS 13-3/8" CSG, 68#, K-55/72#, L-80 10 = 12.347" IT' TBG, 26#, L-80, .0383 bpf, ID = 6.276" TOPOF BKR C-2 TIEBACK SLV, 10 = 7.50" 363T 3683' Minimum ID = 3.725" @ 8083' 4-1/2" HES XN NIPPLE PERFORA TION SUMMARY REF LOG: SCMrON01/10/02 ANGLE AT TOP PERF: 4 @ 9020' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9020 - 9036 0 03/23/03 2-718" 6 9070 - 9110 0 02/09/02 2-7/8" 6 9120 - 9138 0 01/10/02 3-3/8" 6 9158 - 9170 0 07117/06 04-19A NOTES: 2184' - 7" HES R NIP, ID = 5.963" I -i7" X 5-1/2" TBG XO, 10 = 4.892" I -i 9-5/8" X 7" BKR ZXP PKR I - 9-5/8" X 7" BKR FLEXLOK HNGR I 9-5/8" CSG MILLOUT WINDOW 3853' - 3869' (OFF WHIPSTOCK) -15-1/2" TBG, 17#, L-80, .0232 bpf, 10 = 4.892" -15-112" X 4-112" TBG XO, 10 = 3.958" I -4-1/2" HES X NIP, 10 = 3.813" I - 7" BKR S-3 PKR, ID = 3.875" I -4-1/2" HES X NIP, 10 = 3.813" I -14-1/2" HES XN NIP, 10 = 3.725" I -14-1/2" WLEG I I B...M 'IT LOGGED 01/10/02 7" LNR, 26#, L-80, .0382 bpf. 10 = 6.276" I 9348' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9430' DATE 04/11/88 12/22/01 02/11/02 02/25/02 03/23/03 REV BY COMMENTS ORIGINAL COMPLETION CHlKAK RIG SIDETRACK JLM'tlh ADD PERF JRClKAK 7" LNR FWElKK ADD PERF DA TE REV BY COMMENTS OS/29/05 DFRlDTM CSG CORRECTIONS (11/24/04) 07/17/06 DFRlPJC PERFORATIONS PRUDHOE BA Y UNIT WB...L: 04-19A PERMIT No: ~012180 API No: 50-029-21791-01 SEe 26, T11 N, R15E 916' FSL & 258' FWL BP Exploration (Alas ka) MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Reggk?;> G c;,l.c"·c/CI.,? P.I. Supervisor, /:'1 { ~ OA TE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04..19A PRUDHOE BAY UNIT 04-]9A 1lJ \" 'J-}\ lP FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 'Jr5i2- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 04-19A API Well Number 50..029-21791-0 I -00 Inspector Name: Chuck Scheve Insp Num: mitCS060805150735 Permit Number: 201-218-0 Inspection Date: 8/4/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --~. rType Inj. i w I TVD I I .. Well 04..19A 7553 i IA 70 2490 2450 2440 I i j i ì 1 2012180 - ~-~~ I I P.T. jTypeTest . SPT i Test psi i 1888.25 i OA 450 740 740 ' 740 I , I i I --+- I - Interval 4YRTST P/F P v/ Tubing: 740 740 ì 740 ' 740 I ! m" I I Notes Pretest pressures were observed and found stable. S(;ANNED AUG 2 4 2006 Wednesday. August 09,2006 Page I of 1 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc J {kA- á, Permit to Drill 2012180 Well Name/No. PRUDHOE BAY UNIT 04-19A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21791-01-00 ~~~~~~ m_~_~~ 1~ -~~~~= REQUIRED INFORMATION l () f~ À~ t '{ , DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 3~~\ Mud Log No Samples No Directional Survey Yes -- -.----.---.-.-------------- --------------- ---.--------------- --- ----- ------------------ -------- ---..------------------------.---. .-------..---..-.----- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Electr Dataset Number - 41081 -1 0627 vf1554 (data taken from Logs Portion of Master Well Data Maint) ( Name ~1$Yø(ifÎqati6h....'. Log Log Run Scale Media No ---- 1 1 Interval Start Stop ---- 3845 9408 OH/ CH Received Comments ------------------_.------ Case 9/27/2002 Case 3/5/2002 Case 2/13/2003 Digital Well Logging Data Case 9/27/2002 ". ...................." "'.""'" "..' :<?~m.~.~R~¥......'..,. . . ......'" . .. ... '$ee N()~ès. . ,¡ 1 1 7900 3842 9334 9430 9408 Rpt . ....... ... .'... hiS Y~f¡fI¿~ti6ñ'."..' 3845 .--- -----..--. -..-.----------------------- -- ------.-.------ .--...-----.-.-------- -----.--------------.- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y 0 Chips Received? -Y-¡-N Formation Tops GJN ~/N ( Daily History Received? Analysis Received? ~/N-- ------ ~~m~e~~~;---ru ~~---"RV5 l~ ïM-J --.. SI ~ ~ c..-t~ ~ ~ la~6.J\- ~'"\.- --------- "------'-'-----"----'----" Jet (')ð - at J 1 ~ ~ ::::==.:.:_=:- ':'==:=:'::-.=::':_-:::':': ::=.::=====~-=-=== :..t~ - -::_==--===--= ====..::::--=.=:-=.::::::.::=====-:==.::=.:..:==.:. =.=:..... --- .. ._--_:::::==--=========--::_:===::':::::'::=:':==='='-::':".:::::=:- -:;f=='::'-J=:--===--==::::':":' -::-. -- - -.:.:-- .-. -:---.- --.. . . . ... -...- - Compliance Reviewed BY:__________m--_____-------------------- Date: ----}----~-~~-------------- " ( ~ ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: SBG I ADD PERFS 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing 4373'FNL,5023'FEL,Sec.26,T11N, R15E,UM At top of productive interval 2361' FNL, 5102' FEL, Sec. 26, T11N, R15E, UM At effective depth 2363'FNL, 5101'FEL, Sec. 26, T11N, R15E,UM At total depth 2338' FNL, 5106' FEL, Sec. 26, T11N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Length 115' 2952' Size 20" 13-3/8" Surface Intermediate 3821' 5317' 845' 7" X 4-1/2" 9-5/8" 7" Liner Sidetrack Liner Stimulate _X Alter casing 5. Type of Well: Development - Exploratory- Stratigraphic- Service_X Plugging - Perforate _X Repair well - Other 6. Datum elevation (OF or KB feet) RKB 51 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number (asp's 713060, 5952~ 04-19A "" 9. Permit number / approval number (asp's 712921, 5954795) \..1 201-218 10. API number (asp's 712922, 5954793) (asp's 712917, 5954818) 9430 feet 8933 feet 50-029-21791-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Oil Pool Plugs (measured) Tagged TO @ 9082' (03/23/2003) 9082 feet 8586 feet Junk (measured) Measured Depth 147' 2984' 3853' 3683' - 9000' 8089' - 9432' True Vertical Depth 147' 2984' 3853' 3683' - 8504' 8089' - 8934' Perforation depth: measured Open Perfs 9300'-9312',9336'-9340',9344'-9348', 9358'-9368', 9780'-9997',10050'-10160', Cemented 2150 # Poleset 2500 sx CS III, 600 sx CS II 1350 sx Class 'G', 300 sx CSI 102 sx Class 'G' 156 sx Class 'G' true vertical Open Perfs 8788'-8789',8810'-88141,8817'-8820', 88291-88391, 89721_8959', 8960'-89621, Tubing (size, grade, and measured depth) 5-1/2",17#, 13-CR-80, TBG @ 2984'. 5-1/2" x 4-1/2" XO @ 29841. 4-1/2" 12.6#, 13-CR-80, Tubing @ 8738'. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" TIW HBBP PKR @ 8676'. 5-1/2" Otis 22QOS45611 Nipple @ 2107'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Dailv Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl 19719 Prior to well operation 03/18/2003 Subsequent to operation 04/24/2003 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations Oil Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,4.?J ~ ~ ~ T;tle, T echicol Assistan' DeWavne R. Schnorr fC¡}rc~.::.'.-)'~'IM.h.\'\1.'.' I',L,,).II:" I'"~ ~r~J',l. '\,/11\,-/ 1,,7 ,l~ Form 10-404 Rev 06/15/88 . ~AV ~ r.)li\:;¡;i i IlJI . ~ ~~ ;11 16788 16. Status of well classification as: Suspended ORIGINAL i""" :1 ;:; ,,'.i;-' " ". ; \:\ :", r::;':-,'~ ",,"-;¡,:. :,. ¡:" "':, '::) "-:., f/.'\ Of' (i :;' ;""'" t?::"""';'i'::J"'i" T ~."."'";,, ",,",' , . "\..; ".'"".,::,,'.;:~...""';:""'~"""'\ i~; :<,~:¡ ,:: -;: Casinç¡ Pressure Tubinç¡ Pressure 1557 1365 Service WATER INJECTOR Date April 25. 2003 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE ~ "' 03/06/2003 03/06/2003 03/08/2003 03/11/2003 03/23/2003 03/24/2003 04/24/2003 03/06/03 03/06/03 03/08/03 03/11/03 03/23/03 03/24/03 04/24/03 BBLS 1 (: ( 04-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERFORATING: DRIFT/TAG PERFORATING: LOAD WELL TO SECURE PERFORATING: SCMOO-B-GON E PERFORATING: DRIFT/TAG PERFORATING: PERFORATING PERFORATING: PERFORATING TESTEVENT --- INJECTION PRESSURE, PSI: 1,365 16,788 BWPD. TYPE: PW VOLUME: EVENT SUMMARY RUN 3.365 DUMMY GUN TO 9044' SLM, GET STUCK, PULL FREE, SAMPLE BAILER IS FULL OF INJECTION SCHMOO,NO FL SEEN. (BTM SHOT @ 90601) ASSIST SLICK-LINE, PUMP 15 BBLS OF 60/40 MEOH DOWN TUBING. PUMPED 254 BBLS SBG TREATMENT. «< WELL INJECTING ON ARRIVAL »> TAGGED BOTTOM @ 9086' WLM. STICKY SMOO IN S-BAILER. OS OP. PUT BACK ON INJECTION. PERFORATED INTERVAL FROM 90201-90361 W/ 3-3/811 x 30' (16 FOOT OF GUNS LOADED) IIPUREII GUN - CHARGE IS 2-7/811 2906 (INSIDE 3-3/811 CARRIER), 6 SPF, 60 DEG PHASE. WELL INJECTING UPON ARRIVAL. SHUT IN WELL AND RIH. TAGGED TO @ 9082' MD, STICKY BOTTOM. TIED INTO SWS SCMT LOG (1- 10-2002). FIRED GUN. SAW WEAK INDICATION. LOGGED OFF AND POOH. NO PROBLEMS POOH, ALL SHOTS FIRED. RDMO, PLACED WELL BACK ON INJECTION. «< TWO GUN RUNS REMAINING FOR JOB »> ATTEMPT PURE PERFORATING SYSTEM: RIH WITH 3-3/811 X 30' GUN, 161 LOADED INTERVAL, 2-7/811 2906 PJ CHARGE (CARRIER IS 3-3/811),6 SPF. SETTING DOWN AND STICKING AT 9017' - 90221, COULD NOT GET DEEPER. APPEARS THAT TOOL IS DIFFERENTIALLY STICKING ACROSS UPPER PERF INTERVAL 9020' - 90361, MAXIMUM TENSION PULL ON LAST ATTEMPT 2400 LBS, 2500 LBS IS MAX SAFE PULL. DECISION MADE TO PULL OUT W/O FIRING, RIG DOWN. NOTIFY DSO, PUT WELL BACK ON INJECTION. TESTEVENT --- INJECTION PRESSURE, PSI: 1,365 TYPE: PW VOLUME: 16,788 BWPD. FLUIDS PUMPED ¡DIESEL PUMPED FOR PRESSURE TEST, Page 1 \I (" (' 10 NEAT METHANOL 15 60/40 METHANOL WATER 3 DIESEL 42 SCHMOO-B-GONE 212 FRESH WATER 283 TOTAL 04-19A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ADD PERFS 03/23/2003 THE FOllOWING INTERVAL WAS PERFORATED USING THE 2-7/811 2906-PJ, 6SPF, 60 DEG PHASING, RANDOM ORIENTATION. 9020. - 9036' Page 2 (I" ( dOI-d. ) 8 , J 55'-1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 12, 2003 RE: MWD Formation Evaluation Logs: 04-19 A, AK-MM-11205 04-19A: Digital Log Images 50-029-21791-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~ ~ Date: RECEIVED FEB 1:3 2003 Alaska Qfl & Gas Coos. CommiS3ion Anchorage & '\ ~ ;). 0 1- d,J ~ I/O?;} WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COmtn. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 ~chorage,Alaska September 26, 2002 RE: MWD Formation Evaluation Logs 4-19A, AK-MM-11205 1 LDWG formatted Disc with verification listing. API#: 50-029-21791-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. ~chorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~~ ~ RECEIVED SEP 27 2002 Alaska Oj~ & Gas Cons. Commission Anchorage (" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ( 1. Status of Well Classification of Service Well 0 Oil 0 Gas 0 Suspended 0 Abandoned !HI Service Water Injection 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-218 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ".. .- 50- 029-21791-01 ..., ' 4. Location of well at surface ~.. '~. 9. Unit or Lease Name 907' NSL, 5023' WEL, SEC. 26, T11 N, R15E, UM ¡ ~ ,~j. " , Prudhoe Bay Unit At top of productive interval --Z ~ ' ~r.,:_:,,--.. -. , 2919' NSL, 5102' WEL, SEC. 26, T11N, R15E, UM ¡; ~ 'J 1;~l . ~ t'" . '" ", ""'"" ~ '. - ~~"~':L, 1 O. Well Number At total depth """""'M-~'"_""-",-,, . - '. ."..:.1- 04-19Ai 2942' NSL, 5106' WEL, SEC. 26, T11N, R15E, UM . ".."t"-~"-N'.,_..,,:.~~..I 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 51' ADL 028324 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 12/3/2001 12/18/2001 1/1 0/2002 NI A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 9430 8933 FT 9348 8851 FT !HI Yes ONo (Nipple) 2182' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, CBT, DEN, NEU, CBL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 115' 30" "150 # Poleset 13-3/8" 68# I 72# K-55 I L-80 Surface 2984' 17-1/2" )500 sx CS III 600 sx CS II 9-518" 47# L-80 Surface 3853' 12-1/4" 1350 sx Class 'G1. 300 sx CS I 7" 26# L-80 3683' 9000' 8-1/2" 102 sx Class 'G' 7" x 4-1/2" 12.6# L-80 8089' 9432' 6-1/8" 156 sx Class 'G' 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 7" 26#, L-BO x 5-1/2",17#, L-BO (XO 3636') 7968' MD TVD MD TVD 4-1/2", 12.6#, L-80 8096' 8039' 9070' - 9110' 8574' - 8614' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9120' - 9138' 8624' - 8642' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8699' - 8702 & 8200' - 8203' Perf for Cement Squeeze of 7" Casing 2200' Freeze Protect wI 140 Bbls Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 17, 2002 Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit RECEIVED No core samples were taken. APR 5 2002 AIaIk8 Oil I: GIS Cons. Commission {" "iì r"""~ ~ :("\ 1 "\ :llj! ~ AnChorage :: : ': " I~ ¡'.' !, .. i~"._)11 "'. I :;, ~;!i\" " \:1 AJR 8 2002 - II \\ I) , I,: J"'~' ; , , " . , Form 10-407 Rev. 0701-80 I j ~ ,I ~ t",.. R B OM S B F L ~tV Submit In Duplicate (' (' 29. 30. Formation Tests Geologic Markers Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GaR, and time of each phase. LCU 8996' 8500' Zone 3 9013' 8517' Zone 2 9111' 86151 Zone 2A 9202' 87061 Zone 1 B 9240' 8744' Zone 1 A 9289' 8793' Base of Sadlerochit 9331' 8834' RECEIVED 5 200) NlllraOl & Gas ConI. Commission A~ APR 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the f~oin~ is true and correct to the best of my knowledge Signed Terrie Hubble ~~ tit J ~ Title Technical Assistant 04-19Ai 201-218 Well Number Permit No. / ADDroval No. Date 04~OS .O~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 2.8: If no cores taken, indicate 'none'. '1 Ii ii .1 . I '.'. I,..,.,., Form 10-407 Rev. 07-01-80 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: 04-19A Common Name: 04-19A Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 12/3/2001 FIT 3,878.0 (ft) 3,888.0 (ft) 9.70 (ppg) 565 (psi) 2,524 (psi) 12.50 (ppg) 12/16/2001 FIT 9,000.0 (ft) 8,505.0 (ft) 9.30 (ppg) 309 (psi) 4,418 (psi) 10.00 (ppg) 1/ I\. , , Printed: 12/26/2001 8:39:34 AM {' ( BP EXPLORATION Operations Summary Report Page 1 of 10 Legal Well Name: 04-1 9A Common Well Name: 04-1 9A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 11/25/2001 End: 12/22/2001 Contractor Name: NABORS Rig Release: 12/22/2001 Rig Name: NABORS 2ES Rig Number: l;iQursActivityCocie NPT D~$criþtiönofOperatipns 11/27/2001 03:00 - 12:00 9.00 MOB P PRE REMOVE BELLY BOARD FROM DERRICK, PREP TO MOVE. 12:00 - 00:00 12_00 MOB P PRE MOVE RIG TO DS-04-19A. 11/28/2001 00:00 - 15:00 15_00 RIGU P PRE MOVE PITS AND CAMP TO DS-04-19A LOCATION. SPOT SAME AND CONT. TO RU. ACCEPT RIG ON DAYWORK AT 1500 HRS, 11/28/01. 15:00 -16:00 1.00 RIGU P PRE HOLD PRE-SPUD SAFETY MTG. 16:00 -18:30 2.50 RIGU P PRE RU LINES FOR DIESEL DISPLACEMENT, TAKE ON SEA WATER. 18:30 -19:30 1.00 RIGU P PRE RU DSM PULL BPV. PRESSURES: 9-5/8"X13-3/8" = 0 PSI, 7"X9-5/8" = 200 PSI, 7" TBG = 250 PSI. RD DSM. 19:30 - 20:30 1.00 RIGU P PRE RU THE TREE FOR DISPLACEMENT. 20:30 - 23:00 2.50 RIGU P PRE CLEAN RIG, COMPLETE RU OF LINES, CONT. TAKING ON SW. PJSM. 23:00 - 00:00 1.00 RIGU P PRE ATTEMPT TO DISPLACE FP. SHUT DOWN AND TIGHTEN LEAKING TREE FLANGE. 11/29/2001 00:00 - 02:30 2.50 RIGU P PRE CIRC OUT DIESEL FP PLUS ONE HOLE VOLUME AT 3 BPM, 390 PSI, THRU CHK- MONITOR WELL - OKAY. 02:30 - 03:00 0.50 RIGU P PRE BLOW DOWN LINES. CLEAN RIG FLOOR. 03:00 - 03:30 0.50 RIGU P PRE ATTEMPT TO SETTWC- WOULD NOT SET. 03:30 - 04:00 0.50 RIGU N SFAL PRE WAIT ON DSM LUBRICATOR. 04:00 - 05:00 1.00 RIGU N SFAL PRE RU LUBRICATOR, OPEN WELL AND FLOW CHECK. WELL HAD SLIGHT FLOW. SI PRESSURE 20-50 PSI. 05:00 - 08:30 3.50 RIGU N SFAL PRE WEIGHT UP SW WITH SALT, FROM 8.5 PPG TO 8.7 PPG. CIRC AT 3 BPM AND 270 PSI THRU CHK. SHUT DOWN AND MONITOR WELL. SMALL FLOW, SHUT IN WELL. 08:30 - 10:00 1.50 RIGU P PRE DISPLACE WELL W/ PREPARED 9.7-9.8PPG BRINE, AT 3 BPM, 270 PSI, THRU CHK. SD, MONITOR WELL - DEAD. 10:00 - 11 :00 1.00 RIGU P PRE INSTALL TWC. TEST BELOW TO 500 PSI, ABOVE TO 2,000 PSI. RD DSM. 11 :00 - 11 :30 0.50 RIGU P PRE BLOW DOWN LINES, CLEAN RIG FLOOR. 11 :30 - 13:30 2.00 RIGU P PRE PJSM. ND TREE. 13:30 - 18:30 5.00 RIGU P PRE NU BOPS. 18:30 - 20:30 2.00 RIGU P PRE PJSM. PU AND SET TEST PLUG. RU TEST EQUIPMENT. 20:30 - 00:00 3.50 RIGU P PRE TEST BLIND RAMS, UPPER/LOWER PIPE RAMS, CHK MANIFOLD TO 250/4,000 PSI -OKAY. 11/30/2001 00:00 - 02:00 2.00 RIGU P PRE CONT. PRESSURE TESTING CHK MANIFOLD. TEST ANNULAR PREVENTER TO 250 / 3,500 PSI. TEST TIW AND DART TO 250 / 4,000 PSI- OKAY. RD TEST EQUIP. 02:00 - 03:00 1.00 RIGU P PRE RU DSM AND PULL TWC. WELL ON VACUMN. PUMPED 24 BBLS TO FILL. HOLE STAYING FULL. 03:00 - 04:00 1.00 PULL P DECOMP PU / MU SPEAR ASSEMBL Y. 04:00 - 04:30 0.50 PULL P DECOMP BACK OUT LOCK DOWN SCREWS. 04:30 - 05:30 1.00 PULL P DECOMP PJSM. PULL TBG FREE WITH 165k LBS. STRNG WT (ABOVE SEAL ASSEMBLY) = 117K IN BLOCKS. CIRC. ONE HOLE VOL. AT 5 BPM, 240 PSI. 05:30 - 07:30 2.00 PULL P DECOMP PULL TBG HNGR TO FLOOR. RU TBG HANDLING EQUIPMENT. RU CONTROL LINE SPOOLING UNIT. 07:30 - 13:00 5.50 PULL P DECOMP LD 7" 26 LB/FT TBG TO SSSV AT 2,226'. RECOVERED 28 OF 30 STEEL CONTROL LINE BANDS. 13:00 - 13:30 0.50 PULL P DECOMP RD SPOOLING UNIT. 13:30 - 14:30 1.00 PULL P DECOMP CONT. PULLING 7" TBG. TOTAL PULLED = 68JTS, 3 PUP Printed: 12/26/2001 8:39:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date .. 11/30/2001 12/1/2001 12/2/2001 12/3/2001 ( ( BP EXPLORATION Operations Summary Report 04-19A 04-19A REENTER+COMPLETE NABORS NABORS 2ES From - To Hours Activity Code NPT 13:30 -14:30 14:30 - 15:00 15:00 - 16:30 16:30 - 19:00 19:00 - 20:00 20:00 - 20:30 20:30 - 21 :30 21 :30 - 00:00 00:00 - 02:30 02:30 - 04:00 04:00 - 06:00 06:00 - 06:30 06:30 - 08:00 08:00 - 10:00 10:00 -10:30 10:30 -13:30 13:30 -15:30 15:30 -17:00 17:00 - 21:30 21 :30 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 04:30 04:30 - 05:30 05:30 - 07:00 07:00 - 12:00 12:00 - 13:00 13:00 -15:00 15:00 -15:30 15:30 -16:30 16:30 - 17:30 17:30-21:30 21 :30 - 23:30 23:30 - 00:00 00:00 - 01 :00 01 :00 - 02:00 1.00 PULL 0.50 PULL P P 1.50 PULL 2.50 PULL P P 1.00 PULL 0.50 PULL 1.00 PULL 2.50 PULL 2.50 PULL 1.50 PULL 2.00 PULL 0.50 PULL P P P P P P P P 1.50 PULL P 2.00 PULL P 0.50 PULL 3.00 PULL 2.00 PULL P P P 1.50 STWHIP P 4.50 STWHIP P 2.00 STWHIP P 0.50 STWHIP P 1.50 STWHIP P 3.00 STWHIP P 1.00 STWHIP P 1.50 STWHIP P 5.00 STWHIP P 1.00 STWHIP P 2.00 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 1.00 STWHIP P 4.00 STWHIP P 2.00 STWHIP P 0.50 STWHIP P 1.00 DRILL P 1.00 DRILL P Phase ... . DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT INT1 INT1 Page 2 of 10 Start: 11/25/2001 Rig Release: 12/22/2001 Rig Number: Spud Date: 11/25/2001 End: 12/22/2001 Description of Operations ....". JTS, 1 SSSV. RU FALSE FLOOR FOR PULLING SCAB LINER AND SEAL ASSEMBL Y. LD SEAL ASSEMBLY, RD FALSE FLOOR. PULL AND LD 4-1/2", 15.1 LB/FT, STL TBG. RECOVERED 35 JTS PLUS CUTOFF. LD 4-1/2" TBG HANDLING EQUIP. LD SPEAR ASSEMBLY SET WB. CLEAN RIG FLOOR, PU MILLING BHA#1 PJSM. MU BHA #1. PU 6-1/4" DCS. CONT. PU DRILL COLLARS AND HWDP. CUT AND SLIP 109' OF DRILL LINE. SERVICE TOP DRIVE. PU 4" DP AND RIH TO 2,992'. TAG TOP OF 9-5/8" PKR. OBTAIN DRILLING PARAMETERS. 115K UP, 115 DWN, 115K ROTATING. MILL 9-5/8" PKR W/ 10-15k WOB, 5-6,000 FT-LB. MILL 2,992-2,995'. MONITOR WELL - STABLE. CO NT. RIH AND PICKING UP 4" DP. PUSHED PKRlCMPL ASSEMBLY TO 4,436'. CBU, MONITOR WELL - STABLE. POOH TO BHA POOH W/ PKR MILLING BHA LD MILLS, CLEAN JUNK BASKETS. CLEAR FLOOR. PU/MU BHA #2 PU DP AND RIH TO 4,400'. POOH WI DP. LD STRING MILL, JARS. CLEAR FLOOR. PJSM. RU WIRELINE TO RUN 9-5/8" EZSV. RIH, CORRELATE W/ GR AND SET AT 3,886'. POOH AND RD WL. RIH, CORRELATE W/ GR AND SET AT 3,886' WLM. POOH AND RD WL. RU AND TEST 9-5/8" CSG AND BP TO 4,000 PSI FOR 30 MIN. - OKAY. PU WHIPSTOCK ASSEMBLY AND ORIENT. RIH W/ WHIPSTOCK BHA PU 4" DP AND RIH TO 3,836'. RU WL TO ORIENT WHIPSTOCK. RIH W/ GYRO AND ORIENT WHIPSTOCK TO 351 DEG AZIMUTH. RD WL. PU ONE STAND, RIH AND TAG BP AT 3,876' DPM. SHEAR PINS AND SET WHIPSTOCK WITH 35K DOWN. PU AND CHECK SET. CLEAN OUT FREEZE PLUG IN G&I HARDLINE. DISPLACE WELLBORE WITH 9.8 PPG HT MUD, AT6 BPM, 450 PSI. MILL WINDOW FROM 3,853' TO 3,869', PUMPING SWEEPS AS NEEDED. DRILL TO 3,888' TO BURY MILLS. BACKREAM AND WORK MILLS THRU THE WINDOW. RU FOR FIT. PTSM, PJSM. PTSM, PJSM. RU AND PERFORM FIT TO 12.5 PPG EMW W/ 9.7 PPG MUD IN HOLE. MONITOR WELL - OKAY. PUMP SLUG. BLOW DOWN TOP Printed: 12/26/2001 8:39:41 AM ( ( BP EXPLORATION OperationsS u mmaryReport Page 3 of10 Legal Well Name: 04-19A Common Well Name: 04-19A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 11/25/2001 End: 12/22/2001 Contractor Name: NABORS Rig Release: 12/22/2001 Rig Name: NABORS 2ES Rig Number: Date Hours Activity Code NPT Descri pti onetO perpti 0 Ii s 12/3/2001 01 :00 - 02:00 1.00 DRILL P INT1 DRIVE. 02:00 - 04:00 2.00 DRILL P INT1 POOH TO HWDP. CIO ELEVATORS. 04:00 - 04:30 0.50 DRILL P INT1 POOH W/ HWDP, AND STAND BACK. 04:30 - 08:00 3.50 DRILL P INT1 POOH AND LD WINDOW MILLING BHA. 08:00 - 09:00 1.00 DRILL P INT1 CLEAN METAL CUTTINGS AND WASH DOWN STACK. PULL WB. 09:00 - 10:00 1.00 DRILL P INT1 INSTALL WB. RUN IN LDS. 10:00 - 11 :00 1.00 DRILL P INT1 CLEAR FLOOR. PU DRILLING BHA. C/O ELEVATORS. 11:00 -14:00 3.00 DRILL P INT1 PU/MU BHA. PTSM, PJSM. 14:00 - 16:30 2.50 DRILL P INT1 RIH, PICKING UP THE REMAINING 4" DP FOR REACHING TD. 16:30 - 17:30 1.00 DRILL P INT1 CO NT. RIH TO 3,820'. 17:30 - 20:00 2.50 DRILL P INT1 RU ELECT. LINE AND GYRO. RU SIDEENTRY SUB AND RIH. 20:00 - 21 :00 1.00 DRILL P INT1 ORIENT TOOLFACE, SLIDE THRU WINDOW - OKAY. 21 :00 - 00:00 3.00 DRILL P INT1 DRILL BUILD SECTION. 12/4/2001 00:00 - 01 :00 1.00 DRILL P INT1 PTSM. CONT. DRLG TO 4,007'. 01 :00 - 02:30 1.50 DRILL P INT1 POOH TO 3,820'. SURVEY/ORIENT WI GYRO. 02:30 - 03:30 1.00 DRILL P INT1 POOH WI E-LiNE AND GYRO. RD/LD. 03:30 - 04:00 0.50 DRILL P INT1 RIH TO BTM, CIRC. 04:00 - 12:00 8.00 DRILL P INT1 DRILL W/ 1.5 DEG MOTOR, SURVEY W/ MWD-GR/RES FROM 4,007' TO 4,381'. 12:00 - 00:00 12.00 DRILL P INT1 PTSM. DRILL TO 5,129'. 12/5/2001 00:00 - 18:00 18.00 DRILL P INT1 PTSM, PJSM. DRILL TO 6,438' TMD (THRU INJECTION ZONE). BIT WAS DRILLING ERRATICALLY. RAN CENTRIFUGE TO REDUCE MW TO 9.8 PPG. 18:00 - 19:30 1.50 DRILL P INT1 CIRCULATE AND CONDITION FOR TRIP. 19:30 - 20:00 0.50 DRILL P INT1 PULL 5 STANDS AND CHECK THE WELL FOR FLOW - OKAY. 20:00 - 21 :30 1.50 DRILL P INT1 PUMP SLUG AND CONTINUE POOH FROM 5,970' TO 5,315'. INCREASING OVERPULL WITH EACH STD PULLED, FROM 20-50K. 21 :30 - 22:00 0.50 DRILL P INT1 CIRC AND CONDITION HOLE. 22:00 - 23:00 1.00 DRILL P INT1 CONT. POOH TO FIRST 5 STDS TO 4,854', PULLED SLICK. CONT. PULL WI INCREASING TIGHT HOLE TO 4,649', WITH OP 20-50K. 23:00 - 00:00 1.00 DRILL P INT1 CIRC. & CONDITION HOLE. 12/6/2001 00:00 - 02:00 2.00 DRILL P INT1 CO NT. POOH. HOLE TIGHT, UNTIL 4,150'. PULL THRU WINDOW-OKAY. 02:00 - 04:00 2.00 DRILL P INT1 PJSM, CUT & SLIP 92' OF DL. ADJUST BRAKES. SERVICE TOP DRIVE. 04:00 - 04:30 0.50 DRILL P INT1 PUMP SLUG, BLOW DOWN TD. 04:30 - 06:30 2.00 DRILL P INT1 POOH TO 741' - BHA. 06:30 - 08:00 1.50 DRILL P INT1 C/O TO 5" ELEVATORS. POOH AND LD BHA. 08:00 - 09:30 1.50 DRILL P INT1 DOWNLOAD MWD DATA. POOH TO BIT. 09:30 - 10:30 1.00 DRILL N RREP INT1 REPAIR PIPE SKATE. 10:30 - 11 :00 0.50 DRILL P INT1 LD MWD AND MOTOR. 11 :00 - 12:00 1.00 DRILL P INT1 SERVICE TOP DRIVE (CHANGE FILTERS, RESET HANDLERS AND EYE SENSOR). 12:00 - 15:00 3.00 DRILL P INT1 PTSM. PUlMU BHA W/O RES. MU 1.22 DEG MOTOR. SURFACE TEST - OKAY. 15:00 - 16:30 1.50 DRILL P INT1 RIH TO 1,500'. ST - NO SIGNAL. CO NT. IN HOLE TO 2,500'. ST - OKAY. Printed: 12/26/2001 8:39:41 AM ( ( BPEXPLORATION Operations Summary Report Page4of10 Legal Well Name: 04-19A Common Well Name: 04-19A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 11/25/2001 End: 12/22/2001 Contractor Name: NABORS Rig Release: 12/22/2001 Rig Name: NABORS 2ES Rig Number: Date From.-To HolJrsAqtivity Code NPT Phase D~scription . ofOperatiöns 12/6/2001 16:30 -17:30 1.00 DRILL P INT1 CO NT. IN HOLE TO 3,789', FILLING EVERY 5 STDS. 17:30 -19:30 2.00 DRILL P INT1 ORIENT, PASS THRU WINDOW. RIH TO 5,377', BREAK CIRC AND CHK SHOT SURVEY. 19:30 - 20:30 1.00 DRILL P INT1 CO NT. IN HOLE TO 5,720' DEPTH CONNECTION. HOLE TIGHT. PULLED 200K (50K OVER). CIRC WITH NO LOSSES. INCREASE CIRC TO 550 GPM. WORK TIGHT SECTION. POOH TO 5,380'- OKAY. 20:30 - 21 :30 1.00 DRILL P INT1 CO NT. RIH TO 6,438' TD. WASH AND REAM LAST 100' TO BTM - 2' OF FILL. 21 :30 - 00:00 2.50 DRILL P INT1 DRILL TO 6,589'. 12/7/2001 00:00 - 07:00 7.00 DRILL P INT1 CONT. DRLG 6,589' TO 6,809'. MOTOR STALLED. 07:00 - 07:30 0.50 DRILL P INT1 WORK TIGHT HOLE 200-250K UP. CIRC AT 550 GPM AND 2550 PSI. PULL FREE. 07:30 - 08:00 0.50 DRILL P INT1 CIRCULATE. 08:00 - 20:30 12.50 DRILL P INT1 DRILL TO 7,522'. SLIDE TO 7,619'. WORK THRU TIGHT SPOT AND PUMP SWEEP. CBU AND WASH FROM 7,525' TO 7,619'. 20:30 - 23:00 2.50 DRILL P INT1 SHORT TRIP TO 6,124'. MAX OP = 20K. 23:00 - 00:00 1.00 DRILL P INT1 DRILL TO 7,629'. 12/8/2001 00:00 - 00:00 24.00 DRILL P INT1 PTSM. DRILL FROM 7,627' TO 8,644'. 12/9/2001 00:00 - 05:30 5.50 DRILL P INT1 DRILL 8-1/2" HOLE FROM 8,644' TO 8,923'. 05:30 - 06:30 1.00 DRILL N RREP INT1 BLOW DOWN TD. REPAIR FLOWLINE AIR BOOT. 06:30 - 08:00 1.50 DRILL P INT1 DRILL TO TD AT 9,000' MD, 8,505' TVD. CONTROL LAST 50' LOCATING CASING POINT. 08:00 - 10:00 2.00 DRILL P INT1 CIRCULATE BOTTOMS UP. MONITOR WELL - STABLE. 10:00 - 11 :00 1.00 DRILL P INT1 SHORT TRIP TO 7,510' - NO PROBLEMS. MONITOR WELL - STABLE. 11 :00 - 11 :30 0.50 DRILL P INT1 RIH TO 9,000'. NO PROBLEMS. 11 :30 - 13:00 1.50 DRILL P INT1 PTSM. CIRCULATE SWEEP. 13:00 - 13:30 0.50 DRILL P INT1 SPOT LINER RUNNING PILL. 13:30 - 14:30 1.00 DRILL P INT1 POOH (SLM) TO 8,450'. MONITOR WELL - STABLE. PUMP SLUG. 14:30 - 20:30 6.00 DRILL P INT1 POOH W/ INTERMITTENT TIGHT SPOTS F/5,900'-5,270', AND 4,710 - 4,390', W/ MOP OF 20-35K. WORK THRU SAME, NO PROBLEMS. 20:30 - 21 :30 1.00 DRILL P INT1 C/O TO 5" ELEVATORS, AND POOH FROM 896' TO 155'. 21 :30 - 23:00 1.50 DRILL P INT1 LD BHA. 23:00 - 00:00 1.00 DRILL P INT1 CLEAR RIG FLOOR. PREP TO CHANGE TOOLS. 12/10/2001 00:00 - 01 :30 1.50 DRILL P INT1 PTSM. C/O TOP PIPE RAMS FROM VARIABLES TO 7". PRESSURE TEST DOOR SEALS TO 3,500 PSI- OKAY. 01 :30 - 02:00 0.50 DRILL P INT1 PULL TEST PLUG. 02:00 - 02:30 0.50 DRILL P INT1 RU CASING EQUIP. PJSM. 02:30 - 03:00 0.50 DRILL P INT1 PUlMU SHOE JTS, AND THREAD LOCK. CHK FLOAT-OKAY. 03:00 - 08:00 5.00 DRILL P INT1 RUN 93 JTS (3,782') OF 7", 26 LB/FT, L-80, BTC-M CASING, WITH 26 CENTS, FILLING EVERY 5 JTS. WT = 120K UP AND 115K DWN. 08:00 - 08:30 0.50 DRILL P INT1 STAGE MUD PUMPS UP TO 10 BPM AND CIRCULATE ONE LINER VOLUME UP. 08:30 - 10:30 2.00 DRILL P INT1 SLIDE THRU WINDOW OKAY AND CO NT. IN HOLE TO 5,293' (TOTAL = 130 JTS OF 7" CSG). 10:30 - 11 :00 0.50 DRILL P INT1 MU LINER HANGER AND C/O PIPE HANDLING EQUIP. 11 :00 - 11 :30 0.50 DRILL P INT1 CONT. RIH WI 5" HWDP TO 6,038' 11 :30 - 14:30 3.00 DRILL P INT1 CO NT. RIH W/4" DP. Printed: 12/26/2001 8:39:41 AM (" ( BPEXPLORATION Operations Summary Report PageS of 10 Legal Well Name: 04-1 9A Common Well Name: 04-19A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 11/25/2001 End: 12/22/2001 Contractor Name: NABORS Rig Release: 12/22/2001 Rig Name: NABORS 2ES Rig Number: Date Hour~~ Ac;tivityÇode NPT Phase Description of Operations 12/10/2001 14:30 -15:00 0.50 DRILL P INT1 MU CMT HEAD. 15:00 -18:00 3.00 DRILL N DPRB INT1 ATTEMPT TO CIRC, BUT THERE WERE NO RETURNS. PULL CASING TO 400K. NO MOVEMENT. 18:00 -19:00 1.00 DRILL N DPRB INT1 LD CMT HEAD AND LINES. BACKOFF (ROTATE OFF) HANGER RUNNING TOOL FROM HNGR. POOH F/ 3,683'-3,614'. 19:00 -19:30 0.50 DRILL P INT1 CLEAR FLOOR. 19:30 - 20:30 1.00 DRILL P INT1 CUT AND SLIP DRILL LINE. SERVICE TO. 20:30 - 23:30 3.00 DRILL N DPRB INT1 PUMP SLUG, POOH TO 709'. 23:30 - 00:00 0.50 DRILL N DPRB INT1 LD HWDP, TO 400'. 12/11/2001 00:00 - 00:30 0.50 DRILL N DPRB INT1 POH LAY DOWN 5" HWDP. 00:30 - 01 :00 0.50 DRILL N DPRB INT1 LAY DOWN BAKER LINER RUNNING TOOLS. 01 :00 - 02:00 1.00 DRILL P INT1 CHANGE TOP RAMS FROM 7" TO 3 1/2" X 6" VARIABLES 02:00 - 02:30 0.50 DRILL P INT1 PULL WEAR BUSHING AND SET TEST PLUG. 02:30 - 07:30 5.00 DRILL P INT1 TEST BOP AND ALL ASSOCIATED VALVES TO 250 PSI LOW FOR 5 MINUTES AND 4000 PSI HIGH FOR 10 MINUTES. ANNULAR PREVENTER TESTED TO 3500 PSI. TEST WITNESS WAIVED BY CHUCK SHEVE OF AOGCC. 07:30 - 08:00 0.50 DRILL P INT1 PULL TEST PLUG, SERVICE AND INSTALL WEAR BUSHING 08:00 - 09:00 1.00 DRILL N DPRB INT1 RIG UP SCHLUMBERGER E-LiNE. 09:00 - 13:30 4.50 DRILL N DPRB INT1 RUN 5.95" GAUGE RING TO 8913' TOP OF 7" LANDING COLLAR. 13:30 -17:00 3.50 DRILL N DPRB INT1 RUN IN WITH 3 3/8" BIG BORE PERFORATING GUN TO PERFORATE FROM 8699' TO 8702' (3') WITH 4 SPF. GUNS DID NOT FIRE. 17:00 - 20:00 3.00 DRILL N DPRB INT1 CHANGE FIRING HEAD AND RERUN 3 3/8" BIG BORE PERFORATING GUN AND PERFORATE FROM 8699' TO 8702' (3') WITH 4 SPF. ALL SHOTS FIRED. 20:00 - 21 :00 1.00 DRILL N DPRB INT1 RIG DOWN SCHLUMBERGER AND LUBRICATOR. 21 :00 - 00:00 3.00 DRILL N DPRB INT1 RIH WITH CHAMP PACKER TO 3639' 12/12/2001 00:00 - 00:30 0.50 DRILL N DPRB INT1 RIH WITH CHAMP PACKER TO 3706' 00:30 - 01 :00 0.50 DRILL N DPRB INT1 CIRCULATE AT 5 BPM WITH 700 PSI TO FILL DRILL PIPE WITH FRESH MUD. 01 :00 - 02:30 1.50 DRILL N DPRB INT1 SET CHAMP PACKER AT 3735'. ATTEMPT TO ESTABLISH CIRCULATION THROUGH TOP PERFS AT 8200'. PRESSURED UP TO 900 PSI WITH NO RETURNS. SEVERAL ATTEMPTS. 02:30 - 04:00 1.50 DRILL N DPRB INT1 POH WITH CHAMP PACKER AND LAY DOWN. 04:00 - 04:30 0.50 DRILL N DPRB INT1 CLEAR RIG FLOOR. 04:30 - 08:30 4.00 DRILL N DPRB INT1 RUN SCHLUMBERGER 3 3/8" BIG BORE PERFORATING GUN. PERFORATE FROM 8200' TO 8203' (3') 4 SPF. PULL OUT, ALL SHOTS FIRED. 08:30 - 09:30 1.00 DRILL N DPRB INT1 RIG DOWN SCHLUMBERGER. 09:30 - 12:00 2.50 DRILL N DPRB INT1 RIH WITH CHAMP PACKER TO 3652'. 12:00 - 13:00 1.00 DRILL N DPRB INT1 CIRCULATE AND CONDITION MUD. 13:00 -13:30 0.50 DRILL N DPRB INT1 RIH WITH CHAMP PACKER TO 3735'. 13:30 -16:00 2.50 DRILL N DPRB INT1 SET CHAMP PACKER AT 3735'. ATTEMPT TO ESTABLISH CIRCULATION THROUGH UPPER AND LOWER PERFS AT 900 PSI. SEVERAL ATTEMPTS WITH NO SUCCESS. 16:00 - 21:00 5.00 DRILL N DPRB INT1 RIH TO 8095' WITH CHAMP PACKER. 21 :00 - 21 :30 0.50 DRILL N DPRB INT1 CIRCULATE AT 5 BPM TO FILL DRILL PIPE WITH FRESH MUD. Printed: 12/26/2001 8:39:41 AM (' (' BP EXPLORATION Operations Summary Report Legal Well Name: 04-1 9A Common Well Name: 04-19A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 11/25/2001 End: 12/22/2001 Contractor Name: NABORS Rig Release: 12/22/2001 Rig Name: NABORS 2ES Rig Number: Date From-To HoUfsActivityCode NPT Phase D~sêription,.. of 0 perations 12/12/2001 21 :30 - 22:30 1.00 DRILL N DPRB INT1 SET CHAMP PACKER AT 8095' WITH TAIL PIPE AT 8200' TOP OF UPPER FERFS. ATTEMPT TO ESTABLISH CIRCULATION WITH 900 PSI, NO SUCCESS. 22:30 - 23:00 0.50 DRILL N DPRB INT1 RIH TO 8585' WITH CHAMP PACKER. 23:00 - 23:30 0.50 DRILL N DPRB INT1 SET CHAMP PACKER AT 8585' WITH TAIL PIPE AT 8699'. ESTABLISH CIRCULATION BETWEEN UPPER AND LOWER PERFS AT 1 1/2 BPM WITH 550 PSI, FULL RETURNS. 23:30 - 00:00 0.50 DRILL N DPRB INn RIH TO 8800' WITH CHAMP PACKER BELOW LOWER PERFS. 12/13/2001 00:00 - 00:30 0.50 DRILL N DPRB INT1 SET CHAMP PACKER AT 8800' 00:30 - 04:00 3.50 DRILL N DPRB INT1 CIRCULATE THROUGH 7" LINER SHOE AND PERFS. ESTABLISH CIRCULATION RATE OF 5 BPM WITH 1100 PSI, CIRCULATE TWO ANNULAR VOLUMES. UNSET PACKER. CIRCULATE 7" LINER AND 9 5/8" VOLUMES AND CONDITION MUD. 04:00 - 04:30 0.50 DRILL N DPRB INT1 POH ABOVE UPPER PERFS TO 8173'. 04:30 - 05:00 0.50 DRILL N DPRB INT1 SET CHAMP PACKER AT 8079'. TEST PACKER WITH 800 PSI TO CONFIRM INTEGRITY OF PACKER ELEMENTS. 05:00 - 08:30 3.50 DRILL N DPRB INT1 POH. LAY DOWN CHAMP PACKER. 08:30 - 09:00 0.50 DRILL N DPRB INT1 CLEAR RIG FLOOR 09:00 - 10:00 1.00 DRILL N DPRB INT1 RIG UP SCHLUMBERGER E-LiNE. CONNECT 7" EZSV CEMENT RETAINER. 10:00 -13:30 3.50 DRILL N DPRB INn RUN 7" EZSV CEMENT RETAINER AND SET AT 8732'. POH AND RIG DOWN SCHLUMBERGER. 13:30 -18:00 4.50 DRILL N DPRB INT1 RIH TO WITH HALLIBURTON STINGER AND CENTRALIZER ON DRILL PIPE TO 8717' 18:00 -19:00 1.00 DRILL N DPRB INT1 RIG UP CEMENTING LINES AND EQUIPMENT. CIRCULATE AND WASH TO TOP OF EZSV RETAINER AT 8732'. 19:00 - 20:30 1.50 DRILL N DPRB INT1 STING IN AND OUT OF CEMENT RETAINER. OK. STING IN AND ESTABLISH CIRCULATION. 20:30 - 21 :00 0.50 DRILL N DPRB INT1 TEST CEMENT LINES TO 3000 PSI. 21 :00 - 22:00 1.00 DRILL N DPRB INT1 MIX AND PUMP 20 BBL (102 SX) PREMIUM CEMENT AT 15.8 PPG WITH 0.5% UCS AND 0.3% HALARD-344 AT 2 BPM 460 PSI MAX. DISPLACE WITH RIG PUMP AT 5 BPM WITH 1250 PSI. FULL RETURNS. 22:00 - 23:00 1.00 DRILL N DPRB INT1 UNSTING FROM CEMENT RETAINER. PICK UP TO 8687'. CIRCULATE OUT EXCESS CEMENT AT 10 BPM WITH 2750 PSI. NO PURE CEMENT RETURNS BUT CONTAMINATED MUD WITH INCREASED WEIGHT OF 10.1 PPG AND A PH OF 11. APPROX 70 BBL 23:00 - 00:00 1.00 DRILL N DPRB INT1 RIG DOWN CEMENT LINES AND EQUIPMENT. CLEAR RIG FLOOR. 12/14/2001 00:00 - 02:30 2.50 DRILL N DPRB INT1 POH TO 3683' TOP OF THE 7" LINER. 02:30 - 03:00 0.50 DRILL N DPRB INT1 CIRCULATE 9 5/8" CASING VOLUME ONE BOTTOMS UP WHILE ROTATING AND RECIPROCATING THE DRILL PIPE. 03:00 - 05:00 2.00 DRILL N DPRB INT1 POH AND LAY DOWN HALLIBURTON CEMENT RETAINER STINGER AND CENTRALIZER. 05:00 - 07:00 2.00 DRILL N DPRB INT1 PICK UP BAKER LINER SETTING ASSEMBLY, 23 JTS OF 5" HWDP AND RIH TO 3716'. INSIDE 7" LINER HANGER. 07:00 - 08:00 1.00 DRILL P INT1 SET 7" LINER HANGER WITH 3000 PSI. SET ZXP LINER TOP PACKER. 08:00 - 10:30 2.50 DRILL P INT1 PRESSURE TEST ZXP LINER TOP PACKER WITH 4000 PSI, Printed: 12/26/2001 8:39:41 AM Page 6 of10 (' ( BP EXPLORATION 0 pe ratio nsS u mma ryRe po rt Page 7 of 10 Legal Well Name: 04-19A Common Well Name: 04-1 9A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 11/25/2001 End: 12/22/2001 Contractor Name: NABORS Rig Release: 12/22/2001 Rig Name: NABORS 2ES Rig Number: Date From-To Hours Activity Code NPT Phase De~criptibn .of..Operations 12/14/2001 08:00 - 10:30 2.50 DRILL P INT1 HOLDING 2000 PSI ON INSIDE OF DRILL PIPE. HOLD PRESSURE FOR 30 MINUTES. OK. 10:30 -11:00 0.50 DRILL N DPRB INT1 POH TO 2714' 11 :00 - 13:00 2.00 DRILL N DPRB INT1 INSTALL HALLIBURTON RTTS WITH SUB SURFACE CONTROL VALVE (STORM PACKER) IN STRING, RUN IN TO 33' BELOW WELL HEAD AND SET IN 9 5/8" CASING AND TEST TO 1000 PSI. 13:00-15:30 2.50 DRILL N DPRB INT1 DRAIN BOP STACK AND BLOW DOWN LINES. NIPPLE DOWN BOP AND ADAPTER FLANGE 15:30 -19:00 3.50 DRILL N DPRB INT1 REMOVE TUBING SPOOL. REPLACE 9 5/8" PACK OFF. INSTALL NEW TUBING SPOOL AND TEST TO 5000 PSI. OK. 19:00 - 21 :00 2.00 DRILL N DPRB INT1 NIPPLE UP BOP. TEST BOP X TUBING SPOOL CONNECTION TO 5000 PSI. 21 :00 - 21 :30 0.50 DRILL N DPRB INT1 PULL TEST PLUG AND INSTALL WEAR BUSHING. 21 :30 - 23:00 1.50 DRILL N DPRB INT1 RETRIEVE HALLIBURTON RTTS WITH SUB SURFACE CONTROL VALVE (STORM PACKER) 33' BELOW WELL HEAD. POH AND LAY DOWN. 23:00 - 00:00 1.00 DRILL N DPRB INT1 POH WITH LINER HANGER SETTING TOOLS. 12/15/2001 00:00 - 00:30 0.50 DRILL N DPRB INT1 POH WITH LINER HANGER SETTING TOOLS 00:30 - 02:30 2.00 DRILL N DPRB INT1 LAY DOWN LINER HANGER SETTING TOOLS 02:30 - 04:30 2.00 DRILL P PROD1 MAKE UP CLEAN OUT BHA WITH 6 1/8" BIT 04:30 - 05:30 1.00 DRILL P PROD1 CUT AND SLIP DRILLING LINE 05:30 - 06:00 0.50 DRILL P PROD1 SERVICE TOP DRIVE 06:00 - 07:00 1.00 DRILL P PROD1 RIH TO 3660' 07:00 - 08:30 1.50 DRILL N RREP PROD1 REPAIR TOP DRIVE. BYPASS FILTER IN HYDRAULIC SYSTEM. 08:30 - 11 :30 3.00 DRILL P PROD1 RIH FROM 3630' TO 8580' 11 :30 - 12:00 0.50 DRILL P PROD1 WASH FROM 8580' TO 8736' TOP OF EZSV. NO CEMENT ON TOP OF RETAINER. 12:00 - 20:30 8.50 DRILL P PROD1 DRILL EZSV CEMENT RETAINER, CEMENT TO LANDING COLLAR AT 8913', CEMENT TO FLOAT COLLAR AT 8955' AND CEMENT TO SHOE AT 8999'. 20:30 - 22:30 2.00 DRILL P PROD1 DISPLACE 9.9 PPG LSND MUD WITH 8.4 PPG QUICKDRIL-N MUD. 22:30 - 00:00 1.50 DRILL N DPRB PROD1 WELL FLOWING. SHUT IN WELL. CHECK FOR TRAPPED PRESSURE. SIDPP 310 PSI. SICP 210 PSI. KILL WEIGHT MUD 9.2 PPG TO KILL WELL AT PERFS AT 8200' (7712' TVD) 12/16/2001 00:00 - 03:00 3.00 DRILL N DPRB PROD1 KILL WELL. CIRCULATE OUT INFLUX USING DRILLER'S METHOD WHILE BUILDING KILL WEIGHT MUD IN PITS FROM 8.4 PPG TO 9.3 PPG. JOHN CRISP OF AOGCC NOTIFIED. 03:00 - 08:00 5.00 DRILL N DPRB PROD1 KILL WELL. CIRCULATE 9.3 PPG KILL MUD USING WEIGHT AND WAIT METHOD. 30 SPM FINAL CIRCULATING PRESSURE 370 PSI. 08:00 - 09:30 1.50 DRILL N DPRB PROD1 MONITOR WELL. CIRCULATE THROUGH FULL OPEN CHOKE. WELL DEAD. OPEN BOP. 09:30 - 14:30 5.00 DRILL N DPRB PROD1 CIRCULATE AND CONDITION NEW 9.3 PPG QUICKDRIL-N MUD WHILE WEIGHTING UP SURFACE VOLUME TO 9.3 PPG. 14:30 - 17:30 3.00 DRILL P PROD1 DRILL 7" LINER FLOAT SHOE. DRILL 61/8" HOLE TO 9020' 17:30 - 18:30 1.00 DRILL P PROD1 PULL BIT BACK INTO 7" LINER SHOE. PERFORM FIT AT Printed: 12/26/2001 8:39:41 AM (' ( BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: 04-19A Common Well Name: 04-19A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 11/25/2001 End: 12/22/2001 Contractor Name: NABORS Rig Release: 12/22/2001 Rig Name: NABORS 2ES Rig Number: ,,' Qate.,... ... From -To Hours Activity Code NPT Phase Qescriptionof OPerations ... ... , .. 12/16/2001 17:30 -18:30 1.00 DRILL P PROD1 9000' MD (8505 TVD) TO 10.0 PPG EMW WITH 9.3 PPG MUD TO 309 PSI ON SURFACE. 18:30 - 22:00 3.50 DRILL P PROD1 POH TO 556' 22:00 - 23:00 1.00 DRILL P PROD1 SERVICE TOP DRIVE. 23:00 - 23:30 0.50 DRILL N RREP PROD1 REPAIR CROWN-O-MATIC. AIR SUPPLY SYSTEM. 23:30 - 00:00 0.50 DRILL P PROD1 POH TO BHA. 12/17/2001 00:00 - 04:00 4.00 DRILL P PROD1 CHANGE BIT AND BHA. HOLD PJSM WITH CREW, INSTALL RADIOACTIVE SOURCE, MAKE UP NEW BHA. 04:00 - 09:00 5.00 DRILL P PROD1 RIH TO 8955' 09:00 - 09:30 0.50 DRILL P PROD1 CIRCULATE AND PRECAUTIONARY WASH TO BOTTOM AT 9020'. 09:30 - 00:00 14.50 DRILL P PROD1 DRILL 61/8" HOLE FROM 9020' TO 9348'. 12/18/2001 00:00 - 06:00 6.00 DRILL P PROD1 DRILL 61/8" HOLE FROM 9348' TO 9430'. 06:00 - 08:00 2.00 DRILL P PROD1 CIRCULATE HIGH VIS SWEEP AND SPOT LINER PILL IN OPEN HOLE. 08:00 - 09:30 1.50 DRILL P PROD1 POH TO 7" LINER SHOE. TIGHT HOLE FROM 9300' TO 9250'. HOLE NOT TAKING CORRECT FILL MONITOR WELL, STATIC. 09:30 - 10:00 0.50 DRILL N DPRB PROD1 RIH TO BOTTOM 9430'. NO PROBLEMS. 10:00 -12:30 2.50 DRILL N DPRB PROD1 CIRCULATE HIGH VIS BARFIBER SWEEP. SPOT 20 BBL LINER RUNNING PILL IN OPEN HOLE. MONITOR WELL, STATIC. 12:30 -14:00 1.50 DRILL N DPRB PROD1 POH FROM 9430' TO 8947'. WELL NOT TAKING ANY FLUID. WELL STATIC. 14:00 - 14:30 0.50 DRILL N DPRB PROD1 RIH TO 9430' TD. NO PROBLEMS. WELL STATIC. 14:30 - 16:00 1.50 DRILL N DPRB PROD1 CIRCULATE BOTTOMS UP. NO INFLUX NOTED. WELL STATIC. 16:00 -16:30 0.50 DRILL N DPRB PROD1 POH FROM 9430' TO 8947'. WELL NOT TAKING ANY FLUID. WELL STATIC. 16:30 -17:30 1.00 DRILL N DPRB PROD1 POH FROM 8947' TO 8000'. HOLE NOT TAKING CORRECT FILL WELL STATIC. 17:30 -18:00 0.50 DRILL N DPRB PROD1 RIH FROM 8000' TO 9430'. NO PROBLEMS. WELL STATIC. 18:00 - 20:00 2.00 DRILL N DPRB PROD1 CIRCULATE AND RAISE MUD WEIGHT FROM 9.3 PPG TO 9.5 PPG. WELL STATIC. 20:00 - 20:30 0.50 DRILL P PROD1 POH FROM 9430' TO 8947' INSIDE THE 7" LINER SHOE. CORRECT HOLE FILL MONITOR WELL, STATIC. 20:30 - 21 :00 0.50 DRILL P PROD1 POH FROM 8947' TO 8434'. SLM. DROP 2" DRIFT. 21 :00 - 22:00 1.00 DRILL P PROD1 CUT AND SLIP DRILLING LINE. 22:00 - 22:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE 22:30 - 00:00 1.50 DRILL P PROD1 POH FROM 8434' TO 4757'. SLM. 12/19/2001 00:00 - 02:00 2.00 DRILL P PROD1 POH TO BHA. 02:00 - 05:30 3.50 DRILL P PROD1 LAY DOWN BHA. PJSM WITH CREW AND LAY DOWN RADIOACTIVE SOURCE 05:30 - 06:00 0.50 CASE P COMP RIG UP CASSING RUNNING EQUIPMENT. 06:00 - 06:30 0.50 CASE P COMP RUN 41/2" LINER FLOAT EQUIPMENT. CHECK FLOATS ARE CLEAR. 06:30 - 09:00 2.50 CASE P COMP RUN 33 JTS 4 1/2" L-80 12.6# BTC-MOD LINER. 09:00 - 09:30 0.50 CASE P COMP MAKE UP BAKER 7" X 5" FLEXLOCK HYDRAULIC LINER HANGER AND ONE STAND OF 4" DRILL PIPE. 09:30 - 10:00 0.50 CASE P COMP CIRCULATE LINER VOLUME. CHECK WEIHTS. 10:00 - 12:00 2.00 CASE P COMP RIH WITH 41/2" LINER ON 4" DRILL PIPE, 1439' - 3118'. 12:00 -13:00 1.00 CASE N RREP COMP REPAIR HYDRAULIC HOSE ON LINK TILT TOP DRIVE 13:00 -19:30 6.50 CASE P COMP RIH WITH 41/2" LINER ON 4" DRILLPIPE FROM 3118' TO Printed: 12/26/2001 8:39:41 AM ( ( BP EXPLORATION Operations Summary Report Page 90f 10 Legal Well Name: 04-19A Common Well Name: 04-19A Spud Date: 11/25/2001 Event Name: REENTER+COMPLETE Start: 11/25/2001 End: 12/22/2001 Contractor Name: NABORS Rig Release: 12/22/2001 Rig Name: NABORS 2ES Rig Number: Ho.urs ..ActivityCode NPT Phase . Dj9§criptipnof Operations 12/19/2001 13:00 - 19:30 6.50 CASE P COMP 8925'. FILL PIPE EVERY 10 STANDS. MAKE UP CEMENT HEAD AND STAND IN DERRICK. 19:30 - 20:30 1.00 CASE P COMP CIRCULATE DRILL PIPE AND LINER VOLUME. 20:30 - 21 :30 1.00 CASE P COMP RIH WITH 4 1/2" LINER ON 4" DRILLPIPE FROM 8925' TO 9430'. 21 :30 - 23:30 2.00 CEMT P COMP MAKE UP CEMENTING LINES. CIRCULATE. HOLD PJSM WITH RIG, CEMENTING AND TRUCK CREWS. START BATCH MIXING CEMENT. 23:30 - 00:00 0.50 CEMT P COMP TEST CEMENTING LINES TO 4000 PSI WITH WATER. 12/20/2001 00:00 - 01 :00 1.00 CEMT P COMP PUMP 20 BBL ALPHA SPACER 9.8 PPG. PUMP 33 BBL BATCH MIXED 15.6 PPG PREMIUM CEMENT WITH 2 % LATEX-2000, 3% D-AIR 3,3.4% HALARD-434B, 1% BENTONITE AND 0.35 CFR-3. AT 4 BPM WITH 700 PSI. DISPLACED WITH 101 BBL MUD AT 5 BPM WITH 300 PSI. BUMP THE PLUG WITH 4000 PSI. FLOATS HELD. CEMENT IN PLACE 00:47 HRS. 01 :00 - 02:00 1.00 CEMT P COMP SET 7" X 5" FLEXLOCK HYRRAULIC LINER HANGER. CIRCULATE 25 BBL TO MOVE EXCESS CEMENT UP THE HOLE. SET ZXP LINER TOP PACKER. CIRCULATE BOTTOMS UP. 5 BBL CEMENT RETURNS. 02:00 - 02:30 0.50 CEMT P COMP TEST ZXP LINER TOP PACKER WITH 3500 PSI. OK. 02:30 - 05:00 2.50 CEMT P COMP DISPLACE 9.3 PPG MUD IN WELL WITH SEA WATER AT 10 PBM WITH 1950 PSI 05:00 - 06:30 1.50 CEMT P COMP RIG DOWN CEMENT HEAD AND LINES. CLEAR RIG FLOOR. 06:30 - 15:00 8.50 CEMT P COMP POH LAY DOWN 4" DRILL PIPE 15:00 -16:00 1.00 CEMT P COMP LAY DOWN LINER RUNNING/SETTING TOOLS. CLEAR RIG FLOR. PULL WEAR BUSHING. 16:00 -17:00 COMP TEST 9 5/8" CASING, 7" LINER AND 41/2" LINER TO 4000 PSI. 17:00 -19:30 COMP RIG UP TO RUN 41/2" X 51/2" X 7" COMPLETION. RIG UP TORQUE TURN TONGS AND EQUIPMENT. HOLD PJSM WITH RIG CREW, BAKER AND POWER TONG CREW. 19:30 - 00:00 COMP RUN 4 1/2" WIRELINE ENTRY GUIDE ASSEMBLY, XN NIPPLE, X NIPPLE, PACKER, X NIPPLE AND ONE JT 4 1/2" NSTC 12.6# L-80 TUBING. CROSS OVER TO 51/2" STL 17# L-80 TUBING AND RIH TO 1231' 12/21/2001 00:00 - 08:00 COMP RUN 5 1/2" 17#, STL, L-80 TUBING FROM 1231' TO 4458'. TORQUE TURN EVERY CONNECTION. 08:00 - 08:30 COMP CHANGE OVER POWER TONG EQUIPMENT FROM 5 1/2" TO 7" 08:30 - 17:30 COMP RUN 7" 26#, STL, L-80 TUBING FROM 4458' TO 8095'. TORQUE TURN EVERY CONNECTION 17:30 - 20:30 COMP SPACE OUT TUBING. INSTALL 7" TUBING HANGER AND LAND STRING WITH WLEG 2' OFF BOTTOM OF TIE-BACK SLEEVE. 20:30 - 21 :30 COMP INSTALL 7" TWO WAY CHECK. TEST TO 1000 PSI FROM BELOW. 21 :30 - 22:30 COMP RIG DOWN TUBING RINNING TOOLS AND CLEAR RIG FLOOR 22:30 - 00:00 1.50 WHSUR P COMP NIPPLE DOWN BOP. 12/22/2001 00:00 - 01 :00 1.00 BOPSU P COMP NIPPLE DOWN BOP. 01 :00 - 04:00 3.00 WHSUR P COMP NIPPLE UP TUBING HEAD ADAPTER AND TREE. FMC 13 Printed: 12/26/2001 8:39:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ( (' BP EXPLORATION Operations Summary Report 01 :00 - 04:00 3.00 WHSUR P COMP 04:00 - 05:00 1.00 WHSUR P COMP 05:00 - 06:00 1.00 WHSUR P COMP 06:00 - 08:30 2.50 CHEM P COMP 04-19A 04-19A REENTER+COMPLETE NABORS NABORS 2ES 3.00 WHSUR P COMP Page 10 of 10 Start: 11/25/2001 Rig Release: 12/22/2001 Rig Number: Spud Date: 11/25/2001 End: 12/22/2001 From,- To HoUrs' Activity Code NPT Phase Descriptign bf.Qperations 12/22/2001 08:30 - 11 :30 11:30-14:30 14:30 - 16:00 16:00 - 16:30 3.00 WHSUR P COMP 1.50 WHSUR P 0.50 RIGD P COMP COMP 5/8" X 7 1/16" 5000 PSI. PRESSURE TEST TREE AND TUBING HEAD ADAPTER TO 5000 PSI FOR 1 0 MINUTES. OK. PULL TWO WAY CHECK WITH DRILL SITE MAINTENANCE LUBRICATOR. REVERSE CIRCULATE 275 BBL CLEAN SEA WATER AND SPOT 83 BBL SEA WATER WITH CORROSION INHIBITOR IN 7" X 9 5/8" ANNULUS. FREEZE PROTECT 7" X 9 5/8" ANNULUS AND 7" TUBING TO 2200' WITH 140 BBL DIESEL AND ALLOW TO 'U' TUBE. DROP PACKER SETTING BALL AND ROD. SET BAKER S-3 7" X 41/2" PACKER. TEST TUBING AND ANNULUS TO 4000 PSI. OK. NOTE: JEFF JONES OF AOGCC WAVED WITNESSING TEST. INSTALL BACK PRESSURE VALVE. SECURE WELL RIG DOWN. FINISH CLEANING PITS. RIG RELEASED AT 16:30 HRS 12/22/2001 FOR MOVE TO WELL 5-26A Printed: 12/26/2001 8:39:41 AM (' ( Well: Field: API: Permit: 04-19Ai Prudhoe Bay Unit 50-029-21791-01 201-218 Rig Accept: Rig Spud: Rig Release: Drilling.B!g: 11/28/01 12/03/01 12/22/01 Nabors 2ES "~_.'_._--'------------'-_.'------_._._----'-------------.-'-------".--------.".-- POST RIG WORK 01/01/02 PULL BPV. PULLED BALL & ROD. PULLED 4 112" RHC PLUG BODY FROM XN NIPPLE @ 8062' WLM. RDMO. LEFT WELL SHUT IN. NOTIFIED DSO. 01/02/02 MIRU CTU#3. N2 LIFT OFF TOP 4000' TO UNDERBALANCE WELL BY 1000PSI. RESERVOIR PRESSURE ESTIMATED AT 3350. RDMO. 01/06/02 RAN 2 718" DUMMY GUN WI SAMPLE BAILER & TAG TO @ 9326' SLM. RET SAMPLE OF CEMENT. WELL LEFT SHUT-IN. 01/10/02 TAGGED TO AT 9345 FT MD. RUN CBL. TOP OF CEMENT FOUND AT 8123 FT MD. GOOD CEMENT FOUND FROM 8825-8700 FT MD. FAIR TO GOOD CEMENT SEEN THROUGHOUT THE REST OF THE INTERVAL FROM 9262 TO TOC. PERFED 9120-9138 FT MD WITH 2 7/8" HSD @ 6 SPF (2906 POWRJET, HMX). RDMO. WELL LEFT SHUT IN. 01/27/02 RIH, TAGGED HARD AT 1698' ON SUSPECTED ICE PLUG. 02/08/02 MIRU CTU#3. WEEKLY BOP TEST. REBUILD TOP BLINDS. COMPLETE BOP TEST. RIH WITH 3" DOWN-JET NOZZLE. TAG ICE PLUG AT 795' CTM. JET THRU ICE BRIDGES TO 1920' CTM. SHUT IN RETURNS. DRIFT TBG TO 3700' CTM. POOH IDLING IN 60/40 MW ON WAY OOH. LEFT WELL SHUT-IN FOR UPCOMING PERFS. 02/09/02 MIRU ELINE, PJSM, PT LUB, RIH WITH 2 7/8" HSD PJ GUN 6 SPF, LOG TIE IN PASS, PERFORATE 9090- 9110, GUN FIRED, POOH, RU 2ND 2 7/8" HSD PJ GUN 6 SPF, LOG TIE IN PASS, PERFORATE 9070-9090, GUN FIRED, POOH, TOTAL PERFORATED INTERVAL 9070-9110. RDMO ELINE, NOTIFY PAD OP THE WELL IS SHUT IN. 02/11/02 MIRU CTU#3. PUMP DOWN BACKSIDE AND RIH. WELL LOCKED UP AFTER 86.3 BBLS. BLEED PRESSURE, LOOK FOR PLUG IN SSS NIPPLE (2184'). ** SUGGEST TO APE THAT WE PRE-PRODUCE THIS INJECTOR.** 02/12/02 RE-FP WELL, REPAIR REEL SWIVEL AND REPLACE 5 CHICKSANS ON FLOWBACK. RIH W/3" JSN. ACID WASH PERFS WITH 94 BBLS 7.5% DAD ACID, 51 BBLS 9:1 MUD ACID. OVER-DISPLACE ACID INTO FORMATION W/3% NH4CL. GAS IN WELLBORE MASKED WHP MONITORING F/ACID REACTION. OBSERVED GOOD BREAKS IN CT PRESSURE AS EACH ACID STAGE HIT PERFS. OMIT INJ TEST DUE TO GAS IN WELLBORE. POOH. LEFT WELL SHUT-IN FP'D TO 2500'. 02/17/02 PUMP 290 BBLS OF 50/50 METHWATER @ 5 BPM DOWN THE TUBING FOR INJECTIVITY TEST. 02/24/02 MITIA PASSED TO 2500 PSI. 02/25/02 MITIA PASSED TO 2500 PSI (AOGCC WITNESSED - JEFF JONES, POST RWO). ( ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 4-19A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 3,820.50' MD 3,853.00' MD 9,430.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECE'\/ED JAN 0 3 2002 Alaska Oil & Gas Con:), wm!!l~~Il\ AnrJ;.orage 29-Dec-0 1 ~"" "¡iJiF2"'~'~";:'rl':;':"6":':'~ ~~"":"""""~"""""'.:.'""'" "':'.':.' t. . ';ià~~¡'.:'" I. . ."'-., North Slope Alaska Alaska Drilling & Wells PBU _EOA DS 04, Slot 04-19 04-19 - 4-19A Job No. AKMM11205, Surveyed: 18 December, 2001 c--- SURVEY REPORT 28 December, 2001 Your Ref: API 500292179101 Surface Coordinates: 5952791.73 N, 713057.60 E (70016' 26.4359" N, ~48° 16' 35.2441" W) Kelly Bushing: 51.00ft above Mean Sea Level ( Survey Ref: 5vy11060 A Halliburton Company North Slope Alaska Measured Depth (ft) I , ',- 3820.50 3853.00 3888.21 3918.00 3948.26 3972.22 3999.96 4031.42 4063.03 4093.14 4125.73 4156.70 4189.79 4219.36 4252.16 4283.03 4313.23 4345.35 4376.46 4405.32 4436.88 4468.62 4498.56 4533.03 4563.40 4595.03 4687.00 4778.28 4873.67 4967.50 Incl. 0.300 0.260 2.810 5.360 8.450 10.630 14.180 15.810 16.500 17.320 18.150 18.880 20.200 21.240 23.170 24.710 26.900 29.880 31.960 34.640 37.600 38.390 38.420 38.620 38.810 38.960 39.170 33.770 33.910 33.590 Azim. 181.500 186.030 357.060 357.530 357.700 357.770 357.820 357.860 357.890 357.910 355.340 356.990 358.440 358.810 359.390 0.370 359.580 359.120 359.080 357.450 356.540 356.740 356.880 356.150 356.330 356.060 355.890 355.570 353.830 355.920 Sub-Sea Depth (ft) 3769.22 3801.72 3836.92 3866.63 3896.67 3920.29 3947.38 3977.77 4008.13 4036.94 4067.98 4097.35 4128.53 4156.19 4186.55 4214.77 4241.95 4270.21 4296.90 4321.02 4346.51 4371.52 4394.98 4421.95 4445.65 4470.27 4541.68 4615.05 4694.29 4772.31 Sperry-Sun Drilling Services Survey Report for 04-19 - 4-19A Your Ref: AP/500292179101 Job No. AKMM11205, Surveyed: 18 December, 2001 Vertical Depth (ft) 3820.22 3852.72 3887.92 3917.63 3947.67 3971.29 3998.38 4028.77 4059.13 4087.94 4118.98 4148.35 4179.53 4207.19 4237.55 4265.77 4292.95 4321.21 4347.90 4372.02 4397.51 4422.52 4445.98 4472.95 4496.65 4521.27 4592.68 4666.05 4745.29 4823.31 ..-- ----,,_.._...,,------,---- m"_"'-,-,.",'_m,_",_""",-_.'---,,-,"'-""-".--...,..-,-"""","-""'.-.----.".--.-...---.----..----- 28 December, 2001 - 15:13 Local Coordinates Northlngs Eastlngs (ft) (ft) 9.44 N 9.28 N 10.06 N 12.18 N 15.82 N 19.79 N 25.74 N 33.87 N 42.66 N 51.41 N 61.32 N 71.13 N 82.19 N 92.65 N 105.04 N 117.57 N 130.71 N 145.98 N 161.97 N 177.80 N 196.38 N 215.88 N 234.45 N 255.88 N 274.83 N 294.65 N 352.46 N 406.55 N 459.44 N 511.35 N 5.97 E 5.96 E 5.91 E 5.81 E 5.66E 5.50E 5.27 E 4.97 E 4.64 E 4.32 E 3.73 E 3.08 E 2.64 E 2.39 E 2.20 E 2.17 E 2.16 E 1.99 E 1.74 E 1.25 E 0.27E 0.88W 1.91 W 3.22W 4.46 W 5.78W 9.8SW 13.88 W 18.78 W 23.44 W Global Coordinates Northings Eastings (ft) (ft) 5952801.33 N 5952801.18 N 5952801.96 N 5952804.07 N 5952807.70 N 5952811.66 N 5952817.61 N 5952825.73 N 5952834.51 N 5952843.25 N 5952853.13 N 5952862.92 N 5952873.96 N 5952884.41 N 5952896.79 N 5952909.31 N 5952922.45 N 5952937.71 N 5952953.68 N 5952969.50 N 5952988.04 N 5953007.50 N 5953026.03 N 5953047.42 N 5953066.33 N 5953086.09 N 5953143.77 N 5953197.72 N 5953250.45 N 5953302.21 N 713063.30 E 713063.29 E 713063.22 E 713063.06 E 713062.81 E 713062.54 E 713062.14 E 713061.61 E 713061.03 E 713060.46 E 713059.59 E 713058.66 E 713057.91 E 713057.36 E 713056.82 E 713056.44 E 713056.06 E 713055.45 E 713054.75 E 713053.81 E 713052.31 E 713050.61 E 713049.05 E 713047.14 E 713045.36 E 713043.48 E 713037.78 E 713032.22 E 713025.81 E 713019.69 E Page 2 of 5 --.---...-."..",--....-- . Alaska Drilling & Wells PBU_EOA DS 04 Dogleg Vertical Rate Section (0/100ft) 0.141 8.711 8.561 10.212 9.099 12.797 5.181 2.183 2.723 3.500 2.901 4.250 3.545 5.922 5.152 7.340 9.303 6.686 9.790 9.532 2.519 0.307 1 .441 0.727 0.716 0.256 5.920 1.026 1.284 9.28 9.12 9.91 12.03 15.67 19.64 25.59 33.73 42.53 51.28 61.20 71.03 82.09 92.56 104.95 117.47 130.61 145.88 161.87 177.71 196.30 215.83 234.42 255.88 274.86 294.70 352.60 406.77 459.77 511 .79 Comment Tie On Point Window Point c--- ( DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 04-19 - 4-19A Your Ref: AP/500292179101 Job No. AKMM11205, Surveyed: 18 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU EOA DS 04 - Measured Sub.Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 5061.79 31.910 3.130 4851.64 4902.64 562.27 N 23.94 W 5953353.10 N 713017.75 E 4.501 562.71 C------ 5153.91 31.430 2.840 4930.04 4981.04 610.57 N 21.42 W 5953401.45 N 713018.90 E 0.547 610.92 "- 5248.25 31.050 2.480 5010.70 5061.70 659.45 N 19.15 W 5953450.37 N 713019.79 E 0.449 659.72 5340.16 31.080 1.870 5089.43 5140.43 706.84 N 17.35 W 5953497.79 N 713020.24 E 0.344 707.05 5434.43 30.910 1.970 5170.24 5221.24 755.36 N 15.72 W 5953546.34 N 713020.50 E 0.188 755.51 5526.58 31.000 1.710 5249.26 5300.26 802.73 N 14.20 W 5953593.74 N 713020.68 E 0.175 802.83 5619.99 30.780 1.600 5329.42 5380.42 850.67 N 12.82 W 5953641.69 N 713020.70 E 0.243 850.71 5713.66 31.030 1.270 5409.79 5460.79 898.76 N 11.61 W 5953689.80 N 713020.55 E 0.322 898.76 5806.30 31.360 0.970 5489.04 5540.04 946.74 N 10.67 W 5953737.78 N 713020.12 E 0.394 946.69 5900.30 31.490 1.510 5569.25 5620.25 995.73 N 9.61 W 5953786.79 N 713019.80 E 0.330 995.65 5993.61 31.120 0.530 5648.98 5699.98 1044.21 N 8.75W 5953835.27 N 713019.29 E 0.675 1044.08 6086.69 29.850 359.220 5729.19 5780.19 1091.43 N 8.84W 5953882.47 N 713017.86 E 1.540 1091.29 6179.85 30.250 359.380 5809.83 5860.83 1138.07 N 9.41 W 5953929.08 N 713015.97 E 0.438 1137.93 6272.84 29.140 353.560 5890.62 5941.62 1184.00 N 12.20 W 5953974.91 N 713011.88 E 3.321 1183.92 6366.19 29.210 352.790 5972.13 6023.13 1229.19 N 17.61 W 5954019.92 N 713005.19 E 0.409 1229.23 6448.43 30.120 350.830 6043.59 6094.59 1269.47 N 23.42 W 5954060.02 N 712998.25 E 1.617 1269.65 6539.05 30.460 350.510 6121.84 6172.84 1314.57 N 30.83 W 5954104.90 N 712989.56 E 0.415 1314.93 6634.57 29.990 352.000 6204.37 6255.37 1362.09 N 38.14 W 5954152.19 N 712980.91 E 0.927 1362.62 ( 6728.44 28.560 352.760 6286.25 6337.25 1407.58 N 44.24 W 5954197.50 N 712973.53 E 1.574 1408.26 6822.24 28.150 353.220 6368.80 6419.80 1451.80 N 49.68 W 5954241.54 N 712966.84 E 0.495 1452.60 6914.44 28.740 355.860 6449.87 6500.87 1495.51 N 53.84 W 5954285.11 N 712961.44 E 1.506 1496.40 7008.61 26.890 355.270 6533.16 6584.16 1539.31 N 57.23 W 5954328.81 N 712956.81 E 1.986 1540.28 7102.80 25.220 357.500 6617.77 6668.77 1580.59 N 59.87 W 5954370.00 N 712953.01 E 2.055 1581.62 7196.96 24.870 359.020 6703.08 6754.08 1620.43 N 61.08 W 5954409.78 N 712950.66 E 0.778 1621.47 7290.60 24.840 358.480 6788.05 6839.05 1659.78 N 61.94 W 5954449.09 N 712948.69 E 0.244 1660.83 7383.80 24.940 356.410 6872.59 6923.59 1698.96 N 63.69 W 5954488.21 N 712945.83 E 0.941 1700.05 7476.51 21.100 354.390 6957.91 7008.91 1735.09 N 66.54 W 5954524.24 N 712941.96 E 4.228 1736.24 7569.68 18.770 352.050 7045.49 7096.49 1766.63 N 70.26 W 5954555.67 N 712937.35 E 2.643 1767.86 7664.00 15.960 356.570 7135.50 7186.50 1794.61 N 73.13 W 5954583.55 N 712933.68 E 3.303 1795.91 7757.75 12.780 358.510 7226.31 7277.31 1817.85 N 74.17W 5954606.75 N 712931.99 E 3.430 1819.17 ""'-------"""""----""'-"""---"'" .... ...,...,...-......................--.......",..... ..,............-.....-.........-..........------.-- '---'-"'--"""--" ._..-....... 28 December, 2001 - 15:13 Page 3 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 04-19 - 4-19A Your Ref: AP/500292179101 Job No. AKMM11205, Surveyed: 18 December, 2001 . Alaska Drilling & Wells North Slope Alaska PBU_EOA DS 04 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 7851.57 11.530 1.970 7318.03 7369.03 1837.60 N 74.12 W 5954626.49 N 712931.48 E 1.542 1838.90 (---- 7944.41 11.190 3.080 7409.05 7460.05 1855.87 N 73.32 W 5954644.78 N 712931.76 E 0.435 1857.14 '---.. 8038.95 10.700 2.310 7501.87 7552.87 1873.80 N 72.47 W 5954662.72 N 712932.10 E 0.541 1875.05 8132.84 10.460 0.460 7594.16 7645.16 1891.03 N 72.05 W 5954679.96 N 712932.04 E 0.443 1892.26 8225.31 10.190 0.040 7685.13 7736.13 1907.60 N 71.98 W 5954696.53 N 712931.64 E 0.303 1908.83 8318.75 9.720 358.700 7777.17 7828.17 1923.75 N 72.15 W 5954712.67 N 712931.01 E 0.561 1924.98 8411.85 8.780 358.680 7869.06 7920.06 1938.71 N 72.49 W 5954727.61 N 712930.24 E 1.010 1939.94 8505.34 7.790 357.380 7961.57 8012.57 1952.18 N 72.95 W 5954741.06 N 712929.41 E 1.078 1953.41 8596.87 7.230 354.870 8052.31 8103.31 1964.11 N 73.75 W 5954752.96 N 712928.27 E 0.709 1965.36 8688.80 6.500 355.530 8143.58 8194.58 1975.06 N 74.67 W 5954763.88 N 712927.04 E 0.799 1976.33 8783.06 5.630 352.300 8237.32 8288.32 1984.96 N 75.71 W 5954773.75 N 712925.72 E 0.991 1986.26 8876.28 5.130 346.020 8330.13 8381.13 1993.54 N 77.32 W 5954 782.28 N 712923.86 E 0.828 1994.87 8952.89 4.740 349.420 8406.45 8457.45 1999.97 N 78.73 W 5954788.67 N 712922.27 E 0.636 2001.34 9079.16 4.430 348.380 8532.32 8583.32 2009.88 N 80.67 W 5954798.52 N 712920.05 E 0.254 2011.29 9173.24 4.440 349.540 8626.12 8677.12 2017.02 N 82.07 W 5954805.61 N 712918.46 E 0.096 2018.47 9265.17 4.270 348.210 8717.78 8768.78 2023.86 N 83.41 W 5954812.42 N 712916.92 E 0.215 2025.35 9358.21 4.120 352.230 8810.57 8861.57 2030.57 N 84.57 W 5954819.09 N 712915.57 E 0.355 2032.08 9430.00 4.120 352.230 8882.18 8933.18 2035.68 N 85.27 W 5954824.18 N 712914.73 E 0.000 2037.21 Projected Survey ( All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.7020 (02-Dec-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 358.510° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9430.00ft., The Bottom Hole Displacement is 2037.46ft., in the Direction of 357.601° (True). '..-..---..-.""""'.-."""... ...---..-...........-..-.......,----"...---."",."""-,,'.".'-"-""--"""-".-,'.""----"---'--'--.--- ""...--.._..-"...,-....... 28 December, 2001. 15:13 Page 4 of 5 DrillQuest 2.00.08.005 North Slope Alaska Comments "-'"-' Measured Depth (ft) 3820.50 3853.00 9430.00 Sperry-Sun Drilling Services Survey Report for 04-19 - 4-19A Your Ref: API 500292179101 Job No. AKMM11205, Surveyed: 18 December, 2001 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 3820.22 3852.72 8933.18 9.44 N 9.28 N 2035.68 N Survey tool program for 04-19 - 4-19A From Measured Vertical Depth Depth (ft) (ft) 0.00 ,..,' """" ,," "', ..." . ' 0.00 28 December, 2001. 15:13 To Measured Vertical Depth Depth (ft) (ft) 9430.00 8933.18 Comment 5.97 E 5.96 E 85.27 W Tie On Point Window Point Projected Survey Survey Tool Description MWD Magnetic (4-19A) '......" "'.."".., """""""'-"""""""""---0'_--__-"--- Page 5 of 5 ---..-.....,,---.. ....,."......,,_. - ,,- .. . Alaska Drilling & Wells PBU EOA DS 04 (-- - ( DrillQucst 2.00.08.005 02/19/02 Scblmnbepger NO. 1826 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska 011 & Gas Cons Comm Attn: LIsa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay I Well Job # Log Description Date Bluellne Sepia Color Prints CD "( J-178 ......;\.€:)tt, "\ ...." d 22065 MCNL 01/20/02 1 1 1 NK-19A dO 1- 070 22041 SCMT (PDC) 01/22/02 2 1 D.S. 4-19A ~ D I-~' 'X'" 22061 SCMT (PDC) 01/10/02 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage, AK 99503-5711 ATfN: Sherrie Rece~ Ú Ck.p..... ) t1J\R 0 5 2002 ~Cons.Com~ Anchorage ImNNn Date Delivered: Re: DS4-19A -~ Cementing of 7" Casing ~C)\~ d-\% Subject: Re: DS4-19A -- Cementing of 7" Casing Date: Tue, 11 Dec 2001 16:00:29 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Quay, Walter D (Fairweather)" <QuayWD@BP.com> CC: "Robertson, Brian B" <RobertBB@BP.com> (' '. I( Walter and Brian I Bummer on the 7". There really aren't a lot of other options right now. North Star ran into a similar situation and they ran a USIT to determine the stuck point prior to perforating. Might get you a little deeper. Your 4-1/2" plan is acceptable. You need to assure that you get good cement above the liner top. The bond log will show you the quality on the 4-1/2" liner. Call with any questions. Tom Maunder, PE AOGCC "Quay, Walter D (Fairweather)" wrote: > Tom, > The drHling on 4-1 9A has progressed to the 7" casing point, the 7" liner > was run to bottom (9000' MD, 8505' TVD) and became packed off. Efforts to > establish any circulation were unsuccessful. Reciprocation was not possible > as the pipe was stuck. We believe the stuck and packed off pipe are in the > HRZ (top @ 8788' MD) 8S we had no losses and minimal drag until near bottom. > Our present operation is to perforate the 7" at 8700' MO, establish > circulation and proceed with cementing operations. > We would then complete the drilling of the well and cover these perfs with > the 4-1/2" liner. This would result in our completion packer being set > -400' above the Ivishak injection, not the < 200' as originally planned. > > On another issue with this well, we saw no evidence of the cuttings injected > zones. No anomalies in L WD logs, cuttings or drilling parameters. > > Please call or email if you would like to discuss this issue. > > Walter Quay > quaywd@bp.com > (907)564-4178 > (907)440-8632 .. Cell -------.-----. ----. ---- Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission I -.---_._----------------~-----_._---~._-_."-~-_..-.---1 10f2 12/11/01 4:00 PM RE: OS 04-19A ('" { ( Subject: RE: DS 04-19A Date: Tue, 20 Nov 2001 13:17:25 -0600 From: "Robertson, Brian B" <RobertBB@BP.com> To: "'Tom Maunder'" <tom_maunder@admin.state.ak.us>, "Quay, Walter D (Fairweather)" <QuayWD@BP.com>, "Robertson, Brian B" <RobertBB@BP.com> "Bill, Michael L" <BiIlML@BP.com> ' CC: Bob Crandall <bob_crandall@admin.state.ak.us> Tom, We believe that the likelihood of achieving valuable information from logging has been significantly diminished since we are now purposely proposing that we kick the well far enough away from the injection zone to avoid drilling problems. Further to our conversation we propose the following: 1. Run LWD GR/Res over the injection zone at +1- 5600' TVD. 2. If there is significant deviation 1 change of character between the GR/Res log and previous well logs (4-19 and 4-6? - will confirm), we will consider running electric line logs at section TD. 3. If hole conditions are acceptable and the above significant deviation was seen, we propose a single run containing, the Dipole sonic tool plus the triple combo (Den/Neut/Res etc.). Please call either myself or Walter if you have further questions that have to be resolved to allow for approval of the drilling permit. Many thanks for your help in expediting this permit and helping out with our changed view of the well. Regards Brian Robertson GPB Rotary Drilling Office: (907) 564-4192 Cell: (907) 240-8032 email: robertbb@bp.com -----Original Message----- From: Tom Maunder [mailto:tom maunder~admin.state.ak.uS] Sent: Tuesday, Noveñïber 2~ 7:55 A To: Walter Quay; Brian Robertson; Mike Bill Cc: Bob Crandall Subject: OS 04-19A Gentlemen, We are completing review of your proposed sidetrack of 4-19. I am aware that problems were encountered in your attempts to squeeze the disposal interval and have approved the alternate abandonment. In the proposed sidetrack plan, minimal logs are proposed over the 8-1/2" hole interval that may encounter some of the disposed mud. While I understand there is some concern what hole conditions might be encountered, we believe there needs to be a logging plan for that hole section that includes more than a GR. Please respond to this email with your proposal. On receipt and agreement to the logging program, you permit application will be forwarded for approval. Your early attention to this issue will 1 of 2 ~~~ 1K!M ~~~ /I ¿ eÞt~ ¡'fA t v'j '" ~ St#V ,).~,.j, þ~1 f'1 11/20/01 10:22 AM RE: OS 04-19A ( /1" ~ I, be appreciated. Tom Maunder, PE Sr. Petroleum Engineer AOGCC 2 of2 11/20/01 10:22 AM l ~ ~1r~1rŒ (ID~ ~~~~~~ ( ALAS IiA 0 IL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. PH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Walter Quay Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 04-19Ai BP Exploration (Alaska) Inc. Permit No: 201-218 Sur. Loc. 912' NSL, 5024' WEL, Sec. 26, TI1N, RI5E, UM Btmhole Loc. 2963' NSL, 5067' WEL, Sec. 26, TI1N, RISE, UM Dear Mr. Quay: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit 04-19Ai. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ú,~~ ~ Cammy d~chs1i Taylor Chair BY ORDER OF THE COMMISSION DATED this 21st day of November, 2001 jj c/Enclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Enviromnental Conservation wlo encl. STATE OF ALASKA . AND GAS CONSERVATION COMM( PERMIT TO DRILL 20 AAC 25.005 Open: 5930' - 6883' Sqzd: 5617' - 5625' true vertical Open: 5930' - 6883' Sqzd: 5617' - 5625' 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Siü.. .i?_tåói~ 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed R~LI'~ð'5'O'R'ëqüifëments Contact Engineer Name/Number: Walter Quay, 564-4178 Prepared By Name/Number: Sandra Stewman, 564-4750 21. I h, ereby certify that the foregoin~ ~s trlf ?~(~ correct to the bes, t of my ~nowl~~ge , J -- J Signed Brian Robertson ~1 't"eJltYv¡ Title Senior Drilling Engineer Date" I ¡ S; I () f ;;, '," ,,'," """ '.",:',<'",::,./(.<,:,::'::./:', , .",..CoOìm,issi:oh.,U$~,ønÎy,:":."::"',,,:::':'.'.'" .,:\.,',:..,;):::!:,'::','.:';:,,:,;'; , Permit Number J r ~ API Number Apt>rovaJ Date See cover letter ~4')1 -" 2 / L) 50- 029-21791-01 \ r c:+- \ \C') \ for other reQuirements Conditions of Approval: Samples Required DYes ~ No Mud Log Requiråd 0 YesBfNo Hydrogen Sulfide Measures ~Yes 0 No Directional Survey Required ..I81Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K CJ..?K 0 1 OK 0 15K '( 3.5K psi f~TtI Qt~E!r: 'b'\~~~~\ ",,~~~~~\ \()~~ \~ ~~~ ",~J1Ç)Cl~(t~~\. \. Onglnsl Sìgned By by oreter of \ \ Approved By """" ... ""'" - . -. Commissioner the commission Date \ \ \ C) \ ,() l Form 10-401 Rev. 12-01-85" UK' lJ , NAl Submit In triplicate .. ALASKA t 1 a. Type of work 0 Drill 181 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 912' NSL, 5024' WEL, SEC. 26, T11 N, R15E, UM At top of productive interval 2822' NSL, 5064' WEL, SEC. 26, T11N, R15E, UM At total depth 2963' NSL, 5067' WEL, SEC. 26, T11 N, R15E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028325, 211' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 3870' MD Maximum Hole Angle 18. CaSi~&~rOgram Specifications Hole Casino Weiaht Grade Couolina 8-1/211 7" 26# L-80 BTC-M 6-1/8" 4-1/211 12.6# L-80 BTC-M 1 b. Type of well Lenath 5185 585' 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 Scab Liner 7000 feet 7000 feet 6992 feet 6992 feet Length Size 115' 2984' 2011 13-3/8" 6993' 9-5/811 2946' 5" X 4-1/211 Perforation depth: measured 20. Attachments JON ~~~ d-1'liJ4 4 , ~ 10\ 0 Exploratory Q-Stratigraphic Test 0 Development Oil 181 Service 0 Development Gas rn Sin9l~Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Planned RKB = 50.2' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028324 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 04-19Ai 9. Approximate spud date 11/27/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9340' M 0 / 8918' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 0 32 Maximum surface 2554 psig, At total depth (TVD) 8455' / 3400 psig Setting Depth TCin Bottom MD TVD MD TVD 37201 3720' 8905 8506' 8755' 18363 9340' 8918' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Owmtitv of Cement (include staae data) 22 sx Class IG' 156 sx Class 'G' 113 sx Class 'G' Plugs (measured) Junk (measured) Cemented MD TVD 2150# Poleset 2500 sx CS III, 600 sx CS II 115' 29841 115' 2984' 1350 sx Class 'G', 300 sx CS I 6993' 6993' 65 Bbls Class 'G1 2947' - 5893' 2947' - 5893' RECEIVED NOV 1 5 2001 ( IWell Name: ( 4-19A Drill and Complete Summary I Type of Redrill (producer or injector): Injector Surface Location: x = 713,058/ Y = 5,952,792 9121 FSL, 50241 FEL, Sec. 26, T11 N, R15E Umiat Target Location: x = 712,962 1 Y = 5,954,700 28221 FSL, 50641 FEL, Sec. 26, T11 N, R15E Umiat Bottom Hole Location: x = 712,954 1 Y = 5,954,840 29631 FSL, 5067' FEL, Sec. 26, T11 N, R15E Umiat I AFE Number: 14J0473 I Estimated Start Date: 111/27/2001 I I MD: 19340' I TVD: 18918' I lB!U Nabors 2ES l.Qperatin~s to complete: 119.75 I Cellar Elevation: 121.2 I AKB: 150.2 I I I~ I I I Well Desi9!!-(conventional, slim hole, etc.).:j Conventional Big Bore - 9-5/8" Sidetrack ~ective: I Complete well as Zone 1 Injector. Formation Markers Formation Tops (wp3) MD TVD Com ments SV3 I T5 3833 3833 SVI I T3 4479 4434 UG4 I K15-Cl 5211 5059 UGI lUgS 6169 5921 ., TUZC 6759 6475 WS1/W.SAK 6977 6681 CM3/ K12 7230 6921 THRZ 8665 8279 LCU 8905 8506 7" Casinq Point Zone 4 8905 8506 Zone 3 8919 8519 Zone 2A 9111 8701 Bsad/Kavik 9225 8809 TO 9340 8918 TD Criteria: Need all LWD logs through the Base Sad (log -20' in Kavik). Also, would like a minimum of 20' of cased hole rat hole below the BSad when 4-1/2" liner is cemented in place. Therefore, will plan for 25' of rat hole, placing TD -lIS' MD below Bsad. The Base Kavik / Top Lisburne is estimated to be 150'+ TVD below the Bsad. Therefore, TD should be -50' TVD (57' MD) above the Lisburne. , 4-19A Permit to Drill 11/1412001 Page 1 c IT b" p ( ( aslng u Ing rogram. Hole Size Csg/ WtlFt Grade Conn Length Top Btm Tbg O.D. MDITVD M DITVD 8-1/2" 7" 26# L-80 BTC-Mod -5185' 3720' / 3720' 8905' / 8506' 6-1 /8" 4-1/2" 12.6# L-80 BTC-Mod -585' 8755' / 8363' 9340' /8918' Tubing 5-1/2" 17# L-80 8TL 5105 3650' / 3650' 8755' /8363' Tubing 7" 26# L-80 N8CC 3650 0' /0' 3650' / 3650' Directional KOP: 13870' MD Maximum Hole Angle: The original wellbore is essentially vertical. -320 at end of build Close Approach Well: This well passes all Close Approach issues. The closest approach well is D84-17 well near the 3850' KO center to center distance of 175' and deeper in the well, 435' center to center from DS 11-35A at 9236'( 4-19A) and 12,875'(11-35A). Survey Program: Gyro to set whipstock and KO. Standard MWD Surveys from once surveys are acceptable (high side established and interference is OK) from kick-off toTO. LSND PV 15-19 Whipstock Window in 9-5/8" Yield Point tauO H 25 - 35 3 - 8 9.0 - 9.5 HTHP ee's/3D min <9 Intermediate Mud Pro erties: LSND Densit Viscosit PV 9.7 45 - 55 15 - 19 8-1/211 hole section Yield Point tauO 20 - 25 3 - 7 H 9.0 - 9.5 HTHP ee's/3D min <9 Production Mud Pro erties: Ouickdril-N Densit Viscosit PV 8.4 - 8.5+ 45 - 60 5 - 8 6-1/811 hole section YP tauO 20 - 25 5 - 8 MBT <3 H 8.5 - 9.0 API FI N/C Lo 8 Y2" Intermediate: Drilling: MWD /GR Realtime over entire interval. Sam Ie catchers as er on-site Geolo ist. 0 en Hole: Cased Hole: CBT for AOGCC classification of this well. 6-1/8" Production: Drilling: Open Hole: Cased Hole: 4-19A Permit to Drill 11/14/2001 Page 2 c tp f ( emen ro~ ram ' Casing Size 7" Drilling Liner I Basis: lead: lead: -7905' MD to 3720' Liner Hanger with 100% OH excess. Tail: Based on 1000' of open hole with 30% excess and 82' of 7" shoe track. Tail TOC: -7905' MD -7559' TVD Fluid Sequence & Volumes: Pre None Flush Spacer 50 bbls Alpha Spacer weighted to 1 ppg above MW lead 186 bbl I 1022 ft3 I 322 sks of Premium, 3% Econolite, at 11.2 ppg and 3.24 dIsk, BHST 1800 I 130 BHCT 0 TT = Batch Mix 5 hrs Tail 32 bbl 1180 fe 1156 sks of 'G' at 15.9 ppg and 1.15 dIsk, BHST 1800 I 130 BHCT 0 TT = Batch Mix + 4 to 4.5 hrs Casing Size 14-1/2" Production Liner I Basis: lead: None Tail: Based on 82' of 4-112" shoe track, 574' of open hole with 50% excess, 150' of 7" x 4%" liner lap, and 200' of 7" x 4" DP annulus volume. Tail TOC: -8677' I' MD (8170'TVD).- Liner top. Fluid Sequence & Volumes: Pre 5 Bbls Walter Flush Spacer 40 bbls Alpha Spacer at 9.8 ppg lead None Tail 24 bbl 1135 ft3 1113 sks of Halliburton 'G' at 15.9 ppg and 1.19 dIsk, BHST 1900 I BHCT 1350 TT = Batch Mix + 4 to 4.5 hrs 4-19A Permit to Drill 11/14/2001 Page 3 ( ( Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section- . Maximum anticipated BHP: 3400 psi @ 8455' TVDss - Ivishak . Maximum surface pressure: 2554 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 3500 psi 8.6 ppg seawater / 6.8 ppg Diesel . Disposal . No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. . . 4-19A Permit to Drill 11/14/2001 Page 4 Sidetrack al,d Complete ProcedurJ ';ummary Pre-RiQ Work: * Notify the field AOGCC representative with intent to re-enter the well * 1. RU CTU and set bridge plug +/-5250' in 4.5" tubing. bridge plug. 2. Rig up slickline, tag and document top of cement and drift tubing for upcoming tubing cut. 3. Test the integrity of the cement plug and 9-5/8" casing by simultaneously pressure testing both the tubing and 9-5/8" annulus to 3500 psi for 30 minutes. 4. Rig up E-line. Run CMT cement evaluation log into 4Y2" scab liner to determine top of cement behind the liner. Log from -5000' MD to -500' above the TOC, as determined by the logging tool. Calculated TOC based upon volumes pumped is -4700' MD. If the log shows any signs of cement behind the liner which is expected to interfere with the planned tubing cut at -4250' MD, contact the project Drilling Engineer to discuss options. Otherwise, cut the 4Y2" L-80 tubing at -4250' MD (cut tubing in the center of full joint). This cut will not be fished, so the use of a jet or chemical cutter is at the discretion of the Wells Group Representative. Pressure test the 9-5/8" X 4-1/2" annulus to 1000 psi. 5. Perforate the 7" tubing at -2900' MD, immediately above the 4-1/2" scab liner. Design the tubing punch to perforate the 7" tubing, without damage to the 9-5/8" casing. 6. Displace the well to clean seawater by circulating down tubing through the perforations above the packer. Continue to circulate until clean seawater returns to surface. Freeze protect top 2200. MD with diesel. 7. Test the FMC 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. 8. Set a BPV in the tubing hanger. Secure well. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. . Place 200' of 15.8ppg class 'G' Cement on top of the RiQ Operations: 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC & test from below. 3. Nipple down tree. Nipple up and test BOPE to 250 / 3500 psi. 4. PU on 7" tubing and pull the seal assembly from the seal bore below 9-5/8" packer. Pull and lay down 7" tubing and 4-1/2" scab liner from E-line cut and above. 5. MU 9-5/8" packer milling assembly. RIH and mill 9-5/8" 'FB-1' permanent packer and push packer and remainder of tailpipe assembly to top of tubing stub. POOH. 6. RU E-line and set BP at -3894' MD (set as needed to avoid cutting casing collar). Test 9-5/8" casing to 3500 psi for 30 minutes. 7. RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock and set on BP. Mill window in 9-5/8" casing at -3870' MD. Prior to POH, perform FIT to 12.5 ppg EMW. 8. RIH with 8%" drilling assembly (with MWD/GR) to whipstock. Kick-off and drill the 8-1/2" intermediate section to Top Sadlerochit Zone 4 @ :1:8905' MD (8506' TVD). 9. Run and cement 7",26# intermediate drilling liner to -150' back into window. POH. 10. Make up and RIH with a 6-1/8" directional assembly (with MWD/GR/RES/DEN/NEU) to the 7" liner landing collar. 11. Test the 9-5/8" casing and 7" liner from the landing collar to surface to 3500 psi for 30 minutes. 12. Drill shoe track and 20' of new formation. Conduct FIT to 9.5 ppg EMW. 13. Drill 6-1/8" production section as per directional plan to an estimated TD of 9340' MD (8918' TVD). 14. Run and cement a 4%", 12.6# L-80 solid production liner throughout the 6-1/8" wellbore. Displace well to clean seawater above liner top. POOH LD DP. r 15. Test the 4%",7", and 9-6/8" casing from the 4-1/2" landing collar to surface to 3500 psi for 30 min. 16. RU e-line unit and run CBT to evaluate cement behind 7" casing (AOGCC regulations for injection well classification). 17. Run a 4Y2" x 5%" x 7" L-80 completion tying into the 4-1/2" liner top. 18. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 19. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 20. Freeze protect the well to -2200' and secure the well. 21. Rig down and move off. Post-RiQ Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below the production packer. 2. Perforate approximately 75' of Zone 2 & 3 with E-line conveyed guns. 3. Rig up flowline. 4-19A Permit to Drill 11/14/2001 Page 5 Job 1: MIRU Hazards and Contingencies ~ The G&I Plant is very close to this well. The Super-Sucker tent and the cement berm will need to be removed to get the rig over the well. The two adjacent wells, 4-18 and 4-24 are approximately 60' and 60' from the 4-19 wellhead respectively. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. ~ DS 4 Pad is designated as an H2S site. Follow Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: ( ( Adjacent producers at Surface: 4-49 1950 ppm 4-40 615 ppm 4-18 440 ppm 4-37 405 ppm 4-33 360 ppm 7/1/2001 1/1 0/2001 10/9/2001 9/21/2001 8/10/2001 ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. Job 2: Decomplete Well Hazards and Contingencies ~ The perforations and bottom section of this well should be isolated by 2 barriers (the cement plug and the seawater). \The plug will be tested in the Pre-rig operations. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. Job 3: Run Whipstock Hazards and Contingencies ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings which may have settled out. Job 5: Drill 8Y2" Intermediate Hole Hazards and Contingencies ~ On prior 4 Pad wells, lost circulation in the intermediate section has been a minor problem. Extreme care should be taken when picking the 7" casing point at the base of the HRl to remain above lone 4 (with its significant loss circulation risk with 10 ppg mud and 7.6 ppg pressure) ~ To drill through the HRl, 4 Pad has a limited history of wellbore stability problems and have drilled this with 9.4 to 10.2 ppg mud weights. At the 12-15° inclination the HRl could be drilled with MW as low as 9.5 ppg. 9.7/9.8 ppg is the targeted MW.. Follow all shale drilling practices to limit high ECD's, and maintain proper mud weights and shale stabilizers in the drilling fluid. ~ The kick tolerance for the 8Y2" open hole section would be 135 bbls assuming a kick from zone 4 at 8900' MD, or 70 bbls with a kick from the injected zone at 6000'. The zone 4 scenario assumes 7.6 ppg pore pressure @ 9030' MD (8506' TVD) with the injected zone scenario assuming a 9.1 ppg pore pressure at 6000' MD (5950' TVD). Both of these scenarios assume 12.5 ppg fracture gradient at the 9-5/8" window, and 9.5 ppg mud in the hole. ~ Drilling Close Approach: All wells pass BP Close Approach guidelines in this interval. Job 6: Install 7" Intermediate Liner Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the HRl instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. 4-19A Permit to Drill 11 /14/2001 Page 6 Job 7: Drill 6-1/8" productio~~ .Dle Hazards and Contingencies ~ No fault crossings are planned Lisburne/Base Kavik. ~ Pad 4 has a history of minor lost circulation events while drilling in the reservoir section. These losses have been handled by LCM/time. Be prepared for losses by establishing a contingency plan(pumping fibrous LCM pills, sufficient drilling fluid volume). ~ The kick tolerance for the 6-1/8" open hole section would be an infinite influx assuming a kick from the Ivishak at -8905' MD. This is a worst case scenario based on an 7.6 ppg pore pressure gradient, a fracture gradient of 9.5 ppg at the 7" shoe, and 8.5 ppg mud in the hole. ~ Drilling Close Approach: All wells pass BP Close Approach guidelines. Job 9: Install 4Y2" Production Liner Hazards and Contingencies ~ Differential sticking could be a problem. The 8.5 ppg Ouickdril will be -400 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RPs .:. "Modified Conventional Liner Cementing" RP ( in the drilling of 4-19A. Ensure the TD is -50' TVD above the Operational Specifics . Run 4 Y2" liner as follows: NOTE: The Baker 'ZXP' is planned to be run and set mechanically without the Hydraulic Pusher Tool, however if lost circulation is encountered while drilling the production interval the Pusher Tool will be run to allow the packer to be set with hydraulic pressure. 0 Hallibu rton Float Shoe 0 One joint 4-1/2",12.6#, L-80, IBT-Mod 0 Halliburton Float Collar 0 One joint 4-1/2",12.6#, L-80, IBT-Mod 0 Baker Landing Collar 0 Sufficient joints 4-1/2",12.6#, Buttress for 150' of liner lap. 0 Baker 7" x 5" 'HMC' Hydraulic liner hanger pinned for -2600 to 2900 psi. (with xo to 4 ¥2" Vam ACE). 0 Baker 'ZXP' mechanical-set packer with 6' tie back sleeve (set with Rotating Dog Sub). 0 Baker 'C-2' running tool & Rotating Dog Sub for setting 'ZXP' liner top packer. 0 DP to surface Job 12: Run Com~ Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psiaat100°F. Job 13: ND/NU/Release Ri Hazards and Contingencies ~ See Job 1 for adjacent well spacing. Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. 4-19A Permit to Drill 11/14/2001 Page 7 TREE = CrN WELLHEAD= FMC GEN IV """w,.."""._-,--'^",W"""w"'""",'"""""",.-""",""",,""'~' "ACTUATOR= BAKERC -,,^'W,""^W,'~'-^"',""","'^,'_W'N,,",",'W^"""'~W_""w".. KB. ELEV = 60' ....,.........,.........,.."",..........""......,.............."..,........",....".. BF. ELEV = ----",-,,--'"_.,,-"'"'--,~'"-"^, "~~!'-~--_...__..^,--"",,-,,-=7- Max Angle = 2 @ 2449' -----^--"-"--"""""~-~"-"W"""" Datum MD = 8877' -'-"-"".-"""""""'-""""'-"""""...."..-."'.""---'..."... DatumlVD= 8800' SS 04-1 g' :urrent Status TOPOF 5" LNR- SCAB I 15" LNR-SCAB, 15#, .0189 bpf, ID = 4.408" I 4-1/2" SCAB LNR, 15.1# STL, 0.0142 bpf, ID = 3.826" 113-3/8" CSG, 72#, L-80, ID = 12.347" I 7" TBG-PC, 26#, L-80, 0.0383 bpf, ID = 6.276" TOP OF 5-1/2" TBG-PC 29471 29551 29711 29841 29931 29931 ÆRFORA TION SUMMA RY REF LOG: BHCS 04/06/88 ANGLEATTOPÆRF: 4 @ 5617' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 5617 -5625 S 6/12/1996 3-3/8" 6 5620-5625 S 2/17/1995 4" 0.5 5930-5950 0 9/3/1989 4 0.5 5962-5984 0 9/3/1989 4 0.5 5990-6020 0 9/3/1989 4 0.5 6072-6080 0 9/3/1989 4 0.5 6100-6138 0 9/3/1989 4 0.5 6155-6172 0 9/3/1989 4 0.5 6246-6366 0 5/31/1989 4 4 6394-6404 0 3/31/1989 4 4 6366-6388 0 3/31/1989 4 4 6394-6404 0 3/31/1989 4 4 6434-6454 0 3/31/1989 4 4 6455-6485 0 5/15/1988 4 4 6563-6603 0 5/15/1988 4 4 6799-6843 0 5/15/1988 4 4 6869-6883 0 5/15/1988 ITag FiI11/09/2001 59451 19-5/8" CSG, 47#, L-80, ID = 8.681" I 69921 ITD 70001 8 22101 29361 29471 29541 29551 29931 30031 30041 47101 58931 59041 65981 69951 DATE REV BY COMMENTS DATE REV BY COMMENTS 02/07/98 LAST WORKOVER 12/27/00 SIS-SL T CONVERTED TO CANVAS 01/05/01 SIS-MD FINAL 03/30/01 RN/CH/TP CORRECTIONS 11/14/01 WOO ( -17" CAM BAL-O SSSV NIP, ID = 5.937" I -17" BKR FAB 85-47 PKR/SEAL ASSY, ID = 4.00" -17" X 5" HMC LNR HGR, ID = 4.438" I -l5"X4-1/2"XO, ID=4.00" I 4-1/2" BKR MODEL E EXPANSION JOINT (8' STROKE), ID = 3.875" -17"X 5-1/2" XO (BEHIND SCAB LNR) I -15-1/2" BKR SEAL ASSY(BEHIND SCAB LINER) I -i 9-5/8"x 7" BKR FB-1 PKR (BEHIND SCAB LNR) I -1TOC I Estimated I -14-1/2" FLOAT SHOE I 1-1 ELMD TT - LOGGED 12/01/96 J -1 (WLM) FAILED IBP(LOST03/10/~~ -1TS&-100'.125"WIRE(LOST12/19/96) I PRUDHOE BAY UNIT WELL: 04-19 ÆRMIT No: 88-024 API No: 50-029-21791-00 SEC 26 T11 N R15E 5029.5 FEL 4375.45 FNL BP Exploration (Alaska) TREE' = CrN WELLHEAD= FMC GEN IV ,'M""""."M'^"^"",^^~"M_.."'MW_."""",-",.-.",-"W^'^"_'" .. ACTUA TOR= BAKER C ""__'M'M'_^",^~,^.."~",-~-~"^",.""""'M"_"",,,,, KB. ELEV = 60' """""""""""'-""""""""""""""""""'W"""""""'....'"'""".oW BF. ELEV = --",-~,--,^,w_--,---"",, ~~p_~-,.."",--"_.__..~? Max Angle = 2 @ 2449' ---_..__.."'.._.._.._^-"""',,.._w- Datum MD = 8877' ""-"",~-"-",,--,,,,,,---,,",'.o""-'-"""""""'- Datum 1VD= 8800' SS 04-1 g" ~roposed Pre Rig TOPOF 5" LNR- SCAB I 15" LNR-SCAB, 15#, .0189 bpf, ID = 4.408" I 4-1/2" SCAB LNR, 15.1# STL, 0.0142 bpf, ID = 3.826" 113-3/8" CSG, 72#, L-80, ID = 12.347" I 7" TBG-PC, 26#, L-80, 0.0383 bpf, ID = 6.276" TOP OF 5-1/2" TBG-PC 2947' 2955' 2971' 2984' 2993' 2993' PERFORA TION SUMMA RY REF LOG: BHCS 04/06/88 ANGLEATTOPÆRF: 4 @ 5617' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 5617-5625 S 6/12/1996 3-3/8" 6 5620-5625 S 2/17/1995 4" 0.5 5930-5950 0 9/3/1989 4 0.5 5962-5984 0 9/3/1989 4 0.5 5990-6020 0 9/3/1989 4 0.5 6072-6080 0 9/3/1989 4 0.5 6100-6138 0 9/3/1989 4 0.5 6155-6172 0 9/3/1989 4 0.5 6246-6366 0 5/31/1989 4 4 6394-6404 0 3/31/1989 4 4 6366-6388 0 3/31/1989 4 4 6394-6404 0 3/31/1989 4 4 6434-6454 0 3/31/1989 4 4 6455-6485 0 5/15/1988 4 4 6563-6603 0 5/15/1988 4 4 6799-6843 0 5/15/1988 4 4 6869-6883 0 5/15/1988 Tag Fil11/09/2001 5945' 19-5/8" CSG, 47#, L-80, ID = 8.681" I 6992' ITD 7000' 8> 2210' 2936' 2947' 2954' 2955' 2993' 3003' 3004' -i 7" CAM BAL-O SSSV NIP, ID:: 5.937" I -i 7" BKR FAB 85-47 PKR/SEAL ASSY, ID = 4.00" -17" X 5" HMC LNR HGR, ID:: 4.438" I -15" X 4-1/2" XO, ID:: 4.00" I 4-1/2" BKR MODEL E EXPANSION JOINT (8' STROKE), ID :: 3.875" -17"X 5-1/2" XO (BEHIND SCAB LNR) I -i5-1/2" BKR SEAL ASSY(BEHIND SCAB LINER) I -i 9-5/8"x 7" BKR FB-1 PKR (BEHIND SCAB LNR) I ubing Cut @ 4250' 4710' 5893' 5904' 6598' 6995' DATE REV BY COMMENTS DATE REV BY COMMENTS 02/07/98 LAST WORKOVER 12/27/00 SIS-SL T CONVERTED TO CANVAS 01/05/01 SIS-MD FINAL 03/30/01 RN/CHlTP CORRECTIONS 11/14/01 WDO -i TOC I Es timated I 200' Cement Above BP Bridge Plug @ 5250' -i4-1/2"FLOATSHOE I l-i ELMD TT - LOGGED 12/01/96 -i(WLM) FAILED IBP(LOST03/10/95) I -iTS&-100'.125"WIRE(LOST 12/19/96) I PRUDHOE BAY UNIT WELL: 04-19 PERMIT No: 88-024 API No: 50-029-21791-00 SEC 26 T11 N R15E 5029.5 FEL 4375.45 FNL BP Exploration (Alaska) TREE: 7-1/16" - 5M CIW L-80 WELLHEAD: 11" - 5M FMC Gen IV ( 4-19A Proposed Completion Cellar Box Elevation = 21.2' Nabors2ES RKB = 49.7 7" 'R' Landing Nipple with 5.963" seal bore. I 2200' I 7", 26 #/ft, L-80, NSCC Tubing 4-1/2" Gas Lift Mandrels with handling pups installed. 13-3/8",72 #Ift, L-80, BTC I 2984' Window Milled from Whipstock Top of Window at +1-3870' MD 5-112" X 7" crossover above 7" liner top I +/-3720' I BAKER 7" x 9-5/8" Liner Tie Back Sleeve ZXP Liner Top Packer 'Flex-Lock' Hydraulic Liner Hanger 5-1/2" 17# L-80,STL Tubing Bridge Plug set at +/-3894' MD ---- Pre-Rig Tubing Cut at +1-4,250' Perforations from 5617' to 6882' 9-5/8", 47 #Ift, L80, BTC Date 6/20/01 Rev By WSI 11/06/01 woo 4-1/2" 'X'Landing Nipple with 3.813" seal bore. 7"x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. BAKER 5" x 7" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger 7", 26 #/ft, L-80, BTC-Mod 1+/-8905' I Plug Back Depth I +/-9255' I 4-1/2" 12.6 lIft, L-80, BTC-Mod I +/-934.Q:] Comments PRUDHOE BAY UNIT WELL: 4-19A API NO: 50-029-21791-01 Proposed Completion Proposed Completion BP Alaska Drilling & Wells bp COMPANY DETAILS m> Amoco REFERENCE INFORMATION Co~>nlinale (N/E) Relorence: Well C.,lIre: 04.19, Tnle North Vertical (lW) ReIL'II.""': 51' 51.00 Seelinn (VS) Rel"",n,,: User Defined (7,32N,5,69E) M"'lSn~~,::'r~:,~e~~~~: ~;nimn~ii~::Vature ",.,""'~.,~~"~:; J ~ {:~: ; ~:?;""b~ 3 ¡;r ii~~6n ° Start Dir 60/100' : 3916.94' MD, 3916.46'TVD \6° , l.ð,~." "'" " '" "" ~, End Dir: 4366.94' MD, 4339.27' TVD I' ,!..."""",~5??O...,..~~fr,.,~"'.s,:'t~' :;~:;S'1100" 4866,94' MD, 4763,3'I'VD 4800 "-"."""'-'-' """"""""."""""""", -:.==...,-..........- ......-.......... , , . ' , :: . 5000 \ . "..~):""~",:",::"..""""",:"..,:~,,~,~,,..,:,,~:"",:",\;"""""','~'G4A,Ki5'~C 1 560~-~!J:¡:!:5~:~;.I::;;::l :¡j , ,.- ¡ " '00'\"""""]""""',"" """:":""\~""""""'UG:¡::'UgS"" """",..i\-""':""'+"" :":'::::r:\j,":",:,r:::""..", : ': Ehd Dir : 6623.24' MD 6346.15' TVD ,6500.. "';':::;;"",""""" " > :s ~ 0 0 ~ ,.J:I 15.. a.> ~ 6400 '" <.> ~ a.> Þ Calculati"" Method: Miuimum CUlvalure ~~;: ~;:~~: ~~v~~~ndcr North Em>r Surl.ce: Ellipt;CIII' Cu.'ing Wnmin Mcthod: R"!,,,: Based """'" 4000 " ; ",,::':':::,,'::i,,:':,,:':,,'::t\:J~~' ':::,f,::: : \\". .... \\~:: \\..:,\K I -/11111 . , ..,,- 1 I I , , , """"""""0"""""""',""""""""'0"""""""" """"""""'0""""""""',""""""""',"""""""" "'04cI9(O4c1,9)'" .."i".. 720 8000- """" 8800 0 800 1600 2400 Vertical Section at 358.56° [800ft/in] " 3:f1:K12' J Al/2~~ , 3200 SURVEY I'ROGRAM Depth Fm Depth To Survcyll'~111 3ROO,00 9340,32 P~1I1I1,:d:04-19awp06VI Tool MWD \'Ian: 04-19a wpO6 (04. 191Plan 04-19a) Creatc-d By: Ken Allen Checked: Date: 11/13/2001 Dale: Reviewed: Date: WELL DETAILS Name +N/,~ +I".W Northing Easling Latitude Longitude Slot 04-19 .524,63 I ROR,70 5952791.13 71J057.CIO 70"16'2M36N 14R"16'35,244W N/A TARGET DETAILS Nan1O lVD +N/-S '¡¡¡.W Ntlrthing lJa.'ting Shape fault~ct 5351.00 1562R .140,2R 5952943.97 712912.96 Point 04.19n 'I R506,OO 1910.30 -41.99 5954699,9R 712961.54 Polygon SECTION DETAILS See MD Inc I 3800.00 0.31 2 3820.00 2.09 3 3916.94 5.00 4 4366.94 32.00 5 4866.94 32.00 6 6623.24 18.83 7 8905.19 18.83 8 9225.32 18.83 9 9340.32 18.83 Azi TVD +N/-S 172.27 3799.72 9.66 359.36 3819.72 9.97 358.56 3916.46 15.96 358.56 4339.27 157.39 358.56 4763.30 422.26 358.55 6346.15 1174.09 358.55 8506.00 1910.30 358.55 8809.00 2013.58 358.55 8917.85 2050.68 0 trIP I -;00 ..000 ~(/IJ 6,¡!J I rjlJ° JO tfJtfJ I .. '000 ',yOOO . .?t"> ""00 4- /000 ~ '/000 +E/-W DLeg TFace VSec Target 5.91 0.00 0.00 2.33 5.91 12.00 186.18 2.64 5.78 3.00 358.62 8.64 2.23 6.00 360.00 150.11 -4.43 0.00 0.00 415.07 -23.37 0.75 ..179.99 1167.13 04..19a TIC ..41.99 0.00 0.00 1903,57 -44.60 0.00 0.00 2006.89 -45.54 0.00 0.00 2044.00 CASING DETAILS No. TVD MD Name Size 1 8506.00 8905.19 7" 7.000 2 8917.84 9340.31 41/2" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 3833.00 3833.29 SV3 2 4434.00 4478.64 SV1 3 5921.00 6169.19 UGI UgS 4 5059.00 5210.91 UG4A KI5-CI 5 6475.00 6759.38 TUZC 6 6681.00 6977.02 WSI/W.SAK 7 6921.00 7230.59 CM3 / KI2 8 8279.00 8665.36 THRZ 9 8506.00 8905.19 LCU / Zone 4 10 8519.00 8918.93 Zone 3 II 8701.00 9111.22 Zone 2a 12 8809.00 9225.32 BSAD / Kavik ( All TVD depths are ssTVD plus 51' for RKBE. COMPANY DETAILS REFERENCE INFORMATION IJI' Amoco ('o~'ßlinllto (NIE) Reforeneo: Woll ("'lire: 04.19. TnlO North Vertleul O'VD) Roferenee: 51' 51.00 Section (VS) Relerenee: User Do lined (7.32N,5,69E) MCUSl\fC¿u:~~~~:(~~o~~~:;:¡: ~;nimu~I¿:~ln'" CII!enllllion Mellll.l: Minimnm CurvIIIII'" ~~:[ ~~:~~t \~~~V;:~~nder North Error Surlaee: Elliplicul' ClLsing Wllmin Method: Rilles Bllsed .. " .r' No. TVD MD I 8506.00 890 I 4 1/: 2 8917.84 934 r,:~'~' '),':r:' ";':'/ U' MD, 8917.85' TVD , (I.: - : -);~ ',\ r: \:oi' FO . ...., -' No, TVDPath 85(0 .,- 7" I 3833.00 2 4434.00 0' .lle ~ 3 592 1,00 i 4 5059.00 5 6475.00 801 10 6 6681,00 7 6921.00 8 8279.00 9 8506.00 10 85]9.00 I.; UU II 8701,00 , 12 8809.00 ,,' " " ,,"'" ,7( 00 , ,,'" ,', ""', , 6: 00 , AllTVD , I nd Pir /62: ::24' MD, 6346.15' TVD "" ,,'" '" "'" ssTVD P , - ,,'" ,," 61 ,," ',', ~OO "',' '" " ,,"" ! - " ,"" '", '" " "" ,,', I""" ¡, ",' -I "",' J 'v, I ':It -I '" "" ,0' I ",I " '" UUI """,',""'" ,,', " ,' ,I ""'" " ", Sta .- Qir ( 1.75 !'/I( '0' : 4866.94' MD, 4763.3'TVD ¡ - 0 ':' " " .. f50 .. , ",,' " ," "", I<M Ir MD, 4339.27' TVD - " "" '" , -- 3916.94' MD, 3916.46'TVD 01 3820' MD, 38]9.72'TVD - ' i;;¡ I\A' II\A Sta :t ir 10C : 3800' MD, 3799.72'TVD - " , , , 0 I I ' CASING DETAILS 5.19 0.31 Name 7" 4 1/2" RMA TION TOP DETAILS 1600 MDPath 3833.29 4478.64 6169.19 5210.91 6759.38 6977.02 7230.59 8665.36 8905.19 8918.93 9111.22 9225.32 Formation SV3 SVI UGI UgS UG4A KI5-CI TUZC WSI/ W.SAK CM3/ KI2 THRZ LCU / Zone 4 Zone 3 Zone 2a 8SAP / Kavik SURVEY PROGRAM Plan: 04.19a wpO6 (O4-I9IPlan 04-19a) Too Deplh I'm Depth To Smwy/l'hlll 3800,00 9340.32 .'I:mncd:O4-19uwpO6VI Size 7.000 4.500 = £i <:> <:> ~ 3:: ~ 0 ~ ~ 0 VJ 1200 depths are Ius 51' for RKBE. 800 40 -40 -400 0 400 West(-)/East(+) [400ft/in] 800 Crealt:d By: Ken Allen Checked: Dale: 11/1312001 MWD Dale: ReviewC<!: Date: WELL DETAII$ Nume Northing L<>ngltllde Slot Easting Latitllde IN/~~ "IY-W 04-19 .524.63 1808.70 713057.(.0 70"16'26.436N 148°6'35.244W NlA 5952791.73 TARGET DETAILS Name lVD .IN/-S +E/oW N<"rthing Ea.,ting S\II~ ~~~:9~lt 5351.00 156.28 -140.28 5952943.97 712912.96 Point 8506.00 191030 -41.99 5954699.98 712961.54 Polygon SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee 1 3800.00 0.31 172.27 3799.72 9.66 5.9] 0.00 0.00 2.33 2 3820.00 2.09 359.36 3819.72 9.97 5.91 12.00 186.18 2.64 3 3916.94 5.00 358.56 3916.46 15.96 5.78 3.00 358.62 8.64 4 4366.94 32.00 358.56 4339.27 157.39 2.23 6.00 360.00 150.11 5 4866.94 32.00 358.56 4763.30 422.26 -4.43 0.00 0.00 415.07 6 6623.24 18.83 358.55 6346.15 1174.09 -23.37 0.75 -179.99 1167.13 7 8905.19 18.83 358.55 8506.00 1910.30 -41.99 0.00 0.00 1903.57 8 9225.32 18.83 358.55 8809.00 201358 -44.60 0.00 0.00 2006.89 9 9340.32 18.83 358.55 8917.85 2050.68 -45,54 0.00 0.00 2044.00 Target 04-19a TI( \ ¡"" ,/' ,/i i /ol """- ",0" "" " .... '. /, /]' ."". ""',...... I ". ,/ "" ,i'~ i / 0, ". Irl 'fÞ° ~OO l '. ~ /'1 it "': ØOO i.i/ .....,............. "';-:"',.........,,/.., . .9000 ~rfJ° ~/,k""""~~~,, " '1/ <000 4' ,I. ' ""'"",,-!' ""':><"'" / /000 7Y 1° ~ i"""'"", ":/no -', / ~ """'",/' ~ ~ '/000 ~ .!/ ! .", I ","'; !.,i ."" ,." ", "" r"", , "", ", " <. ( BP Amoco (' Planning Report - Geographic ------- CoÏ11pany: BP Amoco Date: 11/13/2001 Time: . 12:07:55 Field: . Prudhoe Bay. Co-ordinate~E) Reference: Well: 04-19, True North Site: PB DS 04 Vertical (TVD) Reference: 51' 51.0 Well: 04-19 Section (VS) Reference: User (7.32N.5.69E,358.56Azi) Wellpath: Plan 04-19a Plan: 04-19a wp06 . :~::~]~~~~~;e:;oo~:~te=::s~::=~ .". .,... ., . ... ,.,... .=~~ap ~~:=. .-"., ='-~~:::'z~~'~'-'O'O ~~==... ". ====-=1 I Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre J ,-Sys Datum: Mean Sea Level ------.- Georna~~etic Model: BGGM2001______----_. ---- -t- Site: PB DS 04 TR-11-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5953265.35 ft 711234.97 ft LaMude: 70 16 31.598 N Longitude: 148 17 27.907 W North Reference: True Grid Convergence: 1.61 deg ----------- Well: 04-19 04-19 Surface Position: +N/-S -524.63 ft +E/-W 1808.70 ft Position Uncertainty: 0.00 ft Reference Point: +N/-S -524.63 ft +E/-W 1808.70 ft Slot Name: Northing: 5952791.73 ft Latitude: 70 16 26.436 N Easting : 713057.60 ft Longitude: 148 16 35.244 W Northing: 5952791.73 ft Latitude: 70 16 26.436 N Easting : 713057.60 ft longitude: 148 16 35.244 W Measured Depth: 28.50 ft Inclination: 0.00 deg Vertical Depth: 28.50 ft Azimuth: 0.00 deg .--------- -------.--- -- ---------.--------- --------------.--------.---------- ---------. -----------------. ------- ------------_._- --------- Wellpath: Plan 04-19a 3/28/2001 57510 nT Depth From (TVD) ft 4399.72 Drilled From: 04-19 Tie-on Depth: 3800.00 ft Height 51.00 ft Above System Datum: Mean Sea Level Declination: 26.93 deg Mag Dip Angle: 80.82 deg +N/-S +E/-W Direction ft ft deg .--------------------------- ------- -------------------------------.--.--.- ----.._---- - ----- -----------.------ 7.32 5.69 358.56 Current Datum: Magnetic Data: Field Strength: Vert!cal Section: 51' ------ ----. - --------- ----- -- --- ----- ------...- ----- -----.-.- -.-- --- --- ---- -- ------ - - -------.----.- -- - ---- ---------- -------- -- ---_. --- -- -- - - --. - .--- - -. -- ran; 04-19. wP06 -- Principal: Yes ----. ----==j::¡;:OS=-j:~:/::fi~i~ve p~~= J Plan Section Information 3800.00 0.31 172.27 3799.72 9.66 5.91 0.00 0.00 0.00 0.00 3820.00 2.09 359.36 3819.72 9.97 5.91 12.00 8.91 -864.53 186.18 3916.94 5.00 358.56 3916.46 15.97 5.79 3.00 3.00 -0.83 358.62 4366.94 32.00 358.56 4339.27 157.39 2.23 6.00 6.00 0.00 360.00 4866.94 32.00 358.56 4763.30 422.27 -4.43 0.00 0.00 0.00 0.00 6623.25 18.83 358.55 6346.15 1174.09 -23.37 0.75 -0.75 0.00 -179.99 8905.19 18.83 358.55 8506.00 1910.30 -41.99 0.00 0.00 0.00 0.00 04-19a T1 9225.32 '18.83 358.55 8809.00 2013.58 -44.60 0.00 0.00 0.00 0.00 9340.32 . 18.83 358.55 8917.85 2050.68 -45.54 0.00 0.00 0.00 0.00 . ------ -.-------...- , i Section 1: Start ! ß~~tg~iif..:fflli~WrfLdJ~[-_if~~~~I~'~lf~i~J~!~~,;j~£~ Section 2: Start ~~~~J[=~~_f~j~U~I~~~_C_~---_t__J~£~~~-~-~~_.-~_I_._-__-~_____~3iCLIT-~j¡ 3900.00 4.49 358.62 3899.58 14.56 5.82 7.23 3.00 3.00 -0.92 -1.38 3916.94 5.00 358.56 3916.46 15.97 5.79 8.64 3.01 3.01 -0.36 -0.60 ---.------. -------------.-----------------------..---- --.--------..---.---..--------.-----------------.--------------------------..... ..--...-..----.----..-------..---.----.---- ( BP Amoco ( Planning Report - Geographic Compäoy:. BPAmóco. Field: Prudho~Bay Site: PROS 04 ..- Well: 04~19.. . Wellpath: PlanO4-19a Section 3: Start . Date:. 111t3/2001 Time: .' 12:07:55. CoooQl"dinate(NEJRefel"ence:Well:O4-19,..-TrueNorth V~..tical {TYD):Refel"ence:' 51' 51.0 .. . . .. Section (VS) Refel"ence: User (7.32N,5.69E,358.56Azi)' Plan: '. 04-19awp06 ' . . .--'---.-----...... .' .........----..--..........--...-...-..--...--...................,........"""".-'" ...................... .... .......... .................. ........................... ....- -. . ..........................-.............. ........-----' MD loci Azim TVD +N/-S +E/-W VS DLS Build Tul"ß TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg ...-.....-.......--......................... -- -....--...-..----.......-. .--...' ...... "'---.. __..n....... .... .... .. '.m_.."""""""," ........... . ...... .. ....- .".' .. -.----.....-.. ....--.-............. .......-...--...--..-. ..........-............ .. ....--................... .... ... .....-................... .... ..................... ...--. ..... 3950.00 6.98 358.56 3949.34 19.42 5.70 12.10 6.00 6.00 0.00 0.00 4000.00 9.98 358.56 3998.79 26.79 5.52 19.47 6.00 6.00 0.00 0.00 4050.00 12.98 358.56 4047.78 36.74 5.27 29.42 6.00 13.00 0.00 0.00 4100.00 15.98 358.56 4096.18 49.24 4.95 41.93 6.00 6.00 0.00 0.00 4150.00 18.98 358.56 4143.87 64.26 4.58 56.95 6.00 6.00 0.00 0.00 4200.00 21.98 358.56 4190.70 81.75 4.14 74.44 6.00 6.00 0.00 (j).00 4250.00 24.98 358.56 4236.56 101.66 3.64 94.36 6.00 6.00 0.00 0.00 4300.00 27.98 358.56 4281.30 123.95 3.08 116.66 6.00 6.00 0.00 0.00 4350.00 30.98 358.56 4324.82 148.55 2.46 141.27 6.00 6.00 0.00 0.00 4366.94 32.00 358.56 4339.27 157.39 2.23 150.11 6.00 6.00 0.00 0.00 .--.--------.-- ------"-----.- Section 4: Start r~ :~~~:~~ ~--~"~~~:~~~~I~:~~~~~1f~~:~~~~~~"~~i:~~' ~'~~~'I~f~~'-' ~~~:~~ ~_.~..""~~:~~... . -~~~:f~"~~ ~:~I~~L~~.~~:~f~'c-~~c'~~-"-~~-~1 4600.00 32.00 . 358.56 4536.92 280.85 -0.87 273.61 0.00 0.00 0.00 180.00 J 4700.00 32.00 358.56 4621.72 333.83 -2.21 326.60 0.00 0.00 0.00 180.00 --;~~~:~~--_.~~:9_~_I~~:~;- :;~~It__- ¡~~:~~---_. ~t¡j--- ¡~t~~ -----~~~--- ~:~~ ---~J~--- '~~~:~9___._--------------- . Section 5: Start : r~'_~-]~¡' .' i ~m T}JE¡----:r!ET5.TI;;tr~~~~;~J~ipoh~t_I.. TLLJ 4900.00 31.75 358.56 4791.37 439.72 -4.87 432.53 0.75 -0.75 0.00 -179.99 5000.00 31.00 358.56 4876.75 491.77 -6.18 484.60 0.75 -0.75 0.00 -179.99 5100.00 30.25 358.56 4962.80 542.70 -7.46 535.54 0.75 -0.75 0.00 -179.99 5200.00 29.50 358.56 5049.51 592.50 -8.71 585.36 0.75 -0.75 0.00 -179.99 5300.00 28.75 358.56 5136.86 641.16 -9.93 634.03 0.75 -0.75 0.00 -179.99 5400.00 28.00 358.56 5224.85 688.67 -11.13 681.56 0.75 -0.75 0.00 -179.99 5500.00 27.25 358.56 5313.44 735.03 -12.30 727.93 0.75 -0.75 0.00 -179.99 5600.00 26.50 358.56 5402.64 780.22 -13.43 773.14 0.75 -0.75 0.00 -179.99 5700.00 25.75 358.56 5492.42 824.24 -14.54 817.17 0.75 -0.75 0.00 -179.99 5800.00 25.00 358.56 5582.77 867.08 -15.62 860.03 0.75 -0.75 0.00 -179.99 5900.00 24.25 358.56 5673.67 908.74 -16.67 901.70 0.~"5 -0.75 0.00 -179.99 6000.00 23.50 358.56 5765.12 949.21 -17.69 942.18 0.75 -0.75 0.00 -179.99 6100.00 22.75 358.56 5857.08 988.47 -18.68 981.45 0.75 -0.75 0.00 -179.99 6200.00 22.00 358.56 5949.55 1026.53 -19.64 1019.52 0.75 -0.75 0.00 -179.99 6300.00 21.25 358.55 6042.51 1063.37 -20.57 1056.38 0.75 -0.75 0.00 -179.99 6400.00 20.50 358.55 6135.94 1099.00 -21.47 1092.02 0.75 -0.75 0.00 -179.99 6500.00 19.75 358.55 6229.83 1133.40 -22.34 1126.43 0.75 -0.75 0.00 -179.98 6600.00 19.00 358.55 6324.17 1166.56 -23.17 1159.60 0.75 -0.75 0.00 -179.98 6623.25 18.83 358.55 6346.15 1174.09 -23.37 1167.13 0.74 -0.74 -0.01 -179.67 ------ ..-- --------- - -----.--..------ - ..--- .--. -----.----.-- -'-----.-------- Section 6: Start [.i!EJI:~L",_~]tlI!LJ:JdTIßtL~ï§j';L;~.:..;J;1f~~Æ~;1~~~~~:LW~é;2';~L~~ 6700.00 18.83 358.55 6418.79 1198.85 -24.00 1191.90 0.00 0.00 0.00 0.00 6800.00 18.83 358.55 6513.44 1231.12 -24.81 1224.18 0.00 0.00 0.00 0.00 6900.00 18.83 358.55 6608.09 1263.39 -25.63 1256.46 0.00 0.00 0.00 0.00 7000.00 18.83 358.55 6702.74 1295.65 -26.45 1288.73 0.00 0.00 0.00 0.00 7100.00 18.83 358.55 6797.38 1327.92 -27.26 1321.01 0.00 0.00 O.QO 0.00 7200.00 18.83 358.55 6892.03 1360.18 -28.08 1353.28 0.00 0.00 0.00 0.00 7300.00 18.83 358.55 6986.68 1392.45 -28.90 1385.56 0.00 0.00 0.00 0.00 7400.00 18.83 358.55 7081.33 1424.71 -29.71 1417.84 0.00 0.00 0.00 0.00 7500.00 18.83 358.55 7175.98 1456.98 -30.53 1450.11 0.00 0.00 0.00 0.00 7600.00 18.83 358.55 7270.62 1489.25 -31.35 1482.39 0.00 0.00 0.00 0.00 7700.00 18.83 358.55 7365.27 1521.51 -32.16 1514.67 0.00 0.00 0.00 0.00 7800.00 18.83 358.55 7459.92 1553.78 -32.98 1546.94 0.00 0.00 0.00 0.00 7900.00 18.83 358.55 7554.57 1586.04 -33.80 1579.22 0.00 0.00 0.00 0.00 8000.00 18.83 358.55 7649.22 1618.31 -34.61 1611.49 0.00 0.00 0.00 0.00 ------... --..----- ------ - ---... ---------- - ------ '---"" -.------- -"--........" - -- - ---- --- --- '--------'-' -"-'-"-- - ---- ..---.-....-..----.- ( BP Amoco ( Planning Report - Geographic '. Company: BPAriloco Date:" 11113/2001 Time: 12:07:55 Field: Prudhoe Bay Co-ordinate(~E) Reference: Well: 04-19, True North . Site: PB DS 04 Vertical (TVD) Reference: 51' 51.0 Well:' 04-19 Section (VS) Reference: User (7.32N,5.69E,358.56Azi) l.u~~!.~.!P'.~.!~:--.....~.I~~..~.~~.~.~.~.u_... ,-,"----....u_uu__u.........--u............. ........ ......... -.--.---.................. ..-........ ...--....~I~.~.~.....uu......uu......--...... ....u" ".., ..--...... ..._._~~.~.~-~~..~~.~~.._u------- .... un--...u_u_........ ...---....-...----- :...-.--- ....uu_; Section 6: Start Page: 3 _.,--,----_.,----- .......u_u..,...------.-----.. -",-",'-""""""""'........._u__--_._m.._.. -..........-..u......-......-. "'" ..............u_...___.m___...._......u......-.----....--.-.... ..... uuuuu..........-........ -'...........m ..uu .U. """----"'. --.......,..... '....u.. 'n........_-.--. """" MO Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/10OO deg "...u_...... .....u...u......_-_._u..............u. U_'--'-.-...-............._u_....u... ........ ""_U_""'---'----"-""""__--.__m"_u,,_-- ..............u.--..u ...... u... . ........ '--....-...-.----.........-......... ""..----......... ............-...... .-...... "'...----.............. ..--._uu...,......-.- -""-'. 8100.00 18.83 358.55 7743.86 1650.58 -35.43 1643.77 0.00 0.00 0.00 0.00 .- 8200.00 18.83 358.55 7838.51 1682.84 -36.25 1676.05 0.00 0.00 0.00 0.00 8300.00 18.83 358.55 7933.16 1715.11 -37.06 1708.32 0.00 0.00 0.00 0.00 8400.00 18.83 358.55 8027.81 1747.37 -37.88 1740.60 0.00 0.00 0.00 0.00 8500.00 18.83 358.55 8122.46 1779.64 -38.70 1772.87 0.00 0.00 0.00 0.00 8600.00 18.83 358.55 8217.11 1811.90 -39.51 1805.15 0.00 0.00 0.00 0.00 8700.00 18.83 358.55 8311.75 1844.17 -40.33 1837.43 0.00 0.00 0.00 0.00 8800.00 18.83 358.55 8406.40 1876.44 -41.15 1869.70 0.00 0.00 0.00 0.00 8905.19 18.83 358.55 8506.00 1910.30 -41.99 1903.58 0.00 0.00 0.00 0.00 Section 7: Start " ., ..fir. .","-.~~~..'.... .' 9000.00 18.83 9100.00 18.83 9200.00 18.83 9225.32 18.83 ...- . I>LS .'.' Briild'}~;n----""-j'F() .-~' . '.' ...-. ",o-'T"'--""'-'j .d~g/1ÖOft dêg/W~!!_~'i~100tt:~_d~~c- '."-. i"-~_.L1....uL.~L,i 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ' 0.00 0.00 0.00 0.00 0.00 0.00 ~~;~j_.~:_~~ T¡¡f~ L..- +NÃS ,)~j1~__, 358.55 8595.74 1940.89 -42.76 358.55 8690.38 1973.16 -43.58 358.55 8785.03 2005.42 -44.40 358.55 8809.00 2013.58 -44.60 ys " , ff " 1934.18 1966.45 1998.73 2006.89 Section 8: Start :~---~~=~T" .... ~... :~--~~h-~[~~~I~~fbÖft11ó\I~~-~~ ~~C"'=:=-' ~ 9300.00 18.83 358.55 8879.68 2037.68 -45.21 2030.99 0.00 0.00 0.00 0.00 9340.32 18.83 358.55 8917.85 2050.68 -45.54 2044.00 0.00 0.00 0.00 0.00 ---- --------------- Survey [ill ~D~I~iI¡ -I'., ,l~~ITIE~~~T¥lJIT'~1~JfI~N£I~~ITJf~1~~ 3800.00 0.31 172.27 3799.72 9.66 5.91 5952801.55 713063.23 70 16 26.531 N 148 16 35.072 W 3820.00 2.09 359.36 3819.72 9.97 5.91 5952801.86 713063.23 70 16 26.534 N 148 16 35.072 W 3900.00 4.49 358.62 3899.58 14.56 5.82 5952806.45 713063.00 70 16 26.579 N 148 16 35.075 W 3916.94 5.00 358.56 3916.46 15.97 5.79 5952807.86 713062.94 70 16 26.593 N 148 16 35.075 W 3950.00 6.98 358.56 3949.34 19.42 5.70 5952811.30 713062.75 70 16 26.627 N 148 16 35.078 W 4000.00 9.98 358.56 3998.79 26.79 5.52 5952818.67 713062.36 70 16 26.699 N 148 16 35.083 W 4050.00 12.98 358.56 4047.78 36.74 5.27 5952828.61 713061.83 70 16 26.797 N 148 16 35.091 W 4100.00 15.98 358.56 4096.18 49.24 4.95 5952841.09 713061.16 70 16 26.920 N 148 16 35.100 W 4150.00 18.98 358.56 4143.87 64.26 4.58 5952856.09 713060.35 70 16 27.068 N 148 16 35.111 W 4200.00 21.98 358.56 4190.70 81.75 4.14 5952873.56 713059.42 70 16 27.240 N 148 16 35.124 W 4250.00 24.98 358.56 4236.56 101.66 3.64 5952893.45 713058.36 70 16 27.436 N 148 16 35.138 W 4300.00 27.98 358.56 4281.30 123.95 3.08 5952915.71 713057.17 70 16 27.655 N 148 16 35.155 W 4350.00 30.98 358.56 4324.82 148.55 2.46 5952940.28 713055.85 70 16 27.897 N 148 16 35.173 W 4366.94 32.00 358.56 4339.27 157.39 2.23 5952949.11 713055.37 70 16 27.984 N 148 16 35.179 W 4400.00 32.00 358.56 4367.31 174.90 1.79 5952966.61 713054.44 70 16 28.156 N 148 16 35.192 W 4500.00 32.00 358.56 4452.11 227.88 0.46 5953019.52 713051.61 70 16 28.677 N 148 16 35.231 W 4600.00 32.00 358.56 4536.92 280.85 -0.87 5953072.43 713048.78 70 16 29.198 N 148 16 35.269 W 4700.00 32.00 358.56 4621.72 333.83 -2.21 5953125.35 713045.94 70 16 29.719 N 148 16 35.308 W 4800.00 32.00 353.56 4706.53 386.80 -3.54 5953178.26 713043.11 70 16 30.240 N 148 16;, 35.347 W 4866.94 32.00 358.56 4763.30 422.27 -4.43 5953213.68 713041.22 70 16 30.589 N 148 16 35.373 W 4900.00 31.75 358.56 4791.37 439.72 -4.87 5953231.12 713040.28 70 16 30.761 N 148 16 35.386 W 5000.00 31.00 358.56 4876.75 491.77 -6.18 5953283.11 713037.50 70 16 31.272 N 148 16 35.424 W 5100.00 30.25 358.56 4962.80 542.70 -7.46 5953333.98 713034.78 70 16 31.773 N 148 16 35.461 W 5200.00 29.50 358.56 5049.51 592.50 -8.71 5953383.72 713032.12 70 16 32.263 N 148 16 35.498 W 5300.00 28.75 358.56 5136.86 641.16 -9.93 5953432.32 713029.52 70 16 32.742 N 148 16 35.533 W 5400.00 28.00 358.56 5224.85 688.67 -11.13 5953479.78 713026.98 70 16 33.209 N 148 16 35.568 W 5500.00 27.25 358.56 5313.44 735.03 -12.30 5953526.08 713024.50 70 16 33.665 N 148,-16 35.602 W 5600.00 26.50 358.56 5402.64 780.22 -13.43 5953571.22 713022.08 70 16 34.109 N 148 :16 35.635 W .- ---- .--- u_- --------- --------_.._-- -------- --....--------- -----------_u_-,-- ---- - --,,- - -.. - ---- . ------- -------- ----- ---.. --- .. -- ---,--. --- - ( BP Amoco (' ,- Planning Report - Geographic "nn,'n_,_...,....... - .-....,- -..-..".,..------. I U""--,-"",,----_,,""...n...,,......__UnO..."..._--_...n..,_--,_---..--..------._...'..._...n""'_,--'---' Date: " 11/13/2001 Time: 12:07:55 I)age: 4 I 'Company: ' BP Amoco ' Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 04-19, True North I Site: PB DS 04 Vertical (TVD) Reference:, 51' 51.0 ! ! 'Well: 04-19 Section (VS) Reference: ' ,User (7.32N,5.69E,358.56Azi) : I Wellpat~.:.:...!~.an 04-19a Plan: 04-19a wp06 " ' I ----------- .---.--...-.- '____n- . ._,--"'---~--_._-------, n_.__....~ Survey I --:---.,.., Map Map ' <- Latitude ~ " ' <- Longitude"':"'>'! MD Incl Azim ,TVD " +N/-S +E/-W Northing , Easting Deg Min See Deg Min See ft deg øeg ft ft ft ft ft --- .---...,. '-'- ,_. - - --. --- -, -..- ,--- - -- ---- ---_.. -. ---, - ----- ,----- - ..--.-- -- --_..- ------. ------, --.., '-.- ---- -- 5700.00 25.75 358.56 5492.42 824.24 -14.54 5953615.19 713019.73 70 16 34.542 N 148 16 35.668 W 5800.00 25.00 358.56 5582.77 867.08 -15.62 5953657.98 713017.44 70 16 34.964 N 148 16 35.699 W 5900.00 24.25 358.56 5673.67 908.74 -16.67 5953699.59 713015.21 70 16 35.373 N 148 16 35.730 W 6000.00 23.50 358.56 5765.12 949.21 -17.69 5953740.01 713013.04 70 16 35.771 N 148 16 35.759 W 6100.00 22.75 358.56 5857.08 988.47 -18.68 5953779.23 713010.94 70 16 36.157 N 148 16 35.788 W 6200.00 22.00 358.56 5949.55 1026.53 -19.64 5953817.24 713008.91 70 16 36.532 N 148 16 35.816 W 6300.00 21.25 358.55 6042.51 1063.37 -20.57 5953854.04 713006.93 70 16 36.894 N 148 16 35.843 W 6400.00 20.50 358.55 6135.94 1099.00 -21.47 5953889.63 713005.03 70 16 37.244 N 148 16 35.869 W 6500.00 19.75 358.55 6229.83 1133.40 -22.34 5953923.99 713003.18 70 16 37.583 N 148 16 35.895 W 6600.00 19.00 358.55 6324.17 1166.56 -23.17 5953957.11 713001.41 70 16 37.909 N 148 16 35.919 W 6623.25 18.83 358.55 6346.15 1174.09 -23.37 5953964.63 713001.00 70 16 37.983 N 148 16 35.925 W 6700.00 18.83 358.55 6418.79 1198.85 -24.00 5953989.37 712999.67 70 16 38.227 N 148 16 35.943 W 6800.00 18.83 358.55 6513.44 1231.12 -24.81 5954021.59 712997.94 70 16 38.544 N 148 16 35.967 W 6900.00 18.83 358.55 6608.09 1263.39 -25.63 5954053.82 712996.21 70 16 38.861 N 148 16 35.990 W 7000.00 18.83 358.55 6702.74 1295.65 -26.45 5954086.05 712994.48 70 16 39.179 N 148 16 36.014 W 7100.00 18.83 358.55 6797.38 1327.92 -27.26 5954118.28 712992.75 70 16 39.496 N 148 16 36.038 W 7200.00 18.83 358.55 6892.03 1360.18 -28.08 5954150.51 712991.02 70 16 39.813 N 148 16 36.062 W 7300.00 18.83 358.55 6986.68 1392.45 -28.90 5954182.73 712989.29 70 16 40.131 N 148 16 36.086 W 7400.00 18.83 358.55 7081.33 1424.71 -29.71 5954214.96 712987.56 70 16 40.448 N 148 16 36.109 W 7500.00 18.83 358.55 7175.98 1456.98 -30.53 5954247.19 712985.83 70 16 40.765 N 148 16 36.133 W 7600.00 18.83 358.55 7270.62 1489.25 -31.35 5954279.42 712984.10 70 16 41.083 N 148 '16 36.157 W 7700.00 18.83 358.55 7365.27 1521.51 -32.16 5954311.65 712982.37 70 16 41.400 N 148 16 36.181 W 7800.00 18.83 358.55 7459.92 1553.78 -32.98 5954343.88 712980.64 70 16 41.717 N 148 16 36.205 W 7900.00 18.83 358.55 7554.57 1586.04 -33.80 5954376.10 712978.91 70 16 42.035 N 148 16 36.228 W 8000.00 18.83 358.55 7649.22 1618.31 -34.61 5954408.33 712977.18 70 16 42.352 N 148 16 36.252 W 8100.00 18.83 358.55 7743.86 1650.58 -35.43 5954440.56 712975.45 70 16 42.669 N 148 16 36.276 W 8200.00 18.83 358.55 7838.51 1682.84 -36.25 5954472.79 712973.72 70 16 42.987 N 148 16 36.300 W 8300.00 18.83 358.55 7933.16 1715.11 -37.06 5954505.02 712971.99 70 16 43.304 N 148 16 36.323 W 8400.00 18.83 358.55 8027.81 1747.37 -37.88 5954537.24 712970.26 70 16 43.621 N 148 16 36.347 W 8500.00 18.83 358.55 8122.46 1779.64 -38.70 5954569.47 712968.53 70 16 43.939 N 148 16 36.371 W 8600.00 18.83 358.55 8217.11 1811.90 -39.51 5954601.70 712966.80 70 16 44.256 N 148 16 36.395 W 8700.00 18.83 358.55 8311.75 1844.17 -40.33 5954633.93 712965.07 70 16 44.573 N 148 16 36.419 W 8800.00 18.83 358.55 8406.40 1876.44 -41.15 5954666.16 712963.34 70 16 44.891 N 148 16 36.442 W " ,,~1..9- 18;83""'-'.""'358;55"":.'~6506.00 """"""191 0;30,"","".,-41.99.".,§954699.98 .."}"",7l296t;54i~,~!\\'\~",70,.\.16"œ.45¡224".N.-.~.48.,,J6:¡;¡!t~6..467 W . " " 9000.00 18.83 358.55 8595.74 1940.89 -42.76 5954730.54 712959.90 70 16 45.524 N 148 16 36.490 W 9100.00 18.83 358.55 8690.38 1973.16 -43.58 5954762.77 712958.17 70 16 45.842 N 148 16 36.513 W 9200.00 18.83 358.55 8785.03 2005.42 -44.40 5954794.99 712956.44 70 16 46.159 N 148 16 36.537 W " 9225.32 18.83 358.55 8809.00 2013.58 -44.60 5954803.14 712956.01 70 16 46.239 N 148 16 36.543 W 9300.00 18.83 358.55 8879.68 2037.68 -45.21 5954827.21 712954.72 70 16 46.476 N 148 16 36.561 W ., ,.' ,9340.32" "',.18.83 358.55 8917.85 ,2050.68 -45.54 5954840.20 . 712954.02, ¡7016 , A6. 604:N . ,"~~,~48.~J6 'il~6,67,Q. W H 198741 DATE INVOICE / CREDIT MEMO 092701 CK092701E PYMT OMMENT5: HANDL NG I NST: DESCRIPTION GROSS 100.00 Per it to Drill ee 5/H - Terri Hubb e X4628 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA .99519-6612 PAY TOTAL ~ DL{ ~lq A- DATE 09/28/01 VENDOR DISCOUNT CHECK NO. 00198741 ALASKAOILA NET 00 100.00 H ( 100.00 100.00 FIRST NATIONAL BANk OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56.389 412 No.H 198741 CONSOLIDATED COMMERCIAL ACCOUNT 00198741 .. . . . " ONESH\.)ISIDRED& OO/10Q"t**"'***************~"'*"'************** US DOLLAR ( . . . . . ." .. .c.'-.,:' . . '."., 'ALAS~A ÐìLAIsIPG#1tS , .' C.QN$ERV~TIQhI(;OMi1ISSJDN.. 33:3WE~1F 71t-1~VENuE " . . ".",- . SUITElqo .,,-'.',.' ',.' . ANCHORAGe To The ORDER Of AK 99501 . . DATE. 09/28/0 t.I:1 III ~ '1 a ?.. ~ III I: 0 La ~ 2 0 j a ~ 5 I: 0 0 a La'" ~ 11111 AMOUNT $100. 001 ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME f!6tl û c¡ - /1 ¡1¿ CHECK 1 ST ANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) DEVELOPMENT RED RILL PILOT HOLE (PH) EXPLORATION I ANNULAR IISPOSAL (\/ )NO INJECTION WELL ANNULAR DISPOSAL <-> YES / INJECTION7E RED RILL ANNULAR DISPOSAL THIS WELL "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(f), all records, data and logs acquired for the pilot hole must be. clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <-> YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved . subject to fuil 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) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY WELL NAME I' - . ¿" PROGRAM: exp - dev - redrtl FIELD & POOL' ( INIT CLASS ~ ¿ GEOL AREA ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3. Unique well name and number. ., . . . . . . . . . . . . . . . ) N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . ' N 5. Well located proper distance from drilling unit boundary. . . . .. N 6. Well located proper distance from other wells.. . . . . . . . . Y ) N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . N. 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . ~ N 10. Operator has appropriate bond in force. . . . . . . . . . . . . . 'N 11. Permit can be issued without conservation order. . . . . . . . N 12. Permit can.be issued without administrative approval.. . . . . N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y' N 14. Conductor string provided . . . . . . . . " . . . . . . . . . ~ ~ ß, ~~: ~~~e(/::~~:t':~~~\:t~": ~~~:~r & ~urt ~g: : : : : /M. Ý :}: ....fi~ -: ::!Æt::; ¡., j ,~~~ ;f> 17. CMT vol adequate to .tie-in long string to suñ csg. . . . . . . . ~j " ~ ~,~ ,,'- ~ ---'1(...:\' 18. CMT will cover all known productive horizons. . . . .'. . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . Y N 20. Adequate tank. age or reserve pit.. . . . . . . . . . . . . . . . N C¿ ti.\~\ \f'o., ~\~ \ ~~ttc;rë~~ f)~ 21. If a re-drill, has a 10-403 for abandonment been approved. . . N ~ "' 22. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N 23. If diverter required, does it meet regulations. . . . . . . . . . ~ 24. Drilling .fluid program schematic & equip list adequate. . ~ . . Y N 25. BOPEs, do they meet regulation. . . . . . . ~ . . . . N , [try¡ ~ . 26. BOPE press rating appropriate; \esllo 3~ psig. N ~<;. ~ ..... ~~ d-S'S'-\ \'~ \ 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N ~~: ~~~:'e~~~~h;:~~~::fe~~~U~d~~n: .. .. .. .... .. .. .. .. .. ~ ~~~~~~~~\~~~~~~. 30. Permit can be issued wlo hydrogen sulfide measures. . . . ,. Y . N 31. Data presented on potential overpressure zones. . . . . . . Y 32. Seismic anal~~is of shallow gas zones. . . . . . . . . .~. . ~ N PATE 33. Seabed condition survey (If off-shore). . - . . . . . . . . . . Y N /I../S-- O( 34. Contact name/phone for weekly progress reports [explora only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; . .' (C) will not impair mechanical integrity pf the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GËOLOGY: ENGINEERING:.' UIC/Annuiar COMMISSION: ~ ~-.' '8~s vru:::z'fÞ- "I . JM . well bore seg _ann. disposal para req - O//(;YS-D ON/OFF SHORE O/rJ UNIT# A~ ?tJf~b' ENGINEERING ~ ~~ ,~~~V~~ {c;R'(,\~~~Q\.c.~ S. ~ . GEOLOGY APP APPR Y N Y N DATE Com me ntsllnstructions: 0/ c:\msoffice\wordian\cliana\checklist (rev. 11/01/100) c 0 Z 0 -i :E :xl (' - -i m - Z -t .J: - en > :xl m » ( // ( ¡i( Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information. infonnation of this nature is accumulated at the end of the file under APPENDIX. No special" effort has been made to chronologically organize this category of information. ~ ~' { dOJ-dJg I ) O~ I Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Sep 16 08:15:31 2002 Reel Header Service name........... ..LISTPE Date.....................02/09/16 Origin...................STS Reel Name..... ... ...... ..UNKNOWN Continuation Number..... .01 Previous Reel Name..... ..UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.. ... ......, .LISTPE Date.....................02/09/16 Origin...................STS Tape Name.............. ..UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 4-19A 500292179101 BP Exploration Sperry Sun 16-SEP-02 (Alaska), Inc. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-ll205 P. SMITH J. RALL MWD RUN 2 AK-MM-ll205 J. PITCHER R. BORDES MWD RUN 3 AK-MM-ll205 P. ROGER R. BORDES # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 26 Tll R15 912 5024 MSL 0) .00 51.00 22.50 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 6.125 CASING SIZE (IN) 13.375 9.625 7.000 DRILLERS DEPTH (FT) 2984.0 3853.0 9000.0 OPEN HOLE BIT SIZE (IN) # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 ( ( (EWR4) . 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS. 4. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITH-DENSITY (SLD). 5. NO ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) DATA LOGGED OVER THE INTERVAL DRILLED ON MWD RUN 2. 6. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 3842' MD, 3842' TVD TO 3853' MD, 3853' TVD. 7. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 8967' MD, 8472' TVD TO 9000' MD, 8504' TVD. 8. DIGITAL DATA AND LOG DATA ARE DEPTH CORRECTED TO THE PDC GR LOG OF 01/10/02 WITH KBE = 51.0' A.M.S.L.. THIS WELL KICKS OFF FROM 4-19 AT 3853' MD, 3853' TVD (TOP OF WHIPSTOCK). ALL MWD LOG AND HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 9. MWD RUNS 1 - 3 REPRESENT WELL 4-19A WITH API # 50-029-21791-01. THIS WELL REACHED A TOTAL DEPTH OF 9430' MD, 8933' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED SBD2 = SMOOTHED SCO2 = SMOOTHED BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR FORMATION EXPOSURE TIME BULK DENSITY (LOW-COUNT BIN) STANDOFF CORRECTION (LOW-COUNT (LOW-COUNT BIN) TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE ENVIRONMENTAL PARAMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 6.125" MUD WEIGHT: 9.3 PPG MUD FILTRATE SALINITY: PPM CHLORIDES FORMATION WATER SALINITY: FLUID DENSITY: G/CC 2400 - 6000 15,000 PPM CHLORIDES 1. 00 $ ( MATRIX DENSITY: G/CC LITHOLOGY: SANDSTONE File Header Service name.... ....... ..STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..02/09/16 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.... ...STSLIB.OOO Cormnent Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NCNT FCNT NPHI RHOB DRHO PEF $ 1 (' 2.65 clipped curves; all bit runs merged. .5000 START DEPTH 3845.5 3847.0 3847.0 3847.0 3847.0 3847.0 3893.0 8995.0 8995.0 8995.0 8999.5 8999.5 8999.5 STOP DEPTH 9408.5 9415.5 9415.5 9415.5 9415.5 9415.5 9430.5 9380.0 9380.0 9380.0 9396.0 9396.0 9396.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 3845.5 7983.0 7998.0 8007.5 8029.5 8044.0 8054.0 8058.0 8062.0 8069.0 8092.5 8111.0 8134.0 8151. 0 8158.0 8166.5 8177.0 8180.0 8191. 0 8197.0 8200.5 8204.0 8217.0 8239.5 8254.5 8258.0 8265.5 8277.0 8289.5 8295.0 8312.5 8320.0 8337.0 8351.5 DEPTH GR 3841. 5 7979.0 7994.0 8003.0 8026.0 8040.0 8051.0 8054.0 8058.5 8067.0 8089.0 8107.5 8131. 5 8149.5 8156.5 8166.0 8175.0 8179.0 8191.0 8195.5 8198.5 8201.0 8214.5 8237.0 8251.0 8257.5 8262.0 8274.0 8284.5 8293.5 8309.0 8317.0 8333.5 8348.0 ( ( 8361.5 8372.0 8382.0 8391.0 8396.0 8403.0 8411. 0 8424.5 8437.0 8454.0 8461.5 8470.5 8474.0 8477.5 8484.0 8489.5 8493.5 8498.5 8503.0 8507.0 8510.0 8516.0 8520.5 8527.0 8531.0 8540.0 8552.5 8557.0 8568.5 8574.0 8576.5 8590.5 8597.5 8601.0 8609.5 8616.5 8619.0 8639.0 8641. 5 8644.0 8646.0 8649.5 8659.0 8662.5 8673.0 8675.5 8684.0 8693.5 8703.5 8707.0 8711.5 8719.5 8729.0 8731. 5 8733.0 8744.5 8749.0 8754.5 8757.0 8761.5 8767.5 8770.0 8772.5 8788.5 8808.0 8813.0 8823.0 8826.0 8832.0 8836.0 8848.0 8851. 5 8864.5 8872.0 8875.5 8883.5 8358.0 8368.0 8377.5 8387.5 8392.0 8399.0 8407.5 8420.5 8433.0 8454.0 8461.5 8467.5 8471.5 8474.0 8479.5 8485.0 8489.5 8494.5 8499.5 8504.5 8506.5 8512.5 8518.0 8522.5 8526.5 8535.5 8548.5 8553.0 8564.0 8569.0 8572.5 8585.5 8592.5 8597.0 8604.5 8611.5 8615.0 8635.5 8637.0 8639.0 8642.0 8645.0 8654.5 8658.5 8668.0 8671.0 8678.5 8687.5 8699.5 8702.0 8707.0 8716.0 8725.5 8727.0 8728.5 8739.5 8744.0 8750.5 8752.0 8755.5 8763.0 8765.5 8767.5 8783.5 8803.5 8807.5 8817.5 8821. 5 8828.0 8831. 5 8843.5 8847.0 8860.0 8866.5 8871.5 8878.5 ( 8887.5 8882.0 8894.0 8889.0 8899.0 8895.5 8904.5 8899.0 8909.0 8903.5 8914.5 8909.0 8927.0 8921. 5 8930.5 8925.5 8938.0 8933.0 8941. 0 8936.5 8943.5 8938.5 8953.0 8947.5 8957.5 8952.0 8959.0 8954.5 8964.0 8957.5 8967.0 8962.0 8971.0 8968.0 8982.0 8978.5 8985.0 8981. 0 8987.5 8982.5 8997.5 8992.5 9004.0 9001.0 9007.0 9006.5 9009.0 9009.0 9013.5 9014.0 9036.0 9038.0 9073.5 9074.0 9096.0 9095.0 9111.5 9112.0 9118.0 9118.0 9122.0 9122.0 9140.0 9140.0 9143.0 9144.5 9157.5 9158.0 9171. 5 9171.5 9173.5 9174.0 9176.0 9176.0 9178.0 9177.5 9181.0 9181.0 9185.5 9185.5 9189.0 9190.0 9202.0 9202.5 9206.0 9206.0 9209.0 9209.0 9217 . 0 9216.5 9230.5 9230.5 9240.0 9240.5 9242.0 9242.0 9243.5 9243.5 9260.0 9260.0 9263.0 9263.0 9268.5 9268.5 9270.5 9270.5 9273.0 9272.5 9285.5 9284.5 9287.5 9287.5 9289.5 9289.0 9296.5 9296.0 9300.5 9300.0 9303.0 9302.5 9305.0 9305.0 9307.0 9306.5 9319.0 9318.5 9430.5 9430.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: MERGED MAIN PASS. $ # BIT RUN NO MERGE TOP 1 3841.5 2 6435.0 3 9000.5 ( MERGE BASE 6434.5 9000.0 9430.0 ( (' Data Format Specification Record Data Record Type.... .... ..........0 Data Specification Block Type.....O Logging Direction....... ......... . Down Optical log depth units... ....... .Feet Data Reference Point............. .Undefined Frame Spacing....... ...,..... ... ..60 .1IN Max frames per record............ . Undefined Absent value...... ........ ....... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CP30 4 1 68 36 10 NCNT MWD CP30 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3845.5 9430.5 6638 11171 3845.5 9430.5 ROP MWD FT/H 0.81 431.99 117.344 11076 3893 9430.5 GR MWD API 11.71 414.2 93.1294 11127 3845.5 9408.5 RPX MWD OHMM 0.61 1570.58 14.4536 5918 3847 9415.5 RPS MWD OHMM 0.78 2000 31.4849 5918 3847 9415.5 RPM MWD OHMM 0.73 2000 37.1569 5918 3847 9415.5 RPD MWD OHMM 0.79 2000 46.9747 5918 3847 9415.5 FET MWD HR 0.2 193.44 1.64611 5918 3847 9415.5 NPHI MWD PU-S 6.42 57.32 22.3649 771 8995 9380 FCNT MWD CP30 118.02 2383.42 742.225 771 8995 9380 NCNT MWD CP30 14110 41302.5 28035.6 771 8995 9380 RHOB MWD G/CM 1. 57 2.87 2.39087 794 8999.5 9396 DRHO MWD G/CM -0.95 0.35 0.0714861 794 8999.5 9396 PEF MWD B/E 1. 35 12.72 2.55528 794 8999.5 9396 First Reading For Entire File. ........ .3845.5 Last Reading For Entire File. ......... .9430.5 File Trailer Service name....... ..... .STSLIB.001 Service Sub Level Name... Version Number.... ..,... .1.0.0 Date of Generation...... .02/09/16 Maximum Physical Record..65535 File Type... ........... ..LO Next File Name.... ...... .STSLIB.002 Physical EOF File Header Service name....... ..... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/09/16 Maximum Physical Record..65535 File Type...... ... ...... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER ( FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPM FET RPX RPD ROP $ 2 ( header data for each bit run in separate files. 1 .5000 START DEPTH 3841.5 3843.0 3843.0 3843.0 3843.0 3843.0 3889.0 STOP DEPTH 6386.5 6380.5 6380.5 6380.5 6380.5 6380.5 6434.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record...... ...... .Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type. ..0 05-DEC-Ol Insite 4.05.5 66.16 Memory 6435.0 18.2 39.2 TOOL NUMBER PB02321HRGV6 PB0232lHRGV6 8.500 LSND 9.70 55.0 9.0 1000 4.0 .960 .627 .250 1. 270 66.0 104.6 66.0 66.0 i( ( Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDOI0 FT/H 4 1 68 4 2 GR MWDOI0 API 4 1 68 8 3 RPX MWDOI0 OHMM 4 1 68 12 4 RPS MWDOI0 OHMM 4 1 68 16 5 RPM MWDOI0 OHMM 4 1 68 20 6 RPD MWDOI0 OHMM 4 1 68 24 7 FET MWDOI0 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3841.5 6434.5 5138 5187 3841.5 6434.5 ROP MWDOI0 FT/H 1. 89 429.71 135.629 5092 3889 6434.5 GR MWDOI0 API 11. 71 131. 78 72.6261 5091 3841. 5 6386.5 RPX MWDOI0 OHMM 0.61 1012.79 3.50387 5076 3843 6380.5 RPS MWDOI0 OHMM 0.78 1192.92 3.70483 5076 3843 6380.5 RPM MWDOI0 OHMM 0.73 2000 12.604 5076 3843 6380.5 RPD MWDOI0 OHMM 0.79 2000 10.2532 5076 3843 6380.5 FET MWDOI0 HR 0.2 5.02 0.947951 5076 3843 6380.5 First Reading For Entire File....... ...3841.5 Last Reading For Entire File... .....,. .6434.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .02/09/16 Maximum Physical Record. .65535 File Type... ........... ..LO Next File Name........ ...STSLIB.003 Physical EOF File Header Service name.......... ...STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/09/16 Maximum Physical Record. .65535 File Type.. .....,..... ...LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 6387.0 6435.0 STOP DEPTH 8966.5 9000.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG 09-DEC-Ol Insite 4.05.5 66.37 Memory 9000.0 ( MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ...... ... ..0 Data Specification Block Type.....O Logging Direction.......... ...... . Down Optical log depth units.... ...... .Feet Data Reference Point............. .Undefined Frame Spacing.. ........ .......... .60 .1IN Max frames per record. ...... ..... .Undefined Absent value.. ........ ........... .-999 Depth Units....................... Datum Specification Block sub-type...O 4.7 30.5 TOOL NUMBER PB02328HG6 8.500 9000.0 LSND 9.80 49.0 9.0 1000 3.8 1. 000 .476 .290 1. 310 Name Service Order DEPT ROP MWD020 GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API Min 6387 0.81 23.92 Max 9000 354.85 414.2 First Reading For Entire File......... .6387 Last Reading For Entire File..... ..... .9000 File Trailer Service name.. .... .... ...STSLIB.003 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation.. .... .02/09/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name.... ...., ..STSLIB.004 Mean Nsam 7693.5 5227 113.264 5131 116.849 5160 t 70.0 154.4 70.0 70.0 First Reading 6387 6435 6387 Last Reading 9000 9000 8966.5 Physical EOF ( File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/09/16 Maximum Physical Record..65535 File Type.......... .~... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPX RPM FET NPHI FCNT NCNT RPS PEF RHOB DRHO ROP $ 4 l header data for each bit run in separate files. 3 .5000 START DEPTH 8967.0 8990.0 8990.0 8990.0 8990.0 8990.0 8990.0 8990.0 8990.0 8995.0 8995.0 8995.0 9000.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 CTN SLD $ # STOP DEPTH 9408.0 9415.0 9415.0 9415.0 9415.0 9379.5 9379.5 9379.5 9415.0 9395.5 9395.5 9395.5 9430.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 COMP THERMAL NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # 18-DEC-01 Insite 4.05.5 66.16 Memory 9430.0 4.1 4.4 TOOL NUMBER PB02304HAGR4 PB02304HAGR4 PB02305NL4 PB02305NL4 8.500 QUIKDRIL-N 9.30 42.0 9.0 2800 9.0 .650 .312 .520 1. 250 68.0 149.0 68.0 68.0 ( ( NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ....... ...0 Data Specification Block Type.....O Logging Direction... ... ....... ....Down Optical log depth units.... ... ....Feet Data Reference Point....... .... ...Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.................... ..-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CP30 4 1 68 36 10 NCNT MWD030 CP30 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 B/E 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8967 9430 9198.5 927 8967 9430 ROP MWD030 FT/H 6.87 435.79 34.2185 860 9000.5 9430 GR MWD030 API 15.45 198.96 72.9141 883 8967 9408 RPX MWD030 OHMM 1. 51 1570.58 76.2428 851 8990 9415 RPS MWD030 OHMM 1. 52 2000 188.365 851 8990 9415 RPM MWD030 OHMM 1. 62 2000 187.934 851 8990 9415 RPD MWD030 OHMM 1. 57 2000 259.987 851 8990 9415 FET MWD030 HR 0.31 193.44 7.08129 851 8990 9415 NPHI MWD030 PU-S 6.42 57.6 22.7591 780 8990 9379.5 FCNT MWD030 CP30 118.02 2383.42 734.097 780 8990 9379.5 NCNT MWD030 CP30 14110 41302.5 27898.3 780 8990 9379.5 RHOB MWD030 G/CM 1. 57 2.87 2.38883 802 8995 9395.5 DRHO MWD030 G/CM -0.95 0.35 0.067207 802 8995 9395.5 PEF MWD030 B/E 1. 34 12.72 2.63956 802 8995 9395.5 First Reading For Entire File......... .8967 Last Reading For Entire File...... ... ..9430 File Trailer Service name........... ..STSLIB.004 Service Sub Level Name... Version Number..... ... ...1.0.0 Date of Generation...... .02/09/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name...... .... .STSLIB.005 Physical EOF ( Tape Trailer Service name... ....... ...LISTPE Date.....................02/09/l6 Origin...................STS Tape Name.............. ..UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments.................STS LIS Reel Trailer Service name........... ..LISTPE Date.....................02/09/16 Origin...................STS Reel Name......... """ . UNKNOWN Continuation Number..... .01 Next Reel Name.... ..., ...UNKNOWN Comments...... .......... .STS LIS Physical EOF Physical EOF End Of LIS File Writing Library. Writing Library. (' Scientific Technical Services Scientific Technical Services