The URL can be used to link to this page

Home My WebLink About201-178 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI N , REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 133 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Mo a i " ✓rL 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 201-178 3. Address: P.O.Box 196612 Anchorage, Development 8 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22742-60-00 7. Property Designation(Lease Number): ADL 0028288 8. Well Name and Number: PBU P-25L1 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: r I V E D Total Depth: measured 11205 feet Plugs measured N/A feet 7 true vertical 9010 feet Junk measured N/A feet DEC 1 20tt1q 5 Effective Depth: measured 11194 feet Packer measured 9495 feet � � true vertical 9011 feet Packer true vertical 8633 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 75 20"91.5#H-40 35-110 35-110 1490 470 Surface 3267 9-5/8"40#L-80 35-3303 35-3175 5750 3090 Production 9059 7"26#L-80 32-9091 32-8276 7240 5410 Production 1030 7"29#L-80 9091-10121 8276-8971 8160 7020 Liner 281 3-1/2"8.81#L-80 9518-9799 8653-8899 Liner 1406 2-7/8"6.16#L-80 9799-11205 8899-9010 13450 13890 Perforation Depth: Measured depth: 9897-9961 feet 10117-11193 'j True vertical depth: 8945-8955 feet 8970-9011 CA � FEB 0 4 2016 16 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 31 -9551 31-8682 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 9495-9499 8633-8636 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9897-9961,10117-11193 Treatment descriptions including volumes used and final pressure: 360BBLS NH4CI,96BBLS MUD ACID,96BBLS 12%HCI 371 psi at 1.5bpm 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 203 930 474 0 274 Subsequent to operation: 190 554 221 0 259 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations WI Exploratory 0 Development IZ Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I3 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Summerhays,Nita M(W'RO Technologies) Email Nita.Summerhays@bp.com Printed Name Summerhays ' a (WIPRO Technologies) Title Petrotechnical Data Engineer SignalA:.„/ .---'1, _....,,,,,,', f",,,,_....,,,,,,', f",,,, ice- Phone +1907-564-4035 Date 12/17/2015 Form 10-404 Revised 5/2015 VTC /2123 /5 / b RBDMS LE Z 1 9015 Submit Original Only S • Daily Report of Well Operations PBU P-25L1 ACTIVITYDATE SUMMARY T/I/O =240/1700/0. Temp = 98*. TIFL(Eval high IAP). GLT online. GLTP= 1990 psi. IA FL @ 10/22/2015 8465' (sta#3, SIO 150 bbls). Stacked out tubing/IA to 1820/1860 psi. Started IA bleed to production from 1840 psi. ***job continued on 10/23/15. WSR.*** ***Job continued from 10/22/15 AWGRS WSR***TIFL FAILED. (Eval high IAP). Continued IA bleed to production from 1840 psi to 630 psi in one hour. IA FL unchanged at 8465' 10/23/2015 (S/O 150 bbls). Monitored for 1 hour. T FL @ 8800'(140 bbls). TP decreased 30 psi, IAP increased 250 psi and no change in IA FL. Final WHPs = 1690/880/Vac. SV, WV= C. SSV, MV= 0. IA&OA= OTG. NOVP. 0230. *****WELL S/I ON ARRIVAL**** DRIFTED WITH 2.25" CENT, 1-1/2"SAMPLE BAILER TO 9842' SLM SET 4-1/2"WHIDDON ON PATCH @ 9160' SLM 10/28/2015 PULLED INT-OGLV FROM STA#3 @ 8455'SLM/8465' MD PULLED INT-LGLV FROM STA#4 @ 7313' SLM/7325' MD SET INT-LGLV IN STA#4 @ 7313'SLM/7325' MD SET INT-OGLV IN STA#3 @ 8455' SLM/8465' MD ****WSR CONTINUED ON 10/29/15**** ***WSR CONT FROM 10/28/15***(gl-integrity) 10/29/2015 PULL WHIDDON (empty) FROM 9160' SLM. ***WELL S/I ON DEPARTURE PAD-OPR NOTIFIED OF STATUS*** T/I/0=265/1730/80. Temp= 98*. TIFL PASSED. (Eval T x IA Communication). ALP @ 1730 psi & open to well. IA FL @ 8465' sta#3 SO (149 bbl). See Log for Details. Stacked TP from 265 psi to 1700 psi in 1 hour, no change in IA FL. Bled IAP from 1765 psi to 315 psi in 1 hour, No change in 10/31/2015 IA FL. Rig down & monitor for 1 hour. TP stacked out to 1800 psi during 1 hour monitor, No change in IAP, IA FL or OAP during 1 hour monitor. Final WHP's = 1800/315/0. Pad OP informed to POP well. Job Complete. SV&WV'S = C. MV&SSV= 0. IA&OA= OTG. NOVP. 14:15 11/23/2015 LRS Test Unit 1. Assist CT Mill/Acid FB/Test. Inlet P-25 Outlet P26***Rig Up, SB, Continue RU***Continue to WSR 11/24/15 CTU#8 w/ 1.5" 11/23/2015 Objective: D&T, Cont. Mill Scale, &Acidize Slotted Liner MI CTU#8- Standby for ASRC RU/Well Support to RU ***Continued on WSR 11/24/15*** 11/23/2015 T/I/O-200/1700/0 Assist well testers. Freeze protect flowline with 10 bbls neat meth. Final WHP- SSV/1700/0 FP tags hung SV,WV,SSV-closed MV-open IA/OA-OTG AL-open. 11/24/2015 LRS Test Unit 1.Assist CT Mill/Acid FB/Test. Inlet P-25 Outlet P-26. ***Continued on from WSR 11/23/15***Rig Up, PT, SB for CTU, Assist CTU, ***Job in progress continued to WSR 11/25/15*** CTU#8 w/ 1.5" (CT Vol 25.2 bbls) Objective: D&T, Cont. Mill Scale, &Acidize Slotted Liner 11/24/2015 MI CTU#8- Standby for ASRC RU/Well Support to RU - RU CTU#8- Pump 1" Drift Ball thru CT- 1" Ball Recovered- BOP Test weekly-Passed, functioned tested on installation. MU BOT ctc/mha and pressure tested lub, unable to get checks to hold, break off well. ***Continued on WSR 11/25/15*** 11/24/2015 T/1/0=0/0/0 Temp=S/I Assist CTU (ACID) Heated Ch2 diesel transport to 90***Continued on 11-25- 15 WSR** 11/25/2015 LRS Test Unit 1. Assist CT Mill/Acid FB/Test. Inlet P-25 Outlet P-26. ***Continued on from WSR 11/24/15***Assist CTU, flow well. ***Job in progress continued to WSR 11/26/15*** • • Daily Report of Well Operations PBU P-25L1 CTU#8 w/ 1.5" (CT Vol 25.2 bbls) Objective: D&T, Cont. Mill Scale, &Acidize Slotted Liner ***Continued from WSR 11/24/15*** Break off well, PT BOT ctc, mu new DFCV and passing PT on back deck, mu tools stab on well, 11/25/2015 DFCV leak. Break off well replace BOT ctc and PT'd on back deck, failed, rolled oring and passed, MU tools stab on well. Passing PT and DFCV test. Open well pump SI 1% kcl, RIH with BOT MHA/DFCV/DISCO/JSN 2.18", OAL 12.3007'. Tag 9656'and jetted with no success, POOH Attempt to mill scale using a 2.25" mill and 1.69" motor. Milled 1' in 2 hours. 8 stalls. Decision made to change out bha to a 2.125" motor and parabolic diamond speed mill. ***Job in Progress continue on WSR 11/26/15*** 11/25/2015 ***Continued from 11-24-15 WSR***Assist CTU#8 Load IA(Mill scale/Acid) Standby for CTU#8 milling. **Continued on 11-26-15 WSR*** ***Continued from 11-25-15 WSR***Assist CTU#8 w/ IA load. Standby for CTU to mill. LRS unit 11/26/2015 was released due to duration of milling. CTU in control of well upon departure. Did not pump any fluids. 11/26/2015 LRS Test Unit 1. Assist CT Mill/Acid FB/Test. Inlet P-25 Outlet P-26. ***Continued on from WSR 11/25/15***Assist CTU. ***Job in progress continued to WSR 11/27/15*** CTU#8 w/ 1.5" (CT Vol 25.2 bbls) Objective: D&T, Cont. Mill Scale, &Acidize Slotted Liner ***Continued from WSR 11/25/15*** 11/26/2015 Get tree valves serviced. RIH with 2.30" DP Mill, OAL 20.3'. Tag 9974' initial then solid at 9978', mill with many stalls, pull heavy up to 9920'and wt drops from 23k to 14.5k suspect dogleg issues, decision to Flag pipe at up wt 9975'and 9900', POOH ***Job in Progress Cont. on WSR 11/27/15*** 11/26/2015 T/I/0=1080/1040/0 Temp= SI Assist CTU w/ IA load. (ACID) Pumped 2 bbls ambient neat followed by 142 bbls crude down IA for load. ***Job Cont to 11-27-2015 WSR*** ***Job Cont from 11-26-2015 WSR***Assist CTU w/IA load (ACID) Pumped an additional 37 bbls 11/27/2015 crude (180 total) down IA for acid job. CTU in control of well per LRS departure. F W H P's=350/480/0 CTU#8 w/ 1.5" (CT Vol 25.2 bbls) Objective: D&T, Cont. Mill Scale, &Acidize Slotted Liner ***Continued from WSR 11/26/15*** LRS load IA with 180 bbls of crude. RIH with 1.90"JSN. Load well with 120 bbls of NH4CI and cap 11/27/2015 with 130 bbls of diesel. Tag @ 9664'. Talk to town and decision was made to bullhead acid from above slotted liner @ 9613. Followed Mud Acid pump schedule from 9610'. Well head injection pressure pre-acid—500 psi at 1.5 bpm down coil and post-acid 371 psi at 1.5 bpm down coil. Well turned over to Well Testers. ***Job Completed*** Fluids Summary BBLS Type 131 DIESEL 12 METH 216 60/40 METH 435 1% KCL 691 SLICK 1% KCL 322 CRUDE 360 NH4CI 96 MUD ACID 96 12% HCI 30 DIVERTER 2389 Total 'TREE= 4-1/16"ow III F3-25 ETY NOTE:WELL ANGLE>70 DEG @ 9875'&> WELLHEAD= RC 90 DEG@ 10478'.*PRE-SOTRK WELLBORE HAS OPEN • ACTUATOR= BAKER 1NMAL KB.ELE 88.95' Ll POIFS BELOiN WHIPSTOCK at PIP PKR @ 9810' HAS 11D FLOVVPATH W/DUAL FLAPPER BTM. BF.B_EV= 53.9' 1 I I 1 .. KOP= 1700' MaiAngle= 96°@ 10547 PI 0 1 1944' H4-1/2"FES KIC)SSSVN,0=3.813" I Datum ND= 9906' /8 8. EbtumlN/D= 8800'SS . 18 f 2300' HEST TOP OF CEVENT(09/19/06) • • l• • • • 19-5/8*CSG,40#,L-80,SIC-U,ID=8.835" H 3303' 1.8. &I — GAS LFT MAPERELS 1 ST ND TVD CEV 'TYPE VLV LATCH FORT DATE Minimum ID = 2.23" @ 9978' 6 3081 2977 27 KBG-2LS DONE NT' 16 03/29/13 LNR OBSTRUCTION 5 5600 5191 27 KBG-2LS DOW INT 16 03/29/13 X 4 7325 6719 29 KBG-2LS DOME INT 16 10/28/15 r CSG,26#,L-80 BTC-M,ID=6276" H 9091' .--X 3 8465 7725 28 KBG-2LS SO NT 22 10/28/15 2 9188 8362 27 KBG-2LS "DPAY INT 0 03/19/13 4-1/2"VWD STRADDLE PATCH,ID=2.35" —I 9177%9207 I (03/21/13) 1 9338 8495 29 KBG-2LS *DMY NT 0 03/20/07 STA#1=LIMY BEHRO PATCH 4-1/2"BKR STRADDLE PATCH,C=2.45" —19315%9365' "STA#2=DMY BENNO PATCH HAS EXTENDED PACKING (04/04/07) ii I I 9485' —14-112"HES X fsW,ID=3.813" 1 NOTE r CSG IS 26#FROM Z 9495' H7"X 4-1/2"BKR S-3 FKR,ID=3.875" SURFACE TO 9091'&29#FROM 951 T H3.70"BKR DEPLOY SLV,E1=3.00" 1 9091'TO TiE SHOE @ 10121'. . 9518' 1-13.70"XO TO 3-1/2",ID=2.992" 1 I TOP OF 3-1/2-LNR — 9519' 1 I I 9519' H4-1/2"HES X MP,ID=3.813" 1 I II 9539' 1—4-112"HES XN NP,ID=3.725" I I 4-1/2"TBG,12.6*,L-80,.0152 bpf,ID=3.958" H 9549' 1---/ \ 9551' H4-1/2"1NLEG,13=3.958" 1 9555' 1— ELMO TT LOGGED 04/30/97 1 13-1/2"SOLID LMR,8.81#,L-80,.0087 bpf,D=2.992" J— 9613' I 7-timucur VVNDOW(P-25L1)9725'-9731' 13-1/2"SLID LNR,8.81#,L-80,.0087 bpf,D=2.992" I-1 9706' 11BAKE:R FLOW-TI-RU WHPSTOCK H 9722' i , -. --..'-----... 9799' 3-1/2"SOLD LNR,8.81#,L-80, V V, 0087bpf,13=2.992" IRA TAG— 9732' ' — N. 9800 H3-1/2'X 3-3116"XO,D=2.786" .1 ,, 13-1/2" BKR PP PKR VW 1-D FLOVVPATH H 9810' , ><I 9801' H3-3/16"X 2-7/8-XO,ID=2.377- 1 ... 1 F ,,.. ,, 1-1 9978' 0:4_COULD NOT PALL ' PERFORATION%MARY ‘ PAST OBSTRUCTION REF LOG: SV S GR/RESISTIVITY of 10/10/01 w/223"RILL ANGLE AT TOP FERE:29°@ 9613' N Note:Refer to Proeuctidn DB for historical perf data ‘ PBTD J 11194' SIZE SPF NIERVAL Opn/Sqz SHOT SOZ \ ‘ \ N, 3-1/2" SLID 9613-9706 0 10/11/01 's-,,,, 3-318" 6 9844-9870 0 04/30/97 ,,.. 2-7/8" SLID 9897-9961 0 10/11/01 2-7/8" SLID 10117-11193 0 10/11/01 N. # *1 PBTD H 10036' ******** 12-7/8"LNR,6.16#,L-80,.0058 bpf,ID=2.441- 1-1 11205' 1 1 ... .....1.4.1...#.1. 1.......... IT'CSG,29#,1-80,SIC-U,D=6.184" H 10121. .........44.11.444.4 DATE REV BY CONIVENTS v DATE REV BY COMMENTS PRUDHOE BAY UNIT 03128/97 CHH IMTIAL COMPLETION 11/02/15 DIS/J1413 GLV CIO(10a8/15) It'VELL P-25L1 10/11/01 CFVKAK CTD SIDETRACK :12/03/15 ATOMMDLIIR OBSTRUCTION FERMI-No:"t011780 10/19/12 RCT/PJC GLV C/O(10/15/12) AR fio: 50-029-22742-60 4 . 10/30/12 DLWIJIVIDGLV C/0(10/26/12) Sec.31,11 1N,R13E,2635'FM..&2475'FVVL 11/10/12 PJC GLV/LIR CORRECTION - 08/27/13 MAC1.111/44)SET PATCH/GLV CIO(03/19-29/13) BP Exploration(Alaska) Schlumbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth dot - 'i7-"&" ~ED JAN 1 0 Z007 Well Job# Log Description Date BL 17 -20 11536189 PRODUCTION PROFILE 12/13/06 1 N-22A 11538587 LDL 12/10/06 1 R-04 11536188 LDL 12/12/06 1 17-12 N/A PRODUCTION PROFILE 11/27/06 1 B-01 N/A LDL 11/28/06 1 J-12 11513655 PRODUCTION PROPILE 11/29/06 1 13-24A 11522675 MEMORY INJECTION PROFILE 11/28/06 1 L2-06 11487579 LDL 11/29/06 1 DS 04-15 11477943 INJECTION PROFILE 12/01/06 1 P-25L 1 11513656 LDL 12/05/06 1 W-29 11549353 US IT 12/18/06 P2-50B 11513652 SCMT 11/26/06 03-08 11536186 SCMT 12/10/06 M-15 11486170 USIT 12/02/06 S-31A 11478134 USIT 11/27/06 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 01/05/2007 NO. 4101 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD ( 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Received by: e e ao' -l~' r? I~ Ii ~ FRANK H. MURKOWSKI, GOVERNOR AI¡ASHA OIL AlU) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Beverly Luedke-Chap Petroleum Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, P-25L1 Sundry Number: 306-197 SCANNE.D <:,' r) r, ¡ n (',J" J, ;~. ...0\; Dear Ms. Luedke-Chap: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisL day of June, 2006 Enel. ê)ol- I~~ 1. Type of Request: Abandon U Suspend U Operational shutdown U Perforate U Ala~8il& Gas Cons. Alter casing 0 Repair well [2] Plug Perforations 0 Stimulate 0 Time Extension 0 Anchorage Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5, Permit to Drill Number: BP Exploration (Alaska), Inc. Development ø / Exploratory 0 201-1780 / 3. Address: P.O, Box 196612 Stratigraphic 0 Service 0 6. API Number: Anchorage, AK 99519-6612 50-029-22742-60-00 / 7. KB Elevation (ft): 9, Well Name and Number: 88.95 KB P-25L 1 / 8, Property Designation: 10, Field/Pools(s): ADL-028288 PRUDHOE BAY Field 1 PRUDHOE OIL Pool ,/ 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): I Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): IPlugs (measured): IJUnk (measured): 11205 9009.84 11194 9011,03 None None Casing Length Size MD / TVD Burst Collapse Conductor 80 20" 91,5# H-40 37 117 37 117 1490 470 Surface 3268 9-5/8" 40# L-80 35 3303 35 3175 5750 3090 Production 9693 7" 29# L-80 32 9725 32 8836 8160 7020 Slotted Liner 284 3-1/2" 8.81# L-80 9517 9801 8652.19 8900 10160 10530 Slotted Liner 1404 2-7/8" 6.16# L-80 9801 11205 8899,95 9010 10570 11160 Perforation Depth MD (ft~ Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9613 - 9706 8735.97 - 8818.95 4-1/2" 12.6# L-80 30 - 9549 9897 - 9961 8944.5 - 8955.1 / 10117 -11193 8970.42 - 9011.14 9844 - 9870 8925,45 - 8936.57 Packers and SSSV Type: HES HRQ SSSVN Packers and SSSV MD (ft): 1944 4-1/2" Baker S-3 Packer 9495 ./ 12. Attachments: Descriptive Summary of Proposal ø 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Developm ent ø / Service 0 14. Estimated Date for ~6)2~06 15, Well Status after proposed work: Commencing Operations: Oil ø Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: -'. Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: Prepared by Sharmaine Vestal 564-4424 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Beverly Luedke-Chan Printed Name Be~rly)..ued~e-ChaD./ # Title Petroleum Engineer Signature ~ ..;t;,díC -~ Phone 564-5452 Date 6/2/2006 /' ~ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SUndry Number: zao~,q'ì Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: RBDMS BFt ,¡UN Q '7 70nR Subsequent Form Required: 10m) i APPROVED BY 6"1-06 Approved by: .....~MISSIONER THE COMMISSION Date: Form 10-403 Revised 7/2005 bR1BINAL Submit in Duplicate ~ ~fC. C~/d /ß/LWl1 / STATE OF ALASKA WTj ....ð'" ,J A& OIL AND GAS CONSERVATION COMMI ON lf1{' APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 W6Ä- l, /1 [Z-ÐC!)Co RECEIVED JUN 0 5 2006 sion e e To: C. Olsen/J. Bixby, GPB Well Ops TL Well Operations Team Leader Date: June 1, 2006 From: Jessica Pedota, Wells Engineer Herry Subekti Subject: P-25L 1 OA DownsQueeze PBPPDWL25-M Est. Cost: $Æ!M lOR: 400 Please pump cement down the OA as described in the following procedure. This procedure includes the following steps: Step Type Procedure 1 F OA cement down squeeze 2 F MIT OA 2400# after WOC (3 days) / P-25L 1 is a gas lifted producer that was shut in 01/06/2006 after failing annual compliance test for T x IA waiver. DGLV was done 02/28/06 but the MIT-IA still failed 03/23/06. The most recent caliper run 01/06/06 indicated no holes. A waiver would require production casing as a primary bar~r (passing CMIT-TxIA 03/23/06( and surface casing as secondary barrier (MIT-OA). The well failed an MITOA 12/28/05 with ~J.tqu~d leak rate (LLR) 4 BPM @ 1750 psi. In order to bring the well back on in line with ( ne"'!)1vaiver principles, an OA downsqueeze is recommended. " ._/./' This program is designed to pump approximately 500 feet of cement iust above the shoe in order to have a successful MITOA. The procedure includes the following major steps: 1. DHD 2. DHD 3. DHD 4. F 5. F Shoot fluid levels and record WHP's Depress OA FL w/AL Fluid pack OA with diesel as required. Bleed the Tbg and IA to +/- 200 psi. OA cement down squeeze MIT OA 2400# after waiting on cement (WOC) 3 days If you have any questions or comments regarding this procedure, please call Jennifer Julian at 564-5663 (W), 274-0929 (H), 240-8037 (C), or Jessica Pedota 830-2377 (C). cc: Well file J. Julian H. Subekti w/o: S. Rossberg e e JOB PLANNING DETAILS: MITOA on 12/28/05 failed with a LLR of 4 bpm at 1750 psi. Current wellhead temperature = Shut In (Cold) OA= 9-5/8" 40# L-80 IA= 7" 29# L-80 Shoe at 3303' OAxIA Annular Capacity=0.0282 bbls/ft Volume to shoe=93 bbl 500' of cement=14 bbl Displacement= 93 -2 (H20 spacer) - 14 (cement) - 5 (H20 flush) = 72 bbls Approximate Fluid Requirements (DownsQueeze Only): Diesel: 140 bbl DS CW101: 10 bbl Fresh Water: 80 bbl of 80 of (includes water for cement mixing and clean up.) Crude Displacement: 69 bbl at 30-60°F Arctic Set 1 Cement (15.7 ppg): 14 bbl pumpable (design the pumping time for 3+ hrs.) Note: Adjustments may be made as necessary by supervisor on-site. DHD/FB PRE-SQUEEZE: 1. Shoot fluid levels and record WHP's 2. Depress OA FL w/AL. NOTE: DO NOT proceed with procedure if the fluid level ,,/ can not be depressed to the shoe. 3. Bleed the Tbg, lA, and OA to +/- 200 psi. 4. Rig up the OA with a flanged 1502 integral union and in-line T valve. NOTE: Ensure that the OA has two valves as per double barrier policy. CEMENTING OPERATIONS: 1. Rig up cementers and Little Red/HOT Oil to in-line T valve. Flood lines with warm fresh water and pressure test lines to 3000 psi. 2. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate / up to the maximum pressure of 2000 psi. Note injectivity at pertinent times during the displacement. MITOA on 12/28/2005 failed with a LLR of 4 bpm at 1750 psi. Start pumping into the OA as follows: a. -140 bbl of warm diesel to flush OA (-1.5 times annular volume) b. 5 bbl of fresh water spaeer c. 10 bbl of DS CW101 surfactant (may be omitted) d. 5 bbl of fresh water spacer e. 14 bbl of 15.7 ppg Arctic Set 1 cement / e e f. 5 bbl of fresh water flush g. 72 bbl of 30-60 of crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 62 bbl of displacement has been pumped. Then, cut the rate to 1 BPM for another 5 bbl, then drop the rate to 0.5 BPM for the last 5 bbl. This will leave the leading edge of the cement 2 bbl short of the shoe or 71 feet. This is what we want - do not place edge of cement at shoe. 3. Shut down pumps and leave the well SI. Please DO NOT try to achieve a sQueeze or to build SQueeze pressure. The intent of this job is to place cement near the OA shoe, not to achieve a squeeze past the shoe. Reeord final pressures. Rig down and release cementers and pump trucks. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the OA. 4. Notify the Pad Operator prior to leaving location that the OA may be subject to rapid thermal pressure increases when the well is BOL. Frequent OA monitoring will be necessary for several days following the OA downsqueeze. Post SQueeze: FB: 5. woe for 3 days. MIT-OA to 2400 psi (1.2 times max wellhead pressure.) Have a pre-job safety meeting on location prior to pumping the job to discuss options to safe out the wellhouse. TREE = WELLHEAD = 4-1/16" CIW FMC BAKER 8895' 53,9' 1700' 10542' 9906' 8800' SS e 19-5/8" CSG, 40#, L-80, BTC-M, 10 = 8,835" Minimum ID = 2.372" @ 9802' 3-3/16" X 2-7/8" LNR XO 17" CSG, 26#, L-80, BTC-M. 10 = 6,276" 9091' NOTE: 7" CSG IS 26# FROM SURFACE TO 9091' & 29# FROM 9091'TOTHESHOE@ 10121', ITOP OF 3-1/2" SOLID LNR 8,81#,10 = 2992" 1 14-1/2" TBG, 126#, L-80, ,0152 bpf, 10 = 3958" I 9549' 9613' 13-1/2" BKRPIPPKRW/1"IDFLOWPATH H 9810' PERFORA TION SUMMARY REF LOG SWS GR/ RESISTIVITY of 10/10/01 A NGLE A T TOP PERF: 29 @ 9613' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-1/2" SLTD 3-9706 0 10/11/01 3-3/8" 6 9844 - 9870 0 04/30/97 SLTD 9897-9961 0 10/11/01 2-7/8" SLTD 10117 -11193 0 10/11/01 I PBm I 17" CSG, 29#, L-80, BTC-M, 10 = 6,184" DATE 03/28/97 10/11/01 12/31/05 02/28/06 REV BY COMMENTS CHH ORIGINAL COMPLETION CH/KAK CTD SIDETRACK AH/TLH GLV CORRECTIONS (10/01) V/PJC GLV C/O DATE P-25L 1 G REV BY COMMENTS / SAF OTES: WELL ANGLE> 70 DEG@ 9875' & > 90 DEG @ 10478'. * PRE-SDTRK WELLBORE HAS OPEN PERFS BELOW WHIPSTOCK. BKR PIP PKR @ 9810' HAS 1" ID FLOWPA TH WI DUAL FLAPPER BTM. 1944' -14-1/2" HES HRQ SSSVN. 10 = 3,813" I ST MD TVD DEV 6 3081 2888 28 5600 5101 27 7325 6629 29 8465 7637 28 9188 8273 28 9338 8405 28 GAS LIFT MANDRELS TYPE VLV LATCH PORT DATE KBG-2LS DMY INT 0 02/28/06 KBG-2LS DMY INT 0 02/28106 KBG-2LS DMY INT 0 09/22/01 KBG-2LS DMY INT 0 09/22101 KBG-2LS DMY INT 0 09/22101 KBG-2LS DMY INT 0 9485' -14-1/2" HES X NIP, ID = 3,813" 9495' 9517' 9519' 7" X BKR S-3 PKR. 10 3,875" 3,70" BKR DEPLOYMENT SLY, 4-1/2" HES X NIP. ID = 3,813" 9539' -14-1/2" HES XN NIP, ID = 3,725" -14-1/2" WLEG, ID = 3.958" I H ELMO TT LOGGED 04/30/971 7" CSG MILLOUT WINDOW 9725' 9731' ( OFF WHIPSTOCK) ./ 2-7/8" SL TD LNR DETAIL 9897' - 9961' SL TD LNR 10117' - 11193' SL TO LNR I 2-7/8" LNR, 616#, L-80, ,0058 bpf, 10 = 2.372" I PRUDHOE BA Y UNIT WELL: P-25L 1 PERMIT No: 201-177 API No: 50-029-22742-60 2644' NSL & 2529' WEL. Sec, 31, T11 N, R13E BP Exploration (Alaska) . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marlœr.doc I ( r~~ oj ~-~j~ DATA SUBMITTAL COMPLIANCE REPORT 1 0/22/2003 Permit to Drill 2011780 Well Name/No. PRUDHOE BAY UNIT P-25L 1 Operator BP EXPLORATION (ALASKA) INC 51' ~ ¿ ~- 0 t1- ),(j ~ fJ API No, 50-029-22742-60-00 MD 11205 ~ TVD 9010 /' Completion Date 10111/2001""'" Completion Status 1-01L Current Status 1-01L UIC N --- -- - '-~ ---- ---- REQUIRED INFORMATION Mud Log No Samples No Directional Survey ~--~~ - - ~-------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) - Log/ Data Digital Type Med/Frmt b C Pds ......--- D C Pds I IRJ*~ I I Rpt- he I Electr Dataset Number Name - --.. . u- . 0475 Induction/Resistivity 0/10475 Induction/Resistivity l..tñéÍu ctio nlRes is tiv ity L-Jfldû6tion/Resistivity M[) Tvb Log Log Run Interval OH/ Scale Media No Start Stop CH Received 1 9715 11205 Open 12/21/2001 1 9715 11205 Open 12/21/2001 25 Sep 1 9715 11205 Open 12/21/2001 25 Sep 1 9715 11205 Open 12/21/2001 Comments of- G .ru r ~ f c. \ ~ ---- ! : , -- --- --- ---- .- -_J Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y Æ) Daily History Received? ~ GIN ~-. Chips ReœÞ1ed"'? Y I N Formation Tops Analysis-- Y I N Received? - - ------. .'- Comments: Compliance Reviewed By: I~ Date: I () iV, .;~-J,_c~.cc_"'-' 1. Status of Well ~ Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ~_.,' ",,~~,,",.~--.., . "" .':',;':-::';0:\; : 2644' NSL, 2529' WEL, SEC. 31, T11 N, R13E, UM ' , "\~. ',": ' At top of productive interval ~ I 469' NSL, 4892' WEL, SEC, 30, T11 N, R13E, UM ~: .tí--:: i(~~-f- ! 1~~~~~k~~~~~, WEL, SEC, 25, T11N, R12E, UM ::.,~;:,-~~~:::J 5. Elevation in feet (indicate KB, DF, etc,) 6, Lease Designation and Serial No. KBE = 88.95' ADL 028288 12. Date Spudded 13. Date T,D, Reached 14, Date Comp" Susp., or Aband. 10/5/2001 10/10/2001 10/11/2001 17, Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 11205 9010 FT 11205 9010 FT 181 Yes 0 No 22. Type Electric or Other Logs Run GR, RES, MWD 23. CASING SIZE 20" 9-5/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-1/2" Slotted Liner 2- 7/8" Slotted Liner MD TVD MD TVD 9613' - 9706' 8736' - 8819' 9897' - 9961' 8945' - 8955' 10117' - 11193' 8970' - 9011' "- 7" 3-1/2" x 2-7/8' WT. PER FT. 91,5# 40# 26# / 29# 8.81# /6.16# 27. Date First Production October 24, 2001 Date of Test Hours Tested 1/9/2002 4 Flow Tubing Casing Pressure Press. ( STATE OF ALASKA ( ALASKA ùlL AND GAS CONSERVATION COMMI~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 7. Permit Number 201-178 8. API Number 50- 029-22742-60 '-À 9. Unit or Lease Name 'LOCA";-:oi.¡s Prudhoe Bay Unit . 1 O. Well Number P-25L 1 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21, Thickness of Permafrost (Nipple) 1944' MD 1900' (Approx.) GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 30" 60 sx Arctic Set A rox. 35' 3303' 12-1/4" 06 sx PF 'E', 293 sx Class 'G' 32' 9725' 8-1/2" 162 sx Class 'G' 9518' 11205' 3-3/4" Uncemented Slotted Liner AMOUNT PULLED 25. TUBING RECORD DEPTH SET (MD) 9551' PACKER SET (MD) 9495' SIZE 4-1/2", 12.6#, L-80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 9722' Set Whipstock 2250' Freeze Protected with 34 Bbls MeOH PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD CALCULATED 24-HoUR RATE OIL-BBL 1229 OIL-BBL GAs-McF 3096 GAs-McF WATER-BBL 432 WATER-BBL CHOKE SIZE GAS-OIL RATIO 176 2520 OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit corem:. "-""'. ..:....~;,'¡!A't.""'.~~'~: r~ :7i~.t.-"D ~ '¡)~~.L\Q'IJ..:.@ 't K: ' No core samples were taken. Form 10-407 Rev, 07-01-80 J!~~\~ 2 :1 2002 Alas?ía Oil 8: Gas Cells. Commission Ancl¡orage (: 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Sag River 9723' 8834' Shublik A 9740' 8850' Shublik B 9795' 8896' Shublik C 9839' 8923' Eileen 9875' 8938' Sadlerochit I Zone 4 1 0000' 8959' 45 SB (44P) 10257' 9004' 45 SB (44P) 1 0327' 9020' 45 SB (44P) 10960' 9027' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys .. ( 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. ~í~~» ~:~'(t-C::~; Co:~' I; "\\/l¡'r"':;o m1>'J~ Ii""~' ¡~...-.".. \\ '.,f..:-.~J 1,1 1(1.// .'.".".-.-.' L!." :" æ ~ t~""""., .~""þ l~""w ~¡ i\V ,6 ¡!".. ' JA.. N ~~ ~.' ¡"'onz. .. (", r~' ,- ,I d I\I",J"" l').~I t¡ 1""'"", 1"'....". f"r""."III"II¡<"..("¡Oi' .i"í"Ií~¡;¡'1\1(;t !1\.)!;\,)~,,~~,:\:.."J\~.~..~...O¡i. iili';¡';¡, i~ f¡¡~'I',hi'rl'..)r.lì""' :f"'III~.Wi".1 ,-I,:.:.,,", 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~ Title Technical Assistant Date () - ~3-0 P-25L 1 Well Number 201-178 Permit No. / A roval No, INSTRUCTIONS Prepared By Name/Number: Terrie Hubble, 564-4628 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none', Form 10-407 Rev. 07-01-80 OR\G\NAL (" (' Well: Field: API: Permit: P-25L 1 Prudhoe Bay Unit 50-029-22742-60 201-178 Rig Accept: Rig Spud: Rig Release: DrillingB!9: 10/03/01 10/05/01 10/11/01 Nabors 3S --.-.---.----- -.---------.----- ------- -.- -- -_. - ._-------------- _. ---.----.-. PRE-RIG WORK 09/21/01 TAG PBTD AT 9845' ELM W/ 3,65" X 20'9" DUMMY WHIPSTOCK. PULLED PART OF STA 1, 9327'. BOTTOM 4" OF 1" INTEGRAL OGLV STILL IN POCKET. PULL STA 3,8453',1" INT LGLV. PULLED ST#6INT-LGLV. PULLED ST#4 INT-LGLV, JOB IN PROGRESS. 09/22/01 PULLED ST#5 INT-LGLV. SET INT-DGLV AT ST#6, ST#5, ST#4, ST#3. PUMP 5 BBLS METHANOL, 305 BBLS CRUDE DOWN lA, SET INT-DGLV STA 1. PULLED C-SUB AND RECOVERED BOTTOM 4" OF OGLV W/COLLET(LOST 09-21-01). ATTEMPT MITIA (lA TRACKING TBG), RIH W/41/2"CAT STANDING VALVE. LOAD AND TRANSPORT 190 BBLS. OF D,C. FROM F,S.#1. PJSM. RIG TO LA, & P,T, DISPLACE LA. WITH 305 BBLS. OF D,C, STANDBY WHILE SLICK LINE SET DUMMY. M,I.T, THE LA. AT 3000 PSI. FAILED AT 2600 PSI. PUMPED 42 BBLS, D.C, TO CONFIRM TBG. COMMUNICATION. 09/23/01 MITOA PASSED/PPPOT-T PASSED/ MIT-MV & WING & SWAB, PASSED CMIT AT 3000 PSI. FREEZE PROTECTED THE TBG, WITH 38 BBLS. AND THE F/L WITH 15 BBLS, 50/50 MEOH. SET 4 1/2" CAT STANDING VALVE AT XN NIPPLE AT 9526'SLM. PERFORM CMIT W/HB&R. GOOD TEST (3000 PSI). PULLED STANDING VALVE OOH. DSO NOTIFIED OF MIT & FREEZE PROTECT, WELL LEFT S/IN. 09/28/01 MIRU DS CTU #5 (18,760'- 1,75" TAPERED STRING, 40.7 BBLS). RIH WITH 3" JET SWIRL NOZZLE, TAG HARD AT 9847' CTD, START FCO TAKING RETURNS TO TANKS, SOME GAS IN RETURNS. HARD TAGS AT 9976' AND 9987' CTD, CONTINUE FCO WITH BIOZAN AND 2% FILTERED SLICK KCL TO A FINAL DEPTH OF 10027' CTD (PBTD). POOH AT 80% 09/29/01 FCO TO PBTD OF 10027' CTD, FREEZE PROTECT WELL TO 2500' WITH 50/50 METH, FLOW LINE FREEZE PROTECTED PER PAD OPERATOR. 09/30/01 BAKER PIP PACKER SET @ 9810', 1 0/01/01 WHIPSTOCK SET @ 9722' , ORIENTED 6 DEG. LEFT OF TOP. BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: P-25 Common Well Name: P-25L 1 Spud Date: 9/28/2001 Event Name: REENTER+COMPLETE Start: 10/2/2001 End: 10/11/2001 Contractor Name: NABORS Rig Release: 10/11/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/2/2001 06:00 - 23:00 17.00 MOB N WAIT PRE RIG STANDBY WAITING ON LOCATION PREP AT P-25 (BLEED FLOWLINE, REMOVE WELLHOUSE, ND FLOWLINE AND TREE, GRADE AND LEVEL LOCATION). 23:00 - 00:00 1.00 MOB P PRE POSITION RIG OVER WELL. RU. 10/3/2001 00:00 - 05:00 5.00 RIGU P PRE RIG UP. ACCEPT RIG 05:00 HRS 10-3-2001. 05:00 - 06:00 1.00 RIGU P PRE START NU BOPE. 06:00 - 06:45 0.75 RIGU P PRE CREW CHANGE SAFETY MEETING. 06:45 - 09:30 2.75 RIGU P PRE CONTINUE NU. 09:30 - 11 :00 1.50 BOPSUF P DECOMP RU FOR BOP TEST 11 :00 - 11 :30 0.50 BOPSUF P DECOMP PT BACKSIDE LINE. 11 :30 - 12:00 0.50 BOPSUF P DECOMP CREW CHANGE SAFETY MEETING. 12:00 -13:00 1.00 BOPSUF P DECOMP PERFORM INITIAL BOP TEST. WITNESS WAIVED BY JOHN SPAULDING (AOGCC). 13:00 -15:30 2.50 BOPSUF N SFAL DECOMP REPLACE LEAKING BLINDS. 15:30 - 21 :00 5.50 BOPSUF P DECOMP CONTINUE BOP TEST. 21:00-21:30 0.50 STWHIP P WEXIT PRE-JOB SAFETY MEETING. 21 :30 - 22:30 1.00 STWHIP P WEXIT PRESSURE TEST THE INNER COIL VALVE, PACKOFFS 22:30 - 23:15 0.75 STWHIP N MISC WEXIT ATTEMPT TO PULL THE 2-WAY CHECK. HYDRAULIC UNIT ON WELL SUPPORT TRUCK NOT WORKING. TROUBLE SHOOT HYDRAULICS. 23:15 - 23:45 0.50 STWHIP P WEXIT PULL 2-WA Y CHECK. 23:45 - 00:00 0.25 STWHIP P WEXIT FILL HOLE WITH FLUID PRIOR TO PU OF BHA. 10/4/2001 00:00 - 01 :30 1.50 STWHIP P WEXIT FILL HOLE AND MONITOR FOR LOSSES. HOLE TOOK 31 BARRELS TO FILL. 01 :30 - 02:00 0.50 STWHIP P WEXIT MU MILLING BHA WITH 3.8' MILL. 02:00 - 04:30 2.50 STWHIP P WEXIT RIH WITH MILLING BHA. 04:30 - 04:40 0.17 STWHIP P WEXIT TAG THE SWN NIPPLE AT 9543' CTD (no correction) 04:40 - 05:05 0.42 STWHIP P WEXIT MILL THE SWN NIPPLE AT 9543' TO 3.8" ID. 05:05 - 05:15 0.17 STWHIP P WEXIT MAKE THREE PASSES THROUGH THE SWN NIPPLE WITH THE STRING REAMER. 05:15 - 06:00 0.75 STWHIP P WEXIT RIH TO THE WHIPSTOCK. DRY TAG 9709' CORRECTED DEPTH. STALLED 9710.3' WITH PUMPS. 2.6/1900 PSI FS-- NO LOSSES. 06:00 - 09:00 3.00 STWHIP N WEXIT START MILLING AT 9710.1' CORRECTED DEPTH, EASING INTO IT TO ESTABLISH A PATTERN. GETTING SLIGHT PRESSURE INCREASE WITH EACH MOVEMENT, AND SEEING IT TAKE WEIGHT AND GIVE IT BACK -- BUT LOOKS LIKE WE'VE BEEN MILLING AIR FOR 3 HRS. 09:00-13:15 4.25 STWHIP P WEXIT RIH AND TAG THE REAL PINCH POINT 9725'. MILLED WINDOW AND 10' FORMATION TO 9741'. 13:15 -14:30 1.25 STWHIP P WEXIT REAM WINDOW. RIH DRY -- CLEAN. 14:30 -15:00 0.50 STWHIP P WEXIT SWAP WELL OVER TO FLO-PRO MUD. 15:00 -17:00 2.00 STWHIP P WEXIT POOH. 17:00 -18:00 1.00 STWHIP P WEXIT LD MILLING BHA. DIAMOND MILL GAGE 3.72"-- SIGNIFICANT WEAR ON GAGE, BUT GOOD (NORMAL) CENTER WEAR. STRING MILL TOOK A BEATING -- GAGE AT 3.70". CALL FOR ANOTHER STRING MILL. 18:00 -18:30 0.50 STWHIP P WEXIT CREW CHANGE SAFETY MEETING. 18:30 - 20:30 2.00 STWHIP P WEXIT CUT 150' OF PIPE (BAD WRAPS CAUSING SPOOL TO "GROW" -- PIPE SCRAPING THE SUMP). REHEAD WITH DRILLING CONNECTOR. 20:30 - 20:50 0.33 STWHIP N DPRB WEXIT MU NEW STRING MILL AND USED TAPERED DSM. 20:50 - 00:00 3.17 STWHIP N DPRB WEXIT RIH WITH BHA TO DRESS THE WINDOW TO FULL GAUGE ( (" Printed: 10/15/2001 12:38:00 PM BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: P-25 Common Well Name: P-25L 1 Spud Date: 9/28/2001 Event Name: REENTER+COMPLETE Start: 10/2/2001 End: 10/11/2001 Contractor Name: NABORS Rig Release: 10/11/2001 Rig Name: NABORS 38 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/4/2001 20:50 - 00:00 3.17 STWHIP N DPRB WEXIT OF 3.8". RUNNING THE SAME CONFIGURATION AND DIMENSIONS AS PREVIOUS BHA, ONLY WITH NEW STRING MILL AND WINDOW MILL. CONDUCTED SPILL DRILL. 10/5/2001 00:00 - 01 :30 1.50 STWHIP N DPRB WEXIT CONTINUE IN HOLE WITH MILL. HOLE IS DRINKING ABOUT 6 BPH OF FLO-PRO. 01 :30 - 02:10 0.67 STWHIP N DPRB WEXIT REAM THROUGH THE WINDOW. OBSERVED MOTOR WORK OF APPROX 60 PSI. MADE A TOTAL OF 3 PASSES THROUGH THE WINDOW WHILE CIRCULATING AND THEN ONE DRY PASS. TAGGED TD AT 9741' AND FLAGGED THE COIL. 02:10 - 04:00 1.83 STWHIP N DPRB WEXIT POOH WITH MILL. 04:00 - 04:30 0.50 STWHIP N DPRB WEXIT LAY DOWN MILLING BHA 04:30 - 05:30 1.00 DRILL P PROD1 MU DRILLING BHA 05:30 - 06:15 0.75 DRILL P PROD1 RIH WITH DRILLING BHA (BHA #3) 06:15 - 06:45 0.50 DRILL P PROD1 SHALLOW TEST. THROTTLE PROBLEMS, CAN'T CHECK ORIENTER. MWD OK. 06:45 - 08:15 1.50 DRILL P PROD1 RIH. SD IN #5 GLM. PU, SKIP PAST. RIH. Saw #1 GLM. 08:15 - 08:45 0.50 DRILL P PROD1 LOG TIE-IN AT 9546+' GR SPIKE. LOSSES: 2.7/2.4 2600 PSI. lAP = 1000PSI. LOSSES INCREASED TO 2.7/2.0 DURING LOG. NO CORRECTION. 08:45 - 09:00 0.25 DRILL N PROD1 ADJUST THROTTLE. 09:00 - 09:15 0.25 DRILL P PROD1 RIH HIGHSIDE. TAG 9716' BUT FELL THRU. RIH TO TD 9741'. 09:15 - 09:30 0.25 DRILL P PROD1 TF AT 22L. DRILL ABOUT 2 FEET, STALL. PU. TF AT 70R, THEN 150R. 09:30 - 10:30 1.00 DRILL N DFAL PROD1 CAN'T GET TF TO COME OFF OF 150R. LOSSES STEADY 2.8/2.3. 10:30-12:15 1.75 DRILL N DFAL PROD1 POOH. 12:15 - 13:45 1.50 DRILL N DFAL PROD1 SWAP TORC TOOLS (HIGH VOLTAGE SHORT). CO BITS -- BROKEN TEETH (FROM GLM'S?). 13:45 - 15:15 1.50 DRILL N DFAL PROD1 RIH. SHALLOW TEST. TORC NOT ACCEPTING COMMANDS -- LAST TOOL AVAILABLE. CALL FOR SPERRY ORIENTER. POOH. 15:15 -17:15 2.00 DRILL N DFAL PROD1 LD TORC. PERFORM SURFACE CHECKS WHILE WAITING ON SPERRY'S STUFF. SURFACE TEST SPERRY ORIENTER. 17:15 -18:00 0.75 DRILL N DFAL PROD1 MU BHA #5. 18:00 -18:15 0.25 DRILL N DFAL PROD1 RIH. SHALLOW TEST MWD GOOD. 18:15 - 20:00 1.75 DRILL N DFAL PROD1 CONTINUE TO RIH WITH BHA 20:00 - 20:30 0.50 DRILL N DFAL PROD1 ADJUST LINKAGE ON PUMP THROTLE. 20:30 - 21 :30 1.00 DRILL N DFAL PROD1 ORIENT MOTOR AND INITITATE MWD TOOL FOR CONTINUOUS INCLINATION. 21 :30 - 23:00 1.50 DRILL N DFAL PROD1 TRIED TO DRILL NEW HOLE FROM 9746' WITHOUT SUCCESS. MOTOR KEPT STALLING WHEN IT TAGGED BOTTOM. TRIED PICKING UP AND ORIENTING THE MOTOR TO A DIFFERENT DIRECTION, BUT STILL COULD NOT KEEP THE MOTOR FROM STALLING ON BOTTOM. ACTED LIKE THE BIT WAS STALLING ON METAL. FINALLY, ORIENTED THE MOTOR TO 30R AND BEGAN MAKING HOLE. 23:00 - 00:00 1.00 DRILL P PROD1 DRILLING AHEAD. SLOW CIRCULATION RATES I ( ( Printed: 10/15/2001 12:38:00 PM BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: P-25 Common Well Name: P-25L 1 Spud Date: 9/28/2001 Event Name: REENTER+COMPLETE Start: 10/2/2001 End: 10/11/2001 Contractor Name: NABORS Rig Release: 10/11/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/5/2001 23:00 - 00:00 1.00 DRILL P PROD1 PRESSURES: 0.5/350, 1.7/1200,2.5/2550. LOSSES ARE ABOUT 8 BPH. 10/6/2001 00:00 - 04:00 4.00 DRILL P PROD1 DRILLING AHEAD. 04:00 - 04:10 0.17 DRILL P PROD1 DRILLING AHEAD AT 9820'. 04:10 - 05:00 0.83 DRILL P PROD1 DRILLING AHEAD AT 9833' AT 0500 HRS. FLUID LOSS RATE OF 10 BPH. 05:00 - 05:30 0.50 DRILL P PROD1 DRILLING AHEAD TO 9841'. 05:30 - 09:00 3.50 DRILL P PROD1 DRILL 2.7/2.6 2950 PSI FS. HIGH LEFT TF. TYPICAL SHUBLIK DRILLING AT <20 FPH. DRILL TO 9915', END OF DESIRED 30 DEG CURVE (GOT UP TO 42 DEG DL). Reached "CAPS LOCK" burnout, need a weekend reprieve. 09:00 - 09:30 0.50 DRILL P PROD1 Slow wiper to window. 09:30 - 11 :30 2.00 DRILL P PROD1 POOH. 11 :30 - 13:00 1.50 DRILL P PROD1 LD BHA #5. MU BHA #6 (1.15 deg motor; DS49). 13:00 - 14:45 1.75 DRILL P PROD1 RIH. Shallow test good. 14:45 -15:15 0.50 DRILL P PROD1 Log tie-in at 9546+' GR spike. No correction 15:15 -17:15 2.00 DRILL N DFAL PROD1 Attempt to orient to 70R in open hole. No clicks. Attempt to orient in cased hole. No clicks. Drill 10' to 9925' at 1 Gal. Slam into bottom and stall motor. PUH and try to get clicks in open hole and cased hole. Nothing. 17:15-19:00 1.75 DRILL N DFAL PROD1 POOH for failed orienter. 19:00 - 20:00 1.00 DRILL N DFAL PROD1 Swap orienters and MWD. 20:00 - 21 :00 1.00 DRILL N DFAL PROD1 RI H and shallow test orienter at 1700'. OK. 21 :00 - 22:35 1.58 DRILL N DFAL PROD1 Tag window with the bit. 22:35 - 22:50 0.25 DRILL N DFAL PROD1 Pick up to above the window and orient to topside. 22:50 - 23:00 0.17 DRILL N DFAL PROD1 RIH to TD. Coil depth was 9928', actual TD was 9925'. Subtracted 3' from coil depth. 23:00 - 00:00 1.00 DRILL N DFAL PROD1 Orient toolface. Orienter clicking once for every two cycles. Fluid losses of 14 BPH from 11 :00 pm to midnight. 1017/2001 00:00 - 00:10 0.17 DRILL N DFAL PROD1 Orient tool face to 79R. 00:10-01:10 1.00 DRILL P PROD1 Resume drilling at 9925'. 01:10-01:30 0.33 DRILL P PROD1 Orient tool face from 60R to 79R. 01 :30 - 01 :50 0.33 DRILL P PROD1 Drill to 9975' 01 :50 - 02:10 0.33 DRILL P PROD1 Wiper trip from 9975' to 9745'. 02:10 - 02:35 0.42 DRILL P PROD1 Drill to 9998'. 02:35 - 02:50 0.25 DRILL P PROD1 Orient tool face to 90R from 60R. 02:50 - 03:50 1.00 DRILL P PROD1 Fluid losses of 12 BPH. Drilling at 10,027' at 3:50 AM. 03:50 - 04:00 0.17 DRILL P PROD1 Orient tool face to 97R from 85R. 04:00 - 05:30 1.50 DRILL P PROD1 Drill ahead to 10,075'. 05:30 - 05:45 0.25 DRILL P PROD1 Wiper trip and high vis sweep from 10,075' to 9,750'. 05:45 - 06:15 0.50 DRILL P PROD1 Get survey and orient toolface to 121 R. 06:15-07:15 1.00 DRILL P PROD1 Drill to 10125'. 07:15 - 08:00 0.75 DRILL P PROD1 Wiper to window with 10 bbl sweep (25# Flo-Vis in 30 bbls). Overpull with stall in 10,000' shale. Ream this area. 08:00 - 08:35 0.58 DRILL P PROD1 Drill to 10160' at 120R TF. 08:35 - 08:45 0.17 DRILL P PROD1 Orient to drop down faster (we've been about 8' above line and want to get closer to it before crossing fault). 08:45 - 09:00 0.25 DRILL P PROD1 Drill to 10180'. 09:00 - 09:45 0.75 DRILL P PROD1 Project 76 deg at bit. Orient -- struggle getting clicks. 09:45 - 10:45 1.00 DRILL P PROD1 Drill85L 2.6/2.5 to 10225'. Losses 5 BPH. 10:45 - 11 :45 1.00 DRILL P PROD1 Wiper to window. Work 10000' stinker (white clay). 11:45 -12:50 1.08 DRILL P PROD1 Drill80L 2.5/2.4 to 10275'. Losses about 10 BPH. ( ( Printed: 10/15/2001 12:38:00 PM BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: P-25 Common Well Name: P-25L 1 Spud Date: 9/28/2001 Event Name: REENTER+COMPLETE Start: 10/2/2001 End: 10/11/2001 Contractor Name: NABORS Rig Release: 10/11/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10n/2001 12:50 - 13:50 1.00 DRILL P PROD1 Wiper to 9950'. White clay at 10000' getting uglier both directions. Will bump-up Kla-Gard to 12 ppb. 13:50 - 15:15 1.42 DRILL P PROD1 Lost desired TF working the clay. Orient around. Just getting 10 deg clicks. Also, lots of noise -- slow getting TF verification. Losses last hour = 8 bbls. 15:15 - 16:00 0.75 DRILL P PROD1 Drill to 10,327'. 16:00 - 16:45 0.75 DRILL P PROD1 Wiper to window. 16:45 - 17:45 1.00 DRILL P PROD1 Drill 2.5/2.4 3,000 psi FS to 10,375'. 17:45 - 18:15 0.50 DRILL P PROD1 Wiper to 9,950'. Clay at 10,000' cleaning up -- less grabby, less pucker. 18:15 - 18:45 0.50 DRILL P PROD1 Orient 18:45 - 20:00 1.25 DRILL P PROD1 Drill to 10,425'. 20:00 - 20:50 0.83 DRILL P PROD1 Wiper to window. Still sticky at +/- 10,000'. 20:50 - 21 :30 0.67 DRILL P PROD1 Orient and survey. Losses over the last hour were 14 barrels. 21 :30 - 23:00 1.50 DRILL P PROD1 Drilling ahead, 2.6/2.4/3,075, 23L. Stop at 10,475'. 23:00 - 00:00 1.00 DRILL P PROD1 Wiper to window. Very sticky 9,980' to 10,100'. Pumped 10 barrel sweep. 10/8/2001 00:00 - 01:10 1.17 DRILL P PROD1 Drilling ahead to 10,525' 01:10 - 02:00 0.83 DRILL P PROD1 Wipe hole to window. Pumps run at 2.5 BPM while pulling up hole. Tight spots and motor work observed between 9980' and 10,100'. Hole loosing 15 BPH. 02:00 - 02:40 0.67 DRILL P PROD1 Orient tool face to 60L 02:40 - 03:20 0.67 DRILL P PROD1 Drilling ahead to 10,575'. 03:20 - 04:30 1.17 DRILL P PROD1 Wiper trip from 10,575' to the window. Pumps running at 2.5 BPM while pulling up hole. The hole is again sticky (9980' to 10,100') with the stickiest spot at about 10,030'. Pumped a 10 barrel sweep. 04:30 - 05:15 0.75 DRILL P PROD1 Orient tool face to 11 OR. 05:15 - 06:30 1.25 DRILL P PROD1 Drill to 10625'. 06:30 - 07:30 1.00 DRILL P PROD1 Wiper to window. 07:30 - 08:15 0.75 DRILL P PROD1 Drill to 10680'. 08:15 - 09:30 1.25 DRILL P PROD1 Wiper to window. Big struggle getting back down thru 10030' clay. 09:30 - 10:10 0.67 DRILL P PROD1 Drill to 10,686'. 10:10 -11:15 1.08 DRILL P PROD1 Orient around. Took 33 clicks. 11:15 -12:30 1.25 DRILL P PROD1 Drill 2.5/2.3 to 10720'. TF shifted 50 deg to right. 12:30 - 13:45 1.25 DRILL P PROD1 Wiper to window. 13:45 - 14:15 0.50 DRILL P PROD1 Need to orient around (bazillion clicks). Stop halfway there. TORC tool ready!! 14:15 - 16:30 2.25 DRILL N DFAL PROD1 POOH 16:30 - 17:30 1.00 DRILL N DFAL PROD1 Dump memory data, swap probes. Errosion on probe. Swap collar adjacent to this. Swap motors. LD Sperry orienter. 17:30 - 19:00 1.50 DRILL N DFAL PROD1 MU BHA #8 with Torc orienter. 19:00 - 19:30 0.50 DRILL N DFAL PROD1 Perform shallow hole test at 1700', ok. 19:30 - 21:20 1.83 DRILL N DFAL PROD1 RIH to tie-in point (9560'). 21 :20 - 22:00 0.67 DRILL N DFAL PROD1 Tie-in at 9547', no correction. Saw very little hang-up at 9980'-10,100' on the way in the hole. 22:00 - 22:25 0.42 DRILL N DFAL PROD1 RIH to TD at 10,724'. 22:25 - 23:00 0.58 DRILL P PROD1 Orient Toolface to 60R. 23:00 - 00:00 1.00 DRILL P PROD1 Drill Ahead to 10,790'. 10/9/2001 00:00 - 00:40 0.67 DRILL P PROD1 Drill from 10,790' to 10,820'. Pump sweep. 00:40 - 01 :55 1.25 DRILL P PROD1 Wiper trip to window. Lost 16 bbls 00:00 to 01 :00 hrs. 01 :55 - 04:00 2.08 DRILL P PROD1 Drilling ahead to 10,903'. Drilling got very slow, pumped sweep. ( (' Printed: 10/15/2001 12:38:00 PM BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: P-25 Common Well Name: P-25L 1 Spud Date: 9/28/2001 Event Name: REENTER+COMPLETE Start: 10/2/2001 End: 10/11/2001 Contractor Name: NABORS Rig Release: 10/11/2001 Rig Name: NABORS 38 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/9/2001 04:00 - 05:10 1.17 DRILL P PROD1 Immediately followed sweep with short trip to the window. Hole was very sticky again from 10,000' to 10,100'. Lost 17 barrels of fluid from 04:00 to 05:00 hrs. 05:10 - 05:40 0.50 DRILL P PROD1 Orienting tool face and pumping up survey. 05:40-07:15 1.58 DRILL P PROD1 Drill from 10,950'. Lots of stacking. 07:15-07:30 0.25 DRILL P PROD1 BHA wiper. Mix drum of lubetex in 30 bbl 70000 LSRV pill. 07:30 - 09:20 1.83 DRILL P PROD1 Drill slow. Acts like shale. 10 bbllubetex pill didn't appear to help slide this time. Drill to 11000'. 09:20 - 10:15 0.92 DRILL P PROD1 Wiper to window. Minimal motor work thru 10000' shale, but could see entire BHA on wt ind dragging it thru. Last hour losses: 11 bbls. 10:15 -14:00 3.75 DRILL N DPRB PROD1 Try to work past clay starting at 9990' wlo pumps and 130R TF (drilled at 120R). Unable to work past. Clean PU's. Try to skip past with min pumps. No go. Adjust TF to 30R. Work pipe. Try highside. Made 5' to 9995'. PU. RIH. Bobble at original 9990', then SD at 9995'. Try TF's high left. Pump 10 bbl 7% lubetex pill. Work pipe while trickling pill out bit. 14:00 - 15:30 1.50 DRILL N DPRB PROD1 POOH with BHA. 15:30 - 17:40 2.17 DRILL N DPRB PROD1 Download Res data. Problems with surface computer reading data. PIU dual-gauge bit. 17:40 - 20:00 2.33 DRILL N DPRB PROD1 TIH shallow test tools at 1700'. 20:00 - 21 :00 1.00 DRILL N DPRB PROD1 Tie-in with GR spike at 9547'. No correction. 21 :00 - 00:00 3.00 DRILL N DPRB PROD1 Try to enter hole at 9995' with the TF at 0, 135R, 165R, 165L, etc. no luck. Pick up to 9950' and orient to 120R and work down to 9993' at 1.1, 1.6, and 2.6 BPM. No luck. Orient high side and bring pumps up to 2.6 BPM and set down to 9997'. Pick up and set down several more times to 10,005'. Pick up several more times and worked the bit down to 10,007'. 10/10/2001 00:00 - 00:30 0.50 DRILL N DPRB PROD1 Continue to pump at 2.6 BPM and maintain the tool face high side. Work the coil down and through the shale and into zone 4 at +1-10,100'. 00:30 - 00:45 0.25 DRILL N DPRB PROD1 Continue in the hole to 10,996'. 00:45 - 01 :15 0.50 DRILL P PROD1 Pump up direction and inclination survey and orient tool face to 11 OR. 01:15-02:10 0.92 DRILL C PROD1 Drilling ahead from 11,000' to 11,057'. Lost 8 bbls from 01 :00 to 02:00 hrs. 02:10 - 02:35 0.42 DRILL C PROD1 Pump up D&I survey. Slow pump rates are as follows: 0.5/430, 1.3/900, 2.7/3000. 02:35 - 03:10 0.58 DRILL C PROD1 Drilling ahead from 11,057' to 11,109'. 03:10 - 03:25 0.25 DRILL C PROD1 Pump up directional survey. 03:25 - 04:00 0.58 DRILL C PROD1 Drilling ahead from 11,109' to 11,137'. Hole got sticky. 04:00 - 04:20 0.33 DRILL C PROD1 Wipe hole up to 10,800'. Hole sticky on the way back to bottom. 04:20 - 06:30 2.17 DRILL C PROD1 Drill ahead from 11,137' to 11200' while making frequent mini-short trips to keep weight on the bit. Motor stalling. 06:30 - 07:00 0.50 DRILL P PROD1 Survey at 11169'MD. Project to 11200' with a 8920.8' TVD. 07:00 - 08:00 1.00 DRILL P PROD1 Wiper trip to 10200'. Tight at 10920'. Noticing chunks of stator rubber across shaker screens. Explains frequent motor stalling this AM while drilling. 08:00 - 10:30 2.50 DRILL P PROD1 Logging tie-in points f/1 0220' to 10360' for TD correction. (ordered KCL and NaCL for weighting material to bring MW up to 8.9ppb) Mud losses this morning averaging 5 bph. 10:30 - 11 :30 1.00 DRILL N RREP PROD1 Replace worn altenator cable on CTU power pack (' (i Printed: 10/15/2001 12:38:00 PM BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: P-25 Common Well Name: P-25L 1 Spud Date: 9/28/2001 Event Name: REENTER+COMPLETE Start: 10/2/2001 End: 10/11/2001 Contractor Name: NABORS Rig Release: 10/11/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/10/2001 11 :30 - 11 :45 0.25 DRILL P PROD1 Resume logging. +9' correction. 11 :45 - 12: 15 0.50 DRILL P PROD1 RIH to bottom. Tag 11196' correct to 11205'. Pump pressure up 500 psi from previous off-bottom drilling pressures.. Maybe paritially plugged jets from stator rubber. 12:15 - 12:30 0.25 DRILL P PROD1 Drilled f/11205' to 11206'. Recieved orders from town to quit drilling and call this TD. PIU and tag calling final TD 11205'. 12:30 -13:30 1.00 DRILL P PROD1 Circulate off bottom and continue weighting up mud system to 8.9ppg. Notified AOGCC of BOP test due tomorrow and asked for 1 day extension - granted. 13:30 - 16:35 3.08 DRILL P PROD1 Wiper trip to window overpull at 10,890' some motor work through shales 10,150-10,000'. Going back stopped at 9,992'. toolface at 30R worked pipe wo pumps no luck. Orient to 5L work wlwo pump at varies rates no luck. Orient to 20R worked pipe down to 9,998'. Continue working pipe mainly wo pump for next hour down to 10,006' and finally went though. TIH small bobble at 10890 plu and went through okay to TD. 16:35 - 18:30 1.92 DRILL P PROD1 Circulate/condition hole and pump 10 bbl 75k LSRV sweep to surface. Fluid losses averaging 5 BPH. 18:30 - 21:00 2.50 DRILL P PROD1 TOH for liner laying in 75k LSRV new mud in open hole. BHA was pulled up through the hole section from 10,100' to 9,980' with no noticable drag or motor work. 21:00-21:15 0.25 DRILL P PROD1 PJSM prior to laying down drilling BHA and picking up liner. 21:15 - 22:30 1.25 DRILL P PROD1 Lay down drilling BHA. Found a piece of motor stator rubber in nozzle of bit. 22:30 - 00:00 1.50 CASE P PROD1 Make up slotted liner assembly. Fluid losses averaging 5 BPH. 10/11/2001 00:00 - 01 :20 1.33 CASE P PROD1 Finish picking up liner assembly. 01 :20 - 02:20 1.00 CASE P PROD1 Make up Baker coil connector and test. 02:20 - 04:45 2.42 CASE P PROD1 RIH with liner. Tag TD at 11,207' with liner. Noted weight indicator bobbles when guide shoe passed through 9995', 10,005', and 10,025'. 04:45 - 07:10 2.42 CASE P PROD1 Drop and pump .625" ball but unable to get on seat. Dropped 2nd ball and on seat after 42 bbls pumped. Sheared liner release tool. P/U and confirmed liner released. 07:10 - 07:35 0.42 CASE P PROD1 Circulate around 3% KCL water. 07:35 - 08:50 1.25 CASE P PROD1 TOH to 2250'. 08:50 - 09:30 0.67 CASE P PROD1 Freeze protect well with 34 bbls of 60/40 meth from 2250' to surface. 09:30 -10:10 0.67 CASE P PROD1 LID Baker tools. 10:10-15:00 4.83 CASE P PROD1 RID CTU #4. Same time install BPV, clean rig tanks etc. N/D BOP's and hard lines to outside tanks. Installed and tested tree cap to 4500 psi. CTU #4 to Deadhorse off location @ 1445 hrs Nabors 3S released at 1500 hrs 10-11-2001 (' (" Printed: 10/15/2001 12:38:00 PM ANADRILL SCHLUMBERGER Survey report Client...... .....,. ......: BP Exploration (Alaska) Inc. Field,.....,.............: Prudhoe Bay Well.....................: P25-L1 API number..... ..........: 50-029-22742-60 Engineer.................: E. Roux COUNTY:..................: Nabors 3S / Dowell #4 .........................: Alaska ----- Survey calculation methods------------- Method for positions....,: Minimum curvature Method for DLS.....,....,: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference.... ......: GR Tie-in @ 10329 ft GL above permanent.......: 0.00 ft KB above permanent...,...: -50000.00 ft DF above permanent,. .....: -50000.00 ft ----- Vertical section origin---------------- Latitude (+N/S-)...,....,: 0.00 ft Departure (+E/W-),.,.....: 0.00 ft ----- Platform-reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-).......,: -999.25 ft Azimuth from rotary table to target: 342.87 degrees [(c)2001 Anadrill IDEAL ID6_1C_10J 10-0ct-200113:36:26 Spud date..............,.: Last survey date.,...,...: Total accepted surveys.,,: MD of first survey......,: MD of last survey...,..,,: Page 1 of 3 04-0ct-01 10-0ct-01 38 9717.51 ft 11205.00 ft ~= ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2000 Magnetic date.....,......: 03-0ct-2001 Magnetic field strength..: 1149.32 HCNT Magnetic dec (+E/W-).....: 26.39 degrees Magnetic dip.............: 80.73 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..,........... : H..,....,......: Dip.....,......: of G...... , . . . . : of H...,.......: of Dip.........: Criteria --------- 1002.68 mGal 1149.32 HCNT 80.73 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ---"-- ----- Corrections --------------------------- Magnetic dec (+E/W-)..,..: 26.39 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)..,,: 26.39 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)..,.....: No degree: 0,00 ANADRILL SCHLUMBERGER Survey Report 10-0ct-200113:36:26 Page 2 of 3 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) ( deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 1 9717.51 23.55 325.44 0.00 8740.52 3444.46 2908.43 -2257.93 3682.01 322.18 0,00 TIP 2 9731.50 24.90 325.40 13.99 8753.28 3449.94 2913.16 -2261.19 3687.74 322.18 9.65 MWD 3 9758.00 29.32 328.86 26.50 8776.86 3461.56 2923.31 -2267.71 3699.76 322.20 17.70 MWD 4 9788.00 40.22 332.78 30.00 8801.47 3478.28 2938.25 -2275.97 3716.64 322.24 37.07 MWD 5 9815.01 51.25 336.32 27.01 8820.30 3497.39 2955.71 -2284,22 3735.49 322.30 41.88 SP 6 9846.67 61.60 336.74 31.66 8837.78 3523.57 2979.87 -2294.70 3761.03 322.40 32.71 SP - "-~ 7 9871.62 69.05 329.39 24.95 8848.20 3545.87 3000.03 -2305.00 3783.28 322.46 40.08 SP 8 9893.29 76.15 327.44 21.67 8854.68 3565.88 3017.63 -2315.83 3803.84 322.50 33.87 SP 9 9921.68 80.43 323.22 28.39 8860.44 3592,37 3040.48 -2331.64 3831.59 322.52 20.98 SP 10 9987.57 84.53 327.22 65.89 8869.07 3654,59 3094.11 -2368,89 3896.81 322.56 8.66 SP 11 10041.73 86.58 339.14 54.16 8873.28 3707.71 3142.21 -2393,20 3949.80 322.71 22.28 SP 12 10091.50 82.80 346.20 49.77 8877.90 3757.23 3189.47 -2407.96 3996.38 322.95 16.03 MWD 13 10146.61 79.20 353.94 55.11 8886.53 3811.18 3243.04 -2417.35 4044.86 323.30 15.33 SP 14 10191.75 73.28 351.77 45.14 8897.27 3854.34 3286.52 -2422.80 4083.03 323.60 13.93 SP 15 10242.38 75.10 346.29 50.63 8911.07 3902.75 3334.32 -2432.08 4127.07 323.89 11.00 SP 16 10294.00 76.95 338.94 51.62 8923.55 3952.80 3382.08 -2447.05 4174.50 324.11 14.27 SP 17 10342.03 77.95 332.47 48.03 8934.00 3999.29 3424.78 -2466.33 4220.42 324.24 13.33 SP 18 10391.65 80.10 326.49 49.62 8943.45 4046.65 3466.71 -2491.07 4268.90 324.30 12.58 SP 19 10421.45 82.20 322.64 29.80 8948.04 4074.60 3490.70 -2508.14 4298.34 324.30 14.58 SP 20 10443.85 85.10 321.62 22.40 8950.51 4095.41 3508.27 -2521.80 4320.58 324.29 13.73 SP 21 10454.81 87.08 322.09 10.96 8951.26 4105.62 3516.87 -2528.56 4331.51 324.28 18.50 SP - "-' ", 22 10477.51 90.50 323.49 22.70 8951.74 4126.93 3534.94 -2542.28 4354.19 324,28 16.32 SP 23 10493.76 92.65 325.54 16.25 8951.30 4142.35 3548.16 -2551.71 4370.43 324.28 18.28 SP 24 10541.76 96.03 325.04 48.00 8947.67 4187.97 3587.50 -2578.96 4418.28 324.29 7.12 SP 25 10592.56 95.68 327.67 50.80 8942.48 4236.41 3629.57 -2606.96 4468.78 324.31 5.18 SP 26 10646.79 88.88 330.92 54.23 8940.33 4289.04 3676.12 -2634.61 4522.72 324.37 13.89 SP 27 10686.61 86,33 333.82 39.82 8941.99 4328.16 3711.36 -2653.07 4562.12 324.44 9.71 SP 28 10742.11 87,25 343.34 55.50 8945.11 4383.35 3762.88 -2673.28 4615.81 324.61 17.23 SP 29 10788.68 88.47 349.94 46.57 8946.86 4429.76 3808.13 -2684.03 4658.96 324.82 14,40 MWD 30 10830.71 91.70 353.54 42.03 8946.79 4471.27 3849.71 -2690.06 4696.46 325.06 11.51 SP ANADRILL SCHLUMBERGER Survey Report 10-0ct-200113:36:26 Page 3 of 3 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 31 10868.75 93.58 357.27 38.04 8945.04 4508.36 3887.58 -2693.11 4729.29 325,29 10.94 SP 32 10917.25 94.58 3.51 48.50 8941.60 4554.47 3935.94 -2692,79 4768.93 325.62 13.02 SP 33 10963.32 96.20 9.86 46.07 8937.27 4596.41 3981.47 -2687.46 4803.59 325.98 14,17 SP 34 11023,22 94.30 15.94 59.90 8931.79 4648.02 4039.58 -2674.14 4844.50 326.50 10.59 SP 35 11073,17 90.98 20.41 49.95 8929.49 4688.73 4086.97 -2658.58 4875.59 326.96 11.15 SP 36 11113.36 91.65 24.34 40.19 8928.57 4719.72 4124.11 -2643.29 4898.50 327,34 9.92 SP - -", 37 11169.76 96.20 29.59 56.40 8924.71 4760.11 4174.23 -2617.80 4927.18 327,91 12.30 SP - 38 11205.00 99.43 32.34 35.24 8919.92 4783.43 4204.17 -2599.84 4943.10 328.27 11.99 Pro] ected to TD [(c)2001 Anadrill IDEAL ID6_1C_I0J -~, ~- ;2.Q\, \1~ ?-ot,\¡tõ - 12/13/01 le_lIDbll'ßØl' NO. 1696 Alaska Data & Consulting Services 3940 ArcHc Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska 011 & Gas Cons Comm Aftn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date Blueline Color Prints CD Sepia P-15L 1 21514 ARC DATA 09/30/01 1 P-15L1 21514 MD VISION RESISTIVITY 09/30/01 1 1 P-15L1 21514 TVD VISION RESISTIVITY 09/30/01 1 1 P-25L 1 21497 ARC DATA 10/10/01 1 P-25L1 21497 MD VISION RESISTIVITY 10/10/01 1 1 P-25L 1 21497 TVD VISION RESISTIVITY 10/10/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnlcal Data Center ~Î- 900 E. Benson Blvd. I'"'{I:: Anchorage. Alaska 99508 . eEl VE 0 Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage. AK 99503-5711 ATTN: Sherrie Receive~ ~ Date Delivered: DEe 2 L2I1o1 AlBSftó íJtj & Gas Cons. Commission Anchorage (II' ~. .~ì,D--J 7""'11 '?J:~ . ç:;ð....I'_..:.'!:'\'i,..."..,:¡l.,,'~' ..,-.' ...' \,...." ,,-,'.-.. - ."0- .,\¡:'.;¡.I""II",I\i¡"(¡l""¡"\,I\!!t,,.)I..,,, .!Ù:,,:.:,::i,,::b"" MWD/LWD Log Product Delivery Customer BP Exploraton (Alaska) Inc. Dispatched To: Lisa Weepie Well No P25-L 1 Date Dispatche 27-Nov-O1 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Flo ies Surveys 2 1 ECEIV"O Alaska a ¡ & Gas Cons. Co Anct;orage Received By: Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ( ~1T~1fŒ illJ~ ~~~~~~ ~ ALAS IiA 0 IL AlWD GAS COl\TSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. TH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration, Alaska Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit P-25Ll BP Exploration (Alaska), Inc. Permit No: 201-178 Sur Loc: 2644' NSL, 2529' WEL, Sec. 31, TIIN, RI3E, UM Btmhole Loc.1461' NSL, 15' WEL, Sec. 25, TIIN, RI2E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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 P-25Ll. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607, . BY ORDER OF THE COMMISSION DATED this 13th day of September 2001 jjc/Enc1osures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25,005 ~ d1Lt ,~ ~ q It t"j (Jl ........... ~. £'ì. Iq ......... 1 a. Type of work 0 Drill B Redrill 1 b. Type of well 0 Exploratory ~ratigraPhic Test B Development Oil 0 Re-Entry 0 Deepen 0 Service 0 Development Gas Sin9.'~ Zone 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) fo. Field and Pool BP Exploration (Alaska) Inc. KBE = 88,95' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation ¥ ?1. Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028288 e>zß2 ,!b 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2644' NSL, 2529' WEL, SEC. 31, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 309' NSL, 4801' WEL, SEC. 30, T11 N, R13E, UM P-25L 1 Number 2S 100302630-277 At total depth 9. Approximate spud date 1461' NSL, 15' WEL, SEC, 25, T11N, R12E, UM 10/08/01 Amount $200,000.00 12. Distance to nearest property line 13, Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028264,138' MD No Close Approach 2560 11023' MD / 8944' TVDss 16. To be completed for deviated wells 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9722' M D Maximum Hole Angle 89 Maximum surface 2244 psig, At total depth (TVD) 8800' / 3300 psig 18, Casing Program Specifications Setting Depth OL ...,.... of - t C ize Too 31.. JI LJII2IIL1LV Lci ICI Hole I :~~Inn Weiaht I ;nllnlina Lenath MD TVD .MIl ITVD (include staae data) 3-3/4" 3-1/2" x 2-7/8" 8.81#/6.16# L-80 STL 14981 95251 85701 110231 89441 Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations, Present well condition summary Total depth: measured 10135 feet Plugs (measured) true vertical 9224 feet Effective depth: measured 10035 feet Junk (measured) true vertical 9129 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 260 sx Arcticset (Approx,) 110' 110' Surface 3268' 9-5/8" 906 sx PF 'E', 293 sx Class 'G' 3303' 3175' Intermediate Production 1 0089' 7" 162 sx Class 'G' 10121' 9211' Liner RECEIVED SEP 07 2001 Perforation depth: measured 9844' - 9870' true vertical 8947' - 8972' Alaska Oil & Gas Cons, Commission Anchorage 20, Attachments B Filing Fee 0 Property Plat B BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requi rements Contact Engineer Name/Number: Thomas McCarty, 564-5697 Prepared By Name/Number: Terrie Hubb/e, 564-4628 21, I hereby certify that the foregoing is true and correct to the best of my knowledge :1/5- /C I Signed Thomas Mcë~;';/c:::..4~ ß~~:?~. -'-.~-..::" Title CT Drilling Engineer Date ,'.:. ¡: ,::;::': !".:. :.i.,,:.. ,; ::: ::',':::y: :'. ::.. .i:::r::,:;.:' :: .'.' ::,::..:.::;::,::-,:-::.::.::;,;.".'::::. 'i:: .'::.:'<';},:¡':;::..';!::¡ÞQ,".rni~i~:ij:jJ:$Ö:¡ØiriI1 I.:/::',:;:;.::':>;:',:!;::,:,;: ...,.,.::¡.::::.:::,',,' ...:.,:..-¡:,;:¡..',:::\¡;:.... .,. ';..'" ,;, . ¡::"L'i,;':::X,i:':::: .'..,. :,.",:::., ,..',:". '.";,'. .,' :...',,:"". :'.. ,:','. .'-..." Permit Number API Number APPGf~ilg;~t~ \ See cover letter 2C.) /--- /'78 50- 029-22742-60 for other reQuirements Conditions of Approval: Samples Required DYes .&tNo Mud Log Required DYes mNo Hydrogen Sulfide Measures g[Yes DNo Directional Survey Required.Erf'es D No Required Working Pressure for BOPE D2K D3K D 4K D 5K D 10K D 15K ~,5K psi for CTU (ê)fRIiGlNAl SIGNED BY by order of q . )?) . 0 J 0 Taylor Seamount Approved By '" ,.....,.., ! ,'~.". " '~ C ;>mmissioner the commission Date Form 10-401 Rev, 12-01-85 UKll".' . I'l~ Suomit In Triplicate : ,j J . I,. , '. '" ""'. ( ( BPX P-25 Sidetrack Summary of Operations: A CTD through tubing sidetrack is planned for well P-25. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Isolate & integrity test inner annulus (IA). Set whipstock. Mill Window Completed on Sept 12, 2001 . Drift well with dummy whipstock. . Integrity test IA after displacing to seawater & installing dummy gas lift valves. . Set IBP with check valve above perforations at approx. 9810' (-8827'tvdss) . Set whipstock using e-line at approximately 9722' (-8744'tvdss) . 3.8" window will be milled off the whipstock with service coil time permitting. Phase 2: Drill and complete sidetrack. Planned to begin Oct 8, 200t. 2-%" coil will be used to drill approx. 1300 feet of 3-%" OH sidetrack, (as per attached plan) and run a slotted, uncemented 2-'1'8" x 3-112" liner completion. A memory CNL will be run and the liner will be perforated. Mud Program: . Phase 1: Seawater . Phase 2: SeawaterlBiozan and Flo-Pro (8.6 - 8.7ppg) Disposal: . No annular injection on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 27/8",6.16#, L-80, X-over to 3112,8.81#, L-80 slotted liner be run from approx. 9525' (TOL, -8570'TVDss) to TD. Liner to be left un-cemented. The 3112 liner will be placed from the TOL down to approx. two joints outside the window. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray log with resistivity will be run over the open hole section. Hazards H2S was measured at 15 ppm on July 10,2001. H2S was measured as high as 20ppm on this well recently. Two prognosed faults will be crossed along the planned hoizontal well path. Reservoir Pressure Res. press. is estimated to be 3300 psi at 8800ss. Max. surface pressure with gas (0.12 psi/it) to surface is 2244 psi. (' \ TREE = 4" CrN Wa.U-EAD= FMC A CfUA TOR= BAKER KB. ELEV = 88.95' BF. ELEV = 53.9' KOP= 1700' Max Anale = 31 @ 4412' Datum MD = 9781' Datum TVDss= 8800' 9-518" CSG, 47#, L-80, 10 = 8.681" 3303' Minimum ID = 3.725" @ 9539' 4-1/2" HES 'XN' NIPPLE 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 =3.958" 10036' P-25 9551' (8 7-5/8" CSG, 29.7#, L-80, 10 = 6.875" 10121' f I SA FRY NOTES ST MD 6 3081 5 5600 4 7325 3 8465 2 9188 1 9338 1VD ŒV 2888 28 5101 27 6629 29 7637 28 8273 28 8405 28 DATE REV BY COMtvENTS 03/28/97 CH-I ORIGINAL OOfvPLErION 03/04/01 SIS-SL T OONVERrEÐ TO CANVAS 03/05/01 SIS-MD FINAL 05/14/01 RN'tlh OORRECfIONS 1944' 9485' 9495' 9519' 9539' 9551' 9555' 4-1/2" HES BVN SSSV NIP, 10 = 3.813" GAS LFT MA.f\DRELS TYPE VLV LATa; SIZE DA.TE CA-KBG2LS DOME OK-1 BTM 1 10/11/97 CA-KBG2LS DOME OK-1 BTM 1 10/11/97 CA-KBG2LS DOME OK-1 BTM 1 10/11/97 CA-KBG2LS DOME OK-1 BTM 1 10/11/97 CA-KBG2LS DGLV OK-1 BTM 1 03/28/97 CA-KBG2LS SlO OK-1BTM 1 10/11/97 -14-1/2" HES 'X' NP, 10 = 3.813" I -17" x 4-1/2" BKR S-3 PKR, 10 = 3.875" 1 -14-1/2" HES 'X' NP, 10= 3.813" I -14-1/2" HES 'XN' NIP, 10 = 3.725" 1 -14-1/2" WLEG, 10 = 3.958" 1 1-1 ELMO- TT 04/30/971 PRLDI-DE BA Y LNIT WELL: Ft25 PffiMIf No: 97-0260 AA No: 50-029-22742-00 Sec. 31, T11 N. R13E BP Exploration (Alas ka) TREE = WELLHEAD= ACTUATOR= KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = ..... .. ...... ". Datum 1VDss= ,r ( ~ P-25L 1 ~ETY NOTES PROPOSED CTD COMPLETION 4" CM/ FMC BAKER 88.95' 53.9' 1700' 31 @ 4412' .. ......... ...... 9781' 8800' 1944' 8) 19-5/8" CSG, 47#, L-80, ID = 8.681" I 3303' ST MD 1VD DEV 6 3081 2888 28 5 5600 5101 27 4 7325 6629 29 3 8465 7637 28 2 9188 8273 28 1 9338 8405 28 Minimum ID = 3.725" @ 9539' 4-1/2" HES 'XN' NIPPLE 9485' 9495' 9519' 9525' 9539' 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9551' 9551' 9555' ÆRFORA TION SUMMA RY REF LOG: SWS BHCS, 3/25/97 ANGLEATTOPPERF: 119 @ 9844 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz I DATE 3-318" 6 9844-9870 0 I 04/30/97 1 Mill Window off Flow -by Whipstock -I II ~ 0.0 0 0 -14-1/2" HES BVN SSSV NIP, ID = 3.813" I GAS LIFT MANDRB..S TYPE VLV LATCH CA-KBG2LS DOME OK-1BTM CA-KBG2LS DOME OK-1 BTM CA-KBG2LS DOME OK-1 BTM CA-KBG2LS DOME OK-1 BTM CA-KBG2LS DGLV OK-1BTM CA-KBG2LS SIC OK-1BTM SIZE DATE 1 10/11/97 1 10/11/97 1 10/11/97 1 10/11/97 1 03/28/97 1 10/11/97 ~4-1/2" HES 'X' NIP, ID = 3.813" 1 -l7" x 4-1/2" BKR S-3 PKR, ID = 3.875" 1 -l4-1/2" HES 'X' NIP, ID = 3.813" I -lTOP of Proposed 3-1/2" Liner I -14-1/2" HES 'XN' NIP, ID = 3.725" 1 -l4-1/2" WLEG, ID = 3.958" I l-l ELMO- TT 04/30/971 3-1/2" X 2-7/8" XO I 13-3/4" Open Hole I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 12- 7/8" L-80 Pre-drilled Liner 1 11022' I PBTD 1 ~o ::0*;;0 ~u: o~~œ ~u,~u Q U 0U"G'iJ'J(J~'O'Ufìl'-' ~~~.~OoGu~~OUOU 10036' 17-5/8" CSG, 29.7#, L-80, ID = 6.875" I 10121' DATE REV BY COMMENTS 03/28/97 CHH ORIGINAL COMPLETION 03/04/01 SIS-SL T CONVERTED TO CANVAS 03/05/01 SIS-MD FINAL 05/14/01 RN/tlh CORRECTIONS 07/18/01 pcr P-25L 1 Proposed CTD Completion PRUDHOE BA Y UNIT WELL: P-25L 1 Proposal ÆRMfT No: 197-026 APt No: 50-029-22742-00 Sec.31,T11N,R13E BP Exploration (Alaska) BP Amoco WELL PATH OETAI.... PIa- P-:>5L1 500212274210 Pa...t Wallpatlo: TIe 00 MD: RlI: Ref. Dota.... P-25 1722.00 31 : 25121121111112:00 88.2Oft V.soctioa 0';"10 0"'" Startla. ¡ Aoo", +NI-S +/!J.W "...m TVD I " 350.00' 0.00 0.00 ..00 i ! REFERENCE INFORMATION I : Co-ordinale (NÆ) Reference: Well Centre: P-2S, True North I' i Vertical (TVD) Reference: System: Mean Sea Level I Section (VS) Reference: Slot - 25 (O.OON.O.OOE) I i Measured Depth Reference: 36: 25 12/12/1996 12:00 89.20 ; I Calculation Method: Minimum CUivature i , I I SECT1ON DETA"'" ¡ IS.. NO ... "" 1VD ........ +.,.W DLeI TFa.. Vie. T...... I . 1 1717.51 23.55 325.44 a740.:Ie ZOO.... .2257.07 0.00 0.00 3256.40 I I ~ :~~ ~~~::o. :~:1: :m~ :~1~ 2~~ 1a::~ ~~~:¡; I I . 1021.12 0..00 330.03 ".'.05 303.... -2337.0' 30.00 5.00 33100.11 , : . 1OZ..... S3.:Ie u. .003... 3347.37 -2411..' 10.00 10.00 3715.21 . ""'..7 ............ ..a... 3547.51 -2431.00 10.00 :le7.00 311..17 7 10550..7 ..... 334.42 ....... .-.05 -247"'. 10.00 300.00 401...0 . 11022... .0.31 ....3 ....... ....... ........ 10.00 10.00 ""..72 ANNOTATIONS TVD MD ""aotalloa p."U T5' """00 306195 .23<6.09 PcflI P.25U T82 ""'"00 335'U8 .241351 Pori P.25LIT83 '""00 "18"87 .2510" PcflI TARGET DET AA S TVD -.s <£I.W Shope 1740.21 1717.51 TIP 17....31 1722.00 KOP '153M 1732.00 1 11...05 112M2 2 '103"1 '."'.'2 3 8821.27 ,"'..17 . 8831.51 '."..17 5 IN4.01 ".22.17 TO 8300 8350 8400 8450 ë8500 ~ = 8550 0 II) -8600 .c .. a.8650 GJ ~ 8700 c; .!:! 8750 't ~ 8800 ~ 8850 .. ... 8900 8950 9000 9050 - + ;E'3500 i 3400 Z ::;-'3300 - .c 'S 3200 0 en 3100 bp LEGEND P-2S (P-25) Plan#6 P-25L 1 Plan #6 T 4( Azimuths to True North Magnetic North: 26.42. Magnetic Field Strength: 57476nT Dip Angle: 80.74. Date: 8/6/2001 Model: BGGM2001 Plan: Plan #6 (P.2S/Plan#6 P-2SL 1) Crealed By: Brij Polnis Dale: 8/6/2001 Cùr:lar;¡i"!'.1Ifn<lli(",. n"';(.l. 1:107) bì7.(,(,13 E ."",ii lJflj¡;OH1i,'¡;:ir,tcq ,em B~Kf;r H¡,,)!1\'\ !NTEG" ('Jon 2f;ì.t:CI)i) /-~'> 2600' -3600 -3500 -3400 -3300 -3200 -3100-3000 -2900 -2800 -2700 -2600 -2500 -2400 -2300 -2200 -2100-2000 -1900 -1800 -1700 -1600 -1500 -1400 -1300 -1200 -1100 -1 000 West(-)/East(+) [100ft/in] ~. -~ ~"".,,~---:., 4300 ----- ,\-,~ \-'...!.; , \ \. --c ;' 5! "'-'_"h"'_m..m__-_m ._.~~~i- ~ ;~'!fP~5~1j ; P-25L1 T6.1; 3900 .U!f'J /> KOP i ',\1l \\, \'" \. """ \ ",., W \ """"'-L.l"___,--- \\ '. ,."" '~~~---'--~'-"-"'::"-_..",_..."--_.,..__.- \. \ I P-2S(P-2S):,\ \, \ ,,\ .:>-. 4200, ; P-25L 1 T6.3 ~!êan#6 P-25L 1 i ! JQj ¿-25Ln6.3j 295030003050310031503200325033003350340034503500 355036003650370037503800 3850 3900 3950 4000 405041004150420042504300435044004450450045504600 4650 4700 4750 4800 4850 4900 Vertical Section at 3500000 [50ft/in] 3:42 PM 4100 4000 . ¡ i - .5 3800 - = 0 3700 0 ~3600 , , \ 3000 2900 2800 2700. 8/6/2001 (' , ,( '- ObP BP Amoco Baker Hughes INTEQ Planning Report Ríi8 BAJŒa IIUGHIS --------------.------- INTEQ ______00_____'----- .--- ------ ------.-----.------ ------ -------- ----. ----.---------------.---.--.--------------------.-------------------- .----- -- -----_____00- ---. -- - --------------. ~--------------'.- -----.-------- Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB P Pad P-25 Plan#6 P-25L 1 Date: 8/6/2001 Time: 15:41 :05 Co-ordinate(NE) Reference: Well: P-25, True North Vertical (fVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,350.00Azi) Survey Calculation Method: Minimum Curvature Db: Page: 1 Oracle '_nn -'-'--------...-.---- _____n__n_______n____- -- --- ----.--.----- - -n______n___- .-- --_.o__n- ---- -- ----- --- --- -.- ---.--- ------_.------ _.___h_m__--_- ---_'____m --- _00______---- -.---- ----- _n___.__-.--.. -- -- -- --- -- -.. --- 00___00 -- - -- --.- -. ----.--.--.. --._-- __n_- --- ___.00__- - - ---- ---.- ---- .n______- --- - -- -- ---- - _00--_- - --- ._----.,---. _m___- ------.._-- -------.-----..-.----------- ------- - _n- _nn______-------------- ____nn-____.__n -_u_-----------_u_-'.'--------------------------------- ------- - Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) I Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 ---------.n.-._---------""'-----'--'----------~---'-' ------'-.-""'-----.-' --...- --'----'.-----.-----------_-'_m______-- ._--- '--------n-------'--" -.- -.-'---------.-- --- - - ----..-- --'-'--' --- ------.---- .------ n- .--- --. .n___..-_n . -- - --------'---'------'-----------' Site: PB P Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5949377 .17 ft 623154.06 ft Latitude: 70 16 Longitude: 149 0 North Reference: Grid Convergence: 12.612 N 14.402 W True 0.94 deg l I I I __n_J ... -_.---..--_._---- ----..-.-----.---.___-_nn._n. --------___.._n__.___---.--. -----.---- -----'--_____'00----__-------.------'------'- .-.---. _.____n___._._--_.._-_._----.--_._---_...__m___~--__n-n__.. .- ----..-----'-'_-____n _n_.. .--.-.____..n._.__. '--'---.u-'----------"-----.-----------'-.-'-----'---_n__-'-"'-___"_n_'__._---'- .'-- ----.--.--.....-----------.-.-_____.n____._---- Well: P-25 P-25 Well Position: +N/-S -2138.46 ft Northing: +E/-W 8569.84 ft Easting: Position Uncertainty: 0.00 ft Slot Name: 25 5947379.39 ft 631757.03 ft Latitude: Longitude: 70 15 51.533 N 148 56 4.999 W -.-_____.n.- -.-------.- ._00 ----... ------.---_u_.....--.--.-.-------.--.----- __.--m.._n --- -- "-..____n... - _n.._...-.---.-. -..-.-- .-.--..-----.---.-.-.--------.----.--------_.____n___-n__'___---__----n_'---------'--',- __00 ---'---n"- _____'00______---.-.---.--------..-.--------.----.-- - ..--' n____.. - -..' ------ -. ._- --. -- . _._n_._._. - - --___.._n_- ---- .--.- -.-. ."-'-_'____n__'_"-"-'_____n_.____------'-'-'--"-'---__m.n-______._- -- .-- ~------._. Wellpath: Plan#6 P-25L 1 500292274260 Current Datum: 36: 2512/12/199612:00 Magnetic Data: 8/6/2001 Field Strength: 57476 nT Vertical Section: Depth From (TVD) +N/-S ft ft --------...-..------.---..-----------...---.------. --------...-. --.-.-- .--_.. ----------. -- - .....- --. .-..- -..- -- 0.00 0.00 Height 89.20 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft --'-.'--'-'-'..---"". ----'u_.----. .-------... 0.00 P-25 9722.00 ft Mean Sea Level 26.42 deg 80.74 deg Direction deg ._n,_""___-___---__m___.__----.-.-- '---"-"'-.-------"---- 350.00 -.. .-------. - . ---. -- -. ---.---""...--.- -.--- ...-- --- -------.-----.- -..--.--.---------. ----.- -------...--.- ..-.-. ..- ._--, ._- ..- ---___._.n_.___.-.--.- ----.---.--- .------.---.-- _____m_____._-----_._-----~._---------.,._.'-'-------'---.-..----.-- . __'___n.__n_._.__.--.-.-'--"-'-'--_n_-__'_"---.-------------'----u.---'---"--'-- ------------..--.-----.-.--___._.m --- ----.- -.-...-.--.----._._'.m.__._..-...---.--..___._m._._..--.----.-- .-.._..,-. -'--'-'..----.----....----m--.-. ---- .-........--.,-.-.-------.-------- .-.- ..-------.-.- --...----.--.-.-.---.-.-.- Principal: Plan #6 Identical to Lamar's Plan #6 Yes Date Composed: Version: Tied-to: 8/6/2001 1 From: Definitive Path Plan: ----'-'----...._._.n_._'----- . .'_._n__._...-------.--.--..---.--.-------.------' .-.-----------------..---.----.---.-.---.....---....._._n..----"-'-- ----"----'--,,'.-..--_u_..-------"'--.,.. - -..- __n-_'-"'---,---..-,.'-' .- - --- --.-..--.-..----.--...-..---...-.----..-.--- --. -.-.-..--.--------.. Targets . ..-....-------... -- ....-.... .m_'-""-."." - """'.00'_"_. .m.... - .....- -... --. ..-- _.... --. '..m -.. .-. _m..m -. -. - .. - -." ...-..-... ._m_.... _m_----_. .-.... -m... m. m.n. _'00.____.--' -.... --..---.. - .....m...n.... - m. .__.m_m ----- -.--. --.. _. -. ...mm_.m__"-"-- ..n_.... -.-.. -.-.----.." '.._.m __.....m...._... ..- ..-...-........_n _m..- _"".00 _m_.__.. .-..--. --- --..---.-,- - -... ...-..-..- m_- _..m_... Map Map <--- Latitude ---> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min See . ----. -.-...- -., --.----. .._. -.. -.- .--- --.,-.-- - ____un' _un. - ---- ~--- --- -- - ft ------ ----- _!L. -- ---.- -~- -.-. -.- ---'._._~ -. -. --"-- ----...-..-- - .-'-'-'---'-'--' ..- -. -_.- ...- .--.--.- .n. ,----'-..-- -- --. ¡ P-25L1 T6.1 8864.00 3061.95 -2346.89 5950399.56 629357.11 70 1621.643 N 148 57 13.327 W -Plan out by 5.13 at 8864.00 3056.83 -2347.19 5950394.43 629356.90 70 16 21.593 N 148 57 13.336 W P-25L1 T6.2 8903.00 3350.18 -2423.51 5950686.38 629275.46 70 16 24.478 N 148 57 15.561 W -Plan out by 15.52 at 8903.00 3339.88 -2411.91 5950676.28 629287.24 70 16 24.377 N 148 57 15.223 W P-25L1 T6.3 8945.00 4118.67 -2510.84 5951453.16 629174.71 70 1632.036 N 148 57 18.111 W - .--.--..... --.-.-.----.--.--.-----..--.-.. ._n__._'-,------."---,-------------,.----------".-, .-- ---.--.----.-"'...--------'------'-----.'-'- ----.----.- ----------.-.....--.-----.----. ..-_... -- -.-.__.n..__- -._n --'-'-----' --'-'..---..__..m_.__._'."-"-'---.-.-'--'--- ....-.-.--.- -..----... Annotation .'..-.'.m_._._..._..m'..__"-..--...-....--...._.m..___.,---..----.-..---....--.-.--..-..-..-.,--..,-n._...m_mn__---_'_'_'00'_"_"-""'.-"-..-.'.""""'-"-"--'-"--'-.n___m..,.._.-...,..--m--------'-"'---"----------"-'...-n.._.m. .. . .-"-_"m"_'_".'.._._mm_m__..'--'--"'---'--.---""---....-----.-.---.-.,..----..- MD TVD ft ft '-"'."--'..-'.'----.---.--"-.'..-'---."--'..-."".'...-.-----......-.--..--...- -.---.--.----.-....'--.__._.m- 9717.51 8740.26 TIP 9722.00 8744.38 KOP 9732.00 8753.49 1 9921.12 8861.05 2 10246.12 8903.89 3 10450.67 8929.27 4 10550.67 8936.58 5 11022.67 8944.07 TD .---...---.---------..........__M______---'-'---.---.-----------'----------.---.--..-...___n ----.---_____.n -.----'.-------"'..-.--.'-'-- .--...---.-.--__.__.n..._._-------.---..-...-...... .--.-.-.-..---.--.--.-.-...- .--_.-..__. -..- -. --.--...-.-..u_-------.-.-...-.-.--. ..---...-.- Plan Section Information r-------- - - - -'--'-------'------'------'----------"--------- .....,.. ...'.1\11)"'..-111(:1 Aibn ft deg deg 9717.51 23.55 325.44 9722.00 23.35 325.40 9732.00 25.34 325.81 9921.12 82.00 330.03 TVD +N/-S +E/..W DLS BUild Turn TFO Target ft ft ft deg/100ft deg/100ft deg/10OO deg .. ...-. .... ... 8740.26 2908.60 -2257.87 0.00 0.00 0.00 0.00 8744.38 2910.07 -2258.88 4.47 -4.45 -0.89 184.53 8753.49 2913.48 -2261.21 20.00 19.93 4.07 5.00 8861.05 3038.45 -2337.04 30.00 29.96 2.23 5.00 --l -----.-..--. ----.u-.-----.. '--'--- --.-- ...--.-._____m____..--,-.-____._n____..-.--..-.------.--'--'--'.----.-.-.-----.' "-"--'.-----.-------u-.-------"'-'_---_.n_..- ._-----_.-...-------- -'m_- .-------.--.-.-- --.--...-----.-.--.----. n___-'- ---- --...-- -'--"..--'-"--'--.-- _.--.m_'." ObP (' ( BP Amoco Baker Hughes INTEQ Planning Report ~.-.._-....__..- -""'-""""'_.'-""-'-"'--"~-"-'-- '---'--" . ... -"'--...."---""""--'-'--"""""",-,-"", .....-..- --. '--"""""---""-'-------'--'-"-'-"--'-"" Rii8 BAKU HUGHES """""""""""""""""-'-""""-'-- INTEQ '----'----"".. Company: BP Amoco Date: 8/6/2001 Time: 15:41 :05 Page: 2 : Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: P-25, True North I Site: PB P Pad Vertical (fVD) Reference: System: Mean Sea Level Well: P-25 Section (VS) Reference: Well (0.00N.0.00E.350.00Azi) i Well path: Plan#6 P-25L 1 Survey Calculation Method: Minimum Curvature Db: Oracle """'.""""""""."""'...................................-.-......-....................-...........-.. .-.................-.. """"".'..""'-"""'-".-..... """"""""'-""""""""""-""""""""--""-"""-"'---'.""-"""""'-'-"""""""""""""""-"..."""'.'.'............................................ ........-...-.......................................... """"""""""""'.""""""." Plan Section Information --- -----"'-"'-"-"--"'-"--'-' ---.-. .... .---.---------.. ----.....-. ""--- "-'-"-"---- ---'-"--'-'-'--'--'.-"'-_0_-'- Incl Azim TVD +N/-S +EI-W DLS Build Turn TFO Target I deg deg ft ft ft deg/10OO deg/10OO deg/10OO deg I ......................--... -_........ o. -"'.. ........ .....- ...... .......... ........ ..... -..................... m.- ............. ... 0- ..-- -..-........-. -... 0""""""'-""'" - ..... 0... '0"'_"" ........ "--'- .-.....- ..--"-""."_"0.. "-"'-"'-"'-.............. ... ..... 0..0._.._..........-.. ......... ......0 .........-..-..... ......... ... ......0...... ...... --- ... -.. ...'0'."-.._....... ..~.., 83.26 2.78 8903.89 3347.37 -2411.61 10.00 0.39 10.08 90.00 82.64 342.18 8929.27 3547.51 -2438.00 10.00 -0.30 -10.07 267.00 88.98 334.42 8936.59 3640.05 -2474.86 10.00 6.34 -7.76 309.00 89.31 21.63 8944.08 4098.49 -2490.66 10.00 0.07 10.00 90.00 i MD l.....................~_.._...... 10246.12 : 10450.67 10550.67 I 11022.68 1_.- '-"..------....- 'u---'-----..- ...-......---- Survey MD ft 9717.51 9722.00 9725.00 9732.00 9750.00 9775.00 9800.00 9825.00 9850.00 9875.00 9900.00 9921.12 9925.00 9950.00 9975.00 10000.00 10025.00 10050.00 10075.00 10100.00 10125.00 10150.00 10175.00 10200.00 10225.00 10246.12 10250.00 10275.00 10300.00 10325.00 10350.00 10375.00 10400.00 10425.00 10450.00 10450.67 10475.00 10500.00 10525.00 10550.00 10550.67 10575.00 10600.00 10625.00 10650.00 Incl deg 23.55 23.35 23.95 25.34 30.72 38.21 45.69 53.19 60.68 68.17 75.67 82.00 82.00 82.01 82.04 82.08 82.13 82.20 82.29 82.39 82.50 82.63 82.78 82.93 83.11 83.26 83.24 83.12 83.01 82.91 82.83 82.76 82.71 82.67 82.64 82.64 84.17 85.76 87.35 88.94 88.98 88.98 88.98 88.99 89.00 Azim deg 325.44 325.40 325.53 325.81 326.73 327.61 328.24 328.73 329.13 329.47 329.78 330.03 330.42 332.95 335.47 337.99 340.52 343.04 345.56 348.08 350.60 353.12 355.64 358.15 0.66 2.78 2.39 359.88 357.36 354.84 352.32 349.80 347.29 344.77 342.25 342.18 340.28 338.34 336.40 334.47 334.42 336.85 339.35 341.85 344.35 SSTVD ft 8740.26 8744.38 8747.13 8753.49 8769.37 8789.97 8808.55 8824.79 8838.43 8849.21 8856.96 8861.05 8861.59 8865.07 8868.54 8871.99 8875.43 8878.84 8882.21 8885.54 8888.83 8892.06 8895.24 8898.35 8901.39 8903.89 8904.35 8907.32 8910.34 8913.40 8916.50 8919.64 8922.80 8925.98 8929.18 8929.27 8932.06 8934.26 8935.76 8936.57 8936.58 8937.02 8937.47 8937.91 8938.35 .----.. ....-- "'--"-"U_-'-----"-----...-u_. .u.....--.------..-...--...-.-.... N/S ft 2908.60 2910.07 2911.06 2913.48 2920.52 2932.40 2946.56 2962.74 2980.67 3000.05 3020.54 3038.45 3041.79 3063.58 3085.87 3108.61 3131.77 3155.29 3179.14 3203.26 3227.61 3252.15 3276.83 3301.59 3326.41 3347.37 3351.22 3376.04 3400.84 3425.60 3450.24 3474.74 3499.05 3523.11 3546.88 3547.51 3570.39 3593.69 3616.72 3639.44 3640.05 3662.21 3685.40 3708.97 3732.89 E/W ft -2257.87 -2258.88 -2259.56 -2261.21 -2265.90 -2273.56 -2282.42 -2292.33 -2303.14 -2314.64 -2326.64 -2337.04 -2338.95 -2350.69 -2361.46 -2371.24 -2380.01 -2387.75 -2394.46 -2400.10 -2404.69 -2408.20 -2410.63 -2411.97 -2412.23 -2411.61 -2411.44 -2410.95 -2411.54 -2413.23 -2416.00 -2419.86 -2424.78 -2430.77 -2437.81 -2438.01 -2445.78 -2454.58 -2464.18 -2474.56 -2474.85 -2484.89 -2494.22 -2502.52 -2509.78 MapN ft 5950247.80 5950249.25 5950250.23 5950252.62 5950259.57 5950271.32 5950285.32 5950301.32 5950319.06 5950338.23 5950358.51 5950376.23 5950379.53 5950401.12 5950423.21 5950445.78 5950468.78 5950492.16 5950515.88 5950539.90 5950564.17 5950588.64 5950613.27 5950638.00 5950662.81 5950683.78 5950687.63 5950712.45 5950737.24 5950761.95 5950786.55 5950810.98 5950835.19 5950859.14 5950882.78 5950883.41 5950906.15 5950929.28 5950952.14 5950974.68 5950975.28 5950997.26 5951020.28 5951043.71 5951067.49 MapE ft 629448.79 629447.76 629447.06 629445.37 629440.56 629432.69 629423.59 629413.39 629402.28 629390.44 629378.08 629367.37 629365.40 629353.28 629342.12 629331.95 629322.77 629314.62 629307.50 629301.43 629296.43 629292.49 629289.63 629287.85 629287.16 629287.41 629287.52 629287.57 629286.54 629284.42 629281.22 629276.94 629271.59 629265.18 629257.73 629257.51 629249.35 629240.14 629230.14 629219.36 629219.06 629208.63 629198.91 629190.20 629182.52 DLS deg/100ft 0.00 4.47 20.00 19.96 30.00 30.00 30.00 30.00 30.00 30.00 30.00 30.01 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 9.99 9.99 10.00 10.00 10.00 10.00 10.00 10.00 10.00 9.99 9.99 9.99 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 10.00 VS ft 3256.49 3258.11 3259.20 3261.87 3269.62 3282.65 3298.13 3315.79 3335.32 3356.41 3378.67 3398.11 3401.73 3425.23 3449.05 3473.15 3497.47 3521.98 3546.63 3571.37 3596.15 3620.92 3645.65 3670.27 3694.75 3715.29 3719.05 3743.40 3767.94 3792.61 3817.36 3842.16 3866.95 3891.68 3916.32 3916.97 3940.85 3965.32 3989.67 4013.85 4014.50 4038.07 4062.53 4087.18 4112.00 ---.--- .......-.----__._-.1 TFO deg 0.00 TIP 184.53 KOP 5.00 MWD 4.94 1 5.00 MWD Tool 4.19 MWD 3.46 MWD 2.99 MWD 2.67 MWD 2.45 MWD 2.30 MWD 2.20 2 90.00 MWD 89.95 MWD 89.59 MWD 89.24 MWD 88.90 MWD 88.55 MWD 88.20 MWD 87.86 MWD 87.53 MWD 87.20 MWD 86.87 MWD 86.55 MWD 86.23 MWD 85.92 3 267.00 MWD 267.05 MWD 267.34 MWD 267.65 MWD 267.96 MWD 268.27 MWD 268.59 MWD 268.92 MWD 269.24 MWD 269.56 4 309.00 MWD 309.22 MWD 309.35 MWD 309.47 MWD 309.53 5 90.00 MWD 89.96 MWD 89.91 MWD 89.87 MWD .. .......-..-..-- ._0.._......-..-....-.....,......... ...--... ..... ...-.. .-----..--..- --'-"-""-"--""""'_0"0.---.'.".--.....--.....-----.....-..""-""""""'--""---'-'--'-"'-"""----'--.-.---....--------_'0_"--"-""""'0""'__"0"""___-""---'--.'-'-'-- ( ({ ObP BP Amoco Baker Hughes INTEQ Planning Report R¡¡8 BA.KaIt HUGIll S -..............................-......-....,...-- lNTEQ . -....... ""...-............... -,-,,""-~.--. ..... m" - -oo.... ......--... .-..._... ."".- --... ......- ......... --...'-'" . _.. -_.... -..-" .. '-""'-'" '-... .-"'-"-""""""""'------'-'- --_..._..~._. ..-..--.----....."'" "---"'-'--""""'-", Company: BP Amoco Date: 8/6/2001 Time: 15:41 :05 Page: 3 I ! Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: P-2S, True North j Site: PB P Pad Vertical (TVD) Reference: System: Mean Sea Level Well: P-25 Section (VS) Reference: Well (0.00N,0.00E,350.00Azi) Wellpath: Plan#6 P-25L 1 Survey Calculation Method: Minimum Curvature Db: Oracle Survey ---......-------...--..- '--' ...--..--.. "...----'-'. -.......-.----.---.... ----.. -.-_..."- .-..---..- _.__....._._~ ...----..-.-.---- ..... .....-----...-..---..---------. MD Incl Azim SSTVD N/S EfW MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/10OO ft deg ~-_..........._............. ..... ...... ............ -.- ....... ....... . .-.... ....... ....... "_"m-- -.. ..... .......- -_.' -...-......... ....-... ......- _........ .........-.......""" .-..... ...........-. .......... _..-.................. -' -_.- -...... ...-........ ...._-..._........... -...'-"-"" ."m-." ,.... . .....""""""" """"""""'-"""""""...." ........ ..." ........ '--'........... ...... '-"""-'-"-.--'" 10675.00 89.00 346.85 8938.79 3757.10 -2515.99 5951091.58 629175.88 10.00 4136.92 89.82 MWD 10700.00 89.01 349.36 8939.22 3781.56 -2521.15 5951115.95 629170.30 10.00 4161.90 89.78 MWD 10725.00 89.03 351.86 8939.65 3806.22 -2525.23 5951140.53 629165.79 10.00 4186.89 89.74 MWD 10750.00 89.04 354.36 8940.07 3831.03 -2528.23 5951165.28 629162.36 10.00 4211.85 89.69 MWD 10775.00 89.06 356.86 8940.48 3855.95 -2530.14 5951190.16 629160.01 10.00 4236.72 89.65 MWD 10800.00 89.08 359.36 8940.89 3880.93 -2530.97 5951215.13 629158.75 10.00 4261.47 89.61 MWD 10825.00 89.09 1.86 8941.29 3905.93 -2530.70 5951240.12 629158.57 10.00 4286.04 89.57 MWD 10850.00 89.12 4.36 8941.68 3930.88 -2529.35 5951265.09 629159.49 10.00 4310.38 89.53 MWD 10875.00 89.14 6.86 8942.06 3955.76 -2526.90 5951290.01 629161.50 10.00 4334.46 89.49 MWD 10900.00 89.16 9.36 8942.43 3980.50 -2523.38 5951314.81 629164.59 10.00 4358.21 89.45 MWD 10925.00 89.19 11.86 8942.79 4005.07 -2518.78 5951339.45 629168.76 10.00 4381.61 89.42 MWD 10950.00 89.22 14.36 8943.14 4029.42 -2513.11 5951363.89 629174.00 10.00 4404.60 89.38 MWD 10975.00 89.25 16.86 8943.47 4053.49 -2506.39 5951388.07 629180.30 10.00 4427.14 89.35 MWD 11000.00 89.28 19.36 8943.79 4077 .25 -2498.62 5951411.96 629187.65 10.00 4449.19 89.31 MWD 11022.68 89.31 21.63 8944.08 4098.49 -2490.66 5951433.34 629195.24 10.02 4468.72 89.21 TD ..-n.... -- .-...-. ..-.---.....""'--""...--..-.."'-""--- -----..----.......-...-. -...'.'..""- .............-."'-"""'..-........--"""."""""-'--.. -"'-" -..-.. ,--...-.............-....- ....-....-.........-.. ""'-......................."""-'-."'" (' t 38 CTD BOP Detail Methanol Injection Otis 711 WLA Quick Connect - 7-1/1611 10,5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Flanged Fire Resistant Kelly Hose to Dual Choke Manifold EJ 7-1/1611 10, 5000 psi worKing pressure . Ram Type Dual Gate BOP~ ~ Manual over Hydraulic XO Spool as necessary Single Manual Master Valve (optional depending on RU) MOJ 5/21/01 -- CT Injector Head --- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ - 7" Riser Annular BOP (Hydril),7-1/1611 10 5000 psi working pressure Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold I 2 7/811 Combi Pipe/Slip I 2 3/811 Combi Pipe/Slip 2 flanged gate valves 711 Annulus o~ 9 5/8" Annulus I I t' ,. ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BEINCLUDEDINTRANSNUTTALLETTER WELL NAME $!( ¡12~ L I CHECK 1 STANDARD LETTER DEVELOPMENT (If api number last two (2) digits are between 60-69) DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORATION INJECTION WELL ANNULAR DISPOSAL <--> YES INJECTION WELL 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(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). 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 + SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The permit is approved 'subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Comoanv Name) will assume the liability of any protest to the spacing exception that may occur. ~({ì s is a -ó ub ~ () ed ¿:pel ( .£rCt/)~ co ~ ?-ÐMC 2S-:~e-)) ~ ~/oû -{-eL skull Templates are located m drlve\jodyltemplates be... re- -I-u r ~ -1-0 tP. (\Ì\~~0¡~1Ù (\eÞr¿;~ ~\ ~ V ~~ ~ ,(;~iI"(O 0\\1) Ý WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION COMPANY INIT CLASS ~~ ~::~t ~~~~~~~hpep~~Pri~t~~? ~ W I~þ ~~ / >9 ~LJ:c / 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . , . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9, Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force, . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . 12. Permit can be issued without administrative approval.. . . . . 13. Can permit be approved before 15-day wait.. . . . . . . . . . 14, Conductor string provided. . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. . . . . . . . . . . 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. , . . . . . . . . 19. Casing designs adeqúate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . , . . . , . . . . . . , . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . . , . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling fluid program schematic & equip list adequate. . . , . 25. BOPEs, do they meet regulation. , . . . . . . . . . . . , . . 26. BOPE press rating appropriate; test to s.sùCJ psig. 27. Choke manifold complies w/API RP-53 (May 84). , . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . , , . . . . . , . . . Y ""-~\.,) \. Þ 30. Permit can be issued wlo hydrogen sulfide measures. . , . . Y N' .? z..Ç. ~. rt f~ 31. Data presented on potential overpressu. re zones. . . . . . . Y \f~ 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . .. . 11;1 )Y1\J - DATE 33. Seabed condition survey (If off-shore). . . . . . . .";"';"r~~ Nft. Y N Cf, / (). D I 34. Contact name/phone for weekly progress reports [e~",ry 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 of 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 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annuiar COMMISSION: ~ÞB ßz> W~ -.,. APm ~A TE ( -..41l- ,10-0 ENGINEERING APPR DATE APPR DATE PROGRAM: exp - dev - redrll serv wellbore seg _ann, disposal para req - GEOLAREA UNIT# ()11~s:-o ON/OFF SHORE OÞî ~~~~\~ \ 1Iz..~ Y N Y N Com m ents/l nstructions: pt~ c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ~¿-s6.öo /) k ,-e.(~r..dec:l. c 0 Z 0 -f :E :::tI ( - -f m '...".. . - Z -t :I: - CA » :::0 m » .(