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Home My WebLink About200-005Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) [] Two-Sided RESCAN Golor items: rayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA ~"~D;~-kettes, No. j [] Other, No/Type OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES: "¢~ NOTES: ORGANIZED BY: BEVERLY BR~HERYL MARIA LOWELL Other DATE: Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BR SHERYI_ MARIA LOWELL ?--? ,s, DATE: Scanned (done) PAGES: SCANNED BY: (at the time of scanning) BEVERLY BREN VINCEN~ARIA LOWELL RESCANNED BY; BEVERLY BRE~HERYL MARIA LOWELL General Notes or Comments about this file: ~:~,,...~ PAGES: Quality Checked (done) Rev1 NOTScanned.wl~l . • e �\� 1/%.i,%., THE STATE /— a L_ 'i . ,'! ' G K��ry _— — ---- 333 Wesi Seventh Avenue ,e GOVERNOR SEAN [BAR\Ei.[. Anchorooe, A!oska 99501 3572 Mom 907.279 43 Mary Endacott sCANNED MAY 0 9 2014 Engineering Team Leader BP Exploration (Alaska), Inc. ca00 ©°S- P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-19B Sundry Number: 314-077 Dear Ms. Endacott: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, l , P - Cathy P. Foerster Chair o.DATED this / day of February, 2014. Encl. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 10 2014 APPLICATION FOR SUNDRY APPROVAL 0 T s 4J/7/11^ 20 AAC 25.280 AOGCC 1. Type of Request: ❑Abandon ®Plug for Redrill • 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 0 Exploratory 0 Stratigraphic 200-005 3. Address: ®Development 0 Service 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 , 50.029-20735-02-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU C-19B. Will planned perforations require a Spacing Exception? 0 Yes ®No 9. Property Designatior 10.Field/Pool(s): ADL 028305 • Prudhoe Bay Field/Prudhoe Bay Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12986' • 8947' ' 12909' 8944' 9995' None Casing Length Size MD TVD Burst Collapse Structural - Conductor 110' 20"x 30" 35'- 145' 35'- 145' Surface 2650' 13-3/8" 38'-2688' 38'-2687' 4930 2670 Intermediate _ Production 10584' 9-5/8" 34'-10618' 34'-8356' 6870 4760 Liner 580' 7" 10149'- 10729' 8020'-8437' 7240 5410 Liner 2840' 2-7/8" 10146'- 12986' 8018'-8947' - 13450 13890 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11595'- 12892' 8908'-8943' 5-1/2", 17#x 4-1/2", 12.6# 13Cr80/L-80 10217' Packers and SSSV Type: 9-5/8"x 5-1/2"Baker S-3 Packer Packers and SSSV 9909'/7853' 9-5/8"x 5-1/2"Otis Packer MQ(ft)and ND(ft): 10050'/7951' 12. Attachments: 13.Well Class after proposed work: IS Description Summary of Proposal ®BOP Sketch - 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic ®Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation. March 1,2014 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG IS Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Takahiro Kosaka,564-5994 Printed Name: Mary Endacott Title: Engineering Team Leader Email: Takahiro.Kosaka@bp.com Signature: /-1/1q‘,/I42, Phone: 564-4388 Date:�Ci Comission Use Only Conditions of approval: Notify Commission so that a representative may witness `� 0-1-1 Sundry Number: ❑Plug Integrity u BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: 30 p fi c. s f fa 3500 p 5, RBDMS-. MAY 0 9 2014 Spacing Exception Required? 0 Yes ("J No Subsequent Form Required: /d — 4 6 7- / APPROVED BY /' / Approved By: ' P ^ C�O�MISSIONER THE COMMISSION Date: 2 —/ ' — `f- Form 10-403 Revised 0/20 2 Approved�o6Rtil,G4lNrLLY rhonths from the date of approval Submit In Duplcate p,t\ I/'t r /2//÷//4 �:/ VVV 1 r1 1� ? �.� 0 by rieff M� , ,. Afir Well Name: C-19B Well Type: Producer Current Status: Shut-In Request: P&A for Rotary Sidetrack MIT-T passed to 3000 psi with a plug at 9995' (4/23/2013) CMIT-TxIA passed to 3000 psi with a plug at 10146' (4/26/2011) MIT-OA fail to 2000 psi, IA pressure unchanged during the test and no return to surface (1/24/14) PPPOT-T passed to 5000 psi (1/11/2014) PPPOT-IC passed to 3500 psi (1/11/2014) Well History: CTD sidetrack C-19B was completed in 2000. In 2008 9-5/8" CSG was cut and pulled, install new casing and cemented OA to surface. Well is shut-in since February 2011 due to failing MIT-IA. Reason for P&A: LDL in 2013 revealed a production packer leak. Given the lack of well work potential in the reservoir section due to fluids, and a poor primary cement job on the CTD liner, the remaining value is ,• low. SCMT in 10/11/09 showed enough cement above the TSGR to prevent us from attempting a cut & pu ip-(Jr' with CTD side track. Thus a rotary rig sidetrack is the best option. T GoAE 'r. te-e(/ f'ocroceff 0.,,7-44Ze/4/,' ,4* 17,fr4 G6es # Pre-Rig Work: 'AC/'e afr'� watyl /�0W��`�e, . ' "IP�rf T4. ,�!/ for /QA#y// it Sffo.. f dr /`'r/rotor le ®1f co ',u ,,, ,`4,s f r;DD•r o,/ i�Y t t 1. Drift&Tag PXN plug @9995' in 5-1/2" 17#Tubing ii 2. Punch Tubing -9904' (-5' above 9-5/8"x5-1/2" Baker S-3 Packer) //�'�" �f 3. Circulate Cement Plug in to Tubing & IA-74 bbl of 15.8 ppg Class G. TOC -8800'. ..� 4. Drift&Tag Cement. Drift for Jet Cut. 5. MIT-T. MIT-IA. 6. Jet Cut Tubing -3400' (Planned KOP for RST is 3200') 7. Bleed T/I/O to 0 psi. 8. Install Dry Hole Tree. Install Annulus Valves. Set TWC. Rig Operation: 1. MIRU P 5 3-6 U 1,51 2. Nipple down tree and adapter flange 3. Nipple up and spacer spool and BOP (configured from top to bottom: annular preventer, 2-7/8"x5- 1/2"VBR, blind/shear, mud cross, 2-7/8"x5-1/2"VBR). 4. Pressure test BOP/Annular to 250 psi low/3500 psi high with 4"and 5-1/2"test joints. k--- 5. Rig up and test DSM Lubricator. Pull TWC. 6. Circulate out diesel freeze protect with sea water. 7. Pull 3400' of 5-1/2"TBG. 8. Set 9-5/8" EZSV-3200'. 9. Set whipstock and mill window at 3200' and drill 20' of open hole. End of Sundry: Start of PTD 10. Drill 8-1/2" intermediate section to -11400' with GR/RES. 11. Change upper 2-7/8"x5-1/2"VBRs to 7" casing rams and test with 7"test joint to 250 psi low/3500 psi high. 12. Run 7" 26# L-80 liner and cement 264 cuft, 228 sks of 15.8 ppg Class G to planned TOC 1500'. 13. Test Liner Top Packer to 250 psi low/3500 psi high. 14. Change 7" casing rams to 2-7/8"x5-1/2"VRBs. Pressure test with 4" test joints to 250 psi low/3500 psi high. 15. Drill 6-1/8" production section to—15000' with GR/RES/NUE/DEN. 16. Run 4-1/2" 12.6# 13Cr liner and cement 461 cult, 398 sks of 15.8 ppg Class G to TOL. Circulate out excess cement above TOL. 17. Test Liner Top Packer to 250 psi low/3500 psi high. 18. DPC perforate as per geologist. 19. Run 4-1/2" 12.6# 13Cr completion and stab into 7" Liner Top Packer. 20. Drop ball and rod to set the production packer and test tubing to 250 psi low/3500 psi high. Bleed tubing pressure to 2000 psi, and test IA to 250 psi low/3500 psi high. 21. Shear the DCK shear valve. 22. Freeze protect well and install TWC. 23. ND BOPE, NU Tree and test to 250 psi low/5000 psi high. 24. RDMO Drilling Engineer: Takahiro Kosaka (907) 564-5994 Production Engineer: Ryan Rupert (907) 564-4238 Geologist: John Boyd (907) 564-5384 I FEF=" MCEV OY SAFETY NOTE: _ W LHEAD= MCEVOY Cj 19 B SPOT @ 1725 PERA E6/6 05 70 CHROME TBG*** _ACTUATOR= OTIS OB.REV= ---- 68.62' BF.REV= ---33-.82'KOP= 3300 I; I2074' —9-5/8"HES ES CEMENTER Max-Angle= 94"@ 11748' , 2118' --15-1/2"HES X NIP,D=4.562" Datum MD= 1145T D 2572' 9 518"DV PKR Datum TVD= 8800'SS 9-5/8"CSG,47#,L-80 HYD 563,ID=8.681" H 2087' _____... 1 2688' H 9-5/8"FOC GAS LIFT MANDRELS 9-5/8"BKR BOWEN PATCH,ID=?" H2087'-2091' ST MD I'> ? DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BUTT,D=12-347" — 2688' 3 3310 3306 10 MMG DMY RK 0 03/05/11 2 6625 5741 52 MMG DMY RK 0 03/05/11 Minimum ID = 2.372" @ 10152' 1 9399 7512 49 MMG DMY RK 0 06/12/08 3" X 2-7/8" LNR CROSSOVER I 9888' H5-1/2"HESX NP,D=4.562" ►.1 Z 9909' H 9-5/8"X 5-1/2"BKR S-3 PKR,ID=4.76" 5-1/2"TBG,17#,13CR-80 VAM TOP, —I 10016' -0232 bpf,D=4-892" 9995' 5-1/2"I-ES XN NP,D=4-455" 1 1 9995' —15-1/2"PXN RUG(04/23/13) H 5-1/2"TBG STUB 10019' 10031' —9-5/8"X 5-1/2"UNIQUE OVERSHOT 5-1/2"TBG,17#,L-80,.0232 bpf,D=4-892" — 10050' I a ►� 10050' --19-5/8"X 5-1/2"OTIS PKR,D=4.76"?? �� 10093' J5-112"XO 4-1/2",ID=3.94" 10134' 4-112"OTIS X PF,D=3.813" TOP OF 2 7/8"LNB2 H 10146' 10147' 1 j3.75"BKR DEPLOY SLV,ID=3.00" 1 9 k 10160" _I BKR TNB3ACKSLV,D=?(BEHIND CT LNR) 7"BOT LNR HGR — 10150' . 10152' 3"X 2-718"XO,D=2.372' • 10159' _19-5/8"X 7"BKR LNR HGR,D=? 4-1/2"TBG,12.6#,L-80,-0152 bpf,D=3.958" —1 10217' 10173' _14-1/2"OTIS XN NP, D=3.725" BEHIND 9-5/8"CSG,47#,L-80 BUTT,.0733 bpf,D=8.681" —I 10618' \ 10217' —I4-1/2"OWEG CT LNR PERFORATION SSR, 10190' —I E3MD TT LOGGED 08/11/83 LOGS:BRCS 06/09/82;SY MWDVGR 02/200 0 ��4SWSML04/21/02 ►ANGLEATTOPP : 81@11595' ►ote:Refer to Producon DB for htocal pert data ii • �SIZE SPF INNTEI/AL Opn/Sgz SHOT SOZ • MLLOWIOW(C-19B) 10729-107362" 6 11595 11625 O 07/05/052" 4 11720 11730 *S 03/03/00 3/4/2000 1-1/2" 4 11795-11820 0 12/15/02 ••.4%1. 1-1/2" 4 11850-11900 0 12/15/02 •41 1-1/2" 4 12050-12100 0 12/15/02 ►1•��1111111��• 2" 4 12132-12222 0 03/05/00 ►11111111111111111 12909' —{TOP OF CMT 2" 4 12267-12417 0 03/05/00 ►�1�1�1�1�1�1�1�1� ` 2" 4 12457-12502 0 03/05/00 ►11111111111111111 2" 4 12552-12652 0 03/05/00 111111111 111111111 2" 4 12752-12892 0 03/05/00 ►11111111111111111 vim.' ►11111111 gl•::aZ 111111111 �-�= *"SQZ PERM ARE FLOW CAPABLE PB2 5/2005 LOG ►11111111 v 7"WHPSTOCK H 10736' FBTD H 12954' 7"LNR,26#,L-80 IJ4S,.0383 bpf,ID=6.276" H 11580' 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,D=2.441" —I 12986' DATE REV BY COMvENTS DATE REV BY COMMNTS PRUDHOE BAY UNIT 06/14/82 A-26E ORIGINAL COMPLETION 10/16/08 AK/JMJ DRLG DRAFT CORRECTIONS WELL: C-19B 02/19/97 CTD C-19A SIDETRACK 04/28/11 ALH/PJC FULL F'N/SET LTTP(4/19-20/11) PERMT No:'2000050 03/06/00 CTD C-19B SIDETRACK 04/30/13 CDJ/JM) PULLED LTTP/SET PXN(04/22-23/13 AR No: 50-029-20735-02 06/15/08 D14 RWO 01/10/14 PJC DRAWING CORRECTIONS SEC 19,T11N,R14E,555'FNL&1521'FEL 11/15/06 OOB/TLH SQZ'D PERFS PRODUCING 10/07/08 MXJMD DRLG DRAFT CORRECTIONS BP Exploration(Alaska) f l/� SAFETY NOTES:W ELL ANGLE " y 7D"la 11456'_" C 1 9 B TIORT 51507 e• ,11x25 PER APES/6105'"5-1.2" CRONE g t ,r 1 1 41 2074' -19 5.'8'I D G co.un Tt :4 ill 19 5'6'...MG,b7,5',L 86 1 h D 933.IC 5.601' H 2071' = 2119' H 5 1.2"I M X NP,D-c.562' 9 1."a• U1 PkR H 2572 13 38"(?v: 721.L 65 DJTT,IU-12.•:.' H 2698' 1 - 71689' H ��L CAS LFT R1kNORJi9 Planned KOP 3200'- ST ISO .1 DEX TYrE VL'.., LATCH I'ORT DATE Tubing Gut 3400 - 3 3310 33576 10 MMC CIMY ,9K 0 03A05:11 Estimated TOC 70' .3C"11: =,s: --_ IIIP 2 E,i25 5741 52 kW LIMY-4H 0 03)05:11 1 9398 To'7 40 LARK.. WY -4IC 0 IX&I me. Planned TOC 8800' Tubing Punch 891)4' 9089' -15 1/2"1 C;X NP.D 1.5f2' -w - - - `� gE4 9909' H9 5.6'X 5 1?2'OI92 S a 47...D-4.73' I .5-1;1TBC%174,13CR-8d'.`.AIATOr, - 100'[4' I- -own.- • 9999' I-1^1,"IIICS1SNNP,D-i.4!u' I .0292 Lpf, D-4.892' 1 99'35' I-1^112.PXN PLLI]{Lw 2;l'1 a; I 5 172'113-.3STJO I I 10019' I 10031• H`D5'13`X51i7'LNCLC�1CIS 10T 5 1.2'TOG,17 .L(0_0102:ipL D-c.a;i' H 10050' 0 10030' Ha5A8'X5112-arts P1ir,ID- ,•I - 10093' 115 1:2'X44 1'2'.D .i M In!nil um ID =2.372"(a 11:1159' TOP OF 2-7f3' LINER 10134' I_Ia-1,x1:11 xNt•,u=:!.H'!• I TT]P 2 7 W LJI.C? -I 10146' 111 10146' u,4»'DKR LH;CCFLC.rY SW,D-1.02' I 16130' H0IF'11 JAO<SW.0-7 I('aUTLM IGR I-I 101$0' ■ r 10152' u3"X27,13') D 2.377' IL ▪ 16139' I_I9 5.•A'X 7'D CR LkR I I.M.D-7 I I 4 •'.2'TDG,1213. L 8D..I}15,2 LTJF,D-5.955' H 10.217- I` I FLFf:JRllTlt7hl S.JF,1b1 RY 10173' I-I 1 L7'GTE XY P.P. D 9.72; 111S LID S.OHCS 05dD3.'il2 SPOTTY f.f1'.OGRCQ.251U: lei sm.;ba3.1. L 01:2111)2 104$ til OA II1410 AFX_L to I 10W I tftl-: 81-g 115'M' P1cte:F4etEr-,Itaiucl1cn Lb'or riEWICa 6EY da:9 TSGR 10623' SE= 5P'F NTS-NAL 01....,&4c SI-CT SQZ / PIN kill ' I 115,95-I1F:9:5 ' C) :77!IkSd25 ` "' 4 11/2::-1I/30 "S C3'5VNU 34;21Y_10 N ! IA_LC_rT'P.1.DOW[C-19134 1C7113.1 1:2' 4 11795 11A217 0 '2/1572 r 1-1.'2 4 11 lfi':-I1SIX1 G 15,TX7 ` 1-1¢' 1 1267-12140 L 2'1941 2" 4 12'32-12222 C 9L"Carl 0111114 'l' 4 12:4,,_1241/ l:', 7r3rQ3i0(1I Ili Ns.r Tc4r4si i" -1 12157-12502 C 02'0.0.1 + fI 17909' -fTCF Cr CWT 2" 4 12552 1244& 52 0 Cn.DO 0:10,41;44444:44.40:1 s'41.1444 . 7' 4 17762-121195 C 21.1.05.111 f "9r'�Z PEAFS ARE PLUM CA PAR_E PER Ira D3 S LO lloS SO.i ) .4.4.0.., +r 9"8'C C,471',L 50 DLITT..157:.]b:lf,D-6.FA 1' I- 10616' I 9 T'va IPrTrxr; 10736' / Pam12964' (J 17' LIR 2611.L 60.AS .0351 bjf.D-6.276' - 11900r I!/ 2 7:e LNR 6.1641.1.L 60 STL,.0:55 bpi_D-2.441' - 12986' L14IL- - '1-Y L ATWILNI Lbs It He,'by c::7t1NLNI 1-1ILL1-KJbL-,4'f UNI 06,"11132 A-26E ORIGINAL 4UMPLETIUH altI.t1T.41 AK'.P.4 r1PJ OFAFTCY7REF TIGh.fi V.1=11'C; fin 921-161.117 CTDC-19A5IDETRACK (14.c5iI 41H J[; H,1 I F7irJ'Si-I I I IH:519--:fir11i I--f-All 1AV JWW!�LI 93/116400 CTDC-196911:EFRACK 04.':lrp171 1711:Jr.1) H.I I 1-1)1 II-i F-IFXV[1)1.-1)-1:iI? AIH Nrr-10-079-JrJr3:-rJ 96h5A29 D'14 RYPO SEC 1.. 1111%,Ft14L 664'FFL 8.151T Fki _ 1 1.1 j.Lk. Cc-JR'i I H SI,k"1:.PH-4,9 1-111:H)I,Cie, 10.4.,7.09 AL1'JML2 LihLC,L1-L4F1 cul-Nbr:Irrtr EP Exploration[Alaska'. Ferguson, Victoria L (DOA) From: Kosaka,Takahiro <Takahiro.Kosaka@bp.com> Sent: Friday, February 14, 2014 9:03 AM To: Ferguson,Victoria L(DOA) Subject: RE: PBU C-19B(PTD 200-005, Sundry 314-077) Follow Up Flag: Follow up Flag Status: Flagged Victoria, MPSP (Maximum Potential Surface Pressure) is 3060 psi @Sag River 8358'TVD for both intermediate and production hole. In the intermediate hole,there is a permeable formation with higher pore pressure, 9.35 ppg EMW @4620' @UG4, but this will give lower 1784 psi @surface pressure with 0.1 psi/ft gas gradient. Please let me know if I answered what you are looking for. Thanks, Takahiro Kosaka From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Thursday, February 13, 2014 10:52 AM To: Kosaka,Takahiro Subject: PBU C-19B(PTD 200-005, Sundry 314-077) Please provide the MPSP for this operation. Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferguson aa..alaska.gov 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 : I August 22, 2011 = : ' t ' ` * 1 1 RECEiVED f VG 31 2f f Mr. Tom Maunder Alaska Oil and Gas Conservation Commission Mita & Gas C . �On 333 West 7 Avenue Anther . Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB C -Pad �� `� Dear Mr. Maunder, C ictB Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -278 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -378 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 NOT OPERABLE: Producer C -19B (Po #2000050) Failing MITIA during gaut -off diagnos... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] r Q q 3 I Sent: Sunday, March 06, 2011 3:16 PM( it To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC3 &PCC OSM; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers Cc: Walker, Greg (D &C); AK, D &C Well Integrity Coordinator; Glasheen, Brian P Subject: NOT OPERABLE: Producer C -19B (PTD #2000050) Failing MITIA during gas shut -off diagnostics All, Slickline was performing diagnostics to identify increased gas production in C -19B (PTD #2000050) on 3/4/11. After setting a LTTP and performing an MIT -T, the IA pressure was seen tracking the tubing. Slickline set DGLVs and performed an MITIA that was unsuccessful. The well has been secured with a load and kill and will be reclassified as Not Operable until diagnostics are completed to identify the leak path. The well did not break MOASP and therefore does not need to be reported to the AOGCC. Please call with any questions or concerns. Thank you, ©tv nG�l° Ce p V Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 y MAR 8 2D1 f Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 3/15/2011 Slumherper NO. Alaska Data Consulting Services r�f� Cor 2525 AnchorageeAK Street, 99503- -2838 400 o 7 uLi ATTN: Beth Well Job Log Description Date Bl_ H -26 BOCV -00028 PRODUCTION LOG hs ,Q 6 10/06/09 1 12 -31 B14B -00076 INJECTION PROFILE t )'f'_0 /.4 on -4 3 10/12/09 1 P2 -21 BOCV -00029 PRODUCTION LOG 1 9L -O 10/07/09 1 12 -35 B2NJ -00029 MEM PROD PROFILE 436 G 10/04/09 1 12 -30 B3SQ -00030 INJECTION PROFILE 0 i 1'5/53 /U h 7 t 10/11/09 1 K -19AL1 B69K -00028 LDL (-3()?> --/9 tst"--- 10/18/09 1 C -19B B5JN -00016 SCMT I 67 10/11/09 V -105 AYS4 -00100 INJECTION PROFILE a t 10/05/09 1 OWDW -SE B69K -00021 RST (j p :9 i 4/ 09/23/09 1 OWDW -NW B69K -00022 RST -/D &3 09/24/09 1 OWDW -SW B69K -00023 RST .3 a 09/25/09 1 04 -26 B5JN -00014 RST 21/ it 6 09/26/09 1 12 -05A 40015441 OH M D/L D EDIT ...Jiff a ig e 07/26/07 2 M -19B 09AKA0028 OH MWD /LWD EDIT p r---- 01/29/09 2 III PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: (Alaska) Inc. A B P Exploration as a) Petrotechnical Data Center LR2 -1 21 A 900 E. Benson Blvd. STATE OF ALASKA ALASI~IL AND GAS CONSERVATION COMMI N °' ~" '' REPORT OF SUNDRY WELL OPERA~NS ~` ~~ ~ ~ zo~~ 1. Operations Performed: ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate 0:"~d~-~tiiit~r ~tisp~io'tff~d ~Q%f~~`"`~ ® Alter Casing - ®Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other - " ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ~ ^ Exploratory 200-005 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20735-02-00 7. KB Elevation (ft): 68.62 9. Well Name and Number: PBU C-19B ` 8. Property Designation: 10. Field /Pool(s): ADL 028305 " Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 12986 - feet true vertical 8947 - feet Plugs (measured) None Effective depth: measured 12909 feet Junk (measured) None true vertical 8944 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 145' 20" x 30" 145' 145' Surface 2650' 13-3/8" 2688' 2687' 4930 2670 Intermediate Production 10584' 9-5/8" 10618' 8356' 6870 4760 Liner 580' 7" 10149' - 10729' 8020' - 8437' 7240 5410 Liner 2840' 2-7/8" 10146' - 12986' 8018' - 8947' 13450 13890 ~~;ANNfi~ JUL ~, ~ 2008 Perforation Depth MD (ft): 11595' - 12892' Perforation Depth TVD (ft): 8908' - 8943' 5-1/2" x 4-1/2", 17# x 12.6# 13Cr80 / L-80 1021 T Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 5-1/2" Baker S-3 Packer 9909' 9-5/8" x5-1/2" OTIS Packer 10074' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 10019'. Cut and pull 9-5/8" casi ng from 2088'. Run 9-5/8" (47#, L-80, TC-II) tieback to surface. Cement w/ 150 bbls Class'G' 842 cu ft / 726 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®.Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 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: Contact Mackie Derrick, 564-5891 308-178 Printed Name Sondra Stewman Title Drilling Technologist Si ture Prepared By Name/Number: Phone 564-5743 Date ~~l (° ~ Sondra Stewman 564-4750 °`~i~1fi Form 10-404 Revised 04/2006 Submit Original Only ORIGINAL S ~~ ~~~ ~ ~ 1QO~ ,~~,,~ TREE= 6" McEVOY WELLHEAD = McEVOY ACTUATOR = OTIS KB. ELEV - 68.62' BF. ELEV - 33.82' KOP = 3300' Max Angle = 94 @ 11748' Datum MD = 11458' Datum TV D = 8800' SS SA~NOTES: W ELL > 70° @ 11485' AND GOES C ~ ~ ~ ~ TIGHT SPOT @ 11726 PER APE 6/6/05 • ,~ 2118` 5-112" X NIPPLE, iD = 4.562'• ...~. 2088"_~ 288$' 1_ 9-~/~' FOC t~AS LIFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" 26$$' 9 5/8°' Bowen external casing patch 2088' Minimum ID = 2.372" @ 10152' TOP OF 2-7/8" LINER 5-1/2" TBG; 17#, 13CR, .023 by#, ID = 4,892" ( 9909` 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 10050' 3.75" BKR LNR DEPLOYMENT SLV, ID = 3.00" ~ 10146' TOP OF 2 7/8" LINER, ID = 2.372" 10152' 7" BOT LNR HGR 10149' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10216' 9-5/8" CSG, 47#, L-80, .0732 bpf, ID = 8.681" 10618' PERFORATION SUMMARY REF LOGS: BHCS 06/09/82; SPERRY MWD/GR 02/25/00 SWS MEM CNL 04/21/02 ANGLE AT TOP PERF: 81 @ 11595' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11595 - 11625 O 07/05/05 2" 4 11720 - 11730 S**" 03/03/00 1-1/2" 4 11795 - 11820 O 12/15/02 1-1/2" 4 11850 - 11900 O 12/15/02 1-1/2" 4 12050 - 12100 O 12/15/02 2" 4 12132 - 12222 O 03/05/00 2" 4 12267 - 12417 O 03/05/00 2" 4 12457 - 12502 O 03/05/00 2" 4 12552 - 12652 O 03/05/00 2" 4 12752 - 12892 O 03/05/00 ***SG1Z PERFS ARE FLOW CAPAE3LE PEFZ 512005 L~JG 7" LNR, 26 #, L-80, U4S, ID = 6.276" 11580' ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3310 3306 10 MMG DOME RK 16 06,~22f08 2 6625 5741 52 MMG SO RK 20 06/22/08 1 9399 7512 47 MMG DMY RK 0 06112/08 9888' --~ 5-1i2" X NIPPLE, ID = 4.562„ 9949' 9-5/8" X 5-112" BAKER S-3 PKR, 9995' S-112" XN NIPPLE, ID = 4.455„ 14416' 9-5(8"X5-1(2"UNIOUEOVERSHOT 10074' ~ 9-5/8" X 5-1/2" OTIS PKR, ID = 3.813" 10134' 4-1/2" OTIS X NIP, ID = 3.813" 10173' ~ 4-1/2" OTIS XN NIP, ID = 3.80" 10217' -~ 4-1/2" OTIS WLEG 10190' ELMD TT LOGGED 08/11/83 7" MLLOUT WINDOW 10729'-10736' TOP OF WHIPSTOCK @ 10736' NOTE: NO RA TAG 12909' ~--~ TOP OF CMT ) PBTD -~ 12954' ~' `'' 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.37" 12986' DATE REV BY COMMEMS DATE REV BY COMMENTS 06/14/82 ORIGINAL COMPLETION 02/19/97 CTD C-19A SIDETRACK 03/06/00 CTD C-196 SIDETRACK 06/15/08 D14 RWO 06/28/08 JLJ/SV GLV GO (06/22/08) 06/28/08 GJF/SV PULL JC / WRP (06/26/08) PRUDHOE BAY UNfT WELL: G196 PERMIT No: 2000050 API No: 50-029-20735-02 SEC 19, T11 N, R14E, 664' SNL & 1521' WEL BP Exploration (Alaska) Page 1. of 2 'Well. C-19 Well History Well Date Summary C-19B 5/17/2008 T/I/O=SSV/300/0. Temp=Sl. Monitor for cellar prep upcoming FB CMIT for RWO prep (SC leak). Conductor is 30". Cellar has 6" of ice that will need to be melted, ordered heater. Cellar is 40-45" deep and may require some shoveling to install containment. C-19B 5/18/2008 T/I/O=SSV/350/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: External check installed. Stung into test port (500 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void until clean fluid was achieved. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: External check installed. Stung into test port (200 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void until clean fluid was achieved. Unable to achieve test pressure, re- energized secondary Y seal with plastic (1 J stick). Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi.***suspect internal check still installed***. C-19B 5/18/2008 T/I/O=SSV/320/0. Temp=Sl. Remove gravel and install containment for FB CMIT. Conductor is 20" w/open flutes with 30" insulator insatlled. Heater has been installed. There is 2' of the conductor exposed above ground. removed small amount of gravel for a sample. Will need to remove 3' of gravel to see if there are any circulation ports. C-19B 5/21/2008 T/I/0= SSV/330/0. Temp= SI. T & IA FL for FB (call in). FO could not open SSV possible system frozen, called for heater. IA FL C 366' (19 bbls). Cellar is 40-45" deep. Flutes are 84" deep. Conductor is 30". Cellar is ready for a pit liner. Heater installed in wellhouse. C-196 5/22/2008 T/I/O =SSV/330/0. Temp = SI. TBG FL (cal in). SSV frozen, put heater trunk inside well house. C-19B 5/22/2008 T/I/0=300/300/0 CMIT TxIA to 3500 psi. PASSED Pumped 3 bbls neat meth and 39 bbls of crude to reach test pressure.. Tubing and IA lost 140 psi 1st 15min, 40psi 2nd 15min, for a total of 180psi in 30min. Bled down TxIA pressures (35 bbls) FWHP's=280/50/0 Annulus casing valves tagged and left open to gauges C-19B 5/23/2008 ***WELL S/I ON ARRIVAL*** RAN 3.50" CENT & 2.50" LIB, SD ~ 10105' SLM. NO IMPRESSION ON LIB. DUMP BAILED 100 Ibs OF SLUGGITS ~ 10105' SLM TO 10090' SLM (4 1/2" TBG] DRIFT TBG TO 10027' SLM W/ 4.45" GENT & S. BAILER. [EMPTYI SET 3.75" JUNK CATCHER ~ 10,090 SLM. [10' OAL, 4 1/2" G-F.N.] ***LEFT WELL SHUT IN, TURNED WELL OVER TO PAD-OP*** C-19B 5/23/2008 WELL SHUT IN ON ARRIVAL. T/I/0= 330/100/0 RUN 4.15" POWERCUTTER TO CUT TUBING AT APPROXIMATELY 10000' IN THE FIRST FULL JOINT ABOVE THE PACKER. PLUG AT 10093 NOT TAGGED. TOOL HUNG UP AT APPROX 10,020 FT. COULD NOT LOG SEAL ASSY. BELOW CUT. PERMISSION GRANTED TO CUT @ 10.00 *** JOB CONTINUED ON 24 MAY 2008 AWGRS REPORT *** C-19B 5/24/2008 *** CONTINUE AWGRS FROM 23 MAY 2008 *** CONFIRMED JET CUTTER FIRED. RD ELINE. TURN WELL OVER TO DSO. WELL LEFT SI UPON DEPARTURE. T/I/A 300/110/0 ****JOB COMPLETED**** C-19B 5/24/2008 T/I/0=400/100/0 Circ out (RWO Prep) Pumped 10 bbls of neat meth, 1082 bbls 1 % KCL down Tbg taking returns up the IA and down FL. U-Tube FP 160 bbls diesel.GMIT TxIA to 3500 phi. FAILED 5 attempts pumped 11.1 bbls diesel to reach test pressure. Lost T/IA 40/20 psi in the 1st 15 min, lost T/IA 40/50 psi in the 2nd 15 min for a total loss of T/IA 80/70 in 30 min. **Job in progress continued on 05-25-08** C-19B 5/25/2008 **Job in progress,Continued from 05-24-08** T/I/0=3450/3500/0 Temp=S/I Circ out(RWO prep) Pumped 10 bbls neat meth,1082 bbls 1%KCL down TBG taking returns up the IA & down F/L. U-tube FP 160 bbls diesel.CMIT-TxIA to 3500 PSI, FAILED 5 attemats. Pumped 11.2 bbls 40* diesel to test. T/IA lost 40/20 PSI in 1st 15 min & T/IA lost 40/50 PSI in 2nd 15 min for a total loss of T/IA 80/70. Bleed TBG & IAP down & bled back APR.10 bbls. Pumped 5 bbl Neat meth & 99 bbls crude & 47 bbls diesel to freeze protect F/L pumping through jumper Ioop.FWHP's=0/0/0 Annulus casing valves tagged & left open C-19B 5/25/2008 T/I/O = 0/0/0 ***CMIT TxIA PASSED to 1500 si.*** (RWO Prep) Pumped 6.4 bbls diesel down Tbg to reach test pressure. u ing and IA lost 40psi 1st 15min, 20psi 2nd 15min, for a total of 60psi in 30min. Bled to zero. (5 bbls). FWHP's T/I/O = 0/0/0 Page 2 of 2 • • C-19B 5/26/2008 T/I/0=0/0/0; Set 6-3/8" CIW "J" BPV #405 thru tree for Do on 14 re-ri ; 1-2' ext. used, tagged @ 108" ***Complete es o am C-196 6/6/2008 T/I/O =Vac/0/0 Pulled 6-3/8" GIW "J "BPV @108" 1-2 ext, used, for Doyon 14 to move on. C-196 6/7/2008 T/I/0= 0/0/0. Pull 6" CIW type J TWC thru BOPE.Dovon 14 C-19B 6/14/2008 T/I/0=0/0/0; Pulled 6-3/8" CIW "J" TWC #409 thru tree for Do on 14 Com letion• 1-2' ext. used, tagged C~ 114"; ***Comp e e es ort am C-196 6/18/2008 T/I/0=0/0/0; Pulled 6-3/8 CIW "J" BPV thru tree post rig; 1-2' ext. used, tagged @ 108'; ***Complete*** (Best/Wortham) C-19B 6/22/2008 ***WELL SHUT IN ON ARRIVAL*** PULL BALL AND ROD FROM RHC-M ~ 9968'SLM. PULL RK-DGLV STA.2 C~ 6625' MD. PULL RKP-DCR FROM STA. 3 @ 3310' MD. SET RK-OGLV IN STA.2 ~ 6625' MD. SET RK-LGLV IN STA.3. @ 3310' MD PULL 5 1/2" RHC-M PLUG BODY ~ ss7n:SI M ~ ATTEMPT TO PULL 4-1/2"JUNK CATCHER, SAT DOWN HIGH @ 10023' SLM RAN 3.70" CENT. & 3.25" LIB TO 10027' SLM, (PKR) SEVERAL GOUGES ON EDGE OF LIB RAN 10'x3.0" P. BAILER W/ MULESHOE BTM TO 10,061' SLM **"CONT. POOH W/ BAILER ON 6/22/08*** C-19B 6/23/2008 *** CONT FROM 6-22-08 WSR *** RAN 3.0" PUMP BAILER TO 10,061' SLM -RECOVER LIGHT MUD, SMALL AMOUNT OF RUBBER & METAL DEBRIS RAN 3.805" GAUGE RING TO OBSTRUCTION @ 10,003' SLM. RAN 3.25" CENT & 4 1/2 BRUSH -BRUSH FROM 10,031' SLM TO 10,041' SLM. MAKE MUTIPLE RUNS USING 2.25", 3.0" & 3.5" X 10' PUMP BAILERS RF[`OVER FULL BAILERS OF THICK HFAVY Ml1D (- 20 GALLONS) '**CONT. BAILING ON 6/24/08*** C-19B 6/24/2008 ***JOB CONT. FROM 6/23/08*** RAN 3.5" X 10' PUMP BAILER - SPANGS FROZE UP -MADE IT TO 10,064' +-. MADE MULTIPLE 3" & 3.5" BAILER RUNS TO 10,092' SLM. FULL OF METAL & MUD. RAN 3.75" GAUGE RING DOWN TO 10,080'SLM -TIGHT SPOTS @ 10,075', 10,065' & 10,019' SLM. FINALLY GOT METAL MARKS. RAN 3.75" GAUGE RING SET DOWN ~ 10,088'SLM (HAD TO WORK THRU STUB @ 10,005'SLM RAN 4-1/2" GR TO 10089' SLM, LATCH UP TO & SHEARED TOOL ON JUNK CATCHER RAN 4-1/2" GS, LATCHED JUNK CATCHER C~3 10089' SLM, SHEARED OFF ***JOB CONT. ON 6/24/08*** C-19B 6/25/2008 ***JOB CONT. FROM 6/24/08**' PULLED JUNK CATCHER FROM 10089' SLM BEGIN BAILING SLUGITS W/ 3.5" PUMP BAILER ~ 10092' SLM, BAILER HUNG UP DROPPED TWO CUTTER BARS (DID NOT CUT) & TOOLSTRING CAME FREE, TOOLS OUT OF HOLE BAILED W/ 3.0" PUMP BAILER FROM 10103' SLM TO 10110' SLM ***CONT. BAILING INTO 6/26/08*** C-19B 6/26/2008 ***JOB CONT. FROM 6/25/08*** (INSTALLED GENERIC GLV'S 6/22/08) RAN 3.0" X 10 PUMP BAILER TO 10,109'SLM RAN 3.0" X 10' PUMP BAILER W/WRP EO BTM SUB TO 10,109'SLM -TT PIN SHEARED. RAN 4 1/2" GR & 4 1/2" WRP PULLING TOOL. LATCHED WRP ~ 10,109'SLM -SHEARED RAN 4 1/2" GR -LATCHED WRP C~ 10,109'SLM -SHEARED RAN 4 1/2" GS W/NOSE CONE. LATCHED WRP @ 10 109'SLM PULLED 4 1/9" wRP DRIFTED TO DEVIATION W/ 2.20" CENTRALIZER/SMPL BAILER, SLOWED TO A STOP ~ 11453' SLM ***TURN WELL OVER TO DSO*** '--"~~~ Print Date: 7/11/2008 Page 1 of 1 • BP EXPLORATION Operations Summary Report Legal Well Name: C-19B Common Well Name: C-19B Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date~~ From - To Hours Task Code NPT 6/6/2008 102:30 - 04:30 2.00 MOB P 04:30 - 06:00 I 1.501 RIGU I P 06:00 - 09:30 I 3.501 RIGU I P 09:30 - 11:00 1.501 WHSUR P Page 1 of 9 Spud Date: Start: 6/5/2008 End: Rig Release: 6/15/2008 Rig Number: Phase ~ Description of Operations PRE -Skid rig floor to moving position -Move rig off well C-29A and down C-pad to well C-19B PRE -Position rig over well C-19B and shim -Skid rig floor to drilling position -Spot and berm rock washer Accept rig ~ 06:00 DECOMP -RU cellar -Remove blank flange on wing valve -Install pump in flanges. Install secondary valve on IA DECOMP -RU lubricator. Test to 500 psi x 5 min on chart SIMOPS: Spot and berm tiger tank. RU hard line 11:00 - 11:30 0.50 WHSUR P DECOMP -Test hard line w/ air. -Tie up hard line to rig lines and test hard line w/ water to 3500 psi 11:30 - 14:00 2.50 WHSUR P DECOMP Displace out freeze protect: -Pump 60 bbls seawater down IA, taking returns out tubing to tiger tank. Observed returns C~3 16.5 bbls pumped away. 4 bpm / 520 psi. -Blow down and swap lines -Pump 170 bbls seawater down tubing, taking returns out IA to tiger tank. 4 bpm / 450 psi -Wait 30 min for diesel migration -Pump 30 bbls seawater down tubing, taking returns out IA to tiger tank. Blow down lines 14:00 - 16:00 2.00 WHSUR P DECOMP -RU lines to circulate back to rig pits -Circulate 20 bbls seawater, overboard 15 bbls of returns to rock washer -Blow down lines. Attempt to bleed off tree, no success. Well out of balance -Circulate tubing volume, 5 bpm / 690 psi -Confirm well dead 16:00 - 18:00 I 2.001 WHSUR I P 18:00 - 19:30 1.50 W HSU R P 19:30 - 22:00 2.501 BOPSUF( P 22:00 - 23:00 1.00 BOPSUF~ P 23:00 - 00:00 1.00 BOPSU~{P 16/7/2008 100:00 - 03:30 3.501 BOPSUp P DECOMP -D rod TWC -Test TWC f/ below to 1000 six 10 min on chart. Test f/ above to 3500 six 10 min on chart DECOMP -ND tree and adapter flange -Verity tubing hanger threads and XO DECOMP NU BOP -Stack configuration (top to bottom): 1. 13 5/8" Annular Preventer 2. 3-1/2" x 6" VBR (top rams) 3. Blind rams 4. Mud cross 5. 2-7/8" x 5" VBR (bottom rams) DECOMP RU to test BOP DECOMP Testing BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3500 psi high (annular to 250 psi low - 3500 psi high) x 5 min each on chart. Testing w/ 4" test joint. Test witnessed by WSL and Tourpusher. Chuck Scheve, AOGCC rep, waived witness of test. DECOMP Cont. testing BOP and related equipment per BP / AOGCC procedures and regulations. Test to 250 psi low - 3500 psi Printed: 7/7/2008 11:49:44 AM BP EXPLORATION Page2of9 Operations Summary Report Legal Well Name: C-19B Common Well Name: C-19B Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 Date From - To Hours Task Code '~ NPT 6/7/2008 100:00 - 03:30 ( 3.50 BOPSU~P 03:30 - 04:00 I 0.501 BOPSURP 04:00 - 05:00 I 1.001 WHSUR I P Spud Date: Start: 6/5/2008 End: Rig Release: 6/15/2008 Rig Number: Phase ~! Description of Operations DECOMP high (annular to 250 psi low - 3500 psi high) x 5 min each on chart. Tested w/ 4" test jt. Tested upper rams w/ 4" and 5-1/2" test jts. Test witnessed by WSL and Tourpusher. Chuck Scheve, AOGCC rep, waived witness of test. -Perform koomey test: 1. System Pressure: 3050 psi 2. Pressure after close: 1700 psi 3. 200 psi attained at 41 sec 4. Full pressure attained at 3 min 10 sec 5. Nitrogen bottles: 4 x 2175 psi avg. -Tested 29 components: 1.13-5/8" annular 2. 3-1/2" x 6" VBR (upper rams) 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams) 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. Inside BOP, FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP) DECOMP -RD testing equipment -Mobilize lubricator and extension to rig floor DECOMP -MU lubricator and extension. Test same to 500 osi x 5 min on 05:00 - 06:30 I 1.501 PULL I P 06:30 - 08:30 I 2.001 PULL I P 08:30 - 12:30 I 4.001 PULL I P 12:30 - 13:00 I 0.501 PULL I P 13:00 - 21:00 ( 8.00 I PULL I P 21:00 - 22:30 I 1.50 I CLEAN I P 22:30 - 23:00 0.50 WHSUR P 23:00 - 00:00 1.00 CLEAN P 6/8/2008 100:00 - 01:00 I 1.001 CLEAN I P -RD lubricator and extension and mobilize off rig floor DECOMP -MU XOs and 1 jt 4" DP -RIH and screw in tubing hanger. Back out LDS (blocks weight 50k). PUW after tubing hanger pulled free: 200k (including blocks) DECOMP -Circulate Safe Surf O pill surface -surface. 7 bpm / 140 psi. SIMOPS: -RU to LD 5-1/2" completion: slips, elevators and tongs -RU control line spool DECOMP -LD 4" DP jt and XOs. LD tubing hanger. -Pull and LD 5-1/2" 17# L-80 BTC tubing to SSSV (+/- 2100'). LD SSSV -Recover control line. Recover 2 SS bands and 25 clamps DECOMP -RD control line spool -Install tubing air slips DECOMP -Cont. pulling and LD 5-1/2" 17# L-80 BTC tubing. -Total LD 237 jts + Sliding Sleeve w/ 2 pup jts + 12.51' cut off jt. -Jet cut uniform, flared to 6-1/4" DECOMP -Clear rig floor of tubing equipment -Mobilize BHA tools to rig floor DECOMP install wear bushing DECOMP MU Dress off / Cleanout BHA w/ 8-1/2" x 5-9/16" Washover shoe, 8-1/8" Washpipe extensions, 5-1/2" Dressing mill (inside extensions) and 9-5/8" casing scraper. DECOMP -Torque washpipe assy. -PU 6-1/2" DCs 1x1 Printed: 7!7/2008 11:49:44 AM BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: C-19B ell Name: C-19B e: WORKO Name: DOYON DOYON From - To Hours VER Start DRILLING INC. Rig 14 Rig NPT Phase Task Code Spud Date: : 6/5/2008 End: Release: 6/15/2008 Number: Description of Operations - - - - 6/8/2008 - - 01:00 - 05:30 - 4.50 CLEAN P DECOMP - - RIH w/ Dress off BHA on 4" DP 1 x 1 to 6393' 05:30 - 07:00 1.50 CLEAN P DECOMP Cont. RIH w/ Dress off BHA on 4" DP stands f/ 6393' to 9891' (102 stands in hole) 07:00 - 08:00 1.00 CLEAN P DECOMP -Cut and slip 49.5' drilling line -Service top drive, drawworks and crown 08:00 - 08:30 0.50 CLEAN P DECOMP -MU stand 103. Break circulation -Work and scra a f/ 9891' to 9986'. Pass 08:30 - 10:30 2.00 CLEAN P DECOMP -Wash down f/ 9986' and tacl top of stub ~ 10018' -Work top of stub w/ washover shoe and swallow 17' of stub inside washpipe extensions -Dress off 1' top of stub w/dressing mill. New top of stub ~_ 10019' -PUW 210k /SOW 140k / ROTW 160k. Torque 6k 10:30 - 11:30 1.00 CLEAN P DECOMP Circulate hole clean -Pump Hi-vis sweep surface -surface -525 gpm / 2750 psi 11:30 - 13:00 1.50 CLEAN P DECOMP -Rack back one stand. Flow check. Blow down top drive -POOH to 7000' -Chain in drawworks broke 13:00 - 15:00 2.00 CLEAN N RREP DECOMP -Replace broken chain in drawworks 15:00 - 17:30 2.50 CLEAN P DECOMP Cont. POOH f/ 7000' to BHA 17:30 - 19:00 1.50 CLEAN P DECOMP -Rack back 6 6-1/2" DCs -LD Dress off BHA 19:00 - 19:30 0.50 CLEAN P DECOMP -RU to test casing -Test casin to 3500 six 30 min on chart. Good t t -RD testing equipment 19:30 - 20:00 0.50 CLEAN P DECOMP Mobilize BHA tools of rig floor 20:00 - 22:00 2.00 EVAL P DECOMP RU Schlumberger a-line equipment 22:00 - 00:00 2.00 EVAL P DECOMP -RIH w/USIT log in cement and corrosion mode -Logging f/ 3200' in 9-5/8" casing 6/9/2008 00:00 - 02:00 2.00 EVAL P DECOMP -Cont. running USIT log in 9-5/8" casing to surface 02:00 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 04:30 0.50 0.50 1.00 0.50 EVAL DHB DHB DHB P P P P DECOMP DECOMP DECOMP DECOMP RD Schlumberger a-line equipment -Mobilize 9-5/8" RBP and running tool to rig floor. -MU 9-5/8" RBP assy. RIH w/ 9-5/8" RBP to 2204'. -Take parameters PUW 80k /SOW 80k -Set 9-5/8" RBP er Halliburton re COE ~ 2200' To of -Release running tool and verify release. -Rack back one stand 04:30 - 05:00 0.50 DHB P DECOMP Displace well w/ 150 bbls 9.8 ppg brine. -7 bpm / 160 psi 05:00 - 05:30 0.50 DHB P DECOMP Test RBP to 1500 psi x 15 min on chart 05:30 - 09:00 3.50 DHB P DECOMP -Dump 44 bags (2200 Ibs) of 20/40 sand -Wait 10 min for sand settling. Pump 12 bbls (half drill pipe capacity) 9.8 ppg brine, 1.5 bpm. Wait another 10 min. -PU one stand 4" DP, RIH and tag top of sand ~ 2179' -Pull back 70'. Wait another 10 min. -RIH a ain and to to of sand ~ 2152'. 09:00 - 09:30 0.50 DHB P DECOMP POOH w/ running tool to surface. 09:30 - 10:00 0.50 FISH P DECOMP -LD running tool -Mobilize multi string cutter assy. to rig floor Printed: 7!7/2008 11:49:44 AM BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: C-19B Common Well Name: C-19B Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date I~ From - To Hours Task Code l NPT 6/9/2008 10:00 - 10:30 0.50 FISH P 10:30 - 13:00 2.50 FISH P 13:00 - 14:30 1.50 FISH P Spud Date: Start: 6/5/2008 End: Rig Release: 6/15/2008 Rig Number: Phase Description of Operations DECOMP MU multi string cutter BHA per Baker rep. DECOMP RIH w/ multi string cutter to 2100' DECOMP -Pump 165 gpm / 250 psi to open cutters. Run down and locate collar ~ 2115'. Pull up and locate collar ~ 2077' -Set cutter C~ 2087' and cut 9-5/8" casing. 60 RPM ~ 0-3k -Start pump C~3 178 gpm / 300 psi. After 2 min increase pump rate to 233 gpm / 600 psi. Pressure dropped to 320 psi after cutters made it through casing wall. 14:30 - 19:00 4.50 FISH P DECOMP Close annular preventer and displace arctic pack from 9-5/8" ~ -Break circulation through cut out OA w/mud pumps and 9.8 ppg brine. -Pump 115 bbls 120 deg. diesel down drill pipe and into OA w/ Little Red Svcs. pumping unit, taking returns out OA to tiger tank. 1.5-2 bpm, 300 psi. -Displace all diesel into OA w/ 30 bbls hi-vis sweep followed by 23 bbls 9.8 ppg brine. Let diesel soak in OA f/ 1 hr. -Circulate down drill pipe, taking returns out OA to tiger tank, w/ 260 bbls 9.8 ppg brine and displace diesel, arctic pack and hi-vis sweep. 210 gpm / 500 psi out 13-3/8" casino through fluted hanger and landinn rinn +n . Stayed sucking fluids leaked with vaccum truck during all operation. 19:00 - 19:30 0.50 FISH P DECOMP -Line up choke to gas buster. Open HCR and choke and verify no pressure. -Open annular preventer. Close HCR and choke -Circulate 9.8 ppg brine down drill pipe taking returns out IA until clean. 126 gpm / 150 psi 19:30 - 20:30 1.00 FISH P DECOMP POOH 4 " DP w/ multi string cutter BHA. -LD last 15 jts of 4" DP and multi string cutter BHA -Pull wear ring. 20:30 - 21:30 1.00 FISH P DECOMP -Clear rig floor of tools not needed. -Mobilize spear assy. to rig floor -MU spear BHA to 1 jt 4" DP. 21:30 - 22:00 0.50 FISH P DECOMP -RIH and engage 9-5/8" casing below mandrel hanger. BOLDS. -Work casin ullin f/ 175k to 310k until madrel h free blocks wei ht k . PUW 135k after mandrel hanger pulled free. Pull hanger to rig floor. 22:00 - 23:00 1.00 FISH P DECOMP Circulate w/ 9.8 ppg brine down 9-5/8" casing through cut until clean. 320 gpm / 50 psi. -RU to LD 9-5/8" casing pulled. -Little arctic pack back with returns when started circulating NOTE: continue sucking fluids leaking out 13-3/8" casing through fluted hanger and landing ring. 23:00 - 00:00 1.00 FISH P DECOMP -Disengage and LD spear assy. -Break out and LD mandrel hanger 6/10/2008 00:00 - 06:00 6.00 ~ FISH P DECOMP ~ Cont. LD 9-5/8" 47# L-80 BTC casing Printed: 7/7/2008 11:49:44 AM • BP EXPLORATION Page 5 of 9 Operations Summary Report Legal Well Name: C-19B Common Well Name: C-19B Spud Date: Event Name: WORKOVER Start: 6/5/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/15/2008 Rig Name: DOYON 14 Rig Number: Date From - To ~~ Hours Task I, Code ! NPT Phase Description of Operations --- - _ _ - - 6/10/2008 00:00 - 06:00 6.00 FISH P DECOMP -Connections tight 06:00 - 06:30 0.50 FISH P 06:30 - 07:30 1.00 FISH P 07:30 - 08:30 1.00 FISH P 08:30 - 09:00 0.50 WHSUR P 09:00 - 10:00 1.00 FISH P 10:00 - 11:30 1.50 FISH P 11:30 - 12:00 0.50 FISH P 12:00 - 13:30 1.50 FISH P 13:30 - 14:00 0.50 FISH P 14:00 - 14:30 0.50 FISH P 14:30 - 17:00 2.50 FISH P -Casing coming out fairly clean of arctic pack -Total LD: 53 jts + 10.52' cut off. DECOMP RD casing equipment: tongs, slips and elevators DECOMP -Clear and clean rig floor -Clean pollution pan under rig floor DECOMP -PU spear assy. Service break and LD same -Mob wear bushing and tools for dress off assy. to rig floor DECOMP Install long bowl wear bushing DECOMP MU 9-5/8" casin dress off BHA w/ 12" x 9-5/8" washover shoe, 11-3/4" washpipe extension, 9-5/8" dress off mill inside the washpipe extension and 13-3/8" casing scraper. DECOMP RIH w/ casing dress off BHA to 2020' DECOMP -Obtain parameters: PUW 92k /SOW: 92k -Break circulation and wash down. Tag top of 9-5/8" stub ~ 2087'. 336 m / 300 si. -Work top of stub w/ washover shoe and swallow +/-9' of stub. -Dress off 1' f/ top of stub with dress off mill. Too of stub C~3 2088'. 80 RPM / 1-2k torque DECOMP CBU x2 while rotating and reciprocating. 322 gpm / 200 psi DECOMP POOH to 1644' DECOMP -MU 13-3/8" RTTS on top of string. -RIH w/ 13-3/8" RTTS and set same ~ 486' DECOMP -Test 13-3/8" casing below RTTS to 2000 psi x 15 min. Good it again C~? 80'. Attempt to 17:00 - 18:30 1.50 FISH P 18:30 - 19:30 1.00 FISH P 19:30 - 20:00 0.50 WHSUR P 20:00 - 22:00 2.00 CASE P 22:00 - 00:00 I 2.00 I CASE I P 6/11/2008 100:00 - 02:00 I 2.001 CASE I P 02:00 - 02:30 ~ 0.50 ~ CASE ~ P casing oeww n i i s. rressure oieeas on uicici returns to cellar throu h fluted han er and landin -Move RTTS down and set ~ 113'. Test 13-3/8" casin below RTTS to 2000 six 5 min. ood -Close rams and pump down DP x casing annular. Obtain leak rate: 1 bpm ~ 120 psi DECOMP -Pull 13-3/8" RTTS out of hole and LD same. -Cont. POOH w/ casing dress off BHA DECOMP -LD casing dress off BHA -Clear rig floor DECOMP Pull wear bushing DECOMP RU to run 9-5/8" casin w/ casin atch -Install elevators, tongs and torque turn equipment -Mobilize ES Cementer, pup jts, XOs and casing patch to rig floor DECOMP -MU 9-5/8" Bowen Casing Patch w/ pup jt + HES ES Cementer + XO pup jt. Baker lock connections. -Run 9-5/8" 47# L-80 HYD 563 casing w/ casing patch and ES Cementer to +/- 760' DECOMP Cont. running 9-5/8" 47# L-80 HYD 563 w/ casing patch and ES Cementer. -Total jts run: 54 -Torque turn all connections. -PUW 135k /SOW 135k -1 floating centralizer on XO pup above ES Cementer -1 floating centralizer on first 53 joints DECOMP -Make up pup jt + XO pup on top of string Printed: 7/7/2008 11:49:44 AM • • BP EXPLORATION Page6of9~ Operations Summary Report Legal Well Name: C-19B Common Well Name: C-19B Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Spud Date: Start: 6/5/2008 End: Rig Release: 6/15/2008 Rig Number: Date From - To Hours Task Code' NPT 6/11/2008 02:00 - 02:30 0.50 CASE P 02:30 - 03:00 I 0.501 CASE I P 03:00 - 04:00 I 1.001 CASE I P 04:00 - 04:30 I 0.50 I CASE I P 04:30 - 05:30 I 1.00 05:30 - 06:30 I 1.00 06:30 - 07:30 I 1.00 07:30 - 08:30 I 1.001 BOPSUR P 08:30 - 11:30 I 3.001 WHSUR I P 11:30 - 14:00 I 2.501 BOPSUR P 14:00 - 17:00 ~ 3.00 BOPSUFtP 17:00 - 19:00 I 2.001 BOPSURP Phase ', Description of Operations DECOMP -Ta to of stub ~ 2088'. Swallow 3' w/ casin atch and bottom out Pull to 175k per Baker rep. Slack off again. -Pull to 250k and pull test casing patch. -Slack off to 100k and set on casing slips. -Bottom of casing patch C~ 2091'. ES Cementer ~ 2074' DECOMP -C/O bales. RD tongs. -MU head pin and RU to pressure test casing DECOMP -Pull casing to 235k (100k over PUW) -Test casing to 2000 psi x 30 min on chart_ -Bleed off pressure -Verify circulation through ES Cementer. 4 bpm / 50 psi DECOMP -Slack off to 100k and set on casing slips. -RD testing equipment and head pin -RU cement head and cement lines. DECOMP Give to Schlumberger: -Pressure test lines with water to 4500 psi. Flush water out to mud bucket line w/ cement. Line up to cement head. -Pump 150 bbls 15.8 ppg class G cement w/ the following additives:.20% D046 - .30% D065 - .40% D167 & .20% S002 -Drop closing plug -Kick out w/ 1 bbl 15.8 ppg cement DECOMP Switch to rig pumps: -Displace w/ 8.5 ppg seawater -Caught cement at 600 stks - Cement to surface at 1150 stks -Bump plug w/ 1465 strokes -Pressure up to close HES ES Cementer w/ 1700 psi (Good indication). Keep pressuring up to 2300 psi and hold x 5 min per Halliburton rep. -Bleed off -Check floats - OK' -Cement returns through flut_ed__hanger and landing ring in cellar. -Est. cement to surface = 25 bbls - CIP at 06:00 hrs -Maintain 100k overpull on casing during cementing operation. DECOMP RD cementers -Flush surface equipment DECOMP ND BOPE -ND flowline, riser, choke line -Split tubing and casing flange -PU stack DECOMP Set emer enc sli s w/ 100k -RU & cut 9 5/8" casing w/ WACHS cutter per Cameron Rep. -LD cut joint (29.86') and XO pup -Remove tubing spool -Set back BOP -Install new tubin s ool w/ YBT seconda seal -Test same to 3800 psi f/ 30 min per Cameron Rep. -Good test DECOMP -NU BOPE -Clear rig floor DECOMP -C/O bales on top drive -Flush stack w/ stack washer and jet flow line -Open ram doors in stack and clean cement remains DECOMP -RU to test. PU 4" test jt _ -Test BOP breaks to 250 psi low - 3500 psi high x 5 min on Printed: 7/7/2008 11:49:44 AM BP EXPLORATION Page 7 of 9 ~ Operations Summary Report Legal Well Name: C-19B Common Well Name: C-19B Spud Date: Event Name: WORKOVER Start: 6/5/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/15/2008 '.Rig Name: DOYON 14 Rig Number: Date I From - To ' Hours Task ~ Code ~ NPT ~ Phase Description of Operations 6/11/2008 17:00 - 19:00 2.00 BOPSU~P 19:00 - 19:30 0.50 BOPSU P 19:30 - 21:30 2.00 CLEAN P 21:30 - 22:00 0.50 CLEAN P 22:00 - 23:00 1.00 CLEAN P 23:00 - 00:00 1.00 CLEAN P 6112/2008 00:00 - 01:00 1.00 CLEAN P 01:00 - 01:30 0.50 CLEAN P 01:30 - 02:00 0.50 CLEAN P 02:00 - 02:30 0.50 CLEAN P 02:30 - 03:00 0.50 CLEAN P 03:00 - 03:30 ~ 0.501 CLEAN ~ P 03:30 - 04:00 I 0.50 I CLEAN I P 04:00 - 05:00 1.00 CLEAN P 05:00 - 05:30 0.50 CLEAN P 05:30 - 08:00 2.50 CLEAN P 08:00 - 09:00 I 1.00 I CLEAN I P 09:00 - 11:00 I 2.00 I CLEAN I P 11:00 - 11:30 I 0.501 FISH I P 11:30 - 12:30 I 1.001 FISH I P DECOMP -RD testing equipment DECOMP Install wear bushing DECOMP LD 14 stands 4" DP from derrick in mouse hole, while WOC -Confirmed 500 psi compressive strength on cement w/ Schlumberger lab DECOMP Mobilize BHA tools to rig floor DECOMP MU cleanout BHA w/ 8 1/2" bit, 2 Boot Baskets and 9 5/8" casing scraper. DECOMP RIH w( cleanout BHA to 2050' DECOMP -Break circulation and obtain parameters: PUW 92k /SOW 92k -Wash down and to ES Cementer ~ 2074'. -Drill out plug and ES Cementer. Observed pieces of plug rubber in shale shakers w/ returns. -cleanout cement stringers to 2100'. -60 RPM / 2-5k torque. 336 gpm / 410 psi DECOMP Circulate Hi-vis sweep surface -surface. 336 gpm / 410 psi -Rotate and back ream through ES Cementer while circulating DECOMP -RIH and to to of sand/debris ~ 2144' - -Dry drill debris to 2147'. DECOMP -Blow down top drive -POOH w/ cleanout BHA DECOMP -Rack back 6-1/2" DCs. -LD and clean boot baskets. Boot baskets brought pieces of internal parts in ES Cementer and cement. -LD casing scraper. Break out bit DECOMP -Mobilize casing scraper off rig floor -Mobilize RCJB to rig floor SIM OPS: RU to test casing. DECOMP -Test 9-5/8" casing to 3500 psi x 30 min on chart. Good test.. -RD testing equipment -Blow down kill and choke line DECOMP MU cleanout BHA w/ 7 7/8" RCJB and Boot Baskets. DECOMP RIH w/ RCJB BHA to 2020' DECOMP -Break circulation. 315 gpm / 450 psi. Wash down to 2114' -Drop 1" ball. RIH and tag (~ 2144'. -Dry drill 3'. Attempt to circulate. Pipe pressure up w/ no returns. -Attempt to unplug w/ no success. RU & reverse circ. 1/2 drill pipe volume. Attempt to circulate again down the drill pipe w/ no sucess. -Rack back one stand. RU head pin. Reverse Circulate 2.5 drill pipe volumes, 336 gpm / 390 psi. -Drop another 1" ball. Circulate down drill pipe w/ good returns. -Wash down with RCJB f/ 2144' to 2175'. 317 gpm / 2500 psi -Circulate Hi-vis sweep surface -surface. DECOMP -Blow down top drive and kill line. -POOH to BHA DECOMP -LD 6 6-1/2" DCs to pipe shed. -LD jars, boot baskets and RCJB. -Mobilize tools off rig floor.. DECOMP -MU RBP retrieving tool. -RIH w/ RBP retrievin tool to 210 ' DECOMP -Screw in top drive. Break circulation, 420 gpm / 410 psi Printed: 7/7/2008 11:49:44 AM • BP EXPLORATION Operations Summary Report Legal Well Name: C-19B Common Well Name: C-19B Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To !Hours Task ~ Code 6/12/2008 ~ 11:30 - 12:30 ~ 1.00 FISH ~ P Spud Date: Start: 6/5/2008 End: Rig Release: 6/15/2008 Rig Number: ~~ Page 8 of 9 NPT ' Phase ' Description of Operations 12:30 - 13:00 0.50 FISH P 13:00 - 13:30 0.50 FISH P 13:30 - 15:30 2.00 FISH P 15:30 - 16:00 0.50 FISH P 16:00 - 18:30 2.50 FISH P 18:30 - 19:30 1.00 FISH P 19:30 - 21:00 1.50 FISH P 21:00 - 21:30 0.50 FISH P 21:30 - 00:00 2.50 FISH P 6/13/2008 00:00 - 02:00 2.00 FISH P 02:00 - 02:30 0.50 WHSUR P 02:30 - 03:30 1.00 FISH P 03:30 - 06:30 3.00 BUNCO 06:30 - 19:00 12.50 BUNCO 19:00 - 20:30 1.50 BUNCO RREP 20:30 - 00:00 3.50 BUNCO 6/14/2008 00:00 - 01:00 1.00 BUNCO 01:00 - 02:00 I 1.001 BUNCO DECOMP -Tag sand ~ 2175' Wash down w/ retrieving tool per Halliburton rep. to top of fishing neck ~ 2195' DECOMP -Latch retrieving tool on fishing neck -Bet 'ev BP DECOMP CBU C~3 420 gpm / 390 psi DECOMP -POOH w/ RBP and LD 39 jts 4" DP to pipe shed. Had mechanical problems w/ pipe skate. -Cont. POOH by stands w/ RBP while working on pipe skate. DECOMP -LD RBP and retrieving tool. Mobilize same off rig floor -MU mule shoe DECOMP RIH 4" DP stands f/ derrick to +/- 7000' DECOMP CBU ~ 420 gpm / 1200 psi. R&R @ 90 RPM / 1 k torque. DECOMP -Cut and slip 59.5' drilling line -Service top drive DECOMP -Started POOH when observed fluid off balance. -Circulate ~ 420 gpm / 1200 psi, while mixing dry job. Pump same. DECOMP POOH and LD 4" DP 1x1 to pipe shed. DECOMP Cont. POOH and LD 4" DP 1x1 to pipe shed DECOMP Pull wear bushing DECOMP -Load tail pipe components in pipe shed -Clean rig floor RUNCMP RU to run 5-1/2" 13Cr Vam To com letion -C/O bales. RU tongs. Install torque turn equipment. Install single joint compensator and elevator. Mobilize slips. -Mobilize tubing hanger to rig floor. -Mobilize XOs to rig floor. MU XO to floor valve. -Buck off collars in 2 pup jts and Bakerlock (for tail pipe). RUNCMP -PJSM on running completion -MU tail pipe: 9-5/8" x 5-1/2" Unique Overshot Assy + XN niple Assy + 1 5-1 /2" 17# 13Cr80 Vam Top HC jt (w/ 10' pup jt below and above) + S-3 Packer Assy + X nipple Assy. Bakerlocked all connections below packer -Run 5-1/2" 17# 13Cr80 Vam Top HC tubing w/ completion equipment to +/- 6490'. Torque turn all connections. RUNCMP Repair hydraulic hose in pipe skate RUNCMP Cont. running 5-1/2" 17# 13Cr80 Vam Top HC w/ completion equipment to +/- 9000'. Torque turn all connections RUNCMP Cont. running 5-1/2" 17# 13Cr80 Vam Top HC tubing w/ completion equipment to 9969' (233 jts). Torque turn all connections. -Take parameters: PUW 205k /SOW 150k RUNCMP Space out completion -PU jts 234 and 235. -Observe 1st shear ins ~ 15' in 't # 235 100 ' . Shear pins w/10k shear pins ~ 23' in jt # 235 (10034'1. Shear pins 02:00 - 04:00 w/ 10k -Bottom out @ 25' in it # 235 10036' . Slack off 20k -Pull and LD jts 235, 234 and 233. -Determine space out. Space out w/ 5' off bottom out 2.00 BUNCO RUNCMP -MU 9.81', 7.89' and 7.78' pup jts on top of jt 232 -MU jt 233. Printed: 7/7/2008 11:49:44 AM e • • BP EXPLORATION Page 9 of 9 Operations Summary Report !Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To ! C-19B C-19B WORKO DOYON DOYON Hours I VER DRILLIN 14 Task INC 'Code . NPT 6/14/2008 02:00 - 04:00 2.00 BUNCO 04:00 - 09:00 5.00 BUNCO 09:00 - 11:00 2.00 BUNCO 11:00 - 13:00 2.00 WHSUR P 13:00 - 15:30 2.50 BOPSU P 15:30 - 18:30 3.00 WHSUR P 18:30 - 19:30 1.00 WHSUR P 19:30 - 22:30 3.00 WHSUR P 22:30 - 00:00 1.50 WHSUR P 6/15/2008 00:00 - 01:30 1.50 WHSUR P 01:30 - 03:00 1.50 WHSUR P Spud Date: Start: 6/5/2008 End: Rig Release: 6/15/2008 Rig Number: Phase ~ Description of Operations RUNCMP -MU tubing hanger, XOs and 1 jt 4" DP for landing jt. -Land com letion. RILDS Total jts run in completion: 233 Bottom Unique Overshot ~ 10030'. XN nipple Cad 9995'. Packer C~3 9909'. X nipples ~ 9888' and ~ 2118'. GLMs ~ 9399', 6625' and 3310'. RUNCMP -RU to reverse circulate. -Reverse circulate w/ 780 bbls clean seawater. Added corrosion inhibitor f/ 330 bbls to 600 bbls seawater pumped away. -3 bpm / 630 psi RUNCMP -Drop ball-and-rod to set packer -Pressure u tubin to 3800 si. Set acker. Hold 3800 si x 30 min. Pressure dro s 50 si in first 15 min. 100 si total ressure dro in 30 min. MIT-T ood. -Bleed off ressure in tubin to 1500 si. Pressure u IA to 3500 si and hold x 30 min. No ressure dro .MIT-IA ood. -Bleed off pressure in tubing and observe DCR-1 valve shear. Bleed off all pressures. Establish circulation: IA to tubing ~ 2 bpm / 180 psi. Tubing to IA C~3 3 bpm / 350 psi. -Chart all tests. RUNCMP -RD testing equipment. -LD 4" DP jt + XOs used for landing. -Suck out stack -Cameron rep. dry rod TWC. -Test TWC f/ above to 3500 psi x 10 min on chart. Test f/ below to 1000 psi x 10 min on chart. RUNCMP -Blow down choke, kill and fill up lines to stack. Suck out stack with rig vac. -ND BOP. Set BOP stack back RUNCMP -NU adapter flange and production tree -Test adapter flange to 5000 psi x 30 min per Cameron rep. -Fill production tree w/diesel. Test production tree w/diesel to 5000 psi x 10 min on chart RUNCMP -RU DSM lubricator and test to 500 psi. -Pull TWC. -RD lubricator RUNCMP -RU Little Red Services to pump down IA -Test lines to 3000 psi -Little Red services pumps 140 bbls 80 F diesel down IA, taking returns out tubing, for freeze protect. 2 bpm / 600 psi. RUNCMP Jump IA to tubing. Let diesel U-tube. RUNCMP -Verify well stable. Suck out lines to tubing and RD same. -Cameron rep dry rod BPV. -Test BPV f/ below to 1000 psi x 10 min on chart. Use diesel and Little Red to test BPV. -Bleed off pressure. Suck out lines. RD Little Red RUNCMP Secure tree: -Remove pump in flanges. Remove secondary valve in IA. -Install blind flanges and gauges. -TBG= 0 psi / IA= 0 psi / OA= 0 psi Release riq ~ 03:00 Printed: 7/7/2008 11:49:44 AM • AI<A58A ®I~i A~I~ `]r~7 CO1~T5ERQATI[Oi~T CODIIK155IO1~T David Reem Engineering Team Leader BP Exploration (Alaska), Inc. PO Box 196612 ~, _' ~ 200 Anchorage, AK 99519 ~~~~ MAY ~. • SARAH PALIN, GOVERNOR 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU C-19B Sundry Number: 308-178 by . p05 a Dear Mr. Reem: 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, ~~ ~ ~°` Daniel T. Seamount, Jr. Chair DATED this d 2 day of May, 2008 Encl. STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N APPL~ATION FOR SUNDRY APPRO AL 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension Anchorage ~ Alter Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 200-005 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20735-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU C-19B Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028305 68.62 Prudhoe Bay Field / Prudhoe Bay Pool 12- PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12986 8947 12909 8944 10093' N/A a in en h Si a MD TVD t Colla se tr r I r 1 5' 20" x 14 ' 14 ' dace 2650' 1 -3/8" 2688' 2687' 4 0 2 70 Int rm i to 1 84' - /" 10 1 3 7 in 580' 7" 10149' - 10729' 8020' - 8437' 7240 5410 Liner 2840' 2-7/8" 10146' - 12986' 18' - 947' 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11595' -12892' 8908' - 8943' 5-1/2" x 4-1/2", 17# x 12.6# L-80 10217' Packers and SSSV Type: 9-5/8" x 5-1/2" OTIS Packer Packers and SSSV MD (ft): 10074' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ~ Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: June 10, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mackie Derrick, 564-5891 Printed Na David Reem Title Engineering Team Leader Prepared By Name/Number: Signature ~ ~; ~~-~ Phone 564-5743 Date S~$ ~l ~ Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: ~~~ ~ -' ~--x-~ ~ ~ ~~ Subsequent Form Required: `.-~ R A roved B : COMMISSIONER THE OMM SSION Date Form 10-403 edv66/2006 ~ DUpL; rg7E ,~''~~~ ~ i ~ ~~ Submit In Duplicate 1 !/ MAY 0 ~ 200 a ii G fission by cr y C-19B Expense Rig Workover Scope of Work: Repair Surface Casing Leak: Pull 5?/z" L-80 completion, cut and pull 9 s/e" casing, run and cement to surface 9 $/e" casing, run 5-'/z' 13Cr-80 "stacker-packer" completion. MAASP: 2420 psi Well Type: Producer Estimated Start Date: June 10, 2008 Production Engineer: James Dean Intervention Engineer: Mackie Derrick Pre-Rig Work Request: F 1 CMIT-TxIA to 3500 si, LLR if fails S 2 Ta WRP 10093' MD. Dum 10' of slu its on WRP. Set 4-'/2" 'unk catcher on slu its. E 3 Power Jet cut 5-%z" L-80 tubing at 10,000' MD, in the middle of the first full joint above the Otis acker. Reference tubin tall dated 06/17/82. F 4 Circulate well with kill wei ht fluid and diesel thru the cut. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & tC. W 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU BOPE with 3-%z" x 6" VBR pipe rams. Pressure test to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5-%z" tubing string to the cut. 3. Run USIT log to determine top of cement in 9 5/e' x 13-3/8" annulus. 4. Set retrievable bridge plug 100' below the top of cement and pressure test to 1500 psi for 15 minutes. 5. Cut and pull 9 8/a" casing from above the top of cement. Note: Pipe rams will not be changed to 9- %." as the well has two tested barriers (Fill plug and RBP) to the reservoir. 6. Run and fully cement new 9-B/a" casing to surface. Squeeze cement thru surface casing leak 7. Drill out 9 b/a" shoetrack +, ~ ~ ~ ~~ 8. Pressure Test 9 6/s" casing to 3500 psi W _ ~C ~~ 9. Pull retrievable bridge plug 10. Pull junk catcher, LDDP 11. Run 5-'/z" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at 9960' MD. 12. Displace the IA to packer fluid and set the packer. 13. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 14. Set BPV. ND BOPE. NU and test tree. RDMO. TREE _ ~ 8" WFiLHEAD= McEVOY ACTUATOR= OTIS KB. ELEV = 68.62' BF. ELEV = 33.82' KOP = 3300' Max Angle = 94 (~ 11748' Datum MD = 11458' Datum TV D = 8800' SS 13-3/8" CSC, 72#, L-80, ID = 12.347" 2688' Minimum I©= 2.372" c~ 10152' TOP OF 2-7/8" LINER 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~-~ 10050' 3.75" BKR LNR DEPLOYMENT SLV, ID = 3.00" I 10146' TOP OF 2 7/8" LINER, ~ = 2.372^ 10152' 7" BOT LNR HGR 10149' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ~ = 3.958" 10216' 9-5/8" CSC, 47#, L-80, .0732 bpf, ID = 8.681^ 10618' PERFORATION SUMMARY REF LOGS: BHCS 06!09/82; SPERRY MWDIGR 02/25/00 SWS MEM CNL 04/21/02 ANGLEATTOPPERF: 81 ~ 11595' Note: Refer to Productron DB for histor~al perf data S¢E SPF NITERVAL OpnlSgz DATE 2" 6 11595 - 11625 C 07/05/05 2" 4 11720 - 11730 S*** 03/03/00 1-1/2" 4 11795 - 11820 C 12/15/02 1-1/2" 4 11850 - 11900 C 12/15/02 1-1/2" 4 12050 - 12100 C 12/15/02 2" 4 12132 - 12222 C 03/05/00 2" 4 12267 - 12417 C 03/05/00 2" 4 12457 - 12502 C 03/05/00 2" 4 12552 - 12652 C 03/05/00 2" 4 12752 - 12892 C 03/05/00 -.-SG2L PERFS ARE FLOW CAPABLE PER 512005 LOG 7" LNR, 26 #, L-80, U4S, ~ = 6.276" -~ 115$( G ~ ~ ~ SAFEITNOTES:WELL > 70° aQ 11485' AND CabES HORIZONTAL @ 11700'. TIGHT SPOT (~ -11725 PER APE 618/05 2144' 5-1/2" OTb SSSVN, ID = 4.562" ( 9-5/8" FOC ~ (5-1/2" OTIS XA SLDNUVG SLEEVE, ID=4.562" ~ 10050' -1 TUBNJG SEAL ASSY 10074' _ 9-5/8" X 5-1/2" OTI.S PKR, ID = 3.813" 10093' _ 4-1/2" WFO WRP (os/1 s/os> 10134' 4-1 /2" OTIS X NAB, ~ = 3.813" 10I 173, I_( 4-1/2" OTiS XN NIP, ID= 3.80" 1021T a-vr' orls vvLEG 10190' ELMD TT LOGGED 08/11183 7" MLLOUT WINDOW 10729'-10736' TOP OF WHIPSTOCK (d3 10736' NOTE: NO RA TAG 12909' -{TOP OF CMT ~ ~ PBTD hi 12~ 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.37" DATE REV BY COMMENTS DATE REV BY COMMENTS 06/14/82 018GINAL COMPLETION 08/03/05 ROY/TLH PERF CORRECTIONS ('48 OFF) 02H8/S7 CTD C-19A SIDETRACK 09/18/06 MSS/'TLH WFD WRP SET OSI06I00 CTD C-18B SIDETRACK 11/15/06 OOB/TLH SQZ'D PERFS PRODUCING 07/29/02 CWKAK CORRECTIONS 12/15/02 KSBlKK ADPERFS 07!06/05 JLG/TLH ADPERFS PRlIDHOE BAY UNIT WELL: C-19B PERMIT No: 2000050 API No: 50-029-20735-02 SEC 19, T11 N, R14E, 664' SNL & 1521.' WEL BP Exploration (Alaska) rREF = " 6" W AHEAD = McEVOY ACTUATOR = OTIS KB. ELEV = 88.87 BF. ELEV = 33.82' KOP= 3300' Max Angle = 94 ~ 11748' Datum MD = 11458' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I--~ 2688' Minimum ID = 2.372" ~ 10152' TOP OF 2-7/8" LINER 1/2" TBG, 17#, 13CR, .023 bpf, ID = 4.892" i 10000' 5-1 /2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 10050' 3.75" BKR LNR DEJ~OYMENT SLV, ID = 3.00" ~-t 1o14s• TOP OF 2 7/8" LINER, ~ = 2.372" 10152' 7" BOT LNR HGR 10149' 14-1 /2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 9-5/8" CSG, 47#, L-80, .0732 bpf, ID = 8.681" PERFORATION SUMMARY REF LOGS: BRCS 06!09/82; SPERRY MWD/GR 02/25/00 SWS MEM CNL 04/21 /02 ANGLEATTOPPERF: 81 X11595' Note: Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE T' 6 11595 - 11625 C 07/05/05 2" 4 11720 - 11730 S*** 03/03/00 1-1 /2" 4 11795 - 11820 C 12/15/02 1-1 /2" 4 11850 - 11900 C 12/15/02 1-1 /2" 4 12050 - 12100 C 12/15/02 2" 4 12132 - 12222 C 03/05/00 2" 4 12267 - 12417 C 03/05/00 2" 4 12457 - 12502 C 03/05/00 2" 4 12552 - 12652 C 03/05/00 2" 4 12752 - 12892 C 03/05/00 ---~4lL rrms Ate rL(AN CAPABLE PER 5/2005 LOG 7" LNR, 26 #, L-80, U4S, ID = 6.278" 11580' C-19B Proposed RWO S OTES: WELL> 70° ~ 11485' AND GOES HawaONra. ~ 11700•. 11GFFf SPOT ~'-11725 PER APE 8/8/05 21015-1 /2" X NIPPLE, ID = 4.562" Cement to surface .._ 2688' 9-5/8" FOG ..-o~. GAS LIFTMAIUIIRFI G ST MD TVD DEV TYPE VLV LATCH PORT . DATE 3 3305 3300 10 DMY 2 6640 5750 51 DMY 1 9381 7500 54 DMY 9940' -- ~5-1/2" X NIPPLE, ID= 4.562" 9960' 9-5/8" X 5-1l2" BAKER S-3 PKR, 99$0' 5-112" XN NIPPLE, ID = 4.455" 10000' 9-5/8" X 4-1/2" llNILIUE OVERSHOT 10074' 9-5/8" X 5-1/2" OTIS PKR, ID = 3.813" I 4-1 /2" OTIS X NIP, ID = 3.813" ~ 10~ 173' 1~ 41 /2" OTIS XN NIP, ID = 3.80" 10217' 4-1/2" OT1S WLEG 10190' ELMD TT LOGGED 08/11 /83 7" MLLOUT WINDOW 10729'-10736' TOP OF WHIPSTOCK ~ 10736' NOTE NO RA TAG 12909' I-iTOP OF CMT u 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.37" DATE REV BY CONMBd'1'S DATE REV BY COMMENTS 08/141$2 ORIGNNAL COMPLETION 08!03105 ROY/TLH PERF CORRECTIONS ('48 OFF) 02/19/97 CTD C-19A SIDETRACK 09/18/06 MSS/TLH WFD WRP SET 03/06/00 CTD C-1SB SIDETRACK 11 /15/06 008/TLH SQZ'D PERFS PRODUCING 07/29/02 CH/KAK CORRECTIONS 12/15/02 KSB/KK ADPERFS 07/06/05 JLG/TLH ADPERFS PRUDHOE BAY UNR WELL: C-19B PFJi(1AIT No: 2000050 API No: 50-029.20735-02 SEC 19, T11 N, R14E, 664' SNL & 1521' WEL BP ExploraEion (Alaska) 11/28/05 Schlumberger E1VEU NO. 3613 --- t:: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ì ¡J :;'0n~ .:.- " i-'<J;J '- Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 .~~~ ¡J.i~S Cons. COfnm~n ':'J¡d"F)f~e Field: Prudhoe Bay, Milne pt. BL C C Well Job # Log Description Date olor D PSI-07 40009685 OH LDWG EDIT OF MWD/LWD 10/12/03 1 PSI-07 40009685 MD VISION DENSITY 10/12/03 1 PSI-07 40009635 TVD VISION DENSITY 10/12/03 1 PSI-07 40009685 MD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 TVD VISION DEN/NEUTRON 10/12/03 1 PSI-07 40009685 MD VISION SERVICE 10/12/03 1 PSI-07 40009685 TVD VISION SERVICE 10/12/03 1 Z-02A 11132059 USIT 10/06/05 1 S-14A 10987547 USIT 09/13/05 1 Y-1OA 10889216 SCMT 02/21/05 1 D.S. 03-33A 10893093 SCMT 03/05/05 1 C-19B 1092863~ $CMT. :.:2 C)oo05" 05/15/05 1 09-20 10889215 SCMT 02/18/05 1 D.S.09-31C N/A SCMT 11/05/05 1 P-06A 11076455 SCMT 07/29/05 1 2-22A 11084275 SCMT 07/10/05 1 K-20B 11075899 SCMT 07/04/05 1 0.5. 06-20 11062630 USIT 06/14/05 1 C-18A 10621788 SCMT 06/06/04 1 P1-07A 10621778 SCMT 04/21/04 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: \ I l.oc:~ \ 05 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage. AK 99503-2838 ATTN: Beth R"'i'''bJÞ~)u G ~ 5(;ANNEC BEG 1 9 20G5 . , Schlumbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Z-15 I~ð'- fl1h? L5-17A lG·..í -ÀJ.3 DS 04-26 / S r" - J 1"1 S-14A ~1.. \J 4.; - 0" t G-27 / 3"'-1 r <D DS 05-20B ~ t....¡ .- À.3 ~ E-37A :t (¡ ç - (;¡t, 7-.... D-29 I ~.ç- :tYJ i2-28 !~~. r- - c 3 S· C-13A i q 7 - I t_; J OWDw-sw/lJ \ì.-.'¡ 3 y 06-08A 9r-1 q J 12-29 J 8'1 - t,Y.1.. C-19B;ÃG ',:- Ct r G-27 j XI \s - , ç(,¡¡ F-02A ~ V~'- ... C ,-,( c.¡ 03-33B ).ø.ç-6J~ MPK-22 )d.:~')-- C.Â...->-. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 11084273 11075898 11072873 10893047 10942221 10942220 10928640 11084274 11076453 11075900 10893096 11062628 11072867 10928632 10942221 10928630 10913011 10893106 jl Log Description PPROF W/DEFT/GHOST/CALlPER MEM PPROF W/DEFT/GHOST PRODUCTION PROFILE LEAK DETECTION LOG MEM PPROF & IPROF MEM INJECTION LOG MEM PPROF, IPROF & WARMBACK RST RST MCNL RST -BORAX CHANNEL DETECTION LOG RST RST MCNL MCNL MCNL US IT PDC-GR US IT Date 07/08/05 07/03/05 07/30/05 10/17/04 06/29/05 06/26/05 06/14/05 07/09/05 07/27/05 07/05/05 03/24/05 05/17/05 07/07/05 05/12/05 06/29/05 05/08/05 03/19/05 04/20/05 r->t~'!.·· "':,¡,¡'~F>.. ..~~. r F' 2nn'- ·~~AN!v¡FL, .~;!"'D d ,.7 ." í-, ~~..-'tI ;;.. ~ '"' .....~þ/ ":..:-.;1:..: -;,./ i..: - ;J\:''hf ~ ,t~\-- 08/30/05 NO. 3460 aÐO- ooS Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD .---' i 31 J. 3 i 3~.2&(· i 3;.) r í J l..). (¡; j) 1;1 7 J.?lJ...8 j 3 ). 2~1 J ~ Á 3~ 13 l. J i 1",,). J ",1.., -- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99.5.g.3.-2.l38 ...-,'!'!/i¡" .. " A TTN: Beth .,..,..]/ k! /' ì I) /- . / I . Received by: #~'~'"'_u . V: / '\ STATE OF ALASKA '\ ALA.... .A OIL AND GAS CONSERVATION COMI\.._JSION REPORT OF SUNDRY WELL OPERATIONS D D o 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 68.62 KB 8. Property Designation: ADl-028305 11. Present Well Condition Summary: Total Depth measured 12986 true vertical 8947.26 Effective Depth measured 12954 true vertical 8945.5 Casing Conductor Surface Production Liner Liner length 111 2655 10586 580 2840 Size 20"x30" 8 cu yds cmt 13-3/8" 72# l-80 9-5/8" 47# l-80 7" 26# l-80 2-7/8" 6.16# l-80 Perforation depth: Measured depth: 11595 - 11625 12132 - 12222 True Vertical depth: 8907.56 - 8911.51 8918.13 - 8922.64 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations Oil-Bbl 630 688 x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: ~q:n18I1t: r;?]' Stratigap,ic ,D feet feet feet feet MD 34 - 145 33 - 2688 32 - 10618 10149 - 10729 10146 - 12986 11720 - 11730 12267 - 12417 8915.84 - 8915.3 8924.26 - 8933.82 5-1/2" 17# 4-1/2" 12.6# 9-5/8"x 5-1/2" Otis Packer Stimulate D Other D Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 200-0050 6. API Number: 50-029-20735-02-00 9. Well Name and Number: ExpIaatcry SeNce C-19B 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE Oil Pool Plugs (measured) Junk (measured) TVD 34 - 144.99 33 - 2687.19 32 - 8355.91 8020.44 - 8436.98 8018.33 - 8947.26 11795 - 11820 12457 - 12502 8912.58 - 8912.97 8935.08 - 8935.18 l-80 l-80 None None Burst 1490 4930 6870 7240 13450 11850 - 11900 12552 - 12652 8913.61 - 8914.62 8934.05 - 8933.48 32 - 10074 10074 -10217 10074 SCj~NNE['; J~UG 1 7 2005 RBDMS BFL AUG ] 9 1005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 27432 6 0 28251 5 0 15. Well Class after Droposed work: ExpIac.tcry C ~q':} , Silt ¡;¡ 16. Well Status after proposed work: 01 p-. <?as C VVA.G r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signat Form 10-404 Revised 04/2004 GNJC V\ANJ r Collapse 470 2670 4760 5410 13890 12050 -12100 12752 - 12892 8914.76 - 8916.27 8937.14 - 8943.07 Tubing pressure 815 889 SeNce r v\osPL r Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr pQe~jß I N A L Date 8/16/2005 Submit Original Only ) ) C-19B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 7/5/2005 MIRU CTU#5. MU MHA wi memory logging tools in 2.2" carrier. OAL = 12.37'. Pump 150 bbls of meth and 2% KCL to knock down wellhead pressure. RI H. Log at 40 fpm from 11,698' to 11,100'. Paint flag at 11,550'. POOH. Process log data. Tie in to 5-12-05 Schlumberger GR/CCL. 4' depth shift up. Corrected flag at top shot = 11,542.6'. MU MHA with 2" perf guns. RIH. Perforate interval 11 ,595-11 ,625.. POH RD Turn well over DSO JOB Complete... Move to 2-22 fishing operation FLUIDS PUMPED BBLS 37 50/50 meth 130 20/0 KCL 167 TOTAL F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Per[orate _X ADD PERFS Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 69 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 665' FNL, 1521' FEL, Sec. 19, T11 N, R14E, UM (asp's 663841, 5960543) C-19B At top of productive interval 9. Permit number / approval number 1675' FNL, 3042' FEL, Sec. 17, T11N, R14E, UM (asp's 667490, 5964894) ~ 200-005 At effective depth 10. APl number 1401' FNL, 4355' FEL, Sec. 17, T11N, R14E, UM (asp's 666170, 5965139) ~ 50-029-20735-02 At total depth 11. Field / Pool 1387' FNL, 4384' FEL, Sec. 17, T11N, R14E, UM (asp's 666141, 5965152) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 12986 feet Plugs (measured) true vertical 8947 feet Effective depth: measured 12954 feet Junk (measured) true vertical 8945 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 145' 20" 72 c.f. Concrete 183' 183' Surface 2650' 13-3/8" 3720 c.f. Arctic Set II 2688' 2687' Intermediate 10584' 9-5/8" 1190 c.f. AS, 1481 c.f. 10618' 8356' Class 'G' Production 925' 7" 408 c.f. Class 'G' 10149' - 11074' 8021 '-8660' Sidetr~.ck Liner 2840' 2-7/8" 39 c.f. Class 'G' Behind 10146' - 12986' 8018'-8947' Pipe Perforation depth: measured Open Perfs 11795'-11820', 11850'-11900', 12050'-12100', 12180'-12270', 12315'-12465', Open Perfs (cont) 12505'-12550', 12600'-12700'; 12800'-12940'. Sqzd Perfs 11720'-11730'. true vertical Open Parrs 8913'-8913', 8914'-8915', 8915'-8916' 8921 '-8924', 8927'-8935' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 @ 10074'MD. 5-1/2"x4-1/2" XO @ 10074'. 4-1/2" 12.6# L-80 @ 10217' Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" Otis Packer @ 10074'. 5-1/2" Otis SSSV Nipple @ 2144' MD. 13. Stimulation or cement squeeze summary r-~, A~ch0r~ge Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Dailv Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casinq Pressure Tubing Pressure Prior to well operation 12/05/2002 728 23048 9 652 Subsequent to operation 12/18/2002 1244 16035 15 659 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X _Gas __ Suspended __ Service 17~~~o the best of my kn owl ed{]e.SCANNED FEB 0 4 ?.0D3 T~tle: Technical Assistant Date December 20, 2002 DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174~. Form10-404 Rev 06/15/88 o RBDMS BFL ' : '; S ,T,.D PL,OA E < 10/27/2002 11/18/2002 11/24/2002 12/13/2002 12/14/2002 12/15/2002 12/16/2002 12/17/2002 12/18/2002 10/27/02 11/18/02 11/24/02 12/13/O2 12/14/O2 12/15/O2 12/16/02 12/17/02 12/18/02 C-19B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS TESTEVENT --- BOPD: 860, BWPD: 10, MCFPD: 19,209, AL Rate: 0 PERFORATING: DRIFT/TAG TESTEVENT --- BOPD: 803, BWPD: 9, MCFPD: 22,422, AL Rate: 0 PERFORATING: PERFORATING PERFORATING: JEWELRY LOG--DEPTH CONTROL; PERFORATING PERFORATING: PERFORATING PERFORATING: PERFORATING PERFORATING: N2 LIFT TESTEVENT --- BOPD: 1,244, BWPD: 15, MCFPD: 16,035, AL Rate: 0 EVENT SUMMARY TESTEVENT --- BOPD: 860, BWPD: 10, MCFPD: 19,209, AL Rate: 0 DRIFTED DOWN TO 11,579' SLM W/2" DUNNY GUN. HAW. TURNED WELL OVER TO DSO. DSO TO POP WELL. TESTEVENT --- BOPD: 803, BWPD: 9, MCFPD: 22,422, AL Rate: 0 MIRU COIL #5. RIH WITH I 11/16" MHA & PDS GR/CCL. TO 12,200' CTMD, LOGGED AT 40 FPM TO 11,200', POOH. COMPLETED LOGGING RUN, POOH. RIH WITH 25' X 2" GUN SAT DOWN AT 11,716' AND UNABLE TO WORK PAST. POOH. WAIT ON NEW GUNS. RIH W/ 25' X 1.56" HSD, 1606 P J, HMX PERF GUNS. PERF 12, 075 TO 12,100' ALL SHOTS FIRED. MU NEXT SET OF GUNS RIH & PERFORATE 12,050', POOH. ALL SHOTS FIRED. RIH WITH 25' 1.56" HSD, 1606 P J, HMX PERF GUNS. PERF 11,875' TO 11,900', POOH. ALL SHOTS FIRED. CHANGED OUT PACKOFFS, CHAIN INSPECTION, PERFORM WEEKLY BOP TEST. MU NEW MHA (PULL AND PRESSURE TESTED) AND I 11/16" GR/CCL LOGGING TOOL. RIH AND LOGGED FROM 12,200' TO 11,200', POOH. RIH WITH GUN #4 - 25' X 1.56" HSD, 1606 PJ, HMX. PERF 11,850' TO 11,875', POOH. RIH WITH GUN #5, 25' X 1.56" HSD, 1606 P J, HMX PERF GUNS. PERF 11,795' TO 11,820', POOH. RIH WITH GUN #6, 25' X 1.56" HSD, 1606 PJ, HMX. POOH. ALL GUNS FIRED. ATTEMPTED TO BACK FLOW WELL WHILE WAITING FOR N2 PUMPER. BACK FLOW WAS UNSUCCESSFUL. CTU #5 N2 LIFT POST ADD PERF. PUMP 500 SCF/MIN. RHI LIFT FROM 7,000'. PUT WELL IN LP TEST SEPARATOR. MONITOR TO ENSURE UNASSISTED FLOW. RDMO. TESTEVENT --- BOPD: 1,244, BWPD: 15, ivlCFPD: 16,035, AL Rate: 0 SGANNED FEB 0 4:2_003 Page I C-19B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS Fluids Pumped BBLS 1 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL 522 60/40 METHANOL WATER 380 2% KCL WATER 120 DIESEL 229 CRUDE NITROGEN PUMPED --- 8600 SCF. 1252 TOTAL ADD PERFS 12/14-16/2002 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 1.56" HSD 1606 P J, 4-SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 11,795'-11,820' 11,850'-11,900' 12,050'-12,100' Page 2 $C/-~NED FEB 0 ~: 2003 TR~E = 6" McEVOY WELLHEAD = McEVOY SAFETY NOTES: WELL > 70 deg @ 11485' AND GOES ACTUATOR ...................................................................... = OTIS C- t9B HORIZONTAL @ 11700'. KB. ELEV = 68.62' jBF. ELEV = 33.82' == ,., ~..~=..=.. ~ KOP = 3300' DatumMaX Angle :MD= g4@ 11748'11461,j ~]-- - ~ 2144'H5'l~"°T'SS~VN' D=4'502" I Dat u m TV D = 88~'-§'~1 " 'r'~ 2688' H 9-5/8- FocI I 13-3/8" CSG, 72~, L-80, ID = 12.347" H 268S' -J__~ ~ Minimum ID = 2.372" @ 10152' TOP OF 2-7/8" LINER I--i- - mi 9983' H 5-1/2" OTIS XA SUDING SLEEV E, 'D=4.562" ~ 10074''J_J 9-5/8" X 5-1/2" OTIS FKR, ID=3.813" I 3.75"BKRLNRDEPLOYMI~TSLV, ID:3.00" 101J--[~.~~__ il 'J 10134' H 4-1/2" OTIS X NIP' ID : 3'813" I J TOPOF 2 7/8" LINER, ID: 2.372" ~. 10152' ~ -- J 7" eOT LNR HGR 10149' J io19o' H ELIVD 'Fr LOGGED 08/11/83 J 9-5/8"CSG, 47#,L-80,0.0732bpf, ID=8.681"H 10618' J~ · R PERFORATION SUIVNIA RY 7" MLLOUT WINDOW 10729'-10736' EF LOGS: BHCS 06/09/82; SPERRY MWD/GR 02/25/00 TOP OF WHIPSTOCK @ 10736' SWS MEM CNL 04/21/02 NOTE NO RA TAG ANGLEATTOP FERF: 93 @ 11720' Note; Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-1/2' 4 12050 - 12100 O 12115102 2" 4 12180 -12270 0 03105100 Z' 4 12315-12465 0 03/05/00 ~ I ~~ Z' 4 12505 -12550 O 03/05/00 2" 4 12600 -12700 O 03/05/00 J 7" LNR, 26 #, L-80, U4S, ID = 6.276" H 11580' I , · J 2-7/8"LNR, 6. 6#~8bpf, ID:2.37"H 12986' ~ SCANNED FEB 0 & 2003 DATE REV BY COMIVENTS DATE ~ BY COMIVENTS PRUDHOEBAY UNIT 06/14/82 ORIGINAL COMPLETION WELL: C-19B 02/1g/g7 CTD C-19A SIDETRACK PERMIT No: 2000050 03/06/00 CTD C-lgB SIDETRACK APl No: 50-029-20735-02 07/29/02 CH/KAK CORF~CTIONS SEC 19, T11N, R14E, 664' SFL & 1521'WEL 11/01/01 WB/TP SURF LOC CORRECTION 12/15/02 KSB/KK ADPEI~S BP Exploration (Alaska) PERFORATION SUIVNIA RY {EF LOGS: BHCS 06/09/82; SPERRY MWD/GR 02/25/00 SWS MEM CNL 04/21/02 ANGLEATTOP FERF: 93 @ 11720' NOte; Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 11720 - 11730 S 03/03/00 1-1/2' 4 11795 - 11820 O 12/15/02 1-1/2' 4 11850 -11900 O 12/15/02 1-1/2' 4 12050 - 12100 O 12/15/02 2" 4 12180 -12270 O 03~05~00 2" 4 12315 -12465 O 03~05~00 Z' 4 12505 -12550 O 03/05~00 2" 4 12600 -12700 O 03/05/00 2" 4 12800 -12940 O 03/05/00 Permit to Drill No. 2000050 MD 12986 TVD DATA SUBMITTAL COMPLIANCE REPORT 3/21/2002 Well Name/No. PRUDHOE BAY UNIT C-19B Operator BP EXPLORATION (ALASKA) INC 8947 Completion Date 3/6/2000 ~ Completion Status 1-OIL Current Status APl No. 50-029-20735-02-00 1-OIL UIC N REQUIRED INFORMATION Mud Log No -- Samples No Directional Survey~l~lo-~ 7.~'~_ , DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Format Name (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Dataset Scale Media No Start Stop CH Received Number Comments Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / Chips Received? ~Pbbt'~ Analysis Received? Daily History Received? Formation Tops Receuived? Compliance Reviewed By: ~ ..... Date: Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2135 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Usa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 06/06/02 Color Well Job # Log Description Date Blueline Sepia Prints CD D.S. 13-29L1 ~O~-~-O(o(~ 22247 OH EDIT GR,ROP5 04/23/02 1 D.S. 13-29L1 -I 22247 MD VISION RESISTIVITY 04123/02 1 D.S. 13-29L1~ 22247 TVD VISION RESISTIVITY 04/23/02 1 C-19B ~C)D. ~O~ 22224 MCNL 04/21/02 1 1 1 P2-53 l~ ~- ~q I PROD PROF/DE~ 05/17/02 1 E-29 I ~ ~-~ ~ ~ PROD PROFILE 05/27/02 1 ......... S-2~A I ~, ~ J LEAK DETECTION LOG 05115102 1 X-2lA I ~' I O ~ GAS LI~ SURVEY 05/2~02 1 .-~s~ l ff~- !1~. IP.o~ Lo~/~LS os/~s/o~ ~ x-2a I q ~ - Il ~ INJECTION PROFILE 05/26/02 ! D.S. 3-07 J'~ -O~ INJECTION PROFILE 05/23/02 1 ,. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska)Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: RECEIVED JUH 11, 2002 AlaskeOil &GasCons. Cmmaisdon Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Received~~~~.J~ I WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs C- 19B, 1 LDWG formatted Disc with verification listing. API#: 50-029-20735-02 May23,2002 AK-MW-90248 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED 2002 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie HeUsser, Commissioner Tom Maunder, P. I. Supervisor DATE' April 23, 2001 FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit C Pad Monday, Ar~ril 23. _2001' i traveled to BPXs C Pad and witnessed a portion of the . · . 30-day retest of the safety valve systems. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 11 wells and 22 components with 1 failure. The Surface Safety Valve on well C-20B failed to pressure test. This valve is a repeat failure from the previous test. An attempt was made at this time to service the valve but the subsequent retest also failed. This welt was shut in until repairs could be completed. I departed location prior to completion of the testing on this Pad due to a required BOP test on Nabors Rig 9ES. I spoke with Merv Liddelow on the morning of 4-24-01 and he indicated there were no further failures on remainder of the wells tested. Merv Liddelow performed the testing today; he demonstrated good test procedures and was a pleasure to work with. Summary: I witnessed a potion of 30-day SVS testing at BPXs C-Pad. PBU C Pad, 11 wells, 22 components, 1 failure 4.55% failure rate on the witnessed portion of the pad. .A.tt.,ach ..me. n~t; SVS PBU C Pad 4-23-01 CS X. Unclassified Confidential (Unclassified if doc. removed ) SVS PBU C Pad 4-23-01 CS Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Prudhoe / PBU / C Pad Separator psi: LPS 174 HPS 4/23/01 644 i i i I i i I i i ii Weft Permit Separ set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE C-01 1720300 C-02 1730040 C-03A 1981840 644 550 500i P P OIL C-04A 1960920 , C-05 1730110 174 125 100: P P OIL C-06A 1981570 , C-07A 2000520 644 550 520 P P OIL C-08A 1950280 174 125 120 P P OIL · C-09 1790260 , C-1.0 1790350 , C-11 · 1790460 C-12A 1981160 , C-13A 1971430 C-15 1791090 C-16 1800100 , C-17A 1980230 C-18A 1991290 , C-19B 2000050 644 550 525 P P OIL , C-20B 2001140 174 125 110 P OIL C-21 1820810 174 125 115 P P OIL C-22 1820880 644 550 550 P P OIL! C-23A 1961190 C-24 1821410 644 550 525 P P 0IL , C-25A 1950110 644 550 475 P P OIL , C-26A 1981450 C-27A 1961390 , ,, C-28 1821950 C-29A 1961700 C-30 1871360 , C-31A 1950060 , C-33 1930770 C-34 1880150 ,, RJF 1/16/01 Page 1 of 2 SVS PBU C Pad 4-23-01 CS I Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI ,Trip Code Code Code p,as,sed ,GAS ,o,r CYCLE C-35A 1952000 C-36A 2000020 C-37 1930550 " C-38 '' 1860660 ....... C-39' ' 19309~10 '644 '550 500 p ~ P .... OIL C.41 1930990 , , C-42 1930500 , , , }Fells: 11 Components: 22 Failures: 1 Failure Rate: 4.55% ['-'! 90 Day Remarks: S .uffa, .,ce ,Safety Valve on Well C-20B failed when. p,r. essure tested. Retest after. valve serviced ~ failed.,,w..ell: ,was shu, t. in, pendig, g r,e.p~. . .... Tiffs,' is a part[a! pad test. , RJF 1/16/01 Page 2 of 2 SVS PBU C Pad 4-23-01 CS MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, ~, ~,~'~0\ DATE' March 23, 2001 Commissioner Tom Maunder, ~ P. I. Supervisor o~/o~-(:3 I, FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests PBF/PBU C Pad Mar.ch 23, 200.1: ! traveled to Prudhoe Bay Field to witness Safety Valve System tests on BPX's C Pad. Well house inspections were also conducted. Merv Liddelow was the BPX representative in charge of testing, and performed the tests in a professional manner. Twenty-one wells on C-Pad were tested with five failures witnessed. The SSV on well C-04A tripped below 50% of the separator psi, the SSV on well C-07A failed to hold D/P, the pilot on well C-19B was frozen, the pilot on well C-20B failed to trip and the SSV failed to hold D/P. Mr. Liddelow indicated to me that all failures were repaired within 24 hours. I inspected 21 well houses and noted leaking wing valves on wells C-03A, C-13A and C-19B. A hydraulic fluid leak on the SSV control line of well C-05 and a slight crude oil leak from the SSV on well C-25A were also noted. Mr. Liddelow indicated he would have these items corrected. The AOGCC test forms are attached for reference. SUMMARY: I witnessed the SVS tests on twenty-one oil producing wells on C Pad in the Prudhoe Bay Field. 21 wells tested 42 components, 5 failures witnessed, and 11.9% failure rate. 21 well houses inspected. A,tt.achments: SVS PBU C-Pad 3-23-01 JJ cc: SVS PBU C Pad 3-23-01 JJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBF/PBU/C Pad Separator psi: LPS 174 Date: 3/23/01 HPS 662 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PS! Trip Code Code Code Passed GAS or CYCLe: C-ol 1720300 :c-02 " 17'30040 662 550 '525 P" P ..... OIL :~-03A "' 1981840 ' 662 550 530 ' P P .... OiL C-04A "' 1960920 '662 ' 550 ' ' 220 ' 3 P ' ' OIL C-05 1730'1j0 ' 174 125 115 P P ' " OIL, C-06A 1981570 662 550 580 P P ' ' OIL C-07A ' 20005'20 662 550[ 545 " P ' 4 ...... OIL C-08A 1950280 C-09 1790260 C-10 1790350 ' C-11" 1790460 662: 550 ..... 595'' P" P OIL C-12A 1981160 C-13A 1971430 662 550 590 ' P -P oIL C-15 1791090 C. 16' 1800100 ................. i2-'i7A' '1980230" ' 662 550 580 P 1~ ....... OIL ~z!.gA ............. ~.~19~}1290'i ............... ~ ~0'00050 662 550 250 '2 P ..... OIL C-20B 20011401 '662 550 0 1 4 ....... OIL C-21 "1820810 174 " 125 120 P ~ OIL C-22 1820880' '662 ' 550 560 P 'P ' " 0IL C-23A 1961190 C-24 182i410 662' '550 545 'P P .... OIL C-25A ' '1950110 662 .... 550 510 'P P 0IL C-26A 198'1450 ............ , , , C-27A '1961390 C-28 1821950 'C-29A 1961700 ..... (~-30 '' '1871360 662 '550l 525 P ' P 0IL C'-31A 1950060 662 550 ' 560 P' 'P .......... oiJ~ c-33 ' 193077~) .... ic-3 1880150 C-35A 1955000 i74 120 "P P .... oIL "C'56A 2000020"' 174 12~ .... 115 'p 'p .... OIL RJF 1/16/01 Page 1 of 2 SVS PBU C Pad 3-23-01 JJ1 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code , Code , Code , Passed GAS or C.¥CLW ~C-3'] 1930550 662 550 550 P P OIL , , , , C-38 1860660 , C-39 1930940 C-41 1930990 C-42 '193'0500 '662 ' 5~0 590 P " P ' OIL }Yells: 21 Components: 42 Failures: 5 Failure Rate: 11.90o/~10o Day Remarks: Op,erator reports all failures re. paired and passed retest. , RJF 1/16/01 Page 2 of 2 SVS PBU C Pad 3-23-01 JJ1 r ~ STATE OF ALASKA ALAS~'''~ OIL AND GAS CONSERVATION COIv''vIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. staias of Well ..... Classificaiion of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator !~~ 7. Permit Number BP Exploration (Alaska) Inc. V~,I{~. ! 200-005 3. Address ~k~,_ l~:H,~;~.. !:'~~~ 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20735-02 4. Location of well at sudace u~i?~ ::.~ ~;.~'~.; 9. Unit or Lease Name 664' SNL, 1521' WEL, SEC. 19, T11N, R14E, UM ~ ~'~7~,.~ ~ Prudhoe Bay Unit 38~3' ~Sk, 870' fiWk, S[G. 17, 111 ~, B14[, OM ....... ~ .......... ~2~'~ 11. Fiold and ~o0'i ............. 5. filovation in foot (indicato KB, ~F, otc.) ~. keaso ~osi~nation and Sorial ~o. ~rudhoo Bag Fiold / ~rudhoo Bay ~ool KBfi = ~8.~2' ADk 028305 ota, opth ao. ackbopt, ao.'D,ro i0n , Sumov 12o. oPt, w,oro sssv sot12a. ",ckn0 S orma roSt 12~8~ 8047 F~I 12054 8045 F~I ......... ~ Yos ~ ~oI (~ipplo) 2144' MDI 1000' (Approx.) 22. Typo filoctdc or Othor ko~s Bun MWD, G~ 23. G~s~o, k~[~ ~ C[~[~,~o ~fico~ ..... CASING SE~ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOSOM S~ZE CEMENTING RECORD AMOUNT PULLED 20"X 30" InSulated ConduCtor sU~ace i45' 36" 8 cu yds Concrete 13-3/8" 72ff L-80 38' 2688' 17-1/2" 3720 cu ~ Arctic Set II 9-5/8" 47ff L-80 ~' 10618' 12-1/4" 1190 cu .fl AS, 1481 cu ft Class 'G' 7" 26ff L-80 10149' '~"1074; ....... ~-1/2" 408 cu ~ Class '~' ' .... 2-7/8" 6.16ff L-80 i0146' 12986' 3-3/4" 39 cu E Class 'G' Behind Pipe (Appr~'~.) " 24. Peal°rations open to Production (MD+TVD of Top and 2'5. TUBING RECORD BoSom and inte~al, size and number) SIZE . DEPTH SET (MD) PACKER SET (MD) ..... 2" Gun Diameter, 4 spf 5-~'/2", 1'~, L-8'~' 10050' MD TVD MD TVD ~'1/2"' T~ilpip~ "' 10190' 1 °o 74' 11720'- 11730' 8916' - 8915 ........ 12180' - 12270' 8921' - 8924' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 12315' - 12465' 8927' - 8935' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12505' - 12550' 8935' - 8934' 11720' - 11730' (Peal'd) For Remedial Cmt Sqz for 2-7/8" Liner 12600' - 12700' 8933' - 8935' 12800' - 12940' 8940' - 8945' "27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 22, 2000 Flowing "~ate'~"'~est Hours Tested ' .p~'~'~UCTi0~'FOR '" OiL.B~'~ .... GAS.MCF WATE~-BBL CHOKE SIZE I'GAS'OIL RATIO .... TEST PERIOD I Flow Tubing Casing Pressure '" CALcutTa'"' OIL-BBL GAs-M'~F WA~ER-BBL O~L CRAWl-APl (CORR) Press. 24-Hour RATE ..... ~8.. ...... ' ............... CORE"~ATA .... ' ....... Brief description of lithology, 'porosity, fractures, apparent dips and presence of oil, gas or wa'{er. Submit core chips'. RECEIVED ' 0 000 ....... Form 10-407 Rev. 07-01-80 Submit In Duplicate 30. 29. Geologic Markers Formation Tests , Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. , , Top of Sadlerochit 10767' 8464' 44N 10807' 8490' 44P 10815' 8496' 43N & 43P 10851' 8519' 42N 10900" 8551' 42P 10907' 8556' 41N 10929' 8570' 41P 10931' 8571' Top of Zone 3 11007' 8620' Top of Zone 2C 11136' 8696' 24N 11243' 8757' 24P 11271' 8773' 22N 11326' 8805' 22P 11331' 8807' Top of Zone lB 11451' ~' RECEIVED Top of Zone lA 11672' 8915' ~ ~ 30 ?_000 Ataska Oil & Gas Cons. Comm'~ssi°n Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,~j~~ (ll~j..~~:~ Title Technical Assistant III Date 03'~O' O(~ C-19B 200-005 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No ..... ...... INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: C-19B Accept: 02/13/00 Field: Prudhoe Bay Spud: 02/15/00 APl: 50-029-20735-02 Release: 03/06/00 Permit: 200-005 CTD Unit: Nordic #1 02/14/00 1 Accept rig on C-19b at 06:00 hrs 2/13/00. Test BOPE 250/4000 psi - no failures. MU GS spear and BHA #1. RIH to 9000 feet displacing freeze protection diesel from well. Outside green tank full with freeze protect diesel/seawater. SD and order out vac truck to empty green tank. Clean tank & cont RIH with GS spear to fish at 10,074 ft. Latch fish and pick up clean. POOH with 2 7/8" liner. Lay out 22 2/3 jts of recovered liner. Clean chemical cut on bottom of liner, liner very clean, no sign of cement, no corrosion. Rig up SWS E-line unit to run Baker Whipstock. Calibrate toolface indicator on catwalk. RIH with whipstock and setting tool on E-Line. Sat down with 3 5/8" OD whipstock assembly at 10,692 and 10,700 ft. Overpull picking up. Apparent cement sheath from 2 7/8" liner cement job. POOH with whipstock. Lay out whipstock and rig back SWS E-line unit. M/U Baker 6" underreamer and HP motor. RIH with underreamer BHA to cleanout cement sheath in liner. 02/15/00 2 10746' RIH with underreamer to 10250'. Underream in 7" liner to 10740'. SD pump and tag up on 2 7/8" liner stub. Correct depth to 10760'. Make 2 passes with underreamer 10755'-10650' pumping 2 FIoPro sweeps to clean hole. Got back some fines and balls of cement. Drop ball and pump down to open circ sub. POH circulating at 2.8 BPM to clean hole. OOH. LD underreamer. Stand back injector head. RU SWS E-Line. PJSM. MU whipstock on setting tool. RIH with whipstock on E line. Tie in to CBL/GR (- 2.5'). Run in and PU to setting depth. Set whipstock. Top @ 10726'. Orientation - 14 deg Left of highside. POOH. R/D SWS. M/U 3.8" window milling BHA #3. RIH with tandem 3.8" diamond mill and 3.8" string reamer on BHI, HP motor. Tag whipstock and correct CTD to 10,729 ft. Mill window at 2 FPH from 10729 - 10736 ft. Drill formation from 10736 - 10746 ft. Ream window area from 10726 - 10746 ft, ream up and down four times. Clean window. 02/16/00 3 11055' Back ream window. POH. MU parabolic mill and long string reamer. RIH and correct to flag (-35'). Run thru window dry and tag bottom. Ream window and had I stall. Work up and down thru window twice without pump - no problems. Window appears clean. Displace well to FIoPro mud. Lay out milling / reaming BHA. M/U drilling BHA #5. RIH with BHA #5. Shallow test MWD / orientor. RIH to window. Orient highside to get thru window. Tag bottom and correct depth. Drill ahead to 10761 '. Cannot get clicks with orienter. Pull up above window - still no clicks. SD pump at 10700' to get static PWD pressure data point. POH. Change out orienter to non locking version. LD shock sub - seal failure & no replacement tool available. RIH. Shallow test tools - OK. RIH to window. Orient highside and go thru window. Orient to 90L. Tag bottom & drill ahead to 11005'. Wiper trip up to window. 02/17/00 4 11172' Drill Zone 3 from 11,005 - 11,033 ft. Trip to window. Tied-in with CBL/GR, added 6 ft to CTD. Flagged CT. POOH. C/O bit. RIH with BHA #7. Stop at 6750 ft. Rig down time. Reel drive planetary gears failed. Replaced gears and drive motor on reel stand. Repairs complete at 19:30 hrs. RIH & correct depth to 10704' bit depth. Orient highside and go thru window. RIH to bottom. Drill ahead in Zone 3. Several stalls 11050-55' - somewhat better below that. Continue drilling ahead to 11172' (in to Top Zone 2). POH for new bit. RECEIVED .... '-,?: 2000 Alaska Oil & Gas Coos. Commission C-19B, Coil Tubing Drilling Page 2 --'RECEIVED 2000 Alaska 0ii & Gas Cons. Commission 02/18/00 5 11565' ,AllChOrage Tied-in with CBL/GR, added 2 ft to CTD. Flag CT. POOH. Download PWD and MWD data, Change motor and Bit. RIH with drilling BHA if 8, [1.37 deg motor and DS49 Bit if3RR]. Correct depth to flag at 10,706 ft. RIH. Orient TF and drill from 11,172 - 11,310 ft. Orient TF to left side and drill 11,310 - 11386 ft. Shod trip to window. RIH. Orient and drill to 11442'. 100' wiper trip to clean up hole - starting to stack out more weight. ROP dropped to 10 fph. Orient & drill ahead - ROP increased back up to 150 fph. Drill ahead to 11541 '. Not building angle fast enough to land well on target. Have already drilled into (possibly thru) 14N shale. POH for 1.75 deg shod radius motor. Will swap mud out to 9.2 ppg system when back on bottom. OOH. Change bit, motor. RIH with BHA ¢9. Run thru window & tag bottom. Orient for build & drill ahead to 11565'. 02/19/00 6 11794' Drill from 11565 - 11613 ft. Orient TF. Drill to 11665 ft. Landed well at 11630 ft at 8865 ft TVDSS. Stacking weight / stalls on junk in hole. Orient TF. Drill to 11680 ft with stacking wt and stall problems. Short trip to window. Tied-in with GR and added 3 ft to CTD. RIH. Orientor rolled on bottom after a stall. Orient TF. Drilled to 11744 ft with several stalls. Made a 200 ft shod trip. Drilled to 11791 ft. POOH to plug back well. Lay out drilling BHA. M/U cementing BHA. RIH. Tag bottom. POH to window. Safety meeting. Batch mix 14 bbl cement @ 17.0 ppg. Test lines to 4000 psi. Stage cement to coil while RIH to bottom. Displace cement to nozzle. Displace cement to annulus while POH at 1:1. POH to 10550' - WCTOC 10766'. Circ down to WCTOC - full returns. Contaminate cement down to 11160' & POH chasing contaminated cement out of hole. LD cementing BHA. WOC prior to PU drilling BHA. 02/20/00 7 11673' WOC. MU drilling BHA if11 & bit #5. RIH to 10600'. Correct (-35'). DS cement sample at 4500 psi comp strength. Tie in to CBL/GR - Corr'n (+6'). Ream down to top of plug at 11166'. Orient and drill down to 11180' - 2 stalls. Good plug. Stad sidetrack. Drill to 11240'. Appears to be hard cement. Drill to 11351' @ 60-100 fph - TF @ 75-105L. Shod trip to window. RIH. Orient and drill to 11435'. Orient around for 80-90 L. Drill to 11155'. Trip to window to clean up hole. RIH. Drill to 11615'. Lost orientation. Pull up hole and orient. Drill ahead - slow in shale. Bit may be balled up or hole needs cleaning. Shod trip to window. RIH. Attempt to drill - no progress. POH to assess possible causes. LD BHA. Test BOPE. Witness of test waived by AOGCC Rep J. Crisp. Prep for mud swap when back on bottom. 02/21/00 8 12432' Complete weekly BOPE test. Fax repod to AOGCC. Safety Meeting. Cut off 200 ft of CT. M/U Drilling BHA If12 with 1.04 degree motor and DS49 Bit If6. RIH. Tied-in with CBL/GR, [-30.5 ft CTD]. RIH to TD. Orient TF. Drilled horizontal hole from 11,673 - 11,893 ft. Short trip to window. Hole in good condition. Orient left and drill ahead to 11940' - ROP 135 fph. Orient around for 90+L and drill ahead to 12100'. Wiper trip up to window - hole condition good. RIH. Drill ahead orienting to hold 87 deg inclination. Drill to 12275'. Angle building above 88 deg. Make wiper trip to window & get clicks. RIH. Finish orienting. Drill ahead. 02/22/00 9 12461' Drilled to 12435 ft. Oriented to right. Drilled to 12461 ft. Shod trip to window. Bit stuck at 12,280 ft. Work free going down. RIH 100 ft and back ream slow. Ream thru stuck point with minimal motor work. Continue wiper trip to window. Generator if2 overheated and shut down. Pump down for 5 minutes. Stad pump and had stall pressure. Pull up and stuck. RIH. No pipe movement. Work pipe 0-60K up/down. No luck. Circulate while wait on crude. Pump 20 BBLS crude. Spot 10 bbls crude out bit. C-19B, Coil Tubing Drilling Page 3 Soak. Work CT up/down [-10 to +80K]. Hold 80K and let crude soak. Safety Meeting. Pump steel ball for DS hyd. Disconnect. Released at 5600 psi. Pulled CT free at 48K [free up wt -- 33K]. Circulate new FIoPro on top of fish at 12,048 ft. POOH while circulate new FIoPro at 3.1 BPM. Blow down reel at surface with N2 & bleed off N2 pressure thru gas buster. Spool coil back on to reel & clamp off same. Hold safety meeting. Swap out reels. Hook up hard line and stab pipe thru injector. Install packoff and MU coil connector - pull test to 30klbs. Pump dart thru coil. Rig up to PU fishing tools. 02/23/00 10 12461' M/U Baker fishing BHA with GS Spear, Dailey Jars, 6 DC's and Accelerator. RIH with Fishing BHA #13. RIH and latched onto fish at 12,060 ft CTD. Jarred down 57 times with no movement of fish. Spotted crude oil around fish and jarred down 53 times with no movement. Release from fish. POOH for CT fatigue management. Cut off 200' CT, LD 2 Drill Collars. TIH, tag up and latch fish. Jar down-no movement. Jar up--appeared to move fish 8' uphole. May be stretch in new CT. 02/24/00 11 12901' Worked fish free by moving downhole 30'. Work fish up hole past tite spot. POOH with fish. LD fishing BHA. LD fish-no marks to indicate stuck point or problem. MU new drilling tools. RIH with BHA #15 (1.0° motor). Precautionary ream to TD and had clean hole. Drill from 12461-12611' and had trouble dropping angle. Wiper to window. Tie-in, correct depth (+8'). Drill and short trip every 150'. Differential stuck at 12901 '. Work pipe and wait on dead crude oil. 02/25/00 12 12986' Continue to work stuck BHA. Pump 20 bbls dead crude and came free. Wiper to window. Tie-in, add 13.0'. RIH reaming. Couldn't get past shale at 12550'. Swap to new FIo Pro mud at 9.2 ppg. Work thru shale area 12500-600' and next shale 12700-800'. Wash to bottom. Drill ahead to 12971 '. Short trip to window. GR log for correlation, correct depth (+8'). TIH, drill to 12986', POOH, LD Drilling BHA 02/26/00 13 12986' LD drilling BHA. MU 88 jts 2-7/8" 6.16# L-80 STL liner. MU Baker CTLRT. RIH with liner on CT to TD at 12986'. Release from liner. Displace mud to 2% KCI water. DS cementers load CT with 25 bbls 15.8 ppg G cement with latex. Load wiper dart. Displace dart with rig 2% KCI water to liner wiper plug. Could not shear LWP. Unsting from liner. POOH for milling assy. OOH, inspect CTLRT. Shear screws sheared, Liner Wiper Plug gone. PU 2.25" mill and 1.69" motor. TIH, tag up at 10165' uncorrected depth, probably top of liner. Work down to 10168' uncorrected, stalling. Mill on cement and plug. 02/27/00 14 12986' Mill on wiper dart and cement at TOL with little progress. POOH. Standback CSH workstring. LD motor and mill. MU 3.73" mill and 2-7/8" motor. RIH on CT to TOL, clean. Mill up wiper dart and verify tubing tail clean to TOL. POOH. LD mill and motor. MU 2.25" mill on 2-1/8" motor. RIH on 20 stds CSH. RIH with CT to TOL. Mill cement, pump sweeps. Frequent short trips to liner top. 02/28/00 15 12986' Continue milling cement in liner from 10615-11151' at approximately 50'/hr with occasional wiper trips to TOL. POOH to change motor and mill. Test BOP-weekly test. Witness waived by Lew Grimaldi- AOGCC. PU new mill, motor, and hydraulic dis-connect. TIH, mill on cement. RECEIVED 2000 Alaska Oil & Gas Cons. Commissiort Anchorage C-19B, Coil Tubing Drilling Page 4 02/29/00 16 12986' Continue milling cement in 2-7/8" liner from 11220-400'. Wiper to liner lap. Test liner lap with fresh water across lap at 2160 psi and lost 60 psi in 10 minutes. Mill cement from 11400-540' and ROP slowed. POOH for mill and motor. Stand back CSH work string. Change out complete BHA for new tools. TIH, did not tag up at 11540'. Wash in hole and tag up at 11611 '. Could get very little motor work, finally broke thru. Wash in hole, appeared to be pushing something. Wash in hole at 150+ ft/hr with very little motor work. Wash to 11875', POOH for more 1 ~,~" CS Hydril. 03/01/00 17 12986' POOH and PU more CSH workstring. RIH with cement mill. Mill cement to 11800'. Displace hole to 2% KCI water. POOH. Pressure annulus to 1200 psi. Pressure test well to 3000 psi. Lost 20 psi in 5 min. MU 10' perf gun (SWS 2" powerjet). RIH. Tag debris at 11323' CTM (57 deg). Overpull. Repeat tags. No progress. POOH. 03/02/00 18 12986' POOH for cleanout assembly. LD perf gun. RIH with nozzle. Wash to 11,790' with hi-vis sweeps. POOH. MU 10' perf gun (2" P J, 4SPF, 60 deg). RIH. Drop ball and perforate 11720' - 11730'. POOH. LD gun. Est injection at 0.5 BPM; 3000 psi. RIH with cement nozzle. 03/03/00 19 12986' RIH with nozzle. Bullhead 11 bb115% HCI into the 10' of perfs. Injectivity improved from 0.6 BPM; 2950 psi WHP to 1.5 BPM; 1000 psi WHP. Mix and pump 13 bbls 15.8 ppg latex cement. Squeeze perfs to 3000 psi and lay in remaining cement (perfs took about 3 bbls). Wash excess cement to 11600', pumping hi-vis sweeps. Pressure back up to 3000 psi to verify squeeze is holding. POOH. MU motor and mill for cement cleanout. RIH. Tag hard cement 10680'. Mill cement to 11560'. 03/04/00 20 12986' Mill/wash cement to 11,800'. Pressure test squeeze perfs to 1500 psi. Lost 65 psi in 5 min. Mill cement 11,800' - 12,900'. 03/05/00 21 12954' Mill cement to latch collar at 12954'. Wash liner. Lay in 150k LSRV FIo-Pro. POOH. MU SWS perf guns. RIH to latch collar, correct depth, position guns, drop ball and perforate. POOH. LD guns. Perforated the following with 2", P J, 4 SPF, 60 deg guns: 12180' - 12270', 12315' - 12465', 12505' - 12550', 12600' - 12700', 12800' - 12940'. 03/06/00 22 12954' Load out perf guns. All guns fired. PU nozzle. RIH to 6500'MD and nitrogen lift well 550 SCF/min to LDF and test separator. Final test numbers 3200 BFPD; 3.0 MMSCFD; WC 55% and falling. POOH. Leave 600 psi nitrogen cap on well. Pressure test and service tree valves. Load methanol in tree above master valve. ND BOPE. NU tree cap and pressure test. RDMO. Release rig 02:00 hrs 3/6/00. RECEIVED ,,,,-,r. 2000 Alaska Oil & Gas Co~s, Commission Anchorage 8200 8300 -+- 8400 -4'-- ~ 8500 8600 Cf~ 8700 --~ t-- 8800 I V 8900 B.P. Exploration {True} Structure : Pad C Field : Prudhoe Boy Well : C-19B, 50-029-20735-02 Location : North Slope, Alaska East (feet) -> CreeLed by potnls DeLe plotted : tO-Mar-2000 PLot Reference is C-19B. Coordinates ere in feet reference C-19. True Vertlcel Depths ore reference RK~I - I~SL = 68.6 ft. Brij Potnis 267-6613 --- Baker Hughel INT£Q --- 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700. 3800 3900 4000 4100 4200 4300 I I I I I I I t I I 1 I I I I I I I I I I I ? I I 1 I I I I I I I I I I I I I I I I I C-19B CeeB105 Plan Projected to TD Tie-in Point RECEIVED ' aka Oil & Co s. Comm/s n An orage Point Projected to TD Projected to TD Projected~ 48OO 4700 4600 4500 4400 4300 4200 4100 4000 3900 3800 3700 3600 A I Z O 9000 i i i i i I ~ [ i i I i i i ~ i i i i t ~ i i i i i i i i i i i i i i i i i t i i t 200 1 O0 0 1 O0 200 300 400 500 600 700 800 9 O0 1000 11 O0 1200 1300 1400 1500 1600 1700 i800 1900 Vertical Secfion (feet) -> Azimuth 304.00 with reference 3716.52 N, 3725.39 E from C-19 B.P. Exploration (True) Pad C C-19BPB1 C-19 Prudhoe Bay North Slope, Alaska SURVEy L I STING by Baker Hughes INTEQ Your ref : C-19BPB1 Our ref : svy308 License : 50-029-20735_70 Date printed : 10-Mar-2000 Date created : 10-Mar-2000 Last revised : 10-Mar-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 665344.787,5961240.589,999.00000,N Slot location is n70 17 54.790,w148 40 23.075 Slot Grid coordinates are N 5960543.990, E 663841.000 S10t local coordinates are 663.39 S 1518.86 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED t $0 000 Alaska Oil & Gas Cons. Commi$~n Anchorage B.P. Exploration (True) Pad C,C-19BPB1 Prudhoe Bay,North Slope, Alaska Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth RECTANG COORDIN 10700.00 43.05 52.30 8347.17 10725.00 42.95 52.25 8365.46 10756.93 45.91 44.08 8388.27 10791.91 48.74 35.70 8412.01 10832.98 50.04 26.72 8438.77 3716.52N 3726.95N 3741.87N 3761.59N 3788.22N 10864.83 49.04 27.39 8459.44 10900.73 49.13 18.25 8482.98 10935.73 49.75 8.76 8505.77 10984.56 50.45 356.28 8537.16 11031.55 53.88 347.84 8566.01 3809.80N 3834.76N 3860.56N 3897.85N 3934.53N 11063.36 53.44 345.56 8584.86 11106.33 54.67 1.02 8610.19 11136.71 54.23 3.66 8627.85 11156.53 54.51 8.99 8639.40 11187.20 55.28 14.91 8657.05 3959.47N 3993.84N 4018.54N 4034.54N 4059.07N 11221.38 56.25 21.42 8676.30 4085.89N 11254.20 56.51 26.16 8694.47 4110.88N 11285.70 54.84 31.08 8712.24 4133.71N 11321.90 51.86 32.67 8733.85 4158.38N 11354.40 51.77 24.58 8753.96 4180.77N 11392.92 55.19 17.55 8776.90 11422.80 58.27 13.33 8793.30 11452.02 60.80 7.88 8808.12 11490.90 60.03 1.02 8827.33 11521.49 64.60 356.10 8841.55 4209.63N 4233.71N 4258.45N 4292.13N 4319.19N 11558.71 73.04 352.41 8854.99 11591.19 -80.77 351.53 8862.34 11624.09 88.77 347.84 8865.34 11659.04 95.01 341.86 8864.18 11691.74 94.83 335.89 8861.38 4353.68N 4384.98N 4417.18N 4450.86N 4481.24N 11720.49 91.85 329.74 8859.70 11754.09 92.64 320.42 8858.38 11771.04 94.22 316.73 8857.37 11791.00 94.22 316.73 8855.90 4506.75N 4534.25N 4546.94N 4561.43N SURVEY LISTING Page 1 Your ref : C-19BPB1 Last revised : 10-Mar-2000 U L A R Dogleg Vert G R I D C O O R D S A T E S Deg/100ft Sect Easting Northing' 3725.39E 0.30 0.00 667483.45 5964341.33 3738.87E 0.42 -5.35 667496.71 5964352.05 3755.47E 20.15 -10.77 667512.97 5964367.32 3771.90E 19.37 -13.36 667528.96 5964387.40 3788.00E 16.89 -11.82 667544.47 5964414.38 3799.03E 3.52 -8.89 667555.02 5964436.20 3809.53E 19.23 -3.64 667564.96 5964461.38 3815.71E 20.67 5.66 667570.58 5964487.31 3817.33E 19.64 25.17 667571.38 5964524.62 3812.15E 15.94 49.98 667565.39 5964561.18 3806.26E 5.94 68.81 667558.96 5964585.97 3802.25E 29.24 91.35 667554.19 5964620.25 3803.26E 7.22 104.33 667554.66 5964644.96 3805.03E 21.90 111.80 667556.08 5964660.99 3810.23E 15.99 121.21 667560.73 5964685.63 3819.04E 16.00 128.90 667568.95 5964712.64 3830.06E 12.05 133.74 667579.42 5964737.87 3942.51E 13.94 136.19 667591.36 5964760.96 3857.84E 8.95 137.28 667606.14 5964785.96 3870.06E 19.56 139.67 667617.86 5964808.61 3881.13E 17.14 146.63 667628.30 5964837.71 3887.76E 15.67 154.59 667634.40 5964861.92 3892.38E 18.26 164.60 667638.47 5964886.76 3895.01E 15.47 181.25 667640.36 5964920.48 3894.30E 20.64 196.97 667639.06 5964947.52 3890.80E 24.48 219.16 667634.80 5964981.92 3886.38E 23.94 240.33 667629.69 5965013.12 3880.51E 26.75 263.20 667623.12 5965045.18 3871.40E 24.72 289.59 667613.26 5965078.65 3859.66E 18.20 316.31 667600.86 5965108.76 3846.55E 23.74 341.44 667587.20 5965133.98 3827.36E 27.82 372.73 667567.40 5965161.05 3816.16E 23.65 389.11 667555.93 5965173.48 3802.52E 0.00 408.52 667541.97 5965187.67 RECEIVED 000 Alaska Oil & Gas Cons. CommOn Anchorage All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from C-19 and SSTVD from RKB - MSL = 68.6 ft. Bottom hole distance is 5938.50 on azimuth 39.82 degrees from wellhead. Vertical section is from tie at N 3716.52 E 3725.39 on azimuth 304.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computedusing the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad C,C~19BPB1 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : C-19BPB1 Last revised : 10-Mar-2000 Comments in wellpath MD SSTVD Rectangular Coords. Comment 10700.00 8347.17 3716.52N 11791.00 8855.90 4561.43N 3725.39E Tie-in Point 3802.52E Projected to TD NO Targets associated with this wellpath RECEIVED :- ~0 2000 ~a Oil ~, Gas Co~s. Commi~ion Anchorage B.P. Exploration (True) Pad C C-19B C-19 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : C-19B Our ref : svy310 License : 50-029-20735-02 Date printed : 10-Mar-2000 Date created : 10-Mar-2000 Last revised : 10-Mar-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 665344.787,5961240.589,999.00000,N Slot location is n70 17 54.790,w148 40 23.075 Slot Grid coordinates are N 5960543.990, E 663841.000 Slot local coordinates are 663.39 S 1518.86 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED UAR 000 Alaska Oil & Gas Cons. Commission Anchorage B.P. Exploration (True) Pad C,C-19B Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 1 Your ref : C-19B Last revised : 10-Mar-2000 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing' 10700.00 43.05 52.30 8347.17 3716.52N 3725.39E 0.30 0.00 667483.45 5964341.33 10725.00 42.95 52.25 8365.46 3726.95N 3738.87E 0.42 -5.35 667496.71 5964352.05 10756.93 45.91 44.08 8388.27 3741.87N 3755.47E 20.15 -10.77 667512.97 5964367.32 10791.91 48.74 35.70 8412.01 3761.59N 3771.90E 19.37 -13.36 667528.96 5964387.40 10832.98 50.04 26.72 8438.77 3788.22N 3788.00E 16.89 -11.82 667544.47 5964414.38 10864.83 49.04 27.39 8459.44 3809.80N 3799.03E 3.52 -8.89 667555.02 5964436.20 10900.73 49.13 18.25 8482.98 3834.76N 3809.53E 19.23 -3.64 667564.96 5964461.38 10935.73 49.75 8.76 8505.77 3860.56N 3815.71E 20.67 5.66 667570.58 5964487.31 10984.56 50.45 356.28 8537.16 3897.85N 3817.33E 19.64 25.17 667571.38 5964524.62 11031.55 53.88 347.84 8566.01 3934.53N 3812.15E 15.94 49.98 667565.39 5964561.18 11063.36 53.44 345.56 8584.86 3959.47N 3806.26E 5.94 68.81 667558.96 5964585.97 11106.33 54.67 1.02 8610.19 3993.84N 3802.25E 29.24 91.35 667554.19 5964620.25 11136.71 54.23 3.66 8627.85 4018.54N 3803.26E 7.22 104.33 667554.66 5964644.96 11156.53 54.51 .8.99 8639.40 4034.54N 3805.03E 21.90 111.80 667556.08 5964660.99 11180.00 55.07 13.53 8652.94 4053.34N 3808.78E 15.98 119.21 667559.41 5964679.87 11209.80 55.72 7.70 8669.87 4077.43N 3813.29E 16.25 128.94 667563.39 5964704.05 11247.17 55.46 359.97 8691.01 4108.15N 3815.35E 17.08 144.41 667564.77 5964734.81 11279.63 54.05 352.41 8709.76 4134.57N 3813.61E 19.50 160.63 667562.45 5964761.19 11312.42 55.99 345.91 8728.58 4160.93N 3808.54E 17.28 179.57 667556.81 5964787.42 11355.65 57.39 340.11 8752.33 4195.45N 3797.98E 11.67 207.63 667545.49 5964821.70 11393.58 59.06 333.08 8772.32 4225.01N 3785.17E 16.36 234.78 667532.03 5964850.97 11423.60 64.34 329.91 8786.55 4248.21N 3772.54E 19.89 258.22 667518.90 5964873.89 11454.25 68.29 325.52 8798.87 4271.92N 3757.55E 18.39 283.92 667503.38 5964897.26 11484.67 71.19 319.89 8809.41 4294.60N 3740.25E 19.80 310.93 667485.60 5964919.55 11519.60 71.89 314.27 8820.47 4318.85N 3717.70E 15.39 343.19 667462.52 5964943.30 11556.00 74.79 307.76 8830.92 4341.71N 3691.40E 18.89 377.78 667435.72 5964965.57 11588.78 80.42 304.77 8837.95 4360.63N 3665.59E 19.35 409.75 667409.50 5964983.92 11625.60 83.93 300.03 8842.97 4380.16N 3634.80E 15.92 446.20 667378.30 5965002.76 11661.91 85.43 293.17 8846.34 4396.34N 3602.50E 19.26 482.03 667345.64 5965018.22 11692.66 89.12 290.01 8847.80 4407.63N 3573.94E 15.79 512.02 667316.85 5965028.89 11715.99 92.72 292.47 8847.43 4416.08N 3552.21E 18.69 534.76 667294.93 5965036.86 11747.71 94.04 297.57 8845.55 4429.47N 3523.52E 16.58 566.03 667265.97 5965049.61 11778.71 91.23 301.96 8844.13 4444.84N 3496.65E 16.80 596.90 667238.76 5965064.38 11807.09 88.86 304.42 8844.11 4460.37N 3472.90E 12.04 625.27 667214.68 5965079.39 11843.39 88.77 310.40 8844.86 4482.41N 3444.09E 16.47 661.49 667185.39 5965100.79 11881.86 88.77 316.55 8845.68 4508.86N 3416.19E 15.98 699.40 667156.92 5965126.61 11917.36 89.47 314.09 8846.23 4534.10N 3391.24E 7.20 734.21 667131.42 5965151.29 11946.69 90.09 309.87 8846.34 4553.71N 3369.44E 14.54 763.24 667109.20 5965170.42 11977.19 90.88 306.36 8846.08 4572.53N 3345.45E 11.80 793.66 667084.80 5965188.71 12008.59 90.44 301.79 8845.72 .4590.12N 3319.45E 14.62 825.05 667058.42 5965205.72 12042.41 -88.68 297.39 8845.98 4606.81N 3290.05E 14.01 858.76 667028.66 5965221.76 12075.79 88.59 293.35 8846.78 4621.11N 3259.90E 12.10 891.74 666998.21 5965235.39 12108.51 86.76 288.46 8848.11 4632.77N 3229.37E 15.95 923.58 666967.43 5965246.38 12147.56 86.04 282.63 8850.56 4643.21N 3191.84E 15.01 960.53 666929.68 5965255.99 12179.71 87.54 277.18 8852.36 4648.73N 3160.23E 17.56 989.82 666897.96 5965260.81 12217.94 87.89 270.67 8853.89 4651.34N 3122.14E 17.04 1022.86 666859.83 5965262.58 12247.44 88.07 266.28 8854.93 4650.56N 3092.68E 14.88 1046.85 666830.39 5965261.15 12282.59 87.36 259.42 8856.33 4646.19N 3057.85E 19.61 1073.28 666795.67 5965256.02 12315.56 85.87 254.15 8858.28 4638.67N 3025.82E 16.58 1095.63 666763.82 5965247.79 12346.86 86.04 248.70 8860.49 4628.73N 2996.24E 17.38 1114.59 666734.46 5965237.20 RECEIVED Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from C-19 and SSTVD from RKB - MSL = 68.6 ft. Bottom hole distance is 5150.83 on azimuth 27.78 degrees from wellhead. Vertical section is from tie at N 3716.52 E 3725.39 on azimuth 304.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed Using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad C,C-19B Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : C-19B Last revised : 10-Mar-2000 Measured Inclin Azimuth Subsea Depth Degrees Degrees Depth R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S C 00 R D I N A T E S Deg/100ft Sect Easting Northing~ 12383.51 85.69 242.37 8863.13 12418.99 87.27 235.17 8865.32 12447.13 88.77 235.69 8866.29 12480.83 89.91 239.21 8866.68 12517.56 91.14 243.43 8866.34 4613.60N 2962.98E 17.25 1133.70 666701.55 5965221.35 4595.25N 2932.72E 20.74 1148.53 666671.70 5965202.34 4579.29N 2909.57E 5.64 1158.80 666648.90 5965185.88 4561.16N 2881.17E 10.98 1172.21 666620.91 5965167.13 4543.54N 2848.95E 11.97 1189.06 666589.09 5965148.80 12548.05 91.76 248.00 8865.57 12591.91 91.05 252.74 8864.49 12635.23 88.94 256.43 8864.49 12666.73 88.07 260.13 8865.32 12700.63 88.42 265.40 8866.36 4531.01N 2821.18E 15.12 1205.08 666561.60 5965135.66 4516.28N 2779.89E 10.92 1231.07 666520.65 5965120.03 4504.77N 2738.14E 9.81 1259.25 666479.17 5965107.61 4498.38N 2707.31E 12.06 1281.23 666448.49 5965100.54 4494.11N 2673.71E 15.57 1306.70 666414.99 5965095.53 12734.58 87.19 269.62 8867.66 12765.95 86.92 272.78 8869.27 12795.15 87.1'0 276.47 8870.79 12824.10 87.98 280.34 8872.04 12863.10 87.80 286.14 8873.47 4492.64N 2639.82E 12.94 1333.97 666381.15 5965093.31 4493.29N 2608.51E 10.10 1360.30 666349.83 5965093.28 4495.64N 2579.45E 12.63 1385.71 666320.73 5965094.99 4499.87N 2550.84E 13.70 1411.79 666292.03 5965098.59 4508.79N 2512.92E 14.87 1448.22 666253.93 5965106.67 12900.88 88.42 291.59 8874.72 12936.68 87.45 295.63 8876.01 12949.75 86.84 296.69 8876.66 12986.00 86.84 296.69 8878.66 4521.00N 2477.20E 14.51 1484.65 666217.95 5965118.09 4535.32N 2444.42E 11.60 1519.83 666184.87 5965131.69 4541.08N 2432.71E 9.35 1532.77 666173.03 5965137.18 4557.33N 2400.37E 0.00 1568.67 666140.35 5965152.72 RECEIVED MAR ,%0 2000 A aska Oit & Gas Cons. Commission Anchorage Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from C-19 and SSTVD from RKB - MSL = 68.6 ft. Bottom hole distance is 5150.83 on azimuth 27.78 degrees from wellhead. Vertical section is from tie at N 3716.52 E 3725.39 on azimuth 304.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed Using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad C,C-19B Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 3 Your ref : C-19B Last revised : 10-Mar-2000 MD SSTVD Rectangular Coord$. 10700.00 8347.17 3716.52N 3725.39E 12986.00 8878.66 4557.33N 2400.37E Comments in wellpath Comment Tie-in Point Projected to TD NO Targets associated with this wellpath RECEIVED MAR ;~0 ~.000 Alaska Oil E Gas Cons. Commissio~ Anchorage North Slope Alaska Alaska State Plane 4 PBU_ WOA C Pad C-19B Surveyed: 25 February, 2000 SURVEY REPORT 10 March, 2000 Your Ref: AP1-500292073502 Surface Coordinates: 5960544.00 N, 663841.00 E (70° 17' 54.7901 " N, Kelly Bushing: 68.62ft above Mean Sea Level 148° 40' 23.0746" W) RECEIVED MAR ~0 2000 Alaska Oil & Gas Cons. Commission Anohorage DRILLING SERVICES Survey Ref: svy9675 A H,~lI.IBU~TO~ COUI~A~NY Sperry-Sun Drilling Services Survey Report for C-19B Your Ref: AP1-$00292073502 Surveyed: 25 February, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (fi) (ft) (ft) (ft) (ft) 11156.53 54.510 8.980 8639.38 8708.00 11180.00 55.070 13.520 8652.92 8721.54 11209.80 55.720 7.690 8669.85 8738.47 11247.17 55.460 359.960 8690.99 8759.61 11279.63 54.050 352.400 8709.74 8778.36 11312.42 55.990 345.900 8728.56 8797.18 11355.65 57.390 340.100 8752.31 8820.93 11393.58 59.060 333.070 8772.30 8840.92 11423.60 64.340 329.900 8786.53 8855.15 11454.25 68.290 325.510 8798.85 8867.47 11484.67 71.190 319.880 8809.39 8878.01 11519.60 71.890 314.260 8820.45 8889.07 11556.00 74.790 307.750 8830.90 8899.52 11588.78 80.420 304.760 8837.93 8906.55 11625.60 83.930 300.020 8842.95 8911.57 11661.91 85.430 293.160 8846.32 8914.94 11692.66 89.120 290.000 8847.78 8916.40 11715.99 92.720 292.460 8847.41 8916.03 11747.71 94.040 297.560 8845.53 8914.15 11778.71 91.230 301.950 8844.11 8912.73 11807.09 88.860 304.410 8844.09 8912.71 11843.39 88.770 310.390 8844.84 8913.46 11881.86 88.770 316.540 8845.66 8914.28 11917.36 89.470 314.080 8846.21 8914.83 11946.69 90.090 309.860 8846.32 8914.94 4034.52 N 3805.01 4053.32 N 3808.75 4077.41 N 3813.26 4108.14 N 3815.31 4134.55 N 3813.57 4160.91N 3808.50 4195.43 N 3797.93 4224.99 N 3785.11 4248.19 N 3772.48 4271.90 N 3757.48 4294.57 N 3740.18 4318.82 N 3717.63 4341.67 N 3691.32 4360.59 N 3665.51 4380.11N 3634.72 4396.28 N 3602.41 4407.58 N 3573.85 4416.02 N 3552.11 4429.40 N 3523.43 4444.77 N 3496.55 4460.30 N 3472.81 4482.33 N 3443.99 4508.77 N 3416.09 4534.01N 3391.12 4553.62 N 3369.32 E 5964660.52 N 667557.14 E E 5964679.40 N 667560.47 E E 5964703.58 N 667564.45 E E 5964734.34 N 667565.84 E E 5964760.72 N 667563.52 E E 5964786.96 N 667557.87 E E 5964821.24 N 667546.55 E E 5964850.51N 667533.10 E E 5964873.43 N 667519.97 E E 5964896.80 N 667504.45 E E 5964919.10 N 667486.66 E E 5964942.84 N 667463.58 E E 5964965.12 N 667436.78 E E 5964983.47 N 667410.57 E E 5965002.32 N 667379.36 E E 5965017.78 N 667346.70 E E 5965028.45 N 667317.91 E E 5965036.41 N 667295.99 E E 5965049.17 N 667267.02 E E 5965063.94 N 667239.82 E E 5965078.95 N 667215.74 E E 5965100.35 N 667186.44 E E 5965126.18 N 667157.97 E E 5965150.86 N 667132.47 E E 5965169.99 N 667110.24 E RECEIVED 2000 Dogleg Rate (°/100fl) 15.982 16.247 17.075 19.505 17.282 11.669 16.356 19.891 18.385 19.805 15.392 18.893 19.346 15.921 19.259 15.79o 18.688 16.581 16.800 12.o36 16.472 15.983 7.204 14.542 Alaska State Plane 4 PBU_WOA C Pad Vertical Section (ft) Comment -777.87 ~77o.o7 -759.84 -743.78 -727.1o -7o7.75 -679.19 -651.66 -627.96 -602.02 -574.81 -542.39 -507.72 -475.72 -439.31 -4o3.59 -373.76 -351.13 -319.98 -289.17 -260.81 -224.56 -186.51 -151.57 -122.44 Tie-on Survey Window Point Continued... 10 March, 2000- 10:06 Alaska 0ii~-Gas Cons. C0mmissi0n An~0rage DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for C-19B Your Ref: API-500292073502 Surveyed: 25 February, 2000 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 11977.19 90.880 306,350 8846.06 8914.68 12008.59 90,440 301.780 8845.70 8914.32 12042.41 88.680 297.380 8845.96 8914.58 12075.79 88.590 293.340 8846.76 8915.38 12108.51 86.760 288.450 8848.09 8916.71 12147.56 86.040 282.620 8850.54 8919.16 12179.71 87.540 277.170 8852.34 8920.96 12217.94 87.890 270.660 8853.87 8922.49 12247.44 88.070 266.270 8854.91 8923.53 12282.59 87.360 259.410 8856.31 8924.93 12315.56 85.870 254,140 8858.26 8926.88 12346.86 86.040 248.690 8860.47 8929.09 12383.51 85.690 242.360 8863.11 8931.73 12418.99 87.270 235.160 8865.30 8933.92 12447.13 88.770 235.680 8866.27 8934.89 12480.83 89.910 239.200 8866.66 8935.28 12517.56 91.140 243.420 8866.32 8934.94 12548.05 91.760 247.990 8865.55 8934.17 12591.91 91.050 252.730 8864.47 8933.09 12635.23 88.940 256,420 8864.47 8933.09 12666.73 88.070 260.120 8865.30 8933.92 12700.63 88.420 265.390 8866.34 8934.96 12734.58 87.190 269.610 8867.64 8936.26 12765.95 86.920 272.770 8869.25 8937.87 12795.15 87.100 276.460 8870.77 8939.39 Local Coordinates Northings Eastings (fi) (ft) 4572.43 N 3345.33 E 4590.02 N 3319.32 E 4606.71 N 3289.92 E 4621.00 N 3259.77 E 4632.65 N 3229.24 E 4643.09 N 3191.71E 4648.60 N 3160.10 E 4651.21N 3122.01 E 4650.42 N 3092.55 E 4646.04 N 3057.72 E 4638.52 N 3025.69 E 4628.57 N 2996.11E 4613.43 N 2962.86 E 4595.08 N 2932,60 E 4579.12 N 2909.45 E 4560.99 N 2881.05 E 4543,36 N 2848.84 E 4530.82 N 2821.06 E 4516.09 N 2779.78 E 4504.57 N 2738.03 E 4498,17 N 2707.20 E 4493.90 N 2673.60 E 4492.42 N 2639.72 E 4493.07 N 2608.40 E 4495.41N 10 March, 2000 - 10:06 Alaska State Plane 4 PBU_WOA C Pad Global Coordinates Northings Eastings (ft) (ft) Dogleg Rate (°/'~OOft) Vertical Section (ft) Comment 5965188.28 N 667085.84 E 5965205.29 N 667059.46 E 5965221.34 N 667029.70 E 5965234.97 N 666999.25 E 5965245.96 N 666968.47 E 5965255.57 N 666930.72 E 5965260.39 N 666899.00 E 5965262.17 N 666860.86 E 5965260.74 N 666831.42 E 5965255.60 N 666796.70 E 5965247.38 N 666764.84 E 5965236.79 N 666735.48 E 5965220.93 N 666702.57 E 5965201.92 N 666672.72 E 5965185.46 N 666649.92 E 5965166.71 N 666621.92 E 5965148.39 N 666590.11 E 5965135.25 N 666562.61 E 5965119.62 N 666521.66 E 5965107.19 N 666480.17 E 5965100.12 N 666449.49 E 5965095.12 N 666415.99 E 5965092.90 N 666382.15 E 5965092.87 N 666350.82 E 666321.72 E 2579.34 E 5965094.58 N R- CEIVED 11.796 14,620 14.011 12.103 15.945 15.014 17.556 17.040 14.885 19.605 16.584 17.377 17.253 2O.738 5.641 10.978 11.967 15.121 10.924 9.812 12.062 15.573 12.938 10.097 12.635 -91.99 -60.60 -26.96 5.91 37.57 74.24 103.23 135.84 159.44 185.35 207.16 225.57 243.99 258.09 267.79 280.51 296.63 312.07 337.28 364.72 386.19 411.16 437.98 463.93 489.01 MAR ;50 2000 Ala~a 0il & Gas Cons. Commissmn Anchorage Continued... DrillQuest 1.05. 04e Sperry-SUn Drilling Services Survey Report for C-19B Your Ref: API-500292073502 Surveyed: 25 February, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (fi) (ft) (ft) Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/lOOft) 12824.10 87.980 280.330 8872.02 8940.64 4499.63 N 2550.73 E 12863.10 87.800 286.130 8873.45 8942.07 4508.55 N 2512.81 E 12900.88 88.420 291.580 8874.70 8943.32 4520.75 N 2477.09 E 12936.68 87.450 295.620 8875.99 8944.61 4535.07 N 2444.31 E 12949.75 86.840 296.680 8876.64 8945.26 4540.82 N 2432.59 E 12986.00 86.840 296.680 8878.64 8947.26 4557.07 N 2400.25 E 5965098.18 N 666293.02 E 5965106.26 N 666254.92 E 5965117.68 N 666218.94 E 5965131.28 N 666185.86 E 5965136.78 N 666174.02 E 5965152.32 N 666141.33 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.205° (15-Feb-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 305.260° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12986.00ft., The Bottom Hole Displacement is 5150.55ft., in the Direction of 27.776° (True). 13.697 14.869 14.511 11.598 9.348 0.000 Alaska State Plane 4 PBU_WOA C Pad Vertical Section (ft) Comment 514.81 550.92 587.13 622.16 635.05 670.84 Projected Survey R CEIVED UAR 30 2000 Alaska 0it & Gas Coas. C0mmi~i0n Continued... 10 March, 2000 - 10:06 - 4 - DrillQuest 1,05.04e Sperry-Sun Drilling Services Survey Report for C-19B Your Ref: API-500292073502 Surveyed: 25 February, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA C Pad Comments Measured Depth (ft) 11156,53 11180.00 12986.00 Station Coordinates TVD Northings Eastings (ft) (it) (it) 8708.00 4034.52 N 3805.01 E 8721.54 4053.32 N 3808.75 E 8947.26 4557.07 N 2400.25 E Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (it) (it) 0.00 0.00 10725.00 8434.06 TO Measured Vertical Depth Depth (it) (it) 10725.00 8434.06 12986.00 8947.26 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro MWD Magnetic RECEIVED MAR 3,0 2000 Alaska Oii & Gas Cons. Commission 10 March, 2000 - 10:06 - 5 - DrillQuest 1.05.04e North Slope Alaska Alaska State Plane 4 PBU_ WOA C Pad C-19BPB1 Surveyed: 18 February, 2000 SURVEY REPORT 10 March, 2000 Your Reft AP1-500292073570 Surface Coordinates: 5960544.00 N, 663841.00 E (70° 17' 54.7901" N, 148° 40' 23.0746" I/V) Kelly Bushing: 68.62ft above Mean Sea Level RECEIVED MAR ~0 2000 Alaska Oil & Gas Cons, Commission Anchor~ DRILLING SERVICES Survey Ref: svy9673 Sperry-Sun Drilling Services Survey Report for C-19BPB1 Your Ref: API-500292073570 Surveyed: 18 February, 2000 North Slope Alaska Measured Depth (ft) Incl. 10700.00 10725.00 10756.93 lO791.91 10832.98 10864,83 10900.73 10935.73 1 o984.56 11031.55 11063.36 11106.33 11136.71 11156.53 11187.2o 11221.38 11254.20 11285.70 11321.90 11354.40 11392.92 11422.8o 11452.02 11490.90 11521.49 43.o5o 42.950 45.91o 48.740 5o.o4o 49.o4o 49.130 49.750 50.450 53.880 53.440 54.670 54.230 54.51o 55.280 56.25O 56.510 54.840 51.860 51.770 55.19O 58.270 60.8OO 60.030 64.600 Azim. 52.300 52.240 44.070 35.690 26.710 27.380 18.240 8.750 356.270 347.830 345.550 1.010 3.650 8.980 14.900 21.410 26.150 31.070 32.660 24.570 17.540 13.320 7.870 1.010 356.090 Sub-Sea Depth (ft) 8347.15 8365.44 8388.25 8411.99 8438.75 8459.42 8482.96 8505.75 8537.14 8565.99 8584.84 8610.17 8627.83 8639.38 8657.03 8676.28 8694.45 8712.22 8733.83 8753.94 8776.88 8793.28 8808.10 8827.31 8841.53 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 8415.77 3716.49 N 3725.42 E 8434.06 3726.93 N 3738.90 E 8456.87 3741.84 N 3755.50 E 8480.61 3761.57 N 3771.92 E 8507.37 3788.20 N 3788.02 E 8528.04 3809.78 N 3799.04 E 8551.58 3834.74 N 3809.54 E 8574.37 3860.54 N 3815.72 E 8605.76 3897.84 N 3817.33 E 8634.61 3934.52 N 3812.14 E 8653.46 3959.45 N 3806.25 E 8678,79 3993.83 N 3802.23 E 8696.45 4018.52 N 3803.24 E 8708.00 4034.52 N 3805.01 E 8725.65 4059.05 N 3810.20 E 8744.90 4085.87 N 3819.01 E 8763.07 4110.87 N 3830.03 E 8780.84 4133.70 N 3842.47 E 8802.45 4158.37 N 3857.79 E 8822.56 4180.76 N 3870.01 E 8845.50 4209.63 N 3881.08 E 8861.90 4233.70 N 3887.70 E 8876.72 4258.45 N 3892.32 E 8895.93 4292.13 N 3894.94 E 8910.15 4319.19 N 3894.23 E RECEIVED MAR 2000 5964340.83 N 667484.50 E 5964351.56 N 667497.76 E 5964366.83 N 667514,02 E 5964386.91N 667530.02 E 5964413.89 N 667545.53 E 5964435.70 N 667556.08 E 5964460.89 N 667566.02 E 5964486.82 N 667571.64 E 5964524.13 N 667572.44 E 5964560.70 N 667566.46 E 5964585.49 N 667560.02 E 5964619.77 N 667555.26 E 5964644.48 N 667555.72 E 5964660.52 N 667557.14 E 5964685,16 N 667561.80 E 5964712.17 N 667570.02 E 5964737,40 N 667580.49 E 5964760.49 N 667592.43 E 5964785,49 N 667607.21 E 5964808,14 N 667618.94 E 5964837.25 N 667629.37 E 5964861.46 N 667635.47 E 5964886.30 N 667639.55 E 5964920.02 N 667641.43 E 5964947.06 N 667640.14 E Dogleg Rate (°/lOOft) 0.433 20.155 19.370 16.890 3.524 19.232 2O.665 19.643 15.944 5.937 29.236 7.217 21.901 15.987 15.997 12.052 13.944 8.954 19.562 17.137 15.671 18.256 15.469 2O.635 Alaska State Plane 4 PBU_WOA C Pad Vertical Section (ft) Comment -896.47 -901.46 -906.40 -908.42 -906.19 -902.73 -896.89 -887.04 -866.83 -841.42 -822.21 -799.09 -785.66 ~777.87 -767.95 -759.65 ~754.22 -751.19 -749.47 -746.52 -738.89 -730.40 -719.88 -702.58 -686.38 Tie-on Survey Window Point MWD Magnetic Continued... 10 March, 2000.7:26 Alaska Oil & Gas Cons. Commis,~m Anchorage DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for C-19BPB1 Your Ref: API-500292073570 Surveyed: 18 February, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°~lO0~t) 1 1558.71 73.040 352.400 8854.97 8923.59 4353.67 N 3890.72 E 1 1591.19 80.770 351.520 8862.32 8930.94 4384.97 N 3886.30 E 11624.09 88.770 347.830 8865.32 8933.94 4417.17 N 3880.42 E 1 1659.04 95.010 341.850 8864.16 8932.78 4450.86 N 3871.30 E 1 1691.74 94,830 335.880 8861.36 8929.98 4481.23 N 3859.56 E 1 1720.49 91,850 329.730 8859.68 8928.30 4506.74 N 3846.45 E 1 1754.09 92,640 320.410 8858.36 8926.98 4534.24 N 3827.24 E 11771.04 94.220 316.720 8857.35 8925.97 4546.92 N 3816.05 E 11791.00 94.220 316.720 8855.88 8924.50 4561.41 N 3802.40 E 5964981.47 N 667635,88 E 5965012.66 N 667630.77 E 5965044.73 N 667624.20 E 5965078.20 N 667614.34 E 5965108.31N 667601.94 E 5965133.53 N 667588.28 E 5965160.60 N 667568.48 E 5965173.04 N 667557.01E 5965187.23 N 667543.05 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.205° (15-Feb-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 305.260° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11791.00ft., The Bottom Hole Displacement is 5938.42ft., in the Direction of 39.815° (True). 24.483 23.945 26.755 24.717 18.198 23.735 27.816 23.645 0.000 Alaska State Plane 4 PBU_WOA C Pad Vertical Section (ft) Comment -663.61 -641.93 -618,54 -591,65 -564,53 -539.09 -507.54 -491.08 -471.57 Projected Survey RECEIVED MAR ~0 2000 Alaska 0il & Gas Cons. C0mmi~n Continued.., 10 March, 2000 - 7:26 - 3 - DrillQuest 1,05,04e Sperry-Sun Drilling Services Survey Report for C-19BPB1 Your Ref: AP1-$00292073570 Surveyed: 18 February, 2000 North Slope Alaska Alaska State Plane 4 PBU_WOA C Pad Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 10700.00 8415.77 3716.49 N 3725.42 E 10725.00 8434.06 3726.93 N 3738.90 E 11791.00 8924.50 4561.41 N 3802.40 E Comment Tie-on Survey Window Point Projected Survey Survey tool program From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) o.o0 o.oo 10725.00 8434.06 lO725.oo 8434.06 11791.00 8924.50 Survey Tool Description AK-1 BP_HG - BP High Accuracy Gyro MWD Magnetic RECEIVED U/ R 2000 Alaska Oil & Gas Cons. Commission Anchorage 10 March, 2000 - 7:26 - 4 - DrillQuest 1.05.04e TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COM~ISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit C- 19B BP Exploration (Alaska) Inc. Permit No: 200-05 SurLoc: 664'SNL, 1521'WEL, Sec. 19, TllN, R14E, UM Btmhole Loc. 3991'NSL, 882'EWL, Sec. 17, T11N, RI4E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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. Robert N. Christenson, P.E. Chair BY ORDER OF TI-~COMMISSION DATED this ~ ~ day of January, 2000 dlf/Enclosurcs cc: Departmcnt of Fish & Gmne. Habitat Section w/o encl. Department of Environmental ConscrYation sv/o cncl. ,-.., STATE OF ALASKA ALAS; OILAND GAS CONSERVATION CC .IlSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. N~'r~e of OPerator 5.'" Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 68.62' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028305 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 664' SNL, 1521' WEL, SEC. 19, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 3080' NSL, 2255' EWL, SEC. 17, T11N, R14E, UM C-19B At total depth 9. Approximate spud date Amount $200,000.00 3991' NSL, 882' EWL, SEC. 17, T11N, R14E, UM 02/10/00 12. Di~'ance to ne~est pr0p'erty line113. Distance to nearest will 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028304, 1287' MDI No Close Approach 2560 13036' MD / 8884' TVD ..... 16. To be completed for deviated wells ....... 1'7". Anticipated '~'ressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 10753' MD Maximum Hole Angle 89° Maximum surface 2244 psig, At total depth (TVD) 8800'/3300 psig 18. Casing Program Specifications Setting Depth Size Top Bottom. Quantity. of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 STL 2881' 10154' 7955' 13035' 8884' 140 cu ft Class 'G' .................... , [. / r:. n ..... 19. To b'e"completed"i~r Rearill, Re'-~'~try, and DeePen OpErations.' ....... Present well condition summary .-,:-.,.,, Total depth: measured 12821 feet Plugs (measured) true vertical 8927 feet J0t~a$~l 0il & Gas Cons. Commission Effective depth: measured 12815 feet Junk (measured) Anchorage true vertical 8926 feet Casing Length Size Cemented MD TVD Structural Conductor 145' 20" x 30" 8 cu yds concrete 145' 145' Surface 2650' 13-3/8" 3720 cuft Arctic Set II 2688' 2687' Intermediate 10584' 9-5/8" 1190 cuft AS, 1481 cuft Class 'G' 10618' 8356' Production Liner 7" 408 cuft Class 'G' 10149' - 11074' 8020' - 8692' Liner 2745' 2-7/8" 106 cuft Class 'G' 10070' - ~'5'~ 7965' - Perforation depth: measured 11664'-11849', 12229'-12459', 12509'-12709' ORIGINAL true vertical 8932' - 8927', 8925' - 8921', 8918' - 8985' 20. Aii"achmenis [] Filing Fee [] Property plat [] BOP sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the fore_going is true and correct to the best of my knowledge Signed ~.~ Ted Stagg Title CT Drilling Engineer Date Commission Use Only Permit Number APl Number Approval Date I See cover letter '~._C.~-~,~" 50-029-20735-02 / %,.~ ~ - ~ OJ for other requirements Conditions of Approval: Samples Required [] Yes ~[No Mud Log Required [] Yes ,~ No Hydrogen Sulfide Measures l~Yes I--! No Directional Survey Required ~[~K~ No Required Working Pressure for'BOPE [-]2K; I-I3K; 1~4K; [-]FK; E-I10K; Other: by order of ORIGINAL SIGNED BY Commissioner the commission Date/.-~,?~--, Approved By Robert !~1 ~.h,~o,~, .... ' Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX C-19b Sidetrack Summary of Operations: C-19 is being sidetracked to target Zone 1 reserves. This sidetrack will be conducted in three phases. Phase 1' Kill and Plug C-19a, Cut C-19a liner' Planned for Jan. 31, 2000. · A Tubing Integrity Test will be performed prior to killing C-19a. · C-19a will be killed, a CIBP set at approx. 11,100' and a chemical cut made at approx. 10,760'. Phase 2: Service coil will be used to confirm that the 2 7~8" pipe is free. Phase 3: Recover 2 7/8", Set Whipstk, Mill Window, Drill & Complete sidetrack: Planned for Feb. 10, 2000. Directional drilling coiled tubing equipment will be rigged up to recover the severed 2 7/8", set a new whipstock, mill the window then drill and complete the directional hole as per attached plan. Mud Program: · Phases l& 2: Seawater · Phase 3: Seawater and FIo-Pro (8.7 - 8.8 ppg) 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: · 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 10,154' MD and cemented with approx. 25 bbls. cement to bring cement 200 ft above the window. The liner will be pressure tested to 2200 psi and perforated with coiled tubing conveyed guns. Well · · · Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Cased hole will be logged with Memory CNL. Hazards No faults or lost circulation are expected. Res. pressure is normal. Reservoir Pressure Res. pressure is 3300 @ 8800ss. Max. surface pressure with gas (0.12 psi/ft) to surface is 2244 psi. TREE: 6" McEVOY WELLHEAD: McEVOY ACTUATOR: OTIS 13-3/8"' 72#/ft' I L-80, BTRS 2688' KB. ELEV = 68.62' O-19b Proposed Completion BF. ELEV=33.82' FOC -- SSSV LANDING NIPPLE I 2144' ( OTIS DBE)( 4.562" ID) IKOP: 2800' MAX ANGLE: 53.5° @ 7300' t5-1/2", 17#/ft, L-80,BTRS UBING (IPC) UBtNG ID: 4.892" APACtTY: .0232 BBL/FT TOPOF I 10,149,I 7" LINER 9-5/8", 47#/ft, [10,618' L-80, BTRS SLIDING SLEEVE ( OTIS "XA" )( 4.562" I9,983' iD) I10,050' ASSY. 9-5/8" PACKER I 10,074' ( OTIS )(3.813"1D) 2", 12.6#/ft, L-80 (OTIS)(3.813"1D) [ 10,134' 41/2" "XN" NIPPLE I10,173' (OTIS) ( 3.725" ID) 4 1/2" TBG TAIL (OTIS SOS)/ELMD) C-19a liner will be abandoned, cut at approx. 10,760' MD and retrieved. Whipstock for C-19b will be set at approx. 10,742' MD, near the base of the Shublik. C-t9b PBTD I 11,538'] 7", 26#/ft, L*80, ,J4S [11,580' C-19a abandoned 1,500 2,000 C-19 5,500 C-19b Sidetracked from C-19 Case 103 1/13/00 5,000 4,500 3,500 , , +--- ~ ~ 3,000 3,000 3,500 4.000 4.500 5,000 5,500 X distance from Sfc Loc IWell Nome C"19 ] ctosUR IDistance 5,231 ~ AZ 26 de~ NEW HOLE E/W (x) N/S (Y} Kick Off 3,671 3,82C TD 2,284 ,4,707 State Plane 666.125 5,965,251 Su~iace Loc 663,841 5,960,544 DLS dell/100 Tool Face Len~llh Curve 1 6 C ~0 Curve 2 12 -7C 220 Curve 3 12 -911 360 Curve 4 12 -15 292 Curve 5 8 -91~ 809 Curve 6 8 9[~ 574 2,285 Drawn: 1/17/2000 15:33 Plan Name: Case 103 C-19 Vertical Section 0 5O0 Path Distance (Feet) 1.000 1 500 2.000 2,500 3,000 Angle @ K.O.= 43 deg MD:lD753 TZ3 8550ss fT7_2 8629ss 8900- 8950- 9OOO Tot Drld:2283 fl 13036 TD Marker Depths ~Orig Welir°°i'e TsAG I 8;291 Irt ~VD TSHU ~ff WD 8,855~ft TVD TSAD ~ ft Kick Off 8,386 ft TVD 101753 ft MD Deprtr @KO 5,31;3 ft MD KO Pt lo,7531 MD New Hole 2283J I Total MD 1~ TVD TD 8,884J DLS de~//lO0 Tool Face Len~ltt' Curve I 6 0 Cuwe 2 12 -70 22a Curve 3 12 -90 36a CUrve 4 12 -15 292 Curve 5 8 -90 809 Curve 6 8 90 574 2,285 Drawn: 1/17/2000 15:33 Plan Name: Case 103 2 3/8" Cq Lubricato C-19b CT Drilling & Completion BOP 12" 36" Blind/Shear 71/16" Pipe/Slip ~"~ 2 3/8" 22.5" 38~ SWAB OR MASTER VALVE H 1 59952 DATE I [ CHECK NO. 1 I I VEN~R ALASK~OILA O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT 'NET '" 1~09c)9 CK 1~0999E 100. O0 100. O0 HANI)L]NO INST: S/H TERRI HUBBLE X4&~8 .... THE AI'rACHED CHECK IS IN PAyMr'~'T FOR IT~'--'~ DESCRIBED ABOVE. ml[l]lJ-*l~ I 100. 00 100. O0 :.,:BP EXPLORATION (ALASKA), INC, . :' ':". i'i ::. : '..!:'.: ·' : ..'" P.O. BOX' 196612 ANCHORAGE, ALASKA 99519-6612 , FIRST NATION~.iBANK.OF AS.LAND · '.':.:.~. · ."~ .:Afl:'~..m..UA?E ~ ~:~;::. "::' NATIONAl;CITY BANK ' '" :' : CLEVELAND. OHIO '56-389 No. :::H ..... CONSOL!D~'~ED COMMERCI~,:L','~cCOUNT": 0015995~ PAY TO: The :: ORDER. :' .: . DATE AMOUNT CONSERvAT ION ':CI3MM'~sSION ::: "-:: ' 3001: PORCUP I NE :: DR I VE :':i:'-:; '" ::-: ' ; .. · AK 99501 ANCHORAGE ll"~.5qqS;~,' m:OL, i, 2O~.O. ci5,: OOBL, L,I, tH" STATE OF ALASKA ALASK, . OIL AND GAS CONSERVATION C'-"/IMISSION APPLICATION FOR SUNDRY APPROVAL Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [--I Exploratory [] Stratigraphic ~--1 Service 4. Location of well at surface 664' SNL, 1521' WEL, SEC. 19, T11N, R14E, UM At top of productive interval 3080' NSL, 2255' EWL, SEC. 17, T11N, R14E, UM At effective depth 272' NSL, 3604' EWL, SEC. 17, T11N, R14E, UM At total depth 2758' NSL, 3605' EWL, SEC. 17, T11 N, R14E, UM 6. Datum Elevation (DF or KB) KBE = 68.62' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number C-19A 9. Permit Number 197-015 10. APl Number 50- 029-20735-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary PerfGun,~at12462' 12821 feet Plugs (measured) Total depth: measured true vertical 8927 feet , ~ ,,~"~_~ Effective depth: measured 12815 feet Junk (measured) ~48~bf~" Perf true vertical 8926 feet Casing Length Size ,~. //,'Cemented Structural / ~ Conductor 145' 20" x 30" 8x:u vU~'concrete Surface ....... ~"~' 13-3/8~ 2~cu ft Arctic Set Il Intermediate .... / 105~14' ~/', [ //'190 cu ft AS, 1481 ca ft Class 'G' Production / f,~ [ J~/'~ '-" Liner '~ / / ~. ~J 408 cuff Class 'G' Liner ~ .... \,~.745' !* ' -/t~ ~,2.J7/8"106 ca ff Class 'G' / , i ' ./ Perforation depth*: measured I11664' - 11849', 12229' - 12459', 12509 - 12709 ,/ / I ~'l. true vertical/8932' - 8927', 8925' - 8921', 8918' - 8985' Tubing (size, gra~red depth) 5-1/2", 17#, L-80 with 4-1/2" tailpipe to 10190' Packers and SSSV (type and measured depth) MD TVD 145' 145' 2688' 2687' 10618' 8356' 10149'-11074' 8020'-8692' 10070'-12815' 7965'-8926' 9-5/8" Otis Packer at 10074'; Otis SSSV Landing Nipple at 2144° 13. Attachments [] Description summary of proposal [--I Detailed operations program [] BOP sketch 14. Estimated date for commencing operation January 31, 2000 16. if proposal was verbally approved Name of approver Contact Engineer Name/Number: Date approved Ted Stagg, 564-4694 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the fore ,~rue and correct to the best of my knowledge Signed TedStagg~~. Title CT Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance __ Mechanical Integrity Test Subsequent form required 10- lAppr°val N°'._~t~ - i~/"~ Approved by order of the Commission Form 10-403 Rev. 06/15/88 Commissioner Date Submit In Triplicate FIELD & POOL ~? 4.//~/~'~"~ 'INI~- CLASS ADMINISTRATION 1. Permit fee attached ....................... DATE ENGINEERING .DATE PROGRAM: exp ~ devv/ redrll v/ serv __ wellbore seg ann. disposal para req ~ GEOL AREA ~~ UNit# (~/"/~.~_~ ON/OFFSHORE ~/z GEOLOGY 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 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 adequate 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 L~(~q_,~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... N N N Y N ' ~-~ ' Y N N N N Y N DATE. Data presented on potential overpressure zones ..... .,~,.~ 31. Seismic analysis of shallow gas zones ........... /,y'. ;.,,~,rd Y N 32. ,4//--/ Y N 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory only]/~"~ N With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N 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 AAC 25.252 or 20 AAC 25.412. Y N ANNULAR DISPOSAL 35. APPR DATE GEOLOG..y~ ENGINEERING: UIC/Annular COMMISSION: JDH ,~ ~ RNC Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 09/27/99) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX, No special 'effort has been made to chronologically organize this category of information. oo-S Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 S LisLib SRevision: 4 $ Men May 13 16:08:13 2002 Reel Header Service name ............. LISTPE Date ..................... 02/05/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation NuRSer ...... 01 Previous Reel Name ....... UN?~O~ Coum~ents ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/05/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Nun~er ...... 01 Previous Tape Name ....... UNKNO~ Cou~nents ................. STS LIS Writing Library. Scientific Technical Se~?vices Scientific Technical Seuvices Physical EOF Con~ent Record TAPE HEADER Prudhoe Bay MWD/~AD LOGS WELL N~{E: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: C-19B 500292073502 BP Exploration (Alaska) Inc. Sperry Sun 13-~AY- 02 FP~.}D RUN 1 MWD RUN 2 MWD RUN 3 AK-MW-90248 AK-MIq-90248 AK-MW-90248 S. LATZ S. LATZ S. LATZ PRSKELL / WH PLASKELL / WH MASKELL / WH JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MWD RUN 6 MWD RUN 7 AK-MW-90248 AK-M%q-90248 AK-MW-90248 S. LATZ S. LATZ S. LATZ MASKELL / WH MASKELL / WH P~SKELL / WH JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TO~',~SHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 8 AK-MW-90248 S. LATZ SEVCIK / PAR 19 lin 14E 664 1521 68.62 .00 33.22 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 3.750 7.000 10726.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVDSS). 3. C-19B KICKS OFF FROM C-19A AT WHIPSTOCK WITH TOP SET AT 10726' MD, 8365.5' TVD. 4. MWD RUNS 1-8 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. 5. C-19B KICKS OFF FROM C-19B PB1 AT CEMENT PLUG AT 11180' MD, 8652.9' TVD FOLLOWING MWD RUN 5. 6. DEPTH-SHIFTING WAS WAIVED PER THE E-MAlL OF 12/4/2001 OF D. SCHNORR OF BP EXPLORATION (ALASKA) INC. 7~ M%~D RUNS 1-4 AND 6-8 REPRESENT THE MWD DATA FOR WELL C-19B WITH API# 50-029-20735-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12986~ MD, 8878.7' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED Gi.%~PL~ ~Y - SCINTILLATION DETECTORS $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date ef Generation ....... 02/05/13 Maximum Physical Record..65535 File Ts~e ................ LO Previous File Name ....... STSLIB.000 Co~lm~ent Record FILE HEADER FILE NUMBER: 1 EDITED MERGED ~gqD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SU~,~RRY PBU TOOL CODE START DEPTH STOP DEPTH SGRD 10716.0 12960.0 SROP 10738.0 12986.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MND t~D MWD MWD MWD EQUIVALENT UNSHIFTED DEPTH BiT RUN NO MERGE TOP MERGE BASE 1 10716.0 10761.0 2 10761.5 11040.0 3 11040.5 11171.5 4 11172.0 11179.5 6 11180.0 11672.5 7 11673.0 12461.0 8 12461.5 12986.5 REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-t~%oe...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD AP1 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10716 12986.5 11851.3 4542 ROP P~D FPH 0.21 2306.11 107.345 4498 GR M~D AP1 16.96 367.41 55.3903 4489 First Reading For Entire File .......... 10716 Last Reading For Entire File ........... 12986.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File T5~e ................ LO Next File Name ........... STSLIB.002 First Reading 10716 10738 10716 Last Reading 12986.L 12986.5 12960 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Nul~er ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW ~D Curves and log header data for each bit run in separate files. BiT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUP}{ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10716.0 10730.0 ROP 10738.0 10761.0 $ LOG HEADER DATA DATE LOGGED: 15-FEB-00 SOFT%~ARE SURFACE SOFTWARE VERSION: Insite DO{,~NHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT : BOTTOM LOG INTERVAL FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: N'~XIHUM AN'GLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL G~94A PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BlT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHPPI) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPE~A. TURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL P~TRIX: PL~TRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): E~R FREQUENCY (HZ): REPRRKS: $ Data Format Specification Record Data Record T}~e .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical leg depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 10761.0 10746.0 10761.0 43.0 45.9 TOOL NUMBER PB02100HWRG6 3.750 FloPro 8.60 65.0 8.6 23000 8.6 · 000 .0 .000 141.7 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP N~D010 FPH 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10716 10761 10738.5 91 ROP P~D010 FPH 0.5 1843.32 506.913 47 GR MWD010 API 76.66 336.29 151.787 29 First Reading For Entire File .......... 10716 Last Reading For Entire File ........... 10761 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Nun~er ........... 1.0.0 First Reading 10716 10738 10716 Last Readi ng 1076] 10761 10736} Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Ts~e ................ LO Next File Name ........... STSLiB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Ma×imum Physical Record..65535 File T}~e ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW P~D Curves and log header data for each bit. run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUN~{ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10730.5 11014.0 ROP 10761.5 11040.0 $ LOG HEADER DATA DATE LOGGED: 16-FEB-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER {FT): 11033.0 TOP LOG INTERVAL (FT): 10761.0 BOTTOM LOG INTERVAL (FT): 11033.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM .~NGLE: 48.7 ~LRXIMUM .~GLE: 50.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER N G P NATUraL G.~ PROBE PB 02100 HWRG 6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: FloPro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 8.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPEraTURE (MT): .000 .0 MUD AT P~X CIRCULATING TERMPERATURE: .000 133.3 MUD FILTraTE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL S%~DOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block T~.~e ..... 0 Legging Direction ................. Down Optical leg depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Hax frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification 8!eck sub-t}~e...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FPH 4 1 68 4 2 GR P~D020 API 4 1 68 8 3 Name Service Unit Hin Max Mean Nsam DEPT FT 10730.5 11040 10885.3 620 ROP [,~7D020 FPH 2.26 200.06 85.4222 558 GR ~D020 API 18.08 367.41 51.5408 568 First Reading For Entire File .......... 10730.5 Last Reading For Entire File ........... 11040 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.O04 First Reading 10730.5 10761.5 10730.5 Last Reading ]1040 11040 11014 Physical EOF File Header Service name ............. STSLtB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW ~,{D Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUN~RY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11014.5 11153.0 ROP 11040.5 11171.5 $ LOG HEADER DATA DATE LOGGED: 17-FEB-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DO~%~HOLE SOFT~,qARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: ~,~XIMUM ,~2qGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAP~A PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT ~X CIRCULATING TERHPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL ~RTRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record T5rpe .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Fee~ Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Memory 11172.0 11033.0 11172.0 53.4 54.7 TOOL NUMBER PB02100HWRG6 3.750 FioPro 8.60 65.0 9.5 24000 8.0 .000 .0 · 000 145.0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ReP NR~D030 FPH 4 1 68 4 2 GR N~D030 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 11014.5 11171.5 11093 315 ReP P~D030 FPH 0.94 361.6 21.4663 263 GR ~D030 AP1 17.94 66.9 23.4845 278 First Reading For Entire File .......... 11014.5 Last Reading Fer Entire File ........... 11171..5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... First Reading 11014,5 11040,5 11014.5 Last Reading 11171. !~ 11].153 Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version hula. er ........... 1.0.0 Date ef Generation. 02/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAH MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUN~'L~RY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11153.5 11179.5 ROP 11172.0 11179.5 $ LOG HEADER DATA DATE LOGGED: 17-FEB-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11180.0 TOP LOG INTERVAL (FT): 11172.0 BOTTOH LOG INTERVAL (FT): 11180.0 BIT ROTATING SPEED {RPH): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.8 NL~XIMUM ANGLE: 60.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUHBER NGP NATURAL G~MMA PROBE PB02100HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: FlePre MUD DENSITY (LB/G): 8.65 MUD VISCOSITY (S): 65.0 MUD PH: 9.5 MUD CHLORIDES {PPM): 2400{} FLUID LOSS (C3): 6.2 RESISTIVITY {OHP~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 HUD AT N.U~X CIRCULATING TE~{PERATURE: .000 141.7 HUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: PL~TRIX DENSITY: HOLE CORRECTION (IN): TOOL STanDOFF (IN): ENR FREQUENCY (HZ): RE~RKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Ts,~e ..... 0 Logging Direction ................. Down Optical leg depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP N~D040 FPH 4 1 68 4 2 GR ~,'~D040 APi 4 i 68 8 3 Name Service Unit Min Hax Mean Nsam DEPT FT 11153.5 11179.5 11166.5 53 ROP N~D040 FPH 1.5 63.99 34.4063 16 GR N~D040 AP1 21.06 33.18 24.9692 53 First Reading For Entire Pile .......... 11153.5 Last Reading For Entire File ........... 11.179.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Ts~e ................ LO Next File Name ........... STSLIB.006 First Reading 11153.5 111'72 11153.5 Last Readi~lg ]1179.5 11179.~i 11179.5 Physical EOF File Header Service name ............. STSLiB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Tpe ................ LO Previous File Name ....... STSL!B.005 Comment Record FILE HEADER FILE NUMBER: 6 ~W NK, gD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUN, RAY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11180.0 11642.5 ROP 11180.0 11672.5 $ LOG HEADER DATA DATE LOGGED: 20-FEB-00 SOFT~{ARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM iai~GLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMPLA~ PROBE $ BOREHOLE RND CASING DATA OPEN HOLE BlT SIZE (IN): DRILLER'S CASING DEPTH (FT): 66.16 Memory 11673.0 11541.0 11673.0 54 . 0 83.9 TOOL NUMBER PB02100HWRG6 3.750 BOREHOLE CONDITIONS MUD TYPE: FioPro MUD DENSITY (LB/G): 8.75 MUD VISCOSITY (S): 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 2500{I FLUID LOSS (C3): 7.5 RESISTIVITY (OHN~) AT TEMPERATURE {DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT Pt~X CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL NRTRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record T}-pe .................. 0 Data Specification Block Tpe ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined ~sent value ...................... -999 Depth Units ....................... Datum Specification Block sub-tl~e...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FPH 4 1 68 4 2 GR I,'~D060 AP1 4 i 68 8 3 .0 141.7 .0 Name Service Unit Min Max Mean Nsam DEPT FT 11180 11672.5 11426.3 986 ROP P~D060 FPH 0.31 305.13 103.275 986 GR N~D060 AP1 16.96 123.68 34.9609 926 First Reading 11180 11180 11180 Last Reading 11672.5 11672.5 11642.5 First Reading For Entire File .......... 11180 Last Reading For Entire File ........... 11672.5 File Trailer Service name ............. STSLIB.O06 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Tpe ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW ~,~D Curves and log header data fer each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUHN~RY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11643.0 12438.5 ROP 11673.0 12461.0 $ LOG HEADER DATA DATE LOGGED: 21-FEB-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12461.0 TOP LOG INTERVAL (FT): 11673.6} BOTTOM LOG INTERYRL (FT): 12461.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.4 NURI4IHUM ~qGLE: 94.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATUraL G~'Ph~ PROBE PB02100HWRG6 $ BOREHOLE ~D CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: FloPre MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 65.0 HUD PH: 9.5 MUD CHLORIDES (PPM): 44000 FLUID LOSS (C3): 6.0 RESISTIVITY (OHMM) AT TEMPEraTURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT NZ~X CIRCULATING TERHPE~ATURE: .000 150.1 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REbIRRKS: $ Data Format Specification Record Data Record Tt~pe .................. 0 Data Specification Block Tppe ..... 0 Logging Direction ................. Down Optical leg depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-t~e...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP P~D070 FPH 4 ! 68 4 2 GR N~D070 AP1 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 11643 12461 12052 1637 ROP P~,~D070 FPH 20.54 2306.11 135.109 1577 GR HWD070 AP1 30 121.99 55. 683 1592 First Reading For Entire File .......... 11643 Last Reading For Entire File ........... 12461 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Tpe ................ LO Next File Name ........... STSLIB.008 First Reading 11643 11673 11643 Last Reading 1246]. 12461 12438.5 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date ef Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RA~ ~^~D Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: FILE SUMPL~RY VENDOR TOOL CODE GR ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE .5000 START DEPTH STOP DEPTH 12439.0 12960.0 12461.5 12986.5 25-FEB-00 SURFACE SOFTWARE VERSION: DO, HOLE SOFTWARE VERSION: DATA TYPE {MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL {FT): BOTTOM LOG INTERVAL {FT): 8IT ROTATING SPEED (RPM): HOLE INCLINATION {DEG MINIHUH AiqGLE: PRXIMUM ANGLE: TOOL STRING (TOP TO 8OTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAH~,~ PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE {IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT PLaX CIRCULATING TERMPE~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: PRTRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Tl~e .................. 0 Data Specification Block T~e ..... O Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Insite 66.16 Memory 12986.6 12461.0 12986.0 86.8 91.8 TOOL NUMBER PB02100HWRG6 3.750 FioPro 9.20 65.0 9.5 72000 6.4 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP ~D080 FPH 4 1 68 4 2 GR MWD080 API 4 i 68 8 3 .0 158.6 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 12439 12986.5 12712.8 1096 ROP N'~D080 FPH 0.21 225.39 85.875 1051 GR ~qD080 AP1 25.75 269.42 82.5471 1043 First Reading For Entire File .......... 12439 Last Reading For Entire File ........... 12986.5 First Reading 1243e 12461.5 12439 Last Readi ~g ] 12986. 12986. 12 9(~0 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/05/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Nul~er ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/05/13 Origin ................... STS Reel Name ................ UNK~O[~ Continuation Nu~er ...... 01 Next Reel Name ........... UNKNOWN Co~nents ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File C~ wELL LOG Tto~sM1TTAL May 23, 2002 State of Alaska ' Comm. Alaska Oil and Gas Conservation Attn.: Lisa Weepie 333 West 7~ Avenue, Suite 100 Anchorage, Alaska AK_MW-90245 l LDWG formatted Disc with verification listing. APl#: 50_029-20735-70 LETTER sro BP Exploration (Alaska) inc. Sperry-Sun Drilling Services Arm: lira Gal~ 6900 Arctic Blvd. Anchorage, Alaska 99518 Petro_Technical Data Center Lg2-I 900 E. Benson Blvd. Anchorage, Alaska 99508 Signe~ Date:_ RECEIVED JU:'t 0 5 2002 Al~l&Gas~ns.~m~oo Md~ore~e Sperry-Sun Dr±lling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Men May 1'3 16:06:26 2002 Reel Header Service name ............. LISTPE Date ..................... 02/05/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Nun~er ...... 01 Previous Reel Name ....... UNKNO},~ Coi~ents ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/05/13 Origin ................... STS Tape Name ................ UN~OWN Continuation NurSer ...... 01 Previous Tape Name ....... UNKNO~s~ Confronts ................. STS LIS Writing Library. Scientific Technical Sol-vices Scientific Technical Seuvices Physical EOF Con~ent Record TAPE HEADER Prudhee Bay MWD/PULD LOGS WELL AP1 NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: HWD RUN 1 ~-MW-90248 S. LATZ D. MASKELL / C-19B PB1 500292073570 BP Exploration (Alaska) Inc. Sperry Sun 13-MAY-02 ~'~D RUN 2 MWD RUN 3 AK-N~-90248 AK-MW-90248 S. LATZ S. LATZ D. MASKELL / D. MASKELL / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: ~NGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD P~D RUN 4 MWD RUN 5 AK-Pgq-90248 AK-MW-90248 S. LATZ S. LATZ D. MASKELL / D. MASKELL / 19 lin 14E 664 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1521 68.62 .00 33 oo OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 10726.0 1. ALL DEPTHS ARE MEASURED DEPTHS {MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUBSEA TRUE VERTICAL DEPTHS (TVDSS). 3. C-19B KICKS OFF FROM C-19A AT WHIPSTOCK WITH TOP SET AT 10726' MD, 8365.5t TVD. 4. N~D RUNS 1-5 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. C-19B KICKS OFF FROM C-19B PB1 AT CEMENT PLUG AT 11180' MD, 8652.9' TVD FOLLOWING ~4D RUN 5. DEPTH-SHIFTING WAS WAIVED PER THE E-MAIL OF 12/4/2001 OF D. SCHNORR OF BP EXPLOraTION (ALASKA) INC. 7. ~D RUNS 1-5 REPRESENT THE MWD DATA FOR WELL C-19B PB1 WITH API# 50-029-20735-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11791t MD, 8855.9~ TVD. SROP = SMOOTHED RATE OF PENETRATION SGRD = SMOOTHED G.A}'~MA RAY - SCINTILLATION DETECTORS $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File T~e ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SU~'PL~ RY PBU TOOL CODE START DEPTH STOP DEPTH GR 10716.0 11761.5 ADP 10738.0 11791.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIET DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE ~'~D 9~D MWD MWD REMAR~[S: EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record T~.~e .................. 0 Data Specification Block T}~pe ..... 0 Logging Direction ................. Down MERGED MAIN PASS. BIT RUN NO MERGE TOP MERGE BASE ! 10716.0 10761.0 ~ 10761.5 11040.0 3 11040.5 11171.5 4 11172.0 11541.0 5 11541.5 11791.0 Optical log depth units ........... Feet Dhta Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-t],~e.-.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP N~4D FPH 4 1 68 4 2 GR N~qD AP1 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10716 11791 11253.5 2151 ROP P~D FPH 0 .~o 3125 105.789 2107 GR N~D API 17.1 367.41 51.5601 2092 First Reading For Entire File .......... 10716 Last Reading For Entire File ........... 11791. First Reading 10716 10738 10716 Last Reading 1179] 1179] 111'i(ol. 5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Tpe ................ LO Previous File Name ....... STSLIB.O01 Comment Record FILE HEADER FILE NUMBER: 2 RA[~MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: i DEPTH INCREMENT: .5000 FILE SUNg~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10716.0 10730.0 ROP 10738.0 10761.0 $ LOG HEADER DATA DATE LOGGED: 15-FEB-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10761.0 TOP LOG INTERVAL (FT): 10746.0 BOTTOM LOG INTERVAL (FT): 10761.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 43.0 MAXIMUM ~GLE: 45.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GANhMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OH~'I) AT TEMPEraTURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT PRX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL PRTRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): E~R FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Tl,~e .................. 0 Data Specification Block Tl~e ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-t~e...0 TOOL NUMBER PB02100HWRG6 3.750 FloPro 8.60 65.0 8.6 23000 8.6 .000 · 000 .000 .000 .0 141.7 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP N~D010 FPH 4 1 68 4 2 GR MWD010 API 4 I 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10716 10761 10738.5 91 ROP I~D010 FPH 0.5 1843.32 506.913 47 GR ~D010 AP1 76.66 336.29 151.787 29 First Reading For Entire Pile .......... 10716 Last Reading For Entire File ........... 10761 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 10716 10738 10716 Last Reading ]076] 107611 10730 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Nu~er ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~W MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUN~iARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10730.5 11014.0 ROP 10761.5 11040.0 $ LOG HEADER DATA DATE LOGGED: 16-FEB-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOI~NHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11033.0 TOP LOG INTERVAL (FT): 10761.0 BOTTOM LOG INTERVAL (FT): 11033.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 48.7 MAXIMUM ANGLE: 50.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GA}~ PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): TOOL NUMBER PBO2100HWRG6 3.750 BOREHOLE CONDITIONS MUD TYPE: FloPro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 8.6 RESISTIVITY (OHNP~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAi{ CIRCULATING TERMPERATURE: .000 MUD FILTraTE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL ~%~TRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .0 133.3 .0 .0 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block T~e ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-t~e,..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP Nf~D020 FPH 4 1 68 4 2 GR ~D020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10730.5 11040 10885.3 620 ROP Pg~D020 FPH 2.26 200.06 85.4222 558 GR N~qD020 API 18.08 367.41 51.5408 568 First Reading For Entire File .......... 10730.5 Last Reading For Entire File ........... 11040 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File T5,~e ................ LO Next File Name ........... STSLIB.004 Firsk Reading 10730.5 10761.5 10730.5 Last Readil~q ] 104 {~ 11014 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Nun~er ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Tk~e ................ LO Previous File Name ....... STSLIB.003 Co~m~ent Record FILE HEADER FILE NUMBER: 4 RAW N~D Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUN9.t~RY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11014.5 11153.0 ROP 11040.5 11171.5 $ LOG HEADER DATA DATE LOGGED: 17-FEB-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: '66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11172.0 TOP LOG INTERVAL (FT): 11033.0 BOTTOM LOG INTERVAL (FT): 11172.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 53.4 MAXIMUM .Ai~GLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATUP~L GANPh~ PROBE $ BOREHOLE }~WD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHN~{) AT TEMPE~RTURE (DEGF) MUD AT MEASURED TEMPEPGRTURE (MT): lv~D AT PLaX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Tl~e .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-t~e...0 54.7 TOOL NUMBER PB02100HWRG6 3.750 FloPre 8.60 65.0 9.5 24000 8.0 .000 .0 .000 145.0 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP NggD030 FPH 4 1 68 4 2 GR N~D030 API 4 1 68 8 3 Name Service Unit Mir Max Mean Nsam DEPT FT 11014.5 11171.5 11093 315 ROP i"~D030 FPH 0.48 361.6 21.452 263 GR M%~D030 AP1 17.94 66.9 23.4845 278 First Reading For Entire File .......... 11014.5 Lest Reading For Entire File ........... 11171.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Ts~e ................ LO Next File Name ........... STSLIB.005 Fi~'st Reading 11014.5 116140.5 11014.5 Last Readii~q ]1171.5 11171 . 5 ]11~3 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Nuit~er ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW HWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUN~IRY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11153.5 11510.5 ROP 11172.0 11541.0 $ LOG HEADER DATA DATE LOGGED: il-FEB-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DO[~NHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11541.0 TOP LOG INTERVAL (FT): 11172.0 BOTTOM LOG INTERVAL (FT): 11541.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 51.8 MAXIPFGM ANGLE: 60.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATUgi~L G.~94A PROBE PB02100HWRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (ET): BOREHOLE CONDITIONS MUD TYPE: FlePre MUD DENSITY (LB/G): 8.65 MUD VISCOSITY S): 65.0 MUD PH: 9.5 MUD CHLORIDES PPM): 24006} FLUID LOSS (C3 : 6.2 RESISTIVITY (OHMic{) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPEraTURE (MT): .000 .0 MUD AT MPd{ CIRCULATING TERMPERATURE: .000 141.7 MUD FILTraTE AT MT: .000 .ID MUD CAKE AT MT: .000 .0 NEUTRON TOOL PRTRIX: ~TRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet. Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-tlrpe...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 t ROP MWD040 FPH 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 11153.5 11541 11347.3 776 ROP N~D040 FPH 0.22 3125 118.461 739 GR P~D040 AP1 17.1 151.7 39.7245 715 First Reading For Entire File .......... 11153.5 Last Reading For Entire File ........... 11541 File Trailer Service name ............. STSLIB.005 Service Sub Level Hame... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Tl~e ................ LO Next File Name ........... STSLIB.006 First Reading 11153.5 11172 11153.5 Last Reading 1154'1 11510.$ Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMNLARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11511.0 11761.5 ROP 11541.5 11791.0 $ LOG HEADER DATA DATE LOGGED: 18-FEB-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DO~qHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11791.0 TOP LOG INTERVAL (FT): 11541.0 BOTTOM LOG INTERVAL (FT): 11791.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM] VENDOR TOOL CODE TOOL TYPE NGP NATURAL GANh~A PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 64.6 95.0 TOOL NUMBER PB02100HWRG6 3. 750 BOREHOLE CONDITIONS MUD TYPE: FloPro MUD DENSITY (LB/G): 8.70 MUD VISCOSITY (S): 65.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3): 5.0 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TE~4PERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): RE~RKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-t~e...0 · 0 141.7 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FPH 4 1 68 4 2 GR M%qD050 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 11511 11791 11651 561 ROP MWD050 FPH 1.64 574.03 116.443 500 GR MWD050 API 34.87 120.83 78.1973 502 First Reading For Entire File .......... 11511 Last Reading For Entire File ........... 11791 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Nun~er ........... 1.0.0 Date of Generation ....... 02/05/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 First Reading 11511 11541.5 11511 Last Reading 11791. ]1791 11761.5 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/05/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation NubS, er ...... 01 Next Tape Name ........... UNKNOWN Con~ents ................. STS LIS Writing Library. Reel Trailer Service name ............. L!STPE Date ..................... 02/05/13 Origin ................... STS Reel Name ................ Continuation Nuraber ...... 0i Next Reel Name ........... UNK~O%YM Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File