Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
201-001
Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 7/30/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240730 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 14B 50133205390200 222057 5/22/2024 YELLOW JACKET PERF BCU 14B 50133205390200 222057 6/11/2024 YELLOW JACKET GPT-PLUG-PERF BCU 19RD 50133205790100 219188 7/17/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 7/1/2024 AK E-LINE CBL BRU 222-26 50283201950000 224035 7/11/2024 AK E-LINE PressureTemp CLU 16 50133207200000 224021 5/16/2024 YELLOW JACKET SCBL CLU 16 50133207200000 224021 5/31/2024 YELLOW JACKET SCBL END 2-14 50029216390000 186149 5/9/2024 YELLOW JACKET PLUG KU 33-08 50133207180000 224008 5/9/2024 YELLOW JACKET GPT-PLUG-PERF MPU H-08B 5.00292E+13 201047 7/14/2024 READ CaliperSurvey MPU I-40 50029236890000 220071 7/6/2024 AK E-LINE TubingCut MPU R-101 50029237930000 224078 7/16/2024 YELLOW JACKET SCBL MPU S-17 50029231150000 202173 7/12/2024 AK E-LINE TubingCut MPU S-17 5.00292E+13 202173 7/18/2024 READ CaliperSurvey PBU NK-43 50029229980000 201001 6/11/2024 YELLOW JACKET PL PBU PTM P1-13 50029223720000 193074 7/4/2024 YELLOW JACKET PL Pearl 11 50133207120000 223032 7/10/2024 AK E-LINE Plug/Perf Please include current contact information if different from above. T39310 T39310T T39311T T39312T T39312 T39313 T39313 T39314 T39315 T39316 T39317 T39318 T39319 T39319 T39320 T39321 T39322 YELLOW PBU NK-43 50029229980000 201001 6/11/2024 JACKET PL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.07.30 13:09:33 -08'00' OF TtJ • • 9,4 I/7, %, THE STATE Alaska Oil and Gas '� e T Conservation Commission .- -�- �, o fALASc � �,,,2__ !, 333 West Seventh Avenue * GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Travis Alatalo Production Engineer ® �flAR 3 20 6 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field,Niakuk, Prudhoe Bay and Raven Oil Pools, RAVN NK-43 Permit to Drill Number: 201-001 Sundry Number: 316-118 Dear Mr. Alatalo: 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, Cathy '. Foerster Chair DATED this 23 day of February, 2016. RBDMS L1-- FEB 2 4 2016 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ON APPLICATION FOR SUNDRY APPRO S 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations Q- Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate Q - Other Stimulate 0 Pull Tabing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Clot j'+'1 Ii 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 201-001 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development Q 99519-6612 Stratigraphic 0 Service 0 6. API Number 50-029-22998-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? 4 I [� Will planned perforations require a spacing exception? Yes 0 No Q RAVN NK-43 • CC !' 9. Property Designation(Lease Number): 10. Field/Pools: FEB 10 ZQ1U / ADL 0034635` PRUDHOE BAY,NIAKUK OIL/PRUDHOE BAY,RAVEN OIL.n Ts `31/4 11. PRESENT WELL CONDITION SUMMARY AOC"'°‘;C Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13948• 10074 • 13905 10033 13859 Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20"91.5#H-40 34-112 34-112 1490 470 Surface 7031 10-3/4"45.5#L-80 34-7064 34-5114 5210 2480 Intermediate 13649 7"26#L-80 32-13680 32-9824 7240 5410 Production Liner 600 4-1/2"12.6#L-80 13348-13947 9522-10073 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 31 -12984 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"DOS SSSV 2134/2047.63 12.Attachments: Proposal Summary 0 Wellbore Schematic Q 13.Well Class after proposed work: Detailed Operations Program Q BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development Q • Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil Q . WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Alatalo,Travis be deviated from without prior written approval. Email Travis.Alatalo@bp.com Printed Name Alatalo,Travis Title Production Engineer Signature ,Gam ,_ Phone +1 9075645351 Date L. / p1 / / 6 C/ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 2D `(Q_1 \ 13 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No IEI / Spacing Exception Required? Yes 0 No IR'' Subsequent Form Required: f 0 — 4 (2 g. Approved by: PAPPROVED BYTHE COMMISSIONER COMMISSION Date:Z-Z3—,// g4//1 --t_ 71ielik !e ORIGINAL RBDMS Lt— FEB 2 4 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • a) N co m v- N- N N CO N O CO p_ ti CO co a) co CO N N- p CO CO O) CO p O) O) O) O) I- 0.a 0 F' O) N d' 10 CO .0 N- IC) N N-- N 15. O f- 00 LO 0 N N N v U) W 0 co M 'Y cO co > O o) a) a) o) o) 0 > w CL 0 O 0 W Z W W UO W 0 a) gg Jo W 0Y U O ,a 0 0 < Y Y _ u) co J U U W W _ CD r ti CO CN O J _1 J Q Q fn W a' C O co M co co M U EL Z U < OJ J WCD J O v, =E CO 0 0 a 1 a U U 0 W Z ~ 0 = t'7 W W W a � 1- Q _JQ o Tr 2 2 2 O u) co co co co RI 1 < 0. Lo C z t IC) N- O a N CO N N- _O > a, r- '- N CO N- 47, COCOCOCO LLL 0 O 2 ccco = 00 (1) ta 2 2 O co co cn co co O O. a) Ts oU c ° LL LL N Li_ a ill O 3a. a dcnCDQm a 0 a, d 0- 2 m F- o r r-- .- co O p 0 0 0cz, 0 0 > CO co N. ,, N Z W W 0 CO p N N 'IT Z a `9W0 al 0 WW W a W 0 0 1- 0 CO moz � zwJJ —' oaa < < mamcc) U it LL d a ct m E co Z co co co co co a a co O a N cc LL_ m COcndWZZZZZ < < m U- E L_ • • Packers and SSV's Attachment RAVN NK-43 SW Name Type MD TVD Depscription NK-43 SSSV 2134 2047.63 4-1/2"QOS SSSV NK-43 TBG PACKER 12927.79 9150.08 4-1/2" Baker S-3 Perm Packer NK-43 PACKER 13347.58 9521.77 5" Baker ZXP Top Packer • • To: AK, D&C Wireline Operations Team Lead AK, D&C Well Services Team Lead Date: January 11, 2016 From: Todd Sidoti, Well Intervention Engineer Travis Alatalo, NK PE Subject: NK-43 Coiled Tubing Squeeze 1 S Drift to deviation. Dummy GLVs. Perform SBHPS. 2 F MIT-IA 3 C Squeeze 4 C WOC 3 days. Clean out 5 E Re-perforate 6 S Set live GLV design Current Status: Operable Max Deviation: Max 54° @ 3798' Last Downhole Op: 3/12/15 SBHPS Last Tag 3/12/15 Tagged hard bottom at 1.75" centralizer&s-bailer Minimum ID 2.313" @ 12973' nipple reducer Last BHP/BHT: 3/12/15 4075 psi @ 9850' TVDSS/ 196 F Last test 12/21/15 119 BOPD, 4628 BWPD, 354M form gas, 622 FTP Latest H2S Value: 50 ppm on 1/1/16 Program Objectives: NK-43 is a commingled Kuparuk and Sag producer. Recent logs suggest there is communication between the Sag and Ivishak through the shoe and channeling in cement behind pipe. The most recent PPROF shows 75% of the water coming up from beneath the bottom perfs. The most recent geochemical analysis results show that all of the oil production in this well is coming from the Kuparuk,_supporting the theory that the Sag is being dump flooded by Ivishak water. We will squeeze all current perforations and the shoe, then re-perforate the Sag. Program Contacts Contact Phone -Work Phone -Mobile/Home Interventions Engineer Todd Sidoti 907-564-5113 907-632-4113 Pad Engineer Travis Alatalo 907-564-4476 907-378-3949 CC: Well File North Slope Page 1 of 4 • S Procedure Volumes Tubing top MD bot MD Size ID bbl/ft ft vol,bbls 4-1/2"tub 0 12984 4-1/2"12.6# 3.958 0.0152 12984 197 Casing top MD bot MD Size ID bbl/ft ft vol,bbls 7"liner above sheath 12984 13251 7"26# 6.276 0.0383 267 10 Milled cement in 7" 13251 13348 5-1/4" 5.75 .032 97 3 4-1/2"liner 13348 13859 4-1/2"12.6# 3.958 0.0152 511 8 .... ... ...... CT Squeeze: 1. MIRU 1.75" CT, tanks, and associated squeeze equipment. 2. Liquid pack well by bullheading 200 bbls of 2% KCI at-120 F followed by 130 bbls of warm diesel down tubing. This should make the WHP underbalanced by 200 psi. 3. RIH with ball drop cementing BHA and dry tag TD. Pull up 10' and paint flag. 4. Pump the following schedule: a. 5 bbl FW spacer b. 24 bbls LARC c. 5 bbl FW spacer d. 60/40 FP 5. Once cement exits the nozzle allow 1 bbl to circulate above the nozzle and lay in the remaining volume 1:1 to WCTOC. 6. Pull up to safety and once a 500 psi pressure bump is observed perform hesitation squeeze. Aim for a 3000 psi squeeze. 7. Drop ball, contaminate with powervis and jet down to TD. a. Keep-850 psi whp throughout the contamination and cleanout. 8. POOH jetting & chasing contaminated slurry at 80%. Made an additional pass across the 12984-13348' 7" lap. Jet across jewelry. 9. At surface RIH displacing coil to methanol. FP well with 40 bbls of 60/40 meth. The depth requested for the methanol top is 2560' MD. Trap 950 psi on WHP which will leave us with an 800 psi overbalance at the squeeze. Record WHP after rigging down. CT Post Squeeze: 1. WOC for 3 days. Record WHP. 2. MIRU CT tanks. Plan on milling with 1% slick KCL& Powervis sweeps. 3. MU underreaming BHA: CTC, DFCV, U/D Jars, Hyd Disconnect, Dual Circ Sub, 2-1/8" underreamer set up for 4-1/2" liner. 4. RIH, performing wt checks as needed. 5. Dry tag TD or TOC and PUH -50'. Begin pumping down CT&establish returns. 6. Mill out cement down to TD. Perform sweeps and short trips as necessary. 7. Circulate bottoms up. POOH to above liner top. 8. Perform a 500 psi MIT of squeeze by pumping down CT with choke closed. Once WHP increases 500 psi, SD pumping & monitor pressure for 15 min. 9. POOH, chasing returns to surface at 80%. 10. FP well. Page 2 of 4 Cement Type: LARC • Thickening Time: 10 hours using BP ramp below Fluid loss: <20-60 mI/30 min Density: 15.8 ppg Pv: 25-45 cp Ty: <51bf/100 ft2 Filter cake: 0.75"-1.0" Free Water: 0 UCA: Pre-job only Cement Thickening time calculations 3 hrs mixing &shearing surface time, Pre-pumping PJSM 3 hour pumping time 1 hour to pressure up to sqz pressure 1 hour at squeeze pressure 1 hour to contaminate 1 hour safety factor Total: 10 hours minimum thickening time BP Cement/Gel Testing Schedule (BP ramp): BHST is 196 F 180 minute Batch time: 90 degF and 0-500 psi 30 minute ramp to 115 deg F and 4000 psi 30 minute ramp to 140 deg F and 5600 psi 30 minute ramp to 155 F at 5600 psi 30 minute ramp to 170 F at 5600 psi 30 minute ramp down to 3500 psi and start a 1 deg F per minute increase to BHST. Hold until end of test. Page 3 of 4 TREE= 4-1/16 • — wa.LHEAD 13-5/8' ORATOR �,/ I� SAFETY NOTES: WELL REQUIRES SSSV. 103.ELEV= 519' ,M` 3 0F.E3 EV 380' Mix Aright= 54 03798' © 2134' 4-112-HES 1-0(0 LANDING N DP D=3.813- etum MD= GAS LFMAIC HEIS MARE3,S °Mum TVD= 900'SS ST MD TVO Dai TYPE VLV LATCH FORT DATE ' 6 3675 3026 52 K(,22-1-S COM Ni 16 10/10)11 10-3/4"GSG,45.5#,L-80,BTC,D.9-950" _4- 7085' S 7444 5356 50 {K8G2-1 S SO MIF 22 10110111 4 10077 7048 50 1 KBG2-LS DM1' INT 0 10/09/11 3 11768 8168 39 ,KSG2-LS 'OMY NT 0 05/12107 2 12531 8806 31 K(3G2-LS DMf Nr 0 105112/07 1 12840 9073 29 KBG2-LS DFM NT 0 105/12/07 "ST#3=DM Y HAS EXTE3 DED PKG&COVERED BY PATCH 11754'-11789'ELM =4-111'5"(021106) X2.45"(09//21!(X1} J II N ' 12907' -j 41/2"x MP,D=3.113'1 Minimum ID=2,313"t 12973 x 4 ir '928 1 ���( 2921r BAKaz S-3 PKn 4-112"x 2-718"NIPPLE REDUCER2:1 ` 2 'J-117 -- --- ' , 12951' H4-112"X NP,D=3-813" 12973' I_44-1/2'XN NP,D=3.725" r 12973' —I4-1/2"x 2-718"X NP REDUCER(09116/06) 4-1/2"TBG,12.611/,L-80..0152 f,D=3 958" ; 12984' 2 r 12984' � � I"—�--, � 1-�4-1tP"W(FG,D=3.958"j 13112975' --(ELry TT LOGGED 03/10101 t3r�s_a P13251' I-TOP OF F,LLED Ca lir(01/04/06) 13348' f—5"X T BKR ZXP LNR TOP F1 R 17"CSG,26#,L-80,.0383 bp1,10=6 2(6' 13641' , PERFORATKJfJ SUMMARY FIEF LOG ADN 02/07101 ANGLE ATTOP PERF. 28°@13121` :'-T .:. Note Refer to Roduclion DB for historical perf data SIZE SFT NTET7VAL Opn/Sgz' SHOT SOZ 2-718" 6 13121 13171 0 05/04/01 2-7/8" 6 13121-13171 0 07/08/01 2-7/8" 6 13185-13196 S 06/27)01 2-7/8" 6 13227-13242 S 06/27/01 2" 6 13674-13704 0 05/24/07 2-78" 6 13674-13704 0 05/04/01 2-718" 6 13710-13740 0 054)4/01 ilk 13859' 1-1 FIS - 144_LB 3 BKR(.EP(01/04106) i4-1/2"TBG 12.6#,(-80 FIT-M, i-- 13948' I D158hot,Os-3958 14,1.441444..4 •4414441 DATE (REV BY COMNBJTS CA.TE REV BY 0314Ae/TS PR CHDEBAY(x4( 02/10101" GM( ORIGINAL COMPLETION ;05121/07 MGS/TLH GLV C/O WELL N�-43 01/04/06'BMOC-Lk PALL CMT/EC /FLL_(EP --t 06101/07 Jbf/PAG REEDY I41U VAL(05,24/07) FUS4T No.'2010010 09/22/06IRLMPAG SET BKR PATCH(09121/06) 01/05)10 GWIPJC GLV(10(12/31/09) Al1No:50-029-22998 10/02/06(TWSIPAG FULLED XX TTP til 12973' 02/18/11 MB/JMD ADDED SSSV SAFETY NOTE SEC 36,T12N,1215E 1441'NSL&802'EVYL 12/18/06(CJNPAG GlV C/O 10)12/11 TA/PJC GO/CPO(10/09-10/11) 05/12/07 j JRPIPAG GLV CFO — -_ BP Exploration(Alaska) Page 4 of 4 • • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 July 6, 2011 JU • Mr, Tom Maunder a 0 _ ©O 1 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA Niakuk Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA Niakuk 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, Mehreen Vazir, at 659-5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Niakuk Date: 05/15/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbis ft na gal NK -01A 1760280 500292015801 P&A 3/9/91 NA NA NA NA NA NK -02A 1780790 500292018001 P&A 3/13/91 NA NA NA NA NA NK -03 1780940 500292035000 P&A 4/14/80 NA NA NA NA NA NK -04 1842000 500292121700 P&A 4/14/96 NA NA NA NA NA NK -05 1850270 500292129000 P&A 4/15/96 NA NA NA NA NA NK-06 1852760 500292148800 P&A 4/15/98 NA NA NA NA NA NK -07A 2010630 500292241001 0.2 NA 0.2 NA 0.9 4/30/2011 NK-08A 2010290 500292249101 0.2 NA 0.2 NA 0.9 4/30/2011 NK-09 1941400 500292251800 2.1 NA 2.1 NA 17.0 4/30/2011 NK -10 1931840 500292242500 1.5 NA 1.5 NA 11.9 4/30/2011 NK -11A 2020020 500292278901 1.5 NA 1.5 NA 11.9 4/30/2011 NK -12C 2030550 600292241403 1.8 NA 1.8 NA 31.0 4/30/2011 NK -13 1961340 500292289300 2.3 NA 2.3 NA 22.1 5/4/2011 NK -14A 2060310 5002922668801 1.8 NA 1.8 NA 17.0 5/4/2011 NK -15 1970320 500292274500 1.8 NA 1.8 NA 18.7 5/4/2011 NK -16 1940220 500292244700 2.5 NA 2.5 NA 20.4 5/4/2011 NK -17 1981650 500292270900 3 NA 3 NA 20.4 5/4/2011 NK -18 1931770 500292242100 2 NA 2 NA 17.0 5/6/2011 NK -19A 2010700 500292260701 1.8 NA 1.8 NA 15.3 5/8/2011 NK -20A 2050400 500292242901 2.1 NA 2.1 NA 13.6 5/9/2011 NK -21 1940860 500292248700 2 NA 2 NA 22.1 5/15/2011 NK -22A 2012280 500292240201 1.5 NA 1.5 NA 11.9 5/11/2011 NK -23 1940350 500292245500 3.6 NA 3.6 NA 20.4 5/10/2011 NK -25 1970680 500292276000 2.5 NA 2.5 NA 15.3 5/11/2011 NK -26 1940050 500292244000 2.9 NA 2.9 NA 17.0 5/11/2011 NK -27 1950210 500292254700 2.3 NA 2.3 NA 13.6 4/30/2011 NK -28 1960930 500292267800 Sealed Conductor NA Sealed Conductor NA NA NA NK -29 1981900 500292272400 1.7 NA 1.7 NA 10.2 4/30/2011 NK -38A 2042410 500292254001 3.1 NA 3.1 NA 13.6 5/6/2011 NK-41A 1971580 500292277801 9.1 NA 9.1 NA 54.0 5/9/2011 NK-42 1941080 500292249900 2 NA 2 NA 13.6 5/9/2011 NK-43 2010010 500292299800 1 NA 1 NA 5.1 5/9/2011 NK-61A 2060350 500292289301 14 NA 14 NA 110.5 5/15/2011 NK-82A 2030470 500292285201 1.3 NA 1.3 NA 13.6 5/4/2011 NK-85A 2050630 500292288901_ 1 NA 1 NA 8.5 5/6/2011 • • BP closes site over loss in Slope rent dispute HEALD POINT: Oengas fight oil giant over rent for use of their land. By ELIZABETH BLUEMINK \V--1C6 ebluemink@adn.com adn.com k \L-- c a os - 0(c." Published: January 4th, 2011 10:09 PM "—� ��l—' t ' - ‘3 a0 — OO Last Modified: January 4th, 2011 10:09 PM N �L� \ C a 0 \ _ oi BP shut down a small portion of the Prudhoe Bay oil field last week after a judge ruled that federal regulators failed for years to get approval from the Inupiat Eskimo family that owns the land. ( S 1 S; NED JAN Heald Net Is\\Q) .. tM as.i 7rM_ 1 lncatica A hRArA — A 'uc6R» ` 1. '' Y 4 + m r -i x F Photo courtesy of BP Exploration (Alaska) Inc. Heald Point drill pad at Prudhoe Bay has been used to access oil from several oil pools, including Raven. The BIA told BP to suspend Raven production in late December due to a court ruling. Read more: http://www.adn.com/2011/01/04/v- gallery /1631936/bp- closes- site - over - loss- in- rent.html #ixzz l AB7r0Irl • • The shutdown affects less than 1 percent of production from the nation's largest oil field, but so far it's the most visible consequence of a significant legal victory for the Native family, which has battled lawyers for the federal Bureau of Indian Affairs and BP in federal court over the oil production from its land. Federal claims court judge Nancy Firestone ruled this fall that the Oenga family is owed millions in unpaid rent because the BIA improperly allowed BP to tap three offshore oil deposits from the family's allotment on the northern edge of the vast Prudhoe oil field. The BIA approved BP's expanded use of the allotment without the family's consent, in violation of the family's contract with BP, Firestone said in her 168 - page ruling on Nov. 22. A week ago, the BIA told BP to shut down production from Prudhoe's Raven unit, the only one of the three disputed offshore deposits that BP was still accessing from the allotment. BP shut down Raven, which produced about 25,000 barrels of oil in November, on Friday. BP is still legally tapping the Niakuk field from the allotment. The battle over unpaid rent and unauthorized land use involves a nondescript finger of land called. Heald Point that extends into the Beaufort Sea. The Oenga family acquired its 40 -acre allotment at Heald Point decades ago for subsistence hunting. But in 1989, the family patriarch, Andrew Oenga, signed a contract with BP allowing the oil giant to use Heald Point as a right of way. Years later, believing that BP was giving the family annual rent payments much lower than the land's true value, eight of Oenga's heirs -- including two children, his grandchildren and great - grandchildren -- sued the BIA in 2005. The family said it had to go to court because it was unable to persuade the agency, which is in charge of collecting the family's rent from BP, to take action on its behalf. In an eight -day Lower 48 trial last July, the agency and the oil giant defended themselves against the Oengas' claims. BP argued in court filings that no additional money was owed to the family. The BIA argued that the family's claims for unpaid rent were exorbitant. • • The judge ruled for the family, saying the BIA owes it roughly $5 million for the unauthorized use of the land, but she also said that BP is paying too little for the land it is authorized to use. The judge is still taking briefings on the exact amount owed but it will be far below the $200 million the Oengas originally sought. BP Alaska spokesman Steve Rinehart said Tuesday the company is evaluating its best path forward on a potential appeal. He emphasized that Raven represented a fraction of Prudhoe's output. BIA's acting director in Alaska did not return a call for comment on Tuesday. In a written statement late week, Oenga family member Tony Delia said the family is willing to end the matter. "Earlier this month we made BP a fair offer -- pay what is owed and we will renegotiate the lease so they can use our land to produce from Raven and wherever else they want to drill. They haven't responded," he said. According to a written statement from the family's attorney, Ray Givens, the total amount owed the family is $15 million. That figure includes the Oenga family's calculation of how much additional money it is owed in unpaid rent for BP's authorized use of the land, which was not part of the this lawsuit. In her ruling, Firestone said evidence from the trial showed that BP withheld critical information about Heald Point's strategic value for oil development when it negotiated a contract with the family to use the land. "Clearly, (BP) did not wish to share much with the plaintiffs," she wrote. Find Elizabeth Bluemink online at adn.com /contact/ebluemink or call 257-4317. Read more: http://www.adn.com/ 2011 /01/04/1631936/bp- closes - site - over - loss -in- rent.html#ixzz 1 AB73YsM3 ~~~ PROACTIVE DIAGNOSTIC SERVICES INC. ~~L LO6 1°R4/USf7`T.4L To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ~. ~~1 ,_ ~~ ~~~, ~, ,b: :~r~w_~4,.s: ~s...~- RE : Cased Hnle/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Static Spinner Survey 18-Mar-10 NK-43 a~ ~-~j l ~s~- a • 1 BL / EDE 2] _ Signed : Date Print Name: 50-029-22998-00 ,; -_, . ~- ~, °~,. ~ "~ `. ~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907j245-8951 FAX: (907)245-88952 E-MAIL : P~S~fHCI1dDr~q@(U~1'712t7DOrldioQ.B;€39r! WEBSITE: w/WW.tTiBlT60r~tlog.carn C:\Documents and Settings\Diane WilliamslDesktop\Transmit_BP.docx S -26 Commingled Production R- • Page 1 of 1 Schwartz, Guy L (DOA) From: Ohms, Danielle H [Danielle.Ohms @bp.com) Sent: Friday, October 16, 2009 5:28 PM To: Schwartz, Guy L (DOA) 0 S Subject: S-26 Commingled Production Report Guy, Following up on the S -26 Commingled Production Report, "RE: Conservation Order 4578 (Rule 13) and Conservation Order 341 D (Rule 18) - Commingled production from the Aurora Oil Pool and Prudhoe Oil Pool in Well S -26" sent on 4 -29-09. Attachment 1: OilTracers Report No. 09-826 was listed as Confidential. I discovered that in order to change this labeling I would need to get approval from the GPB co- owners. A similar report for NK-43 sent to AOGCC on 6 -19 -07 did not include this detailed report from OilTracers. We provided the OilTracer data as back -up for S -26 though it likely did not need to be included as all of the relevent information is summarized in the report 1I0 woul&HketakeWthecarollelential iabelin9 on OwOffracers report included as an ,1. -00\ attachment. Danielle Ohms BP Exploration _(Alaska) Inc. GPB West Waterflood Lead PE .(907) 564 -5759 i nn i nnn9 ~ _ STATE OF ALASKA . ¿ -/-éJ? ALA" OIL AND GAS CONSERVATION COM ION ~ ~ REPORT OF SUNDRY WELL OPERATIONS q)' D Stimulate D Other D ~ D Waiver D Time Extension D ~ íJ' ~ o Re-enter Suspended Well D ~ 0o?, 5. Permit to Drill Number: ~~ 201-0010/ .. 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Ope rat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 53.9 KB 8. Property Designation: ADLO-034635 11. Present Well Condition Summary: .¿ Total Depth measured 13948 I true vertical 10073.68 I Effective Depth measured 13905 true vertical 10033 Casing Conductor Surface Production Liner Length 80' 7032' 13609' 600' Size 20" 91.5# H-40 10-3/4" 45.5# L-80 7" 26# L-80 4-1/2" 12.6# L-80 Perforation depth: Measured depth: 13121' - 13740' True Vertical depth: 9321' - 9879' 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 367 SHUT-IN x / Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development W Stratigraphic Exploratory Service 6. API Number: 50-029-22998-00-00 ... ~ 'P 9. Well Name and Number: NK-43 / 10. Field/Pool(s): PRUDHOE BAY Field/ NIAKUK OIL Pool - feet feet Plugs (measured) NONE Junk (measured) Milled BKR CIBP @ 13859' feet feet MD 34' - 114' 33' - 7065' 32' - 13641' 13348' - 13948' TVD 34' - 114' 33' - 5114' 32' - 9788' 9522' - 10074' Burst nm>' 5210 7240 8430 ~GANNED JUN 1 4 2007 - - - - 4-1/2" 12.6# L-80 32' - 12984' 7"X4-1/2" BAKER S-3 PKR 5"X7" BAKER ZXP LINER TOP PACKER o o 12928' 13348' o o RBDMSBFl JUN 1 3 2DD7 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 805 864 0 o 0 0 15. Well Class after proposed work: Exploratory Development W 16. Well Status after proposed work: Oil W Gas WAG Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WINJ Contact Gary Preble Signature Title Data Management Engineer Phone 564-4944 Date 5/29/2007 ~~ ~,Þ 0~ ,. Collapse 470 2480 5410 7500 ''''' Tubing pressure 502 o WDSPL R , GIN AI 11 / Submit Original Only "11:...., 0 (' . . NK-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY BBLS I 1 DIESEL 1 TOTAL 5/24/2007 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O: 2550/ UNKNOWN/ O. PERFORATE 13674' - 13704' USING 2" HSD PJ HMX GUN, 6 SPF, 60 DEG PHASING. POSITIVE INDICATION OF SHOT SEEN ON SURFACE. WELL LEFT SHUT-IN. FINAL T/I/O = 2550/ UNKNOWN/ O. ***JOB COMPLETE*** FLUIDS PUMPED Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 03/15/2007 NO. 4184 cJO {-WI Company: State of Alaska Alaska Oil & Gas Cons Gomm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Loa Description Date BL Color CD Z-20 11686722 PRESS/TEMP SURVEY 02/26/07 1 P2-35 11657107 PRODUCTION PROFILE 02/19/07 1 L5-28A 11661127 MEMORY STP 01/30/07 1 NK-43 11686716 PRODUCTION PROFILE 02/17/07 1 C-06B N/A MEM PROD PROFILE 02/25/07 1 05-31A 11686719 SCMT 02/19/07 1 03-02 . 11626072 USIT CORROSION EVALUATION 02/22/07 1 03-02 11626072 USIT CEMENT EVALUATION 02/22/07 1 2-54/Q-12 11626376 USIT 02/22/07 1 4-18/S-30 11638613 USIT 02/12/07 1 DS 03-08 11630455 USIT 02/07/07 1 DS 16-20 11666863 PRODUCTION PROFILE 01/26/07 1 14-24 . 11549359 RST 12/26/06 1 1 U-06BPB1 40011873 OH EDIT MWD/LWD 05/01/05 2 1 U-06B 40011873 OH EDIT MWD/LWD 05/08/05 2 1 . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. st;ANNED APR 0 3. 2007 Petrotechnical Data Center LR2-1 900 E Benson Blvd Anchorage, Alaska 99508 Date Delivered: ILl Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth '\ Received by: Ü_ !\~Ar{ ~ ;!r nlOI e 0 011 escriptlon ate olor D P2-37A 11491392 MEM PROD PROFILE 11/15/06 1 Y-23B 11418299 MEM PROD PROFILE 09/06/06 1 NK-07A 11588698 MEM GLS 12/21/06 1 07-01A 11555031 GAS ENTRY SURVEY 12/19/06 1 NK-08A 11485780 MEM GLS 12/20/06 1 NK-27 11588699 MEM GLS 12/22/06 1 NK-43 11513659 PRODUCTION PROFILE 12/22/06 1 DS 09-32 11555530 INJECTION PROFILE 12/16/06 1 P2-14 11539745 MEM PROD PROFILE 12/07/06 1 Y-05A 11539744 MEM INJECTION PROFILE 12/06/06 1 S-02Ä 11285936 MEM PROD PROFILE 08/17/06 1 12-32 11536184 USIT 12/05/06 1 MPS-10A 11486087 COMPOSITE WFLlLDL 12/14/06 1 Z-19A 11226013 SCMT 10/28/06 1 Y-30L 1 11588700 MEM PROD PROFILE 12/23/06 1 E-11 B 11434757 DSI 10/24/06 1 E-11 B 11434760 DSI 10/29/06 1 E-11 B 11434760 FMI 10/29/06 1 G-14A 11485777 MEM PROD PROFILE 11/27/06 1 G-14A 11485777 SCMT 11/27/06 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WII " '~~ é)OI ~OOI 01/25/2007 NO. 4125 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay D BL C C . J b# L D . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: SCANNED JAN 3 0 2001 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 'J\ 12/11/06 Schlumbergep NO. 4070 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Orion Prudhoe Bay Well Job# Log Description Date BL Color CD V-211 40011188 OH EDIT OF MWD/LWD 11/17/04 2 1 S-213A 40011201 OH EDIT OF MWD/LWD 12/11/04 2 1 DS 09-13 11491394 MEM PROD PROFILE 11/24/06 2 14-3OA 11485775 MEM PROD PROFILE 11/21/06 2 DS 09-36C 1149225 INJECTION PROFILE 11/23/06 2 W-12A 11418301 MEM PROD PROFILE 09/10/06 2 Y-29A 11485776 MEM PROD PROFILE 11/25/06 2 NK-43 11414407 PROD PROFILE WIDEFT 10/26/06 2 6-13A 11212899 USIT 11/05/06 1 14-3OA 11485775 SCMT 11/22/06 1 DS 02-39L 1 11491395 SCMT 11/25/06 1 - . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd Anchorage AK 99508-4254 Date Delivered DEC 1 3 zmm Schlumberger-DCS 1l 2525 Gambell St. Suite 400 . Anchorage, AK 99503~283 ATTN: Beth e Received by:./ --. . <, t, ,f;,. ,., Mj~;W~" ~~",~'-~~~~.1~; l,,¿; 90 l -()O ( RECEIVED 1/J-S/cb STATE OF ALASKA . SEP 2 2 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL oPE~fltl~~shCons. Commission ~c orage . ;.¡ 1. Operations Performed: Abandon 0 Alter CasingO Change Approved ProgramO 2. Operator Name: 3. Address: . ~f¿ Repair WellŒJ Pull TubingD Operation ShutdownD Pluç Perforations 0 Perforate New Pool 0 Perforate 0 Stimulate 0 WaiverO 4. Current Well Class: Development 00 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 53.90 8. Property Designation: ADL-034635 11. Present Well Condition Summary: Total Depth ExploratoryO OtherD Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 201-0010 6. API Number 50-029-22998-00-00 measured 13948 feet true vertical 10074.0 feet Plugs (measured) None measured 13905 feet Junk (measured) Milled BKR CIBP @ 13859 (01/0412006) true vertical 10033.0 feet Effective Depth Casing CONDUCTOR SURFACE PRODUCTION LINER Length 81 7031 13607 600 Perforation depth: StratigraphicD ServiceD 9. Well Name and Number: NK-43 10. Field/Pool(s): Prudhoe Bay Field 1 Niakuk Oil Pool Size 20" 91.5# H-40 10-3/4" 45.5# L-80 7" 26# L-80 4-1/2" 12.6# L-80 TVD - 114.0 - 5114.0 - 9788.0 - 10074.0 MD . 114 - 7065 . 13641 - 13948 33.0 34.0 34.0 9522.0 33 34 34 13348 SCANNED SEP 2 41 2DDB Measured depth: 13121-13171,13674-13704,13710-13740 True vertical depth: 9321-9365,9818-9846,9851-9879 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 32 - 12984 Packers & SSSV (type & measured depth): 4-1/2" BI<R KB Patch 7" Baker S-3 Packer 7" Baker ZXP Liner Top PKR 4-1/2" HES HXO Landing Nip @ 11768 @ 12928 @ 13.348 @ 2134 - 11810 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 _ Burst Collapse 1490 470 5210 2480 7240 5410 8430 7500 RBDMS 8FL SEP2 (1 7006 Oil-Bbl SI 348 o 1,235 Representative Daily AveraQe Production or Iniection Data Gas-Mef Water-Bbl Casing Pressure Tubing Pressure 536 556 o 345 2{ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilOO GasD -.- --. DevelopmentŒJ serviceD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. /Sundry Number or NIA if C.O. Exempt: / N/A Title Petroleum Engineer 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWaY[1e R. Schnorr ^ Signature ~.n/ - RfC_~ J! .-/ Phone 564-5174 ) . I 1\ I Form 10-404 Revised 4/2004 L I f\ I D I I \J J-\ L Date 9/19/06 . . NK-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/07/2006 *** WELL SHUT IN ON ARRIVAL *** RAN 2.90 SETTING SUB BEAT ON PATCH FOR ONE HOUR. MIT IA TO 2000 PSI FAILED LOST 325 PSI IN 15 MIN. **** WELL LEFT SHUT IN AND TURNED OVER TO DSO *** 08/20/2006 (post patch Idl) LRS PRESSURED UP IA TO 3000# . LOGGED PDS LDL TOOLS AS PER PROGRAM. LEAK APPEARS TO BE IN PATCH @ 11,756' . LRS PERFORMED TWO MIT'S ON IA , ONE PASSED. RAN 2.88 SWAGE TO TOP OF PATCH @ 11, 736'SLM , JARRED DOWN LIGHTLY ON PATCH. ATTEMPTED MIT ON IA W/TRIPLEX , MIT FAILED. ***WELL LEFT SII ON DEPARTURE*** 08/20/2006 TII/O=2250/1 000/1 00 Assist slickline w/ LDL - Pumped 50 bbls crude down IA for LDL. MIT IA 3000 psi Pressured IA to 3000 psi. IA lost 20 psi in 1 st 15 min. IA lost 40 psi in 2nd 15 min. -IA taking less fluid to maintain 3000 psi during LDL - Performed MIT while waiting on PDS data. Possible gunk plugging off leak?? 08/19/2006 T/I/O=1850/850/150 Assist slickline with LDL, Pressured up IA with 7 bbls crude. FWHP's=2200/760/150 08/19/2006 ***WELL S/I ON ARRIVAL*** (post patch Idl) DRIFTED W/2.25 CENT,TEL,& S.B. TO 13,736'CORR ELMO. BTM OPEN PERF @ 13,740',4' OF FILL. SAMPLE OF FORM SAND. RAN PDS LDL TOOL AS PER PROGRAM. LOGGED FROM 12,968'SLM TO 12,289'SLM AND HAD TO SHUT DOWN FOR FLUID. STANDBY FOR LRS. 08/16/2006 T/I/O=2250/800/180. Temp=SI. IA FL. (Pre-SL techwell). IA FL @ Surface. 08/07/2006 T/IIO=2220/770/160. Temp=SI. LLR-IA (post failed MIT-IA, pre LDL) w/triplex. IA FL @ surface. Pumped 8.2 bbls of diesel to achieve 1950 psi. Pumped 75 gals for 10 mins @ 1950 psi=LLR of 7.5 gals per min. Final T/I/O=2220/780/160. 08/02/2006 T/I/O=1940/290/60. Temp=SI. WHP's. 07/19/2006 MIT IA FAILED to 3000 psi. (Post Patch) Pumped 13 bbls crude down IA. 3rd test lost 2000 psi in 15 min. Final WHP's= 2120/250/0 07/18/2006 T/I/O= 2120/750/0 Temp= S/I MIT IA 3000 psi (Post Patch) - Bled lAP from 750 psi to 100 psi. Pumped 25 bbls crude down IA. 07/18/2006 T/I/O=2150/1200Nac Temp=SI MIT IA 3000 psi **POST-PONED** called to assist S/L 07/14/2006 T/I/O= 2140/2220Nac. Temp= SI. Bleed WHP's (pre MITIA, call in initial/final Pressures). AIL line SI @ IA casing valve. fA FL @ 6077' (106 bbls) between sta# 5 & 6. Bled lAP to production from 2220 psi to 490 psi in 1.5 hours. During bleed tubing pressure decreased 100 psi. Monitored for 30 minutes. IA FL 5270'. lAP increased 10 psi. Final WHP's= 2040/500Nac. **Note: Needs to be re-freeze protected.** Page 1 . . NK-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/14/2006 MIT IA to 3000 psi (INCONCLUSIVE) (Restore TBG integarty post patch) Second test- MIT IA pressured up to 3000 psi with 8.5 bbls crude. IA lost 150 psi in 15 minutes and 80 psi 2nd 15 minutes. For a total of 230 psi in 30 minutes. Need to bleed IA gas off and attempt again. Bleed pressure down. FWHP's=2150/2600/vac 07/13/2006 TII/0=2100/2000/VAC temp=SI MIT IA to 3000 psi (Restore TBG integarty post patch) First test failed---MIT IA pressured up to 3000 psi with 56 bbls crude. IA lost 190 psi in 15 minutes and 110 psi 2nd 15 minutes. For a total of 300 psi in 30 minutes 07/13/2006 T/I/O= 2090/1970/Vac. Temp= SI. IA FL (Fullbore PE). AIL line SI @ IA casing valve. IA FL @ 7599' (133 bbls) below sta# 5. 07/12/2006 T/I/0=2080/1980/VAC, Temp=SI. IA FL (pre-MITrA). AlLP=2290 shut-in @ casing valve. IA FL @ 7646' (134 bbls). Between STA# 4 & STA# 5. 07/11/2006 (dmy off glm's) SET DMY GLV @ 7422' SLM STA#5 SET DMY GLV @ 10052' SLM STA#4 PULLED WHIDDON C.S. @ 11710' SLM (EMPTY) ****LEFT WELL SHUT IN**** 07/10/2006 DRIFTED TO SSSV W/ 2' STEM, 3.805" GAUGE RING PULLED 41/2" QOS (SER# QOS- 43) @ 2102' SLM PULLED GLV'S FROM STA'S #4, #5 & #6 SET 1" DGLV IN STA #6 @ 3052' SLM (INT LATCH) 07/03/2006 TII/0=2250/2300/0+ Temp= 58* TIFL***FAILED*** (Post patch, lOR> 500) Shut in well and backflow tubing to 2250 psi. InitiallA FL =11,635' (Between GLM's 3 & 4) Bleed lAP to production from 2300 psi to 570 psi in 1 hr. TBP dropped to 2050 psi and IA FL rose 514' during bleed. lAP increased 30 psi and IA FL rose another 781' to 10,340' during 1 hr. monitor.(1295' total inflow) Post TIFL TBG FL= 8200'. Well released to POP. FWHP= 2050/630/Vac 07/01/2006 TestEvent --- BOPD: 346 BWPD: 1,595 MCFPD: 3,126 AL Rate: 2,673 06/30/2006 CONTROL LINE THAWED OUT. SET 4.5" QOS (SER# QOS-43, TOP TWO SETS ARE 0- SIZED) SET @ 2100' SLM. ***WELL LEFT S/I, ALL VLV's FLAGGED*** 06/29/2006 PULLED STA #6. SET 1" DOME (1/4" PORTS, 2458#) W/ INT. LATCH IN STA #6,1" DOME (1/4" PORTS, 2459#) W/ INT. LATCH IN STA #5 & 1" S/O (5/16" PORTS) W/ INT. LATCH IN STA#4. PULLED WHIDDON. CONTROL LINE FROZEN. FLOWING WELL TO THAW. 06/28/2006 ***WELL SI ON ARRIVAL *** DRIFT TO 3500' SLM W/ 3.625" CENT., SET 4.5" WHIDDON @ 11,729' SLM. PULLED LGLV'S FROM STA #'S 4 & 5, WORKING ON STA #6. 06/25/2006 T/I/O=21 00/21 00/0 TBG Blocked w/ Hydrates. (Shut in)(Post TBG Patch) Bled TBG to Flowline. TBG presseured up to 1500 psi w/ 3.5 bbls Meth pumped. Bled IA to Flowline. Pumped 10 bbls Meth and 290 bbls 180*f Crude into fA. TBG appears to freed up. Pumped 10 bbls Meth and 163 bbls 180*f Crude into TBG. Turn over to DSO to POP. Final WHP's=1500/1250/500 Page 2 . . 1 . NK-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/22/2006 ***WELL SI ON ARRIVAL*** DRIFT W/ 3.625" CENT & SAMPLE BAILER. SAT DOWN @ 940' SLM. RECOVERED ICE SB. RIG DOWN. ***WELL LEFT SI*** 06/18/2006 FINISH RIGGING DOWN. WELL LEFT SHUT IN. TURNED OVER TO DSO. *"'JOB COMPLETE** 06/17/2006 SET BAKER "45" KB STRADDLE PATCH ACROSS GLM #3. PATCH SET 11754' -11789'. NO PROBLEMS RIH OR POOH. 06/17/2006 TII/O=900/1 000/150 Load TBG (pre- e-line patch) Pumped 1 0 bbls neat methanol spear, 207 bbls 1 % kcl and 30 bbls diesel freeze protect. Final WHP's=850/1200/0 06/16/2006 TfO= 860/980/20. Sf. TBG & IA FL's (pre-Patch). TBG FL @ 3228'? (49 bbls), fA FL @ 972' (17 bbls). FLUIDS PUMPED BBLS 4 PT Surface Equipment 10 Neat Methanol 83 Methanol Water 38.2 Diesel 200 1 % KCL Water 549.5 Crude 884.7 TOTAL Page 3 TREE = 4-1116" I I WRLHEAD = 13-5/8" N K-43 SAFETY NOTES: ACTUATOR = 'KB. REV = 53.9' BF. REV = KOP= 380' Max Angle = 54 @ 3798' . 2134' 1-14-1/2" HES HXO LANDING NIP, 10 = 3.813" I Datum MD = Datum ND- 900' SS GAS LIFT MANDRELS ST MD NO DEV TYÆ VLV LA TCH PORT DATE L 6 3675 3026 52 KBG2-LS-MOD DMY INT 0 07111/06 5 7444 5356 50 KBG2-LS-MOD DMY INT 0 07/11/06 L: 10077 7048 50 KBG2-LS-MOD DMY INT 0 07111/06 ~~ 11768 8168 39 KBG2-LS-MOD **DMY INT 0 05/12/06 110-3/4" CSG, 45.5#, L-80, BTC, ID = 9.950" I 7065' ~ ~ -, 12531 8806 31 KBG2-LS-MOD DMY INT 0 .. 1 12840 9073 29 KBG2-LS-MOD DMY INT 0 '- **::>T#3 HAS DMY w/EXT. PCKG J. ~i 11768' H4-1I2" x 42' BKR KB PA TCH, 10= 2.37" (6/17/06) I · I ! 12907' H 4-1/2" X NIP, 10" 3.813" I Minimum ID =2.37" @ 11768 :8 ~ I 12928' H7" X 4-1/2" BAKERS-3 PKR I 4-1/2" X 42' BKR KB PATCH ~ · I I 12951' H4-1/2" X NIP, ID" 3.813" I · I I 12973' 1-14-1/2" XN NIP, ID - 3.725" I /4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID" 3.958" I 12984' 12984' H4-1/2" WLEG I IJ I 12975' H ELMD TT LOGGED 03/10101 I ~ I 13251' H TOP OF MILLED CEMENT (01/04/06) I ~ 8 ..,..., 13348' - 5" X 7" BA KER ZXP LINER TOP PA CKER I ..... I 7" CSG, 26#/FT, L-80, 10" 6.276" I 13641' l-----..4 .. PERFORA TION SUMMARY REF LOG: ADN 02/07/01 ANGLEAT TOP PERF: 23@ 13710' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 13121 - 13171 0 05/04/01 2-7/8" 6 13121 - 13171 0 07/08/01 2-7/8" 6 13185 - 13196 S 06/27101 2-7/8" 6 13227 - 13242 S 06/27/01 2-7/8" 6 13674 - 13704 0 05/04/01 2-7/8" 6 13710 - 13740 0 05/04/01 .,. 13859' H FISH: MILLED BKR CIBP (01/04/06) I I 4-1/2", 12.6#/FT, L-80, IBT-Mod I 13948' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNrr 02110/01 GNK ORIGINAL COM PLETION 07/04/06 TWS/PAG GLV ClO (06/29/06) WELL: NK-43 05/04101 JJ/KA K ADPERFS & CIBP 07/11/06 KSB/TLH GL V ClO ÆRMrr No: "2010010 07/13/01 WW/KAK REPERFS API No: 50-029-22998 01/04/06 BMc N/TLI- MILL CMT/FCO/MILL CIBP SEC 36, T12N, R15E, 1441' NSL & 802' EWL 06/17/06 GJB/PJC SET BKR KB PATCH 06/17/06 GJB/PJC PULLED XN PLUG (5/22/06) BP Exploration (Alaska) . . REl~[:iVF:D WELL LOG TRANSMITTAL AUG 2 9 2006 ProActive Diagnostic Services, Inc. AI8stta 011 & Gas Cons. Commission Anchorage To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 EDE Disk NK - 43 Leak Detect - WLD 20-Aug-06 1) 2) 3) 4) 5) 6) 7) SÇANNED AUG 3 0 2005 Print Name: (\ Q~, CJ ~ Aj-~~e {lp"L Date: if / (-'PI / ()~ , I Signed: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM ÐDI-CD ( -¥ ILfcf67- D:\OO ]DSANC-2006\Z _ Word\Distribution\TransITÚttal_ Sheels\TransITÚt_ Original.doc R~~;:.~" LÙ '.' '"' \ ,\",'EC 1\ \J G ~~r·Ìtl:..· .. ,,- Ç. A ~~ ?\\U:) 1 ~~ -"" AUG 0 8 2006 Schlumbepger ~...G!æ Oil & Gas Cons, Com~ NO. 3883 Anchorage Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Qú{ -00 ( Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Wit BL CD J b # CI L D D e 0 og escrlptlon ate o or NK-43 11211388 ROFILE WIDEFT 04/02/06 1 NK-22A 10568415 PROD PROFILE W/DEFT 02/26/03 1 L4-12 N/A WFULDL 05/09/06 1 L2-21A 10670034 MEM PROD PROFILE 09120104 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 01-17B 11209602 MEM PROD PROFILE 04/27/06 1 09-08 11296705 INJECTION PROFILE 07/21/06 1 09-19 11296704 INJECTION PROFILE 07/20/06 1 09-25 11296703 INJECTION PROFILE 07/19/06 1 04-09 11211398 INJECTION PROFILE 04/28/06 1 04-10 11211380 INJECTION PROFILE 03/23/06 1 17-21 11223104 PROD PROFILE W/DEFT 03/22/06 1 18-03B 11057071 SBHP 12/02/05 1 X-15A 11212877 USIT 07/18/06 1 J-018 11511430 USIT 07/24/06 1 15-12A 11221595 USIT 07/25/06 1 Z-148 11217268 USIT 07/29/06 1 S-400 10987564 CH EDIT PDC-GR OF USIT 01/26/06 1 D-03A 11217269 US IT 07/31/06 1 05-28A 11217267 USIT 07/28/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consultmg Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 08/01/06 . . , bp e e o "''0'""....,..--- ".- BVExploration (Alaska) Inc 900 East Benson Boulevard PO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 20, 2006 Bill Van Dyke, Acting-Director Division of Oil & Gas Department of Natural Resources 550 West ih Avenue, Suite 800 Anchorage, AK 99501-3560 ~;j 0 ADL 034630 - NK-38A Well- Request for Extension of Tract Operation~ ADL 034635 - NK-43 Well - Request for Extension of Tract Operations~ ADL 034635 - NK-65A Well - Request for Extension of Tract Operations ~ Prudhoe Bay Unit G Dear Mr. Van Dyke: Re: On September 12,2005, the Division approved tract operations for BP Exploration (Alaska) Inc. (BPXA) to produce and inject from the Ivishak interval from the NK-38A and NK-65A Wells. This approval is valid until April 1,2006 to allow production and injection during the Raven Participating Area (RP A) application process. On October 27,2006, the Division approved tract operations for BPXA to commingle and conduct production from the Sag River and Kuparuk intervals in the NK-43 Well. This approval is valid for 180 days from the date test production from the Sag River interval in the NK-43 well bore flows into the Lisburne Production Center. Test production commenced on February 3, 2006, and thus this approval extends through August 3, 2006. On" February 8, 2006, BPXA submitted an application with the Division to approve formation of the RPA. The proposed RPA will encompass the Ivishak and Sag River Formations in this area, including production from the NK-38A and NK-43 Wells. BPXA. has also filed an application with the AOGCC for pool rules for a Raven OilPooL To allow continued production and injection for the NK-38A, NK-43 and NK-65A Wells while the Division completes its review and action on the RP A, we request that the above referenced tract operations for each of the wells be extended until September 1, 2006, or the date the RP A becomes effective, whichever occurs first. Please contact Gary Gustafson at 564-5304 if you should have any questions. Thank you. Sincerely yours, ~ ~an~J GPB Manager , e -- CC: Don Ince, ConocoPhillips Alaska Greg Threadgill, ExxonMobil Gary Forsthoff, Chevron Paul Winslow, Forest Oil Gary Benson, BPXA Gary Gustafson, BPXA Art Copoulos, DO&G Jane Williamson, AOGCC NK-43 (PTD #2010010) Classified as Problem Well ,-) S'\'t~Ò(P Sub.iect: NK-43 (PTD #201(010) Classified as Problem Well \«('1[/ . From: "NSU, ADW Well Integrity Engineer" <NSUADWWcllIntcgrityEnginecr@BP.com> Date: Sun, 19 Mar 2006 19: 19:56 -0900 To: "Kincaid, Les" <les.kincaid@BP.eom>, "GPB, GPMA Area Mgr" <GPBGPMA TL@BP.com>, "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@BP.com>, "AOGCC Jim Regg (E-mail)..<jim_regg@admin.state.ak.us>. "AOGCC Winton Aubert (E-mail)..<winton__aubert@admin.state.ak.us>. "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupcrvisor@BP.eom>, "GPB, LPC DS Ops Lead" <GPBLPCDSOpsLcad@BP.eom>, "Kurz, John" <john.kurz@BP.com> CC: "NSU, ADW Well Integrity Engineer" <NSUADWWeIlIntegrityEngincer@BP.com>, "Austin, Paul A" <Pau1.A.Austin@BP.com> All, Well NK-43 (PTD #2010010) has been found to have sustained casing pressure on the IA. The TIO's on 03/19/06 were 2830/2630Nac when the well failed a TIFL. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. WIE: Eval for GLV c/o 3. SL: GL V c/o 4. DHD: Re-TIFL :scP M.J~(p fo!vUitf 7~: 3".3t~ ,.;;.'(" l..;;t \ì),~';~\tL; 01¡¡¡f~-'" 5A ð/'¡ lBO/$. A we II bore schematic has been included for reference. «NK-43.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, }lnna ( )u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ol¿ p{]- (~') /-fì'z.. . (:-4'(% }v1k(f) Content-Description: NK-43.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 3/22/20063:52 PM 4-1/16" 13-5/8" 53.9' NK-43 I SAFETY NOTES: 380' . 2134' H4-1/2" HES HXO LANDING NIP, ID = 3.813" I I 7065' µ ~ GAS LIFT MANDRELS ST MD TVO DEV TYÆ VLV LA TCH PORT DATE 6 3675 2975 KBG2-LS-MOD DOME INT 16 06/17/02 L - 5 7444 5300 KBG2-L5-MOD DOME INT 16 06/17/02 4 10077 7000 KBG2-LS-MOD DOME INT 16 06/17/02 12973' 3 11768 8100 KBG2-LS-MOD SO INT 24 06/17/02 2 12531 8750 KBG2-LS-MOD DMY INT 1 12840 9020 KBG2-LS-MOD DMY INT I I 12907' H 4-1/2" X NIP, ID = 3.813" I :8: ~ 12928' H 7" X 4-1/2" BAKER S-3 PKR I I.<:.:::> I I I 12951' H 4_1/2" X NIP, 10 = 3.813" I I I I 12973' H 4-1/2" XN NIP, ID = 3.725" I I 12984' 12984' H 4-1/2" WIR8..INE ENTRY GUIDE I I 12975' H 8.MD TT LOGGED 03/10/01 I ~ ~ 13251' H TOP OF MILLED CEMENT (01/04/06) I ><: "..., 13348' H 5" X 7" BAKER ZXP LINER TOP PACKER I F-' I 13641' ~ ~ 710' al perf data qz DATE 05/04101 07/08/01 06/27/01 d 06/27/01 05/04/01 05/04/01 ~ 13859' H FISH: MILLED BKR CIBP (01/04/06) I -r xxx I 13948' I 900'SS 110-3/4" CSG, 45.5#, L-80, BTC, ID = 9.950" Minimum ID = 3.725" @ 4-112" XN NIPPLE 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" 7" CSG, 26#/FT, L-80, 10 = 6.276" ÆRFORA TION SUMMARY REF LOG: AON 02/07/01 ANGLE AT TOP PERF: 23 @ 13 Note: Refer to Production DB for historic SIZE SPF MERV AL Opn/S 2-7/8" 6 13121 - 13171 0 2-7/8" 6 13121-13171 0 2-7/8" 6 13185-13196 Sqz'd 2-7/8" 6 13227 - 13242 Sqz' 2-7/8" 6 13674 - 13704 0 2-718" 6 13710 -13740 0 4-1/2", 12.6#/FT, L-80, IBT-Mod DATE 02/10/01 02/17/01 03/20/01 04/09/01 05/04/01 07/13/01 REV BY COMMENTS GNK ORIGINAL COM PLETION JLA/tp CORRECTIONS A TDlTLH ADD ÆRF CS/KAK PERFS JJ/KAK ADPERFS & CIBP WW/KAK REÆRFS DATE 07/20/01 06/18/02 01/04/06 REV BY PCR/DRS JMlTLH BMcNITL COMMF-NTS UPDA TES GL V UPDATE MILL CMT/FCO/MILL CIBP PRUDHOE SA Y UNIT WELL: NK-43 PERMIT No: '2010010 API No: 50-029-22998 SEC 36, T12N, RiSE, 1441' NSL & 802' EWL BP Exploration (Alaska) e e " MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc ·~=~_fp.-;~;¡~---=- o· <,. ._ __ .:"~_";_ i1 - r---- 4 ~ J :~>-= U'òt ~. . ....:¡ ," Schlumberger t:EB' . 4') ,-" ~~ ¡¡1d'C.¿~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth -." __v~ !-. ...;'.)~ ¡;~rH~-S!Ü:: Anchor~ge Well Job# log Description Date Bl 13-31 A .:)05- il1JO 11162828 MEM JEWELRY & PRESSURE SURVEY 01/07/06 1 DS 18-03B ~OS ~Of'.(¡, 11057071 SBHP SURVEY 12/02/05 1 NK-43 6)6/-00 I 10987562 SBHP W/SPINNER PASSES 01/07/06 1 B-13A /C¡9 - C-S7 11183463 lEAK DETECTION lOG 01/28/06 1 DS 06-22A ¡Q?Y-CS7 N/A SENSAlMEM lDl 01/28/06 1 DS 11-26 If:;~- /34- 11183462 INJECTION PROFilE 01/28/06 1 P1-09 19~"/51- 11098756 PROD PROFilE WID EFT & GHOST 01/30/06 1 l5-05 Jf.7-C(cC¡' 11058541 RST 11/11/05 1 Z-29 it¿C¡ -C(~Ç- 11051081 RST 08/10/05 1 lS-09 IC¡C -/~ 11090725 RST 11/11/05 1 15-44 ,qLt - I {ð 11194155 RST 01115/06 1 C-20B .;(O{-I [4- 11075913 MCNl 08/29/05 1 02-14A ~03 -/~5 11075901 MCNl 07/29/05 1 Z-21A -901- ið r 11076449 RST 06/30/05 1 F-27 A d05 - I ó?4- 10928641 MCNl 09/01/05 1 MPH-15 ~?cr:5 -- 15'1 11076486 US IT 12/15/05 13-31 A -:QC5-llL'ö 11133211 SCMT 12/23/05 WGI-04 J 7'1 - ofx,.; 11183461 USIT 01/26/06 WGI-04 nq -cst) 11211566 USIT 02/03/06 WGI-08 Iq()..- O¥"j 10987559 USIT 01/02/06 WGI-08 jC1ð - C49 11058259 USIT 01/12/06 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 'ð,~bO ' i:~R ~CANt'~~C " bÞ "'j c) ¿nOR ~~Q ~- Date Delivered: _')/{ ,:)7 ( oG 02/09/06 NO. 3677 Company: State of Alaska Alaska Oil & Gas Cons Comm Artn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD -' 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ---- Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by t~Qclö ) RECEIVED - STATE OF ALASKA '\ AlA~ ) Oil AND GAS CONSERVATION COMI"v.. ,~ION REPORT OF SUNDRY WELL OPERATIONS 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: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 53.9 KB 8. Property Designation: ADL-034635 11. Present Well Condition Summary: Total Depth measured 13948 true vertical 10073.68 Effective Depth measured 13859 true vertical 9989.76 Casing Conductor Surface Production Liner Length 80 7032 13609 600 Size 20" 91.5# H-40 10-3/4" 45.5# L-80 7" 26# L-80 4-1/2" 12.6# L-80 Perforation depth: Measured depth: 13121 - 13171 True Vertical depth: 9320.79 - 9365.11 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 407 x Plug Perforations [] Perforate New Pool D Perforate D 4. Current Well Class: Development II;?] Stratigraphic D feet feet feet feet MD 34 - 114 33 - 7065 32 - 13641 13348 - 13948 13674 - 13740 9818.15 - 9878.88 4-1/2" 12.6# JAN 3 0 2006 Stimulate D AI.~ Gas Cons. Commiss'Jn Waiver D Time Extension D Anchorage Re-enter Suspended Well D 5. Permit to Drill Number: [] 201-0010 [] 6. API Number: 50-029-22998-00-00 Exploratory Service 9. Well Name and Number: NK-43 10. Field/Pool(s): Prudhoe Bay Field/ Niakuk Oil Pool Plugs (measured) Junk (measured) None 13859 TVD 34 - 114 33 - 5114.49 32 - 9787.93 9522.14 - 10073.68 Collapse 470 2480 5410 7500 Burst 1490 5210 7240 8430 L-80 31 - 12984 4-1/2" Baker S-3 Per~AMNE[)) Jl~N 3 1 20088 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 467 783 0 SHUT-IN 15. Well Class after proposed work: Exploratory r Development R' 16. Well Status after proposed work: Oil R' Gas r WAG 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 ._ --, ) _, ..' Signatur~k~.,¿..., ~ Form 10-404 Revised 04/2004 ¡""\ r" ~ r ,t"" r ( ) ~.,' l l'; _.~ i ......" , \ E..." i RBDMS BFI~ JAN :3 02D06 Tubing pressure 487 Service r GINJ r WINJ r WDSPL r Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Date 1/26/2006 Phone 564-4424 {:, I liL Submit Original Only ) ') N K-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 1/2/2006 CTU #9, FCO/UR/MILL; MIRU. MU/RIH w/ 2.0" JSN. Jet hot diesel from surface to TT. Tag fill @ 13210' ctmd. Turn well over to 1 % KCL and demonstrate 1:1 returns. FCO from 13210' to 13237' ctmd with 25 bbls FloPro taking returns to tanks. ... Job in Progress - Cont' on WSR 01/03/2006 ... 1/2/2006 T/I/O=400/1600/0 Assist Coil w/ Parafin Clean-Out (Flowing on Arrival) Pumped 213 bbls 155*f Diesel. Final WHP's=400/1750/0 1/3/2006 CTU #9, UR/MILL; ... Cont' from WSR 01/02/2006... POOH at 80%. FP flowline w/ 60/40 Meth. Perform BOP test (AOGCC rep Jeff Jones declined to witness). MU/RIH w/ 2-7/8" mtr & Reeves UR, 2-7/8 x 5-3/4 arms. Tag 13233', UR down to 13284', clean sand below. POOH. MU/RIH w/ 3.70" 3- bladed junk mill. Clean out sand from 13291 to 13500 with FloPro sweeps. Tag CIBP at 13500' ctmd. ... Job in Progress - Cont' on WSR 01/04/2006 ... 1/4/2006 CTU #9, UR/MILL; ... Cont' from 01/03/2006 WSR ... Milled CIBP at 13500' and pushed to bottom. PBTD 13859' ctmd. POOH and freeze protect well with 39 bbls 60/40 Meth. *** Job Complete *** 1/7/2006 STATIC BOTTOM HOLE PRESSURE SURVEY WITH SPINNER PASSES TAGGED AT 13610' SO WE COULDN'T GET BOTTOM TWO REQUESTED STATIC PRESSURES STATICS TAKEN AT 12932',13045',13158',13291',13549',13598' 1/14/2006 TII/O = 680/2420/Vac. SI. TBG & IA FL (Post CMIT). AL line open at tree (2420 psi), No integral. TBG FL @ 438', IA FL @ 1590'. FLUIDS PUMPED BBLS 1199 1 % KCL 190 60/40 Meth 66 FloPro 1455 TOTAL e e 1r 17'\ 91" r? Ii lll\ : I ¡ Þ u ;..,n>.l U u: Jr' ! ' Ir , ¡ :,u FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ross Warner Production Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 ~"'.'._....".'.~..'.'.."'..."'."·······t············ .. ...... " .~~.. ..' .. ." <' ,/' _.' ~,. ··'t¿· .' Re: NK-43 305-358 :sCANNED DEe 1 ~ 2005 Dear Mr. Warner 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. Please provide at least twenty-four (24) hours 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. Encl. ® e e õ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, AK. 99519-6612 November 17, 2005 Alaska Oil & Gas Conservation Commission Attention: Mr. Winton Aubert 333 west ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Winton Aubert: I?~C€ NOI¡ II/SD 41/1,.. Oil & 17 2005 0" F\ A "'Dill. F\ ~n.ÇhfJ' . ~1}h1tni . , '" '$11011 Reference: Sundry Notice for NK-43-Drillout for Commingling Production BP Exploration (Alaska) Inc. proposes to drill out the existing plug in this well and production test the Sag River Formation by commingling this zone with the existing Kuparuk production interval. This method of production testing has received approval by the Department of Natural Resources and the AOGCC has given us verbal endorsement for the enclosed/) program. These Agencies have specified that the testing will be completed in ~days. Listed below is the summary for the planned operations: 1 0 Obtain well test before starting job and take a wellhead sample. 2 S Make a Slickline Drift & Tag 3 0 Shut the well in for one week 3 S Run a Bottom Hole Static Pressure Survey 4 C CTU Cleanout and Drill out of the CIBP 5 0 Put the well back on production 6 0 Take commingled wellhead sample. I have attached a complete copy of this program and a well sketch with this letter. Currently this well is producing from the Kuparuk Reservoir. Service work will commence when approval is received from your organization. If you have any questions please contact: Les Kincaid at 564-5219 or Ross Warner at 564-5359. Si~rel~ /Ø~ Ross L. Warner Attachments: ("ffL I tV IJ !5 STATE OF ALASKA vr -r I ~(() A. OIL AND GAS CONSERVATION COM4oN APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Î.\..i()(\ UtI i¡ Lao.)- 1. Type of Request: Abandon Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Suspend Repair well 0 Pull Tubing 0 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 / Exploratory 0 Perforate Waiver Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 2OJ-0010 / Other .,¡ Stratigraphic 0 Service 0 6. API Number: 50-029-22998-00-00 /" 9. Well Name and Number: /" 53.9 KB NK-43 10. FieldlPools(s): b PRUDHOE BAY Field / NIAKUK OIL poor(~ PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 13905 10033.12 8. Property Designation: ADL-034635 11. Total Depth MD (ft): 13948 Total Depth TVD (ft): 10073.68 Casing Length Size TVD Conductor 80 20" 91.5# H·40 34 11434 114 Surface 7032 10-3/4" 45.5# L-80 33 7065 33 5114 Production 13609 7" 26# L-80 32 13641 32 9788 5410 Liner 600 4-1/2" 12.6# L-80 13348 139489522.14 10074 7500 Perforation Depth MD (ft): 13121 - 13171 Perforation Depth TVD (ft): 9320.79 - 9365.11 Tubing Size: 4-1/2" 12.6# Tubing Grade: L-80 Tubing MD (ft): 31 - 12984 r Packers and SSSV Type: 4-1/2" HES HXO SVLN 4-1/2" Baker S-3 Perm Packer 7" Baker ZXP L T Packer Packers and SSSV MD (ft): 2134 12928 13348 /' 12. Attachments: DescriDtive Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for 13. Well Class after proposed work: Exploratory 0 Development 0 / Service 0 Date: 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Prepared by Sharmaine Vestal 564-4424 Commencing Operations: 16. Verbal Approval: Commission Representative: 12/01/2005 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Ross Warner Title Production Engineer Signature ~ ~ Phone 564-5359 Date COMMISSION USE ONLY Ross Wamer 11/17/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test ~ Other: T-e s \- \)" 0 r I: to S () 0 () Mechanical Integrity Test 0 A" 1""-011... ¡ Location Clearance (.ìV\.. elf f'A V\(' 'S o 1/ ¡ 1'2.00(" RBDMS 8Ft ? 7 OO~ COMMISSIONER APPROVED BY THE COMMISSION Date: v Form 10-403 Revised 11/2004 ORIGINAL Submit in Duplicate e e To: Doug Cismoski/ Jerry Bixby GPB Wells Operations Supervisor Date: November 9, 2005 From: Ross Warner for Les Kincaid Subject: NK-43: CTU Drillout for Commingling Production Cost Code: AFE 5L0546 Estimated cost: $90K lOR: 500 bopd Summary: 1 0 Obtain well test before starting job and take a wellhead sample. 2 S Make a Slickline Drift & Taq 3 0 Shut the well in for one week 3 S Run a Bottom Hole Static Pressure Survey 4 C CTU Cleanout and Drill out CIBP 5 0 Put the well back on production 6 0 Take a commingled wellhead sample. This well is on gas lift. Max Deviation: 54 Deg at 3798' MD. BHP: ,..,3200 psi @ 13,120' MD. (Kuparuk) ,..,4000 psi @ 13,700' MD. (Sag River) 3.725" @ 12,973'. XN Nipple. 6/12/05. Slickline tag 13,182' MD. Last TD below the CIBP was 13,854' MD on 5/2/01 As above. 100 ppm on 7/14/05 See Well Sketch Min.ID: Last TD tag: Last DH Ops: Latest H2S Value: Perforation: Backaround information NK-43 was completed in March of 2001. It was drilled to test the Sag/Ivishak and after about 6 weeks of testing the well was shut in and the Sag Formation was isolated with a CIBP at 13,500' MD. (Production during this test period was about e e 500 bopd). The Kuparuk was then perforated. Initial production from the Kuparuk was about 5000 bfpd, mostly water. A Borax log was run which indicated a channel to 13,220'. June 27, 2001 the well was squeezed after placing ,..,3000 Ibs. of 20/40 River Sand on the CIBP. On July 3-4,2001 the cement top was tagged at 13,128' and the liner was underreamed to 13,260' CTM. On July 7-8, 2001 the well was re-perforated 13,121-13,171' using 2-7/8" guns 6 shots per foot. This well has a long history of hydrates, asphaltines, and paraffin problems. This well does not have any integrity issues. Objective Obtain a static pressure survey before the cleanout begins. The last SBHP was taken 8/14/01. Obtain oil samples before the cleanout and after the zones are commingled. The reason for taken the samples is we will be using OilTracers for allocating commingled production using oil geochemistry. Mill out cement, circulate out the 20/40 sand and mill the CIBP so it can be pushed to bottom. The Sag River perforations need to be exposed, 13,674-13,710' MD. POH and change BHA. Underream cement sheath to top of liner. Procedure: 1. Obtain another well test before commencing work. Obtain an oil wellhead sample. Instruction as to what to do with the sample appears at the end of this document. Eight (8) to 12 (12) ounces of oil will be sufficient. Label sample as date taken, etc. 2. Make a drift and tag run for the SBHP survey. Load the tubing with crude/diesel/ freeze protect so the static survey run crew can get the tools to bottom without pumping any fluids. Shut the well in for one week 3. One week from the shut in time run a static pressure survey. Use E Line or memory slickline tools. I suspect the liner will be too RA to correlate using a Gamma Ray log for tie-in if electric line is used. Note on the Well Service Report how long the well had been shut in when the job is started. The correlation log for this work is the Anadrill Schlumberger 1/11/01 thru 2/6/01. If the tools won't go to bottom abort this portion of the job. Make the following stops: 2 e e M D Depth Subsea Depth Time 12,932 -9154 10 minutes 13.045 -9200 10 minutes 13,158 -9300 10 minutes 13,045 -9200 10 minutes 4. Cleanout the well in the following manner. Although I would like the cement sheath underreamed first I believe going in with a junk mill first is the lesser of two evils as if a blade broke off the underream and got on top of the plug it might become next to impossible to mill; therefore I prefer going in with a junk mill first, drilling out the cement, circulate out the 20/40 river sand, and then milling/ pushing the CIBP to bottom. POH, change out the BHA and underream the remaining cement sheath to the top of the liner. Note: A Coil Cade Run indicated with a 1-3/4" string, 2500 Ibf. WOB and 12,500 Ibf pull available at CIBP depth. 5. Put the well back on production. 6. Take another wellhead commingled oil sample. The two samples (pre-job and this sample) need to be put into approved DOT containers and the sent to the following address: Baseline Resolution 143 Vision Park Blvd. Shenandoah, TX 77384 Additional sampling requests will be sent to the Slope at a later date. Any questions concerning this program please contact: Les Kincaid at 564-5219 (work); 929-1317 (home); 230-2202 (cell). Ross Warner at 564-5359 (work), 333-9017 (home), 251-3441 (cell). Attachment CC: Well Files Les Kincaid G ANC Well Work LPC Lead Drill Site Operator LPC Drill Site Operator 3 TREE " WELLHEAD = 4-1/16" 13-5/8" NK-43 e I SAFETY NOTES: e / KB, ELEV = 53.9' BF. ELEV = KOP= ~... .....- _.~.~_.~--- Max Angle" ,~4~,3~~~' Datum MD = -_....~..._-~ - -_._._-~-_.__..."-""._--~ Datum TVD = 900' SS . 2134' -14-1/2" HES HXO LANDING NIP, ID = 3.813" I 110-3/4" CSG, 45,5#, L-80, BTC, ID = 9.950" I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LA TCH PORT DATE 6 3675 2975 KBG2-LS-MOD DOME INT 16 06/17/02 5 7444 5300 KBG2-LS-MOD DOME INT 16 06/17/02 4 10077 7000 KBG2-LS-MOD DOME INT 16 06/17/02 3 11768 8100 KBG2-LS-MOD SO INT 24 06/17102 2 12531 8750 KBG2-LS-MOD DMY INT 1 12840 9020 KBG2-LS-MOD DMY INT 12907' -1 4-1/2" X NIP, ID = 3.813" I 12928' -1 7" X 4-1/2" BAKER S-3 PKR I 12951' H 4-1/2" X NIP, ID - 3.813" I 12973' -1 4-1/2" XN NIP, ID = 3.725" I 12984' -1 4-1/2" WIRELINE ENTRY GUIDE 12975' H ELMD TT LOGGED 03/10/01 I -1 TOP OF UR'd C8v1ENT - 07/05/01 - TOPOFSAND- 6/27/01 I -1 5" X 7" BA KER ZXP LINER TOP PA CKER -i BAKER CIBP I Minimum ID = 3.725" @ 12973' 4-1/2" XN NIPPLE 14-1/2" TBG, 12.6#, L-80, ,0152 bpf, ID = 3.958" I 12984' 7" CSG, 26#/FT, L-80, ID = 6.276" I ÆRFORA TION SUMMARY REF LOG: ADN 02/07/01 ANGLEATTOPPERF: 23 @ 13710' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 13121 - 13171 0 05/04/01 '( 2-7/8" 6 13121 - 13171 0 07/08/01 > 2-7/8" 6 13185 - 13196 Sqz'd 06/27/01 2-7/8" 6 13227 - 13242 Sqz'd 06/27/01 2-7/8" 6 13674 - 13704 Isolated 05/04/01 2-7/8" 6 13710 - 13740 Isolated 05/04/01 4-1/2", 12.6#/FT, L-80, IBT-f\I1od 13948' DATE 12/30/00 02/10/01 02/17/01 03/20/01 04/09/01 05/04/01 REV BY COMMENTS WSI Proposed Completion GNK ORIGINAL COMPlETION JLA/tp CORRECTIONS A TDITLH ADD PERF CS/KAK PERFS JJ/KAK ADPERFS & CIBP DATE 07/13/01 07/20/01 06/18/02 REV BY COMMENTS WW/KAK REPERFS PCRlDRS UPDA TES JrwTLH GLV UPDATE PRUDHOE BA Y UNIT WELL: NK-43 PERMIT No: 2010010 API No: 50-029-22998 SEC 36, T12N, R15E, 1441' NSL & 802' EWL BP Exploration (Alaska) Permitto Drill 20100'10 MD 13948 j TVD DATA SUBMITTAL COMPLIANCE REPORT 8~7~2003 Well Name/No. PRUDHOE BAY UN NIA NK-43 Operator BP EXPLORATION (ALASKA) INC 10074 ~ Completion Dat 3/10/2001 f Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22998-00-00 UIC N REQUIRED INFORMATION Mud Log N._9 Sample N_.9 Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH / Dataset CH Received Number Comments ~.ME) Composite ~¥,~ ~',~/5 FINAL CBL ~) ,,~,,,~, 5 FINAL CBL 5 FINAL ~ Composite AND 2/5 FINAL C~omposite AND 2/5 FINAL 5_~ Composite Array 2/5 FINAL Res FINAL SBHP 5 FINAL FINAL Production Profile 5 FINAL Gas Lift Survey 1 FINAL FINAL 55O 12990 349O 55O 12950 12950 9271 9271 55O 55O 12990 12990 3300 349O 349O 13948 13483 12940 13948 13860 13860 13948 13948 13948 13948 13483 13483 13203 12940 12940 Open 6/15/2001 10137 _~550-13948 Case 7/13/2001 10187.~ 12990-13483 Case 4/3/2001 09982 ~3490-12940 OH 6/15/2001 550-13948 BL, Sepia ch 3/23/2001 12950-13860 Color Print ch 3/23/2001 12950-13860 Color Print OH 6/15/2001 9271-13948 BL, Sepia OH 6/15/2001 9271-13948 BL, Sepia OH 6/15/2001 550-13948 oh 6/15/2001 10137'~'-550-13948 Digital Data CH 7/13/2001 12990-13483 BL, Sepia CH 7/13/2001 10187 12990-13483, Digital Data ch 10/26/2001 3300-13203 BL, Sepia ch 4/3/2001 3490-12940 BL, Sepia 4/3/2001 9982 r.-/3490-12940 Digital Data Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2010010 MD 13948 TVD 10074 Well Cored? Y ~ Chips Received? ~ Analysis ~ Rnr. eivnd? DATA SUBMITTAL COMPLIANCE REPORT 8/712003 Well Name/No. PRUDHOE BAY UN NIA NK-43 Operator BP EXPLORATION (ALASKA) INC Completion Dat 3/10/2001 Completion Statu 1-OIL Current Status Daily History Received? ~.~ N Formation Tops ~ N 1-OIL APl No. 50-029-22998-00-00 UIC N Comments: Compliance Reviewed By: Date: 10/23/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1552 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD iNK-43 ~. c-~D)-OOI PRODUCTION PROFILE J t0/13/01 'R-35 / ~"'l~ PROD PROFILE/DEFT/GHOST l// 09/29/01 ~D.S. 1-29 / ~-iD ~ LEAK DETECTION LOG v/ 09/28/01 !D.S. 4-13 !-7~'-(~ INJECTION PROFILE v'~ 10112101 ~D.S. 4-t4 /'-7 ~-O~:/,,p PSP-INJECTION PROFILE b/ 10/11/01 D.S. 4-49 / ~o~t "7 ! PSP-INJECTION PROFILE/JEWELRY. / 10114101 D.S. 4-49 / ~ --i ~ ! PSP-INJECTION PROFILE~/ 10114/01 D.S. 5-23 /~o)--O-Tc~ LEAK DETECTION LOG / 10107/01 D.S. 7-26 /-~'~--OL-/~ LEAK DETECTION LOG ~/' 10/02/01 D.S. 15-088 .LC~ "7 -1 ~,3. LEAK DETECTION LOG ~ 10/04/01 F-34A / _~,,-.//(~? 21430 MCNL v/ 09/06/01 J-12 )~t<~O-_~)) ") 21409 RST L// 09/05/01 J-14/A- _~Oi"t5 ~' 21429 MCNL I/"'" 09/01/01 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 OCT 2 2001 AJaska 0il & Gas Cons. C.m, mi~,_!~ Anchor~e Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'FI'N: Sherrie ! - STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3838' FNL, 802' FEL, Sec. 36, T12N, R15E, UM At top of productive interval 2852' FNL, 5066' FEL, Sec. 29, T12N, R16E, UM At effective depth At total depth 2582' FNL, 4854' FEL, Sec. 29, T12N, R16E, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic_ Service__ (asp's 721757, 5979982) (asp's 727435, 5986421) (asp's 727638, 5986697) 6. Datum elevation (DF or KB feet) RKB 53.9 feet 7. Unit or Property name Niakuk 8. Well number NK-43 9. Permitnumber/approvalnumber 201-001 10. APInumber 50-029-22998 11. Field / Pool Niakuk Oil Pool 12. Present well condition summary Total depth: measu red true vertical 13948 feet Plugs (measured) 10074 feet Effective depth: measured 13224 feet Junk (measured) true vertical 9412 feet Tagged PBTD @ 13224' MD on 8/14/2001. Set CIBP @ 13500' MD on 5/04/2001. Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 1 14' 20" 260 Sx AS 1 14' 114' Surface 701 1' 10-3/4" 1082 Sx AS Lite III & 419 Sx 7065' 5114' Class G Production 13587' 7" 756 Sx Class G 13641' 9788' Liner 600' 4-1/2" 96 Sx C~ass e 13948' 10074' Perforation depth: measu red 13121' - 13171 '; (isolated below cement cap / sand plug / CIBP 13674' - 13704'; 13710' - 13740'). true vertical 9321' - 9365'; (Isolated below cement cap / sand plug / ClBP 9818' - 9846'; 9851' - 9879'). Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 Tbg @ 12984' MD. ~ 7" X 4-1/2" BAKER S-3 PACKER @ 12928' MD; Baker ZXP Liner Top Packer @ 13348' MD. L' ~'~ 4-1/2" Halliburton HXO Landing Nipple @ 2134' MD. ~ · 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation(8~10~2001) Subsequent to operation(8~30~2001) Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 82 0 68 - 454 479 329 Tubing Pressure 537 546 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas m Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signe~~b,~~~~ Title: Niakuk Surveillance Engineer Dwight Warner Date September 10. 2001 Prepared by Paul Rauf 564-5799 SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 · ORIGINAL NK-43 DESCRIPTION OF WORK COMPLETED ACID STIMULATION Date Event Summary 8/14/2001' 8/27/2001' RIH w/Slickline & tagged PBTD @ 13224'. Performed a CT Acid Stimulation as follows: MIRU CTU & APC Test Separator. PT'd equip. RIH w/CT & washed perfs with 25 bbls of 35/65 Diesel/Xylene. Jetted 103 bbls of 12% HCI / 10% Xylene across the open perforation intervals located f/: 13121' - 13171' MD (Kuparuk Zone) Reference Log: A DN 2/07/2001. Well initially locked up when attempted to establish injection. Later, perforations easily took acid. Swapped to 2% KCI Water & POOH w/CT. RD CTU. Used APC Test Separator for flowback. Placed well BOL & obtained a representative welltest. Page I i_" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pertorate _X Pull tubing _ Alter casing _ Repair well _ Other _X (SQZ for WSO) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3838' FNL, 802' FEL, Sec. 36, T12N, R15E, UM At top of productive interval 2852' FNL, 5066' FEL, Sec. 29, T12N, R16E, UM At effective depth At total depth 2582' FNL, 4854' FEL, Sec. 29, T12N, R16E, UM 5. Type of Well: Development _X Exploratory__ Stratigraphic_ Service__ (asp's 721757, 5979982) (asp's 727435, 5986421) (asp's 727638, 5986697) 6. Datum elevation (DF or KB feet) RKB 53.9 feet 7. Unit or Property name Niakuk 8. Well number NK-43 9. Permit number / approval number 201-001 10. APl number 50-029-22998-00 11. Field / Pool Niakuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 13948 feet Plugs (measured) 10074 feet Effective depth: measured 13251 feet Junk (measured) true vertical 9436 feet Tagged TOC @ 13251' MD on 7/05/2001. Set CIBP @ 13500' MD on 5/04/2001. Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 114' 20" 260 Sx AS 114' 114' Surface 7011' 10-3/4" 1082 Sx AS Lite III & 419 Sx 7065' 5114' Class G Production 13587' 7" 756 Sx Class G 13641' 9788' Liner 600' 4-1/2" 96 Sx C~ass G 13948' 10074' Perforation depth: measured 13121' - 13171'; (isolated below cement cap / sand plug / CIBP 13674' - 13704'; 13710' - 13740'). true vertical 9321' - 9365'; (Isolated below cement cap / sand plug / CIBP 9818' - 9846'; 9851' - 9879'). Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 12984' MD. Packers & SSSV (type & measured depth) 7" X 4-1/2" BAKER S-3 PACKER @ 12928' MD; Baker ZXP Liner Top Packer @ 13348' MD. 4-1/2" Halliburton HXQ Landing Nipple @ 2134' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Oil-Bbl 591 Representative Dailv Avera.qe Production or Iniection Data Gas-Md Water-Bbl 430 1703 610 290 40 Casing Pressure Tubing Pressure 750 543 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify tl-cAt~ foregoing is true and correct to the best of my knowledge. Signed ~,,~ . Title: Niakuk Surveillance Engineer Dwight Warner ~ ~/'~./,~~,¢'/~¢/~,~' ~ Form 10-404 Rev 06/15/88 · ORIGINAL Prepared by Paul Rauf 564-5799 SUBMIT IN DUPLI NK-43 DESCRIPTION OF WORK COMPLETED CEMENT SQUEEZE FOR WSO & REPERFORATING OPERATIONS Date Event Summary 6/14/2001- 6/22/2001' 6/23/2001 - 6/25/2001' 6/26/2001- 6/27/2001' 7/02/2001' 7/03/2001- 7/04/2001' 7/05/2001' 7/06/2001 - 7/07/2001' 7/08/2001' Ran RST Borax Log. Found channel f/13220' to 13196' & f/13185' - 13171' RIH &tagged CIBP @ 13498'. Dummied GLV's. Performed MITIA to 1500 psi - passed. MIRU CTU. PT'd equip. Performed a CT Cement Squeeze for WSO as follows: Killed well w/Filtered 2% KCI Water. RIH w/CT & tagged CIBP @ 13500'. Pumped a gelled sand slurry consisting of 3000 lbs of 20/40 mesh River Sand, to place a sand plug on top of the CIBP. Tagged TOS @ 13240'. Reversed off sand top to 13275'. Pumped 25 bbls of 15.9 ppg Latex Acid Resistive Cement to squeeze of the following perforation intervals: 13121' - 13171' MD (Kuparuk Zone) Reference Log' A DN 2/07/2001. 13185'- 13196' MD (Kuparuk Zone) 13227'- 13242' MD (Kuparuk Zone) Placed 6 bbls of cement behind pipe. Attained DP of 3500 psi for 1 hr. Contaminated cement w/Biozan & cleaned out to 13100'. POOH w/CT. FP'd well. Trapped 500 psi on wellhead. RD CTU. WOC. RIH & tagged TOC @ 13116' ELM Corrected. MIRU CTU. PT'd equip. RIH w/UR &tagged TOC @ 13128' CTM. UR'd to 13166'. UR'd cement to 13260' (left sand plug w/cement cap above CIBP). Circulated BTM's up w/ Water. PT'd cement to 1000 psi - bled to 850 psi in 10 min. POOH w/UR while pumping dead Crude f/13235'. Swapped to Diesel @ 3800'. RD CTU. RIH & tagged TOC @ 13251 '. Installed live GLV's. MIRU ELU. PT'd equip. RIH w/perf guns & reperferated 50' as follows: 13121' - 13171' MD (Kuparuk Zone) Used 2-7/8" PJ & all shots @ 6 SPF, 60° phasing, random orientation, & balanced press. POOH w/guns - ASF. RD ELU. Placed well BOL & obtained a representative welltest. Page 1 TREE = 4-1/16" WELLHEAD= 13-5/8" ACTUATOR= " KB. ELEV 53.9' 'BF] FiEv = K0P :- 380' Max Angle = 54 @ 3798' Datum MD = ' i DatUm TVD= 900' SS 10-3/4" CSG, 45.5#, L-80, BTC, ID=9.950" I I 7065' ~ Minimum ID = 3.725" @ 12973' NO-GO ID NK-43 2134' 4-1/2" HALLIBURTON HXO LANDING NIP, ID = 3.813" GAS LIFT MANDRELS TYPE MAN KBG2-LS-MOD KBG2-LS-MOD KBG2-LS-MOD KBG2-LS-MOD KBG2-LS-MOD KBG2-LS-MOD LATCHI INT IN'F INT 4-1/2" X NIP, ID: 3.813" 7" X 4-1/2" BAKER S-3 PKR I 4-1/2" X NIP, ID = 3.813" 4-1/2" XN NIP, ID = 3.725" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I--~{ 12984' I 7" CSG, 26#/FT, L-80, ID = 6.276" I'-"~ 13641' PERFORATION SUMMARY REF LOG: ADN 2/7/2001 ANGLE AT TOP PERF: 23 @ 13710' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 13674-13704 Isolated 05/04/01 2-7/8" 6 13710-13740 Isolated 05/04/01 2-7/8" 6 13121-13171 O 05/04/01 2-7/8" 6 13185-13196 Sqz'd 06/27/01 2-7/8" 6 13227-13242 Sqz'd 06/27/01 2-7/8" 6 13121-13171 O 07/08/01 112984'H 4-1/2" WIRELINE ENTRY GUIDE 1' 2975'H I ." ,:' .':;".'].....:'.' --~ Top of UR'd Cement (7/05/2001) --{TOS tagged 6/27/2001 I I~ ~'~ ",,' ',.:~ ~ ~ 13348' ~ 5" x 7" BAKER ZXP LINER TOP PA CKER I I© ~'~ ~'~'~ I ~ : : L .13500'HBAKERc,BP, I4-1/2''' 12'6#/FT' L-80, IBT-M°d I I13948' ~J~ DATE REV BY COMMENTS DATE REV BY COMMENTS 12/30/00 WSI Proposed Completion 05/04/01 JJ/KAK ADPERFS & CIBP 02/10/01 GNK ACTUAL 07/13/01 WW/KAK REPERFS 02/17/01 JLA/tp CORRECTIONS 07/20/01 pcr/drs updates "03/20/01 ATD/TLH ADD PERF '04/09/01 CS/KAK PERFS -- , PRUDHOE BAY UNIT WELL: NK-43 PERMIT No: 201-001 APl No: 50-029-22998 BP Exploration (Alaska) 07/10/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1273 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Blueline Sepia Prints CD NK-29 J'l~l~ll '/~'O 21303 RST 06110101 1 I '1 NK-43 ~.¢~! -- ~ ! 2t 304 RST 06114101 I I '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 JUL 1'13 2001 AJaka Oil & Gas Cons. ConHnission Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherde 6/12/2001 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. 12t0 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Niakuk Color Well Job # Log Description Date Blueline Sepia Prints CD NK-43 21096 M10,CDR, IMP& DIN 02/07101 '1 :.43 21096 MD ARRAY RES 02/07101 1 3 21096 ']'VD ARRAY RES 02/07101 NK-43 21096 MD ADN 02/07101 K-43 21096 TVD ADN 02/07101 I '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: Schlumberger GeoQuest REC.C v D 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A-I-rN: Sherde 'JUN 15 2001 Received ~~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pedorate _X Pull tubing _ Alter casing _ Repair well _ Other _X (ClBP) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3838' FNL, 802' FEL, Sec. 36, T12N, R15E, UM At top of productive interval 2852' FNL, 5066' FEL, Sec. 29, T12N, R16E, UM At effective depth At total depth 2582' FNL, 4854' FEL, Sec. 29, T12N, R16E, UM 5. Type of Well: Development _X Exploratory__ Stratigraphic_ Service__ (asp's 721757, 5979982) (asp's 727435, 5986421) (asp's 727638, 5986697) 6. Datum elevation (DF or KB feet) RKB 53.9 feet 7. Unit or Property name Niakuk 8. Well number NK-43 9. Permit number / approval number 201-001 10. APl number 50-029-22998-00 11. Field / Pool Niakuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 13948 feet Plugs (measured) 10074 feet Effective depth: measured 13500 feet Junk (measured) true vertical 9659 feet Set ClBP @ 13500' MD on 5/04/2001. Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 114' 20" 260 Sx AS 114' 114' Surface 7011' 10-3/4" lO82 sx AS Lite III & 419 Sx 7065' 5114' Class G Production 13587' 7" 756 sx Class G 13641' 9788' Liner 600' 4-1/2" 96 Sx Class G 13948' 1 0074' Perforation depth: measured 13121'- 13171'; 13185'- 13196'; 13227'- 13242'. (isolated below CIBP 13674'- 13704'; 13710' - 13740'). true vertical 9321' - 9365'; 9378' - 9387'; 9415' - 9428'; (Isolated below CIBP 9818' - 9846'; 9851' - 9879'). Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 Tbg e 129~' MD. ~'~ ~Sk~ 7" x 4-1/2" BAKER S-3 PACKER ~ 12928' MD; Baker ZXP Liner Top Packer ~ 13348' MD. 4-1/2" Hallibudon HXO Landing Nipple ~ 2134' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl 67O Representative Daily Average Production or Injection Data Gas-Md Water-Bbl 9344 31 1014 517 3437 Casing Pressure Tubing Pressure - 889 572 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations .__X 16. Status of well classification as: Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~ '~' ~?'2 ~" Title: Niakuk Surveillance Engineer Scott Mattison ~,.-' ~ Date May 16, 2001 Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · ORI6 I AL SUBMIT IN DUPLICATE NK-43 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS & SET ClBP Date Event Summary 5/02/2001: 5/04/2001' 5/05/2001: RIH w/dummy gun &tagged PBTD @ 13854' SLM. MIRU Wireline Unit. PT'd equip to 3000 psi. RIH & set a Baker model 1AA Cast Iron Bridge Plug @ 13500' MD (top) to isolate all the initial perforation intervals located f/: 13674' - 13704' MD (Sag Zone) 13710' - 13740' MD (Sag Zone) POOH w/CIBP setting tool. RIH w/perf guns & did tie in to SCMT log. Shot 26' of add perforations f/: 13185' - 13196' MD (Kuparuk Zone) 13227'- 13242' MD (Kuparuk Zone) Used 2-7/8" PJ carriers & all shots @ 6 SPF, random orientation, & 500 psi underbalanced. POOH w/guns - ASF. LDFN. PT'd equip. RIH w/perf guns & shot the remaining add perfs f/: 13121' - 13171' MD (Kuparuk Zone) Used 2-7/8" PJ carriers & all shots @ 6 SPF, random orientation, & 500 psi underbalanced. POOH w/guns - ASF. RD Wireline unit. Placed well BOL & performed a representative welltest. Page 1 STATE OF ALASKA M(",oSiON ALASK oIL AND GAS CONSERVATION COM WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-001 .3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22998-00 4. Location of well at surface - ..::...-.. .... !~' 9. Unit or Lease Name 1442' NSL, 802' WEL, SEC. 36, T12N, R15E, UM .... _ .... .." .'' -"--"'""'"'", ~ Niakuk At top of productive interval 2426' NSL, 213' EWL, SEC. 29, T12N, R16E, UM At total depth;i .........;~::~.,. ~ .~'~ .;. 10. Well Number NK-43 2697' NSL, 425' EWL, SEC. 29, T12N, R16E, UM · 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designatiori'and Serial No. Niakuk Oil Pool KBE - 53.90' ADL 034635 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 13948 10074 ETI 13905 10033 FTI [] Yes [] NoI (Nipple) 2134' MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, NED, DEN 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 114' 30" ~_60 sx Arctic Set IApprox.) 10-3/4" 45.5# L-80 34' 7065' 13-1/2" 1082 sx AS Lite 3, 419 sx 'G' 7" 26# L-80 34' 13641' 9-7/8" 756 sx Class 'G' 4-1/2" 12.6# L-80 13348' 13948' 6-1/8" 96 sx Class'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 12984' 12928' MD TVD MD TVD 13674' - 13704' 9818' - 9846' 13710' - 13740' 9851' - 9879' 26. ACID, FRACTURE, CEMENT SQUEEZE, FTC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 130 Bbls of Dead Crude 27. PRODUCTION TEST . Date First Production Method of Operation (Flowing, gas lift, etc.) March 11, 2001 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 3/31/2001 4 TEST PERIOD 1021 15344 2 176I 15028 FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAViTY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .APR i ZOO1 , , ~ i i ,'-~ n ,-, .-'~ r'h ........ 1.,, .; ...... Form 10-407 Rev. 07-01-80 ORIGINAL Anc',hor;,,~ge Submit In Duplicate (' tr 29. Geologic Markers 30. 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. Kuparuk 13114' 9315' Kingak 13258' 9442' Sag River 13654' 9800' Shublik 13743' 9882' Sadie rochit 13816' 9949' I~.~ ~! .~."'~"~'~.~ i'i ..... i'i 7...., ..:/;~.. ....... Alaska Oil & Gas Cons. C(;;'r',miss~o,~ Anchor~(m 31. List of AUachments: Summaw of Daily Drilling RepoAs, Su~eys 32. I hereby ceAify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~~~ Title Technical Assistant Date NK-43 201-001 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 Icg 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 0 i g I It A L Legal Name: NK-43 Common Name: NK-43 Test Date Test Type Test ~e~:(~MD) : Test B~pth(~): ~: : i~AMW: i::: :SUrface Pressure Leak Off Pressure (BHP) EMW 1/23/2001 FIT 7,064.0 (ft) 5,119.0 (fi) 9.40 (ppg) 825 (psi) 3,325 (psi) 12.50 (ppg) 2/6/2001 FIT 13,641.0 (fi) 9,788.0 (ft) 9.60 (ppg) 735 (psi) 5,616 (psi) 11.05 (ppg) Printed: 2127/2001 1:37:08 PM BP EXPLORATION Page 1 of 9 Operations Summa Report Legal Well Name: NK-43 Common Well Name: NK-43 Spud Date: 1/8/2001 Event Name: DRILL+COMPLETE Start: 1/9/2001 End: 1/8/2001 Contractor Name: DOYON Rig Release: 2/10/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/10/2001 15:00 - 17:00 2.00 MOB PRE Accept Rig. PJSM- discuss BP HSE standards and conduct throurough cleanup of rig after rig up operations. 17:00 - 20:30 3.50 MOB PRE Conduct spud meeting w/both crews & all services hands. Flange up diverter. Hook up & function test Tiger tank. Install wind sock & establish safe briefing areas. 20:30 - 23:00 2.50 MOB PRE Hold PJSM. PU 5" DP & rack in derrick. (Rabbit same) 23:00 - 00:00 1.00 MOB PRE Transfer DP to pipe shed, steam same. 1/11/2001 00:00 - 09:00 9.00 MOB PRE Continue to Pick Up 5" Drillpipe- 65 stands. Rack back in derrick. Periodically stop and check top drivel skate. 09:00 - 12:30 3.50 MOB PRE P/U 23 joints of HWDP rattling each joint and drifting same. Rack Back. P/U Drillcollars and rack back. 12:30 - 13:00 0.50 MOB PRE Conduct a D3 Diver[er Drill and Evacuation Drill. Function Test Diverter. 13:00 - 14:00 1.00 DRILL SURF Break Diverter Line and gel jack knife valve. 14:00 - 16:30 2.50 DRILL SURF M/U 9.5/8" motor @ 1.5 deg bend and MWD- orientate same. 16:30 - 17:00 0.50 DRILL SURF John Crisp of AOGCC witness Diver[er Function and tested Hydrogen Sulphide/Methane Alarm system and PVT system. 17:00 - 19:00 2.00 DRILL SURF Fill riser with water, drill cement from 114 ft to 130 ft and drain riser. Prepare to displace to mud. 19:00 - 20:00 1.00 DRILL SURF Displace well to mud. Monitor diverter jack knife - no leaks. 20:00 - 21:00 1.00 DRILL SURF Drill (rotate) 13.5" hole from 130 ft to 169 ft. Flange up diver[er line 21:00 - 21:30 0.50 DRILL SURF Pull 1 std, PU MU MWD monel, jars & 5" HWDP 21:30 - 22:00 0.50 DRILL SURF Slide drill from 169 ft to 263 ft 22:00 - 00:00 2.00 DRILL SURF Hold PJSM. RU slickline unit for Gyro 1/12/2001 00:00 - 14:00 14.00 DRILL SURF ' Directionally Drill 13.1/2" hole from 263 ft to 1274 ft. Release Gyro @ 712 ft. No Drag, No Losses. Observing BUR f/2- 3 degs/100'. Sliding 100%. AST= 9.1 ART= 0 14:00 - 16:30 2.50 DRILL PROP SURF Vis Dropped to less than 100. Raise vis to above 250 while working pipe 30 ft off bottom. 16:30 - 21:30 5.00 DRILL SURF Directionally Drill 13.1/2" hole from 1274 ft to 1590 ft. No Drag, No Losses. Observing BUR f/2- 3 degs/100'. Sliding 100%. AST- 4.2 ART-- 0 21:30 - 22:30 1.00 DRILL CIRC SURF Change swab in #2 pump. 22:30 - 23:00 0.50 DRILL SURF Drill 13 1/2" hole from 1590 ft tO 1591 ft. Unable to hold tool faces steady. Suspect bit damage. Vary parameters- no go 23:00 - 00:00 1.00 DRILL SURF Circ & condition mud for trip. Vis in/out 285 1/13/2001 00:00 - 00:15 0.25 DRILL SURF Circulate shakers clean @ 550 GPM/1400 psi. 00:15 - 02:30 2.25 DRILL SURF POOH. Pump first two stands. Rest hole good. 02:30 - 03:30 1.00 DRILL SURF Break out bit and inspect same. Heel row wear, undergauge. Even wear. 03:30 - 06:00 2.50 DRILL SURF Inspect Top Drive and install Automatic Driller. Clean rig. 06:00 - 07:00 1.00 DRILL SURF Remove UBHO and install crow's foot for ESS. 07:00 - 09:00 2.00 DRILL SURF RIH. Hole good, No fill. Wash down last stand and orientate same. 09:00 - 00:00 15.00 DRILL SURF Directionally Drill 13 1/2" hole 1591 ft to 3120 ft. Normal drag. No Losses. BUR when sliding 3-6 degs/100'. Backreaming stands from 2,070ft. Rotating ahead- dropping and walking right tendency- sliding 30% to compensate. AST-- 7.75 ART= 2.7 Printed: 2/26/2001 3:21:37 PM BP EXPLORATION Page 2 of 9 Operations Surnma Report Legal Well Name: NK-43 Common Well Name: NK-43 Spud Date: 1/8/2001 Event Name: DRILL+COMPLETE Start: 1/9/2001 End: 1/8/2001 Contractor Name: DOYEN Rig Release: 2/10/2001 Group: RIG Rig Name: DOYEN 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/14/2001 00:00 - 10:30 10.50 DRILL SURF Directionally Drill 13.1/2" hole from 3,120 ft to 3,953 ft. No Drag, No Losses. Back reaming each stand. Solids Control Van reducing MW from 9.3 to 9.0 ppg. Running two pit system. ART= 3.25 AST= 2.25 10:30 - 11:30 1.00 DRILL SURF Sweep Hole with Hi-vis. Shakers clean. 11:30 - 16:00 4.50 DRILL SURF Make wiper trip due to footage drilled. Drag 10-20 klbs. Tight from 2400 ft to 2200 ft thru clay/high dogleg interval- backream and wipe out. RIH and hit bridge @ 3,300 ft 16:00 - 16:30 0.50 DRILL STAB SURF Work thru bridge @ 3300 ft varying parameters. Dry wipe- OK. Log Indicates a shale ledge 16:30 - 17:15 0.75 DRILL SURF RIH- Hole good. 17:15 - 00:00 6.75 DRILL SURF Directionally Drill 13.1/2" hole from 3,953 ft to 4,624 ft. Normal Drag, No Losses. Back reaming each stand. Solids Control Van reducing MW from 9.2 to 8.9 ppg @ 180 gpm. Running two pit system. Building & walking right trend 3953 ft to 4100 ft. Holding in¢, & pushing hard right 4,100 ft to 4,624 ft. 30 ft slides to maintain Azm. ART= 3 AST= .75 1/15/2001 00:00 - 14:00 14.00 DRILL SURF Directionally Drill 13.1/2" hole from 4,624 ft to 5,677 ft ( Just above SV3 sands). Some drag and torque on connections indicating clays, No losses. BHA staying neutral. ART= 9.75 AST= .25 14:00 - 15:30 1.50 DRILL SURF Sweep Hole clean with Hi-vis sweep while working/rotating pipe. 15:30 - 19:00 3.50 DRILL SURF Make wiper trip back to 3187 ft. Average drag 15- 20 klbs with occaisonal 30 klbs overpulls- work thru same. 19:00 - 19:30 0.50 DRILL SURF Precaution ream last 90 ft. Establish circ. & flow rate. 19:30 - 00:00 4.50 DRILL SURF Directionally Drill 13.1/2" hole from 5,677 ft to 5,964 ft ( Into the SV3 sands). No losses. BHA staying neutral. Normal drag. Solids removal from 9.1 ppg to 8.9 ppg @ 180 GPM ART= 2.75 AST= .75 1/16/2001 00:00 - 22:00 22.00 DRILL SURF Directionally Drill 13 1/2" hole from 5,964 ft to 7,075 ft. Surface casing point. No losses. BHA staying neutral. Normal drag. ART'- 16.75 AST= 1.75 22:00 - 00:00 2.00 DRILL SURF Sweep hole with Hi - vis, circ shakers clean. 1/17/2001 00:00 - 01:00 1.00 DRILL SURF Circulate hole clean. 01:00 - 10:00 9.00 DRILL SURF Flow check. PJSM. Wiper trip to 1,560 ft. Normal drag. 10:00 - 13:30 3.50 DRILL SURF Sweep hole. Circulate & condition mud. 13:30 - 16:30 3.00 DRILL SURF Flow check, PJSM. POOH - 40k overpull @ 1,220 ft. 16:30 - 17:00 0.50 DRILL TGHT SURF Work tight hole from 1,220 ft. to 1,140 ft. 17:00-19:00 2.00 DRILL TGHT SURF Back ream from1,140 ft to 812 ft. 19:00 - 20:30 1.50 DRILL SURF POOH to surface check bit & stab's O-K. 20:30-22:00 1.50 DRILL SURF RIH w/13 1/2" bit to 2,140 ft. 22:00 - 00:00 2.00 DRILL TGHT SURF Work tight hole 2,140 ft to 2,290 ft. Suspect cuttings from reaming in permafrost fell into DLS at this interval. 1/18/2001 00:00 - 00:30 0.50 DRILL SURF RIH from 2,290 ft to 2,520 ft 00:30 - 02:30 2.00 DRILL STAB SURF Wash & ream from 2,520 ft to 2,965 ft 02:30 - 05:30 3.00 DRILL SURF Con't RIH from 2,965 ft to TD @ 7,075 ft. Minimum drag. 05:30 - 09:30 4.00 DRILL SURF Circulate & condition mud. 09:30 - 13:30 4.00 DRILL SURF POOH w/13 1/2" bit. Hole in good shape. Normal drag. Printed: 2/26/2001 3:21:37 PM BP EXPLORATION Page 3 of 9 Operations Surnma Report Legal Well Name: NK-43 Common Well Name: NK-43 Spud Date: 1/8/2001 Event Name: DRILL+COMPLETE Start: 1/912001 End: 1/8/2001 Contractor Name: DOYEN Rig Release: 2/10/2001 Group: RIG Rig Name: DOYEN 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/18/2001 13:30 - 16:30 3.00 DRILL SURF PJSM. Lay down BHA. 16:30 - 18:00 1.50 DRILL SURF PJSM. Clear floor & RU for RIH w/10 3/4" surface casing. 18:00 - 20:00 2.00 DRILL SURF Tour change, PJSM con't RU for RIH w/10 3/4" surface casing. 20:00 - 20:30 0.50 DRILL SURF PJSM with all personel for RIH wi 10 3/4" surface casing. 20:30 - 21:30 1.00 DRILL SURF Make dummy run with landing joint. Mark same. 21:30 - 00:00 2.50 DRILL SURF PU & RIH w/10 3/4" surface casing. 1/19/2001 00:00 - 08:30 8.50 CASE SURF Run 10 3/4" 45.5# L-80 BTC casing. Total 170 jts run. Land casing on mandrel hanger. Shoe at 7064'. Float collar at 6978'. Wash last two joints to bottom as precaution. 08:30 - 09:00 0.50 CEMT SURF Circulate with fill up tool and slowly increase circulation rate to 10 BPM. 09:00 - 10:00 1.00 CEMT SURF Rig down casing running tools, clear floor and install cementing head 10:00 - 13:00 3.00 CEMT SURF Circulate and condition mud. Lower Vis to 50 and YP to ~20. PJSM held with all personel while circulating. 13:00 - 16:00 3.00 CEMT SURF Pump 10 bbl water and test lines to 3500 psi. Pump 75 bbl Mud Push 10.4 ppg weighted spacer with red dye. Mix and pump 856 bbl Arcticset Lite III at 10.7 ppg followed by 87 bbl class 'G' at 15.5 ppg. Drop top plug and clear lines with 2 bbl of cement and 8 bbl water. 16:00 - 17:30 1.50 CEMT SURF Displace cement with 666 bbl mud using the rig pumps. Displaced at 10 BPM, full returns, 8 bbl good cement to surface. Did not bump plug. Floats held. .17:30- 18:00 0.50 CEMT SURF Flush out diverter, riser, & flowline. :18:00 - 18:30 0.50 CEMT SURF PJSM with new crew. Observe well static. 18:30 - 00:00 5.50 CEMT SURF RD all casing & cement equipment. Flush all surface lines & valves. LD landing joint, riser, diver[er & diver[er line. Load pipe shed for next hole interval. Clean mud tanks. 1/20/2001 00:00 - 03:00 3.00 BOPSUF SURF Rig down flow line and riser. Stand riser in cellar and secure with chains and boomers. Pick up 21 1/4" diverter and stand in cellar and secure. 03:00 - 16:00 13.00 WHSUR SURF Nipple up FMC well head sections A and B. Change out mud cross on BOP. NU BOP & kill lines. 16:00 - 17:00 1.00 BOPSUF SURF PJSM. RU testing equipment to test BOP & related equipment. 17:00 ~ 00:00 7.00 BOPSUF SURF Test BOP & related equipment 250 psi Low / 5000 psi High. Hydril 500 asi Low / 3500 psi High. Witness by John Spalding of AOGCC. Incomplete. 1/21/2001 00:00 - 06:00 6.00 BOPSUF SURF Test BOP. Blind rams leaking. Change seals and retest OK. 06:00 - 07:30 1.50 BOPSUF SURF R.D. test equipment. Pull test plug. Install wear bushing. 07:30 - 10:00 2.50 DRILL INT1 PJSM. PU & MU BHA. Change out jars, orient MM. 10:00 - 11:00 1.00 DRILL INT1 RIH w/5" HWDP from derrick. 11:00 - 16:30 5.50 DRILL INT1 PU & RIH w/5" DP from pipe shed to 3,834 ft. Drift same. 16:30 - 18:00 1.50 DRILL INT1 PJSM. Slip & cut drlg line. 18:00 - 18:30 0.50 DRILL INT1 PJSM w/Night crew on slip & cut operations. Also picking up pipe from shed. First time for crew on this rig for both operations. 18:30 - 19:00 0.50 DRILL INT1 Complete slip & cut drlg line. 19:00 - 19:30 0.50 DRILL INT1 Calibrate Anadrill hook height sensor. 19:30 - 22:30 3.00 DRILL INT1 PU & RIH w/5" DP from pipe shed from 3,834 ft to 5,272 ft. Drift same. 22:30 - 23:00 0.50 DRILL INT1 RIH 5" DP out of derrick from 5,272 ft to 6,700 ft. Break circ. 23:00 - 23:30 0.50 DRILL INT1 Wash from 6,700 ft to 6,976 ft (Top of FC) 23:30 - 00:00 0.50 DRILL INT1 Circulate & condition mud prior to casing test. 1/22/2001 00:00 - 01:00 1.00, DRILL INT1 ~ Circulate & condition mud prior to casing test. 01:00 - 03:00 2.00 DRILL INT1 Attempt to pressure test 10 3/4" casing, no success, bled off 1,500 psi in 10 minutes. Isolated all surface equipment by installing test gauge in annulus valve on casing head, closing both manual & HCR valves on BOP. Also closed IBOP on top drive & standpipe valve. Broke bleeder Printed: 212612001 3:21:37 PM BP EXPLORATION Page 4 of 9 Operations Surnma Report Legal Well Name: NK-43 Common Well Name: NK-43 Spud Date: 1/8/2001 Event Name: DRILL+COMPLETE Start: 1/9/2001 End: 1/8/2001 Contractor Name: DOYON Rig Release: 2/10/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/22/2001 01:00 - 03:00 2.00 DRILL INT1 line on all three lines & observe no surface leaks. 03:00 - 04:30 1.50 DRILL ©THR INT1 Circulate and condition mud. Rearrange drill pipe in derrick. 04:30 - 10:30 6.00 DRILL OTHR INT1 Flow check. Pump dry job and POH with 9 7/8" BHA. 10:30 - 12:00 1.50 DRILL OTHR INT1 Lay down BHA, mud motor and MWD. 12:00 - 13:30 1.50 DRILL OTHR INT1 PJSM. Pick up Halliburton RTTS testing packer and RIH to 1030'. 7 ft below port collar 13:30 - 14:30 1.00 DRILL OTHR INT1 Set RTTS at 1030'. Pressure up to 3500 psi, hold for 15 minutes OK. Bleed off pressure and open rams. Pump down dril pipe and pressure up to 2500 psi. Stop pumping, pressure drop to 2100 psi in 4 minutes. Pressure up to 3000 psi, stop pumping and pressure drop to 2200 psi in 5 minutes. Unset RTTS. 14:30 - 18:00 3.50 DRILL OTHR INT1 RIH to 6976 ft, tag float collar, POH to 6966 ft. 18:00 - 20:00 2.00 DRILL OTHR INT1 Break circulation. Set RTTS at 6966'. Close pipe rams, test 10 3/4" X 5" annulus to 3500 psi for 30 minutes OK. Bleed off, open rams. Test down drill pipe to 2500 psi, (observe annulus static) bled to 1500 psi in 5 minutes. Bleed off pressure, unset RTTS. 20:00 - 23:30 3.50 DRILL OTHR INT1 Flow check. Pump dry job and POH with 10 3/4" RTTS. LD same. 23:30 - 00:00 0.50 DRILL OTHR INT1 PJSM. PU & MU mud motor, MWD & 9 7/8" bit. 1/23/2001 00:00 - 01:30 1.50 DRILL OTHR INT1 PU & MU mud motor, MWD & 9 7/8" bit and RIH. 01:30 - 04:30 3.00 DRILL OTHR INT1 RIH with 5" drill pipe to 3400', break circulation. RIH to 6976' 04:30 - 05:30 1.00 DRILL INT1 Drill float collar at 6976', wash to float shoe, no hard cement. Drill float shoe at 7064', wash soft cement out of rat hole to 7075' and drill 20' of new hole to 7095'. POH to 10 3/4" casing shoe. 05:30 - 06:00 0.50 DRILL INT1 Perform FIT. EMW 12.5 ppg. 06:00 - 21:00 15.00 DRILL INT1 Drill directional from 7095 to 8263. WOB-15-20 GPM=550 PS1=1850 ART=11 1/4 AST=I/2 '21:00 - 23:00 2.00 DRILL INT1 Pump barofibre sweep weighted to 3 ppg. over mud wt. 23:00 - 00:00 1.00 DRILL INT1 POOH from 8263 to 7900 working intermittent tight/swabbing hole. 1/24/2001 00:00 - 02:00 2.00 DRILL INT1 Worked tight/swabbing hole, with 30k overpull, from 7900-7700. Back reamed out of the hole from 7700 to shoe. (7062) 02:00 - 02:30 0.50 DRILL INT1 Service top drive at 10 3/4 shoe. 02:30 - 03:30 1.00 DRILL INT1 RIH to 8263, washing last stand down. No adverse hole conditions or fill. 03:30 - 18:00 14.50 DRILL INT1 Drill from 8263 to 9270. WOB=20-25 GPM=650 PS1=2550 ART--7 1/4 AST-- 1 18:00 - 19:00 1.00 DRILL INT1 Pump weighted barofibre sweep, 3 ppg. over mud weight. 19:00 - 21:00 2.00 DRILL INT1 POH from 9270 to 8515, working intermittent, 30k overpulls/swabbing hole. 21:00 - 23:00 2.00 DRILL INT1 Back ream out of hole from 8515 to 8100 to prevent swabbing. POH to shoe. Slug pipe. Observe well. 23:00 - 00:00 1.00 DRILL INT1 POH from 7062 to 4700. 1/25/2001 00:00 - 03:00 3.00 DRILL INT1 POH from 4700 to 887. 03:00 - 04:30 1.50 DRILL INT1 Lay down BHA, break bit. 04:30 - 08:30 4.00 DRILL INT1 Make up and orient BHA, load source. RIH with HWDP. Shallow test. 08:30 - 13:30 5.00 DRILL INT1 P/U 45 joints d.p. from pipeshed and RIH from derrick to 7025. 13:30 - 14:00 0.50 DRILL INT1 Safety/SURE meeting with Tony Bunch. 14:00- 15:30 1.50 DRILL INT1 Slip/cut drilling line. 15:30 - 16:00 0.50 DRILL INT1 Service top drive. 16:00 - 16:30 0.50 DRILL INT1 RIH from 7025 to 7121 16:30 - 19:00 2.50 DRILL INT1 Circulate and condition mud while getting PWD/Drilling parameters. 19:00 - 21:00 2.00 DRILL INT1 RIH from 7100-9270 washing last stand to bottom. (Trip into open hole ,was with no adverse hole conditions.) 21:00 - 00:00 3.00 DRILL INT1 Drilling ahead from 9270-9515 as per directional program. Printed: 2/26/2001 3:21:37 PM BP EXPLORATION Page 5 of 9 Operations Summa Report Legal Well Name: NK-43 Common Well Name: NK-43 Spud Date: 1/8/2001 Event Name: DRILL+COMPLETE Start: 1/9/2001 End: 1/8/2001 Contractor Name: DOYON Rig Release: 2/10/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/25/2001 21:00 - 00:00 3.00 DRILL INT1 ART- 2 AST= 0 WOB= 5-8 GPM- 630 @ 2400 psi 1/26/2001 00:00 - 21:00 21.00 DRILL INT1 Drilling from 9515 to 11,040 in West Sak formation. AST = .8 ART: 8.6 700 gpm @ 3000 PSI. 7-10 WOB. 21:00 - 21:30 0.50 DRILL INT1 Circ. open hole volume up inside casing in preparation for short trip. ECD's while drilling have showed hole is being properly cleaned. 21:30 - 00:00 2.50 DRILL INT1 Short trip from 11040 to 9240. Very minumal hole drag, with no swabbing during short trip. Went back to bottom with no adverse hole conditions. Wash last joint to bottom as precautionary measures. 1/27/2001 23:59 - 23:59 24.00 DRILL INT1 Drilling from 11040 to 12480 in West Sak/Tuff formation. Begin 3 degree per hundred drop, at 11,264. AST = 4.8 ART -- 11.8 575 gpm @ 2700 PSI. 7-10 WOB. 1/28/2001 00:00 - 08:00 8.00 DRILL INT1 Drilling from 12,480' to 12,545' in West Sak/Tuff formation. ROP fell off to below 5ft/hr and torque increase. AST = 0 ART = 6.75 595 gpm @ 2700 PSI. 7-10 WOB. 08:00 - 09:00 1.00 DRILL INT1 Circ. hole clean and observe well for flow. 09:00 - 10:00 1.00 DRILL INT1 Pull 5 stands D.P. and check torque values with those recorded on torque and trend sheets. Test choke manifold on trip out of hole, on approval of AOGCC. 10:00 - 19:00 9.00 DRILL INT1 Pump dry job and POH for new bit. 19:00 - 20:30 1.50 DRILL INT1 Check for flow. POH with BHA. STOP operations for PJSM on nuclear source. 20:30 - 21:00 0.50 DRILL INT1 PJSM with all those to be involved with the laying down and handling of the radioactive source. Lay down same. 21:00 - 22:30 1.50 DRILL INT1 POH to bit and break/Lay down same. Stand back BHA. 22:30 - 00:00 1.50 DRILL INT1 P/U test joint and retrieve wear bushing. Set test plug and rig up to test BOP to 250-5000. Witness of BOP test waived by AOGCC representative, "Chuck Scheve". 1/29/2001 00:00 - 03:00 3.00 BOPSUF INT1 Test BOP 250 psi Iow and 5000 psi high. 03:00 - 04:30 1.50 BOPSUF :INT1 Pull test plug and install wear bushing. 04:30 - 05:00 0.50 DRILL !INT1 Service Top Drive. 05:00 - 08:00 3.00 DRILL TEST INT1 Test MWD. Plug cable to tool failed during programming of MWD. 08:00 - 10:00 2.00 DRILL INT1 Make up new 9 7/8" PDC bit and RIH with BHA. ~10:00 - 16:30 6.50 DRILL INT1 RIH to 10 3/4 shoe. 16:30 - 18:00 1.50 DRILL INT1 Slip and cut drilling line. 18:00 - 20:00 2.00 DRILL INT1 Get drilling parameters, spot 40 bbl., 13.1 ppb.sweep, treated with 9% E.P. mud lube. 20:00 - 22:00 2.00 DRILL INT1 RIH to 9948, when # 3 rig generator dropped off the line. 22:00 - 23:30 1.50 DRILL POWR INT1 Orient toolface to high side of hole and work and circ. slowly while rig generator is repaired. 23:30 - 00:00 0.50 DRILL INT1 RIH from 9948 to 10,900. 1/30/2001 00:00 - 00:30 0.50 DRILL INT1 RIH from 10,900 to 12,960. 00:30 - 02:00 1.50 DRILL INT1 Ream from 12274 to 12545 in an attempt to reduce torque in "Tuff" formation. Pumped 40 bbl. weighted sweep treated with 9% E.P. mudlube. Began adding Lubetex immediately following sweep. 02:00 - 00:00 22.00 DRILL INT1 Drilling from 12545 to 13632. Torque subsided from 28-30k to 23-26k. Some indications of minor packing off in HRZ on connections- modify connection practices. HRZ @ 12,857 ft. ART= 6.4 ART= 7.4 WOB= 10-15 600gpm @ 2950 psi 1/31/2001 00:00 - 00:30 0.50 DRILL INT1 Drill to the calculated top of the Sag River, from 13,632 to 13,641. ART=.2 AST= 0 WOB= 5 600 gpm @ 2950. 00:30 - 04:00 3.50 DRILL INT1 Circulate sample up to confirm Sag River formation. Pump weighted sweep around until hole is clean. Monitor well for static condition. 04:00 - 05:00 1.00 DRILL INT1 POH to tight spot at 13,210. (Pulling 60K over normal up weight) Printed: 2/26/2001 3:21:37 PM BP EXPLORATION Page 6 of 9 Operations Surnma Report Legal Well Name: NK-43 Common Well Name: NK-43 Spud Date: 1/8/2001 Event Name: DRILL+COMPLETE Start: 1/9/2001 End: 1/8/2001 Contractor Name: DOYON Rig Release: 2/10/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 1/31/2001 05:00 - 06:00 1.00 DRILL INT1 Clean up tight hole by back reaming from 13,210 to 13,050. (Transition area between HRZ and Kuparuk) Top of Kuparuk at 13113 MD. 06:00 - 11:00 5.00 DRILL INT1 POH to 10 3/4 casing shoe with no adverse hole conditions. 11:00 - 13:00 2.00 DRILL INT1 Cut drilling line= 1.5 hours. Service top drive = .5 13:00 - 17:00 4.00 DRILL INT1 RIH to 13567. 17:00 - 19:00 2.00 DRILL INT1 Ream to bottom from 13,563 to 13,641. Pump sweep around once on bottom. Minor packing off, as pipe was being rotated and reciprocated, with sweep coming up open hole section. 19:00 - 22:00 3.00 DRILL INT1 Circulate and condition mud for casing running operation. Lots of "drilled" cuttings throughout circulation, with no major increase as sweep came around. (95% of cuttings from kingak section, but no indication of major sloughing.) Shakers cleaned up and up/down ~weights reduced. Spot App. 155 bbls., slick, liner running pill on bottom 22:00 - 00:00 2.00 DRILL INT1 POH, working intermittent overpulls of 10-25 from 13,641 to 12,800. Highest and most active overpulls in upper section of Kuparuk and lower section of HRZ. 2/1/2001 00:00 - 10:00 10.00 DRILL INT1 POH standing back first 70 stands in derrick, then lXl with remainder of string. 10:00 - 14:30 4.50 DRILL INT1 Lay down all HWDP, collars and remaining BHA. Download MWD tool. Clear floor of all excess equipment. 14:30 - 15:00 0.50 DRILL INT1 Remove wear ring. 15:00 - 18:00 3.00 CASE INT1 PJSM. Rig up casing equipment and casing fill up tool, prepare to RIH with 7" 18:00 - 00:00 6.00 CASE INT1 RIH with 7" casing, monitoring well for fluid lost to wellbore-no losses. 2/2/2001 00:00 - 11:30 11.50 CASE INT1 Run 331 joints of 7", 26 lb/fi, L-80, IBT-M casing to 13,649 ft- tag 8 ft deep on tally. M/U Pup joints- reciprocate pipe. Broke over @ 450 klbs. Up weight 425 klbs, Down weight 175 klbs. Pipe displacement good- no losses. 11:30 - 12:30 1.00 CASE INT1 PJSM> RID Franks fill Up Tool and r/u Cement head & Hose. 12:30 - 16:00 3.50 CEMT INT1 Stage Up Pumps gradually from 2 BPM to 8 BPM and reciprocate Pipe. Condition Mud. Hold PJSM while circulating. Up/Down= 375 klbs/185 klbs. 8.6 BPM/730 psi. 16:00 - 16:30 0.50 CEMT INT1 Pump 5 bbls Chemical Spacer, test lines. Pump 65 bbls Chemical Spacer followed by 50 bbls Mud Push Spacer @ 12 ppg @ 5 BPM/ 900 psi. 16:30 - 17:00 0.50 CEMT INT1 Mix and Pump 158 bbls 15.8 ppg Latex G Cement ( 760 sks) @ 4 BPM/ 400 psi. Reciprocate Pipe. 17:00 - 18:30 1.50 CEMT INT1 Drop Top Plug and displace with Rig Pumps @ 8.6 BPM/270 psi. Continue to reciprocate pipe until Cement turn corner- getting sticky- park pipe. Bump Plug w/96% Pump efficiency. Full Returns. Hold 3000 psi. Check floats- good. 18:30 - 21:30 3.00 CEMT INT1 Nipple down BOP to install 7" emergency slips. Secure and P/U stack with bridge crane. P/U to 300,000 hook load on blocks and install emergency slips in bowl. RID cement head and R/U mud evacuation system on top of casing. Evacuate mud from 7" casing to app. 40' below rotary table. 21:30 - 00:00 2.50 CEMT INT1 PJSM. Rough cut 7" casing and stand back BOPs out of the way. Make final cut and dress 7" stump for installation of Pack-off. 2/3/2001 00:00 - 00:30 0.50 CEMT INT1 LID cement head, slips and spider and all remaining equipment used on cement job. 00:30 - 03:30 3.00 CEMT INT1 Install 7" packoff and reducer bushing assembly in wellhead. 03:30 - 06:30 3.00 CEMT INT1 Install 3 1/2 rams in upper pipe ram cavity. N/U choke hose, riser and Printed: 2/26/2001 3:21:37 PM BP EXPLORATION Page 7 of 9 Operations Surnrna Report Legal Well Name: NK-43 Common Well Name: NK-43 Spud Date: 1/8/2001 Event Name: DRILL+COMPLETE Start: 1/9/2001 End: 1/8/2001 Contractor Name: DOYON Rig Release: 2/10/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/3/2001 03:30 - 06:30 3.00 CEMT INT1 flowline. 06:30 - 15:30 9.00 BOPSUR INT1 Perform weekly BOP test as per BPX policy. 250 Iow for 5 minutes, 5000 high for 10 minutes. Witness of test waived by AOGCC representative "John Crisp". 15:30 - 16:30 1.00 BOPSUR INT1 Attempt to remove test plug from bowl. The upper driller side pipe ram would not retract when put in the open position. Toolpusher mechanic trouble shooting situation while crew moved to next task. 16:30 - 21:00 4.50 DRILL INT1 Change top drive saver sub for next string of d.p.. (4" H.T. 38) Install bails and 5" elevators to begin lay down opeation of 70 stds. d.p., currently racked back in derrick. 21:00 - 00:00 3.00 DRILL INT1 PJSM. Lay down 70 stands D.P. from derrick to mouse hole lxl. 2/4/2001 00:00 - 04:00 4.00 DRILL INT1 PJSM Lay down 5" drill pipe in mouse hole. Attempting to remove the stuck ram block from cavity while laying down the drill pipe. 04:00 - 06:00 2.00 DRILL INT1 PJSM R/U to lower annulus valve and pressure test lines to 3500. Pressure up on 10 3/4 X 7" annulus and break down with 1950 PSI after 10.5 bbls. pumped. Pump 100 bbls. water with final injection rate of 3 bbls. per minute at 1200 PSI. Swap over to "Little Red" and test lines to 3500. Freeze protect annulus with 110 bbls. of crude at 2.4 bbls. per minute @ 1900-2050 PSI.( Shut in pressure at end ofjob=1010 PSI.) Continue to LID d.p. ,when able, during this operation. 06:00 - 08:30 2.50 DRILL !INT1 Continue to lay down 5 inch drill pipe from derrick. 08:30 - 00:00 15.50 DRILL INT1 PJSM P/U 3 1/2 drillpipe from pipeshed 1X1 and stand back in derrick. Continue to repair upper pipe ram cavity and change repair ram block. 2/5/2001 00:00 - 02:30 2.50 DRILL PROD1 PJSM P/U 4 inch drill pipe and stand back in derrick. 02:30 - 05:00 2.50 BOPSUF PROD1 Install upper pipe rams and function/pressure test to 250-5000. 05:00 - 08:00 3.00 DRILL PROD1 PJSM P/U and M/U BHA. Install sourc. Building BHA with 6 1/8 STX O9D bit, motor set to "zero bend", MWD and LWD. 08:00 - 10:30 2.50 DRILL TDRV PROD1 Change saver sub on top drive. Wrong button grabbed, resulting in damaged threads 10:30 - 22:30 12.00 DRILL PROD1 RIH from derrick, then P/U lxl from pipeshed, to 12,577. 22:30 - 23:30 1.00 DRILL PROD1 Slip and cut drilling line. 23:30 - 00:00 0.50 DRILL PROD1 RIH from 12577 to 13,100. 2/6/2001 00:00 - 02:00 2.00 DRILL PROD1 RIH and tag Float Collar @ 13,560 ft. 02:00 - 03:30 1.50 DRILL PROD1 Circulate Bottoms up at 5.2 BPM/3500 psi. 03:30 - 04:30 1.00 DRILL PROD1 Conduct Casing Test to 300/3500 psi for 30 minutes. 5.5 bbls Pumped/ Returned. 04:30 - 05:00 0.50 DRILL PROD1 Drill medium hard cement from 13,560 ft to 13,633 ft ( 10-12 klbs WOB @ 130 fi/hr) 05:00 - 07:00 2.00 DRILL PROD1 Circulate and condition mud to lower weight to 9.6 ppg in/out. 07:00 - 11:00 4.00 DRILL PROD1 Drill Reminder shoetrack and new formation to 13,663 ft. Up/Down= 240/145 klbs. Torque 12-14 Kftlbs. 250 GPM/3100 psi. Slow ROP at top of Sag ( 6-10 fi/hr) 11:00 - 11:30 0.50 DRILL PROD1 Conduct FIT to 11.0 ppg EMW. 735 surface pressure. 1.3 bbls pumped/ returned. 11:30 - 23:30 12.00 DRILL PROD1 Drill new formation from 13,663 ft to 13,948 ft. MM stalling on bottom unable to drill. Geologist called TD. Up/Down= 230/155 klbs. Torque 10-11 Kftlbs. 250 GPM/3100 psi. 23:30 - 00:00 0.50 DRILL PROD1 Circulate bottoms up. 250 GPM/3100 psi 2/7/2001 00:00 - 01:00 1.00 CLEAN COMP Circulate bottoms up @ 6.2 BPM/3400 psi 01:00 - 01:30 0.50 CLEAN COMP Check Trip back to 7" shoe @ 13,641 ft- hole good. 01:30 - 04:30 3.00 CLEAN COMP Sweep Hole clean and spot Liner Pill. Flow check. Pump Dry Job. 04:30 - 11:30 7.00 CLEAN COMP 'POOH to 7" shoe. Drop 1.875" hollow rabbit. POH and lay down 3.1/2" HWDP. Printed: 2/26/2001 3:21:~,7 PM BP EXPLORATION Page 8 of 9 Operations Sumrna Report Legal Well Name: NK-43 Common Well Name: NK-43 Spud Date: 1/8/2001 Event Name: DRILL+COMPLETE Start: 1/9/2001 End: 1/8/2001 Contractor Name: DOYON Rig Release: 2/10/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/7/2001 11:30 - 13:30 2.00 CLEAN COMP Lay down BHA and remove nuclear source. Bit 6/8 and 1/8" undergauge. Rotor turning. 13:30 - 15:00 1.50 CLEAN COMP Clear rig floor and R/U to run 4.1/2" Liner. PJSM. 15:00 - 17:30 2.50 CASE COMP PU & Run 4 1/2" liner as per program. MU hanger, break circ @ 6.5 BPM / 200 psi 17:30 - 00:00 6.50 CASE COMP RD csg handling equipment. Con't RIH w/liner on 3 1/2" & 4" DP. Fill pipe every 10 stds. 2/8/2001 00:00 - 04:30 4.50 CASE COMP RIH the 4.1/2" Liner on 3.1/2" x 4" tapered string to 7" shoe @ 13,641 ff. 04:30 - 05:00 0.50 CASE COMP Circulate string contents @ 5.3 BPM/1800 psi. 05:00 - 06:00 1.00 CASE COMP Run liner into open hole and tag bottom @ 13,948 ft. 14 joints 12.6 lb/fi, L-80 IBT-M run. 06:00 - 08:30 2.50 CASE COMP Circulate and condition hole @ 5.2 BPM/1600 psi with full returns and full reciprocation. Up/Down weight - 240 klbs/140 klbs. Hold PJSM and batch mix slurry volume while conditioning hole. 08:30 - 10:30 2.00 CEMT COMP Pump 20 bbls Chemical Wash, 50 bbls Mud Push @ 11 ppg, 20 bbls 15.8 ppg Slurry ( 96 sx) and displace with 40 bls Perforation Pill and 93 bbls Mud with Cement unit. Observe Dart Latch and bump plug to 3000 psi. Set Packer with 4200 psi. Full returns and full reciprocation throughout. CIP @ 10:04 hrs. Check Floats - good. 10:30 - 11:30 1.00 CEMT COMP Release from Liner and circulate maximum rate - no losses. Check Packer set by slacking off 60 Klbs. Observe spacer and traces of cement and remainder of perforation pill on bottoms up @ 9.5 BPM/ 3500 psi. 11:30 - 16:00 4.50 CASE COMP Lay out two singles and displace well to 9.6 ppg Brine. Pumped two complete hole volumes. 16:00 - 16:30 0.50 CASE DISP COMP Discover brine splashing through seam of cuttings chute and conveyor during displacement operations. All hands responded & the contaminated snow was placed back in the originating stream. 16:30 - 17:30 1.00 CASE COMP Con't displacing well to 9.6 ppg brine. Final NTU reading = 48, 17:30 - 18:00 0.50 CASE COMP PJSM for LD DP & BHA. Break & lay down cement head. 18:00 - 00:00 6.00 CASE COMP POH & rack 60 stds of 4" DP in derrick. Con't POH & LD DP. 2/9/2001 00:00 - 01:30 1.50 CASE COMP Con't to LD excess DP leaving 60 stds in derrick for rig move. 30 stds on each side. 01:30 - 03:30 2.00 CASE FLOR COMP Repair hydraulic line to pipe skate. 03:30 - 05:00 1.50 CASE COMP LD rest of DP. Inspect liner running tools O-K. Pull wear bushing. 05:00 - 06:00 1.00 CASE COMP Test casing 300 / 3500 psi. 6.2 bbls pumped / returned. 06:00 - 07:00 1.00 CASE COMP PJSM. RU to run 4 1/2" completion. 07:00 - 18:00 11.00 RUNCOI~ COMP PU & RIH w/4 1/2" completion string as per program 18:00 - 19:30 1.50 RUNCOI~ COMP MU SSSV, test control lines 5000 psi O-K. 19:30 - 22:30 3.00 RUNCOr~ COMP Con't RIH w/4 1/2" completion string maintaining 5000 psi on control lines. Total 53 bandit clamps used. 22:30 - 00:00 1.50 RUNCOr~ COMP MU tubing hanger & landing jr. RU & test contol lines to 5000 psi O-K. Land hanger. 2/10/2001 00:00 - 02:00 2.00 RUNCOI~ COMP Reverse Circulate Inhibited brine into well @ 3 BPM. 02:00 - 05:30 3.50 RUNCOI~ COMP Drop ball and rod. Set Packer and test tubing to 3500 psi/30 minutes and test annulus to 3500 psi/30 minutes. Shear RP valve @ 7444 ft. Break circulation to esnure open. Install TWC and test from below to 1000 psi. 05:30 - 08:00 2.50 RUNCOr~ 'COMP Nipple down BOPE 08:00 - 11:00 3.00 RUNCOI~ 'COMP Nipple up Tree and test same to 5000 psi/30 minutes- good. 11:00 - 12:30 1.50 RUNCOI~ COMP Pull TWC with DSM. 12:30 - 15:00 2.50 RUNCOI~ COMP Line up to Hot oil and freeze protect well with 130 bbls of Dead Crude Printed: 212612001 3:21 ::37 PM BP EXPLORATION Page 9 of 9 Operations Summary Report Legal Well Name: NK-43 Common Well Name: NK-43 Spud Date: 1/8/2001 Event Name: DRILL+COMPLETE Start: 1/9/2001 End: 1/8/2001 Contractor Name: DOYON Rig Release: 2/10/2001 Group: RIG Rig Name: DOYON 14 Rig Number: Sub Phase Description of Operations Date From-To Hours Task Code 2/10/2001 12:30 - 15:00 2.50 RUNCO~ COMP @ 1.75 BPM/2000 psi. 15:00 - 16:00 1.00 RUNCO~ COMP U-tube Diesel 16:00 - 16:30 0.50 RUNCO~ COMP Install BPV. RDMO. RELEASE RIG FROM NK-43 @ 1630 HRS ON 10TH FEBRUARY. Printed: 2/26/2001 3:21:37 PM Well: NK-43 Accept: 01/10/01 Field: N iakuk Spud: 01/11/01 APl: 50-029-22998-00 Release: 02/10/01 Permit: 201-001 Rig: Do¥on 14 Date POST-RIG WORK 03/10/01 Perfed with 2-7/8" Powerjet, 6 spf from 13710' to 13740'. Logged jewelry from TD to 12500'. 03/27/01 Perforate 30' interval with 2-7/8" HSD, 6 spf, 2906 Powerjet from 13674' to 13704'. ProActive Diagnostic Services, Inc. 14/ £ L L TRANSMITTAL To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE · Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of · Joey Burton / Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration [Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 , . LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S] OR CD-ROM FILM BLUE LINE ,_ Open Hole I I 1 c:~c~J- OC)l Res. Eval. CH I I 1 ,, Mech. CH 1 Caliper Survey I Signed' ~ Date' RECEIVED Print Name: L i~q ~,~ APR 0 3 2001 I ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage(~memorylog.com Website: ?_:"_~'il'%_!!~¥;~!}!~}.iq,_J.!.~'.:,¢ig)}i'!. 3/21/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. T3 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Niakuk Color Well Job # Log Description Date Blueline Sepia Prints CD NK-43 c~Ol-OOt 21137 SCMT 03/10/01 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson BIvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED 2 3 2001 l~k.~ Oil & Gas Cons. Comrmss~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 Al-tN: Sherrie Received ~ , (1 i~_ ~_.,..~ ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : Niakuk Well ..................... : NK-43 API number ............... : 50-029-22998-00 Engineer ................. : A. Nutter COUNTY: .................. : Doyon 14 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Driller's Tally GL above permanent ....... : 18.70 ft KB above permanent ....... : Top Drive DF above permanent ....... : 53.90 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point-- Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 43.38 degrees 7-Feb-2001 16:43:16 Page 1 of 6 Spud date ................ : il-Jan-01 Last survey date ......... : 07-Feb-01 Total accepted surveys...: 151 MD of first survey ....... : 0.00 ft MD of last survey ........ : 13948.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 13-Jan-2001 Magnetic field strength..: 1150.11 HCNT Magnetic dec (+E/W-) ..... : 27.08 degrees Magnetic dip ............. : 80.87 degrees MWD survey Reference Criteria Reference G ............... 1002 68 mGal Reference H ............... 1150 11 HCNT Reference Dip ............. 80 87 degrees Tolerance of G ............ (+/-) 2 50 mGal Tolerance of H ............ (+/-) 6 00 HCNT Tolerance of Dip .......... (+/-) 0 45 degrees Corrections Magnetic dec (+E/W-) ..... : 27.08 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.08 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report Seq Measured % depth - (ft) Incl angle (deg) 0'.00 0.00 174.00 0.40 201.60 0.10 288 65 0.58 380.00 1.66 'Azimuth angle (deg) 43 38 301.0© 345.83 60.32 55.62 COurse length (ft) 0.00 174.00 27.60 817. o5 91~35 6 7 8 9 10 469.00 1.72 559.99 1.92 651.71 2.87 741.39 5.94 831.00 7.03 56.71 42.02 51.42 53.88 58.22 89.00 90.99 91.72 89.68 89.61 11 12 13 14 15 16 17 18 19 20 929.00 9.20 1023.00 11.24 1117.00 14.34 1213.00 15.41 1308.00 15.74 58.49 98.00 54.72 94.00 53.33 94.00 49.14 96~00 47.25 ~95.00 TVD depth (ft) 21 22 23 24 25 0.00 174.00 201.60 288.65 379.98 468.94 559.88 651.52 740.93 829.96 926.98 1019 48 1111.14 1295.43 1404.00 16.33 43.78 96.00 1387.70 1497.00 17.45 48.44 93.00 1476.69 1530.00 18.61 48.86 33.00 1508.07 1597.00 19.88 48.11 67.00 1571.33 1692.00 19.78 45.63 95.00 1660.69 1788.00 21.69 1884.00 25.44 1980.00 31.17 2076.00 36.94 2171.00 43.09 44.00 96.00 41.48 96.00 41.53 96.00 42.91 96.00 42.96 95.00 26 2267.00 47.79 27 2362.00 49.71 28 2457.00 51.67 29 2553.00 49.65 30 2648.00 51.45 1750.47 1838.45 1922.94 2002.44 2075.17 42.53 96.00 2142.51 42.73 95.00 2205.14 42.05 95.00 2265.32 42.74 96.00 2326.18 43.36 95.00 2386.54 7'Feb-2001 16:43:16 Vertical section (ft) 0.00 -0.13 -0.14 0.32 2.06 4.62 7.47 11.28 18.07 27.93 41.29 57.53 77.98 102.38 127.80 154.29 181.25 191.42 213.42 245.58 279.55 317.91 363.39 417.11 478.17 546.54 617.96 691.45 765.68 839.03 DiSPl +N/S- (ft) Displ +E/W- (ft) 0.00 0.31 0.39 0.68 1.65 3.11 5.00 7.57 11.71' 17.33 24.58 33.80 46.05 61.49 78.5O 97.08 115.77 122.52 137.16 159.19 183.31 211.53 245.60 285.36 330.06 0.00 -0.52 -0.61 -0 .~24 1.25 3.43 5.59 8.41 13.92 22.33 34.11 47.99 64.81 83.99 103.00 121.90 141.38 149.05 165.58 189.10 213.04 239.03 269.18 305.33 346.92 380.29 432.83 487.12 541.96 595.56 393.32 441.69 491.24 541.29 591.37 Page Total displ (ft) At Azim (dew) 0.00 0.61 0.72 0.72 2.07 0.00 301.00 302.35 340.13 37.06 4.63 7.50 11.32 18.19 28.26 47 48 48 49 52 .75 .21 .02 .94 .18 42.04 58.70 79.50 104.10 129.5'0 54 54 54 53 52 .22 .84 .61 .79 .69 155.84 182.74 192.94 215.01 247.18 51 5O 50 5O 49 .47 .69 .58 .36 .91 281.05 319.18 364.39 417.92 478.84 49 48 47 46 46 .29 .49 .62 .94 .43 547.10 618.42 691.81 765.97 839.29 45.97 45.58 45.24 44.96 44.80 2 of 6 DLS (de9/ 100f) 0.00 0.23 1.22 0.65 1.19 0.08 0.56 1.12 3.43 1.33 2.21 2.28 3.31 1.58 0.64 1.17 1.89 3.54 1.93 0.89 2.08 4.04 5.97 6.06 6.47 4.91 2.03 2.14 2.18 1.96 Srvy tool type TIP MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD__M MWD__M MWD__M MWD__M MWD__M MWD_M MWD_M MWD_M MWD_M MWD_M Tool qual type (c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 7-Feb-2001 16:43:16 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 31 2743.00 53.35 41.70 95.00 2444.50 32 2839.00 52.01 42.54 96.00 2502.70 33 2935.00 52.69 41.47 96.00 2561.34 34 3030.00 51.09 42.08 95.00 2619.97 35 3127.00 50.34 42.50 97.00 2681.39 36 3223.00 50.49 42.50 96.00 2742.57 37 3318.00 51.61 42.41 95.00 2802.29 38 3412.00 51.89 42.83 94.00 2860.48 39 3508.00 49.67 44.61 96.00 2921.18 40 3606.00 51.13 43.34 98.00 2983.65 41 3703.00 52.84 42.56 97.00 3043.39 42 3798.00 54.26 40.77 95.00 3099.83 43 3894.00 54.80 41.22 96.00 3155.53 44 3986.00 53.88 40.74 92.00 3209.17 45 4083.00 54.01 41.11 97.00 3266.26 46 4179.00 53.41 42.42 96.00 3323.08 47 4275.00 52.77 43.20 96.00 3380.73 48 4370.00 51.79 45.29 95.00 3438.86 49 4467.00 51.07 45.91 97.00 3499.33 50 4564.00 52.32 45.74 97.00 3559.46 51 4660.00 53.06 43.88 96.00 3617.65 52 4754.00 52.45 43.70 94.00 3674.54 53 -4850.00 52.29 42.16 96.00 3733.16 54 4948.00 52.47 41.02 98.00 3792.98 55 5043.00 52.43 41.11 95.00 3850.88 56 5140.00 53.02 40.33 97.00 3909.63 57 5235.00 52.40 40.23 95.00 3967.18 58 5331.00 52.19 40.30 96.00 4025.89 59 5427.00 51.44 41.24 96.00 4085.24 60 5522.00 51.87 41.88 95.00 4144.18 914.28 651.03 990.61 707.65 1066.59 764.14 1141.31 819.88 1216.37 875.42 1290.35 929.97 1364.22 984.48 1438.03 1038.80 1512.39 1092.56 1587.89 1146.90 1664.31 1202.84 1740.68 1259.92 1818.80 1318.93 1893.48 1375.36 1971.83 1434.61 2049.17 1492.33 2125.93 1548.64 2201.06 1602.47 2276.84 1655.54 2352.89 1708.58 2429.21 1762.75 2504.04 1816.77 2580.06 1872.43 2657.64 1930.49 2732.90 1987.27 2810.00 2045.77 2885.47 2103.43 2961.31 2161.39 3036.69 2218.54 3111.16 2274.29 642 693 744 794 844 .23 .43 .29 .08 .60 894 944 994 1045 1098 .59 .45 .44 .82 .24 1150 1201 1252 1301 1352 .31 .09 .38 .40 .77 1404.31 1456.47 1508.89 1563.07 1617.66 1671 1723 1775 1826 1876 .47 .25 .03 .55 .03 1926.38 1975.25 2024.34 2073.61 2123.04 Page Total displ (ft) At Azim ( dew ) 914.49 990.77 1066.71 1141.39 1216.44 44.61 44.42 44.25 44.08 43.97 1290.40 1364.26 1438.06 1512.42 1587.93 43.89 43.81 43.75 43.75 43.76 1664.34 1740.70 1818.80 1893.48 1971.83 43.72 43.63 43.52 43.42 43.32 2049.18 2125.93 2201.06 2276.84 2352.89 43.26 43.24 43.28 43.35 43.43 2429.22 2504.04 2580.06 2657.65 2732.90 43.48 43.49 43.47 43.42 43.35 2810.01 2885.49 2961.34 3036.73 3111.22 43.28 43.20 43.12 43.07 43.03 3 of 6 DLS ( deg / 100f) 2.43 1.56 1.13 1.76 0.84 0.16 1.18 0.46 2.72 1.79 1.87 2.13 0.68 1.09 0.34 1.27 0.93 2.02 0.89 1.30 1.72 0.67 1.28 0.94 0.09 0.88 0.66 0.23 1.10 0.70 Srvy tool type MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M Tool qual type [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL sCHLUMBERGER Survey RepOrt 7-Feb-2001 16:43:16 Page 4 of 6 Seq -- 61 62 6,3 64 65 66 67 68 69 70 Measured Incl AzimUth depth angle angle (ft) (deg) (deg) Course length (ft) TVD dePth (ft) Vertical sectiOn (ft) Displ +N/S- (ft) 5617.00 52 53 41.91 95.00 4202.41 3186.20 2330.16 5712.74 51.28 41.96 95.74 4261.47 3261.52 2386.21 5807.02 51.10 40.99 94.28 4320.56 3334.94 2441.25 5903.82 50.66 41.46 96 80 4381.64 3409.99 2497.74 5999.69 50.66 42.04 95.87 4442.41 34'84.10 2553.05 6094.97 49.68 42.28 95.28 6191.66 49.72 42.76 96.69 6289.00 50.71 42.93 97.34 6383.00 51.28 41.36 94.00 6479.00 51.37 42.29 96.00 4503.44 3557.26 2607.29 4565.98 3630.99 2661.64 4628.27 3705.79 2716.49 4687 . 43 3778 · 81 2770 · 65 4747.42 3853.73 2826.49 Displ +E/W- (ft) 2t73.16 2223-.52 2272.17 2321.66 2371.03 2420.14 2469.98 2520.85 2569.86 2619.84 Total displ (ft) At Azim (deg) 3186.27 3261.60 3335.04 3410.10 3484.23 3557.40 3631.14 3705.94 3778.97 3853.91 43.00 42.98 42.95 42.91 42.88 42.87 42.86 42.86 42.85 42.83 DLS (deg/ 100f) 0.70 1.31 0.82 0.59 0.47 1.05 0.38 1.03 1.43 0.76 Srvy tool type MWD_M MWD_M MWD_M MWD_M MWD_M MWD__M MWD__M MWD __M MWD_M MWD_M Tool qual type 71 72 73 74 75 76 77 78 79 80 6575.00 51.76 42.11 96.00 6671.00 51.45 42.53 96 00 6766.00 50.83 42.97 95.00 6861.26 50.47 4'3.64 95.26 6957.14 51.21 43.67 95.88 7016.4t 51.49 43.90 7062.00 51.64 44.08 7153.00 51.11 44.45 7248.92 50.48 44.59 7345.00 49.87 45.18 59.27 4'5.59 91.00 95.92 96.08 4807.10 4866 72 4926.33 4986.73 5047.27 5084.29 5112.63 5169.44 5230.07 5291.60 3928.91 2882.20 2670.35 4004.14 2937.83 2721.00 4078.11 2992.16 2771.22 4151.77 3045.76 2821.74 4226.11 3099.55 2873.06 4272.40 3132.97 4308.11 3158.66 4379.19 3209.57 4453.50 3262.57 4527.27 3314.85 29-05.09 2929.89 2979.51 3031.63 3083.70 3929.10 4004.34 4078.31 4151.97 4226.31 4272.59 4308.29 4379.37 4453.66 4527.41 42.81 42.81 42.80 42.81 42.83 42.84 42.85 42.87 42.90 42.93 .43 .47 .75 .66 .77 .56 .45 .66 .67 .79 MWD_M MWD_M MWD_M MWD_M MWD_M MWD__M MWD MWD__M MWD__M MWD_M 81 82 83 84 85 86 87 88 89 90 7441 . 00 49 · 61 45.01 7536.00 50.26 43.43 7632.00 50.98 42.24 7727.71 50.98 42.14 7821.46 50.72 42.49 7918.32 50.36 42.66 8013 . 33 50 . 48 42 . 03 8108 . 62 49 . 02 43 . 35 8204.93 48.18 43 .29 8299.30 49.47 43.36 96,00 95.00 96.00 95.71 93.75 96.86 95.01 95.29 96.131 94,37 [(c)200t Anadrill IDEAL ID6 i1C 08] 5353.64 5414.79 5475.70 5535.96 5595.15 5656.71 5717.24 5778.81 5842.50 5904.63 4600 50 3366.57 4673.19 3418.67 4747.39 3473.09 4821.73 3528'.18 4894.42 3581.94 4969.19 3637.01 5042.41 3691.13 5115.13 3744.59 5187.37 3797 15 5258.40 3848.82 3135.59 3186.28 3236.73 3286.67 3335.61 3386.21 3435.53 3484.83 3534.40 3583.13 4600.62 4673,30 4747.50 4821.85 4894.55 4969.33 5042.55 5115.28 5187.52 5258.55 42.97 42.98 42.98 42.97 42.96 42,95 42.95 42.94 42.95 42.95 0.30 1.45 1.22 0.08 0.40 0.40 0.53 1.86 0.87 1.37 MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 91 8396.49 49.54 43.21 92 8490.01 49.42 44.33 93 8588.00 49.43 41.58 94 8684.00 49.54 42.46 95 8780.00 48.83 43.32 96 8874.45 49.75 43.12 97 8969.87 50.51 42.32 98 9066.01 50.55 42.49 99 9162.00 50.81 43.25 100 9211.60 50.77 42.84 101 9250.74 50.46 43.02 102 9345.73 50.51 42.32 103 9440.72 50.42 43.49 104 9536.76 50.14 42.78 105 9632.03 50.03 42.58 97.19 93.52 97.99 96.00 96.00 94.45 95.42 96.14 95.99 49.60 39.14 94.99 94.99 96.04 95.27 TVD depth (ft) 5967.74 6028.51 6092.25 6154.62 6217.36 6278.97 6340.14 6401.25 6462.07 6493.43 6518.26 6578.71 6639.17 6700.55 6761.68 106 9727.02 49.97 42.08 94.99 6822.73 107 9824.29 49.82 42.01 97.27 6885.39 108 9919.78 50.09 42.64 95.49 6946.83 109 10015.53 49.92 41.95 95.75 7008.37 110 10110.98 49.78 41.33 95.45 7069.92 111 10206.01 49.98 41.36 95.03 7131.15 112 10301.25 50.11 44.02 95.24 7192.32 113 10397.26 50.12 44.40 96.01 7253.89 114 10492.90 49.93 42.03 95.64 7315.34 115 10588.07 50.05 41.81 95.17 7376.53 116 10684.28 50.33 42.53 96.21 7438.12 117 10780.27 50.36 42.55 95.99 7499.38 118 10875.60 50.00 42.27 95.33 7560.43 119 10971.12 49.96 41.87 95.52 7621.85 120 11066.92 49.76 41.09 95.80 7683.61 7-Feb-2001 16:43:16 Vertical section (ft) 5332.31 5403.40 5477.81 5550.77 5623.42 5695.02 5768.24 5842.45 5916.71 5955.14 5985.39 6058.66 6131.92 6205.79 6278.85 6351.61 6425.98 6499.07 6572.41 6645.34 6717.96 6790.95 6864.61 6937.89 7010.76 7084.65 7158.55 7231.76 7304.89 7378.08 Displ +N/S- (ft) Displ +E/W- (ft) 3902.63 3953.96 4008.43 4062.65 4115.88 363 368 373 378 383 3.81 2.99 3.69 2.55 1.99 4168.05 4221.86 4276.66 4331.08 4359.17 388 393 398 403 405 1.02 0.70 0.75 1.27 7.50 4381.32 4435.20 4488.86 4542.76 4596.48 407 412 417 422 427 8.11 7.78 7.65 8.15 7.69 4650.28 4705.53 4759.57 4813.83 4868.35 432 437 442 447 452 6.69 6.52 5.74 5.10 3.58 4922.91 4976.56 5029.37 5082.77 5137.01 457 462 467 472 477 1.58 1.08 2.45 2.63 1.33 5191.79 5246.24 5300.30 5354.60 5409.47 482 487 492 496 501 0.94 0.91 0.29 9.30 7.81 Page Total displ (ft) At Azim (deg) 5332.45 5403.54 5477.95 5550.92 5623.58 5695.17 5768.40 5842.62 5916.87 5955.31 5985.56 6058.84 6132.09 6205.96 6279.04 6351.80 6426.19 6499.28 6572.63 6645.57 6718.21 6791.21 6864.86 6938.14 7011.02 7084.92 7158.82 7232.04 7305.19 7378.40 42.96 42.97 42.97 42.96 42.95 42.96 42.95 42.95 42.95 42.95 42.95 42.94 42.94 42.95 42.94 42.94 42.93 42.92 42.91 42.90 42.88 42.88 42.89 42.90 42.89 42.88 42.88 42.87 42.86 42.85 5 of 6 DLS (deg/ 100f) 0.14 0.92 2.13 0.71 1.00 0.99 1.02 0.14 0.67 O.65 0.87 0.57 0.95 0.64 0.20 0.41 0.16 0.58 0.58 0.52 0.21 2.15 0.30 1.91 0.22 0.64 0.04 0.44 0.32 0.66 Srvy tool type MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD__M MWD__M MWD__M MWD__M MWD__M MWD__M MWD__M MWD__M MWD__M MWD__M MWD__M MWD__M MWD__M MWD__M MWD__M Tool qual type [(c)2001 Anadrill IDEAL ID6_iC_08] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl # depth angle - (ft) (deg) 121 11162.78 49.33 122 11255.77 49.12 123 11353.55 47.66 124 11449.26 46.69 125 11546.15 44.97 126 11642.12 42.97 127 11736.97 40.56 128 11833.62 37.11 129 11929.20 33.81 130 12025.48 32.85 Azimuth angle (deg) 41.62 41.07 42.03 43.72 45.38 45.27 45.59 46.30 47.37 48.58 131 12122.60 32.55 48.11 132 12218.10 32.04 47.58 133 12313.98 31.51 47.15 134 12410.47 31.66 46.78 135 12508.09 31.34 45.92 136 12595.08 31.01 45.07 137 12690.46 30.30 44.17 138 12787.14 29.65 43.74 139 12884.66 28.67 43'.12 140 12982.03 28.10 42.56 141 13078.09~'' 27.66 41.47 142 13175.04 27.54 41.04 143 13271.77 ~ 27.76 39.64 144 13368 27 26.47 39.32 145 13463 92 24.88 39.01 146 13559.41 24.11 37.55 147 13664.69 23.67 37.05 148 13763.21 22.23 36.25 149 13858.95 19.79 33.64 150 13888.38 19.39 32.08 Final Survey Projected to TD 151 13948.00 19.39 32.08 CourSe length (ft) 95.86 92.99 97.78 95.71 96.89 TVD depth (ft) 7745.81 7806.54 7871.47 7936.5-3 8004.05 95.97 94.85 96.65 95.58 96.2-8 97.12 95.50 95.88 96.49 97.62 86.99 95.38 96.6-8 97.52 97.37 8073.11 8143.85 8219.13 8296.97 8377.42 8459.14 8539.87 8621.38 8703.58 8786.81 8861.24 8943.29 9027.04 9112.20 9197.86 96.06 9282 77 96.95 9368 69 96.73 9454.37 96 50 9540.27 95.65 9626 47 95.49 9713.37 105.28 9809.63 98.52 9900.34 95.74 9989.71 29 43 10017,44 59 62 10073~68 7 Feb-2001 16:43:16 Vertical section (ft) 7450.98 7521 35 7594.42 7664.61 7734.08 Displ +N/S- (ft) Displ +E/W- (ft) 5464.22 5517.09 5571.80 5623.24 5672.78 5066.00 5112.52 5161.01 5208.76 5257.50 7800.67 7863.80 7924.34 7979.68 8032 41 8084.68 8135.55 8185 92 8236~35 8287.29 8332.29 8380.91 8429.21 8476 72 8523.01 5719.62 5763.96 5806.10 5844.04 5879.46 . 5914.33 5948.58 5982.77 6017.26 6052.47 6084.03 6.118.64 6153.41 6187.92 6221.86 5304.88 5349.88 5393.42 5433.84 5473.13 5512.33 5550.16 5587.30 5624.24 5661.15 5693.27 5727.43 5760.95 5793.62 5825.10 8567.92 8612.80 8657.62 8701.50 8742.83 8782.26 8824.66 8862.81 8896.76 8906 46 _ 8925.87 6255.23 6288.99 6323.21 6357.15 6389.28 6420.35 6454.27 6485.08 6513.19 6521.47 6538.24 5855 5884 5913 5941 5967 5992 6018 6041 6060 6066 6076 .17 .78 .84 .80 .98 .51 .35 .28 .98 .33 .84 Page Total displ (ft) At Azim (deg) 7451.32 7521.71 7594.80 7664.99 7734.45 7801.01 7864.12 7924.63 7979.94 8032.64 8084.87 8135.71 8186.06 8236.48 8287.40 8332.39 8381.00 8429.30 8476.81 8523.10 8568.01 8612.90 8657.74 8701.63 8742.98 8782.43 8824.86 8863.04 8897.02 8906.74 8926.18 42.83 42.82 42.81 42.81 42.82 42.85 42.87 42.89 42.92 42.95 42.99 43.02 43.04 43.07 43.09 43.10 43.11 43.11 43.12 43.11 43.11 43.10 43.08 43.07 43.05 43.03 43.00 42.97 42.94 42.93 42.91 6 of 6 DLS (deg/ 100f) 0.61 0.50 1.66 1.64 2.16 2.09 2.55 3.60 3.51 1.21 0.40 0.61 0.60 0.25 0.57 0.63 0.89 0.71 1.05 0.65 0.70 0.24 0.71 1.35 1.67 1.03 0.46 1.50 2.73 2.24 0.00 Srvy tool type MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD__M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD_M MWD Tool qual type S T A T E OF ALASKA ALASKA OIL AND GAS CONSER VA TION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7th Ave., Suite 100 Anchorage, AK 99501 PHONE: (907) 279-1433 FAX: (907) 276-7542 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, Ak 99519-6612 Re: Niakuk NK-43 BP Exploration (Alaska) Inc. Permit No: 201-001 Sur Loc: 1441'NSL, 802'WEL, Sec. 36, T12N, R15E, UM Btmhole Loc. 2743'NSL, 570'EWL, Sec. 29, T12N, R16E, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 0351 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. Commissioner BY ORDER OF TIlE COMMISSION DATED this ~- ~z( day of January, 2001 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Depamnent of Environmental Conservation w/o encl. Re: Niakuk NK-43 Subject: Re: Niakuk NK-43 Date: Thu, 04 Jan 2001 08:26:19 -0900 From: Robert Crandall <Bob_Crandall@admin.state.ak. us> Organization: DOA-AOGCC To: Julie Heusser <julie_heusser@admin.state.ak. us>, "Seamount, Dan" <dan_seamount@admin.state.ak. us> CC: "Davies, Steve" <steve_davies@admin.state.ak. us> Julie: The primary cementing concern with Niakuk wells is a good cement job on the surface casing which must be below the base of the permafrost, no aquifers are present in this portion of the slope (exempted aquifers are present in the KRU). Hydrocarbons above the the Kuparuk are present as small fault and stratigraphically controlled non- commercial gas accumulations in sands of the West Sak and Ugnu. While these sands may represent a drilling concern they have manifested themselves only as gas cut mud and occur sporadically. We see a similar distribution of gas at Northstar and are concerned about granting a diverter wavier there as at Northstar the potentially gas charged interval is in the surface hole portion of the wells. We will be talking with BP about that in the next week or so. The Kingak shale has had a few sandy looking intervals with oil shows, but nothing we would classify as significant, still there is some (very) small chance something could be encountered here. The NK-43 well is programed to set surface casing at 5057 TVD, above the Ugnu 4A marker, this is primarily to accommodate the high departure directional plan and to get a good casing seat above the very sandy Ugnu. It will also accommodate any concerns we have about gas ( the BOP will be nippled up while drilling the intermediate hole). Note the logging program will evaluate any intermediate hole shows (Ugnu, West Sak, and Kingak - GR/Resistivity/Neutron/Density). We aren't holding our breath, but hey who knows? Bp has done a good job of designing this program from the perspective of evaluating potential shows. RPC Julie Heusser wrote: > > Guys, > > I'm attempting to fill Tom's shoes here for the next few days and am in > the process of doing the engineering evaluation for NK-43. In the > Niakuk area are there any hydrocarbons shallower than the Kuparuk that > should be covered wi th cement~ Inquiring minds want to know ..... > > Thanks > > Julie 1 of 1 1/4/01 10:29 AM .~.,. STATE OF ALASKA ALASK~ ~IL AND GAS CONSERVATION COMIi..~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill 11 b. Type of well [] Exploratory [] Stratigraphic Test ~ Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [~ Single Zone ~,~ltiple Zone 2. Name of Operator 5. Datum Elevation (DF or KI~) 10. Field and Po01 BP Exploration (Alaska) Inc. Plan RKB = 52.9' Niakuk Oil Pool 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 a$,/¢~7o~. 6/~DL 034635 4. Location of well at surface 7. Unit or: Property Name 11. Type Bond (See 20 AAC 25.025) 1441' NSL, 802' WEL, SEC. 36, T12N, R15E, UM Niakuk At top of productive interval 8. Well Number 2422' NSL, 265' EWL, SEC. 29, T12N, R16E, UM NK-43 Number 2S100302630-277 At total depth 9. Approximate spud date 2743' NSL, 570' EWL, SEC. 29, T12N, R16E, UM 01/05/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028338, 2743' MDI NK-19 is 17.32' away at 493' MD 2459 13969' MD / 10093' TVD 16. TO be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 400' MD Maximum Hole Angle 50 ° Maximum surface 3713 psig, At total depth (TVD) 9870' / 4700 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casinq Weiqht Grade Couplinq Lenqth MD TVD MD TVD (include staqe data) 30" 20" 91.5# H-40 Weld 80' Surface Surface 113' 113' 260 sx Arctic Set (Approx.) 13-1/2" 10-3/4" 45.5# L-80 BTC 6875' Surface Surface 6905' 5057' ~.29 sx AS Lite 3, 358 sx 'G', 995 sx AS Lite 3 9-7/8" 7" 26# L-80 BTC-M 13575' Surface Surface 13605' 9778' 533 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 630' 13340' 9548' 13969' 10093' 96 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production LinerRECEIVED DEC g 2000 Perforation depth: measured true vertical Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch ~ Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements 'Contact Engineer Name/Number: Bill Isaacson, 564-5521 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true a~r~l c/.~rrect to the best of my knowledge S~gned LowellCrane ~, ~ , ~,~..--Title SemorDrl ng Engineer Date /~.(,.- ~'O ~ "' ":'"." .:. ' :. :': ,'.' ..',.'..'":','/::::':i.:??'.':'.'::'? ': ',: '.:.."'.:': ,.:.::':,. ;::... '.. ".i. "~:'i: ':'.':.,:':.".~: :.:':.'~;'..'commtssion"'use only;'.,.=. .;". ',:.:..,.:' ..:. :..:'~ .'...:: ',...:....':'...:?.'. '~. :,. ":i :. ::" '," '..." ": ." ".:'".' '."....,'.'..!..". ". :'= .. :'. permit Numl~er -IAPl' Numbe'r ' _ '_ ~' ' "' ' "I'i'' ' 'APProvalbme '" J' see cover letter ..... ;zoo.- oo/ I 0- I I for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Loz~Requit"ed [] Yes [] No Hydrogen Sulfide Measures [] Yes [] No Directional Survey Required [] Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K [] 3.5K psi for CTU Other: by orderof Approved By Commissioner the commission Date~) [ Form 10-401 Rev. 12-01-85 ORIGINAL Triplicate NK-43 Permit to Drill I Well Name: INK-43 Drill and Complete Plan Summary I Type of Redrill (producer or injector): I Producer Surface Location: x = 721,757 / Y = 5,979,983 1441' FSL 802' FEL S36T12N R15E Umiat Target Location: X = 727,487 / Y = 5,986,418 2422' FSL 265' FWL S29 T12N R16E Umiat Bottom Hole Location: X = 727,781 / Y = 5,986,748 2743' FSL 570' FVVL S29 T12N R16E Umiat I AFE Number: 15L0506 I I Estimated Start Date:I 1/5/01 I MD= 113,969' I I TVD: I~ 0,093' I I Rig: I Doyon 14 I Operatin~l days to complete: 125 I Cellar Elevation:119.5' I RKB: 152.9' I Well Design (conventional, slimhole, etc.): I Slimhole I Objective: I Niakuk Kuparuk Development and Sag River Ivishak appraisal Formation Markers Formation Tops MD TVDss Comments Base Permafrost 1966' 1800' SV3 5761' 4270' SV1 6749' 4904' Ugnu 4A 7444' 5350' Est. pore pressure 2420 psi (8.7 ppg EMW) West Sak 9181' 6465' Est. pore pressure 2925 psi (8.7 ppg EMW) CM3 / K-12 10,451' 7280' Tuffs 12,162' 8475' Top HRZ 12,785' 9015" Top Kuparuk 13,085' 9275' Est. pore pressure 3750 psi (7.8 ppg EMW) Top Kingak 13,244' 9412' Sag River 13,599' 9720' Est. pore pressure 4500 psi (8.9 ppg EMW) Ivishak 13,772' 9870' Est. pore pressure 4700 psi (9.2 ppg EMW) TD 13,969' 10,040' RECEIVED DEC g g 2000 Alaska 0ii & Gas Cons. Commission Anchorage NK-43 Permit to Drill Casing/Tubing Program Hole §ize -Csg/- Wt/Ft Grade Conn Length Top Btm Tb~l O.D. MD/TVD MD/I'VD 30" 20" 91.5# H-40 WLD 80' GL 113' / 113' 13-1/2" 10-3/4" 45.5# L-80 BTC -6875' GL 6905' / 5057' 9-7/8" 7" 26# L-80 BTC-M -13,575' GL 13,605' / 9778' 6-1/8" 4-1/2" 12.6# L-80 IBT-M -630' 13,340' / 9548' 13,969' / 10,093' Tubing 4-1/2" 12.6# L-80 IBT-M -12,905' GL 12,935' / 9198' Directional KOP: I 400' MD Maximum Hole Angle: Close Approach Well: Survey Program: -50° In Tangent Interval 2398' to 11,416' MD -30° Through Reservoir Target Intervals 12,085' to 13,969' MD All wells pass BP Close Approach guidelines. The two nearest close approach wells are NK-19 & NK-41/41A. NK-19 is 17.32' well-to-well at 493' MD and passes under Major Risk rules. NK-41/41A is -97' well-to-well at 7076' MD and passes under Risk Based rules. This well is plugged back and is of very minimal risk to the drilling operations on NK-43. Gyrodata single shots to -1500' MD for magnetic interference from offset wells. Standard MWD Surveys from -1500 to TD. Mud Program 13-1/2" Surface Hole ',0' to 6905' MD) Interval I Initial SV Sands Interval TD Density (PPg) 8.6 - 9.0 9.0 - 9.4 9.4 IExtended Bentonite Spud Mud I Viscosity YP (seconds) -300 75-60 150-200 50-30 80-110 30-25 LSR YP 30-40 18-11 8-15 Gel-10 sec Fluid Loss 40-65 12-15 20-35 6-8 20-30 6-8 9-7/8" Intermediate/Production Hole LSND (6905' to 13,599' MD) Interval Density Funnel YP LSR YP pH APl FL (ppg) Viscosity Initial 8.8 - 9.0 40-50 18-15 4-7 8.5 - 9.5 8-6 Ugnu 9.1 - 9.2 45-60 18-25 8-10 8.5 - 9.5 8-6 West Sak 9.2 - 9.3 45-60 18-25 8-10 8.5 - 9.5 8-6 Colville 9.3 - 9.4 45-60 18-25 8-10 8.5 - 9.5 +/-6 Tuffs 10.3 45-60 18-25 8-10 8.5 - 9.5 +/-4 'Shale Wall' H RZ 10.3 45-60 18-25 8-10 8.5 -9.5 +/-4 Kuparuk 10.3 45-60 18-25 8-10 8.5 -9.5 +/-4 Kingak 10.3 45-60 18-25 8-10 8.5 -9.5 +/-4 6-1/8" Production Hole (6905' to 13,599' MD) Interval Density (PPg) Entire Interval 9.6 - 9.7 ILSND Funnel YP Viscosity 35-50 15-20 LSR YP 8-10 pH 8.5 -9.0 RECE APl FL +/-4 DEC 2 2 2000 Alaska Oil & Gas Cons. Commission Anchorage NK-43 Permit to Drill Logging Program Surface Hole Section Intermediate / Production Section Production Hole Section Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD Open Hole: None Cased Hole: None / GR ! Resistivity / Neutron / Density Drilling: MWD Open Hole: None Cased Hole: None / GR / Resistivity / Neutron / Density Cement Calculations The following cement calculations are based upon a two stage job using a stage tool. If a port collar is run rather than a stage tool, circulating cement to surface will be attempted using a single stage job. Cement volumes under this scenario will be as follows: Lead - as noted for both 1st and 2nd stage. Tail - as noted below for 1st stage. Casin~l Size I 10-3/4" Surface - 1sT Stage I Basis: Lead: Based on 4025' of open hole from top of tail slurry to stage collar + 30% excess. Lead TOC: At -2100' MD (1956' TVD), planned set depth of stage tool. Tail: Based on 780' MD (-500' TVD) open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -6125' MD (4556' TVD). ITotal Cement Volume: Lead I 339 bbl / 1904 ft~ / 429 sks of Dowell ARTICSET Lite 3 at 10.7 I ppg and 4.44 cf/sk. Tail 74 bbl / 416 ft~ / 358 sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk. Casing Size I 10-3/4" Surface - 2n~ Stage Basis: Lead: Based on 2100' of open hole from stage collar to surface. 1966' across permafrost w/ 350% excess + 134' below permafrost w/30% excess + 9-5/8" casing capacity from surface to stage tool. Lead TOC: At surface. Tail: None Tail TOC: N/A Total Cement Volume: Lead Tail 787 bbl / 4419 ft~ / 995 sks of Dowell ARTICSET Lite 3 at 10.7 ppg and 4.44 cf/sk. None Casin9 Size I 7" Intermediate / Production I Basis: Lead: None Tail: Based on 82' shoe track volume and 1520' of open hole (to 1000' MD above top Kuparuk formation) with 50% excess. Tail TOC: At -12,085' MD (8462' TVD). Total Cement Volume: Lead I None Tail I 111 bbl / 623 ft~ / 533 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 cf/sk. RECEIVED DEC 2 2 2000 Alaska 0il & Gas Cons. Commission Anchorage NK-43 Permit to Drill Casin9 Size I 4-1/2" Production Liner I Basis: Tail: Based on 364' of open hole with 50% excess, 265' of 7" x 4.5" liner lap, 200' of 7" x 4" drill pipe annulus volume, and 82' of 4-1/2" shoe joint. Tail TOC: At top of liner -13,340' MD (9548' TVD). Total Cement Volume: I Tail I 20 bbl / 112 ft~ / 96 sks of Dowell Premium 'G' at 15.8 ppg I I and 1.17 cf/sk. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 5000 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate/Production Section- . Maximum anticipated BHP: 3750 psi @ 9275' TVDss - Kuparuk · Maximum surface pressure: 2825 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) Maximum anticipated BHP: 4500 psi @ 9720' TVDss - Sag River Maximum surface pressure: 3528 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) Maximum anticipated BHP: 4700 psi @ 9870' TVDss - Ivishak Maximum surface pressure: 3713 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 5000 psi 9.6 ppg Brine / 6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE - H2S Niakuk Pad is not designated as an H2S drill site, however Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Adjacent producers at Surface: NK-18 20 ppm Oct 1, 99 NK-19 Well is Shut-in and will remain shut-in until sidetracked later this year. NK-20 40 ppm July 8, 00 Adjacent producers at TD: NK-20 40 ppm July 8, 00 NK-62 25 ppm Oct 1, 00 The maximum recorded level of H2S on the pad was 60 ppm from NK-28 on iVE DEC 2, 2 2000 Alaska Oil & Gas Cons. Commission Anchorage NK-43 Permit to Drill DRILLING CLOSE APPROACH: All offset wells pass close approach guidelines, however it is critical to address and understand all close approach issues prior to beginning operations. There are several close approach wells both shallow and deep that could become an issue if the well path deviates to far from the plan. Gyro single shots will be required in the surface hole to -1500' MD for magnetic interference from offset wells. SURFACE HOLE SECTION: · High doglegs at the base of the permafrost have been typical and have caused problems while running casing. There is a natural tendency to build rapidly at the base permafrost. Rotate through the base for +/-100' and then commence directional work at that point. · Minor tight hole has been encountered in the clay sections below the permafrost. · Differential sticking could be problematic in this hole section adjacent to the permeable SV Sands. Avoid leaving drill string stationary for extended periods, tighten fluid loss properties of mud, and string in Barofibre prior to penetrating sand intervals. · Lost circulation has not been a problem while drilling in the surface section, however losses have occurred while running and cementing surface casing. Be sure to condition and thin mud appropriately prior to pulling out of the hole to run casing, and once on bottom with casing, bring circulation up slowly and reduce mud viscosities before pumping cement. INTERMEDIATE ! PRODUCTION SECTION: · Gas cut mud has been observed in the Ugnu and West Sak sands. This will be controlled with appropriate mud weights. A minimum of 9.2 ppg is recommended in the West Sak. · The NK-43 well path will drill full sections of the Tuffs, HRZ, and Kingak shales. Each of these formations have been troublesome in the Niakuk area and have shown severe hole instability problems. Follow all shale drilling practices to limit high ECD's. We will also be using increased mud weights and shale stabilizers in the drilling fluid. · The Kuparuk reservoir is expected to be under-pressured at the NK-43 bottom hole location. Because of the high mud weights required to drill the surrounding shale intervals, losses and differential sticking could be a problem. To be prepared for any potential lost circulation, a copy of the 'Recommended Lost Circulation Procedures' and the 'Lost Circulation Decision Tree' will be sent to the rig prior to drilling out in the 9-7/8" production interval. · Differential sticking will be a problem if the drill string or casing is left stationary for an extended period of time across the permeable Ugnu, West Sak, or Kuparuk Sands. · The kick tolerance for the 9-7/8" open hole section would be 240 bbls assuming an influx from the Sag River interval at -13,600' MD. This is a worst case scenario based on a 9.2 ppg pore pressure gradient, a fracture gradient of 12.5 ppg at the 9-5/8" shoe, and 10.3 ppg mud in the hole. · The kick tolerance for the 7" shoe would be an infinite influx (annular volume) assuming an influx at section TD of 13,968'. This is a worst case scenario based on a 9.4 ppg pore pressure, a minimum fracture gradient of 12.0 ppg at the 7" casing shoe, and 9.7 ppg mud in the hole. Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. RECEIVED DEC 2, 2 Alaska Oil & Gas Cons. Commission Anchorage NK-43 Permit to Drill DRILL & COMPLETE SUMMARY Pre-Riq Work: 1. Set 20" conductor and weld an FMC landing ring for the FMC Wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Ri.q Operations: 1. MIRU Doyon 14. 2. Nipple up and function test 21-1/4" diverter system. PU 5" DP as required and stand back in derrick. 3. MU 13-1/2" drilling assembly with MWD/GR and directionally drill surface hole to approximately 6905' MD / 5057' TVD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sands. 4. Run and cement the 10-3/4", 45.5# surface casing back to surface. A port collar or stage tool will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 5. ND diverter system and NU casing / tubing head. NU BOPE and test to 5000 psi. 6. MU 9-7/8" drilling assembly with MWD/GR/Res/Neu/Den and RIH to float collar. Test the 10-3/4" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 10-3/4" shoe and perform Leak Off Test. 8. Continue to drill ahead to 7" casing point at top Sag River formation (13,605' MD / 9778' TVD). Short trip and condition hole for running the 7" casing. POOH laying down the 5" DP. 9. Run and cement the 7", 26# production casing, bringing cement -1000' MD above the Kuparuk interval. Displace the 7" casing with drilling mud during cementing operations and freeze protect the 7"x 9-5/8" annulus as required. 10. Make up and RIH with 6-1/8" directional assembly (MWD/GR/Res/Neu/Den) to the landing collar on 4" DP. 11. Test the 7" casing to 3500 psi for 30 minutes. 12. Drill the 6-1/8" production section as per directional plan to an estimated TD of 13,969' MD / 10,093' TVD. 13. Run and cement a 4 Y2", 12.6# solid production liner throughout the 6-1/8" wellbore. Displace well to clean 9.6 ppg brine above liner top. POOH LD DP. 14. Test the 4-1/2" and 7" casing from the 4-1/2" landing collar to surface to 3500 psi for 30 minutes. 15. Run 4-1/2", 12.6# L-80 IBT-Mod completion as per completion diagram. 16. Set packer and test the tubing to 3500 psi and annulus to 3000 psi for 30 minutes. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 18. Freeze protect the well to -2200' and secure the well. 19. Rig down and move off. Post-Riq Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from 'X' nipple below the new production packer. 2. RU E-line and perforate desired intervals with E-line conveyed guns. Estimated Pre-rig Start Date: 12/22/00 Estimated Spud Date: 01/07/01 William Isaacson Operations Drilling Engineer 564-5521 RECEIVED 2, 2, Z000 Alaska Oit & Gas Cons. Corr~ssion Anchorage NK-43 Proposed Well Profile - Geodetic Report Schlumberger Report Date: December 19, 2000 Client: Alaska Ddlling & Wells Field: Niakuk Structure I Slot: Main Pad / NK-43 Well: NK-43 Borehole: NK-43 UWIIAP~: Proposal Name I Modified Date: NK-43 (PS) / December 19, 2000 Tort / AHD I DDI I ERD ratio: 70.154° / 9040.40 fl / 5.943 / 0.896 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Lat/Long: N 70 20 51.282, W 14811 58.618 Location Grid NIE Y/X: N 5979982.900 flUS, E 721757.370 flUS Grid Convergence Angle: +1.69557501 ° Grid Scale Factor: 0.99995586 Survey/DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Minimum Curvature / Lubinski 43.380° N 0.000 fl, E 0.000 fl KB 52.9 ft relative to Mean Sea Level Magnetic Declination: 27.107° Total Field Strength: 57505.186 nT Magnetic Dip: 80.870" Declination Date: December 19, 2000 Magnetic Declination Model: BGGM 2000 North Reference: True Nodh Total Corr Mag North .> True North: +27.107° Coordinate Reference To: Well Head Grid Coordinates Geographic Coordinates I"l I°) I°~ I") I"l I") I"t t°t'~°°"l I"ust I"us) ............. KBE 0.00 0.00 43.38 0.00 0.00 0.00 0.00 0.00 5979982.90 721757.37 N 70 20 51.282 W 148 11 58.618 KOP Bid 1/100 400.00 0.00 43.38 400.00 0.00 0.00 0.00 0.00 5979982.90 721757.37 N 70 20 51.282 W 148 11 58.618 500.00 1.00 43.38 499.99 0.87 0.63 0.60 1.00 5979983.55 721757.95 N 70 20 51.288 W 148 11 58.601 Bid 2/100 600.00 2.00 43.38 599.96 3.49 2.54 2.40 1.00 5979985.51 721759.69 N 70 20 51.307 W 148 11 58.548 700.00 4.00 43.38 699.82 8.72 6.34 5.99 2.00 5979989.41 721763.17 N 70 20 51.345 W 148 11 58.443 Bid 3/100 < 800.00 6.00 43.38 799.43 17.44 12.67 11.98 2.00 5979995.92 721768.97 900.00 9.00 43.38 898.56 30.49 22.16 20.94 3.00 5980005.67 721777.64 1000.00 12.00 43.38 996.88 48.71 35.40 33.46 3.00 5980019.27 721789.77 1100.00 15.00 43.38 1094.10 72.05 52.37 49.49 3.00 5980036.71 721805.29 1200.00 18.00 43.38 1189.98 100.45 73.01 68.99 3.00 5980057.92 721824.17 1300.00 21.00 43.38 1284.23 133.83 97.27 91.92 3.00 5980082.84 721846.37 1400.00 24.00 43.38 1376.61 172.09 125.08 118.20 3.00 5980111.42 721871.81 1500.00 27.00 43.38 1466.86 215.14 156.37 147.76 3.00 5980143.57 721900.43 1600.00 30.00 43.38 1554.73 262.85 191.04 180.53 3.00 5980179.19 721932.16 1700.00 33.00 43.38 1639.98 315.09 229.01 216.42 3.00 5980218.20 721966.91 1800.00 36.00 43.38 1722.38 371.73 270.18 255.31 3.00 5980260.50 722004.56 N 70 20 51.407 W148 11 58.268 N 70 20 51.500 W148 11 58.006 N 70 20 51.630 W148 11 57.640 N 70 20 51.797 W148 11 57.172 N 70 20 52.000 W148 11 56.602 N 70 20 52.239 W 148 11 55.932 N 702052.512 W148 11 55.164 N 702052.820 W148 11 54.300 N 702053.161 W148 11 53.343 N 70 20 53.535 W 148 11 52.294 N 702053.939 W148 11 51.158 NK-43 (P5) report.xls Page 1 of 2 12/19/2000-4:09 PM J Station ID End 3/100 Base Permafrost Bid 3/100 1900.00 39.00 43.38 1801.71 432.60 314.42 297.12 1965.87 39.00 43.38 1852.90 474.05 344.55 325.59 2029.05 39.00 43.38 1902.00 513.81 373.44 352.90 2100.00 41.13 43.38 1956.30 559.47 406.63 384.27 J Grid Cojrdinates J DLS Northing Easfing (°.OOft) {~USt ("USI 3.00 5980305.96 722045.04 0.00 5980336.92 722072.61 0.00 5980366.60 722099.05 3.00 5980400.70 722129.42 Geo~lraphic Coordinates Latitude J Longitude N 70 20 54.375 W 148 11 49.936 N 70 20 54.671 W 148 11 49.104 N 7020 54.955 W148 11 48.306 N 70 20 55.281 W 148 11 47.389 End Bid SV3 SV1 10-3/4" Csg Pt Ugnu 4A Colville CM3 Drp 3/100 2200.00 44.13 43.38 2029.87 627.19 455.85 430.77 3.00 5980451.27 722174.44 N 70 2300.00 47.13 43.38 2099.79 698.66 507.80 479.86 3.00 5980504.65 722221.97 N 70 2398.28 50.08 43.38 2164.77 772.38 561.38 530.49 3.00 5980559.70 722270.99 N 70 5761.11 50.08 43.38 4322.90 3351.36 2435.95 2301.68 0.00 5982485.77 723985.86 N 70 6749.02 50.08 43.38 4956.90 4108.99 2986.64 2822.01 0.00 5983051.59 724489.65 N 70 20 55,765 W148 11 46,030 20 56.276 W148 1144.595 20 56,803 W148 11 43,116 21 15.236 W148 10 51,340 21 20,650 W148 10 36,124 6904.84 50.08 43.38 5056.90 4228.49 3073.50 2904.08 0.00 5983140.84 724569.11 N 70 21 21,504 W148 10 33,724 7443.99 50.08 43.38 5402.90 4641.96 3374.04 3188.05 0.00 5983449.63 724844.05 N 70 21 24,459 W148 10 25,419 10451.34 50.08 43.38 7332.90 6948.32 5050.45 4772.02 0.00 5985172.10 726377.65 N 70 21 40.938 W148 9 39,083 11416.22 50.08 43.38 7952.12 7688.30 5588.31 5280.22 0.00 5985724.73 726869.69 N 70 21 46.224 W148 9 24,211 11500.00 47.56 43.38 8007.28 7751.34 5634.14 5323.52 3.00 5985771.82 726911.61 N 70 21 46,675 W148 9 22,944 11600.00 44.56 43.38 8076.66 7823.35 5686.47 5372.97 3.00 5985825.59 726959.49 N 70 21 47.189 W148 9 21.497 11700.00 41.56 43.38 8149.71 7891.62 5736.10 5419.86 3.00 5985876.59 727004.89 N 70 21 47.677 W148 9 20.125 11800.00 38.56 43.38 8226.23 7955.98 5782.88 5464.06 3.00 5985924.65 727047.68 N 70 21 48.136 W148 9 18.831 11900.00 35.56 43.38 8306.02 8016.24 5826.68 5505.45 3.00 5985969.65 727087.76 N 70 21 48.567 W148 9 17.620 12000.00 32.56 43.38 8388.85 8072.25 5867.38 5543.91 3.00 5986011.47 727124.99 N 70 21 48.967 W148 9 16.495 End Drp 12085.45 30.00 43.38 8461.87 8116.61 5899.63 5574.39 3.00 5986044.61 727154.51 N 70 21 49,284 W148 9 15.602 Tuffs 12161.69 30.00 43.38 8527.90 8154.73 5927.34 5600.57 0.00 5966073.08 727179.85 N 70 21 49,556 W148 9 14,836 Top HRZ 12785.23 30,00 43.38 9067.90 8466.50 6153.93 5814.70 0.00 5986305.90 727387.18 N 70 21 51,783 W146 9 8,569 Top Kuparuk 13085.45 30.00 43.38 9327.90 8616.61 6263.04 5917.80 0.00 5986418.00 727487.00 N 70 21 52.855 W148 9 5.551 Target 13085.45 30.00 43.38 9327.90 8616.61 6263.04 5917.80 0.00 5986418.00 727487.00 N 70 21 52.855 W148 9 5,551 Top Kingak 13243.65 30.00 43.38 9464.90 8695.71 6320.53 5972.13 0.00 5986477.07 727539.60 N 70 21 53,420 W148 9 3.961 Top Sag River 13599.30 30.00 43.38 9772.90 8873.53 6449.77 6094.26 0.00 5986609.86 727657.85 N 70 21 54,690 W148 9 0,386 7" Csg Pt 13605.07 30,00 43.38 9777.90 8876.42 6451.87 6096.25 0.00 5986612.02 727659.77 N 70 21 54.711 W148 9 0,328 Ivishak 13772.50 30.00 43.38 9922.90 8960.14 6512.71 6153.75 0.00 5986674.53 727715.45 N 70 21 55,309 W148 8 58,645 4-1~"Lnr Pt 13968.80 30.00 43.38 10092.90 9058.29 6584.05 6221.16 0.00 5986747.83 727780.71 N 70 21 56.010 W148 8 56,672 TD 13968.80 30.00 43.38 10092.90 9058.29 6584.05 6221.16 0.00 5986747.83 727780.71 N 70 21 56,010 W148 8 56,672 Le.qal Description: Surface: 1441 FSL 802 FEL S36 T12N R15E UM Target: 2422 FSL 5015 FEL S29 T12N R16E UM BHL: 2743 FSL 4710 FEL S29 T12N R16E UM No~hinR(Y)[ffUS] Eastin~(X) 5979982.90 721757.37 5986418.00 727487.00 5986747.83 727780.71 [ftUSl RECEIVED DEC 2 2 Z000 NK-43 (P5) report.xls Page 2 of 2 Alaska Oil & Gas Cons. Commission Anchorage 12/19~2000-4:09 PM lib VERTICAL SECTION VIEW Client: Alaska Drilling & Wells Well: NK-43 (P5) Field: Niakuk Structure: Main Pad Section At: 43.38 de~ Date: December 19, 2000 Schlumberger -2000- o c 400( v O r'h ~ 6000 ~ .. F- > 8000 10000 12000 KOP Bid ~100400 MD 400TVD ...- 0,00" 43.;~8° az 0 departure Bid 2/~00 600 MD 600 TVD ~43,38° az 3 departure BIll 31100 800 MD 799 TVD 6,00° 43,38° az 17 departure ~ .End 31100 1900 MD 1802 TVE .- ...... ]"' 39,00° 43,38° az 433 departu¢9 .... [ Bid 31100 2029 MD 1902 TVD ..... ~'" '39,00"' 43:38°'az 5~4 depar ~re ................................................................................................ End Bid 2398 MD 21~ 5 TVD 50.08" 43.38' az 772 )arture ~old Angle 50.08°i Pt // 6905 MD 5057 TVD ..'? / 4228 departul'e Drp 31100 11416 MD 7952 TVD 50.08 43,38° az i/ 7688 departure X End Drp ~blv'ii~ C~i':~ l'd~.5 "~D '"~;.%"~"i"v'~' ...................................................................... i ....................... /'~ .................. 12085 MD 8462 TVD i ! / i / 30 00° 43 38" az I'"' ..... !~..r,~.~--2,.~r~--~.~...~, ..... ! ................................................................................................... ~-A ................ ~-.~o.oo~ ~.~,~ I"' ...... ~",, ~:~'~z'"~' '~'~ M:~"~ ~ f ................................... ~ ...................................................................... ¢ ..... ¥ ~ ........... _ _ _. r ....... ~%~'~,~(~ '~'~'~"~c~"~*~'*~rv~ ............................................................................................ ~/~ ~'.~ ......... ~,'~,~' ~'~ ~,~'"~ .................................... i ................................... : ................................ ;; ...... ~"~"" ~oooo ~ ~8. az ......... [ ................................... ~ ............................................. ] .................... 8876 depa~ure ~'1'o ) S~g R,ver '135gS~ MO 9773 'I'~D :, ~ ............ ! ....... ~'" .... ~ HoJd Angle 30.00° 30.00" 43.38' az 9058 depa~ure I I 0 2000 4000 ~000 8000 Vedical Section Depa~ure at 43.38 de~ from (0.0, 0.0). (~ in = 2000 feet) PLAN VIEW Client: Alaska Drilling & Wells Well: NK-43 (P5) Field: Niakuk Structure: Main Pad Scale: 1 in = 2000 ft Date: 19-Dec-2000 Schlumberger A A A 0 Z v v v 0 2000 4000 6000 8000 I I I I I I 10000 ......... I True North Mag Dec ( E 27.11 10000 8000 ...................................................................................................................................................................................................................................................................................................................................................................... 8000 20O0 -2000 7" Csg Pt TD 14-112" Lnr Pt 13605 MD 9778 TVD 13969 MD 10093 TVD :30,00" 43.38" az 30,00" 43.38" az 6452 N 6096 E 6584 N 6221 E -4000- End Drp : 12085 MD 8462 TVD 5900 N 5574 E End Bid 2398 MD 2165 TVD 50.08" 43.38" az 561 N 530 E BIll 311002029 MD 1902 TVD Drp 31100 11416 MD "Z~'~b" 50.08" 43,38" ~z 5588 N 5280 E Target 13085 MD 9328 TVD 30.00" 43.38" az 6263N 5918E 10-314" Csg Pt 50.08° 43.38" az 3074 N 2904 E 6000 400O 2000 ~-, 39i00° 43.38" az 373 N 353 E ~ ~ End 31100 1900 MD 1802 TVD 39.00° 43.38" az 314 N 297 E "~ Bid 31100 800 MD 799 TVD ' x,, 6.00" 43,38° a~ 13 N 12 E KOP Bid 11100400 MD 400 TMD Bid 21100 600 MD ~00 TVD ~ 0.00° 43.38° az 0 N 0 E 2.00° 43.38" az 3 ? 2 E 2000 I I i 0 2000 4000 6000 800( <<< W ST ^sT RECEIVED DEC 2 2 ZOO0 Alaska Oil & Gas Cons. Commission Anchorage TREE: 4-1/16" - 5M CIW LoS0 WELLHEAD: 13 5/8" - 5M FMC SH NK-43 Proposed Completion Cellar Elevation = 19.5' Doyon 14 RKB: 53.0' 4-1/2" Halliburton 'HXO' Hydraulic Landing Nipple with 3.813" seal bore ID. Requires two control lines to surface. 10-3/4", 45.5 #/ft, L-80, BTC 4-1/2" x 1" Camco 'KBG-2' Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS ..... '~ .... -[ MD Size Valve Type 1 ! TBD 1" RPShear 2 / TBD 1" DV 3 ! TBD 1" DV 4 ! TBD 1" DV 5 I TBD 1" DV 6 ! TBD 1" DV 4-1/2" 12.6# L-80, IBT-Mod Tubing 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. 4-1/2" WireLine Entry Guide spaced-out to -12,935' (150' above the Top Kuparuk). 7", 26 #/ft, L-80, BTC-Mod 13,605' 3,340' I BAKER 5" x 7" Liner Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger RECEIVED Plug Back Depth 4-1/2" 12.6 #/ft, L-80, IBT-Mod DEC 2, 2, 2000 13~885'I Alaska Oil & Gas Cons. Commission 13'969'1 Anchorage Date 12/21/00 Rev By Comments WSI Proposed Completion NIAKUK WELL: NK-43 APl NO' 50-029-????? BP Alaska Drilling & Wells De~-Z1-2000 13:04 From-MCC WING,,.R +907-$$9-§0!' T-987 P.OOZ/OOZ F-422 '~ SuRlY. E < T.12N, 35 , VlClN! T_Y blAPI NK-&~ t i~ N.T.S. ~11 · 27 DEC 2 2 2000 Al~a ~1 & Gas C~s. Co~ission ~ A~mge 1, DATE OF SURveY: DgG~MBER 21, 2000. 2, REFERENCE FIE~D BOOK', 3. ALASKA STATE PLANE CQORDINAT~$ NIAKUN PAD ~. ~,o~,~ coo,~,.~,s ~,~ ~; ~,~. LOCATED WITHIN PROTRACTED SECTION 36, T. 12 N,, R, 15 E,, UMIAT M~RIDIAN, ALASKA WELL A,S,P, PLANT F GEODETIC GEODETIC - -~ROUND SECTION-~ NO, COORDINATES .COORDINATES FOSITION(OMS) POSITION(D.DD) ELEVATION OFFSETS Y:5,979,982,63 ' N=- 5~17.00 70'20'51,280" ' - 70. 3&75778' ~ ~4~" FSL 4~ X= 721.757.0~ E= &918,00 1~8'11'58.628" 1~8.1996189' 19.~' '802' FEL ,. ~ PAT~: ~2/2~/~0 FtLE NA~E: ~EV: SHEET: , ~22.? ~.'[%~.~.~. ,X?,RK PK O;_ · . J MOD:___ /..., 1 WELL A,S.P. PLANT GEODETIC GEODETIC -aROUND SECTION-- NO, COORDtNATES COORDfNATES PO$1TION(OMS) POSITION(D.DD) ELEVATION OFFSETS y=5,979,982,65 N=- 54-17.00 70'20'51,280" -70.3475778' 19.4,' 1,4,4,~"FSL 4.5 X,.- 721.757.04, E= 4-918,00 14-8"11'58.628" 14-8,1996189' 802' FEL DZVERTER PzpE 0 18 32 $O.~d.E IN FEET II [~oxc~ RIG 14 jnnz LEVEL 1 I GENERAL ARRANGEMENT o~/o,/~ .. I ~ ~ o II RECEIVED AOCU~ULA'I'BR: IlL StrAFe(T, I~4) ~ $ STATION TRIPLEX PU~P; 5-/5 YAC, 3D HP A1FT Pl~'k,r'P: 1, ~L StGqFT'DR ACCUI,~dL~TOR N~,~IIFOLD t:~ BDT11.~. 10 CAULONS EA/'~ .Tfl"I~O~:-'TI I~ACKUP BOil!.E:S 4 DDliLES, 220 cu. iT. ANO I,.nlIJTY ~D_Dt.,1LE DEC g g 2000 Alaska Oil & Gas Cons. Commission Anchorage VEN~R ALASKASTAT 10 DATE INVOICE ! CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET ._ · 13000 CK1130000 100. OO 100. O0 PYMT (;OMMENTS: Perftit to drill t-~ee HANDL]'NO INST: S/H - Ter~'ie X4~28 , AIl'ACHED CHECK IS IN PAYMENT FOR i-I~MS DESCRibED ABOVE. ml[lllF_'l~ --m 1 OO. OO 1 OO. OO :':': Bp EXpLoRATION (ALASKA),.:,INC, ...... !':' ~.O...'[~OX" 1'96612 :?::::::?: :..:..AN~HO'~,G:E;=[A~S~ i~. 99519-6612 ?.!':!:::.i!:~ :" '''/ · :. :FIB. ST N'.ATIq~AI~,:BANI~ :~F ASH.,L:',AND .......... ,]'.ii >, :'i: ::A~!A .,I~..LIATE::C~F~ ':!:!ii:'] .:' >j .' ., '..:.':'. .... ;:':;i :: .::' NATIQN/~.~ITY;.~ANK "' ':.: .'."~ :' :~; ' ." .?:.' :::..:.~:: ..:: .; 'O~VE~ND, 0HtO .".: ". :'.. :.." ,;~:, .,:.: ~;¥:?::~':" ..... :: ! ..... ':'.. ;~:::.[:::~:389" ~;["~:; ":[ '" 412 ~AY 12/01/00 :.....,.: ,: :,..,.., · :, AK 99501 I1' m, 7q m. 8 re. IIm m'-Oh & E~O Ei,q,q 5m~- OI]P,L,m., ~.qllm COMPANY WELL PERMIT CHECKLIST FIELD & POOL ,5 ,/_/t~/t/~ INIT' (~I~ASS ~:>~" /*d)/~ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropdate~.. '.5:f-~...~.V.,J., '..~.~,,,.././.~: yq ~. 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling 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 canbe issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... APPR DATE ENGINEERING WELL NAME ~/~/~"- '~/..~ PROGRAM: exp dev '/redrll se~ wellbore seg ann. disposal para req GEOLAR~ ~?~ UNIT~ ~//~D ON/OFF SHORE ~ N N APPR DATE l' to t 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 require~, does it meet regulations .......... 24. Drilling fluid progr,~m schematic & equiP list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~{~-.- 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 ................. N GEOLOGY . 30. 31. 32. APPR DATE 33. ~ l'"J / . Z . t.> t 34. ~NNULAR DISPOSAL35. APPR DATE (A) will contain waste in a suitable receiving zonei ....... Permit can be issued w/o hydrogen sulfide measures ..... ~.y._~') ,/'~/'~g-'~-/-./,~'-ro,,=:/c, tc~r-~ ,'(~:,'~ ~$*',~' .~ & 5'z°.,,~,../~,,.~.~ ,,9/z..~. ,,~. Data presented on potential overpressure zones . . . .... ~ ~ '- ' ~. ' ~':" ' ' "-- Seismic analysis of shallow gas zones ............. ~ ~ .~,~/5 ~e~./..,.- ,<rio ~ ....~-r~. . ,~,~: ...~_~./-,C~,~ ~/ ~,~ ~ ~ ~.z ~ ~---,,'~.(..,f S:~.~,u.~. / ' Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [explora~f~ only] Y N With proper cementing records, this plan 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 o(.l 41,u,:s bv~,~ .. GEOLB.~Y: ENGINEERING: UlC/Annular COMMISSION: TEM -~-r~,. A ~, ~1~1Ol Comments/Instructions: 0 Z 0 Z -I -1- c:\msoffice\wordian\diana\checklist (rev. 11/01//00)
