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Home My WebLink About194-140 • • FgiA M4 goo Regg, James B (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, May 2, 2017 2:21 PM ��'l/r7 To: AK, GWO SUPT Well Integrity; AK, OPS GPMA OSM; AK, OPS GPMA Field Og TL; AK, OPS LPC DS Ops Lead;AK, OPS LPC Board Operator;AK, OPS Prod Controllers;AK, OPS EOC Specialists; AK, OPS LPC DS Operator; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Schultz, Kirsten L Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Worthington, Aras J;AKIMS App User; Regg,James B (DOA);Wallace, Chris D(DOA) Subject: OPERABLE: Producer NK-09 (PTD# 1941400) Sustained OA Normal Operating Limit (NOL) Revised to 1,500psi All, Producer NK-09 (PTD# 1941400) now has a revised OA Normal Operating Limit(NOL, formerly MOASP) of 1500 psi. The NOL revision is via eMoC 10221. An engineering design review of the well and wellhead system was completed and approved. A sign indicating the revised NOL has been installed. With the NOL revision this well now meets BP operability criteria and can continue to operate as Operable. Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering `J(11 Office 907-659-8110 2QF. Cell 907-980-0552 Harmony 4530 RECEIVED STATE OF ALASKA ((11 ALASKA OIL AND GAS CONSERVATION COMfv, JN 1�J� 2015 1 Z REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed / p Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations skioC Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ ,.- Plug for Rednll 0 Perforate New Pool ElRepair Well ElRe-enterSusp Well 0 Other Jam{1/roP , 2. Operator Name. BP Exploration(Alaska),Inc 4. Well Class Before Work 5 Permit to Drill Number: 194-140 3 Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number 50-029-22518-00-00 7. Property Designation(Lease Number): ADL 0034625 8. Well Name and Number: NIA NK-09 9 Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY.NIAKUK OIL 11.Present Well Condition Summary: Total Depth. measured 18570 feet Plugs measured 18148 feet true vertical 9340 feet Junk measured 18470 feet Effective Depth: measured 18148 feet Packer measured See Attachment feet true vertical 9137 feet Packer true vertical See Attachment feet Casing: Length: Size: MD• TVD: Burst: Collapse. Structural Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth Measured depth: 18008-18064 feet 18078-18148 feet 18162-18306 feet 9105-9137 feet 9143-9210 feet True vertical depth: 9074-9099 feet 4-1/2"12.6#L-80 17759-17924 8971 -9038 Tubing(size,grade,measured and true vertical depth) Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"HES CP-2 10 TRSV 2230 2228 12.Stimulation or cement squeeze summary. Intervals treated(measured): SCANNED .,LiL i 1 i(I 15 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 220 228 5209 2200 580 Subsequent to operation: 333 700 4066 1905 572 14.Attachments'(required per 20 AAC 25 070 25 071,&25 283) 15 Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development m Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Il Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Summerhays,Nita M(WIPR!Technologies) Email Nita.Summerhays@bp corn Printed Name Sumrrierhays,N'�J��( , RO Technologies) Title Petrotechnical Data Manager Signatu .�//�7��J//�i� / Phone +1 907 564-4035 Date 06/30/2015 Form 10 404 Revised 5/2015 _ RBDMS in JUL - 1 1015 T ��q/�S Submit Origin I Only Daily Report of Well Operations ADL0034625 ACTIVITYDATE SUMMARY CTU#9 1.75" Coil Objective: Mill/Under ream, Set IBP MIRU, MU milling tools 5/28/2015 ***Continued on WSR 05/29/15*** CTU#9 1.75" Coil Objective: Mill/Under ream, Set IBP RIH w/BOT 3.71"Opti cut parabolic mill. Milled scale from 17,657'to target depth of 18,350'. Avg ROP of 30 fpm. POOH. MU BOT Underreamer for 5"liner. RIH and under ream from 17,950'to 18,350' pumping gel sweeps. No stalls were encountered during milling or UR operations. Dropped 5/8"ball to open circ sub and chase 20 bbl gel pill out of hole at 80%. 5/29/2015 ***Continued on WSR 05-30-15*** CTU#9 1.75"Coil Objective: Mill/Under ream, Set IBP POOH and chased gel pill out of hole at 80%. Inspected UR blades and had some wear on the leading edge. Cut 50' of pipe for chrome management. MU BOT CTC connector and pull test. Weight cell was not responding correctly with hydraulic pressure, stop to trouble shoot. Perform 7 day BOP test. MU PDS GR/CCL logging tools in 2.20"carrier&3.70"JSN and RIH. Log at 40 fpm from 18,350'to 17,600'. Paint yellow flag at 18,200'. POOH 5/30/2015 ***COntinued on WSR 05-31-15*** 5/31/2015 IBP Mid Element 18,200.34'. Top of plug at 18,148' ELMD. CTU#9 1.75"Coil Objective: Mill/Under ream, Set IBP POOH with PDS logging tools. Tie-in to PPROF w/DEFT 01-JULY-2005, -6'correction. MU BOT 3-3/8" IBP and RIH. RIH to flag at 18,204'CTMD, Correct to IBP Mid Element 18,200.34'. PUH to 18,151.6'and start inflate procedure, shear off plug 2.5 hrs later at 2,600psi CT pressure. Pick up clean start POOH, FP well with 38 bbls of 50/50. Top of plug at 18,148' ELMD. 5/31/2015 ***Job Complete*** BBLS Fluids Summary 54 50/50 METH 504 SLICK 1% KCL W/SAFELUBE 333 SLICK 1% KCL 40 POWERVIS 931 Total m a a O O O O O !d N N CO (O N O N . N O L0 0 4i M N O- ON (O M • to 0 CO CO r CO 111COCOCOCO co N M N M CO M CO CO O M r r CO CO r O r MI� 0) 0) M r r CO r CO CO N N M M CO 0) M I` CO 41) co co co O N 0 co0) Tr M r r r ✓ 0 • N Q CD co CD 0) COrCON co h. C O M r r ▪ 0 3 J w ▪ Q v (O ) co co co co 0 • w ZZ ~ it N NZ # # Z (N V � COaoNN N 0D lf Ln I. M O a7 4 Ch t r CYD O CO 0) CD N LU C CO M Co) N O J d M 0 r w w Q Q co O No , ww U• o u_ CL a c Z 0Z � UCOZzJH Packers and SSV's Attachment ADL0034625 SW Name Type MD ND Depscription NK-09 SSSV 2229.84 2227.72 4-1/2" HES CP-2 10 TRSV NK-09 PACKER 13857.43 7823.51 7" Baker H Packer NK-09 PACKER 17837.41 9002.2 4-1/2" Baker SABL-3 Packer NK-09 PACKER 17920.79 9036.78 5" Baker ZXP Top Packer WELL REQUIRES A SSSV.""5" D= 13-5/8"5M BC GE iC N K_0 9 ALE LM &41 WELL ANGLE>70°/2 CHROME TOG&NPPL6S"' 7717. KB ELEV= 60 z !! BF.E 2500' ,,r I • i 2217 H4-1/2"WELLSTARTRSV NP(9-CR),D=3.813' 1 Max Angle= 76"(4 10160' 'I Datum MD= 18409 P. 3370' H9-5/8'.1- S ES CEMENTER ontumTVD= — 9200'SS iv 3393' H9-5/8"BKR ECP 9-5/8"CSG,47#,L-80 HY DRL 563,D=8.681" --I 3418' ,� GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 9-5/8"BOWE N CSG PATCH H 3418' 5 3577 3489 34 MMIG DOME RK 16 09/26/09 k 4 6225 5403 45 MMG DOME RK 16 09/26/09 13-3/8"CSG,68#,NT-80 CY HE,D=12.415" —I 4426' 3 7634 6228 68 MNG SO RK 32 09/26/09 2 10861 7046 75 MNG DAY RK 0 09/18/09 Minimum ID =3.725" @ 17912' 1 13754 7797 75 MNG DMY RK 0 09118/09 4-1/2" HES XN NIPPLE 13849' � _--ITACK SLV w/6'EXTENSION,D=7.50" TOP OF 7"LNR —I 13849' 13857' H 9-5/8"X 7"BKR TY FE"M LIP,D=6.313" 9-5/8"CSG,47#,NT-80 NSCC,D=8.681" — 14009' • 13863' H9-5/8"X r BKR FLEX LOCK HGR,D=6.188' 1 17640' —4-1/2 HES X NP(9-CR),D=3.813" Z el 17671' —17 X 4-1/2"BKR S-3 PKR,D=3.875' 4-1/2"TT3G,12.64,13CR-85 VAM TOP, — 17735' ' • 17704' —4-1/2'HES X NP(9-CR),D=3.813" .0152 bpf,D=3.958" 17750' —17'X 4-1/2"UNIQUE OVERSHOT TBG STUB(09/17109) —I 17746' ' 17816' H4-112"HES X NP,D=3.813' z 17837' —7"X 4-1/2"BKR S-3 FKR,D=3.875" &KBIT-22 ANCHOR SEAL ASSY ' 17912' ..1—4-1/2"HES XN NP,0=3.725" TOP OF 5"LM —I 17913' 17913' I—7"TEBACK SLV,D=4.438" 4-1/2"TSG 12.64,L-80 NSCT,.0152 bpf,D=3.958" -{ 17924' - 17921' --17"X 5"BKR LTP w/LNR HGR,D=4.434" ' 17924' H4-1/2"1MLEG,D=3.958" 7"LHR,29#,NT-80S NSCC,.0371 bpf,D=6.184" —I 18072 I—A 17931' —I ELND TT LOGGED 03/27/95 18148' I-11 -N6. W. (05/31/15) PERFORATION SUMMARY REF LOG:SWS CDR ON 11/29&12/5/94 ` ANGLE AT TOP PERF:64'@ 18008' 18470' —FISH 4-1/2"FASCRLL Note:Refer to Roduction DB for historical perf data //f ` PLUG(09/15/09) SIZE SPF INTERVAL Opn/Sqz SHOT SQZ // 3-3/8" 6 18008-18064 0 01/01/95 3-3/8" 6 18078-18148 0 01/01/95 3-3/8" 6 18162-18306 C 01/01/95 I Aim. Aviv PBTD — 18485' `ilk, 5"LHR,15#,KO,13CR-80 STL,.0189 bpf,D=4.408" --I 18570' DATE REV BY COL*. TS DATE REV BY COMMENTS MAKUK LINT 01/04/95 POOL 7 ONAL COMPLETION 06/25/15 JLS/JMD SET EP(05/31/15) WELL: NK-09 09/20/09 D16 MVO PERMT No:'1941400 09/24/09 PJC DRLG HO CORRECTIONS AFI No: 50-029-22518-00 10/03/09 BSE/SV GLV C1O(09/26/09) SEC 36,T12N,R15E,1281'ESL&1073'FEL 02/01/10 MLYJMD DRLG DRAFT CORRECTIONS 02/18/11 MBIJMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) • I BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 ,t Post Office Box 196612 Anchorage, Alaska 99519-6612 July 6, 2011 8 al jUL, Mr. Tom Maunder I Q i -() Alaska Oil and Gas Conservation Commission 1 1 1 333 West 7 Avenue OK,09 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 • • 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 PTO # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal NK -01A 1760280 500292015601 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 4/14/98 NA NA NA NA NA NK-05 1850270 500292129000 P&A 4/15/98 NA NA NA NA NA NK-06 1852760 500292148800 P&A 4/15/98 NA NA NA NA NA NK -07A 2010830 500292241001 0.2 NA 0.2 NA 0.9 4/30/2011 C.3 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 600292278901 1.5 NA 1.5 NA 11.9 4/30/2011 NK -12C 2030650 500292241403 1.8 NA 1.8 NA 31.0 4/30/2011 NK -13 1981340 500292289300 2.3 NA 2.3 NA 22.1 5/4/2011 NK -14A 2080310 500292288801 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 1981850 500292270900 3 NA 3 NA 20.4 5/4/2011 NK -18 1931770 500292242100 2 NA 2 NA 17.0 5/8/2011 NK -19A 2010700 500292250701 1.8 NA 1.8 NA 15.3 5/8/2011 NK -20A 2050400 500292242901 2.1 NA 2.1 NA 13.8 5/9/2011 NK -21 1940860 500292248700 2 NA 2 NA 22.1 5/16/2011 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 1970880 500292278000 2.5 NA 2.5 NA 15.3 5/11/2011 NK -28 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 500292287800 Sealed Conductor NA Sealed Conductor NA NA NA NK -29 1951900 500292272400 1.7 NA 1.7 NA 10.2 4/30/2011 NK-38A 2042410 500292254001 3.1 NA 3.1 NA 13.8 6/8/2011 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-81A 2080350 500292289301 14 NA 14 NA 110.5 5/15/2011 NK-62A 2030470 500292285201 1.3 NA 1.3 NA 13.6 5/4/2011 NK-65A 2050830 500292288901 1 NA 1 NA 8.5 5/8/2011 I0 /n8/09 �elifwaberger t_ 13, r { :+� f1 P, 2D09 N0.5410 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Streal, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2839 Ann: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job N Log Description Date BL Color CO MPC -05A 11661124 MEMORY PROD PROFILE 01/25/07 1 1.4 -03 AYIM-00032 PRODUCTION PROFILE 09/09/09 1 L5 -05 AP3O -00061 PRODUCTION PROFILE EX194 I MA q 09/15109 1 03 -24A AZCM -00042 LDL 09/14/09 1 07 -328 BOCV -00027 JEWELRY LOG/GR W/PRESS/TEMP 15/09 1 W -214 AYS4 -00095 INJECTION PROFILE Q 08/12/09 1 04 -26 BSJN-00014 PRODUCTION PROFILE / — 09/25/09 1 07 -21 AYS4 -00098 PRODUCTION PROFILE 09/17/09 1 W -04 88K5 -00003 PRODUCTION PROFILE 09124109 1 P2 -53 AP3O.00060 PRODUCTION PROFILE 09/13/09 1 S43 AWLS -00037 PRODUCTION PROFILE 09125/09 1 12 -23 AWLS -00035 INJECTION PROFILE — 09/19/09 1 05 -38 AYTO -00029 LDL — 09/18/09 1 W -29 AWJI.00050 MEM INJECTION PROFILE 09/20/09 1 W -30 AY1M -00034 BACK W/X -FLOW CHECK — ( 09/12/09 1 3- 37/L -35 03S0 -00024 PRODUCTION PROFILE V 09/16/09 1 NK -09 AP3O.00057 USIT 09/07/09 1 W -07A AWJI -00047 MEM AU AL ATION 09/07/09 1 11 -10 AVTU -00054 USIT 08/28109 1 02 -068 ANHY -00111 USIT 09121/09 1 G-1 8A AWJI -00048 MEM CEMENT BONG LOG 09117/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street. SUR. 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ~ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit'f~Q Drill Number: ~ BP Exploration (Alaska) Inc. ~ Development ^ Exploratory ~' 194-140 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 ~ 50-029-22518-00-00 7. Property Designation'~ ~ ' 8. Well Name and Number. K-09 ~ ADL 034630 & 034625 PBU N 9. Field / Pool(s): ~ Prudhoe Bay Field / Niakuk Pool 10. Present well condition summary ~ Total depth: measured ~ 18570' feet true vertical '~ 9340' feet Plugs (measured) None Effective depth: measured 18484' feet Junk (measured) None true vertical g2g7' feet Casing Length Size MD ND Burst Collapse Structural Conductor 80' 20" 110' 110' 1530 520 Surface 4385' 13-3/8" 4426' 4132' 5020 2270 Intermediate Production 13971' 9-5/8" 14009' 7862' 6870 4760 Liner 4223' 7" 13849' - 18072' 7821' - 9102' 8160 7020 Liner 657' 5" 17913' - 18570' 9033' - 9340' 8290 7250 PerForation Depth: Measured Depth: 18008' - 18306' ~~t~~~~~% l~ ~°! ~`~ 2~~~ True Vertical Depth: 9074' - 9210' Tubing (size, grade, measured and true vertical depth): 4-1/2", 12.6# 13Cr80 / L-80 17924' 9038' Packers and SSSV (type, measured and true vertical depth): 4-1/2" Wellstart TRSSSV; 2217'; 2215'; 7" x 41/2" BKR S-3 packer 9002' 11. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~' `~ ~ ~ ~(~(~~ Treatment description including volumes used and final pressure: ~~~g~~~p~ ~~a~ ~;p~~. ~~mmission 235 B l " ' ' " Cut and putl tubing to ~17775 . Cut, pull and dress .5 s ie ac o 34a~~~~„~nent with b . Run 9-5/8 off 9-5/8 casing to -3415 ° r~e tubing. Class 'G' (Yield 1.16). Dress off tubing stub to 17,745'. Mill plug and cleanout to approximately PBTD. I~un c ro ~ 2, Representative Daily Average Produdion or Injedion Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 73. Attachments: ^ Copies of Logs and Surveys run ~4. Well Class afterwork: ^ Exploratory ~ Development ^ Service ort of Well O erations ~ Dail Re ~ y p p ~ Well Schematic Diagram ~ 5. Well Status after work: ~ Oil ^ Gas ^ WDSP! ^ GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. I hereby ceRiy that the foregoing is true and correct to the best ot my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mackie Derrick, 564-5891 309-264 Printed Name Terrie Hubble Tit1e Drillin Technolo ist ~ '~ ~ Prepared By Name/Nwnber Signature Phone 564-4628 Date Teme Hubble, 564-4628 Form 10-404 Revised'07/2009 ~~{~)~ l,~ ~ ~' / ~/-; • ~ ~~ _~~~g Submit Original Only ~~ ( ~ ( • ~ NK-09, Well History (Pre Rig Workover) Date Summary 8/6/2009 WELL SHUT IN ON ARRIVAL. TAG TRSV WITH 3.84" NO-GO CENTRALIZER C~3 2076' SLM / 2107' MD. RAN FLAPPER CHECKER TO 2076' SLM & CONFIRM TRSV FUNCTIONING PROPERLY. WHILE RUNNING IN HOLE W/ BRUSH & LRS PUMPING HOT CRUDE LOST CONTROL LINE PRESSURE, CONFIRMED NOT BLEEDING BACK TO UNIT. 8/6/2009 T/I/0=1400/920/620 Temp=Sl Assist Slickline, Brush and Flush (RWO prep) Pumped down Tbg with 3 bbl meth spear and 15 bbls 180°F diesel while Slickline brushed. 8/7/2009 Assist Slickline (RWO prep) Pumped 32 bbls diesel down Tbg (47 bbls total) to assist Slickline with brush and flush. Pumped 0.3 bbls diesel down Tbg to assist Slickline in setting lockout device in SSSV nipple. Slickline on well upon LRS departue. IA, OA - OTG, operator notified. FW HP's = 1400/920/620. 8/7/2009 B&F SVLN LOCKOUT PROFILE W/ 3.84" NO-GO, 3'x1.5" STEM, & BRUSH. LOCKED OUT HES TRSV W/ 4-1/2" SERIES 10 LOCKOUT TOOL C«~ 2078' SLM. CONFIRM LOCKOUT W/ 3.84" NO-GO, PRONG, & FLAPPER CHECKER C~ 2076' SLM. WELL TURNED OVER TO DSO. 8/14/2009 T/I/0=1240/920/640. Temp=Sl. TBG & IA FL (pre EL). A/L is disconnected. TBG FL C~ 720' (11 bbls), IA FL C«3 700' (36 bbls). WV, SV = Closed. SSV, MV = Open. IA, OA = OTG. NOVP. 8/15/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O: 1250/900/650 PSI. 8/16/2009 T/I/0-1500/900/640 Assist E-Line (Pre RWO) Loaded Tbg with 7 bbls 60/40, 285 bbls seawater. Freeze protected with 100 bbls crude capped with 5 bbls diesel. E-Line set fast drill plug. E-line had miss -run. Job postponed. RDMO. FWHP=1100/920/640. E-line rigging down upon LRS departure. IA, OA, master, SSV open. Wing & swab closed. 8/16/2009 LRS LOAD AND KIL~ WELL. FiIH WTH 4.5" HALLIBURTON FASDRILL PLUG. BEGIN TRACTORING AT 8168'. PROBLEMS ENCOUNTERED W/ TRACTOR AT 12937'. TRACTOR TROUBLE SHOT DOWNHOLE W/ NO RESULTS. POOH. SHORTED MOTOR QISCOVERED ON SURFACE CALLED OFF WELL DUE TO RIG JOB. FINAL T/I/O: 1100/900/650 PSI. SWAB, SSV = C, A/L = S.I., MASTER = O, CASING OPEN TO GAUGES. JOB INCOMPLETE. 8/17/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/O = 1125/900/650 PSI. RIH WITH TS: HEAD-ERS/PSTE/ 3- MAXTRAC SONDES/WPST/ ATPS/ HAL SHORTY SETTING TOOV HALFASDRILL PLUG. 8/18/2009 HES 4.5" FASDRILL PLUG MID-ELEMENT SET AT 17879'. TOP OF PLUG AT 17878'. OAL = 29.92", MAX OD BEFORE SET = 3.66", SET WITH 30000 LBS OF SHEAR STUDS. LRS MIT TBG TO 3500, JUMPERED TBG & IA TO CMIT TO 3500 PSI. RIH W ITH HEAD-ERS/ TRACTOR CARTRIDGE/ 3 TRACTOR SONDES/ WPST/ 2 WPSA/ ATPS/ 3 SHOCK MANDRELS/ FIRING HEAD/ SLB 3.65" POWER CUTTER. MAX OD 3.65 IN, WEIGHT 460 LBS, 69.4' TOTAL TS LENGTH. SAT DOWN DUE TO DEVIATION AT 8477' _-75.6 DEGREES DEVIATION. INITIALIZE AND BEGIN TRACTORING -1,500'/HR. 8/18/2009 T/I/O= 400/900/640. Assist E-line. MIT-T PASSED to 3500 psi. CMIT TxIA PASSED to 3500 psi. (RWO prep) MIT-T Pumped 4 bbls of crude down TBG to reach test pressure. MIT-T lost 20 psi. in thE first 15 mins, 0 psi in the second 15 mins, for a total of 20 psi in 30 mins. CMIT-TxIA Pumped 59 bbls of crude into IA to reach test pressure. CMIT Tx IA lost 20/0 in the first 15 mins, 0/0 psi in the second 15 mins for a total of 20/0 psi in 30 mins. Bled pressures back. Bled back 23 bbls. E-Line still on well at LRS departure. Final WHP = 500/640/660. 8/19/2009 T/I/O = 500/680/640 Temp = S/I. CMIT-TxIA PASSED to 3500 psi. (Pre RWO). Pressured up TxIA with 21 bbls diesel. TxIA lost 40/40 psi in first 15 min and 20/20 psi in second 15 min for a total loss of 60/60 psi in 30 min test. Bled pressures back, bled aprox 12 bbls diesel. Final WHPs 680/700/640 WV, SV, SSV = Shut MV, IA, OA = Open. Page 1 of 2 ~ L~ ~~ NK-09, Well History (Pre Rig Workover) Date Summary 8/19/2009 CONTINUE TRACTORING TO 17875'. CORRELATE AND CUT TUBING W/ 3.65" SLB POWER CUTTER AT 17775'. FINAL T/ I/ 0=450 / 750 / 600 PSI. WELL LEFT SHUT IN. SWAB, WING, SSV = ; MASTER = O; CASING OPEN TO GAUGES. DSO APPROVED VALVE POSITIONS. JOB COMPLETE. 8/26/2009 T/I/0= 750/700/630, Temp= S/I. Circ Out, (Pre RWO). Pumped 5 bbls neat meth, 1673 bbls seawater, 3 bbl meth spacer and started pumping diesel down TBG, threw jet cut at 17780', taking returns up the IA, threw hardline to NK-07's FL. 8/27/2009 Temp = SI Circ-out, CMIT TxIA to 3500 psi PASSED (RWO prep) Pumped a total of 137 bbls 50° diesel down TBG thru jet cut C~3 17780' taking return up IA thru hard line to FL of well NK-07, U-tube TxIA for 1 hr to put FP in place. CMIT TxIA Pumped 11.9 bbls diesel down TBG to reach test pressure, T/IA lost 0/0 psi in ist 15 min and 0/0 psi in 2nd 15 min for total loss of 0/0 psi in 30 min test, Pumped 3 bbls meth down hardline to well NK-07 for FP. Bleed WHP's, Final WHP's 0/0/380. DHD will bleed OAP as per PE. Valve position C~ departure: Swab, Wing, SSV - SI, Master, IA & OA = Open. 9/1/2009 T/I/O=BPV/0/400, Temp=BPV. PPPOT-T (FAIL), PPPOT-IC (PASS). Eval for RWO (voidage test) PPPOT-T: Stung into test port (2000 psi), bled to 0 psi. DHD on site to pressure IA to 3000 psi. Test void held 0 psi up to 3000 psi. test void (2960 psi) during DHD's 30 min test. Attempted to bled void to 0 psi void would not bleed down (2940 psi) Monitored void while DHD bled IA to 0 psi. test void dropped to 2700 psi. monitored test void for 30 min test lost 0 psi in 15 min, lost 0 psi in second 15 min. held 2700 psi for 30 min. Bled void to 0 psi. PPPOT-IC: Stung into test port (200 psi), bled to 0 psi. Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 9/1/2009 TIO=BPV/vac/410. SI. CMIT-TxIA *"" PASSED"`~" PU from IA while stung into the void and monitor any pressure response in the tree & void. IA FL near surface. No AL line. Pump 12 bbls of diesel down the IA to 3000 psi, tree & void remained unchanged C«~ 0 psi. Test lost 0 psi in the 1 st 15 mins, and 0 psi in the 2nd for a total loss of 0 psi in 30 mins. During the 1 st 15 mins tree remained unchanged and void pressured up to 2960 psi. Bled IAP to 0 psi. OA FL C~ 624' (36 bbls), bled OAP to 110 psi in 2 hrs, FTS. SI bleed monitor for 15 mins. OAP increased 30 psi Final WHPs= BPV/0/140 Unable to continue bleed due to shift change. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 9/3/2009 T/I/0= 0/0/60Temp= S/I. Load OA (Pre RWO). Pumped 53 bbls crude down OA, pressured up to 500 psi. DHD bled OAP off. FWHP= 0/0/0. SV, WV, SSV - Closed, MV = Open, IAV, OAV = OTG. 9/3/2009 T/I/O = BPV/5/220. Temp = SI. Bleed WHP's to 0 psi (pre rig). No wellhouse, flowline, scaffold or AL. OA FL C~ 804' (47 bbls). Bled OAP from 220 psi to 60 psi in 2.5 hours (gas). OA FL near surface. Bled IAP from 5 psi to 0 psi in 1 min (fluid). LRS on loc to load OA w/ crude. Pumped 40 bbls crude, SD & let gas swap out (15 min). Bled OA from 40 psi to 0+ psi. Pumped 10 bbls crude, OAP increased to 500 psi, SD & let gas swap out (15 min). Bled OAP from 500 psi to 0 psi (fluid). LRS r/d. Monitor for 30 min. OAP unchanged. FWHP's BPV/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. Page2of2 , ~ ~ BP EXPLQRATION Operations Summary Report Legal Well Name: NK-09 Common Well Name: NK-09 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 16 '.. . i ~ T_ 1., I T , I~ , I 9/4/2009 00:00 - 04:30 4.50 MOB P 04:30 - 08:00 3.50 MOB P 08:00 - 08:30 0.50 WHSUR P 08:30 - 09:30 1.00 WHSUR P 09:30 - 10:00 0.50 WHSUR N 10:00 - 10:30 0.50 WHSUR P 10:30 - 11:00 I 0.501 KILL I P 11:00 - 11:30 0.50 KILL P 11:30 - 12:30 1.00 KILL P 12:30 - 16:00 3.50 KILL P 16:00 - 17:00 1.00 WHSUR P 17:00 - 18:30 1.50 WHSUR P 18:30 - 19:30 1.00 WHSUR N 19:30 - 20:00 0.50 WHSUR N 20:00 - 21:30 I 1.50 ~ W HSUR ~ N 21:30 - 22:30 I 1.001 WHSUR I R! „y., Spud Date: 11/1/1994 Start: 9/1 /2009 End: 9/20/2009 . Rig Release: 9/20/2009 Rig Number: 16 NPT Phase Description of Operations PRE Move Rig from Maintenance staging area to NK-09. -Spot rig over NK-09 and shim in place. PRE RU in cellar, installing all annulus valves. -Spot 3516 and MP #2 modules and Slop tank. -Level ramp for Vac trucks to offload into pits and begin taking on 120-degree 8.5-ppg seawater to pits. "Accept rig at 0700-hrs" DECOMP PU DSM lubricator and pressure test to 500-psi. Good test. DECOMP Fill pits with 120-degree 8.5-ppg seawater. WAIT DECOMP Well Support arrive with correct tank. Build containment for tank. RU hardline & choke from cellar to flowback tank. DECOMP DSM pull BPV - no pressure under BPV. -LD lubricator and BPV. -RU to circulate out freeze protection. DECOMP Hold PJSM with rig crew, CH2MHill truck drivers & pusher, and BP WSL on testing lines and circulating out freeze protection. Discussed spill potential and high pressure testing. Assign people to positions during circulation. DECOMP Fill all lines and pressure test to 4000-psi. Good test. DECOMP Reverse 40-bbls of 8.5-ppg seawater at 6-BPM with 1900-psi, capturing diesel in flowback tank. Swap over and circulate the long way at 6-BPM / 2400-psi for 170-bbis, capturing diesel in flowback tank. DECOMP Circulate at full wellbore volume (the long way) at 5.5-BPM with 2900-psi. -Crude returns from OA throughout circulations. -Monitor well - Static. -Pump dry job. DECOMP FMC tech dry rod in TWC. -RU to test TWC. DECOMP Test TWC above to 4000-psi and below to 1000-psi. Hold and c art eac test or 10-minutes. -Test from below to 1000 psi for 10 minutes, Good Test -Test from above to 4000 psi Failed, unable to get a good test, cycle valves on tree, isolate tree from test pump without success, Pressure bleeding 50-100 psi / 5 minutes, very small amount of fluid dripping from IA WAIT DECOMP Mobilise DSM to pull TWC -Load pipe and install bales while waiting SFAL DECOMP Change out TWC -Rig up DSM Lubricator and Test to 500 psi, good test -Pull TWC, no pressure under plug, No signs of where fluid is leaking by SFAL DECOMP Re-Test TWC above to 4000-psi and below to 1000-psi. Hold and chart each test for 10-minutes. -Test from below to 1000 psi for 10 minutes, Good Test -Test from above to 4000 psi Failed, Same as before unable to get a good test, cycle valves on tree, isolate tree from test pump without success, Pressure bleeding 50-100 psi / 5 minutes, very small amount of fluid dripping from IA Contact ODE and adapted plan to set plug into TSRV C~ 2107' SFAL DECOMP iq own es eauipmen an ear oor or ire ine Printed: 9/29/2009 11:3722 AM ~ ~ BP EXPLORATION ' Page 2 ot 17 Operations Summary Report Legal Well Name: NK-09 Common Well Name: NK-09 Spud Date: 11/1/1994 Event Name: WORKOVER Start: 9/1/2009 End: 9/20/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/20/2009 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 9/4/2009 21:30 - 22:30 1.00 WHSUR N SFAL DECOMP Operation 22:30 - 23:30 1.00 WHSUR N SFAL DECOMP Rig up DS M Lubricator and Test to 500 psi, good test -Pull TWC, no pressure under plug, No signs of where fluid is leaking by and Plug appear un-damaged 23:30 - 00:00 0.50 DHB N SFAL DECOMP PJSM with SLB Slickline crew and Supervisor with DDI TP & Rig Crew and BP WSL -Position Slickline Unit and Tool Trailer 9/5/2009 00:00 - 03:30 3.50 DHB N SFAL DECOMP PJSM with SLB Slickline crew and Slickline Supervisor with the new DDI rig crew, DDI TP and BP WSL -RU and Test Full Pressure control Equipment, Test to 500 psi, good Test 03:30 - 05:30 2.00 DHB N SFAL DECOMP MU tools and RIH, Set Slickline "XX" Plug at 2104' WLM, POH and Confirm plug setting -Rig Down Slickline tools and pressure control equipment. 05:30 - 06:30 1.00 DHB N SFAL DECOMP Test Slickline "XX" plug set in TSRV from above to 4000-psi and below to 1000-psi. Hold each test for 10-minutes. Chart Record each test. -Test from below to 1000 psi for 10 minutes, Good Test -Test from above to 250-psi for 5-minutes and then to 4000 psi for 10 minutes, Good Test 06:30 - 07:00 0.50 DHB N SFAL DECOMP RD SLB Slickline unit and leave staged in position. 07:00 - 09:00 2.00 WHSUR P DECOMP PJSM on ND tree and adapter flange. -ND production tree and adapter flange. -FMC bleed and cap control line. -Test fit 4-1/2" NSCT XO. MU with 8-turns. -2 barriers for ND are 1 Fasdrill at 17 879' and 2 tested XX plug in TRSV. 09:00 - 11:30 2.50 BOPSU P DECOM s ac . 11:30 - 12:00 0.50 BOPSU P DECOMP RU to test BOPE. 12:00 - 12:30 0.50 BOPSU P DECOMP Hold ADW safety performance review with both rig crews. Discuss ADW goal of "No Recordables for the rest of the year", safety performance across ADW operations and the definition of a "hand". 12:30 - 17:00 4.50 BOPSU DECOMP Perform initial BOP test. -Test to 250-psi low and 4000-psi, using 4" and 4-1/2" test jts. -Test annular with 4" test jt to 250-psi low and 3500-psi high. -Hold and chart all tests for 5-minutes. -AOGCC re Bob Noble witnessed test. -BP WSL and DDI toolpusher witness all tests. 17:00 - 17:30 0.50 BOPSU P DECOMP Rig Down Test equipment and clear floor 17:30 - 21:30 4.00 DHB P DECOMP PJSM with Schlumberger Slickline crew, DDl Rig Crew, TP and WSL -Rig up Lubricator, BOP's and Sheaves , -Full Pressure Control equipment, Test Slickline Lubricators and BOP's to 500 psi, good test -RIH with Equalizing assembly and POH -RIH with Plug Retrieving assembly, Pull Plug on first attempt -Rig Down Slickline Equipment Schlumberger slickline crew did a good job. Participatied in the PJSM and performed the job on short notice without No Incidents. No Injuries. No Environmental Releases. 21:30 - 22:30 1.00 PULL P DECOMP Pull Hanger Printed: 9/29/2009 11:37:22 AM ~ ~ BP EXPLORATION Page 3 of 17 `Operations Summary Report Legal Well Name: NK-09 Common Well Name: NK-09 Spud Date: 11/1/1994 Event Name: WORKOVER Start: 9/1/2009 End: 9/20/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/20/2009 Rig Name: DOYON 16 Rig Number: 16 Date i From - To Hours Task Cod~ NPT Phase Description of Operations 9/5/2009 21:30 - 22:30 1.00 PULL P DECOMP -Make up Landing Joint and Crossover, -RIH and engage hanger with 8.5 turn, Make up Top Drive, -Back out Lock Down Screws -Pull Hanger free with 140,000 (with 40k Block Wt) -Monitor well for 10 minutes, static -Pull Tubing to rig Floor PUW 185,000 (with 40k Block Wt) 22:30 - 00:00 1.50 PULL P DECOMP Circulate Surface to Surface -Pump 20 bbl High Vis Sweep -12 bpm / 1330 psi 9/6/2009 00:00 - 01:00 1.00 PULL P DECOMP Finish Circulating Surface to Surface -12 bpm / 1330 psi -No significant increase in debris with the return of the High Vis sweep 01:00 - 01:30 0.50 PULL P DECOMP Lay Down Landing Joint and Hanger -Hanger profile threads damaged on one side 01:30 - 02:00 0.50 PULL P DECOMP Service Draw Works and Top Drive -Inspect Top Drive -PJSM with HES control line crew and DDI rig crew 02:00 - 03:30 1.50 PULL P DECOMP Lay Down 4 1/2" NSTC 12.6# Tubing From 17,775' - 16,600' -Spooling Dual encapsulated line as POH -PUW 165,000 03:30 - 04:00 0.50 PULL P DECOMP Change Out Control Line spool 04:00 - 04:30 0.50 PULL P DECOMP Lay Down 4 1/2" NSTC 12.6# Tubing From 16,600' - 15,763' -Spooling Dual encapsulated Iine as POH -Recovered 62 SS Bands out of 67 reported. 04:30 - 05:00 0.50 PULL P DECOMP Rig Down HES Spooling Unit -Norm inspected control Iine before leaving location 05:00 - 08:30 3.50 PULL P DECOMP Lay Down 4 1/2" NSTC 12.6# Tubing From 15,763' - 11,665' 08:30 - 09:00 0.50 PULL N SFAL DECOMP Change out Doyon Casing power tongs -Up / Down valve bleeding off. 09:00 - 17:00 8.00 PULL P DECOMP Continue to Lay Down 4-1/2" NSCT 12.6# Tubing from 11,665' to su ace. -Thin coat of scale over e~erior of last 15-jts pulled. No notable connection damage. -Recovered 425-jts of 4-1/2" 12.6# NSCT tubing, 4-GLMs, 1-TRSV, 1- X Nipple and 1-cut jt. -Cut jt is 27.86' long and flared to 4-15/16" OD. "`Completion NORM Contaminated "* 17:00 - 18:30 1.50 PULL P DECOMP RD 4-1/2" handling equipment. Clean & Clear rig floor. -Function rams to check for SS bands. 18:30 - 19:00 0.50 BOPSU P DECOMP Set Wear Bushing - 9" ID 19:00 - 20:30 1.50 FISH P DECOMP Make 9 5/8" Cleanout BHA -PJSM with Rig Grew an fishing hand -8 1/2" bit, Csg. Scraper, Bit Sub, Bumper Sub, XO, 6 x 6 1/4" DCs, XO 20:30 - 00:00 3.50 FISH P DECOMP RIH picking up 4" DP 1 x 1 to 3681' 9/7/2009 00:00 - 01:00 1.00 FISH P DECOMP Pick Drill Pipe 1 x 1 to 5326' 01:00 - 02:00 1.00 FISH P DECOMP Circlate 20 bbl High -Vis sweep -12 bpm / 1430 psi -Monitor Well, Static 8.4 seawater in and out 02:00 - 03:30 1.50 FISH P DECOMP POH Printed: 9/29/2009 17:3722 AM ~ • BP EXPLORATION '' Page 4 ofi 17 Operations Surnmary Report Legal Well Name: NK-09 Common Well Name: NK-09 Spud Date: 11/1/1994 Event Name: WORKOVER Start: 9/1/2009 End: 9/20/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/20/2009 Rig Name: DOYON 16 Rig Number: 16 Date' From - To Hours Task Code NPT Phase ' Description of Operations 9/7/2009 03:30 - 04:30 1.00 FISH P DECOMP Set back Drill Collars and Lay Down Csg. Scraper Assembly 04:30 - 05:00 0.50 EVAL P DECOMP Clear Floor and prepare to rig up logging tools -PJSM with Schlumberger Wire line crew 05:00 - 06:30 1.50 EVAL P DECOMP Spot and Rig up E-Line -PU Dutch Riser and Set -PU SWS Lubricator and Sheaves -Prep tools to RIH -Pressure test lubricator to 500-psi. Good test. 06:30 - 09:00 2.50 EVAL P DECOMP E-line RIH with USIT logging tools to 4600' and log back to surface looking for TOC in 13-3/8" x 9-5/8" annulus and 9-5/8" casing for corrosion. 09:00 - 10:00 1.00 EVAL P DECOMP PJSM with Schlumberger on RD E-line. -RD E-line equipment & Dutch Riser. 10:00 - 12:30 2.50 DHB P TIEB1 MU NES 9-5/8" RBP and running tool. -RIH on 4" DP from derrick. -RBP sets unexpectedly at 389'. -Release RBP & Reset to confirm it is still on running tool. -POH to check RBP for damage or problems. -Inspect RBP - no visible issues or damage. 12:30 - 14:00 1.50 DHB P TIE61 RIH with HES 9-5/8" RBP on 4" DP from derrick without issue. -PU wt = 90K-Ibs, SO wt = 92K-Ibs. 14:00 - 14:30 0.50 DHB P TIE61 Set RBP per HES rep. -To f RBP at 3514'. enter of EI ment t 1' 14:30 - 15:00 0.50 DHB P TIEB1 RU testing equipment and test RBP to 1000-psi for 10-charted minutes. -Good test. -RD test equipment 15:00 - 17:00 2.00 DHB P TIEB1 Dump 2200-Ibs of 20/40 mesh river sand on top of RBP. 17:00 - 18:30 1.50 FISH P TIEB1 Displace Drill Pipe volume at 1 bpm -Let sand settle for 30 minutes, PJSM while Waiting -Tag Top of Sand at 3465'md 18:30 - 20:00 1.50 DHB P TIE61 POH and Lay down running tool 20:00 - 20:30 0.50 FISH P TIE61 Test casinq to 4000 psi for 10 minutes, good test -Chart recorded test 20:30 - 21:30 1.00 FISH P TIEB1 Make up Multi-string casing cutter BHA -PJSM with Baker Fishing hand and DDI Rig Crew on picking up BHA 21:30 - 23:00 1.50 FISH P TIEB1 RIH and tag top of sand at 3463' md 23:00 - 00:00 1.00 FISH P TIEB1 MU Top Drive and break circulation -PUW 90k / SOW 90k 9/8/2009 00:00 - 00:30 0.50 FISH P TIEB1 Look for casing collar at 3404 and 3444', unable to detect collar Test Hardline to Flow back tank 3000 psi, Test LRS line to 3000 psi -PJSM with CH2MHill truck drivers, LRS, BOT , DDI Rig Crew and TP, BP WSL on Displacing OA 00:30 - 04:30 4.00 F1SH P TIEB1 Cut casing at 3414' md and displace OA to seawater -Start rotation without pump , free torque 4k ft-Ibs, ut casing with 5 bpm / 620 psi, 70 rpm 4- 8k TQ, -Felt Pipe jump when knives broke through, pipe was in suspension -Open up to OA , establish circ -Shut in OA and have LRS pump 37 bbl of 100 F deg diesel at 2 bpm, Close bag and pump another 13 barrels out to OA with Printed: 9/29/2009 11:37:22 AM ~ ~ B P `1 Operation Legal Well Name: NK-09 'Common Well Name: NK-09 ~Event Name: WORKOVER IContractor Name: DOYON DRILLING INC. '~, Rig Name: ~ DOYON 16 ~ ~ ~ ~ 9/8/2009 00:30 - 04:30 4.00 FISH P 04:30 - 05:30 1.00 FISH P 05:30 - 06:00 0.50 WHSUR P 06:00-07:30 ~ 1.50~WHSUR~P 07:30 - 09:00 1.50 BOPSU P 09:00 - 09:30 0.50 WHSUR P 09:30 - 10:30 1.00 WHSUR P 11~:30 - 16:00 4.50 BOP URF~ P 16:00 - 18:00 2.00 FISH P 18:00 - 18:30 0.50 FISH P 18:30 - 19:30 1.00 FISH P 19:30 - 00:00 4.50 FISH P 9/9/2009 I 00:00 - 00:30 I 0.501 FISH I P 00:30 - 01:00 0.50 FISH P 01:00 - 01:30 0.50 FISH P ~ummary Report Spud Date: 11/1/1994 Start: 9/1 /2009 End: 9/20/2009 Rig Release: 9/20/2009 Rig Number: 16 Phase Description of Operations TIEB1 LRS, Shut in LRS and Blow down, Displace diesel from DP with rig pump, Pump 120 F deg seawater displacing all the diesel in OA, Let Diesel soak for 30 minutes, Pump 40 bbl Safe-Surf-O pill at 2 bpm 130 psi and flush FP and diesel from OA, Pump a total of 300 barrels to Flowback tank, Open up bag and CBU at 10 bpm / 1800 psi Monitor well, static 8.4 seawater in/out TIEB1 POH and LD Cutter TIE61 Pull wear ring. -MU packoff retrieval tool. -RIH and engage packoff. TIEB1 FMC re BOLDS & Pull Packoff. -Work pull up to 70K-Ibs and packoff comes free. -POH & LD packoff and pulling tool. TIEB1 PJSM on ND BOP. -ND BOP between tubinq and casinq spools. -Insufficient room between top of casing spool and bottom of tubing spool to pull slips. -2-barriers for ND are 1) FasDrill at 17,879 and 2) RBP at ~ 3514'. TIEB1 Discuss situation with RWO engineer. Decide to remove tubing spool and weld slips to casing. TIE61 Set tubing spool and stack down on casing spool. -Break between tubing spool and BOP stack. -Remove tubing spool and set aside. -Clean API ring groove and prep siips for welding. TIEB1 Weld slips to casing and allow to cool for 30-minutes. TIEB1 NU BOP stack and install riser. -Riser blocking hole fill line. -Modify riser to keep hole fill clear and install. -Check all connections on casing spear and MU circulating head w/ TIW and 9-5/8" NSCC XO while modifications taking place. TIEBt PJSM on pulling 9-5/8" and CBU. -RIH with ITCO spear dressed for 9-5/8" 47# Csp.._ -Engage casing. Pull free Q 300K & 700 PS POH to rig floor with 1 set of slip dies only, suck out stack, open lower pipe ram door and retrieve 2nd set slip dies and both bowl pieces, pipe pulling free @ 195K TIE61 LD 1 jt DP, B/O & LD spear assy, cut joint TIE61 Circulate surface to surface C~ 10 BPM @ 550 PSI TIEB1 POH, LD 9 5/8" 47# L80 NSCC csg from 3414' to surface `ecovered 82-full jts of casing, 1-wellhead cut jt at 33.20', and 1-downhole cut jt at 12.01'. TIEB1 Continue to ~D 9-5/8" 47# L80 NSCC casing. Total recovery = 82-full jts of casing, 1-wellhead cut jt at 33.20', and 1-downhole cut jt at 12.01'. Average breakout torque for casing = 30 - 35K-ftlbs. TIEB1 RD 9-5/8" handling equipment and power tongs. Clean & Clear rig floor. TIEB1 PU 9-5/8" spear and release from wellhead cut jt. LD cut jt and spear. Printed: 9/29/2009 11:37:22 AM ~ ~ BP EXPLORATION ' Page 6 af 17 Operations Surnmary R~port Legal Well Name: NK-09 Common Well Name: NK-09 Spud Date: 11/1/1994 Event Name: WORKOVER Start: 9/1/2009 End: 9/20/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/20/2009 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase ' Descr~ption of Operations 9/9/2009 01:30 - 03:30 2.00 FISH P TIEB1 PJSM on PU dress off assembly. MU 9-5/8" Dress off BHA. BHA consists of Dress off shoe, Was pipe xtension, nternal Dress off Mill, Boot Basket, 13-3/8" Csq Scraper, 13-3/8" Cs~ Brush, Bumper sub, Float sub, and 2-stds of 6-1/4" DCs. Total length = 23225' 03:30 - 04:30 1.00 FISH P TIEB1 RIH with dress-off assembly to 3342'. PU wt = 105K-Ibs, SO wt = 95K-Ibs, Rot wt = 102K-Ibs. Rotate at 70-rpm with 4K-ftlbs of free torque. Bring pump on at 7-BPM with 340-psi. 04:30 - 05:30 1.00 FISH P TIEB1 Wash down and tag stub at 3414'. Dress off with 5K-Ibs WOB and above parameters down to 3415'. PU off of stub and slide down over stub without rotation or issue. 05:30 - 07:00 1.5Q FISH P TIEB1 Pump 40-bbl Safe Surf O sweep and chase out of hole at 11-BPM with 800-psi. Monitor well - Static. Stand back 1-std of DP 07:00 - 08:00 1.00 FISH P TIE61 Hold PJSM on slipping & cutting drilling line. Slip & cut 88' of drilling line. Inspect & service Top Drive. 08:00 - 09:00 1.00 FISH P TIE61 Pump 15-bbl dry job. POH to 223', standing back 4" DP in derrick. 09:00 - 10:30 1.50 FISH P TIEB1 Stand back 2-stds of 6-1/4" DCs. LD 9-5/8" Dress off BHA. Boot basket full of inetal shavings. 10:30 - 13:30 3.00 CASE P TIE61 Hold PJSM on RU to run 9-5/8" tieback. Move 2-stds of 6-1/4" DCs to Off Driller's Side. RU handling equipment and double stack power tongs to run 9-5/8" 47# L80 Hydril 563 tieback. RU and function test torque turn equipment. MU 9-5/8" Hydril 563 XO to TIW valve. 13:30 - 22:00 8.50 CASE P TIEB1 Hold PJSM on runninq 9-5/8" 47# L80 Hvdril 563 casinn tieback. Run 9-5/8" 47# L80 Hydril 563 casinq tieback. Patch / ECP assembly and ES cementer RIH at 1430-hrs. BakerLok all connections below ES cementer. Use Jet Lube Seal Guard thread compound on all Hydril 563 connections. MU BTC connection to mark. Torque turn all Hydril 563 connections to 15,800-ftlbs optimum torque. While running casing, layed down 2 joints due to bad pin thread and bad box threads. Finai weights before engaging casing stub PU 186K, SO 184K 22:00 - 22:15 0.25 CASE P TIEB1 En a e casin stub and SO 25K-Ibs PU 30K-Ibs on casing patch to set grapples. PU to 250K-)bs to pull test casing patch. SO and maintain 100K-Ibs overpull. 22:15 - 23:00 0.75 CASE P TIEBi Hold PJSM on RU CMT head. RU CMT head 23:00 - 00:00 1.00 CASE P TIE61 Pressure test casin , sta e u to 1000- si hold for 10-minu s, then increase to 1200-psi and let stabilize; increase to 1400-psi and let stabilize; then increase to 1600-psi and let stabilize; i~crease to 1650-psi to ooen the inflation valva nc~ the ECP. Pressure decrease to 1600-psi indicatina inflation Slowly increase pressure to 2000-psi to close the inflation valve, then PT the casing to 2000-psi for 10 minutes. Bleed off the casing pressure to 0-psi. All pressure test ok. 9/10/2009 00:00 - 00:30 0.50 CEMT P TtEB1 Circulate heated seawater throughout system bringing temperature of returns from 65 F to 80 F. 00:30 - 01:00 0.50 CEMT P TIEB1 Hold PJSM with cementers, rig crew, CH2MHill truck drivers, DDI tower pusher, BP WSLs. Discussed hazards while pumping cement dangers about high pressure lines and spill Printed: 9/29/2009 11:37:22 AM i ~ or cnr~vrtr~ i i~iu: ~ Qy~ , ~~ ~,, Operations Summary Report I Legal Well Name: NK-09 Common Well Name: NK-09 Spud Date: 11/1/1994 Event Name: WORKOVER Start: 9/1/2009 End: 9/20/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/20/2009 Rig Name: DOYON 16 Rig Number: 16 Date ' From - To Hours Task Code NPT Phase Description of ~perations 9/10/2009 00:30 - 01:00 0.50 CEMT P TIE61 potentials. RU cement lines 01:00 - 03:00 2.00 CEMT P TIE61 Batch Up cement. Pump 5-Bbls water and test lines to 3 500- si. Pum 235.1-Bbls of 15.8- class G cement wit Gasblok (yield = 1.16-cu.fVsack) Q 5.5-BPM ICP 567-psi, FCP 777-psi. Shut down and drop ES cementer closing plug; kick out with 10-Bbls freshwater. (Confirmed plug left head) Displace cement with rig pump at 5-BPM. ICP 110-psi caught cement 106-Bbis into displacement. Slowed rate to 2-BPM for the last 15-Bbls. Bumped plug 8-Bbl under calculated displacement. Pressure up and close ES cementer, closed with 2,200-psi held for 10-min. 36-Bbls cement returned to surface. Bleed off pressure and check for flowback. No flow. CIP Q 0240-HRS. 03:00 - 04:00 1.00 CEMT P TIEB1 Flush stack and OA vaive to flowback tank with 40-Bbl citric pill. Rig down cement head and circulating lines. Vac out fluid from casing joint. 04:00 - 05:00 1.00 WHSUR P TIEB1 ND stack at casing spool. Pickup stack and set slips with 100k. RU WACHs cutter. 2 barriers for ND are 1 FasDrill at 17879' amd 2 RBP at 3514'. 05:00 - 06:00 1.00 WHSUR P TIEB1 Make ACHs cut and LD 19.7' cut jt. MU packoff running tool on rig floor 06:00 - 07:30 1.50 WHSUR P TIE61 Prep casing spool for packoff installation. Notice long grooves in bowl of casing spool. Buff grooves with buffer wheel. Install packoff and RILDS. LD packoff running tool. 07:30 - 09:30 2.00 WHSUR P TIEB1 NU existing tubing spool. FMC rep pressure test packoff to 3800-psi for 30-minutes. Good test. 09:30 - 10:30 1.00 BOPSU P TIEB1 NU BOP stack. Install turnbuckles and use come-alon s to straighten stack. ` 10:30 - 11:00 0.50 BOPSU P TIEB1 Function all rams. MU stack washer and RIH. Flush stack with seawater. POH and LD stack washer. 11:00 - 13:00 2.00 BOPSU P TIEB1 Set test pluq in tubinp spool. RU and pressure test BOP/tubing spool break and lower pipe ram door. Test to 250-psi low and 4000-psi high. Hold and chart both tests. AOGCC rep John Crisp waived witness of test. RD test equipment. 13:00 - 14:30 1.50 CLEAN P CLEAN PJSM on making up Drill out BHA. MU Drill out BHA. BHA consists of 8-1/2" Reed Hycalog bit, 4(ea) Boot Baskets, Bumper Sub, Oii Jar, Pump Out Sub, and 2-stds of 6-1/4" DCs. Total length = 228.83' 14:30 - 15:30 1.00 CLEAN P CLEAN RIH with 9-5/8" Drill out BHA on 4" DP from derrick to 3357'. 15:30 - 21:00 5.50 CLEAN P CLEAN Obtain parameters. PU wt = 100K-Ibs, SO wt = 97K-Ibs, Rot wt = 100K-Ibs. Rotate at 60-RPM with 3K-ftibs of free torque. Pump on at 6-BPM with 310-psi. Wash down and tag cement at 3367'. Wash and ream ahead to tag plug at 3369'. Drill ES cementer plug with above parameters and 2-3K-Ibs WOB. Bring rotation up to 80-RPM with 3-4K-Ibs torque and mill ahead. Cement and very fine rubber returns seen across shakers. 21:00 - 21:30 0.50 CLEAN P CLEAN Rig service. Repair top drive hydraulic hose leak 21:30 - 22:00 0.50 CLEAN P CLEAN RIH tag sand Q 3463'. Dry drill with 80-rpm, 2K-wob. Drill to 3470' totaling 15 min drilling sand. Pump dry-job. \ ~ ~~ Printed: 9/29/2009~ 11:3722 AM ~ ~ BP EXPLQRATlQN Page 8 of 17 Qperations Summary Report Legal Well Name: NK-09 Common Well Name: NK-09 Spud Date: 11/1/1994 Event Name: WORKOVER Start: 9/1/2009 End: 9/20/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/20/2009 Rig Name: DOYON 16 Rig Number: 16 ` Date From - To Hours Task Code NPT Phase Description of Operations 9/10/2009 22:00 - 00:00 2.00 CLEAN P CLEAN POH from 3470' to 225'. Stand back 2-stds of 6-1/4" DCs. 9/11/2009 00:00 - 00:30 0.50 CLEAN P CLEAN LD BHA, clean out boot baskets. Baskets completely filled with cement rubber ieces, shear pin pieces, and aluminum pieces. 00:30 - 02:00 1.50 CLEAN P CLEAN PJSM held for PU BHA. MU RCJB assembly. M 7 8 RCJB with 8.5" head, 4(ea) 7" boot baskets, 9 5/8" CSG scraper, bit sub, pump out sub, XO sub, 2-stds of 6-1/4" DCS, XO. Total length = 218.65'. 02:00 - 03:00 1.00 CLEAN P CLEAN RIH to 3442' and obtain parameters. PU wt = 102K-Ibs, SO wt = 98K-Ibs, Rot wt = 100K-Ibs. Rotate at 80-RPM with 3K-ftlbs of free torque. Pumping at 8-BPM with 600-psi. 03:00 - 03:30 0.50 CLEAN P CLEAN RIH and tag top of sand at 3461'. Drop ball and pressure increased to 1450-psi at 7-BPM with bali on seat. Wash down from 3461' to 3482' with above parameters. 03:30 - 04:30 1.00 CLEAN P CLEAN Pump and recover 20-bbl Hi Vis sweep. Rubber, small pieces of aluminum, and sand across shakers. Monitor well - Static. Pump 15-bbl dry job. 04:30 - 05:30 1.00 CLEAN P CLEAN POH from 3482' to 218', standing back 4" DP in derrick. 05:30 - 06:30 1.00 CLEAN P CLEAN Stand back 2-stds of 6-1/4" DCs. Clean RCJB and boot ~ baskets. Recover 2-1/2" long section of small o-ring in RCJB. Palm size 1/4" thick piece of aluminum in lowest boot basket. Recover 5-gallons of cement and sand in boot baskets also. 06:30 - 07:00 0.50 CLEAN P CLEAN MU RCJB BHA with same configuration as above minus the 9-5/8" casing scraper. Total length = 214.45' 07:00 - 08:00 1.00 CLEAN P CLEAN RIH with RCJB BHA #2 on 4" DP from derrick to 3442'. Obtain parameters: PU wt = 102K-Ibs, SO wt = 98K-Ibs, Rot wt = 100K-Ibs. Rotate at 70-RPM with 2.5K-ftlbs of free torque. Pump on at 7-BPM with 450-psi. 08:00 - 08:30 0.50 CLEAN P CLEAN RIH and tag top of sand at 3485'. Drop ball and pump down at 7-BPM, when ball on seat pressure increases to 1470-psi. Wash down to 3500' without issue using above parameters. 08:30 - 09:30 1.00 CLEAN P CLEAN Pump 20-bbl Hi Vis sweep and chase out of the hole at 8-BPM with 1470-psi. Sand, cement and small amount of rubber seen at bottoms up and again when sweep came back. Monitor well - Static. 09:30 - 10:30 1.00 CLEAN P CLEAN Pump 15-bbl dry job. POH, standing back 4" DP in derrick. 10:30 - 11:30 1.00 CLEAN P CLEAN LD 6-jts of 6-1/4" DCs. LD RCJB BHA #2. Recover a 3" long piece of wire from RCJB and -4-gals of sand and fine metal shavings in boot baskets. All 4-boot baskets had material in them. No metal or rubber of any size seen. 11:30 - 12:00 0.50 CLEAN P CLEAN Clean & Clear rig floor. RU to pressure test casing tieback. 12:00 - 13:30 1.50 CLEAN P CLEAN est 9-5/8" casin tieback to 4000- si for 30-charted minutes. Good test. RD test e ui ment. 13:30 - 14:30 1.00 DHEQP P OTHCMP PJSM on retrieving RBP. MU RBP retrieval tool. RIH to 2293'. 14:30 - 15:00 0.50 DHEQP P OTHCMP Hold meeting with incoming crew regarding "No Recordables for the rest of the year" and safety expectations of ADW. 15:00 - 16:00 1.00 DHEQP P OTHCMP Continue RIH with RBP retrieval tool. ~IH tag sand @ 3502'. PU 90k-Ibs, SO 90k-Ibs. Wash down to top of RBP @ 7 bpm^ w/280- psi. Latch onto RBP @ 3516' 16:00 - 16:30 0.50 DHEQP P OTHCMP Circulate 20- bbl sweep Q 10- bpm w/ 510- psi. Steady sand returns with bottoms up ahead of the sweep. 16:30 - 17:00 0.50 DHEQP P OTHCMP Release RBP. Set down 20k then turn 2 rounds to the right and pull up 125K 17:00 - 18:00 1.00 DHEQP P OTHCMP Circulate bottoms up @ 10- bpm w/ 660- psi. Flow check for 10 Printed: 9/29/2009 11:37:22 AM . ~ BP EXPLORATION ' Page 9 of 17 Operations Summary Report Legal Well Name: NK-09 Common We!! Name: NK-09 Spud Date: 11/1/1994 Event Name: WORKOVER Start: 9/1/2009 End: 9/20/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/20/2009 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of Operations 9/11/2009 17:00 - 18:00 1.00 DHEQP P OTHCMP min, well static. ~^ 18:00 - 19:00 1.00 DHEQP P OTHCMP POH to surface and LD RBP and runnin tool. ~ 19:00 - 20:00 1.00 DHEQP P OTHCMP Pull wear ring, set test plug, RU to test BOP O 20:00 - 00:00 4.00 BOPSU P OTHCMP PJSM held for BOPe test, discussed hazards around high pressure testing. Perform weekly BOP test. Test upper pipe rams with 4" and 2 7/8" test joint, HCR choke and kili HCR, 2" DEMCO, upper and lower IBOP, lower rams w/ 4.5", manuai kill, manual choke, choke valves, 4' TIW. Test to 250-psi low and 4000-psi. Test annular with 2 7/8" test jt to 250-psi low and 3500-psi high. Hold and chart all tests for 5-minutes. All test held. Tested accumulator and passed. AOGCC rep John crisp waived witness on tests. BP WSL Josh Drury and DDI toolpusher Pete Martinusen witness all tests. 9/12/2009 00:00 - 01:30 1.50 BOPSU P OTHCMP PJSM held for BOP test, discussed hazards around high pressure testing. Finish performing weekly BOP test. Test 3.5x6" VBR with 4" & 4.5" test joint. Test 2 7/8" x 5" VBR with 2 7/8" & 4.5" test joint. All tests to 250-psi low and 4000-psi high. Test annular with 2 7/8" test joint to 250-psi low and 3500-psi high. Hold and chart all tests for 5-minutes. All test held. AOGCC rep John crisp waived witness on tests. BP WSL Josh Drury and DDI toolpusher Pete Martinusen witness ali tests. 01:30 - 02:00 0.50 BOPSU P OTHCMP RD BOP test equipment 02:00 - 02:30 0.50 CLEAN P CLEAN Rig service. Service top drive. 02:30 - 04:30 2.00 CLEAN P CLEAN PJSM held for MU BHA. Brinq fishing tools to rig floor and MU HA assembly: dress-off shoe, `r extension, inner tbg dress-off mill, washover boot basket, XO, csg scraper, bit sub, bumper sub, XO, 6-DCS. Total length = 214.30' 04:30 - 06:00 1.50 CLEAN P CLEAN RIH with dress-off assembly on drill pipe from derrick to 5536'. Break circulation at 6-BPM with 700-psi. 06:00 - 12:00 6.00 CLEAN P CLEAN RIH with dress off BHA from 5536' to 10680', picking up 4" DP from pipe shed. PU wt = 165K-Ibs, SO wt = 125K-Ibs. 12:00 - 12:30 0.50 CLEAN P CLEAN Rig Service. Inspect and service top drive. Inspect pipe skate and tighten hydraulic hoses. 12:30 - 15:00 2.50 CLEAN P CLEAN Continue to RIH with dress off BHA from 10,680' to 13,849', picking up 4" DP from pipe shed. 15:00 - 15:30 0.50 CLEAN P CLEAN Circulate at 13,849' to ensure 7" liner top is ciear of debris. Pump on at 8-BPM with 1840-psi. 15:30 - 19:00 3.50 CLEAN P CLEAN Continue to RIH with dress off BHA from 13,849' to 17,718'. Work scraper from 17,653' to 17,718'. 19:00 - 21:30 2.50 CLEAN P CLEAN MU to Top Drive. Obtain parameters: PU wt 232K-lbs, SO wY 130K-Ibs, ROT 175K-Ibs. Rotate at 70-RPM with 11 K-free ` torque. Pump at 8- BPM, 1830- psi. RIH and tag Q 17,738'. Wash over stub while rotating C~3 70-rpm and pumping at 7-BPM, 1760-psi. Run between 1-12K-Ibs WOB with torque from 11 K- 16K-ftlbs torque. Dress off and swallow to 17,745'~ Able to slide easily over stump without rotation and without pumps and rotation. 21:30 - 00:00 2.50 CLEAN P CLEAN Pump 20-bbl high-vis sweep surface to surface. Trace sand seen across shakers, quantity of a cup of small metal shavings Printed: 9/29/2009 11:3722 AM ~ ~ Qperations Summary Report Legal Well Name: NK-09 Common Well Name: NK-09 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 i Date : From - To Hours Task Code NPT 9/12/2009 21:30 - 00:00 2.50 CLEAN P 9/13/2009 00:00 - 01:30 1.50 CLEAN P 01:30 - 08:00 6.50 CLEAN P 08:00 - 09:00 1.00 CLEAN P 09:00 - 09:30 0.50 WHSUR P 09:30 - 10:00 0.50 CLEAN P 10:00 - 13:00 3.00 BOPSU N RREP 13:00 - 14:00 1.00 BOPSU N 14:00 - 14:30 0.50 WHSUR P 14:30 - 15:00 0.50 CLEAN P 15:00 - 16:30 1.50 CLEAN P 16:30 - 22:00 5.50 CLEAN P 22:00 - 22:30 0.50 CLEAN P 22:30 - 00:00 1.50 CLEAN P 9/14/2009 00:00 - 02:30 2.50 CLEAN P 02:30 - 04:00 1.50 CLEAN P 04:00 - 04:30 0.50 CLEAN P 04:30 - 00:00 19.50 CLEAN P 9/15/2009 00:00 - 00:30 0.50 CLEAN P Spud Date: 11/1/1994 Start: 9/1 /2009 End: 9/20/2009 Rig Release: 9/20/2009 Rig Number: 16 Phase Deseription of Operations CLEAN collected on magnets. No increase of sand and nothing else noticed when sweep returned. CLEAN Slip and cut drill line. CLEAN POH with dress off BHA from 17,745' to 214'. CLEAN Stand back 2-stds of 4-3/4" DCs. LD BHA. Inspect Dress off milis. Inner mill brass tattletales are worn smooth and inner mill shows wear pattern consistent with dressing tubing. Boot basket contained ~1/4-cup of scale. CLEAN Drain BOP stack. Pull wear ring. Install test plug in tubing spool. Ensure Kill line manual valve is shut. CLEAN RU all 2-7/8" handling equipment and power tongs. CLEAN Hold PJSM on changing out Kill HCR valve. Discuss working at heights, use of proper toois for the job and positions of people. Change out Kill HCR valve. CLEAN Fill lines, RU test equipment and test breaks in kill line and new Kill HCR valve. Test to 250-psi low and 4000-psi high. Hold and chart all tests for 5-minutes. Test witnessed by BP WSL and Doyon Toolpusher. Good Tests. RD test equipment. CLEAN Pull FMC test plug. Install wear ring and RILDSs. CLEAN Hold PJSM on making up FasDrill drill out BHA with Baker Fishing rep. Discuss power tong safety, handling small tubulars, proper torque for connections and positions of people. CLEAN MU FasDrili drill out BHA. BHA consists of 3-5/8" convex mill, 25-jts of 2-7/S" PAC HT DP, XO, Bumper sub, Jar, XO and 2-stds of 4-3/4" DCs. Totai BHA length = 1,003.95'. Pump DP volume through BHA to ensure mill is clear. CLEAN RIH with FasDrill drill out BHA on 4" DP from derrick. Break circulation evern 3000-ft to ensure mill is clear. CLEAN Circulate at 7.5-BPM with 2900-psi while spotting CH2MHill vac trucks for displacement CLEAN Pump 40-bbi Hi Vis sweep and begin displacing wellbore to 9.8-ppg brine at 6-BPM with 2850-psi. CLEAN Continue to displace well from 8.5-ppg seawater to 9.8-ppg seawater at 6-BPM with 2850-psi. Got sweep back and had clean 9.8-ppg brine behind sweep. CLEAN PU wt =220K-Ibs, SO wt = 125K-Ibs, Rot wt = 171 K-Ibs. Rotate at 20-RPM with 7.5K-ftlbs free torque. Pump at 3-BPM with 950-psi. Tag tubing stump at 17,738'. PU and rotate through tubing stubmp at 20-rpm without issue. Continue RIH and tag plug at 17837'. Mill plug with 4-5K-Ibs WOM and 40-RPM with 10K-ftlbs torque on bottom. Mill to 17839' and plug lets go. Wash down to 17,849'. PU and position tool jt. CLEAN Close annular and bulihead 40-bbls at 5-BPM with 2150-psi. Open Choke HCR valve and check pressures. Pressure stabilized at: DP = 190-psi, Csg = 180-psi. Bleed 20-bbls back. Check pressures again: DP = 140-psi, Csg = 130-psi. CLEAN Remain shut in and continue to monitor pressures. Notify RWO engineer, RWO Superintendent and AOGCC (John Crisp) of well kill operations. Pressures holding steady with DP = 140-psi and Csg = 130-psi. Calculate KWF = 10.3-ppg which includes 100-psi safety margin. Order 5 full loads (1450-bbls) of 10.3-ppg brine. Hole volume = 1075.7-bbls. CLEAN Remain shut in and continue to monitor pressures. Pressures Printed: 9/29/2009 11:37:22 AM • ~ BP EXPLORATION i Page 11 of 17 `Operations Summary Report Legal Well Name: NK-09 Common Well Name: NK-09 Spud Date: 11/1/1994 Event Name: WORKOVER Start: 9/1/2009 End: 9/20/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/20/2009 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phas 9/15/2009 00:00 - 00:30 0.50 CLEAN P CLEAN 00:30 - 01:00 I 0.501 CLEAN I P I I CLEAN 01:00 - 07:30 I 6.501 CLEAN I P I I CLEAN 07:30 - 08:30 I 1.001 CLEAN I P I I CLEAN 08:30 - 09:30 I 1.001 CLEAN I P I I CLEAN 09:30 - 14:00 ~ 4.50I CLEAN ~ P ~ ~ CLEAN 14:00 - 16:00 I 2.001 CLEAN I P I I CLEAN 16:00 - 17:00 I 1.001 CLEAN I P I I CLEAN holding steady with DP = 140-psi and Csg = 130-psi. Calculate KWF = 10.3-ppg which includes 100-psi safety margin. Order 5 full loads (1450-bbls) of 10.3-ppg brine. Hole volume = 1075.7-bbls PJSM with rig crew, tool pushers, BP WSLs, CH2MHILL truck drivers, MI mud engineer about hazards associated with kiil operation, possible H2S in returned gas, evacuation safe area, and positions of people. Begin pumping KWM 10.3-ppg Q 3-bpm, SIDPP = 140-psi and SICP = 13U-psi. Bring pump online at 3-BPM with ICP of 1030-psi and Casing pressure of 290-psi. Follow pressure schedule on choke to FCP of 990-psi. Calculated pumping schedule of 2234-strokes to bit, 10454-strokes bit to surface, 12688-strokes for KMW to displace hole. Pump 13985-siks (1183-bbls), which is 107-bbls past calculated displacement. Returns consistently weighing 9.8-ppg which reduced to 9.6-ppg just prior to shutting in. Returns had a large amount of crude. Little gas noted during circulation. Stop pumping and shut in well. Initial pressures: SIDPP = 140-psi, SICP = 180-psi. Allow pressures to stabilize with SIDPP = 20-psi and SICP = 50-psi. Monitor pressures and discuss plan forward with RWO engineer. Bullhead 20-bbis of 10.3-ppg brine down DP to formation. Took -2-bbls to catch pressure. Pump at 5.3-BPM with 2990-psi. Shut in and monitor pressure. Initiai pressures: SIDPP = 470-psi, SICP = 550-psi. Pressures stabilize at SIDPP = 20-psi and SICP = 50-psi. Wait for 870-bbls of 10.3-ppg brine to be made at MI plant and brought to location to resume well kill operations. Continuously monitor pressures. SIDPP = 20-psi and SICP = 50-psi. Perform light maintenance and housekeeping throughout rig. lnspect and service top drive and pipe skate. Circulate 10.3-ppg brine at 3-BPM. At 1418-hrs, bring pump up to 29-SPM at 20-psi, CP at 40-psi. DP pressure increases rapidly to 800-psi in the first 5-minutes with gas through the gas buster. At 8-minutes pumping time and with pump rate increased to 37-SPM (3-BPM on pump #1), DP pressure is 1040-psi and CP is 100-psi. Get returns to surface after 203-strokes (17-Bbls), FL at 290'. MW in returns is 9.6-ppg. Continue pumping at 36-37-SPM and MW in returns at 1450-hours is 9.8-ppg with 1060-psi on DP and CP held at 100-psi with choke. 1520-hours, 2190-strokes (184-Bbis) into circulation, DP 1030-psi, CP 0-psi, choke full open, returning MW 10.2-ppg heavy. 1526-hours, calculated loss rate with open choke is134.5-BPH, DP 1040-psi, CP 0-psi, 202-Bbls pumped, returning MW is 10.3-ppg. Circulate back to Pits until 1600-hours at 37-SPM (3-BPM), DP 1040-psi, CP 0-psi. 1600-hours, calculated loss rate is 19.2-BPH. Stop pumping and watch gas buster fluids bleed back to shakers. Monitor weli for 30-minutes. Open Hydril and fluid level drops to the Mud Cross. Hold PJSM to discuss the Plan Forward. Start by thanking crew for their safe, excellent work during the Well-Kill circulation. Ask crew members if they had any Printed: 9/29/2009 113722 AM ~ . BP EXPLOR~4TION' Page 12 of 17' Operations Summary Report Legal Well Name: NK-09 Common Well Name: NK-09 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task `Code NPT 9/15/2009 16:00 - 17:00 1.00 CLEAN P 17:00 - 18:30 1.50 CLEAN P 18:30 - 19:00 0.50 CLEAN P 19:00 - 19:30 0.50 CLEAN P 19:30 - 22:00 2.50 CLEAN P 22:00 - 22:30 0.50 CLEAN P 22:30 - 00:00 1.50 CLEAN P 9/16/2009 00:00 - 12:00 12.00 CLEAN P 12:00 - 13:00 1.00 CLEAN P 13:00 - 16:00 3.00 CLEAN P 16:00 - 17:00 1.00 CLEAN P 17:00 - 19:00 2.00 RUNCO 19:00 - 21:00 I 2.00 Spud Date: 11/1/1994 Start: 9/1/2009 End: 9/20/2009 Rig Release: 9/20/2009 Rig Number: 16 Phase Description of Operations CLEAN questions regarding the Well-kill operations, and if they were satisfied that the well was dead. We discussed monitoring the fluids coming out of the gas buster into the Possum Belly and why it was important to observe until the last drip was seen. CLEAN P/U wt 230-K-Ibs, S/O wt 125-K-Ibs. RIH with the last joint of the circulating stand and see slight indication that we're pushing something downhole from the last spot, 17,849', that the FasDril plug was pushed to. P/U another stand, M/U to Top Drive and circulate at 2-BPM while slowly RIH. See very slight bobble on the weight indicator. Continue RIH and push the FasDrill plug out the bottom of the 4-1/2" and into the 5" Liner at 17,924'. Continue RIH with stands from Derrick. Circuiate at 1.5-BPM with returns to Pits. Hit fill at 18,242', P/U, start rotating at 40-RPM, slowly RIH and mill through the obstruction with 12K-ib-ft of torque and 3-4K-Ibs WOB. P/U stand #183, M/U to Top Drive and wash down without rotating to 18,343'. P/U stand #184, M/U to Top Drive, bring pump up to 2-BPM, wash down to 18 438'. M/U to stand #185, bring pump up to 2.5-BPM and wash down to 18,470' to hard tag. Bottom set of perforations are 18,162' to 18,306', ELMD. 20-Bbls lost to formation from 1700-hours to 1815-hours. CLEAN PU to 18,444' and circulate 220-Bbl at 5-BPM at 2100-psi. CLEAN POH from 18,444' to 17,690' (above 4-1/2" tubing stub) racking back drill pipe CLEAN Drop ball and pump down at 5-BPM. Circulation sub opened at 1940-psi. Complete bottoms up circulations. Pump 665-Bbl at 8-BPM with 2170-psi. Loss rate = 20-BPH. CLEAN Flow check weil. Well not flowing, took 1-bbl in 15-min. CLEAN POH & LDDP. Maintaining continuous hole fill while pulling out of hole. Loss rate = 12-BPH. CLEAN POH & LDDP. MAINTAINING CONTINUOUS HOLE FILL WHILE PULLING OUT OF HOLE. LOSS RATE = 12-BPH. DP JOINT #384 POH AT 0830-HOURS (555-JOINTS 4" DP, 6-EA 4-3/4" DC, AND 25-EA 2-7/8" PAC DP ORIGINALLY RIH). 1015-HRS, UO JT #450. 1130-HOURS, UD #500. ROUSTABOUT AND DERRICKMAN DISCOVER LEAKING HOSE ON OFF-DRILLER-SIDE PIPE ELEVATOR DURING THEIR PRE-TOUR HANDOVER INSPECTION. CLEAN RIG MECHANIC AND MOTORMAN CHANGEOUT HYDRAULIC HOSE IN ODS PIPE SKATE ELEVATOR. CLEAN RESUME POH AND LD DP. 1400-HOURS, L/D #530; LOSS RATE IS CALCULATED 7.5-BPH. 1415-HOURS AT FIRST OF 6-EA 4-3/4" DCS. UD 25-JTS OF 2-7/8" PAC DP. CLEAN CLEAR AND CLEAN RIG FLOOR. P/U LANDING JOINT AND M/U TO TEST PLUG AND RIH TO PREPARE FOR BOP TEST. RUNCMP R/U TO TEST HYDRILL AND EQUIPMENT UTILIZED JOINT. TEST HYDRIL TO 250-PSI LOW AND 3500-PSI HIGH. TEST REMAINDER OF EQUIPMENT TO 250-PSI LOW AND 4000-PSI HIGH, RECORDED ON CHART FOR 5-MIN TEST. RD BOP TEST JOINT RUNCMP RIG SERVICE. SLIP AND CUT DRILL LINE Printed: 9/29/2009 11:37:22 AM ~ ~ BP EXPLORATION ' Page 13 of 17 Operations Summary Report Legal Well Name: NK-09 . . Common Well Name. NK-09 Spud Date. 11/1/1994 Event Name: WORKOVER Start: 9/1/2009 End: 9/20/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/20/2009 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Code NPT Phase Description of aperations 9/16/2009 21:00 - 22:00 1.00 RUNCO RUNCMP 22:00 - 23:00 1.00 RUNCO P RUNCMP 23:00 - 00:00 1.00 RUNCO P RUNCMP 9/17/2009 00:00 - 05:00 5.00 RUNCO P RUNCMP 05:00 - 06:00 1.00 RUNCO RUNCMP 06:00 - 17:30 11.50 RUNCO P RUNCMP 17:30 - 18:00 0.50 RUNCO P RUNCMP RU 4.5" TUBING RUNNING EQUIPMENT AND TORQUE TURN SERVICES. PJSM HELD WITH RIG CREW, DOYON CASING, BAKER, WSL, TOOL PUSHER ON RUNNING TUBING AND HAZARDS WHILE RUNNING IN HOLE. BEGIN RUNNING IN HOLE WITH 4.5" 12.6# 13CR85 VAM TOP COMPLETION JEWELRY AND TUBING. H2S ALARM WENT OFF AT DRILLER CONSOLE. ALARM APPEARED TO BE FALSE. SECURED WELL AND CHECKED WITH HANDHELD SNIFFER. READINGS WERE 0-PPM H2S. WAITED FOR ELECTRICIAN TO CALIBRATE RIG ALARM. HELD A POST DRILL DISCUSSION ABOUT WHAT WENT WELL AND WHAT SHOULD HAVE BEEN DONE IF IT WAS A REAL ALARM. CONTINUE MONITORING HOLE FILL 18-BBL HOUR LOSS. CONTINUE RUNNING IN HOLE WITH 4.5" 12.6# 13CR85 VAM TOP TUBING. USE JET LUBE SEAL GUARD ON ALL I CONNECTIONS. TORQUE TURN ALL CONNECTIONS TO I OPTIMAL MU TORQUE OF4,440-LB-FT (MIN=4,000-LB-FT; MAX=4,880-LB-FT) MAINTAIN CONTINUOUS HOLE FILL. RIH WITH 97 JOINTS 3,645'. RIG SERVICE. SERVICE & INSPECT TOP DRIVE & PIPE SKATE. REPAIR SPRING TENSIONER ON SINGLE JT ELEVATORS. MAINTAINING HOLE FILL WITH 12-BPH LOSS AVERAGE SINCE 0000-HOURS. CONTINUE RUNIVING IN HOLE WITH 4.5" 12.6# 13CR85 VAM TOP TUBING. USE JET LUBE SEAL GUARD ON ALL CONNECTIONS. TORQUE TURN ALL CONNECTIONS TO OPTIMAL MU TORQUE OF 4,440-LB-FT (MIN=4,000-LB-FT; MAX=4,880-LB-FT) MAINTAIN CONTINUOUS HOLE FILL.0915-HRS, JT #162 AND 2ND GLM RIH. 1020-HRS, JT #189 RIH. 1200-HRS, JT #219. 1300-HRS, JT #239. 1530-HRS, JT #293. 1630-HRS, JT #323. 1730-HRS LOSS RATE IS 9-BPH. RIG SERVICE. SERVICE TOP DRIVE AND INSPECT SKATE. 18:00 - 19:00 1.00 RUNCO P RUNCMP CONTINUE RUNNING IN HOLE WITH 4.5" 12.6# 13CR85 VAM TOP TUBING. USE JET LUBE SEAL GUARD ON ALL CONNECTIONS. TORQUE TURN ALL CONNECTIONS TO OPTIMAL MU TORQUE OF4,440-LB-FT (MIN=4,000-LB-FT; MAX=4,880-LB-FT) MAINTAIN CONTINUOUS HOLE FILL. 19:00 - 20:00 1.00 RUNCO P RUNCMP PJSM WITH HALLIBURTON ON RU TRSV SPOOLING CABLE CONTROL LINE. RU SHEAVE TO PAD-EYE ON OFF DRILLER SIDE WINDWALL. 20:00 - 22:00 2.00 RUNCO RUNCMP SAFETY STAND DOWN TO DISCUSS DROPPED OBJECT NEAR MISS. WHILE RIGGING UP A SHEAVE IN DERRICK FOR CONTROL LINE, RIG HAND DROPPED SHACKLE PIN (WEIGHING 6-OZ) FROM HIS HAND. HE WAS WORKING 24' ABOVE THE RIG FLOOR. THE PJSM DISCUSSED MAKING SURE THE FLOOR WAS CLEARED WHEN PERSONNEL ARE WORKING ABOVE. NO ONE WAS ON THE FLOOR WHEN PIN FELL. THE CLOSEST EMPLOYEE WAS 5' FROM WHERE THE PIN LANDED. AN INCIDENT INVESTIGATION Printed: 9/29/2009 11:3722 AM ~ ~ BP EXPLORATION Pac~e 14 of 17 Qperations Sumrnary Report Legal Well Name: NK-09 Common Well Name: NK-09 Spud Date: 11/1/1994 Event Name: WORKOVER Start: 9/1/2009 End: 9/20/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/20/2009 Rig Name: DOYON 16 Rig Number: 16 Date From - To Hours Task Cad~ NPT Phase Description of Qperations 9/17/2009 20:00 - 22:00 2.00 RUNCO P RUNCMP WAS CONDUCTED AND SAFETY STAND DOWN HELD WITH CREW INVOLVED. 22:00 - 23:00 1.00 RUNCO P RUNCMP CONTINUE WITH RU TRSV CONTROL LINE. HANG SHEAVE ON PAD-EYE AND STRING TUBING THROUGH SHEAVE. CONNECT CONTRO~ LINE TO SAFETY VALVE AND PRESSURE TEST WITH 5000-PSI FOR 15-MIN. GOOD TEST. 23:00 - 00:00 1.00 RUNCO P RUNCMP CONTINUE RUNNING IN HOLE WITH 4.5" 12.6# 13CR85 VAM TOP TUBING WITH SINGLE CONTROI LINE. INSTALL 1-SS BAND PER JT. USE JET LUBE SEAL GUARD ON ALL CONNECTIONS. TORQUE TURN ALL CONNECTIONS TO OPTIMAL MU TORQUE OF 4,440-LB-FT (MIN=4,000-LB-FT; MAX=4,880-LB-FT) MAINTAIN CONTINUOUS HOLE FILL. LOSS RATE IS 9-BPH. 9/18/2009 00:00 - 03:30 3.50 RUNCO P RUNCMP PJSM WITH RIG CREW COMING ON TOUR ON RUNNING TUBWG IN HOLE. CONTINUE RUNNING IN HOLE WITH 4.5" 12.6# 13CR85 VAM TOP TUBWG WITH SWGLE CONTROL LINE. INSTALL ONE SS-BAND PER JT. USE JET LUBE SEAL GUARD ON ALL CONNECTIONS. TORQUE TURN ALL CONNECTIONS TO OPTIMAL MU TORQUE OF 4,440-LB-FT (MIN=4,000-LB-FT; MAX=4,880-LB-FT) MAINTAIN CONTINUOUS HOLE FILL. LOSS RATE IS 9-BPH. 03:30 - 04:30 1.00 RUNCO P RUNCMP 04:30 - 07:00 2.50 RUNCO P RUNCMP 07:00 - 08:00 1.00 RUNCO RUNCMP 08:00 - 09:00 1.00 RUNCO RUNCMP 09:00 - 10:00 1.00 RUNCO P RUNCMP MU JT #420. PU WT = 185K-LBS, SO WT = 110K-LBS. RIH AND SEE FIRST SET OF PINS SFiEAR AT 17750' WITH 12K-LBS TO SHEAR PINS. CONTINUE RIH AND SEE SECOND SET OF PINS SHEAR AT 17752.5' WITH 12K-LBS DOWN. CONTINUE RIH AND NO GO AT 17,753.5'. CALCULATE STUB AT 17,746'. CALCULATE WITH SPACEOUT USING 9.892', 9.882' AND 7.832' PUP JTS. THIS PLACES BOTTOM OF UNIQUE OVERSHOT AT 17,750.3' WITH 4.3' SWALLOW. POH LAYING DOWN JOINTS # 419-421. MU 9.892', 9.882' AND 7.832' PUP JTS, JT #419, TUBING HANGER AND LANDING JT. INSTALL VALVE IN CONTROL LINE AND TEST LINE TO 5000-PSI. USE 57 CONTROL LINE CLAMPS. TAKE CALL FROM ADW TO DECIDE WHAT PRESSURE TO LEAVE ON THE TRSV VALVE. WRAP CONTROL LINE AROUND HANGER NECK AND PROTECT 1/4". 1/4-TURN BALL VALVE WITH DUCT TAPE AND LEAVE 2500-PSI ON LINE, CLOSE VALVE AND M/U LANDING JOINT TO HANGER. P/U WT 185K-LBS, S/0 WT 108K-LBS. USE TUGGER LINE TO CENRALIZE LANDING JOINT AND SLOWLY RIH TO SET HANGER. TAGGED STUB AT 17.738' AND LEFT THE BOTTOM OF THE UNIQUE MACHINE OVERSHOT AT 17,742.5'. FMC RILDS TORQUED TO 450-FT-LBS. M/U CIRCULATING LINE TO TUBING FINISH R/U AND TESTING LIL RED EQUIPMENT AND LINES AND PREPARE TO REVERSE CIRCULATE 10.3-PPG COMPLETION FLUID. PJSM WITH LIL RED CREW, VAC TRUCK DRIVERS, RIG CREW, AND WSL TO DISCUSS THE REVERSE CIRCULATION PROCEDURE AND JOBS ASSOCIATED Printed: 9/29/2009 11:37:22 AM ~ ~ BP EXPLORATION Page 15 of 17 Qperations Summary Report Legal Well Name: NK-09 Common Well Name: NK-09 Spud Date: 11/1/1994 Event Name: WORKOVER Start: 9/1/2009 End: 9/20/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/20/2009 Rig Name: DOYON 16 Rig Number: 16 Date; From - To Haurs Task Code NPT Phase Description of Operations s 9/18/2009 09:00 - 10:00 1.00 RUNCO P 10:00 - 12:00 I 2.00 ~ RUN 12:00 - 22:00 I 10.00 22:00 - 00:00 I 2.001 RU 9/19/2009 I 00:00 - 01:00 I 1.00 01:00 - 02:30 I 1.50 RUNCMP WITH THE OPERATION. FLOORHAND REVIEWED THE MSDS PPE REQUIREMENTS FOR THE EC-1124A CORROSION INHIBITOR. THE WSL ASKED EVERYONE TO MAKE SURE THEY ADHERED TO THE PPE REQUIREMENT AND ALSO TO MAKE SURE THAT THERE WAS ADEQUATE VENTILATION IN THE HOPPER ROOM WHERE THE CI WOULD BE PUMPED FROM DRUMS. THE DERRICKMAN DESCRIBED THE PPE HE WOULD BE WEARING WHILE CHANGING OUT DRUMS. RUNCMP REVERSE CIRCULATE 900-BBLS OF f20-F 1Q.3-PPG BRINE MIXED ON THE FLY WITH 25-GALS/100-BBLS OF EC-1124A CORROSION INHIBITOR. VERIFIED THAT A RABBIT OF 3.833" WAS RUN THROUGH THE HANGER AND THE LANDING JOINT. THE MAX METAL OD OF THE HACPA PACKER SETTING TOOL IS 2.5" AND THE MAX OD OF THE SWAB CUPS IS 4.210". TEST LIL RED DISCHARGE LINE TO 3500-PSI. START CHARGE PUMP TO SUPPLY LIL RED AND PRESSURE IS TOO HIGH FOR THEIR SUCTION. STOP CHARGE PUMP AND LET GRAVITY FEED THE LIL RED PUMP. LIL RED PUMP IS HAPPY WITH 1.5-BPM AND 800-PSI DISCHARGE; IA PRESSURE IS 550-PSI. BAKER COMPLETIONS REP WANTS IA PRES TO STAY BELOW 800-PSI. 1130-HOURS, LOSE RETURNS WITH LIL RED DISCHARGE PRESSURE INCREASING TO 1050-PSI AND IA TO 800-PSI; CONTINUE PUMPING FROM 40-BBLS TO 53-BBLS AWAY AND SHUT-DOWN AT 1145-HOURS. CALL ADW ENGINEER AND DISCUSS POSSIBILITY OF TRSV CLOSING. RUNCMP DISCUSS PROBLEM WITH HALLIBURTON REPS ONSITE AND DECIDE THAT WE'LL NEED TO P/U ON THE HANGER TO CLEAR THE U/M OVERSHOT ABOVE THE STUB AND ATTEMPT TO CIRCULATE BEFORE WE PULL THE HANGER TO THE FLOOR TO CHECK PRESSURE ON THE CONTROL LINE. WHILE WAITING ON FMC REP TO ARRIVE TO BOLDS, RESTART LIL RED TO KEEP 1/2-BPM HOLE-FILL, AND SEE RETURNS SHORTLY THEREAFTER. INCREASE LIL RED TO 1-BPM AT IA PRES OF 250-PSI, GETTING GOOD RETURNS. INCREASE LIL RED TO 1.5-BPM AND IA PRES OF 350-PSI WITH GOOD RETURNS. 1230-HOURS, 83-BBLS PUMPED AT 650-PSI LIL RED DISCHARGE, 350-PSI IA PRES, AND 112-F. CONTINUE PUMPING WITH NO CHANGE IN PRESSURES OR TEMPERATURE. RUNCMP LRS BEGIN PUMPING 290-BBLS OF HEATED 10.3-PPG BRINE WITHOUT CORROSION INHIBITOR DOWN THE IA. PUMP AT 1.5-BPH, 650- PSI LIL RED DISCHARGE, 350-PSI IA PRES, 120-F. RUNCMP CONTINUE PUMPING THE REMAINING 90-BBLS OF 290-BBLS OF 10.3-PPG BRINE WITHOUT ANY CORROSION INHIBITOR DOWN THE IA. PUMP AT 1.5-BPH, 650- PSI LIL RED DISCHARGE, 350-PSI IA PRES, 120-F. MAINTAIN HOLE FILL WITH 9-BPH LOSS RATE. RUNCMP CIRCULATE PITS THROUGH LIL RED TO BRING BRINE Printed: 9/29/2009 11:3722 AM • ~ BP EXPLORATIQN Page 16 of 17 Operations Summary R~port Legal Well Name: NK-09 Common Well Name: NK-09 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours Task Code NPT 9/19/2009 01:00 - 02:30 1.50 RUNCO P 02:30 - 03:00 0.50 RUNCO P 03:00 - 11:30 8.50 RUNCO P 11:30 - 15:00 3.50 RUNCO Spud Date: 11/1/1994 Start: 9/1 /2009 End: 9/20/2009 Rig Release: 9/20/2009 Rig Number: 16 Phase ' Deseription of Operatians RUNCMP TEMPERATURE FROM 100-F TO 120-F. CIRCULATE AT 200-PSI ON LIL RED DISCHARGE, 1-BPM. 0230 HRS. INADEQUATE PRESSURE TO HEAT FLUID AT A REASONABLE RATE. RUNCMP -MADE DECISION TO RE-RIG UP LIL RED FROM SUCTION ON CHARGE PUMP #1 AND TO DISCHARGE TO THE RIG FILL UP LINE. -MAINTAIN HOLE FILL DOWN THE TUBING AND IA WITH CHARGE PUMP #2. CYCLING PUMP EVERY 30 MIN TO FILL HOLE WITH 5-BBL EACH CYCLE. -hiELD PJSM AND MADE SURE THAT EVERYONE INVOLVED IN THE CHANGE IN FLUID LINEUP UNDERSTOOD TASKS OF CHANGING LINES AROUND AND THE IMPORTANCE OF TAKING TIME TO MAKE SURE THAT WE DID NOT HAVE A SPILL. MADE CHANGES TO LINES AND RESUME OPERATIONS. RUNCMP -USE LIL RED HOT OILER PUMP TRUCK TO CIRCULATE FROM THE PITS WITH A STARTING TEMPERATURE OF 80-F AND BRING IT UP TO 120-F WITH 150-PSI DISCHARGE PRESSURE @ 1.0-BPM. -MAINTAIN HOLE FILL DOWN THE TUBING AND IA WITH CHARGE PUMP #2; CYCLING PUMP EVERY 30-MIN TO - FILL HOLE WITH 5-BBLS PER CYCLE. -0830-HOURS, INLET TEMPERATURE TO LIL RED HEAT EXCHANGER IS 115-F, OUTLET IS 130-F. -0845-HOURS, COfVDUCT MAfV-DOWN DRILL ON RIG FLOOR; HOLD AFTER-ACTION REVIEW. -1130-HOURS, PIT #3 AT 120-F; PITS 1, 2, AND 4 AT 116-F. CALL ADW ENGINEER AND DISCUSS; DECIDE TO PROCEED WITH INSTALLING HACPA TOOL AND PUMP IT DOWN HOLE. -CREW CHANGEOUT. RUNCMP -HOLD PJSM WITH DAY-TOUR CREW, BAKER TECH, AND WSL TO DISCUSS THE HACPA TOOL LOADING AND PUMPDOWN PROCESS. IT IS THE FIRST TIME T E R HAS EVER USED THIS TOOL SO THE BAKER TECH AND WSL EXPLAINED ITS INTENDED USE TO THE CREW. -BREAK OFF CIRCULATING HEAD AND TIW VALVE; P/U AND INSTALL THE HACPA TOOL IN TUBING STUMP AND THE SWAB CUPS ARE STIFF ENOUGH TO ALLOW THE TOOL TO BE PUSHED INTO THE STUMP, YET S~OP IT WHEN APPLIED FORCE IS STOPPED. -1220-HOURS, INSTALL CIRC HEAD AND TIW VALVE AND START PUMPING, BRINGING PUMP UP TO 3-BPM AT 620-PSI. -1235-HOURS AND 400-STROKES, HACPA PASSES THROUGH TRSV WITH NO INDICATION ON CHART OF OBSTRUCTION TO MOVEMENT. -1240-HOURS AND 644-STROKES, HACPA PASSES THROUGH GLM #5, NO OBSTRUCTION. -1255-HOURS, 1120-STROKES, NO OBSTRUCTION THRU GLM #4. -1303-HOURS, 1374-STROKES, GLM #3, SMOOTH SAILING Printed: 9/29/2009 11:37:22 AM ~ • BP EXPLORATIQN Page 17 of 17 Operations Sumrnary Report Legal Well Name: NK-09 Common Well Name: NK-09 Spud Date: 11/1/1994 Event Name: WORKOVER Start: 9/1/2009 End: 9/20/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 9/20/2009 Rig Name: DOYON 16 Rig Number: 16 Date ' From - To Hours Task Code NPT Phase Description of Operations 9/19/2009 11:30 - 15:00 3.50 RUNCO P RUNCMP -1327-HOURS, 1954-STROKES, GLM #2, SMOOTH SAILING. -1350-HOURS, 2475-STROKES, GLM #1, SMOOTH SAILING. -1420-HOURS, 3151-STROKES, RHC-M PLUG AND SEE PRESSURE CLIMB TO 2500-PSI,. -1425-HOURS, S/D PUMP TO TIGHTEN UP TIW VALVE CONNECTION TO TUBING. BRING PUMP ONLINE AND GET TO 2000-PSI AND CONNECTION CONTINUES TO LEAK. -1430-HOURS, DECIDE TO PULL LANDING JOINT AND CLOSE BLINDS TO CONTINUE THE PACKER SETTING. -1450-HOURS, PRESSURE UP TUBING TO 4000-PSI AND HOLDS SOLID FOR 30 RECORDED MINUTES. -1425-HOURS, BLEED OFF TUBING TO 1500-PSI. -1430-HOURS, PRESSURE UP ON THE IA TO 4100-PSI AND HOLDS JUG TIGHT FOR 30-RECORDED MINUTES. -1500-HOURS, BLEED OFF PRESSURE AND PREPARE TO SET TWC FOR N/D BOPE. 15:00 - 17:00 2.00 WHSUR P RUNCMP FMC P/U TWC AND DRY-ROD INTO TUBING HANGER. -TEST TWC FROM THE TOP TO 4000-PSI FOR 10-CHARTED MINUTES. GOOD TEST. 17:00 - 22:00 5.00 WHSUR P RUNCMP PJSM HELD ON ND BOP. -ND BOP STACK. 2 BARRIERS FOR ND ARE 1) BALL & ROD ON SEAT W/ KWF ABOVE AND 2) TESTED TWC. -RD RIG FLOOR. & PREP TOP DRIVE TO LD DERRICK. - RD KILL HCR VALVE. -RD #2 PUMP & 3516 MOTOR MODULES. 22:00 - 00:00 2.00 WHSUR P RUNCMP NU AND TEST ADAPTER FLANGE AND TEST TO 5000-PSI FOR 30-MIN. TEST GOOD. -TORQUE BOLTS TO 2,750 FT-LBS USING SWEENEY WRENCH. 9/20/2009 00:00 - 02:00 2.00 WHSUR P RUNCMP PJSM HELD FOR NU TREE. -NU TREE. -TEST TREE WITH DIESEL TO 5000-PSI AND HOLD FOR 5-MIN. GOOD TEST. 02:00 - 03:00 1.00 WHSUR P RUNCMP RU LUBRICATOR AND TEST TO 500-PSI. GOOD TEST. -PULLTWC. 50 PSI ON WELL. -RD LUBRICATOR 03:00 - 03:30 0.50 WHSUR P RUNCMP RU TO BLEED DOWN PRESSURE FROM TUBING. -OPEN TRSV WITH 5000-PSI ON CONTROL LINE. NO PRESSURE BELOW TRSV. -TEST CONTROL LINE TO 5000-PSI FOR 10-MIN. GOOD TEST. -BLEED CONTROL LINE TO 0-PSI AND CLOSE TRSV. - BLOW DOWN LINES. 03:30 - 04:30 1.00 WHSUR P RUNCMP RU LUBRICATOR. -SET TWC IN TUBING HANGER. -PRESSURE TEST TWC TO 1000-PSI FOR 10-CHARTED MIN. GOOD TEST 04:30 - 05:00 0.50 WHSUR P RUNCMP -INSTALL WELLHEAD / TREE GAUGES. SECURE WELL. -RELEASE RIG AT 0500-HOURS. Printed: 9/29/2009 11:37:22 AM TREE~ 4 1/16" -5M CNV WELLHEAD = 13-5/8" 5M FMC GEN II ACTUATOR = BAKER KB. ELEV - 60.2' BF. ELEV - _ 19.6' KOP = . 2500' Max Angle = 76 @ 10160' Datum MD = 18409' Datum N D= 9200' SS 9-518" CSG: 47#, L-80, HYQF2EL 583, IC} = 8.681" 3417~ 13-3/8" CSG, 68#, NT-80 CYHE, ID = 12.415" 4426~ Minimum ID = 3.725" @ 17912' 4-1/2" HES XN NIPPLE ~ NK-09 ~RLV DRAFT TOP OF 7" LNR ~-1 13849~ ~ SAFET TES: X NIPPLE IS 70' BELOW GLM #2. '"'* 5" M E LNR **" WElL ANGLE> 70° @ 7717'*** 2217' 4-1/2" Wellstar TRSSSV 337Q' HaEco 9-5J8° E5 Cerr~nter 3393' 9-518" Baker ECP 3d15' 9-518" Casing Stub 34"18` 9-518'" Bowen Casing Patch GAS LIFf MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3577 3489 34 MMG DOME RK 16 09/26/09 4 6225 5403 45 MMG DOME RK 16 09/26/09 3 7634 6228 68 MMG SO RK 32 09/26/09 2 10861 7046 75 MMG DMY RK 0 09/18/09 1 13754 7797 75 MMG DMY RK 0 09/18/09 13849~ TIEBACK SLV w/ 6' IXTENSION, ID = 7.5Q" 13857' 9-5/8" X 7" BKR TY PE "H" LTP, ID = 6.313" 13863~ 9-5/8" X 7" BKR FLIX LOCK HGR, ID = 6.188" 9-5/8" CSG, 47#, NT-80 NSCC, ID = 8.681" ~-i 14009~ 4-1/2" TBG, 12.6#, 13CR-85 VAM TOP I 17735~ .0152 bpf, ID = 3.953" 4-1/2" TUBING CUT (08/19/09) ~-~ 17775~ TOP OF 5" LNR ~~ 17912' ~ 4-1/2" TBG, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.953" ~ 7" LNR, 29#, NT-80S NSCC, .0371 bpf, ID = 6.184" ~~ 18072~ PERFORATION SUMMARY REF LOG: SWS CDR ON 11/29 & 12/5/94 ANGLE AT TOP PERF: 64° @ 18008' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 18008 - 18064 O 01/01/95 3-3/8" 6 18078 - 18148 O 01/01/95 3-3/8" 6 18162 - 18306 O 01 /01 /95 I ~aTD I 17~ 64Q' I 1767'N ° 177Q4' ~ 17750' 17816' 1a-~~~~~ x N~~ ~, ~~=s.$~s~° ~ 7" X 4-1!2" flKF2 S-3 ~{R, ID = 3.875" 4-1l2°' X NIF'PLE, ID = 3.813,~ 9-51&" X 4-1l2" UNEQUE OVERSH{3T 4-1/2" HES X NIP, ID = 3.813" ' 17837~ -~7" X 4-1/2" BKR S-3 PKR, ID = 3.875" ~& KBH-22 ANCHOR SEAL ASSY 17912~ 4-1/2" HES XN NIP, ID = 3.725" 17913~ 7" TIEBACK SLV, ID = 4.438" 17921 ~ 7" X 5" BKR LTP w/ LNR HGR, ID = 4.434" 17924' 4-1/2" WLEG, ID = 3.958" 17931 ~ ELMD TT LOGGED 03/27/95 I 18485' I ~ 5" LNR, 15#, KO, 13CR-80 STL,.0189 bpf, ID = 4.408" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 01/04/95 POOL 7 ORIGINAL COMPLETION 09/20/09 D16 RWO 09/24/09 PJC DRLG HO CORRECTIONS 10/03/09 BSE/SV GLV C/O (09/26/09) NIAKUK UNff WELL: NK-09 PERMIT No: ~1941400 API No: 50-029-22518-00 SEC 36, T12N, R15E, 1281' FSL & 1073' FEL BP 6cploration (Alaska) • • ~ ~ ~ ~~ ~~ ~ ,~, _ ~. SEAN PARNELL, GOVERNOR ~~ ~ ~ 1~~ Mr. David Reem Engineering Team Leader BP Exploration (Alaska) Inc. - h P.O. Box 196612 ~, '~ ~ ~"t~ Anchorage, Alaska 99516-6612 ~~ ~ Re: Prudhoe Bay Field, Niakuk Pool , PBU NK-09 Sundry Number: 309-264 , ; , ~ ~ - ~~ ~s r r~~~,. i.v~,,s~::`~:iEw :.~ ~ .r ~.~ :4. t~ ~:~~~.~::f Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days af~er written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this ~! day of August, 2009 Encl. /~~ STATE OF ALASKA ~-p "` ~.0~ AIA~OIL AND GAS CONSERVATION COM11~ION ~~O` ~' APPLICATION FOR SUNDRY APPROVAL ~' 2o aAC 2s.2so . ~ e -~9 ~~~~~~~~~ ~1~~. ~ ~ 2(~Q9 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^'~~~~h~io~~~ ~~~~~. ~~~~ISSI~ ~ Alter Casing . ~ Repair Well ~^ Plug Perforations ^ Stimulate ^ Re-Enter Sus~~~F~l ^ Change Approved Program ~ Pull Tubing ~^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. -~ Development ^ Exploratory 194-140 ~' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22518-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU NK-09 ' Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): - ADL 034625- 60.20' ~ Prudhoe Bay Field / Niakuk Pool 12~ PRESENT WELI CONDITION SUM MARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 18570, 9340, 18484 9297 N/A N/A Casin Len th iz MD TVD B rs Coll s Structural n r 80' 2" 11 ' 11 ' 15 0 Surface 4385' 13-3/8" 4426' 4132' 020 2270 Intermediate Pr ion 1 971' -/" 14 7 2' 7 47 Liner 4223' 7" 13 4'- 1 072' 7821' - 9102' 81 0 7020 Liner 657' 5" 17913' - 18570' 9033' - 9 8290 7250 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 18008' - 18306' 9074' - 9210' 4-1 /2", 12.6# L-80 17924 Packers and SSSV Type: 7" x 4-1/2" BKR S-3 packer Packers and SSSV MD (ft): 17837' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ' ^ Exploratory ~ Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: August 25, 2009 ~ Oil ~ ^ Gas ^ Plugged ^ Abandoned 17. Verbal ApprovaL Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mackie Derrick, 564-5891 Printed Name avid Reem Title Engineering Team Leader ~ Prepared By Name/Number: Signature Phone 564-5743 Date ~ j~ Q Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: ~ q Conditions of approval: No ify Commission so that a representative may witness ^ Plug Integrity L~'BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other. ~-(~Ot~~ ~~lA ~eSJ Z Soo~ ~I ~-•,,~..~. T~~ Subsequent Form eq ired: 7() ~ 5/ p t~/ APPROVED BY Q`~~ A roved B: COMMISSIONER THE COMMISSION Date (> Form 10-403 Re~d~06/~006 ~,%' ORIGINAL ~ _ ~~~ ~t~:~~~~~~~ Submit In Duplicate . ~~~:~~-~~. ~,~. P- Y- o q • • ~ ~ ~ ~~ ~ ~~ NK-09 Expense Rig Workover / Scope of Work: Repair Surface Casing Leak: Pull 4-1/2" L-80 completion, cut and pull 9 5/8" casing, run and cement to 9-g/8" surface casing, run 4-~/2" L-80 stacker packer completion. MAASP: 3727 psi Well Type: Producer Estimated Start Date: Production Engineer: Intervention Engineer: August 25th , 2009 Bob Gerick Mackie Derrick Pre-Riq Work Reauest: S 1 Pull CSV at 17912' MD. Drift as dee as ossible. E 2 Set 4-1/2" HES composite plug at 17880' MD, in the middle of the first full joint below the packer. CMIT T x IA to 3500 psi. Jet cut the 4-1/2" tubing @ 17780' MD in the top of the first full 'oint above the Baker SABL acker. Reference tubin tall dated 01/02/1995. F 3 Circulate well with kill wei ht fluid and diesel thru the cut. W 4 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka e check one at a time . PPPOT-T & IC. W 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Pronosed Procedure: 1. MIRU workover rig Doyon 14. ND tree. NU 3 ram stack, Blind rams, VBR's 2-7/8" x 5-1/2", and VBR's 3-1/2" x 6" and test to 4000 psi/250 psi low. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-1/2", 12.6#, L-80 tubing string down to the cut. 3. Run 9-5/8" casing scraper to the tubing stub. 4. RU E-line, run USIT in 9-5/8" casing from the tubing stub to surface. 5. Set retrievable bridge plug 100' below the top of cement and pressure test to 3,500 psi for 10 min. 6. Cut and Pull 9-5/8" 47#, NT-80S surface casing. Note: Pipe rams will not be changed to 9-$/e" as the well has two tested barriers (FasDrill plug and RBP) to the reservoir. 7. Run and cement new 9-5/8" L-80 47# Hydril 563 casing to surface. 8. Drill out the ES cementer assembly. 9. Pressure test 9-5/8" casing to 3,500psi for 30 minutes. 10. Retrieve bridge plug. 11. Drill out FasDrill and push it to the bottom of the wellbore. 12. Run 4-~/2" 12.6#, 13Cr-80 completion with Baker S-3 packer. 13. Displace the IA to packer fluid and set the packer. 14. Test tubing and IA to 3500 psi. Freeze protect to 2000' TVD. 15. Set BPV. ND BOPE. NU and test tree. RDMO. TR~ _ 4" -5M qW ~ SA NOTES: X WIPPLE IS 70' BH.OW GLM #2. N K~O V ~~~ME LNR""` WE1L ANGLE> 70° @ 7717'*** C~ W~LHEAD = 13-5/8" 5M FMC GEN II ACTUATOR = BAK KB. E1EV = 60.2' BF. ELEV = 19.6' KOP = 2500' Max Angle = 76 @ 10160' Datum WID = 18409' Datum ND = 9200' SS 13-3/8" CSG, 68#, NT-80 CYHE, ~= 12.415" 442E Minimum ID = 3.725" @ 17912' 4-1/2" HES XN NIPPLE TOP OF 7" LNR 1384 9-5/8" CSG, 47#, NT-80 NSCC, ID = 8.681" H 14009' 2107' 4-1/2" TRSV, HES CR2 10 NIP, ID = 3.813" GAS LIFf MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3048 3021 23 HES LB SPRING RA 16 12/02/96 3 5673 5013 45 HES LB SPRING RA 16 12/02/96 2 6945 5888 52 HES LB SO RA 16 12/02/96 1 13777 7803 75 HES LB DMY RA 0 12/02/96 7016~ -14-1/2" HES X NIP, ID = 3.813" ~ 13849' TIEBACK SLV w/ 6' IXTENSION, ID = 7.50" 13857' 9-5l8" X 7" BKR TY PE "Ff' LTP, ID = 6.313" 13863' H 9-5/8" X 7" BKR FLIX LOCK HGR, ID = 6.188" 17816' 4-1 /2" HES X NIP, ID = 3.813" 17837~ 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" & KBH-22 ANCHOR SEAL ASSY ~7912' 4-1/2" HES XN NIP, ID = 3725" ' TOP OF 5° LNR 17912' II 17913~ 7" TIEBACK SLV, ID = 4.438" II 4-1/2" TBG, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.953• 17924' 17921' 7" X 5" BKR LTP w/ LNR HGR ID = 4.434" 17924' 4-1/2" WLEG, ID = 3.958" 7" LNR, 29#, NT-80S NSCC, .0371 bpf, ID = 6.184" ~ 807y 17931 ~ ~MD TT LOGGm 03/27l95 PERFORATION SUMMARY REF LOG: SWS CDR ON 11/29 & 12/5/94 ANGLEATTOPPEFiF: 64° @ 18008' Note: Refer to Production DB for historical perf data SIZE SPF IPffERVAL Opn/Sqz DATE 3-3/8" 6 18008 - 18064 O 01/01/95 3-3/8" 6 18078 - 18148 O 01/01/95 3-3/8" 6 18162 - 18306 O 01 /01 /95 ~ PBTD H 18485' f-- 5" LNR, 15#, KO, 13CR-80 STL,.0189 bpf, ID = 4.408" 18570~ DATE REV BY COMMENTS DATE REV BY CONNAE7YTS 01104/95 POOL 7 ORIGINAL COMPLEf10N 02/15/08 GWPJC DRAWING CARRECTIONS 09/23/05 ¢UTLH WANER SFfY NOTE D~ETm 09l08/06 CS/PJC ND/ MD DATUM CORRECTION 01/04l07 ??/TLH W~LHEADCORRECTION 01/29/08 RLW/SV GLV CORRECTIONS 02/10/08 ?/ PJC GLV/ DRAWING COW2ECTION NIAKUK UNff WELL: NK-09 PERMfT No: ~1941400 API No: 50-029-22518-00 SEC 36, T12N, R15E, 1281' FSL & 1073' F~ BP E~cploration (Alaska) TREE = 4" -5M CNV WELLHEAD = 13-5/8" 5M FMC GEN II A~TUATOR = BAKER KB. ELEV = 60.2' BF. ELEV = 19.6' KOP = 2500' Max Angle = 76 @ 10160' Datum MD = 18409' Datum ND = 9200' SS SAF TES: X NIPPLE IS 70' BELOW GLM #2. ~ N K~O V ~ 5'~OM E LNR *** WELL ANGLE > 70° @ 7717'*** • --~4-1/2" Wellstar TRSSSV Cement to Surface GAS LIFf MANDRELS 5/8" CSG, 47#, L-80, HYDRIL 563, ID = 8.681" 13-3/8" CSG, 68#, NT-80 CYHE, ID = 12.415" 4421 Minimum ID = 3.725" @ 17912' 4-1/2" HES XN NIPPLE I TOP OF 7" LNR I ~ 9-5/8" CSG, 47#, NT-80 NSCC, ID = 8.681" ~ TOP OF 5" LNR ~ 4-1/2" TBG, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.953" ~ ~ 7" LNR, 29#, NT-80S NSCC, .0371 bpf, ID = 6.184" ~ PERFORATION SUMMARY REF LOG: SWS CDR ON 11/29 8 12/5/94 ANGLE AT TOP PERF: 64° @ 18008' Note: Refer to PYOduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 18008 - 18064 O 01/01/95 3-3/8" 6 18078 - 18148 O 01/01/95 3-3/8" 6 18162 - 18306 O 01/01/95 PBTD ~-~ 1 ~ 5" LNR, 15#, KO, 13CR-80 STL,.0189 bpf, ID = 4.408" ~ ST MD TV D DEV lY PE V LV LATCH PORT DATE 5 3591 3500 4 6221 5400 3 7615 6221 2 10863 7000 1 13766 7803 13849~ 13857~ TIEBACK SLV w/ 6' IXTENSION, ID = 7.50" 9-5/8" X 7" BKR TY PE "H" LTP, ID = 6.313" 13863~ 9-5/8" X 7" BKR FLIX LOCK HGR, ID = 6.188" ~ 4-1/2" X NIPPLE, ID = 3.813" ~ 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" ~ 4-1/2" X NIPPLE, ID = 3.813" 9-5/8" X 4-1/2" UNIQUE OVERSHOT 17816~ 4-1/2" HES X NIP, ID = 3.813" 17837' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" & KBH-22 ANCHOR SEAL ASSY 17912~ 4-1 /2" HES XN NIP, ID = 3.725" 17913~ 7" TIEBACK SLV, ID = 4.438" 17921 ~ 7" X 5" BKR LTP w/ LNR HGR ID = 4.434" 17924~ 4-1/2" WLEG, ID = 3.958" 17931' ELMD TT LOGGm 03/27/95 DATE REV BY COMMENTS DATE REV BY COMMENTS 01/04/95 POOL 7 ORIGINAL COMPLETION 02l15/08 GR/PJC DRAWING CORRECTIONS 09/23/05 QL/TLH WANER SFTY NOTE DE1ETm 09/08/06 CS/PJC ND/ MD DATUM CORRECTION 01/04/07 ??/TLH WELLHEAD CARRECTION 01/29/08 RLW/SV GLV CORRECTIONS 02/10/08 ?/ PJC GLV/ DR4WING CORRECTION NIAKUK UNff WE1L: NK-09 P~2Mff No: ~1941400 API No: 50-029-22518-00 SEC 36, T12N, R15E, 1281' FSL & 1073' FEl BP Exploration (Alaska) • ~~L 6.~[~ ~• ProActive Diagnostic Services, Inc. A • To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 ~~~ ~ ~ ~ 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 following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and PrbActive Diagnostic Services; Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907) 245-6952 1) Leak Detectection - WLD 2&Dec-07 NK - 09 1 EDE 50.029-22518-00 2) _ ~ ~~. i ~, .~ ~ .« ,~ Signed : ~ ~ ~~ Date ~°`~ w `~ `~ ~G~~~ Print Name: ~~,(~i . ~ ~~ ~l ,, Q.~.r_ ia~~=~ ~a~, ' ~ ~ ~.. ~ ~~?i~~h~~°; PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-WAIL : pdsarechoraae(a~memorylog.com WEBSITE : www.memorylog.com D:\Master Copy_00_PDSANC-101ac~Z Word\Dishibution\Tmnsmittal Sheets\Transmit_Original_New.doc ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION a .or REPORT OF SUNDRY WELL OPERA 1!2~~ T 2 6 2004 1. Operations Performed: ""..,." 1","; I;.;i AbandonD Repair Well 0 PluQ PerforationsD Stimulate [&] mft~f~ge Alter CasingD Pull TubingO Perforate New Pool 0 WaiverD Time ExtensionO Change Approved ProgramD Operation ShutdownO Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development ŒJ 60.20 8. Property Designation: ADL-0034625 11. Present Well Condition Summary: Stratigraphic 0 9. Well Name and Number: NK-09 10. Field/Pool(s): Niakuk Field / Niakuk Oil Pool ExploratoryD Service D 5. Permit to Drill Number: 194-1400 6. API Number 50-029-22518-00-00 Total Depth measured 18570 feet measured 18484 feet true vertical 9297.5 feet Plugs (measured) Junk (measured) None true vertical 9340.4 feet Effective Depth None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 94# H-40 42 122 42.0 122.0 1530 520 Liner 4223 7" 29# NT80S 13849 - 18072 7821.3 - 9102.5 8160 7020 Liner 657 5" 15# 13CR80 17913 - 18570 9033.5 - 9340.4 8290 7250 Production 13971 9-5/8" 47# NT80S 38 - 14009 38.0 - 7862.2 6870 4760 Surface 4385 13-3/8" 68# NT80CYHE 41 - 4426 41.0 - 4131.7 5020 2270 Perforation depth: Measured depth: 18008 -18064,18078 -18148,18162 -18306 True vertical depth: 9074.37 - 9098.94, 9105.13 - 9136.52, 9142.88 - 9210.1 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 35 17924 Packers & SSSV (type & measured depth): 4-1/2" Baker SABL-3 Packer 4-1/2" HES CP-210 TRSV 5" Baker ZXP Liner Top Packer 7" Baker H Packer @ 17837 @ 2107 @ 80.ANNED NO\! n 3 2004 @ 13857 12. Stimulation or cement squeeze summary: Intervals treated (measured): 18008 - 18306 Treatment descriptions including volumes used and final pressure: 57 Bbls 50/50 DiesellXylene, 84 Bbls 90/10 DAD Acid @ 2405 psig Prior to well operation: Subsequent to operation: Oil-Bbl 1529 1239 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 1 3155 1900 0.9 3445 1780 Tubing Pressure 573 581 13 Copies of Logs and Surveys run- Daily Report of Well Operations. ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD DevelopmentŒ) Service D 14. Attachments: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Jd~c~ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Signature Phone 564-4657 Form 1 0-404 Revised 4/2004 n R , G \ ~~\ 'i "'c '."",,;' " , iØ)8AS BFL Date ~( a 7 lijW. 10/13/04 ) ) N K-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/23/04 CTU #5, FCO/ACID TREAT; MIRU DS CTU #5 ALONG WITH ASRC TEST SEPARATOR. RIH WITH 2.5" JSN. TAG HARD FILL @ 184411 CTMD (SL TAGGED @ 178531). CLEAN OUT FILL FROM LOW SIDE OF THE HOLE FROM 177501 TO 184631 CTMD USING SEVERAL FLOPRO SWEEPS. JETTED 55 BBLS OF 50/50 DIESEUXYLENE ACROSS PERF INTERVALS AND CHASED OUT OF HOLE. SWAP TO 3" SIDE JET NOZZLE. 09/24/04 CTU #5, ACID TREAT; CONI' FROM WSR 9/23/04... BLEED DOWN lAP. FLUID PACK WELL WITH 400 BBLS OF FILTERED 10/0 KCL. RIH WITH 3.0" SJN. TREAT PERFORATION INTERVALS WITH 84 BBLS OF 7.5% HCL WITH 10% XYLENE (90/10 DAD). ACID LOAD CAME OUT TO LOCATION SHORT. TREATING PRESSURE DROPPED ONLY 75 PSI OVER THE COURSE OF THE JOB. OVER FLUSH ACID WITH 50 BBLS OF FILTERED KCL. SAMPLE OF 1 % KCL OVERFLUSH WAS COLLECTED FOR WF ION ANALYSIS. POOH AND BLOW DOWN REEL FOR REEL SWAP. ASRC TO POP AND FLOW BACK ACID UPON CTU DEPARTURE. DSO NOTIFIED OF WELL STATUS - WING IS CLOSED, SSSV CONTOL LINES ARE BLOCKED IN. BBLS 1127 37 80 57 521 18 84 1924 FLUIDS PUMPED XS 1 % KCL 60/40 Methonal FloPro 50/50 Diesel/Xylene Filtered 1 % KCL 50/50 Methonal 90/10 DAD Acid TOTAL Page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor DATE: April 16, 2001 FROM: Jeff Jones, SUBJECT: Petroleum Inspector Safety Valve Tests Niakuk Field BPX PBU / Niakuk Pad A~3rii 16, 200~.: I traveled to the Niakuk Field to witness Safety Valve System tests on BPX's oil producing wells. Well house inspections were also conducted. The testing went well with Ron White as the BPX representative in charge of testing. 12 wells were tested with two failures witnessed. The pilot on NK-12A tripped below 50% of the separator pressure and was replaced and passed a retest. The SSV on NK-62 failed to hold D.P. and was stroked and passed a retest, i inspected 12 well houses and all were in order with no exceptions noted. The AOGCC test forms are attached for reference. SjUMMARY:,. I witnessed SVS tests on 12 oil producing wells in BPX's Niakuk Field. 12 wells tested, 36 components. 2 failures witnessed, 5.5% failure rate. 12 well houses inspected, no exceptions noted. ..Attachments,: SVS PBU Niakuk 4-16-01 JJ .c.c,; NON-CONFIDENTIAL SVS PBU Niakuk 4-16-01 JJ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Ron White AOGCC Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBU/Niak~ Field Separator psi: LPS 460 Date: 4/16/01 HPS Sss l ...... We~ Permit Separ Set L/P Test Test Test Date oil, waG, GIN J, Nnmber Number PSI PSI TOp Code Code Code Passed G~S or C¥CL~ ~qK207 1931590 ................ NK-08 1940950 466 '" 55'0' 3~0 P P "P ' OIL NK-09 1941400 460 350 340 P P P ' 0IL NK-12A 1940070 460 350 200 3 P P 4/16/01 OIL NK-i3 1961340 NK214 1960~60 460 350 '' 350 P P " P 0IL NK-18 1931570 ' NK-19 1941230 NK-20 19315'16'' 460 3sb 525 P ' e ...... ~ OIL NK-21' 1940860 460 '550 325 P "P '"e ...... OIL NK-22 'i931350 .................... ~'K-57 1950210 '460 '550 325 'P P .... P ' "OIL I~K-28 1960936 ..... NK'-59 1961'900 h6b 350 250 P ~" e .... OIL , , , , , , , ,,, ,_, , , , , _ , , , ,,, NK-34 1980850 NK-42 1941080 '' ~60" 350 340' P P e " 'OIL NK-6i .... 1981140 '" 4~0' '350 325 e e ~' e ...... OIL NKk62 1972560 460 '3~0 325 P 4 ...... P' 4/1~201 '0iL L6-26 1940050 460 350 350 'P" P e ......... OIL Wells: 12 Components: 36 Failures: 2 Failure Rate: 5.56% Fl90 var Remarks: Nm-12A pilot was replaced and passed retest on 4/16/01 NK-62 stroked valve and Passed retest on 4/16/01 L6- 26 is on the Niakuk Pad and drilled into the Lisburne formation. 12 well house inspections, no exc,,e, ptions:, RJF 1/16/01 Page 1 ofl SVS PBU Niakuk 4-16-01 JJ Og- ggFORg W c:LO~M 9.~.~ .... i~,~0 CPI/SI....IM GR /'ii 6680-- 'i 808 (l~ . .~%/I 8 I O0 ..... 18500 9 a--,- 9 a. - I a- 0 D G rS / E W R/: F X E ...,...1,~-'/i 5 ? a. S .... 'i 6 7 0 0 9 a...- 'i L,,. 0 Pi W D/,'£ R ! .... 'i 8 0.5 8 .... i 8 5 '? 0 'J 0 6/' J !~, / q ':: y e S I'h 0 A iq ,Ea 'l y s '¥ s & d (:} s c i"' '¥ IL')t '¥ o I't I" d} ,:::: c:- :i ",,/4:; (I Ai"e we'li 1:.es-ts r'equ'¥/ ..... ~c~' '>. yes Wel'i '¥s '¥n cornpi'i'ance ...... ~.4 i n i' 't: "m' ,a i C ;S, M H E N T S : e "i' v e d "? %sred n/ices rilling BP Exploration/Arco Date: To: June 25, 1996 Alaska Oil & Gas Conservation Commission From: Subject: Kathy Campoamor Technical Assistant 10-407 for Permit #94-140, NK-9 Due to a clerical error, the original Well Completion Report (10-407) was submitted with the incorrect surface location for NK-9. Additionally, the 'At Top Producing Interval' and 'At Total Depth' have been recalculated and corrected accordingly. Attached is a revised 10-407 and a copy of the As-Built for verification. The well history summaries and directional surveys have previously been filed with the Commission and there are no changes. I apologize for any inconvenience this may have caused. Thank you for your assistance in this matter, Kathy Campoamor /klc REVISED 06/24/96 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG · Status of Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] Classification of Service Well 2. Name of Operator BP Exploration (Alaska) Inc. 7. Permit Number 94-140 APl Number 5 O- 029-22518 3. Address P. O. Box 196612, Anchoraqe, Alaska 99519-661..2 4. Location of well at surface 1281' NSL, 1073' WEL, SEC. 36, T12N, R15E At Top Producing Intewal . 1402' NSL, 3829' WEL, SEC. 23, T12N, R15E At Total Depth 1857' NSL, 4017' WEL, SEC. 23, T12N, R15E 5. Elevation in feet (indicate KB, DF, etc.) KBE = 60.2' 6. Lease Designation and Serial No. ADL 034625 Unit or Lease Name 111o. Well Number NK-9 INiakuk Oil Pool 11/01/94 112/21/94 IOl/O4/95 N/A feet MSL I One 7. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 18570' MD/9340' TVD'1 18484' MD/9297' TVD '1 YES [] ~0 [] I 2107' feet MD 1800' (Approx.) 22. Type Electric or Other Logs Run DLL/TEMP/ZDL/CAL/CNL/GR/SP 23. CASING, UNER AND CEMENTING RECORD SE-FriNG DEPTH MD CASING SIZE ~N'['. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 30' 110' 30" 13-3/8" 68# NT8OCYHE 41' 4426' 16" 260 sx Arcticset (Approx.) 1383 sx PF "E"/375 sx "G" 9-5/8" 47# NT80S 38' 14009' 12-1/4" 425 sx Class "G" 7" 29# NTSOS 13849' 18072' 8-1/2" 730 sx Class "G" 5" 15# 13CR80 17913' 18570' 6" 132 sx Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Gun Diameter 3-3/8" 6 spf MD TVD 18008;18104! 9074;9117' 18078'-18148' 9105;9136' 18162'-18306' 9143;9210' 25. TUBING RECORD SIZE 4ll/2", L-80 DEPTH SET (MD) PACKER SET (MD) 17924' 17837' 26. ACID, FRACTURE, CEMENT SQUEF-ZF, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTIQN TEST Date First Production 02/11/95 Date of Test Hours Tested Flow Tubing Casing Pressure Press. 28. CORE DATA I Method of Operation (Flowing, gas lift, etc.) Flowing fODUCTION FOR OlL-BBL GAS-MCF IWATER-BBL ST PERIOD LCULATED . DIL-BBL IWATER-BBL -HOUR RATE ~ GAS-MCF I ICHOKE SLZE IGAS-OIL OIL GRAVITY-APl (corr) RATIO Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water· Submit core chips. ORIGINAL RECEIVED JUN 2 6 1996 Alaska 0Il & (~as Cons, Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MF_AS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea HRZ 17573' 8838' Kuparuk 1801 O' 9015' Kingak 18443' 9217' 31. LiST OF A-I-rACHMENTS , 32' I hereby~..~.,~,///~,~certifY that the foregoing~(~ . is 'true a~d c°rrect~, to the best of my knowledge E,~~,,~/~~___~~ Signed · ~ Title Senior Ddllina Enaineer Date - ,v - - / / INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. R E C E[V E D Item 28: If no cores taken, indicate "none". Form 10-407 JUN 2 ~ 1996 Alaska 0il & Ga~ Cons. Commissior~ Anchor,',,g0 LOCATED WITHIN PROTRACTED SEC. 56, T. 12 N., R. 15 E., U.M., AK. WELL A.S.P. PLANT GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION BOX ELEV. OFFSETS Y= 5,979,782.16 N/A 70'20'49.401" 1250' FSL 7 X= 721,440.24 N/A 148'12'08.054" 19.2' 1125 FEL Y25,979,798.60 N/A 70'20'49.555" 1266' FSL 8 X= 721,465..30 N/A 148'12'07.308" 19.1' 1099' FEL .Y= 5,979,814.59 N/A 70'20'49.705" 1281' FSL 9 X= 721,491.37 N/A 148'12'06.5-33" 19.0' 107,3' FEL Y= 5,979,8.30.55 N/A 70'20'49.855" 1297' FSL 10 X= 721,516.50 N/A 148'12'05.791" 19.1' 1047' FEL Y= 5,979,846.80 N/A 70'20'50.007" 1512' FSL 11 X= 721,541.89 N,/A 148'12'05.030" 19.1' 1021' FEL Y= 5,979,862.62 N/A 70'20'50.155" 1.327' FSL 12 X= 721,567.13 N/A 148'12'04.279' 18.9' 996' FEL Y= 5,979,878.55 N/A 70'20'50.304" 1342' FSL 1.3 X= 721,592.23 N/A 148'12'05.5.32" 19.1' 970' FEL Y25,979,894.64 N/A 70'20'50.455" 1358' FSL 14 X= 721,617.74 N/A 148'12'02.77.3" 19.1' 944' FEL Y= 5,979,910.87 N/A 70'20'50.607" 1.37`3' FSL 15 X= 721,643.06 N/A 148'12'02.019" 19.2' 918' FEL Y= 5,979,926.79 N/A 70'20'50.756" 1`388' FSL 16 X= 721,668.52 N/A 146'12'01.262" 19.t' 892' FEL Y25,979,942.60 N/A 70'20'50.904" 1403' FSL 17 X= 721,693.78 N/A 148'12'00.510" 19.2' 866' FEL Y= 5,979,958.43 N/A 70'20'51.055" 1418' FSL 18 X= 721,719.61 N/A 148'11'59.742" 19.5 840' FEL Y25,979,974.74 N/A 70'20'51.206" 1434' FSL 19 X= 721,744.78 N/A 148'11'58.993" 19.4' 815' FEL Y= 5,980,030.72 N/A 70'20'51.730" 1487' FSL 20 X= 721~8,35.51 N/A 148'11'56.553" 19.6 724' FEL , Y= 5,980,005.19 N/A 70'20'51.475" 1461 FSL 21 X= 721,849.`35 N/A 148'11'55.912" 19.4" 709' FEL Y= 5,979,979.87 N/A 70'20'51.221"' 14`35' FSL 22 X= 721,865.42 N/A 148'11'55.465" 19.2 694' FEL Y25,979,954.64 N/A 70'20'50.968" 1410' FSL 2.3 X= 721,881.44 N/A 148'11'55.018" 19.2 679' FEL y25,979,929.04 N/A 70'20'50.712" 1384' FSL 24 X= 721,897..30 N/A 148'11'54.577" 19.5 664' FEL Y= 5,979,916.27 N/A 70'20'50.584" 1371' FSL 25 X= 721,905.28 N/A 148'11'54.355" 19.3 656' FEL Y= 5,979,905.85 N/A 70'20'50.460" 1.358' FSL 26 X= 721,915.21 N/A 148'11'5,¢.134" 19.5 648' FEL y~ ~ F SURV1E PRUDHO~Z~A SAG 5 ~/~I T. 12N. T.11N. VICINITYNVlAP o ° °°°°°o ~°°°°°°°°°°°°°°°° SURVEYOR'S C£RTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF DATE OCTOBER 17, 1993. NOTES 1. DATE OF SURVEY: 9`/,28-50/95 & 10/17,/,95. 2. REFERENCE FIELD BOOKS: PB 93-43 (PGS. 39 THRU 53). PB 93-41 (PGS. 4.3 1-HRU 5.3). 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD27. 4. PAD SCALE FACTOR: 0.99995581 REF: CED-4400-11200 R.O 5. ELEVATIONS ARE ARCO DATUM M.L.LW. AND ARE BASED ON DRILL SITE L-5 MONUMENTS. 6. REFERENCE SHT. 1 OF 2 FOR THE CONDUCTOR LOCATIONS. 1 10/18/9.3 ORIGINAL AS-BUILT ISSUE DATE REVISIONS i°1 REV. RECEIVED JUN 2 ~ 1996 Alaska 011 & Gas Cons. CommissJor LF. R. BELL & ASSOCIATES BP EXPLORATION IDRA~NG NAME: WELL'S 7- 26 I I I OCT. 18, 1995 BARNHART MINISH I I I'c :-:2oo' Fc': I^F": NIAKUK-HEALD POINT CONDUCTOR AS-BUILTS IAJ~PROVAL: CADO FILE i: HPW~LLAB S)-IE~ l: REV~ 2o~2 0 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: NK-9 BOROUGH: NORTH SLOPE UNIT: LISBURNE FIELD: LISBURNE LEASE: API: 50 PERMIT: APPROVAL: ACCEPT: 10/31/94 05:00 SPUD: 11/01/94 07:00 RELEASE: OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 11/01/94 ( 1) TD: 110 PB: 0 11/02/94 ( 2) TD: 1780' (1780) 11/03/94 ( 3) TD: 4108' (2328) 11/04/94 ( 4) TD: 4438' ( 330) MU BHA MW: 0.0 MOVE RIG. NU DIVERTER SYSTEM & MIX MUD. CO 3.5" HEAD & SAVER SUB ON TOP DRIVE T/5". PU HWT DP & STND BACK IN THE DERRICK. PU BHA T/RIG FLOOR. MU BHA CHANGE STAB SLEEVES & MU BIT. DRILLING MW: 0.0 VIS: 0 MU BHA #1. ORIENT THE MOTOR W/MWD. RU DIVERTOR. FUNCTION TEST. WITNESS OF TEST WAIVED BY AOGCC REP: LOU GRIMALDI. ' FILL STACK, CHECK F/LEAKS. DRILL T/1780. DRILLING MW: 0.0 VIS: 0 HELD SFTH MTGS W/EACH CREW. TOPICS: REVIEW PRESPUD MTGS.; PINCH POINTS & HOUSEKEEPING AFTER RIG MOVE. DRLG T/3237. CBU. 100% ANNUL VOL. POOH T/1839. (SHORT TRIP 15 STNDS) AT TOP OF CHK TRIP INTERVAL. RIH T/3237. DRIL T/4108. RUN CASG MW: 0.0 VIS: 0 HELD SFTY MTGS. W/BOTH CREWS. TOPICS: STEAM & CLEAN ELEVATORS SO THE DP WON'T SNAG; HEADS UP WHEN THE DERRICKMAN IS HNDLNG THE DP SCREENS; BEING AWARE DETECTS POTENTIAL PROBLEMS; AWARENESS OF WINTER DRIVING CONDITIONS. DRLLED T/4438. REACHED PLANNED EOR/ SECTION TD. CBU. BLOW DN TOP DRIVE. OBSERVE WELL. 100% ANNUL. VOL. POOH T/3220. 13 STNDS. RIH T/4438. BLOW DOWN TOP DRIVE. OBSERVE WELL. OBTAIN 150% HOLE VOL. POOH T/222. PULL BHA. LD ALL STABS, LD DYNADRILL. RU T/RUN CASG, 13-3/8" OD. MU & PUMP THRU FLT EQUIP. RIH W/CASG T/3808. REC£iVED ~AR ;51 1995 At~ska ~J[l & Gag CoDs. Commission Anchor~ -. WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 2 11/05/94 (5) TD: 4438' ( 0) 11/06/94 (6) TD: 4438' ( 0) 11/07/94 ( 7) TD: 4438' ( 0) RUN CSG MW: 0.0 VIS: 0 RAN CSG TO 4426'. HANGER LANDED. CIRC AT 4426'. OBTAINED CLEAN RETURNS - 200% HOLE VOLUME. TESTED HIGH PRESSURE LINES. PRESSURE TEST COMPLETED SUCCESSFULLY - 3500 PSI. PUMPED SPACERS - VOLUME 50 BBL. REQUIRED VOLUME OF SPACER PUMPED. WATER. MIXED AND PUMP SLURRY - 534 BBL. LEAD. LEAD CMT PUMPED. MIXED AND PUMPED SLURRY - 77 BBL. TAIL CMT PUMPED. DISPLACED SLURRY - 644 BBL PLUG BUMPED 2000 PSI. RIGGED DOWN CMT UNIT. WORK COMPLETED, EQUIP LAID OUT. CIRC AT 120'. OBTAINED CLEAN REUTRNS - 300% HOLE VOLUME. MIXED AND PUMPED SLURRY - 30 BBL. LEAD CMT PUMPEED. RIGGED DOWN DIVERTOR. WORK COMPLETED, EQUIP LAID OUT. INSTALLED CSG SPOOL. EQUIP WORK COMPLETED. M/U STARTING HEAD. RIGGED UP BOP STACK. WORK COMPLETED - BOP STACK IN POSITION. TESTED BOP STACK. PRESSURE TEST COMPLETED SUCCESSFULLY - 5000 PSI, 250 PSI LOW AND 5000 PSI HIGH. INSTALLED WEAR BUSHING. EQUIP WORK COMPLETED, RUNNING TOOL RETRIEVED. MADE UP BHA %2. SHALLOW TEST MWD. RIH TO 4342'. AT FLOAT COLLAR. CIRC AT 4342' MUD VERY THICK. CIRC AT 4342' MW: 0.0 VIS: 0 CIRC AT 4342'~ OBTAINED REQ'D FLUID PROPERTIES - 100%, HOLE VOL. TESTED CSG. PRESSURE TEST COMPLETED SUCCESSFULLY - 3000 PSI. DRILLED CMT TO 4448'. DRILLED F/C, CMT, F/S & 10' NEW HOLE TO 4448'. AT 13-3/8" CSG SHOE. CIRC AT 4448'. OBTAINED CLEAN RETURNS - 200% HOLE VOLUME. PERFORMED FORMATION INTEGRITY TEST. OBTAINED LEAK OFF 13.9 PPG EMW. DRILLED TO 5405'. FIGHTING CLAY BALLS. FLOW LINE AND POSSOM BELLY PLUGING. JETTING LFOW LINE W/AIR AND FRESH WATER. 2-1/2 HRS TOTAL TIME. STARTED SCHEDULED WIPER TRIP: DUE TO FOOTAGE DRILLED. CIRC AT 5405'. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). POOH TO 4400'. AT 13-3/8" CSG SHOE. SERVICED BLOCK LINE CUT 90' LINE SLIPPED AND CUT. SERVICED TOP DRIVE. ADJUST BRAKES. EQUIP WORK COMPLETED. RIH TO 5405'. ON BOTTOM. DRILLED TO 5553' DRILLED TO 6475' MW: 0.0 VIS: 0 DRILLED TO 6475'. REACHED PLANNED END OF RUN - DIRECTIONAL OBJECTIVE MET. CIRC AT 6475'. OBTAINED CLEAN RETURNS - 125% HOLE VOLUME. POOH TO 5381' AT TOP OF CHECK TRIP INTERVAL. RIH TO 6475'. ON BOTTOM. CIRC AT 6475' · OBTAINED CLEAN RETURNS - 200% HOLE VOLUME. CONT TO CIRC AND R/U WESTERN ATLAS WIRE LINE AND GYRODATA GYRO. RIH TO 6316' ON. BOTTOM. TOOK BYRO MULTI-SHOT W/LINE SVY. MOVING PIPE BETWEEN GYRO SETS. HOLE IN GOOD CONDITION. ~X~ 3 '~ 1995 Gas Cons. Commission Anchor~ WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 3 11/08/94 (8) TD: 4438' ( 0) 11/09/94 ( 9) TD: 7938' (3500) 11/10/94 (10) TD: 8537' ( 599) 11/11/94 (11) TD: 9243' ( 706) WELLBORE SVY MW: 0.0 VIS: 0 TOOK GYRO SVY MULTI-SHOT W/LINE SVY. ACCEPTABLE SVY OBTAINED AT 6361' RIGGED DOWN SVY WIRELINE UNIT. WORK COMPLETED, EQUIP ~AID OUT. CIRCA T6475'. OBTAINED CLEAN RETURNS - 150% HOLE VOLUME. POOH TO 241' PULLED BHA. CHANGE OUT JARS, MWD. P/U L/C & DC. CHANGE BIT. SERVICE WEAR RING. CHECK MWD AND MTR. MADE UP BHA #3. RIH TO 4366'. AT 13-3/8" CSG SHOE. SERVICED TOP DRIVE. EQUIP WORK COMPLETED. RIH TO 6475'. ON BOTTOM. BENCH MARK SVY @ 5885'. DRILLED TO 7101' POOH MW: 0.0 VIS: 0 DRILLED TO 7231' LINER'FAILED - WORK STRING. PUMP LINER. SERVICED LINER. WORK COMPLETED, LINER CHANGED OUT. DRILLED TO 7468' STARTED SCHEDULED WIPER TRIP: DUE TO FOOTAGE DRILLED. CIRC AT 7468' OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). POOH TO 6391'. AT TOP OF CHECK TRIP INTERVAL.- HOLE IN GOOD SHAPE. RIH TO 7468'. ON BOTTOM. DRILLED TO 7581'. LINER FAILED - WORK STRING. CIRC W/1 PUMP. SERVICED LINER. WORK COMPLETED, LINER CHANGED OUT. DRILLED TO 7604', LINER FAILED - CIRC. WASH OUT IN #1 DISCHARGE LINE (IN UNION) WORK PIPE. SERVICED HIGH PRESSURE LINES. CHANGE LINER IN #1 PUMP. WORK COMPLETED, HIGH PRESSURE LINES CHANGED OUT. DRILLED TO 7879'. SVY . INSTRUMENTS FAILED - END BHA RUN. CIRC AT 7879' OBTAINED CLEAN RETURNS - 120% HOLE VOLUME. PUMP HI VIS SWEEP. POOH TO 6441'. OBSERVE WELL 10 MIN. PRIOR TO POOH. DRILLED TO 8478' MW: 0.0 VIS: 0 POOH TO 219'. PULL 10 STDS WET. PUMP DRY JOB. OBSERVE WELL 10 MIN. POOH TO SHOE. OBSERVE WELL. L/D HWDP. AT BHA. PULLED BHA. CHANGE BIT, MWD, DROP L/C. SERVICE WEAR RING. SURFACE TEST MWD AND MTR. BHA STOOD BACK. BHA #4 MADE UP. RIH TO 4366'. AT 13-3/8" CSG SHOE. SERVICE TOP DRIVE. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. RIH TO 7879'_ PRECAUTIONARY RAM 7804-7938'. RETAKE LAST 3 SVYS. ON BOTTOM. BENCH MARK SVY @ 5887' DRILLED TO 8478' DRLG MW: 0.0 VIS: 0 DRILLED TO 8894'. STARTED SCHEDULED WIPER TRIP: DUE TO FOOTAGE DRILLED. CIRC AT 8894' OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). POOH TO 5846'. BENCHMARK SVY. ACCEPTABLE SVY OBTAINED AT 5846'. RIH TO 8894' ON BOTTOM. DRILLED TO 9029' PISTONS FAILED - CIRC. WITH #1 PUMP. SERVICED PISTONS. CHANGE SWAB IN #2 PUMP. EQUIP WORK COMPLETED. DRILLED TO 9202'. RECEIV£D ~VlAfi 3 1 1995 Oil & 6as Cons. Commissio~ Anchor~: WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 4 11/12/94 (12) TD: 9494' ( 251) 11/13/94 (13) TD:10300' ( 806) 11/14/94 (14) TD:10915' ( 615) 11/15/94 (15) TD:ll152' ( 237) 11/16/94 (16) TD:l1960' ( 808) RIH T/BYYM MW: 0.0 VIS: 0 DRILLED T/9453. ROP DROPPED F/40 FT/HR T/10 FT/PH. BIT QUIT.CBU @ 9453. RECOVER 150% HOLE VOL. POOH T/259. PULLED BHA CHANGE OUT MWD. LD 2 STABS. BHA STOOD BACK. TEST WELL CONTROL EQUIPMENT. BOP STACK, PULL WEAR RING. TEST CHOKE & BOP EQUIP. PRESS TEST T/5000. OK. MU BHA #5, RIH T/2559. SHALLOW TEST MWD & MOTOR. H2S ALARM SOUNDED. SHUT WELL IN. EVACUATED. T/PUSHER, RIG REP; DRILLER & PIT WATCHER RE-ENTERED RIG W/PROPER PPE EQUIP. FOUND SENSORS & SHAKERS WERE BAD, THERE WASN'T ANY EVIDENCE OF H2S. OPEN FLOW CHK & TEST FOR H2S. ELECTRICIAN REPLACED SENSOR. CREW HAD SFTY MTG. RIH T/9453. DRILLING MW: 0.0 ViS: 0 RIH T/9453. DRIL T/10102. PISTONS FAILED. CBU. SERV. PISTONS. CHANGE SWAB IN #1 PUMP. PUT PUMP ON LINE. LUBE OIL PUMP SHORTED OUT. TROUBLE SHOOT ELECTRICAL PROBLEM IN LUBE OIL PUMP. POOH T/9453. RIH T/10101. WORK ON LUBE OIL PUMP #1. CBU OBTAINED CLEAN RETURNS .75&% OF HOLE VOL. DRILLED T/10259. DRILLING MW: 0.0 VIS: 0 DRILING T/10721. PISTON FAILURE, CBU. SERV. PISTONS. CHANGE SWAB 92 PUMP. WORK COMPLETED. PISTONS CHANGED OUT. DRILLED T/10874. DRILLING MW: 0.0 VIS: 0 HELD 2 SFTY MTGS: DAY CREW TOPIC: CONJESTED WORK AREA. NIGHT CREW TOPIC: FOCUS ON SFTY. DRLG T/10968. ROP DRIPPED F/40 T/20 FPH. BIT QUIT. CBU @10968. OBTAINED 150% HOLE VOL. ON RETURNS. POOH T/300. PULL BHA REMOVE WEAR BUSHING SERV. THE WEAR RING. RU1ETRIEVE RUNNING TOOL. MU BHA #6. SHALLOW TEST MWD RIH T/4400. SERV. BLOCK LINE CUT 102' OF DRILLING LINE. RIH T/10968. BENCH MARK SURV. @5889. PU 36 JTS. SL35 DP WASH & REAM 90 T/BTTM. DRILLED T/11152. DRILLING MW: 0.0 ViS: 0 DRILLED T/11954. HAD DRILLING BREAK OF +/- 115' PER HR. ON LAST CONNECTION. DRILLED 7'. SWAB WENT OUT ON #2 PUMP. HOLE IMMEDIATELY GOT STICKY. REPAIR PUMP & CIRC. PUT BOTH PUMPS ON HOLE - HOLE IN GOOD SHAPED. STARTED SCHEDULED WIPER . TRIP. CBU @11954. OBTAINED 150% HOLE VOV. POOH T/10930. OBSERVE WELL F/10 MIN. PRIOR T/POOH. NO TIGHT SPOTS. WELL BORE IN GOOD CONDITION. RIH T/11954. DRILLED T/11960. RECEIVED MAR ,5 i i995 A!~,s~ Oil & 6as 6ohs. 6ommission Anchors ' WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 5 11/17/94 (17) TD:12343'( 383) 11/18/94 (18) TD:13219'( 876) 11/19/94 (19) TD:13868' ( 649) 11/20/94 (20) TD:14009' ( 141) DRILLING MW: 0.0 VIS: 0 DRILLING T/12180. MUD PUMPS FAILED ON WORK STRING. REPAIRED BY C/O SWAB & LINER ON %1. DRILLED T/12321. HAD A CHANGE IN TRQ F/4000 T/7000 FT. LB. BIT QUIT. DOWN HOLE TRQ INDICATOR SHOWED TRQ SPIKE. CBU @12321. HAD CLEAN RETURNS 150% HOLE VOL. MONITOR HOLE 10 MIN. POOH T/11380. POOH WET 10 STNDS. HOLE IN GOOD SHAPE, PUMP DRY JOB. POOH T/281. PULL BHA & CHANGE BIT. SERV. BOP STAK WEAR BUSHING. MU BHA 97. SHALLOW TEST MWD. RIH T/12321. BM SURV @ 5889. FILL PIPE @9702. DRILLED T/12343. DRILLING MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS: TOPICS: TUNNING TBG & CHECKING THREAD PROTECTORS AND THREADS; KICK WHILE DRILLING. DRILLING T/13219. ADT= 18 HRS, AST= 1.5 HRS. DRILLING MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS: IST AID KITS, TRIPPING PIPE & INSIDE MAINTENANCE DURING BLOW. DRILLING T/13299. STARTED SCHEDULED WIPER TRIP. CBU. 100% ANNUL. VOL. POOH 12265. MONITOR HOLE 10 MIN. BEFORE STARTING OUT.-PIPE PULLED CLEAN. HOLE IN GOOD SHAPE. RIH T/13299. DRILLED T/13880. MUD PUMPS FAILED. WORK STRING. REPAIRED PISTONS. CONNECTION ROD BROKE ON PUMP #1. C/O SWAB. DRILLED T/13868. CIRC FLT. EQUIP T/CHK MW: 0.0 VIS: 0 DRLG T/14009. SECTION TD. CBU 100% ANNUL. VOL. POOH T/13030. MONITOR WELL 10 MIN. BLOW DOWN TOP DRIVE SHORT TRIP 10 STNDS. PIPE PULLED CLEAN. HOLE IN GOOD SHAPE. RIH T/14009. CBU. 175% HOLE VOL. POOH T/4000. MONITOR HOLE RETAKE LAST 4 SURVEYS BECAUSE OF POSSIBLE MAGNETIC INTERFERANCE. OK. POOH 10 STNDS WET. PUMP DRY JOB. POOH TOOK BM SURV. @ 5889 T/DBL CHK MWD TOOL. SERV. BLOCK LINE. SLIP & CUT 132' DL. POOH T/281. PULLED BHA MOTOR LOCKED UP. SERV. TOP RAMS. SET TEST PLUG, CHANGE TOP RAMS, TEST DOORS T/2500. RUN CASG 9-5/8" T/120'. PU FL. EQUIP, CIRC FLT EQUIP. T/CHECK. RECEIVED ivlAR 5 i 1995 Ai~S~ Oil & Gas Cons. Commission ~chor~. WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 6 11/21/94 (21) TD:14009' ( 0) 11/22/94 (22) TD:14009' ( 0) 11/23/94 (23) TD:14743' ( 734) 11/24/94 (24) TD:14986' ( 243) RD CASG EQUIP. MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS: WORKING DURING A BLOW, RUNNING CASG & REVIEW ACCIDENT SUMMARY. RAN CASG T/14009. CBU. & COND MUD F/CMT JOB. RD CASG SLIPS. OBTAINED 100% HOLE VOL. MIX & PUMP SLURRY 87 BBLS. DISPLACED CMT W/RIG @10 BPM. COULDN'T RECIP. BUMP PLUG, FLTS. HELD. CIP @ 05:25. RD CASG EQUIP. PREPARE T/LIFT STACK T/SET EMERGENCY SLIPS. RIH TO 13000' MW: 0.0 VIS: 0 L/D CEMENT HEAD. UNBOLT AND PICKUP STACK, SET SLIPS, DRAIN PIPE AND MAKE ROUGH CUT, DRESS STUMP, SET PACKOFF, BOLT UP BOP, TEST PACKOFF TO 3500 PSI. CHANGE TOP RAMS TO 5". L/D CASING ELEVATORS, C/O BAILS, L/D CEMENT EQUIPMENT, CLEAR RIG FLOOR. TEST BOPE, HYDRIL TO 250/2500 PSI, RAMS, CHOKE MANIFOLD, ALL MANUAL AND HCR VALVES, FLOOR VALVES AND IBOP TO 250/2500 PSI. REPLACE BAD SOLINOID ON PRESSURE INCREASE/DECREASE FOR HYDRIL. THAW FROZEN KILL LINE.. RETEST KILL LINE HCR AND MANUAL VALVES. BLOW DOWN ALL LINES, SET WEAR BUSHING. MADE UP BHA #8. SINGLED IN DRILL PIPE TO 4280' PICKUP 4000' OF 5" E DRILL PIPE. STOP AT 900' TO CK MWD. 129 JOINTS PICKED UP. RIH TO 13000'. DRILLING MW: 0.0 VIS: 0 HELD 3 SFTY MTGS. #1: PU DP. #2: SNOW IN PIPE SHED F/CASG. #3: WELL KILL DRILL. RIH T/13924. CBU OBTAINED 75% HOLE VOL. RU DRILLFLOOR/DERRICK. RU T/TEST CASG, BLOW DOWN TOP DRIVE. REPAIR FLUID SYS. VALVE ON STAND PIPE LEAKING, MUD MANIFOLD LINE HAD A PIN HOLE LEAK. TEST. CASG PRESS T/3500/30-MIN. OK. CIRC CLOSED IN WELL @ 13924. BRING PIPE UP TO ICP. PRESS CHANGED F/1050 T/890 IN 1 HR. THIS WAS A DRILL. SEV. BLOCK LINE SLIP & CUT DL. REPAIR FLUID SYS. REPLACE 0 RING IN BONNETT ON STNAD PIPE VALVE. DRILL CMT T/14019. CBU. DISPLACED HOLE W/WBM 100%. PERFORM INTEGRITY TEST. 11.500 PPG EMW. DRILLED T/14743. DRILLING MW: 0.0 VIS: 0 DRLG T/14797. PRESS CHANGED F/3450 T/4200 IN 0.10 HR. STRING BLOCKED. CBU CK SURF. EQUIP. DP SCREEN, CBU. 100% ANNUL VOL. MONITOR WELL. STABL. TRIP TANK, PULL 10 STNDS WET, CK WELL, PUMP DRY JOB. BLOW DOWN TOP DRIVE. POOH T/280. MOTOR STATOR BAD, RUBBER IN BIT. LD MOTOR & BIT. MU BHA #9. TIH T/7242 & SERV. DRLG EQUIP. RIH T/14640. FILL DP @ CASG SHOE. OBSERVED 30000 LBF RESISTANCE. REAMED T/14797. HOLE TIGHT & PACKING OFF. CBU @14797. 100% HOLE VOL. DRILLED T/14986. RECEIVED ~AR 7)'~ 1995 A~sk~ Oil & Gas Cons. Commission Anchor; '- WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 7 11/25/94 (25) TD:15725' ( 739) 11/26/94 (26) TD: 15725' ( 0) 11/27/94 (27) TD:16300' ( 575) 11/28/94 (28) TD:16767' ( 467) CIRCULATING MW: 0.0 VIS: 0 HELD 2 SFTY MTGS. 1) ENCOUNTERING H2S. 2) MAINTAINING TRUCKS IN WINTER. DRILLED T/15386. MUD PUMPS FAILED. REPAIRED--PUMP UP DAMPENERS. DRILLED T/15725. HAD CHANGE IN TRQ F/25000 T/28000 FT. LB. BIT QUIT. CBU @ 15725. SERV. TOP DRIVE MW: 0.0 ViS: 0 CBU @ 15725. 150% HOLE VOL. MONITOR WELL. POOH. HOLE NOT TAKING PROPER FILL. RIH T/15725. CBU. OBTAIN 100% ANNUL VOL GOT SOME OIL & GAS CUT MUD @ BTTMS UP. POOH T/13960. MONITOR WELL START T/PULL PIPE, NOT TAKING CORRECT FILL. PUMP OUT 19 STNDS T/SHOE. POOH T/10600. PULL 15 STNDS WET, MONITOR WELL. PUMP DRY JOB. PULL 21 STNDS. HOLE FILL NOT RIGHT. RIH T/15725. CBU. 150% HOLE VOL. BACKREAM & PUMP T/ SHOE. CIRC LO HI VIS SWEEP @ 600 GPM. ROTATE @ 150 RPM T/CLEAN UP CASG. HOLE SWEPT W/SLUG. 150% HOLE VOL. POOH T/280. PULL 10 STNDS WET, HOLE FILL GOOD. PUMP DRY JOB. BLEW DOWN TOP DRIVE. POOH. LD BIT, MUD MOTOR & MWD. MU BHA #10. PDC BIT, RIH T/1220. STOP T/SERV. DRILLING EQUIP. SERV. TOP DRIVE. DRILLING MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS: 1) HANDLING SLINGS. 2) CHANGING SWIVEL PACKING. RIH T/14000. REPAIRED TOP DRIVE CHANGE OUT WASH PIPE PACKING. RIH T/15725. TAKE BENCH MARK SURVEY. DRILLED T/16030. HOLE LOADING UP. HAVE T/PU & WIPE EVERY 30'. AFTER WIPING PENETRATION RATE WOULD INCREASE, TRQ & DRAG WOULD DECREASE. OBSERVE 20000 LBF DRAG ON CONNECTIONS. CBU 16030. CIRC LO/HI VIS SWEEP. HOLE SWEPT W/SLUG 200% HOLE. VOL. START BRINGING YP UP F/30 T/35. DRILLED T/16300. BHA STOOD BACK MW: 0.0 VIS: 0 HELD SFTY MTNGS W/BOTH CREWS. 1) WORKING ON BHA. 2) WINTER DRIVING. DRILLED T/16767. ROP DROPPED F/30 T/12 FT/HR. BIT QUIT. CIRC LO/HI SWEEPS AROUND, CUTTINGS BACK ON RETURNS. HOLE SWEPT W/SLUG. 150% HOLE VOL. MONITOR HOLE, PULL 10 STNDS WET, HOLE FILL GOOD. PUMP DRY JOB & POOH T/296. LD BIT, MOTOR & MWD. ~AR 7)~ !995 Gas Cons. Commission Anchor~ ~' WELL ' NK-9 OPERATION: RIG : POOL 7 PAGE: 8 11/29/94 (29) TD:16783' ( 16) 11/30/94 (30) TD:17030' ( 247) 12/01/94 (31) TD:17164' ( 134) 12/02/94 (32) TD:17545' ( 381) DRILLING MW: 0.0 VIS: 0 3 SFTY MTGS W/BOTH CREWS: #1: BLOWING SNOW CONDITIONS. #2: TRIPPING PIPE. #3: PU BHA. MU BHA #11. TEST WELL CONTROL EQUIP: BOPE, HYDRIL 250/3000. CALIBRATE H2S SYSTEM. TEST REMAINING SYSTEMS @ 250/5000. OK. PU & TEST ANDERGUAGE STABS. WOULDN'T LATCH. WORK ON STABS F/3 HRS. TIH T/8000. HOLD SFTY MTG. SERV. TOP DRIVE & DRAWWORKS. RIH T/14009. REAM T/14074. PRESS CHANGE F/3300 T/3900 IN .05 HRS. HOLE IS DETERIORATING. CBU 100% ANNUL. VOL. REAM OUT F/SHOE. HOLE CLEANED UP. MADD PASS F/14060 T/14274. TAKE BENCHMARK SURVEY @14809. OBSERVED 20000 LBF RESISTANCE. REAMED T/16767. DRILLED T/16783. DRILLING MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS: #1: PINCH POINTS. #2: FUELING EQUIPMENT. #3: PLANNING WORK. DRILLED T/17025. TOP DRIVE FAILED. CBU & REPAIR. REPLACE WASH PIP PACKING. DRILLED T/17030. RIH T/3200 MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS: #1: LOCK OUT TAG OUT. #2: USING THE RIGHT TOOL FOR THE JOB. DRILLING T/17060. TOP DRIVE FAILED. CIRC. WASHPIPE PACKING. DRILLED T/17164. PUMP HI-LO VIS SWEEP @17087. CIRC. 120% HOLE VOL. POOH T/14970. OBSERVE WELL. PULL 10 STNDS WET. HOLE FILL GOOD. NO TIGHT SPOST. PUMP DRY JOB. BLOW DOWN PUMPS. MAD PASS F/14940 T/14755. POOH T/300. PULL BHA, UNLOAD CDR TOOL C/O ANDER GUAGE STAB. LD ROLLER REAMER, L/C. PU NB STAB. TEST ANDER GUAGE STA. MU BHA #12 & RIH T/3200. DRILLING MW: 0.0 VIS: 0 SFTY MTGS HELD W/BOTH CREWS. TOPICS: #1 AIR TUGGER USE T/HOIST PERSONELL #2: USE OF SFTY BELTS & LANYARDS WHEN WORKING ABOVE FLOOR. #3: OBSERVE WEATHER PHASE WARNINGS WHEN DRIVING. RIH T/13600. STOP T/SERVICE DRILLING EQUIP. SERV. TOP DRIVE. SERV. BLOCK LINE. LINE SLIPPED & CUT. RIH T/17164. BENCHMARK SURV. @14796. SURV. LEDGES @ 15620 & 16380. MAD PASS F/17130 T/17154. DRILLING T/17545. Anchor~ '~ WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 9 12/03/94 (33) TD:17885' ( 340) 12/04/94 (34) TD:18082' ( 197) 12/05/94 (35) TD:18082' ( 0) 12/06/94 (36) TD:18082' ( 0) DRILLING MW: 0.0 VIS: 0 SFTY MTGS W/BOTH CREWS: #1: RIG ALARM SOUNDS. #2: EYE WASH STATIONS, CARE & USE. #3: 1ST DAY BACK. KEEPING YOUR MIND ON YOUR JOB. DRLG T/17652. MUD PUMP #2 FLUID END CRACKED BETWEEN SUCTION & DISCHARGE VALVES. CBU. 100% ANNUL. POOH T/16700. HOLE NOT CLEAN DUE T/REDUCED FLOW RATE. WELDED #2 FLUID END, PUT PUMP ON LINE. CIRC. @16700. RECOVERED A LARGE AMT. OF KINGAK & SHALE CUTTINGS. SWEEP HOLE W/SLUG: 10% HOLE VOL. RETURNED. POOH T/13920. CHANGE SWIVAL PACKING AS A PRECAUTION. FINISH INSTALLING THE NEW FLUID END ON PUMP #2. COMMISSIONED MUD PUMPS. RIH T/17652. DRILLED T/17885. PUMP HI/LO VIS SWEEP @BTTM. RIH T/1800. MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS. #1: VISUAL INSPECTION OF DL. #2: CONGESTION ON PAD CAUSING DRIVING HAZARDS. #3: PROPER CARE & USE OF TOOLS. DRLG T/18082. REACHED SECTION/WELL TD. CIRC HI/LO VIS SWEEP. CBU OBTAIN 250% HOLE VOL. POOH T/300: SWAB @17800. CIRC OUT T/17700. STARTING T/PACK OFF. CIRC & ROTATE OUT T/17000. PULLED CLEAN T/16700. PUMP DRY JOB & POOH. OBSERVE WELL @ SHOE. HOLE FILL GOOD. PULL BHA UNLOAD CDR & LD BHA. MU BHA #13. RETR. WEAR BUSHING/INSTALL WEAR BUSHING. RUNNING TOOL RETRIEVED. SERVICE THE BLOCK LINE. SLIP & CUT 53' OF DL. RIH T/1800. RUN CASG T/1500 MW: 0.0 VIS: 0 RIH T/13900. SERV. FLOW LINE-INSTALL NEW 5" VALVE ON STND PIPE. RIH T/18082. CIRC HI-LO VIS SWEEP. OBTAIN CLEAN RETURNS:120% HOLE VOL. OBSERVE WELL 10 MIN. POOH 10 STNDS WET. OBSERVE 50 K OVERPULL @ 17390 & 17340. BOTH SPOTS BROKE FREE & PULLED OK. HOLE FILL GOOD. OBSERVE 10 MIN. @ SHOE. PULLED BHA & DOWNLOAD LOGGING TOOLS. CHANGE TOP SET RAMS T/7-5/8" TEST DOOR SEALS T/2500. PRESS TEST T/2500. OK. RU CASG HANDLING EQUIP. RUN CASG T/1500. RUNNING CASG FfW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS, #1: RABBITING DP WHILE RIH. #2: RUNNING CASG & RABBITING F/DERRICK. #3: HOUSEKEEPING. RAN CASG T/4230. STOPPED T/CHANGE HANDLING EQUIP. LD CASG HANDLING EQUIP. RU DP HANDLING EQUIP. RU DRILLSTRING HANDLING EQUIP. pU LINER HANGER & 1 STND. CBU @4300. OBTAINED CLEAN RETURNS 0.50% HOLE VOL. RABBIT EACH STND. FILL EVERY 10 STNDS & RUN CASG T/13900. CBU. GAS CUT MUD T/8.7 PPG ON BTTMS UP. OBTAINED CLEAN RETURNS 120% HOLE VOL. OPEN HOLE IN GOOD SHAPE SO FAR/RUNNING CASG T/15500. M~R 3 ] 1995 Gas Gons. Commission Anchor~ '~ WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 10 12/07/94 (37) TD:18082' ( 0) 12/08/94 (38) TD:18082' ( 0) LD CASING MW: 0.0 VIS: 0 RUN CASG T/17673. HIT LEDGE & TIGHT SPOTS @ 16510 &17020. BOTH SPOTS OK W/O WORK THROUGH. PIPE STOPPED @ 17673. CIRC @17673. HOLE PACKING OFF. POOH OK BUT REENTRY W/PUMP ON ISN'T POSSIBLE. HOLE DETERIORATED UP T/17643. STOOD BACK 1 STND. WORK PIPE ATTEMPTED T/ROTATED. COULD NOT ROTATE @ 32000 FT/LB. WORKED BACK DOWN T/17673 ONE TIME. OBTAINED .50% HOLE VOL. PULLED CASG IN STNDS T/13900. PUMP OUT OF HOLE T/PREVENT SWABBING. CHK UP/DN ROTAITION WT. W/O PUMP. UP WT = 310K, DN WT.= 150K. ROT. WT.= 202K. WITH PUMP; UP WT.= 288K & DN WT. = 140K. ROTATED & RECIP. RE-CHK WTS AFTER GETTING BTTMS UP. W/PUMP UP WT. = 300K, DN WT. = 105K, ROT. WT. = 190K. W/O PUMP; UP WT. = 320K, DN WT. = 140K. OBTAIN CLEAN RETURNS, 120% HOLE VOL. SERV. BLOCK LINE SLIP & CUT 93' OF DL. PULLED DP IN STNDS T/4250. PUMP EA. STND OUT. HOLE WILL SWAB IF NOT PUMPING. STOP T/RU CASG HNDLNG EQUIP. LD LINER HANGR. STILL ATTEMPTING T/SWAB. PUMP DRY JOB IN 7-5/8" CASG. WILL LAY DOWN CASG AFTER SFTY MTG. @ . CREW CHANGE OUT. RAN DP T/2706 MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS: #1: RIG EVACUATION. #2: PULLING CASING. LD CASG T/2360. HAD 8 BBLS GAIN IN 1 HR. MONITOR WELL. ISOLATE & STRAP THE #1 SUCTION PIT. WELL STATIC - NO FLOW. PU 1 JT. DP. PUMP OUT FOR JTS. MONITOR HOLE FILL. HOLE TOOK 1.7 BBLS PER JT. CALC. DISP = 2.26 BBLS/JT. NET GAIN 2 BBLS. TOTAL GAIN 10 BBLS. LD CASG T/2520. BEGAN PRECAUTIONARY MEASURES, FLOW CHK. SUCTION PIT FOAMED UP. UNABLE T/DETERMINE EXACT VOL. PU 1 STND OF DP. RIH. WELL STATIC. NO FLOW. ADD DE-FOAMER T/PIT. CIRC. ANNUL & CASG VOL 195 BBLS. GAINED 1.7 BBLS WHILE CIRC. 1.700 BBLS GAINED IN 1.5 HR. MONITOR WELL PRESS F/02:30 T/03:30. 0 PSI. CHANGE TOP RAMS T/5" F/03:30 T/04:00. TEST BONNET SEALS T/1000 @04:00 T/04:30. OPEN CHOKE & MONITOR WELL. NO FLOW. OBSERVE PRESS: STRING = 0. ANNULUS = 0 PSI. OPEN HYDRILL & MONITOR WELL-NO FLOW. RUN DP IN STNDS T/2706. WILL NOT COMMENCE STRIPPING AT THIS TIME. REC[[V D MAP, ~ I i995 Oil & Gas Cons. Commission Anchor~ .... WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 11 12/09/94 (39) TD:18082' ( 0) 12/10/94 (40) TD:18082' ( 0) 12/11/94 (41) TD:18082' ( 0) 12/12/94 (42) TD:18082' ( 0) CIRC. DP VOL. MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS: #1) PROPER USE OF POWER TONGS. #2) PULLING CASG. RAN DP IN STNDS T/8000. FILL DP EVERY 10 STNDS. CIRC @8000. OBTAIN BU 100% ANNUL. VOL. RAN DP T/13963. FILL DP EVERY 10 STNDS. CBU @13963. CIRC OUT GAS CUT MUD. LOWEST MUD WT RETURNS WAS 9.2.PPG. OR 10.2 W/PRESSURE SCALES. 15 UNITS OF GAS. MOSTLY AIR. WT UP MUD T/10.6 PPG. HOLE DISPLACED W/WBM 100%. OPEN HYDRILL. MONITOR WELL. SLIGHT FLOW F/ANNUL. SUSPECT MUD T/BE HEAVY INSIDE DP. OBSERVED .5 BBL GAIN IN ANNULUS IN 1/2 HOUR. CBU @ 13963. CIRC DP VOL. TO BALANCE SUSPECTED U TUBE. LD CASG T/1200 MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS. #1: LAYING DOWN CASG. #2: HOLE FILL/ #3: EVACUATION PROCEDURES & SAFE AREAS. CIRC. @ 13963. OBTAINED REQ'D FLUID PROPERTIES. .30% HOLE VOL. FLOW CHK. OBSERVE WELL/STATIC. PULL DP IN STNDS. T/2500. DP DISPLACEMENT CALC. IS 96.2 BBLS. ACTUAL DISPLACEMENT IS: 113.2. STOP T/ CHANGE HANDLING EQUIP. NU BOP STACK. RU TOP RAM. CHG T/7-5/8" TEST DOORS T/1000. TOP RAM IN POSITION. RU CASG EQUIP. LD CSG T/1200'. LD 30 JTS/33JTS REMAINING. REAM T/16100. MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS: #1: PINCH POINTS. #2: HOUSEKEEPING ON THE RIG FLOOR. BOP TEST WAS WITNESSED BY LOU GRIMALDI W/AOGCC. LD CSG T/O'. 63 JTS LD. 108 TOTAL. 68 JTS DEEMED BAD AFTER INSPECTION. RD HNDLG EQUIP. RETRIEVE WEAR BUSHING/TEST BOP STACK. CHANGE TOP SET RAMS T/5" TEST 5000/250. TEST HY DRILL & CHK MANIFOLD T/2500. OK. INSTALL WEAR BUSHING. RETRIEVE RUNNING TOOL. MU BHA #14. RIH T/14930. CBU. 0.05% HOLE VOL. RIH T/16067. CBU. 0.06% HOLE VOL. HIT BRIDGE @16100. OBSERVE 60K LB/F RESISTANCE. WASH & REAM T/16160. COND. MUD. 11.2 PPG MI/D RETURNS @ BU. MUSHY GREY SHALE CUTTINGS IN RETURNS. WASH & REAM MW: 0.0 VIS: 0 REAMED T/16413. HOLE PACKING OFF @16413. TRQ INCREASED. WASH & REAM HOLE. OBSERVE 25000 LBF RESISTANCE. HOLE PACKING OFF. PULL INCREASING/MAX OVERPULL IS 75K. BACKREAM T/15877. HAD ~HANGE IN TORQUE F/35050 FT/LB. T/1000. FT/LB. JUNK IN HOLE. POOH T/14000. CIRC @14000. HOLE SWEPT W/SLUG. 0.05% HOLE VOL. VERY LITTLE INCREASE IN CUTTINGS. WASH & REAM F/14009 T/16446. TRQ @ 23250 120 RPM. 2900 PSI @ 606 GPM. RECIEJV£D Oil & (~as Cons. Commission Anchor~ ,'- WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 12 12/13/94 (43) TD:18082' ( 0) 12/14/94 (44) TD:18082' ( 0) 12/15/94 (45) TD:18082' ( 0) 12/16/94 (46) TD:18082' ( 0) WASH & REAM MW: 0.0 VIS: 0 HELD SFTY MTG W/BOTH CREWS: COMMUNICATE WITH YOUR RELIEF. WASH & REAM F/16446 T/17044. WASH & REAM MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS. #1: LOW VISIBILITY DUE T/POOR LIGHTING. #2: USE OF SFTY LANYARDS. WASHED T/17138. SUB-SURFACE EQUIP. FAILED. CBU. @lT138MIX & PUMP HI/LO VIS SWEEPS. HOLE SWEPT W/SLUG, 100% HOLE VOL. POOH T/SHOE & PUMP DRY JOB. MONITOR WELL. PIPE PULLED GOOD. NO SWAB. 30K DRAG MAX. SERV. BLOCK LINE, SLIP & CUT LINE. POOH T/300. PULL BHA. REMOVE WEAR BUSHING/INSTALL. RETRIEVE RUNNING TOOL. MU BHA #15. RIH T/14000. SERVICE TOP DRIVE. RIH T/17138. NO TIGHT SPOTS. REAM T/17300. REAMING T/18045 MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS. #1) FIRE PREVENTION. 92) INSPECTING HEATERS, CORDS, BURNABLES NEAR HEATERS; ETC. POOH T/10500 MW: 0.0 VIS: 0 HELD SFTY MTGS W/BOTH CREWS: #1': KEEPING YOUR MIND ON THE JOB TOWARD THE END OF A HITCH & DURING THE HOLIDAY SEASON. #2: WORKING TOGETHER AS A TEAM. %3: STORAGE OF PAINTS & FLAMABLES. REAMED T/18082. CBU 150% HOLE VOL.BACK REAM 2 TIGHT SPOTS @17480 & 17250. HOLE SWABBING MOST OF THE WAY. CIRC OUT MOST EVERY STD. SERVICE THE TOP DRIVE-CHK GEARS & BRUSHES ON TOP DRIVE LOOKING F/NOISE SOURCE. SLIP & CUT DL. ADJUST THE BRAKES. RIH - TAG BRIDGES @16666 & 17963. PU & WORK THRU W/NO PROBLEMS. DIDN'T ROTATE. CBU @18082. PUMP 2 SWEEPS AROUND. DIDN'T SEE MANY CUTTING AFTER THE lST SWEEP. SPOTTED 5 PPB SOLTEX PILL ON BTTM. OBTAINED 350% HOLE VOL. PULL 15 STNDS, PIPE PULLED CLEAN, HOLE FILL RIGHT, PUMP DRY JOB, PULL T/SHOE, HOLE STILL LOOKING GOOD. MONITOR WELL, FILL TRIP TANK & POOH T/10500. RECEIVED NiAF~. $ ] 1995 ~.~s~ Oil & Gas Cons. Commission Anchor~ ~ WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 13 12/17/94 (47) TD:18082' ( 0) 12/18/94 (48) TD:18082' ( 0) RAN DP TO 18082' MW: 0.0 VIS: 0 POOH TO 136'. AT BHA. PULLED BHA. L/D JARS & BIT. BHA STOOD BACK. RIGGED UP CSG HANDLING EQUIP. WORK COMPLETED - CSG HANDLING EQUIP IN POSITION. HOLD SAFETY MEETING. RAN CSG TO 4233'. BAKER LOCK BTM 4 JTS, CIRC THRU FIT EQUIP. STOPPED: TO CHANGE HANDLING EQUIP. PICK UP LINER HGR/PKR. RIGGED DOWN CSG HANDLING EQUIP. EQUIP WORK COMPLETED. CIRC AT 4233'. PICK UP CSG HGR/PKR. CIRC CSG VOLUME. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). RAN DP IN STANDS TO 13925'. PICKED UP 49 JTS OF HWT DP, AT 9-5/8" CSG SHOE. CIRC AT 13925'. GET UP WT, DOWN WT, ROT WT, & TORQUE AT THE CSG SHOE, CIRC A FULL CIRC TO GET LIGHT MUD OUT OF THE HOLE. CAME BACK AS LIGHT AS 9 PPG. OBTAINED CLEAN RETURNS - 100% HOLE VOLUME. RAN DP IN STANDS TO 18082' RIH, CK UP, DOWN, ROT WTS AND PUMP PRESSURES EVERY 1000', COULD NOT ROTATE AFTER 15000', EXTREMELY STICKY FROM 16600' TO BOTTOM, BUMPED IT AND OCCASIONALY CIRC TO BTM. CSG ON BTM AT 0610 HRS. AT SETTING DEPTH. REPAIRS MW: 0.0 VIS: 0 CIRC AT 18082'. OBTAINED REQ'D FLUID PROPERTIES - 150%, HOLE VOL. CIRC 1 FULL CIRC, RECIPROCATE PIPE AND CLEAN UP HOLE, BLOW DOWN TOP DRIVE. MIXED AND PUMPED SLURRY - 149 BBL. V/U FLOWMETER, TEST LINES TO 4500 PSI, PUMP 20 BBLS H20 PREFLUSH, 70 BBLS OF NSCI SPACER, 149 BBLS OF 'G' PREMIUM CMT. CMT PUMPED. DISPLACED SLURRY - 378 BBL. DISPLACE WITH RIG AT 8.2 BPM. PLUG BUMPED. FLOATS HELD, CIP @ 1045 HRS, PRESSURE TO 3500 TO SET LINER HGR, PRESSURE TO 4200 TO SET PACKER AND RELEASE. REVERSE CIRC AT 13848' REVERSE OUT DP WHILE STILL IN TIE BACK SLEEVE, PUMPED 100 BBLS OVER DP VOLUME, OBTAINED CLEAN RETURNS - 50% HOLE VOLUME. RIGGED DOWN HANDLING EQUIP. R/D HALLIBURTON & BAKER QUIP, BLOW DOWN KILL LINE. WORK COMPLETED, EQUIP LAID OUT. POOH TO 5220' PULL & STD BACK 20 STDS, LAY DOWN 5300' (168 JTS) DRILL PIPE AND 1460' (49 JTS) HWT DP. BEGAN PRECAUTIONARY MEASURES. HAD TO LEAVE THE REST OF THE PIPE IN THE HOLE SO WE HAD ROOM TO GET THE TOP DRIVE OUT THE V-DOOR. SERVICED BLOCK LINE. LINE SLIPPED AN CUT. PUT EXTRA 238' OF LINE ON DRUM TO LAY DOWN TOP DRIVE. REPAIRED TOP DRIVE. RIG DOWN AND LAY DOWN TOP DRIVE. RECEIVED ~viAR ~i !995 A~.~.~ Oil & Gas Cons, Commissior~ Anchor~ '. WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 14 12/19/94 (49) TD:18082 PB: 0 12/20/94 (50) TD:18082 PB: 0 12/21/94 (51) TD:18415 PB: 0 BHA RUN #16 MW: 0.0 REPAIRED TOP DRIVE. L/D TOP DRIVE AND ASSY. EQUIP WORK COMPLETED. POOH TO 20'. AT BHA. PULLED BHA. L/D BAKER RUNNING TOOL, P/U STD OF DRILL COLLARS OUT OF DERRICK AND LAY DOWN. BHA LAID OUT. RIGGED UP DRILLFLOOR / DERRICK. PICK UP & RIG UP KELLY, SWIVEL AND RAT HOLE. EQUIP WORK COMPLETED. INSTALLED WELLHEAD INTEGRAL COMPONENTS. CHANGE BOTTOMM RAMS TO 3-1/2" EQUIP WORK COMPLETED. TESTED WELL CONTROL. TEST FLOOR VALVES, KELLY VALVES, CHOKE MANIFOLD, BOP STACK TO 500/5000 PSI, HYDRIL BAG TO 500/2500 PSI. UPPER KELLY COCK FAILED, SENT FOR REPLACEMENT. PRESSURE TEST COMPLETED SUCCESSFULLY - 5000 PSI. INSTALLED WEAR BUSHING. TIE-DOWN BOLTS ENERGISED. REPAIRED DRAW WORKS. CHANGE OUT BRAKE BANKS. EQUIP WORK COMPLETED. REPAIRED KELLY COCKS. CHANGE OUT UPPER KELLY COCK AND TEST TO 500-5000 PSI, CHANGE OUT SWIVEL PACKING. EQUIP WORK COMPLETED. BHA RUN #16. P/U STABS & DRILL COLLARS TO RIG FLOOR & MAKE UP. DRILLED CMT TO 17955' MW: 0.0 MADE UP BHA #16. M/U 4-3/4" DCS & 6" STABS, TEST MWD. SINGLED IN DP TO 5154' P/U 3-1/2" DP. 153 JTS PICKED UP. RIH TO 13848'. CHANGE TO 5" HANDLING TOOLS, CIRC TO CK MWD, RIH W/STDS. AT TOP OF LINER CIRC AT 13848' P/U KELLY TAG TOP OF LINER. TORQUE METER NOT READING RIGHT. OBTAINED REQ'D FLUID PROPERTIES - 50%, HOLE VOL. TESTED LINER HANGER - VIA ANNULUS. TEST LINER TOP PKR & LINER TO 3500 PSI FOR 30 MIN. PRESSURE TEST COMPLETED SUCCESSFULLY - 3500 PSI. BLOW DOWN KILL LINE. MILLED SETTING TOOLS AT 13848' DRILL UP PACKOFF BUSHING AT THE TOP OF LINER. SET BACK KELLY. NO FURTHER RESISTANCE. RIH TO 17880' TAG CMT. ON BOTTOM. DRILLED CMT TO 17935' TAGGED LANDING COLLAR. DRILLED CMT TO 17955' DRILL UP LANDING COLLAR (5 HRS) & CMT. DRILLED TO 18415' MW: 0.0 DRILLED CMT TO 18092'_,,7 D2 DRILL. DRILL CMT, FLT EQUIP & 10' OF NEW HOLE. AT CSG SHOE. CIRC AT 18092'. CBU, CLEAN PIT THAT WE WERE DRLG CMT INTO, PUMP 50 BBL LOW VISC SWEEP AND 100 BBL HIGH VISC SWEEP AHEAD OF KCL MUD. HOLE DISPLACED WITH WATER BASED MUD - 100% DISPLACED. CHANGED 2 SHAKER SCREENS AFTER DISPLACEMENT. DRILLED TO 18415'. RECEIVED 4AF , 3 1995 ~t~k~. Oit & Gas Cons. Commission Anchor~'" WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 15 12/22/94 (52) TD:18570 PB: 0 12/23/94 (53) TD:18570 PB: 0 12/24/94 (54) TD:18570 PB: 0 REAMED TO 18388' MW: 0.0 DRILLED TO 18570'. REACHED PLANNED END OF RUN - GEOLOGICAL. CIRC AT 18570'. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). POOH TO 18060' PULL 5 STDS & SINGLE TO THE SHOE, FIRST 3 STDS PULLED REAL TIGHT, LAYED DOWN 4 SINGLES WHILE PUMPING AND WORKING PIPE OUT. AT 7" CSG SHOE. LD DP TO 282'. LD DP TO REAM BACK TO BOTTOM. 9 JTS LAID OUT. RIH TO 18185-'. BEGAN PRECAUTIONARY MEASURES. REAMED TO 18388'. RAN ELECTRIC LOGS MW: 0.0 REAMED TO 18570'. ON BOTTOM. CIRC AT 18570'_ OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). POOH TO 186' PULL TO SHOE, NO TIGHT SPOTS, GOOD HOLE FILL, PUMP DRY JOB, PIPE DIDN'T DRY UP, PUMPED ANOTHER DRY JOB AFTER, 7" LINER. AT BHA. PULLED BHA. PUPLL ANADRIL SVY TOOL & LAY IT DOWN. BHA STOOD BACK. WIRELINE WORK. RIGGED UP WIRELINE UNITES. RIG UP WIRELINE TOOLS TO RUN IN HOLE ON DRILL PIPE. EQUIP WORK COMPLETED. RAN ELECTRIC LOGS. RUN IN HOLE W/DP AND WL TOOL, JUST THRU THE TOP OF THE LINER AT 0600 HRS. RAN DLL/TEMP/ZDL/CAL/CN/GR/SP. RD LOGGING/BRAIDED CABLE EQUIP MW: 0.0 RAN ELECTRIC LOGS. RIH W/WL TOOL ON DP, INSTALL SIDE ENTRY SUB AT 0700 HRS, PUMP DOWN WIRE TO LATCH TOOL, MAKE 2 LOGGING PASSES, POOH TO SIDE ENTRY SUB. COMPLETED RUN WITH DP FROM 18072' TO 18570'. RAN ELECTRIC LOGS. PULL WIRE FREE FROM TOOL, POOH W/WIRE, L/D WL & SIDE ENTRY SUB. COMPLETED RUN WITH SLICKLINE/BRAIDED CABLE FROM 17500' TO 0'. CIRC AT 17500' OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). PULLED DP IN STANDS TO 117' STOPPED: TO RETRIEVE SVY. RIGGED DOWN LOGGING/BRaIDED CABLE EQUIP. WORK COMPLETED, EQUIP LAID OUT. RECEIVED qAR 1995 A!a~ka Oil & Gas Cons. Commission Anchor[ - WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 16 12/25/94 (55) TD:18570 PB: 0 12/26/94 (56) TD:18570 PB: 0 R/D LOGGING/BRAIDED CABLE EQUP MW: 0.0 RIGGED DOWN LOGGING/BRAIDED CABLE EQUIP. SURFACE CK LOGGING TOOLS AND L/D. WORK COMPLETED, EQUIP LAID OUT. RIGGED UP LOGGING/BRAIDED CABLE EQUIP. RIG UP GR/FMT LOGGING TOOL. WORK COMPLETED - LOGGING/BRAIDED CALBE EQUIP INPOSITION. RAN DP IN STANDS TO 18042'. RIH W/LOGGING TOOL ON DP. AT 7" CSG SHOE. RIGGED UP LOGGING/BRAIDED CABLE EQUIP. HANG SHEEVE IN DERRICK, INSTALL SIDE ENTRY SUB. WORK COMPLETED - LOGGING/BRAIDED CALBE EQUIP IN POSITION. RIGGED UP LOGGING/BRAIDED CALBE EQUIP. RAN W/L INSIDE DP TO 7000', PUMP DOWN F/7000' TO LATCH UP AT 17981', INSTALL PACKOFF IN SIDE ENTRY SUB. WORK COMPLETED - LOGGING/BRAIDED CABLE EQUIP IN POSITION. RAN ELECTRIC LOGS. LOGGING W/PIPE CONVEYED TOOLS, GR/FMT. COMPLETED LOGGING RUN WITH FMT FROM 18082' TO 18414' PULL BACK INTO SHOE. RIGGED DOWN LOGGING/BRAIDED CABLE E~UIP. UNLATCH FROM LOGGING TOOL AND POOH W/WIRE. REAMED TO 18483' MW: 0.0 RIGGED DOWN LOGGING/BRAIDED CABLE EQUIP. PULL WIRE LINE OUT OF DP, FID DOWN WIRE LINE SHEAVE AND SIDE ENTRY SUB. WORK COMPLETED, EQUIP LAID OUT. CIRC AT 18070'. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). PULLED DP IN STANDS TO 0' COMPLETED OPERATIONS. RIGGED DOWN LOGGING/BRAIDED CABLE EQUIP. RIG DOWN AND LAY OUT FMT/GR TOOL. WORK COMPLETED, EQUIP LAID OUT. TESTED WELL CONTROL. PULL WEAR RING, SET TEST PLUG, TEST BOPE, RAMS, KILL LINES, CHOKE LINES AND VALVES, AND CHOKE MANIFOLD ALL TESTED TO 500/5000 PSI, HYDRIL TESTED TO 500/2500 PSI. ACCUMULATOR, HWS AND GAS ALARMS ALL TESTED. NO STATE MAN ON THE SLOPE. PRESSURE TEST COMPLETED SUCCESSFULLY - 5000 PSI. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. MADE UP BHA #17. BHA #17 MADE UP . RIH TO 18070'. AT 7" CSG SHOE LD DP TO 124'. BREAK CIRC AT THE SHOE, L/D 4 JTS OF D~. BEGAN PRECAUTIONARY MEASURES. REAMED TO 18483'. RIH, P/U KELLY AND REAM F/18421', HIT TIGHT SPOT AT 18454', CONTINUE TO REAM TO BTM. Gas Cons. Commission Anchor~" WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 17 12/27/94 (57) TD:18570 PB: 0 12/28/94 (58) TD:18570 PB: 0 RAN DP IN STANDS TO 6000' MW: 0.0 REAMED TO 18570' REAM F/18421 TO TD, HOLE PACKING OFF. ON BOTTOM. WORKED PIPE, GOT HOLE CLEANED UP. CIRC AT 18570'. HOLE SWEPT WITH SLUG-150% HOLE VOLUME. POOH TO 18010' SHORT TRIP TO SHOE, PIPE PULLED CLEAN, HOLE FILL RIGHT, AT 7" CSG SHOE. RIH TO 18570'. HIT LEDGE 40' OFF BOTTOM, PICKED UP AND WIPED THRU IT A COUPLE OF TIMES, DIDN'T SEE IT AGAIN. ON BOTTOM. CIRC AT 18570'. OBTAINED CLEAN RETURNS - 125% HOLE VOLUME. POOH TO 185'. PULL TO SHOE, HOLE CLEAN, PUMP DRY JOB, POOH. AT BHA. PULLED BHA. BHA LAID OUT. RIGGED UP CSG HANDLING EQUIP. WORK COMPLETED - CSG HANDLING EQUIPI IN POSITION. RAN CSG TO 760'. CK FLOAT EQUIP. HANGER ASSY INSTALLED. CIRC LINER VOLUME. RIGGED DOWN CSG HANDLING EQUIP. WORK COMPLETED, EQUIP LAID OUT. RAN DP IN STANDS TO 6000'. RIH TO 720' MW: 0.0 RAN DP IN STANDS TO 18070' AT 7" CSG SHOE. CIRC AT 18070' OBTAINED REQ'D FLUID PROPERTIES - 40%, HOLE VOL. CIRCA DP VOLUME PLUS. RAN DP IN STANDS TO 18570'. RIH TO TD, NO PROBLEM GETTING TO BOTTOM. AT SETTING DEPTH. CIRC AT 18570'. BREAK CIRC AND WORK PUMP UP TO 5 BPM WHILE RECIPROCATING THE LINER. LINER BECAME INCREASINGLY STICK, MOSTLY IN THE UP STROKE. FINALLY COULDN'T MOVE PIPE OFF BOTTOM. CONTINUE TO CIRC. BATCH CMT. OBTAINED REQ'D FLUID PROPERTIES - 100%, HOLE VOL. MIXED AND PUMPED SLURRY - 27 BBL. PRESS TEST LINES TO 4500 PSI, PUMP 20 BBLS WATER, 70 BBLS ALPHA SPACER, 27 BBLS CLASS 'G' CEMENT, RELEASED DART. CLEARN CMT LINES TO CELLAR. DISPLACED SLURRY - 269 BBL. DISPLACE W/RIG PUMP, BUMP PLUG ON CALCULATED STKS. CIP @ 1830 HRS. PRESS TO 3500 PSI TO SET HGR, 4300 PSI TO SET PACKEWR. BLEED PRESSURE, FLOATS HELD. ROTATED TO RELEASE FROM HANGER. PLUG BUMPED. REVERSE CIRC AT 17920' REVERSED OUT CEMENT, SPACER AND PREFLUSH, OBTAINED CLEAN RETURNS - 50% HOLE VOLUME. RIGGED DOWN HANDLIN GEQUIIP. RIG DOWN CMT HEAD, HOSES & REVERSE CIRC LINES. WORK COMPLETED, EQUIP LAID OUT. PULLED DP IN STANDS TO 0'. PULL 15 STDS DP, PUMP DRY JOB, POOH, HANGER ASSY LAID OUT L/D BAKER RUNNING TOOL. MADE UP BHA %18. P/U 19 3-1/2 DCS, SCRAPER, XOS AND JARS. BHA %18 MADE UP. RIH TO 720' Gas Cons. Commiss~o~ WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 18 12/29/94 (59) TD:18570 PB: 0 12/30/94 (60) TD:18570 PB: 0 POOH TO 18480 MW: 0.0 RIH TO 4000' STOPPED: TO SERVICE DRLG EQUIP. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. SERVICED TOP DRIVE. EQUIP WORK COMPLETED. RIH TO 17913' TOP OF 5" LINER. OBSERVED 5000 LBF RESISTANCE. WASHED TO 17918' TAGGED CMT OR CUTTINGS @ TOP OF LINER. WASHED 5'_ CONTINUE RIH. NO FURTHER RESISTANCE. RIH TO 18330'. OBSERVED 3000 LBF RESISTANCE. WASHED TO 18484'. TAGGED SOFT CMT @ 18330' . WASH AND REAM TO L/C @ 18484'. ON BOTTOM. CIRC AT 18484'. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). SOFT CMT IN BU. TESTED CSG. TEST 5" CSG TO 3500 PSI/30 MIN. PRESSURE TEST COMPLETED SUCCESSFULLY - 3500 PSI. CIRC AT 18484'. PREP TO DISPLACE TO BRINE. SAFETY MEETING WITH CREW, MUD ENG AND TRUCK DRIVERS. OBTAINED CLEAN RETURNS - 50% HOLE VOLUME. CIRC AT 18484'. PUMP 250 BBL SEA H20, 50 BBL SAFE CLEAN, 100 BBL HI-VIS SWEEP, 250 BBL SEA HWO. DISPLACE W/9.7 PPG NACL BRINE. BLOW KELLY DN. SET BACK. HOLE DISPLACED WITH BRINE - 100% DISPLACED. REVERSE CIRC AT 18484'. FILTER BRINE TO 32.5 MG/LTR (1 CIRC). OBTAINED REQ'D FLUID PROPERTIES - 100%, HOLE VOL. POOH TO 18480'. POOH TO 2000' MW: 0.0 POOH TO 200'. DROPPED PIN FROM 5" SLIPS INTO HOLE. I"DIA, 2" LONG. AT BHA. PULLED BHA. BHA LAID OUT. OPENED DOORS ON BOP STACK LOOKING FOR SLIP HANDLE PIN. NONE FOUND. TESTED BOP STACK. TESTED DOOR SEALS WITH TEST JT. 250# LOW & 5000# HIGH. PRESSURE TEST COMPLETED SUCCESSFULLY - 5000 PSI. MADE UP BHA #19. MU REVERSE CIRC BASKET, BOOT BASKET, X/O 127 JTS 3-1/2" DP, 2-3-1/2" PUPS (22'), BOOT BASKET, X/O, 26 JTS 3-1/2" DP, X/O AND 5" DP TO SURFACE. BHA #19 MADE UP. RIH TO 13848'. TOP OF 7" LINER. AT TOP OF LINER. CIRC AT 13848'. HAD TO P/U KELLY TO ROTATE REVERSE CIRC BASKET THROUGH TOP OF LINER. WORKED THRU LINER TOP WITH PUMP ON 70 STKS/MIN 2200 PSI. REPEATED PROCESS 6 TIMES. OBTAINED CLEAN RETURNS - .01% HOLE VOLUME. RIH TO 17913'_ AT TOP OF LINER. TOP OF 5" LINER. CIRC AT 17913'. CIRC 7,, LINER VOLUME THRU REVERSE CIRC SUB. WORK PIPE WHILE CIRC 5.5 BPM @ 2400 PSI. OBTAINED CLEAN RETURNS - .2% HOLE VOLUME. POOH TO 2000'. NO JUNK FOUND IN TOP BOOT BASKET. WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 19 12/31/94 (61) TD:18569 PB: 0 01/01/95 (62) TD:18569 PB: 0 RAN ELECTRIC LOGS MW: 0.0 PULLED OUT OF HOLE TO 12' AT BHA. PULLED BHA. L/D BHA/CLEAR FLOOR. BHA LAID OUT. MADE UP BHA #20. M/U PERF GUN ASSY. BHA #20 MADE UP RIH TO 18377'. STOPPED: TO CORRELATE DEPTH. RIGGED U~ LOGGING/BRAIDED CABLE EQUIPMENT. WORK COMPLETED - LOGGING/BRAIDED CABLE EQUIP IN POSITION. RIH TO 7940' OBSERVED 3000 LBF RESISTANCE. LOG STOPPED. PUMP @ 5 BPM 800 PSI. INCREASED TO 5.5 BPM @ 900 PSI. POOH 0' AT BHA. P/U 2" WEIGHT BAR. RIH TO 17500'. TOOLS ST6PPED @ 8882' PUMPED TOOLS DOWN W/lll0 PSI 6 BPM. STOPPED: TO CORRELATE DEPTH. RAN ELECTRIC LOGS.. CCL/GR. TIE IN LOG. RAN ELECTRIC LOGS MW: 0.0 RAN ELECTRIC LOGS. RAN CCL/GR TIE INTO DEPTH. POOH. RD WIRELINE UNIT. COMPLETED LOGGING RUN WITH GR FROM 17560' TO 17050'. TIE IN TO ATLAS DLL/SP/GR OPEN HOLE LOG. RIGGED DOWN LOGGING/BRAIDED CABLE EQUIP. WORK COMPLETED, EQUIP LAID OUT. LAID DOWN DP TO 18306.75'. BOTTOM OF PERF GUN ASSY. AT SETTING DEPTH. SET RETRIEVABLE PACKER AT 17638.44'_ RIG UP TEST MANIFOLD. TEST ALL LINES AND CHOKE TO 3500 PSI. PUMP 191 BBL DIESEL DOWN DP THRU PACKER BYPASS. SIDPP = 1100 PSI. PACKER SET AT 17638.44'. 30K ON PACKER. PRESSURE UP ANN TO 1200 PAI FIRED DPC PERF GUNS W/CHOKE FULL OPEN 48/64. FLOWED WELL-OIL 126 US GAL/MIN, WATER 0 BBL/MIN, GAS 0 MMSCF/DAY. FLOWED BACK 191 BBL OF DIESEL @ 600 TO 375 PSI. 70 MIN CHOKE OF VARIOUS SETTINGS. CLOSED IN WELL. REV CIRC AT 17638' REVERSE CIRC FORMATION FLUIDS TO PITS. RECOVERED 247 BBL OF FORMATION FLUID. LOST 119 BBL OF BRINE WHILE REVERSE CIRC. STRING DISPLACED WITH BRINE - 95% DISPLACED. SHUT WELL IN COMPLETION FLUID CONTAMINATED AND VOLUME IN PITS LOW. BUILD 90 BBL BRINE ON LOCATION. ORDERED 300 BBL FROM MI MLrD PLANT. MONITOR WELL PRESSURES. ISIDP PRESSURE 150 CASING PRESSURE. OBSERVED PESSURES - STRING: 0 PSI, ANNULUS:0 PSI. REVERSE CIRC AT 17638'. UN SET PACKER -- REV CIRC DP VOLUME. LOST 65 BBL> TOOK 40 BBL TO GET CIRC WHILE REV CIRC. TOTAL LOSSES 184 BBL. HOLE DISPLACED WITH BRINE - 100% DISPLACED. CIRC AT 17638'. SWAP OVER AND PUMP DOWN DP. OBTAINED CLEAN RETURNS - 100% HOLE VOLUME. CIRC OUT OIL AND GAS FROM ANNULUS. HELD 150 PSI ON RIG CHOKE. HAD OIL AND GAS TO SURFACE WITH 262 BBL PUMPED. WORK DP WHILE CIRC. (GUNS ARE FREE) LOST 43 BBL WHILE CIRC. CONVENTIONALLY. TOTAL LOSSES 227 BBL. FLOW CHECK. HOLE STATIC ESTIMATED LOSSES PER HR STATIC 6 BBL. PREP TO POOH. WELL : NK-9 OPERATION: RIG : POOL 7 PAGE: 20 01/02/95 (63) TD:18569 PB: 0 01/03/95 (64) TD:18569 PB: 0 RAN TBG TO 7000' MW: 0.0 FLOW CHECK. HOLE TAKING 6 BPH STATIC. OBSERVED WELL STATIC. POOH TO 870' HOLE FILL +- 1 BBL OVER CALCULATED PER 5 STANDS. AT BHA[ PULLED BHA. L/D PACKER 2-7/8" PAC COLLARS AND PERF GUNS. BHA LAID OUT. REMOVED WEAR BUSHING. RETEST 9-5/8" PACKOFF TO 5000 PSI 15 MIN. EQUIP WORK COMPLETED. CHANGED BOTTOM RAMS TO 4" X 7" VBRS. CHANGED TOP SET RAMS TO 4-1/2". SET TEST PLUG. TEST DOOR SEALS TO 2500 PSI. TESTED BOP STACK. PRESSURE TEST COMPLETED SUCCESSFULLY - 2500 PSI. INJECTED 215 BBL DIESEL DOWN 13-3/8" X 9-5/8" ANNULUS FOR FREEZE PROTECTION @ 3 BPM 1100 PSI_ RAN TBG TO 7000'. 175 JTS RUN @ 0600. HAVE LOST 30 BBL BRINE WHILE RUNNING TBG. NO REpoRT REC'D MW: 0.0 01/04/95 (65) TD:18569 PB: 0 COMMISSIONED TOP DRIVE MW: 0.0 REMOVED HANGER PLUG. EQUIP WORK COMPLETED. FREEZE PROTECT WELL - 185 BBL OF DIESEL PUMP DOWN ANNULUS TO 2900 PSI. SHEAR OUT RP SHEAR VALVE IN GLM @ 3050' DISPLACE W/185 BL DIESEL. U-TUBE 35 BL INTO TBG. COMPLETED OPERATIONS. INSTALLED HANGER PLUG. SET BACK PRESSURE VALVE THROUGH LUBRICATOR. EQUIP WORK COMPLETED, RUNNING TOOL RETRIEVED. WELL SECURE. LAID OUT DP FROM DERRICK. DRILLSTRING HANDLING EQUIP FAILED - ABORT OPERATION PIPE SKATE VALVE FAILED. STOP TO REPIAR/REPLACE VALVE. CHANGE OUT VALVE ON PIPE SKATE. REPAIRED DRILLSTRING HANDLING EQUIP. WORK COMPLETED, DRILLSTRING HANDLING EQUIP CHANGED OUT. LAID OUT DP FROM DERRICK. 230 JTS LAID OUT. 230 JTS TOTAL LAID OUT. L/D KELLY AND MOUSE HOLE. RIG RELEASED @ 0100 1/4/95. COMMISSIONED TOP DRIVE. INSTALLING TOP DRIVE. SIGNATURE: (drilling sUperintendent) DATE: COMPANY ~=' E~?LO~tATiON~ !NC, LGtAT!O~ i N!AiUi 'DATE: Of-NOV-94 WTM ~=~ WELL HEAD LOCATION: ;~T(H/-S} 0,00 AZIMUTH FRO~ ROTARY .... ~m.~ .'.'0. ?ARG£T. zo"~ T;= iN POiNT(TiP) : MEASURSD DEFTH O,-"X~ ~n,_,E PERT u.r't!, 0,00 LATiTUDE(N/-S} O, 00 DEPARTURE<E/-~) 0,00 3~3~56 RECEIVED MAR 3 1 i995 .~,!~sk~ Oil & Gas Cons. Commission Anchor~" 7:R~£T STATION AZIMUTH LATiTUDF fz ~e._-- Oe~ f: O, O0 ','~, O0 ,".; ~ O0 :)~ :JO 0,22 0,i6 331.;',71; -. o, (], 62 ;i ~ :.:.4 ': 27 ....~, ,07 0 1,02 0,2,5 312~34 0,,'-'i 1 .its -..- ,oo O,.,'y '3.-04,54 I n, :/-:a · f: f: de-~ !O-)f: 0,50 O,O0 ,)&O -O, 06 0,: 3 :~:,"-" 75 O, 2,~. -c',37 i1..¢5' ,::~ .w, 0,23 -0,76 1,54 3i3,20 -:, !3 i ~ ~1 ~ ,,sq ..... 500,00 i00,0 49%9? ~0,)0 lO0~O 799,99 2,06 0,39 ~,// v,~ :i,',.z~ !,88 3,45 0,35 3,30 0o17 3!6,~4 2,71 -i,60 2,11 3i0,68 0,i! ..~-- ,.-. :o.~ ._ :~., :': 3i!,62 il,.:....~ . -'2,5-.;' 3,52 Y., 2,51.;'0,07. ........... ...1,_, ;_,0,i8 -", 'Y-' .5,77 ~ '] '"~ -3,20 4,.2:7 3i2,92 0,:2 !000,.90 : !00, O0 !2.'X,, 1300,00 : ~.':J'V ~ j.'-'i i¢~,0 i00,0 4,72 4,95 0,i6 ~9~53 3,20 5,02 O~iS 5,02 0,22 ~6,46 '>.~ 4,39 0,i7 230,7? 2,37 ---~, ,.-..o 4, ,_:~"° dli,:~O :.3,14 -4, ,..,,.,'¢' _.., -,~ ' :' 3 ¢.'2,, 7::;O, .: S -4 :'" ......... · ,r/ D,// -_%)D ,'Y/ -4,53 5,37 302,::0 0,03 - 4,7.-:; 5,47 279,!6 0,02 :,::,0 !47'.;', 78 lO0,O !599, i0(:,0 iO0,O ' 0'"' h .:r.,-:,- 5,45 0,55 274,69 2,53 9,40 2,1! 306,03 4,55 -5,08 _,--', ~.='., ._. 29,."., 4-~. -5,75 ;,, ;.~ 272~,75 '),35 -7,20 7,8! ;y_-',7.3 0,74 , '" .,..,., A~. ..... --*,,.'../ ,' v,,.,., -"?5,20 0,'.',"3 -14 -" :vu, 4.'..',-, c.c, ,~..: i6,54 ......... 2i00,00 2S00,O0 2400,00 i,:Y..,,O !999,31 IO0,O 20'.;'8]TM ~,.;v,v '2!75,09 i-::,o,c, ::,; ,:¢ 100,0 2296,50 -20,% E,63 305,0.3 1,i8 -':'7,17__ ~7,37 3i,3,?i 0 ,,~ .... -.a,~,6 57.41 o .... ,.. 0,50 -52,16 72,31 315,33 0,47 25'[:0, O0 '2100.,.00 2700, O0 2800, :.;,0 2.'?00,00 I00,0 24'?5,45 iW,O ,,.,;v,~.- lO0,,J 2787,09 !0},0 28~2,4! ~s ,4-" ",'.] '-'" - -~ AS, 83 '-:-. * - Y '7~ .... 104 ·" ,27 ~ .':.. =.v 71!7,34 7~,ov ,.~: I, .'., .... 12,7,87 !4,,87 3!7,20 ?2,02 ~54,71 "~, '~' ,,,..,4_, ";17,88. .,,z,,.,. ?4 i 84,7~, 18,70 ....,...,':'~ '" ,78 i 34,5':..' -.:.i, ~:, :,' 7-,. 31~,5! " -.;4,55 !05,46 315,82 3,5.7 -90,.65 127,17 3i5,4i 2,30 -128-,'72 i8.:,,.'.'! 316,21 2,27 :~...:,'E:O,. ,'-, ¢¢:~ ! 310a,,h) I00,0 :';'"-'.'.% - :'0 ~00,0 '~ -'a 3300, &'.' ioo~o '-.;+.~0,'~©I00,0 3338,3'? ~A,gA ~? 5~ ~1o ~ ..... ~¢,-~ ,-.',,-.. i87,23 277,~' "'~ "~ 32!,27 - -' -i51,50 220,62 363,43 2,78 -176,35 '"~ ....... ~,.,~ ~i/,02 1,8i -202,30 ,~3,r~ 3!7,41 -~2'~,57 *'" " ' . .. -~6,97 389,55 318,34 3,12 3700,00 !00,0 3423,57 100,0 3507,42 !00,0 1663,54 i00,0 3746,7! 439,6'.:,' 32,3~ 323,.73 332,-.:. 4v4.',,., ;~ 34,56' ' 222,,~,5 . ~/ -- ...,-,,-=~:~,..,: 4.23,55 ................. 47 ~,';'2 -:-75,:---6 ........ "J.i ' ' ,::';-: .~ -';'c"3, f:n_,., .... aal, ..,~ 3i8,90 2,40 -322,.62 %6,07 ql.~,a:~ ,~ ~.~ -':"= o,,:. ~='~,¢'0 3i?,&7 ,.,.jj ,.. -.~ . .. - 2.'73,24 614,28 32,"~,20 i ,47 -431,"'.q jC,,:.O 3Z::),:= .... .d:-' .,. .. RECEIV[D MAR 311995 A!aska Oil & Gas Cons. Commission Anchorr -, ':0'::0~ 03 100.0 . - ~-."'S.~ 13 4200,0,3 i00,6 31;70,20 w-2ff.~,, -2' 4400,0,:-" t00,0 -,ff.-" '-' ~ ()U 45!0, 05 4540,00 4570,00 46~0,00 4~60,50 4900,% ,47~.t , ,.:I....' 5000,00 :,;,.~ v, O0 5040,00 5070, O0 5!08,00 5i60,00 5170, X~ ---. 7' .'-'fi 5.'-~0, O0 5.310,00 5370, 'JO 5400,00 5430,60 740,00 4!,02 320,7? 571,43 gOd,AA ~.:. ~ ..... ,-~ . A7= c:? .. :?44,56 ,~ ~, 40,0 " 4.'?~ ,:$0 30,0 4!.;,2.97 :0.63,78 4'-/.~,w' 1070,~0 30,0 4!:7i,40 2f,,O 4Z76,38 !175, ¢7 SO,.j 429B,20 Ii76,~5 44,58 320,77 873,05 ~:a 320,72 44,52 ~0,4P 44,39 320,38 921,78 44,30 32'0,29 4~62,5,3 !257,84 4405,35 ~30~:gg 442~,68 i322,90 44,,=~ 320,22 954,07 =4,47 320,i? ~70,22 ,. ~v,22 ........ 44,65 320.C~ 44,70 320,08 10!8,72 30,0 4447,79 1343,98. 30,0 44A';; Pa ~ 30,0 -" ':":~ ....~'-". ~ ,~: 7,.,, ~:., .t :.c,..:, Z:4 ~-.,':, c, ,='.o,-..-. · - - ff.~Z, t ,-' 7 44,77 320,08 !034,91 45,04 320,';j 105t,i7 *= "' 320,20 ;aa? ~ -~.~ t_.. 45,26 '~ ~ 44,A~ 320,62 110~,76 i0,0 '~"q 83 t442 4..,.., ~n'O ~oo,14 1464,06 30,0 46i0,71 !~06,£7 o0,0 463!,~? 1527,.37 ~,87 320,72 1t!!,22 44,68 320,40 111,57 44,75 320,~i !143,~5 -- o~Y,o~ i!68,06 44,35 $19 =~ ii76,17 20,0 a653,24 1548,47- 30,3 4.574,4A 30,0 4695,6£ !590,84 30,0 4716,63 16!2,!3 44,q3 31~27 1i92,26 45,05 3i9,!2 i208,32 '- !22~ .. , .~ · 45,54 ~!'P,20 i240,54 45,85 3~'~,01 1256,80 30,0 4758,53 1655,0! 30,0 4800,34 1697,74 3':,0 462i,26 ....-, ~, 50,0 4342,13 !740,3~ 45,85 - . -, 45,85 31~,53 :267,49 45,76 ~!9,67 i305,87 45,6! 31~,Z5 !JzZ,21 45,7.7 317,41 f: ft -471,9! 74t,10 -514,'.~ 807,84 -556,5! -~. 7~ ?46. ~,..~. 320,2? -668,12 10'44,54 320,24 -6J$,4! !072,63 32'9,2! -.6?;',Ao 1093,7: .~,~ ~, /.~,=~ 11!4,80 320,22 -726',63 1135,87 320,23 -.739,94 "=',91 Jzu,24 -753,30 I177.% 320 '~= -7~6,6~ iI%,95 320,25 -7~0,07 ..... ' ..... -793,50 12~,92 520,25 -8~,,76 126!,95 320.25 -320.42 !282,97 320,25 -~o~,~i 1304,03 320,25 -:47,44 l~zJ,~z - .- -886,16 1386,~7 -PO1 ,.LB i ',~9, '?7 -919,75 1488,£B q~.': ~ -Tzs,:: 1445,oo '9~7,67 !466,51 320,25 -751,I~ 1487,65 320,26 -0a4,72 1508,76 ~o~,~ 320,25 -992,18 1551,10 320,22 -I006,04 !572,3! 320,22 -10i9,~7 15f3,57 320,E0 -10'33,~5 I.S14,93 3£0,19 -i047,-¢A 1656 -I061,?~ !6~,92 320,17 -i075,98 167;,44 320,!6 -i089,72 17~:,95 320,15 '~:~; ,~- 1/43,95 0,58 0,62 i 0,63 0,54 0,6? 1,03 1,07 0,13 0,4! 0,49 1,07 0,40 · lOOft 1,76 1,72 0,28 i,5i 2,13 0,83 4,713 1,26 0,42 9,29 0,71 0,44 0,36 0,78 0,!i 0,!7 0,84 0,48 ~ ~,'0 0,88 14.:.0,0.': :_:'0,0. · 54'.;'0,00 30,0 4&:-4.,07 55%,00 I0,0 ~20, :.:0 20,0 4905,09 5_-'-.50,',->) 'J~,O 49.:-'.3,134 -3EC~:ON iNCL,, 1762>27 45,73 2i'?,73 1354,84 ,,v,~_-: iSYi ~7:: g7 45,56 "-" !790,79 45,45 .2i?~7 i376,56 ~ As' 1326,46 45,75 32::,03 i403,'~0 ce,: 32:),11 320,11 .o .. :~:/ lOOT: 0,87 0,74 1,47 0,46 55~0,00 56'!0, )0 5640,00 5700, O0 ::n ' 4946, F? 20,0 4?,48,03 30,0 15'.?o;:: 30,3 :"'~"" ..d'd J. '~, 30,0 503i146 1847,y0 ,. .... ~ :.-:/:J, ':, 7 .' ~ .... = ~s,;:,, ';~n,'-:O i436 J Z,..Y ,4J ........ iC. 7 V, 2,'-4._.' ~ ...,-' O'ZU:iU 19!1,80 45,14 ~20,126 14,$9,55 732,.98 44,67 - S20,i._~, 14651,':-.7 ""7" 1~51 26 320,'' - ! zOO, 'YY i.372,64 320, i ~ -1214,,s6 i893,77 320, ii ~ , , i,O0 5730JM, 5760,00 30,0 5052,73 30,0 ~A73,99 %,0 5095,25 30,0 5116,53 -30,0 5!37,32 ~..~ , . ~.~ ._ i975,23 44,?i 320,30 1516,40 2017,48 44,76 ~?c,._~ ~.--7 1s%,9~ ..... 2036,58 44,3! -1255;37 -:~,J'"~ ~.~ 320,11 -126b,"y2 1$'78,81 320,~ -t282,44 1999,76 320,i2 _'~ ~ 9~:~1 ,~- 3~t~ ,~ . -!309,44 2042,25 320,12 0,!5 0,34 0,24 0,36 0,2! 5680,00 57!0,:~) 5940,00 6000,00 J~O,iO 30,0 3~:.,0 5201,33 :30,0 30,0 5~3:63 2059,75 45,!9 ~-~=~,~v .... 4~AS,S4..~ _. 208!,(~ 45,15 320,25 i597,?! 2i02,25 45,17 320,39 1616,26 2144.74 44.96 320J? !649.12 -1322,97 2063,47 320,12 _1~%,:~ ~n~.7~ 320,12 ~..1 ~ ~ ~ ~. r, ~ 'l~-JU,aw £/Ub __ -~A~,7~ 9~7.g9 320,i3 .~.~ ~ , ~, ,~ !,27 0,43 6040,00 6070,00 t, iOU, Vt' !0,0 :ZSu,/~ 30,0 5273,i3 3~ ^ 53!4,43 30,0 5335,50 91~I.79 2174,16 24,~5 .... 22i5,26 44,57 320,47 1703,65 2236,29 44,60 310,34 i717,38 -iE61,72 2!55,64 320,14 -i3%,i? 2176,85 320,i4 -!403,63 2!96,07 320,14 -. ..... "~'~ ' :320, 1,0! 0,74 0,52 1,27 0,31 6i60, ..4i70,00 62.20,00 .3:0,00 6 ..... 30,0 5357,i2 30,0 5373,38 30,0 30,0 5420,82 '." .~ ~4£9.IA ~= .... 44,~0 320,45 ~7~,,~ 22.73,49 44,?3 320,55 1752,46 ~79,67 45,C~ 320~45 i768,83 2320,34 44,38 320,38 !785,i7 2341,75 44,79 3i9,74 !80i,37 -14.c4,79 228.1,36 320,15 ~. ,.- ,,~ - ~%~,~: 2262,:z '3£0,''= -1475,94 ?.%.q,.73 -1,.39,~5 2324,?~ 320,!6 ,' 0,50 0,62 i,53 ,5'3!0,00 6340,00 ._~370WO · 1400, O0 6476, )7 30,0 5463,28 30,0 5484,35 30,0 5505,4i 30,0 5526,36 ,%,i 557'?,.~ '~ 2363,14- 45,2,5 ']19.52 i817,58 £OOff, ...... 2405,74 45,a^.. 3i8,70 2427,I! 45,93 317,23 1865,80 2481,70 %,20 320,87 1907, -!516,7~ 2367,32 320,15 :elv,~4 320,14 -1544,78 "' ' -!575,04 2486,25 320,0? 1,62 0,59 3,84 3,46 6570,67 6608, ~.4 .3763, .i7 O0'J! +/. 5710,27 5772,?1 55?3,09 ..:_,j~,~ ,,,~ 32!,34 1960,7i 2622,60 47,38' 3£0,75 2016,76 2765,3! 50,71 320,5? 2840,72 52,0 320,07 2!35,76 -i638,24 2555,04 320,i2 -1683,5.5 2,SZ7,28 320 -1728,34 2698,i8 320,17 'II~ ~ -~=~ 2845,66 !,04 0,133 1,42 1.60 2,04 NX-09 ft 7047, ~'?. 73,.:' . ~94~, ?'?' ~ .... ,~ ,,, ,,,,, 7:44,;: 97,3 7740,!5 75,6 60_=.'~,03 ,7~.3,'-'~ ;472~6 6099,56 7a.27,24 ¢.:,5 .A~/.'~ """' ..... SURVEY ************* CiRCU%AR ARC METHOD******** :'"; ~ S~,35 320,23 2243,55 2'~96,05 56,3i ~20,£0 2305,24 3077,24 59 ~ ...... :*' 2367 3157,76 61,43 .321,j4 ~430,37 324i,39 63,32 320,52 24~5,23 ,..-:.,, ~.,u,,,. M::FLACE~D4? :,'- f: ft -1870.37 -i92!,83 -2024,60 3i63,i8 -2077,55 324.5.90 320,18 320,:? 320,22 !00fi' 1,84 2,63 2,88 2,06 7614,66 771.5,69 /~V~i~ 92,1 61¢2,94 95,i :0i,8 6~7,63 31,7 6310,52 ~37=,47 A= :~ 320,63 2~59,50 341i,95 67,33 317.77 3506,76 70.37 320,~0 2700,07 357!,03 72,:~ 32!,32 36.66,~5 73,02 - 320,98 2826,41 -2130,33 3330,i0 320,£3 -~46,'D 3512,66 320,23 -?~79,90 3597,01 320,2E -2348,33 3674,99 320,27 '-=,73 i,69 3,08 2,20 , ~V 8077,22 8i70,61 ?4.6 6336,48 95,2 6360,99 93.6 6364,74 -9~,5 6432,C4 375y,/6 /..,~:__ ~a:,_.-~ 2897,20 zo%,Za 75,0& 321.4n '" .... .... .-~ · 3942,20:~,~: =' q?~.'?~ 3a~,92._. , '~ 3!1!,35 4130,21 76,Z? 32i,76 3i57,00 -P~o%~8 376i.90 320,2? -2463,2a, 3857,~'"' 32n,32. -~;~4 ?2 .a039,94 R2n.~,? -2637,0i 4i36,52 320,3? 2,23 0,33 0,62 0,24 0,60 845!,58 ~4~,/:'"" 8741,38 8,f.,8 .3453,21 100,4 6478,13 92,8 6500,97 96,6 652~47 '74,.,46547,29 44fi1,-'~ ~ .... ._. ... e= 75,7'? ~¢~,77 ~9~,74 .... ,U~ ~SSA,3A 76,04 '~,~7 -2689,27 4220,65 320,42 -7747,75 43i7,89 320,44 ~,.~ ,~v, ,o~ 320,47 -~o¢,_.~'" ~ 4501,49 320,50 -2920,0t 4593,30 32:3,53 0,90 0,24 0,i8 O,~o 8930,4! 9i20,78 92i4,46 9310,47 96,8 66i6,34 ?3,7 6638,63 ?6,0 6661,$3 4678,37 75,69 322,20 3617,86 4767,i1 7A.n~ 323,74 4863,07 76,Z? 321~!0 3764,78 4954,0! 76,20 .32i,48 3835,80 ous/,iO 75,82 ~ O0 -='"'A.r/.,o~':s 4684,8t o~u,:o"=" =' -3030,¢7 4//--V5,47 320.50 -3088,28 4867,40 320,64 -3145,20 4960,~ 320,65 -3202,a8 5053,53 ~'.~ ~^, o/'? 0,50 1,64 2,66 0,40 0,66 9406,29 9501,7! 9669,77 95,4 6709,06 99 '~ 873! A¢ 96,! 6755,55 95,2 6779,79 5139,96 75,73 322,83 3982,54 5232,38 75,5! 322,i9 4055,87 532!,69 ~,~3 3~,06 4126,40 54i4,73 75,4! 32!,46 4179,>v ~avo,.:~ 75,i4 520,zZ 427,3,89 -3259,53 514.5,37 320,70 -3315,78 5233,75 320,73 -3370,63 5326,07 320,76 -3428,P~ 542! _. ,1., -3¢36,38 5513,20 320,77 0,84 0,69 0,47 0081 1,29 %77.67 'D7~,63 10065,46 lO!-fO,3: 10257,42 92,5 6K~3,&7 95,0 6826,65 94,? 687!,10 97,! ~893,84 ~SOa.n=- /5,44 320,27 5687,89 76,03 320,12 44!0,36 5777,86 76,34 3i9,75 4477,37 5869,32 76,47 319,2! 4549,46 5963,'?~ 76.~ 3i8.86 4620,7a -3543,60 5602,6.7 320,77 -360272 5674,7! 320,7.5 -3660.55 ~84,84 320,74 -3720,45 5877,0! 320,72 "-~ ~ 5971. -~/~,~4 SS 320.70 0,35 0,62 0,51 0,57 0.3-'5 10354,76 i0449,91 10540,07 10638,37 10731,53 97,3 6917,1~ 95,2 6940,34 90,1 6962,31 98,3 6788,~3 93,2 7012,68 6058,10 . 75,33 318,64 469!,80 .6i50,10 75,98 3i9,03 476i,29' 6237,1! 75,13 3!8,77 ¢B27.16 6331.72 74,78 3!8.7~ 4895.67 ~ ...... 4 74 .... ~ .... -3844,65 6065,83 320,67 -3705o42 6158,10 320,04 -3962,68 6245,34 320,62 -4025,1! 6340,23 320,59 -4~-4,14 64313,i2 320,57 0,67 0,43 0,94 0,41 0,43 D£F'Th DEF!H 10.3Z7, ".-N 75,?. 7037,58 · !0'.;-'22,---':_,,., 95,i 70,,:,7',0; " ...... '- " 7085,46 i1112,00 97,8 7!10,75 11207,,'.-.7 'L5,,7 !135,6i SECTION i~CLN, N/--S 3513,69 74,78 3i8&! 503&,41 ~g~,32 75,£3 3i?,i? 5i05,73 56?3,72 75,1, 317,~7 5173,02 6787,8? 74,84 3!9,33 5244,7! 6880.00 7~ "' ,17 ,,~ 319 cee/ · -4!aa,9~,. ._65~ ,.,,~' 320.55 0,37 -42(~,22 66'i4,60 3i0,52 0,47 -42-52,'79 8703.22 32'3,51 0,30 -4334,,57 6687,97 320,48- 0,!3 11302,4! 11396,70 11490,06 11584,37 11680,79 94,7 7!60,i8 ?4,3 7i84,46 93,4 ..... 94,c %,4 7258,84 7062,20 75,ii 5i9,69 5453,86 ......... 7~ c~ ~w~,?~ 5523,03: /£D£,£e ,, 7243,09 74.,s^... 32,3,~3 J~z,~=="~ '"~ /0~2,=/ 7~,54 3i9,80 %64,0? -4444,i3 6~81,4~ 320,46 -4501,75 7072,56 320,46 -4560,68 7162,7a 320,'= -461'?,10 7253,80 320,45 -4676,78 7346,75 09;),44 0,44 0,2! 0,35 0,35 l!WS,iO 11670,30 11963.30 !2(~0,63 12152,92 94,4 7284,01 ~,i 7308,9! v. ~-,.~- -. ! Od£ ~ / 'Y 96,8 7357,50 -'72,3 7381,41 ~02,02 75,17 320,62 5945,74 779t ,04 74.7? "*,64 ,¢31a ' ' ....... 2£V .~ -4737',58 7437,70 320,43 -~v~g ~ 7~-' =? -~. .~ ~.-~ -4970,50 7802,68 320,43 0,77 0,53 0.41 12248,?2 12438,35 !2533,~0 !2826,~2 ?6,0 7406,76 9s,O 743i,87 94,4 7456,83 95,5 748'2,25 95,i 7506,73 ~. .. ~.. -~ .0 w ~-'.- · .-. 7,~7~.,]~ 74,76 320,?4 Al~A,9~ 8065,98 74,58 321.~% 62~',69 3157,70 74J3 32!,09 6299.24 -502¢,40 785'5,27 320,43 -5087,5! ~" ..... /~,~,'yz 320,43 -~4.=s 8077,96 e%,~4 -5202,69 81,59,9o 320,45 -5250,0~ 626i,8! 320,46 0.62 0.20 0,09 1,04 12724,i9 12710,21 t34)06,13 95,3 7520,74 ~2,1 7553;60 ?3,9 7575,77 95,9 7600,97 ?4,3 7324,'79 ~34! ~ 75,64 _ ~w~ ~! ,/i .... ~s;2,O0 75,59 522,38 6585,24 o/VO,O0 /3. ......... -5317,34 8324,04 320,47 -5372,48 ~4~o,c .~ 2! 320,~g,_ -5428,31 "=~ _. 320 -' 0~4,!,4 ~ -5484,88 862b,96 3'20,52 -5540,53 87!5,i0 320,54 0,29 0,23 0,44 0,30 0,49 i'¥oq 13291 13387,~ 13666,65 !3763,C~ 13860,52 13902,53 13930,49 94.6 764¢,55 96,3 7674,32 ?6,4 7700,42 91,I 7725,00 96,4 7750,52 9~,'? 7774,26 96,2 777g,17 '?7,5 7624,25 42,0 7834,57 34,0 27843,63 ,.- .... 74,81 ~...,~o ... " 6875,67 9070,5,5 74,18 3~,37 7018,74 9!63,49 75,11 .322,63 7092,47 /=.,=,23- 74,?4 .x~,,,. 7162,61 7345,!2 75,04 32,39 7235,9! · .-.~ ~u ~ . ~t~ ~479,92 75,28 ?..2~63 7343,00 -5597.13 6809,47 320,55 -5654,q3 3902,!0 320,57 -57!I,i7 8994,97 320,5~ -5~2!,30 9!75,55 320,62 -5875,7i ?264,2? 320,64 -5932,82 9357,17 320,65 -5790,% ~451,32 320,67 -6014,7i 7491,9! 320,68 -6034,65 9524,73 320,69 i,0! 1,09 0,!9 !,00 0,64 · .m~ 0,4! 14220,45 72o! 97,3 '"'~ I0 '74,0 79i6,i3 ~a,7 79~0 :~ 9,301.80 96?6,37 75,2~ 323,53 7516,33 9787,v* ?878,79 75,02 323,53 7~62,75 ~o~O.aT,,...,. .... 74,62 .q2.~,27 7735,76 -6088,!~ 96i3,7! 320,7! 0,98 -A144,'w. . ~, 7708,17 .....J=O,,.. 0,09 %198,47 97%,75 320,7.6 0,!9 -6£52,?1 ?850,38 320,7? 0,i4. -6306,96 9980,97 320,8! 0,33 ?J:'TH f: fr. ft 14503, .;5 '74,9. 79:89.8'.:' ~[)-.., "'- .4 i4f.;'0,~4 5'2,3 8-038,70 '" ....... '?5,? :"~ !48&3,87 '~7,+ 60.'.-.'0,37 ?~RGET 10061,0q 10112,15 14,85 323~06 . . . . . ~ ~ ~-.- ,~,~ !0427,~3 7~,2~ 32~+77 BIC~,05 f: ft -$361,57 10072,45 -6416,04 I01,f3~47 -6468,)8 10212,45 -6523,~0 10344,:'? -6577.24 10438,43 320,83 320,~8 320,¢0 320,~3 DLS !OOfr 0,45 i,01 1,03 1,71 14317,I¢ I~671.20 15263,,% i5358,3~ ..-- %,2 8177,52 I0516,¢9 73,~ 325,82 8177,72 10607.07 73,34 328,04 8252,40 !0699.17 73.4i 326,92 ~329,23 ........ /4,vi ~~A.~a 8407 ~' i088i,~4 TS,AA._ ' ~¢~.~,~.;~ 8484,55 -6630," zo 10527,78 320,'?7 -6680,.% 10617.59 321,01 -673!,53 10709,40 321,0~ -678i,i! i%01,56 32!,21 -482~,00 10~i,41 32!,!? 1,30 0,33 0,87 1,46 0,35 15454,58 15545,14 i5.541,22 15736,78 ~5A~i .... .... ?6,2 8:0,77 90,6 827.5,24 95,7 8332,29 -74,'? 8360,40 i0973,97 /~,=.-* ==328,89 8563,3~ 1!060,5i 73,47 328,86 8637,76 '''=~ ~= 79,?4 ~Ofi ~z ~ ...... . ~ 11332,73 72,86 ~'~,Olo:v 8875,84 %877;2! 10983,05 -$722,i3 11067,i8 -6%8,50 11160,26 -7013,23 11250,46 -7058,06 11340,05 321 ~ 321,29 0,70 0,41 1,87 0,77 0,74 15923,'?0 .,Pt:./ ,/U' . i,4206, i..A27Z ,'?2 92,0 8387,25 %.8 ,5.4t3,98 92,.7 8433,.63 ~., ,.,.-,; · 91,2 3490,46 !!420,18 73,20 330,i4 8952,08 11509,55 73,68 32¢,5? 3027,6A !1597,98 74,18 330,8I 9107,!0 1i630,01 74,2! 330.07 9!87,72 11777,30 74,31 333,00 3263,83 -7101,34 -7!47,08 -719!,33 -7237.06 -7280,35 I!427,~ 11516,02 11604,07 ii675,70 11782,64 32!,57 32!,70 0~£,/'/ 32!,33 0,39 0,76 1,37 0,75 0,07 16398,49 16495,30 10685,58 16779,76 1,X,,6 8517,69 95.7 8597, 94,2 8624,34 11873,46 74,~~ 320,48 9347,87 11966,08 74,1! 328,76 9428,22 12052.77 73,~7 329,43 9502,96 I2147,86 73,26 330,00 9585,54 12237,47 73,1! 32~,78 9663,53 -7329,0! ':~/,.,ii -7420,85 -7469,08 -75i4 11878,43 12151,34 ILLql,L/ 32!,% 321,76 322,0! 5." ." 322,13 0,46 1,72 0,74 0,30 0,27 16675,02 10966,30 17~7,03 i7068,49 I7!.50,29 95,7 8652,37 90,7 868i,23 80,7 8708,11 2!,5 87!5,53 31,3 874~.00 12328.47 72,27 329,47 ?742,48 !24!4,il 7!,TM~= 327,87 9~16,83 12489,73 69,63 230,45 9882,87 t2774,67 68,92 332,~4 9976,11 ,7560,59 -7604,07 -765i,30 -7692,32 12332,0I i2417,41 12472,81 12512,72 12597,4! 322,24 322,30 322,37 0,93 1,18 1,91 1,9! 2,19 17~3, !6 17349,02 17444,34 !75%,39 i742--"5--. ,Oz· 92,? 8780,79 95,3 88!4,22 95,? 8885,48 94,1 892!,~2 12660,35- 69,74 333,48 10053,65 12768.87 ~" ''~ 333 .... "= .-Y,e~ ,~ 10133 i2857.01 68,0i o¢=~,'79 10213,66 12944,63 67,38 332,52 10292,58 13030.1b o/.19 '- ~4,5~ 10370,33 -7731.55 -7771,83 -7612,25 -7852,3~ -7891,57 12682,77 12770,99 128.58,86 !29~.5,24 13031,53 3';/.2,44 322,52 322,5-,~ ~.,-, ,- ~,.',66 1,10 0,41 1,50 0.79 17723,72 17824,71 !7720,79 17975,88 18077,00 34,7 8759,07 ?5,0 $977,04 . ~ i ?080.35 101,I 1 .... .,57 86,47 334,78 10449,01 ~o£uz,O0 oo, ~u ~3a,gl. . 1052/,73 13286,67 .M,31 o~,~7 10667,2! zoo~5.~? 64,37 335,79 13424,14 vo,/u 335,80 -7%6,02 -8002,53 -8060,21 13116,5? 13287 ~ 13335,89 13424,57 322 322, 323, 3~,I0 0,78 0,17 2,10 0,86 0,66 ::"E? ~H DEF'?H f: f: · i~.2'-:5,."JO '.94:0 9'17.:'. , 4.7 i,£,426, :)0 '?6,2 i.3520,~}J ?4,0 '73!5,3./,. PRL"iJEErTE£, I.~570,00 50,0 9340,.3,5 _' ._,_'v_ ~ £/ · ' ~'"' ,~.A ..... :"~ L3723,.34 323,42 13802, :..~. 32_2,30 13843,6.7 gyro/data B.P. EXPLORATION (Alaska)Inc. Niakuk Well NK-09 North Slope Alaska Pool Rig 7 Gyro Multishot of 4 1/2 Inch Drillpipe Survey date: 07 November, 1994 Job number: AK1094G241 Gas Cons. ~ch0r~ ' SR241 .DOC gyrodata Gyrodata Incorporated P.O. Box 79389 Houston. Texas 77279 713/461-3i 46 Fax: 713/461-0920 November l 1, 1994 Ms Katie Nitzberg BP Exploration 900 East Benson Blvd. Anchorage, Ak 99519-6612 MB?-2 Re'. Dear Ms. Nitzberg Niakuk, Well #NK-09 North Slope Alaska Pool Rig 7 Enclosed please find one (1) original and six copies (6) of the completed survey of Well NK-09 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Robert Shoup Assistant Operations Manager RJS/gr Serving the Worldwide Energy Industry with Precision Sun/ey Instrumentation gyro/data CONTENTS JOB NUMBER · AK1094G241 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR241 .DOC ,,gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR241 .DOC gyro/data DISCUSSION JOB NUMBER' AK1094G241 Tool 510 was run in well NK-09 on a Atlas 15/32" Wireline in the 4 1/2 inch drillpipe to a depth of 6420 ft.. The wireline rezero on return to surface was 00009. SR241 .DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER' AK1094G241 The data for this survey and the calculations for this survey were obtained and performed by me according to the standards and procedures as set forth by Gyrodata, Inc., and are true and correct to the best of my knowledge. ROB SHOUP OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. ~ This report represents a true and correct directional survey of this well based on the original data .. obtained at the wellsite. Checked by :- ERNIE SURMAN OPERATIONS ENGINEER SR241 .DOC gyro/data 2. SURVEY DETAILS SR241 .DOC lyro/data SURVEY DETAILS JOB NUMBER: AK1094G241 CLIENT: B.P. EXPLORATION (ALASKA)INC. RIG: POOL 7 LOCATION: WELL: NORTH SLOPE ALASKA NIAKUK NK-09 LATITUDE: 70.347140 N LONGITUDE: 148.201815 W SURVEY DATE: 07-NOV-1994 SURVEY TYPE : DRILLPIPE SURVEY OF 9 5/8" CASING DEPTH REFERENCE: POOL R.K.B. MAX. SURVEY DEPTH: 642O SURVEY TIED ONTO: SURFACE SURVEY INTERVAL: 100 ft OUTRUN 30 ft. OPEN HOLE TARGET DIRECTION: 323.560 GRID CORRECTION: o CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: SHOUP SR241 .DOC ~tyro/data 3. OUTRUN SURVEY LISTING SR241 .DOC A Gyrodat a D i r e c t i ona I Survey for B.P. EXPLORATION WELL: NIAKUK NK-09 Location: POOL #7, PRUDHOE BAY, ALASKA Job Number: AKl194G241 Run Date: 7-Nov-94 01:30:00 Surveyor: ROB SHOUP Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.347140 deg. N Sub-sea Correction from Vertical Reference: 59 ft. Bearings are Relative to True North Proposed Well Direction: 323.560 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gy r o d a t B.P. EXPLORATION WELL: NIAKUK NK-09 Location: POOL #7, PRUDHOE BAY, ALASKA Job Number: AKl194G241 a Dire ctional Survey MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. Page 0.0 0.00 0.00 0.00 0.0 -59.0 CLOSURE H O R I Z 0 N T A L DIST. AZIMUTH C O O R D I N A T E S feet deg. feet 0 - 6420 FT. GYRO SURVEY RUN IN DRILLPIPE. MEASURED DEPTHS REFERENCED TO POOL RIG 7 R.K.B~ AT'59 FT. 0.0 0.0 0.0 0.00 N 0.00 E 100.0 .26 339.79 .26 100.0 41.0 200.0 .26 287.09 .23 200.0 141.0 300.0 .26 312.34 .12 300.0 241.0 400.0 .29 304.54 .04 400.0 341.0 500.0 .39 310.98 .11 500.0 441.0 600.0 .44 317.34 .07 600.0 541.0 700.0 .35 315.63 .09 700.0 641.0 800.0 .17 316.14 .19 800.0 741.0 900.0 .29 310.53 .12 900.0 841.0 1000.0 .27 280.59 .15 1000.0 941.0 1100.0 .16 259.53 .14 1100.0 1041.0 1200.0 .18 238.42 .06 1200.0 1141.0 1300.0 .21 226.46 .06 1300.0 1241.0 1400.0 .17 230.79 .05 1400.0 1341.0 1500.0 .22 257.39 .10 1500.0 1441.0 1600.0 .55 274.69 .34 1600.0 1541.0 1700.0 1.23 294.73 .74 1700.0 1641.0 1800.0 2.11 306.03 .93 1799.9 1740.9 1900.0 4.75 311.34 2.66 1899.7 1840.7 2000.0 5.87 315.21 1.17 1999.3 1940.3 .2 .6 1.0 1.5 2.1 2.8 3.5 3.9 4.3 4.7 5.0 5.0 5.0 5.0 5.1 5.5 6.7 9.4 15.2 24.3 .2 339.8 .6 322.4 1.0 312.9 1.5 311.4 2.1 310.5 2.8 311.5 3.5 312.5 4.0 312.9 4.4 312.8 4.8 311.2 5.1 308.7 5.3 306.0 5.4 302.5 5.5 299.2 5.7 296.5 6.3 293.7 7.8 292.7 10.7 295.2 16.6 300.4 25.7 305.1 .21 N .08 W .49 N .38 W .71 N .77 W 1.01 N 1.15 W 1.38 N 1.61 W 1.89 N 2.13 W 2.39 N 2.61 W 2.71 N 2.92 W 2.98 N 3.22 W 3.19 N 3.64 W 3.21 N 4.01 W 3.10 N 4.27 2.89 N 4.54 2.67 N 4.79 W 2.54 N 5.09 W 2.53 N 5.76 W 3.02 N 7.22 W 4.56 N 9.69 W 8.38 N 14.29 W 14.74 N 21.00 W A Gy r o d a t a B.P. EXPLORATION WELL: NIAKUK NK-09 Location: POOL ~7, PRUDHOE BAY, ALASKA Job Number: AKl194G241 D i r e c t ional Survey Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2100.0 6.35 317.91 2200.0 6.73 319.58 2300.0 7.23 319.71 2400.0 7.67 318.38 2500.0 9.00 317.44 .56 2098.7 .42 2198.1 .50 2297.3 .47 2396.5 1.34 2495.4 2039 2139 2238 23"37 2436 .7 .1 .3 .5 .4 34.9 46.3 58.4 71.3 85.7 36.1 308.4 47.4 310.9 59.4 312.7 72.3 313.8 86.8 314.5 22.48 N 28.31 W 31.05 N 35.82 W 40.31 N 43.69 ' 50.10 N 52.19 v, 60.85 N 61.92 W 2600.0 12.57 317.34 2700.0 14.87 317.20 2800.0 16.45 317.88 2900.0 18.70 318.78 3000.0 21.48 319.02 3.57 2593.7 2.30 2690.8 1.59 2787.1 2.27 2882.4 2.78 2976.3 2534 2631 2728 2823 2917 .7 .8 .1 .4 .3 104.3 127.9 154.7 184.8 219.0 105.5 315,.0 129.2 315.4 156.2 315.8 186.3 316.2 220.7 316.6 74.61 N 74.58 W 92.03 N 90.67 W 111.95 N 108.89 W 134.51 N 128.95 W 160.39 N 151.53 W 3100.0 23.28 319.46 3200.0 24.27 320.39 3300.0 26.92 321.27 3400.0 29.99 322.47 3500.0 32.30 323.73 1.81 3068.8 1.06 3160.3 2.68 3250.5 3.12 3338.4 2.39 3424.0 3009 3101 3191 3279 3365 .8 .3 .5 .4 .0 257.0 297.2 340.4 388.0 439.7 258.7 317.0 299.0 317.4 342.1 317.8 389.6 318.3 441.2 318.9 189.23 N 176.38 W 220.08 N 202.33 W 253.58 N 229.61 W 291.08 N 259.01 W 332.44 N 290.04 W 3600.0 34.56 323.65 3700.0 36.45 323.61 3800.0 37.83 322.77 3900.0 39.32 321.60 4000.0 41.02 320.66 2.26 3507.4 1.89 3588.8 1.48 3668.5 1.66 3746.7 1.80 3823.1 3448 3529 3609 3687 3764 .4 .8 .5 .7 .1 494.8 552.9 613.2 675.6 740.0 496.1 319.4 554.0 319.9 614.3 320.2 676.6 320.4 741.1 320.4 376.82 N 322.66 w 423.58 N 357.10 471.92 N 393.28 W 521.17 N 431.52 W 571.38 N 472.00 W 4100.0 42.73 320.18 4200.0 44.14 319.27 4300.0 43.87 318.98 4400.0 45.38 319.17 4440.0 44.53 319.10 1.74 3897.6 1.54 3970.2 .33 4042.1 1.51 4113.3 2.12 4141.6 3838 3911 3983 4054 4082 .6 .2 .1 .3 .6 806.7 875.3 944.5 1014.6 1042.7 807.9 320.4 876.6 320.4 946.1 320.3 1016.3 320.2 1044.6 320.2 622.83 N 514.53 W 675.28 N 558.98 W 727.81 N 604.45 W 780.88 N 650.47 W 802.25 N 668.96 W A Gy r o d a t a B.P. EXPLORATION WELL: NIAKUK NK-09 Location: POOL ~7, PRUDHOE BAY, ALASKA Job Number: AKl194G241 Dire ctiona 1 Survey Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 4470.0 44.64 319.42 4480.0 44.60 320.06 4510.0 44.60 320.52 4540.0 44.64 320.61 4570.0 44.58 320.77 .83 4163.0 .52 4170.1 .07 4191.4 .25 4212.8 .41 4234.2 4104 4111 4132 4m53 4175 .0 .1 .4 .8 .2 1063.7 1070.7 1091.8 1112.8 1133.9 1065.6 320.2 1072.6 320.2 1093.7 320.2 1114.8 320.2 1135.8 320.2 818.21 N 682.70 W 823.57 N 687.24 W 839.77 N 700.70 W 856.05 N 714.08 872.35 N 727.43 W 4600.0 44.50 320.72 4630.0 44.52 320.42 4660.0 44.39 320.38 4690.0 44.30 320.29 4720.0 44.53 320.22 .29 4255.5 .71 4276.9 .43 4298.3 .39 4319.8 · 79 4341.2 4196 4217 4239 4260 4282 .5 .9 .3 .8 .2 1154.9 1175.9 1196.9 1217.8 1238.8 1156.9 320.2 1177.9 320.2 1198.9 320.2 1219.9 320.2 1240.9 320.2 888.65 N 740.75 W 904.89 N 754.10 W 921.08 N 767.50 W 937.22 N 780.88 W 953.37 N 794.30 W 4750.0 44.49 320.19 4780.0 44.49 320.22 4810.0 44.65 320.08 4840.0 44.70 320.08 4870.0 44.77 320.08 .14 4362.6 .07 4384.0 .62 4405.4 .15 4426.7 .26 4448.0 4303 4325 4346 4367 4389 .6 .0 .4 .7 .0 1259.8 1280.7 1301.8 1322.8 1343.9 1261.9 320.2 1283.0 320.2 1304.0 320.2 1325.1 320.2 1346.2 320.2 969.52 N 807.76 W 985.68 N 821.22 W 1001.84 N 834.72 W 1018.02 N 848.25 W 1034.21 N 861.80 W 4900.0 45.04 320.25 4930.0 45.21 320.20 4960.0 45.26 320.45 5000.0 44.84 320.62 5010.0 44.89 320.72 .97 4469.3 .59 4490.4 .63 4511.6 .09 4539.8 .84 4546.9 4410 4431 4452 4480 4487 .3 .4 .6 .8 .9 1365.0 1386.3 1407.5 1435.8 1442.8 1367.4 320.2 1388.7 320.2 1410.0 320.2 1438.3 320.2 1445.3 320.2 1050.48 N 875.37 W 1066.81 N 888.97 1083.21 N 902.57 1105.07 N 920.56 W 1110.52 N 925.03 W 5040.0 44.88 320.40 5070.0 44.75 320.31 5100.0 44.81 319.88 5130.0 44.85 319.51 5160.0 44.93 319.27 .75 4568.2 .50 4589.5 1.01 4610.7 .90 4632.0 .63 4653.3 4509 4530 4551 4573 4594 .2 .5 .7 .0 .3 1464.0 1485.1 1506.2 1527.3 1548.4 1466.5 320.2 1487.6 320.2 1508.8 320.2 1529.9 320.2 1551.1 320.2 1126.87 N 1143.16 N 1159.37 N 1175.50 N 1191.57 N 938.48 W 951.97 W 965.53 W 979.21 W 992.99 W A Gy r o d a t a B.P. EXPLORATION WELL: NIAKUK NK-09 Location: POOL #7, PRUDHOE BAY, ALASKA Job Number: AKl194G241 D± rectiona 1 Survey Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL C O O R D I N A T E S feet 5190.0 45.05 319.12 5220.0 45.25 319.05 5250.0 45.54 319.20 5280.0 45.85 319.31 5310.0 45.85 319.36 .52 4674.5 4615 .71 4695.7 4636 .01 4716.7 4657 .08 4737.7 4678 .12 4758.6 4699 .5 .7 .7 .7 .6 1569 1590 1612 1633 1654 .6 .8 .1 .5 .9 1572.3 320.2 1593.6 320.2 1614.9 320.2 1636.4 320.1 1657.9 320.1 1207.62 N 1006.85 W 1223.69 N 1020.78 W 1239.84 N 1034.76 ", 1256.11 N 1048.77 ,~ 1272.44 N 1062.80 W 5340.0 45.85 319.53 5370.0 45.76 319.69 5400.0 45.81 319.25 5430.0 45.77 319.41 5460.0 45.78 319.38 · 39 4779.5 4720 · 49 4800.4 4741 · 05 4821.3 4762 · 39 4842.2 4783 .07 4863.1 4804 .5 .4 .3 .2 .1 1676 1697 1719 1740 1762 .4 .9 .3 .8 .2 1679.4 320.1 1700.9 320.1 1722.4 320.1 1743.9 320.1 1765.4 320.1 1288.79 N 1076.79 W 1305.17 N 1090.73 W 1321.52 N 1104.70 W 1337.83 N 1118.72 W 1354.15 N 1132.71 W 5490.0 45.56 319.43 5500.0 45.45 319.57 5520.0 45.63 319.94 5550.0 45.75 320.03 5580.0 45.69 320.17 · 73 4884.1 4825 · 52 4891.1 4832 · 61 4905.1 4846 · 46 4926.1 4867 .40 4947.0 4888 .1 .1 .1 .1 .0 1783 1790 1805 1826 1847 .6 .7 .0 .4 .8 1786.9 320.1 1794.0 320.1 1808.3 320.1 1829.8 320.1 1851.2 320.1 1370.44 N 1375.87 N 1386.76 N 1403.20 N 1419.68 N 1146.67 W 1151.31 W 1160.53 W 1174.33 W 1188.11 W 5610.0 45.26 320.20 5640.0 45.35 320.10 5670.0 45.14 320.36 5700.0 44.87 320.18 5730.0 44.83 320.21 · 43 4968.1 4909 .39 4989.2 4930 · 95 5010.3 4951 · 99 5031.5 4972 · 14 5052.8 4993 .1 .2 .3 .5 .8 1869 1890 1911 1932 1954 .2 .5 .7 .9 .0 1872.6 320.1 1894.0 320.1 1915.3 320.1 1936.5 320.1 1957.6 320.1 1436.11 N 1452.48 N 1468.86 N 1485.17 N 1501.42 N 1201.80 W 1215.47 1229.10 1242.66 W 1256.20 W 5760.0 44.91 320.30 5790.0 44.85 320.35 5820.0 44.76 320.27 5850.0 44.81 320.32 5880.0 45.19 320.29 .35 5074.0 5015.0 1975 .25 5095.3 5036.3 1996 .35 5116.6 5057.6 2017 .20 5137.9 5078.9 2038 .29 5159.1 5100.1 2059 .2 .3 .4 .5 .7 1978.8 320.1 2000.0 320.1 2021.1 320.1 2042.2 320.1 2063.4 320.1 1517.70 N 1533.99 N 1550.26 N 1566.51 N 1582.83 N 1269.73 W 1283.25 W 1296.75'W 1310.25 W 1323.80 W A Gy r o d a t a B.P. EXPLORATION WELL: NIAKUK NK-09 Location: POOL #7, PRUDHOE BAY, ALASKA Job Number: AKl194G241 Direct ional Survey MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL CLOSURE DEPTH DEPTH SECTION DIST. AZIMUTH feet feet feet feet deg. 5910.0 45.19 320.25 .09 5940.0 45.17 320.39 .33 5970.0 45.26 320.52 .41 6000.0 44.98 320.59 .94 6010.0 44.88 320.62 1.01 5180.2 5121.2 2080.9 2084.7 320.1 5201.4 5142.4 2102.2 2106.0 320.1 5222.5 5163.5 2123.4 2127.3 320.1 5243.7 5184.7 2144.6 2148.6 320.1 5250.8 5191.8 2151.7 2155.6 320.1 6040.0 45.10 320.57 .73 6070.0 44.95 320.51 .50 6100.0 44.57 320.47 1.27 6130.0 44.60 320.34 .30 6160.0 44.80 320.45 .71 5272.0 5213.0 2172.9 2176.8 320.1 5293.2 5234.2 2194.1 2198.0 320.1 5314.5 5255.5 2215.2 2219.2 320.1 5335.8 5276.8 2236.2 2240.2 320.1 5357.2 5298.2 2257.3 2261.3 320.1 6190.0 44.93 320.55 .49 6220.0 45.06 320.45 .49 6250.0 44.88 320.38 .61 6280.0 44.79 319.74 1.54 6310.0 45.36 319.62 1.90 5378.4 5319.4 2278.4 2282.5 320.1 5399.6 5340.6 2299.6 2303.7 320.1 5420.9 5361.9 2320.7 2324.9 320.1 5442.1 5383.1 2341.9 2346.1 320.1 5463.3 5404.3 2363.1 2367.3 320.1 6340.0 45.41 318.94 1.64 6370.0 45.46 318.70 .59 6400.0 45.93 317.23 3.83 6420.0 46.31 318.82 6.03 5484.4 5425.4 2384.3 2388.6 320.1 5505.5 5446.5 2405.6 2410.0 320.1 5526.4 5467.4 2427.0 2431.5 320.1 5540.3 5481.3 2441.4 2445.9 320.1 Final Station Closure: Distance: 2445.87 ft Az: 320.08 deg. Page HORIZONTAL COORDINATES feet 1599.20 N 1615.58 N 1632.00 N 1648.41 N 1653.87 N 1670.26 N 1686.64 N 1702.94 N 1719.17 N 1735.43 N 1751.75 N 1768.12 N 1784.46 N 1800.68 N 1816.87 N 1833.06 N 1849.14 N 1865.09 N 1875.81 N 1337.40 W 1350.99 W 1364.55 T,~ 1378.05 1382,53 W 1396.00 W 1409.48 W 1422.92 W 1436.35 W 1449.80 W 1463.26 W 1476.75 W 1490.26 W 1503.84 W 1517.58 W 1531.51 W 1545.58 1559.96 1569,60 W A Gyro da t a D i r e c t i ona i Survey for B.P. EXPLORATION WELL: NIAKUK NK-09 Location: POOL #7, PRUDHOE BAY, ALASKA Job Number: AKl194G241SS Run Date: 7-Nov-94 01:30:00 Surveyor: ROB SHOUP Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.347140 deg. N Sub-sea Correction from Vertical Reference: 59 ft. Bearings are Relative to True North Proposed Well Direction: 323.560 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gy r o d a t a B.P. EXPLORATION WELL: NIAKUK NK-09 Location: POOL #7, PRUDHOE BAY, ALASKA Job Number: AKl194G241SS Direct SUBSEA I N C L AZIMUTH VERTICAL DOGLEG VERTICAL DEPTH DEPTH SEVERITY SECTION feet deg. deg. feet deg. / feet 100 ft. -59.0 0.00 0.00 0.0 0.00 0.0 0 - 6420 FT. GYRO SURVEY RUN IN DRILLPIPE. MEASURED DEPTHS REFERENCED TO POOL RIG 7 R.K.BJ AT 59 FT. i o n a 1 CLOSURE DIST. AZIMUTH feet deg. 0.0 0.0 Survey Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .26 308.70 159.0 .24 .5 200.0 .26 301,99 259.0 .16 .9 300.0 .28 307.74 359.0 .07 1.3 400.0 .35 308.34 459.0 .08 1.8 500.0 .42 314.73 559.0 .09 2.5 600.0 .39 316.33 659.0 .08 3.2 700.0 .24 315.93 759.0 .15 3.7 800.0 .24 312.83 859.0 .15 4.2 900.0 .28 292.86 959.0 .14 4.6 1000.0 .20 268.16 1059.0 .14 4.9 1100.0 .17 247.07 1159.0 .09 5.0 1200.0 .20 231.36 1259.0 .06 5.0 1300.0 .19 229.01 1359.0 .05 5.0 1400.0 .20 246.49 1459.0 .08 5.0 1500.0 .42 267.60 1559.0 .25 5.3 1600.0 .95 286.52 1659.0 .58 6.2 1700.0 1.75 301.40 1759.0 .85 8.3 1800.0 3.67 309.17 1859.0 1.95 12.9 1900.0 5.42 313.65 1959.0 1.77 20.6 2000.0 6.16 316.83 2059.0 .81 30.7 · 6 329.5 1.0 316.8 1.5 312.0 2.1 310.9 2.8 311.1 3.5 312.1 4.0 312.7 4.4 312.9 4.8 311.9 5.1 309.7 5.3 307.1 5.4 304.0 5.5 300.6 5.7 297.6 6.3 294.8 7.8 293.1 10.7 294.2 16.6 298.3 25.7 303 .2 36.1 307.1 .37 N .25 W .62 N .61 W .89 N .99 W 1.23 N 1.42 W 1.68 N 1.92 W 2.18 N 2.41 W 2.58 N 2.79 W 2.87 N 3.10 W 3.10 N 3.47 W 3.20 N 3.86 W 3.15 N 4.16 W 2.98 N 4.43 W 2.76 N 4.68 W 2.59 N 4.97 W 2.53 N 5.49 W 2.82 N 6.62 W 3.93 N 8.68 W 6.82 N 12.41 W 12.16 N 18.28 W 19.39 N 25.39 W A Gy r o d a t a B.P. EXPLORATION WELL: NIAKUK NK-09 Location: POOL #7, PRUDHOE BAY, ALASKA Job Number: AKl194G241SS D i rectional Survey Page SUBSEA I N C L AZIMUTH VERTICAL DOGLEG DEPTH DEPTH SEVERITY feet deg. deg. feet deg./ 100 ft. VERTICAL CLOSURE SECTION DIST. AZIMUTH feet feet deg. HORIZONTAL COORDINATES feet 2100.0 6.58 318.92 2159.0 .48 2200.0 7.04 319.66 2259.0 .47 2300.0 7.50 318.88 2359.0 .48 2400.0 8.51 317.79 2459.0 1.02 2500.0 11.31 317.38 2559.0 2.78 41.8 47.4 309.9 53.7 59.4 312.0 66.4 72.3 313.4 80.4 86.8 314.3 97.8 105.5 314.8 27.68 N 32.87 W 36.73 N 40.65 W 46.40 N 48.98 W 56.89 N 58.33 W 69.76 N 70.11 W 2600.0 14.12 317.24 2659.0 2.72 2700.0 15.99 317.68 2759.0 1.80 2800.0 18.15 318.56 2859.0 2.10 2900.0 20.97 318.97 2959.0 2.68 3000.0 23.09 319.41 3059.0 1.91 120.2 129.2 315.3 146.9 156.2 315.7 177.4 186.3 316.1 2i2.7 220.7 316.6 253.0 258.7 317.0 86.33 N 85.41 W 106.14 N 103.58 W 128.97 N 124.03 W 155.62 N 147.37 W 186.18 N 173.75 W 3100.0 24.25 320.38 3159.0 1.07 3200.0 27.22 321.38 3259.0 2.73 3300.0 30.55 322.77 3359.0 2.95 340.0.0 33.25 323.69 3459.0 2.34 3500.0 35.75 323.62 3559.0 2.03 296.7 299.0 317.4 345.0 389.6 317.9 400.5 441.2 318.5 462.8 496.1 319.1 531.6 554.0 319.7 219.65 N 201.97 W 257.22 N 232.46 W 301.04 N 266.48 W 351.07 N 303.74 W 406.45 N 344.48 W 3600.0 37.67 322.87 3659.0 1.53 3700.0 39.60 321.45 3759.0 1.68 3800.0 41.85 320.43 3859.0 1.77 3900.0 43.92 319.41 3959.0 1.57 4000.0 44.23 319.02 4059.0 .61 606.0 614.3 320.2 685.9 741.1 320.4 772.1 807.9 320.4 864.7 876.6 320.4 961.1 1016.3 320.3 466.13 N 388.95 W 529.24 N 438.03 V 596.18 N 492.50 W 667.20 N 552.13 W 740.39 N 615.37 W 4100.0 44.62 319.36 4159.0 1.07 4200.0 44.51 320.67 4259.0 .36 4300.0 44.50 320.19 4359.0 .25 4400.0 44.91 320.17 4459.0 .63 4500.0 44.89 320.54 4559.0 .79 1059.8 1065.6 320.2 1158.3 1177.9 320.2 1256.2 1261.9 320.2 1354.8 1367.4 320.2 1454.9 1466.5 320.2 815.25 N 680.15 W 891.28 N 742.91 W 966.79 N 805.49 W 1042.61 N 868.80 W 1119.82 N 932.68 W A Gyrodat a D i re c t i ona I Survey B.P. EXPLORATION WELL: NIAKUK NK-09 Location: POOL #7, PRUDHOE BAY, Job Number: AKl194G241SS ALASKA SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. VERTICAL DOGLEG VERTICAL CLOSURE DEPTH SEVERITY SECTION DIST. AZIMUTH feet deg./ feet feet deg. 100 ft. 4600.0 44.96 319.23 4700.0 45.85 319.37 4800.0 45.78 319.39 4900.0 45.44 320.19 5000.0 44.85 320.23 4659.0 .60 4759.0 .13 4859.0 .14 4959.0 .99 5059.0 .20 5100.0 45.19 320.29 5200.0 44.96 320.60 5300.0 44.81 320.46 5400.0 45.24 319.65 5481.3 46.31 318.82 1554.1 1655.4 1757.9 1860.0 1960.2 5159.0 1.29 2059.6 5259.0 .90 2159.9 5359.0 .69 2259.1 5459.0 1.83 2358.7 5540.3 6.03 2441.4 Final Station Closure: Distance: 2445.87 ft Az: Page HORIZONTAL COORDINATES feet 1572.3 320.2 1679.4 320.1 1765.4 320.1 1872.6 320.1 1978.8 320.1 2063.4 320.1 2176.8 320.1 2282.5 320.1 2367.3 320.1 2445.9 320.1 1195.90 N 996.73 W 1272.77 N 1063.09 W 1350.92 N 1129.94 W 1429.03 N 1195.90 W 1506.20 N 1260.17 W~ 1582.77 N 1660.24 N 1736.83 N 1813.56 N 1875.81 N 1323.75 W 1387.77 W 1450.96 W 1514.77 W 1569.60 W 320.08 deg. gyro/data 4. QUALITY CONTROL SR241 .DOC Quality Control Comparisons B.P. EXPLORATION WELL: NIAKUK NK-09 Location: POOL #7, PRUDHOE BAY, ALASKA Job Number : AKl194G241 / AKl194G241 INRUN/OUTRUN Comparison INRUN OUTRUN Depth Inc Inc Delta 1500.0 .28 .22 .054 2000.0 6.25 5.87 .379 2500.0 9.09 9.00 .087 2600.0 12.79 12.57 .219 2700.0 14.96 14.87 .094 2800.0 16.33 16.45 -.119 3000.0 21.39 21.48 -.089 3500.0 32.47 32.30 .172 4000.0 41.16 41.02 .144 5000.0 45.04 44.84 .196 5500.0 45.54 45.45 .095 6000.0 44.93 44.98 -.045 For Inclinations Greater than 10 degrees: Average Inclination Difference = .07401 deg. Average Azimuth Difference = -.1040 deg. INRUN Az 260.56 319.71 315.44 316.12 316.48 318.93 318.94 324.40 319.41 320.02 318.82 321.19 OUTRUN Az 259.25 315.75 316.37 314.35 317.20 319.88 319.77 324.15 319.93 319.66 319.54 320.77 Delta 1.314 3.961 -.926 1.769 -.714 -.952 -.836 .241 -.514 .357 -.718 .429 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK1094G241 TOOL NUMBER: 510 MAXIMUM GYRO TEMPERATURE: 77.98°C. MAXIMUM AMBIENT TEMPERATURE: 42.40°C MAXIMUM INCLINATION: 46.31 o AVERAGE AZIMUTH: 320.08° WIRELINE REZERO VALUE: 00009 REZERO ERROR / K: 1.40/K CALIBRATION USED FOR FIELD SURVEY: 19-OCT-1994 CALIBRATION USED FOR FINAL SURVEY: 19-OCT- 1994 PRE JOB MASS BALANCE OFFSET CHECK: POST JOB MASS BALANCE OFFSET CHECK: .. CONDITION OF SHOCK WATCHES .055241 .24015 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ANCHORAGE: OK BOTTOM LINE COMPARISONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 6420 46.31 318.82 5540.3 1876.5 -1568.80 FINAL SURVEY 6420 46.31 318.82 5540.3 1875.81 -1569.60 FUNCTION TEST SR241 .DOC gyro/data JOB NUMBER: AK1094G241 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 6000 44.93 44.93 44.93 44.93 44.93 AZIMUTH M.D. ft I 2 3 4 5 6000 321.19 321.41 321.24 321.33 321.54 SR241 .DOC gyro/data III ! 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR241 .DOC yro/data EQUIPMENT REPORT JOB NUMBER: AK1094G241 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 510 GYRO SECTION A0064 DATA SECTION A0060 POWER SECTION A0037 BACKUP TOOL No. 053 GYRO SECTION A0008 DATA SECTION A0020 POWER SECTION A0050 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0145 A0064 A0029 A0042 A0078 A0056 A0036 A0052 WIRELINE COMPANY: WESTERN ATLAS CABLE SiZE: 15/32" RUNNING GEAR 2 1/4 inch system using the eccentric weight bar. TOTAL LENGTH OF TOOL: MAXIMUM O.D.: TOTAL WEIGHT OF TOOL: 22 feet 2 1/4inches 200 Lbs. SR241 .DOC , yro/data CHRONOLOGICAL REPORT JOB NUMBER: AK1094G241 06-NOV-94 07:00 Arrive at airport. 10:45 Arrive Atlas 11:30 Check out tools. OK Standby 22:00 On location. 07-NOV-94 00:15 Set up equipment and test. 12.45 Power up tool. 01:30 Pick up the tool. 03:10 06:30 T.D. 642O FT. Out of the hole. 08:30 Arrive back at atlas. 09:30 Post run test on gyro 510 and 053. 13:00 Fax copy to rig. 18:10 20:00 Leave the North Slope for Anchorage. Arrive in Anchorage. SR241 .DOC BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 26, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached are blueline and folded sepias for well Niakuk 9. Per 20.AAC 25.537(d) BP Exploration would like these logs held confidential for 24 months. The specific attached log includes: Log Type Company Run Date Depths PLS (Static Pressure Atlas 2/7/96 17982'-18452' survey) Please contact me at 564-4531 if you have any questions. Sincerely, Katie Nitzberg,'Sr.{Ge}ologist Greater Point Mcln~-r~ Area MS Enclosures Please sign below and return to Marian Sloan, BPX, Mail Stop MB7-2 for reciept of transmittal. ...... .'?'~' '.i~ #[rF ;~} Anchor~:~ge State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage AK 99501-3192 The AOGCC releases confidential data to authorized employees of the Division of Oil and Gas (DNR/DOG). Blueline logs and copied of_the IJndefAigned DN4:~JDOG employee. rep°rts ar'e invent°tied bY pri°r t° release' These c°nfidentia' d~/a~'be~/'r"?°nsibil~ty .~/~a~'~ ~" _ ~~ ~Signature Print Name ;: ~' :j~ ~,':A~~ ORM PAGES 401 403 407 PICKS CoMMENTs Formation Picks or _Geolo_g,.ical Markers REPOP. TS SURVEY CORE DWOP DSTs PAGES COMMENTS f DeScription- ---- Anal~/Sis ' Conventional SWC / Producti,on Tests / BLUE LINE RUN INTERVAL 08~03~95 co nfid ri r. doc Anchorage AK 99501-3192 The AOGCC releases confidential data to authorized employees of the Division of Oil and Gas (DNR/DOG). Blueline logs and co[. reports are inventoried by prior to release. These confidential data are then responsibility of the undersigned DNR/DOG employee BLUE L!N~E WELL NAME". PAGE TWO IF NEEDED INTERVAL , SCALE I NOTE DIGITAL DATA RUN INTERVAL OIC NOTE:. rev 08/03/95 confidnr,doc Facsimile Cover Sheet To: Company: Phone: Fax: LARRY G RANT Alaska O&G Conservation Comm. 907-279-1433 907-276-7542 From: Company: Phone: Fax: Emall: Timothy J. Ryherd Alaska D.N,R.- Div. of Oil & Gas (907)269-8771 (907)562-3852 tjr @ dog,d n r,state,ak, us Date: 11/16/95 Pages Including this cover page: I Lam/: Please prepare the following well data for me to pick up tomo~w afternoon, 11/17/95: BP NIAKUK NK-07 (permit 93-015B)--all well logs, well history, completion report, drilling permit, horizon picks, directional surveys, co~e descriptlona, core analyses, production test summaries and production teat detailed mpo~ (OONFIDENT'IAL WELL DATA). BP NIAKUK NK-08 (permit g4-0Og3)-all well logs, well history, completion report, drilling pe~It, horizon pick~, directional surveys, ~'ore descriptions, core analyses, production test summaries and production teat detailed reports (CONFIDENTIAL WELL DATA). BP NIAKUK NK-09 (permit 94-0140)-all well logs, well histo~, completion report, drilling permit, horizon picks, directional surveys, core descriptions, core analyses, production test summaries and production test detailed reports (CONFIDENTIAL WELL DATA). I will be over to pk~'k up this data tomon'ow. Thank you. $inoemly, BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 3, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ~'J/'//)~ Dear AOGCC Representative, '"( Attached are blueline and folded sepias for well Niakuk 9. Per 20.AAC 25.537(d) BP Exploration would like these logs held confidential for 24 months. The specific attached Icg includes: Log Type Company PLS (Production profile) Atlas Run Date Depths 10/25/95 17790'-18360" Please contact me at 564-4531 if you have any questions. Sincerely, Katie Nitzberg, Sr. ~eol~gCst Greater Point Mclntyre Area Enclosures .'~'O~, Or? .~) Please sign below and return to Marian Sloan, BPX, i~t~il ~top~.,.MBT-2 for ! BP EXPLORATION Alaska 0ii & Gas Cans. u0~'nrniss~ Anchj~rage June 1, 1995 /~./-"' Alaska Oil and Gas Cb. Cservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Dear AOGCC Representative, Attached is a blueline, folded sepia and an LIS tape of MWD logs for well Niakuk 09. Per 20.AAC 25.537(d) BP Exploration would like these these logs held confidential for 24 months. The specific attached logs include: Log Type Company Run Date Depths DGREWR-P4/FXE Sperry Sun 8/24/93 15745'- 16700' Please contact me at 564-4531 if you have any questions. Sincerely, Katie Nitzbe~-g/S'~. Geblogist Greater Pt. MclntyreArea MS Enclosures WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME NK-7 4/27/95 ?s- / F? NK-7 5~5~95 15000'- 15420' 3000'-15350' NK-9 3/27/95 NK-9 .NK-9 ~1'~'"I(~ 3/27/95 12/19-21/94 ~NK-9 12/21/94 17470'-18240' 17720'-18250' 18020'-18570' 18020'-18570' NK-18 c~..~-/?7 3/18/95 2700'-11090' NE-21 c~- ~/,~ 3/30/95 11100'-11865' NE-23 ?c~- ~S'"" 3/30/95 14700'-16759' NE-42 ~. q-[ b"~ 3/17/95 3683'-15642' GAMMA RAY/CCL (PERFORATING LOG) PLS (PRODUCTION PROFILE) GAMMA RAY/CCL (PERFORATING LOG) PLS (STATIC PRESSURE SURVEY) GAMMA RAY/CCL (JEWELRY LOG) PLS (STATIC PRESSURE SURVEY) SLIM GR - MWD/DEPTH CORRECTED MWD OPEN HOLE EDIT GR TAPE PLS (SPINNER TEMP/PRESSURE SURVEY) PLS (STATIC PRESSURE SURVEY) PLS (STATIC PRESSURE SURVEY) PLS (STATIC PRESS SURVEY) (TEMP GRAD) 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 SCHLUMBERGER 1 SCHLUMBERGER 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE RECEIVED MAY 2 2 1995 oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 18, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached are blueline, folded sepia and an LIS tape of e-line logs for well Niakuk 09 and a blueline and folded sepia e-line log for well Niakuk 21. Per 20.AAC 25.537(d) BP Exploration would like these these logs held confidential for-24 months. The specific attached logs include: Well NK-09 NK-09 ~,,~~//~,L'~b NK~09 NK-09 NK-09 Log Type Formation Multi-Tester (Gamma Ray) Z-Densilog; Comp. Neut. ;Gamma Ray/Caliper Dual Laterolog (Gamma Ray/SP) SSVD (MWD Dir. Survey) Borehole Profile LIS Tape Company Run Date Depth~ Atlas Wireline 12/25/94 18090-18390 AtlasWireline 12/23/94 17910-18520 AtlasWireline 12/23/94 18064-18550 Atlas Wireline 12/23/94 18064-18550 AtlasWireline 12/23/94 18064-18520 AtlasWireline 12/23/94 18064-18550 11120-11881 NK~21 PLS (Static Pressure Survey) AtlasWireline 1/1/95 Please contact me at_564-4531 if you have any questions. Sincerely, Katie Nitzberg, Sr. GeOlogist/-') R ~ C E IV E D Greater Pt. Mclntyre Area JAN '1 8 1995 KEN Enclosures A!~ska. 0il & 6as Cons. Commission Anchorage DOCUMENT 'STORAGE, INC. CORE SAMPLE TRANSMITTAL FROM: BP Exploration Alaska, Inc. c/o Document Storage Core Store 2410 W. 88th Ave. Anchorage, Alaska 99507 Attn: dohn'Trautw6in--- (907) 522-2684 AIRBILL #: /~/,,z~ SAMPLE TYPE: DATE: /--m'- ¢.3'~--- TRANSMITTAL NO.: //¢ 7 NUMBER OF BOXES: REFERENCE: DESCRIPTION OF MATERIALS TRANSPORTED: ,7 /-~ ~£ ~d/= Please acknowledge receipt in whole of the material described above by signing this transmittal and returning a copy to the address shown above. Sent by: Received Date: /'----/z¢-,/'..~ Date: 8840 Goloyin Street · Anchorage, Alaska99507 · Tclcphonc (907) 522-2521 MEMORANDUM State of Alaska TO: THRU: Alaska Oil and Gas Conservation Commission David Jo~-~~ DATE- December 10, 1994 Chair~..~~-~ Blair Wondzell, ~ FILE NO: AZ1JLJBD DOC P. I. Supervisor FROM: Lou Grimaldi;'/~,'~- SUBJECT: Petroleum Inspector BOP test Pool rig ¢7 BPX well ¢ NK-9 Niakuk, Prudhoe Bay field PTD ¢ 94-140 Thursday, August 4, 1994: i witnessed the weekly BOP test on Pool rig ¢ 7 drilling BPX well Niakuk ¢9. The test went well with one flange leak at the APl ring on the Kill line. I also found evidence of hydraulic fluid in the Nitrogen backup system for the accumulator indicating a faulty check valve. The rest of the BOPE passed its function and pressure test. The equipment seemed well maintained. The test procedure insured that all valves were tested from the proper direction. The rig is in good shape and I found evidence of regular maintenance. Although there is much activity on the pad, Good access was provided and the area was clean and neat. SUMMARY: ! witnessed the weekly BOP test on Pool rig ¢ 7. Test time 3 hours, No failures. Attachments: AZlJLJBD.XLS cc: Scott Sigurdsen/Steve Horton (Prudhoe Bay drilling) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Pool Arctic Alaska Operator: Arco Well Name: NK-9 Casing Size: Set @ Test: Initial Weekly Rig No. 7 PTD # 94-140 Rep.: Rig Rep.: Location: Sec. X Other DATE: 12/10/94 Rig Ph.# 659-4815/4816 Tommy Johnson Jimmy Greco 36 T. 12N R. 15E Meridian Umiat MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N/A Well Sign OK Drl. Rig OK BOP STACK: Annular Preventer Pipe Rams Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Test Quan. Pressure P/F 1 250/3000 :~ 1 250/5000 1 250/5000 1 250/5000 1 250/5000 2 250/5000 5 250~5000 N/A N/A MUD SYSTEM: Visual Trip Tank P Pit Level Indicators P Flow Indicator P Methane Gas Det. H2S Detectors FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP CHOKE MANIFOLD: No. Valves 16 No. Flanges Manual Chokes 1 Hydraulic Chokes 2 Test Quan. Pressure P/F 1 250 / 5000 P 1 250/5000 P 1 250/5000 P 1 250/5000 P Test Pressure 250 / 5000 P/F 38 250 / 5000 P Functioned P Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure Alarm 200 psi Attained After Closure P System Pressure Attained 1 P Blind Switch Covers: Master: ,,, P Nitgn. Btl's: Six Bottles 3000 P 1800 P minutes 25 sec. minutes 55 sec. X Remote: X 2600 Psig. See Note #1 TEST RESULTS Number of Failures 3 Test Time 4 Hours Number of valves tested 28 Repair or Replacement of Failed Equipment will be made within N/A days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 278-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 II III I II II I I I IIII III I II I IIIII REMARKS: #1)Hyd fluid present in Nitrogen backup, purge bottles and repair check valve. Leak at APl ring in Kill Line Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c -Inspector FI-021L (Rev. 2/93) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: JLJBD.XLS Louis R Grimaldi NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME WELL Z,.NK-08 NK-08 NK-08 Q)'SNK_08 NK-09 NK-09 NK-09 '"/~,/O NK_09 ~"¢;' ,qK-10 7_~ NK-21 NK-21 NK-21 :~-~-~,~'":N K-22 ~"O~.~1K-23 >~,~. NK-42 NK-42 ~o,~K-42 2/10/95 2/10/95 2/9/95 2/1 O/95 1 2/31/94 11/29 - 12/5/94 11/29-12/5/94 1 2/5/94 1/15/95 12/28/94 7/9/94 7/9/94 1/14/95 1/15/95 1/24/95 9/13-17/94 9/13-17/94 15950'-16400' 15950'-16400' 15950'-16260' 15925'-16416' 16682'-17629' 17936'-18080' 16680'-18080' 14640'-14900' 16682'-18080' 13050'-13310' 11600'-11820' 10462'-11942' 10448'-11941' 12850'-13300' 15889'-16739' 14560'-16062' 14620'-16020' 14565'-15956' PDK-100 - GR/Temp/CL (BORAX) PLS (Spinner/Temp) PLS (Flowmeter/Temp/Pressure) LDWG Tape (PDK-100/GR - Borax Log) Gamma Ray/CCL (Spot TCP Guns) CDN - Depth Corrected CDR - Depth Corrected LDWG Tape (CDR/CDN) PLS (Static Pressure/Temperature) PFC Gamma Ray/Collar Log (Perf. Record) CDR Enhancement- LWD/Depth Corrected CDR - LWD/Depth Corrected PLS (Production Profile) PLS (Static Survey) LWD 2 Bit Run Merged CDR & CDN CDR - Depth Corrected CDN - Depth Corrected 1 Atlas Wireline 1 Atlas Wireline I Atlas Wireline I Atlas Wireline I Atlas Wireline Composite Schlumberger Composite Schlumberger I Schlumberger I Atlas Wireline I Atlas Wireline I Schlumberger I Schlumberger I Atlas Wireline 1 Atlas Wireline 1 & 2 Schlumberger Composite Schlumberger Composite Schlumberger ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPIINE DRIVE ANCtlORAGE, ALASKA 99501-3192 PHONE: (907)279-1433 TELECOPY: (907)276-7542 December 1, 1994 A C Clark, Drlg Engr Spvr BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc NK-9 revised BP Exploration (Alaska) Inc 94-140 1281'NSL, 1037'WEL, Sec 36, T12N, R15E, UM 2199'NSL, 1020'EWL, Sec 23, T12N, R15E, UM Dear Mr Clark: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the original approved permit dated October 31, 1994 are in effect for this revision. BY ORDER OFT MMi ION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl BP EXPLORATION ARCO Alaska, Inc. To: Date: November 16, 1994 Alaska Oil 8, Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: David Johnston Subject: NK-9 Permit (#94-140) Enclosed is a revised permit for well NK-9. This permit replaces the previously approved permit # 94-140 for well NK-9. The proposed well will target a different bottom hole location. Yours Sincerely, Adrian Clark Drilling Engineer Supervisor MS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill I'"lllb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] Deepenr-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator !5. Datum Elevation (DF or KB)' 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 59' feet Niakuk Oil Pool 3. Address 16. Property Designation P. 0. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 34625 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 ,v,c 25.o25) 1281' NSL, 1037' WEL, SEC. 36, T12N, R15E Exploration At top of productive interval 8. Well number Number 1654' NSL, 1251' EWL, SEC. 23, T12N, R15E NK-9 25100302630-277 At total depth 9. Approximate spud date Amount 2199'NSL, 1020' EWL, SEC. 23, T12N, R15E 10/30/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(MD,~d'rVD) property line ADL 34826-1020' feet NK-10-355'@ 11300'MD feet 2560 18961'MD/9355' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o ,,,Ac 25.035 (e)(2)) Kickoff depth 1500 feet Maximum hole angle 75 o Maximum surface 2905 psig At total depth (TVD) ~200'/4~)0 psig ~'18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD. TVD (include stage data) 30" 20" 94~ H-40 Weld 80' 30' 30' 110' 110' 260 sx Arcticset (Approx.) 16" 13-3/8" 68# NT8OLHE B TC 4403' 41' 41' 4444' 4140' 1383 sx PF "E"/375 sx 'G"/250 sx "C' 12-1/4" 9-5/8" 47# NT80S NSCC 13959' 41' 41' 14000' 7859' 424 sx Class "G" 8-1/2" 7-5/8" 29.7# NT95HS STL 4480' 13851' 7820' 18331' 9139' 1555x Class "G" 6-3/4" 5-1/2" 17# NTaoS NSCC 780' 18181' 9088' 18961' 9355' 155 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 Measured depth True Vertical depth Structural Conductor Surface ?,ECEIVEb Intermediate ,, f.., .~ r) 'i .',. r~ f-~ ' Production IJL/,/ 4 [::,"uz', Liner Perforation depth: measured "' ' ~.:~I(~ .0ii & Oas 60n~. 60mmissi0p, true vertical Anchor;. ~0. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] LDrillin. g fluid program [~.,Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirementsl-I 121' I here~'~ify tha{Lthe f'd'ce~°ing isjtrue and c°rrect t° the best °f my kn°wledge~(.~_7 Date Il , Signed''~-''' ~ ~(,.~. Title Drilling EngineerSupervisor I Commission Use Only Perm_Lt Number IAPI number IApproval date See cover letter ~"/~('-//'~/,/(~ J50- O ~---~' - ~ ~-----~",,/oc~ for other requirements I CondJtJons of approval Samples required ,]~ Yes [] No Mud Icg required I~Yes [] No Hydrogen sulfide measures [] Yes ,J~ No Directional survey required J~ Yes [] No , Required working pressure for BOPE 1-12M; r-i3M; J~]5M; I-I10M. []15M; by order of /// Other: Ori~Jnal Signed By Commissioner [ne commission Date/2 Approved by David W. ,lnhnefnn . Form 10-401 Rev. 12-1-85 Submit in plicate CONFIDENTIAL J Well Name: INK 09 Well Plan Summary Type of Well (producer or injector): I PRODUCER I iSurface Location' Target Location: Bottom Hole Location- 1281' FSL, 1037' WEL, SEC 36, T12N, R15E 1654' FSL, 1251' FWL, SEC 23, T12N, R15E 2199' FSL, 1020' FWL, SEC 23, T12N, R15E AFENumber: 1731085I IRis: I POOL#7 I Estimated Start Date: I 10/30/94 I IMD= 118961 I ITvD= IWell Design (conventional, slimhole, etc.): JOperating days to complete' 19355 I 51 I KBE: 159' JBig bore, with intermediate liner Formation Markers: Formation Tops MD TVD (BKB) WEST SAK 11374 7179 Max required mud weight: 9.5 ppg BASE WEST SAK 12263 7409 Top of Tuffs 17061 8716 HRZ 17823 8966 HRZ thickness _+50' KUPARUK 18331 9139 Max required mud weight: 9.5 ppg_ _, KINGAK 18901 9334 J~ ~. L ~' TD 18961 9355 IVED NOV 2 I ]994 Casin t/Tubing Proqram: ~. 0, & ~as c0.s. c0mmr~o~ Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tb~l O.D. MD/TVDbkb MD/'FVDbkb 30" 20" 94# H-40 WLD 80' GL 80/80 16" 13-3/8" 68# NT-80LHE BTC 4403' 41'/41 4444/4140 12-1/4" 9-5/8" 47# NT-80S NSCC 13959' 41'/41 14000/7859 8-1/2" 7-5/8" 29.7# NT-95HS STL 4480' 13851/7820 18331/9139 6-3/4" 5-1/5" 17# NT-80S NSCC 780' 18181/9088 18961/9355 TBG 4-1/2" 12.6# NT-80S NSCT 18181' 41'/41 9870/8962 NE 09 Well Plan Summary Page 1 CONFIDENTIAL Logging Program: Open Hole Logs- SURFACE INTERMEDIATE PRODUCTION Cased Hole Logs: Anadrill directional MWD only. Anadrill directional MWD only. Anadrill MWD/GR or Sperry MWD/GR/Resistivity from top Kuparuk to TD. Atlas FMT with sample bottles. Atlas triple combo, tCN L/LDT/DIL/BHCS/G R/SP) None Mud Program: Special design considerations 3% KCL mud for Kuparuk formation damage control. LSND will include additions of Xanvis for rheological properties. Lubricant may be added if torque increases. Surface Mud Properties' I Spud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5-9.6 300 20-60 30-60 60-80 8.5-9.0 NC to 10 ,,, Intermediate Mud Properties: start I Fresh LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.5-9.8 50 20-30 8-12 <20 9-9.5 5-15 DISPLACEMENT WILL BE PERFORMED at 7-5/8" CASING SHOE TO 3% KCL Production Mud Properties: Kuparuk 13% KCL Density PV Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.8-10.2 8-15 25-30 8-12 <20 9-9.5 5 <20HTHP RECEIVED NOV 2_ i 1994 A~ska. Oil & Gas Cons. Commission Anchora.? NK 09 Well Plan Summary Page 2 CONFIDENTIAL Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: 11500'; Departure to TD=14268' I Maximum Hole Angle: 175°, drop to 70° @ TD. Azimuth=319-337° Close Approach Wells:I NK-10 from 11,300' to 12,550' MD (355') NK-8 from 13,500 to 17,250' MD (500') The above listed wells with deep close approaches will pose no risk to environment or personnel in the event of an intersection. NK 09 Well Plan Summary Page 3 .pll (NW-t Target) VERTICAL VIEK SCALE 100O ft. / DIVISION T~q) REF: %'ELLHEAD %~RTICAL SECTION REF: ~ELkHEAD 0-~ o.oo' e o ~o rli: IN I ~ a7.50' e 3300 ~ 3t.SD' ~ 3SOO ~ 5000 ~ 5545 ~.00' ~ 643i ~ ST~T ~ ~ · e. O0'/lO0 Ft ~5 6100 S7t6 i o lOOO ~ooo 3600 4o00 5060 ~,'ERTICM., SECTION PLA_N'E;: 323.56 HOR/Z01%'I'AL ~ (TRUE NORTH) SCALE 1000 (t. / DMSION SURVEY P, EF: i~19 ~990503 ] jN~-I T~rge~ 9139 10938 N 8844 V 718934 ~ec~[o~ Lines 9139 9878 N 4~II V 717011 59889651 CRITICAL P~INT DATA ~n~ Az,. TV~ 319.0C' 00' KDP / START 150000' 319.00' !500 DF BUILD 8 .00'/~05 ~ END DF BUILD18003.00'319.0G' 1800 18593.00'319.00' 1859 Perm~rosl !TART ~F BUILD 8000 3.00'319.08° ~000 ~ 1.50'/100 START OF BUILD 8300 7.50'31~.0~' !~ E.OO'/IOG tEND OF BUILD4175 45.00° 3~9.0~' 3950 ];TA~T O? 6431 aS-OO° 319.00' 5545 CURVE 8 jS.00'/lOO ct END DF CURVE 6E89 7935 75.00' 381.61' To~ ~. 3AK I!37Z 75.00' 38!.61 7179 IB~se V. 3ok!EB63 75.0? 321,6! 7405 START DF 14~3E 75.00'381.6l' $I00 ~CURVE 8 0.50'/100 Ct ;Top H~J. TuPFsiT061 7t.43'338.09' 87!8 J ToD M!n. TuF~S ~7350 70.$9'333.55' 8809 [Top HRZ ~78a3 70.3~'335.94' lEND ~ CURVE18031 70.00'337.00' 9036 18E17 70.00'337.00' 9100 IN~-I TonDe~ / 18331 70.00'337.00' 9139 TOD Kup~ruk Top Klng~k 18901 70.00'337.00' ~334 ON 14 N 1~ 35 N 30 1853 N !611 61B4 ~ 5~B6 8144 N 66E7 9~47 N 774l 10090N 7B66 10494 N ~0673 N 10938 N 8E~4 11486 N 8454 75,00. · tt37~ t~ 12-~°3 I,~ ~' ~' s~ ~ ~ 1~ ~ 7 5/8 la OD, S I8331 HD. 9139 ~' 66100 7OD0 BOO0 9000 lO000 ILO00 [~000 13000 14600-- 15000 13 3/~ ih aD, t 4444 I~D. 414O 5/8 iff 9139 1/2 In 18961 70,00' 337.00' 9354 11477 13000 ~1~000 LII060 i i i PROPOSED BI{L ~ 9354.52 S{D 18960.68 VS 14267.69 N/S 11477.41 E/~ 8475.62 I Da~e PLotted, 10/E6/94 ) Cre~ed By ~ Checke~ ~y :/e~3~g ADD-OVen ~y : Gas Cons° gommis,sion Surface Casing Depth: Surface Casing Size: Surface Casing Weight: Bit Diameter: Excess Factor Intermediate Casing Depth: Intermediate Casing Size Intermediate Casing Weight: Proposed Top of Cement Bit Diameter: Excess Factor: Liner Size: Liner Weight: Hole TD Top of Cement Bit Diameter: Excess Factor: Drillpipe OD: Liner Size: Liner Weight: Hole TD Bit Diameter: Excess Factor: Drillpipe OD NK 09 Cement Volumes Surface String 4444 13 3/8 68 16 1.8 LEAD (TYPE "E" PERMAFROST) Yield 2.17 Density I 2 # sacks 1383 (3002 Cu. Ft.) TAIL (CLASS G) Yield 1.15 Density 15.8 # sacks 375 (431 Cu. Ft.) TOP JOB (TYPE "C" PERMAFROST) # sacks 250 (235 Cu. Ft.) .94 cuft/sx 15.6 ppg Production String 14000 9 5/8 47 13200 12 1/4 1.9 LEAD Yield 1.98 Density 1 5 # sacks 0 # bbls 0 TAIL (CLASS G) Yield 1.2 Density 15.8 # sacks 424 # bbls 91 Intermediate Liner ( 0 Cu. Ft.) (509 Cu. Ft.) 7 5/8 45.5 18331 16500 8.5 1.9 5 TAIL (CLASS G) Yield 1.2 Density 15.7 # sacks 1 55 # bbls 3 3 (185 Cu. Ft.) Production Liner 5.5 17 18961 6.75 2 TAIL (CLASS G) Yield Density # sacks 1.2 15.7 155 (186 Cu. Ft.) 3.5 RECEIVED i.,!()'.,,~ ? 'i '~,,",,' ... ,- ,~ ! .;' :3'-'.' ^ncflor:. , 1 1 . , , . . 10. 11. NK 09 Operations Summary MIRU drilling rig. NU BOPs and test to 5000 psi. NU diverter and function test. Spud well and drill 16" hole to 1500' md. Kick off and build angle to 45° by 4175'. Hold angle to 4444' md surface hole TD (4140' TVD). Set 13-3/8" casing and cement same. Test casing to 3000 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. Pick up 12-1/4" BHA and drill 10' of new hole and perform leakoff test. Drill ahead and hold 45° hole angle to 6431' md and build angle to 75 o by 7935' md. TD the 12-1/4" hole below the West Sak formation at 14000' md, 7859' 'I-VD. Pick up 8-1/2" BHA and drill 10 of new hole and perform leakoff test. Drill ahead and hold 75° hole angle to 14932' md and begin drop and east turn to the top of the Kuparuk formation at 18331' md. Run 7-5/8" intermediate liner to the 8-1/2" hole TD and cement same. Pick up 6-3/4" BHA and drill 10' of new hole and perform FIT to maximum anticipated mud weight. Drill ahead and hold 70° hole angle to TD at 18,961' Run open hole logs and RFT's drillpipe conveyed. Run 5-1/2" Liner and cement same. Test casing to 3500 psi for 30 minutes. Run 4-1/2" N'i'-80S tubing. Freeze protect with diesel. Release rig. Niakuk # .9 H2S Contingency Planning Detection Monitorina' -- Automatic montors: "General Monitor" visual and audio H2S alarm system Probe locations: rig floor shale shakers bell nipple cellar Setting Levels' Low - 10 ppm High - 20 ppm Manual' 1 -"Industrial Scientific" Model HMX271 H2S detector 2- "Industrial Scientific" Model STX410 H2S detectors 2- Dregers with benzene and H2S tubes Contingency and Control; H2S treating material for the drilling will be Zinc Carbonate and is on location. Detailed emergency operating procedures are in place. Detailed step by step remedial procedures during tripping, fishing and drilling are in place. 9- 30 minute self contained breathing apparatus on location. H2S Training' All personnel onsite have H2S training. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage Alaska 99501-3192 Re .' THE APPLICATION OF BP EXPLORATION (ALASKA) INC. for an order granting an exception to spacing requirements of Title 20 AAC 25.055 to provide for the drilling of the BP Niakuk 9 development oil well Conservation Order No. 346 BP Exploration (Alaska) Inc. Niakuk 9 November 21, 1994 IT APPEARING THAT: . BP Exploration (Alaska), Inc. submitted an application dated October 26, 1994 requesting exception to 20 AAC 25.055(a) (3) to allow drilling the BP Niakuk 9 development oil well to a producing location in the Niakuk Oil Pool that is closer than 500 feet to the pool rule area boundary. . Notice of opportunity for public hearing was published in the Anchorage Daily News on October 29, 1994 pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: The BP Niakuk 9 well as proposed will be a deviated hole drilled from a surface location 3998' from the north line and 1073' from the east line of Section 36, T12N, R15E, Umiat Meridian (UM) to a proposed bottom-hole location of 2599' from the south line and 850' from the west line of Section 23, T12N, R15E, UM. . Offset owners Exxon USA and ARCO Alaska, Inc. have been duly notified. An exception to 20 AAC 25.055(a)(3) and Rule 3 of Conservation Order No. 329 is necessary to allow drilling of this well. CONCLUSION: Granting a spacing exception to allow drilling of the BP Niakuk 9 well as proposed will not result in waste nor jeopardize correlative rights. Conservation Ord@~=~No. 346 November 21, 1994 Page 2 NOW, THEREFORE, IT IS ORDERED: BP Exploration (Alaska), Inc.'s application for exception to 20 AAC 25.055 for the purpose of drilling the Niakuk 9 well is approved as proposed. DONE at Anchorage, Alaska and dated November 21, 1994. David W. Johnston, ommissioner Alaska. Oil and Gas C ,nservation Commission T~ckerman Babcock, Commissioner Alaska Oil and Gas Conservation Commission AS 31 .()5.08() provides that within 20 days after receipt of written notice of thc entD' of an order, a person affected by it may file with thc Commission an application tbr rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day folioxving the date of the order, or next working day if a holiday or weekend, to be timely filed. The Conmfission shall graut or refitse the application in whole or in part within 10 days. The Commission can rcfitse'an application by not acting on it within the 10-day period. An affected persou has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of thc Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by uonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which thc rcttucst is deemed denied (i.e., 10th day after the application for rehearin~ was filed). MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Johnst~~, Chairmar~~ Blair Wondzell, ~ P. I. Supervisor /z/,f Bobby Foster ~ FROM' ~ SUBJECT: Petroleum Inspector DATE: FILE NO: November 29, 1994 QD11k3BD.doc Rig Inspection - Pool Artic 6 ARCO - PBU - NK- 9 Prudhoe Bay Field Tuesday, November 29, ..1994: I traveled this date to ARCO'S well NK-9 being drilled by Pool Artic RIG 6 and did a walk through inspection. The rig was clean and orderly and all equipment seemed to be in good working order. All of the BOPE equipment and related items, as the attached Rig / BPS Inspection Report shows, were in compliance. Summary: I did a Rig / BPS Inspection on Pool Artic's rig 6and found all items to be in good shape and in compliance. Attachment: QD11K3BD.XLS · '~, STATE OF ALASKA ...... ALASKA Oil_ ,.tND GAS CONSERVATION C~JMMISSION RIG I BPS INSPECTION REPORT OPERATION: Drig Contr: Operator: Location: Drilling X Workover Cmpl. UIC Well Name: POOL ARTIC Rig No. 7 Rep. ARCO Rep. LES PEAK Section 36 T. 12N R. 15E M. U NK-9 DATE: 11/29/94 PTD# 94-140 GARRY GLORAIC Rig Ph.# 659-4815 (A.) B.O.P. STACK Wellhead fig wkg press Stack wkg press Annular preventer Pipe rams Blind rams Stack anchored Chke/kill line size tums targeted ( chke & kill Ln.) HCR valves (chke & kill Ln.) Manual valves (chke & kill Ln.) Connections (Figd, Whd, Clamped Drilling spool Flow Nipple Flow monitor Control lines fire protected (B.) CLOSING UNIT Working pressure Fluid level Operating pressure Pressure gauges Sufficient valves Regulator bypass 4-way valves (actuators) Blind rams handle cover Driller control panel Remote control panel Firewall Nitrogen power source (backup) Condition (leaks, hoses, ect.) REMARKS: MUD SYSTEM Pit level floats installed Flow rate sensor Mud gas separator ;Degasser Separator bypass Gas sensors Choke line connections Trip tank i INSPECTION: ITEMS (D.) RIG FLOOR Kelly cocks (upper, lower, IBOP) Floor valves (dart, ball, ect.) Kelly & floor valve wrenches Drillers console (flow monitor, flow rate indicator, pit level indicators, gauges) Kill sheet up-to-date Gas detection monitors (H2S & methane) Hydraulic choke panel~ Choke manifold ECTION ;ITEMS (E.) MlSC. EQUIPMENT Flare/vent line All tums targeted (downstream choke lines) Reserve pit tankage Personnel protective equip, avail. All Ddllsite Supervisors Trained For Procedures H2S probes Rig housekeeping IN COMPLIANCE IN IN COMPLIANCE RECORDS: Date of Last Rig t BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? YES 11/28/94 NONE Kill Sheet Current? Distribution: orig - Well File c - Oper./Rig c - Database c -Tdp Rpt File c- Inspector AOGCC REP: OPERATOR REP: FI-022 (Rev. 3/93) BOBBY D. FOSTER LES PEAK QD1 IK3BD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION October 31, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Adrian Clark Drilling Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: NK-9 BP Exploration (Alaska), Inc. Permit No: 94-140 Sur. Loc. 1281'NSL, 1037'WEL, Sec. 36, T12N, R15E, UM Btmhole Loc. 1941'NSL, l129'EWL, Sec. 23, T12N, R15E, UM Dear Mr. Clark: 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 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] RedrillDIlb. Type of well. Exploratoryr-I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI-11 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 59' feet Niakuk Oil Pool 3. Address i6. Property Designation P. 0. Box 196612. Anchoraae. Alaska 99519-6612 ADL~ _.~z~2.~ /~"~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 2S.025) 1281'NSL, 1037' WEL, SEC. 36, T12N, R15E Exploration At top of productive interval 8. Well number Number 1654' NSL, 1251' EWL, SEC. 23, T12N, R15E NK-9 2S100302630-277 At total depth 9. Approximate spud date Amount 1941' NSL, 1129' EWL, SEC. 23, T12N, R15E 10/30/94 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property 15. Proposed depth (MD and TVD) property line ADL34826-1129' feet NK-10-355'@ 11300'MD feet 2560 18662'MD/9252'TVD feet 116. To be completed for deviated wells 17. Anticipated pressure (me 20 AAC 25.o35 (e)(2)) :Kickoff depth ~5oo feet Maximum hole an~)le 75 o Maximum surface 2905 psig At total depth (TVD) 9~(~{~'/#~;00 psis] 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TV.D (include stage data) 30" 20" 94~ H-40 Weld 80' 30' 30' 110' 110' 260 sx Arcticset (Approx.) 16" 13-3/8" 68# NTeOLHE B TC 4403' 41' 41' 4444' 4140' 7383 sx PF "E"/375 sx "G"/250 sx "C' 12-1/4" 9-5/8" 47# NTaos NSCC !13959' 41' 41' 14000' 7859' 424 sx Class "G" 8-1/2" 7-5/8" 29.7# NT95HS STL 4480' 13851' 7820' 18331' 9139' 155 sx Class "G" 6-3/4" 5-1/2" 17# NTaOS NSCC 480' 18181' 9088' 18662' 9252' 113 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 Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate OCT ?- 8 1994 Production Liner A.i.a, ska. Oil & Gas Cons. Commission Perforation depth: measured Anch0ra..e true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l~l Drilling fluid program [~.~ime vs depth pict ~/ Refraction analysis[] Seabed reportl-I 20 AAC 25.050 requirements[] 21. I hereby~,/~ertify tha~-/3(~)~-fo~e(~g is true/and correct to the best of my knowledge Signed - ! --~'/------ Title Drilling EnEineer Supervisor Date ~'0 ~ Commission Use Only / / Permit Number IAPI number IAp. prov/d date~ See cover letter ,...¢-~'//-//~zd::) 150' 02- 9''' 2''~'''~/~'I/O /e~q,-,~( ~?¢y I,°r °the, requrements i uonditions of approval Samples required j~ Yes [] No Mud Icg uire es [] No Hydrogen sulfide measures [] Yes ~ No Directional survey required [] Yes [] No Required working pressure for BOPE [] 2M; EI3M; J~5M; I-I10M; [-115M; Other: Original Signed By by order of _Approved by David W. Johnston Commissioner me commission Date/~/"~r//'?~ Form 10-401 Rev. 12-1-85 Submit in triplicate CONFIDENTIAL I Well Name: INK 09 Well Plan Summary I Type of Well (producer or injector): I PRODUCER tSurface Location' Target Location- IBottom Hole Location- 1281' FSL, 1037' WEL, SEC 36, T12N, R15E 1654' FSL, 1251' FWL, SEC 23, T12N, R15E 1941' FSL, 1129' FWL, SEC 23, T12N, R15E AFENumber: 1731085i IRig: I POOL#7 I Estimated Start Date: 110/30/94 I Operating days to 151 complete: I !MD: 1~8662 I ITVD' 19252 I IWell Design (conventional, slimhole, etc.): I KBE' 159' IBig bore, with intermediate liner Formation Markers: Formation Tops MD TVD (BKB) WEST SAK 11374 7179 max mud wt required: 9.5 ppg BASE WEST SAK 12263 7409 Top of Tuffs 17061 8716 HRZ 17823 8966 HRZ thickness ___50' KUPARUK 18331 9139 max mud wt required: 9.5 ppg TD 18662 9252 Casin ]/l'ubinq Proqram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tb~l O.D. MD/TVDbkb MD/TVDbkb 30" 20" 94# H-40 WLD 80' GL 80/80 16" 13-3/8" 68# NT-80LHE BTC 4403' 41741 4444/4140 12-1/4" 9-5/8" 47# NT-80S NSCC 13959' 41'/41 14000/7859 8-1/2" 7-5/8" 29.7# NT-95HS STL 4480' 13851/7820 18331/9139 6-3/4" 5-1/5" 17# NT-80S NSCC 481' 18181/9088 18662/9252 TBG 4-1/2" 12.6# NT-80S NSCT 18181' 41'/41 9870/8962 RECE VEb Well Plan Summary NK O9 OCT 2 8 . Page .0il & Gas Cons. Commission CONFIDENTIAL Logging Program: Open Hole Logs: SURFACE INTERMEDIATE PRODUCTION Cased Hole Logs: Anadrill directional MWD only. Anadrill directional MWD only. Anadrill MWD/GR or Sperry MWD/GR/Resistivity from top Kuparuk to TD. Atlas FMT with sample bottles. Atlas triple combo. (CNL/LDT/DIL/BHCS/G R/SP) None Mud Program: Special design considerations 3% KCL mud for Kuparuk formation damage control. LSND will include additions of Xanvis for rheological properties. Lubricant ma)/be added if torque increases. Surface Mud Properties: I Spud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5-9.6 300 20-60 30-60 60-80 8.5-9.0 NC to 10 Intermediate Mud Properties: start I Fresh LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.5-9.8 50 20-30 8-12 <20 9-9.5 5-15 DISPLACEMENT WILL BE PERFORMED at 7-5/8" CASING SHOE TO 3% KCL Production Mud Properties: Kuparuk 13% KCL Density PV Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.8-10.2 8-15 25-30 8-12 <20 9-9.5 5 <20HTHP Well Plan Summary NK O9 RECEIVED OCT 2 8 1994 A!ask~ 0il & Gas Cons. Commission Anchora~? Page 2 CONFIDENTIAL Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: IKOP: 11500'; Departure to TD=13995' I Maximum Hole Angle: 175°, drop to 70° @ TD. Azimuth=319-337° Close Approach Wells:I NK-10 from 11,300' to 12,550' MD (355') NK-8 from 13,500 to 17,250' MD (500') The above listed wells with deep close approaches will pose no risk to environment or personnel in the event of an intersection. RECEIVED OCT 2 8 1994 Alaska Oil & Gas Cons. Commission Anchora~..~ ~ 09 Well Plan Summary Page 3 .,iakuk NK-09 WpiO (NW-1 Target) sc~ looo ,, VERTICAL SECTION REF: ~LLHEAD iN¢-I Tc~ge~ 9!39 1~93~ ~ 8~44 ~ 71~934 5990503 CRITICAL P~INT DATA ~TIE IN KOP / START J0F BUILD E iI.O0'/lOO Ct END Or BUILD Base HD ~nc AZ;. TVD N/S E/WE 0 O 0O' 319.00' 0 ~ N C 1500g. O0' 319.00'1500 C N 0 E lBO0 ~.00' 3!9.00'lBO0 1B59 .~O' 319.00' [B59 ~ ~ ~ ~ ~.~c' e ~oo~ ~ s~A~t ~ iu[~ e l.s~'/x~c ¢* START D~ BUILD 2000 3.00' 319.00" 2000 ILS=" m ~C~ ~ START Or BUILD ~3007.50'3!9.00' 2~98 35 ..... ' ...... !E 2.00'/100 L ..... ' ..... i? ' ' ~3.~o' e 31oo w~ E~D OF BUILD 4175 45. 00' 319.00' 3950 3I.S~' e 35~C ~D START Dr ~4~1 45.00' 319.00' 5545 1853 N [61J ~ ~ JB S~k 1~263 75.00'3~:.61' 7409 612~ NSO~G W ...... START OF 14932 75.00' 321.61' BIO0 8!44 N 6627 I CURVE E 0.50'/100 Ft ToD N~J. Tu¢~sl706l 71.43' 33~.09' B7~6 9B47 ~7741 Top Min, ~u¢¢s 17350 70.99' 333,55' 8809 1~090 7866 41.00' e~43t~ sr~t~e~.~0'/l~0~t To~ HRZ 17B~3 Z~.3O' 335.9~' 896610494 NBO56 2449 5~.~' e ~731 ~D .~' e 7032 ND ~ ~ 18217 7C. DO' 337.00' 9100~0834 N 8202 ~ ~.~. ~ 7331 ND ~ ~ NW-] Target / 18331 70.00' 337.00' 9139 37~ ~~el~ j Top KuD~ruk I I I I I I I i I I i I I I~ ~ 45.00' 31~.00'4140 793 H ~0~0~ ~ ~F: ~ 18662 70.00' 337.00'92~ l l~le N 8~G V I -- . .~ ._- - % ' ~ ~ '~' CPA I / ~,- ~x:5-. / ~- -~ .-~. .~' 90O~ B00~ 700~ 6 oo~ 5oo~ 4000 PROPOSKD BI'fl, T~ 9252.52 1~ 18662.45 ~ 13995.28 N/S 11219.44 E/~ 8366.12 Dcte P tc:'ceO , I 0125/94 C ..... d By , . , /^ Checked By ApD,"oveci By , D~e , ECEIVED OC','r 2 8 i994. Gas Cons. Commission Anch0r~. · , , , . o , , , , 10. 11. NK 09 Operations Summary MIRU drilling rig. NU BOPs and test to 5000 psi. NU diverter and test. Spud well and drill 16" hole to 1500' md. Kick off and build angle to 45° by 4175'. Hold angle to 4444' md surface hole TD (4140' TVD). Set 13-3/8" casing and cement same. Test casing to 3000 psi for 30 minutes. Nipple up BOPs and test same to 5000 psi. Pick up 12-1/4" BHA and drill 10' of new hole and perform leakoff test. Drill ahead and hold 45° hole angle to 6431' md and build angle to 75 ° by 7935' md. TD the 12-1/4" hole below the West Sak formation at 14000' md, 7859' 'I-VD. Pick up 8-1/2" BHA and drill 10' of new hole and perform leakoff test. Drill ahead and hold 75° hole angle to 14932' md and begin drop and east turn to the top of the Kuparuk formation at 18331' md. Run 7-5/8" intermediate liner to the 8-1/2" hole TD and cement same. Pick up 6-3/4" BHA and drill 10' of new hole and perform FIT to maximum anticipated mud weight. Drill ahead and hold 70° hole angle to TD at 18,662' Run open hole logs and RFT's drillpipe conveyed. Run 5-1/2" Liner and cement same. Test casing to 3500 psi for 30 minutes. Run 4-1/2" NT-80S tubing. Freeze protect with diesel. Release rig. RECeiVED 0CT 2 8 1994 0il & Gas Cons. Commission Anch0ra~ Kick Tolerance Calc. Kick Tolerance Calculation Sheet: I Kick Tolerance: 128 bb~s (Based on Gas Influx) ^~`-~-`~-~--`-~.~`~-~.~.~`~-~j .......... ... ~....,...... ...... .~.~.. TD of hoe interval (tvd) ~iiiii~i~iiiiiiiiiiiiiiiifeet tvd Est Pore Press of Formation: ";';iiii':;iii~';i~'~i~'~;i';i~;;~i~iii'1 psig Density of Influx OIL ii!iiiiiiiiiii!iiiiiiii!iiii!ii~iiiii!iiiiiiiiiiiiiiiii ppg Density of Influx GAS iiii!iiiiiiliii!i!i!iiiiiiii~i~i i ii i i!iiiiil PPg Last Casing Shoe Depth (md): 4444 feet ii~ii~}~i~:.~'.:}~i!ii~i!~i'~!ii'i?i'i?!'i?!'!?i' Last Casing Shoe Depth (tvd): 4140 feet Hole Angle at the Shoe 4 5 degrees / LOT or FIT at Last Casing Shoe: ~iiii::ii!ii!ii[iiii~i~iiii::?:ii?:?:iiiiiii[?:iliiiii ppg Current Hole Size: iiiiiiiiiiliiii!i~i!iiiiiiiiiiiiiiiiiiiiiilil inches I dP in Annulus tor this MW I ................. ~'~'~' ............... psi/1000 ft 1. Estimate the Safety margin to be applied to the leak-off pressure at the open hole weak point: Annulus Back Pressure: 1 6 Safety Margin for Choke Operator: 150 I 1 66 psig 2. Calculate the maximum allowable static weak point pressure (Pmax): , :Max Allowable Static Pressure at the Shoe: 2525 psig EMW: 11.7 PPg I 3. Calculate the Maximum Allowable Height of Influx in the Openhole Section: Vertical Length I Vertical Length Length @ Influx Pt. Length @ Shoe C~ 3969 11604 5613 1078 3152 1525 4. Calculate the Volume that this height corresponds to at initial Shut-In Conditions: I OIL feet bbls bpf a) Across the BHA 270 23 0.0861 b) Across the DP 11334 1418 0.1251 Total BBLS influx 14411 bbls influx GAS (Assumes Free Gas) ! feet bbls I bPf I a) Across the BHA 270 23 0.0861 b) Across the DP t 2882 I 360 I 0.1251 Total BBLS influx i 3 84 bbls influx i I i · , 5. Calculate the volume of this height when the influx is at the Casing Shoe (Weak Point) S i 1451 bbls (Assumes Free Gas) I I 91 bi)Is 6. Calculate what this volume (in Step 5) is at intial shut in conditions: N/A to Boyles Law OIL I I I Boguss #- I 9641bbls (Assumes Free Gas) GAS I 1 28!bbls For worst case of wellbore intersection with flowing well NK-10 belore intermediate casing is set. Surface Casing Depth: Surface Casing Size: Surface Casing Weight: Bit Diameter: Excess Factor Intermediate Casing Depth: Intermediate Casing Size Intermediate Casing Weight: Proposed Top of Cement Bit Diameter: Excess Factor: Liner Size: Liner Weight: Hole TD Top of Cement Bit Diameter: Excess Factor: Drillpipe OD: Liner Size: Liner Weight: Hole TD Bit Diameter: Excess Factor: Driilpipe OD NK 09 Cement Volumes Surface String 4444 13 3/8 68 16 1.8 LEAD (TYPE "E" PERMAFROST) Yield 2.17 Density 1 2 # sacks 1383 (3002 Cu. Ft.) TAIL (CLASS G) Yield 1.15 Density 15.8 # sacks 375 (431 Cu. Ft.) TOP JOB (TYPE "C" PERMAFROST) # sacks 250 (235 Cu. Ft.) .94 cuft/sx 15.6 ppg Production String 14000 9 5/8 47 13200 12 1/4 1.9 LEAD Yield 1.98 Density 1 5 # sacks 0 # bbls 0 TAIL (CLASS G) Yield 1.2 Density 15.8 # sacks 4 24 # bbls 9 1 Intermediate Liner ( 0 Cu. Ft.) (509 Cu. Ft.) 7 5/8 45.5 18331 16500 8.5 1.9 5 TAIL (CLASS G) Yield 1.2 De nsity 15.7 # sacks 1 55 # bbls 3 3 (185 Cu. Ft.) Production Liner 5.5 17 18662 6.75 2 3.5 TAIL (CLASS G) Yield Density # sacks 1.2 15.7 113 (136 Cu. Ft.) RECEIVED 0C7 2 8 '19 4 ,nchor ,; NIAKUI~ASING DESIGN CASING DESIGN LIMITATIONS 8/30/93 N, EM · . , '/-'-u7-u , 4- 1/2", 10-3/4, 45.5, 29.7#, 13-3/8" 68#, 9-5/8", 47#, NTSOS, NSCC NT95HS, NT80, NSCC NT80S, NSCC 12 6#, L-80 NSCT .~_ · ' ~ .... -~----43- ......... NOM. WEIGHT 45.5 29,7 . 68 .... 47 12.6 ,~,, ~,_ DESIGN'~PECS: TENSION ' '1063000 813000 1545000 1122000 288000 ""'-" =~-'-:: ..... COLLAPSE 2470 7200 2260 4750 7'500 ........... ~.,~-~---_¢:_---~-"- ~ - _ B U FLS'q' ... 5210 8180 5020 6870.. 84:.3.0 ..... _~, .... ~.,,~..__~ ..... BP LIMITS: TENsi°N 70'86G7 ' ' '542000 1030000 748000 192000 COLLAPSE 2245 6545 2055 431 8 681 8 :72 BURST 4008 6292 3862 5285 6485 MAXIMUM FT.: MD TENSION.. - ~6472 31'017 25745''' 27050 ' 25899 ................... TVD COLLAPSE 1 0795 31'469 9878 20760 32780 TVD BUR,St 9634 15126 9283 12703 ! 5588 .......... Bi-axial stress not accounled f . , I_N__Ti,E__R__NAL FLUID DENSITY: ..... 7 PPG,,(COLLA',PSE) . ' _, ,, ,1, 0.5, P-'~G (BURS]') " EXTERNAL FLUID DENSITY: 1 1 PPG (COLLAPSE) ..... 2.5 PPG (BURST) I GAS SAFETY FACTORs..( 3_~); ..TENSIONCOLLAP.SE ...'..'.. 1.5'1. ! I ..... _ BURST 1.3 TVD AVERAGE: 9000 Fi: ' _ AVERAGE HOLE ANGLE: 4 5~° SURFACE PRESSDRE 4 0 0 0' PSI Page 1 Niakuk # 9 H2S Contingency Planning Detection Monitoring' Automatic montors: "General Monitor" visual and audio H2S alarm system Probe locations: rig floor shale shakers bell nipple cellar Setting Levels' Low - 10 ppm High o 20 ppm Manual: . . 1 -"Industrial Scientific" Model HMX271 H2S detector 2- "Industrial Scientific" Model STX410 H2S detectors 2- Dregers with benzene and H2S tubes Contingency and.Control: H2S treating material for the drilling will be Zinc Carbonate and is on location. Detailed emergency operating procedures are in place. Detailed step by step remedial procedures during tripping, fishing and drilling are in place. " 9 - 30 minute self contained breathing apparatus on location. H2S Training' All personnel onsite have H2S training. RECEIVED. OCT 2 8 1994 Alaska Oil & Gas Cons, Cor~rnissior~ -Anchora_, ,~ BP EXPLORATION ARCO Alaska, Inc. To: From: Robert P. Crandall Sr. Petroleum Geologist Alaska Oil and Gas Commission Adrian Clark Drilling Engineering Supervisor Shared Services Drilling Date' October 24, 1994 Subject' Exploratory Well Niakuk #9 Point of contact for exploratory well NiakUk #9 will be Phil Smith, Senior Drilling Engineer, Shared Services Department (564-5475). In the event that Phil cannot be reached, you may contact me at 564-4720. Re~ards,. ~t cc: Phil Smith Well file RECEIVED 0CT 2 8 1994 /~l~s~ Oil & Gas Cons. Commission Anchora~ic Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of BP Exploration (Alaska) Inc. for exception to 20 AAC 25.055 to allow drilling the Niakuk 9 development oil well. BP Exploration (Alaska) Inc. by letter dated October 26, 1994 has requested an exception to the provisions of 20 AAC 25.055(a)(3) for the drilling of an development oil well within the Prudhoe Bay Unit on the North Slope. The exception would allow BP to directionally drill the Niakuk 9 development oil well to a bottom-hole location that is closer than 500 feet from a quarter section line. The proposed surface location is 3998' from the north line and 1073' from the east line of Section 36, T12N, R15E, Umiat Meridian (UM) and the proposed bottom-hole location is 2599' from the south line and 850' from the west line of Section 23, T12N, R15E, UM. . A person who may be harmed if the requested order is issued may file a written protest prior to 4:00 PM November 14, 1994 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is timely filed and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 9:00 am on December 1, 1994 in conformance with 20 AAC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433 after November 14, 1994. if no protest is filed, the Commission will consider the issuance of the order without a hearing. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279-1433 no later than November 28, 1994. Russell A. Douglass, Commissioner Alaska Oil and Gas Conservation Commission Published October 29, 1994 WELL PERMIT CHECKLIST COMPANY UNIT# PROGRAM: exp n dev~ redrll ri serv [] ADMINISTRATION ENGINEERING GEOLOGY APPR DATE 1. Permit fee attached ................... Y 2. Lease number appropriate ................ Y 3. Unique well name and number ............... Y 4. Well located in a defined pool .............. Y 5. Well located proper distance from drlg unit boundary...Y 6. Well located proper distance from other wells ...... Y 7. Sufficient acreage available in drilling unit ...... Y 8. If deviated, is wellbore plat included ......... Y 9. Operator only affected party ...... ......... Y 10. Operator has appropriate bond in force .......... Y 11. Permit can be issued without conservation order ..... Y 12. Permit can be issued without administrative approval...Y 13. Can permit be approved before 15-day wait ........ Y 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N~_~ 17. CMT vol adequate to tie-in long string to surf csg . . . Y ~(~ 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. x(~w, N 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ 22. Adequate wellbore separation proposed .......... 9 N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N ~~ ~3 25. BOPEs adequate ..................... %k; N 26. BOPE press rating adequate; test to 5C)~ psig.G N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ ~ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............. Y ~ 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y N 32. Seismic analysis 9f shallow gas zones .......... Y N 33. Seabed condition survey (if off-shore) ......... Y N 34. Contact name/phone for weekly progress reports ..... Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: ~w~ Comments/Instructions: Z HOW/jo - A ~FORMS~cheklist rev 03/94 WELL PERMIT CHECKLIST GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] aery [] ADMINISTRATION 1. Permit fee attached ................... 2. Lease number appropriate ................ 3. Unique well name and number ............... Well located in a defined pool ............. 5.4' Well located proper distance from drlg unit boundary. 6. Well located proper distance from other wells ...... 7. Sufficient acreage available in drilling unit ...... 8. If deviated, is wellbore plat included ......... 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING GEOLOGY 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. 33. 34. GEOLOGY: Conductor string provided ....... · ........ Surface casing protects all known USDWs ........ CMT vol adequate to circulate on conductor & surf csg. CMT vol adequate to tie-in long string to surf csg . . CMT will cover all known productive horizons ...... Casing designs adequate for C, T, B & permafrost .... Adequate tankage or reserve pit ............ If a re-drill, has a 10-403 for abndnmnt been approved. Adequate wellbore separation proposed .......... If diverter required, is it adequate .......... Drilling fluid program schematic & equip list adequate BOPEs adequate ..................... [~ N . BOPE press rating adequate; test to ~~ psig. Choke manifold complies w/API RP-53 (M~ay 84) ....... Work will occur without operation shutdown ....... Is presence of H2S gas probable ............ Permit can be issued w/o hydrogen sulfide measures. · .~ Data presented on potential overpressure zones ..... Y Seismic analysls 9f shallow gas zones .......... Y Seabed condition survey (if off-shore) ......... Y N Contact name/phone for weekly progress reports ..... [exploratory only] d,-~,~J ~.,~/ / ~/~_~ Comments/Instructions ENGINEERING: COMMISSION: TAB c) z HOW/jo - A:~ORMS~ch.ek!ist rev 03/94 , :, · ~,. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. RECEIVED MAY 2! £ 1995 Alaska 011 & (;as Cons. Commission Anchorage tS Tore Veri~I,,cat:ion !~,ist,i..r~ ;hlomber!:!er; ,a!asica Co~.put, inq Cen. t~r 1 $'? STP t'.t4G 500292251,8,00 SCI.,,~[,,Uh'IBEt;?GER ~,,1!.',[.~[,, SERVICE',S 22-t' RUN 2 BlT .pI, l~>t 3 t 1281 !037 1 9. v 0 ['}PEr.: !'t/] !,t.:: C~SI ~,}G [)Ri LLE:¢S ~.!.r'.17 ,.<,!g.tC ['if",') SIZE (!..\Ii DEPTt-! 1,. 7,250 9.625 ! 4009 a, SO(', ~, 000 ! 8072 PAGE: chltimberc~.er i~.]..;::~sK.a C,'.)mF, utj..n<.~ Center 22- :~,~AR~!.995 1.6:04 PAGE: F.. 8H!FT D~:TA BASE;b I NE: 1'..) E: b' T ~.~ 8491.0 t~456.0 844.~ . 5 ~ ~44.3.0 1839~.S 1836~.n 18245.0 !7!4~,0 !8099,0 8033.0 1 O0,0 and clip~ed 0,5000 curvesg all. bit:. runs merqed, 1.~492,0 18482,0 !E454,5 1 84.45.5 18397.5 18392,0 183h7.0 ! 806 7.5 1. b036.0 ] (.~ 3.0 chlu'mberoer Alaska ¢oml?,ut;ir~o (:enter [,l.'~wG TO f!!. COD. E: TO OPmPjR ~ ~,0(; TY'OT CLASS ~tOO NUllS5 5~P ~':LE/,': CODE (HEX) ..................................._ __ ; .... GRRW rt~O AAPI (90 6 ,:,) O 00 0 1 1 ~. 4 68 0000000000 GPI~ ~" t', r: AAPI O(', CON O0 0 1. 1 1 a.. 68 0000000000 GP GR G a [~! ('.o 00 N 0 C 0 ! 1 ~ 4 68 0060000000 IS Taoe Verification chlumber,?.~er ~],,as~a Com[:~ut,~,n~ Cer>ter PAGE: t:) ~,i ? T. 1 g 500.000 G a P ~. i'< w i') G~.GR 10~.802 D F7 p T o 1, 9400. (i' 0 () G i?, [.~ w. i;"! ¢i L> G~ .G'R fi, t{ - 9 9 9. ~ 5 0 G [,~ l, it. i':: w 0 -999,250 79.0 () 0 50.971. 2~.271 28.734 29. O00 -999.25O ROP.MWD ROP.~D ROP. MWD 7.700 1, 0.20O 20.969 27.033 28.315 37.438 -999.250 ** END Curves and :l,o<t r~eaaer data each bit run _-!.r, ser:arate fi]eS. chlumherger ~'~laska Com!,..~t.i...ng Cent',er 22-MA['~-! 905 1,6:04 PAGE: t~. T 0 0 L LOGGED A ~ E: I L ,b E R ;,~ b O G .I. N C b i N X 1 ~,'[ U M STOP ~)EPTF~ OPI~.;N HOI,E 6'IT S!2, E fIN): D R I L t.., ['7: R $ C A 51 ,~.~ G 0 F. P T ii ( Ir T. ): N ~,TP I.Y: i"a A St' R I X TOO.i. ~TA~,!I)C, FW I' iLI): 2 1 - i:) F: C - 9 4 REAb-TIME ],8570.0 18548.0 60.0 64.4 TOOL NU~,tBER 6.000 1.8570,0 0,00{) 0.000 0.000 0o0 0,0 0,0 chlumbermer AlasKa Computi. nrJ Cemt. er 22-~.? AR.- 1. 995 16:04 P AGE: .bI~ FF~R~,AT I) ATA ROPV RAW F/HR VDE~ 0(;3 FT h N ** AP.I, AF't APl AP! FI [,,E NuMB N l.,J ~ ~ SIZE REPR PROCESS I.,OG TYPE CbASS N(3F) NUMi5 SAMP b2hE~'i CODE (HEX) ............. ;;; ................... -.-.; .......................... O~ oe o 2 ! 4 68 000000000 00 000 () 0 0 2 1 1. 4 68 000000000 On 000 O0 0 2 1 I 4 68 0000000000 On OOn O0 0 2 1 ! 4 68 000000000 OO Ouo oo 0 2 1 1 4 68 0000000000 (:0 00() (..}O 0 2 1 I. 4 68 0000000000 Oo OOO t)O 9 2 l 1, 4 68 0000000000 0e o(,o oo 0 2 1 1 4 68 000000000 DATA ** DEPT 1fi571 {~nO G'~ RA~,; -agq 250 GR .~,'it~b 99q 250 GR NOt: RFIPF:RAW -9e9.25~ R ~.'~P E. ,M ;::: L) -999.250 POPE. HC.)h -999.250 VDEP.O03 -999.250 9340.400 68.000 9304.900 I$ Tat~e verif!catJ, on !, i s t: i, r'~ <] chltlmber:'.i, er P,],,aske Cofnpl,t'Eii~c~ Cemter 22-g;!AR-! 995 1,6194 DEPT. ROPE.RAW DEPT. ROPE,RAW DEPT. ROPE. DEPT. ROPE DEpg" , g O p E'. P A W 51.000 9256,314 2O 000 92072936 30,000 91.61,373 33,000 91~6.678 -999,250 -999.250 f'; ! AKUi<., 50-029-22518-00 50-029-2251~-00 Well Records [,$ Tape Verif.!catic~n [~i. stinq ~l~lUm~erger alaska Comp~t~r.,q Ce.te.r L ,9 (.; G '1 ri (; E S U Ik F' h C ~; I., t3 C .~ :.i:n i-,~ ;',) ,.':.; N I P t" N i.,: F.F.L: ~ I.,, i!: V ,l'v I r_~ i,,t ( F' T wEt, bY D F: P R ! ',,'..! F L f, 9 5 0 q3 36 12~Jl 1037 59,6O 59, 19, t; 0 ,.3 P E :.,i i-1 I,) I'., dCASIt, G :~,'IT $lZ, t.;; (ir,i) SIZE 1.2.250 9,625 !4009,0 8,5o0 7, O00 I ~072, PAGE: ~hlumber'ger Al, asKa Compu~i. ng Center 22-I':'~ AR- 1995 16:90 ,,la0!3 - 18571 PAGE]: F ][: L F N [.i ~'rt E' E a: Depth shifted and # B ~ S L I N F: C tl P, V E: 1:,' C] R S ,t.~ I F' '? 5 E 5HI?T DA'.FA (iaFi~SUP.~_.': .............. la482.5 ~ R4.62,0 ~J.45~,0 I 8454.5 84.43.0 !.0441 ,5 a39~.5 la397,5 a39~,0 1G392,0 8245. n ! ~2,1.3. S 829R,5 16206.5 ~509~.0 ! gng9.~ 1.~n87.0 8o7(;. o !. 8~)~.~7. ~ & 033.0 ~. g n 36,0 1 on, O 1. 03,0 S'l~OP DEPT[i 18020.0 !':) E P T I..t .......... ItS ~,:~o~. Ver.i. flcat~o. Listi, na ch],,t.,..~erqer Alaska Co~,~:,~ttir, q Center 22-~,'~i,R-1,905 16:00 P Ii,; M A R k o, PAGE: , * D A T' A F n F], m A T $ .P E C ! ir I C A T 'l',' [,'~ N R. E C: O,R ~,,) ~, Tape '~eri~i. caC~.on 5J. st.it~g zhlumber<:ler AlasKa Computi..n<J Center (; P. (, R - 9 ~} 9.25 'J G~.GR 27 . ~.1..j; I) El p T. 1. 8200.000 (; R f:,' V,i. 4 W Gn.GR 42.021 DEPT, 1, ~I100. 000 GRP, W. MW D Gp.GR 37.3G,~, Gt~.GR 3.4,837 22-~,tAR-1.995 !6:00 -999.250 GR.!: tV, Mw[) 7 9.0 0 0 G R I ~,i. f4 W 9 2!.271 GRIN.MWD 2 g. 734 G R I ~,i. M w 13 2q 000 GRIN,I'qWt) -999,250 G,RtN. MWD -999.250 79.000 50.971 21.271 28,734 29.000 -999,250 R 0 P. M N~ D ROP.MWD RUP. PAGE: 7.700 10.200 20.969 27,633 28.315 37.438 -999.250 * * * * F ! L ~7 T iq a..I, L, E R * *, * F'TL~ NA~ : Ebl:l'~ .00!. S, ERVICE : VERSION : 001C01 i)arF : 95/a3/22 PIL, P TypK : !.,~..1 i.., l ST ~' I [. [{: * * * * F !'. 1., E H i:] h 0 kT. ~-~ * · *, S~'7p V !C~: : Fi.,! C V B.',R S I Clx'! : O01COl l'.) A T F : 931(23/722 ~nX RF:C SIZE : 1924 LnST FI!,g for each bit run in separate files. I.',$ Ta~'~e Ver,ificat!,on f.,istinq :hlumber'ger .~.l.'.aska Compu. t:.i.r~c~ Center 22 -~:~!AR-.!,995 1.6:00 P AGE: S T 0 P t:') E P T H 1 8 () 2 ,, 0 21. - D E C '- 94 DA?A TYPE (MEMO~'?' or REAl .... ~.!~',';C TOP [.,OG INT[:~VAh LF'T): PIT RGT.~']C]LP..]G 5PEF:D (RP~.,'~): VENDOR TOE)L, C[)t')E TC~()I,,, TYPE' ~[[,l.,,.~]a$ CAS,lNG I:,F'PT.H (FT): 1.8570.0 $ P 0 R E D H i 'I P, l' ~; PE~.'~A PKS: 0.0 ',.-.blu~-berger h!aska Comput~,n,n Center 22 >~ AI.~,., 199~ 0() - ...'; 516: PAGg: DFPq 185'/, ] . .':) C,~u O-R. R A'.,:, -99q. 250 R O'PF': ~ A W - ':~ q. ~. 2 5{.~P fid P,,. ,~", ~', i'). .Otaq. ,... · ?__t-;O_ ., i) I~ p 'r o 1 ¢ 5 0 0 o 0 C' (.' (-" 14 o P, ;,, ;~; 3 4 o 3 0 0 (; R. ~',t ~,,,,' 0 - 999.250 (..; g. H 0 L .~{OPe:. HC)b -999.250 VD~';P. 003 GR. [,,!WD 68. 000 C;1R · R 0 P b.;. H 0 i., l 0.800 V D F..'. P. n 0 .] -999.250 9340.400 68.000 9304.900 .IS Taee veri..iicati, on !i, istina cblumberger AlasKa Co~putj.'og Cent. er F I L F. r,l A. ~ id .. E i,',,) t T .0 O, 2 S [-"R v ICE : V ERS,[ r)h{ : 001C01 DATE : 05103/22 F 7I .f...~ E T Y P I'.,, ~ 8~r' F f !5 !~..: 51.. 000 1 ~. 9OO 20. 000 26. 30.0 o 0 28.500 33.00o 37.100 -999. 250 4,.'2,. 8OO G R. H t') b V f.;).i'!; P. o03 G ~ ... H U L 'V DE P. o 0.3 GP.. V D E P. 0 0.3 G f~. H Lt I,, V [')E P. 003 VDEP. 003 51.000 9256.31,4 :: 2~ 000 920 936 30,000 9161..373 33.000 9i16.678 -999.250 '999,250 ,,,, '..r, A p F., T R tX I [,, E P $1gI.~V!;CE ~Ja/iE : F, OIT D/t'];F? : o5!03 0 ~ .i ¢, l t,i : F 1,,,, ~ C !'A. PW t\)A~,~E : 95093 CONTI NUP,.Tl[irq ~ : 1. CO~.'~I'.:~E;~.~[I.' : f~f:' E;×PI.,L.;.PA'rI(.;!'~ 50-029-2251,~-00 R£CEIV£D & (::. J 2 ~' ]. P A ? f.;, 5.3 9 ¢, 29 o n 7 0 12.1,14 1,3.!16 -999.250 -999.2,50 2.067 4.461 2.861 8.837 9.11,4 4.629 - 999.250 -999. 250 ,., ,, ..':: , ; [ ., ,. . ,;-).i..1 !"] t F'J'n$ :';e'..r~';~?¢~o PAGE: 2.47U '999.250 2.688 '999.250 :--!1 , (' -999.250 265.9 o 9 ,q.:. 1'," i P - 999. ';> 50 V T:,'. 1;:'. ?, A. L'? 2.470 -999.250 2.6B8 -999.250 9. 'l 'l 7 ~..;, ~., .,, ;.., ,a, f'.: 5.971 -990. 250 ~,~,. ?," Al:.', .=. 09 C', ,'2.50 '",,*' k P. ,',!AP -0'¢9,75q 6.:, ,,. ,'!. 0 ,',"'1 -999,25.0 -999.250 -999.250 3,906 6.53~ 9.561, -999o250 -9o9.250 -999.250 ? 3 o '~ lO '7 4.0 5.r,t . 0 O. 0 . ,I, -999.250 9.042 -999.250 .,. f i ;I. e s, PAGE !.,' -9~9.250 2.067 -999.250 fi,],es. 16 O, 0 1.7 i -999.250 -0.039 -0.045 -999,250 (), (,') - , i,, .::" / ,,~ (,. ~ .,} .:'i .j .,,? ,. ,i., ?;: L 4< ,'i ~:i ".', ~J :'.:t :"..L :]. ".!~ ! ':; ~:: J' '. .... :~'_~ ,:t 'V i ,'~ ~' } c.! ,"! .i" ':i `''~ :[~ ..".. t ;' ;: .a. ~' .... ,.. :;"' .!] t:/ :.~-?~; ,.~: .,..' ~, ~'~ ..... ? <,, ,.' .j '.:'i :¢,: .~ O~ 21 4~. 9t 3 5.!72 297. ~'75 -999,250 -999.250 -999,250 -999.250 0.194 4.81.0 7.323 6.404 -999.250 -999,250 -999,250 6.400 B,:)-O?9-22b 1 b- (.,0 50-029-22518-hr! ECEIVED JAN Alaska Oil & Gas Cons. /%, /%. Run 1' 23 - December - 1994 DLL/ZDL/CNIGR Pipe Conveyed ATLAS 1855O Atlas Wireline Services lfape Subfile 2 is type: LIS TAPE HEADER NIAKUK UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6335.00 JOHN DAHL BOYER/PEAK NK - 09 500292251800 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 30-DEC-94 RUN 2 RUN 3 36 12N 15E 1281 1037 59.80 59.80 19.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 2ND STRING 3RD STRING 7.000 PRODUCTION STRING 6.000 REMARKS: DLL/ZDL/CN/GR. CIRCULATION STOPPED AT 1230, 22-DEC-94. PIPE CONVEYED LOGGING OPERATION. 18072.0 18570.0 CIRCULATED MUD SAMPLE NOT AVAILABLE. LOG TIED TO MWD CDR (05-DEC-94/SWS) PER CUSTOMER'S REQUEST. WIRELINE MARK REFERENCE WAS 2' SHALLOW TO MWD LOG AT 18000'. BARITE PRESENT IN MUD SYSTEM (5%), CAN EFFECT PE RESPONSE. RELATIVE BEARING REFERENCE: 180 DEG. = DENSITY PAD ON LOW SIDE OF HOLE. REPEAT SECTION NOT LOGGED TO TD DUE TO POSSIBLE HOLE PROBLEMS. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, OPEN HOLE BOREHOLE CORRECTION = 6.0", CHISM FILTERING IS ACTIVE, CASING CORRECTIONS OFF, SALINITY = 0.00 PPM. GR/CNC RAN TO 17910' IN LINER. NEUTRON LOG PARAMETERS: CASED HOLE SANDSTONE MATRIX, BOREHOLE CORRECTION = 8.5", CHISM FILTERING IS ACTIVE, CASING CORRECTIONS ACTIVE: CEMENT THICKNESS = 0.750" CASING THICKNESS = 0.408", SALINITY = 0.00 PPM. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 18064.0 18496.0 DLL 18064.0 18550.0 SDN 18064.0 18520.0 2435 18064.0 18502.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH LL3 NPHI RHOB 18073.5 18072.5 18087.0 18087.0 18086.0 18095.0 18094.0 18095.5 18095.0 18099.0 18099.5 18099.0 18109.0 18109.5 18108.5 18137.5 18137.0 18142.0 18142.0 18141.5 18170.5 18169.5 18200.5 18199.5 18206.0 18206.0 18206.5 18205.5 18209.0 18208.5 18223.5 18222.0 18231.5 18231.0 18243.5 18242.5 18255.0 18254.5 18254.0 18261.5 18261.0 18260.5 18272.5 18271.5 18273.0 18273.5 18276.0 18276.0 18285.0 18284.5 18284.0 18291.0 18291.0 18293.0 18291.0 18293.5 18294.0 18302.0 18302.0 18302.5 18301.5 18309.0 18308.5 18333.5 18332.5 18342.5 18343.5 18342.5 18358.5 18358.5 18372.5 18373.0 18372.0 18380.5 18380.5 18387.0 18387.0 18387.5 18392.0 18393.0 18391.0 18402.0 18401.5 18411.0 18410.5 18416.5 18416.0 18417.0 18419.0 18419.0 18424.0 18424.5 all runs merged; no case 18430.0 18430.0 18432.5 18432.5 18434.5 18439.5 18439.0 18441.0 18443.5 18442.5 18446.0 18446.0 18446.5 18449.0 18451.5 18473.5 18474.0 18474.0 18474.0 18478.0 18482.0 18482.5 18482.0 18482.5 18492.0 18491.5 18492.0 18496.0 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. PASS NO. GR 1 3 DLL 1 3 SDN 1 3 2435 1 3 $ REMARKS: 18434.5 18441.5 18448.5 18451.5 18473.5 18477.5 18481.0 18492.5 18496.0 MERGE TOP 18064.0 18064.0 18064.0 18064.0 MERGE BASE 18496.0 18550.0 18520.0 18502.0 OPEN HOLE portion of MAIN PASS. LLD, SP, MTEM, TEND, & TENS WERE SHIFTED WITH LL3. FUCT & NUCT WERE SHIFTED WITH NPHI. DRHO, PEF, CALl, & RB1 WERE SHIFTED WITH RHOB. / ? ?MATCH1. OUT / ? ?MATCH2. OUT /??MATCH3 .OUT $ CN : BP EXPLORATION WN : NK - 09 FN : NIAKUK COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units GR DLL 68 1 GAPI LL3 DLL 68 1 OHMM LLD DLL 68 1 OHMM SP DLL 68 1 MV MTEM DLL 68 1 DEGF API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 57 515 01 6 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 6 TEND DLL 68 1 LB 7 TENS DLL 68 1 LB 8 RHOB SDN 68 1 G/C3 9 DRHO SDN 68 1 G/C3 10 PEF SDN 68 1 BN/E 11 CALl SDN 68 1 IN 12 RB1 SDN 68 1 DEG 13 NPHI 2435 68 1 PU-S 14 FUCT 2435 68 1 CPS 15 NUCT 2435 68 1 CPS * DATA RECORD (TYPE# 0) Total Data Records: 67 966 BYTES * 4 30 739 95 4 30 739 95 4 22 779 91 4 22 779 91 4 22 779 91 4 22 779 91 4 22 779 91 4 98 211 23 4 98 211 23 4 98 211 23 60 Tape File Start Depth = 18564.000000 Tape File End Depth = 18064.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16017 datums Tape Subfile: 2 241 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 17913.0 2435 17913.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH NPHI 17922.0 17922.0 17927.5 17927.5 17938.0 17937.5 17944.5 17944.5 17959.0 17959.5 17963.0 17963.0 17967.0 17967.5 17987.5 17988.5 18002.0 18002.0 18004.5 18005.0 $ REMARKS: STOP DEPTH 18064.0 18064.0 - EQUIVALENT UNSHIFTED DEPTH CASED HOLE portion of MAIN PASS. FUCT, NUCT, TEND, & TENS WERE SHIFTED WITH NPHI. / ? ?MATCH4. OUT $ CN : BP EXPLORATION WN : NK - 09 FN : NIAKUK COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units GRCH 2435 68 1 GAPI NPHI 2435 68 1 PU-S FUCT 2435 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 08 501 10 0 4 98 211 23 1 4 98 211 23 1 4 NUCT 2435 68 1 CPS 5 TEND 2435 68 1 LB 6 TENS 2435 68 1 LB * DATA RECORD (TYPE~ 0) Total Data Records: 1014 BYTES * 24 98 211 98 211 98 211 23 23 23 Tape File Start Depth = 18064.000000 Tape File End Depth = 17908.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 2192 datums Tape Subfile: 3 49 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE S~Y FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 1 3 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 17910.0 18501.0 DLL 18050.0 18556.0 ZDL 17910.0 18525.0 2435 17910.0 18503.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT ISO ISO KNJT MODL GR CN ZDL KNJT TEMP PCM RB MIS DLL FTS $ SWIVEL SUB CABLEHEAD TENSION BRIDAL ISOLATOR BRIDAL ISOLATOR KNUCKLE JOINT MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR RB SUB MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS 23-DEC-94 FSYS J1V2 BETA RELEASE 4 1230 22-DEC-94 1511 23-DEC-94 18570.0 18562.0 17910.0 18550.0 1500.0 TOOL NUMBER 3944XA 3974XA 3997XA 3997XA 3921NA 1309XA 1309XA 2435XA 2222MA/2222EA 3921NA 2806XA 3506XA 3975XA 3967XA 1229MA/1229EA 6.000 18072.0 18064.0 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ CN : BP EXPLORATION WN : NK - 09 FN : NIAKUK COUN : NORTH SLOPE STAT : ALASKA 3% KCL POLYMER 9.95 50.0 9.1 5.2 177.0 .198 68.0 .081 177.0 .219 70.0 .000 .0 .298 66.0 .000 .0 THERMAL SANDSTONE 2.65 6.000 1.5 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 GR DLL 68 1 GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/M/~ ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 SHR ZDL 68 1 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN RB ZDL 68 1 DEG CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L 4 4 57 515 01 6 4 4 40 514 81 0 4 4 39 859 45 0 4 4 23 415 80 5 4 4 84 503 82 1 4 4 46 103 82 1 4 4 46 103 82 1 4 4 11 639 82 1 4 4 52 443 33 1 4 4 09 884 61 1 4 4 37 715 66 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 06 777 14 5 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 18 LSN 2435 68 1 CPS 19 SSN 2435 68 1 CPS * DATA RECORD (TYPE# 0) Total Data Records: 219 966 BYTES * 4 84 023 70 4 83 368 34 76 Tape File Start Depth = 18564.000000 Tape File End Depth = 17908.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 68518 datums Tape Subfile: 4 305 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 4 .2500 VENDOR TOOL CODE START DEPTH STOP DEPTH GR 18062.0 18414.0 DLL 18062.0 18469.0 ZDL 18062.0 18438.0 2435 18062.0 18416.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV CHT ISO ISO KNJT MODL GR CN ZDL KNJT TEMP PCM RB MIS DLL FTS $ SWIVEL SUB CABLEHEAD TENSION BRIDAL ISOLATOR BRIDAL ISOLATOR KNUCKLE JOINT MODAL SUB GAMMA RAY COMPENSATED NEUTRON Z-DENSITY KNUCKLE JOINT TEMPERATURE PULSE CODE MODULATOR RB SUB MASS ISOLATION SUB DUAL LATEROLOG FEED THROUGH SUB BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): 23-DEC-94 FSYS J1V2 BETA RELEASE 4 1230 22-DEC-94 1634 23-DEC-94 18570.0 18562.0 18064.0 18550.0 1500.0 TOOL NUMBER 3944XA 3974XA 3997XA 3997XA 3921NA 1309XA 1309XA 2435XA 2222MA/2222EA 3921NA 2806XA 3506XA 3975XA 3967XA 1229MA/1229EA 6.000 18072.0 18064.0 3% KCL POLYMER 9.95 MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: REPEAT PASS. $ CN : BP EXPLORATION WN : NK - 09 FN : NIAKUK COUN : NORTH SLOPE STAT : ALASKA 50.0 9.1 5.2 177.0 · 198 .081 .219 .000 .298 .000 THERMAL SANDSTONE 2.65 6.000 1.5 68.0 177.0 70.0 .0 66.0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 19 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 GR DLL 68 1 GAPI RS DLL 68 1 OHMM RD DLL 68 1 OHMM SP DLL 68 1 MV TEMP DLL 68 1 DEGF CHT DLL 68 1 LB TTEN DLL 68 1 LB SPD DLL 68 1 F/MN ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 SHR ZDL 68 1 PE ZDL 68 1 BN/E CAL ZDL 68 1 IN RB ZDL 68 1 DEG CNC 2435 68 1 PU-S CNCF 2435 68 1 PU-S CN 2435 68 1 PU-L LSN 2435 68 1 CPS SSN 2435 68 1 CPS 4 4 57 515 01 6 4 4 40 514 81 0 4 4 39 859 45 0 4 4 23 415 80 5 4 4 84 503 82 1 4 4 46 103 82 1 4 4 46 103 82 1 4 4 11 639 82 1 4 4 52 443 33 1 4 4 09 884 61 1 4 4 37 715 66 1 4 4 76 731 33 1 4 4 24 115 90 6 4 4 06 777 14 5 4 4 98 211 23 1 4 4 98 211 23 1 4 4 52 326 75 5 4 4 84 023 70 1 4 4 83 368 34 1 * DATA RECORD (TYPE# 0) Total Data Records: 140 966 BYTES * 76 Tape File Start Depth = 18477.000000 Tape File End Depth = 18060.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 35573 datums Tape Subfile: 5 224 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 6 is type: LIS 94/12/30 01 **** REEL TRAILER **** 94/12/30 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 30 DEC 94 1:47p Elapsed execution time = 12.91 seconds. SYSTEM RETURN CODE = 0