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MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NGI-08 PRUDHOE BAY UNIT NGI-08 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/15/2022 NGI-08 50-029-20219-00-00 176-052-0 G SPT 7403 1760520 1851 3436 3436 3437 3430 1 1 2 2 4YRTST P Brian Bixby 5/22/2022 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT NGI-08 Inspection Date: Tubing OA Packer Depth 271 2517 2491 2478IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220522153952 BBL Pumped:4.1 BBL Returned:4 Wednesday, June 15, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9James B. Regg Digitally signed by James B. 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JLC 1/4/2022 Jeremy Price Digitally signed by Jeremy Price Date: 2022.01.04 14:48:07 -09'00' RBDMS HEW 1/5/2022 tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůEĂŵĞ͗E'/ͲϬϴ W/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϬϮϭϵͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗'ĂƐ/ŶũĞĐƚŽƌ >ĞŐ͗ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗:ĂŶ ϭϳƚŚ͕ϮϬϮϮ ZŝŐ͗Eͬ ZĞŐ͘ƉƉƌŽǀĂů ZĞƋ͛Ě͍ϭϬͲϰϬϯ ĂƚĞ ZĞŐ͘ƉƉƌŽǀĂů ZĞĐĞŝǀĞĚ͗ ZĞŐƵůĂƚŽƌLJŽŶƚĂĐƚ͗ĂƌƌŝĞ :ĂŶŽǁƐŬŝ WĞƌŵŝƚƚŽ ƌŝůůEƵŵďĞƌ͗ϭϳϲͲϬϱϮ &ŝƌƐƚĂůů ŶŐŝŶĞĞƌ͗ĂǀĞũŽƌŬ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϰϲϳϮ Ğůů͗ϵϬϳͲϰϰϬͲϬϯϯϭ ^ĞĐŽŶĚĂůů ŶŐŝŶĞĞƌ͗ZLJĂŶdŚŽŵƉƐŽŶ KĨĨŝĐĞ͗ϵϬϳͲϱϲϰͲϱϮϴϬ Ğůů͗ϵϬϳͲϯϬϭͲϭϮϰϬ 'ĂƐ/ŶũĞĐƚŝŽŶZĂƚĞ͗ ΕϮϮϬ͕ϬϬϬ DƐĐĨͬĂLJ /ŶũĞĐƚŝŽŶWƌĞƐƐƵƌĞ͗ϯ͕ϱϭϴϳ ƉƐŝ ZĞƐĞƌǀŽŝƌWƌĞƐƐƵƌĞ; ƐƚŝŵĂƚĞͿ͗ϯϮϱϬ ƉƐŝ WƌŽŐƌĂŵKďũĞĐƚŝǀĞ;ƐͿ͗ E'/ͲϬϴ ŝƐĂŐĂƐ ĐĂƉ ŝŶũĞĐƚŝŽŶǁĞůůƚŚĂƚŚĂƐĚĞŵŽŶƐƚƌĂƚĞĚĂĚĞĐƌĞĂƐĞŝŶŝŶũĞĐƚŝǀŝƚLJ͘dŚĞǁĞůůŚĂƐŶŽƚďĞĞŶǁĂƚĞƌ ǁĂƐŚĞĚƐŝŶĐĞ ϮϬϬϮ͘tĂƚĞƌǁĂƐŚĞƐĂƌĞĚĞƐŝŐŶĞĚƚŽĚŝƐƐŽůǀĞƐĂůƚƐĂŶĚĂƐƉŚĂůƚĞŶĞƐŝŶƚŚĞƚƵďŝŶŐĂŶĚĨŽƌŵĂƚŝŽŶ͘ dŚĞŽďũĞĐƚŝǀĞŝƐƚŽƉĞƌĨŽƌŵĂƚƵďŝŶŐǁĂƚĞƌǁĂƐŚƚŽŝŶĐƌĞĂƐĞŝŶũĞĐƚŝǀŝƚLJĂŶĚƉĞƌĨŽƌŵĂŐĞŶĞƌĂůŵĂŝŶƚĞŶĂŶĐĞŽŶ 'ĂƐ/ŶũĞĐƚŝŽŶtĞůůƐ͘ WƌŽƉŽƐĞĚWƌŽŐƌĂŵ͗ WƵŵƉĚŝĞƐĞůĨŽůůŽǁĞĚďLJ&ƌĞƐŚtĂƚĞƌĂŶĚ^ƵƌĨĂĐƚĂŶƚĂƐƉĞƌĂƚƚĂĐŚĞĚƉƵŵƉŝŶŐ ƚĞŵƉůĂƚĞ͘ '/% tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ tĞůůtŽƌŬWƌŽŐŶŽƐŝƐ '/% • MEMORANDI State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,May 15,2018 TO: Jim Regg P.I.Supervisor Teri / 5 (/l S SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. NGI-08 FROM: Austin McLeod PRUDHOE BAY UNIT NGI-08 Petroleum Inspector Src: Inspector Reviewed B..y:j,, P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-08 API Well Number 50-029-20219-00-00 Inspector Name: Austin McLeod Permit Number: 176-052-0 Inspection Date: 5/9/2018 Insp Num: mitSAM180509151712 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NGI-08 Type Inj G TVD 7403 'Tubing 3345 - 3345 - 3344 - 3340 PTD 1760520 Type Test SPT Test psi 1851 IA 255 2500 - 2480 - 2483 BBL Pumped: 2 6 BBL Returned: 2.8 OA 1 - 0 1 1 Interval 4YRTST P/F P Notes: MIT-IA to 2500 psi as per operator request. 136 inj temp-start. 140 inj temp-end.Bled IA to 250 once test complete.OA had cmt to surface. SCANNED JUN 01241$ Tuesday,May 15,2018 Page 1 of 1 STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMIllikN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 176-052 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service 13 6. API Number: 50-029-20219-00-00 7. Property Designation(Lease Number): ADL 0028302 8. Well Name and Number: PBU NGI-08 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10925 feet Plugs measured feet true vertical 8704 feet Junk measured feet IVn I O\I 0 Effective Depth: measured 10820 feet Packer measured 8914 feet Bf �j�"� true vertical 8643 feet Packer true vertical 7406.5 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 82 20"94#H-40 31 -113 31-113 1530 520 Surface 2695 13-3/8"72#MN-80 29-2724 29-2724 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 1820 7"29#MN-80 9094-10914 7543-8697 8160 7020 Perforation Depth: Measured depth: See Attachment feet 4 L,0rlG scow, .e' Th IG vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 7"Baker S-3 Packer 8914 7406.5 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 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: 174716 260 3404 Subsequent to operation: 198367 300 3422 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ H SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature C. 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BPV GRAYBGAKERNGI ( BPV WILL NOT FULLY-�$ TEAT IN PROFILE 2006 R11Y0). ACTUATOR= KB.H.EV= 47 BF.F1EV= ? % I . KOP= 3200' '1 J 24' H7'X 7-5/8"XO,D=6.276" Max Angie= 58@10200' i Datum MD= 11106' �4 Datum TVD= 8800'SS �1 A.. 2190' —{7-5/8"X 7"XO,D=6.276" 7-518"TBG IPC,29.7#,L-80 VT,D=6.875"H 1211' ' I( ; 2201' —17"CA MCO DB-6 NP,ID=6.000" 9-5/8'TIEBACK CSG,47#,L-80 TCI,D=8.681" -- 2207' 1; 1' 1 2213' H 7"X 7-5/8"XO,D=6.276" 1� 1 fo • 2247' H9-518'HALLO ES CEM31TEB2 A, ? 9-5/8"TAB3ACK CSG,47#,L-80 BTC,D=8.681" —I 2259' .i' 4 13-3/8"CSG,72#,MN-80,D=12.347" —1 2695' , Minimum ID = 5.770" @ 8933' 7" HES RN NIPPLE 7-5/8"TBG-IPC,29.7#,NT95 VT.0459 bpf,13=6.875"H 8877' j ♦ / 8877' —17-5/8"X r XO,D=6.276" I I 8888' ---17"FES R NP,D=5.963" Z Z 8909' H9-5/8"X r BKR S-3 PKR,D=6.000" I I 8933' H7"FES RN NP,D=5.770" 7"TBG,26#,L-80 TCA,.0383 bpf,ID=6.276" H 8956' / \— 8956' H7"WLEG,D=6.200' H E31.0 TT NOT LOGGED TOP OF 7"LNR —1 9095' —11 9-5/8"CSG,47#,MN-80,D=8,681" --{ 9422' --'a PERFORATION SUMMARY REF LOG:BHCS ON 08/06/76 ANGLE AT TOP PERF:53©9952' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 3-3/8" 4 9952-10020 0 07/01/90 3-3/8" 4 10106-10209 0 05/02/87 3-3/8" 4 10225-10482 0 05/02/87 2-7/8" 6 10287-10377 0 10/28/15 3-318" 4 10500-10525 0 10/20/77 3-3/8" 4 10566- 10613 0 05/01/87 3-3/8" 4 10623- 10717 0 10/20/77 3-3/8" 4 10746- 10766 0 05/01/87 3-3/8" 4 10776-10786 0 10/20/77 %10716' —SELL TAGGED BY RIG(DMS 04/29/06) PBTD -H 10727' 111111111111 7"LNR, 29#,MN-80,.0371 bpf,D=6.184" S~ 10915' ........ DATE REV BY COMMENTS DATE REV BY COMVENTS FRUDHOE BAY UNIT 08/22/76 ORIGINAL COMPLETION 02/11/11 l,&JND ADDEDSSSV SAFETY NOTE WELL: NGI-08 05/02/06 N4ES RWO 11/16/15 DLW/JM)ADPE RFS(10/28/15) FERMI-Pb: 1760520 05/08/06 /TLH BP&RN PLUGS FULLEDAPI No: 50-029-20219-00 05/21/06 DC PTI'LH DRLG DRAFT(X)RF ECTIDNS SEC 12,1114,R14E 4244.42 FE_829.04 FTI. 03/04/07 LBS(TLH TBG PC CORRECTION 05/27/08 ST/SV IHEEC/O(05/21/08) BP Exploration(Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conser tion Commission TO: Jim Regg �� DATE: Tuesday, July 2014 I1 , 7I Zz IQ SUBJECT: Mechanical lnt}grity Tests i P.I. Supery sor 1 BP EXPLORATIbN (ALASKA) INC NGI-08 FROM: John Crisp PRUDHOE BAY UNIT NGI-08 Petroleum Inspector Src: Inspect Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-08 API Well Number 50-029-20219-00-00 Insp Num: mitJCr140513135549 Permit Number: 176-052-0 Rel Insp Num: Inspector Name: John Crisp Inspection Date 5/11/2014 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min W- NGI-08 ell - --- PTD I760520 - - - �---�--- : -- - -, TypeInj G'TVD 7403- IA 708 - 2508 2474 2445 �� 2422 2407 SPT' 1851 5 5 5 5 5 Test Test OA Intervaii4YRTST Type l-_ psi' - P/F P Tubing 3386 3388 3398 3399 3404 3406 . Notes: 2.17 bbls pumped. OA cemented to surface. 3CaNNED OCT 09 201.4; Tuesday, July 22, 2014 1 Page I of I MEMORANDUM TO: Jim Regg � 7 Its114 P.1. Supervisor v( FROM: John Crisp Petroleum Inspector State ofIaska Alaska Oil and Gas Conseriation Commission DATE: Wednesday, + 09, 2014 SUBJECT: Mechanical Intlegrity Tests BP EXPLORATION (ALASKA) INC NGI-08 PRUDHOE BAY UNIT NGI-08 Sre: . Inspecti r Reviewed By: 0.1. Supry y5f NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-08 API Well Number 50-029-20219-00-00 Inspector Name: John Crisp Permit Number: 176-052-0 Inspection Date: 5/11/2014 Insp Num: mitJCr140513135844 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Nell NCI -08 Type Inj G TVD 7403 IA 2445 - T 2445 I 2422 - 2407 'TD 1260520 Type Test SPT Test psi 1851 - OA 5 s 5 5 nterval .4YRTST P/F P Tubing 3399-- 3399 3404 3406 Notes: Retest. SCXNNED OCT 0 9 2 Wednesday, July 09, 2014 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, July 09, 2014 "� P.I. Supervisor k_Gr!j, &/,(, SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-08 FROM: John Crisp PRUDHOE BAY KNIT NGI-08 Petroleum Inspector Src: lnspecto� [reviewed By: P.I. Supry 3 -94 -- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT NGI-08 API Well Number 50-029-20219-00-00 Inspector Namej John Crisp Permit Number: 176-052-0 Inspection Date:l 5/11/2014 Insp Num: mitJCrl40513135549 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min NGI-08 , Type Inj G • TVD 7403 - IA 708 2508 - 2474 - 2445 rT�Well 1760520 Type Test SPT Test psi 1851 OA 5 4 s s - Interval I 4YRTST P/F P Tubing 3386 3388 3398 3399 Notes: 2.17 bbls pumped. OA cemented to surface. SCANNED 0 CT 0 9 2014, Wednesday, July 09, 2014 Page I of I • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 24, 2010 TO: Jim Regg ~~~ ~~~I Id P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-08 FROM: BOb Noble PRUDHOE BAY UNIT NGI-08 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv JT~-- Comm Well Name: PRUDHOE BAY UNIT NGI-08 Insp Num: mitRCN100518044252 Rel Insp Num: API Well Number: 50-029-20219-00-00 Permit Number: 176-052-0 Inspector Name: Bob Noble Inspection Date: 5/17/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NGI-08 'T`ype Inj. N'f TVD 7403 .% IA 0 4440 4400 4380 P.T.D I76osio TypeTest , SPT Test psi 4440 ~' OA o 0 0 0 1 aYRTST p/F Interv a P '~ Tubing zoso zs6o zs6o zsso ~ _ _ _ -- Notes: ails, ~~I I~ ~~ [~Fs; _ ,\\{{,~. i~ ~F\'. e tl ~1 E~~' Monday, May 24, 2010 Page 1 of 1 Gas Injector Volume Calculation~Flow meters replaced Page 1 of 1 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] A~ Ib~ ~ Sent: Wednesday, May 27, 2009 9:46 AM ~~~ `~ To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: Engel, Harry R; Rossberg, R Steven; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; NSU, ADW Well Integrity Engineer; GPB, FS1 Fac Engr Subject: Gas Injector Volume Caiculations -- Flow meters replaced Attachments: Gas Injector volume calculations.xis Jim, ~ / The flow meter on NGf-13 was blocked in on 03/29/09~n returned to surface on 05/11/09; as this transmitter developed a small gas leak and was removed from service at that time. It wasn't until later that the lower design pressure was noticed on this and other transmitters, at which time the remainders were blocked in. The flow meters on NGI-01 03 04 05 08 12 were blocked in on 04/23/09 ancJ o a ed b ck in service on 05/12/09. The pressure-rate data for operation before and after this time was extrapolated graphicall to determine the rates for the time the transmitters were blocked in. Allowing them to operate or a short time after they were put back in senrice has been helpful in assuring the most accurate representation of the time they were out of service. I have attached a spreadsheet containing daily rates and pressures, as well as the graphical analysis completed to obtain the data for the time the transmitters were out of service. «Gas Injector volume calculations.xls» ,./ Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 c~~e-~-- ~__-- ~c~ ~G.~- o I ~Gc~~c r~GT - 0 3 P,~ , ,.~~ ~~~~~~ ~~ ~ ~l ° ~~ 2009 ~~ ~~- ~'~~ ~~~- os ('~u ~-~s~ ~'l~u !~C~-~Z ~~i~ ~~- i 3 ~ ~ t ~S-D~~ I~~-bC;( I~S°D~~'I r~~--~c~c~ ~~~ --' s= 177-C~"~I 2~~- 1~~ 8/6/2009 ~ • SUMMARY OF INJECTED VOLUMES DURING FLOW TRANSMITTER OUTAGE Volume Tubing Injected Pressure Date (MCFPD) (psi) NGI-01 05/12/09 119,210 3,165 05/11/09 117,670 3,148 05/10/09 136, 884 3, 360 05/09/09 144,134 3,440 05/08/09 143,228 3,430 05/07/09 145,131 3,451 05/06/09 143,681 3,435 05/05/09 140,146 3, 396 05/04/09 140,509 3,400 05/03/09 142,865 3,426 05/02/09 141,868 3,415 05/01 /09 140, 871 3,404 04/30/09 135,796 3,348 04/29/09 135,977 3,350 04/28/09 134,708 3,336 04/27/09 133,530 3,323 04/26/09 140,056 3,395 04/25/09 142,503 3,422 04/24/09 140,328 3,398 04/23/09 138,515 3,378 NGI-03 05/12/09 110,330 3,450 05/11/09 110,692 3,455 05/10/09 110,836 3,457 05/09/09 111,053 3,460 05/08/09 113,151 3,489 05/07/09 113,657 3,496 05/06/09 113,006 3,487 05/05/09 112, 211 3,476 05/04/09 113,947 3,500 05/03/09 113,368 3,492 05/02/09 114,814 3,512 05/01 /09 114, 091 3, 502 04/30/09 113,874 3,499 04/29/09 112,934 3,486 04/28/09 112,138 3,475 04/27/09 111,487 3,466 04/26/09 113,802 3,498 04/25/09 113, 947 3, 500 04/24/09 114, 091 3, 502 04/23/09 114,742 3,511 NGI Volume Calculations ~ ~ • NGI-04 05/12/09 112,110 3,070 05/11/09 112,143 3,050 05/10/09 111,633 3,356 05/09/09 111,437 3,474 05/08/09 114,568 1,595 05/07/09 113,765 2,077 05/06/09 111,428 3,479 05/05/09 111,498 3,437 05/04/09 111,488 3,443 05/03/09 111,445 3,469 05/02/09 111,460 3,460 05/01 /09 111,488 3,443 04/30/09 111,587 3,384 04/29/09 111, 575 3, 391 04/28/09 111,603 3, 374 04/27/09 111,630 3,358 04/26/09 111,493 3,440 04/25/09 111,450 3,466 04/24/09 111,490 3,442 04/23/09 111,410 3,490 NGI-05 05/12/09 179,667 3,375 05/11/09 179,789 3,380 05/10/09 179,910 3,385 05/09/09 180,007 3,389 05/08/09 179,813 3,381 05/07/09 180,299 3,401 05/06/09 179,935 3,386 05/05/09 179,010 3,348 05/04/09 179,108 3, 352 05/03/09 179,667 3,375 05/02/09 179,472 3,367 05/01/09 179,156 3,354 04/30/09 177,892 3,302 04/29/09 178,062 3,309 04/28/09 177,721 3,295 04/27/09 177,405 3,282 04/26/09 179,108 3,352 04/25/09 179,667 3,375 04/24/09 179,156 3,354 04/23/09 180,178 3,396 I-08 05/12/09 150,117 3,470 05/11/09 150,117 3,470 05/10/09 150,117 3,470 05/09/09 149, 821 3, 467 05/08/09 148,833 3,457 05/07/09 151,599 3,485 05/06/09 150,117 3,470 05/05/09 145,869 3,427 05/04/09 146,067 3,429 05/03/09 148,438 3,453 NGI Volume Calculations 2 ~ ~ 05/02/09 147, 351 3,442 05/01/09 145,573 3,424 04/30/09 139,744 3,365 04/29/09 140,535 3,373 04/28/09 138,954 3,357 04/27/09 137,275 3,340 04/26/09 145,672 3,425 04/25/09 148,142 3,450 04/24/09 145,968 3,428 04/23/09 151,006 3,479 NGI-12 05/12/09 179,508 3,400 05/11/09 179,508 3,400 05/10/09 179,508 3,400 05/09/09 181,429 3,419 05/08/09 180,216 3,407 05/07/09 179,508 3,400 05/06/09 179,508 3,400 05/05/09 177,485 3,380 05/04/09 177,587 3,381 05/03/09 180,014 3,405 05/02/09 179,002 3,395 05/01/09 177,283 3,378 04/30/09 171, 721 3, 323 04/29/09 172,429 3,330 04/28/09 170,912 3,315 04/27/09 169,294 3,299 04/26/09 177,485 3,380 04/25/09 180,014 3,405 04/24/09 178,193 3, 387 04/23/09 182,946 3,434 13 05/10/09 246,658 3,350 05/09/09 246,368 3,341 05/08/09 246,078 3,332 05/07/09 246,754 3,353 05/06/09 246,497 3,345 05/05/09 243,279 3,245 05/04/09 245,306 3,308 05/03/09 245,692 3,320 05/02/09 245,660 3,319 05/01/09 243,247 3,244 04/30/09 240,801 3,168 04/29/09 243,955 3,266 04/28/09 243,375 3,248 04/27/09 243,086 3,239 04/26/09 245,370 3,310 04/25/09 246,078 3,332 04/24/09 245,564 3,316 04/23/09 246,979 3,360 ~ NGI Volume Calculations 3 • ~ 04/22/09 247,494 3,376 04/21/09 246,979 3,360 04/20/09 247,366 3,372 04/19/09 247,333 3,371 04/18/09 247,301 3,370 04/17/09 247,301 3,370 04/16/09 246,658 3,350 04/15/09 246,722 3,352 04/14/09 245,821 3,324 04/13/09 244,244 3,275 04/12/09 243,536 3,253 04/11 /09 239,160 3,117 04/10/09 243,729 3,259 04/09/09 244,051 3,269 04/08/09 244,823 3,293 04/07/09 246,304 3,339 04/06/09 247,816 3,386 04/05/09 247,591 3,379 04/04/09 247,816 3,386 04/03/09 248,234 3,399 04/02/09 248,363 3,403 04/01/09 245,692 3,320 03/31/09 243,987 3,267 03/30/09 246,175 3,335 03/29/09 247,237 3,368 03/28/09 249,103 3,426 03/27/09 248,588 3,410 03/26/09 245,757 3,322 03/25/09 245,049 3,300 03/24/09 245,049 3,300 NGI Volume Calculations 4 155, 000 150,000 145,000 0 140,000 ~ 135,000 130,000 125, 000 NGI-01 y = 90.632x - 167640 3,300 3,350 3,400 3,450 3,500 3,550 pressure ~ • NGI-03 140,000 120,000 100,000 80, 000 w ~ ~ 60,000 40,000 20,000 0 3, 350 3,400 3,450 3,500 3, 550 3,600 ~ ~ PRESSURE y = -1.6665x + 117226 160,000 140, 000 120, 000 100,000 w ~ 80,000 ~ 60,000 40,000 20,000 NGI-04 3,300 ~ ~" ~ -i r.~ r.'.. 3,350 3,400 3,450 3,500 PRESSURE 3, 550 3,600 ~ ~ NGI-05 182, 000 181,500 181,000 180, 500 180,000 a~ r ~ ~ 179, 500 179,000 178,500 178,000 177, 500 y = 24.302x + 97587 ~ n ~ 3,300 3,320 3,340 3,360 3,380 3,400 3,420 3,440 3,460 3,480 Pressure , 160,000 155,000 150,000 m ~ 145,000 140, 000 135, 000 130 000 NGI-08 y = 98.79x - 192684 3,300 3,350 3,400 3,450 3,500 3,550 3,600 Pressure i • NGI-12 rate = 101.13(pressure) - 164334 200,000 195, 000 190,000 185, 000 d ~ 180,000 175, 000 170,000 165,000 160,000 ~- 3, 300 3,350 3,400 3,450 3, 500 • Pressure NGI-13A 260,000 255,000 ~ 250,000 245,000 w t-- ~ 240,000 235,000 ~ 230,000 225,000 2,500 2,600 2,700 2,800 2,900 3,000 PRESSURE 3,100 3,200 3,300 3,400 3,500 UPDATE: NGI Flow Transmitte~ ~ Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, May 04, 2009 2:11 PM ~L' ~~'~/~ ~ To: Regg, James B (DOA) ~~ Cc: GPB, FS1 OTL; GPB, Area Mgr North (Gas Plants/GPMA); GPB, FS1 Fac Engr; Rossberg, R Steven; NSU, ADW Well Integrity Engineer; Daniel, Ryan; Bill, Michael L(Natchiq}; Cahalane, Ted W; Dahlem, Jason E; Seymour, Len I; NSU, ADW Well Operations Supervisor; Cismoski, Doug A; Engel, Harry R Subject: UPDATE: NGI Flow Transmitters Jim, After further evaluation, it has been decided to leave the underrated flow transmitters on the seven_N I wells isolated until the fully rated transmitters are available for replacement. The fully rated transmitters are expected to arrive on the slope on May 13th and work to install them is planned to begin on May 15th. After the transmitters are replaced, calculations will be made to determine injection volumes and rates for the time the meters were out of service. We will also provide our calculation and the exact number of days the flow meters .~ were out of service. We will continue to update you on the status of the replacements. If you have any questions in the interim, please don't hesitate to contact me or Anna Dube. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Engel, Harry R Sent: Thursday, April 23, 2009 4:57 PM To: )ames Regg Cc: GPB, FSl OTL; GPB, Area Mgr North (Gas Plants/GPMA); GPB, FSl Fac Engr; Rossberg, R Steven; NSU, ADW Well Integrity Engineer; Daniel, Ryan; Bill, Michael L(Natchiq); Cahalane, Ted W; Dahlem, Jason E; Seymour, Len I; NSU, ADW Well Operations Supervisor; Cismoski, Doug A; Engel, Harry R Subject: NGI Flow Transmitters Jim- This is a follow up to our telephone conversation this afternoon regarding flow transmitters at ~ NGI pad. The NGI 13 flow transmitter failed on March 29th. There was a minor gas release associated with the failure, far below 1 MMSCF. The flow transmitter was found to be underrated, yet the 8/6/2009 ~ UPDATE: NGI Flow Transmitte Page 2 of 2 ~ ~ body is fully rated. We disc~vered six additional underrated flow transmitters at NGI 1, 3. 4. 5, 8, 12. All seven flow transmitters have been temporarily taken out of service. The wells remain on injection. No other gas injection well flow meters are affected. We have taken the following actions; a. Contacted the manufacturer and ordered metal backed Viton O rings which will increase transmitter operating pressure rating. These O rings will be installed in all seven wells within 1'~ week. This is a temporary modification until new transmitters are installed. b. New fully rated transmitters have been identified and will be installed in all wells in ~ approximately 2-6 weeks. Flow rates will be calculated during the periods when the transmitters are out of service. ~ As you requested, we will send you the flow rate calculation method and the total number of ~ days the transmitters were out of service. I will be out of the office for a few days next week. If you have any questions, please contact Andrea Hughes at 659-5102. Regards, Harold R. Engel (Harry) Engineering Team Leader Integrity Management, Alaska Drilling & Wells 907-564-4194 office 907-564-5510 fax 8/6/2009 RECEIVED \1(g~Ob~ Schlumberger MAY 2 4 2006 NO. 3812 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth ;,kSa C'ÍI .& Gõs COns. CCmæ{&-.¡c,; 1 ~1d'.c~.e Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Date BL Color CJ) D-23A 10942207 MCNL Ie; Cc -- í~";;' 04/22/05 1 UJ " Arl.1,.'d"J.. 1.:>. L3-08 11136738 RST I'<~ - I <.J~ 11/04/05 1 1 L3-08 11212839 RST I"'x' ~ - t-/3 03/29/06 1 1 03-14A 11212846 US IT ~C"" "" 1"::1 'fr 04/24/06 1 D.S. 3-09 11212840 USIT 1'1£1 - ò 9,~ 03/31/06 1 D.S. 15-17 11221562 SCMT ¡ 'f'-ì- I")~ 04/10/06 1 NGI-08 11225958 USIT U ':te.. l-r r'.-. - ö,"1~ 04/11/06 1 D.S.01-04A N/A USIT ~() 1- 1:5";:J 05/06/06 1 12-08C 11221571 USIT ;'Òd- - I 3 J... 05/06/06 1 AGI-07 11221569 USIT U~c:. \ '1:; - 69"1- 05/05/06 1 E-158 11212857 US IT I e>,C; -04::), 05/18/06 1 L-50PB1 40012467 OH LDWG EDIT OF MWD/LWD ::¡{~ ,.ç - I -=< C-o 10/18/05 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATIN: Beth ~,Jk- s-i () s/(JÇo BDOZ £ U ¡\ìl~) f· (t4A'Ml{\ý;~..\.. ..' II ~ H'?:M!~I" ,,;~1~.~ 05/19/06 e e MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: . Jim Regg P.I. Supervisor -¡-:>.-¡ I I c...,fé?1 ::;, (C(,C~ DATE: Wednesday, May 17,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-08 PRUDHOE BAY UNIT NGI-08 lei' 05 ')-- \'\ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ ),~?- Well Name: PRUDHOE BAY UNIT NGI-08 API Well Number 50-029-202 I 9-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS0605I7070617 Permit Number: 176-052-0 Inspection Date: 5/1 6/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --." , I ! Well ¡ NGI-08 ¡Type Inj. I G I TVD 7402 I IA 500 3000 2980 2980 I 10 I I I P.T. 1760520 ¡TypeTest ¡ SPT I Test psi 1850.5 , OA ! 0 0 0 i ¡ -- Interval WRKOVR P/F P Tubing i 3650 , 3650 i 3650 3650 , .-----'------ Notes Pretest pressures were observed and found stable. Well demonstated good mechanical integriy. NON-CONFIDENTIAL Comm IUl' < (,2 r¡I"':\\'n¡~J' SCANNED ,-,' \ _~ ...: L~, Wednesday, May 17,2006 Page I of I STATE OF ALASJ¿ ..ff/¡bb ALAS~IL AND GAS CONSERVATION d!!I1MISSION REPORT OF SUNDRY WELL OPERATIONS!', 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program ~ Repair Well ~ Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Time Extension o Other o Re-Enter Suspended Well 2. Operator Name: BP Exploration (Alaska) Inc. ress: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Well Class Before Work: o Development 0 Exploratory o Stratigraphic ~ Service 99519-6612 176-052 6. API Number: 50-029-20219-00-00 47' 9. Well Name and Number: PBU NGI-08 8. Property Designation: ADL 028302 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 10925 feet true vertical 8704 feet Plugs (measured) None Effective depth: measured 10716 feet Junk (measured) None true vertical 8584 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' 1530 520 Surface 2695' 13-3/8" 2695' 2695' 5380 2670 Intermediate 9422' 9-5/8" 9422' 7790' 6870 4760 Production Liner 1820' 7" 9095' - 10915' 7544' - 8698' 8160 7020 , " . N~r ~\f~Nt,:.' Perforation Depth MD (ft): Perforation Depth TVD (ft): 9952' - 10786' 8159' - 8623' Tubing Size (size, grade, and measured depth): 7-5/8",29.7# x 7", 26# NT-95/L-80 8956' Packers and SSSV (type and measured depth): 9-5/8" x 7" Baker 'S-3' packer 8909' 12. Stimulation or cement squeeze summary: Intervals treated (measured): DMS BFL MAY 1 6 2006 13. Treatment description including volumes used and final pressure: Pulled tubing. Cut 9-5/8" casing and pulled from 2259'. Ran 9-5/8" tieback to surface. Cemented w/135 Bbls Class 'G' using an ES Cementer located at 2247'. Ran new 7-5/8" x 7" tubing. Re resentative Dail Gas-Mcf 144,787 85,318 15. Well Class after proposed work: o Exploratory 0 Development ~ Service 16. Well Status after proposed work: o Oil 0 Gas 0 WAG ~ GINJ 0 WINJ 0 WDSPL t at t e oregolng IS true and correct to t e best 0 my know edge. Sundry Number or N/A if C.O. Exempt David Reem, 564-5743 306-024 Oil-Bbl Water-Bbl Tubin Pressure 3,521 3,829 Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ Well Schematic Diagram Title Technical Assistant Phone 564-4628 Date 05//0(OCo PrepareQ By Name/Number: Terrie Hubble, 564-4628 Submit Original Only · DRLG DRAFT 3200' 58 @ 10200' 11106' 8800' SS 9-5/8", 47#, L-80 TC-II fully cemented to surface above existing TOe in 9-5/8" x 13-3/8" annulus 113-3/8" CSG, 72#, MN-80, ID = 12.347" I 17-5/8",29.7#, L-80, IPCVamTop HCTUBING 17" 26# L-80 NPC, TC-U TUBING I TOP OF 7" LNR 1 9-5/8" CSG, 47#, MN-80, ID = 8.681" I PERFORA TION SUMMA RY REF LOG: BHCS ON 08/06/76 ANGLE AT TOP PERF: 53 @ 9952' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 9952 - 10020 0 07/01/90 3-3/8" 4 10106 - 10209 0 05/02/87 3-3/8" 4 10225 - 10482 0 05/02/87 3-3/8" 4 10500 - 10525 0 10/20/77 3-3/8" 4 10566 - 10613 0 05/01/87 3-3/8" 4 10623 - 10717 0 10/20/77 3-3/8" 4 10746 - 10766 0 05/01/87 3-3/8" 4 10776 - 10786 0 10/20/77 IPBTD I 10727' 10727' 10716' I FILL PBTD (MD) 05/01/87 I IPBTD I 17" LNR, 29#, MN-80, .0371 bpf, ID = 6.184" I 10915' DATE 08/22/76 07/18/01 12/04/05 REV BY COMMENTS ORIGINAL COMPLETION RNlTP CORRECTIONS DAV/PAG CORRECTIONS DATE NGI-08 ~NOT~ SPV PROALE IS NOT RJ NAL ILL NOT RJLL Y SEAT IN PROALE'I REV BY -17" CAMeO DB-6 NIP, ID = 6.000" I 8888' H 7" HES R LANDING NIP, ID = 5.963" I 8909' l-i 9-5/8" x 7" Baker S-3 Packer, ID = 6.00" 8933' H 7" HES RN LANDING NIP, ID = 5.770" COMMENTS PRUDHOE BA Y UNff WELL: NGI-08 PERMff No: 76-052 API No: 50-029-20219-00 SEC 12, TUN, R14E 4244.42 FEL 829.04 FNL BP Exploration (Alaska) e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/212006 03:00 - 12:00 9.00 MOB P PRE Wait on slickline to finish pulling plug in SSSV on NGI-08, so as to be able to move rig on. 12:00 - 13:30 1.50 MOB P PRE PJSM. Scope down & layover derrick. Rig down rig components. 13:30 - 16:00 2.50 PRE PJSM. Move rig & rig components from WGI-04 to NGI-08. 1/2 mile move. 16:00 - 19:30 3.50 MOB P PRE PJSM. Layout herculite & matting boards. Back rig sub up on matting boards & spot rig components over well & rig up on NGI-08. 19:30 - 21:00 1.50 MOB P PRE Hold PJSM. Raise & scope up derrick. Con't to RlU equip. 21 :00 - 23:00 2.00 WHSUR P DECOMP Accepted rig @ 2100 hrs. Take on 9.8 ppg brine. Check annulus, slight vacuum, then died. Check tree. Slight blow. P/U lubricator pull BPV & check for pressure. Lube pressure 50 psi. Bled off & died. Reset BPV & Dart. UD lubricator. 23:00 - 00:00 1.00 WHSUR P DECOMP Begin N/D tree & Adapter flange. Bolts corroded & tight. 4/3/2006 00:00 - 02:00 2.00 WHSUR P DECOMP N/D Tree & adapter flange. Inspect threads. Do not appear to be 7" 8 Rd as per program. Unable to get X-Over over BPV/Blanking plug. Plan to spear casing. 02:00 - 03:00 1.00 WHSUR P DECOMP Bleed off SSSV control lines. Back out SMRs & blank off same. 03:00 - 06:00 3.00 BOPSU DECOMP N/U BOPE. Wellhead very crooked. 06:00 - 06:30 0.50 BOPSU DECOMP PJSM. Pressure up & body test BOPE against 2 way check & hanger, flatlining @ 4000 psi, OK. Will not need to hang off 7" & set RTTS, as previously planned. 06:30 - 08:30 2.00 BOPSU DECOMP PJSM. C/O pipe rams from 3 1/2" x 6" VBRs to 7". 08:30 - 09:00 0.50 BOPSU DECOMP PJSM. Commence BOPE test, small leak noted in blind rams, bleed all pressure. 09:00 - 12:00 3.00 BOPSU DECOMP PJSM. Change out blind rams to blind I shear rams. 12:00 - 18:00 6.00 BOPSU DECOMP Conduct full test on 13 5/8" x 5M BOPE. AOGCC State Rep Chuck Sheve witnessing test. Test all components @ 250 I 4000 psi. Annular preventor tested @ 250 I 3500 psi. Kelly & kelly valves tested @ 250 I 4000 psi. No failures. 18:00 - 18:30 0.50 BOPSU P DECOMP RID test equip. drain lines & stack. 18:30 - 19:30 1.00 WHSUR P DECOMP P/U & M/U 7" Spear Assy.P/U lubricator & pull Blanking plug & BPV. UD lubricator. 19:30 - 20:00 0.50 PULL P DECOMP P/U & M/U Spear Assy. as follows: 7" Pack off, Sub, ITCO Spear, Spear Extension, Stop Sub, Sub. TL = 13.88'. 20:00 - 20:30 0.50 PULL P DECOMP RIH & latch spear into 7" tubing. BOLDS. 20:30 - 23:00 2.50 PULL P DECOMP Work pipe & attempt to pull hanger to floor. Pulled to 275K, Approx 55K over. No success. Mix 40 bbl EP Mud lube pill & around. 4 BPM @ 370 psi. Con't to work pipe. Pipe finally started to move. Pull hanger up into Stack & then hung up. 23:00 - 00:00 1.00 PULL P DECOMP Drain BOP stack & inspect hanger. Retaining ring & snap ring came loose & are floating on top of hanger body, causing string to hang up. Fish out both rings w sheperds hook. 4/4/2006 00:00 - 00:30 0.50 PULL P DECOMP Fish out rings on top of hanger;pull & work hanger thru stack. Have 30-60K drag while coming out. Finally got hanger to surface. Top seal rubber missing. Calc string wt = 222K. 00:30 - 01 :00 0.50 PULL P DECOMP Break out hanger, pup jt & spear. UD same. Tubing has much gritty scale externally. 01 :00 - 02:30 1.50 PULL P DECOMP Install circulating head & circulate bottoms up. 5 1/2 BPM @ 400 psi. RlU tubing tongs & spooling unit. Work pipe. drag dropping off. Printed: 5/812006 11 :55:43 AM ,e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/4/2006 02:30 - 06:00 3.50 PULL P DECOMP POOH & UD 7" tubing. Spool up control lines. Drag dropped to 15-30K over. Casing very scaley externally. Pulling slowly due to bands binding. 9 jts laid down @ 06:00 hrs. 06:00 - 12:00 6.00 PULL P DECOMP PJSM. Continue pulling 7" tubing & dual control lines, pipe very scaly, (loose scale). Sample sent in to Dowell lab for analysis. Control line & control line bands broken & separated in places. Tong head on hydraulic tongs fractured longitudinally along the insert edge resulting in (1) tong die being lost down hole. Recovered (50) control line bands. 12:00 - 13:00 1.00 PULL P DECOMP PJSM. Rig down spooling unit. 13:00 - 14:00 1.00 PULL P DECOMP Continue to POOH & UD 7" 8 rnd tubing. 14:00 - 15:00 1.00 PULL P DECOMP Small amount of diesel flow up tubing. M/U headpin & circulate well. Monitor well, well dead. Remove headpin. 15:00 - 00:00 9.00 PULL P DECOMP Continue to POOH & UD 7" tubing. At 20:00 hours, PU Hanger and Spear to attempt to release Spear - No Joy. Will send in the Hanger and Spear to Baker to attempt to release without having to cut it out. Continue to POOH and UD 7" Tubing. 4/5/2006 00:00 - 00:30 0.50 PULL P DECOMP On surface with 7" x 51/2" XO and (1) full joint of 51/2" L-80 8 round Tubing. Lay down the XO and joint. Next up is Sliding Sleeve and then (2) full joints of 5 1/2" Tubing. The third joint was cut about half way through it. 00:30 - 01 :30 1.00 PULL P DECOMP On surface with 5 1/2" Tubing Stub from Jet Cut. The cut appears to be fairly clean and slightly flared out. Doesn't appear to have any indications of possible problematic areas on the Stump below when trying to enter later. Lay down the Stub. Stub length = 15.95'. Noticed some stainless steel control line bands in the BOP Stack. Fished out 6 and 1/2 bands along with (1) API ring / hanger ring. That brings the total to 56 and 1/2 bands recovered. 01 :30 - 05:00 3.50 BOPSU P DECOMP PJSM. Begin to change out Pipe Rams to 3 1/2" x 6" Variable Rams. Once the changeout is complete, ND BOP Stack and PU Stack to remove SS Bands and Ring from Hanger. Unable to set test plug with all that metal in the Stack. Recovered the die that had fallen out along with 6 and 1/2 stainless steel bands. That makes a total of 63 stainless steel control line bands recovered. 05:00 - 06:00 1.00 BOPSU DECOMP NU BOP Stack. Take on 10.4 ppg brine into pits and round-tripped truck for another full load. 06:00 - 07:00 1.00 FISH DECOMP PJSM. Clear and clean Rig Floor. Change out elevators and all handling equipment from 7" to 3 1/2". 07:00 - 08:30 1.50 BOPSU DECOMP PJSM. Set test plug, test 3 1/2" pipe rams to 250 / 4000 psi, OK. Test choke line, OK. Pull test plug. 08:30 - 09:30 1.00 FISH P DECOMP Rig down 7" equipment, rig up to run DP. 09:30 - 11 :30 2.00 FISH P DECOMP PJSM. M/U BHA to rotate out K Anchor, including type "B" spear, bumper sub, oil jars, (9) 6 1/4" drill collars, & pump out sub. 11 :30 - 14:00 2.50 FISH P DECOMP PJSM. RIH w/ K Anchor fishing BHA on 3 1/2" DP, picking up DP 1 x 1. 14:00 - 14:30 0.50 FISH P DECOMP PJSM. Diesel flowing over on DP. Make up headpin @ circulate (1) DP volume of 10.4 ppg brine. 14:30 - 20:00 5.50 FISH P DECOMP Continue picking up 3 1/2" DP 1 x 1. 20:00 - 20:30 0.50 FISH P . DECOMP In with 270 jts of 3.5" DP. PU and MU Kelly one joint of DP shy of Fish. UW = 139K, DW = 112K. Break circulation to ensure Printed: 518/2006 11 :55:43 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/5/2006 20:00 - 20:30 0.50 FISH P DECOMP BHA not plugged off with scale. Bring pump online at 3 bpm / 520 psi. Rotate string to obtain rotational weight = 124K with 150 Amps (3500 ft-Ib of torque). 20:30 - 00:00 3.50 FISH P DECOMP Begin to displace well with 10.4 ppg brine. Wash down with Kelly to 35' of Kelly in the hole. No problems RIH and no change in weight noticed. 35' Kelly in the hole puts us at 8884'. Fish should be at 8896' +/-. Increase pump rate to 5 bpm / 1270 psi to fully displace well to 10.4 ppg. Total hole volume is 650 bbls with DP displacement at 50 bbls. 4/6/2006 00:00 - 01 :00 1.00 FISH P DECOMP Continue displacing well to 10.4 ppg brine. At 01 :00 hours started getting 10.4 ppg returns. Pumped a total of 640 bbls. Down on the pump. 01 :00 - 04:00 3.00 FISH P DECOMP PU and MU pup joint of 3.5" DP. Length of pup = 23.85'. PU and MU Kelly. Bring on the pump at 2.75 bpm /460 psi. UW = 137K , DW = 11 OK , RW = 121 K with 150 Amps (3500 ft-Ib of torque). Stop rotation and begin RIH with Kelly. Stack 10K on top of fish at 20' Kelly = 8893'. Rotate into fish and stack out at 25' Kelly in (8898'). Bring on rotation to rotate out K-anchor. Torque worked up to 300 Amps (10,000 ft-Ib of torque). Begin to work and jar fish. PU to 175K and give it 10 jar licks. Attempt to rotate out and torque worked up to 300 Amps again. PU to 200K and give it 10 jar licks. Attempt to rotate K-anchor out again. Worked torque up to 330 Amps (11,000 ft-Ib). No Joy. 04:00 - 05:00 1.00 FISH P DECOMP Turn to left and release Spear. Took some work to get Spear to release. Stop circulation. Blow down lines. Set back Kelly. Decision made to wash over PBR assembly down to or through the Packer. 05:00 - 09:30 4.50 FISH P DECOMP PJSM. POOH w/3 1/2" DP & B spear assembly. 09:30 - 10:30 1.00 FISH P DECOMP PJSM. Stand back collars & UD spear, spear looked very good. 10:30 - 12:30 2.00 FISH P DECOMP PJSM. Pick up shoe, (3) jts washpipe, washover basket, bumper sub, oil jars & (9) 6 1/4" DCs. 12:30 - 19:00 6.50 FISH P DECOMP PJSM. RIH w/ milling / cleanout BHA on 3 1/2" DP. Fluid running over, stop & circulate weighted pill w/10 stands in the hole & again w/ 40 stands, not much improvement. Continue in at a speed that minimizes fluid running over. Total of 268 joints of DP in the hole. 19:00 - 20:30 1.50 FISH P DECOMP PU and MU Kelly. Bring on the pump at a rate of 5 bpm /1400 psi. UW = 140K, DW = 11 OK. Rotate string to obtain rotational parameters, RW = 123K and Torque at 150 Amps (3500 ft-Ib). Begin to wash down with Kelly to 35' of Kelly in. No real weight bobbles noticed indicating no fill. PU and MU joint 269 of DP. Proceed to wash down with Kelly. In 35' with the Kelly with no problems - again no fill noticed. PU and MU joint 270 of DP. Wash down with Kelly and tag top of Packer with 21' Kelly in the hole = 8960'. 20:30 - 00:00 3.50 FISH P DECOMP Bring on rotation and begin to mill/ burn through the Packer from 8960'. Rotating at about 75 RPM with torque values of about 210-240 Amps (6000-7000 ft-Ib). Pumping down the drillstring at 3 bpm / 500 psi. Slowly continue to burn through Packer. 4/7/2006 00:00 - 04:00 4.00 FISH P DECOMP Continue to mill/ burn through Packer at 8960'. At 02:00 hours had made about 2' of hole. Continue to slowly work mule shoe Printed: 5/8/2006 11 :55:43 AM · e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/7/2006 00:00 - 04:00 4.00 FISH P DECOMP down. At 03:00 hours, pumped a 20 bbl high-vis sweep. 04:00 - 04:30 0.50 FISH P DECOMP Lost returns so appears that Fish is about to go. Increase pump rate to 5 bpm and got returns again. Work Kelly completely down to 35' Kelly in = 8974'. Fish is not falling and had to rotate BHA to push Fish down. No need to push to bottom for subsequent Spear run. Total fluid loss at 50 bbls and continuing to drink. Order out a load of 80 degree seawater to fill hole. 04:30 - 05:00 0.50 FISH P DECOMP Stand back Kelly and begin to TOH with 3.5" DP. Stand back DP for subsequent fishing run. Pump in double displacement with 10.4 ppg brine. Got 9 stands out. 05:00 - 07:30 2.50 FISH P DECOMP Stop and begin to circulate a bottoms-up to ensure any gas below packer is circulated out. Monitor and keep track of losses into formation. W/125 bbls pumped, see gas percolating up in returns. Shut down & close annular preventor. SICP = 50 psi, SIDP = 90 psi. Circulate through gas buster @ 4 bpm, 750 psi. Complete the bottoms up. Monitor well, well is dead w/ fluid level dropping. 07:30 - 10:30 3.00 FISH P DECOMP PJSM. POOH w/3 1/2" Dp & wash pipe / packer millng BHA, double displacing w/10.4 ppg brine. 10:30 - 12:30 2.00 FISH P DECOMP PJSM. UD washpipe & shoe. M/U BHA #4 as follows: spear, extension, stop sub, bumper sub, jars, (9) 6 1/4" DCs & pump out sub. 12:30 - 17:30 5.00 FISH P DECOMP RIH w/ spear assembly (BHA #4) on 31/2" DP. 271 jts 17:30 - 19:00 1.50 FISH P DECOMP PJSM. Pick up kelly. Up wt - 147K, down wt - 11 OK. Bring on pump @ 2 bpm, hole not full & DP not full. Kelly down without finding tubing stub. Depth w/ kelly down - 8913'. Make a connection & run that kelly down as well to 8945' without finding fish. Must have dropped down hole. Stand back Kelly and continue to single in with joints of DP from the Pipe Shed. Tagged Fish with joint # 274 and stacked 10K. PU and the Fish fell again. Continue to single in. Tagged Fish with 7.5' in on joint # 279 = 9105'. Latch Fish and try to PU. Fish not moving. PU 50K over and jar one time. Fish came loose. Work Fish up and down and noticeing some drag. 19:00 - 20:30 1.50 FISH P DECOMP PJSM. Begin to TOH with BHA #4 on 3.5" DP while standing back DP in the Derrick. No returns from circulations. Pumping in double displacement as TOH. 20:30-21:15 0.75 FISH P DECOMP Stop TOH and line up to pump down the backside into the 9 5/8" with 10.4 ppg brine to find out how much the well has drank. Discuss with Anchorage Engineering and if well is definitely drinking substantially, order out 9.8 ppg brine to keep hole full. It took 36 bbls to fill the hole. Wait 15 mins and the fluid falls below the Stack into the Casing and re-fil with 5.5 bbls. No need to swap well over to different weight of fluid. 21 :15 - 23:30 2.25 FISH P DECOMP Continue TOH with BHA #4 on 3.5" DP. Double displace with 10.4 ppg brine as coming out of the hole. At 21 :30, notified of water spill at the Rig. Reported the discharge but since it is fresh water, it is not considered a spill. We were taking on rig water and employee left his watch position to perform another task. Water began to overflow out onto the pad. Approximate amount of water on the pad was 1 bbl. Immediately shut down transfer and spread nut plug over affected area. Held safety Printed: 5/812006 11 :55:43 AM · It Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/7/2006 21:15 - 23:30 2.25 FISH P DECOMP discussion with employee and tourpusher as to causes, what should have been done, and what we will do to ensure prevention of such incident. 23:30 - 00:00 0.50 FISH P DECOMP On surface with BHA #4. Stood back a total of 93 stands of 3.5" DP and 3 stands of 6 3/8" DCs. Begin to break apart Fish components. We recovered everything from the 5.5" Tubing Stump down to the K-anchor. Totallenght of Fish recovered = 67.30'. Total length of Fish left in the hole is 140' down to the WLEG. Sheared off of Packer and had a 6" ring of metal around the K-anchor. Suspect this is why we were able to rotate after a while without rotating out the K-anchor on the previous run and reason for not retrieving complete Fish down to the WLEG. 4/8/2006 00:00 - 01 :00 1.00 FISH P DECOMP Finish laying down Fish components. PU Spear and release from 5.5" Tubing Stump. Lay down Tubing Stump. Re-dress Spear with a new Grapple to Fish out the rest of the completion. Make up BHA #5 the same as BHA #4. 01 :00 - 01 :30 0.50 FISH P DECOMP Fill up hole with 10.4 ppg brine to see how much it has drank. 71 bbls were needed to fill the hole. Observed the fluid level drop in the Well through the BOP Stack. It took 4 minutes to fall and the Stack volume is approximately 3 bbls. This would equate to approximately 45 bbl/ hr drink rate. Decision made to order out a full load (290 bbls) of 9.8 brine to keep Well full. 01 :30 - 03:00 1.50 FISH P DECOMP Clear and clean Rig Floor and Equipment. Thorough PJSM held prior to TIH. 03:00 - 06:00 3.00 FISH P DECOMP TIH with BHA #5 on 3.5" DP from Derrick. 06:00 - 09:00 3.00 FISH P DECOMP PJSM. Hang off blocks & slip & cut 84' of drilling line, inspect remaining line & opt to slip & cut another 84'. 09:00 - 10:00 1.00 FISH P DECOMP Continue in hole w/3 1/2" DP, 93 stands & (1) single ....280 jts total. Spear is now @ 9161'. 11 :30 - 13:00 1.50 FISH P DECOMP Opt to displace well to 9.8 ppg brine due to extreme loss rate w/10.4 ppg. Line up & circulate @ 5 bpm /1200 psi. Pumped 150 bbls ... pumped 25 bbls before hitting fluid in DP ... continue pumping 9.8 ppg brine, 150 bbls .... no returns. Slow rate down to 3 bpm @ 450 psi & pump another 50 bbls ... still no returns. Opt to go to seawater. 13:00 - 15:00 2.00 FISH P DECOMP Trucks are hard to come by, round up a couple more & get seawater coming this way. 15:00 - 15:30 0.50 FISH P DECOMP PJSM. Line up to circulate remaining 9.8 ppg brine. Break circulation .... pump a few bbls & see returns ...return rate quickly increasing with gas in returns.. .shut well in. SICP 180 psi, SIDP O. 15:30 - 17:30 2.00 FISH N FLUD DECOMP PJSM. Line up & bullhead remaining 80 bbls of 9.8 ppg brine @ 4 bpm / 450 psi. Line up on seawater & pump @ 5 bpm / 950 psi, taking returns, (gas & fluid), thru choke to tiger tank. Pump 144 bbls & shut down. Pumped @ 4 - 5 bpm with pump pressure increasing to as much as 1150 psi, casing pressure to 800 psi. Shut down & monitor ... bleed off casing in increments watching dp pressure decrease & shutting choke back in to see if dp pressure builds. Able to bleed casing until dp bleeds to 10 psi. Shut in well & monitor. After 45 minutes, SIDP = 8 psi. Notified Team Leader Steve Rossberg and AOGCC State Rep Lou Grimaldi. Printed: 5/8/2006 11 :55:43 AM · - Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/8/2006 17:30 - 18:30 1.00 FISH N FLUD DECOMP PJSM. Line up & bring on pump, pumping down dp @ 4 bpm / 800 psi, with 770 psi on casing. Keep 4 bpm / 800 psi & take returns, (gas), thru choke top tiger tank. Observe casing pressure gradually drop to zero & finally lose returns entirely with choke fully open. Suspect influx was caused by significant amount of air in DP that was displaced into backside lightening the fluid column enough to allow an influx. 18:30 - 21 :00 2.50 FISH P DECOMP PJSM. Blow down Kelly and lines. Monitor well dead. No fluid level noticeable on either the backside or the DP. Well is dead. Decision made to load the well completely with seawater. DP already filled with seawater from previous pumping. Line up to bullhead down the backside with seawater. Begin pumping at 4.5 bpm /140 psi. Pumped a total of 568 bbls of seawater down the backside. Maximum pressure seen was 1500 psi at 5 bpm. Monitor well dead. Backside is on a vacuum. Open up the bag and no fluid level seen in the backside. 21 :00 - 21 :30 0.50 FISH P DECOMP Begin TIH with BHA #5 with the Kelly to latch Fish. Total of 280 joints of 3.5" DP in the hole. BHA length = 303.90'. UW = 145K , DW = 115K. Begin pumping down the DP to wash down with Spear to the Fish. Pumping at 3 bpm / 350 psi. Stack 20K on top of Fish with 13' Kelly in the Hole = 9174' (Top of Fish at 9172'). Pump pressure up to 450 psi. PU to neutral weight and drop back down to ensure Fish is latched - Good. PU to 200K and jar Fish. Weight dropped to 195K. Re-jar Fish with 225K. Weight dropped to 195K again. Jar two more times at 250K and Fish came loose. Weight dropped to 125K. PU and shut down pump. 21 :30 - 00:00 2.50 FISH P DECOMP PJSM. Stand back Kelly and blow down lines. Lay down one single joint of 3.5" DP. Begin TOH with BHA #5 on 3.5" DP while standing back DP in Derrick. Double displace with seawater down the backside as TOH. Take on (2) loads of seawater to ensure all pits full. 4/9/2006 00:00 - 06:00 6.00 FISH N HMAN DECOMP 26 stands of 3.5" DP out of the hole. Took a 22 bbl influx into pits. Shut the annular and secure the well. SlOP = 160 psi, SICP = 170 psi. MU Headpin on DP and line up to circulate out kick through Gas Buster. SIDP = 60 psi and SICP = 260 psi when started circulating. Hold backpressure while circulating out kick. Notifications made to Anchorage Engineering and AOGCC. Bullhead 110 bbls down the DP with seawater at 6 bpm / 2200 psi max. Resume circulation of kick down the DP and up the annulus. Getting gas-cut returns with 900 psi on the casing. Maintain 1250 psi on the DP. Work casing pressure down to 20 psi and getting constant fluid (8.5 ppg) returns. Shut in and monitor well. Zero pressure on the DP and casing. 06:00 - 07:00 1.00 FISH P DECOMP PJSM. Open annular preventor, monitor well, well is on a drink. Bring on charge pump, pumping down killlline, well is staying full but taking 5 - 7 bbls every 5 minutes. Prepare to POOH w/ packer & packer fishing BHA on 3 1/2" DP. 07:00 - 08:00 1.00 FISH P DECOMP PJSM. POOH w/3 1/2" DP, with hole fill constant. Loss rate = 50 -70 bph. W/45 stands total out, stop & pump down DP to determine fluid level in DP. Pumped 1 1/2 bbls & caught fluid, (225'). Continue to POOH. Well is taking 11 -14 bbls every 5 stands. Should be taking 2.1 bbls. Printed: 5/8/2006 11 :55:43 AM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/9/2006 08:00 - 09:00 1.00 FISH P DECOMP Continue to POOH w/3 1/2" DP. W/26 stands left in hole & spear @ 2777', observed flow up DP & made up headpin, no flow up backside ... still taking fluid. Suspect gas trapped in 4 1/2" tailpipe below plug ...(approximately (1) bbl in volume), is expanding and finding the easiest way to surface. 09:00 - 10:30 1.50 FISH P DECOMP PJSM. Circulate seawater down the DP, taking returns thru the choke to the gas buster and back to the pits. .. maintaining constant bottom hole pressure. Circulate approximately 1 1/2 times around seeing fluid losses while pumping averaging 5 -10 bbls every 5 minutes. Observe gas back & eventually turning to fluid. Monitor well, casing & DP both on a vacuum. Open annular and unable to see fluid. Pump to fill hole & observe fluid in DP staying even with level of fluid in flow nipple. 10:30 - 13:30 3.00 FISH P DECOMP Continue to POOH w/ constant hole fill. Packer hung up @ 2490' DPM. (FO in 9 5/8") Pulled 50K over up wt, no good, pulled 75K over up wt, still no good. Slacked off to bring stand down & ran down till (1) full jt sticking up, broke off & laid down, then pulled 2nd jt, broke off & laid down, then installed floor valve & picked up to work packer, pulled thru OK w/ no overpull. Continue OOH. W/ (2) stands left in hole, circulate to make sure no gas. Circulate (2) btms up from 500' (+ -). Some gas back. Shut down & monitor w/ well open, champagne bubbles up back side, well on vacuum both sides. Pull (1) more stand & observe medium flow w/ gas up back side. Shut in well. 13:30 - 17:30 4.00 FISH P DECOMP PJSM. SIDP = 80 psi, SICP = 210 psi. Bring on pump @ 5 bpm / 575 psi & open choke, maintaining 575 psi, circulate 3 - 4 bottoms up taking gas cut returns thru gas buster to pits. Shut in & monitor f/10 minutes. SIDP = 100 psi, SICP = 160 psi. Repeat process many times over the next few hours, watching SIDP, after 10 minute shut in and monitor period, gradually drop to 0 psi @ 17:00 hrs & SICP to 30 psi, both pressures recorded after 10 minute shut in. While doing this, line up Little Red & fill tiger tank w/ sea water, also line up 290 bbls of 9.6 ppg 100 (+) LSRV used Flo Pro from MI. Losses of 5 - 15 bbls every 5 minutes observed during the pumping time of the above described operation. Notified AOGCC State Rep John Crisp of BOPE test due tomorrow & updated him on well situation. Recieved permission to not test until bridge plug is set above 7" liner top. Consulted Steve Rossberg & Dave Reem regarding plan forward. 17:30 - 20:30 3.00 FISH P DECOMP PJSM. Line up & go on constant hole fill down DP @ 1 bpm while rigging up Little Red on itA. Top off pits 2 and 3 with seawater leaving pit 1 empty for Flo-Pro. Re-Ioad vac truck with seawater from Tiger Tank and have him RU to Little Red Services. Wait on load of Flo-Pro. Flo-pro on location at 20:00 hours. Finish filling up vac truck with seawater from Tiger Tank and RU to Little Red. Move in vac truck of Flo-Pro to start offloading into Pit 1. Little Red pressure test lines to 3500 psi. 20:30 - 21 :00 0.50 FISH P DECOMP PJSM with all parties involved: Nabors, Little Red Hot Oil Services, Veco and Peak. Pumping procedure discussed as well as importance of safety during operations. Printed: 5/812006 11 :55:43 AM -- e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/9/2006 21 :00 - 22:00 1.00 FISH P DECOMP Line up to bullhead down the DP with the rig pump. Close Variable Pipe Rams and Annular Preventor around Drill Pipe. Begin bull heading 290 bbls of 9.6 ppg 100 (+) LSRV Flo Pro. Bring pump on at 5 bpm / 580 psi. Increase rate to 5.5 bpm / 920 psi. Increase one more time to 6 bpm /1450 psi. While pumping the IA was at 900 psi and the OA was at 0 psi. Pump pressure decreased to 1300 psi with all the Flo-Pro in the Well. 22:00 - 23:00 1.00 FISH P DECOMP Immediately after all 290 bbls of Flo-Pro in the well, begin displacing the Flo-Pro down the DP and IA with seawater. Lined up with the Rig Pump down the DP and Little Red Services down the IA. Work Little Red up to 5 bpm and Rig Pump to 5 bpm for a combined rate of 10 bpm. Rig pump pressure = 1400 psi, Little Red pump pressure = 1050 psi, IA pressure = 1100 psi, OA pressure = 0 psi. At 22:30 hours leading edge of Flo-Pro at the top perfs. Rig pump pressure = 1550 psi, Little Red pump pressure = 1250 psi. Continue bull heading seawater at 10 bpm combined. Pumped a total of 600 bbls of seawater to spot 190 bbls of Flo-Pro into the formation and 100 bbls of Flo-Pro at the bottom of the Well. 23:00 - 23:30 0.50 FISH P DECOMP Shut down both Little Red and Rig Pump. Pressure in IA dropped off to 400 psi and DP to 800 psi. Wait until all pressure back to zero. Monitor well dead - good. Open Pipe Rams first and then Annular Preventor. Circulate with seawater down the DP and up the IA and notice gas bubbling through fluid column. Circulate until no gas in returns (5 minutes). Monitor drink rate = 21 bbls / hour. Flo-Pro has slowed down the drink rate from yesterday. 23:30 - 00:00 0.50 FISH P DECOMP Go on constant hole fill with the Charge Pump. Begin TOH 1 stand of DP, 3 stands of DCs and BHA #5. Keep Little Red and Peak truck on standby to ensure well is dead and we are TIH again. 4/10/2006 00:00 - 02:00 2.00 FISH P DECOMP On surface with BHA #5 and the Fish. Well is still full of seawater. Maintain constant hole fill. Begin breaking apart and laying down Fish components. The Packer body on the outside is scored from what appears to be drag due to junk in the Well. Punch holes in 4.5" Tubing joints to drain fluid above the Plug in the X nipple. Also punch hole in joint below plug and bled off trapped gas. 02:00 - 03:00 1.00 FISH P DECOMP WLEG on surface. Cover hole and keep constant hole fill going. Clear and clean Rig Floor due to lots of mud and fluid everywhere from the Fish. 03:00 - 04:00 1.00 CLEAN P DECOMP Begin PU and MU BHA # 6 as follows: Mule Shoe, Double Pin Sub, Casing Scraper, Bit Sub, Bumper Sub, Oil Jar, XO, (9) DC's and XO. Once BHA made up open up Pipe Rams and monitor drink rate = 12 bbls / hour. 04:00 - 06:00 2.00 CLEAN P DECOMP Begin TIH with BHA #6 on 3.5" DP from Derrick. Maintain constant hole fill as TIH with Charge Pump. Order out Salt Pill and viscosified brine from MI. 06:00 - 07:00 1.00 CLEAN P DECOMP Service rig & crew change out. 07:00 - 09:30 2.50 CLEAN P DECOMP Continue in hole w/3 1/2" DP. Encounter some obstacle, probably packer remnants, @ 8805'. Work thru, OK. Run on in w/93 stands & (1) single, (280) jts total. Printed: 5/8/2006 11 :55:43 AM -- e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/10/2006 09:30 - 10:30 1.00 CLEAN P DECOMP PJSM. P/U kelly & establish parameters. 140K up wt, 118K down. Rotate on down to liner top & tag w/ scraper. 22' in on kelly. Liner top @ 9181' DPM. Stand back kelly. UD (3) jts DP. Mule shoe now at 9065' DPM. 10:30 - 11 :00 0.50 LCR P DECOMP Pre job safety meeting w/ regard to pumping & spotting / squeezing pill. Take on 100 blls 10 ppg viscosified NaCI brine. Hook up vacuum truck w/100 bbls sized salt pill to feed to charge pump & on to rig pump. 11 :00 - 13:00 2.00 LCR P DECOMP Line up & pump 50 bbls 10 ppg viscosified brine down DP @ 4 bpm, 270 psi ICP. W/30 bbls away, shut in well, continuing to pump, (bullhead) into formation. W/50 bbls away, follow with 100 bbls sized salt pill. Bullheading @ 4bpm /480 psi. W/20 bbls sized salt pill away, pumping 4 bpm @ 570 psi. W/60 bbls sized salt pill pumped, pumping, (bullheading), @ 4 bpm / 1190 psi. I/A pressure @ 550 psi. 70 bbls away, sized salt pill is now entering top of 7" liner. With 100 bbls sized salt pill away, bullheading @ 4 bpm /1300 psi, itA @ 550 psi. Switch back to 10 ppg viscosified brine chaser. Continue bullheading sized salt pill @ 4 bpm / watching pressure climb steadily to 1550 psi @ 4 bpm. This is with 30 bbls of chaser pumped. Pump another 20 bbls & observe pressure begin to break over & back to 1430 psi. Shut down & observe DP pressure slowly drop to 210 psi in 10 minutes, itA now @ 800 psi. Sized salt pill is now squeezing into perfs. Bring on pump @ 213 bpm & squeeze away 6 bbls, observing DP pressure climb to 750 psi, itA @ 950 psi. Shut down for 10 minutes & observe pressure on DP dropped & stabilized @ 350 psi, itA @ 950 psi. 50 bbls chaser away, go to seawater. Bring on pump @ 213 bpm & squeeze away another 7 1/2 bbls, observing squeeze DP pressure climb steadily to 850 psi, itA to 1100 psi. Shut down for 10 minutes, DP pressure bled to 550 psi, itA to 1050 psi. Squeeze away another 4 1/2 bbls @ 213 bpm, watching DP pressure steadily climb to 910 psi, itA to 1175 psi. Shut down for 10 minutes & observe DP drop & stabilize @ 580 psi, itA @ 1100 psi. Squeeze 3 more bbls @ 213 bpm, watching DP steadily climb to 1320 psi, I/A to 1550. Shut down. itA bled to 1220 psi in 10 minutes & DP to 750 psi. Close surface valve on DP & bleed pressure off of circulating hose & break off same Line up itA on choke & slowly bleed to 0 psi. Open surface valve, DP is on a strong vacuum. 13:00 - 14:00 1.00 LCR P DECOMP PJSM. POOH slowly & UD (20) jts of DP. W/8 jts out, fill DP w/ sea water w/ hose & observe returns. Estimate top of sized salt pill is @ 9150' (+ -) & top of viscosified brine chaser is @ 8500' (+-) 14:00 - 19:00 5.00 CLEAN P DECOMP POOH & stand back remaining DP. Well taking proper amount of fluid. 19:00 - 19:30 0.50 CLEAN P DECOMP BHA #5 on surface. Inspect Spear and one big notch of metal is gauged out from junk in the well. Break down BHA components and lay down in Pipe Shed. MU 9 5/8" RBP and running tools as per Halliburton Rep. 19:30 - 00:00 4.50 DHB P DECOMP Begin TIH with 9 5/8" RBP on 3.5" DP. PU (2) single joints of DP from Pipe Shed and continue with 255 joints of DP from Derrick. PU 23 single joints of DP from Pipe Shed and a 23.85' Printed: 5/8/2006 11 :55:43 AM -- e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/10/2006 19:30 - 00:00 4.50 DHB P DECOMP pup joint. Monitor well as TIH and stil taking some fluid but not much, slowed down almost completely. 4/11/2006 00:00 - 01 :30 1.50 DHB P DECOMP Continue TIH with 9 5/8" RBP. Junk at 8805' not seen with this run. Continue on down to set depth. Total of 280 joints of DP along with a 23.85' pup in the hole. Length of running tools and plug = 18.31'. Bottom of toolstring at 8899'. PJSM with all personnel to discuss setting procedure and testing procedure. Establish parameters: UW = 117K, DW = 102K. Set 9 5/8" RBP @ 8893' (middle of rubber element). Top of Fish Neck @ 8886'. Had to work to release. Lay down (1) joint of DP to attempt to re-set to prove Plug is already set - good. 01 :30 - 02:00 0.50 DHB P DECOMP PJSM. TOH with 15 joints of 3.5 DP standing back in the Derrick. MU Headpin. Line up to PT RBP down the DP. Close Pipe Rams and bring on pump at 2 bpm. Pressure up to 4000 psi and shut down pump. Pressure stabilized at 3850 psi. After 15 minutes, pressure was 3830 psi. Good test. Bleed all pressure off. 02:00 - 03:00 1.00 DHB P DECOMP Clear and clean Rig Floor. 03:00 - 04:30 1.50 DHB P DECOMP PJSM. CBU from 8362' to ensure all seawater for upcoming US IT log. Monitor weight of returns to ensure getting seawater. Pumped a total of 525 bbls of seawater and all returns seawater. 04:30 - 05:30 1.00 DHB P DECOMP TIH with 15 joints from Derrick and PU a single from Pipe Shed. Line up to reverse circulate to sweep out fluid from just above the Plug to seawater for upcoming US IT log. Monitor weight of returns to ensure getting seawater. Pumped a total of 80 bbls of seawater. Had some returns of 9.1 ppg besides seawater but mostly seawater. 05:30 - 09:00 3.50 DHB P DECOMP PJSM. Begin TOH with Halliburton running tools and 3.5" DP while standing back DP in Derrick. 09:00 - 10:00 1.00 DHB P DECOMP PJSM. UD Hallliburton bridge plug. Clear clean rig floor. 10:00 - 11 :00 1.00 DHB P DECOMP PJSM. Close blind / shear rams & test 9 4/8" casing from surface to rubbers on bridge plug @ 8893', @ 4000 psi f/30 minutes, charted. Good test, (flat lined). No indication of pressure increase on O/A. Bleed all pressure. 11 :00 - 12:00 1.00 BOPSU P DECOMP PJSM. Drain BOP Stack. Set test plug & RU test equipment. 12:00 - 16:30 4.50 BOPSU P DECOMP Test BOPE per BP / AOGCC requirements. State's right to witness the test was waived by John Crisp. Test to low pressure of 250 psi and high pressure of 4000 psi. Good test. 16:30 - 17:00 0.50 BOPSU P DECOMP Rig down Test Equipment. Pull Test Plug and ND Flow Nipple. 17:00 - 18:00 1.00 EVAL P DECOMP NU Shooting Flange in preparation for US IT log. Pre-tour meeting with night crew, tourpusher and company man. Change out crews. 18:00 - 18:30 0.50 EVAL P DECOMP PJSM with Schlumburger E-line and Nabors personnel. Discuss RU of E-line and running of USIT. 18:30 - 21:00 2.50 EVAL P DECOMP RU Schlumburger E-line to Shooting Flange. PU logging tools and lubricator through Beaver Slide to Rig Floor. Pressure test lubricator to 500 psi to ensure no leaks. Change out one O-Ring that failed during pressure test. Pressure test again to 500 psi - good test. 21 :00 - 00:00 3.00 EVAL P DECOMP RIH with USIT logging tool with Schlumburger E-line. Reached 8850' at 22:05 hours. Begin logging main pass up to surface at 50 feet per minute. US IT being logged in corrosion mode. Log Printed: 5/812006 11 :55:43 AM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/11/2006 21 :00 - 00:00 3.00 EVAL P DECOMP repeat pass over cemented interval. 4/1212006 00:00 - 03:00 3.00 EVAL P DECOMP Continue running USIT with Schlumburger E-line in corrosion mode. At 01 :00 hours finished main pass. Log repeat over TOC and anomaly. TOC determined to be at 2350' which is at the top FO. Log indicates no corrosion issues. Log does indicate possible change in pipe densities in the 95/8". Anomaly noted at 5220' - possible junk in the well or decentralized pipe. 03:00 - 03:30 0.50 EVAL P DECOMP RD Schlumburger E-line. 03:30 - 04:00 0.50 DHB P DECOMP PJSM with Halliburton and Nabors. 04:00 - 05:30 1.50 DHB P DECOMP ND Shooting Flange and NU Flow Nipple. Prepare to run 95/8" RBP. 05:30 - 08:00 2.50 DHB P DECOMP TIH with Halco 9 5/8" RBP, Running Tool, and 3 1/2" Drill Pipe (126 jts). PUW = 63K. SOW = 63K. 08:00 - 09:00 1.00 DHB P DECOMP Circulate 15 bbls of Sea Water at 2.0 bpm around RBP. Set RBP with center element at 3,999'. Top of fishing neck is at 3,992'. Pull 1 Stand of Drill Pipe. Test RPB at 2,000 psi x 5 minutes. (Took 2.35 bbls) 09:00 - 10:30 1.50 DHB P DECOMP Dump 1,500 Ibs (30 sks) 20/40 mesh sand down Drill Pipe. Flush Drill Pipe with 26 bbls of Sea Water at 1.0 bpm. Tag TOS at 3,959'. 10:30 - 11 :00 0.50 CASE P DECOMP Stand-back 16 stands of Drill Pipe and park Running Tool at -2,475'. 11 :00 - 14:00 3.00 CASE P DECOMP Circulate 4 volumes (-760 bbls total) of hot Sea Water at 5 bpm from 2,475' to pre-warm up Well bore for Arctic Pack recovery. Final temp in 88 degs F. Final temp recovered 80 degs F. 14:00 - 16:00 2.00 CASE P DECOMP Cut and slip Drilling Line. 16:00 - 17:30 1.50 CASE P DECOMP Continue TOH with 3.5" DP. Lay down RBP running tools. 17:30 - 18:00 0.50 CASE P DECOMP PU and MU BHA # 7 as follows: Multi-String Cutter with 3 1/2" Knives (11.0" Sweep), XO, Stabilzer and XO. OAL = 9.23' 18:00 - 19:30 1.50 CASE P DECOMP TIH with BHA # 7 on 3.5" DP on 23 stands from the Derrick. 19:30 - 21 :30 2.00 CASE P DECOMP On bottom with 69 joints of 3.5" DP. PU a single joint and a 24' pup from the Pipe Shed. MU Headpin. Bring on pump at rate of 1 bpm 170 psi. Wash down to find collar - no joy. PU to the single joint and try locating with it. Bring on pump at rate of 1.7 bpm 1120 psi. Locate collar at 2217'. RD Headpin and PU 9.95' pup joint. MU Headpin. Bring on pump at rate of 2.2 bpm I 200 psi. Locate collar at 2259'. That means it is a 42' long joint of casing which corresponds to third full joint above TOC. Cut depth will be 2235' which is 18' from top collar and 24' from bottom collar. RD Headpin and lay down both pup joints. MU Kelly. UW = 40K, DW = 40K. RIH to 8' Kelly in. Bring on rotation at 80 RPM. RW = 45K. Bring pump on at rate of 4 bpm 1650 psi with a torque of 110 Amps (2000 ft-Ib). Cutting stalled out twice, acting really weird and rough with Amps spiking up to 300 (10,000 ft-Ib). After 40 minutes of cutting, the torque is back to original value of 110 Amps. Weight indicator on Pipe is showing decrease in weight. Torque decreased to 90 Amps. Good indications of cut. 21 :30 - 22:00 0.50 CASE P DECOMP Attempt to circulate through cut into 13 3/8" x 9 5/8" Annulus with the Pipe Rams closed. Open up the OA to the Tiger Tank. Bring on pump at rate of 1.6 bpm 11150 psi. Pressure dropped off to 1050 psi and getting returns in Tiger Tank. Leave Plinted: 5/8/2006 11 :55:43 AM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/1212006 21 :30 - 22:00 0.50 CASE P DECOMP circulating and pressure dropped to 120 psi. 22:00 - 22:30 0.50 CASE P DECOMP PJSM with Nabors and Little Red Services. Discuss pumping procedure to flush out Arctic Pack from OA. Discuss RU of Little Red to Test Spool to assist with pumping hot diesel. 22:30 - 00:00 1.50 CASE P DECOMP Line up to pump down the backside of the DP in the 95/8". Line up with the OA to the Tiger Tank to receive returns from OA. Begin pumping hot seawater (120 degree) down the OA at a rate of 2 bpm 1100 psi. Pressure at one point slowly increased to 500 psi and then fell back off to 120 psi. Pump 150 bbls of seawater. Next pump a 40 bbl Safe Surf-O Pill down the 9 5/8". Next have Little Red pump 100 bbls of hot (190 degree) diesel down the 9 5/8". 4/13/2006 00:00 - 01 :30 1.50 CASE P DECOMP Continue circulating down the 9 5/8" into the 133/8" to clean out Arctic Pack. Spot the diesel in the OA by pumping 140 bbls of hot seawater behind it. Pump the seawater at a rate of 5 bpm I 520 psi. Increase to 6 bpm I 530 psi. Shut down to let the diesel soak in the OA for 45 minutes. 01:30 - 02:15 0.75 CASE P DECOMP Wait 45 minutes while the diesel is spotted in the OA to break down the Arctic Pack. 02:15 - 04:00 1.75 CASE P DECOMP Pump a second 40 bbl Pill of Safe Surf-O down the 9 5/8". Follow that up with Little Red pumping 90 bbls of hot diesel down the 9 5/8". Spot the diesel into the OA with 140 bbls of hot seawater. Pump the hot seawater at 6 bpm I 550 psi. Shut down to let the diesel soak in the OA for 45 minutes. 04:00 - 06:00 2.00 CASE P DECOMP Wait 45 minutes while the diesel is spotted in the OA to break down the Arctic Pack. Had (2) vac trucks go to Pad 3 with returns. One truck was rejected due to thickness of load. Other truck's load was all seawater which is why he was unable to unload. Have the one truck that was rejected on standby until we can try and get clearance to dispose at G&I's open pit. The other truck will try and take a 50/50 load to Pad 3 (100 bbls clean hot fresh water and 100 bbls of returns) and see if it will be accepted. Tiger Tank is full so wait until we can dispose of returns to continue circulating out diesel from OA. Current state of fluids in the well is diesel in the OA and seawater in the 9 5/8". 06:00 - 14:00 8.00 CASE P DECOMP Tiger Tank full. Clean-up "rejected" Pad 3 Vac Truck. Clean-up Remainder of Arctic Pack in Tiger Tank. Thin-out all loads with 50% 160 deg F. Fresh Water and dispose at Pad 3. 14:00 - 16:00 2.00 CASE P DECOMP Pump final 13 3/8" x 9 5/8" Annulus clean-up as follows: 10 bbls hot Sea Water and 40 bbls "extra-thick" Hi-Vis pill. Circulate pill to Tiger Tank with 325 bbls hot Sea Water at 5.0 bpm/325 psi. 16:00 - 17:00 1.00 CASE P DECOMP Trip out with 3 1/2" Drill Pipe and BHA #7. 17:00 - 18:00 1.00 CASE P DECOMP Lay down BHA # 7 assembly. Move Drill Collars to right side rack so they are out of the way. Install Test Plug. 18:00 - 20:00 2.00 BOPSU P DECOMP Change out 3 1/2" x 6" Variable Pipe Rams to 9 5/8" Pipe Rarns. Had one seal pop off that was changed out. 20:00 - 21 :00 1.00 BOPSU P DECOMP Pressure test on the BOPE Door against the 9 5/8" Pipe Rams to 250 psi low and 4000 psi high - good test. 21 :00 - 22:00 1.00 CASE P DECOMP Drain BOPE Stack. Lay down Test Plug. BOLDS. PU BHA #8 components and MU as follows: ITCO Spear with 8.681" Grapple, Spear Extension, 103/4" Stop Sub, XO. OAL = 9.99'. Printed: 5/8/2006 11 :55:43 AM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/13/2006 22:00 - 23:00 1.00 CASE P DECOMP Open up Blind Rams and pull Bushings. Plant Spear in Casing Hanger. Anticipated String Weight = 105K plus 10K extra for Blocks. PU and Fish started moving at 135K, got it completely loose at 150K. PUW as coming out of hole with Fish = 115K. Got the Hanger on surface and have a 2' pup joint underneath. Break pup joint apart, release Spear and lay down Hanger. 23:00 - 00:00 1.00 CASE P DECOMP RU to handle 9 5/8" and POOH with 9 5/8" 47# MN-80 Casing. Use thread protectors to aid in laying down the Skate. 4/14/2006 00:00 - 06:00 6.00 CASE P DECOMP Continue POOH with 95/8" 47# MN-80 Casing. Casing will be sent to Stores for disposal. All casing joints covered in Arctic Pack. Wipe down joints and wash down handling equipment as POOH. 06:00 - 11 :30 5.50 CASE P DECOMP Finish laying down 9 5/8" Casing. Recovered a total of 54 Joints and a cut-off stub 16.46'. Recovered stub cut end was jagged. Also a large piece of casing wall fell out of the joint. Evidence that the Cutter had "walked" during the cut. 11 :30 - 12:30 1.00 CASE P DECOMP Rig down handling equipment. Clear and clean Floor. 12:30 - 14:30 2.00 CASE P DECOMP Set test plug. Remove 9 518" Pipe Rams. Install 3 1/2" x 6" VBPRs. Test. Drain Stack. Remove test plug. 14:30 - 16:30 2.00 CASE P DECOMP Rig up equipment to handle Washpipe. Pick-up BHA #9 as follows: 121/8" Mill Shoe, 2 jts 11 3/4" Washpipe, Washover Boot Basket, XO, 133/8" Casing Scraper, Bit Sub, Bumper Jar, Oil Jar, XO, 9 Drill Collars, XO, Pump-out Sub. Rig down handling equipment. 16:30 - 00:00 7.50 CASE P DECOMP TIH with BHA #9 on 3.5" DP. Slowly TIH due to Arctic Pack coming up DP and not wanting to plug DP off. Stop every 5 stands to reverse circulate with hot seawater to clean out any remaining Arctic Pack. Getting Artic Pack "chunks" in returns. Discard Arctic Pack returns to Tiger Tank while catching clean seawater returns in pits. Pumping at 3 bpm 1160 psi. 4/15/2006 00:00 - 01 :30 1.50 CASE P DECOMP In with 20 stands of 3.5" DP. Break apart joint #60 and set in mouse hole. Go in until 2' above the cut @ 2235' with joint #59. MU Headpin. Line up and reverse circulate with hot seawater to clean up the remaining Arctic Pack. Bring on pump at 3 bpm I 200 psi. Getting lots of Arctic Pack back in the returns. Had to stop reverse circulation to clear returns trough of Arctic Pack. Pumped a total of 115 bbls of seawater until returns clean. Stop reverse circulation. 01 :30 - 02:30 1.00 CASE P DECOMP PJSM. Line up to circulate down the DP. MU Kelly and begin to wash down with the Kelly. Pumping at 4 bpm 1225 psi. UW = 60K, DW = 58K. Lightly tag 9 5/8" Casing Stump at 2235'. Rotate BHA through the Stump with no problems. Torque was 100 Amps (2,000 ft-Ibs). Stop rotation and continue to wash down. String is taking weight just to wash down. Decide to rotate down at 15 RPM with 120 Amps of torque (2,500 ft-Ibs). See collar with 23' of Kelly in the hole = 2258'. Continue to work pipe with rotation to wash over collar. Torque increased as high as 270 Amps (9,000 ft-Ibs). Suspect there may be some cement on top of or around the collar. Made it past the collar after about 5 minutes of working it. Wash down with Kelly completely in to depth of 2271 '. PU and stand back Kelly. PU joint #60 and MU Kelly to it. Wash down with Kelly 20' in to depth of 2287'. Encountered what appears to be cement Printed: 5/812006 11 :55:43 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/15/2006 01 :30 - 02:30 1.00 CASE P DECOMP stringers as we washed down. 02:30 - 04:00 1.50 CASE P DECOMP Circulate bottoms up at 6 bpm I 380 psi. Got a whole bunch more Arctic Pack returns. Showing some signs of cement in returns as well. Pumped a total of 400 bbls of hot seawater. Stop the pump and blow down lines. Stand back Kelly. Prepare to TOH with BHA # 9 on 3.5" DP. 04:00 - 06:00 2.00 CASE P DECOMP PJSM. TOH with BHA #9 while standing back DP. 06:00 - 07:30 1.50 CASE P DECOMP Lay down BHA #9 07:30 - 09:00 1.50 CASE P DECOMP Rig down handling equipment for Washpipe. Clean and clean Floor. 09:00 - 10:00 1.00 CASE P DECOMP Make-up BHA #10 as follows: 41/2" Bull Nose, 8 1/2" Watermellon Mill, Bumper Sub, Oil Jar, XO, Drill Collars, XO, Pump-out Sub. 10:00 - 11 :30 1.50 CASE P DECOMP Trip in with BHA #10 and # 31/2" Drill Pipe. Entered the top of the 9 5/8" Casing Stump with no problems. Repeated same with no problems. Continue down to top of Sand at 3,959'. Pick-up 15'. 11 :30 - 14:00 2.50 CASE P DECOMP Reverse circulate in with 9.8 Iblgal Brine and take Sea Water returns to the Tiger Tank. Pump rates of 1 - 4 bpm depending on the amount of Arctic Pack slugs still coming back. Total Volume pumped = 420 bbls. Final sample check = Clean 9.8 Iblgal Brine. 14:00 - 15:30 1.50 CASE P DECOMP Trip out with 3 1/2" Drill Pipe and BHA #10. 15:30 - 16:30 1.00 CASE P DECOMP Break apart and lay down BHA #10 components. Clear and clean Rig Floor. 16:30 - 18:00 1.50 CASE P DECOMP Nipple down Adapter Flange and Flow Nipple. NU Shooting Flange. 18:00 - 20:15 2.25 CASE P DECOMP PJSM with Nabors and Schlumburger E-line. RU E-line to Shooting Flange. Damaged O-Ring on 11" Otis and had to replace it. Pressure tested to 500 psi to ensure no leaks at any connection - good test. 20:15-21:00 0.75 CASE P DECOMP RIH with String Shot on E-line to collar at 2248' ELMD (Tied into USIT log). 21 :00 - 21 :30 0.50 CASE P DECOMP On bottom tie-ing in to shoot. String Shot covered interval from 2245' - 2251.7'. Collar was seen at 2248'. No problems shooting, RIH or POOH. POOH with E-line. 21 :30 - 22:00 0.50 CASE P DECOMP PJSM. Begin RD of Schlumburger E-line. Inspected tool and all shots fired. 22:00 - 23:30 1.50 CASE P DECOMP ND Shooting Flange. NU Adapter Flange and Flow Nipple. 23:30 - 00:00 0.50 CASE P DECOMP PJSM. Begin PU and MU BHA #11 as follows: Bull Nose, XO, DCs, Pin Sub, Blanking Sub, Lower Anchor Section, Backoff Power Section, Upper Anchor Section, XO, XO, Pump Out Sub. OAL = 319.78'. Distance from top of BHA to middle of Power Section = 22.66'. 4/16/2006 00:00 - 01 :00 1.00 CASE P DECOMP Continue MU BHA #11 above Drill Collars. 01 :00 - 03:30 2.50 CASE P DECOMP TIH with BHA #11 on 3.5" DP from Derrick. Stop after 6 joints of DP in and fill up down the DP with diesel to lubricate downhole tools. Continue TIH and stop every 30 joints of DP to fill up down the DP with 9.8 ppg brine. 03:30 - 05:30 2.00 CASE P DECOMP 70 joints of DP in the hole. PU and MU Kelly. UW = 65K, DW = 65K. RIH to 18' Kelly in the hole which puts the middle of the Power Section at 2258'. PJSM to discuss backoff procedure with all personnel. Bring on pump at rate of 0.5 bpm until Printed: 5/8/2006 11 :55:43 AM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/16/2006 03:30 - 05:30 2.00 CASE P DECOMP pressure up to 1500 psi. No movement. Bleed pressure off. Reverse circulate to re-set the tool to backoff. Pressure up on tool to 2700 psi and connection began to backoff - estimated torque 27,000 ft-Ib. Joint backed off 1/2 turn. Continue to backoff in 1/2 - 3/4 turn increments until backed off a total of 5 5/8 turns. 05:30 - 08:00 2.50 CASE P DECOMP Blow down lines. Stand back Kelly. Drop dart to open Pump Out Sub. Begin TOH with BHA #11 while standing back DP. After 1 stand out, pressure up to open the Pump Out Sub. TOH with BHA #11 . 08:00 - 09:00 1.00 CASE P DECOMP Lay down BHA #11. Clear and clean Floor. 09:00 - 09:30 0.50 CASE P DECOMP Pick-up BHA #12 as follows: 41/2" Bull Nose, ITCO Spear w/8.681 Grapple, Extention, Stop Sub, XO 09:30 - 10:00 0.50 CASE P DECOMP Trip in with Spear and Drill Pipe. 10:00 - 10:30 0.50 CASE P DECOMP Pick-up Kelly. Plant Spear in top of Casing at 2,234'. Complete back-off. 10:30 - 11 :00 0.50 CASE P DECOMP Set back Kelly. 11 :00 - 11 :30 0.50 CASE P DECOMP Trip out with Drill Pipe and BHA. 11 :30 - 12:00 0.50 CASE P DECOMP Lay down BHA and recovered 9 5/8" Casing Stump = 24.12'. 12:00 - 13:00 1.00 BOPSU P DECOMP Drain Stack and install Test Plug. Remove 3 1/2" x 6" VBPRs. 13:00 - 14:30 1.50 BOPSU P TIEB1 Install 95/8" Pipe Rams. Test. Drain Stack and pull Test Plug. 14:30 - 16:00 1.50 CASE P TIEB1 Rig-up 9 5/8" handling equipment. PU Shoe Track as follows: Screw-in-Sub w/Pin, HSE Baffle Plate w/Plug on seat and cemented in place, Pup Joint, HSE ES-Cementer, BTC pin x TCII XO Joint. Baker-Lok ES- Cementer. 16:00 - 23:30 7.50 CASE P TIEB1 RIH with 95/8" 47 Iblft L-80 TC-II Casing. Fill each joint with 9.8 ppg brine. Running free-floating centralizers on each joint and utlizing Jet Lube Seal Guard. Make-up torque = 17,500 ftllbs. 23:30 - 00:00 0.50 CASE P TIEB1 On bottom with 54 joints of 9 5/8" Casing. PU 29.26' pup joint. PU 4.72' pup joint. UW = 102K , DW = 100K. PU a single joint and slightly tag the 9 5/8" collar at 2259'. Screw in the new 9 518" with Torque Turn. 4/17/2006 00:00 - 00:30 0.50 CASE P TIEB1 Work pipe up and down about 10K in each direction while maintaining 11,000 ft-Ib of torque on the pipe. Once completely made up, pull test to 250K - good test. 00:30 - 01 :00 0.50 CASE P TIEB1 RD Torque Turn and lay down the single joint of 9 5/8" Casing. MU Headpin and RU test equipment. PU and hold 250K on Casing. 01 :00 - 03:30 2.50 CASE P TIEB1 Begin pressure testing 9 5/8" to 1500 psi for 30 minutes. Chart the test and monitor OA for any pressure response. Test pressure not holding but no response noted in OA. Isolate mud manifold and try maintaining test pressure - no joy. Continue to bump pressure up and getting better with each test. Blocked different valves on mud manifold and finally got a good test for 30 minutes and charted. Clear and cleaned Rig Floor while attempting to get a test. 03:30 - 05:00 1.50 BOPSU P TIEB1 PJSM. RD test equipment and Headpin. ND BOP Stack and Tubing Spool. 05:00 - 06:00 TIEB1 Set and install emergency slips on Casing head per Cameron representatives. 06:00 - 07:00 1.00 BOPSU TIEB1 NU BOP Stack. 07:00 - 07:30 0.50 CASE TIEB1 Shear open ES-Cementer at 2,300 psi to circulate Wellbore to Printed: 518/2006 11 :55:43 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/17/2006 07:00 - 07:30 0.50 CASE P TIEB1 maintain 80 deg temp while waiting on cementing equipment. 07:30 - 22:30 15.00 CASE N WAIT TIEB1 Service and maintain Rig while waiting on Cementing equipment tied up on other jobs. 22:30 - 00:00 1.50 CEMT P TIEB1 SWS Cementers on location. Begin spotting and RU Cementers. Vac trucks to be on location at 00:00. Give 1 hour call outs to MI Mudman and Halliburton rep. 4/18/2006 00:00 - 01 :00 1.00 CEMT P TIEB1 Continue spotting equipment and rigging up. RU Cementing Head and install ES-Cementer Closing Plug into Head above (2) pins ready for dropping. 01 :00 - 01 :30 0.50 CEMT P TIEB1 PJSM with all personnel to discuss pumping procedure, hazards and assign personnel to specific tasks. Those in attendance were Nabors, Shlumberger, Halliburton, MI and Veco. 01 :30 - 03:00 1.50 CEMT P TIEB1 Prepare to batch mix cement with Schlumberger and take 9.8 ppg brine to clean vac in preparation for pumping. Lab test on cement came in. At 02:00 hours, discovered a 1 bblleak from the batch mixers of freshwater and latex mixture. The cause was failure to recognize a cap was not installed. The mixture overflowed from containment in the truck and spilled out onto the pad. The spill was called in to Environmental. Had loader operator block off spill area so no traffic would come in contact with it. There are 16 gallons of latex per 1 bbl of fresh water. SRT will come out in the morning to inspect and deal with spill. Schlumberger to get more latex delivered to location to continue job. 03:00 - 04:00 1.00 CEMT P TIEB1 More latex on location. Start batch mixing again in preparation for cement job. 04:00 - 05:30 1.50 CEMT P TIEB1 Start pumping 25 bbls of 9.8 ppg brine at a rate of 6 bpm I 860 psi to warm up well and lines. Shut down pump and pressure test lines to 4500 psi - good test. Start pumping 135 bbls of 15.8 ppg class "G" cement at a rate of 6 bpm 1850 psi. Shut down the pump and drop the ES-Cementer Closing Plug. Begin pumping 9.8 ppg brine at a rate of 7 bpm I 550 psi to displace plug to ES-Cementer. With 100 bbls away, switch to taking returns to 200 bbls open top tank. At 155 bbls away, slow rate to 2 bpm 11150 psi. Bump pressure up to 2150 psi with 165.5 bbls away. Hold pressure for 5 minutes. Bleed off and got 1.5 bbls back. Looks good. Estimate 2 bbls of clean Cement returned to surface. 05:30 - 07:30 2.00 CEMT P TIEB1 Rig down and release Schlumberger Cementers. Rig-down Cement Head. Drain cut-off Joint. 07:30 - 09:00 1.50 BOPSU P TIEB1 Nipple down BOP Stack. 09:00 - 10:00 1.00 CASE P TIEB1 Install Wachs Cutter. Cut Casing per Cameron Servicehand. Lay down cut-off stub = 21.49'. 10:00 - 11 :00 1.00 WHSUR P TIEB1 Nipple down old Tubing Spool. 11 :00 - 14:30 3.50 WHSUR P TIEB1 Install 95/8" Pack-off. Nipple up new tubing Spool. 14:30 - 15:00 0.50 WHSUR P TIEB1 Pressure test Pack-off at 3,800 psi/30 minutes. Good test. 15:00 - 16:30 1.50 BOPSU P TIEB1 Nipple-up BOP Stack. 16:30 - 18:00 1.50 BOPSU P TIEB1 Set Test Plug. Remove 9 5/8" Pipe Rams. Install 3 1/2" x 6" VBPRs. 18:00 - 22:00 4.00 BOPSU TIEB1 Test BOP equip as per BP/AOGCC requirements. LP 250 psi, HP 4000 psi. No failures. BOP test witnessing waived by Jeff Jones wI AOGCC. Printed: 5/8/2006 11 :55:43 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/18/2006 22:00 - 23:00 1.00 CASE P TIEB1 Set back kelly. Pull test plug. RID test equip & blow down lines. Set wear bushing. 23:00 - 00:00 1.00 CASE P TIEB1 P/U & M/U BHA as follows: 8 1/2" Bit, 2 Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 9 * 61/4" DCs, XO. TL = 308.19'. 4/19/2006 00:00 - 01 :00 1.00 CASE P TIEB1 RIH wI BHA to clean out shoe track. Ran in wI BHA + 20 Stands. 01 :00 - 04:00 3.00 CASE P TIEB1 P/U kelly & break circulation. RIH & tag up wI 32' of kelly for a total of 2239'. Circulate bottoms up & had green cement over shaker. Wash & drill hard cement from 2239 to 2256'. Drilled ES cementer @ 2247'. P/U Wt = 58K, SIO Wt = 58K, Rot Wt = 58K. Circulate @ 6 BPM, 425 psi. Torq = 2.5-3.5K ftl-bs. 85 RPMs, WOB 2-8K. 04:00 - 05:00 1.00 CASE P TIEB1 Pump 2 Hi-Vis sweeps & clean up wellbore. 6 BPM @ 425 psi. 05:00 - 06:00 1.00 CASE P TIEB1 Con't to clean out shoe track as above. Drilled baffle plate to 2257'. 06:00 - 07:30 1.50 CASE P TIEB1 Drill out Baffle Plate and complete drilling up shoe Track. Set back Kelly. 07:30 - 08:00 0.50 CASE P TIEB1 Continue to TIH to top of sand at 3,959'. Wash into sand to 3,964'. 08:00 - 09:00 1.00 CASE P TIEB1 Reverse in with a 20 bbls Hi-Vis sweep. Continue to reverse circulate with 9.8 Iblgal Brine at 5 bpm/750 psi to clean-up Well bore. Recovered some Arctic Pack, some Sand, and a few bit of rubber. 09:00 - 10:00 1.00 CASE P TIEB1 Lay down two Drill Pipe singles. Rig up test equipment. Test 9 5/8" Casing at 4,000 psi for 33 minutes (lost 125 psi). Monitored an open OA during test and observed no flow. Good test. Blown down lines. 10:00 - 11 :00 1.00 CASE P TIEB1 Trip out with Drill Pipe and BHA 13. 11 :00 - 11 :30 0.50 CASE P TIEB1 Lay down BHA #13. 11 :30 - 12:30 1.00 CASE P DECOMP Clear and clean Floor. Bring tools to the floor for the next BHA 12:30 - 13:00 0.50 CASE P DECOMP Make-up BHA #14 as follows: 77/8" RCJB w/8.187" Head, XO, XO, 95/8" Casing Scraper, Boot Basket, Boot Basket, Bit Sub, Bumper Sub, Oil Jar, XO, Drill Collars, XO, Pump-out sub. 13:00 - 14:00 1.00 CASE P DECOMP Trip in with BHA #14 and 3 1/2" Drill Pipe. 14:00 - 14:30 0.50 CASE P DECOMP Pick-up Kelly. Tag Sand at 3,959'. Wash and rotate down to 3,976'. at 6 bpm/570 psi. 14:30 - 16:00 1.50 CASE P DECOMP Set back Kelly. Blow down lines. Trip out with Drill Pipe and BHA #14. 16:00 - 17:00 1.00 CASE P DECOMP Break-ou RCJB and Boot Baskets. Recovered aarge chunk of rubber, one large piece of metal and several smaller pieces of rubber and metal. Boot Baskets were full of sand. 17:00 - 18:00 1.00 CASE P DECOMP Clear & clean rig floor. 18:00 - 18:30 0.50 CASE P DECOMP M/U RCJB BHA for 2nd run. 18:30 - 19:30 1.00 CASE P DECOMP RIH wI RCJB assy. 19:30 - 20:30 1.00 CASE P DECOMP P/U kelly. Break circulation, 6 BPM @ 425 psi. & tag @ 3973'. Wash from 3973 to 3981'. Work junk basket up & down. P/U Wt = 81 K, SIO Wt = 75K. Rot Wt = 81 K. Set back kelly. 20:30 - 22:00 1.50 CASE P DECOMP Cut & slip 84' of drilling line. 22:00 - 23:00 1.00 CASE P DECOMP POOH wI RCJB assy. 23:00 - 00:00 1.00 CASE P DECOMP Break out Rcjb & recovered 2 pcs of ring from wiper plug & 1 pc of 9 5/8" casing. Empty bott baskets & recover 2 gals of sand. 4/20/2006 00:00 - 00:30 0.50 CASE P DECOMP Make up RCJB wI 4' extension as follows: RCJB, Extension, 2 Printed: 51812006 11 :55:43 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/20/2006 00:00 - 00:30 0.50 CASE P DECOMP Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 9· 6 1/4" DCs, XO, Pump out Sub. TL = 317.89'. 00:30 - 02:00 1.50 CASE P DECOMP RIH wI RCJB Assy on 31/2" DP. 02:00 - 03:00 1.00 CASE P DECOMP P/U kelly & break cirulation. 6 BPM @ 2600 psi. Work RCJB & Wash from 3981 to 3987'. P/U 81 K, SIO 78K, Rot 81 K. Work RCJB up & down 4 times allowing sand to fall after each run. Set back kelly. 03:00 - 04:30 1.50 CASE P DECOMP POOH wI RCJB BHA on 3 1/2" DP. 04:30 - 06:00 1.50 CASE P DECOMP Break out RCJB & recover final piece of plug ring. Clean out boot baskets & recover 1 1/2 gals of sand. UD remainder of BHA & 9 . 6 1/4" DCs. Clear & clean rig floor. 06:00 - 06:30 0.50 CASE P DECOMP Lub Rig and inspect Derrick. 06:30 - 08:00 1.50 CASE P DECOMP Trip in with Halco Retrieving Tool. Wash down to top of RBP at 3,992' 08:00 - 09:30 1.50 CASE P DECOMP Mix and reverse in with a 20 bbl Hi-Vis Sweep. Reverse back to surface at 5.5 bpm/970 psi. Recovered much 20140 mesh sand and a few small pieces of rubber. No pieces of metal were observed in the returns. 09:30 - 10:30 1.00 CASE P DECOMP Continue to reverse circulate and swap Well over to clean 100 deg F Sea Water at 5.0 bpm/850 psi. 10:30 - 12:30 2.00 CASE P DECOMP Latch and attempt to release HAlco RBP at 3,999' (center of element). No-joy. 12:30 - 14:00 1.50 CASE P DECOMP Release Retrieving Tool. Trip out to add Oil Jars for next run. 14:00 -15:00 1.00 CASE P DECOMP P/U & M/U new BHA. 15:00 - 16:00 1.00 CASE P DECOMP RIH wI Reteiving tool on 31/2" DP. 16:00 - 17:00 1.00 CASE P DECOMP Engage RBP work BP & release. 17:00 - 19:00 2.00 CASE P DECOMP POOH wI RBP & retreiving tool. Stand back 3 1/2" & DCs. 19:00 - 19:30 0.50 CASE P DECOMP Recovered RBP. Inspect same. Rubbers intact. No apparent damage to BP. UD RBP. Clear & clean rig floor. Inspect retreiving tool to re-run. 19:30 - 22:30 3.00 CASE P DECOMP RIH wI retreiving tool, DCs & jars on 3 1/2" DP. Ran 271 jts. 22:30 - 00:00 1.50 CASE P DECOMP Tag up on RBP @ 8886'. Work torq & weight down to retreiving tool. BP released. Monitor well & allow rubbers to relax. Well static. Go down 15', then pull up & insure plug free & no swabbing. Monitor welL.. Well.Static. FL @ surface. 4/21/2006 00:00 - 00:30 0.50 CASE P DECOMP Monitor well. Well static. RIU lines to circulate. 00:30 - 06:00 5.50 CASE P DECOMP Circulate bottoms up. 3BPM @ 400 psi, then increse to 4 BPM @ 650 psi. Had gas to surfaceafter 5300 stks (311 bbls). Slow to 3 BPM @ 350 psi & con't to circulate 1 1/2 bottoms up. gas dropped off to 0 @ 645 bbls. Con't to 835 bbls. SID & monitor well. 06:00 - 06:30 0.50 CASE P DECOMP Lub Rig. Inspect Derrick. 06:30 - 10:00 3.50 CASE P DECOMP Well remains full and static. Trip out with 10 Stands. Shut down charge Pump. Stop and monitor. Well remains full and static. Continue to TOH with 31/2" drill Pipe and RBP, keeping constant hole fill. 10:00 - 10:30 0.50 CASE P DECOMP Lay down Halco RBP and Retrieving Tool. RBP recovered complete. 10:30 - 11 :30 1.00 CASE P DECOMP Clear and clean Floor. Bring next BHA to the Floor. 11 :30 - 12:00 0.50 CASE P DECOMP Make-up BHA as follows: 8 1/2" Bit, 9 5/8" Casing Scraper, XO, Oil Jars, XO, 9 ea 6 1/4" Drill Collars. Total Length = Printed: 5/812006 11 :55:43 AM It e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/21/2006 11 :30 - 12:00 0.50 CASE P DECOMP 281.65' 12:00 - 15:00 3.00 CASE P DECOMP Trip in with Bit/Casing Scraper and 3 1/2" Drill Pipe (276 joints). Bit at 9,012'. 15:00 - 18:00 3.00 CASE P DECOMP Mix and reverse in with a 20 bbl Hi-Vis Sweep. Continue to reverse circulate bottoms-up to condition Well at 4 bpm/650 psi. No gainlNo losses in Pits. 18:00 - 21 :00 3.00 CASE P DECOMP POOH wI bit & scraper Assy. 21 :00 - 21 :30 0.50 CASE P DECOMP Stand back DCs. Break out bit & scraper. UD same. 21 :30 - 22:00 0.50 WHSUR P DECOMP P/U running tool. Pull Wear Bushing. UD running tool. 22:00 - 23:30 1.50 CASE P DECOMP RIH w/3 stands of DCs & 8 stands of 31/2" DP. M/U 9 5/8" storm packer, RIH & set @ 35'. Back out & UD landing jt. Pressure test to 1000 psi, Ok. 23:30 - 00:00 0.50 WHSUR P DECOMP P/U running tool & set Test plug. UD running tool. 4/2212006 00:00 - 02:00 2.00 BOPSU P RUNCMP Change out rams for 7 5/8" tubing. Test same. Lp 250 psi, HP 4000 psi. Charted same. 02:00 - 02:30 RUNCMP Drain stack. P/U running tool. Pull test plug & UD same. 02:30 - 03:00 RUNCMP M/U landing jt. RIH & engage storm packer. Unset packer. & pull to surface. UD same. 03:00 - 04:00 1.00 RUNCMP POOH & stand back 8 stands of 31/2" DP. Break out & UD 9 * 6 1/4" DCs. 04:00 - 06:00 2.00 RUNCMP R/U to run completion. R/U Torq Tum equip & Gator-Hawk equip. 06:00 - 07:00 1.00 RUNCMP Complete rig-up. 07:00 - 07:30 0.50 RUNCMP Pre-job safety and operations meeting with all. 07:30 - 08:30 1.00 RUNCMP Pick-up Completion Jewlery as follows:, 7" WLEG, 7" 261b/ft L-80 TCII Pup Joint, 7" 26 Ibltt L-80 TCII Pup Joint, 7" RN-Nipple w/RHC-M Plug installed, 7" 26 Ib/ft L-80 TCII Pup Joint, 7" 26 Ib/ft L-80 TCII Pup Joint, 95/8" Backer S-3 Production Packer, 7" 26 Ib/ft L-80 TCII Pup Joint, 7" 26 Iblft L-80 TCII Pup Joint, 7" R-Nipple, 7" 26 Ibltt L-80 TCII Pup Joint, 7" TCII pin x 7 5/8" box XO. All connections below Packer are Baker-Lok'd. 08:30 - 18:00 9.50 RUNCO RUNCMP Begin running 7 5/8" 29,7 I bitt NT-95 and L-80 VT HC IPC Tubing. (Note all Tubing Joints have L-80 Couplings). All Joints have been drifted. Used Torque Turn and Gater-Hawk services. Yam PTS Service Hand on Floor to monitor each connection. Make-up torque = 14,450 ft/lbs. Gater-Hawk tested couplings at 3,800 psi. Used Jet Lube Seal Guard pipe dope. Have 83 Joints run at Crew Change. Found one leak so far on Joint number 45 (Pin end below Collar. Break-out Collar. Clean and re-dope. Install Collar and re-torque. Tested good.) 18:00 - 00:00 6.00 RUNCO P RUNCMP Con't to P/U & run 7 5/8" 29.7#, NT-95 & L-80 , VT HC IPC tubing. Torq Turn & Gator Hawk all connections. Replaced control valve on Torq Turn unit. Jt #s 86, 94, 95, & 99 boxes on mill end leaks. Had to break off collars, clean & re-dope.replace. Jt #88, would not test.UD same & replace jt. Had 99 jts in hole @ midnight. 4/23/2006 00:00 - 06:00 RUNCMP Con't to RIH w/7 5/8" 29.7#, NT-96 & L-80, VT HC IPC tubing. Torq Turn to 14450 ft-Ibs & Gator Hawk to 3800 psi all connections. Jt # 105,128, 129 would not test. Had to break out collar, clean & re-dope connection to test. 06:00 - 18:00 RUNCMP Continue running 7 5/8" Completion. Joints 131, 148,169, and Printed: 5/8/2006 11 :55:43 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 188 did not test on the mill end. Break out coupling, clean and re-dope. Re-torque Collar and re- test good. Joints 145 and 146 did not test and were rejected. Total Joints ran at 18:00 hrs = 200. 18:00 - 22:30 RUNCMP Con't to run 7 5/8" 29.7#, NT-95 & L-80, VT HC IPC tubing. Torq turned connections to 14450 ft-Ibs & gator Hawked connections to 3800 psi. Jt # 219, 220, 221, & 225 would not test. Had to break out coupling, clean & re-dope the connections to test. Ran a total of 225 jts + 5.57',7.99', & 9.37' pups. Pups were buried below jt # 225. 22:30 - 00:00 1.50 RUNCO RUNCMP P/U & M/U landing jt into hanger. Gater-Hawked & Torque Turned connection. Orient & Land hanger. P/U Wt = 244K, SIO Wt = 190K. 4/24/2006 00:00 - 00:30 0.50 RUNCO RUNCMP Finish landing completion & RILDS. 00:30 - 01 :30 1.00 RUNCO RUNCMP RID Torq Turn equip & Gator Hawk Equip. Clear rig floor. 01 :30 - 06:30 5.00 RUNCO RUNCMP Line up, close rams & reverse circulate well down IA as follows: Pump 250 bbls of seawater from pits, Follow wI 200 bbls of 140 degree heated seawater. Chase wI 200 bbls of 140 degree inhibited seawater. Pump @ 3 BPM, 360 psi. RlU hot oilers & pump 45 bbls of diesel for freeze protection. Close in IA. 06:30 - 07:30 1.00 RUNCO RUNCMP Drop Packer setting Ball/Rod. Rig up chart testing equipment. 07:30 - 09:30 2.00 RUNCO RUNCMP Pressure up on tubing to set Packer. Test tubing at 4,000 psi/30 minutes. Record on chart. No flow from IA during test. Good test. Bleed pressure down to 1500 psi and shut-in tubing. Pressure up on IA with diesel to 4,000 psi/30 minutes. Lost 100 psi on 30 minutes. Record on chart. Good test. Bleed pressure off from IA first. Bleed pressure off of tubing. 09:30 - 10:00 RUNCMP Drain BOP Stack. Blow down Lines. Rig-down test equipment. Spot SWS S-line Unit. 10:00 - 15:30 5.50 BOPSU RUNCMP Rig-up Drill-Site Maint. Pick-up Lubricator and extention. Atempted three times with two different Plugs to set BPV/Dart. BPV becames stuck in Tubing Hanger profile. Pull free. Rig down DSM. 15:30 - 18:00 2.50 BOPSU RUNCMP Order out Plug to set in DB-6 Nipple at 2,200'. Begin to rig up S-Line. 18:00 - 19:00 1.00 BOPSU RUNCMP P/U plug for DB nipple & attempt to RIH. Plug would not go thru hanger. POOH & inspect plug. dogs were extended & would no t retract. 19:00 - 20:30 1.50 BOPSU RUNCMP Re-dress DB plug. 20:30 - 22:30 2.00 BOPSU RUNCMP RIH wI plug & set in DB nipple @ 2212' WLM. POOH & UD slick line equip. 22:30 - 23:00 0.50 BOPSU RUNCMP Pressure test plug to 1000 psi, OK. 23:00 - 00:00 1.00 BOPSU RUNCMP NID BOP stack & set back. 4/25/2006 00:00 - 00:30 0.50 BOPSU RUNCMP Finish NID BOP stack. Inspect hanger. No damage or junk in hanger profile. 00:30 - 02:30 2.00 BOPSU RUNCMP P/U BPV & attempt to set manually. No luck. Re-dress SPY. Attempt to install redressed BPV, could only get 5 of the neccessary 8 rounds to fully set plug. No Joy. Measure OD of plug wI dogs extended 6.5". Caliper profile of hanger where dogs engage, 67/16". Believe profile of hanger is not correctly machined. ? 02:30 - 04:00 1.50 BOPSU P RUNCMP NIU BOPE. Printed: 5/8/2006 11 :55:43 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 07:30 - 08:30 08:30 - 09:30 09:30 - 18:00 RUNCMP RUNCMP RUNCMP 1.00 1.00 8.50 18:00 - 19:30 RUNCMP 19:30 - 21 :00 RUNCMP 21 :00 - 22:30 RUNCMP 22:30 - 00:00 RUNCMP 4/26/2006 00:00 - 00:30 RUNCMP 00:30 - 05:00 RUNCMP 05:00 - 06:00 1.00 DHEQP P POST 06:00 - 09:30 3.50 DHEQP P POST 09:30 - 10:30 1.00 DHEQP P POST 10:30 - 12:00 1.50 WHSUR P POST 12:00 - 15:30 3.50 BOPSU P POST 15:30 - 20:00 4.50 DHB P POST 20:00 - 21 :00 1.00 DHB P POST 21 :00 - 21 :30 0.50 DHB P POST 21 :30 - 23:30 2.00 DHB P POST 23:30 - 00:00 0.50 DHB P POST 4/27/2006 00:00 - 00:30 0.50 DHB P POST 00:30 - 02:00 1.50 DHB P POST 02:00 - 08:00 6.00 DHB P POST 08:00 - 12:00 4.00 DHB P POST 12:00 - 14:30 2.50 DHB P POST 14:30 - 18:00 3.50 DHB POST P Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 Pressure test rams & breaks. Change out 7 5/8" pipe rams to 3 1/2" x 6" VBRs. Test as follows: LP 250 psi, HP 4000 psi. & chart same. Discuss plan forward with Anch Eng. Blow down lines. RID test equip. RID Schlumberger Slickline unit & equip. NID shooting flange. NIU flow nipple. TIH w/3 1/2" DP in 2000' stages & POOH & LDDP. RIH wI last 2100' to top of DB plug & wait on Hotoilers wI diesel freeze protect. RlU hotoilers. Heat diesel to 60 degrees. Pressure test lines to 3000 psi. Reverse circulate & displace well to diesel above DB plug. Pump 4 BPM @ 420 psi. Pumped 90 bbls. Drain lines & stack. POOH & UD 31/2" DP. Fill hole wI diesel. used 12 bbls. Clear & clean rig floor. RID Hot oilers. NID BOPE. Finish NID BOPE. N/U Adapter flange. Test hanger void to 5000 psi, OK. N/U X-mas tree. Fill & test to 2500 psi, OK. Clean, service & maintain rig. WIO slick line unit. MIRU SWS slickline unit with braided line. RU on tree-cap with full lubricator, BOPs and pack-off. Shut down operation. SL not rigged up on tree as yet. Discuss plan forward with Anchorage Engineering. Asset wants to proceed with fill cleanout with the rig. Notify AOGCC Inspector (Chuck Scheve) of upcoming BOP test - AOGCC waived witnessing the test. ND tree and adapter flange. NU BOPE. Fill stack with seawater and body test same to 2000 psi for 15-min. Good test - witnessed by WSL D. Reem. NU shooting flange on top of Hydril. RU Schlumberger wireline unit (braided line). RIH wI retrieving tool & recover plug prong. UD same. M/U "PRS" plug retreiving tool, RIH & jar on DB plug. POOH & UD "DB" plug. P/U blanking plug, RIH & set. POOH. P/U blanking plug prong & RIH. POOH after setting prong. Close in well & test DB Blanking plug to 4000 psi, OK. RID Slickline equip. N/D shooting flange. N/U flow nipple. RlU test equip. Test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 4000 psi. BOP test witnessing waived by Chuck Scheve wI AOGCC. RD test equip. ND riser. NU shooting flange. RU SWS slickline w/pump-in sub, braided line BOP, lubricator and pack-off. MU pulling tool for prong retrieval. PT slickline lubricator to 2000 psi against blanking plug set in DB-6 nipple. RIH w/JUC inside bell-guide, latch & pull prong. RIH with GS, latch plug body, one 1100# jar-lick, plug is free. POH with same. RIH with pulling tool inside bell-guide. Latch prong and spang Printed: 5/812006 11 :55:43 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/27/2006 14:30 - 18:00 3.50 DHB P POST free (1 lick). POH with prong. 18:00 - 21 :00 3.00 DHB P POST P/U pulling tool. RIH & jar RHC plug body free. (1 lick) POOH & UD same. RD slickline equipment. 21 :00 - 22:30 1.50 DHB P POST M/U BHA to clean out salt plug & fill as follows: 5 3/8" Mill, Bumper Sub, Jars, 9 * 4 3/4" DCs. TL = 298.67'. 22:30 - 00:00 1.50 DHB P POST P/U 3 1/2" DP, 1x1 & single in hole. Had 44 jts in @ 12PM. 4/28/2006 00:00 - 01 :00 1.00 DHEOP P POST Con't To P/U 3 1/2" DP 1 x1 & RIH to 2260' (62 jts) 01 :00 - 01 :30 0.50 DHEOP P POST M/U circulating head. Displace diesel wI seawater. Circulate clean. 5 BPM @ 450 psi. 01 :30 - 07:30 6.00 DHEOP P POST Con't to P/U 3 1/2" DP 1x1 & RIH . 07:30 - 11 :30 4.00 DHEOP P POST Tag up on jt 306 (12' in on kelly) at 10002'md. Repeat tag 2X w/5K set down weight. Pick-up and line up to reverse circulate with seawater. Reverse down @ 4 bpm with losses ranging from 5 bbls/5-min to 12 bbls/5-min. Reversed down 3 jts. Parked and reversed until final slug of salt observed across shaker. Continue 3 jt washdown pattern. Abundant salt across shakers with each bottoms-up reversed. 11 :30 - 11 :45 0.25 DHEOP P POST Reverse washed joint 318 down. Loss rate -12 bbls/5-min, reverse rate 4.5 bpm. Observe 40/60 carbolite in returns with some 12x18 carbolite. No more salt solids. Mill depth -10400'md. 11 :45 - 12:00 0.25 DHEOP P POST Attempt to wash #319 down...stacking weight with no wash-off at -10402'md. Try spudding thru w/10K down weight. Work pipe maintaining reverse circulation trying to get past 10402'md. 12:00 - 12:30 0.50 DHEOP P POST Reverse drill-pipe volume. Lost returns, increase rate to 5.3 bpm...still no returns. Open annular and observe fluid level dropping away. 12:30 - 13:00 0.50 DHEOP P POST Line up to circulate the long way. Establish circulation at 4 bpm. RU kelly. Attempt to mill thru obstruction at 10402'md. Pick-up w/20-30K over-pull. Drill pipe plugging off and pressuring up. Pick up to 10396'md. 13:00 - 13:45 0.75 DHEOP P POST Line back up to reverse, now able to get reverse circulation. Reverse 2X drill-pipe volume. Nothing major over shaker just formation sand - no large slugs of it at all. 13:45 -14:15 0.50 DHEOP P POST Swap back to the long way at 4.5 bpm. Attempt to work mill down. Work down to 10404'md and drill pipe beginning to pack -off again. Pick-up off bottom (sticky again). 14:15 - 15:30 1.25 DHEOP P POST Line back up to reverse @ 5 bpm, 600 psi. Losses ranging 5-15 bbls/5-min. Formation fines strung out in retruns. No big surgeslslugs of solids. 15:30 - 16:30 1.00 DHEOP P POST Line up the long way, mix and pump 20-bbl 40K LSRV pill followed by clean seawater. 18 bbls to fill hole and achieve circulation. Kelly up and work pipe rotating. Pump pressure steady at 850 psi, 4.5 bpm. Mill torquing up to 10k ft-Ibs. Many pick-ups off bottom, occasional over-pulls (10-15K over). 16:30 - 18:00 1.50 DHEOP P POST Able to get past 10404'md. Rotate full kelly down slowly to 10435'md, steady returns throughout. Pick-up w/2 over-pulls (25K over) to 10396'md. Wash back down wlo rotating wIno problems. PUH to 1 0396'md with no over-pulls. 18:00 - 00:00 6.00 DHEOP P POST Make connection & Reverse down to 10435', no problem. Make connection & attempt to reverse wash down & clean well bore. Could not make hole when reversing. Swap over to Printed: 5/8/2006 11 :55:43 AM -- e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/28/2006 18:00 - 00:00 6.00 DHEOP P POST long way & wash jt down very easily. Pick back up & swap back over to reversing. Wash down reversing & circulate hole. 1 1/2 DP volume. Make connection & repeat process of washing down long way then P/U & reverse back down. Losses running 60 to 80%. Con't to reverse out 4 times DP volume. Now unloading much sand. Elect to Vis up system to approx 34 vis & con't to P/U singles & wash down long way, then reversing out. Losses averaging 60%. Got to 10588' @ midnight. 4/29/2006 00:00 - 02:30 2.50 DHEOP P POST Con't to wash & reverse circulating to clean out well bore. Cleaned from 10588 to 10716'. pumping 5 BPM @ 475 psi. Recovering clean frac sand & some pieces of scale & debris. Circulating each jt down the long way, then P/U & swap to reversing. Losses now 33-50%. P/U Wt = 150K, SIO Wt = 115K. 02:30 - 04:30 2.00 DHEOP P POST Reverse well clean. Pump 5 BPM @ 450 psi. Losses running 30-50%. SID monitor well. FL dropping. Prep to POOH. 04:30 - 08:30 4.00 DHEOP P POST POOH & UD 31/2" DP. Using greater than double displacement. Check hole fill w/65 joints laid down: 53 bbls. Cut & slip drill line @ 07:15 - continue idling charge pump w/seawater. Resume POH and LDDP at 08:30 keeping hole full with charge pump. 08:30 - 15:00 6.50 DHEOP P POST At surface with mill. Used -400 bbls seawater keeping hole full while LDDP. Mill and jars showed evidence of metal scarring from junk? C&C floor and prep for rigging up slickline unit. 15:00 - 16:00 1.00 DHEOP P POST ND flow nipple, NU shooting flange. Spot SWS wireline. LRS heating diesel to 60 degF off to the side of the location. PJSM and plan forward w/crew. 16:00 - 21 :00 5.00 DHEOP P POST Con't to RIU Slickline equip. Spot in Hot oilers. & hookup to vac truck. P/U lubricator & "RN plug. Test lubricator to 1 000 psi. Take on seawater in pits. 21 :00 - 22:30 1.50 DHEOP P POST Bullhead kill well. SIP 1520 psi. Pump 10 BPM, (5 BPM rig pump + 5 BPM Hot oil truck). Initial pumping pressure 1700 psi. Final pumping pressure 750 psi. SID well pressure dropped to o psi. Pumped total of 610 bbls. Open well well on vacuum. 22:30 - 23:00 0.50 DHEOP P POST RIH wI "RN" plug. Hung up in "DB" nipple. Feft plug in nipple. POOH. When tools got to surface, had 70 psi on well. 23:00 - 00:00 1.00 DHEOP P POST Bleed off lubricator & M/U plug retreiving tool. RIH & pull plug from "DB" nipple @ 2200'. POOH & UD same. SIP 180 psi. 4/30/2006 00:00 - 01 :00 1.00 DHB P POST Re-dress & re-pin "RN" plug. Plug had some gravel & junk debris in plug. Must be from kill operation? Discuss wI wireline supervisor from wells group (Joe Mcinnis) & elect to make brush run. 01 :00 - 03:00 2.00 DHB P POST P/U wireline brush to insure nipple profiles are clean. RIH & brush thru tubing & out WLEG. POOH. WHP = 1420 psi. Close rams & bleed off lubricator. Inspect brush. UD brush. M/U "RN" plug & seeting tool. 03:00 - 04:00 1.00 DHB P POST RIH wI "RN" plug to 8700'. Pump 105 bbls of diesel freeze protect @ 3 BPM. WHP = 1470 psi. 04:00 - 05:00 1.00 DHB P POST Con't in hole thru top of 7" liner. Work plug "R" nipple & packer. Set "RN" plug in nipple @ 8942' WLD. Shear out plug. 05:00 - 06:00 1.00 DHB P POST Wireline POOH wI Plug setting tool. Close in rams & bleed off pressure in lubricator. Inspect tool. Plug gone. WHP = 1530 psi. Printed: 5/812006 11 :55:43 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 4/30/2006 06:00 - 07:30 1.50 DHB P POST "RN" plug equalizing prong set. POH w/JD setting tool. WHP = 1750 psi. Close blind rams. SL crew change-out. Bleed down lubricator. Pop off lubricator and check tools: prong is gone. MU "R" plug body on running tool.. Stab lubricator back on. 07:30 - 09:00 1.50 DHB P POST Line up thru choke to bleed off WHP (1910 psi) out to tiger tank to test RN plug. Bleed off WHP (all gas) down to 1000 psi. SI f/5-min, WHP remained at 100 psi. Plug is holding. Continue to bleed down WHP (all gas) to 500 psi. SI and monitor WHP - steady at 500 psi. 09:00 - 11 :30 2.50 DHB P POST Pressure up on lubricator to 500 psi, open bland rams and RIH with "R" plug body. Observe fluid level at -4600'md. Set "R" plug body, POH with setting tools, observe fluid level again at -4600', 11 :30 - 13:30 2.00 DHB P POST RIH wlequalizing prong for "R" plug. See FL again at 4600'. Attempt to set prong, looked to be a mis-run and running tools gettin wedged alongside prong. POH. Prong lost downhole 13:30 - 15:30 2.00 DHB P POST RIH with pulling tool inside 3.60" bell-guide. Bring LRS on line with diesel down the tubing at 1.0 bpm to ensure adequate amount of freeze protect fluid. Latch prong, one small lick and POH. Inspect prong, defenite marks on outside showing where JD ran alongside the prong. 15:30 - 16:30 1.00 DHB P POST Re-dressed JD, added 3.60" bell-guide, made-up prong and RIH, see fluid level at -3000' (56 bbls diesel away). Set prong - good set this time. POH. Check tools - prong is gone. Increase rate on LRS to 1.5 bpm until 90 bbls pumped. 16:30 - 19:00 2.50 DHB P POST Finish filling hole with seawater. PT "R" plug to 1500 psi. SD pumping and allow diesel to migrate to surface. 19:00 - 23:00 4.00 DHB P POST Bleed off pressure, open rams @ allow well fluids to equqalize. Diesel & bubbles rising to surface. Close in rams last 1 hr to insure no pressure build up. pressure 0 after 1 hr. No bubbles, well static. 23:00 - 00:00 1.00 DHB P POST P/U lubricator & RIH wI blanking plug to 2202'. . Set in "DB" nipple & POOH. Open lubricator & flound blanking plug gone. M/U prong & RIH. Set prong in blanking plug & POOH. Set back lubricator. Prong gone. 5/1/2006 00:00 - 02:00 2.00 DHB P POST Close in wll & pressure test blanking plug to 1500 psi. Tested good. RID Slickline equip. NID shooting flange. Install flow nipple. 02:00 - 04:00 2.00 BOPSU P POST Start ND BOPE. Had diesel sucked down approx l' below hanger. While Nippling down prior to breaking last few bolts. Noticed small amt of diesel seeping out. Checked wellbore from floor & diesel had risen above hanger to nearly rams. Approx. 3'. Pumped out diesel wI cellar pump to approx. 1 ' below hanger & monitor. Fluid did not appear to rise. Suddenly well "burped" & fluid was above hanger.again. Tighten up BOP bolts & monitor well. 04:00 - 06:00 2.00 BOPSU P POST Observe fluid level in stack and monitor same to ensure that wellbore fluids are not increasing in volume - may be thermal expansion? 06:00 - 11 :30 5.50 BOPSU P POST Monitor and measure frequency of fluid level rising event. Consult with Anchorage engineering & evaluate options. Frequency appears to be slowly dropping off. Order out 3-3/8" Printed: 5/8/2006 11 :55:43 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NGI-08 NGI-08 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 4/2/2006 Rig Release: 5/2/2006 Rig Number: Spud Date: 7/16/1976 End: 5/2/2006 IBP and setting tools and LRS pump truck. Load pipe shed w/-20 joints drill pipe. 11 :30 - 12:30 1.00 DHB P POST MU Baker IBP (3-3/8" OD), hydraulic running tool, screen sub, inflate valve, 2 x-o to 3.5" IF box. OAL = 18.73'. Re-confirm that IA pressure is zero. 12:30 - 13:15 0.75 DHB P POST RIH wllBP on 18 jts 3.5" IF drill-pipe. Drop 1/2" steel setting ball. Stab TIW valve. Standby for arrival of LRS pump and diesel. 13:15 - 15:00 1.75 DHEQP P POST Wait for LRS. 15:00 - 16:00 1.00 DHEQP P POST RU LRS. Spot unit, hook up 5000 psi hose, chk valve ass'y to TIW valve. Fluid pack line and PT to TIW valve to 3500 psi (OK). 16:00 - 17:30 1 .50 DHB P POST Attempt to set IBP per Baker rep. Does not appear to be inflating properly (ball not on seat?). Work pump, bleed off etc trying to get inflation valve to open. Try reversing thru the screen sub to un-plug the inflation valve. Able to reverse one bbl, tried inflating again...no joy. POH to check tools. 17:30 - 19:30 2.00 DHB P POST POOH w/IBP. Pull 18 jts of 31/2" DP, comming wet wI diesel. 19:30 - 20:00 0.50 DHB P POST Inspect & re-dress IBP setting tool. Screen plugged wI debris. 20:00 - 21 :30 1.50 DHB P POST M/U IBP & setting tool wI ball on seat. P/U 18 jts of 31/2" DP & RIH. 21 :30 - 22:30 1.00 DHB P POST Hold PJSM. Test lines to 3000 psi. Pressure up to 700 psi & inflate valve sheared started to inflate elements. slacked off 6K. Con't to Pressure up in 500 psi increments & tool sheared @ 2600 psi. Circulate 1 bbl. Plug set @ 602'.3 Element IBP. 22:30 - 23:30 1.00 DHB P POST POOH & UD 31/2" DP. Pipe dry. 23:30 - 00:00 0.50 DHB P POST RIU, Fill stack to above blind rams. Close in blind rams to test. Pressure test IBP to 1000 psi, OK. Bleed off. 51212006 00:00 - 02:00 2.00 DHB P POST Open blind rams. Monitor wellbore. Well static. 02:00 - 04:00 2.00 DHB P POST NID BOPE. 04:00 - 07:00 3.00 RIGD P POST NIU adapter flange & tree. PT hanger void to 5000 psi. PT tree to 2500 psi. Secure cellar and well. Release rig at 07:00. Printed: 5/8/2006 11 :55:43 AM e e FRANK H. MURKOWSKI, GOVERNOR ALASIiA ORAND GAS CONSERVATION COMMISSION 333 W 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 \1~~05}- Re: Prudhoe Bay, NGI-08 Sundry Number: 306-024 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount Jr. Commissioner -Fl DATED this2.1 day of January, 2006 Encl. VJ4A- ' / I ~ I lJ)OC,p e STATE OF ALASKA e RECEIVED ALASKA Oil AND GAS CONSERVATION COMMISSION JAN 1 8 2006 APPLICATION FOR SUNDRY APPROVAL . . 20 AAC 25.280 Alaska Oil & Gas Cons. Commtsslon Anchorage 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Other ----------~~ 181 Alter Casing I 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. D Development D Exploratory 176-052 / 3. Address: D Stratigraphic 181 Service / 6. API Number: . P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20219-00-00 / 7. KB Elevation (ft): 47' 9. Well Name and Number: PBU NGI-08 ~. 8. Property Designation: 10. Field / Pool(s): ADL 028302 Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONOITIONSUMMARY Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10925 8704 10727 8590 None None Casina Lenath Size MD / TVD Burst Collapse I 110' 20" 110' 110' 1530 520 Surface 2695' 13-3/8" 2695' 2695' 5380 2670 . 9422' 9-5/8" 9422' 7790' 6870 4760 Prnn. ,,,tönn I inAr 1820' 7" 9095' - 10915' 7544' - 8698' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: I Tubing MD (ft): 9952' - 10786' / 8159' - 8623' 7" x 5-1/2", x 4-1/2" I L-80 9103' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker packer Packers and SSSV MD (ft): 8929' / 12. Attachments: 13. Well Class after proposed work: 181 Description Summary of Proposal D BOP Sketch D Exploratory D Development 181 Service D Detailed Operations Program 14. Estimated Date for February {¥2006 15. Well Status after proposed work: Commencing Operations: DOil D Gas / D Plugged D Abandoned 16. Verbal Approval: Date~ DWAG 181 GINJ DWINJ D WDSPL Commission Representative: 17. I hereby cer ~ that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Na~ e David Reem -. Title Drilling Engineer Prepared By Name/Number: Sianature J. \.. ALA~/ (~ ¡,.I~~~-- Phone 564-5743 Date' -I" -0' Terrie Hubble, 564-4628 , Commission Use Only Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ('j()( 0 .. ():J.. 4- D Plug Integrity æ(BOP Test ~echanicallntegrity Test D Location Clearance Other: Të.ç t 'Eo r E to 4000 , ~I\.]:I YðlA/Í~d. f~' RBDMS 8Ft ,tAN '" 4 2006 Subsequent Form Required: to - 404-. iNOOWWS NY(] APPROVED BY {!J.4 / Da Approved By: ~9 P8U8Is I8UI8IIo COMMISSIONER THE COMMISSION Date . . Form 10-403 Revised 07/2005 OF<\G\\\JAL Submit In Duplicate e e Well Status: Shut-in gas injector. Well has confirmed tubing x inner annulus communication. The well is secured with two tubing plugs. Project: Retrieve existing 7",29#, L-80 non-IPC LTC 8rd completion including the ~ packer and tail-pipe. Cut and pull -2300' of 9-5/8". Tie-back in with 2300' of new 9- 5/8", 47#/ft, L-80 TC-II casing and cement in place. Re-complete with 7.625", 29.7#/ft, ,; L-80 Vam Top HC tubing, permanent packer with tail-pipe -2' above existing 7" liner- top packer. Provide AOGCC field inspectors 24-hr notices as required to witness BOP tests and MITIA post packer setting. PRE-RWO · Set TTP in "RN" nipple to secure well (DONE). · Chemical cut 5-1/2" tubing in 1 st full joint above the packer. · Circulate the well over to seawater with diesel freeze protect. CMIT to 2000 psi to verify tubing tail plug integrity. MITOA to 2000 psi to verify 13-3/8" shoe r integrity. Set and test BPV in tubing hanger. RWO 1. MIRU workover rig. Circ out diesel freeze-protect and verify well is dead. Set TWC in tubing hanger and test. 2. ND tree, NU~llY test BOPE per BP and AOGCC regulations (250 psi low pressure test! psi high pressure test (test the annular to 3500 psi). / 3. Pull 7" x 5-1 " tubing down to the cut. 4. Run 9-5/8" scraper to the tubing stub. /,' 5. Run 9-5/8" USIT to locate top of cement in 9-5/8" x 13-3/8" annulus. 6. Set 9-5/8" RBP -1500' below the TOC indicated on the USIT log. Spot 30' of sand on RBP. 7. Mechanically cut the 9-5/8" casing in the 1 st full joint above the TOe. 8. Mobilize and circulate out all Arctic Pack from the 9-5/8" x 13-3/8" annulus. 9. Pull 9-5/8" down to the cut. 10. Run wash shoe and 13-3/8" scraper down to the 9-5/8" stub. Ensure wash shoe is able to get beyond the next 9-5/8" collar by -6'. Reverse circulate the wellbore clean. 11. Back-off 9-5/8" casing stub. / 12. ND BOP and tubing spool. NU BOP on casing head. Test same per step #2. ./ 13. Rill with new 9-5/8", 4 7#/ft, L-80 TC- II casing, shoe-track and over-shot guide- sub. Screw into existing 9-5/8" casing. Pull test casing to 250K. Pressure up to ./ open ES-cementer. Verify communication up 9-5/8" x 13-3/8" annulus. 14. Pull 250K tension on 9-5/8" casing. Split stack below BOPs and install 9-5/8" emergency slips and primary pack-off. Slack off -lOOK to fully engage slips and energize pack-off. 15. Cement 9-5/8" in place with target top of cement = SURFACE. Close ES- / cementer. :;~. e e 16. Split stack, cut 9-5/8". Set back BOPs. Make final dressing cut on 9-5/8" if required and NU tubing spool with secondary pack-off. NU BOPs. Test spool/BOPs to 4000 psi. /' 17. Drill out shoe-track down to sand top on RBP. PT casing to 4000 psi. 18. Retrieve the 9-5/8" RBP. 19. Over-shot tubing stub and rotate k-anchor free from BOT packer. 20. Mill over and recover BOT packer and tail-pipe. ( 21. Rill with bit and scraper. Cleanout 7" liner to PBTD (l0727'md). POH and LDDP. 22. Rill with 7" WLEG, 7" 26#/ft L-80 tail-pipe, 7" x 9-5/8" L-80 S-3 packer, 7" ,{ crossed over to 7-5/8", 29.7#/ft, L-80, VamTop HC completion. Will have a 7" DB-6landing nipple at -2100' for flapper-type safety valve installation after the rig moves off. 23. Tag top of existing liner-top packer, P/U 2-3', reverse in packer fluid and freeze protection. Allow freeze-protect fluid to U-tube between tubing and inner annulus. 24. Set S-3 packer. MIT-T to 4000 psi, MIT-IA to 4000 psi. /' 25. Set BPV. ND BOP, NU and PT tree to 5000 psi. 26. RDMO. POST-RWO · Pull ball&rod from RHC sleeve. Pull RHC sleeve. · Set A-I injection valve in DB-6 landing nipple. · Tie-in injection lines, re-set wellhouse and instrumentation. · POI. MIT-IA w/AOGCC witness. TREE = ? .. WELLHEAD = GRAY ".-._.",_,_,_-,c,_",_,_,,<,__A,._.,,,,___=,,,,«<=.'=<====""'''''''''''''''''''''''''<'< ACTUA TOR = AXELSON KB. ELEV = 47 BF. ELEV = ? KOP = 3200' Max Angle = 58 @ 10200' Datum MD = 11106' Datum TVD = 8800' SS e 113-3/8" CSG, 72#, MN-80, ID = 12.347" I 17" TBG-NPC, 29#, L-80, .0371 bpf, ID = 6.184" 1-1 8779' TOPOF 5-1/2" TBG-NPC H 8779' Minimum ID = 3.813" @ 9038' 4-1/2" OTIS X NIPPLE 15-1/2" TBG-NPC, 17#, L-80, .0232 bpf, ID = 4.892" H 8975' ITOP OF 4-1/2" TBG-NPC H 8975' I TOP OF 7" LNR 14-1/2" TBG-NPC, 12.6#, L-80, .0152 bpf, ID = 3.958" 9103' NGI-08 e I SAFETY NOTES ~ .. 2200' -17" OTIS RB SSSV NIP, ID = 5.963" I -i 7" X 5-1/2" XO I / -15-1/2" OTIS XA SLIDING SLV -15-1/2" OTIS XN LANDING NIP, ID = 4.455" -15-1/2" BOT PBR ASSY 1 -19-5/8" X 5-1/2" BOT PKR I 8975' -15-1/2" X 4-1/2" XO I / 9038' -14-1/2" OTIS X NIP, ID = 3.813" 1 9100' 9103' 9099' 19-5/8" CSG, 47#, MN-80, ID = 8.681" I ÆRFORA TION SUMMARY REF LOG: BHCS ON 08/06/76 ANGLEATTOPÆRF: 53 @ 9952' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 9952 - 10020 0 07/01/90 3-3/8" 4 10106 - 10209 0 05/02/87 3-3/8" 4 10225 - 10482 0 05/02/87 3-3/8" 4 10500 - 10525 0 10/20/77 3-3/8" 4 10566 - 10613 0 05/01/87 3-3/8" 4 10623 - 10717 0 10/20/77 3-3/8" 4 10746 - 10766 0 05/01/87 3-3/8" 4 10776 - 10786 0 10/20/77 I FILL PBTD (MD) 05/01/87 I IPBTD I 10727' 10727' 17" LNR, 29#, MN-80, .0371 bpf, ID = 6.184" 10915' DATE 08/22/76 07/18/01 12/04/05 REV BY COMMENTS ORIGINAL COMPLEfION RNlTP CORRECTIONS DA V /PA G CORRECTIONS DATE REV BY COMMENTS H 4-1/2" BOT SHEA ROUT SUB -+-1/2" TUBING TAIL I H ELMD TT LOGGED 12/14/76 PRUDHOE BA Y UNIT WELL: NGI-08 ÆRMIT No: 76-052 API No: 50-029-20219-00 SEC 12, TIIN, R14E 4244.42 FEL 829.04 FNL BP Exploration (Alaska) TREE = WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = ? GRAY AXELSON 47 ? 3200' 58 @ 10200' 11106' 8800' SS ~GI-08 proposeI' 9-5/S", 47#, L-80 TC-II fully cemented to suñace above existing TOC in / 9-5/S" x 13-3/8" annulus 113-3/8" CSG, 72#, MN-80, ID = 12.347" I 17-5/8".29.7#. L-80, IPC Vam Top HCTUBING 17" 26# L -80 NPC, TC-II TUBING I TOP OF 7" LNR 19-5/8" CSG, 47#, MN-80, ID = 8.681" I PERFORATION SUMMARY REF LOG: BHes ON 08/06/76 ANGLE AT TOP PERF: 53 @ 9952' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 4 9952 - 10020 0 07/01/90 3-3/8" 4 10106 - 10209 0 05/02/87 3-3/8" 4 10225 - 10482 0 05/02187 3-3/8" 4 10500 - 10525 0 10/20/77 3-3/8" 4 10566 - 10613 0 05/01/87 3-3/8" 4 10623 - 10717 0 10/20/77 3-3/8" 4 10746 - 10766 0 05/01/87 3-3/8" 4 10776 - 10786 0 10/20/77 I FILL PBTD (MD) 05/01/87 I IPBTD I 17" LNR, 29#, MN-80, .0371 bpf, ID = 6.184" DA TE REV BY COMMENTS 08/22/76 ORIGINAL COMPLETION 07/18/01 RNITP CORRECTIONS 12/04/05 DA V /PA G CORRECTIONS 10727' 10727' 10915' DATE REV BY -9030' - 7" HES R LANDING NIP, ID = 5.963" I ",. -I -9050' 1"9-5/8" x 7" Baker S-3 Packer, 10 = 6.00" I -9075' H 7" HES RN LANDING NIP, ID = 5.770" I COMMENTS PRUDHOE BA Y UNIT WELL: NGI-08 ÆRMIT No: 76-052 API No: 50-029-20219-00 SEe 12, TIIN, R14E 4244.42 FEL 829.04 FNL BP EXploration (Alaska) STATUS: NGI-08 e e -'--;:':.:_--~' Prb·j"1'~·5"2-- Sub.icct: STATUS: 1\:GI-08 From: "NSLJ, AD\-V wcn rntcgrity Enginccr" <NSUADWWclllntegrityEnginccr(q}BP.com> D~tte: Mon. 21 Nov 2005 13:09:56 -0900 /ùS- .. . .,. .. .-~. 1I~l" 10: wmton_aubert@admm.state.ak.us, .llm_..rcgg(~)ldmm.state.ak.us \(~ I CC: "Rossberg, R Steven" <RossbcRS@ßP.com>, "Engel, Harry R" <EngeIHR@)BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWcIlOperationsSupcrvisor@BP.eom>, "Schmoyer, AI" <SchmoyAL@BP.com>, "Mielke, Robert L." <robert.mic1kc@BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com>, "NSU, ADW WL & Completion Supervisor" <NSUAOWWL&CompletionSupcrvisor@BP.com>. "Luckett, Ely Z. (VECO)" <luckcz@BP.com>, "GPB, FSI/SIP/STP Area Mgr" <GPBFSITL@BP.com>, "GPB, FSI OS Ops Lead" <GPBFS I DSOpsLcad@BP.com>, "GPB, WeBs Opt Eng" <GPBWellsOptEng@BP.com:.>, "GPB, Prod Opt TL" <GPBProdOptTL@BP.com>, "GPB, Optimization Engr" <GPBOptimizationEngr@BP.com>, "NSlJ, AOW Well Integrity Engineer" <NSUADWWcIITntegrityEnginccr@BP.com>, "Hoffman, Wilmer" <hoffma,^,j@BP.com> Hi Jim & Winton. Well NGI-08 (PTD 1760520) is exhibiting symptoms of IA pressurization. There are 2 potential leak paths: there is a small degree of tubing head adaptor mis-alignment, and the SSSV control line does not have integrity. Objective of this work is to properly align the THA, then return the well to injection and monitor for IA repressurization. Current plans are as follows: 1. FB: L&K 2. SL: Set TIP @ 9038' MD 3. DHD: Bleed WHPs to 0 psi 4. CAM: Tighten Tbg hanger nuts to engage metal to metal seals in wellhead 5. SL: Pull TIP, POI 6. DHD: Monitor lAP BUR Attached is a wellbore schematic. Please call if you have any questions. «NGI-08.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com iCANNED DEC 1 6 Z005 Content-Description: NGI-08.pdf NGI-08.pdf . Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 11/22/2005 8:41 AM TREE = WB.LHEAD = ACTIJð. TOR = KB. ELEV = BF. ELEV- KOP= Max Ange = Datum MD = DatumìVD - ? GRAY AXELSON 47 ? 3200' 58 @ 10200' 11106' 8800' SS 13-318" CSG, 72#, MN-80, ID= 12.347" I7"TBG-NPC, 29#, L-80, 0.0371 bpf, ID= 6.184" H 8779' ITOPOF5-1/2"TBG-NPC H 8779' Minimum 10 = 3.813" @ 9038' 4-1/2" OTIS X NIPPLE 15-1/2"TBG-NPC, 17#, L-80, 0.0232 bpf, ID= 4.892" H 8975' TOP OF 4-112" lBG-NFC H 8975' TOP OF 7' LNR 4-112" lBG-NFC, 12.6#, L-80, 0.0152 bpf, ID= 3.958" 9103' NGI-08 . 2200' e I SAFETY NOTES 7' OTIS RB SSSV NIP,ID= 5.963" I I 8975' 5-1/Z' OTIS XN LA t'ÐING NIP, ID = 4.562" 5-1/2" BOT PBR ASSY 9-5/8" X 5-1/Z' BOT PKR 5-1/2" X 4-1IZ' XO 9038' 4-1/2" OTIS X NIP, ID= 3.813" 9100' 9103' 9099' 9-5/8" CSG, 47#, M\J-80, D = 8.681" PERF ORA TlON SlMMð. RY REF LOG: BHCS ON 08/06176 A NGLEA T TOP ÆRF: 53 @ 9952' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 3-318" 4 9952-10020 0 07/01/90 3-3/8" 4 10106-10209 0 05/02/87 3-3/8" 4 10225-10482 0 05/02/87 3-318" 4 10500-10525 0 10/20m 3-3/8" 4 10566-10613 0 05/01/87 3-3/8" 4 10623-10717 0 10/2Om 3-3/8" 4 10746-10766 0 05/01/87 3-318" 4 10776-10786 0 10/20/77 10727' 10727' 7' LNR, 29#, M\J-80, 0.0371 bpf, ID = 6.184" 10915' DATE REV BY COMWEN1S DATE REV BY 08/22/76 ORIGINAL CO~LETION 01/11/01 SIS-CS CONVERfEDTO CANVAS 01/29/01 SIS-LG REV IS ION 07/18/01 RNlTP CORRECTIONS COrvr.t1ENTS H4-1/Z' BOT SHE'AROUT sæ 4-1IZ' TUBING TAIL H ELMDTTLOGGBJ 12/14/76 I PRUDHOE BA Y UNrr WELL: NGI-08 ÆRIItfT No: 76-052 API lib: 50-029-20219-00 Sa:; 12, TlIN, R14E 4244.42 FB. 829.04 FNL BP Exploration (Alaska) -, 'I, ; MEMORANDUM TO: Jim Regg V 0{21 ~ P.I. Supervisor I ~ ~ I '10:> FROM: John Crisp Petroleum Inspector Well Name: PRUDHOE BAY UNIT NGI-08 Insp Num: mitJCr050825113850 Rei Insp Num Packer Well. NGI-08 IType Inj~-l G _II TVD I p~i---r 17~0:_2_~_ J!ype_T ~~! 1_ SPT _L ! e_st p~ J _Jm~rval 4YRTST P/F P Notes 2 bbls pumped for pressure test Tuesday, August 30, 2005 State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 30,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NGI-08 PRUDHOE BAY UNIT NGI-08 Src: Inspector NON-CONFIDENTIAL API Well Number 50-029-20219-00-00 Permit Number: 176-052-0 Depth Pretest Initial 2200 . lo~ 05d- \1' Reviewed By: P.I. Suprv :jlP,,- Comm Inspector Name: John Crisp Inspection Date: 8/23/2005 15 Min. 30 Min. 45 Min. 60 Min. ¡------ - i "-'-¡- I 1-- ,--~--- I IA I 1::~~5m_-~-- I ~50 ~~~gt 75 3600 2200 ! 2220 h"_ --,--iSi----7-Š--- ----- I 3600 r"- 3600--1- , -' ì' ~ 1¡[\r~T-' '~~f~-~tJl'~ ,J L" :)E';:: ~:\ l t (,~~5 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser Commissioner THRU: Tom Maunder P.I. Supervisor FROM: Jeff Jones Petroleum Inspector DATE: August 20, 2001 SUBJECT: Mechanical Integrity Tests BPX NGI Pad NGI-06, 07, 08, 10, 12 PBU PBF NON- CONFIDENTIAL I Packer Depth Pretest Initial 15 Min. 30 Min. wellI NGI~ ITypelnj. I G I T.V.D. I 7426. I Tubir~'!'.3450 '1 345o I 34,~o I 345o I~.t~.,I 4' I P'T'D'I 1760_~90ITXpe: I P IT'll s857'lcaSin~l 64o I 20~0 1.2000 I 2000 I P": I e I__1~,~,____- Pre-test pre~__,_,res monitored 30 minutes & stable... WellI NGI-07 ITvp~.i.I G I T.V.D. 17308 I Tu~,.~l 330O133OOI 33o0133oo I,nt--- l 4 P.T.D.I 1760----~-ITxp. t.-tl P IT~p~"I ~o Ic~,n~l 8o I 20~0 I 20~.0 I 20~0 I P/F IE I __1~,~__- Pre-test monitored 30 minutes & stable. 1770810 Pre-test p _re~_~res monitored 30 minutes & stable. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Monday~ Amtust 20, 2001: I traveled to BPX's NGI Pad to witness 4 year MIT's on wells NGI-06, NGI-07, NGI-08, NGI-10 and NGI-12. Scott Lyon (BPX representative) performed the tests today. The pre-test pressures were monitored for 30 minutes and observed to be stable. All five wells passed the MIT's and are suitable for continued injection. Summary: I witnessed 5 successful MIT's at BPX's NGI Pad in the Prudhoe Bay Field. MI.T.'s performed: _5 Number of Failures: -5 Total Time during tests: $.$ bm. Attachments: cc: MIT report form 5/12/00 L.G. MIT PBU NGI-06,07,08,10,12 8-20-01 JJ.xls 8/27/01 STATE OF ALASKA ALASKA . AND GAS CONSERVATION CC 41SSION R E Po_ Or , ,TTu,i nF___sUNDRY -;- WELL --O P E 1. Operations performed: Pull tubing ..--- Alter casing ..--. Repair well 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Development Exploratory Stratigraphic /4/41 6. Datum of olevation(DFgr KB) .,~ 47 RKB "? ,., feet 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 98' FNL & 965' FWL, Sec. 12, T11N, R14E, UM At top of productive interval 710' FNL & 1662' FWL, Sec. 11, T11 N, R14E, UM At effective depth 690' FNL & 1071' FWL, Sec. 11, T11 N, R14E, UM At total depth 684' FNL & 985' FWL, Sec. 11, T11N, R14E, UM 5. Type of Well 8. Well number NGI-8 9. Permit number/approval number 76-52 10. APl number 50 - 029-20219 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10925 feet Plugs(measured) 8676 feet Effective depth: measured 10820 feet true vertical 8615 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 76' 20" Cement to Surface 100' 100' Surface 2671' 13-3/8" 4000 sx Permafrost II 2695' 2695' Production 9398' 9-5/8" 750 sx Class G Cement 9422' 7770' Liner 1820' 7" 375 sx Class G 9095-10915' 7526-8670' Perforation depth: measured 9952-10020'; 10106-10209'; 10225-10482'; 10500-10525'; 10566-10613'; 10623-10717'; 10746-10766'; 10776-10786' true vertical 8135-8176'; 8226-8281'; 8289-8424'; 8435-8449'; 8472-8498'; 8504-8556'; 8573-8584'; 8590-8595' Tubing (size, grade, and measured depth) 7", 29#, L-80, NPCT @ 8779'MD; 5-1/2", 17#, L-80, NPCT @ 8957' MD; 4-1/2", 12.6#, C-75, NPCT @ 9103'MD Packers and SSSV (type and measured depth) BeT Packer @ 8929' MD; 7" Otis RB sss~@'-2~00 M 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Reoresentative Daily Ayera0e Produqtion or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation -- 90 MMcfpd ? .... 3750 Subsequent to operation 176 MMcfpd ~' -- -- 3652 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas Suspended Service [ ~ Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic~ned Title Engineering Supervisor Form 10-404 Rev 06/15/88 dA-/I'~A k"l::lC' ~,r,. _O.W _IWP Date SUBMIT IN DUPLICATE NGI-8 DESCRIPTION OF WORK COMPLETED CTU FILL CLEANOUT & DIESEL / XYLENE / HCL WASH 10/8/92: MIRU CT & PT equipment. Loaded wellbore w/400 bbls Seawater, then RIH w/CT & jetted fill encountered at 10406' MD, for wellbore cleanout, while reciprocating a Diesel/Xylene/HCL acid wash across the perforation intervals at: 9952 - 10106 - 10225 - 10500 - 10566 - 10623 - 10746 - 10776 - 10020' MD (Sag) 10209' MD (Z4) 10482' MD (Z4,3,2) 10525' MD (Z2) 10613' MD (Z2) 10717' MD (Z2,1B) 10766' MD (Z1B) 10786' MD (Z1B) Ref. Log: BHCS 8/6/76. Jetted 250 bbls 75% Diesel/25% Xylene at maximum CTU rate, followed by 250 bbls 15% HCL, while maintaining Seawater injection on CT x 7" annulus throughout the treatment, to displace dissolved fill & solids to the formation. Pumped an additional 50 bbls of Seawater for complete displacement following acid. POOH w/CT. Rigged down. Returned the well to gas injection & obtained a valid injection rate. STATE OF ALASKA ALASKA'-~LAND GAS CONSERVATION CC MISSION REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X ~, , Pull tubing Alter casing -- Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 98' FNL& 965' FWL, Sec. 12, T11N, R14E, UM At top of productive interval 710' FNL& 1662' FWL, Sec. 11, T11N, R14E, UM At effective depth 690' FNL & 1071' FWL, Sec. 11, T11 N, R14E, UM At total depth 684' FNL & 985' FWL, Sec. 11, T11N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic . Service X 6. Datum of elevation(DF or KB) 47 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-8 9. Permit number/approval number 76-52/90-300 10. APl number 50 - 029-20219 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10925 feet 8676 feet Plugs(measured) 10820' - Cement Effective depth: measured 10820 feet true vertical 8615 feet ~'±].1. (measured) 10406 Casing Length Size Cemented Measured depth True vertical depth Conductor 76' 20" Cement to sudace 100' 100' Sudace 2671' 13-3/8" 4000 sx Permafrost II 2695' 2695' Production 9398' 9-5/8" 750 sx Class G Cement 9422' 7770' Liner 1820' 7" 375 sx 9095-10915' 7526-8670' Perforation depth: measured 9952-10020'; 10106-10209'; 10225-10482'; 10500-10525'; 10566-10613'; 10623-10717'; 10746-10766'; 10776-10786' true vertical 8135-8176'; 8226-8281'; 8289-8424'; 8435-8449'; 8472-8498'; 8504-8556'; 8573-8584'; 8590-8595' Tubing (size, grade, and measured depth) 7", 29#, L-80, ABMOD LT&C @ 8779' MD 5-1/2", 17#, L-80, ABMOD 8rd @ 8779'-8957' MD 4-1/2", 12.75#, C-75 CS-CB Hydril, 8957'-9103' MD Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker SAB Packer @ 8963' MD/Otis RB Ball Valve @ 2200' MD 13. Stimulation or cement squeeze summary REC~-.IVEP 14. Intervals treated(measured) ~'~" Treatment description including volumes used and final pressure '~... ~ · Representative Daily Averaoe Produ~ion or Ini~tion Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tub±ng Pressure - - 202M .... 3900 217M .... 390O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Gas Injection 17. I hereby certify th~t~e foregoing is true and correct to the best of my knowledge. Signed Y ~/~~, ~//~~ Title Senior Area Engineer Form 1 4 Rev 06/15/88 ( NGI-8 Work Summary Qn July 2, 1990 the following perforations were added in Well NGI-8. Interval, MD (BHCS 08/06/76) Interval Length Formation Name SPF 9952-1 0020' 68' Sag River 4 STATE OF ALASKA ~--~- ALASKA OIL AND GAS CONSERVATION COIV, .... SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well REVISED* OIL [~1 GAS ~ SUSPENDED r"-'l ABANDONED [--'1 SERVICE [~ GAS INJECTION 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 76-52 · 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20219 4 Location of well at surface 9 Unit or Lease Name 98' FNL, 965' FWL, SEC 12, T11N, R14E UM *LOCATIONS CHANGED DUE TO PRUDHOE BAY UNIT At Top Producing Interval GYRO SURVEYS BEING RERUN. lO Well Number 844' FNL, 1723' FWL, SEC 11, T11N, R14E UM* NGI-8 At Total Depth 11 Field and Pool 830'FNL, 1034'FWL, SEC 11, T11 N, R14E UM* PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL RKB 47'I ADL 28302 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 116 No. of Completions 07/16/76. 08/08/76. 08/22/76**I N/A feet MSLI 1 , 17 Total Deplh (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 10925' MD/8704' TVD 10820' MD/8643' TVD YES ~ NO I~1I 2200' feet MDI 1900' (approx) 22 Type Electric or Other Logs Run DIL, SONIC, FDC/CNL, GR/CCL, CBL/VDL, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 SURF 110' 32" 240 SX AS CMT 13-3/8" 72.0# MN-80 SURF 2695' 17-1/2" 4000 SX PF II 9-5/8" 47.0# MN-80/S-95 SURF 9422' 12-1/4" 750 SX CLASS G & 275 SX PF 'C' 7" 29.0# MN-80 9095' 10915' 8-1/2" 375 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10106'-10209'MD/8249'-8305'TVD W/4 SPF 7" / 5-1/2" / 4-1/2" 9103' 8963' 10225'-10482'MD/8313'-8451q'VD W/4 SPF 10500'-10525'MD/8461'-8475'TVD W/4 SPF 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 10566'-10613'MD/8498'-8525'TVD W/4 SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10623'-10717'MD/8530'-8585'TVD W/4 SPF N/A 10746'- 10766'MD/8601'-8613'TVD W/4 SPF 10776'-10786'MD/8618'-8624'TVD W/4 SPF 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 10/27/77. I INJECTION ON 7" TBG WITH PACKER Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I 10/26-27/77 24 TEST PERIOD ,,~ 14,770 MSCF/D Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. - 24-HOUR RATE ~ 4,770 MSCF/D 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. **NOTE: PERFORATED WELL 1121177, 10120177, 5II/87. RECOMPLETED WELL 12/15/76. '~, ~ ~.~88 Form 10-407 Submit in duplicate Rev. 7-1-80 CC~TINUED ON REVERSE SIDE ARCO ALAS'KA., INC~ P.O. BOX i ANCHORA(;E, ALA R E F:' E R E N C E ' A R C 0 C A 5.' E i'D H 0 L EL F' l N A L. NE.;!-3 6'-29-9(~, N(..'; 1-4 6 .... 29-9g, N[;i .... 6 6-3(3-9(.) N !]- I - 7 7 - i -- 9 NGI--8 7-i - 9 t:.~ NGI.-9 7--2.-9,::':, N C; I .... i ,3 7-- 4- 9':::, C 0 L I... A R ,," F:' iE 1:;.: F' C: 0 L L A I;.'. ,.'"' t-'-" F R 1:: C O L f... A R /P E R F C: ') L L A R .," F' E !';..' i'" C 0 I_ t_ A F;..' ," F' E R F' C OI...L AR/F' F'F,.~F C 0 t... L A R/F:' E R I:: (20 L L A i:;.: /F:' IE F;..' I:'" . C: 0 L. L ~ R /i-'E R F: OF- )}AI'A, t-tA;.,"E A NICE DAY! ;'-"-:A L L. Y H, OFFECKER ATO- i 529 A 'i'l_ A,¥ All_A::? ,A T' L. A ,':~ 'i I_ P, :!.? ¥' I ~..:'~ ici ~ L.I..I ,::. A 'i'l_ A ,'",':' A 'F LA.~i: A 'FLA£ '() 1:7 T R I B U 7' I 0 N F':iEN TI-;..'Ai_ F l I_tE~2 "- F:HF'VRriN D '~ M ": ..' 'l -- '~ .~. "' · il: EXTEN::TiON E.,-t. FI..UR~-,I ION · $ EXXON MARATHON · ~ MOBIL · ¢ F'HILL I F'~: F'B WELL_ F]:L..iEZ F',' & D ~'~ BPX :~ ~.'TATE OF ALA;:71<A STATE OF ALASKA ALASF'~-' ')IL AND GAS CONSERVATION ~ -"~S~lt~ ]~ [ APPLICATION FOR SUNDRY A PROVALS 1. Type of Request: Abandon Suspend Operation shutdown -- Alter casing Repair well Plugging Change approved program Pull tubing Variance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 98' FNL& 965' FWL, Sec. 12, T11N, R14E, UM At top of productive interval 710' FNL & 1662' FWL, Sec. 11, T11N, R14E, UM At effective depth 690' FNL & 1071' FWL, Sec. 11, T11N, R14E, UM At total depth 684' FNL & 985' FWL, Sec. 11, T11N, R14E, UM 5. Type of Well Development .. Exploratory Stratigraphic Service X Re-enter suspended well Time extension Stimulate Perforate X Other 6. Datum of elevation(DF or KB) 47 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number NGI-8 9. Permit number 76-52 10. APl number 50 - 029-20219 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 76' Sudace 2671' Production 9398' Liner 1820' 10925 feet 8676 feet Plugs(measured) 10820'-Cemeni'' !"', i,'i : 10820 feet 8615 feet Junk(measured) None Size Cemented 20" Cement to sudace 13-3/8" 4000 sx Permafrost II 9-5/8" 750 sx Class G Cement 7" 375 sx Measured d~pi~hor~J'4~e vertical depth 100' 100' 2695' 2695' 9422' 7770' 9095-10915' 7526-8670' Perforation depth: measured 10106-10209'; 10225-10482'; 10500-10525'; 10566-10613'; 10623-10717'; 10746-10766'; 10776-10786' true vertical 8226-8281'; 8289-8424'; 8435-8449'; 8472-8498'; 8504-8556'; 8573-8584'; 8590-8595' Tubing (size, grade, and measured depth) 7", 29#, L-80, ABMOD LT&C @ 8779' MD 5-1/2", 17#, L-80 ABMOD 8rd @ 8779'-8957' MD 4-1/2", 12.75#, C-75 CS-CB Hydril, 8957'-9103' MD Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker SAB Packer @ 8963' MD/Otis RB Ball Valve @ 2200' MD 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation May 1990 16. If proposal was verbally approved Name of approver Date approved Service gas injection well 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '_~~~/~~ Title Operations Engineering Manager FOR COMMI~II3N IJ~E t3NLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- 1~,.y 15. Status of well classification as: Oil . Gas Suspended Date Approved by order of the Commissioner Original 3tgned By David W. ,Jghn~t~r~ Form 10-403 Rev 06/15/88 Comm. is,,sioner Approve(] ~u¢~ Returned Date ,~'- ~ -~::~ ~) SUBMIT IN TRIPLICATE NGI-8 Proposed Additional Perforations ARCO Alaska, Inc. proposes to add perforations in Well NGI-8. The proposed perforation intervals are as follows: Interval, MD Interval, MD Interval Formation (BHCS 8/6/76) (Tie-in) Length Name 9952-10020' 9952-10020' 68' Sag River A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. All perforations will be made with the wellbore loaded with sea water. After perforating, gas injection will resume with the wellbore load fluid being displaced into the wellbore formation. No flaring is anticipated. ARCO ALAYKA, INC. P.O. BOX ANCHORAGE, ALASKA 995i0 DATE· t0-9-89 REFERENCE' ARCO CASED HOLE FINALS t-7 9-27-89 F'ERF RECORD RUN i-22 9-2'7-89 PERF RECORD RUN 5-2t 9-30-89 CB]' RUN 7-23 9-2~-89 PIT~ RUN 9-24 9-24-89 LEAK DETECTION RUN tt-8 9/24-25/89 INJECTION PROFILE RUN tt-9 i(~-t-89 PERF RECORD RUN t4-25 9-23-89 INJECTION PROFILE RUN ~4-27 9-2S-89 INJECTION PROFILE RUN ~4-S2 9-~0-89 LEAK DETECT ION--REV~ RUN ~7-5 9-25-89 F'RODUCTION PROFILE RUN ~8-24 9-28-89 COMPLETION RECORD RUN NGI-~ 9-28-89 INJECTION PROFILE RUN NGI-8 9-29-89 INJECTION PROFILE RUN PI_EASE SIGN AND RETURN THE ATTACHED COPY AS' RECEIF'T OF DATA RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO- i 529 DISTRIBUTION .L ,,- CENTRAL FILES ~' F'I-tI LL IF'S '"' PB WELl.. F']:LE:£' .,- CHEVRON D & M R & D ~ EXTENSION EXPLORATION $ BPX ~ EXXON ~ STATE OF ALASKA MARATHON $ TEXACO ~ MOBIL SCH '2CH SCH CAMCO CAMCO (]AMC(] S C H CAMCO [)AMC(] CANCO [)ANCO SCH 5'CH SCH . THE CORRECTED AF'I~ FOF,' ii--9 IS DATF',.m-t-RE RFFEREN£E' ARCO RASED Hill F F~N~I.. '~ 4-i ? A-,?.C"-R7 --.4-t ''>,._ 6-'20-R7 ~' 5-i G R-t ~-R7 ~7-1 t R-ia-R7 ~ t ~--2t~ .F]-,.'?4-R7 ~N .F, T- t 5-4-R7 "~ NF. T -) 5-~-,.q7 '-~Ng 'r -6, 5- P-- R 7 ~ NF,]'-i t 5-~°-R7. ,. ~ NF-T-t':' %_'":,-z % NOT-t 4 ...... · .% ~ W C, .ll - ,..'2.. 5:-"~ ~'- P, 7 ,:_ .... COl .I nf]l. I. p, nl_l nnl. l. COl .... cci... p, rll.. cci... l.',fll ...... nnl. C ii ! .... .C. f'll . CEll .I AR'/F'FRFF1RAT T lIN AR' (F'AEKFR) A R' AR/F'FRFF1RTTRN AR/F'FRF[]RATT ON AR'/F'FRFF~R'AT T AR/PFR'F'FIRAT .T F1N Ali' / F'F RF'F~R'A T T FIN AR/F'ERFOR~TTON AK' / F'E R'F R K'A T T.flN AIT/F'ER'FRR'ATTON AR' ./F'F R'F FICA T T Al-;'./F'FR'FF~RA T T COl.. I. AR'/F'FRFFllTATTON EI]l..I. AF,'/F'ER'F ORA T .T. t,.Ig I - 4 ..5-25-87 /I CFl, J~.. A R' / P F F;'F F1R A T T F1N PI.EASE SIF;N AND 17 - E.-.I) 5;' -~. :--£: L ./ .,_-~ ~ HAVE A p... ,, ...... a,,¢-,-fame NT....E~ ! ......... A." ..... · F' E". F- G Y BENNETT ATO-~ ~oc) ..'" z:.. · ]"F: A NI?, ..-8~ O~'',: AF'F'ROVED D 1' .?TR' T RI .IT T ON RI-T. CF.T.F'T ~F DATA, DRFSSFF-< I) F--,,' F .~ .~' I: R' I)RF~.~FR' 'D R F X'.S' F R' f) P F 5' X' F P DRF.~.~FR T) Fi.' F ..? .*7.. F Iq-: 1~ R' F.~.? F. F< 15 R' IE' .? X' I: Fi' B Fe F.~.? F F.' DR F .~ sJ F g: - CENTRAl_ F]'I.E*'' "-,,- CFtF'VR'nN. ,~ EXTFN,'.'7 T ON F'X'F'I...FIRA T T ON ~ E X Y. Fi ?4 NAR'A TIqi-IN '"-.~ fdF~R T_ I._ F'H TI.. I... T F'~ F'P, WFI..I F-TI. .~A F'[: -.- ,.~TAI'F F1F AI..ASKA TFWAEF1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM,,,iSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska~ ]:nc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 98' FNL & 965' FWL, Sec. 12, T11N, R14E, UM 5. Datum elevation (DF or KB) 47' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-8 (21-11-11-14) At top of productive interval 709' FNL & 1670' FWL, Sec. At effective depth 693' FNL & 1115' FWL, Sec. At total depth 684' FNL & 985' FWL, Sec. 11, T11N, R14E, UM 11, T11N R14E, UM 11, T11N, R14E, UM 8. Approval number 7-224 9. APl number 50-- 029-20219 10. Pool Sadlerochit 11. Present well condition summary Total depth: measured true vertical 10925 feet 8676 feet Effective depth: measured 10767 true vertical 8585 Casing Length Size Conductor 76' 20" Surface 2671' 13-3/8" Production 9398' 9-5/8" Liner 1820' 7" Plugs (measured) feet Junk (measured) feet 10820' - Cement 10767' - Fill Cemented Measured depth Cement to surface 100' 4000 sx Permafrost II 2695' 750 sx Class G Cement 9422' 375 sx 9095-10915' ~ue Vertical depth 100' 2695' 7770' 7526-8670' Perforation depth: measured 10106-10209' 10225-10482' 10500-10525' 10566-10613' 10623-10717' 10746-10766' 10776-10786' true vertical 8226-8281' 8289-8424' 8435-8449' 8472-8498' 8504-8556' 8573-8584'' , 8590-8595'' ' ' ' ~bing (size, grade and measured depth) 7" ~ 5~~ 29#, L ABMOD LT&C @ 8779'MD - 17# ~ ABMOD 8rd @ 8779'-8957'MD 4["~ 12.~5#, C-75 CS-CB Hydril, 8957' - 9103'MD Packers and SSSV (type and measured depth) 9-5/8" x 7" Baker SAB Packer Fa 8963'MD/Otis RB Ball Valve Fa 2200'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure -- 156353 .... 3795 183537 .... 3756 5/1/87 5/11/87 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run F3 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~!/---/' -(~'-(~? Form 10-404 Rev. 12-1-85 Title Oper. Engr. Mgr. MRO (265-6810) Date ~//~k~ Submit in Dupli.cate NGI-8 DAILY OPERATIONS REPORT ADD PERFORATIONS 4/30/87 PT lower BOPs, upper BOPs and lub to 4000 psi. OK Pulled SSSV PT lub to 4000 psi. OK RIH w/3-3/8" dummy gun, TTL & bailer Could not get past 9124'. POOH PT lub to 4000 psi. OK RIH w/3.25" GR & TTL Could not get past 9158'. POOH PT hardline to 4500 psi. OK Pump in xylene wash w/methanol SD for 40 min. soak time 511187 Displace xylene w/ 60/40 methanol/water displacement PT Rams to 4000 psi, lub to 3500 psi, harlding to 4000 psi. OK RIH w/3-3/8" x 20' dummy gun Tagged PBTD @ 10749'. POOH RIH w/gun #1, 3-3/8" x 24', 4 SPF @ 120° phasing Perf 10643 -10661' and 10446'-10452' POOH - all shots fired RIH w/gun #2, 3-3/8" x 20 , 4 SPF @ 120° phasing Perf 10597 -10613' and 10386'-10390' POOH - all shots fired RIH w/gun #3, 3-3/8" x 26 , 4 SPF @ 120° phasing Perf 10420 -10446' POOH - all shots fired RIH w/gun #4, 3-3/8" x 26 , 4 SPF @ 120° phasing Perf 10360 -10386' POOH - all shots fired RIH w/gun #5, 3-3/8" x 25 , 4 SPF @ 120° phasing Perf 10315 -10330' and 10280'-10290' POOH - all shots fired RIH w/gun #6, 3-3/8" x 20 , 4 SPF @ 120° phasing Perf 10275 -10280' and 10235'-10250' POOH - all shots fired RIH w/gun #7, 3-3/8" x 25 , 4 SPF @ 120° phasing Perf 10681 -10697' and 10106'-10115' POOH - all shots fired RIH w/gun #8, 3-3/8" x 20 , 4 SPF @ 120° phasing Perf 10566 -10572' and 10180'-10194' POOH - all shots fired RIH w/gun #9, 3-3/8" x 20 , 4 SPF @ 120° phasing Perf 10746 -10766' POOH - all shots fired 5/2/87 RIH w/gun #10, 3-3/8" x 15', 4 SPF @ 120° phasing Perf 10150'-10165' POOH - all shots fired PT BOPs & lub to 4000 psi. OK Set SSSV @ 2176' POOH RD STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COM~,..,¢SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend E] Operation Shutdown [] Re-enter suspended well E] Alter casing Iii Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing E] Amend order [] Perforate J~ Other 2. Name of Operator ARO(3 Alm.qka, Thc,. 3. Address Post Office Box 100360~ Anchorage~ AK 99510 4. Location of well at surface 98' FNL & 965' FWL~ Sec. 12, TllN, R14E, UM At top of productive interval 710' FNL & 1662' FWL, Sec. 11, TllN~ R14E, UM At effective depth 690' FNL & 1071' FWL, Sec. 11, TllN R14E, UM At total depth 684' FNL & 985' FWL~ Sec. 11~ TllN~ R14E~ UM 5. Datum elevation (DF or KB) b7 ' RWB 6. Unit or Property name Prudhoe Bay Unit 7. Well number NGI-8 (21-11-11-14) 8. Permit number 9. APl number 10. Pool Sadlerochit 11. Present well condition summary Total depth: measured true vertical 10925 feet 8676 feet Plugs (measured) 10820' - Cememt Effective depth: measured 10820 true vertical 8615, Casing Length Size ~ue Verticaldepth Conductor 76' 20" 100' Surface 2671' 13-3/8" 2695' Production 9398' 9-5/8" 7770' Liner 1820' 7" 7526-8670' feet Junk (measured) None feet , Cemented Measured depth Cement to surface 100' 4000 sx Permafrost II 2695' 750 sx Class G Cement 9422' 375 sx 9095-10915' Perforation depth: measured 10115-10150' , 10165-10180' , 10194-10209' , 10225-10235' 10250-10275',10290-10315' , 10330-10360' , 10390-10420' 10452-10482' 10500-105~5' , 10572-10597', 10623-10643', 10661-10681'~ 10697-10717'~ 10776-10786'~ true vertical 8230-8249', 8257-8265', 8273-8281', 8289-8294', 8302'-8315', 8323-8336' , 8344-8360' , 8376-8392' , 8409-8425' , 8435-8449' , 8475-8489' , 8504-8515' , 8525-8536' , 8545-8556' , 8590-8595' Tubing (size, grade and measured depth) 7", 29#, L.-80 ABMOD LT&C @ 8779'MD 5t~", 17#,~-84 ABMOD 8rd @ 8779'-8957'MD Packers and SSSV(type and measured depth) 4½", 12 .75#, C-.75 CS-CB Hydril, 8957' - 9103'MD 9-5/8" x 7" Baker SAB Packer @ 8963'MD/Otis RB Ball V~lv¢ @ 2200'MD 12.Attachments Description summary of proposal [] Detailed operations program [TJ BOP sketch ~ 13. Estimated date for commencing operation May, 1987 14. If proposal was verbally approved Name of a'pprover Date approved 15. I hereby~rtify thatth~for~oin~is true and correct to the best of my knowledge ~(z_~~~~~.~l/~//I/// Title Operations Engineering Manager Signed Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I ~,~,pp ro veo C. ~.~ '.,' Approved by Commissioner by order of the commission Date ~-- ~'-j~ Submit in triplicate Form 10-403 Rev 12-1-85 H~O (265-6810) NGI-8 Proposed Additional Perforations ARCO Alaska Inc. proposes to add perforations within the Sadlerochit interval in Well NGI-8. The proposed perforation intervals are as follows: Existing Perforations 10115-10150 (35') 10165-10180 (15') 10194-10209 (15') 10225-10235 (10') 10250-10275 (25') 10290-10315 (25') 10330-10360 (30') 10390-10420 (30') 10452-10482 (30') 10500-10525 (25) 10572-10597 (25) 10623-10643 (20) 10661-10681 (20) 10697-10717 (20) 10776-10786 (10) TOTAL = 335' Proposed Perforations 10106-10115 (9') 10150-10165 (15') 10180-10186 (6') 10190-10194 (4') 10242-10250 (8') 10315-10330 (15') 10375-10390 (15') 10420-10452 (32') 10566-10572 ( 6 ) 10597-10613 (16) 10643-10661 (18) 10681-10697 (16) 10746-10771 (25) 10786-10804 (18) TOTAL = 203' Reference BHCS of 8/6/76 A 5000 psi WP wireline lubricator, tested to working pressure will be utilized for this work. All perforations will be made with hollow carrier type guns at 4 shots per foot. All perforations will be made with an appropriate fluid, the perforating performed, and gas injection resumed with the wellbore load fluid being displaced into the wellbore formation. No flaring is anticipated. WELL: SURFACE LOCATION: BOTTOm4 HOLE LOCATION: ' · ORIGINAL RKB: TOP OF SADLEROCHIT: ALL DEPTHS ,ARE RKB MD Depths are to TO___~P of equipment NGI #8 --- SPUD DATE: 7/16/76 98'S & 965'E of NW cr. ~c. 12, TllN, R14C, UM 684'S & 985'E of NW cr. Sec. ll, TI!N, RI4E, UM 47' RKB TO Gray HANGER 24' 10098 ' MD AVERAGE HOLE ANGLE: 48o MAXIMUM ANGLE: 59o @ 10200' ANGLE AT TD: 54o ANNULUS FLUID: 10.8 ppg CaC12 L 82' 20" 94# H-40 Vetco (19.124" ID) 2200' Otis RB Ball Valve Landing Nipple (5.963" ID) 2346' .Bottom of 9-5/8", 47#, SOC-SS DTC {8.581" 2367' 9-5/8" FO ~2493' 9-5/8" FO 2695' 13-3/8", 72#, MN-80 BTC (12.347" ID) w/ 4000 sx 8779' 8814' 8918' 8929' 8957' 8963' 8975' 9038' 9095' 7", 29#, L-80 ABMOD LT&C (6.184" ID) Otis XA Sliding Sleeve (4.562" ID) Otis XN Landing Nipple (4.562" ID w/ 4.455" No-Go) BOT PBR Assembly Bottom of 5½", I7#, L-80 ABMOD 8rd (4.892" ID) 9-5/8" x 7" Baker SA8 Packer 4%" XO Otis X Landing Nipple (3.813" ID w/ 3.725" No-Go) Top of Liner, BOT MC Hanger 9103' Bottom of 4½", 12.75#, C-75 CS-CB Hydril Tubing Tail (3.958" ID) 9424' 9-5/8", 47#, MN-80 BTC (8.681" ID) w/ 750 sx 10115 10165 10194 10225 10250 10290 103~0 10390 10452 10500 10572 10623 10661 10697 10776 10150' 10180' 10209' 10235 10275 10315 10360 10420 10482 10525 10507 106¢3 10681 10717 10786 WORKOVER-STIHULATION 12/76 Well recompleted for gas injection .... and to replace 13-3/8" x 9-5/8" casing ~ackoff. 10820' PBTD 10915' 7", 29#, MN-80 BTC (6.814" ID) w/ 375 sx 10925' TD 1/84 ii III II I I II iii i i iiiii 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PS! 4 1/6" FLOW TUBE PACK-OFF H I REL I NE BOP EOU I PMENT North Alaska District th~_!gineering T RAN S M I T TA I,' .: Tra.smittea herewith are t~e f61iowing for the subject we. ii-' Run No.. -. .'. '-.. .... Scale' . Xerox -. - . BHC Sonic/Ca!ipe~ Log ' . ..... BHC Sonic/Caliper - G~a Ray Log ' ........ BHC Sonic/G~ma ~Y Log .... Caliper/CCL . . ... .. .' ~ Cement Bond L0g~L" -. -' ~-Condenser.eR Formation ~nsity Ldg' Compensated Neutron-Fo~ation Dans%ty~ '- Compe~ateR Neutron Log. . Core ~alysis - Inte~al . . ...... - · Core' Core ~gscription {SWC) - Inte~al ' ' .Core Description '(Cony.) - Core No.' ~' ~-- Directional Su~ey...- ~ro' · ..... Single Shot ' · '. ~hltishot Drill Stem ~est - Test No. -Peat Induction' Laterolog. .-- Fo~atio~ Density Log ' ' Fo~ation Density Log/G~a Ray- :. ~ Gm~a t~z/CCL . '"~ r~ ~i ~-'~¢ ~- ~-~ . Laterolog ' ~(~ '[ ~ ~' '- ·. . . Location Plat '" " j~it~ 3 't: . 1,'[crolaterolog .... . Microlog ' ' . Senile Log (A.R. Co~ - Intewa~ ~'~'~'~=" - ...... · Synergetic Log' -- ~TD-I)IL .:.r . ~D-Porosity ~g.' '.' - ro . Recd:ipt Acknoi~lcdgefl tbr' Date: Please return receipt to' By' 6t}~tic Pfichfield Company N+6rth Alaska Engineering P. O. Box 360 . . - . Office ~3~x Telephone 987 277 November 8, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' NGI #8 (21-11-11-14) Permit No. 76-52 Dear Si r' Enclosed please find our Sundry Notice of Subsequent Report along with the Well Completion Report detailing the work done on the above-mentioned well. Very truly yours, ~ ~ .~*~ ..... ~-~ ,;~ .,¢,~'~i~-~'} F. M. Brown District Drilling Engineer /am Enclosures Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. O~L l--1 GAS N Gas Injection WELLI I WELLi i OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 5. APl NUMERICAL CODE 50-029-20219 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P.O. Box 360; Anchorage, Alaska 99510 NGI #8 (21-11-11-14) 4. LOCATION OF WELL At Surface -. 98'S & 965'E 13. 14. of NW cr Sec. 12, T11N, R14E, UM 10. FIELD AND POOL, OR WILDCAT ~rudhoe Bay Field-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 11, T11N, R14E, UN ELEVATIONS (Show whether DF, RT, GR, etc.) 18.4' Gravel Pad Check Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ ~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) 12. PERMIT NO. 76-52 3ort, or Other Data SUBSEQUENT REPORT OF: PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS WATER SHUT-OFF FRACTURE TREATMENT SNOOTING OR ACIDIZING (Other) REPAIRING WELL ALTERING CASING ABANDONMENT* Perforate (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent ~letalls, and give pertinent dates, Including estimated date of starting any proposed work. Beg.an perf. operations 10/20/77. Tstd tree, csg & wireline BOP's. Pulled ball valve. Perf'd intervals 10,587'-~', 10-~5~72'-10,587', 10,510'-~, ~' 10,510', 10,472'-~, 10,472'-~', ,1.CL~d~j~'-lO,400', 10,400'-10,390', 10,360'-10,350', ~-10,35'0~, 10,300'-~~,~-10,300', 10,265'-~Z5',~50'-10,265', 10,225'-10,235', 10,194'-10,209', 10',165'-10~80', 10,135'JI~),1~(~-~, 10~-10,135' wit~-~-4 sh6ts ~er foot.---;--Ran ~*~et bal~'~alve. "~Tstd balance & control 1Tn-~s to 5000 psi OK. Bled press above ball valve to 0 psi, held OK. Installed & tstd tree cap to 5000 psi OK. ,Released well to Production Dept' 10/26/77. 16. I hereby certify that the foregoing is true and correct District Drlg Engineer SIGNED TITLE DATE 11/8/77 (This space for State office use) APPROVED BY . CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side SUBMIT IN DU~'~/C.a rE* " STATE OF ALASKA (See other st ructions on reverse side) OIL AND GAS CONSERVATION COhIMITTEE III I I I I II WELk COMPLETION OR RECOMPLETION REPORT AND LOG* II ~ I 1~. TYPE OF ~'ELL: " Oll,,v ELL ~ GABi,rE,.L ~i D~ ~Other _GaInjection b. TYPE OF COMPLE~ON: NEW ~] Wi)~,( ~ DEEP- ~ F'I. UG ~ DIFF. ~ Pe X~ EI,I, ~VER ~ EN ~ BACK RESVR. Other r NAME ()P OPER^'roR ^tl anti c Ri chfi el d .Company AI)DRES~q OF OPERATOR P.0. Box 360, Anchorage, AK 99510 4. i,oc,,.riox oF W~:LL (Report location clearly and in accordance with any State requirements)* At sorface 98'S & 965'[ of NW cr Sec. 12, IllN, R14[, UM At t.p prod, Interval reported below 710'S & 1675'[ of NW cr Sec. 11, IllN, R14[, UM At total depth 684'S & 985'E of NW cr Sec. 11, IllN, R14E, UM 1:! l);'k'i~t:; S}'UIIDED 7/16/76 10925'MD, 8676'TVD ]10,820'MD (8623'TV~) Single '"2. PII. ODUCING !NT'EHVAL(S~. OF ~IS COMP~TION~TOP, BOSOM, NAME (MD AND ~)~ 10,098'MD, 8222'~VD - Top Sadlerochit 10,734'MD, 8566'TVD - Bottom Sad]erochSt 5. API N~CAL CODE 50-029-20219 ~. h~-~sr/O,~SmNX4nOr~ m'~D s~nr~n >~o. ADh-28302 7.IF INDIikN, ALLOTTEE OR TRIBE NAME 8.UNIT,FAT/iVI OR LE~kSE NAME Prudhoe Bay Unit 9. WELL NO. NGI #8 (21-11-11-14) 10. FIELD AND POOL, OR WILDCAT 'rudhoe oB?~ Field )rl~dhoa Pool 11. SEC., T., R., M., (BOTTOM I-IO]L,l~ OBJECTIVE) Sec. 11, T11N, R14E, UM 12. PEP,~IT l~O. 76-52 21. INTER~'ALS DRILLED BY ROTARY TOOLS -- CABLE TOOLS None 23. WAS DIRECTIONAL SURVEY AIADE Yes 2.1. TYPE lqL,l'if'Til[(' AND O'I'IIEH, LOGS RUN DIL, Sonic, FDC/CNI, GR/CCE & CBL/VDL _ 25. 'CASING RECORD (Report all strings set in well) [ 944/ [ H-401 100+] i~:: Cement to surface' 13-3/8" i 72# [MN-80[ 26g.~ .1 ~ I 4000 sx PF II ~ ~ ~ ] .[ 750 sx Class G cmt ~ JMN-an I qae2 12k" TOP (2, ID~ EO't'TO},4 (Z,ID) ISACKS CEMENT* ~ SCi-:E~ (RID) J SIZE DEPTH SET (MD 9095' 10,915' 375 sx 7" 9103' i £CVfOUNT PULLED 20" 9-5/8" S~Zb] 7" 28. PEIIFt)I{A'I /O~'S OPEN TO PRODUCIi~ION [interval, size and nurnber) "10,572' - 10,597' '~10,330' - 10,360' 29. DJ~PT7i 1NT;~,tV.AL (MD) I , , N/A 1 i si~o~s per foo~. "10,500' - 10,525' t'10,290' - 10,315' '~'~10,452' - 10,482' q10,250' - 10,275' c10,390' - 10,420' ~10,225' - 10,235' '510,194' - 10,209' 10,165' - 10,180' ~,,. ' ..... I0 11c' ..... , i~o~-uc¢~, ~ou w/, ! ) ~PACIfiER SET ~ ,, ,t fi963' ACID, Si!CT, ]FiLS~C2 ClX, E, C~,IENT SQUeeZe, ETC. DATE FIR.E'P ['ILODLICTION [ PI'~ODUCTION MILItiOD (Flov,'i~g, ~r(as lif[, pumping--size and type of pump). .[V/ELL STATUS (Producing or · ' II ~zuC-in) 10/27/77 , i Injection on 7 tbg with packer [ inie ti .... · ,, ..... , ,. .. __ ..... ~._. C ng DATE ~,~ TIgST. I}iUURS q ESTF-,D ICI!OXE SIZE tPP. OD'N FOP~ OIL--BDL. G-;kS~ICF. %;£~TER~BBL. /GAS-OIL ILkTIO 10 26 27 24 r o ~,!- )/Tp.. h,s 190 ! 4770] FL. OXV, '['L.:iIIN ~1 ICASLNG PRESSURE [CALC~T~ OIbBBL. GAS--~CF. WA~--BBL. J OIL GRAVITY-~I (CORR.) !'[~.SS. I 124-HOU~ RA~ t / ,, , I ,. 1' L ! 4770 ,l J 3 . tUSPOSITIONOF GAS tSold, uaed ]or ]ue~, vented, etc.) t TEST WITNESSED BY Reinjection into producing zone Leland Tate 32. t,lS'r oF tTTACHM~NT8 ii 2.2 I heroby certify that the foregoing and attached information is complete and correct as determined from all-available records 'SIGNEI, TITLE District_Drlg Engineen___ DATE __ I I Il II Ifil ] *(See Instructions and Spaces I:or Additional Data on Reverse Side) ~ !/8LTL.. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completior~ report end log on all types of lan:ts and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise showr~) for depth measure- ments given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate, prc, duction from more than one i~terval zone (multiple * ' completion), so state ~n item 20, and ir~ ite,~ 22 show the prcJ~c~r~.kl interrupt, or ~ntervals, top(s), bottom(s) and name (s) (if any) for only the interv,~l ret~orted ir~ ~ter~ 30. Submit a separate report (page) on this form, adequately identified, for each additior~al ir~te~val to be seperately produce,d, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above). 34. SUMMARY C)l~ b"OI{MATION TF2ST.'-; IN('LLII)'.N(; INTEItVAL TE.qTED, I'llE~SURE DATA ~ ~C'OVEIIIF~$ ()F OIL. GAS. 35. G~GIC MARK~ WAT~ AND MUD , , M~AS. D~ ~ V~.T] D~{ 3a'. CORE DATA. Aq'I'ACII nn~ D~CRI.P-~ONS O~ LITI[OLOGY. POROSITY. FRAC~R~. APP~NT DIPS' ~ND'. I~I'E~'TEI) S[IOWS O~ OIL, GAS OR WAq'~I. Divis~ of Oil ~ Gas Cc~serv~tic~ O. K. Gilbreth, Jr~ ~i~~ · Director /~J~'~ ~~/~' ~ ~~ 27, 1977 ~~ R. ~s Wi~ss S~~a~ S~~ V~ (~) ~~le~ ~~r ~~ ~ ~~ ~~ V~ (S~ .Fr'_~ay, ~ 21, 1977 - I left Anchorage by Wien Airlines at 5:30 PM ~&~ arrived in ~-at 9:00- PM. Ben Davis, field foreman for Arco cn NGI 98, picked me up an~ took me to Drill Site 2-11. He said they had a misrun with ~ guns on perforating and tests w~uld be held up.. Perforating was for the upper zone. ~turday, ._Octc::9~e_ .r.~.~_~977 - Perforating was finished and ~qSV was run at =4:00 pM. C~ntrol -i~ ~ tested to 5000 psi. At 6:15 t~4 pressure above SSSV was bled down to approximately 1600 psi ~ 1800 psi. S~qV blew up hole about 350' and got stuck. Time, 6:30 PM. .~~.,..~ 23, 1977 - SSSV was finally pulled and a n~w SSSV was run at 6:00 t~4, .... T~' ~trol lines would not test. SSSV was pulled again. ~te~ to 5000 'psz but w~mald not bleed down, indicating pack/ng failure again. SSSV was pulled again and repa~ed and rerun at 6:00 PM. Cc~trol lines tested to 5000 psi OK. At 7:30 PM the manumatic, surface safety valve. was closed, pres~are above SSV was bled to zero. There was no buildup of pressure. The SS~ was open with 1800 psi on tubing. The SSV v~s then opened and the SSSV vatv~ was closed with 1800 psi ~ SSSV and bled down to 1000 psi. There was no buil~ of pressure, indicating both the SSV and SSSV were not leaking and were locked in OK. I observed the SSV test for 10 minutes and the SSSV tests for 20 minutes on final tests. The SSSV was set at 2193.53 feet. ~ was the operator setting the 7" Otis SSSV. During the job the wireline BOP leaked and w~ repaired. ~n_~~: There ~ four failures on attests to test subsurface s~fety raise-s- (SSS%9. But'~ f~ ~ts were done, the ~%SV and ~SV tested satisfactory. Attachment · '~--~i~ Al~.~.~ Oil and Gas Conservation Commit e ' Field Inspection Report Drlg~ Permit No. Well/Platfm Sec T R M Operator ~ ~ Z;'"/~- Represented by~/~/~.,~, .~/~.'~ Name & Number Satisfactory Type Inspection Satisfactory Type Inspection Yes No Item ( ) Location,General Yes No Item ( ) BOPE Tests ( ) ( ) 1. Well Sign ( ) ( ) 15. "Casing set ( ) ( ) 2. General Housekeeping ( ) ( ) 16. TesL fluid-( )wtr. ~ )mud ( ) oil ( ) ( ) ~. Reserve Pit-( )open( )filled ( ) ( ) 17. Master Hyd. Control Sys.- psig ( ) ( ) 4. Rig ( ) ( ) 18. N2 btls. (X) Safety Valve Tests ( ) 5. Stir'face-No. Wells /-- ( ) 6. Subsurface-No. Wells ( ) Well Test Data ( ) ( ) 7. Well Nos. ( ) ( ) 8. Hrs. obser , , ().i~ ( ) 9. BS&W , , , ( ) ( ) 10. Gr. Bbls. ( ) Final Abandonment ( ) ( ) 19. Remote Controls ( ) ( ) 20. Drilling spool- "outlets ( ) ( ) 21. Kill Line-( ) Check valve ( ) ( ) 22. Choke Flowline ( ) HCR valve ( ) ( ) 23. Choke Manifold No. valvs flus__ ( ) ( ) 24. Chokes-( )Remote( )Pos.(-~dj. ( ) ( ) 25 Test Pluo-( )Wellhd(')csg( )none ( ) ( ) 26. Annular Preventer,__~vsim ( ) ( ) 27. Blind R. ams,~psim ( ) ( ) ll. P&A Marker ( ) ( ) 28. Pipe Rams psiq ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock ~psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve psi~ ( ) ( ) 14. Pad leveled ( ) ( ) 31 Safety Floor valves--L-(- --)-BV ( )Dart Total inspection observation time ~/~}~/days Total number leaks and/or equip, failures ~t/ Remarks ~S-,~ B*>: ~ ,~//~ ~ ~/~ ~' ~~/~Z~ ~~~ ~/( ' - - - . ~ Ins-pec'ted by ];-./c9</~' ~)/'r ;/~_/j~.)a te !y~/_,2__~_ cc :~ZT? /?//~.N~ Noti fy in days .or when ready AtlanficRichfieldCompany North Amc'A~n Producing Division North Alas )istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 6, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage,,Alaska 99501 Subject' NGI #1 (33-12,11-14) Permit No. 75-48 NGI #3 (32-11-11-14) Permit No. 75-61 NGI #5 .(33-01-11-14) Permit No. 76-14 Permit No. 76-52 Dear Sir' Enclosed please find a Sundry Notice outlining our plans for the above mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosure Fog% 10-403 REV. 1-10-73 Submit °'Intentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for ~uch proposals.) OiL i----i GAS r-] OTHER Gas Injection WELLL_.J WELL 2.. NAME OF OPERATOR Atl anti c Ri chfi el d Company 5. APl NUMERICAL CODE 50-029-20219 6. LEASE DESIGNATION AND SERIAL NO. ADL-28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME ~rudhoe Bay Field-Prudhoe 0il Pool 9. WELL NO. :3. ADDRESSOFOPERATORpo0o Box 360; Anchorage, Alaska 99510 NGI #8 (21-11-11-14) 98'S & 956'E of NW cr Sec. R14E, UM LOCATION OF WELL At surface 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18' Gravel Pad 12, T11N, Check Appropriate Box To Indicate Nature of Notice, Re 14. 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 684'S & 956'E of NW cr Sec. 11, T11N, R14E, UM 12. PERMIT NO. 76-52 sort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING g...a MULTIPLE COMPLETE ABANDON* CHANGE PLANS Perforate SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Welt Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate additional selected intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with 'all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. After setting and testing the downhole safety valve, the well will be blown down and flared to the pit for clean up only. A static bottom hole pressure survey will then be taken. Estimated Start Date' 9/15/77 16. I hereby certify that the foregoing is true and correct TITLE Di stri ct Dri 11 i ng Engineer DATE (This space for State office use) CONDITIONS 0'~ ApPROvAL, IF A~.. - ,-~LE See Instructions On Reverse Side D^T~,12-77 From: · J. A- Rochon/p. Hellstrom.~ Date' May 1 2.,.. ! 9 7 7 Ifell ::--~' NGI #8 ' Transmitted herewq_th are the £°l!o.',~ing for the subject well:. Run No. . : Scale BHC S6nic/C~]~per Log- ':~ - ' BHC Sonic/Caliper - Gan~aa Ray-'Log ----" ~-; ...... 'J: BHC ~~/~~ ~y Log .-' C~per/C~. - . - . C~ent Bona Ap~L ' - . : :.,_ 1 .... ~e~te~ Neu~6n Log . -... Core ~~ysE - ~nten~ ' ~.. -- - Core' No. ' ' ~re ~s~ti~ C~'C) - Inte~a~ 'la-/ .' ], ~ Core Des~iption [Cony.) - CQre No. ...." U_ ' ~rection~ S~y -. ~o . . . -'. - ' .- . S~gle S~6t " ~tishot . ~~ St~'Test - Test No. ~~1 Induc~om Lmte~olog F~a~on De~i~ Log - . -. . .e m , -. : -- Lmtero!og ' ... . ~ - Lo~tio~ Plat : - .. ~~log. : 1,~og- ~te~al ~' ' : S~le Log ~ ~erge~c Log , - . ~-DIL ..... ~ ~_ -- ~-Porosi~ Log Receipt Acknowledged For: Date P]case return receipt to' . / Atlantic Richfield Co.,,-p. any North Alaska Engineering P. O. Box 360 ; ~ .l .... ,.,~ A Ir,-:' ' - :" #334 ATtJ~NTI C RICHFIELD To' TRANSM I TTAL From: J.A. Rochon/p. Hells'cmn. Date' .. . Apt, il 15, .1977 .... . Well Nzme' . NC, I ~8 Transmitted herewith are the following for the subject well' Run No. Scale Xerox Sepia BL Line BHC Sonic/CaliI~r L. og- BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gm Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Den_s.i..tX Log Compensated Neutron.-~_ormation Density Compensated Neutron Log Core Analysis..- Interval Core No. . Core Description [SWC)'- Interval'. Core Description [Cony,) - Core No. Directional Survey- Gyro .- Single ShOt Multishot Drill Stem Test - Test No. Dual Induction Laterolog Pormation Density Log Pormation Density Log/Gamma Ray Gamma Ray/CCL Laterolog. ' Location Plat ~licrolaterolog Microlog Mudlog- Interval Sample Log (A.R.Co'.)-Interval) Synergetic Log TVD-DIL TeD-Porosity Log C~tt · ~ =, -Receipt Acknowledged For' Date ' Please return receipt to' Atlantic Richfield Co,,?~y North-Alaska Engineering M~nager APR ~ ~ ]~77 P. O. Box 360 #214 An~-h~-~ Alaska ~--~' ' " .~- ATLANTIC RICHFIELD DISTRIBUTED TO: STATE OF ALASKA D'[VfSION OF OIL ~ G~ North Alaska Distric,t, Engineering TRANSMITTAL . . To' From' J. A. Rochon/p. Hellstmm Date: , ,March ,4,. !977 ,, ,.. Well Name' NGI #8 Transmitted herewith are the following for the subject well' Run No. Scale Xerox Sepia BL Line BHC Sonic/Caliper Log- BHC Sonic/Caliper -' Gamma Ray Log . . BHC Sonic/Gamma Ray Log Caliper/CCL _ _ _ Cement Bond Log/VDL " Compensated Formation Density Log _ Compensated Neutron-Formation Density Compensated Neutron Log ' Core Analysis - Interval ..... ...... . Core No. ·J,_ ,. _., Core Description (~?C) - Interval Core Description (Cony.) - Core No. Directional Survey- Gyro Single'Shot '"" '" Multishot ,,,, ,, ,, , Drill Stem Test - Test No. Dual Induction Laterolog Fomation Density Log Formation Density Log/Gamma Ray Gavma Ray/CCL Laterolog · - ~ Location, Plat ~[icrolat~rolog Microlog ' Mudlog- Interval Sample Log (A.R.Co.)-Intervai) Synergetic Log WD-DIL WD-Porosity Log 1 . CCL/Gamma ~ay 5" - ~.~., . .... _. -._ . . .... .~ . . ,, ~_ . . , ,, , Receipt. Acknowledged For' Date' ~~~ ,~.,_. ,/'?.. :~, ,~, ...... Please return receipt to: Atlantic Richfield Company North Alaska Engineering blanager P. O. Box 560 Anchorage, Alaska 99510 · · ,, .,_. v . . - · , , _.f L / .'i' ea."" O~OO1 B STATE ^U s DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas Conservation TO: Hoyle H. Hamilton /~#~/ Di rector Thru: LonnieC. Smith Chief Petroleum Engineer FROM: Harold R. Hawkins Petroleum Inspector DATE :February 8, 1977 SUBJECT: Subsurface Safety Valve and Surface Control Safety Valve Tests for ARCO NGI #8 ~unday, January 23, 1977 - I left my house at 6:00 AM for a 6'30 AM check 'i~'~fo~ ~'-fiig'h~:-'tO~'prUdh% Bay to witness a subsurface safety valve and surface control safety valve test on NGI #8 for ARCO. John Creg was operator at the tim~. When I arrived, they .were finishing up on perforating. They ran a subsurface safety valve about IO:O0 PM. The valve did not hold around the packing control line with pressure bled off. The SSSV had to be pulled. J~o~.nday, January 24,~_1977 - The SSSV was rerun at 5:15 PM, SSSV has been set. I observed the SSSV closed with no buildup of pressure for 15 minutes. The SSSV was opened and tubing pressure was 1350 psi. The surface control safety valve was closed and pressure was bled down to 400 psi above the SCSV. watched the pressure gauge. There was no buildup in 20 mim~tes. The SCSV held OK. The SCSV was opened and psi rose back to 1350 psi. The SSSV was Closed and tubing pressure bled down in 300 psi incr~nents. The SSSV did not hold. There was a slight buildup of pressure. The Otis operator opened and shut the valve several times thinking there might be something caught in the valve~ '~ TuesdaY' January 25, 1977 - Testing was started again at 1:00 AM on ?,',GI i w-itn~-ssed'-tubi'hg PressUre drops in 300 psi increnmnts at 15 minutes each and 0 psi for 30 minutes with no buildup of pressure. This time the SSSV tested OK with no leakage. At 2-30 AM tests were c~npleted. In suimtary_: I witnessed testing of the SSSV and SCSV with only one failure which was corrected. All tests were successfu. 1 when completed on NGI #8. The SSSV was set at 2199.53 feet. Attachment y. es']-i~, Nd?il]~!item~?!~!~)':~6'~a~i~io~i~!~6ne~l~-~ ~!~,,.i.i ~ Yes ~.].~-~. ( ).. (~) 4?R,ig '-- . .- ~ ( ) '( ) 18. Nc btls. , ., ' . ~.(~) Sa~ety Valve Tests ( ) ( ) 19 R~mote Controls (A~' ( ) ~ 5.~ Surface,No. Wells ! (X.) ( ) 6. 'Subsurface-No. Wells / ", (). Well Test Data ( ) ( ) 7~ Well NoS. ,__, , ( ) ( ).' 8. Hrs. obser , ,__ (..) ( ) 9. BS&W , ,__,__ ( ) ( ) 10~ 'Gr. Bbls. ( ) Final Abandonment () () () () () (-) () () () () () () () () ~I) () ) () 20. Drilling' spool- "oui~lets 21. Kill Line-( ) Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. valvs flgs 24. Chokes-( )Remote( )Pos.(-~dj. 25 Test Plug-( )Wellhd(')csg( )none 26. Annular Preventer,__psig 27. Blind Rams,_____psig ( ) ( ) 11. P&A Marker 28. Pipe Rams psig ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock psi,q ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve psig ' ( ) ( ) 14. Pad' leveled ~ ( ) ( ) 31. Safety Floor valves-( )BV ( )Dart Total inspection observation time~, hr~f(~a~ Total number leaks and/or equip, failures / RemarkS..~7=?~/? 5 .~ ~ ~? /~y/+ ~ .~z-Y--~z~ .~/~l~-' 7" ~ ~-.m~¢,~/,x:7-~: 7~_~_~_ days or when ready ~Atlanti-~RichfieldCompany North Ameri~ Producing Division North Alasl ;trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 3, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, A1 aska 99501 Subject: NGI #8 (21-11-11-14) Permit No. 76-52 Dear Sir' Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /jw Enclosure RECEIVED Anohora~e Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use ,'APPLICATION FOR PERMIT--" for such proposals.) Oil n GAs F-I WELLU WELLi I OTHER Gas .Injection 2. NAME OF OPERATOR atl anti c Ri chfi el d Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, A1 aska 99510 4. LOCATION Of WELL At surface 98'S & 956'E of NW cr Sec 12, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18.4' Gravel Pad 14. CheCk Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20219 6. LEASE DESIGNATION ANO SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI #8 (21-11-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec ll, TllN, R14E, UM 12. PERMIT NO. 76-52 )orr, or Other Data NOTICE Of INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL SUBSEQUENT REPORT Of: (Other) MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING ABANDON* SHOOTING OR ACIDIZlNG ABANDONMENT* CHANGE PLANS (Other) Perforate (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. Moved onto NGI #8 @ 0600 hrs 1-21-77. Installed & press tstd surf connections. RU & press tstd lubricator. RIH & pulled dummy valve. Ran CCL. ~Perf.'_d w/4 shots per ft.10,776' 10,786' 10 697' - 10,717' 10,661' - 10,68l' ]0~,~23..'~.~]0,6.43, ..... RIH&'set' ball valve. Press tstd balance & control lines 5000 psi OK. Tstd ball valve 1150 psi below & zero press above. Ran press recorders. Suspended Flow Tst & Cleanup @ 1400 hrs 1-25-77. Resumed operations @ 1030 hrs 1-27-77. Opened well to flow thru 3/4" choke w/3000 psi flowing pressure. Shut well in~3100 psi shut in press. After well was shut in press built up thru lower master valve. Packed master valve w/low temp grease. Press tstd valve OK. Monitored press above master valve, no increase. Released well to production department 2-4--77. RECEIVFD D!vision ol Oil and Gas Con~erv~tion 16. I hereby certify that the foregoing is true and correct TITLE District Drillin9 Engineer DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE , DATE See Instructions On Reverse Side AtlantLcRichfieldCompany North Amer. Jc.-an Producing Division North Ala,. ~trict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 28, 1976 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: NGI #8 (21-11-11-14) Permit No. 76-52 "~:--EN¥--~ '. l--~'-~io-'-'i- ..__l i~:--~:.i°"-,~ A ..... ~ ~:~v T--s~C CONFER: FILE: _.. ~'. } Dear Si r' Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned wells. Very truly yours, / C. R. Knowles District Drilling Engineer CRK/jw Enclosures RECEIVED 'd~N I ~ lg77 Submit "intentions" in Triplicate & "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL Gas Injection 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0, Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 98'S & 965'E of NW cr Sec 12, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) RBK 47' 5. APl NUMERICAL CODE 50-029-20219 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI #8 (21-11-11-14) 10. FIELD AND POOL, OR WILDCAT Prudh0e Bay - Sadler0chit Po01 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec ll, TllN, R14E, UM 12. PERMIT NO. 76-52 CheCk Appropriate Box To Indicate Nature of Notice, Re 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L-~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTER lNG CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. See Attached. RECEIVED Division of Oil and Gas Conservatio: Anchorage 16. I hereby certify that the foregoing is true ~..nd correct SIGNED ~Y/ TITLE /~ J~,{- DATE - ~ ~ ~ ~ ~ ..... ~ .- ~ ~ ~ {Thi~ ~lc~ for St~t~ offic~ u~} /-~- 7'7 APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side NGI #8 SUNDRY NOTICE OF SUBSEQUENT REPORT Accepted ri9 @ 1600 hrs 12-4-76. RU & press tstd lubricator. Pulled dummy valve. Opened sliding sleeve @ 8879'. Rev out diesel w/lO.9 ppg CaCl2 wtr. Ran GR/CCL 10,801' to 8900'. Set BPV in tbg hgr. ND tree. NU & tstd BOPE. Sheared out of PBR w/300,O00#. Pulled & LD 7" tbg. Chgd & press tstd pipe rams. RIH & set retrievable BP @ 1079'. ND BOPE. Removed old 9- 5/8" pkoff. Install & tstd new 95/8" pkoff to 5000 psi. NU BOPE. RIH & retrieved BP. Chgd & tstd BOPE 7" rams. Ran wireline gauge ring & junk basket. Landed 246 its 7" 29# L-80 A-B mod LT&C tbg. Tagged top of PBR & sheared guide ring. Spaced out 7" & made up tbg hgr. Ran 2nd dummy valve to +_80' for gauge ring. Installed control lines. Control lines would not circulate. PUlled dummy valve. Pumped control lines clear. Reset dummy valve & tstd OK. Landed tbg & tstd control lines & hgr to 5000 psi OK. Set 7" retrievable BP @ 88'. ND BOPs & NU xmas tree. Tstd tree to 5000 psi. Found leak in Otis adapter & packing around lower master valve stem. Redressed adapter & replaced master valve. Set BPV & tree tst plug & tstd tree to 5000 psi OK. Retrieved Baker BP. RU 7" riser & lubricator. Tstd to 3000 psi OK. RIH to pull dummy valve. Tools worked down thru soft ice & stuck @ 248'. Jarred loose & POH. ND tree & NU BOPs. Installed 3½" rams. PU 3½" DP & 7" csg scraper. RIH. Circ & cond CaCle wtr. LD DP. Installed BPV ND BOPE. NU & press tstd xmas tree to 500D psi OK. RU lubricator. Puiled dummy valve. RIH & opened sliding sleeve @ 8874'. Displ tbg w/330 bbls of diesel Placed 20 bbls of diesel in 7" x 9-5/8" anul. Closed & press tstd sliding sleeve. Flushed ball valve & control lines. Set dummy valve. Press tstd control lines to 5000 psi. Ran GR/CNL/CCL logs & dummy gun. Began long term press tst on tbg & tbg anul. Released ri.9 @ 1500 hrs 12-15-76. RECEIVED -,JAN/ 1977 Division of Oil and Gas Conservation Anchorage AUanhcHichl~,elciC?mpany North A:a skr'~":strict Post Office L 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 23, 1976 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: NGI No. 6 (44-2-11-14) N~J..._.blo .... ?~..( 11 - 12-11 - 14 ) ~ NGI No. ....... 8'~g. 1-11-11-14) Dear Si r' Enclosed please fi nd a Sundry Notice outlining our perforating plans for each above-mentioned well. Very truly, yours, / M. L. WagDi~n,e~, for C. R. Knowles District Drill ing Engineer CRK/jw Enclosures Form 10-403 ~EV. 1-10-73 Submit "Intentions:' in Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. O~L i--1 GAS [--] WELLI I WELL OTHER Gas Inj ecti on 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anch0rage, A1 aska 995]0 4. LOCATION OF WELL At surface 98'S & 956'E of NW cr Sec 12, TllN, R14E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 18.4' Gravel Pad 14. Check Appropriate Box To Indicate Nature of Notice, Re 5, APl NUMERICAL CODE 50-029-20219 6. LEASE DESIGNATION AND SERIAL NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e Bay 9. WELL NO. NGI #8 (21-11-11-14) 10. FIELD AND POOL, OR WILDCAT 11. SEC., T., R,, M., (BOTTOM HOLE OBJECTIVE) Sec 11, TllN, R14E, UM 12. PERMIT NO. 76-52 loft, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Perforate SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log forrn.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, Atlantic Richfield Company proposes to perforate the intervals as follows: 10623' - 10643'; 10661' - 10681'; 10699' - 10719'; and 10776' - 10786'. A 5000 .psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with 3-1/8" JumboJet hollow carrier guns at 2 shots per foot. The downhole safety valve will be installed .upon conclusion of perforating. Well will then be flowed to burn pit for clean up only. Bottom hole static pressures will be measured with downhole pressure bombs run on wireline. Estimated start date, December 5, 1976. 16. I hereby ce~rtlfy t!~ th/C/foregoing Is true and correct SIGN EE~,~/f / /~ Y" TITLE , (This space for State of~.u~ .. CONDITIONS O~PROVAL, IF ANY: DATE Approved <. op ~..,..:, Returned See Instructions On Reverse Side ~anticRichfieldCompany North Ame ~-r--L~q Producing Division North Ala,. strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 23, 1976 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject: NGI ://8 (21-11-11-14) Permit No. 76-52 Dear Mr. Hamilton: Enclosed please find Sundry Notice outlining our plans for the above mentioned well. Very truly yours, MLW/cs Enclosure Fo~m, 10-403 REV. 1-10-73 Submit "Intentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals,) ~' o~L F-1 CAS E] WELLL--J WELL OTHER GaS Inj ectlon Well 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR ~. 0. Sox 360, A~cbo~ase, AE 99510 LOCATION OF WELL At surface 98'S & 965'E of NW cr Sec 12, TllN, R14E, UM 13, ELEVATIONS (Show whether DF, RT, GR, etc,) RKB 47 ' 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUF~ERICAL CODE 50-029-20219 6. LEASE DESIGNA-rlOhl AND .SERIAL. NO. ADL 28302 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. NGI ¢/8 (21-11-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 11, TllN, R14E, OM 12, PERMIT NO. 76-52 ~ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L------ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF : REPAIRING WELL FRACTURE TREATMENT ' ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion er Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estlmated date of starting any proposed work. Atlantic Richfield Company proposes replacing the 9-5/8" x 13-3/8" packoff Jn the subject well. A rig utilizing a 13-5/8" 5000 psi BOPE stack consisting of annular preveter, two pipe ram preventers, and a blind ram preventer will be used. The BOPE will be tested to 5000 psi weekly and functionally tested on trips. Weighted CaC12 will be circulated before the present 7" completion assembly is. puli. ed. A 9-5/8" retrievable bridge plug will be used at ]_000~ while replacing the packoff. The same 7" completion assembly ~.~,il! be rerun. Operations will begin approximately November 26, 1976. hei'eby certi~,~' .'.h'at the foregoir:g is true and correc~ space for State[o,f~ce use) ..~: ir,,str,..!ctior;s On Reverse Side .b~ ReSumed To' CONFIDENTIAL DISTRIBUTED TO~ STATE OF ALASKA ~DFISION OF OIL ~ GAS ATL/I~TI C RICHFIELD North Alaska District_ Engineerin~ TRAN SM I TTAL From' J.A. Rochon/p. Uel].stror.~. Date' Oct. 6, 1976 Well Nmne' No. Gas Inj. # 8 Transmitted herewith are the following for the subject well' Rrm No. Scale BHC Sonic/Caliper Log .B!tC Sonic/Caliper - Gamma Ray Log BHC Sonic/Garmma Ray Log Caliper/CCL Cament Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey- Gyro Single Shot Multishot Drill Stem Test - Test No. Paa! Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Gm~a Ray/CCL Laterolog Location Plat' Microlaterolog b2crolog Mudtog- Interval Sample Log (A.R.Co.)-Interval) Synergetic Log Tt(D-DIL TVD-Porosity Log CkSING COLLAR LOG Xerox Sepia BL Line Receipt Acknowledged For' Piease return receipt to' Atlantic Richfield Compmny North Alaska Engineering Mam. o~r P. O. Box 360 Anchorage, Alaska 99510 1976 ~'""' 0'0 * '~-~ ATIJtNTIC RIC~-~IELD CO~'~\] .... CONFIDENTIAL DISTRIBUTED TO: STATE OF ALASKA OIVISION OF OIL & GAS North Alaska District Engineerin~- TRANSMITTAL From: J.A. Rochon/p. He]_]stror.: Date' Oct. 5,1976 Well Name' No. Gas Inj. # 8 Transmitted herewith are the following fOr the subject well' Rrm No. Scale Xerox BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Comp ens ated Neutron- Format ion Dens i ty Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey- Gyro Single Shot ~'~ltishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Ga.~a Ray/CCL Laterolog - Location Plat Microlaterolog 5Iicrolog Mud!og- Interval Sample Log (A.R.Co-.)-Inte~-¢al) Synergetic Log T%q3-DIL TFD-Poros.i ty Log 2"& 5" 5~ - 5~~ - 2"& 5" Sepia BL Line Receipt Acknowledged For' Date· Please return receipt to' Atlantic Richfield Company North Alaska Engineering M~anager P. O. Box 360 Anchorage, Alaska 99510 DIVISION OF ©1l ^t4O GAS ,? To' A'I'J.~N'I'~C I(ICI tl:i ti!,!~ Nos .... Alaska D~str~:L I!nf;ineerin~ T R A N S bi I T T A From' J.A. Roc]mn/W. Tolivcr Date' September 16, 1.976 Transmitted herewith are the fol!oO'ing: I~a #1, Dresser Atlas-CBL/~q3L/GR, 5" Receipt Ackr~owledged For: Please return receipt to' At' ~mtic Ri. cl~"'" , ,, Lc.Id North Alaska }Mgineering Manager ,~ ~chorage, Ala.;ka 995]0 /~ b!CJ ;;' ~t~an~cRichfieldC©mp~y .... AAchoFase, A~aska September 8, 1976 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Enclosed are the Well Completion Reports along with the Well History and Directional Survey for each above mentioned well. Very truly yours, C. R. Knowle~- District Drilling Engineer CRK/jw Enclosures Form P--7 SUBMIT IN DUPLICATE* STATE OF ALASKA ',se~ other st ructions on reverse side~ OIL AND GAS CONSERVATION COMMITTEE WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la, TYPE OF WELL: OIL,,.ELL ~] ~ASWELL ~-] DRY U Other Sas Injection b. TYPE OF COMPLETION: WELL OVER EN DACK RESVR. Other 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, AK 99510 LOCAIION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 98'S & 965'E of NW cc Sec 12, TllN, R14E, UM At top prod. interval reported below 710'S & 1675'E of NW cc Sec ll, TllN, R14E, UM At total depth 684'S & 985'E of NW cr Sec ll, TllN, R14E, UM 5. API NUlVLFA{IC~ CODE 50-029-202] 9 6.LEASE DESIGNATION A_ND SERLA/~ NO. ADL 28302 '7. IF INDIA.N, ALLOTTEE OR TRIBE NA1VLE UNIT,F.~R.M OR LF-~SE NAME Prudhoe Bay NGI No. 8 (21-1l-ll-14) 40. FI~.I.~D ~D PO(~L, OR WI~CAT Prudhoe Bay - Sadlerochit 11. SEC., T., R., M., (BOTTOM HOL~ OBJECTIVE) Sec 11, TllN, R14E, UM 12. P~IVIIT NO. 76-52 7-16-7612' D~ISE SI~UDDF-J:) 14' D;~TE T'D' RF'P~C~8--8--76Ii~' D~ co.~_, susP o~ ~A~.8_22_76 I1 8.4' Gravel Pad ~/~/~./. ~/ ~1 I ( 10925'MD, 8676'TVD ~ 10,820' MD 8623'TV .oA~ ~oo~ ~. PRODUCING IN~VAL(S), OF ~IS, COM~TIO~, BOSOM, N~E (~ AND ~)' 23. WAS DIRE~ON~ [0,098'MD, 8222'TVD'- Top 5ad]erocb]t ]0,734'MD, 8566'IVD:- Bottom Sad]eroch]t [ Yes 24. ~E E~CTRIC ~D OTH~ ~GS RUN DIL, Sonic, FDC/CNL, GR/CCL & CBL/VDL 25. :. CASING RECORD (Report all strings set in well) CA, SLNGSIZE WEIGHT, LB/FT. 20" 94# 1-3--3/8" 72# --9-5/8" 47# 26. LINER l%E C OlqI) GRADE ~-40 qN-80 qN-80 ~S00-9~ DEPTH SET (MD) I HOLE SIZE 100, ]32" 2695 17½" 9422 12%, SIZ]~ '[ TOP(MD) ~ 'BO/~TOM (I~D) [ SACKS Ck--'MENT PERFORATIONS OP~.-2N TO PRODUCTION (Interval. size and number) 20. : I:~ODUCTION C~MLN TING REC OIAD Cement to surface 4000 sx PF II 750 sx Class G cmt I 27, SCREEN (MD) SIZE ')..~. TUBiNG REC O'FJ2) DEPTH SET (MD) AMOUNT PULLED ~ PACI~ER SET (MD) 9103 , t 8963 ACID, St!OT, FZ~A.C'I'URE, CE~SIE:NT SQUEEZe, E"I'C. D]~'~TIt INT]gRVA_L (MD) AMOUN£ ;~ND KIND OF MA. TE2,AAL USED DATE FIRST Pt%ODUCTION NA DATE OF T~ST, [I'{OU-RS TESTE~D [CI{OXE SIZE ~PROD'N FOR ~--OW, TUBING' [CASING PRESSURE ICALCULA~ GAS---iV~CF. 1 ~1. DISPOSITION Or ~aS (Sold, used ~r iuel, vented, etc.) - I PRoDuCTION MEIHO'D (Flowh~g, gas lif~, pumping--size and type of pump) [WELL STATUS (Producing or ] ~nut-in) OI~BDL. G~kS--IVICF. WA~I~EYi--BBL. [ GAS-OIL ItA.TIO WA~B~. ] OIL GRAVITY-~I (CO~.) TEST W ITNE~D . _. ~2.LIST OF ATTACHMENTS Drilling Hist~y and Directional Survey 33.I h~~7 foregoing and af~ed information i. co~leterd c~rrect'as .etermined from all-available reco . "' FYI.Y - ,, ~, · (See I~ructions and S~ces [or Additional Data on Reverse S,de) INSTRUCTIONS General: This form is designed for submitting a complete and correct v,..ell completion report end 10g on all types of lands and leases in Alaska. Item: ]6: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in clher spaces on this form and in any atta."hmer-,ts Items 20, and 22:: If this Well is completed for separate prcc]uction from. more th,'~n one ~nterval zone (multiple completion), so state ~n item 20, and in ite,~ '22 show the p~c:Juc~.tl interval, or ~ntervals, top(s), bottom(s) and name (s) (if any) for only the interv.~! reported in item 30 Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). ,,, 34. SUMMARY OF PoH. MATION T~X.S'I'S IN(.'LUI)IN(; IN'I'EI'i. VAL TF_~TED. PHIg~S. SURE DATA AND P,.ECOVERIEH OF (.)IL. GAS, 35 G EX)I.,OG IC M AR Klgl:~ WAT~.~q. AND MUD NAMg MEAS. IDi~PTI{ q'~U'~ Top Sadler0chit 10098 8222 *.,.~ ~¢~,~,~. ~..~s o~ o~, o~s ~ ,~.~. Base Sadl er0chi t i 0734 8566 . . 1 ATLANTIC RICHFIELD COMPANY NGI #8 (21-Il-11-14) API 50-029-20219, ADL 28302 Permit No. 76-52 ._Sj~.ud~@ 1800 hrs 7-16-76. Drilled 17-1/2" hole to 2727'. Ran 13-3/8", 72#, MN-80 Buttress csg w/shoe @ 2695'. Cemented w/4000 sx PF II. Landed 13-3/8", installed and tested 13-3/8" x 20" packoff. NU and test BOPE. Drilled cmt, shoe and formation to 2737'. Test formation to 0.65 gradient. Directionally drilled 12-1/4" hole to 9444'. Ran DIL/SP/GR logs and mulitshot survey. RU and ran 9-5/8" 47# MN-80 and S00-95 Buttress csg w/shoe @ 9422'. FC @ 9337', and FO's @ 2490' & 2395' Cemented 9-5/8" csg w/ 750 sx Class G cmt. Installed and tested ~-5/8" csg packoff. RIH w/RTTS, cemented 2nd stage thru lower FO w/ 275 sx PF- C cmt. Closed and tested lower FO. Opened upper FO, pumped 305 bbl Arctic Pack into 9-5/8" x 13-3/8" annulus. Closed and tested upper FO. RIH w/8-1/2" bit, drld cmt from 9239' to 9337'. Drld shoe and tested w/500 psi. Drilled 8-1/2" hole to 10,925'. Circ. and cond. hole to log. Dropped multishot survey. Ran DIL/SP/BHCS/GR & FDC/CNL/GR/Caliper logs RU and ran 7" 29# MN-80 csg w/shoe @ 10, 915', top of lnr @ 9095'. Cmtd 7" lnr w/375 sx Class G cmt. RIH w/8-1/2" bit and 9-5/8" csg. scraper. Ran CBL/CCL and Gyro survey. Press tst csg to 3000 psi. RIH w/6" bit. Drl EZ drill @ 10,798' and hard cmt to 10,825'. Press tst 3000 psi ok. Trip in w/6" bit and 7" csg scraper to 10,825. Set pkr @ 9122'. Open for 1 hr tst w/weak blow, dead after 20 min for balance of 1 hr. Charts indicated tst ok. Ran 7" 29# L-80 LT&C (A-B) tbg w/Baker pkr @ 8995', RB nipple @ 2229'. ND BOPE NU and tested Xtree. Ran dummy valve and tst BV control lines to 5000 psi. Drop ball and set Baker SAB pkr @ 8963' Shear press 3700 psi. Press tst tbg and tbg annulus, okay. Ran 3-1/8'; OD dummy gun and CCL log. Released rig @ 2100 hrs. 8-22-76 $ UB-S URFA CE DIRECTIONAL SURVEY ~---'J UIDANCE J'~'JONTINUOUS J'TIOOL Company ARCO ALASKA, INC. Well Name NGI-8 (98', FNL,965' FWL,SEC,, Field/Location PRUDHOE, BAY, NORTH SLOPE~ ! 12,T1 1N,R14E~UM) ALASKA ii I Job Reference No. 73688 Loaned By: PORTER Date 29-SEP-89 Computed By: KOHRING GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKAp INC. NGI-8 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: 29-SEP-Ig89 (RUN ENGINEER: PORTER METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 87 DEG 56 MIN WEST DATA FROM SURFACE TO 10660.t' ACQUIRED WITH TANGENTIAL METHOD FROM SCHLUMBERGER GCT TOOL. DATR FROM 10700' TO 10925' ACQUIRED WITH RADIUS OF CURVATURE METHOD FROM MEASURED WHILE DRILLING SURVEY. MWD DATA TIED Tg GCT DATA AT DEPTH 10660.1e. COMPUTATION DATE: 02-MAR-90 PAGE I ARCo ALASKA, INC. NGI-8 PRUOHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: Z9-SEP-lgB~ KELLY BUSHING ELEVATION: 47.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUD-SEA COURSE qEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH DEG HIN DEG MIN 0.00 0.00 -47.00 0 0 N 0 0 E lO0. O0 100.00 53.00 0 6 S 12 30 W 200.00 200.00 153.00 0 5 S 44 19 W 300.00 300.00 253°00 0 14 S 35 15 E 400.00 400.00 353.00 0 9 S 40 30 E 500.00 500.00 453.00 0 12 S 0 43 E 600.00 600.00 553.00 0 11 S 8 47 E 700.00 700.00 653°00 0 10 S 39 21 W BO0.O0 800.00 753.00 0 11 S 7 g E 900.00 900.00 853.00 0 7 S 41 57 W 1000.00 1000.00 953.00 1100.00 1099.99 1052.99 1200.00 1199.99 1152.99 1300.00 1299.99 1252.99 1400.00 1399.99 1352.99 1500.00 1499.99 1452.99 1600o00 1599.99 1552.99 1700.00 1699.99 1652.99 1800.00 1799.98 1752.98 1900.00 1899.98 1852.98 0 18 S 45 50 E 0 14 S 87 ZO E 0 26 S 79 5 E 0 16 S 48 45 E 0 25 S 57 39 E 0 11 S 31 10 E 0 14 N 74 20 E 0 28 N ZB 59 E 0 25 N 2g 57 E 0 35 N 87 49 E 2000.00 1999.98 1952.98 2100.00 2099.97 2052.97 2200.00 2199.96 2152.96 2300.00 2299.96 2252.96 2400.00 2399.95 2352.95 2500.00 2499.95 2452. 2600.00 2599.94 2552.94 2700.00 2699.93 2652.93 2800o00 2799.91 2752.91 2900.00 2899.86 2852.86 0 21 N 86 16 E 0 42 N 80 15 E 0 35 N l'O 6 E 0 44 N 86 15 E 0 16 S 61 39 E 0 29 S 61 lO 6 0 57 S 63 40 E I 4 S 42 31E 1 6 516125 2 46 S 40 30 W 3000-00 2999.63 2952.63 4 59 3100.00 3099.05 3052.05 7 4 3200.00 3198.03 3151.03 9 21 3300.00 3296.32 3249.32 11 34 3400.00 3393.98 3346.98 13 ZO 3500.00 3490.90 3443.90 15 lB 3600.00 3586,.63 3539.63 lB 21 3700.00 3680.68 3633.68 Z1 20 3800.00 3772.82 3725.82 24 20 3900. O0 3862.77 3815.77 27 30 ENGINEER: PORTER VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 S 0.00 W 0.07 0.00 0.12 S 0.07 W 0.07 O.lg 0.38 S 0.05 W -0.18 0.21 0.63 S O.ZO E '0.22 0.00 0.92 S 0.25 E -0.23 0.33 1.24 S 0.27 E -0.13 0.47 1.63 S 0.19 E -0.03 0.25 1.83 S 0.10 E 0.03 0.00 2.15 S 0.05 E 0.03 0.57 2.40 S 0.06 E -0.44 0.31 2.62 S 0.54 E -1.05 0.45 2.69 S 1.15 E -1.39 0.09 Z.9Z S 1.50 E -1.92 0.19 3.31 S 2.04 E -2.25 0.20 3.51 S 2.38 E -2.55 0.54 3.70 S 2.68 E -2.84 0.37 3.32 $ 2.96 E -3.17 0.16 Z.62 S 3.26 E -3.98 0.92 2.17 S 4.06 E 0.00 N 0 0 E 0.00 S 16 23 W 0.14 S 29 56 W ~ 0.39 S ? 48 W 0.66 S 17 26 E 0.96 S 15 B E 1.27 5 12 18 E 1.65 S 6 40 E 1.83 S 2 59 E 2.15 S I 17 E -4.65 0.71 2.18 S 4.73 E -5.83 0.89 2.17 S 5.92 E -6.92 0.56 2.06 S 7.00 E -7.98 0.40 1.82 S 8.05 E -B.B9 0.34 1.84 S 8.96 E -9.40 0.53 2.13 S 9.48 E -10.51 0.33 2.64 S 10.61 E -12.01 0.67 3.71 S 12.15 E -12.79 0.93 5.22 S 12.99 E -11.69 '2.39 8.02 S 11.99 E 2.40 S I 22 E 2.68 S 11 33 E 2.93 S 23 7 E 3.28 S 27 15 E 3.89 S 31 40 E 4.24 S 34 6 E 4.57 S 35 56 E 4.45 S 41 46 E 4..18 S 51 17 E 4.60 S 61 5! E S 56 35 w -6.28 2.62 S 65 44 w 3.32 2.25 S 77 30 W 17.07 2.77 S 76 15 W 35.10 1.56 S 76 38 W 56.15 1.69 S 78 6 W BO.3Z 2.75 S 79 10 W lOB.B1 3.32 S 79 17 W 142.38 2.94 S 79 25 W 180.76 Z.B9 S 79 30 W 223.93 3.04 5.21 S 65 14 E 6.30 S 69 53 E 7.30 S 73 38 E 8.25 S 77 18 E 9.14 S 78 23 E 9.72 S 77 20 E 10.94 S 76 0 E 12.70 $ 73 3 E 14.00 S 68 6 E 14.43 S 56 13 E 12.11 S 6.73 E 13.86 S 29 3 E 17.15 S 2.71 W 17.36 S 8 58 W 20.92 S 16.33 W 26.54 S 37 58 W 25.17 S 34.21 W 42.47 S 53 40 W 30.ZB S 55.09 W 62.87 S 61 12 W 35.64 S 79.08 W 86.74 S 65 45 W 41.30 S 107.39 W 115.06 S 68 58 W 47.63 S 140.75 W 148.59 S 71 18 W 54.80 S 178.90 W 187.10 S 7Z 58 W 62.83 S 221.80 W 230.53 S 74 11 W COMPUTATION DATE: 02-MAR-g0 PAGE 2 ARCO ALASKA, INC. NGI-8 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 29-SEP-1989 KELLY BUSHING ELEVATION: 47.00 FT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN OEG MIN 4000.00 3950.25 3903.25 30 21 4100.00 4035.14 3988.14 33 34 4200.00 4116.70 4069.70 37 1 4300.00 4195.03 4148.03 39 36 4400.00 4270.31 4223.31 42 50 4500.00 4341.70 4294.70 45 55 4600.00 4410.23 4363.23 47 12 4700.00 4478.28 4431.28 46 53 4800.00 4546.66 4499.66 47 0 4900.00 4615.11 4568.11 46 38 5000.00 4683.92 4636.92 46 29 5100.00 4752.98 4705.98 46 21 5200.00 4822.33 4775.33 45 46 5300.00 4892.17 4845.17 45 38 5400.00 4962.30 4915.30 45 27 5500.00 5032.65 4985.65 45 14 5600.00 5103.23 5056.23 44 52 5700.00 5174.06 5127.06 44 51 5800.00 52¢4.71 5197.71 45 19 5900.00 5314o68 5267.68 45 50 ENGINEER: PORTER VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG MIN S 79 51 W 271.85 $ 80 0 W 324.17 S 79 36 W 381.43 S 79 22 W 442.90 S 78 59 W 507.93 S 79 3 W 577.08 S 79 22 W 649.06 S 79 15 W 721.49 S 79 10 W 793.62 S 79 5 W 865.65 6000.00 5383.93 5336.93 46 23 6100.00 5452.57 5405.57 47 5 6200.00 5520.36 5473.36 47 34 6300.00 55~7.64 5540.64 47 42 6400.00 5655.06 560)3.06 47 28 6500.00 5722.70 5675.70 47 25 6600.00 5790.56 5743.56 47 7 6700.00 5858.76 5811.76 46 55 6800.00 5927.33 5880.33 46 38 6900.00 5996.19 5949.19 46 25 S 79 1 W 937.33 7000.00 6065.22 6018.22 46 18 7100.00 6134.54 6087.54 46 1 7200.00 6204.19 6157.19 45 52 7300.00 6273.21 6226.21 46 34 7400.00 6341.61 6294.61 47 11 7500.00 6409.27 6362.27 47 35 7600.00 6476.17 6429.17 48 17 7700.00 6542.38 6495.38 48 34 7800.00 6608.88 6561.88 47 51 7900.00 6676.43 6629.43 47 11 S 78 59 W 1008.78 S 79 10 W 1079.96 S 79 13 W 1150.69 S 79 5 W 1221.15 S 78 59 W 1291.36 S 79 17 W 1361.36 S 79 18 W 1431.15 S 79 14 W 1501.11 S 79 13 W 1571.73 S 79 24 W 1643.04 S 79 26 W 1714.98 S 79 13 W 1787.65 S 79 43 W 1860.83 S 79 55 W 1933.95 S 80 1 W Z006.88 S 80 12 W 2079.64 S 80 17 W 2152.12 S 80 10 W 2224.25 S 80 2 W 2296.10 S ~0 1 W 2367.77 S 79 56 W 2439.15 S 79 56 W 2510.22 S 80 6 W 2581.88 S 80 ZO W 2654.17 S 80 28 W 2727.17 S 80 20 W 2800.86 S 80 37 W 2875.15 S 80 26 W 2949.21 S 80 28 W 3022.32 2.97 3.80 3.13 2.25 3.21 2.75 0.67 0.88 0.01 0.55 71.52 S 269.44 W 278.77 S 75 8 W 80.73 S 321.46 W 331.44 S 75 54 W 378.39 W 389.16 S 76 29 90.93 S 102.28 S 439.49 w 451.24 S 76 54 W 114.66 S 504.12 W 516.99 S 77 11 W 128.07 S 572.82 W 586.96 S 77 24 W 141.75 S 644.36 W 659.76 S 77 36 W 155.36 S 716.35 W 733.00 S 77 46 W 169'05r S 788.03 W 805.95 S 77 54 W 182.86 S 859.60 W 878.84 S 77 59 W 0.79 1.52 2.07 0.74 0.37 0.63 0.62 0.29 0.73 1.00 196.70 S 930.83 W 951.39 S 78 4 W 210.49 S 1001.83 W 1023.71 S 78 8 W 224.17 S 1072.56 W 1095.74 S 78 12 W 237.64 S 1142.85 W 1167.30 S 78 15 W 251.03 S 1212.87 W 1238.58 S 78 18 W 264.58 S 1282.64 W 1309.65 S 78 Z1 W 277.97 S 1352.20 W 1380.47 S 78 23 W 291.14 S 1421.56 W 1451.07 S 78 26 W 304.33 S 1491.09 W 1521.83 S 78 28 W 317.66 S 1561.28 W 1593.26 S 78 30 W 0.74 1.06 0.73 0.96 0.52 0.21 1.01 0.71 0.59 0.38 331.10 S 1632.15 W 1665.39 S 78 32 W 344.37 S 1703.66 W 1738.11 S 78 34 W 358.05 S 1775.88 W 1811.62 S 78 36 W 371.57 S 1848.62 W 1885.59 S 78 38 W 384.66 S 1921.31 W 1959.43 S 78 41 W 397.53 S 1993.82 W 2033.06 S 78 43 W 410.24 S 2066.17 W 2106.50 S 78 46 W 422.63 S Z138.25 W 2179.61 S 78 49 W 434.94 S 2209.99 W 2252.38 S 78 52 W 447.37 S 2281.43 W 2324.88 S 78 54 W 0.96 0.95 0.95 0.54 0.80 1 0.79 0.79 0.27 0.97 459.88 S 2352.69 W 2397.22 S 78 56 W 472.39 S 2423.67 W 2469.28 S 78 58 W 484.88 S 2494.33 W 2541.02 S 79 0 W 497.45 S 2565.59 W 2613.37 S 79 Z W 509.88 S 2637.48 W 2686.31 S 79 4 W 522.14 S 2710.08 W 2759.92 S 79 6 W 534.52 S 2783.37 W 2834.23 S 79 8 W 547.06 S 2857.25 W 2909.15 S 79 10 W 559.34 S 2930.91 W 2983.81 S 79 12 W 571.60 S 3003.63 W 3057.53 S 79 14 W COMPUTATION DATE: O2-MA~-90 PAGE 3 ARCO ALASKA, INC. NGI-8 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 29-SEP-1989 KELLY BUSHING ELEVATION: 47.00 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SU~-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZo DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 8000.00 674&.74 6697.74 46 36 8100.00 6813.97 6766.97 45 54 8200.00 6884.05 6837.05 45 10 8300.00 6954.87 6907.87 44 30 8400.00 7026.43 6979.43 44 0 8500.00 7098,77 7051.77 43 21 8600.00 7171.85 7124.85 42 46 8700.00 7245.71 7198.71 42 5 8800.00 7320.26 7273.26 41 32 8900.00 7395.48 7348.48 40 40 S 80 21 W 3094.72 S 80 23 W 3166.26 S 80 30 W 3237.00 S 80 38 W 3307.02 S 80 40 W 3376.32 S 80 42 W 3444.82 S 80 46 W 3512.54 S 80 41 W 3579.43 S 80 26 W 3645.55 S 80 37 W 3710.88 0.88 0.96 1.06 1.07 1.00 0.68 1.19 1.01 4.56 3.66 583.76 S 3075.64 W 3130.55 S 79 15 W 595.81 S 3146.79 W 3202.70 S 79 17 W 607.51 S 3217.15 W 3274.01 S 79 18 t, J 619.03 S 3286.81 W 3344.59 S 79 20 W 630.31 S 3355.74 W 3414.42 S 79 ZZ W 641.40 S 3423.89 W 3483.44 S 79 23 W 652.39 S 3491.26 id 3551.69 S 79 25 W 663.18 S 3557.80 W 3619.08 S 79 26 W 673.94 S 3623.57 W 3685.71 S 79 28 W 684.83 S 3688.55 W 3751.59 S 79 29 W 9000.00 7471.32 7424.32 40 38 9100.00 7546.93 7499.93 40 56 9200.00 7622.45 7575.45 40 59 9300.00 7697.91 7650.91 41 7 9400.00 7773.10 7726.10 41 22 9500.00 7847.85 7800.85 42 0 9600.00 7920.76 7873.76 44 31 9700.00 7990.79 7943.79 46 27 9800.00 8058.87 8011.87 47 44 9900.00 8125.09 8078.09 49 34 S 80 27 W 3775.54 S 81 10 W 3840.48 S 81 57 W 3905.62 S 82 52 W 3970.92 S 83 44 W 4036.64 S 94 10 W 4102.91 S 85 21 W 4171.22 S 87 38 W 4242.57 N 89 52 W 4315.79 N 88 39 W 4390.62 1.55 2.21 1.07 I .17 0.59 1.12 2.29 2.55 2.10 3.49 695.40 S 3752.87 W 3816.75 S 79 30 W 705.91 S 3817.47 W 3882.19 S 79 31 W 715.58 S 3882.30 W 3947.70 S 79 33 W 724.30 S 3947.34 W 4013.24 S 79 36 W 731.93 S 4012.82 W 4079.03 S 79 40 W 738.96 S 4078.88 W 4145.27 S 79 44 W 745.29 S 4147.01 W 4213.45 S 79 49 W 749.68 S 4218.24 W 4284.34 S 79 55 W 750.99 S 4291.46 W 4356.68 S 80 4 W 749.98 S 4366.38 W 4430.32 S 80 15 W 10000.00 8187.62 8140.62 53 10100.00 8245.63 8198.63 56 4 10200.00 8299.50 8252.50 58 25 10300.00 8352.32 8305.32 57 44 10400.00 8406.15 8359.15 57 12 10500.00 8461.04 8414.04 56 8 10600.00 8517.36 8470.36 55 27 N 88 14 W 4468.46 N 88 51 W 4549.74 N 89 46 W 4633.88 N 89 45 W 4718.73 N 89 35 W 4802.92 N 89 37 W 4886.43 N 89 54 W 4968.99 2.84 2.83 0.47 0.84 0.36 1.69 I .83 747.53 S 4444.36 W 4506.79 S 80 27 W 745.46 S 4525.77 W 4586.75 S 80 39 W 744.49 S 4610.00 W 4669.73 S 80 50 W ) 744.15 S 4694.91 W 4753.52 S 81 0 W ' 743.60 S 4779.18 W 4836.69 S 81 9 W 742.95 S 4862.77 W 4919.20 S 81 19 W 742.60 S 4945.40 W 5000.84 S 81 28 W 10660.1 *** TIE-IN POINT GOING FROM GCT TO MWD ~ATA ¢SEE INTERPOLATED VALUES FOR CHOSEN HORIZONS). 10700.00 8574.50 8527.50 55 50 10800.00 8631.98 8584.98 55 1 10900.00 8689.46 8642.46 54 1Z N 88 1 W 5050.99 N 86 54 W 5132.45 N 85 47 W 5213.92 0.51 0.77 1 .O3 741.92 S 5027.47 W 5081.92 S 81 36 W 737.30 S 5109.15 W 5162.08 S 81 47 W 732.68 S 5190.84 W 5242.29 S 81 58 W 10925.00 8703.83 8656.83 54 0 N 85 31 W 5234.28 0.00 731.53 S 5211.26 W 5262.35 S 82 1 W COMPUTATION DATE:- OZ-HAR-90 PAGE ARCO ALASKA. [NC. NGI-8 PRUDHOE BAY NORTH SLOPE. ALASKA DATE OF SURVEY: 19-SEP-1989 KELLY BUSHING ELEVATION: 47.00 FT [NTERPOLATEO VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG H[N DEG MIN 0.00 0.00 -47.00 0 0 1000.00 1000.00 953.00 0 18 2000.00 1999.98 1952.98 0 21 3000.00 2999.63 2952.63 4 59 4000.00 3950.25 3903.25 30 21 5000.00 4683.92 4636.92 46 29 ENGINEER: PORTER VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 0.00 S 45 50'E 0.03 0.57 N 86 16 E -4.65 0.71 S 56 35 W -6.28 2.62 S 79 51 W 27t.85 2.97 S 79 ! W ~37.33 0.79 0.00 N 0.00 E 0.00 N 0 0 E 2.40 S 0.06 E 2.40 S 1 22 E. 2.18 S 4.73 E 5.21 S 65 14 E ) 12.11 S 6.73 E 13.86 S 29 3 E T1.SZ S 269.¢4 W 278.77 S 75 8 W 196.70 S 930.83 W 951.39 S 78 4 W 6000.00 5383.93 5336-93 46 23 S 79 24 W 16¢3.04 0.74 331.10 S 1632.15 W 1665.39 S 78 32 W 7000.00 6065.22 6018.22 46 18 S 80 1 I,,t 236T.TT 0.96 459.88 S 2352.69 1,1 2397.22 S 78 56 W 8000.00 6744.74 6697.74 46 36 S 80 21 W 3094.72 0.88 583.76 S 3075.64 N 3130.55 S 79 15 W 9000.00 7471.32 7424.32 40 38 S 80 27 W 3775.54 1.55 695.40 S 3752.87 W 3816.75 S 79 30 W 10000.00 8187.62 8140.62 53 0 N 88 14 W 4468.46 2.84 747.53 S 4444.36 W 6506.79 S 80 27 W 10660.1 ~:qc TIE-TN POINT GOING FEO/~ GCT TO MWD DATA CSEE INTERPOLATED VALUES FOR CHOSEN HORIZONS). ~** 10925.00 8703.83 8656.83 54 0 N 85 31 t4 5134.28 0.00 731.53 S 5211.26 W 5262.35 S 82 I W COMPUTATION DATE: O2-MAR-90 PAGE 5 ARCO ALASKA, INC. NGI-8 PRUOHOE 8AY NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN DATE OF SURVEY: 29-SEP-1989 KELLY BUSHING ELEVATION: 47.00 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0.00 0.00 -47.00 0 0 N 0 0 E 47.00 47.00 0.00 0 3 N 78 44 W 147.00 147.00 100.00 0 5 S 14 31 W 247.00 247.00 200.00 0 10 S 3 48 W 347.00 347,00 300.00 0 12 S 54 22 E 447.00 447.00 400.00 0 11 S 6 21 E 547.00 547.00 500.00 0 11 . S 0 12 E 647.00 647.00 600.00 0 17 S 11 22 W 747.00 747.00 700.00 0 6 S 32 53 W 847.00 847.00 800.00 0 16 S 3 33 W 947.00 947.00 900.00 1047.00 '1047.00 1000.00 1147.01 1147.00 1100.00 1247.01 1247.00 1200.00 1347.01 1347.00 1300.00 1447.01 1447.00 1400.00 1547.01 1547.00 1500.00 1647.01 1647.00 1600.00 1747.02 1747.00 1700.00 1847.02 1847.00 1800.00 0 8 S 13 24 W 019 S 69 I E 0 22 S 84 43 E 0 10 S 56 28 E 0 24 S 50 27 E 012 S 70 gE 0 14 S 51 23 E 0 14 N 36 49 E 0 26 N 14 50 E 0 34 N 57 9 E 1947.02 1947.00 1900.00 2047.03 2047.00 2000.00 2147.03 2147.00 2100.00 2247.04 2247.00 2200.00 2347.05 2347.00 2300.00 2447.05 2447.00 2400.00 2547.05 2547.00 2500.00 26¢7.07 2647.00 2600.00 2747.08 2747.00 2700.00 2847.10 2847.00 2900.00 FEET DEG/IO0 FEET FEET FEET DEG MIN 0 24 S 77 49 E 0 45 S 84 42 E 0 40 S 87 49 E 038 N 73 5/ E 036 N $8 5 E 023 S 62 35 E 0 42 S 66 53 E I 9 S 57 45 E 0 59 S 29 35 E I 38 S 14 16 W 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 N 0.00 E 0.04 0.12 0.04 S 0.04 W 0.11 0.00 0.21 S 0.11 W -0.06 0.56 0.53 S 0.08 E -0.20 0.23 0.73 S 0.23 E -0.22 0.16 1.10 S 0.26 E -0.22 0.55 1.45 S 0.27 E -0.04 0.07 1.72 S O.1l E -0.03 0.32 2.02 S 0.11 E 0.08 0.04 2.24 S 0.00 E -0.19 0.13 2.55 S 0.28 E -0.68 0.12 2.63 S 0.77 E -1.25 0.40 2.76 S 1.36 E -1.58 0.62 3.08 S 1.69 E -2.16 0.75 3.43 S 2.28 E -2.36 0.67 3.67 S 2.49 E -2.68 0.86 3.60 S 2.81 E -3.02 0.43 2.96 S 3.13 E -3.42 1.08 2.32 S 3.51 E -4.34 0.20 2.22 S 4.42 E -5.09 1.19 2.21 S 5.18 E -6.34 0.37 2.13 S 6.42 E -7.43 0.49 1.92 S 7.50 E -8.56 1.71 1.82 S 8.63 E -9.08 0.61 1.97 S 9.16 E -9.!33 0.34 2.35 S 9.92 E -11.24 0.21 3.07 S 11.35 E -12.47 0.31 4.38 S 12.63 E -12.77 3.02 6.26 S 13.00 E S 52 50 W -9.67 2.47 S 61 54 W -2.21 2.49 S 75 35 W 9.38 2.83 S 76 19 W 25.59 2.24 S 76 10 W 45.62 2.04 S 77 28 W 68.91 2.06 S 78 48 W 96.35 3.08 S 79 16 W 129.70 3.06 S 79 24 W 169.42 2.94 S 79 25 W 215.93 3.24 2947.22 2947.00 2900.00 3 47 3047.60 3047.00 3000.00 6 9 3148.37 3147.00 3100.00 8 4 3249.73 3247.00 3200.00 10 37 3351.81 3347.00 3300.00 12 25 3454.59 3447.00 3400.00 14 14 3558.41 3547.00 3500.00 17 3 3663.96 3647.00 3600.00 20 15 3771.75 3747.00 3700.00 23 31 3882.27 3847.00 3800.00 26 56 0.00 N 0 0 E 0.00 N 0 0 E 0.06 S 44 18 k 0.23 S 27 3 W 0.54 S 8 35 E 0.77 S 17 29 E 1.13 S 13 11 E 1.48 S 10 43 E 1.72 S 3 31 E 2.02 S 3 2 E 2.24 S 0 7 E 2.56 S 6 21 E 2.74 S 16 23 E 3.08 S 26 7 E 3.51 S 28 49 E 4.12 S 33 42 E 4.43 S 34 14 E 4.57 S 38 0 E 4.31 S 46 35 E 4.21 S 56 34 E 4.95 S 63 ZO E 5.63 S 66 54 E 6.77 S 71 40 E 7.74 S 75 39 E 8.82 S 78 5 E 9.36 S 77 53 E 10.20 S 76 42 E 11.76 S 74 53 E 13.37 S 70 53 E 14.43 S 64 18 E 9.80 S 10.03 E 14.02 S 45 39 E 14.47 S 2.74 E 14.73 S 10 42 E 19.20 S 8.69 W 21.08 S 24 22 W 22.87 S 24.78 W 33.72 S 47 18 W 27.76 S 44.65 W 52.57 S 58 8 W 33.19 S 67.76 W 75.45 S 63 54 W 38.89 S 95.01 W 102.66 S 67 44 W 45.24 S 128.15 W 135.90 S 70 33 W 52.69 S 167.63 W 175.72 S 72 33 W 61.35 S 213.85 W 222.48 S 74 0 W COMPUTATION DATE: 02-MAR-90 PAGE 6 ARCO ALASKA, INC. NGI-8 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 29-SEP-1989 KELLY BUSHING ELEVATION: 47.00 FT ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HQRIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 3996.23 3947.00 3900.00 30 15 4114.29 4047.00 4000.00 34 5 4238.22 4147.00 4100.00 38 13 4368.49 4247.00 4200.00 41 48 4507.62 4347.00 4300.00 46 8 4654.11 4447.00 4400.00 47 9 4800.50 4547.00 4500.00 47 0 4946.39 4647.00 4600.00 46 28 5091.34 4747.00 4700.00 46 21 5235.32 4847.00 4800.00 45 40 S 79 50 W S 79 58 W S 79 30 W S 79 6 W S 79 3 W S 79 15 W S 79 10 W S 79 OW 269.97 2.91 332.07 3.6t 404.48 3.3t 486.98 3.43 582.49 2.32 688.31 0.31 793.98 O.O0 898.93 0.74 1.32 0.80 S 78 56 W 1002.59 S 79 11 W 1104.94 71.19 S 267.57 W 276.88 S 75 6 W 82.12 S 329.32 W 339.40 S 76 0 W 95.16 S 401.30 W 412.43 S 76 40 ~, 110.62 S 483.30 W 495.80 S 77 6 W 129.11 S 578.20 W 592.44 S 77 25 W 149.10 S 683.37 W 699.44 S 77 42 W 169.12 S 788.39 W 806.32 S 77 54 W 189.27 S 892.68 W 912.52 S 78 2 W 209.29 S 995.68 W 1017.44 S 78 8 W 228.91 S 1097.39 W 1121.01 S 78 13 W 5378.20 4947.00 4900.00 45 25 5520.39 5047.00 5000.00 45 17 5661.82 5147.00 5100.00 44 55 5803.26 5247.00 SZO0.O0 45 20 .5946.52 5347.00 5300.00 46 10 6091.83 5447.00 5400.00 47 2 6239.56 5547.00 5500.00 47 45 6388.07 5647.00 5600.00 47 30 6535.86 5747.00 5700.00 47 17 6682.77 5847.00 5BO0.O0 46 59 S 79 7 w 1205.80 S 78 58 w 1305.67 S 79 17 W 1404.51 S 79 14 W 1503.39 S 79 15 w 1604.81 S 79 27 W 1709.06 S 79 26 W 1816.57 S 79 55 W 1925.24 S 79 59 W 2033.00 S 80 14 W 2t39.64 0.26 0.72 0.69 0.76 0.92 1.26 0.60 0.50 0.54 0.56 248.09 S 1197.62 W 1223.05 S 78 18 W 267.35 S 1296.86 W 1324.13 S 78 21 W 286.14 S 1395.08 W 1424.13 S 78 25 W 304.77 S 1493.36 W 1524.14 S 78 28 W 323.91 S 1594.15 W 1626.72 S 78 31 W 343.27 S 1697.77 W 1732.13 S 78 34 W 363.47 S 1804.62 W 1840.86 S 78 37 W 383.12 S 1912.65 W 1950.65 S 78 40 W 402.11 S 2019.79 W 2059.43 S 78 44 W 420.50 S 2125.84 W 2167.03 S 78 49 W 6828.61 5947.00 5900.00 46 30 6973°62 6047.00 6000.00 46 23 7117.92 6147.00 6100.00 45 55 7261.88 6247.00 6200.00 46 33 7407.95 6347.00 6300.00 47 15 7556.25 6447.00 6400.00 48 7 7706.98 6547.00 6500.00 48 32 7856.58 6647.00 6600.00 47 28 8003.29 6747°00 6700.00 46 36 8147.31 6847.00 6800.00 45 29 S 80 13 W 2244.84 S 80 2 W 2348.86 S 79 57 W 2451.90 S 80 I W 2554.47 S 80 20 W 2659.96 S 80 26 W 2768.53 S 80 38 W 2880.34 S 80 26 W 2990.66 S 80 20 W 3097.09 S 80 39 W 3199.84 0 ,.44 1.26 0.85 0.14 0.82 0.44 0.51 0.42 0.86 1.28 438.48 S 2230.46 W 2273.15 S 78 53 W 456.57 S 2333.90 W 2378.14 S 78 56 W 474.64 S 2436.35 W 2482.15 S 78 59 W 492.66 S 2538.33 W 2595.70 S 79 I W 510.86 S 2643.23 W 2692.14 S 79 4 W 529.06 S 2751.22 W 2801.62 S 79 7 W 547.91 S 2862.41 W 2914.38 S 79 10 W 566.31 S 2972.14 W 3025.61 S 79 13 W 584.16 S 3077.99 W 3132.94 S 79 15 W 601.39 S 3180.19 W 3236.56 S 79 17 W 8288.95 6947.00 6900.00 44 36 8428.57 7047.00 7000.00 43 52 8566.11 7147.00 7100.00 42 56 8701.74 7247.00 7200°00 42 5 8835.58 7347.00 7300.00 41 15 8967.98 7447.00 7400.00 40 34 9100.09 7547.00 7500.00 40 56 9232.51 7647.00 7600.00 40 56 9365.24 7747.00 7700.00 41 17 9498.86 7847.00 7800.00 42 0 S 80 41 W 3299.33 S 30 42 W 3395.98 S 80 45 W 3489.68 S 80 40 W 3580.58 S 80 57 W 3668.83 S 80 32 W 3754.90 S 81 10 W 3840.54 S 82 11 W 3926.81 S 83 30 W 4013.75 S 84 9 W 4102.15 1.08 I .51 0.97 1.00 4.30 1.12 2.20 1.18 0.92 1.10 617.78 S 3279.15 W 3336.84 S 79 20 W 633.52 S 3375.30 W 3434.24 S 79 22 W 648.68 S 3468.51 W 3528.64 S 79 24 W 663.37 S 3558.94 W 3620.14 S 79 26 W 677.81 S 3666.72 W 3709.18 S 79 28 W 691.96 S 3732.34 W 3795.94 S 79 30 W 705.92 S 3817.53 W 3882.25 S 79 31 W 718.52 S 3903.41 W 3968.99 S 79 34 W 729.38 S 3990.01 W 4056.13 S 79 38 W 738.88 S 4078.12 W 4144.52 S 79 44 W COMPUTATION DATE: OZ-MAR-90 PAGE 7 ARCO ALASKA, INC. NGI-8 OATE OF SURVEY: Z9-SEP-1989 PRUDHOE BAY KELLY BUSHING ELEVATION: 47.00 FT NORTH SLOPE~ ALASKA ENGINEER: PORTER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERI'TY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 9637.08 7947.00 7900.00 45 18 9782.39 8047.00 8000.00 47 27 9934.19 8147.00 8100.00 50 40 tOlOZ.44 8247.00 8200.00 56 8 10290.03 8347.00 8300.00 57 49 10~74.69 8447.00 8400.00 56 28 10651.72 8547.00 8500.00 54 45 10826.13 8647.00 8600.00 54 48 10925.00 8703.83 8656.83 54 0 S 86 '8 W ' 4197.40 S 89 51 W ¢302.79 N 88 11 W 4416.81 N 88 52 W 4551.76 N 89 47 W 4710.30 N 89 33 W 4865.39 N 89 50 W 5011.34 N 86 36 W 5153.74 N 85 31 W 5Z34.Z8 2.76 1.99 3.42 2.83 0.74 0.99 2.14 0.84 0.00 747.22 S 4173.14 W &239.50 S 79 51 W 750.99 S 4278.46 W 4343.87 S 80 3 W 749.23 S 4392.61 W 4456.05 S 80 19 k 745.42 S 4527.78 W 4588.73 S 80 39 W 744.19 S 4686.48 W 4745.2.0 S 80 59 W 743.11 S 4841.71 W 4898.40 S 81 16 W 742.47 S 4987.78 W 5042.74 S 81 32 W 736.0g S 5130.50 W 5183.03 S 81 50 W 731.53 S 5211.26 W 5262.35 S. 82 I W ARCO ALASKA. INC. NGI-8 PRUOHOE BAY NORTH SLOPE. ALASKA MARKER SAG SHUBLIK TOP SADLEROCHIT ZONE 4 ZONE 3 ZONE Z GCT LAST READING MWD FIRST READING ZONE lB PBTD BASE SADLEROCHIT TD COMPUTATION DATE: OZ-MAR-90 PAGE 8 DATE OF SURVEY: Zg-SEP-1989 KELLY BUSHING ELEVATION: 47.00 FT ENGINEER: PORTER INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 98' FNL & 965' FWL. SEC1Z TllN R14E MEASUREO DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 10834.00 8651.52 8604.52 735.73 S 5136.93 W 10925.00 8703.83 8656.83 731.53 S 5211.26 W 9951.00 8157.59 8110.59 748.80 S 4405.66 W 10024.00 8201.95 8154.95 746.96 S 4463.60 W 10096.00 8243.38 8196.38 745.54 S 4522.46 W 10096.00 8243.38 8196.38 745.54 S 4522.46 W 10267.00 8334.77 82~7.77 744.27 S 6666.97 W 10368.00 8388.85 8341.85 743.80 S 4752.27 W 10660.10 8551.83 ~504.83 742.45 S 4994.63 W 10700.00 8574.50 ,8527.50 741.92 S 5027.47 ~ 10717.00 8584.27 8537.27 741.13 S 5041.35 W 10820.00 8643.48 8596.48 736.37 S 5125.49 W COMPUTATION DATE: 02-MAR-g0 PAGE 9 ARCO ALASKAt INC. NGI-8 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER SAG SHUBLIK TOP SADLEROCHIT ZONE 4 ZONE 3 ZONE 2 ZONE tB PBTD BASE SADLEROCHIT TD DATE OF SURVEY: Z9-SEP-1989 KELLY BUSHING ELEVATION: 47.00 F'T ENGINEER: PQRTER ~,~~ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 98' FNL & 965e FWL, SEC12 T11N R16E MEASURED OEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 9951.00 8157.59 8110.59 748.80 S 10024.00 8201.95 8154.95 746.96 S 10096.00 8243.38 8196.38 T45.54 S 10096.00 8243.38 9196.38 74,5.54 S 10267.00 8334.77 8287.77 764.27 S 10368.00 8388.85 8361.85 743.80 S 10717.00 8584.27 8537.27 741.13 S 10820.00 8643.48 ,8596.48 736.37 S 10834.00 8651.52 8604.52 735.73 S 10925.00 8703.83 8656.83 73t.53 S 4,40 5.66 W 4663., 60 W 6522.46 W 4522.46 W 4,666.97 W 4752.27 W 5041.35 W 5125.49 W 5136.93 W 5211.26 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH · FEET DEG MIN 10925.00 8703.83 8656.83 5262.35 S 82 1 W SCHLUMBERGER O I RE C T I ONAL SURV E Y COMPANY ARCO ALASKA, INC. NELL NOI -8 FIELD PRUDHOE BAY COUNTRY USA RUN DATE LODGED TWO · 2:9- SEP - 89 REFERENCE 93688 WELL · (98' NGI-8 ~-~ · HORIZONTAL PROJECTION FNL, 965' FWL, S 12, TllN, R14E, UM) 4000 3OOO 1ooo -1000 -ZOO0 -3000 SOUTH -4000 -6000 N£ST REF ?~688 SCALE : 1/1000 IN/FT · · : ' ~ : . · : · . : ~ : ........ : . : ~ : : . ' · . : · ~ ~ ...... ; : , : : : : : . . ; : : ' . I ........ --i..-?i---~--r?'-r-? ..... m"?'"r' "?-r'?'--i ....... ?i..-?-?--!---t---!.-?-i---.-i..-~.--~-.i..-?-t.--t..-r--~ ....... ?.--?.-.t...-?-?i---i..-?-! ..... ??.t..-i.-.t ....... ~.--.?.--~ ....... ?'i'"?'-bt"-i ............. i"-H-+ --4"-~ ..... ~ ....... ~ .................. 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SCALED IN VERTICAL BEP'THS HORIZ SCALE = 1/1000 IN/fT Eastman ~ ~, Whipstock~2 A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY Atlantic Rich£ield COMPANY N. G. I. #8 WELL NAME · Prudhoe LOCATION JOB NUMBER A876 GO166 TYPE OF SURVEY Gyroscopic DATE 8-24-'76 SURVEY BY Jay Martin OFFICE Alaska COHPLET[ON REPORT AUGUST 18, !976 AU 411-0-70 ATLANTIC RICHFIE.LD ...... C/{).~P,A.NY /~L,L..NO..NG.!_-8 A876-GOI66 ...................................... GYi~OSCOP~C SURVEY. ~ ~.DECL!NATION ~I DEG, EAST CO~P~TED FOR. EAST. HAN_~WHI.p. sTOCK ..... .!NC. ~Y F...~',~.. L!.NDSE.Y .... RECORD OF SURVEY ALL CALCULATIONS PERFOI-{i',,'IED' BY I i3. /',,~ ELECTRONIC COIviPUTFR 2O0 2 300 2 500 0 5 499,99 ~52,99 N fl,OOE S~,6V ~.: :1.'1i, o74 w ~0o07 I'~ 1Z 500 .... 0 0 ......... 599",99 ........... 552,99--N 8,OOE - 821,7~ N 17~,73 w ~aO,!~ N 12 700 0 5 699.99 652.99 S88.00E 82!.52 N 17~.68 W 8~0.18 N Il il 800 0 !0" ..... 799'.'99 ............ 752.99-' S20.OOE ~2 900 0 5 899,99 852,99 S45,00W 52 ........ !000 ........ 0'~'5 9'9'9",-99---'9'52-,'99 ...... S16','O~OW- '-~2 IlO0 ...... 0~"15 ..... ~'099.99 ...... 1052,99 S21.OOW ...... 82 1200 0 5 1!99,99 1152,99 S !,OOE . 82 1300 0 ....... 0 ~'"29-9-,'¥9 ..... ~252,99 S 1,OOE 82 1400 .... 0 .... 0 ..... !-399,-99 ...... 1352.99--S I,OOE ...... 82 1500 0 ..... 0 .......... 1'499,99' '-!~52.99 S !.OOE 82 1,69 N 17a.5! W 840°02 1,4S N 17a.55 W 539,82 1.23 N 17a.70 w 699.61 0.~I N !7~.8~ W 839,23 0.52 0,45 0,45 O,a5 16{)0 0 5 1599,99 1552,99 t!j O, OOT 82 O, ~z* ~' 174,84 W 83~..86 .. "" .... "74 64 V,' ~7C'0 0 !5 1699.99 !55~.,99 N~2,00~ 8Z0,63 N ~ . .. ].~00 0... 5 1799,99 ~752,9 ..... ..... ...... ..... 200~ _ ~. 0 !0 1999.99 ~952,99 ~81,OOE 82!,12 ~w !74.07 W ~.39,37 - 2100 0 !5 2099.99 2052,99 $ 2,00W 820.91 X 173.83 w ~.39.3.! 21A2.99 S 2252.99._ SIO.OOE ~ lC. ~'rl 2'~":' 2, °9 52!,00 2200 ...... 0 .... 2'0 ..... 2'1"99'.'99 2300 0 20 22o9,9g 2aO0 0 20 23q9,99 0 0 200,00 153,00 N 8,00E 82!,62 N 174.,76 W 840,00 N '1 0 0 300,00 253,00 N 8,00E 82!.62 .~' 174..75 W ~-4-0.00 N 1 !I 12 12 ~2 !2 !2 -- -- !2 ,. -- !! II .. !i !! 0 0 0 0 59 59 59 0 ! 2 0 2 0 2 0 4~ W ........... 0,080 .............. 35 , ... 0,160 . 2. 29 ~,,' 0,022 2~'~ w._.. 0,090 ............... w.._ O.UO0 ..... 2'0.23 ,, ' ~ TRUE .............................. DOG LEG MEAS, DRIFT VERTICAL SUB DRIFT TOTAL COORD!NA'TE'S ............... C L 0 S U' R' E S SEVERITY SECTION DEPTH"ANGL-E ...... DEPT'H .............. SEA ....... DIREC ........................ DISTANCE A~'~GLE" D~'~/." ~"'dOFT' . ........................ DISTANCE ~ ....o .... o ......... o ................ 0-;'-0"0"'"": ......... ~z~7"oo ........ ~ ~"o"0~ ~'2 ..... N i'7'~;-;%'j[~? ............. ~'-6",0o ..... N i2 o' 2e,_ .,... ............... o..~...oo .............. .......... i'-O0 ...... o ...... o : g~6,0o-' ........ ~Y'"OO'~N 8'.O0'F_ ...... ~Si ..... ~ ............ iC:F~:fg-'~,;.' ~+'0''°'° ...... ~ ...... i'~ ......... 0 .... ~ .~. W 0.000 .................... :~ 10. ~+. RECORD OF SURVEY }'EP"T H'-'AN'~-~"E' ..... D-E-P'~ N ...................... sEA ............... D I RE C D.I 5 T_ANC E ................... ANGLE .......... D.EG/iO0.FI .......... D I $ T ANCE D N DEG. .D ...... FI.. 5. 2?00 0 45 2599 · 97 2652 · 97 ....... ~..~..9.,...0~_~ .......... ~_i~.~...,.60 N Z ?~._,.~..~ W ~.3~_,_62~~~5~_~~_Q~~-Q.7..-~ -2"8-00 ~ 0~2-? 99 · 9-5 ............. 2 T ~ 2.96 .......... S 15 '.O 0 E .......... 8_Z..5_..1 ~._..._N ............. !72 .Q.2_W .............. 8_3.3 ..1_0 ..... !~__ii__~..~ ..... 5_8_~ .... ~_,250 ............... 2.0 Z · ~ 3 ....... 2900 2 45 2899,90 28~2.90 5~'0.50w 8~2,07 ~ 172.?~.W ........ 830,2~..N i2 0..2~ W .................... l,.T..~ ........... 207,69 BO00 ~ 45 2999.68 2952,68 555.00W 807,69 N 17..7_,_5~ W__ 8.g_~.~_9..7_B_12~.~_5.P_N~~.02. 212.,32 -3300 .... 10 ...... 30 ......... 3296.83 32~9.~3 sso.,..O.Q~ 7..9....fi...,.~6 ....... N ....... 2_!_5~_!..9 W 8_2~3.19 N 15 9 15 ~ ~_,3_0_7 .~2.~9,37 -3'4'00 ....i~'~ ..... 3394",'73 .... 3347'.'?'3 .......S80.OOW 791,02 N ......... 235.,2~_W ........ .Bg.5.,._2.5_N ..... !6 3Fi ...... .4.4._.W ...... .2~_5.0Q .................. 269.25 -3500 i5 ...... 0 .......... 3~gz.T5 344~.~5 .... 580.50W ........... ~'~6.93 N ........... 259..09 W ................. 62..8_,_~8._~ ...... ~8_.~3 2.5 W _2,0.00 .......... 292.89. -3600'~18 ...... 0 ......... 3587,52" 35~0.62 ..... SSl,OOW ............. 782,36 N 287,12 .W 833,38_~_2.p .... 9_._9 W~~_O_O.O. . 32.0.,70 -'3700-2~'~--5"5 .....3681,90 ...... 363a'.90 ....... 581.00w 777.15 N 320_..02__.W_ .... 840...E6_N_22__2g_54 W 2~..9~P ~3.35 ..... ~800'~2a ..... 0 ....377&,30 3727,30 581,00W 771,17_N ....... 357376 ..... W ............ 8_.5.0,._~2 N._24_.~3 ~.5 W 3._0__~_0 ..... 390.80 -3900 27 ...... i5 ....... 385~,z, 5 3817,z~9 580,50w 764,_22 ~ 400,~4 W ~&..23_7_~_2_~.~ 14 W 3_,~2 . ~33.,13 -~'~'oo ..... ~ ~ ..... ~ ....... ~o ~ 7. ~-~ ~ ~o'. ~: s~ ~. oow-i~.7'__'~ a~-~U'~U'~'~"~'~',~?75_:~:F ........ ~OtO~.~L'~7~.N_~.~__~ ....... ~....w_. ~_.~_~ ................ ~ ~ ~. ~.. -4200-36 .... ~5 ........ 4119.09 ~072,09 581.00W 7~0.2& N 556.55 W__926.~4 N 36 ~_6__1.3 %' _~.~_9 S5_8....0.6 ~4'00'~-43 ..... 0 ~272.99' a225.99 579.00W 718,62 N 582.,~6 W ..... 9._90~_9! ....N_~__3~..77 W 3._,.~_3..8__ 712.7i -4500-'46 ........... 0 ..... ~-34'4'.3i ...... 4297.3i S7g,50W 705.55 N 7_5.1_~1i W 103_~_5~_~ ~7~9 W 3~_O~l 7.8..0.,94 4600 47 30--4412.S3 4365.83 S79.50W ~92,28 ~X ~22.73 W iQ_~5~._2_~_ _N_A9 55 16 W i_._5_00 ~1.,91 . 5200 ~6 0 4821.25 ~774.25 SSI.OOW 516.26~_N .... 1255~2.~__139.8..,..70 ..... N_6.~J .... 51__2.8 W ....... 1,~..6~ ............. 1281.11.. 5300 45 0 4890,72 4843,72 S81,50W 605,32 N 1326,71 W i458,2~ N 65 2~ 29 W ...... Q-~-O ..............1351.,66 . : ....... A~_L_..L.._.~A_L,qU..LAZ.! .0. ~N.5,..?.E RFO R N E.L). BY.,.._[ B....N.,._~;..L.g_C..3r~Q N.I ¢ .... COM PUI..E[~ MEAS,"DR-I-'FT--'~'ER-T[CAL SUB DRIFT TOTAL CO0..~.~_I_~..AZ..E.5_ ......... q_.b_...O .... 5~..U_R E._..S ...................... SE. VER..!.~.Y SE.~%[.,ON. _D. EP.T.H _.ANG.~E ............ _D.EP?.N ............... SEA ................. D.I..REC D.I STANCE .....ANGLE DEG/~OOFT .................. 1,~ I STANC. 6100 47 20 5~+48,76 5~01. 6200 ~-i0 ........ 5515,'99 - 5~68, 6~00 ~8 0 56~9.~8 5602. 6500'-~7 .... 30 571~,72 ....... 5669, 670~ ~7 10 5852,05 5805. .... 6~00 ~7 0 5920,!4 5873. ~900 ~6 BO 5988,66 YO00 ~6 20 5057,50 5400 45 ..... 3_5_ 4950,4.4. 4913,44 ...... $8!'5.0W ............... ~59.4_.,.72.._..N ............. !_397.,61..W ........ !.5!8.,89 N..56 56. 5.5 W ...... 0,~10 ...................... 1422,0~. ..... 5500 ~4..5 ..30 .......... 50.3.0_,48 .... z+983,48 ....... SS.!,DOW .......... 58~_,_1Z N ...... lZ+58_.,2~ .... w ............... ._!_580..,.! 6 ~... 68 18 ..... l l_ w ...... 0,090 ................. 1492.,11. ...... 5700..._~5 ...... ¢ ....... 5.~7..!,.59 ..... 5!.2~,59 581,00W ........... 562.~9.2 .....[~ ........... .!608,33..W ......... !70~.,00.. N -/0... ~2 ..... ~5_. w 0,;5~ ............... 16~! 6000_ ~7.. 0 ..... '5.~_80..,78 ...... ~333,~8 580,50w 528,3.5.._.~..~,~~~~ i895,67.N .73.. ~8 ........ ~8 W ....... Z,O?O .................. 76 S80,OOW ............51.5,9..3 ...... N ......... 1892.82 ..... W ......... 1961,88...N 7~ .45 .... 11 W ............. 0.,434 .................. 191~..,~8 68 SSZ,OOW .......... &91,~2 .... ~ ...... 203g,~3..W .... 2097~70 N 76 27.. 5 W ....... 0,~73 ............. 20~8~68 48 .SSZ,O0~ .............479,78. N .... 2112,82 W .... 2166,61 N..77 ~2__22 W ........0,~70 ................. 28 S81.OOW ......... ~.56_,66 N .... 2258,.79 ..w ........ 23o~,~6 N_78 34 .... z2_._w ........... o,ooo .................. 2276..,.~.0. 05 582,00W .......... ¢~5,79 .... N 2331,~8 .W_ ..... 2373,.72 N..79. 10_.30 W ...... 0,631 .................. 2,~ ..82 OOW ~35~.60 N 2z~O~,O0 W 2~3.~_!5 N 79 ~3 4~ W 0,170 2~:" 60 50 S82,00W ~5,38 N Z%Q.Y,...~¢ ........ 258!,50 N.._80 ~ 25 W .......... 0,~50 ............. 7~00 ~5 _55_ .626~,98 ....... 62~7~98 583,00W ........... ~85~8~_N ..... 2762,6~ .... W ..... Z. 7.89~3 N, 82 _ 2_.56 W ......... 1,072 ............ 2776,72 ..... 7~00 ~7 30 6332,90 6285,g0 S83,50W 377,21 ...................... N 2835~0 W 2860,48._N 82_2~ ..... I?_W ......... 0.,.63.~ ....... 28~9_,.Ib 7500-4'8--~'0--6'~'-g9-,"8'2---6'35'2','82 ..... 583',"50W 3~"8',80 N 2909,33 W 2932,62 N 82 ~6...31..W ....... ~,000 ..............2922,57 7600 48--'~0-" 6465,97 6ale,97 583,00W 359,99 t~ 2983,8! W 3005,44 N _83 7__14 _W ....... 0,~29 .................. 2996,59 .................................................... 7700 49 20 5531,57 6484,~7 583,50W 351,12 N ~058,76 W 3078,85 N...83 Z.7 ......... 5_..W ........0 .729 .............3071, ...................... -- . ...................... - ...................................... · , ~ ' 09 '- ~52,2B N 83 46 21 W 0,937 ......... 7~00 48 ~5 6597,22 5550,22 58~,50W 341,92 N ~33,63 W 3 7900 ~7 _30 ..... 666~,07 ............................... 6617,07 ..... 582,50W 332,22 N 3207,36 W 322~,52 N.81+ ...5..~O.W ................ 1,090 ............... 3218,73 8000 ~7 0 6731,95 66~,95 583,00W 322,95 N ~.~80,~O W .~ 3296,06 N 8~ 22 37 W .... 0.,55'7 ................. 3291,1.0 ............................................... ~:~.~ -,~ ......... ~ ~ ,~t ~ ~- :~ ,.',~-..-~: 8100 45 15 6800,63 6753,63 582,00W 313,46 N 3352,26 W 3366,89 N_8~ 39 28 W .... 0,91~ ..... 3362,09 8200 ~5....30 ...... 6870,25 ..... 5823,25 582,_00W .......... 303,4T N ..... 3z+23..,..3.5...W ........... 3~6,77 N.8~ 55 2 W 0,750 .... 3433,27 'r u[ ......... D'E P TH ..?N.~_~.E .............. ~.E.P.Z.H ......................... SEA ............... D !.R.~C. D [5.TANC[ ............ ANGLE DEG/ZOOFT ................ 'DISTANCI ................................................D N DEG. D 850U 43 45 7083.62 7036.62 S83.00W 275,3~ ~,6~2...3.~ W . .~6.4.~ ..... 75 N,,,__85 ..... 39 .... 51~ .... W ............ 0..721 ............... 3640..8~_ 8600 ~3 .....0 ....... 7!_56_,_3.Z ......7109.3l 582.00W ............266.~7 ........ N ............. ~?O0.al_ W ........ 3709~9.9._N 85 52 57 W ........... 0.883 ...... 3'/0~.~7.. 8700 ~2 .... ~0 .......... Y2.29.94 ~182.9~ 582.00W ............256.95 N ......... 3767.42_ W ......... 3775.18 N 85 5 ..5~ W ........ 0.830 3775.01. ......... ~ 8 O0....,&,2 ........ 0 ..... 7.~.04_.,_,Z.,5 .... y257.25 ....... 582.00w 8900 &Z _5 .........Y379..00 ..... 7332.00 S82.OOW ......... 23.8..5e, .... N ....... ~89.9.51..,,,,' ....... 3906.81 N,_.86 29.._50 w ............. 0.935 ..... 3905.18... 9100 ~! ~0 7529.50 7482.60 583.50W .... 22.2,64_~ 9200 ~ ..... 15 ...... 7'6'0-~'~"54- .....7557.54 SS~.flOW 215,7~ N ~095.85 W 0300 ~! 35 7579.63 7632.53 585.00W 209,68 N a161.7~ W ~!67.02 N 87 6 56 W ..... 0.~05 4166.92 9aO0 42 0 775~. 18 7707.18 585.00W 95C0 ~2'-~0---7828-.'~0---7781.20 586.50W 198.89 N 4295.18 w 4299.79 N 87 20 55 W 0.81~8 ~199.'77. 9600 ~4_ 55 .... 7900.4.7 .... 7853.&7 587.00W !94.97 N a36a.!7 w 4368.5~.._N 87 25 30 w .......... 2.4~3 ........ ~358.52 9700 47 0 7969.98 7922.98 589.50W ..... !92.78-'N ......... ~436.02'-W .... 4~40.21 N 87 '~0 .... 41._W 2_.?.64 ....... 44~ ~I. ....... 9800-"48'--~0" 8"0'3-7-,-3-2~ t 9 9~. 32 ........ NS~.OOW ....... 9900 49 55.'~[ .... 81'02-.7~ ........................................... ....... 8055.74 N86.OOW ....... !99.01 N 458~.40 W a589.72 N 87 30 ~3 W 1.694 4589.71 --'i0100 5'6--1'5----8-~2'2'.~'2 .... 8175'.22 NSV.OOW 209,~7 N a745.25 W ~7~9.87 10200 59 0 8275.85 8228.86 N88.00W 213.15 N 4529.61 W 4834.31 10300 58 .... ].S ....... 8';~2'7.92 ..... 8280.92 N88.00W ........ 2_L6_e.Z.~__N~].,~.9. Z~..3_~w_~9_Z_g...f19 ~0~00 ................. s~ ~0 8380.98 a333.gs Nss.oow ~19.09 ~ ~999.6s__w ..... 10500 ~5 35 ..... 8'-~"3'5"'2'5 ....... 8388.25 ,N89,00W 221.29 ~ 50,~3.61 W 5088.¢3 ~0600 56 0 8490,7~ 8~3.?~ N89.00W 222.7~ N 5156.79 Z0700 55..50 .......8_5.~5._77 .......8~99.77. N.~8....9.~?____22~.9l .... N ....5249_,.59 W L0750 55 30_ 8_5_7_~_..97 ...... 8527.97 N.8_7_._~_OW 225.53 .... ~'_ ..... 52.90_~_B_4_W ..... 52.~5.69 10e35 ..... 5.5 0~_8.5_2.3_,._~2 ........ 8575....42 ..... NB. 6..50W__230.1~ N 5~50.59 W ~/0925 5~ 0 8675.58 8628.68 NSD.50W :~35.B0 N 5~33.68 ............................................. .,,,,u ._ ;,.~ ,. - 28 22 W ........ 2.846 ............ 4834,31 28.__55 W ~,~0.._7~.0_ 491.9.6.9.. 31 .... 53 W ........ 0...5.9.0 ................ 5.17!,59 32 48 W ........ 0.703 ............ 525~.40 32 53 W ............. 0.,961 ........... 5295.69 32 2~ .... W ........... 0.9.8~ ................. 5~55.53 31 13. W ..... 1_,328 ...... 5438.77 TRUE ....................................................... _TAU~ ~E.ASUR._ED ............ V.E~R.T.ICAL SUB ......... MD-TVO ........................... V. ERI.I..CAL~ .... 0 ~.P 7_~ .............................. O.E.? T.H ..... 5 EA .._D ]. F.F.~ R EN ~. E ..................... ~0 RR.E C T I 0 N ................ .T_O_T AL .......... CO OR D. ! N A T E 5 . ............................... !57 .......................... !~7_, .............. !00 ................ O 0 82.~_,.6.2 ...... N ._ ~7~_,7.6 W .................. _3.47 ................................... 3.47 .., ............ 3.0.0 ................... 0 ~ ............................. 82 ~.,.6.~..._N ........~ T ~ · 76 w .................. ~.47 ........................................... 4..47. ................ .~_0..~ ................... 0 0 .......................................... ?[2.1_, 6 3 .... N .............. 174. ,.7.5 W .......................... 5_~.7 ............. 5.47_, .........D.O.O ..................... D ............................................. ~. .............................................................. 62.1_, 74_~ .................. 174,_7.4 ..... w ............... 647 ...................................... 647~ ..........~0.0 .................... O: ........................~ ........................... 82!,7e_.N ............ :i 74,7...~ ............... 7.4 7 .................................... 7 4 7_. .................... 70..0 ................... o .......................................... 0 ........................... ~ z ~. 7 ~.._~ .............. 17 ~ · 5 o w 947 947, 900 0 0 82!,40 N 174,61 ..... W ........... !04~ ...................... 1047, 1000 .................... 0 ...................................... 0 ................. 82%,0~ .... N ..... 174,7~ ..... W ................... g _~ 47 1147.~ ...... ']... !.! .0 0 ........ 0 ............................ .0 ................................................... 8.2.0.,.6.5 ..... N ............... 174..,..89_ .W 1~47 ............ 1247, . _1200 .......... 0 .~ .... ~20,47_....~ !74,89 1347 1347, 1300 0 0 520,45 N 174,.B9_. W ....................... 1 ~9.~ Z T ~ T.~ ............... !.700 .............. 0 ..................... ~ ....................................... 8.20_,.67.__N ................. %7~ ,.~_7_W 1847 1847, 1800 0 0 ~20,79 N !74,30 W 1947 ....................... 1947, 1900 ...... 0 ...................... 0 ...... 82!,04..N _ 174,gO_._W ................... 2047 2047. ............ 2000 ................... 0 ........................................ 0 ....................................... ~.2.!., 08 ~ ............. I..73 ,_9.3_W ......................................................... ...... 2147 ....................... 21~7, 2100 . _0 ..................... 0 820,69 N .17),8~. W . .2247 ................. 22~7, 2200 ...... 0 .................... 0 520,~3 .~{ .......17~,.76 2Z+n7 ,:~4z~: , 2400 0 0 8 ~ 8,96. N i 7~, 44 W 254~ 2547, 2500 0 0 818,!8 N !7B,08 W 2647 2647, 2600 .............0 ................................ 0 ............................. ~.],.7 · 22..~.~ .......... 1.72,69_ 2747 2747~ 2700 0 0 8!5,97 N !72,26 2847 .................. 28~7, 2800 .............0 ................... 0 ............. 814,0.0 N ..... 17!,9~ ~ .................. 294.7 ........................... 2947~ ..........2900 ............ O_ .......................0 ....................... 8.]. 0.,.16.._ ~ ....... . .... !74,5:~ W 3048 ..................... 304.7, ...... 3000 ._ 0 ....... O ........................... 806., ~7__ f{ 16!,!~ ~!4~ .................... 3147, .... 3100 .............. ~_ ..... ! ................ 800,~! ~._ !91,44 W . ............ ............. 3..2 ~ 9 3247, 3200 2 l ................................... 7_96_,. 25~...N ........... 206,40 ..W. .......................................................... ~3~1 ...................~3'~7',- 3300 ~ 2 792,85 ~ 22z~,~0 W . 345~ ............... 3.~ a.7, 3nO0 6 2 788,8~ N 247.54 .................... V~EASURED DEP Id ND 0 HER D FOR E ER E I FE T F B E D T ,, ........................... LT2 ..... Aj .......... _T. ................. A..TA .................. V ..... Y._.g~V .... ~ ..... 1.00 .... ~..E ...... O ...... GU .... S. A ....... EP.. H , ...................................................................... ~U.E MEASURED VERTICAL SUB ~ D-T...VD ..................... v E.R.T. [.CAL~ ............ DEPTH ........................ DEP'T H SEA DIFFERENCE ..................... CoR R.E..q.T.! O~N ............TOTAL .... _ ..... ;- ;-""; ..... ,' ........ .................. ...................................... ....... seco ~8~. 3800 .................... 3~ 1.0 .......... 765,59 N ...... 391,50 399~ .............................. 3947, .............. 3900 ..................... ~6 ............................................ ~ ............ 7~6,79 N .. ...................... 4 112 40 ~.7, .......... ~.00..0 ................ 64 ..................................... 1 ~ ................................................. ~ 4 '7, ~ 5_ N ................... 506 ,.11 4235 4147, 4100 88 ~4 ................ 736,a8 N .... 577,45 4365 ............................... 42.47, ........ 4200 117 29 ................... 722,76 FI 659,04 ~504 4347. a300 156 39 70..5.. C Z.._. N ................. 4650 4447. 4aO0 203 ' 47 6a5,41 _N_. 658,~1 4798 45~7~ 4500 25! 48 666.66 N 9f16.14.W ......................... 494~ .............. ~.6.~7...., ......... 4.500 ........298 ................................ ~..7 ....................................... 54_7,91 .... N .......... 1072 3~5 .......................... ~7 ................... 629,2~ .N 117[~,35 300 45 6~':~ i0 N 1281 .. ~, .90 434 ...................................... ~ .............................................. 5 %6..2 ~_.~ ...... 50~2 4747, 4700 :5237 48f+7~ a. ~:300 ~ ~ ~ 1 4947, 5523 5047. 5000 476 42 5~1.61 5665 5147, 5!00 5!8 42 566,49 '5807 ............................... 52-~-7 · 5200 560 ........... 59~'o ~-'j"47". ~oo ~o3 6097 .............. 5447. 5400 550 ......... 624 6 5.5. E.7.. .......... 5500 .... 5e9 ............................................... 6396 56~7. 5600 749 50 ~50.24 6545 57a7. 5700 798 6839 59a7, 5900 892 47 4.3!.6~ 698~ ..................... 6047, _6000 937 ................... 45 ................... 7!.29 6.lq.'/.· .......... 6100. _. 982 .............................. .. 7273 62a7, 6200 1026 ........... ~.~ 376:,29 7421 6347. 6300 1073 47 375.32 ................... _'7_571 6/ta.T~. ............ 6400 ............... 1..! 2~ 7723 ..................... 5.5~7, __ 6500 .... .. 7.,~.7 4_ .......................... 6 6.,+_7... 5 6 0 0 ...... B022 57a7. 6700 _!275 8.15.7 ...................... 6.~ z+7... 8449 ~043 · 6~]00 .... 1320 .................... 4~ ..................... ~05,7,5 6900 1962 ......... a2 ..... 292,72 7 o0.o .......... !...4.02 ...................................... ~..0 ...................................... 2 ~>, · 50 1583.84 w ....... !68:'3.3.6 .... W ............................................................ 1890.59 ~' ........... 1999,..56 W 2!09,~9 W 221~,57 ',,',' 2325,67 .... W 2432,20 W ...... 2536,~0. W _ ............. 2640 · 11 2962 · !6 W 3076,05 W . 31~:~ ,24 W ..3295 ,.16. 3399, ~1 W ..... r~EASURED ................VERTICAL SUB N!D-TVD ............ VERTICAL.. DEPTH ................................. DEPTH SEA DIFFER~NgE .............. cO..?ggCT!ON. TOT'A'L."]]~'Q~RD"i~'ATE$ 8723 72~7, 7200 1476 35 25~,80 N 3782 .................... 8857 ................................ 7.3.47 · ........... 73.00 ........ ~..~ .!.0 3.~ ............ 2 ~. 2 · 34 8990 ......................... 7.~a.7 · ......... 7~.~ OO ...... !54.3 ................................................. 3..~5 ................ 230,92 ......... 9256 ............................ 76~7. ............. 7600 !~09 ....................... 33 2!2,05 9390 ........................... ~7~,7. .........7700 16/~ 34 ...................... 204.~6 ............................... 9526 78..42... ......... 7800 .......... !.67~,,8 ..................................... _3..,~ ...................................................... ], 9 ~ · 70...~ .. 9~66 ..................... 79~7. ............ 7~00 ...... !7!9 ~.! ...................... 193.05._N ....... 98~_ ....................... 80~7. _. 8000 1767 .......... ........ ~+f] .................................... 19~.95 N ..................... 9971 8 ! E,77 ...... 8.1,00 ...... ! 8_2.~ ...................................... 5.,6 ........................................... 20.2., ~ ~:~...,_,~ 101~6 ............................... 82~7.. 8200 !898 .......... 75 ......... 211,33 N ~783 10336 .............................. 83A7. 8300 !989 ............... 91 217.20 N ...~9~+5.61 1 052 1 8.~.~+ 7_, ............. 8 ~+ 00 ........ 2 O7 ~ ........................................ ~ 5 .............................................. 22 .! .., .59,. 10700 ........ 8547. 8500 2153 . .79 224.91 10876 86/+7, 8600 ~229 76 ~ 3;: · ~.~ N ~'~ 93, ~J ~.~ _ TRUE ~EASURED VERT I CAL SU~ . ................................ !P~9 9.79_. ................... 9_5.2? .................. ~.2,1,..._~3_..~ ................... ],.7.4.,.7..0 ..... W 3000 2999, 2952. 807.67 N 177.52 4000 3952. 3905. 756.32 hl 4~-/". 69 ................ 500.0 ............................... 4.6_8 4. ...... L...__4.6..~_7_* .......... : ................ 6.40_..92 ....N ......... !. !!.2 ..l 3 . W .;=~ . j:. _60.0.0 '. ................... ~.3..8.0. · ......... _5_3~3..~. · ............................ 52. 7_,.73._N ............ 1 S 20._,..43. · .............................. 5 .................... 2, 5.47. ,. ~ 6 ..................................... 7.0_00 ........................ s 0_57 60 !.0 · . 4 !- ._38 .,u .~,8,000 ' 6731, 6684. ~422 (~3 N ......... 32~0.16 W . ] .......................................................................... - I ,,.. .................. .~,,9000 7454. 7407, - 230._1! _.N ....... 3.964.6! ................... .... VERTICAL SECTION _ _ SCALE I''= IOOO' ATLANTIC RICHFIELD COMPANY WELL No. N.G.I. 8 RADIUS OF CURVATURE'j ........ [- ...... GYROSCOPIC SURVEY .... 32(]0- 44, ................................................. ~ .............. 60 ,.. ...... ~ ..... 68 .............. : .......... i'. ............... ~ ..... "~' .... :'f':~:"- i -'_- ....... .': ..... .' 'i '~i ...... ! ALL DEPTHS SHOWN _._ ARE TVD. 84( - ¢ TVD= 8,676' TMD= 10,925' HORIZONTAL VIEW_' SCALE I"-IOO0' ATLANTIC RICHFIELD COMPANY WELL No. N.G.1. 8 RADIUS 'OF CURVATURE, . AtlanticRichfieldCompany North Amer?._.,~q P~oduch~g North A]as~- strict Post Office ~× Anchora~e~ A~a~k~ ~9510 Telephone 90'F 2?7 5(~37 August ll, 1976 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 3-5 (31-14-10-15) r..~.DS.~9~6 ( 13-1 1 O- 15 ) ~ ....... B..G~21-1 ~-11-14) Dear Sir' Enclosed please find the Monthly Report of Drilling Operations for the above mentioned wells. Sincerely, C. R. Knowles District Drilling Engineer CRK/jr Enclosures ~,~ ~G. P-~ STATE OF ,,j.A~KA SUIM~II'T EN DUPIACA'X'~ OIL AND GAS CONSERVATION COMJVHTTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 50-029-20219 f; L~$£ DF-.S:t~NAx--XON A.~D S]~AL ~O. ADL 28302 o,~ ~ o,, ~ o,,,, Gas Injection WKLL W~LL ~. NAME OF OPERATOR Atlantic Richfield Company P. O. Box 360, Anchorage, Alaska 99510 4. L,OCATION OF WE. IA. · .... 98'S & 965'E of NW cr Sec 12, TllN, R14E, UM 8. UTqXT FP~'~! OH LE~S£ Prudhoe Bay 9 w~ NO NGI No.8 (21-11-11-14) 10 FIELD A.N'D POOL. OR WILDCAT >rudhoe Bay - Sad]erochit Pool lX SEC. T., R., M. (HO~TOM HOLE Sec 11, TllN-R14E, UM PER.MIT ~rO 76-52 ~3. REPORT TOTAL DI~TH AT END OF MONTH. CHANGES IN HOLE SIZE. CASING AND CK!Vi'E~TZNO JOBS INCLUDING DEPTH SET A.N'D VOLU~VFES USED. PERFO~TIONS. TESTS AND RESULTS FISHING JOB~ JIYNK LN' HOLE A~D SIDE-TRACKED HOL~ A.ND .~.NY OTI~.~ SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report on operations for the month of JulY. Spud @ 1800 hrs 7-16-76. Drilled 17½" hole to 2727' Ran 13-3/8", 72#, MN-80 Buttress csg w/shoe @ 2695' Cemented w/4000 sx PF II. LandJd 13-3/8", installed and tested 13-3/8" x 20" packJff. NU and test BOPE. Drilled cmt, shoe and formation to 2737'. Test formation to 0.65 gradient. Directionally drilled 12~'~" hole to 9444'. Ran DIL/SP/GR logs and multishot survey. RU and ran 9-5/8" 47# MN-80 and S00-95 Buttress csg w/shoe @ 9422', FC @ 9337', and FO's @ 2490' & 2395'. Cemented 9-5/8" cs§ w/750 sx Class G cmt. Installed and tested 9-5/8" csg packoff RIH w/RTTS, cemented 2nd stage thru lower FO w/275sx PF-C cmt. Closed and tested lower FO. Opened upper FO, pumped 305 bbl Arctic Pack into 9-5/8" x 13-3/8" annulus. Closed and tested upper FO. RIH w/8½" bit, drld cmt from 9239' to 9337' Drld shoe and tested formation w/500 psi. Drilling 8½" hole @ 9733' on AugUst 1. 14. i hereby certtfy that the ~oregotng ts~,~rue m~d COXT~~ iii sm~.,rz~ ~~~.~ ~ District Drilling Enginegr~ ~ m m mmmlm mill m mm m m NoTE-Rlpor,t on t~it form ti required for loch cole~dor ~th~ regOrdless of the stat~ of o~mtm~, ond must ~ filed ~ dupli~lt otl lad gal contervofion commi~ee bythe ISm of the suoc~ding mon~, ~le~ otherwise directed. Division of Oil and Gas 3001 Porcupine Drive, Anchorage, Alaska 99501 June 4, 1976 Re: Prudhoe Bay NGI #~ (21-Il-11-14) Atlantic Richfield. Company State Permi t No. 76-48 C. R. Knowles District Drilling Engineer Atlantic Richfield Company P. O. Box 360 Anchorage, Alaska 99510 Dear Sir: Enclosed is the approVed application for pemit to drill the above referenced well at a location in Section ll, Township llN, Range 14E, U.M. Well samples, core chips and a mud log are not required. A directional survey is required. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder {Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Depart- ment of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article ? and the regulations prol mu l ga ted thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this pemit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a representative of the Division may be .present to witness testing of blowout preventer equipment before surface casing shoe is drilled. C. R. Knowles 2- June 4, 1976 In the event of suspension or abandonment please give this office adequate advance notification so that we m~y have a witness present. Very truly yours, ~mber Alaska Oil and Gas Conservation C~]ittee Enclosure cc: Department of Fish and Game, Habitat Section w/o encl. Departjnent of Environmental Conservation, w/o encl. Department of I~abor, Supervisor, Labor Law Compliance Division w/ encl. AtlanticRichfieldCompany North Amc "-~an Producing Division North Aia'. ~3istrict Post Office Box 360 Anchorage, Alaska 995~J0 Telephone 907 277 5637 May 25, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99504 RE- North Gas Injection Well No. 8 (21-11-11-14) Sec 11, TllN, R14E, UM Dear Si r' Enclosed is our Application for Permit to Drill the above- mentioned well, together with the $100 application fee and required survey plat. Since this is the eighth well drilled from this drill site, we request the waiver of the double diverter line requirement of CO 137, Rule 4. This well will be directionally drilled. The surface and bottom- hole locations are located on lease 28302, having an effective date of October l, 1975 and a termination date of March 27, 1984. The information in the above paragraph will be helpful to the State Department of Labor. Very truly you.rs, C. R. Knowles District Drilling Engineer CRK/JWS/jr Enclosure SUlqMIT IN TRIg (Other instruction. reverse stde) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE API # 50-029-20219 PERMIT TO DRILL OR DEEPEN 1~.. ?TPI OJ' WOIK DEEPEN J-I DRILL 6. LEASE DI2~ilGNA'FION /~N"D Sl~L NO. 'ADL 28302 IF INDIAN, A.I.~LOT'TEE OR 'I'I~BE NA~M.,I~ b. ?TP]= OF WILL OIL ~ OA/~ r.-.1 Gas Injection z NAME OF OPEI~ATOR Atlantic Richfield Company 3.ADDRE.S.S ~ OP~TOi~ P. O. Box 360, Anchorage, AK 99510 98'S & 965'E of NW cr Sec 12, TllN, R14E, UM A'. W:oposed prod. zone -8300'SS, 270'S & 1500'E of NW cr Sec ll,TllN, R14E, UM 13 DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE' Approx 8 miles northwest of Deadhorse 14 BOND INFOR.MATION =~..=~ Statewide sure,~o~ederal Insurance Co. 15 DISTANCE FROM PROPOSED' LOCATION TO NEAREST PROPERTY OR LEASE LINE, (Ai.~o to nearest drig, unit. if any) 1500' DISTANCE FROM PROPOSED LOCATiON* TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR. FT. ?qsfl' (NfiT No_ ELEVATIONS ;SNow whether DF. RT. GR. ete.~ 18' Gravel Pad #80113840 ~,,o,,., $100,000 i8. NO. OF ACRES IN LEASE , j la. PROPOSED DE'PTH I 8837'TVD (11,300'MD) [I?. NO. ACRF~S ASSIGNED TO THiS WELL 320 20 ROTARY OR CABLE 'rOODS Rotary 22. APPROX. DATE V¢ORK WILL STAR'F* August 24, 1976 **See below.*~ PROPOSED CASING AND CEMENTING PROGRA2~ SIZE OF HOLI~ SIZE OF CASING WEIGHT PER FOOT GRADE SKTI'ING DEPTH ' quantity of cement 32" ' 20" "' 94# ~t-40 IO0"MD irc to surf'.' +500 sX Permafrost- 17-1/2" 13-3/8" 72# qN-80 2700'MD lCirc- to~ surf. T4000 sx Permaf?6st- 12-1/4" 9-5/8" 47~, , MN,-80 9440'MD klSOO' ~m.t.col~-m.n"lst s, tg +__750. s~' & L5.00-95 +300' cmt column 2nd stg +__275 s.x .... .',,8-1/2" 7" lnr 29# iMN-80 TD ~1800" cmt column_+300 sx _ The Atlantic Richfield Company proposes to directionally drill this well to 8837'TVD (ll,300'MD) for future use as a gas injection well into the Sadlerochit gas cap. Logs will be run over selected°intervals. 'A 20-3/4" Hydril and single 4" diverter line will be used on the 20" conductor. A 1$-5/8" 5000 psi Hydril and 13-5/8" 5000 psi pipe and blind rams will be us'ed on the 13-3/8" casing. The BOP equipment will be tested weekly and operationally checked each trip. A non-freezing fluid will be left in all uncemented annuli in the permafrost interval. Seven inch 29# MN-80 tubing with a Baker "SAB" Packer assembly and a 7" safety valve 1-anding nipple will be run as completion assembly. This well will be shut in pending perforation. **Note' This work could start approx.June 15, r~ ^~ov~ S~A~ ~mc~ mo/'osr= ~aoo~.,~: ,, .~, ,~ ~o ~ ~. ~ o~ ~.~ .~.~,.'. ~o...~ ~o~,~ 1976. new prddumxve ~ne. _1[~.[o~1 is ~ arlll or ~n awe~ionally, ~lVe ~rtment ~' on sUbsu~a~ ~t~ ~a meas~d ~d ~ue ve~icai dept. Give blo~u[ pre~e~ter' program. 21.1S!GNlyDhereby certt fyc~7v ~'''~ t hat)~e ~ zg~in~e -,,-~ ~/] an~ Correct DAT~ Tn~.~District Drlg Engineer space for State ofilce SA:,fPLEiS AND CORE CHIPS [] Ym ~ No DI~ON~ SURVEY ~ ,~ ~ NO CONDITIONS OF APPROVAL, IF MUD LOG OTHE~ R}'~U FI~KM~: A.P.I. ~CA.L CODI[ 50-029-20219 .... Oune 4. 197'6 DA"I~ June 4, 1976 SE CTiON 915' section I/ne 965' 989' 1014' 1039' 1064' 1089' 1139' ~9 SECTION 12 SURVEYOR 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 LOCATION SURVE,': MADE BY ME OR UNDER MY SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. OCT 4, 1975 DATE SURVEYOR' - BUILT WELL NO I LAT. 70°19'36.129'' LONG. 148°28'50016" WELL NO. 2 L A T 70° 19' 37 284" LONG. 148° 2850.762 WELL NO. 5 LAT 70° 19'38.441" LONG. 148°28'51.49`3'' WELL NO. 4 LAT 70° 19'39.596" LONG. 148°28'52.223'' WELL NO. 5 LAT 70° 19'40.749" LONG. 148°28'52.947'' WELL NO. 6 LAT. 70°19'41.908'° LONG. 148°28'53.68~' WELL ko. 7 LA't: 70° 19',45.052" LONG. 148°28 54.412" WE'LL NO. 8 LAT. 70° 19' 44.210" LONG. 148°28' 55.126'' WELL NO. 9 LAT. 70° 19' 45.37Q" LONG. 148°28'55.850°' WELL NO. I0 LAT. 70° 19'46.519" LONG. 148028'56.589''' Y 5 c~71 400.07 X 687 .350.54 Y 5 971 5~690 X 687 322 06 Y 5 971 6,33 76 X 687 29409 Y 5 971 750.62 X 687 266.18 Y 5 971 867.11 X 687 2.]8.47 y 5 971 984.28 X 687 210.34 Y 5 972 099.94 X 687 182.47 Y 5 972 217.07 X .687 155.06 Y 5 972 334.`31 X 687 127..31 972 ¢50.53 687 099./4 EXISTING WELL OR' CONDUCTOR PIPE WELL NO. I TOP PAD ELEV. -- 18.4 FT. MLLW ARCO~ AFE 292265 HVL #. ATLANTIC RICHFIELD CO. AS -BUILT WELL I THUR I0 NORTH INJECTION SITE LOC/~'rED IN PROTRACTED SECTIONS I Etl2~T/!,.N~ RI4E~U.M. PREPARED BY HEWITT V. LOUNSBURY ~ ASSOC. 725 W 6 -I'H. AVE., ANCHORAGE, ALASKA DATE OCT 9~ 1975 SCALE f": 300' LOOSE CHKD: BY G. O. FIELD BK. LEAF CHECK LIST FOR ,NEW WELL PERMITS . Is the permit fee attached . . . Company /~-~C<~ Yes No Remarks . Is well to be located in'a defined pool ............. /~mj}(,~ o Is a registered survey plat attached . . ts well located proper distance from property line . Is well located proper distance from other wells ...... , Is sufficient undedicated acreage available in this pool ...... ~W~J~ . Is well to be deviated ...... .. Is operator the only affected party . . .. Can permit be approved before ten-day wait ........... %~( Does operator have a bond in force .............. ~v~' . Is a conservation order needed ................. . Is administrative apF, roval needed JAL LCS ,.r'-'( JCM ~?! Revised 1/15/75 I. Is conductor string provided .......... .. Is enough cement used to circulate on conductor and surface . i. Will cement tie in surface and intermediate or production strings i. Will cement cover all known productive horizons . . '. Will surface casing protect fresh water zones . . t. Will all casing Qive adequate safety in collapse, tension & burst ~. Does BO?E have sufficient pressure rating '. !ditional Requirements' Approval Recommenc=~ Geel ogy Enoineerinm-
