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Home My WebLink About194-034MEMORANDUM TO: Jim Regg , I 2GZv P.I. Supervisor Of FROM: Brian Bixby Petroleum Inspector Well Name PRUDHOE BAY UNIT 04-45 Insp Num: mitBDB220205154546 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, February 14, 2022 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 04-45 PRUDHOE BAY UNIT 0445 Sre: Inspector Reviewed By: P.I. Supry J"! Comm API Well Number 50-029-22454-00-00 Inspector Name: Brian Bixby Permit Number: 194-034-0 Inspection Date: 2/4/2022. Packer - —- ryp Well 0445 T e InJ w " VD 1940340 T e Test I SPT -!Test psi BBL Pumped: 0.6 BBL Returned: Interval 4YRTST -- rPIF Notes: Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 7032 Tubing 1678 1677 1676 1677 - 1758 IA�499 2470 2418 2404 " 0.6 OA 316 " �i 416 406 P ! Monday, February 14, 2022 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,February 21,2018 TO: Jim Regg P.LSSuper �evisor 4q !Z71l(1j SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 04-45 FROM: Bob Noble PRUDHOE BAY UNIT 04-45 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry/32— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-45 API Well Number 50-029-22454-00-00 Inspector Name: Bob Noble Permit Number: 194-034-0 Inspection Date: 2/20/2018 Insp Num: mitRCN180220154956 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 04-45 Type Inj W rTVD 7032 ' Tubing 1881- 1884 1898- 1893 ' PTD 1940340 Type Test SPT Test psi 1758 IA 50 2700 1 2665 2660 ' BBL Pumped: BBL Returned: 1.2 OA 71 80 sl 80 ' Intervale 4YRTST - 1[p/F P Notes: .—,..14 v1 Lel? i (t�;C11 to in lL�2cu, /J�4�i a& Ie G-kry 13� Wednesday,February 21,2018 Page 1 of 1 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, February 13, 2018 8:01 AM To: AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;G GPB FS2 Drillsites; Stechauner, Bernhard;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel,Joshua;Worthington,Aras J Subject: OPERABLE: Injector 04-45 (PTD#1940340) Ready to be brought online for AOGCC MIT- IA All, Injector 04-45 (PTD#1940340)was made not operable on 1/10/2017 for missing its 4 year AOGCC witnessed MIT- IA. The well is now ready to be brought back online and is reclassified as Operable. An AOGCC witnessed MIT-IA will be conducted once the well is on stable injection. Plan Forward: 1. Fullbore—HOT Tubing 2. Operations—POI 3. DHD—AOGCC witnessed MIT-IA Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANNED wo eogrowasnow From: AK, GWO We • -a ity Well Information Sent: Tuesday, January 10, 20 : S PM To: AK, GWO SUPT Well Integrity; Cismos i, • A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Pro toilers; Stechauner, Bernhard; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS FS2 Ops Le ; GPB FS2 Drillsites Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; A ,--GWO Completions Well Integrity; AK, OPS FF Well 1 STATE OF ALASKA .LASKA OIL AND GAS CONSERVATION COMMI, lt REPORT OF SUNDRY WELL OPERATI 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate 1k1 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 194-034 3. Address: P.O.Box 196612 Anchorage, Development ❑ Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service Q 6. API Number: 50-029-22454-00-00 7. Property Designation(Lease Number): ADL 0028328 8. Well Name and Number: PBU 04-45 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL T LG C E I%F 11.Present Well Condition Summary: Total Depth: measured 11875 feet Plugs measured feet MAR 21 2016 true vertical 9180 feet Junk measured feet Effective Depth: measured 11721 feet Packer measured See Attachment feet ,AOGCC true vertical 9050 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20"94#H-40 37-115 37-115 1530 520 Surface 3894 9-5/8"47#NT-80 36-3930 36-3556 6870 4760 Intermediate Production 11824 5-1/2"17#L-80 33-11858 33-9165 7740 6280 Liner Perforation Depth: Measured depth: See Attachment feet APR 2 1 2016 True 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 See Attachment See Attachment See Attachment 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: 9985 800 1887 Subsequent to operation: 7985 780 1835 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations O Exploratory ❑ Development ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas El WDSPL ❑ Printed and Electronic Fracture Stimulation Data El GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP ❑ SPLUG El 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 y Signature )1Ci Y .. Phone +1 907 564 4424 Date 3/16/16 Form 10-404 Revised 5/2015 1/" T v 4-1/2/140 I Submit Original Only A ,�I % RBDMS I,v MAR 2 2 2016 • • Packers and SSV's Attachment PBU 04-45 SW Name Type MD TVD Depscription • 04-45 TBG PACKER 6635 5404.12 2-3/8" Baker FH Packer 04-45 TBG PACKER 9043.42 7038.25 2-3/8" Baker FH Packer • • d Cl) co Cn CO O) N- Ln O N. Ln O M V = CO O) M CO Ln I-- N CO r M p. Ln Ln Ln 6 O d' 00 M NO y 0) O N I� 0) O CO I,- r N NI- ❑ Ln CO O a) CO I` c0 00 O) 0) O ❑ c0 C'O OO 00 M 00 c0 c0 c0 c0 0) > I- a 0 I- MLnoorLc, N. LUMvrnCO .c r O) CO O M O) CO 00 N CO LC) a O 00 M I--: O) O) co 0) Ln (-6 CO a a) co O) r CO I-- O) Ln 0 O r 0 W ❑ Ln Ln CO CO000c0cca) OO > p cc cc ccc000c ccccc o 0 > 2 I- W cL 0 W Z DLI a O W a a) Q Q 0 0 O w JJ Y U O m O O co cn w 1 YY. H cr g co O Ln O O M N 00 O O O __I Q Q w WLij « I, -O) r CO O r O ` r J 0 I O Z" r r N N M C) Ln Ln Ln LC) I� < < < Wa O O_ ❑ rrrr r r r U 0 0 J W W CO) J _I0_ Z _ O p J aa1 W 000 Z Qp Z t w w w a H F- < J < V Ln 2 2 2 O co co co co co RI 4 �ia < O 12 _ = 0) N O Ln O LC) N 00 O O O p. Ln c0 O a) 00 O O) O in co I` O COQ r r N CV CN ") d C ' Ln in Ln CO COay r r r r r = = = = = = 'a L d O E acnJit = = Ooa � a Z 2 O w co co co Ln a) a y 0 0 c LL. L.L. L.L. LL LL LL Ll_ LL_ LL Lt_ w To' d o_ d IZ o_ Cl.. d d a_ CL W a� Q Q Q Q Q Q Q Q Q Q o_ a O a) a) a m I- m O O O O O O CO CO CO M y 0 ❑ 0) 0 O 000000000o0) W Z O N N N N N N N N N N N- Z IL < W CO CO Ln LO n In N- N- I,- I,- Ln O W N W CO N N N N N N N- ,- ,- N Z a o U W LL W O CO O CCOO 0 CCOO CCOO N N N N CO m p p W J _1 -I D Ir a Q Q a co LL L_ u_ cn d cr a) E ca Z• Ln Ln in Ln in to Ln to Ln Ln Ln v v V v v V v Cr w a u) O LL N LL Nv � vvvvvvvNYNt m a 0_ a o J 00w a 0 0 0 0 0000000 < Q 03 CO LL. LL Cn Cl) a cL • • Q, 00c c cc c 00 O M CO M CO M CO M CO R NN �O O O O Oo U N o 0 0 0 0 0 0 0 0 0 0 L M N- co O M O (U O O O , O r O = O = O LoO LOM M N M LOCO I— = M O O N N = = M M M O) LO (O (O lO H M 00 N M LO O M M M M O O O LOLOLON- C O ,0M O = M O N N IO O) O O O CO 0 0 0 _ = M = O (fl O (O 0) 0) 0) 0) p MO = MOO N N 0M M cM M CO (O (O (O O O O _ (0 (0 (0 (00) 0) 0) mm a 0 0 0 0 0 0 0 0 0 C) 00 00 00 00 CO CO CO CO CO a) J J J J J J J J J "# N- N O N O N O N (.0 07 O) U N N o0 N 00 N 00 N 00 O M M M M N L6M N M N M N M N N N M CN- CONN0_ N M N M M Z CF-OO w H R D < D C O O O O O O O O O LLO Z Z Z Z Z Z Z Z Z O M M OOM M 000000 10 41 • b - g & ii, N. N. r \ / LU L \ k b / \ \ 0 $ - _r & 2 \ , \ u i O d � < < < LU \ z > > > > w m 1 E E E E z Cc; 0 -I ? / % $ / \ / / \ / © z q E E E E Cr $ I % < g L \ ct ƒ LU 7_ 0 / h ƒ O m O O 0 I c @\ I I \ k ƒ ƒ ƒ a w ¢ o >- ± 2 2 2 L L < G 2 / ƒ / I 3 E I I / / E o E .RI 2 e m / E 2 ± CO H _ sa 0 Rti; Z - (7)IDD k 0 < \ ® m G 2 / / 3 / : / \ / i _$ Tr e > 0 * / % / / 0 /_ / / / / / \ < \ k 0 -1 > 01 H j \ / CO ± 2 CO CD CO co - o a N \ o LU / a \ / \ \ LU w \ CD : '— °o c / E ,_ 2 E / 0 0 _1 O ± R � C 7 cp \ / 0 Y < / b_ N- O b_ _O b a -J / c (N � � / pa � c) � xf / xX x /- - / # ,- 2 O H6a a ,, ¥ it \ 2 I \ / E ƒ % I- Z f \ � / / / / / / 6uj Z I '- Z Z2 2 r O / O / / _ \ --:)- ON x 0 O / \ / 0 . 02 \ m R R x 6 § \ % & ƒ \ R (DEE E k / q ® / O O ® F t LU / < ± — E 3 w a 4 i / E $ . 2 / „ < D § / * - / D / 47 D D z \ D Z / $ : E : i ccw o : : z O » : : cccc ± < -, ± : 5 E < e CO (0 CO � d d \ 17; / n \ \ \ CO ~ 00 / = \ / < TREE= aw 0 FirifY NOTES: ***CHROME NIPPI FS*" WELLFEAD= RC 04-45 ACTUATOR= BA KER C KB„ELB/= 64' I I BE ET_EV= KOP= 1967 , I 2033' --i3-1/7 FES X NW(9-CR),ID=2.813" ktur Angie= 49° .) 6263' Datum MD= 11502' -roc — -331T Datum ND= 8800'SS ... S 1 .*1 .A., 9-5/8'CSG,47#,NT-80,13=8.681" — 3928' Minimum ID = 1.791" @ 9124' I I 6593' H3-1/7 FES X 1413(9-CM,0 2,813" = 2-3/8" HES XN NIPPLE \ 6624' —13-1/2"X 2-3/8"X0,ID=1.950' >< 6626' —5-1/2-X 2-3/8"BKR FH MI,L)=1,990" [ 6631' —2-3/8"X 3-1/7 XO,0=1.950' 6652' —13-1/2-X 2-3/8"XO,ID=1.920' I 6653' —12-3/8"I-ES X MP(9-CR),D=1.875' i 6654' —12-3/8"X 3-1/2'X0,ID=1.920" .....---> 6771'-6866' H BOATED CSG LEAK • 9001' —3-1/2'X2-3/8"XO,Cr=1.920" 3-1/2'TBG,92#,L-80 TEX — 9033' .0087 bpf,0=2.992" N)I 9001' H2-3/8"I-ES X NIP(9-CR),0=1.875' 9003' —12-3/8"X 3-1/2"XO,0=1,920" PERFORATION SLRIMARY REF LOG:NIIAD ON 03/19/94 ANGLE AT TOP PEW:35° .., 1115g \ 9033' H3-1/2-X 2-3/8"XO,0=1.960" Note:Refer to Production CO for historical perf data SIZE SPF INTERVAL Opn/Cry [ATE >< 9034' —5-1/7 X 2-3/8'BKR FH 14<R,11)=1.990' 1.56" 6 11159-11178 0 06/26/10 1,56" 6 11182-11190 0 06/26/10 1,56" 6 11200- 11215 0 06/26/10 I 9064' H2-3/8"I-ES X NV(9-CR),ID=1.875' 1.56' 6 11265- 11280 0 06/26/10 1,56' 6 11280-11300 0 06/26/10 1,56' 6 11305-11313 0 06/26/10 1.6875' 7.5 11492-11502 0 02/17/16 I 9124' —2-3/8"I-ES XN MP(9-CR),13=1.791" 1.6875" 7,5 11508-11518 0 02/17/16 1.6875' 7.5 11550- 11560 0 02/17/16 1.6875' 7.5 11560- 11570 0 02/17/16 3-3/8" 6 11670-11710 0 06/25/94 / 9166' —2-3/8"WLEG,ID=1,920- 2-3/13'TBG,4.6#,L-80 STL, —1 9166' .0039 bpf,13=1.995" •••••••••s• S**11..... .......11.1 FB-ro —I 11774' .0..4..1..1 1././..... 5-1/2'CSG, 17#,L-80,0=4.097 — 11856' ....1*.... 1...1.1.... TD — 11875' LATE REV BY COMENTS DATE REV BY (X)144.ENTS FDI-UE BAY INT 03/20/94 ORIGINAL COMPLETION :02/18/16141GB/JIA7 A DPI:RFS(02/17/16) WELL: 04-45 06129/94 LAST WORKOVER FERMT No: 1940340 12/13/08 018 MVO , AR No: 50-029-22454-00 , 12/25/08 fTLH CORRECTIONS(PASSNG XOs) SEC 34,T11N,R15E,594'FNL&449'FEL 09/04/09 F8/JM) DRLG DRAFT CORRECTIONS 06/29/10 KJB/PJC PERFORATIONS(06/26/10) BP Exploration(Alaska) Pga 04--q-L; Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep [AKOPSFFWellOpsCompRep @bp.com] Sent: Tuesday, June 04, 2013 12:01 PM �� //4 I t 3 To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Subject: FW: PBU/East Area/FS2/04 defeated pilots Mr. Regg, Here is the info you requested on the DS-4 water injectors that were temporarily SI yesterday for pigging operations. Well PTD 04-06 1760830 04-08 1760100 04-10 1760420 04-13 1780310 04-15 1780370 04-19 2012180 SCANNED ' 04-20 1831190 04-25 1860490 04-27 1852950 04-45 1940340 I apologize for the time delay since the initial email was sent. I will have this data available for future notification emails since I now know it is required. Thank you, Lee Hulme From: AK, OPS FS2 DS Ops Lead Sent: Tuesday, June 04, 2013 8:35 AM To: AK, OPS FF Well Ops Comp Rep Cc: AK, OPS FS2 Facility OTL; AK, OPS FS2 OSM Subject: RE: PBU/East Area/FS2/04 defeated pilots Lee, All of the PWI wells are gagged during pigging operations in order to prevent inadvertent blocked flow and a stuck pig.— This is how we always pig and how we will always pig every week in the future. It is a manned operation. The wells gagged yesterday were DS4-6,8,10,13,15,20,25,27,19,45. I9n `White Ak, Ops FS2 DS Lead 907-659-5493 Alt: James Barndt From: AK, OPS FF Well Ops Comp Rep Sent: Tuesday, June 04, 2013 7:43 AM To: AK, OPS FS2 DS Ops Lead Cc: Regg, James B (DOA); Redmond, Randy; AK, OPS FF Well Ops Comp Rep 1 Subject: FW: PBU/East Area/FS2/04 dereated pilots Importance: High Ron, ' Please supply me with a list of the water injectors on DS-04 that were defeated during the pigging operations yesterday so I can look up the PTD numbers and pass on to Mr. Regg. Thanks, Lee From: Regg, James B (DOA) [mailto jim.regg@ alaska.gov] Sent: Monday, June 03, 2013 9:08 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU/East Area/FS2/04 defeated pilots Our approvsl only covers injectors. And yes, I want a record of the injectors involved. Particularly since it is DS 4. Sent from Samsung Mobile Original message From: "AK, OPS FF Well Ops Comp Rep" <AKOPSFFWellOpsCompRep @bp.com> Date: 06/03/2013 6:32 PM (GMT-09:00) To: "Regg, James B (DOA)" <jim.regg cr,alaska.gov> Subject: RE: PBU/East Area/FS2/04 defeated pilots Mr. Regg, I just called the FS2 Field Lead Tech and he told me the pigging operation is completed and the temporary defeat for PWI wells has been lifted. It will take some research to determine which wells were involved since the DSD log blanketed the whole pad. I can get this data tomorrow if you still want it. Please advise. Lee Hulme FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony—7187 (Alternate: Ryan J Hayes) From: Regg, James B (DOA) [mailto:jim.re•g@alaska.gov] Sent: Monday, June 03, 2013 5:01 PM To: AK, OPS FF Well Ops Comp Rep Subject: RE: PBU/East Area/FS2/04 defeated pilots Please identify wells and PTD for each. Jim Regg AOGCC 2 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 From: AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWelIODsComDRep@ bp.com] Sent: Monday, June 03, 2013 4:25 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Redmond, Randy; AK, D&C Well Integrity Coordinator; Bill, Michael L (ASRC); Starck, Jennifer L; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, RES GPB East Wells Opt Engr Subject: PBU/East Area/FS2/04 defeated pilots Dear Mr. Regg, Per AOGCC waiver dated 3/11/13, PBU Oil Pool Low Pressure Water Injectors, BPXA is providing notification that wells on DS-04 are now operating with its SVS defeated as of 6/3/13 for pigging operations. Per the wavier, BPXA has tagged and logged the defeated components, and will notify AOGCC once the SVS is returned to service. Please contact me with any questions. Thank you, Lee Hulme FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony-7187 (Alternate: Ryan J Hayes) 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday, January 15, 2013 Jim Regg P.I. Supervisor -r1 ( 'Z4 (i 7j SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04 -45 FROM: Bob Noble PRUDHOE BAY UNIT 04 -45 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry :113(2----- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04 -45 API Well Number 50- 029 - 22454 -00 -00 Inspector Name: Bob Noble Permit Number: 194 -034 -0 Inspection Date: 1/8/2013 Insp Num: mi1RCN130108174033 R In el sp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 04- 45 [Type J SP Test psi 5 398 OA 272 2195 2199 - 2203 X205 - 2203 Well IT e In TVD IA - PTD 1 940340 ' Type T est 1500 29 38 39 38 39 38 , ■ Interval 4YRTST IP /F P - 1 Tubing 1347 1358 - ' 1365 1372 1360 1352 - I N o t es: .84 bbls pumped to pressure up. 3 1/2" x 5 1/2" SCANNED APR 1 1 2013 Tuesday, January 15, 2013 Page 1 of 1 • • WELL LOG TRANSMITTAL PROAcTivE DiimNosTic SERVICES, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave :.r v !. Z011 Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Nita Summerhays LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Injection Prifile 11- May -11 04-45 BL/ CD 50-029 - 22454 -00 2) f Y 73/ Signed : v Date : v �.. t Print Name: - k-t> caw 0 k-(0•-.4 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 Fax: (907)245 - 8952 E-MAIL : PDSANCHORAGEOMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution \TransmittalSheets\BP Transmitdocx 1 C I q ° 3 (/ onoe/to ~_ Schlumh~rger ~ V ~ " d c3 J Alaska Data & Consulting Services ~ ~ ... - 2525 Gamhell Street, suhe 400 Anchorage, AK 99503-2538 ATTN: Beth Well Job # Log Description N0.5557 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD ., ~_~u 04-45 L-203 P-28 P-28 AYKPA0086 83S0-00065 AY1M-00047 BB6M-00018 JEWELRY LOG/PERF RECORD USIT USIT SONIC CBL 06/25/10 05/02/10 06/08/10 06/14/10 1 1 1 1 1 1 1 1 N-01A 8.01 N-16 AYKP-00092 BCRD-00031 BCRD-00032 PRODUCTION PROFILE ' LEAK DETECTION LOG PRODUCTION PROFILE ~ 07/05/10 07/02/10 07/04/10 1 1 1 1 7 1 W-21 A H-02A BAUJ-00034 AYKP-00088 MEMORY PROD PROFILE a USIT 07/03/10 06/26/10 1 1 1 1 8-130 H-23A AYKP-00091 65JN-00048 SCMT RST 07/02/10 04/16/10 1 1 1 1 B-21 B3S0-00062 RST 04/28/10 1 1 \ BP Exploration (Alaska) Inc. ~v"r ., Petrotechnical Dala Center LR2-1 900 E. Benson Blvd. ~ ~ ~ ~~~~ ~u~ ~ ~~~~~~ ~~,• ~: Alaska Data & Consulting Services 2525 Gambell Street, SuAe 400 Anchorage, AK 99503.2038 r,, .. ?r.71.. ~~ ~, jt11f~ 62 STATE OF ALASKA ALAS AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 194-0340 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ .API Number: Anchorage, AK 99519-6612 50-029-22454-00-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: , ADLO-028328 PBU 04-45 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 11875 feet Plugs (measured) None feet true vertical 9179.65 feet Junk (measured) None feet Effective Depth .measured 11721 feet Packer (measured) 6626 9034 true vertical 9049.62 feet (true vertical) 5398 7032 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" SURFACE - 112 SURFACE - 112 1490 470 Surface 3894 9-5/8" 47# NT-80 SURFACE - 3928 SURFACE - 112 5750 3090 Intermediate Production 11825 5-1 /2" 17# L-80 SURFACE - 11856 SURFACE - 9164 7740 6280 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 3-1/2" X 2-3/8" L-80 SURFACE - 9166 SURFACE - 7125 9.2# / 4.6# L-80 ~ Packers and SSSV (type, measured and true vertical depth) 5-1/2" SealBore Receptacle W/X Lock 6626 ~ ~ kv 5398 5-1/2" SealBore Receptacle W/X Lock 7032 9034 G ~+~~~ t 12. Stimulation or cement squeeze summary: ~ ~ Intervals treated (measured): t ~, ~, „ r~ ~ ~ E ~~.~~- jS~jO~ Treatment descriptions including volumes used and final pressure 6P ~F ~~ ~ Q~1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 5830 1833 Subsequent to operation: 500 1955 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL G TOR ^ WAG ^ GINJ ^ WINJ ^~ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 7/7/2010 i viiii iv--rv-' ~~c~+wc~ ~iwv~ ~VIVf~~V JUL v a cuiue~. 04-45 194-034 PFRF ATTArI-IMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth. Base Tvd Depth Top Tvd Depth Base 04-45 6/25/94 PER 11,670. 11,710. 9,006.56 9,040.34 04-45 11/5/08 BPS 9,016. 11,710. 7,019.07 9,040.34 04-45 12/27/08 BPP 9,016. 11,710. 7,019.07 9,040.34 04-45 6/25/10 APF 11,200. 11,215. 8,613.68 8,625.97 04-45 6/25/10 APF 11,265. 11,280. 8,667.01 8,679.35 04-45 6/25/10 APF 11,280. 11,300. 8,679.35 8,695.84 04-45 6/25/10 APF 11,305. 11,313. 8,699.97 8,706.59 04-45 6/26/10 APF 11,159. 11,178. 8,580.13 8,595.68 04-45 6/26/10 APF ~ 11,182. 11,190. 8,598.95 8,605.49 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 04-45 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/25/2010 ***WELL INJECTING UPON ARRIVAL. T/I/O: 1600/0/0 PSI.*"" ~ ~*"WEEKLY WIRELINE VALVE TEST WITNESS BY KEVIN BRACKETT** ~ 6/26/2010 WELL SHUT IN PRIOR TO RIH. LOGGED JEWELRY PASS FROM 6310-11680 FT WITH PBMS TS PRIOR TO PERFORATION PASSES. PERFORATED INTERVALS BELOW WITH 1.56" PJ HSD 1606, 6 SPF, 60 DEG PHASING. SURFACE AND VISUAL INDICATION OF SHOTS FIRED. RUN 1:11,305-11,313 FT RUN 2: 11,280-11,300 FT RUN 3: 11,265-11,280 FT RUN 4: 11,200-11,215 FT BEGIN RIH WITH FIFTH GUN. "**JOB CONTINUED 26-JUNE-2010.*** """JOB CONTINUED FROM 25-JUNE-2010.""'` PERFORATED INTERVALS BELOW WITH 1.56" PJ HSD 1606, 6 SPF, 60 DEG PHASING. SURFACE AND VISUAL INDICATION OF SHOTS FIRED. RUN 5: 11,182-11,190 FT RUN 6: 11,159-11,178 FT SWAB CLOSED, SSV OPEN, MASTER OPEN, WING CLOSED, TC INSTALLED AND PT. FINAL T/I/O: 30/0/0 PSI. DSO CLOSES PERMIT. SUPPORT EQUIPMENT RELEASED AND UNIT LEAVING LOCATION. ***JOB COMPLETE.'`** FLUIDS PUMPED BBLS 2 DIESEL 5 METH 7 Total TREE = CNV WELLHEAD =' FMC ACTUATOR = BAKER C KB. ELEV = 64' BF. ELEV = KOP = 1967' Max Angle = 49° @ 6263' Datum MD = 11502' Datum TV D = 8800' SS 9-5/8" CSG, 47#, NT-80, ID = 8.681" ( 3928' Minimum ID =1.791" @ 9124' 2-7/8" HES XN NIPPL.E SA ES: ***CHROME NIPPLES*** 04-45 I 3317' I 3-1/2" HES X NIP (9-CRI, ID = 2.813" - 6593' -j 3-1 /2" HES X NIP (9-CR}, ID = 2.813" - 6624' 3-1/2" X 2-3/8" XO, ID = 1.950 - 6626' 5-1/2" X 2-3/8" BKR FH PKR, ID = 1.990" 6631' 2-318" X 3-1/2" XO, ID = 1.950" - 6652' 3-1/2" X 2-3/8" XO, ID = 1.920" 6653' 2-3/8" HES X NIP (9-CR}, ID = 1.875" 6654' 2-3/8" X 3-1 /2" XO, ID = 1.920" 6771' - 6866'1 ISOLATED CSG LEAK 9001' 3-1/2"' X 2-3/8" XO, ID = 1.920" 9001' 2-318" HES X NIP {g-CR), ID = 1.875" 9003' 2-3/8" X 3-112" XO, ID = 1.920" 3-1/2" TBG, 9.2#, L-80 TCII, I 9033' .0087 bpf, ID = 2.992" PERFORATION SUMMARY REF LOG: MWD ON 03/19/94 ANGLE AT TOP PERF: 32° @ 11670' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 3-3/8" 6 11670 - 11710 O 06/25/94 2-3i8" TBG, 4.6#, L-80 STL, .0039 bpf, ID = 1.995" 9033' -~ 3-1 i2" X 2-3/8" XO, ID = 1.960" 9034' 5-112" X 2-3/8" BKR FH PKR, ID = 1.990" 9064' I-12-3/8" HES X NIP {g.CR}, ID = 1.875" 9124' I-{ 2-318" HES XN NIP (9-CR), ID = 1.791" 9166' I-{ 2-3/8" WLEG, ID = 1.920" PBTD -( 11774' 55=1/2" CSG, 17#, L-80, ID = 4.892" 11856' TD 11875' DATE REV BY COMMENTS DATE REV BY COMMENTS 03!20194 ORIGINAL COMPLETION 06!29!94 LAST WORKOVER 12!13!08 D18 RWO 12/25/08 /TLH CORRECTIONS (MISSING XOs) 09/04/09 HBiJMD DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: X04-45 PERMIT No: 1940340 API No: 50-029-22454-00 SEC 34, T11 N, R15E, 594' FNL & 449' FEL BP Exploration (Alaska} MEMORANDUM TO: Jim Regg ~~, ~ ~2 P.I. Supervisor `~ FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, February 02, 2009 SLIB.IF.CT: Mechanical hitegrity "Costs BP HXPLORATION (ALASKA) INC Oa-as PRUDIfOE BAY UNI'C Oa-4s Sre: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UNIT 04-45 API Wel- Number: 50-029-22454-00-00 Inspector Name: John crisp Insp Num• mit1G•090120135802 Permit Number: 194-o3a-o Inspection Date: lit3~2oo9 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ _ oa-as TYPe Inj. ~' ., TVD ssyx ~ _ IA Izvo zsoo zsoo ,soo ,~ P.T.D 14aosao ,TypeTest sPT. Test psi.. zsoo '' Op Aso xoo xoo xoo ..Interval tNIT.4L _ P/F P _ J Tubing Iaso Ia,o laso laso NOtes• .5 bbl pumped for test. . - ~. i"~:..,, t ~ ~ 1 , Monday., February 02, 2009 Paee I of l We1104-45 /~~ 0 2~ • ,,gl J • Fleckenstein, Robert J (DOA) From: Stewman, Sondra D [Sondra.Stewman@bp.com] Sent: Wednesday, January 28, 2009 1:46 PM To: Fleckenstein, Robert J (DOA) Subject: We1104-45 Attachments: 04-45, 10-404.pdf Here's a signed copy, «04-45, 10-404.pdf» Thank you, Sondra Stewman ADW Drilling Technologist 13e reat, X~e resc>t arxc rrtcist crf atI Ise I'(35~'Z"[TE! +~'~ Ic~ilau~~C.r~:%~ clf'!1`~ C; CJ (e~~'i3~ Ua,~ Page 1 of 1 1/28/2009 STATE OF ALASKA AI~tA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPER~IONS 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension __ 2. Operator Name: 4. Well Class Before Work: 5. Permit 7o DriN Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 194-034 3. Address; ®Service ^ Stratigraphic 6. APt Number: P,O. Box 196612, Anchorage, Alaska 99519-6612 SO-029-22454-00-00 7, KB Elevation (ft}: ~ 80, 9. Well Name and Number; PBU 04-45 8. Property Designation: 10. Field /Pool(s): ADL 028328 Prudhoe Bay Field / Prudhoe Bay Pooi 11. Present well condition summary Total depth: measured 11874' feet true vertical 9179` feet Plugs (measured) N!A Effective depth: measured 11721' feet Junk (measured) N/A true vertical 9050' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 3894' 9-5/8" 3928' 3555' 5750 3090 Intermediate Production 11825' 5-1/2" 11856' 9164' 7740 6280 Liner Perforation Depth MD (ft): 11670' - 11710' Perforation Depth TVD (ft): 9004' - 9038' 3-112" x 2-3/8", 9.2#! 4.6# L-80 9166' Tubing Size (size, grade, and measured depth}: Packers and SSSV (type and measured depth): 5-1/2" x 2-3/8" Baker'FH' Packers 6826' &9034' 12. Stimulation or cement squeeze summary: Intervals treated (measured}: Treatment description including volumes used and final pressure: 13, Re resentative Dail Avera a Production or In`ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 100 1894 Subsequent to operation: 0 0 3864 1100 1894 14. Attachments: ^ Copies of Logs and Surreys run 15. Well Class after work: ^ Ex lorato ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ~ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.b. Exempt: Contact Hank Baca, 564-5444 308-311 Printed Name ndra Stewman Title Drilling Technologist ,~t~ PrepBted 8y Narrie/WumUer: Si ature ~ r------n_..._~hone 564-5743 Date ~ . i 'ct^7Sondra Stewman 564.4750 Form 10-404 Revised 04/2006 Submit Original Oniy ~ ~ o~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REP OF SUNDRY WELL OPEIONS ~~~;~i ~ 4 2009 1. Operations Performed: ~~;;~ ~~~ ~8~ ~Of15- ~ ^Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Ente~~~~g Well' ea d e t ~ 8 ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 194-034 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22454-00-00 7. KB Elevation (ft): 64.80' 9. Well Name and Number: PBU 04-45 8. Property Designation: 10. Field /Pool(s): ADL 028328 Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11874' feet true vertical 9179' feet Plugs (measured) N/A Effective depth: measured 11721' feet Junk (measured) N/A true vertical 9050' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 3894' 9-5/8" 3928' 3555' 5750 3090 Intermediate Production 11825' S-1/2" 11856' 9164' 7740 6280 Liner Perforation Depth MD (ft): 11670' - 11710' Perforation Depth TVD (ft): 9004' - 9038' 3-1/2" x 2-3/8", 9.2# / 4.6# L-80 9166' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 5-1/2" x 2-3/8" Baker'FH' Packers 6626' & 9034' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 100 1894 Subsequent to operation: 0 0 3864 1100 1894 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ~ Service ~ Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ®WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Hank Baca, 564-5444 308-311 Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number: Signature Phone 564-5743 Date Sondra Stewman 564-4750 Form 10-404 Revised 04/2006 U .~___. ~ ~ .~~~ ~ ~ 2ooQ Submit Original Only ~~~~ .~ ll TREE _ ~ FMC NEW STAND WELLHEAD = CM/ ACTUATOR= BAKERC KB. ELEV = 64' BF. ELEV..- __ KOP = 1967 Max Angle = 49 @ 6263' Datum MD = 11502' Datum TVD = 8800' SS F S .NOTES: 04-45 2033'---3.5" tJtis X nipple, lD 2.813" 3317' I~ ESTIMATED TOP OF CEMENT 9-5/8" CSG, 47#, NT-80, ID = 8.681" L 3928' F' Minimum ID =1.791" @ 9124' 2-7/8" HES XN NIPPLE 113-1/2" TBG, 9.2#, L80 TCII, O.xxx bpf, ID = 1.920" I I 9033' I ~ 6593' ~- 13-1/2" HES X NIP, ID = 2.813 I 6624' 3-1/2" X 2-3/8 XO, ID = 1.950" 6626' S-1/2" X 2-3/8" BKR FH PKR, ID = 1.990" 6631' 2-3/8" X 3-1/2" XO, ID = 1.950" >6771 ` to 6886'---Isolated Casln Leak 6652' 3-1/2" X 2-3/8 XO, ID = 1.920" - 6653' 2-3/8" HES X NIP, ID = 1.875" 6654' 2-3/8" X 3-1/2" XO, ID = 1.920" 9001' 3-1/2" X 2-3/8 XO, ID = 1.920" - 9001' 2-3/8" HES X NIP, ID = 1.875" 9003' 2-3/8" X 3-1/2" XO, ID = 1.920" 9033' 3-1/2" X 2-3/8 XO, ID = 1.960" 9034' S-1/2" X 2-3/8" BKR FH PKR, ID = 1.990" 9042' 2-3/8" X 3-1/2" XO, ID = 1.910" 9064`---2.375" C}tis nipple, 1.875" Pk Bore 9124`--®2.375" Otls XN nipple, lD - 1.791" 2-3/8" TBG, 4.6#, L80 STL, O.xxx bpf, ID = 1.920" 9166' 9166`---2.375" LEG, lD - 1.9209} PERFORATION SUMMARY REF LOG: MWD ON 03/19/94 ANGLE AT TOP PERF: 32 @ 11870' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11670 - 11710 O 06/25/94 PBTD ~ 11774, 5-1/2" CSG, 17#, L-80, ID = 4.892" 11856' TD I-i 11875' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/20/94 ORIGINAL COMPLETION 06/29/94 LAST WORKOVER 12/13/08 D16 RWO 12/25/08 /TLH CORRECTIONS (MISSING XOs) PRUDHOE BAY UNfT WELL: 04-45 PERMfT No: 1940340 API No: 50-029-22454-00 SEC 34, T11 N, R15E, 4079.54' FEL & 978.72' FNL BP Exploration (Alaska) BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: 04-45 Common Well Name: 04-45 Spud Date: 3/7/1994 Event Name: WORKOVER Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/13/2008 Rig Name: DOYON 16 Rig Number: Date j From - To Hours I, Task Code NPT Ph ase ' Description of Operations 11/30/2008 02:30 - 04:00 1.50 RIGD P PRE Back Rig Off Well. Rig Up Bridle Lines and Rig Down Floor. Lower Derrick. 04:00 - 04:30 0.50 RIGD P PRE Remove BOP's from cellar and place in carriage for transport. 04:30 - 05:30 1.00 MOB P PRE Pull Rear Booster Wheels around and R/U. Ready rig to move down road. 05:30 - 10:00 4.50 MOB P PRE Move Rig from DS 12 to DS 4. 10:00 - 12:00 2.00 RIGU P PRE Remove Rear Booster Wheels from well cellar area. Position 12:00 - 15:00 3.00 RIGU P 15:00 - 15:30 0.50 RIGU P 15:30 - 18:00 2.50 RIGU P 18:00 - 19:00 1.00 RIGU P 19:00 - 21:30 2.50 RIGU P 21:30 - 22:30 1.00 RIGD P 22:30 - 00:00 1.50 PULL P 12/1/2008 00:00 - 00:30 0.50 KILL P 00:30 - 01:30 1.00 KILL P 01:30 - 02:30 1.00 KILL P 02:30 - 04:00 I 1.501 KILL I P 04:00 - 04:30 0.50 KILL P 04:30 - 05:15 0.75 KILL P 05:15 - 06:00 0.75 KILL P 06:00 - 07:00 1.00 KILL P 07:00 - 07:30 0.50 KILL P 07:30 - 10:30 3.00 KILL P 11:00 - 13:00 I 2.001 KILL I P 13:00 - 14:30 ~ 1.501 KILL ~ P Rig on Pad for Crane Work and Place BOP's Back in well cellar. Raise Derrick and begin R/U. PRE Acce t Ri at 12 hr Continue to Rig Up and Wait of Crane Crew to arrive. PRE PJSM with rig crew, Drlg HSE, and crane operator on installing Belly Board in Derrick. PRE Install Belly Board and Pin in Place. PRE Finish installing Belly Board. Rig down Crane. PRE Move Rig over 4-45 Well Slot. Center and shim Rig. PRE Spot Slop Tank. Install double Annulus valves. Rig up circulating lines. OAP = 0 psi. IAP = 0 psi. DECOMP Pick u DSM I bricat r BPV. Lay down same. Tubing pressure =slight vacuum. DECOMP Test circulating lines at 4,000 psi. Good. Finish taking on 9.3 Ib/gal Brine in Pits. DECOMP PJSM. Pump a 10 bbl Hi-Vis pill. Follow with 190 bbls of 9.3 Ib/gal Brine at 7.0 bpm/625 psi. Saw most of the sweep come ack after um in 500 strokes -42 bbls). DECOMP Shut down Pump. Monitor pressure fall off. Initial pressures. TP = 0 psi, IA = 100 psi, OAP = 0. Pressure after one hour. TP = 0 psi, IAP = 50 psi, DECOMP Continue to monitor pressures while waiting for additional Brine to arrive on location. Bleed IA to 0 psi. Initial pressures. TP = 0 psi, IAP = 0, OAP = 0. After 30 minutes IAP = 40 psi. After one hour IAP = 30 psi. DECOMP Pump a second circulation. Pumped 10 bbls pill followed by 190 bbls 9.3 Ib/gal Brine at 7.0 bpm/625 psi. DECOMP Shut down pump. Monitor pressure fall off. Initial pressures. TP = 0 psi, IAP = 0 psi, OAP = 0 psi. Pressures after 45 minutes. TP = 0 psi, IAP = 0, OAP = 0. DECOMP Pump the third and final circulation. Pumped a 10 bbl Hi-Vis pill. Follow with 190 bbls of 9.3 Ib/gal Brine at 7.0 bpm/625 psi. DECOMP Shut down pump. Monitor well. TP, IAP, and OAP remail at 0 psi. DECOMP Open well and observe no flow. DECOMP Set TWCV. Pressure test from below at 1000 psi. Good test, Attempt to test from above at 4,000 psi. Test failed.. Make multiple attempts to get pressure test on TWC from above, not seeing a fluid at IA. Isolate problem to TWC, Town wants to wait on VBR's. DECOMP Started seeing a small amount of fluid at IA, pressure building slighty to just below 10 psi and bleeds off quickly. Calll out DSM. Rig up lubricator and test to 500 psi Pull TWCY. Lay down same. Dld not see any real problems with TWC. DECOMP R/U Surface Lines to Tree and IA. Pressure Test lines to 3500 psi. Open IA and Tbg, -90 psi. Bleed down and circulate Printed: 12/30/2008 12:32:54 PM r~ u BP EXPLORATION Page 2 of 12 Operations Summary Report Legal Well Name: 04-45 Common Well Name: 04-45 Spud Date: 3/7/1994 Event Name: WORKOVER Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 12/1/2008 13:00 - 14:30 1.50 KILL P DECOMP wellbore volume of 200 bbls at 6 bpm and 500 psi. 14:30 - 16:00 1.50 KILL P DECOMP Shut down pumps and monitor well. No pressure increase seen at IA or Tbg, well static. R/U to Circ. Town communicated at 1600 hrs that it wants to continue to N/U BOP's and Decom lete well. 16:00 - 16:30 0.50 KILL P DECOMP Circ Well at 8 bpm and 890 psi. Circ 2 wellbore volumes, 360 bbls. 16:30 - 18:00 1.50 KILL P DECOMP Monitor well till FMC Tech arrive to set TWCV. No pressure seen at IA or Tbg, well static. 18:00 - 22:30 4 50 KILL P DECOMP Install TWCV #2. Once a ain attem ted to et a test on t . 4 000 si. is failed. Discussed options and plan forward with Anchorage, PEs, and several service companies. 22:30 - 00:00 1.50 KILL P DECOMP Call out DSM Pick up Lubricator and test. Pull TWCV #2. Lay down same. 12/2/2008 00:00 - 03:00 3.00 WHSUR P DECOMP Install TWCV #3 Pressure test on top of TWCV several time to 4,000 psi x 10 minutes. "Bucket test" a drip per second coming from the IA. Still the TWC. Decission made to set IBP on E-Line 03:00 - 04:30 1.50 WHSUR P DECOMP Call out DSM, SWS E-Line, and Baker Thru Tubing. Pick-up Lubricator and test to 500 psi. Good. dull TWCV #3. Lay down same. 04:30 - 08:00 3.50 WHSUR P DECOMP Baker IBP and setting tools on location. Wait for SWS E-Line Unit to arrive on location. Monitor Well 08:00 - 09:00 1.00 WHSUR P DECOMP Consult with town and Beside to try TWC one more time while waiting for E-Line. R/U and Circ 190 bbls at 5 bpm and 430 psi. While waiting on FMC to arrive with new TWC. 09:00 - 11:00 2.00 WHSUR P DECOMP R/D to Set TWC. FMC Tech set TWC PT From Above to 4000 psi. Make Multiple attempts with bleed off. Cycle Tree Valves and adjust all valve to halfway open. Able to aet a good test on TWC after cvclinp valves. Hold test for over 30 mins to insure good. Test TWC from Below for 10 mins to 1200 psi. Good Test on TWC, all tests charted. 11:00 - 12:00 1.00 WHSUR P DECOMP Blow Down and Rig Down Clrc lines. Suck out tree and prep to N/D 12:00 - 13:30 1.50 WHSUR P DECOMP Nipple Down Tree and 7-1/16" Adapter Flange. Dress Top of adapter flange for Cross Over Flange. 13:30 - 17:00 3.50 BOPSU P DECOMP N/U 7/16" x 13-5/8" Ada ter Flan N/ 1 - 8" P's 3-1/2" x 6" VBR's and Blind Shear Rams. 17:00 - 21:30 4.50 BOPSU P DECOMP Rig U BOP Test E ui ment and test BOPE per BP procedures and AOGCC regs to 250-psi low and 4000-psi high. Hold and chart each test for 5-minutes. AOGCC rep John Crisp waived witness. All tests witnessed by BP WSL and Doyon toolpusher. Test Choke manifold, Choke & Kill manual & HCR valves, Top Drive IBOPs, 3-1/2" IF Dart &TIW valves, and 2-7/8" Dart &TIW valves. 3-1/2" IF Dart valve failed test. Baker tech redress & then retest -passed. 21:30 - 22:00 0.50 BOPSU P DECOMP Blow down choke and kill lines. Vac out BOP stack. Prepare for VBR Chan a out. 22:00 - 23:30 1.50 BOPSU P DECOMP Remove 3-1/2" x 6" VBRs from BOP stack and install brand new 2-7/8" x 5" VBRs. Function test new VBRs. 23:30 - 00:00 0.50 BOPSU P DECOMP PU 3-1/2" test joint and RU to continue BOPE test. 12/3/2008 00:00 - 03:00 3.00 BOPSU P DECOMP Continue to Test BOPE per BP procedures and AOGCC regs. Test 2-7/8" x 5" VBRs with 3-1/2" and 2-7/8" test joints. Test to BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Name: 04-45 Common Well Name: 04-45 Spud Date: 3/7/1994 Event Name: WORKOVER Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To 'Hours ', Task Code NPT Phase Description of Operations 12/3/2008 19:00 - 20:30 1.50 FISH P DECOMP the end of the first wellbore circulation. Sweep returned -60-bbls later than calculated and very thinned out. Continue to circulate until fluid weight in and out stablizes at 9.2-ppg. Total amount of fluid circulated = 342-bbls. 20:30 - 21:00 0.50 FISH P DECOMP PJSM on standing back 2-7/8" DP in derrick. Monitor well - static. Pump Dry job. Blow down Top Drive. LD 4" DP jt. 21:00 - 22:30 1.50 FISH P DECOMP POH with fish to BHA. Rack back 13-stds of 2-7/8" PAC HT DP in derrick. After racking back 5-stds, pump second dry job as well is still out of balance. Continue POH without problem for rest of 2-7/8" DP. 22:30 - 00:00 1.50 FISH P DECOMP Release overshot from Coiled Tbg fish and LD BHA. Baker fisherman redress overshot for use in Coiled Tbg floor valve assembly. MU Coiled Tbg floor valve assembly. Manually cut top of Coiled Tbg to give a smooth stub and test install floor valve assembly. 12/4/2008 00:00 - 12:00 12.00 PULL P DECOMP POH with 3-1/2" 7# Coiled Tbg. Cut Tbg into -15' sections using hydraulic cutter & LD sections to pipe shed. Scale noted on exterior of tbg just below where it had parted. At 0430-hrs, LD SSSV assemby located at 3303' per well records.. 12:00 - 18:00 6.00 PULL P DECOMP Continue POH with 3-1/2" 7# Coiled Tbg. Cut Tbg into -15' sections using hydraulic cutter & LD sections to pipe shed. 18:00 - 19:00 1.00 PULL P DECOMP Secure well & rig crew eat dinner. Hold tabletop Man Down Drill. Discuss crew response in various situations. Identify location of all equipment that would be needed in a Man Down situation. 19:00 - 21:00 2.00 PULL P DECOMP Continue to POH with 3-1/2' 7# Coiled Tbg. Cut Tbg into --15' sections using hydraulic cutter & LD sections to pipe shed. Recover 616-cut sections of CT, 1-SSSV assembly and one 12.55' cut jt of CT. Total measured length of CT recovered = 8956.35'. Clean 'et cut flared to 4" OD with 3.125" ID. 21:00 - 22:30 1.50 PULL P DECOMP Clean and Clear Rig Floor. RD all equipment used for cutting CT. 22:30 - 00:00 1.50 PULL P DECOMP Bring Baker tools to rig floor. RU to handle 2-7/8" PAC HT DP. MU Seal Assembl fishin BHA. BHA consists of: 3-1/2" Spear dressed with 2.949" nominal catch, Bumper Sub, Oil Jar, XO, Pump Out Sub, nine 3-1/8" DCs, XO. Total BHA length = 285.04'. 12/5/2008 00:00 - 01:30 1.50 PULL P DECOMP RIH with Seal Assy fishing BHA on 10-stds of 2-7/8" PAC HT DP from derrick. Discover that incorrect grapple is installed on S ear. 01:30 - 02:00 0.50 PULL P DECOMP POH with Seal Assy fishing BHA. Rack back 2-7/8" PAC HT DP in derrick. LD 3-1/8" DCs in pipe shed. Redress spear with a ra le that has 3.073" nominal catch. 02:00 - 02:30 0.50 PULL P DECOMP RIH with Seal Assy fishing BHA on 3-1/8" DCs from Pipe shed. 02:30 - 12:00 9.50 PULL P DECOMP RIH with Seal Assy fishing BHA on 2-7/8" PAC HT DP. First 10-stds of DP from derrick. Then PU DP from pipe shed & RIH. Break circulation every 30-stds to ensure spear is clear of debris. 12:00 - 12:30 0.50 PULL P DECOMP Establish Paramters. P/U Wt = 135,000 Ibs S/O Wt = 100,000 lbs. Pump Rates = 2.1 bpm at 1040 psi. Tag Up on Top of CT Fish f~ 8985 ft rkb; No Go with Spear 8989 ft rkb. 12:30 - 15:30 3.00 PULL N WAIT DECOMP Circ while stung into CT fish while waiting on Vac Trucks to arrive. Dispatch said that trucks were never placed off of will Printed: 12/30/2008 12:32:54 PM • • BP EXPLORATION Page 5 of 12 Operations Summary Report Legal Well Name: 0 4-45 Common W ell Name: 0 4-45 Spud Date: 3/7/1994 Event Nam e: WORKO VER Start : 11/6/2008 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 12/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task ' Code. NPT Phase Description of Operations 12/5/2008 12:30 - 15:30 3.00 PULL N WAIT DECOMP call. Want Sw on location in case well goes on vac when faring out fish. 15:30 - 16:00 0.50 PULL P DECOMP PJSM w/ Vac Truck Drivers and Rig Crew on Pulling Sealbore and Displacing well to SW. 16:00 - 16:30 0.50 PULL P DECOMP Pull Fish U Hole. Pull Slick Stick t -30 000 Ibs over string wt. Pull Up hole -30 feet. Confirm by S/O and Tagging High. 16:30 - 19:00 2.50 PULL P DECOMP Pump 20 bbls High Visc Sweep and Displace well with 120 degree SW at 3 bpm and 1200 psi. 19:00 - 22:30 3.50 PULL P DECOMP POH with Seal Assy fishing BHA. Rack 93-stds of 2-7/8" PAC HT DP back in derrick. 22:30 - 00:00 1.50 PULL P DECOMP LD 3-1/8" spiral DCs to pipe shed. Release Spear from fish and LD fish to pipe shed. Overall length of fish = 27.93'. Length of 3-1/2" Coiled Tbg = 15.30'. Length of 3.5" x 2-7/8" XO and Seal Assembly = 12.12'. OD of Seal Assembly = 2-15/16". 12/6/2008 00:00 - 01:30 1.50 PULL P DECOMP Baker fisherman redress Pump Out Sub. MU Tailpipe Fishing BHA BHA consists of: GS Spear, Bumper Sub, Oil Jar, XO, Pump Out Sub, nine 3-1/8" DCs and XO. Total length of BHA = 281.7'. 01:30 - 04:30 3.00 PULL P DECOMP RIH with Tailpipe Fishing BHA on 2-7/8" PAC HT DP from Derrick. Break Circulation with 81-stds in the hole. Run BHA thru X Nipple at 7,999' without anv issues. 04:30 - 05:00 0.50 PULL P DECOMP Obtain parameters. PU wt = 135K-Ibs, SO wt = 100K-Ibs. RIH and tag top of fish at 9003'. Turn pump on at 2-BPM with 1110-psi and PU out of fish. Wash down and note pressure increase to 1200-psi. Turn pump off and set down 10K-Ibs. PU and weight breaks over at 30K-Ibs overpull. Fluid level in stack drops -1' when weight breaks over. PU to next tool jt and break DP connection. Drop ball to open Pump Out sub. Screw back into DP and set SBR back on seat. Bring pumps on and pump ball onto seat. Pump Out sub shears open at 2400-psi. PU and see same overpull, breakover and fluid level drop as before. 05:00 - 07:30 2.50 PULL P DECOMP Stage pump up to 4-BPM with 1900-psi and circulate 2 bottoms up. Initial loss rate while circulating = 12-BPH. Gas breaking out from 50-bbls ahead of first bottoms up through end of first wellbore circulation. Gas reduces through second bottoms up. Final loss rate while circulating = 20-bbls. Establish static loss rate of 6-BPH. Monitor well. 07:30 - 11:00 3.50 PULL P DECOMP POOH and Stand Back DP. 11:00 - 12:00 1.00 PULL P DECOMP UD BHA and B/O Spear From Fish. 12:00 - 13:00 1.00 PULL P DECOMP PJSM. Punch holes in fish and break out plug from 2-7/8" Tail Pipe for PE's. Found Tubing Tail Packed full of Schmoo. 13:00 - 13:30 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. Gather Up BHA Components for milling out Nipple 13:30 - 16:30 3.00 CLEAN P DECOMP M/U 4-3/4" Tapered Mill with String Mill, Junk Baskets, and casing scraper for milling out nipples in 5-1/2" casing. Total Length of BHA = 295.64 ft. 16:30 - 20:30 4.00 CLEAN P DECOMP RIH with Mi ' on 2-7/8" PAC HT DP from derrick to 7982'. 20:30 - 22:00 1.50 CLEAN P DECOMP PU single jt of 2-7/8" DP w/ XO for Saver Sub. MU to Top Drive. Obtain milling parameters: PU wt = 121 K-Ibs, SO wt = Printed: 12/30/2008 12:32:54 PM • BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: 04-45 Common Well Name: 04-45 Spud Date: 3/7/1994 Event Name: WORKOVER Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To ~ Hours Task Code NPT Phase ', Description of Operations 12/6/2008 20:30 - 22:00 1.50 CLEAN P DECOMP 98K-Ibs, Rot wt = 105K. Rotate at 60-RPM with 4K-Ibs/ft of free torque. Pump on at 3.2-BPM with 1650-psi. RIH and tag top of fish at 7991'. Begin milling at 2100-hrs with 1 to 2K-Ibs WOB and 4-8K-Ibs/ft of torque. Watermelon mill thru nipple at 2115-hrs to a depth of 8013'. Ream thru nipple x3 without problem. Shut off rotation and run thru nipple again without issue. LD single jt of 2-7/8" DP and drain Top Drive. 22:00 - 23:00 1.00 CLEAN P DECOMP RIH with Milling BHA on 2-7/8" PAC HT DP from 8013' to O(1!1 A ~ 23:00 - 00:00 1.00 CLEAN P DECOMP MU to Top Drive. Obtain milling parameters: PU wt = 130K-Ibs, SO wt = 100K-Ibs, Rot wt = 112K-Ibs. Rotate at 60-RPM with 3K-Ibs/ft of free torque. Pump on at 3-BPM with 1500-psi. Shut pump and rotation off. RIH and tag top of fish at~900r3'. Begin milling at 2315-hrs with 1 to 2K-Ibs WOB and 4 to 8K-Ibs/ft of torque. Watermelon mill thru nipple at 2345-hrs. Ream thru nipple x3 without problem. Shut down rotation and run thru nipple again without issue. Drain Top Drive. 12/7/2008 00:00 - 01:30 1.50 CLEAN P DECOMP PU 3-single jts of DP and RIH. Work scraper full stand from 9025' to 9120' several times. Pump 20-bbl Safe Surf-O Sweep followed by 20-bbl Hi Vis sweep at 2.5-BPM with 1250-psi. Stage pumps up to 3.3-BPM with 1940-psi and chase sweeps out of hole. Thumbnail size wads of Schmoo seen just ahead of and during Safe Surf-O sweep. Loss rate while circulating 2.4-BPH. 01:30 - 02:00 0.50 CLEAN P DECOMP Monitor well -Fluid level dropping very slightly, no gas breakout noted. Pump dry job. Break XO out of Top Drive & Blow Down. 02:00 - 04:30 2.50 CLEAN P DECOMP POH & Stand back 2-7/8" DP back in Derrick. 50-stds out of the hole at 0330-hrs. 04:30 - 05:30 1.00 CLEAN P DECOMP LD nine 3-1/8" DCs to pipe shed. LD Csg Nipple Milling BHA. Good wear patterns on both tapered and watermelon mills. Recovered -1-cup of metal shavings and 1-GS spear dog from Boot Baskets. 05:30 - 06:30 1.00 CLEAN P DECOMP Clean and Clear Rig Floor. LD all unneeded Baker Tools. 06:30 - 07:30 1.00 CLEAN P DECOMP Load RBP and RTTS into Pipe shed. P/U and M/U HES RBP for 5-1/2" 17 # Casin on to 2-7/8" DP 07:30 - 12:00 4.50 CLEAN P DECOMP RIH w/ RBP on 2-7/8" DP from Derrick 12:00 - 12:30 0.50 CLEAN P DECOMP Service Rig. Discover Fast Line Sheave is rubbing. 12:30 - 13:00 0.50 CLEAN N RREP DECOMP Inspect Fast Line Sheave. Take Pictures and review. Discuss situation with town and decide to set RBP at current location to assess derrick situation. 13:00 - 13:30 0.50 CLEAN P DECOMP P/U Single Jt and Set RBP at 7727 ft. (COE ~ 7731.5 ftl 13:30 - 15:00 1.50 CLEAN P DECOMP R/U to Pressure Test above RBP. Tested to 2500 psi for 30 mins good test. Attempt to bring pressure up to 4000-psi and it 15:00 - 16:00 1.00 CLEAN N DPRB DECOMP Bleed all pressure off. Check all surface equipment and Outer Annulus. When all pressure bled off, note flow back to pits. Shut in Well with Annular preventer. Open pipe rams that were closed for testing RBP. SIDPP = 100-psi. SICP = 100-psi. Total ain = 4.2-bbls. 16:00 - 20:30 4.50 CLEAN N DPRB DECOMP Fill Gas Buster. Pump 1 full circulation of 149-bbls. ICP = 630-psi. FCP = 570-psi. Fluid lost during circulation = 4.6-bbls. Shut in choke and monitor well. SIDPP rises to Printed: 12/30/2008 12:32:54 PM a • BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: 04-45 Common Well Name: 04-45 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date j From - To Hours ~ Task Code NPT 12/7/2008 16:00 - 20:30 4.50 CLEAN N DPRB 20:30 - 22:00 1.50 CLEAN N DPRB 22:00 - 22:30 0.50 CLEAN N DPRB 22:30 - 00:00 1.50 CLEAN N RREP 12/8/2008 00:00 - 00:30 0.50 CLEAN N RREP 00:30 - 01:00 0.50 CLEAN P 01:00 - 03:30 2.50 CLEAN P 03:30 - 04:00 0.50 CLEAN P 04:00 - 05:00 1.00 CLEAN P 05:00 - 05:30 0.50 CLEAN P 05:30 - 06:30 1.00 CLEAN 06:30 - 07:30 1.00 CLEAN 07:30 - 08:00 0.50 CLEAN P 08:00 - 09:00 1.00 CLEAN P 09:00 - 09:30 0.50 CLEAN P 09:30 - 11:30 2.00 CLEAN P 11:30 - 15:30 4.00 CLEAN P 15:30 - 16:00 0.50 CLEAN P 16:00 - 16:30 0.50 CLEAN P 16:30 - 17:00 0.50 CLEAN P 17:00 - 21:30 4.50 CLEAN P 21:00 - 22:00 1.00 CLEAN P Spud Date: 3/7/1994 Start: 11 /6/2008 End: Rig Release: 12/13/2008 Rig Number: Phase Description of Operations DECOMP 90-psi. Bleed DP pressure off and shut back in. SIDPP rises back to 80-psi immediately. Continue circulating at 2-BPM with 450-psi on DP and 100-psi on casing while waiting on 9.7-ppg brine to arrive. DECOMP Pump 9.7-ppg kill weight brine at 2-BPM with ICP of 450-psi and FCP of 250-psi. Pump a total of 182-bbls. DECOMP Shut in choke and check for pressure. SIDPP = 0-psi, SICP = 0-psi. Open choke and monitor well -Static. Blow down choke. RD Circulating equipment. DECOMP PJSM on inspection and work on fast line sheave with rig crew, Doyon toolpusher and BP WSL. No losses while static. MU Top Drive to drill string. Hang blocks. Send derrickman and floorhand to crown to reposition fast line sheave. Circulate thru Top Drive at 2-BPM with 770-psi while crew is working on sheave. Loss rate while circulatina = 5-BPH. DECOMP Complete work on fast line sheave. Unhang blocks. Shut pump off. Unscrew from Top Drive and blow down same. DECOMP RIH w/ 2-stds of DP. PU wt = 100K-Ibs, SO wt = 97K-Ibs. En a e RBP. Set down 12K-Ibs and turn 1/4-turn to right. PU to 20K-Ibs over and RBP releases. Allow elements to relax. DECOMP Bring pumps online at 4-BPM with 2000-psi. PU 5' and then RIH past set depth to confirm RBP is free. Pump 3-full circulations at 3.8-BPM with 1900-psi ensure 9.7-ppg brine all the way around. Losses while circulating = 18-BPH., DECOMP Monitor well -fluid level dropping very slowly. Blow down Top Drive. DECOMP POH with RBP to 3834'. DECOMP Set RBP at 3834' DECOMP R/U Circ Head and Pressure Test 5-1/2" Casing to 2500 psi for 10 mins. DECOMP Unseat RBP and Circulate 2 full wellbore volumes at 4bpm and 1030 psi. Gas seen in returns from first bottoms up through first full circulation. No gas noted during final circulation. DECOMP Monitor Well after circulating. B/O and B/D Top Drive. DECOMP POOH and Stand back 2-7/8" DP. DECOMP UD RBP. Clean and Clear Rig Floor. DECOMP P/U Joint of DP and M/U Pulling Tool. Pull Wear Ring. M/U Setting Tool and Set Test Plug in Wellhead. R/U to Test BOP's DECOMP Test BOP Equipment used to kill well. VBR's with 2-7/8" and 3-1/2" Test Joint, Test Annular Preventer with 2-7/8" Test Joint. Test Choke HCR and #5. Annular Preventer Test to 250 psi / 3500 psi and all other tests 250 psi / 4000 psi for 5 charted mins. DECOMP RD all ROPE test equipment. Blow Down choke and kill lines. Pull Test Plug from Wellhead. Install Wear Ring DECOMP Service drawworks and rig. Check Hydraulic oil in Top Drive. DECOMP MU 5-1/2" HES RBP to 2-7/8" DP. DECOMP RIH with RBP to to 9025'. Obtain parameters: PU wt = 127K-Ibs, SO wt = 98K-Ibs. Set RBP per Halliburton Rep. Top of RBP = 9025'. COE on RBP = 9030'. DECOMP MU Top Drive. Bring pump on at 3.5-BPM with 1970-psi. Circulate a full wellbore volume to ensure 9.7-ppg brine to Printed: 12/30/2008 12:32:54 PM BP EXPLORATION Page 8 of 12 Operations Summary Report Legal Well Name: 04-45 Common Well Name: 04-45 Spud Date: 3/7/1994 Event Name: WORKOVER Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/13/2008 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task j Code NPT Phase Description of Operations 12/8/2008 21:00 - 22:00 1.00 CLEAN P DECOMP 9025'. Dynamic loss rate = 8-BPH. Send Derrickman to crown to check fast line sheave while circulating. Sheave did not move during trip. Monitor well -Static. Break XO out of Top Drive and blow down same. 22:00 - 00:00 2.00 CLEAN P DECOMP POH from 9025' to 7161'. Stand back 2-7/8" PAC HT DP in derrick. Maintain continous hole fill while POH. 12/9/2008 00:00 - 02:00 2.00 CLEAN P DECOMP POH with RBP runnin tool from 7161;. Rack back 2-7/8" PAC HT DP in derrick. Maintain continuous hole fill while POH. 02:00 - 02:30 0.50 CLEAN P DECOMP LD RBP running tool. PU & MU 5-1/2" RTTS with circulating valve to 2-7/8" PAC HT DP per HES rep. Derrickman inspect crown prior to RIH. Fast line sheave has not moved further. 02:30 - 05:30 3.00 CLEAN P DECOMP RIH with 5-1/2" RTTS on 2-7/8" PAC HT DP from Derrick to 7727'. 05:30 - 06:30 1.00 CLEAN P DECOMP PJSM. Slip & Cut drilling line. 06:30 - 07:00 0.50 CLEAN P DECOMP Set RTTS at 7721 ft -center of element. 07:00 - 08:00 1.00 CLEAN P DECOMP R/U Circ Head and attempt to pressure test from below RTTS from 7721 ft to 9029 ft. Found that circ valve on RTTS not fully closed getting returns back. Reset RTTS at same depth. 08:00 - 09:00 1.00 CLEAN P DECOMP Wlth RTTS set at 7721 ft pressure up below RTTS to 2500 psi. and hold for a minute then brin ressure u to 4000 si for 1 mins. Test Good. Bleed down pressure and R/U to Test above RTTS. Unable to et above 1000 si. Pump 1.0 bpm at -680 psi, pumped away 7 bbls of fluid into leak. Test Failed, the leak is above 7721 ft. R/U Down Pressure Test Equipment. Zero psi seen on OA. 09:00 - 10:00 1.00 CLEAN P DECOMP POOH w/ DP to -5200 ft. 10:00 - 17:00 7.00 CLEAN P DECOMP Set RTTS at 5254-ft COE. R/U Equipment to pressure test. Pressure test below RTTS to 4000-psi. Pressure test failed at 1.35-BPM at 1150-psi. Zero psi seen on OA. Bleed down and pressure up above RTTS to 4000-psi. Pressure test above 5254-ft passed to 4000-psi. Release RTTS and re-set at 6487'; test from below failed with an injection rate of 1.3-BPM at 1 ccg, ~~ l ` ~` ~j~ ~ 1160-psi. Release RTTS and RIH and re-set at 7151'; test from below was solid at 4000-psi. Release RTTS and POH 3-stands and re-set at 6866'; test from below held solid at 4000-psi. Release RTTS, POH 1-stand and re-set at 6771'; test from below failed with an injection rate of 1.3-BPM at 1100-psi. Close VBRs and test from above fora 30-minute. 4000-osi rock-solid test. Communicate results to ADW engineer. 17:00 - 17:30 0.50 CLEAN P DECOMP R/D test equipment and blowdown lines. ADW engineer agreed that the plan forward is to be changed to POH and L/D RTTS; RIH and move RBP from 9029' to 6770'; POH 3-stands; P/U RTTS and RIH and set 1-stand below Rig Floor; N/D BOP; change Pack-off, spool; N/U BOP and perform weekly BOP test. 17:30 - 18:30 1.00 CLEAN P DECOMP POH with RTTS from 6771' to 4881' and learn that the weather is turning worse and that Phase 3 is expected to be called within 1-2-hours. Decide to stop POH to ensure that we have pipe in the hole and the RTTS ready to be re-set if needed. The current hole loss rate as of 1730-hours is 1.7-BPH. 18:30 - 00:00 5.50 CLEAN N WAIT DECOMP Wait on Phase 3 weather. Circulate across the top of the hole while waiting. Loss rate remains 1.7-BPH. Winds gusting in excess of 50-MPH. At 2200-hrs, talk to Roads & Pads and Printed: 12/30/2008 12:32:54 PM • • BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Name: 04-45 Common Well Name: 04-45 Spud Date: 3/7/1994 Event Name: WORKOVER Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/13/2008 Rig Name: DOYON 16 Rig Number: Date `From - To Hours ~ Task ~ Code ~ NPT Rhase ~ Description of Operations 12/9/2008 18:30 - 00:00 5.50 CLEAN N WAIT DECOMP they say they are in the process of calling Phase 3. Talk to Well Operations Supervisor (Drilling IMT when in Phase 3) and he approves travel of rig crew if phase 3 is called while in the process of change out. Rig crew change out is complete by 2330-hrs. 12/10/2008 00:00 - 04:30 4.50 CLEAN N DECOMP Wait on weather. Discussion with Roads and Pads regarding phase conditions. Continue to wait on weather due to winds gusting over 50-MPH. Circulate across the top of the hole while waiting. Loss rate at 0200-hrs = 1.4-BPH. Loss rate at 0400-hrs = 1.8-BPH. 04:30 - 06:30 2.00 CLEAN P DECOMP POH with RTTS.,Stand back 2-7/8" PAC HT DP in derrick. At 0500-hrs, weather conditions were down-graded to Phase 1, Level 1. 06:30 - 10:30 4.00 CLEAN P DECOMP RIH with RBP Overshot set/retrieve tool and latch onto the RBP. Release RBP. Stop job and hold 15-minute Safety discussion in Doghouse to cover the current operation of RIH with 2-7/8" PAC DP. Driller Sean's crew had a new member as well as a new employee that was being trained for floors. The new member had previously worked on a Nabors rig. 10:30 - 12:30 2.00 CLEAN P DECOMP Circulate Bottoms Up 3.5-BPM at 1980-psi. Loss rate was -16-BPH at be innin of CBU, but decreased to -2.5- t Bottoms U .Stop to monitor well and get a little gas back. Decide to perform another CBU 3.0-BPM at 2000-psi; circulating loss at 2.5-BPH. Monitor well and well is dead with fluid level static at the flow line. 12:30 - 14:00 1.50 CLEAN P DECOMP POH and standback 24-stands of 2-7/8" PAC DP to prepare to set the RBP at -6770'. 14:00 - 15:00 1.00 DHB P DECOMP Set RBP with Center Of Element at 6766'. Test t 1 - rom above and record for 10-minutes for solid test. 15:00 - 16:30 1.50 DHB P DECOMP POH and stand back three stands. P/U RTTS, RIH and set one stand below the Rig Floor. POH and S/B one stand plus one single. COE at 126' below Rig Floor. Test to 1000-psi per Halliburton re uirements with 6500' of 2-7/8" 1 .4-I ft DP hangin from the RTTS. Rock solid, 10-minute recorded test. 16:30 - 18:30 2.00 BOPSU P DECOMP R/U to begin weekly BOPE test. RIH with Wear Ring pulling tool, M/U and pull the Wear Ring. P/U Test Plug, RIH and set in hanger. Hold PJSM with rig crew, Doyon Toolpusher, BP WSL and Rig Safety Auditor. Assign people to positions and discuss hazards and concerns for each position. 18:30 - 23:00 4.50 BOPSU P DECOMP Test BOPE er BP rocedures and AOGCC re ulations. All tests witnessed by BP WSL and Doyon Toolpusher. AOGCC rep Jeff Jones waived witness of weekly BOP test. All tests to 250-psi low and 4000-psi high except annular preventer which was tested to 250-psi low and 3500-psi high. Test VBRs with 2-7/8" and 3-1/2" test jts. Test annular with 2-7/8" test jt. Hold and chart all tests for 5-minutes. Inspect derrick and fast line sheave while testing. Fast line sheave has not movedful3her. 23:00 - 00:00 1.00 BOPSU P DECOMP RD all BOP test equipment. Blow down Top Drive, Kill Line, Choke line and manifold. BOLDS. Pull Test plug. Drain stack. RD Riser and turnbuckles on BOP stack. 12/11/2008 00:00 - 01:00 1.00 BOPSU P DECOMP ND BOP stack 13-5/8" x 7-1/16" Adapter spool and false bowl hold down flange. 2-barriers for ND BOP stack are 1) Tested Printed: 12/30/2008 12:32:54 PM BP EXPLORATION Page 10 of 12 Operatfons Summary Report Legal Well Name: 04-45 Common Well Name: 04-45 Spud Date: 3/7/1994 Event Name: WORKOVER Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/13/2008 Rig Name: DOYON 16 Rig Number: Date i From - To Hours ' Task Code NPT I Phase Description of Operations 12/11/2008 00:00 - 01:00 1.00 BOPSU P DECOMP RBP at 6766' and 2 Tested RTTS at 126'. 01:00 - 02:00 1.00 WHSUR P DECOMP PU 1-jt of 4" DP and XO to false bowl. RIH and screw into false bowl. BOLDS on tubing spool. Pull false bowl to rig floor. LD false bowl and XO. 02:00 - 03:30 1.50 WHSUR P DECOMP MU Pack Off pulling tool to jt of 4" DP. Vac out tubing spool. FMC tech bleed pack off void. BOLDS on casing spool. RIH and engage casing pack off. Pack off pulls free 55K-Ibs. POH. LD pack off. PU new pack off, RIH and set. RILDS. Clean ring gasket groove on top of tubing spool. RU and FMC tech test void to 5000-psi for 30-minutes. Good test. 03:30 - 05:30 2.00 BOPSU P DECOMP P stack. 05:30 - 06:00 0.50 BOPSU P DECOMP RU to test BOP stack break. Set test plug. Test to 250-psi low and 4000-psi high for 5-minutes each, recorded. 06:00 - 07:00 1.00 CLEAN P DECOMP RIH with RTTS retrieval tool, latch, release and POH with RTT Break off and UD RTTS. 07:00 - 07:30 0.50 CLEAN P DECOMP RIH to en a e RBP and unseat. Fluid level slowl dro ed immediatel after releasin RBP. 07:30 - 08:30 1.00 CLEAN P DECOMP CBU at 4-BPM, 1990-psi. Monitor well and well is dead. Blowdown Top Drive. 08:30 - 09:30 1.00 CLEAN P DECOMP RIH with remaining 2-7/8" PAC DP from Deririck. 09:30 - 11:00 1.50 CLEAN P DECOMP CBU and get small amount of gas at surface when Bottoms Up. CBU again 4-BPM at 2470-psi. Monitor well and well is dead. Well loss was ~6-BPH during the two CBUs. The tour loss from midni ht w .Derrickman inspected the Fast Line Sheave and it has not moved since last inspection. 11:00 - 18:30 7.50 CLEAN P DECOMP Pump dry job, blowdown Top Drive. PJSM to POH and UD 2-7/8" PAC DP. POH with 2-7/8" PAC DP. 45-joints UD at 1245-hours. 105-jts ~ 1400-hrs. 135-jts C~ 1445-hrs, S/D POH and send Derrickman to inspect Fast Line Sheave and sheave has not moved. 225-jts @ 1655-hrs. When finished POH, Derrickman again inspected Fast Line Sheave and it had not moved. 18:30 - 19:00 0.50 CLEAN P DECOMP LD 5-1/2" HES RBP and runnin tools. 19:00 - 19:30 0.50 BUNCO RUNCMP Pull wear ring. Remove 2-7/8" DP elevators and short bails. 19:30 - 20:30 1.00 BUNCO RUNCMP RU to run 3-1/2" 9.2# L-80 TCII straddle acker com letion with 2-3/8" 4.6# L-80 STL tail i e. RU long bails, power tongs, torque turn equipment and compensator. RU and function test Stabbing board. 20:30 - 00:00 3.50 BUNCO WAIT RUNCMP While checking completion jewelry, discover that ID of X-nipples between packers is larger than the bore of the packer. This would render the X-nipples useless. Call and discuss the situation with town. Decide to find 2-3/8" X-nipples to be run between the ackers. Locate necessary nipples at Stores. Send nipples and 3-1/2" tubing pup jts to Baker Machine. Baker Machine is manufacturing XOs for nipples from 2-3/8" IBT (nipples) to 3-1/2" TCII (tubing) and will then buck up the X-nipple assemblies. While waiting, circulate across the top of the hole. Loss rate at 2200-hrs is 6-BPH. Also, service Top Drive and Drawworks, clean throughout the rig and check the moving system in preparation for upcoming rig move. 12/12/2008 00:00 - 09:00 9.00 BUNCO WAIT RUNCMP Wait on jewelry. While waiting, circulate across the top of the hole. Loss rate while circulating = 5 to 6-BPH. Also, perform Printed: 12/30/2008 12:32:54 PM • • BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: 04-45 Common Well Name: 04-45 Spud Date: 3/7/1994 Event Name: WORKOVER Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/13/2008 Rig Name: DOYON 16 Rig Number: Date ;From - To Hours Task Code NPT Phase I, Description of Operations 12/12/2008 00:00 - 09:00 9.00 BUNCO WAIT RUNCMP light housekeeping and maintenance, work on skate ejectors and install new driller-side cellar door. 2-3/8" X-nipple assemblies built, bucked up and leaving Baker Machine for pressure testing at Halliburton at 0415-hrs. One X-nipple assembly pressure tested by 0515-hrs. Called Slickline to check capability of fishing the Ball & Rod through reduced ID of 2-3/8" X-nipplesy The 2" RB pulling tool for pulling the Ball and Rod is 1.775" OD and the 2-3/8" GS/GR spear for pulling the RHC-M plug is 1.80" OD versus the 1.855" drifted ID of the 2-3/8" X-Nipples. Check all jewelry against the revised completion running summary to verify accuracy. Current fluid loss as of 0830 is -6-BPH. 09:00 - 09:45 0.75 BUNCO RUNCMP Check out the 2-3/8" handling equipment set up with pancake pressure sensor to set torque at 600-Ib-ft for the 2-3/8" STL connections. Hold Completion Running PJSM with rig crew, Baker Technician, Doyon Casing Technician, Toolpusher and WSL. Discuss the additional safety requirements for lifting the 2-3/8" STL into position with lifting nubbin and sling. Also discuss how all of the 2-3/8" 'ewel includin X-ni les and ackers are to be drifted with I and Rod• keeping the pin end of each assembly close to the heavy rig floor carpet when removing the thread protectors to prevent injury to personnel and damage to the ball end of the rod. 09:45 - 18:30 8.75 BUNCO RUNCMP P/U 2-3/8" WLEG assembly, 2-3/8" XN-Nipple assembly (drifted on Skate), 2-3/8" tubing joint, 2-3/8" X-Nipple assy (drifted on Skate), bottom Baker FH Packer assy (drifted on Skate), and 2-3/8" X-Nipple assy (drifted on Skate). All connections below the bottom packer were BakerLoked and torqued to 600-Ib-ft. The 3-1/2" 9-~#- L-8~, TCII torqued to 2300-Ib-ft optimum torque using a compensator and Jet Lube Seal Guard pipe dope. 48-joints RIH at 1500-hours. 95-jts RIH at 1830-hrs. 18:30 - 19:00 0.50 BUNCO RUNCMP During inspection, discover that fast line sheave had moved. Gather tools and send derrickman up to reposition sheave. 19:00 - 19:30 0.50 BUNCO RUNCMP Service drawworks and Top Drive. 19:30 - 00:00 4.50 BUNCO RUNCMP Continue to RIH with 3-1/2" 9.2# L80 TCII compeletion. Utilize Jet Lube Seal guard pipe dope and Torque turn services. Torque all 3-1/2" connections to 2300-Ib-ft. 150-jts RIH at 2140-hrs. 175-jts RIH at 2240-hrs. 190-jts RIH at 0000-hrs. Inspect fast line sheave at tour change. It had not moved since 12/13/2008 00:00 - 04:00 4.00 BUNCO RUNCMP -Run 3-1/2" 9.2# L80 TCII Straddle packer Completion. Use Jet Lube Seal Guard pipe dope on all connections. All connections torque turned to 2300-ft-Ibs of torque. 205-jts RIH at 0030-hrs. 240-jts RIH at 0215-hrs. PU wt before landing hgr = 108K-Ibs. SO wt before landing hgr = 90K-Ibs. 04:00 - 05:00 1.00 BUNCO RUNCMP RD compensator. PU Landing jt and MU to tubing hanger. Using torque turn services, MU hanger to tubing string. Drain BOP stack. RD torque turn equipment. 05:00 - 06:00 1.00 BUNCO RUNCMP Land tubing hanger. FMC tech RILDS. RU head pin to landing jt to take returns up tubing. 06:00 - 06:30 0.50 BUNCO RUNCMP PJSM with rig crew, Vac truck driver, Lil Red crew, Tourpusher, and WSL. Discuss the displacement with corrosion inhibited Printed: 12/30/2008 12:32:54 PM • BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: 04-45 Common Well Name: 04-45 Spud Date: 3/7/1994 Event Name: WORKOVER Start: 11/6/2008 End: Contractor Name: DOYON DRILLING INC. Rig Release: 12/13/2008 Rig Name: DOYON 16 Rig Number: Date Frorn - To i, Hours I Task Code NPT Phase ~ Description of Operations 12/13/2008 06:00 - 06:30 0.50 BUNCO RUNCMP 9.8-ppg brine, followed by diesel freeze protection fluid. Each person in the meeting described what he thought was the most significant, hidden hazard for the job he was going to perform. 06:30 - 08:00 1.50 BUNCO RUNCMP PT circulating lines to 4000-psi. Reverse circulate 90-Bbls of clean 110-F, 9.8-ppg brine from Pits at 500-psi. Follow with 110-Bbls of 110-F, 9.8-ppg brine mixed with EC-1124A Corrosion Inhibitor. 08:00 - 08:30 0.50 BUNCO RUNCMP Reverse circulate 20-Bbls of diesel freeze protect at 2.5-BPM, 400-psi. Realign valves and pump 15-Bbls of diesel down the tubing at 1-BPM, 400-psi. Bleed off pressure and get ready to drop ball and rod. 08:30 - 10:00 1.50 BUNCO RUNCMP Drop ball and rod at 0835-hours. Lil Red pressure up on tubing to 4000-psi and record for 30 minutes. Needle valve in cellar develops a leak after 15-minutes. S/D, bleed down and replace needle valve. Lil Red pressure up to 4000-psi and record for 30-minutes for solid line test. Bleed tubing down to 1500-psi. 10:00 - 11:00 1.00 BUNCO RUNCMP Lil Red swap over to IA and pressure up to 4000-psi and hold for 30-minutes, recorded for solid line test. Bleed down and Lil Red and blow down rig lines. 11:00 - 14:00 3.00 BOPSU P RUNCMP P/U TWC, RIH and FMC Tech set in Han er. PT to 3500-psi from above. The TWC cannot be tested from below because there is no fluid path from IA into the tubing. Drain diesel out of stack to use water for testing TWC. Bump up TWC several times and et solid flatline test Bleed down circulating manifold in cellar. Slowdown Choke and Kill Lines, blowdown hole-fill line, drain BOP Stack. 14:00 - 15:00 1.00 BOPSU P RUNCMP PJSM to changeout VBRs, and discuss the DAFWAC case involving severed fingertip on Nabors Rig. ~hangeout VBRs from 2-7/8" x 5" to 3-1/2" x 6" rams for next well. 15:00 - 16:00 1.00 BOPSU P POST PJSM. Pull Riser and turnbuckles, lift BOP stack onto stump, clean wellhead and fill void with hydraulic oil. 16:00 - 18:30 2.50 WHSUR P POST Steam adapter flange and NU to wellhead. NU tree to adapter flange. FMC tech test adapter flange and hanger seals to 5000-psi for 30-minutes -good test. 18:30 - 23:00 4.50 WHSUR P POST Fill tree with diesel and pressure test to 5000-psi for 30-charted minutes. RD mud manifold while testing. Having trouble getting a test. Work to isolate leak as none are seen on the tree. Isolate test pump and discover it is leaking. Good test once isolated from test pump. RD test equipment. 23:00 - 00:00 1.00 WHSUR P POST Secure well and cellar. RD double annulus valve. Install tree cap, OA & IA gauges. Bridle up while securing well. Release Ri at 2400-hrs on 12/13/2008. Printed: 12/30/2008 12:32:54 PM • Well History Well Date Summary 04-45 11/5/2008 ***WELL S/I ON ARRNAL*** RAN 2.84" CENT TO 1100'SLM. DID NOT SEE FLUID LEVEL. LOAD TUBING W/ 5 BBLS 60/40 METH SPEAR, 132 BBLS KCL, 25 BBLS 60/40 FREEZE PROTECT RAN KJ, 2.31" CENT/BRUSH/. S/D(c~ 9,013' SLM BRUSH XN. ATTEMPT TO RUN 2 7/8" XXN PLUG THRU RESTRICTION AT 1,256' SLM. MAKE SEVERAL RUNS WITH TAPERED CENT. FROM 2.50 TO 2.72 CENT THRU RESTRICTION AT 1,256' SLM SET 2-7/8" XXN PLUG WITH 6 1/4" C-O. PORTS AT 9.016' SLM LRS CMIT-T TO 4000#. (PASS)... - DRIFT W/ 2.72" CENT, 2.625" CENT, 2.61" SWAGE TO 2/7/8" X-OVER @ 9006' MD. ****CONT JOB ON 11-06-08**** 04-45 11/5/2008 T/V0=200/140/0 Assist Slickline, CMIT TxIA PASSED to 40Q,Q ~(RWO Preol Pumped dow n Tbg w ith 5 bbls methanol, 132 bbls of 1 % KG, followed by 25 bbls of 60!40 mth/wtr for freeze protect. Pressured up TxIA to 4000 psi w ith 28.3 bbls of 60/40 meth/w ater for CMIT TxIA. T/I lost 0/0 psi in 1st 15 min and 10/10 psi in 2nd 15 min, ran CMfT out fora 3rd 15 min and T/I lost 10/10 psi, ran test ou a 4th 15 min and T/I lost 0/0 psi for a total loss of 20/20 psi in 60 rrin. Bled pressures, FWHPs=450/450/0. Slickline in control of w ell upon LRS departure. 04-45 11/5/2008 Load fluid for upcoming CMfT TxIA. 04-45 11/6/2008 ***WELL SHUT-IN ON ARRNAL*** T/VO = 150/200/0. RUN JEWELERY LOG FROM 9018' UP TO 8880' FOR DEPTH CONTROL ON SECOND RUN. RUN 2.5" JET POWERCUTTER CUT 3.5" TUBING AT 8985' , WELL SI ON DEPARTURE FINAL T/VO = 125/150/0. ***JOB COMPLETE*** 04-45 11/6/2008 ***CONTINUED FROM 11/5/08 WSR***(secure well) RAN 2.72" CENT/2.625" CENT/2.61" SWEDGE TO 9,006 MD NO PROBLEMS. ***WELL LEFT S/I*** DSO NOTIFIED. 04-45 11/7/2008 Circ Out (Pre RWO) ***Job In Rogress Continued On WSR 11-08-08*** 04-45 11/8/2008 T/V0=500/500/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (0 psi). Functioned LDS (ET style), all moved freely (1 "). Pumped through void, clean returns. Pressured false bow I void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Tested coil hanger to 5000 psi for 30 rrin, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (200 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (1 "). Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. 04-45 11/8/2008 T/V0=100/100/0 Grc Out, MIT OA PASSED to 2000 osi (Pre RWO) Speared into Tbg w ith 5 bbls of meth followed by 162 bbls of 60*F 9.3 brine dow n Tbg taking returns up IA to 04-05 treecap. Pumped 6.6 bbls of diesel dow n OA to reach 2000 psi for MIT OA. OA lost 130 psi in 1st 15 min and 50 psi in 2nd 15 min lost for a total pressure loss of 180 psi in 30 min. Bled OA (- 2 bbls). ***Job In Progress. Continued On WSR 11-09-08*** 04-45 11/9/2008 ***Job In Progress Continued From WSR 11-08-08*** Grc Out CMIT TxiA FAILED 4000 osi_ (R-e RWO) Pumped 267 bbls of 60*F 9.3# brine dow n Tbg up IA to 04-05. Punped 5 bbls of 9.3# brine dow n Tbg to reach 3200 psi for CMIT TxIA, T/IA pressure started falling gradually, monitored pressures and in 15 min T/IA w ent on vac, Pumped 4 bbls diesel down IA to reach 500/500 psi, T/IA lost 460/480 psi in 7 min re- pressured up T/IA w ith 1 bbl 9.3# brine to reach 500/500 psi, T/IA lost 500/500 psi in 6 min. Purrped 1 bbl of diesel dow n Tbg to reach 500/500 psi, monitored w ellhead pressure, in 10 rrin IA w ent on vac and Tbg w ent on vac in 15 nin. Ramped additional 3 bbls diesel dow n Tbg for Freeze Protect. Freeze protect surface pipe w ith 5 bbls diesel. ***Job In Progress Continued on WSR 11-10-08*** 04-45 11/9/2008 ***WELL S/I ON ARRNAL***(pre rw o) DRIFT W/ 2.30" SWA QB TO ET PASSED 9001 S M ****CONT JOB ON 11-10-08**** 04-45 11/10/2008 ***Job In Progress, Continued From WSR 11-09-08*** T/V0=5/10/25 Load Tbg & IA (RWO Prep) Bled wellhead pressure. Ramped 12 bbls of 30*F diesel dow n IA. Bled Tbg/IA. FWHPs=O/vac/0. Casing valves open to gauges. Print Date: 1/13/2009 Page 1 oft a Well Date Summary 04-45 11/10/2008 ****CONTJOB FROM 11-9-08****(pre rwo) ATTEMPT TO RIH TO CUT TUBING (a7 9001' SLM. UNABLE TO PASS 1258' SLM. SUS -T PARTED TUBING ***WELL S/I ON DEPARTURE"** (DISCUSSED VALVE POSffION W DSO) 04-45 11/12/2008 T/V0=0/0/0; Set 4-1/16" CNV "H" BPV #150 thru tree for Doyon 16 ire-rig; 1-2' ext. used, tagged @ 96"; Set 2" FMC VR Plug in VA and removed 2-1/16" Annulus Valve from front side of tree and Blinded for rig clearance; ***Complete*** (BesUFraker) 04-45 12/1/2008 T/V0=125/125/0; Pulled 4-1/16" CNV "H" TWC #256 thru tree for Dovon 16; Well building pressure, need to pump bll wt. fluid; 1-2' ext. used, tagged @ 102"; ***Complete*** (Best/Fraker) 04-45 12/1/2008 T/VO=Vac/0/0. Pull 4-1/16" CNV H BPV #150 thru tree rip move ovet~ell. 1-2' ext used, tagged @ 98". No problems. 04-45 12/2/2008 T/V0=0/0/0. Pull 4 1/16" CNV H TWC #256 thru tree, w ould not hold pressure from top side. Dry Rod in CM/ H TWC #284 thru tree. ND/NU BOP. Would not hold pressure again. Pulled TWC. 1-2' ext used, Tagged @ 96". No problems. 04-45 12/3/2008 T/VO=vac/0/0. Pull 4 1/16 CNV H TWC thru stack, post BOP test. RKB=22.54'. 22' ext used, tagged @ 62 no problems 04-45 12/24/2008 T/VO = 0/0/0 Pulled 4-1/16" CNV "H" TWC # 257 thru tree. 1-2' ext.used...tag @ 102"....post -rig....no problems. 04-45 12/27/2008 '**WELL S/I ON ARRNAL*** (post rw o) PULLED BALL & ROD FROM 9111' SLM PULLED 2 3/8"" RHC FR M 911 DRIFTED W/ 1.71" CENT, 1 1/2" SAMPLE BAILER TO TD (a7 11671' SLM (CORRECTED TD @ 11677' MD) (7' OF OPEN PERFS - 33' OF COVERED PERFS) (SAMPLE OF SCHMOO) ***WELL LEFT S/I ON DEPAR 04-45 1 /11 /2009 04-45 1 /12/2009 T/V0= 1450/1020/310. Temp= Hot. IA FL (pre-AOGCC Mfg. IA FL @ surface. SV= C WV, SSV, MV= O IA, OA= OTG NOVP. T/V0=1450/1100/300 MIT IA 2500 PASS [Post RWOI temp=iniecting Purrped .5 bbls 0* neat meth down IA to reach test pressure 2500 psi. IA lost 0 psi in 15 rrin's, 0 psi in 2nd 15 min's, total loss 0 psi in 30 min's. Bled back .5 bbls **Sw ab valve closed, SSV/ Master/ Annulus valves open on departure** FWHPs= 1450/1100/300 Print Date: 1/13/2009 Page 2 oft 4-45 Page 1 of 1 i ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent; Wednesday, December 10, 200$ 8:12 AM To: 'Baca, Hank' Cc: 'Ream, David C ; Regg, James B (DOA); 'NSU, ADW Well Integri#y Engineer' Subject: RE: 4-45 (194-034) Hank, You, Dave and I discussed what the pressure testing had determined. Long "scabs" have been set in other wells. Since this is an injector, a MITT as well as the MITOA will need to be performed. The both tests will be required whenever integrity is being demonstrated. Tom Maunder, PE AOGCC From: Baca, Hank [mailto:hank.baca@bp.com] cti ~~ Sent: Tuesday, December 09, 2008 4:48 PM ~~~~~~ fit` ~ ~1~> L .S. ~'^' ''- To: Maunder, Thomas E (DOA} Subject: 4-45 Tam, the leak is between 6771-6866'. We're planning to scab from ^6700' to 9010'. We'll bullhead corrosion inhibitor to cover the entire scab length prior to setting the packers. New proposed diagram attached. Holler with any questions. Thanks, «,4-45 cret diagram.pdf» Hank Baca Drilling Engineer 907-564-5444 office 907-748-13997 cell 12/10/2008 Page 1 of 2 Maunder, Thomas E (DOA) From: Baca, Hank [hank.baca@bp.com] Sent: Monday, December 08, 2008 4:10 PM To: Maunder, Thomas E (DOA) Subject: RE: Problems with casing test -- DS 04-45 (194-034) -- Sundry (308-311) Tom, this was a test above the suspected jet cut damage. I'm forwarding the more detailed note from the WSL. We'll be setting the RBP deeper than the planned production packer and using a retrievable packer to isolate the upper leak and see ifi there is indeed casing damage from the jet cut. We also milled out some nipples, so we want to test below that as well. Once we have those results we'll get a plan together and get back with you. Thanks, and holier if the other note doesn't answer your questions. Hank Baca Drilling Engineer ~,~~i~;.`,~? 41~1~ ~. ~~ ~~~ 907-564-5444 office 907-748-0997 cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, December 08, 2008 11:00 AM To: Baca, Hank Subject: RE: Problems with casing test -- DS 04-45 (194-034) -- Sundry (308-311) Hank, Looking back at the file, it appears this is a different leak than that resultant from the tubing jet cut. Is that so? How did the casing test develop? Was the pressure rise straight line until the failure? Thanks in advance. Tom Maunder, PE AOGCC From: Baca, Hank [mailto:hank.baca@bp.com] Sent: Monday, December 08, 2008 10:27 AM To: Maunder, Thomas E (DOA) Subject: RE: Problems with casing test -- DS 04-45 (194-034) -- Sundry (308-311) Tom, we attempted to test production casing to 4000 psi. An RBP was set @ 7727'. We were unable to get above 3850 psi. After bleeding off remaining pressure, there was ~4 bbl gain noticed in the pit. The well was shut-in with the annular, SlDPP pressure was 90 psi. The well was killed with 9.7 ppg brine. Afterwards shut-in pressure on bath sides was 0. We suspect a Cretaceous leak at this point. We're currently planning to finish some rig repair, then reset the RBP deeper and RIH w/ an RTTS to isolate the leaks}. We need the leak info to determine the path forward. Holler if you need more information. Thanks, Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, December 08, 2008 9:02 AM To: Baca, Hank Cc: Reem, David C; DOA AOGCC Prudhoe Bay 1 /28/2009 Page 2 of 2 Subject: F1IV: Problems with casing test -- DS 04-45 (194-034) -- Sundry (308-311) Dave, Below is the message I received from John Crisp late yesterday. I have not seen anything else on the incident and well conditions. Could you please provide an update on the situation at DS 04-45? Thanks in advance. Tom Maunder, PE AOGCC From: Crisp, John H (DOA) Sent: Sunday, December 07, 2008 8:31 PM To: Regg, James B (DOA) Cc: Scheve, Charles M (DOA); Regg, James B (DOA); Grimaldi, Louis R (DOA); Noble, Robert C (DOA); Maunder, Thomas E (DOA) Subject: Problems with casing test Doyon 16 Well Site Leader Mike Ivano called about 1700 hrs 12/07/08 to notify AOGCC they had attempted to test casing on PBU 4-45 with RBP when the test pressure suddenly dropped off. They thought Surface Circulating Equipment but after investigation they realized the casing had probably burst or possibly parted. The notification to us was the well started flowing & they are monitoring pressures. I requested Mike send us a mail with detailed information about the incident. 1 /28/2009 TREE = FMC NEW STAND WELLHEAD = CM/ ACTUATOR = BAKER C KB. ELEV = 64' BF. ELEV = KOP = 1967' Max Angle = 49 @ 6263' Datum MD = 11502' Datum TVD = 8800' SS • 0 4 -4 5 OTINGTLIMITS* MAX' ~ = 2000 SI; MAX PROPOSED oAP =100o Psl l01/o3/os wav~l ~•* 3.5" Otis X nipple, ID 2.813" @ - 2000' 3317' I--i ESTIMATED TOP OF CEMENT 9-5/8" CSG, 47#, NT-80, ID = 8.681" Minimum ID = 2.25" @ 9035' 2-7/8" OTIS XN NIPPLE 3.5" Otis X nipple, ID 2.813" 2.375" X 5.5" Baker packer @ 6620' casing leak 6771-6866` 3-1/2" 9.3# L-80 TC-2 tubing PERFORATION SUMMARY REF LOG: MWD ON 03/19/94 ANGLE AT TOP PEf2F: 32 @ 11670' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11670 - 11710 O 06/25/94 PBTD 11774' 5-1 /2" CSG, 17#, L-80, ID = 4.892^ 11856' r~ 11875' 2.375" X 5.5" Baker packer @ 9010` 2.375" Otis X nipple 2.375" Otis XN nipple DATE REV BY COMMENTS DATE REV BY COMMENTS 03/20/94 ORIGINAL COMPLETION 01!03/06 EZL/PJC UPDATE WANER SFTY NOTE 06/29194 LAST WORKOVEI2 01/09!06 KDGPJC TTP PULLED @ 9005' 04/28/03 ATD/TLH WANER SAFETY NOTE 11/07/04 JAF/TLP PULL PXN PLUG 8< PRONG 07/21/05 MCJ/PJC OA DOWN SQUEEZE 12!13/05 DAV/TLH TTP SET PRUDHOE BAY UNfr WELL: X04-45 PERMfT No: 1940340 API No: 50-029-22454-00 SEC 34, T11 N, R15E, 4079.54' FEL & 978.72' FNL BP Exploration (Alaska) A short summary of events from on Doyon 16, well PBU 04-45 ~• ~~ ~~~ ~~ Regg, James B (DOA) From: Aivano, Michael J (ANC) [Michael.Aivano@bp.com] Sent: Monday, December 08, 2008 11:43 AM ~~ ~ ~ "I ~~~~~ To: Regg, James B (DOA}; DOA AOGCC Prudhoe Bay; Fleckenstein, Robert J (DOA) Cc: Baca, Hank; Hefley, G Mike Subject: A short summary of events from on Doyon 16, well PBU 04-45 A short summary of events from on Doyon 16, well PBU 04-45 Page 1 of 1 13:00 hrs on 12/7/2008 A Halliburton RBP was set on drill pipe at 7727 ft. in the 5-1/2" casing. The plug was going to be the first of two barriers set prior to removing the BOP Stack and performing some wellhead work. With the plug set and released from the drill pipe it was pressure tested and chart recorded to 2500 psi for 30 mins. While waiting on word from town on some other work to take place once the barriers were in place it was decided to bring the pressure test up to 4000 psi for a ten minute test. The casing was going to be pressure tested to 4000 psi just after the wellhead work was completed from a deeper depth. This test was just a data point that could be used in case the casing failed the 30 minute 4000 psi pressure test that was planned just prior to running completion. The casing pressure was increased from 2500 psi, when the pressure on the casing reached 3850 psi it drastically fell off. The DP was opened to the bleed line and all surface equipment was quickly checked as well as the pressure on the outer annulus, nothing was found. Flow was noticed through the bleed line soon after checking the surface equipment. With the bleeder closed pressure built to and stabilized just under 100 psi on the casing and drill pipe. Contacted and notified John Crisp with the AOGCC in Prudhoe Bay and BP Supervisor in Anchorage. A wellbore volume was circulated with the seawater underneath the annular and through the choke. Shut-in pressures were checked again once a full circulation was made. The pressures were the same. No significant amount of gas was seen during the circulation but returns at bottoms up showed to be a dark grey color. The well was then circulated with 9.7 ppg brine through the choke. With 9.7 ppg brine in and out, shut-in pressures were checked again with zero psi on both the drill pipe and the casing. The choke was opened to check for flow and then the annular preventer was opened. If you have any questions please contact me. Mike Aivano Doyon 16 Welfsite Leader 907-659-4168 office 907-943-1381 cell 12/8/2008 Regg, James B (DOA) From: Sent: To: Cc: Crisp, John H (DOA) Sunday, December 07, 2008 8:31 PM Regg, James B (DOA) • ~~~1 z~ ~- Page 1 of 1 Scheve, Charles M (DOA); Regg, James B (DOA); Grimaldi, Louis R (DOA); Noble, Robert C (DOA); Maunder, Thomas E (DOA) Subject: Problems with casing test Doyon 16 Well Site Leader Mike Ivano called about 1700 hrs 12/07/08 to notify AOGCC they had attempted to test casing on PBU 4-45 with RBP when the test pressure suddenly dropped off. They thought Surface Circulating Equipment but after investigation they realized the casing had probably burst or possibly parted. The notification to us was the well started flowing & they are monitoring pressures. I requested Mike send us a mail with detailed information about the incident. 12/8/2008 04-45 changes . • Maunder, Thomas E (DOA) From: Baca, Hank [hank.baca@bp.cornJ Sent: Monday, November 17, 2008 8:53 AM To: Maunder, Thomas E (DOA) Cc: Reem, David C Subject: RE: 04-45 changes Tom, I'd say 7-10 days. Should we submit another sundry? Q T~p Hank Baca Drilling Engineer {~~~~~~ j1~'~. ~ u ~' ~~;4 907-564-5444 office 907-748-0997 cel! Page 1 of 2 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sen#: Sunday, November 16, 2008 10:24 AM To: Baca, Hank Cc: Reem, David C Subject: RE: 04-45 changes Hank and Dave, Thanks for the info. When is the rig work to be started? This may take a new sundry due to the change in plans on an injector. Tom Maunder, PE AOGCC From: Baca, Hank [mailto:hank.baca@bp.com] yen#: Friday, November 14, 2008 11:03 AM To: Maunder, Thomas E (DOA) Subject: 04-45 changes Hi Tom. Here's the information for the well we discussed earlier this week. We most likely damaged the 5.5" production casing while cutting the tubing. The well passed a combo MtT to 4000 psi prior to cutting tubing and failed afterwards. We got to step 3 in the pre-rig work plan. We're planning to verify the leak is at the tubing cut depth (8985') and assuming it is, straddle the damage with 2 packers. I've attached a revised schematic and scope of work. Let me know if you need more info. Thanks, «revised 04-45 Scope of Work.ZlP» «4-45 proposed.pdf» Hank Baca Drilling Engineer 907-564-5444 ofFce 12/8/2008 • by C'~a~Prudh~Bav • 04-45 Rig Workover (Injector tubing swap TxIA communicaton) Scope of Work: Remove 3.5" coil & 2-7/8" L-80 completion. Run 3.5" L-80 completion. Engineer: Hank Baca MASP: 3300 psi Well Type: Injector Estimated Start Date: December 1st, 2008 S 1 RIH and set lu in 2-7/8" XN ni le 9005' F 2 CMIT TxIA to 4000 psi for 30 charted minutes. MIT OA to 2000 psi for 30 charted minutes PASSED 11/5/0$, FAILED POST JET CUT 11/9/08 E 3 Power Jet cut coiled tubin 8985'. DONE O 4 PPPOT-T, -IC, check all LDS. PASSED 11/8108 Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/ 4000 psi high. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 3.5" coiled tubing string to the cut. 3. recover 2-7/8" tailpipe and seal bore 4. Run 3 '/:" L-80 completion with two FHL packers straddling casing damage @ 8985'. 5. Displace the IA to packer fluid and set the packers. 6. Test tubing and IA to 4000 psi. Freeze protect to 2,200' MD. 7. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. TREE = FMC NEW STAND WELLHEAD = CNV ACTUATOR= BAKERC KB. ELEV = ba' BF. ELEV = KOP = 1967' Max Angle = 49 @ 626 3' Datum MD = _ 11502' Datum TV D = 8800' SS 04-45 PROPOSED 3.5" Otis X nipple, ID 2.813" 3317' I-i ESTIMATED TOP OF 9-5/8" CSG, 47#, NT-80, ID = 8.681" Minimum ID = 2.25" @ 9035' 2-7/8" OTIS XN NIPPLE 3-1/2" 9.3# L-80 TC-2 tubing PERFORATION SUMMARY REF LOG: MWD ON 03/19/94 ANGLE AT TOP PERF: 32 @ 11670' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11670 - 11710 O 06/25/94 PBTD I~ 11 5-1/2" CSG, 17#, L-80, ID = 4.892" I-I 11 TD I~ 11875' 3.5" Otis X nipple, ID 2.813" 2.375" X 5.5" Baker FHL packer @ -8950' casing damage @ 8985' 2.375" X 5.5" Baker FHL packer @ -9010` 2.375" Otis X nipple 2.375" Otis XN nipple DATE REV BY COMMENTS DATE REV BY COMMENTS 03/20/94 ORIGINAL COMPLETION 01/03/06 EZUPJC UPDATE WAVER SFTY NOTE 06/29/94 LAST WORKOVER 01/09/06 KDGPJC TTP PULLED @ 9005' 04/28/03 ATD/TLH WANERSAFETY NOTE 11/07/04 JAF/TLP PULL PXN PLUG & PRONG 07/21/05 MCJ/PJC OA DOWN SQUEEZE 12/13/05 DAVfTLH TTP SET PRUDHOE BAY UNIT WELL: X04-45 PERMff No: 1940340 API No: 50-029-22454-00 SEC 34, T11 N, R15E, 4079.54' FEL & 978.72' FNL BP Exploration (Alaska) • • - w.~ _ .~ ~ ~ v. m~ _ ~"- _~7 !al , , ~~ ~s; 6 r~ ~I1 ~ ~ ¢ 9~ t~.~~i s~""1 ~ ~ SARAH PALIN, GOVERNOR .~ ~_~ CUI~SEBQ~ A,IIOH Off= 5.7~-,: f 333 W. 7th AVENUE, SUITE 100 i` ~ii ~~i1~ii~7 ~I~o~„~ ~ ANCHORAGE, ALASKA 99501-3539 a~ PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Senior Drilling Engineering BP Exploration Alaska Inc. ,~ ~ ,~ ~~~$ PO Box 196612 ~~ S ~ P -~ ~- ©3 ~- Anchorage, AK 99519-6612 ((,1 (,~ ' Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04-45 Sundry Number: 308-311 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided iri 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, Cathy . Foerster Commissioner DATED this ~~ay of September, 2008 Encl. I~.C~/~i~ 4>>A STATE OF ALASKA c~/ AUG ~ 9 ~~~8 ~ ALAS OIL AND GAS CONSERVATION COMM ION ~ ~ APPLICATION FOR SUNDRY APPROVA aska ®i~ ~ ~~~ ~Qns. ~ofnrnissi~n O~, 20 AAC 25.280 Gnu!„~~„~o 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ®Repair Well ° ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing • ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Nu ber BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 1944 Q~ 3. Address: ®Service • ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22454-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 04-45 Spacing Exception Required? ^ Yes ^ No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028328 64.80' Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11874' - 9180' 11721' 9050' N/A N/A in L h iz MD TVD Bu Ila s r rl n r 112' 1 2' Surfa -5/8" 28' 555' 57 30 Inter ediate 11 2 ' -1 7740 Lin r Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11670' - 11710' 9004' - 9038' 3-1/2" x 2-7/8", 7# / 6.5# QT-800 / L-80 9041' Packers and SSSV Type: 3-1/2" CAM DS SSSV Packers and SSSV MD (ft): 3003' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: September 15, 2008 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ~ WAG ~ ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Na David Reem Title Senior Drilling Engineer Prepared By Name/Number. Signature Phone 564-5743 Date $l~ ~& .Sondra Stewman, 564-x750 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity BOP Test Mechanical Integrity Test ^ Location Clearance Other: L`~~®~St ~Q~~S~- Subsequent Form Required: ~®L-t APPROVED BY 9 ' ~~ A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Revised 0/2006 Submit In Duplicate f` ~ ~ ~~~ `~~P 1 ~ 1Q08 ~I~~, • by CJ 04-45 Rig Workover (Injector tubing swap TxIA communicaton) Scope of Work: Remove 3.5" coil & 2-7/8" L-80 completion. Run 3.5" L-80 completion. Engineer: Hank Baca MASP: 3320 psi Well Type: Injector Estimated Start Date: September 15th, 2008 S 1 RIH and set lu in 2-7/8" XN ni le @ 9035' F 2 CMIT TxIA to 4000 si for 30 charted minutes. MIT OA to 2000 si for 30 charted minutes E 3 Power Jet cut coiled tubin @ 9000'. O 4 PPPOT-T, -IC, check all LDS. Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/ 4000 psi high fluid and circulate well to clean seawater through the cut. 2. Pull and LD 3.5" coiled tubing string to the cut. 3. recover 2-7/8" tailpipe and seal bore 4. Run 3-'h" L-80 completion with Baker SABL-3 packer. 5. Displace the IA to packer fluid and set the packer. 6. Test tubing and IA to 4000 psi. Freeze protect to 2,200' MD. 7. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. Circulate out freeze protection RDMO. I TREE = FMC NEW STAND WELLHEAD = CNV ACTUATOR = BAKER C KB. ELEV = 64' BF. ELEV = KOP = 1967' Max Angle = 49 @ 6263' Datum MD = 11502' Datum TVD = 8800' SS • 0 4 -4 5 SAFETY NOTES: ***RAPID TxIA COMM. O TING LIMITS: MAX IAP = 2000 PSI; MAX O 1000 PSI (01/03/06 WAVER) *** ~'1~ 3003' ~3-1/2" CAM DS SSSV NIP, ID = 2.812" ~„Yf 3317' ESTIMAT® TOP OF CEMENT 9-5/8" CSG, 47#, NT-80, ID = 8.681" ~ 3928' Minimum ID = 2.25" @ 9035' 2-7/8" OTIS XN NIPPLE 3-1/2" TBG-COILED, 7#, OT-800, .00930 bpf, ID = 3.094" TOP OF 2-7/8" TBG PERFORATION SUMMARY REF LOG: MWD ON 03/19/94 ANGLE AT TOP PERF: 32 @ 11670' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11670 - 11710 O 06/25/94 ~ ~ 2-7/8" TBG, 6.5#, L-80, .00579 bpf, ID = 2.441" ~-~ 9041' 15-1/2" OTIS XN NIP (BEHIND CT), ID = 4.562" I 9005' 3-1/2" OTIS XN NIP, ID = 2.75" 9006' 3-1/2" X 2-7/8" XO 9007' 2-7/8" LOC SEAL UNTT 9009' 5-1/2" SEALBORE RECEPTACLE W/X LOCK 9010' 5-1 /2" OTIS XN NIP (BEHIND CT), ID = 4.455" 9006' I 9~06~ 9020' I~ 3" x 2-7/8" XO 9035' ~ 2-7/8" OTIS XN NIP PRIOR TO SETTING PLUG SEE WELL FILE, ID = 2.25" ~9040~-12-7/8" MULESHOE WLEG 9046' ELMD TT LOGGED 07/05/94 PBTD 11774' 5-1/2" CSG, 17#, L-80, ID = 4.892" 11856' ~~ 11875' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/20/94 ORIGINAL COMPLETION 01 /03/06 EZL/PJC UPDATE WA V ER SFTY NOTE 06/29/94 LAST WORKOV ER 01 /09106 KDGPJC TTP PULLED @ 9005' 04/28/03 ATD/TLH WANERSAFETY NOTE 11/07/04 JAF/TLP PULL PXN PLUG & PRONG 07/21/05 MCJ/PJC OA DOWN SQUEEZE 12/13/05 DAV/TLH TTP SET PRUDHOE BAY UNIT WELL: ~4-45 PERMTf No: 1940340 API No: 50-029-22454-00 SEC 34, T11 N, R15E, 4079.54' F~ & 978.72' FNL BP Exploration (Alaska) TREE = FMC NEW STAND WELLHEAD = CNV ACT~JATOR = BAKER C KB. ELEV = 64' BF. ELEV = KOP = 1967' Max Angle = 49 @ 6263' Datum MD = 11502' Datum TV D = 8800' SS ~ 0 4 -4 5 S NOTES: "*'RAPID Tx1A COMM. O TING LIMITS: MAX IAP = 2000 PSI; MAX PROPOSED O -1000 PSI (01/03/06 WAVER) "' 3.5" Otis X nipple, ID 2.813" 3317' H ESTIMATED TOP OF CEMENT 9-5/8" CSG, 47#, NT-80, ID = 8.681" I 3928' Minimum ID = 2.25" @ 9035' 2-7/8" OTIS XN NIPPLE 3-1/2" 9.3# L-80 TC-2 tubing PERFORATION SUMMARY REF LOG: MWD ON 03/19/94 ANGLE AT TOP PERF: 32 @ 11670' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpnlSgz DATE 3-3/8" 6 11670 - 11710 O 06/25/94 PBTD ~ 11774' 5-1/2" CSG, 17#, L-80, ID = 4.892" 11856' 11875' 7999' H 5-1/2" OTIS XN NIP, ID = 5" Otis X nipple, ID 2.813" --~ 9010' ~ 5-1/2" OTIS XN NIP, ID = 4.455" 3.5" X 5.5" Baker SABL-3 packer 3.5" Otis X nipple, ID 2.813" 5" Otis XN nipple, ID 2.75" DATE REV BY COMMENTS DATE REV BY COMMENTS 03/20/94 ORIGINAL COMPLETION 01 /03/O6 EZL/PJC UPDATE WA V ER SFTY NOTE 06/29/94 LAST WORKOV ER 01 /09/06 KDGPJC TTP PULLED @ 9005' 04/28/03 ATDlfLH WANERSAFETY NOTE 11/07/04 JAF/TLP PULL PXN PLUG & PRONG 07/21/05 MCJ/PJC OA DOWN SQUEEZE 12!13/05 DAV/TLH TTP SET PRUDHOE BAY UNfr WELL: ~4-45 PERMIT No: 1940340 AR No: 50-029-22454-00 SEC 34, T11 N, R15E, 4079.54' Fli & 978.72' FNL BP 6cploration (Alaska) FW: 04-45i Step #1 of Exten~Patch Program Page 1 of 2 • Maunder, Thomas E (DOA From: Chivvis, Robert [Robert.Chivvis@bp.com] Sent: Thursday, June 12, 2008 8:48 AM To: Maunder, Thomas E (DOA) Cc: Preble, Gary B (BRIG); Chivvis, Robert Subject: RE: 04-451 (194-034) Step #1 of Extended Patch Program Hi Tom, We will submit a 10-403 once we finalize a procedure for setting the extended patch and upper packoff. The Klondike will be used for setting the extended patch. Bob tw'`d J From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, June 06, 2008 10:31 AM To: Preble, Gary B (BRIG) Cc: Chivvis, Robert Subject: RE: 04-45i (194-034) Step #1 of Extended Patch Program Gary and Bob, I don't see any issue with setting the lower packer. correct for the follow-up work. As discussed, the follow-up work will need a sundry scaffolding? Tom Maunder, PE AOGCC The well is SI and this step is necessary to get the spaceout Will the work platform (Klondike) be employed or just From: Preble, Gary B (BRIG) [mailto:Gary.Prebie@bp.com] Sent: Friday, June 06, 200$ 9:36 AM To: Maunder, Thomas E (DOA) Cc: Chivvis, Robert Subject: FW: 04-451 Step #1 of Extended Patch Program Tom, This is the well that I discussed with you this morning. Please let me know if this is enough info to proceed with creating a 10-403? Thanks From: Chivvis, Robert Sent: Thursday, June 05, 2008 11:25 AM To: Preble, Gary B (SAIC) Cc: Chivvis, Robert Subject: FW: 04-45i Step #1 of Extended patch Program 12/8/2008 FW: 04-45i Step #1 of Exten~Patch Program Page 2 of 2 • Gary, This is step #1 of a tubing patch on 04-45i. Step #2 has not been written yet. Is this enough to got forward with a 10-403? Bob Chiwis PE, PMP Production Engineer for Drillsites 4 and 11 GPB Eastern Waterflood 564-5412 From; Schmoyer, AI Sent: Thursday, June 05, 2008 11;09 AM To: G ANC Wellwork Program Cc: Chiwis, Robert Subject: 04-451 Step #i of F_xtended Patch Program «04-45 2008-05-05 Set lower packer.doc» 1218/2008 To: Clark Olsen/Jerry Bixby Date: June 5, 2008 GPB Well Ops Team Leaders AFE: PBD04WL45-N From: Tiffany Quy, Wells PE IOR: 100 Bob Chiwis, Production Engineer Subject: 04-451 Set Lower Packer for Tubing Patch Est. Cost: $50,000 Please perform the following procedures: 1. S Run 3.5" Baker Dummy Lower Packer to 1600' 2. E/F Set 3.5" Baker Set L-80 KB Lower Packer with tailpipe assembly and nipple profile with TTP at 1500'. CMIT TxIA to 2400 psi. Status: Not Operable due to TxIA communication Last Injection Rate: 12/27/2007: 5501 BWPD @ 1894 psi Max Deviation: 49 degrees @ 6263' Perf Deviation: 32 degrees @ 11670', top perf Min. ID: 2.25" @ 9035' 2-7/8" Otis XN Nipple Last TD tag: 04/02/2008 tag soft bottom at 11697' ELMD pre caliper Last Downhole Ops: 04/03/2008 to 11600' SLM - B&F tubing and calliper to surface Latest H2S level: Injector --- DS 04 is a H2S Drill site Objective: The objective of this procedure is to begin repair of several tubing leaks between 1142' and 1184' by setting a lower packer assembly for an extended tubing patch. A subsequent procedure will be prepared for setting the extended patch and upper pack-off using the Wellwork Platform. Well History: Well 04-45 is a shut-in water injector completed in 1994 with 3.5" 7# QT-800 coil tubing. In 2000 the well had high IA pressure and a LDL run on 06/11/2000 showed a series of holes in the tubing at 1142', 1155', 1172' and 1184'. The well was waivered to allow water injection only and kept on-line. The well was SI on 12/27/2007 due to the waiver policy changing on January 1, 2008. The well passed aCMIT-TxIA on 01/30/2007 proving production casing integrity. A caliper was run on 04/03/2008 which verified the tubing holes found by the LDL and indicated the tubing below 1370' had minimal corrosion. A RWO package was prepared in 2007 but drd not make the 2008 Rig Schedule although the economics were favourable. The estimated reserves benefit was 690 MBO with a peak rate of 21:2 BOPD. Patching the tubing leak will allow the well to return to injection and realize this benefit without the expense of a RWO and without the delay. Please contact Jennifer Julian at 564-5663(w), 240-8037(c), 274-0929(h), Tiffany Quy at 564-5322 (o), 253-576-6153 (c), or Bob Chivvis at 564-5412(w), 346-1859(h), 980-2597(c) with any questions or comments. • Discussion: The objective of this procedure is to set a lower packer assembly for an extended .patch. Originally this well was not considered for a patch due to the 3.5" coiled tubing completion. However, Baker has a packer that will seal over the weld bead along the inside of the coil. Typically, WRP diagnostics would be used prior to setting the lower packer. It was decided to set the lower packer without these diagnostics due to the good tubing condition below 1500' indicated by the calliper log. A dummy patch will be run first to 1600' to verify there are no restrictions in the tubing. The lower packer assembly will have a nipple profile with a plug for pressure testing. After the lower packer assembly is set, it will be pressure tested with a CMIT TxIA to 2400 psi. Following successful pressure testing, another procedure will be issued to seta 1500' 2-3/8" flush joint patch using the Wellwork Platform. This top of this patch will be set in the profile for the BPV. Pre-Patch Slickline **Note: all depths tied into calliper log. 1. Shoot T and IA fluid levels. 2. Run 3.5" dummy Baker patch lower packer to 1600'. Consult Baker for length and OD of dummy for this 3.5" coiled tubing completion. Set lower Packer Assembly Pre-Extended Patch 3. RU E-Line and pump. 4. RIH with 3.5" Baker Set L-80 KB patch lower packer with tailpipe assembly and nipple profile with TTP installed. (This well is a water injector, so chrome is not needed.) 5. Set packer at 1500' MD (see caliper attached). Log up from surface across tree after setting the packer. This log will be used to determine final length and space out of the extended patch. (From 2000 LDL, it will be possible to tie into pup and riser at surface. There was also a splice recorded at 1000' MD.) This well has a coil tubing completion so packer depth is not critical (no joints). No initial tie-in is necessary. 6. Perform CMIT-TxIA to 2400 psi. (Please refer to sketch below for further explanation of pressure testing.) a) If CMIT passes, RDMO. Well will be ready for extended patch program. b) If CMIT fails, determine LLR and notify town (Jennifer Julian or Tiffany Quy) for further analysis. • • CMIT Patch Dia4nostics C MIT Pas ses CMI T Fails it Known Known Tubing Tubing Holes WRP Holes WR Unknown Tubing Hole tr~rr a rrv~~t~ r~~~v s~~r~ 4'dE~IHEAL?- CPN Cl~'~~A TOR - BAk:ER G ihcd. EiE,' - E4'. ~. IfiF ELE~= w KOI'- _ :~tiT iF;t,tr i~n;t~ -19 o r,;i ~U;3turPAL~- ?'5i'L~ L3tua~~PJC~ , 88JU' S ~~ ~~ SAFETYNOTES~ •*•RAPIdTxIACOMM. ® OPERATING LIMITS: MAX IAP = 2004 PSI; MAX OAP =1 d04 PSI (411U3~D6 WAIVER} `"` I 3317` I ~-5f8" CSG; 47~, NT-80. lD n 8.58'" r-j 392E 11~I111TIZlUtTI III = 2.25'" @ g~35~ 2-7/8'° C}TIS XN NIPPLE s=t=z" tB~-cott_EQ, ~~, car-sty. flfls~ ~~. ~ m s~asa~ ToP ~F z-~rs° T~~ I 9t}U7' I PEfiFdRAT~N SUhttMAFTY REF LC7G: Eta L7N Cl3 r, JI~t AN(.~LEATTOPPERF:32 t357t' Note: Refer ~~d~t~n DB fot hutori~21 pe~tf data SIZE S~ F~dfERVAL Opn,'Syz DATE 3-3.~8" 5 i55TE3- 117YQ C t}ti'25a'~34 T6G, ~i.5#; L-Bfl, .0'J539 bpf, ~} = 2.~M1t" f--I 9041' ~PBTQ H 11 ~~~' 5- ":2" CSG, ~ 7», L-BJ. ~ t 4. B92" 11856' To 11875' 5,'2" OTG XN NIP. IQ = 2. ~~~° x z-7.~s" xa 1~s" LC}C s~L UNIT t:'2" SEALBflRE F2E~EP1 3G2" {7TH XRf NIP(BF3-!IN 91320' Hs, x r'2" CAht DS SSSV N~', [3 N Ta~i7El3 7OF~ OF G~1ENF (5-t ~2' OTtS XN NbP {Bt3itN©CT}, p = ~.5fi2" I d= A.d55' 91735' 2~7t8" OTIS XN NIP PRtG~R TC~ SE°i PLtlG SEE W ELL F~ E, D } 2.28,, g0~0' H2-7.'8" t~R}LESHwr?El°rLEG ~Q¢~" ELh+~3 T7 Lf3GGED {l7i'i35:KJ4 DATE REl? BY C~3Pa1A1FA~IFS l?t1TE RE1f F3Y CC}Fdtt~tENTS f33i2D3`~4 ORIGINAL COA7PLETt4N 0?;'fl3~x~5 EZLiP.lC L~PflAI'EiiVttA~ER SFTY Nt7TE Ofi128,'9d LAS7 WG~RKOVER p'.±09ii1e, K(~'PJC TTPPULLF17~9445' fl~,23~fl3 .JiTQ`TLH 4'vAlt+ff~SAFETYNt3TE ~ ..fli`fl4 Jt'~F,'Tlf~ FLFLL PXN PLLIG$ .UNG fl7,2' ~[i5 t:1C,t+P.k:. aA C7G.VN Sc7UF_EZE 2 ?: s='US DA~j,TLH TTF~ SET PRUC}FI<JEB.AY UNIT t~Jt1L' RJA-45 PERRNT M1k}: ~ ~~3Y30 API N;~: 5fl-U29-2245-t};7 SEC 39. T = ~ N_ R~ AJ~9.5d' FEL 8 528.72' FNL BP F.reptoratlQ€t (AlasEca) • • • ShlB~i ~~~ 04-d5 Ik8ffi ~rep~red 9y SCORE _~ x/2:9/99 ~-,~ Ire ~ Ii~AX ~(3D ~ @ilgl~. d© ~s~ LI:h1G't~l ~ ~ DEP7'!d c 1 ~~ ~ry~ ~~p JAU fi~R7Cd] +J l y~ r V. 7V a V 5 2 772 MSCT X?OS PUP 3.5 3.~6 1.4 85.73 8 3 7.%2 Tfl3 °~.YDLtJ1R 4.3 0.fi '37.:19 ~~ _ a 4 3142 7'QS X EUE ~[3 SUP IiV/ COLLAR 4.5 2.892 2,71 37.73 5 ~ 3:5 9.1±25 1.87 48,dd __, l , ~ a _.. ~ _._ $. ? I72'OOIL:EA ]'IJBI~iG X40 3:5 ~.3 9.Ix9~1 3.A^~5 .2:955 tf.BB 47 ,51 2D9~&.51 _ 9 f $: F1.CANPl3N13 4.S 9 8 288738 9 L3S1+ 9.8 2..812 i.38 '3803:39 `: ~4 F2~(7VUOOUPL~+1G 4.5 ~ 9 fi 340+{:77 _ ~ •f 1 C~L~ d,8 3.125 .0.85 3D7 0.:77 12 3 i/2 L:C9lLE'b'NBtF~iG 3..5 9.094 5032.5 38 ~ 1,:65 7 3 12~.~ d_8 8.725 8.88 8i18d.1'S _ l's 1 813 ~cR1 NIPPLP X4.3 2.75 .21 8805x03 l 15 3172 AB I~X ~ 2 7~ Bt)E PI~1 4..3 2.dd7 0.58 8848;24 i__ i + 7d t i _~., .~~_ ___ _ , ~ " 18: 7 1 'L~DGATOF3~AL.11- SFA,I.AC~fi'IliBE 17NIT (~ 3..8 .2:88 3 2x375 :2.378 2.375 1.'11 5.88 1 98i~7,35 8808.d8 8874.84 18. SEAL iJ~ll~'. D 3 2..375 ~ 7 881:5.94: 4 ~ '2 a. 2 4 ~ MLfl.Ir SIit7E 3 2::375 2.34 887:6,34 91318.68 `; ` 27' SEAL®C>RE~fA;t1E .51~23{Lt1CK _4.:625 9.115 1.71 90A'9 - __..,..._. - 7 :~__. 22 _ __ __ 22 2 2A ~ 26 27 1fix' ~( 3' 3;BE CROBsO>JEf3:1~OM SBE X 2 IJ8 E1~ 15' :X 2 778 PUP JOHVT 2.313 XI+4 TIIPPL:E 311€7 2:25 3d0-GO 2 778 PUP ~344APC3 3.75 :4.43 2.875 3.85 2..$75 3.15$ 3 2.44 2.4d 2.25 249 2,44 9.73 0 14:75 :4.x8 4.22 U:64 941.8..77 9428:.+44 9828.44 8835.: 9836.:OII 9048,3 9840:94 ~ 1 1 .~ ~ S i 2 t2 •Y ' 2A ` '2'5 ....~ ..... ,~8 } ..~ ..__ ~.~. .. r27 3 ~. 3 ...3.. ..,.., t . _ ' ~ ~ i ..._ } ~ __... ~ «.. Y .. _. ~ __ 1'I.IBIhK3.LAJ~ED 01+151,1 X 1:C~C~~SF.Ai:HOl~E 3iEGEPTACLE __._.,~. ~D PIPE FOR SPACEOUT W NEU~k- Pll3AR WAnS 6.}_.___ _.~._..~.. ~V 1 ~~{ 1'.A~DD171~+IAL POPE 1~ ~ 1~ IHf ~ ~' ~~" ~~~~ ~EJ!14. ~OCA7 1YY OF3E711R ~;PAC1fER «y i ANNt7l.l)6 /NVD TLf9ItdG :FREEZE i~DTECTE© 7'<i 25fl0' 1Nlatilrtl llV>C 183 ' i;ORFiEG1'ED i)EP71#5 7O [3EP3'ti A 11' T4 GT Il~11G1}I ___s__ 7 - • • _ ADS ~e~~ort C~vervi~~•v ~-'' lady ~e~;ior~ Analy~~s !t eli: DS O4-45 Sure ey Date: April 3, 2008 Field: Prudhoe bay Tool Type: U~b' h'1FC 2.1 Ext No 2 ! 40.10 Compar7y: BP Exploration Alaska Inc Tool Size: t .b9 Country: USA No of Fingers: 2~. Anal•~, st: Then-o.or Tubing: tiom.OD 1•Veight Grade S Thread NomJD Nom. l,pset Upper len. Lo~.ver len. 3.5 ins ? pp L-80 3.09 ins 3.?36 ins 6.0 ins 0.0 ins Penetration and A~ietal Loss (°o wall) ~ pelretraaon body ~ metal loss body 3S0 7 {~ a~ 50 0 1? -.. I to ~ to 20 to 30 to oaer I'c IQ°~ 2',',°.n ~0"o T57°u 85°'0 Number o1• Dints anah•sed itottal =1821 pone- 0 103 5S Z1 Z 2 loss 103 77 0 t 1 0 Damage t~onfig~ration (bod; 1 l!) ,, - . ,. ~~ D isolsted general lirw r.•? hole, Doss c:•t~ng corra:iaa car•o-:ix~ ccso:ior i•s'ehole number of -Dints damaged total = +1~; 35 Z C' ? 2 Damage Profile (.°-o wall) ~ penetration body ~ metal loss body o so Io0 0 SO 100 I~0 Bottom of Sur.ey = O.t~ C PLUS ~~Pt~RT {tv)INT T~f~. PIS:eC . 5.') E R ? SJ S?~ I_YSL? 141 ~.; . Each, t1'all: t~.~(i3 ir, Fle#a: 1.Irsetlb'a!I: t1.33t in Curnl?arn f~,u,zrn~:l i.D._ 3.U'3+ in {:uurztl3 Suf•~es t~at~ • lL~T(C~~ S~{~ET C7S 13•~-~3 Prt•ui~z,~ 8.as 81' ~x~I~r~ftit~n ~I~~ka SIU: l.M: ~, :i~zri '3, t`17i#i I{?i^t f,q Jt. C3el~ttz ;~t.! :: v ~ >.:, F'en. ^cn:h .I^5_i Pen. °~ ;~te:a' Lo_° Qo :'tin I.O. ~Ir;.; t1a~,a s.,e 1-~ixct I +C»rnm.stzi'; t`sl•s5~%, ~.~ 377 IiR.~ G Lt~ _ 71.11:+ 2~ ~ 7 t~.:i ,iJI3L;°~,^. .ItLIl1-r 3 1 1 ~ 17.t}t5 a ' ."3i<.e ;sz)I zt~~: ~ittirrr 4 11?.T _ 7'.'1' ~ ? ~7 'a+CS '"C711tis^ )Ittl`T.r Z1'3 f.ut~ 31 ~'~,~< ,?later ?ittirr= Zfa'} 7 ?~ 0 I ~.'.?~~; ~,a b'st; :)ittirrr. 31 ~ fs?~ 19 I 2.'.}~< ;•,a'ba:° :i,tirrr .il ?h7: _ r; X12 12 I ),3t, `? 1"16 f ?:d 16 1 Z'~i7 i!zall,a:s ? ICLIr,<r 177 ~f:~6 I?.tl~ 1 1 '?'~~' 1 1 a I F, 73.173 t I ?'?,°~ 1L 5r;6 - 11~ 2t 1 Z9==~ !:t?latr~ ittifnr. 1 : ii1 _ 731?1 19 t Z'~c .-a b<;: ;?iairrr. 1+ br:.' - l;' ~?~ T 7 1 Z'3`~ 'a bx.: :~iairrr 1 ~ ' 1.' ~` 7 .?~ I _' '~F. : Iate )itti•r.= 113 'Y,' v f7'~' t 7 I ~.'~!~ 1.~ 151;5 ~? l ):9 7 ~'~'~ ~:IaLe :: ?ILLI`1:=. 1,<<.~ t:.r1~5 `,'. f~;~F;, 3~ t '.'.~'a ?Ilte•~ titti:,•= t'.? u 1;5 ;:` f . ~' 36 ~ .'_ `.?`~ .:+ I zt . itti:r?. II .. t1 1~~9 ~' 7?,1,3 a Z'.~'~ z~lats~ >ittr,:r ~` 1~;`~ t.''1;~ ,6 >,a;> )lat3^ titu~rr d e p '3 It1~ ;;= 171;5 90 q '.'~`~ '(:71.E' ~~+ t t ~1~ _ 7J .':J-7 I ~ ~~tc 71 ti?? ~ ?ItLI`,:? ~ ~'i3 l~ " " 1CC~ ' ~ ~C1LE' „> - ~-, , z ~~r, ~ ° t I ~~ ~::.,' t , I , ,,: Alternate ' _ dept tY 7s J I G ii ~~I T 1 1 I t sa I ::' ~ 1..,11 7 1 t '.~r_~ 2 ?: _ 7 i ~'i l I~ 1 ) f~C~ _ ! 1.~. 1 a,~r J 1; .~ t 11) , t s~<r cker th setting h P:~ :di,: °' &~ a'~s~ 'a;`r:• 1 • WSR --- Brush and Flush 10/18/2004 WELL SERVICE REPORT WELL JOB SCOPE UNIT 04-45 PRESSURE TEST (MAINT) SWCP #s DATE DAILY WORK DAY SUPV 10/18/2004 BRUSH /BROACH SCHULTZ COST CODE PLUS KEY PERSON NIGHT SUPV PBD04WL45-M SWCP-BLOUNT HARRIS MIN ID DEPTH TTL SIZE 2.25 " 9035 FT 2.5 " DAILY SUMMARY ~_ ~_ _~_~~~__~~~~ CONT FROM 10-17-04 LRS PUMP SBG. RUN 3.5" BRUSH W/ 2.5" G-RING, CANT WORK PAST 150' SLM RUN 3,5" BRUSH W/ 2.25" G-RING TO 8987' SLM SET 2.81 PXN PLUG @ 8987' (PLUG HAS 4 X 114" EQUAL PORTS, 1 O" X 2.15 P- BODY) SET 96" PRONG (1 3/8" FISH NECK, 1.750 BODY, 1.50" ON PACKING STACK) @ 8985'SLM. PREFORM CMIT-PASSED GIVE WELL BACK,SI LOG ENTRIES Init Tb , IA, OA -> 950 500 250 TIME COMMENT ___~A__~~~__~~w__ 00:01 CONT FROM 10-17-04 WAITING FOR LRS .~._.....~...._~_M,m.~...Y~.-M~ 00:35 TGSM W/ LRS ~ ~~~~ 01:00 LRS TIES INTO WELLHEAD, LRS PT LINE ~ ~~_ ~~~ ~ 01:10 LRS STARTS PUMPING, METH &SBG _ ....a_wm _~ ~, 01:43 FINSH PUMPING SBG, LRS RIG OFF TREE CAP ~~_~~~__~ 02:25 STAB ON, PT LUB 300 LOW, 2500 HIGH W/METH _ _ti 03:25 RIH W/ 1 7/8" TOOL STRING W/ 3.5" BUSH & 2.5" G RING _ ~~ ~ ~ 04:00 SD 150' SLM, POOH ~ ~~~_~ ~~ 04:12 OOH W/BRUSH & G.RING PACKET OFF W/ SHMOO ~~~~~~~ 04:30 CUT BRUSH DOWN A LITTLE & LET SBG SIT ANOTHER 1/2 HOUR ~ 05:03 CONFER W/ BP RUN 2.25 G-RING BELOW BRUSH _ ~ ~~~ 05:12 RIH W/ 13'x1 7/8" STEM, OJS, LSS, 3.5" BRUSH W/ 2.25 G-RING ~ 07:22 CONT IN HOLE W/ BRUSH TO 8985' SLM XN NIPPLE 08:54 OOH, LRS BEGINS PUMPING WATER ~~ ~_~ 10:15 FINISH PUMPING WATER 150 BBLS, SWITCH TO PUMP METH 10:20 LRS BEGINS PUMPING METH ~~,_rv ~ _~ d.,~ 10:40 FINISH PUMPING METH 11:00 RIH W/ 2.81 PXN PLUG (4 X 1/4" EQUAL PORTS, 1 O" X 2.15 BODY, 27" XLOCK OPENED, 24" XLOCK CLOSED _~~q~~„ 12:10 LOCATE AND SET PXN 8987 SLM, POOH _~ ~_ ~_ 13:20 OOH SIBD PLUG SET ~ ~~~~ ~~ 13:50 FIX CHECK SET mm..~ ~~~~ ~~~~ 14:00 ~ RIH W/ CHECK SET ~ ~ ~~ 14:56 SD 8987 JAR DOWN SEVERAL TIMES TO SHEER CHECK SET _ ~~ ~~ 15:45 OOH SIBD PIN SHEER ON CHECK SET PLUG SET IN PLACE ~~ ~~ ~~ 15:47 SAFETY COACH SHOWS UP FOR INSPECTION 16:18_... RIH W/ 2" JDC W/ 96" PRONG 1 3/8" FISH NECK, 1.750 BODY,_1mm50" ON PACKING STACK ~_..w_......_..m.. 17:12 ~ JAR DOWN SEERAL TIMES SET PRONG 8985' SLM 17:36 OOH SIBD PRONG SET, MAKE CALLS TO BP CO-REP ~~~~~~~~~ ~~~ 18:25 ~ ~ SWING LUB OUT OF WAY ,rrv__.__.~~.,.._,,,~_,_._~.~,_.~..~._._~.__...~_. ~...,..,~..______.~.._.~~.,~~ .~,. 19:05 LRS SHOW UP, TGSM .._~__v.,._._.__~~...~_u_.~.~_~__~..__.~..,~..._.~.,..,_~.~...~.._.._._._~~ 19:16 LRS RIG UP TO WELLHEAD FOR CMIT _...._....... ..~_~.._.~~ ~.__.~~~.~_m~.~. ~,_~_..~.~a__ ~,~,___w~_.__.,~ __ ~~„~ 19:25 LRS PT LINE - ~~~~ ~ 20:19 ~ CMIT PASSED, SEE LRS REPORT ~~ ~~~ ~~ ~~~ 20:20 _ CONFER W/ REP,RD ~~~ __...~._...__.m__.r~~,..._.__r~.,.~...~.~..~...,...._._..~.~.._...~r.~.~_~~...__ 20:23 RD _._......_~..._._,__.___.w.~..~._~. ~ __.r,.._w,_,_....~... ~.,._..~ ~~.._..__.~- ~ ~..~ m.~......_,~ .__... 21:20 FINSH RD, HANG PLUG TAG __ ~~rv._ _„~~_~~__~,~ ,_, ~_ ~ 22:00 _ ~~~~~~ ~._~ GIVE WELL BACK ,ORDER TOOLS FOR NEXT JOB 23:59 TRAVEL TO PSI -10 ~ Final Tbg, IA, OA -> 340 500 240 ~ WSR --- LDL Loa 06/11/2000 • WELL SERVICE REPORT WELL JOB SCOPE UNIT 04-45 LEAK DETECTION LOG SWS - 2145 DATE DAILY WORK DAY SUPV 6/11/2000 LEAK DETECTION LOG LORENTZ COST CODE PLUS KEY PERSON NIGHT SUPV 361325 SWS-STEPHENSON UNKNOWN MIN ID DEPTH TTL SIZE 2.25 " 9035 FT 2.875 " DAILY SUMMARY ~., ~,~,_,w.,,,_~__,..._..~,_~,. MULITPLE LEAKS FOUND FROM 1135' TO 1185', TTP TAGGED AT 9006' LOG ENTRIES )nit Tb , IA, OA -> 0 0 100 TIME COMMENT _ ___ _~ _,tl 07:00 DEPART SWS SHOP FOR DS 4-45 07:45 ARRIVE ON LOCATION -HOLD SAFETY MEETING 08:00 START RIG UP ~~~~~ 08:35 PT TO 3000# 08:45 RIH WITH WGT BAR - CCL - GR -TEMP - PRES -TENS/COMP - GRADIO - CFS -CALIPER - FBS FROM SURFACE TO TTP AT END OF 3.5" TUBING LOGGING BASELINE TEMP PASS ~~~~~~ ~~ 09:50 TAG TTP 9006' -LOG TIE IN STRIP 10:00 HOLD SAFETY MEETING ~~ 10:10 START PUMPING IN IA 10:30 MIT IA & TUBING AT 3000#, NO FLOW IN TUBING - TTP IS HOLDING, NO TEMPERATURE CHANGE - SBR IS HOLDING _,_, __ ,,_......~. 10:45 WHP 2940# AFTER 15 MIN ~ ~~ 11:00 WHP 2900# -PASSED MIT - NO CASING LEAK ..,_,_,~~_ ~ 11:05 OPEN WING TO NEIGHBOURING WELL __ 11:20 START PUMPING @ 1 BPM, ADJUST CHOKE SO BACK PRESSURE ON WHP IS APPROX 1000 PSI & 1300 PSI ON IA __ ~r, a 11:45 25 BBL AWAY 1 BPM ~ ~~~~-~ ~„~,._..~,~....,.,,~_.~_,,..~,.~. 12:10 50 BBL AWAY 1 BPM ~~~~ ~ ~ ~~ ~~~ 12:30 LEAK FOUND AT ~~~ ~~ 12:35 LOG UP & DOWN 80 FPM PASSES ~ ,...~.~ 12:55 ~ LOG STOP COUNTS THORUGHOUT THE LEAKING ZONE ~~~ ~. 13:00 100 BBL AWAY 1 BPM ~~ 13:10 LOG UP FROM 1300' 13:20 LOG INTO BUMP UP AT 30 FPM TO CHECK FOR TUBING HANGER LEAK ~~ 13:45 NO LEAK OBSERVED IN TREE-STOP PUMPPING-START RIG DOWN ~ _~..V~~ ~_ 14:30 COMPLETE RIG DOWN -LEAVE LOCATION 15:00 RETURN TO SWS SHOP Final Tb , iA, OA -> 1300 1000 100 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST ~~~ CUMUL TOTAL ~~ ARCO ~~_ $909 ~ $909 ~ LITTLE RED ~ ~ ~ ~ $1,540 ~~ $1,540 ~~~ PEAK ~~~ ~~ ~ _ $2,500 _ $3,000 ~~ SCHLUMBERGER ~~~ ~ ~~ ~ $6,908 _ $6,908 UNKNOWN ~~~~~ ~~ $1,875 $2,323 ~ VECO ~~~ ~ ~ ~,._._.,_,. $500 _.__,_..~,,, $1,500 ...,,,_~~_ COBURN MACHINE ,,,_.-",,-~"~_,_._.~,_,.~,.___._~.__~ .._.,,, $0 ~ ~ $125 ~ HALLIBURTON , .~ $0 _,.,_,_,~„ $6,002 ,__.,~~___,.~., CAMCO ..-„_.,_.._~..~.,.w..-_____.____-__ _~_„__,..~_,_,. ~,M , $0 $795 TOTAL FIELD ESTIMATE: $14,232 $23,102 FLUID SUMMARY ~.~.~.,.~~~,~_. ,~___. ._ ~__.~ 250 BBL OF INHIBITED 50/50 METHANOL~~ • ~, ~ ~_a ~, - ,-4- ~ 7 =.._ ~ ~ ~ i p° - ' ~ SARAH PALIN, GOVERNOR i~ ~T ~S~ Q~ ~]~`~~~T ~~ 333 W. 7th AVENUE, SUITE 100 C01`S~RQA-~01` C~~rIIS'~T`I~" ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 CANCELLATION SUNDRY APPROVAL N0.303-285 Ms. Anna T. Dube ~~~~ ~~~ ~1 ~' ~~'~ Attention: Well Integrity Coordinator, PRB-20 BP Exploration (Alaska) Inc. P.O. Box 196612 Q 3 Anchorage, AK 99519-6612 ~- RE: Cancellation of Sundry Approval 303-285 (Well PBU 04-45) Dear Ms. Dube: Pursuant to BP Exploration (Alaska), Inc. ("BPXA")'s request dated January 18, 2008 Alaska Oil and Gas Conservation Commission ("Commission") hereby cancels Sundry Approval 303-285, which allows continued water injection. This well exhibited tubing by inner annulus communication, and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to conditions set out in the sundry approval. Since then, BPXA has shut in and does not plan to operate PBU 04-45 until repairs have been completed. Consequently, Sundry Approval 303-285 no longer applies to operation of this well. Instead, injection in well PBU 04-45 will be governed by provisions of the underlying Area Injection Order No. 4E. The copy of Form 10-404, Report of Sundry Operations, provided with BPXA's request noting the cancellation of Sundry 303-285 has been placed in the Commission's files. DONE at Anchorage, Alaska and dated February 1, 2008. The Alaska Oil and Gas Conservation Commission ~/ Cathy P. F erster Commis oner Commissioner .. • • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 18, 2008 Mr. John Norman, Chairman Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit well 04-45 (PTD #1940340) Application for Cancellation of Sundry #303-285 Dear Mr. Norman: by This request is to cancel Sundry #303-285 for Prudhoe Bay Unit well 04-45 (PTD #1940340). The Sundry, originally issued September 29, 2003 was for continued water injection with tubing by inner annulus communication. The well no longer adheres to BP's Well Integrity System Policy and will remain shut-in until the well has been repaired. An AOGCC witnessed MITIA for UIC compliance will be conducted once integrity has been restored and the well is on injection. The application for Sundry cancellation form 10-404 is attached. If you require any additional information, please contact Andrea Hughes or myself at (907) 659-5102. Sincerely, /r- Anna T. Dube, P.E. Well Integrity Coordinator ~~ .a P~~ ~' 4 ~, ~~,~~,st~ ~las~~ 0°~ ~ ~~~~~~~g~ • Attachments: • Application for Sundry Cancellation form 10-404 STATE OF ALASKA ~ ~~0~ ALASKA OIL AND GAS CONSERVATION COMNITSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ CANCEL SUNDRY Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ 303-285 - Change Approved Program [] Operat. Shutdown[] Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 1 194-0340 3. Address: P.O. Box 196612 Stratigraphic ~ Service I~~I 6. API Number: Anchorage, AK 99519-6612 50-029-22454-00-00 7. KB Elevation (ft): 9. Well Name and Number: 64.8 KB - PBU 04-45 8. Property Designation: 10. Field/Pool(s): ADLO-028328 Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11875 ' feet Plugs (measured) None true vertical 9179.65 ~ feet Junk (measured) None Effective Depth measured 11721 feet true vertical 9049.62 feet Gasing Length Size MD TVD Burst Collapse Conductor 112" 20" Surface - 112' Surface - 112' Surface 3864' 9-5/8" 47# NT-80 Surface - 3928' Surface - 3755' 6870 760 Production 11762' 5-1 /2" 17# L-80 Surface - 11856' Surface - 9164' 7740 ~ 6280 ~$ c~ ~ ~~ - ~S~pf1 me 0~ ~P ~~~~~ Perforation depth: Measured depth: 11670 - 11710 _ _ _ , ~~ ~ c~~ ~C ~~O P~~j True Vertical depth: 9006.56 - 9040.34 = _ _ ' '~~~~K~ + Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 9006 - 9009 2-7/8" 6.5# L-80 9020 - 9041 Packers and SSSV (type and measured depth) 5-1/2" SealBore Receptacle W/X Lock 9009 0 0 0 0 0 0 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: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~ Service Daily Report of Well Operations T 16. Well Status after proposed work: ,n~,{-~, u,fp~ ~ ~B?- Oil Gas WAG ~ GINJ i~-' WINJ ~~'~ WDSPL 17. I hereby certify that the foregoing is true nd correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 6, ~ ~ ` <~~~~ 303-285 Contact Anna Dube Prepared by Gary Preble 564-4944 Printed Name Anna e Title Well Integrity Coordinator Si atur ,~,~~ Phone 907-659-5102 Date 1/7/2008 Form 10-404 Revised 04/2006 \~~ ~I?~t~y ~ l~ ~~ Submit Original Onty 04-45 (PTD #1940340) Internal ~ver Cancellation -Not Operable Well Page 1 of 1 Re James B DOA • 99, ( ) From: Lau, John, Jack [IaujjO@BP.com] on behalf of NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~j ~ ~, ~~ ~?~ `~`' Sent: Monday, December 31, 2007 7:03 AM h To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, FS2 DS Ops Lead; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2/COTU OTL; GPB, Wells Opt Eng; GPB, EOC Specialists; Engel, Harry R; Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Chivvis, Robert; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Lau, John, Jack; Holt, Ryan P (ASRC); Dahlem, Jason E; Boyles, Gerald J; Culpepper, Jerry K. (Orbis) Subject: 04-45 (PTD #1.940340} Internal Waiver Cancellation -Not Operable Well All, An internal waiver was issued for TxIA communication on water injector 04-45 (PTD #1940340) on 01/03/06. The dispensation from the Well Integrity System Policy for this well has expired. Please ensure the well has been shut-in by the end of today and arrangements have been made to freeze protect the well. The well has been reclassified as Not Operable. A secure program will be sent shortly. Please remove all Waivered well signs and the laminated copy of the waiver from the wellhouse. The paperwork to cancel the corresponding AOGGG Sundry #303-285 will be signed and mailed this week. Please call if you have any questions. Thank you, Jack Lau (for Anna Dube) Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~a1,: `,,,'`@~fl~~'JAN ~ ~ 200 1 /17/2008 04-45 (PTD #1940340) MIT For Regg, James B (DOA) • Page 1 of I From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Thursday, November 08, 2007 12:30 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA ~ L ~~~~~~~ Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: 04-45 (PTD #1940340) MIT Form Attachments: MIT PBU 04-45 11-07-07.x1s Jim, Tom and Bob, Please see that attached MIT form for the MITOA performed on 04-45 (PTD #1940340) for variance compliance. «M1T PBU 04-45 11-07-07.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Y I 1 /8!2007 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. ~~~ FIELD /UNIT /PAD: Prudhoe Bay /PBU / DS 04 ~ ~ DATE: 11!07/07 OPERATOR REP: Andrea Hughes AOGCC REP: Packer Dep Pretest Initial 15 Min. 30 Min. Well 04-45 Type lnj. W ND 7014 Tubing 1760 1760 1760 1760 Interval O P.T.D. 1940340 Type test P Test psi X400 Casing 1720 1720 1720 1720 P/F P Notes: MIT-OA for variance compliance. OA 600 ,12'400 2295 2260 Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interva{ P.T.D. Ty e test Test psi Casing P!F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing PIF Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test i'' INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT PBU 04-45 11-07-07.x1s MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 0f ~/'Z'(ð 7 P.J. Supervisor 1\ ~1 ?f DATE: Wednesday, January 31, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04-45 PRUDHOE BA Y UNIT 04-45 FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 04-45 Insp Num: mitLG070I31062248 Rei Insp Num API Well Number 50-029-22454-00-00 Permit Number: 194-034-0 Inspector Name: Lou Grimaldi Inspection Date: 1/30/2007 Well 04-45 P. T. 1940340 Interval REQVAR __·.,·..···_···.·_,____.·____·,,_···,·,,_,,·_·.,,_~u___.,,' . Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. P IA OA Tubing 2400 5 10 PÆ 2380 Notes Combo MIT for variance compliance. ~ S4,~ 3D 3 - ~'b5 I Zl(e... ~T~~ scANNED fEB () '7 20D7 Wednesday, January 31, 2007 Page 1 of 1 ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '~ '/4/00 P.I. Supervisor 11 r DA TE: Wednesday, January 04, 2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04-45 PRUDHOE BAY UNIT 04-45 \qL.\- - o3Y FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,"'CS-2- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 04-45 Insp Num: mitJJ060 I 04082824 Rei Insp Num API Well Number 50-029-22454-00-00 Permit Number: 194-034-0 Inspector Name: Jeff Jones Inspection Date: 1/2/2006 Well--¡ 04-45 Type Inj. N P.T. 11940340 TypeTest SPT Interval REQVAR P/F Notes 2.5 BBLS methanol pumped. TTP set @ 9005' MD for the test (packer@ 9010' MD). 1 well house inspected; no exceptions noted. C ¡.,tÝ1 T )<J;A Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. TVD 7015 IA 0 2400 2310 2300 ---1---- + ...--..--- Test psi 1753.75 OA 0 0 I I P Tubing 0 2550 2450 2450 ,,:~ (11 ~;'(ì utì M~.U.·..E. ..fì\.' . II ~\ N\ ..~ (M r". .' 5CA~~"!'lCf) .Ih Wednesday, January 04, 2006 Page 1 of 1 TREE = FMC NEW STAND WELLHEAD = CrN ACTUA TOR = BAKER C KB. ELEV = 64' BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD = 04-45 SAFETY NOTES: ***RAPID TxlA COMM. OPERATING LIMITS: MAX lAP = 2500 PSI, MIN OAP = 1000 PSI (04/21/03) *** . . .(AI l.' 034- ?\V\"\ 3003' -13-1/2" CAM OS SSSV NIP, 10 = 2.812" I -1 ESTIMA TED TOP OF CEMENT I \~0\D~ 1967' 49 @ 6263' 11502' 8800' SS 19-5/8" CSG, 47#, NT-80, 10 = 8.681" I 7999' -15-1/2" OTIS XN NIP (BEHIND CT), 10 = 4.562" I Minimum ID = 2.25" @ 9035' 2-7/8" OTIS XN NIPPLE 3-1/2" TBG-COILED, 7#, QT-800, 9006' .00930 bpf, 10 = 3.094" TOPOF 2-7/8" TBG I 3-1/2" OTIS XN NIP, 10 = 2.75" 3-1/2" PXN TTP (12/11/05) H3-1/2" X 2-7/8" XO I -12-7/8" LOC SEAL UNIT I -15-1/2" SEALBORE RECEPTACLE W/X LOCK I -15-1/2" OTIS XN NIP (BEHIND CT), 10 = 4.455" I PERFORA TION SUMMARY REF LOG: MWD ON 03/19/94 ANGLE AT TOP PERF: 32 @ 11670' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 6 11670-11710 0 06/25/94 9020' -13" X 2- 7/8" XO I 9035' 2-7/8" OTIS XN NIP PRIOR TO SETTING PLUG SEE WELL FILE, 10 = 2.25" 12-7/8" TBG, 6.5#, L-80, .00579 bpf, 10 = 2.441" I 9041' 9040' -12-7/8" MULESHOE WLEG I 9046' H ELMO TT LOGGED 07/05/94 I IPBTD H 11774' ~ (' c, L Ce 15-1/2" CSG, 17#, L-80, 10 = 4.892" I 11875' 11856' [!£J DATE 03/20/94 06/29/94 12/27/01 04/28/03 11/07/04 07/21/05 REV BY COMMENTS ORIGINAL COM PLErION LAST WORKOV ER RN/TP CORRECTIONS A TD/TLH WAIVER SAFETY NOTE JAF/TLP PULL PXN PLUG & PRONG MCJ/PJC OA DOWN SQUEEZE DA TE REV BY COMMENTS 12/13/05 DAV/TLH TTPSET PRUDHOE BAY UNIT WELL: "'04-45 PERMIT No: '1940340 API No: 50-029-22454-00 SEC 34, T11 N, R15E, 4079.54' FEL & 978.72' FNL BP Exploration (Alaska) ~G""? ',A\ ~ rL '·Ii 'jj11f iE J r \, l~ ¡~ 7!® '/""1"/ ,~ !.hJ " . ALASKA OIL AND GAS / CONSERVATION COMMISSION / í~l\ ir WJlr ) /71/- tJ:J i ) FRANK H. MURKOWSKI, GOVERNOR 333 W. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 J ennifer Julian Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 SCANNED JUL 1 2 2005 Re: Prudhoe Bay 04-45 Sundry Number: 305-1 75 Dear Ms. Julian: 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 0 holiday or weekend. A person may not appeal a Commission decis' n 0 Superior Court unless rehearing has been requested. DATED this /1 day of July, 2005 Enc!. ') ) July 05, 2005 RECEIVED JUL 07 2005 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Alaska Oil & GIS Cons. Commission Anchorage Dear Winton: RE: Sundry Notice for 04-45 OA Downsqueeze BP Exploration Alaska, Inc. proposes to do the following wellwork to obtain an injection waiver for well 04-45. Step Type Procedure 1 0 OA FL depress 2 F OA cement down squeeze /' 3 F MIT OA after WOC Well 04-45 is an injector which requires a waiver for TxlA communication. In . order to waiver the well for injection, an OA down squeeze must be performed. /' CITOA on 05/13/2005 failed with LLR of 2.5 bpm at 1600 psi. This program is designed to pump a column of cement from the shoe to approximately 500 feet above the shoe for waiver compliance. Please contact Jennifer Julian at 564-5663 (H) 274-0929, (Cell) 240-8037 with any questions. Sincerely, ð~Î ~~ Jennifer Julian Wells Engineer OR\Gt' ,. " I-:\. ii Ii ~ '-- WG 1\-. 1 (l/-¿O tJ <;; ) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION RECEIVED APPLICATION FOR SUNDRY APPROVAL: . 0,··' 200.5 20 AAC 25.280 JUL 7 PerforateD Alaska Oil ~~~r~S. CO~~SJ~ StimulateD Time Ext~~~ht!fge Re-enter Suspended Well D StratigraphicD Service Œ] 9. Well Name and Number: 04-45 /" 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 9179.7 11721 8984.8 Size MD TVD 1. Type of Request: D D Abandon Suspend Alter Casing D Repair Well l&:I Change Approved Program D Pull Tubing D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 64.80 KB 8. Property Designation: ADL-028328 11. Present Total Depth MD (ft): 11875 Casing Length Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: 5. Permit to Drill Number: 194-0340 .,/' Development D Exploratory D / 6. API Number r~ 50-029-22454-00-00 Plugs (md): None Burst Junk (md): None Collapse CONDUCTOR SURFACE PRODUCTION top bottom top bottom 80 20" 91.1# NT-80 32 112 32.0 112.0 3897 9-5/8" 47# NT-80 31 3928 31.0 3554.7 11826 5-1/2" 17# L-80 30 11856 30.0 9163.6 460 4760 6280 Perforation Depth MD (ft): 11670 - 11710 Perforation Depth TVD (ft): 9007 - 9040.3 Packers and SSSV Type: 5-1/2" SealBore Receptacle W/X Lock 3-1/2" Cameo SSV Nipple 12. Attachments: Description Summary of Proposal [!) Detailed Operations Proç¡ram D BOP Sketch D 14. Estimated Date for Commencing Operation: July 20, 2005 2960 6870 7740 Tubing Size: Tubing Grade: Tubing MD (ft): 3-1/2" 7.0 # OT-800 28 9006 2-7/8" 6.5 # L-80 9006 9009 3" 9009 9020 2-7/8" 6.5 # L-80 9020 9041 Packers and SSSV MD (ft): 9009 3003 13. Well Class after proposed work: Exploratory D DevelopmentD 15. Well Status after proposed work: Oil D GasD PluggedD WAG D GINJD /" ServiceŒ] Date: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Abandoned D / WINJŒ] WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Jennifer Julian Printed Name Signature Jennifer Julian Title Phone Wells Engineer 564-5663 7/6/05 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness BOP TestD \ <,.- 4-04-- Sundry Number: 3oS: /~ Mechanciallntegrity Test ~ Location Clearance D RBDMS BFl .JUt J j 7005 ¥riot' BY ORDER OF THE COMMISSION Date: OR\G\Nf\L SUBMIT IN DUPLICATE TREE = FMC NEW STAND WELLHEAD = CrN ÄcrüÄrÒR; . 'SÄkËRC KB. ELEV :::;. 64' , 'è¡£'.'ÊLBi"; , KOP= Max Angle = .."...,.......",....,..',..",."..""",,,,,. Datum MD = ",,,..,,.,,,<0.,,,...,..,..,,'..,....,.......,,..,,,...,,... Datum TV D = ') 1967' ,~~~?~?~' 11502' """,,,,,,,,,,,,,,,,,,.,,,,,,,,,. 8800' SS I 9-5/8" CSG, 47#, NT-80, ID = 8.681" 1-1 3928' Minimum ID = 2.25" @ 9035' 2..7/8" OTIS XN NIPPLE 3-1/2" TBG-COILED, 7#, QT-800, -I 9006' .00930 bpf, ID = 3.094" TOPOF 2-7/8" TBG 1-1 9006' ÆRFORA TION SUMMARY REF LOG: MWD ON 03/19/94 ANGLE AT TOP ÆRF: 32 @ 11670' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 11670-11710 0 06/25/94 // I 2-7/8" TBG, 6.5#, L-80, .00579 bpf, ID = 2.441" 1-1 9041' IPBTD 1-1 11774' I 5-1/2" CSG, 17#, L-80, ID = 4,892" 1-1 11856' I TD 1-1 11875' 04-45 / SA )r NOTES: ***RAPID TxlA COMM. OPEAATING LIMITS: MAX lAP = 2500 PSI, MIN OAP = 1000 PSI (04/21/03) *** e ~ 3003' 1-13-112" CAM DS SSSV NIP, ID = 2.812" 1 ~ . r----1 7999' 1-15-1/2" OTIS XN NIP (BEHIND CT), ID = 4.562" 1 I ~ ~ , 9005' 9006' 9007' 9009' 9010' 9020' 1-13-1/2" OTIS XN NIP, ID = 2.75" 1 1-13-1/2" X 2-7/8" XO I 1-12-7/8" LOC SEAL UNIT 1-15-1/2" SEALBORE RECEPTACLE W/X LOCK I 1-15-1/2" OTIS XN NIP (BEHIND CT), ID = 4.455" 1 1-13" X 2-7/8" XO 1 9035' 1- 2-7/8" OTIS XN NIP PRIOR TO SETTING PLUG SEE WELL FILE, ID = 2.25" 9040' 9046' DA TE REV BY COMMENTS 10/18/04 SGS/TLP SET PXN PLUG & PRONG 11/07/04 JAF/TLP PULL PXN PLUG & PRONG DATE 03/20/94 06/29/94 12/27/01 11/30/02 01/05/03 04/28/03 R8J BY COMMENTS ORIGINAL COM PLErION LAST WORKOVER RNlTP CORRECTIONS JtvVtlh PXN PLUG SET JtvVKAK PULL PXN PLUG A TD/TLH WAIVER SAFETY NOTE I I / " Jl X X I .. x \ ) I X X X ) I. X X ) ~ li2-7/8" MULESHOEWLEG I 1-1 ELMD TT LOGGED 07/05/94 1 PRUDHOE BA Y UNIT WELL: 04-45 ÆRMIT No: 1940340 API No: 50-029-22454-00 SEC 34, T11 N, R15E, 4079.54' FEL & 978.72' FNL BP Exploration (Alaska) ') ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ~~S~~~isOr 'K11 ;1(/** DATE: Monday, November 08, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04-45 PRUDHOE BAY UNIT 04-45 ¡.qbf:<Ð0Lf- FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv \T~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 04-45 Insp Num: mitJCr0411 04122117 Rei Insp Num: API Well Number: 50-029-22454-00-00 Permit Number: 194-034-0 Inspector Name: John Crisp Inspection Date: 11/2/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04-45 Type Inj. P TVD 7015 IA 410 2990 2940 2930 P.T. 1940340 TypeTest SPT Test psi 1753.75 OA 250 250 280 270 Interval REQV AR PIF P Tubing 320 2980 2940 2920 Notes: Tbg x IA communication. TTP set for MIT. C- M.:vr j)(::&.A- (fK~1 U/(~~ SCANN- , Er"\', ttlO' . g "r l ') .... ,L' t'! t \, (. ':1: ¿ 0 Monday, November 08, 2004 Page 1 of 1 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 bp September 12, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Subject: 04-45 (PTD 1940340) Application for Sundry Approval Dear Mr. Aubert: Attached is Report of Sundry Operations form 10-404 and Application for Sundry Approval form 10-403 for Well 04-45. This request is to cancel the current sundry and receive approval for a new sundry to continue produced water injection with known Tubing by IA communication. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or myself at (907) 659-5102. Sincerely, Joe Anders, P.E. Well Integrity Coordinator Attachments RE CE \/ED Alaska 0it & Gas Cons. C0mmissim~ ,Anchorage OCT 1 ~: 2DD3 ORIGINAL ALAS OIL AND GAS CONSERVATION C ,,,MISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon r-1 suspend E] Operation Shutdown E~ Perforate[~ Variance~l Annuar Disposalr-~ Alter Casinq E~] Repair Well r-] Plu.q Perforations r-~ stimulateD-1 Time Extension[--~ Otherr-'] Change Approved Program r-1 Pull Tubing BI Perforate New Pool [~ Re-enter Suspended WellE] H20 INJ VARIANCE 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development E] Expl°rat°ryE] 194-034 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-66'12 StratigraphicE] Service II 50-029-22454-00-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 71.00 04-45 /" 8. Property Designation: 10. Field/Pool(s): ADL 028328 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft):l 1875 IT°ta' Depth TVD IErrect've Depth MD (ft): IErrective Depth TVD Ct): IP'ugs (measured): I Junk (measured):9180 11721 9050 None None Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 112 20" 64' - 176' 64' - 176' 40K 520 Surface 3864 9-5~8" 64' - 3928' 64' - 3555' 80K 4760 Production 11792 5-1/2" 64' - 11856' 64' - 9164' 80K 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11670'-11710' 9004'-9038' 3-1/2" 7# TBG-Coiled, 2-7/8" 6.5#. CT-800, L-80 9040 Packers and SSSV Type: Packers and SSSV MD (ft): 5-1/2" Sealbore Receptacle wiX Lock; 3-1/2" Camco DS SSSVLN SEALBORE ASSY @ 9009', SSSVLN @ 3003' 12. Attachments: Description Summary of ProposalI 13. Well Class after proposed work: Detailed Operations Program r"l BOP Sketch r-] Exploratoryl-1 Developmentr'-] ServiceI 14. Estimated Date for Commencin~ Operation: cr ! I'l°~ 15' Weollil~'~tus after pr°p°sed w°rk: Gasr'-~ PluggedE~ Abandonedr-] 16. Verbal Approval: Date: WAGE] elNJE] WINJ~ WDSPLr-] Commission Representative: Prepared by DeWayne R, Schnorr 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders Printed NameflJ°e Anders Title GPB Well Inte~lrity Engineer Signature ¢~/(/~-( ~ Phone 907~ 659-5102 Date 09/11/2003 / Commission Use Only I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness :~ ¢,3 .- ,2, Plug Integrity D BOP Testl'-I Mechancial Integrity TestD Location ClearanceD lf~ ~,-,.~ ......... ,, , Alaska Oil & Gas Cons, Commissi~ Subsequent Form Required: · ,,.,,.~..-~,----- w '~' BY ORDER OF Approved by: COMMISIONER THE COMMISSION Date: Form 10-403 Revised 2/2003 SUBMIT IN DUPLICATE 04-45 Description Summary of Proposal 09/12/03 Problem Injector with Rapid Tubing by IA communication. Current Sundry requirements are not aligned with Sundry Matrix. Well History and Status Well 04-45 (PTD 1940340) is an injector with Tubing by IA communication. CMIT-TxlA's pass, demonstrating competent production casing. Current Sundry requirements are not aligned with the Sundry Matrix dated 5/13/03. This proposal updates the Conditions of Approval to the current requirements. Pertinent well events: > 07/05/00: AOGCC approved Sundry #300-173 for continued water injection > 11/26/02: CTU jet SBG to clear tubing for TTP > 11/30/03: SL set TTP > 12/02/02: CMIT-TxlA Passed to 3000 psi w/AOGCC witness > 01/06/03: SL pulled TTP This request is to cancel the existing Tubing by IA Sundry and issue a new Sundry for Tubing by IA communication using current Conditions of Approval. The following supports the request: · A CMIT-TxlA passed on 12/02/02 to 3000 psi, demonstrating competent production casing. · Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. · A CMIT-TxlA will be conducted every 2 years to confirm production casing integrity. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Submit a monthly report of daily pressures and injection rate. 4. Perform CMIT-TxIA every 2 years., 5. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. TREE = FMC NEW STAND WELLHEAD = CIW ACTUATOR = BAKER C KB. ELEV = 64' BF. ELEV = KOP = 1967' Max Angle = 49 @ 6263 Datum MD = 11502'/ J i Datum TVD = 8800' SS J 9-5/8" CSG, 47#, NT-80, ID = 8.681" I'"~ 3928' IMinimum ID = 2.25" @ 9035' 2-7/8" OTIS XN NIPPLE 3-1/2" TBG-COILED, 7#, QT-800, Id .00930 bpf, ID = 3.094" 04-45 9006' ITOPOF 2-7/8" TBS Id 9006' 11774' 11856' PERFORATION SUMMARY REF LOG: MWD ON 03/19/94 ANGLE AT TOP PERF: 32 @ 11670' Note: Refer to Production DB for historical perf data sIzE SPF INTERVAL Opn/Sqz '"DATE 3-3/8" 6 11670- 11710 O 06/25/94 2-7/8" TBG, 6.5#, L-80, .00579 bpr, ID= 2.441" Id 9041' S,C'---TY NOTES: ***RAPID TxlA COMM. Ot ATING LIMITS: MAX lAP = 2500 PSI, MIN OAP = 1000 PSI (04/21/03) *** 3003' Id 3-1/2" CAM DS SSSV NIP, ID=2.812"I 7999' 1-15-1/2" OTIS XN NIP (BEHIND CT), ID=4.562" I 9005' ]~3-1/2" OTIS XNNIP, ID= 2.75"I 9006' I-! 3-1/2" x 2-7/8" xo I 9007' Id 2-7/8,, Loc SEAL UNIT ] 9009' I-~5-1/2" SEALBORERECEPTACLEW/X LOCK 9010' Id5-1/2" OTIS XN NIP (BEHIND CT), ID=4.455" I PLUG SEE WELL FILE, ID = 2.25" 9040' I--~2-7/8" MULESHOEWLEG I 9046' Id ELMD TT LOGGED 07/05/94 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/20/94 ORIGINAL COMPLETION 04/28/03 ATD/TLH WAIVER SAFETY NOTE 06/29/94 LAST WORKOVER 02/12/01 SIS-FINAL 12/27/01 RN/TP CORRECTIONS 11/30/02, JM/tlh PXN PLUG SET 01/05/03 JM/KAK PULL PXN PLUG PRUDHOE BAY UNIT WELL: 04-45 PERMiT No: 1940340 APl No: 50-029-22454-00 SEC 34, T11 N, R15E, 4079.54 FEL 978.72 FNL ,, BP Exploration (Alaska) 04-45 TIO P~ot 4,000 ,~ Tbg 3,000 2,000 1,000 A OA OOA ~ OOOA 0 9/9/2002 11/9/2002 1/9/2003 3/9/2003 5/9/2003 7/9/2003 9/9/2003 ' l STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonD Suspendr'~ Operation ShutdownE] PerforateE] VarianceD Annuar UisposalE] After Casin.qD RepairWellr-] Plu.q Perforations[--'] Stimulate[--] Time Extension[~ Other[~ Change Approved ProgramD Pull TubingE] Perforate New PoolE] Re-enter Suspended WellE] CANCEL 10-403 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developement E~ ExploratoryF1 194-034 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphicr-'l Service[] 50-029-22454-00-00 7. KB Elevation (ft): 9. Well Name and Number: 71.00 04-45 8. Property Designation: 10. Field/Pool(s): ADL 028328 Prudhoe Bay Field I Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 11875 feet true vertical 9180 feet Plugs (measured) Effective Depth measured 11721 feet Junk (measured) true vertical 9050 feet Casing Length Size MD TVD Burst Collapse Conductor 112' 20" 164' 168' 40K 520 Surface 3864' 9-5/8" 3928' 3555' 80 K 4760 Production 11792' 5-1/2" 11856' 9164' 80K 6280 Perforation depth: Measured depth: Open Perfs 11670'-11710' RECEIVED True vertical depth: Open Perfs 9004'-9038' ~r...r' JL ¢,laska 0il & Gas Cons. Anchorage Tubing: ( size. grade, and measured depth) 3-1/2" 7# QT-800 TBG-COILED @ 9006'. 3-1/2"x 2-7/8" XO @ 9006'. 2-7/8" to 9007'; 3" from 9009' to 9020'; 3"x 2-7/8" XO @ 9020'; 2-7/8" to 9040'. Packers & SSSV (type & measured depth) 5-1/2" SEALBORE RECEPTACLE W/X LOCK @ 9009. 3-1/2" CAMCO DS SSSV Nipple @ 3003'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 21,000 1265 Subsequent to operation: 21,000 1265 14. Attachments: 15. Well Class after proposed work: ExploratoryE] DevelopmentE] service~ Copies of Logs and Surveys run __ 16. Well Status after proposed work: oi~l--I easE] WAGE] G~NJFI W~NJ[ WDSPLE] Daily Report of Well Operations __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.C. Exempt: Contact Joe Anders I #300-173 t~:~j~.e(~_,~e~ ~i)~rs Title GPB Well Integrity Engineer Signature /(.,,~¢ C~'7~"'~ r~n,r',,t, AP, o.e 907'659-5102 Date Sept11,2003 U ! Form 10-404 Revised 2/2003 BFL "0' ,'I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ SCMOO-BE-GONE Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 591' FNL, 448' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 644' FNL, 3842' FEL, Sec. 03, T10N, R15E, UM At effective depth 912' FNL, 4035' FEL, Sec. 03, T10N, R15E, UM At total depth 979' FNL, 4080' FEL, Sec. 03, T10N, R15E, UM 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X (asp's 712399, 5951266) (asp's 709165, 5945843) (asp's 708980, 5945570) (asp's 708936, 5945500) 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Wellnumber 04-45 9. Permitnumber/approvalnumber 194-034 10. APInumber 50-029-22454-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical 11875 feet Plugs (measured) 9180 feet Effective depth: measured 11721 feet Junk (measured) true vertical 9050 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 112' 20" 260 sx AS 112' 112' Surface 3864' 9-5/8" 1012 sx CS III, 975 sx 3928' 3555' Class 'G' Intermediate 11792' 5-1/2" 710 sx Class 'G' 11856' 9164' Liner Perforation depth: measured Open Perfs 11670' - 11710' true vertical Open Perfs 9004' - 9038' Tubing (size, grade, and measured depth) 3-1/2", 7#, QT-800 @ 9006' MD; Packers & SSSV (type & measured depth) RECEIVED ] Gas 6on,.,s. 3" from 9009' to 9020'; 3" x 2-7/8" XO ~ 9020'; 2-7/8" to 9040'. 5-1/2" Sealbore Receptacle W/X Lock ~ 9009'. 3-1/2" CAM DS SSSV ~ 3003' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 11/25/2002 Subsequent to operation 02/23/2003 OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 8696 3741 Casing Pressure Tubing Pressure 1586 1645 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil _ Gas __ Suspended __ Service WATER INJECTION 17. I hereby certify that the foregoing is true and correct to the best of my k~owledge. "9O S BFL Form 10-404 Rev 06/15/88 · Title: Technical Assistant Date Febraury 24, 2003 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE q~ 11/07/2002 11/14/2002 11/15/2OO2 11/15/2OO2 11/16/2OO2 11/18/2002 11/26/2002 11/27/2002 11/30/2002 12/01/2002 12/02/2002 12/04/2002 01/05/2003 01/06/2003 02/01/2003 02/05/2003 02/14/2003 02/14/2003 02/19/2003 11/07/02 11/14/02 11/15/02 11/15/02 11/16/O2 11/18/02 04-45 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COHM (AC-EVAL AND ANN-COMIVl (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMIVl (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COHM (AC-EVAL AND ANN-COMM (AC-EVAL AND ANN-COMM (AC-EVAL AND TESTEVENT--- INJECTION 2,305 REPAIR): REPAIR): REPAIR): REPAIR): REPAIR): REPAIR): REPAIR): AC-FLUID LEVEL TUBING TAIL PLUG TUBING TAIL PLUG SCMOO-B-GONE SCMOO-B-GONE TUBING TAIL PLUG SCMOO-B-GONE REPAIR): TUBING WASH / PICKLE REPAIR): TUBING TAIL PLUG REPAIR): AC-MONITOR REPAIR): AC-CMIT TXIA REPAIR): AC-MONITOR REPAIR): TUBING TAIL PLUG REPAIR): TUBING TAIL PLUG REPAIR): AC-LNFF REPAIR): AC-MONITOR REPAIR): AC-MITOA REPAIR): MIT-OA PRESSURE, PSI: 1,666 TYPE: PW VOLUME: EVENT SUMMARY T/I/O = 1220/1080/300 TEMP = HOT IA FL (PREP FOR CMIT T x IA) IA FL @ SURFACE (FOAMY). WELL IS CURRENTLY ON INJECTION. FREEZE PROTECT TUBING PRIOR TO SLICKLINE SETTING TUBING TAIL PLUG/ DSO WILL FREEZE PROTECT FLOWLINE OUT TO TWIN #42 THROUGH NEEDLE VALVE. RAN 2.80 GAUGE RING TO 3121' WLM. UNABLE TO MAKE ANY MORE PROGRESS DUE TO SCHMOO. <<< LEFT WELL SHUT-IN >>> PUMPED DOWN TUBING, 5 BBLS NEAT METHANOL, 140 BBLS SCHMOO-B- GONE MIX. LET SOAK FOR 3 HOURS. PUMPED 100 SEAWATER, LET SOAK FOR 3 HOURS. AFTER LETTING FIRST SEAWATER FLUSH SOAK FOR 3 HOURS. PUMPED 145 BBLS SEAWATER DOWN TUBING, FOLLOWED BY 40 BBLS 60/40 METHANOL TO FREEZE PROTECT. ( WELL SHUT IN ON ARRIVAL ) RUN 2.8 GAUGE BEGIN CUTTING SCHMO @ 2200' WLMD. UNABLE TO CUT FURTHER THAN 3300' WLM. TALK W/CO. REP. BRING WELL ON INJECTION. DRIFT W/1.94 SWEDGE 2.20 GR STOP @ 7160' SLM POOH. RDMO. ( LEFT WELL ON INJECTION ) SCANNED MAR 1 0 2003 Page I 11/26/02 11/27/02 11/30/02 12/01/02 12/02/02 12/O4/O2 12/O5/O2 12/O6/02 02/01/03 O2/O5/O3 04-45 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS MIRU CTU#9. SHUT-IN INJECTION. RIH WITH sjn JETTING TUBING AND PERFS WITH SCHMOO-B-GONE. LET SOAK. FLUSH 1.5 WELL VOLUME DOWN BACKSIDE. POOH JETTING LINER AND TUBING WITH SBG. OOH. <<< LEAVE WELL SHUT-IN. NOT FREEZE PROTECTED.>>> NOTIFY OPERATOR OF STATUS, BRING WELL BACK ON INJECTION 3 HOURS AFTER RIGGING DOWN TO FLUSH TREATMENT OUT OF TUBING. RDMO. FREEZE PROTECT FL WITH 10 BBLS METHANOL & TBG WITH 25 BBLS METHANOL. **** WELL SHUT IN ON ARRIVAL **** RAN 2.80 GAUGE RING TO XN NIPPLE @ 9000' SLM. SET 2.81 PXN PLUG W/2.15 OD "P" PRONG BODY IN XN NIPPLE @ 9000' SLM. RUN 3-1/2 CHECK SET TO PLUG (GOOD SET). SET "P" PRONG IN PLUG @ 9000' SLM (LENGTH = 97", W/F.N.= 1.75".) COMPLETED 30 MIN. CMIT TO 3000 PSI (GOOD TEST) -- BLEED TUBING DOWN TO- 100#/BLEED IA DOWN TO- 0#. ****LEFT WELL SHUT IN**** T/I/O=70/20/220 PREP FOR AOGCC CMIT; TBG FL @ SURFACE. IA FL NEAR SURFACE. T/I/O = 680/640/220. CMIT - T x IA TO 3000 PSI --- PASSED. (STATE WITNESSED, CHUCK SHEVE). TBG AND IA FL's @ SURFACE. PRESSURED TBG AND IA TO 3000 PSI WITH 4 BBLS OF METHANOL. STARTED 30 MINUTES TEST. IN THE FIRST 15 MINUTES TBG LOST 10 PSI AND IA LOST 20 PSI. PRESSURES REMAINED UNCHANGED DURING THE SECOND 15 MINUTES. TOTAL PRESSURE LOSS WAS 10 PSi ON THE TBG AND 20 PSI ON THE IA. BLED TBG AND IA TO 0 PSI. FINAL WHP's = 0/0/250. T/I/O=SI/0/220 MONITOR WHP's ( POST CMIT T x IA ) **WELL SHUT IN UPON ARRIVAL** PULL PXN PRONG FROM PLUG @ 8989' SLM. PULL PXN PLUG FROM 3 1/2 XN NIP @ 8991 SLM. *** RETURNED WELL TO OPERATOR FOR INJ.*** T/I/O = 1700/1630/290 TEMP = HOT. LNFT-T FAILED (EVALUATION TBG x IA COMM WAIVER). SI INJECTION @ 0730 HOURS. TBG PRESSURE AT 400 PSI SIX HOURS LATER. TBG FL @ SURFACE. FINAL WHP's = 400/450/270. TIO= 1850/1700/280. OA FL @ Surface. (Eval T x IA Waiver). MAR 1 0 2003 Page 2 02/14/03 04-45 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS T/I/O = 1820/1650/200. TEMP = HOT. MIT - OA FAILED. LLR = 2 BPM @ 1540 PSI. (WAIVER EVALUATION). OA FL @ SURFACE. PRESSURED OA TO 700 PSI WITH 2 BBLS OF DIESEL. AFTER ANOTHER 3 BBLS OAP INCREASED TO 800 PSI. INCREASED PUMP RATE TO 1.5 BPM. OAP INCREASED TO 1200 PSI. PUMPED AN ADDITIONAL 7 BBLS WITH LITTLE INCREASE IN OAP. INCREASED PUMP RATE TO 2 BPM. OAP INCREASED TO 1540 PSI. PUMPED ANOTHER 8 BBLS WITH NO INCREASE IN PRESSURE. SD AND OAP DROPPED FROM 1540 PSI TO 450 PSI IN 10 MINUTES. BLED OA TO 200 PSI. FINAL WHP's = 1820/1650/200. 02/14/03 MITOA *ATTEMPTED* ( FAILED; UNABLE TO REACH TEST PSI ) ESTABLISHED LLR = 2 BPM @ 1540 PSI. 02/19/03 TESTEVENT --- INJECTION PRESSURE, PSI: 1,666 TYPE: PW VOLUME: 2,305 Fluids Pumped BBLS 3 DIESEL FOR SURFACE PRESSURE TEST (2 TESTS) 54 DIESEL 115 METHANOL 85 60/40 METHANOL WATER 116 FRESH WATER 245 SEAWATER 170 1% NON-SLICK KCL WATER 150 SCHMOO-B-GONE 24 SCHMOO-B-GONE CONCENTRATE 962 TOTAL SCANNED NIAR 1 0 2003 Page 3 \' ~ () ~ Iio.\ \. ':7 Summary of Sundry Changes 09/12/03 Well Request 10-403 1 0-404 04-45 Align Conditions of Approval with Sundry XX XX Matrix 09-12 Align Conditions of Approval with Sundry XX XX Matrix 11-10 Align Conditions of Approval with Sundry XX XX Matrix 11-29 Align Conditions of Approval with Sundry XX XX Matrix 14-21 Align Conditions of Approval with Sundry XX XX Matrix A-31 Align Conditions of Approval with Sundry XX XX Matrix P1-01 Align Conditions of Approval with Sundry XX XX Matrix P-14 Cancel Sundry XX Y -03 Cancel Sundry XX Contact Joe Anders or John Cubbon with questions. (907) 659-5102 ( Well is L TSI Well is L TSI /0/ 'I - t:J 3'1' Comments ~v MEMORANDUM TO: Mike Bill~'t~ Commissioner THRU: Tom Maunder P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 2, 2002 SUBJECT: Mechanical Integrity Tests ~QI~'°-~ DS4 4-45 PBU Prudhoe Bay NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. w~,,I ~ N I T.V.D.I ~0~ I Tubi,g I 680 I 3000 ] 2990 I 2990 I,nte~va,] V' P.T.D..] 194-034 Imypetestl P ]mestpsi] 1754 ICasingI 640 I 29701 29501 29501 P/F I P Notes: Known tubing leak, CMIT required by vadance Welll I TypeInj. I I T.V.D. I I Tubing I I I I 'l Intervall' P.T.D.I ITypetestl ITestpsil I Casingl I I I I P/F I Notes: WellI P.T.D.I Notes: P.T.D.I Notes: P.T.D.I Notes: Type INJ. Fluid Codes F -- FRESH WATER INJ. G = GAS I NJ. 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 I traveled to BPXs Drill Site 4 and witnessed thc CMIT on well 4-45. A plug had been set in the tubing at 9005' measured depth, below the}mom leak. The casing and tubing were then pressured tested for 30 minutes demonstrating mechanical integrity of the production casing and packer. M.I.T.'s performed: 1 Attachments: Number of Failures: 0 Total Time during tests: 2 hoUrs CC: 5C~NED DE C ~L 9 2 0 02 MIT report form 5/12/00 L.G. MIT PBU 4-45 12-2-02 CS.xls 12/5/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate_ SCMOO-BE-GONE Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 591' FNL, 448' FEL, Sec. 34, T11 N, R15E, UM At top of productive interval 644' FNL, 3842' FEL, Sec. 03, T10N, R15E, UM At effective depth 912' FNL, 4035' FEL, Sec. 03, T10N, R15E, UM At total depth 979' FNL, 4080' FEL, Sec. 03, T10N, R15E, UM 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X (asp's 712399, 5951266) (asp's 709165, 5945843) (asp's 708980,5945570) ~sp~708936, 594550~ 6. Datum elevation (DF or KB feet) RKB 71 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 04-45 9. Permit number / approval number 194-034 10. APl number 50-029-22454-00 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical 11875 feet 9180 feet Plugs (measured) Effective depth: measured true vertical Casing Length Conductor 112' Surface 3864' Intermediate 11792' Liner 11721 feet 9050 feet Junk (measured) Size 20" 9-5/8" 5-1/2" Cemented Measured Depth True Vertical Depth 260 sx AS 112' 112' 1012 sx CS III, 975 sx Class 'G' 3928' 3555' 710 sx Class 'G' 11856' 9164' RECEIVED Perforation depth: measured Open Perfs 11670' - 11710' true vertical Open Perfs 9004' - 9038' APR 1 I Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 7#, QT-800 @ 9006' MD; 3-1/2" x,2-7/8" XO @ 9006'; 2-7/8" to 9007'; 3" from 9009' to 9020'; 3" x 2-7/8" XO @ 9020'; 2-7/8" to 9040'. 5-1/2" Sealbore Receptacle W/X Lock @ 9009'. 3-1/2" CAM DS SSSV @ 3003' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 03/09/2002 Subsequent to operation 03/21/2002 OiI-Bbl Representative Daily Avera.qe Production or Injection Data Gas-Mcr Water-Bbl 3878 5901 Casing Pressure Tubing Pressure 1859 1799 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WATER INJECTION 17. I hereby certify that the foregoing istru~e and correct to the best of my knowledge. D~~,~..~~*~,~. Title: Technical Assistant Date April 08, 2002 Prepared by DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 04-45 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/17/2002 SCMOO-B-GONE--SBG' SCMOO-B-GONE EVENT SUMMARY 03/17/02 PUMPED 170 BBLS SCHMOO-B-GONE AND 5 BBLS MEOH FROM SKID TO WELL.TURN OVER TO DSO FOR 3 HR SOAK. Fluids Pumped BBLS 5 METHANOL 170 SCHMOO-B-GONE 175 TOTAL Page I Phillips Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 June 27, 2000 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: DS 04-45 (PTD 194-034) Sundry Notice Variance Request Dear Mr. Maunder: Attached is an Application for Sundry Approval form 10-403 variance request for well 04-45 (PTD 194-034). The request is for approval to continue produced water injection with known tubing by production casing. Aisc attached is a proposed Action Plan and a wellbore schematic. If you require any additional information or clarification, please feel free to contact either Jerry Dethlefs or me at (907) 659-5102. Sincerely, Joe Anders, PE Problem Well Specialist Attachments STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter st~spend~d well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 64 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number I i 591' FNL, 448' FEL, Sec. 34, T11N, R15E, UM (asp's 712399, 5951266) 04-45 At top of productive interval 9. Permit number/approval number 644' FNL, 3842' FEL, SEC. 3, T10N, R15E, UM (asp's 709165, 5945843) 194-034 At effective depth 10. APl number 50-029-22454 At total depth 11. Field / Pool 979' FNL, 4080' FEL, Sec. 3, T10N, R15E, UM (asp's 708936, 5945500) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 1 1875 feet Plugs (measured) true vertical 9180 feetORIGINAL Effective depth: measured 1 1721 feet Junk (measured) true vertical 9050 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 112' 20" 260 SxAS 112' 112' Surface 3864' 9-5/8" lO12 Sx CS III & 375 Sx Class G 3928' 3555' Production 11792' 5-1/2" 710 Sx Class G 11856' 9164' Perforation depth: measured 11670' - 11710'. r !~1 3, 0 2000 true vertical 9004' - 9038'. - ~ : Tubing (size, grade, and measured depth 3-1/2", 7#, QT-800 Tbg @ 9006' MD; 2-7/8", 6.5#, L-80 Tbg @ 9041' MD. ~. '~-~',~"-.~" Packers & SSSV (type & measured depth) 3-1/2" CAMCO DS SSSV Nipple @ 3003' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: July 10, 2000 16. If proposal was verbally approved Oil__ Gas __ Suspended __ Name of approver Date approved Service Water Inj 17. I hereby cedify that the foregoing is true and correct to the best of my knowledge. Questions? Call Joe Anders/Jerry Dethlefs @ 659-5102 Signed ~f]'~ (Lv-~~/''~ Title: p~l~*w~ (./~(il ~'1a-~;¢.i,'5~' Date Prepared by Paul Rauf 263-4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity_ BOP Test__ Location clearanceI ZOO Mechanical Integrity Test ~ C~.~'~'~,~ ~,~.!~ S'~i.equ~J~r~rn~uirq~j~2 ~t~vx~.hr,,~,[ ~-~:.~ ~.~.~_ ~,'-[~.~,~ q: ~'~\~ ~, ORIGINAL SIGNED BY ,..-'-~.~*oved Oopv --~/~ /. Approved.~y order of the Commission D Tavbr .c;..¢.=m.o,_,~t Ret,,r,,,,P~,~o.~nl~issi°ner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE DS 04-45 Sundry Request SUNDRY DISCUSSION AND PROPOSED ACTION PLAN June 26, 2000 DISCUSSION Well 04-45 is a produced/sea water injector exhibiting tubing x 9-5/8" communication. An MIT-IA was attempted on 6/6/00. It failed and an injection rate of 7 GPM @ 1840 psi was established into the 9-5/8" casing. A spinner/temperature log was run 6/11/00 and located a leak in the 3-1/2" coiled tubing completion at 1140'. A combination MIT tubing x 9-5/8" casing against a tubing tail plug passed to 3000 psi on 6/11/00, indicating competent production casing and packer. While attempting to set the tubing tail plug on 6/9/00, an obstruction was encountered at the top of the 2-7/8" crossover and we were unable to drift below this point. This sundry request is to continue water injection into the well, based on the following information: · A combination MIT (tubing x 9-5/8") passed 6/11/00 to 3000 psi demonstrating mechanical integrity of the casing and injection in the approved zone; · Normal wellhead injection pressure is 1800-2000 psi at 10,000 BWPD. · Engineering is evaluating a RWO to replace the tubing. This area is near the GOC and it is desired to maintain injection while the RWO evaluation and rig mobilization are being evaluated. PROPOSED ACTION PLAN · Continue water injection into the well; · Monitor wellhead pressures daily; · Submit monthly report to AOGCC of daily injection rate, tubing and annulus pressures; · Perform a combination MIT tubing x 9-5/8" casing to 3000 psi against a plug once per year; · Shut-in and secure the well should MIT's, injection rates or wellhead pressures indicate problems, and notify the AOGCC. /- 3-1/2" Tubing Leak 1140' 9-5/8" Surface Casing 3928' /2" Coiled Tubing 5-1/2"x2-7/8" Packer, 9010' EOT 9041' 5-1/2" Production Casing "" 11,856' Well Name: 04-4~. i Well Type: Injector Status: Shut-in Tubing leak @ 1140', found with LDL on 6/ 11/00. CMIT TxIA to 3000 psi passed 6/11/00 Leak Location: Tubing leak @ 1140' Well 04-45 Failed MITIA (PTD 194-034) Subject: Well 04-45 Failed MITIA (PTD 194-034) Date: Sun, 11 Jun 2000 17:20:48 -0900 From: "PRB Problem Wells" <P1041@ppco.com> To: blair_wondzell@admin.state.ak, us, tom_maunder@admin.state.ak, us CC: john_spaulding@admin.state.ak, us Hello Blair & Tom. A spinner/temperature log was run in well 04-45 on 6/11/00. A tubing leak was identified at 1140'. A combination MIT TxIA was conducted during the LDL and passed to 3000 psi. The well is currently SI and secured with a tubing tail plug. We are evaluating repair options and will leave the well shut-in. Call if you have any questions. Joe Anders, PE Problem Well Specialist Phillips Alaska, Inc. (907) 659-5102 p1041@ppco.com 04:52 PM Fomarded by PRB Problem WelIs/AAI/ARCO on 06/11/2000 06/06/2000 12:34 PM PRB Problem Wells PRB Problem Wells PRB Problem Wells 06~06~2000 12:34 PM 06~06~2000 12:34 PM To: blair_wondzell@admin.state.ak, us, tom_maunder@admin.state.ak, us cc: john_spaulding@admin.state.ak, us Subject: Well 04-45 Failed MITIA (PTD 194-034) Hello Blair and Tom. Well 04-45 (PTD 194-034) failed an MIT-IA today (6/6/00). Leak rate was 7 GPM @ 1840 psi. 04-45 is currently injecting produced water, approximately 10,000 bwpd @ 1950 psi. Leak location is unknown. It is completed with 3-1/2" coiled tubing inside 5-1/2" production casing. Plan is to leave the well online and run a leak detect log to locate the leak point. Call if you have any questions. Joe Anders, PE Problem Well Specialist Phillips Alaska, Inc. (907) 659-5102 p 1041 @ppco. corn .... 6/12/00 7:56 AM ..... AOGCC In,di'v'i'dua'i soiogi'ca i i~fater'i a i s F'ERBtZT DA'FA T DATA ...... F'L. US 94 ..... 034. ~iT' (C;EhtENT) L 550-'11718 9 4. '.-.-0 3 fi. ~i~. T,3 L 1 1 0 5 0--- 'i I 7 i 5 94----03z~ ~/~'rDTP L I i050.-1 I715 94.---03~ ~,d~.~,GF,'/E~,~.tR-.P~ L 8562-~-9i80~ I,~WD~ TVD 94----.03a- ~'ERF L 1 I050--11690 9a.---03~+ ~STAT L 8900.---t!709 94--0Sa- ~7 R COHF' DATE~ 06/26/'94. 9~ .... 03~ ~c~ R 0S/0}--07/'0a/'9~ 9~.-0S.~ ~DT ..... P/BORAX L I 1120-1i690 Ar'e dr'y ct~ tch samp'i es r'equ'i r'ed9 yes -d ~,.,e'..~; es no Was the we i'i cor'ed? C O hi hi E N T S :,GeOQuest :1500 W.:lnternational Airport Road ,Anchorage, AK 99518-1199 Sherrie NO. 10053 Company: Alaska Oil & Gas Co~,'s Co~'mT~ Attn: I_arry Grant 3001 Porcupine Drive Anchorage, Al( 9950'1 3/419(~ Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Survey Performance Disk Calculation Letter "D~s. 1-17A ~f~--Io~Z'.'': J~96042 DUAL BURST TDT.'p ..... 960121 ............... 1 DiS. 15-1 £~.- 0~(, 96043 DUAL BURSTTDT-P BORAX 96011 6 1 D;S, '4-45 ~/,-/- 0.1.'~ 95015 DUAL BURSTTDT-P BORAX 941 21 2 ' 1 ...... , ................. D~S. 5,4 7~t-~)5-? 96035 .. DUAL BURST TDT-P " , 1960129 1 D;S. 5-25 8~-12, 96040~ DUAL BURST TDT-P BORAX ~ ' 960126 1..' ,. ; , i ? · : , : , . .: SIGNED: .please sign and return one c(~py of this transmittal to Sherrie at the above address. Thank you. DATE: GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 A'I'TN: Sherrie NO. 9183 Company: 1/1 O/95 Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field- Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 3-7 "7 ~- 6~'~'2~ STATIC BH PRESS SURVEY (12-11-94) 1 1 D.S. 3-14 ~ T~ TUBG CUTTER RECORD (12-11-94) 1 1 D.S. 3-14 l I - ~) STATIC BH PRESS SURVEY (12-11-94) 1 1 D.S. 4-27 ~-{~'--'",~ ~ STATIC BH PRESS SURVEY (12-14-94) 1 1 D.S. 4-28 ~ ~-,." :~--~'~::) STATIC BH PRESS SURVEY (12-14-94) I 1 D.S. 4-44 ,cI L~._-(O"J'~)' DUAL BURST TDT-P (12-13-94) I 1 D.S. 4-45 ~ C~f (~.~ L~ .... DUAL BURST TDT-P (12-12-94) I 1 D.S. 5-16A C~ L/~ { _?~ TUBG PUNCHER & POGLM SETTING RECORD (12-13-94) I 1 D.S. 9-32 ~'~-~'--'_~ ]~ INJEC PROFILE (12-12-94) ? I 1 D.S. 11-32 C~ 4-/---../~i STATIC BH PRESS SURVEY (12-12-94) " I 1 O.S. 15-40 ~ ~-~ \.~>~ PDC (12-11-94) I 1 D.S. 3-13 -7 ~-~ C3'~, STATIC PRESS SURVEY (12-19-94) I 1 D.S. 4-20 ~ ~ _~ STATIC PRESS SURVEY (12-14-94) I 1 D..S... 4-20 L) ~ INJEC PROFILE (12-14-94) I 1 D.S. 5-33 ~, 1-~' (-:7 (0~ PERF RECORD (12-19-94) I 1 D.S. 11-30~.~: -~6 -~7 STATIC PRESS SURVEY (12-16-94) 1 1 D.S. 12-27 ~J(- (~5' INJEC PROFILE (12-21-94) 1 1 D.S. 15-23 J I PROD LOG (CT E-LINE) (12-19-94) I 1 D.S. 16-21 ~ ~)'~ } ~ INFLATABLE BRIDGE PLUG SET RECORD (12-20-94) I ,/~ I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9139 Company: Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 12/30/94 Field: Prudhoe Bay Floppy Well Log Description BL RR Sepia RF Sepia Mylar Disk "'~. 2-20 ~" ,;2 -- O :7.- c/' CNTD (5-13-94) ~ 1 '13~. 2-23 ST ~ ~--/2. C) DUAL BURST TDT-P (2-25-93) 1 .t~)~. 3-25A cf ~ . O 2...~ ICNTH (4-23-93) .... 1 ~.S. 3-28 ? ~ .- Q ~ 2-- DUAL BURST TDT-P (2-8-93) ~ [~ '~ ~ .. 1 D.>~4-2 '70- ~3~ ~ .CNTD (3-20-93) . l.~.L-~ ~.2~~ 1 ~.S. 4-43 ~...._ c~/.J' ,.,.~ CNTG (3-29-94) ~.~_~ 1 !DIS. 4-43 ~ / ,/' ~/~ --~ DUAL BuRsT TDT-P (3-29-94) tt r- ~ ~,, ~,.- ~.~ ' ..... .'i' I "' D.S. 4-44 ~ ~j L,/ /,, ,~ CNTG (4-!4-94) / 0~'~ ~ J[ E L ~ J ~ [~ !.~ 1 D.S. 4-44 ~ I ~ - ~J ~ DUAL BURST TDT-P (4-14-94) ~~ 1 D.S. ~-45 ~~ ~ ~ 0 ~ DUAL BURST TDT-P (4-24-94) ~~~ JAN 0 D'.S. 4-45 / I I~ ~D I CNTG (4-24-94) ~ 1 D~S. 4-37 ~/"' OG7 DUAL BURSTTDT-P (6-20-9~) . . ~H~' ' ~~a~ J &~asC0ns.b~h~i~s~',',n .... 1 p.S. 5-17A ~-~1 DUAL BURST.TDT-P (8-26-93) ~q~ ~i~uhurage .... 1 s- e UAL BURST T ?P , S. 5-3~ DUAL BURST TDT-P (7-17-91) 1 D,S. 5-34 q / ~ / ~ I DUAL BURST TDT-P (1-26-93) ~~ 1 D.S. 5-36 ~ / ~ ~ 7~ lCETD .(2'1'93) h ~ .... I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. .- -ska Oil & Gas Cons. Comm[ssJo.rl Anchorage Page 2 ARCO Alaska, Inc. Date: September 20, 1994 P.O. Box 10036[ I ,nchorage, AK Transmittal #: 94111 Subject: ARCO Static Pressure Survey's From/Location: Telephone: To/Location: · ! 12-10A i ~ 12-12 ~ 13-31 Karla Zuspan/ATO- 1529 (907) 263-4310 Distribution Log Bate i Tool Type i Numberi (M-D-Y)! 04-19 i 05-23-941 Pressure Survey i 04-45i~ 107'05'94 Pressure Survey' 11-29i i 07-08-94 Pressure Survey' 121.,03¢A' 06-09-94 i Pressure Survey , /"7~'"i I i 06-06-94 i'-Pressure Survey' i 06-07-94 ! Pressure Survey 06-08-94 ! Pressure Survey' 07-07-94 i Pressure Survey' 06-08-94 t Pressure Survey' 06-09-94 i Pressure Survey 06-09-94 ! Pressure Survey 06-04-94 ! Pressure Survey 06-10-94 I Pressure Survey Run Contractor SCH 1 1 SCH 1 SCH 1 SCH 1 SCH 1 SCH SCH SCH. SCH 1 SCH SCH 1 1 SCH ! SCH Number of Records: 13 Karla Zuspan Distribution: Central Files BPX State of Alaska Mobil Please ]e receipt Phillips Exxon D&M ret u rr~i/ct~ Date: ~smi' ,I. r ARCO Alaska, Inc. Is a Su~sidlaty of AtlantlcRIcflfi~dCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RI:COMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SLISPEt,,DED [] ABANDONED [] SERVICE El( WAG Injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 94-34 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22454 4. Location of well at surface ~ ....... ~ 9. Unit or Lease Name 594'At TopSNL'Producing449' WEL,intervaISEC. 34, T11N, R15E~i'~_~_ '~'_"_~_~~ ~'~ ~ "!i ~IF. tEDJ~' ' 10.Prudh°ewell NumberBay Unit _ . 11. Field and Pool At Total Depth ..................... -~':.~ ~ ~ Prudhoe Bay Field/Prudhoe Bay Pool 982' SNL, 1197' EWL, SEC. 3, TION, R15E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 64.8' ! ADL 28328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 3/7/94 3/18/94 6/26/94I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ~20. Depth where SSSV set ~1. Thickness of Permafrost / 11875'MD/9174'TVD 11721'MD/9047' TVD YES [] t¢~ [] 3003' feet MD ! 1900'(Approx.) 22. Type Electric or Other Logs Run MWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 32' 112' 30" 260 sx Arcticset (Approx.) 9-5/8" 47# NT-80S 34' 3928' 12-1/4" 1012 sx CS 111/375 sx "G" 5-1/2" 17# L-80 31' 11856' 8-1/2" 710 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 (MDI PACKER SET (MD) Gun Diameter 3-3/8" 6 spf 3-1/2" x 2-7/8" 9040' 9005' MD TVD 11670'-11710' 9004'-9038' coil tubing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Date First Production IMethod of Operation (Flowing, gas lift, etc.) 8/5/94 I lnjection Date of Test Hours Tested PRODIJOTION FOR OIL-BBL GAS-MOF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Oasing Pressure CALOULATED OIL-BBL GAS-MOF WATER-BBL DIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. OORE DATA SEP 1 5 1994 Alaska 0il & 6as Cons. Commission Anchoraoe Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. [ GEOL~ MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Sag River 11050' 8491' Shublik 11058' 8497' Sadlerochit 11131' 8557' RECEIVED SEP 1 5 1994 Alaska Oil & Gas Cons. Commission Anch0ra~e 31, LIST OF ATTACHMENTS 32. I hereby cedify that the foregoing is true and correct to the best of my knowledge ~/~_.~-~'/~V"'-~ Title Dril/inoEn{3ineerSuoevisor c~"~'~?[t INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 4-45 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 03/07/94 10:00 SPUD: RELEASE: 03/20/94 10:00 OPERATION: DRLG RIG: NABORS 28E WO/C RIG: 03/07/94 ( 1) TD: 0'( 0) 03/08/94 ( 2) TD: 850' ( 850) 03/09/94 (3) TD: 3200' (2350) 03/10/94 ( 4) TD: 3945' ( 745) 03/11/94 ( 5) TD: 5360'(1415) 03/12/94 ( 6) TD: 7000' (1640) MIRU RIG MOVE FROM DS 4-44 TO DS 4-45. MW: 0.0 VIS: 0 DRILLING MW: 8.7 VIS:300 FINISH MIRU. NU RISER AND FLOWLINES. PU BHA TO RIG FLOOR, MIXING SPUD MUD. FUNCTION TEST DIVERTER SYSTEM. MU BHA. DRILLING F/ 92-124'. LEAK THRU VALVE ON DIVERTER LINE. CLEAN UP DRILLING MUD, THAW OUT DIVERTER LINE. ORIENT TOOLS. DRILLING F/ 124-565'. CHANGE OUT SWIVEL WASH PIPE AND PACKING. DRILLING F/ 565-850'. DRILLING MW: 9.2 VIS:300 DRILLING F/ 850-2808'. SHORT TRIP TO HWDP WITH NO PROBLEMS. DRILLING F/ 2808-3200' NIPPLE DOWN DIVERTER MW: 9.5 VIS: 58 DRILL F/ 3200-3945'. CIRCULATE BOTTOMS UP. SHORT TRIP TO 2766' REAM BRIDGES @2924 & 3115' CIRCULATE SWEEP & DROP SURVEY. TRIP OUT OF HOLE & LAY DOWN BHA. RIG UP AND RUN 9 5/8" CASING. NO PROBLEMS. CIRCULATE & RECIPROCATE 9 5/8" CASG BJ 1 HR LATE. HAD PROBLEMS WITH TRUCKS. PUMP 50 BBL WATER + 345 BBLLEAD & 77 BBL TAIL CEMENT. DISPLACE WITH 284 BBL MI/D @ 10 BPM. 250 SACK TOP JOB. LAY DOWN LANDING JOINT & CASING TOOLS. NIPPLE DOWN DIVERTER & FLOW LINE. CLEAN MUD PITS. DRILLING MW: 9.5 VIS: 40 NIPPLE DOWN DIVERTER AND NIPPLU UP BOPE. TEST BOPE. INSTALL WEAR BUSHING. MAKE UP AND ORIENT BHA #2. TRIP IN HOLE & TAG @3814' CIRCULATE BOTTOM UP. TEST 9 5/8" CASING. DRILL CEMENT, FLOAT EQUIPMENT & 10' NEW HOLE. PERFORM LOT. DRILL FROM 3955-4963' SHORT TRIP TO 3875'. NO PROBLEM. DRILL FROM 4963-5360' DRILLING MW: 9.6 VIS: 42 DRILL FROM 5360-6184' CIRCULATE SWEEP. DROP SURVEY. -- TRIP OUT OF HOLE. L/D STAB, CHANGE MWD PROBE & ORIENT. SERVICE WEAR BUSHING. TRIP IN HOLE WITH BIT & BHA #3. PRECAUTIONARY REAM FROM 6091-6184'. DRILL FROM 6184-7000' EP 1 5 ~99q' Gas Cons. Commission Anchor~i~ WELL : DS 4-45 OPERATION: RIG : NABORS 28E PAGE: 2 03/13/94 ( 7) TD: 8222' (1222) 03/14/94 ( 8) TD: 9295'(1073) 03/15/94 ( 9) TD:10508' (1213) 03/16/94 (10) TD:10745' ( 237) 03/17/94 (11) TD: 11625' ( 880) 03/18/94 (12) TD:l1790' ( 165) 03/19/94 (13) TD:11875' ( 85) DRILLING MW: 9.6 VIS: 43 DRILL FROM 7000-7443'. CIRCULATE SWEEP AND DROP SURVEY. TRIP OUT OF HOLE FOR NEW BIT. NO PROBLEMS. TRIP IN HOLE TO 9 5/8" CASING SHOE. CUT AND SLIP DRLG LINE. TRIP IN HOLE, PRECAUTIONARY REAM FROM 7351-7443'. GOOD TRIP. DRILL FROM 7443-8222' DRILLING MW: 9.6 VIS: 43 DRILL FROM 8222-9079'. CIRCULATE SWEEP. TRIP OUT OF HOLE FOR NEW BIT. NO PROBLEMS. CHANGE MWD PROBE & BIT. TRIP IN HOLE. BENCHMARK SURVEY @4128' PRECAUTIONARY REAM FROM 9017-9079'. NO PROBLEMS. DRILL FROM 9079-9295'. DRILLING MW: 9.6 VIS: 46 DRILL FROM 9295-10300'_ CIRCULATE SWEEP. SHORT TRIP 14 STANDS TO 9005'. NO pROBLEMS. DRILL FROM 10300-10508'. DRILLING MW: 9.6 VIS: 44 DRILL FROM 10508-10626'. CIRCULATE SWEEP. DROP SURVEY AND TRIP OUT OF HOLE FOR BIT & BHA. TIGHT @ 9690-9532' CHANGE OUT DYNA DRILL, MWD PROBE AND BIT. SERVICE WEAR BUSHING. TRIP IN HOLE & CHANGE OUT JARS. CUT AND SLIP DRILLING LINE. TRIP IN HOLE. NO PROBLEMS. BENCH MARK SURVEY @4133' PRECAUTIONARY REAM FROM 10545-10626' DRILL FROM 10~26-10745' DRILLING DRILL FROM 10745-11625' MW: 9.6 VIS: 42 DRILLING MW: 9.6 VIS: 47 DRILL FROM 11625-11656' CIRCULATE SWEEP, DROP SURVEY. DRY JOB. TRIP OUT OF HOLE, SLM. LD BHA. NO PROBLEMS. PULL WEAR BUSHING & INSTALL TEST PLUG. TEST BOPE. M/U NEW BHA AND LOAD RLL TOOL. TRIP IN HOLE TO 11137' NO PROBLEMS. LOG FROM 11137-11659' WITH RLL. DRILL FROM 11656-11790'. RUNNING 5 1/2" CASING MW: 9.6 VIS: 48 DRILL FROM 11679-11875' SHORT TRIP 15 STANDS NO -- -- PROBLEMS. CIRCULATE HI/LOW SWEEPS. DROP SuRvEy & PUMP DRY JOB. PULL OUT OF HOLE 10 STANDS. CONTINUE OUT OF HOLE LAYING DOWN DRILL PIPE. CUT AND SLIP DRILL LINE. FINISH LAYING DOWN DRILL PIPE. LAY DOWN BHA & READ LOGS FROM RLL TOOL. RIG UP TO RUN 5 1/2" CASING. RUN 5 1/2" CASING. SEP '1 5 1994- Alaska Oit & Gas Cons. Commission Anchora:,-~,~ WELL : DS 4-45 OPERATION: RIG : NABORS 28E T~ PAGE: 3 03/20/94 (14) TD:11875' ( 0) RELEASE RIG MW: 9.6 VIS: 0 RUN 5 1/2" CASING. MAKE UP LANDING JOINT AND CEMENT HEAD. CIRCULATE & BATCH MIX TAIL CEMENT. TEST CEMENT LINES. FLUSH BOPE STACK & LINES. L/D LANDING JOINT. CLEAR RIG FLOOR OF CASG TOOLS AND CEMENT HEAD. INSTALL 7 5/8" PACKOFF AND TEST. INSTALL WEAR BUSHING. PICK UP 3 1/2" DC * 2 7/8" DP TO 2000' DISPLACE WELL WITH DIESEL @2000' LAY DOWN 2 7/8" DP AND 3 1/2" DC. INSTALL FALSE BOWL PROTECTOR & BPV. NIPPLE DOWN BOPE. NIPPLE UP ADAPTER FLANGE AND TREE VALVE. TEST FLANGE. CHANGE OUT MASTER VALVE AND PULL BPV. INSTALL TBG HANGER & 2-WAY CHECK. TEST TREE AND HANGER. RELEASE RIG @0600 HRS ON 03/20/94. SIGNATURE: (drilling superintendent) DATE: RECEIVED SEP 1 5 1994 Alaska Oil & Gas Cons. Commission Anchora~ 4-45i DESCRIPTION OF WORK COMPLETED COILED TUBING COMPLETION INSTALLATION 3/29/94: Ran CCL/GR/USIT logs from PBTD at 11718' MD to surface. 4/24/94: Ran CNT-G/TDT-P logs. Tagged PBTD at 11720' MD. 5/1/94 - 5/3/94: Ran 2-1/2" & 1-11/16" RST/CCL/GR logs. Tagged PBTD at 11721' MD. 6/25/94: RIH w/perforation guns & shot initial perforations at: 11670 - 11710' MD (Z1) Ref Log: MWD 3/19/94. Shot perfs at 6 spf, w/60 degree phasing, from 3-3/8" HSD carriers. Rigged down. 6/26/94: Ran & set Sealbore Receptacle & Tail Assembly in the well as follows: MIRU & RIH w/5.5" brush to brush the XN Nipple at 8989' MD. POOH w/brush, then RIH w/5.5" XXN Plug & set in XN Nipple at 8989' MD. PT Plug to 1500 psi; tested good. RIH & pulled Plug from 8989' MD, then assembled Sealbore Receptacle & Tail Assembly. RIH w/SBR assembly on XN lock & set assembly (see equipment details & depths on schematic attached) POOH w/setting tool. Rigged down. 6/27/94: RIH & set a 2-7/8" XN Plug at 9021' MD. PT Sealbore Assembly to 1500 psi OK. POOH w/XN Plug, then RIH & set a DXXN pump-thru Plug at 9021' MD. POOH. Rigged down. 6/28/94 - 6/29/94: Ran & set a 3-1/2" Coiled Tubing Completion in the well as follows: MIRU 3-1/2" CT Spool#1 & PT equipment. MU & RIH w/Seal Assembly & 3-1/2" Coiled Tubing (details of assembly on schematic attached). Spooled off CT to RIH to 6010' MD, cut the CT, & moved in 3-1/2" CT spool #2. MU Connector & continued RIH w/Spool #2 CT to land in Sealbore Receptacle. PT backside to 1530 psi OK. Fluid packed CT w/Meth Water, cut CT at surface, MU connection, & MU & landed tubing hanger. Tested CT x 5-1/2" annulus to 1550 psi / 30 minutes; tested good. Rigged down. 7/4/94: Pulled the DXXN Plug from the XN Nipple (above) & made RIH to tag PBTD at 11696' MD. SF_P ~ 5 '~994 Gas Cons. Commission SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-45I 500292245400 NORTH SLOPE COMPUTATION DATE: 3/22/94 TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN 0 .00 -63.80 116 116.00 52.20 217 217.00 153.20 308 308.00 244.20 397 396.99 333.19 DATE OF SURVEY: 031694 MWD SURVEY JOB NUMBER: AK-MW-40025 KELLY BUSHING ELEV. = 63.80 FT. OPERATOR: ARCO ALASKA INC COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 0 0 N .00 E .00 .00N .00E 0 18 S 5.90 W .26 .30S .03W 0 18 N 79.70 E .47 .52S .20E 0 18 N 45.40 W .58 .31S .27E 1 6 N 65.50 W .93 .21N .68W VERT. SECT. .00 .27 .33 .12 .19 487 486.91 423.11 547 546.82 483.02 637 636.66 572.86 727 726.46 662.66 826 825.23 761.43 3 5 N 85.80 W 2.34 .75N 3.89W 3 24 S 86.50 W .88 .76N 7.28W 3 24 N 82.20 W .74 .96N 12.59W 4 5 N 83.90 W .79 1.66N 18.43W 3 47 N 86.70 W .36 2.22N 25.23W 1.47 3.28 5.97 8.53 11.71 922 921.02 857.22 1017 1015.79 951.99 1112 1110.60 1046.80 1206 1204.48 1140.68 1302 1300.38 1236.58 3 47 S 88.70 W .32 2.34N 31.59W 4 5 S 88.80 W .32 2.19N 38.13W 3 5 S 83.00 W 1.12 1.81N 44.07W 2 47 S 76.30 W .49 .96N 48.83W 2 17 S 53.90 W 1.15 .73S 52.66W 15.04 18.68 22.21 25.49 28.98 1395 1393.31 1329.51 1491 1489.23 1425.43 1586 1584.10 1520.30 1681 1678.82 1615.02 1776 1773.42 1709.62 2 5 S 38.90 W .65 3.16S 55.24W 2 30 S 15.30 W 1.06 6.55S 56.90W 3 30 S 23.60 W 1.14 11.20S 58.60W 5 5 S 27.30 W 1.71 17.61S 61.70W 5 24 S 37.30 W 1.01 24.92S 66.35W 32.41 36.15 41.00 48.07 56.73 1871 1867.92 1804.12 1967 1963.02 1899.22 2062 2056.44 1992.64 2158 2149.65 2085.85 2254 2241.35 2177.55 6 24 S 34.60 W 1.09 32.84S 72.06W 9 11 S 37.50 W 2.94 43.33S 79.77W 11 41 S 33.50 W 2.74 57.39S 89.71W 15 53 S 32.10 W 4.39 76.66S 102.08W 18 30 S 27.40 W 3.07 101.32S 116.08W 66.47 79.47 96.67 119.56 147.89 2349 2330.58 2266.78 2444 2417.83 2354.03 2540 2504.44 2440.64 2635 2588.78 2524.98 2730 2671.07 2607.27 21 36 S 28.80 W 3.30 130.03S 131.44W 25 0 S 35.10 W 4.43 161.80S 151.42W 26 6 S 35.30 W 1.15 195.63S 175.29W 28 42 S 32.80 W 2.99 231.86S 199.72W 31 12 S 33.60 W 2.66 271.53S 225.70W 180.35 217.87 259.23 302.92 350.34 2826 2751.94 2688.14 2922 2830.37 2766.57 3017 2905.98 2842.18 3112 2979.48 2915.68 3207 3050.19 2986.39 34 0 S 34.10 W 2.93 314.48S 254.51W 36 24 S 34.30 W 2.50 360.23S 285.61W 38 5 S 31.50 W 2.53 408.51S 316.81W 40 30 S 30.80 W 2.57 460.00S 347.92W 43 17 S 32.40 W 3.15 514.01S 381.18W 402.04 457.34 514.82 574.96 638.38 REE£1VED SEP 1 5 1994 Alaska Oil & Gas Cons. Commission Anchor~u~ SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-45I 500292245400 NORTH SLOPE COMPUTATION DATE: 3/22/9 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 3303 3119.24 3055.44 3399 3187.12 3123.32 3494 3254.00 3190.20 3589 3320.59 3256.79 3685 3387.15 3323.35 COURS INCLN DG MN DATE OF SURVEY: 031694 MWD SURVEY JOB NUMBER: AK-MW-40025 KELLY BUSHING ELEV. = 63.80 FT. OPERATOR: ARCO ALASKA INC COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST 44 42 S 32.70 W 1.47 570.22S 417.06W 45 17 S 33.80 W 1.02 626.98S 454.28W 45 12 S 32.20 W 1.20 683.56S 491.02W 45 47 S 31.30 W .92 741.18S 526.67W 46 24 S 31.30 W .63 800.28S 562.61W VERT. SECT. 705.07 772.94 840.40 908.15 977.30 3780 3452.61 3388.81 3867 3512.66 3448.86 3966 3580.55 3516.75 4065 3648.32 3584.52 4163 3716.11 3652.31 46 30 S 32.50 W .92 858.73S 598.99W 46 12 S 30.80 W 1.46 912.31S 632.02W 47 12 S 33.10 W 1.97 973.43S 670.15W 4-6 24 S 33.80 W .96 1033.64S 709.93W 46 5 S 28.70 W 3.77 1094.12S 746.63W 1046.15 1109.08 1181.11 1253.27 1323.99 4258 3782.34 3718.54 4353 3849.16 3785.36 4449 3916.39 3852.59 4544 3982.50 3918.70 4639 4048.49 3984.69 45 30 S 25.70 W 2.35 1154.67S 777.76W 45 5 S 28.70 W 2.28 1214.71S 808.61W 46 0 S 28.50 W .95 1274.88S 841.41W 45 47 S 27.80 W .57 1335.03S 873.60W 46 12 S 28.50 W .68 1395.28S 905.84W 1391.78 1458.98 1527.34 1595.36 1663.49 4736 4115.69 4051.89 4831 4181.98 4118.18 4927 4249.56 4185.76 5022 4315.73 4251.93 5117 4380.21 4316.41 46 5 S 30.40 W 1.42 1456.19S 940.23W 45 24 S 31.70 W 1.23 1514.48S 975.32W 45 5 S 30.80 W .74 1572.76S 1010.69W 46 35 S 29.40 W 1.90 1631.73S 1044.86W 47 54 S 29.90 W 1.42 1692.35S 1079.37W 1733.33 1801.35 1869.51 1937.60 2007.26 5212 4443.90 4380.10 5307 4507.78 4443.98 5402 4571.96 4508.16 5498 4636.57 4572.77 5593 4700.13 4636.33 47 54 S 28.00 W 1.48 1754.02S 1113.49W 47 35 S 27.40 W .56 1816.28S 1146.17W 47 24 S 27.80 W .38 1878.35S 1178.62W 48 0 S 29.70 W 1.59 1940.59S 1212.77W 48 0 S 28.90 W .63 2002.16S 1247.32W 2077.60 2147.66 2217.44 2288.27 2358.76 5689 4764.18 4700.38 5785 4828.17 4764.37 5880 4892.10 4828.30 5975 4957.07 4893.27 6071 5023.03 4959.23 48 17 S 29.00 W .32 2064.73S 1281.94W 48 5 S 32.00 W 2.34 2126.38S 1318.24W 47 17 S 33.80 W 1.63 2185.37S 1356.40W 46 24 S 33.60 W .96 2243.03S 1394.85W 46 47 S 34.50 W .80 2300.82S 1433.91W 2430.12 2501.62 2571.87 2641.16 2710.89 6167 5088.44 5024.64 6263 5152.61 5088.81 6357 5215.63 5151.83 6452 5280.35 5216.55 6537 5338.00 5274.20 47 17 S 34.50 W .52 2358.73S 1473.71W 48 47 S 33.90 W 1.63 2417.77S 1513.83W 47 0 S 33.80 W 1.92 2475.69S 1552.68W 47 5 S 33.10 W .55 2533.71S 1591.01W 47 30 S 33.60 W .64 2585.89S 1625.35W 2781.12 2852.48 2922.20 2991.72 3054.18 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-45I 500292245400 NORTH SLOPE COMPUTATION DATE: 3/22 /94 DATE OF SURVEY: 031694 MWD SURVEY JOB NUMBER: AK-MW-40025 KELLY BUSHING ELEV. = 63.80 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6643 5409.34 5345.54 6739 5473.26 5409.46 6834 5536.58 5472.78 6930 5600.94 5537.14 7025 5664.88 5601.08 47 54 S 33.80 W .40 2651.11S 1668.85W 48 35 S 35.70 W 1.65 2709.95S 1709.67W 47 47 S 35.40 W .87 2767.56S 1750.85W 48 0 S 33.90 W 1.18 2826.16S 1791.34W 47 24 S 31.80 W 1.75 2885.17S 1829.45W 3132.57 3204.13 3274.85 3346.03 3416.28 7121 5730.10 5666.30 7215 5794.21 5730.41 7310 5858.82 5795.02 7395 5916.51 5852.71 7491 5981.68 5917.88 47 0 S 33.60 W 1.44 2944.44S 1867.50W 47 0 S 35.90 W 1.79 3000.91S 1906.68W 47 17 S 35.70 W .35 3057.40S 1947.42W 47 12 S 35.40 W .29 3108.19S 1983.71W 47 17 S 35.00 W .32 3165.79S 2024.34W 3486.71 3555.39 3624.93 3687.26 3757.68 7586 6046.10 5982.31 7680 6109.73 6045.93 7777 6175.26 6111.46 7873 6240.12 6176.32 7968 6304.30 6240.50 47 17 S 33.90 W .85 3223.36S 2063.84W 47 30 S 34.30 W .38 3280.66S 2102.63W 47 30 S 35.00 W .53 3339.49S 2143.29W 47 30 S 33.90 W .84 3397.85S 2183.32W 47 30 S 34.30 W .31 3455.85S 2222.59W 3827.46 3896.63 3968.10 4038.83 4108.85 8064 6368.97 6305.17 8159 6432.79 6368.99 8255 6497.39 6433.59 8350 6561.70 6497.90 8446 6627.17 6563.37 47 47 S 32.00 W 1.80 3515.24S 2261.38W 47 47 S 31.00 W .78 3575.24S 2298.15W 47 35 S 32.50 W 1.17 3635.62S 2335.51W 47 12 S 29.90 W 2.06 3695.41S 2371.73W 46 47 S 30.10 W .44 3756.22S 2406.83W 4179.78 4250.14 4321.13 4391.02 4461.16 8541 6692.26 6628.46 8636 6757.41 6693.61 8730 6821.82 6758.02 8826 6887.54 6823.74 8921 6952.87 6889.07 46 42 S 31.70 W 1.23 3815.58S 2442.36W 46 42 S 33.10 W 1.07 3873.96S 2479.41W 46 47 S 30.40 W 2.09 3932.16S 2515.42W 46 47 S 33.20 W 2.13 3991.62S 2552.29W 46 17 S 31.00 W 1.76 4050.03S 2588.94W 4530.32 4599.45 4667.89 4737.85 4806.80 9016 7018.86 6955.06 9111 7085.51 7021.71 9202 7149.74 7085.94 9293 7213.64 7149.84 9388 7279.81 7216.01 45 42 S 30.60 W .70 4108.73S 2623.93W 45 12 S 32.00 W 1.17 4166.57S 2659.09W 45 0 S 29.90 W 1.65 4221.84S 2692.24W 45 47 S 31.10 W 1.29 4277.66S 2725.13W 45 54 S 31.80 W .54 4335.81S 2760.69W 4875.10 4942.78 5007.20 5071.95 5140.10 9482 7344.99 7281.19 9577 7410.86 7347.06 9671 7475.74 7411.94 9765 7540.21 7476.41 9859 7605.15 7541.35 46 17 S 31.30 W .57 4393.53S 2796.13W 45 54 S 31.00 W .48 4452.11S 2831.54W 46 47 S 33.10 W 1.88 4509.75S 2867.63W 46 35 S 32.50 W .51 4567.25S 2904.69W 46 0 S 32.20 W .68 4624.66S 2941.06W 5207.82 5276.25 5344.25 5412.66 5480.61 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-45I 500292245400 NORTH SLOPE COMPUTATION DATE: 3/22 /94 DATE OF SURVEY: 031694 MWD SURVEY JOB NUMBER: AK-MW-40025 KELLY BUSHING ELEV. = 63.80 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9953 7670.03 7606.23 46 42 S 32.70 W .84 4682.05S 2977.55W 10049 7735.93 7672.13 46 35 S 33.10 W .32 4740.66S 3015.47W 10143 7800.76 7736.96 46 12 S 33.80 W .69 4797.46S 3052.99W 10237 7866.35 7802.55 45 17 S 33.90 W .96 4853.38S 3090.49W 10332 7934.33 7870.53 43 17 S 32.20 W 2.45 4908.97S 3126.68W 5548.63 5618.44 5686.50 5753.81 5820.14 10426 8003.46 7939.66 42 0 S 30.10 W 2.05 4963.45S 3159.63W 10521 8075.58 8011.78 39 12 S 29.60 W 2.97 5017.06S 3190.41W 10615 8147.21 8083.41 41 30 S 29.10 W 2.47 5070.10S 3220.23W 10710 8219.33 8155.53 39 42 S 29.00 W 1.90 5124.14S 3250.24W 10803 8291.96 8228.16 37 35 S 32.00 W 3.03 5174.19S 3279.68W 5883.79 5945.54 6006.29 6067.99 6126.02 10897 8366.59 8302.79 37 17 S 35.50 W 2.29 5221.70S 3311.42W 10992 8443.14 8379.34 35 17 S 37.30 W 2.39 5266.97S 3344.77W 11086 8520.04 8456.24 34 54 S 38.20 W .70 5309.70S 3377.86W 11180 8597.04 8533.24 35 5 S 36.60 W 1.00 5352.53S 3410.60W 11274 8674.14 8610.34 34 42 S 35.40 W .85 5396.04S 3442.21W 6183.14 6239.24 6293.07 6346.79 6400.47 11369 8752.89 8689.09 33 17 S 33.80 W 1.75 5439.75S 3472.38W 11463 8831.68 8767.88 32 47 S 35.00 W .88 5482.05S 3501.34W 11556 8910.03 8846.23 32 24 S 33.60 W .92 5523.44S 3529.58W 6453.55 6504.79 6554.87 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6554.87 FEET AT SOUTH 32 DEG. 34 MIN. WEST AT MD = 11556 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 212.58 DEG. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-45I 500292245400 NORTH SLOPE COMPUTATION DATE: 3/22/94 DATE OF SURVEY: 031694 JOB NUMBER: AK-MW-40025 KELLY BUSHING ELEV. = 63.80 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -63.80 .00 N .00 E 1000 998.84 935.04 2.22 N 36.91 W 2000 1995.55 1931.75 47.76 S 83.07 W 3000 2892.60 2828.80 399.57 S 311.33 W 4000 3603.65 3539.85 994.33 S 683.77 W .00 1.16 1.16 4.45 3.28 107.40 102.95 396.35 288.95 5000 4300.61 4236.81 1617.81 S 1037.01 W 6000 4974.31 4910.52 2258.11 S 1404.87 W 7000 5647.95 5584.15 2869.53 S 1819.76 W 8000 6325.92 6262.12 3475.34 S 2235.89 W 9000 7007.69 6943.89 4098.87 S 2618.10 W 699.39 303.04 1025.69 326.30 1352.05 326.36 1674.08 322.03 1992.31 318.23 10000 7702.27 7638.47 4710.84 S 2996.03 W 11000 8449.67 8385.87 5270.64 S 3347.57 W 11556 8910.03 8846.23 5523.44 S 3529.58 W 2297.73 305.42 2550.33 252.60 2645.97 95.64 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-45I 500292245400 NORTH SLOPE COMPUTATION DATE: 3/22/94 DATE OF SURVEY: 031694 JOB NUMBER: AK-MW-40025 KELLY BUSHING ELEV. = 63.80 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 .00 -63.80 63 63.80 .00 163 163.80 100.00 263 263.80 200.00 363 363.80 300.00 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST .00 N .00 E .03 S .00 W .53 S .04 W .47 S .41 E .05 S .10 W MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 .00 .00 .00 .00 .00 .01 .00 463 463.80 400.00 564 563.80 500.00 664 663.80 600.00 764 763.80 700.00 864 863.80 800.00 .65 N 2.64 W .70 N 8.29 W 1.17 N 14.19 W 1.94 N 21.09 W 2.37 N 27.79 W .05 .05 .21 .16 .39 .18 .63 .24 .86 .23 964 963.80 900.00 1065 1063.80 1000.00 1165 1163.80 1100.00 1265 1263.80 1200.00 1365 1363.80 1300.00 2.27 N 34.44 W 2.10 N 41.50 W 1.43 N 46.89 W .13 N 51.47 W 2.32 S 54.56 W 1.08 .22 1.33 .25 1.48 .15 1.59 .12 1.67 .08 1465 1463.80 1400.00 1565 1563.80 1500.00 1665 1663.80 1600.00 1766 1763.80 1700.00 1866 1863.80 1800.00 5.48 S 56.60 W 10.07 S 58.11 W 16.42 S 61.09 W 24.20 S 65.79 W 32.46 S 71.80 W 1.74 .07 1.86 .12 2.12 .25 2.53 .42 3.06 .52 1967 1963.80 1900.00 2069 2063.80 2000.00 2172 2163.80 2100.00 2277 2263.80 2200.00 2384 2363.80 2300.00 43.45 S 79.86 W 58.72 S 90.59 W 80.16 S 104.23 W 108.14 S 119.65 W 141.78 S 138.28 W 3.99 .94 5.73 1.74 8.94 3.21 13.93 4.99 21.10 7.16 2494 2463.80 2400.00 2606 2563.80 2500.00 2721 2663.80 2600.00 2840 2763.80 2700.00 2963 2863.80 2800.00 179.43 S 163.82 W 220.62 S 192.37 W 267.86 S 223.26 W 321.10 S 259.00 W 380.68 S 299.49 W 30.97 9.88 42.84 11.86 57.70 14.86 76.50 18.81 99.77 23.27 3091 2963.80 2900.00 3225 3063.80 3000.00 3365 3163.80 3100.00 3507 3263.80 3200.00 3651 3363.80 3300.00 448.49 S 341.06 W 127.58 27.80 524.85 S 388.05 W 161.91 34.33 607.40 S 441.17 W 202.05 40.14 691.91 S 496.28 W 244.11 42.06 779.33 S 549.87 W 287.34 43.23 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-45I 500292245400 NORTH SLOPE COMPUTATION DATE: 3/22/94 DATE OF SURVEY: 031694 JOB NUMBER: AK-MW-40025 KELLY BUSHING ELEV. = 63.80 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3796 3463.80 3400.00 3941 3563.80 3500.00 4087 3663.80 3600.00 4231 3763.80 3700.00 4373 3863.80 3800.00 868.68 S 605.33 W 958.28 S 660.27 W 1047.23 S 718.79 W 1137.67 S 769.58 W 1227.59 S 815.67 W 332.46 45.12 377.55 45.08 423.63 46.08 467.75 44.12 509.94 42.19 4517 3963.80 4661 4063.80 4805 4163.80 4947 4263.80 5092 4363.80 3900 4000 4100 4200 4300 .00 .00 .00 .00 .00 1318.02 S 864.63 W 1409.31 S 913.46 W 1498.80 S 965.63 W 1585.03 S 1018.00 W 1676.61 S 1070.32 W 553.38 43.44 597.32 43.94 641.31 43.99 683.37 42.06 728.72 45.35 5241 4463.80 5389 4563.80 5538 4663.80 5688 4763.80 5838 4863.80 4400 4500 4600 4700 4800 .00 .00 .00 .00 .00 1773.47 S 1123.82 W 1870.51 S 1174.49 W 1966.87 S 1227.76 W 2064.36 S 1281.73 W 2159.85 S 1339.34 W 777.88 49.16 826.15 48.27 874.90 48.75 924.62 49.72 974.45 49.82 5984 4963.80 6130 5063.80 6279 5163.80 6427 5263.80 6575 5363.80 4900 50OO 5100 5200 5300 .00 .00 .00 .00 .00 2248.91 S 1398.76 W 2336.72 S 1458.58 W 2428.38 S 1520.96 W 2518.78 S 1581.28 W 2609.34 S 1640.93 W 1020.95 46.51 1066.86 45.91 1116.18 49.32 1163.88 47.70 1211.39 47.51 6724 5463.80 6874 5563.80 7023 5663.80 7170 5763.80 7317 5863.80 5400 5500 5600 5700 5800 .00 .00 .00 .00 .00 2701.23 S 1703.41 W 2792.03 S 1768.24 W 2884.18 S 1828.84 W 2974.43 S 1887.65 W 3061.79 S 1950.57 W 1260.90 49.50 1310.72 49.83 1359.61 48.89 1406.61 47.00 1453.55 46.94 7464 5963.80 7612 6063.80 7760 6163.80 7908 6263.80 8056 6363.80 5900 6000 6100 6200 6300 .00 .00 .00 .00 .00 3149.92 S 2013.23 W 3239.28 S 2074.53 W 3329.24 S 2136.11 W 3419.30 S 2197.74 W 3510.40 S 2258.36 W 1500.83 47.29 1548.29 47.46 1596.23 47.94 1644.25 48.02 1692.50 48.25 8205 6463.80 8353 6563.80 8499 6663.80 8645 6763.80 8791 6863.80 6400.00 6500.00 6600.00 6700.00 6800.00 3604.51 S 2315.81 W 3697.38 S 2372.86 W 3789.88 S 2426.50 W 3879.63 S 2483.11 W 3970.47 S 2538.45 W 1741.36 48.86 1789.29 47.94 1835.70 46.41 1881.51 45.81 1927.52 46.01 SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/4-45I 500292245400 NORTH SLOPE COMPUTATION DATE: 3/22/94 DATE OF SURVEY: 031694 JOB NUMBER: AK-MW-40025 KELLY BUSHING ELEV. = 63.80 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE 8936 6963.80 6900.00 4059.83 S 2594.83 W 1973.02 9080 7063.80 7000.00 4148.03 S 2647.51 W 2016.39 9221 7163.80 7100.00 4234.03 S 2699.25 W 2058.08 9364 7263.80 7200.00 4321.77 S 2751.99 W 2101.20 9509 7363.80 7300.00 4410.35 S 2806.36 W 2145.43 VERTICAL CORRECTION 45.50 43.37 41.69 43.12 44.23 9653 7463.80 7400.00 4499.09 S 2860.69 W 2189.76 9799 7563.80 7500.00 4588.29 S 2918.10 W 2235.54 9943 7663.80 7600.00 4676.49 S 2973.98 W 2280.11 10089 7763.80 7700.00 4765.33 S 3031.57 W 2325.75 10233 7863.80 7800.00 4851.24 S 3089.06 W -~- 2369.58 44.33 45.78 44.58 45.63 43.83 10372 7963.80 7900.00 4932.46 S 3141.46 W 2408.69 10505 8063.80 8000.00 5008.62 S 3185.60 W 2441.93 10637 8163.80 8100.00 5082.93 S 3227.36 W 2473.35 10767 8263.80 8200.00 5155.39 S 3268.22 W 2503.45 10893 8363.80 8300.00 5219.97 S 3310.19 W 2529.70 39.10 33.24 31.43 30.09 26.25 11017 8463.80 8400.00 5278.60 S 3353.63 W 2553.52 11139 8563.80 8500.00 5333.78 S 3396.66 W 2575.57 11261 8663.80 8600.00 5390.20 S 3438.06 W 2597.63 11382 8763.80 8700.00 5445.71 S 3476.37 W 2618.25 11501 8863.80 8800.00 5499.01 S 3513.20 W 2637.41 23.82 22.05 22.06 20.63 19.16 11556 8910.03 8846.23 5523.44 S 3529.58 W 2645.97 8.56 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ARCO Alaska, Inc. Date: Subject: From/Location' Telephone: To/Location: P.O. Box 100360, Transmittal #: 94054 July 6, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution JUL I 1' 'f g4 .4~ska Oil & Gas COns. Cornn~ission Anct~ora~Le · I Well !Number (4-0 i 1-05ST · Ocr ! 1-17 Z'q !2-20 ,2. [ 2-28 ~.q i 3-2 ~* i 4-2 ~9' ! 4-30ST '~q i 4-40 t% i 4-43 !0 ! 4'44 · ~.u i 4-45 fo'~ //i 5-03A · \i 5-03A %¢ 5-03A ~.7_.. i 6-8 Loq;, ! 6-12A '[~ ! 7-6 9-30ST 9~t-~t%Z ¢ 11-29i ~~ i 12-23 1t5% 14-39 ~ 14-39 ff -lu2 ! 16-28 Log Date i Tool Type i Run, (M-D-Y)! I Scale 6-21-94 i Prod Prof i 1,1"&5" 6-20-94 !/ Prod Prof 6-18-94 i/IBP Setting Rec i 1, 5" 6-28-94 i/Leak Detection i 1,2"&5" 6-22-94 ,.['" Leak Detection i 1,1 "&5" 6-17-94 P"' Patch Set Rec i 1, 5" 6-25-94 i / Perf Rec i 1, 5" 6-25-94 i .,/ Peri Rec i 1,5" 6-23-94 I /' Comp Rec I 1, 5" 6-20-94-! / PerfRec Contractor SCH SCH SCH SCH SCH SCH SCH SCH SCH ~ 1 SCH 6-25-94 !,/' Perf Rec i 1, 5" SCH SCH 6-9-94 i " CDN i 1,2" &5" 6-9-94 i /' Slim1 GR ! 1, 2"&5" 6-9-94 i -/ CDR i 1, 2" &5" 6-17-94 i/Leak Detection ! 1,1" & 5" 6-29-94 i "' Perf Record 6-15-94 i f TDTP SCH 6-19-94 i.. Perf Rec 6-21-94 ! f Perf Rec 6-22-94 ] f Perf Rec 1 5" 1 5" 15" 15" 5" 1 15" 1 5" SCH SCH 1 5" SCH SCH 6-24-94 ! .-- Perf Rec SCH 6-28-94 !/ Perf Rec SCH SCH 6-29-94 i "" Dual Burst 6-22-94 I -'"' Prod Prof i'"' Perf Rec 6-27-94 6-28-94 i'"' Inj Pmf 6-27-94 i~"Leak Detection 6-27-94 t ~- Inj Prof SCH SCH SCH : SCH SCH 1, 5" SCH 1, 5" SCH 1,5" SCH 6-28-94 i~' InjProf i I 5" 6-27-94 ! ~' Prod Prof ! 1, 5" 6-30-94 I ~ Perf Prof i 1, 5" 6-15-94 i /' CNL i 1, 5" 6-19-94 I '1_eak Detection i 1, 1" &5" 6-19-94 ~ Leak Detection i 1, 2" 6-20-94I "PerfRec i 1, 5" SCH SCH SCH SCH SCH SCH SCH * DS# 04-02 The APl# is 50-029-20088-00 Number of Records: 35 ARCO Ala$1m, Inc. Is a Subsi~ary of AtlanflcRIchfleldCornpany ARCO Alaska, Inc. Date: Apr 22, 1994 Subject: From/Location: ARCO Open Hole Finals John E. DeGrey/ATO.- 1529 Telephone: (907) 263-4310 To/Location' Distribution Well Nurr~er 01-09A 01-09A 01-09A 01-09A 04-45 9-34A Log Date (M-D-Y) \i Tool Type Run, Scale 03-17-94 i "Dual Lateroloc~ ! 1. 2"&5" 03-17-94 i" SSTVD i 1, 1"&2" 03-17-94 ~/ BHCA/GR ! 1. 2"&5" 03-17-94 i'" CNL/GR : 1. 2"&5" 03-18-94 'MWD/TVD:DGR, ¢ EWR-P4 ' 03-18-94 /'MWD/MD:DGR, EWR-P4 03-30-94 vMWD/MD:GRC, ~ EWR,FXE 1. 2"&5" 1. 2"&5" 1-7, 2"&5" Contractor Atlas Atlas Atlas Atlas Sperry Sperry Sperry 9-34A 03-30-94i ,,MWD/TVD:GRC, 1-7, 2"&5" Sperry · : ¢ EWR,FXE 9-34A 04-19-94 iv' Slimhole 1,2" Sperrv 12-13A 03-31-94 i,," MWD: SSTVD 1. 1"&2" Atlas 12-13A 12-13A 12-13A 13-31 03-31-94 i,,/ BHCA/GR 03-31-94 i,,/' CNL/GR 03-31-94 ~ Dual Larerolo,g 04-14-94 i,/MWD/MD:GRC, ~ EWR,FXE 04-14-94 i,,'MWD/TVD:GRC, 03-31-94 13-31 13-35 13-35 03-31-94 i M91WD/MD:GRC, i EWR,FXE : ¢'I;¢IWD/TVD:G RC, EWR,FXE :,/ Slimhole ¢MWD/MD: DGR, CNP,SLD ' ,,,MWD/TVD: DGR, CNP,SLD v~/IWD/'TVD: DGR, EWR,FXE I/MWD/MD: DG R, EWR,FXE 15-07A 15-33 15-33 15-33 1. 2"&5" 1. 2"&5" 1. 2"&5" 1, 2"&5" 1, 2"&5" 1, 2"&5" 1, 2"&5" , 2" 1-9,2"&5" 1-9, 2"&5" 1-20 2"&5" 1-20 2"&5" 15-33 03-15-94 03-29-94 03-29-94 03-29-94 03-29-94 * ~/includes spiral notebook and disk ** DS#15 logs are Pilot Hole Atlas Atlas Atlas Sperry Sperry Sperry Sperry Sperry Sperry Sperry Sperry Sperry Number of Records: 22 4~.~ ~,, & 8~ Cons Co~io~ ARCO Alaska. Inc. Is a Subsl~ary of AtlantlcRIchfleldCompany : ARCO Alaska, inc. Date' Subject' From/Location: Telephone: To/Location: P.O. Box 100360, Anchorage, A'K May 10, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Transmittal #: 94037 99510,4~ ~ Gas Cons. Distribution i Well i Number OWDW- cb- 2_q 0 ------~' NW _~__~ OWDW- CO' 2--'5cl . SE 1-2 1-17 1-24A Log Date i Tool Type i R un, Contractor (M-D-Y)! ~ Scale 04-30-94 Pump-in Temp i 1 5" Sch ~ ' Sch 04-30-94 i Pump-in Temp 04-19-94 i CNL J 04-20-941 / TDT-P 04-07-94] /- TDT-P 2-18 2-19 04-17-94 ]/ Prod Profile 2-25 2-34 2-35 3-17 3-17 3-21 °04-08-94 i / Perf Record ; 04-16-94 i--' Perf Record 04-18-94 if Bridge Plug 04-19-94 i--- Prod Log 04-12-94 i~- Prod Profile 04-27-94 i/Injection Profile 1,5" 5" 5" 1.5" "&5" :' 1,5" 04-1 9-94 ~ ;/ Perf Record i 1, 5" 04-20-94 i f Perf Record .04-14-94 i f Leak Detect 1, !' 1"&2"&5" Sch { Sch i Sch : Sch [ Sch ~ Sch ~ Sch ~ Sch ~ Sch Sch Sch ~; Sch Sch Sch ~~ 4-29 ------ -i' 4-33 i 4-44 : 4-44 4-45 i 4-45 4-46 5-10 I 5-15A. 5-15A 5-35 6-6 ~ F 6-14A ~ i 6-14A * : 6-22A' ~ 07-23 i 07-23 04-29-94 i/'Injection Profile 04-12-94 ! ~ USIT 1,5" 04-14-94 ! /' CNTG 04-24-94 ! ~ CNTG 04-24-94i /- TDT-P 04-22-94 I ~Perf Record 04-13-94 t'~ Leak Detect 1 5" Sch 04-14-94 i /'~ TDT-P i Sch Sch 04-25-94 i / CTU Prod Log 04-26-94 I -" TDT-P 04-16-94 ~ -~ Leak Detect 04-17-94 i,~'~ Completion 04-08-94 i~ TDT-P 1 5" -15" 1 5" I 5" I 5" Sch : 1~ 5II Sch 1, 2"&5" Sch 1, 5" Sch Sch 1, 5" Sch i 1, 5" Sch ! Sch ! 5II 1~ 5II 04-19-94 ~.~- Completion ~ 1 5" Sch ~ 04-27-94 i ~'Perf Record ! 1, 5" Sch Sch 04-13-94 i -~Patch Record 04-16-94 i ~'~Leak Detect 1, 2"&5" Sch 7-24 12-09-93 i ~ TDT-P ~ 1, 5" Sch :.' 7-24 04-18-94 i ~-~ InjProfile i 1 5" Sch ' 9-1 Sch : 04-12-94 i-~ Patch 04-23-94 i ,.~Patch Record 511 1~ 5II 1~ 5II · ~ 9-9 04-20-94 i -'-Inject Profile Sch Sch ARCO Alaska, Inc, is a Subsicllary of Al/~n'dcRIchfleldCompany ARCO Alaska, Inc. Date' Apr 14, 1994 P.O. Box 100360, ,i .,;horage, AK Transmittal #: 94034 99510,~ ~, Subject- ARCO Cased Hole Finals From/Location: Telephone: To/Location: John- E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well Number Log Date~ Tool Type (M-D-Y)! 01-09A 01-1 01-33 03-02 03-19 o3-29 ' _o3-2 o3-31 ~ /04-43 04-43 ~ %04-43 04-44 04-45 05-08 06-19 07-08 07-23 09-01 09-02 09-03 09-19 09-27 11-04 11-24A 12-06A i 13-20 14-03 14-23 /14-28 ~L-I~ 14-28 ~ ~14-28 14-35 16-04A 16-18 16-28 8-0 Run, Scale : 03-28-94 J TDT-P 03-27-94 i¢- Perf Record 04-02-94 ~,/' Perf Record 1, 5" 03-25-94 ! TDT-P ~ 1, 5" 1 5" Leak Detection 03-22-94 03-22-94 !,,- Bridge Plug 03-18-94 ~ Leak Detection , 03-27-94 i,/ Bridge Plug · 03-27-94 i./' Bridge Plug 03-29-94 iv" TDT-P 03-29-94 i/ CNTG 03-1 0-94 i ,/' USIT 03-13-94 iv' USIT 03-29-94 i¢- USIT Cement 03-14-94 !-,' Prod Profile 03-18-94 i¢' Perf Record 04-03-94 i-' Perf Record 03-21-94 1'/ Bridge Plug 03-30-94 i,,' Prod Profile 03-17-94 i-/ Prod Profile 03-29-94 i / Prod Log 04-01-94 !,," Perf Record 03-16-94 i/ Prod Log 03-22-94 ! / Perf Record 1 5" 1 2" 1 5" 1 5" 1 5" 1 5" ' 1 5" 1 5" 1 5" 1 5" 1 5" ~ 1 5" i 15" !' 1 5" ! 1 5" 1, 1"&5" 03-16-94 ! ,,' Patch setting] 03-29-94 i./ Perf Record 1, 1"&5" ; 1,5" 1, 5" 1, 5" : 1,5" 03-18-94 i- Prod Profile 1, 1"&5" Leak Detection 1, 1"&5" CNL Prod Profile 03-15-94 03-28-94 i ~' ! 5II 03-19-94 ! -/ 1, 1 "&5" 03-15-94 !,,' Leak Detection ' 1, 5" 03-28-94 iv~ 1, 5" : 1,5" . o,,;,~ ~,. /~'$¢ Contractor b'e Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Patch Setting 03-21-94 !/ Brid~le Plu~ 03-17-94 !¢' CNL Sch ' 1 5" Sch 03-15-94 i,,-- Perf Record i 1, 5" Sch 03-14-94 i¢-'Leak Detection 1, 2"&5" ' Sch 03-14-94 i ,/ Perf Record i 1, 5" Sch 03-20-94 i,/ TDT-P Sch Number of Records: 38 ARCO Alaska. Inc. Is a Subsidiary of AtlanflcRIchfleldCompany ~.. March 1, 199'4 : Terry Jordan. ~;~ - Drilling Engineer Superviso~. ARCO Alaska, Inc. .~. P 0 Box ~966~2 Anchorage, AK 99519-6612 -?~ ' Re: Prudhoe Bay Unit 4-45? ~CO Alaska, Inc. Permi~ No: 94-34 ~:. WALTER J. HICKEL, GOVERNOR 3001 PORcuPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Sur Loc 594'SNL, 449'WEL, Sec 34, TllN, R15E, UM · - Btmho~0 Loc. 1084'SNL, 1209-'EWL, ..Sec. 3, T10N, R15E, UM ,~ ~ ~. Dear Mr. Jordan: Enclosed.is the approved aPPlicatiOn fo~ permit to drill the above referenced ~ell '~ '~ ' - · The permit, to drill does n0~ exemp~ you~..from obtaining additional permits ~equired by law from other' governmental agencies, and does not ~ authorize conducting drilling oper~tio~ until all other required · permitting determinations ~e made~ .. The blowout' prevention eq~£pment "(BOP~) must be:. tested in accordance with 20 g.~h.C 25.035~ and th~' mechanical ¢integrity (MI) of the injection -. '~ wells must be demonstrate~ under~ 20 .AAC 25.412 and 20 25.030(g)(3). ': Sufficient ~otice (approx~mately~ 24 hours) of' the MI test before · · operation, ~nd of the BO~ test.j.perf~rmed before drilling below the surface 'ca~ing shoe, must-~.be given so that a ·:representative of the :-- Commission may witness the .~ests. ~Noti~ may be given by contacting the · Commission petroleum fiel~ inspector~ on the ~orth Slope pager at · ~ .. '"~ 659-3607; . .. . David ~.' ..... ~;. . Chairman. · · ( BY-ORDER; OF THE COMMISSION.:~ '' · · 't~ ';- .~ :~. dl'f/Enclosures · ~- cc: Department of Fish &~Game, Habita~ Section ~/o encl ~. ¥~ ' · . D~partment of Environmental ~Conse~vation w/Q encl ~_ .~ .. .~?~ _ ..~ ' · STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work Drill [] Redrill r-Illb. Type of well. ExploratoryF'i Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen FII Service [] Development Gas [] Single Zone [] Multiple Zone [] -2,-Name-of~©perator &-Datum-Elevation(DF-or-KB) .... I10. Field and.Pool ARCO Alaska, Inc.. KBE = 64.8 feet Prudhoe Bay Field/Prudhoe 21 Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADL 28328 4. Location of well at surface 7. Unit or property Name I11. Type Bond(s,,e 2o ,~c 25.025) 594'SNL, 449' WEL, SEC. 34, T11N, R 15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 953' SNL, 1290' EWL, SEC. 3, TION, R15E 4-45 U-630610 . . At total depth r...c~~mate spud date Amount 1084' SNL, 1209' EWL, SEC, 3, TION, R15E --~/7'/9~ I $200,000.00 12. DiStance to nearest 13. Distance to nearestw~eI-F''h4~r of acres in property 15. Proposed depth (Ma property line ADL28325.1084' feet 4-6-397'@ 11803'MD feet 2560 11921'MD/9192' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (s,,e 2o ^AC 25.035 Kickoff depth ~5o~ feet Maximum hole an~le,~¢.8 o Maximum surface 3330 psig At total depth (TVD) 8800'/4590 psi~ 18. Casing program Setting Depth s~ze SpecificationS Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) .. 30" 20" 91.5# H-40 Weld 80' 32' 32' 112' 112' 260 sx Arcticset (Approx.) 12-1/4" 9-5/8" 47# NT8OLS NSCC 3904' 31' 31' 3935' 3562' 1012 sx CS IIl/375 sx "G"/250 sx CS II ~1/2" 5-1/2" 17# !L80/N80 BTC/LTC 11871' 30' 30' 11901' 9075' 827sx Class "G" 1'9. To be completed for Redrill, Re-ent~:y, and Deepen' Operations. ,Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate . Production ~:~!~ ~)' 5 Liner ~,~ .... ~, 0il & Gas C;on$. Commission Pedoration depth: measured Al]ch0rage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirementsl-I 21. I hereby certify tha~ the foregoing is true and correct to the best of my knowledge Signed ~V~/¢/~V~.¢]_ _ Title Drilling Engineer Supervisor Date E- Commission Use Only Permit 'Number 1APl number IApproval date ISee cover letter .~/~'.~ J50-O~¢- .~z ~--~J'~ J J-/-/~¢' Jfor other requirements Conditions of approval Samples required [] Yes 'J~ No Mud log required []Yes [] No Hydrogen sulfide measures [] Yes ~ No Directional survey required 'J~ Yes [] No Required working pressure for BOPE FI2M; 1-13M; 1~SM; FI10M; 1-115M; Other: Original Signed By by order of Approved by David W. Johnston Commissioner [ne commission Datei.~./~ FOrm 10-401 Rev. 12-1-85 Submit in~ cate I Well Name: IDS4-45i Well Plan Summary Type of Well (producer or injector): I WAG INJECTOR Surface Location: Target Location: Bottom Hole Location: 594' FNL 449 FEL S34 T11N R 15E UM 953'FNL 1290'FWL S03 T10N R15E UM 1084'FNL 1209'FWLS03 T10N R15E UM I AFE Number: 1 4J0250 I I Estimated Start Date: I 3/7/94 IMD: 111,921' I Well Design (conventional, slimhole, etc.): I Rig: ] Nabors 28E I Operating days to complete: I 15 ITVD: 19,192' I IRTE: !64.8' [ Ultra-Slimhole Lon~string Formation Markers: Formation Tops TVD (brt) MD (brt) K-15 4917 5881 K-10 7332 9348 K-5 7932 10210 LCU/SAG RIVER 8484 11002 SHUBL1K 8502 11028 TSAD/Ivishak 8572 11129 Zone 4A/X-Ray 8643 11228 Zone3 8719 11331 D Zone2/2C 8772 11401 Zone 2B/Tango 8822 111466 Zone 2A/Romeo 8927 11598 Zone 1B/L. Romeo 8972 11653 Top HOT 9042 11739 ........ ,,~. Cu[nmlssi, Base SAD/Kavik 9052 11751 ......... TD 9192 11921 Casing/Tubin,, ['rogram: Hole Size Wt/l Hole Size' Csg/ - WtTFt Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 Weld 80 32/32 112/112 12-1/4" 9-5/8" 47# NT-80LS NSCC 3904 31/31 3935/3562 8.5" 5-1/2" 17# L80/N80 BTC/LTC 11871 30/30 11901/9075 N/A 3-1/2" Coil 0.20Y' LB0 Equiv N/A (+/-) 7071 29/29 (+/-) 8000/6393 Tubin~j Well Plan Summary Page 1 Logging Prol [ _Open_HoleLogs: Cased Hole Logs: ;ram: ~L_'~5~_.xG R~md3Les/sfivity fromzhe~ase_S AD ~o200 '...abo ye TS AD .......... USIT/CBL from TD to 200' above K15 CNGT, TDT, GR from the base SAD to 200' above TSAD Mud Program: [Special design considerations [None. Surface Mud properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.5 200 30 30 40 9 15 to to to to to to to 9.2 300 60 60 80 10 25 Intermediate Mud Properties: [ Density Marsh Yield 10 sec 10 rain pH Fluid (PPG) Viscosity Point gel gel Loss N/A N/A N/A Production Mud Properties: ] Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel ...gel Loss 9.0 25 8 3 "'7 8 4 to to to to to to to 9.8 50 13 10 15 10 10 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: I 1501'@ 2.5 deg/100' [ Maximum Hole Angle: ] 4S.8 DEG Close Approach Well: 4-06: 397' @ 11,803' MD. The above listed wells will be secured during the close approach. RECE]VED Well Plan Summary DS4-45i CEMENT PLAN- BJ Casing Size: Circ, Temp,: Spacer: Lead Cement: 9-5/8" SURFACE CASING 9-5/8", 47# 38°F 50 bbls fresh water ahead of lead slurry Coldset III Additives: Weight: Yield: Retarder 12.2 ppg 1.92 cufVsx Tail Cement : Class G Volume (sacks): 1012 Mix Water: 10.5 gps Thickening Time: > 4 hrs @ 50°F Volume (sacks): 375 Additives: Weight: Yield: Top Job: Coldset II Additive: Weight: Yield: Cement Volume Summary: 2% A-7, FP-6L lghs 15.8 ppg Mix Water: 5.0 gps 1.15 cuft/sx Thickening Time: >3-1/2 hrs @ 50°F Retarder 15.6 ppg 0.95 cuft/sx Volume (sacks): 250 Mix Water: 3.7 gps Thickening Time: >2 hrs @ 50°F (1) Lead slurry to surface w/ 100% excess (2) Tail slurry volume: 375 sx, (to cover at least 500' of casing shoe w/100% excess + 80' shoe vol.). (3) Top job volume 250 sx (fixed volume) 5-1/2" LONGSTRING CASING Casing Size: circ. Temp.: Spacer: 5-1/2", 17# 140°F 70 bbls of MCS-4 Spacer weighted 1 ppg above current mud weight Lead Cement: Class G Additives: Weight: Yield: Fluid Loss: Volume (sacks): 463 A-2: 3%, FL-52: 0.4%, CD-32: 0.5%, FP-6L: lghs 11.0 ppg Mix Water: 20.92 gps 3.31 cuft/sx Thickening Time: >5 hrs @ 140°F 150-250 cc Free Water: 0.0 cc Tall Cement: Class G Additives: Weight: Yield: Fluid Loss: Cement Volume Summary: Volume (sacks): 364 A-2: 0.1%, FL-52: 0.3%, CD-32: 0.5%, FP-6L: lghs 15.8 ppg Mix Water: 4.85 gps 1.14 cuft/sx Thickening Time: 3.5 - 4.5 hfs @ 140°F 100-150 cc Free Water: 0.0 CC (1) Lead Slurry to 500' MD above top of Cretaceous (top of K15 @ 5881' MD) with 30% excess (2) Tail Slurry to 600' MD above Top of Sadlerochit (top of SAD @ 11,1 29 MD) with 30% excess plus 80' of 5-1/2", 17# capacity for float joints RECEIVED Operations Summary DS 4-45i ....... 1: ..... MlRLT-d~fll~ng rig. NTU'-d[~e~rt~r---an-d functisrf'-~e§t-same. . Drill 12-1/4" hole to surface casing point. Run and cement 9-5/8" surface casing. Nipple up BOPE and function test same to 5000/250 PSI. . PU 8.5" BHA and RIH. Test casing to 3000 psi for 30 minutes. Drill 10' new hole and perform leak-off test. . Drill 8.5" hole to TD. Wiper Trip, Primary Plan is to Icg with LWD (Gamma/4 phase resistivity) from 200' above TSAD to Base of Same. not, then secondary plan is to Wireline Log .-- Back Up Drill Pipe Conveyed. Perform Conditioning Trip after Wireline Logs. . Run and cement 5-1/2" production casing-- Bump Plug with filtered Seawater. Test casing to 3500 psi for 30 minutes. 6. Back out Landing Joint, Run & Test Packoff to 5000 psig. . RIH w/2.875" DP to 2000' and Displace Filtered Sea Water w/diesel for freeze protection. POOH L/D 3-1/2" drill pipe. o Freeze protect top 2000' of 5-1/2" x 9-5/8" annulus with 60/40 methanol water mixture with corrosion inhibitor. 9. ND BOP's, N/U Tree and Test same. 10. Release Rig. 11. MIRU wireline unit run cement bond Icg to 500' above TSAD. RDMO wireline unit. 12. MIRU Coil Tubing Unit and perform Coil Tubing Completion. Anticipated BHP: Maximum AntiCipated BHP: Surface Pressure' Planned Completion Fluid' 3480 psi @ 8800 sstvd 3480 psi @ 8800 sstvd 2600 psi 8.6 ppg Sea Water Notes: a. The drilling fluid program and surface system will conform to the regulations set fo~h in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). c. Based on previous logs at Drill Site 4, no potential produc!~ive zones are anticipated above 8572 TVD RKB (TSAD). !;( ~ ~' I~iV 1~ D FEB £B '9~ 10:03AH ALASKA Prudhoe Bay Prudhoe Bay Drill Site 04 04-45 04-45i WP3 Drilling Unit VERTICAL ¥1~ SCALE 500 £t. / BIV]SION TVD REF; WELLHEAD VERTICAL SECT[ON REF: W~LLHEAD ~00-- ~ I.OO' e (aa~a S0' ~ ~.OD' ff ~a~ ~ - ' 139S ~ 3000 -- 2.~00 -- ¢000 -- ,$0~ -- 4917-- HALLIBURTOH DRILLIHG / ~ ~500 :/; tn m, a 3;:: .=, ::~; tva ~O0~~ 35C0 ~OO ~5C0 ~CO0 1500 :C~O 5~0 0 500 I ' ~ I CA~ING ~IqT DATA RECE1VED ' - ..... ~D 9095 1T ~ I V5 ~g.55 Chec~e~ ~y , Oas Oons. Commissio~ . A~chorage ......... ~e -- -- ' ~' Q 9~ ~ K-I~ ....... ~ , , , [OOq 3500 4000 4500 ;OCO 5500 On'no 6500 7Doo IOCO~ P. 2/18 HALLIBURTD~ 14 O R { 2-O NTA L--V[I~.W--(?R UE -NORTH) ................................ SCALE 500 ft. / DIVISION SURVEY REF: WELLHEAD --lDO0 ~,000 I I VCRTICAL SECTION PLANE: 212,06 FEB 23 -'~4 10:09AM ALASKA HALLIBURTOH DRILL1HG ?m ud,qo._ Bay Pr~ ~dl,-,oe Bo.y ~d:.'~iLL Si~e 04 04-45 04-45i VP3 TraveLL;n~ Cyl;nder - No~?~_P~one ~eCe~ce gelJ - 0~-45 ALI ~ireC~ions ~el ~o True ,' / 2 400 E~ EgO h'.lq/l~ HALLIBURT3N ~/~Sf94 805 n~ ?~lo x\ \ \ 60* O~O~ \ C~T'r,'C.~ ,=r.'.~h.'T T,,,pTA Pr uolhoe Bay Pr udhoe :Bey D~i~L Si~e 04 04-45 04-45~ WP3 Tr'~velJ, ln© Cyllmdep - Nor, mo/ Prone Re~er~ence ~ell - 04-45; Wp3= ND~ 0 - 1180~ ~, in~enva~ ~0 C~, Att ;l~ectlons Del ~o True No~h ~70° // · -% 550 45CI HALLIBURTON ~/~/g4 8(t6 am O~OB ~0 RECEIVED WELL PERMIT CHECKLIST oo,. COHPANY ADMINISTRATION D~TE / 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ....... ENGINEERING WELL NAME GEOL AREA PROGRAM: exp [] dev [] redrll [] serv~ ON/OFF SHORE 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ............... ~ N Surface casing protects all known USDWs ........ ~ N CMT vol adequate to circulate on conductor & surf csg.~ N CMT vol adequate to tie-in surf csg to next string.. .Y CMTwill cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. ~ N If a re-drill, has a 10-403 for abndnmnt been approved. Adequate wellbore separation proposed .......... ~ N If diverter required, is it adequate .......... ~ N Drilling fluid program schematic & equip list adequate .~ N BOPEs adequate ..................... ~ N BOPE press rating adequate; test to ~ psig~ N Choke manifold complies w/API RP-53 (May 84) ....... Y Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............. Y GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N~/_ 31. Data presented on potential overpressure zones ..... Y N~ _ 32. Seismic analysis of shallow gas zones .......... ~/~/A/~ ~ 33. Seabed condition survey (if off-shore) ......... / N 34. Contact name/phone for weekly progress reports .... /Y N [explora%ory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. .. No special'effort has been made to chronologically organize this category of information. Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 6703.00 BROWN/GABEL J. CARL ILE D.S. 4-45 /~7 )l) 500292245400 ARCO ALASKA INC. SPERRY-SUN DRILLING SERVICES 03 -JUL- 96 34 liN 15E 64.80 63.80 29.60 OPEN HOLE CASING DRILLERS RECEIVED JUL 0,3 1996 Alaska Oil & Ga~ Gon~. c;om~n Anchorage 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.625 3928.0 8.500 11875.0 MWD - EWR4/GR. SURFACE LOCATION: X=712,398.98 Y=5,951,285.79 LAT=70.16' 11.517" N LONG=148.15' 55.668" W. ALL DEPTHS ARE MEASURED BIT DEPTHS. THE HOLE SECTION FROM 11137 - 11656 WAS DRILLED PRIOR TO LOGGING. FILE HEADER FILE NLIMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 11111.0 RP 11117.0 $ BASELINE CURVE FOR SHIFTS: UNKNOWN CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 11108.0 11111.0 11112.0 11115.0 11124.5 11125.0 11180.0 11180.0 11191.0 11191.0 11200.0 11200.0 11222.5 11222.5 11233.5 11233.5 11245.0 11245.5 11246.5 11248.0 11275.0 11276.0 11290.0 11290.5 11300.5 11303.0 11305.0 11305.5 11318.5 11319.0 11468 . 0 11469 . 5 11475 . 5 11476 . 5 11480 . 0 11479 . 5 11485.5 11486.5 11495.5 11496.5 11501.5 11502.5 11508.5 11509.0 11520.0 11521.0 11540.0 11542.0 11549.5 11550.5 11559.5 11559.5 11569.5 11574.0 11605.5 11607.0 11629.5 11632.0 11662.5 11665.5 11678.0 11680.5 11873.0 11875.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD $ REMARKS: all bit runs merged. STOP DEPTH 11844.0 11854.0 EQUIVALENT UNSHIFTED DEPTH SHIFTED PASS. ALL MWD CURVES WERE SHIFTED WITH GR. BIT RUN NO MERGE TOP MERGE BASE 1 11137.0 11875.0 CN WN FN COUN STAT /? ?SHIFT. OUT $ : ARCO ALASKA INC. : D.S. 4-45 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 MR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 50 Tape File Start Depth = 11875.000000 Tape File End Depth = 11111.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12233 datums Tape Subfile: 2 162 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NIIMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11111.0 EWR4 11119.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11847.0 11857.0 18-MAR- 94 MWD 1.98 3.93 MEMORY 11857.0 11137.0 11857.0 0 .0 .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 8.500 3928.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 9.60 45.0 8.9 90O 5.0 2.100 1.200 1.600 3.100 80.0 142.0 80.0 80.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: CN WN FN COUN STAT : ARCO ALASKA INC. : D.S. 4-45 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 50 Tape File Start Depth = 11876.000000 Tape File End Depth = 11111.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12249 datums Tape Subfile: 3 115 records... Minimum record length: 62 bytes Maximum record length: 998 bytes Tape Subfile 4 is type: LIS O1 **** REEL TRAILER **** 96/ 7/ 3 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 3 JLY 96 ll:31a Elapsed execution time = 0.88 seconds. SYSTEM RETURN CODE = 0 * ALASKA COMPUTING CENTER * . ****************************** . ............................ , ....... SCHLUMBERGER ....... , ............................ , ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 4 -45 FIELD NAME : PRUDHOE BAY BOROUGH · NORTH SLOPE STATE · ALASKA API NUMBER : 50-029-22454-00 REFERENCE NO : 95015 MAR 0 b 1996 ~ & G~ Cons. com~ An~or~e LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE · 97/02/27 ORIGIN : FLIC REEL NAME : 95015 CONTINUATION # : PREVIOUS REEL : CO~94F2TT : ARCO ALASKA INC, D.S. 4-45, PRUDHOE BAY, 50-029-22454-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/02/27 ORIGIN : FLIC TAPE NAME : 95015 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT · ARCO ALASKA INC, D.S. 4-45, PRUDHOE BAY, 50-029-22454-00 TAPE HEADER PR~JDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 4-45 API NI]MBER: 500292245400 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 27-FEB- 96 JOB ArO?4BER: 95015 LOGGING ENGINEER: D. WARNER OPERATOR WITNESS: M. JOHNSON SURFACE LOCATION SECTION: 34 TOWNSHIP: 1 iN RANGE: 15E PTVL: 594 FSL : FEL: 449 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 64.80 DERRICK FLOOR: 63.80 GROUND LEVEL: 29.60 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT)WEIGHT (LB/FT) 9.625 3928.0 47.00 5.500 11856.0 17.00 3.500 9006.0 7.00 2.625 9014.0 6.50 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NU~fBER : DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH .............. $ EQUIVALENT UNSHIFTED DEPTH .......... REMARKS: NO depth adjustments were performed because the first pass of this TDTP log has been declared the depth reference for this well, according to Ted Cahalane of ARCO 26-FEB-96. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION . O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~ff4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11690.0 11106.0 TDTP 11694.0 11106.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 3 RE~iARKS: This file contains TDTP Pass #1 (Base Pass #1). No pass to pass shifts were applied to this da~a. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NO?4B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NOY¢B SAMP ELEM CODE (HEX) DEPT FT 500666 O0 000 O0 0 1 1 1 4 68 0000000000 SIGMTDTP CU 500666 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 500666 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 500666 O0 000 O0 0 1 i 1 4 68 0000000000 SBHN TDTP CU 500666 O0 000 O0 0 1 ! 1 4 68 0000000000 SIGC TDTP CU 500666 O0 000 O0 0 1 1 1 4 68 0000000000 SIBH TDTP CU 500666 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT TDTP 500666 O0 000 O0 0 1 1 1 4 68 0000000000 LCO1 TDTP 500666 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 500666 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 500666 O0 000 O0 0 1 ! 1 4 68 0000000000 FBAC TDTP CPS 500666 O0 000 O0 0 1 1 i 4 68 0000000000 TCANTDTP CPS 500666 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 500666 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 500666 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 500666 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 500666 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PA GE: NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TSCF TDTP CPS 500666 INND TDTP CPS 500666 INFD TDTP CPS 500666 GRCH TDTP GAPI 500666 TENS TDTP LB 500666 CCL TDTP V 500666 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 ! 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 I 1 1 4 68 0000000000 ** DATA ** DEPT. 11694. 000 SIGM. TDTP 23. 606 TPHI. TDTP SBHN. TDTP 47. 849 SIGC. TDTP O. 985 SiBH. TDTP LCO1 . TDTP 2. 819 SDSI. TDTP O. 688 BACK. TDTP TCAN. TDTP 21881 . 879 TCAF. TDTP 7761 . 390 TCND. TDTP TSCN. TDTP 4319. 317 TSCF. TDTP 1532. 040 INND. TDTP GRCH. TDTP - 999. 250 TENS. TDTP 1585. 000 CCL. TDTP 39 378 54 736 138 706 22389 176 1536 569 0 000 SBHF. TDTP TRA T. TDTP FBAC. TDTP TCFD. TDTP INFD. TDTP 40.209 1.855 41.595 6519.060 351.979 DEPT. 11106.000 SIGM. TDTP 14.839 TPHI. TDTP 14.843 SBHF. TDTP 35.228 SBHN. TDTP 48.264 SIGC. TDTP 0.994 SIBH. TDTP 52.882 TRAT. TDTP 1.404 LCO1.TDTP 1.882 SDSI.TDTP 0.302 BACK. TDTP 113.959 FBAC. TDTP 21.752 TCAN. TDTP 28612.336 TCAF. TDTP 15206.236 TCND. TDTP 24992.367 TCFD. TDTP 9119.598 TSCN. TDTP 5833.453 TSCF. TDTP 3100.232 INND. TDTP 1631.867 INFD. TDTP 367.964 GRCH. TDTP 35.031 TENS.TDTP 1540.000 CCL.TDTP 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 97/02/27 {~REC SiZE : i024 FILE TYPE. : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS AFJMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11690.0 11400.0 TDTP 11694.0 11400.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11685.5 11681.5 11677.5 11673.5 11668.5 11665.5 11649.5 11645.5 11644.5 11641.5 11640.5 11637.5 11633.5 11625.5 11624.5 11621 5 11620 5 11617 5 11616 5 11608 5 11604 5 11600.5 11597.5 11596.5 11593.5 11592.5 11589.5 11588.5 11585.5 11584.5 11581.5 11580.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP .............. 88889.0 88886.5 11669.5 11645.5 11641.0 11624.5 11619.5 11616.0 11608.0 11603.5 11599.5 11596.0 11592.0 11589.0 11585.0 11580.5 11684.0 11681.0 11678.5 11674.5 11666.0 11650.0 11646.5 11641.5 11638.0 11633.5 11625.5 11622.0 11617.5 11597.5 11594.5 11589.5 11586.0 11581.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-i996 11:36 PAGE: 11577.5 11573.5 11565.5 11561.5 11560.5 11557.5 11556.5 11553.5 11537.5 11536.5 11533.5 11532.5 11525.5 11521.5 11517.5 11513.5 11501.5 11497.5 11488.5 11484.5 11480.5 11477.5 11476.5 11473.5 11472.5 11469.5 11468.5 11464.5 11461.5 11457 5 11449 5 11445 5 11441 5 11437 5 11433 5 11432 5 11429 5 11425.5 11421.5 11417.5 100.0 $ 11560.5 11556.0 11536.0 11532.5 11488.5 11484.0 11479.5 11475.5 11472.0 11467.5 11463.5 11434.0 101.5 11577.0 11574.0 11566.0 11561.0 11557.0 11553.5 11537.5 11533.0 11525.0 11521.5 11517.0 11513.5 11501.5 11497.0 11477.0 11474.0 11469.5 11461.5 11457.0 11449.0 11444.5 11441.0 11437.5 11433.5 11431.0 11428.5 11424.5 11419.0 101.5 REPU~KS: T.his file contains Borax Pass #1 of the TDTP. The depth adjustments shown above reflect Borax Pass #1 GRCH to Base Pass #1GRCH and Borax Pass #1 SIGMA to Base Pass #1SIG~. All other TDTP curves were carried with 8he SIGMA shifts. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 7 * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500666 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU 500666 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 500666 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 500666 O0 000 O0 0 2 1 1 4 68 0000000000 SBHNTDTP CU 500666 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 500666 O0 000 O0 0 2 1 ! 4 68 0000000000 SIBH TDTP CU 500666 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 500666 O0 000 O0 0 2 I 1 4 68 0000000000 LCO1 TDTP 500666 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 500666 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 500666 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 500666 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 500666 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 500666 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 500666 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 500666 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 500666 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 500666 O0 000 O0 0 2 1 ! 4 68 0000000000 INND TDTP CPS 500666 O0 000 O0 0 2 i 1 4 68 0000000000 INFD TDTP CPS 500666 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 500666 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 500666 O0 000 O0 0 2 1 I 4 68 0000000000 CCL TDTP V 500666 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Lis~ing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: ** DATA ** DEPT. 11692. 500 SIGM. TDTP 22. 595 TPHI. TDTP 45 . 626 SBHF. TDTP SBHN. TDTP 53. 671 SIGC. TDTP O. 095 SIBH. TDTP 67. 944 TRAT. TDTP LCO1 . TDTP 2 . 911 SDSI. TDTP O. 585 BACK. TDTP 142. 361 FBAC. TDTP TCAN. TDTP 19288. 980 TCAF. TDTP 6625. 435 TCND. TDTP 19516. 465 TCFD. TDTP TSCN. TDTP 3801.858 TSCF. TDTP 1305.873 INND. TDTP 1628.411 INFD. TDTP GRCH. TDTP - 999. 250 TENS. TDTP 1495. 000 CCL. TDTP O . 000 52.128 1.934 38.189 5313.741 351.302 DEPT. 11401 . 500 SIGM. TDTP 15. 798 TPHI. TDTP 31 . 416 SBHF. TDTP 52. 892 SBHN. TDTP 73 . 743 SIGC. TDTP O. 042 SiBH. TDTP 110. 509 TRAT. TDTP 1 . 763 LCO1 . TDTP 2. 328 SDSI. TDTP O. 269 BACK. TDTP 119. 023 FBAC. TDTP 23 . 982 TCAN. TDTP 28227. 965 TCAF. TDTP 12127. 539 TCND. TDTP 17705. 199 TCFD. TDTP 6146. 852 TSCN. TDTP 5727.817 TSCF. TDTP 2460.833 I~flVD. TDTP 1648.338 INFD. TDTP 345.792 GRCH. TDTP 31. 703 TENS. TDTP 1410. 000 CCL. TDTP O. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE N~E : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE · 97/02/27 MAX REC SiZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE ArUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE S~4MARY LDWG TOOL CODE START DEPTH GRCH 11690.0 TDTP 11694.0 STOP DEPTH .......... 11400.0 11400.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 11685.5 11681.5 11677.5 11673.5 11665.5 11664.5 11661.5 11660.5 i1657.5 11656.5 11653.5 11649.5 11645.5 11644.5 11641.5 11640.5 11636.5 11633.5 11632.5 11629.5 11628.5 11625.5 11624.5 11621.5 11620.5 11616.5 11613 5 11612 5 11609 5 11600 5 11597 5 11596 5 11593 5 11592.5 11589.5 11588.5 11584.5 11568.5 11565.5 11564.5 11561.5 11560.5 11557.5 11549.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88889.0 88888.5 11665.5 11661.5 11656.5 11644.5 11640.0 11637.0 11633.5 11629.0 11625.0 11620.0 11616.5 11612.0 11600.0 11596.5 11592.5 11589.0 11584.5 11568.5 11565.0 11560.5 11686.0 11681.5 11678.5 11675.0 11666.5 11662.5 11658.0 11654.0 11650.5 11646.5 11642.0 11634.0 11629.5 11625.5 11622.0 11614.0 11609.5 11597.5 11594.5 11590.0 11566.0 11561.0 11557.5 11549.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 10 11545.5 11544.5 11540.5 11537.5 11536.5 11533.5 11532.5 11528.5 11512.5 11508.5 11493.5 11489.5 11481.5 11477 5 11473 5 11469 5 11468 5 11464 5 11461 5 11457.5 11453.5 11449.5 11445.5 11441.5 11433.5 11429.5 100.0 $ 11544.5 11540.0 11536.0 11532.5 11529.0 11513.0 11508.5 11468.5 11464.0 99.5 11546.0 11538.0 11533.5 11493.5 11489.0 11481.0 11477.5 11474.0 11469.5 11461.5 11457.0 11453.5 11449 0 11445 0 11441 5 11433 5 11428 5 99 0 REMARKS: This file contains Borax Pass #2 of the TDTP. The depth adjustments shown above reflect Borax Pass #2 GRCH to Base Pass #1 GRCH and Borax Pass #2 SIGMA to Base Pass #1 SIGMA. Ail other TDTP cu~-ves were carried with the SIGMA shifts. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 LIS Tape Verification LisTing Schlumberger Alaska Compu ting Center 27-FEB-1996 11:36 TYPE REPR CODE VALUE 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** N~qE SERV UNIT SERVICE APi API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 500666 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 500666 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 500666 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 500666 O0 000 O0 0 3 1 i 4 68 0000000000 SBI{N TDTP CU 500666 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 500666 O0 000 O0 0 3 1 1 4 68 0000000000 SIBHTDTP CU 500666 O0 000 O0 0 3 1 1 4 68 0000000000 TRATTDTP 500666 O0 000 O0 0 3 1 1 4 68 0000000000 LCO1 TDTP 500666 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 500666 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 500666 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 500666 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 500666 O0 000 O0 0 3 1 1 4 68 0000000000 TCAFTDTP CPS 500666 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 500666 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 500666 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 500666 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 500666 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 500666 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 500666 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 500666 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 500666 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 500666 O0 000 O0 0 3 1 1 4 68 0000000000 PAGE: 11 ** DATA ** DEPT. 11694 . 500 SIGM. TDTP 22 . 947 TPHI. TDTP 49. 960 SBHF. TDTP 53 . 389 SBHN. TDTP 54. 887 SIGC. TDTP O. 000 SIBH. TDTP 70. 702 TRAT. TDTP 2. O10 LCO1. TDTP 2. 982 SDSI. TDTP O. 565 BACK. TDTP 156. 278 FBAC. TDTP 42. 652 TCAN. TDTP 19835. 602 TCAF. TDTP 6652.251 TCND. TDTP 19393. 141 TCFD. TDTP 5270. 079 TSCN. TDTP 3926. 442 TSCF. TDTP 1316. 808 INND. TDTP 1 665 . 915 INFD. TDTP 372. 029 GRCH. TDTP -999. 250 TENS. TDTP 1530. 000 CCL. TDTP O. 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 12 DEPT. 11399. 000 SIGM. TDTP 15. 603 TPHI. TDTP 31 . 798 SBHF. TDTP 52. 480 SBHN. TDTP 70. 001 SIGC. TDTP O. 053 SIBH. TDTP 102. 641 TRAT. TDTP 1 . 782 LCO1 . TDTP 2. 337 SDSI. TDTP O. 252 BACK. TDTP 126. 918 FBAC. TDTP 22. 691 TCAN. TDTP 29877. 953 TCAF. TDTP 12784 . 576 TCND. TDTP 17906. 563 TCFD. TDTP 6258.538 TSCN. TDTP 5866. 296 TSCF. TDTP 2510. 148 INND. TDTP ! 768. 089 INFD. TDTP 352. 010 GRCH. TDTP -999. 250 TENS. TDTP 1445. 000 CCL. TDTP O. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 G~ma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, TDTP $ REMARKS: NO actual arithmetic average was computed because only one Base pass was logged. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * I~fPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500666 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 500666 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 500666 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 500666 O0 000 O0 0 4 1 1 4 68 0000000000 SBHNPNAV CU 500666 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 500666 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 500666 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 500666 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 500666 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 500666 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 500666 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 500666 O0 000 O0 0 4 i 1 4 68 0000000000 TCAF PNAV CPS 500666 O0 000 O0 0 4 ! 1 4 68 0000000000 TCND PNAV CPS 500666 O0 000 O0 0 4 1 ! 4 68 0000000000 TCFD PNAV CPS 500666 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 500666 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 500666 O0 000 O0 0 4 1 1 4 68 0000000000 INNDPNAV CPS 500666 O0 000 O0 0 4 1 ! 4 68 0000000000 INFD PNAV CPS 500666 O0 000 O0 0 4 1 1 4 68 0000000000 LCO1 PNAV 500666 O0 000 O0 0 4 1 ! 4 68 0000000000 GRCH TDTP GAPI 500666 O0 000 O0 0 ~ 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 14 DEPT. I1694. 000 SIGM. PNAV 23 . 606 TPHI. PNAV 39. 378 SBHF. PNAV 40. 209 SBHN. PNAV 47.849 SIGC. PNAV 0.985 SIBH. PNAV 54.736 TRAT. PNAV 1.855 SDSI.PNAV 0.688 BACK. TDTP 138.706 FBAC. TDTP 41.595 TCAN. PNAV 21881.879 TCAF. PNAV 7761.390 TCND.PNAV 22389.176 TCFD.PNAV 6519.060 TSCN. PNAV 4319.317 TSCF.PNAV 1532.040 INND.PNAV 1536.569 iNFD. PNAV 351.979 LCO1.PNAV 2.819 GRCH. TDTP -999. 250 DEPT. 11106.000 SIGM. PNAV 14.839 TPHI.PNAV 14.843 SBHF. PNAV 35.228 SBHN. PNAV 48.264 SIGC. PNAV 0.994 SIBH. PNAV 52.882 TP~AT. PNAV 1.404 SDSI. PNAV O. 302 BACK. TDTP 113. 959 FBAC. TDTP 21. 752 TCAN. PNAV 28612. 336 TCAF. PNAV 15206.236 TCND. PNAV 24992.367 TCFD. PNAV 9119.598 TSCN. PNAV 5833. 453 TSCF. PNAV 3100.232 INND. PNAV 1631.867 INFD. PNAV 367.964 LCO1.PNAV 1.882 GRCH. TDTP 35. 031 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : 0 O! CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SO~n~ARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 11694.0 11106.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 15 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL TDTP TDTP TDTP TDTP $ $ COLLAR LOG TDTP SONDE GENERATOR TDTP SONDE DETECTOR TDTP CARTRIDGE TDTP TELEM. CART. 12-DEC-94 CP40.2 1714 12-DEC-94 11690.0 11697.0 11120.0 11690.0 1800.0 NO TOOL NUMBER CAL-UB-614 TNG-400 T~-395 TNC-390 ATC-CB-433 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 3928.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID D~..¥SITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEAWATER/BORAX 180.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THEP~fAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): LIS Tape VerificaTion Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 16 REMARKS: TIED-IN TO SWS USIT/GR DATED 29-MAR-94 PUMPED 105 BLS BORAX, 84 BBLS SEAWATER, i 0 BBLS METHANOL. O. 5 BBLS/M RATE WHILE PUMPING GAMMA RAY HOT ON FIRST FILE FROM RESTARTING PASS #1. CHANNEL IS NOT APPARENT. This is the only Baseline Pass available. $ LIS FORMAT DATA * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 i 0 66 1 * * SET TYPE - CHAN ** N~4E SERV UNIT SERVICE API APi API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500666 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 500666 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 500666 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PS1 CU 500666 O0 000 O0 0 5 1 1 4 68 0000000000 SBHNPS1 CU 500666 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PS1 CU 500666 O0 000 O0 0 5 i 1 4 68 0000000000 SIBH PS1 CU 500666 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PSi 500666 O0 000 O0 0 $ 1 i 4 68 0000000000 LCOi PS1 500666 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PSI CU 500666 O0 000 O0 0 $ 1 i 4 68 0000000000 BACK PSI CPS 500666 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 17 NAME SERV ~JNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~KIMB SAMP ELEM CODE (HEX) FBAC PS1 CPS 500666 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPS1 CPS 500666 O0 000 O0 0 5 1 1 4 68 0000000000 TCAFPS1 CPS 500666 O0 000 O0 0 5 ! 1 4 68 0000000000 TCND PS1 CPS 500666 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD PS1 CPS 500666 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PS1 CPS 500666 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PS1 CPS 500666 O0 000 O0 0 5 1 1 4 68 0000000000 INND PS1 CPS 500666 O0 000 O0 0 5 i 1 4 68 0000000000 INFD PS1 CPS 500666 O0 000 O0 0 5 ! 1 4 68 0000000000 TENS PS1 LB 500666 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 500666 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 500666 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11700.000 SIGM. PS1 25.414 TPHI.PS1 41.253 SBHF. PS1 SBHN. PS1 45.311 SIGC. PS1 0.413 SIBH. PS1 48.980 TRAT. PS1 LCO1.PS1 2.970 SDSI.PS1 0.706 BACK. PSI 126.094 FBAC. PS1 TCAN. PS1 23027.125 TCAF. PS1 7753.175 TCND. PS1 22367.133 TCFD.PS1 TSCN. PS1 4372.973 TSCF. PS1 1472.369 INND. PS1 1611.549 INFD.PS1 TENS.PSI 1610.000 GR.PS1 85.063 CCL.PS1 0.000 35.086 1.908 39.269 6455.684 351.424 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01COi DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE ' FLIC VERSION · 001C01 DATE · 97/02/27 ~REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 18 FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCR~"~ENT: 0.5000 FILE SUM~UL~Y VENDOR TOOL CODE START DEPTh' TDTP 11694.0 $ LOG= HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPT~ CONTROL USED (YES/NO): STOP DEPTH 11400.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL TDTP TDTP TDTP TDTP $ $ COLLAR LOG TDTP SONDE GENERATOR TDTP SONDE DETECTOR TDTP CARTRIDGE TDTP TELEM. CART. BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHEPJ~ OR THERMAL): MA TRIX: 12 -DEC- 94 CP40. 2 1714 12-DEC-94 11690.0 11697.0 11120.0 11690.0 1800.0 NO TOOL NUMBER ........... CAL-UB-614 TNG-400 TND-395 TNC- 390 ATC-CB-433 3928.0 SEAWATER/BORAX 180.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 19 MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT_ RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: TIED-IN TO SWS USIT/GR DATED 29-~LAR-94 P~?4PED 105 BLS BORAX, 84 BBLS SEAWATER, 10 BBLS METHANOL. O. 5 BBLS/M RATE WHILE PUMPING GAMMA RAY HOT ON FIRST FILE FROM RESTARTING PASS #1. CHANNEL IS NOT APPARENT. This is Borax Pass #1. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 !1 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 2 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 500666 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 500666 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 500666 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 500666 O0 000 O0 0 6 ! 1 4 68 0000000000 SBHNPS2 CU 500666 O0 000 O0 0 6 ! 1 4 68 0000000000 SIGC PS2 CU 500666 O0 000 O0 0 6 ! 1 4 68 0000000000 SIBH PS2 CU 500666 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 500666 O0 000 O0 0 6 ! 1 4 68 0000000000 LCO1 PS2 500666 O0 000 O0 0 6 I 1 4 68 0000000000 SDSI PS2 CU 500666 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 500666 O0 000 O0 0 6 ! 1 4 68 0000000000 FBAC PS2 CPS 500666 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 500666 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PS2 CPS 500666 O0 000 O0 0 6 ! 1 4 68 0000000000 TCND PS2 CPS 500666 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS2 CPS 500666 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 500666 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 500666 O0 000 O0 0 6 1 1 4 68 0000000000 INNDPS2 CPS 500666 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 500666 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 500666 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 500666 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 500666 O0 000 O0 0 6 1 1 4 68 0000000000 * * DA TA * * DEPT. 11700.000 SIGM. PS2 22.212 TPHI. PS2 46.817 SBHF. PS2 53.669 SBHN. PS2 53.625 SIGC.PS2 0.196 SIBH. PS2 67.839 TRAT. PS2 1.975 LCOi.PS2 2.919 SDSI.PS2 0.580 BACK. PS2 141.771 FBAC. PS2 35.488 TCAN. PS2 20027.844 TCAF. PS2 6860.694 TCND.PS2 19498.738 TCFD. PS2 5285.335 TSCN. PS2 3861.622 TSCF. PS2 1322.829 INND.PS2 1586.945 INFD. PS2 335.010 TENS.PS2 1460.000 GR.PS2 63.375 CCL.PS2 0.000 DEPT. 11384.000 SIGM. PS2 14.870 TPHI.PS2 30.901 SBHF. PS2 50.205 SBHN. PS2 67.274 SIGC. PS2 0.035 SIBH. PS2 96.069 TRAT. PS2 1.788 LCO1.PS2 2.302 SDSI.PS2 0.267 BACK. PS2 121.617 FBAC. PS2 22.222 TCAN. PS2 31477.090 TCAF. PS2 13671.744 TCND.PS2 18408.492 TCFD.PS2 6487.587 TSCN. PS2 6380.682 TSCF. PS2 2771.382 INND.PS2 1563.050 INFD.PS2 333.912 TENS. PS2 1400.000 GR.PS2 25.953 CCL.PS2 0.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 21 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION · O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION · O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NIIMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O. 5000 FILE VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 11694.0 11400.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL TDTP TDTP TDTP TDTP $ 12-DEC-94 CP40.2 1714 12-DEC-94 11690.0 11697.0 11120.0 11690.0 1800.0 NO COLLAR LOG TDTP SONDE G~¥ERATOR TDTP SONDE DETECTOR TDTP CARTRIDGE TDTP TELEM. CART. TOOL NUMBER CAL-UB-614 TNG - 400 T~VD - 3 9 5 TNC- 390 ATC-CB-433 LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 22 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BOREHOLE COIv-DITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) ~ 3928.0 SEAWATER/BORAX 180.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NOP~ALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): RE~APJ<S: TIED-IN TO SWS USIT/GR DATED 29-MAR-94 PUMPED 105 BLS BORAX, 84 BBLS SEAWATER, 10 BBLS METHANOL. O. 5 BBLS/M RATE WHILE PUMPING GAfV~IA RAY HOT ON FIRST FILE FROM RESTARTING PASS #1. CHANNEL IS NOT APPARENT. This is Borax Pass #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 23 * * DATA FORMAT SPECIFICATION RECORD * * ** SET TYPE - 64EB ** I~fPE REPR CODE VALUE 1 2 3 73 4 66 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 ! 4 65 15 66 16 66 0 66 66 0 66 0 92 1 0.5 FT i1 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV O~IT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 500666 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 500666 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 500666 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 500666 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS3 CU 500666 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 500666 O0 000 O0 0 7 ! 1 4 68 0000000000 SIBH PS3 CU 500666 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 500666 O0 000 O0 0 7 1 1 4 68 0000000000 LCO1 PS3 500666 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 500666 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 500666 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 500666 O0 000 O0 0 7 1 1 4 68 0000000000 TCANPS3 CPS 500666 O0 000 O0 0 7 1 1 4 68 0000000000 TCAF PS3 CPS 500666 O0 000 O0 0 7 1 1 4 68 0000000000 TCND PS3 CPS 500666 O0 000 O0 0 7 1 ! 4 68 0000000000 TCFD PS3 CPS 500666 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 500666 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 500666 O0 000 O0 0 7 1 1 4 68 0000000000 iNND PS3 CPS 500666 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS3 CPS 500666 O0 000 O0 0 7 1 1 4 68 0000000000 T~¥S PS3 LB 500666 O0 000 O0 0 7 i 1 4 68 0000000000 GR PS3 GAPI 500666 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 500666 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape VerificaTion Listing Schlumberger Alaska Computing Center 27-FEB-1996 11:36 PAGE: 24 ** DATA ** DEPT. 11700.000 SIGM. PS3 SBHN. PS3 54.781 SIGC. PS3 LCO1.PS3 2.895 SDSI.PS3 TCAN. PS3 19166.289 TCAF. PS3 TSCN. PS3 3787.763 TSCF. PS3 TENS. PS3 1510.000 GR.PS3 22.892 TPHI.PS3 0.065 SIBH. PS3 0.581 BACK. PS3 6621.296 TCND.PS3 1308.542 INND.PS3 61.250 CCL.PS3 46.553 SBHF. PS3 70.462 TRAT. PS3 158.167 FBAC. PS3 19179.098 TCFD.PS3 1686.646 INFD. PS3 0.000 DEPT. 11378.000 SIGM. PS3 13.669 TPHI.PS3 30.384 SBHF. PS3 SBHN. PS3 69.130 SIGC. PS3 0.041 SIBH. PS3 100.764 TRAT. PS3 LCOi. PS3 2.319 SDSI.PS3 0.206 BACK. PS3 119.851 FBAC. PS3 TCAN. PS3 32464.520 TCAF. PS3 14001.449 TCND.PS3 17652.285 TCFD. PS3 TSCN. PS3 6416.627 TSCF. PS3 2767.393 INND.PS3 1641.583 INFD.PS3 TENS.PS3 1450.000 GR.PS3 28.266 CCL.PS3 0.000 49.913 1.934 37.836 5284.622 341.946 47. 327 1. 815 22. 809 6284. 091 309. 557 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/02/27 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/02/27 ORIGIN : FLIC TAPE NAME : 95015 CONTINUATION # : 1 PREVIOUS TAPE : COIV~4ENT : ARCO ALASKA INC, D.S. 4-45, PRUDHOE BAY, 50-029-22454-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/02/27 ORIGIN · FLIC REEL NAME : 95015 CONTINUATION # : PREVIOUS REEL COMPIENT : ARCO ALASKA INC, D.S. 4-45, PRUDHOE BAY, 50-029-22454-00 , ~3&N~D gNI&fldWOO V~gV~V , , , ****************************** O0'Lf 0'8[6[ ~g9'6 09'6~ 08'£9 # :aooq~ ;qSJ :dlH~NMO& :%N~OO DNIDDOq X~ 30HOflad 9 /[t/96 : : ~ NOilVRNI&~03 3iqM : NI~IaO 9 t~I/~6 : ~$~0 **** 820~3H qMMM **** Ii:~l ~'66 ['AON-9 but~sI'l uo';~eol~t~a^ a~e~ S: ~m~m~m~ ~mmm~mm~m ~m~mm~m~m~ H~d30 dO~S H~d3Q ~S 3QO~ ~00£ DMO~ O00S'O ;£N3~3~3NI H~djQ I02IO0 : ~00' ~I03 ~ 3NVN 'Sq~NNVHD d&O~ £# SSVd qq~ '~# SgVd QNV ~# SSVd d~O& ~3~aaoJ H~d~O 0£ 3S~B ~H~ SY )E:~I ~66t-AON-9 :OJDDOq 3~¥0 :~QOD qO0~ D~Oq S~IH~ ~0~ ~AMflD 3NI~3S¥~ UOT~e~o~ o~U~T~ ~L~ (UOT~e~ sso~D e~n~eD ~o~neN) e~T~ ~D~g ad~& ~TnTJ ~UTTTT~Q T~A~e~uI ~oq ao& te~e~u! bo~ eo~og ~eTTT~Q - q~ea Te~o& Te~e~ ~uno~g ~o ~ooTj ~T~ea ~o UOT~e~eT3 DUTqeng' &TTe~ ~o uoT~e~eT3 - ~n~ea.~ueue~ee e~gqv ~o~3.pe~neee~ mn~ea ~ueu~m~ea ;o ~n~ep ~ueuem~ea ~eqanN ~eP~O uo~3eN " ~3uno~ ebuea d!qsu~o& "uo~30.eS, ~eqaaN TeT~eg la~ emeN.TTe~ ~6-ad~-S~ LI:EO '069ii ~ 8*~g £~ OdV ~3gg~3H 3I~P ~£~ vgn I&~N 3dOqg H&~O'N NNO3 emeN PTeT& ~g 30HOfiad I~3O NqVA # O& &~iHg O~ O30IAOad e~ X~B ¥~D 3NIq3S~a ON H~d30 3NiqMg¥~ TE:~ ~66g'AON'9 bUT3STq uoT3e~I.~aA eOe~ ~; , 0 g 0 i 99 9I 89 99 SI $~ S9 0 99 89 S*O 89 8 S9 L ~L 9 99 ~ 99 0 99 0 99 · 3flq~A ~OOD ~d~ 3dA& · ~m~~mm~m~m~m~mm~ mm#m~mmmmm:~#mmm#~mmmmmm#mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm uotsua~ ~oe~ns bul~eD"ut .e e~me~' HDaD I02~eO le~ - a~eH~unoD punolb~De~ zo~a~aQ ze~ = g~uno3 pe~a~I~S Ie~o£ ~o~a~aQ ~eaN = s~unoD pa~e!a~ Icao& ~o2oe~oaP ~e~ - s~unoo e~n~oeoIe~o~ ~o~aa~ap ~eeN - s~u[~oo a~n~aeo te~oz (d~Q&] ~o3oe3ep ~e~ - pezAIeue s~uno~ te~o~ Cd&Gl) ~o~e3ep 7eau - pezateue s~unoo ICAO& aVO& zo~e~ep ~e~ - e~bl~ atoqazo~ emOTg ~o uoI~eIAap p~epue~g lgOg mm~m~mmmmmmmmmm~mmmmmmmmmmm~mm~mmmm~mmmmmmmmmmmmmmmmmmmm~mm TEI$I )66I'AON-9 bullstq uoIleo't~t~eA aue~ g~ · £90:88 896.~:E8~ L6L,.8~L6'~ O06.t 06~' 0f&-:666 6~6 96~ 09 ~6 £0~ t80 999~ 969 686~L ~9 t~ ~06 86 O00'09Z~ 9g;.600~8 d£O&'N'~D& 600 8g ~6)'gg d~O~ NDIS O00'glLt! ~mm~mm~m~m~mmmm~m~m~m#m#mmmmmmmm~m~mm#mm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mm oooooooooo e~. ~ ~ ~ ~ o oo ooo oo ~68~ aq d~O~ ~.a~ 000000000'0 89 ~ ~ ~ ~ 0 O0 000 O0 ~68L8~ ~dffD d~G~ HD~D oooooooooo e~ ~ ~ ~ ~ o oo ooo oo ~8~8~ ~ d~ ava~ oooooooooo 89 t g t ~ 0 O0 000 O0 ~6e~8~ ~d~ d&O& ND{H 0000000000 8g ~ ~ ~ ] 0 O0 000 O0 ~e84$~ ~dO dZO* O~Z 0000000000 e~ t ~ ~ ~ o oo ooo oo ~8~8~ ~d~ d,o~ os~z 0000000000 89 ~ ] g ~ 0 O0 000 O0 ~68L8~ ~dD d~O~ ~DS& 00'00000000 8~ ~ ~ ~ ~ 0 O0 000 O0 ~:~ gd~ a*O* a~ 0000000000 ~ ~ ~ ~ ~ 0 O0 000 O0 ~b~:~ ~d~ d:O* O~Z 0000000000 aS ~ i ~ ~ 0 O0 000 O0 ~b8~ g~ ~:0~ 0.~ oooooooooo e~ t ~ ~ ~ o oo ooo oo ~68~8~ ~d~ d~O~ ~v~ 0000000000 89 ~ ~ I ~ 0 O0 000 O0 ~68L8~ ~-ad d~a& ZHd& oooooooooo 89 ~ ~ ~ ~ o oo ooo oo ~8~8~ d~OZ ~va~ oooooooooo e9 ~ ~ ~ t o oo ooo oo ~68~8~ a~ a~ ~a~ 0000000000 8~ t ~ ~ ~ 0 oo 000 oo ~6e~8~ ~: d~o, ~.ag 00°°°°°°°°°°e9 ~ ~ ~ ~ 0 oo 000 oo ~68~8~ n: ~,~, ~ea~ 00000000 ~ t ~ ~ ~ 0 oo 000 oo ~8~ n: d~o~ ~eie 0000000000 ~ ~ ~ ~ ~ 0 oo 000 oo ~8~8~ n: ~,~, ~x~ ~~#m~m~m~m~m~mmm~#~m~m~mmmmmmmmmmmmmmmmmmmm~#mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mm##mm ~E:g'I 966~'AON-9 buI~s~q uo~3eo~eA aoe£ S3 IS Taue Verification Listino =hlumberoer AlasKa ComputinO Center 6-NOV-!gg4 1~:31 PAGE~ 6 FIL~ NA~E : EDTT .001 S~RVICE : FLIC VFRSION : 00lC01 DAT~ : 94/1t/ 6 MAX REC BIZ~ : ~0~4 FILE TYPE : LO LAST FILE : $~* FILE HEADER F!LF NA~E : ~DIT ,002 $~RVICE ! FLIC V~R$ION : O0~C0! DATF' ! 94/lt/ 6 MAX REC SIZE : FILF TYPE : LO LAST FiLE : FIL~ HEADER FiLE ~UMBER: 2 EDITED CURVES ~epth shifted and cl~PDed cu~¥es for each Pass PASS NU~BER~ 2 D~PTH INCREMENT: 0,5000 FILF SUMMARY LDWG TOOL CODE START DEPT~ STOP D~PTH '"'""" TDTP 11715.0 11050,0 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDW~ CURVE CODE~ GRCH P~SS NUMBER: ~ASELINE DEPTH 1715.0 m167~.0 {1678.0 1166~.0 ~1661.5 !1655.0 11647.0 ~1637.o 1163o.n 11617.0 ----------EOUIVALENT UNSHIFTED DEPTH---------- GRCH TDTP 88.. 8,0 88888,0 11715.0 11679,0 {1678.o 1166~,5 11662.0 11655.5 1_1647.5 11637.5 1163~.5 1161.,0 0'sg~]~ O'90ill f'Llilt S'9[£Tt S'88~lt fi~66~tI S' iii 0'38~1t 5'9091l 0'[80([ 0 0 O'$£ilt o 0 O'8~tlI 0 0'89Iit 0 O'lStII 0 O'itltt 0 0 0'9£[II 0 0 0 0'90£1t ~ 0 0 90~li 0 0 ~'989,t ~ 0'969t~ 0 0 ~'~0~[~ 0 0 O'L6~[t ~ 0'66~tt 0 f'909II t i '9 '6 'L '8 '8 9L~I~ t611I 90[t~ 8I£I~ 68EI[ LL~t'[ 88~I~ 96~1[ 66~11 ~85t[ 965T~ bul~sTq uoI~eo~t~aA a~e~ S3 zooT~ ~o~ea ~o uo~eAe~ ~uTqsng ~TTe~ ~o uo~e~eT3 · n~ea ~ueu~ed e^oqv mo~ pe~nsee~ ~o~ · n~ea ~ueue~e~ ;o uoT~e~aT3 ~n~ep ~ueue~ee ~eq~n~ ~ep~O e~eN sseu~T~ uoT~eN e~uT~o~ ~o e~e~g A~u~oD d~qsu~o~ uo~3~eg uo~le~o~ PToTJ · *OCL~ ~ *069~ ~ 8*tg ~ adV ~68L8~ NOS ~ggfl3H 3I~P ~dOq~ H~ON ~NOD emeN lle~ S~ - ~ '9 O e~eN ~ueamoD 'DNZ 'v~gvqv OD~V ' i~30 ~qVA $ $ 0'00~ S'O0~ 0'00~ ~'ot~, O'OtOt; 8 13DVd TE:~T ~66~'AON-9 ~uT~sTq uo~e~aeA ede~ S3 Tape Verification Listing :blumberger AlasKa Computing Center 6'NOV-1994 12:31 TABLE TYPE : CURV DEFI D~PT Depth S~G~ S~ma (Neutron Capture Cross Section) SIGC Sigma Correction SIB~ Corrected Borehole Sigma SDSI Standard deviation of Sigma SPHN Borehole $~gma - Near detector $~HF Boreho!e Sigma - far detector T~AT Ration Total Near to Far counts TPH! TDT POrOSitY TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TD?P) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSC~ Total Selected Counts - Near, Detector TSCw Total Selected Counts - Fa~ Detector INND Inelastic count rate - near detector INFD Inelastic count rate - far detector BAC~ Background Count Rates - Near Detector FBAC Bac~ground~Count~.Rate - Far Detector G~CH Gamma Ray ln~.Caslng ~TENS Surface Tension PAGE{ ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE -.64EB ** TYPE R~PR CODE VAbUE m~m~e~mmm~m~m~mm~m~m~~ 1 66 0 2 66 0 3 73 84 4 66 5 66 6 73 7 65 9 65 1! 66 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 1 tODIO0 ~ NOI~A gOO' ~I03 0f[~666'. I60'8t, OT 0000000000 89' ~ T T ~ 0 O0 000 O0 T68~8~ aq d&a£ SN3£ 0000000000 89 ~ T T g 0 O0 000 O0 T68£8~ l~ d~O$ HD~D 0000000000 89 ~ T T ~ 0 O0 000 O0 I68~8~ ~b 0000000000 89 ~ I I ~ 0 O0 000 O0 T68LS~ 9dD 0000000000 89 ~ I T ~ 0 O0 000 O0 I68£8~ 9dD d£~ Q~NI. 0000000000 89 ~ I I ~ 0 O0 000 O0 T68LS~ gd~ 00000'00000 89 ~ I t g 0 O0 000 O0 T68£8~ 9d3 0000000000 89 ~ l' I ~ 0 O0 000 O0 168£8~ 9d~ 0000000000 89 ~ T T [ 0 O0 000 O0 T68£8~ 9dD 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~6~8~ 9dj 0000000000 89 ~ I T g 0 O0 000 O0 T~8~6~ ~-il~ d~O~ iHd~ 0000000000 89 ~ i I g 0 O0 000 O0 T68LS~ 0000000000 89 ~ T T g 0 O0 000 O0 T68L8~ lid d~Q~ 0000000000 89 '~ I I ~ 0 O0 000 O0 I68£8~ fid 0000000000 89 ~ T T ~ 0 O0 000 O0 TB8£8~ fid d~O$ i909 0000000000 89 ~ t t ~ 0 O0 000 O0 168~8~ fid 0000000000 89 ~ I I ~ 0 O0 000 O0 t68£8~ aD 0000000000 89 ~ I T ~ 0 O0 000 O0 I68£8~ aD 0000000000 89 ~ T I g 0 O0 000 O0 T68LS~ ~J (X~X) 3ODD ''w~q3 d~g B~fl~ QOW ~VqJ ~dA£ DOq # ~3Q~O T~:~T ~66T'AON-9 Je~ueb ~UT%ndmo~ e~Sel¥ ~eS~aqanTq: ouT~sT~I UOl~eOt~T~al ace~ g] o'LgsII O'[SSII O'Ltg;; S'8LglI 0°L89~ mmMmmIi 0'86~tt S'609I[ 0'6~9tI 0°g99tI ~'8L9tI S'[89/t $'889It 0'98888 mmmmmmm 0'~09I~ ~'909I[ 0'609Ii S'9t9T~ 0'~£95~ 9~ 0 6891~ S:969t[ 0 8888~ $ O'OSO{; O:StL;~ mm~m~mmm mmmmmmmmmmm mmmmmmmmmmmmmm 000~'0 ;£NMMMHDNI H~dMG 3qla O'L90*~ 0'gLOt[ ~'960[[ ' l£gI I O'~90II ~'L9OI[ ~'LSOIt o'8911[ O'16tII O'8g~II 0'gLglI O't6gI[ 0'90ill i'69[tt O,~SO S,L90 0,£90 80 O'LSO 0'960 O'lOt O'itl ~9~ Lg~ 08t L~ '£~ 16~ aO~ 9O[ LIE 69E ~0~ ~0~ 66~ (UOT~Oag ssozD a~n~deD uoz~ne~) emoT~ ~g~g la,a~ puno~g ~o ouTqsng RTTa~ ~o uo~e,aT3 ~' anaea ~ueue~ed_eAoq~ ae~ep ~ueue~e~ ~eq~nN ~ep~o ..caen sseu~T~ uoT~eN aeueu uo~oag ~aq~nN eeN TTaM 9 6~ ~a qD3 8~£9 Z~ 8'~9 &d qgW ~V~d I68L8~ NOg 3dOSg fl~ON 3ST ,mOD 'DNI '~g~q¥ ODaV aD # 'ONq 'gDag I~ ~gqd O~ HD~D E# SgVd DNI~3IX~'l# 05 O3$D~OD X&daO ~ 9gVd ~Ia~ *i# ~gVd d~O~ ~0 O'OOI O'EgOtt OiOOI 0 0 li:~l ~66I'A0~-9 =h!umberger AlasKa Co~putln~ Center 6-NOV-1994 12:31 DEFI I8~ Corrected ~orehole Slqma DST Standard deviation of Stoma SBHN Borehole S~gma: Near detector SBHF ~orehole S~.gma far detector TPAT Ration Total Near to Far counts TPHT TOT Porosity TCAN Total counts analyzed - near detector (TDTP) TCAF Total counts analyzed - far detector (TDTP) TCND Total capture counts - Near detector TCFD Total capture Counts - far dectector TSCN Total Selected Counts - Near Detector TSCF Total Selected Coumts - Far Detector INNP Inelastic count rate - near detector INFO Inelastic count rate - far detector B~CK BacK,rOUnd Count Rates - Near Detector FBAC Back~round, Count~Rate - Fa~ Detecter G.CH ~amma ~a in,.,Caslng T~N$ Surface ~enslon ** DATA FORMAT SPECIFICATION ~ECORD ** SET TYPE - 64EB ** TYPE REPR CODE VA~UE 1 66 0 2 66 0 4 66 5 66 6 73 7 65 11 66 12 12 68 1] 66 0 14 65 15 66 68 16 66 0 66 1 IS ?ape Yeriflcation Listlno :hlumberger AlasKa Computino Center 6-NOV-1994 12:31 ** SET TYPE - C~AN NRM~ SERV UNIT SERVICE API APl API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP ~LEM. CODE (HEX) D~PT FT 487891 O0 000 O0 0 3 1 ! 4 68 0000000000 $IG~ TDTP CU 487891 O0 000 O0 0 3 t 1 4 68 0000000000 $1GC TDTP CU 487891 O0 000 O0 0 3 1 1 4 68 0000000000 $IBH TDTP CU 487891 O0 000 O0 0 3 I I 4 68 0000000000 SDS! TDTP CU 487891 O0 000 O0 0 3 1 ! 4 68 0000000000 SBH~ TDTP CU 487891 O0 000 O0 0 3 I I 4 68 0000000000 $BHF TDTP CU 487891 O0 000 O0 0 3 ! ! 4 68 0000000000 T~AT TDTP 487891 O0 000 O0 0 3 ! I 4 68 0000000000 TP~? TDTP PU-B 487891 O0 000 O0 0 3 ~ 1 4 68 0000000000 TCA~~ TDTP CPS 487891 O0 000 O0 0 ~ I ~ 4 68 0000000000 TCAF TDTP CPS 487891 O0 000 O0 0 3 ! 1 4 68 0000000000 TCND TDTP CPS 487891 O0 000 O0 0 ) 1 ! 4 68 0000000000 TCFD TDTP CPS 487891 O0 000 O0 0 ~ I ! 4 68 0000000000 TSCN TDTP CPS 487891 O0 000 O0 0 3 t ! 4 68 0000000000 T~C~ TDTP CPS 487891 O0 000 O0 0 ~ ! ! 4 68 0000000000 INND TDTP CPS 487891 O0 000 O0 0 ! ! 4 ~8 0000000000 INFO TDTP CPS 487891 O0 000 O0 0 1 I 4 ~8 0000000000 B~CK TDTP CPS 487891 O0 000 O0 0 ! I 4 68 0000000000 FBAC TDTP CPS 487891 O0 000 O0 0 ) t ! 4 68 0000000000 GnC" TDTP GAPI 487891. O0 000 O0 0 3 ! ! 4 6~ 0000000000 T~N~ TDTP LB 487891 O0 000 O0 0 3 1 ! 4 68 0000000000 DATA D~PT. 1~715.000 $IGN.TDTP $D$I TDTP !.261 $BRN,TDTP TPHI;TDTP 60 085 TCAN.,TDTP TCFD.TDTP 1282~7~! T$CN.TDTP INFD.TDTP 78.5~8 BACK.TDTP TFN$.TDTP 2205.000 35 435 47 398 2272,35 7 7 54 ! 95 lOl BIGC'TDTP TCAF,TDTP TBCF,TDTP FBAC,TDTP 1,301 'SIBH.TDTP _38.630 TRAT.TDTP 57!6'594 TCND.TD?P 204,236 ZMND.TDTP 30.249 GRCH.TDTP 55~.998 3,,693 S72i.,6~0 .446,095 999,250 END OF DATA FTbF NAME : EDIT ,003 SERVICE ~ FLIC VERSION i o0{C0! DATF : 94/ll/ 6 MAX REC SIZ~ : ~024 FILF TYPE : LO L~$T FILE : ao~ peznse~ oo~ · nlea lueue~ed ~o uolle~el~ · nlep ~ueue~ed ~eq~nN ~ep~O eaeN sseu~l~ uol~e~ dtqSu~o$ 168L8~ NO~ NI~ NMO~ $ "NQ~ DNIDDOq dSO& ~0 ~a~N~IN ~d ~OO3 qO0$ 9MG'I ~D~i~A~ NI Q~Qf'tqDNI abel~Ae Dl~eaq~l~e lsluno~ punol~eq Pue AcH emmeD ~ ssed"PellPe pebe~eAe, u~:uo~neN pesind .... '$en~no tie aol sesse~ pe~lpe ~o e§eieae ~lle~q~l~ {uo~2aeN pe~esued~O3 ~QV2H 103~00 : NOI~a~A ~00' ~I~M : 3~VN MqlM ~ 99 9 08 £& £ 0 99 ~ 0 99 T ao~e~e~ ae~ - e~e~'"~unoD punoao~e~ ~o~e~aG ~eeN - se~e~ ~unoD puno~b~e8 ~o~e~eP ze~ = e~e~ ~unoa a]~seleuI ~o%~e~ep ~eeu - e%e~ ~uno~ ~T~sel~uI dNNI ~o~ae~ao ~e~ . s~unoD pa~ele~ ~e~o& ~o~e~eO ~eeN - s~unoD pe%~ele~ ~e~o£ ~o3~e3ep ~eeN- s3uno~ e~n3deo te3o& (d&O&) ~o3~e3, eP ae; - pez~zeue s3uno~ ie~oG (a~) ao33e3ep aeeu . pez~zeue e3unoo ze~ol s3uno3 ~e~ 03 ~eeN Te3o~ uo~ea ~sO~Od &Q~ IHd~ emb~9 atoqa~o8 pe~oa~oD (uo~33a9 ~So~D e~n~deD uo~3neN) emO~ ~elYiaa - q3~e~ lelo& "06g'[; ~ teaeq puno~9 ~'o uo;~eaeI3 9'6~ ~J qD3 , buI3$t,l uot3e3I~aA eoe~ ~3 . 6&9'gg AV~d*~Dg& ~L6 80~ AVNd.'ND ~ S0~'£~ AVNd*~DZg~g9°~£ AVNd*HDI~ O00°~iL~ ~mmmmm~m~mmmm~m~mmmmmmmmmm#~mmmmmmmmmmmmmm 0000000000 89 t ~ ~ t 0000000000 89 t ~ ~ t 0000000000 89 t ~ ~ t 0000000000 89 t t ~ ~ 0000000000 89 ~ t ¥ t 0000000000 89 t I ~ ~ 0000000000 89 t I I ~ 0000000000 89 ~ I ~ ~ 0000000000 89 ~ t ~ ~ 0000000000 89 t I t t 0000000000 89 ~ t ~ ~ 0000000000 89 t I ~ ~ 0000000000 89 t I I t 0000000000 89 ~ t I ~ 0000000000 89 t ~ t t 0000000000 89 t I t t 0000000000 89 9 I ~ ~ 0000000000 89 t ~ t t 0000000000 89 t t ~ t 0000000000 89 ~ i t ~ em~mememmm.m, mmmm.~m#mmmmmemmm~m~#~mmmmmmmmmmmm em~mmmmmmmmmmmmmm#mmmmmmmmmmm~mmm~m~mmmmmm 0 O0 000 O0 ~68&8~ Id~D AVN~ 0 O0 000 O0 ~68L8~ gd~ ^~d 0 O0 000 O0 ~68L8~ gdD A~Nd 0 O0 000 O0 I68L8V gdD AVid 0 O0 000 O0 ~68L8~ gd~ A~d 0 O0 000 O0 ~68L8~ gd3 A~d 0 O0 000 O0 I68L8~ gd~ A~Nd 0 O0 000 O0 I68L8~ ~d3 A~Nd 0 O0 000 O0 I68~8~ ~d3 A~Nd 0 O0 000 O0 t68L8~ ~d~ A~Nd 0 O0 000 O0 ~68L8~ AVNd 0 O0 000 O0 T68L8~ 3-fid AVNfl 0 O0 000 O0 168L8~ ~ AVMd 0 O0 000 O0 i68£8~ ti~ AVNd 0 O0 000 O0 I68~8~ ~ AVNd 0 O0 000 O0 168~8~ fl~ AVM~ 0 O0 000 O0 ~68L8~ ~ elmmllimlmmmmljmjm~mmm~mlJmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm mmmmm~mmmmm#mmmmmmmmmmmmmmmmmm T 99 0 ~ 99 9~ 89 99 ~T 0 99 ET 89 ~T ~ 99 TT ~d ~9 6 TE~ ~66T'AON-9 ON 0'i009 00gO~ O*O~L~I 0'069~ ~'09 d~ /~.~seT u~ ssea puno~b~eq ~e~ lseT$$ (~O~Og O& dO~) 9NIa~ qOO& :(ON/~3A) QMgQ ~Oa~.OO :(~) ~Aa3&NI 90q ~O~OU V~VQ a3QV3H 90q $ O'OgO~[ O'~Lfi H&d3O dO&¢ H&~3Q ~aV[~ 3QO0 '100~ O00g'O I&N~W~DNI H~d~Q 03[00 = NOI~MMA gOO' IOO~[O0 : NOI~MA uo~e~ ~£ ~3~ 9NOD : ~d~£ 3'lg~ # :(NI) 2JOGNV£~ qO0~ :(gdO,)_3q~O~ HDIH 3~ &NaOD ~2 2NOZ ~lO NZ NOZ~VZ~qV~ON ~&~a ~NaOO :(NI) NOI~D2B~OD 2qOH qo0~ 3Ni~B :0l~¥~ ~IO/g~D :(~3 q2A3q :(Ndd) X~INIq~ ~NOIiIONOD 3"lOH3aO~ O'996T[ :(NI) 3Zig £1fl 3qOH N~O ¥£¥~ DNI~VD ON~ 3qOH3aO~ Og :2D~d TE:gT 966['AON-9 :hlumberger lasts Co~,put ng Center R~NC 1SE Ranqe COUN NORTH SLOPE county STAT ALASKA State or Prov~nce NATT USA ,ation WIT. OUblE HEU$$ER Witness Name SON 487891 Service Order NUmber PD FT 0 Elevation of Permanent Datum ~r R~$ 5oq Meesured From APD FT 64,8 Above Permanent Datum .... EKB FT 64,8 Elevat$on of Kelly.Bushing EDF FT 8 Elevat$on of Perric~Floor Total De th Bottom bog lnte:rva! TLI FT Ii05 O~ TOp bog ~nte~val DFT BRINE Prllli6gFluid Type TLA~ . 031:1,7 25-APR-94 Time bogger'a~..Bott~m .. TABLE TYPE ~ CORV D~PT De $TG~ $i~th ma (~eutron Capture Cross Section) STDT Status of TDT ~PH~ TDT Porosity ISHu TDT Shunt Current SFFD Sigma ~ormat~on - far detector (TDTP) SFND Sigma ~ormation -.near detector (~DTP) SBHF 8orehole Sigma - far detector SFHN Borehole Sigma - Near detector FTDT Far TDTM Count Rate NTD~ Near TDT Count Rate AFFD Amplitude formation -- far detector (TDTP) AFFD AmPlitude borehole -- Far detector (TDTP) AFND Amplitude formation - near detector (TDTP) ABND AmPlitude 8orebole -- near detector (TDTP ) $IGC ,Sigma Correction SIBH Corrected Borehole TPAT BACK FBAC TCAN TCAF TCFD TSC~ ~initron mode monitor ratio (TDTP) ~ation Total ~ear to Far counts Standard deviation of Siema ~ac~round Count Rates - Near Detector Background Count Rate - Far Detector Total counts ana]yzed -.near detector (TDTP) Total counts analyzed - far detector (TDTP) Total capture counts - Near detector Total capture Counts - ~ar dectector Total Selected Counts - Near Detector 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 IbSL8~ gd3 0000000000 89 ~ t { ~ 0 O0 000 O0 ~68L8~ ~d3 ~d 0000000000 89 ~ T ] ~ 0 O0 000 O0 I68L8~ gd3 0000000000 89 t T ] 9 0 O0 000 O0 {bSLS~ ~3 0000000000 89 ~ $ ] S 0 O0 000 O0 ~68L8~ i13 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~68L8~ fid 0000000000 89 ~ ~ ~ S 0 O0 000 OU ~bSLS~ ~3 ~d 0000000000 89 9 ~ ~ ~ 0 O0 000 O0 [68L8~ ^ 0000000000 89 ~ ~ [ ~ 0 O0 000 O0 t68LS~ ~d ~gd ~Hd& 0000000000 89 ~ ~ ~ S 0 O0 000 O0 ~68L8~ 0000000000 89 ~ ~ ~ S 0 O0 000 O0 ~68L8~ fid 0000000000 89 t ~ ~ S 0 O0 000 O0 TbS~8~ ~ m#~m~i~m~m~m~mm~mm~m~m~m~mmmmmm~m~mmmmm~mmmmmmmmmm#mmmmmm#mmmm#~mmmmmmmmmmmmmmmmm (X~H) '~OOD 'w~q~ dWVg ~NflN OOW ~gV~D 3dA& gOq # ~0 ~e~emm~e~eeememmme~~m~m~em~mmmm~memmmmmmmmmmmmm~mmmmmmmmmmmm~mm~mmm~m~mm~m~mm ] 99 0 [ g9 89 99 0 99 ET 89 L 99 99 0 99 0 99 mmmmmmemmmm#mmmme#mmmmmmmmmmmm ~fl~A ~OOD ~d~8 3dA& eeemaeem##emaemeeleem#emmmmeemmemmmmmmeemmmmemmmmmmmm#meeee apn~T~m~ q3~ uo~sue£ aoe~n9 Ae~ emmeD Pa~e~oD-idV ~o~oa~ep ze~ - a~e~ ~unoa a;aselaui ~o~oa~ap ~eau - a~e~ ~unoo OT~SeTaU~ ~o~e~eO ~e~ - s~unoD pe~aaleg le~o~ IAgO 000~0;;~ 000~0 000:0 000,0 000 0'. ~£0'0' ;ga l~Og 000~0 ;~d~U~ mmmm~mmm~##mmm~mm#~m~m~mm~mm~m#~mmm~mmmmmmmm~mmmmmmmm 0000000000 89 ~' ; ; ~ 0 O0 0 0000000000 89 t ; ; ~ 0 O0 000 O0 T6 0000000000 89 ~ ; ; ~ 0 O0 000 O0 0000000000 89 t ; ; ~ 0 O0 000 O0 0000000000 89 t ; ; ~ 0 O0 000 O0 0000000000 89 ~ ; ; ~ 0 O0 000 O0 0000000000 89 9' ; ; ~ 0 O0 000 O0 0000000000 89 t ; T ~ 0 O0 000 O0 0000000000 89 t ; ; ~ 0 O0 000 O0 0000000000 89 ~ ; ; ~ 0 O0 000 O0 t6 0000000000 89 ~ ; ; ~ 0 O0 000 O0 0000000000 89 t ; ; ~ 0 O0 000 O0 0000000000 89 t t ; S 0 O0 000 O0 0000000000 89 ~ ; ; ~ 0 O0 000 O0 0000000000 89 t ; ; ~ 0 O0 000 O0 0000000000 89 t ; ; ~ 0 O0 000 O0 0000000000 89 t ; ; ~ 0 O0 000 O0 0000000000 89 t ; ; ~ 0 O0 000 O0 0000000000 89 9 ; ; ~ 0 O0 000 O0 0000000000 89 ~ ; ; ~ 0 O0 000 O0 000'0 igd'q~J g68'L~L[ ISd*~NNI 69L~$0~ ;Sd'~OVg 000~0 EbL II- )gd°ONNi 690*g98£- OtL L; ~m~mmmmm#mmmmmmmm~mmmmmmm O0 O0 ;68L8~ A ; mmmmemmm gd qD3 8L8~ 8q ~gd 8L8~ Id~D '~gd aD 8L8~ gdD ~d 8L8~ gdD ;~d 8L8~ l~d 8L8~ ~D ~gd 8L8~ 9d~ Igd QNaV 8L8~ 9dD ;ga AU~S ~INR A~S IE:~/ )66['AON-9 bu~n [$ ~aDe Verlflcat.ton Listlncj :hlum ergerh AlasKa Computtn~ Center 6-NOV-1994 12:3t PAGE~ 24 **** FILE TRAILE~ **** FILM NAME ~ EDIT ,005 SERVICE : FLIC RSION ~ 001CO1 ATF ~ ~411It 6 M~X REC SIZE : 10~4 FILF TYPE ~ LO L~ST FILE : **** FILM ~EAD~R **** F~LF MA~E ~ ~DIT ,006 SERVICE : FLIC VERSION : 00~CO1 DATE : 94/i~/ 6 MAX REC SIZE : 1024 FIL~ TYPE ~ LO FILE HEADER FILF NUMBER 6 R~W CURVES Curves and log header data for each Pass in separate P~S$ NUMBER~ 2 DEPTH IMC~E~ENT: 0,5000 FILF SUMMARY VENDOR TOOL CODE START DEPT~ STOp.DEPTH .......-... .......... 11715.0 11050,0 LOG HEADE~ DATA DATE LOGGED: SOFTWARE VERSION~ TI~E LOGGER ON BOTTO~ TD DRILLER ~D LOGGER(F ~OP bOG ~NTERVAL (FT): ~OTTOM LOG INTERVAL (FT): LO~GING SPEED DEPTH CONTROL USED (YES/NO)I TOOL ST~IMG (TOP ?O BOTTOm) VENDO~ TOOL CODE TOOL TYPE TDTP THERMAL DECAY TDTP T~ERM~L D~C~Y TDTP T~ERM~L DECAY TDTP T~ERMAL DEC~Y TDTP T~ERM~L DECAY TDTP THERMAL DECAY fi:Les~ raw bacl~eround pass ':l.n .:Last '~ 24-APR-94 CP 40,2 317 11690.0 11720,0 11050.0 il?iL,0 600*0 NO 25-APR-g4 TOOL NUMBER TNG-PB-400 TND-PC-3g5 TNC-PB-3gO ~TC-CB-433 CAL-UB-38! AT~-RA-lgO :hlumberqer lasKa Comput no Center 6-NOV-lEg4 12:31 PAGE:; 25 $ ~OREMObE AMD CASING DATA bO~GERS CASIMG DMPTH (FT)~ ~OREMObE CONDITIONS Fb~ID TYPF~ FLUID DENSITY (LB/G)I SURFACE T~MPERATURE (DEGF)~ BOTTOM HOLE T~MPERATUPE (DEGF): FLUID SALINITY (PPM)I FbUID bEVELw(F~): FLUID RATE AT 'EL HEAD WATER CUTS GAS/OIL RATIOS CHOKE NEUTRON TOOL TOOL TYPE (EPITWERM~L OB THER~AL)~ MATRIX: MATRIX DENSITY: HOhM CORRECTION (IN): BLUrb!NE COUNT RATE NORMALIZATION iN OIL ZONE TOP NORMALIZING WINDOW BASE NORMALIZING WINDOW (FT)~ ~LUEI, INE COUNT RATE SCALES SET BY FIE~D ENGINEER FA~ COUNT RATE LOW SCALE (CPS): FAR COUNT ~ATE ·HIGH SCALE (CPS){ NEAR COUNT R~T~ LOW SCALE WE~R COUNT RATE HIGH SCALE (CPS): · OOb STANDOFF (IM)~ R~M~RKS: TEED IN TO SWS CNT DATED 24-APR-94. LOGGING SPEED AS PER CUSTOMER REOUEST, $ FORMAT DATA 11856,0 BRINE THERMAOb :SANDST NE 2.65 T~BI.E TYP~ ; CONS TUNI VALU DEFI CN ARCO ALASKA, INC. Company Name FW PRUDHOE BAY Field Name IN P.~ 4 - 45 Well Name PIN 50 ~29-22454 API Serial Number FL 594' FNL & 449' FEL rield Location SEC~ 34 Section TOWN I1N Township Tare Verificatio, Listing :hlumberger .~las~a Computtno Center 6-NOV-!g94 12:31 PA~E~ 26 COU, NORTH sLOpE STAT ALASKA NAT! USA SON 487891 PDAT MSL b~F APD FT 64,8 EKB FT 6.4,8 EDF FT 63,8 EEL FT 29 6 TDD FT 1t~90, TO5 ~T II720, BbI FT t171~. TLI FT 110 , DFT B~INE TLAF 03117 25-APR-94 Range Countv Stage, at on or Province Witness Name Service Order Number Permanent datum Elevation o~ Permanent Datum Log ~easured, rrom Above Permanent Datum EleVation o'~ Kelly .Sushin~ Elevation o~ Oerric~ Floor Elevation ot Ground'bevel Tota! Depth - Driller Total Depth - Logger Bottom bog InterVal Top 5og X6terval Drilling Fluid Type Time bo~ger TABLE TYPE : CU~V DEPT STDT TPHT SFN~ F?DT NTDW ABF~ ArND AFND SDS! BACg FPAC TCAN TCAF TCND TCFD TSC~ DePth Sigma (Neutron Capture Cross Section) Status of TDT TDT Porosity TDT S~unt Current 8t~ma formation - far detector CTDTP) Sigma formation -_near detector (TDTP) Borehole Sigma - far detector Borehole Sigma - Near detector Far TDTM Count Rate Near TDT Count Rate Amplitude formation -- far detector (TDTP) AmPlitude borehole -- Far detector (TDTP) Amplitude formation - near detector (TDTP) ~mplitude Rorehole -- near detector (TDTP) Sigma Correction Corrected 8orehole Sigma ,lnltron mode monitor ratio (TDTP) Ration Total Near to.Far counts Standard deviation of SiOma ~ac~oround Count Rates - Near Detector ~ac~oround Count Rate - Far Detector Total counts analFzed - near detector (TDTP) Total. counts analyzed - far detector (TDTP) Total capture counts - Near detector Total capture Counts - far dectector Total Selecte~ Counts - Near Detector 0000000000 89 f ~ ~ 9 0 O0 000 O0 ~bSLS~ gd3 [gd ~JaV 0000000000 89 ~ t ~ 9 0 O0 000 O0 ~6~L8~ ~dD ~d ~&V 0000000000 89 ~ ~ I 9 0 O0 000 O0 I68L8~ gdo ~gd ~O~N 0000000000 89 ~ ~ [ 9 0 00 000 00 [68L8~ gd3 ~d ~O~ 0000000000 89 ~ ~ I 9 0 00 000 00 ~68L8~ ~D ~g~ aHag 0000000000 89 ~ [ ~ 9 0 O0 000 00 I68L8~ £1D ~d ~H6~ 0000000000 89 ~ { [ 9 0 00 000 00 ~68L8~ £13 [~ ON~ 0000000000 89 ~ t ~ 9 0 O0 000 O0 $68L8~ tlD ~gd ~J~9 0000000000 89 ~ ~ ~ 9 0 O0 000 O0 I~8L8~ A ~gd ilH~! 0000000000 89 ~ ~ ~ 9 0 O0 000 O0 168~8~ ll~ ~ IHd~ 0000000000 89 t ] ~ 9 0 O0 000 00 ~68£8~ ~ ~ 0000000000 89 ~ ~ [ 9 0 O0 000 O0 ~68L8~ lID [9~ ~ 0000000000 89 t I '~ 9 0 O0 000 O0 ]b8£8~ ~J ~d~O ~m~m~m~#mmmm~m~m~mm~m~mm~m#mmmmmmmmmmm~m~mm~mmm#mmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmm~ (X~H) 3QOD w~q~ dWV~ gWflN OOW ~g~D ~dA& ~Oq # ~QHO ~m~mm~~m~m~m~mm~~mm~~m~~mm~~mm~m~mmmm~m~m~mm~m~m~~m~ ~ 99 0 I 99 9t 89 99 0 99 89 L 99 ~J S9 6 S~O 89 8 £L 9 99 t 99 0 99 0 99 mm~m~mmmmmm~mm~mmmmmmmmmmmm ~~m~m~mmmmm~mm~mmmmmmmmmmmmmmmmmmmmmmmmm#mmmmmmmm~m~m~ uo~gue£ ooe~n9 Ae~ emmeD Po~oelloO-Id~ ~o~oe%eP Ie~ - ~e~ ~unoo D~eloui ~NI ~o2oe~ep ~eeu - e~e~ ~uno~ o~se~eul ~NNI )[t~) ~66~'AON-9 '~99 zsa'~ 86L'L86 ~gd'&Hag L08.0~ ~gd~O.Jg ~LZ'O~ gd'ZHd~ 000 99 ~gd*&a&g L08*O~ 99g;9I~ 000:99 000'0 9~O'EO) I6~'£b ~00'8~ ~Sd HgIS ~69'9g ggd 000'0 ~Sd~gVa& :L8.'O :gd:,JOW~ 66L'0S ZSd'.~O&N £09:9 zsa:-a Js L.L; p ~Sd:::O~jS ooo'0 ggd'ONNI ~Sd H~I9 gd3O 0000000000' 89 '' ~' I I 9 0 0000000000 89 t g I 9 0 0000000000 89 t t ~ 9 0 0000000000 89 t ~ I 9 0 0000000000 89 t ~ I 9 0 0000000000 89 t I t 9 0 0000000000 89 t t I 9 0 0000000000 89 ~ ~ ~ 9 0 0000000000 89 t I ~ 9 0 0000000000 89 t t I 9 0 0000000000 89 ~ t I 9 0 0000000000 89 ~ t ~ 9 0 0000000000 89 t I t 9 0 0000000000 89 ~ ~ ~ 9 0 0000000000 89 ~ ~ ~ 9 0 0000000000 89 ~ t t 9 0 0000000000 89 ~ t ~ 9 0 0000000000 89 t ~ I 9 0 0000000000 89 ~ t t 9 0 0000000000 89 t ~ ~ 9 0 00' 000 O0 T68L8~ A O0 000 O0 T68L8) Bq O0 000 O0 I68£8f IdVD O0 000 O0 ~68L8~ gdo O0 000 O0 t68L8~ SdO O0 000 O0 ~68L8~ gdo ~Sd O0 000 O0 ~68L8~ 9dD O0 000 O0 ~68£8~ 9dD O0 000 O0 ~65L8~ 9dD O0 000 O0 T68L8~ 9dD ~Sd O0 000 O0 ~68L8~ 9dD ggd O0 000 O0 ~68L8~ gd2 gSd O0 000 O0 ~68L8~ gd3 O0 000 O0 ~68L8~ iiD O0 000 O0 ;U8~8~ O0 000 O0 ~68L8~ ~Sd ~0~ O0 000 O0 ~68L8v fid O0 000 O0 168£8~ FiD 5Sd jgig O0 000 O0 t68/8~ 9d3 ~Sd O0 000 O0 ~08L8~ 9d3 jj~j~j~jjj~j~j~j#~m~~jjjj~j~~m~jj~j~~j~#~ij~jj~j~mj~#~~j~m~ (X~H) ~00~' W~q3 d~¥S ~flN qO~ SgVqD 2dA& 90q # ~080 8~:. l:gDVd tE:gI ~66i=AON-9 bu~3s~q uo~2eo~2ek aoe~ S] , O0~-gd-DN& ~3~N qOO& ON 0'009 00SO~ 0'0~6~ 0'069~ t6-aaV-~ 5'09 aD T~.3ee! UT seed punozb~eq ~eJ ~SeTT) xv33a ~3H~ d~ 3dX& 300£ 3003 900~ (~0~0~ O~ dO£) 9NIa~ ~00~ :(ON/S3X) 0~ ~Oa~NOO :(~J) 9~Aa3~N~ DO~ dO~ :~O£~Og NO a3DDOq :~3DDO~ S O'OSO~ O'S~L~[ m~mmmmm~.~m mmmmmmm~mmm mmmmmmmmmmmmmm~ e3e~e~es u] gsed q~ea ~o~ e3ep ~epe~q boy pue Oq : 3d~ ~qI~ )~0) : 22Ig OMH X~N OZq~ : 33IAa~g LO0' £IOM : 3~VN ~qlA ;03;O0 : ~oz~aa^ 3IqZ : 3DIA~ 900' £IOM : 3NVN MqZM :39Vd £S Tape Veri~icstion Listing :blumbergerAlaska Co~.~putino Center 6-NOV-1994 12:31 PAGEI 30 $ # BOREHOLE AMD CASING DATA OPE~ HOLE BIT SIZE DRILLERS CASIN~ DEPTH CFT): LOGGERS CASING DEPTH MO~EHOLE CONDITIONS FLUID TYPE: FLUID DENSITY CLB/G): SURFACE T~MPERATURE (DEGF): BOTTOM MOLE TMMPE~ATURE FLUID SALINITY FLUId,LEvEL FLUID R ·~ AT ~ELLHEAD WATER CUTS CHOKE NEUTRON TOOL TOOL TYPE (EPITWERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOb~ CORRECTION CIN): BLUEbINE COUNT RATE NORMALIZATION IN OIL ZONE BASE NORMALIZING WINDOW BLUELINE COUNT RATE SCALES $~T BY FIELD ENGINEER FAR COUNT RATE LOW SCALE FAR COUNT RATE HIGH SCALE (CPS) ~E~R COUNT RATE LOW SCALE (CPS): NEaR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF R~MaRKS: TIED IN TO SWS CNT DATED 24-APR-94. LOGG!~G SPEED AS PER CUSTOMER REQUEST. $ LIS FORMAT DATA 11856.0 THERMAL SANDSTONE ~.65 TABLE TYPE TUN! VALU DEF! CN ARCO ALASKA, INC. Company Name FN PRUDHOE BAY FieldName W~' ~,S~~4 45 Well Name APIe ~0-029-22454 RPI Serial Number Fi- 594' FNL & 449' FEb Field Location SEC? 34 Section· TOW~' 11N Township ~o~a~ep ~eeN - ~uno~ a~n~e~ te~o& (~&q~) ~o~a~aP ~eeu - pez~Ieue s~uno~Ie~o~ zo~a~aG Aej - a~e~ ~uno3 punoz~e~ zo~a~aG zeaN - sa~e~ ~uno3 s~unoo 2e~ o~ AeaN Ie~o~ uoI~e~ (a~O&> oT~e~ ~o~Tuom apom uo~TuT~ e~b;g eTo4e~o~ UOT~Oe~oJ e~T~ e~e~ ~uno3 ~ ~eeN ~o~oa~ap AeeN - e~OTg (uoT~oeg sso~D e~n3de~ uo~neN) ~d3Q mmm~mmmm~mmmmmmmmmm~m~mmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm edA& ptnTJ Te,~a~u! eog ~o~oe taAa~ punozg,~o mn~e~ ~ueuem~e~ eAoq~ mn~ea ~ueuea~ea ao uol~eAaT3 an~ep ~uauem~ed ~aqmnN ~ep~O e~e~ sseu~ uoT.~eN ~unoD eOue~ ~ ~ Iq9 o6~ t~ cai [68L8~ NOg 3dOqg H~HON !~:~T ~66g-AON-9 bu~3sTq uoT3e3T~T~eA aoe~ 0000000000 89 ) { ~ L 0 O0 000 O0 I68L8~ ~d~ E~d 0000000000 89 ~ t ~ L 0 O0 000 O0 ~68L8~ ~D [~d 0000000000 89 ~ ] ~ L 0 O0 000 O0 t68L8~ ~dD [~d 0000000000 89 9 ] I L 0 O0 000 O0 t68LS~ ~d3 [~d 0000000000 89 9 ~ ~ L 0 O0 000 O0 I68L8~ ~D ~gd 0000000000 89 9 t ~ L 0 O0 000 OO Ib8L8~ ~D ~gd 0000000000 89 ~ ~ ~ L 0 O0 000 O0 t68L8~ ~1D Egd 0000000000 89 t I I L O O0 000 O0 t6flLS~ ~b (ga 0000000000 89 ~ I ~ L 0 O0 000 O0 168£8~ ^ E~d dX~I 0000000000 89 ~ ~ ~ L 0 O0 000 O0 t68L8~ tld Egd 0000000000 89 ~ t ~ L 0 O0 000 O0 t68L8~ ~gd 00000'00000 89 ~ t I L 0 O0 000 O0 168L8~ lid ggd 0000000000 89 ~ ~ ~ L 0 O0 000 O0 ~b8~8~ ~J ~~#m~.~m~~m~m~mmmmmmm~mm~mmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm#mmmmmmmm~mm (X3H) 3QO~ W~Q3 dWV~ 8~NN QOW ~D ~dA& 90q # ~3Q~O O~ m~amaamaa~maaaa~mmmmmmmmmaammmmmmmmm~mm~aa~mmmmmmmmmmmmmmmmmmm~mmmm~mmmmmmmmmmm~mmmmm mmmam.mmmmmmmmammmmmmmmmmmmmmm #am#ammmammmamaammmammmmmmma#mmmmmmm#mmmamammmmmmmmmmamma~a apn3~Ta~ qOO qj3 uo~sue& a~e)~ng ~N~& ~o3oa3aP ~e~ - a3e~ ~unoo oT~seTaul a~NI :o3oa~ap ~eau - a~e~ ~unoa ~T3seTau~ QNN ~o3aa3aO ~e~ - s3unoD Pa3OalaS te~o~ ~DS& IE:~I 966t'AON-9 bullsTq uo~%eo$~e^ a~e& ~' O00:gSO: ~Lg;;t. Lt OL9 '. 000'0 000'~ ~t~L[t~ OL~'~. 000"0 000'0 ~gd IHB$ 000 "99 ~gB':$Q~: 6LO' t~ ~d '~I~ 009')661{ Egd*uNNI £d~O [gd I'IHSI 0000000000 '89 ) T t £ 0 O0 000 O0 i68L8~ A [gd q33 0000000000 89 ~ ~ ~ L 0 O0 0.00 O0 ~68L8~ flq [~d 0000000000 89 ~ ~ ~ L 0 O0 000 O0 I68L8~ I~D [~d 0000000000 89 ~ T I L 0 O0 000 O0 ¥68L8~ 9dD igd 0000000000 89 t I I L 0 O0 000 O0 168L8~ 9d3 E~d aNN! 0000000000 89 t I i L 0 O0 000 O0 168L8} ~d3 £~d 0000000000 89 ~ I I L 0 O0 000 O0 168L8~ gdD £9d 0000000000 89 ~ I I L 0 O0 000 O0 168£8~ ~d3 [Sd qtDl 0000000000 89 ~ { I L 0 O0 000 O0 168/8~ gd3 [~d ONJI 0000000000 89 ~ ~ I L 0 O0 000 O0 T68L8~ 9dD £gd 0000000000 89 ~ I T L 0 O0 000 O0 168L8~ 9d3 igd 0000000000 89 t t I L 0 O0 000 O0 16818~ gdD [~d 0000000000 89 t I t L 0 O0 000 O0 168£8~ 9dD [Sd 0000000000 89 ~ ~ t L 0 O0 000 O0 168L8~ fid £9d igOg 0000000000 89 ~ I I L 0 O0 OOO O0 I68/8~ [gd 0000000000 89 ~ I ~ ~ 0 O0 000 O0 lbSLS~ ~gd 0000000000 89 ~ I t L 0 O0 000 O0 I68~8~ il3 Egd 0000000000 89 ~ ~ ~ L 0 O0 000 O0 lU8LS~ iiD Egd 0000000000 89 ~ ~ I L 0 O0 000 O0 I68L8~ 9dD igd UNSV 0000000000 89 ~ ~ ~ L 0 O0 000 O0 ~68L8~ 9d3 [~d JljJjJjJjJjJJJJljiJJJlJiJiJJ ' jmmmmmjmmmmmmmmmmmmmJmJJJmmJmjJmJJ iJJJJ buI~sTq uot~eoI~'~'~aA a~e~ S2 Tape Verification Listing ~hl~mberger Alaska Computing Center 6-NOV-1994 I'2:31 . **** FILE TRAIbE~ **** FILF MA~E : EDIT ,007 SERVICE : FL!C VERSION : OO!.COl DAT~ ~ 94/11/ 6 MAX REC SIZE ~ ~024 FIL~ TYPE : LO LAST FILE ~ **** TAPE TRAILER **** S~RVICE NAME : EDIT DATE : 94/11/ 6 TAP~'NA~ : 94314 CONTINUATION ~ : ! P~EVIOU$ TAPE : CO~"ENT : ARCO ALASKA INC.,D.$. 4-45, PRUDM~E BAY, 50-029-~2454-00 **** REEL TRAILER **** S~RVlCE NAME : EDIT DATW : g4/11/ 6 O~IGIN : FLIC EL NA~E : g4~14 uNTINU~TIO~ # : P~EVlOUS RE~b : COMMENT : ARCO ALASKA INC,,D'$, 4-45, PRUDMOE BAY, :hlumi. erger lasKa Computin 26-0CT-] 994 21:.18 **** REEL HEADER **** S~RVICE NA~E : EDIT DAT~ ~ 94/1,0/14 O~ICIN : ~hIC REEL NAME : 94313 CONTINUATION # ~ PREVIOUS REEL : COMMENT : ARCO ALASKA INC., DS 4-45, PRUDHOE BAY, API 50-029-22454-00 **** TAPE HEADER $~RVICE N~N~ ~ EDIT D~TE ~ 94/10/!4 ' T~PF NA~E : 94~13 CONTINU~TIOW # : 1 PREVIOUS TAPE : · CO~ENT : ARCO ALASKA INC., DS 4-45, PRUDHOE BAY, API 50-029-22454-0 T~P~ HEADER PRUDHOE BAY # API NUMBER: OPErATOr: LOGCING COMPANY: T~PF CREATION DATE: JOB ~IlRFACE SECTIONs TOWNSHIP: RANGE: FNL~ FWL: ELEVATION(FT FROM MSL O) KELSY ~USE{IN~: DERRICK FLOOR: GROUND LEVEL: 4 - 45 ARCO ALASKA. ~NC SCHLO~BE~G~ E'L£ SERVICES ~4-0CT-94 94~1~ BAILEY HEtISSER' 34 lin 594 449 64,80 63,80 29,60 WELL CA$IWG RECORD OpEN HOLE CASIng DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST ST~IMG O0 q,625 39~8.0 47 O0 ~ND ST~IWG 00 5,500 11856.0 17:00 ]RD STRING O0 O0 PRODUCTION STRING CURVE SHIFT DAT~ - ALL PASSES TO ST~NDARD(~EASURED DEPTH) ECEIVED JAN 0 5 1995 Oil & Gas Cons. Commisslon Anclmrage $ g'8~O~t 0'669~ mmmmmm~mmm em~mmmmmmmm mmmnmmmmmm~n~ 000~'0 :~N~DNI H£d~O 0 ~ NOI~2A ~09)l) * ~08Eit NO~& g~NflOD B~ ~ B~N Q~ZIqV~BON '~92flO28 ~N~IqD 82~ SV HdJ OOB~ ~ OJDDOq Q2S9~8 32BH~ $ 8%:tg 966~-&30-9~ :~NYd~OO 9NIDDOq :~QOD ~A~D :~OOO qo0~ ~e=uej ~ :lSlrl uoI~eot~'~eA e~e£ S] IS Ta~e Ver.tficstlon List~no :hlum~erqer ~lasXa Comput!nc~ Center $ ~LIS FORMAT DATA 26-0CT-1994 21:t, 8 P~GE: T~B!.,E TYPE ~ CONS TUNI VALU DEF! FN PRUDHOE BA ¥ WN D.$. 4.- 45 APIN 50-029 22454 Fl,, 594' FNL & 449; $~CT 34 TOw~ lin RANC 15E COUN NORTH SLOPE STAr ALASKA NAT! USA APD FI 64,8 EKB FT 64,~ EOF FT EGL FT ~2 ,6 Company Name Field Name well Name APl' Serial Number Field Location Section Township Sta 'or Province .Natton Permanent datum Elevation ~ Permanent Datum boq Peas~red FrO~ Above Per~anen~ Datum., Elevation o~ Kelly.BuShi~ EleVation o~ Derr~c~:Floe~ Elevation of Ground,.bevel ..... TABLE TYPE : CURV D~F! D~PT DePth NPH! Compensated Neutron Porosity, 85 ~atrlx, call & dead time ENPP Epithermal Neutron Porosity CPM! Compensated ~eutron Poro,, $$ matrlx, tool & Environ' Cor~, FCNT ~aw~war Detector Count rate, Dead Time Corrected NCNT ~aw Near De~ector Cou~t ~ate, Dead Time Corrected CWAw ,eutron ~atlo, Dead Time Corrected NPAT Neutron ~atio~ Non-Dead time. Corrected (N/F) ENRA ~Pithermal Neutron Ratlo Calibrated CFTC Corrected Far Detector Count Rate CWTC Corrected Near Detector Count Rate CFEC Corrected Far EPithermal Counts CNEC Correcte~ Near EPitberma! Counts G~CH ~amma ~a~ i~ Casing TENS Surface Tension 0S~'666 O00*O00E 9&NO*IHdD 0S~'666- D£NO*&UBO Of~*666- D&ND*HdNa 0f~'666- DSND:D£~D D~N~'I~dN 0f~'666- 0~Z'666- 0~'666- O00'9[L[t ~ :~DVd ~#~~#mm~m~m~m~mm~mm~mmmm~mmmmmmmmmmmm~m~m~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmm 0000000000 89 ~ 0000000000 89 ~ 0000000000 89 ~ 0000000000 89 ~ 0000000000 89 ~ 0000000000 89 ~ 0000000000 89 ~ 0000000000 89 ~ 0000000000 89 ~ 0000000000 89 t 0000000000 89 ~ 0000000000 89 t 0000000000 89 t 0000000000 89 t 0000000000 89 t t t I 0 I I I 0 I t I 0 t I I 0 t t I 0 I I t 0 t t t 0 I t t 0 t t t 0 t t t 0 I t t 0 O0 000 O0 tb8L8~ Bq D£ND O0 000 O0 168L8~ IdVD DmNO O0 000 O0 168L8~ 9d3 O0 000 O0 T68LS~ 9dD D&ND O0 000 O0 IbSLS~ gdo D~N3 '00 000 O0 I68L8~ gdo D~ND O0 000 O0 i68L8~ 9£ND O0 000 O0 ~68£8~ D~NO O0 000 O0 t68L8~ 00 000 00 t68L8~ gdo 9~NO ~NON O0 000 O0 168£8~ gdo 9~NO £NDJ O0 000 O0 168L8~ g-fid 9&ND IHdO O0 000 O0 168L8~ g-ad O0 000 O0 t68L8~ g'lld DSNO 1ada I t I 0 O0 000 O0 I68£8~ &8 ~m~m~mmm~mm~mm#mmmmmm~mmm 0 99 0 89 99 0 99 89 Lt 99 f9 99 I 99 09 iL £ 0 99 0 99 mmsmm~mm.mmmmmSm, mmm~mmmmJmmmmm 8i:t~ ~66t'&DO-9~ Tape Verification Listing :hlumberger Alaska ¢omput!nO Center 26-0CT-1994 PAGE: E~Rn.CNTG CNEC.CNTG 1!.045,500 329,590 6,446 2537,394 END OF DATA CFTC,, GRC~.C~TG 1419,695 CRAT,CNTG CNTC,CNTG TENS,CNTG 4.$02 NRAT,CNTG 1333.368 CrE:C.CN~G 2455.000 ~ 4,220 393.630 **** FILE TRAILER $*** FIL~ NA~E : EDIT .OO1 S~RVICE ~ FLIC VERSION : 001C01 DATF ~ 94/i0/~4 ~AX AEC SIZE ~ !024 FIL~ TYPE : LO bAST FILE : **** FILE HEADER **** FIb~ NA~E : EDIT .002 'SERVICE : FLIC V~RSION : 001C01 DAT~ ~ 94/10/14 MAX R~C SIZE : 1024 FILF TYPE : LO LAST FILE : FILF HEADER FIL~ ,U~B~R: 2 EDITED CURVES DePth shifted and clipped curves for each pass ~n separate PASS ~U~B~RI 2 DEPTH INC~E~ENT: 0,5000 FILE SUUN~RY [~DWG TOOL CODE START DEmTH STOP DEPTH CNTG ~713.5 ~RCH ~1700.5 11048.5 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) ~ASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~U~B~R: ---- .... --EQUIVALENT UNSHIFTED DEPTH---------- PASELINE DEPTH CNTG GRCH mo~j pa~n~ea~ ..- an~ep aousAo~c] ~o - aDueu uoT~e~o~ pTeIj 8*~g Sa ~dOqg H&~ON ~3J ,6~ ~ ~NJ ,~6g # CiNV 'I ggVd .aO HD~ID 3H& Ol (i313IHg ~M i~ g3Vd HDaD ~HI :g~laVia2 0'00'[ O'OOI 0 O"SgOlt 0 O'~901I 0 0'8~tlI 0 0'98[tl ~ o'goilI 0 g"i8[t~ S 0'~'[ 0 S~6~9T~ S 0'619tt 0 ~'C891t S O'Ot£I~ S 0'88888 S'L8~88 0 :00~ '~90t'~ LT/t~ 18£I~ 6~9tl ~99~g ' 89 ~ 88888 8~:tg ~66t-J, DO-91 ~a2uaj Out2~dmo~ e~seI~ ~ab~aqmflTq: IS Tape Vertffcatlon Llstino :hlumberger AlasKa Computlno Center 26-0CT-1994 21~18 DFPT DeDth NPH! Compensated Neutron Porosity, SS Matrt~, cal!& ~ead time tort, ENPW Eptthermal Neutron Porosity CPM! Compensated ~eutron Poro,, $5 matr~X, tool 9 Environ, Cor~, FCNT Paw Far Detector Count rate, Dead Time Cot~cted NCNT Raw Near De~ector Cou~t ~ate, Dead T~me Corrected CRAT Neutron ~atio, Dead Time Corrected (RN/RF) N~AT geutron ~atlon Non-Dead time...corrected (N/F) ENRA ~plthermal Neutron Ratio Calibrated CFTC Corrected Far Detector Count Rate CNTC Corrected Near Detector Count. Rate CFEC Corrected Far Ep~hermal Counts CNEC Corrected Near Epithermal Counts G~C~ ~amma Ray tn Casing T~NS SurfaceTe ~ ns~on ¸.7 DATA FORMAT SP~CiFICATIO~ ~ECORD ~* ** ~ET TYPE - 64EB ** TYPE R~PR CODE VALUE I 66 0 2 66 0 3 73 6O 4 66 5 66 6 73 7 65 8 68 0 5 1! 66 17 1~ 68 13 66 0 14 65 1~ 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** N~r S~RV U~I~ SE~V!CE API AP! APl ~P! FILE NUMB NUMB SIZE REPR P~OCES$ ID ORDEP ~ bOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) ~mmmmmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~m~m~mmmmmmmmmmmmm~m~m~m DFPT FT 487891 O0 000 O0 0 2 1 1 4 68 0000000000 NPHT CNTG PU-S 487891 O0 000 O0 0 ~ I I 4 68 0000000000 IS Tame verification Llstino :hlumberger AlasKa OomputlnQ Center 26-0CT-~.994 21118 .. m~Mm~mMm~mmm~m~mmm~mmm~mmmmmmmmm~m~mmmm~mm~mm~m)~*Nm~m~~m~mmm~M~)~mm~ ENPH CNTG pU-$ 487891 O0 000 O0 CPHT CNTG PU-8 457891 O0 000 O0 FCN? CNTG CPS 487891 O0 000 O0 NCNT CNTG CPS 487891 O0 000 O0 C~AT CNTG 487891 O0 000 O0 ,PAT CNTG 487891 O0 000 O0 ENR~ CNTG 487891 O0 000 O0 CFTC CNTG CPS 487891 O0 000 O0 CNTC CNTG CPS 487891 O0 000 O0 CFEC CNTG CPS 487891 O0 000 O0 CNEC CNTG CPS 487891 O0 000 O0 G~CH CNTG GAPI 487891 O0 000 O0 TENS CNTG LB 487891 O0 000 O0 0 2 ! 1 4 68 0000000000 0 2 I I 4 68 0000000000 0 2 ! ! 4 68 0000000000 0 2 ! I 4 68 0000000000 0 2 I I 4 68 0000000000 0 ~ 1 1 4 68 0000000000 0 2 1 1 4 68 0000000000 0 2 1 I 4 68 0000000000 0 2 I I 4 68 0000000000 0 2 I 1 4 68 0000000000 0 2 i ! 4 68 0000000000 0 2 1 ! 4 68 0000000000 0 2 1 .1 4 68 0000000000 ** DATA ** DEPT. 11717.500 NPHI'CNTg FCN?,CNTG -999.250 NCNT'~CNT~ ENR~.CNTG -999.250 CFTC~CMT~ CNEC.CNTG -909.250 GRCH'CNT~ END OF OATA ** 99 9.250 ENPH;CNT~ 999,250 CRAT~CNTG 999,250 CNTC,CNTG. -999.250 TENS:~:C~TG 999.250 CPI'{I'CNTG 999,250 NEAT.CNTG -999.250 CFEC,CNTG 2860.O00 "999' 250 -999,250 **** FILE TRAILER FILE NA~E : EDIT .002 SERVICE : WLIC VERSION : 001C01 DATE : 94/10/14 ~X RFC SIZE = 1024 FILE TYPE : **** FILE HEADER **** FILE NAME ~ EDIT ,00~ SFRVICE : FDIC VERSION ~ 001C01 DATE : 04/10/14 M~X RFC 8TZE = 1024 FILE TYPE : LO LAST FILE = FTLF HEADFR :hlumberqer AlasKa Co~putin~ Center 26-0CT-1.994 21:18 pAGE: FILF NUMBER: 3 EDITED CURVES Depth shifted and clipped curves P~SS NU~BER: 3 DEPTH IMC~EMENT: 0.5000 t, DWG TOOt, CODE START DEPTH "iii"'"' ~RCH il CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) ~ASEtIME CURVE FOR SHIFTS 6DWG CURVE CODE~ GRCH PASS NU~BER~ PASELINE DEPTH BBS 678 661 647 638 ~42 1342 1238 1223 1148 1126. 101. 087. 1071. 1063. 1061 105~ !00. ~or each Pass in separate ~iles. STOP DEPTH !1047.0 1!047.0 ~E~ARKS: THE GRCH PASS 3 WAS SHIFTED TO THE GRCH OF PASS 1, AND THE flPH! PASS 3 ~AS SHIFTED TO THE NPHI OF PASS I WITH ALb CNTG CURVFS SHIFTED ~ITH NPHI. $ LIS FORMAT DATA 1163~,0 ~,1524.5 11503.0 11497.0 11482,0 1~365.0 11342,5 1i342,5 11238,5 11223.5 11148.0 1.1126 0 11~01:~ 11087.0 11071.5 1106~.5 11061.5 1105O.0 98.5 100.0 1166~,0 1164 .0 ------=---EOUIVA5EN~ UNSHIFTED DEPTH'--"-'-'-- CNTG GRCH 88888.5 88888,5 ~1679,0 Tape Veriftcat).on Listing :hlumherger Alaska Computing Center 26-0CT-1994 21~t8 PA E: lO TABI,E TYPE : CONS TUN! VALU DEFI ......... C" ARCO ALASKA, INC. FN PRUDHOE BAY W" D.S. 4 45 API~ 50'029'~2454 FL 594' FNL & 449~ F~L SFC~ 34 COUN NORTH sLOpE STAT ALASKA N~T! USA PDAT ESL EPD FT L~F RKB APD FT 64,8 E~B FT 64,8 EDF FT 63,8 EGL FT 29,6 Company Name Field Name Well Name APl Serial Number Field Location Section, Towns~i~ Ranoe County Permanent datum Elevation of Per~anent Datum 5og ~easured From Above ~ermanent Datum .~ ~levatlon o~ Kelly Bushl. n~ Elevation o~ Derric~ Floor Elevation 0£ Ground ~evel~:, ..... TABLE TYPE = CURV DEF! D~P? Depth NPHT Compensated Neutron Porosity, sS ~atrlx, caIi & dead t~me torT, ENPH Eptthermal Neutron Porosity CPH! ComPensated Neutron Poro,, SS matrix, tooI & Environ, Corr'~ FCN~ ~aw Far Detector Count rate, Dead Time Corrected NCNT Raw Near Detector Count Rate, Dead Time Corrected C~AT Neutron Ratio, Dead Time Corrected NRAT weutron Ration Non-Dead time Corrected ENRa Fpithermal Neutron Ratio Calibrated CFTC Corrected Far Detector Count Rate CWTf Corrected Near Detector Count Rate CFEC Corrected Far EPltbermal Counts CNEC Corrected Near EPit~erma! Counts G~C~ Gamma Ray in Casi TFNS Surface Tension 0f~:':666,- 0S~-666" ,666- 000°0t8~ D&N~'IHd3 0G~'666- 0~°666- DIND°£NDN 0~'666- D£ND'mNj~ ti 0000000000 89 9 ~ t f 0 O0 000 OO t68L8~ 0000000000 89 ~ t I f 0 O0 000 O0 t68L8~ Id~9 0000000000 89 9 I ¥ [ 0 O0 000 O0 ~68L8~ 0000000000 89 9 t t ~ 0 O0 000 O0 t68L8~ 9dD 9£ND D3&D 0000000000 89 ~ ~ ~ f 0 00 000 00 0000000000 89 9 ~ i [ 0 O0 000 O0 ~68L8~ 9dD D£ND 0000000000 89 ~ I ~ ( 0 O0 000 O0 I68L8~ D£N3 0000000000 89 ~ I I £ 0 O0 000 O0 t68L8~ 9iN~ 0000000000 89 9 { I E 0 O0 000 O0 168L89 D£ND 0000000000 89 ~ ~ ~ ~ 0 O0 000 00 I68£$9 9dD DiND £NDN 0000000000 89 ~ I I [ 0 O0 000 O0 I68L8~ gdD 9£ND 0000000000 89 t I I £ 0 O0 000 O0 168L8~ ~-fla 9~J d3 0000000000 89 9 ¥ I f 0 O0 000 O0 168L8~ 9-fid D&ND HdN3 0000000000 89 9 I t [ 0 O0 000 O0 I~8L8~ S-Qd 9iND iHdN 0000000000 89 9 '. ~ f 0 O0 000 O0 ~68L8~ £J £d3fl ~emee~ee~m~Nmm~em~mm~mee~em~mmemm~mmmmmae~mmmmmmmm~mmmmmmmmmmmmmmmmm~m~mmm~mm ' ' {X3H) ~3QOD ...... W~3 "dWVg 8~N QOW 9~q3 3dA& 90q # ~ae`~i~W~mm~mmae~meeeeememm~emmem~m~mmam~mmmmm~mm~mmmmm~mmmmmm~mm~mmmmmmmmmmmmm~mmmm mmm lllmemmmmmmmmmmmmmmm#mmmmmmmm I 99 0 I 99 9t 89 g9 $~ S9 0 99 89 LI 99 t 99 09 iL 0 99 0 99 mme~eem~mmmmmmamammmmmmmmmmmmm 2flOrA ~qOj ~d~8 3dl& :3'DVd , 000~*0 SN3~3~ONI H£d~q e~e~e~e.~)~e~qlt~e ~3uno3 puno~eq pue ~e~ e~e~ I ~sed'"pe~)pe'pebe~eAeu~ =uo~neN pesln~ - ~ 'seA~n~ Tie ~o~ sensed pe~pe ~o e~e~eae ~e~q~V =uo~lneN pe~esued~oO ~03~00 = **** MMGVMH 2qIJ **** {03100 : NOIS~^ EO0* 11~3 : ~VN . ~m~mm~mmmm#~mmmm~mmmm~m~mmm#~mmmmmmmm~mmmmmmmmmmmmmmmm~mmm pe~e~qsteD ot~e~ uo~neN Te~eq3td~ (~/N) Pe~ae~oD~em$% peeo-UON uoT%e~ uo~naN ~N pakkawood emtZ peeO 'e~ ~unoD ~o~oe~eO :eeN ~ *uo~$Au3 ~ TOO xT~em gg o~o~ uo~neN pe~esue~oj tHdD - ~So~od uo~neN Tem~eq~$d3 prep ~ ~T~ 'XT~%e~ gg 'A%Tso~o~ uo~naN ~e~sue~mo~ ~HdN 8'E9. Z3 ..... Xa~e~.-p'~no~g"~o ~eoTJ ~T~eO ~o '~ mn~ea ~ueuem~ e~9q~ amu~O~d uo~e~o~ PTeT& e~eN pTeT& 8'Dg Z3 9X~ 3~q 'DNI ~g~ OD~Y ND u~sTq uo~e~JaA ede~ Si chl~erq~r Alas~ ¢o~putlna Center 26-0CT-1994 2'1 :!8 ** ~ATA FORWAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REP~ CODE VALUE 1 66 0 2 66 0 5 66 7 65 9 Ii 66 1~ 68 1~ 66 0 14 65 ~ 66 68 ~6 66 0 66 ! ** SET TYPE - CHAN N~F SERV UNIT SERVICE API AP! APl AP! FILE NUMB NUMB 'SIZE REPR PROCESS ID ORDER # ~OG TYPE CbA$S MOD NUmB SAMP. EL£M CODE (HEX) FT 487891 O0 000 O0 0 4 I 1 4 68 PR-S 487891 O0 000 O0 0 4 I I 4 68 P~-$ 48789~ O0 000 O0 0 4 I X 4 68 P~-S 487891 O0 000 O0 0 4 1 I 4 68 CPS 487891 O0 000 O0 0 4 ! 1 4 68 CPS 487891 O0 000 O0 0 4 ! ~ 4 68 487891 O0 000 O0 0 4 1 I 4 68 487891 O0 000 O0 0 4 1 I 4 68 487891 O0 000 O0 0 4 1 1 4 68 CPS 487891 O0 000 O0 0 4 1 1 4 68 CPS 487891 O0 000 O0 0 4 I 1 4 68 CPS 487891 O0 000 O0 0 4 I I 4 68 CPS 487891 o0 000 O0 0 4 ! ! 4 68 GAP! 487891 O0 000 O0 0 4 t 1 4 68 bB 487891 O0 000 O0 0 4 ! 1 4 68 D~PT NPH? AVE ENPH CPHT AV~ FCNT AV.E NCNT AV~ C~AT AVE N~AT AVE ENR~ AV~ CFTC AV~ C~TC AVE CFEC C~EC G~CH AVE TFN~ 00000o0000 0000000000 0o00000000 00o0000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmm~mmmm~#mmm#~mmmmmmm~m~mm#~ DFPT 11716.000 NPHX AVE :999.250 ENPH. AVE FCNT:AVE 999.250 NCNT:AVE 999.250 CRAT:AVE ENR~ AVF -999.250 CFTC.AVE ..999 250 CNTC'AVE CNECiAVF -999.250 GRCH,AVE -999."950 TENS,AVE . 50 NRAT.AVE ,.999.250 CFEC.AYE 2778.056 -999.250 ..999,,250 -999.250 ~hlumberger AlasKa Computing Center 26-0CT-1994 21:18 DF~pT 1104 500 NPHI'AVE 136 153 ENPH*AVE 51.922 CPHI,AVE 49~,488 CRAT.AVE 4~98 NRAT.AVE 4'234 CN~C,AVE 1347 4.4 CFEC..AVE 384'878 TENS,AVE 2419.7'58 END Ur DATA **** FILE TRAILER FILF NAME : EDIT ,004 SERVICE : rbIC VERSION : 00~C01 DATE { 94/10/14 MAX REC SIZE : FILE TYPE ~ LO LA:ST rILE : **** FY~E HEADER FILE NA~E ~ EDIT ,005 SERVICE : TLIC V~R~ION : D~TE : 94/10/~4 ~X R~C SIZ~ ~ ~024 FIL~ TYPE : LO FILE HEADER FILE NUMBER 5 R~W CURVES Curves and 1o~ header data for each pass in separate ~les~ Ta~ background Pass D~PTH INCREmEnT: 0,5000 # FILF SUMMARY VENDOR TOOL CODE START DEPT~ #0 b. G H~ADER DATA ~ATE LOGGED: SOFTWARE VERSION~ TI~E LOGGE~ ON BOTTOM: ~D DRILLER TD LOGGER(FT): TOP LOG INTERVAD (FT)~ POTTON L~G INTERVAl, LOGGING SPEED 8TOP DEPTH 24-APR-94 CP 40.2 1439 24-APR-94 11690,0 1 50,0 11715,0 !800.0 0 000'8 :(NI) qO0~ :{~g30) 3~fl~V~3dN~ ~qOH ~0£~0~ E9 D=DND ~MVD NOB&A, MM O3~VgN3dHOD D£ND 86~ Vg O9~~ l~ V~D DiND ~3~fiN qoo& 3di£ 'lDO& MO00 900& aOGNMA 8t:Ig 966~-&OO-9Z · e~Do~ UOT3eaTTdd~ ue ~o~ A~$o~od uo:3neN ~OdN · ' ~TSO~Od uo~3naN te~aU~ ~d~& g~u~o~ [e~eq~d3 ~eaN pe~oa~o~ s~uno3 Tem~eq~$d~ ~e~ pa~oe~oo a~ea ~u~o~ ~oaaa~aO :eaN pa~oa::o~ R~so~od uo~ne~ Tem~aq~$d~ HdN3 pa~e~q~TeD o$~eB uo~naN Tem:aq~d3 OI~e~ UO~DeN [e~Iaq& ~eN ~N~ mmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm .... taAa~,,puno~D ~a uO~eAa~ "mnaea ~uauem~a~ aAoq~ moaj.pa~nseaa boq mn'~eQ lueuem2e~ 70 uo 3eAeT~ · ,n~ep lu~ue~ad UOT~eN aouTAO~d ~o uo~eooq ~q~N TaT:ag I~ ~eN PTeT3 · ~eN ~ueo~oD meam e#~e:em# m m,m ~ e m m,m m mm mmmmalam ~, memem ameemm#mm m am mmemm memmm a a e ! m m ~mmm mm m mae m mm mm m mm mm mm m m m m mm iii,,,,-m mm m m m mm m mm .. mm~m~mmm~mm~m~m~mm~m~mm~m~m~m~mmmmmmmmmmmmmmmmmm~mmmm#mmm#mmmmmmmmmmmmmmmmmmmm~mmmmmm 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 !~8L8~ 0000000000 89 ~ ~ { ~ 0 O0 000 O0 [68£8~ ~d ~d ~HdN 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 ~68L8~ Ad ~gd UOdN 0000000000 89 ~ ~ ~ S 0 O0 000 O0 t68L8~ 0000000000 89 ~ ~ T S 0 O0 000 O0 ~68L8~ 0000000000 89 ~ I ~ S 0 O0 000 O0 ~68L8~ 0000000000 89 ~ I I S 0 O0 000 O0 ~68£8~ 0000000000 89 ~ I ~ S 0 O0 000 O0 ~bSLS~ 0000000000 89 9 T T ~ 0 O0 000 O0 ~68L8~ fid ~Sd ~dN3 0000000000 89 ~ I { S 0 O0 000 O0 0000000000 89 ~ ~ ~ ~ 0 O0 000 O0 0000000000 89 ~ I ~ S 0 O0 000 O0 ~68L8~ 0000000000 89 ~ ~ ~ S 0 O0 000 O0 t68&8~ 0000000000 89 ~ I ~ S 0 O0 000 O0 T~8L8~ 0000000000 89 ~ T T S 0 O0 000 O0 T68LS~ 0000000000 89 ~ T ~ S 0 O0 000 O0 ]68L8~ 0000000000 89 ~ ~ ~ S 0 O0 000 O0 ~68L8~ 0000000000 89 ~ ~' ~ ~ 0 O0 000 O0 ~68L8~ aaiia~m~mm~imaaam~mmmmammmmm~m~m~mmm~m~m~aammmmmmmmmmmmmmmmmmmmm~mmm~mm~mmmmm~mm~mm CX3X} ~QO~'-- W353 dW~g ~AN ~O~ g~D 3dA& boq ~~~~~m~mm~m~mm~~mm~m~m~m~m~m~m~m~~mm~m~m~mmm~mm~mm~m ] 99 0 ~ 99 9I 89 99 0 99 89 9~ 99 99 0 99 0 99 ~flq~A 3QO~ ~d~8 ~dA& ~a~uab buI~hdmoD e]$elV 2ab~aqmn~q: Dul~sTq UOT~eOT~T~aA ade& SI Tape Feri~ication List[no :hlumberger Alaska Co~Putinq Center 26-0CT-1994 21:18 DEPT. 1!740.000 TEN$~: PSl 1845 RCF~.PSI 798.843 ~CNT PS1 2104 ' PS{ 624'724 CNEC.,PS! 303! NPHT,PS! ~0,779 GR'PS! 148 END OF DATA 931 ENRA,PS! 4.853 RCEF.PSl 892 CFTC'PS! 797.780 CNTC.PS! 1974,45 921 TNPH.PS~ 24.466 NPOR.PS~ 24-466 F/L~ NA~E : EDIT ,005 SERVICE : FLYC D~T~ { 94/{0/~4 ~X R~C SIZE : 1024 FILE TYPE : LO bAST FILE : **** FILE HEA. D~R **** FILE NAME : EDIT .006 S~RVICE : FLIC V~RSION : O01CO1 D, T~ : 94/10/14 ~AX R~C SIZE : 1024 'FILE TYPE ! LD L~$T FILE : FTbF ~EADER FIEF NUMBER 6 RAW CURVES Curves and log header data ~or each pass in separate D~PTH INC~EUE~T{ 0.5000 FYL~ SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ....-.-...-..... --------.- CNTG 11735 11048.5 LOG H~ADER DATA PATE bOGGED: SOFTWARE VERSION: TI~E LOGGE~ ON BOTTOm: VD DRILLER TD LOGGE~(FT): TOP LOG INTE~¥AL (FT): mOTTOM LaG INTERVAL (FT){ LOGGING SPEE~ (FPH~): ~iles; raw background pass in last '.Zi 24-APR-94 CP 40.~ 1510 24-AP~-94 11690.0 11720.0 1050.0 ~1715.0 1800.0 &~3~O3B &N3IgD 83d 9V qOB&NOD H&d~O ~BVNI~d 0 l(gdO) 3q~D~ HDIH 3~V8 &NiiOO 000'8 ~9'~ :(NI) NOI£J2~aOO JqOH qO0£ :( V~Q DNIg~D QN~ 3'10H3~08 $ biND 3~i~ qOO& 3~OJ 900~ ~OQN~A :(ON/SDi) Oa~a qO~i~OJ 8[:~ 966)'&Do-gz peep ~ TTeO °xT~eN gg 'A~Tso~od uo~naN pa~esuadmoD IHdN ~$sO~Od uo~3naN Te~aq~ sauaoD ~e~aq3~d3 ~eoa pe3oa~oD ~3N3 a3e~ ~unoo ~o~oe~ea ~eaN pa~oa~o~ e~e~ ~unoD ~o~oe~e~ ~e~ pa~oa~o~ A3~so~oa uo~3neN Zem~aq3~d3 HdN3 S~UnOD ~eaN'~ea~eq3~d~ pa~oe~o~ ~e~ pa3e~qsze3 o13ea uo~aaN Zea~eq3~da emmeammmmmmeemmeemmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmammmmmm ~OOX& ~o~:~eO ;o uoT~eAe~3 an'~ep:3ueuea~ea ue~3eN aoueu ~Tqsu~o& ~eqmnN ie~es ld~ 9'6~ 8'~9 3dOq9 H&~ON amen ......... l~3Q NqVA buT~sT'] uo$~eo'~;'~za^ eoe£ ~: · ~#~m~#~m~m~mmm~mmm~m~~mm~mmmm~m~mm~m~m~mm~m~mmmm~mmmmmmmmmmmmm~m~m~m~m~mm 0000000000 89 ~ ~ I 9 0 O0 000 O0 ~68L8~ ~di~ 0000000000 89 t ~ ~ 9 0 O0 000 O0 ~68L8~ ad ~d 0000000000 89 ~ T T 9 0 O0 000 O0 ~68L8~ ~d ~gd ~OdN 0000000000 89 ~ t T 9 0 O0 000 O0 T68LS~ fid 0000000000 89 ~ t T 9 0 O0 000 O0 ~68L8~ gd3 0000000000 89 t ~ I 9 0 O0 000 OO ~68£8~ gdD 0000000000 89 ~ I ~ 9 0 O0 000 O0 ~68L8~ gdD ~gd 0000000000 89 t I ~ 9 0 O0 000 O0 ~68L8~ ~d3 0000000000 89 t ~ ; 9 0 O0 000 O0 teSCS~ aa o0oooooooo 89 t t t 9 0 O0 000 O0 ~bSLS~ Sd3 0000000000 89 t ; ; 9 0 O0 000 O0 ~68LO~ gd~ 0000000000 89 t ~ ~ 9 0 O0 000 O0 ~68L8~ 0000000000 89 t t ~ 9 0 O0 000 O0 ~68L8~ ~d3 0000000000 89 t ~ ~ 9 0 O0 000 O0 [68L8~ gad 0000000000 89 t ~ ~ 9 0 O0 000 O0 ~68L8~ 0000000000 89 ~ ~ ~ 9 0 O0 000 O0 ~68L8~ 0000000000 89 ~ ~ T 9 0 O0 000 O0 ~68L8~ 8q ~d 0000000000 89 t ~ ~ 9 0 O0 000 O0 ~68L8~ ~ (X~H) :'300D .... W3q~ 'dW~g g~flN 00~ Sg~qD 3~& gOq # a3~O m~#~m,m~m~mmmmmmmm#m.~m~mmmmm ; 99 0 ; 99 9T 89 89 99 ~ 99 ~L E~ E 0 99 0 99 3flq~A 3000 ad~B 3dA& , ~~m~~m~mm~~m~~m ou~3sTq uo'~3eo~Tzeg aae£ g' ., [~ TaPe Verif~¢atJ[on :hlumberger AlasKa Computtnc~ Center 26-OCT-!994 21:18 ¸'2] D~PT, RCFT.PS~ RCEN,PS~ CFEC.PS~ 11735 500 786 325 2738 747 736 547 TENS.PS2 RCNT. PS2 ENPH, PS2 CNEC, PS2 C,R'P$2 1 000 TNR. A.PS2 4 527 CFTCi*PS~ 2999.983 TNPH,PS2 147. 500 ..07~ RCEF.P$2 ~785.279 CNTC.PS2 27'052 NPO~*P$2 744,545 2-7.052 END OF DATA FILF NAME : EDIT ,006 SERVICE : FDIC YER~ION : O0~C0! DArF : 94/10/14 ~X EEC SIZE : 1024 FI5~ TYPE ~ LO **** FILM HEADER **** FIDE NA~E ~ EDIT ,007 $~RVICE ~ FDIC VERSION : OO1CO1 D~TF : 94/i0/~4 M~X R~C SIZE : 1024 F~LF TYPE ~ LO LAST FILE : FILM HEADER FIL~ NUMBER 7 R~W CURVES Curves and log header data for each pass i~ separate P~S~ NUMB~R~ DEPTH INCREMENT: 0,5000 FIDF SUMM~RY VENDOR TOOL CODE START DEPTH STOP DEPTH rN?G 11734. 11048,5 ~OG HEADER DATA DATE LOGGED: SOFTWARE VERSIONt TI~E LOG~E~ ON TD DEILLFR · D LOGGER(FT): TOP LOG INTERVAL POTTOM bOG INTERVAL bOGGTN~ SPEED (FPHR)~ 24-APR-94 CP 40.2 1536 24-APR-94 11690.0 11720.0 11050,o 11715,0 1800,O £S Ta~e Verification List~nQ :hlumberger AlasKa Computing Center 26-0CT-1994 21:15 YES CNT~ CNT~ $ BOREMOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH LOGGERS CASING DEPTH (FT)~ BORE~O[,E CONDITIONS FLUID TYP~ FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF)~ FLUID SALINITY FLUID LEVEL (FT)t FLUID RATE AT WELLHEAD WATER CUTS (PCT). GAS/OIL RATIO: CMOKE NEUTRON TOOL TOOL TYPE (EPITMERMA5 OR THeRmAL)~ MATRI×: MAT~I× DEN$ITY~ HOLE CORRECTION (IN): GAM~A RAY SGC-SA 598 COMPENSATED NEUTRON CART CNC-O 63 [1856.0 EPITHERMAL SANDSTONE 2.65 B,O00 BbUMLINE COUNT RATE NORMALIZATION IN OIL zONE TOP NORMALIZING WINDOW ~ASE NORMALIZING WINDOW (FT)~ BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT ~ATE LOW SCALE CCPS): 0 mAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE ¢CP~)~ 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF RFM~RKS~ THR~E PASSED LOGGED AT 1800 FPH A8 PER CLIENT REQUEST, PRI.A~Y DEPTH CONTROL AS PER CLIENT REOUE~T .. N~R~ALIZED NEAR & FAR COUNTS FROM 113B0'- {'~460', $ LiS FORMAT DATA PAGEI 24 · e~bO~ uoT~e~d~ ue ~o~ A3~so~od uo~lneN dOdN s3uno~ Te~aq~ ~e~ pe~3e~oD a3ea ~uno3 ~oloe~ao ~e~ pe~oa~oj A3$sO~Od uo~naN Tem~e43)d~ fldN3 pa~e~qTTeD o~3e~ uo~eaN Tem~aq3~d~ oT~e~ uo~neN le~aq~ ~ea pa3e~qTTe~ oT~e~ uo~3neN Te~aq: ~~mm~mmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~mmmm ....... Ta,.aq puao~g.~o uolleAa)3. eu~'~.ng,RZTa~ ~o uo~3eAaT3 .... , a'nae~ ~uauem~aa a,oq~ mn3eo 3ueuem~ed ;o uo~e~.eT3 mn3ep 3u~uem~aa .uoT3eN aouT,o~d ~o a~e.3g uol~eooq PTaT3 ~aqmnN Te~'~ag Ia~ 3dOq9 H~BON NflOD N~ amen TTaM S~ - ~ g 0 NM amen PlaT& ~V~'3OH~d NJ aaeN ~ue~moD 'DNI 'V~gVqV ODa~ ........ I~30 Q~A 8g:gg ~66I-&DO-gE bUT~STq uoT3e~T~'~eA eae~ gl ~mmm~mmm~m~m~m~m~mm#mmmmmm~mmmmmmm~mmm~mmmmm#mm#mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm 0000000000 89 ~ I I L 0 O0 000 O0 ~68~8} Iai9 0000000000 89 ~ i t i 0 O0 000 O0 168L8~ ~8 E~d iXdN 0000000000 89 ~ ~ T L 0 O0 000 O0 T68LS~ ~d [~d ~OdN 0000000000 89 ~ t T L 0 O0 000 O0 ~68~8~ q~ 0000000000 89 ~ T ~ L 0 O0 000 O0 ~68L8~ gd~ 0000000000 89 9 ~ ~ L 0 O0 000 O0 ~68L8~ gd~ 0000000000 89 ~ T T L 0 O0 000 O0 I68L8~ gdD 0000000000 89 ~ T T L 0 O0 000 O0 ~68L8~ ~D 0000000000 89 ~ T T ~ 0 O0 000 O0 ~68~8~ fid 0000000000 89 ~ T T t 0 O0 000 O0 ~68L8~ ~dD 0000000000 89 ~ T ~ L 0 O0 000 O0 ~68L8~ 9dD 0000000000 89 t T T L 0 O0 000 O0 T68LS~ ~d 0000000000 89 ~ T ~ L 0 O0 000 O0 T68LS~ gab 0000000000 89 ~ T T L 0 O0 000 O0 t68L8~ gdo ~gd 0000000000 89 ~ ~ ~ L 0 O0 000 O0 ~68£8~ 0000000000 89 ~ T ~ L 0 O0 000 O0 T68L8~ 0000000000 89 t T T L 0 O0 000 O0 T68£8~ ~q Egd 0000000000 89 ~ ~ ~ L 0 O0 000 O0 t68L8~ ~ ~me~emmm~e~m~m~m~mee~me~a`~m~m~mem~im~eemmmm~mm~m~mm~mmm~mmm~mmm~mm~m~~ .' ' , .' ' ' . ~ 99 0 t g9 9T 89 99 ~T 0 99 89 99 0 99 0 99 , ~e~uaD pUT%ndmOO eMse'K~ ~ab~eq~n~q: bu~sTq uo~e~~eh aOe& g~ o9~Oo8~ ~L~ O' ~L~ 0'069~ ~6-adV-t~ :(£~) q~A~3mNI DOq dom :~0£~0~ NO a3DDOq :Q3~DOq $ EESO'O ~N2~2~DNI ~o~Too ~ ~Olsa~A 03~00 : L 6£ ~ ~68 ~ 61: 000 ~iLgt HdN ~e~uaD bul~nd~oD e~seiV ~abaaq~ntq: L:~ {~9~d 8~.1[~ D66~-~30-9~ bUT~STq uoT3eo{~IZaA cae& S' # # :(&J] MOONIM DNIZIqV~ON :(&J) MOONI~ DNI~I~ON dO& 000'8 3NO[gON~ qO0~ ~ou£n2~ S (WO&~OB O& dO~) DNI~S ~00~ 8~:tg ~66[=&oo-gg bUT~STq uo[leoT~TIaA a~e~ ~1 :hlumberqer Alask Comput nq Center 26-0CT-1994 2~[.'18 PAGE~ .29 TABLE TYP~ : CONS TU~! VAt, U DEF'! · ~. CN ARCO ALASKA, INC. ComPany Name FN PRUDHOE BAY FteidName APIN 4 - 45 welt Name FL 594 FNL & 449~ FE5 F/eld 5ocatlon TOW~ lIN Township RANC 1SE Range COUN NORTH SLOPE County STAT ALASKA State or Province NAT! USA Nation. P~A? MSL Per.man~nt datum 50q ~easured F~om APD FT 64,~ AbovePetmanent.Oatu~ .~. B ~T 64.8 Elevation ot Kelly Bushing EDF ~T 63,8 Elevat$on et ,EGL FT 29,6 Elevation o~.GrOundbevel .... TABLE TYPF = CURV ** DATA FORMAT SPECIFICATION RECORD ** SET T ! 66 0 2 66 0 3 73 ~ 4 66 1 5 66 6 73 7 65 9 65 I1 66 ~28 12 68 13 66 0 14 65 FT ;~ ~;eT u; ssea punozb~oeq ~e$ 6 8~9~nN IOD*O0 { DIq~ { 3DIA83S TO~O0 ~ NOI~3^ mm#mm~m~mmmmmm~mmmm#mmmm~mmmmmmmmmmmmmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~`/ ' : ' 0000000000 89 ~ i i 8 0 O0 000 O0 T68L8~ A [gd 0000000000 89 ~ t · 8 0 O0 000 O0 ~68L8~ &~ m~m~~m~mmm~m~mmmmm~mmm~mmm~mmmmmmmm~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm~m~ (X3H) 3QOD 'W3q3 d~g B~flN OO~ ~S~QD 3dA& 90~ ~ a3080 aaaaaaa~aaammaaaammmmmmmmmmm~mmmmmmmmmmmammmmmam~mmmmm~m~m~m~m~mmmm~mm~mmmmmmmmmm~mamm · , NVHD - SdA£ &~S m~m~mm~m#mmmmmmmmmmmmmmmmmmmmm t 99 o ¥ 99 9t 89 99 ~] m~m~mm~mm~mmmm~mm~mmm Du~2STq uo~2e~IOA e~e~ SI 000'8 0'9~8~ :(NI) NOi&D~02 AqOH :XI~£Vw ~00£ NO~ZfI~N :(NI) 3ZI~ ~18 3~OH N3dO V&V~ DNIg~D QNV 3~0H3~0~ $ O.'OgOTT o;o lt 00691I ~6'~dV=~g OT~l ~*BtOTT H&~a ~0~ :(Sm) gVA~3~NI DO~ dO~ :NOIg83A 3~VM&~O~ $ 6'~E£TI D~ND 8I:[~ ~66t-&J0-9~ KS Taue Verification List~n~ .-hlumberger A!as~a ComputinQ Center 26-0CT-1994 21:18 FAB COUNT RATE LOW SCALE CCP$): 0 WAR COUNT RATE HIGH SCALE (CP$): 0 WEAR COUNT RATE LOW SCALE (CP~): 0 ~EAR COU~T RATE HIGH SCALE (CPS)= 0 TOOL STANDOFF R~R~S~ THREE PASSED LOGGED AT ~800 FPH AS PER CLIENT REQUEST.. P~IMARY DEPTH CONTROL AS PE~ C~IE~T REQUEST. NORMALIZED NEAR & FAR COUNTS FROM i~380' - ~460~, T~IS FILE CONTAINS HIGH SAMPLE ~ATE CASING COLLAR LOG, LIS FORMAT DATA TABLE TYPE : CONS TUN! VALU DEF! ...... , .... ~,~, · CN A~CO ALASKA, INC. API~ 29-~2454 FL 594 FNL & 449~ FEL $~CT 34 TOWN lin R~NC 1SE COUN NORTH sLOPE STAT ALASKA NAT! USA PDAT MS~ APD FT 64.8 EKB WT 64,8 EDF FT 63,8 E~L FT 29,6 Company ~ame ~teld .ame weil,~ame A~I Serial ~umb,e'r Pieid Location Township Range County State or Ptov~nce Nation Permanent datum Elevation of Permanent Datum Log Measured From Ab6ve Permanent Datum Elevation ot Kelly Bushin~ Elevation of Derrlc~ E2oo~ Elevation T~BLE TYPE = CURV ~Ol ; ~ZI9 D~ X~W 6:0'0- ~gd'qDD 8~6'~£Lt1 ~mmm~mmemm~m#ema~mmmmmmmm~m~#~mmmm~m~mmmmmmamm~m~m~mmmmmmmmmmmmmmmm~mmmmm~mmm~mmmmm~m~mm 0000000000 '89' ~ t I 6 0 O0 000 O0 t68£8~ A ~gd 0000000000 89 ~ I t 6 0 O0 000 O0 t68L8~ ~A me~memmme~m~aa~maaamm.mmmm~mmmm~mmmmmm~mmmm~emme~mm~mm~mmmmmmmmmmm~mmmmmm~emm~mmmm~mm eemmmemmmm#mm,memmmmmmmmmmmemmm~ I 99 0 I 99 9t 89 99 St 0 99 K~ 89 ~i £80 89 8 t 99 ~ 8 EL E 0 99 ~ 0 99 ~ 81:I~ 966I-&D0-9~ 2NI~ ~(NI) 3ZI~ ~i~ ~qOH S3dO $ (~O&~O~ O~ dO£) 9NIa~S 'I00~ ~3A O'OgO~I 0'069tt :(ON/S3A) Q2~fl qO~&NOj Hld3O :(aHd~) O33d~ DNIDDO'I $ S'890~ 6'~£L~ 9~NJ £[80'0 :~Ng~3~DNI HmdgO ~g~g~as u~ ggg~ q~ga ~o~ g%gp ~apgaq DO% pug SaA~nO IOD~O0 : NOISH~A 8~:T~ 966;'£D0-9~ buI3stq uo~eot~eA aoe& S] mn~ep ~uauem~ed uoT~eN aou{Ao~d ~o A~unoD abueu uo]~eao~ amen '0 ~J 'DNZ 'V~gYqV ODaV # $ :(N~) ~OQNV~$ qO0~ :C~J) MOONIM DNI2I~W~ON dO~ 0o0') ~:NO&gC]NV~ ~VN~I3H&Id3 :(NI) NOI&D28~OD ~qOH :A~ISN3~ XIa&VW qo0~ NOB~ 81:]: ~66]-&30=9~ ~a~ueD ~u~ndmOb e~se[v ~ab~aqmnlq: 0000000000 89 ) ~ I Ol 0 O0 000 O0 ~68L8~ A ~gd 0000000000 89 ) I I Ot 0 O0 000 O0 t68L8~ ~ m~~~m~~mmmm~m~m~m~mm~~~mmmm~m~m~m~~mm~~mm~m~m~~ mm~#mmmmmmmmmmmmmmmmmmmmmm~mmm $ 99 0 $ 99 89 99 0 99 89 8~I 99 68 99 99 0 99 mmm~m~mmmmmmmmmmmmmmmmmmmmmmmm #~mmm~m~mlmmm i #ml ~m#mm~mmmlmmmm~mmmlmmmmmmmmmm~mmmmmmmmm Te~,eqpuno~9 )o UOT3eA~T~ 9'6~ £~ q~3 · iJ30 AqVA IN[IZ ~ # NOII~NI$N03 ~TE~6 : M~Vm qMM8 OtO' ~IflM : MN~N $t0'0- £gd'qOD 8;6'~£LII 'mdMO 8¥:tg 966t=&Do-gg