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Home My WebLink About188-057 • P t,k_ P t 3&)510 Regg, James B (DOA) From: Regg,James B (DOA) IS ' Sent: Monday, August 15, 2016 3:46 PM I/ I I To: 'AK, GWO SUPT Well Integrity' Cc: Wallace, Chris D (DOA) Subject: RE: REQUEST FOR CLARIFICATION:Injector W-42 (PTD #1880570) MIT-IA Test Pressure PBU W-42 was discussed with our Commissioners today.The AOGCC is preparing a replacement Admin Approval with the following conditions: - Water only injection; monthly TIO plots as in AIO 3.026; - Annual MITIA to 1500psi; test month is July; - Max allowablep ressures: Tubing and IA—1500psi; OA—500psi; - Annual caliper survey of tubing; first due September 2016; - AA expires 12/31/18 or if deteriorating conditions observed by pressure monitoring,tests or surveys. BPXA is encouraged to repair the tubing. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 %WED JAN 1 12017 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: AK, GWO SUPT Well Integrity [mailto:AKDCWellIntegrityCoordinator@ bp.com] Sent: Saturday, August 13, 2016 1:36 PM To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA); AK, GWO SUPT Well Integrity Subject: REQUEST FOR CLARIFICATION: Injector W-42 (PTD #1880570) MIT-IA Test Pressure Jim, I am seeking clarity on the required MIT-IA test pressure for Injector W-42 (PTD#1880570).The well is currently Not Operable for 2 reasons: 1) Starting Head leak 2) Witnessed MIT-IA on 07/31/16 to 1400 psi did not satisfy the minimum test pressure required by A10 3B: a. 1500 psi; or b. 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater. For W-42, this is 2078 psi. The well operates under Administrative Approval AIO 3.026,for manageable inner annulus repressurization.The AA requires an MIT-IA every 2 years to maximum anticipated injection pressure. Based on the last 4 years of data, maximum injection pressure is 1100 psi. 1 • • It was BPXA's understanding that the AA requirements superseded the A10 3B requirements; hence the reason we conducted the MIT-IA to 1400 psi. We have since received clarification from you that, since the AA requirements were, in this case, less stringent than the A10 3B requirements in terms of minimum test pressure,the A10 3B requirements should have been followed, or an updated AA specifying a lower test pressure due to calculated tubing de-ration should be pursued. The calculated de-rated collapse pressure of the 7" tubing is 1516 psi, based upon a 2013 caliper log that indicated a 72%wall penetration at 6951' MD.An explanation of the de-ration methodology is attached for your reference. Based on the de-rated collapse pressure,the hydrostatic pressures exerted by the fluids in the tubing and inner annulus, and an expected wellhead injection pressure of 800 psi: • An applied IA test pressure of 1930 psi would exceed 80%of de-rated tubing collapse; • An applied IA test pressure of 2230 psi would exceed 100%of de-rated tubing collapse. Prior to commencing starting head leak repair, we would like to ascertain whether we will be able to satisfy AOGCC MIT- IA requirements,given the tubing condition. Could you please provide guidance on which, if any, of the following options would be acceptable, assuming we were to repair the starting head leak and put the well online Under Evaluation for an updated witnessed test: 1) Conduct a witnessed MIT-IA to 1650 psi max applied (starting) pressure, 1500 psi target (ending) pressure. Although this test pressure does not meet the requirements of A10 3B, it is well above the maximum anticipated injection pressure of 1100 psi. We would pursue an updated AA specifying the test pressure if required. 2) Conduct a witnessed MIT-IA to 2078 psi max applied (starting) pressure (0.25 x Packer TVD), 1870 psi target (ending) pressure.The starting pressure is 93%of de-rated tubing collapse, based on the conditions outlined above. I am not sure if this satisfies Al0 3B, since we would be starting, rather than ending, the test at 0.25 x Packer TVD. 3) Conduct a witnessed MIT-IA to 2200 psi max applied (starting) pressure, 2078 psi target(ending) pressure.This would satisfy A10 3B. However, the starting pressure is 99%of de-rated tubing collapse based on the conditions outlined above, and we would likely elect to leave the well Not Operable. Call or e-mail with any questions. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate: Jack Lau) 0:(907)659-5102 H: 2376 Email: AKDCWelllntegrityCoordinator@BP.com 2 , 0 • ai o . 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WHF-N x "- p-=W1. a,n N z_ '^l India O $ m8 QCW� 0 ) o E Y ei W 000a a -,N -d-kO,0,,,,O9 t N 0 ti n .ni gI N N ry N N P gi Nh 4 N2 g M M gni M";;AP p 4 N O C V 4.t pp N N1 hA N N Nf S• Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, August 13, 2016 1:36 PM To: Regg, James B (DOA) Cc: Wallace, Chris D (DOA);AK, GWO SUPT Well Integrity Subject: REQUEST FOR CLARIFICATION:Injector W-42 (PTD#1880570) MIT-IA Test Pressure Attachments: W-42 Tubing De-Ration Methodology 2016-08-13.docx Jim, scA�NNED JAN 1 8 2017 I am seeking clarity on the required MIT-IA test pressure for Injector W-42 (PTD#1880570).The well is currently Not Operable for 2 reasons: 1) Starting Head leak 2) Witnessed MIT-IA on 07/31/16 to 1400 psi did not satisfy the minimum test pressure required by AIO 3B: a. 1500 psi; or b. 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater. For W-42, this is 2078 psi. The well operates under Administrative Approval A10 3.026,for manageable inner annulus repressurization.The AA requires an MIT-IA every 2 years to maximum anticipated injection pressure. Based on the last 4 years of data, maximum injection pressure is 1100 psi. It was BPXA's understanding that the AA requirements superseded the AIO 3B requirements; hence the reason we conducted the MIT-IA to 1400 psi. We have since received clarification from you that, since the AA requirements were, in this case, less stringent than the AIO 3B requirements in terms of minimum test pressure, the AIO 3B requirements should have been followed, or an updated AA specifying a lower test pressure due to calculated tubing de-ration should be pursued. The calculated de-rated collapse pressure of the 7" tubing is 1516 psi, based upon a 2013 caliper log that indicated a 72%wall penetration at 6951' MD.An explanation of the de-ration methodology is attached for your reference. Based on the de-rated collapse pressure,the hydrostatic pressures exerted by the fluids in the tubing and inner annulus, and an expected wellhead injection pressure of 800 psi: • An applied IA test pressure of 1930 psi would exceed 80%of de-rated tubing collapse; • An applied IA test pressure of 2230 psi would exceed 100%of de-rated tubing collapse. Prior to commencing starting head leak repair, we would like to ascertain whether we will be able to satisfy AOGCC MIT- IA requirements, given the tubing condition. Could you please provide guidance on which, if any, of the following options would be acceptable, assuming we were to repair the starting head leak and put the well online Under Evaluation for an updated witnessed test: 1) Conduct a witnessed MIT-IA to 1650 psi max applied (starting) pressure, 1500 psi target(ending) pressure. Although this test pressure does not meet the requirements of AIO 3B, it is well above the maximum anticipated injection pressure of 1100 psi. We would pursue an updated AA specifying the test pressure if required. 2) Conduct a witnessed MIT-IA to 2078 psi max applied (starting) pressure (0.25 x Packer TVD), 1870 psi target (ending) pressure.The starting pressure is 93%of de-rated tubing collapse, based on the conditions outlined above. I am not sure if this satisfies AIO 3B, since we would be starting, rather than ending, the test at 0.25 x Packer TVD. 1 • i 3) Conduct a witnessed MIT-IA to 2200 psi max applied (starting) pressure,2078 psi target(ending) pressure.This would satisfy AIO 3B. However,the starting pressure is 99%of de-rated tubing collapse based on the conditions outlined above,and we would likely elect to leave the well Not Operable. Call or e-mail with any questions. 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O Wi=Po 4 O m 0 Q W W O m OW,o ? c000. a -N m-,- .+n m -....+.mi ti.v'+��°..°�rvn[[ynnWn n .R.g P,A).1gmrnaov4oavv42.12232�°��.1; • 0 Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday,August 01, 2016 1:33 PM To: AK, GWO Well Integrity Well Information;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead; Peru, Cale;AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: NOT OPERABLE:Injector W-42 (PTD#1880570) Startinghead Leak All, Injector W-42 (PTD#1880570) has been found to have a starting head leak on August 12016 post AOGCC MIT-IA. Operating under Administrative Approval,this constitutes a further deterioration of well integrity.The well is now reclassified as Not Operable and will remain shut in until starting head integrity is restored. Please call with any questions or concerns. Ryan 11 Hol BP Alaska-We lil Integrity ntegrity GVVGlobal Wells Organization too 017, Office: 907.659.5102 From: AK, GWO Well Integrity Well Information nt: Saturday, July 23, 2016 3:17 PM To: GWO SUPT Well Integrity; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Contr. - s; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Slickline; AK, GWO SUPT Special Projects; AK, RES GPB West Wells Opt • AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; Peru, Cale; AK, OPS WELL PAD W; 'chris.wallace@alaska.•. ' Cc: AK, GWO DHD Well Int-; •ty; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessic., ickerman, Eric; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: OPERABLE: Injector W-42 (• : #1880570) Surface Equipment Issues Resolved All, Injector W-42 (PTD#1880570) is now ready to be placed on inj- 'on post surface repair work.The well is now reclassified as Operable. Plan Forward: 1. Operations: Place on Injection 2. Downhole Diagnostics:AOGCC Witnessed MIT-IA Please call with questions or concerns. 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Saturday,July 23, 2016 3:17 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Slickline;AK, GWO SUPT Special Projects;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead; Peru, Cale;AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers,Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: OPERABLE:Injector W-42 (PTD#1880570) Surface Equipment Issues Resolved All, Injector W-42 (PTD#1880570) is now ready to be placed on injection post surface repair work.The well is now reclassified as Operable. Plan Forward: 1. Operations: Place on Injection 2. Downhole Diagnostics:AOGCC Witnessed MIT-IA Please call with questions or concerns. Ryan Holt BP Alaska-Well Integrity GIV Global Wells Organization SCANNED NOV 1 8 2016 Office: 907.659.5102 Fro • AK, D&C Well Integrity Coordinator Sent: Thu •- November 19, 2015 8:16 PM To: AK, OPS GC2 S • AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; A 0 SUPT Slickline; AK, GWO SUPT Special Projects; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; • , •PS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, GWO SUPT Well Integrity; A , WO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Si cer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: NOT OPERABLE: Injector W-42 (PTD #18: - 0) Surface Equipment Issues All, Injector W-42 (PTD#1880570), operating under Administrative Approval A Injection Order(AIO)3.026. The well was placed on injection to facilitate state testing. Due to surface equipment issues th- ell was shut in and freeze protected.The state testing was not completed.The well is reclassified as Not Operab : d will be added to the quarterly AOGCC not operable injector report until the surface equipment is operational. Please call with any questions. 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday, November 19, 2015 8:16 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: NOT OPERABLE:Injector W-42 (PTD#1880570) Surface Equipment Issues All, Injector W-42 (PTD#1880570), operating under Administrative Approval Area Injection Order(A10) 3.026. The well was placed on injection to facilitate state testing. Due to surface equipment issues the well was shut in and freeze protected.The state testing was not completed.The well is reclassified as Not Operable and will be added to the quarterly AOGCC not operable injector report until the surface equipment is operational. Please call with any questions. Thank you, Kevin Parks SCOWSAY ® 2 201b (Alternate: Whitney Pettus, BP Alaska-Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Wednes0y, November 04, 2015 7:51 PM To: AK, OPS GC OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity CoordinatoriAK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; SternickrQIiver R; Morrison, Spencer; 'jim.regg@alaska.gov'; Pettus, Whitney; Sayers, Jessica; Dickerman, Eric Subject: UNDER EVALUATION: Injector W-42 (PTD #880570) Place on Injection for Compliance Testing All, Injector W-42 (PTD#1880570), operating under Administrative Approval Area Injection Order(A10) 3.026, was due for compliance testing on April 10, 2013. The well is now ready to be placed on injection and has been reclassified as Under Evaluation to facilitate state testing. Please use caution when bringing the well online as the annuli are fluid packed. • • • 4z_ Regg, James B (DOA) P� it�osio From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, November 13, 2015 7:31 PM To: Regg, James B (DOA) I j4'Ic Cc: AK, D&C Well Integrity Coordinator; Wallace, Chris D (DOA) Subject: Injector W-42 (PTD #1880570) Evaluate for a lower MIT-IA pressure Attachments: MIT PBU W-42 11-05-15.xls; W-42 aio3-026 corrected 05-08-09.pdf; W-42 WBS.pdf; W-42 caliper shot.docx;Injector W-42 (PTD #1880570) TIO and Injection Plot.docx Jim, Injector W-42 (PTD#1880570) had a caliper performed on April 6, 2013.The caliper recordings indicate the 7 inch tubing appears to be in good to poor condition with respect to corrosive and mechanical damage, with a maximum recorded wall penetration of 72% in a of line corrosion - at 6,951 feet. Additional recorded damage appears as isolated pits and a line of pits that broadens into corrosion. Twenty- four percent cross-sectional wall loss is recorded in an area of corrosion at 3,903 feet. Due to the caliper results BP would like approval to perform an MIT-IA to 1400 psi. The well was brought on line to obtain an AOGCC MIT-IA. The well is currently on line injecting with the tubing pressure @ — 500 psi. its currently injecting at its target, and historical data supports our recommended test pressure by showing a max online injection pressure of—1200 psi. Operating and testing W-42 to a lower pressure allows us to preserve the mechanical integrity within limits and to verify barriers. Enclosed is a copy of the TIO and Injection plots, MIT-IA form, schematic, clip of the caliper, and Administrative Approval. Thank you, Kevin Parks (Alternate: WAitncy Petals BP Alaska-Well Inter Coordinator GWGlobalWels Orgjaniz tion Office: 907.659.5102 'SCANS APR 0 8 2016 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com ,4(14,14 4-JQ App/AK 3,024, i acKi T — OA, 14;4k sooysi 4l-( (WI( Z6-70 4(zoo 3 welt it(6lzL)G-- 1 Res -(4 cd,CoJzt & ) • • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoo@alaska.gov; AOGCC.Inspectors[rDalaska.gov phoebe.brooks[rDalaska.00v chris.wallace(Dalaska.gov �j Y t ui I� OPERATOR: BP Exploration(Alaska),Inc. 1 FIELD/UNIT/PAD: Prudhoe Bay/GPB/W pad DATE: 11/11/15 OPERATOR REP: Kevin Parks AOGCC REP: Non Witnessed Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. Well W-42 Type Inj. W TVD " 8,312' Tubing 490 493 490 490 Interval0 P.T.D. 1880570 - Type test P Test psi " 2078 Casing 0 1,396 1,309 1,287 P/F /Pi 4A C445/z Notes: AA 3.026 for TX IA comm. OA 130 300 290 289 BP Internal test pumped 5.2 bls of diesel Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing _ P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval - P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT PBU W-42 11-05-15.xls KB.ELEV= 0.95--'9- ' LYNNTOATLESW: ELWLEL7L0.79U541R5,ES A SSSV. 6 '1'ttliv-------- '''' 54.26' • KOP:-= 423 ' 4 W-42 Pr6 ief-30-qc, Max Angle= 90 @ 10800' Datum MD= 11924' Datum TVD= 8800'SS II 2001' }—7"OTIS SSSV LANDING NIP, ID=5.963" 13-3/8"CSG,72#,L-80,ID=12.347" —1 2690' ; Minimum ID = 2313" © 8979' z-'to 0.4iciiw, r_c6Tekd L4z-it refie4-(z-visia 0 5 i,q 8800' —17"X 5-1/2(":12.0,ipt-V_r=4.89.71 Z-If 6113) 5-1/2" x 2-7/8" NIPPLE REDUCER \ 7"TBG,26#,L-80,.0383 bpf, ID=6.276" — 8800' 8823' — 5-1/2"OTIS XA SLD SLV, ID=4.562" 11:11 8865' -8910'1-- 5-1/2"ER PKR w/EXPANSION JOINFT ID=2.375"(09/05/08) CI CI ii 1 I 1 2 I 0 I 8890' TIVV OVERSHOT SEAL ASSY W/LATCH 8896' 1--9-5/8"X 5-1/2"TIW HBBP FKR, ID=4.75" CI CIp (rz4-1A16 -.-S 311.. t 8944' —5-1/2"OTIS X NIP, ID=4.562" I8979' —15-1/2"OTIS XN NIP, ID=4.455" mil 5-1/2"TBG, 174, L-80, .0232 bpf,ID=4.892" --I 9866' II 8979' --I 2-7/8"NIPPLE REDUCER, ID=2.313" L.—> TO --: €33P 9866' 5-1/2"OTIS OVERSHOT SEAL ASSY i w/SEALS TOP OF 5-1/2"LNR —1 9869' ', Iliki,:g,..u itilit pekcke„To = sia 7"q" 9-5/8"CSG,47#, L-80, ID=8.681" --I 9957' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 81°@ 10112' Note: Refer to Production DB for historical perf data .. SIZE SPF INTERVAL Opn/Sqz DATE .. 5-1/2" SLTD 10112- 11781 0 .... ....... 5-1/2"SLTD LNR, 174, L-80, ID=4.892" — 11781' 5-1/2"LNR, 174,L-80,.0232 bpf,ID=4.892" —I 11825' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/22/88 ORIG HORIZ COMPLETION 08/24/06 JCM/PAG PXN PLUG PULLED WELL: W-42 02/07/03 ?/KAK WAIVER SAFETY NOTE 08/20/07 RDW/PJC WAIVER SFTY NOTE DELETED PERMIT No:r1880570 05/18/06 TWS/TLH PXN PLUG SET(05/13/06) 08/17/08 JRA/SV SET NIP RED(08/13/08) API No: 50-029-21816-00 05/15/06 TWS/PJC SSSV INSERT PULLED(00/00/00 09/06/08 RRD/PJC SET LOWER PKK(08/16/08) SEC 21,T11N,R12E 05/15/06 PJC MIN ID CORRECTION 02/16/11 MB/JMD ADDED SSSV SAFETY NOTE 08/24/06 COM/TLH WAIVER SAFETY NOTE BP Exploration(Alaska) • • • PDS Report Overview iir4S Body Region Analysis Well: W-42 Suroet Date. April 06,2013 Field: Prudhoe Bay Tool Type: UW MFC 40 Ext.No.218452 Compam: BP Exploration(Alaska),Inc. Tool Size: 2.75 Country: USA No.of Fingers: 40 Tubing: 7 ins 26 ppf L-80 Analyst: 1.Bruning Tubing: Nom.OD Weight Grade A Thread Nom.ID Top Depth Bottom Depth 7 ins 26 ppf L-80 6.276 ins 27 ft 8800 ft Penetration(%wall) Damage Profile(%wall) 100 � = mol Penetration body0 MO metal loss body 100 0 II .1.111101 40 20 0 49 -- 0 to 20 to 40 to over .9ii 20°o 40% 85% 85% -7-_ Number of(Dints analysed(total=225) , -Mg 61 94 70 0 � ---� 98 Damage Configuration(body) - 21 200 ,.r .1.iimit 150 ...,— 14: _- 1.111 `- 100 - 50 --i 0 wam.r General Lino Mho. .w.; 19; _Mill Pew% C«.mon Common nmaie Pm.1104 . . .: . 10. . . • _ .. 18 14 154 0 0 Bottom of Survey=222.1 I • • Injector W-42 (PTD#1880570) Injection Plot : I SOO 1500 yq 4,./.41r1 ,OLa jiarrr MP 000 11 vitk .ate •3000 } 0t0511 0l00 0131.170,113 BS%t]ant?g7511 tu]btl 111.1713 OYLfI OYTnI OIO,JJ WW1)WI,OIMu Moo.:n ..3.su tOtri. ,t,a QV,Oa'tyry Obw,!Oi,}M W!,M] Injector W-42(PTD#1880570)TIO Plot Wel VI 12. 10.11) 211,0 Oaas —6—0120m • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, November 04, 2015 7:51 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Superintendent;AK, D&C Well Services Operations Superintendent;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead; Burton, Kaity; AK, OPS WELL PAD W; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; jim.regg@alaska.gov'; Pettus,Whitney; Sayers,Jessica; Dickerman, Eric Subject: UNDER EVALUATION:Injector W-42 (PTD#1880570) Place on Injection for Compliance Testing All, Injector W-42 (PTD#1880570),operating under Administrative Approval Area Injection Order(AIO) 3.026,was due for compliance testing on April 10, 2013. The well is now ready to be placed on injection and has been reclassified as Under Evaluation to facilitate state testing. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1. Operations: Place well on injection 2. Downhole Diagnostics:Once thermally stable, perform AOGCC witnessed MIT-IA Please call with any questions or concerns. Thank you, sCAtitiE Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator 3VV O n t�pt�s f)<�j�r.tat on WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: A &C Well Integrity Coordinator Sent:Tuesday, 'p •', 5:16 AM To: 'jim.regg@alaska.gov'; 'chris. • e@alaska.gov' Cc: AK, D&C Well Integrity Coordinator Subject: NOT OPERABLE: Injector W-42 (PTD ::1570) Due for 2 Year AOGCC MITIA All, Injector W-42 (PTD#1880570) operates under Administrative Approval 3.026, • is due for is due for its 2 year AOGCC compliance MITIA on 4/10/2013,and will not be tested prior to this date. The well is r- .ssified as Not Operable and will be added to the quarterly AOGCC not operable injector report. 1 MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission -? � S ' DATE: Thursday, May 19, 2011 TO: Jim Regg � i P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W -42 FROM: Matt Herrera PRUDHOE BAY UNIT W -42 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry .fee NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT W - 42 API Well Number: 50 029 - 21816 - 00 - 00 Inspector Name: Matt Herrera , Insp Num: mitMFH110408115705 Permit Number: 188 - 057 - Inspection Date: 4/7/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well W-42 "'Type Inj. W ' TVD 8312 IA 2370 2670 ' 2635 2630 P.T.D 1880570 TypeTest SPT Test psi 2500 OA 290 330 320 320 Interval REQVAR p/F P 'Tubing 560 560 560 560 Notes: Retest i 540 AWNED MAY 52011 Thursday, May 19, 2011 Page 1 of 1 MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, May 19, 2011 TO: Jim Regg � � I V 1 1 P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W -42 FROM: Matt Herrera PRUDHOE BAY UNIT W -42 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J Cr NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT W - 42 API Well Number: 50 029 - 21816 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH110519133018 Permit Number: 188 - 057 - Inspection Date: Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well W-42 - Type Inj. W - TVD 8312 IA 840 2550 , 2460 2410 2375 P.T.D 1880570 typeTest SPT Test psi 2500 ' OA 110 320 310 300 290 Interval REQVAR p/F P ' Tubing 560 560 560 560 560 Notes: MITIA required at 2 yr by AA with a prerequisite of a 2500 psi test pass on IA tOliw Thursday, May 19, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, April 08, 2011 TO: Jim Regg k I )/ P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W -42 FROM: Matt Herrera PRUDHOE BAY UNIT W -42 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 1 NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT W -42 API Well Number: 50- 029 - 21816 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFH110408115705 Permit Number: 188 - 057 - Inspection Date: 4/7/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! W42 "Type Inj. W ' TVD 8312 ' IA 840 2670 - 2635 2630 P.T.D 1880570 ' TypeTest ! SPT Test psi 2500 . OA 1 110 330 320 320 Interval REQVAR p/F P Tubing 560 560 560 560 Notes: MITIA required at 2 yr by AA with a prerequisite of a 2500 psi minimum test passs on IA ✓ 1 s �ri Friday, April 08, 2011 Page 1 of 1 _ _ __ . ~~~~ • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION ,~}~~ '~ 1C~~`~, REPORT OF SUNDRY WELL OPERAT • ~ ~ ~~ ~~~~~~ ~,t~ft1ff11a59Uti 1. Operations Pertormed: ~~~~~ f~~ Abandon^ Repair Well^X Plug Pertorations^ Stimulate ^ Otfler X^ WH Repair Atter Casing^ Pull Tubing^ Perforate New Pool^ Waiver^ Time Extension[ SealTite Change Approved Program^ Operation Shutdown^ Perforate ^ Re-enter Suspended Well^ 2. Operator gp Exploration (Alaska), Inc. Name: 4. Current Well Class: Development ^ Exploratory^ 5. Permit to Drill Number: 188-0570' 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic^ Service^X 50-029-21876-00-00 7. KB Elevation (ft): 9. Well Name and Number: 91.00 - W-42 8. Property Designation: 10. Field/Pool(s): ADL-028263 - Prudhoe Bay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11825 ~ feet true vertical 8824.0 • feet Plugs (measured) None Effective Depth measured 11783 feet Junk (measured) None true vertical 8823.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 94.0# H-40 37 - 147 37.0 - 147.0 1530 520 SURFACE 2653 13-3/8" 72# L-80 37 - 2690 36.0 - 2690.0 5380 2670 PRODUCTION 9922 9-5/8" 47# L-80 35 - 9957 35.0 - 8735.0 6870 4760 SIDE TRACK LINER 243 5-1 /2" 17# L-80 9869 - 10112 8715.0 - 8763.0 7740 6280 SLOTTED LINER 1669 5-1/2" 17# L-80 10112 - 11781 8763.0 - 8823.0 7740 8280 SIDE TRACK LINER 44 5-1/2" 17# L-80 11781 - 11825 8823.0 - 8824.0 7740 6280 Perforation depth: ~ .,f„~ ,, , , ~. ,,+ q~ r,. ~ ~ ~~ ~+r:a~~~~BSd~~ fui~t~ ~~ c~ ~ Measured depth: Slotted Liner --- 10112-11781 True vertical depth: 8763-8823 Tubing (size, grade, and measured depth}: 7" 26# L-80 ~ Surt _ 8800 5-1/2" 17# L-80 ~ 8800 - 9866 Packers &SSSV (type & measured depth): 9-5/8" x 5-1 /2" TIW HBBP PKR @ 8896 7" Otis SSSV Landing Nipple @ 2001 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Infection Data Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Exploratory^ Development^ Service^X ' Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ X Oil^ Gas^ WAG ^ GINJ^ WINJ^X WDSPL^ Prepared by DeWayne R. Schnorr (907) 564-5174. 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 Jason E. Dahlem N/A Printed Name Jason E. Dahlem Title Well Integrity Engineer Signature 4/23/09 59-5098 Date Phone 907 6 Form 10-404 Revised 4/2004 r ~ / = ~E~~ ~ ~ , ~ 7/-Z~ oil-Bbl Gas-Mcf water-ebi Casing Pressure Tubing Pressure __ __ 04/28/07 8700 --- 900 --- - 05/05/08 3565 --- 283 hY '~ l ~ "0~=1 • • W-42 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/29/2007 T/I/0=900/1060/250. Temp= Hot. MIT OA FAILED 2500 psi. (Waiver Compliance). (Witnessed by AOGCC inspector Jeff Jones). Pumped 1.7 bbls of meth down OA to reach 2500 psi for MIT-OA. Once test pressure was achieved fluid and gas was observed seeping from upper braiden-head at the 5 o'clock position on the wellhead. Bled OAP down to 120 psi (1+ bbl meth returned). Notifed Well Integrity Engineer and pad operator. Cleaned pipe below leak for further diagnosis. Final WHP's=900/1060/120 05/01/2007 T/I/0=0+/340/0+. Temp=Sl. Bleed IAP < 300 psi, OAP to 0 psi (eval BH leak). Bled IAP from 340 psi to 160 psi in 5 min (fluid). Bled OAP from 0+ psi to 0 psi in 10 sec. 1 visible fluid line down SC @ 2:00. SI monitor for 15 min. IAP increased 10 psi. FWHP=O+/160/0. 05/02/2007 T/I/0= 60/190NAC. Temp= SI. WHP's post-bleed (evai BH leak}. TBGP increase 60 psi, IAP increased 30 psi, OAP went on a VAC overnight. Signs of a BH leak at the 2 o'clock position, cleaned area for future signs of a leak. 11/08/2007 TIO =SSV/0/vac. Temp = SI. OA FL, bleed OAP to 0 psi (pre seal-tight). OA FL near surface. 11/10/2007 T/I/0= SSV/0/0. Temp= SI. MITOA to 2000 psi, assist seal tite (Seal tite). Used 2.68 bbls of diesel to pressure OA from 0 psi to 2000 psi. During MIT bradenhead started to leak at the 5 o'clock position at 1200 psi and IAP increased 20 psi. Continued to pressure OA to 2010 psi. OA lost 70 psi in the first 15 minutes and lost 40 psi in the second 15 minutes. Bled OAP from 1900 psi to 0 psi.tiPumped aprox 10 gal of seal tite Gel seal down OA from 0 psi to 600 psi. Let cure over night, will continue iob in the AM. Final WHP's= SSV/15/600. 11/11/2007 T/I/0= SSV/0/550. Temp= SI. MITOA, pump seal tite w/tri-plex (seal tite). Pumped 20 gallons of seal tite down OA from 550 psi to 1200 psi. Monitored for 4 hours. OAP decreased 40 psi to 1160 psi during monitor. Continued to pump 25 gallons of seal tite from 1160 psi to 1950 psi. Monitored for 30 minutes. IAP increased 5 psi & OAP decreased 30 psi during monitor. Final WHP's= SSV/5/1920. 11/17/2007 T/I/O=SSV/0/1300. Temp=Sl. Bleed OAP to <200 psi. (Repair SH leak). OA FL @ Surface. Bled OAP from 1300 psi to 200 psi in 2 minutes. Monitor for 30 minutes. OAP increased 60 psi to 260 psi, bled back to 200 psi in 1 minute. Monitor for 15 minutes. OAP increased 20 psi, bled OAP back to 200 psi. Monitor for 15 minutes. OAP remained @ 200 psi. Final WHP's=SSV/0/200. 01/11/2008 T/I/0=0/0/250 MIT IA FAILED to 2500 psi. (Pre AOGCC MiT IA} Pressured up IA w. 4.5 bbls neat meth. IA lost 40 psi in 15 min and 50 psi in second 15 min. fora 90 psi loss over 30 min. Bled back 3.8 bbls fluid. (IA & Wing tagged & wellhead valves checked for position upon departure, SSV dumped) FWP's=0/60/240 01/22/2008 T/I/0= 700/1000/750. 81eed OAP to 0 psi (pre-MIT). OA FL @ surface, bled OAP from 750 psi to 0 psi in 40 mins. Shut-in bleed and monitor for 30 mins, OAP unchanged. Final WHP's= 700/1000/0. Page 1 • W-42 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/26/2008 T/I/0=765/1000/40. Temp=Hot. Clean up SH and take pictures (SC leak). Unable to clean SH do to cellar grating in the way. Grating will need to be unbolted to be removed. OAP increased 40 psi from 1/22/08. 01/27/2008 T/I/0=770/1030/40. Temp=Online. Clean SH, pictures (eval SH leak). Pulled floor grating for access. Photographed existing SH leaks from 0300 to 0600. Cleaned SH. All leaks evidenced will be new. Replaced floor grating. 01/30/2008 T/I/O = 770/1020/70. Temp =Hot. Monitor SC leak (post seal tite). IAP increased 10 psi, OAP increased 30 psi since 1/27/08. IA has integral flange installed. No noticeable SH leak ~ pressent at this time. 01/31/2008 T/I/0 = 770/1020/70. Temp Hot. Monitor SC leak (post Seal tite). IA has integral flange. No visable SC leak. T/I/0= 785/1060/100 TEMP= Hot ,MIT-IA to 2500 psi. (AOGCC State witnessed John Crisp) FAILED 2 attempts. 1st test IA lost 260 psi. in 20 min., 2nd test IA lost 150 psi. in the 1st 15 min. and 125 psi. in the 2nd 15 min. Pumped 2.2 bbls to reach test pressure for test 1 and pumped additional 0.4 bbls for test 2. Bled back 1.5 bbls. Final WHP=785/1100/100 02/01/2008 TIO = 500/800/0. Temp = SI. Monitor SC for leaks post Seal-Tite. TP decreased 270 psi, IAP decreased 220 psi, OAP decreased 70 psi overnight. No SC leaks detected. 02/02/2008 T/I/O = 30/280/vac. Temp = SI. Monitor SC leaks post Seal-Tite. No visible leaks on SC. 03/20/2008 DHD SHOT FLUID LEVELS T=400' IA= SURFACE BRUSH XN NIPPLE @ 8979' MD SET 5 1/2" PXN PLUG BODY (6-1/4" PORTS) @ 8979' MD SET "P" EQ. PRONG IN PXN BODY (a) 8979' MD T/I/0=50/40/20 Temp=Sl Assist Slickline MIT Tubing to 3000 psi PASSED. Pumped 22.3 bbls of neat methanol into the tubing to reach test pressure. MIT Tubing lost 0 psi in the 1st 15 min and 0 psi in the 2nd 15 min for a total loss of 0 psi in the 30 min test. Bleed Pressures back to starting. Final WHP's = 75/40/20 03/24/2008 T/I/0=80/60/50, Temp=S1. PPPOT-T (PASS), PPPOT-IC (PASS). Eval IA x OA comm. PPPOT-T: External check previously installed. RU high pressure bleeder tool (1200 psi), bled to 0 psi. Functioned LDS, all moved freely, torque 500 Ib/ft. Pumped through void until clean fluid returns achieved. Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Function LDS, all moved freely. PPPOT-IC: External check previously installed. Functioned LDS, all moved freely, torque to 500 Ib/ft. RU high pressure bleeder tool (0 psi), bled to 0 psi. Pumped through void until clean fluid returns achieved. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 03/27/2008 T/I/0=0/100/0 Temp=S/I """MITIA to PASSED to 2500psi**'` (Evaluate possible communication through wellhead) Pumped 3.5bbls meth to pressure up. IA lost 60psi 1st 15min, 30psi 2nd 15min, for a total of 90psi in 30min. Bled IA to zero. FWHP's = 0/0/0 Page 2 MEMORANDUM ~ State of Alaska llaska (]hi and Gas ("onservation Commission DATE: Wednesday, April I5, 2009 To: Jim Regg '~ /~ P.I. Supervisor 1~e `('l~ ~z~~ SUBJECT: Mechanical Lriegrity"1'~ts f'3P EYPLORATICIN (AI. ~SKA) JNC 111 W ~` FROM: Bob Noble I'RC.TDHOE 13AY UNIT W-42 Petroleum Inspector Src: Inspec9or NON-CONFIDENTIAL Reviewed By': P.I. Suprv Jr j C'Omm Well Name: PRUDHOF, BAY L!NI1' W-42 API Well Number: 50-029-21x16-00-00 jnspector Name: Rob Noble Insp Num: mitRCN090413053523 permit Number: lxx-057-0 ~ Inspection Date• ¢'10/2009 Rel Insp Num: Packer Depth -- - _ . Well _~w-4z TYAe Inj w. TVD x I' - - - - _ _ _ ]880570 SPT ~S~X) p•'r• - TypeTest Test pst - ._Interval, oTl~x--- P/F _ - ~ -- - - / _ ----- Notes: MIT-IA to 2500 psi pre r'1A Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. IA ~ 930 ~ 29(X) ~~ 241Nj ~ 3360 ' --_ - OA ~ 250 ~ 430 ~ 430 ~ 430 _ ._ Tubing1 6~r) ~ 690 ~9n ~ 690 -, ° 4 ~ ~ ~~,r r ~ ~. ~ 1. l~ ~' -¢~ Wednesday, April 15, 20()<J Page I of 1 UNDER EVALUATION: W-~PTD #1880570) TxIA Communication Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, March 27, 2009 10:33 AM ~p~j ~ ~ j ¢~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Robertson, Daniel B (Alaska) Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: W-42 (PTD #1880570) TxIA Communication Attachments: W-42 TIO.doc; W-42.pdf All, Well W-42 is a shut-in produced water injector with a history of TxIA communication. The well passed an MIT-IA to 2500 psi on 3/22/09, but still requires an AOGCC witnessed MIT-IA to while on injection for continued injection. The well has been reclassified as Un er va uation so it may be put on injection for the test. The 28-day clock will start once the well is POI. The plan forward for the well is as follows: 1. WOE: POI 2. WIE: Monitor forTxlAcommunication -.y~; ;~~"~~~~ ~~~ ¢ ~~~~= 3. F: AOGCC MITIA to 2500 psi 4. WIC: Eval for Administrative Approval A wellbore schematic and TIO plot have been included for reference. «W-42 TIO.doc» «W-42.pdf» Please call with any questions or concerns. Thank you, Winton Aubert Office: 659-5102 4/14/2009 PBU W-42 PTD 188-057 3/27/2009 TIO Pressures a,ono • ~ o00 :,000 1,000 t t~ ~ a ~- OA OOA -~- OOOA ^ On • yv KB. ELEV - 90.95' BF. ELEV = ~.~ 54.20' KOP = 4234' Max Angle = 90 @ 10800' Datum MD = 11924' Datum TVb = 8800' SS SA TES: HORIZONTAL WELL - 70° @ 9545' ~~~ 2001' ~ 7" OTIS SSSV LANDING NIP, ID = 5.963" 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-i 2690' ~ ~ ~ Minimum ID = 2.313" @ 8979' 5-1 /2" x 2-718" NIPPLE REDUCER 8800' 7"X5-1/2"xo, ID=4.892" 7" TBG, 26#, L-80, .0383 bpf, ID = 6.276" 8800' ' I 8823' 5-1/2" OTIS XA SLD SLV, ID = 4.562" 8865' - 8910' 5-1/2" ER PKR w /EXPANSION JOINT ID = 2.375" (09/05/08) $$90' TNV OVERSHOT SEAL ASSY WlLATCH RAQR' Q_F!R" X F_1 M" TM/ HRRP PKR If) = d 75' $944' ~~ 5-1 /2" OTIS X NIP, ID = 4.562" ~ 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~ TOP OF 5-1/2" LNR 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 81 ° @ 10112' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 5-1/2" SLTD 10112 - 11781 O 5-1/2" SLTD LNR, 17#, L-80, ID = 4.892" 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/22/88 ORIG HORIZ COMPLETION 08/24/06 JCM/PAG PXN PLUG PULLED 02/07/03 ?/KAK WAVER SAFETY NOTE 08/20!07 RDW/PJC WA V ER SFTY NOTE DELETED 05/18/06 TWS/TLH PXN PLUG SET (05/13/06) 08/17/08 JRA/SV SET NIP RED (08/13/08) 05/15/06 TWS/PJC SSSV INSERT PULLED(00/00/00 09/06/08 RRD/PJC SET LOWER PKK (08/16/08) 05/15/06 PJC MIN ID CORRECTION 08/24/06 COM/TLH WANER SAFETY NOTE PRUDHOE BAY UNIT WELL: W-42 PERMIT No: 1880570 API No: 50-029-21816-00 SEC 21, T11 N, R12E BP Exploration (Alaska) 8979' I~ 5-1 /2" OTIS XN NIP, ID = 4.455" 8979' 2-7/8" NIPPLE REDUCER, ID = 2.313" 9866' 5-1/2" OTIS OVERSHOT SEAL ASSY w/SEALS ~~. .` ., .\ ~~. • I/lf~LL LAG li ~A l l l~ l V l f 7" T~ 4 L ProActive Diagnostic Services, Inc. • To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 ~ (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnicai Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1 ] Leak Detection -WLD 1 S-Dec-08 06-17 2] Leak Detection -WLD 19-Dec-08 W-42 Signed Print Name: l~""~~- ~2-gyp c~ 33~ 1 Color Log / EDE 50-029-20760-00 1 Color Log / EDE 50-029-20533-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~dsanelt€ar~ae~t~aem®r~t9ocl.cor~t WEBSITE : ~,v~.rrserr3t3rt9~~.c~~a~s C:\Documen~ and SettingstOwnec\Desk[op\Transmit_BP.docx • • 1/1/~~ ~~ t! TI~i4/~SIVI/T w?"a4L ~a _.~ r----~ ~ a ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning. a signed copy of this transmittal letter to the following ~ BP Exploration (Alaskaj, Inc. Petrotechnical Data Center ~;,;,~~L~~~l~' ~~,~,~ f ~~ ~~~ Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. 1~3~G/ Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-6952 1) Leak Detection - WLD 19-Dec-08 W-42 Color Log / EDE 50-029-2181 E~00 Signed : Date Print Name: -.~ 3 _,. PROACTIVE DIAGNOSTIC SERVICES, lNC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8851 FAX: (9071245-88952 E-MAIL: ~~sar~~hor~ele~~r~~a~:nat~awE~e~.~~r~t WEBSITE:~,~wuv,~~u~rr~~c~~"~V~c~~c4~H~d ''~ C:\pocuments end Settings\Oamer\Desktop\Transmit_BP.do~ NOT OPERABLE: W-42 (PTD #1880570) WAG Injector with IA repressurization Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] '~~~ (Zf 2cF~ ~~ Sent: Sunday, December 21, 2008 7:20 PM I To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad SW; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Prod Controllers Cc: Robertson, Daniel B (Alaska); Quy, Tiffany; Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: W-42 (PTD #1880570) WAG Injector with IA repressurization All, The leak detection log has been completed on well W-42 (PTD #1880570) indicating the patch across the acker ma not be holding. The well has been reclassifed as No# Operable and has been shut-in. The well wi e eva uated for another atte prat a repair. Thank you, Anna 1~u6e, ~. E. Well Integrity Caordinator GPB Wells Group Rhone: {907} 659-5102 Rager: {907} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, December 02, 2008 8:27 PM ~~ ~._ To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad MN; GPB, Prod Controllers; GPB, Well Pad SW Cc: Robertson, Daniel B (Alaska); Townsend, S. Eliot; Winslow, Jack L.; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: W-42 (PTD #1880570) WAG Injector with IA repressurization All, Well W-42 (PTD #1880570) is a PW injector currently online and is showing signs of IA repressurization. The wellhead pressures were tubing/IA/OA equal to 920/1180/240 on 11/14/08. The well was bled on 11/15/08, 11/22/08, and 11/25/08 to check to build up rate and stabilization. The well has been reclassified as Under Evaluation with a start date of the 28 day clock of 11/25/08. The well has a passing MITIA to 2500 psi on 09/26/08. The well shall remain on produced water injection with the following plan: The plan forward for this well is as follows: 1. E-line: Run Leak Detect Log 2. DHD: Bleed IAP to 0 psi and monitor build-up rate 2. Well Integrity Engineer: Evaluate log and build-up rate for repair or AA application A TIO plot and wellbore schematic have been included for reference. 12/24/2008 NOT OPERABLE: W-42 (PTD #1880570) WAG Injector with IA repressurization Page 2 of 2 • Please call with any questions or concerns. Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 12/24/2008 UNDER EVALUATION: W-42 ~ #1880570) WAG Injector with IA re ressurization Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ IZI 4~I Sent: Tuesday, December 02, 2008 8:27 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well Pad MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; GPB, Well Pad MN; GPB, Prod Controllers; GPB, Well Pad SW Cc: Robertson, Daniel B (Alaska); Townsend, S. Eliot; Winslow, Jack L.; NSU, ADW Well Integrity. Engineer Subject: UNDER EVALUATION: W-42 (PTD #1880570) WAG Injector with IA repressurization Attachments: W-42 TIO.doc; W-42.pdf AI I, Well W-42 (PTD #1880570) is a PW injector currently online and is showing signs of IA repressurization. The wellhead pressures were tubing/IA/OA equal to 920/1180/240 on 11/14/08. The well was bled~on 11/15/08, 11/22/08, and 11/25/08 to check to build up rate and stabilization. The well has been reclassified as Under Evaluation with a start date of the 28 day clock of 11/25/08. The well has a passing MITIA to 2500 psi on 09/26/08. The well shall remain on produced water injection with the following plan: The plan forward for this well is as followsi 1. E-line: Run Leak Detect Log 2. DHD: Bleed IAP to 0 psi and monitor build-up rate 2. Well Integrity Engineer: Evaluate log and build-up rate for repair or AA application A TIO plot and wellbore schematic have been included for reference. «W-42 TIO.doc» «W-42.pdf» Please call with any questions or concerns. Thank you, Taylor Wellman filling in for Anna Dube/Andrea Hughes Office: 659-5102 Pager: 659-5100 x 1154 12/4/2008 PBU W-42 PTD ~ ~ ~.~~ 12/2/2008 ~, TIO pressures • r~ro oco KB. ELEV = 90.95' BF. ELEV = 54.20' KOP = 4234' Max Angie - 90 @ 10800' Datum MD = 11924' Datum TV D = 8800' SS 13-318" CSG, 72#, L-$0, ID= 12.347`° ~-j 2690 Minimum ID = 2.313" @ 8979' 5-112" x 2-718" NIPPLE REDUCER 7" TBG. 26#, L-80, .0383 bpf, ED = 6.276" 8$C ( 5-112" TBG, 17#, L-80, .0232 bpf, ID = 4.892" TOP OF 5-1J2" LNR 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 81 ` @ 10112` Note: Refer to Production DB far historical pert data SIZE SPF INTERVAL OpnfSgz DATE 5-112" SLTD 10112 - 11781 O W_~~ SA OTES: HORIZONTAL WELL - 70° @ 9545' 2001' X17" OTIS SSSV LANDING NIP, ID = 5.963" 7" X 5-1/2" XO, ID = 4.892" 8823' 5-1/2" OTIS XA SLD SLV, ID = 4.562) .65' - 8910` 5-112" ER PKR w 1 EXPANSION JOINT ID = 2.375" {09/05f08) 8890' TNV OVERSHOT SEAL ASSY W/LATCH 8896' ~- 9-5f8" X 5-1/2" TNV HBBP PKR ID = 4.75 $$Qt~' I~ 5-1l2" OTIS X NIP, ID = 4.562" 8979' 8979' I 9866' I `~. DATE REV BY COMMENTS DATE REV BY COMMENTS 07122/88 ORIG HORIZ COMPLETION 08124(06 JCM1PAG PXN PLUG PULLED 02/07/03 ?1KAK WAVER SAFELY NOTE 08/20107 RDWrPJC WAVER SFTY NOTE DELETED 05118/06 TWSITLH PXN PLUG SET (05113!06) 08!17108 JRAtSV SET NIP RED (08113108) 05115106 TWS(PJC SSSV INSERT PULLED{00%CC!00 09!06/08 RRD!PJC SEf COINER PKK (08!16108} 05115106 PJC MEN ID CORRECTION 08!24/06 COMlTLH WAVER SAFEYY NOTE 5-112" OTIS XN NIP, ID = 4.455" 2-718" NIPPLE REDUCER, ID = 2.313" 5-1/2" OTIS OVERSHOT SEAL ASSY w /SEALS PRUDHOE BAY UN(r WELL: W-42 PERMR No: 1880570 API No: 50-029-21816-00 SEC 21, T11 N, 812E BP Exploration (Alaska) MEMORANDUM Toy Jim Regg P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 13, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-42 PRUDHOE BAY UNIT W-42 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: PRUDHOE BAY UNIT W-42 Insp Num: mitLG080926121955 Rel Insp Num: API Well Number: 50-029-21816-00-00 Permit Number: 188-057-0 Inspector Name: Lou Grimaldi Inspection Date: 9/26/2008 i ~!S~ 1 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~'-42 !Type Inj. ~ W ' TVD 8312 IA ~ o zslo zals 2360 2320 2285 P.T. 1880570 TypeTest sPT Test psi i 2078 QA ' l0 270 ~ 260 ~ 250 240 230 Interval °T~R P/F P Tubing Tao ~ 7ao Tao Tao Tao Tao Notes' 4.3 bbl's pumped. Failed test. Post tubing patch test. Repressured IA, see subsequent test. Monday, October 13, 2008 Page 1 of 1 MEMORANDUM To: Jim Regg ~ I P.I. Supervisor ~~~~ ( ~~zl ~ `~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, October 13, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-42 PRUDHOE BAY UNIT W-42 Src: Inspector NON-CONFIDENTIAL Reviewed Bye~: ~~ P.I. Suprv ti.l!.~'~ Comm Well Name• PRUDHOE BAY UNIT W-42 API Well Number 50-02 9-2 1 8 1 6-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG080926 1 3 1 5 1 1 Permit Number: Iss-o57-o Inspection Date: 9/26/2008 Rel Insp Num: T~~~ ~' Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well w-az Type Inj. W ! TVD 8312 Ip zzss 2510 ~ 2470 zaso p T Isaos7o TypeTest SPT Test psi zsto OA I zao zw zao ~ zao ~ Interval oT~R P/F P ~ Tubing Tao Tao I Tao Tao Notes' 2nd test today on post-patch..2 bbl pumped, Repressm~ed IA after questionable results on previous test (mitLG080926121955). 60 psi loss vs 150 psi loss on previous test. Monday, October 13, 2008 Page 1 of 1 ,, STATE OF ALASKA ~ ~ ~ :;; ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OP~R~~IONS , - ~i~' a ~' ~M s, 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other Tubing patch Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ 8870'-8910' ELM 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 iss-o57o- 3. Address: P.O. Box 196612 Stratigraphic Service ;~ 6. API Number: Anchorage, AK 99519-6612 50-029-21816-00-00 7. KB Elevation (ft): 9. Wetl Name and Number: 91 KB - PBU W-42 8. Property Designation: 10. Field/Pool(s): ADLO-028263 Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11825 ~ feet Plugs (measured) 8979 true vertical 8824.3 feet Junk (measured) None Effective Depth measured 11783 feet true vertical 8823.1 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 30 - 110 30 - 110 1530 520 Surface 2661 13-3/8" 72# L-80 29 - 2690 29 - 2690 5380 2670 Production 9929 9-5/8" 47# L-80 28 - 9957 28 - 8735 6870 4760 7740 6280 Liner 1956 5-1/2" 17# L-80 9896 - 11825 8715 - 8824 g~ T ~' ~~ 200 ~ ~t ~~ i .. C3. `a Perforation depth: Measured depth: SL 10112' - 11781' True Vertical depth: 8762.7' - 8823.4' Tubing: (size, grade, and measured depth) 7" 26# L-80 Surface - 8880 5-1/2" 17# I-80 8800 - 9866 Packers and SSSV (type and measured depth) 5-1/2" TIW HBBP PKR 8896' 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: 7358 920 638 Subsequent to operation: 8935 673 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~~ Development "' Service ~ - Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas ~ WAG ~' GINJ WINJ I~''- 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: 308-275 Contact Gary Preble Printed Name Gary Pr le Title Data Management Engineer Signatur Phone 564-4944 Date 9/25/2008 Form 10-404 Re~s~d ~~(2~006 ~ ~~ „~~ ; ~ t~ ~'~ ~ ~- ~ ~ ~QO~ Submit Original Only }~ `~ I ` • s W-42 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDAT~ SUMMARY 9/4/2008;.*** WELL S/I ON ARRIVAL ~~' (patch) ';RU SL UNIT. *'`'` CONT 09/05/08 WSR '*'' 9/5/2008':**" CONT FROM 09/04/08 WSR*** (patch) ',ISET WFD MODEL B SPLINED EXPANSION JOINT (19' WHEN CLOSED, 30' ':WHEN OPENED) WITH SNAP LATCH IN LOWER ER PACKER AT 8900' SLM ';(8906 MD). UPPER PATCH AND 5-1/5" ER PKR WITH E-FIRE AT PATCH AT 8840' SLM (8865' MDI. UPPER PKR ELEM 8870' MD. MIN ID OF ASSY IS 2.375". *** WELL LEFT S/I. TURNED WELL OVER TO PAD-OP'** PATCH ASSY WAS DRIFTED WITH A 2-7/8" XX PLUG (2.313" OD) PRIOR TO SETTING. 9/14/2008:T/I/O=0/0/0 MIT IA PASSED to 2500 psi. Pumped 4.6 bbls methanol to reach ':test pressure. 1 st 15 min lost 60 psi, 2nd 15 min lost 10 psi for a total loss of 70 ',,psi in 30 min. Bled down IA to 0 psi. (4.5 bbls) FWHP's=0/0/0 Annulus casing valves tagged and left open to gauges DSO notified of valve positions upon departure. Swab= shut, wing= shut, ssv= open, master= open, IA= open, OA=open FLUIDS PUMPED BBLS 4.6 METHANOL 4.6 TOTAL • • a ~ ~ I ~ ~ ~ p~t ~~~ ~ ~ SARAH PALIN, GOVERNOR ..~ .$ L~is[1-7~ OIL L7•.1~i1 ~L1~7 333 W. 7th AVENUE, SUITE 100 C01~5ERQA7'IO1~T COMI~'IISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Robertson Sr. Petroleum Engineer BP Exploration Alaska Inc. PO Box 196612 ©©~ " ~~ Anchorage, AK 99519-6612 `a Re: Prudhoe Bay FYeld, Prudhoe Bay Oil Pool, PBU W-42 Sundry Number: 308-275 Dear Mr. Robertson: S~M~~~i'~~ AEG :;<. ~ 2008 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ Daniel T. Seamount, Jr. Chair DATED this~° day of August, 2008 Encl. ~~~~ • STATE OF ALASKA r~ ~ (~ ALASKA OIL AND GAS CONSERVATION COMMISSIG~ka~ ~~ ~ ~Q(~$ ~~ ~ ~~~+ APPLICATION FOR SUNDRY PR VAL g ,,.. ~~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ 3~Vaiver ^ Othe Alter casing ^ Repair well ^~ Plug Perforations^ Stimulate ^ Time Extension ^ TUBING PATCH Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development^ Exploratory ^ 188-0570 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: Anchorage, AK 99519-6612 50-029-21816-00-00 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 W-42 Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028263 ~ 91 KB Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11825 _ 8824.3 _ 11783 8823.1 8979 PXN NONE Casing Length Size MD TVD Burst Collapse Conductor 80 20" 30 110 30 110 1530 520 Surface 2661 13-3/8" 72# L-80 29 2690 29 2690 5380 2670 Production 9929 9-5/8" 47# L-80 28 9957 28 8735 6870 4760 Liner 1956 5-1/2" 17# L-80 9896 11825 8715 8824 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SL 10112' - 11781' 8762.7' - 8823.4' 7" 26# L-80 SURFACE - 8800' - - 5-1/2" 17# L-80 8800' - 9866' Packers and SSSV Type: 5-1/2" TIW HBBP PKR Packers and SSSV MD (ft): 8896' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/13!2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Robertson Printed Name an Ro rt n Title Petroleun Engineer Signature ~ Phone 564-5546 Date 7/30/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent For quired: ~(,`~ APPROVED BY Approved by COMMISSIONER THE COMMISSION Date: Form 1~ ~evised 06/20 ~` Submit in Duplicate l~ ~ ~, ~ ~ S ~F~_ FaUG ~D ~ 20DB • by To: J. Bixby/ C. Olsen GPB Well Ops Team Leaders From: Dan Robertson, Petroleum Engineer DeWayne R. Schnorr, Design Engineer Subject: W-42i Install 5-1/2" L-80 Tubing Patch Date: July 29, 2008 AFE: PBWPDWL42-N Sundry 10-403: Est. Cost: $80,000 IOR: 500 1. S Run 5-1/2" Dummy Patch, install 5.5" XN x 2 7/8" X profile nipple reducer with plug installed at 8979 MD. Pressure test at 3000 psi. Pull 2 7/8" XX lu . 2. E Run Weatherford 5-1/2" tubing patch (2 trips, install lower packer, then ex ansion 'oint and u er acker assembl , 40' overall len th 3. F MIT-IA at 2500 si, Establish LLR if MIT-IA fails, ost atch 4. F AOGCC witnessed MITIA at 2500 si Current Status: Not Operable --- slow TxIA Communication, 0.08 gal/minute Typical Injection Rate: 12 MBWPD at 1000 psi Max Deviation: 90 degrees @ 10800' and Deviation at Perfs: 81 degrees @ 10112' and Min. ID: 4.455" @ 8979', 5-1/2" OTIS XN Nippie Note: Minimum ID through SSSV & SS is 4.562". Last Downhole Ops: 05/22/2008: TecWel LDL. Latest H2S level: Source Water Injection Job Objective The objective of this procedure is to run 5-1/2" tubing patch over seal assembly and packer to restore tubing integrity. Well History Source water injection well W-42 has a history of intermittent, slow, T x iA communication. The well failed a MITIA 1/08. A tailpipe plug was then installed and the tubing and inner annulus pressure tested independently. Both passed these pressure tests. Both the tubing hanger seals and intermediate casing hanger seals also passed pressure tests. The tailpipe plug was retrieved and another MITIA performed. This MITIA while on injection failed with a pressure bleed off rate of 360 psi/ hour. No leak rate was established. Injection water to this well is supplied directly from the W-400 water supply well via the electric submersible pump installed in W-400. Note that the injected source water is cooler than typical injection water, approximately 60 F, so the entire well is cooled significantly when on injection. It is possible that the leak may be somehow thermally induced. • • On 05/23/2008 a TecWel LDL was run and found a small leak (0.08 gal/minute) in the seal assembly above the packer. It is recommended that a patch with an expansion joint be set over the seal assembly and packer to eliminate this leak. This expansion joint will allow for seal assembly movement when 60 degree source water is injected into well. The overshot seal assembly above the packer was pinned to shear at 80M# overpull. It was not sheared when run, but tubing movement calculations simulating various conditions indicate it may have sheared through applied forces at some point in well life. Tubing movement calculations indicate seal movement on the order of 5-6' under typical injection conditions. Worst case seal movement of 8.5' is indicated with a deadhead ESP pressure of 2582 psi under injection conditions i.e. the entire wellbore cooled to 60 F. These conditions would require a complete obstruction below the packer to occur, in which case the rate is likely to be significantly reduced and tubing likely to be warmer than 60 F. The worst case conditions seem to have a low probability of occurrence. It is planned to run a 10' expansion joint which will allow for up to 10' of longitudinal seal movement. The polished riser in the well is 13.3' long, so if more than this amount of movement occurs it is possible the overshot seal assembly will be disengaged from the polished riser. Ann Comm Highlights > 04/26/07: MITIA Passed to 3000 psi, MITOA Passed to 2500 psi > 04/29/07: MITOA Failed - BH leaking > 05/29/07: Confirmed well will remain PWI only > 11/11/07: Gel-Seal SealTite repair WH leak > 01/11/08: MITIA Failed > 01/31/08: AOGCC MITIA Failed > 03/19108: Caliper 7": 104 jts <20%; 109 jts 20-40%; 12 jts 40-61 %. 5.5" 29 jts 1-22% > 03/20/08: Set TTP @ 8979' MD, MITT Passed to 3000 psi > 03/24/08: PPPOT-T Passed to 5000 psi, PPPOT-IC Passed to 3500 psi, LDS > 03/27/08: MITIA Passed to 2500 psi > 04/28/08: TTP pulled from 8979' > 05/10/08: MIT-IA Failed on pressure bleed off rate, no leak rate obtained > 05/22/08: Tecwel found leak @ top of packer ~ 0.08 gal/min If you have any questions or comments regarding this procedure, please call Dan Robertson at 564-5546 (w), 907-529-5818 (c) or 907-346-3714 (h). cc:j/s: Well File 2 Job Ob'ective ~ • The objective of this procedure is to run a 5-1/2" tubing patch with expansion joint over the seal assembly and packer to restore tubing integrity. Patch Specs 5-1/2" Weatherford patch, 40 ft long. L-80 patch with expansion joint is to be run. All components rated to at least 5000 psi differential pressure. Expansion joint allows for 10' of longitudinal movement, 4.125" OD, 2.375" ID Patch Depth Control - All depths are referenced to TecWel LDL log dated May 22, 2008. Patch Setting Depths are 8870' to 8910' ELMD Patch Length: 40' from element to element. Leak is above Packer and in the Latch Assembly @ 8893' ELM Collar. Locator Summary from ELine TecWel LDL log Note: Minimum ID - 4.562" through SSSV & Sliding Sleeve X-Over 8803' Sliding Sleeve 8823 Pup JT 8827' Tbg JT 8836+' Pup JT 8874' Seal Assembly 8879' Packer 8895' MOE 8898' Tbg JT 8904' X Nipple 8946' XN Nipple 8981' Pre-Patch 1. Assemble patch at Weatherford shop and drift with 2 7/8" XX plug. Plug OD is 2.313". Expansion joint ID is 2.375". 2. Drift tubing with 5.5" dummy patch to 9000 MD. Assuming patch drift in shop was successful, install 5.5" XN x 2 7/8" X profile nipple reducer with plug installed at 8979 MD. Pressure test at 3000 psi. Pull 2 7/8" XX plug. If shop patch drift was unsuccessful, do not install reducing nipple. Eline Set Weatherford Patch Installation 3. RU EL. RIH with lower packer of patch and tie into Jewelry around Packer @ 8895' ELM (reference TecWel LDL log 05/22/2008). Drop down and log up to setting depth. 4. Set lower packer of patch @ 8910'. See attached techwell log. • 5. PU & RIH with 10' expansion joint, 2 7/8" 6.5# L-80 pup joints as needed, upper packer and setting tool. Stab into lower packer and set upper packer per manufacturer's recommendation. If upper packer/ expansion joint assembly is too long to safely run in 1 trip, a slickstick type assembly can be used in multiple runs. Note: Run 10' Expansion joint, and pin it at 2000#. Note: After latching into lower packer, shear expansion joint and pull up 5' before setting upper packer. F (Post Patch) 6. MIT-IA to 2500 psi. Establish LLR if MIT-IA fails. Note that in the past the well has passed both tubing and IA pressure tests while shut in, but failed while on injection. May want to put the well on injection for a few days prior to MITIA. 7. AOGCC witnessed MITIA at 2500 psi. 4 TREE = 6" CAN WH.LHEAD= MCEVOY ACTUATOR -. }. OTIS KB. l3EV == 90.85' BF. liE\/ = 54.20' ~ KOP= _ Max Angle =v Datum WD = _~ 4234' 90 ~ 708DD' _ ~ ~ i 1924' Datum ND = $800' SS 13-3l8' CSG, 72#, L-8Q, D = 12.347 Minimum ID = 4.455" @ 8979' 5-1l2" OTIS XN NIP 17" X 5-112' XO, D = 4.892" 1 SLV, 1 5-112" TBG, 17#, L-BD, .0232 bpT, D = 4.892' 1 15-1?2' OTIS XN NP, D = 4.455 1-112" OTIS OV ERSHOT SEAL ASSY w? SFALS PERFORATDN Sl1MAMRY REF LOG: ANGLEAT TOP PERF: 81 ~ 10112' Note: Retar to Productbn CB for h'storical perT data SeE SPF NTERVAL OpNSgt DATE 5-1?2" SL7D 10112-11781 O \` 5-1/2" SLTD LNR 17#, 1-80. D = 4.$92" 5-112' LNR 17#. L-80, .0232 tpf, D = 4.892" 1'1825' DATE REV BY COMvHVTS DATE REV BY COMMENTS 07!22!88 ORIG HORIZ COMPLETION 08/24J06 JCMYPAG PXN PLUG PIALED 02/07103 71KAK WANERSAFETY NOTE 08/20A7 RDMV/PJC WAN ERSFTY NOTE DELETED 05118306 H PXN UG SET (05/13N8) D53/5?06 TW5/PJC SSSV MSBiT PULLED{00100?00) 05?15106 PJO MN D CORRECiFON 0832dfD6 COAMft.H WANER SAFEf1' NOTE W ~~ I SAFt'T1/ PWTES~ HDI~ONR'AL WELL - 70° ~ 9545' PRtJDFiOE BAY UNiT wFtt: w-42 FERA~ff No: Rt88D570 A PI No: 50-029-218 1 8-00 SEC 21. T7 1 N_ R1 ~ 8P Bcploratlan (Alaska) W-421--- PDS Caliper (07/10/2007) • 8870' ~- Pup JT f- Seal Assembly PATCH with Expansion Joint ~- Packer ~- MOE 8910' Slce'YE • is -OY2f . - - _ - -~- ~ __ _.. - - ;- - -t--__ ------- 1JU-A~2 Tec1/Uel LDL (05/22f2008) ~~-~- Reference Log __ t -~--- # -f --1--- ' > i 'acker 8940 Tie in ~ i ~ ~ ' f . , ,. ~~ - --~- -t --f-; ~--- ~ - -- { --: , _~__ ,1'~__ •-Suspect Leak - _ _. '• j. ~ ;; --- i _, ._ ~ l y ~ i I ~ - l ~ ' . _i =-- __.._ _ _. _ -- - -- -- - ---- - t .__. _ --, _ -~ --- i G ~ i ' -__..__~.T____.... 1 .. __-._ _ _ -- ~----1- - -------- ._ _ - _ _ _.1__ __ . I i. + ~ ~ _ r._ __. __ _ -._ ~ 1 ; ; ~ ~' ~ 1 __ .. ._ _.._.._ _' i V, ' .~~ ~ ~ cuwu 7 ' ~ ~ ., - r• • t . ~ ' uwot ww~at: ~~ . 'TUBING DE~i'AIL TURD ~, {.` .•~, ~-~uacrRS ~ooucno~+ taoLS - -~ . 7 `,?% q.M ~~alM •-AT O4 w~tM F '~~~ CLLMi as ,~ y ~ sa D.6 ` ~ ~ ~G ~. Lpipl ~zy,~5,t~ er+ f~.~. awwea~~ ~' Tw~cZa~ ~, = TUBING w:c « +~.sN• ~ .. a*~ac~.`~.. « rMwc //.o~~~ ...• aw~~twN~~., ~`~ ....+.-- ~ 7NWIO ai ~ • +~- n wX~~d 7e,Nf a I Bps ~+dt~ ~ 7 ~ae . ~_ o~:cR~.s~ _ QO ID ~ENGitk QEPTN =y a ,,.,3Z,,,1~_ 6- 4L Pia Tt -__..__._... 7'0 G•e?7 • ~ s.~ s ors s~ 4~/ ~~ - -a • a rr- Y y--ovFrt Su _-~,.~. Y.C .70 $+4t~ I.~ 4 .rC"'~._ ~~ % Wit` __..._ .____._.. 'I ~z ~ g // / ~ ~z~ r Jib -S~ ~ 17 ~ .~~~,~'~S ___.~. . '~' ~ ~ a ,; ~'~ ' iCt1i ~.~n .lf __ ~F t • S. 4 5-- rf' Tt,r- 8 SA~ S~~ .t7_~, x.~..- _ 0 9y ~ It 3f-AuKiP frs r .Y' !. -~.- - 31.z_~ ~..~ n i Jf • S2S ~ i7'{ .t •F o ~ ~ d '~ ,3 ' .~~~ ,~r~s ~-~~ ° .,'` ~: ~~' TAG ;,~~ • • y -~ ,~,rs:5 ° P~~ st ~ ~ 7 ~T T : .~ ~~.Ga L ~ ~--- ...,~-~, ., r ~-... ~ ; r ~ ~~ s A~~ G~4aI or ~iwi _.._..L.~ S ~' ?3-- 8 • • ~~ ~~r ProActive Diagnostic Services, Inc. To: AOt~C Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing (nspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ~~~p JUN ~ ~ 200$ ~tive~iagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245.8952 1) Leak Detection - WLD 23-May-08 W-~42 2) Signed Print Name: ~'r~l~,~ ; ~-I l ~ ~ ~~'~ ~,~,~ Lt- 1 BL / EDE 50-029-21816-00 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130. W. INTERNATIONAL AIRPORT RD SUITE C, ANChORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL ^i? ~. ~i ,?t7. "v :9~. v. _ ~...~ci^ WEBSITE : ti ~^~ . r,~ ~l'. C:\Documents and Settings\OwnerlDesktop\Transmit_BP.doc W-42 (PTD #1880570) Reclassified as Not Operable • Regg, James B (DOA) From: Sent: To: • NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj Saturday, May 24, 2008 9:18 AM Page 1,.4~2'~~ Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Robertson, Daniel B (Alaska); GPB, Wells Opt Eng; GPB, Optimization Engr Cc: Townsend, S. Eliot; U, ADW Wefl Integrity Engineer; Julian, Jennifer Y Subject: W-42 (PTD #1880570) Reclassified as Not Operable Ail, Well W-42 has been reclassified as Not Operable. The well failed an MIT-IA on 05110/08 and an LDL found a leak at the packer on 05/22!08. The plan forward far the well is to evaluate it far a packer squeeze. If the squeeze is not attempted, the well will be secured while waiting for another type of repair. Please call with any questions or concerns. Thank you, Andrea Hughes ~~A~NED JUN ~. ~. 2008 From: NSU, ADW Well Integrity Engineer Sent: Tuesday, April 29, 2008 2:02 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr West (GC2JWRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Robertson, Daniel B (Alaska); GPB, Wells Opt Eng; GPB, Optimization Engr Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Dahlem, Jason E Subject: W-42 (PTD #1880570) UNDER EVALUATION - Eval TxIA comm for AA Request All, W-42 (PTD #1880570) passed aMIT-IA to 2,500 psi while shut-in on 03/27/08, but exhibits TxIA communication. The plan forward is to place the well on produced water injection and perform an AOGCC witnessed MIT-IA, once the well is thermally stable, in order to obtain an AA for continued injection with slow TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Please see the attached MIT form for the test on 03/27/08 for more details. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator 6/4/2008 <w./ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~,~~ ~~Z~~t~ Sent: Tuesday, April 29, 2008 2:02 PM 1`'(Q To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Robertson, Daniel B (Alaska}; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Dahlem, Jason E Subject: W-42 (PTD #1880570) UNDER EVALUATION - Eval TxIA comm for AA Request Attachments: MIT PBU W-42 03-27-08.x1s All, / ~ ~ W-42 (PTD #1880570) passed aMIT-IA to 2,500 psi while shut-in on 03/27/08, but exhibits TxIA communication. The plan forward is to place the well on produced water injection and perform an AOGCC witnessed MIT-IA, once the well is thermally stable, in order to obtain~n AA for continued infection with slow TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Please see the attached MIT form for the test on 03/27/08 for more details. «MIT PBU W-42 03-27-08.x1s» ~ Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~ ~~ MAY 2 ~ 200 5/20/2008 ~~ , """ 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 / W Pad ~ ~ ~ ~ I~jId~C? DATE: 03127!08 OPERATOR REP: Andrea Hughes AOGCC REP: Packer De th Pretest Initial 15 Min. 30 Min. Well W-42 T e In'. N TVD ,312' Tubing 0 .250 250 250 Interval O P.T.D. 1880570 T e test P Test psi 2078 Casing 100 2500 2440 2410 P/F P Notes: MIT-IA for barrier verification. OA 0 0 0 0 Well T e In'. TVD Tubing Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well T e In'. TVD Tubing Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well T e In'. TVD Tubing Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well T e In'. TVD Tubing Interval P.T.D. T e test Test si Casing P1F 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 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 W-42 03-27-08.x1s • Page 1,~€~£ biu.-~u Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, February 17, 2008 7:44 PM ~ C~ ~~~~Do To: Regg, James B (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: RE: MIT PBU W-42 1-31-08 Tests Attachments: MIT PBU W-42 01-30-08 rev 1.xls Hi Jim and Bob, Attached is a revised MITIA form for W-42 (PTD #1880570). By reporting both tests, the reported results match the ~ inspector's forms except for the pre-test IA pressure on the second test, Our report documented a pressure of 2240 psi and the inspector reported 2230 psi. Please review the attached form and let me know if you have any further questions. Thank you, jf~9Zfl[L 68,, . ~. ell Integrity Coordinator PB ells Group Phone: (~~ 659-x1132 Pager: (907) 859-5'QU x1154 ~ FED ~ ~~ 10D From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, February 15, 2008 12:22 PM To: NSU, ADW Well Integrity Engineer Cc: Fleckenstein, Robert J (DOA) Subject: FW: MIT PBU W-42 1-31-08 Tests More MITs to review; appears to be similar to PBU 03-12 send earlier today. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Fleckenstein, Robert J (DOA) Sent: Friday, February 15, 2008 9:54 AM To: Regg, James B (DOA) Subject: MIT PBU W-42 1-31-08 Tests Jim, Attached are the three W-42 MIT tests. Same as the 03-12 tests. BobF Robert J. Fleckenstein Statistical Technician II Alaska Oil and Gas Conservation Commission 2/19/2008 • • 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.u\s; Tom_Maunder@admin.state.ak.us OPERATOR: BP Exploration (Alaska), Inc. ~ ~ '~ 'L''Z.~~(~:'~ FIELD /UNIT /PAD: Prudhoe Bay / PBU / W ' DATE: 01/31!08 OPERATOR REP: Andrea Hughes AOGCC REP: John Crisp Packer De Pretest Initial 15 Min. 30 Min. Well W-42 Type Inj. W TVD 8,312' Tubing 785 785 785 785 Interval O P.T.D. 1880570 Type test P Test psi 2078 Casing 1060 2500 2290 2240 P/F F Notes: MIT-IA to request Administrative Approval for OA 100 300 260 240 continued injection with slow IA repressurization First test failed. Well W-42 Type Inj. W TVD 8,312' Tubing 785 785 785 785 Interval O P.T.D. 1880570 Type test P Test psi 2078 Casing 2240 2500 2350 2225 P/F F Notes: MIT-IA to request Administrative Approval for OA 240 300 260 220 continued injection with slow IA repressurization. Second test failed. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD 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 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 2008-0131_MIT_PBU_W-42_(2tests)Jc.xls • MEMORANDUM To: Jim Regg ~~ ~ ~~~ g P.I. Supervisor FROiVL• John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 05, 2008 SliBJECT: Mechai~ica( Integrity Tests BP EXPLORATION (ALASKA) P_~IC W-42 PRUDHOE BAY (~NtT W-42 Src: Inspector NON-CONFIDENTLAL Reviewed By: P.I. Suprv ~~~ Comm Well Name: PRUDHOE BAY iP,VIT ~~~-42 Insp Num: mitJCr080201042719 Rel Insp Num: API Well Number: 50-029-21816-00-00 Permit Number: 188-057-0 Inspector Name: John Crisp Inspection Date: 1/31;2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 ~Iin. 60 Nlin. -~ Well ~ W-42 iT3'pe In], ~' W ~ TVD 8312 ~ ';~ I:1 1060 2500 2290 2240 i ~- I _- ' ] 880570 SPT ` P.T. sTypeTest ~ i Test psi 2078 i I OA i i o0 300 z6o Zoo ~ ~, ! _ Interval °T~R P/F F 78s 78s Tubing '; ~i ' 7s~ s, ~ i NOteS' MIT-IA for AA. 2.2 bbl's pumped. Pressure dropped from 2290 psi to 2240 psi in 5 minutes. This was more than 10% for failure. ~~~/~NNEt~ FEB ~ 0 2008 Tuesday, February O5, 2008 Page 1 of I • MEMORANDUM To: Jim Regg ~ 2~ ~ ~v o P.I. Supervisor ~f c( FROM: John Cnsp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February O5, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-42 PRUDHOE BAY U~iIT W-42 Src: Inspector NON-CONFIDENTIAL Reviewed Bv: P.I. Suprv ~~~- Comm Well Name: PRUDHOE BAY UNIT W-42 Insp Num: mitJCr080201043504 Rel Insp Num: ApI Well Number: 50-029-21816-00-00 Permit Number: ts8-os~-o Inspector Name: John Crisp Inspection Date: 1%31!2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~7~Ie11 ~~ W-42Type Inj. W ~ TVD ~ 83i2 "~ ~ jA ~ 2230 ~ 2500 `~ 2225 ~ ~ 2350 ~ ~ P T. ~ 1880570 ~Typ Te est ~ SPT ~~ Test p51 ~ 2078 ! OA ~ 240 ~ 300 ~ - 260 ~i 220 ~ Interval orHER P/F P " ~ Tubing ~ 7as ~s5 I ass gas j NOteS' Operator wanted to perform 2nd test for dianostic information..4 bbl pumped. ~~~N~ FEB ~ 0 200 Tuesday, February 0~, 2008 Page 1 of 1 oslzslo7 ~Chlll~ilb~1'1~~~' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99603-2838 ATTN: Beth ~~~~ NQV ~ ~ 2007 Well Job ~ 1 nn ^psrrintinn N0.4440 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay r)ntu RI Rnlnr Crl 15-39A 11661174 MEMORY PROD PROFILE 09/23/07 W-42 11745235 MEM SBHPS/TEMP 09/14/07 Z-07A N/A SBHP SURVEY - 09/14/07 1 A-04 11594519 SBHP SURVEY a - 08/26/07 1 Y-24 11630499 LDL 09/04/07 1 L5-28A 11855810 PRODUCTION PROFILE d 08/31/07 1 X-33 11849931 SBHP SURVEY - t{G 08!31/07 1 E-14A 11686784 LDL ~~ ~ 09!23/07 1 01-15A 11855509 DDL ~ - a(6 09/22/07 1 D-21 11626119 PRODUCTION PROFILE '~a - 09/11/07 1 K-07D 11745234 MEM PROD PROFILE C _ 09106107 1 11-32 11630498 PRODUCTION PROFILE L _ 09103/07 1 L-01 11745233 MEM LDL a (~ ~ - ~ 09/04/07 1 07-30A 11661168 MEM STP & CORRELATION 08/28/07 1 Z-28 11630500 INJECTION PROFILE '_~',. 09/05/07 1 Z-16 N/A SBHPS/JEWELRY / 09113/07 1 14-26 11676959 LDL -/1 09109/07 1 04-02A 11630504 LDL Jr 09/11/07 1 14-37 11695075 LDL 09!13!07 1 3-35/L-36 11630502 PRODUCTION PROFILE 09/09/07 1 1-LCMJG NIiT\IYV YYLG V\7C RGVCII-1 ~T ~lIV 1V11YV fR1Y V_RC.J, Ur[r1/WW-CYIVC l+Vi'T CAli11 IV: BP Exploration (Alaska) Inc. - Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~°A~' ~~ ~ q $~~~ h~ ~ ~_ Date Delivered: i ,a rpNly ,s;,;: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~ Anchorage, AK 99503-28 ATTN: Beth Received by: • • . - J SARAH PALIM, GO!/ERAIOR ~~ ® ~ ~~ 333 W. 7;h AVENUE, SUITE 100 ~i®wTL+~~arA-sts®~T !'e®~~r~,rs~+~~®~aT ~.s sd-7 s ~a ld ii ui~`7 1` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ,FAX (907) 276-7542 CANCELLATION ADMINISTRATIVE APPROVAL NO. AIO 3.009 ~~~~~~~ JAN ~ ~ 2008 Mr. Steve Rossberg, Wells Manager Attention: Well Integrity Engineer, PRB-24 ~~ Q ~/~ ~~ RE: Cancellation of Administrative Approval AIO 03.009 (Well PBU W-42) BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99~ 19-6612 Dear Mr. Rossberg: Pursuant to BP Exploration (Alaska) Inc. ("BPXA")'s request dated August 28, 2007 Alaska Oil and Gas Conservation Commission (`'Commission") hereby cancels Administrative Approval AIO 03.009, which allows continued water injection. This well exhibited tubing by inner annulus pressure 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 a number of restrictive conditions set out in the administrative approval. Since then, BPXA has shut in the well following a failed mechanical integrity test and a confirmed casinghead leak. BPXA states it does not intend to operate Well W'-42 without passing a mechanical integrity test of the outer annulus. Consequently, Administrative Approval AIO 03.009 no longer applies to operation of this well. Instead, injection in well PBLT VV-42 will be governed by provisions of the underlying AIO No. 3. DONE at Anchorage, Alaska and dated September 14, 2007. ,Q~~1y ~~ ~~ ~ ,~ ~~` ri, ~~~hn~ ~' ~' ~ ~ ;: ,a''~~alrma3r !! , ~~: ,. ~ - ~ 3 ` dr 5 i} /~~ N,. . r ` - ~~ ~` - , The Alaska Oil and Gas Conservation Commission iJanlel T . jeamOUnt, Jr. Commissioner Cathy P~ r oerster Commissioner • ELDiyIINISTRATIVE APPItGVAL AI® 3.009 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Sox 196612 Anchorage, AK 995 1 9-66 1 2 FRANK H. NlURKOIli/S1Cl, GO-1~R~lOR 333 W. 7'" AVENUE, SUITE 100 ANCHOFAGE, ALASKA 995Q1-3539 PHONE (907) 279-1433 FAX (907) 276-7542 RE: PBU W-42 (PTD 188-057} Request for Administrative Approval Dear iVlr. Rossberg: In accordance with Rule 9 of Area Injection Order ("AIO") 003.000, the Alaska Oil and Gas Conservation Commission (`'AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU UV-42. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, PBU W-42 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in PBU W-42 is conditioned upon the following: l . BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; 3. BPXA shall perform an annual MIT' - OA to 1.2 times the maximum anticipated well pressure, the anniversary date of which shall be this approval's effective date; Vir. Steve Rossberg tune 6, 2006 Page 2 of 2 ~ '~ 4. BPXA shall perform an annual ~~IIT' - L~ or CMIT - T Y IA to 1.2 times the maximum anticipated well pressure, the anniversary date of which shall be this approval's effective date; ~. BPX?. shall limit the well's OA pressure to 1000 psi: 6. BPXA shall immediately shut in the well and notify the A~G~C i~ there is any change in the well's mechanical condition; and 7. after well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. As provided in AS 31.0.080, 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 Pti1 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. DOtiE at An~hpr~.ge, Alaska and dated June 6, 2006. ! ~. Cathy P~'Foerster Commissioner ~ * ~ " "\ ~ ~~ ~ ~~,~ g ~ W`^ j ~ k ~ - A ~'~/ i V 't?L . 'S, a i ~,., ~ ~ `. L, i f ~l'~ `4.~ W-42 (PTD #1880570) Internal wal Cancellation Regg, James B (DOA) . Page 1 of 1 From: NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sent: Sunday, August 19, 20072:54 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: NSU, ADW Well Integrity Engineer; Robertson, Daniel B (Alaska); NSU, ADW WI Tech Subject: W-42 (PTD #1880570) Internal Waiver Cancellation í<:é'ff rt/Z1/01 All, An internal waiver was issued for TxlA communication on well W-42 (PTD #1880570) on 08/17/06. The well passed an MITIA on 04/26/07 proving two competent barriers. However, the well is currently shut-in and classified as Not Operable due to a / casing head leak. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Paperwork will also be sent to the AOGCC canceling the corresponding Administrative Approval. In addition, a new AA request will be sent to align with our new policy. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 iI,w;r'~ SEP 1 1 2007 SGANJ1lo"" 8/2912007 l\-lEMURANDUM . TO: '-:> !( ;...., (L¡ ,) 14 j Jim Regg P,I. Supervisor FROM: Jeff Jones Petroleum Inspector Well Name: PRUDHOE BAY UNIT W-42 Insp Num: miùJ070502110733 Rei Insp N urn: Well ' I P.T.DI WA2 Packer ¡Type Inj. ¡ W : TVD I :Typ~Te~t I SPT~ Test psi f 1880570 --- Interval REQVAR P/F F State of Alaska Alaska Oil and Gas Conservation comm. DATE: Thursday, May 03, 2007 SUBJECT: Mechamcallntegnty Tests BP EXPLORATIOì\ (ALASKA) INC \VA2 PRLDHOE SA Y lJMT W'42 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-029-21816-00-00 Permit Number: 188-057-0 Depth Pretest Initial \ q¡<b "" oS ~i~" B,:c__ P.I. Suprv -.J D!~ Comm Inspector Name: Jeff Jones Inspection Date: 4/29/2007 15 Min. 30 Min. 45 Min. 60 Min. .~---~ ----,--..--.-- I ---------~-- ---,---- IA I 1140 , ' <:>Ai--;40"- 8312 1 ]60 , I --t----~-------r-----_r_-~--- ! ' 2500 I -- 2078 __-.1..__ _/___!_~~ing__9~~~__ I Notes: MIT·OA for waiver compliance. Test aborted when tluid and vapor were observed leaking to atmosphere at the bottom of the braden head. Well shut in for repair. L/ ---~- ._._~_._---~--~ Thursday, May 03, 2007 sCANNED MAY 0 9 2007 Page I of 1 Re: W-42 Failed MIT; invalidated AA . . Thanks for your persistence with this well. Looks like you make the best decision possible in witnessing it. I did get your call about shutting in the well. You have the right to require the well to be shut in if they do not. The admin approval is clear about notification and actions if there is any change in the well's mechanical condition. I did get an email yesterday (4/30/07) from BP advising that W-42 was shut in and safed out due to braidenhead leak. I will discuss the test procedure and concerns about duration with BP. Jim Jeff Jones wrote: Hi Jim, I don't know if you got my phone message but this is a follow up e-mail. PBU well W-42 (PTD 1880570) has a waiver for water injection due to a known T x IA leak that requires a passing MIT-IA & MIT-OA for waiver compliance. On 4/29/07 I witnessed the failure of the MIT-OA where there was vapor & liquid released to atmosphere at the surface pipe/braden head connection in the cellar. I instructed them freeze protect & shut in the well. According to their own paperwork the pad operator had already reported this leak on 12/10/06 and no repairs had been made since. This well supposedly passed a non-state witnessed MIT-OA @ 2500 psi & MIT-IA @ 3000 psi on 4/26/07. The BPXA rep was trying to get me to waive witnessing these tests, after setting them up and canceling them and stringing it out a few days he called and tried to give 1 hour notice & asked if I would waive the witness since I couldn't witness them right away. I said no way, we need to see the MIT's. The competency situation at PBU DHD appears to be declining, it took 9+ hours to perform 2 MIT's yesterday and there are no BPXA employees that perform the actual testing anymore. Part of the problem as I see it is that with only contractors doing the tests they have a very difficult time getting a Little Red pump truck scheduled and BPXA doesn't supply enough or install the integral flanges they require for pumping in advance. If BPXA would make the pump trucks available and install the integral flanges in advance of testing it would take up much less of the Inspectors' time trying to get pump trucks for tests scheduled and waiting for them to get wells rigged up. This would free us up to do more witnessed tests in the field. Thanks, Jeff ... - - - '." $'~MAY 0''1 ZOD1 ¡" .~, ~ .. w . ~ ,"".' . "C.""Þ#.- '"',-..........................,..--...¡,...........'....\,.., 1 of 1 5/1/200710:37 AM " ,"'. """j 1,_' \! L~ U Ir¿ 5"/ðI/Oh e e ,2 I' 0"""00' ","d," n Repair Well D Plug Perforations D StimulateD Other [j Cancel Sundry Performed: Alter Casing --- Pull Tubing D Perforate New Pool 0 WaiverD Time Extension 0 Change Approved Program [J Operat. Shutdown D Pertorate 0 Re-enter Suspended WeilD I~' Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: ¡Name: DelÆlopment ¡- Exploratory r 188-0570 3. Address: P.O. Box 196612 Stratigraphic Sel"JÍce 9' 6. API Number: Anchorage, AK 99519-6612 50-029-21316-00-00 7. KB Elevation (ft): 9. Well Name and Number: 91 KB W-42 8. Property Designation: 10. Field!Pool(s): ADL-028263 Prudhoe Bay Field! Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 11325 feet Plugs (measured) 8979 PXN ; true vertical 8824.3 feet Junk (measured) None I I Effective Depth measured 11ì83 feet true vertical 8823.1 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" Conduotor 30 110 30 110 1530 520 Surface 2661 13-3/8" 72# L-80 29 2690 29 - 2689.96 5380 2670 Production 9929 9-5/8" 47# L-80 28 9957 28 - 8735.27 6870 4760 Liner 1956 5-1/2" 17# L-80 9869 11825 871522 - 8824.3 7740 5280 Perforation depth: Measured depth: 10112 - 11781 Slotted Liner True Vertical depth: 8762.7 - 8823.04 Slotted Liner Tubing: (size, grade. and measured depth) 7" 2ô# L-80 30 - 8800 5-1/2" 17# L·80 8800 - 9866 I ¡PaCkers and SSSV (type and measured depth) 5-1/2" T1W HBBP Packer 8896 , ¡ - .,., '. (\. "'1' 1\ I ";'J,0dNc.., ';';;iiiJ' ....,...' '~ ¡ 112. Stimulation or cement squeeze summary: ! Intervals treated (measured): , RBDMS 8FL JUN 0 1 2006 ¡Treatment descriptions including 'Jolumes used and final pressure: I 113. Representative Daily Average Production or Injection Data i Oil-Bbl Gas-Met Water-8bl Casing Pressure Tubing pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r DelÆlopment r Se!'\1ce 9' Daily Report of Well Operations X 16. Well Status after proposed work: Oil r Gas r WAG 9' GINJ r WINJ r;¡ WDSPL ,- , 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number Dr N/A if CO. Exempt: 302-170 Contact Anna Dube i Joe Anders Printed Name Anna Dube . . Title Well Integrity Coordinator ~ 8T A TE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS /"" ,/'-., ¡~J..L-,~_~l,'~C2"'A~' Phone 907-659-5102 Date 5/22/2006 S· t if..... ,- Igna u~ i'ifft"í '\A.-, v-l.,\.... :'''rm 1"": "Qa\1¡:nrl ()A l'JonA 911nmit O"igin~i On~/ ORIGINAL e e STATE OF ALASKA ALASKA OIL AND GAS .CONSERVATION COMMISSION; / \t~\\)0 Mechanlcallntegnty Test (t'4 (1 -? 1. Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Mauhder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay! PBU I W Pad OS/20/06 Anna Dube q..-os1 ,to Packer Depth Pretest Initial 15 Min. 30 Min. We1l1W-42 I Type Inj. I N TVD I 8,311' Tubing 300 600 600 600 Interval I V P.T.D.11880570 I Typetest ! p Test psi! 2077 Casing 850 3,000 2,950 2,910 P/F! P Notes: LLR-IA for Sundry #302-170 Compliance OA 0 0 0 0 AOGCC rep John Crisp declined to witness Weill I Type Inj. I I TVD I Tubing I Interval P.TD.I I Type test I I Test psi I Casing I P/F Notes: OA Weill I Type Inj.1 I TVD I I Tubing! I ! Interval I P.TD. I Type test I Test psi! Casing I I ! I P/FI Notes: OA I I Weill I Type Inj.1 I TVD I Tubing Interval! P.TD.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval! P.T.D.I I Type test I I Test psi I Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly SUlvey 0:::; Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) r\"'n"? c.\I'JC 2006-0520_MIT _PBU _ W-42.xls MEMORANDUM TO: Jim Regg ~11 jl (î-b 10'5 P.I. Supervisor ( l FROM: John Crisp Petroleum Inspector Well Name: PRUDHOE BAY UNIT W-42 Insp Num: mitJCr050512121834 Rei Insp Num: MITOP000000643 ) ) State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 20,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-42 PRUDHOE BAY UNIT W-42 ".-. *, ",,' "..",'1Q;:9·"'" ' \ (.¡:¡l I V l' Src: Inspector Reviewed By: P.I. Suprv<Jeæ..- 7/zpJD5 Comm NON-CONFIDENTIAL API Well Number: 50-029-21816-00-00 Permit Number: 188-057-0 Inspector Name: John Crisp Inspection Date: 5/10/2005 Packer Wen W-42 ITYpe Ioj. W I TVD P.T. 1880570 ITypeTest SPT I Test psi Interval REQVAR P/F F Notes: We repressured IA three times to verify leak rate. This well has variance for Tbg x IA corom. 02/07/03. This was a LLRT as required by variance, Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 8312 IA 700 3020 2750 2078 OA 0 0 0 0 Tubing 500 500 500 500 Wednesday, July 20, 2005 :SCANNED f\UG 0 '9 2005 Page I of 1 ~~!!!~~J1,~~}1f~~'} . . ... . .... ............... ,~~~:»;t:...~~~S,:.,~,~.~g~'i~µ~eg9~a~JJ1Î11.s~a~~....~~:US>· , ~~~~,1;~~~~~~~~j~~*1' .:"X;:~~~"·i. · .,....,... ,'.. . .~..: ~~;: . ,', ..,....' ""0 :, .~;.;. "";, :,".; :,,:.; .':;.:,,, ',", .::::".'::::,.:.;.;"..:: . .: ",:, '", : :-.~. : :', : .' '" re: PBU W-42 MIT done 5/10/05; this was the MIT you asked me about when in office last; snapshot attached. You inspection report shows test as a pass; did not show the 30 minute pressure for IA I suggest you edit report with following changes: 1) Add a remark that this was a LLRT as required by variance 2) Show the MIT as a failure Jim Content-Type: application/octet-stream 2005-0510_MIT_PBU_ W-42.Jc.snp j Content-Encoding: base64 1 of 1 5/17/2005 10:01 AM ) ) Subject: Re: 03-33B (PTD #L050180), V-221 (PTD #2050130), 09-20 (PTD #1770410), Z-103 (PTD siit'#2042290) and W -42 (PTD #1880570) MITIAs ~ 1/ From: James Regg <jim_regg@admin.state.ak.us> Date: Fri, 13 May 2005 10:16:35 -0800 To: '~SU, ADW Well.~tegrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> CC: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> Anna - John Crisp was in the office yesterday and we discussed the W-42 MIT¡ actually, based on what he explained to me, this appears to be the annual LLRT required by a past sundry approval. He noted that they had difficulty getting the IA to pressure up, and it would not hold pressure after multiple attempts. John was unclear about the objective of the test, but agreed to witness since he was in the area for other tests. We do not routinely witness the LLRT because there is no acceptance criteria (no limits have been agreed upon) that guide us like a conventional MIT. Please ask whoever is contacting the inspectors about scheduling a MIT (or other test) to be clear about the test type and test objective. Thanks. Specific to the W-42 test, the leak rate has increased (from 0.3 gpm to 1.7 gpm) and this is the first MIT-IA failure since the 4/2002 failure (passed MITIA in 4/2003 and 4/2004), indicating possible deteriorating conditions in the well. Is BP planning additional diagnostics (CMIT TxIA) to confirm the production casing remains a casing barrier (appears that one is due in December of this year)? Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Jim, Winton, and Bob, Please see the attached MITIA forms for the following wells: 03-33B (PTD #2050180) V-221 (PTD #2050130) 09-20 (PTD #1770410) 2-103 (PTD #2042290) W-42 (PTD #1880570) «MIT PBU W-42 OS-10-0S.xls» «MIT PBU V-221 OS-10-0S.xls» «MIT PBU 2-103 OS-10-0S.xls» «MIT PBU 09-20 OS-10-QS.xls» «MIT PBU 03-33B OS-10-0S.xls» AOGCC representative John Crisp witnessed these tests. 03-33B, V-221, and 2-103 are post initial injection. 09-20 is for the UIC 4 year required test post RWO. W-42 is compliance testing for the slow TxIA sundry. Please let me know if you have any questions. Thank you, * / Anna Dube/* *Well Integrity Coordinator* *GPB Wells Group* * Phone : (907) 659-5102* *Pager: (907) 659-5100 x11S4* I of 1 5/17/2005 10:01 AM ) Alaska Oil and Gas Conservation Comm.. .1n ~(a(e 01 AlaSKa H' .I.ßl U. V.&1-\.l ~ U U 1 t'J. TO: Jim Rega '17 P.I. Super~isor l\ê11 ~11:.;loç DATE: Wednesday, June 15,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-42 PRUDHOE BAY UNIT W-42 vCõf{¡J 067 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ~/"I P.I. Suprv"J~ Comm Well Name: PRUDHOE BAY UNIT W-42 Insp Num: mitCS050612083506 ReI Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-21816-00-00 Permit Number: 188-057-0 Inspector Name: Chuck Scheve Inspection Date: 6/11/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well W-42 Type Inj. I N I TVD 8312 I IA 410 3000 2980 2980 I I P.T. 1880570 TypeTest I SPT : Test psi 2078 lOA 0 0 0 0 I Interval OTHER P/F p Tubing 430 2925 2910 2900 Notes: This well has a known tubing leak. A plug had been set in the tubing tail and the tubing and lA were pressured together verifying the integrity of the production casing. SG,ANNED JUl O? 200:1 Wednesday, June 15,2005 Page I of I STATUS: W-42 (PTD #1880570) '. '. . . ..... ..... ...... .... ..... . ..........) ...... ) $:1Ì~je~t~~~it\.T1.f~ :~T~~~~W~:#~·8ß~'$S~~)¡.':.. ..... ............:.. .........»...:..... ..... .' .... ... .i.. ...,..........................................,........., .... .........'....... .......... ..)...... ...................... ............ ... ¡rrrm.:...·."~f)~~.·.·~~....Y'f.~tl·...W~T~ty.·]j~gil1e~r1~..~NSV~WMT~.UWte~ityltl1gil1e~t@~·r...~()ll1?".;· ])~te:Fri,03~u;ll~00514:QO':47 ~0800· Hi Jim. Thanks for the note, sorry about the delay in this response. We will schedule setting a TTP and conduct the CMIT TxIA in well W-42. Please call if you have any questions. Joe 659-5102 -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Friday, May 13, 2005 10:17 AM To: NSU, ADW Well Integrity Engineer Cc: Winton Aubert (E-mail) Subject: Re: 03-33B (PTD #2050180), V-221 (PTD #2050130), 09-20 (PTD #1770410), Z-103 (PTD #2042290) and W-42 (PTD #1880570) MITIAs Anna - John Crisp was in the office yesterday and we discussed the W-42 MIT¡ actually, based on what he explained to me, this appears to be the annual LLRT required by a past sundry approval. He noted that they had difficulty getting the IA to pressure up, and it would not hold pressure after multiple attempts. John was unclear about the objective of the test, but agreed to witness since he was in the area for other tests. We do not routinely witness the LLRT because there is no acceptance criteria (no limits have been agreed upon) that guide us like a conventional MIT. Please ask whoever is contacting the inspectors about scheduling a MIT (or other test) to be clear about the test type and test objective. Thanks. Specific to the W-42 test, the leak rate has increased (from 0.3 gpm to 1.7 gpm) and this is the first MIT-IA failure since the 4/2002 failure (passed MITIA in 4/2003 and 4/2004), indicating possible deteriorating conditions in the well. Is BP planning additional diagnostics (CMIT TxIA) to confirm the production casing remains a casing barrier (appears that one is due in December of this year)? Jim Regg AOGCC SCANNEC .Iln (ì f'¡ 2 0 rPl , I· V '1,. NSU, ADW Well Integrity Engineer wrote: Jim, Winton, and Bob, Please see the attached MITIA forms for the following wells: 03-33B (PTD #2050180) V-221 (PTD #2050130) o 9 - 2 0 (PTD # 1 7 7 04 1 0 ) 2-103 (PTD #2042290) W-42 (PTD #1880570) 1 of 2 6/20/2005 3 :42 PM STATUS: W-42 (PTD #1880570) ') ) «MIT PBU W-42 05-10-05.xls» «MIT PBU V-221 05-10-05.xls» «MIT PBU 2-103 05-10-05.xls» «MIT PBU 09-20 05-10-05.xls» «MIT PBU 03-33B 05-10-05.xls» AOGCC representative John Crisp witnessed these tests. 03-33B, V-221, and Z-103 are post initial injection. 09-20 is for the UIC 4 year required test post RWO. W-42 is compliance testing for the slow TxIA sundry. please let me know if you have any questions. Thank you, * /Anna Dube/* *Well Integrity Coordinator* *GPB Wells Group* * Phone: ( 907 ) 659 - 51 02* *Pager: (907) 659-5100 xl154* 20f2 6/20/2005 3 :42 PM Re: 03~33B (PTD #2050180), V-221 (PTD #205)130), 09-20 (PTD... ) Subject:Re: 03-33B (PTD #2050180), V-221 (PTD#2050130), 09-20 (PTD #1770410), Z-103(PTD #2042290) and W-42 (pTD #1880570) MITIAs From: James Regg <jim_regg@admin.state.ak.us> Date: Fri,13 May 2005 10:16:35 -0800 ..' ... . ' To: ."NSU,.ADWWef1:IntegritY·Ëngih~er"'<~SµApWW~1I~tegntyEhgi1iè6r@BP . com> , CC : "Wititon Aubert (E~mail)" <winton ~âµbert@adtnii1~state~ak. ùs>: Anna - John Crisp was in the office yesterday and we discussed the W-42 MIT¡ actually, based on what he explained to me, this appears to be the annual LLRT required by a past sundry approval. He noted that they had difficulty getting the IA to pressure up, and it would not hold pressure after multiple attempts. John was unclear about the objective of the test, but agreed to witness since he was in the area for other tests. We do not routinely witness the LLRT because there is no acceptance criteria (no limits have been agreed upon) that guide us like a conventional MIT. Please ask whoever is contacting the inspectors about scheduling a MIT (or other test) to be clear about the test type and test objective. Thanks. Specific to the W-42 test, the leak rate has increased (from 0.3 gpm to 1.7 gpm) and this is the first MIT-IA failure since the 4/2002 failure (passed MITIA in 4/2003 and 4/2004), indicating possible deteriorating conditions in the well. Is BP planning additional diagnostics (CMIT TxIA) to confirm the production casing remains a casing barrier (appears that one is due in December of this year)? Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Jim, Winton, and Bob, Please see the attached MITIA forms for the following wells: 03-33B (PTD #2050180) V-221 (PTD #2050130) 09-20 (PTD #1770410) 2-103 (PTD #2042290) W-42 (PTD #1880570) «MIT PBU W-42 05-10-05.xls» «MIT PBU V-221 05-10-05.xls» «MIT PBU Z-103 05-10-05.xls» «MIT PBU 09-20 05-10-05.xls» «MIT PBU 03-33B 05-10-05.xls» AOGCC representative John Crisp witnessed these tests. 03-33B, V-221, and Z-103 are post initial injection. 09-20 is for the UIC 4 year required test post RWO. W-42 is compliance testing for the slow TxIA sundry. Please let me know if you have any questions. Thank you, * IAnna Dube/* *Well Integrity Coordinator* *GPB Wells Group* *Phone: (907) 659-5102* *Pager: (907) 659-5100 xl154* '\\ .....~- 'UN t"'J ~ö ~QQ5 ~~$CAN~~t.\) '''' (..,' '- 1 of 1 5/24/2005 10:59 AM ...... it STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / 04/24/03 Joe Anders Well IW-42 Type Inj. P.T.D. I1880570 Notes: Annual LLRT, required by Sundry WellI Type Inj. P.T.D.I Notes: WellI Type Inj. P.T.D.I Notes: WellI Type Inj. P.T.D.I Notes: WellI Type Inj. , Notes: Packer Depths (ft.) Pretest Initial 15Min. 30 Min. Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test 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 Revised: 06/19/02 2003-0424_M IT_PBU_W-42.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ 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 1495' FNL, 1455' FEL, Sec. 21, T11N, R12E, UM At top of productive interval 4732' FNL, 720' FEL, Sec. 21, T11 N, R12E, UM At effective depth 1079' FNL, 353' FEL, Sec. 28, T11N, R12E, UM At total depth 1120' FNL, 343' FEL, Sec. 28 T11N, R12E, UM 5. Type of Well: Development _ Exploratory __ Stratigraphic __ Service_X (asp's 611788, 5958757) (asp's 612579,5955532) (asp's 612974, 5953910) (asp's 612985, 5953870) 6. Datum elevation (DF or KB feet) RKB 91.0 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-42 9. Permit number / approval number 1880570 10. APl number 50-029-21816-00 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2653' Intermediate 9920' Sidetrack Liner 243' Slotted Liner 1669' 11825 feet Plugs (measured) 8824 feet 11783 feet Junk (measured) 8823 feet Size Cemented Measured Depth True vertical Depth 20" 72 c.f. concrete 147' 147' 13-3/8" 3840 c.f. Cold Set II 2690' 2690' 9-5/8" 2222 c.f. Class 'G' 9957' 8735' 5-1/2" Uncemented 9869' - 10112' 8715' - 8763' 5-1/2" Uncemented 10112' - 11781' 8763' - 8823' Perforation depth: measured Slotted Liner 10112' - 11781' true vertical Slotted Liner 8672' - 8730' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 7", 26¢, L-80 TBG 8 8800'. 7" x 5-1/2" 8 8800', 5-1/~fa~ 5-1/2" 17¢ Tubing Tail Below PKR to 9866'. 9-5/8" x 5-1/2" TIW HBBP Packer ~ 8896'. 7" Landing Nipple (No SSSV Catergow II) ~ 2001'. 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation May 23, 2002 16. If proposal was verbally approved Name of approver Date approved Oil _ Gas _ Service Water Iniector Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~(/~I ¢~ Title: Well Integrity Engineer Joe Anders, P.E. FOR COMMISSION USE ONLY Questions? Call Joe Anders or Kevin Yeager at 659-5102. Date May 23, 2002 Prepared by DeWayne R. Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness I Approval no:_~,,~c~- --/,,~.¢ Plug integrity_ . B,.OP Test _ ~ Location clearance _ Mechanical Integrity Test)(.. ~ ~ ,~ ~ Sqbseg~ent form required 1,0- Approved by order of the Oommission ~oinal Slg~ed g~ CommisSioner D~te [ ~ ['~ [ ~')r ~ ' ' ........ "S ED JUN 200Z' Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE W-42 Description Summary of Proposal O5/23/O2 Problem: Injector with Slow TxlA communication Well History and Status Well W-42 (PTD 1880570) is an injector that failed an MIT-IA on 09/01/01. The Pad Operator reported high IA pressure and an MITIA was conducted to evaluate the pressure source. A LLR of .3 gpm @ 3000 psi established. Recent events: > 09/01/01: MITIA Failed, 350 psi/15 min. > 11/11/01: SL set sleeve across sliding sleeve, MITIA still failed > 11/12/01' Pulled sleeve, set XXN plug' > 12/27/01' CMIT T x IA passed to 2500 psi > 12/28/01: WL pulled XXN plug > 04/07/02: MITIA Failed, LLR = 0.28 GPM @ 3000 psi (70 psi/15 min) This sundry request is to allow for continued injection of water. The following supports the request: - A CMIT-TxIA Passed on 12/27/01 to 2500 psi against a tubing plug, ~ demonstrating competent production casing. - Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. - An annual IA leak rate test will be conducted to monitor the leak severity. - A CMIT TxlA against a TTP will be conducted every 4 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.'J'/ 4. Perform an annual IA leak rate test. 5. Perform combination MIT Tubing x IA against a plug every 4 years. 6. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. 5GANNED JUN 2'~ ~00~. TREE = 6" CIW W 42 A~q'UATOR = ' 0~[~'1 KB~ E~ ~ ..... ~'~'5; 9545' ~D90° ~ 10800' BF. ~ = 54.20' K~ = 4234' ~ H DatumM~An~b=MD= ~0800'~ ~024' ~atumWD = ~00' ~inimum ID = 3.8~ 3" ~ 200 I ~",~,~,~-~o,o.o~,,,~=~.~"~ ~oo' ~ ~ ~~t ~oo' H ~'~-~"~°1 ~F kOG: I ANGLEATTOP P~F: 81 ~ 10112' ~te: Refer to ~oduc~on DB for hisDrical ~rf da~ 10112-11781 ' 'DATE ~ BY COMME~S ~TE R~ BY ~MM~TS ~U~OE BAY UNIT 07/22/88 ORIG HORIZ COM~ON W~L: W-42 02/16/01 SIS-~A ~NVE~EDTO CANVAS ~IT No: 188-0570 03/05/01 SIS-LG RNAL APINo: 50-029-21816-00 01/04/02 R~TP ~R~IONS SEC 21, T11N, R12E ,, ~ ~ploration (Alaska) ., . , . ... II1-1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perfom/J~'_ Repair well _ 6. Datum elevation (DF or KB-f~t)- ............. ~ RKB 91 feet CONVERSI~t,% Oth~_X SI MI well to H20_.,.~ CONVERSION FROM SI MI to H20 Pull tubing _ Alter casing _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1495' FNL, 1455' FEL, Sec. 21, T11N, R12E, UM At top of productive interval 4732' FNL, 720' FEL, Sec. 21, T11N, R12E, UM At effective depth 1079' FNL, 353' FEL, Sec. 28, T11N, R12E, UM At total depth 1120' FNL, 343' FEL, Sec. 28, T11N, R12E, UM 5. Type of Well: Development _ Exploratory__ Stratigraphic__ Service__X (asp's 611788, 5958757) (asp's 612579, 5955532) (asp's 612974, 5953910) ~sp~ 612985, 5953870) 7. Unit or Property name Prudhoe Bay Unit 8. Well number W-42 9. Permit number / approval number 188-057 10. APl number 50-029-21816 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11825 feet Plugs (measured) 8824 feet Effective depth: measured true vertical Casing Length Conductor 110' Surface 2653' Production 9920' SideTrack Liner 243' Slotted Liner 1669' Perforation depth: 11783 feet Junk (measured) 8823 feet Size Cemented Measured Depth True Vertical Depth 20" x 30" 72 c.f. concrete 147' 147' 13-3/8" 3840 c.f. Cold Set II 2690' 2690' 9-5/8" 2222 c.f. Class 'G' 9957' 8735' 5-1/2" Uncemented 9869' - 10112' 8715' - 8763' ,~ 8763' - 8823' 5-1/2" Uncemented 10112'-1178' ~E~IVEp measured Slotted Liner 10112' - 11781' true vertical Slotted Liner 8672'- 8730' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) JUL ! 5 200£ Alaska Oif & Gas (',o~s. Oor~'~rass~" Anchorace 7", 26#, L-80 TBG @ 8800'. 7" x 5-1/2" @ 8800', 5-1/2" 17#to PKR @ 8896'. 5-1/2" 17# Tubing Tail below PKR to 9866'. 9-5/8" x 5-1/2" TIW HBBP Packer @ 8896'. 7" Landing Nipple (No SSSV Catergory II) @ 2001'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 12/31/2001 Subsequent to operation 01/10/2002 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Shut-In 45OO Tubing Pressure 104 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __ 16. Status of well classification as: Oil__ Gas__ Suspended_ Service WATER INJECTOR _. Date January 18,2002 / Prepared by DeWar/ne R. Schnorr 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE W-42 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/11/2001 11/12/2001 11/13/2001 12/26/2001 1 2/27/2001 1 2/28/2001 12/29/2001 01/01/2002 01/10/2OO2 INJECTION CONVERSION: SET SLV IN SSD-MITIA (INJ CONV) INJECTION CONVERSION: SET SLV IN SSD (INJ CONV) INJECTION CONVERSION: SET XXN PLUG (INJ CONV) INJECTION CONVERSION: BLEED TBG INJECTION CONVERSION: LOAD TBG, MITIA, CMIT T X IA, MIT T INJECTION CONVERSION: PULL 5 1/2 XXN PLUG INJECTION CONVERSION: PULL 5 1/2 XXN PLUG STARTED WATER INJECTION WATER INJECTION RATE EVENT SUMMARY 11/11/01 SET SLEEVE ACROSS SLIDING SIDE DOOR AT 8798' WLM. ATTEMPT TO MIT IA. FAILED TWICE (WENT FROM 2000 PSI TO 1800 PSI IN 15 MIN). IN PROGRESS. 11/12/01 SET BLANK INSERT IN SVN. ATTEMPT TO MIT IA. FAILED TWICE. PULL INSERT. PULL SLEEVE FROM SSD. RAN 5 1/2" XXN PLUG. IN PROGRESS. 11/13/01 SET 5 1/2" XXN PLUG @ 8947' WLM. RAN CHECK SET. SHEARED PIN INDICATED GOOD SET. RDMO. 12/26/01 BLED TBG TO 170 PSI (CMIT PREP) [Ann Comm, BLEED TBG] 12/27/O 1 MITIA PASSED, CMIT T X IA PASSED, MIT T PASSED [Ann Comm, LOAD TBG, MITIA, MIT T, CMIT T X IA] 12/28/O 1 RUN 5 1/2 EQ. PRONG TO 5 1/2 XXN PLUG @ 8944' WLM -- RUN 2.50" PUMP BAILER TO PLUG @ 8944' WLM 1 2/29/O 1 RUN 5 1/2 EQ. PRONG TO 5 1/2 XXN PLUG @ 8944' WLM -- PULL 5 1/2 XXN PLUG FROM XN NIPPLE @ 8944' WLM 01/01/02 STARTED WATER INJECTION 01/10/02 WATER INJECTION RATE IS 4500 BWPD @ 104 PSI. FLUIDS PUMPED BBLS 348 50/50 METHANOL 8 DIESEL 356 TOTAL Page 1 TREE= 6" CIW SAFETY NOTES: 7" SSSV HAS 3.813" W 42 ACTUATOR = OTIS KB. ELEV = 90.9E 9545' AND90° @ 10800' BF. ELEV = 54.20' KOP 4234' MaxAn~lle= 90@10800' ~ J 2001' H7"OTISSSSVLANDNGNIP, ID=3.813"I Datum TVD = 8800' SS I ~'~'~" ~, ~', ~-~o,,~: 12.347" H 2690' Minimum ID = 3.813" @ 2001' INSERT INSIDE 7" SSSV NIPPLE I ~"~,~#,~-~o,o.o~,,,~=~.~'H ~oo'1 ~ , t 8~oo' I-I ~'x~-~,~"xol [ TOP OF 5-1/2" TBGH 8800' I ! I 8'?~' 1~5'112"OT~SXNNP,'D=4.455"I PERFORATION SUMMA RY REF LOG: ANGLEATTOP PERF: 81 @ 10112' Note: Refer to R'oduc~on DB for historical perf data 5-1/2" 10112-1178~ SLID DATE REV BY COMMENTS DATE REV BY OOrv/vlENTS PRUDHOE BAY UNIT 07/22/88 ORIG HORIZ COMFLETION WFIL: W-42 02/16/01 SIS-QAA CONVERTED TO CANVAS PERMIT No: 188-0570 03/05/01 SIS-LG RNAL APINo: 50-029-21816-00 01/04/02 RN/TP CORRECTIONS SEC 21, T11N, R12E BP Exploration (Alaska) DATE REV BY COMMENTS DATE REV BY COMMENTS 07~22~88 ORIG HORIZ COMFLETION 02/16/01 SIS-QAA CONVERTED TO CANVAS 03/05/01 SlS-LG RNAL 01/04/02 RN/TP CORRECTIONS MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor~T' DATE: September 1, 2001 Chair _ ,~, S~..UBJECT: Mechanical Integrity Tests THRU: Tom Maunderp.i. Supervisor ~:~['~ ~(\~ BPX W-P & H Pads c~ ', W-42 P-24 & H-31 FROM: John Crisp Prudhoe Bay Unit Petroleum Inspector Prudhoe Bay Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. w,,~l w-,2 I Type~nj.I N I T-V.9. I ~3~21Tu~i.gl 2~1 2~1 2~01 I,.~e..,I O p.T.D.I, 1880570 IType testI P I Test psi'I 2078 I,CasingI0 I 3ooo I 2720 I I P/F I No~t~: Converted from Producer. wa~I P-24 I Type~nj.I G I T.V.O. 18734 'lTubingl 34~g I 3,~ I 3,~ I 3,~ I~.t~,a~l 4 ,'.T-D.I '~,705~ ITypet=! . I-r,,.t,s,I 2183 I casir.:jI 700 I 2500 I 2480 I 2480 I "~ I'_.., We,I H-3'~ I Type,.j.! ~ I T.V.D. I s4.~7 ITubi.gl 3~2S I 3r:,50 I 3~1 ~ I*"te~a~l 4 WellI P.T.D.I Notes: P.T.D.I I Typ~ t.j.II T.V.D. I I Tubing I I I I l intervall ' Type testII're-",,~l ICasingI I I I I P~: I Type testII Test psiI · I Casing II I I I P/F I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Itraveled to BP's Prudhoe Bay Field to witness MIT's on W-P & H Pads. These MIT's were spread out over the Field causing longer than normal test & travel times. One failure witnessed, W-42. Kevin Yeager was BP Rep. in charge of testing. Testing was conducted in a safe & efficient manner. As always, Kevin was a pleasure to work with. M.I.T.'s performed: 3 Attachments: Number of Failures: 1_ Total Time during tests: _6 CC.' MIT report form 5/12/00 L.G. MIT PBU W-P & H Pads 9-01-01jc.xls 9/4/01 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO ARCO EXXON Date: 05/18/89 T~: 79392 SYSTEM Tape & Transmittal Only ARCHIVES BP MAGNETIC LIS TAPE & LISTING The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: W-42 OH/MWD/Mag Tape 07/14/88 9- 9325-11830 TP9 6092 Teleco#636 1600bpi API~50-029-2i8!6 Please Replace this tape for the one we sent to you on ~0/10/88 If you have any question please give me a call at 564-4445. /0 > Received: Date: Information Control Well Records LR2-1 J. Dietz/S. McCurry BP EXPLORATION -~CO BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 E~L~ON Date: Of/f 3/89 ~O: PHILLIPS ~: 79392 STATE OF AK SYSTEMS (Transmittal & Tape) ARCHIVES ~CE: BP MAGN-ETIC LIS TAPES & LISTINGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: /W-42 OH Teieco MWD Mag tape T~eco#636 1600bpi 07/14/88 #I 9300-11830 Tape Pos.~06092 * E~ON: An Asterisk (*) next to a listing above means you should have received the Tape(s) and Listing(s) directly from the respective service company. Please confirm this. Received Date Jennifer Dietz ~ We!! Records LR2-t · BP E)(PLORATION HOUSTON ARCO CHEVRON E.~LTON TEXAuO MOBIL PHILLIPS BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anct~orage, Alaska 99519-6612 (907) 561-5111 I NOEXED Date: 02/14/89 79812 STATE OF ALASKA GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES B~ CASED HOLE FINAL LOGS The follo~!ng mater|al Is being submit'i'ed herewith. Please acknowledge receipt by signing a copy of this let't'er and returning It to this office: A-12 Prod 02/08/89 F-I I Prod 02/09/89 H-14 Prod 02/06/89 W. 38 Prod 02/10/89 W-42" HP- Press Fa~-Of f 02/09/89 7941-9628 Sch 5" 8900-9480 Sch 5" 10350-10878 Sch 5" 14200-14680 Atlas 5" #I 9600-9600 Sch Received Date Jennifer Dietz NFORMAT 1 ON CCNTROL t I Records LR2-1 TO: REFERENCE: HOUSTO,, ARCO CHEVRON E~XON TEXACO MO B IL PHILLIPS STATE OF ALASF~ GEOSCIENCES RESERVOIR ARCHIVES SAPC CASED HOLE FINAL LOGS I ND£XED STANDARD '~.! l'.,c'.'2:: / . ,.) . Date: 10-31-88 r#: 79483 B-09 ""- c-J5 ~'~ C-30 ~F-02 -'~G-02 '-'"' H-08 '~ W-29 ~ W-42 --7 Z-20 ~ Z~20 The following material ls being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: FBS/INJ 10-25-88 #3 9550-9923 Sch 5" CNL/GR (2.5" Tool) 10-24-88 #4 9000-9757 Sch 5" CNL 10-22-88 #1 8750-9701 Sch 5" PROD 10-23-88 #1 10150-10600 Sch 5" CCL/PERF 10-24-88 #1 8820-9400 Sch 5" CNL 10-23-88 #5 8868-9423 Sch 5" PROD 10-24-88 #1 10550-10895 Sch 5" HiP-PRESS Fall-off 10-21-88 #1 9600~9600 Sch CBT 10-22-88 #1 10265-11518 Sch 5" CET 10-22-88 #1 10265-11540 Sch 5" Rece ~ ved Da te .Oil & Clas cons. Commi~aion ,, gnchoraga Fou-ded ,- Cle.elo~:l. C)~,o. ,,, 1870 Shirley R. McCurry [NFORMAY[ON CONTROL Well Records LR2-1 TO: TEXACO INDEXED STANDARD ALASF-~ PI~ODUCTION Date: 08/09/88 TI: 79173 MARATHON MOBIL PHILLIPS C-~.._STATE OF ALAS~ GEOSCIENCES REFERENCE: ARCHIVES SAPC OPEN HOLE FINAL LOGS The followlng material ls being submitted herewith. Please acknowledge recelpt by signing a copy of thls letter and returning It to thls office: DAL/UNIT/STATE: W-42 MWD Teleco 07/04-14/88 #12,14-19 9340-11801 5" & 2" W-42 MWD-TVD " " " " II II II II STAT E ONLY: Magnetic Single Shot Directional Survey Date: Gyroscopic Directional ~['v~55~ I ~1 E t~ Date: Rece I ved , DIRECTIONAL SURVEYS 7~19~,88 8~05~,88 7~.19-.88 Date gla~ka Oii & Gas Cons; Commission Founded ;~ Cle~elond. ~io. ,n 1870 AL688-D18 Job//: 72882 : 636 Victoria Aldridge I NFORHA/I ON CONTROL Wel I Records LR2-1 ~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CL,,,ViMISSION WI=! I COMP! ETLON OR RECOMPLETION REPORT AND L 1. Status of Well Classification of Service Well Hioh AnQle Gas - Iniector OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] _ _ 2. Name of Operator 7. Permit Number Standard Alaska Production Company 88-57 3. Address B. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21816 4. Location of well at surface --- . .... · 9. Unit or Lease Name 1496' SNL, 1454' WEL, SEC 21, T11N, R12E , ~t~A~~ Prudhoe Bay Unit At Top Producing Interval~ 10. Well Number ~'~,.~ ~ W-42 (44-21-11-12) 4908'SNL, 726' WEL, SEC21, T11N, R12E ~ [1~~ 11. Field and Pool At Total Depth ~ Prudhoe Bay Field/Prudhoe Bay Pool 1118' SNL, 379' WEL, SEC 28, T11~-R 12E 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE= 90.95 ft. I ADL 28263A & 47452 12. Date SpUdded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 6-20-88 7-19-88 7-22-88I N/A feet MSL I ONE 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 11825'MD 8821'TVD 11783'MD 8820'TVD YES [] NO []I 1976feet MD I 1893 22. Type Electric or Other Logs Run MWD, GAMMA, PLUS DIRECTIONAL 23. CASING, LINER AND CEMENTING R~RD SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Conductor Surface 110' 8 cu yds Concrete 13-3/8" 68# L-80 Surface 2690' 17-1/2" 3840 cu ft Cold Set II 9-5/8' 47# L-80 NSCC Surface 5278' 12-1/4" 2222 cufl Class G 9-5/8" 47# L-80 Butt 5278' 9957' 12-1/4" 5-1/2" 17# L-80 9869' 11824' 8-1/2" Uncemented Slotted Liner 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 (MDI 5-1/2" Slotted Liner 7" 26~ L-80 with 9842' 8867' 10112'-11781'MD 5-1/2" Tailpipe 8672'-8730' TVDss 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13-3/8" X 9-5/8" Down squeeze 13-3/8" x 9-5/8" annulus with 300 sx Coldset I followed by 125 bbls dry crude. 27. PRODUCTION TEST (For well clean up prior to injection) Date First Production IMethod of Operation (Flowing, gas lift, etc.) 7-27-88 I FIowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIT]= IGAS-OIL RATIO 8-3/4-88 44 TEST PERIOD I~ 1987 58236 Trace 47/64 129309 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 3045 0 24-HOUR RATE II~ 1084 31765 Trace 53.8 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED 'Alaska 0il .& Gas Cons. C0mmissi0r~ :orm 10-407 Submit I: :lev. 7-1-80 CONTINUED ON REVERSE SIDE 29. t. 30. GEOLOGIC 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. E ileen 10,085' 8756' Zone 4 10,294' 8778' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ Ti~e PBU Drillin~ Enginoorin~ ~upervi~or Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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 STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well' W-42 (44-21-11-12) Daily Drilling Report -- PRUDHOE BAY .. June 13, 1988 at 0600 hrs AFE # 120706 AFE Amount: Current Amount: 0600 Depth: Day: 24- Hour Ftg: Water Used: -I Current Operation: Moving rig. Mud Type: WT: VIS: PV: YP: FL: Solids: Temp: ~ STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY' June I4, 1988 at 0600 hfs Rig: AUDI#3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: Day: -2 24- Hour Ftg: Water Used: 100 Current Operation: Move in and rig up. 'ReleaSe rig @~ 1400 hours on 6-13-88 for modifications. Mud Type: WT: VIS: PV: YP: FL:' Solids: Temp: ~ STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY June 15, 1988 at 0600 hrs Rig: AUDI/13 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: Day: 24- Hour Ftg: Water Used: -3 Current Operation: Modifying rig. Mud Type: WT: VIS: PV: YP: FL: Solids: Temp: ~F STANDARD: ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY June 16, 1988 at 0600 hfs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: Day: ,4 24- Hour Ftg: Water Used: 90 Current Operation: Mud room modification. Mud Type: WT: VIS: PV: YP: FL: Solids: Temp: STANDARD" ALASKA PRODUCTION Rig: AUDI #3 Well: W-42 (44-21-11-12) Daily Drilling Report -- PRUDHOE BAY June 17, 1988 at 0600 hrs AFE # 120706 AFE Amount: Current Amount: CurrentOperation: Mod mud room. 0600 Depth: Day: 24- Hour Ftg: Water Used: -5 Mud Type: WT: ViS: PV: YP: FL: Solids: Temp: W STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDItOE BAY June 20, 1988 at 0600 hfs Rig: AUDI #3 Well' W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 275' Day: 0 72- Hour Ftg: 275' Water Used: 800 Current Operation: Drilling 17-1/2" hole. Accept rig @ 1500 hours on 6/19/88, spud @ 0300 hours on 6/20/88. Drill 17-1/2" hole to 275'. Mud Type: Spud WT:9.1 VIS:320+ PV:32 YP:56 FL: 12 Solids:5.5 Temp: ~ STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-42 (44-21-11-12) Daily Drilling Report-- PRUDHOE BAY June 21, 1988 at 0600 hrs AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 1450' Day: 1 24- Hour Ftg: 1175' Water Used: 900 Current Operation: Drilling 17-1/2" hole. Drill and survey 17-1/2" hole to 1450'. Mud Type: Spud WT: 9.4 VIS: 145 PV: 25 YP: 48 FL: 12.4 Solids: 8 Temp: °F STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDIIOE BAY June 22, 1988 at 0600 hfs Rig- AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 2700' Day: 2 24- Hour Ftg: 1250' Water Used: 1100 Current Operation: Running 13-3/8" casing. Drill and survey 17-1/2" hole to 2700'. Mud Type: Spud WT: 9.8 VIS: PV: 22 YP: 37 FL: 12.4 Solids: 10 Temp: 62 °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDtIOE BAY June 23, 1988 at 0600 hfs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth' 2700' Day: 3 24- Hour Ftg: Water Used: 1400 Current Operation: TIH. Run and cement 13-3/8". NU and test BOPE. Pick up 12-1/4" BHA. Mud Type: Ligno. WT: 9.4+ VIS: 37 PV: 11 YP: 8 FL: 13.5 Solids: 6 Temp: 61 °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY June 24, 1988 at 0600 hrs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 4000' Day: 4 24- Hour Ftg: 1300' Water Used: 1100 Current Operation: Preparing to kick off. Test 13-3/8" casing. Drill out and perform LOT. Drill and survey 12-1/4" hole to 4000'. PU motor to kick off. Mud Type: LS WT: 9.5+ VIS: 36 PV: 9 YP: 6 FL: 15.2 Solids: 8 Temp: 81 °F Ih.l,_) STANDARD ALASKA P. RODUCTION Rig: AUDI #3 Well: W-42 (44-21-11-12) Daily Drilling Report -- PRUDHOE BAY June 27, 1988 at 0600 hrs AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 6455' Day: 7 72- Hour Ftg: 2455' Water Used: 2700 Current Operation: Tripping. Drilled & surveyed to 6455'. Trip. Mud Type: LSND WT:9.8 VIS:37 PV: 12 YP:8 FL:6.6 Solids:8 Temp: 86°F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY June 28, 1988 at 0600 hfs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 6617' Day: 8 24- Hour Ftg: 162' Water Used: 10 Current Operation: Tripping with new BHA and jars. Drilled to 6617' with Dyna-drill. Mud Type:Soltex/Poly WT:9.9 VIS:38 PV: 12 YP:8 FL:4.8 Solids: 10 Temp: 89°1:: STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY June 29, 1988 at 0600 hrs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 7050' Day: 9 24- Hour Ftg: 433' Water Used: 300 Current Operation: Drilling. Drilling 12-1/4" hole at 7050'. Mud Type: Poly/Soltex WT: 10.0 VIS: 37 PV: 14 YP: 7 FL: 4.5 Solids: 11 Temp: ~F STANDARD ALASKA P_RODUCTION Daily Drilling Report-- PRUDHOE BAY June 30, 1988 at 0600 hfs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 7370' Day: 10 24- Hour Ftg: 320' Water Used: 700 Current Operation: Drilling. Drilling 12-1/4" hole to 7370'. Mud Type: Poly WT: 9.9+ VIS: 36 PV: 12 YP: 8 FL: 4.4 Solids: 11 Temp: °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY July 5, 1988 at 0600 hrs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 9650' Day: 15 120- Hour Ftg: 2280' Water Used: 2500 Current Operation: Drilling 12-1/4" hole. Drill and survey 12-1/4" hole to 7722'. Dyna-drill 12-1/4" hole to 8770'. Drill and survey 12-1/4" hole to 9375'. PU MWD logging tool. Drill, survey and log 12-1/4" hole to 9650'. Mud Type: Poly/Soltex WT: 10.1 VIS:36 PV: 13 YP: 7 FL: 4.6 Solids: 11 Temp: °F STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-42 (44-21-11-12) Daily Drilling Report-- PRUDHOE BAY July 6, 1988 at 0600 hrs AFE # 120706 Al:rE Amount: Current Amount: 0600 Depth: 9790' Day: 16 24- Hour Ftg: 140' Water Used: 600 Current Operation: Drilling 12-1/4" hole. Drill, survey and log 12-1/4" hole to 9733'. Drill and survey 12-1/4" hole to 9790'. Mud Type: Ligno WT: 10.1 VIS: 40 PV: 15 YP: 11 FL: 4.2 Solids: 11 Temp: 80 °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY July 7, 1988 at 0600 hfs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 9965' Day: 17 24- Hour Ftg: 175' Water Used: 500 Current Operation: TOH. Trip. Drill & survey 12-1/4" hole to 9965'. Prepare to mn 9-5/8" casing. Mud Type: Ligno. WT: 10.0+ VIS:37 PV: 13 YP:9 FL:4.4 Solids: 11 Temp: 10501: STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-42 (44-21-11-12) Daily Drilling Report-- PRUDHOE BAY 'July 8, 1988 at 0600 hrs AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 9965' Day: 18 24- Hour Ftg: Water Used: 500 Current Operation: Change out Hydril Rubber. Run and cement 9-5/8" casing. Mud Type: Ligno. WT: 10.0+ VIS: 87 PV: 13 YP: 8 FL: 4.4 Solids: 11 Temp: 94 °F STANDARD ALASKA PRODUCTION Daily Drilling Repo. rt -- PRUDHOE BAY July 11, 1988 at 0600 hrs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 10,304' Day: 21 72- HourFtg: 339' Water Used: 1600 Current Operation: Drilling 8-1/2" hole. Run CBT & Gyro in 9-5/8" casing, test casing. Install oil base mud. Drill & survey 12-1/4" hole to 10,304'. Mud Type: Oil Base WT: 9.5 VIS: 41 PV: 14 YP: 13 FL:. 6 Solids: 9 Temp: °F STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY July 12, 1988 at 0600 hrs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 10,481' Day: 22 24- Hour Ftg: 177' Water Used: 400 Current Operation: Trip. Drill & survey 12-1/4" hole to 10,481'. Mud Type:Oil Base WT:9.5 VIS:41 PV: 15 YP: 13 FL:.6 Solids:9 Temp: 102°F STANDARD ALASKA PRODUCTION Daily Drilling Report -- PRUDHOE BAY July 13, 1988 at 0600 hrs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 10,863' Day: 23 24- Hour Ftg: 382' Water Used: 300 Current Operation: Trip. Drill and survey 8-1/2" hole to 10,863'. POH. Mud Type:Oil Base WT:9.5 VIS:41 PV: 14 YP: 14 FL: 14 Solids: 10 Temp: 82°F . STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY July 14, 1988 at 0600 hrs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 11,371' Day: 24 24- Hour Ftg: 508' Water Used: 500 Current Operation: POH. Drill & survey 8-1/2" hole to 11,371'. Mud Type: Oil Base WT: 9.5 VIS: 41 PV: 14 YP: 13 FL:.4 Solids: 9 Temp: 98 °F STANDARD ALASKA PRODUCTION Rig: AUDI #3 Well: W-42 (44-21-11-12) Daily Drilling Report-- PRUDHOE BAY July 15, 1988 at 0600 hrs AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 11,825' Day: 25 24- HourFtg: 454' Water Used: 500 Current Operation: POH. Drill and survey 8-1/2" hole to 11,825'. Short trip. POH to run liner. Mud Type: Oil Base WT: 9.4 VIS: 40 PV: 13 YP: 12 FL: .4 Solids: 9 Temp: 103 · STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY July 18, 1988 at 0600 hrs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 11,825' Day: 28 72- Hour Ftg: Water Used: 1200 Current Operation: C&C mud. RtH with 5-1/2" slotted liner. Hanger-packer set prematurely @ 3989'. Millout & retrieve hanger. LD liner. TIH for wiper trip. Prepare to run 5-1/2" slotted liner. Mud Type: Oil Base WT: 9.4 VIS: 42 PV: 12 YP: 12 FL: .4 Solids: 9 Temp: 72 °F STANDARD ALASKA P. RODUCTION Daily Drilling Report-- PRUDHOE BAY July 19, 1988 at 0600 hrs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 11,825' TD Day: 29 24- Hour Ftg: Water Used: 400 Current Operation: Lay down 2-1/16" Tbg. Short trip to 9-5/8" shoe. POH. R/U & run 5-I/2" slotted liner. Set packer & test annulus to 2000 psi. POH. Mud Type:Oil base WT:9.5 VIS:46 PV: 15 YP: 11 FL:.4 Solids: 10 Temp: 66~F STANDARD ALASKA PRODUCTION . Rig: AUDI #3 Well: W-42 (44-21-11-12) Daily Drilling Report-- PRUDtIOE BAY July 20, 1988 at 0600 hrs AFE # 120706 AFE Amount: Current Amount: Current Operation: 0600 Depth: I 1,825' Day: 30 24- Hour Ftg: Water Used: 400 Clean pits. POH, L/D 2-1/16" tubing, DC's, & HWDP. RIH with overshot & wash over tieback. Displace hoIe to 9.4 ppg brine. Mud Type: Brine WT: 9.4 VIS: PV: YP: FL: Solids: Temp: STANDARD ALASKA PRODUCTION . Dally Drilling Report-- PRUDHOE BAY July 21, 1988 at 0600 hrs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 11,825' Day: 31 24- Hour Ftg: Water Used: 600 Current Operation: Running tubing. Change over to 9.4 ppg brine. LD drill pipe. Run 7" x 5-1/2" tubing. Mud Type: Brine WT: 9.4 VIS: PV: YP: FL: Solids: Temp: W STANDARD ALASKA PROD(.,,ICTION Rig: AUDI #3 Well: W-42 (44-21-11-12) Daily Drilling Report-- PRUDHOE BAY July 22, 1988 at 0600 hrs AFE # 120706 AFE Amount: Current Amount: 0600 Depth: 11,825' Day: 32 24- Hour Ftg: Water Used: 200 Current Operation: Displace annulus with 9.6 ppg brine. Run 7" x 5-1/2" tubing. NU tree and test. Set packer and test. Mud Type: Brine WT: 9.6 VIS: PV: YP: FL: Solids: Temp: ~ STANDARD ALASKA PRODUCTION Daily Drilling Report-- PRUDHOE BAY July 25, 1988 at 0600 hrs Rig: AUDI #3 Well: W-42 (44-21-11-12) AFE # 120706 AFE Amount: Current Amount: 0600 Depth: Day: 24- Hour Ftg: Water Used: 11,825' 33 20 Current Operation: Rig released @ 1500 hours on 7/22/88. Displace tubing to diesel. Release rig. Mud Type: wT: VIS: PV: YP: FL: Solids: Temp: °F $UB.~URFACE DIRECTIONAL ~URVEY I~UIDANCE I~ONTINUOUS I~OOL Company STANDARD ALASKA PRODUCTION COMPANY Well Name W_z-42(44-2!,-1,1-12) (149, 6' SNL~.J,.454' WEL~SEC 21 .ll 1N~R12E) Fieldll. ocat~ort.,pRUDHOE BAY. NORTH SLOPE. ALASKA I I Il mim ! Jolm Reference NO_. Date, 72882 5-AUG-88 Lo_.~gg.,~[_~,' Computed laY:. RATHERT STEVENS ., GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR STANDARD ALASKA PRODU'CTZON CO. W-~2 C~4-21-11-12) PRUDHOE BAY NORTH SLOPEpALASKA SURVEY DATE: 05-AUG-88 ENGINEER: Jo RATHERT METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZo DISTo PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 13 DEG 9 RIM EAST NOTE - THIS W-42 FINAL DIRECTIONAL SURVEY IS A MERGE OF GCT CS-AUG-88) TO A NEAS DEPTH OF 9TO2t AND GREATLAND DIRECTIONAL MWD DATA C19-JUL-88) FROM 9702 TO 11792. THE LISTED DIRECTIONAL DATA IS EXTRAPOLATED FROM 1179Z TO TO 11825. THE LISTED DIRECTIONAL DATA IS EXTRAPOLATED FROM 1179Z TO TD 11825. STANDARO ALASKA PRODUCTION CO. bi-4.2 ¢4.4.-21-11-12) PRUDHOE BAY NORTH SLOPEgALASKA COMPUTATION DATE: 22-AUG-88 PA GE I DATE OF SURVEY:' *OS-AUG-88 KELLY BUSHING ELEVATIOM:~ 90.95 ET ENGZN:EER: Jo :RATHE.RT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASUREO DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH OEPTH OEPTH DEPTH OEG MIN OEG MIN 0.00 0.00 -90.95 0 0 N 0 0 E 100.00 100.00 9005 0 3 S 55 1Z E 200,.00 200.00 109.05 0 3 N 75 26 bi 300.00 300.00 209.05 0 8 S 33 `49 g `400.00 `400.00 309.05 0 11 S 3 `46 Id 500.00 500.00 `409.05 0 7 S 18 22 kl 600.00 599.99 509.04. 0 5 S 68 37 14 700.00 699.99 609.04. 0 12 S 11 35 bi 800.00 799.99 709.04. 0 15 S 0 8 bi 900.00 899.99 809.04. 0 7 S 25 17 14 0 27 S 23 22 E 0 4,2 S 3,4 57 E 0 4.4. S 39 21 E 0 37 S 4,0 4.9 E 0 26 S 48 4.7 E 016 566 0 E 0 10 S 73 4.3 E 0 8 N 88 14 E 0 Z S 86 33 E 0 4. S 87 39 E 1000.00 999.99 909004 1100.00 1099.99 1009.04. 1200.00 1199.98 1109.03 1300.00 1299.97 1209.02 14.00o00 1399.97 1309.02 1500.00 1`499o96 1409.01 1600.00 1599.96 1509.01 1700.00 1699.96 1609.01 1800.00 1799096 1709.01 1900.00 1899.96 1809.01 0 3 S 74 2 E 0 9 N 84 53 E 010 N 70 & E 0 9 N 57 4`4 E 0 5 N 35 10 E 0 4. N 6 8 ~ 0 6 N 29 32 E 0 16 N 38 24 bi 0 3O N 75 32 bi 0 16 N 87 35 14 2000.00 1999.96 1909.01 2100.00 2099.96 2009.01 2200.00 2199.96 2109.01 2300.00 2299.96 2209.01 2400.00 2399.96 2309.01 2500.00 2499.96 2409001 2600.00 2599096 2509.01 2700.00 2699.96 2609.01 2800.00 2799.96 2709o01 2900.00 2899.96 2809.01 0 26 S 86 21 14 0 29 S 78 58 Id 0 33 S 71 `41 g 033 S 70 314 0 39 S 68 42 14 0 23 S 66 3 14 013 S 71 914 0 23 S 29 47 14 0 34 S 1222 bi 0 38 S 7 4.1 bi 3000.00 2999.95 2909.00 3100.00 3099.95 3009.00 3200.00 3199.95 3109.00 3300.00 3299.94 3208.99 34.00.00 3399.94 3308.99 3500.00 3499.93 3408.98 3600.00 3599.93 3508.98 3700.00 3699.93 3608.98 3800.00 3799.92 3708.97 3900.00 3899.92 3808.97 VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ.,:'.DEPARTURE SECTION SEVERZTY NORTH/SDUTH EAST/NEST DZST° '~ZZNUTH FEET DEG/IO0 FEET FEET FEET. DEG #IN o.oo o.oo o.oo . o.oo -0027 0-68 0o16 N 0.51 14 -0.17 0060 0.01 N 0.72 bi 0, s -U'18. 0076 0'~ S 1.05 14 0.38 0.77 0.66 S 1.16 bi 0-64. 0.03 0.95 S 1.26 bi 0.88 0.34 1.21 S 1.30 1.04 0.58 1.39 S 1.39 bi 1.37 0.23 1.76 S 1.4.9 14 0.00 N 0 0 E 0',2 ',N~. 10 W 0'9~1 S 79 1.~a S 67 5'0 W 1.34 S 6:0 31 W 1.57 5 52 56~tl / 1.7'8 S 4.7 .4. W 1.97 S 4.4. 58 W' 2.30 S 4.0 19 W 1.84 0.33 2.21 S 1.36 14 2.84 0.00 3.11 S 0.82 14 4..01 0.00 4.13 S 0.04. ~1 5.05 0.00 5.02 S 0.72 E 5.91 0.63 5.74 S 1.41 E 6.32 0000 6.05 S 1.88 E 6.56 0.13 6.20 S 2.28 E 6.66 0.29 6.24 S 2.55 E 6.70 0.03 6.25 S 2.70 E 6.73 0.00 6.26 S 2.80 E 2.59 S 31 37 14 3.21 S 14 42 bi 4..I3 S 0 34. bi 5.07 S 8 11 E 5.91 S 13 47 E 6.34. S 17 16 E 6.61 S ZO 11 E 6.74. S 22 11 E 6.81 S 23 23 E 6.85 S 24. 6 E 6.78 0.06 6.27 S 2094 E 6.83 0.00 6.29 S 3.12 E 6.84 0.00 6.23 S 3.4.0 E 6.78 0.00 6.11 S 3.68 E 6064. 0.01 5.92 S 3.86 E 6.52 0.00 5.78 S 3.93 E 6.4.8 0.73 5.73 S 3.97 E 6.19 0.36 5.4.4. S 3.93 E 5.70 0.34 5.08 S 3.28 E 5.4.5 0.00 5.00 S 2.54. E 6.93 S 25 4 E 7.02 S 26 24 E 7.10 S 28 36 E 7.13 S 31 2 E 7007 S 33 6 E 6.99 S 34 13 E 6097 S 34 43 E 6.71 S 35 49 E 6.05 S 32 50 E 5.61 S 26 54. E 5.30 0.00 5.01 S 1.89 E 5.22 0.00 5.11 S 1.08 E 5.25 0.00 5.35 S 0.19 E 5.73 O.'v.., 6.61 S 3.11 14 5.98 0o61 6.95 S 30`45 bi 6.75 0.60 7.82 S 3.79 Id 7.72 0.00 8.85 S 3.95 14 5.35 S 20 42 E 5.22 S 11 57 E 5.35 S I 59 E 5.75 S 7 37 bi 6.31 S 16 6 bi 6093 S 22 5 14 7.31 S 25 I0 ~! 7.76 S 26 23 bi 8.69 S 25 51 14 9069 S 24 I bi STANDARD ALASKA PRODUCTION CO. g-42 C64-21-11-12) PRUDHOE BAY NORTH SLOPEtALASKA COMPUTATION DATE: 22-AUG-88 PAGE DATE OF SURVEY: 05-AUG-88 KELLY BUSHING ELEVATION: 90.95 FT ENGINEERt J°:RATHERT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASUREO OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG NIN DEG NIN 4000.00 3999.91 3908.96 I 16 4100.00 ¢099.64 4008.69 5 57 4200.00 4198.82 4107.87 8 52 4300.00 4297.15 4206.20 11 53 4400.00 4394.29 4303.34 15 27 4500.00 4489.91 4398.96 18 28 4600.00 4583.96 4493.01 21 12 4700.00 4676.12 4585.17 24 21 4800.00 4766.62 4675.67 25 47 4900.00 4856.23 4765.28 26 54 S 11 21 E S 13 26 E S 14 4 E S 18 34 E S 19 51 E S 20 46 E S 19 16 5 S 20 25 E 5 2O 35 E S 19 55 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST'" RZIMUTH FEET OEG/IO0 FEET FEET FEET OEO WIN 5000.00 4944.95 4854.00 28 7 5100'00 5032.48. 4941.53 29 34 5200.00 5119.11 5028.16 30 12 5300.00 5205.29 5114.3, 30 39 5400.00 5291.17 5200.22 30 53 5500.00 5376.95 5286.00 31 5 5600.00 5462.58 5371.63 31 7 5700.00 5548.06 5457.11 3i 23 00.00 9.02 2.59 10.17 S 15.85 2.25 16.75 S 28.54 4.09 29.16 S 46.63 3.09 46.49 S 70.16 3.22 68.81 S 99.16 2.73 96.24 S 132.85 2.91 128.07 S 171.38 2.55 164.62 S 213.54 1.16 204.40 S 257.57 1.33 246.04 S 6000.00 5807.55 5716.60 28 24 6100.00 5895.86 5804.91 27 30 6ZO0.O0 5985.00 5894.05 26 22 6300.00 6075.13 5984.18 24 57 6600.00 6166.27 6075.32 23 51 6500.00 6257.92 6166.97 2~ 9 6600.00 6350.08 6259.13 22 24 6700.00 6442.69 6351.74 22 12 6800.00 6535.31 64~4.36 21 46 6900.00 6628.44 6537.49 21 6 S 19 11 E 303.42 S 18 27 E 351.55 S 18 9 E 401.30 S 17 51 E 651.84 S 17 47 E 502.89 S 17 52 E 556.12 17 35 E 605.60 17 17 E 657.35 S 17 25 E 708.98 S 17 5 E 759.06 7000.00 6721.64 6630.69 21 35 7100.00 6814.16 6723.21 23 3 7200.00 6905.60 6814.65 24 44 7300.00 6995.90 6904.95 25 58 74,00.00 7085.42 6994.47 26 52 7500.00 7174.39 7063.44 27 18 7600.00 7262.93 7171.98 28 T 7700.00 7350.71 7259.76 28 52 7800.00 7438.81 7367.86 27 49 7900.00 7527.57 7436.62 26 56 S 16 28 E 807.44 S 15 41 E 854.29 S 15 0 E 899.57 S 14 6 E 942.86 S 11 31 E 986.03 S 8 23 E 1023.95 S 6 37 E 1062.56 S 4 39 E 1099.97 S 2 39 E 1137.14 S I 4 E 1172.87 I 53 E 1208.31 5 59 E 1245.75 S 11 17 E 1286.11 S 13 38 E 1329o05 S 12 5 E 1373.63 S 9 40 E 1419.26 S 6 51 E 1465.57 S 4 35 E 1513.01 S 9 10 E 1559.99 S 14 22 E 1606.03 3.87 W 10.88 S'20 69 W 2.05 W 16.88 $ 6 57 W 0.73 E 29.1S S I 25 E 5.97 E 46,811, S T 19 E 13.83 E 70.19' S 11 21 E 2 48.68 E 171.67 $ 16 Z8 E 63.73 E 214.11 S 17 18 E 79.04 E 258-43 S 17 48 E 1.80 1.10 0.53 0.13 0.73 0.24 0.30 0.40 0.95 1.01 289.50 S 94.54 E 304.56 S I8 5 E 335.29 S 110.11E 352.91 S 18 10 E 382.73 S 125.75 E 402.85 S 18 11E 430.96 S 141,42 E 453.57 S 18 10 E 479.7'2 S 157.11 E 504.80 S 188 E 528.64 S 172'94 E 556.21 S 18 6 E 577.82 S 188.72 E 607.86 S 18 5 E 627.32 S 204.32 E 659.75 S 18 2 E 676.73 S 219.76 E 711.52 S 17 59 E 724.67 S 234.68 E 761.72 S 17 56 E 0.73 1.14 1.21 1 1.53 1.09 1.16 1.13 1.26 0.82 816.1' S 61 3 E 57. 8 7 73 , E 37 S I E OZ. 7 902.76 S 28~.6Z E 9~5.6~ S ~7 ~ E 9~.88 S 2~.8~ E 986.65 S ~7 ~9 E 982.Z8 S ~00.66 E ~026.~ S ~7 Z E 1019.75 S 305.71 E 106~.59 S 16 41 E 1057.31 S 309.39 E 1101.65 S 16 18 E 1094.92 S 311.78 E 1138.45 S 15 53 E 1131.32 S 313.06 E 1173.83 S 15 28 E 2.06 2.93 2.35 1.06 1.46 1.53 1.80 0.99 1.87 2.02 1167.57 S 313.67 E 1208.97 S 15 2: E' 1205.39 S 316.34 E 1246.21 S 14 42 E 1245.37 S 322.61 E 1286.48 S 14 31 E 1287.27 S 332.05 E 1329.40 S 14 27 E 1330.69 S 342.11 E 1373.97 S 14 25 E 1375.51 S 350.T8 E 1419.53 S 14 18 E 1421.51 S 357.52 E 1465.78 S 14 7 E 1469.17 S 362.05 E 1513.12 S 13 50 E 1516.14 S 367.51 E 1560.05 S 13 37 E 1561.26 S 376.73 E 1606.07 S 13 33 E STANDARO ALASKA PRODUCTION CO. W-42 (¢4-21-11-12) PRUDHOE BAY NORTH SLOPEtALASKA CONPUTATION DATE: II-AUG-88 PAGE DATE OF SURYEY-" O.5-AUG'88 KELLY BUSHING ELEVAT'ZON; 90.95 PT ENGINEER: J. RATHERT. INTERPOLATED VALUES FOR EVEN 100 FEET OF NEASURED DEPTH TRUE SUB-SEA COURSE HEASURED VERTICAL VERTICAL DEVIATION AZINUTH DEPTH DEPTH DEPTH DEG ~IN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ.~;DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/gEST DIST. :~&ZINUTH FEET DEG/IO0 FEET FEET FEET' 8000.00 7616.24 7525.29 28 27 8100.00 7703.32 7612.37 30 23 8200.00 7788.38 7697.42 32 54 8300.00 7871.32 7780.37 34 57 8400.00 7951.92 7860.97 37 42 8500.00 8029.52 7938.57 40 14 8600.00 8104.53 8013.58 42 25 8700.00 8177.42 8086.47 44 '2 8800°00 8247.84 8156.89 46 38 8900.00 8314.36 8223.41 49 54 9000.00 8376.22 8285.27 53 25 9100.00 8433.40 8342.45 56 47 9200.00 8485.73 8396.78 60 5 9300.00 8533.24 8442.29 63 8 9600.00 8575.97 8485.02 66 16 9500.00 8614.09 8523.14 68 59 9600.00 8647.83 8556.88 71 51 9700.00 8679.29 8588.34 75 9 9800.'00 8702.31 8611.36 77 9 9900.00 8724.17 8633.22 79 6 10000.00 8741.71 8650.76 80 27 10100.00 8757.91 8666.96 81 1 10200.00 8770.46 8679.51 84 9 10300.00 8778.33 8687.38 87 32 10400.00 8781.64 8690.69 88 33 10500.00 8783.85 8692.90 88 54. 10600.00 8785.49 8694.5¢ 89 11 10700.00 8786.57 8695.62 89 29 10800.00 8787.06 8696.11 89 44 10900.00 8787.72 8696.77 89 41 11000.00 8789.01 8698.06 89 2 11100.00 8791.34 8700.39 88 22 11200.00 8794.71 8703.76 87 41 11300.00 8799.34 8708.39 87 7 11400.00 8804.23 8713.28 87 5 11500.00 8809.07 8718.12 87 23 11600.00 8813.45 8722.50 87 37 11700. O0 8817.37 8726.42 87 51 11800.00 8820.69 8729.74 88 23 11825.00 8821.39 8730.44 88 23 S 15 45 E 1652.21 S 14 0 E 1701.34 S 14 49 E 1753.90 S 16 48 E 1809.69 S 16 50 E 1868.73 S 15 41 E 1931.69 S 14 20 E 1997.77 S 12 22 E 2066.23 S 11 42 E 2137.20 S 12 30 E 2211.84 S 13 I E 2290.38 S 13 7 E 2372.40 S 12 16 E 2457.60 S 11 17 E 2545.56 S 10 29 E 2635.88 S 9 59 E 2728.20 S 9 41 E 2822.16 S 10 5 E 2906.78 S 9 59 E 3001.34 S 10 I E 3098.42 S 10 14 E 3196.73 S 10 4 E 3295.27 S 10 29 E 3394.32 S 12 5 E 3493.89 S 12 5 E 3593.82 S 12 34 E 3693.78 S 12 48 E 3793.76 S 12 51 E 3886.82 S 13 0 E 3967.0Z S 13 5 E 4067.94 S 12 58 E 4193.74 S 12 54 E 4293.71 S 13 9 E 4393.65 S 13 24 E 4493.54 S 13 30 E 4593.42 S 13 30 E 4693.30 S 13 31 E 4793.20 S 13 45 E 4893.12 S 14 11 E 4993.05 S 14 11 E 5018.03 2.34 2.84 2.32 1.94 2.97 2.60 1.41 2.24 1.34 5.32 3.07 3.19 3.19 3.16 2.14 3.24 3.57 4.10 3.09 1.97 1.49 0.65 2.90 3.88 1.38 0.73 0.47 0.33 0.35 0.39 0.56 0.73 0.74 0.65 0.47 0.30 0.25 0.31 0.00 0.00 1605.83 S 388.96 E 1652.26 .S 13 36 E 1653.31 S 401.66 E 1701.40 $~'~13 39 E 1704.30 S 414.44 E 1753.97 S 13 40 E 1758.02 5 429.74 E 1809.78 S !3 44 E 1814.61 $ 447.04 E 1868'8& S :1,3 50 E 1875.15 S 464.66 E 1931.87 S 13 55 E 1939.01 S 481.76 E 1997.97 S 13 57 E 2005.63 S 497.55 E 2066'42 S 13 55 E 2075.06 S 512-32 E 2137.37 S :X3 52 E 2148.05 S 527.98 E 2211.98 S 13 48 E 2224.63 S 545.44 E 2290.52 S 13 46 E 2304.51 S 564.05 E 237'Z.53 S 13 45 E 2387.62 S 582.83 E 2457'72 S ~3 43 E 2473.75 S 600.78 E 2545.66 S 13 39 E 2562.53 S 617.79 E 2635'95 S 13 33 E 2653.50 S 634.20 E 2728.24 S 13 26 E 2746.25 S 650.21 E 2822.17 S 13 19 E 2837.51 S 631.56 E 2906.94 S 12 32 E 2932.46 S 660.79 E 3001.65 S 12 19 E 3028.20 S 657.70 E 3098.80 S 1.2 15 E 3125.11 S 675.04 E 3197.18 S 12 11 E 3222.23 S 692.43 E 3295.79 S 12 7 E 3319.81 S 710.17 E 3394.92 S IZ 4 E 3417.59 S 729.32 E 3494.54 S 12 2 E 3515.31 S 750.27 E 3594.48 S 12 2 E 3612.95 S 771.73 E 3694.46 S 12 3 E 3710.50 S 793.64 E 3794.43 S I2 4 E 3801.24 S 814.33 E 3887.48 S 12 5 E 3879.39 S 832.30 E 3967.67 S 12 6 E 3977.73 S 855.04 E 4068.59 S 12 T E 4100.27 S 883.45 E 4194.37 S 1.2 9 E 4197.70 S 905.85 E 4294.32 S 12 10 E 4295.07 S 928.37 E 4394.26 S 12 11 E 4392.29 S 951.35 E 4494.13 S 12 13 E 4489.44 S 974.54 E 4593.99 S 12 14 E 4586.56 S 997.85 E 4693.85 S 12 16 E 4683.69 S 1021.21 E 4793.73 S 12 17 E 4780.79 S 1044.79 E 4893.62 S 12 19 E 4877.78 S 1068.88 E 4993.52 S 12 21 E 4902.01 S 1075.01 E 5018.50 S 12 22 E STANDARD ALASKA PRODUCTION CO. W-42 C44-21-11-12) PRUOHOE BAY NORTH SLOPE~ALASKa COMPUTATION DATE: 22-AUG-88 PAGE '4 DATE OF SURVEY: 05-AUG-88 KELLY BUSHING ELEVATION: 90.95 FT ENGINEER: J. RATHERT INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASUREO OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH OEG MZN DEG MZN 0.00 0.00 -90.95 0 0 1000.00 999.99 909.04 0 27 2000~00 1999.96 1909.01 0 3 3000.00 2999.95 2909.00 0 26 4000.00 3999.91 3908.96 I 16 5000.00 4944.95 4854.00 28 7 6000.00 5807.55 5716.60 28 24 7000.00 6721.64 6630.69 21 35 8000.00 7616.24 7525.29 28 27 9000.00 8376.22 8285.27 53 25 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. "AZIMUTH FEET DEG/100 FEET FEET FEET DEG #IN 10000.00 8761.71 8650.76 80 27 11000.00 8789.01 8698.06 99 2 11825.00 8821.39 8730.44 88 23 0 0 ~ 0.00 23 22 E 1.84 74 2 E 6.78 86 21 14 5.30 11 21 E 9.02 119 11 E 303.42 6 28 E 807.44 i 53 E 1208.31 15 45 E 1652,.21 13 I E 2290.38 S 10 14 E 3196.73 S 12 58 E 4193.74 S 14 11 E. 5018.03 0.00 0.33 0.06 0.00 2.59 1.80 0.73 2.06 2.3¢ 3.07 1.49 0.56 0.00 0.00 N 0.00 E 0.00 N 0 0 E 2.21 S 1.36 14 2.5:9 S 31 37 6.27' S 2.94 E 6.93 :ES* 25 4 E 5.01 S 1.89 E 5.35 S"20 42 E 10.17 S 3.87 14 10'88 289.50 S 94.54 E 304.54 S 18 5 E 771.07 S 248.73 E 810,,,~.9 S 17 52 E 1167.57 S 313.67 E 1208o97 S :15 2 E 1605.83 S 388.96 E 1652.2:6 S 13 36 E 2224.63 S 545.4", E 2290.52 S 13 46 E 3125.11 S 675.04 E 3197.18 S 12 11 E 4100.27 S 883.45 E 4194.37 S 12 9 E 4902.01 S 1075.01 E 5018.50 S 12 ZZ E COHPUT AT ION DATE.' ZZ-AUG-88 PAGE STANDARD ALASKA PRODUCTION CO. ti-4Z ¢44-21-11-12) PRUDHOE BAY NORTH SLOPE~ALASKA DATE OF SURVEY: 05-AUG-88 KELLY BUSHZNG ELEVATION: 90.95 F.T ENGINEER:' J. RATHERT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA OEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH OEPTH OEG MIN DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ~"OEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/tiEST OIST' '~ AZIHUTH FEET OEG/IO0 FEET FEET FEET' DEG NIN 0.00 0.00 -90.95 0 0 N 0 0 E 90.95 90.95 0.00 0 3 N 52 43 E 190.95 190.95 100.00 0 7 N 39 38 ti 290.95 290.95 200.00 0 5 S 70 26 ti 390.95 390.95 300.00 0 7 S 12 27 ti 490.95 490.95 400.00 0 4 S 38 18 ti 590.96 590.95 500.00 0 6 S 64 4~ ti 690.96 690.95 600.00 0 13 S 6 2~ ti 790.96 790.95 700.00 0 12 S 0 ¢1 W 890.96 890.95 800.00 0 8 S 35 49 W 0.00 0.00 0.00 N 0.00 E -0.27 0.77 0.16 N 0.52 ti -0.16 0.67 0.00 N 0.71 N -0.05 1.07 0.16 S 0.90 W 0.15 0.94 0.4.0 S 1.05 W 0.36 0.34 0.64 S 1.16 W 0.63 0.25 0.94 S 1.24. tl 0.85 0.20 1.18 S 1.29 W 1.01 0.88 1.36 S 1.39 W 1.36 0.23 1.74 S 1.48 W 0.00 N 0 0 E 0.54 N 72 42 ti 0.71 N 89 46 ti 0.92 ~ S 79 43 ti 1.12 S 69 I W lo32 S 60 58 ti ~ 1.95 S 45 4.1 W 2.28 S ~0 22 W 990.96 990.95 900.00 0 26 1090.96 1090.95 1000.00 0 42 1190.97 1190.95 1100.00 0 45 1290.98 1290.95 1200.00 0 37 1390.98 1390.95 1300.00 0 29 1490.99 1490.95 1400.00 0 16 1590.99 1590.95 1500.00 0 11 1690.99 1690.95 1600.00 '0 9 1790.99 1790.95 1700.00 0 3 1890.99 1890.95 1800.00 0 3 S 21 57 E S 34 0 E S 38 38 E S 40 51E S 46 52 E S 64. 4,0 E 7 3 49 E 89 13 E S 89 30 E S 88 4.0 E 1.77 0.28 2.14. S 1.39 W 2.74 0.02 3.02 S 0.88 W 3.91 0.00 4.04 S 0.12 W 4.97 0.00 4.95 S 0.66 E 5.85 0.37 5.69 S 1.35 E 6.30 0.04 6.04 S 1.84 E 6.55 0.06 6.20 S 2.25 E 6.66 0.22 6.24 S 2.52 E 6.70 0.12 6.25 S 2.T0 E 6.73 0.00 6.26 S 2.79 E 2.55 S 32 55 W 3.14 S 16 15 W 4.04 S I 38 W 4.99 S 7 35 E 5.85 S 13 23 E 6.31 S 16 59 E 6.59 S 19 58 E 6.74 S 21 59 E 6.80 S 23 ZO E 6.85 S 24 I E 1990.99 1990.95 1900.00 2090.99 2090.95 2000.00 2190.99 2190.95 2100.00 2290.99 2290.95 2200.00 2390.99 2390.95 2300.00 2490.99 24.90.95 2590.99 2590.95 2500.00 2690.99 Z690.95 2600.00 2790.99 2790.95 2700.00 2890.99 2890.95 2900.00 0 3 0 9 0 10 0 10 0 6 0 6 0 4 0 14. 0 30 0 17 N 85 51 E N 71 35 E N 59 12 E N 34 24 E N 3 32 E N 46 56 E N 32 4.3 W N 72 11W N 87 4. W 6.77 0.13 6.27 S 2.93 E 6.83 0.00 6.29 S 3.10 E 6.84 0.00 6.24 S 3.37 E 6.79 0.00 6.12 S 3.65 E 6.65 0.20 5.93 S 3.85 E 6.54 0.33 5.79 S 3.93 E 6.49 0.35 5.74 S 3.96 E 6.23 0.42 5.47 S 3.95 E 5.74 0.13 5.11 S 3.36 E 5.46 0.00 5.00 S 2.58 E 6.92 S 25 0 E 7.01 S 26 13 E 7.09 S 28 23 E 7.13 S 30 SO E 7.07 S 32 59 E 7.00 S 34 8 E 6.97 S 34 37 E 6.75 S 35 49 E 6.11 S 33 19 E 5.63 S 27 18 E '-' 2990.99 2990.95 2900.00 3091.00 3090.95 3000.00 3191.00 3190.95 3100.00 3291001 3290.95 3200.00 3391.01 3390.95 3300.00 3491.02 3490.95 3&O0.O0 3591.02 3590.95 3500.00 3691.02 3690.95 3600.00 3791.02 3790.95 3700.00 3891.03 3890.95 3800.00 0 26 0 28 0 33 0 33 0 39 0 24 0 14 0 2O 0 36 0 38 S 87 21 W S 79 OW S 72371,1 S 68 52 W S 69 28 ti S 65 17 W S 71 6 W S 28 11W S 14 33 W S 8 37 W 5.32 0.00 5.00 S 1.96 E 5.22 0.00 5.09 S 1.16 E 5.24 0.00 5.32 S 0.27 E 5.37 0.26 5.67 S 0.68 ~ 5.49 0.00 6.03 S 1.65 W 5.64 0.04 6.39 S 2.55 ti 5.73 0.08 6.60 S 3.07 W 5.94 0.52 6.90 S 3.42 W 6.67 0.16 7.73 S 3.77 W 7.63 0.00 8.75 S 3.93 W 5.37 S 21 24 E 5.22 S 12 47 E 5.33 S 2 53 E 5.71 S 6 50 W 6.25 S 15 21 W 6.88 S 21 43 W 7.28 S 24 57 W 7.70 S 26 21 ti 8.60 S 25 59 ti 9060 S 24 11 W STANDARD ALASKA PRODUCTION CO. W-¢2 (44-21-11-12) PRUDHOE BAY NORTH SLOPEr ALASKA COMPUTATION DATE: 2Z-AUG-88 PAGE 6 DATE OF. SURVEY: 05-AUG-88 KELLY BUSHING ELEVATION.',' 90..95 FT ENGINEER: i J. RATHE~T TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG NIN DEG NIN INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORZ; SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. FEET OEG/IO0 FEET FEET S 10 27 E 8 08~5 2.03 S 14 10 E 14::,o 2.60 S 13 30 E 27.32 3.93 S 18 28 E 45.34 2.96 S 19 49 E 69.23 3.23 S 20 47 E 99.51 2.73 S 19 9 E 135,,,57 3.07 S 20 41 E 178.09 2.01 S 20 22 E 225.28 1.14 S 19 44 E 275.23 1.13 S 18 44 E 328.35 1.50 S 18 9 E 385.00 0.31 S 17 51 E 443.36 0.36 S 17 47 E 502.76 0.72 S 17 53 E 562.53 0.40 683.41 0.99 S 17 15 E 742.46 1.13 S 16 38 E 798.63 1.40 S 15 42 E 851.74 1.15 3991.04 3990.95 3900.00 I 4 4091.26 4090.95 4000.00 5 45 4192.03 4190.95 4100. O0 8 34 4293.66 4290.95 4200.00 11 41 4396.53 4390.95 4300.00 15 21 4501.10 4490.95 4400.00 18 30 4607.51 4590.95 4500.00 21 25 4716.30 4690.95 4600.00 24 42 4827.06 4790.95 4700.00 26 S 4939.00 4890.95 4800.00 27 19 5052.38 4990.95 4900.00 29 0 5167.43 5090.95 5000.00 30 6 5283.33 5190.95 5100.00 30 38 5399.74 5290.95 5200.00 30 53 5516.34 5390.95 5300.00 31 2 5633.15 5490.95 5400.00 31 10 5750.22 5590.95 5500.00 31 15 5866.45 5690.95 5600.00 29 53 5981.10 5790.95 5700.00 28 36 6094.46 5890.95 5800.00 27 33 S 14 57 E 902.52 S 13 44 E 950.17 S 10 31 E 994.92 S 7 42 E 1037.97 S 5 38 E 1079.15 S 3 35 E 1119.50 S 2 0 5 1158.65 S 0 50 E 1196.52 S 4 56 E 1236.06 S 10 39 E 1279.41 6206.64 5990.95 5900.00 26 18 6317.43 6090.95 6000.00 24 43 6426.98 6190.95 6100.00 23 47 6535.91 6290.95 6200.00 22 58 6644.15 6390.95 6300.00 22 6 6752.16 6490.95 6400.00 22 14 6859.79 6590.95 6500.00 21 1'3 6967.03 6690.95 6600.00 21 17 7074.81 6790.95 6700.00 22 38 7183.88 6890.95 6800.00 24 27 S 13 36 E 1326.65 S 11 57 E 1376.43 S 9 11 E 1427.80 S 5 53 E 1480.55 S 6 15 E 1534.71 S 11 58 E 1587.30 S 15 35 E 1638.68 S 14 17 E 1694.14 S 14 53 E 1755.58 S 17 2 5 1823.54 7294.50 $990.95 6900.00 25 55 7406.20 7090.95 7000.00 26 56 7518.65 7190.95 7100.00 27 25 7631.83 7290.95 7200.00 28 27 7745.81 7390.95 7300.00 28 12 7858.87 7490.95 7400.00 27 19 7971.31 7590.95 7500.00 27 49 8085.69 7690.95 7600.00 30 4 8203.07 7790.95 7700. O0 32 58 8324.04 7890.95 7800.00 35 30 1.24 1.76 1.54 0.95 0.77 1.23 0.82 0.92 1.90 2.42 1.06 1.41 1.78 1.82 3.55 3.87 2.26 2.44 2.44 2.77 10.00 S 15.89 S 27.96 S 45.26 S 67.94 S 96.57 S 130.66 S 170.95 S 215.49 S 262.77 S PARTURE ;Z#UTH FEET:':i DEG 3.90 2.26 0.43 5.56 13.51 10.73 'S 21 18 # 16.05' S8 5 W 27-96 :S 0 53 E 45.60 S 7 0 E 69.27 S 11 14 E 24.06 E 99.52 S 13 5'9 E '~ 36.65 E 135.70 S 15 40 E / 51.05 E 178.41 S 16 37 E 67.87 E 225.93 S 17 28 E 85.07 E 276.20 S 17 56 E 313.20 S 102.68 E 329.60 S 18 9 E 367.17 S 120.65 E 386.49 S 18 11 E: 422.87 S 138.81 E 445.07 S 19 I0 E 479.60 S 157.07 E 504.67 S 18 8 E 536.67 S 175.53 E 564.64 S 18 6 E 594.17 S 193.89 E 625001 S 18 4 E 652.26 S 212.09 E 685.88 S 18 0 E 708.78 S 229.77 E 745009 S 17 57 E 762.42 S 246.16 E 801.17 $ 17 53 E 813.69 S 261.04 E 854.53 S 17 47 E 862.70 S 274.50 E 905.31 S 17 39 E 908.86 S 286.37 E 952.90 S 17 29 E 952.58 S 295.91 E 997.48 S 17 15 E 995.22 S 302.63 E 1040.22 S 16 54 E 1036.37 S 307.50 E 1081.02 S 16 31 E 1077.03 S 310.81 E 1120.98 S 16 5 E 1116.81 S 312.67 E 1159.75 S 15 38 E 1155.52 S 313.38 E 1197.26 S 15 10 E 1195.66 S 315.41 ; 1236.56 S 14 46 E 1238.79 S 3Z1.33 i 1279.78 S 14 32 i 1284.93 S 331.49 E 1327.00 S 14 27 E 1333.44 S 342.69 E 1376.77 S 14 24 E 1383.96 S 352.18 E 1428.07 S 14 16 E 1436.50 S 359.19 E 1480.73 S 14 2 E 1490.98 S 364.06 E 1534.79 S 13 43 E 1543.03 S 372.43 E 1587.34 S 13 34 E 1592.79 S 385.29 E 1638.73 S 13 35 E 1646.33 S 399.90 E 1694.20 S 13 39 E 1705.93 S 414.87 E 1755.65 S 13 40 E 1771.30 S 433.78 E 1823.64 S 13 45 E STANDARD ALASKA PRODUCTION CO. W-42 PRUDHOE BAY NORTH SLOPE~ALASKA COMPUTATION DATE: 2?.-AUG-88 PAGE '7 DATE OF SURVEY:' 05-AU~-88 KELLY BUSHING ELEVATION: 90095 ET ENGINEER: Jo RATHERT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG RIM DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/MEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 8449.87 7990.95 7900.00 39 10 8581.63 8090.95 8000.00 42 4 8718.88 8190.95 8100.00 44 Z2 8864.03 8290.95 8200000 49 5 9024.97 8390.95 8300000 54 17 9210.5Z 8490.95 8~00.00 60 25 9~3T.9Z 8590.95 8500.00 67 17 9748o9Z 8690.95 8600.00 76 8 11087.08 8790.95 8700.00 88 28 11825.00 8821.39 8730044 88 23 S 16 1Z E 1899.70 S 14 37 E 1985043 S 12 8 E 2079039 S 12:16 E 2184.52 S 13 6 E 2310.54 S 12 9 E 2.~66o73 S 10 16 E 2670.68 S 9 59 E 2951.81 S 12 52 E 4280.79 S 14 11 E 5018.03 2.76 2.98 1.90 3.13 3.58 3.11 2.67 3.68 0 0.00 184a.35 S 455.87 E 1899.8& S 13 53 E 1927.06 S 478.68 E 1985063 S I3 56 E 2018.49 S 500.35 E 2079058 S 13 55 E 2121.35 S 522.16 E 2184.67: S 13 ~9 E 2244.27 S 549.99 E 2310'68 S :13 46 E 2396.54 S 584.77 E 2466.85 S 13 42 E 2596.80 S 6Z4.07 E 2670.73 S 13 30 E 2883.61 S 632.18 E 295200'9 S 12 21 E 4185.11 S 902.96 E 4281.41 S 12 10 E 4902.01 S 1075.01 E 5018.5'0 S 12 22 E SCHLUMBEROER B I RECT I ONAL SURVEY COMPANY STANDARO ALASKA PROOUCTION NELL N - 42 (44-21-11-12) FIELD PRUOHOE BAY COUNTRY USA RUN t DATE LOOOED 05 - AUO - 88 REFERENCE ?2882 WELL' (1496' W-42 (44-21-117-',) "-" HORIZONTAL SNL, 1454' WEL, JEC 21, TllN, R12E) PROJECTION N(~TH 2000 1ooo - 1000 -2000 -3000 -4000 REF 72882 SCALE : 1/1000 IN/FT T., ~",'~':'r'~'"'"-"r"r'~"~"~-~"~"~'T'~'"~'"r"r'i"~'~-?"r', ~'~"~"~'-+"r"?-'r'~'"~--r"~ ........... r'~'"'~ .......... ~'-~ ............. , ....... ~"-': ...... , .................................. , '--r'~'-~'~+'"-~?-.r?+.~-~.+--~.-.?-~-+.*.*~-.++i-?+-~-~-+.~-..~..+...;...f-----.~ ........ ;"+"~'- ~ ........... ~"?'--: ...... ; ......... : ....... ~ ................. ; .................. 1 .............. : .................... ~ .... --~4-*~...~.4..~...a ....... ~.--,..~-.~.~-~4..4-' .4..-;-:...'-~..4..~..:...4.~..4-1...g..4.4..4-.;....L..L..:...~. 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SCALED IN VERTICAL OEPIHS HORIZ SCALE : 1/lO00 IN/FT ,r TELECOI Teleco Oilfield St=. ~es of Alaska Inc. 6116 Nielson Way Anchorage, AK 99502 (907) 562-2646 July 19, 1988 JOB #636 STANDARD ALASKA PRODUCTION CO. WELL: W-42 EILEEN WEST END RIG: AUDI #3 Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to Standard Alaska Production Company. Teleco is committed to providing the highest quality MWD service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, ,- Dave Reimer Field Service Supervisor DR/el Enclosures A ,~JJJ'i' COMPANY TELECO OILFIELD SERVICES JOB 636 SURVEY CALCULATIONS Date Page )mpany: ill: ~cation: STANDARD ALASKA PROD. W-42 EILEEN WEST END A.U.D.I. #3 CO. ~LECO Job # 636 TAK :id Correction: Lgnetic Declination: ~tal Correction: :oposed Direction: 0.00 degrees 30.80 degrees 30.80 degrees 170.88 degrees RADIUS OF CURVATURE CALCULATION MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG )EPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' TIE IN TO GREAT LAND SINGLE SHOT ~980.00 1.0 181.0 S 01 00 W 3979.84 1.70 3.94S 13.81W 14.36 S 74.077W 0.000 TELECO MWD SURVEYS 1270.00 10.8 161.6 S 18 24 E 4267.89 31.98 33.47S 6.73W 34.14 S 11.367W 3.449 :367.00 13.6 160.2 S 19 48 E 4362.69 52.17 52.84S 0.02W 52.84 S 0.026W 2.903 1460.00 16.7 159.8 S 20 12 E 4452.44 76.04 75.68S 8.28E 76.13 S 6.249E 3.335 ,176.00 7.7 167.6 S 12 24 E 4175.12 16.97 18.92S 10.74W 21.75 S 29.583W 3.136 :083.00 4.8 164.7 S 15 18 E 4082.68 6.89 9.09S 13.16W 15.99 S 55.367W 3.738 ELECO Job #, 636' TAK 07/15/88 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' ~554.00 19.4 158.8 S 21 12 E 4541.81 104.57 102.92S 18.58E 104.59 S 10.234E 2.891 ~644.00 21.9 161.2 S 18 48 E 4626.02 135.73 132.74S 29.43E 135.97 S 12.503E 2.932 ~750.00 25.0 159.5 S 20 30 E 4723.25 177.20 172.46S 43.61E 177.89 S 14.193E 2.993 ~850.00 26.0 159.8 S 20 12 E 4813.51 219.42 212,83S 58.58E 220,74 S 15.391E 1,009 ~942.00 27.1 160.5 S 19 30 E 4895.81 259.82 251.50S 72.55E 261.76 S 16.091E 1.243 ~041.00 28.5 160.9 S 19 06 E 4983.38 305.27 295.08S 87.81E 307.87 S 16.572E 1.426 5131.00 29.8 161.6 S 18 24 E 5061.98 348.49 336.59S 101.90E 351.68 S 16.843E 1.493 ~224.00 30.1 161.9 S 18 06 E 5142.56 394.33 380.69S 116.44E 398.10 S 17.007E 0.361 ~323.00 30.6 162.3 S 17 42 E 5227.99 443.76 428.29S 131.81E 448.11 S 17.107E 0.545 i416.00 30.9 162.6 S 17 24 E 5307.92 490.80 473.62S 146.15E 495.66 S 17.149E 0.363 i510.00 31.0 163.0 S 17 00 E 5388.53 538.67 519.81S 160.45E 544.01 S 17.154E 0.245 i606.00 31.1 162.6 S 17 24 E 5470.78 587.69 567.11S 175.09E 593.52 S 17.158E 0.240 i699.00 31.3 163.7 S 16 18 E 5550.33 635.43 613.22S 189.05E 641.70 S 17.135E 0.649 i865.00 30.4 163.3 S 16 42 E 5692.84 719.85 694.83S 213.23E 726.82 S 17.060E 0.556 i054.00 28.3 164.0 S 16 00 E 5857.57 811.74 783.72S 239.31E 819.44 S 16.980E 1.126 1241.00 26.1 166.2 S 13 48 E 6023.88 896.78 866.31S 261.28E 904.86 S 16.784E 1.293 1332.00 24.7 166.9 S 13 06 E 6106.08 935.70 904.27S 270.36E 943.83 S 16.646E 1.574 ~LECO Job # ~ 636'TAK ' ~ '07/15/88 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG )EPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' 1522.00 23.2 172.8 S 07 12 E 6279.72 1012.78 980.16S 283.95E 1020.46 S 16.156E 1.487 i719.00 22.2 175.6 S 04 24 E 6461.46 1088.66 1055.79S 291.63E 1095.32 S 15.441E 0.747 i911.00 21.3 179.5 S 00 30 E 6639.79 1159.31 1126.85S 294.67E 1164.74 S 14.655E 0.886 '088.00 22.6 175.3 S 04 42 E 6803.95 1225.03 1192.93S 297.67E 1229.51 S 14.011E 1.151 '225.00 25.0 168.3 S 11 42 E 6929.29 1280.27 1247.61S 305.55E 1284.48 S 13.761E 2.703 381.00 26.5 167.6 S 12 24 E 7069.80 1347.96 1313.89S 319.70E 1352.23 S 13.676E 0.981 475.00 27.2 169.0 S 11 00 E 7153.66 1390.37 1355.46S 328.30E 1394.66 S 13.615E 1.004 567.00 27.5 172.5 S 07 30 E 7235.38 1432.63 1397.18S 335.10E 1436.80 S 13.487E 1.778 662.00 28.6 176.0 S 04 00 E 7319.22 1477.21 1441.62S 339.57E 1481.07 S 13.255E 2.083 742.00 28.4 174.9 S 05 06 E 7389.52 1515.26 1479.67S 342.60E 1518.81 S 13.037E 0.703 835.00 27.9 170.0 S 10 00 E 7471.52 1559.11 1523.15S 348.36E 1562.48 S 12.883E 2.543 022.00 28.7 165.1 S 14 54 E 7636.17 1647.59 1609.69S 367.47E 1651.10 S 12.860E 1.313 251.00 33.8 165.8 S 14 12 E 7831.88 1765.82 1724.64S 397.30E 1769.82 S 12.973E 2.233 386.00 36.7 163.7 S 16 18 E 7942.12 1843.27 1799.80S 417.80E 1847.66 S 13.069E 2.328 576.00 41.8 166.5 S 13 30 E 8089.20 1962.82 1915.92S 448.69E 1967.76 S 13.181E 2.841 794.00 46.4 169.0 S 11 00 E 8245.71 2114.25 2064.13S 982.00 52.9 168.3 S 11 42 E 8367.37 2257.34 2204.53S 480.87E 2119.40 509.05E 2262.54 S 13.114E 2.256 S 13.002E 3.469 LECO Job # · 636 TAK 07/15/88 Page 4 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG EPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' ************************************************************************************************** 170.00 59.1 167.6 S 12 24 E 8472.44 2412.92 2356.88S 541.57E 2418.30 S 12.941E 3.312 360.00 65.0 170.4 S 09 36 E 8561.46 2580.58 2521.54S 573.58E 2585.96 S 12.815E 3.367 519.00 69.3 171.8 S 08 12 E 8623.19 2727.06 2666.26S 596.24E 2732.12 S 12.605E 2.823 609.00 71.6 171.8 S 08 12 E 8653.30 2811.86 2750.21S 608.28E 2816.68 S 12.472E 2.556 703.00 75.2 170.0 S 10 00 E 8680.15 2901.92 2839.14S 622.53E 2906.59 S 12.367E 4.246 892.00 79.0 170.0 S 10 00 E 8722.34 3086.10 3020.55S 654.42E 3090.64 S 12.225E 2.011 026.00 80.8 169.7 S 10 18 E 8745.84 3217.99 3150.41S 677.67E 3222.47 S 12.140E 1.361 122.00 81.1 170.0 S 10 00 E 8760.94 3312.78 3243.73S 694.38E 3317.22 S 12.083E 0.440 234.00 85.5 169.3 S 10 42 E 8774.00 3423.96 3353.12S 714.36E 3428.37 S 12.027E 3.977 295.00 87.5 167.9 S 12 06 E 8777.72 3484.80 3412.80S 726.39E 3489.25 S 12.016E 4.000 415.00 88.7 167.9 S 12 06 E 8781.70 3604.57 3530.09S 751.47E 3609.19 S 12.018E 1.001 541.00 89.0 167.2 S 12 48 E 8784.23 3730.33 3653.09S 778.63E 3735.15 S 12.032E 0.605 665.00 89.4 167.2 S 12 48 E 8785.96 3854.07 3774.02S 806.03E 3859.13 S 12.056E 0.325 827.00 89.9 166.9 S 13 06 E 8786.95 4015.70 3931.89S 842.34E 4021.10 S 12.092E 0.360 !960.00 89.3 166.9 S 13 06 E 8787.88 4148.38 4061.44S 872.42E 4154.09 S 12.123E 0.453 ,055.00 88.7 167.2 S 12 48 E 8789.54 4243.15 4154.01S 893.71E 4249.06 S 12.142E 0.707 .180.00 87.8 166.9 S 13 06 E 8793.35 4367.81 4275.77S 921.71E 4373.98 S 12.165E 0.759 ~.LECO Job # · 636' TAK 07/15/88 Page 5 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG )EPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' .339.00 86.9 166.5 S 13 30 E 8800.71 4526.22 4430.34S 958.24E 4532.78 S 12.205E 0.620 .464.00 87.3 166.5 S 13 30 E 8807.03 4650.69 4551.74S 987.33E 4657.59 S 12.239E 0.323 .587.00 87.6 166.5 S 13 30 E 8812.50 4773.22 4671.24S 1015.95E 4780.44 S 12.270E 0.249 .718.00 87.9 166.2 S 13 48 E 8817.65 4903.71 4798.44S 1046.84E 4911.31 S 12.307E 0.324 .792.00 88.4 165.8 S 14 12 E 8820.04 4977.40 4870.21S 1064.73E 4985.24 S 12.332E 0.865 ID TELECO Oi l~ield PLAN VIEW Serv i cms 800 1800 2 6200 4000 4800 5600 6400 7200 800 ID 800 1800 Z400 9200 4000 9000 VERT i CAL PROJECT ! ON r------~ . - .__.~ :- ....... ..... ~.._.~ ..... ~..~ ~ ...... ~..x ........... .~'. ........ ~ ....................... : ........... =-- ' ~'T-'r'--' .... y T : : ~ '-'~ ...................... ' ' ' . ! ~ ~ ' ~ ; : ' '; ~ ' . ' ............ ~ ..... - ..... · · 70130 ~----~-----,i ~ ~ ~ ~ h~ ~ ~~.'¢---~-- }---t ,~ ..... {~~: .... ~. ~ .... ~ ..... ~,zi~., , :~ .......... -.-w.-~..-+-t-~j , ......... ::,: .... ,--t L~..~ ~ ..-~---~-L ~ ~ ~'-~ ........ ~ -r l ...... ~=_.~ ~ .... ......... ~ ......... :~ ....... T--"T--T- ....... : .; :: ! i ~__ ~_ " , : .: ': - I I : ~~--~"- -'7 i : '-'-'.i -i'~--.-- '~ ........ ~ ......... ',. t ~ ': ' 2000 DEG GRE~T ~ DIRECTIONAL DRIT.T.IN~ INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY STANDARD ALASKA PRODUCTION COMPANY ,~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm COMPANY W - 42 mmmm WELL NAME WEST EILEEN mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm LOCATION AL688-D18 MWD & SINGLE SHOT 7/19/88 JOB NUMBER LYNN HENSLEY DON LEJEUNE TYPE SURVEY DATE DIRECTIONAL SUPERVISOR NAME TITLE SIGNATURE 430 FT 11792 FT DEPTH INTERVAL mmmmmmmmmmmmmmmmmmmmmm DATE SURVEY TAKEN FROM TO 6-19-88 7-15-88 FROM TO THIS IS A RECO~ OF A SUB-SURFACE SURVEY oF YOUB WE HAVE RETAINEDA COPY OF YOUR SURVEY REPORT IN FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOUe DESIRE, ALL COPIES OF THE SURVEY REPORT WI~J. BE FORWARDED TO YOU ON WRITTENREQUEST. A~3- SURVEY! KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIOI~L DRILLING, INC 7/19/88 Client .............. : STANDARD ALASKA PRODUCTION CO. Well ................ : WEST EILEEN It W-42 Ve=ttcal Section at.: S ~;.12 E Magnetic Declination: 30 deg B mtn E Data file name ...... : B:WW42D.DAT RECOf~ OF SURVEY IWe]] assumed ve=ttcal to MO of Computation: RADIUS OF CURVATURE Su=vey date: 6/23/88 Method ..... : SINGLE SHOT & MWD RKB Height.: ~1.0 ft 0.0! MEAS DRIFT TRUVERT SUBSEA SECT]ON DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 0.00 N 0.00 E 1.84 S 2.00 W 3.54 N 8~.00 W 1.18 N 86.00 E 0.62 N 66.00 E ~PTH ~ MN DEPTH DEPTH 0 0 0 0.00 -PO.PS ~30 0 30 429.99 339.04 940 0 .1.5 939.98 849.03 1440 0 30 1439.97 1349.0.2 1940 0 0 1939 . 97 1849 . 02 0.00 N 0.00 E 1.88 S O. 07 W 3.95 S 2.25 W 1.63 S 2.72 W 0.75 S 0.73 W CLOSURE DISTANCE DG MN S 0.00 N 0 0 0 E 1.88 S 2 0 0 W 4.54 S 29 40 52 W 3.17 S 59 1 S W 1.04 S 44 17 24 W' DOG LEG deg/lO0 0.000 0.116 0.0~9 0.050 0.100 2440 2680 3190 3690 3980 0 30 2439.96 2349.01 0 45 3~R9.90 3098.95 0 30 3689.87 35~8.9R 1 0 3979.85 3888.90 0.43 S 86.00 W -1.01 N 34.00 W -4.63 S B5.O0 W -1.]1 S 19.00 E ~.66 S 1.00 W 0.90 S 2.90 W 0.20 N S. 15 W 2.94 N 10..90 W 1.03 S 13.N8 W 4.76 S 12.88 W 3.04 S 72 48 19 W 5.16 N 87 48 35 W 11.29 N 74 54 52 W 13.52 S 85 36 38 W 13.74 S 69 42 23 W 0.100 O.lOh 0.002 0.050 0.172 h083 4 48 ~082.69 3991.74 4176 7 42 4175.13 4084.18 4270 10 48 4267.90 4176.95 +367 13 36 4362.70 4271.75 ~460 16 42 4452.46 4361.51 ~554 19 24 4541.82 4450.87 4644 21 54 4626.03 4535.08 4750 25 0 4723.27 4632.32 4850 26 0 4813.52 4722.57 4942 27 6 4895.82 ~80~.87 7.85 S 15.30 E 17.94 S 12.40 E 32.95 S 18.40 E S3.]4 S 19.80 E 77.00 S 20.~0 E 105.53 S 21.20 E 136.69 S 18.80 E 178.16 S 20.50 E 220.39 S 20.20 E 260.79 S 19.50 E 9.~2 S 12.24 W 19.74 S 9.82 W 34.30 S 5.81 W 53.67 S 0.90 E 76.51 S 9.21 E 103.75 S 19.51 E 133.57 S 30.35 E 173.29 S 44.54 E 213.65 S 59.51 E 252.33 S 73.48 E 15.75 S SO 58 57 W 22.05 S 26 25 57 W 34.79 S 9 36 19 W 53.68 S 0 57 44 E 77.06 S 6 51 60 E 105.57 S 10 38 SS E 136.98 S 12 48 21E 178.92 S 14 24 56 E 221.79 S 15 33 56 E 262.81 S 16 14 7 F 3. 691 3. 119 3.305 2. 888 3. 334 2. 875 2. 802 2. 939 1. 002 I .20,6 5041 28 30 4983.39 4892.44 51711 2~ h~3 ~061.99 4~71.04 522~ 30 5323 30 6 S416 30 S4 S308.35 5217.40 306.23 S 19.10 E 349.45 S 18.h0 E 395.29 S 18.10 E ;;~4.36 S 17.70 E 491.05 S 17.h0 E 295.91 S 88.74 E 381.51 S :117.37 ~28.76 S 132.63 E 473.76 S 1~6.86 E 308.93 S 16 41 35 E 352.74 S 16 S6 SS E z~48.80 S 17 11 15; E 496.00 S 17 13 ~3 E 1 .~17 1. 457 0. 333 O. 102 O. 8t14 WEST EILEEN ~ W-42 7/19/88 RECORD OF SURVEY MEAS DRIFT TRUVERT SUBSEA SECTION DEP'[H DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD SSlO 31 0 5388.97 5298.02 5608 31 6 5471.21 5380.26 ( ;699 31 18 SSSO.?{5 5459.81 58{55 30 24 5{593.27 5{502.32 {5054 28 18 S858.00 S7{57.05 538.92 S 17.00 E 587.94 S 17.40 E {535.68 S 1{5.30 E 720.10 S 1{5.70 E 811.99 S 1{5.00 E 519.94 S 1{51.1{5 E 5{57.25 S 175.80 E {513.35 S 189.7{5 E {594.97 S 213.94 E 783.8{5 S 240.02 E {5241 2{5 {5 {5024.31 5933.3{5 897.02 S 13.80 E 8{5{5.45 S {5332 24 42 {510{5.52 {5015.57 935.94 S 13.10 E 904.41 S {5522 23 12 {5280.15 {5189.20 1013.02 S 7.20 E 980.30 S {5719 22 12 {54{51.89 {5370.94 1088.91 S 4.40 E 1055.92 S {5711 22 18 {5{540.22 {5549.27 1159.5{5 S 0.50 E 112{5.99 S 261.99 E 271.07 E 284.{5{5 E 292.34 E 295.38 E 7088 22 36 6804.39 6713.44 1225.28 S 4.70 E 1193.07 S 7225 25 0 6929.73 6838.78 1280.52 S 11.70 E 1247.75 S 7381 26 30 7070.23 6979.28 1348.20 S 12.40 E 1314.03 S 7475 27 12 7154.10 70{53.15 1390.~1 S 11.00 E 1355.{50 S 75{57 27 30 7235.81 7144.8{5 1432.87 S 7.50 E 1397.31 S 298.38 E 30{5.2{5 E 320.41E 329.02 E 335.81E ( ' ~{5{52 28 3{5 7319.{55 7228.70 1477.4{5 S 4.00 E 1441.75 S /742 28 24 7389.9{5 7299.01 1515.51 S S.10 E 1479.80 S 7835 27 54 7471.9{5 7381.01 1559.36 S 10.00 E 1523.28 S 8022 28'42 7{53{5.80 7545.~5 1{547.83 S 14.90 E 1{509.83 S 8251 33 48 7832.31 7741.3{5 176{5.0{5 S 14.20 E 1724.78 S 340.29 E 343.31E 349.08 E 368.18 E 398.02 E 838{5 3{5 42 7942.55 7851.80 1843.52 S 1{5.30 E 1799.94 S 857{5 41 48 8089.{54 7998.69 19~3.07 S 13.50 E 191{5.0{5 S 8794 4{5 24 8~4{5.15 8155.20 2114.50 S 11.00 E 2084.26 S 8982 SP S4 83~7.80 827{5.85 2257.57 S 1~.10 E ~Oh.Gd S 9170 59 ~ 847a.88 8381.93 2413.12 S 12.40 E 235{5.79 S 418. S1 E 449.41 E 481.59 E 510.2& E 543.31 E 93{50 {55 0 85{51.89 8470.94 2580.77 S 9.{50 E 2521.4{5 S 9519 {59 18 8{523.{52 8532.{57 2727.2{5 S 8.20 E 2{5{5{5.18 S 9{509 71 3{5 8{553.74 8562.79 2812.05 S 8.20 E 2750.12 S 9703 75 12 8880.59 8589.{54 2902.12 S 10.00 E 2839.05 S 9892 79 0 8722.77 8831.82 308{5.29 S 10.00 E 3020.45 S 575.32 E 597.98 E {510.08 E {524.32 E {55{5.31 E CLOSURE DISTANCE DG MN S 544.35 S 17 13 1S E 593.8{5 S 17 13 9 E {542.04 S 17 11 29 E 727.15 S 17 {5 38 E 819.78 S 17 1 28 E 905.19 S 1{5 49 2{5 E 94~.16 S 1{5 41 S E 1020.79 S 1{5 11 32 E 1095.{54 S 15 28 30 E 11{55.0~ S 14 41 12 E 1229.81 S 14 2 29 E 128h.79 S 13 47 2~ E 1352.53 S 13 42 12 E 1394.9{5 S 13 38 33 E 1437.10 S 13 30 48 E 1481.3{5 S 13 1{5 48 E 1519.11 S 13 3 41E 15~2.77 S 12 54 25 E 1{551.39 S 12 52 57 E 1770.11 S 12 59 40 E 1847.95 S 13 S 22 E 19{58.0{5 S 13 11 {50 E 2119.{59 S 13 7 SS E 22d2.84 S 13 1 SS E 2418.61 S 12 58 54 E 258{5.2{5 S 12 51 11 E 2732.42 S 12 38 29 E 281{5.97 S 12 30 28 E 290{5.88 S 12 24 8 E 3090.93 S 12 15 33 E DOG LEG deg/lO0 O. 155 O. 152 O. 385 O. 54{5 1. 114 1. 198 1. 544' O. 9E;S O. 5~7 O. 540 0.814 1. 975 O. 9{5{5 0.807 O. 874 1.433 0.399 1.273 0.740 2.229 2.219 2.7{53 2. 194 3. 477 3.300 3. 333 2.812 2.55{5 4. 227 2.011 WEST EILEEN ~ W-42 7/19/88 RECORD OF SURVEY MEAS DRIFT TRUVERT SUBSEA SECTION DEPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FROM WELL-HEAD 10028 80 48 8748.27 8655.32 3~18.:1~ S 10.30 E 3150.30 S 10122 81 6 8761.37 8670.42 3312.P8 S 10.00 E 3243.62 S 3234 85 30 8774.43 8683.48 3424.16 S 10.70 E 3353.02 S ~0295 87 30 8778.16 8687.21 3484.99 S 12.10 E 3412.70 S 10415 8~ h2 []7~2.;14 8691.19 3604.76 S 12.10 E 3529.97 S 679.55 E 696.26 E 716.24 E 728.27 E 753.41E 10541 89 0 8784.67 8693.7~ 3730.5~ S 12.80 E 36S2.98 S 10665 89 24 8786.~10 8~b.~5 3854.2S S 12.80'E 3773.88 S 10827 89 S4 8787.39 8696.44 401S.89 S 13.10 E 3931.76 S 109~0 89 18 8788.31 8697.36 4148.56 S 13.10 E ~0~1.30 S 1lOSS 88 42 8789.97 8699.0~ 4243.3~ S 12.80 F 41S3.86 S 780.57 E 808.04 E 844.34 E 874.49 E 895.77 E l~RO 87 h8 8793.79 8702.84 4368.00 S 13.10 E 4275.63 S P23.77 E 11339 86 54 8~01.1h 8710.19 4526.40 S 13.50 E q430.20 S ~60.31E 1146q 87 18 8807.47 8716.52 4650.88 S 13.50 E 4551.59 S 989.46 E 11587 87 36 8812.9~ 8721.99 4773.40 S 13.50 E 4671.07 S 1018.14 E 1~718 87 54 8818.08 8727.13 4903.89 S 13.80 E ~798.27 S 1049.03 E '1792 88 24 8820.47 8729.52 4977.58 S 14.20 E 4870.03 S 1066.92 E CLOSURE DISTANCE DG MN S 3222.76 S 12 10 22 E 3317.51 S 12 6 S4 E 3428.66 S 12 3 28 E 3489.54 S 12 2 47 E 3&09.47 S 12 2 53 E 37~i5.44 S 12 3 42 E 38',J9.42 S 12 5 7 E 4021.40 S 12 7 13 E 4154.38 S 12 9 6 E 4249.35 S 12 10 10 E 4374.28 S 12 11 30 E 4533.08 S 12 13 50 E 4657.89 S 12 15 52 E 4780.74 S 12 17 47 E 4911.60 S 12 19 56 E 4985.54 S 12 21 26 E DOG LEG deg/lO0 1.361 0.437 3.~77 ~.000 1.000 0 .~504 0. 323 O. 360 0.451 0.706 O. 759 0. 320 O. 244 0. 324 0.865 WEST EILEEN ~ W-42 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 7119188 MEAS. DEPTH 91 191 291 391 TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DIFF. CORRECT 91 0 0 0 191 100 0 0 291 200 0 0 391 300 0 0 491 400 0 0 591 591 500 0 0 691 691 600 0 0 791 791 700 0 0 891 891 800 0 0 991 991 900 0 0 1091 1191 1291 1391 1491 1591 1691 1791 :1891 1991 2091 2191 2291 2391 2491 2591 2691 2791 2891 2991 1091 1000 0 0 1191 1100 0 0 1291 1200 0 0 1391 1300 0 0 1491 1400 0 0 15~1 1500 0 0 1691 1600 0 0 1791 1700 0 0 1891 1800 - 0 0 1991 1900 0 0 2091 2000 0 0 2191 2100 0 0 2291 2200 0 0 2391 2300 0 0 2491 2400 0 0 2591 2500 0 0 2691 2600 0 0 2791 2700 0 0 2891 2800 0 0 2991 2900 0 0 RELATIVE COORDINATES FROM WELL-HEAD 0.07 N O.OS 0.07 N 0.36 0.1~4 S 0.74 1.47 S 0.48 2.39 S 0.04 3.13 S O. 20 E 3.68 S 0.62 E 4.02 S 1.15 E 4.13 S 1.71 E 3.98 S 2.48 W 4.23 S 2.93 W 4.73 S 3.25 W 5.37 S 3.31 W 6.00 S 3.04 W 1.46 S 2.34 W 1.18 S 1.70 0.97 S 1.22 0.83 S 0.91 0.76 S 0.75 0.73 S 0.71 0.56 S 0.67 0.21 S 0.86 0.00 S 1.51 0.39 S 2.47 0.98 S 3.36 1.48 S 4.28 W 0.32 N 5.23 W 1.30 N 6.10 W 2.08 N 7.14 W 2.~53 N 8.33 W ~EST EILEEN ~ W-42 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 7119188 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 3091 3191 3291 3391 3491 3591 3{591 3791 3891 3991 ~091 ~192 4294 4396 4500 4607 4715 4937 5050 5164 5280 5396 5512 5629 5746 5862 5977 6091 6203 3091 3000 0 0 3191 3100 0 0 3291 3200 0 0 3391 3300 0 0 3491 3400 0 0 3591 3500 0 0 3691 3600 0 0 3791 3700 0 0 3891 3800 0 0 3991 3900 0 0 4091 4000 0 0 4191 4100 I 1 4291 4200 3 2 4391 4300 S 2 4591 4500 16 7 4791 ~700 3~ 10 4891 ~800 - ~m6 12 ~991 ~900 5~ 13 5091 5000 73 14 5191 5100 89 l& 5291 5200 105 16 5391 5300 121 16 5491 5400 138 17 5591 SSO0 155 17 S691 S600 171 16 5791 5700 186 15 5891 S800 200 14 5991 S900 212 12 RELATIVE COORDINATES FROM WELL-HEAD 2.92 N 9.60 W 2.9~+ N 10.91 W 2. {50 N 12.12 W 1.89 N 13.06 W 0.94 N 13.61 W 0.09 S 13.75 W 1.04 S 13.47 W 1.99 S 13.08 W 3.15 S 12.44 W S.O0 S 12.89 W 10.60 S 12.05 W 21.91 S 9.32 W 38.62 S 4.35 W t50.37 S 3.32 E 87.78 S 13.ztl E 120.52 S 2&.25 E 159.59 S 39.51E 203.37 S 55.86 E 249.84 S 73.07 E 299.82 S 90.09 E 353.20 S 108.10 E 408.15 S 126.13 E 4&3.85 S 143.91 E 521.08 S 1&1.51 E 578.62 S 179.39 E 636.60 S 196.59 E 693.66 S 213.55 E 748.22 S 230.13 E 800.60 S 244.89 E 849.73 S 260.00 E WEST EILEEN ~ W-42 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 7119188 MEAS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT ~315 ~091 ~000 224 12 ~424 6191 6100 233 ~53~ 6291 6200 2~3 10 ~642 6391 6300 251 8 ~750 6491 6~00 259 8 6858 6591 6500 267 8 6966 6691 6600 275 8 7074 6791 6700 283 8 7183 6891 6800 292 9 7293 6991 MgO0 302 10 7404 7091 7000 313 11 7516 7191 7100 325 12 7629 7291 7200 338 13 7743 7391 7300 352 14 7857 7491 7400 366 7970 7591 7500 379 13 8086 7691 7600 395 16 8203 7791 7700 412 17 8323 ' 7891 7800 .- 432 20 B~49 7991 7900 458 26 8578 8091 8000 487 29 8717 8191 8100 526 39 8863 8291 8200 572 ~6 9023 8391 8300 632 60 ~209 8491 8400 718 86 9435 8591 8500 8411 126 9749. 8691 8600 1058 21~ 11087 8791 8700 2296 1238 RELATIVE COORDINATES FRON WELL-HEAD 897.29 S 9111.26 S 98~.86 S 1026.56 S 1067.67 S 269.73 E 280.62 E 285.211E 291.20 E 293.31E 1107.~2 S 1147.03 S 1187.53 S 1230.39 S 1276.21S 297.58 E 295.78 E 297.95 E 303. 011 E 3,12.23 E 132q.17 S 137~.21S lq26.17 S 1~80.34 S 1533.23 S 322.67 E 332.90 E 3110.20 E 3~3.36 E 350.88 E 1585.77 S 1639.99 S 1698.83 S 1764.18 S 1836.41 S 362.10 E 376.26 E 392.32 E ~08.~0 E 1129.49 E 1917.25 S 20O9.81 S 2114.1tl S 2237.14 S 2389.29 S 11119.69 E ~73.32 E k91.52 E S17.26 E 550.62 E 2S88.81S 2883.3S S ~18S.0S S 587.11E 632.13 E 902.88 E WEST E]LEEN ~ W-42 DATA INTERPOLATED FOR EVEN 1000 FEET OF MEASURED DEPTH 7119/88 MEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH RELATIVE COORDINATES FROM WELL-HEAD 1000 1000 909 3.99 S 2.52 W 2000 2000 1909 0.73 S 0.70 W 3000 3000 2909 2.66 N 8.~ W ~000 ~000 3909 5.2~ S 12.88 W SO00 ~9~7 ~856 277.57 S 82.~7 E 6000 5811 5720 758.85 S 233.ql E 7000 6723 6632 1159.78 S 296.27 E 8000 7617 7526 1599.62 S 365.53 E 9000 8379 8288 2218.65 S 513.28 E 1DO00 87~2 86S1 312S.06 S 67q.98 E 11000 8789 8698 ~100.2~ S 883.60 E 500 t000 tSO0 ~000 2500 3000 3500 T 4000 V 4500 D 5000 ~00 6000 6500 7000 7500 8000 8500 9000 -500 0 500 tO00 tSO0 VERTICAL SECTION STANDARD ALASKA PRODUCTION CO. NEST EILEEN # ~-42 SECTION AT S 9.i2 E TVD SCALE: t Inch = lO00 feet DEP SCALE: t inch = 1000 feet DRAWN : 7/19/88 )(aPka, I~nt. tftcatton lid TVD OEMTr U KOP o 0 o BJ 'ID ti79~ BB~O 4976 2000 2500 3000 Departure 3500 4000 4500 5000 5500 4OO 4OO 8OO i200 i600 2OO0 2400 28OO 3200 3600 4000 4400 4800 5200 lim,ker Identification ~ TVD DEPRT U KOP 0 0 0 8J TO 1179~ B~O 4978 HORIZONTAL VIEW STANDARD ALASKA PRODUCTION CO. NEST EILEEN # ~-42 CLOSURE: 4986 ft S 12.4 E DECLINATION: 30.13 deg E SCALE: 1 inch = BO0 feet DRAWN ' 7/t9/88 400 0 400 800 1200 i600 2000 2400 2800 3200 3600 4000 4400 Slandard Alaska Production Company 900 Eo~,! ~.*n'~on B~ule~a~'d PO ~, 19661~ An(ho,og~. AIo~o ~519-661~ 1907l 564-5l I I INDEXED HOUSTON .~c0 STANDARD CHEVRON ALASKA PRODUCTION EXXON Date: 08/23/88 TEXACO lO: TI: 79240 MOBIL PHILLIPS STATE OF ALASKA ARCHIVES REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DAT~ The following material ls belng submitted herewith. Please acknowledge receipt by slgnlng a copy of thls letter and returnlng it to this office: N-23 Injection/Fall-Off 07/08/88 W-42 Static Gradient 08/10/88 Otis Camco Rece 1 red Date A un,, ol the or.ginol $,ondlo,d [~1 Co,'npony Founded ,n Cle-elond. Oh,o. ,n 1870 Jennifer Dietz I NFORMAT I ON CONTROl_ Wol ! Records LR2-1 Standard Alaska Produ¢l~on Comp~-'~, QO0 East Benson ~ Oral P.O. 80. 196612 Anchorage, Alaska 99519-6612 {907) 564-;51 I I DALLAS INDEXED TO: ARCO CHEVRON EXXON TEXACO MOBIL STANDARD ALASKA PRODUCTION Date: 07/15/88 79092 PHILLIPS STATE OF ALASKA GEOSC IENCES RESERVOIR REFERENCE: ARCHIVES DRILLING SAPC CASED HOLE FINAL LOGS The foil°wing material Is being submitted herewith. Please acknowledge recelpt by slgning o copy of this letter and returning it to this office: · · B-09 B-09 B-09 W-42 Perforating.~.Record. Temp-Press-GR Data Frac Data CBT ~ 07/06/88., #1 8700-9680 Sch 07/07/88 #1 9400-9745 Sch 07/09/88 #1 8700-9701 Sch 07/08/88 #1 2590-9378 Sch 1! 5" 5" 5" Rece i ved Date A uni! ol the orig~nol $1ondord C~I Company . :).,::' :" :. Founded in Cl,.,Iond. C)h~o, m 1870. :':- ' ;'~' ;i'~'~'~:-":;;:::';., 'c Jennifer Diertz · }';;!::2.:;i :": INFORMATION CONTROL :,,~: }:'.! .~,ii i: Well Records LR2-1 :: ,i:: :ii!',;'.i{i!:~ii'/:i'!i:{il. !~ MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Smith~i~-~ ~ Commissioner ,/" .f DATE: FILE NO: July 12, 1988 D. HRH 53 TELEPHONE NO: THRU: Michael T Minder ~f?~ susJ~¢~ Sr PetroleUm Engineer BOP Test SAPC PBU W-42 Permit No. 88-57 Prudhoe Oil Pool FROM: Harold R. Hawkins Petroleum Inspector Wednesday, June 22, 1988: I left SAPC DIU .Endicott Field, subject of ~her reports,~'t6"'"S~~-fF 42 (44-21-11-1~-) :. Thursday, June 23, 1988: I witnessed the BOP Test, there was one failure.'..... I' filled'out ~an AOGCC report, which is attached. Friday, June 24, 1988: I received a call on the pager from the SAPC ~'~ra~6~, 'that the ChOke valve failure was repaired. Tested okay. In summary, the BOP Test on AUDI Rig 3, was satisfactorily performed, with the exception of the one failure. Attachment 02-001A (Rev. 8~85) O&G ~/4 5/s4 Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date ~/~ / Well Operator J~ Location: Sec ~ / T//~ R,~ ~ M Drillin~ Contractor ~~ Ri Location, General 0/[ Well Sign General Housekeeping~Rig ~ Reserve Pit ~lud Systems Trip Tank Pit Gauge' Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve.. Kill Line Valves Check Valve Visual Audio Test Pressure Representative ~i~/~ Permit # ~ f7 J3~Casing set ~ A ~?~ ft. # ~ Representative~&Z~ ACCUMULATOR SYSTEM Full Charge Pressure ~'~ psis Pressure After Closure /~ psi~ Pump incr. clos. pres. 200 psig ~ mind, sec. Full Charge Pressure Attained: .~ min~ sec. Control~ Master ~/~ Remote ~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly Test Pressure ~J 0 Lower Kelly Test Pressure ,~ ~ Test Pressure ~-~ Test Pressure ,~-~ Test Pressure Ball Type Inside BOP Choke~nifold No. Valves f ~ No. flanges ~/'/ Adjustable Chokes / Hvdrauically operated choke OZ/~ ~/t Test Results: Failures C3~/~ Test Time ~? hrs. ~Repair or Replacement of failed equipment to be made within ~- days and Inspector/ Commission office notified. Remarks: ~/~y ~-~ ~ .T-~ ~-~ ~ E~D.~.~ /'~.~F~ ~ ~ ~ ~ ./~/~g ~ Distribution orig. - AO&GCC cc - Operator cc - Supervisor Standard Alaska ~-~' Production Company ~ 900 East Benson Bouleva~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 1 June 1988 71 71V Chat V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re' SAPC Gas Injection Well W-41 Dear Mr. Chatterton: The purpose of this letter is to summerize your previous discussion with Stan Gates regarding the cleaning and testing of the above mentioned gas injection well. Near the end of June, SAPC plans to clean the injection zone of the newly drilled well W-41 by flaring gas from the well for approximately 24 hours. Please call Stan Gates at (907) 564-4218 if you have any questions concerning this report'. Sincerely, Steven 1}. 'TaylorI M~nager Environmental an~l Regulatory Affairs SDT:SFG:slh A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. May 26, 1988 Telecopy~ (907)276-7542 Mr. Ted Stagg PBU Drilling Engineering Supervisor Standard Alaska Production Company P.O. Box 196612 Anchorage, Alaska 99519-6612 Prudhoe Bay Unit W-42 Standard Alaska Production Company Permit No. 88-57 Sur. Loc. 1496:SNL, 1454'WEL, Sec. 21, TllN, R12E, UM. Btmhole Loc. 1200'SNL, 650'WEL, Sec. 28, TllN, R12E, UM. Dear M~r. Stagg: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ver~:t-ruly yours, : / .... Chairman o f Alaska Oil and Gas Conservation Co~anission BY O~ER OF THE CO~R,{ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASK. ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll-Illb. Type of well. Exploratoryl-I Stratigraphic Testl-! Development Oill-'! Re-Entry [] DeepenI-II Service J~ Development Gas [] Single Zone [] Multiple Zone [] 12. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Stand~rd Alaska Production Comoanv KB=92 feet Prudhoe Bay Field/Prudhoe - 3. Address 6. Property Designation ~/~,~'~ Bay Pool P. O. Box 196612. Anchorage_ Alaska 99519-6612 ADI_ 28263 A ~ 4. Location of well at surface 7. Unit or property. Name 11. Type Bond(see 20 ^^c 25.o25) 1496' SNL, 1454' WEL, SEC 21, T11N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 5001' SNL, 900' WEL, SEC 21, T11N, R 12E W-42 (44-21-11-12) KOO683449-G-14 At total depth 9. Approximate spud date Amount 1200' SNL, 650' WEL, SEC28, T11N, R12E May 31, 1988 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(uDandTVD) property line ADL 47452 279 feet W-40 70 feet 2560 11858 feet 16. To be completed for deviated wellsKoP2 7927 88e 17. Anticipated pressure (see 20 ^Ac 25.035 (e)(2)) Kickoff depth 4000 feet Maximum hole angle 28 o Maximum surface 3300 pslg At total depth (TVD) psl~ 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD M D TVD (include stage data) 20" Cond. Surface 110' 110' 8 cu yds concrete 17-1/2" 13-3/8" 68# L-80 Butt 2650' Surface 2680' 2680' 3725 cu fl Permafrost 12-1/4" 9-5/8" 47# L-80 NSCC 4474' Surface 4504' 4500' 12-1/4" 9-5/8" 47# L-80 Butt 5846' 4504' 4500' 8783' 10350' 2213 cu fl Class G 8-1/2" 5-1/2" 17# L-80 DSS 1608' 10250' 8777' 11858' 8833' Uncemented slotted liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RE.i EIVED Surface Intermediate MAY 2 ~ 1988 Production Line r Naska Oil & Gas Cons. Commission Perforation depth' measured Anchorage 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 requirements[] ;'1. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed..,_~.~.~-¢~, Title PBU Drillino Eneineorino Suoervisor Date J~-/~3/,~¢ ---~" '" ,/'~" Commission Use Only - - - ~ ' Permit Number IAPI number JAppro.vaJ ,d.at~e. ISee cover letter ~""~'7 15O. Op_..c2 _2_~:,~i~ ~ U.~ / Zb / 88 Ifor other requirements Conditions of approval Samples required [] Yes I~NO Mud Icg required []Yes .I~INO Hydrogen sulfide measures [] Yes I~ No D~rectional survey requ~rea [] Yes [] No working pre ure f B 2M' 3M; ~5M; 1-110M; I-I15M; Other:Required ,/~,~.)~/~~_/_-Z ,/~ e.~~~. '..~ ~ by order of Approved by ( ~ ,~. {, ~'~~,~l~ Commissioner the comm.ssion_ Dat Form 10-401 Rev )licate Standard Alas~ Production Co? ~y 900 East Benso~ ,ulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION May 20, 1988 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn- Mr. C.V. Chatterton Gentlemen' W-42 (34-24-11-12) In accordance with the Prudhoe Bay Field Rules and Standard's policy for drilling the first well on a new pad or a pad previously drilled, a 20" Hydril diverter system was used when drilling the surface hole on W-35 (12-21-11-12), W-38 (34-29-11- 12), W-39 (33-21-11-12) and W-40 (44-21-11-12). We did not experience any surface gas during the drilling of the 17-1/2" hole on any of the W wells and believe it unnecessary to continue the use of the 20" Hydril diverter system on Pad W. We, therefore, request that Rule 4(b) of Conservation Order No. 145 be waived for W-42 (34-24-11-12). Very truly yours, STANDARD ALASKA PRODUCTION COMPANY PBU Drilling Engineering Supervisor TOS/MAW/Im cc: Well File #17 A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. PROPOSED DRILLING AND COMPLETION PROGRAM WELL W-42 [34-24-11-12] PBU/EWE HIGH ANGLE GAS INJECTOR Install and cement 80' of 20" conductor to surface. The drilling fluid program will consist of an 8.5 - 9.5 ppg spud mud in the 17- 1/2" hole, a 9.0 - 9.7 ppg water base mud in the 12-1/4" hole and a 9.4 ppg oil base mud in the 8-1/2" hole. Drill 17-1/2" hole to 2680' and cement 13-3/8" L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVD ss and an oil column to 8800' TVDss. Directionally drill 12-1/4" hole to the 9-5/8" casing point above the Sadlerochit Sandstone. Run 9 5/8" 47# L-80 Buttress/NSCC casing to within 5' of 12-1/4" TD and cement in two stages: First stage using Class G cement around the 9-5/8" shoe. The second stage to be downsqueezed in the 13-3/8" x 9-5/8" annulus followed by nonfreezing fluid. Directionally drill 8-1/2" hole to TD. Run 5-1/2" slotted liner with retrievable SBR and liner hanger/packer from TD to 100' inside the 9-5/8" shoe. Change over to 9.6 ppg NaC1 completion fluid. Test packer and casing to 3000 psi. Run 7" x 5-1/2" tubing with packer and sliding sleeve. Packer to be set at a 55 to 60 degree hole angle. A subsurface safety valve with dual control lines will be placed 50' below the base of permafrost. Install and test Xmas tree. Freeze protect the tubing and annulus. Tubing size: 7" 26# L-80 IJ4S Tubing 5-1/2" 17# L-80 DSS Slotted Liner Tailpipe Size: 5-1/2" JLW:23-MAR-88 RECEIVED MAY 2.3 1.988 Alaska Oil & Gas Cons. Commissior~ Anchorage PROPOSED DOWNHOLE DIAGRAM WELL W-42 [44-21-11-12] PBU/EWE PROPOSED DEPTH BKB 20" Conductor Ball Valve 110 1943 13-3/8" Casing Shoe 17-1/2" Open Hole 2680 2700 7" 26# L-80 IJ4S Tubing Packer 5-1/2" 17# L-80 A/B Mod. Butt. IPC Liner Hanger/Packer 8826 / o~ ;~-~- L,S'. ,,, .x~, . 71~-,/~ · 10250 -- ,~,~ ,~ 9-5/8" Shoe 12-1/4" Open Hole 5-1/2" 17# L-80 DSS Slotted Liner 5-1/2" Liner Shoe 8-1/2" Open Hole 10350 '~ ~ :' 17:? 10355 ~,~Jl~-- RECEIVED MAY 2 3 I988 Alask~ Oi~ & Gas ¢on$, Commission Anchorage 11858 11858 I I I I I I I I I I I I I I I I I I I I I B.O.P. STACK CONFIGURATION 13-5/6 IN. TRIPLE RAM STACK 5000 PSI WP DRILLING ANNULAR PREVENTER 2 IN. KILL LINE CHECK HAND GATE GATE ! I PIPE RAMS 1 1 BLIND RAMS RECE 'VE A~ka Oi~ & Gas Cons, Commissior~ ]- Anchora9~ DRILLING SPOOL I I PIPE RAMS I I 4 IN. CHOKE LINE GATE GATE T. Il N.,R.12 E.,U.M. i. WELLS WELLS 16 15 21 ZZ WI? · WIS WI? WI I W40 % OF WELL PAO Gas Coi~s. II WELL PAD "W" SCALE I" = 400' lEV. I/Il/II JJC · I /Al /I'1~ I LEGEND · EXISTINg CONDUCTOR IOX Q FUTURE CONDUCTOR BOX i i PAD "W" Locoted in PROI'RACT[O IECTION II I T'tI#'II'IIE?t~II4T Surveyed f~ STANDARD ALASKA ~TION CO. Surveyed by * KUUKPIK TECHNICAL SERVICESt INC. · ANCHORAGE, ALASKA (90~ 561-5Z57 ALASKA UNITED RIG NO. 3 MUD SOLIDS CONTROL EQUIPMENT 1 - Brandt Dual Tandem Shale Shaker 1 - Demco 6-12" Cone Shale Desander 1 - Demco 416H w/16 cones & (1) Demco 48H w/16 cones (Desilter) 1- Tri-FIo Horizontal Vacuum Atmospheric Mud Degasser 1- 200 gpm Operating Capacity Centrifuge 19- Brandt MA5 Mud Mix Agitators 1- 125 bbl. Trip Tank 1- Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console 1- Drilling fluid flow sensor with readout at driller's console 1- Cavium Dewatering screen assembly i,/~/:?'," 2 0il & Gas Co~s. C RIG 3 MUD SYSTEM ALASKA UNITED DRILLING INC. RIG 3 MUD SYSIEM October 1987 1 CHECKED FiLE NO hITS _$15DUAIO:[DRANO23]W41_~LOSAP_SHORT7. LIS~14 17-MAY-1988 08:21 --- Closest Approach Analgsis Date' 17-MAY-88 Time' 08'21'13 Search Radius= 3000 7 DEGREE LEAD LINE' For proposed well' ~-~ [44-21-11-12] Location = W-E S-N TVD(SBS) Top 51178~.00 5958757.00 -92.50 Bottom 513255.55 5953~20.48 8740.00 Note' All depths in ~eet Below Kellg Bushing (BKB) WELL IDENT Closest Approach /PROPOSED\ /NEARBY\ CLOSEST TVD DEPART TVD DEPART DISTANCE A029-2000800 KUPST1 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW A02~-2017200 321112 8402.7 23&1. I 9033.4 3343.5 4101.5 A02~-2052400 MP1511 7236.6 1424.8 ~135.~ 6808.0 4435.3 W-T 41~9~7 8.7 425~.~ 1505.6 25~1.0 A02~-2177500 W-40 4000.0 0.0 4000.2 15.9 54.1 A02~-2178400 ' W-3~ 4000.0 0.0 399~. 1 19.3 84.8 Vertical /PROPOSED\ TVD DEPART Intersection /NEARBY\ TVD SUMMARY The well which comes closest to the AO2~-2177bO0 W-40 proposed well is: Closest approach distance = KICK OFF ~or this run = 54. 1 ~eet 4000.0 ~eet DEPART Page 1 VERTICAL DISTANCE oil & Gas Cons. Commission Anchorags _$1$DUAIO: [DRANO~3]W41_CLOSAP_SHORT7. LIS; 14 17-MAY-1988 08:~1 --- Closest Approach Analgsis --- Date' 17-MAY-88 Time' 08~i'13 Search Radius= 3000 7 DEGREE LEAD LINE For proposed well: k~-~ [44-~1-11-12] Location = W-E S-N TVD(SBS) Top 611789.00 5938757.00 -92.50 Bottom 613265.56 5953920.48 8740.00 Note: All depths in ~eet Below Kellg Bushing (BKB) Closest Approach WELL IDENT /PROPOSED\ /NEARBY\ CLOSEST TVD DEPART TVD DEPART DISTANCE A029-2000800 KUPST1 NO COORDINATE POINTS WITHIN SPECIFIED SEARCH WINDOW 221112 8402.7 2361.1 9033.4 3343.5 A029-2052400 MP1511 7236.6 1424.8 9135.9 6808. 0 A029-2103300 W-T 4199.7 8.7 4259.6 1505.6 A029-2177600 W-40 4000.0 0.0 4000.2 15.9 A029-2178400 W-39 4000.0 0.0 3999. I 19.3 4101.5 4435.3 2591.0 54. I ' 84.8 Vertical Intersection /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART SUMMARY Page 1 VERTICAL DISTANCE The well which comes closest to the proposed well is: A029-2177600 W-40 Closest approach distance = KICK OFF ~or this run = 54.1 ~eet 4000.0 ~eet CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2 thru 8) (3) Admin ~ ~/63 ~ 9. (9 thru 13) 10. (10 and 13) 12. 13. (4) Casg ~,~,~. ~-~-M~ (14 thru 22) <5) (23 thru 28) (29 thru 31) rev: 02/17/88 6.011 Company ~/qP~<~ Lease & Well No. YES NO Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. ~ ,. 3. Is well located proper distance from property line .................. ~__ 4. Is well located proper distance from other wells .................... ~_ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... _~ Does operator have a bond in force .................................. ~ Is.a conservation order needed ...................................... · Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... 14. Is conductor string provided ........................................ 15. Will surface casing protect fresh water zones ....................... 16. Is enough cement used to circulate on conductor and surface ......... 17. Will cement tie in surface and intermediate or production strings ... 18. Will cement cover all known productive horizons ......... ~... ........ 19. Will all casing give adequate safety in collapse, tension and burst.. 20. Is this well to be kicked off from an existing wellbore ............. 21. Is old wellbore abandonment procedure included on 10-403 ............ 22. Is adequate wellbore separation proposed ............................ 23. Is a diverter system required ....................................... 24. Is the drilling fluid program schematic and list of equipment adequate~_~ 25. Are necessary diagrams and descriptions of diverter and BOPE attached. 26. Does BOPE have sufficient pressure rating - Test to ~~ psig .. 27. Does the choke manifold comply w/API RP-53 (May 84) .................. 28. Is the presence of H2S gas probable ............. · .................... For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones .......... ..../~ 31 If an offshore loc., are survey results of seabed conditions pressed 32. Additional requirements ............................................. ~ INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks: 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. I LIS VERIFICATION LISTING FOR: STANDARD ALASKA PROD. CO. W-42 WEST EILEEN I i i i i I I' I ! ! !' I ! I ! ! I I I I I ** reel header ** service name :RGD date :89/04/28 origin :2300 reel name :636TAK continuation # :01 previous reel : comments :TELECO OILFIELD SERVICES PROPRIETARY FIELD TAPE ** tape header ** service name :RGD date :89/04/28 origin :2300 tape name :636TAK continuation # :01 previous tape : comments :RIG ALASKA UNITED DRILLING RIG #3 ** file header ** file name :636TAK.001 service name :RGD version # : 1.24 date :89/04/28 maximum length :1024 file type :LO previous file : ** information records ** table type :TOOL MNEM STAT LENG WEIG HEIG GR ALLO 0.000 0.000 0.000 RSN ALLO 72.000 0.000 0.000 DCDS ALLO 360.000 0.000 0.000 ** information records ** table type :CONS MNEM STAT PUNI TUNI VALU I I I I I I I I ! ! I I ! ! I ! I I I BS UNAL CSIZ UNAL SD UNAL WMUD UNAL SHT UNAL BHT UNAL TD UNAL YEAR UNAL MONT UNAL DAY UNAL ** information records ** IN IN F LB/G DEGF DEGF F table type :CONS MNEM STAT PUNI SON UNAL Ri UNAL R2 UNAL R3 UNAL R4 UNAL R5 UNAL R6 UNAL R7 UNAL R8 UNAL HIDE UNAL WN UNAL CN UNAL FN UNAL FL UNAL FL1 UNAL LUL UNAL ENGI UNAL WITN UNAL DFT UNAL LONG UNAL LATI UNAL STAT UNAL COUN UNAL DMF UNAL LMF UNAL PDAT UNAL APIN UNAL IN IN F LB/G DEGF DEGF F TUNI 8.500 9.625 9300.000 9.500 0.000 0.000 11830.000 89.000 4.000 28.000 VALU RESISTIVITY/GAMMA/DIRECTIONAL W-42 STANDARD ALASKA EXPL. CO. WEST EILEEN ANCHORAGE BURTON/WALL POTTER ALASKA NORTH SLOPE BOROUGH RKB RKB I I I I I [ ! ! I ! I i ! ! I I i ! OS1 OS2 OS3 OS4 0S5 OS6 TLAB TCS TN1 TN2 TN3 TN4 TN5 TN6 TN7 TN8 TN9 TN10 TNll TN12 SECT TOWN RANG NATI CONT MSS MFSS MCSS SLAB CLAB CS1 CS2 CS3 BS1 BS2 BS3 HLD RUN LUN OPER LLUN LCC BLI TLI EPD UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL USA NAM STATE COUNTY 13.375 9.625 17.50 12.25 8.50 INCL 0.000 0.000 0.000 2300.000 0.000 0.000 0.000 0.000 I I [ [ I [ I I I I Ir l' I [ I Il I I I APD UNAL EKB UNAL EDF UNAL EGL UNAL TDD UNAL TDL UNAL CW1 UNAL BS D 1 UNAL CBD1 UNAL CBL1 UNAL CW2 UNAL BSD2 UNAL CBD2 UNAL CBL2 UNAL CW3 UNAL BS D 3 UNAL CBD3 UNAL CBL3 UNAL STEM UNAL MRT UNAL DFD UNAL DFV UNAL DFPH UNAL DFL UNAL RMFS UNAL RMS UNAL RMCS UNAL MST UNAL MFST UNAL MCST UNAL ** information records ** table type MNEM :PRES GR ROP SWOB DRHO PHIN PEF BS OUTP GR ROP SWOB DRHO PHIN PEF BS F F F F F F LB/F F F F LB/F F F F LB/F F F F DEGF DEGF LB/G S C3 OHMM OHMM OHMM DEGF DEGF DEGF STAT ALLO ALLO ALLO DISA DISA DISA DISA F F F F F F LB/F F F F LB/F F F F LB/F F F F DEGF DEGF LB/G S C3 OHMM OHMM OHMM DEGF DEGF DEGF TRAC Ti T2 T3 T3 T23 T23 Ti 0.000 90.950 90.950 0.000 11830.000 11830.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 CODI LLIN LGAP HSPO LSPO LDAS HGAP LSPO DEST 1 1 1 1 1 1 1 MODE NB NB NB NB SHIF SHIF NB I I I I I I I I I I I I I I I I I I I TENS TENS DISA FFLS FFLS DISA FFSS FFSS DISA FLS FLS DISA FSS FSS DISA LSHV LSHV DISA SSHV SSHV DISA 14 DUMM DISA 15 DUMM DISA 16 DUMM DI SA 17 DUMM DISA 18 DUMM DISA 19 DUMM DI SA ** information records ** T2 Ti Ti TI Ti T2 T2 Ti TI Ti Ti Ti Ti LSPO LLIN HGAP LSPO HDAS LLIN LDAS LLIN LLIN LLIN LLIN LLIN LLIN 1 2 2 2 2 2 2 NEIT NEIT NEIT NEIT NEIT NEIT NB NB NB NB NB SHIF SHIF NB NB NB NB NB NB table type :FILM MNEM GCOD 1 EEE 2 EEE ** information records ** GDEC DEST PF1 PF2 DSCA S2 D500 table type :AREA MNEM STAT 1 DISA 2 DISA 3 DISA 4 DISA 5 DISA 6 DISA 7 DISA 8 DISA ** data-format record ** entry blocks type 4 8 size 1 4 BEGI Zl Zl Z1 Zl Z1 Z1 Zl Z1 repr code 66 68 END Z1 Z1 Z1 Z1 Z1 Z1 Z1 Z1 entry 255 60.000 PATT BLAN BLAN BLAN BLAN BLAN BLAN BLAN BLAN DEST NEIT NEIT NEIT NEIT NEIT NEIT NEIT NEIT [ [ [ [ ! [ [ [ [ [ ! [ ! [ [ [ [ [ [ 9 12 0 datum specification blocks WARNING the following table is Sub-Type 0 and the API mnem service service id order # DEPT GR ROP SWOB INC AZM TVD NS EW VS DLS unit api log FT 00 00 00 00 00 00 00 00 00 00 00 4 65 .liN 4 68 -9999.000 2 79 0 in LIS Datum Specification Block Type Codes may be Unreliable!!! api api api file size spl repr type class mod no. code 000 00 00 0 4 1 68 000 00 00 0 4 1 68 000 00 00 0 4 1 68 000 00 00 0 4 1 68 000 00 00 0 4 1 68 000 00 00 0 4 1 68 000 00 00 0 4 1 68 000 00 00 0 4 1 68 000 00 00 0 4 1 68 000 00 00 0 4 1 68 000 00 00 0 4 1 68 process level 0 0 0 0 0 0 0 0 0 0 0 depth = 9325.0000 feet GR 1.0000 ROP AZM 1.0000 TVD VS 1.0000 DLS depth = 9425.0000 feet GR 158.5000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = 9525.0000 feet GR 182.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = 9625.0000 feet GR 77.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS 2842.2600 meters 1.0000 SWOB 1.0000 INC 1.0000 NS 1.0000 EW 1.0000 2872.7400 meters -9999.0000 SWOB -9999.0000 -9999.0000 NS -9999.0000 -9999.0000 2903.2200 meters 50.3080 SWOB 65.6600 -9999.0000 NS -9999.0000 -9999.0000 2933.7000 meters 50.7050 SWOB 61.9140 -9999.0000 NS -9999.0000 -9999.0000 INC EW INC EW INC EW 1.0000 1.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 I ! I ! I I I ! i I ! ! ! I I I ! ! ! depth = 9725.0000 feet GR -9999.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = 9825.0000 feet GR -9999.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = 9925.0000 feet GR -9999.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = GR AZM VS 10025.0000 feet 115.0000 ROP -9999.0000 TVD -9999.0000 DLS depth = 10125.0000 feet GR 126.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = GR AZM VS 10225.0000 feet 89.0000 ROP -9999.0000 TVD -9999.0000 DLS depth = 10325.0000 feet GR 345.8750 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = GR AZM VS depth = GR AZM VS 10425.0000 feet 90.0000 ROP -9999.0000 TVD -9999.0000 DLS 10525.0000 feet 52.0000 ROP -9999.0000 TVD -9999.0000 DLS 2964.1800 meters 4.4090 SWOB 65.8560 -9999.0000 NS -9999.0000 -9999.0000 2994.6600 meters -9999.0000 SWOB -9999.0000 -9999.0000 NS -9999.0000 -9999.0000 3025.1400 meters -9999.0000 SWOB -9999.0000 -9999.0000 NS -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 INC EW 20.8150 -9999.0000 -9999.0000 INC EW INC EW 3055.6200 meters SWOB -9999.0000 INC NS -9999.0000 EW 3086.1000 meters SWOB 54.1070 INC NS -9999.0000 EW 3116.5800 meters 46.5500 SWOB 31.3850 -9999.0000 NS -9999.0000 -9999.0000 3147.0600 meters 32.1770 SWOB 48.1330 -9999.0000 NS -9999.0000 -9999.0000 3177.5400 meters 22.9970 SWOB 54.2700 -9999.0000 NS -9999.0000 -9999.0000 INC EW 52.3280 -9999.0000 -9999.0000 INC EW INC EW 3208.0200 meters SWOB 25.4590 INC NS -9999.0000 EW -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 I [ [ ! ! ~' [ ! [ [ ! [ ! I I [ [ [ I depth = GR AZM VS depth = GR AZM VS 10625.0000 feet 53.0000 ROP -9999.0000 TVD -9999.0000 DLS 10725.0000 feet 64.0000 ROP -9999.0000 TVD -9999.0000 DLS depth = 10825.0000 feet GR 51.5000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = 10925.0000 feet GR 51.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = 11025.0000 feet GR 49.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = GR AZM VS depth = GR AZM VS 11125.0000 feet 74.0000 ROP -9999.0000 TVD -9999.0000 DLS 11225.0000 feet 100.5000 ROP -9999.0000 TVD -9999.0000 DLS depth = 11325.0000 feet GR 55.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = 11425.0000 feet GR 59.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS 34.3820 -9999.0000 -9999.0000 3238.5000 meters SWOB 20.7680 INC NS -9999.0000 EW 37.2100 -9999.0000 -9999.0000 3268.9800 meters SWOB 20.4230 INC NS -9999.0000 EW 43.5880 -9999.0000 -9999.0000 3299.4600 meters SWOB 18.3950 INC NS -9999.0000 EW 3329.9400 meters 57.5690 SWOB 29.6960 -9999.0000 NS -9999.0000 -9999.0000 3360.4200 meters 75.1830 SWOB 56.5890 -9999.0000 NS -9999.0000 -9999.0000 3390.9000 meters 51.9780 SWOB 57.7960 -9999.0000 NS -9999.0000 -9999.0000 3421.3800 meters 54.9610 SWOB 64.6970 -9999.0000 NS -9999.0000 -9999.0000 64.5540 -9999.0000 -9999.0000 INC EW 53.2180 -9999.0000 -9999.0000 INC EW INC EW INC EW 3451.8600 meters SWOB 69.0060 INC NS -9999.0000 EW 3482.3400 meters SWOB 46.0380 INC NS -9999.0000 EW -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 ! ! ! !' ! I i' i ! ! I I I~ ! I i i i depth = 11525.0000 feet GR 57.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = 11625.0000 feet GR 73.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = 11725.0000 feet GR 65.0000 ROP AZM -9999.0000 TVD VS -9999.0000 DLS depth = 11825.0000 feet GR -9999.0000 ROP AZM 165.8000 TVD VS 5010.4336 DLS ** file trailer ** file name :636 .001 service name :RGD version # : 1.24 date :89/04/28 maximum length :1024 file type :LO next file name : 3512.8200 meters 45.4830 SWOB 33.3070 -9999.0000 NS -9999.0000 -9999.0000 3543.3000 meters 55.2030 SWOB 38.7310 -9999.0000 NS -9999.0000 -9999.0000 3573.7800 meters 84.3640 SWOB 56.1520 -9999.0000 NS -9999.0000 -9999.0000 3604.2600 meters 70.5480 SWOB 62.6340 8820.5410 NS -4902.2070 0.6380 INC EW INC EW INC EW INC EW -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 88.5000 1073.7849 LIS VERIFICATION LISTING FOR: STANDARD ALASKA PROD. CO. WELL W-~ WEST EILEEN ¸%, i I I I I I I I I I I I I I I I I I ** reel header ** service name :DG date :89/02/08 origin : reel name :636TAK continuation # :01 previous reel : comments :TELECO OILFIELD SERVICES PROPRIETARY FIELD TAPE ** tape header ** service name :DG date :89/02/08 origin : tape name :636TAK continuation # :01 previous tape : comments :RIG ALASKA UNITED DRILLING #3 ** file header ** file name :636TAK.001 service name :DG version # : 1.24 date :89/02/08 maximum length :1024 file type :LO previous file : ** information records ** table type :TOOL MNEM STAT GR ALLO RSN ALLO DCDS ALLO ** information records ** LENG 0.000 72.000 360.000 WEIG HEIG 0.000 0.000 0.000 0.000 0.000 0.000 table type :CONS MNEM STAT PUNI TUNI VALU I I I I Il I I I I I I I I I I I I I I BS UNAL CSIZ UNAL SD UNAL WMUD UNAL SHT UNAL BHT UNAL TD UNAL YEAR UNAL MONT UNAL DAY UNAL ** information records ** IN IN F LB/G DEGF DEGF F table type :CONS IN IN F LB/G DEGF DEGF F 8.500 9.625 9300.000 9.500 0.000 O.O0O 11830.000 89.000 2.000 8.000 MNEM STAT PUNI TUNI VALU SON UNAL Ri UNAL R2 UNAL R3 UNAL R4 UNAL R5 UNAL R6 UNAL R7 UNAL R8 UNAL HIDE UNAL WN UNAL CN UNAL FN UNAL FL UNAL FL1 UNAL LUL UNAL ENGI UNAL WITN UNAL DFT UNAL LONG UNAL LATI UNAL STAT UNAL COUN UNAL DMF UNAL LMF UNAL PDAT UNAL APIN UNAL DIRECTIONAL/GAMMA W-42 STANDARD ALASKA PROD. WEST EiLEEN ANCHORAGE WALL/RANDALL POTTER ALASKA NORTH SLOPE BOROUGH RKB ~ RKB CO. I I I I I I I I I I I I I I I I I I I OS1 OS2 OS3 0S4 OS5 OS6 TLAB TCS TN1 TN2 TN3 TN4 TN5 TN6 TN7 TN8 TN9 TN10 TNll TN12 SECT TOWN RANG NATI CONT MSS MFSS MCSS SLAB CLAB CS1 CS2 CS3 BS1 BS2 BS3 HLD RUN OPER LLUN LCC BLI TLI EPD APD UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL UNAL 0.000 F F F F USA NAM STATE COUNTY 13.375 9.625 17.50 12.25 8.50 INCL 0.000 0.000 · 0. 0. 0. 0. 000 000 000 · 000 000 LUN UNAL I I I I I l' I iI [ I I I I I I I I I I EKB UNAL EDF UNAL EGL UNAL TDD UNAL TDL UNAL CW1 UNAL BSD1 UNAL CBD1 UNAL CBL1 UNAL CW2 UNAL BSD2 UNAL CBD2 UNAL CBL2 UNAL CW3 UNAL BS D 3 UNAL CBD3 UNAL CBL3 UNAL STEM UNAL MRT UNAL DFD UNAL DFV UNAL DFPH UNAL DFL UNAL RMFS UNAL RMS UNAL RMCS UNAL MST UNAL MFST UNAL MCST UNAL ** information records ** table type MNEM :PRES OUTP F F F F F LB/F F F F LB/F F F F LB/F F F F DEGF DEGF LB/G S C3 OHMM OHMM OHMM DEGF DEGF DEGF STAT F F F F F LB/F F F F LB/F F F F LB/F F F F DEGF DEGF LB/G S C3 OHMM OHMM OHMM DEGF DEGF DEGF GR GR ALLO ROP ROP ALLO RSNC RSNC DISA RSNC RSNC DISA SWOB SWOB ALLO TCDS TCDS DISA BS BS DISA TENS TENS DISA TRAC TI T2 T2 T2 T3 T3 TI T2 90.950 90.950 0.000 11830.000 11830.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000. CODI DEST LLIN MGAP LLIN MSPO LDAS HGAP LSPO LSPO MODE NB NB NB NB NB NB NB NB FFLS FFLS DISA FFSS FFSS DISA FLS FLS DISA FSS FSS DISA LSHV LSHV DISA SSHV SSHV .DISA 14 DUMM DISA 15 DUMM DISA 16 DUMM DI SA 17 DUMM DISA 18 DUMM DISA 19 DUMM DISA ** information records ** Ti Ti Ti Ti T23 T23 Ti Ti Ti Ti Ti Ti LLIN HGAP LSPO HDAS LLIN LDAS LLIN LLIN LLIN LLIN LLIN LLIN 2 2 2 2 2 2 NEIT NEIT NEIT NEIT NEIT NEIT NB NB NB NB SHIF SHIF NB NB NB NB NB NB table type :FILM MNEM GCOD GDEC DEST DSCA 1 EEE .... PF1 S2 2 EEE .... PF2 D500 ** information records ** table type :AREA MNEM STAT BEGI END PATT DEST 1 DISA 2 DISA 3 DISA 4 DISA 5 DISA 6 DISA 7 DISA 8 DISA Z1 Z1 ,Z1 Z1 Z1 Z1 Z1 Z1 ** data-format record ** entry blocks typD 4 8 9 size 1 4 4 repr code 66 68 65 Z1 Zl Z1 Zl Z1 Z1 Z1 Z1 BLAN BLAN BLAN BLAN BLAN BLAN BLAN BLAN NEIT NEIT NEIT NEIT NEIT NEIT NEIT NEIT entry 255 60.000 .liN I I I I I I I I I I I I I I I I I I I 12 4 68 -9999.000 0 2 79 0 datum specification blocks WARNING the following table is in LIS Datum Specification Block Sub-Type 0 and the API Type Codes may be Unreliable!!! mnem service service unit api api api api file size spl repr id order # log type class mod no. code DEPT FT 00 000 00 00 0 4 1 68 GR 00 000 00 00 0 4 1 68 ROP 00 000 00 00 0 4 1 68 SWOB 00 000 00 00 0 4 1 68 INC 00 000 00 00 0 4 1 68 AZM 00 000 00 00 0 4 1 68 TVD 00 000 00 00 0 4 1 68 NS 00 000 00 00 0 4 1 68 EW 00 000 00 00 0 4 1 68 VS 00 000 00 00 0 4 1 68 DLS 00 000 00 00 0 4 1 68 process level 0 0 0 0 0 0 0 0 0 0 0 depth = GR AZM VS depth = GR AZM VS depth = GR AZM VS depth = GR AZM VS 9325.0000 feet .... 2842.2600 meters 1.0000 ROP 1.0000 SWOB 1.0000 INC 1.0000 TVD 1.0000 NS 1.0000 EW 1.0000 DLS 1.0000 9425.0000 feet -9999.0000 ROP -9999.0000 TVD -9999.0000 DLS 2872.7400 meters -9999.0000 SWOB -9999.0000 INC -9999.0000 NS -9999.0000 EW -9999.0000 9525.0000 feet .... 2903.2200 meters 182.0000 ROP -9999.0000 SWOB -9999.0000 INC -9999.0000 TVD -9999.0000 NS -9999.0000 EW -9999.0000 DLS -9999.0000 9625.0000 feet -9999.0000 ROP -9999.0000 TVD -9999.0000 DLS 2933.7000 meters 50.7050 SWOB 61.9140 INC -9999.0000 NS -9999.0000 EW -9999.0000 1.0000 1.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 depth = 9725.0000 feet .... 2964.1800 meters I I I I I I I I I I I I I I I I I I I GR AZM VS depth = GR AZM VS depth = GR AZM VS depth = GR AZM VS depth = GR AZM VS depth = GR AZM VS depth = GR iAZM VS depth = GR AZM VS depth = GR AZM VS -9999.0000 ROP -9999.0000 TVD -9999.0000 DLS 9 -9999. -9999. -9999. 9 -9999. -9999. -9999. 10 115. -9999. -9999. 1 -9999 -9999 -9999 1 89 -9999 -9999 825.0000 feet 0000 ROP 0000 TVD 0000 DLS 925.0000 feet 0000 ROP 0000 TVD 0000 DLS 4.4090 SWOB 65.8560 INC -9999.0000 NS -9999.0000 EW -9999.0000 2994.6600 meters -9999.0000 SWOB -9999.0000 -9999.0000 NS -9999.0000 -9999.0000 3025.1400 meters -9999.0000 SWOB -9999.0000 -9999.0000 NS -9999.0000 -9999.0000 025.0000 feet .... 0000 ROP -9999.0000 0000 TVD -9999.0000 0000 DLS -9999.0000 0125.0000 feet .0000 ROP 20.8150 .0000 TVD -9999.0000 .0000 DLS -9999.0000 0225..0000 feet .0000 ROP .0000 TVD .0000 DLS '103 -9999.0 -9999.0 -9999.0 INC EW 104 90.0 -9999.0 -9999.0 INC EW 105 52.0 -9999.0 -9999.0 3055.6200 meters SWOB -9999.0000 INC NS -9999.0000 EW 25.0000 feet 000 ROP 000 TVD 000 DLS 3086.1000 meters SWOB 54.1070 INC NS -9999.0000 EW 25.0000 feet 000 ROP 000 TVD 000 DLS 3116.5800 meters 46.5500 SWOB 31.3850 -9999.0000 NS -9999.0000 -9999.0000 25.0000 feet 000 ROP 000 TVD 000 DLS 3147.0600 meters 32.1770 SWOB 48.1330 -9999.0000 NS -9999.0000 -9999.0000 3177.5400 meters 22.9970 SWOB 54.2700 -9999.0000 NS -9999.0000 -9999.0000 3208.0200 meters 52.3~80 SWOB 25.4590 -9999.0000 NS -9999.0000 -9999.0000 INC EW INC EW INC EW INC EW -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 depth = 10625.0000 feet 3238.5000 meters I I I' I I I I I lI I I I I I I I I I I GR AZM VS depth = GR AZM VS depth = GR AZM VS depth = GR AZM VS depth = GR AZM VS depth = GR AZM VS depth = GR AZM VS depth = GR AZM VS depth = GR :AZM VS 53.0000 ROP -9999.0000 SWOB -9999.0000 INC -9999.0000 TVD -9999.0000 NS -9999.0000 EW -9999.0000 DLS -9999.0000 10725.0000 feet .... 3268.9800 meters 64.0000 ROP -9999.0000 SWOB -9999.0000 INC -9999.0000 TVD ~-9999.0000 NS -9999.0000 EW -9999.0000 DLS -9999.0000 10825.0000 feet .... -9999.0000 ROP 43.5880 -9999.0000 TVD -9999.0000 -9999.0000 DLS -9999.0000 3299.4600 meters SWOB 18.3950 INC NS -9999.0000 EW 10925.0000 feet .... -9999.0000 ROP 57.5690 -9999.0000 TVD -9999.0000 -9999.0000 DLS -9999.0000 3329.9400 meters SWOB 29.6960 INC NS -9999.0000 EW 11025.0000 feet 49.0000 ROP -9999.0000 TVD -9999.0000 DLS 11125.0000 feet 74.0000 ROP -9999.0000 TVD -9999.0000 DLS 3360.4200 meters 75.1830 SWOB 56.5890 -9999.0000 NS -9999.0000 -9999.0000 3390.9000 meters -9999.0000 SWOB -9999.0000 -9999.0000 NS -9999.0000 -9999.0000 11225.0000 feet -9999.0000 ROP -9999.0000 TVD -9999.0000 DLS 3421.3800 meters -9999.0000 SWOB -9999.0000 -9999.0000 NS -9999.0000 -9999.0000 11325.0000 feet 55.0000 ROP -9999.0000 TVD -9999.0000 DLS 3451.8600 meters -9999.0000 SWOB -9999.0000 -9999.0000 NS -9999.0000 -9999.0000 11425.0000 feet 59.0000 ROP -9999.0000 TVD -9999.0000 DLS 3482.3400 meters ~53.2180 SWOB 46.0380 -9999.0000 NS -9999.0000 -9999.0000 INC EW INC EW INC EW INC EW INC EW -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 depth = 11525.0000 feet 3512.8200 meters I I I i I I I I I i I ! GR 57.0000 ROP 45.4830 SWOB 33.3070 INC AZM -9999.0000 TVD -9999.0000 NS -9999.0000 EW VS -9999.0000 DLS -9999.0000 depth = 11625.0000 feet 3543.3000 meters GR -9999.0000 ROP -9999.0000 SWOB -9999.0000 INC. AZM -9999.0000 TVD -9999.0000 NS -9999.0000 EW VS -9999.0000 DLS -9999.0000 depth = 11725.0000 feet 3573.7800 meters GR 65.0000 ROP -9999.0000 SWOB -9999.0000 INC AZM -9999.0000 TVD -9999.0000 NS -9999.0000 EW VS -9999.0000 DLS -'9999.0000 depth = 11825.0000 feet .... 3604.2600 meters GR -9999.0000 ROP 70.5480 SWOB 62.6340 INC AZM 165.8000 TVD 8820.5410 NS -4902.2070 EW VS 5010.4336 DLS 0.6380 I I I I I I I -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 -9999.0000 88.5O00 1073.7849 ** file trailer ** file name :636TAK. 001 service name :DG version # : 1.24 date :89/02/08 maximum length ~ 1024 file type :LO next file name :