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179-019
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, November 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC B-15 PRUDHOE BAY UNIT B-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 11/26/2025 B-15 50-029-20360-00-00 179-019-0 W SPT 7635 1790190 1909 768 771 769 767 8 8 6 6 4YRTST P Bob Noble 10/12/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT B-15 Inspection Date: Tubing OA Packer Depth 99 2142 2069 2050IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN251012163645 BBL Pumped:1.5 BBL Returned:2.1 Wednesday, November 26, 2025 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 6, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC B-15 PRUDHOE BAY UNIT B-15 Src: Inspector Reviewed By: _ P.I. Supry Comm Well Name PRUDHOE BAY UNIT B-15 API Well Number 50-029-20360-00-00 Inspector Name: Bob Noble Permit Number: 179-019-0 Inspection Date: 10/3/2021 - Insp Num: mitRCN211004100257 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well B-15 Type Inj w jTVD 7635 Tubing 762 763 764 764 PTD 1790190 'Type Test SPT Test psi 1909 IA 118 2200 2143 2134 BBL Pumped: 1.8 ii Returned: BBL Ret 1-8 � OA 21 19 19 19 - - Interval 4YRTST P/F P Notes: Wednesday, October 6, 2021 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,October 10,2017 TO: Jim Regg P.I.Supervisor of(G (Vire-11 7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. B-15 FROM: Chuck Scheve PRUDHOE BAY UNIT B-I5 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT B-15 API Well Number 50-029-20360-00-00 Inspector Name: Chuck Scheve Permit Number: 179-019-0 Inspection Date: 10/10/2017 Insp Num: mitCS171010140359 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well B-15 -IType Inj W TVD 7635 - Tubing 444 - 445 _ 444 - 445 - PTD 1790190 �Type Test SPT Test psi 1909 IA 301 2500 - 2462 2456 BBL Pumped: 2.1 • BBL Returned: 2 - OA 34 • 31 ' 31 ' 33 Interval 4YRTST P/F P Notes: SCOlsiE Tuesday,October 10,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, October 15, 2013 To: Jim Regg P.I. Supervisor Z P.I. 4 13 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC B-15 FROM: John Crisp PRUDHOE BAY UNIT B-15 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supr' j6-2— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT B-15 API Well Number 50-029-20360-00-00 Permit Number: 179-019-0 Insp Num: mitJC031014062443 Rel Insp Num: Inspector Name: John Crisp Inspection Date: 10/10/2013 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well B-15 Type Inj w -TVD 7635 IA 638 2517. 2474. 2466 TD 1790190 Type Test SPT Test psi 1909 OA 32 14 20 26 ntervali 4YRTST • P/F P / Tubing 534 534 533 533 Notes: 1 bbl pumped for test. OA cemented to surface. - "IAED 0 C T 1 3 2014 Tuesday, October 15, 2013 Page 1 of 1 • 036k8 -15 Regg, James B (DOA) PTO i7 /0 Iqo To: AK, D &C Well Integrity Coordinator Cc: Brooks, Phoebe L (DOA) 'get 31 Z - 3 t 12 — Subject: RE: MIT Due Dates for BP Thank you. Phoebe will review the discrepancies listed below. Re: PBU B -15 and PBU P2 -24, we will accept the unwitnessed MITs as satisfying the AOGCC requirements. The anniversary dates for MITs are adjusted as follows: e PBU B -15: 4yr MIT interval; last test 10/27/2009; next due 10/27/2013 PBU P2 -34: 2yr MIT interval; last test 4/12/2010; next due 4/12/2012 Jim Regg AOGCC 333 W. 7th Ave, Suite 100 %„ kti - MAR " ZUV Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Thursday, March 22, 2012 10:45 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA) Subject: RE: MIT Due Dates for BP Jim, Phoebe, BPXA has conducted a review of the list provided. The following two online wells are noted as past due for not having an AOGCC witnessed MIT -IA: ,/B -15 (PTD #1790190) was due for a 4 -year AOGCC witnessed MIT -IA on 09/03/2011. An internal MIT -IA was performed on 10/27/2009 which reset our 4 -year testg. The internal test was performed to evaluate TxIA communication and the test form was submitted to the AOGCC. «B- 15.pdf» «MIT PBU B -15 10- 27- 09.xls» «B -15 TIO 03- 22- 12.doc» P2 -34 (PTD #1950660) was due for a 2 -year AOGCC witnessed MIT -IA on 02/14/2011 and MIT -T on 03/30/2011. Internal MITs were performed on 04/12/2010 which reset our 2 -year test flag. The internal tests were performed in order to evaluate this well for MI service «P2- 34.pdf» «MIT PBU P2 -34 04- 12- 10.xls» «P2 -34 TIO 03- 22- 12.doc» The following wells appear to have incorrect information he AOGCC list based on this review: - 11 -08 (PTD #1842290) - AOGCC data notes 8,year test frequency but is online - 12 -21 (PTD #1840480) - AOGCC data notfs''L test frequency instead of 4 year - 13 -32A (PTD #2012350) - AOGCC dat fiotes 8 year test frequency but the well is online - 16 -03 (PTD #1810110) - AOGCC data notes the last test date as 04/15/2010 with a 4 year frequency but still shows a past due test date of 06/13/20! 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg @alaska.gov; tom. maunder @alaska.gov; bob. fleckenstein@ alaska. gov; doa .aogcc.prudhoe.bay @alaska.gov OPERATOR: BP Exploration (Alaska), Inc. • z' jv. FIELD / UNIT / PAD: Prudhoe Bay / PBU / B Pad DATE: 10/27/09 OPERATOR REP: Anna Dube AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well B -15 Type Inj. G " TVD - 7,635' Tubing 1,850 1,850 1,850 1,850 Interval 0 P.T.D. 1790190 Type test P ; Test psi - 1909 Casing 0 - 2,850 2,750 - 2,740 P/F P - Notes: MITIA to eval possible TxIA comm while on MI OA 0 0 0 0 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 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 T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU B -15 10 -27 -09 • • PBU B -15 PTD #1790190 3/22/2012 TIO Pressures Plot wet 545 4,067 9000 -- 1 1-1 181 _ xn 00 000 .- 0004 On 04/08/1' 09709/11 55+0911 07 /10,11 50/15/11 09/10111 10/11111 11/11/11 12/12/2 — - 01112 /12 02/12 /12 01/4,12 Injection Plot Wit 5 2,300 -21.LW 2200 2,100 -19000 2,000 -18000 1,900 -17505 1000 16,000 1,750 1500 -15000 1.500 - 19000 1,100 3000 -120005 —WHP F 1213 - 11A052�3 -Pw 5 /0 1,155 -10000 _aa 1, 050 - 9.000 On 900 B.OW 800 R .)000 700 - 6.000 500 100 300 200 2.000 100 'A) _ 01/09/11 65/00/11 061/9/11 07/10/11 0/110/11 03/10;11 - 10,1/1 11;0111 T 12 ,1211 '--' /1,12/12 02/12/12 034;112 TREE = 6" CMJ SAFTEB: H2S READINGS AVERAGE 125 ppm ACTUATO R = OTIS ,,. CTLAT = MCEVT 1 5 WHEN ON MI. WELL REQUIRES A SSSV WHEN ON KB. ELEV ____ - - 63.7' I. BF. ELEV = 37'18' ► ••:.4 ► • i KOP= 2900' 30" INSULATED - 110' ►•40,, N ►�i�i� - x A E I"" "'"5. " "" ► -•� . 209 HES X NIP, ID = 3 813" 1 Max A l 2 5° n 6300' CONDUCTOR A V '.• Datum MD = 9236' 9 -5/8 "CSG STUB 1878 �' ► �� j j' �• ' 1 2604' 95/8" DV PKR J Datum TV D = =Jo' SS (06/16!07) 4 Ai • 19 FOC H ? :% r 7930' H4 HES X NIP, ID = 3.813" 1 113 - 3/8" CSG, 72#, L - 80 BUTT, ID = 12.347" 1 2850' • 1T' CSG, 26# L - 80 IPC VAM TOP XO TO L BTGM 2818' . " 7960' -IT' X 4-1/2" BKR S- PERM PKR, ID = 3.875" • Minimum ID = 2.313" @ 8224' . ,$ • '', 7996' 4 -1/2" HES X NIP, ID= 3.813" I REDUCING NIPPLE * V • 7999' J- {9 -5/8" X 7" BKR ZXP LTP, ID = 6.290" i 9 8017' ' - - {9 -5/8" X 7" BKR LNR HGR, I0 = 6.310" 17 BKR PORTED TIEBK SEAL ASSY, ID = 6.23" I 8000' � I 8060' _I 4 MULESHOE, ID = 3.958" I .4.1/2" TBG, 12.6#, L - 80 TCII, .0152 bpf, ID = 3.958" I 8060' 7" CSG, 26# L-80 BTC -M, .0383 bpf, ID = 6.276" 8103' 8103' I GUIBERSON SEAL ASSY LOC SUB, ID = 3.954" 1 8128' -- 19 -5/8" X 7" GUIBERSON PBR, ID = 7 l■ 8151' -- I -5/8" GUIBERSON POLAR PKR, ID= 7 I 8193' -14-1/2" OTIS X NIP, 10 = 3.813" 1 [TOP OF 7 " LNR. --1 8213' 1—® I 8213' -- 19 -5/8" X 7" PKR w / 7" TIEBACK, ID = 7 1 8224' -14-1/2" OTIS XN NIP, ID = 3.725" 1 [4-1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3 958" 8256' 11 1 19 -5/8" CSG, 47#, L -80 BUTT, ID = 8 681" __1 8713' 1. 8256' --14 -1 /2" MULESHOE, ID = 3.958" PERFORATION SUMMARY y I 8249' ELMD LOGGED ON ??/?"?/?? REF LOG: SWS- BI-ICS- 5/29179 [ 9011' 1 i BAKER IBP (01/07/94) ANGLE AT TOP PERE 17° @ 9032' ' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/Sgz DATE 2 -7/8" 6 9032 - 9079 0 0824/07 P""6" +.� 9144' -[TOP OF CEMENT (TAGGED 08/15/07) 1 2 -7/8" 6 9083 - 8126 0 ► "/24/07 111111i 2-1/8" 6 9225 - 9240 S 08/13/07 11111111 2-18" 6 9250 - 9270 S 08/13/07 1!1 3-3/8" 4 9270 - 9280 S 08/13/07 1111111( 3-3/8" 4 9290 - 9300 S 08/13/07 1111111 ♦1H111 3-1/8" 4 9300 - 9330 S 08/13/07 1 1 1 1 1 1 1 1 1 1 1 1 1 ", 2 -1/6' 4 9320 - 9330 S 08/13/07 1 11 1 1 111 1 1 11" _ 2-1/8" 4 9340 - 9350 S 08/13/07 1 111111111 3 -18 N11N 1 " 4 9340 -9386 S 08/13/07 1 1111 11 t 3 -3/8" 4 9386 - 9400 S 08/13/07 1 1 1 1 1 1 1 1116 ' 9614' 1 -[FISH - FISHING NECK 11 ► .4 .. 1 41 I PBTD 9734' 1,1.1,1- 9681' H7" MARKER JOINT 1 7" LNR, 29 #, L -80 BUTT, .0371 bpf, ID = 6.184" - 9738' ► + . 44 . DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/03/79 ORIGINAL COMPLETION 05/08/08 MCZ /PJC DRLG DRAFT CORRECTIONS WELL B -15 06/26/07 D-16 RYVO 02/15/11 MB/JMD ADDED SSSV SAFETY NOTE PERMIT No: 1790190 08/19/07 NICZ /PJC P&A (08/13/07) 01/17/12 TMN/JNC) ADDED I SAFETY NOTE API No: 50 -029- 20360 -00 . 08/19/07 SIDIPJC DRLG DRAFT CORRECTIONS SEC 31, T1IN, R14E, 1606' FEL & 152(7 FNL 08/26/07 TEUSV PERFORATIONMS 03/18/08 7/ PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • • by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 11, 2009 Mr. Tom Maunder ,: Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 ~~ ~ ~~ Sub'ect: Corrosion Inhibitor Treatments of GPB Pad B ~ f ~ ~' Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad B that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date: 12/11/09 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor! sealant date ft bbls ft na al B-01 1700080 50029200590000 Sealed Conductor NA NA NA NA NA B-02 1961110 50029200660100 Sealed Conductor NA NA NA NA NA B-03A 1870480 50029203060100 NA 0.5 NA 3.40 8/20/2009 B-04 1700320 50029200720000 Sealed Conductor NA NA NA NA NA B-O58 2010680 50029202760200 NA 1.8 NA 13.60 8/22/2009 B-06 1770740 50029202790000 NA 1 NA 5.10 8/20/2009 B-07 1780020 50029202850000 NA 1 NA 5.10 8/20/2009 8-08 1780410 50029203140000 NA 1 NA 6.80 8/20/2009 B-09 1780490 50029203160000 NA 0.5 NA 3.40 8/20/2009 B-10A 2082050 50029203210100 Cellar liner welded to casin NA NA NA NA NA B-11 1780690 50029203310000 NA 0.5 NA 3.40 8/20/2009 B-12 1970090 50029203320100 NA 0.6 NA 3.40 8/22/2009 B-13 1990570 50029203410100 NA 0.4 NA 1.70 8/20/2009 B-14 2090590 50029203490000 NA 0.4 NA 1.70 8/20/2009 B-15 1790190 50029203600000 NA 0.1 NA 1.70 8/20/2009 B-16 1790250 50029203650000 NA 0.8 NA 5.10 8/21/2009 B-17 1790280 50029203680000 NA 0.1 NA 1.70 8/20/2009 B-18 1820020 50029207020000 NA 1.5 NA 15.30 8/21/2009 B-19 2001610 50029207030100 NA 0.1 NA 1.70 8/21/2009 B-20 1821680 50029208420000 NA 0.5 NA 3.40 8/21/2009 B-21 1821760 50029208500000 25 4.5 BBLS 0.1 11/30/2009 1.70 12/3/2009 B-22A 2001570 50029207590100 34 6.5 BBLs 0.2 11/30/2009 1.70 12/3/2009 B-23 1970590 50029207790100 12 2.2 BBLs 3.2 11/30/2009 10.20 12/4/2009 B-24 1821400 50029208150000 NA 3 NA 22.10 8/21/2009 B-25 1821510 50029208260000 NA 0.25 NA 1.70 8/13/2009 B-26 2000570 50029209760200 NA 0.3 NA 1.70 8/21/2009 B-27 1961010 50029214710100 Sealed Conductor NA NA NA NA NA B-28 1853030 50029215100000 NA 1.1 NA 6.80 8/22/2009 B-29 2002090 50029215230100 NA 0.7 NA 6.80 8/21/2009 B-30 2011050 50029215420100 NA 0.2 NA 1.70 8/21/2009 B-31 1910460 50029221520000 NA 0.3 NA 1.70 8!20/2009 B-32 1991180 50029221650100 NA 0.3 NA 1.70 8/20/2009 B-33 1931450 50029223390100 NA 1.2 NA 8.50 8/21/2009 B-34 1930370 50029223520000 NA 1.2 NA 10.20 8/21/2009 8-35 1931460 50029224060000 NA 0.3 NA 1.70 8/20/2009 B-36 1960650 50029226670000 NA 0.3 NA 1.70 8/21/2009 B-37 2071450 50029233750000 Sealed Conductor NA NA NA NA NA RE: UNDER EVALUATION: B~(PTD #1790190) WAG Injector on ~ith TxIA C... Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com~ Sent: Sunday, October 25, 2009 9:05 AM ~~~~ f~I~l ~( To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA) ~ Cc: NSU, ADW Well Integrity Engineer Subject: RE: UNDER EVALUATION: B-15 (PTD #1790190) WAG Injector on MI with TxIA Communication Hi Jim, Tom, and Guy, I forgot to mention that this well will be added to the Monthly injection Report. Thank you, Anna ~Dude, ~.~. ~alt Torin Roschinger) Well Integrity Coordinator GPB V4lells Group Phone: {907} 659-5102 P~ger: (907} 659-5100 x1154 ~`~,r;~~~~,r ~`?~~ ~~ .~ ~ ~~~~ From: NSU, ADW Well Integrity Engineer Sent: Saturday, October 24, 2009 6:50 PM To: jim.regg@alaska.gov; tom.maunder@alaska.gov; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>'; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven; GPB, GC3 OTL; GPB, Area Mgr Central (GCl/3/FS3); GPB, GC3 Wellpad Lead; GPB, Well Pad AB; Schmoyer, AI; Quy, Tiffany Cc: NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: B-15 (PTD #1790190) WAG Injector on MI with TxIA Communication All, i Well B-15 (PTD #1790190) is a WAG. in1~_e..c.tor currently on MI exhibiting signs of TxIA communication. The IA pressure was bled from 1450 psi to 4~ psi on 10/20/09. Due to the inclement weaf iF er conditions, the IA pressure was monitored again on 10/23/09 and had increased 770 psi. The well has been reclassified as Under ~ Evaluation. Please swa~the well to water injection as soon as safely possible. Then the AOGCC will be invited to witness a MITIA in preparation for applying for an Administrative Approval limiting the well to PWI only. The plan forward: 1. Operations: Swap the well to water injection 2. Fullbore: AOGCC MITIA to 2100 psi / 3. Well Integrity Coordinator: Apply for AA to limit well to PWI only A wellbore schematic and TIO plot have been included for reference. « File: B-15 TIO plot.doc» Please let us know if there are any questions. Thank you, Anna ~ude, ~.~. ~alt Torin Roschinger) 10/30/2009 RE: iJNDER EVALUATION: B~(PTD #1790190) WAG Injector on ~ith TxIA C... Page 2 of 2 V4te11 In#egrity Gaordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907) 659-5100 x1154 10/30/2009 PBU B-15 PTD 179-019 10/25/2009 TIO Pressures ~ u TREE = 6" CMJ WELLHEAD = ~ w ~ .~.,..~_,~..._. ACTUATOR= MGEVOY ~...~,.. w OTIS KB. EtEV - 63.7' BF. ELEV = 37.18' KOP _ 296d' Max Angie = 25° @ 6300' Datum MD =~ ~~9236' Datum TV D= 8800' SS ~ 30"INSULATED -{ ~~G CdNDUCTOR 9-5/8 " CSG STUB 1$7~ (~6116/Q7} 9-518" FOC --~ ? 13-3/8'° CSG, 72#, L-80 BUTf, ID = 12.347" 265~ 7" GSG, 26# ~-80 IF'C VAM TOP XO TO L-80 BTGM --~ ~If11t11U1'Tl LD = ~i.~'~ ~`+ ~ $~24` REDUCING NIPPLE 7-112" BKR PORTED TIEBK SEAL ASSY, ID = 6.23" ~ 4-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.95$" ~ 7" GSG, 26# L-80 BTGM, .0383 bpf, ID = 6.276" -~ 5AFET~ES: 8-15 2Q~~'~--~4-1l2" HES X NIP, ID = 3.$13" 2604' 9-5/8" DV PKR 7930~ -~4-1/2" HES X NIP, ID = 3.813" ~ 7g~~' 7" X A-1(2" BKR S- PERM PKR, iD = 3.875" 7996' 4-1/2" HES X NIP, ID = 3.813„ 7999~ -19-5/8" X 7" BKF{ ZXP LTP, ID = 6.290" $017° 9-5/$" X 7" BKR LNR HGR, ID = 6.310" $Q~iQ' 4-1/2" MU~ESHOE, ID = 3,958" 8103~ GUIBEf2SON SEAL ASSY LOC SUB, Id = 3.954" 8128~ 9-518" X 7" GUIBERS4N PBR, ID =? $'~ ~'J ° 9-5l8" GUIBERSON POLAR PKR, ID =? 8193~ ~-~4-112" OTIS X NIP, IQ = 3,813" TOP OF 7" LNR 8213~ I 8213~ -'~ 9-5/$" X 7" PKR w/7" TIEBACK, ID =? I L $224~ 4-1/2" OTIS XN NIP, iD = 3.725" 4-112" TBG, 12.6#, L-&0, .0152 bpf, ID = 3.958" 9-5/8" CSG, G7#, L-80 BUTI", ID = 8.6$1" PERFORATION SUMMARY REF LOG: SWS-BHCS-5/29179 ANGLE AT TOP PERF: 17° @ 9032' Note: Refer to Production DB for historical perf data SIZE SPF INTERVRL OpnlSqz DATE 2-7I8" 6 9032 - 9079 Q 08/24/07 2-7/8" 6 90$3 - 8126 O O8l24l07 2-1I8" 6 9225 - 9240 S 0&113107 2-1/8" 6 9250 - 9270 S 0&!13(07 3-318" 4 92~0 - 9280 S 08/13/07 3-318" 4 9290 - 9300 S 08/13/07 3-1l8'" 4 9300 - 9334 S 08/13/07 2-1(8" 4 9320 - 9330 S 08l13/Q7 2-118" 4 9340 - 9350 S O8/13/07 3-1(8" 4 9340 - 9386 S O8/13(07 3-3/8" 4 9386 - 9404 S 08/13/d7 PBTD 7" LNR, 29#, L-80 BUTf, .0371 bpf, ID = 6.184" 8256~ °-~ 4-1l2" MULESHOE, ID = 3.958„ $249' E~MD LOGGED ON ??t??;`?? 9011' BAKERIBP(01/07/94) +TOP OF CEMETIT (TAGGED 08/i 5/07) ( 9614' ~-~ FISH - FISHING NECK 9681' 7" MARKERJOINT DATE REV BY CQMMENTS dATE REV BY COMMENTS 06(03i79 ORtGINAL COMPLEfION 05/Q8/08 MCZ/PJC DR~G DRAFT'CORRECTIONS O6i26(07 D-16 RWO O8I19I07 MCZIPJC A&A (08i13i07) 08119(07 SIDtPJC D~2LG DRAFI" CORRECTIONS 2L 48/26/07 TEL/SV PERFORA710NMS 03118(08 ?/ PJC DRLG DRAFT CORRECTIONS PRUDHQE BAY UNIT WELL: 8-15 PERMIT No: 1790190 A PI No: 50-029-20360-00 SEC 31, T11 N, R14E, 1606' FEL & i 520' FNL BP Exploratia~ (Alaska) H-15 PIA PHRFS 8-14-07 Page 1 of 1 Maunder, Thomas E (DOA) From: Preble, Gary B (SAIC) (Gary.Preble@bp.com] Sent: Monday, September 10, 2007 2: 18 PM To: Maunder, Thomas E (DOA) Subject: 8-15 PIA PERFS 8-14-07 Attachments: wellevent_awgs.htm \~q-'()\C\ «wellevent_ awgs. htm» Here is the work summary for B-15 8/14/07 PIA perfs Thanks From: Maunder, Thomas E (DOA) Sent: Monday, September 10, 2007 9:58 AM To: 'Preble, Gary B (SAIC)' Subject: RE: PBU B-15 (179-019) Gary, I don't have a problem writing in the sundry number. But the 404 may need to be resubmitted due not having all the perfs listed as I mentioned below. I have looked at the 404 submitted for the workover and don't find that the perforations were squeezed. Was there additional work done between 6/27107 when Doyon 16 was released and 8/23/07 when the perforations were shot? Tom Maunder, PE AOGCC ---.---~------,-----~------- From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Monday, September 10,20078:29 AM To: Maunder, Thomas E (DOA) Subject: RE: PBU B-15 (179-019) t}~~NED S EP 1 1 2007 Tom, There was a 10-403 submitted (307-165) to plug perfs. The 10-404 I submitted should have referenced it. I can resubmit another 10-404 referencing that 403? " ..... .,...- . Gory Preble Petroleum Data Management Engineer SAIC 907-564-4944- preblegb@bp. com ----~-------- From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov) Sent: Friday, September 07,20072:51 PM To: Preble, Gary B (SAlC) Subject: PBU B-15 (179-019) Gary, I was looking at the 404 submitted regarding perforating on August 23. It does not appear that all the perfs are listed on the 404. I know the well was recently worked over, but I didn't think that the existing perforations were squeezed. Could you check on this. The 404 may need to be re-submitted. Thanks in advance. Tom Maunder, PE AOGCC 9/10/2007 RECE/V€,/) AUG 3 1 200 '",# imulate 0 Gal;! C O «.:..¡·;;Jw, 0 T' E t '0 8f J "nr., -"\" alver ¡me x enslon Anch . "'u"'mIS~J Re-enter Suspended Well 0 Grage 5. Permit to Drill Number: . STATE OF ALASKA . Al~A Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Ope rat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic 0' Exploratory Service P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: - 9. Well Name and Number: 63.7 KB, ~ ,..7-1/7 179-0190 w 6. API Number: 50-029-20360-00-00 PBU B-15 ADLO-028310 - 11. Present Well Condition Summary: 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Pool 8. Property Designation: Total Depth measured true vertical feet feet Plugs (measured) Junk (measured) 9738 ' 9346.5 Effective Depth measured 9626 feet true vertical 9238 feet Casing Length Size MD TVD Conductor 110' 20" x 30" Surface - 110' Surface - 110' Surface 2650' 13-3/8" 72# L-80 Surface 2650' Surface - 2650' Intermediate 8713' 9-5/8" 47# L-80 Surface 8713' Surface - 8362' Liner 1525' 7" 29# L-80 8213' 9738' 7879' - 9347' Tieback Liner 8112' 7" 26# N-80 Surface 8112' Surface - 7781' Perforation depth: 9083 - 9126 Measured depth: 9032 - 9079 True Vertical depth: 8668 - 8713 8717 - 8758 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 7" 26# x 4-1/2" 12.6# 7"x4-1/2" Baker Packer 9-5/8" Guib. Polar PKR o o L-80 L-80 Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 9626 9614 Burst Collapse 4930 2670 6870 4760 8160 7020 7240 5410 Surface - 8060' 8151' - 8256' 7970' 8151' o o Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 Tubing pressure o 1004 13. x 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Title Data Management Engineer Signature Phone 564-4944 Service p GINJ WINJ WDSPL Sundry Number or N/A if C.O. Exempt: ~ 3~(- \b~ J:R.."'M <;1 U) Date 8/30/2007 GIN A L RBDMS BFL SEP 10 20D7 Á~(" Submit Original Only ," .. . . B-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ***WELL SHUT IN ON ARRIVAL.*** PERFORATING WITH 2-7/8" HSD 2906 PJ HMX GUNS. PERFORATING INTERVAL = 9032' - 9079' AND 9083' - 9126'. INITIAL TI 110 = 01010 PSI. ***CONTINUED ON 24-AUG-2007*** 8/24/2007 ***CONTINUED FROM PREVIOUS DAY*** WELL SHUT IN ON ARRIVAL. INITIAL TI 1/ 0 = 01010 PSI. PERFORATING WITH 2-7/8" HSD 2906 PJ HMX GUNS. PERFORATING INTERVAL = 9032' - 9079' AND 9083' - 9126'. WELL SHUT IN ON DEPARTURE. FINAL TIIIO = 501010 PSI *** JOB COMPLETE*** FLUIDS PUMPED BBLS I 1 DIESEL 1 TOTAL . . Page 1 of2 WELL SERVICE REPORT WELL JOB SCOPE UNIT 8-15 INJECTION CONVERSION CTU #9 DATE DAILY WORK DAY SUPV 8/14/2007 PLUG & ABANOON PERFS ZIMMER COST CODE PLUS KEY PERSON NIGHT SUPV PBU4P2507 -0 OS-WOLO MONTGOMERY MINID I DEPTH TIL SIZE 2.313" 8224 FT 4.5" DAILY SUMMARY CTU # 9 w/1.75" CT, (P&A perfs for WAG Swap): Continued from 08/13/07 WSR. MU/RIH w/1.75" BON. Tag TO. Re-set to corrected SIL tag depth of 9589', Flag CT 10' off btm. Kill well with 250 1% KCI down backside followed by 112 bbls of diesel. Mix 34 bbls cement" Lay in 1 for 1. Build pressure to 500 psi, continue laying in Cement. Pull to safety and pressure cement to 2000 psi. In 30 minutes pressure bled to 1748 psi. Cleanout cement to 9140' CTM. TOOH while holding -800 psi. Freeze rotect the to 2500' ottubin ,shut in well with 600 si on well head. ROMO. -Job Com lete*** LOG ENTRIES Initn Q, lA, OA 52 0 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 0 Continued. 00:34 0 Fluid pack coil/lines. 00:38 0 2.3 PT low to 220 psi. PT hiah to 4000 psi. Good. Bleed down. 00:56 0 Call out Pad operator to help normal UP SSV. 01:14 0 52 45 3 Remove and throw away SSV shippina caP. 01:15 0 52 45 3 RIH w/ CT. No returns. 02:04 4270 174 9 0 3 \M ck = 9.5k# Continue RIH. 02:11 4692 184 7 0 3 Call from lab. Test came off @ 70 be fluid los5l3 hr 45 min set time. Too short. Will Put it back on w/ more retarder. 02:38 7430 257 0 0 3 \M ck - 15k#. Continue RIH. 02:55 8130 198 0 0 3 Lab: Puttina on 2 samples: 1 w/.01 0110,1 w/.02 0110. 03:10 9446 228 0 0 3 \M ck = 20k#. 03:18 9599 176 0 0 3 Tag 9599' down. Up@ 9597'. Re-tag. @ 9602', PU @ 9601'. Re- tag. Same @ 9602'. PU. Same up @ 9601'. PU 10'. \M off TO=21k#. 03:32 9591 0 0 5 Park 10' above TO. Re-set counter to 10' above corrected S/L tag on 8/12/07. Set counter to 9579' (-12' correction). Pump down coil to establish circulation. Nozzle not plugged. OK. Pull above perfs. 03:54 9121 132 0 0 5 Park CT. Wait on cement test. IA=O. OA=O psi. 04:51 9121 96 0 0 5 PT isolation valve in horse trailer. Tested good. 09:30 0 0 SLB Cement Supervisor called. He has test results. Crew will head this way shortly. 09:44 9113 4 5 start 5 bbl meth down bacskide 09:46 9113 235 0 4.9 5 Swap to 1 % KCI 09:49 9110 1026 0 3.4 19 reduce rate 09:55 9110 1356 930 4.5 33 increase rate 10:30 9107 1041 828 4.5 200 IAP= 1400 psi, OAP =0 psi 10:43 9104 521 447 1.7 250 Swap to diesel 10:50 9104 755 440 1.7 258 Cement crew on location, beain ria UP 11:54 9097 1060 0 0 374 shut down pump 12:16 9098 300 0 1 0 300 psi, diferential start pumina down CT 12:52 9343 1055 1172 1. 35 lAP = 200 psi, OAP =0 psi 13:06 9579 1173 1340 1 74 TUH 13:36 9439 814 8 0 79 Shut down CT 13:38 9398 1173 2035 1.3 84 Pump 5 bbls water ahead 13:43 9398 674 0 0 0 Pressure test Cement lines to 4500 psi. 13:44 9398 616 0 0 0 beain batchina cement 13:50 9398 960 2622 1.6 0 Start cement down CT, TIH 13:53 9426 1173 3380 1.5 5 start aareQate 13:59 9472 1070 2650 1 9 Cut aareaate 14:10 9579 1136 3325 1.3 24.7 Park at bottom 14:15 9579 1100 3384 1.3 31 Start takina returns file://C:\temp\ Temporary%20Intemet%20Files\OLKF\wellevent awgs.htm 9/10/2007 . . Page 2 of2 14:18 9579 1114 3340 1.4 35 cement @ nozzle 14:44 8749 1114 3340 1.4 69 Cement out, Nozzle 14:45 8707 1100 700 .7 69.5 PUH to safety 14:50 8391 1092 520 0 73 Park at safety 14:54 8391 1500 1100 0 73.2 Pressure up 15:09 8391 2000 1370 0 74.3 Pressure up 15:15 8391 1832 1260 0 74.3 IAP= 450 psi, OAP =0 psi 15:41 8391 1742 1172 0 74.3 Load ball 15:43 8391 889 257 0 0 Bleed well down to 500 psi over wellhead 15:45 8391 909 3280 1.7 2.3 start pumpina with Biozan, ball in CT, RIH 16:02 8672 850 3086 2 35 Biozan at nozzle, TIH @ 25 ftlmin 16:18 9069 865 3194 2 64 SWitch to XS KC 16:22 9140 865 3296 2 72.5 PUH jetting 16:29 8700 850 3978 2 97 RBIH 16:36 9140 843 3301 2 103 PUH 16:49 8670 788 2747 2 120 RBIH 16:56 9140 924 2908 2 142 TOOH 17:54 5004 950 2403 2 26010 swap to 50/50 meth for Freeze protect 18:54 0 630 615 0 95 At Surface 19:19 0 Ball recovered. Continue lavina down. 20:06 0 PT caP. 23:59 0 Rid down complete. Road to J pad. Final Tba, lA, OA 630 600 0 JOB COSTS SER~CECOMPANY-SER~CE DAILY COST CUMUL TOTAL EQUIPMENT FLEET 6 HOT WATER PLANT ORBIS =- PAD THREE - SCHLUMBERGER j VECO LABOR WAREHOUSE - TOTAL FIELD ESTIMATE: I FLUID SUMMARY 320 bbls 1 % KCL 200 bbls XS 1% KCL 5+ bbls fresh water 70 bbls 1.5# bio 34 bbls 15.8 Class G cement 84 # aggregate 120 bbls diesel 100+ 50/50 meth file://C:\temp\ Temporary%20Intemet%20Files\OLKF\wellevent awgs.htm 9/1 0/2007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor '''2 ~/; 1/5/67 I ,'{l( DATE: Wednesday, September 05, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC B-15 PRUDHOE BAY UNIT B-15 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv r-v.3æ.- Comm Well Name: PRUDHOE BAY UNIT B-15 API Well Number: 50-029-20360-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ070904201014 Permit Number: /79-019-0 Inspection Date: 9/3/2007 Rei Insp Num: Packer Depth / Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well B-15 Type Inj. w TVD 7645 </ IA 770 4000 3910 3900 11"·'1'· L '7V17V I TypeTest :,¡r! Test psi 1911.25 -/ OA 0 0 0 0 Interval INITAL PIF P ./ Tubing 740 750 770 770 Notes: 1.3 BBLS methanol pumped. I well house inspected; no exceptions noted SGANNED SEP 1 0 2007 NON-CONFIDENTIAL Wednesday, September 05,2007 Page I of I . ~ STATE OF ALASKA . .;z..;J6-ói1 r~ECEIVED ALASKA Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS JUL 2 5 2007 1. Operations Performed: \;,1:,)\<1 uti,)! iJè:5 lIUII,). o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-Enter~d Well 181 Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension Convert to WAG Injector 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. o Development o Exploratory 179-019./ 3. Address: 181 Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20360-00-00 /' 7. KB Elevation (ft): 63.7' ' 9. Well Name and Number: PBU B-15 r 8. Property Designation: 10. Field 1 Pool(s): ADL 028310 ( Prudhoe Bay Field 1 Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 9738 I feet true vertical 9347· feet Plugs (measured) 9626 Effective depth: measured 9626 feet Junk (measured) 9614 true vertical 9238 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2650' 13-3/8" 2650' 2650' 4930 2670 Intermediate 8713' 9-5/8" 8713' 8362' 6870 4760 Production Liner 1525' 7" 8213' - 9738' 7879' - 9347' 8160 7020 Tieback Liner 8112' 7" Surface - 8112' Surface - 7781' 7240 5410 ~~ANNED JUL 3 1 2007 Perforation Depth MD (ft): 9225' - 9400' Perforation Depth TVD (ft): 8853' - 9021' 4-1/2", 12.6# & L-80 Surface - 8060'; Tubing Size (size, grade, and measured depth): 7" ?n# x 4-1/?" 1? n# A1"1' _ A?"~' Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker Chrome 'S-3' perm packer; 7960'; 9-5/8" Guib. Polar packer 8151' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8FL JUL 3 0 2007 Treatment description including volumes used and final pressure: Cut and pull tubing from -8151'. Cut and pull 9-5/8" casing from 1878'. Run 7" Tieback (26#, L-80) , cement w/4 Stages of Class 'G' Cement: 45.4 Bbls (Yield 1.16), 223 Bbls (Yield 1.17), 78 Bbls (Yield 1.16), 58 Bbls (Yield 1.17). Run new Completion. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations o Exploratory o Development 181 Service 16. Well Status after proposed work: 181 Well Schematic Diagram o Oil o Gas 181 WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Paul Chan, 564-5254 306-366 Printed Name Terrie Hubble Title Technical Assistant Signature /(Ó MiP U~ O~/t?< /.... Prepared By Name/Number: Phone 564-4628 Date ,~{)7Terrie Hubble, 564-4628 ion Form 10-404 Revised 04/20060 RIG 1 N A L ~!d'~ A~ß? Submit Original Only . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 6/7/2007 09:00 - 10:00 1.00 MOB P PRE PJSM with all personnel involved. Move rig off of DS6-07. Move rig to center on pad. 10:00 - 12:00 2.00 MOB P PRE Remove BOP stack from pedestal and place in carrier. Unhook Top Drive and Bridal up. Prep rig floor and derrick to lay derrick over. 12:00 - 13:00 1.00 MOB P PRE Lay derrick over and secure. 13:00 - 13:30 0.50 MOB P PRE Install rear booster assembly. 13:30 - 20:30 7.00 MOB P PRE Move rig from DS6 down spine road to B-pad. 20:30 - 21 :00 0.50 MOB P PRE Remove rear booster assembly. Position rig to raise derrick into prevailing wind. 21 :00 - 00:00 3.00 MOB P PRE Wait on wind speed to lower before raising derrick. Winds gusting up to 50 mph. 6/8/2007 00:00 - 01 :30 1.50 MOB P PRE Wait on wind speed to lower before raising derrick. Winds gusting up to 50 mph. 01 :30 - 02:30 1.00 MOB P PRE Wind speeds dropped below 30 mph. Raise derrick and pin into position. 02:30 - 08:00 5.50 RIGU P DECOMP Move rig down location and spot and level rig over well B-151. Set slop tank, R/U circulating manifold and Rig Floor. Spot #2 Mud Pump and R/U Derrick. Install additional annulus valve. Accept rig at 0600-hrs. Take on 430-Bbls of 120-F 1% KCI. 08:00 - 10:00 2.00 WHSUR P DECOMP Continue to take on 1 % KCI water to pits. P/U DSM lubricator to pull BPV. Release BPV and see a wisp of pressure to the surface, but it didn't register on the gage. IA O-psi, OA O-psi. 10:00 - 11 :00 1.00 WHSUR P DECOMP Pressure test lines to tree from Mud Pumps to 3,500-psi. Hold Well Kill PJSM with 4 vac-truck drivers, MI Engineer, crew, Toolpusher and WSL. 11 :00 - 12:00 1.00 KILL P DECOMP Begin Well Kill by bull heading down the tubing. T/IAlOA pressures are all O-psi. Bring Pump #2 up to 10-BPM and 1,470-psi. SCR for #2 developed a problem when 38-Bbls pumped, SID pump #2 and switch over to pump #1. Took -9-Bbls to catch up to the fluid after 10-minute SID. Continue pumping with #1 at 10-BPM, pressure drops slowly from 1450-psi to 1250-psi and SID when 460-Bbls are pumped. Hook up bleed trailer to OA and bleed of OA from 1500-psi to O-psi in seconds. 12:00 - 12:45 0.75 KILL P DECOMP Realign circulating manifold valves to bullhead down IA. Start with pump #1, bringing pump up to 10-BPM and 2200-psi. Solve SCR problem with pump #2, decrease rate on #1 to 5-BPM and bring #2 rate up to 5-BPM. Continue pumping at 10-BPM and see pressure climb to 2475-psi after 60-Bbls pumped. 2500-psi at 100-Bbls. 2475-psi at 140-Bbls. 2300-psi at 180-Bbls. 2200-psi at 250-Bbls. 2230-psi at 350-Bbls. SID pumps at 1245-hrs to monitor flow for 20-minutes. 12:45 - 13:30 0.75 KILL P DECOMP Monitor well for 20-minutes. Both the tubing and IA are on a vacuum. Pump down tubing at 4-BPM and it takes 25-Bbls to catch up to fluid level. Calculated 1-hour loss of 75-BPH, with fluid level at 654' after 20-minutes shut-in. 13:30 - 14:00 0.50 WHSUR P DECOMP P/U TWC and Cameron Hand RIH and sets in Hanger with dry rod. Test from below with 20-Bbls of 1% KCI, but fluid is pumped away. Test from above to 3500-psi for 10 charted minutes--solid test. 14:00 - 15:00 1.00 WHSUR P DECOMP Bleed down lines and circulating manifold. N/D Tree and Adaptor Flange. Use continuous hole-fill of 40-BPH down IA Printed: 7/10/2007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 while N/D and when N/U BOPE. Continue N/D Tree and adaptor flange. Set outside cellar. Clean and prep TBG spool for BOPE. Check lock down screws and threads on TBG hanger as per Cameron Tec. Used 7" IJ-4S crossover to ensure thread integrity. 18:00 - 23:00 DECOMP N/U BOPE and extension to TBG Spool. Disassemble blind/shear rams and redress with with new inserts. Reinstall rams in bodies and N/U bodies. 23:00 - 00:00 1.00 DECOMP RlU BOPE testing equipment and fill BOPE stack and line. 6/9/2007 00:00 - 04:30 4.50 DECOMP Test BOPE, Choke Manifold, Floor Valves and Top Drive IBOP Valves to 250 psi low and 4,000 psi high. Annular was tested to 250 psi low and 3,500 psi high. Each test was held for 5 minutes. No Failures. AOGCC witness of BOPE test was waived by John Crisp. Test was witnessed by BP WSL and Doyon Toolpusher. Maintain 40-BPH constant hole-fill. 04:30 - 05:00 0.50 BOPSU P DECOMP RID BOP testing equipment and blow down lines. 05:00 - 06:00 1.00 BOPSU P DECOMP P/U and RlU DSM lubricator and tools. Pull TWC valve. UD lubricator. P/U landing joint, M/U to 7" IJ4S crossover, RIH and screw into hanger. 06:00 - 06:30 0.50 PULL P DECOMP P/U slowly on landing joint to 200K; S/O; P/U slowly on tubing and hanger breaks free at 225K. Continue to pull to 300K; S/O; pull to 315K; S/O; pull to 320K and let soak for 2-minutes. S/O; pull to 350K; S/O; pull to 375K and let soak for 2-minutes. S/O; pull to 400K, no joy. Call RWO Engineer to discuss options. 06:30 - 07:00 0.50 BOPSU P DECOMP B/O landing joint with XO and UD same. N/D drilling riser and air boots. 07:00 - 07:30 0.50 BOPSU P DECOMP N/U shooting flange. 07:30 - 14:00 6.50 PULL C DECOMP Wait on Schlumberger E-Line. Gather pressure control equipment and set up assemblies for two String Shot runs, a Tubing Punch run, and a 7" Chemical Cutter run. Will maintain constant hole-fill at 40-BPH during all phases of SWS RlU and runs. 14:00 - 15:00 1.00 PULL C DECOMP Spot Schlumberger van and hold PJSM. 15:00 - 19:30 4.50 PULL C DECOMP RlU Schlumberger Pressure Control Equipment: 10' Extension, Pump In Sub, WIL BOPE, Quick Test Sub, Lubricator, and Grease Injector Head. Attempt to pressure test lubricator. CIO "0" ring and injection hose to grease head port. Pressure test lubricator to 2000 psi. M/U Firing Head to E-Line. 19:30 - 21:00 1.50 PULL C DECOMP Hold PJSM with SWS E-Liners and rig crew to discuss arming back off string shot and safety precautions. RlU and arm SWS 3 strand back off firing head. 21:00-22:15 1.25 PULL C DECOMP RIH with SWS back off string shot. Correlate wireline depth with log data and verify depths. Locate TBG collar @ 8044' WLM and fire across TBG collar. Back off shot covered from 8038' to 8050' WLM. 22:15 - 23:15 1.00 PULL C DECOMP POOH with SWS fired back off string shot. UD spent back off string shot. 23: 15 - 00:00 0.75 PULL C DECOMP Hold PJSM with SWS E-Liners and rig crew to discuss arming string shot and safety precautions. RlU and arm SWS 2 strand string shot firing head. 6/10/2007 00:00 - 00:15 0.25 PULL C DECOMP Hold PJSM with SWS E-Liners and rig crew to discuss arming string shot and safety precautions. RlU and arm SWS 2 strand string shot firing head. Printed: 7/10/2007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 6/10/2007 00:15 - 01:30 1.25 PULL C DECOMP RIH with SWS 2 strand string shot. Correlate wireline depth with log data and verify depths. Locate 7" TBG collars at 3489' and 3529' WLM. Fire string shot from 3500' to 3512' WLM. 01 :30 - 02:45 1.25 PULL C DECOMP POOH with SWS fired string shot. UD spent string shot. 02:45 - 03:00 0.25 PULL C DECOMP Hold PJSM with SWS E-Liners and rig crew to discuss arming TBG punch and safety precautions. RlU and arm SWS TBG punch. 03:00 - 04:00 1.00 PULL C DECOMP RIH with SWS TBG punch. Correlate wireline depth with log data and verify depths. Locate first TBG collar (3489' WLM) above the projected cut off joint. Perforate 7" TBG from 3482' to 3484' WLM with 9 holes. 04:00 - 04:30 0.50 PULL C DECOMP POOH and UD SWS TBG punch. 04:30 - 08:00 3.50 PULL C DECOMP Hold PJSM with SWS E-Liners and rig crew to discuss arming chemical cutter and related safety precautions. Clear all personnel from Rig Floor. Leave Driller and one Floorhand to assist the SWS crew. Barricade and position rig crew at all entry points to the Rig Floor and Cellar. RlU and arm SWS chemical cutter. Bring cutter up through Mouse Hole and into the Lubricator. Install Lubricator to the E-line BOP stack. Tag Chem Cutter on top of Doyon 16 BOP Blinds to calibrate depth control. 08:00 - 09:30 1.50 PULL C DECOMP RIH with Chemical Cutter to 3570' to correlate depth with CCL tool. POH to 3418'; RIH to 3570'; POH to 3420'; RIH to 3570'; POH to 3497.1' placing Chemical Cutter at 3509'. Agree depth with WSL. Fired Chemical Cutter, but saw no "wire jump" or increase in surface current (amperage) to indicate that the cutter fired. Try 2-more times and no success. SWS Engr called SWS shop and decided to try firing again. Tried 4-more times with no success. Called SWS shop and decided to re-correlate to CCL to make sure depth control had not changed. Activated firing sequence 5-more times with no success. Called SWS manager, Bob Templeton, who suggested maximum amperage, leave it on and let the computer time-out the firing interval. Made 4-more attempts with no success. Tried firing sequence a total 16-times. 09:30 - 10:30 1.00 PULL C DECOMP POH with Chemical Cutter to change out Ignitor. Stop POH when chemical cutter is 300' below the Rig Floor. Hold PJSM with crew to cover all aspects of disarming an unexpired chemical cutter. 10:30 - 12:30 2.00 PULL C DECOMP SWS safe-out and N/D the chemical cutter and change-out the ignitor in the Firing Head. Test the Firing Head. Hold PJSM with crew, SWS personnel, Tool Pusher, and WSL for M/U Chemical Cutter and Firing Head. Clear Rig Floor and barricade access to Rig Floor, Mezzanine, and Cellar. Pull Chem Cutter into Lubricator and install same onto SWS BOPs. 12:00 - 13:30 1.50 PULL C DECOMP RIH with Chem Cutter to top of Doyon BOP Blinds to calibrate "zero" for depth control. Open Blinds and RIH to 3570'. POH to 3250' for correlation. RIH to 3570'; POH to 3497.1' to place Chem Cutter at 3509'. Activate firing sequence; the amperage "kick" peaked and the E-line jumped with a corresponding bump felt in the Doghouse. Hold in place for 5-minutes. 13:30 - 14:30 1.00 PULL C DECOMP POH to 300' below the Rig Floor. Hold PJSM with rig crew and SWS personnel to bring expired tools to surface and to RID Printed: 7/10/2007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 6/10/2007 13:30 - 14:30 1.00 PULL C DECOMP tools and SWS E-line equipment. 14:30 - 16:30 2.00 PULL C DECOMP RID SWS expired Chem Cutter assembly (completed @ 1515-hrs). RID Lubricator with Grease Injector; RID BOPs with 10' Extension. UD through Pipe Shed and Beaver Slide. N/D Shooting Flange. 16:30 - 17:00 0.50 PULL C DECOMP N/U Drilling Riser and Air Boots. 17:00 - 17:30 0.50 PULL P DECOMP P/U landing joint and M/U 7" IJ-4S x/o. RIH and M/U into TBG HGR. Pull HGR free at 125,000 Ibs up weight. Pulled HGR to rig floor. 17:30 - 18:00 0.50 PULL P DECOMP RlU circulating head and attempt to CBU at 7 BPM with 30 psi. Could not get returns. 18:00 - 19:00 1.00 PULL P DECOMP Break down and UD landing joint and HGR 19:00 - 00:00 5.00 PULL P DECOMP POOH and UD 7", 26#, L-80 TBG. TBG appears to be in good shape with no visible corrosion. Recovered 84 full joints and one cut off joint 20.01'. Chemical cut was perfect with very little bevel to the cut. Also recovered one SSSV, 23 clamps and 4 stainless steel bands. 6/11/2007 00:00 - 00:30 0.50 PULL P DECOMP RID floor and UD TBG handling equipment. Clear and clean rig floor. 00:30 - 01 :00 0.50 PULL P DECOMP P/U landing joint and set wear ring. P/U 5" drill pipe handling tools. RlU floor. 01 :00 - 02:30 1.50 PULL P DECOMP P/U BHA #1 (7" TBG Spear Assembly) consisting of 7" spear packoff, x/o, 7" ITCO spear and extension, stop ring and sub, x/o, bumper sub, oil jars, x/o, (9) drill collars, and X/O to 5" drill pipe. Total length of BHA #1- 316.42' 02:30 - 07:00 4.50 PULL P DECOMP P/U and RIH with 7" spear assembly on 5" drill pipe with 4-1/2" IF connections. 07:00 - 07:30 0.50 PULL P DECOMP Get parameters: Up wt 126K, Dn wt 121 K. Engage spear into stub @ 3,509' then P/U to set slips until jars go off at 170K. Cont P/U to 325K and see two slight jumps in the pipe. SIO to 110K to recock the jars, P/U to 250K and let the jars go off. Cont P/U to 350K, but no movement. SIO and see two slight "bumps while SIO to recock jars at 110K. P/U to 275K and let jars function and tubing breaks free, pulling at 25K over the estimated buoyed weight of the 5" DP and the 7" tubing to the planned backoff depth of 8,044'. Decide to keep pulling and the packer "resets" -20' higher. 07:30 - 09:30 2.00 PULL P DECOMP Jar on tubing for 8-more times up to 350K, but no more movement. Call town and decide to jar for at least 1/2-hour, then discuss course of action with BP Engineer. 09:30 - 11 :00 1.50 PULL P DECOMP RlU to circulate well. Bent one joint of 5" DP when M/U the 5" to the 4" HT-38 DP short joint and 4" HT-38 x 4-1/2" IF XO to start circulation. SIO to neutral and tum CCW one full turn. P/U, break off, and UD the bent joint. P/U a joint from the Pipe Shed and M/U to the string. Baker Fishing Tool expert called Baker to discuss options regarding pulling the packer versus backing off at the intended spot at -8,044'. Decide to perform the backoff. 11 :00 - 11 :30 0.50 PULL P DECOMP RIH and engage spear into stub, work it down, P/U to 300K to ensure spear is seated. Work reverse torque down into the backoff point by P/U to 225K, the estimated buoyed weight of the DP and 7" (+ Top Drive) down to the backoff point, turning a Printed: 7/10/2007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 6/11/2007 11 :00 - 11 :30 0.50 PULL P DECOMP full CCW revolution, then slowly SIO to 50K. Follow this same sequence four times and see that the torque required to rotate CCW reduces from -8,000-lb-ft to 4-5K-lb-ft. Follow the same P/U and SIO limits, but rotate two rotations CCW. Then increase the SIO wt to 130K to keep above the Jar re-cocking wt, and rotate two revolutions for two cycles. SIO to 130K and P/U to 225K and make 9-CCW revolutions. P/U to 255K and pipe starts up hole. Stop to prepare to circulate Bottoms Up. 11 :30 - 12:30 1.00 PULL P DECOMP Circulate down tubing at 5-BPM and catch up to fluid with 25-Bbls pumped. Fluid returns to surface at 50-Bbls pumped with a skim of crude oil. Keep pumping until 310-Bbls have been pumped, losing about 160-Bbls to the formation, but recovering about 150-Bbls in the slop tank with about 5% crude oil. 12:30 - 14:00 1.50 PULL P DECOMP POH and UD DP. Started with 255K on the weight indicator and experiencing some dragging. POH and UD 50-jts of 5" DP and decide to SID and wait for more 1% KCI; have only 100-Bbls in Pits. 14:00 - 16:00 2.00 PULL P DECOMP Wait on two truckloads of 10/0-KCI brine. Take on one truckload to Pits and prepare to circulate until returns are clean. 16:00 - 16:30 0.50 PULL P DECOMP Circulate 1 %-KCI brine. Start pumping 6-BPM, O-psi tubing. Increase to 8-BPM, and hit fluid with 40-Bbls pumped. Returns to surface after 74-Bbls pumped; contain oil spots, but very little volume. The oil sheen is light brown, with some lumpy, dead crude smudges. Stop pumping after 146-Bbls pumped; returns are slightly opaque. 16:30 - 18:00 1.50 PULL P DECOMP Blow down circulating line, breakoff 4" DP pup and XO to 5" DP and UD. POH and UD 5" DP. 18:00 - 00:00 6.00 PULL P DECOMP CIO handling equipment and UD 7" IJ4S tubing. Tubing was in good condition. On joint #87 found top Alpha tubing patch. Patch was across connection. Cut pipe with hand pipe cutter. There were 4 holes punched in joint #87. Second Alpha patch was found at joint #154. Patch was across connection. Cut pipe with hand cutter. There were 4 holes punched in joint #154. 6/12/2007 00:00 - 02:00 2.00 PULL P DECOMP UD 7" IJ4S tubing. Tubing was in good condition. Recovered 115 full joints of 7" tbg, 20.35' cut joint of 7" tbg for 200 total joints of 7" tbg recovered. Also recovered 13.51' long Seal Spacer nipple from inside the top of the seal assembly in PBR. The top of the PBR is set at - 8,108'. The Seal Spacer Nipple body OD = 3.8", Id = 3.3". Connection at the top max OD = 6.4" and is necked down to 5.2" OD. The collar at the bottom is 4.4" OD. Top of the Seal Assembly is - 12 ft inside the PBR. 02:00 - 03:00 1.00 PULL P DECOMP RID handling equipment and clear and clean rig floor. 03:00 - 04:30 1.50 PULL P DECOMP P/U Spear assembly and release from cut joint. Break down spear assembly. 04:30 - 06:30 2.00 CLEAN P CLEAN Gather equipment and P/U BHA #2.3.75" Clean Out assembly: 3-5/8" Junk Mill, 4-jts 2-7/8" PAC DCs, 2-ea 7" Boot Baskets, 9-5/8" Scraper, Bowen Bumper Jar and Oil Jar, Pump Out Sub, 9-ea 6-1/4" DCs. 06:30 - 08:30 2.00 DHB P DECOMP RIH BHA #2 on 6-joints of 4" HT-38 DP from Pipe Shed. P/U RTTS and Storm Valve and RIH on 3-joints of 4" DP from Pipe Shed and set. 08:30 - 09:30 1.00 DHB P DECOMP Pressure test RTTS packer to 1 ,500-psi for 1 O-minutes on Printed: 711012007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 6/12/2007 08:30 - 09:30 1.00 DHB P DECOMP chart. Tried 4-times, but test wouldn't hold. 09:30 - 13:30 4.00 DHB N DFAL DECOMP P/U one stand of DP from Derrick, RIH and engage RTTS, POH one joint and reset RTTS. Repeat testing of RTTS. Would not test. POH and inspect RTTS and Storm Valve and find no apparent damage. RIH with a pup joint to reposition away from previous setting spots and re-test to 1 ,500 psi from above for 10 minutes. Good test 13:30 - 15:00 1.50 DHB P DECOMP Unsting from RTTS and POH with one stand of 4" HT-38. P/U Test Plug, RIH and install in the Tubing Hanger. Test to 4,000 psi for 10 minutes. Good test. 15:00 - 16:30 1.50 BOPSU P DECOMP Remove 4 1/2"x 7" VBR's and install 3 1/2"x 6" VBR's in lower rams. Test to 250 psi low and 4,000 psi high. Good test. 16:30 - 17:00 0.50 DHB P DECOMP RID BOP test equipment, pull test plug and install wear bushing. 17:00 - 18:00 1.00 DHB P DECOMP Latch into HES RTTS and release, UD RTTS. 18:00 - 00:00 6.00 CLEAN P DECOMP RIH with BHA #2 picking up 4" HT38 DP to 6,538' 6/13/2007 00:00 - 01 :00 1.00 CLEAN P DECOMP RIH with BHA #2 picking up 4" HT38 DP from 6,538' to 8,090' 01 :00 - 01 :30 0.50 CLEAN P DECOMP Establish parameters, Up Weight 190,000#, Down Weight 150,000#. Tag top of PBR at 8,102'. Tag top of seal assembly at 8,115'. Tagged reducer plug at 8,197'. 01 :30 - 02:00 0.50 CLEAN P DECOMP Circulate pipe volume at 5.5 bpm with 1,120 psi pump pressure. Work 9 5/8" casing scraper 4 times from 7,985' to 8,065' 02:00 - 05:00 3.00 CLEAN P DECOMP POOH with BHA #2, standing back 4" HT-38 DP. Pumping 50 bph 8.5 ppg seawater pipe displacement. 05:00 - 06:00 1.00 CLEAN P DECOMP Stand back drill collars and UD clean out assembly. 06:00 - 06:30 0.50 CLEAN P DECOMP M/U BHA #3, 4-1/2" GS Spear Assembly. Total Assembly Length = 441 ' 06:30 - 09:30 3.00 CLEAN P DECOMP RIH wI BHA #3 0 n 4" DP from Derrick to 8100 ft 09:30 - 10:30 1.00 CLEAN P DECOMP Obtain 'nital Parameters. Up Wt =190,000 Ibs Dw Wt = 150,0001bs Pump Rate = 4 bpm at 1620 psi. Wash Down and Tag Up on XN Nipple at 8197' and Pick Up off of it 2 times. Third time wash down to Nipple and Shut Down Pumps. P/U off of Nipple and see 10,000 Ibs over pull initally off bottom. 10:30 - 12:30 2.00 CLEAN P DECOMP POOH and Rack Back 4" DP in Derrick. 12:30 - 14:00 1.50 CLEAN P DECOMP Rack Back 6-1/4" DC's. UD Scraper, Boot Baskets, and 2-7/8" DC's, 4-1/2" GS Spear and 4-1/2" XN Reducer Nipple. 14:00 - 14:30 0.50 CLEAN P DECOMP Clean and Clear Rig Floor of all subs and BHA parts. 14:30 - 15:00 0.50 CLEAN P DECOMP P/U HES 9-5/8" RBP BHA = RBP, Spring Adapter, Overshot, H90 by IF XO, 6-1/4" DC's, and HT38 x H90 XO. Total Length = 298.41'. Legth of BHA to Center of Element = 294.94' 15:00 - 18:30 3.50 CLEAN P DECOMP RIH wI RBP to 8,050' 18:30 - 19:00 0.50 DHB P DECOMP Establish parameters Up weight 190,000#, Down weight 145,000#. Set HES 95/8" RBP at 8,050' 19:00 - 20:30 1.50 DHB P DECOMP RlU test equipment and test 9 5/8" casing to 4,000 psi for 30 minutes on chart. Good test. 20:30 - 23:30 3.00 CLEAN P DECOMP POOH standing back 4" HT-38 DP. UD HES RBP running tool. 23:30 - 00:00 0.50 CLEAN P DECOMP Clear and clean rig floor. 6/14/2007 00:00 - 02:30 2.50 EV AL N WAIT DECOMP Wait on Schlumberger E-line unit and tools. 02:30 - 04:00 1.50 EVAL P DECOMP Spot and RlU SWS wireline unit. Calibrate Tools. 04:00 - 05:00 1.00 EVAL P DECOMP RIH with US IT logging tool on e-line. 05:00 - 07:30 2.50 EV AL P DECOMP Log Up with US IT in cement and corrosion mode from 8025' to surface at 3500 fph. Printed: 7/10/2007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 6/14/2007 07:30 - 08:00 0.50 EVAL P DECOMP RIH to 2800 ft to relog. 08:00 - 09:00 1.00 EVAL P DECOMP Log Up in Hi Res Mode from 2800 -1500 ft at 1400 fph. 09:00 - 10:00 1.00 EVAL P DECOMP Rig Down E-Line 10:00 - 10:30 0.50 CLEAN P DECOMP P/U and M/U HES 9-5/8" 47# RBP. 10:30 - 13:00 2.50 CLEAN P DECOMP RIH wI RBP to 3375' on 4" DP from Derrick. 13:00 - 13:30 0.50 CLEAN P DECOMP Set HES 9-5/8" 47# RBP at 3375'. PUH 1 Stand and Pressure Test to 2000 psi for 15 minutes - charted. Good Test. 13:30 - 15:30 2.00 CLEAN P DECOMP Dump 2200# of 20-40 River Sand on top of RBP. 15:30 - 16:30 1.00 CLEAN P DECOMP PJSM, Slip and Cut 114' of 1-1/4" of Drilling Line. Wait on last load of 9.8ppg brine. 16:30 - 17:30 1.00 CLEAN P DECOMP PJSM, Displace Well to 9.8ppg brine. Pump 20 bbl High Visc Sweep and Chase with 9.8 Brine at 10 bpm at 750 psi. 17:30 - 18:30 1.00 CLEAN DECOMP POOH standing back 4" HT-38 DP. UD RBP running tool. 18:30 - 19:00 0.50 CLEAN DECOMP Clear and clean rig floor. 19:00 - 21 :00 2.00 BOPSU DECOMP Pull wear bushing. Wear bushing hanging up in BOP stack. A 3"W x 7-8" Lx 1/4"t piece of rubber was wedged between stack and wear bushing. Was able to work rubber into lower ram cavity and get wear bushing by. Opened lower rams to retrieve rubber. Rubber was not in cavity. 21 :00 - 22:00 1.00 BOPSU DECOMP RlU BOP test assemblies. 22:00 - 22:30 0.50 BOPSU DECOMP Test plug was leaking, RILDS. 22:30 - 00:00 1.50 BOPSU DECOMP Test BOPE to 250 psi low and 4,000 psi high. AOGCC witness of test was waived by Chuck Scheve. Unable to get tests to hold. Trouble shoot leaks. 6/15/2007 00:00 - 02:00 2.00 BOPSU P DECOMP Test Upper IBOP, Lower IBOP, Floor Valves, Pipe Rams with 4" and 4 1/2" Test Joints to 250 psi low and 4,000 psi high pressure. Each test was held for 5 minutes. Koomey Test - 17 sec to build 200 psi and 1 min 16 see to build to 2900 psi. Average bottle pressure for 5 bottles = 2200 psi. AOGCC witness of test was waived by Chuck Scheve. Test was witnessed by BP WSL and Doyon Tourpusher. 02:00 - 07:30 5.50 N RREP DECOMP Change out spacer spool on choke manifold. Ring groove was washed out. 07:30 - 08:30 P DECOMP Continue wI Testing BOP's. Manual Kill, Annular, Choke Valves #12,13,& 14. Choke Valves #9 and #11 . 08:30 - 14:00 5.50 BOPSU N RREP DECOMP Unable to get good test on either HCR Valve. Replace both HCR Valves. Found Choke HCR 2/3 full of Cement. 14:00 - 17:00 3.00 BOPSU P DECOMP Continue Testing BOP's. Kill HCR, Blinds, Choke Valves 5,8,& 10. Choke Valves 4,6,& 7. Choke Valve #2, and #3. Choke Valve #1. Choke HCR and Choke Manual. 17:00 - 18:30 P DECOMP RID BOP test equipment. Pull test plug and install wear bushing. 18:30 - 19:00 0.50 CLEAN P DECOMP M/U BHA #4, 8 1/4" Multi string cutter, XO, 8 1/2" stablizer, Pump out sub, XO. Total BHA lenght = 15.57' 19:00 - 20:30 1.50 CLEAN P DECOMP RIH wI casing cutter on 4" HT-38 DP to 2,504'. 20:30 - 21 :00 0.50 CLEAN P DECOMP Establish parameters, Up weight 74,000#, Down Weight 74,000#, Rotating weight 74,000#. 10 rpm and 2,000 ftIlbs rotary torque. 3 bpm with 450 psi pump pressure. Locate 9 5/8" casing collars at 2,531' and 2,571'. 21 :00 - 21 :30 0.50 CLEAN P DECOMP Position cutter knives at 2,584'. Cut casing at 80 rpm with 3,000 - 5,000 ftIlbs of rotary torque, 5 bpm with 820 psi. Good indication when casing parted. 21 :30 - 00:00 2.50 CLEAN P DECOMP Break circulation, 1 bpm and 1,900 psi. Pump 20 bbls of Printed: 7/1012007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 6/15/2007 21 :30 - 00:00 2.50 CLEAN P DECOMP heated 9.8 ppg brine. Pump 100 bbls of heated diesel with LRS. 2.5 bpm with pressure dropping from 1600 psi to 750 psi. Chase with 28 bbls of heated 9.8 ppg Brine 6 bpm at 1920 psi. Initial arctic pack returns of 70 -80 bbls extremely thick arctic pack followed by water cut returns. Let diesel soak. All returns were taken into an open top tank. 6/16/2007 00:00 - 06:00 6.00 CLEAN P DECOMP Pump 100 bbls of 9.8 ppg brine 5 bpm at 1,960 psi, Soak for 30 minutes, Pump 100 bbls of heated diesel with LRS, 5 bpm at 1,900 psi followed by 28 bbls of 9.8 ppg brine. Let soak for 30 minutes. Pump 20 bbl high Vis sweep and chase with 150 bbls of 9.8 ppg brine 6 bpm at 1,980 psi. Pump 100 bbls of heated diesel with LRS 5 bpm at 1,900 psi, followed by 28 bbls of 9.8 ppg brine. Let soak for 30 minutes. Pump 180 bbls of heated 9.8 ppg brine at 5 bpm with 1,960 psi. Clear returns on last circulation. All returns were taken into an open top tank. 06:00 - 07:00 1.00 CLEAN P DECOMP POOH with 4" DP and Stand Back in Derrick. 07:00 - 07:30 0.50 CLEAN P DECOMP UD Cutter BHA. 07:30 - 08:00 0.50 CLEAN P DECOMP Pull Wear Ring and Clear and Clean Rig FLoor. 08:00 - 10:00 2.00 CLEAN P DECOMP Nipple Down Flow Riser and BOP's. 10:00 - 11 :00 1.00 CLEAN P DECOMP N/D Tubing Spool. Clean Pastic Packing off Slips and Check I Function all LDS. Install handles on slips. 11 :00 - 12:30 1 .50 CLEAN P DECOMP N/U BOP's and FLow Riser. 12:30 - 13:30 1.00 CLEAN P DECOMP Fill Stack and Pressure Test Break between Casing Spool and BOP's to 1500 psi for 10 mins. Good Test. 13:30 - 14:00 0.50 CLEAN P DECOMP M/U 9-5/8" Casing Spear. RIH and Engage 9-5/8" Casing. 14:00 - 15:00 1.00 CLEAN P DECOMP Attempt to Pull Casing to Surface. Unable to move casing more than a few inches. Place up to 150,000 Ibs over on casing. Estimated String wt = 150,000 Ibs with blocks. Stretch calc's determine casing stuck around 1100' -1200'. Discuss Options with Town. 15:00 - 16:00 1.00 CLEAN P DECOMP RILDS, UD spear assembly. 16:00 - 16:30 0.50 CLEAN P DECOMP M/U cutter assembly. 8 1/4" Multi string cutter, XO, 8 1/2" stablizer, Pump out sub, XO. Total BHA lenght = 15.57' 16:30 - 17:00 0.50 CLEAN P DECOMP RIH with cutter assembly. 17:00 - 18:00 1.00 CLEAN P DECOMP M/U Top Drive, locate casing collars and space out cutters to cut 9 5/8" casing at 1,069'. Make cut with 60 rpm and 3,000- 5,000 ftIlbs of rotary torque, 5 bpm with 750 psi pump pressure. 18:00 - 18:30 0.50 CLEAN P DECOMP POOH, standing back 4" HT-38 DP. 18:30 - 19:00 0.50 CLEAN P DECOMP UD Cutter assembly. P/U 95/8" Spear assembly 19:00 - 20:00 1.00 CLEAN P DECOMP Engage spear in 9 5/8" casing, Back out lock down screws. Pull 9 5/8" casing to rig floor. Came free with 105,000# pull, Up weight 90,000#. Remove Cameron slips. 20:00 - 21 :00 1.00 CLEAN P DECOMP Circulate arctic pack out of 9 5/8" x 13 3/8" annulus, 8 bpm with 130 psi. Reciprocate pipe while circulating. 21 :00 - 22:00 1.00 CLEAN P DECOMP UD spear assembly and 30.35' cut joint of 9 5/8" casing. 22:00 - 00:00 2.00 CLEAN P DECOMP UD 9 5/8" BTC casing. Break out torque 40,000 - 50,000 ftIlbs. Casing is in good condition. 6/17/2007 00:00 - 02:00 2.00 CLEAN P DECOMP UD 9 5/8" BTC casing. Recovered 26 joints. 30.35' upper cut joint and 10.72' cut joint. Casing was in good condition. 02:00 - 03:00 1.00 CLEAN P DECOMP Clear and clean rig floor, RID casing equipment. 03:00 - 03:30 0.50 CLEAN P DECOMP P/U BHA #6, Bull Nose, 95/8" Pack-Off, Itco Spear, Stop Ring, Bumper Jar, Oil Jar, Pump Out Sub, XO, (9) 6 1/4" DC's, XO, Intensifier, XO. Total BHA Lenght = 331.13' Printed: 7/1012007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 6/17/2007 03:00 - 03:30 0.50 CLEAN P DECOMP 03:30 - 04:00 0.50 CLEAN P DECOMP RIH with BHA #6 on 4" HT-38 DP to 1,060' 04:00 - 05:00 1.00 CLEAN P DECOMP Establish parameters, Up weight 70,000#, Down weight 70,000#. Engage casing stub at 1,069'. Jar casing, working up to 275,000#. No movement in string. Release spear from casing stub. 05:00 - 05:30 0.50 CLEAN P DECOMP POOH standing back 4" HT-38 DP. 05:30 - 06:30 1.00 CLEAN P DECOMP Stand back DC's, UD Spear assembly. 06:30 - 07:00 0.50 CLEAN P DECOMP Clean and Clear Rig FLoor. 07:00 - 07:30 0.50 CLEAN P DECOMP M/U 9-5/8" Inside Cutter Assembly. 07:30 - 09:00 1.50 CLEAN P DECOMP RIH to 2504'. 09:00 - 10:00 1.00 CLEAN P DECOMP Locate Collars at 2531', 2571' and Last Cut at 2584'. PUH and Make New Cut at 2544'. All Indications of good cut. 10:00 - 10:30 0.50 CLEAN P DECOMP POOH to 1832' 10:30 - 12:00 1 .50 CLEAN P DECOMP Locate Casing Collars at 1834' and 1873' and Make new cut at 1878 ft. All indications of good cut. 12:00 - 12:30 0.50 CLEAN P DECOMP POOH standing back HT-38 DP. 12:30 - 13:00 0.50 CLEAN P DECOMP UD Multi-String casing cutter. 13:00 - 14:00 1.00 CLEAN P DECOMP P/U Spear Assembly. Bull Nose, 9 5/8" Pack-Off, Itco Spear, Stop Ring, Bumper Jar, Oil Jar, Pump Out Sub, XO, (9) 6 1/4" DC's, XO, Intensifier, XO. Total BHA Lenght = 331.13' 14:00 - 14:30 0.50 CLEAN P DECOMP RIH to 1,000' 14:30 - 15:00 0.50 CLEAN P DECOMP Establish parameters, Up weight 71,000#, Down weight 71,000#.5 bpm with 120 psi. Engage casing stub at 1,069'. Pull free at 175,000#. 15:00 - 15:30 0.50 CLEAN P DECOMP Circulate at 8 bpm with 490 psi. Arctic Pack and gas returns to surface. Monitor well. 15:30 - 16:30 1.00 CLEAN P DECOMP Pump out of the hole wI one stand of DP. 6 bpm with 960 psi. 16:30 - 17:30 1.00 CLEAN P DECOMP Circulate 20 bbl high vis sweep around, 8 bpm with 1,080 psi. 17:30 - 18:00 0.50 CLEAN P DECOMP Pump Out of the Hole wI DP and Stand Back. 18:00 - 20:00 2.00 CLEAN P DECOMP Stand back DC's and UD spear assembly. 20:00 - 20:30 0.50 CLEAN P DECOMP RlU casing handling equipment. 20:30 - 23:30 3.00 CLEAN P DECOMP UD 9 5/8" BTC casing. Connections took 40,000-50,000 ft/lbs to break out. Pipe was in good condition. Recovered 28.50' cut joint, 20 joints casing, and 4.87' cut joint. 23:30 - 00:00 0.50 CLEAN P DECOMP Clear and clean rig floor. 6/18/2007 00:00 - 00:30 0.50 CLEAN P DECOMP Clear and clean rig floor. 00:30 - 01 :30 1.00 CLEAN P DECOMP P/U Spear Assembly. Bull Nose, 95/8" Pack-Off, Itco Spear, Stop Ring, Bumper Jar, Oil Jar, Pump Out Sub, XO, (9) 6 1/4" DC's, XO, Intensifier, XO. Total BHA Lenght = 331.13' 01 :30 - 02:00 0.50 CLEAN P DECOMP RIH to 1,862'. Up weight 82,000#, Down weight 82,000#, 4 bpm 110 psi. 02:00 - 03:30 1.50 CLEAN P DECOMP Circulate out Arctic Pack, 6 bpm with 240 psi. 03:30 - 06:00 2.50 CLEAN P DECOMP Engage casing stub at 1,878'. Work casing trying to jar free. Work up to 275,000# 06:00 - 07:00 1.00 CLEAN P DECOMP Circulate at 6 bpm with 420 psi. 07:00 - 08:30 1.50 CLEAN P DECOMP Service rig. Monitor well. 08:30 - 10:00 1.50 CLEAN P DECOMP Work pipe and obtain pipe stretch data. 6" at 20,000#. Inspect Top Drive and Derrick. 10:00 - 10:30 0.50 CLEAN P DECOMP POOH standing back 4" HT-38 DP 10:30 - 11 :30 1.00 CLEAN P DECOMP Stand back DC's, UD Spear assembly. 11 :30 - 12:00 0.50 CLEAN P DECOMP Clear and clean rig floor. 12:00 - 13:30 1.50 CLEAN P DECOMP Replace pack-off assembly and 8.681" Grapple on Spear Printed: 7/10/2007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 6/18/2007 12:00 - 13:30 1 .50 CLEAN P DECOMP assembly, 13:30 - 14:00 0.50 CLEAN P DECOMP RIH with 4" HT-38 DP to 1,799' 14:00 - 14:30 0.50 CLEAN P DECOMP Establish parameters, up weight 81,000#, down weight 81,000#.5 bpm at 160 psi. Engage casing at 1,878' 14:30 - 15:00 0.50 CLEAN P DECOMP Work pipe trying to pull casing free, Jar with 200,000#. Maximum pull 350,000# 15:00 - 15:30 0.50 CLEAN P DECOMP Circulate around at 9.5 bpm with 1,090 psi. 15:30 - 16:00 0.50 CLEAN P DECOMP Reverse circulate at 8 bpm with 1,680 psi. 16:00 - 17:00 1.00 CLEAN P DECOMP Release spear from casing. POOH, standing back 4" HT-38 DP. 17:00 - 18:30 1.50 CLEAN P DECOMP Stand back DC's, UD Spear assembly. 18:30 - 19:00 0.50 CLEAN P DECOMP Clear and clean rig floor. 19:00 - 21:00 2.00 CLEAN P DECOMP M/U Clean out BHA. 8 1/2" Bit, Bit Sub, Bumper Jar, Oil Jar, Pump Out Sub, XO, (9) 6 1/4" DC's, XO, (37)4"DP, XO, XO, Csg Scraper, XO, XO. Total BHA lenght = 1501.85' 21 :00 - 23:00 2.00 CLEAN P DECOMP RIH with 4" HT-38 DP. Tag at 3,295'. 23:00 - 00:00 1.00 CLEAN P DECOMP Establish parameters, up weight 100,000#, down weight 100,000#. Circulate out arctic pack. 8.5 bpm with 720 psi. 6/19/2007 00:00 - 00:30 0.50 CLEAN P DECOMP Clean out to 3,355' inside 9-5/8" Casing wI Bit, Casing Scraper at 1864'. 00:30 - 01 :30 1.00 CLEAN P DECOMP Circulate 20 bbl hi vis sweep around at 11 bpm with 1,300 psi. 01 :30 - 02:30 1.00 CLEAN P DECOMP POOH standing back 4" HT-38 DP. 02:30 - 03:30 1.00 CLEAN P DECOMP Stand back DC's and UD Clean out assembly. 03:30 - 04:00 0.50 CLEAN P DECOMP Clear and clean rig floor. 04:00 - 05:00 1.00 CLEAN P DECOMP M/U 7 7/8" RCJB BHA wI 8-1/2" OD Head, 2-7" Boot Baskets, Bumper Jar, Oil Jars, Pump Out Sub, 9 - 6-1/2" DC's, Total Length = 324.63' 05:00 - 06:30 1.50 CLEAN P DECOMP RIH RCJB on 4" DP. 06:30 - 09:00 2.50 CLEAN P DECOMP Tag sand at 3355' with reverse basket. Continue to wash down to 3368' at 60 rpm's and pumping at 5 bpm wth 1500-2000 psi. 2-5k WOB. Encountered some harder material at - 3360'-3365'. Could not really get past 3368' with Reverse Basket, seemed like basket full. 09:00 - 10:00 1.00 CLEAN P DECOMP Pump 20 bbls High Visc Sweep and Chase Out of Hole with 375 bbls of Seawater. Displace Well to 8.5 Seawater at 10 bpm and 960 psi. 10:00 - 12:00 2.00 CLEAN P DECOMP POOH wI 4" DP. 12:00 - 13:00 1.00 CLEAN P DECOMP B/O RCJB and Boot Baskets. RCJB just about full, contained cement in gravel to fist size pieces. Also one large piece of heavy thick black rubber was lodged in the mouth of the RCJB. Boot Baskets contained - 1 gallon each of Sand and Cement. 13:00 - 14:00 1.00 CLEAN P DECOMP M/U RCJB and Boot Baskets - Same BHA 14:00 - 15:30 1.50 CLEAN P DECOMP RIH with RCJB to 3360' on 4" DP 15:30 - 17:00 1.50 CLEAN P DECOMP Tag sand at 3365' and easily wash to 3371' wI no rotation. Circulate 20 bbl high visc sweep and chase out of the hole 7 bbl I min and 2000 psi. 17:00 - 18:00 1.00 CLEAN P DECOMP POOH 18:00 - 19:30 1.50 CLEAN P DECOMP B/O and UD RCJB BHA, Small amount of Cement in junk baskets. 19:30 - 20:00 0.50 CLEAN P DECOMP Clear and Clean Rig Floor. 20:00 - 21 :00 1.00 CLEAN P DECOMP Install test plug, RlU and test casing spool connection to 250 low test and 4,000 psi high test. RID test equipment. Install wear ring. Printed: 7/10/2007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 6/19/2007 21 :00 - 23:00 2.00 CLEAN P DECOMP M/U RBP retrieving tool, RIH to 3,353'. 23:00 - 00:00 1.00 CLEAN P DECOMP M/U Top Drive and RIH and latch and release RBP at 3,370'. 6/20/2007 00:00 - 01 :30 1.50 CLEAN P DECOMP POOH w/RBP f/3,370' to surface, UD RBP #1. 01 :30 - 05:00 3.50 CLEAN P DECOMP RIH wI RBP retrieval tool to 8,050', picking up 9 jts of 4" drill pipe from pipe shed. 05:00 - 06:00 1.00 CLEAN P DECOMP Latch and release RBP #2 at 8,050'. Establish loss rate of 54 bph. 06:00 - 10:00 4.00 CLEAN P DECOMP POOH w/RBP fl8,050', UD RBP and running tool. 10:00 - 11 :00 1.00 CLEAN P DECOMP RIH w/3 stand 6.25" drill collars and UD same. 11 :00 - 12:00 1.00 CLEAN P DECOMP Clear and Clean rig floor, load 9-4.75" drill collars in pipe shed and strap same. 12:00 - 13:00 1.00 CLEAN P DECOMP P/U M/U and rack back 9-4.75" drill collars, drifted to 2". 13:00 - 14:00 1.00 CLEAN P DECOMP Slip and cut 66' of drilling line. 14:00 - 19:30 5.50 CLEAN N DECOMP Waiting on Baker ZXP Packer assembly, perform rig inspections and light maintenance. 19:30 - 21 :00 1.50 CASE P DECOMP P/U and M/U 5.5"x 7" XO mule shoe assembly, Insert ball seat landing collar and Baker ZXP packer wI flex lock hanger. 21 :00 - 00:00 3.00 CASE P DECOMP RIH with packer assembly on 9-4.75" drill collars and 4" drill pipe to 3,851 '. 6/21/2007 00:00 - 01 :30 1.50 CASE P DECOMP Continue to RIH w/ZXP packer assembly, f/3,351, to 8,050' up weight=182,000#, down weight=140,000#. 01 :30 - 03:00 1.50 CASE P DECOMP Continue to RIH tagged and worked through PBR at 8,102' work mule shoe and tagged up at 8,113'. Pick up and space out l' to 8,112'. Dropped setting ball and pumped down at 2 bpm. Set packer with 2,500 psi, set 50,000# to confirm set, continue to pressure up to 4,000 psi, bleed off pressure and release from hanger. 03:00 - 04:00 1.00 CASE P DECOMP RlU to pressure test packer, tested to 2,000 psi for 30 charted minutes, RID test equipment. 04:00 - 08:00 4.00 CASE DECOMP POOH wI 4" DP and UD hydraulic running tool. 08:00 - 09:00 1.00 BOPSU DECOMP Pull Wear Ring and Set Test Plug. Pressure Test for 10 mins at 1000 psi. 09:00 - 10:30 1.50 BOPSU DECOMP Pump Out Stack and Open Ram Doors. CIO VBR's to 4-1/2" x 7", 10:30 - 11 :00 0.50 BOPSU DECOMP Rig Up BOP Test Equipment. 11 :00 - 16:00 5.00 BOPSU DECOMP Test BOPE to 250 psi Low Pressure and 4,000 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by Bob Noble. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Choke Valve # 12,13,14, Upper IBOP Test #2- Choke Valve # 9,11, Lower IBOP Test #3- Choke Valves # 5,8,10 Test #4- Choke Valves # 4,6,7, TIW Test #5- Blinds, Choke Valves #2, Kill HCR, Dart Valve Test #6- Choke Valves #3, Manual Kill Test #7- Choke HCR Test #8- Manual Choke 16:00 - 16:30 0.50 BOPSU P DECOMP PJSM with Rig Crew on Pulling Top of BOP to CIO Hydril Bag. 16:30 - 00:00 7.50 BOPSU N RREP DECOMP CIO Hydril. Pull Flow Riser and Top of Hydril. CIO Hydril. Large pieces missing out of element. Change out seal assemblies. Printed: 7/1012007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 02:30 - 03:00 0.50 BOPSU P DECOMP 03:00 - 03:30 0.50 BOPSU P DECOMP 03:30 - 04:30 1.00 CASE P TIEB1 04:30 - 13:30 9.00 CASE P TIEB1 13:30 - 14:00 0.50 CASE P TIEB1 14:00 - 00:00 10.00 CASE P TIEB1 6/23/2007 00:00 - 00:30 0.50 CASE P TIEB1 00:30 - 02:30 2.00 CASE P TIEB1 02:30 - 06:30 4.00 CEMT P TIEB1 06:30 - 07:00 0.50 BOPSU P TIEB1 07:00 - 08:30 1.50 BOPSU P TIEB1 08:30 - 09:00 0.50 WHSUR P TIEB1 09:00 - 10:00 1.00 CASE P TIEB1 10:00 - 13:30 3.50 CASE P TIEB1 13:30 - 15:00 1.50 BOPSU TIEB1 15:00 - 15:30 0.50 CASE TIEB1 15:30 - 16:30 1.00 BOPSU TIEB1 16:30 - 17:30 1.00 BOPSU TIEB1 Install Riser, Clean Cellar Area. Install 7" Test Joint and Rig Up Hoses and Gauges. Continue Testing BOPE Test #9- Choke Valve #1, Annular Preventer to 7". Test #10-VBRs tested to 7". Accumulater Test- 2,900 psi Starting Pressure, 1,850 psi After Actuation, First 200 psi in 19 seconds, Full Pressure in 1 Minute 15 Seconds. 5 Nitrogen Bottles at 2,100 psi. Rig Down BOP testing equipment. BOLDS pull test plug. Rig up 7" casing tools. M/U Seal assembly and 1 jt of 7"csg, Float collar jt, Followed by 7", L-80, 26#, BTC-M Casing. Average M/U Torque 8,600 ft-Ibs using best of life 2000 thread compound. Rig Up Torque Equipment for Vam Top connections Continue to RIH with 7", 26#, L-80, Vam Top Csg. Average M/U Torque 11,950 ft-Ibs using jet lube seal guard thread compound. RlU Long Bails, P/U Jt # 203, and M/U BTC-M x Vam Top XO and Lay down same. Continue to RIH with 7", 26#, L-80, Vam Top Csg. Average M/U Torque 11,950 ft-Ibs using jet lube seal guard thread compound. Continue f/7,899' to 7,920', up weight=252,000#, down weight=198,000# Slacked off and Tagged PBR at 8,000' NO GO at 8,000' with mule shoe at 8,010' Pressure up to 1,000 psi and held for 5 minutes. Bleed pressure to 300 psi P/U and watched for pressure drop as we P/U on seal assembly. Confirmed location of cementing ports on seal assembly. PJSM with SLB Cementers, Halliburton hands, MI, and Rig Crew on Cementing proceedure. RlU Cementers and pressure test lines to 5,000 psi, Cemented CSG and Cement in place at 06:30 Check Floats. Flush Lines and BOP stack with cement retarder, rig down cement head. Nipple Down BOP's and Flush OA Valve with Diesel Install Emergency Slips wI Primary Seal on 7" Casing and work into place. Set Slips with -80K. RILDS on casing slips. M/U Wachs Casing Cutter. Make Cut on Casing 6-1/4" above the flange face. Set Back BOP Stack and UD Cut Joint of 7" Casing. Nipple Up New McEvoy 13-5/8" x 13-5/8" 5M Tbg Spool with YBT Secondary Seals. Install Secondary Annulus on Tbg Spool. Test Pack Off for 30 mins to 4000 psi - Good Test Nipple Up BOP's. CIO VBR's to 3-1/2" x 6". Service Rig, Top Drive, Iron Rough Neck, Koomey, and Drawworks. Attempt to Test VBR's wI 4" Test Joint. Leaking By Test Plug. Pull Test Plug to inspect. Had Difficulties Pulling. Once on surface found Test Plug damaged. Missing 3 screws, 1/4" x 2" long. Printed: 7/10/2007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 CLEAN RIH wI BHA#15 on 4" DP from Derrick. CLEAN Obtain parameters: Up weight=180,000#, Down Weight=134,000#, Rotating weight=155,000#, 10 rpm, 5,000 ft-Ibs torque, Worked through tight spot at 7"x5.5" XO at 8,045'. Continue to Clean out w/20 rpm, 5,000 ft-Ibs torque, string mill at 8,089', Mill depth 8,268'. Pump Hi-Vis Sweep at 8.5 bpm, with 2,700 psi. POOH Laying down drill pipe. Losses at 24 bph. Continue to lay down 4" HT-38 drill pipe f/6,192'. UD 4 3/4" Drill Collars and Junk Mill BHA. Clear and Clean Rig Floor PJSM Rig up to Run Completion Change Elevators, Slips, RlU Torque Turn Equipment. Service Pipe Skate, Draworks, and Top Drive. PJSM Rig Crew, Packer Hand, and Casing Crew. M/U and RIH wI 4-1/2",12.6#, L-80 TC-II Completion. Use Jet Lube Seal Guard Pipe Dope. Average M/U Torque 3,850 ft/lbs. 180 jts of 4.5",12.6#, L-80, TC-II Tbg, 4.5" Mule Shoe Jt, 1 4.5" X Nipple wI RHC, Baker7" x 4.5" S-3 9Cr Pkr, X Nipple, 144 jts 4.5",12.6#, L-80, TC-II Tubing, One X nipple at 2,094' and 36 jts of Tubing to 7,441'. Started using used tubing at jt # 19:30 - 20:30 1.00 TIEB1 20:30 - 21 :00 0.50 TIEB1 21 :00 - 00:00 3.00 CASE P TIEB1 6/24/2007 00:00 - 01 :00 1.00 CLEAN P CLEAN 01 :00 - 04:00 3.00 CLEAN P CLEAN 04:00 - 05:00 1.00 CLEAN P CLEAN 05:00 - 07:30 2.50 CLEAN P CLEAN 07:30 - 08:30 1.00 CLEAN P CLEAN 08:30 - 10:00 1 .50 CLEAN P CLEAN 10:00 - 12:30 2.50 CLEAN P CLEAN 12:30 - 13:30 1.00 CLEAN P CLEAN 13:30 - 14:30 1.00 CLEAN P CLEAN 14:30 - 17:00 17:00 - 18:30 2.50 CLEAN P 1.50 CLEAN P 18:30 - 20:30 2.00 CLEAN P CLEAN 20:30 - 21 :30 1.00 CLEAN P CLEAN 21 :30 - 00:00 2.50 CLEAN P CLEAN 6/25/2007 00:00 - 05:00 5.00 CLEAN P CLEAN 05:00 - 07:00 2.00 CLEAN P CLEAN 07:00 - 07:30 0.50 CLEAN P CLEAN 07:30 - 08:30 1.00 RUNCO RUNCMP 08:30 - 09:30 1.00 RUNCO RUNCMP 09:30 - 10:00 0.50 RUNCO RUNCMP 10:00 - 00:00 14.00 RUNCO RUNCMP Call Out Cameron Wellhead Personal with new test plug. Tested 3.5"x 6" Variable rams with 4" and 4.5" Test joints. good test. RID BOP Testing equipment. M/U clean out assembly, BHA consist of: Junk Mill, 2-junk baskets, casing scraper, bit sub, bumper sub, oil jar, pump out sub, xo, 9-4 3/4" drill collars. RIH with clean out assembly. Continue to RIH with Clean out assembly, up weight=175,000#, down weight=135,000#, rotating weight=155,000#. Tagged cement at 7,902', washed down thru soft cmt to 7,917'. Drill harder cmt from 7917-7948', wob 5-10,000#, 40 rpm, 6 bpm @ 1110 psi. Tag wiper plug I Float Collar at 7,948' drilled at 80 rpm, 8 bpm, 930 psi, continued to drill cmt to 8,820' Pump 20 bbl Hi-Vis Sweep and Displace well with 269 bbls of 120 deg SWat 10 bbl I min and 2200 psi. RlU and Pressure Test Casing to 3,500 psi for 30 charted minutes. Good Test. Continue to Drill Cmt from 8020 - 8029'. Washed down from 8029' to 8035'. Drill Baker Type II Landing Collar and Ball wI 2-5K WOB, 40-80 RPM's, and Pump Rate at 3-7 bpm. Once Through Landing Collar. Continue to Wash Down to 5-1/2" x7" XO at 8043' Circ Btm Up at 7bpm and 900 psi. Monitor Well. Slight Loss Rate while Pumping -1/2 bpm at 7 bpm. POOH and Stand Back 4" DP. Stand Back 4-3/4" DC's and UD Drill Out BHA. P/U BHA#15. 3-5/8" Junk Mill, 6-3.125" DC's, 4-1/2" String Mill, 2-3.125" DC's, Bumper Sub, Oil Jar, Pump Out SUb, 9-4.75" DC's. Total Length = 541.93' Printed: 7/10/2007 10:57:47 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 8-15 8-15 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 6/7/2007 Rig Release: 6/27/2007 Rig Number: Spud Date: 5/16/1979 End: 6/27/2007 80, used tubing required polishing up nose seal area. Rechecked all make up graphes with positive Make ups on tubing. Layed down jt # 161 due to egg shaped tube and Layed down jt # 165 due to bad pin. Up weight=125,000# Down Weight=103,000#. 6/26/2007 00:00 - 02:30 2.50 RUNCMP Continue to run 4.5",12.6#, L-80, TC-II Completion. f/7,441 , to 8,091' No Go on Mule Shoe Collar. 02:30 - 04:00 1.50 RUNCMP Spaced Out Tubing, UD jts # 196, 195, 194, M/U Pup jts 1.97', 3.77',9.60',7.79'. M/U tubing hanger, and landing jt. Land tubing hanger. Mule shoe at 8,062.77', Packer at 7,970'. 04:00 - 05:00 RUNCMP RILDS. Found 4 LDS that were moving poorly. Cameron will C/O. A pressure test was made between hanger and the bag - good test. Hanger is seated correctly. 05:00 - 06:00 1.00 RUNCMP Rig Up Circulating Hoses. Spot Vac Trucks. 06:00 - 08:00 2.00 RUNCMP PJSM with Rig Crew and Vac Truck Drivers. Reverse circulate in 125 bbls of 140 degree seawater followed by 150 bbls 140 deg corrosion inhibited sea water at 3 bpm w/220 psi. 08:00 - 11 :00 RUNCMP RlU Little red and pump 75 bbls of diesel freeze protection down IA at 3 bpm with 350 psi. 1.5 hrs of down time due to problems with pop off. 11 :00 - 12:00 RUNCMP Allow diesel to u-tube in well bore for 1 hr. 12:00 - 12:30 RUNCMP PJSM with rig crew coming on tour and Little Red on setting and testing Baker S-3 packer. 12:30 - 15:00 RUNCMP Drop Ball and Rod Little Red pressured up on tubing to 4,000 psi, held test for 30 charted minutes good test. Bleed pressure to 2000-psi and lined up for annulus test. Pressured up to 4,000 psi on 7"x 4.5" annulus for 30 charted minutes. Witness of Packer test waived by AOGCC Representitive John Crisp. 15:00 - 16:00 1.00 RUNCMP Bleed down pressure from annulus and RID Little Red. 16:00 - 17:30 1.50 RUNCMP Set TWC and Tested from above to 3,500 psi for 10 minutes. 17:30 - 19:30 2.00 RUNCMP Nipple down BOPE and remove 4' spacer spool, and replaced with 14.5" spacer spool. 19:30 - 22:00 2.50 WHSUR P RUNCMP Repaired 4 LDS That where damaged during BOP testing. 22:00 - 00:00 2.00 WHSUR P RUNCMP N/U Adapter Flange and Production Tree and began testing neck seals to 5,000 psi. 6/27/2007 00:00 - 00:30 0.50 WHSUR P RUNCMP Continue to Test Hanger Void to 5,000 psi. 00:30 - 02:00 1.50 WHSUR P RUNCMP RlU Production Tree and Test to 5,000 psi for 30 Charted Minutes. RID Test Equipment. Pump out Tree. 02:00 - 03:00 1.00 RIGU P RUNCMP RlU DSM and Pull TWC and Set BPV. Secure Well. Rig Released at 03:00,6/27/2007 Printed: 7/10/2007 10:57:47 AM TREE! = WELLHEAO= A CTUA TOR= 6" CIVV MCEVOY OTIS 8-15 . Minimum 10 = 2.313" @ 8224' REDUCING NIPPLE -1 9-5/8" Casing Cut I 113-3/8" CSG, 72#, L-80, ,1480 bpf, 10=12,347 I 14-1/2" TLPIPE, 12,6#, L80, ,01522 bpf, 10=3,958 I 8256' 4-1/2" 'X' NIP, 10=3,813 7"" x 4 1/2" Baker Packer 4-1/2" 'X' NIP, 10=3,813 4-1/2" Mule Shoe I GUIB, PBR , 9-5/8" GUIB, POLAR PKR - 4-1/2" OTIS 'X' NIP, 10=3,813 I - 4-1/2" OTIS 'XN' NIP. 10=3,725 I - REDUCING NIP, 10=2,313 I ELMO I 4-1/2" TIL, WLEG I 4-1/2" TBG, 12,6#, 13CR, ID=39581 8151' 8019' 17" TBG, 26#. L-80, ,0382 bpf, ID=6,276 I I TOP OF 7" LINER I 8213' ÆRFORA TION SUMMA RY REF LOG: SWS-BHCS-5/29/79 ANGLEATTOPÆRF: 16 @ 9225' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/8 6 9225' -9240' 0 02/02/96 2-1/8 6 9250' -9270' 0 01/14/96 3-3/8 4 9270'-9280' S 02/24/94 3-3/8 4 9290'-9300' 0 09/09/94 3 1/8 4 9300'-9330' 0 08/20/79 2-1/84 9320'-9330' 0 11/04/94 2 -1/8 4 9340' - 9350' 0 11/04/96 3 1/8 4 9340'-9386' 0 08/20/79 3-3/8 4 9386'-9400' 0 11/26/92 9011' H MARKER JOINT 9-5/8" CSG, 47#, L-80, ,0732 bpf, ID=8681 9614' - FISHING NECK I 9626' - BAKER IBP I PBTD 7" LNR. 29#, L-80, ,0371 bpf, ID=6,184 9738' DATE 06/03/79 12/05/00 02/17/01 09/22/05 05/12/06 OS/29/07 REV BY COMMENTS ORIGINAL COMPLETION SIS-QAA CONVERTEDTOCANVAS JK/TP CORRECTIONS MOR/TLH TIP SET (08/20/01) KSB/PAG C/O GLV (05/05/06) JLM/TLH TIP PULLED (05/06/07) DATE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: B-15 ÆRMIT No: 179-019 API No 50-029-20360-00 SEC31 T11N R14E BP Exploration (Alaska) . . Page 1 of2 Maunder, Thomas E (DOA) From: Thomas Maunder [tom_maunder@admin.state.ak.us] Sent: ~,-Nft), -Jttftlf"'f9':'2'00'7 1'O':'23"ÄM' To: Chan, Paul (PRA) Cc: Reem, David C Subject: Re: P8U 8-15 RWO/Sundry 306-366 O\q "'~ \'^' Paul, That would meet the requirements. Risk is that some issue would be identified, however an assessment of the 7" liner cementing operation should provide clues if problems were experienced. Call or message with any questions. Tom Maunder, PE AOGCC Chan, Paul (PRA) wrote, On 6/13/200710:15 AM: Tom We can run a SCMT log post-rig and that log would cover from the 4-1/2" WLEG at 8256' MD to the top of fish/fill. Will that meet the logging requirements? Thanks again Paul Chan workover Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) SC/~NED JUL 3 1 2007 .._--~-----------~---~~ From: Thomas Maunder Lmëlilto:tom_maunder@admio.stëlte.ëll<.us] Sent: Wednesday, June 13, 2007 9:45 AM To: Chan, Paul (PRA) Cc: Reem, David C Subject: Re: PBU B-15 RWO/Sundry 306-366 Paul, 8100' is 1100' above the top perforation. Logging as you propose will only image the cement behind the 9-5/8" casing. Can you all perform an assessment of the 7" liner and 9- 5/8" cement jobs? Does the production history of the well lead you to believe that there are no cement issues? Is it possible to run a slim tool? Call or message with any questions. Tom Maunder, PE AOGCC Chan, Paul (PRA) wrote, On 6/13/2007 9:34 AM: 7/27/2007 . . Page 2 of2 Tom The approved Sundry for this RWO requires a "cement quality log". We will be setting a R8P at -8100' MD, one stand above the top of the PBR/packer. We will then run the USIT from the R8P to surface. Will this be acceptable to the AOGCC for the logging requirement? Thanks Paul Chan workover Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) 7/27/2007 e 0 og escrlpuon ae o or H-13 11676950 GAS ENTRY SURVEY 06/20/07 1 C-41 11801077 LDL 06/19/07 1 A-30A 11661159 MEM PROD PROFILE 06/23/07 1 W-21A 11661140 MEM PROD PROFILE 04/21/07 1 E-21 B 11661157 MEM PROD PROFILE 06/19/07 1 M-23 11626107 PRODUCTION PROFILE 06/23/07 1 01-21 11824330 PRODUCTION PROFILE 06/22/07 1 J·25A 11767130 MEM PROD PROFILE 06/18/07 1 Z·08A 11630483 GLS/PROD LOG 06/22/07 1 M-34 11824330 PRODUCTION PROFILE 06/22/07 1 02·30B 11594512 LDL 06/23/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 S-38 11801078 LDL 06/20/07 1 H-37A 11594506 PPROF/IPROF (REVISED) 06/05/07 1 N-15 11637129 PROD PROFILE (REVISED) 06/13/07 1 Z·13A 11649962 MEM PROD PROF (REVISED) 04121/07 1 P2-15A 11594511 SCMT 06/15/07 1 12-05 11676951 USIT (CEMENT) 06/24/07 1 12-05 11676951 US IT (CORROSION) 06/24/07 1 B-15 11626097 USIT 06/14/07 1 G-24A 11628750 SCMT 02/05/07 1 Scblumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth WI! J b# 06/29/07 RECEIVED NO. 4324 JUl 0 3 Z007 fìlaska Oil & Gas Coos. CommIssion Andiorage Company: State of Alaska Alaska 011 & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay L D . t' CI CD D t BL . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: SCANNED JUL ,05 2007 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth r1D¡ - orO¡ Received by: Re: PBU B-15i RWO sundry 306-366 . . Subject: Re: PBU B-15i RWO sundry 306-366 From: Thomas Maunder <tom _ maunder@admin.state.ak:.us> Date: Tue, 19 lun 2007 16:59:29 -0800 To: "Chan, Paul (pRA)" <Pau1.Chan@bp.com> CC: "Reem, David C" <ReemDC@BP.com> \ ,"\'1 -0 \ '\ Paul and Dave, I have attempted to contact the Commissioners without success. Your proposal is appropriate. The plan will provide a new casing string to surface and it will be fully cemented. The plan meets the requirements of20 AAC 25.030. Good luck with the operations. Tom Maunder, PE AOGCC SCANNED JUN 2 0 ZU07 Chan, Paul (PRA) wrote, On 6/19/2007 4:21 PM: Tom The scope of this injection well workover was to cut and pull 9-5/8" production casing, then to tieback and fully cement in a new premium threaded 9-5/8" production casing string. We have sucessfully recovered 1878' of 9-5/8" casing but are unable to recover the remaining pipe down to the first 9-5/8" cut at 2584' MD. We have recovered cement debris in a reversing basket and assume that cement stringers are preventing us from recovering the remaining 9-5/8" casing. The USIT log did not show cement down to the cut at 2584' MD. Upon further review and past experience, we would like to deviate from the Approved Sundry program by halting any further efforts to recover the remaining 9-5/8" production casing. BP proposes to repair the well by running a fully cemented 7" 26#1ft tieback and completing with a 4-1/2" L-80 tubing string. The proposed program is: 1) Recover two RBPs. 2) Run and set 9-5/8" ZXP liner top packer/FlexLock liner hanger @ -8050' MD. 3) Run and cement a 7" TC-IIIBTC-mod string from -8050' to surface. 4) Cleanout 7" casing through the shoe track. 5) Drift 7" shoe track and 9-5/8" Guiberson packer. 6) Run 4-1/2" L-80 completion with 7" production packer @ -7900' MD. Would this proposed deviation to the program be acceptable to the AOGCC? Thanks Paul Chan workover Engineer BP Alaska/wells Group (907) 564-5254 (907) 440-0183 (cell) (907) 564-5510 (fax) 1 of 1 6/20/2007 7:30 AM TREE = 6"C WB.LHEAD = McEVOY ACTUATOR = OllS KB. B.EV = 63.71' BF. B.EV = 37.1S' KOP = 2900' Max Angle = 25 @ 6300' Datum MJ = 9236' Datum TVD = SSOO' SS I TOP OF 9-5/S" H 1 13-3/S" CSG, 72#, L-SO, ID = 12.347" I . 8-15 i P ropose~·mY NOT" . LEAVE BKR lB' .. ..... 7", 26#/ft, L-80 Fully cemented to surface 17" CSG, 26#, L-SO, ID = 6.276" ~ 141/2" TBG, 12.6#, L-SO, TC-11, 10= 3.95S" 17" CSG, 26#, L-SO, ID = 6.276" ~ IS-1/2" CSG, 17#, L-80, 10 = 4.892" ~ TOP OF 7" LNR 9-S/S" CSG, 47#, L-80, ID = S.681" 8713' PERFORATION SUMMARY REF LOG: SWS-BHCS-S/29n9 ANGLE AT TOP PERF: 16 @ 922S' Note: Refer to A-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 922S - 9240 C 02/02196 2-1/8" 6 92S0 - 9270 C 01/14/96 3-3/8" 4 9270 - 9280 S 02/24/94 3-3/8" 4 9290 - 9300 C 09/09/94 3-1/8" 4 9300 - 9330 C 08/20n9 2-1/8" 4 9320 - 9330 C 11/04/94 2-1/8" 4 9340-93S0 C 11/04/96 3-1/S" 4 9340 - 9386 C 08/20/79 3-3/8" 4 9386 - 9400 C 11/26/92 I PBTD H 17" LNR, 29#, L-80, .0371 bpf, ID - 6.184" H DATE REV BY COMMENTS 06/03/79 ORIGINAL COM PLErION 02/17/01 JKITP CORRECTIONS 09/22/05 MORfTLH TTP SET (OS/20/01) 05/12/06 KSB/PAG C/O GLV (05/05/06) 10/31/06 AMS A-oposed RWO r 1878' 8213' 9734' I 9738' I DATE REV BY 4-1/2" HES X NIP, 10- 3.813" 9-5/8" BAKER LNR HGRlA<R 4-1/2" HES X NIP, 10 - 3.813" 7" BAKER S-3 A<R , 10 - 3.S75" 4-112" HES X NIP, 10 = 3.813" 8128' 8151' 8193' 8224' 4-1/2" OllS'X' NIP, ID = 3.813" 4-1/2" OllS XN NIP, Ð = 3.813" 8256' 4-1/2" TIL, WLEG 9011' MARKER JOINT FISHING NECK 9626' H BAKER IBP I COtvNENTS PRUDHOE BAY UNIT WB.L: B-15i PERMIT No: 1790190 API No: 50-029-20360-00 Sec. 31, 11N, 14E BP Exploration (Alaska) i. . . SARAH PALIN, GOVERNOR AI~A~IiA OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Herry Subekti Pad Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 1lA."' at ~ \1-' Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU B-15 Sundry Number: 307-165 SGANNED MA'( 2 9 2007 Dear Mr. Subekti: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conãítions 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, Dfu~ T. Sea.l'TIount Commissioner DATED this 1~day of May, 2007 Encl. .' . l5T:J 5/.2.-3 /? ~? RECEIVED STATE OF ALASKA ~)J- ALASKAOILANDGASCONSERVATIONCOMM.ON~ MAY 1 6 Z007 APPLICATION FOR SUNDRY APPROVAL \') , . 20 AAC 25.280 Alaska Oil & Gas Cons. CommIssion Operational shutdown Perforate Wai~ rage Othe Plug Perforations ~~ulate 0 Time Extension 0 ~ Perforate New Pool Ó...,. Re-enter Suspended Well 0 4. Current Well Class: 5. Permit to Drill Number: Suspend Repair well 0 Pull Tubing 0 1. Type of Request: Abandon Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. P.O. Box 196612 Developm ent 179-0190 3. Address: Stratigraphic Anchorage, AK 99519-6612 \Nrè. \ \ 7. If perforating, closest approach in pool(s) opened by this operation to neare t property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: 50-029-20360-00-00 ~ PBU B-15 ADLO-028310 ,. No 0 10. KB Elevation (ft): 11. Field/Pools(s): 63.7 KB PRUDHOE BAY Field / PRUDHOE OIL Pool - PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9626 9238 Plugs (measured): Junk (measured): 9626' 9614' Burst Collapse 2650' 4930 2670 8362' 6870 4760 9347' 8160 7020 11. Total Depth MD (ft): 9738 Total Depth TVD (ft): 9347· Casing Conductor Surface Intermediate Liner Length Size TVD 110' 20"x30" 30' 110' 2650' 13-3/8" 72# L-80 Surface 2650' Surface 8713' 9-5/8" 47# L-80 Surface 8713' Surface 1525' 7" 29# L -80 8213' 9738' 7879' Perforation Depth MD (ft): 9225' -9400' Perforation Depth TVD (ft): 8853' - 9021' Tubing Size: 7" 26# 4-1/2" 12.6# Tubing Grade: L-80 L-80 Tubing MD (ft): Surface - 8151' 8151' - 8256' 5/29/2007 Date: Packers and SSSV MD (ft): 8151' o 0 o 0 o 0 13. Well Class after proposed work: Exploratory 0 Developm ent 15. Well Status after proposed work: --./ Oil 0 Gas 0 Plugged M ~..\~~~~, ~ct\\~,\\.S~\\~ Packers and SSSV Type: 9-5/8" GUIB. POLAR PKR 12. Attachments: DescriDtive Summary of Proposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: Abandoned 0 and correct to the best of my knowledge. Title GINJ 0 WINJ 0 WDSPL 0 Prepared by \::I<try r-rl:lule 564-4944 Contact Herry Subekti Pad Engineer Phone 564-5112 COMMISSION USE ONLY Date 5/15/2007 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test ~ Mechanical Integrity Test o Location Clearance 0 \..JdK \ \JJE:.~ \ C. ~v.c;.~ (S~"> ~ ~~\.C5-' W ~ \\0 ~\ ~'> '-O~~ ~~~ t--..~ \.).::¡:) ~<-. <J...~.\-\....c ~ ~'2_tn) ~ ~ Ceo - <; <ø <ø . ~ Other: ~5"OO fS \ \50"Ç> ~~ COMMISSIONER APPROVED BY THE COMMISSION Date: Subsequent Form Required: '-\0 w Approved by: Form 10-403 Revised 06/2006 RBDMS BFL MAY 24 2007 Submit in Duplicate . . ... .\If.,II, -.,~ ~...- ~..- ~..-- ~.~ ~~ ·'.'·~i\· ". To: J. Bixby/C. Olsen Well Operations Team Leader Date: May 10, 2007 From: Abraham Zambrano, Wells Engineer Subject: 8-15 CT P&A Procedure (Pre-RWO) Capital RWO AFE4P2605 Est. Cost: $100M lOR: Pre Conv. Step Type Procedure 1 S Drift & tag pre P&A to establish TO. 2 C P&A as per attached procedure. 3 S Tag cement top to confirm P&A depth 4 F Pff P&A to 3000 psi. Circulate out tbg and IA to recover diesel. Status: Last test: Max Deviation: Perf Deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S level: L TSI, Trouble Well, T X IA X OAComm. 724 BOPD, 4736 BFPD, 27.5 K GOR, 96 Choke 11/25/99 25 degrees @ 6300'MD 16 degrees @ 9225'MD 2.313" @ 8224' Reducing nipple 11/26/99 CT FSPL up/down passes to 9450' (didn't tag- 9/28/99 deep tag prior to spinner was 9597' 5/6/07 pulled 2.313" XX plug from nipple reducer at 8208'wlm 3 PPM 11/21/98 The objective of this pre RWO cement P&A is to abandon the existing perforations, safe out the well prior to the Rig and circulate out the tbg and IA to recover the diesel from the sqz. B-15 is a LTSI weill since Dec 1998 due to high GOR. The well was secured 8/20/01 due to TxlAxOA communication and has a RWO scheduled for late June 2007. According to the Updip zone 4 injection plan, this well will be converted into an injector to provide injection support to arrest gas cap encroachment in the area. This program will P&A the Zn2/3 perforations and safe out the well for the Rig. Perforations will be added in zone 4 after the RWO and facility conversion is finished. If you have any questions or comments regarding this procedure, please call AI Schmoyer at 564-5865 or 346-2172. cc: Well File . . Objective The primary goal is to P&A all open perforations. Target top of cement is 9140'.(Acceptable window is 9140'- 9180"). Once the RWO is performed injector, Z4 will be perfed uphole for MI/water injection, the new perforated interval is 9032'-9079' and 9083'-9126'. The perforation will be done after RWO is completed. Procedure/Risk Discussion · There is an IBP on bottom at 9626' (Bottom perforation is at 9400'), with a fishing neck whose top is at 9613' left on 6/13/94. · Last deep tag was 9597' on 9/28/99 · NOTE: B-15 has a long history of failing MIT's. The most recent failure was on 7/23/06 with 4000 psi. 08/02/06 LDL indicates Guiberson Polar pkr has failed · The wellbore volume is 363 bbls to 9597 ELM (Last deep run) · This well is scheduled for a RWO · Well has permanent patch · The cement volume may need to be adjusted after injectivity test. Aggregate may need to be considered if injectivity is extremely high (not anticipated on this well) CTU Cement P&A 1. RU 1.75" CTU. Fluid pack well with -500 bb1160ºF KCI water (-1.5 x well bore volume) at max rate. After -500 bbls of water have been pumped, reduce the rate to -1 bpm in order to maintain BHCT. Well will be on a vacuum with a full column of seawater. 2. Run in hole w/ 1.75" fluted no-go CRC, 1 or 2 1.75" stingers, and a 2.00" ball drop nozzle. Ensure ball will drift thru CRC. (This op will be done with no checks and the minimum ID is 2.313") 3. While pumping down backside only (coiled tubing by tubing annulus), tag PBTD with nozzle. Pull up 10 feet and flag pipe. Pull up hole above 9225' (top perf.) and break circulation down the coil to ensure the nozzle isn't plugged. 4. Pump diesel down backside as necessary to achieve positive wellhead pressure under static conditions (not while pumping into the formation). This will be about 335 bbl of diesel (based on SBHPS from well B-18 taken on 07/04/063231 psi and 213°F @ 8800 TVD and a positive pressure differential of 100 psi.) 5. Batch mix 38 bbls of 15.8 ppg Class G cement (no gas-block or latex needed-can be mixed on the fly 6. Line up cementers to the coil. Pump the following down the coil (have the cementers call out displacement volumes from their tanks). a. 10 bbls of fresh wtr spacer Do NOT use friction reducer J313 as it will clabber up cement b. 33+ bbls of 15.8 ppg cement (empty the batch mixer) c. 40 + bbls of fresh water 7. RIH with coil to flag depth as the cement reaches the nozzle. Open choke to take returns up the backside. 8. Do not pull uphole until -4 bbl of cement are out the nozzle. (Ideally, this will place the cement top -105' above the nozzle in order to prevent dilution of cement while the CT is being pulled uphole). After 4 bbls of cement are out of the nozzle, pull uphole and lay in cement at 1:1 9. Pull up to just above the top perf of 9225' (to prevent cement dilution if perfs are taking cement). . . 10. Close the choke and reciprocate just above the top perf at 9225' until wellhead pressure rises 500 psi. Do not build squeeze pressure while coil is below perfs to prevent getting "noded" in. Lay in remaining cement 1:1 11. When 3 bbls are left in the coil, race to the cement top to position nozzle at cement top just as the last barrel of cement exits the nozzle. 12. Pull up hole at maximum speed to safety of at least 8608' a. Note: 33 bbls of cement would extend up the 7" liner to 8708' MD if the perfs take no cement before squeeze pressure develops (assuming PBTD at 9597' MD) 13. With the CT at safety, close choke, swap to CT pump, and slowly walk WHP to a target of 1000 psi. Holding squeeze pressure for 30 minutes while closely monitoring return volumes. May need to break circulation occasionally to avoid freezing. a. If 1000 psi squeeze pressure cannot be reached after delayed hesitation, stop down squeezing cement when TOC is -9139. Target TOC is 9140' (This should be 16 bbls, assuming PBTe of 9597). Reduce WHP to 500psi over baseline. 14. After 30 minutes at squeeze pressure, slowly bleed WHP down to 500 psi above the baseline. Minimize pressure surges while bleeding down WHP and during clean out. 15. Swap to 1-1/2# biozan then RIH at 1:1 to 9140 (target TOC). Make at least one down and one up pass at 50% while jetting biozan. Followed by at least one down while jetting slick water. On final up pass, POOH @ 80% reducing speed at GLM's and nipples. 16. Jet up hole at 80% running speed and max CT pressure, wash BOP stack. FP well to 2500' wI diesel. 17. RD CTU, leaving well secured. Cement Volume Table Cement VOlumes Ccsing: 7, Rat hole Aaœs Perforations AOOve Perforations Subtotd: T otd CementT 0 Mx: . . TREE " B"CrW I I VVELLHEAO - MCEVOY B-1 5 SAFETY NOT ES - LEAVE BKR IBP@ 9626' Âêî'ùATÕR;;~'F """""'OTIS KB. B..EV " 63.71' BF:äEïï; 'H "37:18' ...I 1997' ur" SSSV OTIS LANDN:> NIPWIINSERT, 10=3.813 ~<5~;' . "'290Ö' ...........................,....... ----- Ma~ A ngte ~ ..3,~J£,~,~,~9~ ~ ~ õã!ûm MD;;'~~' 9236' I 3591' ALPHA TBG PATCH, 11)=2.86, WOIINSERT, 1[)=5.962 Daiûm*ñì¡r;;:"""'8aoo:§s ~ ~ GAS LIFT MANDRELS 113-318" CSG, 72:1/, L-BO, I[) " 12.347" 2650' ISTI M) I TVD 100VI TYPE I VLV LATCH1fúRTI DAlE I / /1213608 35291 1 I I 0 1~5I051°~1 1 6336 6058 eM' 0 05105106 Minimum ID = 2.313" @8224' I f- ---13607' "3619' CIRCULATION TBG PERFS, 4·HOLES, l' INTV REDUCING NIPPLE 6321' ALR1A T8G PATCH, I[) "2.86"' I 6336' " 6348' Circulation Tbg. Perfs, 4·hol<ls, l' Intv.1 17" T8G, 26#, L-80. .0382 bpf, 10" 6.276" 8151' ..!J8 8128' H GUtS. PeR I 1SL. ~ 8151' 9-518" GlJIB. POLA.R PKR I 8193' 4-112" OTIS 'X' NIP, I[) "3,813' 1 I TOP OF 7" LNR I 8213' I 1 4-1/2" OTIS XN N1P, W IREDUClNG NIP, I[) " 2.313" - 8224' 1 8224' 2·718" XX TIP (08/20/01) I 14-1/2" LNR. 12.6#, L-80. .01522 bpf,1Ü - 3.958" LJ 8256' I 8256' 4·112" TTL, WLEG I I 8249' l-j ELMO LOGGED ON 'Yi¡??N? 1 19.518" CSG, 47#, L-80, 10" 8.681' LJ 8713' l----A [ .. ÆRFORA TION SUfNAARY [ REF LOG: SWS-BHCS-5/29179 I 9011' H MARKER JOINT I ANGlE AT TOPÆRF: 16 @ 9225' , Note: Refer to Production DB for historical perf data [ SIZE SPF INTffiV AL OpnlSqz DATE 2-118" 6 9225· 9240 C 02102196 2·118- 6 9250 - 9270 C 01114196 ( [ 3·318" 4 9270 - 9280 S 02124/94 3-318" 4 9290 - 9300 C 09109194 3·1/8" 4 9300 . 9330 C 08120179 -, 2-118" 4 9320 - 9330 C 11104194 9614' H FiSHING NECK I 2-118" 4 9340 - 9350 C 11104196 3·1/8" 4 9340 - 9386 C 08120179 3-318" 4 9386 - 9400 C 11126192 ....... -J 9626' H BAKERSP I I PeTD 9734' I 7' LNR,29#, L-BO, .0371 bpf, 10"6.184" I 9738' DATE REV BY CO~"1ENTS DATE REV BY COMM:NTS PRUDHOE SA Y UNIT 06103(79 ORIGINAL COMPLETION WB.L: B-15 02/17101 JKffP CORREC11ONS PERMIT No: 1790190 09¡'22/05 I..oRfTLH ìTPSET (08120101) API No: 50·029-20360-00 05/12106 KSBiPAG 0'0 GL V (05/05106) Sec. 31. 11N. 14E BPExploration (Alaska) . . ... ,"'.'11. _...~ ~...- ~.- ~.... .~ .¡;..~ ·'I'·~I\" ". To: J. Bixby/C. Olsen Well Operations Team Leader Date: May 10, 2007 From: Abraham Zambrano, Wells Engineer Subject: 8-15 CT P&A Procedure (Pre-RWO) Capital RWO AFE4P2605 Est. Cost: $100M lOR: Pre Conv. Step Type Procedure 1 S Drift & tag pre P&A to establish TO. 2 C P&A as per attached procedure. 3 S Tag cement top to confirm P&A depth 4 F PIT P&A to 3000 psi. Circulate out tbg and IA to recover diesel. Status: Last test: Max Deviation: Perf Deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S level: L TSI, Trouble Well, T X IA X OAComm. 724 BOPD, 4736 BFPD, 27.5 K GOR, 96 Choke 11/25/99 25 degrees @ 6300'MD 16 degrees @ 9225'MD 2.313" @ 8224' Reducing nipple 11/26/99 CT FSPL up/down passes to 9450' (didn't tag- 9/28/99 deep tag prior to spinner was 9597' 5/6/07 pulled 2.313" XX plug from nipple reducer at 8208'wlm 3 PPM 11/21/98 The objective of this pre RWO cement P&A is to abandon the existing perforations, safe out the well prior to the Rig and circulate out the tbg and IA to recover the diesel from the sqz. B-15 is a L TSI weill since Dec 1998 due to high GOR. The well was secured 8/20/01 due to TxlAxOA communication and has a RWO scheduled for late June 2007. According to the Updip zone 4 injection plan, this well will be converted into an injector to provide injection support to arrest gas cap encroachment in the area. This program will P&A the Zn2/3 perforations and safe out the well for the Rig. Perforations will be added in zone 4 after the RWO and facility conversion is finished. If you have any questions or comments regarding this procedure, please call AI Schmoyer at 564-5865 or 346-2172. cc: Well File . . Obiective The primary goal is to P&A all open perforations. Target top of cement is 9140'.(Acceptable window is 9140'- 9180"). Once the RWO is performed injector, Z4 will be perfed uphole for MI/water injection, the new perforated interval is 9032'-9079' and 9083'-9126'. The perforation will be done after RWO is completed. Procedure/Risk Discussion · There is an IBP on bottom at 9626' (Bottom perforation is at 9400'), with a fishing neck whose top is at 9613' left on 6/13/94. · Last deep tag was 9597' on 9/28/99 · NOTE: B-15 has a long history of failing MIT's. The most recent failure was on 7/23/06 with 4000 psi. 08/02/06 LDL indicates Guiberson Polar pkr has failed · The well bore volume is 363 bbls to 9597 ELM (Last deep run) . This well is scheduled for a RWO . Well has permanent patch · The cement volume may need to be adjusted after injectivity test. Aggregate may need to be considered if injectivity is extremely high (not anticipated on this well) CTU Cement P&A 1. RU 1.75" CTU. Fluid pack well with -500 bbl160QF KCI water (-1.5 x well bore volume) at max rate. After -500 bbls of water have been pumped, reduce the rate to -1 bpm in order to maintain BHCT. Well will be on a vacuum with a full column of seawater. 2. Run in hole w/ 1.75" fluted no-go CRC, 1 or 2 1.75" stingers, and a 2.00" ball drop nozzle. Ensure ball will drift thru CRC. (This op will be done with no checks and the minimum ID is 2.313") 3. While pumping down backside only (coiled tubing by tubing annulus), tag PBTD with nozzle. Pull up 10 feet and flag pipe. Pull up hole above 9225' (top perf.) and break circulation down the coil to ensure the nozzle isn't plugged. 4. Pump diesel down backside as necessary to achieve positive wellhead pressure under static conditions (not while pumping into the formation). This will be about 335 bbl of diesel (based on SBHPS from well B-18 taken on 07/04/06 3231 psi and 213°F @ 8800 TVD and a positive pressure differential of 100 psi.) 5. Batch mix 38 bbls of 15.8 ppg Class G cement (no gas-block or latex needed-can be mixed on the fly 6. Line up cementers to the coil. Pump the following down the coil (have the cementers call out displacement volumes from their tanks). a. 10 bbls of fresh wtr spacer Do NOT use friction reducer J313 as it will clabber up cement b. 33+ bbls of 15.8 ppg cement (empty the batch mixer) c. 40 + bbls of fresh water 7. RIH with coil to flag depth as the cement reaches the nozzle. Open choke to take returns up the backside. 8. Do not pull uphole until -4 bbl of cement are out the nozzle. (Ideally, this will place the cement top -105' above the nozzle in order to prevent dilution of cement while the CT is being pulled uphole). After 4 bbls of cement are out of the nozzle, pull uphole and lay in cement at 1:1 9. Pull up to just above the top perf of 9225' (to prevent cement dilution if perfs are taking cement). . . 10. Close the choke and reciprocate just above the top perf at 9225' until wellhead pressure rises 500 psi. Do not build squeeze pressure while coil is below perfs to prevent getting "noded" in. Lay in remaining cement 1:1 11. When 3 bbls are left in the coil, race to the cement top to position nozzle at cement top just as the last barrel of cement exits the nozzle. 12. Pull up hole at maximum speed to safety of at least 8608' a. Note: 33 bbls of cement would extend up the 7" liner to 8708' MD if the perfs take no cement before squeeze pressure develops (assuming PBTD at 9597' MD) 13. With the CT at safety, close choke, swap to CT pump, and slowly walk WHP to a target of 1000 psi. Holding squeeze pressure for 30 minutes while closely monitoring return volumes. May need to break circulation occasionally to avoid freezing. a. If 1000 psi squeeze pressure cannot be reached after delayed hesitation, stop down squeezing cement when TOC is -9139. Target TOC is 9140' (This should be 16 bbls, assuming PBTD of 9597). Reduce WHP to 500psi over baseline. 14. After 30 minutes at squeeze pressure, slowly bleed WHP down to 500 psi above the baseline. Minimize pressure surges while bleeding down WHP and during clean out. 15. Swap to 1-1/2# biozan then RIH at 1:1 to 9140 (target TOC). Make at least one down and one up pass at 50% while jetting biozan. Followed by at least one down while jetting slick water. On final up pass, POOH @ 80% reducing speed at GLM's and nipples. 16. Jet up hole at 80% running speed and max CT pressure, wash BOP stack. FP well to 2500' wI diesel. 17. RD CTU, leaving well secured. Cement Volume Table Cement Volumes 7. Rat hoI e Aaœs Perforations Ncove Perforations Subtotd: T otd Cement To Purrp: T otd Cement To Mx: . . , , TREE ' ß"crw I I WELLHEAD - MCEVOY B-1 5 SAFETY NOTES - LEAVEBKR IBP@ 9626' ÃCTUAToR';; . ..v····õTis K¡rwÊlB.r;;-~ """'~o',"«<-,·c.> "53.71' BF:ËLEV;;;V 37:18; .....I 1997' LJ 7" SSSV OTIS LANDING NIP WIINSERT. 10=3.813 ì<OÞ;;; 2900' - "" l:;~~~~1 ~ ~ Datum MD ~ I 3591' ALF+V\ TSG PATCH, 10=286, WOIINSERT, 10=5.962 UaIum IVU- ~ ~ GAS LIFT Ml\NDRElS 113-318" CSG, 7211, L-80,ID" 12.347" 2650' r---' 1ST! M) I TVD I DEV I TYPE I VLV I LATCH I FúRT DATE I / VI 2 3608 I 35291 I I r»AY I BK I 0 1~105/()~1 1 6336 6058 DMY BK 0 0.',105105 Minimum ID = 2.313" @ 8224' I 3607' . 3619' CIRCULA 1100 TBG ÆRF$, 4-HOLES, l' MY REDUCING NIPPLE 6321' ALFtiA TBG PATCH 10-2.85" I 6336' . 6348' Orcu/atbn Tbg. Perfs, 4-hölt1\;, l' InN. 7" TBG, 2611, L-60. .0382 bpf, 10" 6.276' 8151' I 8128' H GU/S, PaR I f2.SL. ~ 8151' 9-518" GUIB. POLAR A<R I . 8193' 4-1/2' OTIS 'X' NIP, 10 - 3.813' I I TOP OF 7" LNR 8213' III! I 4-1/2" OTIS XN NIP, wlREDUaNG NIP, 10" 2.313' ..... I 8224' I 8224' 2-718" XX TTP (08/20101) I 14-1(¿" LNR. 12.6#, L-80, .01522 bpI. ID" 3.958" LJ 8256' r 8256' 4-1/2"TTL, WLEG I I 8249' H B..MO LOGGED ON TIny/? I 19-5/8' CSG, 47#, L-80. ID" 8.681" LJ 8713' l----A r II. ÆRFORA TION SUMMI\RY I [ REF LOG: SWS-BHCS-5I29179 I 9011' H Ml\RKERJOINT I ANGlEATTOPÆRF: 16 @ 9225' Note: Ref ar to Production DB for historical perf <lata [ 1 SIZE SPF INTERVAL OpnlSqz DATE 2-118' 6 >1225 - 9240 C 02102196 2·118" 6 9250 - 9270 C 01/14/96 [ ] 3-318' 4 9270 - 9280 S 02/24/94 3-3/8" 4 9290 - 9300 C 09/09194 3-1/8' 4 9300 - 9330 C 08120179 -, 2-1/8" 4 932Q - 9330 C 11/04/94 9614' FISHING NECK I 2-118" 4 9340 - 9350 C 11/04196 3-118' 4 9340 - 9386 C 08/20179 3-3/8" 4 9386 - 9400 C 11/26192 Þ ....... 9626' H BAKER BP I ...... I P8TD I 9734' I T LNR,29#, L-80. .0371 bpf.ID=6,184" I 9738' DATE REV BY COMv9JTS DATE REV BY COMtvENTS PRUDHOE. SA Y UNIT 06103/19 ORIGINAL COMPLETION WELL: B-15 02/17101 JKfTP CORRECllONS PERMIT No: 1790190 09/22105 M)RfTLH TTPSET (08120/01) API No: 50-029-20360-0Q 05112/06 KSBlPAG 0'0 GL V (05105/06j Sec. 31. 11N, 14E BP EKploratio" (A las ka) . . FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer 8P Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 8-15 Sundry Number: 306-366 a.... 0 t q \1-t Dear Mr. Reem: L"i{"~'" ..~.,.. "ì <èJ;¡A' . ~\¡'!, 'E.\1, ,.¡¡,...r..... .:"'''",,; ......."" (:} It ¡iJ ~) 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, DATED this1:L day of November, 2006 Enc!. K "(I ~ STATE OF ALASKA . ~:) t: ('" '..~ . V e \ >.'^ .,,! ~_ I .. .. ~ ~ 0 ALASKA OIL AND GAS CONSERVATION COM ION ~) \1 I APPLlCA TION ~~~;2~.~8~RY APPROV A~J'\;J'¡ (' 1. Type of Request: o Time Exten~Ii:!~i¡ ')..¡>t o Abandon o Suspend o Operation Shutdown o Perforate o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver 181 Other Convert to WAG Injector 2. Operator Name: 4. Current Well Class: /' 5. Permit To Drill Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 179-019 ~ 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20360-00-00 -- 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 B-15 / Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028310 63.7' Prudhoe Bay Field / Prudhoe Bay Pool 12: ............ ..... lAlJ::t I :. ...... y : .........,.> ....: ..... . ..... Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9738 9347 9626 9238 8224 & 9626 9614 Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 110' 20" x 30" 110' 110' Surface 2650' 13-3/8" 2650' 2650' 4930 2670 Intermediate 8713' 9-5/8" 8713' 8362' 6870 4760 PrnrllJdinn Liner 1525' 7" 8213' - 9738' 7879' - 9347' 8160 7020 Perforation Depth MD (fty Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 9225' - 9400' 8853' - 9021' 7",26# x 4-1/2", 12.6# L-80 8256' Packers and SSSV Type: 9-5/8" Guib. Polar packer packers anlSSSV MD (ft): 8151' 13. Attachments: 14. Well Class after proposed work: / ~ Description Summary of Proposal D BOP Sketch D Detailed Operations Program D Exploratory ~ Development D Service 15. Estimated Date for 16. Well Status after proposed work: Commencina Operations: January 2007 DOil DGas D Plugged D Abandoned 17. Verbal Approval: Date: ~WAG DGINJ DWINJ ~ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Stiem, 564-5294 Printed NamE('\>avid Reem Title Drilling Engineer ~~ Prepared By Name/Number: Signature Phone 564-5743 Date Ii /9/0(, Terrie Hubble, 564-4628 Commission Use Only I Sundry Number: :3{;{¡;- ~ ./ "" Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity Œt'BOP Test ~echanicallntegrity Test D Location Clearance Other: Tës t- -gO PE fo 4000 f cA . RBDMS 8Ft ÅI1. íT, ~~t õ(t¡J9;~åvc1Ved. 2 2006 Subsequent Fonn Required' \ 0 - o. i If ¡,j "tJb 7 ~t 'A~ COMMISSIONER APPROVED BY Approved Bv: THE COMMISSION Date Form 10-403 Revised 06/2006 V I,.,.'V \ Submit In Duplicate lJRlGINAL ~ WH~VV fJlG ~W"iEIDLI¿VC1Co . . G B-15i Rig Workover Scope of Work: Replace 7" 29# L-80 BTC tubing with 4-Y2" 12.6# L-80 TC-II tubing and run 9-5/8" x 4- 1/2" S-3 packer completion to convert well to gas and water injection service. Replace 9-5/8" 47# L-80 / BTC production casing with 9-5/8" 47# L-80 TC-II tie-back cemented to surface. MASP: 2230 Well Type: Injector Estimated Start Date: January, 2007 Pre-riQ prep work: 0 1 Function-check tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakaQe one at a time. 0 2 PPPOT - T & IC F 3 Load tubing and IA with seawater at maximum rate to sweep gas. MIT-OA to 2000 psi. Packer failure so unable to CMIT. Bleed well head pressures to 0 psi. 0 4 Set a back pressure valve in the tubing hanger. Remove the wellhouse & flow line. Level the pad for rig. Proposed Procedure: 1. Move in and rig up workover rig. 2. Bullhead seawater down tubing and IA. 3. Set TWC and pressure test. 4. Nipple down tree and nipple up BOPE with 4-1/2 x 7" VBR pipe rams. Pressure test to 4000 psi. /' 5. Pull and lay down 7" tubing. . 6. Set 2 retrievable bridge plugs in 9-5/8" casing. /' 7. Cut and pull 9-5/8" from above the top of cement. Note: Pipe rams will not be changed to 9-5/8" / since the well has two tested barriers (RBP's) to the reservoir. 8. Run and fully cement new 9-5/8" casing to surface. 9. Run new 4-1/2" premium threaded L-80 tubing completion with Baker S-3 packer at -8,060 MD'. 10. Displace IA with seawater and corrosion inhibitor. Freeze protect to 2200' MD. 11. Test tubing and IA to 4000 psi. 12. Set back pressure valve. 13. Nipple down BOPE. 14. Nipple up and test tree. 15. Rig down and move out. . TREE = , 6"Crw I.ETY NOTES - LEAVE BKR IBP @ 962~ I WELLHEAD = MCEVOY 8-15 ACTUATOR = OTIS KB. ELEV = 63.71' BF. ELEV = 37.18' ~ 1997' I IT' SSSV OTIS LANDING NIPW/INSERT,ID=3.813 KOP= 2900' ~¡,..... Max Angle = 25 @ 6300' FOC "- . Datum MD = 9236' l- I 3591' ALPHA TBG PATCH, ID=2.86, WO/lNSERT, ID=5.962 DatumTVD= 8800' SS ~ ~T GAS LIFT MANDRELS 113-3/8" CSG, 72#, L-80, ID = 12.347" I 2650' MD TVD DEV TYÆ VLV LATCH PORT DATE l-::: V 2 3608 3529 DMY BK 0 05/05/06 1 6336 6058 DMY BK 0 05/05/06 Minimum ID = 2,313" @ 8224' I 3607' - 3619' CIRCULATIONTBG ÆRFS, 4-HOLES, l' INTV REDUCING NIPPLE 6321' H ALPHA TBG PATCH, ID 2.86" I IJ 6336' -6348'H Circulation Tbg. Perfs, 4-holes, l' Intv. 17" TBG, 26#, L-80, .0382 bpf, ID = 6.276" I I , 8128' 1-1 GUIB. PBR I 8151' ~ ~ ~ 8151' H 9-5/8" GUIB. POLAR A<R I I . 8193' H 4-1/2" OTIS 'X' NIP, ID = 3.813" I I TOP OF 7" LNR H 8213' I I 4-1/2" OTIS XN NIP, W IREDUCING NIP, ID = 2.313" - 8224' 8224' -12-7/8" XX TIP (08/20101) I 14-1/2" LNR, 12.6#, L-80, .01522 bpf, ID = 3.958" IJ 8256' I I 8256' H 4-1/2" TTL, WLEG I I 8249' H ELMD LOGGED ON ??/??/?? I 19-5/8" CSG, 47#, L-80,ID= 8.681" I~ 8713' 1----4 ] ~ ÆRFORA TION SUMMARY II [] REF LOG: SWS-BHCS-5/29/79 I 9011' H MARKER JOINT I ANGLEATTOPÆRF: 16@9225' Note: Refer to A-oduction DB for historical perf data I] ¡] SIZE SPF INTERV AL Opn/Sqz DATE 2-118" 6 9225 - 9240 C 02/02/96 2-118" 6 9250 - 9270 C 01/14/96 I) I) 3-3/8" 4 9270 - 9280 S 02/24/94 3-3/8" 4 9290 - 9300 C 09/09/94 3-1/8" 4 9300 - 9330 C 08/20/79 -, 2-1/8" 4 9320 - 9330 C 11/04/94 9614' H FISHING NECK I 2-1/8" 4 9340 - 9350 C 11/04/96 3-1/8" 4 9340 - 9386 C 08/20/79 3-3/8" 4 9386 - 9400 C 11/26/92 I~ r 9626' 1-1 BAKER IBP I I PBTD I 9734' I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 9738' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT 06/03/79 ORIGINAL COM PLETION WELL: B-15 02/17/01 JKlTP CORRECTIONS ÆRMIT No: 1790190 09/22/05 MORlTLH TIP SET (08/20101) API No: 50-029-20360-00 05/12/06 KSB/PAG C/O GL V (05/05/06) Sec. 31, 11N, 14E BP Exploration (Alaska) ~ TREE = , W8.LHEAD = ACTUATOR = KB. 8.EV = SF. 8.EV = KOP= Max Angle = Datum MD = Datum TVD = 6" CrN rv1cEVOY OTIS 63.71' 37.18' 2900' 25 @ 6300' 9236' 8800' SS 9-5/8", 47#/ft, L-80 Tc-II Fully cemented to surface 8-15 Proposed .TV NOTES - LEAVE BKR IBP @¡ 9626' 113-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 2.313" @ 8224' Reducing Nipple 41/2"TBG, 12.6#, L-80, TG-11,ID=3.958" 1 TOP OF 7" LNR I 8213' 141/2" 12.6# L-80 CS Hydril Tail Pipe, ID = 3.958"1 8256' 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 8713' ÆRFORA TION SUMMARY REF LOG: SWS-BHCS-5/29/79 ANGLEATTOPÆRF: 16 @9225' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/8" 6 9225 - 9240 C 02/02/96 2-1/8" 6 9250 - 9270 C 01/14/96 3-3/8" 4 9270 - 9280 S 02/24/94 3-3/8" 4 9290 - 9300 C 09/09/94 3-118" 4 9300 - 9330 C 08/20/79 2-1/8" 4 9320 - 9330 C 11/04/94 2-1/8" 4 9340 - 9350 C 11/04/96 3-1/8" 4 9340 - 9386 C 08/20/79 3-3/8" 4 9386 - 9400 C 11/26/92 1 PBTD H 9734' I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 9738' DATE 06/03/79 02/17/01 09/22/05 05/12/06 10/31/06 REV BY COMMENTS ORIGINAL COM PLETION JK/TP CORRECTIONS MORlTLH TIP SET (08/20101) KSB/PAG C/O GLV (05/05/06) AMS Proposed RWO DATE REV BY -14-1/2" HES X NIP, ID = 3.813" 1 -1 9-5/8" DV PKR I -14-1/2" HES X NIP, ID = 3.813" I -i 9-5/8" BAKER S-3 PKR , ID = 3.875" I H4-1/2" HES X NIP, ID = 3.813" 1 -11" SEAL ASSY(PBR) I 8193' -14-1/2" OTIS X NIP, ID = 3.813" I 8224' -14-1/2" OTIS XN NIP, ID = 3.725" 9011' HMARKERJOINT I -i FISHING NECK I 9626' H BAKER IBP I COMMENTS PRUDHOE BAY UNrr W8.L: B-15i ÆRMrr No: 1790190 API No: 50-029-20360-00 Sec. 31, 11N, 14E BP Exploration (Alaska) . . MECHANICAL INTEGRITY REPORT' "' :~.IG REL~;'_S~: S{lfÞ!7î ¡[ul?? OPER Ii FIELD - ~p - P"ßu. 'W=:LL NUMEER 'B - IS \1q, -'O~ ~ :?UD DA:::::: liQ-O/1 :...~LL DATA I'D: q7'S ~ Jill. q~47 TVD; :?BTD: Q(P2 V HI) Cê.si~g: q~S/i" Shoe: ~7/3 HI) f~G,.2.TVDi DV: . 7 Shoe: c¡ 73-f MD q 347 TVIì i :CF: ./ I ,. -=-~Di:;g: 7 '1-4-/ ,lPacke:r- tfJ"S\ till TVTI j Set ê.t: " .. 1 S· 12 '/..1'/ 0 II .. :'_0 e .:...ze . 1 ê.no. ïJ' 2 qz~f TVD MD TVTI Pe:r-£s i2/ ~ HD 7f7 cr :7D J25~ t:o qt(.D 0 _:..:>e::-: 92 zs :-::EC?..A.NIG·..L INTEGRITY - PART /1 Annulus Press Test: 7? 15 m~n 30 min Corraents: II\. IT If!bUA.:u d ,- :-ŒCHÞ_1\ ICÞ.~ INTEGRITY - PART /2 ~ { b0l> 1 l Cement: Volumes:' .Amt. Liner 4csG. t:{ ; Csg 1/~7 ~ ; DV C~t: -"01 to coveT De:r-=s '30 bblç Þ fA"\Ù.ý tW1~(I'\..-~)lNtJ... +SOO t @ ~O?a e'l-U<;ç. Theorecical TOC ~'11. L @ ~ 0 li70 J<4.CAr.,. CemenC Bond Log (Yes or No) Ai ; In AOGCC File CBL ~valuation, zone aoove perfs (---1:- 1/'.11./' Wi . Y"u k.Î,,~d . Production Log: Type Evaluation CONC;LUSIONS: :? art: if 1: MIT YPbtM r-t cd ? ar:: : Z , CD ""~ ~ t- J; ~ Þt. ¿" j \rlD IIc.Ù.... d No ~l/ç r MI(.., ki64- JI/ l"L / Ùç{)h . , . . Project: To convert inactive producer B-15 into an Updip Zone 4 Injector capable of both water and MI injection. The objective of the conversion is to provide pressure support to current producers, improve volumetric sweep efficiency and to mobilize and capture remaining oil saturation above the expanded GOC. This conversion was included as part of the Waterwheel 3 West project which delivered makeup water injection volumes to GC-3. This program is also consistent with a larger regional strategy to manage and develop the GDWFI area in a manner that considers the maturity of the waterflood areas, the maturing of the GD process and the possible impact of gas sales on overall recovery. B-15 used to produce from Ivishak Z3 and will be recompleted for MI injection into Zone 4 as part of the Updip Zone 4 I~ection (UZI) project for a period of one to two years until the GOR's in the surrounding producers, especially the up dip wells, decrease in response to injection. The MI slug will be followed by chase water injection for at least 7 years. The UZI project will increase water injection capacity in GC-3 and prevent further gas encroachment into GDWFI areas. B-15 status: The well has been LTSI since 2001 due to incompetitive GOR and TxlAxOA communication. During pre RWO screening on 04/02/06, a MITIA failed. A caliper log run on 05/04/06 indicated that the 7" tbg is in good to fair condition. There are no areas of significant cross sectional wall loss or ID restrictions recorded throughout the tubing. After dummying off all of the LGL V's from GL straddles at 3608'MD & 6336'MD, the well passed a MITIA 2500#. Since the 7" 26# AB 1J-4S Tbg is a premium metal to metal connection and should be gas tight, an attempt to waiver the well for MI has been pursued. But unfortunately, the MIT-4000# and MITIA 4000# failed wi a tbg LLR of 1.3 BPM @ 3000 PSI and an IA LLR of2 BPM @ 250 PSI, respectively. The IA was pressured up to 4000 PSI by pumping 6.7 BBLS crude and then the IA pressure then fell off rapidly to 0 PSI. Tubing & IA pressure tracked when pumping on IA. A LDL run on 08/02/06 after the MITIA failure indicated 100% of IA fluid loss was through the packer. The well also exhibited a slow IAxOA communication that might be from communication across the WH or a leak from the 9-5/8" PC connection. The production casing pack off had been plastic packed, no further pack off work could be done to fix the potential root cause of the slow IAxOA from the WHo Offset wells within 1/4 mile: No wells within 1/4 miles in the Ivishak formation, but the closest wells is B-19/19A at 1550' distance. The other offsets: B-18 1990', B-06 2520', B-29A 1900', B-211660'. RECEiVED Schlum.el'ger a·C.Þ¡~~NEn '" c', (~ ¿> ,J\UG 2 :3 2006 NO. 3914 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ),~ çj & Gas Cons. commission And10rage Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 11-0 - 0 to¡ Field: Prudhoe Bay WI( CI C J # L D D BL e ob og escription ate o or D 1S-15 11:l21600 Lul. . IIII/OZl06 1 F-22 11194169 LCL 02/17/116 1 P-14 11212851 LDL 04/28/06 1 F-24 ' N/A PRODUCTION LOG 03/29/06 1 E-10A' 11047361 SENSA/MEMORY LDL 10/19/05 1 H-30' 11223103 LDL 03/19/06 1 A-37 11225946 PROD PROFILE WIDEFT 03/20/06 1 B-12A 11211386 PROD PROFILE W/DEFT & GHOST 03/31/06 1 G-06A 11258691 LDL 04/06/06 1 G-24 11258689 LDL 03/21/06 1 H-30 11217258 US IT 06/09/06 1 A-30A 40010566 OH EDIT OF MWD/LWD 06/26/04 2 1 A-30A PB1 40010566 OH EDIT OF MWD/LWD 06/21/06 2 1 A-30A PB2 40010566 OH EDIT OF MWD/LWD 06/25/06 2 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: 8eth 08/15/06 . . B-15 (PTD # 1 790190) Classified as Problem Well ) ) Subject: B-15 (PTD #1790190) Classified as ProblelTI Well From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Mon, 16 May 2005 09:19:41 -0800 To: "AOGCC - Jim Regg (E-mail)..<jim_regg@admin.state.ak.us>. "AOGCC - Winton Aubert: (E~mail)" <winton_aubert@admin.state.ak.us> . CC: "Rossberg; RSteven" <RossbeRS@BP~com>, "GPB, GC3 AreaMgr" <GPBGC3TL@BP.com>,. "GPB,GC3 Wellpad Lead" <GPBGC3WellpadLead@BP.cotn?",."NSU,ADW '¥eU OperatjottS . Supervisor" <NSUADWW ellQperationsSuperVisor@llP .com>, "Subekti,Herry"<subehl·@BP~com>, "NSU, ADW Well Integrity . Engineer". <NSUADWW: el1Integrity~ngineer@BP . com>, "Engel, ·Harry R".<EngelHR@BP.com>, "NS1j, ADWW,L ~ Çompleti.Qt;lSupervisor,"- .' .. <:NSUAÐWWL&CompletionSupervisor@BP.com>, "GPB,WellsOptEn,g"·. . <GPBW ells0p~Eng@BP .com>,"'GPB·,·Op6mization Engr"<GPBOptimizationEngr@BP~com>. .:. All, Well B-15 (PTO #1790190) has been found to have sustained casing pressure on the OA. The TIO's on 05/15/05 were SSV/1160/1160 psi. A TTP was set in this Trouble Well on 08/20/01 to secure for long term shut-in. The plan forward for this well is as follows: 1. DHD: Eval frequent bleeds by operator - DONE 2. WIE: Have AL line blinded 3. DHD: Bleed WHPs < 300 psi, BUR 4. WIE: If AL blind does not solve BUR, have SL reset TTP The well has been classified as a Problem well. Please call if you have any questions. «B-15.pdf» Thank You, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer (907) 659-5102 (907) 659-5100, 1154 pgr SCANNED JUN 2: t'{ 20.05 Content-Description: B-15.pdf B-15.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 5/16/2005 12:57 PM 1 FOC 1--__ 2650' ~ ) 1REE= 6" OW WELLHfAO= MCEVOY ACTUA TOR= OTIS KB. ELEV = 63.71 BF. ELEV = 37.18 KOP= 2900 Max Angle = 25 @ 6300 catum IVID = 9236'1 catum lVO= 8800' 113-3/8" CSG, 72#, L-80, 10=12.347 l-i Minimum ID = 2.313" @ 8224' REDUCING NIPPLE 17" TBG, 26#, L-80, .0382 bpf, 10=6.276 1-1 8151' ") 8-15 SAFETY NOlES - Leave Baker IBPat 9626' 1997' _I 7" SSSV 011S LA NDlNG NP W/INSERT, I .---- 10=3.813 .-- 3591' Î ALPHA. TBG PATCH, 10=2.86, I WO/INSERT,10=5.962 ~ GAS LIFT I\ILA.NOR8.S .. 5rA MO lVO OBI lYPE MAN LATCH / 2 3608 3529 OOIVE BK f 1 6336 6058 OPEN BK 3607-3619' 1-1 ORCULA TON TBG PERFS, 4-HOLES, l' INlV I 6321' -i ALPHA. TBG PATCH, 10=2.86 1 6336-6348' H Orculation Tbg. Perfs, 4-holes, l' In tv .1 e 1 f" 8128' -i GUIB. PBR 1 8151' -i 9-5/8" GUIB. POLA R PKR 8193' -i 4-112" 011S 'X' NIP, 10=3.813 I TOP OF 7" LNER l-i 8213' .. . " 8224' -1 4-1/2" 011S 'XN' NIp, 10=3.725 8224' -1 REDUCING NIP, D=2.313 ~ 8249' -1 ELMO 1 14-112" llPPE, 12.6#, L-80, .01522 bpf, 10=3.958 I~ 8256' 1 ~ 8256' -1 4-1/2" TIL, VVLEG I 9-518" CSG, 47#, L-80, 10=8.681 I~ 8713' ~ t.. ÆRFORA TON SUIVMARY REF LOG: SWS-BHCS-5/29179 ANGLE AT TOP PERF: 16@ 9225' Note: Refer to Production OB for historical perf data SIZE SPF NTERVAL Opn/Sqz OAlE 2-1/8 6 9225' -9240' 0 02/02/96 2-1/8 6 9250' -9270' 0 01/14/96 3-3/8 4 9270'-9280' S 02/24/94 3-3/8 4 9290'-9300' 0 09/09/94 3 1/8 4 9300'-9330' 0 08120/79 2-1/8 4 9320'-9330' 0 11/04/94 2-1/8 4 9340'-9350' 0 11/04/96 3 1/8 4 9340'-9386' 0 08120/79 3-3/8 4 9386'-9400' 0 11/26/92 I PBTO 1-1 7" LNR, 29#, L-80, .0371 bpf, 10=6.184 l-i 9734' 9738' OATE 6/3/1979 12/5/2000 12/07/00 02/17/01 REV BY ORIGINAL COM='LEfION SIS-SL T COM/ERTED TO CANVAS SIS-JLH REVISEO JKltp CORRECTIONS , I I 9011' -i I\ILA.RKERJOINT I I " ~ ~ I ~ 9614' H FISHING NECK I 9626' H BA KER IBP I COMM:NfS PRUDHOE BA Y UNIT 'NELL: 8-15 PERM If No: 79-019 AA No: 50-029-20360-00 See. 31, 11 N, 14E BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION 'COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate__ Plugging__ Pull tubing .__ Alter casing __ Repair well __ Perforate X Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1520' SNL, 1606' WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 575' SNL, 3322' WEL, SEC. 31, T11N, R14E, UPM At effective depth 413' SNL, 3419' WEL, SEC. 31, T11N, R14E, UPM At total depth 392' SNL, 3431' WEL, SEC. 31, T11N, R14E, UPM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 63. 71 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-15 (21-31-11-14) PBU 9. Permit numbedapproval number 79-19 / 10. APl number 50- 029-20360 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9738 feet BKB 9346 feet 9646 feet BKB 9257 feet Plugs (measured) Junk (measured) fi//at 9646' MD (11/89) Casing Length Structural -- Conductor 110 Surface 2623 Intermediate 8686 Production -- Liner 1587 Perforation depth: measured Size Cemented Measured depth True vertical depth BKB 20 x 30 472 c.f. 137 137 13 3/8 5436 c.f. 2650 2650 9 5/8 1317 c.f. 8713 8362 7 456 c.f. 8151-9738 7819-9346 9270' - 9280', 9290' - 9330', 9340'"9386',9386'"9400' Bridge P lug @9331' Sqz 9270'-9280' true vertical subsea 8832'- 8957' (five intervals) Tubing (size, grade, and measured depth) 7" L-80 to 8151' with 4 1/2" tailpipe to 8256' Packers and SSSV (type and measured depth) 9 5/8" Guiberson Polar packer at 8151 '; 4 1/2" SSSV & insert at 1997' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 81 789 1533 2530 554~~'' 11214 4580 1600 Tubing Pressure 185 249 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well~ Oil X Gas Suspended 17. I'"~er~,J~if"~'th~he fo/egOing is true and c,e~ect t~'h~'best of-~y k'~'owledge.-~---- Signe'~d"~,~,~,.,.?~//~'~,~ ~/~/~~ Title Technica/Assistantlll Form 10-404'Rev 061:15/88 ~" .... Service Date SUBMIT IN D~/UP~,C~ 1/14/96 2/02/96 WELL B-15 (21-31-11-14) Addperf The following additional interval were perforated using guns, 6 SPF, random orientation and 0° phasing. 9250- 9270 MD' The following additional interval were perforated using guns, 6 SPF, Low side orientation and 0° phasing. 2 1/8" 2 1/8" 9225- 9240 MD' LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 January 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL · 70- q.5 -o # DESCRIPTION 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF ! PFC/PERF FINAL BL+RF 1 PLS FINAL BL+RF ! PFC/PERF FINAL BL+RF ECC No. Run # 1 3562.02 Run # 1 4060.05 Run # 1 5798.13 Run # 1 5852.03 Run # 1 6560.01 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage AK 99518 Received by: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE Date: RE: 6 December 1995 Transmittal of Data ECC #: 5798.12 ANCHORAGE Sent by: HAND CARRY AK, 99501. Data: PDK Dear Sir/Madam, Reference: BP B-15 (21-13-11-14) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS 'Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 ' Anchorage, AK 9951.8 Or F~ to (907) 563-7803 Received LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 5 December 1995 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION ! PFC/PERF FINAL BL+RF 1 CN FINAL BL+RF 1 PLS FINAL BL+RF 1 PDK FINAL BL+RF 1CN FINAL BL+RF 1 PDK FINAL BL+RF Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 4313.06 5603.08 5753.05 5798.12 5931.08 6503.02 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201- Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by-~/ ~_.~ ~ J/~ Date: LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 29 December 1994 Transmittal of Data Sent by: MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 CCL FINAL BL+RF 1 PLS-STATIC FNL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 CCL/PERF FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF Run # 1 Run # 1 Run # 1 Run ~ 1 Run # 1 Run ~ 1 Run # 1 Run ~ 1 ECC No. 2012.04 4040.01 4600.02 5798.11 5972.01 6170.08 6170.07 6287.01 Atlas ~b~l~e Services 5 oo ~ /~chorage, AK 99518 (v/~ O~// F~ to~(907) 563-7803 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 November 1994 RE: Transmittal of Data Sent by: COURIER Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION F-05 (14-36-12-13) 1 PFC/GR FINAL BL 1 PFC/GR RF SEPIA 1 PFC/GR FINAL BL 1 PFC/GR RF SEPIA 1 PFC/GR FINAL BL i PFC/GR ~F SEPIA 1 PFC/GR FINAL BL 1 PFC/GR RF SEPIA 1 PFC/GR/CCL FINAL BL 1 PFC/GR/CCL RF SEPIA 1 CCL/PFC FINAL BL 1 CCL/PFC RF SEPIA 1 CN/GR CH FINAL BL 1 CN/GR CH RF SEPIA Run # 1 Run ~ 1 Run' # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 ECC No. 2577.04 4544.01 4547.01 5157.07 5659.03 5798.10 5850.03 P~==o= ~zgn and re~Li-~% tv. ALI=~ wir=li,~= ~ervi~ 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received b , , c ~ ' STATE OF ALASKA ALA,C~- OIL AND GAS CONSERVATION COMMISSIC-- REPORT (.,,; SUNDRY WELL OPE, .ATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well __ Perforate Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1520' SNL, 1606' WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 575' SNL, 3322' WEL, SEC. 31, T11N, R14E, UPM At effective depth 413'SNL, 3419' WEL, SEC. 31, T11N, R14E, UPM At total depth 392' SNL, 3431' WEL, SEC. 31, T11N, R14E, UPM 5. Type of Well: Development Exploratory Stratigraphic Sewice 6. Datum elevation (DF or KB) KBE= 63. 71 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-15 (21-31-11-14) PBU 9. Permit number/approval number 79-19 / 10. APl number 50- 029-20360 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2623 Intermediate 8686 Production -- Liner 1587 Perforation depth: measured 9738 feet BKB 9346 feet 9646 feet BKB 9257 feet Plugs (measured) Junk (measured) fill at 9646' MD (11/89) Size Cemented Measured depth True vertical depth BKB 20 x 30 472 c.f. 137 137 13 3/8 5436 c.f. 2650 2650 9 5/8 1317 c.f. 8713 8362 7 456 c.f. 8151-9738 7819-9346 9270' - 9280', 9290' - 9330', 9340'-9386',9386'-9400' Bridge P lug @ 9331' Sqz 9270'-9280' true vertical subsea 8832'- 8957' (five intervals) Tubing (size, grade, and measured depth) 7" L-80 to 8151' with 4 1/2" tailpipe to 8256' Packers and SSSV (type and measured depth) 9 5/8" Guiberson Polar packer at 8151'; 4 1/2" SSSV & insert at 1997' 13. Stimulation or cement squeeze summary See Attachment ~ 14. Intervals treated (measured) 0CT 1 4 1994 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. Commission Representative Daily Average Production or Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure SI .... . 260--d~'' 2813 323 1700 202 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby c, ertify that the foregoi~ is true and correct to the best of my knowledge. Signed (~ /t42,~~~ ;~1/~ Title Senior Technica/Assistantl Form 10-404"~Rev 06/15/88 / Date SUBMIT IN DUt~LI~ATE ,~------__~-~' 2/09/94 2/20/94 7/14/94 WELL B-15(21-31-11-14) Added Perforation/NRWO The following added interval were perforated using 3 3/8" guns, 4 SPF, random orientation and 60°/120° phasing. 9290'-9300'MD The following added interval were perforated using 3 3/8" guns, 4 SPF, random orientation and 60° phasing. 9270'-9280'MD A Maraseal GSO Squeeze was performed using the following fluids: 927O - 9280' MD SUMMARY Attempted to kill the well; however, the well was taking water. Attempted to spot diesel and u-tube it around the 9 5/8 annulus but it would not u-tube. RIH with packer and set it at 9284 ft (center rubber). Bullheaded 25 barrels of water and 60 barrels of diesel down the 9 5/8 annulus while pumping 120 barrels cool down. Switched to maraseal on the fly. Saw good pressure increase. Reduced the injection rate to 1.0 BPM and ultimately 0.5 BPM. Max. pressure was 1100 psi. Allowed 3 barrels to lay in the casing. Waited on the surface sample to set in temp bath. Never set. Tried to release the packer and it was stuck. Could not circulate either. Eventually, cycling 4500 psi on the coil allowed circulation. The packer was free shortly there after. POOH. Packer was recovered in tact. 7/18/94 FLUIDS PUMPED BBLS. DESCRIFrION 217 diesel. 906 filtered seawater 120 4% maraseal A Tubing Patch was set across tubing perforation at 3591'- 3619' I 'ECEIVED 0CT ] 4 1994 Alaska Oil & Gas Cons. Commission Anchora~,e ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99,501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 10, 1994 Jerry Bixby/Steve Farris Wireline/Completion Supervisors BP Exploration (Alaska), Inc P O Box 196612 Anchorage, AK 99519-6612 Re: No-Flow Verification BPX PBU Wells #B-15 and B-34 PTD 79-019 and 93-037 Dear Mr. Bixby/Farris: On July 28, our Inspector John Spaulding witnessed no-flow tests on BPX's PBU wells B-15 (PTD 79-019) and B-34 (PTD 93-037). The wells were opened up to the atmospheric tank and were allowed to flow for 3 or 4 hours; neither well showed any fluid buildup. The wells were shut in for a 2-hour buildup; B-15 showed 20 psi and B-34 zero. The wells were then put through the gas meter - they showed zero flow on the meter. The Inspector concluded that wells B-15 and B-34 were not capable of unassisted flow of hydrocarbons. The Commission hereby authorizes removal of the subsurface safety valve from BPX's PBU wells B-15 (PTD 79-019) B-34 (PTD 93-037) on the condition that the low-pressure sensor and surface safety valve must be maintained in good condition and, if for any reason, either well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be reinstalled and maintained in good working condition. Sincerely, Blair E. W~~ PI Supervisor bew/nlpb2bws MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Jo~ Chairma~ Blair Wondzell, ~.O~ P. I. Supervisor 9/31~.g~r~ZC' FROM: John Spaulding~7~ SUBJECT: Petroleum Inspector DATE: July 28, 1994 FILE NO: 9HgLG2BD.doc "No Flow" Test BPX PBU Wells B-15&34 Prudhoe Oil Pool Thursday July 28. 1,994: I traveled to BPX PBU wells B-15&34 to witness "No Flow" tests. Both wells were opened up to atmospheric tanks and allowed to flow for 3 to 4 hours, neither one showed any fluid buildup. The wells were shut in for 2 hours to allow for a pressure buildup. Well B-15 showed 20 psig on the 0-200 gauge, well B-34 showed 0 psig on the 0-200 gauge. Both wells were then opened up to the American gas meter. Well B-15 ~ (t ---(..~ ~. Well B-34 ~'¢- O L~ ~' Test 1 -- 120 scf/hr - 0ps'ig Test 1 -- 0 scf/hr -- 0psig Test 2 -- 120 scf/hr -0psig Test 2 -- 0 scf/hr -- 0psig Test 3 -- 120, scf/hr -- 0psig Test 3 -- 0 scf/hr -- 0psig The tests were conducted over a 1 hour period. A slight amount of gas pressure could be felt on the hand during these tests. Well B-15 in the past was given a "no flow" certification and recently received a cement squeeze of the perforations, Summary: I recommend that the AOGCC consider BPX PBU wells B-15 and B-34 for "No Flow" status. ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 20 July 1994 Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL Z-05 s-19 ~--[\7_~ B-23 B-22 (32-32-11-14) B-15 (21-13-11-14) DESCRIPTION /N/GR FINAL SL CN/GR FIN RF SEPIA CN/GR FINAL BL /T CN/GR FINAL BL CN/GR FINAL RF SEPIA ~,-~N/GR FINAL BL CN/GR FINAL RF SEPIA /CCL PATCHST FINL. BL CCL PATCHST RF SEPIA ECC No. Run # 1 5806.02 Run # 1 Run # 1 ~317.01 Run # 1 Run # 1 5808.03 Run # 1 Run # 1 Run # 1 1423.06 Run # 1 5798.09 Run # 1 Please sign and return to: Atlas Wireline-Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: ~ ~~ Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by Date: '~nc/~°ra£~e C°r~rniSs/or~ Date ALASKA OIL & GAS coNSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 23 June 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION /1 PLS INJPROF.FINAL BL 1PLS INJPROF.RF SEPIA ECC No. Run ~ 1 5754.01 Run # 1 /t PLS FINAL BL ! PLS FINAL RF SEPIA Run # 1 5.825.01 Run # 1 N-O1 (13-08-11-13) /! PLS PRESURE FINAL BL ! PLS PRESURE RF SEPIA Run ~ 1 4060.02 Run # 1 F-14 (33-35-12-13) /~ PLS PROF. FINAL BL ! PLS PROF. RF SEPIA Run ~ 1 959.08 Run ~ 1 B-15 (21-13-11-14) !PLS PRESURE FINAL BL PLS PRESURE RF SEPIA Run # 1 5798.08 Run # 1 / PFC/PERF FINAL BL ! PFC/PERF RF SEPIA Run # 1 4887.05 Run ~ 1 COLLAR CHEM.FINAL BL COLLAR CHEM.RF SEPIA Run # 1 5957.03 Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson '~'Chorage C°rnrnissior~ Date: Please sign and return to: Petrotechnical Data Center BP Exploration (Alaska) Inc 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Received by ALASKA OIL AND GAS CONSERVATION COMMISSION · WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 June 22, 1994 Steve Farris/Jerry Bixby Wireline/Completion Supervisors BP Exploration (Alaska), Inc ? O Box 196612 Anchorage, AK 99519-6612 Re: No-Flow Verification BPX PBU Well #B-15 Dear Mr. Farris: As you requested, on .April 16, 1994, our Inspector John Spaulding witnessed a no-flow test on BPX's PBU well B-15 (PTD 79-019). The well was opened up to the atmospheric tank and was allowed to flow for three hours; no fluids were produced. The well was shut in for a 2-hour build-up; there was no reading on the 0 to 60 psi gauge, though a light gas pressure could be felt on the hand. The Inspector concluded that well B-19 was not capable of unassisted flow of hydrocarbons. The Commission hereby authorizes removal of the subsurface safety valve from BPX's PBU well B-15 (?TD 79-019) on the condition that the low- pressure sensor and surface safety valve must be maintained in good condition and, if for any reason, the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be reinstalled and maintained in good working condition. Notice: this "no-flow" certification for PBU B-15 voids the "no-flow" certification of June 15, 1994 for PBU B-14, PTD 78-093, (the correct well was B-15). Sincerely, Blair E. Wondz~l PI Supervisor hew/n fpbubl 5 RECEIVED MAY 1 0 1994 Alaska Oil & Gas Cons. Commission Anchorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 3 May 1994 RE: Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION X-29 (21-12-10-13) (21-12-10-13) ~9-~0~ B-28 (32-29-11-14) Jl SBT/GR FINAL BL 1 SBT/GR RF SEPIA /1' PFC/PERF FINAL BL ! PFC/PERF RF SEPIA / ~i PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA B-15 (21-13-11-14) B-29 (32-31-11-14) ~ 1 ~CL/PERF FINAL BL 1 CCL/PERF RF SEPIA ~1 CN/GR FINAL BL 1 CN/GR FINAL RF SEPIA ECC No. Run # 1 6139.02 Run # 1 Run # 1 6139.03 Run # 1 Run ~ 1 3771.03 Run ~ 1 Run # 1 5798.07 Run # 1 Run # 1 5818.03 Run # 1 Please sign and return to: Atlas Wireline Services .5600 B Street Suite 201 Anchorage, AK 99518 Attn..Rodney D. Paulson Received by: Date: Please sign and return to: Sonya Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 13 April 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~-~ B-17 (43-25-11-13) ~)...--'lc~O H-17 (34-15-11-13) ~-~ Y-14 (44-33-11-13) ~7--[[8 G-30 (12-07-11-14) ~-~ W-37 (24-21-11-12) Cont/ # DESCRIPTION 1 PFC/GR FINAL BL ,-'1 PFC/GR RF SEPIA 1 PFC/PERF FINAL BL' --! PFC/PERF RF SEPIA 1PFC/GR FINAL BL /1 PFC/GR RF SEPIA 1 GR/CCL FINAL BL GR/CCL RF SEPIA 1 PFC/PERF FINAL BL -~'~PFC/PERF RF SEPIA 1 PFC/GR/CCL FINAL BL /1 PFC/GR/CCL RF SEPIA 1 CN/GR FINAL BL' -T CN/GR FINAL RF SEPIA '1 CN/GR FINAL BL /1 CN/GR FINAL RF SEPIA 1 CN/GR FINAL BL -/f CN/GR FINAL RF SEPIA 1 CN/GR FINAL BL //1 CN/GR FINAL RF SEPIA ECC No. Run # 1 5041.01 Run # 1 Run # 1 992.08 Run # 1 Run ~ 1 5798.06 Run # 1 Run # 1 6157.00 Run # 1 Run ~ 1 5665.04 Run # 1 Run # 1 3539.01 Run # 1 Run # 1 5978.01 ~ Run # 1 Run Run ~ 1 4735.02 Run # 1 3583.02 Run # 1 Run # 1 Run # 1 5010.02 -! ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 17 March 1994 RE: Transmittal of Data ECC #: 5798.05 Data: PL Dear Sir/Madam, Reference: BP B-15 (21-13-11-14) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL PFC/GR/CCL FINAL BL PFC/GR/CCL RF SEPIA Run # 1 Run # 1 Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received by: Date: RECEIVE,D Alaska Oil & Sas Cons. Commission Anchorage BP EXPLORA3'ION Memorlndum To: M.A. Townsend/E.J. Walker Date: March 14, 1994 P.B. Production,.~.,ngineer.~_g Supervisor L. SeymOur W.F./MI Fiood'Supervisor From: Subject: B-15 Tubing Circulating Punches Please shoot two sets of tubing circulating holes in B-15 at 3600' and 6750' MD (avoiding collars) using Atlas tubing punchers and charges. Each set should include 4 shots using 4 spf density. The goal of this operation-is to temporary PBGL the well. This will be a temporary arrangement while waiting on the arr!val of Alpha tubing patches with GLMs. B-15 has a conventional L-80 completion with 7" tubing, 7" liner, and 4.5" tailpipe, with a minimum restriction of 3.725" at the XN nipple. The well ceased production after a temporary SI two months ago. its anticipated that the formation gas cone has healed and the near wellbore pressure has stabilized to that of the formation. Its not economically feasible to keep lifting the well using N2 due to the required time and the associated expense. If you have any questions or comments, please contact Majdolin Hanna at Anchorage extension 4377 or 338 - 4625 at home. LS/MFH/mfh m¢~ CO w/a: Well File NS RE NS CE K. Humphrey J. lsby F. McCorkle R. Narayanam A~ska Uli & (;as Cons. Co1111~llsslon Anchorage "-' STATE OF ALASKA --' ~/- ' AL .(AOIL AND GAS CONSERVATION COMMIS ,q ~ ?) APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation Shutdown Re-enter suspended well__ ( '>/.,,~ I Alter casin--g __ Repairw--~ell . Plugging__--Timeextension__ Stimulate__ "/,,///~'~.,I Change approved program Pull tubing _ __ Variance X Perforate _ __ Other_ _ ,~ ~ ,, ~ 5. Type of Well: 6. Datum elevation (DF or KB) '~ ,r(/ I Development X KBE = 63.71 AMSL fe'~t I Exploratory __ ; 1. Type of Request: 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address Stratigraphic 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1520'SNL, 1606' WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 575' SNL, 3322' WEL, SEC. 31, T11N, R14E, UPM At effective depth 413' SNL, 3419' WEL, SEC. 31, T11N, R14E, UPM At total depth 392'SNL, 3431' WEL, SEC. 31, T11N, R14E, UPM Service RECEIVED MAR 2. 5 1994 Oil & Gas Cons. Commission Anchorage Prudhoe Bay Unit 8. Well number B-15 (21-31-11-14) PBU 9. Permit number 79-19 10. APl number 50- 029-20360 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9738 feet BKB 9346 feet 9646 feet BKB 9257 feet Plugs (measured) Junk (measured) fill at 9646' MD (11/89) Casing Length Structural -- Conductor 110 Surface 2623 Intermediate 8686 Production -- Liner 1587 Perforation depth: measured Size Cemented Measured depth 137 2650 8713 20 x 30 472 c.f. 13 3/8 5436 c.f. 95/8 1317c. f. 7 456 c.f. 8151-9738 9270'- 9280', 9290'- 9330', Bridge P lug @9331',9340'- 9400' True vertical depth BKB 137 2650 8362 7819-9346 true vertical subsea 8832' - 8957' (five intervals) Tubing (size, grade, and measured depth) 7"L-80 to 8151' with 4 1/2" tailpipe to 8256' Packers and SSSV (type and measured depth) 9 5/8" Guiberson Polar packer at 8151'; 4 1/2" SSSV & insert at 1997' 13. Attachments Description summary of proposal X Detailed operations program ~ BOP sketch __ 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby c~rtify that the foregoing is true and correct to the best of my knowledge. Signed Title Supervisor Waterflood/Miscible Flood FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness J Approval No. ?,¢/_~'"'-- Plug integrity ~ BOP Test __ Location clearance __. _, .,----~lechanical Integrity Test Subsequent form required 10- /~ d/;,.- i '- Ap prov~b?order o ~/t~'e Commission ~ ~l~lg~~ ~ ~ Form 10-403 Rev 06/15/88 DaVj~ W. Johnston X (~ommissioner Date L./,//./,~ V Approved Copy SUBMIT IN TRIPLICATE Returned , RECEIVED MAR 2 5 1994 Ai~ska Oil & Gas Cons. Commisslon Anchorage ii i i i i iiii i i i i WELLHEAD: McEVOY " BF. ELEV - 37.18' , ACTUATOR: OTIS ~'"- 7' SSSV LANDING.NIPPLE J O (C)TIS w/INSERT)(3.813' ID)1997'1 FOC-- J~ I~ wo/INSER'I')(5.962'ID) 13-3/8'. 721/tt, ~ _ j L-80, BTRS I ~-u~u ! I KOP: 2900' MAX ANGLE: 25' @ F..,300' ! 7'. 264!/tt. L-80. AB/LI4S TUBING TUBING ID: 6.276" CAPACITY: .0382 BIBL/FT i " " (POLAR) ( 'ID) (OTIS) (3.725' ID) 18224'11 L-80, BTRS I 8713' J-- a iN (MULESHOE WLEG ) (ELUm I 824g'1 MARKER JOINT PE!~FORAT1ON SL MMARY _ R_=F LOG: SWS~B.CS- . 3,3/8' 4 9290 - 9300' Open 2-9-94 3 lt8' 9300 - 9330' OPEN/$-20-7.~ · 9340 9386' ' ' 3-3/8 4 938& - 9400' Op. eh/11.26/92 _ ~-.~ ,T, BAKER INFLATABLE PACKER SET AT 9,337 FT ~-~/~ ~ ~'Z~.~- c~50 ~,,,, z/?cl?'-tF---~ ~ CC RUBBER ELEMENT. FISHING NECK AT: 9,331 FI' ELECTRICALLY DISCONNNECTED PBTD I _q7~; J ' ,,- ~ .;,;;;;;,_'.,; I i 7'. ~.. L-~0. BT,S , ,, ~, , ,, , ,, , , , DATE REV. BY CO~ENTS PRUDHOE BAY UNIT ~-~-~_ ~'.'n~,L COU~'I_~C~N' . . . WELL: B-15 (21-31-11-14) A. TE~. PL,~ O~ u^c APl NO: ............... ~1~:' c. no~,~so~ A~ .~s .,~ 11N ' RGE 14E 1-07-,~ .... M. CLEARY i' BRIDGE P'LUS "' ,, ........ ~-~-~" HU~s~ ~ ~o~,~,,~ ..... BP Exploration (Alaska) ....... _ RECEIVED MAR 2 5 1994 0il & Gas Cons. Coll/~liSSlOn ~chorage ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 9950.1. USA Date: 24 January 1994 RE: Transmittal of Data ECC #: 5798.03 Data: PL Dear Sir/Madam, Reference: BP . B-15 (21-13-11-14) PRUDHOE BAY ~'~ l NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 1 Sent by U.S. MAIL PLS STAT. FINAL BL PLS STAT. FINAL RF Run # 1 Run # 1 Received by: Date: Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson RECEIVED Oil & Gas.Cans. ,Commi.s~i~ ,~ Anchora..~ ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 25 January 1994 RE: Transmittal of Data ECC #: 5798.04 Data: NONE Dear Sir/Madam, Reference: BP B-15 (21-13-11-14) PRUDHOE BAY NORTH SLOPE, AK Enclosed, p!saze find the data as described below: Prints/Films: Sent by U.S. MAIL COLLAR LOG FINAL BL COLLAR LOG FINAL RF Run # 1 Run # 1 Received by: Date: -Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson / ~ RECEIVED BP EXPLORATION BP Exploration (Alaska) inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 09/13/93 T# 85001 BPX/PBU 0TAPES W/LISTINGS Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) X-03 CH/CNL 11386.00-12000.00 API#500292040500 B-15 CH/CNL 8775.00- 9645.00 API#500292036000 M-18B CH/PDK-100 8852.00- 9420.00 API#500292085502 FIN 08/08/93 # 1600BPI 9464->TP# FIN 1600BPI 9465->TP~ FIN 1600BPI 9466->TP# 08/16/93 08/19/93 # Information Control Well Records If you have any 564-4004. ATLAS REF#5787.01 ATLAS REF#5798.02 ATLAS REF#5957.02 SEP 2. 0 199,5 ~aska-Oi[ & Gas GoDs, CommissioD Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 08/25/93 T# 84939 BPX/PBU~LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. B-157~l¢~ CNL[ C-32'~(~"5,'~ PDK-100~'~31~ ~~/20/93 G-04 ~~ ~LEAK~E~/F~TEMP 08/17/93 M_06AqS~ERF) ~~ 08/17/93 M-18Bq%-Sq PDK-100 ~e~~/19/93 ~-:'~0~ (~RF39~~~ 08/~9/93 Z-05~O~ ~PERFJ ~/~ 08/18/93 z-0790~57 C~ 08/16/93 #1 #1 #1 #1 #1 #1 #! #1 #1 08/18/93 #1 8800.00- 9645.00 ATLAS 5 " 9850.00-10313.00 ATLAS 5 " 9700.00-10425.00 ATLAS 5 " 200.00-10303.00 ATLAS 2/5" 11130.00-11600.00 ATLAS 5 " 8900.00- 9400.00 ATLAS 5 " 11350.00-11700'.00 ATLAS 5 " 10510.00-10830.00 ATLAS 5 " 9620.00-10050.00 ATLAS 5 " 11670.00-11954.00 ATLAS 5 " Information Control Well Records STATE OF ALASKA "' ' OIL AND GAS CONSERVATION COMMIS~,..~N REP OF SUNDRY WELL OPERATIONS Stimulate X Plugging Perforate X "l Pull tubing Alter casing Repair well Other 1. Operations performed: Operation shutdown __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1520' SNL, 1606' WEL, SEC. 31, T11N, R14E, UPM At top of productive interval 575' SNL, 3322'WEL, SEC. 31, T11N, R14E, UPM At effective depth 413' SNL, 3419' WEL, SEC. 31, T11N, R 14E, UPM At total depth 392' SNL, 3431' WEL, SEC. 31, T11N, R14E, UPM 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) ~ ?//I KBE = 63.71 AMSL f~ '~,. ~ 7. Unit or Property name Prudhoe Bay Unit 8. Well number B-15 (21-31-11-14) PBU 9. Permit number/approval number 79-19 / 10. APl number 50- 029-20360 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 2623 Intermediate 8686 Production -- Liner 1587 Perforation depth: measured 9738 feet BKB 9346 feet 9646 feet BKB 9257 feet Size Plugs (measured) Junk (measured) Cemented 20 x 30 472 c.f. 13 3/8 5436 c. f 95/8 1317c. f. 7 456 c.f. 9300'- 9330', 9340'- 9386' fill at 9646' MD (11/89) Measured depth 137 2650 8713 8151-9738 True vertical depth BKB 137 2650 8362 7819-9346 true vertical subsea 8861 '-8944' (two intervals) Tubing (size, grade, and measured depth) 7" L-80 to 8151' with 4 1/2" tailpipe to 8256' Packers and SSSV (type and measured depth) 9 5/8" Guiberson Polar packer at 8151'; 4 1/2" SSSV & insert at 1997' 13. Stimulation or cement squeeze summary See Attachment ~ L. I v L ,.; Intervals treated (measured) Treatment description including volumes used and final pressure AU G 2 1993 Alask~t 0il & Gas Cons. 6omm[ss~o~ ~,pchora.qe 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1861 12857 90 0 2181 14731 133 0 Tubing Pressure 2178 2144 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby,certify that the foraging is true and correct to the best of my knowledge. Signed ~--~&,3.,~.~0~'~(//) . '~ Oj~ Title Senior TechnicalAssistantl Form 10-40~, Rev 06/15/8~ T Date ~/~/~j~ SUBMIT IN DU~LIC/ATE 11/26/92 12/02/92 fjh 12/13/92 WELL B-15(21-31-11-14) Reperf/HCL The following interval were reperforated using 3 3/8" guns, 4 SPF, 45° orientation and 90° phasing. 9386'- 9400' MD A HCL Treatment was performed using the following fluids: 145.5 bbls Filtered SW down coil into prerfs 230 bbls Filtered SW down backside 104 MSCF Nitrogen 109 bbls 15% HCL with 4% ACI-274, .4% NE-41, 24PPt Ferrotrol 210, .2% MS-10 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP/PBU ~. OGS. Enclosed is your copy of the materials listed questions, please contact BP Well Records at ~A-04~~'O~ PFC 04/07/93 #1 --~ A-23 - ~O PDK-100 04/06/93 #1 ~ A-24~-~ PFC 04/04/93 ~1 ~,~ B-07 ~,.-~' PFC 04/17/93 #1 B-15~~j~ ~ PRODUCTION LOG 04/16/93 #1 B-34~'~ PFC 04/15/93 #1 ~0C-26_~.~ PFC 04/11/93 #1 ~F D-12~~ PFC 04/12/93 #1 .~E-10 . PRODUCTION LOG 04/17/93 #1 ~\~%~-E-11~'&m~ PRODUCTION LOG 04/14/93 #1 F-I~'~~' CCL/PERF 04/06/93 #1 k~H-17 .~ PFC 04/13/93 #1 %~ H-2~ PFC 04/06/93 ~1 .~J-15 ~ LEAK DET 04/15/93 #1 ~ S-15~~ PRODUCTION LOG 04/04/93 #1 ~\'~-35,~ PFC 04/08/93 #1 ~ X-02 PRODUCTION LOG 04/16/93 #1 Y-15~~ PRODUCTION LOG 04/10/93 #1 Y-15~' PRODUCTION LOG 04/10/93 #1 DATE: 04/21/93 T# 84491 below. If you have any (907) 564-4004. 10500.00-10893.00 ATLAS 5 " 11050.00-11495.00 ATLAS 5 " 10754.00-11037.00 ATLAS 5 " 11550.00-11800.00 ATLAS 5 " 9180.00- 9450.00 ATLAS 5 " 11600.00-11950.00 ATLAS 5 " 11371.00-1].795.00 ATLAS 5 " 8700.00- 9200.00 ATLAS 5 " 11450.00-11694.00 ATLAS 5 " 10350.00-10705.00 ATLAS 5 " 9985.00-10240.00 ATLAS 5 " 10280.00-10670.00 ATLAS 5 " 9604.00- 9920.00 ATLAS 5 " 11000.00-11500.00 ATLAS 5 " 3000.00-11610.00 ATLAS 5 " 9600.00- 9900.00 ATLAS 5 " 9500.00- 9920.00 ATLAS 5 " 9930.00-10320.00 ATLAS 5 " 2200.00-10280.00 ATLAS 5 " Information Control~ 0)% Well Records [~~ ~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box lg6612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 12/04/92 T#:84147 FROM: Information Control Well Records MB3-3 SUBJECT: BP ~A~ED H~JLE LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-02 ~ o --/~3 P-16 ~?-/7 B-lS oOZ-/~ 2 A-29 ~Z.-. ~7..,- P-01 PRODUCTION LOG 28-NOV-92 #1 PRODUCTION LOG 29-NOV-92 #1 PRODUCTION LOG 29-NOV-92 #1 PRODUCTION LOG 30-NOV-92 #1 PRODUCTION LOG 28-NOV'-92 #1 11000-11380 ATLAS 10450-10676 ATLAS 9070-9454 ATLAS 10650-10940 ATLAS i 1200-11425 ATLAS Distribution: ARCO CHEVRON EXXON MOBIL PHILLIPS STATE OF ALASKA ARCHIVES A.FRANKENBURG / RECEIVED DEC 1 8 1992 Alaska 0il & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/30/92 T# 84137 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-16 ~0'/23 INJ 11/26/92 #1 A-34A~J--;mJ' PRODUCTION LOG 11/26/92 ~1 B-12 ]~-~/<PDK-100) ~/¢&G 11/27/92 #1 B-15 ~--/~ ~P ERF~ CC~ 11/26/92 #1 Y-1535.~ PRODUCTION LOG 11/27/92 #1 10470.00- 1110.00 ATLAS 5 " 8750.00- 9025.00 ATLAS 5 " 9000.00- 9400.00 ATLAS 5 " 8900.00- 9500.00 ATLAS 2/5" 9700.00-10394.00 ATLAS 5 " Information Control Well Records , RE EiVED DEC 1 8 1992 ~iaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 T° ARCO EXXON Date: 11/16/89 T#: 80597 SYSTEM. Tape & Transmittal Only ARCHIVES BP MAGNETIC LIS TAPE & LISTING Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. B-16- CH/CN/MS 4 Passes 11-01-89 #- TP# 06790 Atlas#73537 1600bpi API#50-029-20365 9500-10315 B-15 CH/CN/MS 4 Passes 11-02-89 #- TP# 06791 Atlas#4028 1600bpi API#50-029-20360 8800-10365 **ARCHIVES ONLY: Information Control Well Records LR2-1 J. Dietz/S. McCurry BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 11/07/89 Transmittal: 80569 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. ~ B-15 F-17 ~ ~-o6 ~ X-07 CNL - GR ~ 11/02/89 #1 9644-9646 Atlas 5" CNL - GR' 11/01/89 ~1 9500-10315 Atlas 5" PFC 11/01/89 #1 11008-11296 Atlas 5" CCL 11/03/89 #1 9750-10050 Atlas 5" COL 11/04/89 ~I 10730-11056 Atlas 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS RESERVO~LR--- ARCHIVES RECEIVED NOV 1 19 9 Oil.& Gas Cons,, ~missi~ Slanda,d Ala$1, a P~oductlon Company 900 East Benson Boulevard P.O. Bo~, 196612 Ant borage. Ala$1~o 99.% 19-66 (907) $64.511 I INDEXED TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA ARCHIVES STANDARD ALASKA PRODUCTION Date: 06/03/88 TI: 78897 REFERENCE: ~A~C FINAL DATA - PRESSURE SURV,.EY. DA. TA The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of thls letter and returning It to this office: A-6 05/05/88 GO Static A-10 05/05/88 .GO " .B-18 05/04/88 GO " B-15 d5/04/88 GO " U-a 05/20/88 GO " X-5 05/06/88' GO " X-14 05/05/88 GO " Y-24 05/11/88 GO " Rece I ved Date A u-;t of the o,;g;~ol S,o-do,d C~I Co,~pony Founded ;- Clevelo-d C~;n ,. Ig7~1 Jennifer Dietz INFORHAT ION CONTROL Wel I Records LR2-1 SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON TO SFO/UNIT/STATE: TE,'CACO (-Marathon) MOBIL PHILLIPS STATE OF AK BPAE 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 6/24/85 T#: 76268 REFERENCE: SO~FIO CASED HOLE FINAL LOGS ~The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office'-- B-15 CNL 5/23/85 #1 8750-9646 Sch 5" C-18 CNL 5/23/85 #1 12000-12812 Sch 5" D-15 CNL 5/19/85 #2 9750-10585 Sch 5" E-17 CNL 5/21/85 #1 10300-11147 Sch 5" R-20 EPL 2/4/85 #2 11300-11900 Sch 5" RECEIVED Victoria Aldridge LR2-1 Technical Documentation Records Management SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA SFO TELEPHONE (9071 265-0000 ARCO MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 , EXXON TO~ PHILLIPS STATE OF AK REFERENCE: SOHIO ~GNETIC ~IS T~ES i LISTINGS Date: 6/11/85 T#: 76232 The following material is being submitted herewith. Please acknowledge receipt by signing a 5~_ ~'c~- ~"'-3 z?..._ .cp, py of thi.s_ letter and returning it to this office:--. open- ~* A-35' O.H. 4/25/85 ~/1 Sch #70408 Tape Pos ~/03383 ~ · · D-15. CH-CNL 5/19/85 ~.}2 Sch ~/70450 Tape Pos.,~.~O338A ~'* C-18, CH-CNL 5/23/85 ~/1 Sch ~/70467 Tap. e Pos.~/03385 ~'- * E-10. CH-CNL 5/20/85 ~/1 Sch 070451 Tape Pos.~/03386 ~--* G-10. CH-CNL 5/22/85 ~/2 Sch ,~/70466 Tape Pos.~/03387 · C-15' CH-CNL 5/25/85 ~/2 Sch f/70464 Tape Pos.f/03388 ~- * B-15, CH-CNL 5/23/85 ~/1 Sch ~/70465 Tape Pos.,~/03389 % * E-17, CH-CNL 5/21/85 ~/1 Sch ,~/70460 Tape Pos.f/03390 ----_, ~ , H-4, CH-CNL 4/28/85 ~/2 Sch ~/70407 Tape Pos.~/03391 H-13, CH-CNL 5/27/85 ~/2 Sch ~/70478 Tap. e Pos.f/03392 '--'* D-9, CH-CI~L · 5/18/85 f/1 Sch ~/70449 Tape Pos.~/03393 ---- * H-14' CH-CNL 5/26/85 ~/2 Sch f/70477 Tape Pos.f/03394 · -- =:; A-34A O,ll. 5/28/85 ~I Sch ~L704,~ T~-p-e Pos.// '~'* A-34, O.H. 5/16/85 ~/1 Sch f/70434 Tape Pos.~/03381 ~" * H-8, CH-CNL LIS 4/28/85 ft3 Sch 1/70406 Tape Pos.f/03380 : An Asterisk (*) n~t to a listing above means you should have received the Tape(s) and Listing(s) directly from the respective semite company. Please confirm this. A'aska 0[i & Gas 6ohs- uumm 'Z~ ~- ' '~ SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON To. SFO/UNIT/STATE: GETTY (-Marathon) MOBIL PHILLIPS STATE OF AK BPAE (Transm±ttal Only) CENTRAL FILES (CC#' s-Transmittal Only) __ 2,111 'C" ANC~tORAG[, ALASKA TELEPHONE (907) 2650000 MAIl POUCH 6 612 ANCHORAGE, ALASKA 99502 Date: 7/25/83 CC#: 74591 REFERENCE: SO.H%~O CASED HOLE FINAL LOGS //~e following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- SFO/UNIT/STATE: B-8/' CNL 5/28/83 #8 8850-9775 Sch 5" B-15~ CNL 5/27/83 #2 8700-9645 Sch 5" F-3 J CNL 5/30/83 #10 10300-11195 Sch 5" Q-2~ CNL 5/14/83 #7 8600-9470 Sch 5" Y-2j TDT-M 6/5/83 #2 10100-10794 Sch 5" G-16~ ~PL 5/25/83 #1 9000-9834 Sch 5" Y-2~/EPL 6/6/83 #1 10100-10700 Sch 5" F-6p/ Tubing Cutter 5/22/83 #1 8900-9200 Sch 5" (4/82) RECEIVED Victoria Aldridge Development Geology Well Records Tp 12'5 SOttlO ALASKA PETF~OI_EUF,/t CQ;{SPANY SFO ARCO EXXON PHILLIPS STATE OF AK. CENTRAL FILES(CC#'s-Transmittal Onl_x 31 1 1 "C" L-lNl El AIJCt40~z~GL. At ASKA IFtLPHO,NL (907) 2[;5-£)000 MAIL: I'OUCH 6-612 ANCttORAGE, ALASKA 99b02 Date: 7-19-83 074579 Trans.~' cc#: Pg. 2of 2 REFERENCE: SOHIO MAGNETIC LIS TAPES & LISTINGS The following material is being submitled he~ewith.-Please ack0owledge ~eceipt copy of this letter and returning it to this office:-- by signing a ACC # RFT 6-13-83 run 1 Sch open hole tape 6-13-83 run 1 SCH TDT-M 6-5-83 run 2 Sch TDT-M 5-20-83 run 2 Sch CH CNL 5-17-83 run 1 Sch DDNI~ 5-16- 83 run - Dres open Hole tape 5-26-83 run 1 Sch CH CNL 5-19-83 run 3 Sch CH CNL 5-28-83 run 1 Sch CH CNL 5-18-83 run 3 Sch 68374 68374 68354 68322 68348 1719 68347 68313 68349 68311 *SFO & EXXON- received the Tape(s) Please confirm this. RECEIVED DATE An Asterisk:(*) next to a listing abouve means you should t~ave and Listing(s) directly from the respective service company. Development Geology Well Records SOliIO ALASKA f)E litOl, l-U;71 COMf'ANY SFO ARCO _ . I[ILI'HO:0[ lgOTI 2r'' OOOO MAIL: t'OI. JCtt 8.612 Ai'JCHDP, AGE, ALASKA 9B502 10: EXXON PHILLIPS Date: 7-19-83_ 074579 Trans.#' cc~: STATE OF AK CENTRAL FILES(CC#' s-Transmittal Onl_.y_. .F. I .._.-, T , . ,. , . I:N:j'. 1of 2 ' ~",..; / i. .... ? .... ...~, ,~'..," ...' ~L: - / /' :':', I/,,'. "' ' '" ;'" ,;i":'/' ;',~/ , .-,~.4 ,,.--,? ..,~ .~ / / --,. / .',." ./i! , ~.," u ,'."..~: :~ ..... ::, / SOHIO MAGNETIC LIS TAPES & LISTINGS The {oIlowing rnalerial is being submitled hetewith.-Please acknowledge ~eceip! by signing copy of lhis letter and returning it tothis office:-- .- ., ~ Y . -/' 1~' , .:- '~ " /?/i? ' ~' ,' ....x ..,...., .. .: L, ' : ,, · ; , ,.~, { -, ,., ,., · / -' ,. ... :' "~ i., ' ACC ,-'~ i ~ .' . ._ · / /;", i ,., >',- ,... ' "' -" -*C-10 CH CNL 6v23-83 :run 1 Sch 68405 .-~M- 4 ~T-M 5-23-83 .run 3 Sch 68324 ~*B-12 TDT-M 5-11-83 :run 2 Sch 68319 ,~*F-3 CH CNL 5-30-83 run 1 Sch 68350 ~*X-7 TDT 5-12-83 run 2 Sd 68292 - .~*F-11 ~A CNL 5-13-83 run 1 Sch 68276 -*N-6 TDT-M 5-18-83 run 3 sCh 68305 .~-~? ~*J-1 TDT-M 5-19-83 run 3 Sch 68308 ~, I"~/' , -.-*G-13 CH CN-L 5-18-83 run 1 Sch 68312 ';'X!,~ !J' -*E-18 CH CNL 6-14-83 run 1 Sch 68375 -..'."'.~'p~ .-*J-16 Ope~ Hole ?-'18-83 ~ - Go 228622 , ,~;'1;-?...w~ *¥-16 Ope~ Hole 6-21-83 ~ - GO 228610 33,,,-- ~'- i ' _.Rep!.a_~~.._t..a.pe... ? \ / .M~24 CT:em :Hole 6-9-83 run - Go 102291 · - I <r -'' J " ' (%' -/ 1,.' , - · --- - ' - ~ . . , : Z / ./ - ..~. ""/~ ~ ./! / · _., · , /. ,::: ~') - ' ' --' .] A i ' : ' " ' , · SFO & EXXOn' Aa As'te~'fsk:(~) ~e_x~ to a 11s~i~g a'Dou~e''~ea~s :you should have ~eceived the Tape(s) a~cl L~st~ng(s) d~ec~ly f~o~ ~he ~espec:iYe se~vi.ce company. PI ease confirm this. ~/~~.~~___/fT_z~_- Anne Jones ~[c[~vEl:). " ~ "/~V,~_./~,I$.j~.~ Development Geology ~s_ Well Records DATE SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHF. VRON 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (9071 265-0000 MAIL: Pouch 6-612 ANCHORAGE, ALASKA 99502 EXXON GETTY To: SFO/UNIT/STATE: (-Mar a tho n) MOBIL PHILLIPS ~. STATE OF BPAE (Transmittal O.nly) CENTRAL FILES(CC#'s-Transmittal Only)' Date: 7-22-82 Trans.#: 1754 CC#: 49754 REFERENCE: SOHIO CASED HOLE. FINAL 'LOGS " The following material is being submitted hereWith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- q-5 Continuous Flow Survey #1 6'28-82 Surf.-~q00 B-15 Continuous Flow Survey #3 6-22-82 9100-9450 B24 ContinUous Flow Survey #4 6-2i-82 10300-10625 A-6 Continuous Flow Survey #1 6-26-82 10400-11055 511 5~ 5" 5" ,/82) ~", .... , t~i! ..... Development Geology t.. 19,,;~ ,[~ DATE ~ ' ' - ~!~;~:;.;;,:~ Well Records SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company 3111 'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 SOHIO--BP ALASKA PRODUCTION DIVISION MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 12/27/79 .... , .... TO: * UNIT/SFO/STA oil & o,,. -- .3.. ~i PorcupineOri~ /r~ ~1 E ~' ,~ Ancho~'age, AI~ ~1 ~ "4 u}N G 1 REFERENCE: SOHIO WELL DATA e ; '~'~ " ~ 'TFC- following material is ~ing submi~ herewith. Please acknowl~ receipt by signing a copy of this le~er and returning it to this office:- coNFER: - COR~CTED SURVEYS/ FIEF: B-15 Bottom-Hole Pressure Data Form 11/24/79 Hewlett Packard Pressure Data 11/24/79 Carol Krieter Well Records * Please note: I will be updating my stamps with addresses after the first of the year. ~you wish to have your address corrected, please note it on this transmittal. Thank you. SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99.502 TO: STATE OF ~'~ ~,x,,r,, 12/27/79 ..... i ,.: . , ~ ...... (minus MarathonL~-~ Spinner 11/26/79 ¢/1 5" [ ,' 3 '(.'x/ [ Carol Krieter Well Records DATE 19 SOHIO PETROLEUM COMPANY Division of Sohio Natural Re~urces Company SOHIO--BP ALASKA PRODUCTION DIVISION TO: ('E O': At..A-!:A :'" O:l & C.'..st: Conser'~a~on ;',.-). cupine Drive A 'oe, Alaska 99501 Att ~. {?,. H. Hamilton REFERENCE: SOHIO WELL DATA ./ /./~e following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- CASED HOLE LOGS: G-7 EPL 11/25/79 Run 1 · . .... ~ ii/2iI~un-1 A-3 EPL 11/22/79 Run 1 J-9 CNL 11/26/79 Run 2 PRESSURE DATA G-5 G-7 /x A-3 H-8 B-15 B-2 Bottom-Hole Pressure Data Form & Survey II Il II Il II II Il Il Il I! Bottom-Hole Pressure Data Form & Survey 11/18/79 (Schlum) 11/25/79 (Hew/Packl 11/23/79 " " 11/11/79 " " 11/11/79 " " 11/24/79 " " 11/14/79 (Hew/Pac] /'." ,. :' Ca:rbl Krieter '; '~' Well Records / /-~ . . . 4'%~z ,. SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION September 10, 1979 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265:0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 ' '': Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Gentlemen: Mr. H. H. Hamilton Well B-15 (21-31-11-14) Enclosed, in duplicate, is Fom P-7, Ccmpletion Report for the above-named well along with the Well History. This well has been perforated and is on production. PRJ:ja Enclosures cc: Well File ~17 C. Tracy - Geology Yours very truly, SOHIO PETROLEUM COMPANY District Drilling Engineer Form P--7 SUBMIT IN DUPL...;TE* STATE OF ALASKA (See other structions on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELLI I DRYr--1 Other b. TYPE OF COMPLETION: NEW ~ WORK DEEP-I---I PLUG [~1 DIFF. ~ WELL~ OVER r--] EN L__J BACKI I RESER.I I Other 2. NAME Of OPERATOR SO.["!io Petro]_eum Company Division of Sohio Natural Resources Company 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 99502 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* Atsurface 1606'WEL, 1520'SNL, Sec. 31, TllN, R14E, UPM At top prod. interval reported below 3371'WEL, 495' SNL, At total depth 3431'WEL, 392' SNL, 13. DATE SPUDDED 114. DATE T.D. REACHED 5/16/79 I 5/29/79 18. TOTAL DEPTH, MD & TVD 9738 'MD 9346 ' TVD Sec. 31, TllN, R14E, UPM 5. APl NUMERICAL CODE 50-029-20360 6. LEASE DESIGNATION AND SERIAL NO. ADT, 28310 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8.UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. B-15 (21-31-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil 1. SEC., T., R., M., (BOTTOM HOLE 13OO1 OBJECTIVE) Sec. 31, TllN, R14E, UPM 12. PERMIT NO. Sec. 31, TllN, R14E, UPM 79-19 115. DATECOMP, SUSP, ORABAND. 116. ELEVATIONS (DF, RKB, RT, GR, ETC)' 117. ELEV. CASINGHEAD 8/21/79 KBE =. 63.71'AMSL 37.18 'AMSL 19. PLUG BACK MD & TVDI20. IF MULTIPLE COMPL., ! I CABLE TOOLS 9~T'~D 9291'TVD HOWMANY* 21. ROTARY TOOLSTotal,NTERVALSDR,LL~USY 23. WAS DIRECTIONAL SURVEY MADE Yes 22, PRODUCING INTERVAL(S), OF THIS COMPLETION -- TOP, BOTTOM, NAME (MD & TVD)* Prudhoe Oil Pool - Top: 9300' MD 8925' TVD Bottcm: 9386 ' MD 9007 ' TVD 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL/SP/BHCS/GR, FDC/CNL/GR/Cal 25. CASING SIZE I WEIGHT, LB/FT./ GRADE / DEPTH SET (MD) 30" x 20" Insulated qonduct~r 110' lm.3 3/8" 72~ m I~80 / 2650' 9 5/8" i47~ I L-R0 I 871 ~' 7" I 29# i I~80 18213'-9734' 26. LINER RECORD SIZE TOP (MD) I BOTTOM (MD) SACKS CEMENT* I 28. PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) 9300 ' -9330 ' BKB 0.5" @4spf (Ref. BHCS/GR, 5-29-79 9340 ' -9386 ' BKB " " " " " ,. , ,_, CASING RECORD (Report all strings set in well) HOLE SIZE I CEMENTING RECORD / AMOUNT PULLED ! 36" 472 cu, ft, Pe~afrost / 8 1/2" I 456 ~u. f~-_. Cl a.~.~ c, 27. TUBING RECORD SCREEN (MD) SIZE DEPTH SET (MD) PACKER SET (MD) 7" 8256 ' 8151 ' 29. ACID, SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 30. PRODUCTION DATE FIRST~'RODOGTION IPRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) · " 8/19/79 . ~ ii Flowinq FLOWTUBING ICASING PRESSURE JCALCULATED lOlL--BBL. GAS--MCF. PRESS. 24-HOUR R ~.~TE 31. DISPOSITION OF GAS (Sold, used for fuel, vented, etc.) ! i ]WE LI~ S?ATb~,;:(~Od uclng or ~, I shut-In) _ · ..... ~' ' ~, ,i Produclnq GAS--MCF. WATERX-BBL IGAS-OIL RATIO [ [ t~;"~v'l'''' ~ [WATER-BBL. )OIL GRAVITY-APl (CORR.) T~ST WITNESSED BY 32. LIST OF ATTACHMENTS Well History 33. I hereby certify that the~mation is coynplete and correct as determined from all available records. __ SIGNED r. '-~. td~r~Q TmTL~)istrict Drilling EQgineer *(See instructions and Spaces for Additional Data on Reverse Side) 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: 16: 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. Items 20, and 22: If this well is completed for separate production from more than one interval zone (multiple com- pletion), so state in item 20, and in item 22 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval. Item 26: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMARY OF FORMATION TESTS INCLUDING INTERVAL TESTED, PRESSURE DATA AND RECOVERIES OF OIL, GAS, WATER AND MUD 36. CORE DATA, ATTACH BRIEF DESCRIPTIONS OF LITHOLOGY, POROSITY, FRACTURES, APPARENT DIPS AND DETECTED SHOWS OF OIL, GAS OR WATER. NAME 35. GEOLOGIC MARKERS Sag River SST Shublik Ivishak MEAS. DEPTH 8863' 8892' 8973' TROE VERT. DEPTH Subsea 8443' 8470' 8548' WELL B-15 (21-31-11-14) WELL HISTORY May, 1979 Spud well at 0200 hours, May 16, 1979. Drilled 17 1/2" hole to 2681'. Ran 67 jts. 13 3/8" 72# L-80 Buttress casing to 2650'. Cemented with 5436 cu. ft. Permafrost II in 3 top jobs. Installed and tested BOPE. Tested casing to 3000 psi. Drilled out to 2711', ran leak-off test. Directionally drilled 12 1/4" hole to 8731'. Ran 225 jts. 9 5/8" 47~ L-80 Buttress casing to 8713'. Cemented in two stages: First stage with 1187 cu. ft. Class G cement; second stage through DV packer at 2607' with 130 cu. ft. Permafrost C preceded by Arct%c Pack.. Cleaned out to 8666', tested casing to 3000 psi. Drilled out to 8741', perfomed leak-off test. Directionally drilled 8 1/2" hole to 9738'. Ran open hole logs. Ran 38 jts. 7" 29~ L-80 Buttress casing liner to 9734'. Cemented with 456 cu. ft. Class G cement. Cleaned out to 9681', tested casing to 3000 psi. Displaced well to NaC1. June, 1979 Ran CBL log. Ran 200 jts. 7" 26~ L-80 AB-IJ-4S tubing to 8256'.. Landed tubing with. ball valve nipple at 1997'. Installed and tested tree. Displaced tubing to diesel. Set packer at 8151', tested tubing to 3500 psi. Ran dummy gun and gradient survey. Released rig 0200 hrs. June 3, 1979. August, 1979 Ran static t~ature survey from 4500 ft. BKB to T.D. Pressure tested tubing and inner annulus. Perforated the following intervals @ 4 s.p.f. using 3-1/8" carrier guns: 9300 - 9330 ft. BKB (30') (Ref. (BHCS/GR 5/29/79) 9340- 9386 ft. BKB (46') (" " " ) Ran static presSure/temperature,, survey @_ 8800 ft. TVD SS. Set and tested SSSV in the ball valve nipple- circa 2000 ft. BKB. Well on production. SOHIO PETROLEU~ COMPANY Division of Sohi~ Natural Resour,ces Company SOHIO--BP ALASKA PRODUCTION DIVISION August 31, 1979 ANCH©RAGE ALASKA ' (907) 265-0000 ~NCHORAG[, ~[~S~ 99502 State of Alaska Department of Natural Resources Division of Oil & Gas COnservation 3001 Porcupine Drive Anchorage, AK 99509 Attn: Mr. H. Hamilton Subject: Well~_/~5 (34-07-11-14), G-6 (44-12-11-13), B-14 (43-32-11-14), L~ Gentlemen: Please find attached in duplicate Fom 10-403, Sundry Notices and Reports on Wells and Form 10-404, Monthly Report of Drilling and V~rkover Operations for the abovementionedwells. Very truly yours, S~O PETROLEUM COMPANY GJP: ~v~Ts: ys Enclosures ' cc: M. J. Snmith A. E. Leske Drilling File Form 10-403 Submit "Intentions" in Triplicate REV. 1-10~73 & "Subsequent Reports" in Duplicate STATE OF.ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OwIELLLr~WELLGAS D OTHER NAME OF OPERATOR Sohio Petroleum Company A Division of Sohio Natural Resources Company 3. ADDRESS OF OPERATOR Pouch 6--612, Anchorage, AK 99502 4. LOCATION OF WELL At surface 1520' SNL, 1606' WEL, Sec. 31, TllN, R14E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KBE = 63.71' AMSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20360 6. LEASE DESIGNATION ANO SERIAL NO. ADL 28310 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. B-15 (21-31-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, TllN, R14E, UPM 12. PERMIT NO. 79-19 )crt, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING M U LTI PLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. The following intervals in this well were perforat~ for production @ 4 s.p.f. using 3 1/8" carrier guns. 9300- 9330 ft. BKB (30') (Ref. BHCS/GR 5/29/79) 9340- 9386 ft. BKB (46') (" " " ) This work was competed during August, 1979. A SSSV was set and tested in the ball valve nipple circa. 2000 ft. 16. I hereby certi~)lhat th~oregoi~; is true and correct TITLE District Field Engineer DATE (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side Form No. 10404 *.EV. 3-1-70 SUBMIT IN DUPLICATE STATE 0F ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NAME OF OPERATOR sohio Petroleum Company A Division of Sohio Natural Resources Company 5. APl NUMERICAL CODE 50-029-20360 6. LEASE DESIGNATION AND SERIAL NO. ADL 28310 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6-612, Anchorage, AK 99502 B-15 (21-31-11-14) 4. LOCATION OF WELL 1520' SNL, 1606' WEL, Sec. 31, TllN, R14E, UPM 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil. Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 31, TllN, R14E, UPM 12. PERMIT NO. 79-19 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. August 12, 1979 Ran static temperature survey from 4500 ft. BKB to T.D. August 19, 1979 Pressure tested tubing and inner annulus August 20/21, 1979 Perforated the following intervals @ 4 s.p.f, using 3 1/8" carrier guns. 9300 - 9330 ft. BKB (30') (Ref. BHCS/GR 5/29/79) 9340 - 9386 ft. BKB (46') (" " " ) August 25, 1979 Ran static pressure/temperature survey @ 8800 ft. TVD SS. Set and tested SSSV in the ball valve nipple circa 2000 Ft. BKB. Well on production. 14. I hereby cer~%.a~t theOand correct SIGNED. [,,A TITLE District Field Engineer DATE NOTE-Report on thi~/qorm is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. SOHIO PETROLEUM COMPANY DivisiOn of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: STATE OF AL,';,f'_ A~.'-:':<~ Oil & Gas Conservation 3~031 Porcupine Drive Anchorage, Alaska 99501 Attn; Mr. H. Hamilton -rE LEPHOIIi£ {907. ) 265-0000 MAIL: POUCH 661~ - ANCHORAGE AL~SKA S ta te/Un i August 30 REFERENCE: Well Data 'Transmission The following material is being submitted herewith. Ple,~stC~cknowledge receipt by signing a copy of this letter and returning it to this office:--J .. Logs for the following Sohio operated wells: H-8 Spinner Run 1 N-7~/ Spinner Run 1 B-13,/ Spinner Run 1 B-10 ~/Spinner Run 2 ~~Tem,p, erature RunRUn 11 ~--'~15~Z-~."'~', " Run 1 G-7' "' " Run 1 G- 6 ',~? · " Run 1 G- 5 '.'~/ " Run 1 Q- 7" " Run 1 B-11L/ HSFM Run 1 Colette Tracy SOHIO. PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION August 8, 1979.- 3111 "C"SIREE/ ] 2,-[<,r; ,~) ANCHORAGE, AI~ , /"- ~ : MAIL; ALASK':A Stat:e of Alaska DepartmeDt of Natural.Resot~ces Division of Oil & Gas Cor, servation 3001 Porcupine Drive Anchorage, Alaska 99509 Attn: Mr. H. Hamilton Subject: Wells G-5 (34-07-11-14), G-6 (44-12-1]-13) ( Gentlamen: 21-31-11-14) Please find attached in. triplicate Form 10-403, Sundry Notices and Reports on Wells for the above mentioned wells· Very truly yours, SOHIO PETROLEUM CO. · J. Plisga District Field Engineer Enclosures cc: M. J. Smith A,. E. Leske Drilling File Form 10-403 RE'V,T 1-~ 0~73 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS .(Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 2. NAME OF OPERATOR 5. APl NUMERICAL CODE 50-029-20360 6. LEASE DESIGNATION AND SERIAL NO. ADL 28310 7. IF INDIAN, ALLOTTEE OR T~IBE NAME 8. UNIT, FARM OR LEASE NAME Sohio Pe~-olet~a ~¥, Div. Sohio Natural ~so~ces C~. 3. ADDRESS OF OPERATOR Pouch 6-612, Anchoraqet Alaska 99502 4. LOCATION OF WELL At surface 1520' SNL, 1606' WEL, Sec. 31, TllN, R14E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, et~) KBE = 63.71' AMSL 14. Check Appropriate Box To Indicate Nature of Notice, Re P~ Bay Unit 19. WELL NO. ~ B-15 (21-31-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 31, TllN, R14E, UPM 12. PERMIT NO. 79-19 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER'CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF [~ REPAI RING WELL FRACTURE TREATMENTH ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTEz Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. The following intervals in this well will be perforated for production @ 4 s.p.f. 9300 - 9330 ft. BKB (30 ') (Ref. BHCS/GR 5/29/79) 9340 - 9386 ft. BKB (46') (" " " ) This work will be completed durincj August 1979. , A~ROVEDBY :' ~ ;~ .,, . CONDITIONS OF A~ROVAL, IF ANY= TITLE TITLE District Field Engineer DATE ~,"' le','~1 See Instructions On Reverse Side App.~aved" '.. c L': )? /;/umad ~ SOHtO PETF~OLEUM COMPANY Di¥ision of Sohio Natural Resourcei Company SOHIO-BP ALASKA PRODUCTION DIVISION TO: STATE OF ALASKA ¢~:~s;,,a Oil & Gas ~(~'~l Eorcupine Drive M,\!L. PQUCt~ 6-012 ANCI-IO ,r:, A? E, A L. AL; I'( A 09502 August 2, 1979 Unit/P&2/S{~a te Well Data Transmission ]-he following material is being submittcM herewith, Please acknowledge receipt by s;flning a copy of this letter and returning it to this office:-- Magnetic tapes for the fol.lowing Sohio operat,-,-i wells: C-1 Open Hole ~~i'5~,OpenHole ~55472 Run 1,2 3/29/79 #55621 Run 1 3/29/79 Well 19 SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO--BP ALASKA PRODUCTION DIVISION TO: State of Alaska Alaska Oil & Gas 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Mr. H. Hamilton 3111 "C" SI[ ~<~ :'.~ -, ;,.,',-:- MAIL: POUC H-6;~'1.2 =: ANCHORAGE, Al. iASI~ A~99§Q2 i June 27, REFERENCE: Well Data Transmission The following material is being submitt~ herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- 2'copies o'f the'fo'll'oWingdat'a: B-15 Boss Gyroscopic Directional Survey 916409 6/13/79 '!'. 'sepia 'and i' pr'int' for the 'following Sohio operated well: B-15 FDC Run 1 '~5" & 2" ~ BHCS Run 1 ~15" & 2"'~ DIL Run 1 ~5" & 2''J CNL/FDC Run 1 --5" & 2''~ CPL Run 1 v5" RECEIVED DATE Colette Tracy Well Records SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION June 28, 1979 3111 "C" ST~ ANCHORAGE, ~1 TELEPHONE (907) MAIL: POUCH ANCHORAGE, ALA~ CONFIDENT/3 FILF: Alaska Oil and Gas Conservation ConxEission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. Hoyle H. Hamilton Chairman Gentlemen: Well B-15 (21-31-11-14) Enclosed, in duplicate, is Form P-7, Completion Report for the above named well, together with the Well History, Well Logs and Directional Surveys. Sincerely yours, SOHIO PETROLEUM COMPANY District Drilling Engineer PPJ:pk Enclosures cc: Well File #17 Colette Tracy' CC ~9741 Yorm P--7 , SUBMIT IN DU .... . :ATE* STATE OF ALASKA (Seeother~.- st ructions on OIL AND GAS CONSERVATION COMMITTEE .... ~:'~' ~':~ i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* ii · la, TYPE OF WELL: OU,,,,ELL~ GASwELL [~ DRY ~-~ Other b. TYPE OF COMPLETION: NEW [~ WOIIK [~] DEEP- ~--] PLUG['--] DIFF. ['~ WELL OVER EN BACK RESVR. Other 2. NA~IE or OPERATOR Sohio Petroleum C~/~any Division of Sohio Natural Resources Compaqy 3. ADDRESS OF OPERATOR Pouch 6-612_~__Anchoraqe,...Alaska 99502 ~. LOCATION OF WELL (Rer~ort location cle~ly and in accordance with any State requirements)* ~t,u~acel606'W~L, 1520'S~L, Sec. 31, TllN, R14E, UPM At top prod. interval reported below Sag R. SST 3306'WEL, 603'SNL, Sec. 31, TllN, R14E, UPM At total depth 3431 , 392' , Sec. 31, TllN, R14E, UPM 2. ~P~ NUt'CAE coDE 50-029-20360 6. LEASE DESIGNATION A_ND SERIAL NO. ADL 28310 7. IF INDiA_N, AJkLOTTEE OR TRIBE NAME 8. UNIT,FA~/-M OR LEASE NAME Prudhoe Bay Unit (~L15.,-'( 21-31-11-14 ) 10. FLELD A2qD POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil ~l. SEC., T., ~., ~., (~o~ro~ HOL~ Pool OBJECTIVE) Sec. 31, TllN, R14E, UPM 12. PERMIT IgO. 79-19 5/16/79 I 5/29/79' ( I 6/3/79 ! KBE = 63.71'AMSL :'! 37.18'AMSL 18. TOTAL DEPTH, MD & TVD~9. PLUG, B~CK MD & TVD~. IF 1VI~LT~PLE CO1VLPL,, 21. ' :~NTERV'ALS~ ' DRILLED BY [ I I-IOW1VIANY* ROTARY TOOLS ' I CABI,E TOOLS 9738'MD 9346'TV~ 9681'MD 9291'TVD1 Total 22. PRODUCING INT~.RVAL(S), OF THIS COMPLETION--TOP, BOTTOM, NA/VIE (MD AND TVI))* ! 23. WAS DIRECTIONAL · ~ SUH. VE¥ MADE None · ! Yes 24. TY~PE ELECTRIC AND OTHER LOGS RUN ,, DIL/SP/BHCS/GR, ,FDC/CNL/GR/Cal, 2~. CASING RECORD (Report all strings set in well) CASING SIZE 1 \V.E,IGHT; LB/FT' ~ 'Glq~AD~.. J DEPTH SET (IVLD) 30" x 20" Iqulated CondectOr I ll0' ]_3 s/ il .... 1 5/8 ] 47~ ! IL-80 [ 87~3' '97" [ 29~ IL-80 I 8213'-9734 26. LINER tLR C ot~D 28. PEP~"Oi:t. ATIONS OPERq' TO PRODUC"~ON' ~Interval, size and number) HOLE SIZE 'i2 :L/4" None 30. PRODUCTION CF~A~LNTING RECOttI) ,~ /kR~OUN'F PULLED 472 cu. ft. Permafrost 5436 cu.ft. Permafrost 1187 cu. ft. Class G; 130 cu. ft. Perma- 456 cu. ft. Class G frost 27. TUBING RECOP~r) 29. ACID, Si!CT, F~CI'URE, C~IE:NT SQUEEZe, ~C. D~I I~'I'~V~ (MD) ] AMOUNC 2~D KiND OF M~'i'EPJAL ! DATE FIRST Pi%ODUCTION I :I~RoDucTION METHO~D (Flowfl~g, gas li/~, pumping--size and type of pump) [V~ELL S'FATUS (Producing or I '"' F OW, ~BING [CASCO P~S~ ]CAL~~ OIbBBL. ~ ~ ~ ~{ 'J I% ~'~y,: I ]TEST WITNESSED BY ..... 32. LIST or ATTACHMENTS Well ~s:to~, Well :~s, Directional S~eys .... 33.'I hereby certify th~e~ore~ing and attached information ,, complete and correct as determined from all-available records S~CN~D p~~~ T~TLE District Drilling ~gin~r D~T~.: _~~~-~ *(See Instructions and S~ces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed Jot subr'n~tt~ng a CO,T~plete ar'~d ccrrect v,,ell cor','~p!et~on report ar"d I09 or'~ all types of lanJs and leases ~r'~ Alaska. Item: 16: Indicate whrch elevation is used as reJerence (where riot otherwise shovvr'~) Jot depth measure- Bents given ~n ether spaces on this forn~ and ir~ any Items :20, and 22:: If this well is completed for separ4~tc production from more than one ~nterval zone (multiple completion), so state ~n ,ten~ 20, and in ~te,'~ 22 show the prc;J~/(;~r~,Q intcrv~.~l, or ~tervals, top(s), bottom(s) and name (s) (if any) for only the intervul re[)orted ir: ~ter, 30 SuhrT~t a separate report (page) on this form, adequately identified, {or each add~tior~,~l ir~te~w~l to be separately produce;~, show- ing the a~itional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool, Item 28: Submit a separate completion re~rt on this form for each interval to be separately produc~. (~e instruction for items 20 and 22 above). ........ ~4. SUMMAIiY OF' ~'ORMAq'ION TES'iiS iNC"I.UI)INC; INTI-qI'tV'AL T~$'rE~'. PtlE~S'~JRE DATA ~COVEltI~ ()F OIL GAS 3~ GD~GIC MARK~ WAT~ AND MUD NAME i a, i~ , , B~ S~sea Sag ~ver SST 8863' 8443' Sh~l~k 8892' 8470 ' Ivish~ 8973 ' 8548 ' 3~. COIIE DATA. A'I'I'ACI[ iIRIE'R D~C~[~[~ONS OP' UlTIIOLOGY, PCmOS~TY. FIIAC~RF~; AP[~T- 6iPa WELT. B-15 (21-31-11-14) WELL HISTORY 1979 Spudwe!l at 0200 hours, May 16,' 1979. Drilled 17 1/2" hole to 2681'. Ran 67 jts. 13 3/8" 725 L-80 Buttress casing to 2650'. Cemented with 5436 cu.ft. Permafrost II in 3 top jobs. Installed and tested BOPE. Tested casing to 3000 psi. Drilled out to 2711', ran leak-off test. Directionally drilled 12 1/4" hole to 8731'. Ran 225 jts. 9 5/8" 475 L-80 Buttress casing to 87].3'. Cemented in two stages: First stage with 1187 cu. ft. Class G cement; second stage thrOugh DVpacker at 2607' with 130 cu. ft. Permafrost C preceded by Arct!c Pack.~ Cleaned out to 8666', tested casing to 3000 psi. Drilled out to 8741'~ performed leak-off test. Directionally drilled 8 1/2" hole to 9738', Ran open hole logs. Ran 38 jts. 7" 29# L-80 Buttress casing liner to 9734'. Cemented with 456 cu.ft. Class G cement. Cleaned out to 9681', tested casing to 3000 psi. Displaced well to NaC1. June, ]_979 Peu~ CBL log.' Ran 200 jts. 7,' 265 L-80 AB-tJ-4S tubing t© 8256'. Landed tubing with ball valve nipple at 1997'. Installed and tested tree. Displaced tubing to diesel' · Seb~ packer at 8151', tested tubing to 3500 psi. · Ran dunv~.f gun ~nd gradient sUrVey. Released rig 0200 hrs. June 3, 1979. d. A. FouchF~ President I~. Gary P!iscia Sohio-BP, }2aska 3111 C. Street }~nchorage, .AK 99503 Re: Our ~ss G7Toscopic Survey Job No. Boss-16409 Well PPdd.hoe Bay Field North Slope, Alaska D~te of S'oa~{ey: June 13, 1979 Dear Mr. P!is¢~a: Please find enclosed the "Original" and six~een (16) copies of our Boss ~Gyroscopic Multishot Directional Survey on the above well. ~na~ you for giving us this opportunity to be of service. lb'ars very truly, SP~RY- SUIW, INC. Bob Wi h~eth District N~nager BW/kc Enclosures -~"._".,.",._,.""",~.('" '""".,---.., . ~;P£j~R-i:-$ù-Ñ-" wtLL"-' sf. Ey'i N"G-"'C<)M P'A ÑŸ-~---"" .""', , , , r ' ANCHORAGE. ALASKA '( , .",.,.-..~-"_.~~,'w,'~,.,',.,',,.,'"""'" """"""""""""""''~','.'"',,., , ,',', "-,-".,.........-..,.~._~ " " , .,,' :'."(:;\:::?:/,, AGE 1,' ~',' ,~J)H I 0 ,l~P ,I\LA,~ KA_.P'R.9P ~ÇJJ,ON,DJ V, I s l..QN"..,_.,."".~."..... ,." R-1c; CONPUTATION DATE PÞUÐHO[ Bl\y JUNE 111. 1979 AU~.KA..,."._--_..._",-_._y._. - ',---..'-'-""'-----, ,.,1, '" ,....---...... ,._.._--",..,""_..,-_..""."",,I. R U~,.,.,."...~..,-~'" ,$.~ß..~.~,r.'~_.l"..."_JJJJJJi~~~~_~.~LÇ.O,tJf{ßE,,, ,,-"-,..,....PO G,'~,~EG,,__. '-"-"-' ,IO.l~,L_""""~,~-~""",,,-,,-,';i;' '~::'/'-4¡'.~_.£~-.;..",,~~,.;,- ~fA~URED VE~TICAl VERTICAL lNCLINAT]öN' tlIRECTtON SEVEHITY k£CTANGULAR COOROINATE:S':'~VERTICAL DEPTH DEPTH OrJ'TH DEG r~lN DEGRE[S OE6/100 NORTH/SOUTH EAS1/WESTSECTIClN " ,..,l'A TE._9F,_.SURVEY .~tJ.NÇ."~,I_~.CUJjL-,,:..~ .--..... eoss GYROSCOPIC SURVEY JOR NUMRER 803S-16409 -,._-_.~.,......._K..,LLLLJi.USl:ll.&{',-... E. 1 E.v',.' . =, 63 .11 F I. .. M . , , . t~1 0";' 0' "O"O"-'-~r:~""'7' "1""7.',~,~".t 0 a" ,. N'"";,,,.:Ji, 0 c. lot ',-""'0'-0'."0' ': :""",."";,,,;;,;,,:,,';""o~o-o' "',' ., 0--'0" 'O"~),),,~,:<,,!,;:.1:;:c,,;.., '"""".......-..- " .'.,;,' ,'Wi'C/,;]"'!:'.",: ", .. .';,;",&\".u. '..;",.";,,(:/,,;ì)i,',,'. ' . '..:',,~,:::::c,,".,,::(:o.oo I~: lj ð' ~ ~ .I¡i '), ,~6 ~:g å.t?/ ',U 4 9;' ;!;;¡~~~h 89 II" . 8 3 .i \;:;:..ii:.i:,!i;I;.11 S ., . 1 s! 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' E::\~Ì-r4ë;c:{)- Mop Åtiy----'----~--'~7'~., ",. : ""t'( ,i4-i.f ,I : 1 - 2--~r~ " ".,' 't' "', :ANCHORAGE.ALASKA , ' ' ", " """""fi~' ' 1tOlf I Q ,.,B,P'..- ~L~,$ K,A_,. PJtO.oJ)ç:l1..Q.t'l,.olY~t$,J..Qy'..,:)~':;;..,:."i~i'~"L......,~-,~".~,.", '" ~.. ---, "",.~""....~.:_",.---."".....~,-~PAIE.,~..o,F..,~,,VJ~.V Ç)'~~-~tJ,~,~",..t~-!...1.9T'1;J.~:¡,~...~ 8-15 COMPUTATION DATE ~OSS GYROSCOPIC SURVEY. -', . PPUrHOE BAY JUNE 18. 1979 JO~ NUMAER BOSS-16409 S ",' " _.~b.I.J:.'].JL~lWHLtJJ:~,:: ,,63 .11..1:T_...,__--- ~. 'c'" , " ' """'>""":"'{:;',; , ,,' , " :, " ".. '",,;c',': ;"',:0,:",, ."Y'f,~,','",,' . ' ' . " " ", , "0 ," ,"'" , , \,'":',-' "':'~'~,,"':c::i;;:,::' L_~_~~,--L..- ~..1tlliE, ,c', .. ':,,:L:.sUR¥ á ~ ~ -.: dlue s t:?:: ,'.. ßítiR S r".3~.;; 'i: .' [1.0.," -U,G ~J~:':b:'2:.:rw L~.. -. ¿;;: :'<;".: , --. 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'."-"'-'~-'-"-".'sp £R,RÝ'.. $lJ N U [LL S /:' ÊY'¡ N G'.'C Õ'Mf;"Á'tj-ÿ--".""'-'-~'--'_."-"'.~w" " AN CtHJRAGE, A LASKA " < <' .........-..-(' A.GÊ--~i.-".~:~,~-' ..$q.~ TO,., 8P_,J~,~~~,~A." p~.Q!J.~LIJ,9!\L.R J..~l S.J,Q.~",."~~,...",----,.~-,,, ,.,', '-'-'-'-----"'-"'._,,~-,_._-, OA TF;...OP", s~~"y t:.Y__~'-!N,E:. . ,,1 :3.!_,J.J.J~l__.,_..,_..",.... -~. P-l~ COMPUTATION DATE BOSS GYROSCOPIC SURVEY PrJUDHD[ BAY JUNE 18, 1979 . JOB NUMR[R B05$-16409 }1 J..." $JS..A , ' -- _..,--- .. - .._KJ':.L.LY_L1USJ:U..N9__C.L t: V --= , , . 'i . ,'" " TRUtt:',;,':','þ",/"",""'.,,'SUB-S£A ,'" ,'",COURSE "" COUI~SE ,',,',.,,' DOG-LE', G:. TOTAL ", ' " , '-'-"""""""'-'-""""""""-'_.~"'-"""'-""""""""-'~"'-""'---""""""----"-".'-""""""""""""."'" ""-"""""'--""'."" """"""."""""""""""'" """"'."."",._--"'.... ",.., ..'. "", ,--, ",,"0"""" .""-",.,.,,.--.. .'.,.,...... 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H&2.79 N', '1656.75 'W' '1862.91 p100 rt~4q.40,",'A2A5.li9 ,14 '19 P-,I'I,().60 \.1,:",',,".86 881.(;9 N',,'16"3.~5'\J ',',""":lB86.A8 "'-"'" ......H,.f\Oß...... ,~(44~..R(}._.,.,_..._._,A.:5~2,.!).þ.;"~-,...:,.... ...J.(.,..."."..11_""_,,~,,,".J'!...3(). ,Q ,w .",,---~~~2.. Q9_..~,...",;,.........YO2,.,.5,1..,."N.~..:,~.;w..16.89_,!II..3.3...JJ~.,...,'~.:,~ 1.9.11....5,l.~,._--- ' ~900 AS41.64 R477.93 17 13 N 31.50 W 1.&5 926.40 N 1705.26 Y ,1937.&2 ':f'O:~O A637.:>'6 8573.55 If. 41') N 31.39 i.J .40 951.3.' N ' 17~O.53 \J':"l~163.74 _----J!.lQJt....., ..._§] 3_~_I!,.Q..ç.~_61~§..~L~.}..~~..__..__JJ->._._-~-,V_--'~j.-.~.l..~-~~ 0 _.., ,J,--~~-~....~.~.,~_,__5L7.~~.II.1t~_N ,II' ...1.7_~.5._'!.!t.2-W.., ~"~ .'-.15Ul9 .._3..Z._- '-92(n:r' ",8828.95",' 8.7b5,.241(;'.,'2~1 '. 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ALASKA," , ,~' "S.O.Hl,O,.~;,.B.P..""iALll~g.tt.QDJJ.Cll,Q1ì~.1;Y,l,$.l_QJ.t;,.~~.,.~."~,...",-;,-.;.....,,. , ,', ,-.i"."", ;.,.;,:,;.,¡"-;,.,,,,~~..;~".;....;;-,;..z.;..OAJE,--:Q.F....SU,RV,E.~t;i,JJlNt~"l,3_L.:tl~7J1::...{ , ~..,-_.,,- "'" R-l~ COMPUTATION DATE BOSS GYROSCOPIC SURVEY . PRUDHOE HAY JUNE 18, 1979 JOB NUMBER ROSS-16409 ÂL.A.s..KlL----,~~......._._...-------._.--"------- ----. ' ~. c-' . -'... -- -------, ... '---,..- .-. K.E...L ,L..l_úJJ ßJ:ll.riG_JJ.J:Y~.3..J...L.fJ...- - , ,', '.." ,. ,,;/,,' ': ,',' ,', """.," "",:",',.,<,"",",:~.>:.',',:.'.:'~~\.".'..',';:""r,",',\.:,,::',',',,:;:-\,,;::,ir~::}/,";>'i, " "<;/~:~{'..',::;; . ':" . ,,:.' ' .. " ",',', ,', ,/. ;::"",,:: ..~..;i;",.,J,,_._:,.lAU t..j..,¿,..~,.._, Su e"$£.Å;:.~~;~_lt(tUR.S.E_,...2L.;,.\c.Ou.R $.E,..........~..o.QG~,LE.G~, ~..--":'~JJ.:2L.~.;:r. a.rA. L.___- ..~~~~., ~-" u- ..- "."..~.._. ..---... MEA~UREV VERTICAL VERTICAL,;; INCLINAl'ION DIRECTION SEVERITy RECTANGULAR COORDINATES VERTICAL DEPTH DEPTH OEHTH> ';.OEG, MIN DFGRtES 0£6/100, N,OKTH1SQUTH EAST/~EST SECTION " ',,", ,/ .. >(,,: "" , ",./' , '.",' ..---~-----~" ' "",." ""<""",."",", ': ","'-,'" -~_...,............--_...__._,------~-,...~........."';""._,._-,~----------,~,;~- ~!¡." ~300 R9~4.:A3':'l:~:K;~i';:ê.tfl{)1>;~'1'~','~ ."'"'16,:"3/4 N'n30.60 t.J "';,'.,14<,W6:;tt1L1O24.55N"'17G4.67,W","',,:' 2039.15, t;-,.~r400 902o.1a,y:::-r~.:'::~',:"A957..'O;7":,':,":-:':',"ió,';'":'7 N';3tl.89,.,tJ."".':~t:'::~::..,4i1}f¡~:;;-;':'~:¡:1048.74' 1779.06 \.1"":<;""::",2..06'+.12 ~L.,.._...~...9..fj.llt) ..- - '."" ,__..,9.1.1,6.._. 8, .s~~ 9 ø.5 ,:3,. .-.1 ...~.:......~~~..lJ) -~.~~,. , ,6., -..-. -"" "L ,,3. .(1. .2,;Q,...;~t ....... "" ,,¡:,~\:L;;o;ki~:'~;.1.~;?b';¡:.;L':l,O 72.! 9.. 4.- ..N'-"-~ 1. 7..9. ~~....:lJ~~i..ij:i~;;";'r;"¡'; 2.QJ1_9._~ ,2 ,ß .---.. Qf,OO 9213.03',:{>~:"~??14~~32" ":,1~,",.40 N ,:30.20 '¡J .43' 1096.31 N 1806.95<W.;":,;'i,,!',:211384( q658 9268.,93::;,..:.9-205.22, ",', ,:',15,',,14 N 29.79 lJ' ",878 1109.70 N 1814.G8,:W;..,')/.'2127.06 '" ~~ ~_.9_3!Leu.J.;22':":f~.az._U.; i',,' ,"",i '.'.:",1t..:,',,~:~--~~2 9....] 9.._...w~-::--., ,<'..:,~.t..tt°_--'- ..l~l. 2.,7. ....9.5. ._.N~~,~li.!i5 ~', HOR110N~^L '[)ISF;:'L~'ê~'M(Nr' = :," ~1:A¿'~:~"5'::('\'FE(T ,Ar NORTH, "58"::CbËG'~',,',:' 17 MIN.' "'EST'Ar~:::'M'D;:::(:~,<,:j'~>:"97':58'::':;,:::"'" ':",',',' , """", ,", , , ' " ' , , " , ~."-"-"~"""""""'--"-""'-"'" -'.",+, .,..,-.__..._..'.._j......_,_:..~-"...,.....;...~.~:"..,-,.,:"'.....':':""".....,¡,:~~., ...--.'"' " .."~W,--....",-,,........, "._.~...;'....._,: ,.,. .." "" .. ""'.°, ..' -." ,_."..............:,.............,--.,---_..."..,............;...........'...........,,--_.._-,.._~~----- THE CALCULATION PROCEDURES' A~E BASED'ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. .;. ------------~-- " ,'--"~--'--.-"'-- , , , , , ," , , , ¡" ,:'; ":..,." ',"',," ' , "","':,', .. " , ' ...' .,::' -- ---...,... . ..- ""',, n I - ". '--:' ,. .... ~:--"~ . . " " --------- ~_.. , ', j. , 1""",-- , I ~..-- ..;~-~-~~~~;t';!J!~~t>.:; "'.~Nc~, .~, .:"'.,..'~Ë..,,.~. .. .~;= i:: . ----~.~-' ~~~,~ ,.- , .~---=::::~JðL:;~~~;.~~:!".:k')E.." - _..- ",',.' , , " ¡ (' /, " ,:'J"":::' ,'" ;-"""""'-',::":':'::,: " --------- --------:-s" !:;trÚ~' ý:-i: ~ ~~~ ~-~~~~ ~'ç ~ ~1~ ~ -lÕ'M PA NY --~-~--;--..~ ~ ","J :(\GEß1 s ,,~.P.H,1_.!L.J1..P.....J~J~.A§JtA-.~~,.P.J~.Q.PJJ.ÇJ,1.9.,~,.J!.,1.V.I~J,Q,rt~.....:,~".......,,~~:.,"... "",,' "".',.. "."....,L~....~~"",,,,~" "k'~', ttAIE:......Q£.......,s..Y.R.V..t.y~~.tUltL.l.~ ,.,~,.1~,19-,~~~... ,,_.....o;,~..>,~. ~-1~ .COMPUTA110N DATE PPIJDHOE r~^y JUNE IH, 1979 ,A L A,S KA , ..--C" .....-,.-.....".. , '~'\ ~. FT .,... . ..,.~~-,;. ...~w_..~~~,~ --~~ J NJ.~ RP'.Q.~Al.~ J2._~V~J~~»J~.$..i.:.E..QLbï,~.N... ..1, Q,lP~.; f~,t C.l.;...J¿£ .J1tll., $Jl.,!U:JJlJ1,..E.e.ltL¡~ ,..' .' , :,;,;?{:l},;;;! " , , '" ',' "';"""""""""""',',',"""'"',,,',',,,';:,',,;' ,',',':,'",i"',,-;',,','" " " " ,;':j,',ry; " ";¡'i¡i:' ',"~ ""';, ::""""....""",,-..............-, TRUE SUB-SEA TOTAL 1:t~-~ t).1iE..Il.-_-Ï.t:..fiil_Ç A..'-' V t:ltLtÇ,ßJ~ R~Ç_1A1H}J~J. ~p , C1LQ..R.D.,I.N...A-IJ:.,S-,-",-__.1JJt-:.fiO....o-' , ' 'Df:Þf:H, "bEP'fH"" 't>tPTHNOFt.'f.HlS:tJ,UTJ+" 'EASTtWE:ST OIFFLRENtE 1',:, "" , ,,' ,,' ," ""'," ,':': !"';', , ',:',' '.' """, "\,"c,'";;,.,t~""~;t;'ÙX,;{;:;'\"",,,.,,'""""", ":"'~~:'.' '~r ,/0.0,,0 """,',.' '"" ",h,3, 8' 7",l"""""';;';"',.:i":,:~,,;'.:,;(~.!;¡Jl."O, O,:"";";:~,;,¡:"..~,¡1;"""."O.,,,,OO , ._--",-"...--,,~.O"UÜ ,.~.-.._,_...,-,.'.."_"_M'_'~',",,,,- """,..." ,...,.......,_........,. "._,--,......,,_._~""~,..,,'- ~~........._,...'.'.. d'- ", -- _.~. .._.,~._--,._._. 1000999;..94 936.238.15 S 1.91 [ .ü6 .OG 2000 4:~:99. 55 1 q ~ ~5 . 8. Lt33.1Ö S . 7'3 E .. 4 5 .. 3 8 \1~.,,~, ", ----M_"__~.O,O O,-~~:~t«t,._l_~...___._..__... 2,9,215 ...lt2...._"".._"_~,::..¿,8_tL6.8-,_S_--_....;._.,, .....4 ".bJ1_f.,- ~~,____,,8_1- ,_._--,___..L4_~ \,:"":'" ~~~ ~ " ¡::~ :~~ ~:; ~: :~~{~~ g:~; ~' ;~ Ä:; ~ ~ ",', 1 ~~: ~~ ',~~ :~~J'.J1L;!Y':~"" ,,{'~\./, ;...~-_...J~O 0, O"'_M......~"~;..$Jtl.$,~,l.L.:~~,,-;~.1.f;,,2,.,,O 3, ,._..~._.~.._,".....fLt~~._~ O_..J\J.._,".,~-_... f.19 2,_,~ a ,;-W.-.- " ",. '," ~.l.,.~,~,....2,(),--_.~.,--_..7.Þ...~_3_5.,.~ """,;,"" ~;",';;:" '~', .-:a'. .. ',. 7000 6727.66 b~63.95 604.23 N 1255.35 U 272.34 H8.07 ßQOO 1671~31" 7609.~O 766.05 N 15~4.79 U 326.&9 5~.35 -__3.,Y..9_.9.,___-~,"ç, ~rJ-!.,f.J:J {!.?.7~..._~,~~..._--__.~_~Lt_!~_I_N____.l ., ?_.\J..'.._~,~~--~,. . " . ~J,2_~".7...lf. . _3._€?_~-~~ --..- "',,' 9'7.38' 9346.12,' ',,:"12,82.41 , ,-l12.7,.':~S," N, lA25.13 """",>,::,,\«:>i,"'\3c.tlebß " ,29.1,4:<,"',::":",<:,:,",':",,, , ' :", :", '," ",' """",,:,,:;:,,,,:<";',,:',',"',"", ':,~':"":,:,,:,,,~>:,,:", C') ""',"'-' ,,",":'",:': ,"','",,':, ':, .....~..I~-b, ._.Ç,~bJ~. V. L, ~l.,l.,QJ'i.-P..ß..Q- çJJ-¿ u ~~t..~- ..A,~,[_.a,A~ ~,~~ttN~Jib~,~ ~L~ f~ft~. Q..f:....,J.H. ~J.~~.....JUl1,E.N..2,lO g.. __,R ,A..P',I.,U..~,....QL.ÇYRy-A.~V_B£..~.J1E,.1H.D, Ll... ~' , ' , ", , ~ , ' [~==~~=~~~~~C' 9. ',""'.,.'",- ...........-...;..;..',.............""',. 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"";'.: ';¡';" ., " .." - -- 'j.. ~~'.." ~.; , '"' ' ---..--..,......-.-....- - :."'.. ,: ':'" . ,'" ,.' " ':':.Y:// >".< '.;;', . :",>,;-.. , , " '...., ,', 'u~ ---...;.~"""-.-... .........:....;...;.........~._--..;., 'y '" " ¡., ','~.~., 'i' '. .; ,<~ "I: '" t' ',""',' ""'N~ ,------------ -- ',' ,. ' .. .. , '" ,.,."""-"""-,,,,,"M"""""""""" ~------""--,,,'-'--'.......--'~--.... " . ..... ---""';"'-'--"--~'--~--'-'.-'--"------""-' .- .""--""'---'-'--""'~"'-'--- ~ . ---'---..... .. ,'-- ,,' "" . . . '.. '. ',,;,,""'::-¡ , .. " . , ", .-:. .r, ,'. . . ,---,-,..-.--""""-'--....':.. .........-.._"..._...,.~..,....------...........__."-;",",,_. -..'" -.. .....".-.-,--" '. ,\ :~, "'.' "" . '" "',,, ","~:/", ". '" . ;\ ,: ' . . , , ' .,.._........__.__.:._"......~~~;,;.........~~.--.';, """'~"";'" " ,~:; , , ' ',,: ~.' ',Ii'" ": "'::":'<'" ..-.............. :~::.,".......,w...,.:"._..._.,.,.....,..~._..........~..""""';';',"i"";o.,¡¡;,;;~.....~.--,-,.._.,~.._-, ,','. .. ...,¡¡....._--~. ~,_..~._.....__._-('" ---,,~_..~.._,~. "~~"-~--",-"~~_.- .._~,.- 's"Þt R ft-Y':'Š LJ r~"-~Ù~'L L:-"- $,i" ¡y'i-~j 'G"-'CÕ-M'P" Ú~ y----~-'-'-~'-_.-:', , ANCHORAGE. ALASKA " S e,.,A L AS.K,AJ~Jt QOJJ.çllQ~tJ) 1.Y.l$ ,lQ..'t~,><.12.~_..".,':~-,. ,- ",:._~_... ,~-"""",,",--..,..,,,-...~;,~~,.....,.,-,~,..ú.JJ. A,T t._~"O.F:"..S'J,B,.vJJ",..~'J.N.E_...J,]~,_:.t2.11-.:L..--_, COMPUTATION DATE " ,JUNE' lH" 197~ " , .~.( ~Ù;'~& .., " !tQ"H I 0 B-1t; PR l.I~'\HO( .ALAS-KA "."""...."., . ...-.--". JOB NUMBER AOSS-16409 KELLY BUSHING lLEV. = ,63.71 FT. '.,-....'-"'-'-":"'--"""."--"---~~--"'~ '" BAY , ~ ':', """>::'::',:,,,: "" c' ,:i:{:::::'.:,;'<' , ",::."¡¡!,,,": "", ~', , ~, -~".. .",~.,._,..~";;:....,.,.._.._,,,....;.=,~ú,:, ~~uLtt:.J\.P'O4LAJ.£.n.~,...\JilJlt$;,:J=.J1R_.E.Y. EbL".1.0Jl.....EE.t,:r"':"O.E~S..u~.si:.ALDiP.._l}f....._,..",~,-~-~--._.-~~~,..: TRUE SUB-SEA TOTAL, .&P-.S,U,E.L.u.._....__\tEJil1.C..81-~.._,~.,~ßI-LL~~J:..Ç~L~l'lJl~tLLAR--!:-Q..O..RJ2.lR~.l.E$----~_~Jt~.lV,D. ,-..-. . .-,.V,c..83_1Ç_A.~.. ,...~ ,~ .,~ ,DEPTH 'tJE:ÞTHDËPJft;.';i?"~{(\NO~THISòuttl" ";;~~,ST/WES~,,.,(JIFFE.HE.NCl CORRECTION ': :"~':,::::;,~:,;;,' ","', ' c,:,,- , ":, '." ::,.' ";,,,,~:.-- 0 , ",,'0.00 ",""", -G3,."'11','":":.',,,',,Q.OQ;'~':",Q.OO ',"""",>,~, ','~ 0.00, '""""',,. "k:"":,',:;:~.~;,~."",;<",,:,..,,,.',.;)' 163 1 (; ~ . 71 100.00" 1 ./15 r; , .2 8,W' .01;:..0 1\ ",.,"."",' < ," ~............J~.6,3..,;_......___26.,.3....,lL';'-----""p2.0JL~~O..o..;,~~~~:-_1..,J.~t....~;--. ... ~....lJL..W;,/,; , ,4!I..O..l...... '. '" ,....,-'>-0,"\:',,' " , 3(,3 3(,3.71 " .~OO.OÒ, " , ?39 S : ',", ";,'.25 It. 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""0" -.. 0.. ~- '-""".""~.""'-""'_."""~._-'-"""""~"_.:w.-~-':"~,¥-~..".__....;.-._-~"".,'J"""""""""';;"""""'~:"..J,'":,,...,,..,*....._,~, ...o_.....,..,_......-.:,-~"-._..._,,.._- """'--"'" .......~.;........-..~~":""'.....,;'-~ '"",;".;;.", ...,.............._...:......_';"'.;,.,;.,..o~....." ,-...,...., . ," ""'+'-,,_'_.',","""'_.'~'-- -~,.,_.__....._-,,~, --( ~"T------""'~":'" ~~~"--~~--.S'P'LR'RY;"šÚN-w-FtC -5 í~J l~r¡-~~ïG-è-ó~ÞÃ-NY'~~~~~- '." ,:.".,,: ,¡., , " , " , "'. ",' " , , . ,,:i' "." , ",',:,"~" ANCHORAGE, ALA:iKA, " ~~~~i_~~~~~.i~}.ï~~t~~l__~ -- ~~"~--~~" .:._----~--- -~~~~~ÞA!~,~Q~_~~ß.ï~~J~MN~,~~~.~.,¡~¡i~~~~~ . a -1 5 ' CO MPUT A T ION DATE PRUDHOt BAY JUNE 18,1979 JOB NUMBER 80SS-16~O9 ~~--.. ":; ",<, ' ' ' , ;, K [ L l Y ß lJ S H 1 N G [LEV. = 6 :5. 11 F" T . f.,~,;,;,:":"",j,..,, "',, ';", ",':;:i~:':"f;:"":r' '" , :", ~._-'-----""-----:----""~--'-';':'",':,"'"';;,:,.,',:,~,,",',',~,',~;';',~?:r":>"";:>:J/:;;',,?:,:<.;: , , :'C', ,: :\":'z.'.' , , ' ,~~,:" """,;,','",:,',.,:::',:\,:.-,:;,,' , ': ':"" , , , ,',' , , ,', "" ','" ' k:-'_""""""'::_"'."'"'~";~~-'~""""'~i~l.L...J:"rtJ:~L.U.._JtA.L.lU:s..._t_O R.,_.E,.v EN....l.D O,_,.E.E. E,.r-:,.a.E.:""s..u,.B.~.s. E A ..,..Ú[ P IH -, -_.._._---,_..--._~~,.._.... - --,- , TRUE . SYB~SEA TOTAL . .M.tA..~JJ.l\.L..Q-------y'_f. f1I.LCA~t.J...çJ.,-'----B._E..C_l.A.N_G_U.LAR....:....ÇjlQR..D..lNJtlE.~~.._J1D,.,":Iv.,D. ,_. -""."'-- . V E, RTI.CA,~' -~_.---.. " , " ' , , ' ", " " ¡DEPTH,' DEPTH :::' ",', "',DE'PJH,, "NORTH/SOUTH' ,EAST/""f..Sr::~;£.",:DI.FFEHENCE ,CORRECT1ÚN""::,',..:<:.,,,,:;:;," " ! "LIlia (;.- --- r 5 (; J . _1.1"-.,_- 7~_( L"Q, L~ __.._H 'L .,1,5. - N. --.-J 5.P f! _._~J.Ji:<' ,'. - ~ 2,2.! ~8 ,,--.- - -- IL~,l-_5 ~ "",., .:-'?,-'------"O- --- ", 1990 7663.71 . 7600,.00 16'+.61 N '1532.,49/W' 326.31' 3.93::~,i,~y«' ",8û9!' 17&3.71. 77tlÖ.'OO 179.7~) N~,.155~'ItO'" W 33Q.l-'3.85\'~",,:.':>~~(:; ,~..l.9.1~71tG.3.....1.L......-......la "',." , , " ~t.4~~~ìL..:..~3_;3_3,_._9.JL_........,_.,..;.-;...;+.Ä-3_l..fl2i"\..:";'<',, .," '" " ' , L 8301 ..,796~.11:",.::::/~;.790"O.Op", ,",:' , ~~,l.7!..,N::',:":;;\:~::,::'16:~.:l.10:"W-';....,:,,,:',:,,';' '?31.~() " ,',','::;:::::;f:::'::,::;',3.6~',",::,/:,:,':~<,,::')~:'f,::,;:,::,:i:::~:':::"~~:,::",::,,:,::<:'" , ~40i4 ,HOb3.71',': ,.'-r'"Aoon.oo ' R2x.55:'N ,:,,':,:;,:16.21.31,1,,1 ',':", 3'+1.u7 :' \:,,\:- :,: "3.40"',:,;'.r,:-" ""':';::"':' , "';':', ~.;.. ,',[¡~\nL1", ,::~,..Y163.:.11~~;"':'í~;/;:i61.' nn'~'.(qi'-~~""C"L'" "H46.11_L~'"~~_:;~~:;,:~1..64'O.:~5'3.~;.u,~,~~,,,~;-:,'~.,' 344.4ú ; ','..:,,',,:'" ..."',:",,:3.'~ :"~;:,,:,::,:"',>"<','>:;,..' ~~,.......J,.I..,!O£..","Y.....~.........._".J...,.. , ". '... .-.... .. ~JL.!._y,.'-----""'~_.'--""" ,_JL- -,._...".w_.._,-,IIJ_..._-,.., -....--..---.¥. ~ b 11 ~ 2 fj~, . ., 1 '8200 . 0 0 H 6 4 . Cj 4 N , ,,1 ';58. 7 '3 ~ .~ ~ 7 . 7 H :3 .3 H ~714 R~63.71 ,R3bo.Oo A84.51 N '1675.58 W 3~1.û( 3.28 .' ' ~,.BJ3., l..H___~!tf?.,~_!t !JJ___Jii!LQ~~_Q,~_P_,Þ..!...?JLJL_.__1Þ.,.2_~..!....~JL...~.____3,.: .'~.....,~.b .--- '. :t~d~_? , , ;:,:' 'A923 " f\56~.71"'",';:'85'OO,.O(J<,,, ,,'93:>..24 : \J,>::'-:::',",,170b'."S3 ,U", ", .:~59.4C ,'",:<"..:,::"",'-4.52,:,:""",;>",:'{,'<'<,'", f",'" "t;O27 "866:!i -/1 ,,:;:,','86'OÓ" on':;' .. 958 20 'N::,;",::,:;'::-'::':"'1-7¿'4'"..¡o ~i' , "..' .Sf. 3 93' ':,':,',"",">:';.:':"":"4' t):f~:,:":'"::>:,;'r,'(',::',,,, "', L.: ',.__~,t~..l__~_~.~~:r .9,-~,:..7,~"~~..l,,e~t9 !l,;~O Q~~~~.,._.9.8 ~.~~,I~r~tL."'<"iL:~~]~Jl.,:~.~.~_.~,' ,'~':"~i~<,,;~ ¿ ~~,:..2 f) ,,~-~,~,:::<,:~;;S~.,L.¡;,'.>~_:.3,~,j~~:~:, ~:,"::~.,::,;.,~~~.... 92~.(' ~H63.71 A800.00 100H.Y2 N ,', "1755.41 \,J ~,72.!)3",,'~';"" 4.27 9340 A9f:t3.71 A900.00 lfL3/+.51N";,,,:<,:,1770.5b W 376.8b"'" '14.33, " f(' -~~-~.. ~--__.~O.6},,~]..L._~..oJLQ_~.,Q~O_-_1..Q.'þ'_t:~.!.J_'Ll~'---_~.1~~.?,.~,,~.. ~-)J_---~,.ftQ....._~I_~_~_.J_? - t;.~<;:; ~ .. ," :c: ~:~: ~ ~:":;:f:~::~: ~~';::":;,;,}~;::¡';¿;~Ð;fjî¡~~:;~ ,~ ,;;"".", ~~~': ~¡'L.,:."... """:':~ :~~!¡;~;;.):),!~~(>~" "',, , " ,,' :~,:.,::';", ,.",,'¡'7't8 " l346.,l~.",~,:,',~"'~,,,9.:",A").,41., ":';.':'"",,,:,..1;¿7._9:5'~¡~(: ,>~:J"H2,~.13 w" ' ,;;191,.88", ,'..'", "" ,3.00".'<: ~ ,?;~':" " _.,-,.".....J""~_..._..",_.......,,...._-_.,..~..- .&_.....!ftJ.._~<...............,-_...."t'o_=-,-,.__. ", , "..-- ....,_....,....."-_..,""",-........."_...,,~,,,_..,.,,,..._--.........................._--_... " ,'" "'-""""",------~, AGE: 1 0 11, . '- THE CALCULATION PROCEDURES USE A LINEAR INTtRPOLATION BETW[EN :,!~ THE. N EAR [ S T 2 0 "F 0 0 T M ü (f ROM R.,\ DIU S 0 F C IJ R V A T U R E ) POI N T S "' ~.'-~, ~=31';:.E~E",~_=-~~~'~-==...: _..~~_.b~"', .'...' ...¡f;:I:~..... =- --- . ,~'~ ~ "" ":' ~, ----..-,-, ',- '.",',', ~.,.. '~~-;;~,.::;;J::; \' . ",'.' ,- , ,-. ~ ..- " ...~, "Yo' ... , ~------_~~L;.~~,.. ~--~~;:'/i~iL' ' ~~~~~....:,', :,:.:",~.i:;,:.~.:."gt?~.Ì~~~- . -..." ,....:';.:,., M_,.. '. n..:: ".'" ;.'.::'--- ,.. "'. -..,.. .,...,-..",. .,..,..'.... ..,..n.,'.', ..,.... ."--"""""""""'n.' """""""""" ','..." "'.' .' ""'....,...., ...0" SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION June 20, 1979 3111 "C" STREET ANCHORAGE, ALASI TELEPHONE (907) 265 MAIL: POUCH 6-6 ANCHORAGE, FI[F: Alaska Oil a~d. Gas Conservation Cc~mission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. Hoyle H. Hamilton Chairman Gentlemen: Well B-15 (21-31-11-14) Enclosed, in duplicate, is Fora 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of June, 1979. Very truly yours, SO~IO PETROIAJ3M COMPANY District Drilling Engineer PRJ: ch Enclosure cc: Well File $17 Form No, 10404 I%EV. 3-1-70 SUBMIT 1N DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. APl NUMERICAL CODE 50-029-20360 6. LEASE DESIGNATION AND SERIAL NO. ADL 28310 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Sohio Petroleum Co. Div. of Sohio Natural Resources Co. Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. Pouch 6-612, Anchorage, Alaska 99502 B-15 (21-31-11-14) 4. LOCATION OF WELL at surface: 1606' WEL, 1520' SNL, Sec. 31, TllN, R14E, UPM 10. FIELD AND POOL, OR WILl)CAT ?rudhoe Bay, Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 31, TllN, R14E, UPM 12. PERMIT NO. 79-19 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. June, 1979 Ran CBL log. Ran 200 jts. 7" 26~ L-80 AB-IJ-4S tubing to 8256'. Landed tubing with ball valve nipple at 1997'. Installed and tested tree. Displaced tubing to diesel. Set packer at 8151', tested tubing to 3500 psi. Ran dunmy gun and gradient survey. Released rig 0200 hrs. June 3, 1979. 14. 1 hereby cert~~ct SIGNED 12~_ R-~'Yfid~[- _ TITLE Dis+__~ict DrillLng EV. g4__ne~TE ~/~ ~p/7 ~ NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 1§th of the succeeding month,unless otherwise directed. SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION June 8, 1979 Alaska Oil and Gas Conservation ~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. Hoyle H. Hamilton Chairman Gentlemen: Well B-15 (21-31-11-14) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the monthofMay~ 1979. PRJ: ja Enclosures cc: Well File #17 Very truly yours, SOHIO PETROLEU/~ COMPANY District Drilling Engineer Form No. 10-404 REV. 3-1-70 ~ SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 5. AP! NUMERICAL CODE 50-029-20360 6. LEASE DESIGNATION AND SI{RIAL NO. ADL 28310 WELL WELL OTItER 2. NAME OF OPERATOR Sohio Petroleum Ccmpany, Div. of Sohio Natural Resources Co. 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 99502 4. LOCATION OF WELL At surface: 1606' WEL, 1520' SNL, Sec. 31, TllN, R14E, UPM 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. B-15 (21-31-11-14) 10. FIELD AND POOL, OR WILl)CAT Prudhoe Bay, Prudhoe Oil Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 31, TllN, R14E, UPM 12. PERMIT NO. 79-19 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES 1N HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. May, 1979 Spud well at 0200 hours, May 16, 1979. Drilled 17 1/2" hole to 2681'. Ran 67 jts. 13 3/8" 72~ L-80 Buttress casing to 2650'. Cemented with 5436 cu.ft. Permafrost II in 3 top jobs. Installed and tested BOPE. Tested casing to 3000 psi. Drilled out to 2711', ran leak-off test. Directionallydrilled 12 1/4" hole to 8731'. Ran 225 jts. 9 5/8" 47~ L-80 Buttress casing to 8713'. Cemented in two stages: First stage with 1187 cu.ft. Class G cement; second stage through D.V. packer at 2607' with 130 cu.ft. Permafrost C preceded byArctic Pack. Cleaned out to 8666', tested casing to 3000 psi. Drilled out to 8741', per- formed leak-off test. Directionallydrilled 8 1/2" hole to 9738'. Ran open hole logs. Ran 38 jts. 7" 29# L-80 Buttress casing liner to 9734'. Cemented with 456 cu.ft. Class G cement. Cleaned out to 9681' tested casing to 3000 psi. Displaced well to NaC1. 14. l herebycert~~egoi~ngistrTandco~ District Drillinq En,qinee~ATE SIGNED _ ,s.~r_- ~ TITLE ..... NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Alaska Oil and Gas Conservation Conunission H oyle H. Hamilton /~<~~' Chairman of the Commissio~ v! Lonnie C. Smith y Commissioner Ben LeNorman Petroleum Inspector May 22, 1979 B.O.P.E. Test on Sohio-BP's B-15 Sec. 15, TllN, R14E, UM Prudhoe Bay Unit Thursday, May 1__7 - I departed my home at 7:45 ~,~ for a 8:15 AM showup and 9:15 ~ departure via the Sohio-BP charter for Deadhorse arriving at 10:55 ~{. I proceeded to "B" pad where I discussed upcoming B.O.P.E. Tests with Drilling Foreman John Salario and Brinkerhoff Rig #36 Toolpusher Jim Davidson. Surface pipe was being run. Weather: +20° F, wind 15 MPH from the North, light snow. Friday, ¥~y.,..~ - The necessity of a top cement job delayed nippling up until afternoon, Tests began at 8:15 PM with the shoe on the 13 3/8" at 2650'. Annular preventer tested to 2500 psig. Upper pipe rams, check valve in the kill line and HCR valve in the choke line tested to 5000 psig. Inside valves on the choke and kill lines then tested to 5000 psig. Lower pipe rams tested to 5000 psig. With the pumps off and accumulator pressure at 2850 psig, both pipe ram preventers and the annular preventer were closed and the HCR valve opened simultaneously. Pressure dropped to 1250 psig and stabilized. The pumps were then turned on and accumulator pressure built 200 psi in thirty seconds. N2 backup bottles tested 2000, 2100, 2400, and 2100 psig. Ten valves and twenty flanges in the choke manifold tested to 5000 psig. Both manual adjustable chokes were free moving and the Swaco superchoke actuated fully opened and fully closed. ~ile pulling the test joint to test the blind rams I toured the location which was well organized, rig in good repair, reserve pit well built, and the well sign was in place. Blind rams and lower Kelly valve then tested to 5000 psig. The Kelly cock failed and would have to be replaced. Both ball and dart type floor valves were in place. Tests were concluded at 10:30 PM.. A field inspection report was prepared with a copy given to John Salario, a copy mailed to Swede Swenson, and the original attached to this report° ~aturday, May !P The Kelly cock was repaired and tested to 5000 psig. I departed Deadhorse via Sohio-BP charter at 12:40 PM arriving in Anchorage at 2:10 PM and at~ my home at 2:40 PM. In Summary, I witnessed successful B.O.P.E. tests on Sohio-BP's B-15. -, , :J.: BP ALASKA 'I NC. )- (,BOP EQUIPMENT TEST REPOR\'f " "'.' . " ...' .. " DATE ,~>--~ I)} , 7 9 RIG g ¡t/,.36 WELL 15. /S ,"'\ TEST FLU I D )..J, ~ .s ~ I ACCUMULATOR VOLUME /_~o C~ I TEST TYPE: DWEEKLY CtFCÃNGE UP ~ING SET LAST CASING: /.lMr II AT ,,;:.>(d:Çð PRESSURE a PERFORMANCE TES.'-s.: -' BOP STACK - LISTALL;\ ITEMS TOP TO BOTTOM. MANUFACTURER AND TY;~,E. SIZE OF RAMS. ETC. , ~ ~~/V't/ /J UNIT ANNULAR BL IND RAM PIPE, RAM U 'I Y' PIPE RAM 1... t...-- CHOK E ", MÄNIF. ' KEt.LYCOCK # I KELLY VALVE:tf:2 INS IDE BOP , KELLY HOSE, STAND' PIPE C:HO'KE" L;tN~'" KI,LL LINE TEST PRESSURE ""\ TEST TIME ".." I P . ACCUMULATOR a PUMps CLOS I NG , ,TIME I ;?5 cc- ACCUMUUATOR ONLY " . , CLOSING RECHARGE TIME TIME " '., "-(... rs=c T,ES",',T","",TO,'OL:', ~,: ".', L,UG.""",.,CJ,,',,'CU, P, , D, iP"A,' C, K, E,,'~,',' CASING TESTED: pc f¡-,ø FT/ TO, .~ PSI. AC,CUMUL4To..R,O 'RECHARGE: ~J$¡" C);O , PSI BEFORE TE, ST. "/~1)PS, I,AFT,ER"CLOSINGALL BOpIS. . MIN. RECHARGE TIME. BOP DR'I'bL SEC. TRIP DRILL' , " ',SEC.... ¡'v' 1// NI""T,RO"."",)ßJi".",'.""~'"",.",'",P,RÁ"'~,'.,H,'".',,,A,.""""R"'"""G,,E, ":""."""~,,,,.7f)rl'V"""""""""'"',.'"'.'"",",,,',,,'2,,,',."""'",,~,",,',, 3'"",',1'-,(,,',',',""', "',4'~,""""5.,, 1"¡¿""',',',,,6. 1,'"'<7.",':c.",,',,S. ,j , 9./ fC., 10. ' II.'!/!" 12. I KS- 13. (IG, 14. 1¡¿""ì'5. It:- 16. l;t., ' ~~ EQUiPMENT" CHECKLIST BA~~rr.E ON HA NO /S ell) SACKS GEL. d'N HA N D40D SACKS WATÈ'R ON HAND '<Pro BBL , SURFACE' MUD VOLUME I()~v ' BBL HYDRAULIC OIL ON HAND II.. DRUMS NJTROGENBACKUP Sys." $'.""""" ,'"NO.OF B, OT16, ES HO,,'()KEDUP.AT.~tvv PSI " " , ' , N tTROG EN PRESS URE. MALFUNCTIONS, a ,COMMENTS (ITEMIZE ALL LEAKS. MALFUNCTI,ON$. MISSING EQUIPMENT. ETC.. AND ,C4",1l.1'. Þul d?(.. , 'tl1$ ¿';':J.I / . ./. . . . .~-J?_itJ,) '. '..'.'. .. . . ~¡> SOPER\lJSQR:-,: ¿~~u">~,~~ '.' ,TO ,'B.E',' ,ØQMPI..¡ÊT:ED::;.Å'N£)~,PU':T,();NcfJ~E' :F.Q.R~EÄC.H'SOPTtS,T; '.,' :',.,":"C"'::X"';""'I..,'"/,".,";,.,;,:.di,J"'"..:,,,::cL,~;:;,'","';;:,.:>:.L:..,.""..";",c;,:..,.,,¿,,::;,,'i:¿,c:Ji14.,::,c:,.:,:,"::"C,' "f.c':",;,"".,:::;"",;:.:',:"",;",;.,,'" c c"',c':...',",:",",:.;':' , ~ka Oil and Gas Conservation Committee Field Inspection Report Drlg. Permit No. '7~-/~ J~N~j Well/~m Sec~jT II/~/RI~, ~ M Operator__~O~¢l~_ ~f:) Represented by ~~~ Name & Number Satisfactory Type Inspection Satisfactory Type Inspection Yes No Item (~-)"Location,General Yes No Item ( ) BOPE Tests (FY() (~() (~)- ( ) (~' ( ) () () () () () () () () () () () () 1. Well Sign 2. General Housekeeping ~. Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. ,__,__,~ 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. Bbls.. , , , ( ) Final Abandonment (~() (~y- ( ) (~() ( (~() () (~)- ( ) 15 ~asing set 16 Test fluid-( )wtF] (-)mud (~"oil 17 Master Hyd. Control Sys.-~j)~-opsig 18 N2 btls~~~~,~'~psig 19 Remote Controls 20 Drilling spool- ~' "outlets 21 Kill Line-(~Check valve 22. Choke Flowline (~HCR valve 23 Choke Manifold No. valvsz~ flgs~ 24 Chokes-(~emote( )~os.(~dj 25 Test Pluo-(~ellhd( )csg( )none 26 Annular Preventer~o~sim 27 Blind Rams~oo~.,psim ( ) ( ) ll. P&A Marker (~)-~ ( ) 28 Pipe Rams ~-~,psiq ( ) ( ) 12. Water well-( )capped( )plugged ( ) (~ 29 Kelly & Kelly-cock ~__psig ( ) ( ) 13. Clean-up (~)~ ( ) 30 Lower Kelly valve,5-~_~,_psi~ ( ) ( ) 14. Pad leveled (~-)-~ ( ) 31 Safety Floor valves-(~WBV /~)fi~art Total inspection observation time~/z~hrs/~lll~~ Total number eaks and/or equip, failures Remarks cc'~~ ~u_~,~Notify in days or when ready Inspected by April 27, 1979 Re- Prudhoe Bay Unit B-15 Sohio Petroleum Company Permit 79-19 Mr. P. R. Judd District Drilling Engineer Sohio Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Dear Mr. Judd: Enclosed is the approved application for permit to drill the above referenced well at a location in Section 31, Township llN, Range 14E, UPM. Well samples, core chips and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information on all logs shall be submitted for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Codec). Prior to commencing operations you may be contacted, by th~ ~{abitat Coordinator's office, Department of Fish and Gan.~e. Pollution of any waters of the State is prohibited by AS 46, Chapter 3r Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may Iv contacted by a representative of the Department of Environmental ConservatiOn. Mr. P, R. Judd Prudhoe Bay Unit B-15 -2- April 27, 1979 Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the .event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, <~?' w* H ~am il ton Chairman Alaska Oil & Gas Conservation 'Commission Enclosure cc: Department of Fish & Game, ~abitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor; Supervisor, Labor Law Compliance Division w/o encl. SOHIO PETROLEUM COMPANY Division of Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION April 24, 1979 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 CONFIDENTIAL Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. Hoyle H. Hamilton Chairman Gentlemen: Well B-15 (21-31-11-14) Enclosed are the following documents: 1. Application to Drill Well B-15 (21-31-11-14) 2. Proposed Drilling Program Outline 3. Our check for $100.00 to cover the permit filing fee 4. Three copies of surveyor's plat showing well location. Very truly yours, PRJ: ja Enclosures cc: Well File ~17 CC~ 7964 P. R. Judd District Drilling Engineer Form 10-401 ' REV. 1-1-71 la. TYPE OF WORK SUBMIT IN TRIP~. .,TE (Other instructions on STATE OF ALASKA reverse side) OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN DRILL b. TYPE OF WELL OILF"21 GAS WELL [_~ WELL OTHER DEEPEN [--] SINGLE ZONE ~-~ MULTIPLE ZONE 2. NAME OF OPERATOR Sohio PetroleLml Cc~pany a Division of Sohio Natural R~qources Co. 3. ADDRESS OF OPERATOR Pouch 6-612, Anchorage, Alaska 99502 4. LOCATION OF WELL At surface 1606' WEL, 1520' SNL, Sec. 31,~Ti1N, R14E, UPM 8800' ss At proposed prod. zone 3430' WEL, 580' SNL, Sec. 31, TllN, R14E, UPM CONFIDENTIAL APZ 50-029-20360 6. LEASE DESIGNATION AND SERIAL NO. ADL 28310 7.IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. B-15 (21-31-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil ll. SEC., T., R., M., (BOTTOM Pool HOLE OBJECTIVE) Sec. 31, TllN, R14E, UPM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. 10 miles NW of DeadhorSe 14. BOND INFORMATION: r~E Blanket 'Surety and/or NO. American Insurance Co. 3348616 Amount $100,000.00 17. Ne,ACRES ASSIGNED TO THIS WELL 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, u~t, if any) 1564' east of ADL 28286 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2468' east of Well A-2 :[ 16. .No. OF ACRES IN LEASE I [ 2491 19. PROPOSED DEPTH [ 9299'TVD 9679'MD 21. ELEVATIONS (Show whether DF, RT, CR, etc.) KBE = 65' AMSL est. 160 20. ROTARY OR CABLE TOOLS 22. APPROX. DATE WORK WILL START June 1, 1979 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE MD SETTING DEPTHTV]~ Quantity of ce,nent 36" 20"x30" InSUlated Coz~uctor 110' 110' 472 cu.ft. Permafrost 17½" 13 3/8" 725 L-80 2670' 2670' 4500 cu.ft. Permafrost 12%" 9 5/8" 475 L-80 8723' 8400' 1360 cu,ft. Class G + 130 cu.ft. Permafrost 8%" 7" 295 L-80 9679' 9299' 300 c~,ft. Class G See attached drilling program. Alaska IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true _~_~,.vertical depths. Give blowout preventer program. 24'Iherebycertify~:;~ea~rrei~,. ' ' · ]TLE Dist. Drilling Engineer (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS REQUIRED I MUD LOG [] ws [~ NO I [] YES J~.NO DIRECTIONAL SURVEY REQUIRED .~yES [] NO OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE 3-0 - 0¥:/ PERMIT NO. APPOVED BY April 27, 1979 DATE )4127179 JNFI!)ENTIAL PROPOSED DRILLING & OOMPLE~ION PROGRAM Dry bucket 36" hole to 80' below ground level and cement 30" x 20" insulated conductor to surface using 472 cu. ft. cement. Drill 17 1/2" hole to 2670' and cement 13 3/8" 72# L-80 Buttress casing to surface using 4500 cu. ft. Permafrost cement. Blowout Preventer Program consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer from 13 3/8" casing point to T.D. Directionally drill 12 1/4" hole to 8400'-+ TVD. Run 9 5/8" 47~ L-80 Buttress casing to 8400' TVD and cement first stage with 1360 cu. ft. cement. Cement second stage through D.V. packer collar at 2600'+- with 130 cu.ft. Permafrost cement. 9 5/8" casing will be hung at surface, the 9 5/8" x 13 3/8" annulus being displaced to Arctic Pack through the D.V. packer placed at 2600'. Directionally drill 8 1/2" hole to T.D. at 9299'5 TVD. Cement 7" liner to 500' inside 9 5/8" casing shoe with 300 cu.ft. Class G cement. Run 7" 26# L-80 Atlas Bradford IJ-4S tubing with a production packer assembly at 7870'+- TVD. A subsurface safety valve, with dual control lines, will be placed at 2000'+-. Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release. Details of proposed perforations to be suh~aitted on Sundry Notice to follow. O5 40 oi 02 04 0 i 02 ' j 4972r 5O b ]. 4994' 51 .--' ....... 29 5450' 52 ~--h--- 664,058 . ~ ~89a' ~_~'~ 4889' '~ ........ ~ 772'~ B-lO . SCALE i':~'_~ MILE (Propos~d) '~, I T IC) N. t I 1 1 SUMP t"~;''~, ~,'-~'~"~ .,,.: PAD DETAIL SCALE_ t': ', '>( >' CERTIFICATE OF SURVEYOR i hereby certify that !.,am properly registered and licensed to practice land surveying in the State of Alaska and ?hot ~his plat represents a location survey made by me or under my supervision, and th,at all dimensions and othe-r details are correct. A?~. /9, /a79 Dote ADDED (PROPOSED) BOTTOM HOLE LOCATIONS B-15 THRU B-J7 8800' SUIB SEA t PAD "B" EXTENSION Locoted in Surveyed for B.R ALASKA I NC. Surveyed i)y ~ E M. LINDSEY 8, ASSOC. ~ L AND ~ HYDRC)GRAF',~i(; F; i ! R"-/ F '( :: ~ ~ :'-'¢~(.'.F' West Northern L ~r~hf¢, ~3( ui,~v~ rd F~¢ ,~ :;c:; ~ CHECK LIST FOR NEW w'ELL PERHITS Company Yes 'No Is the permit fee attached. . . . . . . . . . . . . . . . . . . . . ) .. . Is well to be locate~ in a defined pool ............. . . . Is .é1 registered survey plat attached. ... . . . . . . . . . . .. /~ Is well located proper distance from property line. . . . . . . . : ~ .= Is well loca ted proper distance from other wells. . . . . . . . . .. 9; -- Is sufficient undedicated acreage available in this pool. . . . . Is \-¡ell to be deviated. . . . . . . . . . . . . . . . . . . . . . . ~ . . . . . . . . . . . . . . . . ~ Can'permit be approved before ten-day wait. . . . . . . . . . .. ~ Does operator have a bond in force. . . . . . . . . . . . . . . . :~ --- ~ ~.~ Is conductor string provided. . . . . . . . . . . . . . . . . . .; . ~- . Is operator the only affected party Is a conservation order needed. . . . . . . . . . . . . . . . . . . Is administrative approval needed ..... ............. Is enough cement used to circulate on conductor and surface. . . t3 ':<13 " I',"" n 't.í.." ": .(¡,r:J4 Cø ~ñ )(. '2; c:> -r 0 '::-, €:IS '1 . t~il1 c(,'~ment tie in surface and intermediate or production strings Wi 1] cement cover all known productive horizons ......... hiill surface casing protect fre~:>h 'vater zones .......... Will all casing give adequate safety in collapse, tension & burst ~í" L.-ßo ß ::b~10 l-= Lf1?o 1:/Ø8fø ' e Does BOrE have sufficient pre:3sure rating - Test to $'Dbo psig Approval Recommended: itional Requirements: 0'-"_""--'--- "'" . ..,------.'- .----,-..-.--.-.----..--,..,.........---.-.-.-..,,-----.-,,-,-.-.-"...-.-,",-,--.--.-.-........-.-..--....-...----.. ",-,......."" .~..._...-"-' --..-. ."..-..,.- ,'-""".'.".'" ,... ..- ,-. 5'0/""'- Remarks 1- Lease & Well No. Item -(1) Fee I. (~. C(. Approve ~ (2) Loc. ~ If-Is-' Date .Jt- 7.,':)-7f --¡;;: If/V)''- ì , ~ ... to¡-, ,,~ ... 7 , .~ -11l *': ~ /1 "? , ~ J:)g (¿, IH~ 4-i 4-. Q) <~ 863 +J 'r-! . h 0 ~Z ~ .0 ~. -' ,: .......: , " .-.-- (3) Admin. ~ . ro I 0 ,\ .~ & ~ I U) B M CD ? rd+J - . r-I CfJ +J 'r-! h U) H U) ~ ~ '"b u C ~'.........'..'.'.'.,.....,. \....... " ., Engineering: LCS BË\~~¥I"'2(þI'1!) RAD Revi.~,{,d 01/19/7':. .--.-----------.--'-..-----. -- .-------.-.-.. .-..- ........ _. ._~_.= _. ~,." '"""="="~' ~=-~~.~~~"." ,'~"~"._-=' . "T._==.~' '-~ . ~.. ..-,~. __.n ,~"",~,=...._,.==-=~.__._.,--" '.r_',,- -'-'-----"""""""-"".-~._-~.'~'-=-'~=""-' ..---.= -._-- =.-,,"'.,="., ..-,"-.. ~... T' .=,,"--~ ,-" .", '.', " ,,'."'-. -- "'.~ ,"v.. '... _.',,- '.. .. .~.',"", '=."."." ..",,=. ."...=....-.-.",,", -,,--,.,' =---.-..,.._"".=.-.,..""~",,,- ----""--'- .~- .~ .~ .~. .~. .~~~; - --- (4) Casg. tR~ -- -(5) BOPE Ge.o ¡.g:... HHK K WVA --.=.-. jAI.. ~ ...,...--. .. ..- "..,' .. ."...,." -- "" .., - .-. .. 4i~. Well Histo 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 APPE .NDIXl No Special'effort has been made to chronologically organize this category of information. ,o B- 15 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD B-15 500292036000 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 10-SEP-93 5798.02 R. IORIO C. HUGHES 31 liN 14E 1520 1606 63.71 62.71 37.18 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 9.625 8713.0 47.00 7.000 9738.0 29.00 7.000 8193.0 26.00 4.500 8256.0 12.60 EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 8856.5 8874.0 8885.0 8885.5 8886.5 8913.0 8913.5 8947.0 8953.0 8979.0 8980.5 8988.5 8989.0 UNKNOWN GR LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GRCH 8857.5 8875.0 8886.5 8887.0 8887.5 8914.0 8915.0 8948.5 8954.0 8980.0 8981.0 8989.0 8990.0 8991.0 8993.0 9087.0 9122.5 9128.5 9130.0 9130.5 9131.5 9134.0 9134.5 9161.5 9174.0 9191.0 9191.5 9192.0 9192.5 9200.5 9208.5 9327.0 9327.5 9328.0 9337.5 9352.5 9371.0 9383.0 9385.0 9386.0 9386.5 9387.5 9393.0 9395.0 9402.5 9409.0 9410.0 9415.0 9415.5 9416.5 9429.0 9429.5 9431.5 9432.5 9450.5 9463.5 9464.0 9475.0 9475.5 9476.5 9483.5 9489.0 9496.0 9524.0 9524.5 9535.0 9539.0 9542.5 9552.0 9552.5 9562.5 9571.0 9572.0 8992.0 8993.5 9087.5 9122.5 9128.5 9130.5 9131.0 9131.5 9134.0 9135.0 9162.0 9174.0 9191.0 9191.5 9192.0 9192.5 9200.0 9208.0 9327.0 9327.5 9328.5 9338.0 9353.5 9372.0 9383.5 9385.5 9386.0 9387.0 9388.0 9393.0 9395.0 9402.0 9408.5 9409.0 9415.5 9416.0 9416.5 9429.0 9430.0 9432.0 9432.5 9450.5 9464.0 9464.5 9475.0 9475.5 9476.0 9483.0 9489.0 9496.0 9523.5 9524.0 9535.0 9539.0 9542.0 9551.5 9552.5 9562.5 9570.5 9571.5 9608.5 9614.0 9624.5 $ REMARKS: 9608.0 9615.0 9625.0 CN/GR Cased Hole. LOG TIED TO BHCS RUN 29-MAY-79. CN LOGGING PARMS: LIMESTONE MATRIX CHISM OFF CALIPER CORRECTION = 10.625" CASING CORRECTIONS OFF SALINITY = 0 LOGGED AFTER SEAWATER (90 DEGF) PUMP-IN OF 100 BBLS. PRIOR RATES (07-AUG-93): MBPD = 3.99 MBOPD = 3.16 MBWPD = .84 MMSCFD = 11.19 GOR = 3542 CHOKE = 74.4 MFP = 1680 PSIG @ 165 DEGF WC = 20.9% OPEN HOLE GAMMA RAY SUPPLIED BY BP 7-SEP-93. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS NEUTRON DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT NEUTRON PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS NEUTRON. $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8782.5 9736.5 8790.0 9645.0 BASELINE DEPTH NPHI 8770.0 8770.0 8852.0 8853.0 8863.5 8863.0 8867.5 8867.5 8893.0 8893.0 8928.5 8930.0 8938.5 8939.5 8967.0 8966.5 8977.0 8977.0 8986.0 8986.5 8996.0 8997.0 8999.0 8999.0 9024.5 9024.0 9029.0 9029.0 9032.0 9032.0 9081.5 9081.5 9128.0 9128.0 9157.5 9156.0 9164.0 9164.0 9167.0 9167.0 9173.0 9173.0 9188.0 9187.5 9199.5 9199.0 9246.0 9245.0 9300.0 9299.5 9367.0 9367.5 9391.5 9392.0 9423.0 9424.5 9446.5 9447.0 9499.5 9500.0 9547.5 9547.5 9660.0 9660.0 $ REMARKS: (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH PASS 1. FUCT, NUCT, & TENS WERE SHIFTED WITH NPHI. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. $ CN : BP EXPLORATION WN : B - 15 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units 1 GRCH 2418 68 1 GAPI 2 NPHI 2418 68 1 PU-L 3 FUCT 2418 68 1 CPS 4 NUCT 2418 68 1 CPS 5 TENS 2418 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 4 4 86 720 65 6 20 * DATA RECORD (TYPE# 0) Total Data Records: 42 1014 BYTES * Tape File Start Depth = 9645.000000 Tape File End Depth = 8775.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 10447 datums Tape Subfile: 2 273 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8782.5 9736.5 8790.0 9645.0 BASELINE DEPTH GRCH 8770.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 8770.0 8778.5 8778.5 8785.5 8785.5 8786.5 8786.5 8793.0 8793.0 8807.0 8807.0 8818.5 8821.0 8824.5 8824.0 8825.5 8825.0 8828.5 8830.5 8835.5 8837.0 8849.0 8850.0 8851.0 8852.0 8857.5 8858.5 8858.5 8859.0 8862.5 8860.5 8863.0 8861.0 8863.5 8862.0 8866.0 8864.5 8866.5 8865.5 8867.0 8867.5 8868.0 8868.0 8869.5 8868.5 8870.0 8869.5 8870.5 8870.5 8871.0 8871.0 8872.0 8872.0 8872.5 8873.0 8884.5 8886.0 8885.0 8886.5 8887.0 8887.0 8888.0 8887.5 8892.5 8892.5 8897.0 8896.5 8898.5 8899.0 8900.5 8901.5 8900.5 8901.0 8902.5 8904.5 8906.5 8907.0 8908.0 8909.0 8910.5 8911.0 8911.5 8920.0 8920.5 8922.0 8925.5 8928.0 8934.0 8935.0 8943.5 8948.5 8949.0 8951.5 8952.5 8961.0 8968.5 8978.0 8980.5 8981.0 8982.0 8987.0 8990.0 8990.5 8993.5 8994.5 8999.5 9002.5 9003.5 9004.0 9017.0 9017.5 9018.5 9024.0 9032.0 9037.0 9042.5 9053.5 9074.5 9075.0 9076.0 9076.5 9077.5 9082.0 9085.5 9087.0 9118.0 9120.0 9121.0 9122.0 9125.0 9126.5 9133.0 9133.5 8902.5 8905.0 8911.0 8912.0 8949.5 8952.0 8981.5 8982.0 9004.0 9017.5 9018.0 9018.5 9037.0 9075.0 9075.5 9076.0 9087.0 9121.0 9124.0 9132.5 9133.0 8906.0 8907.0 8908.0 8908.5 8910.5 8911.5 8920.0 8921.0 8922.5 8926.5 8928.5 8935.0 8935.5 8944.0 8948.5 8952.5 8961.0 8967.5 8977.0 8980.5 8986.5 8990.0 8991.0 8994.0 8994.5 8999.5 9002.5 9003.0 9023.5 9031.5 9042.5 9053.5 9076.0 9076.5 9081.0 9084.5 9117.5 9119.5 9120.0 9125.5 9134.0 9142.0 9142.5 9143.0 9144.0 9147.5 9148.5 9155.0 9155.5 9160.5 9175.0 9177.5 9178.0 9182.0 9186.5 9187.0 9187.5 9192.5 9201.5 9202.5 9203.0 9204.0 9204.5 9207.5 9212.5 9216.0 9219.0 9246.0 9251.5 9270.5 9273.5 9274.0 9274.5 9275.0 9278.0 9300.5 9325.5 9326.0 9326.5 9336.0 9338.5 9341.5 9353.0 9368.5 9383.5 9384.5 9385.5 9396.0 9404.0 9407.0 9407.5 9408.5 9409.0 9423.0 9424.0 9424.5 9426.0 9427.0 9432.0 9433.0 9134.0 9142.0 9143.0 9143.5 9144.0 9155.5 9177.0 9177.5 9182.0 9186.5 9187.0 9187.5 9192.5 9201.0 9202.0 9325.5 9326.0 9327.0 9339.0 9354.0 9369.5 9384.0 9385.0 9385.5 9396.0 9403.0 9406.0 9407.0 9408.0 9409.0 9423.0 9423.5 9424.5 9426.0 9426.5 9431.5 9432.0 9148.0 9149.0 9153.5 9159.5 9174.5 9181.5 9186.0 9202.0 9202.5 9203.0 9205.5 9210.5 9215.5 9218.5 9245.5 9250.5 9269.0 9272.0 9272.5 9273.0 9274.0 9277.0 9300.5 9336.5 9342.0 9424.5 9475.5 9510.0 9510.5 9511.0 9514.0 9518.0 9519.5 9524.5 9525.5 9534.0 9539.0 9541.5 9548.0 9553.5 9554.0 9555.5 9556.5 9557.0 9559.5 9562.5 9563.5 9565.0 9566.0 9567.0 9568.0 9574.0 9577.5 9588.0 9603.0 9611.0 9611.5 9626.0 9627.5 9628.0 9629.0 9631.0 9632.5 9633.5 9634.0 9634.5 9635.0 9639.5 9640.5 9643.5 9648.5 9649.0 9650.0 9650.5 9660.0 REMARKS: CN WN FN COUN STAT PASS FUCT, $ · 9475.0 9509.5 9510.5 9510.0 9513.0 9518.0 9519.0 9524.0 9524.5 9534.0 9539.0 9541.0 9548.5 9553.0 9554.0 9555.5 9556.0 9557.0 9559.5 9562.5 9563.0 9565.0 9566.0 9566.5 9568.0 9574.0 9578.0 9587.5 9603.0 9611.5 9612.0 9626.5 9628.0 9629.0 9630.0 9631.5 9632.0 9632.5 9633.0 9634.0 9634.5 9640.0 9641.0 9641.5 9649.0 9649.5 9648.0 9648.5 9660.0 NUCT, & TENS WERE SHIFTED WITH NPHI. : BP EXPLORATION : B - 15 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-L 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 5 TENS 2418 68 1 LB 4 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 42 Tape File Start Depth = 9645.000000 Tape File End Depth = 8775.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 10447 datums Tape Subfile: 3 278 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE GRCH 2418 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8775.5 9736.5 8784.0 9645.0 BASELINE DEPTH GRCH 8770.0 8785.5 8793.0 8807.0 8818.0 8825.5 8835.0 8849.0 8856.0 8856.0 8862.5 8863.0 8863.5 8866.0 8866.5 8869.5 8870.0 8870.5 8871.0 8892.5 8897.0 8899.0 8899.0 8900.5 8901.5 8905.0 8905.5 8906.5 8907.0 8907.0 8907.5 8907.5 8908.0 8909.0 8911.0 8911.0 8911.5 8912.0 8913.0 8920.0 8920.5 8922.0 8924.5 8925.5 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH NPHI 8770.0 8785.5 8793.0 8807.0 8818.0 8824.0 8834.0 8849.0 8860.5 8861.0 8862.0 8864.5 8865.5 8868.5 8869.5 8870.5 8871.0 8891.5 8896.5 8900.5 8901.0 8906.0 8907.0 8908.0 8908.5 8910.5 8911.5 8920.0 8921.0 8922.5 8925.0 8926.5 8928.0 8934.0 8935.0 8936.5 8937.0 8943.5 8946.5 8949.0 8952.5 8961.0 8968.5 8978.0 8980.5 8982.0 8983.0 8987.0 8990.0 8990.5 8993.5 8994.0 8994.5 8999.5 9002.5 9003.5 9019.0 9020.0 9021.0 9021.5 9022.0 9025.0 9026.0 9029.0 9030.5 9031.0 9032.0 9035.0 9037.0 9042.5 9053.5 9074.5 9075.5 9076.0 9076.5 9077.0 9077.5 9078.0 9082.0 9085.5 9087.0 9087.5 9118.0 9120.0 9121.0 9124.0 9126.5 9147.5 9148.5 9155.0 9160.5 9175.0 8937.0 8938.0 8947.5 8952.5 8982.0 8982.5 8993.0 8994.0 9019.0 9019.5 9020.5 9021.5 9025.0 9025.5 9030.0 9031.0 9037.0 9074.0 9075.0 9076.0 9077.0 9077.5 9086.5 9087.5 9123.5 9174.5 8928.5 8935.0 8935.5 8944.0 8948.5 8952.5 8961.0 8967.5 8977.0 8980.5 8986.5 8990.0 8991.0 8994.0 8994.5 8999.5 9002.5 9003.0 9020.5 9028.5 9031.0 9034.0 9041.5 9053.5 9076.0 9076.5 9081.0 9084.5 9117.5 9119.5 9120.0 9125.5 9148.0 9149.0 9153.5 9159.5 9174.5 9182.0 9183.0 9185.5 9187.0 9192.0 9203.0 9204.0 9204.5 9207.5 9212.5 9216.0 9219.0 9246.0 9251.5 9270.5 9273.5 9274.0 9274.5 9275.0 9278.0 9300.5 9308.5 9309.5 9327.5 9332.5 9333.0 9333.5 9336.0 9338.0 9338.5 9341.5 9374.0 9384.5 9385.5 9391.0 9394.0 9394.5 9400.0 9400.5 9401.0 9404.5 9417.5 9422.0 9422.5 9426.5 9427.0 9428.5 9430.5 9435.0 9438.0 9448.0 9474.5 9480.5 9510.5 9518.0 9523.0 9523.5 9524.0 9525.5 9534.5 9181.0 9182.0 9185.0 9191.5 9306.5 9307.5 9327.5 9332.5 9333.0 9333.5 9338.0 9339.0 9385.0 9385.5 9391.0 9393.5 9394.0 9399.0 9399.5 9400.5 9421.5 9426.5 9427.0 9430.0 9447.5 9473.5 9479.5 9521.5 9522.0 9523.0 9524.5 9534.0 9181.5 9186.0 9202.0 9202.5 9203.0 9205.5 9210.5 9215.5 9218.5 9245.5 9250.5 9269.0 9272.0 9272.5 9273.0 9274.0 9277.0 9300.5 9336.5 9342.0 9374.0 9405.0 9417.0 9425.0 9430.0 9436.0 9438.0 9510.5 9518.0 9540.0 9548.0 9559.5 9573.5 9574.5 9577.5 9588.0 9591.0 9595.0 9603.0 9611.0 9611.5 9631.0 9632.5 9633.5 9634.0 9634.5 9635.0 9639.5 9640.0 9640.5 9648.5 9649.0 9660.0 $ REMARKS: PASS 3. FUCT, $ 9573.0 9573.5 9590.0 9631.5 9640.5 9641.0 9540.0 9548.5 9559.5 9578.0 9587.5 9595.0 9603.0 9611.5 9612.0 9632.0 9632.5 9633.0 9634.0 9634.5 9640.0 9649.0 9649.5 9660.0 NUCT, & TENS WERE SHIFTED WITH NPHI. CN : BP EXPLORATION WN : B - 15 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GRCH 2418 68 1 GAPI 4 2 NPHI 2418 68 1 PU-L 4 3 FUCT 2418 68 1 CPS 4 4 NUCT 2418 68 1 CPS 4 5 TENS 2418 68 1 LB 4 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 4 86 720 65 6 20 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 42 Tape File Start Depth = 9645.000000 Tape File End Depth = 8775.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20894 datums Tape Subfile: 4 253 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS GRCH 2418 $ REMARKS: 1, 2, 3 1, 2, 3 AVERAGED PASS. GRCH, NPHI, FUCT, & NUCT WERE AVERAGED FOR ALL 3 PASSES $ CN : BP EXPLORATION WN : B - 15 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units 1 GRCH CNAV 68 1 GAPI 2 NPHI CNAV 68 1 PU-L 3 FUCT CNAV 68 1 CPS 4 NUCT CNAV 68 1 CPS API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 35 725 65 1 4 4 35 725 65 1 4 4 35 725 65 1 4 4 35 725 65 1 16 * DATA RECORD (TYPE# 0) Total Data Records: 35 1006 BYTES * Tape File Start Depth = 9645.000000 Tape File End Depth = 8775.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 19153 datums Tape Subfile: 5 57 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8776.5 2418 8785.0 $ LOG HEADER DATA STOP DEPTH 9657.0 9664.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MOD. GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 16 -AUG- 93 FSYS REV. J001 VER. 1.1 1023 16-AUG-93 9646.0 9646.0 8800.0 9645.0 1500.0 YES TOOL NUMBER 3507 1310 2418 2323 0.000 9738.0 0.0 PRODUCED/SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL LIMESTONE 0.00 10.625 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 1. CHISM OFF NO CASING CORRECTIONS SALINITY = 0 $ CN : BP EXPLORATION WN : B - 15 FN : PRUDHOE BAY COLIN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-L 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TEN 2418 68 1 LB 9 TTEN 2418 68 1 LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 34 020 47 5 4 4 34 675 83 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 142 Tape File Start Depth = 9660.000000 Tape File End Depth = 8776.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 56265 datums Tape Subfile: 6 220 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8777.5 2418 8786.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9651.5 9660.0 16-AUG-93 FSYS REV. J001 VER. 1.1 1108 16-AUG-93 9646.0 9646.0 8800.0 9645.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MOD. GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ TOOL NUMBER 3507 1310 2418 2323 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9738.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED/SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL LIMESTONE 0.00 10.625 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 400 NEAR COUNT RATE LOW SCALE (CPS) : 50 NEAR COUNT RATE HIGH SCALE (CPS) : 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. CHISM OFF NO CASING CORRECTIONS SALINITY = 0 $ CN : BP EXPLORATION WN : B - 15 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 2 CNC 2418 68 1 PU-L 3 CN 2418 68 1 PU-L 4 LSN 2418 68 1 CPS 5 SSN 2418 68 1 CPS 6 CCL 2418 68 1 7 SPD 2418 68 1 F/MN 8 TEN 2418 68 1 LB 9 TTEN 2418 68 1 LB 4 4 19 991 67 5 4 4 86 720 65 6 4 4 31 149 96 6 4 4 34 020 47 5 4 4 34 675 83 5 4 4 79 150 21 1 4 4 65 866 87 0 4 4 31 402 87 0 4 4 31 402 87 0 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 143 Tape File Start Depth = 9660.000000 Tape File End Depth = 8771.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 54724 datums Tape Subfile: 7 221 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8770.5 2418 8779.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9649.5 9658.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCM PULSE CODE MOD. GR GAMMA RAY CN COMPENSATED NEUTRON CCL CASING COLLAR LOC. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 16-AUG- 93 FSYS REV. J001 VER. 1.1 1152 16-AUG-93 9646.0 9646.0 8800.0 9645.0 1500.0 YES TOOL NUMBER 3507 1310 2418 2323 0.000 9738.0 0.0 PRODUCED/SEAWATER 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 THERMAL LIMESTONE 0.00 10.625 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 400 NEAR COUNT RATE LOW SCALE (CPS): 50 NEAR COUNT RATE HIGH SCALE (CPS): 1050 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. CHISM OFF NO CASING CORRECTIONS SALINITY = 0 $ CN : BP EXPLORATION WN : B - 15 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 9 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR 2418 68 1 GAPI 4 2 CNC 2418 68 1 PU-L 4 3 CN 2418 68 1 PU-L 4 4 LSN 2418 68 1 CPS 4 5 SSN 2418 68 1 CPS 4 6 CCL 2418 68 1 4 7 SPD 2418 68 1 F/MN 4 8 TEN 2418 68 1 LB 4 9 TTEN 2418 68 1 LB 4 4 19 991 67 5 4 86 720 65 6 4 31 149 96 6 4 34 020 47 5 4 34 675 83 5 4 79 150 21 1 4 65 866 87 0 4 31 402 87 0 4 31 402 87 0 36 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 143 Tape File Start Depth = 9660.000000 Tape File End Depth = 8770.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 91876 datums Tape Subfile: 8 221 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 9 is type: LIS 93/ 9/10 01 **** REEL TRAILER **** 93/ 9/10 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Fri 10 SEP 93 1:58p Elapsed execution time = 23.73 seconds. SYSTEM RETURN CODE = 0 PRUDHOE BAY ;: - .., ,-..=: · :: '.']i,.'.k; ,.;.. :: -....,. . . .:: · . , , .. .... , . ~ ., ..... , - -. ....... :a' ~ :~. ,:.:..~..'.~ :--,: :.:.; ~: :,.,7:: -::: ,~ .. [... ;:,. ,~::.:..;~.: ........ ..::..~ ::;'~:;~.;.::: ..... Run 1' ~:d-{F~: ?~:';?S ~':'::7:'....;~' (:'L;'i:~.r~:F':-::, ' : . - :--~ ..~--,:. ~ :.: :.-::~ - .., :..:.~:~'~': :~.~:: : :: .:..~ ::~:~:::'::;:'":.::":r~ :: . :,.~-.:-~:.:,::~'~q ~.,.,:,~ _.:~ ~,,_-: ..- ~:.,::~ 8813 9592 WESTEI~I ATLAS Logging Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD B-15 500292036000 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 05-DEC-95 5798.12 K. BRUNNER S. WHIPP 31 liN 14E 1519 1606 63.71 0.00 37.18 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 9.625 8713.0 3RD STRING 7.000 9738.0 PRODUCTION STRING 7.000 8256.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS BHCS GR 2 1 16-MAY-79 SWS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: 47.00 29.00 26.00 BASELINE DEPTH 8829.5 8836.5 8852.O 8878.0 8884.5 8886.0 8887.0 8895.0 8897.5 8900.0 8903.5 8904.5 8911.0 ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH 8832.0 8838.0 8854.0 8879.0 8887.0 8888.5 8889.0 8896.5 8899.5 8901.5 8905.5 8906.0 8912.5 8911.5 8917.5 8918.0 8948.5 8951.5 8964.5 8965.0 8967.0 8968.0 8982.5 8983.5 8986.5 9003.5 9004.5 9006.0 9019.0 9036.5 9037.5 9042.0 9050.0 9057.0 9065.0 9073.5 9074.0 9077.0 9079.5 9087.5 9092.5 9093.0 9099.0 9101.0 9110.0 9122.5 9123.5 9139.0 9139.5 9150.5 9151.5 9156.5 9158.0 9162.0 9167.0 9192.5 9199.5 9202.5 9208.0 9216.5 9221.0 9242.0 9248.5 9274.5 9326.0 9327.5 9338.0 9352.5 9353.0 9354.0 9366.5 9370.0 9371.0 8913.5 8919.5 8920.5 8951.0 8953.5 8966.5 8967.5 8969.5 8970.0 8984.5 8985.0 8988.5 9005.0 9005.5 9007.0 9020.5 9038.0 9038.5 9043.0 9051.5 9058.5 9066.0 9074.5 9075.5 9078.5 9080.5 9088.5 9094.0 9094.5 9099.5 9101.5 9111.5 9124.0 9124.5 9140.0 9141.0 9152.0 9152.5 9157.5 9159.5 9163.5 9168.0 9193 · 5 9200.0 9203.0 9208.0 9219.0 9223.0 9243.0 9249.5 9276.0 9327.0 9328.0 9338.5 9354.0 9354.5 9355.0 9367.5 9371.5 9372.5 9382.5 9386.0 9394.5 9407.5 9408.0 9408.5 9410.0 9410.5 9416.5 9418.0 9419.0 9428.5 9429.0 9441.5 9442.5 9451.0 9462.5 9463.0 9464.0 9485.0 9486.0 9494.5 9495.0 9498.5 9499.0 9506.5 9509.0 9511.5 9512.5 9525.5 9530.0 9534.0 9542.0 9543.0 9552.0 9552.5 9557.0 9558.0 9569.0 9573.5 9575.0 9575.5 REMARKS: 9383.0 9386.5 9395.0 9407.0 9408.0 9408.5 9409.0 9409.5 9416.5 9418.0 9418.5 9428.0 9429.0 9441.5 9442.0 9450.5 9463.0 9463.5 9464.0 9485.0 9485.5 9494.0 9495.0 9498.0 9498.5 9506.0 9508.5 9511.0 9511.5 9525.0 9529.5 9534.0 9542.0 9542.5 9551.5 9552.5 9557.0 9557.5 9568.5 9573.0 9573.5 9574.0 PDK-100/GR. TIED INTO 29-MAY-79 SONIC LOG. WELL TEST SUMMARY TEST DATE ELAPSED TIME GROSS FLUID RATE NET OIL RATE NET WATER RATE FORMATION GAS RATE GOR LIFT GAS RATE CASING PRESSURE TGOR TGLR CHOKE OPENING * HOURS 1.39 MBPD * MBOPD * MBWPD 1.96 MMSCFD 28205 SCF/STB * MMSCFD * PSIG * SCF/STB * SCF/BBL MANIFOLD PRESSURE * MANIFOLD TEMPERATURE * WATER CUT (CALC) 95 PSIG DEGF PCNT CONDITIONS DURING LOGGING: WELL WAS SHUT-IN 23-AUG-95 FOR HIGH WATERCUT. PUMPED 10 BBL METHANOL BEFORE GOING IN HOLE. SEEMS TO BE A WELLBORE CHANGE DURING THE PASSES FROM 9160' TO 9250'. A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR ALL FOUR PASSES. THE CURVE IS CALLED SGNT AND WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8.0" CASING SIZE = 7.0" SALINITY = 25,000 PPM. A PDK POROSITY CURVE (PHI) WAS ALSO CREATED FOR ALL FOUR PASSES. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY o 2) FIRST PASS SGMA (PDK) DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT PDK PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS PDK. / ? ?MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 8813.0 PDK 8825.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH SGMA 8829.5 8832.0 8836.5 8838.0 8852.0 8854.0 8878.0 8879.0 8884.5 8887.0 8886.0 8888.5 8887.0 8889.0 8893.0 8894.5 8895.0 8896.5 8897.5 8899.5 8900.0 8901.5 8903.5 8905.5 8904.5 8906.0 8911.5 8912.5 8917.5 8919.5 8918.0 8920.5 8938.0 8940.0 8948.5 8951.0 8951.5 8953.5 8964.5 8966.5 8965.0 8967.5 8967.0 8969.5 8968.0 8970.0 8972.0 8973.5 8975.5 8976.5 8977.0 8978.0 8982.5 8984.5 8983.5 8985.0 8987.0 8988.5 9003.5 9005.0 9004.5 9005.5 9006.0 9007.0 9019.0 9020.5 9036.5 9038.0 9037.5 9038.5 9042.0 9043.0 9050.0 9051.5 9057.0 9058.5 9065.0 9066.0 for each pass in separate files. STOP DEPTH 9580.0 9592.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH ......... 9073.5 9074.0 9077.0 9079.5 9087.5 9092.5 9093.0 9099.0 9101.0 9110.0 9122.5 9123.5 9128.5 9133.5 9136.5 9139.0 9139.5 9150.5 9151.5 9156.5 9158.0 9162.0 9167.0 9173.5 9187.5 9192.5 9199.5 9202.5 9208.0 9216.5 9221.0 9242.0 9248.5 9274.5 9326.0 9327.5 9333.0 9336.0 9338.0 9352.5 9353.0 9354.0 9366.5 9370.0 9371.0 9382.5 9386.0 9390.5 9394.5 9407.5 9408.0 9408.5 9410.0 9410.5 9416.5 9418.0 9429.0 9441.5 9442.5 9451.0 9074.5 9075.5 9078.5 9080.5 9088.5 9094.0 9094.5 9099.5 9101.5 9111.5 9124.0 9124.5 9130.5 9134.5 9137.5 9140.0 9141.0 9152.0 9152.5 9157.5 9159.5 9163.5 9168.0 9175.0 9188.5 9193.5 9200.0 9203.0 9208.0 9219.0 9223.0 9243.0 9249.5 9276.0 9327.0 9328.0 9334.5 9336.5 9338.5 9354.0 9354.5 9355.0 9367.5 9371.5 9372.5 9383.0 9386.5 9390.5 9395.0 9407.0 9408.0 9408.5 9409.0 9409.5 9416.5 9418.0 9429.0 9441.5 9442.0 9450.5 9462.5 9463.0 9464.0 9485.0 9486.0 9494.5 9495.0 9501.0 9506.5 9509.0 9511.5 9512.5 9525.5 9530.0 9534.0 9542.0 9544.5 9548.0 9557.0 9562.0 9568.5 9575.0 9575.5 $ REMARKS: 9463.0 9463.5 9464.0 9485.0 9485.5 9494.0 9495.0 9501.0 9506.0 9508.5 9511.0 9511.5 9525.0 9529.5 9534.0 9542.0 9545.0 9548.5 9557.0 9562.0 9567.5 9573.5 9574.0 PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. CN WN FN COUN STAT / ??MATCH1B. OUT $ : BP EXPLORATION (ALASKA) :B-15 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GRCH PDK 68 1 GAPI BIF PDK 68 1 BKL PDK 68 1 CPS BKS PDK 68 1 CPS CSLS PDK 68 1 CU LS PDK 68 1 CPS SS PDK 68 1 CPS MSD PDK 68 1 CU RATO PDK 68 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 10 RBOR PDK 68 1 11 RICS PDK 68 1 12 RIN PDK 68 1 13 SGMA PDK 68 1 CU 14 SGMB PDK 68 1 CU 15 SGNT PDK 68 1 CU 16 PHI PDK 68 1 PU-S * DATA RECORD (TYPE# 0) Total Data Records: 116 958 BYTES * 4 51 995 99 4 4 4 4 4 4 64 51 995 99 51 995 99 51 995 99 51 995 99 51 995 99 51 995 99 Tape File Start Depth = 9605.000000 Tape File End Depth = 8795.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27558 datums Tape Subfile: 2 482 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 2 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 .5000 START DEPTH 8813.0 8825.0 STOP DEPTH 9580.0 9592.0 (MEASURED DEPTH) BASELINE DEPTH 8815.0 8827.0 8838.0 8848.5 8850.0 8857.5 8858.5 8860.5 8861.0 8865.0 8866.0 8874.0 8876.5 8877.5 8878.5 8879.0 8881.5 8885.5 8886.0 8886.5 8887.0 8887.5 8898.0 8899.0 8899.5 8901.5 8902.5 8904.0 8905.0 8906.5 8907.0 8912.5 8913.0 8913.5 8915.5 8925.5 8926.5 in separate files. ......... EQUIVALENT UNSHIFTED DEPTH ......... GRCH SGMA 8817.5 8839.5 8850.5 8852.0 8859.5 8860.0 8875.5 8883.5 8887.5 8888.0 8888.5 8899.5 8901.5 8903.5 8905.5 8908.0 8909.0 8914.5 8915.5 8829.5 8859.5 8861.5 8862.5 8866.5 8867.0 8875.0 8878.0 8879.0 8881.0 8881.5 8888.0 8888.5 8889.0 8900.5 8901.5 8903.5 8904.0 8905.5 8906.0 8914.5 8918.0 8928.0 8928.5 8951.0 8952.0 8958.5 8960.0 8960.5 8961.0 8971.5 8973.0 8974.0 8981.0 89-81.5 8993.5 8994.5 9006.5 9007.5 9018.5 9019.0 9038.5 9039.5 9042.5 9043.0 9043.5 9044.0 9046.5 9054.0 9056.0 9061.0 9062.0 9065.0 9065.5 9066.5 9083.0 9083.5 9084.0 9088.5 9089.0 9093.5 9095.0 9096.5 9097.0 9101.0 9109.0 9115.5 9118.0 9119.0 9119.5 9120.5 9121.5 9122.5 9123.5 9124.0 9132.0 9133.0 9134.0 9134.5 9139.0 9139.5 9152.5 9153.5 9154.5 8953.5 8954.0 8995.5 8996.0 9048.0 9055.5 9058.0 9066.5 9067.0 9067.5 9084.0 9084.5 9085.0 9097.5 9098.5 9102.5 9123.0 9124.0 9125.0 9140.0 9141.0 9154.0 9154.5 8960.5 8962.5 8963.5 8964.0 8973.0 8974.5 8975.0 8982.0 8983.0 9008.0 9008.5 9019.5 9020.5 9040.0 9040.5 9043.5 9044.5 9045.0 9045.5 9062.5 9063.0 9089.5 9090.5 9095.0 9096.0 9110.0 9117.5 9120.0 9120.5 9121.5 9122.5 9123.0 9133.5 9134.0 9135.0 9136.0 9155.0 9155.5 9157. 9158. 9159 · 9161. 9161. 9163. 9165. 9166. 9166. 9167. 9179 · 9180. 9180. 9182. 9185. 9193. 9193. 9195. 9199 · 9201. 9210. 9210. 9211. 9211. 9222. 9223. 9225. 9239. 9239. 9240. 9241. 9243. 9244. 9245 · 9245. 9284. 9288. 9288. 9319. 9327. 9327. 9328 · 9329. 9332 · 9333. 9333. 9338. 9352. 9353. 9354. 9371. 9379. 9380. 9383. 9385. 9386. 9394. 9397. 9399 · 9399. 9160.5 9162.5 9163.0 9164.5 9181.0 9182.0 9183.0 9186.0 9194.0 9195.5 9200.0 9242.0 9339.5 9354.5 9355.5 9356.0 9373.0 9384.0 9395.5 9397.5 9399.0 9158.5 9159.5 9166.5 9167.0 9167.5 9168.5 9180.5 9181.0 9194.5 9201.5 9210.5 9212.5 9213.0 9214.0 9225.0 9225.5 9227.5 9240.5 9241.0 9241.5 9242.5 9244.5 9245.0 9246.0 9247.0 9286.0 9290.0 9290.5 9321.0 9328.5 9329.5 9330.0 9330.5 9334.0 9334.5 9335.0 9380.5 9381.0 9386.0 9386.5 9400.0 9401.0 9404.5 9409.0 9409.5 9410.0 9410.5 9413.0 9416.0 9417.0 9426.5 9427.0 9432.0 9441.0 9442.0 9451.0 9451.5 9461.0 9463.0 9464.0 9468.5 9472.0 9481.0 9484.5 9485.5 9492.0 9494.0 9495.0 9499.5 95O0.5 9501.5 9506.5 9507.0 9508.5 9509.5 9510.5 9511.5 9526.0 9526.5 9527.0 9527.5 9532.0 9540.0 9541.0 9549.5 9550.5 9553.0 9558.5 9562.0 9563.0 9563.5 9565.5 9566.5 9567.0 9571.0 9572.5 9573.5 9574.0 9575.5 9579.0 9585.0 9404.5 9409.0 9409.5 9410.5 9416.5 9417.0 9426.5 9427.5 9432.5 9441.0 9451.0 9463.5 9469.0 9472.0 9481.5 9494.5 9495.0 9506.5 9507.5 9511.0 9511.5 9526.5 9527.0 9528.0 9550.O 9550.5 9553.0 9558.5 9563.0 9564.0 9566.0 9566.5 9574.0 9574.5 9401.0 9409.5 9410.0 9413.5 9441.5 9442.0 9451.5 9462.0 9464.0 9464.5 9485.0 9485.5 9492.0 9500.5 9501.5 9502.0 9509.0 9509.5 9526.0 9532.5 9540.5 9542.0 9563.0 9563.5 9566.5 9567.0 9570.5 9572.0 9572.5 9578.0 9584.5 9585.5 9588.5 $ REMARKS: 9585.0 9587.5 PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN STAT / ? ?MATCH2A. OUT / ? ?MATCH2B. OUT $ : BP EXPLORATION (ALASKA) : B - 15 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 8 MSD PDK 68 1 CU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 15 SGNT PDK 68 1 CU 4 16 PHI PDK 68 1 PU-S 4 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 116 Tape File Start Depth = 9605.000000 Tape File End Depth = 8795.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27558 datums Tape Subfile: 3 369 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8813.0 9580.0 8825.0 9592.0 (MEASURED DEPTH) BASELINE DEPTH 8814.5 8851.5 8857.0 8858.0 8858.5 8860.5 8868.0 8869.0 8870.5 8873.0 8877.5 8878.0 8879.0 8879.5 8881.0 8885.0 8886.0 8886.5 8887.0 8887.5 8888.0 8898.5 8899.0 8901.5 8902.5 8904.5 8905.0 8906.0 8907.5 8911.5 8913.5 8915.5 8917.0 8917.5 8918.0 8918.5 8919.5 in separate files. ......... EQUIVALENT UNSHIFTED DEPTH ......... SGMA GRCH 8816.0 8853.0 8858.5 8859.0 8871.5 8881.0 8886.5 8888.5 8889.0 8899.5 8906.0 8906.5 8909.5 8913.5 8920.0 8861.0 8861.5 8869.0 8869.5 8873.5 8879.5 8881.0 8882.0 8883.5 8887.5 8888.0 8888.5 8899.5 8900.5 8903.0 8903.5 8906.0 8906.5 8914.0 8917.5 8919.0 8920.0 8921.0 8921.5 8926.0 8927.0 8927.5 8931.0 8932.0 8946.0 8946.5 8947.5 8948.5 8953.0 8954.0 8958.5 8960.0 8960.5 8961.0 8966.5 8967.0 8970.0 8975.5 8986.0 8994.0 8994.5 9003.5 9004.5 9006.0 9007.0 9008.0 9009.0 9016.0 9016.5 9018.5 9019.0 9028.5 9029.5 9030.0 9031.0 9036.0 9036.5 9037.5 9044.0 9044.5 9045.0 9050.5 9051.0 9052.5 9057.5 9058.5 9071.5 9072.5 9075.0 9075.5 9095.5 9096.5 9100.5 9104.5 9105.0 9109.5 9120.0 9120.5 9121.5 8955.0 895~5.5 8962.5 8969.0 8971.5 8977.5 8987.5 9005.0 9005.5 9020.0 9030.0 9030.5 9037.0 9038.0 9039.0 9053.5 9072.5 9073.0 9075.5 9076.5 9101.5 8928.0 8928.5 8929.5 8933.0 8933.5 8947.5 8948.5 8949.5 8950.0 8960.0 8960.5 8961.0 8968.5 8971.0 8995.0 8996.0 9007.5 9008.0 9009.0 9009.5 9016.5 9017.5 9019.5 9020.5 9031.5 9032.0 9045.0 9045.5 9046.0 9051.5 9052.5 9059.0 9059.5 9096.5 9097.0 9105.0 9106.0 9110.5 9121.5 9122.0 9122.5 9122.0 9123.0 9123.5 9124.0 9127.0 9127.5 9128.0 9129.0 9130.0 9139.0 9139.5 9140.0 9147.0 9148.0 9153.5 9154.5 9164.5 9166.0 9166.5 9167.5 9170.0 9170.5 9177.5 9178.5 9192.5 9193.5 9196.0 9199.0 9203.5 9217.0 9230.0 9239.5 9240.5 9246.0 9247.5 9248.0 9272.0 9272.5 9274.0 9275.0 9278.0 9278.5 9288.5 9289.5 9292.0 9292.5 9299.5 9300.0 9301.0 9326.5 9327.0 9327.5 9337.0 9338.0 9338.5 9352.5 9353.0 9354.0 9355.5 9356.5 9123.5 9124.0 9125.0 9128.0 9128.5 9129.0 9140.0 9141.0 9148.5 9149.0 9165.5 9166.5 9167.0 9168.5 9193.5 9196.5 9204.0 9247.0 9327.5 9339.5 9354.5 9357.5 9358.0 9123.5 9130.5 9131.0 9140.5 9141 · 5 9155.0 9155.5 9171.0 9172.0 9179.0 9179.5 9193.5 9194 · 0 9200.0 9219.5 9231.5 9241.0 9241.5 9248.5 9249.5 9273.5 9274.5 9276.0 9276.5 9279.5 9280.5 9290.5 9291.0 9293.5 9294.0 9301.5 9302.0 9302.5 9328.5 9329.5 9339.0 9339.5 9340.0 9354.5 9355.0 9355.5 9362.5 9363.0 9370.5 9374.5 9375.0 9376.0 9377.0 9382.0 9383.0 9384.5 9385.0 9393.0 9394.0 9395.5 9400.5 9405.5 9406.5 9408.5 9409.5 9411.0 9415.5 9416.0 9417.0 9422.5 9423.0 9434.5 9435.5 9439.0 9440.0 9451.5 9452.0 9460.0 9474.5 9476.5 9477.5 9478.5 9479.0 9479.5 9483.5 9484.5 9485.0 9494.0 9496.0 9505.0 9506.0 9507.5 9518.5 9527.5 9531.5 9532.0 9534.0 9540.0 9540.5 9542.5 9543.5 9551.0 9554.0 9563.0 9567.0 9567.5 9364.0 9365.0 9372.5 9383.5 9385.0 9386.0 9396.5 9401.0 9406.0 9406.5 9408.5 9409.0 9410.5 9417.0 9422.5 9423.5 9452.0 9475.5 9477.5 9478.0 9479.0 9480.0 9484.5 9485.5 9508.0 9519.0 9528.0 9532.0 9535.0 9543.5 9544.0 9376.0 9377.0 9378.0 9378.5 9383.5 9384.0 9394.0 9394.5 9409.0 9409.5 9415.5 9416.5 9435.0 9436.5 9440.0 9440.5 9452.5 9461.0 9480.5 9485.0 9494.5 9497.0 9506.0 9506.5 9532.0 9533.0 9541.0 9542.0 9552.5 9555.0 9564.0 9567.5 9568.0 9568.5 9573.5 9577.0 9578.0 9586.5 9587.5 $ REMARKS: 9574.0 9568.5 9577.0 9577.5 9586.0 9586.5 PASS 3. ALL PDK CURVES WERE SHIFTED WITH SGMA. CN WN FN COUN STAT / ??MATCH3A. OUT / ??MATCH3B. OUT $ : BP EXPLORATION (ALASKA) : B- 15 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 4 51 995 99 1 2 BIF PDK 68 1 4 4 51 995 99 1 3 BKL PDK 68 1 CPS 4 4 51 995 99 1 4 BKS PDK 68 1 CPS 4 4 51 995 99 1 5 CSLS PDK 68 1 CU 4 4 51 995 99 1 6 LS PDK 68 1 CPS 4 4 51 995 99 1 7 SS PDK 68 1 CPS 4 4 51 995 99 1 8 MSD PDK 68 1 CU 4 4 51 995 99 9 RATO PDK 68 1 4 4 51 995 99 1 10 RBOR PDK 68 1 4 4 51 995 99 1 11 RICS PDK 68 I 4 4 51 995 99 1 12 RIN PDK 68 1 4 4 51 995 99 1 13 SGMA PDK 68 1 CU 4 4 51 995 99 1 14 SGMB PDK 68 1 CU 4 4 51 995 99 1 15 SGNT PDK 68 1 CU 4 4 51 995 99 1 16 PHI PDK 68 1 PU-S 4 4 51 995 99 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 116 Tape File Start Depth = Tape File End Depth = 9605.000000 8795.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 55116 datums Tape Subfile: 4 373 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH STOP DEPTH 8813.0 9580.0 8825.0 9592.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH GRCH 8814.0 8815.0 8820.0 8820.5 8820.5 8821.0 8821.0 8822.0 8827.0 8857.0 8858.0 8858.0 8858.5 8859.0 8859.5 8860.0 8860.0 8863.0 8863.0 8863.5 8864.0 8864.5 8865.5 8871.5 8872.5 8873.0 8873.5 8874.0 8874.5 8874.5 8875.5 8883.0 8885.5 8886.5 8886.0 8886.5 8887.5 8887.5 8888.0 8898.5 8899.0 8899.5 8900.5 8900.5 8901.0 8902.5 8903.5 8905.0 8905.5 8906.5 8906.0 8906.5 8907.0 8907.5 8908.0 8908.0 8909.0 8913.0 8914.0 SGMA 8829.5 8858.0 8859.0 8859.5 8865.0 8865.5 8871.5 8872.0 8873.0 8873.5 8876.5 8884.0 8886.5 8901.0 8902.0 8903.5 8904.0 8905.5 8906.0 8913.5 8915.5 8916.5 8926.0 8927.0 8927.5 8928.0 8931.0 8932.0 8951.0 8953.0 8958.5 8961.0 8965.5 8966.0 8967.0 8970.5 8976.0 8977.0 8979.0 8979.5 8993.0 8994.0 9005.0 9006.5 9011.0 9015.5 9016.5 9018.5 9024.5 9025.5 9036.0 9036.5 9037.0 9039.0 9039.5 9040.0 9042.5 9043.0 9047.5 9048.5 9049.5 9050.0 9050.5 9053.0 9062.0 9071.5 9072.0 9072.5 9087.5 9093.0 9094.0 9101.0 9105.5 9106.0 9110.0 9115.5 9120.5 9121.5 9122.0 8918.0 8952.5 8954.0 8962.0 8967.0 8967.5 8968.0 8994.0 8994.5 9005.5 9019.5 9025.5 9026.0 9036.5 9037.5 9038.0 9040.0 9048.0 9049.5 9054.0 9062.5 9072.0 9072.5 9073.0 9088.0 9101.0 8913.5 8917.0 8927.5 8928.0 8928.5 8929.5 8932.5 8933.0 8959.5 8968.5 8971.0 8976.5 8977.0 8979.0 8980.0 9007.0 9011.0 9015.5 9017.0 9039.5 9040.0 9042.5 9043.5 9050.0 9050.5 9051.0 9093.5 9094.0 9105.5 9106.5 9110.5 9116.5 9121.5 9122.0 9123.0 9123.5 9126.5 9128.5 9129.5 9139.5 9140.0 9141.0 9141.5 9153.0 9154.0 9189.5 9190.5 9191.5 9192.5 9193.0 9196.5 9199.5 9207.5 9208.5 9210.0 9210.5 9220.0 9220.5 9222.0 9225.0 9230.0 9231.0 9239.5 9245.0 9246.0 9250.0 9270.5 9271.5 9272.0 9274.0 9275.0 9304.0 9305.5 9306.5 9311.5 9322.0 9326.5 9327.0 9327.5 9337.0 9338.0 9338.5 9352.5 9353.0 9353.5 9354.5 9355.5 9356.0 9359.0 9360.0 9362.0 9364.0 9365.0 9373.5 9374.0 9123.5 9127.0 9141.5 9142.5 9154.0 9154.5 9192 · 0 9192.5 9193.0 9196.0 9199.0 9246.5 9327.0 9339.0 9354.0 9363.0 9365.5 9366.5 9129.5 9130.0 9140.0 9141.0 9154.0 9154.5 9190.0 9190.5 9207.5 9208.0 9209.5 9212.0 9221.5 9222.5 9224.0 9226.0 9228.5 9229.5 9240.5 9246.0 9246.5 9250.5 9271.5 9272.5 9273.5 9275.5 9276.0 9305.0 9306.5 9307.0 9312.0 9323.0 9328.0 9329.0 9338.5 9339.0 9354.0 9355.0 9355.5 9356.5 9357.5 9360.5 9361.0 9374.5 9375.5 9375. 9376. 9382. 9383. 9383. 9398. 9399. 9401 · 9405 · 9406. 9408 · 9409. 9416 · 9416. 9436 · 9437 · 9441. 9442 · 9451 · 9463 · 9464 · 9473. 9474 · 9483 · 9484 · 9485 · 9485. 9494. 9496. 9507. 9508. 9509. 9510. 9522 · 9525. 9526. 9527 · 9528. 9530. 9531. 9536. 9537. 9537. 9540. 9540. 9542. 9543. 9552 · 9553. 9554. 9563. 9566. 9567 · 9570. 9574 · 9577 · 9578 · 9581. 9585. 9587 · 9383.5 9399.0 9401.0 9405.5 9406.0 9408.0 9409.0 9464.5 9473.0 9475.0 9483.5 9485.5 9507.5 9508.5 9509.5 9510.0 9525.5 9526.5 9528.5 9531.5 9537.0 9537.5 9538.0 9543.0 9543.5 9574.0 9377.0 9377.5 9383.5 9384.0 9399.0 9399.5 9409.0 9416.0 9417.0 9437.0 9437.5 9441.5 9442.0 9451.0 9463.5 9484.5 9485.0 9494.0 9496.5 9508.5 9522.0 9527.5 9530.5 9540.5 9541.5 9553.5 9554.0 9555.0 9563.5 9566.0 9567.5 9570.0 9576.5 9577.0 9580.0 9585.0 9586.5 $ REMARKS: PASS 4. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH4A. OUT / ??MATCH4B. OUT $ : BP EXPLORATION (ALASKA) : B- 15 : PRUDHOE BAY : NORTH SLOPE : ALASKA CN WN FN COUN STAT * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 8 MSD PDK 68 1 CU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICS PDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 15 SGNT PDK 68 1 CU 4 16 PHI PDK 68 1 PU-S 4 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 116 Tape File Start Depth = 9605.000000 Tape File End Depth = 8795.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 55116 datums Tape Subfile: 5 367 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: .5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH PDK $ REMARKS: CN WN FN COUN STAT 1 1, 2, 3, 4 AVERAGED PASS. PASSES 1, 2, 3, & 4 WERE AVERAGED. $ : BP EXPLORATION (ALASKA) : B- 15 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PNAV 68 1 GAPI 4 2 BIF PNAV 68 1 4 3 BKL PNAV 68 1 CPS 4 4 BKS PNAV 68 1 CPS 4 5 CSLS PNAV 68 1 CU 4 6 LS PNAV 68 1 CPS 4 7 SS PNAV 68 1 CPS 4 8 MSD PNAV 68 1 CU 4 9 RATO PNAV 68 1 4 10 RBOR PNAV 68 1 4 11 RICS PNAV 68 1 4 12 RIN PNAV 68 1 4 13 SGMA PNAV 68 1 CU 4 14 SGMB PNAV 68 1 CU 4 15 SGNT PNAV 68 1 CU 4 16 PHI PNAV 68 1 PU-S 4 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 116 Tape File Start Depth Tape File End Depth = 8795.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 82674 datums Tape Subfile: 6 138 records... Minimum record length: 62 bytes Maximum record length: 958 bytes = 9605.000000 Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8811.5 PDK 8823.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9584.0 9596.0 28-NOV-95 FSYS REV. J001 VER. 1.1 1021 28-NOV-95 9734.0 9600.0 8825.0 9592.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PDK PDK-100 $ TOOL NUMBER 3913NA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9738.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 700 FAR COUNT RATE HIGH SCALE (CPS): 3200 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): REMARKS: PASS 1. $ 0.0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : B - 15 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 ISS PDK 68 1 CPS 4 9 LS PDK 68 1 CPS 4 10 SS PDK 68 1 CPS 4 11 MON PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 TEN PDK 68 1 LB 4 21 SGNT PDK 68 1 CU 4 22 PHI PDK 68 1 PU-S 4 4 51 310 01 4 51 995 99 4 51 391 51 4 51 390 51 4 51 150 01 4 51 995 99 4 51 995 99 4 51 995 99 4 51 391 99 4 51 390 99 4 51 430 01 4 51 995 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 400 01 4 51 995 99 4 51 636 99 4 51 635 99 4 51 995 99 4 51 995 99 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 291 Tape File Start Depth = 9599.000000 Tape File End Depth = 8799.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 128740 datums Tape Subfile: 7 366 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8809.0 PDK 8821.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9588.0 9600.0 28-NOV-95 FSYS REV. J001 VER. 1.1 1121 28-NOV-95 9734.0 9600.0 8825.0 9592.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PDK PDK-100 $ TOOL NUMBER 3913NA 2725XA BOREHOLEAND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9738.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 700 FAR COUNT RATE HIGH SCALE (CPS) : 3200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) :B-15 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 ISS PDK 68 1 CPS 4 9 LS PDK 68 1 CPS 4 10 SS PDK 68 1 CPS 4 11 MON PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 I 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 TEN PDK 68 1 LB 4 21 SGNT PDK 68 1 CU 4 22 PHI PDK 68 1 PU-S 4 4 51 310 01 4 51 995 99 4 51 391 51 4 51 390 51 4 51 150 01 4 51 995 99 4 51 995 99 4 51 995 99 4 51 391 99 4 51 390 99 4 51 430 01 4 51 995 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 400 01 4 51 995 99 4 51 636 99 4 51 635 99 4 51 995 99 4 51 995 99 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 294 Tape File Start Depth = 9603.000000 Tape File End Depth = 8795.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 157034 datums Tape Subfile: 8 369 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NI/MBER: 8 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8811.5 PDK 8823.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9590.5 9602.5 28-NOV-95 FSYS REV. J001 VER. 1.1 1221 28-NOV-95 9734.0 9600.0 8825.0 9592.0 900.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PDK PDK-100 $ TOOL NUMBER 3913NA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9738.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT) : 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 700 FAR COUNT RATE HIGH SCALE (CPS): 3200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: PASS 3. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : B- 15 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 ISS PDK 68 1 CPS 4 9 LS PDK 68 1 CPS 4 10 SS PDK 68 1 CPS 4 11 MON PDK 68 i CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 I 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 i CU 4 19 SPD PDK 68 1 F/MN 4 20 TEN PDK 68 1 LB 4 21 SGNT PDK 68 1 CU 4 22 PHI PDK 68 1 PU-S 4 4 51 310 01 4 51 995 99 4 51 391 51 4 51 390 51 4 51 150 01 4 51 995 99 4 51 995 99 4 51 995 99 4 51 391 99 4 51 390 99 4 51 430 01 4 51 995 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 400 01 4 51 995 99 4 51 636 99 4 51 635 99 4 51 995 99 4 51 995 99 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 294 Tape File Start Depth = 9606.000000 Tape File End Depth = 8798.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 203100 datums Tape Subfile: 9 369 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8812.0 PDK 8824.0 $ LOG HEADER .DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PDK PDK-100 $ STOP DEPTH 9588.0 9600.0 28-NOV-95 FSYS REV. J001 VER. 1.1 1323 28-NOV-95 9734.0 9600.0 8825.0 9592.0 900.0 YES TOOL NUMBER 3913NA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 9738.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZING WINDOW (FT): 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 700 FAR COUNT RATE HIGH SCALE (CPS) : 3200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS) : 60000 TOOL STANDOFF (IN): 0.0 REMARKS: -~ PASS 4. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : B - 15 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 22 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 ISS PDK 68 1 CPS 4 9 LS PDK 68 1 CPS 4 10 SS PDK 68 1 CPS 4 11 MON PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 TEN PDK 68 1 LB 4 21 SGNT PDK 68 1 CU 4 22 PHI PDK 68 1 PU-S 4 4 51 310 01 1 4 51 995 99 1 4 51 391 51 1 4 51 390 51 1 4 51 150 01 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 4 51 391 99 1 4 51 390 99 1 4 51 430 01 1 4 51 995 99 1 4 51 420 99 1 4 51 420 99 1 4 51 420 99 4 51 420 99 1 4 51 400 01 1 4 51 995 99 4 51 636 99 1 4 51 635 99 1 4 51 995 99 1 4 51 995 99 1 88 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 294 Tape File Start Depth = 9603.000000 Tape File End Depth = 8795.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 231394 datums Tape Subfile: 10 369 records... Minimum record length: Maximum record length: 62 bytes 1018 bytes CONFIDENTIAL STATE OF A~SKA Alaska Oil & Gas Cons. Commission Anchorage SERVICE NAMF : ~.~ £ T DATE :55/05/ ~ 8RiGiN : RE~L N6M= : CONT~,N~ATi~N · :~i COMMENTS : SE~ViCi DATE TAPE Cg7~TZNJATI;N ~V~O~S COMN-NTS FI~E TYP:." . PRCVI~JdS FiL!~ M N ~E M C C N T i~ N T $ jNi'T TYPE CATE 000 0~,0 030 OOC GO0 OO3 0O2 uuO ~gO OOO 000 003 0 5,5 ~ gu O01 : A~ASKA DI'~iS''N CS~PUTiNG CnNT2~: : TGP LO!,,; iNTERVAL = gASING-L2GGEq : 51T S i Zi:: : O.OOO /YP~ H~SL[ FLUIDS : gZL. g£NSiTY = O . ViSCSS~'T . FT. ~} 3 .=T.. ~ C F ~ 0 F ENTRY' gLgC~S MN~M DEPT ~SR SPECiF~'rAT"'ON~ . 5LSCKS S:RVICE S!ERVlZ~ JN~.r~, A FT PSi PU NPH~ , NR~ ~SZ "PS ,~ P S ,SAP1 PU GR P P~i PS 3 .RAT NCNL ~R CPS CPS Pi AP~ APi APi FILE SIZE SO 'TYP: CLASS ~gD NJ. OC 310 O1 0 3 ~ gO ~go JO O ~ 4 OS ~'20 gl C 0 ~ O0 OOO O0 O 0 ~ gO 330 31 G 0 ,~ dC 330 JO O O ~ O0 lSD Oi 0 O Oo ~O O1 o 0 OO 3~0 OO ~ O SP % i ~JO~OuuOuO~O~ ~VP 0i3.H0£ VS~IFi'ATiSN 21gT.l'!JG oaO~ W NR~T PS~ NCNL PS4 CPS CCL ~S~ C)~PT 9'q'O 0" O OgO RNRA ~ '~ L~:R 21'5. 9531 NPHi N'RAT ~.T852 RNRA ~.C~ O. 3C 330 ~0 0 O OC L53 :~I 3 O 0938 ~P~ 7.~0.500C CCL ~.Z221 NCqL -99~.2500 -'~9~,Z500 .~5 00000000000002 ~.~ COOOOJOOOO000~ i ~:5 576..~000 CCc ~ '~578 RNR~ O.OOO0 ~go.oOCO PCNL 52-1562 274~.0030 20.996I 59i.5000 ~.7930 24.D23~ 53~.0000 ~ . .L 4-5 4 Z 7. ~ 3 75 ~ :~ 9 ~'5, JO;lO 17.96.57 13~a.uOuu NCNL 697~,0000 FC~L z3~0.,~030 CC, NPqI 15.5223 NR4T 3.7578 RN~A FCNL 1827,0000 CCL 3,0000 NR~T 3.7910 RN~A 3,7532 :~C '~L CCL 3E~T 9100.0000 SR 25,5313 NP~i GR 2~. 078i NPmi :~CNL ~52~.3000 ~CNL NP~i 28.~57~ NR4T 5.~672 RNa4 FCNL ~t3. 5030 NR~T 5. I1 12 ~NRA 4, ~'961 NC'~L CCL O.OOOO ~ :E~ T 8;~00.,0000 JR, ~..~,1~5 NP,.iI RNRA 3,357~ NCNL 5 5.q-,~. O 00 C '=CNL 1533. OCO0 ~C_ ~NRA .3. 380:9 NC Nt~. O:EPT NCNL $£.5, TSOO CCL rCCL -~9'-~. -999'Z~0C - 999. 2500 ~R ~T - 999. 2500 CC_ 7.5703 -999.2 5 O0 -'~'9 9.2~ OO NC 25.3906 NR~T )~,5. 5000 .5.0977 O.O000 5.0156 NCNL 23.98~4 ~92.~000 ,FCNL ~.5705 O.OOOO I~.06~5 .~lOO.OOOO O.OOCO 2~.5125 4.85!6 53.~375 535~.0000 2.I.&202 5.. ~844 NCNL -9~9,2500 NR~T --99~, 1500 CCi -999. i500 GR 6.5953 NCNL -'~99. ZSOO NPH'i -999.2500 FCN~ '-993.~5g0 ~RZGZN C~NTiNJATiSN ~ :01 N,EXT TAP2 ~,AME : CCM~'ENTS : bis TAPE ~, [iVi~'"UR~iAT.ION RECORDS U ~.: 'l T T ¥ P g C A T E S I, Z E C 0 D F 000 000 03t) 065 0()0 ()00 004 065 000 000 01~ 0~5 ()0() 000 004 065 000 000 004 065 000 000 002 065 000 : 000 004 065 ~ ALASK~ C£~MP!,}TING C~'N]JER ~ ~gLL = b-15 F1EGO = PRtID~i~E~ BAY JEIB i'iUqBEi~ AT ACC: 6834~ R. Ui~ ~I, L) AI!"2 i.,tI3GILL;: 17-~'qaY-S3 [,DP: d ~l Pi I'~ ]']~PE l. bUli) FLUIL) bgVgb -- C. L'~ tJ D P.; [)[ L ID DEp r NPHI PS1 NRAI · 0,~ J3 L, UC 1~,5 oh:ru~, SPECIFICATi' ~EM S~SRvlCe~ SERVICE UNI'I: APl AP1 ~PI APl FILE S1ZE ORDER # LOG TYPE Cb/laS I~iO0 tit:!. 6E~EI~ CODE F T 0 0 0 0 0 4 F U 0 68 2 0 0 4 0 42 I O u 4 : 0 0 0 0 o 4 o 4 0 4 G A P' l 0 31 32 0 0 4 0 :~ 2 I 0 GA[' I 0 3 1 .3 2 0 0 1 Ca8 I b8 I 6 8 1 6 -I 6 8 1, 68 6 ~ 68 6~ C, Al-' 1 0 3 1 3 2 0 0 4 0 NCNb N R A '1 DEPI NRAr GR NCNb NRAT NCNb J~,j F'~ · ' GR NCNb N RAT 9'701,o000 NPHI 24.4141 NRA7~ 2182.0000 FCNN 476.2500 {;R -999.2500 RN~A -999.2500 NCNL -9)9.2500 NPH] -999.2500 NRA'] -999.2500 ~-CNL -999.2500 (;R 9'100.0000 NOhl 24.4141 2[82.0000 FC~I, 476.2500 -999.2500 R~A -999.?500 -999.2500 NPH1 -999.2500 NRAT -999.2500 FCNb -g99.25(i0 9bO0.O000 NP~i! 20.0684 NR~T 253~.0000 FCNb 043.5000 GR 4.5547 RNRA 4.4453 NC~I, 188.1250 NPHI 22.9304 N~AT 2500.0000 ~'C~D bbb.5000 G~ 9500.0000 hPtil 25.2441 NEA~ 2158.00~0 FCNb 445.5000 G~ ~.5977 RN~A 4.1211 NCNI~ 193.8750 NPHI 2~.16~0 NR~T 20?4.0000 ~CNb 527.0000 GR 9':}00. 0000 NPHI 23.7305 Nt~ A'[ 2550.0000 FCNL: : 570.5000 GR 4.6289 NCN[, t'l Z' .218:t NEAT 2822.0000 FC~b ~29.0000 Giq 4.55~6 180,5000 NP~iI : 19,9707 NRA1~ 3 ~ 4.0000 F C N b I 'l 39.0000 (;Iq L)EPT 9200.0000 NPitl NCNL 6000. 0000 FCNL 1:9:'17. 0000 -- ' r~ " "~* ' ~ i NRA[ 3.31~4 RNRa 2 9570 NCNL GR 174.5000 :NPB-t N Z N b 5 ~ 80.0 () 00 F C N R AT GR NCNL, 5. lush RNFA I 81 ' 6250 NPHI 25:':0977 : NRAT: 4016.0000 FC N 1., 8~8'000() (JR D E P I~ 9000.0000 NPill 19.t~242 NRA'I: 4.9414 220.1250 NPH1 -999.2500 -999.7500 -999.2500 4.57Ul -99q.2500 -999.2500 -999.25OO 4.941 4 PhPA 220. I 250 ~PEI - 999.2500 F C t~: I, -999. 2500 RNRA -999.2500 4.578i -999.2500 -999.2500 -ggg.2500 4.4102 191.b250 251.4.0000 4.7578 ~NFA 192.2500 3.9395 21.2402 565.5000 4.4102 5.0391 181.0000 NFHI 2116.0000 FCNL 4.b680 204.7500 4.8033 21.5820 513.0000 3.9336 177.7500 NF'E1 2820.0000 FCNL 4.9~:19 RNRA 179. 3750 4.4844 24.267b 609 0o00 4.4844- 4.3672 ~N~A 4.0820 179.2500 ~t~] 21.240~ · 4712'0000 FC~ii.~ 1042.0000 i84.3945~ RNi~A 3.8,477 .1250 3.2734 RNRA 3. 1289 180,0:000 NPH1 11.-8052 5928.0000 FC~L 2004.0000 3- 293 0 5.12~g [~NRI% 17:9.6250NPH.[: 3974.0000 FCNL RN:Rg 4.8125 2 5.7 3 2 .' 833.5000 4~.6250 4. 3750 4.0508 I 1 ~4. 0000 GR 18.7988 NRAT 1320.0000 6[4 flCNb 46~0.0000 FCN£, bRAT 3.7383 RN~A g~ 1~0.8750 NPttl N~N[., 4692.0000 FC~L 15 . 3 32.0 1367.0000 3.5781 NCNL 15.0391 NRAT 13~0.0000 DEPT 8uOU.O00O r~PH! N~NL 2482.0000 FC~b NRAI' 0.433t~ GR 230.3750 NP~I N~hb 2530.0D00 FCN[, 39.09'73 bRAI: 408.5000 G~ 5.5508 ~Ci~L 42.5781 N~AT 399.5000 (;}~ OEP1 8745.0000 NPHI NCNi,, -999,2500 FCNL NRAii -999.2500 RN~.A GR -9)9,2500 NPHI N~N~ 2b.{2.UO00 FCiqb -999.2500 NRAq o999, ~ 500 (;[~ -999.~500 NCNb 41.113] NRAT 4.1b.2500 GI& 20 1.0000 50 ] ? . 0000 4.2461 204 . '1500 3.7949 197.8150 4'736.0001) 3.7520 194.~750 ~.5508 233.5000 2450.0000 6.7656 ?36.0000 -999.2500 =999.~500 -999.2500 23~.0000 i~PH1 FCNI, k I'~ E A FCNI, I -t. 1875 1. 356..0000 3.8418 3.421.9 14.9414 1323.0()00 3.4492 6.0742 3~.]301 44i.2500 6.347'1 -999.2500 -999.2500 -999.2500 b .OB20 ** FIL, E TRAIt~ER FILE [~ ~,~ L : $i~:kV I.C. 00 I, SER¥ICE NA~iE VER. SIuN ~ : DATE : NEXT ~'IL~ TAPE TRAILER** :Sf;~VIC ,IL. L ] i ,l ! I I I t 11 .Il I t I I 1 i. 11 I1 t [ i i I i I ~Y 11 !1 O~-JL}[,-'?~ 10:1 3:4-% lO:14:42 1070~, 5%621 I. APL', PR~VI[JU~ TAPE: C 0 - 2 F,P 3 CLLD (')lb ~ ClbM L:JL S Ci~.bi~ t)lL 10 L) Fi }-1 (s 1. 1 ?]P~ I (/!'aL 12 14HiiB ~'DC 1 4 '?,,~Ci"iL C'l'.,~l..~ 15 ~C:"~L, C~xiL [.)$L k l)lr, F I b 1_; { .i C F,: fi: L) t~ 1.' i::' tj 't' A iq [-: h '~ 9750.000 Q7vO. 9500 q $ 0 0.0 0 0 930o.000 qgu'o. O00 q ! O0. 000 9 () 0 0 . 000 ~qO0. 000 ~ ~ 0 0.0 0 0 C, 0 5(:,. 00 00 Si" N C H L C' t!., i"~ ] t ~. 0 :l 9 C i., b 8 '2 i 4.7 O 5 ~H(!r~ 2.588 i',~p~A'l 2.801 11., ex 1 ~s ~. 93 ,) C i., i.; 9 b 5. I 13 F~ 5t,.71.9 CAi,I b.e:,t ? kit lb ). 'i 79 i'..,i t4 A 'i :2.453 C liJ~*i 32h. 115 CL, I,~ 154.031 (~k 51. ~ t. 3 (.:AL J ~. 594 ki!tiPt 2.., ~32 r~'. A T 2. t.. l/ ~,t i -:12.ol8 -68. 750 Cibi) 41 ~8.00o rC.Hb lbb5.O00 - ~ 5 · 25 u ('.: .i i, D 4. A. :~ 22 57.2I 9 DT 85. 563 0 ,. O O 7 f,,t [,,' i-t i 24. ~ 65 3 4 7 iq. 0 0 0 b C .f,,l L, I 3 i 0.0 0 (',~ C bt.,8 4.3 . 5 .,';t 7 C/!bt ,8.555 ¢,-~ a A ti 2.3 b 0 C [Lt~'i ~0.888 CLL8 /22. 008 C, f~i 3:3.438 C g L 1 8. fa 4 .i i,e, H t.I t:,, 2. ,¢ l 0 N i-;: A 1' iL. 90 b ell,f! .t?.058 CLb8 z~.Olo t, P 3 I. 90 o C ,ti 1.., .I 8. b 4 ] F, Hf'i~ 2. 268 ~aA'!; 2.676 J~ ~ti, J D 2.42o ,,~ i~ A T 2. ~sq (' I.l.,[vl 3b. 551. ChL8 26.981 (,R bS. 125 C.gbl "-¢. 01 b tx r4tjt:5 2,51 O i",.,tl~ A1 1,835 OR H O .N C iq b CLL, 8 4~.,~. 25b CALl 1. 2.32d L)~H!i !. o 1 9. L) T i) '[' ~ CS,~L~ 11 t.0(]'~2 ? ~. () 0 0 52.~32 d. 07 n,, 0.5 0 iL) 2. u t 0 C b 1,8 CAul C bi. 8 (: A_ b i 7 2b,. 75o 9.u03 4.559 4.559 1024 0 ~ 79t 7/ PROGRAM: LISCAN REVIS ION: 5 · 1 PART NUMBER: W5790-PE32 S:~:~rt of Fr£ 10 NO¥i 89 10:43m **** REEL HEADER **** L IS 89111 1:02 ATLAS 01. :~:L, IS C~USTOMER FORMAT TAPE:' **** TAPE HEADER **** LiS 89/11t02 4028 01 '3 PASS CN/MS AT 8800-965'0 FT.' F I L E fi. 1 PASS I. 001 **** FILE HEADER **** 1024 CN WN PN c OUN STAT : B.P.EXPLORATION : 6-15 (21-3t-11-1:4 : B-15,(i21-31-11-14~) : NORTH SLOPE : .AL A,S~A * FORMAT RECORD ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT 1::2 CURVES : NAM~ I GR 2 SPD 3 TEN 4 TTEN CODE SA:MPLE# UNI:T~ 68 I API 68 I F'/MM 68 I LB 68 I L B BYTES 4 4 8 CN¢ 68 9 CNRA 68 10 LsN 68 11 SSN' 68 I 2 CCL 68 I PCT 4 I C/C 4 I CTS 4 I CTS 4 I VOLT 4 , DATA RECORD (TYPE# DEPTH GR C~SN CSSN LSN SSN 9650.000 72.58234 13.76294 169.7749 55.05177 169.7749 9550.000 90.29918 8.0465:53 129.2705 32.18622 129.2705 9450. 000 23. 61414 1t .74973 163.31141 46.99:893 163. 3141 9350.000 18.60'115 1 2. S7917 170. 8185 50.31 668 I 70. 8185 0~) 994 BY TES * SPD CN CCL 23,99760 25.25491 9.000000 23.99760 37.72427 3.0O00O0 23.99760 30.1!7705 9.000000 23.99760 29.14597 7.00OOOO 9250.000 16.09241 23.99760 37.04;695 284.6257 11.31047 145.1878 284.6:2!57 7.000000 9150.000 70.89668 24.3426:1' 1'$.93201 222.5467 23.48222 75.72798 222'54!167 3.000000 9050.000 24.61720 24.10680 25.50156 253.2981!: 17.99915 102.0063 2i53.2981 9.000000 8950.000 47.11842 24.10680 50.63388 345.7356 8.987122 202.5356 ]48.7356 3.000000 8850.000 80.23253 24.34261 6.74'4003 I 32.0805 54. 14644 26'.97600 132. 0805 6. 000000 · TEN CNC 275.7302 22.61293 -0.4141893 34.61581 -4.259631 Z7.30753 -2.845957 26.31943 -10.28582 9.620455 -7.746392 20.93605 -15.97804 15.79581 -7.277302 7.499876 -2.263101 50.97795 TTEN CNRA 1098.061 0.8106583E-01 1085.367 0.6224584E-01 1123.330 0.7194561E-01 1~1 25. 678, 0.7364058E-01 1072.537 0.1301602 1088.100 0.8506984E-01 1040.676 0.1006780 1082.870 0.1451927 1087.108 0.5105980E-01 TOTAL DATA RECORDS : STARTING, TAPE DEPTH **** FILE TRAILER **** 9650.00 ENDING TAPE OE PTH = 8800.00 FILE #' 2 PAS.S 2.002 **** FILE HEADER '**** FORMAT ONE D EP TAPE DE RECORD ~T~YPE# TH PER FRAME PTM UNIT : 1 2 CURVES : NAME 1 GR 2 SP D 3 TEN 4 TTEN 5 CLSN 6 CSSN ? CN 9 CNRA 10 t_ SN 1 t SSN 12 CCL CODE SAM 68 1 68 "1 68 68 1 68; 1 68 1 68 1 68 1 68 68 68 I PL E# UNIT API F/MM LB LB C~S CTS PCT PCT C lC CTS CTS VOL~ BYTES 4 4 4 4 4 4 4 4 4 4 4 4 * DATA RECO:RD DE'PTH CLSN LSN 9650.000 11 . 99363 47.97453 9550.000 8.295059 33.18024 9450.000 1t.27407 45.0~628 9350.000 !2.30641 49.22562 . 9250.000 37.39838 149.5935 91150,000 ~7.76360 71.05438 9050.000 Z 5,85:;728 1:03.429:1 8950.000 4:8.30856 193.2342 (T;¥ P E # GR C:S S N 74- 60863 185.5739 185.5739 93 · 01 846 133.6037 133.6037 24. 13751 165.7477 165.7477 22.24234 1 '68. 7692 168. 7692 19.08365 285.2795 285.2795 75.14729 214.9180 21 4 . 9180 27.22313 251.2956 251-2956 57.60294 336.6487' 336,.6487 994 BYTES * SPD CN CCL 23.99760 35.53609 0,0000000 23.99760 37.88042 3.000000 24..99750 32.84071 8.000000 24.99750 29~57748 6.000000 24.99750 11 . 14955 8. 000000 24.99750 24.52930 3.000000 25.23331 17.35907 7.000000 25.23331 9.222782 9.000000 TEN CNC 347.2986 32.48320 9.311651 34.76842 -17.44479 29.87167 -18.15605 26.73265 -9.150612 9.473175 -16.71797 21.92564 -1t.52412 15.2003'3 -10.'43863 7.714395 TTEN CNRA 11-08.837 0.64629975-01 1134.670 0.6208704E-01 1107.576 0.6801945E-01 1124.854 0.7291853E-01 1142.31 8 0.1 31 0938 1106.136 0. 8265293E-01 1115.542 0.1028959 1119.857 0.1434984 6.81' 27.27'916 . 3730 1 35. 3730 5.000000 :TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 45 9650.00 ENOING TAPE DEPTH = 8800.00 Ft~LE ~:' 3 '**** FILE PASS.3.003 HEADER 1024 FORMAT RECORD (:T'¥PE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : FT NAME · COD I GR 68 2 SPD 68 3 TEN 68 4 TTEN 68 = C L S N 6,8 ~ . 6 CSSN 68 7 CN. 68 8 CNC 68 9 CNRA 68 1 0 L SN 68 t; 1 S S N 6 8 12 CCL 68 E SAM PLE# UNIT I AP I I F/~M ;1 LB I LB I C TS :1 C TS · 1 PCT I PCT I C/C I CTS I ~ C T S I 'VOLT BYTES 4 4 4 4 4 4 4 4 4 4 DA:TA RECORD , . OEP TH C:LS N, LSN . 9650.000 ,15.10843 60.43370 9550.000 7.889525 31'55811 ~450.000 12.00088 48.00352 ¢ T¥ P E # · GR CSS N S S N 70.81020 223.3799 223.3?99 100.54;'47 131.0'904 131.0904 25.55737 166.8016 I 66. 801 b O) 99-4 BYTES * SPD CN CCL 24 99750 33.12531 6.000000 25.99741 39.86772 0.0000000 25.99741 30.17613 7.000000 TEN CNC 449.8137 30.14661 5.142296 36.71567 -17.02907 27.30666 TTEN CNRA 1327.931 O. 6763554 E-01! 1194.247 0.6018386E-01 1181.378 0.71 94704E-01 9350 . 000 20,8531 2 ~ 2 5 . 99741 -7 . 466096 I I 91 . 31 0 9250. 000 22. 29517 25. 99741 37.37781 280. ~+602 10.78318 I 49.5112 280. 4602 I 2.00000 91 50. 000 69. 75786 I 7.-65010 21.'6. 2241 70.60042 216. 2241 9050.000 22.79947 25.22572 25.5 · 7433 100.9030 255.7433 · 8950.000 56. 99742 47.36949 332.9070 189.4780 332.9070 8850.000 82.36035 6.497510 131;. 5019 25..99004 131 . 5019 25.99741 24.99387 t;2. 00000 25. 99741 18.6t41'8 14.00000 25.99741 9.394529 0.0000000 25.99741 58.14075 1.000000 -0.1082735 9.138073 -8.786747 22.36552 -6.695055 16.36890 -24.73032 7.870815 -22.91159 55.05292 1169.720 0.1332731 1146.626 0.8162874E-01 1135.300 0.9563693E-01 1087.905 0.1422905 1057.803 0.4941002E-01 TOTA~L DATA RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 45 9650.00 ENDING TAPE DEPTH = $800.00 FILE # 4 :PASS 4.004 1024 **** FILE HE~DER~**** FORMAT RECORD (TYPE# 64) ONE DE:PTH, PER FRAME TAPE DEPTH UNIT : FT CURVES : NAME CODE 1; GR 68 2 SPD 68 3 TEN 68 4 TTEN 68 5 CLSN 68 6 CSSN' 68 7 CN. 65 · 8 CNC 68 9 .CNR A 68 1 0 LSN 68 1 t SSN 68 1 2 C CL 6 8 SAM T E S PLE# UNIT 8¥ I API 4 I F /M M 4 I LB 4 I LB 4 I C T;S 4 I C T;S 4 1 PC:T 4 I PCT 4 I ClC 4 I CT S 4 I CTS 4 I '.VOL T 4 * DATA RECORD (TYPE# O) 994 BYTES L SN 9650.000 . 15.1,.0843 60.43370 9550.000 7.889525 31.5581 I 9450.000 1 2. 00088 48.00352 9350.000 13. 57267 54.29068 ', oOO .37. 37781 149.5112 . 9150.000 17.65010 70-..6004 2 9050.000 25.22572 100.9030 8950.000 47.3694 9 1.89.4780 CiS S N 70.8t 020 223.3799 223.3?99 1 O0, ,5447 131.0904 131.0904 25 · 55737 1 66. 8016 166. 8016 20.85312 174.2670 174,2670 22.29517 280.4602 280.4602 69.75786 216. 2241 21 6.2241 255.7433 255.74'33 332.9070 332 · 9070 C N · CC:L 24:.99750 33.12531 ~.000000 25.99741 39.86772 0.0000000 25.99741 30.176113 7.O00OOO 25.99741 26..81256 8.000000 25.99741 10.783t8 12.00000 25.99741 24.99387 12.00000 25.99741 18.61418 14.00000 25.99741 9.39~529 0.0000000 .. 8850. 000 82. 36035 25. 99741 6.4,-9751 0 131 . 5019 58.14075 25. 99004 131. 501 9 I . 000000 CNC 449.8137 30.14661 5.142296 36.71567 -17.02907 27.30666 -7.466096 24.09245 -0.1082735' Q.138073 -8.786747 22.36552 -6.695055 16.36890 -24.73032 7.870815 -22.91159 55.052~2 CNRA 1327.931 0.6763554E-01 1194.247 0.6018386E-01 1181.378 0.7194704E-01 1191.310 0.7788438E-01 1169.720 0.1332731 1146.626 0.8162874~-C1 1135.300 0.9863693E-01 1087.905 0.1422905 1057.803 0.4941002E-01 TOTAL DATA RECORDS : STARTING. TAPE DEPTH = *~**.* ,~.-c TRAILER **** 45 9650. O0 E N O I!NG TAPE DEPTH = 8800.00 **** TAPE TRAILER LIS ... 89/1 I !02 4028 01 TO?AiL RECORDS I.~N' THIS **** REELi; TRAIL, ER **** LIS 89/:11/02 /ITL LOGICAL~ TAPE : ;196 TOTAL RECORDS I'N THIS LOGICAL REEL~ : 197 TOTAL RECORDS IN THIS PHYSICAL REEL: 197 End o~ ei~ec'u~!'i:on: F~r~=i 10 NOV 89 1 0: 44~ , a~sed e~!ecu'~ion = t minute , 3.0 s. econd's. SYSTEM RETURN CODE
