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Home My WebLink About194-035MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, May 12, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC NK-23 PRUDHOE BAY UN NIA NK-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/12/2023 NK-23 50-029-22455-00-00 194-035-0 W SPT 8409 1940350 2102 548 553 554 556 621 895 879 868 4YRTST P Brian Bixby 4/8/2023 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 UN NIA NK-23 Inspection Date: Tubing OA Packer Depth 162 2358 2273 2221IA 560 859 45 Min 2187 560 854 60 Min 2173 Rel Insp Num: Insp Num:mitBDB230408134349 BBL Pumped:6.2 BBL Returned:6 Friday, May 12, 2023 Page 1 of 1           CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector NK-23 (PTD #1940350) Requires online AOGCC MIT-IA Date:Tuesday, April 4, 2023 9:09:56 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, April 1, 2023 4:18 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector NK-23 (PTD #1940350) Requires online AOGCC MIT-IA Mr. Wallace, Injector NK-23 (PTD #1940350) was made not operable for lapsing on required 4 year AOGCC MIT-IA in 2019. The well is now classified as OPERABLE and ready to be placed on water injection. An AOGCC MIT-IA will be performed once the well is thermally stable. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, May 30, 2019 6:50 AM To: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, OPS COA OSM <AKOPSCOAOSM@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GPMA Field PTL <AKOPSGPMAFieldPTL@bp.com>; AK, OPS LPC Board Operator <AKOPSLPCBoardOperator@bp.com>; AK, OPS LPC DS Operator <AKOPSLPCDSOperator@bp.com>; AK, OPS LPC DS Ops Lead <AKOPSLPCDSOpsLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Burton, Kaity <Kaity.Burton@bp.com>; Lundgren, Carl E <Carl.Lundgren@bp.com>; Sauve, Mark A <Mark.Sauve@bp.com>; Schultz, Kirsten L <Kirsten.Schultz@bp.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: NOT OPERABLE: Injector NK-23 (PTD #1940350) will lapse on AOGCC MIT-IA All, Injector NK-23 (PTD #1940350) is due for its 4-year AOGCC witnessed MIT-IA by the end of the month. The well will not be online before the required test will lapse. It is now classified as NOT OPERABLE until the well can be put on injection and an AOGCC witnessed MIT-IA can be scheduled. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday, May 30, 2019 6:50 AM To: Wallace, Chris D (CED); AK, OPS COA OSM; AK, OPS EOC Specialists; Ak, OPS GPMA Field PTL; AK, OPS LPC Board Operator, AK, OPS LPC DS Operator; AK, OPS LPC DS Ops Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Burton, Kaity; Lundgren, Carl E; Sauve, Mark A; Schultz, Kirsten L Cc: Regg, James B (CED); AK, GWO Completions Well Integrity, AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis 1; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector NK -23 (PTD #1940350) will lapse on AOGCC MIT -IA All, Injector NK -23 (PTD #1940350) is due for its 4 -year AOGCC witnessed MIT -IA by the end of the month. The well will not be online before the required test will lapse. It is now classified as NOT OPERABLE until the well can be put on injection and an AOGCC witnessed MIT -IA can be scheduled. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Thursday,June 04,2015 P.I.Supervisor �e°j 0lI 4 115 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC NK-23 FROM: Lou Grimaldi PRUDHOE BAY UN NIA NK-23 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvit- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN NIA NK-23 API Well Number 50-029-22455-00-00 Inspector Name: Lou Grimaldi Permit Number: 194-035-0 Inspection Date: 5/10/2015 Insp Num: mitLG15051019431I Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well NK-23 - Type Inj W TVD 8409 Tubing 1918 1916 - 1914. 1915- PTD 1940350 - Type Test SPT Test psi 2102 IA 350 2504 - 2479 • 2469 - Interval 74YRTST iP/F P ✓ OA 110 380380 380 . Notes: 5 9 bbl's diesel pumped,6.0 returned.Good test All required paperwork supplied prior to test; Att-e-4tA I) CL,trre,d- 'T' f'esSi-ue_s D1uf rrVit Thursday,June 04,2015 Page 1 of I A • • A A A ++ 1 I t`n -.—. 11\ Ji.•• 57: • _ ";--? TREE= CNV SA !NOTES: WELL REQUIRES A SSSV. 9-5/8" ,WELLHEAD= FMC N K CSU SET ON EMERGENCY SLIPS ACTUATOR= BAKER C I(_2 111 KB. ELEV= 60.1' BF. ELEV= 22.4' I I KOP= 1165' 1 2105' —14-1/2"HES X NIP,ID=3.813" Max Angle= 63°@ 15026' Datum MD= 16141' Datum TVD= 9200'SS 4923' -5508' —OA DOWNSQZ(03/17/06) GAS LIFT MANDRELS 13-3/8°CSG,72#,L-80,ID=12.347" -I 5659' ® ST MD TVD DEV 1 TYPE VLV LATCH PORT DATE A 2 7583 4997 59 MMG DMY RK 0 07/06/07 1 12649 7493 60 MMG DMY RK 0 07/06/07 Minimum ID = 3.725" @ 16764' I I 14285' —14-1/2"HES X NIP,ID=3.813" 4-1/2" OTIS XN NIPPLE Z x 14306' —19-5/8"X 4-1/2"BKR S-3 PKR, ID 3.875" 14330' —4-1/2"HES X NIP,ID=3.813" 4-1/2"TBG, 12.6#,L-80 TCII, 4385' .0152 bpf, ID=3.958" 14384' —°I4-1/2"X 5-1/2"XO,ID=3.958" 14395' H 9-5/8"X 5-1/2"UNIQUE OVERSHOT I 5-1/2"TBG STUB(06/19/07) -1 14389' 1----i 14434' 9-5/8"X 5-1/2"TM/PERM PKR W/PKR LATCH,ID=4.75" I 14469' 1-15-1/2"PARKER SWS NIP,ID=4.562" I 14489' —15-1/2"OTIS XN NIP,ID=4.455"1 5-1/2"TBG, 17#, L-80,.0232 bpf,ID=4.892" -1 14511' 14504' TOP OF 9-5/8"X 7"TIEBACK W/6'SEAL ASSY • 14511' —15-1/2"WLEG,ID=? TOP OF 7"LNR 14517' 14518' --)ELMD TUBING TAIL LOGGED 06/22/94 9-5/8"CSG,47#,L-80,ID=8.681" — 14673' A PERFORATION SUMMARY I REF LOG:AWS GR/TEMP ON 06/15/94 ANGLE AT TOP PERF:54°@ 16606' 16689' —1 MARKER JOINTS TWO 19' Note:Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 16584-16590 S 05/15/94 4" 4 16606-16646 0 06/18/94 3-3/8" 6 16656-16706 0 06/04/95 $ e 16754' —17"X 4-1/2"F-1 PERM PKR, ID=4.00" 3-3/8" 6 16775-16781 S 05/15/94 16760' 1-14-1/2"OTIS X NIP,ID=3.813" 2-7/8" 6 16850-16910 0 10/25/07 I 1 1 16764' 1-14-1/2"OTIS XN NIP,ID=3.725" 4-1/2"TBG,12.6#,L-80,.0152 bpf,ID=3.958" -I 16770' 1— . 16770' --I4-1/2"WLEG,ID=3.958"1 -I ELMD TT NOT LOGGED I PBTD —1 17435' I 11111111 7"LNR,29#,L-80,.0371 bpf,ID=6.184" —I 17535' DATE REV BY COMMENTS DATE REV BY COMMENTS NIAKUK UNIT 05/28/94 POOL 7 ORIG COMPLETION WELL: NK-23 06/20/07 N3S RWO PERMIT No: 1940350 05/21/09 HW/JMD DRLG DRAFT CORRECTIONS API No: 50-029-22455-00 02/18/11 MB/JMD ADDED SSSV SAFETY NOTE SEC 36,T12N,R15E, 1410'FSL&679'FEL RP FYnInratinn IAlackal Brooks, Phoebe L (DOA) ?TD#* 19 03S From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, June 04, 2015 12:11 PM To: Brooks, Phoebe L (DOA) Subject: RE: May 2015 AOGCC MIT Forms Attachments: image001.png; NK-23 WBS .pdf; NK-23 (PTD#1940350) Directional Survey.xls Phoebe, Enclosed are the wellbore schematic and directional survey for NK-23 (PTD#1940350). Thank you, Kevin Parks BP Alaska -Well Integrity Coordinator GiNT Organllzteior SCANNED JUN! o W LJ( Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Thursday, June 04, 2015 11:28 AM To: AK, D&C Well Integrity Coordinator Subject: RE: May 2015 AOGCC MIT Forms Kevin, Will you send me the well schematic and directional survey for NK-23 1940350 so I can verify the Packer TVD? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,please delete it, without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIlIntegrityCoordinator@bp.com] Sent: Wednesday, June 03, 2015 7:38 PM To: Regg, James B (DOA); Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay 1 TREE= CNV S. (NOTES: WELL REQUIRES A SSSV. 9-5/8" •WELLHEAD= FMC N K-2 3 CSta SET ON EMERGENCY SLIPS ACTUATOR= BAKER C KB. ELEV= 60.1' BF. ELEV= 22.4' 1 KOP= 1165' ' ' 2105' H4-1/2"HES X NIP,ID=3.813" Max Angle= 63°@ 15026' Datum MD= 16141' Datum TVD= 9200'SS 4923' -5508' —OA DOWNSQZ(03/17/06) GAS LIFT MANDRELS 13-3/8"CSG,72#, L-80,ID=12.347" - 5659' , ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 7583 4997 59 MMG DMY RK 0 07/06/07 _A 1 12649 7493 60 MMG DMY RK 0 07/06/07 Minimum ID = 3.725" @ 16764' I I 14285' —14-1/2"HES X NIP, ID=3.813" 4-1/2" OTIS XN NIPPLE 5< >K 14306' —19-5/8"X 4-1/2"BKR S-3 PKR, ID 3.875" ' ' 14330' _-14-1/2"HES X NIP, ID=3.813" 4-1/2"TBG, 12.6#, L-80 TCII, — 14385' / .0152 bpf, ID=3.958" 14384' —14-1/2"X 5-1/2"XO,ID=3.958" ~� 14395' —9-5/8"X 5-1/2"UNIQUE OVERSHOT 5-1/2"TBG STUB(06/19/07) —I 14389' �- 14434' 9-5/8"X 5 1/2"TMJ PERM PKR W/PKR LATCH,ID=4.75" III 14469' —5-1/2"PARKER SWS NIP,ID=4.562" ' 14489' —15-1/2"OTIS XN NIP, ID=4.455" 5-1/2"TBG, 17#,L-80,.0232 bpf, ID=4.892" 14511' / 14504' —TOP OF 9-5/8"X 7"TIEBACK W/6'SEAL ASSY • 14511' —5-1/2"WLEG, ID=? TOP OF 7"LNR 14517' A 14518' —ELMD TUBING TAIL LOGGED 06/22/94 9-5/8"CSG,47#, L-80,ID=8.681" — 14673' A L PERFORATION SUMMARY I REF LOG:AWS GR/TEMP ON 06/15/94 ANGLE AT TOP PERF:54"@ 16606' 16689' —MARKER JOINTS TWO 19' Note:Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 16584- 16590 S 05/15/94 4" 4 16606- 16646 0 06/18/94 3-3/8" 6 16656-16706 0 06/04/95 t„1 16754' —7”7"X 4-1/2"F-1 PERM PKR, ID=4.00" 3-3/8" 6 16775-16781 S 05/15/94 16760' -14-1/2"OTIS X NIP, ID=3.813" 2-7/8" 6 16850- 16910 0 10/25/07 16764' —4-1/2"OTIS XN NIP, ID=3.725" 4-1/2"TBG,12.6#,L-80, .0152 bpf,ID=3.958" — 16770' , 16770' —14-1/2"WLEG, ID=3.958" — ELMD TT NOT LOGGED I PBTD — 17435' j 4. 004 1 7"LNR,29#, L-80, .0371 bpf, ID=6.184" --1 17535' ,4.4.6.4.4.6. .4 DATE REV BY COMMENTS DATE REV BY COMMENTS NIAKUK UNIT 05/28/94 POOL 7 ORIG COMPLETION WELL: NK-23 06/20/07 N3S RWO PERMIT No:'1940350 05/21/09 HW/JMD DRLG DRAFT CORRECTIONS API No: 50-029-22455-00 02/18/11 MB/JMD ADDED SSSV SAFETY NOTE SEC 36,T12N,R15E, 1410'FSL&679'FEL BP Exploration (Alaska) MD (ft) TVD (ft) S5 (ft) Inclination Azimuth Dog Leg OffsetX OffsetY GeoX GeoY 0 0.00 -58.60 0.00 0.00 0.0 0.0 0.0 721,881.5 5,979,954.' 165 165.00 106.40 0.25 96.19 0.0 0.4 0.0 721,881.8 5,979,954.. 265 265.00 206.40 0.38 91.68 0.1 0.9 -0.1 721,882.4 5,979,954.. 365 364.99 306.39 0.77 98.23 0.4 1.9 -0.1 721,883.4 5,979,954., 465 464.97 406.37 1.76 85.94 1.0 4.1 0.0 721,885.6 5,979,954.. 565 564.89 506.29 2.68 85.93 0.9 8.0 0.3 721,889.4 5,979,954.' 665 664.77 606.17 3.02 90.05 0.4 12.9 0.7 721,894.4 5,979,955.. 765 764.52 705.92 4.93 77.83 2.1 19.7 1.8 721,901.2 5,979,956. 865 864.06 805.46 6.11 75.96 1.2 29.0 4.2 721,910.5 5,979,958.. 965 963.34 904.74 7.60 74.69 1.5 40.5 7.6 721,922.0 5,979,962.. 1,000 998.01 939.41 8.09 73.68 1.5 45.0 9.1 721,926.5 5,979,963. 1,065 1,062.32 1,003.72 8.68 70.93 1.1 54.0 12.2 721,935.4 5,979,966.. 1,165 1,160.92 1,102.32 10.46 66.72 1.9 69.2 18.7 721,950.7 5,979,973. 1,265 1,259.13 1,200.53 11.29 59.84 1.5 85.8 27.7 721,967.3 5,979,982.. 1,365 1,357.02 1,298.42 12.30 64.53 1.4 103.6 37.7 721,985.1 5,979,992. 1,465 1,454.37 1,395.77 14.11 65.99 1.8 124.0 47.9 722,005.5 5,980,002.. 1,565 1,550.68 1,492.08 17.08 67.02 3.0 148.4 59.3 722,029.9 5,980,013.' 1,665 1,645.69 1,587.09 19.27 67.70 2.2 176.8 72.2 722,058.3 5,980,026. 1,765 1,739.56 1,680.96 21.04 68.20 1.8 208.3 86.0 722,089.8 5,980,040.' 1,865 1,832.03 1,773.43 23.69 68.63 2.7 243.3 101.1 722,124.8 5,980,055.' 1,965 1,923.30 1,864.70 24.55 68.47 0.9 280.9 117.1 722,162.3 5,980,071.' 2,065 2,012.71 1,954.11 28.60 67.84 4.1 321.9 135.0 722,203.3 5,980,089.' 2,165 2,098.95 2,040.35 32.20 67.73 3.6 368.1 155.5 722,249.6 5,980,110. 2,265 2,181.93 2,123.33 35.62 67.67 3.4 419.1 178.2 722,300.6 5,980,132., 2,365 2,261.46 2,202.86 39.00 67.95 3.4 474.5 202.7 722,356.0 5,980,157.. 2,465 2,337.14 2,278.54 42.60 67.86 3.6 534.3 229.1 722,415.7 5,980,183.' 2,565 2,409.29 2,350.69 45.03 67.88 2.4 597.6 257.1 722,479.1 5,980,211. 2,665 2,478.00 2,419.40 48.16 67.63 3.1 664.0 286.5 722,545.5 5,980,241. 2,765 2,542.87 2,484.27 50.95 67.20 2.8 733.3 317.9 722,614.8 5,980,272. I 2,865 2,604.48 2,545.88 52.98 66.68 2.1 804.9 350.8 722,686.3 5,980,305., 2,965 2,662.91 2,604.31 55.51 66.60 2.5 878.4 385.2 722,759.9 5,980,339., 3,065 2,717.70 2,659.10 58.03 66.62 2.5 954.1 420.7 722,835.6 5,980,375.. 3,165 2,770.38 2,711.78 58.39 67.07 0.5 1,031.2 456.4 722,912.7 5,980,411.1 3,265 2,822.43 2,763.83 58.88 67.22 0.5 1,108.9 491.9 722,990.4 5,980,446. 3,365 2,873.85 2,815.25 59.23 67.67 0.5 1,187.1 527.1 723,068.6 5,980,481.' 3,465 2,924.58 2,865.98 59.80 67.62 0.6 1,265.8 562.2 723,147.3 5,980,516. 3,565 2,974.56 2,915.96 60.23 67.33 0.5 1,344.8 597.7 723,226.3 5,980,552. 3,665 3,024.33 2,965.73 60.07 66.48 0.8 1,423.5 634.1 723,305.0 5,980,588. 3,765 3,074.21 3,015.61 60.10 65.90 0.5 1,501.8 671.4 723,383.2 5,980,626.1 3,865 3,124.61 3,066.01 59.36 64.87 1.2 1,579.2 709.7 723,460.7 5,980,664.. 3,965 3,175.49 3,116.89 59.48 64.41 0.4 1,655.9 748.9 723,537.3 5,980,703., 4,065 3,225.53 3,166.93 60.46 64.25 1.0 1,732.7 788.7 723,614.2 5,980,743.: 4,265 3,324.81 3,266.21 60.02 64.37 0.2 1,886.9 868.5 723,768.4 5,980,823. 4,365 3,374.61 3,316.01 60.24 65.12 0.7 1,964.2 907.9 723,845.7 5,980,862.. 4,465 3,424.45 3,365.85 59.97 66.77 1.5 2,042.3 945.5 723,923.8 5,980,900. 4,565 3,473.92 3,415.32 60.74 67.61 1.1 2,121.4 981.5 724,002.8 5,980,936. 4,665 3,522.41 3,463.81 61.24 68.43 0.9 2,201.4 1,016.7 724,082.9 5,980,971.: 4,765 3,570.80 3,512.20 60.89 69.48 1.0 2,282.2 1,050.5 724,163.6 5,981,005. 4,865 3,619.36 3,560.76 61.00 69.95 0.4 2,363.2 1,083.2 724,244.7 5,981,037.. 4,965 3,667.55 3,608.95 61.39 69.09 0.9 2,444.4 1,116.3 724,325.8 5,981,070.' 5,065 3,716.29 3,657.69 60.26 68.74 1.2 2,524.9 1,150.1 724,406.3 5,981,104. 5,165 3,766.53 3,707.93 59.42 68.61 0.9 2,604.4 1,183.9 724,485.9 5,981,138.. 5,265 3,817.99 3,759.39 58.64 67.81 1.0 2,683.1 1,218.1 724,564.6 5,981,172.' 5,365 3,870.35 3,811.75 58.21 67.03 0.8 2,760.7 1,253.1 724,642.2 5,981,207. 5,465 3,923.01 3,864.41 58.25 66.39 0.6 2,837.8 1,289.0 724,719.3 5,981,243.1 5,565 3,975.84 3,917.24 57.97 65.97 0.5 2,914.4 1,325.6 724,795.9 5,981,280.. 5,665 4,028.42 3,969.82 58.58 65.27 0.9 2,990.8 1,363.0 724,872.3 5,981,317.' 5,765 4,081.20 4,022.60 57.71 65.26 0.9 3,066.9 1,400.8 724,948.4 5,981,355. 5,865 4,134.23 4,075.63 58.24 65.11 0.5 3,142.7 1,438.6 725,024.2 5,981,393.: 5,965 4,186.53 4,127.93 58.68 65.39 0.5 3,219.1 1,476.6 725,100.5 5,981,431.. 6,065 4,238.08 4,179.48 59.26 65.44 0.6 3,295.9 1,514.5 725,177.4 5,981,469. 6,165 4,289.16 4,230.56 59.31 65.95 0.4 3,373.2 1,552.2 725,254.6 5,981,506., 6,265 4,341.11 4,282.51 58.09 66.18 1.2 3,450.2 1,589.2 725,331.7 5,981,543.. 6,365 4,393.65 4,335.05 58.52 66.66 0.6 3,527.1 1,625.5 725,408.6 5,981,580. 6,465 4,445.80 4,387.20 58.62 67.17 0.5 3,604.6 1,661.3 725,486.1 5,981,615.' 6,565 4,497.58 4,438.98 59.01 68.04 0.8 3,682.7 1,696.2 725,564.2 5,981,650.• 6,665 4,547.83 4,489.23 60.66 68.07 1.7 3,761.9 1,730.9 725,643.4 5,981,685., 6,765 4,597.15 4,538.55 60.23 68.59 0.6 3,841.7 1,765.4 725,723.2 5,981,719.' 6,865 4,646.29 4,587.69 60.90 68.90 0.7 3,921.9 1,799.3 725,803.4 5,981,753.' 6,965 4,694.85 4,636.25 61.00 68.92 0.1 4,002.5 1,833.2 725,884.0 5,981,787.. 7,065 4,743.34 4,684.74 60.99 68.94 0.0 4,083.2 1,867.0 725,964.7 5,981,821. 7,165 4,791.65 4,733.05 61.23 69.46 0.5 4,164.1 1,900.5 726,045.6 5,981,855. 7,265 4,840.05 4,781.45 60.88 68.96 0.6 4,244.9 1,934.0 726,126.4 5,981,888.' 7,365 4,888.83 4,830.23 60.73 68.67 0.3 4,325.4 1,968.0 726,206.8 5,981,922.. 7,465 4,937.92 4,879.32 60.47 68.81 0.3 4,405.6 2,001.9 726,287.1 5,981,956.. 7,565 4,988.05 4,929.45 59.35 68.69 1.1 4,485.3 2,035.7 726,366.7 5,981,990.. 7,665 5,038.46 4,979.86 60.11 68.71 0.8 4,564.8 2,069.4 726,446.2 5,982,024.' 7,765 5,089.30 5,030.70 58.77 69.00 1.4 4,644.1 2,102.8 726,525.6 5,982,057., 7,865 5,140.24 5,081.64 59.99 69.70 1.4 4,723.7 2,135.6 726,605.2 5,982,090. 7,965 5,190.02 5,131.42 60.30 69.34 0.4 4,804.0 2,168.3 726,685.5 5,982,122. 8,065 5,239.75 5,181.15 60.05 69.13 0.3 4,884.2 2,201.4 726,765.7 5,982,156.1 8,165 5,289.29 5,230.69 60.56 68.68 0.6 4,964.3 2,235.1 726,845.8 5,982,189.' 8,265 5,338.95 5,280.35 59.89 68.68 0.7 5,044.2 2,269.0 726,925.7 5,982,223. 8,365 5,388.79 5,330.19 60.32 67.75 0.9 5,123.7 2,303.6 727,005.2 5,982,258. 8,465 5,438.02 5,379.42 60.70 67.87 0.4 5,203.3 2,338.8 727,084.8 5,982,293., 8,565 5,487.08 5,428.48 60.54 67.67 0.2 5,282.9 2,374.2 727,164.4 5,982,328.' 8,665 5,535.75 5,477.15 61.22 68.05 0.8 5,362.8 2,409.4 727,244.3 5,982,364.1 8,765 5,584.59 5,525.99 60.30 67.81 0.9 5,442.7 2,444.6 727,324.2 5,982,399.. 8,865 5,634.03 5,575.43 60.44 67.98 0.2 5,522.2 2,479.7 727,403.7 5,982,434.. 8,965 5,682.77 5,624.17 61.22 68.00 0.8 5,602.2 2,514.8 727,483.6 5,982,469., 9,065 5,730.63 5,672.03 61.59 68.01 0.4 5,682.6 2,550.1 727,564.0 5,982,504.' 9,165 5,777.87 5,719.27 62.04 67.18 0.9 5,763.0 2,586.1 727,644.5 5,982,540. 9,265 5,825.01 5,766.41 61.70 66.72 0.5 5,843.1 2,623.0 727,724.6 5,982,577.. 9,365 5,873.05 5,814.45 60.88 66.43 0.9 5,922.5 2,660.2 727,804.0 5,982,614.. 9,465 5,921.74 5,863.14 60.84 66.01 0.4 6,001.4 2,697.8 727,882.8 5,982,652.. 9,565 5,970.27 5,911.67 61.10 65.81 0.3 6,080.1 2,735.8 727,961.6 5,982,690., 9,665 6,019.39 5,960.79 60.06 65.93 1.1 6,158.5 2,773.8 728,040.0 5,982,728. 9,765 6,069.32 6,010.72 60.03 66.23 0.3 6,236.6 2,811.2 728,118.1 5,982,765.. 9,865 6,119.28 6,060.68 60.03 66.25 0.0 6,314.8 2,848.5 728,196.3 5,982,803.1 9,965 6,169.08 6,110.48 60.23 66.35 0.2 6,393.2 2,885.7 728,274.7 5,982,840.. 10,065 6,218.54 6,159.94 60.49 66.83 0.5 6,471.9 2,922.5 728,353.4 5,982,877. 10,165 6,267.87 6,209.27 60.39 66.48 0.3 6,550.7 2,959.3 728,432.2 5,982,913.' 10,265 6,316.83 6,258.23 60.98 66.39 0.6 6,629.5 2,996.6 728,511.0 5,982,951.. 10,365 6,365.95 6,307.35 60.18 66.29 0.8 6,708.3 3,033.9 728,589.7 5,982,988.. 10,465 6,415.93 6,357.33 59.85 66.45 0.4 6,786.5 3,070.9 728,668.0 5,983,025. 10,565 6,466.34 6,407.74 59.60 66.26 0.3 6,864.6 3,107.9 728,746.1 5,983,062., 10,665 6,515.74 6,457.14 61.19 66.79 1.7 6,943.3 3,144.8 728,824.8 5,983,099., 10,765 6,562.69 6,504.09 62.81 67.55 1.8 7,023.6 3,181.5 728,905.1 5,983,136. 10,865 6,608.79 6,550.19 62.29 67.57 0.5 7,104.6 3,217.8 728,986.1 5,983,172.. 10,965 6,655.80 6,597.20 61.63 67.33 0.7 7,185.1 3,254.0 729,066.6 5,983,208.1 11,065 6,702.95 6,644.35 62.10 67.21 0.5 7,265.4 3,290.5 729,146.8 5,983,245. 11,165 6,750.00 6,691.40 61.77 67.76 0.6 7,345.9 3,326.7 729,227.3 5,983,281. 11,265 6,797.79 6,739.19 61.13 68.05 0.7 7,426.2 3,362.1 729,307.7 5,983,316.' 11,365 6,846.33 6,787.73 60.80 68.28 0.4 7,506.4 3,397.0 729,387.9 5,983,351.' 11,465 6,895.35 6,836.75 60.48 68.57 0.4 7,586.4 3,431.5 729,467.9 5,983,386. 11,565 6,944.48 6,885.88 60.68 68.41 0.2 7,666.5 3,465.8 729,548.0 5,983,420., 11,665 6,993.82 6,935.22 60.19 67.24 1.1 7,746.0 3,501.0 729,627.5 5,983,455.. 11,765 7,044.23 6,985.63 59.27 65.96 1.4 7,824.2 3,537.6 729,705.7 5,983,492.. 11,865 7,095.02 7,036.42 59.68 65.57 0.5 7,901.7 3,575.3 729,783.2 5,983,529.' 11,965 7,145.67 7,087.07 59.46 65.19 0.4 7,979.0 3,613.5 729,860.5 5,983,568. 12,065 7,196.62 7,138.02 59.28 64.69 0.5 8,055.8 3,652.2 729,937.3 5,983,606. 12,165 7,248.01 7,189.41 58.87 64.47 0.5 8,132.2 3,691.4 730,013.7 5,983,645.' 12,265 7,299.51 7,240.91 59.13 63.87 0.6 8,208.2 3,731.0 730,089.7 5,983,685.. 12,365 7,349.96 7,291.36 60.28 63.38 1.2 8,284.4 3,771.6 730,165.9 5,983,726.. 12,465 7,400.14 7,341.54 59.48 62.92 0.9 8,360.4 3,812.9 730,241.9 5,983,767. 12,565 7,450.61 7,392.01 59.90 62.87 0.4 8,436.0 3,854.5 730,317.5 5,983,809. 12,665 7,500.90 7,442.30 59.71 62.99 0.2 8,511.8 3,896.1 730,393.3 5,983,850. 12,765 7,551.40 7,492.80 59.63 63.33 0.3 8,587.6 3,937.3 730,469.1 5,983,891.' 12,865 7,601.95 7,543.35 59.64 63.55 0.2 8,663.6 3,978.2 730,545.1 5,983,932. 12,965 7,652.34 7,593.74 59.84 63.56 0.2 8,739.8 4,018.9 730,621.3 5,983,973.. 13,065 7,702.77 7,644.17 59.59 63.58 0.3 8,815.9 4,059.7 730,697.4 5,984,014.. 13,165 7,753.45 7,694.85 59.51 63.47 0.1 8,891.9 4,100.3 730,773.4 5,984,054.' 13,265 7,804.51 7,745.91 59.08 63.77 0.5 8,967.8 4,140.8 730,849.3 5,984,095., 13,365 7,856.09 7,797.49 58.82 63.84 0.3 9,043.5 4,180.9 730,925.0 5,984,135.. 13,465 7,907.80 7,849.20 58.91 63.75 0.1 9,119.2 4,220.9 731,000.6 5,984,175.. 13,565 7,959.81 7,901.21 58.40 63.85 0.5 9,194.6 4,260.9 731,076.1 5,984,215.. 13,665 8,012.44 7,953.84 58.10 63.84 0.3 9,269.8 4,300.6 731,151.3 5,984,255.. 13,765 8,065.55 8,006.95 57.74 63.37 0.5 9,344.6 4,340.5 731,226.1 5,984,295. 13,865 8,119.04 8,060.44 57.58 63.24 0.2 9,418.9 4,380.7 731,300.4 5,984,335.. 13,965 8,172.73 8,114.13 57.47 63.66 0.4 9,493.2 4,420.6 731,374.7 5,984,375.. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /' <~,' ~),22~-' File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items- Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: scanned by:~Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: ~si REUEDTW STATE OF ALASKA ASKA OIL AND GAS CONSERVATION COMSON JUN 04 2013 REPORT OF SUNDRY WELL OPERATIONS ACC 1. Operations Abandon U Repair Well U Plug Perforations 11 Perforate Li • Other Li] Bright Water Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ 194 -035 -0 • 3. Address: P.O. Box 196612 Stratigraphic Service M. 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22455 -00 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0034634 NIA NK -23 • 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, NIAKUK OIL 11. Present Well Condition Summary: Total Depth measured 17535 feet • Plugs measured None feet p 9 true vertical 10062.65 feet Junk measured None feet Effective Depth measured 17435 feet Packer measured See Attachment feet true vertical 10004.07 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 94# H -40 42 - 122 42 - 122 1530 520 Surface 5618 13 -3/8" 72# L -80 41 - 5659 41 - 4025.29 4930 2670 Intermediate None None None None None None Production 14635 9 -5/8" 47# L -80 38 - 14673 38 - 8527.79 6870 4760 Liner 3018 7" 29# L -80 14517 - 17535 8450.05 - 10062.65 8160 7020 Perforation depth Measured depth 16584 - 16590 feet 16604 - 16646 feet 16656 - 16686 feet 16686 - 16706 feet 16775 - 16781 feet 16850 - 16910 feet True Vertical depth 9523.45 - 9527.06 feet 9535.43 - 9559.96 feet 9565.67 - 9582.58 feet 9582.58 - 9593.82 feet 9632.71 - 9636.09 feet 9674.97 - 9708.69 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4 -1/2" HES HXO SSV 2105 2047.59 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED JUN 1 8 2013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 3660 1880 17 0 802 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorL❑ Development ❑ Service 0 ' Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas U WDSPIU GSTOR ❑ WINJ 0 . WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.SummerhaysaBP.com Printed Name Nita Summerhays / Title Petrotechnical Data Technician • i ` % ��- Phone 564 -4035 Date 6/4/2013 ir k t / , * RBDMS JUN - 7 20 Form 10 -404 Revised 10/2012 6 /14 - / 13 Submit Original Only • • Daily Report of Well Operations ADL0034634 T /I /0= 1500/0/160 Temp = Hot (Brightwater Reservoir weep !o.) Move in and rig up, SB for fluid to arrive on 5 -9 -13. ** *Continued on 5 -9- 5/8/2013 13 WSR * ** ** *WSR continued from 5- 8 -13 * ** (RESERVOIR SWEEP MOD) Riged to tree cap /FL, PT lines to 2500 psi, Started pumping brightwater chemicals down TBG while on water injection @ 14,500 bwpd. Pumped 939 gal. EC9660A (Surfactant) Average of 93.9 gph for 10 hrs. Pumped a total of 939 gal. since start of project. Pumped 4555.5 gal. EC9398A ( Polymer) Average of 455.55 gph for 10 hrs. Pumped a total of 4555.5 gal. since start of project 5/9/2013 ** *Continued on 5 -10 -13 WSR * ** ** *WSR continued from 5- 9 -13 * ** (RESERVOIR SWEEP MOD) Started pumping brightwater chemicals down TBG while on water injection @ 14,500 bwpd. Pumped 2328 gal. EC9360A (Surfactant) Average of 97 gph for 24 hrs. Pumped a total of 3267 gal. since start of project. Pumped 11,371 gal. EC9378A ( Polymer) Average of 473.79 gph for 24 hrs. Pumped a total of 15926.5 gal. since start of project 5/10/2013 ** *Job continued to 5 -11 -13 WSR * ** ** *WSR continued from 5- 10 -13 * ** (RESERVOIR SWEE=P MOD) Started pumping brightwater chemicals down TBG while on water injection © 14,500 bwpd. Pumped 1336 gal. EC -9660A (Surfactant) Average of 89.06 gph for 15 hrs. Pumped a total of 4603 gal. since start of project. Pumped 6871 gal. EC -9398A ( Polymer) Average of 458.06 gph for 24 hrs. Pumped a total of 22797 gal. since start of project Upon LRS departure Valve postions SV= closed, WV, SSV, MV =open, IA/OA =OTG 5/11/2013 FWHP= 1420/20/160 FLUIDS PUMPED GALS 22797.5 EC9398A POLYMER 4603 EC9660A SURFACTANT 27400.5ITOTAL Casing / Tubing Attachment . ADL0034634 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H -40 42 - 122 42 - 122 1530 520 LINER 3018 7" 29# L -80 14517 - 17535 8450.05 - 10062.7 8160 7020 PRODUCTION 14635 9 -5/8" 47# L -80 38 - 14673 38 - 8527.79 6870 4760 SURFACE 5618 13 -3/8" 72# L -80 41 - 5659 41 - 4025.29 4930 2670 TUBING 14350 4 -1/2" 12.6# L -80 35 - 14385 35 - 8385.02 8430 7500 TUBING 122 5 -1/2" 17# L -80 14389 - 14511 8386.98 - 8447.07 7740 6280 TUBING 16 4 -1/2" 12.6# L -80 16754 - 16770 9620.86 - 9629.88 8430 7500 • • • • Packers and SSV's Attachment ADL0034634 SW Name Type MD TVD Depscription NK -23 SSSV 2105 1988.99 4 -1/2" HES HXO SSV NK -23 PACKER 14306 8287.88 4 -1/2" Baker S -3 Perm Packer NK -23 PACKER 14434 8350.46 5 -1/2" TIW Packer NK -23 PACKER 16754 9562.26 4 -1/2" Baker F -1 Packer TREE = CM/ III silk Y NOTES: WELL REQUIRES A SSSV. 9-5/8" WELLHEAD = FMC K -2 3 CSG SET ON EM ERGENCY SLIPS ACTUATOR= BAKER C KB. ELEV = 60.1' BF. ELEV = 22.4' KOP 1165' , I 2105' I -14 -112" HES X NIP, ID = 3.813" Max Angle = 63° @ 15026' Datum MD = 16141' Datum TVD = 9200' SS 4923' - 5508' 11 OA DOWNSQZ (03/17/06) I GAS LIFT MANDRELS 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 5659' I ST MD ND DEV TYPE VLV LATCH PORT DATE A 2 7583 4997 59 MMG DMY RK 0 07/06/07 1 12649 7493 60 MMG DMY RK 0 07/06/07 Minimum ID = 3/25" @ 16764' 1 1 I 14285' 11 4-1/2" HESXNIP, ID= 3.813" I 4 -1/2" OTIS XN NIPPLE X I 14306' H9-5/8" X 4-1/2" BKR S-3 PKR, ID 3.875" I III I 14330' H4-1/2" HES X NIP, ID = 3.813" I 4 -1/2" TBG, 12.6 #, L -80 TCII, -I 14385' .0152 bpf, ID = 3.958" _ / I 14384' H4 -1/2" X 5 -1/2" XO, ID = 3.958" I 14395' . 119 -5/8" X 5 -1/2" UNIQUE OVERSHOT I 5 -1/2" TBG STUB (06/19/07) H 14389' I ./."1 A 1�I 14434' I- j 9 -5/8" X 5-1/2" TIW PERM PKR W /PKR LATCH, ID = 4.75" I I 14469' H5-1/2" PA RKER SWS NIP, ID = 4.562" I I I 14489' H5-1/2" OTIS XN NIP, ID = 4.455" I 5 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" H 14511' 14504' IH TOP OF 9 -5/8" X 7" TIEBACK W/ 6' SEAL ASSY I �' I 14511' I -15 -1/2" WLEG, ID =? I (TOP OF 7" LNR I—I 14517' (-li I 14518' 11 ELMD TUBING TAIL LOGGED 06/22/94 I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 14673' I-A ilih. PERFORATION SUMMARY REF LOG: AWS GR/TEMP ON 06/15/94 ANGLE AT TOP PERF: 54° @ 16606' 1 — I MARKER JOINTS Two 19' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 16584 - 16590 S 05/15/94 4" 4 16606 - 16646 0 06/18/94 3 -3/8" 6 16656 - 16706 0 06/04/95 I 16754' 1-17" X 4-1/2" F -1 PERM PKR, ID = 4.00" I 3 -3/8" 6 16775 - 16781 S 05/15/94 I 16760' (-I4 -1/2" OTIS X NIP, ID = 3.813" I 2 -7/8" 6 16850 - 16910 0 10/25/07 ill, 16764' 114 -1/2" OTIS XN NIP, ID = 3.725" I 14 -1/2" TBG,12.6 #, L -80, .0152 bpf, ID = 3.958" H 16770' I I 16770' 114 -1/2" WLEG, ID = 3.958" I I H ELMD TT NOT LOGGED I PBTD H 17435' I 40004 10040 1 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 17535' DATE REV BY COMMENTS DATE REV BY COMMENTS NIAKUK UNIT 05/28/94 POOL 7 ORIG COMPLETION WELL: NK -23 06/20/07 N3S RWO PERMIT No: 1940350 05/21/09 HW /JMD DRLG DRAFT CORRECTIONS API No: 50- 029- 22455 -00 02/18/11 MB /JMD ADDED SSSV SAFETY NOTE SEC 36, T12N, R15E, 1410' FSL & 679' FEL BP Exploration (Alaska) • • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ' Viiitie JUL 1 8 201) July 6, 2011 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission y' 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA Niakuk Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA Niakuk that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Mehreen Vazir, at 659-5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Niakuk Date: 05/15/11 • Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal NK -01A 1760280 500292015801 P&A 3/9/91 NA NA NA NA NA NK -02A 1780790 500292018001 P&A 3/13/91 NA NA NA NA NA NK -03 1780940 500292035000 P&A 4/14/80 NA NA NA NA NA NK-04 1842000 500292121700 P&A 4/14/96 NA NA NA NA NA NK -05 1850270 600292129000 P&A 4/15/96 NA NA NA NA NA NK-06 1852760 500292148800 P&A 4/15/96 NA NA NA NA NA NK -07A 2010830 500292241001 0.2 NA 0.2 NA 0.9 4/30/2011 NK-08A 2010290 500292249101 0.2 NA 0.2 NA 0.9 4/30/2011 NK-09 1941400 500292251800 2.1 NA 2.1 NA 17.0 4/30/2011 NK -10 1931840 600292242600 1.5 NA 1.5 NA 11.9 4/30/2011 NK -11A 2020020 500292278901 1.5 NA 1.5 NA 11.9 4/30/2011 NK -12C 2030650 600292241403 1.8 NA 1.8 NA 31.0 4/30/2011 NK -13 1981340 500292289300 2.3 NA 2.3 NA 22.1 5/4/2011 NK -14A 2060310 500292288801 1.8 NA 1.8 NA 17.0 5/4/2011 NK -16 1970320 500292274500 1.8 NA 1.8 NA 18.7 5/4/2011 NK -16 1940220 500292244700 2.5 NA 2.5 NA 20.4 5/4/2011 NK -17 1961650 500292270900 3 NA 3 NA 20.4 5/4/2011 NK -18 1931770 500292242100 2 NA 2 NA 17.0 5/6/2011 NK -19A 2010700 500292260701 1.8 NA 1.8 NA 15.3 5/6/2011 NK -20A 2050400 500292242901 2.1 NA 2.1 NA 13.6 5/9/2011 NK -21 1940880 500292248700 2 NA 2 NA 22.1 5/15/2011 NK -22A 2012280 500292240201 1.5 NA 1.5 NA 11.9 5/11/2011 NK -23 1940350 500292245500 3.6 NA 3.8 NA 20.4 6/10/2011 ` NK -25 1970680 500292276000 2.5 NA 2.5 NA 15.3 5/11/2011 NK -26 1940050 500292244000 2.9 NA 2.9 NA 17.0 5/11/2011 NK -27 1950210 500292254700 2.3 NA 2.3 NA 13.6 4/30/2011 NK -28 1960930 500292267800 Sealed Conductor NA Sealed Conductor NA NA NA NK -29 1981900 500292272400 1.7 NA 1.7 NA 10.2 4/30/2011 NK-38A 2042410 500292254001 3.1 NA 3.1 NA 13.6 5/6/2011 NK-41A 1971580 500292277801 9.1 NA 9.1 NA 54.0 6/9/2011 NK-42 1941080 500292249900 2 NA 2 NA 13.8 5/9/2011 NK-43 2010010 500292299800 1 NA 1 NA 5.1 5/9/2011 NK-61A 2080350 500292289301 14 NA 14 NA 110.5 5/15/2011 NK-82A , 2030470 500292285201 1.3 NA 1.3 NA 13.6 5/4/2011 NK -65A 2060630 500292288901 1 NA 1 NA 8.5 5/8/2011 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg cp DATE: Monday, June 13, 2011 P.I. Supervisor N /l4-//( SUBJECT: Mechanical Integrity Tests (� BP EXPLORATION (ALASKA) INC NK -23 FROM: Matt Herrera PRUDHOE BAY UN NIA NK -23 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN NIA NK - 23 API Well Number: 50 029 - 22455 - 00 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH110609210909 Permit Number: 194 - 035 - Inspection Date: 6/9/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well NK-23 Type Inj. W TVD 8346 ' IA 440 2500 - 2475 2470 - P.T.D 1940350 1 TypeTest SPT 'Pest psi 2086 OA 150 380 390 390 Interval 4YRTST _ Pte, P - Tubing 950 975 990 990 Notes: IA tested to 2500 ki ,,JUN I 7 Monday, June 13, 2011 Page 1 of 1 • • ~~ ~, ;- ---, ~ , ~ ~R~f~Cilb~ ~lACgRdOSlIC ~E'sRt/1C~5,, 9r~~e To: 1~OGCC Christine Mahnken 333 V1/. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returr~ing a signed copy of this ~Cransmittal letter to the following : BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~~ ~ ~~~~- a3s'" ~ ~~3~4 ProActive Diagnostic Services, lnc. > t ~~~~ ~,, ~'+ `~ r~. Attn: Robert A. Richey w~~~=~~~°~~~~~ `~'~ ~` 130 West International Airpart Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Injection Profile 18,1uE09 NK 23 2j 3 ~' j~ Signed : ~ ~/~~...~-~ Print Name: BL / EDE 50-029-22455-00 Date . _ ~ 9~ROACTIVE DIAGNOST~C SERVICES, INC., 130 YU. INTERNATIONAL AIRPORT RD SUITE G, ANCHORAGE, AEC 99518 PHONE: (907j245-8951 FAx: (907)245-88952 E-INA1t: c_. = , .<_ ; .;' lNEBSITE: r: '~--•~, ~~ ~ C:~Documents and SetOngs~Owner~Desktop\Transmit_BP.docx T ~ i 2007 ~. STATE OF ALASKA ~~~ Oil $ Gas Cons. Corrxnission ALASKA OIL AND GAS CONSERVATION COM ION Anchorage REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~~~ 194-0350 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: , Anchorage, AK 99519-6612 50-029-22455-00-00 7. KB Elevation (ft): 9. Well Name and Number: 58.6 KB - NK-23 ' 8. Property Designation: 10. Field/Pool(s): ADLO-034634 ~ PRUDHOE BAY Field/ NIAKUK Pool 11. Present Well Condition Summary: Total Depth measured 17535 ' feet Plugs (measured) 16772 Junk (measured) 16727' true vertical 10062.65 - feet rr,, /~'~~}~~~~~9 t~,f~ i~:~l 'A1i E'1~~~ NOt1 ~ ~ ~~~~ r : Effective Depth measured 17435 feet true vertical 10004.07 feet Casing Length Size MD ND Burst Collapse Conductor 80 20" 94# H-40 42 - 122 42 - 122 1530 520 Surface 5618 13-3/8" 72# L-80 41 - 5659 41 - 4025.29 4930 2670 Production 14635 9-5/8" 47# L-80 38 - 14673 38 - 8527.79 6870 4760 Liner 3018 7" 29# L-80 14517 - 17535 8450.05 - 10062.65 8160 7020 Perforation depth: Measured depth: S 16584 - 16590 O 16604 - 16646 O 16656 - 16706 S 16775 - 16781 O 16850 - 16910 True Vertical depth: 9523.45 - 9527.06 9535 - 9560 9566 - 9594 9633 - 9636 9675 - 9709 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# X5-1/2" 17# L-80 TC-11 Surface - 14511' 4-1(2" 12.6# L-80 16762' - i 6777' Packers and SSSV (type and measured depth) 5-1/2" TIW Packer 14434 4-1/2" Baker F-1 Packer 16762 9-5/8"X4-1/2" BKR S-3 14306 7" X 4-1/2" F-1 PERM PKR 16762 12. Stimulation or cement squeeze summary: ~~ t~(~~ ~ a 2~D% Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 11698 9161 20 909 Subsequent to operation: 10539 8507 716 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~' Development ~"J Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas .L~ WAG ~! GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 10/31/2007 Form 10-404 Revised 04/2006 U K ! G I N A L ~ ~* (_,~ Submit Original Only • • NK-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ACTIVITYDATE SUMMARY 10/23/2007. WELL SHUT-IN UN ARRIVAL. INITIAL T/I/O: 400/500/0 RIG UP COMPLETE. RIH TO PERFORATE WELL FROM 16850'-16910'. 1ST RUN: 20' GUN. 19' POWERJET OMEGA 2906, 1' POWERJET 2906. .OVERALL LENGTH = 31', MAX OD = 2.88". '`**JOB IN PROGRESS AND CONTINUED ON 24-OCT-2007 WSR**'` 10/24/2007'`'`*CONTINUED FROM 23-OCT-2007**" 'WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O: 400/500/0 PERFORATE WELL FROM 16850'-16910'. 1ST RUN: 24' GUN. INTERVAL16890'-16910'. 19' POWERJET OMEGA 2906, 1' POWERJET 2906. .:1ST GUN RUN COMPLETED. =2ND GUN RUN: 20' GUN. INTERVAL16870'-16890'. 50% POWERJET OMEGA :2906, 50% POWERJET 2906. :2ND GUN RUN IN PROGRESS. ;3RD GUN RUN: 20' GUN. INTERVAL16850'-16870'. 100% POWERJET 2906. EOVERALL TOOL STRING LENGTH = 31', MAX OD = 2.88". ***JOB IN PROGRESS AND CONTINUED ON 25-OCT-2007 WSR*"* 10/25/2007 ***CONTINUED FROM 24-OCT-2007**" WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O: 600/500/0 PERFORATE WELL FROM 16850'-16910'. 1ST RUN: 20' GUN. INTERVAL16890'-16910'. 19' POWERJET OMEGA 2906, 1' POWERJET 2906. 2ND RUN: 20' GUN. INTERVAL16870'-16890'. 50% POWERJET OMEGA 2906, 50% POWERJET 2906. 3RD RUN: 20' GUN. INTERVAL16850'-16870'. 100% POWERJET 2906. OVERALL TOOL STRING LENGTH = 31', MAX OD = 2.88". DEEPEST DEPTH REACHED FOR TIE-IN = 17,025'. WELL LEFT SHUT-IN. FINAL T/I/O: 500/520/0. "*"*JOB COMPLETE""'`* FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor R~f 7(31!07 DATE: Monday, July 23, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC NK-23 PRUDHOE BAY UN NIA NK-23 . j,.;0-'35 ~Dt, FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :r6L Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN NIA NK-23 API Well Number: 50-029-22455-00-00 Inspector Name: John Crisp Insp Num: mitJCr070723082846 Permit Number: 194-035-0 Inspection Date: 7/1812007 ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -------¡---,------------,---- 1/1 r Well 1 NK-23 ¡Type Inj. I w I TVD I 834ó IA 0 I 2260 2220 1 2210 I ---- P.T.Di 19403sorrypeTest I SPT ¡ Test psi i 2086.5 /1 OA 0 I 120 120 I 120 , ' I : Interval INITAL P/F P ,/ Tubing 450 ! 450 450 450 I Notes: Post workover MIT. sCANNEO AU G 0 6 2007 Monday, July 23,2007 Page I of I ~ . STATE OF ALASKA . 7-/~1 ALASKA Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS ~CE'VËD j .# (ì , ~ d 2007 ;\ iJ ;J.. ,~,,:~;¡<: ('n.." 1'. 1. Operations Performed: . _u" fI' o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter su;~~~~RJ3well o Alter Casing ~ Pull Tubing D Perforate New Pool o Waiver o Other D Change Approved Program o Operation Shutdown o Perforate o Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. D Development D Exploratory 194-035 ..- 3. Address: ~ Service D Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22455-00-00 ./ 7. KB Elevation (ft): 58.60' / 9. Well Name and Number: PBU NK-23 / 8. Property Designation: 10. Field 1 Pool(s): ADL 034634 Prudhoe Bay Field 1 Niakuk Pool ,/ 11. Present well condition summary Total depth: measured 17535 I feet true vertical 1 0063 I feet Plugs (measured) 16772' Effective depth: measured 17435 feet Junk (measured) 16727' true vertical 10004 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' 1530 520 Surface 5659' 13-3/8" 5659' 4025' 4930 2270 Intermediate Production 14673' 9-5/8" 14673' 8527' 6870 4760 Liner 3018' 7" 14517' - 17535' 8450' - 8528' 8160 7020 5~NED JUL 23 2007 Perforation Depth MD (ft): 16606' - 16706' . Perforation Depth TVD (ft): 9537 - 9594' 4-112",12.6# x 5-112",17# TC-II x L-80 Surface - 14511' Tubing Size (size, grade, and measured depth): & 4-1/?" 1? 6# & I-RO 1 R7R?' _ 1 R777' Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker 'S-3 packer; 9-518" x 5-1/2" TIW 14306'; 14434'; Perm packer; 7" x 4-1/2" F-1 Perm Packer 16762' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8FL JUL 2 3 Z007 Treatment description including volumes used and final pressure: Set IBP at 14575'. Cut and pull tubing from -14389'. Change out 9-5/8" packoff. Run new tubing wlovershot to 14395'. 13. Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casinq Pressure Tubinq Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: ~ Daily Report of Well Operations D Exploratory o Development ~ Service 16. Well Status after proposed work: ~ Well Schematis-magram . - DOil DGas o WAG DGINJ ~WINJ D 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 Howard West, 564-5471 307-171 Printed Name Terrie Hubble Title Technical Assistant Signature /fó'Min tt, J ~ Phone 564-4628 o 7/ Prepared By Name/Number: Date 1807 Terrie Hubble, 564-4628 . . ;ssion Form 10-404 Revised 04/2006 OR1G1NAL Í::f11" ~ ~S"bmrt o,~,",' 0"'' Digital Wellfile . Page 1 of 2 . Well: NK-23 Well Events for SurfaceWell - NK-23 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GPMA -> NK -> NK-23 Date Range: 12/May/2007 to 07!Jun/2007 Data Source(s): AWGRS Description PULL 6" CIW BPV THRU TREE POST RIG MOVING ON WELL API VALVE SHOP PULL 6" CIW BPV THRU TREE RIG WORK API VALVE SHOP SET 6" CIW BPV THRU TREE PRE RIG API VALVE SHOP SET 6" CIW BPV THRU TREE PRE RIG WORK API VALVE SHOP ***CONTINUED FROM JUNE 4TH 2007*** CHEMICAL CUT 5-1/2" TBG IN 1ST FULL JOINT ABOVE PRODUCTION PKR. CUT DEPTH 14,414 FT,FINAL T/I/O - 0/0/0. ***JOB COMPLETE*** *** WELL SHUT-IN ON ARRIVAL *** INITIAL T/I/O 100/350/0. CLEANING STRING SHOT 12 FT X 3 STRINGS, TOP OF STRING @ 14,405.3' ***CONTINUED ON JUNE 5TH 2007*** *** JOB CONTINUED FROM 06-03-07 WSR *** (pre rwo) DRIFTED TBG W/ 4.50" SWEDGE & 1 1/2" SAMPLE BAILER. TAGGED XN NIP @ 14498' SLM NO RESTRICTIONS FOUND. SAMPLE BAILER M/T. *** LEFT WELL SHUT IN *** ***WELL S/I ON ARRIVAL *** (pre rwo) MADE 5 RUNS TO IBP @ 14,588' SLM W/ 10' x 3.50" DUMP BAILER. DUMPED FOUR 50# BAGS SLUGGITS FROM 14588' SLM TO 14,584' SLM. IN PROGRESS. *** JOB CONTINUED ON 06-04-07 WSR *** PULL 6" CIW BPV PRE RIG WORK NOT COMPLETE API VALVE SHOP SET 6" CIW BPV PRE RIG WORK API VALVE SHOP ***WSR continued from 5/30/07*** T/I/O= 450/200/100. (RWO Prep) CMIT-Tx IA to 3000 psi. *PASSED* 1st attempt. Tx IA lost 20 psi / 1st 15 min & 10 psi / 2nd 15 min. Pumped 15.0 bbls of 40* meth to achieve test pressure. Bled back 0.6 bbls to 1000/2920/460. lAP did not equalize with the TP. Bled lAP through loop to well #25's flowline. Pump 50 bbls of diesel to verify 5 bpm Tx IA communication. Pump 1460 bbls of 2% KCL down the TBG with IA returns to well #25's flowline. Pumped 150 bbls of diesel down tubing. Closed in hardline loop to #25 flowline and U-Tubed TxIA to Freeze Protect. CMIT- TxIA to 3500 psi. *PASSED* 1st attempt. TxIA lost 20/40 psi. in 1st 15 min.& 20/30 psi. in 2nd 15 min. & 20/20 psi. in 3rd 15 min. Bled WHP off. Freeze protect hardline and well #25 flowline. Final WHP= 0/0/0. 05/30/2007 Rig up for MIT and Circ Out. ***WSR continues on 5/31/06*** 05/30/2007 INITIAL WHP 600/300/100 ~ET BAKER 3 3/8" IBP MID ELEMENT 14,575', FISHING NECK 1. 75" EXTERNAL AT 14,568.5', 1840# DOWN TO RELEASE, 5500# TO PULL RELEASE, TWO 6" SEALS, ONE 1" STIFFNER RING, OVERALL LENGTH 11.59'. CORRELATED TO ATLAS GR/CCL LOG DATED 15 JUNE 1994. WELL SHUT IN FINAL WHP 600/300/100 ***JOB COMPLETE*** 05/30/2007 *** Continued from 5-29-07 WSR*** Attemted Circ-Out Pumped 30 bbls diesel down TBG in an attemt to test IBP. Pressured up to 2400 psi w/ 15 bbls away pumping at 1.5 bbls a min, pressure fell abruptly to 1400 psi at 20 bbls away and continued to fall to 600 psi at 30 bbls away. Job postponed until IBP can be reset. Final WHPs 450/320/100 OS/29/2007 T/I/O= 400/160/0 Circ-Out *** Job continued on 5-30-07 WSR*** OS/29/2007 ***WELL SHUT IN ON ARRIVAL *** WHP=500/100/0 SET BAKER 3-3/8" IBP IN 7" LINER AT 14,600'. TIE IN TO GAMMA RAY / CCL LOG DATED 6/15/1994. ***JOB COMPLETE*** OS/29/2007 *** JOB CONTINUED FROM 05-28-07 WSR *** (drift tbg / pre-ibp / rwo) DRIFTED TUBING W/ 3.80" CENT, 3' STEM, 3.75" CENT, 1.5" SAMPLE BAILER STOPPED @ 14,700' SLM (TARGET=14588' MD) SAMPLE BAILER EMPTY. *** LEFT WELL SHUT IN ON DEPARTURE *** OS/28/2007 ***WELL S/I ON ARRIVAL *** (pull wrp/drift pre-ibp) PULLED 5 1/2" WRP PLUG FROM 14,440' SLM. RIH W/ 3.80"CENT, 3' STEM, 3.75" CENT, S. BAILER. *** JOB CONTINUED ON 05-29-07 WSR *** OS/28/2007 *** CONTINUED FROM OS/27/07 *** RAN 5-1/2" OM-l, 1.70" LIB TO ST#2 @ 13,227' SLM (PIC OF EMPTY POCKET). PULLED 5-1/2" WHIDDON C-SUB @ 14,425' SLM (RA-DGLV INSIDE). RIH 4-1/2" GR, 5-1/2" WRP PULLING TOOL. SAT DOWN @ 14442' SLM, NO PSI CHANGE. WORK TOOLS FOR ~2 HRS JARRING UP TO SHEAR OFF. NOTE: 4-1/2" G BAIT SUB W/5-1/2" WRP PULLING TOOL STILL IN HOLE. ****WELL S/I ON DEPARTURE**** OS/27/2007 ***CONTINUE FROM 5/26/07 WSR*** RECOVER TOOL STRING AND ALL WIRE. C-SUB LEFT IN HOLE. UNABLE TO PULL STA #1. JARRED ON STA# 2 & CAME OUT W/ RA-LATCH F-NECK. (APPEARS TO HAVE SWIVELED OFF) RAN DOUBLE KJ, 2.60 B-GUIDE & CORE LESS 2" JDC & RATTLED MANDRELS, UNABLE TO GET INSIDE C-SUB. *** CONTINUE TO OS/28/07 *** OS/26/2007 **** CONTINUE FROM OS/25/07 *** PARTED WIRE @ 14,412' SLM. LEFT 12,204' OF .125 Events Source Well Date AWGRS NK-23 06/07/2007 AWCiRS NK-23 06/07/2007 8WÇjBS NK-23 06/06/2007 AWGRS NK-23 06/06/2007 AWGRS NK-23 06/05/2007 áWGRS NK-23 06/04/2007 AWGRS NK-23 06/04/2007 8WGßS NK-23 06/03/2007 AWGRS NK-23 06/03/2007 A WGRS NK-23 06/02/2007 AWGRS NK-23 05/31/2007 AWGRS NK-23 8WGRS NK-23 AWGRS NK-23 8WGB.2 NK-23 AWGRS NK-23 AWGRS NK-23 AWGRS NK-23 AWGBS NK-23 AWGRS NK-23 AWGRS NK-23 http://digitalwellfile.bpweb.bp.com/W ellEvents/Home/Defaul 1. aspx 7/18/2007 Digital Wellfile P.WGRS NK-23 OS/25/2007 AWGRS NK-23 05/18/2007 AWGRS NK-23 05/14/2007 6\!\LGß~ NK-23 05/14/2007 AWGRS NK-23 05/13/2007 6WGBS NK-23 05/12/2007 . Page 2 of 2 . WIRE IN HOLE W/ 8' * 2 1/8" ROLLER STEM, 2.62 WHEELS, OJ, LSSJ, 5.5 GS AND 5.5 WHIDDO C-SUB. RAN 4.61" NOGO CENT TO 2162' SLM. RAN FLAPPER-CHECKER TO 2158' SLM (APPEARS TO BE SITTING ON TOP OF FLAPPER.) CYCLED TRSV SEVERAL TIMES. RAN NO-GO & PRONG TO 2158'SLM (PRESS UP C-LINE & TOOLS DROPPED TO 2162' SLM) RE-RAN FLAPPER-CHECKER TO 2162' SLM, PICKED UP CLEAN, DUMPED C-LINE & PULLED BIND, PRESS UP C-LINE & PICKED UP CLEAN. GOOD FUNCTION TEST. RIH W/ 4.61 NO-GO CENT, 10' STEM, 5.5 BLB, TO BRUSH TRSV. RAN WIRE GRAB ASSEMBLY TO TOP OF WIRE @ 2338' SLM. ***CONTINUE ON 5/27/07 WSR*** ***WELL SHUT IN ON ARRIVAL *** (Pre RWO) RIH TO SET CATCHER SUB. *** CONTINUE TO OS/26/07 *** T/I/0=NA/340/50. PPPOT-T (PASS), PPPOT-IC (PASS). Pre rig. PPPOT-T: Stung into test port to check pressure (0 psi). Pumped through void until clean fluid was achieved. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS ). Functioned all LDS, all moved freely with no sign of bent or broken pins. PPPOT-IC: Stung into test port to check pressure (200 psi). Bled pressure to 0 psi. Pumped through void until clean fluid was achieved. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Functioned all LDS, all moved freely with no sign of bent or broken pins. .. 100/120/180. CfvlIT TxIA to 3000 psi. ( FAILED three psi on th"e IA in 15 min. Rate to sm. to establish LlK 400/430/20. CONT FRO!'1 05-13-07 \NSR (pre DRIFTED WI 4.55' SLIY1. SET 5 1/2" Wf:ATHERFORD WRP (ill 14,446' IY1D. lxIA *"* WELL LEFT S/I *"* *** CO NT FROM 05-12-07 WSR *** (pre rwo) DRIFTED W/ 4.50 CENT & 4.55 G-RING TO TOP OF PATCH @ 14,288' SLM. EQUALIZED & PULLED 2.313" XX PLUG FROM NIP REDUCER @ 14,452' SLM PULLED UPPER 5 1/2" WFD PACKER FROM 14288' SLM PULLED LOWER 5 1/2" WFD PKR FROM 14,327' SLM PULLED 5 1/2" X 2 7/8" NIPPLE REDUCER FROM XN-NIP @ 14,451' SLM *** JOB IN PROGRESS/ CONT ON 05-14-07 WSR *** WELL S/I UPON ARRIVAL *** (pre rwo) DRIFTED W/ 4.55 G-RING TO TOP OF PATCH @ 4369' SLM PULLED UPPER 21' SECTION OF WEATHERFORD PATCH FROM 4369' SLM PULLED LOWER WFD PACKER FROM 4389' SLM *** JOB IN PROGRESS/ CONT ON 05-13-07 WSR *** TO XN-NIP ....CMIT- http://digitalwellfile.bpweb.bp .com/W ellEvents/Home/Default. asp x 7/18/2007 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-23 NK-23 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/7/2007 Rig Release: Rig Number: Spud Date: 3/10/1994 End: 6/6/2007 03:00 - 11 :00 8.00 MOB P PRE RID off GPB 11-18. Scope down Derrick. Blow down all lines. Break electrical and steam lines. 11 :00 - 13:00 2.00 MOB P PRE PJSM wI Peak Trucks. Line up Trucks. Pull Pipe Shed and Pits away from Carrier. Back Carrier off of well. 13:00 - 14:00 1.00 MOB P PRE PJSM wI CPS prior to move to Niakuk. CPS measured rig for moving under high lines. 14:00 - 17:00 3.00 MOB P PRE Move to Niakuk 23. 17:00 - 00:00 7.00 MOB P PRE Spot Camp, Carrier, Pits, and Pipe Shed. Contact Pad Operator to shut-in nearby well gas lift. Set carrier mats. Due to space limitaitons and soft edges of well pad, decided to break down BOPE and spot individual components behind well. 6/7/2007 00:00 - 03:00 3.00 MOB P PRE Finish BOPE handling. Line Carrier up with well. Prepared to lay down Herculite. 03:00 - 06:00 3.00 MOB P PRE SD operation at 0300 hrs due to 30+ mph winds prior to laying Herculite spill containment. 06:00 - 18:00 12.00 MOB P PRE Lay Herculite down around wellsite. Move Carrier over Well. Move Pits and Pipe Shed into position. Make electrical and steam line connections. Could not raise derrick due to high wind (gusts to 50+ mph). Spot 4 vac trucks wI hot 9.0 brine on location. Spot Tiger tank. Accept rig @ 1500-hrs. 18:00 - 19:00 1.00 CONS P PRE RU to displace well fluids to Tiger tank. 19:00 - 21 :30 2.50 KILL P DECOMP RU lubricator and pull BPV. Tubing pressure = 350 psi. IA pressure = 500 psi. OA = 0 psi. RD lubricator. Call Anchorage Engineer to discuss wellhead pressures. Decide to pressure test IBP. 21 :30 - 22:00 0.50 KILL P DECOMP Hold pre-spud meeting. 22:00 - 23:00 1.00 DHB C DECOMP RU to pressure test IBP. Test surface lines to 1000 psi. 23:00 - 00:00 1.00 DHB C DECOMP Pressured tubing & IA to 1000 psi. Tubing pressure = 1020 psi. IA pressure = 990 psi. Held pressure for 20 minutes wI final tubing pressure = 1010 psi and IA = 980 psi. 6/8/2007 00:00 - 08:00 8.00 KILL P DECOMP Displace well with hot 9.0 ppg brine. Pump rate 4 bpm @ 410 psi. Slowed pump rate to 1 bpm @ 2200 psi with gas to surface. Calculated displacement volume = 965 bbls. Had gas to surface at calculated bottoms-ups @ 630 bbls. Degassed well @ 700 bbls pumped. Monitor Well. RID lines off Tree. 08:00 - 09:30 1.50 DHB P DECOMP Set TWC and test to 3,500-psi from above and 1 ,OOO-psi from below. RID lines. 09:30 - 11 :00 1.50 RIGU P DECOMP Scope up Derrick. 11 :00 - 13:00 2.00 WHSUR P DECOMP N/D Tree and Adapter Flange and place behind well for re-use. 13:00 - 20:00 7.00 BOPSU P DECOMP N/U BOPE: Single gate Rams (2-7/8" x 5-112" VBR), Flow Cross, Double Gate Rams (Blinds & 5-1/2"), Annular Preventer. 20:00 - 00:00 4.00 BOPSU DECOMP RU to pressure test BOPE. AOGCC Jeff Jones on site to witness test. Attempt to test blind rams, HCR valve, choke line valves wlo success. AOGCC departed location. Trouble-shoot leaking choke manifold valves. 6/9/2007 00:00 - 05:00 5.00 BOPSU P DECOMP Could not get good test on three leaking choke manifold valves (#3 #6 & #7). Ordered and received replacement valves on rig. Could not get good test on kill line HCR valve. Ordered replacement HCR valve. Continue testing BOPE 250/3500 psi (blind rams, TIW, dart, 5-1/2" rams, annular, choke line HCR, manual choke & kill line valves - tested OK) PU 5-1/2" test joint wldonut. Attempt to get donut below bottom 2-7/8" X Printed: 7/10/2007 10:45:11 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-23 NK-23 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/7/2007 Rig Release: Rig Number: Spud Date: 3/10/1994 End: 5-1/2" VBR's wlo success. Drain stack to get visual in BOPE. Called FMC to check height of stub above tubing spool. Confirmed that test joint donut is contacting tubing hanger neck before clearing bottom of VBR's. AOGCC Jeff Jones on location to witness test. 05:00 - 23:00 DECOMP PJSM. Remove and replace choke manifold valves #3, #6, #7 and HCR valve. 23:00 - 00:00 DECOMP Test Valves #3, #6, #7 and HCR valve to 250 psi low and 3500 psi high. AOGCC Jeff Jones waived test. 6/10/2007 00:00 - 01 :30 1.50 RIGU P DECOMP RU stabbing board (high wind). 01 :30 - 03:30 2.00 DHB P DECOMP RU lubricator, 7" Otis lubricator extension and handling equipment to POH. 03:30 - 04:30 1.00 DHB P DECOMP MU lubricator and pull TWC. RD lubricator & extension. Tubing = 0 psi. 04:30 - 05:30 1.00 PULL P DECOMP PU landing joint. Torque up landing joint, crossover and TIW. 05:30 - 07:00 1.50 PULL P DECOMP BOLDS. MU landing joint in tubing hanger. Pull Hanger, P/U to free Hanger = 200 k-Ibs., P/U after Hanger free = 195 k-Ibs. Cut and terminate dual encapsulated contrallines. 07:00 - 08:30 1.50 PULL P DECOMP Open TIW, UD Landing Joint, and Hanger. RIU to pull 5-1/2" completion. RIU Spooling Unit. 08:30 - 09:30 1.00 PULL P DECOMP POH and UD 2-jts of 5-1/2" NSCC 17# Tubing while Spooling control lines. Cut and secure contrallines to Tubing. 09:30 - 11 :00 1.50 DHB P DECOMP PUMU RTTS to 5-1/2" Tubing. P/U 190k -Ibs and SIO 90k-lbs. RIH and set RTTS at 35' MD. PIT RTTS to 1000 psi for 5 minutes. Good Test. 11 :00 - 13:00 2.00 BOPSU P DECOMP RIH and set Test Plug. PU and RIH wI 5-1/2" Test Joint. PIT Pipe Rams (2-718" x 5-112" VBR) on 5-1/2" Tubing to 250 psi low and 3500 psi high. POH wI Test Joint and test plug and UD same. 13:00 - 15:00 2.00 DHB P DECOMP RIH and pull RTTS. Monitor Well. POH and UD RTTS. 15:00 - 00:00 9.00 PULL P DECOMP PJSM. POH wI 5-1/2" 17# NSCC NT80 Tubing while spooling dual encapsulated contrallines and UD singles into Pipe Shed. 10 jts OOH @ 1620 hrs. 80 jts OOH @ 2330 hrs. 6/11/2007 00:00 - 15:00 15.00 PULL P DECOMP Pull & LD 5-1/2" 17# NT80 NSCC tubing. First 107 jts were in very good condition. Remaining jts have intermittent pinlshoulder corrosion and signficant external collar pitting. All 60 SS Bands were recovered. Chem cut was 17.59' in on Jt # 364 (The first full joint above the Packer). 15:00 - 17:00 2.00 BOPSU DECOMP Remove 5-1/2" Fixed Rams and replace with 3-1/2" Fixed Rams. 17:00 - 21:00 4.00 BOPSU DECOMP PT BOPE: VBRs (2-7/8" x 5-1/2"),3-1/2" Fixed Rams, and Annular Preventer w/3-1/2" Test Joint to 250 psi low and 3500 psi high. Test waived by AOGCC Jeff Jones. 21 :00 - 00:00 3.00 BOPSU DECOMP LD test joint. PUMU BHA#1 8-1/2" x 5-1/2" washpipe assembly. 6/12/2007 00:00 - 06:00 6.00 CLEAN P DECOMP MU BHA#1 and RIH: 8-1/2" x 5-1/2" washpipe, extension, boot basket, 9-5/8" scraper, boot basket, jars, DCs on 3·1/2" DP. DIH @ 0500 hrs = 1700'. Brine started hydraulicing out the top of the drill pipe while RIH. Continue RIH to 3900' while building a 15 bb19.9 ppg dry job slug. 06:00 - 06:30 0.50 CLEAN P DECOMP Spot 10 bbl slug inside drill pipe to control brine from hydraulicing out of drill pipe. 06:30 - 20:00 13.50 CLEAN P DECOMP Continue picking up 3-1/2" drill pipe and RIH wI BHA #1 without Printed: 7/10/2007 10:45:11 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-23 NK-23 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/7/2007 Rig Release: Rig Number: Spud Date: 3/10/1994 End: 6/12/2007 06:30 - 20:00 13.50 CLEAN P DECOMP fluid coming over the top. 120 joints in hole @ 09:09 hrs, 210 joints @ 11 :58 hrs, 250 joints @ 01 :12 hrs, 280 joints @ 14:02 hrs, 300 joints @ 16:00 hrs, 350 joints @ 17:00 hrs, 400 joints @ 20:00 hrs. 20:00 - 22:30 2.50 CLEAN P DECOMP P/U rat hole and install in rig floor. Load and P/U Kelly and components. M/U Kelly swivel and Kelly bushing to kelly. Rack back kelly in kelly shuck. 22:30 - 00:00 1.50 CLEAN P DECOMP M/U testing sub to kelly and RIU to test kelly. Test both upper and lower kelly valves to 250 psi low pressure test and 3500 psi high pressure test. Lower kelly valve would not test. CIO lower kelly valve and retest. Good test at 250 psi low pressure and 3500 psi high pressure. Break out test sub and UD. 6/13/2007 00:00 - 01 :00 1.00 CLEAN P DECOMP Test both upper and lower kelly valves to 250 psi low pressure test and 3500 psi high pressure test. Lower kelly valve would not test. CIO lower kelly valve and retest. Good test at 250 psi low pressure and 3500 psi high pressure. Break out test sub and UD. 01 :00 - 03:30 2.50 CLEAN P DECOMP Continue picking up 3-1/2" drill pipe and RIH wI BHA #1. 430 joints in hole @ 02:17 hrs, 458 joints @ 03:30 hrs. Establish parameters of Up Wt- 180,000 Ibs; Down Wt- 85,000 Ibs. Dry tag TBG stub at 14,401'. 03:30 - 06:00 2.50 CLEAN P DECOMP POOH and UD joint #458. PIU kelly and establish dressing parameters of Up Wt- 180,000 Ibs; Down Wt- 92,000 Ibs, Free Rotating Wt- 125,000 Ibs at 40 RPM with 11,500 ft-Ibs torque; Pump Pressure- 770 psi at 3.5 BPM. RIH and tag TBG stub. SIO to 5,000 Ibs rotating WOB, P/U off TBG stub with 25,000 Ibs overpull (205,000 Ibs). SIO and stack 6,000 Ibs rotating WOB with and increase in pump pressure from 450 psi to 500 psi and torque increased 500 ft-Ibs. P/U off TBG stub to 215,000 Ibs and trip jars, P/U to 225,000 Ibs, SIO 80,000 Ibs, P/U to 225,000 Ibs and trip jars and pulled free from TBG stub. SIO to put 4,000 Ibs WOB, drilled off to 3,000 Ibs WOB, torque increased 1,000 ft-Ibs. P/U off TBG stub to 225,000 Ibs, trip jars and pulled free of TBG stub. Pump 25 Bbl of Duo-Vis pill displaced wI 140 Bbls of SW. 06:00 - 09:00 3.00 CLEAN P DECOMP Stand back Kelly, RU and reverse circulate pill wI cuttings back until clean brine returns. Mix 25 Bbl of EP Mud-Lube pill and reverse circulate @ 4 BPM, 930 psi. Displace wI 20K strokes (475 Bbls I Annular volume of 880 Bbls.) 09:00 - 13:30 4.50 CLEAN P DECOMP PU Kelly, Tag tbg stub @ 14,401'. Establish milling parameters of: Up Wt- 170K, Down Wt-93K w/11 K ft-Ibs torque @ 60 RPM. Mill to 14,403' short tripping occasionally and jarring off wI 40K overpull. Appears to be spinning on stub. Flow check well - OK. 13:30 - 23:00 9.50 CLEAN P DECOMP POOH 193 stands of 3-1/2" drill pipe in derrick. 23:00 - 23:45 0.75 CLEAN P DECOMP P/U HES RTTS/Storm PKR and RIH. Set Storm PKR @ 61'. 23:45 - 00:00 0.25 CLEAN P DECOMP RIU and test storm packer to 1000 psi for 5 minutes. Chart results, Good test. 6/14/2007 00:00 - 00:30 0.50 CLEAN P DECOMP P/U landing joint and running tool. Pull wear ring. UD landing joint. 00:30 - 01 :30 1.00 CLEAN P DECOMP P/U FMC pulling tool on 2 joints of 6-1/4" drill collars. 01 :30 - 05:00 3.50 CLEAN P DECOMP "J" into FMC 9-5/8" pack off. P/U with 25,000 Ibs overpull and hold, no movement. P/U with 35,000 Ibs overpull and hold with Pnnled: 7/10/2007 10:45:11 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-23 NK-23 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/7/2007 Rig Release: Rig Number: Spud Date: 3/10/1994 End: 6/14/2007 01 :30 - 05:00 3.50 CLEAN P DECOMP slow movement of the packoff. SIO and P/U with 35,000 to 40,000 Ibs overpull. Packoff coming slowly with 40,000 Ibs overpull. After packoff moved 4", no futher progress could be made. Stack string wt of 5500 Ibs on packoff without any down movement. Several attempts with overpull and setting weight on packoff were made without any more progress. P/U 25,000 Ibs overpull, lost overpull immediately. POOH and examine pulling tool. One lug was damaged, could have rolled out of packoff. Ordered new pulling tool and bumper sub. 05:00 - 06:00 1.00 CLEAN P DECOMP UD used pulling tool. LD 1 DC. 06:00 - 09:00 3.00 WHSUR P DECOMP Crew change. PUMU BOT bumper sub and new packoff pulling tool. Lubricate packoffs with hydraulic oil. Engage packoffs and work bumper sub and DC with air tugger attempting to drive packoffs back down in tubing head. Bump packoffs down into tbg head. Work packoffs up and down with bumper sub and DC. Pull old packoffs. RU and wash tubing head and 9 5/8" stub. Suck dry and RIH and seat NEW 9 5/8" packoffs. 09:00 - 10:00 1.00 WHSUR P DECOMP RILDS. Pressure test packoffs to 3800 psi for 30 minutes. Good Test. 10:00 - 11 :00 1.00 DHB P DECOMP PU 1 Stand of 31/2" DP and Storm valve stinger. RIH, screw into SV, Unseat RTTS, POOH and lay down packer. 11 :00 - 16:00 5.00 CLEAN P DECOMP POOH laying down 71 joints of 31/2" DP in pipe shed. 16:00 - 17:00 1.00 CLEAN P DECOMP Stand back DC's in Derrick. Break out and lay down mill shoe from BHA #1. Mill shoe showed some broken buttons on inside and no sign of swallowing tubing stub. 17:00 - 19:30 2.50 CLEAN P DECOMP PUMU BHA #2. Same as BHA #1 but with new Mill shoe wIlD of 5.625". Add one section of wash pipe and RIH on 2 stands of 6-1/4" DC's. OAL - 175.26. Service Rig. 19:30 - 23:30 4.00 CLEAN P DECOMP RIH on 31/2" DP, picking up 71 singles from pipe shed. 23:30 - 00:00 0.50 CLEAN P DECOMP Slip and cut 91' of drilling line. Inspect draw works and brake linkage. 6/15/2007 00:00 - 01 :30 1.50 CLEAN DECOMP Continue slipping and cutting 91' drill line. Inspect draw works and brake linkage. 01 :30 - 09:00 7.50 CLEAN DECOMP Continue RIH with dressoff assembly (BHA #2) on 3-1/2" drill pipe from derrick. 09:00 - 11 :00 2.00 CLEAN DECOMP RIH to 14390'. PU Kelly. Establish parameters of: 161K UW I 94K DW I 50 RPM 11/2 BPM I 50 PSI I 8000 ft-Ibs rotary torque. Dry tag stub @ 14401', PU and mill over stub wI 500 ft-Ibs torque and 2000 Ibs WOB. Mill to 14411 '. Short trip and repeat with minimal torque. Stub clean. Lay down single of DP. Reciprocate 9 5/8" casing scraper across packer setting depth of 14320'. . 11 :00 - 12:30 1.50 CLEAN DECOMP MU head pin and reverse circulate 300 Bls @ 3.7 BPM 1730 psi 12:30 - 20:00 7.50 CLEAN DECOMP POOH standing back 193 stands of 3-1/2" DP in Derrick. Chuck Scheve wI AOGCC waived State's witnessing of upcoming BOPE test. 20:00 - 23:00 3.00 CLEAN DECOMP Continue POOH and UD 71 joints of 3-1/2" DP. 23:00 - 00:00 1.00 CLEAN DECOMP POOH with BHA #2. Stand back 2 stand of 6-1/4" drill collars. 6/16/2007 00:00 - 01 :00 1.00 CLEAN P DECOMP Continue POOH with BHA #2. UD dress off mill, washpipe, scraper, bumper sub and jars. UD and clean out boot baskets. Recovered 3 gallons of scale, sand, and gunk from boot Printed: 7/1012007 10:45:11 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-23 NK-23 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/7/2007 Rig Release: Rig Number: Spud Date: 3/10/1994 End: 6/16/2007 00:00 - 01 :00 1.00 CLEAN P DECOMP baskets. 01 :00 - 02:00 1.00 CLEAN P DECOMP Clear and Clean rig floor. 02:00 - 03:00 1.00 CLEAN P DECOMP Pull wear ring and set test plug. 03:00 - 04:30 1.50 CLEAN P DECOMP Close blind rams and change out 3-1/2" pipe rams to 3" x 6" variable pipe rams. 04:30 - 13:30 9.00 CLEAN P DECOMP Test BOPE to 250 psi low pressure and 3,500 high pressure. Annular tested to 3500 psi. Each test was held for 5 minutes. AOGCC witness of the test was waived by Chuck Scheve. Test was witnessed by Nabors toolpusher and BPX WSL. Tested w/3 1/2" and 4 1/2" test joints. Test 1- Choke valves 1, 2, HCR kill, and blind rams Test 2- Choke valves 4, 5, and 6 Test 3- Choke valves 7,8, and 9 Test 4- Choke valves 10, and 11 Test 5- Choke valves 12, 13, and manual kill Test 6- TIW and 2-7/8" x 5-1/2" pipe rams with 3-1/2" test joint Test 7- Choke valve 3 and 3" x 6" pipe rams with 3-1/2" test joint Test 8- HCR choke and annular preventer with 3-1/2" test joint Test 9- Dart valve and 2-7/8" x 5-1/2" pipe rams with 4-1/2" test joint Test 10- Manual choke and 3" x 6" pipe rams with 4-1/2" test joint Test 11- Annular preventer with 4-1/2" test joint Accumulater Test- 3,000 psi starting pressure, 1,600 psi after actuation, first 200 psi recovery in 24 seconds, full recovery in 1 minute and 40 seconds. 13:30 - 14:00 0.50 CLEAN P DECOMP Pull test plug. Run wear ring. Prep for BHA #3 14:00 - 15:30 1 .50 CLEAN P DECOMP PUMU 3 1/2" BTC Tbg Muleshoe, 6 joints of 31/2" BTC Tbg, and Baker jars, bumper sub. FCO BHA. 15:30 - 00:00 8.50 CLEAN P DECOMP RIH w/3 1/2" DP, picking up 71 singles from pipe shed, 190 stands from the Derrick. 6/17/2007 00:00 - 03:30 3.50 CLEAN P DECOMP Continue RIH with clean out assembly on 3-1/2" drill pipe from derrick to 14,370'. 03:30 - 04:30 1.00 CLEAN P DECOMP Establish parameters of Up Weight- 145,000 Ibs, Down Weight- 103,000 Ibs. M/U head pin and pump 27 bbls high vis sweep. Spot sweep in drill string at mule shoe @ 3.5 BPM, 700 psi. 04:30 - 05:30 1.00 CLEAN P DECOMP Continue RIH with 3-1/2" drill pipe from derrick through TBG stub. Tag Sluggit sand @ 14,573'. 05:30 - 07:00 1.50 CLEAN P DECOMP Establish new washing parameters of Up Weight- 145,000 Ibs; Down Weight- 105,000 Ibs; pump pressure- 580 psi at 2.75 BPM. Establish circulation, pressure to 1350 psi then break loose (muleshoes packed off with sluggits) and wash through Sluggits to top of IBP at 14,574', pumping 3.5 BPM @ 750 psi. 07:00 - 08:30 1.50 CLEAN P DECOMP Reverse circulate on top of IBP @ 3.75 BPM, 730 psi until sweep returned. Pump additional 100 Bbls after clean up. Get 5 gallons of sluggits back in possum belly when done. 08:30 - 00:00 15.50 CLEAN P DECOMP POOH laying down 31/2" DP, keeping hole full and maintaining trip sheet. UD 50 joints @ 10:35 hrs, 100 joints @ 12:05 hrs, 150 joints @ 13:30 hrs, 200 joints @ 14:55 hrs, 250 joints @ 16:30 hrs, 300 joints @ 20:10 hrs, 350 joints @ 22:08 hrs, 395 joints @ 24:00 hrs. Printed: 7/10/2007 10:45:11 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-23 NK-23 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/7/2007 Rig Release: Rig Number: Spud Date: 3/10/1994 End: 6/18/2007 00:00 - 03:00 3.00 CLEAN P DECOMP Continue POOH laying down 3 1/2" DP, keeping hole full and maintaining trip sheet. UD joint #400 @ 00:09 hrs, joint #450 @ 02:12 hrs. UD a total of 458 joints 3-1/2" DP. 03:00 - 06:00 3.00 CLEAN P DECOMP POOH with BHA #3 (clean out assembly). UD (4) 6-1/4" drill collars, XIOs, bumper sub, jars, (6) joints of 3-1/2" BTC TBG, and 3-1/2" mule shoe. 06:00 - 07:30 1.50 CLEAN P DECOMP P/U Kelly from kelly shuck. UD kelly, kelly bushings and kelly swivel. 07:30 - 09:30 RUNCMP Clean and clear rig floor. RU to run 41/2" Completion. RU torque turn and compensating equipment. Load pipe shed wI 4 1/2" tubing. 09:30 - 11 :00 RUNCMP Clear ice out of Derrick. PUMU overshot, X-nipple w. RHC plug, Baker S-3 41/2" x 9 5/8" packer. All connections below packer Baker-Lok'd. 11 :00 - 00:00 RUNCMP RIH w/4 1/2" TC II completion string. 60 jts in hole @ 15:00 hrs, 100 jts in @ 18:40 hrs, 150 jts in @ 21 :27 hrs, 194 jts @ 24:00 hrs. 6/19/2007 00:00 - 10:30 RUNCMP Continue RIH wI 41/2" TC II completion string. 194 jts in hole @ 00:00 hrs, 200 jts in @ 00:25 hrs, 250 jts in @ 03:45 hrs, 285 jts @ 06:00 hrs. 10:30 - 12:30 RUNCMP MU head pin and TIW valve. RIH and tag tubing stub @ 14,389'. See shear pins and slackoff 20K on stub. PU with slight overpull off of stub. Circualate @ 2 BPM, 50 psi. RIH over stub, see pressure increase to 250 psi. PU off of stub and RU to reverse circulate Brine and inhibited Brine in hole for packer fluids. 12:30 - 19:00 RUNCMP Swap well bore fluids to 250 Bbls of 9 #/gal brine in tubing, and 770 Bbls of inhibited 9# brine in annulus. Pump @ 3 BPM, 275 psi. 19:00 - 19:30 0.50 RUNCMP RID circulating lines and TIW valve. 19:30 - 20:30 1.00 RUNCMP Well out of balance, flowing out tubing, annulus stable. Mix 15 bbl dry job slug with new fluid. Pump dry job at 2 BPM with 130 psi and monitor well. Well stable. RID circulating lines. 20:30 - 00:00 3.50 RNTBH P TUBHGR Break out head pin and laydown 2 jts of 4-1/2" tubing. PUMU space out pup joints, 1 full joint of 4-1/2" Tubing, and FMC 12" x 7" Tubing Hanger on landing joint. RIH and land tubing hanger. Final parameters: Up Weight- 116,000 Ibs; Down Weight- 87,000 Ibs. RILDS 6/20/2007 00:00 - 02:30 2.50 RNTBH P TUBHGR PJSM with rig crew on setting PKR and testing TBG and annulus. Drop ball and rod. RlU circulating lines and pressure test to 500 psi. Set Baker PKR with 350~ psi ~n TBG fer 30 minutes, chart results. Bleed pressure 0 TB to 1500 psi. RlU and pressure test annulus to 3500 psi for 30 minutes, chart results. Bleed pressure off TBG and shear OCR valve with 2900 psi diferential pressure. Confirm communication by reverse circulating at 2 BPM wI 150 psi and circulating long at 2 BPM with 80 psi. 02:30 - 03:45 1.25 RNTBH P TUBHGR RID circulating lines. Pull and RID landing joint. 03:45 - 04:15 0.50 DHEOP P OTHCMP RlU FMC dry rod with TWC. Set TWC 04:15 - 05:30 1.25 DHEOP P OTHCMP RlU and pressure test TWC to 1000 psi from above and below for 10 minutes each. Chart results, good tests. 05:30 - 15:00 9.50 WHSUR P WHDTRE Drain stack and prep for ND BOPE. Change out rams and re-configure stack for MPU RWO's. Break apart and layout all Printed: 7/10/2007 10:45:11 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-23 NK-23 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/7/2007 Rig Release: Rig Number: Spud Date: 3/10/1994 End: 6/20/2007 05:30 - 15:00 9.50 WHSUR P WHDTRE BOPE components. RD stabbing board from Derrick. 15:00 - 18:00 3.00 WHSUR P WHDTRE PUMU tubing head adaptor and tree. Align Dry Hole tree to proper alignment. Pressure test tubing head adaptor and hanger void to 5000 psi for 15 minutes. Test tree to 5000 psi for 15 minutes. OK 18:00 - 19:30 1.50 WHSUR P WHDTRE Pipe shed bridge crane shorted out. RlU hand trolly to overhead beam with chain hoist to handle DSM lubricator. 19:30 - 19:45 0.25 WHSUR P WHDTRE RlU DSM. Pull TWC with DSM and Lubricator. RID DSM lubricator. 19:45 - 20:30 0.75 WHSUR P WHDTRE RlU LRHOS and circulating lines to dry hole tree. 20:30 - 22:45 2.25 WHSUR P WHDTRE Pressure test LRHOS circulating line to 2500 psi. Good test. Pump 110 bbls of 75 deg F diesel freeze protection down annulus with returns from the tubing to the tiger tank. Starting pressure at 2 BPM- 300 psi, final pressure at 2 BPM- 1200 psi. Line up and allow well to U-tube the TBG and IA for 1 hour. 22:45 - 23:30 0.75 WHSUR P WHDTRE RlU DSM lubricator to dry hole tree and set BPV 23:30 - 00:00 0.50 WHSUR P WHDTRE RlU LRHOS and pressure test BPV to 1000 psi from below. Good test. RID LRHOS. Release the rig @ 24:00 hours. Printed: 7/10/2007 10:45:11 AM Digital Wellfile . . Page 1 of 1 Well: NK-23 Well Events for SurfaceWell - NK-23 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GPMA -> NK -> NK-23 Date Range: 27/Jun/2007 to 10/Ju1/2007 Data Source(s): DIMS, AWGRS Events Source Well Date AWGRS NK-23 07/10/2007 AWGRS NK-23 07/09/2007 A\jjf:jRS NK-23 07/08/2007 Description ***JOB CONT. FROM 7/11/07*** SAT DOWN @ 16685' SLM W/ 3.75" CENT. SID @ 16692' W/ 2.62" WIRE GRAB, BEAT DOWN TO 16727' SLM/NOTHING RECOVERED, 2 SIX INCH ELEMENTS & BANDS LEFT IN HOLE. *** RIG DOWN TURN WELL BACK TO DSO.*** ***JOB CONT. FROM 7/8/07*** PULLED 3-3/8" IBP FROM 15228' SLM FISHED TWO 1", TWO 4", AND TWO 7" IBP RUBBERS W/ 3.70 & 2.62" WIRE GRABS RIH TO DRIFT W/ 3.75" CENT. IN PROGRESS. ***JOB CO NT. ON 7/10/07*** ***JOB CONT. FROM 7/7/07*** PULLED 3-3/8" IBP FROM 14575' ELMD, NO BANDS OR RUBBERS RECOVERED RECOVERED ONE RUBBER W/ THREE PRONGED 3.70" WIRE GRAB TAGGED IBP @ 15228' SLM W/ DECENT. & 3.5" LIB, IMPRESSION OF CLEAN FISHING NECK ***JOB CONT. ON 7/9/07*** AWGRS NK-23 07/07/2007 ***JOB CONT. FROM 7/6/07*** MULTIPLE ATTEMPTS TO EQUALIZE IBP SET @ 14575' ELMD ATTEMPT TO PIERCE IBP BAG W/ CENTRALIZED SPREAR ***JOB CONT. ON 7/8/07*** AWGRS NK-23 07/06/2007 ***JOB CO NT. FROM 7/5/07*** PULLED B&R FROM RHC SET IN X NIP @ 14330' MD PULLED RK-DCR AND REPLACED W/ RK-DMY GLV IN STA.#2 @ 7583' MD ****MIT-IA TO 2000 PSI *** PASSED*** PULLED 4.5" RHC FROM X NIP @ 14330' MD BAILED APPROX. 3 GAL OF SLUGGITS W/ 3.5" BAILER OFF TOP OF IBP SET @ 14575' ELMD UNABLE TO GET RETURNS IN BAILER, METAL MARKS ON BTM, RIH W/ 3.75" LIB ***JOB CONT. ON 7/7/07*** ***WELL SHUT IN ON ARRIVAL *** PULLED B&R FROM RHC IN X NIP @ 14330' MD ATTEMPT TO PULL DCR FROM GLM#2 ***JOB CONT. ON 7/6/07*** PULL 6" CIW BPV THRU TREE POST RIG WORK API VALVE SHOP SET BPV, DRY HOLE TREE 8WGKS NK-23 07/05/2007 AWGRS NK-23 07/04/2007 AWGRS NK-23 06/27/2007 http://digitalwellfile.bpweb.bp .comIW ellEvents/Home/Default. aspx 7/18/2007 NK-23 POST RWO 6/20/07 5-1/2" TSG, 17#, l-80. .0232 bpf, 10 4.892" I TOP OF 7" LNR 13-3/8" CSG, 72#, L-80, 10" 12.347" 1-1 5659' Minimum ID = 2.313 @ 14488' 2-7/8" X NIPPLE REDUCER 14-1/2" TBG, 126#, l-80,TC-1I H 15-1/2" TSG STUS, 17#, l-80 H 14384' 14389' 9-5/8" CSG, 47#, L-80, 10 = 8.681" I ÆRFORA TION SUMMARY REF lOG A WS GRlTEMP ON 06/15/94 ANGlEATTOPÆRF: 53 @ 16598' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 16584 - 16590 S 05/15/94 4" 4 16606 - 16646 06/18/94 3-3/8" 6 16656 - 16706 06/04/95 3-3/8" 6 16775 - 16781 S 05/15/94 NOTES: 9-5/8" CSG SET ON EMERGENCY 2105' H 4-112"X-NIPID=3.813 GAS LIFT MANDRELS ST MD TVD DEV TYÆ SIZE Depth 2 TSO TSD MMG .5"x1.5 7583' 1 TSD TSD MMG .5"x1.5 12649' 14923' - 5508' HOA DOWNSQZ (03/17/06) I I I I I I 14434' 14285' 14306' 14330' 14395' 14469' 14488' 14504' 14511 ' H 4-1/2" X-NIP 10=3.813" I H 95/8" X 4-1/2" SAKER S-3 PKR I H 4-1/2" X-NIP 10=3.813" I 1-15-1/2" x 95/8" UMIOvershot 9-5/8" X 5-1/2" TIW ÆRM PKR W/PKR LA TCH, 10 = 4.455" 1-15-1/2" PARKER SWS NIP, ID = 4.562" H 5-1/2" OTIS XN NIP. 10 = 4.455" I HTOP OF 9-5/8" X 7" TIEBACK WI 6' SEAL ASSY -15-1/2" TUBING TAIL WLEG I 16689' -1 MA RKER JOINTS TWO 19' I t\,,72-'7' 1 -:I:"ßP -sW\~ (o7/Jo/oi> 4-1/2" TSG, 126#, L-80, .0152 bpf. ID = 3.958" 16777' I FBTD I 17435' 7" lNR, 29#, L-80, .0371 bpf, ID = 6.184" H 17535' DATE 05/28/94 11/22/01 03/23/06 08/21/06 08/26/06 09/14/06 16762' 16768' 16772' 16772' 16777' REV SY COMMENTS POOL 7 ORlG COMPLETION RN/TP CORRECTIONS MCZ/TlH OA OWN SQZ JCMlPAG SET NIPPLE REDUCER/TIP RlW/TLH ÆRF, LNR & DEPTH CORRECT JRPITLH CIO TIP @ 14488' DA TE REV BY COMMENTS 09/22/06 RRDIPAG SET WFD PA TCHES (9/19 & 20) 10/01/06 TWS/PA PULL XX TIP@ 14487' SlM 11/15/06 CS/TlH DA TUM CORRECTION 11/23/06 DTR/PAG SET XX PLUG @ 14487' SLM 01/17/07 CS/PAG ÆRF CORRECTIONS 7" X 4-1/2" F-1 ÆRM PKR, ID = 4.00" 4-1/2" OTIS X NIP, ID = 3.813" I 4-1/2" OTIS XN NIP, 10 = 3.725" I 4-1/2" OTIS XXN PLUG RUN ON COMPLETION 4-1/2" TUBING TAIL WLEG I ELMO TI NOT lOGGED I NIAKUK UNrf WELL: NK-23 ÆRMrf No: 194-0350 API No: 50-029-22455-00 SEC 36, T12N, R15E, 3630.51 FEL 4062.86 FNl BP Exploration (Alaska) Fwd: NK-23i BOPE Test e e Subject: Fwd: NK-23i BOPE Test From: Date: Sun, 10 lun 2007 12:53:34 -0400 To: tOtn_ maunder@admin.state.ak.us -----Original Message----- From: Stiem, Alexander M. To: Cc: Reem, David C Sent: Sat, 9 lun 2007 9:04 pm Subject: RE: NK-23i BOPE Test \ ~~-O~ S- Mr. Maunder, Thank you for approving the test procedure. All BOPE components (w/exception of the subject 2-7/8" x 5-1/2" VBR's) will be successfully tested and charted prior to unseating the tubing. Regarding your BOPE spacing question, unfortunately due to the added height of the additional set of rams (3-rams vs. 2 rams), Rig 3S did not have sufficient height to add a spacer spool below the lower rams. On this well, the flow nipple/line between the rig floor and the annular preventor has been shortened to it's greatest extent. Whenever a two ram stack is used, or when the existing tubing spool is located at a lower ground elevation, it is my understanding that a spacer spool is added to insure sufficient room for lower ram testing. I hope this answers your question. Please contact me at any time if you have additional questions or comments. Regards, Alex Stiem 659-4485 BP Well Site Leader - Nabors 3S ~~~J;o JUN 1 1 20\17 From: Sent: Saturday, June 09, 2007 8:20 PM To: Stiem, Alexander M.; tom maunder@admin,state.ak.us; aoqcc prudhoe bay@admin.state.ak.us Subject: Re: NK-23i BOPE Test Nick and Alex, You situation has been encountered before. I have attempted to contact the Commissioners without success. This situation has been approved on prior occassions. As I understand, all other components will have been successfully tested prior to unseating the tubing hanger and pulling the 2 joints. So long as all other components test successfully, it is acceptable to test the lower VBRs with the tubing hung on an RTTS. One question, does sufficient height exist under the rig to have included a spool of some sort that would allow the lower rams to be tested? Tom Maunder, PE AOGCC lof2 6/11/200711:47 AM Fwd: NK-23i BOPE Test e e -----Original Message----- From: Stiem, Alexander M. To: tom maunder(ti?admin.state.ak.us Cc: Sent: Sat, 9 Jun 2007 7:00 pm Subject: NK-23i BOPE Test Mr. Maunder, The purpose of the email to request your written approval to proceed with the following BOPE test procedure. Due to a lack of space between our lower set of VBR's and the tubing hanger neck, we are unable to set the test joint below the VBR's. The well has a tested barrier at 14570' MD and kill mud with of 9.0 ppg. The 5-1/2" tubing is cut at 14,414'. The IA pressure = 0 psi. Proposed 2-7/8" x 5-1/2" VBR Test Procedure: · Pull TWC with lubricator. Monitor well. Insure well is dead. · Pull tubing hanger plus two (2) joints of 5-1/2" tubing. · Make up RTTS onto 5-1/2" tubing. Run in hole and set RTTS. · Pressure test RTTS to 1000 psi. · Set test plug in tubing spool and open IA. · Test lower VBR's w/5-1/2" test joint to 250 psi low /3500 psi high. · Recover RTTS. Pull 5-1/2" tubing. Per Mr. Jeff Jones, we request your approval to proceed with the above-described procedure. We are currently in the process of completing our choke valve replacements and will be ready to pull the TWC within the next few hours. Regards, Nick Frazier Alex Stiem BP Rig 3S Well Site Leaders AOL now offers free email to everyone. Find out more about what's free from AOL at AOL.com. 2of2 6/11/200711:47 AM . V~VŒ [ID~ ~~~~[K\~ AItA~1i& OIL AND GAS CONSBRVATION COMMISSION . ;/ SARAH PALIN, GOVERNOR I / / / 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) IncSCANNED JUN 072007 PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Niakuk Oil Pool, PBU NK-23 Sundry Number: 307 -171 ()~ \~ 0(/ Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days 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 this Z day of June, 2007 Encl. ¿;C73 , ~7 qr;J-¡",,,o7 -~? '/ .. STATE OF ALASKA .~- " ALASKA OIL AND GAS CONSERVATION COM ION Ý ~~CEIVED APPLICATION FOR SUNDRY APPROVA~ MAY 232007 20 AAC 25.280 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perfora£lae~lk~i~nS. Commission o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Ent~d Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development o Exploratory 194-035 '" 3. Address: 181 Service o Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22455-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU NK-23 / Spacing Exception Required? DYes 181 No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 034634 - 58.60 < Prudhoe Bay Field / Niakuk Pool .' 112' ...... ..... .... J ..... .... ,....., .' ............... "./¿: ........<.¿»¿¿»<¿¿/ .',.. ...... .... II Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 17535 / 10063 - 17435 10004 14487' & 16772' NONE Casino Lenoth Size MD TVD Burst Collaose Structural Conductor 80' 20" 80' 80' 1530 520 Surface 5659' 13-3/8" 5659' 4025' 4930 2270 Intermediate Prociuction 14673' 9-5/8" 14673' 8527' 6870 4760 Liner 3018' 7" 14517' -17535' 8450' - 8528' 8160 7020 Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 16604' - 16706' 9535' - 9594' 5-1/2",17#,4-1/2",12.6# L-80 14511', 16762' -16777' Packers and SSSV Type: 7" x 4-1/2" F-1 PERM Packer I Packers and SSSV MD (ft): 16762' 13. Attachments: 14. Well Class after proposed work: 181 Description Summary of Proposal o BOP Sketch o Exploratory o Development 181 Service o Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: June 7, 2007 oOil o Gas o Plugged o Abandoned 17. Verbal Approval: Date: o WAG oGINJ 181 WINJ o WDSPL Commission Representative: , 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Howard West, 564-5471 Pnnted Na~ Dav;d Reem Title Drilling Engineer Signature t.(' /p ¡?o....._ Date 5/~--7 Prepared By Name/Number: Phone 564-5743 Sondra Stewman, 564-4750 Commission Use Only I Sundry Number: .-;;¡o?-/?/ Conditions of approval: Notify Commission so that a representative may witness o Plug Integrity ¡l!...BOP Test ~Mechanicallntegrity Test o Location Clearance Other: ~DO \>0::;\ \S 0 Ç>-\-~~ \-. \J\\\ ~ ~~(\"'> 'v\. 0.." '-o.::s w I A,~ () \Y.A , Subsequent Form Required: 40~ ( - /t41 APPROVED BY £-1-or ADDroved Bv: T .A COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 \..,./"t"'" ORtGlNA Submit In Duplicate R8DMS 8FL JUN 0 7 2DD7 L . . G NK-23i Rig Workover Scope of Work: Pull 5-%" completion, change out 9 5/8" packoff, run 4-%" L-80, TC-II stacker packer completion. MASP: 3318 psi Well Type: Injector Estimated Start Date: June 7, 2007 Pre-Rig: 0 1 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. S 2 Pull WRP from 5 W'TBG @ 14439' MD E 3 Set 3 3/8" Baker IBP @ 14588 F 4 CMIT TxlA to 3500 psi. E 5 Power Jet cut the tubing at 14,406' md, in the middle of the first full joint above the packer. Depths referenced to tubinQ tally dated 5/21/94. F 6 Circulate well with seawater and diesel thru the cut. Bleed WHP's to 0 DSi. 0 7 Set a BPV in the tubinQ hanger. 0 8 Remove the wellhouse & flow line. Level the pad as needed for the ria. Proposed Procedure 1. MIRU. NO tree. NU and test 4 ram BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 5-1/2" tubing string to the cut. 3. Change out 9 5/8" packoff 4. Run 4-1/2" L-80, TC-II completion with Baker S-3 packer. Set packer at -14300' MD. 5. Displace the IA to packer fluid and set the packer. 6. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 7. Set BPV. ND BOPE. NU and test tree. RDMO. Post Rig: 0 1. Install flow line and re-set wellhouse. Retrieve BPV. S 2. Retrieve ball & rod. Pull RHC body. F 3. After POI, AOGCC Witnessed MIT IA ÆRFORA TION SUMMARY REF LOG: A WS GRlTEMP ON 06/15/94 ANGLEATTOPÆRF: 53 @ 16598' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 16584 - 16590 S 05/15/94 4" 4 16606 - 16646 C 06/18/94 3-3/8" 6 16656 - 16706 C 06/04/95 3-3/8" 6 16775 - 16781 S 05/15/94 ',TREE- .. WELLHEAD - ACTUA TOR = KB. El...EV = BF. El...EV = KOP= Max Angle = Datum MO = Datum 1V0 = 7-1/16" 5M CrN 13-5/8" FMC BAKER 60.1' 22.4' 1165' 63 @ 15026' 16141' 9200' SS 13-3/8" CSG, 72#, L-80, 10 = 12.347" I Minimum ID =2.313 @ 14488' 2-7/8" X NIPPLE REDUCER 5-1/2" TBG, 17#, L-80, .0232 bpf, 10 = 4.892" 1 I TOP OF 7" LNR I 9-5/8" CSG, 47#, L-80, 10 = 8.681" I 1 4-1/2"TBG,12.6#,L-80,.0152bpf,10=3.958" 1 I PBTD 1 1 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" I DATE OS/28/94 11/22/01 03/23/06 08/21/06 08/26/06 09/14/06 REV BY COMMENTS POOL 7 ORlG COMPLETION RNITP CORRECTIONS MCZIìLH OA OWN SQZ JCMlPAG SET NIPPLE REDUCERITTP RLWIìLH ÆRF, LNR & DEPTH CORRECT JRPIìLH C/O TIP @ 14488' . NK-23 sAY NOTES: 9-5/S" CSG SET ON EMERGENCY 5_ 2188' -15-1/2" TRSV, SERIES 10 NIP, 10 = 4.562" I . 5659' ~ µ GAS LIFT MANDRELS ST MO 1V0 OEV TYÆ VLV LATCH PORT DATE 4 3586 2985 60 OTIS LB RA 3 8789 5597 60 OTIS LB RA r~ ~ 2 13231 7788 60 OTIS LB RA ~ 1 14338 8362 61 OTIS LB RA ~ ~ 1\'1 4412' HSETWFO PATCH ELEMENTS, 10=2.441" (09/20/06) \. ~ ~ 4923' - 5508' -10A DOWNSQZ (03/17/06) 1 ~¡-..... N 14329' H SET WFO PATCH El...EMENTS, 10=2.441 (09/19/06) I I 14378' -15-112" NIP, PARKER SWS, 10 = 4.562" 1 r ~ n .2S 14511' 14517' -- I 9-5/8" X 5-112" TrN ÆRM PKR 1 W/PKR LA TCH, 10 = 4.455" I 14469' -15-1/2"PARKERSWSNIP, 10=4.562" 1 -I 14488' H5-1/2" OTIS XN NIP, 10 = 4.455"1 " -114487' SLM H5-1/2" x 2-7/8" X NIP REDUCER (09/03/06),10 = 2.3131 'of 14487' SLM 1- 2-7/8" xx PLUG SET (11/23/06) 1 I 14504' --TOPOF9-5/8"X7"TIEBACKW/6'SEALASSY I 14511' -15-1/2" TUBING TAIL WLEG 1 Ä I 14518' HELMDTUBt<GTALLOGGED06I22194 I I I I J II 14434' I 14673' ~ I 16689' -1 MARKER JOINTS lWO 19' 1 16777' I x ~ I 16762' H 7" X 4-1/2" F-1 ÆRM PKR. 10 = 4.00" I . I 16768' H 4-112" OTIS X NIP, 10 = 3.813" I .811 I 16772' H 4-1/2" OTIS XN NIP, 10 = 3.725" 1 I 16772' H 4-1/2" OTIS XXN PLUG RUN ON COMPLETION 1 II I 16777' H 4-1/2" TUBING TAIL WLEG 1 1 H ELMO TI NOT LOGGED I 17435' I 17535' OA TE REV BY COMMENTS 09/22/06 RRO/PA G SET WFD PATCHES (9/19 & 20) 10/01/06 lWS/PAG PULLXXTIP@ 14487'SLM 11/15/06 CSIìLH DATUM CORRECTION 11/23/06 OTRlPAG SET xx PLUG @ 14487' SLM 01/17/07 CS/PAG ÆRF CORRECTIONS NIA KUK UNfT WEl...L: NK-23 ÆRMfT No: 194-0350 API No: 50-029-22455-00 SEC 36, T12N, R15E, 3630.51 FEL 4062.86 FNL BP Exploration (Alaska) -TREE= - WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= 7-1/16" 5M CrN 13-518" FMC BAKER 60.1' 22.4' 1165' 63 @ 15026' 16141 ' 9200'SS 13-3/8" CSG, 72#, L-80, ID= 12.347" I Minimum ID = 2.313 @ 14488' 2-7/8" X NIPPLE REDUCER 14-1/2" TBG, 12.6#, L-80,TC-1I H 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" I TOP OF 7" LNR 9-5/8" CSG, 47#, L-80, ID = 8.681" 1 . NK-23 PROPOSED ÆRFORA TION SUMMARY REF LOG: AWS GRlTEMPON 06/15/94 ANGLEATTOPÆRF: 53 @ 16598' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 16584 - 16590 S 05/15/94 4" 4 16606 - 16646 C 06/18/94 3-3/8" 6 16656 - 16706 C 06/04/95 3-3/8" 6 16775 - 16781 S 05/15/94 4-1/2" TBG,12.6#, L-80, .0152 bpf, ID = 3.958" 1 PBTD I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I DATE OS/28/94 11/22/01 03/23/06 08/21/06 08/26/06 09/14/06 REV BY COMMENTS POOL 7 ORlG COM PLETION RN/TP CORRECTIONS MCZffiH OA DWN SQZ JClWPAG SET NIPPLE REDUCERlTTP RLWffiH ÆRF, LNR & DEPTH CORRECT JRPffiH C/O TIP @ 14488' 16777' 17435' 17535' S~ NOTES: 9-5/S" CSG SET ON EMERGENCY SL'" 2100' 1-1 4-1/2" X-NIP ID;3.813 14923' - 5508' HOA DOWNSQZ (03/17/06) I I I ~ I I 14434' I I 1 14469' 14488' 14504' 14511' 14518' 16689' 16762' 16768' 16772' 16772' 16777' DA TE REV BY COMMENTS 09/22/06 RRD/PAG SET WFD PATCHES (9/19 & 20) 10/01/06 TWS/PAG PULLXXTTP@ 14487'SLM 11/15/06 CSfTLH DATUM CORRECTION 11/23/06 DTRlPAG SET XX A..UG @ 14487' SLM 01/17/07 CS/PAG ÆRF CORRECTIONS 4-1/2" X-NIP ID=3.813" I 9 5/8" X 4-1/2" BAKffi 5-3 A<R 4-1/2" X-NIPID=3.813" 4-1/2" XN-NIP ID=3.725" 1--15-1/2" x 9 5/8" UMIOvershot I 9-5/8" X 5-1/2" TIN ÆRM PKR W/PKR LATCH, ID = 4.455" 1--15-1/2" PARKERSWS NIP,ID = 4.562" 1--15-1/2" OTIS XN NIP, ID = 4.455" I HTOPOF 9-5/8" X 7" TIEBACK W/6' SEAL ASSY -15-1/2" TUBING TAIL WLEG I H ELMD TUBING TAIL LOGGED 06/22/94 I -i MARKER JOINTS TWO 19' 1 7" X 4-1/2" F-1 ÆRM PKR, ID = 4.00" 4-1/2" OTIS X NIP, ID = 3.813" I 4-1/2" OTIS XN NIP, ID = 3.725" I 4-1/2" OTIS XXN A..UG RUN ON COMA..ETION 4-1/2" TUBING TAIL WLEG I ELMD TT NOT LOGGED I NIAKUK UNIT WELL: NK-23 ÆRMIT No: 194-0350 API No: 50-029-22455-00 SEC 36, T12N, R15E, 3630.51 FEL 4062.86 FNL BP Exploration (Alaska) Re: NK-23i update . . Howard, Thanks for the updated information. I checked the Niakuk Conservation Order (CO 329) and the Area Injection Order (AIO 14A). According to the AIO, only liquids are approved for injection at Niakuk and the AIO does not have any requirement for a SSSV. The CO does require SSSVs, however that would be for production wells. If the well will only ever be a water injector, then the Commission does not now and under the new proposed Safety Valve regulations will not have a requirement for a SSSV in a water injector. I suspect that NK-23 presently has a SSSV since it originally was a production well. BP may have an internal requirement for SSSV in Niakuk wells and you need to look into that. Providing an X nipple as planned is appropriate. I will forward the sundry recommending approval. I will do all I can to have it ready tomorrow mornmg. Call or message with any questions. Tom Maunder, PE AOGCC West, Howard J wrote, On 6/5/2007 2:09 PM: Mr. Maunder, I wanted to let you know that there was a mistake on the NK-23i (PTD # 194-035) propsed schematic. The x-nipple listed at 2100' will actually be a surface controlled SSSV. If there is anything I need to do because of this, please let me know. I listed the start date as June 7th and although it may be pushed back by a day, the sooner I can square this away, the better I'll feel. I also have a doctor's appointment at 2:30, so if you need to discuss this with me, you can either reach me on my cell phone (230-6628) or contact Dave Reem in our office (564-5743). Thanks for the help, Howard West 1 of 1 6/5/2007 5:26 PM STATUS: NK-23 (PTD 1940350) . . rd51ûP Hello Jim, Winton & Bob. Injection well NK-23 (PTD 1940350) failed an MITIA, post tubing patches. The IA was pressured to 3000 psi and a steady IA pressure loss of 50 psi/15 minutes was observed over a 1 hour period. The well is currently shut-in. Recent events: > 09/19/06: Set Patches @ 14372'-14334' and 4412' to 4432' > 09/28/06: MITIA Passed to 3000 psi, MITT Failed ij{;ANà~lE![J OEC 2 (} 200& ... ... > 10/01/06: TTP pulled from 14,477' SLM > 10/22/06: MITrA Failed, lost 300 psi/15 min > 11/22/06: TTP Set @ 14487' > 11/27/06: MITIA Failed .' . We are evaluating repair options. Attached is an MIT form for the failed MITIA. Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom «MIT PBU NK-23 11-28-06.xls» Content-Description: MIT PBU NK-23 11-28-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 12/5/20063:13 PM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay I PBU I Niakuk 11/28/06 Joe Anders Packer Depth Pretest Initial 15 Min. 30 Min. Well I NK-23 I Type Inj. J N TVD I 8,409' Tubing 280 280 280 280 Interval/ 0 P.T.D. I 1940350 I Type test I P Test psi I 2102 Casing 280 3,000 2,950 2,900 P/FI F Notes: Eval if patch repair was successful OA 0 280 280 280 45 min=280/2850/280, 1 Hr.= 280/2800/280 Weill I Type Inj. I TVD I Tubing Interval! P.T.D.I I Type test I Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval/ P.T.D.I I Type test I I Test psi/ Casing P/FI Notes: OA Weill I Type Inj.J I TVD I Tubing Interval I P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Type test I I Test psi/ Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P =' Standard Pressure Test R = Intern~1 Radioactive Tracer Survey A =Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT PBU NK-23 11·28-06.xls STATUS: NK-23 (PTD 1940350) . Hello Jim & Winton. Well NK-23 (PTD 1940350) failed an MITIA on 10/22/06. Patches were previously set across tubing leaks and a post-patch MITIA passed. The well was returned to injection and a subsequent MITIA failed. The well was left injecting 15,000 BPD of sea water at 600 psi until now. Today, the DSO noted IA bleeding frequency of approximately 1 bleed / week to maintain the TxlA 250 psi dp. We swapped the status of the well from Normal to Trouble and the well is currently SI. Recent events: > 11/10/05: MITIA Passed to 2500 psi, but exhibits slow IA pressurization > 07/08/06: TecWell LDL > 09/19/06: Set Patches @ 14372'-14334' and 4412' to 4432' > 09/28/06: MITIA PASSED to 3000 psi > 10/01/06: Pulled TIP > 10/22/06: AOGCC MITIA Failed, loses 300 psi/15 min > 10/27/06: PPPOT-T Passed to 5000 psi .iI'" iil ~!~ít::;!n ~\iJ'Q~ws.;;. :I¡,..,......- If' lODE Planned actions: 1. EL: Set IBP 2. FB: MITT to 2500 psi, if fails CMIT-TxIA to 2500 psi - LLR IA to TBG 4. APE: Eval for LDL Attached is a well bore schematic. Please call with any questions. «NK-23.pdf» Paul Austin for Joe Anders Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Phone: 1-907-659-5102 Pager: 659-5100,x1154 Content-Description: NK-23.pdf NK-23.pdf Content-Type: application/octet-stream Content-Encoding: base64 l~j~ 11/14/200611:06 AM TREE = 7-1/16" SM CIVV ~NOTES: 9-5/8" CSGSEf ON EMERGENCY WELLHEAD = 13-S/8" FMC NK-23 ~- SLI . ACTUA TOR = BAKER KB. ELEV = 60.1' BF. ELEV = 22.4' KOP= 1165' 2188' -S-1/2" TRSV, SERIES 10 NIP, ID= 4.S62" ~---~~ I Max Angle = 63 @ 15026' . Datum MD - 15360' Datum TVD- 8800' SS GA S LIFT MA NORELS ST~OEV TYPE VLV LATCH PORT OATE 4 3586 2985 60 OTIS LB RA r~ 3 8789 5597 60 OTIS LB RA '" 2 13231 7788 60 OTIS LB RA 1 14338 8362 61 OTIS LB RA \ì 4412' 1-1 SET WFD PA TCH ELEMENTS, 10=2.441" (09/20/06) 1----4 \ I 13-3/8" CSG, 72#, L-80, 10= 12.347" I 5659' ~ ~ ~ 4923' - 5508' HOA DOWNSQZ (03/17/06) I ~ ......... ----r 14329' SETWFD PATCH ELEMENTS, 10=2.441 (09/19/06) I I 14378' -5-1/2" NIP, PARKERSWS, 10=4.562" I Minimum ID = 2.313 @ 14488' ~ 2·7/8" X NIPPLE REDUCER I 14434' 9-5/8" x 5-1/2" TIVV PERM PKR I 2S W/PKR LA TCH, ID = 4.455" I I 14469' -i 5-1/2" PARKER SWS NIP, ID = 4.562" I II . - -I 14488' H5-1/2" OTlSXN NIP, ID = 4.455" 1 - l14487' SLM --15-1/2" x 2-718" X NIP REDUCER (09/03/06), ID = 2.3131 r4 l 14504' - TOP OF 9-5/8" X 7" TIEBACK WI 6' SEAL ASSY I I 5-1/2" TBG, 17#, L-80, .0232 bpf, 10 = 4.892" I 14511' I 14511' -15-1/2" TUBING TAIL WLEG I I I TOP OF 7" LNR I 14517' ~ I 14518' l-i ELMD TUBING TAIL LOGGED 06/22/94 1 . I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 14673' 1----4 II .. PERFORA TION SUMMA RY 0 MARKER JOINTS TWO 19' I .... 16689' -i REF LOG: A WS GRlTEMP ON 06/15/94 Õ ANGLEAT TOP PERF: 53 @ 16598' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE II 3-3/8" 6 16598 - 16590 S 05/15/94 4" 4 16604 - 16646 0 06/18/94 3-3/8" 6 16658 - 16706 0 06/04/95 ~ 25. 16762' H 7" X 4-1/2" F-1 PERM PKR, ID = 4.00" I 3-3/8" 6 16775 - 16781 S 05/22/94 I I 16768' H 4-112" OTIS X NIP, 10 = 3.813" I 11Et. 16772' H 4-1/2" OTIS XN NIP, ID = 3.725" I 16772' H 4-1/2" OTIS XXN PLUG RUN ON COMPLETION I I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 16777' I I 16777' H 4-1/2" TUBING TAIL WLEG I II I H ELMD TI NOT LOGGED I I PBTD I 17435' I .x x X x I 7" LNR, 29#, L-80, .0371 bpf, 10=6.184" H 17535' I DATE REV BY COMMENTS DATE REV BY COMMENTS NIAKUK UNIT 05/28/94 POOL 7 ORlG COMPLETION 09/03/06 MSS/PAG ClO TIP @ 14488' WELL: NK-23 11/22/01 RNfTP CORRECTIONS 09/14/06 JRP/TLH ClO TIP@ 14488' PERMIT No: 194-0350 03/23/06 MCZ/TLH OA OWN SQZ 09/22/06 RRD/PAG SET WFD PATCHES (9/19 & 20) API No: 50-029-22455-00 07/08/06 JOMlPAG TIW PERM PKR CORRECTION 10/01/06 TWS/PAG PULL XX TIP@ 14487' SLM SEe 36, T12N, R15E, 3630.51 FEL 4062.86 FNL 08/21/06 JCMlPAG SET NIPPLE REDUCERfTTP 08/26/06 RLWiTLH PERF,LNR BP Exploration (Alaska) STATUS: NK-23 (PTD 1940350) . Hello Jim & Winton. Well NK-23 (PTD 1940350) failed an MITIA on 10/22/06. Patches were previously set across tubing leaks and a post-patch MITIA passed. The well was returned to injection and a subsequent MITIA failed. The well is currently injecting 15,000 BPD of sea water at 600 psi. Recent events: > 11/10/05: MITIA Passed to 2500 psi, but exhibits slow IA pressurization > 07/08/06: TecWell LDL > 09/19/06: Set Patches @ 14372'-14334' and 4412' to 4432' > 09/28/06: MITIA PASSED to 3000 psi > 10/01/06: Pulled TTP > 10/22/06: AOGCC MITIA Failed, loses 300 psi/15 min '->' ,;', .., 'l\j Hü 7-~ r: ,;;:;;y.;.. ,r'3·........·~ Planned actions: 1. SL: Determine leak point Attached is an MIT form and wellbore schematic. Please call with any questions. «MIT PBU NK-23 10-22-06.xls» «NK-23.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-51 DO, x1154 Email: NSUADWWelllntegrityEngineer@bp.com PBU NK-23 Content-Description: MIT PBU NK-23 1O-22-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 lof2 10/30/2006 9:34 AM STATUS: NK-23 (PTD 1940350) 20f2 . . Content-Description: NK-23.pdf Content-Type: application/octet-stream Content-Encoding: base64 10/30/2006 9:34 AM TREE = 7-1/16" 5M crvv ~NOTES' 9-5"" C9GSET ON EMERŒNCY I WELLHEAD: 13-5/8" FMC NK-23 ACTUATOR: BAKER SLI ¡: 60,1' 22.4' 1165' 2188' -i 5-1 /2" TRSV, SERIES 10 NIP, ID = 4.562" I 63 @ 15Õ26' 15360' . I Datum ND- 8800'SS GAS LIFT MANDRELS ST MD ND DEV TYÆ VLV LATCH PORT DATE 4 3586 2985 60 OTIS LB RA 3 8789 5597 60 OTIS LB RA ~ IXÌ', ~ 2 13231 7788 60 OTIS LB RA [) 1 14338 8362 61 OTIS LB RA [) ~ t>( \"1 4412' H SET WFO PA TCH ELEMENTS, 10=2.441" (09/20/06) ~ \. 13-3/8" CSG, 72#, L-80, ID:= 12,347" I 5659' µ ~ ~ .. 14923' - 5508' HOA DOWNSQZ (03/17/06) I r-..... N 14329'1-1 SET WFD PA TCH ELEMENTS, 10=2.441 (09/19/06) I I I 14378' H 5-1/2" NIP, PARKER SINS, ID = 4.562" I Minimum ID = 2.313 @ 14488' I g ~ 2-7/8" X NIPPLE REDUCER ~ 14434' 9-5/8" x 5-1/2" TIW PERM PKR 1 W/PKR LATCH, ID:= 4.455" . I 14469' -15-1/2" PARKER SINS NIP, ID : 4.562" I I . .. ~ rl 14488' 1-15-112" OTIS XN NIP, ID = 4.455" I r- -114487' SLM H 5-1/2" X 2-7/8" X NIP REDUCER (09/03/06), ID = 2.3131 14504' -1 TOP OF 9-5/8" X 7" TIEBACK WI 6' SEAL ASSY I I 5-1/2" TBG, 17#, L-80, .0232 bpf, 10 = 4.892" I 14511' I .. I 14511' -15-1/2" TUBING TAIL WLEG I TOP OF 7" LNR I 14517' r- I 14518' H ELMO TUBING TAIL LOGGED 06/22/94 I I 9-5/8" CSG, 47#, L-80, 10 = 8,681" I 14673' µ II ~ ÆRFORA TION SUMMARY 0 .í. 16689' -1 MARKER JOINTS TWO 19' I REF LOG: A WS GRlTEMP ON 06/15/94 Ù ANGLE AT TOP PERF: 53 @ 16598' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE II 3-3/8" 6 16598 - 16590 S 05/15/94 4" 4 16604 - 16646 0 06/18/94 3-3/8" 6 16658 - 16706 0 06/04/95 ~ D I 16762' H 7" X 4-1/2" F-1 ÆRM PKR, ID = 4,00" I 3-3/8" 6 16775-16781 S 05/22/94 I H 4-1/2" OTIS X NIP, ID: 3.813" I I I 16768' IBI I 16772' H 4-112" OTIS XN NIP, ID = 3,725" I I 16772' 1-1 4-1/2" OTIS XXN PLUG RUN ON COMPLETION I I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID: 3.958" 16777' I I 16777' H 4-1/2" TUBING TAIL WLEG I I H B.MO TI NOT LOGGED I I PBTD I 17435' I I I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" H 17535' I DATE REV BY COMMENTS DATE REV BY COMMENTS NIAKUK UNff 05/28/94 POOL 7 ORlG COM PLETION 09/03/06 MSS/PAG C/O TIP@ 14488' WELL: NK-23 11/22/01 RNlTP CORRECTIONS 09/14/06 JRP/TLH C/OTIP@ 14488' PERMrr No: 194-0350 03/23/06 MCZ/TLH OA DWN SQZ 09/22/06 RRD/PAG SET WFO PATCHES (9/19 & 20) API No: 50-029-22455-00 07/08/06 JDMlPA G TIW PERM PKR CORRECTION 10/01/06 TWS/PAG PULL XX TIP @ 14487' SLM SEe 36, T12N, R15E, 3630,51 FEL 4062,86 FNL 08/21/06 JCMlPAG SET NIPPLE REDUCERITTP 08/26/06 RL W¡TLH PERF, LNR & DEPTH CORRECT BP Exploration (Alaska) . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERA TOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / Niakuk 10/22/06 Andrea Hughes Jeff Jones \ qq- 0"06 Packer Depth Pretest Initial 15Min. 30 Min. WellNK-23 Type Inj. I W TVD 8,409' Tubing 800 800 800 800 Interval 0 P.T.D.194-035 I Type test I P Test psi 2102 Casing 640 3,000 2,660 2,370 P/F F Notes: MITIA to eval patch integrity OA 0 250 220 180 Weill I Type Inj. I I TVD I Tubing I Interval P.T.D. Type test I I Test psi Casing I ! P/F Notes: OA I Weill I Type Inj. I TVD I Tubing I I Interval P.T.D. ! Type test I Test psi! Casing (PTD I P/F Notes: OA I Weill Type Inj. TVD Tubing I Interval I p.T.D.1 I Type test Test psi Casing P/FI Notes: OA Weill Type Inj. TVD Tubing Interval p.T.D.1 Type test I Test psil Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = standard Pressure Test R = Internal Radioactive Tracer SUlvey A = Temperature Anomaly SUNey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) .....--- ~tfEti~ NOV f¡ 2006-1022_MIT _PBU_NK-23.Jj.xls NK-23 (PTD# 1940350) MITIA Fonn . Jim, Winton and Bob, Please see the attached MITIA for NK-23 (PTD #1940350). Two tubing patches have been set at 14372' to 14334' and 4412' to 4432' MD. The well passed a subsequent MITIA to 3000 psi to prove tubing integrity. The well will be returned to normal service and the AOGCC field office will be contacted for a witnessed MITIA after the well has warmed up and stabilized on injection. In addition, the well will be removed from the monthly UIC report. Please call with any questions. «MIT GPMA NK-23 09-28-06.xls» Andrea Hughes (Filling in for Anna Dube) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: MIT GPMA NK-23 Content-Type: application/vnd.ms-excel Content-Encoding: base64 GPMA NK-23 1 of 1 9/29/2006 8:50 AM .. · . q \ZqlDiP \2(¿tÔl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERA TOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay I GPMA I Niakuk 09/28/06 Andrea Hughes Packer Depth Pretest Initial 15Min. 30 Min. WellNk-23 I Type Inj, I N TVD I 8,409' Tubing 700 750 700 680 Interval I 0 P.T.D,1940350 I Type test I P Test psil 2102.25 Casing 500 3,000 2,940 2,920 P/FI P Notes: MITIA for eval Tubing Integrity. OA 0 0 0 0 Weill Type Inj. I ND I Tubing Interval I P.T.D.I I Type test I Test psil Casing P/FI Notes: OA Weill Type Inj. TVD I Tubing Interval I P.T.D·I I Type test I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Intervall p.T.D.1 I Type test I I Test psi! Casing P/FI Notes: OA Weill I Type Inj, I TVD I Tubing Interval I P.T.D.I I Type test I Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT GPMA NK-23 09·28-06.xls ^ 1. Operations Performed: Repair WellŒ] Plu¡:¡ PerforationsD Stimulate 0 OtherD AbandonD Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 0 ExploratoryD 194-0350 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO Service ŒJ 50-029-22455-00-00 7. KB Elevation (ft): 9. Well Name and Number: 58.60 NK-23 8. Property Designation: 10. Field/Pool(s): ADL-0034634 Prudhoe Bay Field / Niakuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 17535 feet true vertical 10062.6 feet Plugs (measured) None Effective Depth measured 17435 feet Junk (measured) None true vertical 10004.1 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 94# H-40 42 - 122 42.0 - 122.0 1530 520 SURFACE 5618 13-3/8" 72# L-80 41 - 5659 41.0 - 4045.0 4930 2670 PRODUCTION 14635 9-5/8" 47# L-80 38 - 14673 38.0 - 8528.0 6870 4760 LINER 3018 7" 29# L-80 14517 - 17535 8450.0 - 10063.0 8160 7020 LINER SLEEVE 12 7" 29# L-80 14504 - 14516 8443.6 - 8450.0 8160 7020 Perforation depth: Measured depth: 16604-16646, 16658-16706 SCN\lNEif) NO\! 02 True vertical depth: 9535-9560,9567-9594 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 @ 35 - 14511 4-1/2" 12.6# L-80 @ 16762 - 16777 Isolation Assembly 2-7/8" 6.5# L-80 @ 4412 - 4432 Tubing Patch 2-7/8" 6.5# L-80 @ 14329 - 14367 Tubing Patch Packers & SSSV (type & measured depth): 5-1/2" WFD Patch Elements @ 4412 - 4432 5-1/2" WFD Patch Elements @ 14329 - 14367 9-5/8" TIW Packer @14434 7" Baker F-1 Packer @ 16762 5-1/2" TRSSV @ 2188 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure TubinQ Pressure Prior to well operation: --- --- SI -- 44 Subsequent to operation: --- --- 10,759 - 631 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ] Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilD GasD WAG 0 GINJD WINJŒ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact DeWayne R. Schnorr 306-261 Printed Name DeWavne R. Schnorr Title Petroleum Engineer Signature k~-, /- 'iF Phone 564-5174 Date 1 0/3/06 Form 10-404 Revised 4/2004 U b, \j 11\1 A L ..... ,,", v v !J U .L UUU STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TtO'Nf§& Gas Cons. COirli!lissiO/1 . RECEIVED OCT 0 4 ¿ ) . . NK-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10101/2006 TAG XX-PLUG WI EQL. PRONG I PULLED 2.313 XX-PLUG FROM 14,477' SLM. 09/30/2006 *** WELL SI ON ARRIVAL *** RIH WI EQL. PRONG FOR 2.313 XX PLUG SAT DOWN @ 4,380' SLM COULD NOT WORK THROUGH POOH. 09/28/2006 T/l/O = 700/50010 - Temp = SII - MIT IA PASSED to 3000 psi, MIT T FAILED to 3000 psi CMIT TxlA FAILED to 3000 psi (Restore Tubing integrity) - MIT IA - Pressured up IA w/7 bbls 45* neat meth. MIT IA lost 60 psi in 1 st 15 min and 20 psi in 2nd 15 min for a total loss of 80 psi in 30 min test. Bled lAP to 500 psi. MIT T - Pressured up TBG w/4.3 bbls neat meth. MIT T lost 680 psi in 1st 15 min and 340 psi in 2nd 15 min for a total loss of 1020 psi in 30 min test. (2nd test) Pressured up TBG w/1.9 bbls 45* neat meth. MIT T lost 420 psi in 1 st 15 min and 330 psi in 2nd 15 min for a total loss of 750 psi in 30 min test. (3rd test) Pressured up TBG w/1.3 bbls 45* neat meth. MIT T lost 360 psi in 1 st 15 min and 310 psi in 2nd 15 min for a total loss of 670 psi in 30 min test CMIT TxlA - Pressured up IA w/6.6 bbls 45* neat meth. Pressured up TBG w/.9 bbls 45* neat meth. - TBG lost 350 psi in 1 st 15 min and 250 psi in 2nd 15 min for a total loss of 600 psi in 30 min test. IA lost 20 psi in 1 st 15 min and 20 psi in 2nd 15 min for a total loss of 40 psi in 30 min test. Bled to starting pressures. FWP's = 620/44010. 09121/2006 T/I/O=725/38010 MIT IA 3000 psi, PASSED I MIT T to 3000 psi, FAILED, LLR too small for big pump (Restore tubing integrity) - Pressure IA to 3000 psi wI 7 bbls meth, SD, Start testing, 1st test lost 80 psi in 15 min, Lost 30 psi in 2nd 15 min, PASS, Bleed lAP, RD IA RU tubing MIT tubing - Pressure tubing to 3000 psi wI 4 bbls meth, SD, Start testing, 1 st test lost 450 psi in 15 min. Fail, Bumped up with .8 bbls. meth, 2 nd test lost 400 psi. in 15 min. Fail, Bumped up with .9 bbls. meth, 3 rd test lost 380 in 15 min., Fail, LLR too small for big pump, Bleed TP Freeze protect injection line wI 5 bls meth Final WHP's=400/25010 09/20/2006 SET UPPER ELEMENT LOWER PATCH 14334' AND UPPER PATCH ELEMENTS 4412'- 4432', MINIMUM ID 2.441". PDS LOG AT GLM 3586' HAS 10' ADDED BELOW GLM AND MAKES 50' JT, LOGGED FROM GLM 8789' TO SET DEPTH FOR ELEMENT 4432'. DEPTH DISCREPANCY WITH PDS LDL MEMORY LOG. WHERE PDS SLOWED DOWN GOING INTO, THROUGH, AND OUT OF GAS LIFT MANDRELS THE TIME VS. DEPTH CORRECTIONS MADE PUT GAS LIFT MANDRELS ON DEPTH THUS MAKING COLLARS ABNORMAL LENGTHS IN SAME AREA. CORRELATION PASSES MADE ALLOWED FOR CORRECTION. LEFT WELL SHUT IN. NOTIFIED DSO OF RIG DOWN AND MOVING TO NK-43 FOR ONE RUN BAKER PATCH JOB. *****JOB COMPLETE***** 09/19/2006 SET LOWER PACKER ELEMENT OF PATCH 14372', CONTINUE NEXT REPORT. DEPTH DISCREPANCY WITH PDS LDL MEMORY LOG. WHERE PDS SLOWED DOWN GOING INTO, THROUGH, AND OUT OF GAS LIFT MANDRELS THE TIME VS. DEPTH CORRECTIONS MADE PUT GAS LIFT MANDRELS ON DEPTH THUS MAKING COLLARS ABNORMAL LENGTHS IN SAME AREA. CORRELATION PASSES MADE ALLOWED FOR CORRECTION. Page 1 . . NK-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/13/2006 T/I/O=900/70010Assist slickline with CMIT TBG x IA to 3000 psi (Post TTP Set) PASSED Loss 200 psi 1st 15 min, loss 140 psi 2nd 15 min, (2nd test) Loss 140 psi 1st 15 min, 140 psi 2nd 15 min, (3rd test) loss 140 psi 1st 15 min, loss 140 psi 2nd 15 min. Bled well back to o psi, Redue CMIT TBG x IA to 3000 psi. (4th test) Loss 60 psi. 1st 15 min, 90 psi 2nd 15 min, (5th test) Loss 20 psi. 1 st 15 min., 40 psi. 2nd 15 min. (6th test) Loss 0 psi. 1 st 15 min., 0 psi. 2nd 15 min. FWP's=300/40010 09/13/2006 (Pre patch) SET 51/2" X 27/8" NIPPLE REDUCER WI SECONDARY LOCKDOWN INSTALLED, RAN 51/2" CK SET (GOOD), SET 27/8" "XX" PLUG IN NIPPLE REDUCER @ 14,464' SLM (TAGGED WING WI PLUG INFO) , LRS PERFORMED CMIT TO 3000# (SEE LRS WSR). RDMO ***WELL LEFT SHUT IN*** NOTIFIED PAD OP. 09/12/2006 **** WELL SHUT IN ****(Set nipple reducer) ATTEMPTED TO SET 51/2" "XN" NIPPLE REDUCER. (2 7/8" X - INNER NIPPLE). LOST PLUG IN LOWER NIPPLE. RETREIVED NIPPPLE REDUCER. PACKING AND BACK-UP RING WAS PRETTY TORN UP!!! RAN AGAIN, COULDN'T GET THROUGH TRSV. LEFT IN TRSV RIH TO PULL AT REPORT TIME **** JOB STILL IN PROGRESS. 09/06/2006 **** WELL SHUT IN ON ARRIVAL *** PULLED 2 7/8 XX-PLUG AND 5 1/2 XN-NIPPLE REDUCER@ 14,470' (SLM). **** WELL LEFT SHUT IN AND TURNED OVR TO DSO *** 09/03/2006 SET 5.5 XN- NIPPLE REDUCER. W/2.313 X-PROFILE WI SECONDARY LOCKDOWN @ 14,487' (SLM). MIT TUBING FAILED ----WiLL RETURN @ LATER DATE TO RETEST----- *** WELL LEFT SHUT IN AND TURNED OVER TO DSO *** 09/02/2006 PULLED AND RESET 2 718 XX-PLUG @ 14,464' (SLM) (ADDED ON PIECE OF PACKING ON BOTTOM OF STACK) ATTEMPTED TO MIT TUBING, FAILED EQUALIZED 2 7/8 XX- PLUG. PULLED 2 7/8 XX- PLUG AND 5.5 XX- NIPPLE REDUCER *** JOB IN PROGRESS. 09/01/2006 *** WELL SHUT IN ON ARRIVAL *** (PRE MIT-T) ******** SECOND REPORT ******** EQUALIZE 2 7/8" XX TTP @ 14,464' SLM (TBG PRESS. DROPPED 150 PSI FROM 900 PSI TO 750 PSI). 09/01/2006 (PRE MIT-T) ******** FIRST REPORT ******** ATTEMPTED TO GET GOOD MIT ON TBG WI NO SUCCESS RIGGED DOWN TO DO JOB ON NK-12 AND RETURN LATER TO TROUBLE SHOOT TTP *** WELL LEFT SHUT IN & TURNED OVER TO DSO *** 08/31/2006 SET 5.5 NIPPLE REDUCER SET @ 14,464' SLM. CONFIRMED WI 5.5 CHECK SET SET 2.313 XX PLUG TO 14,464' SLM TUBING PRESSURE WAS 850 PSI WHEN PLUG WAS SET ATTEMPTING TO CMIT TX IA. 08/30/2006 ***WELL SII ON ARRIVAL*** RAN 5.5 BRUSH AND 4.0 GAUGE RING BRUSHED X- NIPPLE @ 14,469' MD ATTEMPTING TO SET 5.5" NIPPLE REDUCER (2.313" ID). 08/30/2006 T/I/O= 900/440Nac. Temp= SI. WHP's, TBG FL (E-Line). IA FL @ surface. OA FL near surface. Unable to get tubing FL, (E-Line in hole). Page 2 . . NK-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/29/2006 ***WELL SII ON ARRIVAL*** PULL 2.313" XX PLUG FROM 14460' SLM PULL 5.5" NIPPLE REDUCER FROM 14460' SLM, SHUT DOWN FOR THE NIGHT NO NIGHT CREW ***WELL SII ON DEPARTURE*** ( NOTIFIED DSO ) 08/28/2006 ***WELL SII ON ARRIVAL*** (re-mit-t) RUN 3.650" CENT 33" EQUAL PRONG SD IN SSSV @ 2165' SLM, PRESSURE UP TUBE 1500 PSI, WORK TOOLS THROUGH SSSV, CO NT DOWN HOLE SD @ 14463' SLM HAVE 15PSI PRESSURE CHANGE. GOOD MARKS ON BOTTOM OF EQUALIZE PRONG, NOTE:---- LAY DONW EQUIPMENT DUE TO NO NIGHT SHIFT - WILL RETURN IN A.M. TO COMPLETE JOB ***WELL SII ON DEPARTURE*** ( NOTIFIED DSO ) 08/23/2006 T/IAlOA=1500/60010 MIT-IA to 3500psi, FAILED (Tubing repair) Pressured up IA with 7.6 bbls. Meth, starting test,1 st test IA lost 120 psi. in 1 st. 15 min. & lost 80 psi. in 2nd 15 min. Bumped up with .5 bbls. meth,2nd test IA lost 80 psi. in 1 st. 15 min. & lost 80 psi. in 2nd 15 min. Bumped up with .4 bbls. meth, 3rd test IA lost 80 psi. in 1 st. 15 min. & lost 60 psi. in 2nd 15 min. Bumped up with .3 bbls. meth, 4th test IA lost 80 psi. in 1 st. 15 min. & lost xx psi. in 2nd. 15 min. FAILED, LLR too slow for big pump, Bleed lAP Final WHP's 840/55010 08122/2006 T/IAlOA = 920/60010 MIT-T @ 3500 psi. FAILED (Tubing repair) - Pressured tubing to 3500 psi. with 4.4 bbls. meth, Start testing, Tubing lost 900 psi. in 15 min. Bumped up with 1.8 bbls. meth, 2nd. test lost 600 psi. in 15 min. Bumped up with 1.7 bbls. meth, 3rd. test lost 660 psi. in 1 st. 15 min. Lost 500 psi in 2nd 15 min. FAILED, LLR too slow for big pump 08/21/2006 ***WELL FLOWING ON ARRIVAL *** (pre patch) RAN FLAPPER CHECKER. DRIFTED W/3.80 CENT,TEL,& S.B. TO 16,683' CORR ELMD (BTTM OPEN PERF @ 16,706'MD, 23' OF FILL & 79' OF PERFS STILL OPEN) . NO SAMPLE. RAN PETREDAT TANDEM GAUGES AS PER PROGRAM. SET 5.5 X 2718 NIP REDUCER IN X NIP @ 14,461'SLM . SET 2718 XX PLUG IN NIP REDUCER ***WELL LEFT SII ON DEPARTURE*** 08/21/2006 TAG: ***WELL FLOWING ON ARRIVAL *** (PRE PATCH) RAN FLAPPER CHECKER. DRIFTED W/3.80 CENT,TEL,& S.B. TO 16,683' CORR ELMD (BTTM OPEN PERF @ 16,706'MD, 23' OF FILL & 79' OF PERFS STILL OPEN) 07/09/2006 REDRESS STUFFING BOX. PULLED PXN PLUG FROM XN NIP. @ 14,453' SLM. DRIFT TUBING WI DUMMY PATCH, 4.53" OD, 74" OAL TAG XN @ 14,466' SLM RDMO ***WELL LEFT SI*** 07/08/2006 LOG TUBING WI TECWEL MEMORY LOGGING STRING, SEE PDS FOR DATA, MIT TUBING AND IA GOOD TEST, PULL PX PRONG *** JOB IN PROGRESS*** 07/07/2006 SET PXN-PLUG @ 14,472' SLM, SET PRONG @ 14,472' SLM. TESTED PLUG TO 2500 PSI, IA CAME UP FROM 1500 PSI TO 1950 PSI. RIH WI PDS LDL TOOLS, COULDN'T GET THROUGH SSSV. @ 2156'. CIO CENTRALIZER ON PDS TOOL. RIH WI LOGGING TOOLS. 07/06/2006 SET 5.5 XX-PLUG @ 14,469' SLM. FAILED TEST PULL PLUG. RIH WI 5.5" PXN PLUG 07/05/2006 SET 5.5" XXN PLUG @ 14460' SLM. FAILED MIT. PULLED 5.5" XXN.BRUSH TUBBING DOWN TO 14,600' SLM. Page 3 . . NK-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/04/2006 BRUSHED TUBING WITH 5.5" B. BRUSH & 4" G. RING. BRUSHED TRSV & ALL NIP'S DOWN TO XN @ 14470' SLM. LRS PUMPED A TOTAL OF 90 BBLS OF DIESEL & 283 BBLS OF CRUDE. OIL JARS SWIVELED OFF-FISHED FROM 16654' SLM. ATTEMPTING TO SET 5.5" XXN PLUG. 07/04/2006 Assist Slick-line w/brush and flush (pre-LDL) (Eval for TBG repair) Pumped 283 bbls 180* crude and bbls 180* diesel down TBG. FWHP's=1300/1500/460 07/03/2006 SET 5.5" XN PLUG @ 14460' SLM. PULLED 5.5" XN PLUG @ 14460' SLM AFTER FAILED TEST-CAME BACK FULL OF SAND. BRUSH & FLUSH TUBING WI 4.5" B. BRUSH WI 4.0" G. RING. 07/02/2006 ***WELL S/I ON ARRIVAL *** RAN 4" G. RING WI 5.5" B. BRUSH. BRUSHED ALL NIPS DOWN TO 14465' SLM. TRSV VERY TIGHT! RUNNING IN HOLE WITH 5.5" XN PLUG. 07/01/2006 T/I/O=990/750/260. Temp=SI. TBG & IA FL's. (Pre-SL). TBG & IA FL's both @ Surface. FLUIDS PUMPED BBLS 23 PT Surface Equipment 134.7 Methanol 127 Diesel 283 Crude 567.7 TOTAL Page 4 'fI"REE= 7-1/16" 5MCIW . S.NOTES: 9-5/S" CSG SET ON EMERGENCY WELLHEA D - 13-5/8" FMC NK-23 ACTUATOR = BAKER SL t:(B. ELEV = 60.1' BF. ELEV = 22.4' KOP- 1165' 2188' -15-1/2" TRSV, SERIES 10 NIP, ID = 4.562" I Max Angle = 63 @ 15026' . Datum MD = 15360' Datum ìVD- 8800' SS GAS LIFT MANDRELS ST MD ìVD DEV TYPE VLV LA TCH PORT DATE 4 3586 2985 60 OTIS LB RA r: 3 8789 5597 60 OTIS LB RA Ì'- t~ 2 13231 7788 60 OTIS LB RA ~ 1 14338 8362 61 OTIS LB RA ~ r\'1 4412' l-f SET WFD PA TCH ELEMENTS, ID=2.441" (09/20/06) \. I 13-3/8" CSG, 72#, L-80, ID = 12.347" I 5659' µ r ~ ~ ~ 4923' - 5508' -OA DOWNSQZ (03/17/06) I r---.. N 14329' 1-; SET WFD PATCH ELEMENTS, 10=2.441 (09/19/06) I I 14378' -5-1/2" NIP, PARKER SWS, ID = 4.562" I Minimum ID = 2.313 @ 14488' ~ I I 2-7/8" X NIPPLE REDUCER 14434' 9-5/8" x 5-1/2" TIW PERM PKR I ~ W/PKR LA TCH, ID = 4.455" I I 14469' --f 5-1/2" PARKER SWS NIP, ID = 4.562" I rr~ hits b't'J.t c::::::: -- - I-f 14488' 1-/5-112" OTIS XN NIP, ID = 4.455" I "If/(e.d 10 /OI/AðO~ ....... r--... 114487' SLM1- 5-1/2" x 2-718" X NIP REDUCER (09/03/06), ID = 2.313 N'14487' SLMI- 2-7/8" XX TIP (09/13/06) I ~ 14504' -TOPOF 9-5/8" X 7" TIEBACKW/6' SEAL ASSY I I 5-1/2" TBG. 17#, L-80, .0232 bpf, ID = 4.892" 14511' r f 14511' -/5-1/2" TUBING TAIL WLEG I I I 14518' 1-1 ELMD TUBING TAIL LOGGED 06/22/94 I TOP OF 7" LNR I 14517' }- I 9-5/8" CSG, 47#. L-80, ID = 8.681" I 14673' µ PERFORA TION SUMMARY [ r 16689' - MARKER JOINTS TWO 19' I REF LOG: A WS GRlTEMP ON 06/15/94 ANGLEATTOPPERF: 53 @ 16598' I Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE I 3-318" 6 16598 - 16590 S 05/15/94 4" 4 16604 - 16646 C 06/18/94 3-3/8" 6 16658 - 16706 C 06/04/95 15< ~ 16762' H 7" X 4-112" F-1 PERM PKR. ID = 4.00" I 3-3/8" 6 16775 - 16781 S OS/22/94 1'= I I 16768'1-/ 4-112" OTIS X NIP, ID = 3.813" I .s1::. ~J( ì~ f'lttc.re. ..... fr 16772' H 4-1/2" OTIS XN NIP, ID = 3.725" I 16772' H 4-1/2" OTIS XXN PLUG RUN ON COMPLETION I /0/03/°' I 4-112" TBG,12.6#. L-80, .0152 bpf, ID = 3.958" , 16777' 16777' H 4-1/2" TUBING TAIL WLEG I I I H ELMD TI NOT LOGGED I I PBTD I 17435' I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 17535' I DATE REV BY COMMENTS DATE REV BY COMMENTS NIA KUK UNIT OS/28/94 POOL 7 ORlG COMPLETION 09/03/06 MSS/PAG C/O TIP @ 14488' WELL: NK-23 11/22/01 RNlTP CORRECTIONS 09/14/06 JRP/TLH C/O TIP @ 14488' PERMIT No: 194-0350 03/23/06 MCZITLH OA DWN SOl 09/22/06 RRD/PAG SET WFD PATCHES (9/19 & 20) API No: 50-029-22455-00 07/08/06 JDMlPAG TIW PERM PKR CORRECTION SEC 36, T12N, R15E, 3630.51 FEL 4062.86 FNL 08/21/06 JCMlPAG SET NIPPLE REDUCER/TTP 08/26/06 RLWITLH PERF, LNR & DEPTH CORRECT BP Exploration (Alaska) . . RECEIVEl) WELL LOG TRANSMITTAL AUG 2 !) 20fJ6 ProActive Diagnostic Services, Inc. i\Iaska 0;1 & Gas Cons. Commission Anchorage To: AOGCC Records Department 333 W. 7th Ave Suite 1 00 Anchorage, Alaska 99501 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 [~~J ~_.. Ct.rf?J111 <? (hÖÍ1Aj~-~A/1 1] EDE Disk NK - 23 2) 3) 4] 5) 6] 7) Signed : Print Name: 05-Jul-06 Leak Detection - WLD ~CANNED AUG 30 2006 Date: 15/9 0..( 0 (/1 PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT Ro SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAil: PDSANCHORAGE@MEMORYlOG.COM WEBSITE : WWW.MEMORYlOG.COM l)JC- 1C14~D~ .-tt:- ILfb~b0fs C:\Documenls and SeUingsIPDS Anchorage. MPLIDesktop\Tl1IßSmil_ Original.doc . . FRANK H. MURKOWSKI, GOVERNOR AI.ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ross Warmer Production Engineer BP Exploration (Alaska) Inc. PO Box 196613 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Niakuk Oil Pool, NK-23 Sundry Number: 306-261 ¡:; ') ~. 'nni' ...J ....,f ..., 'co,....",''',) Dear Mr. Warmer: 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 thisi day of August, 2006 Encl. J0~/-D3:) _ STATE OF ALASKA c.,q~'31J/;z A~ OIL AND GAS CONSERVATION COMM_N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 v.J61\- e/ 3 I z,ð 0 ~ 1. Type of Request: Abandon U Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Suspend 0 Repair well [2] Pull Tubing 0 Operational shutdown U / Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development D Stratigraphic D Perforate U Waiver U Stimulate 0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 194-0350 / Other U Exploratory D / Service ø 6. API Number: 50-029-22455-00-00 / 9. Well Name and Number: 58.6 KB NK-23 /' 8. Property Designation: ADL -034634 11. Total Depth MD (ft): 17535 80 5618 14635 3018 7 10p¡i~/POOIS(S): IUGI\- . B . / Niakuk Oil Pool PRESENT WELL CONDITION SUMMARY rEffective Depth MD (ft): Effective Depth TVD (ft): IPlugs (measured): 17435 10004.07 16772 XXN Size MD / TVD Burst 20" 94# H-40 42 122 42 122 1530 13-3/8" 72# L-80 41 565941 4025 4930 9-5/8" 47# L-80 38 14673 38 8528 6870 7" 29# L-80 14517 175358450.05 10063 8160 7" Liner tieback sleeve 14504 14511 8443.61 8447 IJUnk (measured): I None Collapse 520 2670 4760 7020 Casing Conductor Surface Production Liner Liner sleeve rTotal Depth TVD (ft): 10062.65 Length Perforation Depth MD (ft): 16604 - 16706 / Perforation Depth TVD (ft): 9535.43 - 9593.82 Tubing Size: 5-1/2" 17# 4-1/2" 12.6# ./' Tubing Grade: L-80 L-80 Tubing MD (ft): 35 -14511 16762 - 16777 / Packers and SSSV Type: 5-1/2" TIW Packer 7" x 4·1/2" Baker F-1 Packer 5-1/2" TRSSV Packers and SSSV MD (ft): 14434 16762 / 2188 12. Attachments: Descriptive Sum m ary of Proposal D Detailed Operations Program ø BOP Sketch D 14. Estimated Date for 13. Well Class after proposed work: Exploratory D Development D Service ø Date: 15. Well Status after proposed work: /' Oil D Gas D Plugged 0 Abandoned D WAG D GINJ 0 WINJ ø WDSPL D Prepared by Sharmaine Vestal 564-4424 Commencing Operations: 16. Verbal Approval: Commission Representative: 8/16/2006 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Ross Warner /1 Title Production Engineer Signature ( ;V ~ æ'~.IL.J'hone 564-5359 Date COMMISSION USE ONLY Ross Warner 8/2/2006 Conditions of approval: Notify Commission so that a representative may witness SUndry Number: 30 10 .~ lo t Plug Integrity 0 BOP Test 0 Mechanicallntegritfte.~ IVEE):learance 0 Other: MC, Yeo~Y\-ld. AUG 0 2 2006 too ¡zZ¿1-- Anchorage APPROVED BY C~SSIONER THE COMMISSION V~V RBDMS BFL AUG 0 4 2006 Subsequent Form Required: Approved by: Date: ~..tf-()b Form 10-403 Revised 7/2005 ORIGINAL Submit in Duplicate . . Jerry Bixby/ Clark Olsen GPB Wells Operations Supervisors Date: July 31, 2006 To: From: Ross Warner, Chris Stone: GPMA Production Engineers Subject: NK-23 Tubina Patches- Two Leaks to Fix Cost Code: NENIAWL23-N & R bopd lOR: 800 Estimated cost: $100M Backaround Information NK-23 is an injector which supports producing wells NK-42 and NK-20. This well has a tubing to IA communication problem and has been shut in since October 8, ,/ 2005. The outer annulus was unsuccessful squeezed 3/17/06 in order to meet the two barrier safety requirements. On May 16, 2006 a PDS Memory Multi- Finger Caliper was run and it indicated "that the 5-1/2" tubing is in good to poor condition with a maximum recorded penetration of 63% @6873' MD". July 7, 2006 TecWellPDS ran a Leak Detect Log and it indicated two tubing leaks. The shallow leak is at 4422'SLM and the bottom leak is at 13,364' SLM. The ,/ calculated leak rate during logging was about 0.30 gpm. The leak at 4422' has a substantial temperature anomaly, but the deeper leak has almost no temperature change. It will be necessary to use the Arctic Rentals 110ft. crane to set the patches. Well data: Injector: Max Deviation: BHP: Min.ID: Fish: Last TD tag: Last DH Ops: Normal rate was 10,000 bwpd at 1000 psi. 63 degrees at 15,026' ....4500 psia @ 9200' SS 3.725"@16,772'MD. 4-1/2" Otis XN Nipple None 6/4/1995: TD Tagged at 16,749' MD Perforating. Log. 7/9/06: Pulled PXN plug from XN Nipple @ 14,453' MD. Drifted tubing with 4.53" OD dummy patch. . . Latest H2S value: Not in data base. Summary: 1 S Run SBHPS. Tag TD. Set 5-1/2 x 2-7/8" XN reducing nipple. ID W/O plug = 2.313". Set PX plug. Note depth of well. 16,750' MD 2 E Set two tubing patches per program. Need Arctic Rental Crane 3 0 MIT-T. MIT-IA. ¡' 4 S Pull plug from reducing nipple. 5 0 Put the well on injection. ('" Objective: Patch tubing leaks at 4422' and 13,364' MD: Ref. Log is LDL dated 7/8/06 Procedure: 1. Slick line: Run SBHPS per the attached sheet. Use a TEL and tie into Atlas Temperature/ GR/ Collar Log run 6/22/1994. The tubing tail at ELMD is at 14,518 ft. After SBHPS run back in well and set a 5-1/2" x 2-7/8"XN reducing nipple in the profile at 14,488'MD. Set a PX plug in nipple. 2. Rig up E-Line on an Arctic Rental Crane (110ft mast) as the first patch will be 38 ft long. I would strongly suggest you make a separate CC Log run to tie into the Jewelry at the SWS Nipple located just below the bottom leak. With a packer/setting tool the CC locator will be somewhat centralized and collars might be difficult to see. The PDS CCL seems to be right on with the Atlas Temperature CCL run 6/22/1994. · Pick up the lower Weatherford Packer (659-2356) and set the center of the element at 14,372' MD. (Note attached log) POH. · Pick up the upper Weatherford packer with a 2-718" 6.5 #/ft., ID=2.441" spacer tube and set the center of the packer element at 14,334' MD. Overall length of the patch will be 38 feet center to center. POH. · Repeat the above process by setting a 20 ft. patch across the leak at 4422' MD. The center of the bottom element should be at 4432 ft. and the center of the top element should be at 4412 ft. Since all of the joints in this area are rather uniform. I would tie into the GLM #4 and set the packer at 4432' running in the hole. POH and rig down. · Note: Weatherford ERP system for 5-1/2" tubing is rated as follows: 5000 psi differential, I.D. = 3.120", running O.D. = 4.5", length of packer is 4.98" ft. 3. Move in pumping equipment and perform a MIT-T and MIT-IA. ,/ 4. If the above tests are good pull the PX plug from the reducing nipple. 2 . . 5. Put the well on injection. If there are any questions please contact: Ross Warner: 564-5359 (W), 333-9017 (H), 250-3441 (cell) Chris Stone: 564-5684 (W), 347-5238 (Cell). 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NTaOS NSCC 4.892 6.06 19,61 14491.93 14511.54 X·O BTC box X NSCC oin 4.892 6.06 2.03 14489.90 14491.93 5·112" X·N niDDle wI RHC Dlua installed 4.455 6.06 1.40 14488.50 14489.90 X-O NSCC box X BTC oin 4.892 6.06 2.05 14486.45 14488,50 Puo JI, 5·1/2" 17# NT80S NSCC 4.892 6.06 6.07 14480.38 14486.45 Puo Jt 5·1/2' 17# NT80S NSCC 4.892 6.06 9.63 14470.75 14480.38 SWS' niDPle, 5-112" NSCC 4.562 6.06 1.32 14469.43 14470.75 PUP Jt 5·1/2" 17# NT80S NSCC 4.892 6.06 19.61 14449.82 14469.43 PuP Jt 5·1/2" 17# NT80S NSCC 4.892 6.065 9.62 14440.20 14449.82 TIW Packer 9·5/8" X 5·112" 4.75 8.228 5.80 14434.40 14'440.20 TIW Packer Latch 4.822 7.175 1.48 t 4432.92 14434.40 PUD JI 5·1/2" 17# NT80S, NSCC 4.892 6.065 9.62 14423.30 14432.92 1 Jt 5·1/2", 17# L-80 NSCC Too 4.892 6.06 33.95· i... 14389.35 14423.30 PuP Jt 5-1/2" 17# NT80S NSCC 4.892 6.06 9.63 14379.72 14389.35 'SWS' niDDle 5·112" NSCC 4.562 6.06 1.32 \/ 14378.40 14379.72 Puo J 5-1/2" 17#, NT80S NSCC 4.892 6.06 19.61 14358.79 14378.40 PUD Jt 5-112" 17# NT80S. NSCC 4.892 6.06 9.61 14349.18 14358.79 X·O 8 rd box X NSCC Din 4.892 6.05 1.90 14347.28 14349.18 GLM #1 Otis LB 1.5" Dummv. RA Latch 4.57 7.78 9.04 14338.24 14347.28 X·O NSCC box X 8 rd Din 4.892 6.06 1.90 14336.34 14338.24 Puo Jt, 5·1/2" 17#, NT80S NSCC 4.892 6.06 9.61 14326.·73 14336.34 32 Jts 5·1/2" 17#' L·80, NSCC Tba 4.892 6.06 1075.06 13251.67 14326.73 Puo JI 6·1/2", 17# NT80S, NSCC 4.892 6.06 9.61 13242.06 13251.67 X·O 8 rd box X NSCC pin 4.892 6.05 1.64 13240.42 13242.06 GLM #2 Otis LB 1.5" Dummv. RA Latch 4.57 7.78 9.11 13231.31 13240.42 X·O NSCC box X 8 rd pin 4.892 6.06 2.15 13229.16 13231.31 PUD JI 5·1/2" 17#, NT80S, NSCC 4.892 6.06 9.61 13219.55 13229.16 122 Jts, 5·1/2" 17# L-80 NSCC Too 4.892 6.06 4409.99 8809.56 13219.55 PUD Jt 5·1/2" 17# NT80S NSCC 4.692 6.06 9.63 8799.93 8809.56 X·O 8 rd box X NSCC Din 4.892 6.05 1.69 8796.24 8799.93 GLM #3 Otis LB. 1.5" Dummv. RA Latch 4.57 7.78 9.09 8789.15 6796.24 X·O NSCC box X 8 rd cin 4.692 6.06 1.93 8787.22 8769.15 Puo Jt, 5·1/2" 17#, NT80S. NSCC 4.892 6.06 9.63 8777.59 8787.22 125 Jls, 5·1/2" 17#, L-80, NSCC Tba 4.692 6.06 5171.41 3606.18 8777.59 Puo Jt 5·1/2" 17#, NT80S NSCC 4.692 6.06 9.63 3596.55 3606.18 X·O BTC box X NSCC Din 4.892 6.05 2.01 3594.54 3596.55 GLM #4 Otis LB 1.5" Dummv. RA Lalch 4.57 7.78 9,03 3585.51 3594.54 X·O NSCC box X BTC oin 4.892 6.06 2,00 3583.51 3585.51 Puo JI. 5-1/2" 17#, NT80S, NSCC 4.892 6.06 9.63 3573.88 3583.51 33 Jls 5·1/2" 17#, L-80, NSCC Too 4.892 6.06 1360,92 2212.96 3573.88 Puo JI 5·1/2", 17#, NT80S. NSCC 4.892 6.06 9.65 2203.31 2212.96 Flow Coupling 4.767 6.05 5.65 2197,66 2203.31 SSSV Otis model 10 TROP 4.562 8.39 9.70 2187,96 2197.66 Flow CouDlina 4.767 6.05 5,64 2182.32 2187.96 PUD Jt 5-1/2". 17#, NT80S, NSCC 4,892 6.06 9.44 2172.88 2182.32 50 Jts 5-1/2", 17#, L·80 NSCC Too 4.892 6.06 2069,07 103.81 2172.88 Soace Out DUDS 4.892 6.06 19.28 84.53 103.81 1 Jt 5·1/2" 17# L·80 NSCC Tbct 4.892 6.06 41.45 43.08 84.53 , . 43.08 Puo Jt 5·1/2" 17#, NT60S, NSCC 4.892 6.06 2.07 41.01 FMC Too Har wi 7" PuP & 7 X 5-1/2 X·O 4.892 13.54 5.66 I 35.35 41.01 Pool7 Rot Tbl10 Tubina Har LDS 35.35 I 35.35 . . 7-1/16" 5MCIW 13-5/8" FMC BA KER 60.1' 22-4' 1165' 15026' 15360' 8800' SS NK-23 () Minimum 10 3.725" @ 16772' 4-1/2" XN NIPPLE SIZE SPF INTERV A L 3-3/8" 6 16598 16604 4" 6 16604 16646 6 16656 - 16686 3-3/8" 6 16686 - 16706 3-3/8" 6 16775 16781 16777' 17435' 7" LNR. 29#, L-80. .0371 bpf, 10 = 6.184" H 17535' REV COMMENTS POOL 7 ORIG COM PLETION RN/TP CORRECTIONS MCZ/TLH OA OWN SOZ DiVl/PAG TIW PERM PKR CORRECTION DATE BY COMMENTS / 4923' - 5508' 16762' 16768' 16772' 16772' 16777' 14511' 14518' 16689' SAFETY NOTES 9-5/8" CSG SET ON EMERGENCY SLIPS 2188' MD 3586 8789 13231 14338 1VD 2985 5597 8362 RA RA --15-1/2" TUBING TÞ,IL WLEG I 1-1 ELMO TUBING TAIL LOGGED 06/22/94 4-1/2" TUBING TAIL WLEG I NIAKUK UNIT WELL: NK-23 PERMIT No 194-0350 API No 50-029-22455-00 SEC 36, T12N, R15E, 3630.51 FEL BP Exploration (Alaska) · STATE OF ALASKA _ AlAS~ Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well 0' Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic 0 Stimulate D Other· 0 Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 194-0350 R1 6. API Number: 50-029-22455-00-00 9. Well Name arid Number: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 58.6 KB 8. Property Designation: ADL-034634 11. Present Well Condition Summary: Total Depth measured 17535 true vertical 10062.65 Effective Depth measured 17435 true vertical 10004.07 Casing Conductor Surface Production Liner Length 80 5618 14635 3018 Size 20" 94# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 Exploratory Service NK-23 10. Field/Pool(s): Niakuk Field/ Niakuk Oil Pool feet Plugs (measured) 16772 XXN feet Junk (measured) None feet feet MD TVD Burst Collapse 42 - 122 42 - 122 1530 520 41 - 5659 41 - 4025.29 4930 2670 38 - 14673 38 - 8527.79 6870 4760 14517 - 17535 8450.05 - 10062.65 8160 7020 1 t..J '1 ~" ""< ú Perforation depth: Measured depth: 16604 - 16646 True Vertical depth: 9535.43 - 9559.96 16656 - 16706 9565.67 - 9593.82 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 5-1/2" 17# 4-1/2" 12.6# L-80 L-80 30 -14511 16762 - 16777 5-1/2" TIW Packer 4-1/2" Baker F-1 Packer 14434 16762 Treatment descriptions including volumes used and final pressure: RBDMS BFL MAY 2 " 2006 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 0 30 o 0 ~O 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas 0 WAG Tubing pressure 830 800 Service R1- WINJ R1 WDSPl D 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: 306-025 Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signatur~ Form 10-404 Revised 04/2004 ~ Title Data Mgmt Engr Phone 564-4424 Date 5/23/2006 Submit Qriginal Only ~.Þ !-z-C.c&. e e .. NK-23 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDA TE SQlMIfIIÆRY 3/2/2006 T/I/O= 850/650/320. OA INJECTIVITY TEST. 4.5 BPM at 1450 psi. Pumped 190 bbls of 90* dead crude. Final WHP= 850/875/725. 3/10/2006 T/I/O= 840/690/320. Temp= SI. Bleed WHP's <200 psi (Pre OA Down squeeze). Tbg, IA and OA FL's @ surface. Bled TP from 840 psi to 20 psi in 70 minutes (7.22 bbls) lAP decreased 100 psi during the bleed. OAP unchanged. Bled lAP from 590 psi to 10 psi in 60 minutes (1.53 bbls). TP increased to 500 psi during bleed and OAP decreased 80 psi to 240 psi. Bled OAP from 240 psi to 0 in 40 minutes (.83 bbls). Tbg increased to 840 psi and lAP increased to 20 psi. T/I/O= 840/20/0. Monitored for 30 minutes. Final WHP's= 840/20/0. 3/11/2006 T/I/O=830/320/30 Temp=S/1 Monitor TBG decreased 10 psi, lAP increased 300 psi and OAP increased 30 psi from 3-10-06. 3/17/2006 OA Down Squeeze. Pump 12 bbls of 60/40 methanol, 10 bbls DS CW101 Chemical wash, 600 bbls of water, mixed and pumped 34 bbls of 15.7# Arctic Set 1 cement. Displaced with 5 bbls of water and 281 bbls of dead crude. RDMO, DSO notified to watch IA & OA pressures after the job was completed. 3/20/2006 T/I/O= 800/600/400 Temp=S/1 (Post OA Downsqueeze) MIT OA FAILED to 2500 psi. Pumped a total of 35 bbls down OA. Established LLR = 2 bpm @ 2500 psi for 20 bbls. Final WHP's= 830/700/0 FLUIDS PUMPED BBLS 281 Crude 12 Meth 34 Cement 10 Chemical wash 337 TOTAL {."~G:. j ~-r .fMñ ~.~ rr=.. " :\ \' ~ N " ¡Ii 1 ~ \.. \\ î t. ,! ¡d, " ï il I;:~ - '\! ¡ \ '-'. \ ~ , ""l ¡¡, ~ I' I '-'""'I \'1 ¡ \.~/ U L' U id L:::: ( fÍl) r ~) ! n ¡ ! ~~! ~ ! ~ I ~ " ¡¿) U (' /F\ n.' í1\\ (\~) ~/7 ./F..\\ / J \ ! I r L' \ ~\ ¡ t\ \ [d I íl \ ¡ L, I r-, 1 ~U J II' \ ¡.,....., \ !\-. ,~\ l.-, ,__I L\ "___.' r.,_ \_\ L! '-1 I t / FRANK H. MURKOWSKI, GOVERNOR / / I ALASKA. OIL AND GAS / CONSERVATION COMMISSION / Jennifer Julian Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 333 W. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 \q!{.~O§ Re: Niakuk Field, NK-23 Sundry Number: 306-025 ,~t:ANtl\ðE[) ~~ß:;\N ~1, ~) iODb Dear Ms. Julian: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, j,""j ¡: -~ ",/ /....., ~ , ~)f~ Daniel T. Seamount Jr. Commissioner ¡-J DATED thisa day of January, 2006 Encl. .' STATE OF ALASKA l Ali A Oil AND GAS CONSERVATION COMMI~ ..IN APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commission 20 AAC 25.280 Operational shutdown U Perforate U Waiver U AnchoraDEother U Plug Perforations D Stimulate D Time Extension D Perforate New Pool D Re-enter Suspended Well D 4. Current Well Class: 5. Permit to Drill Number: Development 0 Exploratory 0 194-0350 / Stratigraphic 0 Abandon U Alter casing D Change approved program D 1. Type of Request: Suspend U Repair well 0 Pull Tubing D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 8. Property Designation: ADL-034634 11. Total Depth MD (ft): 17535 Casing Conductor Surface Production Liner Liner sleeve Perforation Depth MD (ft): 16604 - 16706 / Packers and SSSV Type: / Service ~ 9. Well Name and Number: 58.6 KB 10. Field/Pools(s): Niakuk Field 1 Niakuk Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 10062.65 Effective Depth MD (ft): Effective Depth TVD (ft): 17435 10004.07 Length Size MD /" TVD 80 20" 94# H-40 42 122 42 5618 13-3/8" 72# L-80 41 5659 41 14635 9-5/8" 47# L-80 38 14673 38 3018 7" 29# L-80 14517 17535 8450.05 7 7" Liner tieback sleeve 14504 14511 8443.61 Perforation Depth TVD (ft): 9535.43 - 9593.82 Tubing Size: 5-1/2" 17# 4-1/2" 12.6# Tubing Grade: L-80 L-80 Tubing MD (ft): 35-14511 16762 -16777 .;"" 5-1/2" TIW Packer 4-1/2" Baker F-1 Packer Baker "H" Liner top pkr Packers and SSSV MD (ft): VJ6M{~fêA~'-U JAN 2 0 2006 6. API Number: 50-029-22455-00-00 / NK-23 /' Plugs (measured): 16772 XXN Burst Junk (measured): None Collapse 520 2670 4760 7020 122 4025 8528 10063 8447 1530 4930 6870 8160 14434 16762 14511 /' 12. Attachments: DescriDtive Sum m ary of Proposal ~ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for 13. Well Class after proposed work: Exploratory 0 Development 0 Service 1;2] Commencing Operations: 16. Verbal Approval: Commission Representative: 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 /' WAG 0 GINJ 0 WINJ ~ WDSPL 0 Prepared by Sharmaine Vestal 564-4424 2/3/2006 Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. p~inted Na(~ ..Lennife~i~ Title Wells Engineer Signature .\.. QtNN.....J'.-- '-- J~ Phone 564-5663 (} 'I ( , COMMISSION USE ONLY Contact Date Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test D ~ Location Clearance Mechanical Integrity Test Other: M.L T I/'u..i~.. Jennifer Julian 1/20/2006 Sundry Number: æ&2 - O;;..S D Subsequent Form Required: to - +0 4-. RBDMS 8Ft .U\N 2 4: 2006 Approved by: COMMISSIONER APPROVED BY THE COMMISSION Date: J ~/oÞ Form 10-403 Revised 7/2005 OR\G\NAL Submit in Duplicate bp ._",,+-ø,ø. ~~ ... .. ..,. g"", JI,.~, To: f ( J. Bixby/ D. Cismoski Well Operations Team Leader Date: January 18, 2006 From: Janet Sack, Wells Engineer Subject: NK-23 OA Cement DownsQueeze REVISION #1 NENIAWL23-N Est. Cost: $22M lOR: 500 BOPD Please downsqueeze the OA as described in the following procedure. This procedure includes the following steps: Step Type Procedure 1 F OA cement downsqueeze 2 F MIT OA cement downsqueeze to 2500 psi after WOC ...... 3 S Pull TTP. /' NK-23 is a PWI with slow TxlA communication. Steps have been taken to obtain a waiver for the TxlA communication. The well is SI with at TTP at 14488'. On 10/27/05, --' the well passed a M ITIA to 2500 psi. However, it failed a M ITOA on 10/26/05 with a LLR of 2 BPM at 1400 psi. In order to obtain a waiver for the TxlA communication, an OA downsqueeze is needed to prove up surface casing integrity. This program is designed to pump a column of cement from the shoe to approximately 500' above the shoe. Although the FL has only been depressed to -2300', the job will be pumped as if the leak is at the shoe in order to prevent the possibility of a cement donut. If this initial job fails, a re-squeeze will be evaluated. The procedure includes the following major steps: 1. 0 2: DHD 3. DHD 4. 0 5. 0 6. WAV 7. WAV 8. SL Depress OA FL to shoe DONE 12/21/05: Depress OA FL to 2310' // Shoot fluid levels and record WHP's. Bleed the T, lA, and OA to +/- 200 psi and fluid pack with crude as req u ired. OA Downsqueeze . M IT OA after waiting on cement. / Obtain AA Obtain waiver post AA approval Pull TTP pending AA & waiver approval If you have any questions or comments regarding this procedure, please call Jennifer Julian at (W) 564-5663, (H) 274-0929, (Cell) 240-8037. cc: w/a: Well File J. Sack L. Kincaid ,Ii" , I~, JOB PLANNING DETAILS: > 10/26/05: TTP set @ 14488', CMIT-TxIA Failed on stabilization in the Tbg, possible TTP leak. MITOA Failed, 2 bpm @ 1400 psi (1 min test only) ,/ > 10/27105: M ITIA Passed to 2500 psi > 11/10105: MITIA Passed to 2500 psi; AOGCC witness John Crisp > 12/11/05: PPPOT - T passed to 5000 psi; PPPOT -IC Passed to 3000 psi > 12/21/05: Depressed OA FL to 2310' Well has slow TxlA communication. OA= 13-318" 72# L-80 IA= 9-518" 47# L -80 Shoe at 5659' OAxlA Annular Capacity=.0581 bbls/ft Volume to shoe = 329 bbls 500' of cement = 29 bbls Displacement= 329 -5 (H20 spacer) - 29 (cement) - 5 (H20 flush) = 290 bbls /'" Approximate Fluid Requirements (Downsqueeze Only): Fresh Water: 700 bbls of =80 degree F (includes water for cement mixing and clean up.) 60/40 Methanol: 20 bbls Crude Displacement: 290 bbls at 30-60 degree F Crude: (volume needed to load OA, OA FL has not been depressed yet) DS CW1 01: 1Q bbls Arctic Set 1 Cement (15.7 ppg): 29 bbls pumpable (design the pumping time for 3+ hrs.) Note: Adjustments may be made as necessary by supervisor on-site. PREP WORK (pre downsQueeze): DHD/FB: 1. Shoot FLs and record WH Ps. 2. The day prior to the downsqueeze, bleed the OAP to +1- 200 psi. 3. Fluid Pack the OA with crude. CEMENTING OPERATIONS: /" FB Pumping 4. Hold a pre-job safety meeting on location prior to pumping the job to discuss options to safe out the wellhouse. 5. Rig up cementers to the OA via a flanged 1502 integral union and in-line T valve. ,1 ~ ( 6. If well has IA x OA communication (well has not shown this communication to date ), the IA pressure must be maintained at a pressure greater than the OA treating pressure to ensure no cement enters the IA. Tie into the IA with a LRS or pump. 7. Flood lines with warm fresh water and pressure test lines to 3000 psi. 8. Ensure the OA is fluid packed, and pump the following into the OA at maximum rate up to the maximum pressure of 2000 psi. rNote injectivity at pertinent times during the displacement. Start pumping into the OA as follows: a. 10 bbls of 60/40 Methanol to establish injectivity b. 10 bbls of OS CW101 surfactant (optional) c. -500 barrels of 800 freshwater to flush OA (approx. 1.5 x annular volume) d. 5 bbls of fresh water spacer e. 29 barrels of 15.7 ppg Arctic Set 1 cement f. 5 bbls of fresh water flush g. 290 bbls of 30-60 degree F crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 280 bbls of displacement has been pumped. Then, cut the rate to 1 BPM for another 5 bbls, then drop the rate to 0.5 BPM for the last 5 bbls. The leading edge of the cement should be 5 bbls short of the shoe when the pumps stop. 9. Shut down pumps and leave the well 51. Please DO NOT try to achieve a r- sQueeze or to build SQueeze pressure. The intent of this job is to place cement near the OA shoe, not to achieve a squeeze past the shoe. Record final pressures. Rig down and release cementers and pump trucks. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the OA. 10. Notify the Pad Operator prior to leaving location that the OA may be subject to rapid thermal pressure increases when the well is BOL. Frequent OA monitoring will be necessary for several days following the OA downsqueeze. POST SQUEEZE FULLBORE: 11. MIT-OA to 2500 psi. / Previous MITOA history: 10/26/05: MITOA Failed, 2 bpm @ 1400 psi (1 min test only) ~ 1REE= WELLHEA D = ACTUA. TOR = KB. 8..EV = BF. 8..EV = KOP= M3x Angle = Q:ltum W = Q:ltum lVD = 7-1/16" 5MCtN 1 3-5/8" FWC BAKffi 60.1' 22.4' 1165' 63 @ 15026' 15360' 8800' SS 13-318" CSG, 72#, L-80, ID = 12.347" 1-1 5659' ~ Minimum ID = 3.725" @ 16772' 4-1/2" OTIS XN NIPPLE 1 TOP OF 7" LI\R l-i 14504' 5-1/2" TBG, 17#, L-80, 0.0232 bpf, ID = 4.892" 1-1 14511' 1 TOP OF 7" LI\R 1-1 14517' B-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 14673' PffiFORA TION SUMVlARY REF LOG: AWS GR/T8v1PON 06/15/94 ANGLEA TTOP ÆRF: 53 @ 16598' Note: Refer to A'oduction DB for historical perf da1a SIZE SPF INTER\! AL Opn/Sqz DA.. TE 3-3/8" 6 16598-16604 S 03/22/94 4" 6 16604-16646 0 06/18/94 3-3/8" 6 16656-16686 0 06/04/95 3-3/8" 6 16686-16706 0 06/04/95 3-3/8" 6 16775-16781 S OS/22/94 I TOPOF 4-1/2" TBG 1-1 16762' 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 16777' 1 1 A3TD 1-1 17435' T' LI\R, 29#, L-80, 0.0371 bpf, ID = 6.184" 1-1 17535' 2188' H5-1/2"1RSV, SERES 10 NIP, ID =4.562" 0 GA S LIFT rv\A. Nffi8..S ST W lVD DBI TYPE VLV LATa-I FORT DATE ~ 4 3586 2985 60 OTE> LB RA 3 8789 5597 60 OTE> LB RA L 2 13231 7788 60 OTE> LB RA 1 14338 8362 61 OTE> LB RA I 14378' 1~5-1/2" NIP, PARKffi SWS, ID = 4.562" k 14434' 1- 9-5/8" X 5-1/2" PffiM PKR W/A<RLATCH, ID= 4.455" J 14469' 1-15-1/2" PARKffi SWS NIP, ID = 4.562" 14488' 1-15-1/2" OTIS XN NP, ID = 4.455" 1 / .J 14504' I-iTOPOF 9-5/8" X T' llEBACK W/ 6' SEAL ASSY 14511' 1-15-1/2" TUBING TAIL WLEG 1 14518' I-1ELW TUBING TAIL LOGGED 06/22/94 NK-23 ~ ~l r-l µ { SAFErY NOTES: 9-5/8" CSG SET ON ErvERG ENCY SLIPS I 16689' H rv\A. RKER JOINTS TWO 19' 1 16762' 1-1 7" X 4-1/2" F-1 ÆRM PKR, ID = 4.00" 16768' 1-1 4-1/2" OllS X NIP, ID= 3.813" 1 16772' 1-1 4-1/2" OllS XN NIP, ID = 3.725" 1 16772' 1--1 4-1/2" OllS XXN PLUG RUN ON COMA..EllON 16777' 1-1 4-1/2" TUBING TAIL WLEG 1 1-1 ELMD TT NOT LOGGED 1 DA..TE RBI BY COMrvENTS DATE REV BY COMrvENTS OS/28/94 ORlG COrvPLETION, (POOL 7) 01/22/01 SIS-1s1 CONVERTED TO CANV AS 02/27/01 SIS-LG FINAL 11/22/01 RN/TP CORRECllONS 1~r I ~ NIAKUK UNIT WELL: NK-23 PffiMT No: 194-0350 A PI No: 50-02B-22455-00 SEe 36, T12N, R15E, 3630.51 FEL4062.86 FNL BP Exploration (Alas ka) MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 16, 2005 - TO'_:'S,::;;..,}?a'ft_"~"Jc' - --~JEC!':~¡:':cii'.;':::~)INC----D?f - -- FROM: John Crisp PRUDHOE BAY UNNIANK-23 \(11. It.... Petroleum Inspector \- \ V'\ Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv :JB¡:"" Comm Well Name: PRUDHOE BAY UN NIA NK-23 API Well Number 50-029-22455-00-00 Inspector Name: John Crisp Insp Num: mitJCr05111 1083759 Permit Number: 194-035-0 Inspection Date: 11/10/2005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I NK-23 ¡Type Inj. / w I TVD I 8409 I IA 600 I 2500 ! 2450 2420 I i P.T. 11940350 /TypeTest i SPT I Test psi i 21 02.25 lOA 0 I 300 / 300 300 I Interval REQVAR P/F P Tubing 780 I 780 i 780 i 780 / i Notes 5 bbl's pumped for PT. ~Ç!ìNNfl c ~~ 1 Wednesday, November 16,2005 Page 1 of I STATUS: NK-23 (PTD 1940350) ) ) Subject: STATUS: NK-23 (PTD 1940350) From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Mon, 09 May 2005 11 :56:44 -0800 Tq: "AOGCC Winton Aubert (E-mail)1t <winton_aubert@admin.state.ak.~us>,. ji~_regg@admin.state.ak.us,bob~fleckenstein@admin.state.ak.us . . .. ... ..... . C(C: "NSU, ADW Well Operations Supervisorlt <NSUADWWe110perati()n$Supervisor@BP.com>,·. nR~eves, DOi1a1d F"<Re~vesDf@BP.COµl>~ ·1t:Eugel, :HaITY R,"<ßngelIfR@BP .com>, ~'~p~_sberg~R: . Steven" <RossbeRS@BP.com>, "Parker;R.Andrew" <ParkerRA@BP.com>, "OPB, GPMA Area· Mgr" <GPBGPMATL@BP~corn>, ItGPB,LPC DS Ops Lead" <GPBLPCDS()psL~ad@BP.co11l>, "NSU, ADWWell Integrity Engineer"<NSUADWWelllntegrityEnginèer@BP .coin>,·:nGPB,W ells·· 0Rt Eng" <GPBWellsOptEng@BP . com>, ItDube, AnnaT" <Anna.Dube@BP.com>: . . Hello Jim, Bob & Winton. An MITIA was conducted on NK-23 on 5/7/05. It initially lost 40/40 psi at 15/30 minutes. On the fourth and final attempt, it lost 20/20 psi at 15/30 minutes. Current plans are to continue water only injection, keep the well on the monthly UIC report, and develop a protocol with the AOGCC Staff Engineers regarding management of injectors with slow tubing leaks. Attached is the MIT form. Please call if you have any questions Joe 659-5102 «MIT NK NK-23 05-07-05.xls» SCANNE.D .IUI 0 '7 2005 From: NSU, ADW Well Integrity Engineer Sent: Saturday, May 07, 2005 1:12 PM To: AOGCC Winton Aubert (E-mail);jim_regg@admin.state.ak.us Cc: NSU, ADW Well Operations Supervisor; Reeves, Donald F; Engel, Harry R; Rossberg, R Steven; Parker, R. Andrew; GPB, GPMA Area Mgr; GPB, LPC DS Ops Lead; NSU, ADW Well Integrity Engineer Subject: NK-23 (PTD 1940350) Hello Jim & Winton. Water injection well NK-23 (PTO 1940350) is exhibiting signs of TxlA communication. The IA is observed to repressure 200-400 psi/day to the tubing pressure. T/I/O pressures on 5/6/05 are 1100/940/20. Recent events: > 07/12/04: MITIA Passed to 2500 psi > 05/02/05: Bled lAP 840 > 270 psi, the IA repressured 200-400 psi/day to the tubing pressure Current plan is to conduct an MITIA. The well has been added to the monthly injection well report. Attached is a wellbore schematic. Please call if you have any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 10f2 5/10/2005 10:40 AM STATUS: NK-23 (PTD 1940350) 20f2 ) ) Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com Content-Description: MIT NK NK-23 05-07-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 5/1 0/2005 10:40 AM NK-23 (PTD 1940350) ) ) Subject: NK-23 (PTD 1940350) From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP .com> Dat~: Sat, 07 May 2005 13: 11 :34 -0800 .. Tc),:' II AOGCC Winton Aubert (E;.mail)" <wiriton~aubert@admin.state.ak.l.!s>, ji111_regg@admin.state.ak.us . . . . ..... c. . .. . ... : Cç: "NSU, .ADW .Well Operations SÙþervisor"<NSUi\DWWellOperationsSupervisor@BP.com>, . "~¢~ves,Dona1d F'.' <ReevesDf(@BP .c0nl>; '~En~el,HarryR" ~ngelHR@ap.com>; '1Ros~b.erg;·~:: St~ven'r <Ròssbe:RS@BP .COfi1>, rlPårker,R~ 'Andrew" <:ParkerRA@BP :c·om>, ;'GPB~GPMA ·Area"· . M$f" <GPBGPMA TL@BP .com>, . "GPB; LPC DS. OpsLead" <GPBLPCDSOpsLead@BP..com>,··· "N:SU,· ADWW ell Integrity Engineer"· <NSUADWW ellIntegrityEngineer@BP .c()m~· Hello Jim & Winton. Water injection well NK-23 (PTD 1940350) is exhibiting signs of TxlA communication. The IA is observed to repressure 200-400 psi/day to the tubing pressure. TII/O pressures on 5/6/05 are 1100/940/20. Recent events: > 07/12/04: MITIA Passed to 2500 psi > 05/02/05: Sled lAP 840 > 270 psi, the IA repressured 200-400 psi/day to the tubing pressure Current plan is to conduct an MITIA. The well has been added to the monthly injection well report. Attached is a wellbore schematic. Please call if you have any questions. «NK-23. pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com SCANNED ,!iJl O? 2005 Content-Description: NK-23.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 5/10/2005 10:08 AM ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_FJeckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay INK / NK-23 05/07/05 Joe Anders Well NK-23 Type Inj. P.T.D. 1940350 Type test Notes: Eval high IA pressure s P Packer Depth TVD 8,409' Tubing Test psi 2,500 Casing Pretest 1,100 1,100 Initial 1,100 2,500 15 Min. 30 Min. 1,100 1,100 Interval 2,480 2,460 P/F I F Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. SCANNEr" ¡ / I! .. 1·..- \.,'~ t) J n II' 2005 MIT Report Form Revised: 06/19/02 2005-0507 _MIT _PBU_NK-23.xls ) TREE = 7-1/16" 5MCW WELLHr=AD= 13-5/8" Fr£ 'A"cfL:iii; to R; ... ... ... .. . ·····ï3A"kef KB. 8.EV = 60.1' BF. REV = 22.4' KO P = 1165' I'v1ax Angle = ·63 @ 15026" Datum W = 15360' oatum·iVO; ...... .. . ··ääöÖö'ss NK-23 e 13-318" CSG, 72#, L-80, 10 = 12.347" 1-1 5659' ~ Minimum ID = 3.725" @ 16772' 4-1/2" OTIS XN NIPPLE L ) SAFEfY NOTES: 9-5/8" CSG SETON EI\iERGENCY SLIPS 2188' H5-1/2" TRSV, SERES 10 NIP, 10 =4.562" GA S LIFT \VLð. NDR8.S ST MO lVO OBI TYPE VLV LATŒi FORT DATE ~ 4 3586 2985 60 OTIS LB RA 3 8789 5597 60 OTIS LB RA 2 13231 7788 60 OTIS LB RA 1 14338 8362 61 OTIS LB RA I 14378' 1-15-1/2" NIP, PARKER SWS, 10= 4.562" 1 ~ k 1 TOP OF 7" LNR 1-1 5-1/2" TBG, 17#, L-80, 0.0232 bpf, 10 = 4.892" 1-1 1 TOP OF 7" LNR 1--1 14504' - -I 14511' 1 ~-- 14517' ---~ 14673' -A J .~ 9-518" CSG, 47#, L-80, 10= 8.681" 1-1 PERFORATION SUM\I1ARY REF LOG: A WS GRlTBVlP ON 06/15/94 ANGLEA TTOP FERF: 53 @ 16598' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTER\! AL OpnlSqz [)ð. TE 3-3/8" 6 16598-16604 S 03/22/94 4" 6 16604-16646 0 06/18/94 3-3/8" 6 16656-16686 0 06/04/95 3-3/8" 6 16686-16706 0 06/04/95 3-3/8" 6 16775-16781 S OS/22/94 I TOP OF 4-1/2" TBG 1-1 16762' 1~{ I 4-1/2" TBG,12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 16777' 1 1 RHO 1-1 I ~ 17435' T' LNR, 29#, L-80, 0.0371 bpf, 10 = 6.184" 1-1 17535' D6.TE REV BY COMM:NTS DATE REV BY COMM:NTS 05128/94 ORlG COIVPLETION, (POOL 7) 01/22/01 SI8-51 CONVERTED TO CANV AS 02/27/01 SIS- LG FIN«\ L 11/22/01 RNITP CORREC110 NS 14434' 1- 9-5/8" X 5-1/2" PERM PKR W/A<R LATCH, 10 = 4.455" 14469' 1-{5-1/2" PARKER SWS NIP, 10= 4.562" 1 14488' 1-15-1/2" OTIS XN NP, 10 = 4.455" 1 14504' I-IToP OF 9-5/8" X 7" 11EBACK W/6' SEAL ASSY 14511' 1-45-1/2" TUBING TAIL WLEG 1 14518' I-IELMO TUBING TAIL LOGGED 06/22/94 I 16689' H \VLð.RKERJOINTS TWO 19' 1 16762' 1-1 7"X 4-1/2" F-1 FERMPKR,IO =4.00" 16768' 1-4 4-1/2" 011S X NIP, 10= 3.813" 1 16772' 1-4 4-1/2" 011S XN NIP, 10 = 3.725" 1 16772' 1-1 4-112" 011S XXN PLOO RUN ON COMR.ETlON 16777' 1-1 4-1/2" TUBING TAIL WLEG 1 1-1 ELMO TT NOT LOGGED 1 NIAKUK UNIT WELL: NK-23 PERMT I't>: 194-0350 A R I't>: 50-029-22455-00 SEe 36, T12N, R15E, 3630.51 FEL 4062.86 FNL BP Exploration (Alas ka) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test .......-:"' ...J "'{.I.. \(A \---~·Yi ~ . Email to.Wlnton_Aubert@admin.stateakus.Bob_Fleckenstein@admin.state.ak.us:Jim_Regg@admmstate.ak.us OPERA TOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc Prudhoe Bay / Niakuk I NK 07/12/04 Anna Dube Packer Depth Well NK-10 Type Inj. S TVD 9,016' P.T.D.193184O Type test P Test psi 2,254 Notes: UIC 4-year required MITIA - witness declined Well NK-16 Type In]. S TVD P.T. D. 1940220 Type test P Test psi Notes: UIC 4-year required MITIA - witness declined Well NK-23 Type Inj. S TVD P . T. D. 1940350 Type test P Test psi Notes: UIC 4-year required MITIA - witness declined Well NK-38 Type Inj. N TVD P.T.D. 1941700 Type test P Test psi Notes: UIC 4-year required MITIA - witness declined Well P.T.D. Notes: Type Inj. Type test TVD Test psi Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting Tubing Casing Pretest 1,780 660 Initial 1,780 2,800 Interval P¡F 4 P 15 Min. 30 Min. 1,780 1,780 2,720 2,690 9,142' Tubing 1,780 1,800 1,800 1,800 Interval 4 2,286 Casing 50 3,000 2,950 2,940 P/F P 8,409' Tubing 1,370 1,370 1,370 1,370 Interval 4 2,102 Casing 400 2,520 2,470 2,460 P/F P 9,365' Tubing 940 Interval 4 2,341 Casmg 580 P/F F Leak rate =1.2 BPM @ 2500 psi. Tubing Interval Casing P/F TYPE TEST Codes M '" Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 MIT NK NK-10, NK-16, NK-23, NK-38 07-12-04.xls ON OR BEFORE ANuARY 03 2001 W MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:ChairmanDan Seamount p/~ THRU: Blair Wondzell ~:~'~ P.I. Supervisor Petroleum Inspector DATE: September 25, 2000 SUBJECT: Mechanical Integrity Tests BPX Niakuk NK-10, 16, 23, 38 Prudhoe Bay Unit Niakuk Field NON- CONFIDENTIAL Packer Depth Pret'est Initial 15 Min. 30 Min. we, I 00o i i P.T.D.~ 1931840 ~Typetest~ P T~st.psi 2254 Casing 2460 2420 2420 Notes: Obse~ed )rete~ conditions for thi~y minutes "OK". We,l~ NK-16 TYpeinj.I S ~T.V.D.I 9~42 I TUbingl =~00 I =~0 I =~"0 I ~0 Jlnte~al~ 4 P.T.D.I 1940220 TypetestI P Test psi 2286 CaSing 1100 2490 2460. 2440 P/F I Notes: Obse~ed )rete~ conditions for thi~y minutes "OK". ¢'*'~'! ~,403S0 i*vP~t~st[ ~¢ . l lestpsiI 2~02 Ca~in~ ~0S0 24S0 2420 24~0 ~ote~: ~.I.D.[ ~¢4~700 Ily~etest[ ~ lestpsi! 234~ Ca~in~ 20 -2480 2440 2450 ~/F ~ot~: Obse~ed xotest conditions for thi~7 minutes "OK". , Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N '- NOT INJECTING Type Test M= Annulus MonitOring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I met Joe Anders and the HBR crew on the Niakuk pad. The testing went well with all wells exhibiting competent tubing and casing, Wells # 10, 16 and 38 tubing injection pressures were high enough to exhibit the required minimum of 500 psi differential between tubing and casing. These wells were held and observed at their pretest conmditions for thirty minutes with no change in annulus pressures observed. The Wellhouses and pad were in good condition. Subsidence does not seem to be a issue on this pad. M.I.T.'s perfOrmed: 4_ Number of Failures: 0 Total Time during tests: _4 Attachments: Well schematics (4) cc: Joe Anders/Kevin Yea~er CBPX) MIT report form 5/12/00 L.G. MIT NIAKUK 9-25 LG7.xls 9/26/00 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 27th, 1996 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached are blueline and folded sepias for well Niakuk 23. Per 20.AAC 25.537(d) BP Exploration would like these logs held confidential for 24 months. The specific attached log includes: Log Type Company PLS (Static Pressure Atlas Survey) Run Date Depths 6/10/96 15880'-16530' Please contact me at 564-4531 if you have any questions. Sincerely, Katie Nitzberg, Si'. G~o~logist Greater Point Mclntyr"C'A~ea MS Enclosures Please sign below and return to Marian Sloan, BPX, Mail Stop MBT-2 for - - - JUL 0 1 1~'.'.. Alsska 0il & Gas Con~ Anchor.ge R CE VE JUL 0 1 199~ Alaska 0ii & (~s 6'or~s. Commission Anchorage PERMIT ~4 .... 9a---.- 035 94,~0:35 9a-~035 94--'035 ~4.-'-035 94,--0~ 5 9~.-.-035 94-,-035 ~4-.. O~ S ~4,,-0~ 5 94-.-0~ 5 ~4~035 ~6.-.,0~ 5 ~4 ..... 035 94~0~ 5 ~--. 0~5 AC.'GCC IIndi'vi~dua i We I I aoiog'¥cai Nater'i'aJs Inverl ! ,,"y E, ATA T DATA .... F'LUS '~'C~a R / C L ~C D N ~E ~ P/s R /c L ~DR-- LWD/DC ~DH ----LWD//DC ~185 ~198 ~,L S,/PROD P/TEHP ~DL.S/STAT kip TEH ~E, N ~LS STATIC ~ R /c c L. ~LS/ZNJ ¢' L S/ZNJ L i6450'- i6'759 L 16400-16900 L 16540~'1'7380 L 16550-.-15'752 L 16114--'1674'1 ~TVIS,~ BLI< ONL. Y L 16741-'- 'i 7195 ,.TVD ~BLK ONLY L 1/,250--16758 L. 16114--..'i7195 L 16114-17195 L 16114---17 i95 T i6073"'17526~ T i4250~'i6758~ L i6400~16700 0 I--I -- C D R / ,C D N ,Ct'--I .... G R/TEH F' L 100-~167i0 L i6114-17535 L 15889 .... 16739 L 14700'-16759 L 16520---16730 L. 16500-'16745 L 16500-.16745 l.;;,a't:c¢: 04/'10/96 R U i'..I C, A "[' E ....... R E C V D '1 06 / "" ''~ 9 ..... / 4 / 06/22/.9/¢ 'i 07 / 08/94- '1 0'?/' 2 O/94 C:N PS 07 / 20/9 '1 07 / 20/ CNF'S 07/20/9 CNI:'S 07 / 2 O/9 CNPS 07/20/9 'i 3 07/20/~:., ¢~ 07/25/94. · 1 i 2 / 08 / 94 '1 '12/08/94 't 03 / 2 'i/' 95 1 02/'2.,/:~ 9 . .., 'i 06/' i 5 / 9 1 06/29/95 1 06 / 29/95 APe cir'y d~'tch samples r'equi'r'ed? yes Was tine we ii cored? Ar'e we l'i Well ~'s y e s ~__~A n a 'i y s 'i s~ t 'i' o n r'e c e '¥ v e d '? y eJ S I] C) tests r'equ ~' ~~eceff~ FI 0 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 28, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached are blueline and folded sepias for well Niakuk 23. Per 20.AAC 25.537(d) BP Exploration would like these logs held confidential for 24 months. The specific attached logs include: _Log Type PLS (Injection profile- 4000 BPD) PLS (Injection profile- 14900 BPD) Company Run Date Depths Atlas 6/24/95 1 6500'-1 6745' Atlas 6/24/95 16500'- 16745' Please contact me at 564-4531 if you have any questions. Sincerely, Katie Nitzberg, S~'. Ge°~gist Lisburne and New Developments MS Enclosures RECEIVED STATE OF ALASKA I AI_Ac,,,A OIL AND GAS CONSERVATION COMMISSIO,',,' REPORT OF SUNDRY WELL OPERATIONS 1. OPerations performed: Operation shutdown __ Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other x 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1410' NSL, 679' WEL, SEC. 36, T12N, R15E At top of productive interval 973' NSL, 928' EWL, SEC. 28, T12N, R16E At effective depth 1208' NSL, 1562' EWL, SEC. 28, T12N, R16E At total depth 1091' NSL, 1695' EWL, SEC. 28, T12N, R16E 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 58.6 feet 7. Unit or Property name Niakuk 8. Well number NK-23 9. Permit number/approval number 94-35 10. APl number 5 O- 029-22455 11. Field/Pool Niakuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 17535 feet Plugs (measured) 10063 feet 17435 feet Junk (measured) 10043 feet Size Cemented Measured depth True vertical depth 80' 5659' 14673' 3032' measured 20" 260 sx AS (Approx.) 80' 13-3/8" 1640 sx "E"/375 sx "G" & 5659' 250 sx "C" 9-5/8" 530 sx Class "G" 14673' 7" 315 sx Class "G" 14503; 17535' 80' 4038' 8528' 8444'- 10063' 16598'-16604~ 16606`-16646~ 16656`-16686~ 16686'-16706~ 16775L16781' true vertical 9553'-9557', 9558'-9581', 9587`-9604', 9604`-9616', 9654'-9658' Tubing (size, grade, and measured depth) 5-1/2", NT80S to 16770'MD PackersandSSSV(typeandmeasureddepth) 9-5/8"TIWpacker@ 14434'MD;Otis ModeI,OTRS~.@~~DvED. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Gas Cons. Commission Anchors :'- 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 4/3/95 4522 Subsequent to operation 6/6/95 3660 /~~595 165 1100 880 17 1150 Tubing Pressure 812 802 15. Attachments Copies of Logs and Surveys run Daily Re~_,.,~rt q~ Well Operations x 17.1 here .i~ ce~if~t_hat tl~, foregoin/~ is true and Signed '~ / ¢'~"L. j /~'''// Form 10-404 Re---v (~/15/88~ 16. Status of well classification as: Oil .___ Gas Suspended correct to the best of my knowledge. Title RE/PE Mana~ler Service Water Injector SUBMIT IN DUPLICATE PRUDHOE BAY, ALASKA TO: FRANKENBURG FROM: Hildreth Well Name: INK-23 Main Category: ICap Sust Sub Category: lAdd Perfs Operation Date: IJune 4, 1995 Date: IJune 4, 1995 I Time O8OO O9O5 0912 O922 0958 1005 1014 1017 1022 1029 1035 1036 1039 1044 1055 1126 1210 1214 1243 1247 1250 1257 1304 1306 1307 1318 1325 1402 1500 FLP = 800 psi Description MI and RU AWS 6442. Arm Guns. CCL to Top Shot = 2.00' and CCL to Bull plug = 23'. RU Lub and guns to BOP's. Set counters to 15' PT the Lubricator w/WHP at 800 psi, Notified LPC that I am shutting in the well to TIH. WHP = 900 psi TIH w/Gun #1 (20' 3 3/8" gun) at 400 to 500 FPM. Tool is keeping up OK. Open well while TIH at 14800' WHP = 950 psi Stopped at 16660' ( 3000 # PU weight with 5/16" Eline) and line up to conduct Tie-in. PUH from 16660' to 16518' for Tie-in. Made (+16' correction). TIH to 16730' Flagged line at 16700'. PUH logging from 16700' to 16519' TIH to 16700' (flag) Corrected Flag to 16699.5' (-0.5' correction) Logged up hole from 16710' to 16684' WHP = 850 psi & 70° F; Perforated 16686' to 16707'; 20' 6 SPF Alpha Jet Random 60° ~ PUH logging to 15575'. 2890# up weight POOH and close the well at 15000' at 1055 hours. POOH CCH and open the well. RU on Gun #2 (30' 3 3/8") RU 30' lubricator and gun to BOP's. Closed well in at the wing. PT Lub. WSI and TIH. at 500 to 600 FPM Open the well while TIH at 15,000' WHP = 950 psig. A small weight + differential at 15600' while TIH. Set counter at 16699' (Flag), PUH logging from 16650'. to 16553', Tie-in. (0' Correction) Tagged bottom at 16749' Corrected. 2900# E-Line up weight Stopped at 16654' WHP = 950 psi at 64 ° F. Perforated from 16656' to 16686'; 30' 6 SPF Alpha Jet, Random, 60° 6i PUH logging. WHP = 950 psi & 64 o F. Stopped at 16550' and POOH to the -rT. SWl at 950 psi. ~ E C E ! V E D POOH. CCH, guns fired, close the SV. Put well on production. Move off location Give well back to LPC. FLT = 80° F IA = 1150 psi CA = 0 psi Status: Flowing '-qaska 0~1 & (~as Cons. Commission Tie in Icg/date GR / CCL June 15, 1994 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Il6686 66 6 13.375 Shot Density Orientation II; Im Phasing WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME NK-7 ?3- ! L"~ 4/27/95 15000'-15420' NK-7'~( 5/5/95 3000'-15350' NK-8 4/20/95 15990'- 16200' 15882'- 16428' NK-9 3/27/95 17470'-18240' NE-9 ~ d"'/~ 3/27/95 17720'-18250' NE-9 7 12/19-21/94 18020'-18570' NE-9 12/21/94 18020'-18570' NK-18 ?.;3-/;77 3/18/95 2700'-11090' NK-21 c~/- ~" 3/30/95 11100'-11865' NE-23 ~- ~5"" 3/30/95 14700'-16759' NE-42 ~. q-[ b"~ 3/17/95 3683'-15642' GAMMA RAY/CCL (PERFORATING LOG) PLS (PRODUCTION PROFILE) GAMMA RAY/CCL (PERFORATING LOG) PLS (STATIC PRESSURE SURVEY) GAMMA RAY/CCL (JEWELRY LOG) PLS (STATIC PRESSURE SURVEY) SLIM GR - MWD/DEPTH CORRECTED MWD OPEN HOLE EDIT GR TAPE PLS (SPINNER TEMP/PRESSURE SURVEY) PLS (STATIC PRESSURE SURVEY) PLS (STATIC PRESSURE SURVEY) PLS (STATIC PRESS SURVEY) (TEMP GRAD) 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 SCHLUMBERGER 1 SCHLUMBERGER 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE 1 ATLAS WIRELINE RECEIVED MAY 2 2 1995 oil & Gas Co~s. Commission Anchorage WELL NAME DATE ~o'~-6c.y NK-07 6/19-22/94 NK-07 6/19-22/94 NK-IO 12/11-14/93 ~'~/~_/~N K- 10 12/14/93 NK-12 11/10-11/93 /~,2NK-12 11/11/93 NK-12A 1/29/94 REPROCESSED DATE,., INTERVALS ~ ,14840'-15707' 10/19/94 ~ 13992'-15707' '"----,~12230'- 13590' 10/13/94 '"'--,312248'-13550 12/15/93--'--.~ 10960'-11416' 1/19/95 ~ 10964'- 11416' ~ 13680'- 15040' 10/16/94 '",~ 13804'- 15040' ~3-/'~-', NK-18 11/26-27/94 NK-18 11/27/93 ~ 10400'- 11205' 10/16/94 ~ 10396'-11206' ¢.,~__/,,~/,, NK-201/4-9/94 NK-20 1/9/94 ~'L//-~E'~ NK-21 7~9/94 ~.~ . NK-22 10/16-25/93 ~--~,rb.~tK-22 9/16/93 ?/7z,,_3..~,..NN K-23 4/23-30/94 K-23 4/3O/94 "--...,J 13150'-14160' · 10/14/94 '~".,J 13151'-14165' 10/19/94'''''''-~ 10392'- 12000' ~ 11310'-13522' 10/14/94 ~ 11330'-13540' ~'--,j16000'-17550' 10/14/94'"'-,,j 16073'-17526' LOG NAME RUN NO CDN- LWD/Depth Corrected LDWG Tape (CDR CDN 1 Bit Run) 1 1 1 1 1 1 1 1 1 1 Composite Composite 1 Composite Composite Composite Composite CDN- LWD/Depth Corrected LDWG Tape (CDR/CDN; Reprocessed Density) CDN- LWD/Depth Corrected (Reprocessed Density) LDWG Tape (CDR/CDN; Reprocessed Density) CDN- LWD/Depth Corrected LDWG Tape (CDR/CDN; Reprocessed Density) CDN- LWD/Depth Corredted LDWG Tape (LWD Open Hole Edit; Reprocessed Density) CDN- LWD/Depth Corrected LDWG Tape (CDR/CDN; Reprocessed Density) LDWG Tape (CDR/CDN; Reprocessed Density) CDN- LWD/Depth Corrected LDWG Tape (CDR/CDN; Reprocessed CDN) CDN- LWD/Depth Corrected LDWG Tape (CDR/CDN; Reprocessed CDN) COMPANY NAME Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger. Schlumberger Schlumberger Schlumberger Schlumberger RECEIVED MAR 21 7995 Alaska 0il & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 21, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached are revised blueline, sepia and LDGS formatted tapes for nine early Niakuk wells. Logs and tapes were sent to you for each of these wells in the past year. Rigcently Anadrill has improved the density algorithm and re- created all of our LWD CDN data using the new algorithm. This processing decreases the density a couple of porosity units, making the readings more accurate. Please replace the first set of tapes and the first set of CDN logs we sent you so that these improved logs are used for your analyses. The NK-21 blueline and sepia you received in December were the m-processed version and, therefore, do not need to be replaced. Per 20.AAC 25.537(d) BP Exploration requests that these logs held confidential for 24 months. Please contact me at 564-4531 if you have any questions. Sincerely, Katie Nitzberg, Sr. Geologist Greater Pt. Mclntyre Area R£C£ VF..D. MAR 2 ~ 199,5 Alaska 0il & Gas Cons. Commission Anchorage Enclosures WELL NK-0__~.7 NK-08 NAME DATE 9/3/94 9/5/94 8/11/94 INTERVALS LOG NAME RUN NO COMPANY NAME 14805'-15604' 15750'-16428' 1 ATLAS WIRELINE 1 ATLAS WIRELINE 11/28/94 10/21/94 10/27/94 10/21/94 10/27/94 10/21/94 10/27/94 10/27/94 1 O/27/94 10/27/94 11/3/94 12/3/94 1 2/4/94 I 0/17-23/94 10/17-23/94 10/17-23/94 10/17-23/94 ~...NK-19 ~NK-19 i~IK-19 t~-I 9 11/17/94 ../,,(]¢,/_ NK-21 b~ ------ 3 NK-42 ~ 7/10/94 7/9/94 11/18/94 1 2/1/94 11/25/94 .,,. ,,~NK-42 ~ 9/26/94 fU~) NK-42 11/30/94 ~,.~_K-42 12/4/94 t,~K-42 11/29/94 LIS (LDWG) - CN/GR & MAC/GR Tape LIS (LDWG) - CN/GR & MAC/GR Tape 14831'-15910' LIS (LDWG) - Open Hole Edit Tape - CDR Only Composite 10576'- 11106' 9050'- 10287' 10010'-11211' 9050'- 10287' 10010'-11211' 10010'-10271' 10680'-11130' 10570'-11212' 10010'-11211' 10570'-11212 10636'-11212' 9760'- 10348' 9950'- 10267' 9214'-10595' 9150'- 10585' 8345'-9645' 829O'-9636' 9149'-10651.5' 10083'- 11892' 10392'-11930' 16400'-16700' 100'- 1671O' 15067'-15643' 15918'-16054' 15067'-15606' 3100'-15644' 15200'-15551' PLS (Static Pressure Survey) BHC Acoustilog/Gamma Ray SSVD Sub-Sea Vertical Depth Composite BHC Acoustilog/Gamma Ray BHC Acoustilog/Gamma Ray Formation Multi-Tester/Gamma Ray Formation Multi-Tester/Gamma Ray Borehole Profile Dual Laterolog Gamma Ray/SP Z-Densilog Compensate Neutron GR/Caliper LIS (LDWG) Tape C r)i'L.//C/g/L/ ~.,,~.j,'~.~~ Segmented Bond Log - Gamma Ray/CCL PFC Gamma Ray/Collar Log (Perf. Record) CDR - Depth Corrected CDN - Depth Corrected TVD CDR TVD CDN LIS (LDWG) - Open Hole Edit Tape LIS (LDWG) - AC/GR Tape CDN - LWD/Depth Corrected PLS - Production Profile (Temp. Survey) PLS (Static HP-Temperature Survey) Segmented Bond Log - Gamma Ray/CCL Collar Log (Severing Tool Record) LIS (LDWG) Tape PLS (Static HP-Temperature Survey) PFC Gamma Ray/Collar Log (Perf. Record) SCHLUMBERGER 1 ATLAS WIRELINE 1 ATLAS WIRELINE 2 ATLAS WIRELINE I ATLAS WlRELINE 2 ATLAS WlRELINE 1 ATLAS WlRELINE 2 ATLAS WlRELINE 2 ATLAS WlRELINE 2 ATLAS WlRELINE 2 ATLAS WlRELINE I & 2 ATLAS WlRELINE 1 ATLAS WlRELINE 1 ATLAS WlRELINE Composite SCHLUMBERGER Composite SCHLUMBERGER Composite SCHLUMBERGER Composite SCHLUMBERGER I SCHLUMBERGER 1 ATLAS WlRELINE I SCHLUMBERGER I ATLAS WlRELINE 1 ATLAS WlRELINE I ATLAS WlRELINE I ATLAS WlRELINE 1 ATLAS WlRELINE 1 ATLAS WlRELINE I ATLAS WIRELINE =. BP EXPLORATION ALASKA INC. CORE SAMPLE TRANSIVI]TTAL "State-of-the-A rt Archivin~," FROM: BP Exploration Alaska, Inc. c/o Document Storage Core Store 2410 W. 88th Ave. Anchorage, Alaska 99507 Attn: John Trautwein (907) 522-2684 AIRBILL#: CHARGE: WELL NAME' SAMPLE TYPE: NUMBER OF BOXES: REFERENCE: TZO. TRANSMITTAL NO.: fi ~"'7 DESCRIPTION OF MATERIALS TRANSPORTED: C c-'T-T- r'~'~ Please acknowledge receipt in whole of the material described above by signing this transmittal and returning a copy to the address shown above. Sent by: ~ Date: ' Received by~ Date. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 , (907) 561-5111 '.... July 19, 1994 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached are blueline, a folded sepia and a LIS tape of e-line logs for various Niakuk wells, indexed below. Per 20.AAC 25.5-37(d) BP Exploration would like these these logs held confidential for 24 months. The specific attached logs include' Well N~,m¢ Loa Tvoe ,,P~S (Static Pressure- Temperature Survey) ,,/PLS (Static Pressure- Temperature Survey ~~~LT LS (Flowmeter- ¢Sm(PL~r~3;e~a p e (;;Qmpany Run Date Depths Atlas Wireline 07/08/94 13000'-13597' Atlas Wireline Atlas Wireline Atlas Wireline 07/08/94 07/10/94 06/15/94 14400'-14922' 10530'-10970' 14250'-16758' Please contact me at 564-4531 if you have any questions. Sincerely, Katie Nitzberg%Sr. G&Zoiogist Lisburne and New Developments KEN Enclosures WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME 4/16/94 4/16/94 4/12/94 3/6/94 3/6/94 3/13/94 4/13/94 3/13/94 3/2/94 4/9/94 5/25/94 2/28/94 2/26/94 5/13/94 5/15/94 5/23/94 13100'-13293' 9760'- 10780' 12970'-13240' 12732'-13598 12732'-13598 14150'- 14933 10525'- 10870 10300'-11113' 10550'-10915 13390'-14025' 13700'-13980 13700'-14076 12900'-13382' 16540'-17380' 16400'- 16900' 16450'-16759' ~' Production Fluid Sample /' Production Profile .,,- Production Profile .'"PFC/CCL · "'Gamma Ray/CCL · '" Static HP-Temperature Survey "'Production Profile ,--Static HP-Temperature Survey .,.PFC/CCL ..,-'Static/Tem peratu re -"Production Profile ,d:'FC/CCL --~FC/GR/CCL · "" Segmented Bond Log .~-~Gamma Ray/Collar Log f PFC Gamma Ray/Collar Log ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELiNE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WIRELINE ATLAS WiRELINE ATLAS WIRELINE ATLAS WIRELINE NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME WELL 9~,,,...&N K-08 NK-09 NK-09 NK-09 ~'"/~ NK-09 ~.~. .~NK-10 -~0~NK-21 NK-21 NK-21 :~"~":N K-22 ?'O~.NK-23 NK-42 NK-42 NK-42 2/10/95 2/10/95 2/9/95 2/10/95 12/31/94 11/29 - 12/5/94 11/29-12/5/94 12/5/94 1/15/95 1 2/28/94 7/9/94 7/9/94 1/14/95 1/15/95 1/24/95 9/13-17/94 9/13-17/94 15950'-16400' 15950'-16400' 15950'-16260' 15925'-16416' 16682'-17629' 17936'-18080' 16680'-18080' 14640'-14900' 16682'-18080' 13050'-13310' 11600'-11820' 10462'-11942' 10448'-11941' 12850'-13300' 15889'-16739' 14560'-16062' 14620'-16020' 14565'-15956' PDK-100 - GR/Temp/CL (BORAX) PLS (Spinner/Temp) PLS (FIowmeter/Temp/Pressu re) LDWG Tape (PDK-100/GR - Borax Log) Gamma Ray/CCL (Spot TCP Guns) CDN - Depth Corrected CDR - Depth Corrected LDWG Tape (CDR/CDN) PLS (Static Pressure/Temperature) PFC Gamma Ray/Collar Log (Perf. Record) CDR Enhancement- LWD/Depth Corrected CDR - LWD/Depth Corrected PLS (Production Profile) PLS (Static Survey) LWD 2 Bit Run Merged CDR & CDN CDR - Depth Corrected CDN - Depth Corrected I Atlas Wireline 1 Atlas Wireline I Atlas Wireline I Atlas Wireline I Atlas Wireline Composite Schlumberger Composite Schlumberger 1 Schlumberger 1 Atlas Wireline 1 Atlas Wireline 1 Schlumberger 1 Schlumberger 1 Atlas Wireline 1 Atlas Wireline 1 & 2 Schlumberger Composite Schlumberger Composite Schlumberger ALASKA OIL AND GAS CONSERVATION COMMISSION February 25, 1994 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 329.02 Re: Spacing exception for Niakuk 23 seawater injection well. Mr. Terry Jordan Drilling Engineering Supervisor BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Dear Mr. Jordan: 'We have received your correspondence dated February 25, 1994 proposing the drilling of the Prudhoe Bay Unit NK-23 development service well to the Niakuk Oil Pool. The well as proposed will penetrate the top of the Kuparuk River Formation 1117 feet from the north line and 1114 feet from the east line of Section 28, Township 12 North, Range 16 East, Umiat Meridian. The Commission has determined that drilling the well will not promote waste or violate correlative rights and will enhance recovery from the Niakuk Oil Pool. Initiation of injection into the well cannot legally commence until the operator of the Class II injection project has obtained an area injection order for the Niakuk Oil Pool. We hereby approve the drilling of the NK-23 service well as proposed pursuant to Rule 3 of Conservation Order No. 329. Chairman ~ ' BY ORDER OF THE COMMISSION BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 · · July 19, 1994 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached in duplicate is detailed information regarding the enclosed well logs for the Niakuk Field. Per 20.AAC 25.537(d) BP Exploration would like . these these logs held confidential for 24 months. Please contact me at 564- 4531 if you have any questions. Sincerely, Katie Nitzberg, Sr."-~3eol,~!st Greater Pt. Mclntyre Are~: RECEIVED Enclosures JUL 2 0 ]994 Alaska 0il & 6as ~ns. 6ommissjorj Ancherage WELL NAME DATE INTERVALS LOG NAME RUN NO COMPANY NAME NK-07 6/19-22/94 NK-07 6/19-22/94 NK-07 6/19-22/94 NK-07 6/19-22/94 NK-07 6/19-22/94 NK-07 6/30/94 NK-23 4/3O/94 NK-23 4/23-30/94 NK-23 4/23-30/94 NK-23 4/23-30/94 NK-23 4/23-26/94 NK-23 4/23-30/94 NK-23 6/15/94 13992'-15707' V/LDWG (LWD Open Hole Edit) Tape 14965'-15695' ~TT~D CDN 14965'-15695' TVD CDR 14965'-15695' '/CDN LWD/Depth Corrected Final 14965'-15695' ~CDR Ve~-Enhanced Res LWD/Depth Corr Final 14060'-15699 ~S (LDWG) Tape 16073'-1 16114'-1 16114'-17195' 16114'-17195' 16114'-16741' 16741 '-17195' 14250'-16758' / 7526' v' LDWG (Open Hole Edit) Tape 7195' JCDN LWD/Depth Corrected Final ....-CDR LWD/Depth Corrected Final ./'CDR Very-Enhanced Res LWD/Depth Corr Final ./I-VD CDR ~~ /"TVD CDN ~-Baseline Temp Log GR/Collar Locator Final 1 Schlumberger 1 Schlumberger 1 Schlumberger 1 Schlumberger 1 Schlumberger 1 Atlas Wireline 1,2,3 Schlumberger Composite Schlumberger Composite Schlumberger Composite Schlumberger 1 Schlumberger Composite Schlumberger 1 Atlas Wireline STATE OF ALASKA / ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG I !1. Stalus of Well Classification of Service Well OIL [] GAS [] SLE, PEI',DED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 94-35 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 ~' '.. 50- 029-22455 4. Location of well at surface 9. Unit or Lease Name 1410' NSL, 679' WEL, SEC. 36, T12N, R15E~ ~'~"~~'~*'~O~'~PL~!~ Niakuk i~ - ,DATE/,. ~ ~~ 10. Well Number 973'NSL, 928'EWL, SEC. 28, T12N, R16E ! VE FIE~ i ~ ........ : 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 58.6' I ADL 34634 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 3/24/94 4/29/94 6/19/94I N/A feet MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost I 17535'MD/10063' TVD 17435'MD/10043' TVD YES [] N3 [] 2188' feet MD I 1800'(Approx.) 22. Type Electric or Other Logs Run CDN/CDR/MWD 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE w'r. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94~ H-40 Surface 80' 30" 260 sx Arcticset (Approx.) 13-3/8" 68# L-80 5659' 16" ~64o sx "E"/375 sx "G"/250 sx "C" 9-5/8" 4 7# L-80 14673' 12-1/4" 530 sx Class "G" 7" 29# NT-80S 17535' 8-1/2" 315 sx Class "G" 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MD) , Gun Diameter3-3/8" 6 spt 5-1/2", NTSOS 16770' 16754' MD TVD 16598'- 16604' (Squeezed) 16775'- 16781' (Squeezed) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 16606'-16646' (Open) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 6/19/94 I Flowing Date of Test Hours Tested PRODUCTION FOR DIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF ¢VATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED JUL. 1 9 1994 A~aska 0il & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE i .,. 30. i GEOLOGIC MARKERS ~2~RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Top HRZ 16162' 9211' Top Kuparuk 16592' 9468' Top Kingak 17456' 9956' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ./C~_~~ Title Dri//inoEnginoerSuoorvisor Date 7//~::~/~ ~' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". R E C E IV E D Form 10-407 JUL ] 9 1994 Alaska Oil & Gas Cons. Commission Anchora,je BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: NK-23 BOROUGH: NORTH SLOPE UNIT: POINT MCINTYRE FIELD: POINT MCINTYRE LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 03/23/94 09:30 SPUD: 03/23/94 06:00 RELEASE: OPERATION: DRLG RIG: POOL 7 WO/C RIG: POOL 7 03/24/94 ( 1) TD: 451' ( 451) 03/25/94 ( 2) TD: 2420' (1969) 03/26/94 ( 3) TD: 4285' (1865) 03/27/94 ( 4) TD: 5260' ( 975) 03/28/94 (5) TD: 5673' ( 413) 03/29/94 ( 6) TD: 5673' ( 0) DRILLING W/BIT MW: 8.7 VIS:124 MOVE RIG F/NK-26 T/NK-23. RIG UP SAFETY EQUIPMENT. TAKE ON WATER & MIX SPUD MUD. RIG UP DIVERTER SYSTEM. TEST DIVERTER W/AOGCC WITNESS:JOHN SPAULDING. CUT DL. SERVICE RIG. PU 32 JTS. HWDP & RACK BACK. PU 3DC'S & JARS. MU BHA, ORIENT MOTOR & MWD. BREAK CIRC, CHECK SURFACE EWUIP. AND DRILL W/BIT #1 F/80' T/451. DRILLING MW: 9.1 VIS:300 DRILLING WITH BIT %1 FROM 451-2014'. DRAM DOWN ANGLE FROM 1900-1935' CONTINUE DRILLING FROM 2014-2420'. DRILLING MW: 9.5 VIS:140 DRILLING W/BIT ~1 T/3144. CBU DROP SURVEY, PUMP DRY JOB. TOOH. RETRIEVE SURVEY. CHANGE BHA. ORIENT MOTOR & MWD. CHECK MWD, SERVICE RIG. TIH, BENCHMARK SURVEY @ 3121. DRILLING T/4285. DRILLING MW: 9.4 VIS:100 CBU F/SHORT TRIP @ 4288, PLUGGED DRILL PIPE SCREEN. CHECK SURFACE EQUIPMENT, FOUND HOLES IN AUGGER SYSTEM ALLOWING CUTTINGS INTO ACTIVE SYSTEM. PLUGGED SOLIDS CONTROL EQUIPMENT. TOOH, CLEAN BHA, PITS REPAIR AUGGER SYSTEM, CLEAN OUT SOLIDS CONTROL EQUIPMENT. TIH, WORK THROUGH BRIDGE @ 2270 W/NO PROBLEM. DRILLING F/4288 T/5260. RUN 13-3/8 MW: 9.6 VIS: 47 DRILLING T/5673. CBU. SHORT TRIP F/5673 T/4200. CBU & DROP SURVEY. RU & RUN 13-3/8" 72# CASG. TEST BOPE MW: 9.7 VIS: 47 RUN 13-3/8" 72# CASG. MU CMT HEAD & CIRC PIPE VOL. CMT CASG. DISPLACE W/RIG. BUMP PLUG @2000PSI. RD FLOOR. ND DIVERTER SYSTEM & PERFORM TOP JOB. NU BOP'S. TEST BOP'S, WITNESSING WAIVED BY AOGCC REP J.SPAULDING. IBOP ON TOP DRIVE WAS CHANGED OUT. RECEIVED JUl_ B 9 1994 A)aska Oil & Gas Cons. [;ommJssJo~, Anchora.~ WELL : NK-23 OPERATION: RIG : POOL 7 PAGE: 2 03/30/94 ( 7) TD: 6350' ( 677) 03/31/94 ( 8) TD: 7973'(1623) 04/01/94 ( 9) TD: 9078' (1105) 04/02/94 (10) TD: 9078' ( 0) 04/03/94 (11) TD:10510' (1432) 04/04/94 (12) TD:l1094' ( 584) DRILLING MW: 9.2 VIS: 46 LAY DOWN TEST EQUIPMENT, INSTALL BOWL PROTECTOR. CHANGE OUT UPPER TOP DRIVE "IBOP" VALVE AND RETEST SAME. MAKE UP NEW BHA, ORIENT MOTOR WITH MWD TOOL. TRIP IN HOLE WITH BHA, TEST MOTOR/MWD. CONTINUE TO TRIP IN HOLE INSTALLING DRILL PIPE RUBBERS. CUT DRILLING LINE. WORK ON TOP DRIVE COMPENSATOR. TEST CASING @ FLT COLLAR 5577' DRILLING FLT EQUIPMENT AND CEMENT + 10' NEW HOLE FROM 5577-5683' CIRC BTTMS UP. LEAK OFF TEST. WORK ON TOP DRIVE COMPENSATOR. DRILLING WITH MOTOR AND BIT #2 FROM 5683-6350' DRILLING MW: 9.6 VIS: 42 SHORT TRIP TO SHOE. CLAY BALLS COMING OUT OF HOLE SO LARGE THEY WILL NOT GO DOWN FLOW LINE. CIRC BTM UP FROM SHOE. BREAKING UP CLAY BALLS SO THEY WILL GO DOWN FLOW LINE. RIH. WASH 90 DEGREE TO BOTTOM. DRILL AND SURVEY 6332-7371' CBU. SHORT TRIP TO 6238'. HOLE IN GOOD SHAPE. DRILLED AND SURVEYED 7371-7973' MU BHA # 4 MW: 9.6 VIS: 48 DRILLED T/8417. START SCHEDULED WIPER TRIP DUE T/FOOTAGE. CBU @ 8417. POOH HAD T/BACKREAM 7438 - 7374. RIH T/8417. DRILLED T/9078. REACHED PLANNED END OF RUN. CBU @ 9078. POOH T/360. PULLED BHA. PU NEW BIT MU BHA # 4. POOH T/9700' MW: 9.6 VIS: 48 PU NEW BIT. MU BHA #4. RIH T/5600. SERVICED THE TOP DRIVE, HELD SAFETY MTG. RIH T/9078. TIH T/ADJUST STOPS ON DP RUBBERS. DRILLED T/10121. START SCHEDULED WIPER TRIP, DUE T/FOOTAGE. CBU. POOH T/9700. RIH T/10510 MW: 9.6 VIS: 58 POOH T/8892. T/TOP OF CHECK INTERVAL. RIH T/10121. BTTM. HOLE IN GOOD SHAPE. DRILLED T/10510. ROP DROPPED T/20FPH. BIT QUIT. CBU POOH T/l171, PULLED BHA. MU BHA #5. RIH T/5600 @ 9-5/8" SHOE. SLIP & CUT DL. SERVICE THE TOP DRIVE. CHANGE OUT ALLIGNMENT CYLINDAR ON TOP DRIVE. RIH T/10510. CHANGE TO DST 1 HR. FORWARD. TIGHTEN THE DP RUBBERS WHILE RIH. RIH T/1500. MW: 9.6 VIS: 55 RIH T/10510. CHANGE TIME T/DST. TIGHTEN TH DP RUBBERS WHILE RIH. DRILLED T/11094. ROP DROPPED F/45 T/25 FPH. BIT QUIT. CBU. POOH T/ll00. PULLED BHA. CHANGED BIT, SERVICED THE WEAR RING. MU BHA # 6. TEST MWD. RIH T/1500. R£CEIVED JUL 9 0[~ & Gas Cons. Commission Anchora.~e WELL : NK-23 OPERATION: RIG : POOL 7 PAGE: 3 04/05/94 (13) TD:l1690' ( 596) 04/06/94 (14) TD:12039' ( 349) 04/07/94 (15) TD:12768' ( 729) 04/08/94 (16) TD:13046' ( 278) 04/09/94 (17) TD:13510' ( 464) 04/10/94 (18) TD:13915' ( 405) DRILLING MW: 9.6 VIS: 46 RIH T/1500. STOP T/SERVICE DRILLING EQUIP. SERV. TOP DRIVE. RIH T/11094. TEST MWD, BREAK CIRC @ 5600. SURVEY @11070. DRILLED T/11690. RIH T/5600 FT. MW: 9.6 VIS: 54 DRILLED T/12094. ROP DROPPED F/50 T/30FPH. BIT QUIT. CBU. POOH T/958. PULLED BHA. TEST BOP STACK. WEEKLY TEST WAIVED BY AOGCC REP: JERRY HERRING. SUCCESSFUL COMPLETION OF THE PRESS. TEST. MU BHA #7. RIH T/5600. DRILLING MW: 9.7 VIS: 50 SERVICED THE BLOCK LINE, SLIP & CUT DL. RIH T/12039. BENCHMARK SURVEY @ 11070. REAM LAST 90' T/BTTM. DRILLED T/12768. RUN IN HOLE MW: 9.6 VIS: 48 DRILLED T/13046. ROP DROPPED F/50 T/20 FPH. BIT QUIT. CBU DROP SINGLE SHOT SURVEY, PUMP DRY JOB. POOH T/214. REMOVE DP RUBBERS OFF 1200' OF PIPE. PULL BHA C/O JARS, BIT, PULL SS SURVEY. RIH T/5400. DRILLING MW: 9.8 VIS: 51 RIH T/5650. SER. TOP DRIVE. RIH T/13046. RETORQUE DP RUBBERS, BENCHMARK SURVEY @ 11070. REAM 90' T/BTTM. DRILLED T/13046. MUD MOTOR FAILED. CBU. POOH T/214. PULL BHA. MU BHA #9, PU NEW MOTOR, CK. MWD. RIH T/5600, SERV. BLOCK LINE, SLIP & CUT DL, RIH T/13046. BM SURVEY @ 11070. DRILL T/13510. RIH T/12500 MW: 9.8 VIS: 45 DRILL T/13915.FORM. CHANGE BHA DROPPING ANGLE. COULDN'T SLIDE W/PDC. POOH F/BHA. CBU. TOOK SURV @ 13825. DROP SS SURV. POOH T/214. PULL BHA SERV. WELL CONTL, WEAR RING. MU BHA. RIH T/5400. SERV. TOP DRVE, BL, SLIP & CUT DL. SERV. DRAW WORKS, SET BRAKES. RIH W/#10 T/12500. TIGHTEN DP RUBBERS. RECEIVED JUL. 1 9 i994 Ai~ska Oil & Gas Cons. Cornmission Anchorage WELL : NK-23 OPERATION: RIG : POOL 7 PAGE: 4 04/11/94 (19) TD:14119' ( 204) 04/12/94 (20) TD:14245' ( 126) 04/13/94 (21) TD:14605' ( 360) 04/14/94 (22) TD:14673' ( 68) 04/15/94 (23) TD:14673' ( 0) 04/16/94 (24) TD:14673' ( 0) 04/17/94 (25) TD:14673' ( 0) DRILLING MW: 9.8 VIS: 43 RIH T/13915, TIGHTEN DP RUBBERS, BM SURVEY @11070. REAM LAST 90' T/BTTM. DRILL T/14054. ROP DROP. F/85 T/0 FPH. STOP T/PDC BIT. CBU. POOH. C/O BIT. MU BHA #11. RIH T/1ST STND DP. CK. MWD. SERV. TOP DRIVE. RIH T/14054. TIGHT. RUBBERS-BM SURV. @11070. FILL PIPE/REAM 50 T/BTTM. DRILL T/14119. BHA RUN # 12 MW:10.0 VIS: 62 DRILL T/14245. BHA BUILDING TOO FAST. CBU. POOH T/214. PULLED BHA, LD LEAD COLLAR, PU STAB, C/O BIT. RIH T/5400 W/BHA. CK. MWD. RIH T/13.375 CASG SHOE. FILL PIPE. SERV. TOP DRIVE. SERV. DRAW WORKS. RIH T/12000 W/BHA #12. DRILLING MW: 9.9 VIS: 39 RIH T/14245. REAM LAST 30' T/BTTM. DRILLED T/14605. RUNNING CASG. MW: 9.9 VIS: 44 DRILL T/14673. REACH SECT. END/CBU. POOH T/13700. RIH T/14673/CBU. POOH T/5658. SERV. BL/CUT DL. POOH T/500. PULL/LD BHA. TEST BOP STACK, CHANGE TOP SET RAMS T/9-5/8. TEST BODY T/2500. OK. RU CASG EQUIP. HLD SFTY MTG. RUN 9.625 OD CASG T/3600. RU T/RUN GYRO MW: 9.9 VIS: 43 RAN CASG T/14673.CBU. MIX & PUMP 80 BBLS SLURRY, RELEASE CMT PLUG/DART. MIX & PUMP 78 BBLS SLURRY. RELEASE CMT PLUG/DART. DISPLACE SLURRY 1093 BBLS. PLUG BUMPED W/4000. RD BOP STK. COMMISION X-MAS TREE/WELLHEAD/HNGR. CUT CASG @ 37.53'. TEST PKOFF T/3500. RU BOP SK. CHANGE RAMS T/7X4.5. INJECT 200 BBLS MUD 140 BBLS DIESEL DOWN 13-3/8X9-5/8 AANUL. TEST BOP STK. OK. INSTALL WEAR BUSHING. RU WESTERN ATLAS T/RUN GYRO. RUN GYRO INSIDE DP MW:10.0 VIS: 40 RIH T/4700, TOOL STOPPED. POOH. ADDED WT BARS. COMPLETED MISRUN W/GYRO T/5800. POOH. MU BHA #13. RIH T/14547. RAN ELECTRCIC LOGS, RU WESTERN ATLAS, RAN GYRO INSIDE DP. RIH T/12000 MW:10.0 VIS: 36 RAN ELECTRIC LOGS, RU WESTERN ATLAS & RUN GYRO INSIDE DP. COMPLETED RUN W/GYRO F/14531 T/0. RD WEST. ATLAS. POOH T/10' PULL BHA. MU BHA #14. RIH T/12000. PICK UP E-PIPE & INSTALL DP RUBBERS WHILE TIH. RECEIVED JUL 1 9 1994 Ataska Oil & Gas Cons. Commission Anchora~-¢ WELL : NK-23 OPERATION: RIG : POOL 7 PAGE: 5 04/18/94 (26) TD:14845' ( 172) 04/19/94 (27) TD:15040' ( 195) 04/20/94 (28) TD:15453' ( 413) 04/21/94 (29) TD:15690' ( 237) 04/22/94 (30) TD:15775' ( 85) 04/23/94 (31) TD:16114' ( 339) DRILLING MW:10.0 VIS: 53 RIH T/14000. STOP TO SERV. TOP DRIVE & BLOCK LINE. SLIP & CUT LINE. RIH T/14546. DRILL FC, CMT & 10' NEW HOLE T/14683. PERFORM FORM INT. TEST. CBU. INTEGRITY LEVEL IS 12.5 PPG EMW. CIRC @ 14683. HOLE DISPLACED W/WATER BASED MUD T/CHANGE OVER FLO PRO SYSTEM. DRLG T/14845. DRILLING MW:10.0 VIS: 56 DRILLED T/15013. BUILD RATE UNACCEPTABLE-CHANGE IN FORMATION. CBU. SURV. PUMP DRY JOB. POOH T/360. PULLED BHA, SET BRAKE, LAID OUT. MU BHA#15. RUH T/15013. WASH & REAM LAST 30' T/BTTM. DRILLING T/15040. POOH PUMP & BK REAM MW:10.1 VIS: 49 DRILLED T/15453. ART= 17 HRS. ROP DROPPED F/20 T/14 FPH. BIT QUIT. CIRC @ 15453. CLEAN RETURNS. POOH T/2200. TIGHT @ 15350. PUMP & BK REAM T/14984. DRILLING MW:10.0 VIS: 54 POOH T/2200. PULL TIGHT @ 15350. PUMP & BK REAM T/14984. PULLED BHA, C/O BIT, PU DRILL COLLAR. SERV. BOP STK./WEAR BUSHING. MU BHA #16. TEST MWD. RIH T/5400. SERV. BLK LINE/SLIP & CUP/SERV. TOP DRIVE. RIH T/15400, RETRQ. DP RUBBERS. TIGHT F/15100 T/15390. PRECAUTION. REAM T/15453. DRLG T/15690. DRILLING MW:10.0 VIS: 57 DRLG T/15713. BUILD RATE UNACCEPTABLE-CHANGE IN FORMATION. CBU. POOH WET T/9.625 CASG SHOE. PUMP DRY JOB. REPAIR DRAW WORKS, WELD ON BREAK FLANGE WEAR PAD. POOH T/214. PULLED BHA. LD NB STAB & MONEL DC. MU BHA #17. PU MOTOR, STAB & LEAD DC, MU BIT, SURF. TEST TOOLS. RIH T/15713. FILL PIPE @7500 & 14600. CK TQUE. ON DP RUBBERS, WASH & REAM F/15425 T/15487. PRECAUTION REAM LAST 35' T/BTTM. DRLG T/15775. PULL BHA MW:20.0 VIS: 56 DRLG. T/16114. WALK RATE UNACCEPT - CHANGE IN FORMATION. CBU. POOH T/14600. SERV. BLOCK LINE. SLIP & CUT. POOH T/214. PUMP SLUG. POOH. PULL BHA. RECEIVED JUL. 9 1994 O~l & Gas Cons. Commission Anchorage WELL : NK-23 OPERATION: RIG : POOL 7 PAGE: 6 04/24/94 (32) TD:16214' ( 100) 04/25/94 (33) TD:16382' ( 168) 04/26/94 (34) TD:16741' ( 359) 04/27/94 (35) TD:16860' ( 119) 04/28/94 (36) TD:17195' ( 335) 04/29/94 (37) TD:17450' ( 255) 04/30/94 (38) TD:17535' ( 85) DRILLING MW:10.2 VIS: 58 PULL BHA PERFORM INTEGRITY TEST. MU BHA NO. 18. PU MOTOR, MWD & BIT. TESTED WELL CNTRL. BOPE MANIFOLD & TOP DRIVE VALVES. MU BHA NO 18 RIH T/298, TEST MOTOR & MWD, CDR & MWD TOOLS FAILED. POOH & REPROGRAM, RETEST. OK. RIH T/6000. SERV. TOP DRIVE. RIH T/15760. PIPE GOT STUCK, ROT. & CIRC. PIPE CAME FREE, REAMED T/16114. DRLG T/16214. RD HANDLING EQUIP MW:10.2 VIS: 60 DRLG T/16382. STOP T/SURV. CBU. POOH T/14670/RERUN GYRO SURV. RU HNDLNG EQUIP/ATLAS WL. WORK COMP. RAN ELEC. LOGS. RD HANDLING EQUIP. POOH . PUMP DRY JOB MW:10.2 VIS: 60 SERV. BLOCK LINE, SLIP & CUT. SERV. DRILLFLOOR/DERRICK/RIG. HELD SAFETY MTG. RIH T/16382. RIH T/15360, WASH & REAM F/16290 T/16382. DRLG T/16741. TOP OF KUPARUK @16595 MD, TVD = 9530. CHANGE IN TORQUE. PR DROPPED. BIT QUIT. POOH. CBU. PULL T/SHOE, PUMP DRY JOB. POOH F/NEW BIT. DRILLING MW:10.4 VIS: 59 POOH T/240. PULL BHA CHANGE BIT & MOTOR STAB SLEEVE. SERV BOP STK/WEAR BUSHING. MU BHA #19. PU CDR/PROGRAM TOOL/ORIENT MOTOR/INSTALL SOURCE/SURF. TEST MWD & MOTOR. RIH T/4000. STOP T/SERV. EQUIP./BLOCK LINE. SLIP & CUT DL. SERV. TOP DRIVE. RIH T/15433/BEGAN CAUTIONARY REAM T/16741 ON BTTM. DRLG T/16860. BHA LAID OUT MW:10.4 VIS: 59 DRLG T/17195, CHANGE IN TORQUE. BIT QUIT. CBU. BACKREAM T/14673.CIRC. PUMP 50 BBLS BELOW LO VIS SWEEP. POOH T/1260. PULL BHA. BHA LAID OUT DRILLING MW:10.3 VIS: 54 PULLED BHA DOWN LOAD MWD SOURCE. LD MOTOR. MU BHA #20. RIH T/7000. SERV. BLOCK LINE, SLIP & CUT DL. 85'. SERV. TOP DRIVE/RIH T/14673. CBU. RIH T/17195. DRLL T/17450. TQ WAS ERATIC BUT SMOOTHED OUT 1050 AMPS ON BTTM. PULLING DP RUBBERS MW:10.3 VIS: 59 DRLG T/17535. CBU. PUMPED OUT OF HOLE T/14670. RIH, REMOVE RUBBERS, HOLE OK. CBU @/BTTM. POOH LD HEAVY WT & BHA. RECEIVED JUL. 1 9 1994 Alaska Oil & Gas Cons. Commissior. Anchora~ WELL · NK-23 OPERATION: RIG : POOL 7 PAGE: 7 05/01/94 (39) TD:17535' ( 0) 05/02/94 (40) TD:17535 PB: 0 05/03/94 (41) TD:17535' ( 05/04/94 (42) TD:17535' ( 05/05/94 (43) TD:17535' ( 05/06/94 (44) TD:17535 PB:10063 o) o) o) CBU MW:10.4 VIS: 48 POOH T/320. LD HWDP. PULLED BHA/DOWNLOAD MWD/LWD. RU CASG HNDLG EQUIP. RUN 7" CASG T/14673. CIRC. RUN T/15430. UNABLE TO RE-ENTER HOLE. WASHED TO 15430. LOSS OF 120000 LBF STRING WT. SET ALL STRING DN WT ON OBSTRUCTION. PULL DP IN STNDS T/14650 & CIRC. RU CASG HANDLG TOOLS WHILE CIRCULATING. MU BHA #21 MW:10.4 WBM CBU @ 14650. PULL DP IN STNDS. RU CASG EQUIPMENT. LAID OUT CASG T/0 FT. RD CASG EQUIP. COMMISSIONED X-MAS TREE. RETRIEVE WEAR BUSHING. TEST WELL CONTROL EQUIP. PRESS TEST OK. MU BHA #21. WASH & REAM T/16034 MW:10.4 VIS: 51 MU BHA #21. SERV. BLOCK/LINE CUT DL/SERV. TOP DRIVE. RIH T /14673. CBU RIH T/15371. REAM T/16470. TOP DRIVE FAILED/WORK STRING. CBU @ 16470. SHORT TRIP. TOP DRIVE WON'T RE-SET. POOH CBU @ 14673. SERV. TOP DRIVE & RE-SET. RIH T/15844, BEGIN CAUTIONARY MEASURES/WASH & REAM T/16034. BACKREAM T/15135 MW:10.6 VIS: 52 REAMED T/17535. WASH & REAM 16034 T/17535. CBU. BACKREAM T/15135. 2 TIGHT SPOTS. PULL T/9.625 CASG SHOE. RAN 7" CASG MW:10.8 VIS: 51 CIRC @ 14673. HOLE SWEPT W/SLUG. RIH T/15475. REAMED T/17535. CIRC & COND MUD. POOH T/14673. SERV. BLOCK LINE CUT DL. ADJST. BRAKES. PULLED BHA/RUN 7" OD CASG. T/2000. CHCKD FLOAT EQUIP. PULLING DP IN STANDS MW:10.4 WBM RAN CASINF TO 3036' PU LINER TOP PACKER. HANGER ASSEMBLY INSTALLED. CIRCULATED AT 3100' OBTAINED BOTTOMS UP. CIRC LINER CLEAR. RAN DRILLPIPE IN STANDS TO 14673' BREAK CIRC EVERY 10 STDS, AT 9.625 IN CASING SHOE. CIRCULATED AT 14673'. CIRC PIPE VOLUME. GET UP, DOWN & ROTATED WTS. OBTAINED CLEAN RETURNS. RAN DRILLPIPE IN STANDS TO 16326. TIGHT @ 15630', COULD'NT WASH THROUGH. ABLE TO REAM THROUGH TIGHT SPOTS. CONTINUED TO REAM TO 16326', LOST PRESSURE & WEIGHT WITHOUT ANY OBVIOUS REASON. PROBABLY LOST LINER. SETTING TOOLS FAILED - ABORT OPERATION. PULLED DRILLPIPE IN STANDS TO 3000' WELL : NK-23 OPERATION: RIG : POOL 7 PAGE: 8 05/07/94 (45) TD:17535 PB:10063 05/08/94 (46) TD:17535 PB:10063 05/09/94 (47) TD:17535 PB:10063 05/10/94 (48) TD:17535 PB:10063 POH MW:10.4 WBM PULLED DRILLPIPE IN STANDS TO 100 FT. POH W/ LINER RUNNING TOOL, IT HAD RELEASED. HANGER ASSEMBLY LAID OUT. SERVICE TOP DRIVE. WAIT ON FISHING TOOLS, SERVICE & CHANGE OUT PART ON TOP DRIVE. MADE UP BHA #22. ID, OD & MAKE UP FISHING TOOL ASSEMBLY. RIH TO 13322'. FISHED AT 13322' SPEAR LINER HANGER AND TRY TO PUSH LINER DOWN HOLE - NO GO. LATCHED FISH. PUMPED OUT OF HOLE TO 14570' PUMP TO THE SHOE W/ THE FISH. CIRCULATED AT 14570'. CBU. OBTAINED BOTTOMS UP. PULLED OUT OF HOLE TO 3400' RIH MW:10.4 WBM PUMPED OUT OF HOLE TO 29'. SWABBING ALL THE WAY OUT WITH LINER. RIGGED UP CASING HANDLING EQUIPMENT. PULLED OUT OF HOLE. LAY DOWN LINER HGR/PKR. RIGGED DOWN CASING HANDLING EQUIPMENT. BHA RUN #23. RIH TO TO 15960'. FILL PIPE @7200' AND AT THE SHOE 14600'_ BEGAN PRECAUTIONARY REAM. REAM ALMOST EVERY STAND F/ 15960-16888'_ NO FURTHER RESISTANCE. RIH TO BTM. NO TIGHT SPOTS. RUN CASING MW:10.4 WBM CIRCUALTED AT 17535'. OBTAINED CLEAN RETURNS. PULLED OUT OF HOLE TO 14600' SHORT TRIP TO SHOE, SOME TIGHT SPOTS AT 9.625 IN CASING SHOE. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. RIH TO 16475' REAMED TO 17535' REAM TIGHT SPOTS F/ 16475-16699', HOLE CLEANED UP, RIH TO TD. CIRCULATED AT 17535'. ROTATE 150 RPM & RECIPROCATE WHILE CBU. OBTAINED CLEAN RETURNS. POOH TO SHOE, HOLE IN GOOD SHAPE. PULLED OUT OF HOLE TO 630'. PUMP DRY JOB. PULLED BHA. BHA STOOD BACK. RIGGED UP CASING HANDLING EQUIPMENT. RUN CASING TO 400' POH @ CSG SHOE MW:10.4 WBM RAN CASING TO 3030' RUN LINER, P/U HGR/PKR. HANGER ASSEMBLY INSTALLED. CIRCULATED AT 14670' OBTAINED REQ'D FLUID PROPERTIES. CIRC LINER VOLUME. RAN DRILLPIPE IN STANDS TO 14670' CRICULATED 1T 14670' M/U CIRC, HEAD & CIRC PIPE VOLUME. RIH W/ LINER, TAG TIGHT SPOT @15633'. ROTATE AND WASH TO 16075'. CASING HANDLING EQUIPMENT FAILED, CONTINUE WITH REDUCED EFFICIENCY. PUSH, PUMP & BUMP LINER TO BTM. CIRCULATED AT 17535'. PULLED DRILLPIPE IN STANDS TO 13500'. PUMP DRY JOB, POH. RECEIVED JUL. 1 9 1994 '" A~aska Oil & Gas Cons. 6omm~ss~o Anchorau¢ WELL : NK-23 OPERATION: RIG : POOL 7 PAGE: 9 05/11/94 (49) TD:17535 PB:10063 05/12/94 (50) TD:17535 PB:10063 05/13/94 (51) TD:17535 PB:10063 05/14/94 (52) TD:17535' ( o) CIRCULATED @ 17535' MW:10.4 WBM PULLED DRILLPIPE IN STAND TO 11' HANGER ASSEMBLY LAID OUT. BREAK DOWN AND LAY DOWN BAKER SETTING TOOL. TESTED WELL CONTROL. PRESSURE TEST COMPLETED. LAID OUT DRILL PIPE. MAKE UP BAKER SETTING TOOL. BHA #24 MADE UP. SERVICE RIG AND TOP DRIVE, ADJUST BRAKES. RIH TO 14500'. P/U CIRCULATING HEAD. LATCH ON TO LINER. WORKED TOOLSTRING AT 17535'. TRY TO WORK LINER FREE, NO LUCK. CIRCULATED @17535' CONTINUE TO TRY AND WORK PIPE FREE. RIH MW:10.4 WBM CIRCULATE AT 17535' CONTINUE TO LOWER MW TO 10.4 PPG. OBTAINED REQ'D FLUID PROPERTIES - 150.00, HOLE VOL. RIGGED UP CEMENT UNIT. MIXED AND PUMPED SLURRY. DISPLACED SLURRY. STOPPED THE DISPLACEMENT. PULLED OUT OF HOLE TO 12650' BEGAN PRECAUTIONARY MEASURES. PULLED WET. CIRCULATED @ 12650' HOLE DISPLACED WITH WATER BASED MUD. LAID OUT DRILL PIPE TO 11100'. SERVICED BLOCK LINE. PULLED OUT OF HOLE @ BHA. TEST WELL CONTROL EQUIPMENT. TESTED TOP RAM. CHANGED TOP RAMS TO 3 1/2" TEST DOOR. FUNCTION TEST COMPLETED SATISFACTORILY. MAD EUP BHA #25. BHA #25 MADE UP. SINGLED IN DRILL PIPE TO 3000'. 69 JOINTS PICKED UP. RIH TO 12500' RU ATLAS T/RUN SBT MW:10.4 WBM RIH T/14517. BREAK CIRC. MILLED LINER HNGR @14520. WASHED T/17040. OBSERVE 20000 LBF RESISTANCE. RIH & TAG STRINGER @ 14614. DRILL CMT T/17439. TAGGED LNDG COLLAR. CMT SPOTTY. CBU @ 17439. CLEAN RETURNS - 200 36777760240LE VOL. LOAD PITS W/9.8 PPG NACL BRINE. MIX SPACERS. HOLE DISPLACED W/50BBLS SAGEKLEEN & 100 BBLS VISCOSIFIED BRINE SPACERS BEFORE 9.8 BBLS BRINE. CLEAN RETURNS AFTER CIRC OF SPACERS. SERV. FL. CLEAN TRIP TANK & POSSUM BELLY. LOAD MORE BRINE INTO MUD SYSTEM. PUMP DRY JOB. POOH T/WELLHEAD. RU ELECT. WL UNIT T/RUN SBT. RIH W/WL MW: 9.8 VIS: 27 RUN ATLAS SBT. UNABLE T/GET PAST 15625. ADD 3 KNUCLE JTS. 2ND RUN, UNABLE T/GET PAST 15610. 3 DEGREE TURN IN WELL PROFILE. COMP. RUN CMT BOND LOG HUNG UP @15625. SERV. TOP DRIVE. RU E-LINE UNIT. WAIT ON DP-COVEYED EQUIP. MOVE DC & HWDP, TEST SBT @ SURFACE BEFORE RIH. SINGLED IN DP T/600. PU 21 JTS. RIH T/15838. OK @ TOL & 15625. TAKE SURV. HOLD SFTY MTG. RU E-WL UNIT. HANG WL SHEAVE IN DERRICK. PU SIDE DOOR ENTRY SUB. RIH W/WL T/14000. R£C£1V£D JUL '~ 9 '~994 0i~ & Gas Cons. Commission Anchorage WELL : NK-23 OPERATION: RIG : POOL 7 PAGE: 10 05/15/94 (53) TD:17535' ( 0) 05/16/94 (54) TD:17535' ( 0) 05/17/94 (55) TD:17535' ( 0) 05/18/94 (56) TD:17535' ( 0) 05/19/94 (57) TD:17535' ( 0) END 3.5" DP RUN MW: 9.8 VIS: 0 RAN E-LOGS. COMP. LOGGING RUN W/CST F/17396 T/16560. RAN SBT ON DP UNTIL TOOL FAILED LOG SHOWED LITTLE OR NO BOND BEHIND PIPE F/ENTIRE INTERVAL. RIG DOWN E-LINE POOH W/WL & WET CONNECT. POOH T/WELLHEAD. SHOOT 2 SETS OF SQUEEZE PERFS (6' @ 6 SPF). 16584, 16590, 16775 & 16781. GUNS RETRIEVED. FIRED SUCCESSFULLY @ 16584. RIH T/2300, PU 7" EZSV. END OF 3.5" DP RUN. PU PLUG CATCHER. CBU MW: 9.8 VIS: 27 RIH T/3000. UPPER ARM FAILED; ABORT OPERATION. REPAIR UPPER ARM BEARING FAILED IN CROWN SHEAVE. C/O FAST CROWN SHEAVE. RIH T/16632. SET DOWNHOLE EQUIPMENT @ 16632. SET EZSV. UNSTING FROM EZSV OBTAIN TBG FRICTION PRESS. EST. STING BACK INTO RETAINER. EST. CIRC. CBU @ 5BPM W/825PSI & FULL RETURNS. POOH T/4000. MW: 9.8 VIS: 27 CBU @ 16632. MIX & PUMP SLURRY 23 BBLS. RELEASE CMT PLUG/DART. PUMP 52 BBLS KCL WATER, 23 BBLS SQZ CMT, 13.5 BBLS 2KCL WATER. DROP DART. DISPLACE W/BRINE. PUMP CALCULATED STRKS-DART DID NOT BUMP. POOH & CBU @14770. BEGAN PRECAUT'Y MEASURES. TOOK SURV. CLOSED HYDRL, PRESS. WELLBORE T/300. HOLD/15 MIN. OK. POOH T/5000. STOP & SERV. BLOCK LINE. CUT & SLIP LINE. POOH T/WELLHEAD. MU BHA #28. RIH T/14500. TOL. WORK TOOLSTRING @14517. POLISH LINER TIE-BCK RECEPTACLE. OK. POOH T/4000. MU CLEANOUT ASSY MW: 9.8 VIS: 27 POOH T/WELLHEAD TEST BOP STACK/CHOKE MANIFOLD/HCR VALVES & ALL FLOOR VALVES. OK. RIH T/14510. PU PCKR & TIE-BACK SLEEVE. TRING INTO PBR. TEST ANNULUS T/500#. OK. UNSTING & DROP BALL. PUMP INTO PLACE. SEAT BALL & STING T/3500# F/30MIN. W/70# OF PRESS LOSS. SHEAR BALL @3300 DOWN DP. ROTATE OFF PCKR. POOH T/WELLHEAD. MU BHA NO. 30. MU CLEANOUT ASSY. PRESS TEST CSG. MW: 9.8 VIS: 0 RIH T/15709. TAG UP ON CMT STRINGERS. OVSERV 10000# RESISTANCE. DRILL CMT T/16626. TAG DOWNHOLE EQUIP. CBU TEST CASG VIA STRING. TEST PERGS T/1000, LOST 75 IN 10 MIN. PRESS UP T/1500. LOST 165 IN 10 MIN. OK. DRILL CMT T/17439. DRILL UP EZSV. DIDN'T SEE ANY CMT UNTIL BELOW THE PERFS @ 16858. T/16898. CLEANED T/LNDG COLLAR. CBU. HOLE SWEPT W/SLUG. 175% HOLE VOL. TEST CASG T/1000, LOST 65 IN 10MIN. PRESS UP 1500PSI. LOST 135 IN 10 MIN. POOH T/12700. RECEIVED JUL_ 1 9 1994 /~ska. OJ~ & Gas Cons. Commission Anchora~i~ WELL : NK-23 OPERATION: RIG : POOL 7 PAGE: 11 05/20/94 (58) TD:17535' ( 0) 05/21/94 (59) TD:17535' ( 0) 05/22/94 (60) TD:17535' ( 0) 05/23/94 (61) TD:17535' ( 0) 05/24/94 (62) TD:17535 PB:10063 RIH W/BIT & SCRAPER MW: 9.8 VIS: 0 POOH SLIP & CUT DL. SERV. TOP DRIVE. POOH. PU HALLIBURTON. CHAMP PKR & RIH. CIRC & WORK SPOT CLEAN T/SET CHAMP PKR. SET PKR @ 16415. CIRC THRU PERFS, 1 BPM. 12000. POOH LD PKR. PU BIT/SCRAPER /BHA. RIH. CIRC/BATCH MIX CMT. MW: 9.8 VIS: 0 RIH T/12000. SERV. DRLG EQUIP. RIH T/BTTM. CBU. POOH. MU BHA ~33. RIH T/16642. SET BRIDGE PLUG/PKR. CBU. HELD SFTY MTG. MIX/PUMP 18 BBL TRTMNT. DISPLACE W/RIG. COMP. DSPLCMNT @ 50PSI/12BBL. CIRC ACID F/HOLE/NEUTRALIZE. STING BACK IN T/EZSV & CIRC THRU PERFS WHILE BATCH MIX CMT. DRLG CMT MW: 9.8 VIS: 0 CIRC THRU PERFS WHILE BATCH MIX CMT. OBTAINED 20% HOLE VOL. MIX/PUMP SLURRY. 35 BBLS. TEST LINES T/3000. PUMP 38 BBLS. SPACER/35 CMT./10 BBLS SPACE. DROP DP WIPER PLUG. DSPLCE SLURRY 244 BBL. BUMPED WIPER IN PLUG CATCHER. CIP. @8:25 HRS. SLURRY IN PLACE. POOH T/15225. PULL 15 STNDS. STOP F/HESIT. SQZ. OK. POOH T/10. LD HLLBRTON. SETTING TOOL. SERV. BOP STACK/WEAR BUSHING/TOP DRIVE. MU BHA #34. RIH T/14403. SERV. DRLG EQUIP. CUT & SLIP DL. ADJUST BRAKES. WASH T/15850. OBSERVE 10000 LBF RESISTANCE. TAG CMT @ 15850. DRILL CMT T/16642. C/O T/THE EZSV. TAG BRIDGE PLUG. DRILL T/16642. CBU MW: 9.8 VIS: 0 DRLG T/16642 ON EZSV. TOP DRIVE FAILURE. CBU. REPAIR TOP DRIVE. WORK ON GROUND FAULT. DRLG CMT T/17435 BELOW PERFS @16772. RIH & TAG LNDG COLLAR. CBU. POOH T/800. PULL BHA. MU #35. RIH T/1500. SERV. DRLG EQUIP. RIH T/17415. RUN 9-5/8 CASG SCRAPER TO TOL. & 7" SCRAPER T/20' OFF BTTM. CBU. RUN COMPLETION MW: 9.8 NaCl/Br CBU. TOOH LD DP T/0. LD 3.5 HWT. DP & 4.75 DCS. 24 JTS. LAID OUT. RAN DP IN STNDS T/16750. MU ISOLATION PKR & RA SUB F/WL TIE-IN. RIH W/PKR & TAILPIPE ASSY ON DP. RAN E-LOGS. RU ATLAS WL. RUN LOGS T/TIE IN PKR SETTING DEPTH W/PERF LOG OF 5/15, COMP RUN W/PERM PKR F/16754 T/16770. RD ATLAS WL. SET PKR, DROP BALL/SHEAR OFF. PKR SET @ 16754 CBU DISPLC HOLE 100% W/BRINE. SERV. BLOCK LINE. CUT DL CLEAN PITS RUN SINGLE COMP. 4.5 OD. CIRC BRINE THRU MI FILTER UNIT RECEIVED JUL ] 9 1994 /qaska Oil & Gas Cons. Commission Anchora~;~, WELL : NK-23 OPERATION: RIG : POOL 7 PAGE: 12 05/25/94 (63) TD:17535 PB:10063 RAN TBG T/800 MW: 9.8 NaC1/Br CBU @ 16754. SET ISOLATION PKR. CIRC WELL & FILTER BRINE W/MI UNIT. TURBITITY METER READ WAS 38 MG/LTR. PULLED DP IN STNDS T/7800. LD DP T/6500. EQUIP FAILURE/ABORT OPERATION. REPAIR DRILLSTRING EQUIP. PULL DP. 5" OD. LD DP T/0' LD 5" OLD S ALL E & 3.5 DP. RUN SINGLE COMP.5.5 OD. RD WELL CONTROL PULL WEAR BUSHING. RU COMP STRING EQUIP. HOLD SFTY MTG. RUN TBG T/800. 05/26/94 (64) TD:17535 PB:10063 RD BOP STACK MW: 9.8 NaCl/Br RAN TBG T/800. LND HNGR. RU LOGGING/BRAIDED CABLE EQUIP. 7/32 SIZE CABLE RAN 4" DUMMY GUNS T/14507. COMP W/GUN ASSY T/14507. ND BOP STCK 05/27/94 (65) TD:17535 PB:10063 RIG RELEASED MW: 9.8 NaCl/Br RD BOP STK. INSTALL X-MAS TREE. TEST MAN. MASTER VALVE. TEST TREE/PCKOFF T/5000/OK. FRZ PRTECT W/160 BBLS DIESEL. U-TUBE INTO TBG. DROP BALL & ROD. SET PKR. W/4000. TEST ANNUL W/4000. BLEED OFF TEST OK. INSTALL X-MAS TREE INTEGRAL COMPONENTS/SET BPV. RELEASE RIG 19:30. ON 5/26/94. SIGNATURE: (drilling superintendent ) DATE: RECEIVED dUL 1 Aiaska Oil & Gas Cons. Commission Anchorage ORIGINAL SURVEY REPORT B.~P. EXPLORATION NIAKUK WELL #NK-23 PRUDHOE BAY UNIT NORTH SLOPE ALASKA POOL 7 MAY 4, 1994 , ,. ,: / · ,- ' ,[ A Gyro da t a D i r e c t i ona i Survey for B.P. EXPLORATION WELL: NIAKUK NK- 2 3 Location: POOL 7, PRUDHOE BAY UNIT NORTH SLOPE ALASKA Job Number: AK0494G215 Run Date: 24-Apr-94 15:36:04 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.334000 deg. N Sub-sea Correction from Vertical Reference: 60.8 ft. Bearings are Relative to True North Proposed Well Direction: 67.300 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c B.P. .EXPLORATION WELL: NIAKUK NK-23 Location: POOL 7, PRUDHOE BAY UNIT Job Number: AK0494G215 NORTH SLOPE ALASKA t i o n a 1 Survey HEASURED I N C L AZIHUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. 0.0 0.00 0.00 0.00 0.0 -60.8 0 - 14339 FT. GYRO SURVEY RUN IN 5" DRILLPIPE. MEASURED DEPTHS REFERENCED TO POOL RIG 7 R.K.B. 0.0 0.0 0.0 Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 165.0 .25 96.19 .15 165.0 104.2 265.0 .38 91.68 .13 265.0 204.2 365.0 .77 98.23 .40 365.0 304.2 465.0 1.76 85.94 1.02 465.0 404.2 565.0 2.68 85.93 .92 564.9 504.1 665.0 3.02 90.05 .40 664.8 604.0 765.0 4.93 77.83 2.08 764.5 703.7 865.0 6.11 75.96 1.20 864.0 803.2 965.0 7.60 74.69 1.50 963.3 902.5 1065.0 8.68 70.93 1.20 1062.3 1001.5 1165.0 10.46 66.72 1.90 1160.9 1100.1 1265.0 11.29 59.84 1.54 1259.1 1198.3 1365.0 12.30 64.53 1.39 1357.0 1296.2 1465.0 14.11 65.99 1.85 1454.3 1393.5 1565.0 17.08 67.02 2.98 1550.6 1489.8 1665.0 19.27 67.70 2.20 1645.6 1584.8 1765.0 21.04 68.20 1.77 1739.5 1678.7 1865.0 23.69 68.63 2.66 1831.9 1771.1 1965.0 24.55 68.47 .86 1923.2 1862.4 2065.0 28.60 67.84 4.06 2012.6 1951.8 .3 .8 1.7 3.7 7.4 12.0 18.7 28.2 40.0 54.1 .4 96.2 .9 94.5 1.9 95.3 4.1 92.3 8.0 89.2 12.9 88.8 19.8 86.6 29.3 83.4 41.2 81.0 55.2 78.9 70.7 71.6 76.5 89.5 90.0 73.8 109.8 110.1 71.6 132.6 132.8 70.6 159.5 159.7 69.9 190.7 190.8 69.5 225.1 225.3 69.2 263.2 263.3 69.1 304.0 304.2 69.0 348.7 348.9 68.9 .04 S .35 E .07 S .90 E .18 S 1.90 E .17 S 4.10 E .11 N 7.96 E .27 N 12.92 E 1.17 N 19.75 E 3.37 N 29.11 E 6.41 N 40.66 E 10.62 N 54.17 E 16.68 N 69.64 E 25.18 N 86.44 i 34.68 N 104.52 E 44.22 N 125.27 E 54.91 N 149.93 E 66.91 N 178.72 E 79.84 N 210.65 E 93.82 N 246.02 E 108.77 N 284.06 E 125.42 N 325.55 E A G y r o d a t a D i r e c t i o na I Survey B.P. EXPLORATION WELL: NIAKUK NK-23 Location: POOL 7, PRUDHOE BAY UNIT Job Number: AK0494G215 NORTH SLOPE ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2165.0 32.20 67.73 2265.0 35.62 67.67 2365.0 39.00 67.95 2465.0 42.60 67.86 2565.0 45.03 67.88 3.60 2098.8 2038.0 3.42 2181.7 2120.9 3.39 2261.2 2200.4 3.59 2336.9 2276.1 2.43 2409.0 2348.2 399.3 455.1 515.7 581.0 650.2 399.4 68.8 455.2 68.7 515.8 68.6 581.1 68.5 650.3 68.4 144.55 N 372.37 E ' 165.71 N 423.96 E 188.58 N 480.07 ' ) 213.16 N 540.58 ~" 239.23 N 604.69 E 2665.0 48.16 67.63 2765.0 50.95 67.20 2865.0 52.98 66.68 2965.0 55.51 66.60 3065.0 58.03 66.62 3.14 2477.7 2416.9 2.81 2542.6 2481.8 2.07 2604.2 2543.4 2.52 2662.6 2601.8 2.52 2717.4 2656.6 722.8 798.9 877.6 958.8 1042.4 722.9 68.3 799.0 68.3 877.7 68.1 958.8 68.0 1042.4 67.9 266.73 N 671.91 E 295.96 N 742.15 E 326.81 N 814.61 E 358.98 N 889.09 E 392.18 N 965.84 E 3165.0 58.39 67.07 3265.0 58.88 67.22 3365.0 59.23 67.67 3465.0 59.80 67.62 3565.0 60.23 67.33 .52 2770.1 2709.3 .51 2822.1 2761.3 .52 2873.6 2812.8 .58 2924.3 2863.5 .49 2974.3 2913.5 1127.4 1212.7 1298.5 1384.7 1471.3 1127.4 67.8 1212.8 67.8 1298.6 67.8 1384.7 67.7 1471.3 67.7 425.60 N 458.76 N 491.65 N 524.43 N 557.62 N 1043.99 E 1122.67 E 1201.88 E 1281.58 E 1361.59 E 3665.0 60.07 66.48 3765.0 60.10 65.90 3865.0 59.36 64.87 3965.0 59.48 64.41 4065.0 60.46 64.25 · 75 3024.0 2963.2 · 50 3073.9 3013.1 · 16 3124.3 3063.5 .41 3175.2 3114.4 · 99 3225.2 '3164.4 1558.0 1644.7 1731.0 1817.0 1903.5 1558.1 67.7 1644.7 67.6 1731.0 67.5 1817.0 67.4 1903.5 67.2 591.64 N 626.64 N 662.61 N 699.48 N 736.98 N 1441.36 E 1520.66 ~ 1599.17 E 1676.97 E 1755.00 E 4265.0 60.02 64.37 4365.0 60.24 65.12 4465.0 59.97 66.77 4565.0 60.74 67.61 4665.0 61.24 68.43 · 23 3324.5 3263.7 · 69 3374.3 3313.5 .46 3424.2 3363.4 · 06 3473.6 3412.8 .88 3522.1 3461.3 2076.8 2163.5 2250.1 2337.0 2424.5 2076.9 67.0 2163.5 66.9 2250.2 66.9 2337.1 66.9 2424.5 66.9 812.24 N 849.23 N 884.56 N 918.25 N 950.99 N 1911.45 E 1989.88 E 2069.03 E 2149.14 E 2230.23 E A Gyro da t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: NIAKUK NK-23 Location: POOL 7, PRUDHOE BAY UNIT Job Number: AK0494G215 NORTH SLOPE ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 4'765.0 60.89 69.48 4865.0 61.00 69.95 4965.0 61.39 69.09 5065.0 60.26 68.74 5165.0 59.42 68.61 .98 .42 .85 .17 .85 3570.5 3509.7 3619.1 3558.3 3667.3 3606.5 3716.0 3655.2 3766.3 3705.5 2511.9 2599.3 2686.8 2774.1 2860.5 2512.0 67.0 2599.3 67.1 2686.8 67.1 2774.1 67.2 2860.5 67.2 982.41 N 2311.9 1012.71 N 2393.9 1043.37 N 2475.9 1074.78 N 2557 4 1106.22 N 2637.9 1 E 0 E 9 E 5265.0 58.64 67.81 5365.0 58.21 67.03 5465.0 58.25 66.39 5565.0 57.97 65.97 5665.0 58.58 65.27 .O3 .80 .54 .46 .85 3817.7 3756.9 3870.1 3809.3 3922.7 3861.9 3975.5 3914.7 4028.1 3967.3 2946.3 3031.5 3116.5 3201.4 3286.4 2946.3 67.3 3031.5 67.3 3116.5 67.3 3201.4 67.2 3286.4 67.2 1138.04 N 2717.6 1170.75 N 2796.2 1204.37 N 2874.3 1238.66 N 2952.0 1273.77 N 3029.5 0 E 7 E 6 E 3 E 0 E 5765.0 57.71 65.26 5865.0 58.24 65.11 5965.0 58.68 65.39 6065.0 59.26 65.44 6165.0 59.31 65.95 .87 .55 .50 .59 .44 4080.9 4020.1 4133.9 4073.1 4186.3 4125.5 4237.8 4177.0 4288.9 4228.1 3371.3 3456.0 3541.2 3626.8 3712.7 3371.3 67.1 3456.0 67.1 3541.2 67.1 3626.8 67.0 3712.8 67.0 1309.30 N 3106.6 1344.88 N 3183.5 1380.56 N 3260.9 1416.21 N 3338.9 1451.60 N 3417.2 4 E 9 E 9 E 1 E 6 E 6265.0 58.09 66.18 6365.0 58.52 66.66 6465.0 58.62 67.17 6565.0 59.01 68.04 6665.0 60.66 68.07 .23 .59 .45 .84 .64 4340.8 4280.0 4393.4 4332.6 4445.5 4384.7 4497.3 4436.5 4547.5 4486.7 3798.2 3883.2 3968.6 4054.1 4140.5 3798.2 67.0 3883.3 67.0 3968.6 67.0 4054.2 67.0 4140.6 67.0 1486.26 N 3495.3 1520.29 N 3573.3 1553.75 N 3651.8 1586.34 N 3730.9 1618.65 N 3811.1 6 E 4 3 E 3 E I E 6765.0 60.23 68.59 6865.0 60.90 68.90 6965.0 61.00 68.92 7065.0 60.99 68.94 7165.0 61.23 69.46 .62 .72 .10 .01 .52 4596.9 4536.1 4646.0 4585.2 4694 . 6 4633 . 8 4743 . 1 4682 . 3 4791.4 4730 . 6 4227.5 4314.6 4402.0 4489.4 4576.9 4227.6 67.0 4314.6 67.1' 4402.0 67.1 4489.4 67.1 4576.9 67.2 1650.77 N 3891.9 1682.34 N 3973.1 1713.80 N 4054.6 1745.24 N 4136.2 1776.33 N 4218.1 5 E 2 E 8 E 9 E 4 E A Gyrodat a Direct ional Survey I3. I~. I~]XP.Ii,ORATION WELL: NIAKUK NK- 23 Lecatien' POOL 7, PRUDHOE BAY UNIT Jeb Number: AK0494G215 NORTH SLOPE ALASKA Page HEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 7265.0 60.88 68.96 7365.0 60.73 68.67 7465.0 60.47 68.81 7565.0 59.35 68.69 7665.0 60.11 68.71 .56 .30 .29 .12 .75 4839.8 4779.0 4888.5 4827.7 4937.6 4876.8 4987.8 4927.0 5038.2 4977.4 4664.4 4664.4 67.2 4751.6 4751.6 67.2 4838.7 4838.7 67.3 4925.2 4925.2 67.3 5011.5 5011.5 67.3 1807.40 N 1838.94 N 1870.53 N 1901.90 N 1933.27 N 4299.95 E 4381.35 E 4462.54 ~ 4623 . 64 E 7765.0 58.77 69.00 7865.0 59.99 69.70 7965.0 60.30 69.34 8065.0 60.05 69.13 8165.0 60.56 68.68 .36 .35 .44 .31 .64 5089.0 5028.2 5139.9 5079.1 5189.7 5128.9 5239.5 5178.7 5289.0 5228.2 5097.6 5097.6 67.3 5183.6 5183.6 67.4 5270.3 5270.3 67.4 5357.0 5357.0 67.4 5443.8 5443.8 67.5 1964.33 N 1994.67 N 2025.02 N 2055.78 N 2087.05 N 4703.94 E 4784.47 E 4865.71 E 4946.83 E 5027.87 E 8265.0 59.89 68.68 8365.0 60.32 67.75 8465.0 60.70 67.87 8565.0 60.54 67.67 8665.0 61.22 68.05 .66 .91 .39 .24 .76 5338.7 5277.9 5388.5 5327.7 5437.7 5376.9 5486.8 5426.0 5535.4 5474.6 5530.6 5530.6 67.5 5617.3 5617.3 67.5 5704.3 5704.3 67.5 5791.4 5791.5 67.5 5878.8 5878.8 67.5 2118.60 N 2150.78 N 2183.66 N 2216.62 N 2249.54 N 5108.72 E 5189.22 E 5269.82 B 5350.48 E 5431.40 E 8765.0 60.30 67.81 8865.0 60.44 67.98 8965.0 61.22 68.00 9065.0 61.59 68.01 9165.0 62.04 67.18 .95 .20 .78 .37 .86 5584.3 5523.5 5633.7 5572.9 5682.5 5621.7 5730.3 5669.5 5777.5 5716.7 5966.0 5966.1 67.5 6053.0 6053.0 67.5 6140.3 6140.3 67.5 6228.1 6228.1 67.5 6316.2 6316.3 67.5 2282.32 N 2315.04 N 2347.76 N 2380.65 N 2414.24 N 5512.27 5592.80 5673.75 5755.17 5836.66 9265.0 61.70 66.72 9365.0 60.88 66.43 9465.0 60.84 66.01 9565.0 61.10 65.81 9665.0 60.06 65.93 .53 .86 .37 .31 1.04 5824.7 5763.9 5872.7 5811.9 5921.4 5860.6 5969.9 5909.1 6019.1 5958.3 6404.4 6404.4 67.5 6492.1 6492.1 6.7.5'" 6579.4 6579.5 67.5 6666.8 6666.9 67.5 6753.9 6753.9 67.4 2448.77 N 2483.64 N 2518.86 N 2554.55 N 2590.16 N 5917.81 E 5998.28 E 6078.21 E 6158.02 E 6237.51 E A Gyro da t a D i r e c t i o na i B.P. EXPLORATION WELL: NIAKUK NK-23 Location: POOL 7, PRUDHOE BAY UNIT Job Number: AK0494G215 NORTH SLOPE ALASKA Survey Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 9765.0 60.03 66.23 9865.0 60.03 66.25 9965.0 60.23 66.35 10065.0 60.49 66.83 10165.0 60.39 66.48 .26 .02 .21 .49 .31 6069.0 6008.2 6840 6119.0 6058.2 6927 6168.8 6108.0 7013 6218.2 6157.4 7100 6267.6 6206.8 7187 .5 6840.5 67.4 .1 6927.1 67.4 .8 7013.8 67.4 .7 7100.7 67.4 .7 7187.7 67.4 2625.29 N 6316.71 E 2660.20 N 6395.99 E 2695.06 N 6475.39 2729.59 N 6555.15 E 2764.06 N 6635.01 E 10265.0 60.98 66.39 10365.0 60.18 66.29 10465.0 59.85 66.45 10565.0 59.60 66.26 10665.0 61.19 66.79 .6O .81 .36 .29 .65 6316.5 6255.7 7274 6365.6 6304.8 7362 6415.6 6354.8 7448 6466.0 6405.2 7534 6515.4 6454.6 7621 .9 7274.9 67.4 .0 7362.0 67.4 .6 7448.6 67.3 .9 7534.9 67.3 .9 7621.9 67.3 2798.92 N 6714.94 E 2833.88 N 6794.71 E 2868.60 N 6874.06 E 2903.23 N 6953.17 E 2937.85 N 7032.92 E 10765.0 62.81 67.55 10865.0 62.29 67.57 10965.0 61.63 67.33 11065.0 62.10 67.21 11165.0 61.77 67.76 .75 .52 .69 .49 .59 6562.4 6501.6 7710 6608.5 6547.7 7798 6655.5 6594.7 7887 6702.6 6641.8 7975 6749.7 6688.9 8063 .2 7710.2 67.3 .9 7798.9 67.3 .1 7887.1 67.3 .3 7975.3 67.3 .6 8063.6 67.3 2972.11 N 7114.28 E 3005.98 N 7196.30 E 3039.82 N 7277.81 E 3073.89 N 7359.15 E 3107.69 N 7440.66 E 11265.0 61.13 68.05. 111365.0 60.80 68.28 11465.0 60.48 68.57 11565.0 60.68 68.41 11~65.0 60.19 67.24 .69 .39 .41 .25 .13 6797.5 6736.7 8151 6846.0 6785.2 8238 6895.0 6834.2 8326 6944.2 6883.4 8413 6993.5 6932.7 8500 .4 8151.4 67.3 .8 8238.8 67.3 .0 8326.0 67.4 .0 8413.0 67.4 .0 8500.0 67.4 3140.73 N 7522.05 F 3173.25 N 7603.20 = 3205.29 N 7684.25 E 3237.23 N 7765.29 E 3270.06 N 7845.83 E 11765.0 59.27 65.96 11865.0 59.68 65.57 11965.0 59.46 65.19 12065.0 59.28 64.69 12165.0 58.87 64.47 .44 .53 .40 .47 .45 7043.9 6983.1 8586.4 7094.7 7033.9 8672.5 7145.4 7084.6 8758.6 7196.3 7135.5 8844.6 7247.7 7186.9 8930.3 8586.4 67.4 8672.5 67.4 8758.6 67.3 8844.6 67.3 8930.3 67.3 3304.36 N 7925.09 E 3339.71 N 8003.63 E 3375.62 N 8082.02 E 3412.07 N 8159.97 E 3448.89 N 8237.45 E A Gyro da t a D i r e c t i o n a B.P. EXPLORATION WELL: NIAKUK NK-23 Locatien: POOL 7, PRUDHOE BAY UNIT Jeb Number: AK0494G215 NORTH SLOPE ALASKA 1 Survey Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. HORIZONTAL C O O R D I N A T E S feet 12265.0 59.13 63.87 1_2365.0 60.28 63.38 12465.0 59.48 62.92 12565.0 59.90 62.87 12665.0 59.71 62.99 12765.0 59.63 63.33 12865.0 59.64 63.55 12965.0 59.84 63.56 13065.0 59.59 63.58 13165.0 59.51 63.47 .58 1.23 .89 .42 .22 .30 .18 .20 .25 .12 7299.2 7238.4 7349 . 7 7288 . 9 7399 . 8 7339 . 0 7450.3 7389.5 7500 . 6 7439 . 8 7551.i 7490.3 7601.7 7540.9 7652.0 7591.2 7702.5 7641.7 7753.1 7692.3 9015.9 9015.9 67.3 9102.1 9102.1 67.2 9188.3 9188.3 67.2 9274.4 9274.4 67.1 9360.6 9360.6 67.1 9446.7 9446.7 67.1 9532.7 9532.9 67.0 9618.9 9619.1 67.0 9705.1 9705.3 67.0 9791.1 9791.3 66.9 3486.24 N 8314.60 E 3524.60 N 8391.95 E 3563.66 N 8469.12 3602.99 N 8545.97 m' 3642.33 N 8 22.93 E 3681.29 N 8~ 99.94 E 3719.87 N 8' 77.12 E 3758.34 N 8[ 54.46 E 3796.78 N 8.~ 31.78 E 3835.22 N 9{ }8.95 E 13265.0 59.08 63.77 13365.0 58.82 63.84 13465.0 58.91 63.75 13565.0 58.40 63.85 13665.0 58.10 63.84 .50 .27 .12 .52 .30 7804.2 7743.4 7855.8 7795.0 7907.5 7846.7 7959.5 7898.7 8012.1 7951.3 9876.9 9877.2 66.9 9962.4 9962.7 66.9 10047.9 10048.2 66.9 10133.1 10133.5 66.8 10218.0 10218.4 66.8 3873.41 N 9035.97 E 3911.23 N 91i2.85 E 3949.02 N 92 19.64 E 3986.73 N 93 .6.27 E 4024.21 N 93 '2.60 E 13765.0 57.74 63.37 13865.0 57.58 63.24 13965.0' 57.47 63.66 14065.0 58.37 64.08 14165.0 59.88 64.43 .53 .19 .37 .97 .54 8065.3 8004.5 8118.8 8058.0 8172.5 8111.7 8225.6 8164.8 8276.9 8216.1 10302.5 10303.0 66.8 10386.8 10387.3 66.8 10471.0 10471.5 66.7 10555.6 10556.1 66.7 10641.3 10641.9 66.7 4061.87 N 94, 8.49 F. 4099 83 N 95. 3 97 ..... 4137.53 N 96: 9.44 E 4174.85 N 96.~ 5.50 E 4212.13 N 97~2.80 E 14265.0 60.93 65.68 14339.0 60.84 64.95 1.51 8326.3 .88 8362.3 8265.5 10728.1 10728.8 66.7 8301.5 10792.8 10793.4 66.7 4248.79 N 98[ 1.64 E 4275.79 N 991 }.38 E Final Station Closure: Distance: 10793.43 ft Az: 66.66 deg. A Gyro da t a D i r e c t i on a i Survey B.P. EXPLORATION WELL: NIAKUK NK-23 Location: POOL 7, PRUDHOE BAY UNIT Job Number: AK0494G215SS NORTH SLOPE ALASKA MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. 0.0 0.00 0.00 0.00 0.0 -60.8 0 - 14339 FT. GYRO SURVEY RUN IN 5" DRILLPIPE. MEASURED DEPTHS REFERENCED TO POOL RIG 7 R.K.B. 0.0 0.0 0.0 Pa re HOR I Z ONT .~L COORD I NA~ ES feet 0.00 N ).00 E 1.60.8 .24 93.74 .15 160.8 100.0 260.8 .37 91.87 .14 260.8 200.0 360.8 76 97.95 .39 360.8 300.0 460.8 1.72 86.46 .99 460.8 400.0 560.9 2.64 85.93 .92 560.8 500.0 661.0 3.00 89.89 .42 660.8 600.0 761.3 4.86 78.29 2.02 760.8 700.0 861.7 6.07 76.02 1.23 860.8 800.0 962.5 7.57 74.72 1.49 960.8 900.0 1063.5 8.67 70.99 1.21 1060.8 1000.0 1164.9 10.45 66.72 1.90 1160.8 1100.0 1266.7 11.31 59.92 1.54 1260.8 1200.0 1368.9 12.37 64.58 1.40 1360.8 1300.0 1471.7 14.31 66.06 1.92 1460.8 1400.0 1575.7 17.32 67.09 2.90 1560.8 1500.0 1681.2 19.56 67.78 2.13 1660.8 1600.0 1788.1 21.65 68.30 1.98 1760.8 1700.0 1896.6 23.96 .68.58 2.09 1860.8 1800.0 2007.1 26.25 68.20 2.21 1960.8 1900.0 2120.9 30.61 67.78 3.80 2060.8 2000.0 .3 .8 1.6 3.6 7.2 11.8 18.4 27.8 39.7 53.9 .4 93.7 .9 94.6 1.9 95.3 4.1 92.4 8.0 89.3 12.9 88.8 19.8 86.7 29.3 83.5 41.2 81.1 55.2 78.9 70.7 71.6 76.5 89.8 110.1 73.7 110.7 132.8 71.6 134.4 159.7 70.5 162.8 190.8 69.8 196.3 225.3 69.4 233.9 263.3 69.2 276.1 304.2 69.1 322.8 348.9 69.0 377.0 399.4 68.8 .04 S .35 E .07 S .88 E .17 S . .86 E .17 S ~ .01 E .11 N '.81 E .27 N 11 .73 E 1.14 N 1~ .50 E 3.30 N 21 .81 E 6.33 N 4, .36 E 10.56 N 51 .97 E 16.67 N 6 .63 N 25.34 N 8 .76 35.05 N 10 .33 E 44.94 N 12 .92 E 56.20 N 15 .01 E 69.00 N 18 .89 E 83.06 N 21 .81 E 98.55 N 25 .06 E 115.78 N 30 .51 E 136.12 N 35 .74 E A Gyroda t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: NIAKUK NK-23 Location: POOL 7, PRUDHOE BAY UNIT Job Number: AK0494G215SS NORTH SLOPE ALASKA Page MEASURED I N C L AZIMUTH DEPTH [.=.et. dog dog DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2239.8 34.76 67.69 2364.4 38.99 67.94 2498.1 43.40 67.86 2640.3 47.39 67.69 2794.6 51.55 67.05 . 3. 3. 2. 2. 46 39 21 96 59 2160.8 2100.0 441 2260.8 2200.0 515 2360.8 2300.0 603 2460.8 2400.0 704 2560.8 2500.0 822 .0 455.2 68.7 .3 515.8 68.6 .9 650.3 68.5 .9 722.9 68.4 .2 877.7 68.2 160.37 N 410.94 E 188.46 N 479.76 E 221.79 N 561.82 259.95 N 655.33 = 305.08 N 763.57 E 2961.9 55.43 66.61 3147.4 58.32 66.99 3340.2 59.14 67.56 3538.1 60.11 67.40 3738.7 60.09 66.05 51 87 52 51 57 2660.8 2600.0 956 2760.8 2700.0 1112 2860.8 2800.0 1277 2960.8 2900.0 1448 3060.8 3000.0 1621 .2 958.8 68.0 .4 1127.4 67.8 .2 1298.6 67.8 .0 1471.3 67.7 .9 1644.7 67.6 357.99 N 886.78 E 419.70 N 1030.22 E 483.49 N 1182.23 E 548.68 N 1340.04 E 617.45 N 1499.84 E 3936.7 59.45 64.54 4136.7 60.30 64.29 4337 . 9 60 . 18 64 . 92 4539.1 60.54 67.39 4744 . 9 60 . 96 69 . 27 62 71 56 16 96 3160.8 3100.0 1792 3260.8 3200.0 1965 3360.8 3300.0 2139 3460.8 3400.0 2314 3560.8 3500.0 2494 .7 1817.0 67.4 .6 2076.9 67.1 .9 2163.5 66.9 .5 2337.1 66.9 .4 2512.0 67.0 689.06 N 763.94 N 839.19 N 909.52 N 976.10 N 1654.98 E 1811.05 E 1968.59 E 2128.37 E 2295.51 E 4951.6 61.34 69.20 5154.1 59.51 68.63 5347.3 58.29 67.17 5537.1 58.05 66.09 5726.9 58.04 65.27 .79 .88 .84 .48 .86 3660.8 3600.0 2675 3760.8 3700.0 2851 3860.8 3800.0 3016 3960.8 3900.0 3177 4060.8 4000.0 3338 .1 2686.8 67.1 .2 2860.5 67.2 .4 3031.5 67.3 .7 3201.4 67.2 .9 3371.3 67.2 1039.26 N 1102.81 N 1164.96 N 1229.09 N 1295.76 N 2464.96 E 2629 . 25 ..... ]1 2782.34 E 2930.35 E 3077.24 E 5916.3 58.47 65.26 6110.0 59.28 65.67 6303.0 58.26 66.36 6494.5 58.74 67.43 6691.9 60.54 68.21 52 52 99 56 37 4160.8 4100.0 3499.7 4260.8 4200.0 3665.5 4360.8 4300.0 3830.5 4460.8 4400.0 3993.8 4560.8 4500.0 4163.9 3541.2 67.1 3712.8 67.0 3883.3 67.0 4054.2 67.0 4227.6 67.0 1363.20 N 1432.14 N 1499.20 N 1563.38 N 1627.29 N 3223.32 E 3374.19 E 3525.00 E 3675.19 E 3832.86 E A Gyro d a t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: NIAKUK NK-23 Location. POOL 7, PRUDHOE BAY UNIT Job Number: AK0494G215SS NORTH SLOPE ALASKA Page MEASURED I N C L AZIMUTH DEPTH feet deg. deg. DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 6895.5 60.93 68.91 7101.7 61.08 69.13 7308.1 60.82 68.84 7511.2 59.95 68.75 7709.5 59.51 68.84 .53 .20 .45 .67 .02 4660.8 4600.0 4760.8 4700.0 4860.8 4800.0 4960.8 4900.0 5060.8 5000.0 4341.2 4402.0 67.1 4521.5 4576.9 67.1 4702.0 4751.6 67.2 4878.7 4925.2 67.3 5049.9 5097.6 67.3 1691.93 N 3997.97 E 1756.66 N 4166.36 E 1821.01 N 4335.07 1885.03 N 4499.82 m 1947.10 N 4659.40 E 7906.9 60.12 69.55 8108.1 60.27 68.93 8309.4 60.08 68.27 8512.1 60.62 67.78 8716.9, 60.75 67.93 .97 .45 .77 .32 .86 5160.8 5100.0 5260.8 5200.0 5360 . 8 53,00 . 0 5460 . 8 5400 . 0 5560.8 5500.0 5219.9 5270.3 67.4 5394.4 5443.8 67.4 5569.1 5617.3 67.5 5745.3 5791.5 67.5 5924.1 5966.1 67.5 2007.39 N 2069.25 N 2132.90 N 2199.16 N 2266.56 N 4818.52 E 4981.74 E 5144 . 49 E 5307.77 E 5473.39 E 8920.6 60.88 67.99 9129.6 61.88 67.48 9340.2 61.08 66.50 9546.2 61.05 65.85 9748.6 60.03 66.18 .52 .68 .78 .32 .39 5660.8 5600.0 5760.8 5700.0 5860.8 5800.0 5960.8 5900.0 6060.8 6000.0 6101.5 6140.3 67.5 6285.0 6316.3 67.5 6470.3 6492.1 67.5 6650.4 6666.9 67.5 6826.3 6840.5 67.4 2333.22 N 2402.34 N 2474.99 N 2547.83 N 2619.52 N 5637.78 E 5807.78 E 5978.33 E 6142.98 E 6303.69 E 9949.0 60.20 66.33 10151.3 60.40 66.53 10355.2 60.26 66.30 10554.6 59.63 66.28 10761.6 62.75 67.52 .18 .34 .79 .30 .75 6160.8 6100.0 6260.8 6200.0 6360.8 6300.0 6460.8 6400.0 6560.8 6500.0 7000.0 7013.8 67.4 7175.8 7187.7 67.4 7353.4 7362.0 67.4 7526.0 7534.9 67.3 7707.2 7710.2 67.3 2689.48 N 2759.34 N 2830.44 N 2899.63 N 2970.96 N 6462.69 F 6624.08. 6786.87 E 6944.96 E 7111.55 E 10976.3 61.68 67.32 11188.2 61.62 67.82 11395.1 60.70 68.37 11598.7 60.51 68.01 11798.2 59.40 65.83 .67 .61 .39 .54 1.14 6660.8 6600.0 6760.8 6700.0 6860.8 6800.0 6960.8 6900.0 7060.8 7000.0 7897.1 7975.3 67.3 8084.0 8151.4 67.3 8265.1 8326.0 67.3 8442.4 8500.0 67.4 8615.0 8672.5 67.4 3043.66 N 3115.37 N 3182.91 N 3248.30 N 3316.11 N 7286.98 E 7459.58 E 7627.64 E 7792.43 E 7951.19 E A Gyr oda t a Di r e c t i ona i Survey B.P. EXPLORATION WELL: NIAKUK NK-23 Location: POOL 7, PRUDHOE BAY UNIT Job Number: AK0494G215SS NORTH SLOPE ALASKA Page MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet £eet cLosuRE H 0 R I Z O N T A L DIST. AZIMUTH C O O R D I N A T E S feet deg. feet 11995.3 59.40 65.04 .42 12190.4 58.94: 64:.32 .48 1238'7.2 60.10 63.28 1.15 12585.9 59.86 62.89 .38 12784.2 59.63 63.37 .28 7160.8 7100 7260.8 7200 7360.8 7300 7460.8 7400 7560.8 7500 .0 .0 .0 .0 .0 8784.7 8952.1 9121.2 9292.4 9463.2 8844.6 67.3 9015.9 67.3 9188.3 67.2 9360.6 67.1 9532.9 67.1 3386.66 N 8105.63 E 3458.38 N 8257.06 E 3533.28 N 8409.09 3611.20 N 8562.02 E 3688.69 N 8714.74 E 12982.4 59.80 63.56 .21 13180.0 59.44 63.52 .18 13374.7 58.83 63.83 .25 13567.4 58.39 63.85 .51 13756.6 57.77 63.41 .51 7660.8 7600 7760.8 7700 7860.8 7800 7960.8 7900 8060.8 8000 .0 .0 .0 .0 .0 9633.9 9804.0 9970.7 10135.2 10295.4 9705.3 67.0 9877.2 66.9 10048.2 66.9 10218.4 66.8 10303.0 66.8 3765.02 N 8867.89 E 3840.94 N 9020.49 E 3914.88 N 9170.28 E 3987.63 N 9318.12 E 4058.71 N 9462.11 E 13943.3 57.49 63.57 .33 14133.7 59.41 64.32 1.36 14336.0 60.84 64.98 .90 14339.0 60.84 64.95 .88 8160.8 8100 8260.8 8200 8360.8 8300 8362.3 8301 .0 .0 .0 .5 10452.7 10614.4 10790.1 10792.8 10471.5 66.7 10641.9 66.7 10793.4 66.7 10793.4 66.7 4129.35 N 9603.05 E 4200.44 N 9748.57 E 4274.69 N 9907.98 E 4275.79 N 9910.38 E Final Station Closure: Distance: 10793.43 ft Az: 66.66 deg. 8. '1::'~, -17 X P'J, O'IR, A. 7' f 0 N W.l.z.,.ll~" N J. AJ:{_U'K NK .... 3o" ''''~ "'<' PRUDHOE L o .., a.'ti o n P 0 0 L '7, BAY UNIT NORTH SLOPE ALASKA AKO494G215 DEFINITIVE 1900,0 2900,0 3900,0 4900,0 5900,0 6900,0 7900,0 8900,0 9900,0 EASTIN6 BAY UNIT NORTN SLOPE ALASKA AK0494G215 DEFINITIVE O) 4,0 ?,0 0,0 i000,0 2000,0 3000,0 4000,0 SO00,O 6000,0 7000,0 8000,0 9000,0 10000,0 11000,0 laO00,O 13000,0 14000,0 FIEASURED DEPTH (¢l:;) bO00,O i;7 7?_,0 8AY UNIT NOR.EH SLOt E ALASKA AK0494G2 15 DEFINITIVE I--1U:TR " ......... UN 'PSINIS / I000,0 1800,0 I400,0 1600,0 1800,0 8000,0 8800,0 8400,0 8600,0 8800,0 3000,0 3800,0 3400,0 3600,0 HEASUFRED DEPTH i1 1~/~I ,.l',[,' ]>,I-]iAKUI( NI<- 33 .I..,o <...: a L:i. o :L'~' P 00 L 7, PlqUD H O E BAY UNIT NORTH SLOPE ALASKA AK0494G215 DEFINITIVE 50,0 0,0 1000,0 8000,0 3000,0 4000,0 5000,0 6000,0 7000,0 8000,0 9000,0 10000,0 11000,0 1~000,0 13000,0 14000,0 15000,0 MEASURED ]?EPTH (£-t:) WELL' NIAKUK NK- 23 65,o Location' POOL 79 PRUDHOE BAY UNIT NORTH SLOPE ALASKA AKO494G215 DEFINITIVE 55,0 40,0 2! 30,0 l(~ ~ 5 '0 --? ..~ " ~x'x'"""x'x ~lt'j ' ' 2~.M~/ I'~'U Y I~ U N BB'INT'3........ I I I I ' I ' I ] 000 , 0 1 ~ 00 ,0 ] ~ 00 I 0 160010 1800'0 ~000'0 ~00,0 ~400,0 ~600'0 ~800,0 3000'0 3~00'0 3400,0 MEASURED DEPTH (9-h) 3600,0 6S,0 60,0 55,0 aSlO 30,0 85,0 ~0,0 W.I:?,LL' ~X]AKUK NK-33 Locatjon' ?OOL :7: ?RUD~OS BAY UNIT NORTH SLOPE ALASKA AK0494G315 DEFINITIVE 3000,0 4000,0 5000,0 6000,0 7000,0 8000,0 MEASURE']3 3EPTH (~'t) 9000,0 lOOOO,O llO00,O 1~000,0 13000,0 14OO0,O 15000,0 lit .' liP. E.Ni P L O iR A? I O N WELL: NIAI{UK NK- 28 I.,ocat, ion' POOL ?~ PRUDHOE BAY UNIT NORTH SLOPE ALASKA AKO494G2 15 DEFINITIVE (L .. · 60,0 20,0 0,0 1000,0 2000,0 3000,0 4000,0 $000,0 6000,0 7000,0 8000,0 9000,0 H~ASURED DEPTH (fl) 10000,0 11000,0 12000,0 13000,0 14000,0 15000,0 Quality Centrel Cemparisons B.P. EXPLORATION WELL: NIAKUK NK-23 Lecation: POOL 7, PRUDHOE BAY UNIT NORTH SLOPE ALASKA Job Number : AK0494G215 / AK0494G215 INRUN/OUTRUN Cemparisen INRUN OUTRUN Depth Inc Inc Delta 565.0 0.00 2.68 -2.677 1065.0 8.09 8.68 -.594 1565.0 15.43 17.08 -1.659 2065.0 26.41 28.60 -2.190 2565.0 43.38 45.03 -1.648 3065.0 56.70 58.03 -1.329 3565.0 60.21 60.23 -.018 INRUN Az 0.00 73.89 67.14 70.01 70.62 71.54 71.57 For Inclinations Greater than 10 degrees: Average Inclination Difference = -1.368 deg. Average Azimuth Difference = .80321 deg. OUTRUN Az 86.07 71.15 66.35 68.82 70.88 69.13 71.67 Delta -86.070 2.731 .786 1.187 -.259 2.408 -.107 WELL: NIAKU'K' NK-23 000000000000 165.00 14339.00 B.P. EXPLORATION AK0494G215 BP EXPLORATION 04494 G 0.00 MINIMUM CURVATURE .. B.P. EXPLORATION PRUDHOE BAY UNIT NORTH SLOPE ALASKA GYRO MULTISHOT OUT-RUN 165 000 265 000 365 000 465 000 565 000 665 000 765 000 865 000 965 000 il. 0 6 5 0 0 0 .i. 165 000 1265 000 1365 000 1465 000 1565 000 1665 000 1765 000 1865 000 1965 000 2065 000 21.65 000 2265 000 2365 000 2465 000 2565 000 2665 000 2765 000 2865 000 2965 000 3065 000 3165 000 3265 000 3365 000 3465 000 3565 000 3665 000 3765 000 3865 000 3965 000 4065 000 4265 000 248 38O 773 1 761 2 677 3 016 4 926 6 110 7 604 8 685 10 455 11 291 12 295 14 112 17 084 19 272 21 036 23 692 24 548 28 601 32 200 35 618 39 004 42 596 45 027 48 160 50 951 52 984 55 505 58 026 58 388 58 880 59 231 59 804 60 229 60 074 60 098 59 358 59 480 60 457 60 016 96 187 91 684 98 226 85 945 85 933 90 054 77 832 75 956 74 691 70 930 '66 718 59 841 64 527 65 986 67 019 67 700 68 203 68 626 68 468 67 838 67 733 67 672 67 946 67 858 67 876 67 625 67 201 66 677 66 603 66 625 67 068 67 224 67 672 67 615 67 327 66 476 65 900 64 867 64 414 64 252 64 370 4/24/94 4365 000 ':1<105 0()0 4565 000 4665 000 4765 000 4865 000 4965 000 5065 000 5165 000 5265 000 5365 000 5465 000 5565 000 5665 000 5765 000 5865 000 5965 000 6065 000 6165.000 6265 000 6365 000 6465 000 6565 000 6665 000 6765 000 6865 000 6965 000 7065 000 7165 000 7265 000 'I,3(~5 000 7465 000 7565 000 7665 000 7765 000 7865 000 7965 000 8065 000 8165 000 8265 000 8365 000 8465 000 8565 000 8665 000 8765 000 60 241 59 968 60 737 61. 237 60 887 60 995 61 391 60 261 59 420 58 643 58 209 58 254 57 966 58 576 57 706 58 242 58 677 59 265 59 307 58 091 58 522 58 619 59 014 60 655 60 231 60 897 60 999 60 992 61 232 60 883 60 729 60 469 59 352 60 107 58 774 59 986 60 300 60 049 60 555 59 893 60 324 60 701 60 535 61 224 60 302 65 122 66 773 67 605 68 430 69 482 69 949 69 089 68 742 68 611 67 815 67 026 66 390 65 968 65 275 65 261 65 109 65 394 65 438 65 949 66 184 66 660 67 169 68 037 68 072 68 590 68 899 68 922 68 937 69 459 68 962 68 669 68 808 68 687 68 711 69 002 69 699 69 336 69 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265 787 549 569 335 209 757 049 28O 575 4O5 235 964 575 195 686 473 865 380 924 868 993 333 546 558 576 474 774 13365 000 13465 000 13565 000 13665 000 13765 000 13865 000 13965 000 14065 000 14165 000 14265 000 14339 000 58 817 58 909 58 399 58 096 57 736 57 577 57 469 58 367 59 883 60 932 60 838 63 838 63 751 63 855 63 835 63 374 63 240 63 657 64 081 64 426 65 681 64 947 PRUDHOE BAY UNIT NORTH SLOPE ALASKA 240494 FMT=' (11 { (Fl0.2} ,2X)} ' 165 00 265 00 365 00 465 00 565 00 665 00 765 00 865 00 965 00 1065 00 1165 00 1265 00 1365 00 1465 00 1565 00 1665 00 1765 00 1865 00 1965 00 2065 00 2165 00 2265 00 2365 00 2465 00 2565 00 2665 00 2765 00 2865 00 2965 00 3065 00 3165 00 3265 00 3365 00 3465 00 3565 00 '3665 00 3765 00 3865 00 3965 00 4065 00 4265 00 4365 00 25 38 77 1 76 2 68 3 02 4 93 6 11 7 6O 8 68 10 46 11 29 12 30 14 11 17 08 19 27 21 04 23 69 24 55 28 60 32 20 35 62 39 00 42 60 45 03 48 16 50 95 52 98 55 51 58 03 58 39 58 88 59 23 59 8O 60 23 60 07 60 10 59 36 59 48 60 46 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133.47 160.66 74.73 307.86 82.80 198.48 203.34 303.57 248.03 293 17 235 09 204 26 162 94 142 24 249 97 241 61 216 44 109 35 182 74 156 91 134 48 131 61 111 60 337 06 295 94 146 34 179 71 123 83 116 04 94 94 144 01 34.79 152 10 125 37 259 63 120 43 142 11 146 55 139 77 72.44 194.97 92.36 76 21 76 22 76 22 76 22 76 23 76 23 76 24 76 24 76 24 76 24 76.26 76 26 76 27 76 27 76 28 76 28 76 29 76 29 76 30 76 30 76 30 76 31 76 31 76 31 76 33 76 32 76 32 76 34 76 34 76.34 76 36 76 36 76 36 76 37 76 38 76 38 76 38 76 38 76 39 76 40 76 40 76 42 4465 O0 4565 O0 4665 O0 4765 O0 4865 O0 4965 O0 5065 O0 5165 O0 5265 O0 5365 O0 5465 O0 5565 O0 5665 O0 5765 O0 5865 O0 5965 O0 6065.00 6165 O0 6265 O0 6465 O0 6565 O0 6665 00 6765 O0 6865 O0 6965 O0 7065 O0 7165 O0 7265 O0 7365 O0 7465 O0 7565 O0 7665 O0 7765 O0 7865 O0 7965 O0 8065 O0 8165 O0 8265 O0 8365 O0 8465 O0 8565 O0 8665 O0 8765 O0 8865 O0 59 97 60 74 61 24 60 89 61.00 61.39 60 26 59 42 58 64 58 21 58 25 57 97 58 58 57 71 58.24 58 68 59 26 59 31 58 09 ri8 ~2 58 62 59 O1 60 66 60 23 60 90 61 O0 60 99 61 23 60 88 60 73 60 47 59 35 60 11 58 77 59 99 6O 3O 60 05 60 56 59 89 60 32 60 70 60 54 61 22 60 30 60 44 66 77 -5642 50 9650.50 67 61 -9229 O0 -6450.00 68 43 10457 50 4142.50 69 48 -5912 O0 -9464.50 69 95 -7115 50 -8613.50 69 09 10056 50 5022.00 68 74 10256 O0 4462.50 68 61 -4118 50 10323.00 67 81 -5831 O0 -9426.50 67 03 -6716 50 -8672 50 66 39 -7314 O0 -8247 50 65 97 11050 50 -469 O0 65 27 -2393 O0 10825 O0 65 26 10644 O0 2954 50 65 11 -1695 50 10875 O0 65 39 -4933 O0 -9896 50 65 44 10821 O0 -2818 50 65 95 -4741 50 10062 O0 66 18 -7260 O0 -8366 O0 66 66 -3040 O0 10741 50 67 17 -4745 50 -9957 O0 68 04 -6710 O0 -8819 O0 68 07 -1747 O0 11027 50 68 59 -7219 O0 -8403 O0 68 90 10867.00 -3024 O0 68 92 10276.00 4603.00 68.94 -9629.50 -5830.50 69.46 -9541.50 -5943.00 68.96 10258.50 4581.50 68.67 -9705.50 -5489.00 68.81 -5904.00 -9560.50 68.69 -9470.00 -5828.00 68.71 -8827 O0 -6762.50 69 O0 10968 50 -1610.50 69 70 -6954 50 -8716.00 69 34 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53 67 43 91 78 47 44 38 58 96 87 57 12 76 26 71 22 83 73 14 13 70 15 24 15 13 34 05 46 11 44 11 39 87 13 69 12 80 19 96 13 77 128 96 15 06 16 89 21 34 92 55 64 47 51 97 125 88 22 70 50 58 14 22 136 13 18 40 14.99 19 96 108 60 27 71 17 75 20 04 32 84 17 24 37 02 25.86 23.34 17.66 11.39 70.82 11.51 21.16 93.85 30 20 125 08 291 70 148 13 140 57 63 36 66 39 158 34 148 38 142 37 138 57 92 44 12 41 285 58 171 18 153 61 104 67 25 13 139 18 164 27 154 62 142 86 8 96 139 47 105 62 65 77 121.31 122.04 294.17 119.61 148.42 121.73 127.59 98.39 141.55 116.21 128.66 106.81 74.04 138.26 123 12 302 33 27 O0 47.64 107.72 76 41 76 43 76 44 76 45 76 46 76 47 76 47 76 47 76 48 76 48 76 50 76 50 76 50 76 51 76 53 76 53 76 54 76 55 76 55 76 55 76 57 76 57 76 57 76 57 76 59 76 60 76 60 76 62 76 62 76 63 76 63 76 63 76 64 76 66 76 66 76 67 76 69 76 69 76 70 76 70 76 71 76 73 76 72 76 73 76.73 8~>¥5 O0 9065 O0 9165 O0 9265 O0 9365 O0 9465 O0 9565 O0 9665 O0 9765 O0 9865 O0 9965 O0 10065 O0 10165 O0 10265 O0 10365 O0 10465 O0 1O568 O0 10665 O0 10765 O0 10865 O0 10965 O0 11065 O0 11165 O0 11265 O0 11365 O0 11465 O0 11565 O0 11665 O0 11765 O0 11865 O0 11965 O0 12065 O0 12165 O0 12265 O0 12365 O0 12465 O0 12565 O0 12665 O0 12765 O0 12865 O0 12965 O0 13065 O0 13165 O0 13265 O0 13365 O0 61 22 61 59 62 04 61 70 60 88 60 84 61. 10 60 06 60 03 60 03 60 23 60 49 60 39 60 98 60 18 59 85 59 60 61 19 62 81 62 29 61 63 62 10 61 77 61 13 6O 8O 60 48 60 68 60 19 59 27 59 68 59 46 59 28 58 87 59 13 60 28 59 48 59 90 59 71 59 63 59 64 59 84 59 59 59 51 59 08 58 82 68 O0 10355 50 -4438.50 68 O1 10722 O0 -3534.50 67 18 11256 50 -1357.00 66 72 11193 50 1644.50 66 43 -9283 O0 6484.50 66 O1 -2283 50 10971.00 65 81 11335 O0 480.50 65 93 -2139 50 10922.00 66 23 10241 50 -4544.50 66 25 -7379 O0 -8354.50 66 35 -9694 50 -5624.50 66 83 607 50 11191.50 66 48 1440 50 11053.50 66 39 4104 O0 10351.50 66 29 -3981 O0 10415.50 66 45 -2420 50 10929.50 66 26 -3541 00 10557.00 66 79 7917 50 8018.50 67 55 11226 O0 1897.00 67 57 4669 50 10363.50 67 33 -1562 00 11076.00 67 21 10165 50 -5124.00 67.76 -8575 68.05 -1491 68.28 6212 68.57 -1905 68.41 -4158 67.24 -8037 65 96 724 50 7384.00 50 11150.50 50 9285.50 O0 10923.50 50 10444.00 00 7774.50 00 11159.50 65 57 6853 O0 -8967.50 65 19 947 O0 11096.00 64 69 -7997 O0 7763.00 64 47 -6679 50 8876.00 63 87 8618 O0 -7118.50 63 38 11265 50 18.00 62 92 -2025 O0 10946.50 62 87 -8573 O0 7284.50 62 99 10556 50 3977.00 63 33 -2328 O0 10894.50 63 55 8278 O0 7548.50 63 56 9558 50 -5906.00 63 58 11002 O0 -2570.00 63 47 -6750 O0 -8876.00 63 77 -9542 50 5696.00 63 84 -5471 O0 -9767.50 18 75 24 19 15 51 15 98 25 88 8 36 42 52 32 32 12 11 18 30 19.43 15 61 15 66 28 37 42 43 29 78 11 18 14 90 8 33 65.36 22.16 13.58 4.51 8.80 40 15 26 33 64 61 8 39 36 68 21 66 6 76 6 20 22 29 7 11 17 12 15 07 13 12 16 81 7 11 16 68 41 68 52 98 6 80 53.54 34.35 16 14 16 79 12 75 24 82 19 94 12 84 42 09 36 72 7 75 17 29 21 46 52 97 24 93 20 96 6 30 12 52 17 73 41 08 21 22 29 O0 5 13 47 30 9 97 15 13 8 57 22 17 198 94 10 82 49 72 70 73 23 74 12 84 18 O0 25 11 2 18 15 94 13 59 9 O0 11 O0 12 78 27 70 36 62 6 39 96 57 36 20 53 19 44 09 50 11 44 68 116 29 83 42 130 67 117 07 59 82 48 15 51 96 52 76 48 95 86 64 59 95 63 79 46 43 66 12 40 46 89 57 50 08 64 76 43 22 38 73 62 76 51 53 131 94 62 86 52 19 74 20 51 40 42 54 43 34 50 56 48 68 39 67 48 78 52 09 40 23 42.93 49.98 50.05 36.79 250.82 76.10 12 41 13 47 28 51 24 05 51 19 13 12 67.30 58.37 32.68 10.85 20.12 28.46 14.77 117 68 18 89 34 31 14 48 70 86 19 O1 51 46 12 08 46 15 17 78 11 41 52 72 24 80 381 80 17 21 28 22 62 66 19 92 10 88 20 62 80 31 16 61 16 10 41 79 21 91 14 20 13 89 32 98 89 91 11 81 243 76 64 86 113 30 108 33 96 91 81 60 54 94 168 30 87 56 168 97 114 03 138 68 120 24 183 09 187 39 338 47 159 17 167 57 161 54 315 50 80 36 204 15 172 O1 116 86 49 14 7 58 326 34 170 15 158 38 45 82 183 69 217 26 184 86 45 71 36 83 230 31 89 91 169 57 49 51 69 27 167 99 312 50 238.17 103.21 142.88 59.05 150.86 76 75 76 76 76 77 76 79 76 80 76 80 76 81 76 81 76 82 76 83 76 84 76 86 76 87 76 86 76 88 76 89 76 89 76 89 76 91 76 92 76 92 76 92 76 93 76 94 76 93 76 95 76 96 76 96 76 97 76 98 76 97 76 99 76 98 76 99 76 99 77 O1 77 O0 77 O1 77 O0 77 02 77.01 77.02 77.02 77.02 77.02 13465 O0 13565 O0 136¥5 O0 13765 O0 13865 O0 13965 O0 14065 O0 14165 O0 14265 O0 14339 O0 58 91 58 40 58 10 57 74 57 58 57 47 58 37 59 88 60 93 60 84 63.75 -6539 O0 8968 50 63.85 2459 O0 10739 50 63.84 11120 O0 770 50 63.37 10801 O0 2066 50 63.24 -3623 O0 10355 O0 63.66 -680 50 11034 O0 64.08 -8326 50 -7326 O0 64.43 11222 50 -483 50 65.68 10629 50 -3755 50 64.95 1790 O0 11110 50 17 21 22 06 34 86 57 71 27 62 131 09 12 88 35 76 13 17 11 33 64 63 33 11 38 94 33 30 81 77 91 51 8 28 1 O0 9 53 9 43 94 19 77 74 101 28 124 56 67 32 104 56 38 23 113 43 54 79 38.62 123.74 114.42 60.87 87.73 128.70 171.64 15.69 52.28 11.95 12.95 35 97 192 84 86 02 280 88 160 80 3 51 131 48 267 52 109 54 350 89 77 02 77 04 77 02 77 03 77 03 77 O1 77 02 76 99 76 99 76 99 WELL: NIAKUK NK-23 000000000000 165 O0 265 O0 365 O0 465 O0 565 O0 665 O0 765 O0 865 O0 965 O0 1000 O0 1065 O0 1165 O0 1265 O0 1365 O0 1465 O0 1565 O0 1665 O0 1765 O0 1865 O0 1965 O0 2065 O0 2165 O0 2265 O0 2365 O0 2465 O0 2565 O0 2665 O0 2765 O0 2865 O0 2965 O0 3065 O0 3165 O0 3265 O0 3365 O0 3465 O0 3565 O0 3665 O0 3'765 O0 3865 O0 3965 O0 4065 O0 4265 O0 4365 O0 25 38 77 1 76 2 68 3 02 4 93 6 11 7 60 8 O9 8 68 10 46 11 29 12 30 14 11 17 08 19 27 21 04 23 69 24 55 28 60 32 20 35 62 39 00 42 60 45 03 48 16 50 95 52 98 55 51 58 03 58 39 58 88 59 23 59 80 60 23 60 07 60 10 59 36 59 48 60 46 60 02 60 24 96 19 91 68 98 23 85 94 85 93 90 05 77 83 75 96 74 69 73 68 70 93 66 72 59 84 64 53 65 99 67 02 67 70 68 20 68 63 68 47 67 84 67 73 67 67 67 95 67 86 67 88 67 63 67.20 66 68 66 60 66 62 67 07 67 22 67 67 67 62 67 33 66 48 65 90 64 87 64 41 64 25 64 37 65 12 4465 O0 4565 O0 4665 O0 4765 O0 4865 O0 4965 O0 5065 O0 5165 O0 5265 O0 5365 O0 5465 O0 5565 O0 5665 O0 5765 O0 5865 O0 5965 O0 6065 O0 6165 O0 6265 O0 6365 O0 6465 O0 6565 O0 6665 O0 6765 O0 6865 O0 6965 O0 7065 O0 7165 O0 7265 O0 7365 O0 7465 O0 7565 O0 'IGOr% 0[) 7765 O0 't'~(,5 8065 O0 8:1.65 O0 8265 O0 8365 O0 8465 O0 8565 O0 8665 O0 8765 O0 8865 O0 59.97 60.74 61.24 60 89 61 O0 61 39 60 26 59 42 58 64 58 21 58 25 57 97 58 58 57 71 58 24 58 68 59 26 59 31 58 09 58 52 58 62 59 O1 60 66 60 23 60 90 61 O0 60 99 61 23 60 88 60 73 60 47 59 35 60 _1.1 58 7~7 %9 90 (_7 (.) 30 60 05 60 56 59 89 60 32 60 70 6O 54 61 22 60 30 60 44 66.77 67.61 68 43 69 48 69 95 69 09 68 74 68 61 67 81 67 03 66 39 65 97 65 27 65.26 65.11 65.39 65.44 65.95 66.18 66.66 67.17 68 04 68 07 68 59 68 90 68 92 68 94 69 46 68 96 68 67 68 81 68 69 68 71 69 O0 69 70 69 34 69 13 68 68 68 68 67 75 67 87 67 67 68 05 67 81 67 98 8965 O0 9065 O0 9165 O0 9265 O0 9365 O0 9465 O0 9565 O0 9665 O0 9765 O0 9865 O0 9965 O0 10065 O0 ].01.65 O0 10265 O0 1.0365 O0 10465 O0 _L(.)565 O0 10665 O0 10765 O0 10865 O0 10965 O0 11065 O0 11165 O0 11265 O0 11365 O0 11.465 O0 11565 O0 11665 O0 11_765 O0 11865 O0 11965 O0 12065 O0 12165 O0 L 2265 00 12365 O0 12465 O0 12565 O0 12665 O0 12765 O0 12865 O0 12965 O0 13065 O0 13165 O0 13265 O0 13365 O0 61 22 61 59 62 04 61 70 60 88 60 84 61 10 60 06 60 03 60 O3 60 23 60 49 60 39 60 98 60 18 59 85 59 60 61 19 62 81 62 29 61 63 62 10 61 77 61 13 60 80 60 48 60 68 60 19 59 27 59 68 59 46 59 28 58 87 59 13 60 28 59 48 59 90 59 71 59 63 59 64 59 84 59 59 59 51 59 08 58 82 68 O0 68 O1 67 18 66 72 66 43 66 O1 65 81 65 93 66 23 66 25 66 35 66 83 66 48 66 39 66 29 66 45 66 26 66.79 67.55 67.57 67.33 67.21 67 76 68 05 68 28 68 57 68 41 67 24 65 96 65 57 65 19 64 69 64 47 63 87 63 38 62 92 62 87 62 99 63 33 63 55 63 56 63 58 63 47 63 77 63 84 13465 O0 ~B56~ oo 13665 O0 13765 O0 13865 O0 13965 O0 14065 O0 14165 O0 14265 O0 14339 O0 58 91 58 40 58 10 57 74 57 58 57 47 58 37 59 88 60 93 60 84 63 75 63 85 63 84 63 37 63 24 63 66 64 08 64 43 65 68 64 95 PAGE NO, **************************************** ***.~**.*** *****:*~* ANADRILL ********** ******'*** SCHLUMB, B~GER *********** SURVEY A~hLYSIS COMPANY BF' EXPLORATION~ INC, WELL N~,4~E N~-23 LOCATION 1 NIA~UI< LOCATION 2 NSB~ ALASKA DATE: ~9'-~PR-94 · ~GN~TIC D~LINATION 29,83 WELL NL~IBER 0 RECEIVED JUL 1 9 i9~4 Alaska Oil & Gas Cons. Commission Anchora:~ *****~***** ANADRILL **:************ SURVEY ANALYSIS **~********** CIRCULAR ARC Mk~HOD******** MD TVD INC_CHG CUMINC_CHG I_RAT~ AZM_CHG CUMAZM_CHG TURN_RA~ f~ f~ deg deg deg_/100f~ deg deg. deg/100f~ CL~URE TOOL FACE DLS BLSRT ft deg deg/lO(~t 14339,0 8363,20 0,00 0o00 0,00 0o00 0,00 0.00 114,24 0,00 0,00 0,00 14604,0 8494,01 -0,64 -0,84 -0,32 -0,75 -0,75 -0,28 125.19 142.36 0,40 0.15 14742,7 8563,06 0,31 -0,53 0,22 0,43 -0,32 0,31 131,25 50,38 0.35 0,04 148.36,0 &~8,56 1,(~J 0,47 1,07 -0,38 -0,70 -0,41 135,32 18.40 1,13 0,64 1493,5 8655,41 1,21 1,67 1,21 0,32 -0,39 0,32 0,00 0,00 1,24 0.11 15026,1 86.96,./-8 0,76 2,43 0,83 -1,04 -1,43 -1,15 144,~ 51,16 1,32 0,09 15120,6 8740,40 -1,67 0.76 -1,77 -0,4! -1,85 -0,44 150,17 167,71 1,81 0,51 15216,3 8786,5'2 -1+35 -0,59 -1,41 0,98 -0,87 1,02 155+59 147.94 1,67 0,15 15311,7 8834,34 -0,15 -0,74 -0,16 0,8? 0,02 0,94 159,59 101,14 0.83 0,88 15405,4 888.2,17 -1,53 -2,27 -1,63 2,25 2,27 2,40 139.76 13,05 2.63 1.92 15501,3 8931,94 0,2? -1,98 0,30 0,65 2,92 0,68 160.96 62,88 0,65 2,06 15594,6 8?78,64 2,23 0,25 2,39 -0,85 2,06 -0,72 160,77 18,~. 2,52 2,00 15689,3 90~,96 0,62 0,87 0,65 1,59 3,66 1,68 160,03 66,52 1,62 0,95 15784,6 9(~9,89 -1,05 -0,18 -1,10 -0,I1 3,55 -0,11 158,20 174.50 1,10 0,54 15860,0 9117,99 -1,87 -2.05 -1,96 2,64 6,19 2,77 161.30 128,94 3,09 2,09 15973,6 9t67,16 -0,94 -2,99 -1,00 3,48 9,67 3,71 146,87 108,48 3,31 0,23 161~D.O 92~,24 -1,94 -4.~ -1.54 2.72 12,39 2,15 130,92 131.19 2,37 0,75 16191,8 9288.16 -0,74 -5,67 -0,80 -2,19 10,2C) -2,38 119,15 112,83 2,12 0,27 16288,5 9344.57 -1,73 -7,39 -1,79 -0.03 10,18 -0,03 108.44 179.04 1,79 0,35 16379,9 'Y'J?9,?9-1,50 -8,90 -1,64 -2,2I 7,97 -2,42 154,60 130,01 2,53 0,81 16477,7 9459,67 0,91 -7,98 0,93 2.73 10,70 2.79 90,49 66,00 2,40 0,13 16574,5 ~18,33 -0,30 -8,29 -0,31 3,27 13,97 3,38 77,15 97,&~ 2,71 0,32 16671.5 9575.05' 3.29 -4,99 3,40 2,71 16,66 2,79 59,45 34,51 4,08 1,42 16765.3 9627,6~ -0,20 -5,20 -0,22 -0,42 16,26 -0,45 40,~ 120,59 0.43 3.90 16857,1 9679,6~ 0,11 -5,05' 0,12 1.02 17,26 1,11 99,92 131,19 0,~ 0,54 16952,1 9732,89 O,Zi -4,84 0,26 -0.74 16,54 -0,78 1,89 68.16 0,70 0,24 I7046,1 9785,28 0,26 -4,58 0,28 -0,45 i6,09 -0,48 -16,94 55,26 0,49 0,22 17143,1 9~8,':/5 0,25 -4,33 0,26 0.40 16,48 0,41 -36,39 53,14 0,43 0,06 17238,6 98~2,05 -0,60 -4,92 -0,63 0.14 16.63 0,15 -55,86 168,88 0,64 0,22 17335,0 9:/46,79 -1.03 -5,95 -1.07 -0,58 16.05 -0,60 21,66 82,77 1.1~ 0.56 17428.5 100(Q,93 -0,47 -6,42 -0,50 -0,44 15,61 -0,47 -92,83 142.86 0.63 0,58 17469,5 10024,85 -0,32 -6.75 -0,79 0,83 16,44 2,03 -100.69 t15,97 1,83 2.91 F~DJEC. TEI) Sbl;."JEY 17535,0 10063,26 0.00 -6.75 0.00 0.00 16,44 0.00 -113,60 94,36 0,04 2,72 PAGE NO~ ~MPAN¥ BF' EXPLORATION WELL NAME LOCATION 1 HIAI(LrK,. LO~TION 2 ~B~ Al< MAG~TIC DECLI~TtON ~83 DATE: WELL NU~ ~;ER WELL HEAD II]CATION: LAT(~q-S) 0,00 DEF'(FY-W) 0,00 TIE IN POINT(TiP) : MEASURED DEFTH 0,~[~ TRUE '~RT DEPTH 0,00 INCLINATION 0,00 AZIMUTH- 0~00 LATITUDE(N/-S) O,~D D~'ARTURE(E/-W) 0~00 AZI~]TH ~OM R~A~;Y TAB~ ~] TAF,~ET IS 67,30 MEA~ORED IN'~ERV~L 7~T]CAL DEPTH DEF~fH ft ft ft 0,00 O,O 0,00 102,63 102,A i0~,,..3 201,00 %,4 201,00 ~2,37 91,4 ~2.36 ~,~0 ~i.7 ~4.08 ~R~Y ~LC~T]~.~S T~G~T STATION ~I~.~ LATITUDE SECTION INCLN, N/-S E/-W ft d~ deb ft ft 0,00 0.00 0,00 0,00 0,16 0,26 115,~ -0,10 0,21 0,59 0.46 110,17 -0,33 0.76 1.26 0 .~ 105,69 -0,59 1.61 2,~ t,36 87,20 -0,67 3,18 DEPARTURE DISF'LAC~Effr at AZI~,'TH ft deb 0.00 O.O0 0,23 115.00 0.85 112.77 1.71 110.14 3.~ 101, ,c,5 DLS d~q/ lOOft 0,00 0,25 0,20 0,20 0,86 469.12 561.64 650.82 742.71 829.14 85,0 469,06 %.~ 5A1.50 89.2 650.55 71,9 742,16 86,4 828,17 4,94 1,5~ 90,43 -0,./,3 5,62 5,66 96,44 0,68 8,47 2,82 90,21 -0,65 9,45 9,47 93,96 0,76 13,01 3,57 92,2~ -0,77 14,42 14,44 93,06 0,86 19,75 5.28 78,13 -0,01 21,42 21,42 9,D,04. 2,18 28,20 6,05 70.72 2,~? 29,61 29,70 85,57 1,22 921,39 1010,35 1099,88 1196,81 1290,93 92,3 919,78 89,0 1007,85 89,5 i~76,21 96,? 1191,50 94,1 12&3,75 38,96 7,43 75,53 5,37 39,98 40,34 82,34 1,60 51,34 8,75 75,79 8,47 52,11 52,79 80,77 1,48 65,75 9,88 64,26 13,48 65,63 67,(X.~ 78,39 2,43 83,45 11,20 64,58 21,12 81,63 84,31 75,50 1,37 102,10 11,72 61,77 29,55 98.31 102.~6 73,27 0,82 1~3,03 1478,93 1575,25 1663,67 1758,~ ~,9 i405,68 96,3 1559,20 88.4 1643.05 ~4.4 1731.66 122,05 13,35 &5,t4 38,28 116,28 122,42 71,78 145,31 14,73 67,05 47,51 137,.~- 145,61 70,96 I72,06 17,52 65,44 58,32 162,11 172,28 70,21 200,13 19,51 67,19 69,58 187,83 2OD,30 69,67 Z32,66 20,82 69,M 81,47 218,11 232,83 67,5~ 2,05 1,46 2.93 2,34 1,69 1852,59 1949,55. 2042,59 2137,83 22~3,51 ~%~25.05 2424.39 ~13,15 2602,82 2700.52 94,5 18!9,t6 97,0 1%7,81 93,0 1991,33 ~,2 2074,11 '~ 7 9;,. 2152,02 94,5 T~'28,86 99,3 2~6.33 88,8 2372,21 89,7 24~,48 97.7 ~,_~00.97 268,~ 23,56 69,50 93,88 307,58 24,25 69,56.'. 107,62 288,39 348,52 27,99 AP,OB k~,09 ~6,71 395,57 3t,25 .~.,02 1[,~,32 370,51 445,74 [d,32 68,09 158.07 417,~ Z,.4,_,2 49,54 2 90 307,82 69,54 0,72 :-d8,78 69,51 4,03 395,83 67,39 3,46 445,99 /.'9,24 3.31 500,79 36,'~ 68,26 178,54 468,16 501,05 69,13 2,7-) 562,94 ~D,55 68,75 201,30 526,0C, 563,2%:, 69,06 3,65 622,39 43,60 .~=,27 223_,~}' 581,33 622,67 69,01 3,45 ~45,9i 46,63 67,6B 246,92 640,~ 686,18 68,91 3,42 758,41 49,19 67,82 274,37 707,32 758,67 65,80 2,62 27?2,58 . 28~6,14 29~),96 [<)74,61 3167,75 92,1 2559,62 59,6 2616,79 94,8 2671,92 '?3,7 Z723,~, 95,1 2773.39 829,35 51,65 67,43 301,38 772,92 829,~0 68,70 903,4! 53,02 ~5,72 5~),2'3 841,!3 903,63 68,56 980,5~ 55,88 67,16 360,43 912,10 980,74 68,44 10~,97 57,90 .~.,..40 389,96 984,77 1059,17 68,40 t139,70 58,26 68,75 419,3~ 1059,59 1139.92 68,42 2,70 1,58 3,04 2,51 0,41 .3'Z63,)7 3452,70 3544,55 3.5~8,28 74,0 2822,51 92,7 2870,43 96,2 ??19,71 91,9 2966,07 73,7 lOp,la 1217,84 58,74 48,~ 448,65 1134,59 1220,08 65,42 1Z,'..9,1? 59,02 68,61 477,77 1Z08,42 12':/9,44. 68,43 1381,82 59,37 67,87 SCx3,41 1285,18 1382,08 68,42 1461,11 60,01 68,28 538,01 1[~8,74 146.1.~ ./,8,40 1542,13 59,64 68,37 56.7,~ 1434,04 1542,41 68,39 0,64 0,40 0,75 0,79 0,39 MEASURD INTEE~AL VEEq'ICAi, DEFTH DEPTH 3731,46 73.2 E<)60,32 3823.99 9~,5 3107~31 4011,94 93,6 3~03,10 4105,43 ~.5 5~50, I9 4197,9I 4294,07 4385,84 4475,92 4570,82 **********~** AN~}RILL *~*~********* SU~dE¥ CALCJLATIONS .~***~****** CIR£~AR ARC M~?HOD*~*~*~ TARG~ SffATI~ AZI~ZH ~TI~E S~I[~4 INCLN, ft -deg deg 16~,4t 59,59 65,57 1702,19 59,37 67,30 631,23 1788.30 59,18 ~.Z7 &f,4,51 1&f,3.72 59.72 63,51 699,97 19~,~ 59.79 ~.84 735,78 92,5 3296.82 2024o(~ 90,1 3437.341 --~24&.84 94,9 3464,45 ~d6,19 59,73 59,48 59,82 ~D.60 64,30 65.14 66,03 67.14 67,70 D~PCCffURE DISPLACEMENT at AZIMUTH ft ft deg 1508,01 1622,75 66,32 1581,07 1702,42 1655,06 1783,48 6~,12 1727,41 1663,84 67,94 179%79 1944,38 67,76 DLS deg./ lOCfft 2,59 1.63 2,77 0,31 770,70 1671,61 2024.09 67,62 0,46 &o,l~ 1946,68 2107,00 67,50 838.87 2018.76 2166.11 67,~ 0,68 &~,9,76 2090,09 2263,84 67,41 1,13 901,38 21./,6,14 22q6,19 67,41 0,?6 44,.65,64 4755,B0 4849,~ 4943,69 5036,41 94.8 3530,77 2428,91 90,2 3574.89 2507,50 ~_. 73,8 ~,20,92 2587,14 94,1 3&%.90 2671.15 92.7 3712,83 2751,60 60,71 ./,0,50 60,70 60,81 59 6~,40 70,90 69,53 732~,03 2242,98 2428,92 67.44 1,07 960.08 2316,44 2~)7,52 47,49 0,74 ?88,76 23")2,93 258~,17 67,55 0,24 1016,58 2470.19 2671.20 67,63 1,30 1043.M 2545,99 2751,67 67,71 1,67 5133,16 5229,49 5320.59 5413,71 96,7 3761,75 2834,?8 -'%,3 S511,26 2917,56 ~1,1 385&~8 2~5,2t 93,1 3907,77 3074,32 95,4 3958,52 3155,21 59,45 58,71 58,11 70,39 67,M 68,~1 66,59 1072,44 2624,40 2635.07 67,77 0,85 1102,02 2701,55 2917,68 67,81 2,56 1130,77 2773,70 2995.~ ~7,82 1.28 115%r~ 2847,27 3074,46 67,84 0,93 1191,19 2521,~ 3155,34 67,82 1,19 5591,35 5696.49 ~89.69 5878.96 5974.52 6069.79' 6165,10 6258,14 ~.,4,~1 6447,49 82,3 , o 105,1 4057,94 ~14,05 '~3,2 4107,'~ ~'"'~ ' 89.3 4i~,02 [d69,17 ?5.5 4293,57 35%,.85 95,3 4~2,66 3632,50 ~J.~ 4301,80 37t4,1X 93,0 4350.33 3793,53 96,8 4400,59 o~l ~ ~! ,.,. ~ 92,6 4445,45 3955,45 57,78 54,34 57,74 ~.r, '70 58,79 59.15' 58,74 5-8,39 59,04 5,5.66 ..%,73 66,35 67,26 1218,77 ?~85,79 3224,96 67,80 0,20 1254,29 3E,7,63 3314.16 67,76 0,62 ,?~ oo 3140,00 ~.0,28 67,72 0,64 1316,62 329~,71 343,9.25 67,70 1,61 1247,9? ~=.,°°°~ 12 3550,93 67,69 0.30 66,72 1379,70 35~J,37 3EC~,~ 67,.~, 66,17 1412,~ 3435,23 3714,23 67,65 66,89 1443,94 350&05 3793,5? 67,15 1476,22 3584,18 ~76,28 67,61 68,26 1506,27 36_%'.49 395-5,51 67,62 0,88 0,68 0,76 0,71 1,10 6543,~ 66~,27 6/~,75 6827,12 6~3,38 --..%.1 4498,13 4037,67 94,7 4545,74 4~9,53 95.5 ...~°°,94 4202,50 93,4 46~,78 4283,80 96.3 4685,52 4367,91 59,10 40,55 60,20 60,96 60,91 69,05 .~,83 68,70 69 1S%4,AS J70~,91 4037,74 67,63 0,48 1.566,37 3810.20 4119.61 67,65 1,65 1576,~3 3887,66 4202,59 67,68 0.42 1625,66 3963.47 42~.91 67,70 0,85 1655,80 4042,04 4368,03 67,72 0,57 7015,63 7111,66., 72O5.63 7394,87 92,3 47~),4I 4448,46 9.5,2 4777,13 45E¢2,54 9.3,8 48-~.50 4614,54 96,0 4~,69.08 46?8,39 .c.J,3 4914,54 4779,82 60.86 61,05 61,08 60,82 69,06 1684,4! 4117.3~, 4448.60 67,75 69,72 17N,02 4196,13 4532,70 67,78 69,14 1742,86 4272,9.5, 4614.73 67,81 69.& 1/"72.76 4351,33 4698,59 67,83 69,05 1801,87 4422,42 47~).LM 67,85 0,24 0,61 0,54 0,27 0,05 MEASLY:ED ItCERVAL V~:TICAL DEPTH D~FTH ft ft ft 7467.51 92,6 7584,4! 76,? 5~8,79 7677~51 93,1 50%,41 ~72.81 ~,3 5105.~ 7668,43 95,6 5152,% ************* AJqADRILL ********-***'*** SURVEY CALCL~ZIONS ******.'****.***. CIRCULAR ARC M~THOD********: TARGET STATION ~IMLCCH LATITUDE SECTION INCLN, N/-S ft deg. deg ft 4840,42 60,17 68,70 1830,92 4944,17 59,%5 69.57 1850,78 5024,11 58,90 69,59 1888,68 5105,89 59,52 70.07 1916.91 5188,65 40,55 69,63 1945,44 DEF'AE~URE DISF'LAC~ME~ at AZ]P~!TH E/-W it ft deg 4502,~ 483,0..~., 67,87 4580,95 4944,45 67,89 46~, 91 5024,40 67,92 4732,76 5106,22 67,95 4810,53 5189,02 67,96 DLS deg/ 0,81 1,00 0.72 0,75' 1,15 7963,48 8059,63 6154,47 8249.70 &q45,59 95.1 5200,t0 96,2 524~,11 94,8 5~95,18 95,2 5342,57 ~+? 5~?0,05 5271,12 59,98 69.56 1974,20 5354,39 ~),12 68,57 2003,96 5436,71 60.37 67.70 2034+62 5519,30 59,94 68,75 2065,27 5602,58 60,69 ~8.94 20'35.S3 4887,89 5271,52 68,01 0,61 4965,70 %~4.82 .&q,02 0,92 5042,11 5437,15 68,02 0,84 5118+81 5519.74 ~,03 1,05 5196,50 %03,04 ~,04 0,80 8437.16 8532,~9 86.25,04 8720,18 8815.09 91,6 5434,79 ~5,1 54~1,25 92,7 5526,85 95.1 5573,89 94,9 5620,74 5682,47 ~,.~ 68,75 2124,17 5765,42 60,70 A9.43. ...~,..'~3 ~o 5646.12 .~,39 69,43 2182,1.6 5928.79 60,362 68+77 ~11,67 ~11,30 60.48 69,13 2241,32 52.71,04 5652,~ &5,05 0,23 5348,57 5765,94 68,07 0,62 5424,18 5846,67 ~.08 0,34 5501,44 5929,37 ~,10 0,61 5578+48 6011+~ ~,11 0,35 8911,10 90~?,19 9102,~ 91~9+37 9~.'4,84 96,0 5367,52 98,1 5714,85 93.7 5759,70 96,4 5~G,58 ~5.5 ~51.41 6095,10 61,20 4~.20 ~1,82 6181,01 61.11 68,23 2303,70 6263,31 61,71 68,19 ~4+25 6348,13 61,46 67,65 2366,14 6431,89 61,15 A(.~,~,=c~ 2~?8,8~ S6.~,,56 6095,72 68,12 1,13 5736,3'5 6181.65 ,5&12 0,09 5812,78 6263,96 68,12 0,~ 5891,~ 63A5,78 &5,12 0,55 5968,48 6432,52 68,10 1.27 9367 ~ 9480,72 9573.74 · L'I ~, ~767.83 9952,87 10148.74 10241.48 ~,0 5896,53 ?2.9 594i,74 93,0 5986,94 94,2 60~,28 99.7 6128,29 94,3 6174.91 99,5 6Z23,97 96,4 6271.67 92,7 &317.69 6513,20 60,80 66,26 2431,58 6594,33 60,94 ~.]0 24.54.34 ~,75,60 ~),92 67,00 2496,70 6762,49 59,88 67.05 2534),62 6844,09 60.26 67,06 ~62,43 6922,87 60,26 68,24 75'72,?? 7004,M 60+49 67,41 2623,33 7091,39 60,42 67.65 2656.41 7175,14 ~0.26 67,02 26~,,68 7255,66 60,25 ' 67.20 2720.(X) 6042,94 6513,80 .~,C~, 6117,15 6594,89 68,06 6191,74 6576,16 E~.04 6271.73 6763.04 68,03 6346,~, 6M4.&3 ~.01 6419,73 6923,40 6~,01 64~.65 7005.~ 66.01 6575,63 7091,93 6~,00 6652,91 71~.67 67.~9 6w~ no 7256,18 67,98 IL1 ~ ~/ 0,38 0.21 0,85 1.04 0,40 1,13 0,60 0,23 0,60 0,17 10334,01 104,32, ?8 !0524,51 1(k420,71 10713,12 96,5 goz~ vo 95,0 ~13,~ 91,5 6459,43 96.2 6~37,29 92,~ 6551.59 7~9,35 59,98 _ .F-4.,45 2752,93 7421,56 59,94 46.62 2785,67 ~ £ L~ 7_.00 .... ~ 5?,57 67,44 2816,53 7584,08 60,76 &5,71 2~49,03 7~65,16 61.94 6~,4~ 2881,24 68(~.03 7~Tfv.~ 67.97 0,73 6879,45 7422,04 67,96 0,16 6952,24 7501.10 67.~5 0.~ 7029,10 7584,54 67,94 1.40 7103.52 7./4.5.61 67.92 1.30 10810,38 10904,40 lC4/_ ,~,1 11096,08 11190,85 97.3 6596,96 94,0 6640,93 ~.1 668.°4,37 .99,6 673!,47 94,8 6776.90 775i,19 62,47 .~,73 2914,01 7834,25 6t,77 69,62 2943,56 7915,42 61,95 69,02 25'72+24 &003,11 61.56 65,45 3004,04 80~,28 61,17 67.52 30~,22 7183,07 7751,64 67,92 2,11 7260,7'2.; 7~34,73 67.93 1,12 7336,73 7915,92 67,95 0,61 7418,48 8,>33.63 ~7,95 0,64 7495,59 8086,81 67,96 0,96 MEASUFtED IN?EASeL V~F,%~C~ DEFTH DERTH ft ft ft 11281.67 ?0.8 &521.14 11~71,?~ 95,? 11~4,~ 98,1 7010,~ *~**.**.'*****~ ANADRILL ****~**~***** St~:VE¥ CALCUI.AT *~*********~ CIROJLAR ARC METHOD~**.**** TARGE'f STATION AZIMUTH LATITUDE SECTION IN[:LN, ft deg deg ft 8165,60 60,53 ~.8,02 304,5,24 8247,26 8 ~*.'.~, 88 60, s.~..., 68,82 3124,98 6413,21 bD,05 69,54 3154,27 8497,94 59,54 69.34 3184,02 DEF'ARTL~:E DISPLACEMENT at AZIMLq'H E/-W ft ft dmg 7569,02 8166,13 67,95 7~5.08 8247,81 7723,18 833i,45 67,97 7800.18 8413.81 6-7,98 7879,58 8q98,57 65,00 DLS deg/ lOOft 0,85 1,14 0,38 0,71 0,53 11758,26 11853,60 11948,20 12944,94 12138,78 94,1 95_.3 7106,23 94,6 7154.30 96,7 7203,75 93,8 7252,19 8579,01 5?.57 67,38 86,51.17 59,51 65,33 3246,85 8742,61 59.42 65,41 3280,80 88.~,73 59,10 &5 r~ 8906,08 ~,,74 66,27 0oq.,42 7554,96 8~?.65 68,00 1,83 8030,23 866~79 67,99 1.85 8104,30 8743,19 67,96 0,12 8180,11 6826,28 67,94 0.68 8253.63 8906.~) 67,92 0,42 12231,31 12326,36 12419,81 12515,70 12610,41 92.5 72?9,95 95,0 7348,27 93.5 95,9 7444.11 94.7 7492,~ 8985,30 59,12 M,98 3~0.13 9067,I1 59.78 65,94 3414,12 . 9147,67 59,52 F i q ~o ? .~,7~ ~4~,4~ c/-~0,19 59,55 64,62 3484,43 9311,68, 59,40 ,M.~ 3519,[~, 8325,82 8985,80 67,90 8~[~.28 9(~7.57.' 67,88 8473,26 9148,10 67,85 8547,65 9230.58, 67,82 8621,36 ,:oto n~ 67,79 1,26 1,11 2,08 0,82 0,16 127~5,74 12802,73 12898.09 12978,78 130M,44 96,3 7541.30 96.0 7590.07 95,4 76~.20 80.7 7678,88 1~,7 7732,56 %'?4,45 5%33 63,99 35_,55,31 9476,97 59,60 63..g~, .3591.97 5559,15 59.78 64,61 3628,06 9628,.-0 59,67 ,M.77 ~557.84 9719,71 5?.27 65,49 3696,10 8696.05 99N.76 67,76 0,58 8770,17 9477,24 67,73 0,61 8844.15 9559.2~, 67,70 1,i~ 8907.15 9628,97 67.67 0,24 8989.72 9719,69 67,65 0,69 13180,17 13273.65' 1LU.% 9,56 134M.82 1[~60 136N.85 13749,31 138~,6I 14022,49 95,7 77/81,56 ,J,J 7825',68 %,. 7879,26 95,3 7928,81 95~2 7?78,70 ?4,5' 8028,86 94.5 8079,21 95,3 8150,41 ~.1 8179,96 95,8 8230,84 9801.92 59,15 ,%,21 37~?.74 9~2,11 58,93 66,58 3761,85 99M,!5 58,78 &~,.~ 3794,47 1(K~5,51 58,54 66,2i 3827,06 10126,5! 58,24 64,78 3,55,0,67 10206,93 ?.90 64,53 3895,I. 3 102&.,,,~ ~ ~ 64,21 ~/, t.~ , 10367,(~ 57,32 64,k3 3964,73 104'44,50 57.56 64,5? 3'3"?8.25 10525,59 58.29 64,08 4033,35 9064,76 9802,09 67,64 9138.~ 9682,26 67,62 '72i3,54 '?964,30 67,62 92e4,10 10(~5.65 67,61 '}~61,84 10126,64 67,59 94~M,60 10D7,04 67,57 9506,65 10286,84 67,54 9579.00 10367.08, 67,52 9648,98 10444,56 67,49 9722,19 10525.~: 67,47 0,66 0,41 0,16 0,42 1.31 0,42 0.37 0,38 0,57 0,93 14128,98 _.96.5 8280~50 14171,00 42,0 8301,35 14222,&q 51.8 8._~6,68 14al ...... 94,0 8372,72 14411,76 55,0 M19,46 10608, ~ 59,75 65.28 .... 49 ...... 72 1~544.68 60,77 64,40 10689,82 60,65 ~ ~' O.,,~/ 4103,01 10771,73 83.68 66,32 4135,81 10854,42 60,37 &5,~' 4169,C~ 9796,97 1~508,26 67,45 98~1,00 10.444,71 67,44, 9871,08 1(E,89,85 67,43 99%.14 10771,76 67,42 10021,87 10854,44 67,41 1 3,03 3,4? 0,15 0,32 145O4,99 14504,25 14742,74 14&36,00 14935,50 93,2 8465,78 99,3 8515,38 138,5 8584,30 93.3 ~d,29,79 99,5 8676.65 lC6~,28 ~,05 64,58 4202,68 11021.16 60.(X) M.25 4~O.81 11141,13 03.31 64,63 4291,64 11222,43 61,30 11310,0? 62,50 64,60 4364,72 10C~5,45 10T~5,~0 67,~?, 10173,01 11021,17 67,38 10281,37 11141,13 67,M 10354,80 11222,43 67,32 1043~3,55 11310.C~ ~7,3;~ 1,62 0,30 0,33 1.14 1,26 DEPTH ft 15026,10 15120,60 15216,30 15311,67 15405,44 1~01 15594,62 1~9,30 15764,59 15840, 15973,61 16100,03 16191,80 16288,48 16399,92 16477,72 16574.51 1&f,71,5~ 16765.25 16952,09 17046,11 17143,06 17334,96 17428,53 17469,48 It~EF, qJAL V~RTICAL DEPTH ft ft 90,6 8717,93 94,5 8761,,f3 95,7 880~,10 55.4 68,55,50 93,8 8~)3,33 95,9 8553,11 94.7 9)45,13 ~,3 9091.05 ~5,4 913~,16 93,6 9188,33 126,4 ~57,41 9!,8 93(xP,34 96,7 ~65,74 91,4 9421,16 97.8 9480,84 96,8 95~',50 97.0 9596,~ 93,7 9649,00 91.9 9700,78 95,0 97~,06 94.0 9806,46 97,0 9803,13 95,5 %'13,23 96,4 9967,97 93,6 1~)22,10 41,0 10046,02 *****.*****.*~ ~ ANADRILL ****.*****~*** SUR~¥ CALCL~ATI[MS ***********~ C]RCUL~ AE~ ~THOI~**~***T~RGET SYATIOH AZIMLri'H LATITUDE SECTION INCLN, N/-S ft deg deg ft 11~0,61 63.30 63,50 4400,02 11474,19 61,60 48.10 4437,&~, 11~7,67 83.30 64,10 4474,86 11640,~ 60,10 ~.97 4510,44 11720,96 56.57 67,22 4543,13 DEPAETURE DISPL~EMENT at AZI~J?H E!-W ft ft deg 10506.47 113'k0.61 67,28 10581,32 11474,1.9 67,25 106%.25 11%7.&5 67,2~ 10730,97 11640,35 67,20 108,34.69 117D.98 67,!9 11802,88 58,&5 67.87 4574,42 11883,67 61,09 67,01 4605,42 119&f,,79 61,71 12050,26 60,66 68,50 4667,34 121[rZ,57 58,79 71.14 4655.78 10880,40 11802,90 67,20 1095_,5,01 11~3.69 67,~! 11031,97 11966,81 67,20 iI109.~ 11~)50,28 67,21 11187,00 121~,58 67,23 1~I1,~ 57,85 74,62 4719,23 12316,48 55,91 ~.3~ 4744,5~ ~'~ . 1~1.22 55,17 75,15 12469,00 53,45 75,13 4763.02 12541,23 51,94 72,92 4803,03 12618,12 75,65 4824.00 12693,94 78,92 48.40,95 12770.5? 81,,.~ 4854,20 12M5,71 81,21 4865,75 1291'?,20 82,23 4876,~4 52,55 55,~5 55.64 55,75 11263,11 12211,83 67,27 11365,81 1~16,49 67,34 114~.~ 125~'1.24 67,40 11515,20 12469,04 67,44 11585,11 1254J..~ 67,48., 11659,69 12618,22 67,52 117~.78 12694.(5' 67,58, 11812,33 12770,84 67,66 11888,~ 126%,09 67.74 11964,01 12919,74 67,82 12995,~ ~5.00 8!,49 4887,81 13071,05 56,26 81.04 485~,67 13149,42 56.,51 81,43 4911,97 13226.35 55,~ 8!.S~ 4'3~3,69 13303,~ 54~89 81,00 49~,71 12041,84 12'93'6.03 67,91 12119,00 1~)?1,99 67,99 12198,80 13150,59 68,07 1~77,29 13227,80 65,15 12~5,74 13~D5.09 68,~ 13377,58 54,42 80.% 1~09,8~ ~.09 81,39 4947,94 12431,08 1~79,60 68,30 .~o, 1.5 12%3,i0 13412,c)3. An..=, o~,5~ DLS deg/ 1,40 1,84 1,64 0,82 2,63 0,65 2.52 1,62 1,11 3,09 3,32 2,37 2,13 1,78 2,53 2,40 2,71 4,09 0,43 0.93 0,70 0,48 0,42 0,63 1,1.8 0,6~ 1,83 PE~JE~ED ....oUnVaI~" I755~,00 65,5 10084,45 13461,35 54,09 61,39 4961,10 0,00 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 7, 1994 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear AOGCC Representative, Attached is a blueline, a folded sepia and a LIS tape of e-line logs for well Niakuk 23. The MWD logs will follow shortly. Per 20.AAC 25.537(d) BP Exploration would like these these logs held confidential for 24 months. The saecific attached logs include: Log Type Company Run Date .Depths ..,'CFC Gamma Ray / Collar Atlas Wireline Log (Perforation Record) 6/18/94 1 6550-1 6762 Please contact me at 564-4531 if you have any questions. Sincerely, Katie Nitzberg,~r.~Ge~logist Lisburne and New Erbvelopments KEN Enclosures MEMORANDU,d TO: THRU: David _Joh~on, Chair~ Blair Wondzell, ~-~ P. I. Supervisor State oi Alaska Alaska Oil and Gas Conservation Commission DATE: May 18, 1994 FILE NO: azlheqbd.doc FROM: Doug Amos, '~ ~ SUBJECT: Petroleum Inspector BOPE Test Pool 7 BPX NK,-23 Niakuk Oil Pool PTD No. 94-0035 Tuesday, May 17, 1994:. I traveled to BP EXPloration Niakuk well NK-23 to witness the BOPE Test on Pool Alaska Drilling, Rig No. 7. The rig and all equipment was in good condition and despite the small footprint of the pad there was ample room on the location should the need arise for additional equipment. The drilling crew and tool pusher were courteous and knowledgeable about the BOP Equipment and the test procedure. As the attached AOGCC BOPE Test Report indicates there were no failures. Summary: I witnessed the BOPE test at BPX NK-23 well on Pool Rig No. 7. Test time 3.0 hours, no failure, 26 valves tested. Attachment, AZIHEQBD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover:~ Drtg Contractor: Pool Alaska Drilling. Operator: BPX Well Name: NIAKUK NK 23 Casing Size: 9 5/8" Set @ Test: Initial Weekly X Rig No. 7 PTD # Rep.: Rig Rep.: 14,672 Location: Sec. Other DATE: 5/17/94 g4 - 35 Rig Ph.# 659 - 4815 or 4816 Vance Houser Skinny Jim 36 T. 12N R. 15E Meridian Umiat Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) Reserve Pit N lA Well Sign OK Drl. Rig OK BOP STACK: Quan. Annular Preventer 1 Pipe Rams Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves HCR Valves Kill Line Valves Check Valve /ViA Test Pressure 500/2,500 P/F P P P P P P FLOOR SAFETY VALVES: Quan. Upper Kelly / IBOP ,_ Lower Kelly / IBOP Ball Type Inside BOP Pressure 500/5,000 500/5,000 500/5,000 500/5,000 P/F MUD SYSTEM: V'suai Alarm Tdp Tank YES YES Pit Level Indicators YES YEs Flow Indicator YES YES Gas Detectors YES YES CHOKE MANIFOLD: No. Valves 16 No. Flanges 42 Manual Chokes 1 Hydraulic Chokes 2 Test Pressure 500/5,000 500/5,00O Functioned Functioned P/F P P ACCUMULATOR SYSTEM: System Pressure 3,000 I P Pressure After Closure 1,550J , P 200 psi Attained After Closure 0 minutes 26 _ sec. System Pressure Attained 2 minutes 25 sec. Blind Switch Covers: Master: YES Rem(~te: "YES Nitgn. Btl's: 6 ~ 2650 AVG. Psig. .. ! Numberof Failures: 0 ,Test Tm~e; 3.0 Hours. Number of valves tested 26 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Wdtten or Faxed verification to the AOGCC Commission Office. at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I I I I I I I I I I II REMARKS: Good test!! All equipment in good condition. Distribution: orig-Welt File c - OperJRig c- Database c - Tdp Rpt File c- Inspector Waived By: Witnessed By: Dcrq. g Amos FI-021L (Rev. 7/19) . AZ1HEQBD~(LS MEMORANDUM TO: THRU: State Alaska Alaska Oil and Gas Conservation Commission P. I. Supervis~ . FROM: John Spaulding,~~'4~ SUBJECT: Petroleum Inspector DATE: March 23, 1994 FILE NO: EZILCWBD.doc Diverter Function Test Pool 7 BPX Well NK-23 Niakuk Field P.T.D. 94-~5 Wednesday March 2..3., 1994: I traveled to BPX Niakuk Field well NK-23 to witness the diverter function test on Pool Rig 7. As the attached AOGCC Diverter Function Test indicates no failures were noted. The pad area has a lot of activity with construction of flowlines and facilities. The west diverter line is in the area of the workers and was a concern of mine, I spoke to Dan Hebert BPX rig rep. about the problem and was informed that the rig has an external horn to warn the workers of any rig problems. I also requested that no heaters be placed within 100 feet of the end of the west diverter line. 'Jim Davidson Pooi tool pusher informed that if the rig had to use the diverter system that they would use the east line first. Summary: I witnessed the Diverter Function Test on Pool Rig 7 BPX / Niakuk Field no failures, 2 hours. Attachment: EZ1LCWBD Drlg Contractor: Operator: Well Name: Location: Sec. STATE OF ALASKA ~/"~ ALASKA OIL AND Otis coNSERVATION COMMISSION Pool BPX NK-23 36 T. 12N R. Diverter Systems Inspection Report Date: 3/23/93 Operation: Development XXX Exploratory: Rig No. 7 PTD # 94-35 Rig Ph. # 659-4815 Oper. Rep.: Dan Hebert Rig Rep.: Jim Davidson ,,, . . 15E Merdian U.M. MISC. INSP~ONS: Location Gen.: OK Housekeeping: OK ((3eh.) Reserve Pit: NA Well Sign: OK Drlg. Rig: OK Flare Pit: HA DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: Yes Valve(s) Auto & Simultaneous: Yes Vent Line(s) Size: 10 Vent Line(s) Length: 100 Line(s) Bifurcated: Yes Line(s) Down Wind: Yes Line(s) Anchored: Yes Turns Targeted / Long Radius: NA in. in. ACCUMULATOR SYSTEM: Systems Pressure: 3000 psig , Pressure After Closure: 1800 psig 200 psi Attained After Closure: min. 27 sec. Systems Pressure Attained: 2 min. 23 sec. Nitrogen Bottles: 6 botties'~650 average MUD SYSTEM INSPECTION: Light Alarm Tdp Tank: OK OK Mud Pits: 6K OK , Flow Monitor: OK OK GAS DETECTORS: Light Alarm Methane OK OK Hydrogen Sulfide: OK OK psig Wind Direction Pool 7 North Non Compliance Items Remarks: Repair Items Within Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - 0per/Rel) c - Database c - Trip Rpt File c - Inspector AOGCC REP.: OPERATOR REP.: John H Spaulding Dan Hebert EZ1LCWBD.XLS DVTRINSP.XLT (REV. 1/94) 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 March 4, 1994 Terry Jordan, Drlg Engr Supv BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 9951-6612 Re: Well Name Company Permit # Surf Loc Btmhole Loc NK-23 BP Exploration 94-35 1410'NSL, 679'WEL, Sec 36, T12N, R15E, UM 1500'SNL, 2018'EWL, Sec 28, T12N, R16E, UM Dear Mr Jordan: Enclosed is the approved apPlication for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) mUst be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of injection wells must be demonstrated under 20 AAC 25.412 and 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Sect - w/o encl Dept of Environmental Conservation - w/o encl r~ printed on recycled paper b y C,t'tl. STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill Clllb. Type of well. Exploratoryn Stratigraphic Test [] Development Oil [] Re-Entry [] Deepeni-II Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 60 f e e t Niakuk Pool 3. Address 6. Property Designation P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 34634 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25,025) 1410'NSL, 679' WEL, SEC. 36, T12N, R15E Niakuk At top of productive interval 8. Well number Number 1117' NSL, 1114' EWL, SEC. 28, T12N, R 16E NK-23 2S 100302630-277 At total depth 9. A~ro_p~imate spud date Amount 1500' SNL, 2018' EWL, SEC. 28, T12N, R16E -d'~ '"'~ $200,000.00 12. Distance to nearest 13. Distance to nearest weli' ~er of acres in property 15. Proposed depth (MD and'rVD) ~ property line ADL 34635-2018 feet NK-22-30'@ 1050'MD feet 2560 17877'MD/10100' TVD feet 116. To be completed for deviated wells 17. Anticipated pressure (see 2o ^^c 25.035 (e)(2)) ..,,.- Kickoff depth =oo feet Maximum hole angle 6o o Maximum surface 3330~psig At total depth (TVD) 8800'/4390 psl~ . 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD MD TVD (include stage data) 30" 20" 94~ H-40 Weld 80' Surface 80' 80' 260 sx Arcticset 16" 13-3/8" 68# NT-80 B TC 5604' 41' 41' 5645' 3980' 1691 sx PF "E"/375 sx "G"/250 sx PF "C" 12-1/4" 9-5/8" 47# VT80-S NSCT 14959' 41' 41' 15000' 8705' 393 sx Class "G" 8-1/2" 7" 29# 13CR80 NSCT 3027' 14850' 8835' 17877' ~10159' 551 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Surface Conductor RECEIVED Intermediate Production Liner Alaska Oil & Gas Cons. Commission Perforation depth: measured true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed reportl-I 20 AAC 25.050 requirementsl-J 21. I hereby certify that t~'~ ~o~g, oing is true and correct to the best of my knowledge Signed F~tt,~),// ,~~'(~'~ Title Drillin~l Engineer Supervisor Date L~! Commission Use Only Permit Number IAPI number IApproval date ISee cover letter I5°- ~'- ~ ~ ~',>"'._.<"~ Ifor other requirements Conditions of approval Samples required [] Yes '~ No Mud log required []Yes ~ No Hydrogen sulfide measures [] Yes '[~ No Directional survey required ~ Yes [] No Required working pressure_.for. P,~..PE ~. 2M; I-]3M; ~35M; I-I10M; I-I15M' Other: .... ~.-:,~¢¢,---.:,**~u.,.,~u_By by order of Approved by Form 10-401 Rev. 12-1-85 Submit cate Well Name: J NK 23 Well Plan Summary IType of Well (producer or injector): I SEAWATER INJECTOR I ISurface Location- Target Location: Bottom Hole Location: 1410 FSL, 679 FEL, SEC 36, T12N, R15E 1117 FSL, 1114 FWL, SEC 28, T12N, R16E 1500 FNL, 2018 FWL, SEC 28, T12N, R16E IAFE Number: IRig: I POOL#7 I Estimated Start Date: 1 3/10/94 I I MD: !17877 I ITvD: IWell Design (conventional, slimhole, etc.): IOperating days to complete: 136 I lingo I IKBE: 160' JConventional big-bore. Formation Markers: Formation Tops MD TVD (BKB) COLVILLE WEST SAK BASE WEST SAK HRZ KUPARUK 16739 9584 F E TD 17877 10100 Ai~,~ka 0il & Gas Cons. Commission Anchorage Casin(i/Tubing Proqram: qw v y Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVDbkb MD/TVDbkb 30" 20" 94# H-40 WLD 80' GL 80/80 16" 13-3/8" 68# NT-80 BTC 5604 41 ?41 5645/3980 12-1/4 9-5/8 47 NT-80S NSCT 14959 41'/41 15000/8705 8-1/2 7 29 13CR80 NSCT 3027 14850/8835 17877/10159 TBG 4-1/2" 12.6# 13CR80 NSCT 14809 41'/41 14850/8835 NK23 Well Plan Summary Page 1 Logging Program: I open Hole Logs: SURFACE PRODUCTION ICased Hole Logs: Anadrill directional MWD only. Anadrill MWD Tdple Combo from top Kuparuk to TD. Atlas wireline CIBL Cement Bond Log (After Rig Release) Mud Program: ISpecial design considerations 3% KCL mud for Kuparuk formation damage control. Surface Mud Properties- I Spud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.7 300 40-60 30-60 60-80 9-10 15-25 Intermediate Mud Properties: start I Fresh LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel gel Loss 9.5 50 20-40 15-20 20-30 9-10 10-20 THE INTERMEDIATE MUD WILL BE CHANGED OUT A T CASING POINT Production Mud Properties: Kuparuk 13% KCL Density PV Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.5 8-15 25-30 5-15 10-20 9-10 10-15 10.0 15-30 25-30 8-12 <25 9-9.5 4-15 <15HTHP Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressu res. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. RECEIVED F~ 2 5 1994 Well Plan Summary NK23 Oil & Gas Cons. Commission Anchorage Page 2 Directional: I KOP: 1 300'; De[:)arture to TD=13915' IMaximum Hole Angle: J60°, Azimuth=67° Close Approach Well: ]NK 22, 30' @ 1050' md The above listed wells will be secured during the close approach. NE23 R[CEIVED .,.~:--..!a.~sl..*,a Oi! & C-as Cons. Corr~mission Well Plan Summary Page 3 Surface Casing Depth: Surface Casing Size: Surface Casing Weight: Bit Diameter: Excess Factor Intermediate Casing Depth: Intermediate Casing Size Intermediate Casing Weight: Proposed Top of Cement Bit Diameter: Excess Factor: Liner Size: Liner Weight: Hole TD Bit Diameter: Excess Factor: NK 23 Cement Volumes Surface String 5645 13 3/8 68 16 1.7 LEAD (TYPE "E" PERMAFROST) Yield 2.17 Density 1 2 #sacks 1691 (3670 Cu. Ft.) TAIL (CLASS G) Yield 1.16 Density 15.8 # sacks 375 (435 Cu. Ft.) TOP JOB (TYPE "C" PERMAFROST) # sacks 250 (235 Cu. Ft.) .94 cuft/sx 15.6 ppg Production String 15000 9 5/8 47 14000 12 1/4 1.4 Liner LEAD Yield 1.98 Density 1 5 # sacks 0 # bbls 0 TAIL (CLASS G) Yield 1.2 Density 15.8 # sacks 393 # bbls 8 4 ( 0 Cu. Ft.) (471 Cu. Ft.) 7 29 17877 8.5 1.4 TAIL (CLASS G) Yield 1.2 Density 15.7 # sacks 551 (661 Cu. Ft.) . , , . . . . , . , . . MIRU drilling rig. NK 23 Operations Summary Spud well and drill 13-1/2" hole to 300' md. Kick off and build angle to 60°. Drill to surface casing point. Set 13-3/8" casing and cement same. Test casing to 3000 psi for 30 minutes. Nipple up BOP's and test same to 5000 psi. Pick up 12-1/4" BHA and drill 10' of new hole and perform leakoff test. Continue drilling to casing point. Run 9-5/8" casing and cement same. Pick up 8-1/2" BHA and RIH. Change over from fresh water mud to KCL mud. Drill out 10' of new hole and perform an FIT. Drill 8-1/2" hole to TD. Set 7" casing and cement same. Test casing to 3500 psi for 30 minutes. Run 5-1/2" carbon tubing. Displace to diesel. Freeze protect the annulus. Release rig. Run cased hole logs: cement bond log. Pr udhoe ]Bay Dmillin9 udhoe Bay, Atastxo WELL: Ni kuk NK-P3 TV~ REP WELL~A~ VE~TIC~_ SECTI~ REF. ~LL~A~ .r'o0 ~ _---:__ 1ll~4 I-O~IZENTAL VIEW (TRUE N[IRTH) SCALE 1OCli Fi:. / DIVISIEN SURVEY IL)CF: WELLHEAD I I 5503 ~ 6500 7000 7'3OD 80CO 8500 gOOD ~'JfD II~OO IO'3OO IIIDI30 II,CO, Ic~OO 1~OO 13000 VERTICAL SECTIEIN PLANE; 67.30° f 1 IIEQ3 ! 2~CDO 1CX~D t To,'?t I HALL]BUI~TDN TVD O-;d X G,id h' 9584 733657 ~53C~. [ CASING F~3INT DATA J OD MD ]nc AZ; TVD NIS E/W ! 13 3/8 ,n ~1 5a66° 67.07° 48~ 1404 N 3%1 E l 9 5/8 in 157~ ~.66° 67,07° ~ 4638 N11107 E TIE IN KD~ / ST/~RT El: DJILD ~ ) ,CO°/100 Fi STAP, T E}- BUILD ~ 1.50°/100 Ct START EY BUILD ~ k.O0°llO0 Ft START [}- CLRVE ~ 8.50°/100 ~± END Et- CURVE TI]~ TuFFs Torget I CRITIC/N_ f:~]INT DATA MD Inc Azi. 0 0.00° 0.00° 300 O.OCP 0.00° TVD N/S E u,- o 300 0 N 0, 600 3.00° 75.O3° 600 ~ N ,'3 E 0C)0 9.OCP 75,03° ,ex)7 13 N 48 [ 400 17.0C? 7500° 1387 36 N 1 ~ E 3114 50.66° 67.07° '87C~ 407 N 110.4 7070 50.66° 67.07° 147C0 1737 N 4~48 ]4711 50,66° 67.07° ~ 430~ NIO_R~8 16739 50.66° 67.07° ,c~584 4987 Nl1933 PRO:q~EDB~L TVD 10159.L::~3 MD 17877.10 VS 13915.68 N/S 5369.75 N E/W 1c~837.gl E D~te .~otted ~/10/94 Cheated By : Checked By ' : Apl:~'oved By : Date, : , Pr"udhoe Boy Dr'i ling Pr', udhoe 80 y, A[o, sl-<o, Watt: Niakuk NK- 3 WetLpo.±h: NK-?3 WP5 Travelling Cylinder - Least Distance ReFerence Well - ~',-~3 hJD 0 - 17877 Ft. In'catv01, 50 All Dir'ec±ions I~el ±o -[nue Ncc±¼ HALLIBL~TON I:~ILL ~ S~SIC~S ~l~OIg4 7:16 pm 330° 55O 3O° 4,50 o,.~D 27O° 240° 400 3~3 /' · /. _ ./ /' // l [ lo,..qe. 't Nor-e 1'VD l'.g ['W Ctid X Crld Y [lo,'.?t I gC--~44.(~7 N 11933 E 73'~57 CAS]I ~Z, FglN1 OD N~,.n Ir,c AZl TVD 13 3/8 ;n fiJ-J~l5066° 6707° 4~)0 1404 N 3461 E O 518 in 1'5700 5966° 67.07° gODg 4638 NI1107 E CPI[IC~I- POiNI' Da, lA - I 24 .rog 3~1~ ~ ~_~) OD ~.4 Q 7B 5 2~ I [U~lp~h Slol t~<-22 G~o ~1<- 22 hi~, -P~ ~ N~-22 CLOSESI J~stor Ce['h-~'C-ti~, F'Ef I4D EgD:?_ ~-'~..2'8·0 _r'n ....... ~9 G&s CoBs. CorrlmJssion Anchorage I~[I loc AZL 1 VD N/S E/~/ lIE IN 0 000° 000° 0 0 N 0 E kL'-~ / %IAPI _'300 orJg° O.OCP 300 0 N 0 E CF _~JILD @ 1 .DD°/I00 £t Slt-~l II- BUILD 60g 30rjo 75.00o 600 8 N 8 E m_ 1.50~/100 Ct STA~T Et- BUILD1000 g00~ 7500° Og7 13 N 48 E ~ 2COO/100 ct SLAP! Or- 1400 1700° 75.00° 1397 ~ N I~ E O?vE o 2 50°/103 [l,IP Or CLI~V[ 31.1,I 5966° 6707° 27C1~ 407 N II04 [ 7070 5066° 6707° 4700 I737 N 4~48 E I[~ i,.,rrs 14711 59E~5° 6707° 8~90 43¢J5 N10382 E lo,,,~t I 16739 59;~6° 6707° 9594 4997 N! lg33 E Dote Rotted 8/10/94 C,'eoted By : CI-ecPecl By App,,oved By WELL PERMIT CHECKLIST · dev [] redrll [] serv~ ON/OFF SHORE ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached .................. Lease number appropriate ............... Unique well name and number .............. Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ..... Sufficient acreage available in drilling unit ..... If deviated, is wellbore plat included ........ Operator only affected party ............... Operator has appropriate bond in force ......... Permit can be issued without conservation order .... Permit can be issued without administrative approval...Y~--'~ Can permit be approved before 15-day wait ....... ENGINEERING APPR 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in surf csg to next string .... Y ~ 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list a~equate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~~ psig.~ 27. Choke manifold complies w/API RP-53 (May 84) ....... Y 28. Work will occur without operation shutdown ....... ~~ 29. Is presence of H2S gas probable ............. Y N N N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y N/ 32. Seismic analysis of shallow gas zones .......... Y 33. Seabed condition survey (if off-shore) ......... Y/ N 34. Contact name/phone for weeklY[exploratoryprogreSsonly]reports ..... / N GEOLOGY: ENGINEERING: COMMISSION: . Co~ents/Instructions: Z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. NK - 23 NiAKUK Run 1: 15 - June - 1994 GR/TEMP Cased Hole 425O 16758 WESTERN ATLAS Atlas Wireline Services Tape Subfile 2 is type: LIS TAPE HEADER NIAKUK 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 NK - 23 500292245500 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 20-JUN-94 6203.02 BRAD ESARY C. MICHEL 36 12N 15E 1410 679 60.10 60.10 19.20 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 14673.0 47.00 7.000 17535.0 29.00 5.500 14512.0 17.00 4.500 16769.0 GR/TEMP. LOG TIED TO WIRELINE MARKS. GR FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. STATIC WELL CONDITIONS, BASELINE TEMPERATURE LOG. REMARKS: BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH -- PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GR GRCH 1 1 15-JUN-94 ATLAS WIRELINE SERVICES FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 14243.0 16748.0 TEMP 14252.0 16758.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE: PASS NUMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH MAIN PASS. NO DEPTH SHIFTS WERE APPLIED AS GRCH IS THE DEPTH REFERENCE FOR THIS WELL. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : NK- 23 : NIAKUK : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 2 TEMP TEMP 68 1 DEGF 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 21 990 60 6 4 06 033 97 0 * DATA RECORD (TYPE~ 0) 1014 BYTES * Total Data Records: 61 Tape File Start Depth Tape File End Depth = 16776.000000 = 14232.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15268 datums Tape Subfile: 2 148 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 14243.0 TEMP 14252.0 $ 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 SB SB PCM CCL GR CENT TEMP $ SINKER BAR SINKER BAR PULSE CODE MODULATOR CASING COLLAR LOC. GAMMA RAY CENTRALIZER TEMPERATURE 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 (DDM) : 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: STOP DEPTH 16762.0 16774.0 15-JUN-94 FSYS REV. J001 VER. 1.1 1249 15-JUN-94 17435.0 16760.0 14250.0 16758.0 1800.0 YES TOOL NUMBER 8250EA 8248EA 8220XA 8232NA 8221XA .000 17535.0 .0 SEAWATER/DIESEL CAP .00 .0 191.2 0 .0 .000 .000 .000 .0 .00 HOLE CORRECTION (IN): . 000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN) : .0 REMARKS: MAIN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : NK - 23 : NIAKUK : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 1 GAPI 4 2 TEMP TEMP 68 1 DEGF 4 3 DTEM TEMP 68 1 DEGF 4 4 CCL TEMP 68 1 4 5 SPD TEMP 68 1 F/MN 4 6 TEN TEMP 68 1 LB 4 4 21 990 60 6 4 06 033 97 0 4 63 705 65 0 4 33 880 89 0 4 16 069 32 6 4 50 533 32 6 24 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 283 Tape File Start Depth = 16776.000000 Tape File End Depth = 14232.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 71240 datums Tape Subfile: 3 Minimum record length: Maximum record length: 361 records... 62 bytes 1014 bytes Tape Subfile 4 is type: LIS 94/ 6/20 01 **** REEL TRAILER **** 94/ 6/21 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 21 JUN 94 2:49p Elapsed execution time = 32.40 seconds. SYSTEM RETURN CODE = 0 RECEIVED UAR 2 1 199,5 * ALASKA COMPUTING CENTER , ****************************** *------- SCHLUMBERGER -------* ~mmmm~m~mmmmmmmm~mmmmmmm~m~ ****************************** ~ELL NAME STATM API MUM~MR REFERENCE BP EXPLORATION (ALASKA} NK-23 MIAKUK NORTH SLOPE ALASKA 50'029'22455 * ~bA~KA CON~U~ING CENTER ~ ~mmmmmmmmmmmmmmmmmmmmmmmmmmmm~ * ..... -- $CHt~UMBERGER -------* ****************************** COMPANY NA~E : BP EXPLORATION WELL NAME ~ NK-23 FIELD NAME : NIAKUK BOROUGN ~ NORTH SLOPE STATE : ALASKA API NUMBER : 50-0~9-2~455 REFERENCE N© : 94331 i$ TaDe Yerlflcat~on tistinq :hlumberqer Alaska Computinci Center 2~-OCT-!9q4 16:44 O~ICI~ : FLIC CONTiNUAI'IUM # : COMuE~'r : ~P EXPLORATIf]N, NK-23, NIAKUK, tPI 50-0~9-22455 DATF : 94/10/14 ORICI~ : Fb!C TAPF M^~E : 94331 CONTINUATIOM # PREVIOUS TAPE COMMENT : BP EXPI~ORATi~N, NK-23, NIAKUK, APl 50-0~9-2~455 TAPF NIA~JK ~WD/~AD LOGS # WELL LOGGING COMPASY~ T~P~ CRFATION DATE~ OPERATIN~ WITNESS: SURFACE LOCATION SECTION: FSL: FEL~ CLCVATION(FT FROM ~i~ O) 5002922455 BP EXPLORATION (AhASKA~ SCHLUMBERGER WELL SERV CES ~4-0CI-94 BIT RUN IL BlT RUN 2 BlT RUN 3 N ICLOS M1CL08 NICLOS 36 1410 679 60,10 J, 9,20 ~.~00 q,625 14'673.0 PAGE~ I IS Taoe ¥oriflcation l, istiI!q gblumberger ~lasKa Computinq Center 26-OCT-19Q4 16:44 3RD ST!~.I HG PROL~UC'r I G,~ RE~aaRKS: DEPTd AS LOGGED SHIETED DEPTH ~TT RUi,~ [ 10114 - 16741 16120 - 16757 31T RU~ 2 16741 - 17195 16757 - 17210 SIT RU~ 3 1.7195 - 17535 17210 - 17550 $ # LIS FfiR~AT DATA LT$ FORe, AT DATA PA~E~ FILE ~'~E : EDIT ,001 SERVICE : FLIC VERSI~ : 001C01 MAX REC SIZE : !074 FILE TYnE ~ LO FILE ~EADER FIL~ HUMBER: t EDITED ~ERGED ~WD Depth sn~ted and clipped curves: ail bit rubs merged. DEPTH I~CRE~E~:I!: O,5QoO # F!LF StJuMARY LDWG TOOL CODE B,~S~bII4~ CURVE FOP S~ilFTS: GR CURVE SPlFT O~'t'A (~EASUPEP nEPTH) BASE~,I~E DEPTk! I67oa,,5 166I~,5 1655~,5 ~64~7,0 ~6470.0 ~64i4,5 ~6370,5 16357.5 START DEPTH 17526 0 17094.0 STOP DEPTH 1~ 15998,0 --- ....... ~TQ!!IVALENT UNSHIFTEP DEPTH----- ..... 16720.0 16628,0 !65~5.5 1.65i~,0 16503.0 16404,5 1642a,0 1638fi,0 16378,5 16365.0 89. 99 St a9 ~a ~ 0 99 ~ 0 99 I # $ H~d~O O'OIELt O"LSL9t O'L~Lql 0'~66~t 0'gESL~ O'Ot~Lg E O'Ot~Lt O"LGLgl O'Ot~LI O'ELOgl $ MOO3 qOO£ g'90I S'g819[ O'9LI9[ S'u6t9~ O'LOg9I 0'8619[ g'~!ggl g'6Ogg~ o'9~9t ~'6£ggg O'L~ggl §'0999I ~'~gggt 0'6g~9~ Tape verifi, catlo~ [istlnq :blumberger AlasKa Computing Center 26-0CT-!994 16:44 ...... ' ..... ........ ...... ' .............. ' ............. RV U~IT SER ~ AP1 I APl AP1 FILE NU~ NUmB SIZE REP PROCESS D OROER ~ bOG TYPE CLASS ~OD gU~iB SA~P ELEM CODE .(HEX) ................... . ..... .--;;- ............... . ........ ...... .....;...... .... DEPT FT O0 000 0 1 1 I 68 000000000 R~OB ~D G/C3 O0 nO0 O0 0 I 1 i. 4 68 0000000000 DRHO ~D G/C3 O0 000 O0 0 1 I 1 4 68 0000000000 PEF ~WD 8N/E O0 000 O0 0 i ~ 1 4 68 0000000000 CILN MwD IN Oo 000 O0 0 I 1 1 4 68 0000000000 NPHI ~C) PU-$ 00 0O0 oO 0 i 1 1 4 68 0000000000 ~l ~WD O~a~ O0 000 O0 0 1 1 1 4 68 0000000000 RP g~D OH~ O0 000 O0 0 1 1 1 4 68 OOO0000000 DER ~;4D 0}t~}~ 00 000 00 0 i 1 1 4 68 0000000000 V~P ~D OHa~ O0 000 O0 0 1 1 t 4 68 0000000000 VRA ~D OH~ O0 000 O0 0 I 1 t 4 68 0000000000 ROP ~O FPHR O0 000 O0 0 i 1 i 4 68 0000000000 GR ~D GAPI 00 000 00 0 i 1 I 4 68 0000000000 NCN~ ~D CPS O0 000 O0 0 1 1 I 4 68 0000000000 FCNT ~D CPS O0 000 O0 0 1 1 I 4 68 0000000000 FET ~W[> H~ O0 000 O0 0 1 1 1 4 68 0000000000 GRCH ~R GAPI 00 000 00 0 1 1 I 4 68 0000000000 DATA ** DEPT 17549.500 PHOB.MWD -999.~50 DRHO.MWD -999.250 PEF.MWD CALN:~v[] -999,250 NPHI,MWI) -999.250 RA.MWO 999.250 RP,MWD DER.M~D -999,250 VRP,.MWD -999.250 VRA,MWD ~999,250 ROP.MWD GR.N~D -999,250 ~CNT.MWD -999 ~50 FCNT GRCM,GR -999,250 . ,MWD 999.~50 FET,~WD DEPT 17500.000 RHOB.Swp -999.250 DRNO,~WO -99~.250 C~LN~WD -909,250 NPNI,~W.~ -999.~50 RA,hWD ~..012 RP:~WD DE~.~¢:D !.958 VRP.i. iWD 1.96~ -I~VR,'A*~4WD 2,104 ROP,~WD GR,NwD 100 ~4~ ~JCNT,MW'D -999 ~50 FC~I'~WD -999,~50 FET,MWD G~CM,CR -999'.250 ..... ' DEPT, 174ou.00!3 RHOM.MWD -999.250 DRHO.~Wi) -999.250 PEF'MWD CaLN,~D -999,2~0 [~IPgl.~i~:,D -999,~50 RA.aWD 5.726 DE~.NWD 5,397 ~RP.M~O 5.~49 V~A.i~WD 5 390 G~CH, ~RGR*c:'~;~D -999o25~70'~52 ~CNT.SWO -999,250 FCNT.~WD -999:250 FET.g~D .-999.250 999,250 . 18,054 999,250 2¸0 '999'9~7 14,470 2,461 '999,250 5,245 26,099 1',245 IS Tape verification l,istil,~ :hlumberger AlasKa Comput~ng Center DFPT. 17300.000 C~LN.~D -999.250 DEP.~ 5.955 VPP.~WD GP.~D 22,963 G~CM.GR -999.250 DFPT. 17200.0~o CALN.M~D -999.250 ~PNI.NWD. DE~.~D 3.679 V~P.~WD GR.~D 62.480 G~C~.Gk -999.25[) D~PT. 17100,O00 PHOB,MwD CALN,u~D -999.250 ?:PHI,MWD DER.~WD 4.359 VRP.MWD GR.~D 60.767 ~!CNT.MWD GRC~.GR -999.250 DEPT. t7000.O00 C~LN.~ 8.577 NP~I.MWD DE~.~D 4.030 VRP,MWO G~,~WP 53.017 ~.iCNT.MWD G~C~.OR -999.250 DEPT. 16900.000 RHOB.MWD CAbN.~WD 8.601 ~IPHI,M~D DEP.~D 2.b39 VRP.MWD G~.~WD ]7.b45 NCNT.~WD G~CM.GR -999.250 D~PT. 16809.000 CAbN.NWn 8,735 NPNI..M%~D DER.~WD 2,903 ~PP,MWD G~CM.~R -999,2~0 D~PT. 16700.O00 CAL~.~'~D. 8.8'12 DER.~,!WD 21.~0o V~P.a~D GP.~W5 -999,250 GPCH,GR 12,682 DEPT. 16({00.o0t,~ PtiOS. iqWL) oEP.H!~D 3.95o GPC~,GR 60.777 DEPT. 16500.000 DEP.~D 3.294 VPP,aWD GD,~WD 2~8.953 GPCM,GR 1!6.368 26-OCT-1994 i6;44 -999.~50 DRHO.M~D -~99.25~ 7.169 VRA.~WD -999.250 -999 250 5!135 7 191 -999 250 -999.250 DRMO.MWD -999.~50 -999.250 RA.iqWO 3.812 3.832 VRA.~WO 4 ~092 -999 250 FCNT ,:WD 999:250 -999.250 DRHO.aWD -999.250 -999.250 RA.~WD 4.448 4.396 'VRA,MWO 4.551 -999.250 FCNT.MWO -999.~50 2.517 DRHU.MWD 20.750 RA.~WD 4.062 VRA.MWD 358.375 FCNT.MWO 2.447 ORMO.MWD 22.300 RA.MWD 2.695 VRA.MWD 350.563 FCNT.MWD 2,829 DRHO.aWD i9.050 RA,MWD 2.998 VRA.MWO 371.375 FCNT.MWD 2.548 ORHO.~WO 31.300 RA.MWO 3.934 VRA.~WO 296.937 PCNT.MWO 36.11~ RA,aWD 3.823 VRA,~WD 282.870 FCNT,mWD PAGEI 008 669 2.680 10'681 0.012 3 .. 097 0 047 PEM.~{%~D ~2.398 19~337 RP.-~,~WD 2.=,400 0.014 3,808 3~650 7.392 0.019 2.895 3.378 6.512 0,021 PEF,MWD 3,012 4.0151, RP.~W'D i!~38 808 FET.~,nD 20 PEF'.M~P -99~:250 RP.MWD 629 FET.M~D 446 PEF.NWD -999.250 RP.M~D i!321 ROP.M'~D 4 445 FET.~WD 397 PEF,.MWD 2' 767 RP,MWD !i624 ROP.~WD 3463 rET.~wD 173 PEF.MWD 6.65! RP.~WO 2,818 ROP.~WD 57,811 FET.~WD 1..070 PEF,MWD 3.605 RP.,M~D 4,037 ROP,.MWD 47,402 FET.M~D 1,847 PEF,~WD 4,521 RP.~'~D 3'644 ROP,MwD 38,013 FET.~WD 2,329 PEF.MWD -999 250 'RP.~,wD 6:266 ROP.~wP 40,984 FET.~{~'D 1,091 IS Tame Veri~.icatiom I.lstlno ~hlUmberger AlasKa Comps]ting Center 26-(]CT-1994 16:44 PAGE: D~PT. 16400.000 C ALN. ~.~ ~'~D 8.500 DE~. N~D 3. 856 ~RP. GR. ~4~D 150,453 DEPT. 163,)0.O00 ~HOB.MWD CALN.~w!} 8.500 i~PHI.~WD DER.~mD 4,909 VRP.MP3D GR.UWD 2~1.98~ NCNT.MWD G~CH.GR I66.509 DEPT. 16200.000 PHOB.MWD C~LN.~D 8.5o0 NPHI.~WP DE~.~WD 4,066 VRP.M~D G~.~WD 170,945 ~CNT,MWD GRC~.~ 94.330 DEPT 16100.000 RriOB.MWD CALM~gWD 10.i74 NPHi,MWD DE~,~D 8,I79 ¥~P.MWD G~.M~[:! 106,855 NCMT.~WD GRC~,GR 46.092 DELP~ 1!950,000 CA ~:~WO 999,25{) DEP, M~D 999,250 G~.~D -999,250 NCMT.~,WD GRC~.GR 58,264 ** END OF DATA 2 603 4,036 V~A.aWO 314.4~3 FCNT,~WO ~.500 DRHO,~WD 43.683 RA.MWO 5.499 VRA.MWD 25~.094 FCNT.~WO 2.348 DRHO.MWD 35.547 RA.MWO 3.887 VRA,MWO 275.408 FCNT.MWD 2.t86 DRHO.MWD 32.150 RA.MWD 9,9~3 VRA.~iMD 281.]75 FCNT.MWD 'g99.~50 DRMO.MWD 36.~50 RA.MWD -999.250 VRA.MW~ 273,229 FCN'T,~WD ~999,250 DRNO,MWD 999.250 RA.MWO -999.250 VRA.~WD -g99.~50 FCNT,MWD 0.011 3.767 3.987 7.937 0.027 4.221 4.639 5.045 0.058 3,968 3~429 6,248 0 OO5 6:135 6,330 7,210 -999.~50 -999~250 -999.250 6,163 999 0 50 PEF.MWD RP.M~D FET.~WD PEF.MWD RP.MWD ROP.MWD WET.~WD PEF,MWD RP,MWD ROP.MWD FET,MMD EF M~D RP:~WD ROP.M~D FEI. MWD PEF,MWD RP..~wD ROP'NwD FET,MWD PEF.~WD RP,MWD ROP..~WD FET,~WD 5.766 3,905 33,809 2,528 4,457 5 2,206 3 752 4:118 20,570 2,150 3~ 74 10 ]62 -999 250 -999 250 '999, 50 -.gv 999,250 '99!, '9g 2 0 -99 ;250 **** FILM TRAILER **** JIbE NAAE : EDIT MRVIC£ : FLIC VER$IO~ : DAT~ ~ 94/10/14 MAX REC SiZE : 1074 FIL~ TYPE : L~S? FII~E 00§ 8 6~OS~D a2~l'l~ qO0£ 6'~§ 0'9ESLt o'£L09t ~'~ alq/l'gt 90Doq 'S~lTl 0'066gi $ (D~Q) NOI&¥NIqDNI ~qOa ~Q29DOq $ O'OPLgI NOD O'O~Lgi aOO 000~'0 ;~3~SaO~qI : 9'1I~ ~gO[ : :~Z19 33a X~w IS Ta~e Ver~f.i. cation Listinm chlUmberger AlasKa Co~?,put, ino Cemter 26-0CT-1994 16:44 TOOL 150.0 0.145 0,131 2.65 8.500 1,000 70.0 70.0 DATA FORMAT SPECIFICATION ~ECORD ** ** SET TYP~ - ~4E~ ** TYP~ .~EPR COD~ VAbUE I 66 0 ~ 66 0 ~ 73 68 ~ 66 1 ~ 73 7 65 ~ 6~ O.5 9 65 ~1 66 lb 13 66 0 i5 66 68 16 66 1 0 6e I IS TaDe ~erificatlon Li~t~t'~q :hlumber.~er AlasK~ Co~pt]CinQ Cer~ter 26-0CT-19o4 !6:44 RV U~.!.LT SE~ C APl I gPI API FILE NUmB ~U B SIZE REPR ~D {i~DEP ~ LOG TYPE CLASS ~OD NU~ SA~P ELEM CODE DEPT FT O0 OOO O0 0 2 ~ 1 4 68 O0 RWOB L~! G/C3 O0 000 OO 0 2 1 I 4 68 O0 DPHI L~ PU O0 OOn OO O 2 1 1 4 68 O0 DRHO L~I G/C3 O0 00o uO 0 2 1 1 4 68 O0 PEF L~I BN/E O0 000 O0 0 2 1 1 4 68 O0 DCAL Lb1 I~ O0 000 uO O 2 1 1 4 68 O0 T~PH L~! PU O0 000 O0 0 2 { 1 4 68 O0 ATR L~I OHM~ O0 000 O0 0 2 1 1 4 68 O0 PSR Lw~ 0~.~ go 000 O0 0 2 l 1 4 68 O0 DER Lw1 0~~ O0 000 O0 0 2 I t 4 68 00 ROPF L~I F/aR O0 000 ga u 2 1 1 4 68 00 G~ [.~ GAPI O0 000 O0 0 2 ! 1 4 68 O0 HENa L~I CPS O0 OOO O0 0 2 ~ 1 4 68 O0 HEFA [.~ CPS O0 000 O0 0 2 1 ~ 4 68 O0 T~B L~I a~ O0 ¢)00 ~0 0 2 1 1 4 68 O0 T~BD L~ t~R O0 o00 uO 0 2 ~ i 4 68 O0 N$I L~I O0 000 O0 0 2 1 ! 4 68 00 PAGE: ROCESS (~X) 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 ~m DAT~ ~* DEPT, 16740 0o<) P~.-iOB LNI -999 250 DPHI,LW1 999 250 DRHO,LWI PEF.L~ -999.25u DCA~,~NI -g99.~0 TNPH,~W1 -999~250 ATR.L~I PSR.L~I -999.250 DER.LWi -999.250 ROPE.,LWI 23:716 GR,LW1 H~N~, L~ ~. -999,250 MEFA.i,W 1 -999.250 TAB,LW~ -999 250 TABD.L~I NSI. L~.~ 1 -999,250 DF. pT. 16700,000 RHOB,b~,!I -999,250 DPHI,~Wl -999,~50 DRHO,LWl PEF,L~J -99g,250 rJCAL,LWI -g99,~50 TNPH,SW1 '999,250 ATR,LW1 PS~,LWI. -999,250, ~ OER,LW1. -999,250 ROPE,LWl. .I08,424 GR,. HENA L~'I -909 250 '{EFA,L~I -999..~50 TAB NSt, L~ ~. -999. 250 DEPT. 16000,00o ~{~,OB. L~s 1 2,31~ DPHI.LWi 16.900 DRHO.LW1 PEF,LW1 2,74i DCAL.LWI 0,175 TNPH,LW1 21,900 ATR,L~I PSR,L~ 38,560 DER,LwI 37.33! ROPE,LW1 33,~86 H~NA,Lv$i 362,3~3 'HEFA.LWi 11.495 TAB, L~I 1,551 TABD,LW1 DEPT. i65n<>.©00 RHnB.h;{t 2.471 DP~I.LW1 10 400 DRHO LW1 PSP.LWI 2,893 {}ER.bWi 2,839 ROPE,LWi 28,557 GR,L~I H~N~.I~,~] 2~,'1,7~<.~ NEFA bWl 6.230 l. B,~W1 2.156 TABD L~I NSI.Lb 1 I DF. PT. 164n0,000 gi.~. Lwi 2.626 DPHI.Lw1 0.[%00 DRNO,LW1 · PE~,LW1 0.49Q DCAL,L~i 0,000 TNPH,LMI 34 700 ATR.LW1 PSP.I,~ 1 2.737 OER.LWi 2.795 ROPE,LWI 22~268 GR,LW1 HEN~.. L~;~ 293..~5(.~ .... ~3FA.. . Lt~I 6. 722 TAB,LWI 2,488 TABD,LW1 '999,250 '999., 250 :999,250 999,250 ~999,250 ~999,250 999'250 '999'250 '0,'028 24,333 25,800 3.335 0.009 2,752 lg~:278 185 0.012 2,911 200,200 5,383 Tape Verification r,istit'~ chlumberger AlasKa Computing Center DEPT 16209.00(* P$~. Lc~ _! 6.2~ 5 DER.LW1 HEN~.I,~ ! 270.563 HEFA.LW1 DF~PT 16100.0o0 ~ttOB.bWl PEF'.[..,~il 2. 802 PSP. b~ ! 9,979 DER. HENA. I~'~, I 274.972 ~EFA.LWI DEPT. l~O00.OOO RPtaB.LW1 PEF.L~I 3.i95 DCAL.LM1 P$~. l,~~1 -999. 250 DER. hW 1 }{MN~. [.~; 1 269.500 ~EFA.LW1 NSI. L~ ~ -9q9. 250 PEF. L~ ~ -999,250 PS~, L~ ~ -9q9. 250 DER. ! -9e9,250 F{EF'A. ~iSI. L~,~ .~ -999 · E~b OF DATa **** FILM TRAILER **** FIbE NA~qE : EDIT .002 SERVICE DATE FILE TYPE LhST FiLE 26-0CT-1994 16;44 ~.226 DP~I.bW1 O.OOO TNPI1.SWI 4.3i0 ~OPE.bwl 5.254 T~.LW1 2.595 DPHI.EWi 0.000 T~PH.bWl 5.823 ROPE.bWl 6.000 TAO.hwl 1,784 DPHI.bW1 O.Olg TNPH.LW1 8,544 ROPC.bwl 6.52i T~B,bWi 2.315 DPHI.hWI 0.638 TNPH,LW1 -999.250 ROPE,LW! 6.1~5 TAO,LW1 -999.250 DPHI.bWl -099.250 TNPH.hW1 '999.250 ROPE.bWl 6.~85 TAB,LWI 25.2OO 42.200 44.131 2.078 3 300 6: oo 24.86! ~.547 51 300 . 33.~00 -999. 50 -999.250 8 O0 -999 250 -999:250 -999.25O -999.250 -999.250 -999.250 DRHO.LWl ATR.LWl GR.LWl TaBD.Lml ATR.LW1 GR.LW1 TABO.LWI DRHO ATRiLW! GR L~I TABD.PWl D~HO.LWl ATR.LW1 GR.LW! TABD.LWI DRMO.LWI ATR.LW1 GR.L~I TABD.LWl PAGE{ 10 0.026 4,,074 2 811 168,311 5.469 082 471 '999,250 999, 2 -999,250 -999.250 -999'~50 -999,250 -999,250 -999,250 Wave Verif~.cation f,istln~ :hlumberDer Al. asKa Computil~q Center 26-OCT-lqO4 16:44 PAGEI 11 S~RVICE : FLTC VERMIm~'~ : ~O~C~I DATE FILE NEADER FILE NU~6Ek 3 Rh~ ~AP Curves and lo9 header data for each bit run l~ separate BTT RUN NU~BE~: 2 DEPTH 1NCRE,~ENT: 0.5(1t00 FILE bD%~G TOOL CODE START C R,D 17195,0 CDN 17195.0 bOG HEADER DATA DATE bOGGED: SOFTWARE~ SURFACE SOFTWARE VERSION: DO~MHOLE SOFTWARE VERS2ONI DATA TYPE (SEnsORY or TD D~ILLER CBT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL CFT): BIT ~OTATING SPEED MOLE INCLIMATION (BEG) TOOL ST~ING (TOP TO BOTTOm4) 'VFNDO~ TOOL COOE TOOL TYPE .. .......... . ........ CDR RESITIVITy CDR RESITIVII'Y Cf)~ POROSITY ~OPEHOLE a~40 CASIi',i~ DATA DRILl, EPS ChSI~,;G D~fPTH (FT)~ BOP E~,~iOI.,E CD~DI TIO¢,,~S ~!I,)[~ TYPE: STOP DEPTH 16620,0 16620.0 files,. 30-APR-94 hO~OS I6,2/blP 2,2 v34 t7535,0 16073.0 17526.0 55.7 56.5 TOOL HUMBER GRSO 2 GRS059 ~DS022 8,500 14673.0 ~0,4 Tape Verification [.,istinq :hlumberqer Alaska Co~.put!nd Center 26-OCT-lqg4 16:44 FLUID bOSS (C3): ~AXI~4U?~ R~iCDNDED TEuPFRATIJRE (D~GF): ~UD A~ ?,AX CIRCULA~IHG ~E,~PEPATU~E : M~TRIX: MATRIX DENSITY: TOOL STAS~DCFF 0.I73 SANDSTnNE 2.65 8.500 I · 64.0 64.0 PAGE: 12 ** DATA FORe, AT SPECIFICATION PECORO ** IS Tare Verification List,no ghlumberQ~r AlasKa Compusinq Center 26-0CT-1994 16:44 PAGE{ 13 DEPT F? RHOB [,~? G/C3 PKF L,'~2 BN/K DCA[. Li:'? PSR L~2 D~R L~2 OHl,i~ GR !,~.2 GAPI HKNA L~2 CPS H£F~ [,W~ C $ T~B L~ HR T~BD LW? AN ~ ~ AP1 ApI APl b~G TYeK CLASS O0 GO0 O0 O 3 1 1 4 6 O0 OOO Oo O 3 1 1 4 6 O0 000 O0 () ] I J. 4 6 GO nUO OO 0 3 1 I 4 6 uO 000 O0 0 3 1 1 4 6 On OOO ,;O 0 3 I ! 4 6 GO 000 uO o 3 I 1 4 6 On O~O gO 0 3 t 1 4 6 O0 000 O0 O 3 1 1 4 6 O0 000 O0 u 3 1 1 4 6 O0 o00 O0 O 3 ! 1 4 6 O0 OOO O0 O 3 I I, 4 6 O0 OOO O0 0 3 t 1 4 6 O0 00o On 0 3 I 1 4 6 On 000 O0 0 3 1 1 4 6 O0 000 O0 O 3 1 t 4 6 (HE 8 00000 8 00000 8 00000 8 00000 8 00000 8 00000 8 00000 8 00000 8 00000 8 00000 8 00000 8 00000 8 00000 8 00000 8 00000 8 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 DEPT P E F: HENA.Lv~2 DEPT DEPT DEPT. DEpT DEPT. 171~5.000 -999.250 -909.25<> -999.250 171 O0. -999,250 4,768 -999. 250 17000 · 0 3 3.73i 352 · 1690 O. 2.761 3.052 355.464 16800. 35~.35L~ 20. 377 379.37h RHOB,,LW2 DCAL.L{~2 DER. h~ 2 A b ~ L ~ 2 DER. LW 2 HEFA. L~'~ 2 DC~. LW 2 DER. L~W 2 PHOB. DER, LV~ 2 r)cab. L: 2 -999 250 OPNI.LW2 -999,250 -999:250 tNPH.LN2 -999.250 -9~9.250 gOPE,LW2 . 30,928 -999.250 TAB,LW2 999.250 -999.250 DPHI,5~2 999.250 -999.250 TNPH.LW2 :999~250 4.830 ROPE,hW2 41.475 -999.250 TAB.bw2 1.728 :o2s 21..o00 3,817 ~OPE.L~2 45,285 11.093 TAB.~W2 1.433 2.453 DPHI.L~2 12.700 0.017 ?NPH.LW2 21.600 3.0q7 ROPE.bW2 33,645 ~i.593 TAB.L~2 1.662 2.7~1 DPNI.Lw2 -6 700 0.1~7 T~PH.L~2 21:000 ~,6q5 ~OP~. b~2 51.429 11.56~ I'A ~, b:;~ 2 1.!.03 2.4u6 DPHI.bW2 14.100 ~.I01 TaPii. L~2 16.600 19.400 ~OPE,LW2 -999.250 14.641 TAb. L~2 -999.250 DRHO.LW2 ATR,LW2 GR.LW2 TABD.LW2 ORHO.L~2 ~TR LW2 GR:L~2 TABD.L~2 DRHO.LW2 ATR.LW2 GR.L~2 TABD.L~2 DRHO.LW2 ATR.LW2 TABD.L~2 DR~O.L~2 ATR.L~2 GR,L.2 TABD.LW2 DRHO.LW2 GB.L~2 TABD.LW2 i99 .250 99~.,250 999, '999,250 58~811 '999.250 0,003 4'015 49'233 3,056 3,039 42',244 3'131 0.~!1 Io 73 43.233 3.172 0.012 14,015 25,178 '999,250 IS wa~e Yeriflcatlon Llst!n~ chlumberger AlasKa Co~putinq Center 26-DC~-1994 16g44 PAGE{ 14 P~F. L:,;2 -999.250 OCAL. L!~:; 2 PS~. L~,; 2 -999.25~ DER. L~2 7,175 DPWI.LW2 -99~.250 TNPH.LM2 -o99.250 ROPE.LW2 9.440 TAB.LW2 -999,250 DRMO.LW2 -999.~50 ATR.L~2 -999.250 GR.LW2 -999.250 TABD.L~2 "0,021 -999.250 -999.250 -999.250 ** E?'iu OF r~ATA **** FILE TSA1LEN FILE NA~!E : ~DIT .003 VERSIO~ : O0~COI DATF : 94/!0/14 MIX RMC SIZE : 1074 FILE TYPE : LO LhST WILE **** FILE HEADER FIL~ NA~E : EOIT ,0~4 SERVIC~ : FLIC VgRSIOi~ : 001C01 D~T~ : q4/10/!4 MAX RFC SIZE : FILM TYPE : LAST FILE Curves and loq header data ~or each bit run in separate BIT RUN NU?~BER; 3 DEPTH INCREMENT: 0.5000 ~IL~ SUUNARY I, DWG TOOl, C~DE START LEPTA! $ LOG HEADER SOFq,'WARE~: ~URFACE S~FT~A~E VERSION: Do~NNCILE SOFTWARE DATA TYPF (~iEt40~¥ or REAI,-Ti~E): TD DRI[,LER TOP LOG 7NT~PVAb ~OTTn~4 b~G i~''~'' .... STOP DEPTH 17050,5 files, 30-APR-94 LOGOS i6,2/bIP 2.2 V34 17535.0 16073,0 17526,o 0'~9 0'~9 00~'8 ~9'~ ~LI'O 0;0~ 8 6~09~D # :XY~I~u ~b~OIiI~O3 3qOfl3~O~ $ A£igcJ~Od A%IAi&I9~ ~dX£ 'IOO& ~Q(JD qoo& (~O£iC}~ fi& dO&) DqI~£9 IS Tame ver~f2i, catlon Llsti~nm chlumberqer AlasKa Comptltin~ ('enter 26-OCT-1994 16:44 16 3 73 4 ~6 5 66 6 73 7 65 B 68 0.5 9 65 ET 11 66 36 1~ 68 13 6~ 0 15 6b 68 16 66 0 ~6 ** SST 'FYPt~ - NAM~ SMRV LiN IT SERVICE ~----.--------;~- .... .--:--;---. .... --~---- .... -...~-.-..- I AP1 API I FILE UM NUMB SI REPR PRO ESS TO ~RDER ~ LOG TYPE CbASS MOD MUMM SAMP ELEM CODE (HEX) ATR Li~3 OHM~ O0 000 00 0 ~ 1 ! 4 68 0000000000 PSR LW3 OM~ 00 000 00 0 6 i 1 4 68 0000000000 DER I.~3 O}~M O0 O00 O0 0 4 1 I 4 68 O000000OO0 ROPE I,~3 FtH~ O0 000 00 0 4 1 I 4 68 O000000O00 GR Lw3 GAPI O0 OO0 00 0 4 ~ I 4 68 0000000000 TAB L~3 HR OO 000 00 0 4 I 1 4 68 0000000000 ** DA.TI a* DEPT. 17535.000 ATR.LW3 -999.~50 PSR.bW3 -999.~50 DER.L~3 -999,250 RO:P~.I~3 16.667 ~R.LW3 -999.~0 TA~.L~3 -999.250 · DEPT. 17500.O00 ATR.LW3 1.445 PSR.LW3 1.263 DER.LW3 1.3~6 ROPF.LW3 13.~13 GR.I,W3 -999.250 TA, B.LW3 1.793 OEP.. 17409.Oo0 ATR.LW3 5.239 PSR.bW3 4.507 DER bw3 4.734 ROPE. L~'~ ~8,614 GR.LW3 71.9b~ TAB,LW3 0.905 DEPT. 173oQ.9(>{~ ATR.LW3 3.569 PSR.Lw3 3.617 DER.LW3 ~.600 ROPE.L~3 32.668 GR.LW3 2~.~2~ TAM,Lw3 ~.024 DEPT. 17200.i~007 A~R,L~w3; 3.895 PSR.LW3 3.824 DER.LW3 3.847 ROPF.LW3 , 7.58~ GR.b 3 56.808 TAB.~3 0.639 D~PT 17100,0~0 ATR.L~3 -999.25~ PSR.[~w3 -999250 DER.LW3 -999,250 RUPE:L~3 '-909.25(~ (,;R.l~k;3 -g~.25~ TAB.LW3 -999~250 ~ : ~ 0'1 : 3dX& aqlA ~1/01/56 : ai~O 0~'666- 0~g'666- ENq'MSd Oqg'b6b- [~q'MiV O0~'OSOLI '£djO Lt 139~d ALASKA COMPUTING CENTER ~mmm~mmmmm~mm~mmmmmmmm~mmm~m~ ~------- SCHLUMBERGER COMPANY NA~E : BP BXPbORATION (AbASKA) WELL NAMB ~ NK-23 FIEbD NAME : N~AKUK BOROUGH ~ NORTH BbOPE STATE : AbASK,A API NUMBER : 50-029-22455 REFERENCE NO : 94216 ' IS ?ape VerJflcatlon Listing chlumberqer AlasKa Computing Center 1i-jb5-1994 i0:08 PAGE~ **** REEL HEADER **** SERVICE NAME : EDIT DATE : 94/07/11 ORIGIN : FbIC REEL NA~E : 9q216 CONTINUATION # : PREVIOUS REEL : COMMENT ! BP EXPLORATION, NK-23, NIAKUK, AP1 50-029-22455 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 94/07/11 ORIGIN : FLIC TAPE NAME : 94216 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, NK-23, NIAKUK, API 50-029-22455 TAPE HEADER NIAKUK MWD/MAO bOGS WELL NAME: API NUNBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: jOB DAT~ JOB NUMBER: LOGGING ENGINEER: OPERATING WITNESS: SURFACE hOCATIO~ SECTION: TOWNSHIP: RANGE: FNb: FSb: FE~: ELEVATION(FT FROM MSb O) KELLY B~SHING: DE~RICK GROUND WMh~ CASING RECORD 1ST STRING 2ND STRING NK-23 5002922455 BP EXPLORATIOi'.; (ALASKA) SChLUMbERGER ELL'SERVICES 8-jUU 94 BlT RUN 1 BIT RUM 2 BIT RUN 3 94216 94216 942~6 NICLOS NICbOS NICLOS 36 1410 679 60,10 60,10 19,20 OPEN HOLE CASIN(~ DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) ''''''8. 500 ....... '.~.';'''''25 IS Tape Verification Listing Chlumberger AlasKa Computing Center PRODUCTIO~ STRTNG ~FMARK~: DEPTH AS LOGGED BIT RHN 1 16114 - 16741 BIT RU~ 2 16741 - 17195 BIT RUN 3 17195 - X7535 $ bls FORMAT DATA LY$ FORMAT DATA lI-JUb-1994 ~.0;08 SHIFTED DEPTH 16120 - 16757 16757 - 17210 172~,0 - 17550 PAGE~ 2 **** FILE HEADER **** FILE NAME : EDIT ,001 SERVICE : FLIC VERSION : O01C01 DATE : 94/07/11 MAX REC SIZE : 1024 FILE TYPE : hO L~ST FILE : FILE HEADER FILM NUMBER: I EDITED ~ERGED MWD Depth shifted and clipped curves; all bit runs merged DEPTH INCRE .EST: 0'5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH CDR'''''''''''''' '~'''''''''! 526.0 ''''''''''16073,0 CDN 17094,0 15998,0 $ NE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASOREO DEPTH) BASELINE DEPTH 88888 0 ~6704 5 16612 5 16555 5 16504 5 16487,0 16470,0 164i4~5 ~.637 5 16357'5 16280,0 16269,0 ----------EQUIVALENT ONSHIFTMD DEPTH---------- 8890,3,5 ~6720,0 16628,0 ~6565,5 16518,0 16503.0 16484,5 16424,0 16386,0 16378,5 16365,0 16285,5 ~6275,5 0 99 0 ] 99 ~9 99 0 99 89 ~, 99 0 89 99 ~ 99 89 ~L 0 99 0 99 {~D~d OiOIgLI O'LSL9t g 0 LSL9I 0'8665t ~ 0 9gSLI O'OtgLI E 00~L~ O'LSL9~ g O*O~L~ O'EL09~ I S'90I ~ 0619t O'LOggI 0'~999~ 0'9~9~ O'L§gg~ ~'0999I $ mmmmmmmmmmmmmm ~dOJ 'lOOI D~q # $ OOI 9LIgl E819[ 86[9I 6099l 80:0! 966I-qNP-II IS Tape Verification Listing chlumberger AlasKa Computin~ Center 1X-JUL-1994 10:08 PAGE= 4 DEPT FT RNOB MWD G/C3 DRHO ~D G/C3 PEF MWD BN/E CALN ~WD IN NPHI MUD RA MWD RP M~D DKR ~WD OHMK VRP ~WD VRA M~D ROP ~wD FPMR GR ~WD GAPI NCNT MWD CPS FCNT S~D CPS FET M~D HR ** DATA DEPT. CALN.MWD DER.~WD GRCH,GR DEPT. CALN.~D DER,~D GR,~D GRCM,GR DEPT. CALN.MWD DER.MWD GRCH,GR DEPT. A~N GRCM,G~ mmmmmmmmm#mmmm~mmm..mmmmmmmmm# ** SET TYPE - CHAN ERV UNIT SERVICE API API API ~P! FILE ID ORDER # ~OG TYPE CLASS MOD NUMB O0 000 O0 0 1 O0 000 O0 0 OO 000 O0 0 O0 000 O0 0 O0 000 O0 0 O0 000 O0 0 O0 000 O0 0 1 O0 000 O0 0 O0 000 O0 0 O0 000 O0 0 00 000 00 0 O0 000 O0 0 O0 000 O0 0 00 000 00 O O0 000 O0 0 i NUMB NUMB SIZE REPR PROCES$ SA~.~P ELEM CODE (HEX) 1 1 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 I I 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 1 I 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 I 1 4 68 0000000000 I 1 4 68 0000000000 I I 4 68 0000000000 I I 4 68 0000000000 68 0000000000 68 0000000~00 17549.500 RHOB.MWO -999.250 DRHO.MWD -999.250 NPHI.MWD -999.250 RA.MWO -999.250 VRP,MWD -999,250 VRA.MWD -999,250 NCNT.MWD -999.250 -999.250 -999 25O -999 250 -999 250 -9'99,250 PEF.MWD RP.MWD ROP.MwD F'ET'~WD 17500.000 R.OB.NWD -999 250 DRHO.MWO -999 50 PEF.MWD -999.250 NPHI.MWO -99~ 250 RA,MWD 2:~12 RP,MWD 1,958 VRP.MWD :963 VRA.MWD 2 ~04 ROP,MWD 100:~48 NCNT,MWO '999'250 FCNT.~WD -999:. 50 FET.MWD -999 50 17000.000 RHOB,~WD ~.519 DRHO.MWD 0,012 PEF 8.577 NPHI.MWD 2 .750 RA.:MWD 4.015 RP:~WD 4.03~ V'RP.MWD 4.062 VRA.~iWD 4.:147 ROP.MWD 53.017 NCNT.MWD 358.375 FCNT.MWD 11.808 FET.~{~D -999.250 16500.000 RMO~.MWD 2.481 DRHO.MWO -0.004 8.500 NPHI,~WD 36,119 RA.MWD 2.895 3.294 VRP,MWO 3.823 VRA.~WO 3.378 ROP.~D 218.953 NCNT.~MD 282.870 FCMT.~WO 6 512 '"999,250 -999 *2.50 18,054 -999,,250 · 2,, 46,1 3.01.2. 54*038 0,.~68 1,120 644 Is Tape verlflcation ~lstlnq chlumberger AlasKa Computing Center 11-JUL-1994 lo:OB DEPT. 16000.000 RHOS.hWD CALN.M~Q -999.250 NPHIoMWD DER.MUD -999.250 VRP.NWD GR.MWD -999.250 NCNT.MWQ GPCH,GR 64.487 -999.2§0 DRE~C.iqwO 36.250 RA.:~wD -999.250 YRA,~WD 273.229 FC~'r.~O -999.25~ -999.250 -999,250 6,163 PEF,MWD RP.MWD ROP.MWD FET.MWD DEPT. 15950.000 RHOB.~WD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.M~D -999.250 NPH~.MWD -999,2~0 RA,MWD -999'250 RP.M~D DER.N~D -999.250 VRP,MWD -999.250 VRA.MWD -999,250 ROP,MWD GR,~D -999.250 NCNT.SWD -999,250 FCNT,MWD -999,250 FET,MWD GRCH.GR 58.264 END OF DATA '999.250 '999.250 '999.250 '999.250 '999.250 '999,250 '999,250 -999,250 FISE NAME : EDIT VERSION : oO1CO1 DATE : 94107/11 MAX REC SIZE : 10~4 FILF TYPE : LO LAST FILE : **** FI5E HEADER **** FIGE NAME = EDIT ,002 SERVICE : F~IC VERSION : O01COI DATE : 94/07111 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILl NUMBER 2 Curves and log header data for each bit run ~n separate BIT RUN NUMBER~ ! DEPTH INCREMENT: FI~E SUg~ARY ~ COD LDWG $ LOG HEADER DATA DATE ~OGGED: 0,5000 START DEPTH 16740,0 STOP DEPTH 15990,0 15990,0 30-APR-94 files, IS Tape 'Verification Listlnq chlumberger AlasKa Computlnq Center Il-jOb-lEg4 10:08 SURFAC~ $OFT~A~E VERSION: LOGO~ 16.2/hip DO~NHObF SOFTWA~ VERSION: v34 DATA TYPE (MFMORY or REAL-TIME): MEMORY TD DRILLER (F'£); 17535 0 TOP LOG INTERVAL (FT): 16073:0 BOTTOM LOG INTERVAL (FI): 17526,0 BIT ROTATING SPEED MOLE INCLINATION (DEG) MINIMUM ANGLE: 51,9 M~XIMUM ANGL~! 55,9 TOOL STRING (TOP TO BOTTOM) V~NDOR TOOL CODE TOOL T ~''DR ............. RES!TIV'''''''~'TY CDR RESITIVITY GRS059 CDR POROSITY NOS022 $ BOR EHOLE AMD CASING DATA OPEN HOLE MIT SIZE (IN): DRILLERS CASING DEPTH (FT): 14673,0 BOREHOLE CONDITIONS MUD TYPE: ~UD DENSITY (LB/G); MUD VISCOSITY MUD MUD CHLORIDES FLUID bOSS MAXIMUM RECORDED TEMPERATURE (DEGF): ~UD AT M ED TEMPERATURE (MT); MUD AT MAX CIRCULATING TEMPERATURE M~D FILTRATE AT-'(MT). ~UD CA~E AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION # TOOL STANDOFF E~R FREQUENCY # REMARKS: $ LIS FORMAT DATA (IN): 10.0 150,O 0,t45 70,0 0,131 70.0 SANDSTONE ~.65 8,500 (IN): 1,000 (HZ): PAGEI 0f~'666,- 06~'666- l~q'~tV 0~'j666- !~q'l~dN~ 0~'666- tarl'qVDO 0~'666- l~q'J~d 0000000000 89 ) t ! ~ 0 O0 000 O0 0000000000 $9 ) t I g 0 O0 000 O0 aN 0000000000 ~9 ~ t I ~ 0 O0 000 O0 0000000000 B9 ~ i I ~ 0 O0 000 O0 '000000000 89 ~ t I ~ 0 O0 000 O0 000000000 89 ~ t '[ ~ 0 O0 000 O0 0000000000 89 ~ I t ~ 0 O0 000 O0 ~i~ 0000000000 89 ~ t l ~ 0 O0 000 O0 0000000000 89 ~ t I ~ 0 O0 000 O0 0000000000 89 ~ t I g <) O0 000 O0 ~HO 0000000000 89 ~ I ~ ~ ~ O0 000 O0 fid 0000000000 89 ~ I ~ ~ 0 O0 000 O0 N! 0000000000 8g ) I t ~ 0 O0 000 O0 ~/N~ 0000000000 89 ~ I t ~ 0 O0 000 O0 £319 0000000000 89 ~ I t ~ 0 O0 000 O0 fid 0000000000 09 ~ I t a 0 O0 000 O0 0000000000 89 ~ t t ~ 0 O0 000 O0 (X3H) 3003 . t 0 t 89 0 0 ~~mm~m~ 3nq~A 2003 99 99 91 99 ~I 99 £I 99 Il ~9 6 §9 L 99 ~ 99 ~ 99 ~ 99 I IS Tape Verification Listing chlumberger AlasKa Computing Center -999.250 DEPT, 16500 000 RHOB.LWl PEF.L~! 4~06 DCA~.L~I PS~,LWl 2.893 DER.LW1 HENA.LW1 284.750 HEFA.LWI N$I,Lw1 !.000 DEPT. 16000.000 RHO~.LW1 PEF.LWI 3.495 DCAL.LWi PSR.L~I -999.250 DER.LWl HENA.L~I 269.500 HEFA.LWl N$l.LW1 -999.250 DEPT, 15990.000 RHOB.LWI PEF.LW1 -999,250 DCAL.LW1 PSR.L~I -999.250 DER,LWX HENA.LW1 -999.250 HEFA.bW1 N$I,LW1 -999.250 END OF DATA 11-JUL-1994 10:08 2.478 DPHI.bWl 0.000 TNPH.bW! 2.839 ROPE.LWl 6.230 TAB.b~I 2.506 DPHZ.LN1 0.638 TNPH.LWl -999 250 ROP.E,LWl 6:135 TAB,~W1 -999.250 DPH'I,bWl -999.250 TNPH,~Wl -999,~50 ROPE'.bWl 6,285 TAB.LWi 10.400 37,300 28:557 2 156 8 700 36:500 -999,250 -999.250 -999 50 -999 ,22~0 -999:50 DRHO.L~! ATR.LW! GR,Lwl TABD.Lwl DRHO.LW! ATR.LWl GR.Lw~ TABD.LW. DRHO.LW! ATR.5Wl GR.LWl TABD.LW1 PAGE~ 0,002 '999'250 '999,250 '999'250 '999,250 -999~'250 -999,250 '999.250 **** FILE TRAILER FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 94/07/11 MAX REC SIZE : 1024 FILE TYPE : LO LAST FI[,£ : **** FILE HEADER **** FILE NAME : EDIT ,003 SERVICE : FLIC VERSION ~ 001C01 DATE : 94/07/11 MAX REC SIZE : 1024 FlUE TYPE = LO LAST FILE ~ FILE HEADER FILE NUMBER 3 RAW MAD Curves and lo[~ header data for each bit run in separate BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 ~I~E SUMMARY files, IS Tape Verificati. on Listlnq cblumberger AlasKa Com.Putln~ Center 10:08 LDWG TOOL CODE START DEPTH ~mm~mm~m~mmmm m~m~~mm CDR 17195.0 CON 17195.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE S~FTWARE vERsION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT)I TOP LOG INTERVA~ (FT): BOTTOM LOG INTERVAL (BT)% ~IT ROTATING SPEED HOLE INCLINATION (PEG) MINIMUM ANGLE: MAXIMI}M ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR R !rlVITY CDR RESITIVITY CDN PORO&ITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY ($): MUD PH~ MUD CHLORIDE8 (PPM): FLUID LOSS MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMS) AT TEMPERATURE MUD AT ~EASURED TEMPERATURE (MT): ~UD AT ~,X CIRCULATING TEMPERATURE ~UD FILTRATE AT (MT): ~UD CAKE.AT (MT): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF E~R FREQUENCY (HZ): STOP DEPTH 16620.0 10620,0 30-APR-g4 bOGOS 16,2/LIP 2,2 V34 gENORY 17535,0 16073.0 17526.0 55.7 56.5 TOOL NUMBER GRS022 GRS059 NDS022 10,4 150,0 0,211 0,173 64,0 64,0 SANDSTONE 2,65 8,500 1,000 PAGE~ IS Tape 'verification Listing cblumDerger AlasKa Computing Center $ LIS FORMAT DATA ll-JUL-1994 10:08 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE YA~UE ~ 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 ? 65 8 68 0,5 9 65 FT 11 66 1~ 68 13 66 0 14 65 FT 15 66 16 66 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SMRVICE API API APl AP! FILE NUMB NUMB SiZE REPR PROCESS ID ORDER # bOG TYPE CLASS MOD NUMB SAMP EbEM . 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IS Ta~e Yerlficatlon Listing chlumberger AlasKa Computing Center I1-JUL-19g4 i0:08 $ # bOG HEADgR DATA ~ATE bOGGED: SOFTWARE: SURFACE 80FT~ARE VERSION: DOWMHOLE SOFTWARE VERSION: DATA TYPE (MEMORY'or REAL-TiME): TD DRILLER (FT): TOP bOG INTERVAL BOTTOM bOG INTERVAL (FT): FIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: ~AXIMUM ANGLE~ TOOL SIRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR'''''''''''''''' RES'''i~'''VITY CDR RESITIVITY CON POROSITY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE DRILLERS CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): ~UD MUD CHLORIDES FLUID kOSS MAXIMUM RECORDEO TEMPERATURE (DEGF): RESISTIVITY (OHMS) AT TEMPERATUR~ (DEGF): MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE ~UD FILTRATE AT (MT): MUD CAKE AT (MT): WEUTRON TOOL MATRIX: MATRIX DENSITY: SOLE CORRECTION (IN): TOOL STANDOFF (IN): EMR FREQUENCY (HZ): REMARKS: NOS TOOL FAILEO ON RUM 3 $ LIS FORMAT DATA 30-APR-94 LOGOS 16.2/bIP 2.2 V34 ~E~ORY 17535 0 16073:0 17526.0 54,1 55,9 TOOL NUMBER GR8022 GR$059 N05022 8 500 10,4 150,0 0,'211 0,173 64,0 64,0 SANDSTONE 2.65 8.500 1,000 I$ TaDe Verl~ication LiSt!hq Il-JUL-1994 10108 PAGE~ 13 chlumberger AlasKa Computing Center ** ~ATA FORMAT SPECIFICATION RECORD SET TYPE REPR CODE VALUE 1 6b 0 2 66 0 3 73 ~ 66 1 5 66 6 73 7 65 8 68 0~5 9 65 F . 11 66 36 13 66 0 14 65 FT 15 66 6B i6 66 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API IPI AP1 API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE C~A$$ ~OD NUMB SA~P E~E~ CODE (HEX) D~PT FT O0 000 O0 0 4 I 1 4 68 0000000000 ATR b~] OHMM O0 000 O0 0 4 1 ! 4 68 0000000000 PSR LW3 OMMM O0 000 O0 0 4 ~ 1 4 68 0000000000 DER LW3 OHM~ O0 000 O0 0 4 1 t 4 68 0000000000 ROPE L~3 F/HR O0 000 O0 0 4 1 i 4 68 0000000000 GR [,~3 GAPI O0 000 O0 0 4 I 1 4 68 0000000000 TAB L~] ~R O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT 17535.000 ATR.L~3 -999.250 PSR.~W3 999 250 DER.L~3 -999,250 ROPE~LW3 16.667 GR.LW3 -999.250 TAO.LW3 ~999:250 ~PT 17500,000 ATR.LW3 1.445 PSR,LW3 1,263 DER,L~3 1,326 ROP~LW3 13.413 GR.~W3 -999,250 TAB'~W3 1.793 DEPT. 17050.500 ATR.LW3 -999.250 PSR.LW3 -999.250 DER.L~3 -999,~50 ROPE.LW3 -999.250 GR-LW3 -999.250 TAB.bW3 -999,250 ' Tape Verification L£stino Il-jOb-1994 10:08 PAGE~ 14 :hlumberger AlasKa Computing Cen%er **** FILE FILE MAM£ ~ EDIT .004 ERVIC~ : FLIC ERSION ~ OOlCO1 D~IE : MAX REC SIZE : 1024 FILE TYPE : LO **** TAPE TRAILER SERVICE NAME : EDIT DATF : 94/07/11 ORIGIN : FLIC TAPE MAME ~ 94216 CONTINUATION # : PREVIOUS TAP~ : COM~ENI : BP EXPLORATION, NK-23, NIAKUK, API 50-029-~2455 **** REEL TRAILER **** 6ERVICE NAME : ~DIT ORIGIN : ~IC REEL MAME : 94216 CONTINUATION # ~ PREVIOUS R'EEb : ~ .~ . _ NK-2B NIAKUK ~PI 50-029-22455 COMME~ : BP EXPLORATION, , ,