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203-055
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Development Exploratory Service 5 Permit to Drill Number:203-055 6.50-029-22414-03-00 PRUDHOE BAY, NIAKUK OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 17515 17482 9242 10796 , 10847 none 7289 , 7316 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 33 - 113 33 - 113 1530 520 Surface 4724 10-3/4" 32 - 4756 32 - 4138 4560 1730 Production 11062 7-5/8" 30 - 11092 30 - 7440 6890 4790 Liner 5387 4-1/2" 10847 - 16234 7316 - 9206 8430 7500 Perforation Depth: Measured depth: 16135 - 17320 feet True vertical depth:9158 - 9179 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 27 - 10852 27 - 7319 Packers and SSSV (type, measured and true vertical depth) Liner 1824 3-1/2" x 3-1/16" x 2 15691 - 17515 8931 - 9257 13450 13890 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 700151710837 8030 1569 0 187 628 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Kirsty Schultz Kirsten.Schultz@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907)564-5258 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9257 Sundry Number or N/A if C.O. Exempt: 320-502 4-1/2" HES TRSSSV 2023 1992 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 034625, 034630 NIA NK-12C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations none By Meredith Guhl at 8:06 am, May 10, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.07 13:41:40 -08'00' Bo York SFD 5/10/2021DSR-5/10/21 RBDMS HEW 5/10/2021 MGR26JUL2021 ACTIVITYDATE SUMMARY 4/15/2021 CTU#6 1.75" coiled tubing Job Objective: Add Perfs MIRU CTU6, MU HES logging BHA and RIH ***Job Continued on WSR 4/16/21*** 4/16/2021 CTU#6 1.75" coiled tubing Job Objective: Add Perfs Continue RIH HES logging BHA = GR/CCL in 2.20" carrier 16,650' ctm. Log 16,650' to 15,400'. Flag pipe. Good data, -10ft correction. Corrected EOP = 16,078.48'. Load & Kill well with 8.48# KCI, WHP still @ 250 psi or EMW= 9.1 ppg. Order 600 bbls of 9.2 ppg brine. L&K well with 9.2 ppg brine SI and monitor WHP fall from 1200psi to 400psi. Open well to TTK to bleed pressure and monitor. ***Job Continued on WSR 4/17/21*** 4/17/2021 CTU#6 1.75" coiled tubing Job Objective: Add Perfs NFT well after loading with 9.2 ppg brine. MU 115' of 2" HES MaxForce guns, RIH to coil flag 16,078.48' Corrected EOP. Correct counter to bottom shot 16,202.66' @ flag. Perforate interval 16,135' - 16,250'. Pooh w/guns, on surface NFT well and circulate 9.2 ppg across flow cross while monitoring w/trip sheet. Guns fired, 1/2" ball recovered. Lay down 115' of 2" HES Maxforce guns. FP tubing w/5 bbls of 60/40 MEOH. Rig down CTU6. DSO bringing well online on departure. ***Job completed*** Daily Report of Well Operations PBU NK-12C Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:203-055 6.API Number:50-029-22414-03-00 PRUDHOE BAY, NIAKUK OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 034625 Property Designation (Lease Number):10. 329B/C 8. NIA NK-12C 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 17515 Effective Depth MD: L-80 11. 12-15-2020 Commission Representative: 15. Suspended Contact Name: Kirsty Schultz Contact Email: Kirsten.Schultz@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: Alter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" HES TRSSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9257 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 10796 , 10847 / 7289,7316 2023, 1992 Date: Liner 1824 3-1/2" x 3-1/16" x 2-7/8" 15691 - 17515 8931 - 9257 13450 13890 Well Status after proposed work: 16. Verbal Approval: Change Approved Program OtherCT extended perf5 32 - 4756 32 - 4138 14. Estimated Date for Commencing Operations: BOP Sketch 33 - 113 Structural 6890 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker S-3, 5" ZXP Top 16390 - 17320 9261 - 9179 4-1/2" 12.6# L-80 27 - 10852 Liner 17482 9242 none 10817 33 - 113 520 10-3/4" 7-5/8" Contact Phone:(907) 350 -4310 Date: 11/24/20 4790 80 153020"Conductor 1730 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 4724 4560 Production 11062 30 - 11092 30 - 7440 5387 4-1/2" 10847 - 16234 7316 - 9206 8430 7500 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:42 am, Nov 25, 2020 320-502 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.11.25 09:15:34 -09'00' Bo York 10-404X ; ADL0034630 DLB MGR27NOV20 DSR-11/25/2020DLB11/25/2020 3387 0 YesRequired? Comm 11/30/2020 dts 11/30/2020 JLC 11/30/2020 RBDMS HEW 12/2/2020 Extended Perforating Procedure To:Well Services Foreman Date:11/18/2020 AFE:2024489 From:Kirsty Schultz IOR:110 Est. Cost: Subject:NK-12C Extended Perforating with Coiled Tubing Revision: Sundry # Job Sequence WBL Steps 1SLSBHP 2CoilMU/RIH and drift with GR/CCL and nozzle. 3CoilShoot Addperfs (depths based on SLB CNL 2/23/2004): 16,135’16,250’ Current Bottom Hole Pressure:4307 psi @ 9200’ TVD 9.00 ppg | SBHPS taken 12/06/2019 Fracture Pressure:6602 psi at 9200' TVD or 0.72 psi/ft (13.8 ppg EMW) Last SI WHP:500 psi on 12/06/19 Min ID:2.377” ID (3-3/16”x2-7/8” XO) @ 17349 MD Max Angle:106 Deg @ 16,693’ Reference Log:SLB CNL 02/23/2004 H2S:70 ppm 11/14/2020 CT Size:1.75"The safety joint shall be the same OD as CT size referenced here. Program Contacts: Contact Work Phone Mobile Phone Operations Engineer Kirsty Schultz 907-350-4310 Secondary Operations Engineer NK-12C Coiled Tubing Extended Perforating Program 1 Scope of Work and Well Summary NK-12C recently had perfs added which resulted in IP of >4000 bopd. The rate has dropped off substantially since initial POP: currently making ~735 bwpd, 165 bopd, and 74 deg F. With the downward trend in rate and flowing temp, we anticipate the well will start to have hydrate/paraffin issues making it difficult for ops to manage. An additional 115’ of perfs should be shot uphole to improve rate and increase temperature. A long term solution to keeping NK-12C online is to get injection support in the area; however, these add perfs should help us in the short term to keep the well flowing. Prior to shooting the perforations, a SBHP should be obtained to confirm reservoir pressure. 2 Sundry Procedure (Approval Required to Proceed): Slickline 1. SBHP as detailed below a. Ensure well has been SI for 5 days before obtaining SBHP b. Datum is 9200’ TVDss/16,356’ MD. It is unlikely we will be able to drift to datum. Drift as deep as possible, and then obtain three additional shallower stops as detailed below. c. If able to drift to 16250, call Kirsty at 907-350-4310. This would indicate we will be able to shoot the perfs with EL rather than coil, and it may change the path forward. d. SBHP to act as pre-coil drift, additional drift at WSL discretion. Stops:MD TVDss Time First As deep as possible TBD 60 min Second 300’ MD shallower than first stop TBD 15 min Third 600’ MD shallower than first stop TBD 15 min Fourth 900’ MD shallower than first stop TBD 15 min Coiled Tubing (Reference Coiled Tubing Extended Perforating Recommended Practice) 1. MIRU Coiled Tubing Unit 2. MU and RIH with logging and drift assembly. a. Kill well with 1.5x WBV to top perf with ~9.1 ppg brine (~245 bbls). Note: The well will be killed and monitored before making up the initial perf guns. This is generally done during the drift/logging run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. 3. Paint flag, POOH and confirm good data. 4. Monitor WHP to confirm well is dead before MU perf guns. If necessary, re-kill well. 5. Pickup 1.75” (safety joint and CT size MUST be the same OD.) safety joint and TIW valve and space out before MU guns. Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary. 6. Break lubricator connection at QTS and begin MU perf guns per the following table (If at any time pressure is seen or there is flow at surface follow the steps in the Standing Orders Appendix E to secure the well): * Table 1: NK-12C Proposed Extended Length Gun Runs Gun Run # Perf Top Perf Bottom Perf Length Overall Gun Length 1 16135 16250 115 115 7. RIH with perf gun(s), tie-in and perforate. POOH. a. Note any tubing pressure changes in WSR. 8. Once at surface, stop to confirm well is dead. 9. Review Standing Orders (Appendix E) prior to breaking lubricator connection and rigging down guns. 10. Either return the well to production or FP well. 11. RDMO. Attachments: A. Current Schematic B. Proposed Schematic C. Coiled Tubing BOP Schematic / Tree Diagram D. Equipment Layout Diagram E. Standing Orders for Open Hole Well Control during Perf Gun Deployment F. Tie In Log/Perf Sheet *See note above regarding kill methods if pressure observed on surface after perforating. Appendix A - Current Wellbore Configuration Appendix B: Proposed Schematic Add Perfs Appendix C: Coiled Tubing BOP Schematic / Tree Diagram Appendix D: Extended Perforating Equipment Layout Appendix E: Standing Orders for Open Hole Well Control during Perf Gun Deployment Appendix F: Tie-In Log / Perf Sheet • • fir/]' A03-05-5— Loepp, Victoria T (DOA) From: Catron, Garry R (Wipro) <Garry.Catron@bp.com> Sent: Thursday, September 24, 2015 11:44 AM To: Loepp,Victoria T (DOA) Cc: Gerik, Bob G; Alatalo, Travis; Daniel, Ryan; Douglas, David W (Wipro); Brown, Matt (Northern Solutions);Worthington, Aras J Subject: FW: PBU NK-12C(PTD 203-055)IA Cement Squeeze; 10-404(5/7/15) Attachments: FW cement packer repairs.msg Follow Up Flag: Follow up Flag Status: Flagged Victoria, Here is an e-mail from Guy Schwartz that left the Engineer with the impression that a 10-403 was not required for Cement Packer because it was classified as "Alteration of mechanical completion". This is why he did not apply for the 10-403. If this interpretation is incorrect, please let us know for future reference. Regards, Garry Catron PDC PE 907-564-4424 SCANNED 6 From: Worthington, Aras J Sent: Thursday, September 24, 2015 11:27 AM To: Catron, Garry R(Wipro); Gerik, Bob G; Alatalo,Travis Cc: Daniel, Ryan Subject: RE: PBU NK-12C(PTD 203-055) IA Cement Squeeze; 10-404(5/7/15) Garry, I did not submit a 403 for this packer squeeze because the last advice we had from the State (see attached e-mail chain) was that they did not require the 403 for packer squeezes (unless for an injector). As the e-mail indicates they only require a 404. Cheers, Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564-4102 Cell: (907) 440-7692 From: Catron, Garry R (Wipro) Sent: Thursday, September 24, 2015 10:59 AM To: Gerik, Bob G; Alatalo, Travis; Worthington, Aras J 1 • Cc: Daniel, Ryan Subject: FW: PBU NK-12C(PTD 203-055) IA Cement Squeeze; 10-404(5/7/15) Folks, Was an approved 10-403 ever received for this work done in March —April this year? Garry Catron PDC PE 907-564-4424 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp©alaska.gov] Sent: Thursday, September 24, 2015 10:34 AM To: Catron, Garry R (Wipro) Subject: PBU NK-12C(PTD 203-055) IA Cement Squeeze; 10-404(5/7/15) Gary, This appears to be an IA packer cement squeeze. Was there a 10-403 for this work? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa?alaska.gov 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 Victoria Loepp at(907)793-1247 or Victoria.Loero@alaska.gov 2 4 06' _ /1 V co �_ v l��' U U c O CU L L C Z. 40w ~ T O O • n3 U a uU.1 CO S E C .O C O 'E 0 ro a� cw a Q J '. . 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CO L p O O O O O Ol 0 2 2 2 0 .� m cD cD co (/) £ra Q w iff U U U U a CC X • > 0a r co C N O O co CO U UO O O O O 0 LO cD CO V +' Q C O CO m c0 'Cr V To N O M M N N I > C N N ry N N N N m N 01 O O O a O.1 N O O O O C 0 O O O O i v In LO Ln Ln Y D m E - w a. z a, z Z �' E a; E o v 7, o m 02 utetN 2m U cc- . cn G OJ C Q O N - o C L N +� OD n, Z O N .- r+ al OL C V1 Lp n J Y ca 0 J a Q N W J (n Z E Z al '6 U N 3 i cCO ,) a 8 e0 b_ 1 . °' I— d d 6 m STATE OF ALASKA ' ASKA OIL AND GAS CONSERVATION COMM*ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well El Other: IA-c'lAY]GYl tSwfC `� 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: !� Name: BP Exploration(Alaska),Inc Development 0 Exploratory❑ 203-055 3.Address: P.O.Box 196612 Stratigraphic ❑ Service❑ 6.API Number: Anchorage,AK 99519-6612 50-029-22414-03-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0034625 NIA NK-12C 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,NIAKUK OIL 11.Present Well Condition Summary: Total Depth measured 17515 feet Plugs measured None feeR I M D true vertical 9257.15 feet Junk measured 10817 feet Effective Depth measured 17482 feet Packer measured See Attachment feet MAY ® 8 2015 true vertical 9241.81 feet true vertical See Attachment feet AOGCC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"94#H-40 32.89-112.89 32.89-112.89 1530 520 Surface 4724 10-3/4"45.5#NT-80S 32.39-4756.39 32.39-4137.97 4560 1730 Intermediate None None None None None None Production 11062.36 7-5/8"29.7#L-80 29.64-11092 29.64-7440.27 6890 4790 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 16940-17190 feet 17210-17320 feet True Vertical depth 9186.51-9170.2 feet 9169.48-9179.16 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 26.64-10851.92 26.64-7318.56 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4-1/2"HES TRSSSV 2023 1992.04 SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED FEB 41 201 10629'-10742'. L� 2 t Treatment descriptions including volumes used and final pressure: 8 Bbls 15.8 ppg Class G Cement, 1063 Psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 161 15 1064 2065 556 Subsequent to operation: 165 238 772 2083 839 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory❑ Development p ❑ Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run El 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ 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 Garry Catron Email Garry.Catront.BP.Com Printed Name Garry Catron Title PDC PE Signature )3(6CCA. ..: Phone 564-4424 Date 5/7/2015 v7-i_ i'63- lI c- RBDMS J"' MAY 1 1 2015 i. Form 10-404 Revised 10/2012 Submit Original Only 1 Ali III k i • Packers and SSV's Attachment 203-055 SW Name Type MD TVD Depscription NK-12C SSSV 2023 1992.04 4-1/2" HES TRSSSV NK-12C PACKER 10795.71 7289.32 4-1/2" Baker S-3 Hydro Set Packer NK-12C PACKER 10846.81 7315.9 5" Baker ZXP Top Packer 1j11 li Iii a 41 0 a) cn (0 N O 000 O O O r` ti Lo G LoC` r V = I,- U i O O o O C0 c, m CO M N- Ln r` r` CO co M CO N N O LO LC) V' N- N O C` CSO N O N- CO l!) 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SCD 00) •q D / 0 0Ce / ± \ � $ � \ � /co \ Z E p -,-,5 0)WN- e \ / f 0 o U 3 = O � 0 O - f2f / R < / & 2 9 Z k -I a i U F- q � � � 0 \ Y \ / $ \ O ± � / (XE / / zE \ ƒ / \ E\ II \ I \ \ Z / / 2 / \ \ / $ ) f / $ ƒ i i J $ $ i « \ 2 c*:' m Lx-; / / Lo o o d / / / d (7) ccr N- ,- cat2c .1- co 4.- !ƒ; \ ƒ. . \%: TT -5!$"5M FMC 4-1/16"5M CNV WELLHEAD13 • 14 K-I 2 C SEAlpOTES: WELL .4 16449''�`WELL R8)URES A SSSV MAX ?ACTUATOR BAKERC4"GAP BETWEEN TBG&PKR@ 10799'MD(CALIPER OKB. ELEI/,, 07106/12)""* BF.ELEV= KOP= 1300' CONDUCTOR, - ( C) 2023' H4-1/2"HES CP-2 TRSSSV NP,U=3.813" Max Angle= 106°@ 16693' _#, , n Datum MD= 16356' D= ______ Datum TVD, 9200'SS GAS LFT MANDRELS 10-314"CSG,45.5#,NT-80S BTC,D=9.950" 4764' ST MD TVD DEV TYPE VLV LATCH FORT DATE 3 3239 3035 39 CA DOME NT 16 04/17/15 2 7098 5467 59 CA SO NT 1622 04/17/15 ESTIMATED TOP OF CEMENT (04/12/15) H -10635 1 _10711 7245 58 CA *EMPTY - - 04/17/15 v ; *STA#1 - MVO CEMENT (04-12-15) Minimum ID = 2.377" a@ 17349' • 3-3/16" X 2-7/8" LNR XO ry +. -10750 --{TOP OFSANDBACKSLURRY (12/28/13) 7 / 10778' H4-1f2"HES X NP,D=3.813" Itioa____ 10778' -14-1/2"DREAM CATCHER ON X-LOCK(04/16/15) 10799' -7-5/8"X 4-1/2"BKR S-3 PKR,D=3.850" POTENTIAL PKR SEPARATION @ 10722'SLY POSSIBLE ID RESTRICTION-3.5"(AWGRS 4/6114) 4641 10817' ctmd -FISH CBP MtLm&PUSH DH(04/13/15) 10822' H 4-1/2"HES x NP,D=3.813" I 111 10843' H4-1/2"HES XN NIP,MLLED TO 3-8" TOP OF 4-1/2"LNR H 10849' 10849' -7-518"X 4-1/2"BKR ZXP LTP,D=4 938" I 4-1/2'TBG,12.6#,L-80 BT--M, --I 10855' ►moi 10855' -{4-112'WLEG,D=3.958` 0152 bpf,D=3-958" a 10854' -I ELME TT LOGGED 06/04101 10869' H 7"X 5"BKR HNC HCR.D=4.938" 10881' -I5"X 4-112"XO,D=3-938' 7-5/8"CSG,29.7#,NT-95-HS, -1 11097 NSCC,D=6-875" MLLOUT WINDOW(NK-12B)11092'- 11104' TOP OF 3-1/2"X 3-1/4:"X 2-7/8" LNR H 15691' 15691' H3.7 BKR DEPLOY SLV,D=3.0" I ,S f 15710' -13-1/2"HOWC.O X NP,D=2.813' I 3-1/2"LNR,8.81#,L-80 Sit,.0087 bpf,ID=2.990" -I 15774' 1� I 15774' H3-1/2"X 3-3/16"XO,D=2.786' ry 4-1/2"LNR 12.6#,L-80 HYD 521, - -16235 MLLOUT WNDOW(NK-12C)16235'- 16240' .0152 bpf,ID=3.958" It PERFORATION SUMMARY N. A 17349' -13-3/16'X 2-7/8"XO,D=2-377" REF LOG:7, ; ,,.��*��I, wc. ANGLE AT TOP PERF: 103°@i 16940' kibil�•••4 N. 4464%4 Note:Refer to Rtoduction DB for historical pert data . SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 3-3/16"LNR, y 6.2#,L-80 TCI, - 17349' sr_ ' 2" 6 16940- 17190 0 02/24/04 .0076 bpf,ID=2.805" `�w 2" 6 17210- 17320 0 02/24/04 PBTD H 17482' • 40 2-7/8"LNR,6.16#,L-80 STL, -1 17515' .0055 bpf,D=2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/13/93 ORIGINAL COMPLETION 04/04/15 I I FU PJC PACKER SQZ/ML.CBP WELL. N<-12C 01/16/94 SIDETRACK(Mf-12A) 04/16/15 STF/PJC SET DREAM CATCHER FERMI-Na w2030550 03/19/01 D-14 SIDETRACK(NK-12B) 04/17/15 STF/PJC GLV C/O(CMT NOTATION#1) API ME 50-029-22414-03 02/25/04 NORDIC CTD SIDETRACK(11K-12C) 05/06/15 PJC DREAM CATCHER U t ATE SEC 36,T12N,R15E 1327'FSL&996'FEL 03/22/15 GJB/PJC RLL STA#1,LEAVE EMPTY 05/06/15 TBD/PJC CAT IA/C8P FISH (4/12-4/13/15) }3/23/15 JCMPJC SET OBSIDIAN CSP �' ,� 3P 6tploration(Alaska) i I in 4 W1nw c N COC'3o0 a) M 0CO NW m W r pip u L OV h CD QTY ll ! c •ci . a) () O 0./ _c L C LJ VI v -QC O L O 0 (6 T O_ OQ 0 ▪ Ca).) U) M UUN U) U) U) U) co O E L m .14 sUYNY N , a) O Y (0Q F- (0 O) (0 ( (0 (0 0n NO NV) r-- T N O M h U) M ,47 C -0 > Z N N N N N N C (0 a) a s Z Ou -O E O T Q a) j N U Y L@ • Y O 0 0 0 0 0 0 0 0 @ N v L 6 J J J J J J J J J "' W W W W W W W W W 03 c (3 0 _ ter.. LL LL LL LL I.L. LL LL LL LL ••, a) E -0 N Q J J J J J J J J J Q _O O C C O r Q Q Q Q Q Q Q Q Q ) �' Z Z Z Z Z Z Z Z Z D O 0 (B v 0 (.+ '"?) 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O v I� Orn O) O) O) Q) Of O) O) O) ! 0 N N N N N N N N N 01 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 N U) U) U) in in U) U) U) y,, =O •a) (u C co O. u C _ ec a) h- E u f0 cY"4-.3 Ci _ Gi '�M " ac, o ., o o CO o M N �„) p E ny � QN l YJJ X J J £ Z d Z ` CU CO Nn / C a a Q XHVZE e e Image Project Well History File Cover Page This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 03 - 0 § Well History File Identifier Organizing (done) o Two-sided 11111111111 III II III o Rescan Needed 11111111111/1111111 RES CAN DIGITAL DATA ¢iskettes, No. / o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: o Other: OVERSIZED (Non'-Scannable) o Logs of various kinds: NOTES: Date3/ar¿ /øJ Dated ~I 0 ~ I o Other:: MP ,!IIIIIIIIIII! 1111/ mP BY: ~ 151 Project Proofing BY: ~ BY: + 1!L- = TOTAL PAGES IJ~O (Count does not include cove~ 151 r Scanning Preparation Date: Production Scanning Stage 1 Page Count from Scanned File: L 50 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: L YES BY ~ Date a/ð!ð /o?; Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11111111111111 "III NO 151 WI P NO BY: Maria Date: 151 11111111111I11 ,,11/ Scanning is complete at this point unless rescanning is required. ReScanned 1/1 II 111111 "' "III BY: Maria Date: 151 Comments about this file: Quality Checked 1/1 111111111 "11111 1 0/6/2005 Well History File Cover Page.doc OF Tk w�\\I%% s� THE STATE Alaska Oil and as - Co ` , 'v i. o1? .mission ^h,, GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 Bob Gerik Petroleum Engineer ab 3 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 r.r Re: Prudhoe Bay Field,Niakuk Oil Pool,NIA NK-12C %AWED Sundry Number: 313-575 Dear Mr. Gerik: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, P4C-.1 4-- Cathy P. oerster Chair, Commissioner DATED this gT d of November, 2013. Encl. • • `. ,17 RECEIVED STATE OF ALASKA ,/X NOV 0 4 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION V` APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well 0 Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development IMI ' 203-055-0 , 3.Address: 6.API Number Stratigraphic ❑ Service ❑ r. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22414-03-00 ' 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? NIA NK-12C ' Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0034625 ' PRUDHOE BAY, NIAKUK OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 17515 9257 ' 10940 7364 10940 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 32-112 32-112 Surface 4724 10-3/4"45.5#NT-80S 32-4756 32-4137.68 4560 1730 Intermediate None None None None None None Production 11062 7-5/8"29.7#L-80 30-11092 30-7440.27 6890 4790 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(it): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 29-10857 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths 4-1/2"HES TRSSSV 2023',1992.04' 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ill BOP Sketch ❑ Exploratory ❑ Development Q ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil Q Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bob Gerik Email Bob.Gerik©BP.Com Printed Name Bob Gerik Title Petroleum Engineer Signature Phone 564-4476 Date Prepared by Garry Catron 564-4424 ' \`/‘12.:AS COMMISSION USE ONLY ` 2 �-r Conditions of approval: Notify Commission so that a representative may witness Sundry Number \ J - 1 5 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ 2 1 1 RSD�iS NOV Other: Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /0 4 C /�' APPROVED BY `� Approved by: COMMISSIONER THE COMMISSION Date: r(_ O ../ 3 P7 4' Form 10-403 Revised 10 012 I �v 12 months from the date of approval. Submit ForrrYSnd Attachments in Duplicate VLF/I/&/i3 (` Casing Summary ADL0034625 Casing Length Size MD Top MD Base ND Top TVD Base Burst Collapse Grade CONDUCTOR 80 20" 94#H-40 32 112 32 112 1530 520 H-40 LINER 1575 3-3/16" 6.2# L-80 15774 17349 8974 9187 L-80 LINER 166 2-7/8"6.16#L-80 17349 ' 17515 9187 9257 13450 13890 L-80 LINER 83 3-1/2" 8.81# L-80 15691 15774 8931 8974 L-80 LINER 5385 4-1/2" 12.6# L-80 10849 16234 7317 9206 8430 7500 L-80 PRODUCTION 11062 7-5/8"29.7# L-80 30 11092 30 7440 6890 4790 L-80 • SURFACE 4724 10-3/4"45.5# NT-80S 32 4756 32 4138 4560 1730 NT-80S TUBING 10828 4-1/2" 12.6#L-80 29 10857 29 7321 8430 7500 L-80 III • • Perforation Attachment ADL0034625 Well Date Perf Code MD Top MD Base TVD Top TVD Base NK-12C 6/12/12 BPS 16940 17190 9187 9170 NK-12C 6/12/12 BPS 17210 17320 9169 9179 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0034625 Well Facility Type MD Top Description TVD Top NK-12C SSSV 2023 4-1/2" HES TRSSSV 1992 NK-12C PACKER 10798 4-1/2" Baker S-3 Hydro Set Packer 7291 NK-12C PACKER 10849 5" Baker ZXP Top Packer 7317 TREE= 41!16"5M OW • NOTES: WELL REQUIRES A SSSV.JOY WBIHEAD= 13-5!8 5M FMC ACTUATOR= BAKER C N K-1 Z C -L ANGLE>TO°eft 11423'. KB.ELEV= 51.88' BF.ELEV= ' KOP= 1300' Max Angle= 106°CO 16693' , Datum MD= 16_356' Q 2023' —{4-1/2'HE3 CP-2 TRSSSV NP,D=3.813" I7�tumTVD= 9200'SS 110-3/4"CSG,45.5#,NT-80S BTC,D=9.950" H 4764' ' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3239 3035 39 CAMCO DMY NT 0 05/08/12 2 7098 5467 59 CAMCO DMY NT 0 05/08/12 1 10711 7245 58 CAMCO DMY NT 0 06/07/12 Minimum ID =2.377" @ 17368' TOP OF 2-7/8" LINER 1o778' —H4-112"HES X NP,D=3.813" 1 1 II NMI 10799' H7-5/8"X 4-1/2"BAKER S-3 PKR,D=3.850" 1 ■ 10822' H 41/2'HES X NAP,D=3.813° 10842' 1--141/2"HES XN NF MILLED ID=3.8" 10855' _-141/2"WLEG 4-1/2"TBG,12.6#,L-80 BT-M,D=3.958" H 10855' I 1054• H gM0 TT LOGGED 06/04/01 I 0 in 10849' —17-518"X 4-1/2"BAKER ZXP PKR,D=4.938" NI SV ' 108,69' I—BAKER r X 5'HMC LNR HGR,ID=4^938' 10940' —{3-3/8"BKR IBP(06/12/12) 7-5/8"CSG,29.7#,NT-95-HS, —1 11092' 1 NSCC,D=6.875" ►: I-15691' —13.7 BKR DEPLOYMENT SLV,D=3.0" I 3-1/2"LNR,8.8#,L-80,.0087 bpf,ID=2.992" — 15774' $ I 15710' —13-1/2"FES X NP,0=2.813" 1 • • PERFORATION SUMMARY ■ % REF LOG:`???? *4 ►�• 15774' —I3-1/2"X 3-3/16"XO,D=2.786'1 ■ANGLE AT TOP PERF: 103°@ 16940' �4 �•� Note:Refer to Production DB for t torical pert data '%,*4 4 .' SIZE- SPF MVTERVAL Opn/Sgz DATE � NILLOtJT WINDOW 16234'-16240' 2' 6 16940-17190' C 02/24/04 .4.►7∎ 2' 4%%6 17210-17320 C 02/24/04 0 ■iiiii•. ` 17349' —13-3/16'X 2-718'XO,D=2.440'1 41/2"LNR,12.6#,L-80,.0152 bpf,ID=3.958" — 16550• 1 '�•••••••••. 3-3/16'LNR,6.2#,L-80,.0076 bpf,D=2.805' H 17349' PBTD 1 17482' I .w. •e, 2-7/8"LNR,6.16#,L-80,.0055 bpf,D=2.377" —1 17515' I DATE REV BY COM ENTS DATE REV BY COM ENTS PRUDHOE BAY UNIT ORIGINAL COMPLETION 01/19/12 JJUJMD PULL FISH(01/15112) WELL: NK-12C 01/16/94 RIG SIDETRACK(NI412A) 05/15/12 MSMJMD GLV C1O(05/08/12) PERMT No: 2030550 03/19/01 CIVKAK RIG SIDETRACK(NK•12B) 06/12/12 JRR'JMD GLV GO(06/07/12) All No: 50-029-22414-03 02/25/04 JLMIKAK RIG SIDETRACK(NI.12C) 06114/12 JCMW.MAD SET BKR BP(06/12/12) SEC 36,T12N,R15E,132T FSL&996'FEL 02/18/11 MB/JMD ADDED SSSV SAFETY NOTE 06/17/12 RRD/PJC BP DEPTH CORRECTION 07/29/11 RCT/PJC FISH-SL TOOLSTRNG(7/2/11) 08/16/12 JMD API NUMBER CORRECTION BP Exploration(Alaska) • • Memorandum To: T. Norene/ L. Seymour Date: Oct. 17, 2013 GPB Well Ops Team Leaders Code: From: Joshua Stephens Bob Gerik Well Interventions Engineer NK Petroleum Engineer (903)816-0183 (907)564-4476 (907)564-5810 (907)240-7961 Subject: NK-12C Packer Repair REV 1 IOR: Est. Cost: 100K Please perform the following procedure: } B Perform MIT IA, CMIT TxIA 1 S Set HES Evo Trieve @ 10,770'MD, MIT-T, Install Circ. Sleeve in GLM# 1 2 F Load tubing and IA with Diesel CMIT-TXIA w/LLR, Pump Gelled Slurry down IA to GLM#1 4 S Pull Circ. Sleeve, Install DGLV, Perform MIT-IA, Pull Evotrieve, Pull IBP and Install live GLV design 5 D A/SL Perform MIT-IA Current Status: Not Operable PAL Last Test: 04/08/2012 486 BOPD; 1,459 BWPD; 305 Mscf form gas; 627 form GOR Max Deviation: 63 degrees @ 8,992'MD Minimum ID: 2.377"@ 17,368' MD top of 2-7/8"Liner Last Downhole Op: 7/07/2012 40 Arm Caliper log 2.75"OD, 17'OAL to 10,940'MD Last TD Tag 07/07/12 3.50"Drift to IBP @ 10,940'MD Latest H25 Value: 04/01/2010 80 ppm H2S Program Objectives: The objective of this program is to repair a slow packer leak by spotting a slurry of sand, silica flower, and barite down the IA via a circulation sleeve in the lowest GLM. Once the slurry is spotted to the GLM we will close in the tubing and allow 48hrs for the gel to break. Once the slurry has had enough time to break and settle out we will then perform an MIT-IA to evaluate the success of the job. Pending a passing MIT-IA we will pull the Evotrieve, IBP, and install a generic GLV design. History Integrity issues with NK-12 began when the well failed a pre SIT TIFIL on 4/9/12. Slickline started diagnostic work on 4/24/12 by changing the orifice GLV @ 10,711' MD. DHD then performed two failing TIFILs on 4/26, 4/29/2012. Slickline returned to the well on 5/6/12 and dummied all GLMs; the well then failed an MIT-IA to 3,000 psi on 5/8/12 with a LLR of .1 bpm with 2,000 psi differential. Slickline then replaced the DGLV in station 1 and set a PX plug at 10,822' MD. The well then failed an MIT-IA with a LLR of .1 bpm; when trying to pump down the tubing the IA tracked and seemed to be in direct communication. Slickline then pulled the PX plug from 10,822' MD and reset a • • plug in the X nipple above at 10,788' MD. The well then passed an MIT-T to 3,000 PSI and failed an MIT-IA with a LLR of .1 bpm @ 2,000psi differential on 5/9/12. Slickline then returned to the well on 5/28/12 to re attempt setting a plug @10,822' MD and performing an MIT-T. Pressure testing once again showed that the tubing was in communication with the IA. Slickline then set a WRP @ 10,811 SLM and the well failed an MIT-T with a LLR of 2.5 bpm; the IA was still in communication with the tubing. With the WRP out of the hole Eline performed a techwell LDL on 6/3/12 and found one leak at the packer with N 1700 psi differential. The well was circulated and an IBP was set at 10,778' MD on 6/12/2012. On 7/7/2012 Slickline ran a 40 ARM caliper from the IBP to surface. Data from the caliper indicates that the tail pipe and lower part of the packer has dropped and is no longer attached to the tubing string. This would explain why the well failed MIT-Ts when a plug was placed below the packer. On 2/9/13 fullbore performed a failing MIT-IA to 3,000psi with a LLR of .145bpm ("2,000 psi differential). On 10/3/13 the well failed a pre job CMIT-TxIA and MIT-T with a LLLR of .2bpm @ 3000psi. It is suspected that the IBP may be hMT 61er a s . Tet an Evotrieve leaking since plug te well above past the a x-nip CI at 10-TxIA,778on ' MD/13/in 2 order one day to achieve aftthe a hard IBP w bottom s et for he the plan pump forward job. will A Mbe IT-T to will be performed after setting the plug and before pulling the GLV in order to prove the competency of the tubing/plug. Pending a passing MIT-T the slurry job will be pumped as planned. AWGRS reports from the well indicate that there are several tight spots in the tubing when running near full bore diameter tools; please proceed with caution. Well Events 2/09/13: Well failed an MIT-IA to 3000psi LLR of 6 GPM @ 2,000psi differential 7/07/12: PDS 40 arm caliper 10,940'to surface 6/13/12: CMIT TxIA passed to 3000psi 6/12/12: 3.375"Baker IBP set at 10,940'(Top of element) —Still in hole 6/03/12:Leak detect log identifies leak is at 10,799'LLR of 5.6gpm @ 1,700psi differential 10/3/13: Pre job MIT-T, MIT-IA failed with a LLLR of .2bpm @ 3000psi PROCEDURE BNB a:—Rccord all LLR Slickline—Install Circ. Sleeve 1. MIRU SL 2. Drift with TEL or nipple locator for depth control 3. Set 4.5"HES Evotrieve with junk catcher directly above the X-Nipple at 10,778' MD. 4. MIT-T to 3,000 PSI a. If MIT-T fails RDMO and call town engineer for a plan forward. • • • b. Record all LLRs 5. Install cir sleeve in GLM# 1 @ 10,711'MD a. Deviation is —59 degrees rollers may be required to reach target depth Fullbore 1. MIRU choke skid to tubing side of the well and install hardline to take returns to open top tanks and to production. 2. Circulate 450bbls of diesel down IA and up tubing taking returns to production. 3. Mix 8 PPA 40Ib HEC gel with sand mixture and breaker as per appendix A a. Final slurry volume should be X4.5 bbls 4. Pump 2 bbls of non-sand loaded 40lb HEC gel as lead in for sand slurry 5. Pump Slurry down IA and while taking returns to the flowline or tanks if needed. a. Pump all 1,0781bs of sand and adjust displacement volume as necessary 6. After pumping slurry close in tubing and note shut in tubing pressure (SITP). a. Tubing pressure should be higher than IA pressure due to increased hydrostatic of the slurry. 7. Displace Slurry down the IA with 270 bbls of diesel while taking returns up the tubing. a. Maintain SITP with choke while displacing slurry to avoid u-tubing and over displacement. 8. Close in well and allow 3 days for gel to break and sand mixture to fall. Slickline—Pull Circ Sleeve, Install DGLV, Pull IBP, Install live GLV 1. Pull circ. sleeve from GLM# 1 @ 10,711'MD 2. Install DGLV in GLM #1 3. Perform a MIT-IA to 3000 psi; record all LLRs a. If well does not pass MIT-IA attempt to cycle surge the IA to push sand down hole. b. If well still does not pass MIT-IA RDMO and notify town engineer. 4. Pull Evotrieve plug from "10,778' MD (pending passing MIT-IA) a. Sand may have fallen on top of Evotrieve Plug and may need to be bailed before pulling. b. Deviation is —60 degrees rollers may be required to reach target depth • a • • • • 5. Pull IBP from 10,940' MD a. Expected reservoir pressure is 4620 psi at 9200 tvdss b. With Diesel above the IBP 1,300 psi of WHP will be required to balance the plug. 6. Install generic GLV design per GL engineer. • • • APPENDIX A: Gelled Slurry Design Sand Mixture Component Fraction (by weight) lbs. required 20/40 Carbolite .65 700 S100 Sand .125 135 D066 Silica Flour .125 135 Barite .10 108 Notes: • Absolute density of mixture will be very close to the bulk density of the 20/40 Carbolite .961bs/ft^3 • Sand mixture weight will be "1,078 lbs • Final sand volume should be "7.28 ft^3 or 1.29 bbls • Final plug length in the annulus should be " 49.154' HEC Gel Design Base Gel —40Ib HEC BHST— 130 deg F Break Time— 12-24hrs Breaker Type-J134 Tested Breaker concentration- 1ppt Slurry Mixture 401b HEC at 8 PPA sand mixture Total Volume of Gel needed is 135 gallons + 84 gallons (2bbls) unloaded for lead = 215 gallons Mixed Slurry Volume is 4.5 bbl Total gel volume (mixed + lead) 6.5 bbls Volume Notes/Assumtions • RKB to BF is "40ft • Annulus capacity factor is .026244 bbls/ft • Distance from BF to GLM#1 is 10,671' • Volume from BF to GLM#1 is 280 bbls • Desired gel distance from GLM#1 when tubing is shut in is 100' • Distance from bottom of gel to packer at tubing shut is 188' • Volume from bottom of gel to packer 5 bbls • • BP Exploration (Alaska) Inc. i : , Attn: Well Integrity Coordinator, PRB -20 Jd Post Office Box 196612 Anchorage, Alaska 99519 -6612 L July 6, 2011 �� ,e, ; .._ l Mr. Tom Maunder aD 3 _ D5 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue t i 'r1 Anchorage, Alaska 99501 d ` 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 1780280 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 4/14/98 NA NA NA NA NA NK -05 1850270 500292129000 P&A 4/15/98 NA NA NA NA NA NK-06 1852780 500292148800 P&A 4/15/98 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 500292242500 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 r e.) NK -12C 2030550 500292241403 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 2080310 500292288801 1.8 NA 1.8 NA 17.0 5/4/2011 NK -15 1970320 500292274500 1.8 NA 1.8 NA 18.7 5/4/2011 NK -18 1940220 500292244700 2.5 NA 2.5 NA 20.4 5/4/2011 NK -17 1981850 600292270900 3 NA 3 NA 20.4 5/4/2011 NK -18 1931770 500292242100 2 NA 2 NA 17.0 5/8/2011 NK -19A 2010700 500292250701 1.8 NA 1.8 NA 15.3 5/8/2011 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 6/11/2011 NK -23 1940350 500292245500 3.6 NA 3.6 NA 20.4 5/10/2011 NK -25 1970880 500292278000 2.5 NA 2.5 NA 15.3 5/11/2011 NK -28 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 1980930 500292287800 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 5/8/2011 NK-41A 1971580 500292277801 9.1 NA 9.1 NA 54.0 5/9/2011 NK-42 1941080 500292249900 2 NA 2 NA 13.6 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 2050830 500292288901 1 NA 1 NA 8.5 5/8/2011 OPERABLE: NK-12C (PTD #20~50) TxIA Comm repaired • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Sunday, October 18, 2009 8:26 PM ~~ ~~~(~' ~~~ To: NSU, ADW Well Integrity Engineer; Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr North (Gas Plants/GPMA); GPB, GPMA OTL; GPB, LPC DS Ops Lead; GPB, LPC DS Operator; Gerik, Bob G Cc: Holt, Ryan P (ASRC) Subject: OPERABLE: NK-12C (PTD #2030550) TxIA Comm repaired All, / Well NK-12C (PTD #2030550) passed an MIT-IA after the gas lift valves were dummied off. The passing test confirms tu ~ integrity has been'restored. The well has been reclassi~ied as Operable and may be placed on production after slickline sets the new gas lift valve design. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~:~~!~:~~'~~: ~;`!`~` ~. ~~ 2~G~; From: NSU, ADW Well Integrity Engineer Sent: Thursday, October Ol, 2009 8:22 PM / To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>'; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr North (Gas Plants/GPMA); GPB, GPMA OTL; GPB, LPC DS Ops Lead; GPB, LPC DS Operator; Gerik, Bob G Cc: Williams, Carrie; NSU, ADW Well Integrity Engineer Subject: UNDER EVALUATION: NK-12C (PTD #2030550) TxIA Comm All, Well NK-12C (PTD #2030550) has been found to have sustained casing pressure due to TxIA communication. A TIFL failed on 9/27/09 when the wellhead pressures were tubing/IA/OA equal to 265%2620/0. The well has been rec a`rssified as Under Evaluation and may remain online while further diagnostics are being conducted. The plan forward includes: 1. DHD: TIFL - FAILED when well was SI 2. Operations: POP well post LPC shut down 3. DHD: Re-TIFL to ensure checks in gas lift valves are closing properly A TIO plot and Wellbore schematic have been included for reference. Please let me know if you have any questions. Thank you, o~ 11 /6/2009 OPERABLE: NK-12C (PTD #20~50) TxIA Comm repaired • Page 2 of 2 Anna ~Du6e, ~P. E. We61 Integrity Coardinafior GPB Welis Group Phone: (9p7} 659-5102 Pager: (9Q7) 659-5100 x1154 11 /6/2009 PBU NK-12C PTD #2030550 10-1-2009 TIO Pressures Ao~1 ................. ................................................................... ... • 3.00o i ~ -!- Tb9 ~N ~y ^~f~-~~-s*!^~~ r-~-f~~-f~~~~~ff-~-f-f~--~-~~~i~~--Nffif-~~~~~~f~ ~Hf~f-~N-~i~~-~- N~-~~~E~~--~~~~-r ~I ^^ ^ IA ~- OA 2A00 OOA I • OOOA ^ On ~ ~ I II I 1.000 i ~ ~-~ ~ ~ ~ - ~ ~ ~ _ s~-~ ~ 07/04/09 07/11/09 07/18/09 0725l09 OB/O1/09 08/08/09 08/15/09 08/7JJ09 06I29/09 09l05/09 09/12l09 09/19/09 09/Z6l09 • TREE = CIW MOD FL5 WELLHEAD = 13-5/8" 5M FMC ~ _~~.T,~,. ~ ACTUATQR = BAKER C KB. ELEV = 51.88' _ BF. ELEV = ~ KOP = Max Angle = Datum MD = 1300' 106 @ 16693' 16356' Datum ND = 920d' SS ~ -'~ 2C ~ ' ~ 10-3/4" CSG, 45.5#, NT-805 BTC, ID = 9.950" (-~ 4764' Minimum ID = 2.377" @ 17368" T4P OF 2-7/8" LINER 4-1l2" TBG, 12.6#, L-80 IBT-M, ID = 3.958° ~-~ 10855~ 7-5(8" CSG, 29.7#, N7-95-HS, NSCC, 10 = 6.875" 3-1/2" LNR, 8.8#, ~-80, .0087 bpf, ID = 2.992" ~ 15774~ PERFORATIdN SUMMARY , REF ~OG: ANG~E AT TOP PEKF: 1 d3 @ 16940' Note: Refer to Praduction DB for historical perf data SlZE SPF INTERVAL Opn/Sqz DATE 2'° 6 16940 - 17190 O 02l24l04 ' 2" 6 1721 q- 17320 O 02/24J04 NOTES: I 2023~ ~-~ 4-1/2" HES CP-2 TRSSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 3 3239 3037 40 CAMCQ DOME INT 16 02/29/04 2 7098 5471 59 GAMCO DOME INT 16 07/03/08 1 10711 fi249 59 CAMCO SO fNT 24 07/03/08 7 0778° 10799' 10822' 14842° 10855' 10854' 10849' -14-1/2" HES X NIP, !D = 3.813" ~ 7-5i8" X 4-1/2" BKft S-3 PKR. ID = 3.85d" 4-1/2" NES X NIP, ID= 3.813" 4-1/2" HES XN NIP, M ILLED ID = 3.8" 4-1/2" WLEG, IF = 3.958'~ F1MQ TT LOGGEQ 06/04/01 7-5l8" X 4-1/2" BKR ZXP PKR, ID = 4.938" 10869° BAKER 7" X 5" HMC ~NR HGR, Ib = 4.938" 15691~ --~ 3.7 BKR DEF'LOYMENT SLV, ID = 3.0" 15710~ 3-1/2" HES X NIP, ID = 2.813" '~ 5774' 3-1l2" X 3-3116" Xd, ID = 2.786" MIL~OUT WINDOW 16234° - 16240' 4-1l2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 16550~ ~ 3-3116" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.805" 17349~ 2-7/8" LNR, 6.16#, L-80, .0055 bpf, ID = 2.377" 17515~ 3-3l16" X 2-7/8" XO, !Q = 2.440" ~, PBTD ~-~{ 17482' DATE REV BY COMMENTS DATE REV BY COMMQVTS ORIG€NAL COM P~ETION 07/D9/48 FLS/PJC TREE MQD 01(76i9d RIG 51DETRACK (NK-12A} 03/19l01 CH/KAK RIG 51DETRACK (NK-12B} 02/25t04 JLM(KA FtIGSfDETRACK(NK-12C) 02(29104 FtMi-UKA GLV 1C0 07I08108 KSB/PJC GLV G/O (07/Q3/08) PRUDHQE BAY UNIT WELL: NK-12C f'FRMIT No: ~2030550 API No: 50-029-23414-d3 SEC 36, T12N, R15E, 1327' FSL & 996' FEL BP Exptoration (Ataska} • • ~.. .-,.._ <~~ "a.- .~ .~" , _ r~ MICROFILMED 03101/2008 DU NOT PLACE ANY NEW MATERIAL UNDER THiS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc Oilfield Services . . 2525 Gambell Street Suite 400 Anchorage, Alaska 99503 (9071273,1700 Fax 19(7) 561-8317 Schlumberger August 28, 2006 Christine Mahnken Alaska Oil & Gas 333 West ih Avenue Suite 100 Anchorage, AK 9950 I Dear Ms. Mahnken, Enclosed please find CDs you returned to Schlumberger for being corrupted. The CD for Well S-17B appears to be blank, and a replacement is enclosed. There is nothing wrong with the other two CDs. I successfully opened the text files on both CDs using W ordPad. The Final.tif files on both CDs were successfully processed with Schlumberger software into ASCII files, which show no sign of corruption. However, a replacement CD for each has been furnished to you. If you require further assistance reading these CDs, please contact: Sincerely, ~~~ '" Q ')finr- ~ÇANNEU SEP 1 ;y {.V'.JJ Dana Kostreba Log Data Planning Coordinator DK:dk Encl: 3 original CDs: Wells C-27B, NK-12C, and S-17B 3 replacement CDs for the above Jþl- IL.{S ~ 1057-3 "W {L.{ D5b ~~)o3 -65~- 863-/'8(0 P' /38/0 e e WELL LOG TRANS MITT AL dD:J-· 055 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7'h Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 )3 tßg ~ RE: MWD Formation Evaluation Logs NK-12C, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 NK-12C: LAS Data & Digital Log hnages: 50-029-22414-03 1 CD Rom ~QQ'1ì ~19¡)!ùG ). .;- M(}.~J, DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Permit to Drill 2030550 MD 17515 / TVD Well Name/No. PRUDHOE BAY UN NIA NK-12C Operator BP EXPLORATION (ALASKA) INC Completion Date 2/25/2004 / 9257 / Completion Status 1-01L Current Status 1-01L ._-~--_.,-_._--~-_._----- >1 t...J... I j Pi'v; À ~ \y~ API No. 50-029-22414-03-00 UIC N -,--~-- ---_.~,---~---~ REQUIRED INFORMATION Mud Log No Samples No Directional surve~ DATA INFORMATION Types Electric or Other Logs Run: SGRC Combined GR & EWR, MGR / CCL / CNL Well Log Information: (data taken from Logs Portion of Master Well Data Maint Electr Digital Dataset Med/Frmt Number Name D Pdf Directional Survey Directional Survey C Pdf 12487 Pressure C Las 12487 Pressure Lis 12635 Gamma Ray LIS Verification Name Interval Start Stop Log Log .ß.,u n Interval OH/ Scale Media No Start Stop CH Received 16212 17515 3/18/2004 16212 17515 3/18/2004 1 0540 12491 Case 3/22/2004 1 0540 12491 Case 3/22/2004 16013 17473 9/3/2004 16013 17473 9/3/2004 -"..._._----_.._-,~-~ .~,--."--_.._-----"--- Sample Set Sent Received Number Comments Daily History Received? 0N Formation Tops ~/N L______~__~____________ Well Cores/Samples Information: . Comments Static Pressure/Jewelry Log Static Pressure/Jewelry Log MWD, GR, EWR, ROP MWD, GR, EWR, ROP, DSN 12635 ADDITIONAL INFORMATION Well Cored? Y Ð Chips Received? .~. Analysis Received? _:£jJ>k Comments: . DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Permit to Drill 2030550 Well Name/No. PRUDHOE BAY UN NIA NK-12C Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22414-03-00 MD 17515 TVD 9257 ~ C:;_P._I~:~D._::__~/25~2004_ Compliance Reviewed By: .. ...... __ ..._ _ Completion Status 1-01L Current Status 1-01L UIC N Date: Î--. ""t LL'L I~~ Cp . . -- . ~~.",Ð6S: jZt;,3S WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.:.BºbmP~n --- 333 W~st 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 20, 2004 RE: MWD Formation Evaluation Logs NK-12C, AK-MW-2916015 1 LDWG formatted Disc with verification listing. ~I#: 50-029-22414-03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date# RECEIVED SEP 0 ~5 2004 Alaska Oil & Gas Cons, Commisskm Anchorage · STATE OF ALASKA e ALASKA~IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ~ Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 ~ Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic Test o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 2/25/2004 203-055 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 2/18/2004 50- 029-22414-03-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 2/21/2004 PBU NK-12C 3952' SNL, 995' WEL, SEC. 36, T12N, R15E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 795' NSL, 1652' WEL, SEC. 23, T12N, R15E, UM 51.88' Prudhoe Bay Field I Niakuk Oil Total Depth: 9. Plug Back Depth (MD+ TVD) Pool 904' NSL, 2823' WEL, SEC. 23, T12N, R15E, UM 17482 + 9242 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 721567 y- 5979863 Zone- ASP4 17515 + 9257 Ft ADL 034625 TPI: x- 715336 y- 5989712 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 714162 y- 5989788 Zone- ASP4 (Nipple) 2023' MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost ~Yes ONo NIA MSL 1900' (Approx.) 21. Logs Run: SGRC Combined GR & EWR, MGR I CCL / CNL 22. CASING, LINER AND CEMENTING RECORD 9~~4~~ WT. PER FT. értA.DE Smlfo,lp [)EPTl-tMD SeTTING [ )EF'Tl-iT'IID HOLE - ~~2~N" " Top BOtTOM lOP I BOTTOM SIZE PULLED 20" 94# H-40 Surface 80' Surface 80' 30" 280 cu ft Arcticset 10-3/4" 45.5# NT -80 40' 4764' 40' 4144' 13-1/2" 435 cu ft Class 'G' 7-518" 29.7# L-80 38' 11092' 38' 7440' 9-7/8" 806 cu ft Class 'G' 4-1/2" 12.6# L-80 10849' 16235' 7317' 9206' 6-3/4" 921 cu ft LiteCrete, 286 cu ft Class 'G' 3-1/2" x 3-3/16" x 2-7/8" 8.81# /6.3# /6.5# L-80 15691' 17515' 8931' 9257' 3-3/4" 112 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. ···.·.·.··.i JJBING Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10855' 10799' MD TVD MD TVD 16940' - 17190' 9187' - 9170' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 17210' - 17320' 9169' - 9179' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7500' Freeze Protected with Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): March 1, 2004 Gas Lift Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl CHOKE SIZE I GAS-Oil RATIO 3/28/2004 10.4 TEST PERIOD ... 1,014 573 -0- 1760 566 Flow Tubing Casing Pressure CALCULATED ... Oll-BBl GAs-McF WATER-BBl Oil GRAVITY-API (CORR) Press. 574 1833 24-HoUR RATE 2,339 1,323 -0- 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). SubmO T~~~~~e, ~œ "none", None ~ -,,-~ tlnlf"ltdAI Form 1 0-407 Revised 12/2003 CONTINUED d,....k~V~R~~D~ i \i { "\ L.. 6 'l\lll~. G ØII)lIIBFL APR (, \~ e 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kuparuk 16136' 9158' None 7FSSB 16136' 9158' 4MFS 16276' 9224' 3SB 16349' 9250' 2FS 16390' 9261' 2FS 16536' 9266' 3SB 16583' 9258' 4MFS 16688' 9233' 4AA 16952' 9185' 4AA 17304' 9176' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 03"3/..0 PBU NK-12C Well Number 203-055 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mary Endacott, 564-4388 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". o i \G\ AL Form 10-407 Revised 12/2003 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ....... u.._"· 2/9/2004 2/10/2004 2/11/2004 2/1 2/2004 2/13/2004 2/14/2004 e - Page 1 of 10 BP EXPLORATION Operations Summary Report NK-12 NK-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: I Spud Date: 11/1/1993 End: 2/25/2004 2/9/2004 2/25/2004 N1 : Fr~~. ~ ~~.~_~~urs . Task ¡ Code L~.~T.I_.~hase 14:00 - 17:00 17:00 - 00:00 - - - - - 00:00 - 06:00 06:00 - 08:00 08:00 - 17:00 17:00 - 20:00 20:00 - 00:00 00:00 - 08:00 08:00 - 18:00 18:00 - 00:00 00:00 - 06:00 06:00 - 00:00 00:00 - 06:00 06:00 - 18:00 18:00 - 00:00 00:00 - 06:00 06:00 - 08:00 08:00 - 11 :00 11 :00 - 12:00 12:00 -12:15 12:15 - 14:15 14:15 - 18:00 18:00 - 21 :45 21 :45 - 22:35 3.00 MOB P PRE 7.00 MOB 0.00 0.00 0.00 0.00 0.00 6.00 MOB N P WAIT PRE DECOMP WEXIT PROD1 COMP POST PRE P P N 2.00 MOB 9.00 MOB 3.00 MOB P P P PRE PRE PRE 4.00 MOB P 8.00 BOPSUF P PRE PRE 10.00 RIGU N WAIT PRE 6.00 RIGU N 6.00 RIGU N 18.00 RIGU N 6.00 RIGU N 12.00 RIGU N WAIT PRE WAIT PRE WAIT PRE WAIT PRE WAIT PRE 6.00 RIGU N 6.00 RIGU N 2.00 RIGU N 3.00 RIGU N 1.00 RIGU P WAIT PRE WAIT PRE WAIT PRE WAIT PRE PRE 0.25 RIGU P PRE 2.00 RIGU P PRE 3.75 RIGU P PRE 3.75 RIGU P PRE 0.83 RIGU P PRE Description of Operations ... .-- .-- Rig released from DS1-17B at 1400 hrs. Move Nordic 1 to edge of pad WOW Temp = -25F Wind = 44 Gust WC = -73 F Visibilty Poor Weather conditions improved at 0400 hrs. At 0530 hrs, T= -14F, WC= 46F w/ Wind @ 14 to 25 mph. Getting ready to move Make ready to move rig. warm up drivers, Road trip Move rig from DS1-17B to NK-12C (11 miles) Prepare wellhead for moving rig over. Wind gusting to 30 to 40 mph. Wind perpendicular to rig. Unable to open cellar doors. Pull ahead and open doors. Pull over well, close doors and secure. RIG ACCEPTED AT 2000 HRS 2/10/2004 NU BOPE Pressure Test BOP. Jeff Jones, AOGCC wavered witnessing the BOP test, due to weather WOW. Winds at 30-50 mph. -12F, -80 Wind chill. Next step is changing reels with Peak Crane. 25 mph wind limit. WOW. Winds at 30-40 MPH w/ WC -65 to 81 F WOW. Wind at 25-40 mph. WOW. Wind at 20-35 mph. WOW, Winds gusting 10 to 40 mph T = -20F, WC = -70F WOW, Winds at 28 gusting to 45 mph T = -15F, WC = -66F. Access road from East dock to Niakuk, blows in very quick. Using rig loader to keep road open. WOW. Wind gusting to 30 to 50 mph WOW T = -19 F Winds gusting to 30 mph, WC = -60F WOW. Wind dropped to 10-24 MPH. Called for Peak Crane. Wait for Peak crane to arrive with reel of coiled tubing. Spot Crane and reel of coiled tubing. RIU lines. Wind at 10-15 mph. -22F, -42 WC. SAFETY MEETING. Review lifting plan, hazards and mitigation for picking reel from rig reel house and installing new reel of coiled tubing. Pick reel from reelhouse. M/U reel stand support bushings. Pick new reel and set on reel jacks in reel house. Set bushings into reel. Good tight fit. M/U internal Coil connecter to pull coil to injecter head. Install reel hardline. Pull CT to injecter head. Installed new CT Pack-off and new brass. Pumped air through end of CT to check integrity of hardline. Stabbed Inject into pack off. Dress CT and install BOT CT (Drifted CTC w/1.44" Steel Ball) Open Well Pw = 0 psi. Pumped 5 bbl MEOH and 5 bbl 2% KCL. PT hardlines to 4500 psi. Pumped CT Dart. At 60 bbl pumped, ilce plug in CT. Printed: 3/1/2004 9:53:55 AM e e Page 2 of 10 BP EXPLORATION Operations Summary Report Start: Rig Release: Rig Number: Phase I ! Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-12 NK-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 , I ¡codel Date ¡ From - To I Hours Task NPT i I ---.--....--.- ...... ------- --...---.... ... 2/14/2004 21:45 - 22:35 0_83 RIGU P 2/9/2004 2/25/2004 N1 Spud Date: 11/1/1993 End: 2/25/2004 Description of Operations ".-." . ...--.... --.--..------ ----.--.- .-...-.......... . PRE Approximately 3120ft from end. Pmax = 3700 psi and holding at 62 bbl pumped. RU to pump MEOH in the end of CT. Pumped 0.5bbl, Pressure up to 2200 psi Cycled between pumping MEOH on both ends ofCT Try and cir down CT. Volume total pumped = 71 bbl, CTvol = 72.1 bbl, ice in last 65 ft of CT. Pressured up to 3700 psi. Lowered level wind and steamed coil outside rig above roof. Working to thaw 1 st 20 ft CT No luck Released pressure Cut off 43 ft CT off. Ice in CT after cutting 30 ft CT off. Rehead CTC, small groove in CT. Pull test CTC to 35k OK Pumped 9 bbl down CT, Pine to 4000 psi, still ice in CT. RU to pump MEOH through end of CT_ Pumped 0.5 bbl, switch and pressured up on CT to 4000 psi. P in 15 min = 3700 psi steady. PJSM on way forward Released Pressure. Make CT ready to RIH. RIH at 1_7 fpm steaming CT. CTP = 3500 psi. RIH. Pumping 120 deg F 2% down annulus while RIH At 90 ft in, CTP dropped off to 100 psi. Cir down CT 1.58 bpm. POOH OOH, SD pumps, closed SV and unstab injector. Pumped Dart to catcher. Landed, SD and removed dart catcher. Recovered dart. Cir CT and warm up Insert 1.44" steel ball and displace. Ball landed at 66.7 bbls. M/U WF CTC. Failed press test. M/U again, Failed PI. M/U again Pull / Press test OK. SAFETY MEETING. Review procedure, hazards and mitigation for M/U Milling / MWD BHA. M/U BHA #1, 3.80" mill, string reamer, WF straight motor, Sperry MWD, WF MHA and CTC. BHA = 49.87 FT. RIH. Take returns to Tiger tank. Dispose of returns. RIH clean to XN nipple at 10,841 ft. Tagged XN on depth, no correction. Milled XN nipple. 2.7/2.7 bpm, 2900 psi, Milled thru it in 20 min. Low WOB, 100 psi motor work. Ream up and down 4 times. RIH at 90 fpm, 2.5 bpm, 2200 psi. Clean liner. Up wt at 14,000 ft = 41K. RIH clean to 16,050'. Stop at 16,050 ft. Up wt = 47 K. Dwn WT = 16K. Log / ream down from 16,050 ft with Sperry MWD GR. 2.5 bpm, 2600 psi, 300 FPH. Logged down to 16,350 ft. Stop and made -7 ft CTD GR Tie-in correction. Tie-in Log was DEN/NEU/GR OF 02/22/01. Backream up to 16,040 ft at 10 FPM. 2.5 bpm, 2700 psi, 43K up wt. Clean liner, no motor work. RIH and flag CT at 16,000 FT EOP. [49.9 ft BHA). POOH with Logging / Reaming BHA. circ at 2.5/1.85 bpm, 2500 psi. PJSM LD Milling BHA and PU Packer setting BHA. Pump dart Vet = 68.7 bbl RIH w/ WFT WS-R-BB Packer assy. Wt Check, up = 34.5K 22:35 - 23:50 1.25 RIGU N WAIT PRE 23:50 - 00:00 0.17 RIGU N FLUD PRE 2/15/2004 00:00 - 01 :00 1.00 RIGU N FLUD PRE 01 :00 - 02:00 1.00 RIGU N FLUD PRE 02:00 - 02:15 0.25 RIGU N FLUD PRE 02:15-03:15 1.00 RIGU N FLUD PRE 03:15 - 03:30 0.25 RIGU N FLUD PRE 03:30 - 04:00 0.50 RIGU N FLUD PRE 04:00 - 05:00 1.00 RIGU N FLUD PRE 05:00 - 05:14 0.23 RIGU N FLUD PRE 05:14 - 06:15 1.02 RIGU P PRE 06:15 - 07:00 0.75 RIGU P PRE 07:00 - 08:45 1.75 CLEAN P WEXIT 08:45 - 09:00 0.25 CLEAN P WEXIT 09:00 - 10:00 1.00 CLEAN P WEXIT 10:00 - 12:30 2.50 CLEAN P WEXIT 12:30 - 14:00 1.50 CLEAN P WEXIT 14:00 - 15:20 1.33 CLEAN P WEXIT 15:20-16:15 0.92 CLEAN P WEXIT 16:15 - 16:45 0.50 CLEAN P WEXIT 16:45 - 19:45 3.00 CLEAN P WEXIT 19:45 - 20:10 0.42 CLEAN P WEXIT 20: 1 0 - 22:05 1.92 CLEAN P WEXIT 22:05 - 00:00 1.92 STWHIP P WEXIT Printed: 31112004 9:53:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e e Page 3 of 10 BP EXPLORATION Operations Summary Report NK-12 NK-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To ' Hours i Date Task : Code NPT Phase - -.-...... ....-- - - --... ..... ..--- 2/15/2004 22:05 - 00:00 1.92 STWHIP P WEXIT 2/16/2004 00:00 - 01 :25 1.42 STWHIP P WEXIT 01 :25 - 01 :33 0.13 STWHIP P WEXIT 01 :33 - 01 :42 0.15 STWHIP P WEXIT 01 :42 - 02:34 0.87 STWHIP P WEXIT 02:34 - 02:45 02:45 - 06:00 06:00 - 09:00 0.18 STWHIP P 3.25 STWHIP P 3.00 STWHIP P WEXIT WEXIT WEXIT 09:00 - 11 :00 2.00 STWHIP N WAIT WEXIT 11 :00 - 12:45 1.75 STWHIP N WAIT WEXIT 12:45 - 13:00 0.25 STWHIP P WEXIT 13:00 - 14:30 1.50 STWHIP P WEXIT 14:30 - 17:15 2.75 STWHIP P WEXIT 17:15 -19:00 1.75 STWHIP N DPRB WEXIT 19:00 - 19:33 0.55 STWHIP N DPRB WEXIT 19:33 - 20:00 0.45 STWHIP N DPRB WEXIT 20:00 - 21 :55 1.92 STWHIP N DPRB WEXIT 21 :55 - 23:00 1.08 STWHIP P WEXIT 23:00 - 23: 15 0.25 STWHIP P WEXIT 2/17/2004 23: 15 - 00:00 00:00 - 01 :20 0.75 STWHIP P 1.33 STWHIP P WEXIT WEXIT Start: Rig Release: Rig Number: Spud Date: 11/1/1993 End: 2/25/2004 2/9/2004 2/25/2004 N1 Description of Operations ..--------. ------.. ... .....---...---..-- up, RIH Wt Check dwn =15k RIH to 16,000 ft and corrected to flag (= + 6.3 ft) PU wt = 53k. RIH logging down at 30 fpm to setting depth 16260 ft (btm packer) Ref Log Sperry Sun dated 2-15-2004 PUH 6.3 ft, (Didn't PU string 100%) to get to ball drop postion, Drop 5/8" ball to set packer Displaced ball at Q = 1.5 bpm using 20 bbl High Vis Biozan pill. Volume pumped 64.7 bbl pressure inc. Pmax = 4000 psi. Allow Pkr to set. Taking orientation survey with Sperry's ESS before pulling off. Lost 300 psi PUH. Released from packer with 15k over and CTP of 3000 psi POOH logging with SWS MGR, CCL to 15,890 ft POOH, filling the hole down back side LIO BHA. Down load Sperry and SWS data. Sperry shows Packer lug at 325 deg. Tray program TF will be at 320 deg. SWS Memory GR/CCL shows bottom of WF packer at 16,264 ft. Wait on orders for whipstock space out. Told to add 15 ft pup joint to place top of whipstock at 16,232.6 ft. Casing collar is at 16,241ft. Wait for WF to deliver whipstock. SAFETY MEETING. Review procedure, hazards and mitigation for M/U WF whipstock BHA. M/U WFT whipstock BHA with latch, 15.66 ft spacer pup jt, whipstock and running tools. BHA = 44.36 ft. 2 SWS RA tags set in Whipstock 7.83 ft from top of whipstock. Lug set to position topside of tray at 320 deg. [40L]. RIH with WF whipstock on running tools. RIH clean to 10,818 ft. Set down several times, increase pumps, Pull up hole 300 ft, RIH set down again several times. Skirted Running tool has square edge that may be setting up on a profile in the Baker S-3 Packer at 10,799'. Skirted running tool is 28' from bottom ofBHA. [10,818-28=10,790'] This area has drifted a 3.80" mill and a 3.56" WF Packer. POH to check BHA for marks. LD WS BHA. Leading edge on Overshot / box tap has a square shoulder and markered MU WFT WS and tapered OS / Box tap (45 deg bevel) RIH with WS to 10600', Wt check = 32k up RIH pastjewerly in tail pipe. RIH to EOP flag 16,000 ft (16,053 ft) Corrected to 16,044.4 ft PU wt 54k-up RIH to latch WS Tagged at 16261' w/5k, latched, worked 3 times Pulled up to 66k (12k over) and sheared off. BOTTON OF WFT WSRBB PACKER @ 16265' (from Tie in) TOW @ 16,233.62 ft BOTTOM OF RAMP @ 16,242.69' RA MARKER @ 16,241.45 ft (2) ORIENTATION @ 40 DEG LEFT HIGHSIDE POOH POOH to 7298' Printed: 31112004 9:53:55 AM _h.O__.__...______ 2/17/2004 2/18/2004 01 :20 - 02:00 02:00 - 03:00 03:00 - 06:00 06:00 - 06:45 06:45 - 09:45 09:45 - 10:45 10:45 - 12:30 12:30 - 13:30 13:30 - 14:45 14:45 - 15:45 15:45 - 16:45 16:45 - 17:45 17:45 - 20:40 20:40 - 21 :30 21 :30 - 23:45 23:45 - 00:00 00:00 - 05:00 05:00 - 06:00 06:00 - 07:00 07:00 - 08:30 e e BP EXPLORATION Operations Summary Report __u__._.._. . ..0 _ 0 n_._ Legal Well Name: NK-12 Common Well Name: NK-12 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date I From - To Hours I Task Code NPT I Phase 0.67 STWHIP P WEXIT 1.00 STWHIP P 3.00 STWHIP P WEXIT WEXIT 0.75 STWHIP P WEXIT 3.00 STWHIP P WEXIT 1.00 STWHIP P WEXIT 1.75 STWHIP P WEXIT 1.00 STWHIP P WEXIT 1.25 STWHIP P WEXIT 1.00 STWHIP P WEXIT 1.00 STWHIP P WEXIT 1.00 STWHIP P WEXIT 2.92 STWHIP P 0.83 STWHIP P 2.25 STWHIP P WEXIT WEXIT WEXIT 0.25 STWHIP P 5.00 BOPSUF P WEXIT PROD1 1.00 DRILL N 1.00 DRILL P SFAL PROD1 PROD1 1.50 DRILL P PROD1 Page 4 of 10 2/9/2004 2/25/2004 N1 Spud Date: 11/1/1993 End: 2/25/2004 Description of Operations ________n_n... h ...__._ .._.__n..-. n Gas to surface from bottoms up, SD, checked flow, OK, lined out circulating gas and contaminated fluid through gas buster. Circulated 26 bbl contaminated mud to solids tanks. CT displacement correct Re-set Trip Sheet to 244 bbl. POOH. LD BHA, 2-3/8". CT crimped at 4' above CTC. Cut off 6 ft CT, dress CT, rehead. Pull tested to 35k. PT to 3800 psi M/U 3.80" Window Milling BHA with 3.80" HC diamond window mill, 3.79" HC diamond string mill, WF motor, 2 jts PH6, WF MHA and CTC. BHA = 83.18'. RIH with BHA #4, window milling BHA. RIH clean to top of whipstock. Tag whipstock at 16,231 ft. Correct to 16,234', [+3 ft CTD]. Flag CT at 16,234 ft. Milling 3.80" window in 4.5" liner with 2# Biozan. 2.5/2.5 bpm, 2400 - 2800 psi, 2500# WOB, 46K up wt, 13K dwn wt. Milled to 16,234.8 ft. No stalls. Milling 3.80" window. 2.5/2.5 bpm, 2350 - 2800 psi, 3-4K WOB, Milled to 16,236 ft. No stalls. Milling 3.80" window. 2.5/2.5 bpm, 2350 - 2800 psi, 4-5K WOB, Milled to 16,237 ft. No stalls. Milling 3.80" window. 2.5/2.5 bpm, 2350 - 2800 psi, 4-5K WOB, Pick up clean and backream window. Ream down. Milled to 16,239 ft. No stalls. Milling 3.80" window. 2.5/2.5 bpm, 2350 - 2800 psi, 4-5K WOB, Milled to 16,239.5 ft. Motor stalled. Pick up clean and backream window. Ream down. Milled to 16,240'. Exit liner into formation @ 16239.5'. Mill 10' formation from 16240' to 16250' with 2.5/2.5bpm, 2350/2800psi, 3-4k WOB & 1 Of ph ave ROP. Tentative window depths are: TOWSfTOW = 16234'; BOW = 16240', RA PIP Tag = 16241.4'. Backream/ream window/rat hole & make several dress/drift passes with & without pumping. Window looks clean. Meanwhile swap wellbore to 8.6ppg reconditioned flopro mud. Recovering metal shavings on magnets. Paint EOP flag @ 15717' & POOH window milling BHA#4. LD BHA. Window mill 3.79", string mill 3.78". Pump MeOH back into coil to FP. Cut off Weatherford CTC. Dress pipe and attempt to install DS CTC. Hammer on DS dimpler to within 2" of required location. Unable to get dim pier on any further. Pull off dimpler with 26K Ibs injector pull. Caliper pipe. Pipe is egged. OD varies from 2.37" to 2.42". While working on CTC, replace threaded connections on choke manifold with new welded connections. RU to test BOPE. Test BOPE to 250/3500 psi as per AOGCC regs and BP policy. Witness of test waived by Chuck Sheve of AOGCC. File & round-off CT tip to uniform OD. Install DS CTC. Pull test to 35k. PT to 3500psi. Line up & PT inner reel valve to 3500psi. PJSM. M/U drilling BHA #5 with BHl1.8deg extreme motor, Sperry PWD/MWD/GR (taper-lock style) & new HTC RWD 3-3/4" x 4-1/8" bicenter bit #3. M/U injector. Printed: 31112004 9:53:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date .... .....-............-.- 2/18/2004 2/19/2004 e e BP EXPLORATION Operations Summary Report NK-12 NK-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 ; From - To Hours: Task Code NPT: Phase 08:30 - 11:45 11 :45 - 12: 1 0 12:10 - 14:25 14:25 - 15:20 15:20 - 15:30 15:30 - 15:35 15:35 - 15:50 15:50 - 16:00 16:00 - 16:35 16:35 -17:15 17:15-17:30 17:30 - 18:15 18:15 - 00:00 00:00 - 01:45 01:45 - 02:15 02:15 - 03:20 03:20 - 03:45 03:45 - 06:45 06:45 - 07:25 07:25 - 08:00 08:00 - 08:30 08:30 - 09: 15 09:15 - 09:30 09:30 - 10:00 10:00-11:10 11:10 -14:15 14:15 - 15:15 15:15 - 17:00 .... .. --- --... ...- 3.25 DRILL P 0.42 DRILL P 2.25 DRILL P 0.92 DRILL P 0.17 DRILL P 0.08 DRILL P 0.25 DRILL N 0.17 DRILL P 0.58 DRILL P 0.67 DRILL P 0.25 DRILL N 0.75 DRILL P 5.75 DRILL P 1.75 DRILL P 0.50 DRILL P 1.08 DRILL P 0.42 DRILL P 3.00 DRILL P 0.67 DRILL P 0.58 DRILL P 0.50 DRILL P 0.75 DRILL N 0.25 DRILL P 0.50 DRILL P 1.17 DRILL P 3.08 DRILL P 1.00 DRILL P 1.75 DRILL P .; PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 RREP PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Page 5 of 10 Start: 2/9/2004 Rig Release: 2/25/2004 Rig Number: N1 I Spud Date: 11/1/1993 End: 2/25/2004 Description of Operations ...... ................-...--- -.-. .. .. .__u__._.... _u. .______ RIH BHA #5. SHT MWD & orienter @ 1300' - OK. RIH to EOP flag. Subtract 3.5' from CTD. Continue RIH & tag TD @ 16248'. Correct CTD to 16250'. Orient TF to 50L. Drill to 16290' with 55L TF, 2.6/2.6bpm, 3500/3680psi, 20fph ave ROP. Observe higher than normal GR MWD readings. Drill to 16316' with 45L TF, 2.6/2.6bpm, 3450/3600psi, 30fph ave ROP. Attempt to float off btm survey - survey not coming thru. PUH into window to rectify SCR overload problem. Rectify SCR problem. PUH 16160' for GR tie-in log. Log down GR & tie-in wellbore to Geology PDC log. RBIH to 16260'. Log down RA PIP tag & add 2' to CTD. Corrected window depths are: TOWSITOW = 16235'; BOW = 16241', RA PIP Tag = 16243'. RBIH & tag btm @ 16320'. Orient & drill to 16335' with 45L TF, 2.6/2.6bpm, 3450/3600psi, 30fph ave ROP. Attempt to float off btm survey - still not able to. Orient & drill to 16354' with 45L TF, 2.6/2.6bpm, 3450/3600psi, 30fph ave ROP. Drill from 16,354' to 16,450' at 2.5/2.53,500/3,700 psi. Erratic detection from MWD. Unable to get full surveys. Short surveys are OK while drilling. Drill to 16,475'. Still not able to get full survey off bottom. Continue using short surveys. Wiper trip to window. Hole in good condition. Attempt to get full survey at various spots, no good. Orient to 90R. Drill at 2.5/2.5 3,400/3,700 psi. Orient to 45L. Drill at 2.5/2.5 3,400/3,700 psi. Drill to 16560'. Orient TF around to 90L. P/U wt = 40k, S/O wt = 15k. Drill to 16589' with 60L TF, 2.5/2.5bpm, 3550/3850psi, 50fph ave ROP & 3k WOB. Not getting any MWD surveys. Wiper trip to window & switch mud pumps to see if MWD surveys will improve. RBIH to 16352'. Shoot off btm survey - no luck. Creep in hole & reshoot surveys - still no luck. Orient TF around to 90L. P/U wt = 39k, S/O wt = 13k. PVT = 322bbls. Drill to 16600' with 80L TF, 2.4/2.4bpm, 3400/3750psi, 25fph ave ROP & 3k WOB. Getting on-the-fly btm surveys again. Drill to 16625' with 90L TF, 2.6/2.6bpm, 3700/3900psi, 25fph ave ROP & 2k WOB. Geo does not want to drill any further without full surveys for azimuth confirmation. Decide to POOH to P/U RES tool & C/O MWD. Paint EOP flag @ 16000' & POOH drilling BHA#5. OOH. PJSM. SIB injector. Flush & UD BHA. Bit gauge 2/3/1 with some abrasive wear on the hole opening blades possibly due to drilling 1-2% Chert/Pyrite. M/U drilling BHA #6 with new BHI 1.5deg Xtreme motor & new HTC RWD 3-3/4" x 4-1/8" bicenter bit #4, new Sperry PWD/MWD/GR-RES, orienter & MHA. Scribe tools & initialize Printed 31112004 953:55 AM e e BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: NK-12 Common Well Name: NK-12 Spud Date: 11/1/1993 Event Name: REENTER+COMPLETE Start: 2/9/2004 End: 2/25/2004 Contractor Name: NORDIC CALISTA Rig Release: 2/25/2004 Rig Name: NORDIC 1 Rig Number: N1 Date I Hours Task Code NPT i Description of Operations I From - To Phase ! ! ---- ..__.____n. ...... ......--------.. n___..___n....._ .... ........ . . ·....n... -.---....-.-.--... 2/19/2004 15:15 -17:00 1.75 DRILL P PROD1 EWR. M/U injector. 17:00 - 20:00 3.00 DRILL P PROD1 RIH BHA #6. SHT MWD & orienter @ 1300' - OK. RIH to EOP flag. Correct +10' at flag. RIH. Tag TD at 16,625'. 20:00 - 20:45 0.75 DRILL P PROD1 Survey at 16,621' bit depth. Orient to TF hole was drilled. Resurvey. 20:45 - 23:45 3.00 DRILL P PROD1 MAD pass from 16,625' to at 125 fpm. 23:45 - 00:00 0.25 DRILL P PROD1 RIH. Survey at 16,352' bit depth. Bad survey due to magnetic interference. RIH to 16,382' 2/20/2004 00:00 - 00:25 0.42 DRILL N PROD1 RIH to 16,439'. Survey. RIH to 16,526'. Survey. 00:25 - 00:30 0.08 DRILL P PROD1 Orient to 45L. 00:30 - 01 :50 1.33 DRILL P PROD1 Drill ahead from 16,625' to 16,675' at 2.6/2.63,850/4,000 psi. 01 :50 - 02:00 0.17 DRILL P PROD1 Orient to 80R. 02:00 - 04:05 2.08 DRILL P PROD1 Drill from 16,675' to 16,733' at 80R - 120R. 04:05 - 04:15 0.17 DRILL P PROD1 Orient to 95L. 04: 15 - 06:35 2.33 DRILL P PROD1 Drill at 2.6/2.63,950 psi. Drill to 16800'. 06:35 - 07: 15 0.67 DRILL P PROD1 Wiper trip clean to window. 07:15 - 07:30 0.25 DRILL P PROD1 Log up GR & tie-into RA PIP tag. Add l' to CTD. 07:30 - 07:45 0.25 DRILL P PROD1 RBIH clean to TD. 07:45 - 08:05 0.33 DRILL P PROD1 Drill to 16818' with 70L TF, 2.4/2.4bpm, 3650/3950psi, 45fph ave ROP & 5-7k WOB. Stacking Wt. 08:05 - 08:25 0.33 DRILL P PROD1 Orient TF around to 100L. 08:25 - 09:30 1.08 DRILL P PROD1 Drill to 16875' with 120L TF, 2.4/2.4bpm, 3650/3900psi, 65fph ave ROP & 4-6k WOB. Still stacking wt - pump down 30bbls of reserve fresh mud & call for new mud. 09:30 - 09:45 0.25 DRILL P PROD1 Short 100' wiper. Freespin drop to 3560psi @ 2.4bpm. P/U wt = 39k, S/O wt = 12k. PVT = 304bbls. 09:45 - 10:15 0.50 DRILL P PROD1 Drill to 16894' with 120L TF, 2.4/2.4bpm, 3560/3950psi, 45fph ave ROP & 5-7k WOB. 10:15-10:30 0.25 DRILL P PROD1 Orient TF around to 80R. 10:30 - 11 :20 0.83 DRILL P PROD1 Drill to 16933' with 80R TF, 2.4/2.4bpm, 3600/3950psi, 55fph ave ROP & 5-7k WOB. 11 :20 - 11 :45 0.42 DRILL P PROD1 Orient 1 click & drill to 16950' with 100R TF, 2.4/2.4bpm, 3600/3950psi, 50fph ave ROP & 7-9k WOB. 11 :45 - 12:30 0.75 DRILL P PROD1 Wiper trip clean to window. RBIH to btm & swap wellbore to new 8.6ppg Flopro mud with 48k LSRV, 4% L-T & 2% F-L. 12:30 - 14:00 1.50 DRILL P PROD1 Orient & drill to 17021' with 100-115R TF, 2.5/2.5bpm, 3600/4000psi, 85fph ave ROP & 3k WOB. Break into good sand @ 16980' - could have crossed a fault contact. 14:00 - 14:15 0.25 DRILL P PROD1 Orient TF to 130L. 14:15 - 14:40 0.42 DRILL P PROD1 Orient & drill to 17052' with 90-100L TF, 2.6/2.6bpm, 3600/3900psi, 85fph ave ROP & 3k WOB. Observe circ pressure spiking to 4000psi @ 2bpm - could be packing-off in the annulus. 14:40 - 17:15 2.58 DRILL N FLUD PROD1 Wiper trip clean to window with no O/Pulls. However still getting hi circ pressures - 4000psi @ 1.8bpm. Continue POOH above window. Getting cuttings sweep back. At 9000' observe very thick mud slug over the shakers. Circ out ca. 20bbls thick mud slug & pressures drop to 3100psi @ 2.5bpm. Continue wiping hole to 6000' (58degs incl). Suspect some mud contamination during mud swap caused a localized gelling problem. On the +ve side, the gel slug was a good sweep for the wellbore. Collected thick mud samples thinned out within 30mins @ surface. I I I Printed: 3/1/2004 9:5355 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date .....--.- ...-.. 2/20/2004 2/21/2004 2/22/2004 e e BP EXPLORATION Operations Summary Report NK-12 NK-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To I Hours I Task ; Code NPT ! ____._.._.l... ....__..__ 17:15 - 19:25 19:25 - 19:30 19:30 - 21 :00 21:00 - 21:15 21:15-00:00 00:00 - 01 :20 01 :20 - 04:10 04:10 - 05:15 05:15 - 06:15 06: 15 - 07:35 07:35 - 07:45 07:45 - 08:00 08:00 - 08:20 08:20 - 09:35 09:35 - 10:00 10:00 -12:15 12:15-14:00 14:00 - 14:35 14:35 - 15:00 15:00 - 15:30 15:30 - 15:35 15:35 - 16:25 16:25 - 16:45 16:45 - 20:10 20:10 - 22:00 22:00 - 23:00 23:00 - 23:20 23:20 - 23:45 23:45 - 00:00 00:00 - 03:15 03:15 - 04:00 2.17 DRILL N 0.08 DRILL P 1.50 DRILL P 0.25 DRILL P 2.75 DRILL P 1.33 DRILL P 2.83 DRILL P 1.08 DRILL P 1.00 DRILL P 1.33 DRILL P 0.17 DRILL P 0.25 DRILL P 0.33 DRILL C 1.25 DRILL C 0.42 DRILL C 2.25 DRILL C 1.75 DRILL C 0.58 DRILL P 0.42 DRILL P 0.50 DRILL P 0.08 DRILL P 0.83 DRILL P 0.33 DRILL P 3.42 DRILL P 1.83 DRILL P 1.00 DRILL P 0.33 CASE P 0.42 CASE P 0.25 CASE P 3.25 CASE P 0.75 CASE P Phase FLUD PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 COMP COMP COMP COMP COMP Page 7 of 10 Start: 2/9/2004 Rig Release: 2/25/2004 Rig Number: N1 Spud Date: 11/1/1993 End: 2125/2004 Description of Operations -.-.--..-.... ._u_____ . .---...---..-"..-- ..-.--- RBIH to continue drilling. Tag bottom and correct depth. Orient one click. Drill to 17,110' at 90L to 45L. Orient back around to 90L. Drill to 17,215' at 120L to 90L. Wiper trip to window. PU=40.4K Ibs Tie in to RA marker. -1' correction. RIH. SO=14Kat16,360'. SO=11.3Kat17,170'. Tag bottom. Drill at 2.5/2.5 3,550/3,900 psi, 150L to 1 OOL TF, 60 fph average ROP. Wiper trip. 20K Ib overpull picking up off bottom. Clean to window. Drill at 2.5/2.5 3,950 psi, 130L TF. Drill to 17410'. Orient 1 click & drill to 17470' with 90L TF, 2.5/2.5bpm, 3600/3900psi, 45fph ave ROP & 4k WOB. Phase-1 driving conditions declared in GPB. Short 100' wiper. P/U wt = 42k, S/O wt = 11 k. PVT = 303bbls. Drill to 17479' with 100L TF, 2.5/2.5bpm, 3650/4100psi, 35fph ave ROP & 5k WOB. Cross end of polygon @ 17477' @ 9187'ssTVD. Orient 1 click & drill to 17500' with 90L TF, 2.5/2.5bpm, 3650/4100psi, 65fph ave ROP & 5k WOB. Plan is to TD @ no more than -9243'ssTVD & roll to HS @ top of 2FS or -9205'ssTVD. Wiper trip clean to window. RBIH to btm. Drill to 17513' with 90L TF, 2.6/2.6bpm, 3600/3850psi, 30fph ave ROP & 6k WOB. Orient 3 clicks & drill into hard spot @ 17515'. Grind-on while W.O. btm samples. Samples contain 2-3% pyrites. Review forward options & decide to be patient & grind thru hard spot. Meanwhile start making plans for possible OH sidetrack with WF AL-W/S. Grind on to 17520' with 35L TF, 2.6/2.6bpm, 3600/3850psi & 6k WOB. Geo seeing close to 20-30% pyrites in sample. ANC team finally calls TD. Wiper trip clean to window. Log up GR & tie-into RA PIP tag. Add 5' to CTD. RBIH clean & tag TD @ 17515'. P/U & reconfirm TD@ 17515'. PUH to 17400' for MAD pass relog. MAD pass GR/RES from 17400' to 16900' @ 10fpm. Meanwhile pump down fresh flopro pill. RBIH to btm. POOH laying in 30bbls of new FloPro pill in OH for running Inr. Paint CT EOP flags @ 15600' & 14300'. Continue POOH for liner. Down load RES tool. LD BHA. Washout in equilizer sub. Bit 1-3-BT -G-X-NO- TO Clear rig floor. Off load motor and MWD. PU Baker tools. PJSM for running liner. RU to run liner. Off load excess 2 7/8" liner. Run liner. Run 2 7/8" x 3 3/16" liner. Cut off DS CTC. Install Baker CTC. Pull test to 35,000 Ibs, PT to 3,500 psi. Printed: 3/1/2004 9:53:55 AM e e BP EXPLORATION Operations Summary Report Legal Well Name: NK-12 Common Well Name: NK-12 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 I ¡ Date I From - To ~ Hours i Task Code NPT ._.... '"o_.h .._no_u_ 2/22/2004 04:00 - 06:00 06:00 - 07:15 07:15 - 08:15 08:15-11:15 11:15-11:30 11 :30 - 13:25 13:25 - 16:30 16:30 - 17:30 17:30 - 18:30 18:30 - 19:30 19:30 - 21 :00 21 :00 - 00:00 2/23/2004 00:00 - 02:45 02:45 - 04:45 04:45 - 06:00 06:00 - 06:30 06:30 - 06:45 06:45 - 08:25 08:25 - 10:45 10:45 - 11 :40 11:40-12:15 Page 8 of 10 Start: Rig Release: Rig Number: Phase 2/9/2004 2/25/2004 N1 Spud Date: 11/1/1993 End: 2/25/2004 --.- .. ..._. .... ._n_ 2.00 CASE P COMP 1.25 CASE P COMP 1.00 CASE P COMP 3.00 CASE P COMP 0.25 CEMT P COMP 1.92 CEMT P COMP 3.08 CEMT P COMP 1.00 CEMT P 1.00 CLEAN P COMP COMP 1.00 CLEAN P 1.50 CLEAN P COMP COMP 3.00 CLEAN P COMP 2.75 CLEAN P 2.00 CLEAN P COMP COMP 1.25 EVAL N 0.50 EVAL P 0.25 EVAL P 1.67 EVAL P WAIT COMP COMP COMP COMP 2.33 EVAL P 0.92 EVAL P COMP COMP 0.58 EVAL P COMP I I Description of Operations n..___ ........ .._.n -....-.... ._.__n -- RIH w/liner on CT to 13,000'. GPB currently in Phase I driving conditions on all main roads and Phase II on all access roads and pads. RIH with liner on CT. See 1st flag @ 16132'. Correct CTD (+1.6') to 16133.6'. Check up wt - 44k, down wt - 14k. RIH smoothly @ 50 fpm thru window. See 2nd flag right on depth. Tag TD @ 17517' CTD. P/U @ 50.5k. RBIH @ 12k & retag TD @ same depth. Load 5/8" steel ball & circ with mud @ 2.012.0bpm, 2900psi. Set down 10k down on CTLRT. Continue circ ball to seat. Slow down @ 50bbls away. Ball on seat @ 59.2bbls. Pressure up to 4400psi & release CTLRT. P/U @ 44k & confirm release. Displace well to 3% KCI at 3.3/3.3bpm & 3950psi. Meanwhile Dowell cement batchmixer get stuck in snow drift on the pad - pull with rig loader. R/U Dowell cementers. Ship back used mud to MI. PJSM with all personnel concerning cementing operations. PVT = 331bbls. Batch mix 20bbls 15.8ppg expansive cmt with D176 & other additives. Cmt to wt @ 11 :55hrs. Flush/PT lines to 4k. Pump 20bbls cmt slurry @ 2.1 0/1.88bpm & 1630psi. Close inner reel valve & clean lines. Loadllaunch CTWP. Chase with bio-KCL @ 2.33/2.18bpm & 1780psi. Start getting 1: 1 returns with cement @ the shoe. CTWP engage LWP at 69.4bbls away. Shear plug with 3100psi. Continue displacing LWP @ 2.55/2.55bpm, 2200psi & bump @ 82.4bbls away. 20bbls cmt pumped around shoe. Floats held. Pressure up to 500 psi & sting out of liner. CIP at 13:20 hrs. PVT = 320bbls. POOH @ 64fpm pumping @ 0.35bpm to replace CT voidage only. OOH. PJSM. SIB injector & UD CTLRT. Prep to run liner cleanout BHA & MCNUCCLlGR. Reviewed unavailability of CNL tool carrier with ANC team & decide to make cleanout run 1st before logging. Crew change & PJSM for PU cleanout BHA and running CSH. PU 2.3" mill and motor. RIH w/ 30 stands of 1 1/4" CSH from mast. MU BHA to CTC. RIH. No motor work while RIH. Tag landing collar at 17,478'. POOH. POOH. Stand back injector. PJSM. Rack back 18 stands of CSH. LD excess CSH and LD BHA. Wait on SWS. Initialize & test logging tools. P/U tool into rig floor. PJSM on P/U & RIH CNL tools & 1-1/4" CHS tbg. M/U logging BHA #9 with SWS MCNUCCUGR logging tool carrier & Nozzle, lower disconnect, XO, 60jts of 1-1/4" CSH tbg, XO & upper MHA. M/U injector. RIH logging BHA#9 on CTto 15500'. Log down @ 60fpm from 15500'. Meanwhile start pumping down 150kcps Flo-Pro perf pill. Continue logging down to PBTD tagged @ 17484'. Log up @ 60fpm from PBTD to 15500' while laying-in 150kcps I Printed: 3/1/2004 9:53:55 AM e e Page 9 of 10 BP EXPLORATION Operations Summary Report NK-12 NK-12 REENTER+COMPLETE Start: 2/9/2004 NORDIC CALISTA Rig Release: 2/25/2004 NORDIC 1 Rig Number: N1 Ho~rs ¡._~ask J?o~:.1 NPT : Phase ___.__ Description ~~Oper~tion~_______ 0.58 EVAL P COMP perf pill in liner. 3.00 EVAL P COMP Paint EOP flag @ 13600' & POOH logging BHA#9. 0.25 EVAL P COMP PJSM for LID & R/B CSH. 2.00 EVAL P COMP LID 12 Jts & R/B 24 stands of 1-1/4" CSH. 0.50 EVAL P COMP PJSM. LID SWS MCNLlCCLlGR logging tool. Check log data quality - OK. Fax CNL log to ANG Geo. From log data, PBTD = 17481' & TOL = 15687'. Line up to test liner lap. Cement was @ 2000psi compressive strength @ 04:00 Hrs today before lab lost power to UCA. IAlOA @ 390/150 psi & PVT @ 186bbls @ onset of test. Staged up in 500 psi intervals, monitoring IA. Pressure up wellbore to 1500 psi. IAP/OAP come up to 1500/300psi. TRSSSV also gained 50psi. After 15mins WHPIIAP/OAP stabilize @ 1208/1450/260psi. Suspect welborellA communication @ 1st GLM @ 3239'. Discussed with ANC team & agreed to do a combo test. RU to bleed pressure off IA. Bleed gas / fluid from IA to 800 psi. Mean while, bring perf guns up beaver slide due to Nordic loader being out of commision. Perform combo T x IA pressure test. Pressure up tubing to 2,000 psi. IA=1277 psi. Monitor pressures. Tubing pressure falling and IA pressure increasing. Repeatedly pressure up tubing and let IA pressure build up. Pressure up tubing to 2,580 psi. Time (MIN) TBG IA OA o 2580 2760 397 1 2534 2780 391 2 2505 2789 388 3 2490 2793 386 4 2487 2794 386 5 2483 2795 386 6 2472 2793 385 7 2472 2793 385 8 2468 2793 385 9 2468 2791 385 10 2468 2789 385 16 2461 2782 383 20 2457 2781 382 25 2545 2777 382 30 2454 2773 382 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 2/23/2004 11:40 -12:15 12:15 - 15:15 15:15-15:30 15:30 - 17:30 17:30 - 18:00 18:00 - 19:00 1.00 CASE COMP P 19:00 - 20:00 1.00 CASE P COMP 20:00 - 22:00 2.00 CASE COMP P 22:00 - 22:15 0.25 PERF P COMP 22: 15 - 23:00 0.75 PERF P COMP 23:00 - 00:00 1.00 PERF P COMP 2/24/2004 00:00 - 00:45 0.75 PERF P COMP 00:45 - 03:30 2.75 PERF P COMP 03:30 - 04:40 1.17 PERF P COMP Spud Date: 11/1/1993 End: 2/25/2004 Bleed off pressure. PJSM for PU perf guns. ANC Geo okays perf picks. PU perf guns. MU firing head to joint of CSH. RIH w/ CSH. RIH w/ CSH. MU hydraulic disconnect, check valves, NRJ. Stab injector. RIH. Flag on depth. Tag landing collar at 17,478'. Correct depth to 17,480'. Pull up to 17,328'. PU=69K. Drop 5/8" aluminum ball. Circulate ball down w/ perf pill at 2 bpm, 2,770 psi. Slow rate to 1 bpm at 50 bbls pumped. Ball on seat at 67.7 bbls. Start moving pipe at 5 fpm. Pressure up and fire guns at 3,050 psi. Printed: 3/1/2004 9:53:55 AM e e BP EXPLORATION Operations Summary Report Start: Rig Release: Rig Number: I Phase i I ...___---L--__ __ _ ________. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NK-12 NK-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours i Task I Code NPT ..--... .. _. n_ ..--.---- .. 2/24/2004 03:30 - 04:40 1.17 PERF P COMP 04:40 - 08:30 3.83 PERF P COMP 08:30 - 08:45 0.25 PERF P COMP 08:45 - 10:45 2.00 KILL N HMAN COMP 10:45 - 12:30 1.75 KILL N WAIT COMP 12:30 - 13:30 1.00 KILL N DPRB COMP 13:30 - 14:00 0.50 KILL N DPRB COMP 14:00 - 14:30 0.50 KILL N DPRB COMP 14:30 - 15:00 0.50 PERF P COMP 15:00 - 16:00 1.00 PERF P COMP 16:00 - 18:00 2.00 PERF P COMP 18:00 - 18:30 0.50 CLEAN P COMP 18:30 - 19:00 0.50 PERF P COMP 19:00 - 19:45 0.75 WHSUR P COMP 19:45 - 22:00 2.25 WHSUR P COMP 22:00 - 22:20 0.33 WHSUR P COMP 22:20 - 22:40 0.33 WHSUR P COMP 22:40 - 23:00 0.33 WHSUR P COMP 23:00 - 23:30 0.50 WHSUR P COMP 23:30 - 23:45 0.25 RIGD P POST 23:45 - 00:00 0.25 RIGD P POST 2/25/2004 00:00 - 01 :30 1.50 RIGD P POST 01 :30 - 04:15 2.75 RIGD P POST 04:15-06:00 1.75 RIGD P POST Page 10 of 10 2/9/2004 2/25/2004 N1 Spud Date: 11/1/1993 End: 2/25/2004 Description of Operations --.- --.- ... .....-.- ..... -·--·0__.". Perforated depths with SWS 2" 2006 PJ, 6 SPF: 16,940' - 17,190' 17,210' - 17,320' POOH. PU=68K. PU weight fluctuating +/- 4K Ibs while POOH. OOH. SIB injector. PJSM for LID 1-1/4"CSH. Check trip data- seems like we gained 14bbls while POOH. Flowcheck well- well trickling. Gained 14bbls. WHPIIAP/OAP @ -35/560/155. Shut-in well & WHPIIAP/OAP stabilize after 1 hr @ 40/549/150psi. Bleed off IA to 300psi - got back little gas & crude & WHP increased to 44psi. Review situation with ANC team & agree to SI the TRSSV. Call DSO. W.O DSO & meanwhile WHP increase to 125psi. DSO having truck problems. DSO shut-in TRSSSV. Open up well & getting little gas bubbles but no continuous flow. Shut-in well & line up to pump via the BHA. WHP increase to 45psi in 15mins. Pump 30bbls of fresh 3% KCL down the BHA @ 1.5bpm/275psi & circ out gas bubbles. Shut-in well & observe no pressure build up. Open-up well - no flow. Observe well - stable. Shut-in well & had Opsi WHP. PJSM. LID 2 jts of 1-1/4" CSH & got back a gas bubble (real valve drill). SI well & had Opsi WHP. Observe well for flow - none. Continue LID 1-1/4" CSH. Hold PJSM for LID perf guns. LD and off load guns. PU nozzle, stinger, disconnect, check valves. MU to CTC. Stab injector. PT master valve to 3,500 psi. RU pad operator to open TRSSSV. Pressure up control line to 2,300 psi. Pressure up well to 400 psi and SSSV opened. Pressure control line to 3,300 psi. Well head pressure 200 psi. Bleed off pressure, well flowing. Close choke. Line up to pump diesel. Start pumping diesel. Taking returns through choke to the tiger tank. RIH to 7,500'. Pump 2 bbls out nozzle. POOH laying in diesel 1 for 1. Follow choke schedule while laying in diesel. Flush stack. Unstab injector. LD BHA. Hold safety meeting prior to installing back pressure valve. Set back pressure valve. Stab on tree with injector. Hold safety meeting prior to purging coil with N2. Blow coil down with N2. Unstab coil, secure to reel. Rig down goose neck. Put injector in stabbing box for transportation to next well. Nipple down BOP stack, and secure for rig move. NU tree cap. PT to 3500 psi with 50/50 water methanol. Rig release at 02:30. Printed: 3/1/2004 9:53:55 AM . . &03~[J55 12-Mar-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well NK-12 C Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 16,212.01' MD 16,235.00' MD 17,515.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Sign~0\ ~ ,~~~...Q cI-. ~ ~~ Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager RECEIVED Attachment(s) I·;' 1 R ¡n¡'../ , t~, l.._W U ....} (!Ü!l~, Comm¡~ioi1 RBDMS RD MAR 30 20M Halliburton Sperry-Sun North Slope Alaska BPXA NIAKUK NK-12C Job No. AKMW2916015, Surveyed: 21 February, 2004 Survey Report 11 March, 2004 Your Ref: API 500292341403 Surface Coordinates: 5979862.62 N, 721567.13 E (70020' 50.1552" N, 148012' 04.2788" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 979862.62 N, 221567.13 E (Grid) Surface Coordinates relative to Structure: 5632.43 S, 5424.70 E (True) Kelly Bushing Elevation: 51.88ft above Mean Sea Level Kelly Bushing Elevation: 51.88ft above Project V Reference Kelly Bushing Elevation: 51.88ft above Structure SpEI"""'I"""'Y-SUI! DRILLING· seRViCeS A Halliburton Company DEFINITIVE e e Survey Ref: svy4167 .. Halliburton Sperry-Sun Survey Report for NIAKUK - NK-12C Your Ref: API 500292341403 Job No. AKMW2916015, Surveyed: 21 February, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (a/100ft) 16212.01 61.130 321.100 9143.25 9195.13 10079.71 N 5987.42 W 5989760.92 N 715284.34 E 5987.42 Tie On Point 16235.00 61.320 321.150 9154.32 9206.20 10095.40 N 6000.07 W 5989776.23 N 715271.23 E 0.848 6000.D7 Window Point 16265.36 64.860 316.010 9168.06 9219.94 10115.68N 6017.98 W 5989795.97 N 715252.73 E 19.071 6017.98 16299.17 68.030 310.570 9181.58 9233.46 10136.90 N 6040.54 W 5989816.52 N 715229.55 E 17.474 6040.54 16330.33 71.810 305.780 9192.28 9244.16 10154.97 N 6063.54 W 5989833.89 N 715206.02 E 18.854 6063.54 e 16360.72 73.800 301.300 9201.27 9253.15 10171.00 N 6087.74 W 5989849.20 N 715181.37 E 15.530 6087.74 16391.62 76.550 294.610 9209.18 9261.06 10184.98 N 6114.11 W 5989862.40 N 715154.59 E 22.740 6114.11 16418.28 81.930 289.010 9214.16 9266.04 10194.70 N 6138.41 W 5989871.39 N 715130.02 E 28.857 6138.41 16448.55 89.210 294.140 9216.50 9268.38 10205.79 N 6166.44 W 5989881.65 N 715101.67 E 29.386 6166.44 16477.03 90.090 298.910 9216.67 9268.55 10218.50 N 6191.92W 5989893.60 N 715075.83 E 17.031 6191.92 16505.60 91.330 303.690 9216.32 9268.20 10233.34 N 6216.32 W 5989907.71 N 715051.00 E 17.283 6216.32 16535.27 96.330 298.780 9214.34 9266.22 10248.68 N 6241.61 W 5989922.30 N 715025.26 E 23.589 6241.61 16567.11 101.690 293.460 9209.35 9261.23 10262.53 N 6269.82 W 5989935.31 N 714996.65 E 23.569 6269.82 16599.54 102.530 287.920 9202.54 9254.42 10273.73 N 6299.47 W 5989945.63 N 714966.69 E 16.902 6299.47 16637.57 102.640 280.110 9194.24 9246.12 10282.71 N 6335.45 W 5989953.54 N 714930.45 E 20.044 6335.45 16663.73 105.290 276.930 9187.93 9239.81 10286.48 N 6360.55 W 5989956.56 N 714905.25 E 15.548 6360.55 16693.25 106.260 281.160 9179.90 9231.78 10290.94 N 6388.60 W 5989960.19 N 714877.09 E 14.175 6388.60 16722.42 102.380 285.740 9172.68 9224.56 10297.52 N 6416.08 W 5989965.96 N 714849.43 E 20.205 6416.08 16764.16 101.150 278.870 9164.16 9216.04 10306.22 N 6455.97 W 5989973.47 N 714809.29 E 16.380 6455.97 16795.71 102.110 270.410 9157.79 9209.67 10308.72 N 6486.74 W 5989975.06 N 714778.46 E 26.438 6486.74 16828.81 102.560 265.300 9150.72 9202.60 10307.51 N 6519.05 W 5989972.90 N 714746.21 E 15.143 6519.05 16865.54 98.680 260.370 9143.94 9195.82 10303.00 N 6554.84 W 5989967.33 N 714710.56 E 16.898 6554.84 e 16899.25 96.120 257.900 9139.60 9191.48 10296.70 N 6587.67 W 5989960.06 N 714677.94 E 10.510 6587.67 16939.52 97.710 266.010 9134.75 9186.63 10291.10 N 6627.22 W 5989953.30 N 714638.57 E 20.378 6627.22 16980.01 97.180 276.400 9129.49 9181.37 10291.95 N 6667.30 W 5989952.96 N 714598.48 E 25.477 6667.30 17021.86 94.010 286.630 9125.39 9177.27 10300.26 N 6708.05 W 5989960.07 N 714557.50 E 25.477 6708.05 17042.79 89.870 284.330 9124.69 9176.57 10305.84 N 6728.20 W 5989965.05 N 714537.19 E 22.624 6728.20 17079.14 89.430 274.640 9124.91 9176.79 10311.82 N 6764.01 W 5989969.97 N 714501.22 E 26.684 6764.01 17104.12 92.860 271.470 9124.41 9176.29 10313.15 N 6788.95 W 5989970.56 N 714476.26 E 18.694 6788.95 17131.65 95.590 268.650 9122.38 9174.26 10313.18 N 6816.40 W 5989969.78 N 714448.82 E 14.236 6816.40 17160.60 93.830 263.540 9120.00 9171.88 10311.22 N 6845.17 W 5989966.97 N 714420.12 E 18.612 6845.17 17202.40 91.980 256.670 9117.88 9169.76 10304.05 N 6886.27 W 5989958.58 N 714379.25 E 17.000 6886.27 17233.17 89.870 251.910 9117.38 9169.26 10295.72 N 6915.87 W 5989949.38 N 714349.90 E 16.919 6915.87 17257.24 86.430 248.390 9118.16 9170.04 10287.55 N 6938.50 W 5989940.55 N 714327.53 E 20.441 6938.50 17293.79 80.880 243.100 9122.20 9174.08 10272.65 N 6971.59 W 5989924.68 N 714294.89 E 20.912 6971.59 11 March, 2004 - 13:06 Page 2 of 4 DrillQuest 3.03.06.002 North Slope Alaska Measured True Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 17323.12 76.040 240.810 9128.07 9179.95 17348.96 71.450 237.290 9135.30 9187.18 17394.30 66.080 229.710 9151.74 9203.62 17444.34 63.960 220.900 9172.90 9224.78 17476.96 62.380 211.910 9187.65 9239.53 17498.17 62.290 209.270 9197.50 9249.38 17515.00 62.290 209.270 9205.33 9257.21 J' Halliburton Sperry-Sun Survey Report for NIAKUK - NK-12C Your Ref: API 500292341403 Job No. AKMW2916015, Surveyed: 21 February, 2004 BPXA Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (0/100ft) 10259.15 N 6996.95 W 5989910.43 N 714269.95 E 18.188 6996.95 10246.40 N 7018.22 W 5989897.06 N 714249.06 E 22.055 7018.22 10221.34 N 7052.18 W 5989871.01 N 714215.86 E 19.565 7052.18 10189.50 N 7084.40 W 5989838.23 N 714184.59 E 16.508 7084.40 10166.12 N 7101.66 W 5989814.35 N 714168.03 E 25.059 7101.66 e 10149.95 N 7111.22 W 5989797.90 N 714158.95 E 11 .032 7111.22 10136.95 N 7118.50 W 5989784.70 N 714152.06 E 0.000 7118.50 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 270.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 17515.00ft., The Bottom Hole Displacement is 12386.72ft., in the Direction of 324.922° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~) ~) 16212.01 16235.00 17515.00 9195.13 9206.20 9257.21 10079.71 N 10095.40 N 10136.95 N 5987.42 W 6000.07 W 7118.50 W Comment e Tie On Point Window Point Projected Survey 11 March, 2004 - 13:06 Page 3 of 4 DrillQuest 3.03.06.002 North Slope Alaska Survey tool prof/ram for NK-12C From Measured Vertical Depth Depth (ft) (ft) 0.00 4800.00 10991.88 0.00 4170.56 7390.54 To Measured Vertical Depth Depth (ft) (ft) 4800.00 10991.88 17515.00 4170.56 7390.54 9257.21 " Halliburton Sperry-Sun Survey Report for NIAKUK - NK-12C Your Ref: API 500292341403 Job No. AKMW2916015, Surveyed: 21 February, 2004 BPXA Survey Tool Description Tolerable Gyro (NK-12) Tolerable Gyro (NK-12A) MWD Magnetic (NK-12B) e e 11 March, 2004 - 13:06 Dri//Quest 3.03.06.002 Page 4 of 4 TREE = 4-1/16" 5M CW WELU-EAD= 13-5/8" 5MFfv1C ACTUATOR = BAKERC KB. ELBI = 51.88' BF. ELBI - KOP= Max An le- Datum MD = Datum 1V D - 1300' 13722' 16332 9200' SS 110-3/4" CSG, 45.5#, NT-80S BTC, ID = 9.950" I Minimum ID = 2.377" @ 17,368' 2 7/8" pin ID Note: SIZ E 2 -7/8" 2 -718" 2 -7/8" 2 -7/8" 2 -1/2" PERFORA TION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 60 @ 16135' Refer to Production DB for historical erf data SPF INTERV AL 0 n/S z DATE 616135-16155 0 10/15/01 6 16150-16175 0 06/04/01 6 16167-16187 0 10/15/01 6 16175-16195 0 05/12/01 6 16330-16390 0 03/15/01 4-1/2" TBG, 12.6#, L-80 IBT-M, ID - 3.958" 10855' 7-518" CSG, 29.7#, NT-95-HS, -i 11092' NSCC, I) = 6.875" 141/2" whipstock with RA tag H 16243' ~ 16259' ~ 16453' I 4-1/2"LNR, 12.6#, L-80HYD521, 1)=3.958" H 16550' I NK-12C SAFETY NOTES: CIBP MILLED & PUSHED TO TD@ 16420'CTM 02/28/02. FROM: CTD DRLG - DRAFT 2023' -14-1/2" HES CP-2 TRSSSV NIP, ID = 3.813" I . ST MD 3 3239 2 7098 1 10711 GAS LIFT MANDR8.S DBI TYPE VLV LATa-i 40 CAMCO CN NT 59 CAMCO CN NT 59 CAMCO CN NT DATE TVD 3037 5471 7249 !'DRf 10778' 10799' 4-1/2" HES X NIP, ID = 3.813" -17 -518" X 4-1/2" BAKER &3 A<R, ID = 3.850" 10822' 4-1/2" HES XN NIP, ID MILLED TO = 3.8" BAKER 7" X 5" Hfv1C LNR HGR, I) = 4.938" 7-5/8" MILL OUT WINDOW 11092' - 11104' TOl & top of emt X nipple 102.813" H lW..3..Slb33'16'x27/g' crcæ::we- ~ 17480' 33/16" 6.2# TCIID=2.800" x 2 7ifJ' 6.5# ST-lID=2.441 L-80 cntd & perfd DATE REV BY COMVIENTS ORIGINAL COrvPLEIlON 01/16/94 RIG SIDEfRA CK 03/19/01 CHiKAK RIG SIDEfRA CK 05/1 /01 AT[)Itlh ADD PERF 06/26/01 JLGltlh SET CIBP 07/13/01 JP/KA K ÆRFS & FISH COMVIENTS EUI/Ð ON XN NlPA...E ADD PERFS MILL OBP@16220' FRUDHOE BA Y UNIT W8.L: NK-12C PERMIT No: 203-055 API No: 50-029-23414-03 SEC 36, T12N, R15E, 1327' FSL & 996' ÆL BP Exploration (Alaska) . WELL LOG TRANSMITTAL e 4/1 0::2 "C'; [::": C' o u j~ ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7'" Street Suite # 700 Anchorage, Alaska 99501 RE : Distribution - Final Print( s) 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 : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TyPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR CoLOR Open Hole 1 Res. Eva!. CH 1 1 1 NK 1 2C 2-28-04 Mech. CH Signed: ". '? ''''''"2:> '. ""'.... 'C". ..~ \~C\3 (. ;,(....." "\ "") ,( C\. '~..c:- /Y'..... RECEIVED Date: t"~ :~' ? ':: ~OjÎ4. . ,; ',: '¡. L- ....... ..... 'J Print Name: f\¡ì]~k~ (}1! & Gas Cons. CommÏ$iO!1 h..f'd·~M.·. Mo .f'~~f~dh\n~~~ PRoACTiVE DiAGNOSTic SERvicES, INC., PO Box 1 }b9 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com .:?,'~:"~ - R ~~.S")\\\~ ·It ~lf~lfŒ lID~ ~~~~[K\~ . AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe NK.-12C BP Exploration (Alaska), Inc. Permit No: 203-055 Surface Location: 3952' SNL, 995' WEL,Sec. 36, T12N, RI5E, UM Bottomhole Location: 1020' NSL, 2206' WEL, Sec. 23, TI2N, RI5E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum. field inspector at 659-3607 (pager). Si11.cerely, ~~~~ ~~d; R~drich Commissioner BY ORDER OF THE COMMISSION DATED this D'f day of April, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section AlC,A- 'II ~ ¡toe') '5 STATE OF ALASKA ALASKAe AND GAS CONSERVATION COM.ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test III Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool RKB ::; 51.88' Niakuk Oil Pool / 6. Property Designation ADL 034625 7. Unit or Property Name Niakuk P (,t. 8. Well Number / NK-12C 9. Approximate spud date/, 04120/03 /' Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and rvD) 2560 çoo..~25!-MD /-9+6e' rvDss o 17. Anticipated pressure {S~20 AAC 25.035 (e) (2)} 'll# 104 Maximum surface 2806 psig, At total depth (TVD) 9200' I 3910 psig Setting Depth To Bottom 1. Type Bond (See 20 AAC 25.025) 1 a. Type of work 0 Drill III Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 721567. Y = 5979863 3952' SNL, 995' WEL, SEC. 36, T12N, R15E, UM At top of productive interval x = 715324, Y = 5989714 797' NSL, 1663' WEL, SEC. 23, T12N, R15E, UM At total depth x = 714775. Y = 5989922 1020' NSL, 2206' WEL, SEC. 23, T12N, R15E, UM Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well ADL 034630, 1020' MD No Close Approach ,/ 16. To be completed for deviated wells Kick Off Depth 16310' MD Maximum Hole An Ie 18. Casing Program Size ~ of Cement 19. To be completed for Red rill , Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 16550 feet Plugs (measured) true vertical 9351 feet Effective depth: measured 16453 feet Junk (measured) 36' of 47' Tool, Gun wI top and bottom rollers (06/01) true vertical 9307 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 80' 20" 4724' 10-3/4" 11054' 7-5/8" 5701' 4-1/2" Cemented MD rvD 280 cu ft Arctic Set (Approx.) 80' 80' 435 cu ft Class 'G' 4764' 4144' 806 cu ft Class 'G' 11092' 7440' 919 cu ft LiteCrete, 272 cu ft 'G' 10849' - 16550' 7317'- 9351' Perforation depth: measured 16135' - 16155', 16150' - 16175', 16167' - 16187', 16175' - 16195', 16330' - 16390' true vertical 9157' - 9167', 9165' - 9177', 9173' - 9183', 9177' - 9187', 9251' - 9279' 20. Attachments III Filing Fee 0 Property Plat III BOP Sketch 0 Diverter Sketch III Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 181 20 AAC 25.050 Requirements Prepared By Name/Number: Terrie Hubb/e, 564-4628 Permit Number ..:zo -ð Conditions of Approval: AP Number 50- 029-22414-03 Samples Required 0 Yes ~ No Hydrogen Sulfide Measures ~ Yes 0 No Required Working Pressure for BOPE Other: Teçt- BaPE fc, ;S'Oc> r¿~ ~~ Date Rev. 12-01-85 / 04K 05K 010K e e BP /~ NK-12c CTD Sidetrack Summary of Operations: Phase 1: Prep work 1. Integrity testing Phase 2: Set whipstock, Mill window, Drill and Complete sidetrack: Drilling coil will be used to set the CIBP, whipstock and mill the window at 16,310' MD (9189'ss) then drill and complete the directional hole as per attached plan. Mud Program: · Phase 1: Seawater / · Phase 2: Mill with seawater/biozan, drill with Flo-Pro (8.6 - 8.7 ppg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / 1'1-5()O' q 2.J.I.t.f. I y.JÚ k The production liner will be 3 3/16:~. x 7/8" ST-L from TO to approx. ~MD (39Te'ss). The liner will be cemented with a minimum V'" to bring cement up to top of liner. Well Control: · BOP diagram is attached. / · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 104 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD Gamma Ray and resistivity will be run in the open hole section. Memory CNL will be run inside the liner. Hazards /' · The maximum recorded H2S at Niakuk is 50 ppm on well NK-14. · The well path comes close to Kingak shale in two places, first at landing and last at TO. · The well path comes close to the HRZ shale at the crest. · NK-12B BHSIP is 4ppg while NK-9 (in the direction we are drilling) BHSIP is 8.2ppg, lost circulation to the high perm, depleted sand in the NK-12B is likely. · One faults will be passed and or crossed, lost circulation at the fault is not considered a risk. Reservoir Pressure Res. press. is estimated to be 3910 psi at 9200'ss (8.2ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2806 psi. TREE = 4-1/16" 5MCW / - WELLI-EA D = 13-5/8" 5M FMC NK-128 SAFETY NOTES: CIBP MILLB> & PUSHED TO AClUATOR- BAKERC TD@ 16420'CTM 02/28/02. KB. ELEV = 51.88' BF. ELEV - KOP= 1300' 4-1/2" HES CP-2 TRSSSV NIP, ID = 3.813" I Max Anole = 79 (â) 13722' I 2023' Datum tvO = 15543' . DatumTVD- 8800' SS 10-3/4" CSG, 45.5#, NT-80S BTC, ID = 9.950" 4764' ~ ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FQRT DATE 3 3239 3037 40 CAMCO Dfv1Y NT 0 08/23/02 2 7098 5471 59 CAMCO Dfv1Y NT 0 08/23/02 lJ 1 10711 7249 59 CAMCO Dfv1Y NT 0 08/23/02 Minimum ID = 3.725" @ 10843' 4-112" HES XN NIPPLE . I ~ 10778' 4-1/2" HES X NIP, ID = 3.813" g 2S 1 0799' 1-i7-5I8" x 4-1/2" BAKffi S-3 A<R ID - 3.850" I I 1 10822' 4-1/2" HES X NIP.ID = 3.813" I 1 0842' 4-1/2" HES XN NIP, ID = 3.725" ~ 10855' 4-1/2" WLEG I 14-1/2"TBG, 12.6#, L-80 IBT-M, ID= 3.958" 10855' I IiQ £1 10854' HEltvO TT LOGGED 06104101 I PERFORA ìlON SlJ'v1f1N1.RY ~ 1 0849' 1-i7-5I8" x 4-112" BAKffi ZXPPKR ID = 4.938" I REF LOG: TCP PERF ANGLEATTOPPffiF: 60@ 16135' 10869' BAKER 7" X 5" HMC LNR HGR, D = 4.938" I Note: Refer to Ffoduction œ for historical perf data SIZE SFT INTffiVAL Opn/Sqz DATE I I 2-7/8" 6 16135- 16155 0 10/15/01 7-518" IVILLOUT WINDOW 2-7/8" 6 16150- 16175 0 06/04/01 11092' - 11104' 2-7/8" 6 16167-16187 0 10/15/01 2-7/8" 6 16175-16195 0 05/12/01 TOPOFBAKffi WHIPSTOCK I 2-1/2" 6 16330 - 16390 0 03/15/01 ,..-- ~ 11092' I E'ZSV BRIDGE R...UG 11106' I 16417' I- RSH- 36' OF 47' TOOL, GUN W /TOP & BOTTOM ROLLERS (06/16/01) '" ~ 16453' I ""- 113590' TOP OF P&A CErvENT I 1~-5I8"CSG, 29.7#, NT-95-HS, 15024' I NSCC, ID = 6.875" 14-1/2" LNR, 12.6#, L-80 HYD 521, ID = 3.958" 16550' 1 DATE REV BY OOIVl'v1ENTS DATE REV BY COIVl'v1ENTS FRUDHOE BA Y UNIT ORIGINAL OOIVl"LEfION 08/04/0 1 1N/TP EltvO ON XN NlPR...E W8...L: NK-12B 03/19/01 CHiKAK RIG SIDEfRA CK 10/15/01 CAO/ijh AOOPffiFS PERMIT No: 2010150 05/08/01 per LPDA TED 03/11/02 DAV/ijh MILL aBP A PI No: 50-029-23414-02 05/12/01 A Tcvtlh ADD PERFS 08/31/02 DlR/1P GLV 00 SEC 36, T12N, R15E, 1327' FSL & 996' FEl 06/26/01 JLGltlh SET CIBP 11 (28/02 1N/TP NIFPLE ID OORRB::TION 07/13/01 JP/KAK ÆRFS & FISH BP Exploration (Alaska) - TREE = 4-1/16" 5M erN WELLHEAD = 13-5/8" 5M FMC ,~W,"",',",="^',',~="W.'.w~",·,wwnn=~~~~="w' ACTUATOR = BAKERC KB. ELEV = 51.88' ,y·_,··_·_,·_,__·_WNn_·W.wN,"".,·_,w~.'" ,'WW==W.W'====_W'W "W.'.W BF. ELEV = """~,,.'.'.',,_.~,w~n.w.~w~'."m"~"'m KOP = 1300' _,_,_,___W__'___W'~'W.WN."WWYNN,',',,,w,,,,=^',,,w=m=·=m,'.',',W"""'" Max Angle = 79 @ 13722' _,__,___"w.w···,·····.··mm-m.·..·~·,w.~m.w.·,·,·,·.·.·.,~m.''''w,w,w,·,·.·,·,·,·,·.·..''mm Datum MD = 15543' _,_·,_'_'·'·m_".w'__w'W'~'_N.','.W,'=='N,w,'.w~'mNN'·' Datum TVD = 8800' SS N~-12c PROPOSED 110-3/4" CSG, 45.5#, NT-80S BTC, ID = 9.950" Minimum ID :.: 2,377" @ 16,650' 2 7/8" ST -L pin ID or 2.35" @ liMr top packer seal assy PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 60 @ 16135' Note: Refer to Production DB for historical erf data SIZE SPF INTERVAL 0 nlS z DATE 2-7/8' 6 16135 - 16155 0 10/15/01 2-7/8' 6 16150 - 16175 0 06/04/01 2-7/8' 6 16167 - 16187 0 10/15/01 2-7/8' 6 16175 - 16195 0 05/12/01 2-1/2' 6 16330 - 16390 0 03/15/01 14-1/2" TBG, 12.6#, L-80 IBT-M, ID = 3.958" 10855' 7-5/8" CSG, 29.7#, NT-95-HS, -1 11092' I NSCC, ID = 6.875" 14 112" whipstock with RA tag 1-1 16310' I CIBP H 16320' I PBTD H 16453' 4-1/2"LNR,12.6#,L-80HYD521,ID=3.958" H 16550' AErv NOTES: CIBP MILLED & PUSHED TO W@ 16420' CTM 02/28/02. 2023' -14-1/2" HES CP-2 TRSSSV NIP, ID = 3.813" I . ST MD 3 3239 2 7098 1 10711 GAS LIFT MANDRELS DEV 1YÆ VLV LATCH 40 CAMCO DMY INT 59 CAMCO DMY INT 59 CAMCO DMY INT DATE 08/23/02 08/23/02 08/23/02 TVD 3037 5471 7249 PORT o o o 10778' -i4-1/2" HES X NIP, ID = 3.813" I 10799' -i 7-5/8" X 4-1/2" BAKER S-3 PKR, ID = 3.850" -14-1/2" HES X NIP, ID = 3.813" I -14-1/2" HES XN NIP, ID MILLED TO = 3.8" -14-1/2" WLEG H ELMD TT LOGGED 06/04/01 -17-5/8" X 4-1/2" BAKERZXPPKR, ID = 4.938" -1 BAKER 7" X 5" HMC LNR HGR, 10 = 4.938" 7-518" MILLOUT WINDOW 11092' - 11104' TOL (-8970ss) & top of liner cmt /' X nipple ID 2.813" 16725' I 3 3/16" , 2 718" "0,""" ~..... J I PBTD I~ ~,,~ :'::.-.~~,,:""::: :::-;:. "':':'. ':':~':::::::"""" ....,~',::~~::::::.:.~:. ....'. ..;:."::~::"...... ........¡;;;"'..".,.::~~:::~:"...,,, . .. ~,~ .""'-" "'-:::- ......"':::::::~~::.::::~:;::~::::.:.;::.7:;~..."...· ....~: ~'. ./" 33/16" 6.2# TCIIID=2.800" x 2 718" 6.5# ST-L 10=2.441 L-80 cmtd & perfd DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNIT ORIGINAL COMPLETION 08/04/01 TNITP ELMD ON XN NIPPLE WELL: NK-12c 03/19/01 CHlKAK RIG SIDETRACK 10/15/01 CA O/tlh ADD ÆRFS PERMIT No: 05/08/01 per UPOA TED 03/11/02 DA V /tlh MILL CIBP API No: 50-029-23414-03 05/12/01 A TD/tlh ADD ÆRFS 08/31/02 DTRlTP GL V C/O SEC 36, T12N, R15E, 1327' FSL & 996' FEL 06/26/01 JLG/tlh SET CIBP 11/28/02 TNITP NIPPLE 10 CORRECTION 07/13/01 JP/KAK ÆRFS & FISH 03/28/03 MSE PROPOSED CTD SIDETRACK BP Exploration (Alaska) BP Amoco WELLPATH DETAILS PI...#14 NK-12C 500212241403 P....nt Wollp.th; Tie.IIMD; RI,_ Ref. D.blm: V.s.ctlon AIISI. no.oo· NK-1Z. 18307.17 NK-1Z. 51"." O+';1~ ~~~ :::a~ uo REFERENCE INFORMATION CO-V~~~c~iA~'6~ ~:~:~~~~ ~~:e~n~:~~~:L~~~~ North Mea~::d'ò~T~ ~:~:~~~~ ~IK~1-2~·OON5~·.~~E) Calculation Method: Minimum Curvature SECTION DETAILS DLeg TF.ce T..,et 1 18307.17 81.82 321.28 81...82 10144.80 2 16310.00 61.95 321.211 11''''115 10146.85 3 18330.00 63.75 321.29 9199.011 10180.73 .. 18420.00 8..:14 312.311 11218.88 10223.71 5 18500.00 1t9.29 280.42 9213.711 10285.04 II 18700.00 104.03 HO.15 8172.47 10283.31 7 18780.00 1J8.15 253.20 81eo.82 102811.72 . 17010.00 115.25 290.118 8130.88 10278.58 II 17210.00 80.23 264.7(1 913&.67 10305.72 1017400.00 59.38 243.91 9204.55 10260.33 11 17500.00 74.38 243.111 1243.70 10220.00 -eo311U3 0.00 0.00 803S.83 -6041.39 1.08 360.00 6041.38 -8052.52 ..00 0.00 6052.52 "112.12 30.00 -20.00 8112.12 -enll.68 30.00 -85.00 8178.80 -8372.15 15.00 -78.00 8372.15 -8429.311 15.00 _130.00 &429.311 -8672.81 15.00 82.00 8072.81 -81188.80 15.00 _120.00 BBB8.58 _70311.711 15.00 ·140.00 70311.711 ·7121.14 15.00 0.00 7121.14 ANNOTATIONS TVD ND .1....2 16307.17 TIP .1..... 18310.00 KOP .1..... 18330.00 3 01.... 18420.00 4 '213.71 18'00.00 . .172A7 18700.00 8 '110..2 18780.00 7 ,130M 1'7010.00 . .1:M.87 17210.00 . 004.5S 17400.00 10 1243.70 17500.00 TD ~~:1~mr141 NK-12ÇT11.1 NK_12ÇT113 NK_12ÇT142 NK-12ÇT14.1 NK-12ÇT114 +EJ-W Shap& !illl il~!¡ Imi ~ .... C .- 8850'" Ì!, ~ 8900 ~ ... i ;¡ 8950l a. CD a9000: _ i ~ 9050J i9100 ... >"tr.l CD....·· ~ 9200 9300 9350 9400"'; T Plan: Plan #14 (NK-12/Plan#14 NK-12C) Created By: Brij Patnis Date: 3/2812003 LEGEND ~~=g ¡~~:g~~ Plan#14 NK-12C Plan #14 Azimuths to True North Magnetic North: 26.16' Magnetic Field Strength: 57567nT Dip Angie: 80.91' Date: 3/28/2003 Model: BGGM2002 Ccmtact jnforrnation DiH;!(;t {GO?) 2t17-66'!3 E-rnaif: br¡j.potni;:~@in!'eq<ccm Baker Hughes nFEQ- (007) 267~6ßOO 10600' 10550 10500 1 Ü,I~;~) 10400 '1 ::1 .." l ...11).~.)J C ¡¡¡ 10:,:¡:) () e!.10:¿~O '\io( ï ."oJo( ';.o:-¡ e '. .-:. '. ( " -- .:!:-.10;(~:;Ú .c i 101~O Z ~101;ì;) , :E' ... 1005 :I o en 10000 '- .' K:)=' -7250 -7200 -7150 -71 00 -7050 -7000 -6950 -6fJOO -61;50 -6800 -6750 -6700 -6650 -6600 -6(;50 -6500 -6450 -6400 -6350 -6iOO -6250 -6200 -6150 -61 00 -6050 -6000 -5950 West(· )/East( +) [50ft/in] e Trrrn', r"": i'. i' i i " 5850 5900 5950 6000 6050 6100 6150 6200 6250 6300 6350 6400 64'50 6500 6550 6600 6700 6950 7050 7100 7150 7200 7250 7300 7350 7400 7450 7500 7550 7600 7650 7700 7750 Vertical Section at 270.00· [50ft/in] e BP Baker Hughes INTEQ Planning Report INTEQ _ .____., _.,.'n ....'p_"~_.....'.'_....N____._ - Company: Field: Site: Well: Wellpath: BP Amoco Niakuk NK Main Pad NK-12 Plan#14 NK-12C ".-...---- __0' _.._..__ . ___ Field: Niakuk North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level e Map Zone: Coordinate System: Geomagnetic Model: ~---~~-- Date: 3/28/2003 Time: 10:28:33 Co'-ordinate(NE) Reference: Well: NK-12, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,O.00E,270.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle ! .- . .-'.--- - _ -··-·""'c-::c·'-c:c".cc·.-::..'·"·:"'''·:·:··'·:·.-:·-.-.-·-::-.c:-:-"-.ooc:=-=:_ =' +E/-W ft -7046.14 -7046.14 -6853.35 -6556.58 -6278.70 -6259.73 -6559.84 -6895.78 -7034.99 -7151.81 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 :\-tap Map :'oIorthing I':asting ft ft 5989674.07 714228.03 5989674.07 714228.03 5989737.08 714419.03 5989767.08 714715.03 5989733.07 714994.02 5990104.08 715002.03 5990130.08 714701.03 5990094.08 714366.02 5990051.07 714228.03 5989988.08 714113.03 9129.00 10301.86 -6746.80 5989960.07 714519.03 Height 51.88 ft +N/-S ft 0.00 +~/-S ft 10024.58 10024.58 10081.91 10103.15 10060.91 10431.53 10466.42 10440.34 10401.43 10341.86 NK-12C T11.3 9138.00 10253.35 -6561.14 5989917.07 714706.03 9143.00 10314.30 -6896.51 5989968.07 714369.03 9205.00 10257.52 -7040.25 5989907.07 714227.03 NK-12C T14.2 NK-12C T14.1 NK-12C T11.4 9218.00 10248.05 -7058.54 5989897.07 714209.03 9253.00 10226.57 -7110.20 5989874.07 714158.03 __O"_.w."". ....... ..... .__ ._.. .. ,._... ........_w....w......_._...__._._..w........._.._ _._____. Page: 1 Alaska, Zone 4 Well Centre BGGM2002 Site: NK Main Pad TR-12-15 UNITED STATES: North Slope Site Position: Northing: 5981257.79 ft Latitude: 70 21 5.879 N From: Map Easting: 714553.26 ft Longitude: 148 15 27.984 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.64 deg Well: NK-12 Slot Name: NK-12 Well Position: +N/-S -1595.51 ft Northing: 5979862.62 ft Latitude: 70 20 50.155 N +E/-W 6971.38 ft Easting : 721567.13 ft Longitude: 148 12 4.279 W Position Uncertainty: 0.00 ft Wellpath: Plan#14 NK-12C 500292241403 Current Datum: NK-12B Magnetic Data: 3/28/2003 Field Strength: 57567 nT Vertical Section: Depth From (TVD) ft 0.00 Targets --.---------...-.-..-....-..- ........-...--.------.. Name Description Dip. Dir. ..................--.--.....----..-.--- NK-12C Polygon14.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 NK-12C T11.2 NK-12C T11.1 TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Annotation MD ft 16307.17 16310.00 16330.00 16420.00 TVD ft 9188.62 9189.95 9199.08 9219.88 TIP KOP 3 4 NK-12B 16307.17 ft Mean Sea Level 26.16 deg 80.91 deg Direction deg 270.00 <-- Latitude ---> <--- Longitude ---> Deg Min Sec Deg Min See ____._._.w___._.._.... ....._..._....... __..__....w..._.... ........_..._.. 70 22 28.713 N 70 22 28.713 N 70 22 29.279 N 70 22 29.490 N 70 22 29.077 N 70 22 32.722 N 70 22 33.063 N 70 22 32.804 N 70 22 32.420 N 70 22 31.833 N 148 15 30.444 W 148 15 30.444 W 148 15 24.805 W 148 15 16.122 W 148 15 7.990 W 148 15 7.444 W 148 15 16.227 W 148 15 26.056 W 148 15 30.129 W 148 15 33.545 W 702231.443N 1481521.693W 70 22 30.968 N 148 15 16.259 W 70 22 31.564 N 148 15 26.074 W 70 22 31.004 N 148 1530.279 W 70 22 30.911 N 148 15 30.813 W 70 22 30.699 N 148 15 32.324 W BP Baker Hughes INTEQ Planning Report e e I Company:' . --- "--'- ....... .----. ...n -_... ...-........-. - BP Amoco Date: 3/28/2003 Time: 10:28:33 Page: 2 ,; I Field: Niakuk Co-ordinate(NE) Reference: Well: NK-12, True North i ! Site: NK Main Pad Vertical (TVD) Reference: System: Mean Sea Level I i Well: NK-12 Section (VS) Reference: Well (0.00N,0.00E,270.00Azi) I Wellpath: Plan#14 NK-12C Survey Calculation Method: Minimum Curvature Db: Oracle --.-"..----- __'_'_0-_' ..~_.~.__. .---"¥--.---- Annotation MD- TVD j ft ft . -.-.---.---.--- ----.----....-.. -~-_._....._..._._.__._- 16500.00 9213.79 5 16700.00 9172.47 6 16760.00 9160.92 7 17010.00 9130.66 8 17210.00 9138.67 9 17400.00 9204.55 10 17500.00 9243.70 TD Plan: Plan #14 Date Composed: 3/28/2003 New targets and profile Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information ¡--...--.......-.....-. H;/-W MD Incl Azim TVD +N/-S DLS Build Turn 1'FO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/10Oft deg ............--. .--.-..---...."" --..-.-....-. ...--..-..-"'--,----- 16307.17 61.92 321.29 9188.62 10144.90 -6039.83 0.00 0.00 0.00 0.00 16310.00 61.95 321.29 9189.95 10146.85 -6041.39 1.06 1.06 0.00 360.00 16330.00 63.75 321.29 9199.08 10160.73 -6052.52 9.00 9.00 0.00 0.00 16420.00 89.34 312.36 9219.88 10223.71 -6112.12 30.00 28.44 -9.93 -20.00 16500.00 99.29 290.42 9213.79 1 0265.04 -6179.66 30.00 12.43 -27.42 -65.00 16700.00 104.03 260.15 9172.47 1 0283.31 -6372.15 15.00 2.37 -15.14 -78.00 16760.00 98.15 253.20 9160.92 10269.72 -6429.38 15.00 -9.79 -11.59 -130.00 17010.00 95.25 290.86 9130.66 10278.58 -6672.91 15.00 -1.16 15.06 92.00 17210.00 80.23 264.79 9138.67 10305.72 -6868.60 15.00 -7.51 -13.03 -120.00 17400.00 59.38 243.91 9204.55 10260.33 -7038.78 15.00 -10.97 -10.99 -140.00 17500.00 74.38 243.91 9243.70 10220.00 -7121.14 15.00 15.00 0.00 0.00 Survey .. . .... .- -.-.....--..-...---......--...-...... -- .-.....--- MD Incl Azim SSTVD N/S E/W MapN MapE VS I>LS TFO Tool ft deg deg ft ft ft ft ft ft deg/10OO deg ----- .... ........-.. '_'_0" m_n__ m_.. 16307.17 61.92 321.29 9188.62 10144.90 -6039.83 5989824.09 715230.30 6039.83 0.00 0.00 TIP 16310.00 61.95 321.29 9189.95 10146.85 -6041.39 5989825.99 715228.68 6041.39 1.06 360.00 KOP 16325.00 63.30 321.29 9196.85 10157.24 -6049.72 5989836.13 715220.05 6049.72 9.00 360.00 MWD 16330.00 63.75 321.29 9199.08 10160.73 -6052.52 5989839.54 715217.15 6052.52 9.00 0.00 3 16344.45 67.83 319.69 9205.00 10170.90 -6060.91 5989849.45 715208.47 6060.91 30.00 340.00 NK-12C 16350.00 69.40 319.10 9207.02 10174.82 -6064.27 5989853.27 715204.99 6064.27 30.00 340.66 MWD 16375.00 76.51 316.58 9214.35 10192.52 -6080.31 5989870.49 715188.43 6080.31 30.00 340.87 MWD 16400.00 83.63 314.21 9218.66 10210.04 -6097.59 5989887.48 715170.64 6097.59 30.00 341.61 MWD 16420.00 89.34 312.36 9219.88 10223.71 -6112.12 5989900.72 715155.71 6112.12 30.00 342.02 4 16425.00 89.98 311.00 9219.91 10227.04 -6115.86 5989903.94 715151.88 6115.85 30.00 295.00 MWD 16450.00 93.14 304.19 9219.23 10242.28 -6135.64 5989918.58 715131.66 6135.64 30.00 295.01 MWD 16475.00 96.26 297.35 9217.18 10255.02 -6157.03 5989930.68 715109.90 6157.03 30.00 294.82 MWD 16500.00 99.29 290.42 9213.79 10265.04 -6179.66 5989940.04 715086.98 6179.66 30.00 294.26 5 16525.00 100.05 286.70 9209.59 10272.89 -6203.02 5989947.19 715063.40 6203.02 15.00 282.00 MWD 16550.00 100.77 282.96 9205.08 10279.18 -6226.79 5989952.77 715039.47 6226.78 15.00 281.37 MWD 16575.00 101.44 279.20 9200.26 10283.89 -6250.86 5989956.77 715015.27 6250.85 15.00 280.70 MWD 16600.00 102.06 275.42 9195.17 10287.01 -6275.13 5989959.17 714990.91 6275.13 15.00 279.97 MWD 16625.00 102.64 271.63 9189.82 10288.51 -6299.50 5989959.95 714966.51 6299.50 15.00 279.20 MWD 16650.00 103.16 267.82 9184.23 10288.39 -6323.86 5989959.11 714942.16 6323.86 15.00 278.39 MWD 16675.00 103.62 263.99 9178.44 10286.65 -6348.11 5989956.66 714917.97 6348.11 15.00 277.54 MWD 16700.00 104.03 260.15 9172.47 10283.31 -6372.15 5989952.60 714894.04 6372.15 15.00 276.66 6 16725.00 101.60 257.22 9166.92 10278.52 -6396.05 5989947.11 714870.30 6396.05 15.00 230.00 MWD 16750.00 99.14 254.34 9162.42 10272.48 -6419.88 5989940.37 714846.66 6419.88 15.00 229.35 MWD 16760.00 98.15 253.20 9160.92 10269.72 -6429.38 5989937.33 714837.25 6429.38 15.00 228.83 7 16775.00 98.07 255.47 9158.80 10265.71 -6443.67 5989932.89 714823.08 6443.67 15.00 92.00 MWD 16800.00 97.90 259.25 9155.33 10260.29 -6467.83 5989926.77 714799.10 6467.83 15.00 92.32 MWD 16825.00 97.70 263.03 9151.93 10256.48 -6492.30 5989922.23 714774.75 6492.30 15.00 92.85 MWD e BP e Baker Hughes INTEQ Planning Report I -...-"..- - \ Company: BP Amoco Date: 3/28/2003 Time: 10:28:33 Page: 3 ¡Field:,"'" Niakuk Co-ordinatc(NE) Reference: Well: NK-12, True North I Site: ' NK Main Pad Vertical (TVD) Reference: System: Mean Sea Level Well: NK-12 Section (VS) Reference: Well (O.OON ,O.OOE ,270.00Azi) Wellpath: Plan#14 NK-12C Survey Calculation Method: Minimum Curvature Dh: Oracle , .....--.-- Survey I~D--- Incl Azim SSTVD N/S EIW MapN MapE VS DLS TFO ~::~ deg deg ft ft ft ft ft ft deg/10OO deg __W'_"___ --"..--.--- 16850.00 97.46 266.81 9148.63 10254.28 -6516.98 5989919.31 714750.15 6516.98 15.00 93.36 MWD 16875.00 97.19 270.58 9145.45 10253.72 -6541.76 5989918.01 714725.39 6541.76 15.00 93.86 MWD 16900.00 96.89 274.34 9142.38 10254.78 -6566.54 5989918.35 714700.59 6566.54 15.00 94.34 MWD 16925.00 96.57 278.11 9139.45 10257.48 -6591.22 5989920.31 714675.85 6591.22 15.00 94.80 MWD 16950.00 96.21 281.86 9136.67 10261.78 -6615.68 5989923.89 714651.27 6615.68 15.00 95.24 MWD 16975.00 95.83 285.61 9134.04 10267.69 -6639.83 5989929.08 714626.96 6639.83 15.00 95.66 MWD 17000.00 95.42 289.36 9131.59 10275.16 -6663.56 5989935.85 714603.02 6663.56 15.00 96.05 MWD 17010.00 95.25 290.86 9130.66 10278.58 -6672.91 5989938.99 714593.58 6672.91 15.00 96.42 8 17025.00 94.12 288.90 9129.44 10283.67 -6686.96 5989943.66 714579.37 6686.96 15.00 240.00 MWD 17050.00 92.23 285.66 9128.05 10291.08 -6710.79 5989950.36 714555.34 6710.79 15.00 239.84 MWD 17075.00 90.34 282.42 9127.49 10297.14 -6735.04 5989955.70 714530.93 6735.04 15.00 239.66 MWD 17100.00 88.44 279.19 9127.76 10301.83 -6759.59 5989959.66 714506.25 6759.59 15.00 239.59 MWD 17125.00 86.54 275.95 9128.85 10305.12 -6784.34 5989962.22 714481.41 6784.34 15.00 239.62 MWD 17150.00 84.66 272.69 9130.77 10307.00 -6809.19 5989963.36 714456.51 6809.19 15.00 239.76 MWD 17175.00 82.80 269.42 9133.50 10307.46 -6834.04 5989963.09 714431.67 6834.03 15.00 240.01 MWD 17200.00 80.96 266.12 9137.03 10306.50 -6858.76 5989961.40 714406.99 6858.76 15.00 240.37 MWD 17210.00 80.23 264.79 9138.67 10305.72 -6868.60 5989960.32 714397.18 6868.59 15.00 240.84 9 17225.00 78.51 263.32 9141.44 10304.19 -6883.26 5989958.36 714382.57 6883.26 15.00 220.00 MWD 17250.00 75.66 260.82 9147.02 10300.83 -6907.39 5989954.29 714358.55 6907.39 15.00 220.27 MWD 17275.00 72.84 258.25 9153.81 10296.46 -6931.04 5989949.23 714335.03 6931.04 15.00 220.83 MWD 17300.00 70.05 255.61 9161.77 10291.11 -6954.13 5989943.19 714312.12 6954.13 15.00 221.53 MWD 17325.00 67.30 252.87 9170.86 10284.79 -6976.53 5989936.21 714289.91 6976.53 15.00 222.37 MWD 17350.00 64.60 250.02 9181.05 10277.53 -6998.17 5989928.32 714268.50 6998.17 15.00 223.37 MWD 17375.00 61.95 247.04 9192.30 10269.36 -7018.95 5989919.54 714247.97 7018.95 15.00 224.53 MWD 17400.00 59.38 243.91 9204.55 10260.33 -7038.78 5989909.93 714228.42 7038.78 15.00 225.87 10 17425.00 63.13 243.91 9216.57 10250.69 -7058.46 5989899.71 714209.03 7058.46 15.00 0.00 MWD 17450.00 66.88 243.91 9227.13 10240.73 -7078.81 5989889.15 714188.99 7078.81 15.00 0.00 MWD 17475 70.63 243.91 923 10230.48 -7099.73 5989878.29 714168.38 7099.73 15.00 360.00 MWD 74.38 243.91 10220.00 -7121.14 5989867.18 714147.29 7121.14 15.00 0.00 TO e All Measurements are from top of Riser ~ CD CJ) .- a: top of bag bttm of bag middle of slips Blind/Shears .......................... middle of pipes middle of flow cross middle of blindlshears .......................... middle of pipelslips ......................... Flow Tee ~rcL 3/28/2003 BAG 71/16" 5000psi TOTs / 7 1/16" 5000psi Mud Cross 71/16" 5000psi / TOTs 7 1/16" 5000psi P055033 DATE 3/12/2003 CHECK NO. 055033 DATE INVOICE I CREDIT MEM DESCRIPTION GROSS VENDOR DISCOUNT NET 3/12/2003 INV# CK030603F . PERMIT TO DRILL ~__\~G n.D R :_..(,..~. ") t"\ r\ . .-~ ~ UtJ,~: .1.l;;.~~ CO: 5. CC~¡:1T'~:J\Gn e THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, A~995:19-6612 No. P 055033 CONSOLIDATED COMMERCIAL ACCOUNT - PAY: AMOUNT TO THE ORDER OF: 1110 5 so :l j III I: 0 ~ ¡. 2 0 :l B q 5 I: 0 ¡. 2 ? B q b 110 . e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well_, Permit No, API No. . (H API number Production should continue to be reported as last two (2) digits a function· of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(t), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 07110/02 C\jody\templates WELL PERMIT CHECKLIST COMPANY BPX WELL NAME NK-12C PROGRAM Exploratory (EXP) Development (DEV) X Redrill X Service (SER) Well bore scg Annular disposal para req --- - - - -.- FIELD & POOL 640148 - Prudhoe Bay, Niakuk Initial ClasslType. DEV /1-0IL GEOLAREA 890 UNIT No. 011650 ON/OFF SHORE On - ADMINISTRATION 1. Permit fee attached .................. ...... ......... .................. ..................... ............... ............ Yes 2. Lease number appropriate .................. ...... ...... ..................... ............... ...... ............ ...... Yes 3. Unique well name and number ......................................................... ,_. ....................... Yes 4. Well located in a defined pool ..................................................................................... Yes 5. Well located proper distance from drilling unit boundary ... ............ ......... ...... ..................... Yes 6. Well located proper distance from other wells ... ............... ...... ............ ............ ...... ........... Yes APPR DATE 7. Sufficient acreage available in drilling unit .................................... ...... ...... ...................." Yes 8. If deviated, is well bore plat included ... ................................. ............ ............ .................. Yes RPC 4/3/2003 9. Operator only affected party.................. ........................... ..................... ...................... Yes 10. Operator has appropriate bond in force ...... ......... ............ ........................ ...... ............... Yes 11. Permit can be issued without conservation order......... ............ ..................... ............ ..... Yes 12. Permit can be issued without administrative approval... ........................... ...... ................. Yes 13. Can permit be approved before 15-day wait .................................... ...... ...... ...... ............ Yes (For Service Well Only) 14. Well located within area and strata authorized by Injection Order # NA Not Applicable (For Service Well Only) 15. All wells within 1/4 mile area of review identified ... ...... ...... ...... ............... ......... ...... ......... NA Not Applicable (For Service Well Only) 16. Pre-produced injector: duration of pre-production less than 3 months ................................ NA Not Applicable 17. ACMP Finding of Consistency has been issued for this project ...... ...... ...... ...... ......... ........ NA Not Applicable ENGINEERING 18. Conductor string provided ...... ...... ................................. .............................. .............. NA Not Applicable 19. Surface casing protects all known USDWs ................................................................... NA 20. CMT vol adequate to circulate on conductor & surf csg ......... ............ ...... ...... ......... ......... NA Not Applicable 21. CMT vol adequate to tie-in long string to surf csg ............ ............ ............ ...................... NA Not Applicable 22. CMT will cover all known productive horizons ........................ ....................................... Yes 23. Casing designs adequate for C, T, B & permafrost...... ............ ............... ...... ......... ......... Yes. 24. Adequate tankage or reserve pit ... ............ ...... .................................... ............... ......... Yes CTDU. 25. If a re-drill, has a 10-403 for abandonment been approved ............ .................................. Yes 4/1/2003. 26. Adequate wellbore separation proposed ...... ........................... ............ ......................... Yes 27. If diverter required, does it meet regulations ...... ............ ............ ................................... NA 28. Drilling fluid program schematic & equip list adequate .................. ...... ..................... ....... Yes Max MW 8.7 PPO. APPR DATE 29. BOPEs, do they meet regulation ....................................... ........................... ............... Yes WGA 4/3/2003 30. BOPE press rating appropriate; test to ...................... 3500 psig ......minimum.......... Yes MSP 2806 psi. \. I/_-,L.- 31. Choke manifold complies w/API RP-53 (May 84) ............ ............ .................................. Yes \N'--f if 32. Work will occur without operation shutdown .................. ..................... ............... ............ Yes 33. Is presence of H2S gas probable .................. ............... ............... ...... .......................... Yes (For Service Well Only) 34. Mechanical condition of wells within AOR verified ............ ...... ............... ...... ................... NA GEOLOGY 35. Permit can be issued w/o hydrogen sulfide measures ... ................................. ...... ........... ~ ¡Va LJ;.- 36. Data presented on potential overpressure zones ............ ............... ...... .......................... Yes APPR DATE 37. Seismic analysis of shallow gas zones ... ........................ ............... ......... ..................... NA Not Applicable 38. Seabed condition survey (if off-shore) ............ .................................... ......................... NA Not Applicable RPC 4/3/2003 39. Contact name/phone for weekly progress reports [exploratory only] ................................ NA Not Applicable GEOLOGY: ENGINEERING: RES. ENGINEERING: COMMISSION: Commentsllnstructions RPC: RPC WGA: X MJW: RR: -{;. l~ l ~ SFD: TEM: JDH: DTS: otJ O<r f Q5 SP: ')/) </ ~ ~ { - - e e 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 infomlation, 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. e e C:<()3-0S':5 ÐfÞ IZfø3 S Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Aug 23 13:31:06 2004 Reel Header Service name....... ......LISTPE Date.................... .04/08/23 Origin.................. .STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.. .......... .LISTPE Date.....................04/08/23 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Niakuk MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA NK-12C 500292241403 BP Exploration (Alaska) Inc Sperry-Sun Drilling Services 19-AUG-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW00029l60l5 S. LATZ WHITLOW/HILD MWD RUN 2 MW00029l60l5 S. LATZ KOLSTAD/EGBE MWD RUN 3 MW00029l60l5 S. LATZ KOLSTAD/EGBE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MAD RUN 3 MW00029l60l5 S. LATZ KOLSTAD/EGBE # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 36 l2N l5E 3952 995 51.88 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 16235.0 # REMARKS: RECEIVED SEP 0 :) 2004 Alaska Oil & Gas Cons. CommissiOn Anchor8ge e e 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE NK-12B WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 16235'MD AND THE BOTTOM WAS AT 16241'MD. 4. MWD RUNS 1 AND 2 WERE DIRECTIONAL, AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. RUN 1 SROP IS ACTUALLY SRAT FOR THE SGRD TIE-IN. THESE DATA ARE INCLUDED FOR QUALITY CONTROL PURPOSES. 5. MWD RUN 3 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4). MAD PASS DATA WERE ACQUIRED AFTER REACHING TD, OVER THE INTERVAL 17408'MD - 16955'MD (UNSHIFTED BIT DEPTHS). 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY RUN ON 23 FEBRUARY 2004. THESE LOG DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 18 AUGUST 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 3 REPRESENT WELL NK-12C WITH API#: 50-029-22414-03. THIS WELL REACHED A TOTAL DEPTH(TD)OF 17515'MD/9205'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SPACING) . SEMP = SMOOTHED PHASE SPACING) . SEDP = SMOOTHED PHASE SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL RUNNING SPEED WHEN NOT DRILLING. CURVE MNEMONICS WITH AN 'M' SUFFIX DENOTE MAD PASS DATA. SHIFT-DERIVED RESISTIVITY ( SHALLOTÑ SHIFT-DERIVED RESISTIVITY (MEDIUM SHIFT-DERIVED RESISTIVITY (DEEP $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/08/23 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY 1 clipped curves; all bit runs merged. .5000 PBU TOOL CODE GR ROP FET RPX RPS RPM RPD $ e START DEPTH 16013.0 16047.0 16236.0 16236.0 16236.0 16236.0 16236.0 e STOP DEPTH 17473.5 17518.5 17486.5 17486.5 17486.5 17486.5 17486.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 16013.0 16013.5 16032.5 16036.5 16046.0 16058.5 16064.0 16071. 0 16073.5 16091. 0 16102.5 16112.0 16125.0 16130.0 16140.5 16157.0 16174.5 16196.5 16322.5 16340.5 16355.0 16374.5 16405.5 16419.0 16427.0 16446.5 16458.5 16482.0 16497.5 16508.0 16513.5 16517.5 16552.5 16567.5 16643.0 16663.5 16674.5 16693.5 16712.5 16737.0 16878.5 16898.5 16942.0 16950.0 16953.0 16960.0 16962.5 16976.0 16993.0 17002.0 17009.5 17019.5 17033.0 17039.0 17054.0 17065.5 17109.0 17120.5 17129.0 17143.0 17170.0 GR 16013.0 16013.5 16030.0 16035.0 16044.0 16055.5 16062.5 16069.5 16073.5 16089.0 16101.5 16110.5 16124.5 16129.5 16138.5 16156.0 16174.5 16194.5 16324.5 16344.5 16358.5 16378.5 16406.5 16419.0 16425.5 16446.0 16457.0 16479.0 16492.0 16503.5 16513.0 16517.5 16556.5 16572.0 16649.0 16670.0 16681.5 16700.5 1671 7.0 16743.0 16883.5 16904.5 16947.5 16955.5 16957.5 16965.5 16966.5 16981. 5 16997.5 17006.0 17014.0 17024.0 17037.0 17043.0 17056.5 17068.5 17112.0 17125.5 17133.5 17146.5 17172.0 e e 17185.5 17192.0 17233.5 17241.5 17288.5 17294.0 17303.0 17312.5 17319.5 17332.0 17351. 0 17372.0 17384.5 17394.0 17417.0 17420.5 17430.0 17440.0 17467.0 17471.0 17518.5 $ 17187.5 17195.5 17237.0 17243.0 17290.0 17294.0 17304.0 17313.0 17322.0 17335.0 17353.0 17373.5 17384.5 17392.0 17412.0 17416.5 17425.5 17436.5 17464.0 17467.5 17515.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 16013.0 16251.5 16631.5 MERGE BASE 16251. 5 16631. 5 17515.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point........ ......Undefined Frame Spacing.................... .60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 16013 17518.5 16765.8 3012 16013 17518.5 ROP MWD FT/H 0.82 791. 62 91. 6729 2944 16047 17518.5 GR MWD API 21.39 356.16 91. 7395 2922 16013 17473.5 RPX MWD OHMM 0.6 1730 14.969 2492 16236 17486.5 RPS MWD OHMM 0.29 2000 18.156 2492 16236 17486.5 RPM MWD OHMM 3.93 1865.36 22.556 2492 16236 17486.5 RPD MWD OHMM 0.15 1705.07 22.9864 2492 16236 17486.5 FET MWD HOUR 0.35 103.7 9.00683 2492 16236 17486.5 First Reading For Entire File..........16013 Last Reading For Entire File...........17518.5 File Trailer Service name.............STSLIB.001 e e Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/08/23 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/08/23 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX RAT $ 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 16906.0 16916.0 16916.0 16916.0 16916.0 16916.0 16949.5 STOP DEPTH 17356.0 17375.0 17375.0 17375.0 17375.0 17375.0 17412.5 # MERGED DATA SOURCE PBU TOOL CODE MWD $ MAD RUN NO. MAD PASS NO. MERGE TOP 3 1 16235.5 MERGE BASE 17515.0 # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type........ . . . . . . . . . .0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units....... ... .Feet Data Reference Point..............Undefined Frame Spacing. ... .................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units.. . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 16906 17412.5 17159.3 1014 16906 17412.5 RAT MAD FT/H 394.72 746.95 557.273 927 16949.5 17412.5 GR MAD API 28.79 129.59 68.7939 901 16906 17356 e e RPX MAD OHMM 5.8 34. 73 17.2629 919 16916 17375 RPS MAD OHMM 6.14 41. 5 22.1013 919 16916 17375 RPM MAD OHMM 6.35 46.25 24.92 919 16916 17375 RPD MAD OHMM 7.15 44.61 25.8964 919 16916 17375 FET MAD HOUR 9.84 29.38 18.7406 919 16916 17375 First Reading For Entire Fi1e..........16906 Last Reading For Entire Fi1e...........17412.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation..... ..04/08/23 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......04/08/23 Maximum Physical Record..65535 File Type................ LO Previous File Name.. .... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 1 .5000 START DEPTH 16013.0 16045.0 STOP DEPTH 16235.0 16251. 5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 15-FEB-04 Insite 7.75 Memory 16350.0 16050.0 16350.0 .0 .0 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG013 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 11092.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: KCl/Biozan .00 .0 .0 e e MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: o .0 .000 .000 .000 .000 .0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type. ....0 Logging Direction........ ...... ...Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units............ . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 Name DEPT ROP GR MWDOI0 MWDOI0 Nsam 1 1 1 Rep 68 68 68 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 16013 16251.5 16132.3 478 16013 16251.5 ROP MWDOI0 FT/H 17 416 342.568 414 16045 16251.5 GR MWDOI0 API 43.07 356.16 130.987 445 16013 16235 First Reading For Entire File..........16013 Last Reading For Entire File...........16251.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/08/23 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... ..........STSLIB.004 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/08/23 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD 4 e e header data for each bit run in separate files. 2 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ START DEPTH 16235.5 16252.0 STOP DEPTH 16586.0 16631. 5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 19-FEB-04 Insite 7.75 Memory 16631.0 16350.0 16631. 0 61. 3 102.8 TOOL NUMBER TLG013 4.125 11092.0 Flo Pro 8.70 65.0 8.5 25000 5.2 .000 .000 .000 .000 .0 146.0 .0 .0 Offset o 4 8 Channel 1 2 3 e e First Last Name Service Ur1Ì t Min Max Mean Nsam Reading Reading DEPT FT 16235.5 16631.5 16433.5 793 16235.5 16631. 5 ROP MWD020 FT/H 0.82 644.72 32.2155 760 16252 16631.5 GR MWD020 API 21.39 135.12 77.8259 702 16235.5 16586 First Reading For Entire File..........16235.5 Last Reading For Entire File...........16631.5 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/0B/23 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/08/23 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPS FET RPM RPX RPD GR ROP $ 5 header data for each bit run in separate files. 3 .5000 START DEPTH 16235.5 16235.5 16235.5 16235.5 16235.5 16586.5 16632.0 STOP DEPTH 17483.0 17483.0 17483.0 17483.0 17483.0 17470.0 17515.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM Al'-!GI,E: 21-FEB-04 Insite 4.3 Memory 17515.0 16631.0 17515.0 62.3 106.3 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER 178425 178425 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 e e DRILLER'S CASING DEPTH (FT): 16420.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: F10 Pro 8.70 65.0 9.5 25000 5.2 .230 .107 .200 .220 69.0 156.0 60.0 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point....... ...... .Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 16235.5 17515 16875.3 2560 16235.5 17515 ROP MWD030 FT/H 0.94 791.62 59.3551 1767 16632 17515 GR MWD030 API 37.69 144.72 87.6268 1768 16586.5 17470 RPX MWD030 OHMM 0.6 1730 14.9471 2486 16235.5 17483 RPS MWD030 OHMM 0.29 2000 18.1274 2486 16235.5 17483 RPM MWD030 OHMM 3.93 1865.36 22.5544 2486 16235.5 17483 RPD MWD030 OHMM 0.15 1705.07 22.9987 2486 16235.5 17483 FET MWD030 HOUR 0.35 103.7 9.13139 2486 16235.5 17483 First Reading For Entire File..........16235.5 Last Reading For Entire File...........17515 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/08/23 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.006 e e Physical EOF File Header Service name.............STSLIB.006 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/08/23 Maximum Physical Record..65535 File Type............... .LO Previous File Name... ....STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET RAT $ 6 header data .5000 3 1 for each pass of each run in separate files. START DEPTH 16912.0 16922.0 16922.0 16922.0 16922.0 16922.0 16955.0 STOP DEPTH 17358.0 17376.0 17376.0 17376.0 17376.0 17376.0 17408.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LÔG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 21-FEB-04 Insite 4.3 Memory 17408.0 16955.0 17408.0 62.3 106.3 # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 TOOL NUMBER 78012 178425 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 16420.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo Pro 8.70 65.0 9.5 25000 5.2 .230 .107 .200 .220 69.0 156.0 60.0 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # e e TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD031 FT/H 4 1 68 4 2 GR MAD031 API 4 1 68 8 3 RPX MAD031 OHMM 4 1 68 12 4 RPS MAD031 OHMM 4 1 68 16 5 RPM MAD031 OHMM 4 1 68 20 6 RPD MAD031 OHMM 4 1 68 24 7 FET MAD031 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 16912 17408 17160 993 16912 17408 RAT MAD031 FT/H 394.72 746.95 557.271 907 16955 17408 GR MAD031 API 28.79 129.59 69.0784 893 16912 17358 RPX MAD031 OHMM 5.8 34.73 17.2995 909 16922 17376 RPS MAD031 OHMM 6.14 41. 5 22.1412 909 16922 17376 RPM MAD031 OHMM 6.35 46.25 24.9589 909 16922 17376 RPD MAD031 OHMM 7.15 44.61 25.8984 909 16922 17376 FET MAD031 HOUR 9.84 29.38 18.7182 909 16922 17376 First Reading For Entire File..........16912 Last Reading For Entire File...........17408 File Trailer Service name.............STSLIB.006 Servi.ce Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/08/23 Maximum Physical Record..65535 File Type............... .LO Next File Name........ ...STSLIB.007 Physical EOF Tape Trailer Service name.............LISTPE Date................... ..04/08/23 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................04/08/23 Origin...................STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN e e Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
