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206-035
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU NK-61A Mill CIBP, Extended Perforating Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 206-035 50-029-22893-01-00 15125 Conductor Surface Intermediate Production Liner 9172 73' 6156' 11768' 3544' 15087 20" 9-5/8" 7" 2-3/8" 9177 42 - 115 40 - 6196 38 - 11806 11581 - 15125 42 - 115 40 - 5102 38 - 9159 8951 - 9172 15062 520 4760 7020 11780 none 1530 6870 8160 11200 11810 - 14890 3-1/2" 9.3# L-80 36 - 11620 9162 - 9194 Structural 4-1/2" Baker S-3, 11574, 8945 TRSV HES Series 10, 2106, 2059 11574 8945 Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com 907.564.4061 PRUDHOE BAY , NIAKUK OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0034630 36 - 8987 56 27 0 0 657 856 2031 2063 558 573 323-199 13b. Pools active after work:NIAKUK OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 9:46 am, Jun 07, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.06.06 16:13:12 -08'00' DSR-6/12/23WCB 2-1-2024 RBDMS JSB 120723 ACTIVITYDATE SUMMARY 5/8/2023 LRS CTU #2 - 1.50" Blue Coil Job Objective: Mill CIBP, Ext. Adperf MIRU CTU. Make up 1-11/16" YJ Milling BHA w/ 1.80" junk mill and RIH ***Continued on 05/09/23*** 5/9/2023 LRS CTU #2 - 1.50" Blue Coil Job Objective: Mill CIBP, Ext. Adperf Dry tag CIBP at 13576'. Mill plug and push to TD at 15062'. POOH. Make up GR/CCL logging BHA and RIH. Log from 13700' to 11500', painting yellow tie-in flag at 13350'. POOH and load well with 9.0 ppg brine for kill. Confirm well kill in place, lay down logging BHA and make up Perf gun BHA #1 with 250' of 1.56" Geo Razor perf guns, 6 spf. Confirm +19.5' correction. RIH and tie-in to flag. Correct to top shot. Perforate 13,400 - 13,650' MD. POOH pumping 0.5 bpm 9.0 ppg brine pipe displacement + 0.3 bpm to maintain well kill. Undeploy guns. ***Continued on 5/10/23*** 5/10/2023 LRS CTU #2 - 1.50" Blue Coil Job Objective: Mill CIBP, Ext. Adperf Make up Perf gun BHA #2 with 89' of 1.56" Geo Razor perf guns, 6 spf. RIH pumping 0.3 bpm 9.0 ppg brine to maintain well kill. Tie-in to flag. Correct to top shot. Perforate 11,963 - 12,052' MD. POOH pumping 0.5 bpm 9.0 ppg brine pipe displacement + 0.3 bpm to maintain well kill. Undeploy guns. RDMO ***Job Complete*** Daily Report of Well Operations PBU NK-61A j Mill plug and push to TD at 15062'. POOH g Perforateg 11,963 - 12,052' MD g Perforate 13,400 - 13,650' MD. The CIBP fish and adperfs are correctly shown on the new WBS, below. -WCB 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size:Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER Extended Perforating Conductor Surface Intermediate Production Liner 520 4760 7020 11780 Structural Date: Current Pools:Proposed Pools: Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov SFD 4/8/2023 10-404 MGR30APR23 DSR-4/4/23GCW 05/01/23 JLC 5/1/2023 05/01/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.01 14:47:08 -08'00' RBDMS JSB 050223 Well: NK-61A PTD: 206-035 API: 50-029-22893-01-00 Well Name:NK-61A API Number:50-029-22893-01-00 Current Status:Online, Operable Rig:Coil Estimated Start Date:April 2023 Estimated Duration:3 days Regulatory Contact:Carrie Janowski First Call Engineer:Eric Dickerman 307-250-4013 Second Call Engineer:David Bjork 907-440-0331 Current Bottom Hole Pressure:4,079 psi @ 9,100’ TVD 8.7 PPGE | Taken 3/18/2020 Maximum Expected BHP:4,079 psi @ 9,100’ TVD 8.7 PPGE Max. Anticipated Surface Pressure:3,169 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2,000psi (Taken on 3/18/2021) Min ID:1.92” - 2-3/8” production liner Max Angle:98.35 Deg @ 15,096’ Brief Well Summary: NK-61A was drilled and completed in April 2006 as a Kuparuk producer in the western block at Niakuk. The well is currently producing at a low fluid rate. Objectives: The objective of this procedure is to perform an extended add perf operation to increase gross fluid rate. Procedure: Coiled Tubing Notes: Due to the necessary open hole deployment of Extended Perforating jobs, 24-hour crew and WSS coverage is required. The well will be killed and monitored before making up the initial perfs 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. 1. After MU MHA and pull testing the CTC, tag-up on the CT stripper to ensure BHA cannot pull through the brass upon POOH with guns. 2. RIH with 1.69” milling BHA and junk mill, mill CIBP at 13,527’, then push to PBTD. PUH to liner top then dry drift liner to PBTD before POOH. 3. Bullhead ~140 bbls (1.2x WBV) of 8.8ppg brine down tubing. Max tubing pressure 2500 psi. (This step can be performed any time prior to open-hole deployment of the perf guns. Timing of the well kill is at the discretion of the WSS.) a. Wellbore volume to bottom perf = 114 bbls b. 3-1/2” Tubing – 11,581’ x 0.0087 = 101 bbl c. 2-3/8” Liner – (14,890’ – 11,581’) x 0.0039bpf = 13 bbl 4. MU and RIH with logging tools. 5. Flag pipe as appropriate per WSS for addperf runs. 6. POOH and freeze protect tubing as needed. 7. Confirm good log data. 8. At surface, prepare for deployment of TCP guns. 3,169 psi Well: NK-61A PTD: 206-035 API: 50-029-22893-01-00 9. Confirm well is dead. Bleed any pressure off to return tank. Kill well with 8.8 ppg brine as needed. Maintain hole fill taking returns to tank until lubricator connection is re-established. Fluids man- watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. 10.*Perform drill by picking up safety joint with 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. a.At the beginning of each job, the crossover/safety joint must be physically MU to the perf guns one time to confirm the threads are compatible. 11. Break lubricator connection at QTS and begin makeup of TCP guns per schedule below. Constantly monitor fluid rates pumped in and fluid returns out of the well. Fluids man-watch must be performed while deploying perf guns to ensure the well remains killed and there is no excess flow. Perf Schedule *HES 1.56” guns were used to estimate for this job and calculate gun weights. Run Perf Interval Perf Length Gun Length Weight of Gun (lbs) #2 11,963’ – 12,052’ 89’ 89’360 # (4ppf) #1 13,400’ – 13,650’ 150’ 150’600 # (4ppf) 12. RIH with perf gun #1 and tie-in to coil flag correlation. Pickup and perforate interval per Perf Schedule above. a. Note any tubing pressure change in WSR. 13. After perforating, PUH and paint flag for next perf run, then continue to PUH to top of liner to ensure debris doesn’t fall in on the guns and stick the BHA. Confirm well is dead and re-kill if necessary, before pulling to surface. 14. Pump pipe displacement while POOH. Stop at surface to reconfirm well is dead. Kill well if necessary. 15. Review well control steps and Standing Orders with crew prior to breaking lubricator connection and commencing breakdown of TCP gun string. 16. Ensure safety joint and TIW valve assembly are on-hand before breaking off lubricator, thenLD gun BHA. 17. Repeat steps 8 – 16 for run #2. 18. RDMO CTU. 19. RTP or FP well. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Coil Tubing BOPE Schematic 4. Standing Orders for Open Hole Well Control during Perf Gun Deployment 5. Equipment Layout Diagram 6. Tie In Log/Perf Sheet 7. Sundry Change Form 250' SFD Make up PCE. Well: NK-61A PTD: 206-035 API: 50-029-22893-01-00 Current Wellbore Schematic Well: NK-61A PTD: 206-035 API: 50-029-22893-01-00 Proposed Wellbore Schematic Well: NK-61A PTD: 206-035 API: 50-029-22893-01-00 Coiled Tubing BOPs Well: NK-61A PTD: 206-035 API: 50-029-22893-01-00 Standing Orders for Open Hole Well Control during Perf Gun Deployment Well: NK-61A PTD: 206-035 API: 50-029-22893-01-00 Equipment Layout Diagram Well: NK-61A PTD: 206-035 API: 50-029-22893-01-00 Well: NK-61A PTD: 206-035 API: 50-029-22893-01-00 Well: NK-61A PTD: 206-035 API: 50-029-22893-01-00 Well: NK-61A PTD: 206-035 API: 50-029-22893-01-00 Well: NK-61A PTD: 206-035 API: 50-029-22893-01-00 Changes to Approved Sundry Procedure • • • 7-4� ����%y*�•a THE STATE AlaskaOil and Gas , . of Conservation Commission Sr�x 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 leisT7 Main: 907.279.1433 ®d' Lg1Fe` Fax: 907.276.7542 www.aogcc.alaska.gov November 28, 2016 Ms. Mary Cocklan-Vendl Pipeline Compliance& Conformance Mgr BP Exploration (Alaska) Inc. 900 E. Benson Boulevand Anchorage, AK 99508 Re: Docket Number: OTH-16-026 SCAMED DEC 0 12016 Notice of Violation—Closeout Defeated Safety Valve System PBU NK-61A(PTD 2060350) Dear Ms. Cocklan-Vendel: Thank you for BP Exploration (Alaska) Inc. (BPXA)'s explanation dated November 16, 2016 regarding the defeated well safety valve system on Prudhoe Bay Unit well NK-61A. The Alaska Oil and Gas Conservation Commission (AOGCC) is satisfied with corrective actions being implemented by BPXA which are intended to prevent recurrence of this noncompliance. The Prudhoe Bay Unit NK-pad wellhead safety valve systems must be tested at intervals not to exceed 90 days between tests(starting from October 22,2016)until the AOGCC determines an acceptable level of performance has been achieved. The AOGCC does not intend to pursue any further enforcement action regarding this Prudhoe Bay Unit NK-61A defeated safety valve system. Sincerely, lJ Cathy . Foerster Chair cc: AOGCC Inspectors(via email) • . p - I -oa(o )111 , bp BP Exploration(Alaska)Inc. 900 E.Benson Boulevard Mary E. Cocklan-Vendl Anchorage,Alaska 99508 Pipeline Compliance&Conformance Manager Tel:(907)564-4766 Email:mary.cocklanvendl@bp.com November 16, 2016 James Regg Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Notice of Violation-Defeated Safety Valve System PBU NK-61A(PTD 2060350) Dear Mr, Regg: On November 2,2016,AOGCC issued a Notice of Violation (NOV)to BPXA for a defeated safety valve system on Prudhoe Bay Unit(PBU)Greater Point McIntyre Area(GPMA) NK-61A well. Specifically, the low pressure pilot on well NK-61A was found defeated at the time of performance testing. The AOGCC inspection revealed the NK-61A was producing prior to the performance test, but the low pressure pilot was rendered inoperable. 20 AAC 25.265 requires a completed well to be equipped with a functional safety valve system. Paragraph(m)establishes tagging procedures for a well safety valve system component that is inoperable, removed or blocked. There was no tag observed on NK-61A that would indicate an inoperable low pressure pilot. Per 20 AAC 25.265, AOGCC requested BPXA provide an explanation of how this event happened and what has been or will be done in the future to prevent its recurrence at BPXA- operated fields. BPXA performed an investigation and found the following: • NK-61A was brought on line on Monday, October 17, 2016. • The BPXA GPMA Normal Start-up Production Wells Procedure(AK-OPS-GPMA-NP- 0014)Step 3 instructs the operator to: Check the wellhead SVS as follows: a) SVS isolation valve is open b) SSSV isolation valves are open c) LPS root valve is open to hydraulic panel d) ESD dump valve is in normal position e) Accumulator valve is in open position Panel power is reset o Step(a)of the procedure was not verified prior to start-up. • A mandatory weekly safety check is done, with a documented check list, typically on Wednesday of each week. • The weekly safety check was performed on Wednesday, October 19, 2016 that showed all was in order in the well house and SVS. • The AOGCC State test was conducted on SaturdaY. October 22, 2016. • Finding the LPP closed during the State Test shows that the defeated low pressure pilot was missed during the weekly safety check. • • The following actions are being taken to prevent recurrence in the future: • The BP GPMA Normal Start-up Production Wells Procedure(AK-OPS-GPMA-NP-0014) will require operator signature after each step of the procedure. • Verbiage will be added to Step 3 of the procedure instructing Operators to use a"hands on"approach when checking the SVS. The existing verbiage could have been understood to be a visual check to look for a flag. • GPMA leadership will refresh expectations for all GPMA personnel to follow procedures and practice Operating Discipline during weekly GPMA Operations and Safety meetings. • GPMA leadership will conduct additional Self Verifications through 2Q2017 to verify procedures are being followed with respect to Well Start Ups and Safety Checks. • The Well Compliance Advisors will review Well Start Up procedures for other BPXA North Slope facilities for clarity of expectations around checking wellhead SVSs. • The Well Compliance Advisors will share lessons learned from the NOV across BPXA Field Operations. Please let me know if you have any questions. Sincerely, 64114( Mary E. Cocklan-Vendl Pipeline Compliance&Conformance Manager BP Exploration(Alaska) Inc. Electronic cc: Glen Pomeroy, BPXA Dave Stobbs, BPXA Chris Fortenberry, BPXA Peter Harriman, BPXA Ryan Daniel, BPXA Krissell Crandall, BPXA Storm Herring, BPXA Lee Hulme, BPXA Vince Pokryfki, BPXA AOGCC NOV—Defeated Safety Valve System PBU NK-61A(PTD 2060350) 11/16/2016 Page 2 410 410 OF Tuti g \\I// 6. THE STATE Alaska Oil and Gas Fp, 4--s a w JJJ\ S]KA Conse atio . Commissi r.I> 4 -ASKA- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 (17' n'ailf)* Fax: 907.276.7542 www.aogcc.alaska.gov November 2, 2016 CERTIFIED MAIL— RETURN RECEIPT REQUESTED 7015 1660 0000 1487 7159 Ms. Mary Cocklan-Vendl Pipeline Compliance and Conformance Mgr BP Exploration(Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Docket Number: OTH-16-026 Notice of Violation Defeated Safety Valve System Prudhoe Bay Unit NK-61A (PTD 2060350) Prudhoe Bay Unit,Niakuk Oil Pool Dear Ms. Cocklan-Vendl: On October 22, 2016, an Alaska Oil and Gas Conservation Commission (AOGCC) Inspector witnessed safety valve system tests performed by BP Exploration (Alaska), Inc. (BPXA) at the Niakuk (NK) drillsite within the Prudhoe Bay Unit. The low pressure pilot on Prudhoe Bay Unit NK-61A was found defeated at the time of performance testing. A copy of the inspection report is attached. The facts reported by the AOGCC Inspector indicate a failure to maintain an operable safety valve system, which would be a violation of State regulations. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with an explanation of how this event happened and what has been or will be done in the future to prevent its recurrence at BPXA-operated fields. Inspection revealed Prudhoe Bay Unit NK-61A was producing prior to the performance test but the low pressure pilot was rendered inoperable; the pilot was placed back in service during the inspection. You are reminded that 20 AAC 25.265 requires a completed well to be equipped with a functional safety valve system. Paragraph (m) establishes tagging procedures for a well safety valve system component that is inoperable, removed or blocked. There was no tag observed on Prudhoe Bay Unit NK-61A that would indicate an inoperable low pressure pilot. • 0 Docket Number:OTH-16-026 Defeated Safety Valve System November 2,2016 Page 2 of 2 Also noted during the testing at the Prudhoe Bay Unit NK drillsite was a safety valve system component failure rate of 12.1 percent(11 wells;33 components;4 failures). The AOGCC's safety valve system test interval requirements provide that the testing frequency will be increased when a failure rate exceeds 10 percent. BPXA is directed to test the well safety valve systems at Prudhoe Bay Unit NK drillsite at intervals not to exceed 90 days between tests until the AOGCC determines an acceptable level of performance has been achieved. When testing is scheduled, BPXA must notify the AOGCC at least 24 hours in advance for an opportunity to witness the SVS tests. The AOGCC reserves the right to pursue enforcement action in connection with the defeated low pressure pilot on Prudhoe Bay Unit NK-61A as provided by 20 AAC 25.535. Questions regarding this letter should be directed to Jim Regg at 907-793-1236. Sincerely, rie-e/bL— Cathy . Foerster Chair, Commissioner Attachment cc: P. Brooks AOGCC Inspectors RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a),within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed,then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The AOGCC shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the AOGCC denies reconsideration,upon denial,this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision denying reconsideration,UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the AOGCC grants an application for reconsideration,this order or decision does not become final. Rather,the order or decision on reconsideration will be the FINAL order or decision of the AOGCC,and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the AOGCC mails,OR 30 days if the AOGCC otherwise distributes,the order or decision on reconsideration. In computing a period of time above,the date of the event or default after which the designated period begins to run is not included in the period;the last day of the period is included,unless it falls on a weekend or state holiday,in which event the period runs until 5:00 p.m.on the next day that does not fall on a weekend or state holiday. j. • 0 a CI 10U C L Ge A N tc 0 0 t s s E c., E opo o Z 1 v A ca C �` ▪ vOi V N ,.C. CO L G i 1• 106 a ▪ C % oo C o c ^ C o Z u Z Z Z Z Z Z7- 7. 7. Z Z y, nO `r CCI .{ w M V/ N '4,..,. � f C7 J N J N U h ON f VN V ^ - 4) +.4N C rte, = 00 Q. r'1 CA '' - G O 00 00 ••• C Y', Yr O 'N. Q .G L r- M M M V h . V, N .1 1. V tP ,C C ••D ‘0 ••O O s0 .: ',C v' VJ c• 0el• r U N p h C GO - wRS ' A) C C R7 y J Q "G" fr C O O N N '01 C U C E d a. N sc O M ^ N ,G N n M M C a 6. -' C . C c CC c c 00 C c C 0- _w C '✓: C O N 0G O rn R 00 O (i, - Q.. '- M N S - K M'O•.. 00 O -� N N N N N N N ' z _ L ^ C ^ 61 11:1 0 r—� < a rQ J 9 C C 00 1 rJ, . 9 Q . i-- ' N ¢ 0 ' 2 �» nx 0 .4 i^ Ems.. : .` , ._ O ��11 a a 4 .. V �L/ X " p _ co 0. C. oo O. C. c C. 17 i4 C C y F J a. .- 4 C C. a. a. a- -r A .. 4. t Lv .. el .o ,-J c a, a. a, a, a. a. w a, a, v , C 4..4eo O -; J7 a Co) N G. .� •O• An , "?'� (^I _. M M M '� M M M M N MIttw `v �f U T Q Q ✓; o o ro C cc o 0 0 o C G( V 1 v v, n n n n n v yr, n v, v y \/V�1 M M M M M M-M M M M M .Y f� yJ 'A n Inonl C.v: 1 -r !r � v ' -a • v •0 (. �^ 1 ' u a. rr, rr. v. v, n vi ti n n v, yr V) �r (.1..1 c c C O O O C ^ O O O ' r K, L Se M P O in ,0 ov O N in ^.y ` G Q ... L' N K n op N N T n O M 1 N Z I E _O K O O N O - O SCG` C,� Q) N Q �• 7 O O O+ 0 0' O O,. O. O C �+ J t,� O Q.. r/ N'N N' :N N N N J l '- F u < s1 Z 'Li 0) eEa . <N < ?` ry _ N S:orn oma M < z n ,. C N ry f N tr1 i CJ 9 .p <,Z Z Z 2Z Z Z Z Z Z o v Ct.• G� U.S. Postal ServiceTM 4 a • CERTIFIED MAIL° REC. T' 0-' Domestic Mail Only Id7 ra For delivery information,visit our website at www.usps.com". Certified Mail Fee $ rR Extra Services&Fees(check box,add fee as appropriate) ❑Return Receipt(hardcopy) $ ______ O 0 Return Receipt(electronic) $ Postmark 0 0 Certified Mail Restricted Dehaery $ _. Here C3 ❑Adult Signature Required $ _. ❑Adult Signature Restricted Delivery$ c3 Postage .D $ .13 Total Postage ,-q $ Ms. Mary Cocklan-Vendl • Sent To Pipeline Compliance and Conformance Manager 0 Street andAp BP Exploration(Alaska), Inc. P.O. Box 196612 City,State,ZI Anchorage,AK 99519-6612 PSForm 38. - ...... ..:.. ---,.a..�..... SENDER: COMPLETE THIS SEt:TION - COMPLETE THIS SECTION ON DELIVERY • Complete items 1,2, and 3 it; Agent Print your name and address on e reverse X • , 1/474w, �%�f 0 Addressee so that we can return the card to yofi. ■ Attach this card to the back of the mailpiece, B• R eived by(Print,.N. e) C. Date of Deliveryr or on the front if space permits. * - �f 5 /& 1. Article Aririreeeed+r,•. �� .�C--� - - --i D. Is delivery address different from item 1? 0 Yes \ If YE en sibiow: ❑ No Ms. Mary Cocklan-Vend) FlEch Pipeline Compliance and Conformance Manager I Inc. NOV 0 8 2016 BP Exploration(Alaska), P.O. Box 196612 Anchorage,AK 99519-6612 t(t ' ILII III III a ServiceType Priority Mail Express® I I III IIIIIIIIIIIIIIIII 1IIIII III 0 Adult Signature ❑Regitered MaiITM 0 Adult Signature Restricted Delivery 0 Registered Mail Restricted WrCertified Mail® Delivery 9590 9401 0057 5071 0133 07 0 Certified Mail Restricted Delivery ErReturn Receipt for 0 Collect on Delivery Merchandise 2. Article Number(Transfer from service label) 0 Collect on Delivery Restricted Delivery D Signature Confirmation'. ured Mail 0 Signature Confirmation 7 015 1660 0000 1487 7159 ured Mail Restricted Delivery Restricted Delivery _,Ter$500) PS Form 3811,April 2015 PSN 7530-02-000-9053 Domestic Return Receipt • • Image Project Well History File Cover Page XHVZE 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. ~~ ~ - D ~yj Well History File Identifier Organizingldone> ^ Two-sided IIIIIIIIIIIIIIIIIII ^ RescanNeeded IIII~'I~IIII~II~III RESCAN DIGITAL DATA OVERSIZED (Scannable) ~C for Items: Diskettes, No. ~ ^ Maps: Greyscale Items: 1 ~ -U ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: Ej` lsl Project Proofing III IIIIII IIIII II III BY: Maria Date: ~ ~ /s/ ~ Scanning Preparation ~ x 30 = ~ + =TOTAL PAGES ~ Count does not include cover sheet BY: Maria Date: Q 8 ( /s/ ) Production Scanning III IIIIIIIIIII II III Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO BY: Maria Date: ~ ~~/~ g /s/ ~ p 1 Stage 7 If NO in stage 1, page(s) discrepancies were found; YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II III II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked II I II II II III II') III P P 10/6/2005. Well History File Cover Page.doc • 410 UP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 July 6, 2011 - 0,4a ) JUL 1 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ., 06—°'5"- L. A 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA Niakuk Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA Niakuk that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Mehreen Vazir, at 659-5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Niakuk Date: 05/15/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal NK -01A 1760280 500292015601 P&A 3/9/91 NA NA NA NA NA NK -02A 1760790 500292018001 P&A 3/13/91 NA NA NA NA NA NK -03 1780940 500292035000 P&A 4/14/80 NA NA NA NA NA NK -04 1842000 500292121700 P&A 4/14/96 NA NA NA NA NA NK -05 1860270 500292129000 P&A 4/15/96 NA NA NA NA NA NK-06 1852780 500292148800 P&A 4/15/96 NA NA NA NA NA NK -07A 2010830 500292241001 0.2 NA 0.2 NA 0.9 4/30/2011 NK -08A 2010290 500292249101 0.2 NA 0.2 NA 0.9 4/30/2011 NK-09 1941400 500292251800 2.1 NA 2.1 NA 17.0 4/30/2011 NK -10 1931840 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 NK -12C 2030550 600292241403 1.8 NA 1.8 NA 31.0 4/30/2011 NK -13 1981340 500292289300 2.3 NA 2.3 NA 22.1 5/4/2011 NK -14A 2060310 500292268801 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 -16 1940220 500292244700 2.5 NA 2.5 NA 20.4 5/4/2011 NK -17 1961850 500292270900 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 5/6/2011 NK -20A 2050400 500292242901 2.1 NA 2.1 NA 13.6 5/9/2011 NK -21 1940860 500292248700 2 NA 2 NA 22.1 5/15/2011 NK -22A 2012280 500292240201 1.5 NA 1.5 NA 11.9 5/11/2011 NK -23 1940350 500292245500 3.6 NA 3.6 NA 20.4 5/10/2011 NK -25 1970680 500292276000 2.5 NA 2.5 NA 15.3 5/11/2011 NK -26 1940050 500292244000 2.9 NA 2.9 NA 17.0 5/11/2011 NK -27 1950210 500292254700 2.3 NA 2.3 NA 13.6 4/30/2011 NK -28 1960930 500292267800 Sealed Conductor NA Sealed Conductor NA NA NA NK -29 1961900 500292272400 1.7 NA 1.7 NA 10.2 4/30/2011 NK-38A 2042410 500292254001 3.1 NA 3.1 NA 13.6 5/6/2011 NK-41A 1971580 500292277801 9.1 NA 9.1 NA 54.0 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-62A 2030470 500292285201 1.3 NA 1.3 NA 13.6 5/4/2011 NK-65A 2050830 500292288901 1 NA 1 NA 8.5 5/6/2011 <~ ~~ p -~^ ..,~,,"' . r .. - ,~e~w. "~ r ~11F ter _ ,tis 1 y, Y3..~ ~ .~. ~a~~; i~ ~ry a4 n ~'* yam. ~~:.: ter: '. ~i ~_. ..`. W MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS.: PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc l~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060350 Well Name/No. PRUDHOE BAY UN NIA NK-81A Operator BP EXPLORATION (ALASKA) INC MD 15125 TVD 9172 Completion Date 4!14/2006 Completion Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD / NGP, GR / ROP, Induction / GR /CCL, MGR /CCL Well Log Information: Log/ Electr Date Digital Dataset Log Log Run Ty~ie Med/Frmt Number Name Scale Media No D D Asc Directional Survey / C Las 15775t~amma Ray pt LI/S Verification ~D C Lis 15965 mamma Ray ~ Pressure 25 Col ~ Log Pressure 25 Col C 16102 ~essure Well Cores/Sampl es Information: Interval Name Start Stop ADDITIONAL INFORM~N Well Cored? Y N Chips Received? '4Ttd"' Analysis ~4'TFf' Received? Comments: Current Status 1-OIL API No. 50-029-22893-01-00 UIC N ~ ~. Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 11800 15125 Open 6/27/2006 11579 15120 Open 12/3/2007 GR, ROP wPDF graphics 11578 15121 Open 2/29/2008 LIS Veri, GR, ROP 11578 15121 Open 2/29/2008 LIS Veri, GR, ROP 8913 9111 Open 4/10/2008 TVD PCG 10-Apr-2006 11605 15125 Open 4/10/2008 MD ROP, PCG 10-Apr- 2006 0 0 Case 4/10/2008 Pressure in MD and TVD logs in EMF, PDS and CGM graphics Sample Set Sent Received Number Comments Daily History Received? V N Formation Tops ~ N DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2060350 Well Name/No. PRUDHOE BAY UN NIA NK-61A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22893-01-00 MD 15125 TVD 9172 ompletion Date 4/14/2006 Completion Status 1-OIL Current Status 1-OILU~ICAN.` Compliance Reviewed By: _ _. _ _ _.. _ _------_--_- __- Date: ~_~ • • To: State of Alaska WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : NK-61A April 7, 2008 AK-MW-430063 NK-61A: 2" x 5" MD PCG Logs: 1 Color Logs 50-029-22893-01 2" x 5" TVD PCG Logs: 1 Color Logs 50-029-22893-01 Digital Log Images: 1 CD Rom 50-029-22893-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date Signed: ~ ~ ~ WELL LOG TRANSMITTAL To: State of Alaska February 25, 2008 Alaska Oil and Gas Conservation Comm. Attn.. Librarian ~ - -~ ,. r:: 333 West 7~' Avenue, Suite 100 `~ ~: Anchorage, Alaska 99501 ~ j ~ RE: MWD Formation Evaluation Data: NK-61A '~ ~ ~~ ~~. ~° AK-NL~V.-~~3~638 ~, 1 LDWG formatted CD rom with verification listing. API#: 50-029-22893-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. AnchorA~~Ca 99°1 & Anchorage, Alaska 99508 DaI~: .. Signed: ~o~-O35 ~~ 1s~5' Date 11-30-2007 Transmittal Number:92922 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) t you have an ueshons, lease contact llou las llortch at the YllC; at 564-4y"/3 Delivery Contents 05-28B ~aG~o~g ~ IS-}(~~{ 05-286PB1 ~o(o-v~9 ~ eS~~S 1-39A/N-16.~~-~~~ e5~(ov7 1-39A/PB1 ~ut~-tb~ 15$-~ 15-126 -no /-t~= C-32C ~o~ -r3g ~ ~5~64• E-11 B - n o l4 P3 E-11 BL1 ~o~--odd -~ tj ~{~~ E-116L1-01 av~-6G2'~15 ~~ E-11 BL1 P61'p-~-pt, t sc t.5-~,~~, E-11BL1P62at~'~--vet ¢i$~~~~ G-25B 2o~-b ~~ *' t S~~-~ NK-14A~ aaco-o3 t ~- 1~-~-3 NK-14AP61 ~o~-o3t ~ r~-~~zl NK-61 A ~t5(o-03S ~ lS~~ S Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2- t 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 995 1 9-66 1 2 .~,~o~ RECEIVED STATE OF ALASKA w ALAOIL AND GAS CONSERVATION COMM~ION APR 2 6 ?.007 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other & Pertormed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ ~ - Change Approved Program ~ Operat. Shutdown ~ Perforate 0 Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 206-0350 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-22893-01-00 `" 7. KB Elevation (ft): 9. Well Name and Number: 59.4 KB NK-61A' 8. Property Designation: 10. Field/Pool(s): ADLO-034630 PRUDHOE BAY Field/ NIAKUK OIL Pool 11. Present Well Condition Summary: Total Depth measured 15125 ' feet Plugs (measured) 13257' true vertical 9171.56 feet Junk (measured) None Effective Depth measured 15087 ~ feet true vertical 9177 ~ feet Casing Length Size MD TVD Burst Collapse Conductor 73' 20" 94# H-40 42' - 115' 42' - 115' 1530 520 Surface 6156' 9-5/8" 47# L-80 40' - 6196' 40' - 5102' 6870 4760 Production 11768' 7" 29# L-80 38' - 11806' 38' - 9159' 8160 7020 Liner 3544' 2-3/8" 4.6# L-80 11581' - 15125' 8951' - 9172' 11200 11780 Perforation depth: Measured depth: 11810' - 14890' True Vertical depth: 9162' - 9194' _ _ Tubing: (size, grade, and measured depth) 3-1/2" 9.3# L-80 0' - 11620' Packers and SSSV (type and measured depth) 7-5/8"X4-1/2" BAKER S-3 PKR 11574' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SHUT IN 0 0 0 0 Subsequent to operation: 30 296 2135 0 504 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 4/20/2007 REPORT OF SUNDRY WELL OPERATIONS ~ . ~ Form 10-404 R ised 04/2006 0 ~ ~ G I~CC A L ~F~ r~AY ~ ~ 20~/ ~~ Submit Original Only NK-61A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ACTIVITYDATE ~ SUMMARY ~ 4/10/2007 MIRU CTU #5 ***Job Scope Set CIBP/Log/Add Perf*** MU BHA to drift for CIBP '**Continue job on 4/11/2007*** 4/11/2007 """Continue job from 4/10/2007*** RIH w/ 2.8" JSN. Drift to 13,600'. RIH w/ 2 3/8" (1.75" OD) CIBP and set at 13,560' CTM. Pressure test CIBP to 3000 psi. POOH. Perform chain inspection, change 3 bad bearings, and replace packoffs. RIH w. SLB Memory GR/CCL ***Continue job on 4/12/2007**" __ 4/12/2007 ***Continue job from 4/11/2007*** Continue in hole w/SLB memory GR/CCL. 'Tag CIBP @ 13,497. PUH & log C 60 fpm from 12,200'-11,800', stop paint flag '; C~ 11,799.2'. POOH. Good data recovered: +2T correction. Perforate intervals 11,810' - 11,840', 12,090' - 12,120', and 12,120' - 12,150' per procedure. ***Continue job on 4/13/2007*** 4/13/2007: CTU #5 *** Continue job from 4/12/2007*** Perforate intervals 11,810' - 11,840', :12,090' - 12,120', and 12,120' - 12,150' per procedure. Turn well over to DSO ***Job Complete*** FLUIDS PUMPED BBLS 144 60/40 METHANOL 144 TOTAL • ~ 17-May-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well NK-61A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 11,800.00' MD Window /Kickoff Survey: 15,095.85' MD (if applicable) Projected Survey: 15,125.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR 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 ~7 ~p~~0~} Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~(P-~~~ STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.ios zoAACZS.~io ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Weli Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 4/14/2006 12. Permit to Drill Number 206-035 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/2/2006 13. API Number 50-029-22893-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 4/10/2006 14. Well Name and Number: PBU NK-61A 1383 FSL, 900 FEL, SEC. 36, T12N, R15E, UM Top of Productive Horizon: 1958' FSL, 4448' FEL, SEC. 25, T12N, R15E, UM g. KB Elevation (ft): 59.4' 15. Field /Pool(s): Prudhoe Bay Field / Niakuk Pool Total Depth: 4883' FSL, 4674' FEL, SEC. 25, T12N, R15E, UM 9. Plug Back Depth (MD+TVD) 15087 + 9177 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 721661 y- 5979921 Zone- ASP4 10. Total Depth (MD+TVD) 15125 + 9172 Ft 16. Property Designation: ADL 034630 TPI: x- 717940 y- 5985670 Zone- ASP4 Total Depth: x- 717628 Y- 5988586 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: ff f k f 20 Thi f P t 18. Directional Surve Y ®Yes ^ No 19. Water depth, i o shore N/A MSL ness o ros . c erma 1800' (Approx.) 21. Logs Run: MWD / NGP, GR / ROP, Induction / GR /CCL, MGR /CCL ASING, INER AND EMENTING ECORD CASING ETTING EPTH MD ETTING EPTH TVD HOLE OUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 42' 115' 42' 115' 30" 60 sx Arctic Set A rox. 9-5/8" 47# L-80 40' 6196' 40' 5102' 12-1 /4" 2410 sx PF 'E', 410 sx Class 'G' 7" 29# L-80 38' 11806' 38' 9159' 8-1 /2" 275 sx Class 'G' 2-3/8" 4.6# L-80 11581' 15125' 8951' 9172' 3" 87 sx Class 'G' 23. Perforations open.to Production (MD +TVD of Top and " " 24. TUBING RECORD Bottom Interval, Slze and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 1.56" Gun Diameter, 6 spf 3-1/2", 9.3#, L-80 11621' 11574' MD TVD MD TVD 13770' - 13860' 9237' - 9235' 14420' - 14540' 9224' - 9219' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 14570' - 14680' 9218' - 9211' 14740' 14800' 9208' 9205' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED - - 14830' -14890' 9202' - 9194' 2500' Freeze Protected w/ 17 Bbls of 60/40 McOH 26• PRODUCTION TEST Date First Production: May 9, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 5/10/2006 Hours Tested 8 PRODUCTION FOR TEST PERIOD • OIL-BBL 144 GAS-McF 115 WATER-BBL 931 CHOKE SIZE 111 GAS-OIL RATIO 797 Flow Tubing Press. 86 Casing Pressure 1,983 CALCULATED 24-HOUR RATE OIL-BBL 433 GAS-MCF 345 WATER-BBL 2,792 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submlt core ch~'Ips; if none, states ~~ hIAY 3 0 2006 ~ oeJ ~~~0 ~~~~~ ~ ~ ~1 iv~ s~..~..p g~~ None ~ F ~ c ~ 7 Form 10-407 Revised 12/2003 ~ ~ €.., ~ ~~~1 \ 1.D ON REVERSE SIDE /! 28. GEOLOGIC MARKS 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Kuparuk 11802' 9155' None 5FS 11802' 9155' 4B6 11846' 9192' 4AA 11906' 9230' 5FS 11961' 9245' 5AA 12351' 9248' 6FS 12624' 9241' 5AA 14634' 9215' Kuparuk 15095' 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. r-,e' Signed t Date v J~ ~O ~~( h i l A i Titl T t , an ec n ca ss s e Terrie Hubble PBU NK-61A 206-035 Prepared By Name/Number.• Terrie Hubble, 564-4628 Well Number Permit No. / Ap royal No. Drilling Engineer: Sean McLaughlin, 564-4387 INSTRUCTIONS GeNeRn,~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 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. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ' . BP EXPLORATION Page 1 of 14 :.Operations Summary 'Report Legal Well Name: NK-61 ( Common WeA Name: NK-61 Spud Date: 6/28/1998 Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task. Code NPT Phase. Description of Operations 3/28/2006 13:00 - 13:30 0.50 MOB P PRE Held pre-rig move safety meeting with Security, Nordic and SWS personnel. Reviewed rig move plan, hazards and mitigation. 13:30 - 00:00 10.50 MOB P PRE Move rig to Oxbow road and to Deadhorse. No problems. 3/29/2006 00:00 - 01:00 1.00 MOB P PRE Moved rig to SWS shop for reel swap. 01:00 - 04:00 3.00 MOB P PRE Swap reels with crane. Install 2" reel with 14880' of coil. No problems. 04:00 - 17:00 13.00 MOB P PRE 17:00 - 20:30 3.50 MOB N WAIT PRE 20:30 - 21:00 0.50 MOB P PRE 21:00 - 21:30 0.50 MOB P PRE 21:30 - 23:00 1.50 RIGU P PRE 23:00 - 00:00 1.00 BOPSU P PRE 3/30/2006 00:00 - 04:00 4.00 BOPSU P PRE 04:00 - 18:30 I 14.501 BOPSUR P I I PRE 18:30 - 21:00 2.50 STWHIP P WEXIT 21:00 - 21:15 0.25 STWHIP P WEXIT 21:15 - 22:45 1.50 STWHIP P WEXIT 13/31/2006 100:00 - 010:45 1.751 STWHIPI P ( WEXIT 01:45 - 04:00 I 2.251 STWHIPI P I I WEXIT 04:00 - 06:00 I 2.001 STWHIPI P I I WEXIT 06:00 - 12:00 6.00 STWHIP P WEXIT 12:00 - 13:00 1.00 STWHIP P WEXIT 13:00 - 13:30 0.50 STWHIP P WEXIT Move rig from Deadhorse to Niakuk. Good rig move, no problems. Rig at Niakuk. Wait on pad prep. Weld on 2" CT connector. Rig up 2" reel hardline. SAFETY MEETING. Held safety meeting before backing rig over well. Reviewed procedure, hazards and mitigation for backing rig over well. Very tight well spacing. Only 6" of clearance on one side. Back rig over well with no problems. ACCEPT RIG AT 2130 HRS, 03/29/2006. General rig up. Spot trailers, tanks N/U BOPE. Change out rams for 2" coil. N/U BOPE. C/O rams for 2" coil. Pressure /function test BOPE. AOGCC inspecter Chuck Scheve & BP rep Bob Laule witnessed test. Repaired 2 choke manifold valves. Repaired blind rams bonnet. Filled pits with 290 bbls of 2# Biozan Fill coil with Biozan. Press test inner reel valve. Pump dart. Dart on seat at 40.1 bbls. SAFETY MEETING. Review procedure, hazards and mitigation for make up of WF milling BHA. M/U Pilot milling BHA #1 with 2.74" diamond parabolic mill, 1.75 deg WF motor, Sperry MWD and orienter and WF MHA. OAL = 46.40'. Test orienter at surface, 3 of 3 clicks. RIH with 2.74" Pilot hole milling BHA. Take returns to cuttings tank. RIH with 2.74" pilot mill on a 1.75 deg WF motor. Tag cement at 11605'. at bottom of tailpipe. 33K up wt. 11 K down wt. Mill Pilot hole in cement. 1.6 bpm, 3320 psi, 20 fph, 4K wob, 160R, hard cement. Milled to 11,645'. Mill Pilot hole in cement. 1.6 bpm, 3200 psi, 20 fph, 4K wob, 160R, hard cement. Milled to 11,670'. Tied-in with GR while milling ahead. Added 2' to CTD. Mill Pilot hole in cement. 1.5 bpm, 3000 psi, 20 fph, 4K wob, 170R, hard cement. Drill to 11790 Wiper tie-in Correction +1.5'. Mill Pilot hole in cement. 1.6 bpm, 3280 psi, 20 fph, 4K wob, 175R, hard cement. Drill to 11798 Printed: 4/17/2006 11:01:40 AM • • BP EXPLORATION Page 2 of 14 Operations Summary Report Legal Well Name: NK-61 Common Well Name: NK-61 Spud Date: 6/28/1998 Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase:• Description of Operations 3/31/2006 13:30 - 13:45 0.25 STWHIP P WEXIT Orient to 10L 13:45 - 14:30 0.75 STWHIP P WEXIT Mill cement ramp[. 1.7 bpm, 3300 psi, 11 fph, 4K wob, 10 L, hard cement. Drill to 11806 End of ramp. 14:30 - 17:00 2.50 STWHIP P WEXIT POH. 17:00.- 18:00 1.00 STWHIP P WEXIT LD cement mill and P/U window mill with brass guide ring and 2.5 deg fixed bend WF motor. 18:00 - 20:50 2.83 STWHIP P WEXIT RIH with BHA #2 window milling BHA. Set down on many collars while RIH. Went thru TRSSSV OK. Circ at 0.2 bpm to get past collars. RIH to 11780'. 20:50 - 21:20 0.50 STWHIP P WEXIT Orient TF to 20L. RIH and tag bottom 3 times at 11816'. Pick up 4 ft off bottom. Start pump at 1.6 bpm. Ease down with 6R TF. 1.5 bpm, 2800 psi, 7K down wt off bottom. First motor work at 11814'. Correct depth to 11806'. Flagged coil at 11806'. Pick up 1 ft as per program. 21:20 - 00:00 2.67 STWHIP P WEXIT Time mill window as per schedule. 1.6 bpm, 3000 psi, 12R, Mill for 3 hours to get back to 11806' as per schedule. 4/1/2006 00:00 - 02:00 2.00 STWHIP P WEXIT Time Milling 2.74" window. 1.6 bpm, 3070 psi, 12R, No WOB. mill as per time schedule. Milled to 11,807'. 02:00 - 04:00 2.00 STWHIP P WEXIT Time Milling 2.74" window. 1.6 bpm, 3070 psi, 12R, 1.5k wob, Mill as per time schedule. Milled to 11,808'. Getting good metal on ditch magnets. 04:00 - 06:00 2.00 STWHIP P WEXIT Time Milling 2.74" window. 1.6 bpm, 3300 psi, 11L, 4-5k wob, Milled to 11,810'. Stacking more weight, but milling off OK. 06:00 - 11:15 5.25 STWHIP P WEXIT Milling window at 1 FPH. 1.6 bpm, 3020 psi, 6R, 3.5K WOB. Continue milling to 11811 stacking no MW. PU found bottom @ 11809. Mill to 11810 seen motor work. Mill open hole to 11820. Make additional pass thru window. Flag pipe EOP 11600' 11:15 - 13:00 1.75 STWHIP P WEXIT POH. 13:00 - 14:15 1.25 STWHIP P WEXIT LD window mill and PU window dressing mill. Mill 2.73" Go 2.72". NOGG. Window dressing mill is 2.74" Go 2.73" NOGO. 14:15 - 16:20 2.08 STWHIP P WEXIT RIH with 1.75 degree motor and Weatherford Diamond Crayola Mill. 16:20 - 17:00 0.67 STWHIP P WEXIT Tie - in to EOP flag at 11600. Correct +10'.Orient to 13R 17:00 - 19:40 2.67 STWHIP P WEXIT RIH wo pump set down 11802. RIH w pump 1.7bpm 3240 psi. Ream at 16 ft/hr, Stalling in window at 11,806. Time mill at 11802-11807'. Ream down and tag bottom on depth at 11820'. 19:40 - 22:30 2.83 STWHIP P WEXIT Backream up thru window at 7R TF. Ream down at 7R TF. Orient to 90R and backream up thru window. Stop pump and RIH clean to bottom. Backream up again while swapping well to New 9 PPG FloPro. 22:30 - 00:00 1.50 STWHIP P WEXIT POH with reaming BHA. 4/2/2006 00:00 - 00:45 0.75 STWHIP P WEXIT POH with window reaming BHA. 00:45 - 01:15 0.50 STWHIP P WEXIT Lay out reaming BHA. Taper mill gauged at 2.74Go, 2.73 no-go. 01:15 - 01:30 0.25 DRILL P PROD1 SAFETY MEETING. Held pre-spud meeting with all personnel. Reviewed well plan, special considerations for this well, hazards and mitigation. 01:30 - 02:30 1.00 DRILL P PROD1 M/U MWD Build BHA #4 with HCC 2.7 x 3.0 Bi-center bit #4 and 2.6 deg BHI Xtreme motor and Sperry MWD with BOT Printed: 4/17/2006 11:01:40 AM • • BP EXPLORATION.' Page 3 of 14 .Operations Summary Report Legal Well Name: NK-61 Common Well Name: NK-61 Spud Date: 6/28/1998 Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006 Rig Name: NORDIC 1 Rig Number: Date .From - To .Hours Task Code NPT Phase. Description of Operations 4/2/2006 01:30 - 02:30 1.00 DRILL P PROD1 MHA. OAL = 59.92'. 02:30 - 05:30 3.00 DRILL P PROD1 RIH with Build BHA #4. SHT tools OK. RIH clean to 11760'. 05:30 - 06:00 0.50 DRILL P PROD1 Orient TF to highside. 06:00 - 06:30 0.50 DRILL P PROD1 RIH clean thru window. Tag bottom at 11826'. Correct depth to 11820'. 06:30 - 07:30 1.00 DRILL P PROD1 Drilling Build section in Kuparuk sand. 1.6 bpm, 3000 psi, HS TF. Sperry pulses failed, drill ahead to see if they start again. Drilled 3' pulser working. Orient to compensate for 80 degrees of reactive torque. PU to 11766. Pulser working again. RIH .25 bpm. RIH to 11820 1.8 bpm MWD failed. 07:30 - 09:30 2.00 DRILL N DFAL PROD1 POH for MWD failure. 09:30 - 10:30 1.00 DRILL N DFAL PROD1 Change out MWP probe. Bit in new condition. 10:30 - 12:45 2.25 DRILL N DFAL PROD1 RIH Shallow hole test at 800' OK. Continue to RIH. 11780. 12:45 - 13:00 0.25 DRILL P PROD1 Orient 24R. RIH .3 bpm @ 1300 psi. Tag at 11832 corrected 11823. 13:00 - 18:25 5.42 DRILL P PROD1 Drill build section thru the Kuparuk sand. 25'/hr, 1.7bpm, 3300psi, 5200#WOB. 18:25 - 18:50 0.42 DRILL P PROD1 P/U and orient TF to 70L. 18:50 - 20:30 1.67 DRILL P PROD1 Drill build section, 1.55 bpm, 3000 psi, 27L, 20 fph, 65 deg incl, Drilled to 11920'. 20:30 - 21:30 1.00 DRILL P PROD1 Drill build section, 1.55 bpm, 3000 psi, 27L, 30 fph, 80 deg incl, Drilled to 11940'. 21:30 - 23:15 1.75 DRILL P PROD1 POH for lateral BHA. Flag Coil at 11760' EOP. POH. 23:15 - 23:50 0.58 DRILL P PROD1 Adjust motor to 0.8 deg bend. C/O Bit, Bit#5 had 2 broken cutters and 2 plugged jets. M/U HCC BC Bit #6. Check motor and CTC. 23:50 - 00:00 0.17 DRILL P PROD1 RIH with MWD Lateral BHA #6 with 0.8 deg motor and Bit #6. 4/3/2006 00:00 - 02:00 2.00 DRILL P PROD1 RIH with Lateral BHA with 0.8 deg motor. Corrected to flag at 11700' EOP. Added 15 ft. 02:00 - 02:25 0.42 DRILL P PROD1 RIH clean thru window and clean to bottom. Tag bottom at 11942' and corrected depth to 11940'. 02:25 - 02:45 0.33 DRILL P PROD1 Orient TF to 30L. 02:45 - 04:00 1.25 DRILL P PROD1 Drilling lateral in Kuparuk sand, 1.6 bpm, 3100 psi, 35L, 35 fph, 82 deg incl, Drilled to 11980'. 04:00 - 06:00 2.00 DRILL P PROD1 Drilling lateral in Kuparuk sand, 1.6 bpm, 3100 psi, 35L, 50 fph, 89 deg incl, Drilled to 12,070'. 06:00 - 09:00 3.00 DRILL P PROD1 Drilling lateral in Kuparuk sand, 1.6 bpm, 3100 psi, 75L, 50 fph, 91 deg incl, drilled to 12161'. 09:00 - 11:25 2.42 DRILL P PROD1 Drilling lateral in Kuparuk sand, 1.6 bpm, 3200 psi, 55L, 55 fph, 91 deg incl, drilled to 12250'. 11:25 - 12:25 1.00 DRILL P PROD1 Wiper trip back to bit just below the window 11815'. Tie in about 20' of GR to shale characteristics at window. Correct +4'. Run back to bottom at 12250'. 12:25 - 14:00 1.58 DRILL P PROD1 Drilling lateral in Kuparuk sand, 1.7 bpm, 3300 psi, 117R, 60 fph, 93 degree incl, drilled to 12330'. 14:00 - 16:00 2.00 DRILL P PROD1 Drilling lateral in Kuparuk sand, 1.7pbm, 3300 psi, 115R, 60 fph, 91 degree incl, drilled to 12401'. 16:00 - 16:30 0.50 DRILL P PROD1 Wiper trip back to window after 150' of drilling. RIH to bottom to resume drilling lateral. 16:30 - 18:30 2.00 DRILL P PROD1 Drilling lateral in Kuparuk sand, 1.6 bpm, 3100 psi, 60 fph, 91 deg incl, Drilled to 12550'. 18:30 - 19:50 1.33 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. Printed: 4/17/2006 11:01:40 AM s • BP EXPLORATION Page 4 of 14' Operations Summary Report Legal Well Name: NK-61 Common Well Name: NK-61 Spud Date: 6/28/1998 Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase: Description of Operations 4!3/2006 19:50 - 00:00 4.17 DRILL P PROD1 Drilling lateral in Kuparuk sand, 1.6 bpm, 3100 psi, 50 fph, 91 deg incl, Dulled to 12700'. X4/4/2006 00:00 - 00:45 0.75 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 00:45 - 01:15 0.50 DRILL P PROD1 Log GR tie-in at window. Added 5.5 ft CTD. 01:15 - 01:45 0.50 DRILL P PROD1 RIH clean to bottom. 01:45 - 03:30 1.75 DRILL P PROD1 Drilling Kuparuk lateral, 1.6 bpm, 3200 psi, 85R, 91 deg incl, clean sand, 120 fph, Drilled to 12850'. 03:30 - 04:20 0.83 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 04:20 - 06:00 1.67 DRILL P PROD1 Drilling Kuparuk lateral, 1.6 bpm, 3200 psi, 100R, 91 deg incl, 80 fph, Drilled to 12,950'. 06:00 - 07:00 1.00 DRILL P PROD1 Drilling Kuparuk lateral, 1.6 bpm, 3200 psi, 100R, 91 deg incl, 80 fph, Drilled to 13000'. 07:00 - 08:15 1.25 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 08:15 - 09:30 1.25 DRILL P PROD1 Drilling Kuparuk lateral, 1.6 bpm, 3400psi, 100R, 91 deg incl, 80 fph, Drilled to 13069'. Azimuth readings becoming erradic. 09:30 - 10:10 0.67 DRILL N DFAL PROD1 POOH to inspect MWD/BHA due to uncertain azimuth readings. 10:10 - 11:20 1.17 DRILL N DFAL PROD1 Install CT Inspect tool on coil once inside casing @ 11585'. Circ at 0.5 bpm 11:20 - 14:00 2.67 DRILL N DFAL PROD1 Continue POOH at 80 FPM to inspect CT wall thickness and provide a base line for the new coil. Circ. 9.1 PPG FloPro at 0.75 bpm, with 0.45 bpm returns while POH. 14:00 - 15:30 1.50 DRILL N DPRB PROD1 Lay out BHA. Slight flow. Did flow check at surface. Well flowing at 0.2 bpm. Shut in well and monitor. SIWHP = 200 psi after 15 min. Reviewed SWS micromotion data and saw where well started slight flow at 3300' while POH at 80 FPM. Calculated 4 BBL pit gain on trip out. Closed TRSSSV and bleed WHP to zero. Flow check again. Well flowing at 0.4 bpm. TRSSSV not holding pressure. Shut in well. SIWHP = 200 psi. Open TRSSSV and hold 4500 PSI control pressure. Had a total of 4 bbl flow at surface from 2 flow checks. Talk to town eng. and ordered 9.8 PPG FloPro from MI mud Plant. 15:30 - 16:00 0.50 DRILL N DPRB PROD1 Close Master Valve, bleed WHP to zero. M/U 2.5" nozzle, BOT circ sub, hyd discon, checks and CTC. M/U injecter head and lubricator. Open master valve. 16:00 - 17:45 1.75 DRILL N DPRB PROD1 RIH with nozzle to circ well to 9.6 PPG FloPro. Hold 500 psi WHP with Choke while RIH. RIH thru TRSSSV with no problem. Continue RIH. Circ. 9.1 PPG FloPro at 0.4 bpm while RIH. 17:45 - 18:30 0.75 DRILL N DPRB PROD1 RIH to 10,000'. Increase pump to 2.1 bpm, open choke completely. RIH while circ 9.1ppg FloPro, full returns. RIH to 11836' and sat down with nozzle. Pick up above window to 11700'. Circ bottoms up, no gass seen. Full returns at 2.1 bpm. Slow pump to 1.9 bpm. 2700 psi. 18:30 - 22:30 4.00 DRILL N WAIT PROD1 Circ 1.9 bpm with full returns while waiting for 9.6 PPG FloPro from MI. Meanwhile SI well & observe Opsi WHP after 40mins. Printed: 4/17/2006 11:01:40 AM • • BP EXPLORATION Page 5 of 14 Operations Summalry Report Legal Well Name: NK-61 Common Well Name: NK-61 Spud Date: 6/28/1998 Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006 Rig Name: NORDIC 1 Rig Number: Date From. - To Hours Task Code NPT Phase Description of Operations 4/4/2006 22:30 - 23:00 0.50 DRILL N DPRB PROD1 Park bit @ 11600' & swap well to fresh 9.6ppg flopro mud with 23:00 - 00:00 1.00 DRILL N DPRB PROD1 4/5/2006 00:00 - 01:00 1.00 DRILL N DPRB PROD1 01:00 - 01:15 0.25 DRILL N DPRB PROD1 01:15 - 01:40 0.42 DRILL N DPRB PROD1 01:40 - 01:50 0.17 DRILL N DPRB PROD1 01:50 - 02:10 0.33 DRILL P PROD1 02:10 - 03:00 I 0.831 DRILL I P I I PROD1 03:00 - 04:00 1.00 DRILL N DFAL PROD1 04:00 - 06:30 2.50 DRILL N DFAL PROD1 06:30 - 07:15 0.75 DRILL P PROD1 07:15 - 07:45 0.50 DRILL P PROD1 07:45 - 08:15 0.50 DRILL P 08:15 - 10:15 2.00 DRILL P 10:15 - 10:45 0.50 DRILL P 10:45 - 11:20 0.58 DRILL P 11:20 - 12:30 I 1.17 DRILL P 12:30 - 14:00 1.50 DRILL P 14:00 - 15:00 I 1.001 DRILL I P 15:00 - 16:15 1.25 DRILL P 16:15 - 18:20 2.08 DRILL P 18:20 - 19:05 0.75 DRILL P 19:05 - 20:15 I 1.171 DRILL I P 20:15 - 20:50 0.58 DRILL P 20:50 - 21:40 0.83 DRILL P 21:40 - 22:25 I 0.751 DRILL I P 22:25 - 00:00 1.58 DRILL P 14/6/2006 100:00 - 00:20 00:20 - 00:30 0.331 DRILL I P 0.171 DRILL I P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 3% KCL, 3% Lo-Torq (MI version of Lubetex) & 10ppb K-G. POOH with nozzle BHA. POOH with nozzle BHA to 1500'. S/D pumps & flowcheck well for 15mins -stable. Continue POOH with nozzle BHA to surface. OOH. P/U injector. L/D nozzle BHA #7. R/U hydraulic cutter & cut 200' of CT for fatigue management. Have 14680' of CT left on reel. GBR weld new weld-on CTC. Pull test to 35k. Pressure test to 3500psi. P/U lateral drilling BHA #8 with same used Hughes 2.7" x 3" DOSTRWD bicenter bit #7, new 0.8deg X-treme motor, new Sperry GR/MWD, orienter & Baker MHA. Scribe tools & M/U injector. RIH lateral drilling BHA #8. SHT MWD. RIH Log GR tie-in. -10 ft CTD. RIH to bottom, 1.6 bpm, 3320 psi, full returns. Tag bottom at 13072' Orient TF to 110R. Drilling lateral, 1.7 bpm, 3500 psi, 120R, 92 deg incl, 70 fph, full returns. Drilled to 13184'. Orient TF to left side. Drilling lateral, 1.6 bpm, 3200 psi, 100L, 89 deg incl, 70 fph, full returns. Drilled to 13200'. Wiper trip to window. Clean hole. RIH to bottom. Drilling lateral, 1.6 bpm, 3200 psi, 90L, 90 deg incl, 80 fph, full returns. Drilled to 13,300'. Drilling lateral, 1.6 bpm, 3200 psi, 90L, 90 deg incl, 80 fph, Stacking wt. no progress, Drilled to 13328'. Wiper trip to window, clean hole, RIH clean to bottom. Drilling lateral, 1.6 bpm, 3200 psi, 90L, 89 deg incl, 80 fph, full retums, Drilled to 13,440'. Drilling lateral, 1.6 bpm, 3200 psi, 90-100L, 89 deg incl, 80 fph, full returns, Drilled to 13,500'. Wiper trip clean to window. Log up GR & tie into GR marker @ 11798'. Add 6.5' to CTD. RBIH clean to btm. Saw minor bobble @ 11880' with HS TF. Run-in wt = 10k. Up wt = 24.5k. IAP = 360psi, OAP = 310psi, PVT = 327bb1s. Drill to 13548' with 85L TF, 1.5/1.5bpm, 3250/3550psi, 3k WOB & 55fph ave ROP. Orient 1 click & drill to 13600' with 70L TF, 1.55/1.55bpm, 3450/3650psi, 3k WOB & 45fph ave ROP. Drill to 13619' with 70L TF, 1.55/1.55bpm, 3450/3650psi, 3k WOB & 55fph ave ROP. Stacking wt. P/U & TF flop 180degs to 115R. Short 100' wiper. Printed: 4/17/2006 11:01:40 AM • • BP EXPLORATION Page 6 of 14' Operations Summary Report Legal Well Name: NK-61 Common Well Name: NK-61 Spud Date: 6/28/1998 Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006 Rig Name: NORDIC 1 Rig Number: .Date from = To Hours Task .Code NPT Phase Description of Operations 4/6/2006 00:30 - 00:50 0.33 DRILL P PROD1 Orient TF around to 50L. 00:50 - 01:25 0.58 DRILL P PROD1 Orient 1 click & drill to 13675' with 70L TF, 1.55/1.55bpm, 3450/3650psi, 3k WOB & 95fph ave ROP. 01:25 - 02:55 1.50 DRILL P PROD1 Wiper trip clean to window. RB1H clean to btm. Up wt = 30k. Run-in wt = 10k. IAP = 420psi, OAP = 350psi, PVT = 317bb1s. 02:55 - 03:10 0.25 DRILL P PROD1 Orient TF to 60L. 03:10 - 03:50 0.67 DRILL P PROD1 Drill to 13735' with 85L TF, 1.55/1.55bpm, 3350/3650psi, 4k WOB & 85fph ave ROP. 03:50 - 04:10 0.33 DRILL P PROD1 Orient TF around to 80R. 04:10 - 05:50 1.67 DRILL P PROD1 Drill to 13800' with 90-110R TF, 1.55/1.55bpm, 3350/3650psi, 3k WOB & 40fph ave ROP. 05:50 - 06:15 0.42 DRILL P PROD1 Orient TF around to 110R. 06:15 - 07:10 0.92 DRILL P PROD1 Drill Lateral with 90-110R TF, 1.55/1.55bpm, 3350/3650psi, 3k WOB & 60fph ave ROP. Drilled to 13850'. 07:10 - 09:00 1.83 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 24.5K up wt, 7K down wt off bottom. 09:00 - 10:30 1.50 DRILL P PROD1 Drilling lateral, 1.5 bpm, 3200 psi, 90-110R, 91 deg incl, 60 fph, Drilled to 13920'. 10:30 - 12:10 1.67 DRILL P PROD1 Drilling lateral, 1.5 bpm, 3200 psi, 90-110R, 91 deg incl, 60 fph, Drilled to 14,000'. 12:10 - 13:30 1.33 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 13:30 - 14:15 0.75 DRILL P PROD1 Log GR tie-in at window. Added 10' to CTD. 14:15 - 15:00 0.75 DRILL P PROD1 RIH clean to bottom. 15:00 - 16:30 1.50 DRILL P PROD1 Drilling lateral, 1.5 bpm, 3300 psi, 90-110R, 91 deg incl, 60 fph, 24.5K up wt, 7.5K down wt. Drilled to 14,072'. 16:30 - 16:50 0.33 DRILL P PROD1 Orient TF to 90R. 16:50 - 18:20 1.50 DRILL P PROD1 Drilling lateral, 1.5 bpm, 3300 psi, 90-120R, 90 deg incl, 60 fph, Drilled to 14,157'. 18:20 - 20:45 2.42 DRILL P PROD1 Wiper trip clean to window. RBIH clean to btm. Up wt = 25k. Run-in wt = 8k. IAP = 450psi, OAP = 370psi, PVT = 288bb1s. 20:45 - 20:55 0.17 DRILL P PROD1 Orient TF to 120R. 20:55 - 21:15 0.33 DRILL P PROD1 Drill to 14185' with 125-145R TF, 1.5/1.5bpm, 3250/3850psi, 5.5k WOB & 75fph ave ROP. 21:15 - 21:40 0.42 DRILL P PROD1 Orient TF around to 90R. Meanwhile swap well to fresh 9.6ppg flopro mud with 3% KCL, 3% L-T & 10ppb K-G. 21:40 - 21:50 0.17 DRILL P PROD1 Shoot off-btm survey. 21:50 - 22:30 0.67 DRILL P PROD1 Orient & drill to 14224' with 80-90R TF, 1.5/1.5bpm, 3375/3625psi, 3k WOB & 65fph ave ROP. 22:30 - 00:00 1.50 DRILL P PROD1 Orient & drill to 14300' with 95-120R TF, 1.55/1.55bpm, 3375/3825psi, 4k WOB & 60fph ave ROP. 4/7/2006 00:00 - 02:40 2.67 DRILL P PROD1 Wiper trip clean to window. RBIH clean to btm. Up wt = 25k. Run-in wt = 5k. IAP = 370psi, OAP = 290psi, PVT = 301 bbls. 02:40 - 03:20 0.67 DRILL P PROD1 Orient & drill to 14320' with 95-105R TF, 1.55/1.55bpm, 3350/3600psi, 2k WOB & 35fph ave ROP. 03:20 - 05:45 2.42 DRILL P PROD1 Orient & drill to 14450' with 95-115R TF, 1.55/1.55bpm, 3350/3600psi, 3k WOB & 65fph ave ROP. 05:45 - 07:30 1.75 DRILL P PROD1 Wiper trip to window. 07:30 - 08:00 0.50 DRILL P PROD1 Log GR tie-in at window. Added 11 ft to CTD. Printed: 4/17/2006 11:01:40 AM • • BP EXPLORATION Page 7 of 14 Operations Summary Report Legal Well Name: NK-61 Common Well Name: NK-61 Spud Date: 6/28/1998 Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006 Rig Name: NORDIC 1 Rig Number: Date From. - To Hours Task Code NPT Phase Description of Operations 4/7/2006 08:00 - 08:40 0.67 DRILL P PROD1 RIH clean to bottom. Tag bottom at 14,457'. 08:40 - 09:00 0.33 DRILL P PROD1 Orient TF to left side. 09:00 - 10:00 1.00 DRILL P PROD1 Drilling lateral, 1.5/1.5 bpm, 3300/3700 psi, 60L, 93 deg incl, 80 fph. Stacking weight. Order LubeTex. FloPro at 3% LT, will use 4%. Drilled to 14,513'. 10:00 - 10:20 0.33 DRILL P PROD1 Orient around to 90L. 10:20 - 11:30 1.17 DRILL P PROD1 Drilling lateral, 1.5/1.5 bpm, 3300/3800 psi, 100L, 92 deg incl, 80 fph. Stacking weight. Drilling with -1 K to -7K# inj wt, stacking full coil weight, but drilling at 80-100 fph. Reactive torque jumped to 180 deg while drilling at 14,576'. Possible fault. No fluid loss. Drilled to 14580'. 11:30 - 12:00 0.50 DRILL P PROD1 Orient TF. 26K up wt. 1.5 bpm, 3350 psi free spin. Made 500' wiper trip, clean hole and pickup wt. Down wt = 3K. 12:00 - 12:50 0.83 DRILL P PROD1 Drilling lateral, 1.5/1.5 bpm, 3350/3800 psi, 50L, 92 deg incl, 90 fph. Stacking full weight, -2K inj wt, Drilled to 14,625'. 12:50 - 17:00 4.17 DRILL P PROD1 POH to pick up 2-1/16" CSH workstring, vibrator and C/O MWD probe. 26K up wt off bottom. Full returns to surface. Flow check, no flow. 17:00 - 17:45 0.75 DRILL P PROD1 L/O BHA. Check bit and motor. Both are still good. Bit has no wear or chips. 17:45 - 18:30 0.75 BOPSU P PROD1 Function test BOPE. Crew change. 18:30 - 18:45 0.25 DRILL P PROD1 Held PJSM for P/U drilling BHA with 25jts of 2-1/16" CSH. 18:45 - 20:45 2.00 DRILL P PROD1 M/U & lock-tite lateral drilling BHA #9 with same used Hughes 2.7" x 3" DOSTRWD bicenter bit #8, same 0.8deg X-treme motor, same Sperry GR/MWD probe with new batteries, same orienter, 25jts of 2-1/16" CSH & Baker MHA. Scribe tools & M/U injector. 20:45 - 23:00 2.25 DRILL P PROD1 RIH lateral drilling BHA #9. SHT tools with 1.45bpm/3700psi OK. RIH clean thru window to 11835'. 23:00 - 23:15 0.25 DRILL P PROD1 Log up GR with 1.40bpm/3950psi & tie into GR marker @ 11798'. Subtract 8.5' from CTD. 23:15 - 00:00 0.75 DRILL P PROD1 Continue RIH drilling BHA #9. 4/8/2006 00:00 - 00:30 0.50 DRILL P PROD1 RIH clean to btm tagged @ 14624'. Up wt = 25k. Run-in wt = 9k. IAP = 270psi, OAP = 200psi, PVT = 277bb1s. Freespin = 1.33bpm/4050psi. 00:30 - 01:30 1.00 DRILL P PROD1 Orient TF 2x to 90L. Tag btm & observe 180degs reactive. PUH & ease back in on btm. TF jumping all over the dial. 01:30 - 01:45 0.25 DRILL P PROD1 Drill to 14628' with unsteady TF, 1.35/1.35bpm, 4050/4150psi, Ok WOB & 9k CT wt. 01:45 - 02:00 0.25 DRILL P PROD1 Orient TF to 154L. 02:00 - 03:15 1.25 DRILL P PROD1 Drill with unsteady TF @ 1.35/1.35bpm, 4050/4150psi, Ok WOB & 9k CT wt. PUH & TF stabilize @ 142L. Ease back in hole & work pipe till TF stabilizes @ HS. Continue drilling to 14663' with 30R to HS TF , 1.35/1.35bpm, 4000/4100psi, 2k WOB & 7k CT wt. 03:15 - 03:30 0.25 DRILL P PROD1 PUH & establish TF @ 80L. Observe 10k O/pull @ 14640'. Wipe up hole to 14500'. RBIH to btm. 03:30 - 03:50 0.33 DRILL P PROD1 Drill to 14668' with 120E TF , 1.35/1.35bpm, 4050/4150psi, 2k WOB & 7k CT wt. Printed: 4/17/2006 11:01:40 AM • • BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: NK-61 Common Well Name: NK-61 Spud Date: 6/28/1998 Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006 Rig Name: NORDIC 1 Rig Number: Date From. = To Hours Task Code NPT Phase Description of Operations 4/8/2006 03:50 - 04:25 0.58 DRILL P PROD1 Orient TF -not getting clicks on btm. PUH to 14600' & attempt to orient TF to 90L - no luck. RBIH to btm to drill. 04:25 - 05:15 0.83 DRILL P PROD1 Drill to 14705' with 50-120L TF , 1.35/1.35bpm, 4050/4250psi, i 1 k WOB, 4k CT wt & 55fph ave ROP. 05:15 - 05:45 0.50 DRILL P PROD1 Orient TF to 75L. 05:45 - 05:50 0.08 DRILL P PROD1 Drill to 14712' & TF flop to 150R. Decide to POOH to check orienter. 05:50 - 09:00 3.17 DRILL N DFAL PROD1 POOH lateral BHA #9 to check orienter. i 09:00 - 11:15 2.25 DRILL N DFAL PROD1 Standback CSH workstring in stands. Check bit and motor, 11:15 - 13:15 2.00 DRILL N DFAL PROD1 13:15 - 14:15 1.00 DRILL N DFAL PROD1 14:15 - 15:15 1.00 DRILL P PROD1 15:15 - 16:00 0.75 DRILL P PROD1 16:00 - 16:30 0.50 DRILL P 16:30 - 17:30 1.00 DRILL P 17:30 - 18:15 0.75 DRILL P 18:15 - 18:40 .0.42 DRILL P 18:40 - 18:55 0.25 DRILL N 18:55 - 19:10 0.25 DRILL P 19:10 - 20:10 20:10 - 20:30 1.00 DRILL I P 0.33 DRILL P 20:30 - 20:55 20:55 - 21:05 21:05 - 21:15 21:15 - 21:35 21:35 - 21:45 21:45 - 22:00 22:00 - 23:15 23:15 - 23:30 23:30 - 23:40 0.42 DRILL P 0.17 DRILL P 0.17 DRILL P 0.33 DRILL P 0.17 DRILL P 0.25 DRILL P 1.25 DRILL P 0.25 DRILL I P 0.17 DRILL P PROD1 PROD1 PROD1 PROD1 STUC I PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 both OK. C/O orienter. M/U 12 stds of CSH and new BOT MHA. OAL = 819.81'. RIH with Lateral BHA #10 with 0.8 deg motor, agitator and 2-1/16" CSH workstring. SHT tools, vibrator working very well, 2 for 2 clicks, RIH clean thru SSSV. RIH. RIH clean thru window. RIH to bottom clean, 1.24 bpm, 3720 psi. Tag bottom at 14,730' and correct to 14712' Orient TF to 80L. 7.5K down wt, 28K up wt. Drilling, 1.3 bpm, 3900/4300 psi, 60 fph, can't keep a correct TF. It keeps going to low side. Made several clicks to try and get correct TF. Can' keep a high side TF. Drilled to 14,734'. Made a 400' wiper to reduce torque in coil. RIH clean to bottom. Drilling, 1.3 bpm, 4000 - 4300 psi, 15R, good wt transfer, differential sticking at 14,745', work free, Drilled to 14,765' and TF wrapped to low side again. Orient TF to high side. Short trip 200 ft to get clicks. Drilling, 1.3/ 1.3 bpm, 3900-4400 psi, 55R, 93 deg incl, 60-80 fph, good wt transfer, drilling with 1 K inj wt. Drilled to 14,800', lose motor work. P/U & get diffrentially stuck. Set CT @ neutral wt & S/D pumps for 10mins. Stack down max wt & pull free with 48k. Short 200' wiper. RBIH to btm. Up wt = 26k. Run-in wt = 4k. IAP = 270psi, OAP = 215psi, PVT = 246bb1s. Freespin = 1.35bpm/4100psi. Orient TF to HS. Attempt to drill -get 130degs reactive. Reorient TF again to 90R. Drill to 14822' with 45L-45R TF , 1.35/1.35bpm, 4100/4350psi, 1 k WOB, 2k CT wt & 65fph ave ROP. Orient TF to 150R. Drill to 14838' with 45L-45R TF , 1.35/1.35bpm, 4100/4350psi, 1 k WOB, 2k CT wt & 65fph ave ROP. Short 100' wiper. Drill to 14850' with 85L-HS TF , 1.35/1.35bpm, 4100/4350psi, 1 k WOB, 2k CT wt & 65fph ave ROP. Short 100' wiper. Orient TF to 20R. Drill to 14882' with 85L-HS TF , 1.35/1.35bpm, 4100/4350psi, 1k WOB, 3k CT wt & 50fph ave ROP. Orient TF to 20R. Short 100' wiper. Drill to 14892' with 85L-HS TF , 1.35/1.35bpm, 4100/4350psi, Printed: 4/17/2006 11:01:40 AM ~ • BP EXPLORATION Page 9 of 14 Operations Summary 'Report Legal Well Name: NK-61 Common Well Name: NK-61 Spud Date: 6/28/1998 Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase. Description of Operations 4/8/2006 23:30 - 23:40 0.17 DRILL P PROD1 2k WOB, 2k CT wt & 50fph ave ROP. 23:40 - 23:50 0.17 DRILL P PROD1 Orient TF to 150R. Short 100' wiper. 23:50 - 00:00 0.17 DRILL P PROD1 Drill to 14900' with 150R-40R TF , 1.35/1.35bpm, 4100/4350psi, 2k WOB, Ok CT wt & 50fph ave ROP. 4/9/2006 00:00 - 01:20 1.33 DRILL P PROD1 Wiper trip to window. 01:20 - 02:00 0.67 DRILL P PROD1 Log up GR & tie into GR marker @ 11798'. Add 31.5' to CTD. 02:00 - 03:30 1.50 DRILL P PROD1 RIH clean to btm tagged @ 14927'. Up wt = 24k. Run-in wt = 9k. IAP = 370psi, OAP = 320psi. Freespin = 1.30bpm/3850psi. 03:30 - 03:45 0.25 DRILL P PROD1 Orient TF to 15R. Meanwhile swap well to fresh 9.6ppg flopro mud with 3% KCL, 4% L-T & 10ppb K-G. 03:45 - 05:00 1.25 DRILL P PROD1 Drill to 14961' with 137E TF , 1.35/1.35bpm, 4000/4250psi, Ok WOB, 6k CT wt & 20fph ave ROP. 05:00 - 05:30 0.50 DRILL P PROD1 Orient TF around to 105L. 05:30 - 06:00 0.50 DRILL P PROD1 Orient & drill to 14972' with 105E TF , 1.35/1.35bpm, 4000/4250psi, Ok WOB, 6k CT wt & 20fph ave ROP. 06:00 - 06:30 0.50 DRILL P PROD1 Orient & drill to 14985' with 70-160L TF , 1.35/1.35bpm, 4000/4250psi, Ok WOB, 4k CT wt & 20fph ave ROP. 06:30 - 07:15 0.75 DRILL P PROD1 Orient TF around 07:15 - 08:00 0.75 DRILL P PROD1 Drilling lateral, 1.4 / 1.4 bpm, 4000-4300 psi, 1K WOB, 4K inj wt, 90L, 94 deg incl. Drilled to 15,001'. 08:00 - 09:30 1.50 DRILL P PROD1 Not able to get clicks near bottom, pull up to 14300' and orient. RIH. Orient on bottom. 09:30 - 09:45 0.25 DRILL P PROD1 Drilling, 1.4 / 1.4 bpm, 3900 - 4200 psi, 60-120L, TF works to left, need highside TF, Drilled to 15015'. 09:45 - 10:00 0.25 DRILL P PROD1 Orient TF to high side. Try to get highside TF. Orient R1H and out of hole. Not able to get any clicks. 10:00 - 11:30 1.50 DRILL P PROD1 Make wiper trip to window. Clean hole. 28K up wt. 11:30 - 12:45 1.25 DRILL P PROD1 Try to orient just below window. No clicks. Pull up to 11620'. Orient just below tailpipe. Got 10 deg clicks. Orient to 140R. 12:45 - 13:00 0.25 DRILL P PROD1 Log GR tie-in at window. Added 15' CTD. New Bottom calculates to 15,030'. 13:00 - 15:00 2.00 DRILL N DFAL PROD1 Not able to orient, talked to town GEO, POH and C/O BHA. 15:00 - 17:45 2.75 DRILL N DFAL PROD1 C/O BHA. Stand back CSH in doubles. L/O MWD probe and motor, Bit was still in new condition. Cut off 10' of coil, found flat spot on coil 2' above CTC. Weld on new CTC. Pull /Press test CTC. 17:45 - 18:45 1.00 DRILL X DFAL PROD1 M/U re-run BC Bit #M/U 0.8 deg motor and scribe with MWD collar, M/U Sperry MWD and orienter. 18:45 - 20:45 2.00 DRILL X DFAL PROD1 RIH Lateral BHA #11 with 0.8 deg motor, agitator & 2-1/16" CSH workstring. SHT tools - OK. RIH to below the window. 20:45 - 21:05 0.33 DRILL X DFAL PROD1 Log up GR & tie into GR marker @ 11798'. Subtract 9' from CTD. 21:05 - 22:40 1.58 DRILL C PROD1 RIH clean to btm tagged @ 15027'. Up wt = 28k. Run-in wt = 4k. IAP = 200psi, OAP = 140psi. Freespin = 1.40bpm/3850psi. 22:40 - 23:00 0.33 DRILL C PROD1 Orient TF around to 40L. 23:00 - 00:00 1.00 DRILL C PROD1 Orient & drill to 15062' with 40-10L TF , 1.40/1.40bpm, 3850/4250psi, Ok WOB, 4-6k CT wt & 45fph ave ROP. 4/10/2006 00:00 - 02:30 2.50 DRILL C PROD1 Orient & drill to 15095' with 25L-40R TF , 1.40/1.40bpm, 4050/4350psi, Ok WOB, 4-6k CT wt & 15fph ave ROP. Drilling very ratty. 02:30 - 02:40 0.17 DRILL C PROD1 Orient TF around to 65L. Printed: 4/17/2006 11:01:40 AM • • BP EXPLORATION Page 10 Qf 14 Operations Sumlmairy Report Legal Well Name: NK-61 Common Well Name: NK-61 Spud Date: 6/28/1998 Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006 Rig Name: NORDIC 1 Rig Number: ..Date from - To Hours Task Code NPT Phase 4/10/2006 02:40 - 05:00 2.33 DRILL C PROD1 05:00 - 05:30 0.50 DRILL C 05:30 - 07:30 2.00 DRILL C 07:30 - 08:15 I 0.751 DRILL I C 08:15 - 10:30 2.25 DRILL C 10:30 - 12:15 1.75 DRILL C 12:15 - 12:30 I 0.251 EVAL I P 12:30 - 14:10 I 1.671 EVAL I P 14:10 - 16:00 I 1.831 EVAL I P 16:00 - 17:50 I 1.831 EVAL I P 17:50 - 18:15 I 0.421 EVAL I P 18:15 - 20:10 I 1.921 EVAL I P 20:10 - 22:00 I 1.831 EVAL I P 22:00 - 22:15 0.25 EVAL P 22:15 - 00:00 1.75 EVAL P 14/11/2006 100:00 - 01:00 I 1.001 CASE I P 01:00 - 01:15 0.25 CASE P 01:15 - 01:30 0.25 CASE P 01:30 - 05:30 4.00 CASE P 05:30 - 07:10 1.67 CASE P PROD1 PROD1 Description of Operations Orient & drill to 15109' with 65L-HS TF , 1.40/1.40bpm, 4050/4350psi, 3k WOB, 4-6k CT wt. Geo seeing up to 1 pyrite & glauconite. Orient TF around to 65L. Orient & drill to 15114' with 65L-HS TF , 1.40/1.40bpm, 4050/4350psi, 4k WOB, 4-6k CT wt. Geo confirms we've penetrated the HRZ & called TD. Have set new overbalanced CTD world record for maximum step-out footage of 3,310'. PROD1 Log GR tie-in at window. Added 9 ft to CTD. Adjust TD to 15,120'. PROD1 POH for PDS memory RES / GR /CCL log. PROD1 Standback CSH workstring, Lay out MWD BHA. Bit had 2 chipped cutters. PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for running PDS memory logging tools on CSH workstring. PROD1 M/U PDS Memory RES / GR /CCL logging tools, BOT MHA and 25 jts, 2-1/16" CSH workstring and CTC. OAL = 780.61 PROD1 RIH with logging BHA. Circ. at 0.7 bpm, 1300 psi. Stop at 11,500 ft for 2 min. PROD1 Log down at 2000 FPH with PDS Memory RES / GR /CCL Logging tools. Circ at 0.6 bpm, 1600 psi. Dwn wt at window = 17.5K, Dwn wt at 12,500' = 12.OK, Circ. 0.6 bpm at 1600 psi Dwn Wt at 14,500' = 9K Dwn Wt at 15,000' = 5K. Tagged TD at 15,134', uncorrected depth. RIH clean to TD, do not need a cleanout run. PROD1 Circ.32 bbls New FloPro with 3.1 PPB Alpine Large Beads to circ. sub at top of logging tools. Circ. at 1.5 bpm at 2720 psi with full returns. Up wt = 26K, PROD1 Tag TD again at 15,132'. Log up at 2000 FPH while lay in New FloPro with Alpine beads at 0.5 bpm. PROD1 Park @ 11500' for 2mins. Paint EOP flags @ 10719' & 8200' & POOH with logging tools BHA. PROD1 Held PJSM for L/D logging BHA. PROD1 S/B injector & L/D 2-1/16" CSH in singles. L/D logging tools. Load out 2-1/16" CSH. Download resistivity data. Tagged TD @ +/-15120' (corrected). RUNPRD M/U dart catcher. Load wiper dart, launch/chase dart with mud & pig CT. Dart bumped on catcher @ 39.6bbls. RUNPRD R/U to run liner. Confirm CTC ID is > 1.05". RUNPRD Held PJSM for M/U &RIH with 2-3/8" completion liner. RUNPRD M/U 2-3/8" STL indexing guide shoe, float collar, 1 shoe jt, float collar, spacer pup & landing collar. M/U & drift 1st 5jts of 2-3/8" STL 4.7# L-80 liner. Continue M/U 97jts of 2-3/8" liner. M/U one 10' pup jt, 12 jts of 2-3/8" liner & one 10' pup. M/U Baker deployment sub & LBRT. M/U CTC. OAL = 3543.71'. RUNPRD RIH with liner circ @ min rate. 0.46 bpm, 1820 psi. Stop at EOP flag at 8500' and correct -10' to 11,748' CTD. Printed: 4/17/2006 11:01:40 AM • • BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: NK-61 Common Well Name: NK-61 Spud Date: 6/28/1998 Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006 Rig Name: NORDIC 1 Rig Number: Date. FI•om - To Hours Task.. Code NPT Phase. Description of Operations 4/11/2006 05:30 - 07:10 1.67 CASE P RUNPRD Up Wt = 32K, pumping 0.5 bpm. Reviewed PDS Memory log TD tag, tied-in at window. This is our best TD control. The TD measured at 15,125'. Adjust TD depths to 15,125'. 07:10 - 09:30 2.33 CASE P RUNPRD RIH thru window clean. RIH at 40 fpm, 0.2 bpm, 1500 psi. 13000', Dwn Wt = 11K, 14000', Dwn Wt = 8K, 14500', Dwn Wt = 5K, UP Wt = 34K SWS computer locked up while RIH. Reset computer and pull up to deeper flag and correct CTD to flag depth of 14,267'. RIH at 30 fpm. Set down at 14790'. with pump at 0.2 bpm. Stop pump and RIH with 2K down wt. 1 K at 14,900'. -7K at 15010', set down at 15016'. -9K. Work pipe down at 10 fpm, Set down at 15,040'. Set down several times at 15,040'. Calculate depth based on mechanical counter at reel. Depth = 15,130'. We corrected to the wrong lower flag or flag was off depth. Liner is at TD, we set down at same depth several times and mechanical depth indicates liner is at TD. 09:30 - 10:30 1.00 CASE P RUNPRD Insert 5/8" ball and displace with FloPro. 0.9 bpm, 2650 psi. Siow pump to 0.3 bpm at 25 bbls. Ball on seat at 29.9 bbls. Sheared at 4100 psi. Circ. 0.8 bpm at 2550 psi. Pick up free from liner at 22K up wt. Top of liner at 11,571'. Liner Guide Shoe at TD at 15,125'. 10:30 - 13:00 2.50 CASE P RUNPRD Circ. well to 9.6 KCL/CaCL brine, 1.66 bpm, 3560 psi, full returns. Clean rig pits. Send used FloPro to MI mud plant. Mix 30 bbls 2# Biozan in pill pit. 13:00 - 13:15 0.25 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pumping cement with SWS. Meanwhile continue circulating flopro down the CT @ 1.25bpm/1400psi. 13:15 - 15:00 1.75 CEMT P RUNPRD Batch mix 18bbls 15.8ppg 'G' expansive cmt with additives. Cmt to wt @ 13:30hrs. Flush/PT lines to 4k. Pump 18bbls cmt slurry @ 1.5bpm/3150psi. Close inner reel valve & clean lines. Load/launch CTWP with 500psi. Chase with 30bbls bio-KCL @ 1.47/1.35bpm & 2500psi. CTWP engage LWP @ 40.2bbls away. Attempt to shear plug & pumps trip out @ 4300psi. Reset pumps & continue pumping @ 1.18/0.94bpm & 4300psi -- seems like we've already sheared the LWP? Continue displacing cement @ 1.18/0.94bpm & 4250psi & did not see any pressure bump after pumping 53.1bbls away. Stop pumping at 53.2bbls total displacement. Sting out of liner & CTP bleeds off. Had a total of 14.6bbls of cement around shoe. CIP @ 15:OOhrs. 15:00 - 17:15 2.25 CEMT P RUNPRD Circ 1bb1 of bio-KCL @ 0.5bpm on TOL. S/D pumps & check floats - no backflow. POOH @ 100fpm, pumping @ 0.4bpm replacing CT voidage only. 17:15 - 17:45 0.50 CEMT P RUNPRD OOH. PJSM. UD LBRT -everything looks good &LWP was Printed: 4/17/2006 11:01:40 AM • • $P `EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Name: NK-61 Common Well Name: NK-61 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Spud Date: 6/28/1998 Start: 3/28/2006 End: 4/14/2006 Rig Release: 4/14/2006 Rig Number: Date From - To (Hours.) .Task I Code I NPT .Phase Description of Operations 4/11/2006 17:15 - 17:45 0.50 CEMT P 17:45 - 18:00 0.25 CEMT P 18:00 - 18:15 0.25 CLEAN P 18:15 - 23:00 4.75 CLEAN P 4/12/2006 102.50 - 05.30 I 2.67 ~ CLEAN 1 P 05:30 - 07:15 I 1.751 CLEAN I P 07:15 - 08:30 1.25 CLEAN I N 08:30 - 09:30 1.00 CLEAN P 09:30 - 10:00 I 0.501 CLEAN I P 10:00 - 10:15 0.25 CLEAN ( P 10:15 - 12:15 2.00 CLEAN P 12:15 - 12:45 0.50 CLEAN P 12:45 - 13:00 0.25 EVAL P 13:00 - 13:15 0.25 EVAL P 13:15 - 15:15 2.00 EVAL P 15:15 - 16:50 I 1.58 ~ EVAL I P 16:50 - 19:30 2.67 EVAL P 19:30 - 20:30 1.00 EVAL P 20:30 - 21:50 1.33 EVAL P 21:50 - 00:00 2.17 EVAL P 14/13/2006 100:00 - 05:15 I 5.251 BOPSURP 05:15 - 06:00 0.75 EVAL P 06:00 - 06:30 0.50 PERFO P 06:30 - 06:45 I 0.25 PERFOB~ P 06:45 - 08:00 1.25 PERFO P RUNPRD sheared. RUNPRD R/U to P/U cleanout mill/motor & 1" CHS tbg. RUNPRD PJSM on P/U &RIH cleanout BHA. RUNPRD M/U cleanout BHA #14 with 1.875" mill, 1-11/16" straight motor, lower MHA, PU, RIH w/ 38 jts of 1" CSH, RIH w/ 42 Stds of 1"CSH tbg & upper MHA. M/U injector. BHA length = 3762' RUNPRD RIH w/ BHA to 8823' RUNPRD Wait on Cement UCA results of 500 psi compressive strength RUNPRD RIH to PBTD at 15086' w/ .97 bpm, 3400 psi, cement contaminated returns w/ MW out 10.1 ppg, well cleaned up w/ MW in/out of 9.6 ppg RUNPRD POOH to 11800' circ out & dumping cement contaminated fluid. WAIT RUNPRD W. O. additional 9.6ppg KCL/NaCL to arrive onsite. RUNPRD Paint EOP flag @ 7700' & continue POOH circ wellbore to clean 9.6ppg brine. RUNPRD OOH. S/B injector. Drop 1/2" ball & open up circ sub to drain 1 "CSH. RUNPRD PJSM for R/B CSH & L/D motor/mill. RUNPRD R/B 61 stands of 1"CSH & L/D cleanout motor/mill. RUNPRD M/U swizzle stick. Stab on injector & jet BOP stack. Flush surface lines. S/B injector & UD swizzle stick. LOWER1 PJSM on P/U &RIH MGR/CCL logging tools & 1"CHS tbg. LOWER1 Initialize & test logging tools. P/U tool into rig floor. LOWER1 M/U logging BHA #15 with SWS MGR/CCL logging tool, lower MHA, XO, 61stds of 1" CSH tbg, XO & upper MHA. M/U injector. LOWER1 RIH with logging BHA to 11300'. LOWERI Log down @ 30fpm from 11300' - 15086' PBTD. Start pumping down 150kcps Flo-Pro pert pill. LOWER1 Log up at 60 fpm f/ 15086' to 11300' LOWER1 POH to BHA, flagged EOP at 7500' LOWER1 POH w/ BHA, Std Back 1" CSH, L/D logging tools, cleared floor. Download log data & fax to ANC. From log data, TOL = 11574' &PBTD = 15076'. LOWERI PJSM on testing BOP's, RU test equipment, greased tree, Test BOP's as per AOGCC reg's, witnessed waived by John Spaulding w/ AOGCC. Tested inner reel valve and lines. LOWER1 Test Liner lap using 9.6 ppg brine to 2100 psi lost 95 psi in first 15 min, lost 33 psi in last 15 min .Lost 128 psi over 30 minutes allowed 206 psi Passed. ISIP = 2069 psi 5 min = 2010 psi 10 min = 1989 psi 15 min = 1974 psi 20 min = 1960 psi 25 min = 1948 psi 30 min = 1941 psi LOWER1 Load pert guns into pipe shed. R/U safety jt & prep to M/U perf guns. Drift MHAs with 1/2" ball - OK. LOWER1 PJSM on perforation job. LOWER1 M/U 23jts of 1.56" HSD 6spf 1606PJ guns & blanks with BCF Printed: 4/17/2006 11:01:40 AM • • BP EXPLORATION. Page 13 of 14 Operations Summary Report _~ _~_. i Legal Well Name: NK-61 Common Well Name: NK-61 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours Task Code NPT ~ Phase ~ 4/13/2006 06:45 - 08:00 1.25 PERFO P 08:00 - 08:15 0.25 PERFO P 08:15 - 09:30 1.25 PERFO P 09:30 - 11:50 I 2.331 PERFOBI P 11:50 - 12:00 i 0.17J PERFOBI P 12:00 - 13:00 I 1.001 PERFOBI P 13:00 - 14:00 I 1.001 PERFO~ P 14:105 - 15:15 0.001 PERFO~ P 15:15 - 15:45 I 0.501 PERFOBI P 15:45 - 17:15 i 1.501 PERFO~ P 17:15 - 17:30 0.25 PERFO P 17:30 - 17:45 0.25 PERFO P 17:45 - 19:15 1.50 PERFO P 19:15 - 19:30 0.25 PERFO P 19:30 - 19:45 0.25 PERFO P 19:45 - 21:15 1.50 PERFO P 21:15 - 23:30 i 2.251 PERFOBI P 23:30 - 00:00 I 0.501 PERFO~ P 14/14/2006 100:00 - 00:20 I 0.331 PERFOBI P 00:20 - 01:00 I 0.671 PERFOBI P 01:00 - 01:15 0.25 PERFO P 01:15 - 03:40 2.42 PERFO P 02:55 - 03:25 0.50 PERFO P 03:25 - 05:20 1.92 PERFO P Spud Date: 6/28/1998 Start: 3/28/2006 End: 4/14/2006 Rig Release: 4/14/2006 Rig Number: Description of Operations l LOWER1 firing system. LOWER1 Held PJSM for P/U 1"CSH. LOWER1 M/U lower disconnect, 51 stds of 1" CSH tbg & upper MHA. M/U injector. LOWER1 RIH with perforating BHA#16 circ 5bbls of perf pill ahead @ min rate. Subtract 11' @ EOP flag. Wt check @ 11500' _ 25.3k. RIH into Inr @ 50fpm & tag PBTD @ 15094'. Pull to P/U wt & correct CTD to 15076' (PBTD as per MGR/CCL log). LOWER1 PUH to ball drop postion @ 14892'. Meanwhile R/U sonogram detector to the wellhead for shot detection. l_OWER1 Load 1/2" AL ball. Blow ball into CT with 5bbls pert pill behind. Position guns for btm shot @ 14890'. Chase ball @ 0.95bpm/2950psi. Slow to 0.46bpm/860psi @ 30bbts. Ball on seat after 41.9bbls away. RBIH to 14895'. PUH very slowly & ramp up to 3500psi with btm shot @ 14890'. Observe guns fire with good pressure drop indication & sonogram detection. Perforated interval = 14420' - 14540', 14570' - 14680', 14740' - 14800', 14830-14890'. LOWER1 POOH with pert gun BHA @ 35fpm pumping down the CT @ 0.58bpm/930psi. Paint EOP flag @ 10500' (for next pert run) & POOH to 11500'. LOWER1 S/D pump &flowcheck well for 15 mins -well stable. LOWER1 POOH with pert gun BHA @ 60fpm pumping down the CT @ 0.5bpm & 800psi. LOWERI OOH. S/D pump &flowcheck well for 30 mins -well stable. Meanwhile held PJSM for L/D & R/B 1" CSH. LOWER1 S/B injector. L/D MHAs & 44 jts of 1" CSH tbg. R/B 29 stds of 1"CSH tbg. LOWER1 R/U to L/D perf guns. LOWER1 PJSM for L/D perf guns. LOWER1 L/D 23jts of pert guns & blanks. ASF! LOWER1 PJSM for handling perforating guns, blanks and 1" CSH. LOWER1 PU 5 jts of 1.56" 6SPF 1606PJ guns and blanks. LOWER1 RIH w/ 39 stands of 1-1 /4" CSH. Overall BHA length = 2510.63' LOWER1 RIH to 13010.6', correct CTD to EOP flag at 10500', continue RIH with perforating assy to 13860.7', pump 5 bbls pert pill, Wt check @ 11545', Up Wt - 25.2k LOWER1 Load & launch 1/2" AL ball w/ 6 bbls of pert pill followed by 9.6 ppg brine, position btm shot @ 13860'. Chase ball @ 1.4 bpm, 3650 psi. Slow to 0.44bpm/550psi @ 30 bbls. LOWERI Circ 1/2" AL ball at .44bpm 550psi. Ball on seat after 39.2 bbls away. S/D pumps &RBIH to 13860.7'. PUH very slowly & ramp up to 2800psi with btm shot @ 13860'. Observe guns fire with good pressure drop indication & sonogram detection. Perforated interval = 13770' - 13860' LOWER1 POH with pert gun assy @ 58 fpm pumping down the CT @ .73 bpm & 1100 psi. POOH to 11500'. LOWER1 Flow check well, stable LOWER1 POH to BHA LOWER1 Flow Check well, monitor for 30 min, well stable LOWER1 Breakdown MHA, std bk injector, RU handling tools, held PJSM on handling procedures for 1" CSH, LD 78 jts of 1"CSH. Printed: 4/17/2006 11:01:40 AM • • BP EXPLORATION Page 14 of 14 Operations Sullnmary Report Legal Well Name: NK-61 Common Well Name: NK-61 Spud Date: 6/28/1998 Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006 Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006 Rig Name: NORDIC 1 Rig Number: Date From - To Holars Task Code NPT Phase Description of Operations 4/14/2006 05:20 - 06:15 0.92 PERFO P LOWER1 R/U to L/D perf guns, PJSM for LD perf guns, L/D 5 jts of pert guns & blanks, alt shots fired 06:15 - 07:00 0.75 PERFO P LOWER1 Load out spent perf guns out of pipe shed. 07:00 - 07:15 0.25 RIGD P POST M/U FP nozzle BHA. M/U injector. 07:15 - 08:30 1.25 RIGD P POST RIH nozzle BHA to 2500'. Pump down 17bbls of McOH to nozzle. POOH freeze protecting with 60/40 McOH. FP from 300' with 100% McOH. SI master & swab valves (23-1/2 turns each). 08:30 - 08:45 0.25 RIGD P POST PJSM for pickling ~ B/D CT with N2. 08:45 - 09:30 0.75 RIGD P POST Pump 15bbls of bleach, 60bbls of fresh water, 15bbls of corrosion inhibitor & 5bbls of McOH. 09:30 - 09:45 0.25 RIGD P POST P/T N2 lines - OK. 09:45 - 11:00 1.25 RIGD P POST Blow down CT with N2 & bleed off. Meanwhile clean out pits & tanks. UD nozzle BHA. 11:00 - 11:30 0.50 RIGD P POST Load excess tubulars out of pipe shed. 11:30 - 11:45 0.25 RIGD P POST PJSM for stripping off & pulling back CT to the reel. 11:45 - 13:30 1.75 RIGD P POST P/U injector. Slip grapple connector into CT & pull test. Strip-off CT from injector & spool back to reel. Secure CT & prep reel for shipment. S/B injector. 13:30 - 13:45 0.25 RIGD P POST PJSM for C/O BOP rams & N/D 80PE. 13:45 - 16:00 2.25 RIGD P POST Changeout ram blocks to 2-3/8" pipe/slips & 2-3/8" - 3-1/2" VBR. 16:00 - 16:30 0.50 RIGD P POST P/U injector & changeout stripper packoffs & brass. 16:30 - 18:00 1.50 RIGD P POST PJSM. N/D BOPE. N/U tree cap & P/Test. Release rig @ 18:00 on 4/14/06. Printed: 4/17/2006 11:01:40 AM Halhburton Company Survey Report Company: BP Amoco Date: 5/12/2006 Time: 13:38:12 Page: I Field: Niakuk Coordinate(\E) Aeferencc: Well: NK-61, True North j Site: NK Main Pad Vertical (TVD) Reference: 43:61 6/15/1 998 15:00 60.2 '~ ~~ c1I: NK-61 Section (VS) Reference: Well (O.OON,O .OOE,328.12Azi) ~t ellpath: NK-61A Survey Calculation Method: Minimum Curvature Db: Oracle Field: Niakuk North Slope UNITED STATES Map System:US State Pl ane Coord inate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: NK-61 Slot Name: NK-61 Well Position: +N/-S -1539.35 ft Northing: 5979921.48 ft Latitude: 70 20 50.707 N +E/- W 7066.53 ft Easting : 721660.64 ft Longitude: 148 12 1.497 W Position Uncertainty: 0.00 ft Wellpath: NK-61A Drilled From: NK-61 500292289301 Tie-on Depth: 11800.00 ft Current Datum: 43: 61 6/15/1998 15:00 Height 60.20 ft Above System Datum: Mean Sea Level Magnetic Data: 3/3/2006 Declination: 24.85 deg Field Strength: 57629 nT Mag Dip Angle: 80.98 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.70 0.00 0.00 328.12 Survey Program for Definitive Wellpath Date: 3/3/2006 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 100.00 11800.00 5 : Gyrodata cont.drillpipe m/ GYD-CT-DMS Gyrodata cont.drillpipe m/s 11802.00 15095.85 MWD (11802.00-1 5095.85) MWD MWD -Standard Survey MD Incl Azim TVD SysT1~D ~;j E/W MapA' MapE Tool ft deg deg ft ft tt ft ft ft 40.70 0.00 0.00 40.70 -19.50 0.00 0.00 5979921.48 721660.64 TIE LINE 100.00 0.31 86.65 100.00 39.80 0.01 0.16 5979921.49 721660.80 GYD-CT-DMS 200.00 0.53 74.00 200.00 139.80 0.15 0.88 5979921.66 721661.51 GYD-CT-DMS 300.00 0.55 39.47 299.99 239.79 0.65 1.63 5979922.18 721662.25 GYD-CT-DMS 400.00 0.63 358.14 399.99 339.79 1.57 1.92 5979923.11 721662.51 GYD-CT-DMS 500.00 1.30 334.23 499.97 439.77 3.15 1.40 5979924.67 721661.95 GYD-CT-DMS 600.00 2.84 330.62 599.91 539.71 6.33 -0.30 5979927.80 721660.15 GYD-CT-DMS 700.00 4.98 333.32 699.67 639.47 12.36 -3.47 5979933.73 721656.81 GYD-CT-DMS 800.00 7.16 328.28 799.10 738.90 21.54 -8.69 5979942.76 721651.31 GYD-CT-DMS 900.00 8.38 327.93 898.18 837.98 33.02 -15.84 5979954.02 721643.83 GYD-CT-DMS 1000.00 10.19 332.54 996.87 936.67 47.05 -23.79 5979967.81 721635.46 GYD-CT-DMS 1100.00 12.12 335.07 1094.97 1034.77 64.42 -32.30 5979984.92 721626.45 GYD-CT-DMS 1201.00 13.51 335.92 1193.46 1133.26 84.81 -41.58 5980005.02 721616.57 GYD-CT-DMS 1250.00 13.91 337.16 1241.06 1180.86 95.46 -46.20 5980015.53 721611.64 GYD-CT-DMS 1300.00 14.39 336.64 1289.54 1229.34 106.70 -51.00 5980026.62 721606.51 GYD-CT-DMS 1350.00 14.62 336.71 1337.95 1277.75 118.20 -55.95 5980037.97 721601.21 GYD-CT-DMS 1400.00 14.88 336.42 1386.30 1326.10 129.88 -61.02 5980049.49 721595.81 GYD-CT-DMS 1450.00 15.03 336.23 1434.61 1374.41 141.70 -66.20 5980061.15 721590.28 GYD-CT-DMS 1500.00 15.07 336.35 1482.89 1422.69 153.59 -71.42 5980072.88 721584.71 GYD-CT-DMS 1550.00 15.08 336.18 1531.17 1470.97 165.49 -76.65 5980084.63 721579.13 GYD-CT-DMS 1600.00 15.18 336.14 1579.44 1519.24 177.43 -81.93 5980096.40 721573.50 GYD-CT-DMS 1650.00 15.42 336.10 1627.67 1567.47 189.49 -87.27 5980108.30 721567.81 GYD-CT-DMS 1700.00 15.82 336.17 1675.82 1615.62 201.80 -92.71 5980120.44 721562.00 GYD-CT-DMS 1750.00 16.42 335.97 1723.85 1663.65 214.49 -98.34 5980132.96 721556.00 GYD-CT-DMS 1800.00 17.07 336.31 1771.73 1711.53 227.67 -104.17 5980145.96 721549.78 GYD-CT-DMS 1850.00 18.31 337.07 1819.37 1759.17 241.62 -110.18 5980159.73 721543.36 GYD-CT-DMS 1900.00 19.52 337.92 1866.67 1806.47 256.59 -116.38 5980174.51 721536.72 GYD-CT-DMS 1950.00 20.31 338.31 1913.68 1853.48 272.40 -122.73 5980190.12 721529.91 GYD-CT-DMS 2000.00 20,90 338.19 1960.48 1900.28 288.74 -129.25 5980206.26 721522.91 GYD-CT-DMS Halliburton Com an P Y Survey Report Company: BP Amoco Date: 5/12/2006 Ti me: 13:38:12 Page: 2 ~ Field: Nia kuk Co-ordinate(N E) Reference: VVeII: NK-61, True North Site: NK Main Pad Vertical (TVD ) Reference: 43:61 6/15/ 1998 15:00 60.2 Well: NK -61 Section (VS) R eference: WeII (O.OON,O.OOE,328.12Azi) Wellpath: NK -61A Surrev Calculation Method: Minimum Curvature Db: Oracle Su r~ e~ ~ MD Incl Azim "1"Vp SvsTVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft ~ 2050.00 21.99 337.43 2007.02 1946.82 305.67 -136.16 5980222.98 721515.51 GYD-CT-DMS 2100.00 22.48 337.03 2053.30 1993.10 323.12 -143.48 5980240.20 721507.67 GYD-CT-DMS 2150.00 22.78 335.66 2099.45 2039.25 340.74 -151.20 5980257.58 721499.43 GYD-CT-DMS 2200.00 23.05 334.76 2145.50 2085.30 358.41 -159.36 5980275.01 721490.75 GYD-CT-DMS 2250.00 23.10 331.77 2191.50 2131.30 375.91 -168.18 5980292.23 721481.42 GYD-CT-DMS 2300.00 23.07 329.85 2237.50 2177.30 393.02 -177.74 5980309.06 721471.36 GYD-CT-DMS 2350.00 23.65 328.55 2283.40 2223.20 410.05 -187.89 5980325.78 721460.71 GYD-CT-DMS 2400.00 23.99 328.24 2329.14 2268.94 427.25 -198.47 5980342.65 721449.62 GYD-CT-DMS 2450.00 25.48 327.36 2374.55 2314.35 444.95 -209.62 5980360.01 721437.95 GYD-CT-DMS 2500.00 26.65 327.27 2419.47 2359.27 463.44 -221.49 5980378.15 721425.55 GYD-CT-DMS 2550.00 28.01 327.96 2463.88 2403.68 482.83 -233.78 5980397.16 721412.69 GYD-CT-DMS 2600.00 29.03 328.64 2507.82 2447.62 503.14 -246.32 5980417.09 721399.55 GYD-CT-DMS 2650.00 30.69 329.36 2551.18 2490.98 524.48 -259.14 5980438.04 721386.11 GYD-CT-DMS 2700.00 31.73 329.45 2593.94 2533.74 546.78 -272.33 5980459.94 721372.27 GYD-CT-DMS 2750.00 32.58 329.12 2636.27 2576.07 569.66 -285.92 5980482.41 721358.00 GYD-CT-DMS 2800.00 33.74 327.94 2678.12 2617.92 592.98 -300.20 5980505.30 721343.04 GYD-CT-DMS 2850.00 34.66 327.37 2719.48 2659.28 616.73 -315.24 5980528.58 721327.31 GYD-CT-DMS 2900.00 35.81 326.75 2760.32 2700.12 640.93 -330.93 5980552.32 721310.91 GYD-CT-DMS 2950.00 36.71 326.75 2800.63 2740.43 665.67 -347.14 5980576.56 721293.97 GYD-CT-DMS 3000.00 38.06 327.04 2840.36 2780.16 691.10 -363.72 5980601.49 721276.65 GYD-CT-DMS 3050.00 39.29 327.61 2879.40 2819.20 717.39 -380.59 5980627.27 721259.02 GYD-CT-DMS 3100.00 40.90 327.79 2917.65 2857.45 744.61 -397.79 5980653.97 721241.01 GYD-CT-DMS 3150.00 41.70 327.87 2955.21 2895.01 772.55 -415.36 5980681.37 721222.63 GYD-CT-DMS 3200.00 41.73 328.06 2992.53 2932.33 800.75 -433.01 5980709.04 721204.15 GYD-CT-DMS 3250.00 41.67 328.24 3029.86 2969.66 829.01 -450.56 5980736.76 721185.77 GYD-CT-DMS 3300.00 41.58 328.40 3067.24 3007.04 857.27 -468.00 5980764.50 721167.50 GYD-CT-DMS 3350.00 42.65 328.64 3104.33 3044.13 885.87 -485.51 5980792.56 721149.16 GYD-CT-DMS 3400.00 44.45 329.04 3140.56 3080.36 915.35 -503.33 5980821.50 721130.47 GYD-CT-DMS 3450.00 44.64 329.13 3176.20 3116.00 945.44 -521.35 5980851.04 721111.57 GYD-CT-DMS 3500.00 44.43 329.39 3211.84 3151.64 975.58 -539.28 5980880.64 721092.77 GYD-CT-DMS 3550.00 43.79 329.90 3247.74 3187.54 1005.61 -556.86 5980910.14 721074.30 GYD-CT-DMS 3600.00 43.90 330.37 3283.80 3223.60 1035.65 -574.11 5980939.65 721056.17 GYD-CT-DMS 3650.00 44.50 330.74 3319.64 3259.44 1066.00 -591.25 5980969.48 721038.15 GYD-CT-DMS 3700.00 45.10 330.63 3355.12 3294.92 1096.72 -608.50 5980999.68 721020.00 GYD-CT-DMS 3750.00 46.25 328.43 3390.06 3329.86 1127.55 -626.64 5981029.95 721000.95 GYD-CT-DMS 3800.00 46.85 327.78 3424.45 3364.25 1158.36 -645.82 5981060.19 720980.87 GYD-CT-DMS 3850.00 46.62 328.48 3458.71 3398.51 1189.28 -665.04 5981090.52 720960.74 GYD-CT-DMS 3900.00 46.50 329.12 3493.09 3432.89 1220.34 -683.85 5981121.00 720941.03 GYD-CT-DMS 3950.00 46.67 329.71 3527.46 3467.26 1251.60 -702.33 5981151.71 720921.63 GYD-CT-DMS 4000.00 46.37 330.64 3561.86 3501.66 1283.08 -720.38 5981182.63 720902.66 GYD-CT-DMS 4050.00 45.44 331.47 3596.65 3536.45 1314.50 -737.76 5981213.53 720884.36 GYD-CT-DMS 4100.00 45.03 332.12 3631.87 3571.67 1345.78 -754.54 5981244.30 720866.66 GYD-CT-DMS 4150.00 44.69 332.32 3667.30 3607.10 1376.99 -770.98 5981275.00 720849.31 GYD-CT-DMS 4200.00 44.45 332.38 3702.92 3642.72 1408.07 -787.26 5981305.59 720832.11 GYD-CT-DMS 4250.00 44.36 332.27 3738.64 3678.44 1439.05 -803.51 5981336.08 720814.95 GYD-CT-DMS 4300.00 44.52 332.45 3774.34 3714.14 1470.07 -819.75 5981366.59 720797.80 GYD-CT-DMS 4350.00 44.75 332.56 3809.92 3749.72 1501.23 -835.97 5981397.26 720780.67 GYD-CT-DMS 4400.00 44.77 332.61 3845.43 3785.23 1532.48 -852.18 5981428.02 720763.54 GYD-CT-DMS 4450.00 44.88 332.72 3880.89 3820.69 1563.80 -868.36 5981458.84 720746.44 GYD-CT-DMS 4500.00 44.88 332.79 3916.32 3856.12 1595.16 -884.52 5981489.71 720729.37 GYD-CT-DMS 4550.00 44.72 333.53 3951.79 3891.59 1626.60 -900.42 5981520.66 720712.54 GYD-CT-DMS 4600.00 44.35 336.80 3987.44 3927.24 1658.41 -915.15 5981552.03 720696.88 GYD-CT-DMS Halliburton Company Survey Report Company: BP Amoco Field: Niakuk Site: NK Main Pad Well: NK-61 Wellpath: NK-61A Survey Date: 5/12/2006 Time: 13:38:12 Page: 3 Co-ordinate(1VE) Reference: VVeII: NK-61, True North Vertical ('I'VD) Reference: 43 : 61 6/15/1998 15:00 60.2 Section (VS) Reference: Well (O.OON,O.OOE,328.12Azi) Survey Calculation Method: Minimum Curvature Db: Oracle MD lncl Azim TVD SysTVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 4650.00 44.10 338.98 __ 4023.27 3963.07 1690.72 -- -928.28 - 5981583.93 __ 720682.80 GYD-CT-DMS 4700.00 44.09 341.49 4059.18 3998.98 1723.46 -940.04 5981616.31 720670.07 GYD-CT-DMS 4750.00 44.32 342.40 4095.02 4034.82 1756.60 -950.85 5981649.11 720658.29 GYD-CT-DMS 4800.00 44.03 342.63 4130.89 4070.69 1789.83 -961.32 5981682.02 720646.85 GYD-CT-DMS 4850.00 43.63 342.85 4166.96 4106.76 1822.90 -971.59 5981714.76 720635.60 GYD-CT-DMS 4900.00 43.26 343.01 4203.26 4143.06 1855.76 -981.68 5981747.32 720624.54 GYD-CT-DMS 4950.00 44.18 343.06 4239.39 4179.19 1888.82 -991.77 5981780.06 720613.49 GYD-CT-DMS 5000.00 45.34 343.20 4274.90 4214.70 1922.51 -1001.98 5981813.43 720602.28 GYD-CT-DMS 5050.00 45.11 343.35 4310.12 4249.92 1956.50 -1012.20 5981847.10 720591.06 GYD-CT-DMS 5100.00 44.77 343.49 4345.51 4285.31 1990.35 -1022.28 5981880.63 720579.99 GYD-CT-DMS 5150.00 44.63 343.46 4381.05 4320.85 2024.06 -1032.28 5981914.04 720568.99 GYD-CT-DMS 5200.00 44.57 343.28 4416.65 4356.45 2057.70 -1042.33 5981947.37 720557.96 GYD-CT-DMS 5250.00 45.00 340.42 4452.14 4391.94 2091.17 -1053.30 5981980.49 720546.00 GYD-CT-DMS 5300.00 45.55 338.56 4487.33 4427.13 2124.44 -1065.75 5982013.37 720532.57 GYD-CT-DMS 5350.00 46.07 335.52 4522.18 4461.98 2157.44 -1079.73 5982045.95 720517.62 GYD-CT-DMS 5400.00 46.16 334.26 4556.85 4496.65 2190.07 -1095.02 5982078.11 720501.37 GYD-CT-DMS 5450.00 46.20 334.13 4591.47 4531.27 2222.55 -1110.73 5982110.11 720484.71 . GYD-CT-DMS 5500.00 46.10 334.05 4626.10 4565.90 2254.98 -1126.48 5982142.06 720468.01 GYD-CT-DMS 5550.00 46.13 334.03 4660.76 4600.56 2287.38 -1142.25 5982173.98 720451.28 GYD-CT-DMS 5600.00 46.29 334.17 4695.37 4635.17 2319.85 -1158.02 5982205.96 720434.57 GYD-CT-DMS 5650.00 46.29 334.12 4729.92 4669.72 2352.38 -1173.78 5982238.01 720417.85 GYD-CT-DMS 5700.00 46.31 333.99 4764.46 4704.26 2384.88 -1189.59 5982270.03 720401.08 GYD-CT-DMS 5750.00 46.44 334.09 4798.96 4738.76 2417.42 -1205.44 5982302.09 720384.28 GYD-CT-DMS 5800.00 46.53 334.13 4833.38 4773.18 2450.05 -1221.27 5982334.23 720367.50 GYD-CT-DMS 5850.00 46.68 334.26 4867.73 4807.53 2482.76 -1237.08 5982366.45 720350.72 GYD-CT-DMS 5900.00 46.95 334.26 4901.95 4841.75 2515.60 -1252.92 5982398.81 720333.93 GYD-CT-DMS 5950.00 47.54 334.29 4935.89 4875.69 2548.67 -1268.85 5982431.40 720317.02 GYD-CT-DMS 6000.00 47.45 334.17 4969.67 4909.47 2581.87 -1284.88 5982464.10 720300.02 GYD-CT-DMS 6050.00 47.48 334.09 5003.48 4943.28 2615.02 -1300.95 5982496.76 720282.97 GYD-CT-DMS 6100.00 47.42 334.03 5037.29 4977.09 2648.14 -1317.07 5982529.39 720265.89 GYD-CT-DMS 6150.00 47.47 334.10 5071.10 5010.90 2681.26 -1333.18 5982562.02 720248.80 GYD-CT-DMS 6200.00 46.96 333.94 5105.07 5044.87 2714.25 -1349.25 5982594.52 720231.76 GYD-CT-DMS 6250.00 47.18 333.66 5139.12 5078.92 2747.10 -1365.42 5982626.87 720214.63 GYD-CT-DMS 6300.00 47.39 333.54 5173.04 5112.84 2780.00 -1381.75 5982659.28 720197.33 GYD-CT-DMS 6350.00 47.52 333.57 5206.84 5146.64 2812.99 -1398.16 5982691.76 720179.96 GYD-CT-DMS 6400.00 47.66 333.43 5240.57 5180.37 2846.02 -1414.63 5982724.29 720162.51 GYD-CT-DMS 6450.00 47.55 333.28 5274.28 5214.08 2879.02 -1431.19 5982756.79 720144.99 GYD-CT-DMS 6500.00 47.43 333.30 5308.07 5247.87 2911.95 -1447.76 5982789.21 720127.45 GYD-CT-DMS 6550.00 47.10 333.58 5342.00 5281.80 2944.80 -1464.18 5982821.56 720110.07 GYD-CT-DMS 6600.00 47.32 333.83 5375.96 5315.76 2977.70 -1480.43 5982853.96 720092.85 GYD-CT-DMS 6650.00 47.76 332.15 5409.71 5349.51 3010.56 -1497.18 5982886.31 720075.14 GYD-CT-DMS 6700.00 48.09 331.46 5443.22 5383.02 3043.27 -1514.72 5982918.49 720056.64 GYD-CT-DMS 6750.00 48.24 329.72 5476.57 5416.37 3075.72 -1533.01 5982950.38 720037.40 GYD-CT-DMS 6800.00 48.70 327.36 5509.72 5449.52 3107.64 -1552.55 5982981.71 720016.93 GYD-CT-DMS 6850.00 48.87 326.72 5542.67 5482.47 3139.20 -1573.01 5983012.65 719995.54 GYD-CT-DMS 6900.00 48.70 326.42 5575.61 5515.41 3170.59 -1593.74 5983043.41 719973.90 GYD-CT-DMS 6950.00 47.73 323.74 5608.93 5548.73 3201.15 -1615.07 5983073.33 719951.67 GYD-CT-DMS 7000.00 47.29 323.17 5642.70 5582.50 3230.78 -1637.03 5983102.29 719928.85 GYD-CT-DMS 7050.00 47.35 323.34 5676.60 5616.40 3260.23 -1659.02 5983131.07 719906.00 GYD-CT-DMS 7100.00 47.09 323.39 5710.56 5650.36 3289.68 -1680.91 5983159.86 719883.24 GYD-CT-DMS 7150.00 47.12 323.39 5744.59 5684.39 3319.08 -1702.76 5983188.60 719860.54 GYD-CT-DMS 7200.00 47.12 323.48 5778.62 5718.42 3348.51 -1724.58 5983217.37 719837.85 GYD-CT-DMS 7250.00 46.71 323.63 5812.77 5752.57 3377.88 -1746.28 5983246.09 719815.30 GYD-CT-DMS Halliburton Company Survey Report Company: BP Amoco Field: Niakuk Site: NK Main Pad Well: NK-61 Wellpath: NK-61A Survey D1D Incl i ft deg zim deg VD ft ys TVll ft /S ft llate: 5/12/2006 Co-ordinate(NE) Reference: Vertical (TV D) Re[erence: Section (VS) Reference: Survey Calculation Method: E/W MapN ft ft Time: 13:38:12 Page: 4 WeII: NK-61, True North 43:61 6/15/1998 15:00 60.2 Well (O.OON,O.OOE,328.12Azi) Minimum Curvature llh: Oracle A1apE Tool ft ~ 7300.00 46.51 323.75 5847.12 5786.92 3407.16 - - -1767.80 5983274.72 719792.93 _ __ GYD-CT-DMS 7350.00 46.76 324.29 5881.45 5821.25 3436.58 -1789.15 5983303.49 719770.71 GYD-CT-DMS 7400.00 47.66 324.63 5915.41 5855.21 3466.44 -1810.48 5983332.70 719748.51 GYD-CT-DMS 7450.00 48.21 324.84 5948.91 5888.71 3496.74 -1831.91 5983362.36 719726.20 GYD-CT-DMS 7500.00 48.03 324.84 5982.29 5922.09 3527.18 -1853.34 5983392.15 719703.87 GYD-CT-DMS 7550.00 47.66 324.66 6015.85 5955.65 3557.45 -1874.73 5983421.77 719681.59 GYD-CT-DMS 7600.00 46.84 324.31 6049.79 5989.59 3587.34 -1896.06 5983451.01 719659.39 GYD-CT-DMS 7650.00 46.37 324.25 6084.14 6023.94 3616.83 -1917.27 5983479.87 719637.32 GYD-CT-DMS 7700.00 46.04 324.24 6118.74 6058.54 3646.13 -1938.36 5983508.52 719615.38 GYD-CT-DMS 7750.00 45.84 324.33 6153.51 6093.31 3675.30 -1959.33 5983537.06 719593.55 GYD-CT-DMS 7800.00 45.92 324.58 6188.32 6128.12 3704.50 -1980.20 5983565.63 719571.83 GYD-CT-DMS 7850.00 46.19 324.85 6223.02 6162.82 3733.89 -2001.00 5983594.39 719550.17 GYD-CT-DMS 7900.00 45.89 324.77 6257.73 6197.53 3763.30 -2021.74 5983623.18 719528.57 GYD-CT-DMS 7950.00 44.89 324.94 6292.84 6232.64 3792.41 -2042.22 5983651.66 719507.23 GYD-CT-DMS 8000.00 45.25 325.28 6328.16 6267.96 3821.44 -2062.47 5983680.09 719486.14 GYD-CT-DMS 8050.00 45.20 324.56 6363.37 6303.17 3850.49 -2082.87 5983708.51 719464.89 GYD-CT-DMS 8100.00 45.56 324.15 6398.50 6338.30 3879.41 -2103.61 5983736.81 719443.31 GYD-CT-DMS 8150.00 45.60 324.42 6433.49 6373.29 3908.41 -2124.45 5983765.17 719421.62 GYD-CT-DMS 8200.00 45.52 324.14 6468.50 6408.30 3937.39 -2145.29 5983793.52 719399.93 GYD-CT-DMS 8250.00 45.19 322.28 6503.64 6443.44 3965.88 -2166.59 5983821.37 719377:80 GYD-CT-DMS 8300.00 44.99 319.84 6538.94 6478.74 3993.42 -2188.84 5983848.24 719354.74 GYD-CT-DMS 8350.00 44.73 319.56 6574.38 6514.18 4020.32 -2211.66 5983874.45 719331.14 GYD-CT-DMS 8400.00 44.37 319.42 6610.01 6549.81 4046.99 -2234.44 5983900.43 719307.58 GYD-CT-DMS 8450.00 44.13 319.39 6645.83 6585.63 4073.48 -2257.14 5983926.24 719284.11 GYD-CT-DMS 8500.00 44.08 319.26 6681.73 6621.53 4099.87 -2279.82 5983951.95 719260.66 GYD-CT-DMS .8550.00 43.65 319.60 6717.78 6657.58 4126.19 -2302.36 5983977.59 719237.35 GYD-CT-DMS 8600.00 43.38 320.82 6754.04 6693.84 4152.64 -2324.39 5984003.38 719214.55 GYD-CT-DMS 8650.00 43.37 321.17 6790.38 6730.18 4179.32 -2346.01 5984029.41 719192.16 GYD-CT-DMS 8700.00 43.21 322.33 6826.78 6766.58 4206.25 -2367.23 5984055.69 719170.15 GYD-C7-DMS 8750.00 43.50 322.82 6863.13 6802.93 4233.51 -2388.09 5984082.32 719148.49 GYD-CT-DMS 8800.00 44.12 323.37 6899.21 6839.01 4261.19 -2408.87 5984109.37 719126.90 GYD-CT-DMS 8850.00 44.23 324.19 6935.08 6874.88 4289.29 -2429.46 5984136.86 719105.49 GYD-CT-DMS 8900.00 45.07 324.78 6970.65 6910.45 4317.90 -2449.87 5984164.84 719084.24 GYD-CT-DMS 8950.00 45.03 324.58 7005.97 6945.77 4346.77 -2470.33 5984193.09 719062.94 GYD-CT-DMS 9000.00 44.94 324.49 7041.34 6981.14 4375.56 -2490.84 5984221.26 719041.59 GYD-CT-DMS 9050.00 45.43 324.44 7076.58 7016.38 4404.42 -2511.45 5984249.50 719020.13 GYD-CT-DMS 9100.00 45.24 324.37 7111.73 7051.53 4433.34 -2532.15 5984277.79 718998.59 GYD-CT-DMS 9150.00 46.22 324.49 7146.63 7086.43 4462.46 -2552.98 5984306.29 718976.91 GYD-CT-DMS 9200.00 46.73 324.49 7181.06 7120.86 4491.97 -2574.04 5984335.16 718954.99 GYD-CT-DMS 9250.00 46.45 324.36 7215.42 7155.22 4521.51 -2595.17 5984364.06 718932.99 GYD-CT-DMS 9300.00 47.35 324.58 7249.58 7189.38 4551.23 -2616.38 5984393.13 718910.91 GYD-CT-DMS 9350.00 47.31 324.52 7283.47 7223.27 4581.17 -2637.70 5984422.44 718888.72 GYD-CT-DMS 9400.00 46.97 324.49 7317.49 7257.29 4611.01 -2658.98 5984451.63 718866.56 GYD-CT-DMS 9450.00 46.76 324.16 7351.67 7291.47 4640.65 -2680.26 5984480.62 718844.42 GYD-CT-DMS 9500.00 46.39 323.71 7386.04 7325.84 4670.00 -2701.64 5984509.33 718822.18 GYD-CT-DMS 9550.00 46.17 323.54 7420.60 7360.40 4699.10 -2723.07 5984537.78 718799.90 GYD-CT-DMS 9600.00 46.54 323.41 7455.11 7394.91 4728.17 -2744.61 5984566.20 718777.51 GYD-CT-DMS 9650.00 46.76 323.35 7489.43 7429.23 4757.35 -2766.30 5984594.73 718754.97 GYD-CT-DMS 9700.00 46.58 323.14 7523.74 7463.54 4786.49 -2788.06 5984623.21 718732.35 GYD-CT-DMS 9750.00 46.00 323.02 7558.29 7498.09 4815.39 -2809.77 5984651.45 718709.80 GYD-CT-DMS 9800.00 45.76 323.03 7593.10 7532.90 4844.06 -2831.36 5984679.47 718687.37 GYD-CT-DMS 9850.00 44.97 323.10 7628.23 7568.03 4872.50 -2852.74 5984707.27 718665.16 GYD-CT-DMS Halhburton Company Survey Report Company: BP Amoco Date: 5/12/2006 Time: 13:38:12 Page: Field: Nia kuk Co-ordinate(\E) Reference: Well: NK-61, True North Site: NK Main Pad Vertical (TVD ) Re[erenee: 43:61 6/15/ 1998 15:00 60.2 Well: NK- 61 Section (VS) Reference: Well (O.OON,O.OOE,328.12Azi) ~ Wellpath: NK-61A Survey Calcu -a6ou Method: Minimum Cu rvature Db: Oracle Survey MD tncl Azim TVD Sys'fVD N/S E/W Map~~ MapE Tool ~' ft deg deg ft ft ft ft ft ft ~ 9900.00 45.07 323.01 7663.57 7603.37 4900.77 -2874.00 5984734.89 718643.08 GYD-CT-DMS 9950.00 45.15 322.97 7698.86 7638.66 4929.06 -2895.32 5984762.53 718620.93 GYD-CT-DMS 10000.00 45.83 323.93 7733.91 7673.71 4957.71 -2916.56 5984790.54 718598:86 GYD-CT-DMS 10050.00 45.82 324.38 7768.75 7708.55 4986.77 -2937.56 5984818.97 718577.01 GYD-CT-DMS 10100.00 45.42 324.22 7803.72 7743.52 5015.79 -2958.41 5984847.36 718555.31 GYD-CT-DMS 10150.00 44.91 323.98 7838.98 7778.78 5044.51 -2979.20 5984875.45 718533.68 GYD-CT-DMS 10200.00 44.41 323.71 7874.54 7814.34 5072.89 -2999.93 5984903.20 718512.12 GYD-CT-DMS 10250.00 44.63 323.84 7910.19 7849.99 5101.17 -3020.64 5984930.86 718490.58 GYD-CT-DMS 10300.00 45.21 324.01 7945.60 7885.40 5129.71 -3041.43 5984958.77 718468.96 GYD-CT-DMS 10350.00 45.24 324.16 7980.82 7920.62 5158.46 -3062.25 5984986.88 718447.30 GYD-CT-DMS 10400.00 46.06 324.43 8015.77 7955.57 5187.49 -3083.12 5985015.29 718425.58 GYD-CT-DMS 10450.00 45.52 325.59 8050.63 7990.43 5216.85 -3103.67 5985044.02 718404.17 GYD-CT-DMS 10500.00 45.09 326.57 8085.80 8025.60 5246.34 -3123.50 5985072.92 718383.48 GYD-CT-DMS 10550.00 44.56 326.72 8121.26 8061.06 5275.78 -3142.88 5985101.77 718363.24 GYD-CT-DMS 10600.00 43.89 326.48 8157.09 8096.89 5304.90 -3162.08 5985130.30 718343.19 GYD-CT-DMS 10650.00 43.37 326.41 8193.28 8133.08 5333.65 -3181.15 5985158.48 718323.28 GYD-CT-DMS 10700.00 42.98 326.01 8229.75 8169.55 5362.08 -3200.18 5985186.33 718303.42 GYD-CT-DMS 10750.00 42.27 325.69 8266.53 8206.33 5390.10 -3219.18 5985213.78 718283.59 .GYD-CT-DMS 10800.00 41.81 325.65 8303.67 8243.47 5417.75 -3238.07 5985240.86 718263.90 GYD-CT-DMS 10850.00 41.38 325.34 8341.06 8280.86 5445.11 -3256.87 5985267.65 718244.30 GYD-CT-DMS 10900.00 40.76 324.96 8378.75 8318.55 5472.07 -3275.64 5985294.04 718224.74 GYD-CT-DMS 10950.00 40.20 324.60 8416.78 8356.58 5498.59 -3294.36 5985319.99 718205.24 GYD-CT-DMS 11000.00 38.73 324.44 8455.38 8395.18 5524.47 -3312.80 5985345.31 718186:04 GYD-CT-DMS 11050.00 36.20 324.18 8495.06 8434.86 5549.17 -3330.55 5985369.48 718167:58 GYD-CT-DMS 11100.00 35.53 323.76 8535.58 8475.38 5572.86 -3347.78 5985392.65 718149.65 GYD-CT-DMS 11150.00 34.75 323.38 8576.47 8516.27 5596.02 -3364.87 5985415.29 718131.89 GYD-CT-DMS 11200.00 33.96 323.08 8617.75 8557.55 5618.62 -3381.76 5985437.38 718114.34 GYD-CT-DMS 11250.00 31.86 323.48 8659.72 8599.52 5640.39 -3398.00 5985458.66 718097.46 GYD-CT-DMS 11300.00 30.96 323.54 8702.39 8642.19 5661.34 -3413.49 5985479.14 718081.35 GYD-CT-DMS 11350.00 29.11 323.85 8745.68 8685.48 5681.51 -3428.31 5985498.86 718065.94 GYD-CT-DMS 11400.00 28.42 323.16 8789.50 8729.30 5700.85 -3442.62 5985517.77 718051.07 GYD-CT-DMS 11450.00 27.78 322.50 8833.61 8773.41 5719.62 -3456.85 5985536.11 718036.29 GYD-CT-DMS 11500.00 26.70 322.77 8878.07 8817.87 5737.80 -3470.74 5985553.87 718021.87 GYD-CT-DMS 11550.00 25.13 323.84 8923.04 8862.84 5755.32 -3483.80 5985570.99 718008.30 GYD-CT-DMS 11600.00 23.41 324.51 8968.62 8908.42 5771.98 -3495.83 5985587.29 717995.78 GYD-CT-DMS 11650.00 23.01 324.36 9014.57 8954.37 5788.01 -3507.29 5985602.97 717983.86 GYD-CT-DMS 11700.00 22.68 324.55 9060.65 9000.45 5803.80 -3518.57 5985618.42 717972.11 GYD-CT-DMS 11750.00 22.20 324.59 9106.87 9046.67 5819.35 -3529.64 5985633.64 717960.59 GYD-CT-DMS 11800.00 21.63 324.74 9153.25 9093.05 5834.57 -3540.43 5985648.54 717949.35 GYD-CT-DMS 11802.00 21.62 324.74 9155.11 9094.91 5835.18 -3540.86 5985649.12 717948.91 MWD 11835.31 38.32 334.25 9183.88 9123.68 5849.60 -3548.95 5985663.30 717940.39 MWD 11865.44 47.11 338.69 9206.00 9145.80 5868.34 -3557.04 5985681.79 717931.76 MWD 11880.07 51.15 340.24 9215.57 9155.37 5878.69 -3560.91 5985692.03 717927.58 MWD 11910.57 65.48 331.59 9231.57 9171.37 5902.23 -3571.60 5985715.24 717916.20 MWD 11943.17 78.57 329.30 9241.61 9181.41 5929.13 -3586.88 5985741.67 717900.13 MWD i 1971.34 80.24 326.32 9246.79 9186.59 5952.56 -3601.63 5985764.66 717884.69 MWD 12001.22 82.70 324.91 9251.23 9191.03 5976.94 -3618.32 5985788.53 717867.29 MWD 12032.09 85.69 323.33 9254.35 9194.15 6001.82 -3636.32 5985812.87 717848.57 MWD 12061.53 88.15 321.92 9255.93 9195.73 6025.18 -3654.16 5985835.69 717830.04 MWD 12093.27 90.88 319.11 9256.20 9196.00 6049.67 -3674.34 5985859.57 717809.15 MWD 12122.21 90.70 318.05 9255.80 9195.60 6071.37 -3693.48 5985880.69 717789.37 MWD 12154.64 91.05 315.59 9255.30 9195.10 6095.02 -3715.67 5985903.67 717766.50 MWD 12185.41 90.88 313.31 9254.79 9194.59 6116.56 -3737.63 5985924.55 717743.91 MWD Halliburton Com an P Y Survey Report Company: BP Amoco Field: Niakuk Site: NK Main Pad Well: NK-61 i ~Vellpath: NK-61A Survey Date: 5/12/2006 Time: 13:38:12 Page: 6 Co-ordinate(NE) Reference: Well: NK-61, True North Vertical (TVD) Reference: 43:61 6/15/1998 15:00 60.2 Section (VS) Reference: Well (O.OON,O.OOE,328.12Azi) Survey Calculation Method: Minimum Curvature Db: Oracle MD Jncl Azim TVD S,ys"I'VD N/S E/W' MapN MapE Tool ft deg deg ft ft ft ft ft ft 12218 .22 91. 14 309. 97 9254 .21 9194. 01 6138 .35 -3762 .14 5985945. 61 717718. 76 MWD 12248. 51 92. 46 307. 86 9253 .26 9193. 06 6157 .37 -3785. 70 5985963. 92 717694. 66 MWD 12281. 08 92. 99 305. 75 9251 .71 9191. 51 6176 .86 -3811. 74 5985982. 63 717668. 05 MWD 12313. 82 93. 34 309. 62 9249 .90 9189. 70 6196 .84 -3837 .61 5986001. 84 717641. 60 MWD 12346. 99 92. 11 314. 01 9248 .32 9188. 12 6218 .92 -3862 .30 5986023. 18 717616. 28 MWD 12381. 47 90. 79 317. 00 9247 .45 9187. 25 6243 .51 -3886 .45 5986047. 04 717591. 41 MWD 12418. 79 92. 20 319. 11 9246 .48 9186. 28 6271 .25 -3911 .38 5986074. 03 717565. 66 MWD 12449. 76 92. 20 318. 76 9245 .29 9185. 09 6294 .59 -3931 .71 5986096. 76 717544. 65 MWD 12482. 14 92. 11 320. 52 9244 .07 9183. 87 6319 .24 -3952 .67 5986120. 78 717522. 98 MWD 12514. 62 91. 76 321. 39 9242 .97 9182. 77 6344 .45 -3973 .12 5986145. 37 717501. 80 MWD 12543 .06 91. 05 327. 37 9242 .27 9182. 07 6367 .55 -3989 .67 5986167. 97 717484. 57 MWD 12572 .81 90. 70 328. 43 9241 .82 9181. 62 6392 .75 -4005 .47 5986192. 69 717468. 03 MWD 12602 .87 90. 77 331. 55 9241 .43 9181. 23 6418 .78 -4020 .50 5986218. 26 717452. 23 MWD 12634. 95 90. 26 334. 05 9241 .15 9180. 95 6447 .31 -4035 .17 5986246. 34 717436. 73 MWD 12666. 80 90. 88 341. 96 9240 .83 9180. 63 6476 .81 -4047 .09 5986275. 48 717423. 95 MWD 12697. 73 90. 35 339. 50 9240 .50 9180. 30 6506 .01 -4057 .29 5986304. 36 717412. 88 MWD 12727. 43 89. 56 345. 30 9240 .52 9180. 32 6534 .30 -4066 .27 5986332. 38 717403. 07 MWD 12748. 68 90. 09 346. 71 9240 .58 9180. 38 6554 .92 -4071 .41 . 5986352. 83 717397. 33 MWD 12781. 27 90. 35 348. 82 9240 .46 9180. 26 6586 .77 -4078 .31 5986384. 46 717389. 48 MWD 12819 .66 91. 76 351. 45 9239 .75 9179. 55 6624 .58 -4084 .89 5986422. 06 717381. 79 MWD 12867 .19 92. 02 354. 62 9238 .18 9177. 98 6671 .73 -4090 .65 5986469. 02 717374. 64 MWD 12895 .07 91. 76 357. 60 9237 .26 9177. 06 6699 .53 -4092 .54 5986496. 74 717371. 93 MWD 12947 .15 89. 84 5. 08 9236 .54 9176. 34 6751 .55 -4091 .32 5986548. 78 717371. 61 MWD 13013 .98 91. 49 10. 79 9235 .76 9175. 56 6817 .70 -4082 .10 5986615. 17 717378. 87 MWD 13054 .25 . 91. 67 12. 55 9234 .65 9174. 45 6857 .13 -4073 .96 5986654. 82 717385. 84 MWD 13085 .44 91. 67 15. 18 9233 .74 9173. 54 6887 .39 -4066 .49 5986685. 29 717392. 41 MWD 13117. 74 90. 59 16. 67 9233 .10 9172. 90 6918 .44 -4057 .63 5986716. 59 717400. 35 MWD 13147. 35 89. 74 20. 63 9233 .02 9172. 82 6946 .49 -4048 .16 5986744. 90 717408. 98 MWD 13180. 46 88. 85 18. 77 9233 .43 9173. 23 6977 .66 -4037 .00 5986776. 39 717419. 22 MWD 13240. 82 88. 07 19. 58 9235 .05 9174. 85 7034 .65 -4017 .18 5986833. 93 717437. 34 MWD 13270 .31 89. 38 15. 01 9235 .70 9175. 50 7062 .79 -4008 .42 5986862. 32 717445. 26 MWD 13301 .19 89. 47 12. 37 9236 .01 9175. 81 7092 .79 -4001 .11 5986892. 52 717451. 68 MWD 13344 .39 89. 12 9. 73 9236 .55 9176. 35 7135 .18 -3992 .83 5986935. 14 717458. 70 MWD 13377 .56 89. 30 3. 93 9237 .00 9176. 80 7168 .10 -3988 .89 5986968. 16 717461. 67 MWD 13413 .60 89. 74 0. 77 9237 .31 9177. 11 7204 .10 -3987 .41 5987004. 19 717462. 08 MWD 13451 .27 89. 74 354. 27 9237 .48 9177. 28 7241 .72 -3989 .04 5987041. 73 717459. 34 MWD 13484 .88 89. 21 350. 57 9237 .79 9177. 59 7275 .03 -3993 .48 5987074. 90 717453. 92 MWD 13517 .96 88. 33 349. 69 9238 .50 9178. 30 7307 .61 -3999 .14 5987107. 30 717447. 29 MWD 13546 .91 88. 42 348. 29 9239 .32 9179. 12 7336 .02 -4004 .67 5987135. 52 717440. 93 MWD 13577 .51 89. 56 346. 35 9239 .86 9179. 66 7365 .86 -4011 .39 5987165. 16 717433. 34 MWD 13606. 34 90. 31 340. 48 9239 .89 9179. 69 7393 .48 -4019 .61 5987192 .52 717424. 30 MWD 13644 .46 91. 30 335. 45 9239 .35 9179. 15 7428 .80 -4033 .91 5987227. 40 717408. 96 MWD 13675 .38 91. 14 330. 36 9238 .69 9178. 49 7456 .31 -4047 .98 5987254. 48 717394. 08 MWD 13713 .69 90. 70 327. 19 9238 .08 9177, 88 7489 .06 -4067 .84 5987286. 63 717373. 27 MWD 13743 .49 90. 97 325. 96 9237 .64 9177. 44 7513 .93 -4084 .25 5987311. 00 717356. 13 MWD 13774 .22 92. 02 328. 07 9236 .84 9176. 64 7539 .70 -4100 .97 5987336. 26 717338. 65 MWD 13816 .58 90. 84 331. 82 9235 .78 9175. 58 7576 .34 -4122 .18 5987372. 26 717316. 37 MWD 13852 .06 90. 88 337. 57 9235 .25 9175. 05 7608 .40 -4137 .34 5987403 .86 717300. 27 MWD 13886 .34 93. 34 341. 26 9233 .99 9173. 79 7640 .46 -4149 .38 5987435 .55 717287. 29 MWD 13920 .47 93. 16 345. 83 9232 .05 9171 .85 7673 .13 -4159 .03 5987467 .92 717276. 68 MWD 13950 .21 92. 11 348. 99 9230 .69 9170 .49 7702 .12 -4165 .50 5987496 .70 717269. 35 MWD 13980 .55 90. 70 352. 68 9229 .94 9169 .74 7732 .06 -4170 .33 5987526 .48 717263. 64 MWD Halliburton Company Survey Report Company: BP Amoco Date: 5/12/2006 Time: 13:38:12 Page: 7 ', N'ield: Nia kuk Co-ordi nate(NE) Reference: Well: NK-61, True North '~ Site: NK Mai n Pad Vertical (TVll ) Reference: 43:61 6/15/1 998 15:00 60. 2 '~, Well: NK- 61 Secrion (VS) Reference: Well (O.OON,O .OOE,328.12A zi) Wellpath: NK-61A _ Survey Calcu lation Meth od: Minimum Cur vature Db: Oracle Survey MD Incl Azim "I'~ D - _ --- Sys TV - D N!S E/W' --- MapN - MapE Tool ft deg deg ft ft ft ft ft ft 14014 .13 91. 41 355. 14 9229. 32 9169. 12 7765 .44 -4173 .89 5987559. 74 717259. 09 MWD 14049 .88 91. 05 358. 84 9228. 56 9168. 36 7801 .13 -4175 .77 5987595. 35 717256. 16 MWD 14085 .67 91. 49 2. 35 9227. 76 9167. 56 7836 .90 -4175 .40 5987631. 12 717255. 47 MWD 14131 .61 90. 93 1. 13 9226. 79 9166. 59 7882 .81 -4174 .00 5987677. 05 717255. 51 MWD 14165 .99 89. 21 9. 91 9226. 75 9166. 55 7917 .00 -4170 .70 5987711. 32 717257. 80 MWD 14192 .17 89. 01 13. 68 9227. 16 9166 .96 7942 .62 -4165 .35 5987737. 08 717262. 39 MWD 14220 .89 90. 18 14. 30 9227. 36 9167. 16 7970 .48 -4158 .41 5987765. 14 717268. 50 MWD 14255 .94 90. 61 18. 35 9227. 12 9166. 92 8004 .11 -4148 .56 5987799. 04 717277. 35 MWD 14284 .81 91. 05 23. 44 9226. 70 9166. 50 8031 .07 -4138 .27 5987826. 29 717286. 84 MWD 14304 .85 . 91. 14 25. 03 9226. 32 9166. 12 8049 .34 -4130 .04 5987844. 80 717294. 52 MWD 14332 .43 91. 32 26. 96 9225. 72 9165. 52 8074 .13 -4117 .96 5987869. 93 717305. 87 MWD 14352 .51 91. 49 30. 48 9225. 23 9165. 03 8091 .73 -4108 .31 5987887. 81 717314. 99 MWD 14383 .00 91. 27 34. 33 9224. 50 9164. 30 8117 .46 -4091 .98 5987914. 01 717330. 55 MWD 14419 .03 91. 67 36. 10 9223. 57 9163. 37 8146 .88 -4071 .21 5987944. 03 717350. 44 MWD 14456 .34 91. 32 38. 21 9222. 60 9162 .40 8176 .61 -4048 .69 5987974. 41 717372. 08 MWD 14485 .73 91. 32 35. 05 9221. 92 9161 .72 8200 .18 -4031 .16 5987998. 49 717388. 90 MWD 14511 .85 93. 25 35. 40 9220. 88 9160. 68 8221 .50 -4016 .10 5988020. 25 717403. 31 MWD 14544 .32 93. 34 32. 06 9219. 01 9158. 81 8248 .46 -3998 .11 5988047. 72 717420. 51 MWD 14576 .80 91. 85 34. 87 9217. 54 9157. 34 8275 .52 -3980 .22 5988075. 30 717437. 59 MWD 14607 .40 92. 83 30. 91 9216. 29 9156. 09 8301 .19 -3963 .62 5988101. 45 717453. 42 MWD 14636 .09 94. 13 29. 07 9214. 55 9154. 35 8325 .99 -3949 .30 5988126. 66 717466. 99 MWD 14664 .85 95. 62 25. 73 9212. 11 9151. 91 8351 .43 -3936 .12 5988152. 47 717479. 42 MWD 14700 .08 93. 43 25. 55 9209. 33 9149. 13 8383 .09 -3920 .92 5988184. 57 717493. 67 MWD 14734 .55 91. 41 26. 26 9207. 87 9147 .67 8414 .06 -3905 .88 5988215. 98 717507. 79 MWD 14776 .70 93. 16 25. 91 9206. 19 9145 .99 8451 .89 -3887 .36 5988254. 33 717525. 19 MWD 14819 .24 95. 27 18. 87 9203. 06 9142 .86 8491 .09 -3871 .21 5988293. 99 717540. 17 MWD 14847 .70 97. 65 26. 08 9199. 86 9139. 66 8517 .20 -3860 .41 5988320. 41 717550. 19 MWD 14884 .31 97. 03 20. 28 9195. 17 9134. 97 8550 .57 -3846 .12 5988354. 18 717563. 48 MWD 14917 .88 97. 65 19. 23 9190. 89 9130. 69 8581 .90 -3834 .87 5988385. 83 717573. 80 MWD 14953 .17 96. 59 19. 05 9186. 51 9126. 31 8614 .98 -3823 .39 5988419. 24 717584. 30 MWD 14988 .56 93. 43 19. 58 9183. 42 9123. 22 8648 .25 -3811 .73 5988452. 83 717594. 97 MWD 15021 .38 92. 46 16. 06 9181. 73 9121. 53 8679 .45 -3801 .70 5988484. 31 717604. 07 MWD 15051 .02 93. 16 14. 48 9180. 28 9120. 08 8708 .01 -3793 .90 5988513. 09 717611. 02 MWD 15084 .84 97. 12 11. 14 9177. 25 9117. 05 8740 .84 -3786 .43 5988546. 12 717617. 52 MWD 15095 .85 98. 35 9. 91 9175. 77 9115 .57 8751 .56 -3784 .44 5988556. 90 717619. 19 MWD 15125 .00 98. 35 9. 91 9171. 54 9111 .34 8779 .98 -3779 .48 5988585. 45 717623. 31 PROJECTED I KCC = 4-- UVV WELLHEAb = FMC 11" GEN 5 ACTUATOR = BAKER KB. ELEV = 59.6' BF. ELEV = 37.8' KOP = Max Angle = Datum MD = 11802 98.35" @ 15095' 11914' -Datum TV D = 9200' SS 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 6196' lFt(FTtU171 ~~ = '~ .32" CL '~ ~ 5$~' 2_318"" STL LNR TOP OF 2-3(8" LNR AS LOGGED BY MGRlCCL 11574' BOT DEPLOY SLEEVE, 6° LONG, 2.25" ID 115$1' C SAFETY NOTES: 2106' ~~ 3-112" TRSV, SERIES 10 FMX NIP, ID = 2.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3854 3457 47 MMG DOME RK 16 09/06/05 4 7974 6297 45 MMG DOME RK 16 09/06/05 3 10100 7790 45 MMG DOME RK 16 09/06/05 2 11099 8524 35 MMG DMY RK 0 1 11502 8867 25 MMG SO RK 20 09/06(05 11562' ~ 3-112" HES X NIP, ID = 2.813" 11574' 7-5/8" X 4-1/2" BAKER S-3 PKR, ID = 3.875" 11581' TOP OF 2-318" LINER & TOP OF CEMENT 11599' 3-112" HES X NIP, ID = 2.813" '(1609' I-~ 3-112" HES X NIP, ID = 2.813" 3-1/2" TBG, 9.3#, L-80, 0.0087 bpf, ID = 2.992" I-{ 11620' PERFORATION SUMMARY REF LOG: MGRICCL OF 4i 12(2006 TIE-IN LOG: GEOLOGY PDC LOG ANGLE AT TOP PERF: 91.88° @ 13770' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 1.56" 6 13,770' - 13,860' Opn 04114!06 1,56" 6 14,420'-14,540' Opn 04113106 1.56" 6 14,570' - 14,680' Opn 04(13106 1.56" 6 14,740` - 14,800' Opn 04113106 1.56" 6 14,830' - 14,890' Opn 04J13f06 ~ NK-61A DRGL DRAFT PBTD I-I 12251' 7" CSG, 26#, L-80, ID = 6.276" I~ 12351' 11605' -iTOPOF P&A t PILOT HOLE CEMENT 11605' ELMD TT LOGGED 07/26/98 11620' 3-1/2" TUBING TAIL WLEG ' I 11722' -~ NIARKER JOINT 11722-11742' (ElMD} l I 11$04' - 11$10' CEMENfi RAMP WINDOW I\ ``~\ 150$7' PBTD [15076` AS PER MGRICCL] ..~~ , `_ - 2-3f8" LINER: CEMENTED & PERFED 15125' 119$2` -MARKER 10' PUP JOINT DATE REV BY COMMENTS DATE REV BY COMMENTS 07!16198 ORIG COMPLETION, (POOL 7) 09/29/01 RN/TP CORRECTIONS 06/27/03 BG/KAK MD & SS DEPTH CORRECTIONS 07/10!04 KSB/KAK GLV GO 09/08105 DAVJTLH GLV GO 04!14106 JUE NORDIC-1 CTD SIDETRACK NIAKUK UNff WELL: NK-61A PERMff No: 206-035 API No: 50-029-22893-01 SEC 36, T12N, R15E, 4549.13' FEL & 3183.43' FNL BP Exploration (Alaska) • ,'1 ~ t a~ ~~ , ALASSA OIL A1~TD GA5 CO1~T5ERQA'TIO1~T COMirIISSIOrT Sean McLaughlin CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 FRANK H. MURKOWSK/, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, PBU NK-61A BP Exploration (Alaska) Inc. Permit No: 206-035 Surface Location: 1383' FSL, 900' FEL, SEC. 36, T12N, R15E, UM Bottomhole Location: 4889' FSL, 4898' FEL, SEC. 25, T12N, R15E, UM Dear Mr. McLaughlin: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Cat P. Foerster Commissioner DATED this~~day of March, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. p 3 00(0 A STATE OF ALASKA r)'i ~ ©~ R I V ALA~OIL AND GAS CONSERVATION COMW~ON 31 Aft 0 PERMIT TO DRILL 7 2006 20 AAC 25.005 Alaska Oi! R Gae r•,,... ~___ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ~ ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is pro s d for: ' ^ Coalbed Methane ~~rates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Wel! Bond No. 6194193 11. Well Name and Number: PBU NK-61A ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 15025 TVD 9100ss 12. Field /Pool(s): Prudhoe Bay Field / Niakuk Pool 4a. Location of Well (Governmental Section): Surface: 1383' FSL 900' FEL R15E UM SEC 36 T12N 7. Property Designation: ADL 034630 , , . , , , Top of Productive Horizon: 1938' FSL, 4441' FEL, SEC. 25, T12N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: March 23, 2006 Total Depth: 4889' FSL, 4898' FEL, SEC. 25, T12N, R15E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 4950' 4b. Location of Well (State Base Plane Coordinates): Surface: x-721661 y-5979921 Zone-ASP4 10. KB Elevation (Height above GL): 59.4' feet 15. Distance to Nearest Well Within Pool: 1350' 16. Deviated Wells: Kickoff Depth: 11804 feet Maximum Hole Angle: 98 de rees 17. Maximum Anticipated Pressures in psig (see 20 AA 5) Downhole: 4200 Surface: 280 18. Casin Pr ram: S ecificatlons T - Settin [)e th -:B ottom ~uanti of f c.f. orsacks '' Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 3420' 11605' 8914' 15025' 9100' 7 sx Class 'G' 19. PRESENT W ELL CONDITION S UMMARY (To be completed f or Redrill and Re-entry Operations) Total Depth MD (ft): 12365 Total Depth TVD (ft): 9684 Plugs (measured): None Effective Depth MD (ft): 12251 Effective Depth TVD (ft): 9576 Junk (measured): None ,Casin Len h Size Cement Volume MD TVD Conductor /Structural 73' 20" 60 sx Arcticset A rox. 115' 115' Surface 6156' 9-5/8" 410 sx Permafrost 'E' 410 sx Class 'G' 6196' 5102' Intermediate 12313' 7" 75 sx Class 'G' 12351' 9671' Liner Pertoration Depth MD (ft): 11803' - 11933' Perforation Depth TVD (ft): 9156' - 9277' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Printed Name Sean McLaughlin Si nature -+ /~"- Contact Sean McLaughlin, 564-4387 Title CT Drilling Engineer Prepared By Name/Number: Phone 564-4387 Date ~j 7 p6 Terrie Hubble, 564-4628 Commission Use Oniy Permit To Drill Number: - p API Number: 50- 029-22893-01-00 Permit Approval Date: ~ See cover letter for other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No HZS Measures: Yes ^ No Directional Survey Req'd:~,Yes ^ No Other: ~ ~c,-~ ~O7C {'o ~-D~D r S~ APPROVED BY THE COMMISSION Q G Date ,COMMISSIONER Ion form 10-401 Revised 12/2005 ~ R f G I ~I`Q ~ Submit In Duplicate ~ 1~ BP Prudhoe Bay NK-61A CTD Sidetrack CTD Sidetrack Summary Pre-Rig Work: 1. O AC-LDS; AC-PPPOT-IC, T 2. C Clean out Done 3. S Set DGLV 4. S Caliper the tubing and the liner 5. O MIT-IA, and OA. 6. C Pump cement for abandonment and cement ramp exit - 17 ppg cmt- 26 bbl (l l bbl casing volume l 1620'-11,900', 10 behind pipe, 5 excess) 7. O Bleed gas lift and production flowlines down to zero and blind flange 8. O Remove wellhouse, level pad The pre CTD work is slated to begin on March 12, 2006. Rig Work: 1. MIRU and test BOPE to 250 psi low and 4000 psi high. ~ 2. Mill 3.8" cement ramp window at 11804' and 10' of rathole. Swap the well to Flo-Pro. 3. Drill Build: 3" OH, 396' (40 deg/100 planned) /. 4. Drill Lateral: 3" OH, 3025' horizontal (10 deg/100 planned) 5. MAD pass with resistivity tools 6. Run 2 3/8" solid liner leaving TOL 11 OS' 7. Pump primary cement job to TO 16 1 of 15.8 ppg liner cmt planned 8. Cleanout liner and MGR/CCL log 9. Test liner lap to 2000 psi. 10. Perforate liner per asset instructions (500') 11. Freeze protect well, RDMO Post-Rig Work: 1. Move wellhouse, Install production flowline 2. Run GLVs 3. Flowback well to separator Mud Program: • Well kill: 9.2 pp vine • Milling/drillin : 9.2 pg Flo Pro or biozan for milling, new Flo Pro for drilling. 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: • 2 3/8" fully cemented liner - 11605' MD to 15025' MD r • A minimum of 16 bbls 15.8 ppg cement will be used for liner cementing. Casing Information 9 5/8", L-80 47#, Burst 6870, collapse 4750 psi 7", L-80 26#, Burst 7240, collapse 5410 psi Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. ~ The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 97 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 4950 ft. • Distance to nearest well~in pool - 1350 ft. Logging • MWD directional, Gamma Ray will be run over all of the open hole section. • Resistivity will be run as a MAD pass • A cased hole GR/CCL log will be run. Hazards • The maximum recorded H2S level on NK-62a i 75 ppm • Lost circulation risk is medium, crossing three fau ts. Reservoir Pressure Res Pressure was recorded at 3731 psi in the parent on 2/27/06 The max res. press. is estimated to be 4200 psi at 9200'ss (8.8 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 3280 psi. TREE _ 4" CM/ ~ N K-61 WELLHEAD = FMC 11" GEN 5 ACTUATOR= BAKER KB. ELEV_- 59.6' BF. ELEV..- _ _ __ 37.8' KOP = _. _ _ 1000' Max Angle = 49 @ 6850' Datum MD = 11914' Datum TV D = 9200' SS 2106' ~--~ 3-1/2" TRSV, SERIES 10 FMX NIP, ID = 2.813" ~ GAS LIFT MANDRELS 9-5/8" CSG, 47#, L-80, ID = 8.681" I-{ 6196' ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3854 3457 47 MMG DOME RK 16 09/06/05 4 7974 6297 45 MMG DOME RK 16 09/06/05 3 10100 7790 45 MMG DOME RK 16 09/06/05 2 11099 8524 35 MMG DMY RK 0 1 11502 8867 25 MMG SO RK 20 09/06/05 11562' 3-1/2" HES X NIP, ID = 2.813" 11574' 7-5/8" X 4-1/2" BAKER S-3 PKR, ID = 3.875" Minimum ID = 2.813" @ 2106' 3-1 /2" HES SERIES 10 FMX TRSSSV 11599' I-{ 3-1/2" HES X NIP, ID = 2.813" 11609' I-i 3-1/2" HES X NIP, ID = 2.813" 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" I-{ 11620' PERFORATION SUMMARY REF LOG: SWS DIPOLE SHEAR SONIC ON 07/11/98 ANGLE AT TOP PERF: 22 @ 11803' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 11803 - 11813 O 11/15/98 2-1/2" 6 11803 - 11840 O 07/27/98 2-1/2" 4 11803 - 11840 O 07/27/98 2-1/2" 6 11908 - 11933 O 11/15/98 PBTD 12251' 7" CSG, 26#, L-80, ID = 6.276" 12351' 11620' -i 3-1/2" TUBING TAIL WLEG 11605' -~MD TT LOGGED 07/26/98 11722' ~~ MARKER JOINT 11722-11742' (ELMD) DATE REV BY COMMENTS DATE REV BY COMMENTS 07/16/98 ORIG COMPLETION, (POOL 7) 09/29!01 RN/TP CORRECTIONS 06/27/03 BG/KAK MD & SS DEPTH CORRECTIONS 07!10/04 KSBlKAK GLV C/O 09/06/05 DAV/TLH GLV C/O NIAKUK UNff WELL: NK-61 PERMIT No: 1981140 API No: 50-029-22893-00 SEC 36, T12N, R15E, 4549.13' FEL & 3183.43' FNL BP 6cploration (Alaska) ~~ _ 4" CfJV WELLHEAD = FMC 11" GEN 5 ACTUATOR = BAKER KB. ELEV = 59.6' BF. ELEV = 37.8' KOP = 1000' Max Angle = 49 @ 6850' Datum MD = 11914' Datum TVD = 9200' SS 9-5/8" CSG, 47#, L-80, ID = 8.681" 2106' I~ 3-1/2" TRSV, SERIES 10 FMX NIP, ID = 2.813" I GAS LIFT MANDRELS • NK-61A Proposed CTD Sidetrack O Minimum ID = 2.813" @ 2106' 3-1 /2" HES SERIES 10 FMX TR-SSSV TOP OF 2-3/8" LNR 11605' Top of Cement 11605' I 3-1/2" TBG, PBTD 12251' 7" CSG, 26#, L-80, ID = 6.276" ~ 351' ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3854 3457 47 MMG DOME RK 16 09/06/05 4 7974 6297 45 MMG DOME RK 16 09/06105 3 10100 7790 45 MMG DOME RK 16 09/06/05 2 11099 8524 35 MMG DMY RK 0 1 11502 8867 25 MMG SO RK 20 09/06/05 11562' 3-1/2" HES X NIP, ID = 2.813" 11574' 7-5/8" X 4-1/2" BAKER S-3 PKR, ID = 3.875" 11580' Liner Top Packer 11599' 3-1/2" HES X NIP, ID = 2.813" 1~ 1609' I- j 3-1/2" HES X NIP, ID = 2.813" 11620' Top of Cement 11620' 3-1/2" TUBING TAIL WLEG 11605' ELMD TT LOGGED 07/26/98 11722' H MARKER JOINT 11722-11742' 11804' -i Cement ramp Window 2-3/8" cmt'ed and perfed liner 15025' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/16/98 ORIG COMPLETION, (POOL 7) 09/29/01 RN/TP CORRECTIONS 06/27/03 BG/KAK MD 8 SS DEPTH CORRECTIONS 07/10/04 KSB/KAK GLV GO 09/06/05 DAV/TLH GLV GO NIAKUK UNfT WELL: NK-61 PERMIT No: 1981140 API No: 50-029-22893-00 SEC 36, T12N, R15E, 4549.13' FEL 8~ 3183.43' FNL BP Exploration (Alaska) ID = 2.992" 11 11620' PERFORATION SUMMARY REF LOG: SWS DIPOLE SHEAR SONIC ON 07!11/98 ANGLE AT TOP PERF: 22 @ 11803' Note: Refer to Roduction DB for historical pert data S¢E SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 11803 - 11813 O 11/15/98 2-1/2" 6 11803 - 11840 O 07/27/98 2-1/2" 4 11803 - 11840 O 07/27/98 2-1/2" 6 11908 - 11933 O 11/15/98 • by BP Alaska Baker Hughes INTEQ Planning Report ~a~ s INTEQ Company: BP Amoco Date: 3/3/2006 Time: 14:41:30 Page: 1 Field: Niakuk Co-ordioate(NE) Reference: Welt: NK-61, True North Site: NK Main Pad Vertical (TVD) Reference: 43 :61 6/15/199815:00 '60.2 Well: NK-61 Section (VS) Reference: Wel{ (O.OON,O.OOE,328.12Azi) Wellpath: PIan4, NK-61A Sarvey Calculation Method: Minimum Curvature Dbo -0racle Field: Niakuk North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 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 Essting: 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-61 Slot Name: 61 NK-61 Well Position: +N/-S -1539.35 ft Northing: 5979921 .49 ft Latitude: 70 20 50.707 N +E/-W 7066.53 ft Essting : 721660.64 ft Longitude: 148 12 1.497 W Positioa Uncertainty: 0.00 ft Wellpat6: PIan4,NK~1A Drilled From: NK-61 500292289301 Tie-on Depth: 11 800.00 ft Current Datnro: 43:61 6/15/1998 15 :00 Height 60.20 ft Above System Datum: Mean Sea Level Magnetic Data: 3/3/2006 Declination: 24.85 deg Field Strength: 57629 nT Mag Dip Angle: 80.98 deg Vertical Section: Deptb From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.70 0.00 0.00 328.12 Plan: Plan li4 Date Composed: 3/3/2006 Copy Lamar's plan 4 Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <--- I.atitnde -> ~- Longitude --> Name Deacriptton TVD +N/-S +E/-W Northing Easdng Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft NK-61A Polygon 60.20 6039.88 -4003.92 5985840.04 717480.02 70 21 50.098 N 148 13 58.587 W -Polygon 1 60.20 6039.88 -4003.92 5985840.04 717480.02 70 21 50.098 N 148 13 58.587 W -Polygon 2 60.20 5775.31 -3684.59 5985585.04 717807.02 70 21 47.497 N 148 13 49.245 W -Polygon 3 60.20 5816.00 -3335.22 5985636.04 718155.02 70 21 47.899 N 148 13 39.029 W -Polygon 4 60.20 6575.13 -3732.96 5986383.04 717735.02 70 21 55.363 N 148 13 50.671 W -Polygon 5 60.20 7169.11 -3756.40 5986976.04 717694.02 70 22 1.205 N 148 13 51.366 W -Polygon 6 60.20 8153.11 -3808.32 5987958.04 717613.02 70 22 10.882 N 148 13 52.899 W -Polygon 7 60.20 9217.94 -3480.67 5989032.04 717909.02 70 22 21.356 N 148 13 43.329 W -Polygon 8 60.20 9291.01 -4225.87 5989083.04 717162.02 70 22 22.071 N 148 14 5.132 W -Polygon 9 60.20 8250.52 X327.69 5988040.04 717091.02 70 22 11.837 N 148 14 8.093 W -Polygon 10 60.20 6508.57 -4256.18 5986301.04 717214.02 70 21 54.706 N 148 14 5.972 W NK-61A Fault 1 60.20 5841.09 -3304.46 5985662.04 718185.02 70 21 48.146 N 148 13 38.130 W -Polygon 1 60.20 5841.09 -3304.46 5985662.04 718185.02 70 21 48.146 N 148 13 38.130 W -Polygon 2 60.20 5838.23 -3917.84 5985641.04 717572.02 70 21 48.115 N 148 13 56.067 W -Polygon 3 60.20 6375.36 ~t792.37 5986152.04 716682.02 70 21 53.393 N 148 14 21.651 W -Polygon 4 60.20 5838.23 -3917.84 5985641.04 717572.02 70 21 48.115 N 148 13 56.067 W NK-61A Fault 3 60.20 8412.24 -3064.29 5988239.05 718349.03 70 22 13.434 N 148 13 31.137 W -Polygon 1 60.20 8412.24 -3064.29 5988239.05 718349.03 70 22 13.434 N 148 13 31.137 W -Polygon 2 60.20 8149.04 -3839.44 5987953.05 717582.03 70 22 10.842 N 148 13 53.809 W -Polygon 3 60.20 8321.94 -4847.82 5988096.05 716569.03 70 22 12.537 N 148 14 23.309 W -Polygon 4 60.20 8149.04 -3839.44 5987953.05 717582.03 70 22 10.842 N 148 13 53.809 W NK-61A Fault 4 60.20 5759.40 -3654.04 5985570.04 717838.02 70 21 47.341 N 148 13 48.352 W -Polygon 1 60.20 5759.40 -3654.04 5985570.04 717838.02 70 21 47.341 N 148 13 48.352 W -Polygon 2 60.20 6846.90 -3754.93 5986654.04 717705.02 70 21 58.036 N 148 13 51.318 W -Polygon 3 60.20 8278.34 -3712.57 5988086.04 717705.02 70 22 12.114 N 148 13 50.100 W -Polygon 4 60.20 6846.90 -3754.93 5986654.04 717705.02 70 21 58.036 N 148 13 51.318 W NK-61A Fault 2 60.20 6557.41 -3641.43 5986368.04 717827.02 70 21 55.189 N 148 13 47.994 W -Polygon 1 60.20 6557.41 -3641.43 5986368.04 717827.02 70 21 55.189 N 148 13 47.994 W -Polygon 2 60.20 6788.54 -4893.20 5986562.04 716569.02 70 21 57.456 N 148 14 24.608 W by BP Alaska Baker Hughes INTEQ Planning Report Ali%~ ~~s INTEQ Company: BP Amoco Date: 3/3/2006 Time: 14:41:30 Paget 2 Field: Niakuk Co~ordinate(NE) Refereace: WeII: NK-01, True North Site: NK Main Pad Vertical (TVD) Reference: 43:61 6/15/199815:00 60:2 Well: NK-61 Section (VS) Reference: Well (O.OON,O.OOE,328.12Azi) Wellpath: PIan4, NK-61A Sorvey Calca~tion Method:. Minimum Curvature Db: Oredo Targets Map Map <--- Latftode ---> <- Longitude -> Name Description TVD +N/-S +E!-W Northing Eaatlng Deg Min Sec Deg Min Sre Dip. Dir. ft ft ft ft ft NK-61A Fault 5 60.20 6270.69 -4703.43 5986050.05 716774.02 70 21 52.364 N 148 14 19.048 W -Polygon 1 60.20 6270.69 X703.43 5986050.05 716774.02 70 21 52.364 N 148 14 19.048 W -Polygon 2 60.20 8323.1 6 -4888.82 5988096.05 716528.02 70 22 12.548 N 148 14 24.509 W NK61 A Target 4 9160.20 8801.1 7 -4002.24 5988600.05 717400.03 70 22 17.255 N 148 13 58.581 W NK61A Target 2 9235.20 7201.80 -4049.57 5987000.05 717400.02 70 22 1.525 N 148 13 59.941 W NK61A Target 3 9235.20 8201.41 -4019.99 5988000.05 717400.03 70 22 11.356 N 148 13 59.091 W NK61A Target 1 9275.20 6246.25 -3877.75 5986050.04 717600.02 70 21 52.128 N 148 13 54.901 W Annotation MD TVD ft ft 1 11800.00 9153.25 TIP 11804.00 9156.97 KOP 11818.00 9169.72 End of 40 Deg/100' DLS 12001.97 9258.50 End of 35 Deg/100' DLS 12201.97 9253.03 5 12901.97 9238.90 6 13251.97 9235.95 7 13401.97 9235.41 8 13651.97 9235.44 9 14051.97 9235.48 10 14401.97 9235.51 11 14526.97 9227.34 12 15025.00 9159.83 TD Plan Section Information MD Intl Azim TVD +N/-S +E/-W DLS BoBd Turn TFO Target:, ft deg deg ft ft ft deg/100ft deg/100ft deg/1l>Oft deg 11800.00 21.63 324.74 9153.25 5834.57 -3540.43 0.00 0.00 0.00 0.00 11804.00 21.61 324.72 9156.97 5835.78 -3541.28 0.52 -0.49 -0.47 199.17 11818.00 27.21 324.72 9169.72 5840.50 -3544.62 40.00 40.00 0.00 0.00 12001.97 91.60 324.72 9258.50 5963.08 -3631.35 35.00 35.00 0.00 0.00 12201.97 91.50 304.71 9253.03 6103.03 -3772.70 10.00 -0.05 -10.00 270.00 12901.97 90.51 14.72 9238.90 6719.42 X000.44 10.00 -0.14 10.00 90.00 13251.97 90.42 339.72 9235.95 7063.59 -4017.16 10.00 -0.03 -10.00 270.00 13401.97 89.99 354.71 9235.41 7209.45 -4050.26 10.00 -0.29 10.00 91.60 13651.97 89.99 19.71 9235.44 7455.51 -4019.12 10.00 0.00 10.00 90.00 14051.97 89.99 339.71 9235.48 7847.43 -4021.09 10.00 0.00 -10.00 270.00 1 14401.97 90.00 14.71 9235.51 8191.61 -0037.85 10.00 0.00 10.00 90.00 ~ 14526.97 97.48 24.75 9227.34 8308.80 -3995.86 10.00 5.99 8.03 53.00 15025.00 97.10 334.52 9159.83 8786.54 -3999.01 10.00 -0.08 -10.09 273.00 Survey MD Inca Aim Sys TVD N/S E/W MapN MapE DLS VS TFq Toot.: ft deg deg ft ft ft ft ft degl100ft ft deg 11800.00 21.63 324.74 9093.05 5834.57 -3540.43 5985648.54 717949.35 0.00 6824.32 0.00 MWD 11804.00 21.61 324.72 9096.77 5835.78 -3541.28 5985649.72 717948.47 0.52 6825.79 199.17 MWD 11807.49 23.01 324.72 9100.00 5836.86 -3542.05 5985650.78 717947.67 40.00 6827.11 360.00 NK61A T 11810.00 24.01 324.72 9102.30 5837.68 -3542.63 5985651.58 717947.07 40.00 6828.11 0.00 MWD 11818.00 27.21 324.72 9109.52 5840.50 -3544.62 5985654.34 717944.99 40.00 6831.56 0.00 MWD 11820.00 27.91 324.72 9111.29 5841.25 -3545.16 5985655.08 717944.43 35.00 6832.48 0.00 MWD 11830.00 31.41 324.72 9119.98 5845.29 -3548.02 5985659.03 717941.45 35.00 6837.42 0.00 MWD 11840.00 34.91 324.72 9128.35 5849.76 -3551.17 5985663.40 717938.17 35.00 6842.88 0.00 MWD 11850.00 38.41 324.72 9136.37 5854.63 -3554.62 5985668.17 717934.57 35.00 6848.84 0.00 MWD 11860.00 41.91 324.72 9144.01 5859.89 -3558.35 5985673.32 717930.70 35.00 6855.28 0.00 MWD 11870.00 45.41 324.72 9151.24 5865.53 -3562.33 5985678.84 717926.54 35.00 6862.17 0.00 MWD 11880.00 48.91 324.72 9158.04 5871.51 -3566.57 5985684.69 717922.14 35.00 6869.49 0.00 MWD 11890.00 52.41 324.72 9164.38 5877.83 -3571.03 5985690.87 717917.48 35.00 6877.21 0.00 MWD by BP Alaska Baker Hughes INTEQ Planning Report ~t~ s `mss INTEQ Company: BP Amoco Date: 3!3/2008 Time: 14:41:30 . Page: 3 Field: Niakuk Co-ordiaate(NE) Reference: Well: NK-61 , This North Site: NK Mairt Pad Vertkal (TVD) Reference: 43 : 61 6115/199815:00 60.2 Weil: NK-61 Sectloa (VS) Reference: Well (O.OON ,O.p0E,328.1 2Aai) Wellpatb: PIan4, NK-61A Survey Caknlatton Method: Minimum Curvature Db: Orade Survey MD Iocl A~Jm Sya TVD N/S EIW MapN MapE DILS VS TFO Toei ft deg deg ft ft ft ft ft deg1100ft ft deg: 11900.00 55.91 324.72 9170.23 5884.44 -3575.72 5985697.34 717912.61 35.00 6885.30 0.00 MWD 11908.86 59.01 324.72 9175.00 5890.54 -3580.03 5985703.31 717908.12 35.00 6892.76 360.00 NK61A T 11910,00 59.41 324.72 9175.58 5891.34 -3580.60 5985704.09 717907.53. 35.00 6893.73 0.00 MWD 11920.00 62.91 324.72 9180.40 5898.49 -3585.65 5985711.09 717902.26 35.00 6902.47 0.00 MWD 11930.00 66.41 324.72 9184.68 5905.87 -3590.87 5985718.31 717896.83 35.00 6911.49 0.00 MWD 11940.00 69.91 324.72 9188.40 5913.44 -3596.23 5985725.72 717891.24 35.00 6920.76 0.00 MWD 11950.00 73.41 324.72 9191.55 5921.19 -3601.71 5985733.30 717885.54 35.00 6930.23 0.00 MWD 11960.00 76.91 324.72 9194.11 5929.08 -3607.30 5985741.03 717879.72 35.00 6939.88 0.00 MWD 11970.00 80.41 324.72 9196.08 5937.08 -3612.96 5985748.86 717873.83 35.00 6949.67 0.00 MWD 11980.00 83.91 324.72 9197.44 5945.17 -3618.68 5985756.77 717867.87 35.00 6959.55 0.00 MWD 11990.00 87.41 324.72 9198.20 5953.31 -3624.44 5985764.73 717861.87 35.00 6969.51 0.00 MWD 12000.00 90.91 324.72 9198.34 5961.47 -3630.21 5985772.72 717855.86 35.00 6979.49 0.00 MWD 12001.97 91.60 324.72 9198.30 5963.08 -3631.35 5985774.30 717854.68 35.00 6981.45 0.00 MWD 12050.00 91.59 319.92 9196.96 6001.06 -3660.69 5985811.39 717824.23 10.00 7029.20 270.00 MWD 12100.00 91.58 314.91 9195.58 6037.85 -3694.50 5985847.16 717789.35 10.00 7078.30 269.87 MWD 12150.00 91.55 309.91 9194.21 6071.55 -3731.39 5985879.76 717751.48 10.00 7126.40 269.73 MWD 12201.97 91.50 304.71 9192.83 6103.03 -3772.70 5985910.00 717709.26 10.00 7174.95 269.59 MWD 12250.00 91.50 309.52 9191.57 6131.99 -3810.97 5985937.82 717670.15 10.00 7219.75 90.00 MWD 12300.00 91.48 314.52 9190.27 6165.44 -3848.09 5985970.15 717632.05 10.00 7267.76 90.13 MWD 12350.00 91.45 319.52 9188.99 6202.00 -3882.16 5986005.68 717596.92 10.00 7316.79 90.26 MWD 12400.00 91.41 324.52 9187.74 6241.38 -3912.91 5986044.14 717565.02 10.00 7366.48 90.38 MWD 12450.00 91.36 329.52 9186.52 6283.30 -3940.11 5986085.23 717536.60 10.00 7416.44 90.51 MWD 12500.00 91.30 334.52 9185.36 6327.43 -3963.55 5986128.65 717511.86 10.00 7466.29 90.63 MWD 12550.00 91.23 339.52 9184.25 6373.44 -3983.05 5986174.06 717491.01 10.00 7515.66 90.75 MWD 12600.00 91.16 344.53 9183.21 6420.97 -3998.48 5966221.11 717474.19 10.00 7564.17 90.86 MWD 12650.00 91.07 349.53 9182.24 6469.67 -4009.70 5986269.46 717461.53 10.00 7611.45 90.96 MWD 12700.00 90.97 354.53 9181.35 6519.17 -4016.63 5986318.72 717453.14 10.00 7657.14 91.06 MWD 12750.00 90.87 359.52 9180.54 6569.08 -4019.22 5986368.53 717449.07 10.00 7700.89 91.15 MWD 12800.00 90.76 4.52 9179.84 6619.02 -4017.46 5986418.51 717449.36 10.00 7742.37 91.23 MWD 12850.00 90.64 9.52 9179.23 6668.63 -4011.35 5986468.27 717454.00 10.00 7781.27 91.30 MWD 12901.97 90.51 14.72 9178.70 6719.42 -4000.44 5986519.36 717463.40 10.00 7818.64 91.36 MWD 12950.00 90.51 9.92 9178.27 6766.33 -3990.19 5986566.55 717472.25 10.00 7853.06 270.00 MWD 13000.00 90.51 4.92 9177.83 6815.89 -3983.74 5986616.28 717477.23 10.00 7891.74 269.96 MWD 13050.00 90.50 359.92 9177.39 6865.83 -3981.64 5986666.25 717477.86 10.00 7933.03 269.91 MWD 13100.00 90.48 354.92 9176.96 6915.76 -3983.89 5986716.10 717474.13 10.00 7976.62 269.87 MWD 13150.00 90.47 349.92 9176.55 6965.31 -3990.49 5986765.42 717466.07 10.00 8022.18 269.83 MWD 13200.00 90.45 344.92 9176.15 7014.09 -4001.38 5986813.86 717453.74 10.00 8069.35 269.78 MWD 13251.97 90.42 339.72 9175.75 7063.59 -4017.16 5986862.86 717436.51 10.00 8119.72 269.74 MWD 13300.00 90.29 344.52 9175.46 7109.28 -4031.90 5986908.10 717420.42 10.00 8166.31 91.60 MWD 13350.00 90.14 349.52 9175.27 7157.99 -4043.13 5986956.45 717407.76 10.00 8213.60 91.63 MWD 13401.97 89.99 354.71 9175.21 7209.45 -4050.26 5987007.68 717399.11 10.00 8261.06 91.65 MWD 13450.00 89.99 359.51 9175.21 7257.40 -4052.67 5987055.54 717395.28 10.00 8303.06 90.00 MWD 13500.00 89.99 4.51 9175.22 7307.36 -4050.92 5987105.52 717395.55 10.00 8344.55 90.00 MWD 13550.00 89.99 9.51 9175.23 7356.97 -4044.81 5987155.28 717400.19 10.00 8383.45 90.00 MWD 13600.00 89.99 14.51 9175.23 7405.86 -4034.41 5987204.46 717409.14 10.00 8419.47 90.00 MWD 13651.97 89.99 19.71 9175.24 7455.51 -4019.12 5987254.54 717422.96 10.00 8453.56 90.00 MWD 13700.00 89.99 14.91 9175.24 7501.35 -4004.83 5987300.78 717435.88 10.00 8484.94 270.00 MWD 13750.00 89.99 9.91 9175.25 7550.17 -3994.09 5987349.89 717445.17 10.00 8520.72 270.00 MWD 13800.00 89.99 4.91 9175.26 7599.73 -3987.65 5987399.62 717450.15 10.00 8559.40 270.00 MWD 13850.00 89.99 359.91 9175.26 7649.67 -3985.54 5987449.60 717450.77 10.00 8600.70 270.00 MWD 13900.00 89.99 354.91 9175.27 7699.61 -3987.80 5987499.44 717447.04 10.00 8644.29 270.00 MWD 13950.00 89.99 349.91 9175.27 7749.15 -3994.41 5987548.77 717438.97 10.00 8689.85 270.00 MWD 14000.00 89.99 344.91 9175.28 7797.93 -4005.30 5987597.21 717426.64 10.00. 8737.03 270.00 MWD 14051.97 89.99 339.71 9175.28 7847.43 -4021.09 5987646.21 717409.40 10.00 8787.40 270.00 MWD 14100.00 90.00 344.51 9175.28 7893.12 -4035.84 5987691.45 717393.30 10.00 8833.99 90.00 MWD 14150.00 90.00 349.51 9175.29 7941.83 X047.07 5987739.80 717380.64 10.00 8881.28 90.00 MWD 14200.00 90.00 354.51 9175.29 7991.33 -4054.01 5987789.07 717372.23 10.00 8926.98 90.00 MWD • by BP Alaska Baker Hughes INTEQ Planning Report ~e~ ski ins INTEQ Company: BP Amoco Date: 3/3/2006 Time: 14:41:30 Page: 4 Field: Niakuk Co~ordinate(NE) Reference: Well: NK-61 , True North Site: NK Main Pad Vertical (TVD) Retereoce: 43:61 6/15/199815:00 60.2 Well: NK-61 Sectlou (V5) Reference: Well (11.00iV ,0.00E,328.1 2Azi) Wellpsth: PIan4, NK-61 A 5nrvey Calculation Method: Minimum Curvature Db: OraGe Survey MD Incl A~alm Sys TVD N/S E/W MspN MapE DLS VS TFO Tool ft deg. - deg ft ft ft ft ft deg/100ft ft deg 14250.00 90.00 359.51 9175.30 8041.25 -4056.61 5987838.89 717368.16 10.00 8970.74 90.00 MWD 14300.00 90.00 4.51 9175.30 8091.20 -4054.86 5987888.87 717368.44 10.00 9012.23 90.00 MWD 14350.00 90.00 9.51 9175.31 8140.81 -4048.75 5987938.63 717373.07 10.00 9051.13 90.00 MWD 14401.97 90.00 14.71 9175.31 8191.61 -4037.85 5987989.73 717382.46 10.00 9088.51 90.00 MWD 14450.00 92.88 18.55 9174.10 8237.60 -4024.11 5988036.10 717394.84 10.00 9120.31 53.00 MWD 14500.00 95.88 22.57 9170.28 8284.26 -4006.61 5988083.26 717410.95 10.00 9150.69 53.10 MWD 14526.97 97.48 24.75 9167.14 8308.80 -3995.86 5988108.10 717420.96 10.00 9165.85 53.40 MWD 14550.00 97.59 22.43 9164.12 8329.72 -3986.73 5988129.28 717429.48 10.00 9178.79 273.00 MWD 14600.00 97.80 17.39 9157.42 8376.29 -3969.86 5988176.33 717444.96 10.00 9209.43 272.70 MWD 14650.00 97.95 12.35 9150.57 8424.14 -3957.15 5988224.54 717456.25 10.00 9243.35 272.02 MWD 14700.00 98.03 7.30 9143.61 8472.92 -3948.71 5988273.54 717463.24 10.00 9280.31 271.33 MWD 14750.00 98.06 2.25 9136.61 8522.24 -3944.59 5988322.96 717465.90 10.00 9320.01 270.63 MWD 14800.00 98.02 357.20 9129.62 8571.73 -3944.83 5988372.42 717464.20 10.00 9362.16 269.92 MWD 14850.00 97.92 352.15 9122.68 8621.01 -3949.43 5988421.54 717458.15 10.00 9406.44 269.21 MWD 14900.00 97.76 347.11 9115.86 8669.72 -3958.34 5988469.96 717447.79 10.00 9452.51 268.51 MWD 14950.00 97.54 342.07 9109.20 8717.48 -3971.51 5988517.31 717433.22 10.00 9500.02 267.82 MWD 15000.00 ~ 97.26 337.03 9102.75 8763.92 -3988.83 5988563.22 717414.54 10.00 9548.60 267.15 MWD 15025.00 97.10 334.52 9099.63 8786.54 -3999.01 5988585.52 717403.69 10.00 9573.19 266.50 3.50" • • a ~~ `!d ....-: . - t-. -.- ... ~ = - - ._ .. a--... .a-... ¢ ::, ~ E fdg j ~d~ ~ ~_:# : _r - '~ _+. -r -j iE 4d i ~ ~ --~ -~ --..f _...i a ._ i .~ - :j - -7 _i _{ ~i -- ~4 Q --' :~ ~~~ c~, .1 _'_.__~ .............................1. _._. i 8 8 C a IUI (')Y~~PUI-)41~w5 ~~ ~ z ,. -a ............... ;~qq;scg9t :ie = 9tadIIIIdBdR _ -- - SSS..• Y•S I deav:d=o:a __ _ 3 g 8 1 q sagggq@g8gq ~ddEl~i~&S -• 8 F °9 G9L.9~9:~ f': z 888e®88888 LiS4 8 0 ~~~$ r 8586888888888 E w~ ~~ g S adBSaae°:3999 c!f ~ ~R a a a ~ s{~{pp~F#F#~ g 33~~~~$~s~~ ~ ~ ~~i3~ii6ii :5. 5. 5 Baez...... ~~ Y ;;;qq:=;;9.9ge ::sssa:ass ~ 3 asassss; i 9gga55cc;c.5;5sz9z E3c@s@~A~ ~~5.~~~:~YBiyS < 4 8n5a5°R.: I .«....~..__'_ 88899x.:. ....Q .. _..-. ~._...,. 4J~aO Qe~111~/~ 61111 Q.-•_. :@ c .~~ . ~ - :~, ~ _- - _ ~ - A -- -' _ _. _.. __ - ---- -- - - ~$ ~~ 8~, g 0 g® C Y . > are from top of Riser 3/3/2006 i ~_ ~ N K-61 A of bag BAG bttm of bag of blind/shear Blind/Shears TOTs l of pipes/slip 2~~ combi ram/slips ~ ~ Mud Cross I I Mud Cross of flow cross of pipe/slip 2 3/8~~ pipe/slip TOTs ~ middle of pipe/slips 2~~ pipe/slips Flow Tee • • TERRY L RUBBLE as-si~2s2 259 BP EXPLORATION AK INC "Mastercard Check" PO BOX .1.966.12 MB 7-5 ANCHORAGE, AK 99519-86.12 OATE W Q~'~~p PAY TO THE I! ~ ~ $ f ~ • ~~ O ER OF ddw77~ DOLLARS First National Bank Alaska Anchorage, )AK 99501 MEMO/ V ~~ ~ ~~ ~:1 2 5 200060:9914••~622?••~L556t1' 0259 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~11 /f~,~''=~~[~ PTD# 2~~ - Q ~`S _~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (,Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checklist C~^ N ~ ~ ~ ~ ~ ', ~ ~ ,~ ~ : i ~ ~ ~ ~ ~, y ~ ~ ~ ~ ~ j 0 > L C f0 ~ ~ ~ O ` a ~I ; Q •~ ' Iii Y ~ Q' Ili : ~) ~ i al •4 m o w i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~~~ o ~ ~~ ~ ~ ~~ ~ ~~ ~ ~~ ~ ~ ~~ ~~ ~ ~ M~ _ ~ i a o o~ ~ ~! of j i g i Q ~~ ui o ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~' ~ ~ N~ oo ~ ~ D ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~ ~~ ~~ I I I N~ V4 N1~ M~ N~ N~ 4A tlD N~ tlY !q N (/!~ ~ (A~ N., VA H~ N~ N~ N~ N~ N~ N~ 41, Q O a~ a~: a~ m: d a~ m a~: m: a~: m d: a~ Q, Q. Q. Q. Q. Q. Q. a~ a~ m: a~ m. Q. a~ a~ m. a~ a~: m. Q. it Q. Q. Q. Q o. } } >- }, } } }: } } } } } >-, Z, Z, Z, Z, Z, Z', Z, Z, ~: ~, >-, }, ~, Z, }, ~: ~. }, ~, ?•: Z, ; Z, Z, Z, Z, Z, ~~ E: 3. : - ~ : i ~ ~3' ~ , : O o' ~ : ~ I T : i ~~ :i : °~ c s, o, : ~. o. ~: I -: >; a~: a ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~. c' ar ~~ ~, c' I Z O 3: "' p, >' •~' •`O. N: ~ N ~ N (wj~ ~: N. D: C, ~ p, N a ~, ~~ ~ ~: ; a~ N. ~ y~ U = a~' °' is >; a~ O' a W Z ~ ~: o c. a' w y: •c: a. m, > ~ o~ I ~~ ~, ~~ >' m: v 4 ~ o~ ~ ~ ~ ~, c c ~ o o g p 'aa-~ ~ E'. E'. =. v. ~: c, c E; ~', ~ ~; o m. I c' c: u : ~"~ ..~ c ° °~' c, °:', ~' c: ax ~' °'rn ~; N: ~, d = I Y o o a` o v' ~' ~: m: •~ c. t ~ o: o. rn ~ V '¢ ~ 4 ~ o y: a °-: n 3 i ° >' rn o' " ~ ~ ~ ~ ~ O' N~ v- C~ .C~ O, ~ 7 •i°-~ 'p fp: O U i ~ y .0.~ ~, 0: N' t6. ~ E, ~ ~ ~~ Q' ~' 10]' N~ T O: N' a . QI d ~: 4 c, `c~, ~ m. ~ ~ t, t a, ~, ~ ~ :: ~ a' m ~ ~~ o- ~~ m. ° %' ~=: a ~ ~ o ~. n a 3 ' o f6; o; v 3: i ~ (0, C• a. N, w: f6. ~ O~ .0. ~ a ~~ a: tA~ N. i C. ~~ M, ~p~ N: t: N. N. O. ~ ~..-, C. >'r ' Z; 'a a: ~ N. N, ~m d' a' ~, 3; •3: ~ ~, m. ..: •~ •a_, ~; •~: ~; o ~, ~ o, ~ o y, a .a ~ ~: o. 3, o t Z, ~. o ~ a~ °~ ~ ~, a, a~ ~ ~ ~~ o ~~ ~~ ~~ °~ ~~~ ~' U ~ ~~ o ~ ~~ Y, ~ ° °~' ~ a m' °~ of o' s tq •°-' ~ °: c o u°i, ~ ~" Hl o o: o a d' a~' a~ - a~: ~' ~~ °: 5' v as .«- °, a; °:~ -, a ai ~ ~': d E, c v. N: '"' ~ a c .~ °tS ~ ~ m ~: ° o o ~ 3 ~: ~ y'. N', m ~ ~; ;c, o, ~ ~ ~ ~; ~, ~, y': ~ N' ~: ~, a ~ '~ a. 3: _ ~', ~ !~, a: • ~, o: °. v p~ m m ~ S. a a ~ w >; m y m. 3' c a ~ ~ c yr or m' c ~ °: - •5 n o: ~: o o. i ~ c> >, ' ' d ~ Ji ~ Q -' a a: a: V ~ N ~: .Q, ~_ a. .t.. I N~ •y. N. N. >~ ~ ~, L, N ~ y~ •t: U' U. Q~ C l9~ ~~ ~~ O. t-~ c c m. ~ °: ~ W' w o. 3: m. m. ~ u~: ~, o E m, .° LL i o o: -: -o u?, •-: n?, ~ ~ Q ~ -_, c i ° y c v `~' v `o' o c' v ~ t'i. o: o: - io. m ui °: c ~, a: t!1 al ~ ~ o' o o ~ ~ ~, m o. o' ~ n p_ ~ ~ ~ > > 3' ~ ~ ~'~ o; ~ ~ w. w, ° 3' ° m li n '~: i m~~ Y ~' m: a°i c o o m ~ -a n o. ~' ~ m; °' -~' ~ U o. ~' ~, ~, ~ ~: v m. v; a = O O' r; ~' °- aUi ~' m ~ a`6i o to ~ a J: ~ ~' ~: ~, cn, 4-, o, o a a c~, ~' a: a; a: , v ~n ~, ~, v, ~, a. ~ a ~_: o m m ~. ~, ~' ~ a o ~ ~ ~ O ~ N M~~ t0 t~ 00 O O ~ O' O ~ N M~ ~O (O ~~ N N N N N .N N N N_N M_ M M__M _M M M M M M e- N M V' t0 Cfl I~ O O ~ r ~- ~ ~- r .- --- ~-- U -~------------ c Y 00 I ,4i 0 ~ w O G O C lp N I ld N ~ R N ~ ~n o p o ~ rn I ~o {LI O ~ M C M M T J N ~c ~ j c ~ Q ~ o ~ U J °, U ~~ p o Q a ~ ~a a ~ iW ate' Icy _a~ I • Well History File APPENDIX Inforrmation of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify T`inding information, information of this nature is accumulated at the end of tl~e file under APPENDIX. No special effort has been made to chronologically organize this category of information. s nk-61a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LiSLib $Revision: 4 $ Mon Feb 18 16:29:36 2008 Reel Header Service name .............LISTPE Date . ...................08/02/18 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................sTS LIS writing Library. Scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/02/18 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 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 JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: MWD RUN 1 w-0004300638 B. JAHN B. LAULE / R MWD RUN 5 w-0004300638 B. JAHN B. LAULE / R MWD RUN 8 w-0004300638 S. LATZ R. WHITLOW / NK-61A 500292289301 BP Exploration (Alaska) Inc. Sperry Drilling Services 18-FEB-08 MWD RUN 2 w-0004300638 B. JAHN B. LAULE / R MWD RUN 6 w-0004300638 B. JAHN B. LAULE / R MWD RUN 9 w-0004300638 S. LATZ R. WHITLOW / 36 Page 1 ~b~ o3S ~/S`3~5 MWD RUN 4 w-0004300638 B. JAHN B. LAULE / R MWD RUN 7 w-0004300638 S. LATZ R. WHITLOW / MWD RUN 10 w-0004300638 S. LATZ R. WHITLOW / C~ J nk-61a.tapx TOWNSHIP: 12N RANGE: 15E FNL: FSL: 1383 FEL: 900 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 59.40 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 3.000 3.500 11806.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 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 CEMENT RAMP IN THE NK-61 WELLBORE. THE TOP OF THE RAMP WAS AT 11798'MD/9102'TVDSS. 4. MWD RUNS 1-10 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. SROP DATA FOR RUNS 1,2 ARE INCLUDED FOR QUALITY CONTROL PURPOSES. NO PROGRESS WAS MADE ON MWD RUN 3. 5. LOG AND MERGED DIGITAL DATA (LDWG) WERE SHIFTED TO A SCHLUMBERGER OPEN HOLE GAMMA RAY RUN ON 11 JULY 1998. THESE LOG DATA WERE PROVIDED BY D.DORTCH (SAIC/BP) ON 27 NOVEMBER 2007, PER DAVE BOYER (BP). LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THIS SHIFTED LOG IS THE PDC FOR NK-61A. 6. MWD RUNS 1-10 REPRESENT WELL NK-61A WITH API#: 50-029-22893-O1. THIS WELL REACHED A TOTAL DEPTH(TD)OF 15120'MD/9112'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED NATURAL GAMMA RAY. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Page 2 nk-61a.tapx Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6,000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP 1 and clipped curves; all bit runs merged. .5000 START DEPTH STOP DEPTH 11578.5 15097.0 11606.0 15121.0 BASELINE CURVE FO R SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 11583.5 11584.0 11589.5 11589.0 11595.0 11595.0 11599.0 11598.0 11603.5 11603.0 11605.0 11604.5 11607.0 11606.5 11608.0 11608.0 11614.5 11613.5 11616.0 11615.0 11617.5 11616.5 11619.5 11618.5 11621.0 11620.0 11631.0 11630.0 11634.5 11634.0 11637.5 11637.0 11641.5 11641.0 11643.0 11643.0 11651.0 11650.0 11653.5 11652.5 11656.5 11655.5 11662.5 11661.5 11664.0 11663.0 11671.0 11669.5 11675.5 11675.0 11682.0 11680.5 11683.0 11681.5 11686.5 11685.5 11692.0 11691.0 11694.0 11693.0 11697.5 11697.0 11705.0 11704.0 11707.0 11706.5 11712.5 11712.0 11714.0 11713.5 11723.5 11722.5 11726.0 11725.0 11733.5 11732.5 11736.0 11735.0 11739.0 11738.0 11749.0 11748.5 11752.5 11751.5 Page 3 C~ nk-61a.tapx 11756.5 11755.5 11760.0 11759.5 11767.5 11767.0 11769.0 11768.5 11798.0 11798.0 11801.0 11800.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 1 11579.0 11805.5 MwD 2 11805.5 11820.0 MWD 4 11820.0 11823.0 MwD 5 11823.0 11940.0 MwD 6 11940.0 13072.0 MWD 7 13072.0 14625.5 MwD 8 14625.5 14712.0 MwD 9 14712.0 15026.0 MWD 10 15026.0 15120.0 REMARKS: MERGED MAIN PA55. 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 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11578.5 15121 13349.8 7086 11578.5 15121 GR MWD API 27.31 316.2 67.1731 7038 11578.5 15097 ROP MWD FT/H 0.01 2683.8 72.3109 7031 11606 15121 First Reading For Entire File..........11578.5 Last Reading For Entire File...........15121 File Trailer service name... .......sTSLIB.001 service sub Level Name... Version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type ................Lo Next File Name...........sTSLIB.002 Page 4 . ~ t~ ! nk-61a.tapx Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11579.0 11777.5 RoP 11605.5 11805.5 LOG HEADER DATA DATE LOGGED: 31-MAR-06 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11806.0 TOP LOG INTERVAL (FT): 11605.0 BOTTOM LOG INTERVAL (FT): 11806.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.0 MAXIMUM ANGLE: 21.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG005 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 2.750 DRILLER'S CASING DEPTH (FT): 11806.0 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 65.0 MUD PH: .0 MUD CHLORIDES (PPM): 0 FLUID LOSS (c3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 137.5 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .0 Page 5 s NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): nk-61a.tapx 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 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 11579 11805.5 11692.3 454 11579 11805.5 GR MwD010 API 87.18 316.2 156.633 398 11579 11777.5 ROP MWDO10 FT/H 0.09 296.64 26.9485 401 11605.5 11805.5 First Reading For Entire File..........11579 Last Reading For Entire File...........11805.5 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File 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.......08/02/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Page 6 nk-61a.tapx Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11778.0 11792.5 RoP 11806.0 11820.0 LOG HEADER DATA DATE LOGGED: O1-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11820.0 TOP LOG INTERVAL (FT): 11806.0 BOTTOM LOG INTERVAL (FT): 11820.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.0 MAXIMUM ANGLE: 21.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG005 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 2.750 DRILLER'S CASING DEPTH (FT): 11806.0 BOREHOLE CONDITIONS MUD TYPE: KCL MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): .0 MUD PH: .O MUD CHLORIDES (PPM): 14000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 137.5 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format Specification Record Data Record Type ..................0 Page 7 nk-61a.tapx Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999.25 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 • Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11778 11820 11799 85 11778 11820 GR MwD020 API 144.39 197.88 171.115 30 11778 11792.5 ROP MWD020 FT/H 0.01 11.95 3.30724 29 11806 11820 First Reading For Entire File..........11778 Last Reading For Entire File...........11820 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.,.....08/02/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and .log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11793.0 11798.0 ROP 11820.5 11823.0 Page 8 nk-61a.tapx LOG HEADER DATA DATE LOGGED: 02-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11823.0 TOP LOG INTERVAL (FT): 11820.0 BOTTOM LOG INTERVAL (FT): 11823.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.0 MAXIMUM ANGLE: 21.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG016 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.000 DRILLER'S CASING DEPTH (FT): 11806.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 65.0 MUD PH: 8.7 MUD CHLORIDES (PPM): 74500 FLUID LOSS (C3): 8.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 142.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD040 API 4 1 68 4 2 Page 9 nk-61a.tapx RoP MWD040 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11793 11823 11808 61 11793 11823 GR MWD040 API 160.7 259.16 198.514 11 11793 11798 ROP MWD040 FT/H 14.68 23.76 18.2617 6 11820.5 11823 First Reading For Entire File..........11793 Last Reading For Entire File...........11823 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type ................L0 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.......08/02/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11798.5 11916.0 ROP 11823.5 11940.0 LOG HEADER DATA DATE LOGGED: 02-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11940.0 TOP LOG INTERVAL (FT): 11823.0 BOTTOM LOG INTERVAL (FT): 11940.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 21.6 Page 10 MAXIMUM ANGLE: nk-61a.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG 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.....0 Loging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 65.5 TOOL NUMBER TL0005 3.000 11806.0 Flo Pro 9.00 65.0 8.7 74500 8.0 .000 .0 .000 142.0 .000 .0 .000 .0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MwD050 API 4 1 68 4 2 ROP MwD050 FT/H 4 1 68 8 3 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 11798.5 11940 11869.3 284 11798.5 11940 GR MwD050 API 47.85 145.74 83.3442 236 11798.5 11916 ROP MWD050 FT/H 0.41 57.93 24.3672 234 11823.5 11940 First Reading For Entire File..........11798.5 Last Reading For Entire File...........11940 Page 11 r nk-61a.tapx File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File TyC~e ................L0 Next File Name...........STSLIB.006 Physical EOF File Header Service name... .... .STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11916.5 13048.0 RoP 11940.5 13072.0 LOG HEADER DATA DATE LOGGED: 04-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13072.0 TOP LOG INTERVAL (FT): 11940.0 BOTTOM LOG INTERVAL (FT): 13072.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 78.6 MAXIMUM ANGLE: 93.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG005 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.000 DRILLER'S CASING DEPTH (FT): 11806.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro Page 12 nk-61a.tapx MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 65.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 74500 FLUID LOSS (C3): 6.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 162.8 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ...... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD060 API 4 1 68 4 2 ROP MwD060 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11916.5 13072 12494.3 2312 11916.5 13072 GR MWD060 API 27.31 111.26 66.4852 2264 11916.5 13048 ROP MWD060 FT/H 1.73 944.53 69.1171 2264 11940.5 13072 First Reading For Entire File..........11916.5 Last Reading For Entire File...........13072 File Trailer Service name... .......STSLIB.006 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Page 13 1 V nk-61a.tapx Physical EOF File Header Service name... .......STSL2B.007 Service sub Level Name... Version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13048.5 14602.0 RoP 13072.5 14625.5 LOG HEADER DATA DATE LOGGED: 07-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14625.0 TOP LOG INTERVAL (FT): 13072.0 BOTTOM LOG INTERVAL (FT): 14625.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.1 MAXIMUM ANGLE: 93.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG016 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.000 DRILLER'S CASING DEPTH (FT): 11806.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 65.0 MUD PH: 8.7 MUD CHLORIDES (PPM): 139000 FLUID LOSS (C3): 5.4 RESISTIVITY (OHMM) AT TEMPERATU RE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMP ERATURE: .000 175.0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: Page 14 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): nk-61a.tapx REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD070 API 4 1 68 4 2 ROP MWD070 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13048.5 14625.5 13837 3155 13048.5 14625.5 GR MWD070 API 29.76 96.7 54.1688 3108 13048.5 14602 ROP MWD070 FT/H 0.59 409.12 81.0471 3107 13072.5 14625.5 First Reading For Entire File..........13048.5 Last Reading For Entire File...........14625.5 File Trailer Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.008 Physical EOF File Header service name... .......STSLIB.008 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.007 Comment Record FILE HEADER Page 15 ~ ~ nk-61a.tapx FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14602.5 14688.5 ROP 14626.0 14712.0 LOG HEADER DATA DATE LOGGED: 08-APR-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 3.35 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14712.0 TOP LOG INTERVAL (FT): 14625.0 BOTTOM LOG INTERVAL (FT): 14712.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 94.1 MAXIMUM ANGLE: 95.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER PCG Natural gamma ray TLG016 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.000 DRILLER'S CASING DEPTH (FT): 11806.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 65.0 MUD PH: 8.6 MUD CHLORIDES (PPM): 135500 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 179.7 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Page 16 nk-61a.tapx optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MWD080 API 4 1 68 4 2 ROP MWD080 FT/H 4 1 68 8 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 14602.5 14712 14657.3 220 14602.5 14712 GR MWD080 API 37.04 74.46 54.2638 173 14602.5 14688.5 ROP MWD080 FT/H 0.51 2683.8 98.1881 173 14626 14712 First Reading For Entire File..........14602.5 Last Reading For Entire File...........14712 File Trailer Service name... .......STSLIB.008 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.009 Physical EOF File Header Service name... .......STSLIB.009 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 14689.0 15002.5 RoP 14712.5 15026.0 LOG HEADER DATA Page 17 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: nk-61a.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG 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 (DEG F) 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: 09-APR-06 Insite 3.35 Memory 15026.0 14712.0 15026.0 91.4 97.7 TOOL NUMBER TLG016 3.000 11806.0 Flo Pro 9.60 65.0 8.6 135500 4.8 .000 .0 .000 180.0 .000 .0 .000 .0 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 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ...... Datum Specification Block sub-type...0 Name Service Order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD090 API 4 1 68 4 2 ROP MwD090 FT/H 4 1 68 8 3 Page 18 i nk-61a.tapx First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 14689 15026 14857.5 675 14689 15026 GR MWD090 API 42.48 83.15 63.1447 628 14689 15002.5 ROP MWD090 FT/H 0.22 985.91 92.8666 628 14712.5 15026 First Reading For Entire File..........14689 Last Reading For Entire File...........15026 File Trailer Service name... .......STSLIB.009 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.010 Physical EOF File Header Service name... .......STSLIB.O10 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 15003.0 15096.0 RoP 15026.5 15120.0 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 ANGLE: Page 19 10-APR-06 Insite 3.35 Memory 15120.0 15026.0 15120.0 93.2 98.4 . nk-61a.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG 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 (DEG F) 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: TOOL NUMBER TL0005 2.750 11806.0 Flo Pro 9.60 65.0 8.6 136000 5.8 .000 .0 .000 180.0 .000 .0 .000 .0 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 .11N Max frames per record .............undefined Absent value ......................-999.25 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 GR MwD100 API 4 1 68 4 2 ROP MwD100 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 15003 15120 15061.5 235 15003 15120 GR MwD100 API 65.49 170.98 80.1843 187 15003 15096 ROP MWD100 FT/H 1.22 119.11 43.1751 188 15026.5 15120 First Reading For Entire File..........15003 Last Reading For Entire File...........15120 Page 20 nk-61a.tapx File Trailer Service name... .......STSLIB.O10 Service Sub Level Name... version Number. ........1.0.0 date of ~eneration.......08/02/18 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.011 Physical EOF Tape Trailer Service name .............LISTPE date . ...................08/02/18 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE gate . ...................08/02/18 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF Physical EOF End Of LIS File scientific Technical services scientific Technical Services Page 21
