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209-032
SOF ? S ID • yw\����y/���� THE STATE Alaska Oil and Gas 0►�� OfA LAsKA Conservation Commission c _,� 333 West Seventh Avenue wR GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O m Main: 907.279.1433 ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov Marc Kuck Well Operations Manager Eni US Operating Co. Inc. SCANNED JAI 0 9 2017, 3800 Centerpoint Drive, Suite 300 Anchorage,AK 99503 Re: Nikaitchuq Field, Ivishak Undefined WTRSP Pool, OP23-WW02 Permit to Drill Number: 209-032 Sundry Number: 316-311 Dear Mr. Kuck: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 84c-lay of June, 2016. RBDMS JUN 1 3 2016 • RECEIVED • STATE OF ALASKA JUN 0 2 16` / • ALASKA OIL AND GAS CONSERVATION COMMISSION 7'S 8/ b APPLICATION FOR SUNDRY APPROVALS BOG 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _ESP Change Out E 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Eni US Operating Co.Inc. Exploratory ❑ Development ❑ 209-032 - 3.Address: Stratigraphic EIService Q,, 6.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 WA-£e 5.'c„t-%Gt 50-029-23411-00-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No [✓f *t OP23-VVVV02 . 9.Property Designation(Lease Number): 10.Field/Pool(s): 0373301, 0355024, 0390616 ' Nikaitchuq . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,323' - 9,550 - 12,323 - 9,550 _ 3376 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20” 154 154 Surface 4594 13 3/8" 4595 3745 5,210 2,480 Intermediate 9087 9 5/8" 9087 6613 6,890 4,790 Production Liner 3435 7" 12323 9550 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,557'-12,045' . 8,791'-9,274' 4 1/2" 13 Cr L-80 8,888 Packers and SSSV Type: TR-MAXX 5 E SSSV 3.81"X profile 1/4"SS Packers and SSSV MD(ft)and ND(ft): . SSSV 2,23T MD/2,198'ND hyd control line 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development❑ Service 0 ' 14.Estimated Date for 15-Aug-16 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ * WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: 'water source x GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Amjad Chaudhry Email amjad.ohaudhry@enipetroleum.com Printed Name Marc Kuck 907-865-3328 Title Well Operations Manager 907-865-3379 Signature Phone D to zie/ , ..,-. 41eL:3,1.--.--- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3 \Le - 3iI Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3.5 ez, 0_5- 1 F Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS JUN 1 3 2016 Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required: /0"' I 3r L APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 6 — 6)—(‘, 2-.4.e....1 .. hs fr Submit Form and II IT♦ Form 10-403 R ised 11/2015 , 1i a t'A lid for 12 1)momont s froo4'the date of approval. Attachments in Duplicate 6 7—(46t c'. • RECEIVED JUN 032016 �� Enii � .�OGCC conn 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone (907) 865-3322 Email: Marc.kuck@enipetroleum.com June 1st , 2015 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Sundry Approval for OP23-WW02 Rig Workover Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Workover Sundry for well OP23-WW02 OP23-WW02 was originally completed on October 23th, 2010 with a ESP pump set at depth of 8,878' MD/6,475' TVD. After an electrical failure a Work Over was performed in April 2015. The ESP has worked on three phases until August 22nd , 2015 when an electrical failure occurred and well lost its one phase. Currently ESP is running on two phases. The well has been scheduled for an intervention with Nabors 245 to change out ESP. The estimated date for beginning this work is August 15t1, 2015. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information, please contact Amjad Chaudhry at 907-865-3379. Sincerely, Marc Kuck Well Operations Manager • • OP23-WW02 Workover— Summary Page OP23-WW02 Rig Workover PTD#:209-032 Current Status Well OP23-WW02 is currently in production not on the full potential of the ESP as because of cable failure it is running on two phases. Scope of Work Scope of this workover is to pull the current completion and run in with a new ESP system. General Well info Reservoir Pressure/TVD: Reservoir depth is 11,557'MD/8,791'TVD. This well is expected to have a static max bottom hole r p pressure of approximately 4,300 psi during the time of workover. 13& J�'_ - 7 Fi L , 3yd'' es- Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind/Flowcross/pipe TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8" was tested 3000 psi x 30' on April, 25th 2010 prior to drill out, and 1000 psi x 10' on June 5th 2014 after running completion. Well type: Water Producer Estimated start date: February 15th 2015 Drilling rig: Nabors 245 Drilling/Completion Engineer: Amjad Chaudhry: Amj ad.chaudhry@enipetroleum.com Work 907-865-3379 Drilling&Completion Marc Kuck: Marc.Kuck@enipetroleum.com Engineering Manager: Work: 907-865-3322 Procedure: 1. MIRU Nabors 245. 2. R/U on x-tree to pump down tubing. 3. Displace by bullheading tubing and liner volume with 9.5#brine. 4. Shear GLM valve and circulate out diesel. 5. Ensure well is killed. 6. Set BPV. ND tree and NU BOP and test to 3500 psi. 7. Pull tubing hanger and circulate annulus volume with 9.5 #brine. 8. Continue POOH to SSSV and L/D same. 9. Continue POOH and lay down ESP assembly. 10. MU new ESP assembly and RIH to setting depth. 11. Land hanger, and test it. 12. Pressure Test IA 1500 psi x 30'. 13. Install BPV and nipple down BOP. 14.NU tubing adapter and tree. 15. Pull BPV, install test plug and test tree.( 5000 psi test) 16. Circulate Freeze protect through tree down IA. 17. Shut in well. 18. RDMO. Below the current schematic of the well: li • • i v.,„r...1)ED Procedure: 1. MIRU Nabors 245. 2. R/U on x-tree to pump down tubing. 3. Displace by bullheading tubing and liner volume with 9.5#b ne. ' '' 4. Shear GLM valve and circulate out diesel. 5. Ensure well is killed. 6. Set BPV. ND tree and NU BOP and test to 3500 psi. 7. Pull tubing hanger and circulate annulus volume wit, 9.5 #brine. 8. Continue POOH to SSSV and L/D same. 9. Continue POOH and lay down ESP assembly. ,p--- 10. MU new ESP assembly and RIH to setting dep . A 1' 11. Land hanger, and test it. p V 12. Install BPV and nipple down BOP. 13. NU tubing adapter and tree. 14. Pull BPV, install test plug and test tree. 5000 psi test) l 15. Circulate Freeze protect through tree •.wn IA. 16. Shut in well. ilL- 17. RDMO. Below the current schematic of the -11: 0. SUP° EL) r-t • • volt OP23-WW02 4-W 13Cr 12.6 ppf Vam Top Production Tubing 2n p�C�o ofleuinnl Wellhead, 13-3/8"x 4-W. CR Flow-wetted 5,000 psi Conductor, 20" Uninsulated set at 154 ft Water Producer with RKB- 32.08' Shrouded ESP Lift Vacuum Insulated Tubing (VIT), I 4-W x 6". approx 105' AS COMPLETED 4/1/15 2137' MD. 2108 TVD 25° Inc-GLM, 4-V2' x 1", KBG with DCK-2 Ann-to-Tubing 2,000 psi 2237' MD, 2198' TVD. 28° Inc-TR-MARX 5E ..._==f I SSSV, 3.81" 'X' Profile, '/4' SS hyd. Control line t" 4-'/2"cable clamps. for ESP Power _: Cable, 3/8" Chem Inj Line ESP Power Cable 1SOLBC 5KV 90 LD B Galv. 3/8" Bare SS Chem Inj Lines 8762' MD, 6398'TVD, 49°Inc - 3.81" 'XIV' Profile Surf. Casing y 8900' MD, 6489' TVD, 49° Inc Motor Centralizer- 13-3/8"68# ` ESP Assy, 31-562P155SXD Pump, SXU/SXL 4595'MD, 3745'TVD Seals. 562 KMX-VC 342 HP Motor � / 7-5/8"29 7# 13Cr Shroud Assembly with Penetrator, (2) Chem Inj Line Feed-Thrus, Tieback 1t,. Seal Stem 8,888' MD—TOL- Flex Lock Liner Hanger and rrr l4P' ZXP Packer Assy /.10 ,. Peri Intervals (Bold new) 11557'-11600' MD, 8791-8835'TVD Interco. Casing 9-5/8"47# i, 11617'-11640' MD, 8850'-8873'TVD 12'/<" OH 9087' MD, � 11654'-11826' MD, 8887'-9057'TVD 11845'-11915' MD, 9076'-9145'TVD 6,613 'TVD, Lower � , 11932'-11995' MD, 9162'-9225'TVD 240' 9-518"47#13 Cr II: 11995'-12045' MD, 9225'-9274'TVD Approx 8°Inc Pump Monitoring: P intake T intake Production Liner, P discharge 7" 26# 13 Cr T motor 8'/2" OH 12,323' MD, V motor 9,550'TVD Confidential VetcoGray MB-247 SURFACE COMPLETION SYSTEM N/CL —63 50 —is- 37.19 v.ii4W-1.140 'es .062 OFFSET C/L I 8.0.S. EL 25' 7-1/4" 0 TOP OF WELLHEAD 5.00' EL 25' 2-1/4" 1 °1 P ill 10 PIT Y or0' 9 FEE0IHRU 21.81 'l�ct� 13-5/8' -5/837 PSIP 'Ir.1AJ1 c L-4. l.-,_ ! !I - .. II.II3.437 OFFSET 108.0 6.60•_ III 111 2 —,- 5000 7PS it 7, / =_� _ II _1= 50001PSI i' �1'' ' ler o if 66.71 POSmON ,lade 13"5000 PSI 52.96' .,..... ..__.€ 'n—� l y tali vC' 134 MOD. 6.5• lid 7, T �, ',-.t:_1111 34.00' 2-1 16"• - ci OtJT OF 24.2 �- - §-11. 15.25• POSITION _ lii TOP OF GRADING 7 a [ TOG 1 ` - 1 EL i6� 1-1/4" L1.DD �PROPRCG.R+V FO7Sc 9t 20" OD 1331 K-55 �j—,. iaiw9r�""/ 13-3/8" 00 681 L-80Lit O1�_61.*45.466 ENI ALASKA 9-5/8" OD 53.5# L-80 moo 4* HORIZONTAL MULTI—BOWL SYSTEM 4-1/7 OD WITH 6-5/8 1111" -� .mow 20 X 13-3/8 X 9-5/8 X C IOW X 4-1/2 WITH 6-5/8 VII ...... ANO ESP FLAT CABLE 13,APL 0-6�—� ..„„„..-1911( I= HW ft I=P H173370-1 '� .4w wax_v� ..spr xx5l.w.am x 1 14221-'5:N PRP 1D161, NC 10 OF 10 23 JANUARY 2009 $2 I C.::if iOGr,o1 C'i L. %s1 r. • 0 R X . B 16 t 1— Wiii IT 1 4gg o z_ aa w§ .1— H� o 3 IP t MI ti a g R W 0 W ,. % t arc ?C7 : ffi Lt.' ,I U V I ci 4 — 0 / U G. Z Z CC / bI G.- F. r� I� �1 a W I q `7 aril + J 012 � a ? h • � � „. 2Wz § ia ,.,g,,, Ail y ! ffJ 111 $I Ii 1 .52 , r il\yh m"if 1i, P. T '..AL '-'"O. 7 v o ——TT j "'".---I II. A._J L- i - —� d n v cc C iS C F—Y 4. .NI -,e S. RECEIVED ' STATE OF ALASKA APR 1 6 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Repair Well H Plug Perforations LJ Perforate U Other U ESP Change Out Performed: Alter Casing ❑ Pull Tubing❑' Stimulate-Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well ❑ 2.Operator Eni US Operating Co.Inc. 4.Well Class Before Work• 5 Permit to Drill Number: Name: Development ❑ Exploratory ❑ 209-0320 3.Address: 3800 Centerpoint Drive,Ste.300,Anchorage, Stratigraphic❑ Service Q 6.API Number: AK 99503 50-029-23411-00-00 7.Property Designation(Lease Number): 8 Well Name and Number: 0373301,0355024,0390616 OP23-WW02 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s). Ivishak water source 11.Present Well Condition Summary: Total Depth measured 12,323 feet Plugs measured feet true vertical 9,550 feet Junk measured feet Effective Depth measured feet Packer measured feet true vertical feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 4,595 13.375" 4,595 3,745 5,210 2,480 Intermediate 9,087 9.625" 9,087 6,613 6,890 4,790 Production Liner 3,435 7" 12,323 9,550 7,240 5,410 Perforation depth Measured depth 11,557'-12,045' feet SCANNED c True Vertical depth 8,791'-9,274' feet �NGD ,_ , Tubing(size,grade,measured and true vertical depth) 4.5" 12.6 ppf L80 8,888'MD 6,481'TVD 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: 1 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 6500 0 100 Subsequent to operation: 0 0 14000 0 165 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service ❑., Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after we Source Water 0 Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 3USP ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O.Exempt: 315-021 Contact Giuseppe Maugen Email giuseppe.maugen@empetroleum.com Printed Name Marc Kuck Title Drilling&Completion Engineering Manager Signature //i . Phone (907)865-3328 Date 4/16/2015 RBDMS APR 1 8 1015 'i-zo t5" tfolf#1 OP23-WW02 2rn1i peCrrolleum 4-'/2" 13Cr 12.6 ppf Vam Top Production Tubing o 0 Wellhead, 13-3/8" x 4-'/2", CR Flow-wetted 5,000 psi Conductor, 20" Uninsulated set at 154 ft Water Producer with RKB- 32.08' Shrouded ESP Lift Vacuum Insulated Tubing (VIT), ' / 4-W x 6", approx 105' AS COMPLETED 4/1/15 2137' MD, 2108' TVD 25° Inc - GLM, 4-'/2" x 1", i KBG with DCK-2 Ann-to-Tubing 2,000 psi Oil fn Al 2237' MD, 2198' TVD, 28° Inc - TR-MAXX 5E SSSV, 3.81" 'X' Profile, '/4" SS hyd. Control line 4-W cable clamps, for ESP Power Cable, 3/8" Chem Inj Line ESP Power Cable 1 SOLBC 5KV 90 LD B GaIv. \\O 3/8" Bare SS Chem Inj Lines L \�� 8762' MD, 6398' TVD, 49° Inc - 3.81" `XN' Profile 1 Surf. Casing8900' MD, 6489' TVD, 49° Inc Motor Centralizer- 13-3/8" 68 # A ESP Assy, 31-562P155SXD Pump, SXU/SXL 4595' MD, 3745' TVD Seals, 562 KMX-VC 342 HP Motor \ �� \ 7-5/8" 29.7# 13Cr Shroud Assembly with % Penetrator, (2) Chem Inj Line Feed-Thrus, Tieback Seal Stem 8,888' MD — TOL - Flex \` � `r Lock Liner Hanger and ZXP Packer Assy .0•' Perf Intervals (Bold new) 11557'-11600' MD, 8791'-8835' TVD Ing-5/8 Casing 11617'-11640' MD, 8850'-8873' TVD 12 '/49 OH 9087' MD, � I 11654'-11826' MD, 8887',9057' TVD 11845'-11915' MD, 9076'-9145' TVD 6,613 ' TVD, Lower MD, 9162'-9225' TVD 240' 9-5/8" 47# 13 Cr995'-12045' MD, 9225'-9274' TVD Approx 8° IncPump Monitoring: \>11932'-11995' P intake T intake Production Liner, P discharge 7" 26# 13 Cr T motor 8 1/2" OH 12,323' MD, ✓ motor 9,550' TVD Confidential Eni E&P Division WeII Name:0P23 WW02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq 2�fii* Date:31612015 - Report#: 1 API/UWI:50-029-23411-00-00 'I ('fln page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spoof(m) 16.22 3 72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1796.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature("C) Weather Wind 0.00 18.0 0.0 Cloudy WC-22 NNW @ 22 MPH Daily summary operation 24h Summary Preparing rig for operations Operation at 07.00 Preparing ng for operations 24h Forecast Cont working on TDS,Boiler&steam lines,preping ng for operations Lithology Shows MAASP(kgflcm2) Mud Weight(g/L) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 05:30 06:00 0.50 0.50 W.O. A 1 P Pre-Tour Safety Meeting 06:00 12:00 6.00 6.50 W.O. A 1 P Cover&Heat Man Rider.HPU/Perform DOMS-Derrick inspection,Set up tool pusher office,cont.working on steam lines, boilers.&house keeping.Hang SRL's,remove cover F/top drive. 12:00 17:30 5.50 12.00 W.O. A 1 P Troubleshoot/repair sub module Tioga,shovel rig floor.dispose of all oil waste per ACS,Install SRL's around rig.stage equipment on rig floor.Start installing camera in derrick,remove laminated sheets F/traction motors. 17:30 18.00 0.50 12.50 W.O. A 1 P Pre-tour safety meeting 18:00 00.00 6.00 18.50 W.O. A 1 P Remove snow in cellar and landings,prep baylor batteries to be installed,house keeping through out rig,cont to remove - cover on TDS. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Dnlling Supv 907-685-0715 Eni representative Billy Petty ENI HSE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1.662 10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division Well Name:0P23WW02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq • 2 II^nliff* Date:3/7/2015 - Report#: 2 APIIUWI:50-029-23411-00-00 II IIpage 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 011110k Popa ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) OP23-WW02 WORKOVER 1797.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind C.00 18.0 -5.4 Light Snow WC-22' NNW@ 10MPH Daily summary operation 24h Summary Finish getting boilers up and runnig,prepare secure line for BOP stack,recieve fuel&water.general R/U preparations. Operation at 07.00 Preparing rig for operations 24h Forecast Continue R/U and Preparations for rig operations Lithology Shows MAASP(kgficm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(Cr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 W.O. A 1 P Pre-Tour Safety Meeting 0030 06:00 5.50 6.00 W.O. A 1 P Cont.installing SRL's in Cellar,Secure Landings,PU Picher Nipple&new flow line,Start sub tinge&monitor,Dress mud pumps out per Eni contract. 0600 12:00 6.00 12.00 W.O. A 1 P Take on boiler water,fill hotwell&boilers and start staging boilers up to pressure.Cont dressing out mud pumps#1, Function test trip tank alarms(good Test),remove and replace securing lines for BOP stack.Redeye 15,000 gal.diesel& 120 bbls water. 12:00 12:30 0.50 12.50 W.O. A 1 P Pre-Tour Safety meeting 12:30 18:00 5.50 18.00 W.O. A 1 P Cont boiler fire up.Swap power over,Analyzed exhaust gases on sub tioga,Got water going thru utility mod,recieved 120 bbls water. 18.00 '00:00 6.00 24.00 W.O. A 1 P Get steam going thru utility mod.,finish changing out BOP secure lines,House keeping Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Billy Petty ENI HSE Eni representative Vance Dale ENI Mails Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15l enipetmleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,795.02 2.031 81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division Well Name:Or23-WW02 DIR ff* • ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq • 2 II ^n Date:3/8/2015 - Report#: 3 APIIUWI:50-029-23411-00-00 II II page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10 13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1798.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 20.0 -164 Overcast WC-39 WSW @ 13 MPH Daily summary operation 24h Summary Cont working on steam system,Function test TD,Skate,IR,install parts on TD,Prepare rig for work over operations Operation at 07.00 Prepare rig for wvrkover operations 24h Forecast Moving Rig to road 8 Pickup BOPE,Prep pad to stage rig over well OP23-W W02. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 00:30 0.50 0.50 W.O. A I P Pre-Tour Safety Meeting 00:30 06:00 5.50 6.00 W.O. A 1 P Install Man Rider SLR's.Start draining water out of Choke Manifold,Cont working on mud pump#2,Circ steam through out sub to thaw ant frozen lines,Thaw all sumps a drains in cellar,Remove cover transformer on sub roof. 06:00 .12:00 6.00 12.00 W.O. A 1 .P Function test draw works,skate,IR&drawworks,Service TD&Skate,Install black Jack,Torque IBOP T/48,000&Saver sub T/32,000,Install Bails&elevators„lower new flow line to cellar,house keeping,drain choke manifold 12:00 12:30 0.50 12.50 W.O. A 1 'P Pre-Tour Safety Meeting 12:30 '18:00 5.50 18.00 W.O. A 1 'P Bring subs to dg floor,organize pipe shed.Snow removal,Install baylor batteries in SCR room.remove old flow line from cellar. 18:00 '00:00 6.00 24.00 W.O. A 1 •P Assembly mud cross for BOP's,Made new hole fill line and staged in cellar.House keeping throughout rig. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Billy Petty ENI HSE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRgClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors ..‘Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1.662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P DivisionWell Name:0P23-W W02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq en(I Date:31912015 - Report#: 4 APIIUWI:50-029-23411-00-00 II II page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) OP23-WW02 WORKOVER 1799.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature("C) Weather Wind 0.00 23.0 -18.5 Mostly Cloudy WC- WSW @ 17 MPH 45° Daily summary operation 24h Summary Prepare rig for move,move rig malts,prep pad, move rig,assemble BOPE,prep pad for laying hurculite Operation at 07.00 Setting Matts 24h Forecast Prep pad,lay herculite and matting boards,move rig over well OP23-W W02,move utility module. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Our(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 06:00 6.00 6.00 W O. A 1 P Prep crib blocks for install after jacking up,remove and replace bent studs on double gate rams,Prep dixi cup for ng move duck ponds,herculite,and excess equipment,stage rig malts,start lampsons roll up curtains. 06.00 12:00 6.00 12.00 W.O. A 2 P Pull steam traps&blow do lines,start cold start,split poer and disconnect all interconnects,secure all landings,jack up rig and set on cribbing blocks,move rig 12.00 13:30 1.50 13.50 W.O. A 1 P Lower dixi cup and remove, 13.30 21:00 7.50 21.00 W.O. A 1 P Assemble BOPE,raise and put on pedestal,move ng malts,prep pad,clear pipe shed of material 21 00 22:00 1.00 22.00 W.O. A 1 P Install dixi cup raise to cellar and secure. 2200 00:00 2.00 24.00 W.O. A 1 P Move Rig malts,prep pad for laying hurculite Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry 'ENI Senior Dulling Sups - 907-685-0715 Eni representative Billy Petty ENI HSE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.corn 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.core 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm°) 2795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division well Name:Or-23 WW02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 • Field Name:Nikaitchuq \� II^ffil* Date:3/10/2015 - Report#: 5 APIIUWI:50-029-23411-00-00 II II n page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N' Operator ENI Share)%) Well Configuration type Oliktok Point ENI PETROLEUM 100-00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9 60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) OP23-WW02 WORKOVER 1800.06 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature('C) Weather Wind C 00 26.0 -27.2 Clear CW-46` SW @ 6 MPH Daily summary operation 24h Summary Move and spot Sub and Utility modules over well OP23.R/U for WO operations.Held Stand Down Meeting with Operabons. Operation at 07.00 R/U on well OP23. 24h Forecast Continue R/U operations and getting steam and heat throughout rig complexes. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 - 6.00• 6.00 W.O. A 2 P PJSA Complete setting matt boards and herculite.Move Sub Module over Well OP23 and center over well. 06:00 12:00 • 6.00 12.00 W.O. A 2 P PJSA Set Sub Module down over well and secure well bay roof and dixie cup. 12:00 21:00 9.00' 21.00 W.O. A 2 P PJSA Prepare to move Utility Module,roll up curtains,set on crib blocks,remove and secure hoses.Move and spot Utility Module next to Sub and set on Matt boards. 21:00 00:00 ' 3.00• 24.00 W.O. A 2 P PJSA Clean up pad.prep.for beetling,R/U interconnects ans swap power to genset.Hold Safety Stand Down for Rig Move Communication with Operations. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Dulling Supv 907-685-0715 Em representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Billy Petty ENI HSE Eni representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1.662 10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 r— Eni E&P Division WeII Name:Or23 WW02 DIR ffill* ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq 2� Date:3/1112015 - Report#: 6 APIIUWI:50-029-23411-00-00 II �'�In page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1801.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature("C) Weather Wind 0.00 25 0 -30.1 Clear WC-46° WSW @ 5 MPH Daily summary operation 24h Summary Cont.R/U,berming,steam throughout ng and load 290 bbls of 9.4 ppg bone.Set cuttings box and prep.hoses for well killing operations.Rig up hydaulic fittings on stack.Prime pumps#1. Operation at 07.00 R/U for killing operations. 24h Forecast Hold pre spud meeting with all personnel.R/U and pump 9.5 ppg brine down tubing and open hole.Pressure IA to 2000 psi and shear GLM.Pump 9.5 brine down tubing returning diesel up IA to open top tank for recycle.Wire line to C/O shear GLM w/dummy valve.Monitor well is dead and Vetco set BPV.N/D tree and N/U Riser and stack.R/U and test BOPE as per AOGCC. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 W.O. A 2 P PJSA Berming rig location,hooking up interconnects,raise and secure ladder extensions on well bay roof as per DSO and permitting,circulate stem throughout rig complexes and install discs. 06:00 12:00 6.00 12.00 W.O. A 2 P PJSA Cont.to R/U.secure Lampson curtains,Load pits w/290 bbls 9.4 ppg bone. 12:00 18:00 6.00 18.00 W.O. A 2 P PJSA Cont.R/U,berming and stage and set cuttings box. 18:00 21:00 3.00 21.00 W.O. A 2 P PJSA Cleaning out pipe shed and rig housekeeping. 21:00 00:00 3.00 24.00 W.O. A 2 P PJSA Stage hoses for well killing operation,install hydraulic fittings on stack and prime pumps#1. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Em representative Ben Perry ENI Senior Dolling Supv 907-685-0715 Eni representative Russ Wimmer ENI Dolling Supv. SIDDnlling@enipetroleum.corn 907-685-0715 907-320-0058 Eni representative Billy Petty ENI HSE Eni representative Vance Dale ENI Malls Coordinator I Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 I Eni representative Jeremey Decker ENI Expediter eniexpedilor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662.10 3.756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 • Eni E&P Divisionwell Name:Vr13-WW02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq • en!PI* Date:311212015 - Report#: 7 APINWe 50-029-23411-00-00 II II I'n page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0023-WW02 WORKOVER 1002.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 0.00 32.0 -30.6 Overcast WC-46 W @ 5 MPH Daily summary operation 24h Summary R/U and pump 262 bbls of 9.5 ppg brine down tubing.Fill IA w/81 bbls of 9.5 ppg brine and pressure up to 2100 psi and shear GLM valve.Pumping 9.5 ppg brine down tubing taking diesel returns from IA to cuttings tank for recycle. Operation at 07.00 Rigging up Halliburton Wireline. 24h Forecast Complete cleaning IA and R/U Howco wireline.CIO sheared GLM valve w/Dummy valve.Vetco install BPV and secure well.N/D tree and N/U HP riser and BOPE.Test BOPE as per AOGCC. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 W.O. L 20 P PJSA Torque up BOP stack and connect hydraulic lines.Stage well kill hoses and equipment.Locate ESP and control line • sheaves,dress and hang. 06:00 12:00 6.00 12.00.W.O. L 20 P PJSA Spot Spooling unit,R/U Gen-Set and berm in area.Flag off area for safety.290 bbls of 9.4 ppg brine to pits. 12:00 16:30 4.50 16.50 W.O. L 20 P PJSA R/U on tubing and annulus for well kill operations. 16:30 22:00 5.50 22.00'W.O. L 9 P PJSA Complete R/U on well kill operations and PT lines to 2000 psi.Open up tubing and annulus w/400 psi tbg,700 psi IA.Bullhead 262 bbls of 9.5 ppg brine down tubing @ ICP430 psi @ 2 bpm,FCP 550 psi @ 5 bpm.Monitor well 15 min. Bleed gas from IA through choke/gas buster.Load pits w/290 bbls of 9.5 ppg brine. 22:00 00:00 2.00 24.00 W.O. L 9 P PJSA R/U to pump down IA and fill IA w/81 bbls of 9.5 ppg brine.Pressure up to 2100 psi and shear GLM valve.R/U and pumping 9.5 ppg brine down tubing and taking diesel returns to cuttings tank for recycle. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruno Ravagli ENI Dilling Superintendt Eni representative Ben Petty ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDnlling@enipetroleum.corn 907-685-0715 907-320-0058 Eni representative Giuseppe Maugen ENI Engineer Eni representative Paul Holley ENI HSE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com $07-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor©gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Longhorn Nabors Tour Pusher Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 0 276 13CrL80 1,662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,795.02 2.031 81 VC-08M 1234.2 119.5 1822.5 370.2 Eni E&P Division Well Name:Ol 23-W W02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq • enfl Date:311312015 - Report#: 8 Af IIUWI:50-029-23411-00-00 II II Ipage 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type Otktnk Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) 0P23-WW02 WORKOVER 1803.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 0 00 28.0 -32.4 Clear WC-53 SSW @ 10 MPH Daily summary operation 24h Summary Complete displacing IA of diesel(150 bbls).Spot Halliburton wireline unit and hold PJSM.Spot and P/U Halliburton equipment.At 0530 hrs while P/U equipment,there was an incident which involved an IP to be sent to Medic/Town.Rig Operations are on Safety Stand Down. Operation at 07.00 Safety Stand Down. 24h Forecast Safety Stand Down. Lithology Shows MAASP(kgflcm2) Mud Weight(gIL) 11384 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 02:00 2.00 2.00 w.0. L 7 P PJSA Complete displacing diesel from IA by pumping 170 bbls of 9.5 ppg brine down the tubing through the GLM Q 1 bpm,5 psi.Recovered 150 bbls of diesel in cuttings tank.Vac diesel to waste oil storage. 02:00 03:30 1.50 3.50 W.O. L 20 P PJSA Blow down and rig down all well kill equipment.Vetco test false bowl seals. 03:30 05:30 2.00 5.50 W.O. R 20 P PJSA Halliburton spot unit at rig complex and secure location.Hold PJSM and stage equipment for P/U&M/U. 05:30 12:00 6.50 12.00 W.O. R 20 1W99 PJSA At 0530 hrs.Operations went to Safety Stand Down from Incident picking up wireline BOP's. 12:00 00:00 12.00 24.00 W.O. R 20 TW99 PJSA Safety Stand Down. Daily Contacts Position Contact Name Company Title E-mall Office Mobile Eni representative Bruno Ravagli ENI Diling Superintendt Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrillirg@enipetroteum.com 907-685-0715 907-320-0058 Eni representative Paul Holley ENI HSE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetnaleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1.662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm2) Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,795.02 2.031 81 VC-OBM 1234.2 119.5 1822.5 370.2 1111* * Eni E&P DivisionWell Name:Gr�3-W W02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq � Date:3114(2015 - Report#: 9 APIIUWI:50-029-23411-00-00 enlo name: OP23-WW02 page 1 of 1 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(in) RKB-Base Flange(m) RKB-Tubing Spool(in) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1804.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 0.00 35.0 -33.0 Overcast WC-55` SSW @ 20 MPH Daily summary operation 24h Summary Investigate Wire Line Valve incident and work on safe plan for P/U and R/U of Halliburton 7 wire line valve installation. Operation at 07.00 Work on procedure. 24h Forecast Continue with procedure on P/U&R/U of Halliburton 7"WLV and equipment.Final discussion and/or approval for work.Staff tip ng personnel so both crews are full,ready and capabale of operations at hand. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 12:00 12.00 12.00-W.O. L 20 TW99 PJSA Safety Stand Down for Rigging up Halliburton tools. 12.00 00:00 12.00 24.00 W.0 L 20 TW99 PJSA Working on safe pick up and ng up procedure for Halliburton 7"wire line valve and equipment. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Bruno Ravagll ENI Dilling Supenntendt Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.corn 907-685-0715 907-320-0058 Eni representative Paul Holley ENI HSE En representative Vance Dale ENI Matls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.corn 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push )Ralph Longhorn Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662 10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P DivisionWell Name:0P23WW02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaiichuq 2^fifi* Date:3/15/2015 - Report#: 10 API/UWI:50-029-23411-00-00 II �I InI page 1 of 1 •Wellbore name: OP23-WWO2 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(rnlhr) DFS(days) OP23-WW02 WORKOVER 1805.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) PO8 Temperature("C) Weather Wind 0.00 30.0 -297 Clear WC-45 WSW(/012 MPH Daily summary operation 24h Summary Safety stand down.Performing house keeping in/out,rig maintenance,gather tools and equipment for up coming operations. Operation at 07.00 Wading on Go Ahead approval. 24h Forecast Continue an guided. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 12:00 12.00 12.00 W 0. L 20 TW99 PJSA Safety Stand Down.Working on procedure for P/U&R/U Halliburton 7"Wire line Valve.House keeping,C/O oil filters on Gen Set#1,C/O electric motor on bridge crane,Clean up herculite and back yard from rig move,Rec'd 280 bbls of 10.0 ppg brine. 12:00 00:00 - 12.00 24.00'W.O. L 20 TW99 PJSA House keeping,Install giatronics in well bay,Remove double gate Halliburton bop's and stage 7"lubricator and single gate WL valve,C/O oil in iron roughneck,service floor equipment.Load Vetco landing jt in shed,verify elephant trunk is on location. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruno Ravagli ENI Dilling Superintendt • Eni representative Ben Petry ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Paul Holley ENI HSE Em representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Posh Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1.662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division Well Name:Gr23-W W02 DIR fill* ENI Petroleum Co.Inc. Daily Report Well Code:23835 • Field Name:Nikaitchuq 2^r��I Date:3/16/2015 - Report#: 11 APIIUWI:50-029-23411-00-00 II �Ipage 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1806.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(CC) Weather Wind 0.00 35.0 -22.7 Clear WC-35' ENE©20 MPH Daily summary operation 24h Summary Well tubing pressure @ 100 psi.R/U and bullhead 250 bbls of 9.6 ppg brine.Bleed off well pressures and R/D lines.R/U Halliburton wire line equipment and string wire line. Operation at 07.00 Halliburton wire line work. 24h Forecast Complete full Halliburton tool rig up and RIH and CIO sheared GLM valve to dummy valve.R/D Halliburton.Vetco to set BPV and NID tree and N/U HP riser and BOPE.Test BOPE w/4.5"and 5"test jts. to AOGCC specs. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1150.3 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 W.O. L 20 TW99 PJSA House keeping,rig maintenance and inspections.100 psi tubing pressure @ 0030. 06:00 12:00 6.00 12.00 W.O. L -20 TW99 PJSA Cont.as above.C/O cable on overhead crane in pipe shed.Bleed tubing to 24 psi,IA @ 160 psi at 1130 hr. 12:00 14:00 2.00 14.00 W.O. L 20 TW99 PJSA P/U&M/U 2"HP hoses to tubing. 14:00 16:30 2.50 16.50 W.O. L 9 TW99 PJSA Bleed of well pressures,Blow down and Rig down. 16:30 22:00 5.50 22.00 W.O. L 9 1W99 PJSA Weight up brine to 9.6 ppg and PT lines to 1000 psi.Bullhead 250 bbls of 9.6 ppg brine down tubing @ 2 bpm,ICP 45 psi,to 5.5 bpm,720 psi.Well pressures 558 tbg,700 IA. 22:00 00:00 2.00 24.00 W.O. R 20 P PJSM with all personnel and R/U Halliburton Lower lubricator and wire line valve.P/U upper lubricator assy.to rig floor and working on stringing wire line. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Davide Simeone ENI Project Manager Eni representative Bruno Ravagli ENI Dilling Superintendt Eni representative Ben Petty ENI Senior Drilling Supv 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative •Paul Holley ENI HSE Eni representative Vance Dale ENI Malls Coordinator Eni representative Mitch Billington ENI Rig Clerk AKRgClerksDoyon15@enipetroleum.com 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,795.02 2031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division Name:Ur-2 WW02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq 2 n^!Pi* Date:3/17/2015 - Report#: 12 API/U WI:50-029-23411-00-00 fl II II page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Pool ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1007.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 36.0 -19.2 Overcast WC-14° W @ 6 MPH Daily summary operation 24h Summary Hold PJSM WI Halliburton Wire Line.M/U Lubricator.RIH W/Slip Stop and tagged up at 8'.POOH and C/O Tool.RIH and set Slip Stop.POOH C/O Tools.RIH and pull Shear Valve.P/U M/U Dummy Valve and RIH ant set.R/U and test IA to 500 PSI good test.RIH and pull Slip Stop.R/D Wire Line.PJSM W/Vetco Grey Rep.Set BPV and N/D Tree.N/U BOPE:Lower riser to Well Head and install Grey Loc.N/U BOPE:Set BOPE Stack.Torque all connections W/Sweeney Wrench.SIMOPS Set well house covers,Herculite and Duck Ponds.Secure floor for spill prevention.Install Flow Line and Katch Kan.Put adapter flange on mud cross and hook up Choke and Kill Line.Hook up Koomey lines.Prepped and cleaned NT2 connection on Stack.SIMOPS CIO bad light bulbs around rig.Repaired grating in Pits.Stage 4.5"and 5"test joints in Pipe Shed.Prep rig floor for BOPE test.Relocate Derrick sheaves for ESP and CAP Tube lines. Operation at 07.00 Test BOPE. 24h Forecast Cont.to N/U BOPE.Test 4.5"and 5"BOPE test,witnessed waived by AOGCC John Crisp.Pull Hanger and unseat seal Assy.Circ Surf.to Surf.Pull Hanger and L/D.R/U ESP and CAP lines.Pull 4.5" Tubing. Lithology Shows MAASP(kgflcm") Mud Weight(gIL) 1150.3 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06.30 6.50 6.50 W.O. R 19 P Hold PJSM WI Halliburton Wire Line.M/U Lubricator.RIH W/Slip Stop and tagged up at 8'.POOH and C/O Tool.RIH and set Slip Stop @ 2,258'SLM.POOH C/O Tools.RIH and pull Shear Valve @ 2.222'SLM.P/U M/U Dummy Valve and RIH ant set.R/U and test IA to 500 PSI good test.RIH and pull Slip Stop.R/D Wire Line. 06:30 09:00 2.50 900 W.O. C 5 P PJSM W/Vetco Grey Rep.Set BPV and N/D Tree. 09:00 12:00 3.00 12.00 W.O. C 5 P PJSM N/U BOPE:Lower riser to Well Head and install Grey Loc. 12:00 17:00 5.00 1700 W.O. C 5 P PJSM N/U BOPE:Set BOPE Stack.Torque all connections W/Sweeney Wrench.SIMOPS Set well house covers, Herculite and Duck Ponds.Secure floor for spill prevention. 17:00 22:00 5.00' 22.00 W.O. -C 5 P PJSM Install Flow Line and Katch Kan.Put adapter flange on mud cross and hook up Choke and Kill Line.Hook up Koomey lines.Prepped and cleaned NT2 connection on Stack.SIMOPS CIO bad light bulbs around rig.Repaired grating in Pits. 22:00 00.00 2.00 24.00 W.O. C 5 P Stage 4.5"and 5"test joints in Pipe Shed.Prep rig floor for BOPE test.Relocate Derrick sheaves for ESP and CAP Tube lines. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative -Davide Simeone 'ENI Project Manager Eni representative Bronx Ravagli ENI billing Superintendt Eni representative Ben Peny ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Paul Holley ENI HSE Eni representative Vance Dale ENI Mat's Coordinator ' Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyon15@enipetroleum.corn 907-685-0722 Eni representative Jeremey Decker ENI Expediter eniexpeditor@gmail.com 907-980-7545 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push 1Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm") 2.795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division Well Name:Gr[3-WW02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq 2 II^nIffil* Date:3/18/2015 - Report#: 13 API/UWc 50-029-23411-00-00 II IIpage 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 011ktok Point ENI PETROLEUM 100.00.DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9 60 10 13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1908.06 Daily Information End Depth(mKB) End Depth(ND)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 0.00 34.0 -16.1 Partly Cloudy WC- NNE @ 20 MPH 20' Daily summary operation 24h Summary Install drain hose on Katch Kan.Fill BOPE with H2O and found leak at dresser sleeve.Reline flow line and fixed leak.Test BOPE.LID Test tools and Equip.Blow down Kill,Choke and Manifold. BOPE Test Witness Waived By AOGCC Rep John Crisp.RAJ Elephant Trunk for ESP and CAP line.Adjust tumbuckles on Beaver Slide.Prep to P/U tools.Relocate chain fall hoist arm in Cellar.P/U GBR and Baker Centerlift tools F/Pipe Shed.R/U tools.C/O Elevators to 4.5"/Prep floor to pull Hanger.Replace steam line to rig floor.Clean and service rig.Grease Choke Manifold.Work on PJSA. Operation at 07.00 Pull test dart and BPV as per Vetco Rep. 24h Forecast Pull test dart and BPV as per Vetco Rep onsite.P/U MIU Hanger as per Vetco Rep.Pull Hanger and seal Assy.from Packer.Circ.out IA of inhibited brine to 9.5 ppg Brine.L/D Hanger and terminate lines.Pull 4.5"Tubing and string up sheaves W/ESP and CAP Tube. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1150.3 Time Log Start End Cum Time Time Dur(hr).Dur(hr) Phase Opr. : Act. Plan Oper.Descr. 00:00 03:00 3.00 3.00 W.O. C 5 P PJSM Install drain hose on Katch Kan.Fill BOPE with H2O and found leak at dresser sleeve.Reline flow line and fixed leak. 03:00 10:30 7.50 10.50 W.O. C 12 P PJSM Test BOPE:Test Annular Preventer W/4.5"and 5"test joints to 250 PSI low and 2,500 PSI high.Test Choke Valves 1-16,Demco Kill,Manual Choke line,HCR Choke and Kill line,TIW and Dart Valve,Upper and Lower Rams,Blind Rams, i ) - Upper and Lower IBOP,all test to 250 PSI low and 3,500 PSI high for 5 Min.Test A&B and Super Choke to 1,500 PSI,all I��v 'I,Y charted.Perform Koomey draw down,Accumulator Press.2,990 PSI,after function Accumulator 1,906 PSI,200 PSI /� increase in 40 Sec.Full charge in 148 Sec.6 bottle Nitrogen average 2,050 PSI. ,( 10:30 11:30 1.00 11.50 W.O. C 20 P PJSA L/D Test tools and Equip.Blow down Kill,Choke and Manifold. 11:30 12:00 0.50 12.00'W.O. G 1 P 'PJSM R/U Elephant Trunk for ESP and CAP line. 12:00 15:00 3.00 15.00'W.O. G 1 P PJSA Cont.to R/U Elephant Trunk for Centralift.Adjust tumbuckles on Beaver Slide.Prep to P/U tools.Relocate chain fall hoist arm in Cellar. 15:00 00:00 9.00. 24.00'W.O. G 1 P PJSA P/U GBR and Baker Centedift tools F/Pipe Shed.R/U tools.C/O Elevators to 4.5"/Prep floor to pull Hanger. 'Replace steam line to rig floor.Clean and service rig.Grease Choke Manifold.Work on PJSA. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Paul Holley ENI HSE Eni representative Greg Parker ENI Mats Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrgclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Posh Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(In) • Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1.662.10 3.756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370 2 I fife* Eni E&P Division Well Name:0k43-WW02 DIR EN/Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq flfl Date:3/19/2015 - Report#: 14 API/UWI:50-029-23411-00-00 2" " page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 1622 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) OP23-WW02 WORKOVER 1809.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature("C) Weather Wind 0.00 39.0 -19.4 Partly Cloudy WC- NNE @ 20 MPH 29° Daily summary operation 24h Summary PJSM W/all essential personnel.Pull test dart as per Vetco Grey Rep onsite.Fill stack W/5 bbl 9.6 ppg Brine.Pull BPV as per Vetco Grey Rep onsite.Brine fluid dropped when BPV was pulled.P/U M/U Landing joint to Hanger as per Vetco Grey Rep onsite.Check IA Press.and bleed off to Bleed Tank.Run out lock down screws as per Vetco.Pull Hanger:PAJ to 175K and SLK to 120K,P/U to 185K SLK to 120K,P/U to 195K and SLK to 120K,P/U to 210K and SLK to 120K.PN to 215K and released from Well Head. Pump 10 bbl 9.6 Brine and monitor well,taking fluid about 20-30 bph.PJSM W/all companies on pulling tubing and emergency evacuation policy.Pull Hanger to rig floor.Test ESP Penetrator and injection line as per Baker Centralift.L/D Hanger and landing joint as per Vetco Grey Rep onsite.Break out TIW and MIU to X/O for safety valve.Pull and LID VIT joints F/8,878'to 8,769'MD.HST 150K.Due to Tubing alignment in rotary table Derrick was re shimmed and leveled.Put inner connect back together and adjust turn buckles on Stack.POOH W/GBR Csg.L/D 4.5"Pup Jnts.Pull CAP,ESP and SSV lines over sheaves.Cont.to POOH 4.5"Vam Top Tubing F/8,765'to 7,558'MD. HST 130K,SLK 100K.Still losing 20-30 bph static.Cut out Gator Splice and test ESP cable.Crimp ESP Splice back together to go thru sheave.Total loss for today 350 bbl 9.5 ppg Brine. Operation at 07.00 Changing ESP Completion Spools. 24h Forecast Cont.to POOH and LID 4.5"Vam Top Tubing,GLM and SSV.Monitor well for loss rates.Cut Brine weight to 9.4 ppg to control loss rate. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1138.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01 30 1.50 1.50 bhp 0 C 19 P PJSM W/all essential personnel.Pull test dart as per Vetco Grey Rep onsite.Fill stack W/5 bbl 9.6 ppg Brine.Pull BPV as per Vetco Grey Rep onsite.Brine fluid dropped when BPV was pulled. 01:30 04:30 3.00 4.50 W.O. C 19 P PJSA P/U M/U Landing joint to Hanger as per Vetco Grey Rep onsite.Check IA Press.and bleed off to Bleed Tank.Run out lock down screws as per Vetco.Pull Hanger:PN to 175K and SLK to 120K,P/U to 185K SLK to 120K,P/U to 195K and SLK to 120K,P/U to 210K and SLK to 120K.PN to 215K and released from Well Head.Pump 10 bbl 9.6 Brine and monitor well,taking fluid about 20-30 bph. 04:30 06:30 2.00 6.50 W.O. L 4 P PJSM W/all companies on pulling tubing and emergency evacuation policy.Pull Hanger to rig floor.Test ESP Penetrator and injection line as per Baker Centrilift.L/D Hanger and landing joint as per Vetco Grey Rep onsite.Break out TIW and • M/U to X/O for safety valve. I 06:30 09:30 3.00 9.50 W.O. G 4 P PJSA Pull and L/D VIT joints F/8.878'to 8,769'MD.HST 150K. ^ 09:30 12:00 2.50 12.00 W.O. L 25 P PJSM Due to Tubing alignment in rotary table Derrick was re shimmed and leveled. nJ,-G1e" 12:00 14:30 2.50 14.50 W.O. L 25 P PJSM Due to Tubing alignment in rotary table Derrick was reshimmed and leveled.Put inner connect back together and f1•••✓✓✓����///// adjust tum buckles on Stack. 14:30 23:00 8.50 23.00 W.O. G 4 P _ PJSM POOH W/GBR Csg.L/D 4.5"Vam Top Pup Jnts.Pull CAP,ESP and SSV lines over sheave&..Cont.to POOH 4.5" Vam Top Tubing Fl 8,765'to 7,558'MD.HST 130K,SLK 100K.Still losing 20-30 bph static. 23:00 00:00 1.00 24.00 W.O. G 20 P PJSA Cut out Gator Splice and test ESP cable.Crimp ESP Splice back together to go'fru sheave. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Peny ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 • Eni representative Paul Holley ENI HSE ' Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative •Bernie Leas ENI Rig Clerk akrgclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative .Ken Bogner ENI Expediter 907-980-7545 Tool Push ',Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2.795 02 2.031 81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division , Well Name:OP23-WW02 DIR ENI Petroleum Co.Inc. Daily Report` Well Code:23835 Field Name:Nikaitchuq eII^ft* Date:3/20/2015 - Report#: 15 APIIUWe 50-029-23411-00-00 II II n page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1810.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 40.0 -18 3 Pally Cloudy WC- NE A.5 MPH 14 Daily summary operation 24h Summary POOH L/D 4.5"12.6#13Cr L80 Vam Top F/7,558'to 7,150'MD.Filling hole over top,loss rate 35 bph.Swap out ESP spool.Cut and shorten CAP Tube due to being too long to run over sheave.Reduce Brine weight to 9.4 ppg due to losses.POOH UD 4.5"12.6#13Cr L80 Vam Top F/7,150'to 6,689'MD.L/D GLM.POOH to 6,587'MD and lay down SSV.Cont.to POOH to 5,579'.Filling hole over top. loss rate 35 bph.Lay down 3rd party tools,clean and clear rig floor.Service rig,Top Drive and Drawworks.Cut CAP Tube and shorten line.POOH L/D 4.5"12.6#13Cr L80 Vam Top F/2,924'to 1.414' MD.Filling hole over top,loss rate 25 bph.Cut CAP Tube and shorten line.POOH L/D 4.5"12.6#13Cr L80 Vam Top F/2,924'to 1,414'MD.Filling hole over top,loss rate 25 bph.Clean and clear rig floor and cellar due to pulling wet pipe with contaminated Brine with Diesel.POOH L/D 4.5"12.6#13Cr L80 Vam Top F/880'to 581'MD.Filling hole over top,loss rate 25 bph.Lost 627 BBL NaCI Brine to formation. Operation at 07.00 Laying down Pump and Shroud. 24h Forecast Cont.to POOH and L/D 4.5"Tubing F/581'to Baker Pump.L/D Pump and shroud as per Baker Centralift.Load 5"D.P.in Pipe Shed,strap and drift all D.P.P/U MN Polish Mill as per Baker.RIH single joints from Pipe Shed. Lithology Shows MAASP(kgflcm") Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 04:30 4.50 4.50 W.O. G 4 P PJSA POOH LID 4.5"12.6#13Cr L80 Vam Top F/7,558'to 7,150'MD.Filling hole over top,loss rate 35 bph. 04:30 06:30 2.00 6.50 W.O. G 20 P PJSA Swap out ESP spool.Cut and shorten CAP Tube due to being too long to run over sheave.Reduce Brine weight to 9.4 ppg due to hole losses. 06:30 10:30 4.00 10.50 W.O. G 4 P PJSA POOH L/D 4.5"12.64 13Cr L80 Vam Top F/7,150'to 6,689'MD.UD GLM.POOH to 6,587'MD and lay down SSV. Cont.to POOH to 5,579'.Filling hole over top,loss rate 35 bph. 10:30 11:30 1.00 11.50 W.O. G 20 P PJSA Lay down 3rd party tools,clean and clear ng floor. 11:30 12:00 0.50 12.00 W.O. G 25 'P PJSA Service rig,Top Drive and Drawworks. 12:00 17:00 5.00 17.00 W.O. G 4 P PJSA POOH L/D 4.5"12.6#13Cr L80 Vam Top F/5,579'to 2,924'MD.Filling hole over top,loss rate 25 bph. 17:00 17:30 0.50 17.50 W.O. G 20 P PJSA Cut CAP Tube and shorten line. 17:30 21:00 3.50 21.00 W.O. G 4 P PJSA POOH L/D 4.5"12.68 13Cr L80 Vam Top F/2,924'to 1,414'MD.Filling hole over top,loss rate 25 bph. 21:00 21:30 0.50 21.50 W.O. G 20 P PJSA Cut CAP Tube and shorten line. 21:30 22:30 1.00 22.50 W.O. G 4 P PJSA POOH L/D 4.5"12.68 13Cr L80 Vam Top F/1,414'to 880'MD.Filling hole over top,loss rate 25 bph. 22:30 23:00 0.50 23.00 W.O. G 20 P PJSA Clean and clear rig floor and cellar due to pulling wet pipe with contaminated Brine with Diesell. 23:00 00:00 1.00 24.00 W.O. G 4 P PJSA POOH L/D 4.5"12.68 13Cr L80 Vam Top F/880'to 581'MD.Filling hole over top,loss rate 25 bph. Daily Contacts Position Contact Name Company Title E-mail Office Mobile - Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Paul Holley ENI HSE Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl 5@enipetroleumcorn 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1.662 10 3.756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 ft* Eni E&P Division Well Name:0P23-W W02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 IField Name:Nikaitchuq • 2^ii Date:3/21/2015 - Report#: 16 API/UWI 50-029-23411-00-00 I� II page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share)%) Well Configuration type Oliktok Pool ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1811.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather wind 0.00 41.0 -19.4 Overcast WC-14 SSW @ 4 MPH Daily summary operation 24h Summary POOH L/D 4.5"12.6#13Cr L80 Vam Top FI 581'to 104'MD.Filling hole over top,loss rate 25 bph.PJSM W/all essential personnel.Made several attempts to beak Pump F/Shroud with chain tongs. Discussion was made to use Power Tongs as per Co Rep onsite.C/O Power Tongs to 7 5/8"Csg Tongs to break out 7 5/8"Shroud.Break Shroud Hanger and LID Pump Assy.as per Baker Centralift Rep.Break 7 5/8"Shroud down and L/D as per GBR.L/D GBR Tongs.Pull ESP and CAP Tube lines over sheaves to Spooler Unit.L/D GBR tools.Ciro,across the top of hole,14 bph loss rate.Clean and clear rig floor.Service rig,Canrig 1250-AC Top Drive,Blocks and Dravw.orks.L/D Elephant Trunk.Clean suction screens on Mud Pumps.Clean Pit PVT sensors.Install Wear Bushing 9"ID as per Baker Rep onsite.Load 5"and 2 7/8"D.P.into Pipe Shed.Brought up 2 7/8"handling Equip to rig floor.Install 2 7/8"Elevators.Total lost today 343 bbl,about 10-15 bph. Operation at 07.00 Process 5"and 2 7/8"D.P.in Pipe Shed. 24h Forecast Cont.to load 5"and 2 7/8"D.P.to Pipe Shed.Strap and rabbit D.P.PtU 2 7/8"Mule Shoe and single in 2 7/8"D.P.with GBR making up D.P.PIU M/U Baker inline BHA for clean out run.P/U M/U 5"D.P. singles F/Pipe Shed. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1114 4 Time Log Start End Cum Time Time Dur(hr) Dur(Er) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 W.O. G 4 P PJSA POOH L/D 4.5"12.6#13Cr L80 Vam Top FI 581'to 104'MD.Filling hole over top,loss rate 25 bph. 03:30 04:30 1.00 4.50 W.O. G 20 P PJSM W/all essential personnel.Made several attempts to beak Pump F/Shroud with chain tongs,Discusion was made to use Power Tongs as per Co Rep onsite. 04:30 06:30 2.00 6.50'W.O. G 20 P PJSA C/O Power Tongs to 7 5/8"Csg Tongs to break out 7 5/8"Shroud. 06:30 10:30 4.00 10.50'W.O. G 20 P PJSA Break Shroud Hanger and UD Pump Assy.as per Baker Centralift Rep.Break 7 5/8"Shroud down and L/D as per GBR. 10:30 12:00 1.50 12.00"W.O. G 20 P PJSA UD GBR Tongs.Pull ESP and CAP Tube lines over sheaves to Spooler Unit.Clean and clear rig floor. 12:00 14:00 2.00 14.00 W.O. G 20 P PJSA L/D GBR tools.Ciro,across the top of hole,14 bph loss rate.Cont.to clean and clear rig floor. 14:00 14:30 0.50 14.50 W.O. L 25 P PJSA Service rig,Canrig 1250-AC Top Drive,Blocks and Drawworks. 14:30 16:00 1.50 16.00 W.O. G 5 P PJSA UD Elephant Trunk.Clean suction screens on Mud Pumps.Clean Pit PVT sensors. 16:00 16:30 0.50 16.50 W.O. C 19 P PJSA Install Wear Bushing 9"ID as per Baker Rep onsite. 16:30 00:00 7.50 24.00 W.O. L 20 TD03 PJSA Load 5"and 2 7/8"D.P.into Pipe Shed.Brought up 2 7/8"handling Equip to ng floor.Install 2 7/8"Elevators Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Dulling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Steve Millea ENI HSE Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER7 6.276 13CrL80 1.66210 3,756.05 513/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(giL) P Surf Applied(kgflcm') Eq.Mud Weight(g/L) P LeakOff(kgflcm') 2,795.02, 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 lEni E&P Division (Well Name:OP2 WW02 DIR 91* I ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq enAPIIUWI:50-029-23411-00-00 e^ Date:3/22/2015 - Report#: 17 II II IIpage 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 011ktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(mlhr) DFS(days) OP23-WW02 WORKOVER 1812.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(Er) Avg ROP(m/hr) POB Temperature("C) Weather Wind 0 00 42.0 -16 1 Overcast WC-17° SW @ 18 MPH Daily summary operation 24h Summary Cont.to load 5"and 2 7/8"D.P.into Pipe Shed.Strap and Rabbit D.P.P/U running tools and GBR Tongs to ng floor. RIO to run 2 7/8"D.P.P/U M/U as per GBR Rep 2.875"Mule Shoe,RIH P/U M/U W/ GBR Power Tongs 102 Jnts 2.875"D.P.F/4.85'to 3,222.23'MD.HST 68K,SLK 70K.R/D GBR Tools and Equip.Remove Sheaves from Derrick to rack back 5"D.P.PJSM W/all essential personnel for inline BHA.As per Baker Rep onsite.M/U X/O,Pump Out Sub,DBL Pin X/O,3 Boot Baskets.Bit Sub,6 1/4"Bumper Sub and 6 1/4"Oil Jars.F/3,222'to 3.265'MD.Co Rep onsite.Filling over top of well,loss rate 10-15 bph.Total lost for day 310 bbl. Operation at 07.00 P/U M/U from Pipe Shed 5"DP and single in hole @4,700'MD. 24h Forecast C/O Handling Equip.to 5"D.P.P/U M/U and single in hole from Pipe Shed 5"HWDP and 5"D.P.Stop and break Circ.at top of Packer to ensure Mule Shoe is not plugged.Cont.to RIH to 12,065'MD. Break Circ.and clean out hole. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1114 4 Time Log Start End Cum Time Time Dur(Er) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 12:00 12.00 12.00 W.O. M '20 TD03 PJSA Cont.to load 5"and 2 7/8"D.P.into Pipe Shed.Strap and Rabbit D.P.PIU running tools and GBR Tongs to rig floor. Filling over top of hole,loss rate 10-14 bph. 12:00 14:00 2.00 14.00 W.O. M -20 TD03 PJSA P/U GBR tools and Equip.RIO to run 2 7/8"D.P. 14:00 20:30 6.50 20.50 W.O. M '4 TD03 PJSA PIU MIU as per GBR Rep 2.875"Mule Shoe,RIH P/U MIU W/GBR Power Tongs 102 Jnts 2.875"D.P.F/4.85'to 3,222.23'MD.HST 68K,SLK 70K. 20:30 22:30 2.00 22.50 W.O. M 20 TD03 PJSA R/D GBR Tools and Equip.Remove Sheaves from Denick to rack back 5"D.P. 22.30 00:00 1.50" 24.00 W.O. M '4 TD03 PJSM W/all essential personnel for inline BHA.As per Baker Rep onsite.M/U X/O,Pump Out Sub.DBL Pin X/O,3 Boot Baskets,Bit Sub,6 1/4"Bumper Sub and 6 1/4"Oil Jars.F/3,222'to 3,265'MD.Co Rep onsite.Filling over top of hole, loss rate 10-15 bph. I Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Ben Perry ENI Senior Dulling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Steve Millea ENI HSE Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 .907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm") Eq.Mud Weight(gIL) P LeakOft(kgflcm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division Well Name:OP23 WW02 DIR fill* ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq 2II II InI Date:3/23/2015 - Report#: 18 API/UWI:50-029-23411-00-00 page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 VLORKOVER 1813.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 41.0 -28.3 Overcast WC-41' SW @ 10 MPH Daily summary operation 24h Summary Cont.to M/U Inline BHA as per Baker Rep onsite.PN M/U and single in 5"D.P.F/3,536'to 8,863'MD Break Circ.@ 88 GPM,320 PSI and wash down through Liner Hanger to 8,895'MD.HST 165K, SLK 140K.Blow down Top Drive.Cont.to P/U M/U 5"D.P.and single in hole F/8,895'to 9,406'MD.Break Circ.and condition Brine Weight, F/9.3 ppg to 9.2 ppg.Pump rate to start 60 GPM,200 PSI increase pump rate to 105 gpm FCP 400 PSI.Dynamic losses slowing to about 5-10 bph.Blow down Top Drive and monitor well.Static loss about 10 bph.Cont.to P/U M/U 5"D.P.and single in hole F/ 9,406'to 11,988'MD.SLK 140K Dynamic loss about 10 bph.Total losses for today 402 bbls. Operation at 07.00 Circ.and prep Brine in well. 24h Forecast Cont.to RIH to 12,065'MD.Circ.and condition Brine to 9.1 to 9.2 making sure to reduce minimal losses during circulating hole clean.Pump 20 bbl Hi Vis sweep and more if needed.Capture all rubber at surface and weight.POOH and rack back 5"D.P. Lithology Shows MAASP(kgflcm"( Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00.00 02:00 2.00 2.00 W.O. M 20 TD03 PJSA Cont.to M/U Inline BHA as per Baker Rep onsite. 02:00 10:30 8.50 10.50 W.O. 'M 4 TD03 PJSA P/U M/U and single in 5"D.P.F/3,536'to 8,863'MD Break Circ.@ 88 GPM,320 PSI and wash down through Liner Hanger to 8,895'MD.HST 165K,SLK 140K.Blow down Top Drive. 10:30 11:30 1.00 11.50 W.O. M 8 TD03 PJSA Cont.to P/U M/U 5"D.P.and single in hole FI 8.895'to 9,406'MD.SLK 140K 11:30 12:00 0.50 12.00 W.O. M 8 TD03 PJSA Break Circ.and condition Brine Weight,reduce Brine weight F/9.3 ppg to 9.2 ppg at 60 GPM,200 PSI. 12:00 19:00 7.00 19.00 W.O. M 8 TD03 PJSM Cont.to Circ.and reduce Brine weight F/9.3 ppg to 9.2 ppg.Pump rate to start 60 GPM,200 PSI increase pump rate to 105 gpm FCP 400 PSI.Dynamic losses slowing to about 5-10 bph. 19:00 19:30 0.50 19.50 W.O. M 11 TD03 "PJSA Blow down Top Drive and monitor well.Static loss about 10 bph. 19:30 00:00 4.50 24.00 W.O. M 4 TD03 PJSA Cont.to P/U MN 5"D.P.and single in hole F/9,406'to 11,988'MD.SLK 140K Dynamic loss about 10 bph. Daily Contacts Position Contact Name Company Me E-mail Office Mobile - Eni representative Ben Perry ENI Senior Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Steve Millea ENI HSE Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1.662.10 3.756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgfIcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm") 2.795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division WeII Name:0P23 WWO2 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq e Date:3/24/2015 - Report#: 19 APIIUWI:50-029-23411-00-00 2" " page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(in) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1814,06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 38.0 -22.2 Partly Cloudy WC- NE @ 20 MPH 33° Daily summary operation 24h Summary Cont.to P/U M/U 5"D.P.and single in hole F/11,988'to 12,064'MD.HST 245K,SLK 170K Dynamic loss about 10 bph.Break Circ.and make sure brine weight in and out is 9.2 ppg.Stage up pump rate F/1 bpm ICP 182 PSI to 5 bpm FCP 1,350 PSI.Monitor well,static loss rate about 4 bph.Pump 20 bbl Hi Vis Sweep,75 s/qt at 5 bpm,1,346 PSI W/about 30%rubber at Shakers.Second 20 Hi Vis Sweep,110 S/qt at 5.5 bpm,1,550 PSI W/about 40%increase of plastic at Shaker.Dynamic losses increased to about 10-15 bph.Break connection and drop ball as per Baker Rep onsite to open Circ. Sub.Sheared open at 1,950 PSI.Monitor well for 15 Min.static loss about 4 bph.Pump Third 20 bbl Hi Vs Sweep,130 s/qt at 6 bpm,180 PSI,increased rate to 8 bpm,380 PSI.W/about 60%rubber at Shakers.Fourth 20 Hi Vis Sweep,130 S/qt at 6 bpm,170 PSI increase rate to 8 bpm,370 PSI,WI about 10%increase of plastic at Shaker.Dynamic losses about 10-15 bph.Circ.across the top of the well and monitor,about 4 bph static loss rate.Make up 20 bbl Hi Vis Sweep in Pits.SIMOPS C/O camera in Derrick and clean rig floor.Pump fifth 20 bbl Hi Vis Sweep 80 s/qt at 6 bpm,290 PSI increase rate to 8 bpm.400 PSI WI about 10%increase at Shakers.Monitor well for 15 Min.,static loss about 4 bph.Blow down Top Drive.Pull 5 stands off bottom F/12,064'to 11,609'MD and watch for swabbing,good.Cont to POOH 5"D.P.and rack back in Derrick F/11,609'to 10,444'MD.HST 238K.Static loss around 4 bph.Total loss today 246 bbl.Recovered about 483 lb of plastic from well. Operation at 07.00 POOH w/5"DP @ 6,200'MD. 24h Forecast Cont.to POOH 5"D.P.on elevators F/10,444'to 8,550'MD.L/D Baker in line BHA and clean out Junk Baskets.L/D Baker tools.R/U GBR Power Tongs.POOH 2 7/8"D.P.and lay down in Pipe Shed Clean Stack and perform BOPE test. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1102.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01.00 1.00 1.00 W.O. M 4 TO03 (PJSA Cont.to P/U M/U 5"D.P.and single in hole F/11,988'to 12,064'MD.HST 245K,SLK 170K Dynamic loss about 10 bph. 01:00 07:00 6.00 7.00 W.O. M 9 TD03 PJSA Break Circ.and make sure brine weight in and out is 9.2 ppg.Stage up pump rate Fl 1 bpm ICP 182 PSI to 5 bpm FCP 1,350 PSI. 07:00 13:00 6.00 13.00 W.O. M 9 TD03 'PJSA Monitor well,static loss rate about 4 bph.Pump 20 bbl Hi Vis Sweep,75 s/qt at 5 bpm,1,346 PSI W/about 30% rubber at Shakers.Second 20 Hi Vis Sweep,110 S/qt at 5.5 bpm,1,550 PSI W/about 40%increase of plastic at Shaker. Dynamic losses increased to about 10-15 bph. 13:00 13:30 0.50 13.50 W.O. M 19 TD03 PJSA Break connection and drop ball as per Baker Rep onsite to open Circ.Sub.Sheared open at 1,950 PSI.Monitor well for 15 Min.static loss about 4 bph. 13:30 18:00 4.50 18.00 W.O. M 9 'TD03 PJSA Pump Third 20 bbl Hi Vis Sweep,130 s/qt at 6 bpm,180 PSI,increased rate to 8 bpm,380 PSI.W/about 60% rubber at Shakers.Fourth 20 Hi Vis Sweep,130 S/qt at 6 bpm,170 PSI increase rate to 8 bpm,370 PSI,WI about 10% increase of plastic at Shaker.Dynamic losses about 10-15 bph. 18:00 19:30 1.50 19.50 W.O. M 20 TD03 PJSA Circ.across the top of the well and monitor,about 4 bph static loss rate.Make up 20 bbl Hi Vis Sweep in Pits. SIMOPS CIO camera in Derrick and clean rig floor. 19:30 21:00 1.50 21.00 W.O. M 9 TD03 PJSA Pump fifth 20 bbl Hi Vis Sweep 80 s/qt at 6 bpm,290 PSI increase rate to 8 bpm,400 PSI W/about 10%increase at Shakers. 21:00 21:30 0.50 21.50 W.O. M 20 'TD03 PJSA Monitor well for 15 Min.,static loss about 4 bph.Blow down Top Drive. 21:30 00:00 2.50 24.00 W.O. M 4 TD03 PJSA Pull 5 stands off bottom F/12,064'to 11,609'MD and watch for swabbing,good.Cont to POOH 5"D.P.and rack back in Derrick F/11,609'to 10.444'MD.HST 238K.Static loss around 4 bph. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Steve Millea ENI HSE Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Bemie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1.662.10 3.756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division Well Name:OP23 WW02 DIR 1 IR,* j EN/Petroleum Co.Inc. Daily Report Well Code:23835 • Field Name:Nikaitchuq Date:3/25/2015 - Report#: 20 Field N I:50-029-23411-00-00 2" " p page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1815.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 0.00 38.0 -23.3 Partly Cloudy WC- NE©15 MPH 32° Daily summary operation 24h Summary POOH on elevators racking back 5"D.P.in Derrick Fl 11,609'to 3,265'MD.HST 205K.Static loss around 4 bph.PJSM W/all essential personnel.UD Oil Jars and Bumper Sub.Break down DBL Pin, Circ.Sub,and Boot Baskets.Recovered 1/2 cup of debris from Boot Baskets as per Baker Rep onsite.POOH and L/D 2 7/8"D.P.to Pipe Shed F/3,224'MD to Mule Shoe'MD.HST 50K.L/D Tools and R/D GBR handling Equip.to Pipe Shed.Pull Wear Bushing as per Baker Rep onsite.P/U single joint 5"D.P.and stack flushing tool.Flush Stack.Drain out Stack and set test plug as per Baker Rep onsite.Filled with water and purge all air from Choke Manifold.Test BOPE with 5"test joint.Test plug looked to be leaking.C/O test plug rubber.Monitor well for 15 Min.Filled stack and purged air out. Monitor IA for slight trickle.Witness waived by AOGCC Louis Grimaldi.Total loss today 37 bbl. Operation at 07.00 Test ROPE.. 24h Forecast Trouble shoot BOPE for leak.Monitor slight trickle at IA valve.may be due to thermal expansion.Test BOPE.P/U M/U Polish Mill as per Baker Rep onsite.RIH WI 5"D.P.and clean Liner top.POOH laying down 5"D.P.to Pipe Shed. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11024 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 05:00 5.00 5.00 W.O. M 4 TD03 PJSA POOH on elevators racking back 5"D.P.and 3 stands of 5"HWDP in Derrick F/11,609'to 3,265'MD.HST 205K. Static loss around 4 bph. 05:00 08:00 3.00 8.00 W.O. M 4 TD03 PJSM W/all essential personnel.LID Oil Jars and Bumper Sub.Break down DBL Pin,Circ.Sub,and Boot Baskets. Recovered 1/2 cup of debris from Boot Baskets as per Baker Rep onsite. 08:00 13:00 5.00 13.00 W.O. E 4 TD03 PJSA POOH and UD 2 7/8"D.P.to Pipe Shed F/3,224'MD to Mule Shoe'MD.HST 50K. 13:00 14:30 1.50 14.50 W.O. M 20 TD03 PJSA L/D Tools and RID GBR handling Equip.to Pipe Shed. 14:30 15:00 0.50 15.00 W.O. C 19 TD03 PJSA Pull Wear Bushing as per Baker Rep onsite. 15:00 15:30 0.50 15.50 W.O. C 19 P PJSA P/U single joint 5"D.P.and stack flushing tool.Flush Stack. 15:30 18:30 3.00 18.50 W.O. C 5 P PJSA Drain out Stack and set test plug as per Baker Rep onsite.Filled with water and purge all air from Choke Manifold. 18:30 00:00 5.50 24.00 W.O. C 12 "P PJSA Test BOPE with 5"test joint,Choke valves 1,2,3,4,6,7,9,16,Demco Kill,Dart Valve and HCR Kill 250 PSI low and 3,500 PSI high for 5 Min all on chart.Test plug looked to be leaking.CIO test plug rubber.Monitor well for 15 Min.Filled 1 stack and purged air out.Monitor IA for slight trickle.Witness waived by AOGCC Louis Grimaldi. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Steve Millea ENI HSE Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Bemie Leas ENI Rig Clerk akrigderksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1.662.10 3,756.05 5/312010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division Well Name:0P23WW02 DIR cif* ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq 2^n Date:3126/2015 - Report#: 21 API/UWI:50-029-23411-00-00 II �I II page 1 of 1 Wellbore name: OP23-WW02 Well Header PermitlConcession N° Operator ENI Share(%) Well Configuration type 011ktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1816.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature(°C) Weather Wind 0 00 43.0 -17.2 Overcast WC-16° NE @ 10 MPH Daily summary operation 24h Summary After setting test plug,IA still had a trickle.Pulled test plug and redressed as per Vetcp Grey onsite.Fill Stack and monitor well for 20 Min.and static loss was 3-4 bph.Set test plug and body test BOPE to 3,600 PSI.No leaks.Slight trickle at IA and was monitored during BOPE test.Test BOPE.R/D test Equip.Pull test plug as per Baker Rep onsite.Install Wear Bushing.Blown tools and Equip.P/U MN Polish Mill as per Baker Rep onsite.RIH W/3 stands of HWDP and 5"D.P.from Derrick to 8,909'MD and tag No Go,Put 8K on it to confirm.Liner top @ 8,900'MD.Filled D.P.Break Circ.and pump 22 bbl Hi Vis Sweep 140 Vis at 5 bpm 120 PSI,stage pump rate up to 8 bpm 300 PSI.ROT 170K,SLK 175K,30 RPM,TRQ 4,700 to 6,200K.Dynamic loss 14 bph.No signs of rubber in sweep.Monitor well for 15 Min.static and observed 4-6 bbl bph.SIMOPS Clean and clear rig floor.As per Baker Rep onsite dress top of Liner at 8,900'MD.Set 5K down W/5 bpm,125 PSI,PN 5'and stage up rotary to 50 RPM,TRF 6.6K.Set down 5K,TRQ 7.8K dress top,mill off 1K TRQ.SLK off 7K,TRO 9.5K.PN ream and wash he back W/8'of stroke.Retag dress top W/SLK 5K,TRQ 9.5K,PN ream and wash he back.Stop rotation and confirm tag @ 8,900'MD W/5K and 5 bpm,FCP 120 PSI.PN out of tie back.Monitor well for 15 Min.4-6 bph.SIMOPS R/U to lay down D.P.POOH F/8,909' to 8,030'MD laying down 5"D.P.to Pipe Shed. Operation at 07.00 POOH laying down 5"D.P.to Pipe Shed. 24h Forecast POOH laying down 5"D.P.to Pipe Shead.L/D Polish Mill.R/U Completion Equip.RIH W/Pump and Motor on 4.5"Vam Cr13. LKhology Shows MAASP(kgflcm') Mud Weight(gIL) 11024 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 03:30 3.50 3.50 W 0 C 20 P PJSA After setting test plug,IA still had a trickle.Pulled test plug and redressed as per Vetcp Grey onsite.Fill Stack and monitor well for 20 Min.and static loss was 3-4 bph.Set test plug and body test BOPE to 3,600 PSI.No leaks.Slight trickle at IA and was monitored during BOPE test.Co Rep onsite. 03:30 10:00 6.50 10.00 W.O. C 12 P PJSA Cont.to test BOPE W/5"test joint:Choke 5,8,10,11,12,14,15,Upper and Lower Pipe Rams,Upper and Lower'BOP, Manual Kill,Choke HCR.Test W/4.5"test joint,Upper and lower Rams,TIW and Annular to 2,500 PSI high all other tested to 250 PSI low and 3,500 PSI high for 5 Mm all charted.Manual Choke A 8 B and Super Choke to 1,500 PSI.Koomey Draw down 10:00 12:00 2.00 12.00 W.O. C 20 P PJSA R/D test Equip.Pull test plug as per Baker Rep onsite.Install Wear Bushing.Blown tools and Equip. 12:00 13:00 1.00 13.00 W.O. M 20 P PJSA P/U M/U Polish Mill as per Baker Rep onsite. 13:00 18:30 5.50" 18.50 W.O. M 4 P PJSA RIH W/3 stands of HWDP and 5"D.P.from Derrick to 8,909'MD and tag No Go,Put 8K on it to confirm.Liner top @ 8,900'MD.Filled D.P.HST 200K,SLK 145K. 18:30 '21:30 3.00 21.50 W.O. M 9 P PJSA Break Circ.and pump 22 bbl Hi Vis Sweep 140 Vis at 5 bpm 120 PSI,stage pump rate up to 8 bpm 300 PSI.ROT 170K,SLK 175K,30 RPM,TRQ 4,700 to 6,200K.Dynamic loss 14 bph.No signs of rubber in sweep. 21:30 22:00 0.50" 22.00 W.O. M 20 P Monitor well for 15 Min.static and observed 4-6 bbl bph.SIMOPS Clean and clear rig floor. 22:00 '22:30 0.50 22.50 W.O. M 19 P PJSA As per Baker Rep onsite dress top of Liner at 8,900'MD.Set 5K down W/5 bpm,125 PSI,P/U 5'and stage up rotary to 50 RPM,TRF 6.6K.Set down 5K,TRQ 7.8K dress top,mill off 1K TRQ.SLK off 7K,TRQ 9.5K.P/U ream and wash tie back W/8'of stroke.Retag dress top W/SLK 5K,TRO 9.5K,PN ream and wash tie back.Stop rotation and confirm tag @ 8,900'MD W/5K and 5 bpm,FCP 120 PSI.P/ll out of tie back. 22:30 23:00 0.50 23.00 W.O. M 20 P Monitor well for 15 Min.4-6 bph.SIMOPS R/U to lay down D.P. 23:00 "00:00 1.00 24.00 W.O. M 4 P PJSA POOH F/8,909'to 8,030'MD laying down 5"D.P.to Pipe Shed. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Steve Millea ENI HSE Eni representative Greg Parker ENI Matis Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyonl5@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662.10 3.756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(g/L) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.705 02 2.031 81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division I Well Name:OP23-WW02 DIR go* EN!Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq iiii Date:312712015 - Report#: 22 API/UWI:50-029-23411-00-00 2" " page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 1622 3.72 960 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1817.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(mlhr) POB Temperature("C) Weather Wind 0.00 47.0 -15.6 Overcast WC-7 W @ 3 MPH Daily summary operation 24h Summary POOH F/9030' to 290'MD laying down 5"D.P.to Pipe Shed.Cut and slip 70'drilling line.Service Rig,Drawworks,Blocks and Skate.Adjust Brakes and set Crown Saver.Lay down 3 stands 5"HWDP to Pipe Shed and break down Baker Polish Mill.Pull Wear Bushing as per Vetco Grey Rep onsite.P/U 3rd party tools and Equip.Baker Centrilift,GBR and Baker Completion Reps onsite.Hold PJSM with all parties on P/U M/U Pump Motor,Shroud and running in hole with 4.5"Tubing.P/U M/U 7"Tieback Assy.as per Baker Completion Rep onsite to 7 5/8"Shroud W/GBR power tongs.to 93'MD.P/U and stand back Shroud Hanger.P/U 6"Centrilizer and M/U to 562 Motor 270 hp as per Baker Centrilift Reps onsite.Lower into shroud. Operation at 07.00 MN Baker Pump Assy.and wotk on splice. 24h Forecast Cont.to make up Baker Motor and Pump Assy.M/U shroud and R/U ESP and CAP Tube lines.RIH W/4.5"Tubing as per Tally. Lithology Shows MAASP(kgf/cm') Mud Weight(g/L) 1102 4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 11:00 11.00 11.00 W.O. M 4 P PJSA POOH F/8,030'to 290'MD laying down 5"D.P.to Pipe Shed. 11:00 14:00 3.00 14.00 W.O. M 25 P PJSA Cut and slip 70'drilling line.Service Rig,Drawworks,Blocks and Skate.Adjust Brakes and set Crown Saver. 14:00 15:00 1.00 15.00 W.O. M 4 P PJSA Lay down 3 stands 5"HWDP to Pipe Shed and break down Baker Polish Mill. 15:00 15:30 0.50 15.50 W.O. C 19 P PJSA Pull Wear Bushing as per Vetco Grey Rep onsite. 15:30 20:00 4.50 20.00 W.O. M 20 P PJSM P/U 3rd party tools and Equip.Baker Centralift,GBR and Baker Completion Reps onsite. 20:00 20:30 0.50 20.50 W.O. K 20 P Hold PJSM with all parties on P/U MN Pump Motor,Shroud and running in hole with 4.5"Tubing. 20:30 00:00 3.50 24.00 W.O. K 20 P Aic PJSA.P/U MN 7"Tieback Assy.as per Baker Completion Rep onsite to 7 5/8"Shroud W/GBR power tongs.to 93'MD. PN and stand back Shroud Hanger.P/U 6"Centralizer and M/U to 562 Motor 270 hp as per Baker Centrilift Reps onsite. Lower into shroud. Daily Contacts Position Contact Name Company Title E-mall Office Mobile . Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Steve Millea ENI HSE Eni representatve Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrgclerksdoyon15Qenipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division IWeIIName:OP23-WW02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq nDate:312812015 - Report#: 23 APIIUWI:50-029-23411-00-00 e II II II page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1818.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 0.00 46.0 -17.8 Light Snow WC-17° NE @ 11 MPH Daily summary operation 24h Summary PJSM WI all essential personnel.Cont.to M/U Baker Pump and Motor Assy.as per Baker Rep onsite.Co Rep onsite to ensure oiling and motor rotation.Mark,cut and connect Tech line.Run ESP and CAP Tube splice thru RMS Pump tool shroud Hanger.PJSM W/all essential personnel for string up ESP and CAP tube over sheave.Run ESP and CAP Tube over sheave in Derrick.Make Hanger splice at shroud and test.RIH W/4.5"Vam Top 12.6#,Cr13 W/ESP and CAP Tube F/93'to 3,512'MD.Checking ESP every 1,000'RIH as per Baker Centrilift onsite.Monitor well,static loss 1 bph.81 Cannon Clamps and 162 Pins.Total Brine lost today 26 bbl. Operation at 07.00 RIH 4.5"12.6#,Cr13 Vam W/ESP and CAP Tube @ 4,400'MD. 24h Forecast Cont.to RIR W/4.5"12.6#,Cr13,Vam F/3,512'to SSSV and GLM @ 6,670'MD.RN Schlumberger SSSV CAP Tube spooler to rig floor.P/U MN SSSV as per Schlumberger Rep onsite.Cont.to RIH 4.5"Tubing as per tally. Lithology Shows MAASP(kgf/cm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:30 6.50 6.50 W.O. K 20 P PJSM WI all essential personnel.Cont.to M/U Baker Pump and Motor Assy.as per Baker Rep onsite.Co Rep onsite to ensure oiling and motor rotation. 06:30 11:00 4.50' 11.00 W.O. K '20 P PJSA Mark,cut and connect Tech line.Run ESP and CAP Tube splice thru RMS Pump tool shroud Hanger.PJSM W/all essential personnel for string up ESP and CAP tube over sheave.Run ESP and CAP Tube over sheave in Derrick. 11:00 13:00 ' 2.00- 13.00'W.O. K 20 P PJSA Make Hanger splice at shroud and test. 13:00 00:00 11.00 24.00 W.O. K 4 P PJSA RIH W/4.5"Vam Top 12.6#,Cr13 W/ESP and CAP Tube F/93'to 3,512'MD.Checking ESP every 1,000'RIH as per Baker Centrilift onsite.Monitor well,static loss 1 bph.81 Cannon Clamps and 162 Pins. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative 'Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Steve Millea ENI HSE Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Bemie Leas ENI Rig Clerk akrigclerksdoyonl 5©enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2.795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P Division Well Name:OP23-WW02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq 2^f1141 Date:3/29/2015 - Report#: 24 APIIU WI:50-029-23411-00-00 II II�In page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N' Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours)hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1819.07 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POE Temperature("C( Weather Wind C.00 46.0 -20.0 Clear WC-34° NE @ 35 MPH Daily summary operation 24h Summary RIH W/4.5"Vam Top 12.64,Cr13 W/ESP and CAP Tube F/3,512'to 4,948'MD.Checking ESP every 1,000'RIH as per Baker Centring onsite.Monitor well.static loss 1 bph.C/O joints 98,116&117 W/207,206,208.PJSM W/all essential personnel.ESP cable damage at 4,935'MD.Decision was made to swap out ESP spool to new spool.Cut and lower ESP line through Sheave and C/O spools. P/U new ESP line and resting through sheave.Make splice W/Gator connector and tested ESP,good.RIH WI 4.5"yarn Top 12.64,Cr13 W/ESP and CAP Tube F/4,948'to 6,674'MD.Checking ESP every 1,000'RIH as per Baker Centrilif onsite.Monitor well,static loss 1 bph.C/O joints 152&153 W/209&210.Total used 74 Cannon clamps and 148 Pins.SLK 92K.PJSM with all essential personnel for SSSV and GLM.P/U Schlumberger tools and Equip.to rig floor.R/U Schlumberger injection spooler on rig floor.PN MN SSSV TRMAXX-5E as per Schlumberger Rep onsite.Static loss about 1 bph,total lost today 23 bbl. Operation at 07.00 RIH 4.5"12.64,Cr13 Vam W/ESP,CAP Tube and SSSV Injection line @ 7,300'MD. 24h Forecast Have PJSM W/all essential personnel for GLM.P/U MN GLM.RIH 4.5"Vam Tubing W/ESP,CAP and SSSV injection line.Using Cannon clamps and stainless for SSSV.Land and space out.Add pups and VIT joints.PN M/U Hanger and terminate lines.Test lines at Hanger.Displace to treated 9.2 ppg Brine.Land Hanger. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1114.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 06:00 6.00 6.00 W.O. K 4 P PJSA RIH W/4.5"Vam Top 12.64,Cr13 W/ESP and CAP Tube F/3,512'to 4,948'MD.Checking ESP every 1,000'RIH as per Baker Centring onsite.Monitor well,static loss 1 bph.C/O joints 98,116&117 W/207,206,208.Used 33 Cannon clamps and 66 Pins.SLK 84K 06:00 16:30 10.50 16.50 W.O. •K 20 P PJSM W/all essential personnel.ESP cable damage at 4,935'MD.Decision was made to swap out ESP spool to new spool.Cut and lower ESP line through Sheave and C/O spools.P/U new ESP line and resting through sheave.Make splice W/Gator connector and tested ESP,good. 16:30 22:30 6.00' 22.50 W 0. K 4 P PJSA RIH W/4.5"Vam Top 12.64,Cr13 W/ESP and CAP Tube Fl 4,948'to 6,674'MD.Checking ESP every 1,000'RIH as per Baker Centrilitt onsite.Monitor well.static loss 1 bph.C/O joints 152&153 W/209&210.Used 41 Cannon clamps and 82 Pins.SLK 92K 22:30 00:00 1.50- 24.00 W 0 K 4 'P PJSM with all essential personnel for SSSV and GLM.P/U Schlumberger tools and Equip.to rig floor.RN Schlumberger injection spooler on rig floor.P/U M/U SSSV TRMAXX-5E as per Schlumberger Rep onsite. Daily Contacts Position � Contact Name Company Title E-mall Office Mobile Eni representative Bruce Simonson ENI Drilling Supv 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Steve Millea ENI HSE Eni representative Greg Parker ENI Matls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) • Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB( Fluid Type Fluid Density(gIL) P Surf Applied(kgflcm') Eq.Mud Weight(gIL) P LeakOtf(kgf/cm') 2,795.02 2,031.81 VC-OBM 1234.2 119.5 1822.5 370.2 r Eni E&P Division !Well Name:0P23-W W02 DIR ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq • 2 ' ^rl Date:3/30/2015 - Report#: 25 API/UWI:50-029-23411-00-00 II III page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N" Operator ENI Share(%) Well Configuration type 011ktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1820.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) PUB Temperature(°C) Weather Wind ()00 45.0 -18.3 Blowing Snow WC- NE @ 30 MPH 26° Daily summary operation 24h Summary PJSM W/all essential personnel.P/U M/U GLM and RIH W/4.5"Vam Top 12.68,Cr13 W/ESP,CAP Tube and SSSV Injection Line F/6,674'to 8,743'MD.Checking ESP every 1,000'RIH as per Baker Centrilift onsite.Monitor well,static loss 1 bph.Land and space out as per Baker Rep onsite.Perform H2S ng evacuation drill W/all rig personnel and third party.Stab in W/Seal Assy as per Baker Rep onsite.F/8,890'MD start pumping at 1.5 bpm 40 PSI,at 8,897'Press.increased to 120 PSI indicating entry into seal bore.Shut pumps off and Cont.to slack off to 8,905'MD and tag No Go.Slack off 20K over SLK weight to 126K.Held PJSM for spacing out Co Rep onsite.L/D 4 4.5"'Joints of tubing.RN VIT compensator and PN M/U 2 spacer Pups and 3 VIT joint to string.PN M/U Hanger as per Vetco Grey Rep onsite.Used a total of 206 Cannon clamps,1 I Single Clamp,1 Green Splice Clamp,415 Pins and 108 Stainless Bands.Terminate ESP,CAP Tube and SSSV Injection line for Hanger as per Baker,Vetco and Schlumberger Rep onsite.Verify termination by ENI Electrician and Co Rep onsite.SIMOPS Prep Brine for displacement. Operation at 07.00 Land 4.5"Tubing Hanger as per Vetco Grey Rep onsite. 24h Forecast Cont.to Prep Brine for displacement.Spot 9.4 ppg Inhibited Brine as per MI Swaco plan forward.Land Hanger and test seals.Test IA to 1,500 PSI for 30 Min on chart.Set BPV and N/D BOPE.NN Tree and test. Lithology Shows MAASP(kgflcm') Mud Weight(g/L) 11144 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan _ Oper.Descr. 00.00 12.00 12.00 12 00 W 0 K 4 P PJSM W/all essential personnel.P/U M/U GLM and RIH W/4.5"Vam Top 12.68,Cr13 W/ESP,CAP Tube and SSSV Injection Line F/6,674'to 8,743'MD.Checking ESP every 1,000'RIH as per Baker Centrilift onsite.Monitor well,static loss 1 bph.Land and space out as per Baker Rep onsite.Used 53 Cannon clamps,106 Pins and 99 bands.SLK 92K 12:00 13:00 1.00 13.00 W.O. K 20 P 'PJSA Perform H2S rig evacuation drill Mall rig personnel and third party. 13.00 20:00 7.00 20.00 W.O. K 4 P PJSA Stab in W/Seal Assy as per Baker Rep onsite.F/8,890'MD start pumping at 1.5 bpm 40 PSI,at 8.897'Press. increased to 120 PSI indicating entry into seal bore.Shut pumps off and Cont.to slack off to 8,905'MD and tag No Go. Slack off 20K over SLK weight to 126K.Held PJSM for spacing out Co Rep onsite.UD 4 4.5"'Joints of tubing.RN VIT compensator and PN MN 2 spacer Pups and 3 VIT joint to string.P/U MN Hanger as per Vetco Grey Rep onsite.Used a total of 206 Cannon clamps,1 I Single Clamp,1 Green Splice Clamp,415 Pins and 108 Stainless Bands. 20.00 00:00 4.00 24.00 W.O. K 5 P •PJSA Terminate ESP,CAP Tube and SSSV Injection line for Hanger as per Baker,Vetco and Schlumbereger Rep onsite. Verify termination by ENI Electrician and Co Rep onsite.SIMOPS Prep Brine for displacement. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Oliver Amend ENI Drilling Supv. 907-685-0715 Eni representative Steve Millea ENI HSE Eni representative Greg Parker ENI Malls Coordinator 907-980-7545 Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1.662.10 3.756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgf/cm') 2,795.02 2,031.81 VC-OBM 1234 2 119.5 1822.5 370.2 Eni E&P DivisionWell Name:OP23-W W02 DIR I ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq nDate:3/31/2015 - Report 26 API/UWI:50-029-23411-00-00 2" " page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type 011ktok Point ENI PETROLEUM 100-00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER 1821.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature(°C) Weather Wind 0.00 41.0 -20.0 Partly Cloudy WC- NE @30 MPH 33" Daily summary operation 24h Summary Circulate and condition brine wl corrosion inhibitor and pump 476 bbls down IA w/9.4 ppg brine @ 80 spm,750 psi.Drain and rinse stack and set tubing hanger.Test upper/lower hanger seals to 5000 psi and IA MIT test on packer to 1500 psi f/30 min.N/D BOPE and N/U tree and test packoff and tree to 5000 psi.Remove test plug. Operation at 07.00 Prep to freeze protect well. 24h Forecast Baker Centrilift and ENI electrician check ESP conductivity and integrity.Lil Red hook up and test lines and pressure up IA to 1500 psi fl 15 min.Continue to pressure up to 2100 psi and shear GLM valve and pump diesel to fill IA and up tubing.R/U Halliburton wire line equipment and Lil Red to test lubricator.Halliburton to C/O sheared GLM valve w/new valve and test to 500 psi.R/D and secure well. Operations to ready and start well pump to check for proper operations and water flow prior to releasing rig from well. Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 1126.4 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00.00 01.00 1.00 1.00 W.O. K 8 P PJSA Circulate and condition brine w/corrosion inhibitor for completion. 01:00 04:30 3.50 4.50 W.O. K 7 P PJSA Displace IA w/476 bbls of 9.4 ppg inhibited brine 80 spm,750 psi.Monitor well for 5 min.Drain and rinse stack.Set tubing hanger as per Vetco. 04:30 09:00 4.50 9.00 W.O. K 12 P 'PJSA Test upper and lower tubing hanger seals to 5000 psi f/10 min.Pressure up IA to 1500 psi for 30 min for MIT test while filling tubing w/brine.Pull landing jt.and UD in pipe shed.Install BPV. ..----------- 09:00 12:00 3.00 12.00 W.O. C 20 P PJSA N/D BOPE,pull and UD mousehole,remove Katch Kan,flow line,hole fill and shut down Koomey and bleed pressure.85 bbls Tourty fluid losses. 12:00 19:30 7.50 19.50 W.O. C 20 P PJSA Complete N/D of BOPE and set back on stump in cellar.Schlumberger and Baker inspected lines and Vetco oriented and set tree assy. 19:30 00:00 4.50 24.00 W.O. C 12 P PJSA Test packoff to 5000 psi for 10 min.Remove BPV and install test plug.Test tree to 5000 psi for 10 min.Remove test Plug. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Bruce Simonson ENI Dulling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrlhing@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Matls Coordinator Eni representative Steve Millea ENI HSE Eni representative Bernie Leas ENI Rig Clerk akrigclerksdoyon15@enipetroleum.com 907-685-0722 907-268-9054 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Gary Hoffman Nabors Toolpusher Last Casing seat Cas.Type OD(In) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1,662.10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(gIL) P LeakOff(kgflcm') 2,795.02 2,031 81 VC-OBM 1234.2 119.5 1822.5 370.2 Eni E&P DivisionWell Name:OP23 WW02 DIR PI* ENI Petroleum Co.Inc. Daily Report Well Code:23835 Field Name:Nikaitchuq eDate:41112015 - Report#: 27 APIIUWI:50-029-23411-00-00 e" page 1 of 1 Wellbore name: OP23-WW02 Well Header Permit/Concession N° Operator ENI Share(%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation(m) Ground Level(m) Water Depth(m) RKB-Base Flange(m) RKB-Tubing Spool(m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth(mKB) Target Depth(TVD...Depth Dr.(MD)(m) Drilling Hours(hr) Avg ROP(m/hr) DFS(days) OP23-WW02 WORKOVER . 1822.06 Daily Information End Depth(mKB) End Depth(TVD)(... Depth Progress(m) Drilling Hours(hr) Avg ROP(m/hr) POB Temperature("C) Weather Wind 0.00 43.0 -18.1 Overcast WC-17` NNE @ 13 MPH Daily summary operation 24h Summary Baker Centrilift and ENI electrician test ESP sym,Lil Red R/U,test lines to 2500 psi,test IA to 1500 psi,shear out GLM valve @ 2200 psi and pump 120 bbls of diesel down IA up tubing.R/U Halliburton wire line equipment and RIH and C/O GLM shear valve and Lil Red test to 500 psi.Production testing well and rig prepping for rig move.Rig released @ 2400 hrs. Operation at 07.00 Permitting for working on Well Bay roof removing and replacing hatch covers.Jacking up modules. 24h Forecast Accept rig to Well OP22-W W03 @ 0001 hrs.Complete R/D procedures and move rig to Well OP22,spot and Rig up same.Last workover report for OP23-W W02 Lithology Shows MAASP(kgflcm') Mud Weight(gIL) 11264 Time Log Start End Cum Time Time Dur(hr) Dur(hr) Phase Opr. Act. Plan Oper.Descr. 00:00 01:00 1.00 1.00 W.O. K 12 P °PJSA Baker Centrilift and ENI electrician test ESP for integrity and continuity. 01:00 02:00 1.00 2.00 W.O. K 12 P PJSA With Lil Red on freeze protection.R/U Lil Red and tubing through choke manifold to gas buster and rig pits. 02:00 05:00 3.00 5.00 W.O. K 1 P PJSA Lil Red Pressure test sym.to 2500 psi.Open IA and pressure to 1500 psi for 15 min.Pressure up and shear GLM valve @ 2200 psi.Pump 120 bbls of diesel down IA,through GLM and up tubing @ 1.5 bpm.Blow down choke and hoses. 05:00 09:30 4.50 9.50 W.O. R 20 P -PJSA with Halliburton on slick line operations/Rig up.R/U from tree to 4.5"WLV and lubricator.R/U wire line tools and wireline assy. 09:30 12:00 2.50 12.00 W.O. R 19 P -PJSA RIH#1 and set catcher.Run#2 retrieve sheared GLM valve.Run#3 install new shear valve in GLM. 12:00 15:00 3.00 15.00 W.O. R 19 P PJSA Run#4 Retrieve catcher.R/D wire line equipment. 15:00 15:30 0.50 15.50 W.O. K 25 P PJSA Service rig,grease Top-drive,blocks,draw works and ruffneck. 15:30 16:00 0.50 16.00 W.O. K 12 P 'PJSA Lil Red Pressure tested IN GLM to 500 psi for 10 min. 16:00 20:00 4.00 20.00 W.O. K 20 P PJSA While Production is testing Well OP23,rig is cleaning and organizing for rig move,cleaning pits,welding herculite and prepping pad. 20:00 00:00 4.00 24.00 W.O. A 1 P PJSA Finish cleaning pits,blow down water and steam on sub,breaking down interconnects and remove cuttings box. Release rig from well OP23 @ 2400 hrs. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Ent representative Bruce Simonson ENI Drilling Supv. 907-685-0715 Eni representative Russ Wimmer ENI Drilling Supv. SIDDrilling@enipetroleum.com 907-685-0715 907-320-0058 Eni representative Vance Dale ENI Malls Coordinator Eni representative Steve Millea ENI HSE Eni representative Mitch Billington ENI Rig Clerk AKRigClerksDoyonl5@enipetroleum.com 907-685-0722 Eni representative Ken Bogner ENI Expediter 907-980-7545 Tool Push Tony Morales Nabors Toolpusher 805-797-6720 Tool Push Ralph Langham Nabors Tour Pusher Last Casing seat Cas.Type OD(in) ID(in) Grade Top(mKB) Bottom(mKB) Run Date LINER 7 6.276 13CrL80 1.662 10 3,756.05 5/3/2010 Last Leakoff Test Depth(mKB) TVD(mKB) Fluid Type Fluid Density(gIL) P Surf Applied(kgf/cm') Eq.Mud Weight(g/L) P LeakOff(kgf/cm') 2,795.02 2,031.81 VC-06M 1234.2 119.5 1822.5 370.2 410 IR 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 ma be scanned during a special rescan activity or are viewable Y may g p Y by direct inspection of the file. 1 QO9 - Well History File Identifier Organizing (done) ❑ Two -sided III (IIII II II IIII ❑ Rescan Needed III III II II II IIII I RE AN DIGITAL DATA OVERSIZED (Scannable) Col r Items: ❑Diskettes, No. ❑Maps: reyscale Items: ❑Other, No/Type: Items Scannable by a Large Scanner LOGS ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria - Date: 1 i d" /s/ Mf Project Proofing 11111101111 BY: Maria Date: 7/I 7 /3_ /s/ mf Scanning Preparation 1 c2 x 30 = 360 + = TOTAL PAGES 3 6 7 '� (Count does not include cover sheet) ^ BY: Maria Date: /1// 7p a__ /s/ 1 Production Scanning III I F II I I I IIIU Stage 1 Page Count from Scanned File: 3 $g (Count does include co sheet) Page Count Matches Number in Scanning Preparation: C YES NO g C g BY: Maria Date: 7// i /s/ f Stage 1 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 1E11111E11i ReScanned 111411111 MI BY: Maria Date: /s/ Comments about this file: Quality Checked I 10/6/2005 Well History File Cover Page.doc _ _ 1"',_L.,—...�.;3-`.sem..:_:` a t -. :5. .,:: -:.•, ,-;,,,,,,L.:,, _.: ..,L.mow.- .:iii °� s.'.__ - tC.ter Try/, _ e'-:\\\Ig//%j � 1 Hit', STATE A C,:, ; ? �1 ` r 'Y q _ ' e% ,''6_„=Z6,/'„\ i_). 1. v'../. 33� '� c Seven�h Aver ue �,'()�'r,�l\!( (: ,a�- k i-,_,i Anc:norocje, Alosko 99>C' 357? NS.: .iv ,_: tom SCANNED MAY 1 �� 6 204 Marc Kuck Q"( Q 3g, Production Optimization Coordinator �r Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Ivishak Undefined Water Source Pool, OP23-WW02 Sundry Number: 314-305 Dear Mr. Kuck: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. cerely, .' Daniel T. Seamount, Jr. Commissioner 71- DATED this //day of May, 2014. Encl. . c5,5 - V\ RECEIVED STATE OF ALASKA MAY 0 9 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ��� 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well❑., ` Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate El. Pull Tubing❑., • Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing❑ Other: _ESP Change Out D• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Eni US Operating Co.Inc.• Exploratory ❑ Development ❑ 209-0320 3.Address: Stratigraphic ❑ Service 0 6.API Number: 3800 Centerpoint Drive,Ste.300,Anchorage,AK 99503 50-029-23411-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0. OP23-WW02 ' (WDA 501-4•.tcE w ) 9.Property Designation(Lease Number): 10.Field/Pool(s): . ff 4' 0373301,0355024,0390616• Nikaitchuq N/A .LUiS & wt�If.Jr'Eck Wait'''.scS`AA.* 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): • 12,323 • 9,550 - 12,323 • 9550 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 154 20" 154 154 Surface 4595 13.375" 4595 3771 5,210 2,480 Intermediate 9093 9.625" 9093 6615 6,890 4,790 Production Liner 3435 7" 12323 9550 7,240 5,410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11845-11915,11995-12045 9076-9145,9225-9274 4 1/2 13 Cr L80 8,888 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A 12.Attachments: Description Summary of Proposal ❑✓ • 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch I] Exploratory ❑ Stratigraphic❑ Development❑ Service ❑., • 14.Estimated Date for 12-May-14 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 5--/o-/4( WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: S„ „„--•i Source Water Well Q• GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true/and correct to the best of my knowledge. Contact Giuseppe Maugeri Email giuseppe.maugeri@enipetroleum.com Printed Name Marc Kuck Title Production Optimization Coordinator Signature r‘4"/"..._,„ Phone Contact 907-865-2e'IIPE Date 5/9/2014 -5322.-- COMMISSION 332zCOMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\`-(-3C) Plug Integrity ❑ BOP Test 12/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: * 3s � C- bp sc� 5o P ( �-s f,--- RBDMS MAY 16 2014 J Spacing Exception Required? Yes ❑ No Subsequent Form Required: /0 - Y O Li i APPROVED BY Approved by: ., 1 SIL•/l n COMMISSIONERIOTHE COMMISSION Date:s/s// L._ �('i� III���II/»]CCCryryrytit/� �r 3151/1 5R �� Submit Form and Form 10-403(Revised 1 2012) Appro i onths from the date of approval. Attachments in Duplicate RECEIVED MAY 092014 -fiti, Enil Petroleum AOGCC 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Marc Kuck Phone(907) 865-3322 Email: Marc.kuck@enipetroleum.com May 08th,2014 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Sundry Approval for OP23-WW02 Rig Workover Dear Commissioners, ENI US Operating Co. Inc.hereby applies for a Workover Sundry for well OP23-WW02 OP23-WW02 was originally completed on October 23th, 2010 with a ESP pump set at depth of ' 8,878' MD/6,475' TVD. The well has been scheduled for an intervention with Nabors 245 to change` oP and increase • ......_...---- perforation interval to improve performance. 7 The estimated date for beginning this work is May 12th,2014. Please find attached for the review of the Commission forms 10-403 and supporting documentation. If you have any questions or require further information,please contact Giuseppe Maugeri at 907-865-3338. Sincerely, Marc Kuck Production Opti 'zation Coordinator /it- v„ •-i-.--- 4 • OP23-WW02 Workover— Summary Page OP23-WW02 Rig Workover PTD#:209-032 Current Status Well OP23-WW02 is currently in production in natural flow. Scope of Work Scope of this workover is to pull the current completion,perforate a new interval and run in with a new ESP system. General Well info Reservoir Pressure/TVD: Reservoir depth is 11950'MD/9180'TVD. This well is expected to have a static max bottom hole pressure of approximately 4300 psi during the time of workover. Wellhead type/pressure rating: Vetco Gray, MB-247/5000 psi BOP configuration: Annular/pipe/blind/Flowcross/pipe TIFL/MIT-IA/MIT-OA: Intermediate csg 9 5/8"was tested 3000 psi x 30' on April, 25th 2010 prior to drill out, and 1500 psi x 15' on October 25th 2010 after running completion. Well type: Water Producer Estimated start date: May 12th 2014 Drilling rig: Nabors 245 Prod. Optimization Coordinator: Marc Kuck: Marc.Kuck@,enipetroleum.com Work: 907-865-3322 Procedure: 1. MIRU Nabors 245. 2. R/U on x-tree to pump down tubing. 3. Displace by bullheading tubing volume with 9.7#NaC1 brine. 4. Shear GLM valve and circulate out diesel. 5. Ensure well is killed. 6. Set BPV. ND tree and NU BOP and test to ..3_521si. 7. Pull tubing hanger and circulate annulus volume with 9.7 #NaC1 brine. 8. Continue POOH to SSSV and L/D same. 9. Continue POOH and lay down ESP assembly. 10. MU and RIH with cleaning BHA to bottom 7" liner. 11. Perform perforations. . Q ; �' _ _- . �- QC''t �) 12. MU new ESP assemblyand RIH to setting depth. 13. Land hanger, and test it. JA -Fo 14. Install BPV and nipple down BOP. ! Sdax 15. NU tubing adapter and tree. 30/` 16. Pull BPV, install test plug and test tree.( 5000 psi test) 17. Circulate Freeze protect through tree down IA. 18. Shut in well. 19. RDMO. Below the current schematic of the well: OP23-WWa2 /* Mi 4-':: 13Cr 12-6 ppf .am Top Production Tubing ' ll.r u 11 a ui ii Wellhead 13-318"x 4-1, '.CR Flow-wetted 5.000 psi Conductor.20"Uninsulated set at 154 ft Water Producer with RKB-32.08' Shrouded ESP Lift Vacuum Insulated Tubing Ori, AS COMPLETED I 4..%"x 6",approx. 105' 10123110 2215'MD,2178'TVD,27°Inc-TR-MAXX 5E SSSV.3.81"'X'Profile,W SS hyd.Control line _ 3024'MD,2783'TVD 50°Inc-GLM.4-IA"x1", KBG with DCK-2 Ann-to-Tubing 2.000 psi [ - 1 4-Yz"cable clamps,for ESP Power Cable.(2)3/8"Chem IN Line 7 0, ESP Power Cable 1SOLBC 5KV 90 LD 6 Gal, ‘ Dual encapsulated 3/8"SS Cheri Inj Lines II ,, __f--- 8748'MD.6390'TVD,49°Inc - 3.e 1"`41"Prole Surf.Casing8878'MD.6475'TVD,49°Inc Motor Centralizer- 13-3.+8"68# f' ESP Assy,31-562P155SXD Pump. SXUISXL 4595'MD. 3745'TVD , � Seals.582 KMX-VC 270 HP Motor ; 7-5'8"29.7# 13Cr Shroud Assembly with " i -<; Penetrator,(2)Chem Inj Line Feed-T1rus,Tieback Seal Stem .5,886'MD—TOL-Flex __ _ _ "l%. Lock Liner Hanger and ` 4 ZXP Packer Assy ,'',,e4,, �►' Intern.Casing 9-5.8"47# Perf Intervals 11845-11915'MD, 9076-9145'TVD 12 ':'OH 9087'MD. - 6,613'TVD.Lower E 11995-12045'MD,9225-9274'ND 240'9-5t8"47#13 Cr \ Approx 8°Inc Purl. Manito`h II P intake ,77 F T intake Production Liner, P discharge 7"26#13 Cr T motor 8 ' OH 12,323'MD. rioter 9,550'TVD Confidential "C` I 114 1 ,. J zasR 2 W g Plinge____I i g_ �Io 6 8aQ3 ffi i o � = °�`_' _1,;^,�- II IiiiImp W d N lullIIttI, T oU8 g. I _ ® I [PIIIII,�mII= O' ^.. Zd w `i 1%7 71 I 1 EN __e= L 1 E' �o '� ozw % 0 mQ W 1 g ukk8 tit2 $ 8 88 a %'2 '.27E.- =1 ~ § 8 Int n i}, n 41k BC z ., •,I N o -1i ■1 x ' vii �'� Y4 12 H Z O 1O3 d' V a c=a iii - IiiIffluiIi::ifI1p1II1II N w —.11 m w U ■ ■firII,A, ' o ''4111 v) .!). > ik SE Y n 0 N VetcoGray MB-247 SURFACE COMPLETION SYSTEM N /CL `3.50 i5' 37.15 1� r"----- I. 810 DoCurI. 3 /•�CPU -- „It"♦ IRIOS r -dir yr " 061f., 1 - - -Aldi ^� �� T.O.S. EL 26' 5-3/4 •X11—;` r.�' 1.062 OFFSET C/L I B.O.S- EL 25' 7-1/4' luJ TOP OF WELLHEAD 5.00" EL 25' 2-1/4' I I 111 /I) 1 CAL PFT ELECTRI o lo 3 FEED CA 21.81 Ii` i'_ 13-5/8'5000 PSI elan! VG S137 CLAMP „�1�� alike! R '• .:� '! 4-1/16• ITI '•MI. .- mel• !! 5000 PSI - __ Inc 1 11 IJE` ILII . •3.437 OFFSET 108.0 6.50" .111...1, �/�' 11 2-1 16' ��ii 5000 PSI 2-1/16• p: �_.��; xo _-------- 5000 PSI t - I:. II= 66.71 our of 1,i-1;10! - PosMoN Ill 1 13"5000 PSI 52.96" ni7cl II u1• VG 134 mOD. . -26.5. ■` ,.�,,1 _:' Oil" S r ,��� i; I'� :� 34.00" oil '.1.14 11 11 POSITION 24.2 .� I 1 ' 1. 15.25' 15.25• �1•i iI ! TOG 1 TCP OF GRADING r I 1 EL 16' 1-1/4' L1.00 PROPRIETARY none tie :=i� vetcogray- 20. OD 133# K-55 ^.a2" ` •tea•"* 13-3/8' OD 68# L-80 ENI ALASKA J.�Lvu Boa 9-5/8` OD 53.5 L-BO - ine�tot HORIZONTAL MULTI-BOWL SYSTEM 4-1/2" OD WITH 6-5/8 V1T - 20 X 13-3/8 X 9-5/B X "19049 w X 4-1/2 WITH 6-5/8 VIT E BOM, AND ESP FLAT CABLE 27 XL oe ,TM„oe ®�-15nI'...�i° H173370-1 le, •,,••,,,„2.-•,1 Do.0,*ma ox.c b,.®c%%%Iro(0.1 % I atm flit PRP 10161, NC 10 OF 10 23 JANUARY 2009 0 GE imagination a:work • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Saturday, May 10, 2014 7:36 AM To: Maugeri Giuseppe Cc: Bettis, Patricia K (DOA); Occhionero Lara; Kuck Marc Subject: Re: OP23-WW02 RWO (PTD 209-032) You have verbal approval to proceed with RWO and perfing on OP23-WW02. Regards Sent from my iPhone On May 9, 2014, at 2:15 PM, "Maugeri Giuseppe"<Giuseppe.Maugeri@enipetroleum.com>wrote: Patricia Here you go. Giuseppe From: Maugeri Giuseppe Sent: Friday, May 09, 2014 2:06 PM To: 'Schwartz, Guy L (DOA)' Cc: Occhionero Lara; Kuck Marc Subject: RE: OP23-WW02 RWO (PTD 209-032) Guy, We would like to have the approval for Monday due to change in schedule. Schedule change was in order to maintain production by limiting the number of production wells shut-in during this period. This will also increase water capacity to increase injection rate. Here the proposed perforation intervals: 1- Top 11,557' MD Base 11,600' MD 2- Top 11,617' MD Base 11,640' MD 3- Top 11,654' MD Base 11,826' MD 4- Top 11,932' MD Base 11,995' MD We will perform a test as per your indications. Thank you for your kindly cooperation, we appreciate it. Best Regards, 1 Giuseppe Maugeri Completion Engineer Eni Petroleum Office: (907) 865-3328 Cell: (907) 947-9110 Email: giuseppe.maugeri@enipetroleum.com 3800 Centerpoint Drive, Anchorage, AK, USA From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Friday, May 09, 2014 11:18 AM To: Maugeri Giuseppe Cc: Occhionero Lara; Kuck Marc Subject: RE: OP23-WWO2 RWO(PTD 209-032) Gieseppe, I looked at completion again... it appears you can test the 9 5/8" casing once the shroud is stung back into the liner top. That will suffice as a pressure test of the 9 5/8" intermediate casing. Test to 1500 psi and chart. Also , please send explanation of the short notice for the sundry. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Schwartz, Guy L(DOA) Sent: Friday, May 09, 2014 10:57 AM To: giuseppe.maugeri@enipetroleum.com Cc: Occhionero Lara; Marc.Kuck@Enipetroleum.com Subject: OP23-WW02 RWO (PTD 209-032) Giuseppe, Please provide the proposed perforation intervals for the RWO planned on OP23-WW02. There were none in the sundry application. Also,The casing has not been tested since 2010 so a separate tubing/test packer run is required before re-running the ESP back into the well. Test casing to 2000 psi and chart/30 min. Guy Schwartz 2 Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that,with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 3 DATA SUBMITTAL COMPLIANCE REPORT 7/9/2012 Permit to Drill 2090320 Well Name /No. NIKAITCHUQ OP23 -WW02 Operator ENI US OPERATING CO INC API No. 50- 029 - 23411 -00 -00 MD 12323 TVD 9549 Completion Date 10/25/2010 Completion Status WTRSP Current Status WTRSP /IC I REQUIRED INFORMATION Mud Log No Samples No Directional Survey all DATA INFORMATION Types Electric or Other Logs Run: GR / RES / NEU / DEN (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr • Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt t Report: Final Well R 0 12323 Open 5/24/2010 End of Well, Tab of Cont, Equip $ Crew, Well Data, Geo Data, Pres /Form Data, Drill Data, Daily Data ED " C Pdf 19671 Report: Final Well R 0 12323 Open 5/24/2010 End of Well, Tab of Cont, Equip $ Crew, Well Data, Geo Data, Pres /Form Data, Drill Data, Daily Data w /Mud logs in PDF graphics Log Mud Log 2 Col 160 12323 Open 5/24/2010 MD Formation Log t/ Mud Log 2 Col 160 12323 Open 5/24/2010 TVD Formation Log / Mud Log 2 Col 160 12323 Open 5/24/2010 MD LWD Combo Log ,/ Mud Log 2 Col 160 12323 Open 5/24/2010 TVD LWD Combo Log -" Mud Log 2 Col 3600 12323 Open 5/24/2010 MD LWD Combo . Log./ Mud Log 2 Col 3600 12323 Open 5/24/2010 MD Formation Log ✓ Mud Log 2 Col 160 12323 Open 5/24/2010 MD Gas Ratio Log ✓ Mud Log 2 Col 160 12323 Open 5/24/2010 TVD Gas Ratio Log / Mud Log 2 Col 160 12323 Open 5/24/2010 MD Drilling Dynamics Log Mud Log 2 Col 160 12323 Open 5/24/2010 TVD Drilling Dynamics ED VC Dls 19672 Induction /Resistivity 0 12323 Open 5/24/2010 EWR logs: DLIS files and / PDS graphics files Log i1 Induction /Resistivity 2 Col 165 12280 Open 5/24/2010 MD Vision Service Log ✓ Induction /Resistivity 2 Col 165 12280 Open 5/24/2010 TVD Vision Service ED ✓ C Las 19715 Sonic 4551 9118 Open 6/8/2010 Sonic, GR, NPHI, Pef, RHO DATA SUBMITTAL COMPLIANCE REPORT 7/9/2012 Permit to Drill 2090320 Well Name /No. NIKAITCHUQ OP23 -WW02 Operator ENI US OPERATING CO INC API No. 50- 029 - 23411 -00 -00 MD 12323 TVD 9549 Completion Date 10/25/2010 Completion Status WTRSP Current Status WTRSP UIC Y Log ` Sonic 25 Col 3764 6605 Open 6/8/2010 TVD Sonic, DT -Comp & DT -Shear Log./ Sonic 5 Col 4588 9071 Open 6/8/2010 MD Sonic, DT -Comp & DT- Shear Log --' Density 25 Col 4588 9112 Open 6/8/2010 MD Platform Express Log tV Density 25 Col 3764 6605 Open 6/8/2010 TVD Platform Express Log ✓ Formation Tester OTH Col 11277 12155 Open 6/8/2010 MD MDT ED Ce- / 20032 Analysis - Misc 0 9367 Open 8/30/2010 Check Shot III Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y`MI% Daily History Received? g N Chips Received? Y / N Formation Tops N Analysis -- Y -- / - i+- Received? Comments: 0 Compliance Reviewed By: Date: C I _ dx_t_H__v__ 0—' STATE OF ALASKA ALASKOIL AND GAS CONSERVATION COMMIS ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status:' Oil ❑ Gas ❑ Plu ❑ Abandoned 111 Suspended El lb. Well Class: 61111\ W1-fz R 3.,(.t ps C; • 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory❑ GINJ❑ WINJ❑ WDSPL WAG Other El No. of Completions: Service StratigraphicTest❑ 2. Operator Name: 5. Date Comp., Susp., or • 12. Permit to Drill Number: ENI US Operating Co Inc Aband.: 10/25/2010 209 -032 3. Address: 6. Date Spudded: 13. API Number: 3800 Centerpoint Drive Suite 300, Anchorage 99503 4/5/2010 • 50- 029 - 23411 -00 -00 ' 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 3130.1 FSL 1703.5 FEL S5 T13N R9E UM • 4/29/2010 OP23 -WW02 . Top of Productive Horizon: 8. KB (ft above MSL): 'h ,r .;l 15. Field /Pool(s): 4240' FSL, 1187' FEL, S32 T14N R9E UM Ground (ft MSL): 12 Nikaitchuq Total Depth: 9. Plug Back Depth(MD +TVD): 4344 FSL 1182 FEL 32 T14N R9EUM 12323 MD/9549 TVD 2 ✓,S!1f4K SOcc.RG 4,44f7 4b, Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 516576.84 • y- 6036483.06 • Zone- 4 • 12323 MD/9549 TVD • 355024, 373301, 390616 O TPI: x- 517059.5534 y- 6042871.893 Zone- 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: ? /•K Total Depth: x- 517064.16 y- 6042977.62 Zone- 4 2215 MD/ 2177 TVD ADL 417493 18. Directional Survey: Yes 0 No ❑ 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): 7 (Submit electronic and printed information per 20 AAC 25.050) (ft MSL) 1 r 7 7.5 r, t 'U vv 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/ RES/ NEU /DEN 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 178.89 X -65 SURFACE 154 SURFACE 154 30 Cement to Surface 13 -3/8" 68 L -80 SURFACE 4595 SURFACE 3771 16 576 bbls 10.7 #ASL, 63 bbls 12 #Crete 9 -5/8" 47 L -80 SURFACE 9093 SURFACE 6615 12.25 76 bbls 15.8# Class G 7" 26 L -80 8883 12323 6461 9549 8.5 105 bbls 15.8# Class G 23. Open to production or injection? Yes El No If Yes, list each 24. TUBING RECORD interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 11845 - 11915 MD 5 SPF, 1195 - 12045 MD 5 SPF 4.5 8896 8897 ( 8ef(c- 3) Sltreu- .e Q Es P - 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. " r16t E-Q4 V e DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 7, L,0. ifiyi , 26 PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): NA ESP Date of Test: Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: NA NA Test Period -► Flow Tubing Casing Press: Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API (corr): Press. 24 -Hour Rate -► 27. CORE DATA Conventional Core(s) Acquired? Yes ❑ No E . Sidewall Cores Acquired? Yes ❑ No El , If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. `3 rli NOV 2 9 2010 ' tasiza till 6163s Cons. C4t`i ;cs'sion) RBDMS Nov 3 0 201 Anchorage t- ik Form 10 -407 Revised 2/2007 CONTINUED ON REVERSE l l f (1►G'�l /1 . 1.- j G. • 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top surf surf needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base 1784 1775 MDT Pressure Readings and Depths previously distributed to the AOGCC along with log data. OA sand top 4300 3592 Ivishak 11556 8788 Formation at total depth: Kavik 12185 9413 30. List of Attachments: Summary of Daily ops, Directional survey, wellbore schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jason Brink @ 907 - 865 -3321 Printed Name: Maurizio Grandi Title: Well Operation Project Manager Signature: AA. CLU.(4i _ _ C. Phone: Date: ti/ 7 3 t o D INSTRUCTIONS /J/ IITIA to 2500 PSI. This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole Item la: Classification of Service wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for / njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with prod Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional in Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 2/2007 r Eni E &P Division I Well Name: OP23 -WW02 ENI Petroleum Co. Inc. Daly Report Well Code: 23835 Field Name: Nikaitchuq 41111 411 • Date: 4/5/2010 •Report #: 1 APINWI: 50 -029- 23411 -00 -00 H page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share ( %) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) 'Ground Level (ft) 'Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA 'NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date 'Target Depth (RKB)' Target Depth (TVD..l Depth Dr. (MD) (ft) Drilling Hours (hr) 'Avg ROP (ft/hr) I DFS (days) 0P23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 1.00 Daily Information End Depth (ftKB) 'End Depth (TVD) (f.. Depth Progress (ft) 'Drilling Hours (hr) 'Avg ROP (ft/hr) 'POB 'Temperature (°F) 'Weather I Wind 285.0 285.0 285.00 3.90 73.1 98.0 6.8 Cloudy with fog. 260 WSW at 2 mph Daily summary operation 24h Summary Spudded well at 2230 hours. Operation at 07.00 Making up BHA #2. 24h Forecast Make up BHA #2. Drill ahead with surface hole. • Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (Iblgal) 0.07 ` Time Log W L r✓ Start End Cum ( 414 Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. DPP 00:00 20'30 20.50 20.50 PREP M 1 P Hook up diverter line. 20:30 22:30 2.00 22.50 PREP M 1 P Test high pressure lines and pumps to 3000 PSI. 22:30 00:00 1.50 24,00 DRILL E 3 P Drill out conductor from 78' to 132', Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI DnIkng Supervisor lack.keener (genipetroleum.com 907 -670 -8623 907. 715 -6434 Eni representative Gary Goedich ENI Drilling Supervisor 907-670-8623 907- 441 -6585 Eni representative Pete Adams ENI Drilling HSE 907 -670 -8624 907- 440.0806 Eni representative Bernie Leas ENI Rig Clerk 907 -670 -8607 907- 575 -9427 Eni representative Alvin Cnswell ENI Expediter 907. 980 -7545 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CONDUCTOR 20 18.250 X -65 5.8 160.0 4/1/2010 Last Leakoff Test Depth (ftKB) 'TVD (f1KB) Fluid Type rFluid Density (lb/gal) IP Surf Applied (psi) I Eq. Mud Weight (Iblgal)'Leak Off Pressure (psi) I • 1 rilfAil Eni E &P Division (Well Name: 0P23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq eini A Date: 4/6/2010 - Report #: 2 PIIUWI: 50- 029 - 23411 -00-00 page 1 011 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° 'Operator I ENI Share (14) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) 'Water Depth (ft) RKB - Base Flange (ft) 'RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA Contractor ' Rig 245 E LAND RIG Job Information Wellbore 'Job Phase Spud Date ' Target Depth (ftKB) 'Target Depth (TVD..] Depth Dr. (MD) (ft) ' Drilling Hours (hr) 'Avg ROP (Mr) ' DFS (days) W OP23 -W02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 2.00 Daily Information End Depth (ftKB) 'End Depth (TVD) (f..' Depth Progress (ft)' Drilling Hours (hr) 'Avg ROP (ft/hr) 'POB 'Temperature ( °F) 'Weather 'Wind 2,115.0 2,087.6 377.00 7.50 50.3 98.0 38.5 323 NW at 5 mph Daily summary operation 24h Summary Directionally drilling ahead Operation at 07.00 Overboard mud line plugged, working to unplug / CCB(Y). Current depth 1205' MD 24h Forecast Drill Ahead Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) Clay and gravel 0.07 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00.00 03:00 3.00 3.00 DRILL E 3 P DRILLING- ROTARY DRILLING SPUD IN HOLE DRILLING DOWN 16 "HOLE TO 285' RAT HOLE TO MAKE UP 257' BHA #2 /l 450 GPM, 105 SPM, 300PSI, 6-12 K WOB, 30 RPM, 1200 ROTARY TORQUE. 0300 04:30 1.50 4.50 DRILL E 4 P TRIP OUT OF HOLE, POOH F /285' T /SURFACE B/D T /D. 04.30 05.00 0.50 5,00 DRILL E 1 P PRE -JOB SAFETY MEETING. PICK UP BHA #2 05 00 08'30 3.50 8.50 DRILL E 4 P TRIPPING, PICK UP BHA #2 AS PER SLB /DD 08 30 09.00 0.50 9.00 DRILL E 4 P TRIPPING, PICK UP BHA, CLEAR FLOOR, LOAD NUKE SOURCE AS PER SLB MWD. 09.00 11 30 2.50 11.50 DRILL E 4 P TRIPPING, PICK UP BHA CONT 11:30 12.00 0.50 12.00 DRILL E 4 P ROTARY DRILLING WASH DOWN FROM 213' TO 285' BTM @ 200 GPM, 120 PSI, 53 SPM, 30 RPM 12.00 22'30 10.50 22.50 DRILL E 7 P ROTARY DRILLING , DRILL FROM 319' TO 872' 22:30 23'00 0.50 23.00 DRILL E 3 P DRILLING -SLIDE DRILLING, SLIDE FROM 872' TO 900' 23:00 23:30 0.50 23.50 DRILL E 3 P DRILLING - ROTARY DRILLING, DRILL FROM 900' TO 940' 23:30 00:00 0.50 24.00 DRILL ' E 3 P DRILLING -SLIDE DRILLING SLIDE FROM 940' TO 965'. 700 GPM, 85 STKS / 1300 PSI ON, 1100 OFF / 95K UP / 90K DWN /90 ROT Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor lack.keener@enipetroleum.com 907-670-8623 907- 715 -6434 Eni representative Gary Goencch ENI Dnlling Supervisor 907 - 670 -8623 907- 441 -6585 Eni representative Pete Adams ENI Dnlling HSE 907 -670 -8624 907.440 -0806 Eni representative Alvin Criswell ENI Expediter 907 - 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907 -670 -8607 907. 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CONDUCTOR 20 18.250 X-65 5.8 160,0 4/1/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) Fluid Type 'Fluid Density (Iblgal) IP Surf Applied (psi) I Eq. Mud Weight (Iblgal) Leak Off Pressure (psi) t i i iiill 1 Eni E &P Division (Well Name: OP23 -WW02 all ENI Petroleum Co. Inc. Daily Report 1 WeII Code: 23835 Field Name: Nikahchuq • APIIUW: 50- 029 - 23411 -00 -00 Date: 4/7/2010 - Report #: 3 page 1 011 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share ( %) !Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) ' Ground Level (ft) I Water Depth (fl) I RKB - Base Flange (ft) ' RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA rig 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date ' Target Depth (ftKB) [Target Depth (TVD..4 Depth Dr. (MD) (ft) Drilling Hours (hr) [Avg ROP (ft/hr) IDFS (days) W OP23 -W02 DRILLING 4/5/2010 12,368.0 8,753.4 12,323.00 216.34 57.0 3.00 Daily Information End Depth (ftKB) ' End Depth (TVD) (f.. Depth Progress (ft)' Drilling Hours (hr) [Avg ROP (ft/hr) IPOB 'Temperature (°E) I Weather ' Wind 2,700.0 2,568.4 1,735.00 36.00 48.2 97.0 5.0 Cloudy, WC -9.4° 267° W Q 9 mph Daily summary operation 24h Summary Drilled ahead as per directional plan. Cleaned out plugged area in trouser leg from drag chain to cuttings tank. Operation at 07.00 Dnikng /Sliding ©2407' at 0400 hours 24h Forecast Drill Ahead Lithology 'Shows MAASP Pressure (psi) I Mud Weight (lb /gal) 9.20 Time Log _ Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00'00 04'00 4.00 4.00 DRILL ' E 3 P DRILLING - ROTARY CONTINUE DRILLING AND SLIDEING FROM 965' TO 1205' © 700 GPM, 1380 PSI -ON, 1180 P51- r OFF, 3-4 TORQUE -ON, 1 -2 TORQUE -OFF, 35 RPM, 15 -25K WOB, 165 SPM, 97K UP -WT, 93K DOWN -WT, 85K ROT - WT. 04:00 08:00 4.00 8.00 DRILL E 25 TP99 MISCELLANEOUS -WAmNG ON ORDERS, TROUSER LEG FROM DRAG CHAIN TO CUTTINGS TANK PLUGGED OFF WITH CLAY. OPENED UP TROUSER LEG AND CLEANED OUT PLUGGED AREA. 08 00 09'30 1.50 9.50 DRILL E 4 P TRIPPING -TRIP OUT OF HOLE, POOH 5 STANDS FROM 1205' AND RIH TO BTM 100K UP -WT, 95K DOWN -WT, NO DRAG, NO SWABBING. 09:30 12:00 2.50 12.00 DRILL E 3 P DRILLING - ROTARY DRILLING CONTINUE DRILLING /SLIDING FROM 1205' TO 1453' © 700 GPM, 1540 PSI -ON, 1230 PSI -OFF, 3-4K TO-ON, 1 -2K TO -OFF, 35 RPM, 25 -35K WOB, 100K UP -WT, 98K DWN -WT, 98K ROT -WT, 163 SPM. 12:00 16.30 4.50 16.50 DRILL E 3 P DRILLING -SLIDE DRILLING FROM 1453' TO 1738' / 30 -35K ON BIT / 1200 PSI -OFF / 1500 PSI -ON / 700 GPM / 85 / 85 STKS / ROP 60 - 120 / ROT AS NEEDED 112K UP -WT / 105K DWN -WT / 105 ROT / ROT TQ 1 -2K OFF -BTM / 3 -5K ON- BTM. 16:30 17:00 0.50 17.00 DRILL E 25 P SERVICE -RIG SERVICE TOP DRIVE SERVICE TOP DRIVE. 17.00 00'00 7.00 24.00 DRILL E 3 P DRILLING -SLIDE DRILLING, DRILL FROM 1738' TO 2115' © 112K UP, 105K DOWN, 105 ROT, 150 STKS, 650 GPM, 1300 PSI -ON, 1200 PSI -OFF, 3-5K ON, 2K OFF, 35 RPM, ROT DRILL AS NEEDED TO GET THROUGH HARD SPOTS. Daily Contacts . Position Contact Name Company Title E-mail Office Mobile En: representative Jack Keener ENI DnIling Supervisor jack.keener@enipetroleum.com 907 -670 -8623 907- 715 -6434 ', Eni representative Gary Goedich ENI Drilling Supervisor 907- 670 -8623 907 -441- 6585 Eni representative Pete Adams ENI DnIling HSE 907- 670 -8624 907- 440 -0806 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907-670-8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CONDUCTOR 20 18.250 X-65 5.8 160.0 4/1/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) 'Fluid Type 'Fluid Density (Iblgal) IP Surf Applied (psi) I Eq. Mud Weight (lb/gal) [Leak Off Pressure (psi) Vii* Eni E &P Division 'Well Name: 0P23 -WW62 ill 4111 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • APIIUWI: 50- 029 - 23411 -00 -00 e ���� ���� �, o Date: 4/8/2010 • Report #: 4 page 1 of 1 Welibore name: OP23 -WW02 Well Header Permit/Concession N° Operator I ENI Share ( %) I Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) I Ground Level (ft) 'Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Welibore I Job Phase Spud Date 'Target Depth (ftKB) 'Target Depth (TVD..lDepth Dr. (MD) (ft) Drilling Hours (hr) I Avg ROP (ft hr) I DFS (days) OP23 -WWO2 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 4.00 Daily Information End Depth (RKB) I End Depth (TVD) (f.. Depth Progress (ft) I Drilling Hours (hr) 'Avg ROP (ft/hr) I POB I Temperature ( °F) 'Weather 'Wind 3,078.0 2,817.6 963.00 24.00 40.1 100.0 -4.7 Cloudy, WC -21.6 223° SW @ lomph Daily summary operation 24h Summary Drilled ahead as per directional plan from 2115' to 3078' Operation at 07.00 Dulling /Sliding @ 3240' at 0320 hours r/ 24h Forecast Drill Ahead Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (Iblgal) 9.30 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Aot. Plan Oper. Decor. 00'00 12 00 12.00 12.00 DRILL E 3 P DRILLING - ROTARY DRILLING CONTINUE DRILLING /SLIDING AHEAD FROM 2115' TO 2700', (2568.16 TVD) 745GPM, 1745PSI -ON, 1550PSI -OFF, 175SPM, 4- 6T0 -ON, 1 -2TQ -OFF, 35RPM, 10- 30W0B, 120K UP -WT, 98K DOWN -WT, 105K ROT -WT, WIPEING 90' BEFORE CONNECTION AST -4.38, ART 2.78, ADT 7.16, JAR TOTAL 31.4, BIT 31.4. 12'00 18:00 6.00 18.00 DRILL E 3 P DRILLING -SLIDE DRILLING DRILL FROM 2700' TO 2875', 180 STKS / 750 GPM / PUMPS ON 1800 / PUMPS OFF 1700 / 2K FREE TRQ / 5 -7K TRQ / 20 -30K ON BIT / 130K UP 105K DOWN 110 ROT / 35 RPM 18.00 1810 0.50 18.50 DRILL E 25 P SERVICE -RIG SERVICE TOP DRIVE 18 30 00'00 5.50 24.00 DRILL E 3 P DRILLING - ROTARY DRILLING DRILL FROM 2875' TO 3078', 180 SPM / 750 GPM / 1820 PSI ON 1520 PSI OFF / 4 -51< TRQ / 2 -3K FREE TRQ / 132K UP / 110K DOWN / 1121< ROT / 35 RPM, AST 4.19, ART 3.64, ADT 7.83, JARS TOT /BIT 39.2 I Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Dnfing Supervisor jack.keener@enipetroleum.com 907 -670 -8623 907- 715 -6434 Eni representative Gary Goerlich ENI Drilling Supervisor 907 -670 -8623 907 -441 -6585 Eni representative Pete Adams ENI Dulling HSE 907- 670-8624 907- 440 -0806 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvtg ENI Rig Clerk 907 - 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (kKB) Bottom (ftKB) Run Date CONDUCTOR 20 18.250 X -65 5,8 1600 4/1/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) 'Fluid Type 'Fluid Density (Iblgal) IP Surf Applied (psi) Eq. Mud Weight (Iblgal) Leak Off Pressure (psi) • IrlAllikl Eni E &P Division I Well Name: 0P23 -W W02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • in 1 Date: 4/9/2010 - Report #: 5 APIIUWI: 50- 029 -23411 -00-00 page 1 of i Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I ENI PETROLEUM I ENI Share (%) 100.001 D el Co figur lion type ()Wok Point Rotary Table Elevation (ft) Ground Level (ft) Water Depth (ft) I RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.201 12.20 31.501 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore 'Job Phase Spud Date 'Target Depth (ftKB) !Target Depth (TVD..lDepth Dr. (MD) (ft) 'Drilling Hours (hr) 1Avg ROP (ft/hr) 1DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 5.00 Daily Information End Depth (ftKB) 'End Depth (TVD) (f.. Depth Progress (ft)' Drilling Hours (hr) !Avg ROP (ft/hr) 1 POB !Temperature (°F) ' 7° Weather 1 Wind 3,666 0 3,191 6 588.00 12.00 49 0 95.0 -17.01P/C, WC -29. 155° SSE @ 5 mph Daily summary operation 24h Summary Drilled ahead 1/3078' 53666' MD, POOH for BHA change Operation at 07.00 M/U BHA 24h Forecast Change BHA, RIH, Drill Ahead Lithology 'Shows MAASP Pressure (psi) I Mud Weight (lb/gal) 9.30 / Time Log r Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 DRILL E 3 P DRILLING - ROTARY DRILLING CONTINUE DRILLING /SLIDING AHEAD FROM 3078' TO 3653' (352 775 GPM, 183 SPM, 5- 6K TQ -ON, 3-4K TO -OFF, 202 PSI ON, 192 P51 OFF, 127K UP -WT, 110K DWN WT, 120 -ROT WT, 35-45 RPM. AST 2.39 HRS, ART 6.48 HRS, ADT 8.87 HRS, AVERAGE SLIDEING 25 -60' PER STAND, REAMING 90' UP /DOWN BEFORE CONNECTIONS. 12'00 13:30 1.50 13.50 DRILL E 3 P DRILLING- ROTARY DRILLING, DRILL FROM 3653' TO 3666' (g35 RPM, 15 -30K ON BIT, 184 STKS, 775 GPM, 2000 OFF, 2150 ON, FREE TRQ 3K, ON TRQ 6-10K, UP WEIGHT 140K, DOWN 155K, ROT 120K. 13'30 14.30 1.00 14.50 DRILL E 3 P DRILLING - ROTARY DRILLING, PUMP 20 BBLS NUT PLUG SWEEP TO CLEAN BIT, CIRCULATE SWEEP AROUND 8000 STKS, 775 GPM, 184 STKS, 2000 PSI PUMP PRESSURE. GAINED MORE TORQUE ON BIT, 8-10K, COULD NOT MAKE HOLE. 14.30 20:30 6.00 20.50 DRILL E 4 P TRIPPING -TRIP OUT OF HOLE POOH WITH DP 140K UP, 120K DOWN, PUMP OUT WHEN NEEDED, 300 GPM, 80 STKS, 500 PSI, DEPTHS PUMPED ON 3600, 3500, 3450, 3350, 3260, 3500, 3450, 2850, 2200, 2050, NO HOLE DRAG WHEN PUMPING. 20:30 22 00 1.50 22.00 DRILL E 4 ' P TRIPPING -TRIP OUT OF HOLE, MONITOR WELL, NO FLOW, STD BACK 4 STDS HWDP, 2 JTS HWDP WITH JARS. 22:00 00:00 2.00 24.00 DRILL E 4 P TRIPPING -LAY DOWN BHA, SAFETY MEETING WITH SLB, BREAK OUT BHA Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener5empetroleum.com 907- 670 -8623 907-715-6434 Eni representative Gary Goedich ENI Dnllmg Supervisor 907- 670 -8623 907 - 441 -6585 . Eni representative Pete Adams ENI Dulling HSE 907-670-8624 907- 440 -0806 Eni representative Greg Parker ENI Expediter 907- 980 -7545 En: representative Tom Norvig ENI Rig Clerk 907 -670 -8607 907- 229 -6100 Eni representative Dave Morris ENI Dnlling Supervisor 907 -670 -8623 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CONDUCTOR 20 18.250 X -65 5.8 160.0 4/1/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) I Fluid Type I Fluid Density (lb/gal) IP Surf Applied (psi) I Eq. Mud Weight (lb /gal) 'Leak Off Pressure (psi) • fr* Eni E &P Division I Well Name: 0P23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikadchuq • Date: 4/10/2010 - Report #: 6 APIIUWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share ( %) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) !Ground Level (ft) 'Water Depth (ft) I RKB - Base Flange (ft) 'RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA Contractor ' Rig 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date 'Target Depth (ftKB) 'Target Depth (TVD..I Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ftlhr) I DFS (days) OP23 -WWD2 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 6.00 Daily Information End Depth (RKB) 'End Depth (TVD) (f..I Depth Progress (ft) 'Drilling Hours (hr) !Avg ROP (ftlhr) ' P08 Temperature (°F) Weather 'Nod 3,684.0 3,202.81 18.00 0.50 36.0 92.0 -17.0 P /C, WC -29.7° 155° SSE @ 5 mph Daily summary operation 24h Summary Change out BHA, RIH, CBU, drill ahead Operation at 07.00 Drctnl dnll towards casing point. 24h Forecast Drill ahead to casing point Lithology 'Shows MAASP Pressure (psi) I Mud Weight (lb/gal) 9.60 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 1. 00.00 05.30 5.50 5.50 DRILL E 4 P Cont handle BHA 92. remove nuke source, break / grade bra. Lay do mud motor, PU new motor. 05:30 0730 2.00 7.50 DRILL E 25 P Service ng. 07:30 1600 8.50 16.00 DRILL E 4 P PJSM, MU BHA #3. PU mud motor, MU new MX1 16" bit. torque all connections. Flow check, RIH same to 1000 ft. MU top drive, attempt fill pipe /break circ. Flow line plugged. 16'00 17:30 1,50 17.50 DRILL E 25 TS99 Clean / flush out plugged flowline clays. 1730 1800 0.50 18.00 DRILL E 7 P Ciro / cond fluids in prep for RIH. 18.00 23.30 5.50 23.50 DRILL E 4 P Resume RIH to 3550 ft. CBU in 1000 ft intervals. Note heavy clays to surface. NO loss / gains. Wash ream 3550 to 3660 ft. Take slight wt. No torque noted. 23.30 00:00 0.50 24.00 DRILL E 3 P Commence drill ahead dretnl 16" hole 3666 - 3684 ft. RPM 60, Up 140, Dn 120, Rot 120, GPM 760, SPM 180 SPP 2000, Off 2000, On 2400, WOB 25 -30 Daily Contacts Position Contact Name Company Title E•mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keeneriempetroleum.com 907 -670 -8623 907 - 715.6434 Eni representative Gary Goedich ENI Dulling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Pete Adams ENI Drilling HSE 907 -670 -8624 907 - 440 -0806 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Non/1g ENI Rig Clerk 907- 670 -8607 907 - 229 -6100 Eni representative Dave Moms ENI Drilling Supervisor 907- 670 -8623 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CONDUCTOR 20 18.250 X -65 5.8 160.0 4/1/2010 Last Leakoff Test Depth (ftKB) ITVD (ftKB) Fluid Type 'Fluid Density (1b/gall I P Surf Applied (psi) I Eq. Mud Weight (lb/gal) I Leak Off Pressure (psi) • • Viii* Eni E &P Division 'Well Name: OP23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • e I) II A Date: 4/11 /2010 - Report #: 7 APIIUWI: 50- 029 - 23411 -00-00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Pennit/Concession N° I Operator 'ENI Share ( %) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) 53.20 I Ground Level (ft) 12.20 I Water Depth (ft) I RKB - Base Flange (ft) 31.50 ' RKB - Tubing Spool (ft) 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA I NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date 'Target Depth (ftKB) 'Target Depth (TVD..] Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) ' DFS (days) 0P23 -WW02 DRILLING 4/5/2010 12,369.01 9,753.4 12,323.00 216.34 57.0 7.00 Daily Information End Depth (RKB) End Depth (TVD) (0..'Depth Progress (ft) 'Drilling Hours (hr) 'Avg ROP (ftlhr) I POB Temperature ( °F) 'Weather ' Wind 4,440.0 3,677.9 774.00 15.78 49.0 94.0 5.2 Cloudy, WC -21.6° 323 NW at 5 mph Daily summary operation 24h Summary Drctnl dnll towards TD casing point Operation at 07.00 Prepare run 13 3/8 csg 24h Forecast TD casing depth, wiper trip, cond fluids, POH for casing run Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (Iblgal) 9,30 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00 00 02 30 2.50 2.50 DRILL E 3 P Drill ahead 16" hole drctnl 3684 - 3850 ft. Encounter difficult formation. Sporadic ROP. Connections free, normal drag. No gain / loss. Cuttings retums nommal quantity / quality. WOB 25. 30, RPM 25, SPM 180, GPM 750, SPP 2060, Up 142, Dn 110, Rot 130, Tq 7 -8 K 02 30 09.30 7,00 9.50 DRILL E 3 P Drill ahead 16" hole drctnl 3850. 3884 ft. Continued difficult formation. Sporadic ROP. Connections free, normal drag. No gain / loss. Cuttings retums normal quantity / quality. WOB 25 - 30, RPM 25, SPM 180, GPM 750, SPP 2050, Up 142, Dn 110, Rot 130, Tq 7 -8 K 09'30 12:00 2.50 12,00 DRILL E 3 P Drill ahead 16" hole drctnl 3884 - 4059 ft. Continued difficult formation. Sporadic ROP, Connections free, normal drag. No gain / loss, Cuttings retums normal quantity / quality. WOB 25 - 30, RPM 25, SPM 180, GPM 750, SPP 2120, Up 152, Dn 110, Rot 130, Tq 7 -8 K AST = 1.04 hrs, ADT = 7.75, ART = 6.71 hrs 12:00 00:00 12.00 24.00 DRILL E 3 P Drill ahead 16" hole drctnl 4059 - 4440 ft. Continued difficult formation. Sporadic ROP. Connections free, normal drag. No gain / loss. Cuttings retums normal quantity / quality. WOB 25 - 30, RPM 25, SPM 180, GPM 750, SPP 2120, Up 152, Dn 110, Rot 130, Tq 7 -8 K AST = .76 hrs, ADT = 7.53 hrs, ART = 6.77 hrs Gas = 150.690 units. Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Jack Keener ENI . Drilling Supervisor 1ack.keeneraenipetroleum.com 907 -670 -8623 907 - 715 -6434 Eni representative Dave Moms ENI Dnlling Supervisor 907 -670 -8623 Eni representative Jack Potter ENI Dnting HSE 907 -670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907-670-8607 907- 229 -6100 Last Casing seat Cas. Type ( OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CONDUCTOR I 20 18.250 X -65 5,8 160.0 4/1/2010 Last Leakoff Test Depth (RKB) I TVD (ftKB) 'Fluid Type 'Fluid Density (lb/gal) I P Surf Applied (psi) I Eq. Mud Weight (lb/gal) I Leak Off Pressure (psi) • • Eni E &P Division I Well Name: OP23 -W W02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • APIIUWI: 50- 029 - 23411 -00 -00 I, M Date: 4/12/2010 - Report #: 8 page 1 of 1 Welibore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share ( %) I Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) 'Ground Level (ft) I Water Depth (ft) I RKB - Base Flange (ft) f RKB - Tubing Spool (ft) 53.20 12 20 31.501 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA Contractor ! Rig 245 E LAND RIG Job Information Welibore Job Phase 'Spud Date 'Target Depth (ftKB) "Target Depth (TVD...1Depth Dr. (MD) (ft) !Drilling Hours (hr) !Avg ROP (ftlhr) I DFS (days) 0P23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.41 12,323.00 216.34 57.0 8.00 Daily Information End Depth (ftKB) End Depth (TVD) (f..' Depth Progress (ft) 'Drilling Hours (hr) 'Avg ROP (ftlhr) 1P06 'Temperature (°F) Weather 'Wind 4,607.0 3,778.6 167.00 4.00 41.8 92.0 5.0 Cloudy, WC -9.4° 267° W @ 9 mph Daily summary operation 24h Summary TD csg point, arc cond fluids, wiper tnp, circ cond fluids, POH / LAy dn BHA Operation at 07.00 RIH 13 -3/8 csg 24h Forecast Lay dn BHA, RU / run 13 -3/8 csg Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) 9.50 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00 00 0400 4.00 4.00 DRILL E 3 P Drill ahead 16" hole drctnl 4440 - 4607 ft (csg pt as per ENI Geo) I ( ) Continued difficult formation. Sporadic ROP. Connections free, normal drag. No gain / loss. sur Cuttings returns normal quantity / quality. WOB 20 - 30, RPM 60, SPM 180, GPM 750, SPP 2150, Up 155, Dn 110, Rot 130, Tq 7 -8 K AST = .94 hrs, ART = 2.04 hrs ADT = 2.98 hrs Gas = 75 - 290 units. 04 00 06.30 2.50 6.50 DRILL E 7 P Circ / cond fluids. Pump sweep / nut plug as fluid caliper. Calculated 11% washout. Circ addtnl BU. Shaker dean. 06:30 07:30 1.00 7.50 DRILL E 6 P Flow check, POH wiper tnp to 3107 ft. Normal drag, no swab. No gain / losses. No backreaming necessary. 07:30 08:30 1.00 8.50 DRILL E 6 P Flow check, RIH wiper tnp 15 stds. No fill. No dn drag. Precaution wash 30 ft to btm. 08:30 12:30 4.00 12.50 DRILL E 7 P Circ / cond fluids. Pump sweep / nut plug as fluid caliper. Calculated 13% washout. Circ addtnl BU X2. Shaker clean. 790 gpm, 2050 psi. 12:30 17:30 5.00 17.50 DRILL E - 4 P PJSm, flow check, POH to BHA. Normal drag. No swab. 17'30 18:30 1.00 18.50 DRILL E - 4 P PJSM all personnel conceming removal nuke source at BHA. Flow check. 18:30 21:30 3.00 21.50 DRILL E 4 P Handle BHA 93, lay dn all components. Remove nuke source. 21:30 22:00 0.50 22.00 DRILL E 25 P Service rig. 22:00 00:00 2.00 24.00 DRILL E 4 P Continue LD BHA#3 Daily Contacts Position Contact Name Company Title E Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener@enipetroleum.com 907- 670 -8623 907 - 715 -6434 Eni representative Dave Moms ENI Dnlling Supervisor 907 - 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907 -670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907 -670 -8607 907 - 228 -6100 Last Casing seat Cas. Type I OD (in) ID (in) 1 Grade Top (ftKB) Bottom (ftKB) Rum Date CONDUCTOR 20 18.250 X -65 5.8 160.0 4/1/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) Fluid Type 'Fluid Density (lb/gal) I P Surf Applied (psi) I Eq. Mud Weight (Iblgal) 'Leak Off Pressure (psi) . • Iri ill* Eni E&P Division a, 'Well Name: OP23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • APIIUWI: 50- 029 - 23411 -00 -00 Date: 4/13/2010 - Report #: 9 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share ( %) ' Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) !Ground Level (ft) I Water Depth (ft) RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12,20 31.50 33 25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E Name ! Rig RIG Job Information Wellbore ' Job Phase Spud Date 'Target Depth (ftKB) 'Target Depth (TVD..' Depth Dr. (MD) (ft) 'Drilling Hours (hr) ! Maw) ROP r) IDFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.01 9,753.4 12,323.00 216.34 57.0 9.00 Daily Information End Depth (ftKB) End Depth (TVD) (f.. Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB Temperature (°F) Weather Wind 4,607.0 3,778.6 0.00 93.0 17,1 P /C, WC +4.1° 191° SSW a 12 _mph Daily summary operation 24h Summary Rig up / run 13/38 csg Operation at 07.00 Batch mix cement 24h Forecast Run / Cmt 13 -3/8 csg Lithology 'Shows MAASP Pressure (psi) I Mud Weight (lb/gal) 9.30 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00 00 01:30 1.50 1.50 DRILL E 4 P Complete lay dn BHA #3. Lay dn MWD, ARC, mud motor, break and grade 16" bit. 01 30 02'30 1.00 2.50 DRILL G 1 P Drain BOP stack, clear floor for 13 -3/8 csg run. 02.30 06:30 4.00 6.50 DRILL G 1 P PJSM, Rig up GBR casing equip on rig floor. Perform dummy run with 13-3/8 csg hgr. Mark landing It as to installed position. Rig up Franks fill up tool, continue ng up GBR and csg tongs. 06 30 0730 1.00 7.50 DRILL G 1 P PJSM all personnel, (subject matter run 13 -3/8 csg.) 07'30 12.00 4.50 12.00 DRILL G 4 P Commence RIH 13 -3/8 68# L80 BTC csg. MU Shoe track guide shoe 2 jts 13 -3/8, float collar. Test floats. RIH csg to 1625 ft filling all jts. Record up / dn WI at 10 jt intervals. 12:00 12:30 0.50 12.50 DRILL G 7 P CBU at 20001 310 gpm / 400 psi. 12:30 14:00 1,50 14.00 DRILL G 4 P Resume RIH 13.3/8 csg. to 3000 ft. 14:00 15'00 1.00 15.00 DRILL G 7 P CBU at 3000 ft. 321 gpm / 430 psi. 15:00 18.00 3.00 18.00 DRILL G 4 P Resume RIH 13-3/8 csg. to 400011. 18:00 19:00 1.00 19.00 DRILL G 7 P CBU at 4000 ft. 321 gpm / 520 psi. 19:00 22:00 3.00 22.00 DRILL G 4 P Resume RIH 13 -3/8 csg. to 4500 ft. 22:00 00.00 2.00 24.00 DRILL G 4 P MU landing jt, work through tight spot at 4555 ft. Collars / tools hanging up on wellhead taper. Sticking downhole. Continue work through all possible wt on casing. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Dnlling Supervisor jack.keenentflenipetroleum.com 907 -670 -8623 907-715-6434 Eni representative Dave Morns ENI Drilling Supervisor 907 -670 -8623 Eni representative Jack Potter ENI Dnlling HSE 907 -670 -8624 Eni representative Greg Parker ENI Expediter 907-980-7545 Eni representative Torn Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CONDUCTOR 20 18.250 X -65 5.8 160.0 4/1/2010 Last Leakoff Test Depth (ftKB) / TVD (ftKB) Fluid Type 'Fluid Density (Ib /gal) 1P Surf Applied (psi) Eq. Mud Weight (1b/gal) I Leak Off Pressure (psi) 1 • frill* Eni E &P Division 'Well Name: 0P23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq a Date: 4/14/2010 - Report #: 10 APIIUWI: 50-029-23411-00-00 pag 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) I Well Configuration type Oliktok Point N° ' Operator PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) 'Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase 'Spud Date 'Target Depth (ftKB) 'Target Depth (TVD..'Depth Dr. (MD) (ft) I Drilling Hours (hr) 'Avg ROP (ftlhr) I DFS (days) 0P23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.41 12,323.00 216.34 57.0 10.00 Daily Information End Depth (ftKB) End Depth (TVD) (f..' Depth Progress (ft) !Drilling Hours (hr) 'Avg ROP (ft/hr) I POB 'Temperature ( °F) 'Weather 'Wind 4,607.0 3,778.6 0.00 94.0 9.3 Cloudy, WC -6° 224° SW @ 12 mph Daily summary operation 24h Summary Run / cmt 13-3/8 csg, nipple dn diverter system Operation at 07.00 Nipple up BOPE 24h Forecast Nipple dn diverter, nipple up BOpe Lithology 'Shows MAASP Pressure (psi) I Mud Weight (lb/gal) 9.60 Time Log Start End Curt Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00.00 0030 0.50 0 50 DRILL G 4 P MU csg hgr assy, work tight hole / 811 to land hgr in Vetco landing rang. Run casing space out with Tarn Collar @ 500' leaving 10' rat hole. Pick up split landing collar which allows running DP in rotary slips to shift tool Circulate landing joint down 15 feet thru a tight spot, the riser couplings were hanging on the near. Worked pipe down to within 4' of landing. Casing faded to break over coming up, pulled 430K, worked pipe down to the shoulder. Rigged down the Franks 811 up tool and installed the cement head. Circulate and condition the mud to the planned Yield point end viscosity. Verify hanger in place. Final depths 13-3/8 shoe 4595.1 ft, float collar 4512.8 ft. Total 109 its 13 -3/8 casg. 00:30 ' 06:00 5.50 ' 6.00 DRILL H 8 P Commence ore / cond fluids for cmt 13-3/8 csg. Lay dn remainder GBR casing tools. Pick up up cmt head, load plugs, MU on top It. Continue circ / cond drlg fluids. 10 bpm / 730 psi. , 06:00 07:00 1.00 7,00 DRILL 1-1 8 P PJSM all personnel ( topic cmt casing), while circulate. _ 07:00 13.30 6.50 13.50 DRILL H 9 P Commence cmt 13 -3/8 casing as follows. Held a PJSM with all people involved with the cement job. Batch mix and pump 1031 sacks of 10.7 ppg B809 Arctic Lite '50* r lead cement followed by 315 sacks of 12 ppg D962 CMCRETE. 110 bbl Mud Push II D970. Displaced with 676 bbls of 9.5 mud, bumped plug on planned strokes, hold 1500 psi on the floats for 5 mins. FCP =1000 psi. CIP @ 13.30 hrs. Wash cement out stack and shaker room. Final cement retums = 385. V 13.30 14 30 1.00 14.50 DRILL '1 9 P Break out cmt head, lay dn same, blow down cmt lines, lay out to pipe shed. 14:30 00 00 9.50 24.00 DRILL C 5 P PJSM, nipple down diverter system. RU platform, clean cellar area, clear rig floor, break out 16" diverter line / knife valve. Remove flow nipple / flow line. Begin remove bolts from annular. Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Jack Keener ENI Dnlling Supervisor jack.keener @empetroleum.com 907 - 670 -8623 907- 715 -6434 Eni representative Dave Moms ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907 -670 -8624 Eni representative Greg Parker ENI Expediter 907 - 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907 -670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (RKB) Run Date CASING 13 3/8 12,415 L80 -5.3 4,595.1 4/14/2010 Last Leakoff Test Depth (ftKB) ITVD (ftKB) 'Fluid Type 'Fluid Density (lb/gal) 'P Surf Applied (psi) Eq. Mud Weight (lb/gal) 'Leak Off Pressure (psi) 0 VI 11* Eni E&P Division 'Well Name: OP23 -W W02 ENI Petroleum Co. Inc. Daily Repo .. 1. Well Code: 23835 Field Name: Nikaitchuq • Date: 4/1512010 - Report #: 11 APIIUWt: 50- 029 - 23411 -00-00 page 1 of 1 Wellbore name: 0P23 -WW02 Well Header Permit/Concession N° Operator I ENI Share ( %) 'Well Configuration type Oliktok Point IENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) I Ground Level (ft) 'Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA I NABORS 245 E 1LAND RIG Job Information Wellbore Job Phase I Spud Date 'Target Depth (ftKB) 'Target Depth (TVD...I Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ftlhr) I DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 11.00 Daily Information End Depth (ftKB) I End Depth (TVD) (f.. Depth Progress (ft) 'Drilling Hours (hr) 'Avg ROP (ftlhr) I POB Temperature ( °F) 'Weather 'Wind 4,607.0 3,778.6 0.00 94.0 5.0 Cloudy, WC -9.4° 267° W @ 9 mph Daily summary operation 24h Summary Nipple dn diverter system, nipple up BOPE Operation at 07.00 Prep for BOP test 24h Forecast Nipple up BOPE, lest BOPE / Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (Iblgal) 9.60 ✓ Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00:00 11'00 11.00 11.00 DRILL C . 5 P PJSM, continue niplle dn drverter system, remove and lay out all components. 11 00.00 13.00 24.00 DRILL C 5 P PJSM, commence nipple up BOPE, choke manifold, choke controls, accumulator system, kiU line, flow line, fill up line, drip pan, all associated plumbing / wiring. Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener@enipetroleum.com 907 - 670 -8623 907 -715 -6434 Eni representative Dave Moms ENI Drilling Supervisor 907 -670 -8623 Eni representative Jack Potter ENI Drilling HSE 907 - 670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907-229-6100 Last Casing seat Cas. Type - OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 13 3/8 12.415 L80 -5.3 4,595.1 4/14/2010 Last Leakoff Test Depth (ftKB) (TVD (ftKB) Fluid Type (Fluid Density (Ibigal) IP Surf Applied (psi) I Eq. Mud Weight (lb/gal) I Leak Oft Pressure (psi) 410 0 Vi* Eni E &P Division I Well Name: O ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • Date: 4/16/2010 - Report #: 12 APIIUWI: 50-029 -23411 -00-00 page 1 of 1 Welibore name: 0P23 -WWO2 Well Header Permit/Concession N° I Operator I ENI Share ( %) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) I Ground Level (ft) 'Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA I NAB 245 E LAND RIG Job Information Welibore I Job Phase ' Spud Date I Target Depth (ftKB) I Target Depth (TVD.. .I Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.41 12,323,00 216.34 57.0 12.00 Daily Information End Depth (ftKB) I End Depth (TVD) (f.. Depth Progress (ft) 'Drilling Hours (hr) 'Avg ROP (ft/hr) I POB Temperature (°F) Weather 'Nod 4,607.0 3,778.6 0.00 93.0 0.9 Clear, WC -11.4° 65° ESE Daily summary operation 24h Summary Nipple up BOPE, test BOPE, MU BHA #4, RIH BHA #4 Operation at 07.00 RIH BHA #4 for drill out 13 -3/8 24h Forecast RIH BHA #4 for drill out 13 -3/8, LOT, drill ahead 12-1/4 hole. Lithology I Shows I MAASP Pressure (psi) 'Mud Weight (lb/gal) 9.00 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00'00 04:00 4.00 4.00 DRILL C 5 P NIPPLE UP BOPE Continue nipple up 13 -5/8 BOPE, all related components. 04:00 15 30 11.50 15.50 DRILL C 12 P TEST ROPE PJSM, commence BOPE. Body test all flanges preventers / choke manifold / standpipe. ,r ,/' Test all components 250 psi low/ 5000 psi high 5 minute durations. ^ (r Test Annular preventer 250 low / 3500 psi high. 5 min duration. rJIJ Test all floor valves, choke manifold, alb connecting plumbing fi 250 low / 5000 high. ✓ 1 " (' f ' Perform volume / time / press test on accumulator. Manual choke with slight bleed off. State to allow 24 hrs for repair and re -test. Will not delay drill out. Pull test plug, Install wear ring, ng down test equip. Mr Chuck Scheve AOGCC witness test. 15 30 17 30 2.00 17.50 DRILL E 20 P PU BHA PJSM, load pipe shed with all BHA and drctnl equipment. 17'30 00:00 6.50 24.00 DRILL E 4 P PU BHA, Commence MU BHA #4 Daily Contacts Position Contact Name Company Tide Email Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907 -670 -8623 907- 715 -6434 Eni representative Dave Moms ENI Drilling Supervisor 907 -670 -8623 Eni representative Jack Potter ENI Drilling HSE 907 -670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907 - 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (RKB) Bottom (RKB) Run Date CASING 13 3/8 12.415 L80 -5.3 4,595.1 4/14/2010 Last Leakoff Test Depth (ftKB) ITVD (f KB) Fluid Type 'Fluid Density (1b/gall IP Surf Applied (psi) IEq. Mud Weight (lb/gal) ILeak Off Pressure (psi) • . Viii(41 Eni E &P Division 'Well Name: OP23 -W WO2 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikadchuq • Date: 4/17/2010 - Report #: 13 APIIUWI: 50 -029- 23411 -00-00 page 1 of 1 Welibore name' OP23 -WW02 Well Header Permit/Concession N° I Operator [ENI Share ( %) !Well Configuration type Oliktok Point ENI PETROLEUM 100 00 DIRECTIONAL Rotary Table Elevation (ft) 'Ground Level (ft) [Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor I Rig Name I Rig Type NABORS ALASKA 'NABORS 245 E LAND RIG Job Information Welibore Job Phase I Spud Date ITarget Depth (ftKB) [Target Depth (TVD.. {Depth Dr. (MD) (ft) Drilling Hours (hr) IAvg ROP (ft hr) IDFS (days) 0P23 -WW02 DRILLING 4/5/2010 12,369 01 9,753.41 12,323.00 216.34 57.0 13.00 Daily Information End Depth (RKB) I End Depth (TVD) (f.. Depth Progress (ft) I Drilling Hours (hr) IAvg ROP (ft/hr) I POB I Temperature (°F) I Weather I Wind 4,635.0 3,795.3 28.00 0.50 56.0 90.0 6.4 Clear, WC -9° 62° ENE @ 12 mph Daily summary operation 24h Summary RIH BHA #4, drill shoe track / new hole, LOT, POH for MWD change Operation at 07.00 Drill ahead 12-1/4 hole. 24h Forecast POH, change out MWD, RIH, drill ahead. Lithology 'Shows MAASP Pressure (psi) [Mud Weight (lb/gal) 9.00 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00'00 01.00 1.00 1.00 DRILL E 4 P Finish P/U BHA and Clear Floor 01'00 01:30 0.50 1.50 DRILL E 7 P Circulate and Condition, Perform S.H.T. W /BHA #4 as per SLB. 677GPM, 1230PSI, 01'30 03:00 1.50 3.00 DRILL E 4 P P/U 30 Joints 5" DP 03:00 03:30 0.50 3.50 DRILL E 4 P Service Top Drive, Grease Crown 03 30 05'30 2,00 5.50 DRILL E 4 P RIH F /DRK T/4268 Filling Every 20 Stds. 05 30 06'00 0.50 6.00 DRILL E 6 P Precaution wash last 200 R to tag float collar at 4509 fl. Approx 8 ft green cmt top of float collar. 542GPM, 1200PSI, 1ORPM 06:00 07.30 1.50 7,50 DRILL E 7 P Cont circ cmt to surface. Circ / cond fluids. 07 30 09:00 1.50 9.00 DRILL E 19 P Test casing 2500 psi / 30 min. Test successful, no re -tests 09'00 11.00 2.00 11.00 DRILL E 19 P Drill float collar, 80 ft cmt shoe track, guide shoe, 12 ft rat hole cmt. 11'00 12 00 1.00 12.00 DRILL E 3 P Drill ahead 12 -1/4 new hole 4606 - 4621 R for LOT 12'00 16.00 4.00 16.00 DRILL E 7 P Circ / cond fluids. Displace well with new VC OBM 9# ddg fluids. 16'00 17.30 1.50 17.50 DRILL E 19 P RU and perform LOT test at 4595 11 MD / 3789 ft TVD Results = 546 psi surface press, 9# obm, 11.78 ppg EMW 17:30 19'00 1.50 19.00 DRILL E 3 XDOI Attempt drill ahead. MWD malfunction. Various attempts, no success. 19:00 00.00 5.00 24.00 DRILL E 4 XD01 POH for MWD change out, Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener@enipetroleum.com 907-670-8623 907 - 715 -6434 Eni representative Dave Moms ENI Dnlhng Supervisor 907-670-8623 Eni representative Jack Potter ENI Dulling HSE 907 -670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907 -670 -8607 907- 229 -6100 Eni representative Michael Seward ENI Ddg. Fac. Adv. 907- 952 -7880 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (RKB) Bottom (RKB) Run Date CASING 13 3/8 12.415 L80 -5.3 4,595.1 4/14/2010 Last Leakoff Test Depth (RKB) I TVD (ftKB) 'Fluid Type FFluld Density (Ib /gal) I P Surf Applied (psi) I Eq. Mud Weight (lblgal) I Leak Off Pressure (psi) 4,607,0 3,778.56 LSND I 9.00 546.0 11.78 2,312.6 1 • frt* Eni E&P Division I Well Name: OP23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • APIIUWI: 50-029-23411-00-00 enii Date: 4/18/2010 • Report #: 14 pag 1 of 1 Wellbore name: OP23 -WW02 Well Header Oliktok Point Permit/Concession N° 'Operator ENI PETROLEUM I ENI Share (%) 100.001 DIRECTIONAL Configuration type Rotary Table Elevation (ft) I Ground Level (ft) !Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA 1 NABORS 245E I LAND RIG Job Information Wellbore Job Phase 'Spud Date 'Target Depth (ftKB) I Target Depth (TVD..l Depth Dr. (MD) (ft) I Drilling Hours (hr) 'Avg ROP (ft/hr) I DFS (days) 0P23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 14.00 Daily Information End Depth (ftKB) End Depth (TVD) (f..' Depth Progress (ft)' Drilling Hours (hr) 'Avg ROP (ft/hr) I POB I Temperature (°F) I Weather ' Wind 5,302.0 4,199.3 667.00 8.50 78.5 92.0 17.0 Clear, WC +10° 49° NE © 5 mph Daily summary operation 24h Summary Continue LD BHA #4 due to MWD failure. CO rebuilt 12 1/4" PDC with new. While loading Nuke source in SADN8 found broken shear pin. LD SADN8 and TIH to 4635' MO. Dnll 12 1/4" hole to 5302' MD/ 4195' TVD Operation at 07.00 Drilling ahead 12 1/4" hole. 24h Forecast Drill ahead 12 1/4" hole to Intermedate Casing Point © 9035' MD Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) 9.10 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 0000 03.00 3.00 3.00 DRILL - 8 4 TD01 LD BHA - Continue LD BHA #4 due to MWD Failure 03 00 07.00 4.00 7.00 DRILL E 4 TD01 PU BHA - Change out rebuilt 12 1/4" PDC with new REED 12 1/4" MSX619S -A2D and PU BHA #5 07.00 10'00 3.00 10.00 DRILL E 4 XD01 PU BHA - While loading source in SADN8 found broken shear pin. LD SADN8. 10.00 12.00 2.00 12.00 DRILL E 4 TD01 PU BHA - Continue PU BHA #5 without SADN8. 12'00 15:00 3.00 15.00 DRILL E 4 TD01 TIH - Shallow pulse test MWD - Good Test. TIH to 4535' MD. 15 00 1530 0.50 15,50 DRILL E 4 P SERVICE RIG- Set floor/ crown saver for drilling mode 15 30 00'00 8.50 24.00 DRILL E 3 P DRILLING - Wash down from 4535' MD to 4635' MD - No Fill. Drill f/ 4635' MD to 5302' MD/ 4195' TVD Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Dave Moms ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Greg Parker ENI Expediter 907 - 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907-670-8607 907- 229.6100 Eni representative Joe Longo ENI Drilling Engineer joe.longo©enipetroleum.com 907-670-8623 907-947-4323 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (RKB) Bottom (ftKB) Run Date CASING 13 3/8 12.415 L80 -5.3 4,595.1 4/14/2010 Last Leakoff Test Depth (ftKB) I TVD (OIKB) 'Fluid Type 'Fluid Density (lb/gal) IP Surf Applied (psi) I Eq. Mud Weight (1b/gal) Leak Off Pressure (psi) 4,607.0 3,778.56 LSND 9.00 548.0 11.78 2,312.6 • 0 Eni E &P Division (Well Name: OP23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • e 1) 11 „ Date: 4/19/2010 - Report #: 15 API /UWI: 50 -029- 23411 -00 -00 1� page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° 'Operator ENI Share ( %) Well Configuration type Oliktok Point IENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) 'Water Depth (ft) RKB - Base Flange (ft) 'RKB - Tubing Spool (ft) 53.20 12,20 31.50 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore 'Job Phase Spud Date 'Target Depth (ftKB) 'Target Depth (TVD..IDepth Dr. (MD) (ft) I Drilling Hours (hr) !Avg ROP (ft/hr) IDFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 15.00 Daily Information End Depth (ftKB) End Depth (TVD) (f..' Depth Progress (ft) [Drilling Hours (hr) !Avg ROP (ftlhr) IPOB !Temperature ( °F) !Weather ! Wind 6,720.0 5,075.7 1,418.00 19.00 74.6 91.0 12.6 Cloudy, WC +7.5° 49° NE @ 2.9 mph Daily summary operation 24h Summary Dulled 12 -1 /4" hole to 6600' MD. Short tripped back to surface casing shoe at 4595' MD without and issues. Continue drilling ahead 12-1/4" hole to 6720' MD Operation at 07.00 Dnlling ahead 12 1/4" hole. Current Depth 7035' MD/ 5272' TVD 12 0400 24h Forecast Drill ahead 12 1/4" hole to Intermedate Casing Point @ 9035' MD Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) 9.50 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00 00 06:00 6.00 6.00 DRILL E 3 P DRILLING - Continue dnlling 12 -1/4" hole from 5302' MO to 5860' MD @ 175 ROP, 15 WOB 906 gpm, 80 rpm, 8-9K TQ, 165 UP -WT/ 135 DWN -WT/ 146 ROT -WT. Reaming every stand. 06'00 12,00 6.00 12.00 DRILL E 3 P DRILLING - Continue drilling 12 -1/4" hole from 5868' MD to 6300' MD @ 100 -170 ROP, 10 -18 WOB, 906 gpm, 80 rpm, 8- 96 TQ, 173 UP -WT/ 135 DWN -WT/ 147 ROT -WT. Reaming every stand. 12:00 17:00 5.00 17.00 DRILL E 3 P DRILLING - Continue drilling 12 -1/4" hole from 6300' MD to 6600' MD @ 110 ROP, 15 -16 WOB, 910 gpm, 80 rpm, 8-9K TQ, 192 UP -WT/ 142 DWN -WT/ 158 ROT -WT. Reaming every stand. / 17:00 18:00 1.00 18.00 DRILL E '7 P CIRCULATE - C8C pnor to short trip, 900 gpm 2900 psi. ✓ 18:00 19.30 1.50 19.50 DRILL E 4 P TRIPPING - Short trip from 6600' MD to intermedate casing shoe @ 4595' MD. 195 UP -WT/ 140 DWN -WT. No change in PU weight while passing through hole section with ghost reamer. 1930 20:30 1.00 20.50 DRILL E 25 P SERVICE RIG - Service topdrive, blocks, drawworks and crown. 20 30 22:00 1.50 22.00 DRILL E 4 P TRIPPING - TIH to 6547' MD. Wash down from 6547' MD to 6600' MD. 195 UP -WT/ 140 UP -WT 22 00 00'00 2.00 24.00 DRILL E 3 P DRILLING - Drill ahead 12 -1/4" hole from 6600' MD to 6720' MD @ 150 ROP, 910 gpm, 15 -16 WOB, 80 rpm, 11K TQ, 195 PU -WT/ 140 DWN -Wli 160 ROT -WT. Reaming everystand Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Dave Moms ENI Drilling Supervisor 907 -670 -8623 Eni representative Jack Potter ENI Drilling HSE 907 -670 -8624 Eni representative Greg Parker ENI Expediter 907 -980 -7545 Eni representative Torn Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Eni representative Joe Longo ENI Drilling Engineer joe.longo@enipetroleum.com 907- 670 -8623 907 - 947 -4323 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (RKB) Bottom (ftKB) Run Date CASING 13 3/8 12.415 L80 -5.3 4,595.1 4/14/2010 Last Leakoff Test Depth (RKB) ITVD (ftKB) I Fluid Type 'Fluid Density (Iblgal) I P Surf Applied (psi) I Eq. Mud Weight (lb/gal) I Leak Off Pressure (psi) 4,607.0 3,778.56 LSND 9.00 546.0 11.78 2,312.6 Eni E &P Division 'Well Name: OP 02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikanchuq 11 • • Date: 4/20/2010 - Report #: 16 APIIUWI: 50- 029- 23411 -00-00 1) 1) r, �) page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share (%) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) I Ground Level (ft) (Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA I NAB 245 E LAND RIG Job Information Wellbore I Job Phase I Spud Date I Target Depth (ftKB) I Target Depth (TVD.. .I Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) OP23 -WW02 DRILLING J 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 16.00 Daily Information End Depth (ftKB) I End Depth (TVD) (f.. Depth Progress (ft) I Drilling Hours (hr) 'Avg ROP (ft/hr) I POB Temperature ( °F) 'Weather 'Wind 8,320.0 6,108.5 1,600.00 23.50 68.1 88.0 19.2 Cloudy, WC +13.1 329° NNW @ 9 mph Daily summary operation 24h Summary Dulled 12 1/4" hole from 6720' MD to 8320' MD. Operation at 07.00 Drilling ahead 12 1 /4" hole. Current Depth 8582' MD/ 6277' WD @ 0400 24h Forecast Did ahead 12 1/4" hole to Intermediate Casing posit @ 9035' MD. Circulate hole clean. Short inp. P001-I on elevators. Lithology 'Shows MAASP Pressure (psi) I Mud Weight (lb/gal) 9.80 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. / 00:00 06.00 6.00 6.00 DRILL E 3 P DRILLING - Continue drilling ahead 12-1/4" hole from 6720' MD to 7200' MD, back reaming every stand. // *902 gpm, 3100psi ON/ 2900psi OFF *90 rpm, 12K TQ ON/ 9 -10K TQ OFF '100 -185 ROP, 18K WOB *200 PU/ 140 SO/ 155 ROB 0600 12.00 6.00 12.00 DRILL E 3 P DRILLING - Continue drilling ahead 12 -1/4" hole from 7200' MD to 7601' MD, back reaming every stand. *902 gpm, 3250psi ON/ 315opsi OFF '40-90 rpm, 11 -12K TO ON/ 9-10K TQ OFF *50 -150 ROP, 10 -20K WOB `212 PU/ 140 SO/ 157 ROB 12:00 1900 7.00 19.00 DRILL E 3 P DRILLING - Continue drilling ahead 12 -1/4" hole from 7601' MD to 8010' MD, back reaming every stand. Slide from 7704' MD -7725' MD, 8000' MD -8010' MD. Introduce 9.8ppg spike fluid to mud system. '902 gpm, 3250psi ON/ 3150psi OFF '90 rpm, 10K TO ON/ 9 -10K TQ OFF '50-150 ROP, 18K WOB '202 PU/ 160 SO/ 170 ROB 19 00 19 30 0.50 19.50 DRILL E 7 U CIRCULATE - Noticed 300psi drop in standpipe pressure. Test surface equipment - GOOD. Found pressure drop was attnbuted to addition of spike fluid. 19:30 0000 4.50 24.00 DRILL E 3 P DRILLING - Continue drilling ahead 12-1/4" hole from 8010' to 8320' MD, back reaming every stand, Slide from 8010' MD- 8020 MD. '864 gpm, 3280psi ON '90 rpm, 14K TQ ON '150 ROP, 20K WOB '215 PU/ 160 SO/ 180 ROB Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Dave Moms ENI Dnlling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Dnlling HSE 907 - 670 -8624 Eni representative Greg Parker ENI Expediter 907 -980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907 -670 -8607 907- 229 -6100 Em representative Joe Longo ENI Drilling Engineer joe.longo@enipetroleum.com 907- 670 -8623 907- 947 -4323 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (RKB) Bottom (ftKB) Run Date CASING 13 3/8 12.415 L80 -5.3 4,595.1 4/14/2010 Last Leakoff Test Depth (ftKB) ITVD (RKB) 'Fluid Type 'Fluid Density (Ib /gal) IP Surf Applied (psi) IEq. Mud Weight (Iblgal) I Leak Off Pressure (psi) 4,607.0 3,778.56 LSND 9.00 546.0 11.78 2,312.6 V* Eni E &P Division 'Well Name: OP23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaachuq • Date: 4/21/2010 - Report #: 17 APIIUWI: 50-029 -23411 -00-00 page 1 of 1 Wellbore name: OP23 -WWO2 Well Header Permit/Concession N° I Operator I ENI Share ( %) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.0o DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) 'Water Depth (ft) RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12,20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA I NABORS 245 E LAND RIG Job Information Wellbore I Job Phase Spud Date !Target Depth (ftKB) !Target Depth (TVD..l Depth Dr. (MD) (ft) I Drilling Hours (hr) 'Avg ROP (ft/hr) I DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 17.00 Daily Information End Depth (RKB) End Depth (TVD) (f.. Depth Progress (ft) [Drilling Hours (hr) 'Avg ROP (ft/hr) I "B I Temperature (°F) 'Weather I Wind 9,120.0 6,634.7 800.00 12.50 64.0 94.0 9.0 Clear, WC -D.4° 109° ESE @ 6 mph Daily summary operation 24h Summary Dolled to Intermediate Casing Point r@ 9120' MD/ 6637' TVD. Short tripped to previous wiper trip depth @ 6600' MD Without any issues. TIH back to bottom and circulated the hole clean. POOH f/ 9120' MD V 4535' MD on elevators. Operation at 07.00 POOH and LD BHA #5. Intermediate CSG Pt @ 9120' MD/ 6637' TVD Current Depth POOH (d3 112.8'MD @ 0400 24h Forecast POOH with BHA #5. Rack back collars, HWDP, and MWD for possible cleanout run. RU SLB wire line and log Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) 9.80 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Poser. 00:00 06'00 6.00 6.00 DRILL E 3 P DRILLING - Continue dnlling ahead f /8320'MD t/8675'MD, reaming every stand. •100-160 ROP, 15-20 WOB *90 RPM, 15-17K TO-ON/ 14 -15K TQ -OFF *850 gpm, 3350 psi-ON /3150 psi -OFF *210 PU/ 150 SO/ 160 ROB 06.00 12.00 6,00 12.00 DRILL E 9 P DRILLING - Continue dnlling f /8675'MD t/9100'MD, reaming every stand. *100 -160 ROP, 10-15 WOB *40-90 RPM, 15 -18K TQ -ON/ 14K TO-OFF *840 gpm, 3430 psi-ON /3325 psi -OFF *239 PU/ 160 SO/ 180 ROB *ECD 10.45 -10.73 ppg 12 00 12:30 0.50 12.50 DRILL E 3 P DRILLING - Continue drilling to Intermediate Casino Point ad 9/9100' MD 1/9120' Mn reaming every viand„ T 1'7 •100 ROP, 15 WOB ` *90 RPM, 15.16 TQ ° *850 gpm, 3425 psi *240 PU/ 160 SO/ 190 ROB 12 30 14'30 2.00 14.50 DRILL E 7 P CIRCULATE - Circulate and condition mud at TD. Take on bottom survey. Pump hi vis sweep. *850 gpm, 3300 psi 14.30 17 00 2.50 17.00 DRILL E 4 P TRIPPING - TOOH (/9120' MD V 6600' MD (to previous wiper trip depth) on elevators. Worked tight spot @ 6738' MD, worked one time with no problem. *200 PU/ 140 SO 17:00 18'30 1.50 18.50 DRILL E 4 P TRIPPING - TIH back to bottom f/ 6600' MD V 9120' MD. Wash down (/9037' MD 1/9120' MD *245 PU/ 160 SO 18:30 2130 3,00 21.50 DRILL E 7 P CIRCULATE - Condition mud on bottom. Pump high vis nut plug sweep, carne back 500 stk early. Circulated hole clean. *825 gpm, 3200 psi 21.30 00'00 2.50 24.00 DRILL E 4 P TRIPPING - TOOH f/ 9120' MD 1./ 4535' MD on elevators. No tight spots encountered. '245 PU/ 160 SO @ 9120' MD *180 PU/ 130 SO @ 4535' MD Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Dave Moms ENI Drilling Supervisor 907 - 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907-670-8624 Eni representative Alvin Cnswell ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907 -670 -8607 907- 229 -6100 Eni representative Joe Longo ENI Dnlling Engineer loe.longo @enipetroleum.com 907- 670 -8623 907 - 947 -4323 Eni representative Gary Goedich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Michael Seward ENI Ddg. Fac. Adv. 907 -952 -7880 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 13 3/8 12,415 180 -5.3 4,595.1 4/14/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) Fluid Type 'Fluid Density (lb /gal) IP Surf Applied (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 4,607.0 3,778.56 LSND 9,00 546.0 11.78 2,312.6 ri Eni E&P Division • 'Well Name: OP23 -WW02 • E NlPetroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • APIIUWI: 50-029-23411-00-00 e �� 1� ,_., o Date: 4/2212010 - Report #: 18 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I EN! Share ( %) I Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) 'Water Depth (ft) RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA I NABORS 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date 'Target Depth (ftKB) 'Target Depth (TVD...IDepth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) OP23 -WW02 DRILLING 4/5/2010 I 12,369.0 9,753.4 12,32300 216.34 57.0 18.00 Daily Information End Depth (ftKB) I End Depth (TVD) (f... Depth Progress (ft) 'Drilling Hours (hr) 'Avg ROP (ft/hr) I POB 'Temperature (°F) Weather 'Wind 9,120.0 6,634.7 0.00 98.0 10 8 Clear, WC +0,7 92° E (0 7 mph Daily summary operation 24h Summary POOH (/4595' MD, R/U SLB Wireline and Open Hole Log f/ 9118' MD Operation at 07.00 SLB Tools Down, Pulling Ware Ring Intermediate CSG Pt @ 9120' MD/ 6637' TVD Current Depth - Surface 24h Forecast Run 9 5/8" Casing, Cement Same Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) 9.80 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00.00 03'00 3.00 3.00 DRILL E 4 P TRIPPING - CONTINUE TOOH F/ 4595' MD SHOE T/ 703' MD BHA. NO SWABBING 03.00 0310 0.50 3.50 DRILL E 4 P PRE JOB SAFETY MEETING - L/D BHA #5 03:30 06.30 3.00 6.50 DRILL E 4 P TRIPPING - L/D BHA #5 AS PER SLB /DD, RACK BACK 8" DC. 0630 09'30 3.00 9.50 DRILL J 24 TWO2 MISCELLANEOUS - WARING ON 3RD PARTY TOOLS - CLEAN DRILL FLOOR AND CELLAR WHILE WAITING ON SLB WIRE LINE PERSONNEL. 09 30 11'00 1 50 11.00 DRILL J 25 P SERVICE RIG - SERVICE TOP DRIVE, GREASE T/D DRAWWORKS, IRON ROUGHNECK, CLEAR PIPESHED OF MWD TOOLS 1100 11:30 0.50 11.50 DRILL J 1 P MEETING - PRE JOB SAFETY MEETING W /SLB, RIG UP WIRE LINE LOGGING EQUIPMENT/TOOLS. 11 30 1210 0,50 12.00 DRILL 'J 1 P WIRE LINE WORK - R/U WIRE LINE EQUIPMENT & LOGGING TOOLS 12.00 16'00 4.00 16.00 DRILL J 1 P WIRE LINE WORK- PJSM W /SLB, MN LOGGING TOO;S AND R/U WIRELINE. LOAD NUKE SOURCE. 16.00 1830 2.50 18.50 DRILL J 4 P LOGGING OPEN HOLE LOGS - RIH W/ WIRELINE PLATFORM EXPRESS /SONIC SCANNER /PPC'S T/ 9118' MD. 18.30 00'00 5.50 24.00 DRILL J 4 P LOGGING OPEN HOLE LOGS - LOG OUT F/ 9118' MD T/ 2500' MD. MONITOR WELL ON TRIP TANK WHILE LOGGING. CLEAN CELLAR. CLEAN /SERVICE CENTRIFUGES, CLEAN SUCTION SCREENS ON MUD PUMPS, Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Dave Moms ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Alvin Cnswell ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907 -670 -8607 907- 229 -6100 Eni representative Joe Longo ENI Dnlling Engineer joe.longo@enipetroleum.com 907 -670 -8623 907- 947 -4323 Eni representative Gary Goeriich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Michael Seward ENI Drtg. Fac. Adv. 907. 952.7880 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 13 3/8 12.415 L80 -5.3 4,595.1 4/14/2010 Last Leakoff Test Depth (RKB) 'TVD (ftKB) 'Fluid Type 'Fluid Density (Iblgal) IP Surf Applied (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 4,607.01 3,778.56 LSND 9.00 546.0 11 78 2,312.6 Eni E &P Division I Well Name: OP23 -wwo2 II ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq IF114 1 n APIIUWI: 50- 029 -23411 -00-00 (I Date: 4/23/2010 - Report #: 19 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share ( %) 'Well Configuration type Oliktak Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) 'Water Depth (ft) RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E I LAND RIG Job Information Wellbore /Job Phase Spud Date (Target Depth (ftKB) !Target Depth (TVD..I Depth Dr. (MD) (ft) (Drilling Hours (hr) !Avg ROP (ft/hr) I DFS (days) W OP23 -W02 DRILLING 4/5/2010 l 12,369.0 9,753.4 12,323.00 216.34 57.0 19.00 Daily Information End Depth (ftKB) End Depth (TVD) (f.. Depth Progress (ft) Drilling Hours (hr) Avg ROP (ftlhr) POB Temperature (°F) Weather Wind 9,120.0 6,634.7 0.00 100.0 19.9 Clear, WC +14.4 109 ESE @ 3.8 mph. Daily summary operation 24h Summary Completed running SLB open hole logs. Change Rams to 9 -5/8". Run 9-5/8" casing. Operation at 07.00 Ran 9-5/8" casing. CBU prior to cement job. Intermediate Casing Pt 81 9,120' MD/6,637' TVD. At 0400: Running 9-5/8" casing at 7,800' MD. 24h Forecast Run 9 -5 /8" Casing. Cement Same. Nipple Up BOPE, Lithology 'Shows MAASP Pressure (psi) I Mud Weight (Ib/gal) 9.90 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00 00 02 00 2.00 2.00 DRILL J 4 P LOGGING OPEN HOLE LOGS - LOG F/2500' MD,ROUGH PATCH AT 6300'. NO OVERPULL. AT 4700' 300 LOS ✓ OVERPULL AS PER SLB. 02:00 04'00 2.00 4.00 DRILL J 4 P PJSM. R/D WIRELINE EQUIPMENT. 04:00 05 00 1.00 5.00 DRILL J 4 P REMOVE WEAR BUSHING. PULL R/W AND INSTALL T/P AS PER VETCO, 05.00 05 30 0.50 5.50 DRILL E 5 P PU TEST TOOLS. PJSM. MAKE UP 9-5/8" TEST JOINT. 0530 06 30 1.00 6.50 DRILL C 5 P CHANGE RAMS, PJSM. C/O BTM 3-5/8" RAMS TO 9 -5 /8" RAMS. ■ 06:30 07'00 0.50 7.00 DRILL C 12 P PU TEST TOOLS, FILL STACK WITH WATER. FLUID PACK TESTING EQUIPMENT. BOP 07:00 07:30 0.50 7.50 DRILL C 12 P TEST 9 -5/8" BTM RAMS TO 250 P51 AND 5000 PSI 5 MINUTES. 07:30 08:00 0.50 8,00 DRILL G 4 P RIG UP /DOWN TO RUN CASING. PERFORM 9 -5/8" HANGER DUMMY RUN AS PER VETCO. vs:- 08'00 10.30 2.50 10.50 DRILL G 4 P RIG UP TO RUN CASING. PJSM. R/U CASING EQUIPMENT. 10:30 12:00 1.50 12.00 DRILL G 4 P PJSM. P/U SHOE AND FLOAT ASSEMBLY. CHECK FLOATS. OK AS PER PROGRAM. 12:00 00:00 12.00 24.00 DRILL G 4 P PJSM All personnel, RUN 9 -5/8" CASING AS PER RUNNING ORDER. Guide shoe, 2 jts csg, Boat collar. 2 centralizers jt #1, 1 centralizers jt #2, 2 centalizers J1 #3 thread lock all shoe track connections, Continue RIH 9 -5/8 csg (L80, 478. BTC) FILL EVERY JOINT, TOP OFF EVERY 10 JOINTS. CBU EVERY 1000'. RIH TO 6000', UP WEIGHT 252 DOWN WEIGHT 172. CBU AT 6000' 5 BPM 390 PSI. MAKE UP TO 8500 FT /LBS, AVERAGE. Depth 5800 ft at end of tour. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Dave Moms ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907 - 670 -8624 Eni representative Alvin Criswell ENI Expediter 907 - 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907-670-8607 907- 229 -6100 Eni representative Joe Longo ENI Drilling Engineer joe.longo@enipetroleum.com 907-670-8623 907 - 947 -4323 Eni representative Gary Goerlich ENI Drilling Supervisor 907 - 670 -8623 907- 441 -6585 Eni representative Michael Seward ENI Ddg. Fac. Adv, 907- 952 -7880 Eni representative Bernie Leas ENI Rig Clerk 907 -670 -8607 907 - 575 -9427 Eni representative Pete Adams ENI Dulling HSE 907- 670 -8624 907-440-0806 Last Casing seat _ Cris. Type I OD (in) ID (in) Grade Top (RKB) Bottom (ftKB) Run Date CASING 13 3/8 12.415 L80 -5.3 4,595.1 4/14/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) I Fluid Type 'Fluid Density (lb/gal) I P Surf Applied (psi) I Eq. Mud Weight (Iblgal) I Leak OH Pressure (psi) 4,607.0 3,778.56 LSND 9.00 546.0 11.78 2,312.6 • el frif* Eni E &P Division `Well Name: OP23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikailchuq • APIIUWI: 50-029-23411-00-00 e n n Date: 4/24/2010 - Report #: 20 'r page 1 of 1 Wellbore name: OP23 -WW02 Well Header Pennit/Concession N° 'Operator I ENI Share ( %) /Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) I Ground Level (ft) [Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.501 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA I NABORS 245 E I LAND RIG Job Information Wellbore / Job Phase I Spud Date 'Target Depth (ftKB)' Target Depth (TVD...1 Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 20.00 Daily Information End Depth (ftKB) End Depth (TVD) (f.. 'Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB Temperature ( °F) Weather Wind 9,120.0 6,634.7 0.00 100.0 17.1 P /C, WC +3.4 242 WSW gfi 17 mph Daily summary operation 24h Summary Completed running 9 -5/8" casing. Layed down casing equipment. Cemented casing. Nipple up BOPE. Tested BOPE. Operation at 07.00 Making up BHA 96. 24h Forecast Test casing. Make up and RIH with BHA 96. Drill ahead with 8-1/2" hole. Lithology I Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) 10.40 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act Plan Oper. Descr. 00:00 08'30 8.50 8.50 DRILL G 4 P Continue RIH 9 -5/8" casing. CBU 1000 ft intervals. 08:30 10,00 1.50 10.00 DRILL G 4 P CBU at last joint before casing hanger in prep for landing. 10:00 12.00 2.00 12.00 DRILL G 4 P MU casing hanger and landing joint. Circulate down to land hanger. Lay down Franks 6llup tool. Make up cement head. ,j 12.00 14:00 2.00 14.00 DRILL G 7 P Circulate and condition fluids. Reciprocate casing. '=v✓` 1400 16:30 2.50 16.50 DRILL H 9 - P Commence to cement 9-5/8" casing as follows: PJSM. Pump 5 barrels water. Test lines to 4000 psi. Mix and pump 40 C M T barrels mud push at 12.8 ppg. Cease pumping, drop btm plug. Mix / pump 75.6 bbls slurry 15.8 ppg G (363 sks), at 6 bpm. Cease pumping, drop top plug, pump 10 bbls H2O wash behind plug. Displace with 650 barrels VC -OBM drilling mud with Schlumberger pumping unit at 8 bpm. Slow to 3 bpm last 10 barrels displacement. Plug did not bump. Pump additional 10 barrels. Did not bump. Bleed to cement unit. Floats holding. ICP = 520 psi at 6 bpm. FCP = 630 psi at 3 bpm. Reciprocate pipe entire job until last 5 barrels displacement. 100% retums at all times. Cement in place at 16.30 hours, 16:30 19:00 2.50 19.00 DRILL G 5 P Lay down cement head. Remove casing elevator and install drillpipe elevators. pickup packoff running tool. Suck out stack and rinse top of hanger. Set packoff and test to 5000 psi (Vetco Gray). 1900 20:00 1.00 20.00 DRILL G 5 P Lay down casing tools and equipment. Set test plug. 20'00 21.00 1.00 21.00 DRILL C 5 P Change out bottom rams from 9-5/8" to 3 -1/2 x 6 VBR's. 21.00 21'30 0.50 21.50 DRILL C 5 P Pick up test tools, Install test joint. Fill BOP's with water. I` 21.30 00:00 2.50 24.00 DRILL C 12 P Test BOP's 250 PSI Low and 5000 PSI High. Annular 3000 PSI High. 5 minutes each. Record on chart. IV I550IP Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Dave Moms ENI Dnlling Supervisor 907 -670 -8623 Eni representative Alvin Cnswell ENI Expediter 907 - 980 -7545 Eni representative Gary Goerlich ENI DnIling Supervisor 907 -670 -8623 907- 441 -6585 Eni representative Michael Seward ENI Drlg. Fac. Adv. 907-952-7880 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907- 575 -9427 Eni representative Pete Adams ENI Dnlling HSE 907- 670 -8624 907- 440 -0806 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (RKB) Bottom (ftKB) Run Date CASING 9 5/8 8.681 L80 -2.1 9,087.0 4/24/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) I Fluid Type 'Fluid Density (Ib /gal) IP Surf Applied (psi) I Eq. Mud Weight (Iblgal)'Leak Off Pressure (psi) 4,607,0 3,778.56 LSND 9.00 546.0 11.78 2,312.6 • • V)11111 Eni E &P Division I Well Name: OP23 -WW02 ENI Petroleum Co. Inc. Daly Report Well Code: 23835 Field Name: Nikanchuq • Date: 4/25/2010 - Report #: 21 APIIUWI: 50-029-23411-00-00 page 1 of 1 Welibore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share ( %) I Well Configuration type °Wok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) 'Ground Level (ft) I Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor 'Rig Name 'Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Welibore Job Phase 'Spud Date 'Target Depth (ftKB)' Target Depth (TVD..I Depth Dr. (MD) (ft) 'Drilling Hours (hr) 'Avg ROP (ft/hr) I DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 21.00 Daily Information End Depth (ftKB) ' End Depth (TVD) (f.. Depth Progress (ft) [Drilling Hours (hr) 'Avg ROP (ft/hr) ' POB Temperature ( °F) 'Weather ' Wind 9,692.0 7,022.9 572.00 10.00 57.2 95.0 4.5 Clear. WC -1.8 307 NW (rD 3 mph Daily summary operation 24h Summary Tested BOPE. Layed doom HWDP from demck. Layed down 12 -1/4" BHA from derrick. Slip and cut drilling line. Changed swabs on mud pumps to oilbase rubber. Pick up BHA 66. Operation at 07.00 Picking up dnll pipe from pipe shed. RIH with BHA 66. 24h Forecast RIH with BHA 66, Drill out 9-5/8" casing. LOT. Dnll ahead with 8 -1/2" hole. 'Lithology 'Shows MAASP Pressure (psi) I Mud Weight (Iblgal) 10 40 Time Log Start End Cum • Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan rr Oper. Descr. 00 00 04'00 4.00 4.00 DRILL C 12 P Test BOPE, all components 2501 500 psi. Test annular 250 / 3000 psi. Witness waived by Mr. Bob Noble AOGCC. Freeze protect 13 -3/8" X 9-5/8" annulus. Total volume 382 bbls. 5 bpm at 1473 psi. Bleed back 1.5 bbls. Annulus static. 04'00 05.30 1.50 5.50 DRILL C 12 P Close blind rams, test 9 -5/8" casing 3000 psi / 30 minutes. Test succescftl Nn meat 10 05 30 06:30 1.00 6.50 DRILL E 4 P RIH with HWDP from mast for lay down. 0630 08 30 2.00 8.50 DRILL E 25 P Slip and cut drilling Inc. 08 30 11'30 3.00 11.50 DRILL E 25 P Repair torque boost. Repair leaks at top drive. 11.30 13 00 1.50 13.00 DRILL 8 4 P Complete lay down 12 -1/4" BHA from mast. 13:00 15'00 2,00 15.00 DRILL E 5 'P Change out trim on mud pumps to OBM trim. 15:00 17:00 2.00 17.00 DRILL E 25 P Change out swabs on mud pumps to oilbase rubbers. Install tarps under rig floor for drip pan. Seal cracks on rig floor. Load pipe shed with dnll pipe. 1700 20:30 3.50 20.50 DRILL E 4 P PJSM. Pick up 8 -1/2" BHA. Load nuclear source. 20.30 21:00 0.50 21.00 DRILL E 25 P Pull mouse hole and try to access mouse hole sump to repair and weld. Not acessible. 21'00 00:00 3.00 24.00 DRILL E 4 'P RIH with HWDP out of derrick. Pick up drill pipe out of pipe shed. Pulse test MWD at 1000 ft. 500 GPM 1500 PSI. Trip in hole to 1600 R. Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Dave Moms ENI DnIling Supervisor 907 -670 -8623 Eni representative Alvin Cnswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Dulling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907. 952 -7880 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 - 575 -9427 Eni representative Pete Adams ENI Dnlltng HSE 907- 670 -8624 907- 440 -0806 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 9 5/8 8.681 L80 -2.1 9,087.0 4/24/2010 Last Leakoff Test Depth (RKB) 'TVD (ftKB) 'Fluid Type 'Fluid Density (lb/gal) I P Surf Applied (psi) Eq. Mud Weight (Iblgal)' Leak Off Pressure (psi) 4,607.0 3,778.56 LSND 9.00 546.0 11.78 2,312.6 En! E &P Division I Well Name: OP23 -WW02 III ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq eini Date: 4/26/2010 - Report #: 22 APIIUWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: 0P23 -WW02 Well Header Oliktok Point Permit/Concession N° 'Operator ENI PETROLEUM IENI Share (%) 100.001 D RECTIONAL don type Rotary Table Elevation (ft) !Ground Level (ft) !Water Depth (ft) I RKB - Base Flange (ft) 1 RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA Contractor ' Rig 245 E LAND RIG Job Information Wellbore Job Phase I Spud Date 'Target Depth (ftKB)' Target Depth (TVD..J Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) 1 DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 22.00 Daily Information End Depth (ftKB) End Depth (TVD) (f..'Depth Progress (ft) 'Drilling Hours (hr) !Avg ROP (ft/hr) 1POB Temperature (°F) Weather !Wind 11,380.0 8,615.7 2,280.00 34,00 66.5 95.0 16.0 P /C, WC 0.2 30 NNE Q 17 mph Daily summary operation 24h Summary RIH with BHA #6. Drilled shoe track and 50 ft new hole. Performed LOT. Drill ahead with 8 1 /r hole. Operation at 07.00 Dolling and sliding ahead in 8 1/2" hole. 0400 Depth: 9,890 ft MD. 24h Forecast DnII ahead with 8 1/2" hole to total depth, Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) 10.30 Time Log Start End Cum Time Time Dur (hr) Our (hr) Phase Opr. Act. Plan Oper. Desor. 00:00 06:30 6,50' 6.50 DRILL E 4 P RIH with 5" drill pipe to 8950 ft. Precaution wash to tag float collar at 9000 ft. 06:30 '10:30 4.00 10.50 DRILL E 4 P DRILLING - Drill float collar, shoe track, guide shoe, 30 fl of rat hole cement. 'WOB 6K/9K TO 7K/8K • RPM 175 SPM 30/40 * PSI 2340/2360 GPM 450 ' 220 UP 160 DN 10.30 11:00 0.50 11.00 DRILL E 3 P DRILLING - Drill 8-1/2" hole from 9,120 ft to 9,170 ft. for LOT. 'WOB 6K/9K TQ 7K/8K 'RPM 175 SPM 30/40 'PSI 3030/3180 GPM 550 '220 UP 150 DN 11.00 11 30 0.50 11.50 DRILL E 7 P CIRCULATE. Circulate and condition fluids for LOT. • GPM 550 PSI 3030 • MW in and MW out 10.3 11 30 12.00 0.50 12.00 DRILL E 4 P TRIP POH to 9 -5 /8" casing shoe for LOT. Lot 12'00 13.30 1 50 13.50 DRILL E 12 P LOT Perform LOT at 9,170' MD / 6,611' ND. 10.3 ppg fluid. 1,700 surface pressure. Resulting in 15.25 EMW. 13 30 19'30 6.00 19.50 DRILL E 3 P DRILLING AND SLIDING Slide intervals from 9,221 ft to 9,250 ft, from 9,323 ft to 9,348 ft, from 9,420 6 to 9,451 ft. RPM 110 TQ 10K WOB 7KI8K • GPM 550 PSI 3100 ' 240 UP 152 DN 180 ROT 19:30 20 30 1.00 20.50 DRILL E 7 P CIRCULATE Circulate and condition hole. Cuttings chute packed off. Cleaned out chute. Drag chain jumped off sprocket. Repaired drag chain. • GPM 330 P51 1300 20:30 00:00 3.50 24.00 DRILL E 3 P DRILLING AND SLIDING: Continue dnlling and sliding ahead from 9,451 h MD to 9,692 ft MD.Slide intervals from 9,451 ft to 9,457 ft, from 9,515 ft to 9,545 ft;from 9,611 6 to 9,658 6. ' WOB 7K/8K TO 10K/11K ' RPM 110 ROP 150 GPM 550 PSI 3100 ' 245 UP 152 ON 182 ROT Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Dave Moms ENI Drilling Supervisor 907- 670 -8623 Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907 -670 -8623 907- 441 -6585 Eni representative Michael Seward ENI Ddg. Fac. Adv. 907 - 952 -7880 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 -575 -9427 Eni representative Pete Adams ENI Dnlling HSE 907 - 670 -8624 907-440-0806 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING I 9 5/8 8.681 L80 -2.1 9,087.0 4/24/2010 Last Leakoff Test Depth (ftKB) 'TVD (ftKB) 'Fluid Type 'Fluid Density (lb/gal) IP Surf Applied (psi) 1Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 9,170,0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 • • I Eni E&P Division 'Well Name: 0P23 -W1102 ENI Petroleum Co. Inc. Daily Repo .. a L Well Code: 23835 Field Name: Nikaitchuq e Date: 4127/2010 - Report #: 23 APIIUWI: 50- 029 - 23411 -00 -00 11 i, page 1 011 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° 'Operator I ENI Share ( %) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) ' Ground Level (ft) ' Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA rig 245 E 1LAND RIG Job Information Wellbore 'Job Phase Spud Date 'Target Depth (ftKB) !Target Depth (TVD...I Depth Dr. (MD) (ft) 'Drilling Hours (hr) Avg ROP (ft/hr) ' DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 23.00 Daily Information End Depth (ftKB) I End Depth (TVD) (f..' Depth Progress (ft) [Drilling Hours (hr) 'Avg ROP (ft/hr) I POB I Temperature ( °F) 'Weather 'Wind 12,0 9,318.5 2,398.00 43.00 55.8 96.0 24.8 P /C, WC 19.8 17NNE @ 4 mph Daily summary operation 24h Summary Drilled 8-1/2" hole directionally from 9,692 ft MD to 11,380 ft MD. Operation at 07.00 Directionally drilling 8-1/2" hole towards Total Depth. At 0400' Directionally drilling at 11,590 ft MD. 24h Forecast Drill ahead with 8 -1/2" hole to Total Depth. Lithology 'Shows MAASP Pressure (psi) I Mud Weight (lb/gal) 10.40 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Dearer. 00:00 12'00 12.00 12.00 DRILL E 3 P DRILLING AND SLIDING' Drill ahead with 8 -1/2" hole directionally from 9,692 ft MD to 10,420 ft MD. TVD 7,674 ft. " UP 275 DN 170 ROT 200 WOB 10K GPM 550 RPM 140 PSI 3050/3140 TQ 11K / 13K to • SPR 182 SPM 20/30 PSI 290/370 • MD 10,267' ND 7,519' • MWT 10.3 ART 3.48 AST 3.78 ADT 7.26 Jar Hrs. 14.70 12.00 00 00 12.00 24.00 DRILL E 3 P DRILLING AND SLIDING' Drill ahead with 8 -1/2" hole directionally from 10,240 ft MD to 11,380 ft MD. Slide from 11,240 ft MD to 11,288 ft MD • UP WT 298 ON WT 185 ROT WT 220 " WOB 10K/12K GPM 550 PSI 3300 " RPM 100 TQ 12K/15K ADT 9.27 * ART 8.65 AST 0.62 Jar Hours 23.9 M -I SWACO WIF AND CCB FULLY OPERATIONAL ON APRIL 27 AT 2000 HOURS. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Dave Morns ENI Drilling Supervisor 907 -670 -8623 Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907 - 670 -8623 907- 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 - 575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Last Casing seat Cas. Type ' 00 (in) ID (In) Grade Top (ftKB) Bottom (RKB) Run Date CASING 9 5/8 8.681 L80 -2.1 9,087.0 4/24/2010 Last Leakoff Test Depth (RKB) TVD (ftKB) 'Fluid Type 'Fluid Density (lb/gal) IP Surf Applied (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 • Sr 31111 III Eni E &P Division 'Well Name: OP23 -5 W02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • APIIUWI: 50- 029 - 23411 -00 -00 n o Date: 4/28/2010 - Report #: 24 �) page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share ( %) 'Well Configuration type (Wok Point ENI PETROLEUM 100,00 DIRECTIONAL Rotary Table Elevation (ft) !Ground Level (ft) 'Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA I NABORS 245 E I LAND RIG Job Information Wellbore Job Phase Spud Date I Target Depth (ftKB) 'Target Depth (TVD..I Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) IDFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 24.00 Daily Information End Depth (ttKB) 'End Depth (TVD) (f.. Depth Progress (ft) I Drilling Hours (hr) I Avg ROP (ft/hr) I POB I Temperature (°F) I Weather I nd 12,323.0 9,549.5 943.00 25.00 37.7 96.0 25 0 Cloudy, WC +15.8 20 NNE CO 6.5 mph Daily summary operation 24h Summary' Dnll 8 1/2" hole directionally to 11,848 ft.MD. Marked increase in gas units and retum flow. Performed flow check, Expenenced losses at approximately 25 bph dynamic and 5 bph slatic.Spotted 40 bbl LCM pill. Pulled 10 stds. RIH and compressed LCM to formation. Resumed drilling ahead with no problems. Operation at 07.00 Directionally drilling 8 1/2" hole to total depth. 24h Forecast Drill ahead with 8-1/2" hole to Total Depth. Circulate and condition hole. Make a short tnp to shoe of 9 -5/8" casing. Lithology I Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) 10.50 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act Plan Oper. Descr. 00:00 11:30 11.50 11.50 DRILL E 3 P Drill 8 -1/2" hole directionally from 11,380 ft MD to 11,848 ft. MD. • UP 315 DN 190 ROT 230 TQ 14K/15K • WOB 10KJ15K GPM 400 PSI 1840/1940 RPM 110 * ART =8.21 ADT = 8.21 Jar Hours = 30.51 Gas units increased to 780 units 81 11,500 ft. Picked up and checked for flow. Return flow up to 26 -30 %.. Picked up and shut down to check for flow. Retums flow increased to 30-40% at 11,714 Expenenced losses at 11,799 ft at approximately 25 bph dynamix / 5 bph static. Reduced pump rate to 100 spm. Experienced continued losses. 11:30 12.30 1.00 12.50' DRILL E 7 P Spot 40 bbl LCM pill (10 ppb Saf Carb 2, 15 ppb Saf Carb 10) across zone. 400 GPM and 1,980 PSI. Slowed pumps down to 200 gpm while chasing pill after 1000 strokes. PSI = 680. Total losses equals 160 bbls. / 12.30 14 00 1.50 14.00 DRILL E 4 P Trip out of hole to 10,937 ft. 10 stands drill pipe above pill. UP = 300 DN = 175. y 14 00 15 30 1.50 ' 15.50 DRILL E 7 P Circulate and condition and reciprocate pipe. GPM = 425 PSI = 2050. Circulate top of pol owth (ECD EMW additional 280 psi). Compress LCM to formation. Monitor losses. 9.5 bbls lost. 15 30 16 00 0.50 16.00 DRILL E 4 P Trip in hole to 11,799 ft.. Wash down to 11,848 ft. UP = 315 DN = 190 16 00 00 00 ' 8.00 24.00 DRILL E 3 P Pump LCM pill at 11,880. Drill ahead 8-1 /2" hole to 12,090 ft MD. UP = 325 DN = 195 ROT = 232. WOB 12K/15K TQ 16K/17K RPM 90 GPM 450 PSI 2365 ART - 5.92 ADT- 5.92 Total of 68 bbls lost. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Dave Morris ENt Drilling Supervisor 907- 670 -8623 Eni representative Alvin Criswell ENI Expediter 907 - 980 -7545 Eni representative Gary Goerlich ENI Dnlling Supervisor 907 -670 -8623 907- 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907-575-9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING I 9 5/8 8.681 L80 -2.1 9,087.0 4/24/2010 Last Leakoff Test Depth (ftKB) ITVD (ftKB) 'Fluid Type 'Fluid Density (Iblgal) I P Surf Applied (psi) I Eq. Mud Weight (Iblgal) ' Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 • • En! E &P Division Well Name: OP23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq � • p APIIUW: 50-029 -23411 -00-00 e I) �) II I) 1) Date: 4/29/2010 - Report #: 25 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° 'Operator I ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) I Ground Level (ft) 'Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53,20 12.20 31.50 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase 'Spud Date 'Target Depth (ftKB) I Target Depth (TVD..lDepth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 25.00 Daily Information End Depth (ftKB) 'End Depth (TVD) (f..1 Depth Progress (ft)' Drilling Hours (hr) I Avg ROP (ft/hr) I POB Temperature (°F) 'Weather Weather I Wind 12,323.0 9,549.5 233.00 6.00 38.8 96.0 21.0 Cloudy, WC +6.3 NE Lgt 18.3 mph Daily summary operation 24h Summary Drill 8 1/2" hole directionally to total depth of 12,323 ft. Made short trip to 9 5/8" casing shoe at 9,087 R Circulate and condition hole. Trip out of hole to pick up Schlumberger wirellne tools. Operation at 07.00 Running Schlumbergerwirehne logs. At 0400. Picking up Schlumberger MDT tool. 24h Forecast Run Schlumberger Mrelme tools. Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (Iblgal) 10.40 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. �f'� 00 00 06:00 6.00 6.00 DRILL E 3 P (trilled dirertinnalN frnm 12 090 6 ft Mn to a Total n =nth nt 17 171 Mn / 9 549 8 Tyr) UP = 340 DN = 190 ROT = 240. ((�� y * WOB 15K GPM 440 PSI 2240/2410 RPM 110 TQ 16K/18K ART = 5.80 0'4 " ADT = 5.80 Jar Hours 44.50 06 00 09 30 3.50 9.50 DRILL E 7 P Circulate and condition hole for E -Logs. Pump HI-VIS weighted msweep. Rotate and reciprocate pipe. GPM 440 PSI 2240 RPM 120 TQ 15K/17K Monitor well for 10 minutes. 09:30 11 30 2.00 11.50 DRILL E 4 P Make a Short Trip out of hole from 12,323 ft to 9,021 ft. Hole in good condition. 11.30 12:30 1.00 12.50 DRILL E 7 P Circulate and condition hole, Rotate and reciprocate pipe. GPM 450 PSI 2020 Total losses = 154 bbls. 12:30 1300 0.50 13.00 DRILL E 25 P Performed service to blocks, crown, and draw works. 13:00 14:30 1.50 ' 14.50 DRILL E 4 P After completing Short Trip run in hole to 12,287 ft. Wash down to total depth at 12,323. UP = 335 DN = 198 1430 17:00 2.50 17.00 DRILL E 7 P Circulate and condition hole. Rotate and reciprocate pipe. GPM 450 PSI 2400 17'00 23.00 6.00 23.00 DRILL E 4 P Trip out of hole to BHA. Drop 2.25 rabbit on stand 105. Recover rabbit at jars. 23'00 00:00 1.00 24.00 DRILL E 4 P Lay down BHA. PJSM with SLB MWD for handling nuclear source. Layed down 2 pants of HWDP and jars. Layed down 2 joints of flex collars. Daily Contacts Position Contact Name Company Title E Office Mobile Eni representative Alvin Criswell ENI Expediter 907 - 980 -7545 Eni representative Gary Goedich ENI Drilling Supervisor 907 -670 -8623 907 - 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907 -670 -8607 907- 575 -9427 Eni representative Pete Adams ENI Drilling HSE 907 -670 -8624 907-440-0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keener@enipetroleum.com 907 - 670 -8623 907- 715 -6434 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) - Bottom (ftKB) Run Date CASING 9 5/8 8.681 L60 -2.1 9,087.0 4/24/2010 Last Leakoff Test Depth (ftKB) 'TVD (ftKB) (Fluid Type Fluid Density (lb/gal) I P Surf Applied (psi) I Eq. Mud Weight (lb/gal)'Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 • 1111 VAllik Eni E &P Division Well Name: OP23 -WW02 E NI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq eni Date: 4/30/2010 - Report #: 26 APIIUWI: 50 -029 -23411 -00-00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° !Operator I ENI Share ( %) !Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) I Ground Level (ft) !Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 3125 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore I Job Phase Spud Date l Target Depth (ftKB) I Target Depth (TVD..! Depth Dr. (MD) (ft) I Drilling Hours (hr) !Avg ROP (ftihr) I DFS (days) OP23 -0 W02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 26.00 Daily Information End Depth (ftKB) I End Depth (TVD) (f..jDepth Progress (ft) I Drilling Hours (hr) 'Avg ROP (ft/hr) I POB !Temperature ( °F) I Weather ! Wind 12,323.0 9,549.5 0.00 99.0 17.4 Cloudy. WC -0.1 49 NE @ 25 mph Daily summary operation 24h Summary Ran in hole with Schlumberger MDT logging tool. Logged hole taking pressure test points. On Ugnu Tank Farm' Mud volume in frozen tank = 275 barrels of 50/50 solids free OBM. Mud volume in good tank = 100 barrels of 50/50 solids free OBM. Operation at 07.00 Running Schlumberger MDT logs. 24h Forecast Run Schlumberger MDT logs. Lithology I Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) 10.10 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Deicer. 00 00 02'30 2.50 2.50 DRILL E 4 P Lay down BHA. Download nuclear source. Clear and clean drill floor. 02'30 06.30 4.00 6.50 DRILL J 11 P Spot Schlumberger unit. Load pipe shed with Schlumberger logging tools. Pick up and make up tools. Plug MDT into tools. 0630 12.00 5.50 12.00 DRILL E 4 P Trip in hole from 143 fl to 7,271 11 with logging tools on HWDP and drill pipe. Ran in hole 90 seconds per stand. Fill hole A Y 'f' ( every 10 stands. Total mud losses 27 barrels. r 12.00 13.00 1.00 13.00 DRILL 'E 4 P Trip in hole. Run in hole to stand 80 at 8230 fl. / c� 13:00 13:30 0.50 13.50 DRILL E 7 P Circulate and condition hole. Fill pipe at 52 SPM, 220 GPM, 30 strokes to break circulation. Circulate 150 strokes. 1 � 13'30 14:00 0.50 14.00 DRILL E 4 P Trip in hole to stand 89. Lay down top joint at 9060 ft. 14'00 16:30 2.50 16.50 DRILL J 11 P Rig up Schlumberger wireline. Make up side entry sub. 16'30 21.30 5.00 21.50 DRILL J 11 P Run in hole to 11,568 ft with drill pipe conveyed logging tool. UP = 280 DN = 190. 21'30 00.00 2.50 24.00 DRILL J 11 P MDT log at set points. Set point at 11,274 ft, Test results Bad; At 11,277 ft Test results Bad; At 11278 ft. Test results Good. At 11,29511. Test results Good. Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goencch ENI Dnlling Supervisor 907 -670 -8623 907- 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 - 575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670-8624 907 -440 -0806 Eni representative Jack Keener ENI Dnlling Supervisor jack.keener@enipetroleum.com 907 - 670 -8623 907 - 715 -6434 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 9 5/8 8.681 L80 -2.1 9,087.0 4/24/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) 'Fluid Type I Fluid Density (Iblgal) I P Surf Applied (psi) Eq. Mud Weight (lb /gal) Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 11P*1 Eni E &P Division I We11 Name: 0P23 -W 402 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • APIIUWI: 50- 029 -23411 -00-00 e n o Date: 5/1/2010 - Report ft; 27 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share (%) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) I Water Depth (ft) RKB - Base Flange (ft) IRKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LA RIG Job Information Wellbore 'Job Phase 'Spud Date 'Target Depth (ftKB) 'Target Depth (TVD...I Depth Dr. (MD) (ft) 'Drilling Hours (hr) !Avg ROP (ft/hr) I DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 27.00 Daily Information End Depth (ftKB) ! End Depth (TVD) (1..I Depth Progress (ft)' Drilling Hours (hr) 'Avg ROP (ft/hr) I POB !Temperature (°E) !Weather Weather ! Wind 12,323.0 9,549.5 0.00 95.0 18.7 Cloudy. WC 00.3 39 NE i§ 27 mph Daily summary operation 24h Summary Ran TCL MDT logs. Tripped out of the hole after MDT tool failed. Operation at 07.00 Tripping out of the hole. Mud losses are minimal. 24h Forecast Trip out of the hole. Lay down MDT tools. Perform BOPE test. At 0100 notified John Crisp Moth AOGCC of todays BOPE test. John Crisp waived witnessing the test. Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) 10.40 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 0000 15:00 15.00 15.00 DRILL J 11 P Performed TCL MDT logging pressure settings. Pressure readings taken at 11,311; 11,313 11.560 11,576: 11,593. 11,612. 11,620. 11,636: 11,656. 11,678 11,693 11,715' 11.736 11,758' 11,782 11,800' 11862: 11,882. 11914 11,937. 11,975 11,996 12,018 12.037 12,109. 12,129. 12,155. UP = 295 DN = 200 Total mud losses 11 bbls, 1500 16.00 1.00 16.00 DRILL J 11 P Performed TCL MDT logging pressure settings. Pull out of hole and took sample at 12 „018, MDT tool not working. 16.00 17:00 1.00 17.00 DRILL J 11 P Pull out of hole to 11,677 ft. Run in hole to 12,018 ft. UP =295 DN =190 10 17.00 00:00 + 7.00 24,00 DRILL J 11 P Performed TCL MDT logging pressure settings. Pressure settings taken at 12,018 and 11,682. MDT tool did not work. Tried taking sample at 11,863. MDT tool did not work. At 0400. Pulling out of hole after MDT tool failure. Lost small piece of metal in hole. Possibly from side entry sub. Piece is 1 1/2” wide x 3 1/2" long x 12" thick. Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goedich ENI Drilling Supervisor 907- 670 -8623 907 - 441 -6585 Eni representative Bemie Leas ENI Rig Clerk 907 - 670 -8607 907 - 575 -9427 1 1 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keeneraempetroleum.com 907 - 670 -8623 907 - 715 -6434 Eni representative Michael Seward ENI DI. FOC. Adv. 907- 952 -7880 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 9 5/8 8.681 L80 -2.1 9,087.0 4/24/2010 Last Leakoff Test Depth (ftKB) ITVD (ftKB) (Fluid Type 'Fluid Density (Iblgal) IP Surf Applied (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 Eni E &P Division (Well Name: OP23 -'1W02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq rat* p• API/UWI: 50 -029- 23411 -00 -00 II Date: 5/2/2010 •Report #: 28 page 1 of 1 Welibore name: OP23 -WW02 Well Header Oliktok Point Permit/Concession N° ' ENI PETROLEUM /ENI Share (�) 100.00 RECT ONAL Configuration type Rotary Table Elevation (ft) I Ground Level (ft) [Water Depth (ft) I RKB - Base Flange (ft) ' RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA ' NABORS 245 E LAND RIG Job Information Welibore Job Phase 'Spud Date 'Target Depth (ftKB) 'Target Depth (TVD.. .I Dr. (MD) (ft) (Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 28.00 Daily Information End Depth (ftKB) End Depth (TVD) (f..1 Depth Progress (ft) I Drilling Hours (hr) 'Avg ROP (Mr) I POB I Temperature ( °F) Weather I Wind 12,323.0 9,549.5 0.00 92.0 15.4 Cloudy. WC -0.6 25 NNE @ 17.4 mph Daily summary operation 24h Summary Trip out of hole with MDT logging tools. Layed down logging tools. Conducted BOPE test. Picked up BHA. Ran in hole with clean out assembly. Operation at 07.00 Tnpping in hole with clean out assembly. 24h Forecast Tnp in hole with clean out assembly. Circulate and condition hole. Pull out of hole, Run 7" liner. Lithology 'Shows I MAASP Pressure (psi) 'Mud Weight (lb/gal) 10.40 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. gr 00'00 02 30 2.50 2.50 DRILL E 4 P Tripped out of hole from 11,863 ft to 9,059 ft. UP = 290 02 30 04:30 2.00 4.50 DRILL E 4 P Pulled out of the hole with wireline. Dropped a 2 -3/8" x 1 -1/2" x 1/2" of metal down the hole, Rigged down sheaves. '04.30 09:00 4.50 9.00 DRILL E 4 P Tripped out of the hole from 9,059 ft. 09 00 11:30 2.50 11.50 DRILL E 5 P Layed down Schlumberger logging tools. Clean rig floor. 11 30 13'00 1.50 13.00 DRILL E 5 P Remove wear bushing. Pull wear ring. Set the test plug. 13:00 22:00 9.00 22.00 DRILL E 11 P Tested BOPE with 5 ", 4 -1/2 ", 3 -1/2" test joints. Tested all to 250 psi low / 5,000 psi high. Tested annular with 3-1/2" to 60 1' 250 psi low / 3,500 psi high. Draw down test 2,925 psi / 1,950 psi / 200 psi 34 seconds, 3,000 psi 185 seconds. Blow down and drain stack. 22:00 22'30 0.50 22,50 DRILL E 5 P Remove wear bushing. Layed down test plug. 22.30 00'00 1.50 24.00 DRILL E 4 P Clean ng floor. Pick up BHA. Trip in hole with clean out assembly. At 0400 Trip in hole with clean out assembly. Daily Contacts , Position Contact Name Company Title E-mail Office Mobile Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Dulling Supervisor 907 -670 -8623 907- 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907- 575 -9427 Eni representative Pete Adams ENI Dnlling HSE 907- 670 -8624 907-440-0806 Eni representative Jack Keener ENI Dnllmg Supervisor lack.keener@enipetroleum.com 907- 670 -8623 907- 715 -6434 Eni representative Michael Seward ENI Drlg Fac Adv. 907- 952.7880 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date CASING 9 5/8 8.681 L80 -2.1 9,087.0 4/24/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) 'Fluid Type 'Fluid Density (Iblgal) IP Surf Applied (psi) Eq. Mud Weight (Iblgal) Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 Eni E&P Division 'Well Name: OP23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq Vii* • APIIUWI: 50 -029 - 23411 -00 -00 1 Date: 5/3/2010 -Report #: 29 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share ( %) !Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) !Ground Level (ft) 'Water Depth (ft) (RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.201 12.20 31.50 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA I NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date (ftKB) Target Depth (TVD.. Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ftlhr) DFS (days) OP23 -W W02 I DRILLING 4/5/2010 'Target Depth 12,369.01 9,753.41 12,323.001 216.341 57.01 29.00 Daily Information End Depth (ftKB) End Depth (TVD) (f.. Depth Progress (ft) [Drilling Hours (hr) "Avg ROP (ft/hr) I POB I Temperature (°F) I Weather I Wind 12,323.0 9,549.5 0.00 90.0 16.3 Cloudy. WC +13.3 15 NNE @ 2.2 mph Daily summary operation 24h Summary Tnpped in hole for dean out run. Serviced dnlling rig. Circulated and conditioned mud and hole for 7" casing run. Operation 0107.00 Tripping out of hole for 7" casing run. 24h Forecast Tnp out of hole, Lay down BHA #7. Rig up and run 7" liner. Lithology IShows MAASP Pressure (psi) 'Mud Weight (Iblgal) 10.30 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00.00 01:30 1.50 1.50 DRILL E 4 P Pick up BHA. Make up clean out assembly to 503 ft. 01:30 0830 7.00 8.50 DRILL E 4 P Trip in hole from 503 ft. Pick up 9-5/8" casing scraper. Trip in hole from 3,223 ft. to 9,029 ft. Fig pipe at 3,287 ft. at 250 GPM and 239 PSI. Fill pipe at 6,252 8. at 250 GPM and 330 PSI. Fill pipe at 9,029 11. at 250 GPM and 460 P51, 08:30 10.00 1.50 10.00 DRILL E 4 P Slip and cut 96 ft. of drilling line. le 10:00 10.30 0.50 10.50 DRILL E 4 P Service top drive, drawworks, and crown. 1030 1200 1.50 12.00 DRILL E 4 P Tnp in hole from 9,029 N. to 10,850 ft. Total mud losses for previous 12 hours = 42 barrels. 12:00 1430 2.50 14.50 DRILL E 4 P Trip in hole with clean out BHA #7 with 9-5/8" casing scraper. Tag bottom at 12,323 ft. UP = 290 DN = 180. 14:30 21 30 7.00 21.50 DRILL E 7 P Circulate and condition mud and hole. Circulate at 450 GPM, 1,900 PSI, 44,030 strokes. UP = 300 DN = 195. Mud weight = 10,2+ in and out. 21:30 00.00 2.50 24.00 DRILL E 4 P Trip out of hole to 10,040 ft. Monitor well for swabbing. UP = 310 DN = 190. At 0400 Tripping out of hole for 7" casing run. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Alvin Cnswell ENI Expediter 907- 980 -7545 Eno representative Gary Goerlich ENI Drilling Supervisor 907 -670 -8623 907- 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907 -670 -8607 907- 575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907440.0806 Eni representative Jack Keener ENI Dulling Supervisor /ack.keener@empetroleum.com 907 -670 -8623 907 - 715 -6434 Eni representative Michael Seward ENI Orig. Fac. Adv. 907 -952 -7880 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (kKB) ITVD (ftKB) (Fluid Type 'Fluid Density (lb /gal) I P Surf Applied (psi) I Eq. Mud Weight (Iblgal)' Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 rok, Eni E &P Division 'Well Name: OP23 -1AAW02 E NI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq i Date: 5/4/2010 - Report #: 30 API /UW I: 50.029- 23411 -00 -00 �`- page 1 of 1 Welibore name: OP23 -WW02 Well Header PermitJConcession N° !Operator I ENI Share ( %) [Well Configuration type Oliktok Point ENI PETROLEUM 1 00.00 DIRECTIONAL Rotary Table Elevation (ft) !Ground Level (ft) I Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA [ NABORS 245 E LAND RIG Job Information Welibore Job Phase 'Spud Date 'Target Depth (ftKB) 'Target Depth (TVD.. JDepth Dr. (MD) (ft) [Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 30.00 Daily Information End Depth (ftKB) End Depth (TVD) (f..I Depth Progress (ft) 'Drilling Hours (hr) 'Avg ROP (ft/hr) IPOB 'Temperature (°F) 'Weather Weather [Wind 1 9,549.5 0.00 99.0 15.1 Cloudy, WC +11.3 308 NW (g 2.4 mph Daily summary operation 24h Summary Completed clean out nun. Tripped out of the hole and Iayed down the casing scraper and BHA. Tested the top rams to 250 psi low and 5,000 psi high. Rigged up the torque turn and casing tools. Ran 7" 26# Vam top 13Cr liner, Operation at 07.00 Running in hole with 7" 26# Vam top 13Cr liner. 24h Forecast Run in hole with 7" 266 Vam top 13Cr L80 liner. Cement liner. Lithology 'Shows I MAASP Pressure (psi) 'Mud Weight (lb/gal) 10.25 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00 00 05 30 5.50 5.50 DRILL E 4 P Trip out of hole from 10,040 8 to 3,217 R. Lay down scraper and cross overs. 05 30 0700 1.50 7.00 DRILL E 4 P Lay down 8 -1/2" BHA. Stand back HWDP, jars, drill collars, 2 stabilizers, and bit Clear and clean the rig floor. 07.00 07.30 0.50 7.50 DRILL E 4 P Remove the wear bushing. Pull the wear ring. / 8� 07:30 10.00 2.50 10.00 DRILL E 4 P Rig up 7" test joint. Torque up 7" x 4 -1/2" cross over. Rig up testing equipment. Test top rams to 250 psi low and 5,000 1/ V psi high. Set the wear ring. 10:00 14 00 4.00 14.00 DRILL E 5 P Pick up torque tum equipment. Rig up casing toots. Rig up to run 7" liner L80 Vam top thread With electronic torque control. 14:00 2230 8.50 22.50 DRILL E 4 P Run in hole with 7" , 26# Vam top 13Cr L80 liner. Run liner using torque turn. Run in hole at 40 seconds per joint. Take up and down weights every 10 Joints. 22.30 23:30 1.00 23.50 DRILL E 4 P Make up hanger. Put Pal Mix in hanger. 2330 00:00 0.50 24.00 DRILL E 7 P Circulate and condition the hole. Circulate hanger volume at 210 GPM, 350 P51, 1,400 Strokes, At 0400: Running in hole with 7" 26# Vam top 13Cr L80 liner. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Alvin Criswell ENI Expediter 907 - 980 -7545 Eni representative Gary Goertich ENI Dulling Supervisor 907-670-8623 907- 441 -6585 Eni representative Bemie Leas ENI Rig Clerk 907-670-8607 907- 575 -9427 Eni representative Pete Adams ENI Dulling HSE 907-670-8624 907 - 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor Jack.keener©enipetroleum.com 907-670-8623 907-715-6434 En: representative Michael Seward ENI Ddg. Fac, Adv. 907 -952 -7880 Eni representative Joe Longo ENI Drilling Engineer Joe.longo @enipetroleum.com 907 -670 -8623 907- 947 -4323 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (RKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) Fluid Type I Fluid Density (Iblgal) I P Surf Applied (psi) Eq. Mud Weight (lb/gal) I Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10,30 1,7000 15.21 5,266.8 11111 ilk VIC* Eni E &P Division I Well Name: OP23 -W W02 ENI Petroleum Co. Inc. Daily Repo Well Code: 23635 Field Name: Nikaitchuq • API /UWE 50-029-23411-00-00 en 0 Date: 5/5/2010 - Report #: 31 �' I' page 1 of 1 Welibore name: OP23 -VWV02 Well Header Permit/Concession N° 'Operator I ENI Share ( %) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) 'Ground Level (ft) I Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA I NABORS 245E LAND RIG Job Information Wellbore Job Phase I Spud Date 'Target Depth (ftKB)' Target Depth (TVD...I Depth Dr. (MO) (ft) I Drilling Hours (hr) [Avg ROP (ft/hr) I DFS (days) 0P23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323,00 216.34 57.0 31.00 Daily Information End Depth (ftKB) End Depth (TVD) (f.. Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB Temperature ( °F) Weather Wind 12,323.0 9,549.5 0 00 114.0 4.1 Cloudy. WC -1.5 213 SSW @ 2.6 mph Daily summary operation 24h Summary Ran 7" 269 Vam top 13Cr liner.Tnp out of hole. Rig up Schlumberger wireline. Operation at 07.00 Rig up Schlumberger ■ireline. Conduct VSP surveys. 24h Forecast Test casing. Rig up Schlumberger ■nreline. Conduct VSP surveys. Lithology I Shows I MAASP Pressure (psi) I Mud Weight (Iblgal) 10.30 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00 00 00.30 0.50 0.50 DRILL E 7 P Circulate liner volume. 220 GPM 350 PSI UP = 115 DN = 105 10 RPM TO 2K ROT 115. 00.30 06'00 5.50 6.00 DRILL E 4 P Run in hole from 498 fl. to 9,050 fl. Fill every 10 stands, f 06.00 11'00 5.00 11.00 DRILL E 7 P Circulate and condition hole. Displace liner and drill pipe volume. 200 GPM 470 PSI UP = 215 DN = 150 10 RPM TO c r" 6K Make up cement head and cement circulating line. Jr 11:00 12 00 1.00 12.00 DRILL E 7 P Circulate and condition hole. Stage pumps up to 212 GPM at 950 PSI. UP = 300 DN = 180 Attempt to rotate at 10 RPM. / 1 /1 String stalled at 10K TO. Total losses for the tour 80 bbls. ""'N !/ 12:00 14'30 2,50 14.50 DRILL E 7 P Circulate and condition hole. Held PJSM with Schlumberger. All hands involved. ' 1 of 14:30 15:30 1.00 15.50 DRILL E 19 P Pump 5 bbls water. Test lines to 4,500 PSI. Batch mix 40 bbls of 13.4 ppg mud push. 15.30 1600 0.50 16,00 DRILL E 9 P Pump 40 bbls. mud push. Pump 105 bbls. of Bass G 15.8 ppg cement slurry. 16.00 16:30 0.50 16.50 DRILL E 9 P Flush cement from lines and above plug. Release dart from head. 16:30 17:00 0.50 17.00 DRILL E 9 P Displace with rig pumps at 7 BPM. Caught cement at 146 bbls. Did not see dart latch in. Displace liner and bump plug to 3200 PSI.Increase pressure to 4200 PSI. Release running tool. Bleed off pressure and check floats. Remove hose from head, Cement in place at 1700 hours. 17:00 18.00 1.00 18.00 DRILL E 9 P Pressure up on packer. Set same and pull out. Flush liner and circulate bottoms up. 18.00 19:00 1.00 19.00 DRILL E 7 P Circulate and condition hole. Circulate bottoms up. 19 00 20:00 1.00 20.00 DRILL E 7 P Break down bottom cement head. Lay down cement head. 20'00 21 00 1.00 21.00 DRILL E 4 P Trip out of hole from 8.858 ft to 8,665 ft. Reciprocate pipe and circulate bottoms up. 21:00 00:00 3.00 24.00 DRILL E 4 P Trip out of hole from 8,665 ft to 4,905 ft, Run in hole 4 stands 5" HWDP to 5,281 ft. At 0400' Testing casing. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Gary Goedich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Bemie Leas ENI Rig Clerk 907- 670-8607 907- 575 -9427 Eni representative Pete Adams ENI Dnlling HSE 907 -670 -8624 907 - 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keener®enipetroleum.com 907-670-8623 907 -715 -8434 Eni representative Michael Seward ENI Drig. Fac. Adv. 907 -952 -7880 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907 -670 -8623 907 - 947 -4323 Eni representative Greg Parker ENI Expediter 907 - 980 -7545 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Rum Date 1 LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) 'Fluid Type 'Fluid Density (Iblgal) I P Surf Applied (psi) I Eq. Mud Weight (Iblgal) Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 fill* Eni E &P Division (Well Name: OP23 -WWO2 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • APIIUWI: 50-029-23411-00-00 ,� n o Date: 5/6/2010 - Report #: 32 ( . (� page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share ( %) 'Well Configuration type Oliktok Point ENI PETROLEUM 100,00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) [Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA I NABORS 245E LAND RIG Job Information Wellbore Job Phase 'Spud Date 'Target Depth (ftKB) 'Target Depth (TVD..I Depth Dr. (MD) (ft) I Drilling Hours (hr) !Avg ROP (ftlhr) I DFS (days) OP23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.4 12,323.00 216.34 57.0 32.00 Daily Information End Depth (ftKB) End Depth (TVD) (f..' Depth Progress (ft) ! Drilling Hours (hr) 'Avg ROP (ft/hr) I P" ' Temperature (°F) !Weather ' Wind 12,323.0 9,549.5 0.00 99.0 5.4 Cloudy. WC +5.4 155 SSE 1 mph Daily summary operation 24h Summary Tripped out of hole. Layed down liner running tool. Tested casing shoe, liner, and liner lap to 1,500 PSI for 30 minutes. Rigged up Schlumberger wireline. Ran VSP logs. Operation at 07.00 Working on ng brakes. Change over to brine mud system. 24h Forecast Complete VSP surveys. Work on ng brakes. Change over to bone mud system. Perforate well. Run completion. Lithology 'Shows MAASP Pressure (psi) I Mud Weight (Iblgal) 10.40 Time Log Start End Cum Time Time Dur(hr) Dur (hr) Phase Opr. Act. Plan Oper. Deter. 00:00 03.30 3.50 3.50 DRILL E 4 P Tnp out of hole. Lay down HWDP from 5,261 ft. to 4,905 R. Lay down liner running tool. 03:30 04:30 1.00 4.50 DRILL E 4 P Pressure test casing shoe, liner and liner lap to 1,500 PSI for 30 minutes. 04:30 05:30 1.00 5.50 DRILL E 11 P Rig up Schlumberger wire line. Load pipe shed with logging tools. 05:30 00:00 18.50 24.00 DRILL E 11 P Run VSP logs. Clean pits and perform general cleaning and maintenance on rig. Daily Contacts _ Position Contact Name Company Title E-mail Office Mobile Eni representative Gary Goeriich ENI Drilling Supervisor 907- 670 -8623 907 - 441 -6585 Eni representative Bemie Leas ENI Rig Clerk 907- 670 -8607 907- 575 -8427 Eni representative Pete Adams ENI Drilling HSE 907-670-8624 907 - 440 -0806 V Eni representative Jack Keener ENI Dnlhng Supervisor lack.keenertenipetroleum.com 907-670-8623 907.715 -6434 Eni representative Michael Seward ENI Drlg. Fac. Adv. 907 - 952 -7880 Eni representative Joe Longo ENI Dnfing Engineer 1oe.longo@enipetroleum.com 907- 670 -8623 907-947-4323 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (ftKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883,4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) 'Fluid Type I Fluid Density (lb/gal) IP Surf Applied (psi) Eq. Mud Weight (lb/gal) I Leak Off Pressure (psi) 9,170.0 6,666.12 VC -O8M 10.301 1,700.0 15.21 5,266.8 0 40 VII* Eni E &P Division ( Well Name: OP23 -W W02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq I, Ic, n Date: 517/2010 - Report #: 33 APIIUWI: 50-029 - 23411 -00 -00 (�I� l� II page 1 of 1 Wellbore name: OP23 -WW02 Well Header Oliktok Point Permit/Concession N° 'Operator ENI PETROLEUM 'ENI Share (%) 100.00 RECT ONAL Configuration type Rotary Table Elevation (ft) I Ground Level (ft) [Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor I Rig Name Rig Type NABORS ALASKA !NABORS 245 E I LAND RIG Job Information Wellbore Job Phase I Spud Date 'Target Depth (ftKB) 'Target Depth (TVD..' Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) 0P23 -WW02 DRILLING 4/5/2010 12,369.0 9,753.41 12,323.00 216.34 57.0 32.33 Daily Information End Depth (RKB) End Depth (TVD) (f.. Depth Progress (ft) Drilling Hours (hr) 'Avg ROP (ft/hr) IPOB Temperature (°F) Weather Wind 12,323.0 9,549.5 0.00 101.0 5.4 Cloudy. WC +5.4 155 SSE / 1 mph Daily summary operation 24h Summary Completed VSP logging program. LD VSP logging tools and RD Schlumberger vireline Operation at 07.00 RIG RELEASED TO COMPLETION - 05/07/2010 08'.00 HRS 24h Forecast RIG RELEASED TO COMPLETION - 05/07/2010 08.00 HRS Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (lb /gal) 10.40 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Dearer. 00 00 06.00 6.00 6.00 DRILL J 19 P LOGGING - Contiune running VSP 06.00 08'00 2.00 8.00 DRILL J 5 P LOGGING - LD VSP logging tools and RD Schlumberger vdreline. RIG RELEASED TO COMPLETION - 05/07/2010 08'00 HRS Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Gary Goertich ENI Drilling Supervisor 907- 670 -8623 907 - 441 -6585 Eni representative Tom Norvig ENI Rig Clerk 907 - 670 -8607 907 - 229 -6100 Eni representative Pete Adams ENI Dnlling HSE 907- 670.8624 907- 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keenerr empetroleum.com 907- 670 -8623 907 - 715 -6434 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907- 952 -7880 Eni representative Joe Longo ENI DnIkng Engineer joe.longo@empetroleum.com 907 - 670 -8623 907- 947 -4323 / Eni representative Greg Parker ENI Expediter 907- 980 -7545 ✓ Last Casing seat Cas. Type OD (in) ID (in) Grade Top (RKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) Fluid Type 'Fluid Density (lb/gal) I P Surf Applied (psi) I Eq. Mud Weight (lb/gal) I Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 I Ent E &P Division 'Well Name: OP23 -W W02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • .410 1F* • Date: 517/2010 -Report #: 1 APIIUWI: 50 -029- 23411 -00-00 n II page 1 of 1 Wellbore name: OP23 -WWO2 Well Header PennitlConcession N I Operator I ENI Share (%) I Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) 'Water Depth (ft) RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase Spud Date 'Target Depth (ftKB) [Target Depth (TVD..lDepth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) OP23 -WW02 COMPLETION 12,323.0 9,709.0 32.06 Daily Information End Depth (RKB) [End Depth (TVD) (f.. Depth Progress (ft) 'Drilling Hours (hr) 'Avg ROP (ft/hr) 1POB Temperature ( °F) !Weather 'Wind 12,323.0 0.0 I 105.0 1,9 Cloudy WC -8.5 4.7 mph Daily summary operation 24h Summary Change out brake band on dravwvorks. Test casino to 3000 psi - Good Test. PJSM on picking up Schlumberger pert guns. PU perf guns and SlimPulse LWD, TIH on 3-1/2" 13.3# G105 DP to 940' MD. Shallow Test SlimPulse Tool - Good Test. There was a reportable hydraulic oil spill at approximately 16:40 hours. A PGS off road Steiger tractor suffered a broken hydraulic hose causing a spill of 5 -8 gallons of fluid to reach the sea ice. ACS, assisted by PGS onsite personnel completed the removal of contaminated ice /snow. Operation at 07.00 TIH with 4 -112" pert guns on 3 -1/2" x 5" DP. Current Depth' 4132' MD / 04.00 hrs 24h Forecast Continue TIH with 4 -1/2" pert guns on 3-1/2" x 5" DP, Condition hole for perforating. Correlate on depth with SlimPulse LWD. Perforate well and POOH. Lithology 'Shows I MAASP Pressure (psi) 1 Mud Weight (Iblgal) 10.40 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr, 08'00 15.30 7.50 7.50 COMP J 25 P SERVICE RIG - Change out brake bands on drawwarks. 15'30 18'00 2.50 10.00 COMP K 19 P CASING TEST - Test casing to 3000 psi for 30 min - Good Test. 18 00 21 00 3.00 13.00 COMP K 1 P RU - PJSM o picking up perforation guns. PU 200' 4 -1/2" Perf gun and SlimPulse LWD tool. 4 -1/2" Perforation Guns. - Total footage loaded 120' ICI - 5spf 21.00 23'00 2.00 15.00 COMP K 4 P TRIPPING - TIH to 940' MD with 4 -1/2" Pert guns on 3 -1/2" 13,30# G105. 23 00 00.00 1.00 16.00 COMP K 7 'P CIRCULATION - Shallow test SlimPulse LWD tool - Good Test. -182 GPM, 300 psi.,, Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Greg Parker ENI Expediter 907 -980 -7545 Eni representative Jack Keener ENI Drilling Supervisor jack.keenert enipetroleum.com 907 -670 -8623 907 - 715 -6434 Eni representative Jack Potter ENI Drilling HSE 907 -670 -8624 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907 -670 -8623 807- 947 -4323 Eni representative Michael Seward ENI Drlg. Fac. Adv. 907- 952 -7880 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (RKB) 'TVD (ftKB) Fluid Type ' Fluid Density (Ib /gal) I P Surf Applied (psi) I Eq. Mud Weight (lb/gal) I Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 r IFAIIII Eni E&P Division 1 'Well Name: 0P23 -W W02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikadchuq Date: 5/8/2010 - Report #: 2 API /UWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Oli Point Permit/Concession N° !Operator ENI PETROLEUM IENI Share (%) 100.00 !Well ECTIONAL Configuration type Rotary Table Elevation (ft) 'Ground Level (ft) 'Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA I NABORS 245 E LAND RIG Job Information Wellbore (Job Phase Spud Date 'Target Depth (ftKB) (Target Depth (TVD...I Depth Dr. (MD) (ft) I Drilling Hours (hr) 'Avg ROP (ft/hr) IDFS (days) OP23 -WW02 COMPLETION 12,323.0 9,709.01 33.06 Daily Information End Depth (ftKB) 'End Depth (TVD) (f.. Depth Progress (ft) 'Drilling Hours (hr) 'Avg ROP (ft/hr) I POB Temperature ( °F) Weather I Wind 12,323.0 0.0 92.0 9.1 Cloudy WC -8.9 17.5 mph SSE Daily summary operation 24h Summary Finish TIN to 12242' MD with 4-1/2" perf guns on 3-1/2" x 5" DP. Circulated and conditioned 10.4 ppg OBM. Cleaned pits, took on 9.7 ppg NaCI, and built sweeps for fluid displacement. Pumped 20 bbls LVT followed by 35 bbls 10.7 ppg weighted sweep. Operation at 07.00 Continue displacing 10.4 ppg OBM with 9.7 ppg NaCI. 24h Forecast Finish displacing 10.4 ppg OBM with 9.7 ppg NaCI. Correlate on depth with Schlumberger SlimPulse LWD, TIN back to bottom and spot 9.7 ppg pert pill. POOH to top perforation interval, perforate well and POOH laying down dnfl pipe. Lithology I Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) 10.50 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act, Plan Oper. Descr. 00:00 05'30 5.50 5.50 COMP K 4 P TRIPPING - Continue TIH with 4-1/r perf guns on 3 -1 /2" DP to 3609' MD. Continue TIH with 5" DP to 4088' MD 05:30 06'30 1.00 6.50 COMP K 1 P SERVICE RIG - Grease topdrive and set crownsaver/ floorsaver. 06:30 10 00 3.50 10.00 COMP K 4 P TRIPPING - Continue TIH with 4 -1/2" pert guns on 3 -12" x 5" DP f/ 4088' MD /1 float collar @ 12242' Mb 10:00 15.30 5.50 15.50 COMP K ' 7 P CIRCULATE - Circulate and condition 10,4 ppg OBM @ 4 bpm. -Indal Mud Properties - Funnel Vis = 150 s /qt -PV = 31 cp, YP = 11 Ibt/100ft "2 -Final Mud Properties - Funnel Vis = 81 s/qt -PV = 28 cP, YP = 616f/100002 -191 gpm, 940 psi 15 30 22 30 7.00 22.50 COMP K 1 P CIRCULATE - Continue to circulate and condition OBM. Clean pits, take on 9,7 ppg NaCI and prepare sweeps. 22 30 0000 1.50 24 00 COMP K 1 P CIRCULATE - PJSM on fluid displacement operations Pump 20 bbls LVT followed by 35 bbls 10.9 ppg weighted sweep. -55 gpm, 600 psi Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Jack Keener ENI Drilling Supervisor 1ack.keenertgenipetroleum.com 907 -670 -8623 907-715-6434 Eni representative Jack Potter ENI Drilling HSE 907 -670 -8624 Eni representative Joe Longo ENI Dnlling Engineer 1oe.longo@Jenipetroleum.com 907 -670 -8623 907- 947 -4323 Eni representative Michael Seward ENI Ddg. Fac. Adv. 907- 952 -7880 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907 - 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883,4 12,323.0 5/3/2010 Last Leakoff Test Depth (RKB) ITVD (ftKB) ' Fluid Type ' Fluid Density (lb /gal) I P Surf Applied (psi) Eq. Mud Weight (Iblgal) I Leak Off Pressure (psi) 9,170.01 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 • ' rit* Eni E &P Division 'Well Name: OP23 -WW02 ENI Petroleum Co. Inc. Daly Report Well Code: 23835 Field Name: Nikailchuq Date: 5/9/2010 - Report #: 3 API/UWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header PermitlConcession N° I Operator I ENI Share (%) I Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) 'Ground Level (ft) I Water Depth (ft) I RKB - Base Flange (ft) ' RKB - Tubing Spool (ft) 53 20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA ' NABORS 245 E I LAND RIG ',. Job Information Wellbore ' Job Phase Spud Date 'Target Depth (ftKB) /Target Depth (TVD..JDepth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ftlhr) I DFS (days) OP23 -WW02 COMPLETION 12,323.01 9,709.0 34.06 Daily Information End Depth (ftKB) End Depth (TVD) (f.. Depth Progress (ft) Drilling Hours (hr) Avg ROP (ftlhr) POB Temperature ( °F) Weather Wind 12,323.0 0.0 94.0 10.4 Cloudy, Light Snow, 22° NNE @ 5 mph WC 4.1° Daily summary operation 24h Summary Continue to pump spacers and displace well with 9.7 ppg NaCI. Prep and clean possum belly, Shakers and return trough to active pits for circulating. Correlate on depth with Schlumberger SlimPulse LWD f/ 12,108' V 12,037' @ 60' fph, made 4 passes. TIH to 12240' MD and spot 9.7 ppg hi vis pert pill. Line up choke manifold, reverse circulate, and establish base line for firing sequence. Test shot detection device - Good Test. Proceed thru pump sequence and fire guns - positive indication. POOH V 11.665' and monitor well for 30 min., static loss 2.4 bph. Cont. POOH to 8874', Circulate BU and monitor well with no static losses. Operation at 07.00 POOH Laying down 5" DP. Current Depth 5450 'MD @ 0400 24h Forecast POOH laying down 5" and 3 -1/2" DP Lithology 'Shows I MAASP Pressure (psi) 'Mud Weight (lb/gal) 9.70 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr, Act. Plan Oper. Descr. 00:00 04'00 4.00 4.00 COMP K 7 P CIRCULATE - Displace 10.4 ppg OBM. Pumped the follvang spacers chased by 9.7 ppg NaCI to displace the well. - Spacers Pumped: -30 bbls LVT -40 bbls 10.9 ppg weighted NaCI with Safe Surf 0 -30 bbls 9.7 ppg NaCI with 2 drums Safe Surf 0 -50 bbls 9.7 ppg viscosified NaCI 04 00 10'30 ' 6.50 10.50 COMP K 1 P MISCELLANEOUS - Clean shakers, possum belly, and pit #4. C/0 shaker screens. Service drawworks and iron ruffneck. 10 30 17:00 6.50 17.00 COMP K 1 P LOGGING - Correlate on depth with SlimPulse LWD, mark pipe (9 top perforation depth of 11845' MD, Made 4 passes @ 6055111/12108' MD V 12037' MD, GR Sensor 246.64' from bottom nose, -210 gpm, 650 psi 1700 1730 0.50 17.50 COMP K 4 P TRIPPING - TIH 5 12037' MD V 12240' MD 17 30 18:30 1.00 18,50 COMP K 7 P CIRCULATE - Spot 80 bbls 9.7 ppg hi vis pert pill. -233 gpm, 720 psi 18:30 19,00 0,50 19.00 COMP K 4 P TRIPPING - POOH to 12045.8' MD, Park guns and prepare to perforate. 19:00 23:30 4.50 23.50 COMP K 16 P PERFORATE - Test shock detection device - Good Test, Reverse circulate to clear all lines of air, Set super choke to 50% and establish baseline bleeding off thru gate valve. Go thru pump sequence, final pressure 3000 psi. Fire 4 -1/2" guns. Recieved positive indication shots were fired. POOH 4 stands to 11665' MD. Monitor well 30 min Static losses @ 2 74 / bph. POOH to 8872' MD. /e,,., / - Ivishak Perforation Intervals - 11845'MD- 11915'MD5 SPF - 11995' MD - 12045' MD 5 SPF 23:30 00:00 0.50 24.00 COMP K 7 P CIRCULATE - Circulate and monitor well @ 8872' MD, Circulation port @ 8646' MD. No Losses. Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Jack Keener ENI Dulling Supervisor 1ack.keener @enipetroleum.com 907 -670 -8623 907 -715 -6434 Eni representative Jack Potter ENI Dnlling HSE 907 -670 -8624 Eni representative Joe Longo ENI Drilling Engineer joe.longo@enipetroleum.com 907- 670 -8623 907- 947 -4323 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) 'TVD (ftKB) 'Fluid Type (Fluid Density (Iblgal FP Surf Applied (psi) Eq. Mud Weight (lb/gal) ' Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 41111 lip Eni E&P Division Well Name: 0P23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikadchuq ``- H tt In l Date: 5/10/2010 - Report #: 4 API/Le/VI: 50-029 -23411 -00.00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header PermitiConcession N I Operator I ENI Share ( %) I Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) 'Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore ' Job Phase 'Spud Date 'Target Depth (ftKB) !Target Depth (TVD.. J Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) OP23 -WW02 COMPLETION 12,323.0 9,709.01 35.06 Daily Information End Depth (ftKB) End Depth (TVD) (f.. Depth Progress (ft) Drilling Hours (hr) Avg ROP (f /hr) POB Temperature (-F) Weather Wind 12,323.0 0.0 90.0 9.7 Cloudy WC -4.9 26° NNE @ 10.5 mph Daily summary operation 2411 Summary POOH laying down with 4 -1/2" Guns on 3-1/2" x 5" DP. LD Schlumberger SlimPulse LWD and 4 -1/2" Guns. Test Choke 250/5000 psi - Good Test. Pull wear bushing, drain stack and set test plug. Begin testing BOPs 250/5000 psi. Operation at 07.00 Testing BOPS 250/5000 psi 24h Forecast Test BOPs 250/5000 psi. PU Halliburton retrievable bridge plug and TIH on 3 -1/2" x 5" DP 10 11745' MD. Set bndge plug and POOH LO DP. Lithology 'Shows I MAASP Pressure (psi) [Mud Weight (Iblgal) 9.70 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr, Act. Plan Oper. Descr. 00'00 01:30 1.50 1.50 COMP K 7 P CIRCULATE - Circulate bottoms up at 8872' MD (Liner Hanger at 8888' MD) -5 bpm, 700 psi. 0130 15.00 13,50 15.00 COMP K 4 P TRIPPING - POOH laying down 3 -1/2" x 5" DP from 8872' MD to 261' MD 1500 19:30 4,50 19.50 COMP K 5 P LD BHA/ GUNS - PJSM on laying down guns. LD Schlumberger SlimPulse LWD and perforation guns. Move all Schlumberger equipment off of floor. 19.30 2030 1.00 20.50 COMP K 5 P SERVICE - Swap over to 5" equipment. Preparing to TIH to LD 6405' 5" DP racked back. 2030 22 30 2.00 22.50 COMP K 12 P TEST BOP - Test choke 250/5000 psi- Good Test. PU and makeup test joint, pull wear bushing, dram stack and set test /� plug. F /"�i 2230 0000 1.50 24.00 COMP K 12 P TEST BOP - Begin to test BOPs 250/5000 psi 10'..- Daily Contacts Position Contact Name Company Title E-mail Office Mobile Em representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Jack Keener ENI Drilling Supervisor jack.keener@empetroleum.com 907- 670 -8623 907 - 715 -6434 001 representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Joe Longo ENI Dnlling Engineer joe.longo©enipetroleum.com 907 - 670 -8623 907 - 947 -4323 Eni representative Tom Norvig ENI Rig Clerk 907-670-8607 907 - 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) 'TVD (ftKB) Fluid Type 'Fluid Density (lb/gal) I P Surf Applied (psi) Eq. Mud Weight (Iblgal) 'Leak Off Pressure (psi) 9,170.0 6,666,12 VC -OBM 10.30 1,700.0 15.21 5,266.8 40 • WI Ilk En! E &P Division 'Well Name: 0P23 -W WO2 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • II Date: 5/11/2010 • Report #: 5 APIIUWI: 50 -029- 23411 -00 -00 page 1 of 1 Welibore name: OP23 -WW02 Well Header PennitiConcession N° 'Operator I ENI Share ( %) [Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) I Ground Level (ft) 'Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor I Rig Name I Rig Type NABORS ALASKA 'NABORS 245 E LAND RIG Job Information Wegbore Job Phase I Spud Date 'Target Depth (ftKB) 'Target Depth (TVD...I Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) OP23 -WW02 COMPLETION 12,323.0 9,709.0 36.06 Daily Information End Depth (ftKB) 'End Depth (TVD) (1..I Depth Progress (ft) 'Drilling Hours (hr) 'Avg ROP (fflhr) I POB Temperature ( °F) Weather I Wind 12,323.0 0.0 81.0 9.7 Cloudy WC -10.8 30° NNE @ 24 mph Daily summary operation 24h Summary Continue testing BOPE 250/5000 psi - Good Test. Unable to get a test on upper IBOP valve. CO IBOP and test 250/5000 psi - Good Test. Made decision to run Baker Wireline Retrievable Bridge Plug. TIH 30 stands 5" DP. LO 80 jts. 5" DP. Operation at 07.00 RU Haliburton Wireline 24h Forecast RU Haliburton Wireline. RIH to 11745' MD/ 8977' TVD. Set Baker Wireline Retnevable Bridge Plug. Test to 2250 psi for 30 min. POOH and RD Haliburton WL equipment. Run 2500' 4-1/2" 12.64 13CrL80 Tubing and freeze protect. Lithology I Shows MAASP Pressure (psi) I Mud Weight (Iblgal) 9.70 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act, Plan Oper. Descr. 0000 07:00 7.00 7.00 COMP K 12 P TEST BOPE - Continue testing BOPE 250/5000 psi - Good Test. Witness waived by Chuck Scheve, Test IBOP - No Test. 07.00 09:00 2.00 9,00 COMP K 12 TRO5 TEST BOPE - LD test joint, blow down top drive and choke manifold. Pull test plug and install wear ring 09:00 09:30 0.50 9.50 COMP K 12 TRO5 TEST BOPE - Test IBOP - No Test. RD testing equipment. 0930 12:00 2.50 12.00 COMP K 12 TRO5 TEST BOPE - PJSM on CO upper 'BOP Valve. CO upper IBOP Valve. /► � 12:00 14:30 2.50 14.50 COMP K 12 TRO5 SERVICE RIG - Service Choke (. P 14.30 15:00 0.50 15.00 COMP K 12 TRO5 TEST BOPE - Test IBOP 250/5000 psi - Good Test 1 ✓ 15.00 16:30 1.50 16.50 COMP K 12 TRO5 SERVICE RIG - Service Choke 16'30 18'00 1.50 18.00 COMP ' K 21 P WOO - Wait on orders regarding wareline retrievable bndge plug. Prepare to TIH and LD 5" DP 18,00 20'00 2.00 20.00 COMP K 4 P TRIPPING - TIH 30 Stands 5" DP to 2968' 20.00 00:00 4.00 24.00 COMP K 4 P TRIPPING - LD 80 jts. 5" DP Daily Contacts Position Contact Name Company Tide E-mail Office Mobile Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Jack Keener ENI Drilling Supervisor jack.keener@empetroleum.com 907 -670 -8623 907 -715 -6434 Eni representative Jack Potter ENI Dulling HSE 907 -670 -8624 Eni representative Joe Longo ENI Dnlling Engineer 1oe.longocenipetroleum.com 907-670-8623 907 - 947 -4323 Eni representative Tom Norvig ENI Rig Clerk 907 -670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date LINER 7 6,276 13CrL80 8,883,4 12,323.0 5/3/2010 Last leakoff Test Depth (ftKB) I TVD (ftKB) 'Fluid Type I Fluid Density (Iblgal) IP Surf Applied (psi) Eq. Mud Weight (Iblgal) Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15,21 5,266.8 V* Eni E &P Division 'Well Name: OP23 -WW02 f ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • I� II Date: 5/12/2010 - Report #: 6 API /UWI: 50-029-23411-00-00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator ENI Share ( %) !Well Configuration type Ohktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) !Water Depth (ft) RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31,50 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA I NABORS 245 E LAND RIG Job Information Wellbore I Job Phase Spud Date 'Target Depth (ftKB) !Target Depth (TVD,..I Depth Dr. (MD) (ft) I Drilling Hours (hr) 'Avg ROP (ft/hr) IDFS (days) OP23 -WW02 COMPLETION 12,323.0 9,709.01 37.06 Daily Information End Depth (ftKB) 'End Depth (TVD) (t..' Depth Progress (ft) 'Drilling Hours (hr) 'Avg ROP (ft/hr) IPOB 'Temperature (°F) Weather I Wind 12,323.0 0.0 81.0 11.1 Cloudy WC -3.1° 5° N @ 11.9 mph Daily summary operation 24h Summary Continue LD 5" DP. Spot and RU Halliburton WL. MU Baker WLRBP. RIH to 8950' MD. Attempt to pull to 7" liner hanger @ 8888' MD/ 6481' TVD. WLRBP stuck @ 8897' MD/ 6487' TVD, Inc. 49.15 °. WOO. Set Baker WLRBP @ 8897' MD/ 6487' TVD, POOH WL. RD Halliburton WL. Clear floor and LD all 5" DP. RU Nabors 4 -1/2" Chrome tubing running equipment. Run 13 jts. 4 -1/2" 12.68 13CrL80 Vam Top tubing to 555' MD/ TVD Operation at 07.00 PU/ MU VetcoGray Tubing Hanger and land out 4-1/2" 12.6# 13CrL80 Vam Top Kill Stnng set @ 2568' MD/ 2470' TVD. Current Depth 2568' MD/ 2470' TVD 24h Forecast Continue running 4-1/2" 12.6# 13CrL80 Kill Stnng to 2568' MD. RD Tbg running equipment. Set BPV and ND BOPE. NU tree, pull BPV and set 2 way check. Test tree to 5000 psi. Pug 2 way check and freeze protect. Install and test BPV to 2000 psi. RDMO Lithology I Shows MAASP Pressure (psi) I Mud Weight (lb/gal) 9,70 Time Log Start End Cum `/ Time Time Dur (hr) Dur (hr) Phase Opr. Act Plan Oper. Descr. ` 4/ Y / /" 00:00 01:00 1.00 1.00 COMP K 4 P TRIPPING - Continue LD 5" DP. 01:00 02'00 1.00 2.00 COMP K 1 P RU - Spot Halliburton wireline unit and stage equipment on the floor. ° ° °°�L��..� 02:00 05:30 3.50 5.50 COMP K 1 P RU - PJSM on rigging up and running Halliburton wireline/ Baker WLRBP equipment. RU Halliburton sheave's, spool WL and MU Baker WLRBP. 05:30 09:30 4.00 9.50 COMP K 19 P WIRELINE - RIH with Raker WI RRP nn Halliburtnn WL to 8950' MD. Attempt to oull on to 7" liner hanner fo 8888' Mn/ 6481' TVO to make depth correction. WLRBP stuck @ 8897' MD/ 6487' TVD, Inc. 49.15 °. Max pulled 1900 lb - would not come free. Hold 1600 Ib, max safe pug - would not come free. WOO. 09:30 10.00 0.50 10.00 COMP K 23 U Decision made to set WLRBP @ stuck point - 8897' MD/ 6487' TVD. Set WLRBP - Recieved positive indication BP set. Pull up - Wireline free. 1600 11:00 1.00 11,00 COMP K 4 P POOH - POOH Halliburton WL. 1160 12:00 1.00 12.00 COMP K 5 P RD - RD Halliburton WL equipment 12:00 13:30 1.50 13.50 COMP K 12 P TEST WLRBP - RU to test Baker WLRBP on blind rams. Test Baker WLRBP to 3000 psi for 30 min.- Good Test. 1330 15:30 2.00 ' 15.50 COMP K 4 P TRIPPING - TIH 36 stands 5" DP 15:30 18 30 4.00 19.50 COMP K 4 P TRIPPING - POOH laying down 109 jts. 5" DP. 1930 20:30 1.00 20,50 COMP K 1 P RIG PREP - Pull and LD wear bushing, setting tool and test plug. Move 3 -1/2" DP equipment off the floor. 2030 22.30 2.00 22.50 COMP K 1 P RU - RU Nabors 4-1/2" Chrome tubing running equipment to set 4 -1/2" kill string 22.30 00'00 1,50 24.00 COMP K 4 P RUN TBG - Run 1311s. 4 -1/2" 12.68 13CrL80 Vam Top tubing to 555' MD/TVD. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Greg Parker ENI Expediter 907 - 980 -7545 Eni representative Jack Keener ENI Dulling Supervisor jack.keener @enipetroleum.com 907 -670 -8623 907 - 715 -6434 Eni representative Jack Potter ENI Drilling HSE 907 - 670 -8624 Eni representative Joe Longo ENI Dnlling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907 - 947 -4323 Eni representative Tom Norvig ENI Rig Clerk 907 -670 -8607 907 - 229 - 6100 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883,4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) Fluid Type 'Fluid Density (lb/gal) IP Surf Applied (psi) Eq. Mud Weight (lb/gal) I Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 fri* Eni E &P Division 'Well Name: OP� 02 ENI Pe(roieum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • APW1M: 50- 029 -23411 -00-00 Date: 5/13/2010 - Report #: 7 page 1 of 1 Welibore name' OP23 -WW02 Well Header Oliktok Point Permit/Concession N° ' PETROLEUM 'ENI Share (%) 100.00 DIRECT ONAL lion type Rotary Table Elevation (ft) ' Ground Level (ft) 'Water Depth (ft) RKB - Base Flange (ft) IRKS - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Welibore 'Job Phase Spud Date 'Target Depth (ftKB) 'Target Depth (TVD../ Depth Dr. (MD) (ft) I Drilling Hours (hr) 'Avg ROP (ft/hr) IDES (days) OP23 -WW02 COMPLETION 12,323.0 9,709.01 38.06 Daily Information End Depth (ftKB) I End Depth (TVD) (f..' Depth Progress (ft) I Drilling Hours (hr) 'Avg ROP (fVhr) I POB (Temperature ( °F) 'Weather ' Wind 12,323.0 0.0 83.0 18.3 Cloudy WC +9,1 72° ENE @ 6.8 mph Daily summary operation eu',' 24h Summary Ran 60 jts. 4 -1/2" 12.68 13CrL80 Vam Top tubing set (4 2568' MDI 2470' TVD. RD Nabors chrome casing running equipment and test upper and lower hanger seals to 5000 psi for 10 min - Good Test. Ki ( ND BOPE and NU VetcoGray tree. Pug BPV and install 2 way check. Test hanger void and tree to 5000 psi for 10 min - Good Test. Pull 2 way check and install BPV. RU Little Red Services and test BPV to 2000 psi for 45 min - Good Test (Witnessed by Bob Noble). Pump 170 bbl diesel freeze protect taking returns to pits. RD Little Red Services and normal up tree. Prepare for nit move. ....! Operation at 07.00 RIG RELEASED TO OPO4 -07 g 5/14/2010 00:00 HRS. ki/4- ( r 24h Forecast RIG RELEASED TO OPO4 -07 o 5/14/2010 00'00 HRS. Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (lb/gal) 01j%. 9.70 n" Time Log ( � n Start End Cum • �'/ Time Time Dur (hr) Dur (hr) Phase Opr. Act Plan Oper. Descr. 00.00 03:30 3.50 3.50 COMP K 4 P RUN TBG - Continue running 4 -1/2" Kill Stnng. Ran 60 jts. 4 -1/2" 12.6# 13CrL80 Vam Top tubing. 03:30 04:30 1.00 4.50 COMP K 1 P RUN TBG - PU MU VetcoGray tubing hanger and set BPV. Land tubing hanger and set lock down screws. 0e .s /p 4 -1/2" 12.68 13CrL80 Vam Top Kill String set @ 2568' MD/ 2470' TVD. 04 30 05:30 1.00 5.50 COMP K 5 P RD TBG EQUIP. - RD Nabors 4 -1/2" chrome tubing running equipment and clear floor Test upper and lower hanger seals Y to 5000 psi each- Good Test, 05.30 12:00 6.50 12.00 COMP K 5 P ND BOPE - PJSM on ND BOPE. ND BOPE and VetcoGray riser, set back same. 1 ,.,t l 12.00 13:00 1.00 13.00 COMP K 12 P NU TREE - NU VetcoGray tree and install 2 way check. Test hanger void to 5000 psi for 10 min - Good Test. Test tree to 5000 psi for 10 min - Good Test. 13 00 15:00 2.00 15.00 COMP K 5 P RU - Pull 2 way check and install BPV. RU hoses and Little Red Services. 15'00 16:00 1.00 16.00 COMP K 12 P TEST BPV - Test BPV to 2000 psi for 45 min. - Good Test, Test witnessed by Bob Noble. Start 15min 30min 45min TBG (psi) 0 0 0 0 IA (psi) 0 2000 2000 2000 OA (psi275 400 400 400 16'00 18.30 2.50 18.50 COMP K 9 P FREEZE PROTECT - Pump 170 bbls diesel freeze protect in 9 -5/8" x 4 -1/2" IA with Little Red Services taking retums to pits. 18 30 20:00 1.50 20.00 COMP K 5 P RD - RD Little Red Services. Blowdown circulating hoses and RD Same. Normal up VetcoGray wellhead. 20 00 23'00 3.00 23.00 COMP K 1 P RDMO - Clean out mud system, move overboard cuttings tank and set diverter line. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Greg Parker EN1 Expediter 907- 980 -7545 Eni representative Jack Keener ENI Dnlling Supervisor jack.keener@enipetroleum.com 907 - 670 -8623 907 - 715 -6434 Eni representative David Smith ENI Drilling Supervisor 907 -670 -8623 Eni representative Jack Potter ENI Dnlling HSE 907 -670 -8624 Eni representative Bernie Leas ENI Rig Clerk 907 -670 -8607 907- 575 -9427 Eni representative Joe Longo ENI Drilling Engineer joe.longo(genipetroleum.com 907- 670 -8623 907-947-4323 Eni representative Mike Nelson ENI HSE Mike.Nelson (genipetroleum.com 907- 685 -1227 Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907-229-6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (RKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323,0 5/3/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) I Fluid Type 'Fluid Density (lb/gal) I P Surf Applied (psi) Eq. Mud Weight (lb/gal) Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 , IIP • Vil RS Eni E &P Division Well Name: OP2� `r V02 EN! Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikanchuq ,,�, • Date: 10118/2010 - Report #: 8 WI: 50-029-23411-00-00 ��� ����'I page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator ENI Share ( %) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) Ground Level (ft) Water Depth (ft) RKB - Base Flange (ft) RKB - Tubing Spool (ft) 53.20 12.201 31 33.25 45 Rig Information Contractor Rig Name Rig Type de 5 NABORS ALASKA NABORS 245 E Name ' Rig RIG -- Job Information Wellbore 1 Job Phase I Spud Date 'Target Depth (ftKB) 'Target Depth (TVD..l Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) OP23 -WW02 COMPLETION 12,323.0 9,709.01 196.06 Daily Information End Depth (RKB) End Depth (TVD) (f.. Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB Temperature (°F) Weather Wind 12,323.0 0.0 85.0 27.3 Cloudy. Blowing 19° NNE a 31.1 Snow WC11,1° mph Daily summary operation 24h Summary Rig was accepted to OP23 -W W02 @ 0000 hours. \ Prep to move rig off 0111 -01 to OP23 -W W02 \ Move equipment & level ground \ Lay down Herculite & mats \ Move Utility module to west - spot Rig module over OP23 -W W02 \ Move Utility module to Rig module (level both) \ Hook -up interconnects between modules and service lines \ Steam operational \ Salvage old Hercukte. Very windy conditions last 24 hours. Operation at 07.00 Prep to take on 9.7 ppg brine & ND tree. 24h Forecast Berm around modules 8 spot equipment \ Install BPV 8 ND tree \ Take on 9.7 ppg brine \ NU BOPE \ Load pipe shed with 4 -1/2" 13Cr tbg. Lithology 'Shows I MAASP Pressure (psi) 'Mud Weight (lb/gal) 9.70 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00 00 06.00 6.00 6.00 COMP A 2 P Rig was accepted to Well OP23•W W02 @ 00:00 hours. Blow down steam lines & unplug complexes. Disconnect interconnection & secure same. Prep modules for move, Roll up curtains / Lampsons. Jack -up module and install blocks. Remove cuttings and CCB off location. 06'00 14:00 8.00 14,00 COMP A 2 P Finished separating rig modules. R/D hot house and move equipment. Perform dirt work to level ground for rig. Lay down Herculite and mats. (Very windy conditions), 14 00 15 00 1,00 15.00 COMP A 2 P Move utility module to the west from rig module against CCB pods, 15 00 18 30 - 3.50 18.50 COMP A 2 P Move rig module from 0111 -01 & spot over OP23 -WW02. Jack up rig & remove blocks. Set down on mats. 18.30 20'30 2,00 20.50 COMP A 2 P Move Utility module & align up with rig. Shim to level both modules, 20'30 00 00 3,50 24.00 COMP A 2 P Hook up interconnects between modules. Remove hatch cover to well house & lower Dixie cup. Steam operational. Hook up flowkne. Salvage old Herculite. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Dulling Supervisor jack.keener@enipetroleum.com 907 -670 -8623 907 - 715 -6434 Eni representative David Smith ENI Drilling Supervisor 907 - 670 -8623 Eni representative Bernie Leas ENI Rig Clerk 907 - 670 -8607 907.575 -8427 Eni representative Mike Nelson ENI HSE Mike.Nelsoncenipetroleum.com 907 -685 -1227 Eni representative Alvin Criswell ENI Expediter 907 - 980 -7545 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (RKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) ' TVD (ftKB) ' Fluid Type 'Fluid Density (lb/gal) I P Surf Applied (psi) Eq. Mud Weight (lb/gal) 1 Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 el • lirli* En! E &P Division Name: OP23 -W W02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nika4chuq • Date: 10118/2010 -Report #: 9 API /UWE: 50- 029- 23411 -00 -00 page 1 of 1 UVellbore name: OP23 -WW02 Well Header PermitlConcession N° !Operator "ENI Share ( %) 'Well Configuration type Okktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) 'Ground Level (ft) !Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information _ Contractor Rig Name Rig Type NABORS ALASKA ! NABORS 245 E ILAND RIG Job Information Wellbore I Job Phase I Spud Date !Target Depth (ftKB) !Target Depth (TVD.. .I Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (Mr) IDFS (days) OP23 -WW02 COMPLETION 12,323.0 9,709.0 197.06 Daily Information End Depth (RKB) End Depth (TVD) (f.. Depth Progress (ft) Drilling Hours (hr) Avg ROP (fUhr) POB Temperature (°F) Weather Wind 12,323.0 0.0 88.0 8.8 Cloudy. Light Snow. 196° SSW @ 8 1 WC -0.6° mph Daily summary operation 2411 Summary Berm around rig & spot equipment \ Pull BPV with Vetco Gray (lubncated out) \ U -tube well & monitor well - dead - Install BPV as per Vetco Gray.\ Check tbg. hanger void - N/D tree \ N/U BOPE \ Test BOPE to AOGCC regulation.\ R/U to displace diesel with 9.7 ppg. Bnne. Operation at 07.00 POOH - L/D 4 1/2" 17Cr tbg. With Nabors casing crew. 24h Forecast T Displace diesel with 9.7 ppg bane & monitor \ R/U Nabors casing to L/D 4 1/2" 13Cr tbg. \ Pull hanger to floor & UD \ POOH L/D 4 1/2" 13 Cr tbg: Vam Top \ P/U BOT WRBP retrieving tool on 3 1/2' drill pipe \ P/U 5" drill pipe to WRBP, Lithology !Shows I MAASP Pressure (psi) I Mud Weight (Iblgal) 9.70 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00:00 0330 3.50 3.50 RE -EN ' K 2 P Install berming around ng (ACS), secure walkways - spot cutting tank @ cuttings dump & CCB outlets. Spot bleed tank - 13 3/8" x 9 5 /8" annulus 300 psi. - 9 5/8" x 4 " annulus on vac. 03.30 0630 3,00 6.50 RE -EN K 20 P Check for pressure on tbg. - Pressure under BPV- R/U Vetco Gray lubricator and pull BPV - 80 psi. on tbg. - U -tube tbg. & annulus, bleed to tank & monitor, dead - install BPV in tbg. hanger. Notified AOGCC for BOP test. 0630 08:30 2.00 8,50 RE -EN K 5 P Check hanger void for pressure & N/D tree as per Vetco Gray. 08.30 13 00 4.50 13,00 RE -EN K 5 P N/U BOP - bell nipple, flow line, hook -up kill & choke lines.\ Install fill -up, bleed lines & Katch -Kan. AOGCC waived vdtness by Jeff Jones of BOP test. �s 13 00 21:00 8.00 21.00 RE -EN K 12 P P/U test joint - function BOPE - fill stack with water - Test BOP to 250/2500 Si. p on annular & 250/3500 psi. on rams, choke/ R h /� kill valves, choke manifold, top dnve & floor valves \ accumulator draw down & check pre- charge on accum bottles - test & �,JV I calibrated gas sensor & alarms, Tested with 5" & 4 " tubular. 21.00 22 00 1.00 22.00 RE -EN K 5 P R/D test joint & blow down - Pull BPV vnth Vetco Gray Rep 22 00 00:00 2.00 24.00 RE -EN K 5 P P/U landing joint & make -up in tbg. hanger - R/U to circulate \ Vetco Gray backed out lock down screws - check annulus & prep to pull hanger. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907- 715.6434 Eni representative David Smith ENI Drilling Supervisor 907 - 670 -8623 Eni representative Bernie Leas ENI Rig Clerk 907 - 670 -8607 907- 575 -9427 Eni representative Mike Nelson ENI HSE Mike.Nelson@enipetroleum.com 907 -685 -1227 Eni representative Alvin Criswell ENI Expediter 907 -980 -7545 Last Casing seat Das. Type OD (in) ID (in) I Grade Top (RKB) Bottom (RKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323,0 5/3/2010 Last Leakoff Test Depth (RKB) ITVD (ftKB) Fluid Type !Fluid Density (Iblgal) IP Surf Applied (psi) I Eq. Mud Weight (Iblgal) !Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 ril* Ent E &P Division 1111/ I Well Name: OP23 -WW02 • ENI Petroleum Co. Inc. dally Report Well Code: 23835 Field Name: Nikaitchuq � , n Date: 10/20/2010 - Report #: 10 APWW: 50-029-23411-00-00 " ��" page 1 of 1 Wellbore name: OP23 -WW02 Well Header Oliktok Point Permit/Concession N° !Operator ENI PETROLEUM 'ENI Share (%) 100.00 DIRECT ONAL Configuration type Rotary Table Elevation (ft) Ground Level (ft) 'Water Depth (ft) RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name I Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore I Job Phase I Spud Date 'Target Depth (ftKB) 'Target Depth (TVD...I Depth Dr. (MD) (ft) Drilling Hours (hr) 'Avg ROP (ft/hr) IDFS (days) OP23 -W 4/02 COMPLETION 12,323.0 9,709.01 198.06 Daily Information End Depth (ftKB) End Depth (TVD) (f.. Depth Progress (ft) Drilling Hours (hr) Avg ROP (ftlhr) POB Temperature ( °F) Weather Wind 12,323.0 0.0 9.0 25.5 Cloudy. WC 11.5° 29° NNE @ 22.2 mph Daily summary operation 24h Summary Pull tbg. hanger off seat 5' (70K) \ Displace diesel with 9 7 ppg NACL bnne & monitor well 1 R/U Nabors casing equipment to pull 4 1 /2" 13Cr tbg \ POOH - UD 4 1 /2" 13Cr tbg. with compensator \ P/U BHA - BOT Model M Retneving Head & XO - P/U 3 1/2" drill pipe (3 joints) \ P/U 5" doll pipe - RIH to 7245'. Operation at 07.00 Operation At 0400 Hours: Circulating hole volume - displace from 9.7 ppg. Bone to 9.5 ppg. Inhibited Brine. 24h Forecast Continue P/U 5" DP /1 8892' \ Circulate hole volume to 9.5 ppg Inhibited Brine \ BOT Rep. latch onto plug (equalized & release same) work 30' +/- Monitor well & CBU \ POOH L/D 5" DP & BHA \ Pull wear bushing \ R/U to run ESP completion assembly. Lithology 'Shows MAASP Pressure (psi) 'Mud Weight (Iblgal) 9.70 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00:00 02.00 2.00 2.00 RE -EN K 7 P Pug tbg. hanger off seat from well head © 70K - Close annular & displace diesel with 9.7 ppg NACL brine through choke manifold la 234 gpm @ 270 psi. - monitor for 10 minutes - static. 02:00 03:00 1.00 3.00 RE -EN K 20 P R/U Nabors csg. equipment to UD 4 1/2" 13 Cr tbg. - PJSM. 03:00 08:00 5.00 8.00 RE -EN K 4 P POOH - L/D tbg. hanger as per Vetco Gray \ Continue L/D 4 1/2 " 13Cr tbg. 1/2568' with Nabors casing - use compensated system to protect threads. 08:00 08.30 0.50 8.50 RE -EN K 20 P R/D Nabors casing equipment. 08:30 09:30 1.00 9.50 RE -EN K 5 P Install wear bushing (9 1/6" ID) with Vetco Gray rep. / 09 10.30 1.00 10.50 RE -EN K 25 U Service rig - Change oil & fitter in top dnve & inspect brakes on same. ✓ 10 30 12.00 1.50 12.00 RE -EN K 20 P Remove 4 1/2" 13Cr tbg. from pipe shed to USAF pad. 12.00 14'00 2.00 14.00 RE -EN K 20 P Finish loading 5" drill pipe in pipe shed - prep to P/U same. \ Mechanic performed monthly service work on Top Drive hydraulic unit. 14:00 15'00 1.00 15.00 RE -EN K 4 P P/U XO & Model M retneving head as per BOT Rep. on 3 joints of 3 1/2 " drill pipe. \ BHA= Baker Model M Retneving Head wdh XO 3.25' (OD 5 1/2" x ID 2.44 ") + 3 1/2" drill pipe 93.85' + XO 1.10" = 98.21' OA. 1500 00:00 9.00 24,00 RE -EN K 4 P P/U 5" doll pipe - RIH with BOT Model M retrieving head 1/7245' DPM. Up wt. 160K - Dn wt. 130K - correct hole displacement. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Greg Parker ENI Expediter 907- 980 -7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher Last Casing seat Cas. Type OD (in) f ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) 'Fluid Type 'Fluid Density (Iblgal) IP Surf Applied (psi) Eq. Mud Weight (Iblgal) Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 • • frit4 Eni E &P Division ' well Name: 0P23 -W W02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • APIIUWI: 50- 029 - 23411 -00 -00 e n o Date: 10/21/2010 - Report #: 11 'r" page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° I Operator I ENI Share ( %) 'Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (ft) I Ground Level (ft) ( Water Depth (ft) I RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA I NABORS 245 E I LAND RIG Job Information ' Wellbore Job Phase I Spud Date I Target Depth (ftKB) I Target Depth (TVD.. .I Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ftlhr) I DFS (days) OP23 -WW02 COMPLETION 12,323.0 9,709.01 199.06 Daily Information End Depth (RKB) I End Depth (TVD) (f.. Depth Progress (ft) 'Drilling Hours (hr) I Avg ROP (ft/hr) I POB Temperature (-F) I Weather I Wind 12,323.01 0.0 87.0 Daily summary operation 24h Summary P/U 5" DP (/7245'- 1)8892' - record parameters \transfer fluids in pits & off load 580 bbls. of 9.5 ppg new bone from CH2MHill Vac truck.\ Circulate - displace 9.7 ppg. bane to 9.5 ppg inhibited bnne.\ Tag BOT WRBP 8912' with 6K - equalize & monitor back side - Chase to 8961' - POOH 5 8841' wth 6K drag (good indication plug was on.)\ CBU & monitor for 15 mms: static 1 POOH L/D 5" DP (service rig & pipe skate) - L/D 3.5" BHA & BOT WRBP \ Pull wear bushing \ Clear & clean floor - prep to R/U Centirlift equipment - finished loading pipe shed with 4 .5" 13Cr tbg. Operation at 07.00 R/U Centrilitt & Nabors equipment to P/U ESP Completion Assembly. 24h Forecast R/U Centritift & Nabors - PJSM P/U ESP completion assembly as per well plan. Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (lb /gal) 9.50 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00 00 02:00 2,00 2.00 RE -EN K 4 P P/U 5" drill pipe - RIH with BOT Model M retneving head 1/7245' - 1)8892' DPM.\ UP wt. 200K - Dn wt. 145K - Rot wt. 175K (§ 8rpm with 4 -5k torque \ Pump rate 126 gpm @ 130 psi. \ Prep pits for displacement. 02'00 04.00 2.00 4.00 RE -EN K 1 P Transfer fluids in pits - 9.7 ppg Brine to raw mud & off load 150 bbls. to CH2MHill Vac-truck to make room & off load 580 bbts. 9.5 ppg. inhibited Bnne to displace. - PJSM. 04.00 06.00 2.00 6.00 RE -EN K 7 P Circulate - displace 9.7 ppg Brine with 9,5 ppg. Inhibited Bnne.\ pump rate 255 gpm @ 240 psi. 06:00 07.30 1.50 7.50 RE -EN K 13 P RIH to 8912' latch on to plug with 6K, (increase in pump pressure when retreiwng over WRBP) - by -pass opened.\ Monitor back side - static.\ Chase plug to 8961' \ POOH to 8841' with indication plug was on with 6K drag - Up wt. 200K - Dn wt. 145k. 07 30 09:30 2.00 9,50 RE -EN K 7 P Circulate bottoms -up pump rate 210 pgm @ 800 psi. - monitor well for 15 minutes - static. 09'30 13:00 3.50 13.00 RE -EN K 4 P POOH - L/D 5" drill pipe with 3 1/2" BHA - BOT Model M Retrieving Head & bridge plug - U 6890'. 13.00 13:30 0.50 13.50 RE -EN K 25 P Service rig & pipe skate. 13.30 22:30 9.00 22.50 RE -EN K 4 P POOH - L/D 5" drill pipe with 3 1/2" BHA - BOT Model M Retrieving Head & bridge plug. 22 30 23'00 0.50 23.00 RE -EN K 5 P Pull wear bushing & L/D running tool. 23'00 0•00 1.00 24.00 RE -EN K 1 P Clear & clean floor of equipment & prep to P/U Centrilift ESP assembly - finish loading [pipe shed with 4 lir 13Cr tbg. form USAF pad. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keenertenipetroleum.com 907 -670 -8623 907 - 715 -6434 Eni representative Gary Goerlich ENI Drilling Supervisor 907 - 670 -8623 907 - 441 -6585 Eni representative Tom Norvig ENI Rig Clerk 907 -670 -8607 907- 229 -6100 Eni representative Jack Potter ENI Drilling HSE 907 -670 -8624 Eni representative Greg Parker ENI Expediter 907-980-7545 Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (RKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (RKB) I TVD (ftKB) Fluid Type 'Fluid Density (lblgal) I P Surf Applied (psi) Eq. Mud Weight (1b/gal) I Leak Off Pressure (psi) 9,170 01 6,666.12 VC -OBM 10.30 1,700,0 15.21 5,266.8 • • • IF* Eni E&P Division ' Well Name; OP23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code; 23835 Field Name: Nikaitchuq • Date; 10/22/2010 - Report #: 12 APIIUWI: 50-029-23411-00-00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Oliktok Point Permit/Concession N° 'Operator ENI PETROLEUM I ENI Share (%) 100.00IDIRECT ONAL lion type Rotary Table Elevation (ft) Ground Level (ft) 'Water Depth (ft) RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name 1Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore IJob Phase 'Spud Date 'Target Depth (ftKB) [Target Depth (TVD..'Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) I DFS (days) OP23 -WW02 COMPLETION 12,323.0 9,709.0 200.06 Daily Information End Depth (ftKB) ' End Depth (TVD) (f.. Depth Progress (ft)' Drilling Hours (hr) 'Avg ROP (ft/hr) I POB Temperature (°F) Weather ' Wind 12,323.0 0.0 103.0 27.7 Cloudy, WC 11.7° 10° N (g 28.9 mph Daily summary operation 24h Summary R/U to run tbg \ run downhole pumps \ one broken seal \ wait on Baker seal assy while P/U shroud and PJSM. P/U M/U Baker ESP seal assy \ M/U hanger assy \ hook up cap lines and splice motor lead. Operation at 07.00 Running completion string 24h Forecast Continue run 4 1 /2" VAM -Top CR -13 tbg. Lithology 'Shows I MAASP Pressure (psi) 'Mud Weight (lb/gal) 9.50 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00'00 10'00 10.00 10.00 RE -EN G 5 P RIG UP /DOWN TO RUN CASING. CLEAN & TALLY 4 1/2" VAM -TOP CR -13 TBG. P/U COMPLETION EQUIPMENT F /BEAVER SLIDE & R /U. HANG SHEAVES, PULL ESP AND CABLES THROUGH SHEAVES. CENTRILIFT TEST ESP CABLES. 10,00 11;00 1 00 ' 11.00 RE -EN G 5 P RUN DOWNHOLE PUMPS SEAL ASSY, 1 BROKE SEAL, BREAK X/0 OUT, LAY DOWN 11 00 12 00 1.00 12.00 RE -EN G 24 U WAITING ON BAKER SEAL ASSY COMING FROM DEADHORSE 12 00 13 00 1.00 13.00 RE -EN G 1 P WAITING ON BAKER SEAL ASSY, PJSM W /CENTRILIFT, ALL HANDS INVOLVED. PICKING UP 7 5/8" SHROUD. PJSM ON PICKING UP ESP. 13 00 15 00 2.00 15.00 RE -EN G 5 P PU MU SEAL ASSY, X/O, 9' PUP, 2 JTS 7 5 /8" TBG, SHROUD HANGER BODY 15'00 00.00 9.00 24.00 RE -EN ' G 5 P PU MU ESP PUMP ASSY / SERVICE SEALS / MU HANGER ASSY / HOOK UP CAP LINES / SPLICE MOTOR LEAD Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener@enipetroleum.com 907 - 670 -8623 907- 715 -6434 Eni representative Gary Goertich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Eni representable Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Tool Push Mike Williams Nabors Alaska Dulling Tool Pusher Last Casing seat Cas. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date LINER I 7 6.276 13CrL80 6,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) Fluid Type 'Fluid Density (lb/gal) I P Surf Applied (psi) ' Eq. Mud Weight (lb/gal) ' Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 • • Vii* Eni E &P Division I Well Name: 0P23 -W W02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • APIIl1VA: 50-029-23411-00-00 e II 1) Date: 10/23 /2010 - Report #: 13 II page 1 of 1 Wellbore name: OP23 -WW02 Well Header Oliktok Point Permit/Concession N° !Operator ENI PETROLEUM I ENI Share (%) 100.001 D RECTIONAL Configuration type Rotary Table Elevation (ft) 'Ground Level (ft) 1 Water Depth (ft) I RKB - Base Flange (ft) 1 RKB - Tubing Spool (ft) 53,20 12.20 31.50 33.25 Rig Information Contractor Rig Name 1Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date 'Target Depth (ftKB) [Target Depth (TVD..IDepth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ft/hr) IDFS (days) OP23 -WW02 COMPLETION 12,323.01 9,709.01 201.06 Daily Information End Depth (ftKB) End Depth (TVD) (f.. Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB Temperature (°F) Weather Wind 12,323.0 0.0 100.0 26.6 Mostly Cloudy, 28° NNE (0 24.1 Blowing Snow, WC mph 11.8° Daily summary operation 24h Summary Finish motor lead splice 8 test \ RIH w/4 1/2" VAM -Top chrome tbg w/ESP and control lines 8/4654' MD, joint #108 \ Install clamps every joint \ continuity testing ESP lines every 1000'1 splice ESP, splice landing 10' in on joint # 107, 4580' MD Operation at 07.00 Running completion string 24h Forecast Finish running 4 1/2" VAM -Top Chrome tbg to TD @ 8907.80' MD Lithology 'Shows I MAASP Pressure (psi) I Mud Weight (Iblgal) 9.50 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00 00 01 30 1.50 1.50 RE -EN G 5 P FINISH MOTOR LEAD SPLICE AND EJECT TEST PER BAKER CENTRILIFT. 01.30 12'00 10.50 12.00 RE -EN G 5 P RIH WITH 4 1/2" VAM -TOP 12.6# CHROME TBG T/2750' MD \ 4500 TO WITH ESP AND CONTROL LINES \ INSTALLING CLAMPS EVERY CONNECTION \ CONTINUITY TESTING ESP LINES EVERY 1000' 12'00 13.30 1.50 13.50 RE -EN G 5 P RIH F/2750' T/3140' MD, JOINT # 72 13.30 14.00 0.50 14.00 RE -EN G 5 P TEST ESP \TEST GOOD v 14 00 16.30 2.50 16.50 RE -EN G 5 P RIH F/3140' T/4276' MD, JOINT #99 16'30 17.30 1.00 17.50 RE -EN G 5 P SWAP OUT SPOOLS \ TIE SNAKE ONTO CABLE 17'30 18'30 1.00 16.50 RE -EN G 5 P RIH F/4276' T/4570' MD, JOINT# 106 1100K UP 195K DOWN 18'30 23:00 4.50 23.00 RE -EN G 5 - P SPLICE ESP 1 SPLICE WILL LAND 10' IN ON JOINT # 107 AT 4580' MD \ MU JOINT # 108 \ CONNECTION ON SPLICE WAS PULLING OUT \ RE- SPLICE CONNECTION 23 00 00:00 1.00 24.00 RE -EN G 5 P RIH F/4570' T/4654' MD, JOINT # 108 /HAD TO BACK OUT, REDOPE AND CHECK THREADS ON JOINT # 108 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack keenertenipetroleum.com 907 -670 -8623 907-715-6434 Eni representative Gary Goerlich ENI Dnlling Supervisor 907 -670 -8623 907- 441 -6585 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907 - 229 -6100 Eni representative Jack Potter ENI Dnlling HSE 907- 670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Tool Push Mike Williams Nabors Alaska Drilling Tool Pusher Last Casing seat Cos. Type OD (in) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) I Fluid Type IFluid Density (lb/gal) I P Surf Applied (psi) I Eq. Mud Weight (lb/gal) I Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 • irlillf4111 Eni E &P Division 'Well Name: OP23 -WW02 ENI Petroleum Co. Inc. Daily Report Well Code: 23835 Field Name: Nikaitchuq • Date: 10/24/2010 - Report #: 14 APIIUWI: 50- 029 -23411 -00-00 page 1 of 1 Welibore name: OP23 -WW02 Well Header Okktok Point Permit/Concession N° !Operator E NI PETROLEUM 'EN! Share (°/0) 100.00 ECT ONAL Configuration type Rotary Table Elevation (ft) Ground Level (H) ' Water Depth (ft) RKB - Base Flange (ft) I RKB - Tubing Spool (n) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name IRig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Welibore I Job Phase Spud Date 'Target Depth (ftKB) [Target Depth (TVD..]Depth Dr. (MD) (ft) Drilling Hours (hr) Avg ROP (ftihr) I DFS (days) OP23 -WW02 COMPLETION 12,323.0 9,709.0 202.06 Daily Information End Depth (f/KB) End Depth (TVD) (f.. Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft/hr) POB Temperature ( °F) Weather Wind 12,323.0 0.0 104.0 25.7 Mostly Cloudy, WC 336° NNW @ 22.4 11.1° _mph Daily summary operation 24h Summary Continued/finished RIH with 4 1/2" Vam Top chrome tbg clamped every joint (209 - 4 1/2" Canon damps, 1 - 4 1/2" Splice clamp, 6 - 1/2" Band clamps, 4 - 1 1/4" Band clamps and 28 5 /8" Band clamps). Landed tbg at 8902' MD. Operation at 07.00 Prepanng to install tree and diesel freeze protect. 24h Forecast Clear floor of casing tools and Baker Centrildt equipment. Test hanger seals to 5000 psi. ND BOPS. Install and test tree to 5000 psi. RU to pressure test annulus and freeze protect. Prepare to RDMO. Lithology 'Shows I MAASP Pressure (psi) 'Mud Weight (lb/gal) 9.50 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00.00 06'00 6.00 6.00 RE -EN G 5 P RIH 4 1/2" VAM TOP 12.68 13CR TBG WITH ESP TO 6,686' MD TORQUE TURN \ CONTINUITY TEST EVERY 1000' \ CLAMPS EVERY JOINT. 0600 08:00 2.00 8.00 RE -EN G 5 P P/U SSV RUN CONTROL LINE AND TEST TO 6500 PSI FOR 10 MIN. TEST CONTINUITY EVERY 1000'. 08 00 ' 18:00 10.00 18.00 RE -EN G 5 P CONTINUE RIH WITH 4 1/2" TBG \ P/U 4 JOINTS OF IBT X0 TO VAM TOP FOR SPACE OUT PURPOSES. TAG LINER NO -GO, PICK UP TO NEUTRAN, MARK FOR SPACE OUT. LEAVE SEAL ASSY .7 FEET OFF NO -GO. P/U SPACE OUT PUPS AND MAKE UP UNDER VIT JOINTS. TOP OF LINER PBR- 8,904' MD \ BOTTOM OF SEAL ASSY MULE Z SHOE- 8,912' MD. 18:00 18:30 0.50 18.50 RE -EN G 5 P LD 4 JOINTS OF IBT 18:30 20'00 1.50 20.00 RE -EN G 5 P SWAP POWER TONGS \ M/U 3 JOINTS VIT 20:00 23:00 3.00 23.00 RE -EN G 5 P P/U M/U HANGER AND LANDING JOINT \ ORIENTATE HANGER 1 INSTALL BPV IN HANGER 23 00 00:00 1.00 24.00 RE -EN G 5 P LAND TBG \ 152 UP \ 118 DOWN RILDS \ 8902' MD .83' OFF NO GO Daily Contacts Position Contact Name Company Title E-mail Office Mobil. Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907 - 715 -6434 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907 - 441 -6585 Eni representative Tom Noting ENI Rig Clerk 907- 670 -8607 907 - 229 -6100 Eni representative Jack Potter ENI Drilling HSE 907- 670-8624 Eni representative Greg Parker ENI Expediter 907 - 980 -7545 Tool Push Mike Wilkams Nabors Alaska Drilling Tool Pusher Last Casing seat Cas. Type OD (in) ID (in) Grade Top (8KB) I Bottom (/KB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) Fluid Type 'Fluid Density (lb/gal) IP Surf Applied (psi) I Eq. Mud Weight (lb /gal) I Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 • rat* Eni E &P Division (Well Name: OP23 -WW02 • • E NI Petroleum Co. Daily Report Well Code: 23835 Field Name: Nikaitchuq e n Date: 10/25/2010 - Report #: 15 APIIUW I: 50 -029 -23411 -00-00 'i page 1 of 1 Wellbore name: OP23 -WW02 Well Header Oliktok Pont Permit/Concession N° 'Operator ENI PETROLEUM IENI Share (%) 100.00 ECT ONAL Configuration type Rotary Table Elevation (ft) Ground Level (ft) 'Water Depth (ft) RKB - Base Flange (ft) I RKB - Tubing Spool (ft) 53.20 12.20 31.50 33.25 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore ' Job Phase I Spud Date 'Target Depth (ftKB) 'Target Depth (TVD..l Depth Dr. (MD) (ft) Drilling Hours (hr) 'Avg ROP (ft/hr) I DFS (days) OP23 -WW02 COMPLETION 12,323.0 9,709.0 203.06 Daily Information End Depth (ftKB) End Depth (TVD) (f.. Depth Progress (ft) Drilling Hours (hr) Avg ROP (ft hr) POB Temperature ( °F) Weather Wind 12,323.0 0.0 21.0 22.8 Mostly Cloudy, WC 10° N i 11.5 mph 11.7° Daily summary operation 2411 Summary L/D Baker Centnlift equipment, Nabors casing tongs, double stacks, handling equipment and SLP control lines spooling equipment. Nipple up /down BOPS. Tested tree to 5000 psi. Freeze protect well. Centnlift completed final tests. Begin clean out of mud system and breaking down interconnects. Rig released at 24:00 hours Operation at 07.00 Preparing for ng move to OP17 -02, 24h Forecast Prepare for rig move from OP23 -W W02 to OP17 -02 Lithology 'Shows MAASP Pressure (psi) 'Mud Weight (lb/gal) 9.50 Time Log Start End Cum Time Time Dur (hr) Dur (hr) Phase Opr. Act. Plan Oper. Descr. 00'00 04:00 4.00 4.00 RE -EN G 5 P CLEAR FLOOR OF BAKER CENTRILIFT EQUIPMENT, NABORS CASING TONGS AND SLB SPOOLING UNIT 04 00 05'00 1.00 5.00 RE -EN K 5 P RIG DOWN ESP CABLE FROM DERRICK 05'00 07.00 2,00 7.00 RE -EN K 5 P NIPPLE DOWN DRIP PANS 07'00 10 00 3.00 10,00 RE -EN K 5 P NIPPLE DOWN BOPE, PULL VETCO GREY RISER AND LAY DOWN 10'00 12 00 2,00 12.00 RE -EN K 5 P NIPPLE UP VETCO GRAY TREE AND SET FLOW CROSS VALVES 12.00 15.00 3.00 15.00 RE -EN K 5 P FINISH NIPPLING UP TREE AND VALVES ° 15:00 16100 1.00 16.00 RE -EN K 5 P TESTED TREE, TEST PLUG LEAKED, RESET PLUG AND TESTED TO 5,000 P51 FOR 15 MINUTES 16:00 17'00 1,00 17.00 RE -EN K 5 P OPEN SSSV WITH 6,150 PSI AND HOLD FOR 15 MINUTES I( T�ir 17:00 18.00 1.00 18.00 RE -EN K 5 P RIG UP LITTLE RED HOT OIL TRUCKTO THE INNER ANNULUS AND A RETURN LINE TO THE MUD PITS, PRESSURE UP ON THE INNER ANNULUS TO 1500 PSI. CHARTED, HELD FOR 15 MINUTES. PUMP UP TO 1800 PSI. GLM SHEARED 18:00 18'30 0.50 18.50 RE -EN K 5 P REVERSE CIRCULATED (a 2 BPM 1600 PSI. MONITOR PERCENT OF RETURNS BACK UP THE TUBING, CALCULATED 207 BBLS TO SEE DIESEL @ SURFACE. 18.30 20:00 1.50 20.00 RE -EN K 5 P FREEZE PROTECT WELL 1202 BBLS DIESEL PUMPED \ FCP 500 PSI 1 BPM \ TBG 20 PSI \ OUTER ANNULUS 270 \ NO LOSSES DURING CIRCULATION 20'00 22.00 2.00 22.00 RE -EN K 5 P CLEAN OUT MUD SYSTEM, VAC OUT BRINE 1 GET READY FOR RIG DOWN 1 TBG 200 /INNER ANNULUS 200 \ OUTER ANNULUS 270 22'00 23:00 1.00 23.00 RE -EN K 5 ' P RIG DOWN CIRCULATION HOSES 1 SECURE WELL 1 BAKER CENTRILIFT PERFORMED FINAL CHECKS 23:00 00.00 1.00 24.00 RE -EN K 5 P CONTINUE TO CLEAN MUD PITS \ START BREAKING DOWN INTERCONNECTS 1 PUT HATCH COVER ON WELL BAY. " "RIG RELEASED AT 24:00' "" Daily Contacts Position Contact Name Company Title E-mail Office l Mobile Last Casing seat Cas. Type OD (In) ID (in) Grade Top (ftKB) Bottom (ftKB) Run Date LINER 7 6.276 13CrL80 8,883.4 12,323.0 5/3/2010 Last Leakoff Test Depth (ftKB) I TVD (ftKB) 'Fluid Type 'Fluid Density (Iblgal) IP Surf Applied (psi) Eq. Mud Weight (Ib/gal) Leak Off Pressure (psi) 9,170.0 6,666.12 VC -OBM 10.30 1,700.0 15.21 5,266.8 Eni Petroleum Schlumberger OP23 -WW02 Survey Report (Def Survey) Report Date: May 05, 2010 - 02.45 PM Survey / DLS Computation: Minimum Curvature / Lubinski Client: ENI Vertical Section Azimuth: 5000 ° (True North) Field: Nikaitchuq Vertical Section Origin: 0 -000 ft, 0 000 ft Structure / Slot: Oliktok Point / OP23 TVD Reference Datum: Rotary Table Well: OP23 -VW02 TVD Reference Elevation: 53 20 ft above MSL Borehole: OP23- VVVV02 Seabed / Ground Elevation: 12 20 ft above MSL UWI / API #: Borehole - 3118384 / 500292349000 Magnetic Declination: 21 742 ° Survey Name: OP23 -WVV02 Total Field Strength: 57669.548 nT Survey Date: 4 -May -10 Magnetic Dip Angle: 80 953 ° Tort / AHD / DDI / ERD Ratio: 168.293 ° / 6540 197 6 / 6.152 / 0.685 Declination Date: Apnl 20, 2010 Grid Coordinate System: NAD27 Alaska State Plane, Zone 04, US Feet Magnetic Declination Model: BGGM 2009 Location Lat / Long: 70 51086102° - 14986435227° North Reference: True North Location Grid N/E Y/X: N 6036483.06 ftUS, E 516576.84 ftUS Grid Correction: 0 000 ° Grid Convergence Angle: 0.12787579 ° Total Corr Mag North -'True North: 21.742 ° Grid Scale Factor: 0.99990031 Local Coord Referenced To: Well Head Ill MD Inc! Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude Comments (ft) ( °) O (ft) (ft) (ft) (ft) (ft) (ft) (ft) (e /100ft) (ftUS) (ftUS) (1 (°1 RTE 0.00 000 0 00 -53 20 0.00 0 00 0 00 0.00 0.00 0.00 N/A 6036483.06 . 516576 84 70.51086102 - 149.86435227 WRP 41.00 0.08 39.43 -12.20 41.00 0.03 0.03 0.03 0 02 0.02 0.21 6036483.08 516576.86 70.51086108 - 149.86435211 100 00 0.21 39 43 46.80 100 00 0 18 0 18 0 18 0.14 0.11 0.21 6036483.20 516576.95 70.51086140 - 149.86435133 20000 0.41 39 43 146.80 200.00 0.71 0.72 0 72 0.56 0.46 0 21 6036483 62 516577.30 70.51086254 - 149.86434853 242.51 0 50 39.43 189.31 242.51 1.04 106 1.06 0.82 0.67 0 21 6036483 88 516577.51 70.51088325 - 149 86434677 276.39 0 20 284.85 223.19 276.39 1.15 1.22 1.18 0 95 0.71 1.80 6036484.01 516577.55 70.51086360 - 149 86434647 300.00 0 12 340 19 246.80 300.00 1.14 1 28 1.18 0.98 0.66 0.70 6036484.04 516577.50 70.51086369 - 149 86434686 307.59 0 13 4.20 254.39 307 59 1.14 1 29 1.19 1.00 0.66 0 70 6036484 06 516577.50 70 51086374 - 149.86434688 337.57 0 03 287.61 284.37 337.57 1.16 1.33 1.22 1.03 0.65 0.42 6036484.09 516577.49 70.51086384 - 149.86434692 368.38 0.34 215_42 315.18 368.38 1.07 1.43 1 13 096 0.59 1 08 6036484 02 516577.43 70.51086364 - 149.86434741 400 00 0.32 29.61 346.80 400.00 1.06 1 52 1 12 096 0.58 2.08 6036484.02 516577.42 70.51086364 - 149.86434751 401.57 0.35 29.89 348.37 401 57 1 07 1 53 1.13 0.97 0.59 2.08 6036484 03 516577.42 70 51086366 - 149 86434747 43006 0.36 270.28 376.86 430.06 1.08 1.65 1 18 1.04 0.54 2.15 6036484.10 516577.38 70 51086387 - 149.86434785 45928 0.13 77.59 406 08 459.28 104 1 73 1 16 1.05 0.48 1 67 6036484.11 516577.32 70.51086389 - 149.86434833 491.87 0.05 47.61 438.67 491.87 1 09 1.78 1 19 1.07 0.53 0.28 6036484 13 516577 37 70.51086394 - 149.86434795 500 00 0 07 74 48 446 80 500 00 1 10 1 78 1 20 1.07 0 54 0.45 6036484 13 516577.37 70.51086395 -149 86434789 523 84 0.17 97.43 470.64 523.84 1.14 1 83 1 22 1.07 0.58 0 45 6036484 13 516577.42 70 51086395 - 149.86434748 600.00 0.05 102 77 546.80 600.00 1.23 1.98 1.28 1.05 0.73 0.16 6036484 11 516577.57 70.51086389 - 149 86434630 612 99 0 03 107.94 559.79 612 99 124 1 99 1.28 1 05 0.74 0.16 6036484.11 516577 58 70.51086388 - 149.86434623 700.00 0 47 106.47 646.79 699.99 1.45 2 37 1.45 0.94 1.10 0.50 6036484.00 516577 94 70.51086359 - 149.86434327 704 70 0 49 106 47 651.49 704.69 1.47 2 41 1 47 0.93 1.14 0.50 6036483.99 516577.97 70.51086356 - 14986434296 800.00 0.71 122 48 746.79 799 99 1 87 3.40 2 09 0 50 2.03 0.29 6036483 56 516578.86 70.51086238 - 149.86433570 804.60 0.72 123.00 751.39 804.59 1.89 3 45 2 13 0.47 2.07 0.29 6036483.53 516578.91 70.51086229 - 149.8643353 867.33 0.22 65 24 814.12 867 32 2.12 3.94 2 53 0.30 2.51 1.01 6036483.37 516579.35 70.51086184 - 149 86433170 900.00 0.46 28.50 846 79 899.99 2 30 4.13 2 67 0.44 2 63 0 97 6036483 51 516579.47 70.51086223 - 149.86433072 902.92 0 49 27.12 849.71 902.91 2.33 4 15 2.69 0.47 2.64 0 97 6036483.53 516579.48 70.51086229 - 149.86433063 967.22 0.97 23.12 914 00 967.20 3.06 4 97 322 1.21 2.98 0.75 6036484.28 516579.82 70.51086433 - 149 86432785 1000 00 0.90 356.41 946 78 999.98 3.46 5 49 3.53 1.72 3.08 1.33 6036484 79 516579.91 70 51086572 - 149.86432709 100375 0.90 353.23 950.53 1003 73 3.50 5 55 3 55 1.78 3.07 1.33 6036484 85 516579.91 70.51086588 - 149.86432714 1029 30 1.64 355 93 976 07 1029.27 3.82 6 12 3 82 2.34 3.02 2.90 6036485.41 516579.86 70.51086742 - 149.86432754 1094.23 3.00 339.46 1040 95 1094.15 4 93 8.73 5.40 4.86 2.36 2 31 6036487 93 516579.19 70 51087430 - 149.86433296 1100.00 3 16 338 95 1046.71 1099.91 5 04 9.04 5 62 5.15 2.25 2.85 6036488.22 516579.08 70.51087509 - 149.86433386 1191.37 5.75 334 70 1137 79 1190.99 7.02 16 14 11.66 11 64 -0 61 2 85 6036494 70 516576.20 70.51089283 - 149.86435728 1200.00 6.03 335.07 1146.38 1199.58 7 24 17 02 12 48 12.45 -0.99 3.27 6036495 50 516575.82 70.51089502 - 149.86436035 1285 68 8 81 337 49 1231.33 1284.53 10.39 28.08 23 23 22 59 -5.40 3.27 6036505.64 516571.39 70.51092273 - 149 86439643 1300 00 9.08 337 58 1245.48 1298.68 11 06 30 31 25 43 24.65 -6.25 1.87 6036507 69 516570.54 70 51092835 - 149.86440339 1380 48 10 58 337 99 1324.77 1377.97 15.26 44.05 39.08 37 37 -11.44 1 87 6036520.40 516565.32 70 51096310 - 149.86444586 1400 00 10 54 337 98 1343.96 1397.16 16.36 47.62 42 64 40 68 -12.78 0 20 6036523 71 516563 97 70.51097216 - 149 86445684 1478.01 10 39 337 92 1420.68 1473 88 20 73 61 79 56.78 53.82 -18 10 0.20 6036536.83 516558 62 70 51100804 - 149 86450037 1500 00 10 11 337.90 1442.31 1495 51 21.93 65 71 60 69 57.44 -19.57 1 27 6036540 45 516557.14 70 51101794 - 149.86451241 1571 46 9 20 337 84 1512.76 1565 96 25.61 77 69 72.65 68 54 -24 09 1 27 6036551 54 516552.60 70.51104827 - 149.86454935 1600 00 9 67 337.66 1540.92 1594.12 27 03 82.37 77.33 72 88 -25.86 1 66 6036555.87 516550.82 70.51106010 - 149.86456384 Palling Office 2009 1 716 0 NlkartchuMOlikrok Pnmt \0P23.6402 \OP23NNA2 10P236NA02 112212010 5 39 PM Page 1 W 5 Comments MD Inc' Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ftUSI (ftUSI ( °) (°) 1666 91 10 78 337 31 1606.76 1659.96 30 60 94.25 89 19 83.85 -30 41 1.66 6036566 83 516546 25 70.51109008 - 149.86460107 1700 00 10 76 338.14 1639 27 1692.47 32.48 100.43 95.37 89 57 -32.75 0 48 6036572 55 516543 89 70.51110571 - 149.86462025 1762 08 10.72 339.72 1700 26 1753.46 36.24 112 00 106.93 100.36 -36.91 0.48 6036583 33 516539 71 70 51113519 - 149.86465427 1800.00 12.71 342 76 1737.39 1790 59 39 04 119.69 114.63 107.65 -39.37 5.48 6036590 61 516537 24 70.51115511 - 149.86467438 1857 28 15 75 345 91 1792.91 1846.11 44 88 133 77 128.66 121 21 -43 13 5.48 6036604 16 516533 45 70.51119215 - 149 86470515 1900 00 17.42 346.27 1833.85 1887 05 50.24 145 96 140 79 133 05 -46 06 3.91 6036615.99 516530 49 70 51122449 - 149.86472912 1952 83 19 48 346.63 1883 96 1937.16 57.69 162 68 157.44 149.30 -49.97 3.91 6036632.23 516526.54 70.51126889 - 149.86476115 2000 00 20 91 346.71 1928 23 1981 43 65.00 178.96 173.67 165 15 -53 73 3.04 6036648.07 516522.75 70.51131218 - 149.86479186 2049.25 22.41 346.79 1974.00 2027 20 73.18 197.14 191.79 182.84 -57.89 3.04 6036665.75 516518.55 70.51136052 - 149.86482595 2100 00 23.48 349 03 2020.74 2073 94 82.45 216 92 211.49 202.18 -62.03 2.71 6036685 09 516514.37 70 51141336 - 149.86485979 2145 23 24.45 350.88 2062.07 2115.27 91.62 235.29 229 73 220.27 -65.23 2.71 6036703 16 516511 13 70 51146277 - 149.86488599 2200 00 26 38 353 17 2111.54 2164.74 104 09 258 79 252.99 243.54 -68.47 3.95 6036726 43 516507 83 70.51152634 - 149.86491256 2243 01 27.91 354.78 2149 81 2203.01 115.06 278 41 272 35 263 06 -70.53 3.95 6036745 93 516505 73 70.51157965 - 149.86492934 2300 00 30.54 356.47 2199.54 2252.74 131.28 306 23 299.73 290 80 -72.63 4.84 6036773.66 516503 57 70 51165543 - 149.86494657 2337.89 32.30 357.46 2231.88 2285.08 14316 325.98 31914 310.52 -73.67 4.84 6036793.38 516502.48 70.51170931 - 149.86495509 2400.00 34.86 358.92 2283.62 2336 82 164 41 360.33 352.86 344.85 -74.74 4.32 6036827 71 516501 34 70.51180310 - 149.86496383 2435 53 36.33 359 68 2312 51 2365.71 177.51 381.01 373.14 365.53 -74.99 4.32 6036848.38 516501 04 70 51185959 - 149.86496588 2500 00 37 99 0.51 2363.89 2417 09 202.60 419 95 411.35 404 47 -74.92 2.69 6036887.32 516501 03 70.51196597 - 149.86496529 2529.00 38.74 0.87 2386 62 2439.82 214.33 437.95 429.02 422 47 -74.70 2.69 6036905.32 516501 20 70.51201514 - 149.86496351 2600.00 40.59 2 72 2441.28 2494.48 244.54 483.27 473 46 467.76 -73.27 3.10 6036950 61 516502.54 70 51213887 - 149.8649517 2624 82 41 25 3.33 2460.03 2513 23 255 64 499 53 489.38 483.99 -72.41 3.10 6036966.84 516503 36 70.51218322 - 149.86494477 2700.00 44 14 3 48 2515 28 2568.48 290.67 550.50 539.36 534.88 -69.38 3 85 6037017.73 516506.27 70 51232223 - 149.86491998 2719 99 44 91 3.52 2529 53 2582.73 300.31 564.52 553.13 548 87 -68.52 3.85 6037031 72 516507 10 70 51236045 - 149.86491298 2800 00 47.52 6.11 2584 89 2638.09 341.04 622 27 609.74 606.41 -63 65 4.01 6037089.27 516511 85 70.51251765 - 149.86487306 2815.43 48.03 6.59 2595.26 2648.46 349 31 633.70 620 91 617 77 -62.38 4.01 6037100.62 516513.09 70.51254867 - 149.86486272 2900.00 50 36 7.01 2650.52 2703.72 395.97 697 71 683 53 681.33 -54 80 2.78 6037164.20 516520.53 70.51272231 - 149 86480068 2911 11 50.67 7.06 2657.59 2710.79 402.25 706.28 691.93 689.84 -53.75 2 78 6037172.71 516521.56 70.51274556 - 149.86479209 3000.00 50.14 8 14 2714.25 2767.45 452.82 774 78 759.05 757.73 -44.70 1 11 6037240.61 516530 46 70.51293103 - 149.86471801 3007 64 50.09 8.23 2719.15 2772.35 457.19 780.64 764.79 763.53 -43.86 1.11 6037246 41 516531.28 70 51294688 - 149.86471118 3100 00 49.74 6.23 2778 62 2831 82 509.06 851 30 834.36 833.63 -34.96 1.70 6037316 52 516540 02 70.51313837 - 149.86463838 3103 34 49.73 6.16 2780.78 2833.98 510 90 853.85 836.88 836 16 -34 69 1.70 6037319.06 516540.29 70.51314529 -149.86483612 3200 00 50 49 5.56 2842.77 2895 97 564.12 928.01 910.34 909.94 -27.12 0.92 6037392.84 516547.69 70.51334683 - 149.86457418 3200 18 50.49 5.56 2842.88 2896.08 564.22 928.15 910.48 910.07 -27 10 0 92 6037392.98 516547 71 70.51334721 - 149.86457407 3293.79 50.04 5.97 2902.72 2955.92 615.80 1000.14 981.90 981.70 -19.87 0.59 6037464.61 516554 78 70 51354288 - 149.86451490 3300 00 50.11 6.02 2906.71 2959 91 61922 1004.90 986.62 986 43 -19.38 1.24 6037469.35 516555 26 70.51355581 - 149.86451083 3390.53 51.09 6.72 2964.17 3017.37 669 86 1074 85 1056.02 1055.95 -11.61 1.24 6037538.88 516562.87 70.51374573 - 149.86444731 3400 00 51.01 6.82 2970.13 3023 33 675.22 1082.22 1063.32 1063.27 -10.75 1.16 6037546.19 516563.72 70.51376571 - 149.86444020 3486.68 50.33 7 77 3025.06 3078.26 724 49 1149.27 1129.78 1129.77 -2.23 1.16 6037612.71 516572_09 70.51394740 - 149.86437054 3500 00 50.43 7.54 3033.55 3086 75 732.08 1159.53 1139.94 1139.94 -0.87 1.50 6037622 88 516573.43 70.51397518 - 149.86435935 3579 59 51.02 6.20 3083.94 3137.14 777 04 1221.14 1201.13 1201.11 6.50 1.50 6037684.06 516580 66 70.51414227 - 149.86429906 3600 00 50 68 6.89 3096 83 3150.03 788.53 1236 96 1216.86 1216 83 8.31 3 11 6037699 78 516582_43 70 51418523 - 149.86428429 3604.35 50.61 7.04 3099 58 3152 78 790.99 1240.33 1220 20 1220 17 8 71 3.11 6037703.12 516582 83 70.51419435 - 149.86428096 3700.00 51.19 6 97 3159 91 3213.11 845 28 1314.56 1293.97 1293 85 17 77 0 61 6037776.81 516591 72 70.51439563 - 149.86420687 3701.02 51 20 6 97 3160.54 3213.74 845 86 1315.35 1294.76 1294 64 17.86 0.61 6037777.60 516591.81 70.51439778 - 149.8642060 3795 07 48.59 7.94 3221.13 3274.33 898.85 1387.28 1366.23 1365 96 27.18 2.89 6037848.94 516600 97 70.51459262 - 149 86412980 3800 00 48.66 7.85 3224.39 3277.59 901.59 1390.98 1369.90 1369 62 27.69 1 92 6037852.60 516601.47 70.51460263 - 149 86412564 3891.67 49.92 6.23 3284 18 3337 38 952.43 1460.46 1439 04 1438.58 36.20 1.92 6037921 57 516609 83 70 51479101 - 149.86405602 3900 00 50.02 6.29 3289.54 3342 74 957.04 1466.84 1445 39 1444.92 36.90 1.32 6037927 91 516610 51 70.51460833 - 149.86405033 3988.48 51.07 6 96 3345 76 3398.96 1006 70 1535.16 1513.44 1512 78 44.78 1.32 6037995.78 516618 24 70.51499371 - 149 86398578 4000.00 50.99 6.99 3353 01 3406.21 1013 25 1544 11 1522 36 1521 67 45.87 0 71 6038004 67 516619.31 70.51501800 - 149 86397688 4081 40 50.43 7.17 3404.55 3457 75 1059.38 1607.11 1585.10 1584 19 53.63 0.71 6038067 20 516626 93 70.51518879 - 149.86391335 4100.00 50.81 6.57 3416.35 3469.55 1069.87 1621.49 1599.42 1598.46 55 35 3.24 6038081.48 516628.62 70.51522779 - 149.86389928 4179 49 52.48 4.06 3465.68 3518 88 1114.17 1883 82 1661.65 1660 52 61 11 3 24 6038143.54 516634 23 70.51539732 - 149 86385217 4200.00 52.53 4 48 3478 17 3531 37 1125.53 1700 09 1677.91 1676 75 62.32 1 64 6038159 77 516635 41 70.51544166 - 149 86384226 4273.14 52 74 5.97 3522 55 3575.75 1166 80 1758.22 1735 95 1734.64 67.61 1.64 6038217.67 516640 57 70 51559980 - 149.86379892 4300.00 52 42 6.11 3538.87 3592 07 1182.15 1779.56 1757 24 1755 85 69.86 1.27 6038238 88 516642 77 70 51565775 - 149.86378054 4370 52 51.58 6.50 3582 29 3635 49 1222.33 1835.13 1812 68 1811 08 75 96 1.27 6038294 12 516648.75 70 51580864 - 149.86373059 4400 00 51.90 5 66 3600 55 3653.75 1239 01 1858.28 1835.78 1834 10 78 41 2.49 6038317.15 516651.15 70.51587152 - 149.86371052 4464 80 52.64 3.84 3640.20 3693 40 1275.08 1909.53 1886 99 1885 17 82.65 2.49 6038368 22 516655 28 70 51601104 - 149.86367582 4500 00 53.02 4 33 3661.47 3714 67 1294.60 1937.57 1915.02 1913 15 84.65 1.54 6038396 20 516657 21 70 51608748 - 149 86365947 4534 04 53.39 4 79 3681 85 3735 05 1313.72 1964.83 1942 27 1940 32 86 82 1 54 6038423.38 516659 32 70 51616171 - 149.86364174 13 -3f8" Csg 4595 00 53 34 4 94 3718 23 3771 43 1348.23 2013.75 1991.14 1989 07 90.96 0.21 6038472.12 516663.35 70.51629486 - 149.86360780 4600 00 53.33 4.95 3721 22 3774 42 1351.06 2017.76 1995 15 1993 06 91 31 0 21 6038476.12 516663 69 70.51630577 - 149.86360497 011199 Office 200917160 939900130019612) Point 10P234105210P23gW9U210P23NNV2 11/22)20105390M Page 2615 MD Inc! Azim True TVDSS TVD VSEC AHD Closure NS EW DLS Northing Easting Latitude Longitude Comments (ft) ( ( (ft) (ft) (ft) (ft) (ft) (ft) (ft) 1 ° /100ft) (ftUS) IUS) 1 ° 1 ( 4638 94 53.30 5 04 3744.48 3797 68 1373 -14 2048.99 2026 35 2024 17 94 03 0.21 6038507 23 516666 34 70 51639076 -149 86358272 4671.22 53.34 4 64 3763.76 3816.96 1391 39 2074.88 2052 22 2049 97 96 21 1.00 6038533 03 516668 47 70 51646123 -149 86356484 4700 00 53.20 4.94 3780 97 3834.17 1407.65 2097 94 2075 27 2072 95 98.14 0.97 6038556 01 516670.34 70 51652402 -149 86354907 4735 67 53.03 5.32 3802 38 3855 58 1427.87 2126 47 2103.78 2101 37 100 69 0 97 6038584.43 516672 83 70 51660165 - 149.86352818 4800.00 53.08 4.91 3841 05 3894.25 1464 29 2177 89 2155 15 2152 57 105.27 0.51 6038635.65 516677 30 70 51674154 - 149.86349065 4832 10 53 10 4.71 3860.33 3913 53 1482 38 2203.55 2180 80 2178.15 107.43 0.51 6038661 22 516679 40 70_51681141 - 149 86347303 4900 00 53 06 4.69 3901 11 3954 31 1520.57 2257.84 2235.06 2232 25 111 87 0.06 6038715.33 516683.72 70 51695921 - 149.86343662 4925.31 53.05 4 68 3916.33 3969.53 1534.79 2278.07 2255.27 2252 41 113 53 0.06 6038735 49 516685.33 70 51701429 - 149.86342310 5000.00 52.90 4 37 3961.30 4014.50 1576.61 2337.70 2314 88 2311 86 118 23 0 38 6038794.94 516689.90 70.51717669 - 149 86338458 5022.27 52.86 4.28 3974 74 4027.94 1589.01 2355.46 2332.63 2329 57 119 57 0 38 6038812.65 516691.20 70 51722506 - 149.86337361 5100.00 52 53 5.32 4021.85 4075.05 1632.58 2417.28 2394 43 2391.18 124.74 1.14 6038874.27 516696 23 70.51739337 - 149.86333128 5119.59 52.45 5.58 4033.78 4086 98 1643.65 2432.82 2409.96 2406 65 126.22 1.14 6038889 74 516697 67 70.51743563 - 149.86331920 5200.00 51 99 7.60 4083 04 4136.24 1689.81 2496.37 2473 38 2469 77 133 51 2.07 6038952.88 516704 82 70 51760809 - 149.86325953 5208 71 51.94 7 82 4088 41 4141.61 1694.89 2503.23 2480.22 2476 57 134.43 2.07 6038959 68 516705.73 70 51762666 - 149.86325200 5300.00 51.98 7.33 4144 67 4197.87 1747.96 2575.13 2551.90 2547 84 143 90 0.43 6039030.96 516715.04 70 51782135 -149 86317443 5312.49 51 98 7.26 4152.36 4205 56 1755.19 2584.97 2561.72 2557.60 145 15 0.43 6039040.72 516716.27 70.51784801 - 149.86316420 5400.00 52.03 7.82 4206.23 4259 43 1806.07 2653.93 2630.49 2625.97 154.20 0.51 6039109.10 516725.16 70.51803479 - 149.86309014 5408 40 52.04 7.87 4211 39 4264 59 1810 97 2660.56 2637 10 2632 53 155.10 0.51 6039115.66 516726 05 70 51805271 - 149.86308274 5500 00 52.06 6 65 4267.73 4320.93 1864 02 2732.79 2709.16 2704.18 164 23 1.05 6039187 32 516735.02 70 51824844 - 149.86300799 5503 36 52 06 6 61 4269.79 4322.99 1865.95 2735 44 2711 81 2706.81 164 54 1.05 6039189.96 516735.32 70 51825564 -149 86300549 5600.00 52.19 6.85 4329.13 4382.33 1921.49 2811 72 2787.97 2782 57 173.48 0.24 6039265.73 516744.09 70.51846259 -149 86293231 5600.53 52.19 6.85 4329.45 4382.65 1921.80 2812.14 2788.39 2782 98 173.53 0.24 6039266 14 516744 14 70 51846373 - 149.86293190 5694.09 52.11 6.47 4386 86 4440.06 1975 53 2886.01 2862.16 2856 36 182.10 0.33 6039339.53 516752 54 70.51866419 - 149.86286175 5700 00 52.12 6.44 4390 49 4443.69 1978.91 2890.68 2866.82 2861 00 182.62 0 47 6039344.17 516753 06 70 51867685 - 149.86285746 5791.04 52.28 5.93 4446 29 4499.49 2030.82 2962.61 2938.69 2932 51 190.37 0.47 6039415.69 516760.65 70 51887222 - 149.86279402 5800.00 52.26 5.75 4451 77 4504 97 2035 90 2969 70 2945.77 2939 56 191 09 1.56 6039422.74 516761 35 70.51889148 -149 86278812 5887.58 52 13 4.03 4505 45 4558 65 2084.74 3038.90 3014.95 3008.51 196.99 1.56 6039491.69 516767.10 70.51907982 - 149 86273980 5900 00 52.16 4.27 4513.07 4566.27 2091 57 3048.70 3024.76 3018 29 197 70 1.53 6039501 47 516767 79 70.51910654 - 149.86273399 5983 37 52.40 5.85 4564.08 4617.28 2138.24 3114.65 3090 68 3083.98 203 52 1.53 6039567.17 516773 45 70.51928599 - 149.86268637 6000 00 52.40 5.88 4574 23 4627.43 2147.70 3127 83 3103 85 3097.08 204,86 0.16 6039580.28 516774.77 70 51932179 - 149.86267534 6077.23 52.39 6.04 4621 36 4674 56 2191.68 3189 01 3164.99 3157.93 211.22 0.16 6039641.14 516780.99 70.51948803 - 149 86262331 6100 00 52.43 5.91 4635.25 4688 45 2204.66 3207.05 3183.02 3175 88 213.10 0.48 6039659.08 516782.83 70.51953706 - 149 86260793 6174 42 52.56 5 49 4680 55 4733.75 2246.91 3266.09 3242.03 3234.62 21896 0.48 6039717.84 516788 56 70.51969754 -149 86255992 6200 00 52.23 5 27 4696.16 4749 36 2261.34 3286.36 3262 29 3254 80 220 86 1.46 6039738.01 516790.41 70 51975266 - 149.86254436 6267 16 51.37 4 68 4737 70 4790.90 2298.64 3339 13 3315.05 3307 38 22544 1.46 6039790 60 516794 88 70.51989630 - 149.86250687 6300 00 51.27 4.28 4758.22 4811.42 2316.60 3364.77 3340.69 3332.94 227.44 1.00 6039816.16 516796.82 70 51996612 - 149 86249048 6363 70 51.09 3 49 4798.15 4851.35 2351.01 3414.40 3390.32 3382.45 230.80 1.00 6039865.68 516800 07 70.52010139 - 149 86246295 6400.00 51 11 3 82 4820 95 4874.15 2370.51 3442.65 3418 57 3410.65 232 60 0.72 6039893 87 516801 81 70.52017841 - 149.86244819 6459.34 51.14 4.37 4858 19 4911.39 2402.65 3488.85 3464.77 3456.72 235 91 0.72 6039939.95 516805.01 70.52030428 - 149 86242116 6500 00 51.16 4.43 4883.70 4936 90 2424.81 3520 51 3496.43 3488.30 238.33 0.12 6039971.52 516807.36 70 52039053 - 149.86240127 6556.10 51.18 4.51 4918 87 4972.07 2455 42 3564.21 3540 13 3531 87 241.74 0.12 6040015.10 516810 67 70.52050956 - 149 86237338 6600.00 51.32 4.49 4946 35 4999.55 2479.42 3598.45 3574.36 3566.00 244 43 0 33 6040049.23 516813.28 70 52060280 - 149.86235138 6654 26 51.50 4.46 4980.19 5033 39 2509.13 3640 86 3616.77 3608.28 247 73 0.33 6040091.52 516816.50 70 52071831 - 149 86232429 6700.00 50.87 4 00 5008.86 5062.06 2533.99 3676 50 3652.41 3643 82 250.36 1.58 6040127.06 516819.05 70.52081541 - 149.86230275 6750 35 50.18 3 49 5040 87 5094.07 2560.87 3715.37 3691.28 3682 60 252.90 1.58 6040165.84 516821 50 70.52092135 - 149 86228194 6800.00 50.00 3.26 5072.73 5125 93 2587.02 3753.45 3729.36 3720 62 255.14 0.51 6040203.86 516823.66 70 52102521 - 149.86226359 6845.23 49.84 3.04 5101.85 5155 05 2610.69 3788 06 3763.97 3755.18 257 05 0.51 6040238.42 516825.48 70 52111961 - 149.86224803 6900 00 49 77 2 99 5137 19 5190 39 2639.23 3829 90 3805.80 3796.96 259.25 0.14 6040280.20 516827.59 70 52123375 - 149 86223000 6942.66 49.72 2.95 5164.76 5217.96 2661.42 3862.46 3838 35 3829 47 260.93 0.14 6040312.72 516829.20 70.52132257 - 149.86221618 7000 00 49.83 2.65 5201.79 5254.99 2691.17 3906.24 3882.12 3873 20 263.07 0.44 6040356.44 516831.24 70.52144203 - 149 86219865 7036.01 49.90 2.47 5225 00 5278.20 2709 79 3933 77 3909.65 3900.70 264.30 0.44 6040383.95 516832.41 70 52151716 - 149 86218856 7100 00 49 85 2.24 5266 24 531944 2742.76 3982.70 3958 56 3949.59 266.31 0.29 6040432.83 516834.31 70 52165072 -149 86217210 7132.39 49.83 2 12 5287 13 5340.33 2759.38 4007.45 3983.30 3974 33 267.25 0.29 6040457.57 516835 20 70.52171830 - 149.86216439 ' 7200.00 49.80 2.74 5330 75 5383.95 2794.23 4059.10 4034.94 4025 93 269.44 0.70 6040509.18 516837.27 70 52185928 - 149 86214645 7227 47 49.79 2 99 5348.49 5401 69 2808.50 4080.08 4055 92 4046.89 270.49 0 70 6040530.13 516838.27 70 52191652 - 149.86213786 7300 00 49.49 4 23 5395.46 5448.66 2846.62 4135 35 4111 18 4102.04 273 97 1.37 6040585.29 516841 63 70 52206719 - 149.86210937 7324 45 49.39 4.65 5411.35 5464 55 2859.62 4153.92 4129 76 4120 56 275 41 1.37 6040603.81 516843.02 70 52211779 - 149.86209759 7400 00 49 17 4.92 5460.64 5513 84 2899.96 4211.18 4187 01 4177 62 280 18 0 39 6040660 87 516847.67 70.52227367 - 149 86205848 7417 80 49.12 4 98 5472.28 5525.48 2909.47 4224.65 4200.47 4191.04 281 34 0 39 6040674.29 516848 80 70 52231031 -149 86204897 7500.00 49 57 464 5525.84 5579.04 2953.42 4287 01 4262.82 4253.18 286 57 0.63 6040736.43 516853.89 70 52248007 - 149.86200614 7512 71 49.64 4 59 5534.07 5587 27 2960.22 4296.69 4272 50 4262 82 287 35 0.63 6040746.08 516854.65 70.52250643 -149 86199976 7600 00 49.65 4 59 5590.60 5643 80 3006 91 4363 21 4339 01 4329 13 292.68 0.01 6040812 39 516859 82 70.52268756 - 149 86195616 7610 74 49 65 4 59 5597.55 5650 75 3012.66 4371.39 4347 20 4337 29 293 33 0 01 6040820.55 516860 46 70 52270985 - 149 86195079 7700.00 49 89 5 35 5655 20 5708.40 3060.82 4439.54 4415 33 4405.18 299.24 0 70 6040888 44 516866 21 70 52289531 - 149 86190242 0r0lag Office 2009 1 716 0 1 bk P0fl2OP23 -0lMV2 OP29 -W0 O2\OP23VJ✓W2 11/2272010539 PM Page 3 of 5 Comments MD Inc) Azim True TVDSS TVD VSEC AHD Closure NS EW OLS Northing Easting Latitude Longitude (ft) ( °) (°I (ft) (ft) (ft) (ft) (ft) (ft) (ft) (1100ft) (ftUS) (ftUS) (°) ( °) 7705.59 49 90 5 40 5658.80 5712.00 3063 86 4443 81 4419.60 4409 43 299 64 0 70 6040892 70 516866 61 70.52290694 -149 86189914 7800.00 49 56 5 32 5719.83 5773 03 3115 12 4515 84 4491 61 4481.15 306 37 0.37 6040964.43 516873 17 70 52310286 -149 86184402 7801.40 49 55 5.32 5720 74 5773.94 3115 88 4516 91 4492.68 448221 306.47 0.37 6040965 49 516873.27 70.52310576 - 149.86184321 7898 59 49.73 5.15 5783 68 5836 88 3168.46 4590 97 4566 71 4555 96 313.22 0 23 6041039.24 516879 86 70.52330723 - 149 86178787 7900 00 49 73 5.16 5784.59 5837 79 3169 22 4592.04 4567.79 4557 03 313.32 0 75 6041040.32 516879 96 70.52331015 - 149 - 86178707 7994.57 49 97 6.04 5845 57 5898 77 3220 87 4664.33 4640.04 4628 97 32038 0 75 6041112.26 516886 85 70.52350668 - 149 86172927 8000.00 49.98 6.08 5849.06 5902 26 3223 86 4668.49 4644.20 4633 11 320 81 0 55 6041116.40 516887 28 70.52351798 -149 86172568 8088 34 50.08 6.70 5905.81 5959 01 3272.88 4736.19 4711.84 4700.39 328.35 0 55 6041183.69 516894 66 70 52370177 -149 86166397 8100.00 50.09 6.64 5913.29 5966.49 3279 38 4745.13 4720.77 4709 27 329 39 0.43 6041192.57 516895 68 70.52372604 - 149 86165547 8184 35 50 17 6.17 5967.36 6020.56 3326.27 4809.87 4785.46 4773.60 336.61 0.43 6041256.92 516902.76 70 52390179 - 149.86159634 8200.00 50.20 6.22 5977.39 6030.59 3334.94 4821 89 4797.47 4785.55 337.90 0 31 6041268.87 516904.03 70 52393444 - 149 86158571 8282 83 50 35 6 49 6030.32 6083.52 3381.04 4885 60 4861.12 4848.87 344.96 0.31 6041332.19 516910.94 70.52410741 - 149.86152795 8300 00 50.09 6.24 6041.31 6094.51 3390.59 4898.79 4874.31 4861.98 346.42 1.89 6041345.31 516912.37 70.52414323 - 149.86151597 8378 29 48 92 5.05 6092.15 6145 35 3433.16 4958.33 4933.82 4921.23 352.28 1.89 6041404.56 516918.10 70.52430508 - 149.86146798 8400.00 48 82 5.09 6106.43 6159.63 3444.74 4974.68 4950 17 4937.52 353 72 0 49 6041420.85 516919.51 70.52434958 - 149.86145614 8474.14 48 47 5.22 6155.42 6208.62 3484 20 5030.33 5005.81 4992.94 358.72 0.49 6041476.28 516924.38 70.52450099 - 149.86141519 8500 00 48 49 5 11 6172.56 6225.76 3497.93 5049 69 5025.17 5012 22 360.46 0 34 6041495.57 516926 08 70 52455367 - 149 86140091 8564.51 48 54 4.82 6215.29 6268.49 3532 08 5098 02 5073.49 5060.37 364.64 0 34 6041543 72 516930.15 70 52468519 - 149.86136666 8600 00 48 62 5 00 6238.77 6291.97 3550.87 5124 63 5100.10 5086.89 366.92 0.45 6041570.23 516932.37 70.52475763 - 149.86134800 8665 89 48 78 5.33 6282.26 6335.46 3585 97 5174.13 5149 60 5136.19 371.38 0 45 6041619 54 516936.72 70 52489232 - 149.86131150 8700.00 48 77 5.18 6304 74 6357.94 3604.19 5199 79 5175.25 5161.73 373.73 0.33 6041645.09 516939 01 70 52496211 - 149.86129225 8762 39 48.75 4.91 6345.86 6399.06 3637 39 5246.70 5222.15 5208.47 377.85 0.33 6041691.83 516943 03 70.52508977 - 149 86125844 8800 00 48.91 4.88 6370.62 6423.82 3657 37 5275.01 5250.46 5236 67 380 27 0.44 6041720.04 516945 38 70 52516683 - 149.86123865 8857 33 49.16 4 83 6408 21 6461.41 3687.91 5318.31 5293.75 5279.81 383 93 0.44 6041763.18 516948.95 70.52528467 - 149 86120864 8900.00 49 15 4 83 6436.11 6489.31 3710 66 5350.59 5326.03 5311.98 386.65 0 02 6041795 35 516951.60 70.52537254 - 149 86118637 8953.58 49 14 4.83 6471.16 6524.36 3739.24 5391 11 5366.55 5352 36 390.06 0 02 6041835 73 516954.92 70.52548286 - 149 86115842 9000 00 49 14 4.66 6501.53 6554.73 3763.95 5426 22 5401.66 5387.35 392 97 0.27 6041870.72 516957.74 70 52557844 -149 86113462 9033.38 49 14 4.54 6523 37 6576.57 3781.68 5451 46 5426.90 5412.51 394 99 0.27 6041895 89 516959.71 70 52564719 - 149.86111803 9-58" Csg 9087.00 50.48 3.77 6557.97 6611.17 3810.21 5492.42 5467.86 5453.36 397 96 2 73 6041936.74 516962.58 70.52575879 -149 86109374 9100.00 50.80 3.58 6566.21 6619 41 3817 15 5502.48 5477.91 5463.39 398.60 2.73 6041946.77 516963 21 70 52578619 - 149.86108846 9142 94 51.88 2.99 6593.04 6646 24 3840 14 5536.01 5511 44 5496 87 400 52 2.73 6041980.25 516965.05 70.52587764 - 149.86107272 9200.00 51 00 3 19 6628.60 6681.80 3870 62 5580.62 5556.05 5541.42 402 93 1.56 6042024.80 516967.36 70.52599935 - 149.86105301 9238.50 50 41 3.33 6652 99 6706.19 3891.04 5610 42 5585.84 5571 17 404.62 1 56 6042054 55 516968.99 70 52608062 - 149.86103912 9300.00 49 71 3.16 6692.47 6745.67 3923 34 5657 57 5632.99 5618.25 407 29 1.15 6042101 63 516971.55 70.52620923 - 149 86101722 9331.13 49.36 3.08 6712.67 6765.87 3939.53 5681 26 5656.67 5641.90 408.58 1.15 6042125.28 516972 79 70.52627383 - 149.86100665 9400.00 47.95 2.58 6758 16 6811.36 3974 68 5732.96 5708.36 5693 54 411.14 2.11 6042176.92 516975 23 70.52641491 - 149.86098570 9429.57 47.35 2 36 6778.08 6831.28 3989 44 5754 82 5730.21 5715 37 412 08 2.11 6042198 75 516976 12 70.52647455 -149 86097797 9500.00 45 76 2.43 6826 51 6879.71 4023.92 5805.95 5781.32 5766 46 414.22 2.25 6042249.84 516978.15 70 52661412 -149 86096044 9525.42 45 19 2.46 6844.33 6897.53 4036.15 5824.07 5799.43 5784.57 414.99 2.25 6042267.95 516978.88 70 52666359 - 149.86095410 9600 00 43.39 2.98 6897.72 6950.92 4071_48 5876 15 5851.49 5836.58 417.46 2.46 6042319.97 516981 23 70.52680569 - 149.86093385 9621 18 42.88 3.14 6913.17 6966 37 4081 36 5890.63 5865.97 5851.04 418.23 2.46 6042334.43 516981.97 70.52684519 - 149.86092751 9700.00 39 88 5 81 6972.31 7025.51 4117.83 5942 73 5918 06 5902 98 422.27 4 41 6042386 36 516985.89 70.52698707 - 149.86089449 9716 85 39 25 6 43 6985.30 7038.50 4125.57 5953.46 5928.79 5913 65 423 41 4.41 6042397.04 516987.01 70.52701622 - 149 86088511 9800 00 35.46 9.14 7051 39 7104.59 4162.89 6003 89 5979.12 5963.62 430.19 4 97 6042447.02 516993.68 70 52715274 - 149 86082957 9813.02 34.87 9.61 7062.03 7115.23 4168.58 6011 39 5986.58 5971.02 431.41 4.97 6042454.42 516994.88 70 52717295 - 149.86081957 9900.00 31.55 7.82 7134.80 7188 00 4204 39 6059 02 6034.06 6018.09 438.66 3.98 6042501.50 517002 02 70.52730154 - 149.86076019 9909 97 31 17 7.59 7143.31 7196.51 4208.22 6064.21 6039.24 6023.23 439.35 3.98 6042506 65 517002 71 70.52731559 - 149 86075449 10000 00 27.93 6 71 7221 62 7274.82 4240 78 6108.60 6083 57 6067.28 444.90 3 63 6042550.70 517008.15 70.52743592 - 149.86070908 10005.56 27.73 6.65 7226.54 7279 74 4242.67 6111 20 6086.16 6069.86 445.20 3.63 6042553.28 517008.45 70 52744296 - 149.86070661 10100 00 23.57 7.85 7311 65 7364.85 4272 66 6152 07 6126.98 6110.41 450.32 4 44 6042593.84 517013.48 70.52755373 - 149.86066462 1010140 23 51 7.87 7312.94 7366.14 4273.08 6152.63 6127.54 6110.96 450.40 4.44 6042594.39 517013.56 70.52755524 - 149.86066399 ■ 10198 60 19.07 6.97 7403 48 7456.68 4299 08 6187 91 6162.76 6145.94 454.98 4 58 6042629 38 517018.06 70 52765081 - 149 86062644 10200 00 19.00 6 99 7404 81 7458.01 4299 41 6188 37 6163.22 6146.40 455 04 4.83 6042629.83 517018.12 70 52765205 -149 86062598 10293.77 14.51 8.90 7494.57 7547.77 4319 6215 39 6190.19 6173.17 458.72 4 83 6042656 61 517021 73 70.52772519 - 149.86059585 10300 00 14 36 8.93 7500 60 7553 80 4320.61 6216.95 6191 74 6174.70 458 96 2 35 6042658 15 517021.97 70 52772938 - 149.86059388 10388.70 12.28 9.50 7586.91 7640 11 4336.08 6237.38 6212.10 6194.88 462 22 2.35 6042678.32 517025.19 70.52778449 - 149 86056713 10400 00 12 24 9 57 7597 96 7651.16 4337 90 6239 78 6214.49 6197.24 462.62 0 40 6042680 69 517025.58 70.52779096 - 149.86056387 10485.83 11 91 10 12 7681.89 7735.09 4351.62 6257 74 6232.36 6214 93 465 69 0 40 6042698 38 517028.61 70.52783928 - 149.86053874 10500.00 11.83 10 16 7695.75 7748.95 4353.86 6260 65 6235 26 6217.80 466 20 0 56 6042701.25 517029.12 70.52784712 - 149.86053453 10579.02 11.39 10 36 7773 16 7826 36 4366.09 6276.55 6251.07 6233.45 469 03 0.56 6042716.91 517031 91 70.52788987 -149 86051134 10600.00 11 26 10 52 7793.73 7846.93 4369.26 6280 67 6255.17 6237.50 469 78 0 63 6042720 96 517032 65 70.52790094 -149 86050522 10674 81 10 80 11.11 7867.16 7920 36 4380 36 6294.99 6269.39 6251 56 472.46 0 63 6042735.03 517035 30 70 52793934 - 149.86048324 10700 00 10 77 11.22 7891 90 7945 10 4384 03 6299.70 6274 07 6256.19 473 38 0 16 6042739 65 517036 21 70 52795197 -149 86047576 Dn188 Office 2009 1 716 0 NrkaacMp000 °k Pooa \OP2W20V2\OP23.WA02\OP23 -1MW2 11/22/20105 30 PM Page 4 of 5 MD Ind Azim True TVDSS TVD VSEC AHD Closure NS EW OLS Northing Easting Latitude Longitude Comments (ft) (e) (e) (ft) (ft) (ft) (ft) (ft) (ft) (ft) (1100ft) (ftUS) (ftUS) (°) ( ° 1 10771 89 10 67 11 54 7962.54 8015.74 4394 47 6313 07 6287.34 6269 29 476 02 0 16 6042752.76 517038.82 70.52798778 - 149 86045415 10800.00 10 62 11 69 7990.16 8043 36 4398 54 6318.26 6292.49 6274 38 477 06 0.19 6042757.85 517039.85 70.52800168 - 149 86044559 10866.97 10 51 12 04 8056.00 8109 20 4408 20 6330.54 6304.66 6286.40 479 59 0.19 6042769.87 517042.35 70.52803451 - 149 86042491 10900 00 10 34 1223 8088 48 8141.68 4412 92 6336.52 6310.59 6292.24 480.84 0.52 6042775.72 517043 59 70 52805047 -149 86041462 10964.46 10 01 12.62 8151.93 8205.13 4421.95 6347.91 6321 86 6303 36 483.29 0.52 6042786 84 517046.01 70 52808085 -149 86039455 11000.00 9 67 12 89 8186 95 8240.15 4426.78 6353.98 6327.87 6309.29 484.63 0 97 6042792 77 517047.34 70 52809703 - 149 86038357 11060.34 9 09 13 39 8246 48 8299.68 4434.65 6363.82 6337.59 6318.86 486 87 0 97 6042802.35 517049.55 70.52812319 - 149 86036527 11100.00 8 77 14.09 8285 66 8338 86 4439 61 6369.97 6343.67 6324 84 488 33 0.84 6042808.33 517051.00 70.52813953 -149 86035330 11154 80 834 15.15 8339.85 8393.05 4446 26 6378.13 6351.69 6332.73 490 38 0.84 6042816.23 517053.04 70.52816109 - 149.86033645 11200.00 8.12 13.88 8384.58 8437.78 4451 53 6384.60 6358.06 6339.00 492 01 0.63 6042822.49 517054.65 70.52817820 - 149.86032316 11248 58 7.89 12.44 8432.69 8485.89 4456 94 6391 36 6364.75 6345 58 493.55 0.63 6042829 08 517056 18 70 52819619 - 149.86031053 11300.00 8 48 7 53 8483.59 8536.79 4462.54 6398.68 6372 03 6352.79 494.81 1.77 6042836.29 517057.42 70.52821587 - 149.86030024 11345.26 9.04 3.76 8528.32 8581.52 4467.46 6405.57 6378 92 6359.64 495.48 1 77 6042843 15 517058.07 70 52823460 - 149.86029474 11400.00 8 79 3.30 8582 40 8635.60 4473.30 6414.05 6387.40 6368 11 496 00 0.48 6042851_61 517058.58 70.52825773 - 149.86029046 11441.16 8.60 2.93 8623 08 8676.28 4477.55 6420.27 6393.62 6374.32 496.34 0.48 6042857.83 517058.90 70.52827470 - 149 86028769 11500 00 8.34 2.76 8681.28 8734.48 4483 45 6428 94 6402.28 6382.98 496 77 0.44 6042866.48 517059.31 70.52829835 - 149.86028416 11537.68 8.18 2.64 8718.57 8771.77 4487 12 6434 35 6407 69 6388.39 497.02 0.44 6042871.89 517059.55 70.52831313 - 149.86028207 11600.00 8 13 2.58 8780.26 8833.46 4493.10 6443.19 6416.53 6397 22 497_42 0 08 6042880.72 517059.94 70.52833725 - 149.86027877 11636.52 8.10 2.54 8816 41 8869 61 4496.59 6448 35 6421.68 6402.37 497 65 0.08 6042885 87 517060.15 70 52835132 - 149.86027688 11700 00 800 2.73 8879.27 8932.47 4502.61 645724 6430.57 6411.25 498 06 0.17 6042894.75 517060.54 70.52837558 - 149 86027353 11730.24 7 95 2 82 8909.22 8962.42 4505.46 6461 43 6434.76 641544 498 27 0.17 6042898.94 517060.74 70.52838703 - 149 86027186 11800.00 786 2 94 8978.31 9031.51 4511 99 6471.03 6444.35 6425.02 498 75 0.13 6042908 53 517061.20 70.52841321 - 149 86026791 11824 78 7 83 2.99 9002.86 9056.06 4514.29 6474 41 6447.73 6428.40 498 92 0 13 6042911 90 517061.37 70 52842243 - 149.86026647 11900 00 7.83 2.91 9077.38 9130.58 4521.28 6484.66 6457.98 6438 63 499.45 0 01 6042922 14 517061 87 70 52845039 -149 86026215 11919 03 7.83 2 89 9096.23 9149.43 4523.04 6487.25 6460.57 6441.22 499 58 0 01 6042924.73 517062.00 70.52845746 - 149.86026107 12000.00 7.74 2.68 9176.46 9229.66 4530.49 6498.22 6471 53 6452 18 500 11 0.12 6042935 68 517062.50 70 52848739 - 149.86025670 12015.86 7.72 2.64 9192.17 9245.37 4531.94 6500.35 6473.66 6454.31 500 21 0.12 6042937.81 517062.60 70.52849321 - 149.86025589 12100.00 7 63 2 82 9275.56 9328.76 4539.56 6511.59 6484.90 6465.54 500 75 0.11 6042949.04 517063.11 70.52852388 - 149 86025150 1211315 7 62 2 85 9289 19 9342.39 4540 80 6513.42 6486.72 6467.36 500 84 0 11 6042950 86 517063.19 70.52852886 - 149 86025076 12200.00 7.55 2.30 9374.68 9427.88 4548 50 6524.80 6498.10 6478 73 501_35 0 12 6042962.23 517063 68 70 52855992 - 149.86024656 12209.18 754 2.24 9383.78 9436.98 4549.31 6526 00 6499.30 6479 93 501 40 0 12 6042963 44 517063.73 70 52856321 - 149.86024617 12254.55 7 07 1 79 9428.78 9481.98 4553.18 6531.77 6505 07 6485 70 501.60 1.04 6042969.20 517063.92 70.52857896 - 149 86024450 12323 00 7 07 1 79 9496.71 9549.91 . 4558.79 6540.20 6513.48 6494 12 501 87 0.00 6042977.62 517064.16 70.52860197 - 149 86024234 Survey Error Model: ISCWSA Rev 0 "` 3 -D 95 000% Confidence 2.7955 sigma Survey Program: MD From MD To EOU Freq (ft) Survey Tool Type Borehole / Survey (ft) (ft) 0.00 41.00 Act Stns SLB_MVVD +GMAG -Depth Only OP23- VVVV02 1 OP23 -VVW02 41.00 12323.00 Act Stns SLB MWD +GMAG OP23 -VWV02 / OP23 -WW02 Legal Description: Northing (Y) Easting (X) Surface 3130.1 FSL 1703.5 FEL S5 T13N R9E UM 6036483.06 516576 84 BHL' 4344 FSL 1182 FEL 32 T14N R9EUM 6042977.62 517064.16 ltalisized markers are not part of the final definitive calculation • Final Definitive Survey Verify and Sign-off I have checked to the best of my ability that the following data is correct: Surface Coordinates and Reference Elevations Declination Information Survey Tool Codes I SLB DE: Client Representative: Date' DO, Office 20091 >160 Nlkaitc.,101■k1o■ Pont10P23- YJrW210P23 -MO210 3 -wJY02 11222010 539 PM Page 5 .5 ■ • • DIRECTIONAL - OP23 -VWV02 (Completion), 11/22/2010 5:36:13 PM MD (ftl<I3) TVD ftKB ) Inc! ( ) DLS Vertical schematic (actual) DLS (°t10... -4.9 -4,9 0.0 0.00 -2 ... 2 1; RKB Nab 245; 13 318 -6.3-31.6; 30.95 0.0 0.0 0.0 3 - 1 ; RKB; 9 5/8; -2.1-33.6; 35 67 _4-1;RKB;9518: -2.1. 33.6;35.67 28.9 28.9 0.1 2.3; Top pup 4-1/2 Vam Top box x pin; 4112;3.958,28.9.33.1 4.21 33.1 33.1 0 . 1 r42; CASING HGR; 9 518; 33.6.34.4; 0.78 -43; CSG PUP; 9 5 /8; 8.681; 34.436.3; 1.91 34.4 34.4 0.1 /:, 22#4---6423::, -2 -4; Vacuum Insulated Tubing (VIT), 4112 Vbm Top box x; 6; 3.958; 33.1. 135. 102.56 2.5; Space out pup, 4112 12.69 Vain Top box x pin, 4112; 3.958; 135.7 - 158.3; 22.65 ' ` " < 135.8 135.8 0.3 2 -6; Tubing 21, 4112 12.69 Vain Top box x pin; 4 1/2; 3.958, 158.3- 2,212.2, 2,053.82 160.1 160.1 0.3 ,r2-7; Pup Jt, 41/2 12.69 Vam Top box x pin; 4 1/2; 3.958; 2.212 2- 2,215.0; 2,84 / 2 -8, SSSV, 41/2 TRMA10655, 41/2 12.69 Vam Top box x p; 4 1/2; 3.812; 2,215.0-2,219.9; 4.86 •.-------- 2,214.9 2,177.8 26.9 ', = 2.9; �up Jt, 41/2 12.68 Vam Top box x pin; 4 112 3.968, 2,219.9 - 2,222.7; 2.82 "AM - , - 2 - 10 T ub i ng Jt, 4 12.69 Vam Top box x pin; 4 1/2 3.958; 2,222.7-3,021.4; 798.67 L'..-. 2,222.8 2,184.8 27.2 ® 2.11; Pup Jt. 4112 12.68 Vam Top box x pin; 4 112 3,968; 3,021.43,024.2; 2.84 2-12; GLM, 41/2 x 1 KBMG with DCK -2 Shear Valve, set at; 4 112; 3.968, 3,024.2-3,031.9; 7.66 3,024.3 2,783.1 50.0 2 -13; Pup Jt, 41/2 12.68 Vam Top box x pin; 4 1t2 3 958; 3,031.9- 3.034.7; 2.83 44; CSG; 9 5/8; 8.681; 36.3-8,671.0; 8,635.29 3,034.8 2,789.8 50.0 3.1; 4-112" Long String; 4 1/2; 0.0-8,803.9; 8,803.83 2-14; Tubing Jt, 41/2 12.69 Vam Top box x pin; 4 1/2; 3.958; 3,034.7. 8,747.9; 5,713.19 ar 45, X0; 9 5/8; 8.681; 8,671.6 - 8,673.1; 1.64 8,671.6 6,340.4 48.7 2 -15; Landing Nipple, 3.81 XN, 41/2 Vam Top box x pin; 4 1/2; 3.725; 8,747.9 - 8,749.2; 1.34 8,748.0 6,390.8 48.7 2 -16; Tubing Jt, 41/2 12.68 Vam Top box x pin; 4 112 3.958; 8,749.2.8,791.2 42.02 ® 1 ,-2-17; Crossover, 41/2 12.69 V a m Top box x 3.112 9.29New; 4 1/2; 3 958 8,791.2 - 8,792.1; 0.90 8,791.3 6,419.3 48.9 / . 2.18; 3 -112 Pup Joint, 3.1/2 9.29 New Vam pin x pin; 3 1■2, 2.992; 8.792 1-8,802.1; 10.00 2 -19; Shroud Hanger Body (spin collar section above FJL; 7 518; 6.875; 8,802.1-8,803.8; 1.70 8,802.2 6,426.4 48.9 3-2; Shroud Hanger Body (below spin collar below FJL bo; 7; 2.990; 8,803.9 - 8,804.4: 0.50 3 -3; Pup Joint, 4 ft, 3 -1/2 9.29 New Vam pin x pin; 3 1/2; 2.990; 8,804.4-8,808.4; 4.00 8,804.5 6,427.9 48.9 MB i 3-4; Adjustable Union, 3 -1/2 9.28 New Vam box x pin; 4.15; 2.990; 8,808.48,813.8, 5.45 Va 3 -5; Offset Sub, 3 -1/2 9.29 New m box x pin; 5 1/4, 3.010, 8,813.8-8,815.0; 1 23 8,813.6 6,433.9 48.9 46' CSG; 9 518; 8.681; 8,673.1- 8,958.6; 285.49 3 -6, Discharge Gauge Unit, 3 -1/2 New V a m box x pin 3 1/2; 2 992; 8,815.0- 8,817.0; 2.00 8,816.9 6,436.1 49.0 ma ® ......... ` ,-3 -7; Pup Joint, 2 ft, 3 -1/2 New Vam box x pin,; 3 1/2; 8,817.0 - 8,819.0; 2.00 digi, ® 3 -8; Pump Discharge Head, Bolt -on, 562XHV, 3 -1/2 9.29 N; 5.62; 8,819.0-8,819.5; 0.50 - ma 8,819.6 6,437.8 49.0 , _ g® 3 -9; Pump.562PLXSXD 31-P155; 5.62; 8,8195.8,833.7;14.20 s.^aa:. ® 3 - Pump Intake, Bolton; 5.62; 8,833.7-8,834.8, 1.10 8,835.0 6,447.9 49.0 °" , ® 3 -11 Upper Seal, SXU 13/9 /B; 5.13; 8,834.8 - 8,841.1; 6.30 .,,--3-12 . Lower Seal, SXL B /B /B; 6.13, 8,841.1-8,847,4; 6.30 8,847.4 6,456.1 49.1 II ' 2 -20; Joint, 7 -5/8 29.79 13 Cr R3 Vam FJL box x pin, 7 5/8; 6.875; 8,803.8. 8,885.6; 81.76 3 -13; Motor, 562 KMX -VC. 270 HP; 6.62; 8,847.48,875 4; 28.00 8,878.0 6,476.2 49.1 "- ® - 3-14; Motor Gauge Sub, WellUft; 4 1/2; 8,875.48,878.1 2.67 v - 3 -15; Motor Centralizer 5.85; 8,878.1.8,880.2; 2.10 8,883.5 6,479.8 491 j 6 -1• PBR• 8.20; 7.600, 8,883.48,892.6; 9.19 -2.21, Pup Joint, 7 -5/8 29.79 13 Cr R3 Vam FJL box x pin; 7 6/8; 6.876; 8,885.6 - 8,895.3; 9.69 8,892.7 6,485.8 49.0 a 6 -2; Baker WLRBP, T 8,892.6- 8,897.2; 4.63 rr t'! 2-22; Crossover, 7 -5/8 29.79 FJL box x 7 299 Vam Top Pin; 7 5/8; 6.876; 8,896.3- 8,896.9; 1.59 8,897.0 6,488.6 49.0 4 ,.. -2 -23; Baker Uner Tieback Seal Stem, 7 298 Vam Top box; 8 1/8; 6.184; 8,896.9- 8,907.8; 10.94 8,907.8 6,495.7 49.0 i 6 -3; LINER HANGER; 9 5/8; 6.130; 8,897.2.8,931.4; 34.14 8,958.7 6,529.1 48.9 47; X0; 9 5/8; 8.681; 8,958.5- 8,960.2; 1.59 --48; CSG; 9 6/8; 8.681; 8,960.2-9.001.3; 41.10 9,001.3 6,557.1 49.0 i 49; FLOAT COLLAR; 9 5/8; 8.681; 9,001.3 - 9.002.8; 1.53 9,043.3 6,584.6 49.1 410; CSG; 9 6/8; 8.681; 9,002.8-9,043.4; 40.56 411; CSG; 9 5/8; 8.681; 9,043 49,086.3; 41.91 9,086.9 6,613.1 49.3 .A 4-12; SHOE; 9 5/8; 9,085,3- 9,087.0; 1.72 6.4; Liner; 7; 6.276; 8,931.411,321.7; 2,390.29 11,321.5 8,557.9 8.8 6.5; Uner Centralizers every other joint after 825.; 7; 5.276; 11.321.7-11.361.7; 40.00 -6 -6; Uner; 7; 6.276; 11,361,7- 12,282.3; 920.63 11,845.1 9,075.9 8.0 Wire Line; 11,845.0- 11,915.0; 5/812010 11 ,995.1 9,224.4 7.9 Wire Line; 11,995.0- 12,045.0; 5/9/2010 _ 12,282.2 9,509.0 7.1 6-7; Uner P11 centralizers floating. No bow springs.; 7; 6.276; 12,282.3 - 12,323.0; 40.70 5hro k AtQ .Sf' P "-"� Page l of l . • Schwartz, Guy L (DOA) From: Kuck Marc [marc.kuck ©enipetroleum.com] Sent: Saturday, October 09, 2010 10:00 PM To: Schwartz, Guy L (DOA) Cc: Longo Joseph; Brink Jason Subject: OP23 -WW02 Continuing Operations Attachments: 10-403 Sundry Approval.pdf PTD zol o s 2- Guys, As we discussed, 1 would like to give you notice that we plan to move in and rig up on our water source well OP23 -WW02 in approximately one week. We plan to pull the WRBP and kill string and then complete with an ESP as originally planned. I have attached a copy of the sundry for your quick reference. Thanks and regards, Marc D. Kuck Senior Completion Engineer ENI US Operating Co. Office: 907 865 -3322 Mobile: 907 242 -6942 "The charm of fishing is that it is the pursuit of what is elusive but attainable, a perpetual series of occasions for hope. "— John Buchan This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 11/8/2010 • Borehole Seismic Processing Center Sc"iumbe" ger 1325 S. Dairy — Ashford , Room 5045 Houston , TX 77077 Tel. ( 281) 285 — 4390 Fax ( 281) 285 —1936 TRANSMITTAL MEMO Job Reference No. BBPG -00009 DATE : August 13 , 2010 =` =- `) j ' '' TO: 2525 Gambell St "O' =' a Suite 400. - - y Anchorage , AK 9950 ATTENTION : Sandra Mendoza ( 907 ) 2731726 The following Products are enclosed for the Eni Petroleum, OP23 -WW02 Well , Nikaitchuq Field , ( Copy for the State of Alaska ) • (1) Final Borehole Seismic Survey CD -ROM Please note Sc hlr erger j's.,:arantees "u[N _'l? a:2)C2tvn g " "' aa3& croiect'eo be valid. Client has 30 days horn I df deiivez ;r o ape °72e°v tha daaa.:Any o.oncarns sitar this period will be considered as r droceoslng <r will Ca ri°;ar aed accordingly TRANSMITTED BY : Nellyana Charmelo nsilva3@slb.com ( 281) 285 — 1298 RECEIVED BY : C'14 )'In.e-- 3kal DATE RECEIVED : Please acknowledge receipt of data by signing and returning a copy of this transmittal to us , via mail or fax . Our fax number is ( 281) 285 -1936 006 —C33' 2a� • 0 CANRIG Dxrt. me "R cmni nc C.ru 301 EAST 92 "° AVENUE, SUITE 2 • ANCHORAGE, ALASKA 99515 • (907) 561 -2465 • FAX (907) 561 -2474 May 24, 2010 E0510004 Ms. Christine Mahnken AOGCC 333 West 7 Avenue Anchorage AK 99501 Re: Final DML Color Log Prints, Well Reports and Digital Data: OP23 -WW03, Nikaitchuq, North Slope Borough, Alaska Dear Christine: Enclosed with this letter are the Final DML Color Formation Togs for the recently drilled OP23 -WW02 well. The following data and corresponding number of copies is included as per your instructions. OP23 -WW02 Description Standard Digital Formation Log 2" =100' MD (Color Prints) 1 Standard Digital Formation Log 2" =100' TVD (Color Prints) 1 Standard Digital Formation Log 5" =100' MD (Color Prints) 1 LWD Lithology Log 2" =100' MD (Color Prints) 1 LWD Lithology Log 2" =100' TVD (Color Prints) 1 LWD Lithology Log 5" =100' MD (Color Prints) 1 Gas Ratio Log 2" = 100' MD (Color Prints) 1 Gas Ratio Log 2" = 100' TVD (Color Prints) 1 Drilling Dynamics Log 2" = 100' MD (Color Prints) 1 Drilling Dynamics Log 2" = 100' TVD (Color Prints) 1 Final Well Reports 1 Final Digital Data on CD ROM (with TIFF File) 1 Ilf I can be of any future assistance, please do not hesitate to call me at your c• veni nce at (907) 561 -2465. 7 ost sincerely, RECENED James R. Carson , 2 4 20 10 Alaska Division Manager .1. Canrig Drilling Technology, Ltd. A' . ConTni33dall AilOiliftrig Rece pd Eby: V , - Tgn 6irti Title Date • 11 1110 ConocoPhillips Alaska RECIPIENTS �''' � No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and /or Digital Datassic3 contact: Lisa Wright, 907 263 -4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk * / 333 West 7th Ave, Suite 100 in lieu of sepia ** Electronic Anchorage, Alaska 99501 CGM / TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk * / David Douglas in lieu of sepia ** Electronic P.O. Box 196612 CGM / TIFF LIS Anchorage, Alaska 99519 -6612 CHEVRON /KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk * / P.O.Box 196247 in lieu of sepia ** Electronic Anchorage, Alaska 99519 CGM / TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk * / 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501 -3510 LIS 2 DO • STATE OF ALASKA 1 RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 2 4 2010 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Commission 1. Operations Abandon LJ Repair Well LJ Plug Perforations U Stimulate Li otheAhdhorage Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown El Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Eni US Operating Co. Inc. 4. Well Class Before Work: \5. Permit to Drill Number: Name: Development ❑ Exploratory 209 -032 3. Address: 3800 Centerpoint Dr. Suite 300 Anchorage AK, Stratigraphic ❑ Service 0 . API Number: 99503 50- 029 - 23411 -00 -00 7. Property Desigkation (Lase Number): �4k. Well Name and Number: ADL 355024, 373301, 390616 0P23 -WW02 9. Field /Pool(s): girl Nikaitchuq / Undefined - Rf 5I01,4.. 1 0 10. Present Well Condition Summary: Total Depth measured 12323 feet Plugs (measured) 8897 feet true vertical 9550 feet Junk (measured) N/A feet Effective Depth measured 12241 feet Packer (measured) N/A feet true vertical 9468 feet (true vertical) N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 4980 3240 Surface 4595 13 -3/8" 4595 3771.4 3450 1950 Intermediate 9087 9 -5/8" 9087 6611.2 6870 4750 Production Liner 3425 7" 12323 9550 7240 5410 Perforation depth: Measured depth: 11845' - 12045' True Vertical depth: 9076' - 9274' Tubing (size, grade, measured and true vertical depth): 4 -1/2" 13CrL80 2568 2470 Packers and SSSV (type, measured and true vertical depth): Baker WLRBP 8897 6487 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: 'Isk Well Class after work: Copies of Logs and Surveys Run x \ Exploratory ❑ Development ❑ Service el v/ATtg- S 0 " r_ Daily Report of Well Operations x ■fi. Well Status after work: Oil ❑ Gas ❑ WDSPL LJ GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 16. 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 Marc D. Kuck Printed Name Marc D. Kuck Title Sr. Completions Engineer Signature /r f 7 i1,..___� Phone 907 865 3322 Date 5/18/2010 RBDMS MAY 24141 6-2-10 J , 0/) Form 10 -404 Revised 7/2009 Submit Original Only • ! ` • • Eni E&P Division Well Name: OP23 -WW02 Daily Summary & EN/ Petroleum Cost Summary Well Code: 23835 Co. Inc ' 7 Field Name: Nikaitchuq 'eat APIIUWI: 50- 029 - 23411 -00 -00 Job Category Job Phase Rig less Activity CP COMPLETION Completion Date start End Date Job Account 5/7/2010 5/14/2010 4449 Scope of work Complete Well in Ivishak. Change of original AFE Scope: Centrilift's chrome motor assembly was damaged. Set Baker WLRBP in 7" liner @ 8897' MD/ 6487' TVD. 4 -1/2" 12.6# 13CrL80 Vam Top kill string set @ 2568' MD/ 2470' TVD. Job Remarks Change of original AFE Scope: Centrilift's chrome motor assembly was damaged. Set Baker WLRBP in 7" liner @ 8897' MD/ 6487' TVD. 4 -1/2" 12.6# 13CrL80 Vam Top kill string set @ 2568' MD/ 2470' TVD. Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Rpt No. Start Date End Date 24h Summary 1 5/7/2010 5/8/2010 I Change out brake band on drawworks. Test casing to 3000 psi - Good Test. PJSM on picking up Schlumberger perf guns. PU perf guns and SlimPulse LWD, TIH on 3 -1/2" 13.3# G105 DP to 940' MD. Shallow Test SlimPulse Tool - Good Test. There was a reportable hydraulic oil spill at approximately 16:40 hours. A PGS off road Steiger tractor suffered a broken hydraulic hose causing a spill of 5 -8 gallons of fluid to reach the sea ice. ACS, assisted by PGS onsite personnel completed the removal of contaminated ice /snow. 2 5/8/2010 5/9/2010 Finish TIH to 12242' MD with 4 -1/2" perf guns on 3 -1/2" x 5" DP. Circulated and conditioned 10.4 ppg OBM. Cleaned pits, took on 9.7 ppg NaCI, and built sweeps for fluid displacement. Pumped 20 bbls LVT followed by 35 bbls 10.7 ppg weighted sweep. 3 5/9/2010 5/10/2010 Continue to pump spacers and displace well with 9.7 ppg NaCI. Prep and clean possum belly, Shakers and return trough to active pits for circulating. Correlate on depth with Schlumberger SlimPulse LWD f/ 12,108' t/ 12,037' @ 60' fph, made 4 passes. TIH to 12240' MD and spot 9.7 ppg hi vis perf pill. Line up choke manifold, reverse circulate, and establish base line for firing sequence. Test shot detection device - Good Test. Proceed thru pump sequence and fire guns - positive indication. POOH U 11.665' and monitor well for 30 min., static loss 2.4 bph. Cont. POOH to 8874', Circulate BU and monitor well with no static losses. 4 5/10/2010 5/11/2010 POOH laying down with 4 -1/2" Guns on 3 -1/2" x 5" DP. LD Schlumberger SlimPulse LWD and 4 -1/2" Guns. Test Choke 250/5000 psi - Good Test. Pull wear bushing, drain stack and set test plug. Begin testing BOPs 250/5000 psi. 5 5/11/2010 5/12/2010 Continue testing BOPE 250/5000 psi - Good Test. Unable to get a test on upper IBOP valve. 1C0 IBOP and test 250/5000 psi - Good Test. Made decision to run Baker Wireline Retrievable 'Bridge Plug. TIH 30 stands 5" DP. LD 80 jts. 5" DP. 6 5/12/2010 5/13/2010 Continue LD 5" DP. Spot and RU Halliburton WL. MU Baker WLRBP. RIH to 8950' MD. Attempt to pull to 7" liner hanger @ 8888' MD/ 6481' TVD. WLRBP stuck @ 8897' MD/ 6487' TVD, Inc. 49.15 °. WOO. Set Baker WLRBP @ 8897' MD/ 6487' TVD. POOH WL. RD Halliburton WL. Clear floor and LD all 5" DP. RU Nabors 4 -1/2" Chrome tubing running equipment. Run 13 jts. 4-1/2" 12.6# 13CrL80 Vam Top tubing to 555' MD/ TVD 7 5/13/2010 5/14/2010 Ran 60 jts. 4 -1/2" 12.6# 13CrL80 Vam Top tubing set @ 2568' MD/ 2470' TVD. RD Nabors chrome casing running equipment and test upper and lower hanger seals to 5000 psi for 10 min - Good Test. ND BOPE and NU VetcoGray tree. Pull BPV and install 2 way check. Test hanger void and tree to 5000 psi for 10 min - Good Test. Pull 2 way check and install BPV. RU Little Red Services and test BPV to 2000 psi for 45 min - Good Test (Witnessed by Bob Noble). Pump 170 bbl diesel freeze protect taking returns to pits. RD Little Red Services and normal up tree. Prepare for rig move. 1 of 1 g tIPY OPa73 - WW663 • e l vs 30 'IS 0 0 D 2 Aim ger ii‘o IIII / • ► 30 M. 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OP23 -WW02 T BPV set and test from bottom to 2,000 psi eno peCroku m 4 -' /2" 13Cr 12.6 ppf Production Tubing Wellhead, 13 -3/8" x 4 -W, CR Flow- wetted 5,000 psi Water Producer with Conductor, 20" Uninsulated set at +/- 120 ft Shrouded ESP Lift Ope rations Shutdown Well Status Diesel Freeze protect to 2500' MD, 2440' TVD All depths are RKB — 53.20 ft +1- 2,500 MD - 4 -' /" 12.6# 13Cr Tub 9.7 ppg Brine to TD Surf. Casing 13 -3/8" 68 # 4595 MD, 3745 TVD 8888' MD - Top of Flex Lock Liner Hanger and ZXP Packer 8897' MD, 6488 TVD - Top of 7" WLRBP tested /charted to 3,000 psi for 30 minutes ge Interm. Casing Perforation Interval 9 -5/8" 47 # 11845 -11915 MD 9087 MD, 6613 TVD, 11995 -12045 MD 0 0 Production Liner, 7" 26# 13 Cr 12,323' MD, 9,550' TVD Confidential MDK 5/12/10 1500 hrs 1 0 Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 Field Name: Nikaitchuq Co. Inc. Date: 4/5/2010 - Report #: 1 API /UWI: 50- 029 - 23411 -00 -00 ■ne page 1 of 1 Wellbore name: OP23 -WW02 Well Header PermiVConcession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 1.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature ('C) Weather Wind 86.87 86.87 86.87 3.90 22.3 98.0 -14.0 Cloudy with fog. 260 WSW at 2 mph Daily summary operation 24h Summary Spudded well at 2230 hours. Operation at 07.00 Making up BHA #2. 24h Forecast Make up BHA #2. Drill ahead with surface hole. Lithology Shows MAASP (kgf /cm.) Mud Weight (g /L) 8.7 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 20:30 20.50 20.50 PREP M 1 P _Hook up diverter line. 20:30 22:30 2.00 22.50 PREP M 1 P Test high pressure lines and pumps to 3000 PSI. , 22:30 00:00 1.50 24.00 DRILL E 3 P Drill out conductor from 78' to 132', - Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907- 715 -6434 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Eni representative Bernie Leas ENI Rig Clerk 907 - 670 -8607 907- 575 -9427 Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CONDUCTOR 20 18.250 X -65 1.77 48.77 4/1/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm') • • Eni E &P Division Well Name: OP23 -WW02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Field Name: Nikaitchuq -eni Date: 4 /6/2010 - Report #: 2 API/UWI: 50 -029- 23411 -00 -00 page 1 of 1 Weilbore name: OP23 -WW02 Well Header PermiUConcession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Welibore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 2.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m/hr) POB Temperature (°C) Weather Wind 644.65 636.28 114.91 7.50 15.3 98.0 3.6 323 NW at 5 mph Daily summary operation 24h Summary Directionally drilling ahead Operation at 07.00 Overboard mud line plugged, working to unplug @ CCB(Y). Current depth 1205' MD 24h Forecast Drill Ahead Lithology Shows MAASP (kgf /cm Mud Weight (g /L) Clay and gravel 8.7 Time Log Cum Start End Dur Dur Time Time (hrs) (hm) Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 DRILL E 3 P DRILLING - ROTARY DRILLING SPUD IN HOLE DRILLING DOWN 16 "HOLE TO 285' RAT HOLE TO MAKE UP 257' BHA #2 @ 450 GPM, 105 SPM, 300PSI, 6 -12 K WOB, 30 RPM, 1200 ROTARY TORQUE. 03:00 04:30 1.50 4.50 DRILL E 4 P TRIP OUT OF HOLE, POOH F/285' T /SURFACE B/D T /D. 04:30 05:00 0.50 5.00 DRILL E 1 P PRE -JOB SAFETY MEETING. PICK UP BHA #2 05:00 08:30 3.50 8.50 DRILL E 4 P TRIPPING, PICK UP BHA #2 AS PER SLB /DD 08:30 09:00 0.50 9.00 DRILL E 4 P TRIPPING, PICK UP BHA, CLEAR FLOOR, LOAD NUKE SOURCE AS PER SLB MWD. 09:00 11:30 2.50 11.50 DRILL E 4 P TRIPPING, PICK UP BHA CONT 11:30 12:00 0.50 12.00 DRILL E 4 P ROTARY DRILLING WASH DOWN FROM 213' TO 285' BTM @ 200 GPM, 120 PSI, 53 SPM, 30 RPM 12:00 22:30 10.50 22.50 DRILL E 7 P ROTARY DRILLING , DRILL FROM 319' TO 872' 22:30 23:00 0.50 23.00 DRILL E 3 P DRILLING -SLIDE DRILLING, SLIDE FROM 872' TO 900' 23:00 23:30 0.50 23.50 DRILL E 3 P DRILLING - ROTARY DRILLING, DRILL FROM 900' TO 940' 23:30 00:00 0.50 24 00 DRILL E 3 P DRILLING -SLIDE DRILLING SLIDE FROM 940' TO 965'. 700 GPM, 85 STKS / 1300 PSI ON, 1100 OFF / 95K UP / 90K DWN / 90 ROT Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907 - 670 -8623 907- 715 -6434 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907 -440 -0806 Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907 - 229 -6100 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (mKB) Bottom (mKB) Run Date CONDUCTOR 20 18.250 X -65 1.77 48.77 4/1/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cml Eq. Mud Weight (g /L) P (LO) (kgf /cm,) • • Eni E &P Division Well Name: OP23 -WW02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Field Name: Nikaitchuq 'eni • Date: 4 /7/2010 - Report #: 3 API/UWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share (%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 3.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 822.96 782.85 528.83 36.00 14.7 97.0 -15.0 Cloudy, WC -9.4° 267°W @ 9 mph Daily summary operation 24h Summary Drilled ahead as per directional plan. Cleaned out plugged area in trouser leg from drag chain to cuttings tank. Operation at 07.00 Drilling /Sliding @2407' at 0400 hours 24h Forecast Drill Ahead Lithology Shows MAASP (kgf /cm Mud Weight (g /L) 1102.4 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 DRILL E 3 P DRILLING- ROTARY CONTINUE DRILLING AND SLIDEING FROM 965' TO 1205' @ 700 GPM, 1380 PSI -ON, 1180 PSI -OFF, 3 -4 TORQUE -ON, 1 -2 TORQUE -OFF, 35 RPM, 15 -25K WOB, 165 SPM, 97K UP -WT, 93K DOWN -WT, 95K ROT-WT. 04:00 08:00 4.00 8.00 DRILL E 25 TP99 MISCELLANEOUS - WAITING ON ORDERS, TROUSER LEG FROM DRAG CHAIN TO CUTTINGS TANK PLUGGED OFF WITH CLAY. OPENED UP TROUSER LEG AND CLEANED OUT PLUGGED AREA. 08:00 09:30 1.50 9.50 DRILL E 4 P TRIPPING -TRIP OUT OF HOLE. POOH 5 STANDS FROM 1205' AND RIH TO BTM 100K UP -WT, 95K DOWN -WT, NO DRAG, NO SWABBING. 09:30 12:00 2.50 12.00 DRILL E 3 P DRILLING - ROTARY DRILLING CONTINUE DRILLING /SLIDING FROM 1205' TO 1453' @ 700 GPM, 1540 PSI -ON, 1230 PSI -OFF, 3 -4K TQ -ON, 1 -2K TO-OFF, 35 RPM, 25 -35K WOB, 100K UP -WT, 98K DWN -WT, 984( ROT -WT, 163 SPM. 12:00 16:30 4.50 16.50 DRILL E 3 P DRILLING -SLIDE DRILLING FROM 1453' TO 1738' / 30 -35K ON BIT / 1200 PSI -OFF / 1500 PSI -ON / 700 GPM / 85 / 85 STKS / ROP 60 - 120 / ROT AS NEEDED 112K UP -WT / 105K DWN -WT / 105 ROT / ROT TO 1 -2K OFF -BTM / 3 -5K ON -BTM. 16:30 17:00 0.50 17.00 DRILL E 25 P SERVICE -RIG SERVICE TOP DRIVE SERVICE TOP DRIVE. 17:00 00:00 7.00 24.00 DRILL E 3 P DRILLING -SLIDE DRILLING, DRILL FROM 1738' TO 2115' @ 112K UP, 105K DOWN, 105 ROT, 150 STKS, 650 GPM, 1300 PSI -ON, 1200 PSI -OFF, 3 -5K ON, 2K OFF. 35 RPM, ROT DRILL AS NEEDED TO GET THROUGH HARD SPOTS. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907 - 670 -8623 907 - 715 -6434 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Eni representative Greg Parker ENI Expediter 907 -980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CONDUCTOR 20 18.250 X -65 1.77 48.77 4/1/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm Eq. Mud Weight (g /L) P (LO) (kgf /cmr) • • iiiiiit Eni E &P Division Well Name: OP23 -W W 02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Field Name: Nikaitchuq .eni Date: 4 /8/2010 - Report #: 4 APIIUWI: 50- 029 - 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 4.00 Daily information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 938.17 858.78 293.52 24.00 12.2 100.0 -204 Cloudy, WC -21.6° 223 °SW @ 10mph Daily summary operation 24h Summary Drilled ahead as per directional plan from 2115' to 3078' Operation at 07.00 Drilling /Sliding @ 3240' at 0320 hours 24h Forecast Drill Ahead Lithology Shows MAASP (kgf /cm=) Mud Weight (g /L) 1114.4 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 DRILL E 3 P DRILLING - ROTARY DRILLING CONTINUE DRILLING /SLIDING AHEAD FROM 2115' TO 2700', (2568.16 TVD) 745GPM, 1745PSI -ON, 1550PSI -OFF, 175SPM, 4- 6T0 -ON, 1 -2TQ -OFF, 35RPM, 10- 3OWOB, 120K UP -WT, 98K DOWN-WT, 105K ROT -WT, WIPEING 90' BEFORE CONNECTION AST -4.38, ART 2.78, ADT 7.16, JAR TOTAL 31.4, BIT 31.4. 12:00 18:00 6.00 18.00 DRILL E 3 P DRILLING -SLIDE DRILLING DRILL FROM 2700' TO 2875', 180 STKS / 750 GPM / PUMPS ON 1800 / PUMPS OFF 1700 / 2K FREE TRQ / 5 -7K TRQ / 20 -30K ON BIT / 130K UP 105K DOWN 110 ROT / 35 RPM 18:00 18:30 0.50 18.50 DRILL E 25 P SERVICE -RIG SERVICE TOP DRIVE 18:30 00:00 5.50 24.00 DRILL E 3 P DRILLING - ROTARY DRILLING DRILL FROM 2875' TO 3078', 180 SPM / 750 GPM / 1820 PSI ON 1520 PSI OFF / 4 -5K TRQ / 2 -3K FREE TRQ / 132K UP / 110K DOWN / 112K ROT / 35 RPM, AST 4.19, ART 3.64, ADT 7.83, JARS TOT /BIT 39.2 Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907 - 670 -8623 907 - 715 -6434 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907 -670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CONDUCTOR 20 18.250 X -65 1.77 48.77 4/1/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Suit) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm=) • • '"' I Eni E &P Division Well Name: OP23 -WW02 ENI Petroleum Daily Report Well Code: 23835 Field Name: Nikaitchuq • Co. Inc. Date: 4 /9/2010 - Report #: 5 API /UWI: 50- 029 - 23411 -00 -00 Wellbore name: OP23 - WW02 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 5.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature ("C) Weather Wind 1,117.40 972.83 179.22 12.00 14.9 95.0 -27.2 P /C, WC -29.7° 155 ° SSE @5 mph Daily summary operation 24h Summary Drilled ahead (/3078' 1/3666' MD, POOH for BHA change Operation at 07.00 M/U BHA 24h Forecast Change BHA, RIH, Drill Ahead Lithology Shows MAASP (kgf /cm =) Mud Weight (g /L) 1114.4 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 DRILL E 3 P DRILLING - ROTARY DRILLING CONTINUE DRILLING /SLIDING AHEAD FROM 3078' TO 3653' @ 775 GPM, 183 SPM, 5 -6K TQ -ON, 3 -4K TQ -OFF, 202 PSI ON, 192 PSI OFF, 127K UP -WT, 110K DWN WT, 120 -ROT WT, 35 -45 RPM. AST 2.39 HRS, ART 6.48 HRS, ADT 8.87 HRS, AVERAGE SLIDEING 25 -60' PER STAND, REAMING 90' UP/DOWN BEFORE CONNECTIONS. 12:00 13:30 1.50 13.50 DRILL E 3 P DRILLING - ROTARY DRILLING, DRILL FROM 3653' TO 3666' @35 RPM, 15 -30K ON BIT, 184 STKS, 775 GPM, 2000 OFF, 2150 ON, FREE TRQ 3K, ON TRQ 6 -10K, UP WEIGHT 140K, DOWN 155K, ROT 120K. 13:30 14:30 1.00 14.50 DRILL E 3 P DRILLING - ROTARY DRILLING, PUMP 20 BBLS NUT PLUG SWEEP TO CLEAN BIT, CIRCULATE SWEEP AROUND 8000 STKS, 775 GPM, 184 STKS, 2000 PSI PUMP PRESSURE. GAINED MORE TORQUE ON BIT, 8 -10K, COULD NOT MAKE HOLE. 14:30 20:30 6.00 20.50 DRILL E 4 P TRIPPING -TRIP OUT OF HOLE POOH WITH DP 140K UP. 120K DOWN, PUMP OUT WHEN NEEDED. 300 GPM, 80 STKS, 500 PSI, DEPTHS PUMPED ON 3600, 3500, 3450, 3350, 3260, 3500, 3450, 2850. 2200, 2050, NO HOLE DRAG WHEN PUMPING. 20:30 22:00 1.50 22.00 DRILL E 4 P TRIPPING -TRIP OUT OF HOLE, MONITOR WELL. NO FLOW, STD BACK 4 STDS HWDP, 2 JTS HWDP WITH JARS. 22:00 00:00 2.00 24.00 DRILL E 4 P TRIPPING -LAY DOWN BHA, SAFETY MEETING WITH SLB, BREAK OUT BHA Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907 - 715 -6434 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907 - 440 -0806 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Last Casing seat Cas. Type OD (In) ID (In) Grade Top (mKB) Bottom (mKB) Run Date CONDUCTOR 20 18.250 X -65 1.77 48.77 4/1/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cmz) Eq. Mud Weight (g /L) P (LO) (kgf /cm') • • Eni E &P Division Well Name: OP23 -WW02 ENI Petroleum Daily Report Well Code: 23835 CO Inc. Field Name: Nikaitchuq • - Da te: 4/10/2010 - Report #: 6 API /UWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Wel! Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 _ 6.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 1,122.88 976.29 5.49 0.50 11.0 92.0 -27.2 P /C, WC -29.7° 155° SSE @ 5 mph Daily summary operation 24h Summary Change out BHA, RIH, CBU, drill ahead Operation at 07.00 Drctnl drill towards casing point. 24h Forecast Drill ahead to casing point Lithology Shows MAASP (kgf /cm=) Mud Weight (g /L) 1150.3 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 05:30 5.50 5.50 DRILL E 4 P Cont handle BHA #2, remove nuke source, break / grade bit. Lay do mud motor, PU new motor. 05:30 07:30 2.00 7.50 DRILL E 25 P Service rig. 07:30 16:00 8.50 16.00 DRILL E 4 P PJSM, MU BHA #3. PU mud motor, MU new MX1 16" bit. torque all connections. Flow check, RIH same to 1000 6. MU top drive, attempt fill pipe / break circ. Flow line plugged. 16:00 17:30 1.50 17.50 DRILL E 25 TS99 Clean / flush out plugged flowline clays. 17:30 18:00 0.50 18.00 DRILL E 7 P Ciro / cond fluids in prep for RIH. 18:00 23:30 5.50 23.50 DRILL E 4 P Resume RIH to 3550 ft. CBU in 1000 ft intervals. Note heavy clays to surface. NO loss / gains. Wash ream 3550 to 3660 ft. Take slight wt. No torque noted. 23:30 00:00 0.50 24.00 DRILL E 3 P Commence drill ahead drctnl 16" hole 3666 - 3684 ft. RPM 60. Up 140, Dn 120, Rot 120. GPM 760, SPM 180 SPP 2000, Off 2000, On 2400, WOB 25 -30 Daily Contacts _ Position Contact Name Company Title E -mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907 - 670 -8623 907- 715 -6434 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Last Casing seat Cas. Type OD (In) ID (In) Grade Top (mKB) Bottom (mKB) Run Date CONDUCTOR 20 18.250 X -65 1.77 48.77 4/1/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm.) Eq. Mud Weight (g /L) P (LO) (kgf /cm') ! • Eni E &P Division Well Name: OP23 -W W 02 !Phi ENI Petroleum Daily Report Well Code: 23835 Field Name: Nikaitchuq • Co. Inc. Date: 4/11/2010 - Report #: 7 API/UWI: 50- 029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 7.00 Daily information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 1,353.31 1,121.13 235.92 15.78 15.0 94.0 -14.9 Cloudy, WC -21.6° 323 NW at 5 mph Daily summary operation 24h Summary Drctnl drill towards TD casing point Operation at 07.00 Prepare run 13 3/8 csg 24h Forecast TD casing depth, wiper trip, cond fluids, POH for casing run Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1114.4 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 DRILL E 3 P Drill ahead 16" hole drctnl 3684 - 3850 ft. Encounter difficult formation. Sporadic ROP. Connections free, normal drag. No gain / loss. Cuttings returns normal quantity / quality. WOB 25 - 30, RPM 25, SPM 180, GPM 750, SPP 2060, Up 142, Dn 110, Rot 130, Tq 7 -8 K 02:30 09:30 7.00 9.50 DRILL E 3 P Drill ahead 16" hole drctnl 3850 - 3884 ft. Continued difficult formation. Sporadic ROP. Connections free, normal drag. No gain / loss. Cuttings returns normal quantity / quality. WOB 25 - 30, RPM 25, SPM 180, GPM 750, SPP 2050, Up 142, Dn 110, Rot 130, Tq 7 -8 K 09:30 12:00 2.50 12.00 DRILL E 3 P Drill ahead 16" hole drctnl 3884 - 4059 ft. Continued difficult formation. Sporadic ROP. Connections free, normal drag. No gain / loss. Cuttings returns normal quantity / quality. WOB 25 - 30, RPM 25, SPM 180, GPM 750, SPP 2120. Up 152, Dn 110, Rot 130, Tq 7 -8 K AST = 1.04 hrs, ADT = 7.75, ART = 6.71 hrs 12:00 00:00 12.00 24.00 DRILL E 3 P Drill ahead 16" hole drctnl 4059 - 4440 ft. Continued difficult formation. Sporadic ROP. Connections free, normal drag. No gain / loss. Cuttings returns normal quantity / quality. WOB 25 - 30, RPM 25, SPM 180, GPM 750, SPP 2120, Up 152, Dn 110. Rot 130, Tq 7 -8 K AST = .76 hrs, ADT = 7.53 hrs, ART = 6.77 hrs Gas = 150 - 690 units. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907 - 715 -6434 Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CONDUCTOR 20 18.250 X -65 1.77 48.77 4/1/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm.) Eq. Mud Weight (g /L) P (LO) (kgt /cm =) • • iiiiis,,, Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 • Co. Inc. Field Name: aq VIII Date: 4/12/2010 - Report #: 8 API /UWI: 50 0 29 - 2341 Nikitchu 1 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit /Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 8.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature ('C) Weather Wind 1,404.21 1,151.71 50.90 4.00 12.7 92.0 -15.0 Cloudy, WC -9.4° 267 °W @ 9 mph Daily summary operation 24h Summary TD csg point, circ cond fluids, wiper trip, circ cond fluids, POH / LAy dn BHA Operation at 07.00 RIH 13 - 3/8 csg 24h Forecast Lay dn BHA, RU / run 13 - 3/8 csg Lithology Shows MAASP (kgf /cmr) Mud Weight (g /L) 1138.4 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 DRILL E 3 P Drill ahead 16" hole drctnl 4440 - 4607 ft (csg pt as per ENI Geo) Continued difficult formation. Sporadic ROP. ' Connections free, normal drag. No gain / loss. Cuttings returns normal quantity / quality. WOB 20 - 30, RPM 60, SPM 180, GPM 750, SPP 2150, Up 155, Dn 110, Rot 130, Tq 7 -8 K AST = .94 hrs, ART = 2.04 hrs ADT = 2.98 hrs Gas = 75 - 290 units. 04:00 06:30 2.50 6.50 DRILL E 7 P Circ / cond fluids. Pump sweep / nut plug as fluid caliper. Calculated 11% washout. Circ addtnl BU. Shaker clean. 06:30 07:30 1.00 7.50 DRILL E 6 P Flow check, POH wiper trip to 3107 ft. Normal drag, no swab. No gain / losses. No backreaming necessary. 07:30 08:30 1.00 8.50 DRILL E 6 P Flow check, RIH wiper trip 15 stds. No fill. No dn drag. Precaution wash 30 ft to btm. 08:30 12:30 4.00 12.50 DRILL E 7 P Circ / cond fluids. Pump sweep / nut plug as fluid caliper. Calculated 13% washout. Circ addtnl BU X2. Shaker clean. 790 gpm, 2050 psi. 12:30 17:30 5.00 17.50 DRILL E 4 P PJSm, flow check, POH to BHA. Normal drag. No swab. 17:30 18:30 1.00 18.50 DRILL E 4 P PJSM all personnel concerning removal nuke source at BHA. Flow check. 18:30 21:30 3.00 21.50 DRILL E 4 P Handle BHA #3, lay dn all components. Remove nuke source. 21:30 22:00 0.50 22.00 DRILL E 25 P Service rig. 22:00 00:00 2.00 24.00 DRILL E 4 P Continue LD BHA #3 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907- 715 -6434 Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CONDUCTOR 20 18.250 X -65 1.77 48.77 4/1/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm') • • Vo Eni E &P Division Well Name: OP23 -W W 02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Date: Name: Nikaitchuq Date: 4/13/2010 - Report #: 9 API /UWI: 50- 029 - 23411 -00 -00 Wellbore name: OP23 - WW02 p age 1 of 1 Well Header Permit/Concession N ° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 9.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m/hr) POB Temperature (°C) Weather Wind 1,404.21 1,151.71 0.00 93.0 -8.3 P /C, WC +4.1° 191° SSW @ 12 mph Daily summary operation 24h Summary Rig up / run 13/38 csg Operation at 07.00 Batch mix cement 24h Forecast Run / Cmt 13 - 3/8 csg Lithology Shows MAASP (kgf /cm =) Mud Weight (g /L) 1114.4 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 DRILL E 4 P Complete lay dn BHA #3. Lay dn MW D, ARC, mud motor. break and grade 16" bit. 01:30 02:30 1.00 2.50 DRILL G 1 P Drain BOP stack, clear floor for 13 -3/8 csg run. 02:30 06:30 4.00 6.50 DRILL G 1 P PJSM, Rig up GBR casing equip on rig floor. Perform dummy run with 13 -3/8 csg hgr. Mark landing jt as to installed position. Rig up Franks fill up tool, continue rig up GBR and csg tongs. 06:30 07:30 1.00 7.50 DRILL G 1 P PJSM all personnel, (subject matter run 13 -3/8 csg.) 07:30 12:00 4.50 12.00 DRILL G 4 P Commence RIH 13 -3/8 688 L80 BTC csg. MU Shoe track guide shoe 2 jts 13 -3/8, float collar. Test floats. RIH csg to 1625 ft filling all jts. Record up / dn wt at 10 jt intervals. 12:00 12:30 0.50 12.50 DRILL G 7 P CBU at 2000 ft. 310 gpm / 400 psi. 12:30 14:00 1.50 14.00 DRILL G 4 P Resume RIH 13 -3/8 csg. to 3000 ft. 14:00 15:00 1.00 15.00 DRILL G 7 P CBU at 3000 ft. 321 gpm / 430 psi. 15:00 18:00 3.00 18.00 DRILL G 4 P Resume RIH 13 -3/8 csg. to 4000 ft. 18:00 19:00 1.00 19.00 DRILL G 7 P CBU at 4000 ft. 321 gpm / 520 psi. 19:00 22:00 3.00 22.00 DRILL G 4 P Resume RIH 13 -3/8 csg. to 4500 ft. 22:00 00:00 2.00 24.00 DRILL G 4 P MU landing jt, work through tight spot at 4555 ft. Collars / tools hanging up on wellhead taper. Sticking downhole. Continue work through all possible wt on casing. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907 - 670 -8623 907- 715 -6434 Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CONDUCTOR 20 18.250 X -65 1.77 48.77 4/1/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm.) Eq. Mud Weight (g /L) P (LO) (kgf /cm.) • • roili Eni E &P Division Well Name: OP23 -W W 02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Date: Name: Nikaitchuq • Date: 4/14/2010 - Report #: 10 API /UWI: 50- 029 - 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG • Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 10.00 Daily information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m/hr) POB Temperature (°C) Weather Wind 1,404.21 1,151.71 0.00 94.0 -12.6 Cloudy, WC -6° 224 °SW @ 12 mph Daily summary operation 24h Summary Run / cmt 13 - 3/8 csg, nipple dn diverter system Operation at 07.00 Nipple up BOPE 24h Forecast Nipple dn diverter, nipple up BOpe Lithology Shows MAASP (kgf /cm=) Mud Weight (g /L) 1150.3 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 00:30 0.50 0.50 DRILL G 4 P MU csg hgr assy, work tight hole / fill to land hgr in Vetco landing ring. Run casing space out with Tam Collar @ 500' leaving 10' rat hole. Pick up split landing collar which allows running DP in rotary slips to shift tool. Circulate landing joint down 15 feet thru a tight spot, the riser couplings were hanging on the riser. Worked pipe down to within 4' of landing. Casing failed to break over coming up, pulled 430K, worked pipe down to the shoulder. Rigged down the Franks fill up tool and installed the cement head. Circulate and condition the mud to the planned Yield point end viscosity. Verify hanger in place. Final depths 13 -3/8 shoe 4595.1 ft, float collar 4512.8 ft. Total 109 jts 13 -3/8 casg. 00:30 06:00 5.50 6.00 DRILL H 8 P Commence circ / cond fluids for cmt 13 -3/8 csg. Lay dn remainder GBR casing tools. Pick up up cmt head, load plugs, MU on top jt. Continue circ / cond drlg fluids. 10 bpm / 730 psi. 06:00 07:00 1.00 7.00 DRILL H 8 P PJSM all personnel ( topic cmt casing), while circulate. 07:00 13:30 6.50 13.50 DRILL H 9 P Commence cmt 13 -3/8 casing as follows: Held a PJSM with all people involved with the cement job. Batch mix and pump 1031 sacks of 10.7 ppg B809 Arctic Lite lead cement followed by 315 sacks of 12 ppg D962 CMCRETE. 110 bbl Mud Push II D970. Displaced with 676 bbls of 9.5 mud, bumped plug on planned strokes, hold 1500 psi on the floats for 5 mins. FCP =1000 psi. CIP @ 13:30 hrs. Wash cement out stack and shaker room. Final cement returns = 385. 13:30 14:30 1.00 14.50 DRILL H 9 P Break out cmt head, lay dn same, blow down cmt lines, lay out to pipe shed. 14:30 00:00 9.50 24.00 DRILL C 5 P PJSM, nipple down diverter system. RU platform, clean cellar area, clear rig floor, break out 16" diverter line / knife valve. Remove flow nipple / flow line. Begin remove bolts from annular. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907- 715 -6434 Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Torn Norvig ENI Rig Clerk 907- 670 -8607 907 - 229 -6100 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 133/8 12.415 L80 0.00 1,400.584/14/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cW) i • • % Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 Field Name: Nikaitchuq i Co. InC. Date: 4/15/2010 -Report #: 11 API/UWI: 50 -029- 23411 -00 -00 p age 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit /Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 11.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature ("C) Weather Wind 1,404.21 1,151.71 0.00 94.0 -15.0 Cloudy, WC -9.4° 267 °W @ 9 mph Daily summary operation 24h Summary Nipple dn diverter system, nipple up BOPE Operation at 07.00 Prep for BOP test 24h Forecast Nipple up BOPE, test BOPE Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1150.3 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 11:00 11.00 11.00 DRILL C 5 P PJSM, continue niplle dn diverter system, remove and lay out all components. 11:00 00:00 13.00 24.00 DRILL C 5 P PJSM, commence nipple up BOPE, choke manifold, choke controls, accumulator system, kill line, flow line, fill up line, drip pan, all associated plumbing / wiring. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907- 715 -6434 Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Torn Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 13 3/8 12.415 L80 0.00 1,400.58 4/14/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Suit) (kgf /cm%) Eq. Mud Weight (g /L) P (LO) (kgf /cm°) • • 1 roils Eni E &P Division Well Name: OP23 -W W 02 EN/ Petroleum Daily Report Well Code: 23835 Field Name: Nikaitchuq It Co. Inc. Date: 4/16/2010 - Report #: 12 AUWI: 50 -029- 23411 -00 -00 epolt # PU page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit /Concession N° Operator ENI Share (%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 12.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m/hr) POB Temperature (°C) Weather Wind 1,404.21 1,151.71 0.00 93.0 -17.3 Clear, WC -11.4° 65° ESE Daily summary operation 24h Summary Nipple up BOPE, test BOPE, MU BHA #4, RIH BHA #4 Operation at 07.00 RIH BHA #4 for drill out 13 - 3/8 24h Forecast RIH BHA #4 for drill out 13 - 3/8. LOT, drill ahead 12 - 1/4 hole. Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1078.4 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 DRILL C 5 P NIPPLE UP BOPE Continue nipple up 13 -5 /8 BOPE, all related components. 04:00 15:30 11.50 15.50 DRILL C 12 P TEST BOPE PJSM, commence BOPE: Body test all flanges preventers / choke manifold / standpipe. Test all components 250 psi low / 5000 psi high 5 minute durations. Test Annular preventer 250 low / 3500 psi high. 5 min duration. Test all floor valves, choke manifold, alll connecting plumbing 250 low / 5000 high. Perform volume / time / press test on accumulator. Manual choke with slight bleed off. State to allow 24 hrs for repair and re -test. Will not delay drill out. Pull test plug, Install wear ring, rig down test equip. Mr Chuck Scheve AOGCC witness test. 15:30 17:30 2.00 17.50 DRILL E 20 P PU BHA PJSM, load pipe shed with all BHA and drctnl equipment. 17:30 00:00 6.50 24.00 DRILL E 4 P PU BHA, Commence MU BHA #4 Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907- 715 -6434 Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907 - 670 -8624 Eni representative Greg Parker ENI Expediter 907 - 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 13 3/8 12.415 L80 0.00 1,400.58 4/14/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Suit) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm5) fit • lot Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 CO. Inc. Field Name: Nikaitchuq eni Date: 4/17/2010 _ - Report #: 13 API /UWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit /Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) OP23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 13.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 1,412.75 1,156.82 8.53 0.50 17.1 90.0 -14.2 Clear, WC -9° 62° ENE @ 12 mph Daily summary operation 24h Summary RIH BHA #4, drill shoe track / new hole, LOT, POH for MWD change Operation at 07.00 Drill ahead 12 - 1/4 hole. 24h Forecast POH, change out MWD, RIH, drill ahead. Lithology Shows MAASP (kgf /cm%) Mud Weight (g /L) 1078.4 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 DRILL E 4 P Finish P/U BHA and Clear Floor 01:00 01:30 0.50 1.50 DRILL E 7 P Circulate and Condition. Perform S.H.T. W /BHA #4 as per SLB. 677GPM, 1230PSI, 01:30 03:00 1.50 3.00 DRILL E 4 P P/U 30 Joints 5" DP 03:00 03:30 0.50 3.50 DRILL E 4 P Service Top Drive, Grease Crown 03:30 05:30 2.00 5.50 DRILL E 4 P RIH F /DRK T/4268 Filling Every 20 Stds. 05:30 06:00 0.50 6.00 DRILL E 6 P Precaution wash last 200 ft to tag float collar at 4509 ft. Approx 8 ft green cmt top of float collar. 542GPM, 1200PSI, 10RPM 06:00 07:30 1.50 7.50 DRILL E 7 P Cont circ cmt to surface. Circ / cond fluids. 07:30 09:00 1.50 9.00 DRILL E 19 P Test casing 2500 psi / 30 min. Test successful, no re- tests. 09:00 11:00 2.00 11.00 DRILL E 19 P Drill float collar, 80 ft cmt shoe track, guide shoe, 12 ft rat hole cmt 11:00 12:00 1.00 12.00 DRILL E 3 P Drill ahead 12 -1/4 new hole 4606 - 4621 ft for LOT 12:00 16:00 4.00 16.00 DRILL E 7 P Circ / cond fluids. Displace well with new VC OBM 9# drlg fluids. 16:00 17:30 1.50 17.50 DRILL E 19 P RU and perform LOT test at 4595 ft MD / 3789 ft TVD Results = 546 psi surface press, 9# obm, 11.78 ppg EMW 17:30 19.00 1.50 19.00 DRILL E 3 XDO1 Attempt drill ahead. MWD malfunction. Various attempts, no success. 19:00 00:00 5.00 24.00 DRILL E 4 XD01 POH for MWD change out. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907 - 715 -6434 Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907- 952 -7880 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 13 3/8_ 12.415 L80 0.00 1,400.58 4/14/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm') 1,404.21 1,151.71 LSND 1078.4 38.4 1411.7 162.5 • 1 til#11 Eni E &P Division • Well Name: OP23 -W W 02 EN I Petroleum Da ily Report Well Code: 23835 Field Name: Nikaitchuq • Co. Inc. Date: 4/18/2010 - Report #: 14 API/UWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit /Concession N° Operator ENI Share (%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) OP23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 14.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 1,616.05 1,279.94 203.30 8.50 23.9 92.0 -8.3 Clear, WC +10° 49 °NE @5mph Daily summary operation 24h Summary Continue LD BHA #4 due to MWD failure. CO rebuilt 12 1/4" PDC with new. While loading Nuke source in SADN8 found broken shear pin LD SADN8 and TIH to 4635' MD. Drill 12 1/4" hole to 5302' MD/ 4195' TVD Operation at 07.00 Drilling ahead 12 1/4" hole. 24h Forecast Drill ahead 12 1/4" hole to Intermedate Casing Point @ 9035' MD Lithology Shows MAASP (kgf /cm =) Mud Weight (g /L) 1090.4 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 DRILL E 4 TD01 LD BHA - Continue LD BHA #4 due to MWD Failure 03:00 07:00 4.00 7.00 DRILL E 4 TDO1 PU BHA - Change out rebuilt 12 1/4" PDC with new REED 12 1/4" MSX619S -A2D and PU BHA #5 07:00 10:00 3.00 10.00 DRILL E 4 XD01 PU BHA - While loading source in SADN8 found broken shear pin. LD SADN8. 10:00 12:00 2.00 12.00 DRILL E 4 TD01 PU BHA - Continue PU BHA #5 without SADN8. 1 12:00 15:00 3.00 15.00 DRILL E 4 TD01 TIH - Shallow pulse test MWD - Good Test. TIH to 4535' MD. 15:00 15:30 0.50 15.50 DRILL E 4 P SERVICE RIG- Set floor/ crown saver for drilling mode 15:30 00:00 8.50 24.00 DRILL E 3 P DRILLING - Wash down from 4535' MD to 4635' MD - No Fill. Drill f/ 4635' MD to 5302' MD/ 4195' TVD Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907 - 670 -8607 907- 229 -6100 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907- 947 -4323 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date - CASING 13 3/8 12.415 L80 0.00 1,400.58 4/14/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cmz) Eq. Mud Weight (g /L) P (LO) (kgf /cm.) 1,404.21 1,151.71 LSND 1078.4 38.4 1411.7 162.5 0 0 riiiii Eni E &P Division Well Name: OP23 -W W02 Daily Report ENI Petroleum Well Code: 23835 Field Name: Nikaitchuq Co. Inc. Date: 4/19/2010 - Report #: 15 API /UWI: 50 -029- 23411 -00 -00 eni page 1 of 1 Wellbore name: OP23 -WW02 Well Header PermiVConcession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2.972.84 3,756.05 216.34 17.4 15.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 2,048.26 1,546.95 432.21 19.00 22.7 91.0 -10.8 Cloudy, WC +7.5° 49° NE @ 2.9 mph Daily summary operation 24h Summary Drilled 12 - 1/4" hole to 6600' MD. Short tripped back to surface casing shoe at 4595' MD without and issues. Continue drilling ahead 12 - 1/4" hole to 6720' MD Operation at 07.00 Drilling ahead 12 1/4" hole. Current Depth 7035' MD/ 5272' TVD @ 0400 24h Forecast Drill ahead 12 1/4" hole to Intermedate Casing Point @ 9035' MD Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1138.4 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P DRILLING - Continue drilling 12 -1/4" hole from 5302' MD to 5860' MD @ 175 ROP, 15 WOB 906 gpm, 80 rpm, 8 -9K TQ, 165 UP -WT/ 135 DWN -WT/ 146 ROT -WT. Reaming every stand. 06:00 12:00 6.00 12.00 DRILL E 3 P DRILLING - Continue drilling 12 -1/4" hole from 5868' MD to 6300' MD © 100 -170 ROP, 10 -18 WOB, 906 gpm, 80 rpm, 8 -9K TQ, 173 UP -WT/ 135 DWN -WT/ 147 ROT -WT. Reaming every stand. 12:00 17:00 5.00 17.00 DRILL E 3 P DRILLING - Continue drilling 12 -1/4" hole from 6300' MD to 6600' MD @ 110 ROP, 15 -16 WOB. 910 gpm, 80 rpm, 8 -9K TQ, 192 UP -WT/ 142 DWN -WT/ 158 ROT -WT. Reaming every stand. 17:00 18:00 1.00 18.00 DRILL E 7 P CIRCULATE - C &C prior to short trip, 900 gpm 2900 psi. 18:00 19:30 1.50 19.50 DRILL E 4 P TRIPPING - Short trip from 6600' MD to intermedate casing shoe @ 4595' MD. 195 UP -WT/ 140 DWN -WT. No change in PU weight while passing through hole section with ghost reamer. 19:30 20:30 1.00 20.50 DRILL E 25 P SERVICE RIG - Service topdrive, blocks, drawworks and crown. 20:30 22:00 1.50 22.00 DRILL E 4 P TRIPPING - TIH to 6547' MD. Wash down from 6547' MD to 6600' MD. 195 UP -WT/ 140 UP -WT 22:00 00:00 2.00 24.00 DRILL E 3 P DRILLING - Drill ahead 12 -1/4" hole from 6600' MD to 6720' MD @ 150 ROP, 910 gpm, 15 -16 WOB, 80 rpm, 11K TQ, 195 PU -WT/ 140 DWN -Wt/ 160 ROT -WT. Reaming everystand Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907- 947 -4323 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (mKB) Bottom (mKB) Run Date CASING 133/8 12.415 L80 0.00 1,400.584/14/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm=) Eq. Mud Weight (g /L) P (LO) (kgf /cmz) 1,404.21 1,151.71 LSND 1078.4 38.4 1411.7 162.5 • 0 ri41 Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 Field Name: Nikaitchuq CO. Inc. Date: 4/20/2010 - Report #: 16 API/UWI: 50- 029 - 23411 -00 -00 eni page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit /Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 1 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 16.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (*C) Weather Wind 2,535.94 1,861.89 487.68 23.50 20.8 88.0 -7.1 Cloudy, WC +13.1° 329° NNW © 9 mph Daily summary operation 24h Summary Drilled 12 1/4" hole from 6720' MD to 8320' MD. Operation at 07.00 Drilling ahead 12 1/4" hole. Current Depth 8582' MD/ 6277' TVD @ 0400 24h Forecast Dril ahead 12 1/4" hole to Intermediate Casing point @ 9035' MD. Circulate hole clean. Short trip. POOH on elevators. Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1174.3 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P DRILLING - Continue drilling ahead 12 -1/4" hole from 6720' MD to 7200' MD, back reaming every stand. '902 gpm, 3100psi ON/ 2900psi OFF *90 rpm, 12K TQ ON/ 9 -10K TQ OFF *100 -185 ROP, 18K WOB '200 PU/ 140 SO/ 155 ROB 06:00 12:00 6.00 12.00 DRILL E 3 P DRILLING - Continue drilling ahead 12 -1/4" hole from 7200' MD to 7601' MD, back reaming every stand. `902 gpm, 3250psi ON/ 3150psi OFF *40 -90 rpm, 11 -12K TQ ON/ 9 -10K TQ OFF *50 -150 ROP, 10 -20K WOB *212 PU/ 140 SO/ 157 ROB 12:00 19:00 7.00 19,00 DRILL E 3 P DRILLING - Continue drilling ahead 12 -1/4" hole from 7601' MD to 8010' MD, back reaming every stand. Slide from 7704' MD -7725' MD, 8000' MD -8010' MD. Introduce 9.8ppg spike fluid to mud system. `902 gpm, 3250psi ON/ 3150psi OFF `90 rpm. 10K TQ ON/ 9 -10K TQ OFF `50 -150 ROP, 18K WOB '202 PU/ 160 SO/ 170 ROB 19:00 19:30 0.50 19.50 DRILL E 7 U CIRCULATE - Noticed 300psi drop in standpipe pressure. Test surface equipment - GOOD. Found pressure drop was attributed to addition of spike fluid. 1 19:30 00:00 4.50 24.00 DRILL E 3 P DRILLING - Continue drilling ahead 12 -1/4" hole from 8010' to 8320' MD, back reaming every stand. Slide from 8010' MD -8020 MD. *864 gpm, 3280psi ON *90 rpm, 14K TQ ON *150 ROP, 20K WOB '215 PU/ 160 SO/ 180 ROB Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907 - 670 -8624 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907- 947 -4323 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 13 3/8 12.415 L80 0.00 1,400.58 4/14/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm=) Eq. Mud Weight (g /L) P (LO) (kgf /cm=) 1,404.21 1,151.71 LSND 1078.4 38.4 1411.7 162.5 • • Viik Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Field Name: Nikaitchuq eni Date: 4/21/2010 - Report #: 17 API/UWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit /Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,75605 216.34 17.4 17.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 2,779.78 2,022.25 243.84 12 50 19.5 94.0 -12.8 Clear, WC -0.4° 109° ESE @ 6 mph Daily summary operation 24h Summary Drilled to Intermediate Casing Point @ 9120' MD/ 6637' TVD. Short tripped to previous wiper trip depth @ 6600' MD without any issues. TIH back to bottom and circulated the hole clean. POOH f/ 9120' MD t/ 4535' MD on elevators. Operation at 07.00 POOH and LD BHA #5. Intermediate CSG Pt @ 9120' MD/ 6637' TVD Current Depth POOH @ 112.8'MD @ 0400 24h Forecast POOH with BHA #5 Rack back collars, HWDP, and MWD for possible cleanout run. RU SLB wire line and log Lithology Shows MAASP (kgf /cmr) Mud Weight (g /L) 1174.3 Time Log Cum Start End Our Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P DRILLING - Continue drilling ahead f /8320'MD t/8675'MD, reaming every stand. `100 -160 ROP, 15 -20 WOB `90 RPM, 15 -17K TO-ON/ 14 -15K TO -OFF *850 gpm, 3350 psi- ON/3150 psi -OFF *210 PU/ 150 S0/ 160 ROB 06:00 12:00 6.00 12.00 DRILL E 3 P DRILLING - Continue drilling f/8675'MD t/9100'MD, reaming every stand. *100 -160 ROP, 10 -15 WOB '40 -90 RPM, 15 -18K TQ -ON/ 14K TO-OFF *840 gpm, 3430 psi- ON/3325 psi -OFF `239 PU/ 160 SO/ 180 ROB *ECD 10.45 -10.73 ppg 12:00 12:30 0.50 12.50 DRILL E 3 P DRILLING - Continue drilling to Intermediate Casing Point @ f/9100' MD 1/9120' MD, reaming every stand. *100 ROP, 15 WOB "90 RPM, 15 -16 TO `850 gpm, 3425 psi *240 PU/ 160 SO/ 190 ROB 12:30 14:30 2.00 14.50 DRILL E 7 P CIRCULATE - Circulate and condition mud at TD. Take on bottom survey. Pump hi vis sweep. '850 gpm, 3300 psi 14:30 17:00 2.50 17.00 DRILL E 4 P TRIPPING - TOOH (/9120' MD t/ 6600' MD (to previous wiper trip depth) on elevators. Worked tight spot @ 6738' MD. worked one time with no problem. `200 PU/ 140 SO 17:00 18:30 1.50 18.50 DRILL E 4 P TRIPPING - TIH back to bottom f/ 6600' MD U 9120' MD. Wash down (/9037' MD 1/9120' MD *245 PU/ 160 SO 18:30 21:30 3.00 21.50 DRILL E 7 P CIRCULATE - Condition mud on bottom. Pump high vis nut plug sweep, carne back 500 stk early. Circulated hole clean. *825 gpm, 3200 psi 21:30 00:00 2.50 24.00 DRILL E 4 P TRIPPING - TOOH f/ 9120' MD U 4535' MD on elevators. No tight spots encountered. '245 PU/ 160 SO @ 9120' MD `180 PU/ 130 SO @ 4535' MD Daily Contacts Position Contact Name Company Title E-mall Office Mobile Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907- 947 -4323 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907- 952 -7880 Last Casing seat - Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 13 3/8 12.415 L80 0.00 1,400.58 4/14/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm=) Eq. Mud Weight (g /L) P (LO) (kgf /cm 1,404.21 1,151.71 LSND 1078.4 38.4 1411.7 162.5 • 0 vioisr Eni E &P Division Well Name: OP23 -WW02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Field Name: Nikaitchuq eni s Date: 4/22/2010 - Report #: 18 API/UWI: 50 -029- 23411 -00 -00 page 1 of 1 Welibore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Welibore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 18.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m/hr) POB Temperature (°C) Weather Wind 2,779.78 2,022.25 0.00 98.0 -11.8 Clear, WC +0.7 92°E @ 7 mph Daily summary operation 24h Summary POOH f/ 4595' MD, R/U SLB Wireline and Open Hole Log f/ 9118' MD Operation at 07.00 SLB Tools Down, Pulling Ware Ring Intermediate CSG Pt @ 9120' MD/ 6637' TVD Current Depth - Surface 24h Forecast Run 9 5/8" Casing, Cement Same Lithology Shows MAASP (kgf /cm Mud Weight (g /L) 1174.3 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 03:00 3.00 3.00 DRILL E 4 P TRIPPING - CONTINUE TOOH F/ 4595' MD SHOE T/ 703' MD BHA. NO SWABBING 03:00 03:30 0.50 3.50 DRILL E 4 P PRE JOB SAFETY MEETING - L/D BHA #5 03:30 06:30 3.00 6.50 DRILL E 4 P TRIPPING - L/D BHA #5 AS PER SLB /DD, RACK BACK 8" DC. 06'30 09:30 3.00 9.50 DRILL J 24 TWO2 MISCELLANEOUS - WAITING ON 3RD PARTY TOOLS - CLEAN DRILL FLOOR AND CELLAR WHILE WAITING ON SLB WIRE LINE PERSONNEL. 09:30 11:00 1.50 11.00 DRILL J 25 P SERVICE RIG - SERVICE TOP DRIVE, GREASE T/D DRAWWORKS, IRON ROUGHNECK, CLEAR PIPESHED OF M W D TOOLS 11:00 11:30 0.50 11.50 DRILL J 1 P MEETING - PRE JOB SAFETY MEETING W /SLB, RIG UP WIRE LINE LOGGING EQUIPMENT/TOOLS. 11:30 12:00 0.50 12.00 DRILL J 1 P WIRE LINE WORK - R/U WIRE LINE EQUIPMENT & LOGGING TOOLS 12:00 16:00 4.00 16.00 DRILL J 1 P WIRE LINE WORK - PJSM W /SLB, M/U LOGGING TOO;S AND R/U WIRELINE. LOAD NUKE SOURCE. 16:00 18:30 2.50 18.50 DRILL J 4 P LOGGING OPEN HOLE LOGS - RIH W/ WIRELINE PLATFORM EXPRESS /SONIC SCANNER /PPC'S T/ 9118' MD. 18:30 00:00 5.50 24.00 DRILL J 4 P LOGGING OPEN HOLE LOGS - LOG OUT F/ 9118' MD T/ 2500' MD. MONITOR WELL ON TRIP TANK WHILE LOGGING. CLEAN CELLAR. CLEAN /SERVICE CENTRIFUGES, CLEAN SUCTION SCREENS ON MUD PUMPS. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Alvin Criswell ENI Expediter 907 - 980 -7545 Eni representative Torn Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907- 947 -4323 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907 - 441 -6585 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907- 952 -7880 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 13 3/8 12.415 L80 0.00 1,400.58 4/14/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm') 1,404.21 1,151.71 LSND 1078.4 38.4 1411.7 162.5 fil_____. TA Well Name: OP23 -W W02 Eni E &P Division Daily Report ENI Petroleum Well Code: 23835 Field Name: Nikaitchuq • Co. Inc. Date: 4/23/2010 - Report # 19 API/DWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,97284 3,756.05 216.34 17.4 19.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 2,779.78 2,022.25 0.00 100.0 -6.7 Clear, WC +14.4 109 ESE @ 3.8 mph. Daily summary operation 24h Summary Completed running SLB open hole logs. Change Rams to 9 - 5/8 ". Run 9 - 5/8" casing. Operation at 07.00 Ran 9 -5/8" casing. CBU prior to cement job. Intermediate Casing Pt @ 9,120' MD/6,637' TVD. At 0400: Running 9 -5/8" casing at 7,800' MD. 24h Forecast Run 9 - 5/8" Casing. Cement Same. Nipple Up BOPE. Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1186.3 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 02:00 2.00 2.00 DRILL J 4 P LOGGING OPEN HOLE LOGS - LOG F /2500' MD.ROUGH PATCH AT 6300'. NO OVERPULL. AT 4700' 300 LBS OVERPULL AS PER SLB. 02:00 04:00 2.00 4.00 DRILL J 4 P PJSM. R/D WIRELINE EQUIPMENT. 04:00 05:00 1.00 5.00 DRILL J 4 P REMOVE WEAR BUSHING. PULL R/W AND INSTALL T/P AS PER VETCO. 05:00 05:30 0.50 5.50 DRILL E 5 P PU TEST TOOLS. PJSM. MAKE UP 9 -5/8" TEST JOINT. 05:30 06:30 1.00 6.50 DRILL C 5 P CHANGE RAMS. PJSM. C/O BTM 3 -5/8" RAMS TO 9 -5/8" RAMS. 06:30 07:00 0.50 7.00 DRILL C 12 P PU TEST TOOLS FILL STACK WITH WATER. FLUID PACK TESTING EQUIPMENT. 07:00 07:30 0.50 7.50 DRILL C 12 P TEST 9 -5/8" BTM RAMS TO 250 PSI AND 5000 PSI 5 MINUTES. , 07:30 08:00 0.50 8.00 DRILL G 4 P RIG UP /DOWN TO RUN CASING. PERFORM 9 -5/8" HANGER DUMMY RUN AS PER VETCO. 08:00 10:30 2.50 10.50 DRILL G 4 P RIG UP TO RUN CASING. PJSM. R/U CASING EQUIPMENT. 10:30 12:00 1.50 12.00 DRILL G 4 P PJSM. P/U SHOE AND FLOAT ASSEMBLY. CHECK FLOATS. OK AS PER PROGRAM. 12:00 00:00 12.00 24.00 DRILL G 4 P PJSM All personnel, RUN 9 -5/8" CASING AS PER RUNNING ORDER. Guide shoe, 2 jts csg, float collar. 2 centralizers it #1, 1 centralizers it 82, 2 centalizers Jt #3 thread lock all shoe track connections, Continue RIH 9 -5/8 csg (L80, 47 #. BTC) FILL EVERY JOINT. TOP OFF EVERY 10 JOINTS. CBU EVERY 1000'. RIH TO 6000'. UP WEIGHT 252 DOWN WEIGHT 172. CBU AT 6000' 5 BPM 390 PSI. MAKE UP TO 8500 FT /LBS. AVERAGE. Depth 5800 ft at end of tour. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Jack Potter ENI Drilling HSE 907- 670 -8624 Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 , Eni representative Tom Norvig ENI Rig Clerk 907- 670 -8607 907 - 229 -6100 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907- 947 -4323 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Michael Seward ENI Orig. Fac. Adv. 907- 952 -7880 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 -575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 13 3/8 12.415 L80 0.00 1,400.58 4/14/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm') 1,404.21 1,151.71 LSND 1078.4 38.4 1411.7 162.5 1 1 Iii#3 Eni E &P Division Daily Report Well Name: 0P23 -W W02 ENI Petroleum Well Code: 23835 • CO- Inc. Field Name: Nikaitchuq Date: 4/24/2010 - Report #: 20 API/UWI: 50- 029 - 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header PermiVConcession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 20.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 2,779.78 2,022.25 0.00 100.0 -8.3 P /C, WC +3.4 242 WSW @ 17 mph Daily summary operation 24h Summary Completed running 9 - 5/8" casing. Layed down casing equipment. Cemented casing. Nipple up BOPE. Tested BOPE. Operation at 07.00 Making up BHA #6. 24h Forecast Test casing. Make up and RIH with BHA #6. Drill ahead with 8 - 1/2" hole. Lithology Shows MAASP (kgf /cmr) Mud Weight (g /L) 1246.2 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan _ Oper. Descr. 00:00 08:30 8.50 8.50 DRILL G 4 P Continue RIH 9 -5/8" casing. CBU 1000 ft intervals. 08:30 10:00 1.50 10.00 DRILL G 4 P CBU at last joint before casing hanger in prep for landing. 10:00 12:00 2.00 12.00 DRILL G 4 P MU casing hanger and landing joint. Circulate down to land hanger. Lay down Franks fillup tool. Make up cement head. 12:00 14:00 2.00 14.00 DRILL G 7 P Circulate and condition fluids. Reciprocate casing. j 14:00 16:30 2.50 16.50 DRILL H 9 P Commence to cement 9 -5/8" casing as follows: PJSM. Pump 5 barrels water. Test lines to 4000 psi. Mix and pump 40 barrels mud push at 12.8 ppg. Cease pumping, drop btm plug. Mix / pump 75.6 bbls slurry 15.8 ppg G (363 sks), at 6 bpm. Cease pumping, drop top plug, pump 10 bbls H2O wash behind plug. Displace with 650 barrels VC -OBM drilling mud with Schlumberger pumping unit at 8 bpm. Slow to 3 bpm last 10 barrels displacement. Plug did not bump. Pump additional 10 barrels. Did not bump. Bleed to cement unit. Floats holding. ICP = 520 psi at 6 bpm. FCP = 630 psi at 3 bpm. Reciprocate pipe entire job until last 5 barrels displacement. 100% returns at all times. Cement in place at 16:30 hours. 16:30 19:00 2.50 19.00 DRILL G 5 P Lay down cement head. Remove casing elevator and install drillpipe elevators. pickup packoff running tool. Suck out stack and rinse top of hanger. Set packoff and test to 5000 psi (Vetco Gray). 19:00 20:00 1.00 20.00 DRILL G 5 P Lay down casing tools and equipment. Set test plug. 20:00 21:00 1.00 21.00 DRILL C 5 P Change out bottom rams from 9 -5/8" to 3 -1/2 x 6 VBR's. 21:00 21:30 0.50 21.50 DRILL C 5 P Pick up test tools. Install test joint. Fill BOP's with water. 21:30 00:00 2.50 24.00 DRILL C 12 P Test BOP's 250 PSI Low and 5000 PSI High. Annular 3000 PSI High. 5 minutes each. Record on chart. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907- 952 -7880 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 - 575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907 - 440 -0806 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 9 5/8 8.681 L80 -0.63 2,769.72 4/24/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgt /cm') 1,404.21 1,151.71 LSND 1078.4 38.4 1411.7 162.5 0 0 iiiiiiil Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 CO- Inc. Field Name: Nikaitchuq Date: 4/25/2010 - Rep #: 21 API/UWI: 50 -029- 23411 -00 -00 r1 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m/hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 21.00 Daily Information _ Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature ("C) Weather Wind 2,954.12 2,140.59 174.35 10.00 17.4 95.0 -15.3 Clear. WC -1.8 307 NW @ 3 mph Daily summary operation 24h Summary Tested BOPE. Layed down HWDP from derrick. Layed down 12 - 1/4" BHA from derrick. Slip and cut drilling line. Changed swabs on mud pumps to oilbase rubber. Pick up BHA #6. Operation at 07.00 Picking up drill pipe from pipe shed. RIH with BHA #6. 24h Forecast RIH with BHA #6. Drill out 9 - 5/8" casing. LOT. Drill ahead with 8 - 1/2" hole. Lithology Shows MAASP (kgf /cmV) Mud Weight (g /L) 1246.2 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 DRILL C 12 P Test BOPE, all components 250 / 500 psi. Test annular 250 / 3000 psi. Witness waived by Mr. Bob Noble AOGCC. Freeze protect 13 -3/8" X 9 -5/8" annulus. Total volume 382 bbls. 5 bpm at 1473 psi. Bleed back 1.5 bbls. Annulus static. 0400 05:30 1.50 5.50 DRILL C 12 P Close blind rams, test 9 -5/8" casing 3000 psi / 30 minutes. Test successful. No retest. 05:30 06:30 1.00 6.50 DRILL E 4 P RIH with HWDP from mast for lay down. 06:30 08:30 2.00 8.50 DRILL E 25 P Slip and cut drilling line. 08:30 11:30 3.00 11.50 DRILL E 25 P Repair torque boost. Repair leaks at top drive. 11:30 13:00 1.50 13.00 DRILL E 4 P Complete lay down 12 -1/4" BHA from mast. 13:00 15:00 2.00 15.00 DRILL E 5 P Change out trim on mud pumps to OBM trim. 15:00 17:00 2.00 17.00 DRILL E 25 P Change out swabs on mud pumps to oilbase rubbers Install tarps under rig floor for drip pan. Seal cracks on rig floor. Load pipe shed with drill pipe. 17:00 20:30 3.50 20.50 DRILL E 4 P PJSM. Pick up 8 -1/2" BHA. Load nuclear source. i 20:30 21:00 0.50 21.00 DRILL E 25 P Pull mouse hole and try to access mouse hole sump to repair and weld. Not acessible. 21:00 00:00 3.00 24.00 DRILL E 4 P RIH with HWDP out of derrick. Pick up drill pipe out of pipe shed. Pulse test MWD at 1000 ft. 500 GPM 1500 PSI. Trip in hole to 1600 ft. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907 - 441 -6585 Eni representative Michael Seward ENI Orig. Fac. Adv. 907- 952 -7880 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 -575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 9 5/8 8.681 L80 -0.63 2,769.72 4/24/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm.) Eq. Mud Weight (g /L) P (LO) (kgf /cm =) 1,404.21 1,151.71 LSND 1078.4 38.4 1411.7 162.5 • o � Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Field Name: Nikaitchuq eni Date: - Report 22 API /UWI: 50- 029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 22.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 3,468.62 2,626.06 688.85 34.00 20.3 95.0 -8.9 P /C, WC 0.2 30 NNE © 17 mph Daily summary operation 24h Summary RIH with BHA #6. Drilled shoe track and 50 9 new hole. Performed LOT. Drill ahead with 8 1/2" hole. Operation at 07.00 Drilling and sliding ahead in 8 1/2" hole. 0400 Depth: 9,890 ft MD. 24h Forecast Drill ahead with 8 1/2" hole to total depth. Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1234.2 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 06:30 6.50 6.50 DRILL E 4 P RIH with 5" drill pipe to 8950 ft. Precaution wash to tag float collar at 9000 ft. 06:30 10:30 4.00 10.50 DRILL E 4 P DRILLING - Drill float collar, shoe track, guide shoe, 30 ft of rat hole cement. "WOB 6K /9K TO 7K/8K ' RPM 175 SPM 30/40 ' PSI 2340/2360 GPM 450 ' 220 UP 160 DN I 10:30 11:00 0.50 11.00 DRILL E 3 P DRILLING - Drill 8 -1/2" hole from 9,120 ft to 9,170 ft. for LOT.I 'WOB6K /9K TO 7K/8K 'RPM 175 SPM 30/40 'PSI 3030/3180 GPM 550 '220 UP 150 DN 11:00 11:30 0.50 11.50 DRILL E 7 P CIRCULATE: Circulate and condition fluids for LOT. ' GPM 550 PSI 3030 * MW in and MW out 10.3 11:30 12:00 0.50 12.00 DRILL E 4 P TRIP: POH to 9 -5/8" casing shoe for LOT. 12:00 13:30 1.50 13.50 DRILL E 12 P LOT Perform LOT at 9,170' MD / 6,611' TVD. 10.3 ppg fluid. 1,700 surface pressure. Resulting in 15.25 EMW. 13:30 19:30 6.00 19.50 DRILL E 3 P DRILLING AND SLIDING: Slide intervals from 9,221 ft to 9,250 ft; from 9,323 ft to 9,348 ft; from 9,420 ft to 9,451 ft. * RPM 110 TO 10K WOB 7K/8K ' GPM 550 PSI 3100 " 240 UP 152DN 180 ROT 19:30 20:30 1.00 20.50 DRILL E 7 P CIRCULATE: Circulate and condition hole. Cuttings chute packed off. Cleaned out chute. Drag chain jumped off sprocket. Repaired drag chain. * GPM 330 PSI 1300 20:30 00:00 3.50 24.00 DRILL E 3 P DRILLING AND SLIDING: Continue drilling and sliding ahead from 9,451 ft MD to 9,692 ft MD.Slide intervals from 9,451 ft to 9,457 ft; from 9,515 ft to 9,545 ft;from 9,611 ft to 9,658 ft. * WOB 7K /8K TO 10K/11K ' RPM 110 ROP 150 ' GPM 550 PSI 3100 " 245 UP 152 DN 182 ROT Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907- 952 -7880 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907- 575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (mKB) Bottom (mKB) Run Date CASING 9 5/8 8.681 L80 -0.63 2,769.72 4/24/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm') 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • ilk lifi./41Eni E &P Division Well Name: 0P23 -W W02 EN! Petroleum Daily Report Well Code: 23835 Field Name: Nikaitchuq y Co. Inc. Date: 4 /27/2010 - Report #: 23 API/UWI: 50 -029- 23411 -00 -00 to page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 23.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 3,685.03 2,840.27 730.91 43.00 17.0 96.0 -4.0 P /C, WC 19.8 17NNE @ 4 mph Daily summary operation 24h Summary Drilled 8 - 1/2" hole directionally from 9,692 ft MD to 11,380 ft MD. Operation at 07.00 Directionally drilling 8 -1/2" hole towards Total Depth. At 0400: Directionally drilling at 11,590 ft MD. 24h Forecast Drill ahead with 8 - 1/2" hole to Total Depth. Lithology Shows MAASP (kgf /cm=) Mud Weight (g /L) 1246.2 Time Log Cum Start End Dur Dur Time Time (hrs) ( Phase Opr. Act. Plan Oper. Descr. 00:00 12:00 12.00 12.00 DRILL E 3 P DRILLING AND SLIDING: Drill ahead with 8 -1/2" hole directionally from 9,692 ft MD to 10,420 ft MD. TVD 7,674 ft. * UP 275 DN 170 ROT 200 " * WOB 10K GPM 550 RPM 140 • PSI 3050/3140 TQ 11K / 13K SPR 1 &2 SPM 20/30 PSI 290/370 " MD 10,267' TVD 7,519' " MWT 10.3 ART 3.48 AST 3.78 ADT 7.26 Jar Hrs. 14.70 12:00 00:00 12.00 24.00 DRILL E 3 P DRILLING AND SLIDING: Drill ahead with 8 -1/2" hole directionally from 10,240 ft MD to 11,3800 MD. Slide from 11,240 ft MD to 11,288 ft MD * UP WT 298 DN WT 185 ROT WT 220 WOB 10K/12K GPM 550 PSI 3300 ' RPM 100 TQ 12K/15K ADT 9.27 ` ART 8.65 AST 0.62 Jar Hours 23.9 M -I SWACO WIF AND CCB FULLY OPERATIONAL ON APRIL 27 AT 2000 HOURS. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 -575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (mKB) Bottom (mKB) Run Date CASING 9 5/8 8.681 L80 -0.63 2,769.72 4/24/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm.) Eq. Mud Weight (g /L) P (LO) (kgf /cm.) 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • • Vt i Well Name: OP23 -W W02 Eni E &P Division ENI Petroleum Daily Report Well Code: 23835 Field Name: Nikaitchuq Co. Inc. Date: 4/28/2010 - Report #: 24 API/UWI: 50- 029 - 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 24.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (`C) Weather Wind 3,756.05 2,910.70 287.43 25.00 11.5 96.0 -3.9 Cloudy, WC +15.8 20 NNE @ 8.5 mph Daily summary operation 24h Summary Drill 8 1/2" hole directionally to 11,848 ft.MD. Marked increase in gas units and return flow. Performed flow check. Experienced losses at approximately 25 bph dynamic and 5 bph static.Spotted 40 bbl LCM pill. Pulled 10 stds. RIH and compressed LCM to formation. Resumed drilling ahead with no problems. Operation at 07.00 Directionally drilling 8 1/2" hole to total depth. 24h Forecast Drill ahead with 8 hole to Total Depth. Circulate and condition hole. Make a short trip to shoe of 9 - 5/8" casing. Lithology Shows MAASP (kgf /cm=) Mud Weight (g /L) 1258.2 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 11:30 11.50 11.50 DRILL E 3 P Drill 8 -1/2" hole directionally from 11,380 ft MD to 11,848 ft. MD. UP 315 DN 190 ROT 230 TO 14K/15K WOB 10K/15K GPM 400 PSI 1840/1940 RPM 110 ART = 8.21 ADT = 8.21 Jar Hours = 30.51 Gas units increased to 780 units at 11,500 ft. Picked up and checked for flow. Return flow up to 26-30%.. Picked up and shut down to check for flow. Returns flow increased to 30-40% at 11,714 Experienced losses at 11,799 ft at approximately 25 bph dynamix / 5 bph static. Reduced pump rate to 100 spm. Experienced continued losses. 11:30 12:30 1.00 12.50 DRILL E 7 P Spot 40 bbl LCM pill (10 ppb Saf Carb 2, 15 ppb Saf Carb 10) across zone. 400 GPM and 1,980 PSI. Slowed pumps down to 200 gpm while chasing pill after 1000 strokes. PSI = 680. Total losses equals 160 bbls. 12:30 14:00 1.50 14.00 DRILL E 4 P Trip out of hole to 10,937 ft. 10 stands drill pipe above pill. UP = 300 DN = 175. 14:00 15:30 1.50 15.50 DRILL E 7 P Circulate and condition and reciprocate pipe. GPM = 425 PSI = 2050. Circulate top of pill with (ECD EMW additional 280 psi). Compress LCM to formation. Monitor losses. 9.5 bbls lost. 15:30 16:00 0.50 16.00 DRILL E 4 P Trip in hole to 11,799 ft.. Wash down to 11,848 ft. UP = 315 DN = 190 16:00 00:00 8.00 24.00 DRILL E 3 P Pump LCM pill at 11,880. Drill ahead 8 -1/2" hole to 12,090 ft MD. UP = 325 DN = 195 ROT = 232. WOB 12K/15K TO 16K/17K RPM 90 GPM 450 PSI 2365 ART - 5.92 ADT - 5.92 Total of 68 bbls lost. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Dave Morris ENI Drilling Supervisor 907- 670 -8623 Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907 -670 -8623 907 -441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907 - 670 -8607 907- 575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 9 5/8 8.681 L80 -0.63 2,769.72 4/24/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm') 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • Eni E &P Division Well Name: OP23 -W W 02 ENI Petroleum Daily Report Well Code: 23835 Co. • Inc. Field Name: Nikaitchuq vitt' Date: 4/29/2010 - Report #: 25 API /UWI: 50- 029 - 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 25.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (`C) Weather Wind 3,756.05 2,910.70 71 02 6.00 11.8 96.0 -6.1 Cloudy, WC +6.3 NE @ 18.3 mph Daily summary operation 24h Summary Drill 8 1/2" hole directionally to total depth of 12,323 ft. Made short trip to 9 5/8" casing shoe at 9,087 ft. Circulate and condition hole. Trip out of hole to pick up Schlumberger wireline tools. Operation at 07.00 Running Schlumberger wireline logs. At 0400: Picking up Schlumberger MDT tool. 24h Forecast Run Schlumberger wireline tools. Lithology Shows MAASP (kgf /cm=) Mud Weight (g /L) 1246.2 Time Log Cum Start End Dur Dur Time Time (hrs) (h ►s) Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 DRILL E 3 P Drilled directionally from 12,090 ft MD to a Total Depth of 12,323 ft MD / 9,549 ft TVD. UP = 340 DN = 190 ROT = 240. ' WOB 15K GPM 440 PSI 2240/2410 RPM 110 TO 16K/18K ART = 5.80 * ADT = 5.80 Jar Hours 44.50 1 06:00 09:30 3.50 9.50 DRILL E 7 P Circulate and condition hole for E -Logs. Pump HI -VIS weighted msweep. Rotate and reciprocate pipe. GPM 440 PSI 2240 RPM 120 TO 15K/17K Monitor well for 10 minutes. 09:30 11:30 2.00 11.50 DRILL E 4 P Make a Short Trip out of hole from 12,323 ft to 9,021 ft. Hole in good condition. 11:30 12:30 1.00 12.50 DRILL E 7 P Circulate and condition hole. Rotate and reciprocate pipe. GPM 450 PSI 2020 Total losses = 154 bbls. 12:30 13:00 0.50 13.00 DRILL E 25 P Performed service to blocks, crown, and draw works. 13:00 14:30 1.50 14.50 DRILL E 4 P After completing Short Trip run in hole to 12,287 ft. Wash down to total depth at 12,323. UP = 335 DN = 198 14:30 17:00 2.50 17.00 DRILL E 7 P Circulate and condition hole. Rotate and reciprocate pipe. GPM 450 PSI 2400 17:00 23:00 6.00 23.00 DRILL E 4 P Trip out of hole to BHA. Drop 2.25 rabbit on stand 105. Recover rabbit at jars. 23:00 00:00 1.00 24.00 DRILL E 4 P Lay down BHA. PJSM with SLB MWD for handling nuclear source. Layed down 2 joints of HWDP and jars. Layed down 2 joints of flex collars. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907 - 670 -8623 907 - 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 -575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907- 715 -6434 Last Casing seat Cas. Type OD (In) ID (In) Grade Top (mKB) Bottom (mKB) Run Date CASING 9 5/8 8.681 L80 -0.63 2,769.72 4/24/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm') 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 1 0 Ifor* I Eni E &P Divisi Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 ' � ' CO. Inc. Field Name: Nikaitchuq Date: 4 /30/2010 - Report #: 26 API/UWI: 50- 029 - 23411 -00 -00 Wellbore name: OP23 -WW02 page 1 of 1 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 26.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature ("C) Weather Wind 3,756.05 2,910.70 0.00 99.0 -8.1 Cloudy. WC -0.1 49 NE @ 25 mph Daily summary operation 24h Summary Ran in hole with Schlumberger MDT logging tool. Logged hole taking pressure test points. On Ugnu Tank Farm: Mud volume in frozen tank = 275 barrels of 50/50 solids free OBM. Mud volume in good tank = 100 barrels of 50/50 solids free OBM. Operation at 07.00 Running Schlumberger MDT logs. 24h Forecast Run Schlumberger MDT logs. Lithology Shows MAASP (kgf /cm Mud Weight (g /L) 1210.2 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 DRILL E 4 P Lay down BHA. Download nuclear source. Clear and clean drill floor. 02:30 06:30 4.00 6.50 DRILL J 11 P Spot Schlumberger unit. Load pipe shed with Schlumberger logging tools. Pick up and make up tools. Plug MDT into tools. 06:30 12:00 5.50 12.00 DRILL E 4 P Trip in hole from 143 ft to 7,271 ft with logging tools on HWDP and drill pipe. Ran in hole 90 seconds per stand. Fill hole every 10 stands. Total mud losses 27 barrels. 12:00 13:00 1.00 13.00 DRILL E 4 P Trip in hole. Run in hole to stand 80 at 8230 ft 13:00 13:30 0.50 13.50 DRILL E 7 P Circulate and condition hole. Fill pipe at 52 SPM, 220 GPM, 30 strokes to break circulation. Circulate 150 strokes. 13:30 14:00 0.50 14.00 DRILL E 4 P Trip in hole to stand 89. Lay down top joint at 9060 ft. 14:00 16:30 2.50 16.50 DRILL J 11 P Rig up Schlumberger wireline Make up side entry sub. 16:30 21:30 5.00 21.50 DRILL J 11 P Run in hole to 11,568 ft with drill pipe conveyed logging tool. UP = 280 DN = 190. 21:30 00:00 2.50 24.00 DRILL J 11 P MDT log at set points. Set point at 11,274 ft. Test results Bad; At 11,277 ft Test results Bad; At 11278 ft. Test results Good. At 11,295 ft. Test results Good. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 -575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907 - 670 -8623 907 - 715 -6434 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 9 5/8 8.681 L80 -0.63 2,769.72 4/24/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm Eq. Mud Weight (g /L) P (LO) (kgf /cm 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • • till* Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Field Name: Nikaitchuq eni Date: 5 /1/2010 - Report #: 27 APUUWI: 50- 029 - 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 27.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 3,756.05 2,910.70 0.00 95.0 -7.4 Cloudy. WC +0.3 39 NE @ 27 mph Daily summary operation 24h Summary Ran TCL MDT logs. Tripped out of the hole after MDT tool failed. Operation at 07.00 Tripping out of the hole. Mud losses are minimal. 24h Forecast Trip out of the hole. Lay down MDT tools. Perform BOPE test. At 0100 notified John Crisp with AOGCC of todays BOPE test. John Crisp waived witnessing the test. Lithology Shows MAASP (kgf /cm=) Mud Weight (g /L) 1246.2 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 15:00 15.00 15.00 DRILL J 11 P Performed TCL MDT logging pressure settings. Pressure readings taken at: 11,311; 11,313: 11,560: 11576: 11,593: 11,612: 11,620: 11,636: 11,656: 11,678: 11,693: 11,715: 11,736: 11,758: 11,782: 11,800: 11862: 11,882: 11914: 11,937: 11,975:11,996:12, 018 :12,037:12,109:12,129:12,155. UP =295 DN =200 Total mud losses: 11 bbls. 15:00 16:00 1.00 16.00 DRILL J 11 P Performed TCL MDT logging pressure settings. Pull out of hole and took sample at 12.,018, MDT tool not working. 16:00 17:00 1.00 17.00 DRILL J 11 P Pull out of hole to 11,677 ft. Run in hole to 12,018 ft. UP =295 DN =190 17:00 00:00 7.00 24.00 DRILL J 11 P Performied TCL MDT logging pressure settings. Pressure settings taken at 12,018 and 11,682. MDT tool did not work. Tried taking sample at 11,863. MDT tool did not work. At 0400: Pulling out of hole after MDT tool failure. Lost small piece of metal in hole. Possibly from side entry sub. Piece is 1 1/2" wide x 3 1/2" long x 1/2" thick. Daily Contacts Position Contact Name Company - Title _ E-mail Office Mobile Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907- 575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907 - 715 -6434 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907- 952 -7880 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (mKB) Bottom (mKB) Run Date CASING 9 5/8 8.681 L80 -0.63 2,769.72 4/24/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm=) Eq. Mud Weight (g /L) P (LO) (kgf /cm') 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 1 • Ir I Eni E &P Division Well Name: 0P23 -W W 02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Field Name: Nikaitchuq eni- Date: 5 /2/2010 - Report #: 28 API/UWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit /Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3770.07 2,972.84 3,756.05 216.34 17.4 28.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 3,756.05 2,910.70 0.00 92.0 -9.2 Cloudy. WC -0.6 25 NNE @ 17.4 mph Daily summary operation 24h Summary Trip out of hole with MDT logging tools. Layed down logging tools. Conducted BOPE test. Picked up BHA. Ran in hole with clean out assembly. Operation at 07.00 Tripping in hole with clean out assembly. 24h Forecast Trip in hole with clean out assembly. Circulate and condition hole. Pull out of hole. Run 7" liner. Lithology Shows MAASP (kgf /cm=) Mud Weight (g /L) 1246.2 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 02:30 2.50 2.50 DRILL E 4 P Tripped out of hole from 11,863 ft to 9,059 ft. UP = 290 02:30 04:30 2.00 4.50 DRILL E 4 P Pulled out of the hole with wireline. Dropped a 2 -3/8" x 1 -1/2" x 1/2" of metal down the hole. Rigged down sheaves. 04:30 09:00 4.50 9.00 DRILL E 4 P Tripped out of the hole from 9,059 ft. 09:00 11:30 2.50 11.50 DRILL E 5 P Layed down Schlumberger logging tools. Clean rig floor. 11:30 13:00 1.50 13.00 DRILL E 5 P Remove wear bushing. Pull wear ring. Set the test plug. 13:00 22.00 9.00 22.00 DRILL E 11 P Tested BOPE with 5 ", 4 -1/2 ", 3 -1/2" test joints. Tested all to 250 psi low / 5,000 psi high. Tested annular with 3 -1/2" to 250 psi low / 3,500 psi high. Draw down test 2,925 psi / 1,950 psi / 200 psi 34 seconds: 3,000 psi 185 seconds. Blow down and drain stack. 22:00 22:30 0.50 22.50 DRILL E 5 P Remove wear bushing. Layed down test plug. 22:30 00:00 1.50 24.00 DRILL E 4 P Clean rig floor. Pick up BHA. Trip in hole with clean out assembly. At 0400: Trip in hole with clean out assembly. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 -575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keener@enipetroleum.com 907 - 670 -8623 907 - 715 -6434 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907- 952 -7880 Last Casing seat Cas. Type OD (in) ID (in) Grade _ Top (mKB) Bottom (mKB) Run Date CASING 9 5/8 8.681 L80 -0.63 2,769.72 4/24/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm.) Eq. Mud Weight (g /L) P (LO) (kgf /cm =) 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • • VilA Eni E &P Division Well Name: OP23 -WW02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Field Name: Nikaitchuq erra Date: 5 /3/2010 - Report #: 29 API /UWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share (%) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 29.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 3,756.05 2,910.70 0.00 90.0 -8.7 Cloudy. WC +13.3 15 NNE @ 2.2 mph Daily summary operation 24h Summary Tripped in hole for clean out run. Serviced drilling rig. Circulated and conditioned mud and hole for T casing run. Operation at 07.00 Tripping out of hole for 7" casing run. 24h Forecast Trip out of hole. Lay down BHA #7. Rig up and run 7" liner. Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1234.2 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 DRILL E 4 P Pick up BHA. Make up clean out assembly to 503 ft. 01:30 08:30 7.00 8.50 DRILL E 4 P Trip in hole from 503 ft. Pick up 9 -5/8" casing scraper. Trip in hole from 3,223 ft. to 9,029 ft. Fill pipe at 3,287 ft. at 250 GPM and 239 PSI. Fill pipe at 6,252 ft. at 250 GPM and 330 PSI. Fill pipe at 9,029 ft. at 250 GPM and 460 PSI. 08:30 10:00 1.50 10.00 DRILL E 4 P _Slip and cut 96 ft. of drilling line. 10:00 10:30 0.50 10.50 DRILL E 4 P Service top drive, drawworks, and crown. 10:30 12:00 1.50 12.00 DRILL E 4 P Trip in hole from 9,029 ft. to 10,850 ft. Total mud losses for previous 12 hours = 42 barrels. 12:00 14:30 2.50 14.50 DRILL E 4 P Trip in hole with clean out BHA #7 with 9 -5/8" casing scraper. Tag bottom at 12,323 ft. UP = 290 DN = 180. 1430 21:30 7.00 21.50 DRILL E 7 P Circulate and condition mud and hole. Circulate at 450 GPM, 1,900 PSI, 44,030 strokes. UP = 300 DN = 195. Mud weight = 10.2+ in and out. 21:30 00:00 2.50 24.00 DRILL E 4 P Trip out of hole to 10,040 ft. Monitor well for swabbing. UP = 310 DN = 190. At 0400: Tripping out of hole for 7" casing run. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 -575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907 - 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907 - 670 -8623 907 - 715 -6434 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907 - 952 -7880 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (mKB) Bottom (mKB) Run Date LINER 7 6.276 13CrL80 2,707.67 3,756.05 5/3/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm.) Eq. Mud Weight (g /L) P (LO) (kgf /cmz) 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • 1 V Tios Eni E &P Division Well Name: OP23 -W W 02 ENI Petroleum Daily Report Well Code: 23835 B Co. Inc Field Name: Nikaitchuq Date: 5/4/2010 - Report #: 3 API /UWI: 50- 029 - 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit /Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 30.00 Daily information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 3,756.05 2,910.70 0.00 99.0 -9.4 Cloudy, WC +11.3 308 NW @ 2.4 mph Daily summary operation 24h Summary Completed clean out run. Tripped out of the hole and layed down the casing scraper and BHA. Tested the top rams to 250 psi low and 5,000 psi high. Rigged up the torque turn and casing tools. Ran 7 26# Vam top 13Cr liner. Operation at 07.00 Running in hole with 7" 26# Vam top 13Cr liner. 24h Forecast Run in hole with 7" 26# Vam top 13Cr L80 liner. Cement liner. Lithology Shows MAASP (kgt /cm') Mud Weight (g /L) 1228.2 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 05:30 5.50 5.50 DRILL E 4 P Trip out of hole from 10,040 ft to 3,217 ft. Lay down scraper and cross overs. 05:30 07:00 1.50 7.00 DRILL E 4 P Lay down 8 -1 /2" BHA. Stand back HWDP, jars, drill collars, 2 stabilizers, and bit. Clear and clean the rig floor. 07:00 07:30 0.50 7.50 DRILL E 4 P Remove the wear bushing. Pull the wear ring. 07:30 10:00 2.50 10.00 DRILL E 4 P Rig up 7" test joint. Torque up 7" x 4 -1/2" cross over. Rig up testing equipment. Test top rams to 250 psi low and 5,000 psi high. Set the wear ring. 10:00 14:00 4.00 14.00 DRILL E 5 P Pick up torque turn equipment. Rig up casing tools. Rig up to run 7" liner L80 Vam top thread with electronic torque control. 14:00 22:30 8.50 22 50 DRILL E 4 P Run in hole with 7" , 26# Vam top 13Cr L80 liner. Run liner using torque turn. Run in hole at 40 seconds per joint. Take up and down weights every 10 joints. 22:30 23:30 1.00 23.50 DRILL E 4 P Make up hanger. Put Pal Mix in hanger. 23:30 00:00 0.50 24.00 DRILL E 7 P Circulate and condition the hole. Circulate hanger volume at 210 GPM, 350 PSI, 1,400 Strokes. At 0400: Running in hole with 7" 26# Vam top 13Cr L80 liner. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Alvin Criswell ENI Expediter 907- 980 -7545 Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907 - 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907 -575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907 - 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907 - 670 -8623 907 - 715 -6434 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907- 952 -7880 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907 - 947 -4323 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (mKB) Bottom (mKB) Run Date LINER 7 6.276 13CrL80 2,707.67 3,756.05 5/3/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm.) 2,795.02 2.031.89 VC -OBM 1234.2 119.5 1822.4 370.2 1 0 $111k Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 ' CO. Inc. Field Name: Nikaitchuq Date: 5 /5/2010 - Report #: 3 API/UWI: 50- 029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 31.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 3,756.05 2,910.70 0.00 114.0 -15.5 Cloudy. WC -1.5 213 SSW @ 2.6 mph Daily summary operation 24h Summary Ran 7" 26# Vam top 13Cr Iiner.Trip out of hole. Rig up Schlumberger wireline. Operation at 07.00 Rig up Schlumberger wireline. Conduct VSP surveys. 24h Forecast Test casing. Rig up Schlumberger wireline. Conduct VSP surveys. Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1234.2 Time Log Cum Start End Dur Our Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 00:30 0.50 0.50 DRILL E 7 P Circulate liner volume. 220 GPM 350 PSI UP = 115 DN = 105 10 RPM TQ 2K ROT 115. 00:30 06:00 5.50 6.00 DRILL E 4 P Run in hole from 498 ft. to 9,050 ft. Fill every 10 stands. 06:00 11:00 5.00 11.00 DRILL E 7 P Circulate and condition hole. Displace liner and drill pipe volume. 200 GPM 470 PSI UP = 215 DN = 150 10 RPM TQ 6K Make up cement head and cement circulating line. 11:00 12:00 1.00 12.00 DRILL E 7 P Circulate and condition hole. Stage pumps up to 212 GPM at 950 PSI. UP = 300 DN = 180 Attempt to rotate at 10 RPM. String stalled at 10K TQ. Total losses for the tour 80 bbls. 12:00 14:30 2.50 14.50 DRILL E 7 P Circulate and condition hole. Held PJSM with Schlumberger. All hands involved. 14:30 15:30 1.00 15.50 DRILL E 19 P Pump 5 bbls of water. Test lines to 4,500 PSI. Batch mix 40 bbls. of 13.4 ppg mud push. 15:30 16:00 0.50 16.00 DRILL E 9 P Pump 40 bbls. mud push. Pump 105 bbls. of class G 15.8 ppg cement slurry. 16:00 16:30 0.50 16.50 DRILL E 9 P Flush cement from lines and above plug. Release dart from head. 16:30 17:00 0.50 17.00 DRILL E 9 P Displace with rig pumps at 7 BPM. Caught cement at 146 bbls. Did not see dart latch in. Displace liner and bump plug to 3200 PSI.Increase pressure to 4200 PSI. Release running tool. Bleed off pressure and check floats. Remove hose from head. Cement in place at 1700 hours. 17:00 18:00 1.00 18.00 DRILL E 9 P Pressure up on packer. Set same and pull out. Flush liner and circulate bottoms up. 18:00 19:00 1.00 19.00 DRILL E 7 P Circulate and condition hole. Circulate bottoms up. 19:00 20:00 1.00 20.00 DRILL E 7 P Break down bottom cement head. Lay down cement head, 20:00 21:00 1.00 21.00 DRILL E 4 P Trip out of hole from 8,858 ft to 8,665 ft. Reciprocate pipe and circulate bottoms up. 21:00 00:00 3.00 24.00 DRILL E 4 P Trip out of hole from 8,665 ft to 4,905 ft. Run in hole 4 stands 5" HWDP to 5,281 ft. At 0400: Testing casing. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907- 575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907- 715 -6434 Eni representative Michael Seward ENI Drlg. Fac. Adv. 907- 952 -7880 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907 -947 -4323 Eni representative Greg Parker ENI Expediter 907 - 980 -7545 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (mKB) Bottom (mKB) Run Date LINER 7 6.276 13CrL80 2,707.67 3,756.05 5/3/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cmz) Eq. Mud Weight (g /L) P (LO) (kgf /cm') 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 1 0 Eni E &P Division Well Name: OP23 -WW02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Field Name: Nikaitchuq Date: 5/6/2010 - Report #: 32 APUUWI: 50- 029 - 23411 -00 -00 1 page 1 of 1 Wellbore name: OP23 -WW02 Well Header PermiVConcession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 32.00 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 3,756.05 2,910.70 0.00 99.0 -14.8 Cloudy. WC +5.4 155 SSE @ 1 mph Daily summary operation 24h Summary Tripped out of hole. Layed down liner running tool. Tested casing shoe, liner, and liner lap to 1,500 PSI for 30 minutes. Rigged up Schlumberger wireline. Ran VSP logs. Operation at 07.00 Working on rig brakes. Change over to brine mud system 24h Forecast Complete VSP surveys. Work on rig brakes. Change over to brine mud system. Perforate well. Run completion. Lithology Shows MAASP (kgf /cm=) Mud Weight (g /L) 1246.2 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 03:30 3.50 3.50 DRILL E 4 P Trip out of hole. Lay down H W DP from 5,261 ft. to 4,905 ft. Lay down liner running tool. 03:30 04:30 1.00 4.50 DRILL E 4 P Pressure test casing shoe, liner and liner lap to 1,500 PSI for 30 minutes. 04:30 05:30 1.00 5.50 DRILL E 11 P Rig up Schlumberger wire line. Load pipe shed with logging tools. 05:30 00:00 18.50 24.00 DRILL E 11 P Run VSP logs. Clean pits and perform general cleaning and maintenance on rig. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907 - 441 -6585 Eni representative Bernie Leas ENI Rig Clerk 907- 670 -8607 907- 575 -9427 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907 - 715 -6434 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907- 952 -7880 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907- 947 -4323 Eni representative Greg Parker ENI Expediter 907- 980 -7545 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (mKB) Bottom (mKB) Run Date LINER 7 6.276 13CrL80 2,707.67 3,756.05 5/3/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm') 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 0 • Vis Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 r Co. Inc. Field Name: Nikaitchuq Date: 5/7/2010 - Report #: 3 API /UWI: 50- 029 - 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share (55) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) 0P23 -WW02 DRILLING 4/5/2010 3,770.07 2,972.84 3,756.05 216.34 17.4 32.33 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 3,756.05 2,910.70 0.00 101.0 -14.8 Cloudy. WC +5.4 155 SSE @ 1 mph Daily summary operation 24h Summary Completed VSP logging program. LD VSP logging tools and RD Schlumberger wireline Operation at 07.00 RIG RELEASED TO COMPLETION - 05/07/2010 08:00 HRS 24h Forecast RIG RELEASED TO COMPLETION - 05/07/2010 08:00 HRS Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1246.2 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 06:00 6.00 6.00 DRILL J 19 P LOGGING - Contiune running VSP 06:00 08:00 2.00 8.00 DRILL J 5 P LOGGING - LD VSP logging tools and RD Schlumberger wireline. RIG RELEASED TO COMPLETION - 05/07/2010 08:00 HRS Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Gary Goerlich ENI Drilling Supervisor 907- 670 -8623 907- 441 -6585 Eni representative Torn Norvig ENI Rig Clerk 907- 670 -8607 907- 229 -6100 Eni representative Pete Adams ENI Drilling HSE 907- 670 -8624 907- 440 -0806 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907- 715 -6434 Eni representative Michael Seward ENI DrIg. Fac. Adv. 907- 952 -7880 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907 - 947 -4323 Eni representative Greg Parker ENI Expediter 907 - 980 -7545 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date LINER 7 6.276 13CrL80 2,707.67 3,756.05 5/3/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm =) 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • • Eni E &P Division Well Name: 0P23 -W W 02 Daily Report ENI Petroleum Well Code: 23835 Co. • Inc. Field Name: Nikaitchuq :Nu Date: 5/7/2010 - Report #: 1 API/UWI: 50 -029- 23411 -00 -00 page 1 of 1 Weilbore name: OP23 -WW02 Well Header Permit/Concession N ° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Welibore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) OP23 -WW02 COMPLETION 3,756.05 2,959.29 32.06 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 105.0 -16.7 Cloudy WC -8.5 4.7 mph Daily summary operation 24h Summary Change out brake band on drawworks. Test casing to 3000 psi - Good Test. PJSM on picking up Schlumberger perf guns. PU pert guns and SlimPulse LWD, TIH on 3 -1/2" 13.3# G105 DP to 940' MD. Shallow Test SlimPulse Tool - Good Test. There was a reportable hydraulic oil spill at approximately 16:40 hours. A PGS off road Steiger tractor suffered a broken hydraulic hose causing a spill of 5 -8 gallons of fluid to reach the sea ice. ACS, assisted by PGS onsite personnel completed the removal of contaminated ice /snow. Operation at 07.00 TIH with 4 -1/2" perf guns on 3 -1/2" x 5" DP. Current Depth: 4132' MD @ 04:00 hrs 24h Forecast Continue TIH with 4 - 1/2" perf guns on 3 - 1/2" x 5" DP. Condition hole for perforating. Correlate on depth with SlimPulse LWD. Perforate well and POOH. ,, Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1246.2 Time Loq Cum Start End Dur Dur Time Time (hrs) ' (hrs) Phase Opr. Act. Plan Oper. Descr. 08:00 15:30 7.50 7.50 COMP J 25 P SERVICE RIG - Change out brake bands on drawworks. 15:30 18:00 2.50 10.00 COMP K 19 P CASING TEST - Test casing to 3000 psi for 30 min - Good Test. is 18:00 21:00 3.00 13.00 COMP K 1 P RU - PJSM on picking up perforation guns. PU 200' 4 -1/2" Perf gun and SlimPulse LWD tool. 4 -1/2" Perforation Guns: - Total footage loaded 120' - 5spf 21:00 23:00 2.00 15.00 COMP K 4 P TRIPPING - TIH to 940' MD with 4 -1/2" Pert guns on 3 -1/2" 13.30# G105. 23:00 00:00 1.00 16.00 COMP K 7 P CIRCULATION - Shallow test SlimPulse LWD tool - Good Test. -182 GPM, 300 psi. Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907 - 980 -7545 Eni representative Jack Keener ENI Drilling Supervisor jack.keener@enipetroleum.com 907 - 670 -8623 907- 715 -6434 Eni representative Jack Potter ENI Drilling HSE Jack.Potter @enipetroleum.com 907 - 670 -8624 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907- 947 -4323 Eni representative Michael Seward ENI Dig. Fac. Adv. Michael.Seward @enipetroleum.com 907- 952 -7880 Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245e @ enipetroleum.com 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date LINER 7 6.276 13CrL80 2,707.67 3,756.05 5/3/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /ctrl) 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • • %I, Eni E &P Division Well Name: OP23 -W W 02 ENI Petroleum Daily Report Well Code: 23835 • CO. InC. a me: aq Date: 5/8/2010 - Report #: 2 API/UWI: Field N 50- 029 - 23411 Nikitchu - 00 fl page 1 of 1 Wellbore name: OP23 -WW02 Well Header PenniVConcession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 - Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m/hr) DFS (days) OP23 -WW02 COMPLETION 3,756.05 2,959.29 33.06 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m/hr) POB Temperature (°C) Weather Wind 92.0 -12.7 Cloudy WC -8.9 17.5 mph SSE Daily summary operation 24h Summary Finish TIH to 12242' MD with 4 -1/2" pert guns on 3 -1/2" x 5" DP. Circulated and conditioned 10.4 ppg OBM. Cleaned pits, took on 9.7 ppg NaCI, and built sweeps for fluid displacement. Pumped 20 bbls LVT followed by 35 bbls 10.7 ppg weighted sweep. Operation at 07.00 Continue displacing 10.4 ppg OBM with 9.7 ppg NaCI. 24h Forecast Finish displacing 10.4 ppg OBM with 9.7 ppg NaCI. Correlate on depth with Schlumberger SlimPulse LWD, TIH back to bottom and spot 9.7 ppg pert pill. POOH to top perforation interval, perforate well and POOH laying down drill pipe. Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1258.2 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 05:30 5.50 5.50 COMP K 4 P TRIPPING - Continue TIH with 4 -1/2" pert guns on 3 -1/2" DP to 3609' MD. Continue TIH with 5" DP to 4088' MD 05:30 06:30 1.00 6.50 COMP K 1 P SERVICE RIG - Grease topdrive and set crownsaver/ floorsaver. 06:30 10:00 3.50 10.00 COMP K 4 P TRIPPING - Continue TIH with 4 -1/2" perf guns on 3 -1/2" x 5" DP f/ 4088' MD U float collar @ 12242' MD 10:00 15:30 5.50 15.50 COMP K 7 P CIRCULATE - Circulate and condition 10.4 ppg OBM @ 4 bpm. - Inital Mud Properties - Funnel Vis = 150 s /qt -PV = 31 cp, YP = 11 Ibt /100ft^2 -Final Mud Properties - Funnel Vis = 81 s /qt -PV = 28 cP, YP = 6 Ibf /100tt ^2 -191 gpm, 940 psi 15:30 22:30 7.00 22.50 COMP K 1 P CIRCULATE - Continue to circulate and condition OBM. Clean pits, take on 9.7 ppg NaCI and prepare sweeps. 22:30 00:00 1.50 24.00 COMP K 1 P CIRCULATE - PJSM on fluid displacement operations. Pump 20 bbls LVT followed by 35 bbls 10.9 ppg weighted sweep. -55 gpm, 600 psi Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907- 980 -7545 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907 - 670 -8623 907 - 715 -6434 Eni representative Jack Potter ENI Drilling HSE Jack.Potter @enipetroleum.com 907 - 670 -8624 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907 - 947 -4323 Eni representative Michael Seward ENI DrIg. Fac. Adv. Michael.Seward @enipetroleum.com 907- 952 -7880 Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245e @ enipetroleum.com 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (mKB) Bottom (mKB) Run Date LINER 7 6.276 13CrL80 2,707.67 3,756.05 5/3/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq- Mud Weight (g /L) P (LO) (kgf /cm') 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • r Viiit Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Well Code: 23835 Field Name: Nikaitchuq • CO. Inc. Date: 5/9/2010 -Report #: 3 APIlUWI: 50-029-23411-00-00 en' page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit /Concession N ° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Weilbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) OP23 -WW02 COMPLETION 3,756.05 2,959.29 34.06 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 94.0 -12.0 Cloudy, Light Snow, 22° NNE @ 5 mph WC 4.1° Daily summary operation ! 24h Summary , Continue to pump spacers and displace well with 9.7 ppg NaCI. Prep and clean possum belly, Shakers and return trough to active pits for circulating. Correlate on depth with Schlumberger SlimPulse , LWD f/ 12,108' t/ 12,037' @ 60' iph, made 4 passes. TIH to 12240' MD and spot 9.7 ppg hi vis perf pill. Line up choke manifold, reverse circulate, and establish base line for firing sequence. Test shot detection device - Good Test. Proceed thru pump sequence and fire guns - positive indication. POOH 1/ 11.665' and monitor well for 30 min., static loss 2.4 bph. Cont. POOH to 8874', Circulate BU and monitor well with no static losses. Operation at 07.00 POOH Laying down 5" DP. Current Depth: 5450 'MD @ 0400 24h Forecast POOH laying down 5" and 3 - 1/2" DP Lithology Shows MAASP (kgf /cml Mud Weight (g /L) 1162.3 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 04:00 4.00 4.00 COMP K 7 P CIRCULATE - Displace 10.4 ppg OBM. Pumped the follwing spacers chased by 9.7 ppg NaCI to displace the well. - Spacers Pumped: -30 bbls LVT -40 bbls 10.9 ppg weighted NaCI with Safe Surf 0 -30 bbls 9.7 ppg NaCI with 2 drums Safe Surf 0 -50 bbls 9.7 ppg viscosified NaCI 04:00 10:30 6.50 10.50 COMP K 1 P MISCELLANEOUS - Clean shakers, possum belly, and pit 64. C/O shaker screens. Service drawworks and iron ruffneck. 10:30 17:00 6.50 17.00 COMP K 1 P LOGGING - Correlate on depth with SlimPulse LWD, mark pipe @ top perforation depth of 11845' MD. Made 4 passes @ 60 FPH f/12108' MD U 12037' MD, GR Sensor 246.64' from bottom nose. -210 gpm, 650 psi 17:00 17:30 0.50 17.50 COMP K 4 P TRIPPING - TIH f/ 12037' MD U 12240' MD 17:30 18:30 1.00 18.50 COMP K 7 P CIRCULATE - Spot 80 bbls 9.7 ppg hi vis perf pill. -233 gpm, 720 psi 18:30 19:00 0.50 19.00 COMP K 4 P TRIPPING - POOH to 12045.8' MD. Park guns and prepare to perforate. 19:00 23:30 4.50 23.50 COMP K 16 P PERFORATE - Test shock detection device - Good Test. Reverse circulate to clear all lines of air. Set super choke to 50% and establish baseline bleeding off thru gate valve. Go thru pump sequence, final pressure 3000 psi. Fire 4 -1/2" guns. Recieved positive indication shots were fired. POOH 4 stands to 11665' MD. Monitor well 30 min. Static losses @ 2.74 bph. POOH to 8872' MD. -lvishak Perforation Intervals - 11845' MD - 11915' MD 5 SPF - 11995' MD - 12045' MD 5 SPF 23:30 00:00 0.50 24.00 COMP K 7 P CIRCULATE - Circulate and monitor well @ 8872' MD, Circulation port @ 8646' MD. No Losses. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907- 980 -7545 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907 - 670 -8623 907 - 715 -6434 Eni representative Jack Potter ENI Drilling HSE Jack.Potter @enipetroleum.com 907- 670 -8624 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907 - 670 -8623 907- 947 -4323 Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245e @ enipetroleum.com 907 - 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (mKB) Bottom (mKB) Run Date LINER 7 6.276 13CrL80 2,707.67 3,756.05 5/3/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm') 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • • Eni E &P Division Well Name: OP23 -W W02 Daily Report ENI Petroleum Well Code: 23835 • Field Name: Nikaitchuq Co. Inc. Date: 5/10/2010 - Report #: 4 APUUWI: 50 -029- 23411 -00 -00 I page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL I Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m/hr) DFS (days) OP23 -WW02 COMPLETION 3,756.05 2,959.29 35.06 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 90.0 -12.4 Cloudy WC -4.9 26° NNE @ 10.5 mph Daily summary operation 24h Summary POOH laying down with 4 -1/2" Guns on 3 -1/2" x 5" DP. LD Schlumberger SlimPulse LWD and 4 -1/2" Guns. Test Choke 250/5000 psi - Good Test. Pull wear bushing, drain stack and set test plug. Begin testing BOPs 250/5000 psi. Operation at 07.00 Testing BOPs 250/5000 psi 24h Forecast Test BOPs 250/5000 psi. PU Halliburton retrievable bridge plug and TIH on 3 - 1/2" x 5" DP to 11745' MD. Set bridge plug and POOH LD DP. Lithology Shows MAASP (kgf /cm') Mud Weight (g /L) 1162.3 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 01:30 1.50 1.50 COMP K 7 P CIRCULATE - Circulate bottoms up at 8872' MD (Liner Hanger at 8888' MD) -5 bpm, 700 psi. 01:30 15:00 13.50 15.00 COMP K 4 P TRIPPING - POOH laying down 3 -1/2" x 5" DP from 8872' MD to 261' MD. 15:00 19:30 4.50 19.50 COMP K 5 P LD BHA/ GUNS - PJSM on laying down guns. LD Schlumberger SlimPulse LWD and perforation guns. Move all Schlumberger equipment off of floor. 19:30 20:30 1.00 20.50 COMP K 5 P SERVICE - Swap over to 5" equipment. Preparing to TIH to LD 6405' 5" DP racked back. 20:30 22:30 2.00 22.50 COMP K 12 P TEST BOP - Test choke 250/5000 psi- Good Test. PU and makeup test joint, pull wear bushing. drain stack and set test plug. 22:30 00:00 1.50 24.00 COMP K 12 P TEST BOP - Begin to test BOPs 250/5000 psi Daily Contacts _ Position Contact Name Company Title E -mail Office Mobile Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907- 980 -7545 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907- 715 -6434 Eni representative Jack Potter ENI Drilling HSE Jack.Potter @enipetroleum.com 907- 670 -8624 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907- 947 -4323 Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245e @ enipetroleum.com 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (mKB) Bottom (mKB) Run Date LINER 7 6.276 13CrL80 2,707.67 3,756.05 5/3/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm.) 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • • vol Eni E &P Division Well Name: OP23 -WW02 ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Field Name: Nikaitchuq erki Date: 5/11/2010 - Report #: 5 API/UWI: 50 -029- 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) OP23 -WW02 COMPLETION 3,756.05 2,959.29 36.06 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 81.0 -12.4 Cloudy WC -10.8 30° NNE @ 24 mph Daily summary operation 24h Summary Continue testing BOPE 250/5000 psi - Good Test. Unable to get a test on upper IBOP valve. CO IBOP and test 250/5000 psi - Good Test. Made decision to run Baker Wireline Retrievable Bridge Plug. TIH 30 stands 5" DP. LD 80 jts. 5" DP. Operation at 07.00 RU Haliburton Wireline 24h Forecast RU Haliburton Wireline. RIH to 11745' MD/ 8977' TVD. Set Baker Wireline Retrievable Bridge Plug. Test to 2250 psi for 30 min. POOH and RD Haliburton WL equipment. Run 2500' 4 -1/2" 12.6# 13CrL80 Tubing and freeze protect. Lithology Shows MAASP (kgf /cm.) Mud Weight (g /L) 1162.3 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 07:00 7.00 7.00 COMP ' K 12 P TEST BOPE - Continue testing BOPE 250/5000 psi - Good Test. Witness waived by Chuck Scheve. Test IBOP - No Test. 07:00 09:00 2.00 9.00 COMP K 12 TRO5 TEST BOPE - LD test joint, blow down top drive and choke manifold. Pull test plug and install wear ring 09:00 09:30 0.50 9.50 COMP K 12 TRO5 TEST BOPE - Test IBOP - No Test. RD testing equipment. 09:30 12:00 2.50 12.00 COMP K 12 TRO5 TEST BOPE - PJSM on CO upper IBOP Valve. CO upper IBOP Valve. 12:00 14:30 2.50 14.50 COMP K 12 TRO5 SERVICE RIG - Service Choke 14:30 15:00 0.50 15.00 COMP K 12 TRO5 TEST BOPE - Test IBOP 250/5000 psi - Good Test 15:00 16:30 1.50 16.50 COMP K 12 TRO5 SERVICE RIG - Service Choke 16:30 18:00 1.50 18.00 COMP K 21 P WOO - Wait on orders regarding wireline retrievable bridge plug. Prepare to TIH and LD 5" DP 18:00 20:00 2.00 20.00 COMP K 4 P TRIPPING - TIH 30 Stands 5" DP to 2968' 20:00 00:00 4.00 24.00 COMP K 4 P TRIPPING - LD 80 jts. 5" DP Daily Contacts Position Contact Name Company Title E-mail Office Mobile Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907- 980 -7545 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907 - 715 -6434 Eni representative Jack Potter ENI Drilling HSE Jack.Potter @enipetroleum.com 907- 670 -8624 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907- 947 -4323 Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245e @ enipetroleum.com 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (in) Grade Top (mKB) Bottom (mKB) Run Date LINER 7 6.276 13CrL80 2,707.67 3,756.05 5/3/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm =) 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • • vot E ni E &P Division Well Name: OP23 -W W02 . ENI Petroleum Daily Report Well Code: 23835 Co. Inc. Field Name: Nikaitchuq eni Date: 5/12/2010 - Report #: 6 API /UWI: 50- 029 - 23411 -00 -00 page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N ° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) a i l . 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) OP23 -WW02 COMPLETION 3,756.05 2,959.29 37.06 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 81.0 -11.6 Cloudy WC -3.1° 5°N @ 11.9 mph Daily summary operation 24h Summary Continue LD 5" DP. Spot and RU Halliburton WL. MU Baker WLRBP. RIH to 8950' MD. Attempt to pull to 7" liner hanger @ 8888' MD/ 6481' TVD. WLRBP stuck @ 8897' MD/ 6487' TVD, Inc. 49.15 °. WOO. Set Baker WLRBP @ 8897' MD/ 6487' TVD. POOH W L. RD Halliburton WL. Clear floor and LD al 5" DP. RU Nabors 4 -1/2" Chrome tubing running equipment. Run 13 jts. 4 -1/2" 12.6# 13CrL80 Vam Top tubing to 555' MD/ TVD Operation at 07.00 PU/ MU VetcoGray Tubing Hanger and land out 4 -1/2" 12.6# 13CrL80 Vam Top Kill String set @ 2568' MD/ 2470' TVD. Current Depth: 2568' MD/ 2470' TVD 24h Forecast Continue running 4 -1/2" 12.6# 13CrL80 Kill String to 2568' MD. RD Tbg running equipment. Set BPV and ND BOPE. NU tree, pull BPV and set 2 way check. Test tree to 5000 psi. Put 2 way check and freeze protect. Install and test BPV to 2000 psi. RDMO Lithology Shows MAASP (kgf /cm.) Mud Weight (g /L) 1162.3 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 01:00 1.00 1.00 COMP K 4 P TRIPPING - Continue LD 5" DP. 01:00 02:00 1.00 2.00 COMP K 1 P RU - Spot Halliburton wireline unit and stage equipment on the floor. 02:00 05:30 3.50 5.50 COMP K 1 P RU - PJSM on rigging up and running Halliburton wireline/ Baker WLRBP equipment. RU Halliburton sheave's, spool WL and MU Baker WLRBP. 05:30 09:30 4.00 9.50 COMP K 19 P WIRELINE - RIH with Baker WLRBP on Halliburton WL to 8950' MD. Attempt to pull up to 7" liner hanger @ 8888' MD/ 6481' TVD to make depth correction. WLRBP stuck @ 8897' MD/ 6487' TVD, Inc. 49.15 °. Max pulled 1900 Ib - would not come free. Hold 1600 Ib, max safe pull - would not come free. WOO. 09:30 10:00 0.50 10.00 COMP K 23 U Decision made to set WLRBP @ stuck point - 8897' MD/ 6487' TVD. Set WLRBP - Recieved positive indication BP set. Pull up - Wireline free. 10:00 11:00 1.00 11.00 COMP K 4 P POOH - POOH Halliburton W L. 11:00 12:00 1.00 12.00 COMP K 5 P RD - RD Halliburton WL equipment 12:00 13:30 1.50 13.50 COMP K 12 P TEST WLRBP - RU to test Baker WLRBP on blind rams. Test Baker WLRBP to 3000 psi for 30 min.- Good Test. f.--" 13:30 15:30 2.00 15.50 COMP K 4 P _TRIPPING - TIH 36 stands 5" DP 15:30 19:30 4.00 19.50 COMP K 4 P TRIPPING - POOH laying down 109 jts. 5" DP. 19:30 20:30 1.00 20.50 COMP K 1 P RIG PREP - Pull and LD wear bushing, setting tool and test plug. Move 3 -1/2" DP equipment off the floor. 20:30 22:30 2.00 22.50 COMP K 1 P RU - RU Nabors 4 -1/2" Chrome tubing running equipment to set 4 -1/2" kill string 22:30 00:00 1.50 24.00 COMP K 4 P 'RUN TBG - Run 13 jts. 4 -1/2" 12.6# 13CrL80 Vam Top tubing to 555' MD/TVD. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907 - 980 -7545 Eni representative Jack Keener ENI Drilling Supervisor jack.keener @enipetroleum.com 907- 670 -8623 907 - 715 -6434 Eni representative Jack Potter ENI Drilling HSE Jack.Potter @enipetroleum.com 907- 670 -8624 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907- 947 -4323 Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245e @ enipetroleum.com 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (in) ID (In) Grade Top (mKB) Bottom (mKB) Run Date LINER 7 6.276 13CrL80 2,707.67 3,756.05 5/3/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm=) Eq. Mud Weight (g /L) P (LO) (kgf /cmr) 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • • Eni E &P Division Well Name: OP23 -W W02 ENI Petroleum Daily Report Weil Code: 23835 Field Name: Nikaitchuq • CO. Inc. Date: 5/13/2010 - Report #: 7 API/UWI: 50- 029 - 23411 -00 -00 eril page 1 of 1 Wellbore name: OP23 -WW02 Well Header Permit/Concession N ° Operator ENI Share ( %) Well Configuration type Oliktok Point ENI PETROLEUM 100.00 DIRECTIONAL Rotary Table Elevation (m) Ground Level (m) Water Depth (m) RKB - Base Flange (m) RKB - Tubing Spool (m) 16.22 3.72 9.60 10.13 Rig Information Contractor Rig Name Rig Type NABORS ALASKA NABORS 245 E LAND RIG Job Information Wellbore Job Phase Spud Date Target Depth (mKB) Target Depth (TV... Depth Dr. (MD) (m) Drilling Hours (hrs) Average ROP (m /hr) DFS (days) OP23 -WW02 COMPLETION 3,756.05 2,959.29 38.06 Daily Information Depth End (mKB) Depth End (TVD) (... Depth Progress (m) Drilling Hours (hrs) Average ROP (m /hr) POB Temperature (°C) Weather Wind 80.0 -7.6 Cloudy WC +9.1 72° ENE @ 6.8 mph Daily summary operation 24h Summary Ran 60 jts. 4 -1/2" 12.6# 13CrL80 Vam Top tubing set @ 2568' MD/ 2470' TVD. RD Nabors chrome casing running equipment and test upper and lower hanger seals to 5000 psi for 10 min - Good Test. ND BOPE and NU VetcoGray tree. Pull BPV and install 2 way check. Test hanger void and tree to 5000 psi for 10 min - Good Test. Pull 2 way check and install BPV. RU Little Red Services and test BPV to 2000 psi for 45 min - Good Test (Witnessed by Bob Noble). Pump 170 bbl diesel freeze protect taking returns to pits. RD Little Red Services and normal up tree. Prepare for rig move. Operation at 07.00 RIG RELEASED TO OPO4 - 07 @ 5/14/2010 00:00 HRS. 24h Forecast RIG RELEASED TO OPO4 - 07 @ 5/14/2010 00:00 HRS. Lithology Shows MAASP (kgf /cm=) Mud Weight (g /L) 1162.3 Time Log Cum Start End Dur Dur Time Time (hrs) (hrs) Phase Opr. Act. Plan Oper. Descr. 00:00 03:30 3.50 3.50 COMP K 4 P RUN TBG - Continue running 4 -1/2" Kill String. Ran 60 jts 4 -1/2" 12.6# 13CrL80 Vam Top tubing. 03:30 04:30 1.00 4.50 COMP K 1 P RUN TBG - PU MU VetcoGray tubing hanger and set BPV. Land tubing hanger and set lock down screws. 4 -1/2" 12.6# 13CrL80 Vam Top Kill String set @ 2568' MD/ 2470' TVD. 04:30 05:30 1.00 5.50 COMP K 5 P RD TBG EQUIP. - RD Nabors 4 -1/2" chrome tubing running equipment and clear floor Test upper and lower hanger seals to 5000 psi each- Good Test. 05:30 12:00 6.50 12.00 COMP K 5 P ND BOPE - PJSM on ND BOPE. ND BOPE and VetcoGray riser, set back same. 12:00 13:00 1.00 13.00 COMP K 12 P NU TREE - NU VetcoGray tree and install 2 way check. Test hanger void to 5000 psi for 10 min - Good Test. Test tree to 5000 psi for 10 min - Good Test. 13:00 15:00 2.00 15.00 COMP K 5 P RU - Pull 2 way check and install BPV. RU hoses and Little Red Services. 15:00 16:00 1.00 16.00 COMP K 12 P TEST BPV - Test BPV to 2000 psi for 45 min. - Good Test. Test witnessed by Bob Noble. Start 15min 30min 45min TBG (psi) 0 0 0 0 IA (psi) 0 2000 2000 2000 OA (psi) 275 400 400 400 16:00 18:30 2.50 18.50 COMP K 9 P FREEZE PROTECT - Pump 170 bbls diesel freeze protect in 9 -5/8" x 4 -1/2" IA with Little Red Services taking returns to pits. 18:30 20:00 1.50 20.00 COMP K 5 P RD - RD Little Red Services. Blowdown circulating hoses and RD Same. Normal up VetcoGray wellhead. 20:00 23:00 3.00 23.00 COMP K 1 P RDMO - Clean out mud system, move overboard cuttings tank and set diverter line. RELEASE RIG TO OPO4 -07 @ 5/14/2010 00:00 HRS. Daily Contacts Position Contact Name Company Title E -mail Office Mobile Eni representative Greg Parker ENI Expediter Greg.Parker @enipetroleum.com 907- 980 -7545 Eni representative Jack Keener ENI Drilling Supervisor jack.keener@enipetroleum.com 907- 670 -8623 907 - 715 -6434 Eni representative Jack Potter ENI Drilling HSE Jack.Potter @enipetroleum.com 907 - 670 -8624 Eni representative Joe Longo ENI Drilling Engineer joe.longo @enipetroleum.com 907- 670 -8623 907 - 947 -4323 Eni representative Tom Norvig ENI Rig Clerk AKRigClerks245e @enipetroleum.com 907- 670 -8607 907- 229 -6100 Last Casing seat Cas. Type OD (In) ID (in) Grade Top (mKB) Bottom (mKB) Run Date LINER 7 6.276 13CrL80 2,707.67 3,756.05 5/3/2010 Last Leakoff Test Depth (mKB) TVD (mKB) Fluid Type Fluid Density (g /L) P (Surf) (kgf /cm') Eq. Mud Weight (g /L) P (LO) (kgf /cm 2,795.02 2,031.89 VC -OBM 1234.2 119.5 1822.4 370.2 • [E it, [,\SEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMPIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Marc Kuck Senior Completion Engineer Eni US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Field, Undefined Pool, Nikaitchuq , OP23 -WW02 Sundry Number: 310 -151 Dear Mr. Kuck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this / q"day of May, 2010. Encl. . . 0 ( AX n c6 4 _ A 0 RECFN ID STATE OF ALASKA MAY 1 I. 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION 1111200 APPLICATION FOR SUNDRY APPROVALS Tasks (�ae Allettgecite 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown 0 Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: \p. Permit to Drill Number: Eni US Operating Co. Inc. Development ❑ Exploratory ❑ 209 -032,- 3. Address: Stratigraphic ❑ Service Q 6. API Number: 3800 Centerpoint Dr. Suite 300 Anchorage AK, 99503 50- 029 - 23411 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El OP23 -WW02 9. Property Qesignati %n (Lease Number): 10. Field / Pool(s').: ADL 355024, 373301, 390616 Nikaitchuq / Undefined Ada& .31,t_ A Ill- j 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12323 9550 Casing Length Size MD TVD Burst Collapse Structural Conductor 160 20" 160 160 4980 3240 Surface 4595 13 -3/8" 4595 3771.4 Intermediate 9087 9 -5/8" 9087 6611.2 6870 4750 Production Liner 3425 7 12323 9550 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11845 - 12045 9076.1 - 9274.2 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 12 BOP Sketch 0 Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 5/11/2010 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended 16. Verbal Approval: Date: 5/10/2010 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Jim Regg 14/4-41-44' 5wJ' GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Marc Kuck Printed Name Marc Kuck Title Senior Completion Engineer Signature ,- Phone 907- 242 -6942 Date 5/10/2010 fl ,f;C/ ■ , COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 -01 S\ Plug Integrity LYI BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: id r i/ 0 y / APPROVED BY lr 1 5/ 1 1-- I )o Approved by: COMMISSIONER THE COMMISSION Date: TA, L 9ii� 0R1G1NAL j� �Dl %. s <o . Form 10 -403 Revised � � O ■ I ~ i � Submit in Duplicate • Page 1 of 2 t Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, May 12, 2010 4:30 PM To: 'Kuck Marc' Cc: Longo Joseph Subject: RE: OP23 -WW02 UPDATE TO 10 -403 r' D X 1 ` 03 2— Marc, Thanks for the schematic. It shows the WRBP set at the current location of 8897' and (higher in the 7" liner than planned due to wellbore issues). It has been tested and will provide an adequate barrier to the reservoir along with the KWF and BPV. You can wait to submit a 10 -404 (Sundry report) when these current operations to secure the well are complete. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Kuck Marc [ mailto :marc.kuck @enipetroleum.com] Sent: Wednesday, May 12, 2010 3:26 PM To: Schwartz, Guy L (DOA) Cc: Longo Joseph Subject: RE: OP23 -WW02 UPDATE TO 10 -403 Guy, Attached is the schematic for well status during our operational shutdown of OP23 -WW02. We have tested the WLRPB to 3000 psi for 30 minutes with charted data. Current operations are laying down remaining drill pipe and will run kill string this evening. Thanks, Marc From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, May 12, 2010 8:11 AM To: Longo Joseph Cc: Kuck Marc Subject: RE: OP23 -WW02 UPDATE TO 10 -403 Joe, I did talk to Marc last night. This is an acceptable change to the approved procedure. Good luck. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 5/12/2010 • • Page 2 of 2 From: Longo Joseph [ mailto :joe.Iongo @enipetroleum.com] Sent: Tuesday, May 11, 2010 10:09 PM To: Schwartz, Guy L (DOA) Cc: Brink Jason; Kuck Marc; Beauchamp Scott Subject: OP23 -WW02 UPDATE TO 10 -403 Guy, I believe you have already talked with Marc Kuck about our decision to run a Baker Wireline Retrievable Bridge Plug (WRBP) as opposed to the Halliburton Bridge Plug set on DP. We will set the WRBP @ — 11745' MD/ 8977' TVD and test it 2250 psi for 30 min. POOH and run 2500' 4- 1/2" 13CrL80 12.6# Vam Top tubing, freeze protect, NU and test tree, set and test BPV to 2000 psi for 30 min, and RDMO. If you have any questions please do not hesitate to ask. Regards, Joseph Longo petroleum Drilling Engineer Anchorage, AK Office: (907) 865 -3323 Cell: (907) 947 -4323 Email: Joseph.Longo@enipetroleum.com This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 5/12/2010 • eni us operating eni us operating co. inc. 3800 Centerpoint Dr., Suite 300 Anchorage, AK 99503 - U.S.A. Tel. 907 - 865 -3300 Fax 907 - 865 -3380 • o _ D MAY 2010 5/10/2010 Anchcireac Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 10 -403 Sundry application for suspension of OP23 -WW02. Dear Commissioners, This application is for the suspension of the OP23 -WW02 water well. The planned completion for this well included a chrome shrouded ESP to artificially lift the water to surface. On transport to Oliktok Point the chrome motor assembly was damaged and deemed unable to run. Currently, the well has been perforated and has 9.7 ppg NaCI brine in the hole. The well is static. We will set a Halliburton retrievable bridge plug in 7" 26# Cr13L80 Vam Top casing at approximately 11745' MD/ 8977' TVD on 3 -1/2" x 5" drill pipe, approximately 100' above top perforation at 11845' MD/ 9076' TVD. Once the bridge plug is set on depth and we have pulled out of the hole with drill pipe, a 4 -1/2" 12.6# 13CrL80 Vam Top kill string will be run to +/- 2500' MD. We will then pump approximately 171 bbls diesel freeze protect, nipple up and test the tree and set the back pressure valve (BPV). If you have any questions please do not hesitate to contact Joseph Longo or Marc Kuck. Sincerely, Joseph Longo Drilling Engineer CeII: 907 - 947 -4323 Office: 907 - 670 -8623 Email: Joseph.Longo @Enipetroleum.com Marc Kuck Senior Completion Engineer � .���� i�� Cell: 907 - 242 -6942 � Office: 907 - 865 -3323 Email: Marc.Kuck @Enipetroleum.com • v ois, eni us veraIing eni OP23 -WW02 Detailed Suspension Procedure: 1.) Test BOPE. 2.) PU single 3 -1/2" 13.3# G -105 Drill pipe. 3.) MU Halliburton retrievable bridge plug running tool and bridge plug. 4.) TIH 129 its 3 -1/2" Drill pipe to +/- 4034' MD while monitoring well. 5.) TIH with 5 -1/2" 19.5# S -135 Drill pipe to 11745' MD/ 8977' TVD 100' above top perforation interval while monitoring well: • Top of perfs at 11845' MD/ 9076' TVD. • Total footage perforated: 120' - 4 -1/2" guns, 5spf • Perforation Intervals MD: 11845' - 11915' MD, 11995' - 12045' MD • Perforation Intervals TVD: 9076' - 9145' TVD, 9224' - 9274' TVD 6.) Spot corrosion inhibitor across packer setting depth. 7.) Set Halliburton Retrievable bridge plug in 7 ", 26 #,13CrL80, Vam Top casing with 1 /4 turn. Setting depth at 11745' MD/ 8977' TVD. (100' above top perforation interval) 8.) Test bridge plug to 2250 psi (TVD x .25) for 30 minutes and record on chart. 9.) Monitor well. 10.)POOH laying down DP with running tool on 3 -1/2" x 5" DP while monitoring well. 11.) RU 4 -1/2" tubing running equipment. • to sr eni us operating n 12.)RIH with +/- 2500' 4 -1/2 ", 12.6 #, 13CrL80, Vam Top tubing and land tubing hanger. 13.) RD tubing running equipment. 14.)RU Little Red and pump +/- 171 bbls diesel freeze protect. 15.) NU and test tree. 16.)Set back pressure valve (BPV). 17.)Test BPV through annular to 2000 psi for 30 min and record on chart. 18.)RDMO OP23 -WW02 and move to OPO4 -07. • ar. OP23 -WW02 BPV set and test from bottom to 2,000 psi peCrroo leurnn 4 - 13Cr 12.6 ppf Production Tubing Wellhead, 13 -3/8" x 4 - ", CR Flow -wetted 5,000 psi Wate Producer With Conductor, 20" Uninsulated set at +/- 120 ft Shrouded ESP Lift Operations Shutdown Well Status Diesel Freeze protect to 2500' MD, 2440' TVD All depths are RKB — 53.20 ft +/- 2,500 MD - 4 -W 12.6# 13Cr Tubing 9.7 ppg Brine to TD Surf. Casing 13 -3/8" 68 # 4595 MD, 3745 TVD 8888' MD - Top of Flex Lock Liner Hanger and ZXP Packer 8897' MD, 6488 TVD - Top of 7" WLRBP, tested /charted to 3,000 ■ `# psi for 30 minutes Interm. Casing Perforation Interval 9 -5/8" 47 # 11845 -11915 MD 9087 MD, 6613 TVD, 11995 -12045 MD D i Production Liner, 7" 26# 13 Cr 12,323' MD, 9,550' TVD Confidential MDK 5/12/10 1500 hrs • • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, May 11, 2010 10:54 AM To: 'Longo Joseph' Cc: 'Marc.Kuck @Enipetroleum.com'; Regg, James B (DOA) Subject: RE: OP23 -WW02 Water Source Well Suspension 10-403 Sundry Application (PTD 209 -032) Marc, As follow -up our phone call... I am going require notification of the inspector for the RBP pressure test. They may or may not decide to witness the PT. Please have the rig supervisor call the inspectors prior to the PT. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From Schwartz, Guy L (DOA) Sent: Tuesday, May 11, 2010 10:32 AM To: 'Longo Joseph' Cc: 'Marc.Kuck @Enipetroleum.com' Subject: RE: OP23 -WW02 Water Source Well Suspension 10 -403 Sundry Application (PTD 209 -032) Joe /Marc: After looking over the attached information and well history a more appropriate status for the well will be an "operational Shutdown ". I will change your application when received to reflect this. A follow -up 10-404 will be required once the wellwork is completed for the shutdown as described. The well procedure should also state pressure testing the RBP and BPV to verify proper settings. Also, I noticed the depth was not stated on the procedure in step # 7 in setting the RBP. Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Longo Joseph [ mailto :joe.longo @enipetroleum.com] Sent: Tuesday, May 11, 2010 12:16 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: Keener Jack; Kuck Marc; Beauchamp Scott; Carballo Nelson; Grandi Maurizio; Brink Jason Subject: OP23 -WW02 Water Source Well Suspension 10 -403 Sundry Application Jim, Attached is the 10 -403 Sundry Application for the suspension of the OP23 -WW02 Water Source Well. I will ask Marc Kuck bring the application to the Anchorage AOGCC office as soon as possible. Currently we are testing BOPE and plan to start running in the hole sometime this morning. If you have any questions concerning the attached documents please do not hesitate to call. Regards, I I 5/11/2010 Page 2 of 2 • Joseph Longo Drilling Engineer Eni US Operating Co. Inc Anchorage, AK Office: (907) 670 -8623 Cell: (907) 947 -4323 Email: Joseph.Longo_ @enipetroleum.com This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 5/11/2010 1 • SUAISLt nA 1-,\AASE1,-,\ SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COM11HSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Maurizio Grandi Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Dr. Ste 300 Anchorage AK 99503 Re: Nikaitchuq Field, Ivishak Undefined Water Supply Pool, OP23 -WW02 ENI US Operating Co. Inc. Permit No: 209 -032 (Revised) Surface Location: 3130' FSL, 1704' FEL, S5, T13N, R9E, UM Bottomhole Location: 4372' FSL, 1154' FEL, S32, T14N, R9E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced service well. This approval supersedes and replaces the permit to drill for this well that was issued on April 1, 2009. In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name Nikaitchuq OP23 -WW02 and API number 50- 029 - 23411- 70 from records, data and logs acquired for well Nikaitchuq OP23 -WW02. 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 1 • • representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). S/a .m sioner DATED this g day of March, 2010 cc: Department of Fish & Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) • • RECEIV / STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION r ' . 4 2010 PERMIT TO DRILL < &Gescons.Commissiurt 20 AAC 25.005 Anchorage Re.0 e, 1 a. Type of Work: 1 b. Current Well Class: Exploratory ❑ Development Oil ❑ 1 c. Specify if well is proposed for: Drill 0 Re -drill ❑ Stratigraphic Test ❑ Service 0 Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: a Blanket ❑ Single Well 11. Well Name and Number: t t ENI US Operating Co Inc Bond No. RLB0008627 ' OP23 - WW02 • Ncie. 3. Address: 6. Proposed Depth: 12. Field /Pool(s): 3800 Centerpoint Drive Suite 300, Anchorage 99503 MD: 12369' TVD: 9753' Nikaitchuq / Undefined . 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 3130' FSL, 1704' FEL, S5 T13N R9E UM • ADL 355024, 373301, 390616 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4160' FSL, 1175' FEL, S32 T14N R9E UM ADL 417493 • 4/1/2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4378' to South Line • 4372' FSL, 1154' FEL, S32 T14N R9E UM • 1,280' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x 516577 • y 6036483 • Zone 4 (Height above GL): 12' MSL & 53.2' RKB ' Well within Pool: NA 16. Deviated wells: Kickoff depth: 900 • ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 50° d Downhole: 4616 psig , Surface: 3693 psig . 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X -65 Welded 124 36 36 160 ' 160 pre - installed 16" 13 -3/8" 68 L -80 BTC 4596 35 35 4631 , 3768. 747 sx 10.7# ASL, 217 sx 12.0# Deeperete 12.25" 9 -5/8" 47 L -80 BTCM 9002 33 33 9035 6628 365 sx 15.8# Class G 8.5" 7" 26 13CrL80 Vam Top 3569 8800 6475 12369 9753 498 sx 15.8# Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor /Structural RECEIVED i Surface RECEIVED Intermediate Production MAR 0 1 2010 Alaska Oil k Cas Cons Commissio# Perforation Depth MD (ft): Perforation Depth TVD (ft): Anchorage 20. Attachments: Filing Fee ❑ BOP Sketc h��II Drilling ProgranQ Time v. Depth Lit Shallow Hazard Analysis Q Property Plat El Diverter Sketcr Seabed Repor0 Drilling Fluid Prog j 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joseph Longo @ 907 - 865 - 3323 Printed Name Maurizio Grandi Title Well Operation Project Manager 1 Signature ( L t Phone Date Z ' S I i ,0 �` Commission Use Only Permit to Drill API Number: / /� Permit A .'nrov�l See cover letter Number: �(0 1 . V V 50- 0 ���., Z, 3 ' / ../ ` l { / .0 C� ;_c Date/ 2 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 in shales: Er * Soot) p ' i 30P £ 'rs �- / , > Samples req'd: Yes No ,, log req'd: Yes o �j I Other: , t i, 1-; a.&) H2S measures: Yes 7'; Er Direct q'd Yes i tQ�N C_ o • -- (/!"G i K PTO V S Ti /2r+..C�C a n 3 e p� C' � . D BY THE COMMISSION at , DATE: , COMMISSIONER Form 1U Kevisea 'IL /LUUb INA ' • id / /G yy it in uupuCate ,( 3 2./0 • 0 RECEIV - 9 . :, ni �,= tr®I u E: . 4 2010 Andicage 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 RECEIVED Maurizio Grandi Phone (907) 865 -3320 MAR 0 1 2010 Email: Maurizio .Grandi @enipetroleum.com February 22, 2010 Alaska Oil & Gas Cons. Commission Anchorage Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, Alaska 99501 RE: REVISED Application for Permit to Drill Water Producer OP23 -WW02 Dear Commissioners, THIS APPLICATION IS A REVISION. Please refer to permit # 209 -032 which was approved 3- 25 -09. ENI US Operating Co. Inc. hereby applies for a REVISION to Permit to Drill #209 -032 for the onshore water production well OP23 -WW02. The well will be drilled and completed using Nabors rig 245E. The planned spud date for OP23 -WW02 is April 5, 2010. Please find attached for the review of the Commission forms 10 -401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Jason Brink at 907 - 865 -3321 or Joseph Longo at 907 - 865 -3323. Sincerely, 04 - Maurizio Grandi Well Operation Project Manager gD/?7'Qr /`et ct / C'o o h a4( /�o. / o ccc d l /-e J ,'v and. //t o r '0 c c✓ 71i.E'ir? 1•6 /�,eg a' G/ 2. 6(/-G 7:9e. , f,"�il� / a h / /D. ,...b. S� a 1Lv9P0. o f a rcoro;..) /y, jr-b-p y 3 //d • vost En PetrolleLulm �i Application for Permit to Drill Well 0P23 -WW02 Saved: 24- Feb -10 REVISED Application for Permit to Drill Document Water Producer Well OP23 -WW02 Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005 (1) 2 2. Location Summary 2 Requirements of 20 AAC 25.005(c)(2) 2 Please see Attachment 7: Surface Platt 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 3 4. Drilling Hazards Information 3 Requirements of 20 AAC 25.005 (c)(4) 3 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005 (c)(5) 5 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 5 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 5 8. Drilling Fluid Program 6 Requirements of 20 AAC 25.005(c)(8) 6 Surface Hole Mud Program (extended bentonite) 6 Intermediate Hole Mud Program (LSND) 6 Production Hole Mud Program (MI VersaClean Mineral Oil Base) 6 9. Abnormally Pressured Formation Information 6 Requirements of 20 AAC 25.005 (c)(9) 6 10. Seismic Analysis 7 Requirements of 20 AAC 25.005 (c)(10) 7 100217 OP23 -WW02 PERMIT Document Page 1 of 9 Printed: 24- Feb -10 vo, • Enli Peiirolleum env Application for Permit to Drill Well 0P23 -WW02 Saved: 24- Feb -10 11. Seabed Condition Analysis 7 Requirements of 20 AAC 25.005 (c)(11) 7 12. Evidence of Bonding 7 Requirements of 20 AAC 25.005 (c)(12) 7 13. Proposed Drilling Program 7 Requirements of 20 AAC 25.005 (c)(13) 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 AAC 25.005 (c)(14) 8 15.Attachments 9 Attachment 1 Directional Plan 9 Attachment 2 Drilling Hazards Summary 9 Attachment 3 BOP and Diverter Configuration 9 Attachment 4 Cement Loads and CemCADE Summary 9 Attachment 5 Well Schematic 9 Attachment 6 Formation Integrity And Leak Off Test Procedure 9 Attachment 7 Surface Platt 9 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25 040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number a to the well by the commission. The well for which this Application is submitted will be designated as OP23 -WW02. This permit request is a revision to the previously approved permit #209 -032. The BHL has been moved by >3000'. This • request will also add a pilot hole for logging just below the intermediate casing shoe. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the properly and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; 100217 0P23 -WW02 PERMIT Document Page 2 of 9 Printed: 24- Feb -10 • �� � Enil � r n Application for Permit to Drill Well 0P23 -WW02 Saved: 24- Feb -10 Location at Surface 3130' FSL, 1704' FEL, S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates . RKB Elevation 53.2' AM S L Northings 6,036,483 Eastings: 516,576' . Pad Elevation 12' AMSL Location at Top of Ivishak Sand Target 4160' FSL, 1175' FEL, S32 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 11,546' Northings: 6,042,793' Eastings: 517,071' Total Vertical Depth, RKB: 8,958' Total Vertical Depth, 55: 8,905' Location at Total Depth 4372' FSL, 1154' FEL, S32 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 12,369' Northings: 6,043,005' Eastings: 517,091' Total Vertical Depth, RKB: 9,753' Total Vertical Depth, 55: 9,700' Please see Attachment 7: Surface Platt and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbare (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25. 005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a /ready on file with the commission and identified in the application: (3) a diagram and description of the blowout prevenb'on equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please see Attachment 3: BOP and Diverter Configuration • 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including 100217 OP23 -WW02 PERMIT Document Page 3 of 9 Printed: 24- Feb -10 en v 4, fp Enii PeiroIIeurn Application for Permit to Drill Well OP23 -WW02 Saved: 24- Feb -10 (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; Sag River sand: The expected reservoir pressure is 0.55 psi /ft, or 10.5 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the planned vertical depth of the formation: MPSP = (8393 ft TVD)(0.55 - 0.11 psi /ft) = 3693 psi • Ivishak sand: The expected reservoir pressure is 0.51 psi /ft, or 9.8 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the planned vertical depth of the formation: MPSP = (8731 ft TVD)(O.51 - 0.11 psi /ft) = 3492 psi Kuparuk sand: The expected reservoir pressure is 0.53 psi /ft, or 10.2 ppg EMW (equivalent mud weight). ' The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the planned vertical depth of the formation: MPSP = (6778 ft TVD)(0.53 - 0.11 psi /ft) = 2846 psi (B) data on potential gas zones; The well bore is not expected to penetrate any gas zones. • and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 100217 OP23 -WW02 PERMIT Document Page 4 of 9 Printed: 24- Feb -10 mIt • E n PeroIIeum � Application for Permit to Drill Well OP23 -WW02 Saved: 24- Feb -10 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a descrlption of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f,; Please see Attachment 6: Formation Integrity And Leak Off Test Procedure 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the fo /lowing items, except for an item a /ready on file with the comet /scion and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre - perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (lb/ft) Grade Connecti (ft) (ft) (ft) Cement Program on 20 178.89 X -65 Welded 124 36 / 36 1607 160' - Cemented to surface Cemented to Surface with 747 sx 10.7# ASLite Lead Yield 4.33 cu. Ft./ sk, 13 -3/8 16" 68 L -80 BTC 4596' 35 / 35 4631' / 3768', 217 sx 12.0# DeepCRETE Tail Yield 1.60 cu. ft./ sk Cement Top plan @ 8035' MD Cemented w/ 365 sx 9 -5/8 12 -1/4" 47 L -80 BTCM 9002' 33 / 33 9035' / 6628' 15.8# Class G Yield 1.16 cu. ft./ sk Cement Top plan @ 9076' MD Pilot 8 -1/2" NA NA NA 582' 9035' / 6628' 9617' / 7057' Cemented w/ 334 sx Hole 17.0# Class G Yield 1.00 cu. ft./ sk 13 Cement Top plan @ 8800' MD 7" liner 8 -1/2" 26 Chrome Vam 3569' 8800' / 6475' 12369'/ 9753' cemented w/ 498 sx L -80 Top 15.8# Class G Yield 1.16 cu. ft./ sk 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the fo /lowing items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 3: BOP and Diverter Configuration 100217 OP23 -WW02 PERMIT Document Page 5 of 9 Printed: 24- Feb -10 • En PetroHeuim em Application for Permit to Drill Well OP23 -WW02 Saved: 24- Feb -10 A 21 -1/4 ", 2000 psi diverter with a 16" diameter diverter line and valve will be the diverter system used for drilling the surface hole. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.8 9.2 9.2 9.6 Funnel Viscosity 250 250 150 200 (seconds) Yield Point 35 45 30 35 (lb/100 sO Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 <6.0 <6.0 (cc/30 min)) Intermediate Hole Mud Program (LSND) Production Hole Mud Program (MI VersaClean Mineral Oil Base) 13 -3/8" Csg Shoe to 9 -5/8" Csg Point Value Value Density (ppg) 10.5 - 11.0 • Density (ppg) 9.2 - 9.5 Plastic Viscostiy <23.0 Funnel Viscosity 45 - 60 (CP) (seconds) Yield Point 20 - 25 Plastic Viscostiy (lb /100 sf) (CP) 12 - 18 HTHP Fluid loss Yield Point (m1/30 min @ <5.0 (lb/100 sf) 18 -24 200psi & 100 °F API Filtrate Oil / Water Ratio 75 / 25 (cc / 30 min)) 4 - 6 Electrical 650 -900 Chlorides (mg /I) <500 Stability pH 9.0 - 10.0 MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: 100217 OP23 -VVW02 PERMIT Document Page 6 of 9 Printed: 24- Feb -10 ni Clnlll Pefirolleuim Application for Permit to Drill Well OP23 -WW02 Saved: 24- Feb -10 (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic, refraction or reflection analysis as required by 20 AAC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. . 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom- founded structure, jack -up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. • 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commisslon and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding }have been met; Evidence of bonding for ENI is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in / rig up Nabors 245E. Install 21 -1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 16" hole to casing point at as per directional plan. Run Gyro and MWD tools' as required for directional monitoring. 3. Run and cement 13 -3/8 ", 68 #, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 4. Remove diverter system, install and test wellhead to 5000 PSI. 5. Nipple up 13 -5/8" 5K BOP and test to 5000 PSI. Notify AOGCC 24 hrs before test. 6. Pressure test casing to 2500 psi per AOGCC regulations. Record results. 7. PU 12 -1/4" bit and 8" directional drilling assembly with MWD, LWD and PWD. 8. Drill out cement and between 20' and 50' of new hole. Perform LOT, recording results. 9. Directionally drill to 9 -5/8" casing point. 10. Run and cement 9 -5/8 ", 47# L80, BTC Mod casing to surface. Pump cement and displace with mud, land casing hanger and bump plug. 100217 OP23 -WW02 PERMIT Document Page 7 of 9 Printed: 24- Feb -10 r mtt • env • Cin��l Peirolleuum Application for Permit to Drill Well OP23 -WW02 Saved: 24- Feb -10 11. Install 9 -5/8" packoff and test to 5000 psi. 12. Flush 13 -3/8" x 9 -5/8" annulus with diesel freeze protect. 13. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 14. PU 8 -1/2" bit and directional drilling assembly including MWD, LWD and PWD. RIH, clean out cement to top of float equipment. 15. Drill out cement and between 20' and 50' of new hole. Displace hole to OBM drilling fluid. Perform LOT, recording results. 16. Directionally drill 8 -1/2" pilot hole through the Jurassic formation as per directional plan. 17. RU and run WL logs. 18. RIH with stinger and cement pilot hole back to +/- 50' below the 9 -5/8" shoe. Tag top of cement. 19. Directionally drill 8 -1/2" hole to TD as per directional plan. 20. RU and run WL logs. 21. Run and cement 7 ", 26# 13CrL80, Vam Top Liner. 22. Liner hanger to be set with 200' Liner lap inside the 9 -5/8" intermediate casing. POOH laying down DP as required. 23. Test casing and liner to 3000 psi and record. 24. Run cased hole wire line logs and perforate. 25. PU ESP completion as required and RIH to depth, before landing tubing spot corrosion inhibited brine throughout entire inner annulus. Land tubing. Set BPV 26. Nipple down BOP, nipple up tree and test. Pull BPV. 27. Freeze protect well with diesel through shear out valve in tubing. 28. Set BPV and move rig off. 29. Rig up wire line unit. Pull BPV. 30. Set dummy valve in mandrel. Use ESP to clean up well. 31. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a /ready on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point ' Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 100217 OP23 -WW02 PERMIT Document Page 8 of 9 Printed: 24- Feb -10 � _ ,241 Peirooeum • eno Application for Permit to Drill Well OP23 -WW02 Saved: 24- Feb -10 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7 Surface Platt • 100217 OP23 -WW02 PERMIT Document Page 9 of 9 Printed: 24- Feb -10 _r Enl Petroleum Schlumberger „ ,. OP23- WW02PB1 (P1) Proposal Report Date: February 10, 2010 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: ENI Vertical Section Azimuth: 5.000° Field: Nikaitchuq Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: Oliktok Point / OP23 ��� � TVD Reference Datum: Rotary Table Well: OP23 -WW02 ■ TVD Reference Elevation: 53.20 ft relative to MSL . Borehole: OP23- WW02PB1 aS' b' I ; Sea Bed 1 Ground Level Elevation: 12.20 ft relative to MSL • UWIIAPI#: 50029xxxxx70 Magnetic Declination: 21.748° Survey Name /Date: OP23- WWO2PB1 (P1) / February 10, 2010 Total Field Strength: 57669.092 nT Tort / AHD / DDI / ERD ratio: 67.173° / 5973.67 ft / 5.737 / 0.832 Magnetic Dip: 80.953° • Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 15, 2010 Location Lat/Long: N 70.51086102, W 149.86435227 Magnetic Declination Model: BGGM 2009 Location Grid AVE Y/X: N 6036483.060 ftUS, E 516576.840 ftUS North Reference: True North Grid Convergence Angle: +0.12787579° Total Corr Mag North -> True North: +21.748° Grid Scale Factor: 0.99990031 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical NS EW Mag / Gray Directional Zone Of Zone Of Comments Inclination Sub -Sea TVD TVD DLS Northing Easting Depth True Section True North True North Tool Face Difficulty Exclusion Exclusion (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft ) (deg) _ (deg/100ft ) Index (deg) Alert (ftUS) (ftUS) RTE 0.00 0.00 340.00 -53.20 0.00 0.00 0.00 0.00 - -- 0.00 0.00 9.05 Alert 6036483.06 516576.84 WRP 41.00 0.00 340.00 -12.20 41.00 0.00 0.00 0.00 - -- 0.00 0.00 9.05 Alert 6036483.06 516576.84 20" Conductor 154.20 0.00 340.00 101.00 154.20 0.00 0.00 0.00 - -- 0.00 0.00 9.05 Alert 6036483.06 516576.84 SV4 728.20 0.00 340.00 675.00 728.20 0.00 0.00 0.00 -- 0.00 0.00 9.05 Alert 6036483.06 516576.84 KOP Bld 1.5/100 • 900.00 0.00 340.00 846.80 900.00 0.00 0.00 0.00 340.00M 0.00 0.00 9.05 Alert 6036483.06 516576.84 SV3 958.20 0.87 340.00 905.00 958.20 0.40 0.42 -0.15 340.00M 1.50 0.00 8.42 Alert 6036483.48 516576.69 Bld 3/100 1000.00 1.50 340.00 946.79 999.99 1.19 1.23 -0.45 340.00M 1.50 0.29 7.99 Alert 6036484.29 516576.39 1100.00 4.25 340.00 1046.65 1099.85 5.73 5.94 -2.16 340.00M 2.75 1.43 6.52 Alert 6036489.00 516574.66 1200.00 7.00 340.00 1146.16 1199.36 14.61 15.15 -5.52 HS 2.75 2.05 6.01 Alert 6036498.20 516571.29 SV2 1218.99 7.52 340.00 1165.00 1218.20 16.79 17.41 -6.34 HS 2.75 2.14 6.06 Alert 6036500.45 516570.47 1300.00 9.75 340.00 1245.09 1298.29 27.81 28.84 -10.50 HS 2.75 2.48 6.70 Alert 6036511.87 516566.28 1400.00 12.50 340.00 1343.20 1396.40 45.30 46.97 -17.09 HS 2.75 2.80 8.29 Alert 6036529.98 516559.64 Cry 2.75/100 1436.36 13.50 340.00 1378.63 1431.83 52.71 54.65 -19.89 32.37R 2.75 2.90 9.01 Alert 6036537.66 516556.83 1500.00 15.01 343.62 1440.31 1493.51 67.12 69.54 -24.76 28.86R 2.75 3.05 9.63 Alert 6036552.54 516551.93 1600.00 17.46 348.05 1536.31 1589.51 93.53 96.65 -31.52 24.61R 2.75 3.27 11.10 6036579.63 516545.11 1700.00 20.00 351.40 1631.01 1684.21 124.51 128.24 -37.18 21.44R 2.75 3.45 12.99 6036611.20 516539.37 SV1 1730.93 20.79 352.27 1660.00 1713.20 135.00 138.91 -38.71 20.62R 2. 3.50 13.63 6036621.86 516537.82 1800.00 22.58 354.01 1724.18 1777.38 159.98 164.24 -41.74 19.00R 2.75 3.61 15.14 6036647.19 516534.73 1900.00 25.19 356.12 1815.61 1868.81 199.86 204.58 -45.19 17.08R 2.75 3.75 17.45 6036687.52 516531.20 2000.00 27.83 357.85 1905.09 1958.29 244.06 249.15 -47.51 15.53R 2.75 3.88 19.88 6036732.08 516528.78 UG4 2074.09 29.80 358.94 1970.00 2023.20 279.53 284.84 -48.49 14.57R 2.75 3.97 21.72 6036767.76 516527.72 WellDesign Ver SP 2.1 Bld( users) OP23\ OP23- WW02 \OP23- WW02PB1 \OP23- WW02PB1 (P1) Generated 2/10/2010 11:50 AM Page 1 of 2 I Measured Azimuth Vertical NS EW Mag 1 Gray Directional Zone Of Zone Of Comments Inclination Sub -Sea TVD TVD DLS Northing Easting Depth True Section True North True North Tool Face Difficulty Exclusion Exclusion (ft) (deg) (deg) (ft ) (ft) (ft) (ft) I (ft) 1 ( deg ) 1 (deg/100ft ) Index (deg) Alert (ftUS) (ftUS) 2100.00 30.49 359.30 1992.41 2045.61 292.48 297.85 -48.69 14.26R 2.75 4.00 22.37 6036780.77 516527.49 2200.00 33.16 0.54 2077.37 2130.57 345.00 350.58 -48.75 13.21R 2.75 4.10 24.92 6036833.49 516527.31 2300.00 35.84 1.61 2159.77 2212.97 401.50 407.21 -47.67 12.33R 2.75 4.20 27.50 6036890.12 516528.27 2400.00 38.53 2.55 2239.43 2292.63 461.86 467.60 -45.46 11.57R 2.75 4.30 30.12 6036950.51 516530.34 2500.00 41.23 3.39 2316.16 2369.36 525.94 531.63 -42.13 10.93R 2.75 4.38 32.75 6037014.54 516533.53 2600.00 43.93 4.14 2389.78 2442.98 593.58 599.14 -37.68 10.38R 2.75 4.47 35.40 6037082.06 516537.83 UG2 2678.08 46.05 4.68 2445.00 2498.20 648.78 654.18 -33.43 10.00R 2.75 4.53 37.47 6037137.10 516541.96 2700.00 46.64 4.82 2460.13 2513.33 664.64 669.98 -32.12 9.90R 2.75 4.54 38.06 6037152.90 516543.23 2800.00 49.35 5.44 2527.04 2580.24 738.94 743.99 -25.46 9.48R 2.75 4.62 40.73 6037226.91 516549.72 End Cry 2806.29 49.52 5.48 2531.13 2584.33 743.72 748.75 -25.01 - -- 2.75 4.62 40.90 6037231.67 516550.17 le L Ugnu 3705.73 49.52 5.48 3115.00 3168.20 1427.86 1429.79 40.34 -- 0.00 4.94 40.90 6037912.79 516613.98 Top N Sand 4121.66 49.52 5.48 3385.00 3438.20 1744.24 1744.73 70.55 - -- 0.00 5.03 40.90 6038227.76 516643.49 Base N Sand 4190.98 49.52 5.48 3430.00 3483.20 1796.97 1797.22 75.59 - -- 0.00 5.05 40.90 6038280.26 516648.41 13 -3/8 "Csg 4529.89 49.52 5.48 3650.00 3703.20 2054.75 2053.83 100.21 - -- 0.00 5.11 40.90 6038536.90 516672.46 Top HRZ 8681.50 49.52 5.48 6345.00 6398.20 5212.62 5197.37 401.82 -- 0.00 5.56 40.91 6041680.79 516967.01 Base HRZ 8797.03 49.52 5.48 6420.00 6473.20 5300.50 5284.86 410.21 - -- 0.00 5.57 40.91 6041768.28 516975.21 8951.08 49.52 5.48 6520.00 6573.20 5417.67 5401.50 421.40 - -- 0.00 5.58 40.91 6041884.94 516986.14 9 -5/8" Csg 8951.10 49.52 5.48 6520.01 6573.21 5417.68 5401.51 421.40 - -- 0.00 5.58 40.91 6041884.95 516986.14 Drp 2/100 8971.08 49.52 5.48 6532.98 6586.18 5432.89 5416.64 422.85 LS 0.00 5.58 40.91 6041900.08 516987.56 9000.00 48.94 5.48 6551.87 6605.07 5454.79 5438.45 424.94 LS 2.00 5.59 40.33 6041921.89 516989.60 9100.00 46.94 5.48 6618.85 6672.05 5529.03 5512.35 432.04 LS 2.00 5.61 38.34 6041995.80 516996.53 9200.00 44.94 5.48 6688.38 6741.58 5600.89 5583.89 438.90 LS 2.00 5.63 36.34 6042067.34 517003.23 Kuparuk 9251.28 43.92 5.48 6725.00 6778.20 5636.79 5619.62 442.33 LS 2.00 5.64 35.32 6042103.08 517006.58 9300.00 42.94 5.48 6760.38 6813.58 5670.28 5652.96 445.53 LS 2.00 5.65 34.35 6042136.43 517009.70 9400.00 40.94 5.48 6834.75 6887.95 5737.12 5719.49 451.91 LS 2.00 5.67 32.35 6042202.97 517015.94 9500.00 38.94 5.48 6911.42 6964.62 5801.31 5783.40 458.04 LS 2.00 5.69 30.36 6042266.88 517021.93 1 9600.00 36.94 5.48 6990.27 7043.47 5862.80 5844.61 463.91 LS 2.00 5.71 28.37 6042328.09 517027.66 9700.00 34.94 5.48 7071.23 7124.43 5921.49 5903.03 469.52 LS 2.00 5.73 26.38 6042386.53 517033.14 do TD 9771.08 33.52 5.48 7129.99 7183.19 5961.48 5942.84 473.34 - -- 2.00 5.74 24.96 6042426.34 517036.87 Survey Error Model: SLB ISCWSA version 24 *** 3 -D 95.00% Confidence 2.7955 sigma Surveying Prog: MD From (ft) MD To ( ft) EOU Freq Survey Tool Type Borehole -> Survey 0.00 41.00 1/100.00 SLB_ZERO -Depth Only OP23- WW02PB1 -> OP23- WW02PB1 (P1) 41.00 4529.89 1/100.00 SLB_MWD +GMAG^^1 OP23- WW02PB1 -> OP23- WW02PB1 (P1) 4529.89 8951.10 1/100.00 SLB_MWD +GMAG^^2 OP23- WW02PB1 -> OP23- WW02PB1 (P1) 8951.10 9771.08 1/100.00 SLB_MWD +GMAG^^3 OP23- WW02PB1 -> OP23- WW02PB1 (P1) Legal Description: Northing (Y) fftUS1 Eastina (X) fftUSI Surface : 3130 FSL 1704 FEL S5 T13N R9E UM 6036483.06 516576.84 BHL : 3793 FSL 1212 FEL S32 T1414 R9E UM 6042426.34 517036.87 WellDesign Ver SP 2.1 Bld( users) OP23\ 0P23- WW02 \0P23- WW02PB1 \0P23- WW02PB1 (P1) Generated 2/10/2010 11:50 AM Page 2 of 2 l; Eni Petroleum Schlumberger OP23 -WW02 (P5) Proposal Report Date: February 10, 2010 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: ENI Vertical Section Azimuth: 5.000° Field: Nikaitchuq Vertical Section Origin: N 0.000 ft, E 0.000 if Structure 1 Slot: Qliktok Point / OP23 TVD Reference Datum: Rotary Table Well: OP23 -WW02 ■ ■ ■ stud y TVD Reference Elevation: 53.20 ft relative to MSL Borehole: OP23 -WW02 s' b'' Sea Bed 1 Gr ound Level Elevation: 12.20 ft relative to MSL UWI/API#: 50029 ea Magnetic Declination: 21.826° Survey Name / Date: OP23 -WW02 ( ) / February 10, 2010 Total Field Strength: 57663.630 nT Tort / AHD / DDI / ERD ratio: 85.696° / 6555.48 ft / 5.853 / 0.672 Magnetic Dip: 80.951° • Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 14, 2010 Location Lat/Long: N 70.51086102, W 149.86435227 Magnetic Declination Model: BGGM 2009 Location Grid N/E YIX: N 6036483.060 ftUS, E 516576.840 ftUS North Reference: True North Grid Convergence Angle: +0.12787579° Total Corr Mag North -> True North: +21.826° Grid Scale Factor: 0.99990031 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical NS EW Mag 1 Gray Directional Zone Of Zone Of Comments Inclination Sub -Sea TVD TVD DLS Northing Easting Depth True Section True North True North Tool Face Difficulty Exclusion Exclusion (ft) (deg) (deg) (ft) (ft) ((t) (ft ) (ft) (deg) (deg/100ft) _ Index _ (deq) Alert (ftUS) (ftUS) Drp 4/100 8970.75 49.52 5.48 6532.77 6585.97 5432.63 5416.39 422.83 179.35R 0.00 5.58 40.91 6041899.83 516987.54 8976.56 49.29 5.48 6536.55 6589.75 5437.04 5420.78 423.25 - -- 4.00 5.58 40.68 6041904.22 516987.95 8978.07 49.29 5.48 6537.53 6590.73 5438.19 5421.92 423.36 LS 0.00 5.58 40.68 6041905.36 516988.06 9000.00 48.41 5.48 6551.96 6605.16 5454.70 5438.36 424.94 LS 4.00 5.59 39.80 6041921.80 516989.60 9100.00 44.41 5.49 6620.89 6674.09 5527.12 5510.45 431.86 LS 4.00 5.63 35.81 6041993.90 516996.36 9200.00 40.41 5.49 6694.71 6747.91 5594.55 5577.57 438.31 LS 4.00 5.66 31.83 6042061.03 517002.66 Kuparuk . 9239.32 38.84 5.49 6724.99 6778.19 5619.62 5602.53 440.71 HS 4.00 5.68 30.26 6042085.99 517005.00 OP WW02 Kup Tgt 9239.33 38.84 5.49 6725.00 6778.20 5619.63 5602.54 440.71 LS 4.00 5.68 30.26 6042086.00 517005.00 9300.00 36.41 5.49 6773.05 6826.25 5656.67 5639.41 444.25 LS 4.00 5.70 27.84 6042122.87 517008.46 9400.00 32.41 5.49 6855.53 6908.73 5713.17 5695.65 449.66 LS 4.00 5.73 23.86 6042179.12 517013.74 e 9500.00 28.41 5.49 6941.75 6994.95 5763.78 5746.03 454.50 LS 4.00 5.75 19.89 6042229.51 517018.47 9600.00 24.41 5.49 7031.29 7084.49 5808.25 5790.30 458.76 LS 4.00 5.78 15.93 6042273.78 517022.63 9700.00 20.41 5.49 7123.72 7176.92 5846.37 5828.25 462.40 LS 4.00 5.80 12.00 6042311.73 517026.19 9800.00 16.41 5.49 7218.58 7271.78 5877.95 5859.69 465.42 LS 4.00 5.83 8.14 Alert 6042343.17 517029.14 End Drp 9835.33 15.00 5.49 7252.59 7305.79 5887.52 5869.21 466.34 - -- 4.00 5.83 6.81 Alert 6042352.69 517030.03 Top Sag 11199.21 15.00 5.49 8570.00 8623.20 6240.50 6220.58 500.11 - -- 0.00 5.84 6.81 Alert 6042704.11 517063.02 Top Shublik 11302.74 15.00 5.49 8670.00 8723.20 6267.29 6247.26 502.67 -- 0.00 5.84 6.81 Alert 6042730.79 517065.52 Top lvishak 11546.03 15.00 5.49 8905.00 8958.20 6330.26 6309.94 508.70 - -- 0.00 5.85 6.81 Alert 6042793.47 517071.40 Kavik Shale 12167.19 15.00 5.49 9505.00 9558.20 6491.02 6469.97 524.08 - -- 0.00 5.85 6.81 Alert 6042953.52 517086.43 Echooka 12317.31 15.00 5.49 9650.00 9703.20 6529.88 6508.64 527.80 - -- 0.00 5.85 6.81 Alert 6042992.20 517090.06 TD • 12369.07 15.00 5.49 9700.00 • 9753.20 6543.27 6521.98 529.08 - -- 0.00 5.85 6.81 Alert 6043005.54 517091.31 WellDesign Ver SP 2.1 Bld( users) OP23 \OP23- WW02 \OP23- WW02 \OP23 -WW02 (P5) Generated 2/10/2010 12:05 PM Page 1 of 2 Survey Error Model: SLB ISCWSA version 24 * ** 3 -D 95.00% Confidence 2.7955 sigma Surveying Proq: MD From (ft 1 MD To (ft 1 EOU Freq Survey Tool Type Borehole -> Survey 0.00 41.00 1/100.00 SLB_ZERO -Depth Only OP23- WW02PB1 -> OP23- WW02PB1 (P1) 41.00 4529.89 1/100.00 SLB_MWD +GMAG^^1 OP23- WW02PB1 -> OP23- WW02PB1 (P1) 4529.89 8970.75 1/100.00 SLB_MWD +GMAG^"2 OP23- WW02PB1 -> OP23- WW02PB1 (P1) 8970.75 12369.07 1/100.00 SLB_MWD +GMAG " "3 OP23 -WW02 -> OP23 -WW02 (P5) Legal Description: Northing (Y) fftUS1 Eastinq (X) fftUS1 Surface : 3130 FSL 1704 FEL S5 T13N R9E UM . 6036483.06 516576.84 Target : 3453 FSL 1246 FEL S32 T14N R9E UM - 6042086.00 517005.00 BHL : 4372 FSL 1154 FEL S32 T14N R9E UM • 6043005.54 517091.31 • • WellDesign Ver SP 2.1 Bld( users) OP23 \0P23- WW02 \0P23- WW02 \0P23 -WW02 (P5) Generated 2/10 /2010 12:05 PM Page 2 of 2 • Eni Petroleum Schlumberger VVELL OP23- WW / WW -02 (P1 -5)I FIELD Nikaitchuq I STRUCTURE Oli ktok Point Magnetic Parameters Surface Locaeen NAD27 Alaska State Planes. Zone 04, US Feet I !M Mkcellaneous Model BGGM 2009 Dip: 80.951° Date : February 14.2010 fat. N703039.100 NMl 8n9: 603548306 SUS GM Cony: 5.12787579° Slay OP33 ND Ref: Rotary Table (5320 ft above MSL) Meg Dec: .21.828° FS 576836 nT ton'. W149 51 51 668 Easdg: 51657814 SUS Scale Fact 0.9999003121 Plan OP23 -WWOZ (P5) Srvy Date February 10.2010 0 1200 2400 3600 4800 6000 0 0 RTE 20" Conductor Bid 3/100 1200 .....:... : V2::.:: v::.: u::•.::.::....:v.:u:......:...a W A w a•......•::.•:.:•.::•.•::..:.{•:.::..:•:.::.::.:,•.•:..:: a::.::.::.:,.•:....,: •.•:...:a::•.:•..:.::•.::•..... 1200 Cry 2.75/100 v1 End Cry 2400 2400 _..-..- ..- ..- ..- ..- ..- .._.._.._.. - - . _.. 9Ru .- ..- ..- .._.._ ._..-..-..-..-..-.._..-..-..-..-..-..-.._..-..-..-. .- ..- ..- .._.._.._.._..- .. -.. -.. _.. _.. _.. _.. _.._ 13 -3/0" Csg 3600 -.._.._..:: �::_::_::_:::::_::_::_::_: _.._..:.._. -:; :. • .::::::_:: Z.: _::_::_::_::_::_::_::_::;::_::_::_::_:: _::_::_..= :: ::_::_::_::_::_ °�� 3600 0 0 N _ 5 4800 4800 ii d 0 CO 0 6000 4 6000 Drp 2 /100 ..... - - _.._.._.._.. _.._.._.. _.._ ._.._.. . . -. ._.. _.. _.._.. .._,.-•TO RRZ„ - _„_„ /.._.._.. ..- ..- ..�.._.._.._.._.._.. gd /" Csg OP W W02 Kup Tgt Kuparuk Drp 4/100 TO OP23- VVWO2PE 1 (P1) 7200 7200 End Drp 8400 8400 i. by Sh _.. .._.,t.._..- .._.._.._.._.. -.._. _.._.._.._..------- -.- -._ ._..... .- ..- .._.._.._.._.. .._..- .._.._.._.._.._.._.. ..- .._.._.._.._.._.._.._..f.._.._ ._.. -.._.. _. op Ivishak 9600 - _.._.._. - - ..- .._.._.._.._.._.._.._ ._.._.._.._.._.._.._.._..r ._.._..-..-.._.._.._.._..-.._.. _.._.._.._.._.._.._..- ..- ..-.._ _. r < c siik3-03 9600 -.._.._.._....-.._.._.._.._. .- .._.._.j_.._.._.._.._.._.._.. _.._ .-.._.._.._.._.._..-..-.. K.._.._. ._.. ..- ..- ..- .._..y.._.._.._.. _.._.. _.. _.. _.. j..._.._.. _.. .. _.. _. chooka OP23 -VVWO2 (P5) 0 1200 2400 3600 4800 6000 Vertical Section (ft) Azim = 5 °, Scale = 1(in):1200(ft) Origin = 0 N / -S, 0 E / -V • • E Petroleum Schlumberger Bli WELL FIELD STRUCTURE OP23- WW02PB1 / WW -02 (P1 -5) Nikaitchuq I Oliktok Point Magnetic Parameters Surface Location NR027 Alaska Slate Planes. Zone 06 US Feet I Miscellaneous Model: BGGM 2009 Dip': 80.951 Date: February 14. 2010 Let N703039.100 Northing. 6036483.06 S Grid Con, 10.1276757T Slot 0P23 ND Re! Rotary Table (6320 R above MSL) Mag Dec: •21626° FS: 576636 nT Len: W149 51 51 668 Eastig'. 51657684 SUS Scale Fact: 09999003121 Ran. OP23- WW02 Srvy Dale: February 102010 -1600 -800 0 800 1600 2400 ENI Lease Line (616) 2 0P23 -W 102 (P5) 6400 TA 6400 GP23- WWp2PB1 (P1) TD End brp 5600 •••OPJMW02•KapTgf 5600 • .�. Drip 2/100 851$" Cep Dry 41100 4800 4800 A 4000 4000 A A Z F 0 o 0 c_ 3200 3200 0 U) V V V 2400 2400 5NI Lease Line (616) 2 ENI Lease Line 5615) 1 133/8' Ca • •P 1600 1600 800 End Cry 800 • 0 Cry 2.75/100 \ • 0 K� ®mom • • -1600 -800 0 800 1600 2400 «< W Scale = 1(in):800(ft) E >» • • ANTICOLLISION SUMMARY REPORT Client: ENI Slot: OP23 Field: Nikaitchuq Well: OP23 -WW02 Structure: Oliktok Point Borehole: OP23 -WW02 Subject Trajectory: OP23 -WW02 (P5) (DEF PLN) Rpt Date: February 10, 2010 Analysis Method: Normal Plane Depth Interval: Every 5.00ft MD EOU Type: Oriented EOU used. Min Pts: All local minima indicated. ProbColMax: 1:25959 Mag Model: BGGM 2009 Offset Trajectory Sep. Allow Sep. Subject Trajectory Separation Factor Alert Status Ct -Ct (ft) Dev. (ft) Fact. MD (ft) I TVD (ft) i Alert I Minor I Major Nikaitchuq 1 (DEF SW PASS 11 18621.57 10391.79 452.19 452.19 MinPt -CtCt 18626.7811 18621.541 10220.31 462.19 462.19 MinPt -O -ADP II 18632.8611 18624.091 4457.36 1009.86 1009.84 MinPts 14234.10 14179.581 410.3211 9605.84 7089.81 MinPt -O -SF 1 14230.331 14175.821 410.37 9616.18 7099.26 MinPts 14264.88 14210.301 410.771 9654.11 7134.18 MinPt -O -SF 14493.40 14438.431 414.271 9718.04 7193.87 MinPt -O -SF 15090.57 15035.831 433.251 9880.60 7349.52 MinPt -O -SF 15252.88 15197.631 433.601 10217.36 7674.80 MinPt -O -SF 16168.92 16106.721 406.151 12369.07 9753.20 MinPt -O -SF Nikaitchuq 2 (DEF SW PASS � 19171.63i1 19166.27 10047.01 433.25 433.25 MinPt -CtCt 19172.1311 19165.8011 7496.28 593.25 593.25 MinPt -O -ADP 1 19174.941 19166.07 4515.75 1007.38 1007.37 MinPt -CtCt 19174.951 19166.061 4496.48 1009.70 1009.68 MinPt -O -ADP 15541.76 15455.32 277.67 9605.87 7089.84 MinPts 15558.66 15472.03 277.361 9633.74 7115.38 MinPt -O -SF 15631.12 15544.23 277.791 9676.98 7155.41 MinPt -O -SF 15783.62 15696.10 278.431 9740.50 7215.07 MinPt -O -SF 15979.30 15891.55 281.111 9811.09 7282.43 MinPt -O -SF 16495.54 16407.53 289.331 11396.18 8813.46 MinPt -O -SF 16647.23 16558.39 289.181 11836.51 9238.79 MinPt -O -SF 16813.79 16723.52 287.281 12369.07 9753.20 MinPt -O-SF Nikaitchuq 3 (DEF SW PASS i 18560.6311 18558.09 770803.92 51.80 51.80 MinPt -CtCt 18561.381 18557.141 16007.92 246.80 246.80 MinPt -O -ADP 18565.19 18558.961 7464.46 611.77 611.77 MinPt -O -ADP 11 18567.5211 18558.95 4586.28 959.32 959.32 MinPt -CtCt 18567.5211 18558.9511 4583.90 960.85 960.85 MinPt -O -ADP 18574.12 18564.951 4179.221 1038.54 1038.50 MinPt -O -SF 13392.73 13340.191 401.401 9763.38 7236.79 MinPt -O -SF 13281.71 13229.591 401.371 9798.23 7270.09 MinPt -O -SF 1 12476.811 12423.031 364.911 12369.07 9753.20 MinPts Nikaitchuq 3PB1 (DEF SW) PASS II 18560.6311 18558.09 770803.92 51.80 51.80 MinPt -CtCt 18561.381 18557.141 16007.92 246.80 246.80 MinPt -O -ADP 18565.19 18558.961 7464.46 611.77 611.77 MinPt -O -ADP II 18567.5211 18558.95 4586.28 959.32 959.32 MinPt -CtCt 18567.5211 18558.9511 4583.90 960.85 960.85 MinPt -O -ADP 18574.12 18564.951 4179221 1038.54 1038.50 MinPt -O -SF 1 13392.73 13340.191 401.401 9763.38 7236.79 MinPt -O -SF 13281.71 13229.591 401.371 9798.23 7270.09 MinPt-O-SF I 12476.811 12423.031 364.911 12369.07 9753.20 MinPts Nikaitchuq 3PB2 (DEF SW) PASS 1 18560.6311 18558.09 770803.92 51.80 51.80 MinPt -CtCt 18561.381 18557.141 16007.92 246.80 246.80 MinPt -O -ADP 18565.191 18558.961 7464.46 611.77 611.77 MinPt -O -ADP II 18567.5211 18558.95 4586.28 959.32 959.32 MinPt -CtCt 18567.5211 18558.9511 4583.90 960.85 960.85 MinPt -O -ADP 18574.12 18564.951 4179.221 1038.54 1038.50 MinPt -O -SF 13392.73 13340.191 401.401 9763.38 7236.79 MinPt-O-SF 13281.71 13229.591 401.371 9798.23 7270.09 MinPt-O-SF 1 12476.811 12423.031 364.911 12369.07 9753.20 MinPts Nikaitchuq 3PB3 (DEF SW) PASS 11 18560.63i1 18558.09 770803.92 51.80 51.80 MinPt -CtCt 18561.3811 18557.1411 16007.92 246.80 246.80 MinPt -O -ADP Version DO 4.0 (doc40x_100 ) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 2/10/2010 12:37 PM Page 1 of 6 0 18565.191 18558.9611 7464.46 611.77 611.77 MinPt -O -ADP 1118567.521118558.95 4586.28 959.32 959.32 MinPt -CtCt 18567.5211 18558.9511 4583.90 960.85 960.85 MinPt -O -ADP 18574.12 18564.951 4179.221 1038.54 1038.50 MinPt -O -SF 13392.73 13340.191 401.401 9763.38 7236.79 MinPt -O -SF 13281.71 13229.591 401.371 9798.23 7270.09 MinPt -O -SF I 12476.811 12423.031 364.911 12369.07 9753.20 MinPts Nikaitchuq 4 (DEF SW) PASS 18601.68 18599.17 N/A 21.94 21.94 Surface 11 18601.6811 18599.14 761802.97 51.94 51.94 MinPt -CtCt 18602.091 18598.841 37280.37 151.93 151.93 MinPt -O -ADP 18607.481 18601.051 7109.01 656.67 656.67 MinPt -O -ADP 1 18609.1511 18600.75 4732.25 952.07 952.07 MinPt -CtCt 18609.161 18600.741 4719.31 955.16 955.16 MinPt -O -ADP 13479.07 13425.581 396.4311 9746.20 7220.47 MinPt-O-SF 1 13388.091 13335.38 9804.23 7275.84 MinPts 15922.15 15842.79 310.671 10883.52 8318.26 MinPt -O -SF Nikaitchuq 4PB1 (DEF SW) PASS 18601.68 18599.17 N/A 21.94 21.94 Surface 1 18601.68i1 18599.14 761802.97 51.94 51.94 MinPt -CtCt 18602.091 18598.841 37280.45 151.93 151.93 MinPt -O -ADP 18607.481 18601.051 7109.01 656.67 656.67 MinPt -O -ADP 11 18609.1511 18600.75 4732.25 952.07 952.07 MinPt -CtCt 18609.1611 18600.7411 4719.31 955.16 955.16 MinPt -O -ADP 13447.79 13394.391 396.241 9755.36 7229.16 MinPt -O -SF 13325.37 13272.431 396.191 9794.86 7266.86 MinPt -O -SF 13291.09 13238.28 =EINE 9806.60 7278.12 MinPt -O -SF 13104.261 13021.031 243.441 10242.11 7698.71 MinPts Kigun 1 (DEF SW) PASS IffEIRIM1 17124.68 36070.01 163.17 163.17 MinPt -CtCt 17127.971 17124.6011 29555.29 188.17 188.17 MinPt -O -ADP 17181.59 17172.10 3683.651 915.08 915.08 MinPt -O -SF 1 17142.26 17133.361 4019.21 1025.45 1025.43 MinPts 1 14346.211 14252.29 235.33 9396.23 6905.55 MinPt -CtCt 14346.2211 14252.2811 235.28 9397.23 6906.39 MinPt -O -ADP 1 13336.701 13235.80 203.27 1 12369.07 9753.20 MinPts 13336.70 13235.80 203.27 12369.07 9753.20 TD Kigun 1 PB1 (DEF SW) PASS 17127.94 17125.43 N/A 18.17 18.17 Surface 1 1 17127.8911 17124.68 36070.01 163.17 163.17 MinPt -CtCt 17127.9711 17124.6011 29555.29 188.17 188.17 MinPt -O -ADP 17181.59 17172.1011 3683.6511 915.08 915.08 MinPt -O -SF 1 17142.2611 17133.3611 4019.21 1025.45 1025.43 MinPts 14346.2111 14252.29 235.33 9396.23 6905.55 MinPt -CtCt 14346.22 14252.281 235.28 9397.23 6906.39 MinPt -O -ADP 14285.451 14158.12 171. 9505.55 6999.84 MinPts Tuvaaq ST 1 (DEF SW) PASS 17127.8 17124.68 36070.02 163.17 163.17 MinPt-CtCt 17127.9, 29555.30 188.17 188.17 MinPt -O -ADP 17181.59 17172.1011 3683.6511 915.08 915.08 MinPI-O-SF 1 17142.2611 17133.3611 4019.21 1025.45 1025.43 MinPts 14346.21 14252.27 235.29 9396.25 6905.57 MinPt -CtCt 14346.22 14252.25 235.23 9397.23 6906.39 MinPt -0-ADP 14645.66 14547.971 230.751 9522.03 7014.41 MinPt -O-SF 23173.94 23010.41 215.84 12369.07 9753.20 MinPt -O -SF Oliktok Point I -1 (DEF SW) PASS 208.54 206.04 44407.65 0.20 0.20 Surface 208.54 206.04 44407.65 40.20 40.20 MinPt -CtCt 208.87 205.82 556.89 120.20 120.20 MinPt -O -ADP 362.73 350.81 57.361 1040.69 1040.65 MinPt -O -SF 1258.28 1232.60 81.271 2114.79 2058.33 MinPt -0-SF 1596.40 1564.90 82.441 2420.19 2308.36 MinPt -O -SF 1908.72 1871.46 82.251 2665.29 2489.29 MinPt -O -SF 5470.62 5374.90 87.991 4600.18 3748.83 MinPt-O-SF 5857.49 5755.57 88.341 5039.28 4033.87 MinPt -O -SF 6165.3811 6015.451 62.701 6084.81 4712.57 MinPts Oliktok Point I -1A -106 (P3) (DEF PLN) PASS 208.54 206.04 44407.65 0.20 0.20 Surface 208.54 206.04 44407.65 40.20 40.20 MinPt -CtCt 208.87 205.82 556.89 120.20 120.20 MinPt -0-ADP 362.73 350.801 57.351 1040.69 1040.65 MinPt -O -SF 1262.22 1236.471 81.261 2118.66 2061.64 MinPt -O -SF 1629.01 1596.791 82.101 2449.16 2330.72 MinPt -O -SF 5842.32 5745.18 92.551 4600.75 3749.20 MinPt -O -SF Version DO 4.0 ( doc40x_100 ) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 2/10/2010 12:37 PM Page 2 of 6 0 1 6178.22 6069.62 87.31 5830.56 4547.53 MinPt -CtCt 6178.6611 6069.261 86.67 5926.25 4609.64 MinPt -O -ADP 6340.70 6198.491 68.051 7490.28 5624.93 MinPt -O-SF 6388.16 6241.141 66.281 7723.15 5776.09 MinPt -O -SF 6500.92 6341.641 62.181 8204.22 6088.38 MinPt -O -SF 6875.79 6688.441 55.771 9089.88 6666.89 MinPt -O -SF 7317.49 7115.931 55.121 9289.27 6817.63 MinPt -O -SF 8709.84 8483.61 58.38 9561.37 7049.53 TD Oliktok Point 1 -2 (DEF SW) PASS II 200.511 198.00 42675.41 39.55 39.55 MinPt -CtCt / 178.11 168.66 37.86 840.10 840.10 MinPt -CtCt 178.26 168.52 36.42 861.95 861.95 MinPt -O -ADP 217.05 202.55 26.811 1194.60 1194.00 MinPt -O -SF 1187.23 1155.401 60.591 2561.95 2415.34 MinPt -O -SF 1468.05 1428.971 60.111 2811.32 2587.60 MinPt -O -SF 2803.14 2728.851 58.521 3856.95 3266.37 MinPt-O-SF 2880.52 2804.241 58.521 3911.66 3301.88 MinPt -O -SF 3481.84 3389.491 58.091 4357.06 3591.01 MinPt -O -SF 9057.97 8875.621 75.521 7953.24 5925.46 MinPt -O -SF OP03 -P05 (DEF SW) PASS 191.96 189.45 40832.52 0.00 0.00 Surface 191.91 189.31 2868.03 66.80 66.80 MinPt -CtCt 1 192.011 188.27 229.52 245.34 245.34 MinPt -CtCt 192.25 188.06 168.15 315.00 315.00 MinPt -O -ADP 286.85 276.14 r 51.91 1112.21 1112.03 MinPt -O -SF 321.88 310.111 51.671 1236.76 1235.81 MinPt-O-SF 347.82 335.341 51.901 1314.67 1312.73 MinPt -O -SF 643.57 622.871 52.831 2052.97 2004.83 MinPt -O -SF 2487.82 2404.821 46.311 4600.30 3748.90 MinPt -O -SF 11 2506.3111 2418.64 44.10 5179.57 4124.94 MinPt -CtCt 2506.331 2418.611 44.07 5190.14 4131.80 MinPt -O -ADP 2509.77 2421.54 43.87 5281.56 4191.14 MinPt -O -SF 2583.35 2493.931 44.541 5853.79 4562.61 MinPt -O -SF 2587.41 2497.851 44.541 5884.78 4582.72 MinPt -O -SF 2867.40 2772.521 46.521 6831.95 5197.57 MinPt -O -SF 5005.38 4869.911 56.441 9265.33 6798.60 MinPt -O -SF OP03- P05PB1 (DEF SW) PASS 191.96 189.45 40832.52 0.00 0.00 Surface 191.91 189.31 2868.03 66.80 66.80 MinPt -CtCt 1 192.011 188.27 229.52 245.34 245.34 MinPt -CtCt 192.25 188.06 168.15 315.00 315.00 MinPt -O -ADP 286.85 276.141 51.911 1112.21 1112.03 MinPt -O -SF 321.88 310.111 51.661 1236.76 1235.81 MinPt -O -SF 347.82 335.341 51.901 1314.67 1312.73 MinPt -O -SF 643.57 622.871 52.831 2052.97 2004.83 MinPt -O -SF 2487.07 2403.861 46.171 4600.25 3748.88 MinPt -O -SF 2553.9711 2330.51) 17.321 5308.65 4208.73 MinPts OP03- P05PB2 (DEF SW) PASS 191.96 189.45 40832.52 0.00 0.00 Surface 191.91 189.31 2868.03 66.80 66.80 MinPt -CtCt 1 192.011 188.27 229.52 245.34 245.34 MinPt -CtCt 192.25 188.06 168.15 315.00 315.00 MinPt -O -ADP 286.85 276.141 51.911 1112.21 1112.03 MinPt -O -SF 321.88 310.111 51.671 1236.76 1235.81 MinPt -O -SF 347.82 335.341 51.901 1314.67 1312.73 MinPt -O -SF 643.57 622.871 52.831 2052.97 2004.83 MinPt -O -SF 2487.82 2404.821 46.311 4600.30 3748.90 MinPt -O -SF 11 2506.3111 2418.64 44.10 5179.57 4124.94 MinPt -CtCt 2506.3311 2418.61i1 44.07 5190.14 4131.80 MinPt -O -ADP 2509.77 2421.541 43.871 5281.56 4191.14 MinPt -O -SF 2583.35 2493.931 44.541 5853.79 4562.61 MinPt -O -SF 2587.41 2497.851 44.541 5884.78 4582.72 MinPt -O -SF 2867.40 2772.52 1 46.521 6831.95 5197.57 MinPt -O -SF 3709.631 3558.64 37.451 8375.69 6199.69 MinPts OPO4-P07 (P7) (DEF PLN) PASS 183.99 181.48 39115.59 0.00 0.00 Surface 183.99 179.30 124.59 300.00 300.00 MinPt -CtCt 184.38 178.93 92.48 379.99 379.99 MinPt -O -ADP 239.30 227.59 38.551 890.10 890.10 MinPt -O -SF 1397.19 1345.861 42.841 4528.38 3702.22 MinPt -O -SF 2461.94 2378.351 45.491 7350.01 5533.87 MinPt -O -SF 2490.72 2406.221 45.521 7413.72 5575.23 MinPt -O -SF 2831.94 2738.091 46.461 8022.62 5970.49 MinPt -O -SF 5782.87 5681.70 87.87 9417.72 6923.75 TD Version DO 4.0 ( doc40x_100 ) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 2/10/2010 12:37 PM Page 3 of 6 • • OP05-P06 (P3) (DEF PLN) PASS 176.04 173.54 37403.12 1.00 1.00 Surface 176.04 170.73 92.48 351.00 351.00 MinPt -CtCt 176.21 170.60 83.84 391.00 391.00 MinPt -O -ADP 278.47 265.88 41.011 1051.32 1051.26 MinPt -0-SF 1405.65 1377.811 83.061 2238.50 2162.60 MinPt -O -SF 4744.18 4647.901 75.841 4601.26 3749.53 MinPt-O-SF 11 4988.6211 4883.67 73.00 5566.97 4376.41 MinPt -CtCt 4988.6411 4883.6511 72.98 5583.81 4387.35 MinPt -O -ADP 5148.93 5021.411 61.751 7082.84 5360.44 MinPt -O -SF 5259.59 5122.181 58.451 7540.38 5657.45 MinPt -O -SF 5746.07 5573.841 50.761 8971.71 6586.59 MinPt -O -SF 5754.02 5581.561 50.761 8978.36 6590.92 MinPt-O-SF 7803.02 7604.51 59.69 9520.31 7012.88 TD OP06 -105 (P3) (DEF PLN) PASS 168.00 165.49 35668.58 1.00 1.00 Surface 168.00 162.68 88.19 351.00 351.00 MinPt -CtCt 168.33 162.34 71.33 421.00 421.00 MinPt -0-ADP 239.55 225.92 31.961 1062.26 1062.19 MinPt -O -SF 252.85 238.621 32.001 1113.04 1112.86 MinPt -O -SF 1137.21 1102.481 52.811 2639.64 2471.27 MinPt -O -SF 1256.47 1218.591 53.171 2804.31 2583.04 MinPt -O -SF 3036.60 2948.441 53.131 4530.88 3703.84 MinPt -O -SF 3792.73 3687.481 55.331 5955.39 4628.56 MinPt -O -SF 4129.14 4010.071 53.101 7381.84 5554.53 MinPt -O -SF 4816.63 4670.311 50.211 8953.36 6574.68 MinPt -O -SF 6501.87 6346.28 63.68 9436.06 6939.41 TD OP07 -104 (P1) (DEF PLN) PASS 152.00 149.49 32221.09 1.00 1.00 Surface 152.00 146.36 71.38 401.00 401.00 MinPt -CtCt 152.19 146.181 63.91 441.00 441.00 MinPt -O -ADP 216.02 203.871 33.171 991.79 991.79 MinPt -O -SF 234.58 221.481 32.841 1066.37 1066.30 MinPt -O -SF 253.78 239.791 32.811 1135.80 1135.53 MinPt -O -SF 276.32 261.351 32.931 1209.77 1209.06 MinPt -O -SF 244.77 1164.51 23.96 4527.83 3701.86 MinPt -CtCt 1245.25 1163.65 23.57 4602.15 3750.11 MinPt -O -ADP 1266.37 1181.79 23.1 4962.42 3983.97 MinPt-O-SF 5112.08 5015.94 81.85 9322.48 6844.44 TD OP08-PO4 (P1) (DEF PLN) PASS 143.80 141.29 30454.21 1.00 1.00 Surface U 143.8011 139.11 96.79 301.00 301.00 MinPt -CtCt 144.1811 138.7311 71.92 380.99 380.99 MinPt -O -ADP 241.86 225.4911 25.90i1 1206.20 1205.52 MinPt-O-SF 94.97 64.58 4.97 3660.19 3138.64 5.00 Enter Alert 84.24 51.48 4.05 3821.37 3243.26 MinPt -CtCt 84.66 51.08 3.96 3853.67 3264.24 MinPt -O -ADP 87.92 52.53 3.90 3918.35 3306.22 MinPt -O -SF 131.04 89.95 5.00 4179.25 3475.58 5.00 Exit Alert 527.90 480.4411 17.5311 5007.74 4013.39 MinPt-O-SF 4652.63 4532.99 59.55 8573.34 6327.99 TD OP09-S03 (P1) (DEF PLN) PASS 136.00 133.49 28771.94 1.00 1.00 Surface 136.00 131.30 91.35 301.00 301.00 MinPt -CtCt 136.41 130.86 65.90 390.99 390.99 MinPt -O -ADP 186.39 176.58 37.771 876.89 876.89 MinPt -0-SF 192.46 182.421 37.781 900.56 900.56 MinPt -O -SF 1170.20 1132.701 50.041 3489.38 3027.76 MinPt-O-SF 1697.64 1647.72 1 53.631 4528.70 3702.43 MinPt-O-SF 4054.30 3938.431 53.611 8951.60 6573.54 MinPt -O -SF 4458.59 4338.761 56.971 9090.70 6667.47 MinPt -O -SF 13447.17 13239.95 98.51 9557.37 7045.94 TD OP1O-P09 (P1) (DEF PLN) PASS 128.01 125.50 27049.83 1.00 1.00 Surface 128.01 123.79 109.86 251.00 251.00 MinPt -CtCt 128.64 122.90 58.55 415.92 415.92 MinPt -O -ADP 190.00 175.861 24.161 973.39 973.38 MinPt -O -SF 199.69 184.951 24.161 1007.58 1007.57 MinPt -O -SF 936.11 908.051 54.791 2807.27 2584.97 MinPt -O -SF 1523.74 1478.081 52.881 3701.42 3165.40 MinPt -O -SF 2081.97 2022.611 54.851 4529.64 3703.04 MinPt -O -SF 4442.81 4325.411 57.971 7986.45 5947.01 MinPt -O -SF 5439.08 5291.61 1 56.251 8829.57 6494.32 MinPt-O-SF 5695.95 5542.22 1 56.471 8923.79 6555.48 MinPt -O -SF Version DO 4.0 ( doc40x_100 ) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 2/10/2010 12:37 PM Page 4 of 6 • • 14364.68 14157.79 105.40 9344.51 6862.48 TD OP11 -101 (P1) (DEF PLN) PASS 120.01 117.50 25325.58 1.00 1.00 Surface 118.13 109.14 26.71 758.19 758.19 MinPt -CtCt 118.57 108.68 23.54 829.39 829.39 MinPt -O -ADP 161.90 144.06 15.591 1306.40 1304.59 MinPt-O-SF 512.29 485.601 31.611 2575.63 2425.34 MinPt -O -SF 1307.79 1228.481 25.491 4493.66 3679.68 MinPt -O -SF 1320.01 1239.98 25.491 4521.00 3697.43 MinPt -O -SF 5305.01 5176.37 63.06 7950.08 5923.40 TD OP12 -P01 (P1) (DEF PLN) PASS 112.00 109.50 23600.56 1.00 1.00 Surface 103.75 94.12 21.30 776.02 776.02 MinPt -CtCt 104.12 93.77 19.43 817.49 817.49 MinPt -O -ADP 128.98 114.05 15.261 1058.67 1058.61 MinPI-O-SF 848.08 815.551 42.241 2629.43 2464.03 MinPt -O -SF 989.21 951.461 41.991 2859.24 2618.70 MinPt -O -SF 2027.66 1947.451 39.091 4256.20 3525.54 MinPt -O -SF 8234.17 8066.15 74.60 8634.60 6367.76 TD OP13 -103 (P1) (DEF PLN) PASS 88.02 85.51 18432.09 1.00 1.00 Surface 76.13 65.45 13.50 903.53 903.53 MinPt -CtCt 76.44 65.13 12.60 938.14 938.14 MinPt -O -ADP 90.02 75.47 10.901 1118.24 1118.04 MinPt -O -SF 3704.83 3621.56 68.761 4529.17 3702.73 MinPt-O-SF 9058.22 8873.491 74.541 8337.08 6174.62 MinPt -O -SF 10143.51 9942.701 76.711 8748.70 6441.82 MinPt -O -SF 14874.50 14657.08 103.80 9163.59 6720.49 TD OP14 -108 (P1) (DEF PLN) PASS 80.03 77.52 16709.22 1.00 1.00 Surface 69.93 59.61 12.94 875.30 875.30 MinPt -CtCt 70.35 59.32 11.94 918.26 918.26 MinPt -O -ADP 80.61 66.70 10.261 1082.82 1082.72 MinPt-O-SF 82.91 68.671 10.281 1102.88 1102.73 MinPt -O -SF 5504.92 5410.181 89.481 4529.84 3703.17 MinPt -O -SF 8896.79 8757.751 97.711 6151.61 4755.93 MinPt -O -SF 9777.23 9626.901 99.181 6465.85 4959.92 MinPt -O -SF 14829.92 14649.31 124.87 8045.93 5985.62 TD OP15 -P08 (P2) (DEF PLN) PASS 71.98 69.48 14975.45 1.00 1.00 Surface 58.90 49.38 12.06 770.63 770.63 MinPt -CtCt 59.03 49.22 11.60 787.51 787.51 MinPt -O -ADP 65.49 53.85 10.341 879.24 879.24 MinPt-O-SF 6284.65 6184.201 96.201 4529.94 3703.23 MinPt -O -SF 9007.74 8875.971 104.491 5624.91 4414.03 MinPt -O -SF 16035.15 15855.291 135.591 7914.18 5900.10 MinPt -O -SF OP16-P03 (P2) (DEF PLN) PASS 64.00 61.49 13254.11 1.00 1.00 Surface 47.48 37.90 9.54 785.60 785.60 MinPt -CtCt 47.68 37.71 9.07 807.89 807.89 MinPt -O -ADP 51.66 40.37 8.391 881.16 881.16 MinPt-O-SF 6642.22 6537.831 97.751 4530.25 3703.43 MinPt -O -SF 7623.29 7509.661 102.861 4834.98 3901.25 MinPt -O -SF 14535.44 14394.05 156.96 6174.79 4770.98 TD OP17-P02 (P3) (DEF PLN) PASS 56.01 53.50 11532.90 0.00 0.00 Surface 35.92 26.39 7.13 790.64 790.64 MinPt -CtCt 36.06 26.22 6.86 807.05 807.05 MinPt -O -ADP 38.29 27.55 6.521 856.02 856.02 MinPt -O -SF 5881.64 5777.061 86.391 4600.07 3748.76 MinPt-O-SF 9984.31 9828.161 97.451 7351.84 5535.06 MinPt -O -SF 14516.62 14318.21 111.13 8603.10 6347.31 TD OP18 -107 (P2) (DEF PLN) PASS 48.00 45.50 9806.99 1.00 1.00 Surface 28.84 20.53 6.81 647.82 647.82 MinPt -CtCt 28.93 20.42 6.60 657.94 657.94 MinPt -O -ADP 30.34 21.27 6.361 687.09 687.09 MinPt -O -SF 2592.19 2555.971 115.211 2461.64 2340.28 MinPt -O -SF 7609.24 7517.601 127.991 4079.96 3411.13 MinPt -O -SF I1 8580.7411 8482.1611 133.921 4179.06 3475.46 MinPts 12062.46 11949.6911 164.051 4529.55 3702.98 MinPt -O -SF 13150.88 13031.56 168.83 4959.57 3982.13 TD OP19 -ENI #1 (P1) (PLAN) PASS 31.99 29.48 6355.81 1.20 1.20 Surface Version DO 4.0 (doc40x_100 ) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 2/10/2010 12:37 PM Page 5 of 6 • 31.99 26.20 13.44 401.20 401.20 MinPt -CtCt 32.12 26.08 12.55 436.20 436.20 MinPt -O -ADP 36.13 29.00 10.901 591.11 591.11 MinPt -O -SF 37.44 30.13 10.891 616.06 616.06 MinPt -O -SF 820.43 789.09 42.551 2658.28 2484.39 MinPt -O -SF 839.28 807.28 42.551 2691.14 2507.23 MinPt -O -SF 882.34 848.80 42.521 2763.72 2556.37 MinPt -O -SF 2024.33 1946.31 40.161 4527.65 3701.75 MinPt -O -SF 3641.55 3512.96 43.291 6906.68 5246.08 MinPt -O -SF 4595.16 4431.93 ff;i! 9818.83 7289.88 MinPt -O -SF 4751.79 4582.14 10544.08 7990.40 MinPt -O -SF OP20 -ENI #9 (P1) (PLAN) PASS 23.96 21.46 4625.84 1.20 1.20 Surface 23.96 18.17 9.78 401.20 401.20 MinPt -CtCt 24.10 18.03 9.08 446.20 446.20 MinPt -O -ADP 25.72 19.05 8.361 551.16 551.16 MinPt -O -SF 3961.85 3878.361 73.331 4530.33 3703.49 MinPt -O -SF 6338.11 6213.491 77.821 6311.37 4859.64 MinPt -O -SF OP21 -ENI #10 (P1) (PLAN) PASS 16.01 13.51 2912.36 1.00 1.00 Surface 16.01 11.17 8.66 301.00 301.00 MinPt -CtCt 16.11 10.75 7.13 400.99 400.99 MinPt -O -ADP 17.80 11.89 6.731 535.85 535.85 MinPt -O -SF 37.04 27.811 7.701 1009.16 1009.15 MinPt -O -SF 3056.03 2997.35 81.531 4413.28 3627.51 MinPt -O -SF 5202.65 5111.97 88.461 6193.37 4783.04 MinPt -O -SF OP22- ENI #1 (P2) (DEF PLN) PASS 8.03 5.52 1192.04 0.00 0.00 Surface 8.03 3.87 4.99 245.00 245.00 5.00 Enter Alert mug 2.39 2.64 400.00 400.00 MinPt -CtCt 8.16 ■ 2.51 435.00 435.00 MinPt -O -ADP 8.35 2.3∎ MERIT 455.00 455.00 MinPt -O -SF 19.55 11.89 4.96 689.62 689.62 5.00 Exit Alert 848.03 815.341 42.021 2721.25 2527.84 MinPt -O -SF 2023.03 1944.761 40.001 4528.87 3702.54 MinPt -O -SF 3642.24 3513.06 43.101 6907.96 5246.91 MinPt -O -SF 4592.83 4428.671 42.591 9830.75 7301.37 MinPt -O -SF 4753.66 4582.98 42.381 10544.17 7990.48 MinPt -O -SF OP24 -ENI #4 (P2) (DEF PLN) PASS 7.91 5.40 1165.82 0.00 0.00 Surface 7.91 3.75 4.89 245.00 245.00 5.00 Enter Alert 7.91 2.27 2.59 400.00 400.00 MinPt -CtCt 8.08 2.0 2.37 450.00 450.00 MinPt -O -ADP 8.30 2.10 2.35' 475.00 475.00 MinPt -O -SF 23.69 14.81 4.98 749.30 749.30 5.00 Exit Alert 2671.77 2577.281 43.521 4531.12 3704.00 MinPt -O -SF 4806.59 4644.481 45.151 6756.52 5148.61 MinPt -O -SF 6060.60 5845.231 42.691 9836.16 7306.59 MinPt -O -SF 6334.61 6114.15 43.58 10349.16 7802.11 TD OP25-DSPO1 (P1) (DEF PLN) PASS 250.42 247.91 53432.99 1.00 1.00 Surface 250.42 240.03 47.13 896.00 896.00 MinPt -CtCt 250.66 239.77 44.36 948.66 948.66 MinPt -O -ADP 301.48 285.75 33.901 1437.42 1432.86 MinPt -O -SF 3532.94 3465.571 81.631 4530.61 3703.67 MinPt-O-SF 3561.08 3493.23 81.68 4554.63 3719.26 TD OP26 -DSPO2 (DEF SW) PASS (I 237.8411 235.3411 50722.7011 0.00 0.00 MinPts 110.03 94.64 12.52 1494.03 1487.74 MinPt -CtCt 110.04 94.631 12.501 1500.64 1494.12 MinPts 114.99 99.171 12.661 1673.10 1658.88 MinPt -O-SE 125.94 108.461 12.361 1817.69 1793.69 MinPt-O-SE 326.19 294.05 M 2849.86 2612.61 MinPt-O-SE 689.78 618.57 1 15.001 4530.51 3703.60 MinPt -O -SF 1103.32 998.78 16.181 6977.15 5291.83 MinPt -O -SF 1500.96 1377.10 18.521 7872.25 5872.88 MinPt-O-SE Version DO 4.0 ( doc40x_100 ) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 2/10/2010 12:37 PM Page 6 of 6 0 • S chlurnberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OP23 -WW02 Oriented EOU Dimension Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anticollision rule used: Minor Risk - Se , aration Factor ` Date: February 14, 2010 ■ North 350 0 10 340 I • VVI �.y•�� 20 riiiii-,.._ pi. �0�B 1�" 330 .►1 , ,Pr- :►. 1 lb* 30 320 . r,.,,., ∎ 40 44.,..*- ), 310 OP17 , � ■ � 4,� ` 50 40 �� r ` ® ® �� P15 -P08 (P2) 300 O• •\���� 0 11J111141ktkil ' I '4" 4101&- • .1 - ''-'� 41 60 O � 4 -E ` � -.- -.; , �: r , � X11 NI # / �� , �� 4 . ��Ia, r sa 290 °� '' • f 70 280 . /* '`, ‘ 1 1 / r' ''''; 44 0 11 170 A . 10 � ••4�. _�� , ENI #1 (P1) 270 , 4&,4•konA% Rua. p ��<<< �.�� � ` 0���, �, , , ', .' � •P22 -ENI #1 (P2) 260 1111110 o , , �� � 100 �" offWei � � �O ENI #9 (P1) 10, 250 Npaajp\ 110 ,..„21 240 * .4 4 4 hhm uV ` , � � 120 230 al N )! 130 'kir 4 � 220 .' \ X21- ENI #10 (P1) 210 150 200 160 ion . __ i 7 Well Ticks Type: MD on OP23 -W W 02 (P5) Calculation Method: Normal Plane Ring Interval: 10.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH = 20.00 ft • 411 S chlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: Oriented EOU Dimension N Field Nikaitchuq Structure: Oliktok Point NoGo Region Anticollision rule used: Minor Risk - Se . aration Factor f ■ Date: February 14, 2010 North 350 0 10 340 r' � . �i p�: 1 � i� 330 / te ,. P,A ( ,� irelp 30 v 6 • (P1) 320 i �kA - � �� 10 4 g9 (P lor •310 to1074.14.4-44vroi:0,11, ` � * , ! ( i t 's ,j� "".�I� , 1 I � � � �� 4 0P08 -PO4 (P1) 300. V/• �l�l ggi'il L ��` .I • ` .� . '4"?'' 60 o• �. ,!._ \ 11• , ` �� Rf ��s )7 ;' N.P07- 104(P1) vb. 290 , � � .A ` � lint � =� �` �� / 1 � 1t,' �� w. Ai 70 280 "'kW 414rtr4 r. -��s� ,r vorip, T - -•ay _ _ .: 80 270 �r 1 . = . n ��i' � =ate 90 NI. ■d II Q Ay •7 „ �4`` - � ,; r te • •, y \ •P19-ENI #1 (P1) ^o s , 4 .40, . � � -I -� • P22 -ENI #1 (P2) �' 260 ` o ° z ` ,,,' 1 ` �..�' � 100 r .. 11.- 1 10 4 °o t� ` rr�► *Li& o 0 ■ 250 o 1z� `"� �� � / / /// °o o ,�� (0P20-EN I #9 (P1) o a v . /1♦ � J o w c<.0.; li) 4 4' 240 � Wa ammo � . �, ° 0) 120 �' ®' �" moo: + � �j , ♦' � Air e r r 130 230 1♦ �,��/ 22 6 -DSP02 140 • ♦® p 210 �OP2 -ENI #10 (P1) 200 160 190 tan 170 Well Ticks Type: MD on OP23 -W W 02 (P5) Calculation Method: Normal Plane Ring Interval: 110.00 ft Azimuth Interval: 1 10.00 deg Scale: 1 INCH = 50.00 ft Dr Ming Hazards Sum iary 16" Open Hole / 13 -3/8" Casin2 Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low , Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced • drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 12 -1/4" Open Hole / 9 -5/8" Casin2 Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of • Lecithin. Stuck Pipe Low Good hole cleaning, pre- treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low , BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 8 -1/2" Open Hole / 7" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low , Stripping drills, shut -in drills, increased mud Pressure weight. Stuck Pipe Moderate Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming Drilling Hazards Summary 2/18/2010 4:38:15 PM I I HYDRIL GK A 13 NN " 5K BOP PSI 4' - 61i" LATCHED HEAD 5K FLANGE CONNECTION 1 1 54 - 1/2" LENGTH 1 _41 — 1 IP= 4" 10,000 WP CAMERON TYPE F" HYDRIL 13 -5/8" 51( PSI 13 — 44" 1 GATE VALVE 3' -ei" MPL DOUBLE GATE 4" 10,0001 WP STUDDED CONNECTION 4" 10,0001 WP CAMERON HCR VALVE 42 -7/8" LENGTH CAMERON HCR VALVE = 411 - W. DRILLING SPOOL 4" CHOKE LINE 1 /II L I\ II 3" KILL LINE 13- 5/8 " -5K PSI FLANGED I�I \II + L II � I — 2' � 11 � � — 2" 4 " -10K PSI FLANGED OUTLETS 4"x3" — Li 26" EST. LENGTH 4" 10,0001 WP ----I HYDRIL 13 - 5/8" 5k PSI CAMERON TYPE F" - GATE VALVE 1 - - _ _E___ _ _ 1 3' - " MPL SINGLE GATE FL ANGED CONNECTION 36-1/4" LENGTH 410 NABORS ALASKA RIG 245E 13.5/8" 5K BOP STACK CONFIGURATION � orsN � ° °» 22 NsYe -.A4 Me A nche eW� m tiN . 20711 Pm"' NABORS ALASKA RIG 245E nn2 &OW -OUT PREV:N1ER 13 -5/8' 5K STUDDED STACIE CONFI(UR4IICN 1•AMRO8 A d4 44 ISSUED . OOZED lit PPFIRMO el W. ° OE ALM JOE ALSTON JOE ALSiON A 41t SOLE WA WICK 17•1 245E_0002 -SK �t d I iii I i L e°_': L 111 11:2 up • ) CON ECTOR I CELLAR , ( L —J ) l 1 1 �F • III WELL BM! ft, 1 I I HYDRIL 13 -5/8" 5K PSI rp {I, GK ANNULAR BOP O I . , 4' - 6} • LATCHED HEAD 1 4; 5K FLANGE CONNECTION - _ 54 -1/2" LENGTH -- 4" 10,000/ WP C AMERON TYPE F• GATE VALVE __. —.4E1 IIII • =OM 1 � 1111 HYDRIL 13 5K PSI : I3' - 4," I J'_ • MPL DOUBLE GATE '�: lll'.s:: WP e 10,000; NP = OM - -- - �= CAMERON YLLVE STUDDED 2 - 7/8" LENGTH CONNECTION ':. I 0 CAMERON HCR VALVE '.J SN DRILING SOOL 4' CHOKE LINE 1 1h /'b 4�I + Eh, V 41/ _ — 3 " KI UNE 2, - 2 . 13 -5/8 5K PSI FLANGED ` 4 " -10K PSI FLANGED OUTLETS a•xl'� � 26 EST. LENGTH 4" 10,0001 WP I HYDRIL 13 -5/8" 5k PSI E STIMATED CAMERON TYPE F' Il I . — MPL SINGLE GATE SO' LENGTH GATE VALVE - - —` - J -( * FLANGED CONNECTION 16" DIVERTER LINE II I + 36 -1/4" LENGTH 13.5/8' 5K BOP STACK CONFIGURATION DIVERTER LINE ROUTING NABORS ALASKA RIG 245E ENI NIKAITCHUO PROJECT 0 21 -1/4" 2,000/ WP 2.000/ STUDDED TOP SHAFFER BY 4 -4 1/2• 21 -1/4" 2,000 / FLANGED BOTTOM H2S TRIMMED ANNULAR DIVERTER SYSTEM O /,s �∎ SURFACE DIVERTER `° 16 -150; FLG PIPING CONFIGURATION 2 ._ 0 . 1 ` I'l PLAN VIEW DAN 2 — 2 - I 0• 4" DIA. 194. s �nNn oorM ar xma iow�unMx� m usY a 1 Rll�L ONLY f .WIIICI®M BI I X4 MALE �� `1 6' KNIFE GATE = Nabors Mara 2sas c sn.. wn. 200 W/ HYD. ACTUATOR A MANON"OU' ~C."" yoi�sereoNOO1° ROW PROJECT NABORS ALASKA RIG 245E 2• -0' TOLE BOP STACK AND DNERTER CONFIGURATION ENI NIKAICHUO PROJECT SURFACE DIVERTER CONFIGURATION APPROVED NY REV. 9JULY08 A JA JA ISSUED J OE ALSTON JOE AL STON JOE &VON A wwr "' T V DESCRIPTION SCALE °0 N/A E O1° JULY 24,5 0201- NYGNICHUO �I of I Nabors Alaska Drilling Rig - 245E Material List i. Item Description 1 -15 4- 1/16" 10M Cameron Manual Gate Valve 16 2- 1/16" 10M Cameron Manual Gate Valve A,B 4- 1/16" 10M Cameron H2 Manual Choke C 3- 1/16" 10M Shaffer Hydraulic Choke • • 1 1 ~O To Gas - 1 .�. ---Q � ; BU - "'. r �J ' ) ' .„ • _ ,. (V IIN ( 4.4 11 / ' mr ..„..,......"*."" ------""_...„ - 111:41 1 <e ft., (DA11 - ' ___________ -,' - - A : 0 11 04 B A e 1 11 I I I _1 _ ' . , . Ilir--- Joil ' ToSha �� O��`, � C J ► r From 4 p ,� �_ r, Ok BOP's Legend QL White Handle Valves $ le ri aD Normally O p en eserve Pik' ED Red Handle Valves Normally Closed Date: 6 -1 -01 Rev. 1 CODS , • • • Schlumberger C emCAD E well cementing recommendation for Surface Casing Operator : Eni Petroleum Well : 0P23 -WW02 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr. Jason Brink Location : Oliktok Point Proposal No. : Draft v3 Service Point : Prudhoe Bay, Alaska Date Prepared : 2 -22 -2010 Business Phone : 907 - 659 -2434 FAX No. : 907 - 659 -2538 Prepared by : Tony Stafford Phone : 907 - 273 -1700 E -Mail Address : tstafford @slb.com S ra,N o n c tal ATE 41? Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. i Mark of Schlumberger Client : Eni Petroleum Well : 0P23 -WW02 3chiumberger String : Surface Casing District : Prudhoe Bay, Alaska Y {{1I Country : US Loadcase : 13 -3 /8in Surface Casing Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 4631.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000) psi OD 20. in 0 — Gm 16oft :� l j • L Frac I Pore '1 . Permafrast OD 13.4in ig 4831tt } o t _ a — . CV T /Cosh 1 LC 14551 ft } _ 4 • czi o _ a Well Lithology Formation Press. Page 2 OP23- WW02.cfw; 02 -22 -2010; LoadCase 13 -3 /8in Surface Casing ; Version wcs- cem453_10 0 • Client : Eni Petroleum Well : 0P23 -WW02 Sallokrier String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Previous String MD OD Weight ID (ft) (in) (Ib /ft) (in) 160.0 20 169.0 18.376 Landing Collar MD : 4551.0 ft Casing /liner Shoe MD : 4631.0 ft Casing /Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib /ft) (in) (psi) (psi) 4631.0 13 3/8 40.0 68.0 12.415 L -80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 79.8 % Mean OH Equivalent Diameter: 17.819 in Total OH Volume : 1379.1 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) ( %) (in) 1901.0 16.000 150.0 19.279 4631.0 16.000 35.0 16.822 Page 3 OP23- WW02.cfw;02 -22 -2010, LoadCase 13-3/8in Surface Casing ; Version wcs- cem453_10 0 • Client : Eni Petroleum Well : OP23 -WW02 Scl 1 's' String : Surface Casing District : Prudhoe Bay, Alaska t Country : US Loadcase : 13 -3 /8in Surface Casing Max. Deviation Angle : 50 deg Max. DLS : 2.759 deg /100ft Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 0.0 0.0 0.0 340.0 0.000 41.0 41.0 0.0 340.0 0.000 100.0 100.0 0.0 340.0 0.000 154.2 154.2 0.0 340.0 0.000 200.0 200.0 0.0 340.0 0.000 300.0 300.0 0.0 340.0 0.000 400.0 400.0 0.0 340.0 0.000 500.0 500.0 0.0 340.0 0.000 600.0 600.0 0.0 340.0 0.000 700.0 700.0 0.0 340.0 0.000 728.2 728.2 0.0 340.0 0.000 800.0 800.0 0.0 340.0 0.000 900.0 900.0 0.0 340.0 0.000 958.2 958.2 0.9 340.0 1.495 1000.0 1000.0 1.5 340.0 1.507 1100.0 1099.9 4.3 340.0 2.750 1200.0 1199.4 7.0 340.0 2.750 1219.0 1218.2 7.5 340.0 2.738 1300.0 1298.3 9.8 340.0 2.753 1400.0 1396.4 12.5 340.0 2.750 1436.4 1431.8 13.5 340.0 2.750 1500.0 1493.5 15.0 343.6 2.754 1600.0 1589.5 17.5 348.0 2.744 1700.0 1684.2 20.0 351.4 2.757 1730.9 1713.2 20.8 352.3 2.736 1800.0 1777.4 22.6 354.0 2.753 1900.0 1868.8 25.2 356.1 2.746 2000.0 1958.3 27.8 357.9 2.750 2074.1 2023.2 29.8 358.9 2.752 2100.0 2045.6 30.5 359.3 2.753 2200.0 2130.6 33.2 0.5 2.749 2300.0 2213.0 35.8 1.6 2.748 2400.0 2292.6 38.5 2.5 2.749 2500.0 2369.4 41.2 3.4 2.753 2600.0 2443.0 43.9 4.1 2.747 2678.1 2498.2 46.0 4.7 2.759 2700.0 2513.3 46.6 4.8 2.731 2800.0 2580.2 49.3 5.4 2.749 2806.3 2584.3 49.5 5.5 2.746 2900.0 2645.2 49.5 5.5 0.000 3000.0 2710.1 49.5 5.5 0.000 3100.0 2775.0 49.5 5.5 0.000 3200.0 2839.9 49.5 5.5 0.000 3300.0 2904.8 49.5 5.5 0.000 3400.0 2969.8 49.5 5.5 0.000 3500.0 3034.7 49.5 5.5 0.000 3600.0 3099.6 49.5 5.5 0.000 3700.0 3164.5 49.5 5.5 0.000 3705.7 3168.2 49.5 5.5 0.000 3800.0 3229.4 49.5 5.5 0.000 3900.0 3294.4 49.5 5.5 0.000 4000.0 3359.3 49.5 5.5 0.000 4100.0 3424.2 49.5 5.5 0.000 Page 4 OP23- WW02.cfw ; 02 -22 -2010 ; LoadCase 13 -3 /Bin Surface Casing ; Version wcs- cem453_10 • Client : Eni Petroleum Well : 0P23 -WWO2 S I 1 iet String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 4121.7 3438.3 49.5 5.5 0.000 4191.0 3483.3 49.5 5.5 0.000 4200.0 3489.1 49.5 5.5 0.000 4300.0 3554.0 49.5 5.5 0.000 4400.0 3618.9 49.5 5.5 0.000 4500.0 3683.9 49.5 5.5 0.000 4529.9 3703.3 49.5 5.5 0.000 4600.0 3748.8 49.5 5.5 0.000 4631.0 3768.9 49.5 5.5 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (Ib /qal) (lb /gal) 154.0 11.20 9.00 Permafrost Sandstone 1901.0 12.00 9.00 Permafrast Sandstone 4225.0 16.00 9.00 T /Cosh 1 Shale 4631.0 16.00 9.00 Shale Geothermal Temperature Profile MD ND Temperature Gradient (ft) (ft) (deg F) (degF /100ft) 0.0 0.0 20 0.0 1901.0 1869.7 32 0.6 4631.0 3768.9 50 0.8 Page 5 0P23- WW02.cfw , 02 -22 -2010 , LoadCase 13 -3 /8in Surface Casing , Version wcs- cem453_10 • • Client : Eni Petroleum Well : 0P23 -WW02 Schiumholler String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing ft degF (x 1000) ft _ 0 1 40 60 11 n 1 r� 1 .5 2.0 2.5 - Geoth.Profile Hori . Depart. 1 I 7r. 1111 ■ ■ ■■ ■ ■■ ■ ■III■ ■ ■ ■BUI i 1111 11111111111.1 ■111111 ■1 I ■ ■■■ ■ ■!■■■■■■■ ■i. ■■■ - 1 ■1 1111111111111111111111111.11111111 7 _ ` ' o - .■ ■ ■■ ■■■■ ■ 1 m ■ 1 ■I U1= U I 1U /I r i■ 1111 1 ■ ■ i■i./ - - 1 -- - N ri■iiiiUU iilii�IRIU ii !u■■■■■ ■1■!■1■n■■ ■■■ ■■1 ■ ■■ ■n■ ■ �- , 1111■■ n I ■ = 1111■! ■ ■ 0 - - A 111 1 111U 1 11111n1■. 1111■ ! ■■■ ■ . ■ ■ ■ ■ ■ ■ ■ ° o _ - o _ MUM - - i - 11 1 ■ /i11111 csi CV ! ■1� 111111 1111 UMW 1 ■■ i ∎I =11 IQI R II c 111•i=1�1 N1111■u■u111 ■1 j C ., _ •i ■ ■ Z■ ■ ■■ 1111■ .1111■ ■■�■■ ■4!■■■■ 1l■■■■■ I - 111■11111111111111011111111111111111111 111 ►1■ ■•1111111 ■1 _ 1111 ■1 -., o-' 111111111111111111111111011111111111111111111 - I 1111■■■■ ■ 1111 ■r► ■ . 111■/ .1u11N ■1►'Il11 = ■1 _ -T- - 1111111111111 ' ° _ .. ° � I 111111111111111M1111111111111•111111111111111 o - N �1 = " =1 1= � =1111 1 - ■ ■ ■ ■ ■ ■ II c. Li - Temperature Hori. Departure Section 2: fluid sequence Job Objectives: ArcticSET Light cement to Surface, 500' 12.0 ppg DeepCRETE Slurry Tail Original fluid Mud 9.60 lb/gal k : 1.08E -2 lbf.s ^n /ft2 n : 0.506 Ty : 15.43 Ibf /100ft2 Displacement Volume 681.4 bbl Total Volume 1420.2 bbl TOC 0.O ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb /gal) MUDPUSH II 100.0 0.0 10.20 k:2.26E -2 Ibf.s ^n /ft2 n:0.435 Ty:13.81 Ibf /100ft2 Lead Slurry 576.2 4131.0 0.0 10.70 k:1.24E -2 Ibf.s ^n /ft2 n:0.412 Ty:9.87 Ibf /100ft2 Tail Slurry 62.5 500.0 4131.0 12.00 k:8.21 E -2 lbf.s ^n /ft2 n:0.350 Ty:6.54 Ibf /100ft2 Mud 681.4 0.0 9.60 k:1.08E-2 lbf.s^n/ft2 n:0.506 Ty:15.43 lbf/100ft2 Page 6 0P23- WW02.cfw; 02 -22 -2010 ; LoadCase 13 -3 /8in Surface Casing ; Version wcs-cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 ScMMumherger String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Static Security Checks : Frac 4 psi at 160.0 ft Pore 14 psi at 160.0 ft Collapse 1906 psi at 4551.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 94 ton fi (X 1000) psi ( il > 0 ? 4 Hydrostatic _ S - Frac -- Pore - -_ • 0 o i u o - 0 0 kn - Fluid Sequence Static Well Security Section 3: pumping schedule Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl /min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 7 -Start Pumping Spacer Pause 0.0 0.0 10.0 0.0 80 4 -Drop Bottom Plug Lead Slurry 5.0 576.2 115.2 576.2 80 13 -Start Mixing Lead Slurry Tail Slurry 5.0 62.5 12.5 62.5 80 16 -Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 18 -Drop Top Plug Mud 8.5 650.0 76.5 650.0 80 19 -Start Displacement Mud 3.0 31.4 10.5 681.4 80 21 -Bump Top Plug Total 04:09 1420.2 bbl hr:mn End Job: Bump Plug; Check floats Dynamic Security Checks : Frac 3 psi at 160.0 ft Pore 5 psi at 160.0 ft Collapse 1906 psi at 4551.0 ft Burst 4696 psi at 0.0 ft Page 7 OP23- WW02.cfw; 02 -22 -2010; LoadCase 13 -3 /8in Surface Casing ; Version wcs- cem453_10 1 • • Client : Eni Petroleum Well : OP23 -WW02 S SCIIMINI101 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Temperature Results BHCT 64 degF Simulated Max HCT 61 degF Simulated BHCT 61 degF Max HCT Depth 4536.5 ft CT at TOC 59 degF Max HCT Time 04:09:41 hr:mn:sc Static temperatures : At Time 1 (hr:mn) (hr:mn) Geo. Temp. Top of Cement (degF) (degF) 1 20 degF Bottom Hole (degF) (degF) 50 degF c) —Cale. WHP I c linp ; —Cale. Pump Press. --1---1 _— - _ ur 1 I ��� ( - _ t 0 40 80 120 160 200 240 280 Time (min) Fluids at 4631 ft _ _ o — Acquired Q Out �_ _L III — Acquired Q In . —_., Q out Mall IC __'� Lo i 0 4 8 1 160 200 2 4 0 280 Time (min) Page 8 0P23- WW02.cfw; 02 -22 -2010; LoadCase 13 -3 /8in Surface Casing ; Version wcs-cem453_10 1 • • Client : Eni Petroleum Well : OP23 -WW02 SGhlrger String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing * CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Depth = 160 ft = 4631 ft - Frac _Depth - Pore - Hydrostatic - Hydrostatic Dynarric - vynamc . co � o r i in To a cn E -0 N �(7 Y O N — 7 N co m N cn a) W r F U U Q co Cri is _ - m 0 cli 1.1 0 100 200 300 0 100 200 300 Time (min) Time (min) 'S o Total Depth = 4631.0 ft Top of Cement = 0.0 ft *Mark of Schlumberger Seklumberpr Page 9 OP23- WW02.cfw; 02 -22 -2010 ; LoadCase 13 -3 /Bin Surface Casing ; Version wcs- cem453_10 • 0 Client : Eni Petroleum Well : OP23 -WW02 S hlumhurgcr String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Section 4: centralizer placement Top of centralization :100.0 ft Bottom Cent. MD :4611.0 ft Casing Shoe :4631.0 ft NB of Cent. Used :24 NB of Floating Cent. :24 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint ( %) (ft) 191.0 2 1/1 NW -TR -13 3/8 -8 -TR 3 W304 0.0 180.1 3751.0 0 0/0 0.0 191.0 4631.0 22 1/1 NW -TR -13 3/8 -8 -TR 3 W304 0.0 3761.9 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) NW -TR -13 3/8 -8 -TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 OD specifications ft % 0 70 40 60 Bo 100 I-- Between Cent. 1 I 1 1 .4 4 Cent. - f + - _ 1 H 11 1 111 1 _ Ln - In ' — 1 11. I it 1 i - 11 0 kr, _ Pipe Standoff Page 10 OP23- WW02.cfw; 02 -22 -2010; LoadCase 13 -3 /8in Surface Casing ; Version wcs- cem453_t0 • • Client : Eni Petroleum Well : OP23 -WW02 SCAT 1111 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing * CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US ton ft 0 20 40 60 80 100 120 140 160 o I — Hooldoad Up — — Hooldoad Dow n Weight \ -- -- Drag Force \ \ \, 1 1 \ I \ 1 \ o \ 1 \ a 1 \ E p 1 \ 3 d 1 \ Lo 1 \ e N \ > 1 \ F 1 \ U 1 \ \ t 1 co I \ c I \ - - I \ 1 \ I \ o p \ R O • O • O o in — 3 3 Running Forces ei o Friction Factor = 0.25 Total Depth = 4631.0 ft Top of Cement = 0.0 ft 'Mark of Schlumberger SCh'ievpr Page 11 0P23- WW02.ctw; 02 -22 -2010: LoadCase 13 -3 /Bin Surface Casing ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 Schlumderger String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Section 5: WELLCLEAN 11 Simulator oh ft ._ o 711 £0 60 80 100 -- Std Betw. Cent. 1 • 1 1 _ — Cement Coverage 1 - _ IIII 1111 CD 0 III �- _ II1 ■ ___. 1110.11111 �. I ----1 , 6 .=' - , I . '---- I 1 o . Ln— Cement Coverage Fluids Concentrations Risk Mud on the Wall 0 0 a-I 1 -a .500- 540 500- te: - 500 1000- 1400 1000- :' ' 1 -1000 _ 1500- 1500 ,---. 1500_ { 1500 :- 2000- 2000 . 2000- 2400 E. 1 2500- 2500 a 0 2500 _ �1 ' i 2500 3000- 3000 3000- -3000 I 3500- 3500 3500- 1 -3500 4000 - 4400 4000 - - 4400 4500 4500 4500 - r - 4500 • a o a v o a k 0 3 k o z z ▪ Mud 1 ( Lead Slurry ® High 111M1 Lou ▪ Tail Slurry ( 1 MUDPUSH II I 1 Medium 1 1 None Page 12 0P23- WW02.cfw; 02 -22 -2010; LoadCase 13 -3 /Bin Surface Casing ; Version wcs- cem453_10 i • Client : Eni Petroleum Well : OP23 -WW02 Ski i" String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Section 6: fluid description Mud DESIGN Fluid No: 1 Density : 9.60 lb /gal Rheo. Model : HERSCHEL_B. k : 1.08E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.506 Ty : 15.43 lbf/100ft2 Gel Strength : (Ibf /100ft2) MUD Mud Type : WBM Job volume : 681.4 bbl Water Type : Fresh VOLUME FRACTION Solids : 4.0 % Oil : 0.0 % Water : 96.0 % MUDPUSH II DESIGN Fluid No: 2 Density : 10.20 lb /gal Rheo. Model : HERSCHEL_B. k : 2.26E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.435 Ty : 13.81 lbf/100ft2 Gel Strength : (lbf/100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No: 3 Density : 10.70 lb /gal Rheo. Model : HERSCHEL_B. k : 1.24E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.412 Ty : 9.87 lbf/100ft2 Gel Strength : (Ibf /100ft2) DESIGN BLEND SLURRY Name : B809 Mix Fluid : 19.043 gal /sk Job volume : 576.2 bbl Dry Density : 105.47 lb /ft3 Yield : 4.33 ft3 /sk Quantity : 747.47 sk Sack Weight : 188 lb Solid Fraction : 41.2 % BASE FLUID Type : Fresh water Density : 8.32 lb /gal Base Fluid : 19.043 gal /sk Page 13 OP23- WW02cfw;02 -22 -2010; LoadCase 13 -3 /8in Surface Casing, Version wcs-cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 SI urger String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Tail Slurry DESIGN Fluid No: 4 Density : 12.00 lb /gal Rheo. Model : HERSCHEL_B. k : 8.21E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.350 Ty :6.54lbf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.0 PPG Lit Mix Fluid : 5.232 gal /sk Job volume : 62.5 bbl Dry Density : 110.20 lb /ft3 Yield : 1.61 ft3 /sk Quantity : 217.44 sk Sack Weight : 100 lb Solid Fraction : 56.7 % BASE FLUID Type : Fresh water Density : 8.32 lb /gal Base Fluid : 5.082 gal /sk Additives Code Conc. Function D046 0.200 %BWOB Antifoam D185A 0.050 gal /sk blend Dispers. LT D186 0.100 gal /sk blend Accelerator D153 1.500 %BWOC Antisettling Sect 7: operator summary Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl /min) (bbl) (min) (bbl) MUDPUSH II 5.0 100.0 20.0 100.0 7 -Start Pumping Spacer Pause 0.0 0.0 10.0 0.0 4 -Drop Bottom Plug Lead Slurry 5.0 576.2 115.2 576.2 13 -Start Mixing Lead Slurry Tail Slurry 5.0 62.5 12.5 62.5 16 -Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 18 -Drop Top Plug Mud 8.5 650.0 76.5 650.0 19 -Start Displacement Mud 3.0 31.4 10.5 681.4 21 -Bump Top Plug Total Pumping Time : 04:09 hr:mn End Job: Bump Plug; Check floats Mix Water Requirements : Fresh water 433 bbl Page 14 OP23- VVW02.cfw , 02 -22 -2010: LoadCase 13 -3 /8in Surface Casing , Version wcs- cem453_10 • Client : Eni Petroleum Well : OP23 -WW02 Shier String : Surface Casing District : Prudhoe Bay, Alaska � Country : US Loadcase : 13 -3 /8in Surface Casing MIXING PREPARATION MUDPUSH 11 Volume : 100.0 bbl Density : 10.20 lb /gal Code Quantity Design Fresh water 92.153 bbl D046 64.404 lb 0.200 %BWOW D182 552.917 lb 6.000 lb/bbl of base fluid D031 10020.897 lb 100.21 lb /bbl of spacer Lead Slurry Volume : 535.4 bbl Density : 10.70 lb /gal Yield : 4.33 ft3 /sk Dry Phase Liquid Phase Blend : 130560 lb Design Mix Water 314.9 bbl 10.0 bbl LAS Design B809 130560.039 Fresh water 314.874 bbl 10.001 bbl lb Tail Slurry Volume : 62.5 bbl Density : 12.00 lb /gal Yield : 1.61 ft3 /sk Dry Phase Liquid Phase Blend : 21987 lb Design Mix Water 27.1 bbl 10.0 bbl LAS Design 12.0 PPG Lit 21744.340 lb Fresh water 26.312 bbl 9.714 bbl D046 43.489 lb 0.200 %BWOB D185A 10.872 gal 4.014 gal 0.050 gal /sk blend D153 199.142 lb 1.500 %BWOC D186 21.744 gal 8.028 gal 0.100 gal /sk blend Page 15 OP23- WW02.cfw, 02 -22 -2010 ; LoadCase 13 -3 /Bin Surface Casing , Version wcs- cem453_10 4110 • Client : Eni Petroleum Well : OP23 -WW02 S Irg�r String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Annulus ID : 13.375 in - OD : 16.000 in - Tail Slurry O Lead Slurry NUDPUSH II CO O � Cfl O to . 2 O V7 Lo F IZ o C O -C cS m O N 0 N I I 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbl /min) S 0 III Mud Herschel : k = 1.08E-2 Ibf.s ^n/ft2 n = 0.506 Ty = 15.43 Ibf /100ft2 MUDPUSH II Herschel : k = 2.26E-2 Ibf.s ^n/ft2 n = 0.435 Ty = 13.81 Ibf /100ft2 3 Lead Slurry Herschel : k = 1.24E-2 Ibf.s ^n/ft2 n = 0.412 Ty = 9.87 Ibf /100ft2 ® Tail Slurry Herschel : k = 8.21E-2 Ibf.s ^n/ft2 n = 0.350 Ty = 6.54 Ibf /100ft2 'Mark of Schlumberger �ichl1 erpr Page 16 OP23- W1NO2.cfw : 02 -22 -2010 ; LoadCase 13 -3 /8in Surface Casing ; Version wcs- cem453_10 Schlumberger C emCAD E * well cementing recommendation for Intermediate Casing Operator : Eni Petroleum Well : OP23 -WW02 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr. Jason Brink Location : Oliktok Point Proposal No. : Draft v3 Service Point : Prudhoe Bay, Alaska Date Prepared : 2 -22 -2010 Business Phone : 907 - 659 -2434 FAX No. : 907 - 659 -2538 Prepared by : Tony Stafford Phone : 907- 273 -1700 E -Mail Address : tstafford@slb.com � Q C7 ' Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. * Mark of Schlumberger s • Client : Eni Petroleum Well : OP23 -WW02 Schlumderger String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9-5/8 Intermediate Casing (a) Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 9035.0 ft BHST : 95 degF Bit Size : 12 1/4 in ft (x 1000) psi OD 20. in 0 "7 4 6 - 1 164ft < 3 ' • ��— Frac Pore I ' - Permafrast ti ._ OD 13.4 in -- i (4631ft l • Shale T/Cosh 1 .- 1 i _ __ t . it II ci o �OD 9.62 in =- Lc) [ 9036ft 1 . Shale Ul I , ... I L 1 LC Q8955 ft Shale j '111 I o 0 IIII 0 0 Well Lithology Formation Press. Page 2 OP23- WW02.cfw; 02 -22 -2010; LoadCase 9-5/8 Intermediate Casing la); Version wcs- cem453_10 • • Client : Eni Petroleum Well : 0P23 -WW02 Schlinkrger String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Previous String MD OD Weight ID (ft) (in) (lb /ft) (in) 4631.0 13 3/8 68.0 12.415 Landing Collar MD : 8955.0 ft Casing /liner Shoe MD : 9035.0 ft Casing /Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib /ft) (in) (psi) (psi) 9035.0 9 5/8 40.0 47.0 8.681 L -80 4760 6870 BTCM Mean OH Diameter : 12.250 in Mean Annular Excess : 25.0 % Mean OH Equivalent Diameter: 12.823 in Total OH Volume : 703.4 bbl (including excess) Max. Deviation Angle : 50 deg Max. DLS : 2.759 deg /100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 0.0 0.0 0.0 340.0 0.000 41.0 41.0 0.0 340.0 0.000 100.0 100.0 0.0 340.0 0.000 154.2 154.2 0.0 340.0 0.000 200.0 200.0 0.0 340.0 0.000 300.0 300.0 0.0 340.0 0.000 400.0 400.0 0.0 340.0 0.000 500.0 500.0 0.0 340.0 0.000 600.0 600.0 0.0 340.0 0.000 700.0 700.0 0.0 340.0 0.000 728.2 728.2 0.0 340.0 0.000 800.0 800.0 0.0 340.0 0.000 900.0 900.0 0.0 340.0 0.000 958.2 958.2 0.9 340.0 1.495 1000.0 1000.0 1.5 340.0 1.507 1100.0 1099.9 4.3 340.0 2.750 1200.0 1199.4 7.0 340.0 2.750 1219.0 1218.2 7.5 340.0 2.738 1300.0 1298.3 9.8 340.0 2.753 1400.0 1396.4 12.5 340.0 2.750 1436.4 1431.8 13.5 340.0 2.750 1500.0 1493.5 15.0 343.6 2.754 1600.0 1589.5 17.5 348.0 2.744 1700.0 1684.2 20.0 351.4 2.757 1730.9 1713.2 20.8 352.3 2.736 1800.0 1777.4 22.6 354.0 2.753 1900.0 1868.8 25.2 356.1 2.746 2000.0 1958.3 27.8 357.9 2.750 2074.1 2023.2 29.8 358.9 2.752 2100.0 2045.6 30.5 359.3 2.753 2200.0 2130.6 33.2 0.5 2.749 2300.0 2213.0 35.8 1.6 2.748 2400.0 2292.6 38.5 2.5 2.749 2500.0 2369.4 41.2 3.4 2.753 Page 3 OP23 -WW02 cfw; 02 -22 -2010; LoadCase 9 -5/8 Intermediate Casing (a), Version wcs- cem453_10 • 0 Client : Eni Petroleum Well : OP23 -WW02 S ) rger String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9-5/8 Intermediate Casing (a) Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 2600.0 2443.0 43.9 4.1 2.747 2678.1 2498.2 46.0 4.7 2.759 2700.0 2513.3 46.6 4.8 2.731 2800.0 2580.2 49.3 5.4 2.749 2806.3 2584.3 49.5 5.5 2.746 2900.0 2645.2 49.5 5.5 0.000 3000.0 2710.1 49.5 5.5 0.000 3100.0 2775.0 49.5 5.5 0.000 3200.0 2839.9 49.5 5.5 0.000 3300.0 2904.8 49.5 5.5 0.000 3400.0 2969.8 49.5 5.5 0.000 3500.0 3034.7 49.5 5.5 0.000 3600.0 3099.6 49.5 5.5 0.000 3700.0 3164.5 49.5 5.5 0.000 3705.7 3168.2 49.5 5.5 0.000 3800.0 3229.4 49.5 5.5 0.000 3900.0 3294.4 49.5 5.5 0.000 4000.0 3359.3 49.5 5.5 0.000 4100.0 3424.2 49.5 5.5 0.000 4121.7 3438.3 49.5 5.5 0.000 4191.0 3483.3 49.5 5.5 0.000 4200.0 3489.1 49.5 5.5 0.000 4300.0 3554.0 49.5 5.5 0.000 4400.0 3618.9 49.5 5.5 0.000 4500.0 3683.9 49.5 5.5 0.000 4529.9 3703.3 49.5 5.5 0.000 4600.0 3748.8 49.5 5.5 0.000 4700.0 3813.7 49.5 5.5 0.000 4800.0 3878.6 49.5 5.5 0.000 4900.0 3943.5 49.5 5.5 0.000 5000.0 4008.5 49.5 5.5 0.000 5100.0 4073.4 49.5 5.5 0.000 5200.0 4138.3 49.5 5.5 0.000 5300.0 4203.2 49.5 5.5 0.000 5400.0 4268.1 49.5 5.5 0.000 5500.0 4333.0 49.5 5.5 0.000 5600.0 4398.0 49.5 5.5 0.000 5700.0 4462.9 49.5 5.5 0.000 5800.0 4527.8 49.5 5.5 0.000 5900.0 4592.7 49.5 5.5 0.000 6000.0 4657.6 49.5 5.5 0.000 6100.0 4722.6 49.5 5.5 0.000 6200.0 4787.5 49.5 5.5 0.000 6300.0 4852.4 49.5 5.5 0.000 6400.0 4917.3 49.5 5.5 0.000 i 6500.0 4982.2 49.5 5.5 0.000 6600.0 5047.1 49.5 5.5 0.000 6700.0 5112.1 49.5 5.5 0.000 6800.0 5177.0 49.5 5.5 0.000 6900.0 5241.9 49.5 5.5 0.000 7000.0 5306.8 49.5 5.5 0.000 7100.0 5371.7 49.5 5.5 0.000 7200.0 5436.7 49.5 5.5 0.000 7300.0 5501.6 49.5 5.5 0.000 7400.0 5566.5 49.5 5.5 0.000 7500.0 5631.4 49.5 5.5 0.000 7600.0 5696.3 49.5 5.5 0.000 Page 4 OP23- WW02.cfw;02 -22 -2010, LoadCase9- 5/ 9 Intermediate Casing (a); Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WWO2 SGi rger String : Intermediate Casing District : Prudhoe Bay, Alaska 1! U1 Country : US Loadcase : 9-5/8 Intermediate Casing (a) Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 7700.0 5761.3 49.5 5.5 0.000 7800.0 5826.2 49.5 5.5 0.000 7900.0 5891.1 49.5 5.5 0.000 8000.0 5956.0 49.5 5.5 0.000 8100.0 6020.9 49.5 5.5 0.000 8200.0 6085.8 49.5 5.5 0.000 8300.0 6150.8 49.5 5.5 0.000 8400.0 6215.7 49.5 5.5 0.000 8500.0 6280.6 49.5 5.5 0.000 8600.0 6345.5 49.5 5.5 0.000 8681.5 6398.4 49.5 5.5 0.000 8700.0 6410.4 49.5 5.5 0.000 8797.0 6473.4 49.5 5.5 0.000 8800.0 6475.4 49.5 5.5 0.000 8900.0 6540.3 49.5 5.5 0.000 8951.1 6573.4 49.5 5.5 0.000 9035.0 6627.9 49.5 5.5 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb /gal) (lb /gal) 154.0 11.20 9.00 Permafrost Sandstone 1901.0 12.00 9.00 Permafrast Sandstone 4225.0 16.00 9.00 T /Cosh 1 Shale 7249.0 16.00 9.00 Shale 9035.0 16.00 9.00 Shale Geothermal Temperature Profile MD ND Temperature Gradient (ft) (ft) (degF) (degF /100ft) 0.0 0.0 20 0.0 1901.0 1869.6 32 0.6 4631.0 3795.9 50 0.8 9035.0 6654.9 95 1.1 Page 5 0P23- WW02.cfw, 02 -22 -2010 ; LoadCase 9 -5/0 Intermediate Casing (a) ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 SON 111111181 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) ft degF (x 1000) ft ao_ 0 51 100 n 7 4 6 - --- Geath.Profile — Hori. Depart. ) i 11 1 ____ __ _ . 1 . , ik. 1 6. L _ � Ili MI 111,1 __ __ , n _ ji 11 _ I 1 1111 - CO 1 IIUI o _ Ill o ( I Temperature Hori. Departure Section 2: fluid sequence Job Objectives: 1,000' of Fill; Zonal Isolation Original fluid Mud 9.80 lb/gal k : 1.08E - 2 Ibf.s ^n /ft2 n : 0.506 Ty : 15.43 Ibf/100ft2 Displacement Volume 655.6 bbl Total Volume 771.1 bbl TOC 8035.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH 11 40.0 573.7 7461.3 12.80 k:2.26E -2 Ibf.s ^n /ft2 n:0.435 Ty:13.81 Ibf/100ft2 Inter. Tail 75.6 1000.0 8035.0 15.80 k:3.93E -3 Ibf.s ^n /ft2 n:0.903 Ty:26.99 Ibf /100ft2 Mud 655.6 0.0 9.80 k:1.08E-2 lbf.sAn/ft2 n:0.506 Ty:15.43 lbf/100ft2 Page 6 OP23- WW02.cfw; 02 -22 -2010 ; LoadCase 9 -5/8 Intermediate Casing (a) Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 Schiumberger String : Intermediate Casing District : Prudhoe Bay, Alaska 111�� YY1 Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Static Security Checks : Frac 1223 psi at 4631.0 ft Pore 158 psi at 4631.0 ft Collapse 4186 psi at 8955.0 ft Burst 6870 psi at 6700.0 ft Csg.Pump out 124 ton ft ( 1000)psi 0 4 6 - Hydrostatic - Frac Pore ;.--1.- I 0 o _ �l i� ' I - ci ; ,s , - fl ci Fluid Sequence Static Well Security Section 3: pumping schedule Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl /min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 4.0 40.0 10.0 40.0 80 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4 -Drop Bottom Plug Inter. Tail 4.0 75.6 18.9 75.6 80 9 -Start Cement Slurry Pause 0.0 0.0 5.0 0.0 80 18 -Drop Top Plug Mud 8.5 620.0 72.9 620.0 80 19 -Start Displacement Mud 3.0 35.6 11.9 655.6 80 21 -Bump Top Plug Total 02:03 771.1 bbl hr:mn End Job: Bump Plug; Check floats Dynamic Security Checks : Frac 1035 psi at 4631.0 ft Pore 158 psi at 4631.0 ft Collapse 4186 psi at 8955.0 ft Burst 6263 psi at 0.0 ft Page 7 OP23- WW02.cfw; 02 -22 -2010; LoadCase 9-5/8 Intermediate Casing (a): Version wcs- cem453_10 • 0 Client : Eni Petroleum Well : OP23 -WW02 Schlumberger String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Temperature Results BHCT 89 degF Simulated Max HCT 95 degF Simulated BHCT 65 degF Max HCT Depth 9035.0 ft CT at TOC 66 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time (hr:mn) (hr:mn) Geo. Temp. Top of Cement (degF) (degF) 85 degF Bottom Hole (degF) (degF) 95 degF 0 ao Cale. UUHP . -- Cale. Pump Press. : = '--- _.-- -_ __ == ,__ = —'. 0- 1 �1•� M w �.- --�' MI _ _1 0 20 40 60 80 100 120 140 Time (min) Fluids at 9035 ft C O — r – .g. r — Acquired Q Out , . . , II NM= - Acquired Q In 1! V- u -- 0 Out a1 o In ip��M�• = ' .... _ 11111111111111111__ MN . ' LcI 0 20 40 60 80 100 120 140 Time (min) I Page 8 OP23- WW02.cfw; 02 -22 -2010; LoadCase 9-5/8 Intermediate Casing la), Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 SGhlrger String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9-5/8 Intermediate Casing (a) * CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Death = 463 ft Depth = 9035 ft `- — Frac '– — Frac — pore — pore — Hydrostatic — Hydrostatic � - n- _- — m vynac 1— I in E t 3 m X in 3 2 u) > N " y N a a C C Q,— Q,— o_ o ch v rn rn E N 0 50 100 150 CO 0 50 100 150 'g Time (min) Time (min) s a O Total Depth = 9035.0 ft Top of Cement = 8035.0 ft *Mark of Schlumberger SCh'I erp• Page 9 OP23- WW02.cfw ; 02 -22 -2010 ; LoadCase 9-5/8 Intermediate Casing (o); Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 S hlumbcrgcr String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9-5/8 Intermediate Casing (a) Section 4: centralizer placement Top of centralization :8000.0 ft Bottom Cent. MD :9015.0 ft Casing Shoe :9035.0 ft NB of Cent. Used :25 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint ( %) (ft) 9035.0 25 1/1 541 - STL -9 5/8 -6 -36 (.171") 3.0 8055.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) 541 - STL -9 5/8 -6 -36 9 5/8 13.126 9.720 No Houma 12.250 238.30 1690.56 (.171 ") (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 OD specifications Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer /Formation :0.25 Total Drag Force :15 ton Hook load Down Stroke :151 ton Hook load Up Stroke :180 ton ft % cp- 0 9n 0 60 00 100 — Between Cent. I 1 + +At Cert. ! II 11111_1 n ill ' _ - 1 1 11 I - - _ 11111 111 o IC i r - Pipe Standoff Page 10 0P23- WW02.cfw; 02 -22 -2010: LoadCase 9-5/8 Intermediate Casing (a); Version wcs- cem453_10 • • Client : Eni Petroleum Well : 0P23 -WW02 Scillukrger String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Page 11 OP23- WW02cfw;02 -22 -2010, LoadCase 9-5/8 Intermediate Casing (a); Version wcs-cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 Sclhrger String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) * CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US ton ft 0 25 50 75 100 125 150 175 200 o- 1 — Hookload Up 1 — — Hookload Dow n I Weight 1 — - Drag Force I \ o I \ a 1 \ E - I \ u 1 \\ • 0 1 .E 0- \ `n I \ 1 \ O 1 \ m 1 \ m 1 \ 1 \ E-3, 1 \ I \ If, I \ a m 0 O O s O N ?, Running Forces gi C C ry Friction Factor = 0.25 Total Depth = 9035.0 ft Top of Cement = 8035.0 ft a O *Mark of Schlumberger SCIIU uIpr Page 12 0P23- WW02.cfw; 02 -22 -2010; LoadCase 9 -5/B Intermediate Casing (a): Version wcs- cem453_10 • S Client : Eni Petroleum Well : OP23 -WW02 Sc brger String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9-5/8 Intermediate Casing (a) Section 5: WELLCLEAN II Simulator 13 16 ft al _ 0 in L0 60 80 100 - -- Std Betw. Cent. — Cement Coverage i , 1 1 ■ I _ MIMI . III _ _ OMNI III MI 11111 II 0 _ ,,11„ o Lti II 11119 , 111111111111111 `. l __ ca a. Cement Coverage Risk Mud on the Wall Fluids Concentrations z g z g 8000 8000 8000 - 8000 8100 8100 8100 8100 8200 8200 8200 8200 B300 8300 B300 8300 6400 8x00 f 8400 8400 U -c 8500 8500 -c s 6500 8500 s a 0 6600 8800 n o ° 8600 8600 n 8700 8700 8700 8700 8800 8800 8800 8300 8900 8900 8900 8900 9000 9000 9000 - 9000 z° z MO Mud Mill High MI Low EN Inter. Tail 1 Medium f 1 None [ MUDPUSH II Page 13 OP23- WW02.crw; 02 -22 -2010; loadCase 9-5/8 Intermediate Casing (a): Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 Seilskrier String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9-5/8 Intermediate Casing (a) Section 6: fluid description Mud DESIGN Fluid No: 1 Density : 9.80 lb/gal Rheo. Model : HERSCHEL_B. k : 1.08E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.506 Ty : 15.43 lbf/100ft2 Gel Strength : (lbf/100ft2) MUD Mud Type : WBM Job volume : 655.6 bbl Water Type : Fresh VOLUME FRACTION Solids : 4.0 % Oil : 0.0 % Water : 96.0 % MUDPUSH II DESIGN Fluid No: 2 Density : 12.80 lb/gal Rheo. Model : HERSCHEL_B. k : 2.26E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.435 Ty :13.81Ibf/100ft2 Gel Strength : (lbf/100ft2) Job volume : 40.0 bbl Inter. Tail DESIGN Fluid No: 5 Density : 15.80 lb/gal Rheo. Model : HERSCHEL_B. k : 3.93E -3 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.903 Ty :26.99Ibf/100ft2 Gel Strength : (lbf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid : 5.100 gal /sk Job volume : 75.6 bbl Dry Density : 199.77 Ib /ft3 Yield : 1.16 ft3/Sk Quantity : 364.98 sk Sack Weight : 94 lb Solid Fraction : 41.4 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.100 gal /sk Additives Code Conc. Function D046 0.200 %BWOC Antifoam D065 0.300 %BWOC Dispersant D153 0.200 %BWOC Antisettling D167 0.350 %BWOC Fluid loss Page 14 OP23- WW02.cfw, 02 -22 -2010; LoadCase 9-5/8 Intermediate Casing la), Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 SIrier String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9-5/8 Intermediate Casing (a) Sect 7: operator summary Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl /min) (bbl) (min) (bbl) MUDPUSH II 4.0 40.0 10.0 40.0 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 4 -Drop Bottom Plug Inter. Tail 4.0 75.6 18.9 75.6 9 -Start Cement Slurry Pause 0.0 0.0 5.0 0.0 18 -Drop Top Plug Mud 8.5 620.0 72.9 620.0 19 -Start Displacement Mud 3.0 35.6 11.9 655.6 21 -Bump Top Plug Total Pumping Time : 02:03 hr:mn End Job: Bump Plug; Check floats TOTAL MATERIAL REQUIREMENTS Mix Water Requirements : Fresh water 77 bbl MIXING PREPARATION MUDPUSH II Volume : 40.0 bbl Density : 12.80 Ib /gal Code Quantity Design Fresh water 33.166 bbl D046 23.179 Ib 0.200 %BWOW D182 198.995 Ib 6.000 lb/bbl of base fluid D031 9692.358 Ib 242.31 Ib /bbl of spacer Inter. Tail Volume : 75.6 bbl Density : 15.80 Ib /gal Yield : 1.16 ft3 /sk Dry Phase Liquid Phase Blend : (Ib) Design Mix Water 44.3 bbl 10.0 bbl LAS Design G 34308.496 Ib Fresh water 44.322 bbl 10.001 bbl D046 68.617 Ib 0.200 %BWOC D065 102.925 Ib 0.300 %BWOC D153 68.617 Ib 0.200 %BWOC D167 120.080 lb 0.350 %BWOC Page 15 OP23 -WW02 cfw 02 -22 -2010 , LoadCase 9 -5/8 Intermediate Casing (a) ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 3 lkIrgel String : Intermediate Casing District : Prudhoe Bay, Alaska fj Country : US Loadcase : 9-5/8 Intermediate Casing (a) CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Annulus ID : 9.625 in - OD : 12.823 in co co — Mud MUDRISH II - Inter. Tail �^ CO CO iV C17 O to '4' m to IN d • 3 � 4 j co • j N m d � C q O m U . 11 cD c _ c M N N I 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbl /min) ■ Mud Herschel : k = 1.08E-2 Ibf.s ^n/f12 n = 0.506 Ty = 15.43 lbf /100ft2 N MUDPUSH II Herschel : k = 2.26E-2 Ibf.s ^n/ft2 n = 0.435 Ty = 13.81 Ibf /100ft2 ■ hter. Tail Herschel : k = 3.93E-3 Ibf.s ^n/ft2 n = 0.903 Ty = 26.99 Ibf /100ft2 "Mark of Schlumberger Page 16 OP23- WW02.cfw; 02 -22 -2010: LoadCase 9-5/8 Intermediate Casing (a): Version wcs- cem453_10 • • Schlumberger C e m CAD E well cementing recommendation for Plug Back Operator : Eni Petroleum Well : 0P23 -WW02 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr. Jason Brink Location : Oliktok Point Proposal No. : Draft v3 Service Point : Prudhoe Bay, Alaska Date Prepared : 2 - - 2010 Business Phone : 907 - 659 -2434 FAX No. : 907 - 659 -2538 Prepared by : Tony Stafford Phone : 907 - 273 -1700 E -Mail : tstaffordCslb.com well description Configuration Plug Stage : Single Rig Type : Land Prev.String MD : 9035.0 ft OD : 9 5/8 in Weight : 47.0 lb /ft Drill Pipe MD : 9716.0 ft OD : 31/2 in Weight : 13.3 lb /ft Mud Line 0.0 ft Total MD 9716.0 ft BHST 132 degF Bit Size 81/2 in Mean OH Diameter 8.500 in � Mean Annular Excess 30.1 To 4 Mean OH Equivalent Diameter 9.503 in Total OH Volume 59.7 bbl (including excess) Target K.O.P. 9100.0 ft 0 C • RTE • Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • Mark of Schlumberger ••age 1•• OP23- WW02cfw :02 -22 -2010; LoadCase Plug Back (al; Version wcs- cem453 JO* • Page 1 OP23- WW02ctw;02 -22 -2010; LoadCase Plug Back fa); Version wcs-cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 SGhiumherger String : Plug Back District : Prudhoe Bay, Alaska Country : US Loadcase : Plug Back (a) Section 1: fluid sequence Job Objectives: Plud Back to Intermediate Casing Original fluid Mud 11.00 lb/gal k : 1.08E -2 Ibf.s ^n /ft2 n : 0.506 Ty : 15.43 lbf/100ft2 Displacement Volume 156.9 bbl Drill Pipe Volume 156.9 bbl Total Volume 259.6 bbl TOC 9076.8 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 60.0 991.1 8085.7 14.00 k:2.26E -2 Ibf.s ^n /ft2 n:0.435 Ty:1 3.81 lbf/100ft2 KOP Slurry 48.5 639.2 9076.8 17.00 k:7.44E -3 Ibf.s ^n /ft2 n:0.887 Ty:2.67 lbf/100ft2 KOP Slurry 11.3 8197.0 17.00 k:7.44E -3 Ibf.s ^n /ft2 n:0.887 Ty:2.67 lbf/100ft2 MUDPUSH II 18.8 7140.3 14.00 k:2.26E -2 Ibf.s ^n /ft2 n:0.435 Ty:13.81 lbf/100ft2 Mud 121.1 324.3 11.00 k:1.08E-2 lbf.s^n/ft2 n:0.506 Ty:15.43Ibf/100ft2 Static Security Checks : Frac 1611 psi at 9716.0 ft Pore 789 psi at 9035.0 ft Csg Pump out 55 ton ft (x 1000) psi 0 0 7.5 Hydrostatic - Frac Pore CD 1 `l nnllll 1/1111111 �_. n 1 �n 4 i tiI3 n � 1 1n11 ! 11 Fluid Sequence Static Well Security Page 2 OP23- WW02.cfw ; 02 -22 -2010 ; LoadCase Plug Back (a) ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 Schlu biller String : Plug Back District : Prudhoe Bay, Alaska Country : US Loadcase : Plug Back (a) Section 2: pumping schedule Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl /min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 4.0 60.0 15.0 60.0 80 7 -Start Pumping Spacer KOP Slurry 4.0 59.7 14.9 59.7 80 9 -Start Cement Slurry MUDPUSH II 4.0 18.8 4.7 18.8 80 7 -Start Pumping Spacer Mud 6.0 121.1 20.2 121.1 80 19 -Start Displacement Total 00:54 259.6 bbl hr:mn End Job: *Cut Displacement Short by 11.7 bbls, POOH Slowly (3min Stand) Reverse Two TBG Volumes Dynamic Security Checks : Frac 1380 psi at 9716.0 ft Pore 692 psi at 9035.0 ft Temperature Results BHCT 114 degF Simulated Max HCT 132 degF Simulated BHCT 90 degF Max HCT Depth 9716.0 ft CT at TOC 91 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time (hr:mn) (hr:mn) Geo. Temp. Top of Cement (degF) (degF) 122 degF Bottom Hole (degF) (degF) 132 degF o- 00 — Cale. 'OM P T-- — Calc. Pump Press. ' n = I o l 0 1 0 20 30 40 6 60 Time (min) 2. u7 Fluids at 9716 ft r- — A cquired 0 Out - E — Acquired 0 In __ _l__ 0 Out T�: --- o QIn — ..r- ( ;___ 6 .. 1 --t ( I I 1 ----f— 0 1 0 2 0 3 0 4 0 5 0 60 Time (min) Page 3 OP23- WW02,cfw ; 02 -22 -2010 ; LoadCase Plug Back la) ; Version wcs- cem453_10 S • Client : Eni Petroleum Well : OP23 -WW02 SI1 ger String : Plug Back District : Prudhoe Bay, Alaska Country : US Loadcase : Plug Back (a) Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 11.00 lb /gal Rheo. Model : HERSCHEL_B. k : 1.08E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.506 Ty : 15.43 lbf/100ft2 Gel Strength : (lbf/100ft2) MUD Mud Type : OBM Job volume : 121.1 bbl Water Type : Fresh VOLUME FRACTION Solids : 15.0 % Oil : 80.0 % Water : 5.0 % MUDPUSH II DESIGN Fluid No: 2 Density : 14.00 lb /gal Rheo. Model : HERSCHEL_B. k : 2.26E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.435 Ty : 13.81 lbf/100ft2 Gel Strength : (lbf/100ft2) Job volume : 78.8 bbl KOP Slurry DESIGN Fluid No: 7 Density : 17.00 lb /gal Rheo. Model : HERSCHEL_B. k : 7.44E -3 lbf.s ^n /ft2 At temp. : 80 degF n : 0.887 Ty : 2.67lbf/100ft2 Gel Strength : (lbf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid : 3.860 gal /sk Job volume : 59.7 bbl Dry Density : 199.77 lb/ft3 Yield : 1.00 ft3 /sk Quantity : 334.40 sk Sack Weight : 94 lb Solid Fraction : 48.6 % BASE FLUID Type : Fresh water Density : 8.32 lb /gal Base Fluid : 3.860 gal /sk Additives Code Conc. Function D046 0.200 %BWOC Antifoam D167 0.200 %BWOC Fluid loss D065 1.000 %BWOC Dispersant D013 0.150 %BWOC Retarder Page 4 OP23 -WW02 cf , 02 -22 -2010 , LoadCase Plug Back (a) , Version wcs- cem453_10 0 0 Client : Eni Petroleum Well : OP23 -WW02 Sek While String : Plug Back District : Prudhoe Bay, Alaska Country : US Loadcase : Plug Back (a) Sect 4: operator summary Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl /min) (bbl) (min) (bbl) MUDPUSH II 4.0 60.0 15.0 60.0 7 -Start Pumping Spacer KOP Slurry 4.0 59.7 14.9 59.7 9 -Start Cement Slurry MUDPUSH II 4.0 18.8 4.7 18.8 7 -Start Pumping Spacer Mud 6.0 121.1 20.2 121.1 19 -Start Displacement Total Pumping Time : 00:54 hr:mn End Job: POOH Slowly (3min Stand) Reverse Two TBG Volumes MATERIAL REQUIREMENTS Mix Water Requirements : Fresh water 85 bbl MIXING PREPARATION MUDPUSH II Volume : 78.8 bbl Density : 14.00 lb /gal Code Quantity Design Fresh water 54.356 bbl D046 37.989 lb 0.200 %BWOW D182 326.138 lb 6.000 lb/bbl of base fluid F103 157.516 gal 2.000 gal /bbl of spacer U067 157.516 gal 2.000 gal /bbl of spacer D031 24536.598 lb 311.54 lb /bbl of spacer KOP Slurry Volume : 59.7 bbl Density : 17.00 lb /gal Yield : 1.00 ft3 /sk Dry Phase Liquid Phase Blend : (lb) Design Mix Water 30.7 bbl 10.0 bbl LAS Design G 31433.197 lb Fresh water 30.729 bbl 10.001 bbl D046 62.866 lb 0.200 %BWOC D167 62.866 lb 0.200 %BWOC D065 314.332 lb 1.000 %BWOC D013 47.150 lb 0.150 %BWOC Page 5 OP23 -W V02 cfw ; 02 -22 -2010 , LoadCase Plug Back (a) ; Version wcs- cem453_10 • Schlumberger C emCAD E * well cementing recommendation for 7" Liner Operator : Eni Petroleum Well : OP23 -WW02 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr. Jason Brink Location : Oliktok Point Proposal No. : Draft v3 Service Point : Prudhoe Bay, Alaska Date Prepared : 2 -22 -2010 Business Phone : 907 - 659 -2434 FAX No. : 907 - 659 -2538 Prepared by : Tony Stafford Phone : 907 - 273 -1700 E -Mail Address : tstafford@slb.com 404 DEW* 4 %,,, Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and on estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. * Mark of Schlumberger • • Client : Eni Petroleum Well : OP23 -WW02 Scklrger String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Section 1: well description Configuration : Liner Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 12369.0 ft BHST : 210 degF Bit Size : 8 1/2 in ft (x 1000) psi OD 20. in O 6 9 o — (d 164ft 4 > Frac Permafrast r P41 i � _ OD 13.4 in _ �∎ 3886ft Y.. Shale T /Cosh 1 1 • - 0D5.in o @ 8800f u-, • OD 9.62 in Shale k t - @9035ft _ H — _. —_._._ ) - LH @8800ft a Shale lJ ' `— o o o OD 7. in O 12369ft 4 Shale LC @12289 ft „'! o _ 0 o - u) Well Lithology Formation Press. Previous String MD OD Weight ID (ft) (in) (lb /ft) (in) 9035.0 9 5/8 47.0 8.681 Drill Pipe MD OD Weight ID Grade Collapse Burst (ft) (in) (Ib /ft) (in) (psi) (psi) 8800.0 5 19.5 4.276 E -75 9960 9500 Page 2 OP23- VVW02.cfw ; 02 -22 -2010 ; LoadCase 7in Liner (a) ; Version wcs- cem453_10 S • Client : Eni Petroleum Well : 0P23 -WW02 SChilikrier String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Liner Hanger : 8800.0 ft Landing Collar MD : 12289.0 ft Casing /liner Shoe MD : 12369.0 ft Casing /Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib /ft) (in) (psi) (psi) 12369.0 7 40.0 26.0 6.276 L -80 5410 7240 LTC Mean OH Diameter : 8.500 in Mean Annular Excess : 25.0 % Mean OH Equivalent Diameter: 8.835 in Total OH Volume : 252.8 bbl (including excess) Max. Deviation Angle : 50 deg Max. DLS : 4.013 deg /100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 0.0 0.0 0.0 340.0 0.000 41.0 41.0 0.0 340.0 0.000 100.0 100.0 0.0 340.0 0.000 154.2 154.2 0.0 340.0 0.000 200.0 200.0 0.0 340.0 0.000 300.0 300.0 0.0 340.0 0.000 400.0 400.0 0.0 340.0 0.000 500.0 500.0 0.0 340.0 0.000 600.0 600.0 0.0 340.0 0.000 700.0 700.0 0.0 340.0 0.000 728.2 728.2 0.0 340.0 0.000 800.0 800.0 0.0 340.0 0.000 900.0 900.0 0.0 340.0 0.000 958.2 958.2 0.9 340.0 1.495 1000.0 1000.0 1.5 340.0 1.507 1100.0 1099.9 4.3 340.0 2.750 1200.0 1199.4 7.0 340.0 2.750 1219.0 1218.2 7.5 340.0 2.738 1300.0 1298.3 9.8 340.0 2.753 1400.0 1396.4 12.5 340.0 2.750 1436.4 1431.8 13.5 340.0 2.750 1500.0 1493.5 15.0 343.6 2.754 1600.0 1589.5 17.5 348.0 2.744 1700.0 1684.2 20.0 351.4 2.757 1730.9 1713.2 20.8 352.3 2.736 1800.0 1777.4 22.6 354.0 2.753 1900.0 1868.8 25.2 356.1 2.746 2000.0 1958.3 27.8 357.9 2.750 2074.1 2023.2 29.8 358.9 2.752 2100.0 2045.6 30.5 359.3 2.753 2200.0 2130.6 33.2 0.5 2.749 2300.0 2213.0 35.8 1.6 2.748 2400.0 2292.6 38.5 2.5 2.749 2500.0 2369.4 41.2 3.4 2.753 2600.0 2443.0 43.9 4.1 2.747 2678.1 2498.2 46.0 4.7 2.759 2700.0 2513.3 46.6 4.8 2.731 2800.0 2580.2 49.3 5.4 2.749 2806.3 2584.3 49.5 5.5 2.746 Page 3 OP23- WW02.cfw,02 -22 -2010; LoadCase 7in Liner (a), Version wcs-cem453_10 0 • Client : Eni Petroleum Well : OP23 -WW02 S ' rger String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 2900.0 2645.2 49.5 5.5 0.000 3000.0 2710.1 49.5 5.5 0.000 3100.0 2775.0 49.5 5.5 0.000 3200.0 2839.9 49.5 5.5 0.000 3300.0 2904.8 49.5 5.5 0.000 3400.0 2969.8 49.5 5.5 0.000 3500.0 3034.7 49.5 5.5 0.000 3600.0 3099.6 49.5 5.5 0.000 3700.0 3164.5 49.5 5.5 0.000 3705.7 3168.2 49.5 5.5 0.000 3800.0 3229.4 49.5 5.5 0.000 3900.0 3294.4 49.5 5.5 0.000 4000.0 3359.3 49.5 5.5 0.000 4100.0 3424.2 49.5 5.5 0.000 4121.7 3438.3 49.5 5.5 0.000 4191.0 3483.3 49.5 5.5 0.000 4200.0 3489.1 49.5 5.5 0.000 4300.0 3554.0 49.5 5.5 0.000 4400.0 3618.9 49.5 5.5 0.000 4500.0 3683.9 49.5 5.5 0.000 4529.9 3703.3 49.5 5.5 0.000 4600.0 3748.8 49.5 5.5 0.000 4700.0 3813.7 49.5 5.5 0.000 4800.0 3878.6 49.5 5.5 0.000 4900.0 3943.5 49.5 5.5 0.000 5000.0 4008.5 49.5 5.5 0.000 5100.0 4073.4 49.5 5.5 0.000 5200.0 4138.3 49.5 5.5 0.000 5300.0 4203.2 49.5 5.5 0.000 5400.0 4268.1 49.5 5.5 0.000 5500.0 4333.0 49.5 5.5 0.000 5600.0 4398.0 49.5 5.5 0.000 5700.0 4462.9 49.5 5.5 0.000 5800.0 4527.8 49.5 5.5 0.000 5900.0 4592.7 49.5 5.5 0.000 6000.0 4657.6 49.5 5.5 0.000 6100.0 4722.6 49.5 5.5 0.000 6200.0 4787.5 49.5 5.5 0.000 6300.0 4852.4 49.5 5.5 0.000 6400.0 4917.3 49.5 5.5 0.000 6500.0 4982.2 49.5 5.5 0.000 6600.0 5047.1 49.5 5.5 0.000 6700.0 5112.1 49.5 5.5 0.000 6800.0 5177.0 49.5 5.5 0.000 6900.0 5241.9 49.5 5.5 0.000 7000.0 5306.8 49.5 5.5 0.000 7100.0 5371.7 49.5 5.5 0.000 7200.0 5436.7 49.5 5.5 0.000 7300.0 5501.6 49.5 5.5 0.000 7400.0 5566.5 49.5 5.5 0.000 7500.0 5631.4 49.5 5.5 0.000 7600.0 5696.3 49.5 5.5 0.000 7700.0 5761.3 49.5 5.5 0.000 7800.0 5826.2 49.5 5.5 0.000 7900.0 5891.1 49.5 5.5 0.000 8000.0 5956.0 49.5 5.5 0.000 8100.0 6020.9 49.5 5.5 0.000 Page 4 OP23- WW02.cfw, 02 -22 -2010: LoadCase 7in Liner (a) , Version wcs- cem453_10 0 • Client : Eni Petroleum Well : 0P23 -WW02 S Schinkrger String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Directional Survey Data MD ND Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 8200.0 6085.8 49.5 5.5 0.000 8300.0 6150.8 49.5 5.5 0.000 8400.0 6215.7 49.5 5.5 0.000 8500.0 6280.6 49.5 5.5 0.000 8600.0 6345.5 49.5 5.5 0.000 8681.5 6398.4 49.5 5.5 0.000 8700.0 6410.4 49.5 5.5 0.000 8797.0 6473.4 49.5 5.5 0.000 8800.0 6475.4 49.5 5.5 0.000 8900.0 6540.3 49.5 5.5 0.000 8951.1 6573.4 49.5 5.5 0.000 8951.1 6573.4 49.5 5.5 0.000 8970.8 6586.2 49.5 5.5 0.000 8976.6 6590.0 49.3 5.5 -3.959 8978.1 6591.0 49.3 5.5 0.000 9000.0 6605.4 48.4 5.5 -4.013 9100.0 6674.3 44.4 5.5 -4.000 9200.0 6748.2 40.4 5.5 -4.000 9239.3 6778.4 38.8 5.5 -3.993 9300.0 6826.5 36.4 5.5 -4.005 9400.0 6909.0 32.4 5.5 -4.000 9500.0 6995.2 28.4 5.5 -4.000 9600.0 7084.7 24.4 5.5 -4.000 9700.0 7177.2 20.4 5.5 -4.000 9800.0 7272.0 16.4 5.5 -4.000 9835.3 7306.0 15.0 5.5 -3.991 9900.0 7368.5 15.0 5.5 0.000 10000.0 7465.1 15.0 5.5 0.000 10100.0 7561.7 15.0 5.5 0.000 10200.0 7658.3 15.0 5.5 0.000 10300.0 7754.9 15.0 5.5 0.000 10400.0 7851.5 15.0 5.5 0.000 10500.0 7948.1 15.0 5.5 0.000 10600.0 8044.7 15.0 5.5 0.000 10700.0 8141.3 15.0 5.5 0.000 10800.0 8237.8 15.0 5.5 0.000 10900.0 8334.4 15.0 5.5 0.000 11000.0 8431.0 15.0 5.5 0.000 11100.0 8527.6 15.0 5.5 0.000 11199.2 8623.5 15.0 5.5 0.000 11200.0 8624.2 15.0 5.5 0.000 11300.0 8720.8 15.0 5.5 0.000 11302.7 8723.5 15.0 5.5 0.000 11400.0 8817.4 15.0 5.5 0.000 11500.0 8914.0 15.0 5.5 0.000 11546.0 8958.5 15.0 5.5 0.000 11600.0 9010.6 15.0 5.5 0.000 11700.0 9107.2 15.0 5.5 0.000 11800.0 9203.8 15.0 5.5 0.000 11900.0 9300.4 15.0 5.5 0.000 12000.0 9397.0 15.0 5.5 0.000 12100.0 9493.6 15.0 5.5 0.000 12167.2 9558.5 15.0 5.5 0.000 12200.0 9590.1 15.0 5.5 0.000 12300.0 9686.7 15.0 5.5 0.000 12317.3 9703.5 15.0 5.5 0.000 12369.0 9753.4 15.0 5.5 0.000 Page 5 OP23- WW02.cfw,02 -22 -2010, LoadCase7in Liner (a }, Version wcs- cem453_10 • • Client : Eni Petroleum Well : 0P23 -WW02 SI rger String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : lin Liner (a) Formation Data MD Frac. Pore Name Lithology (ft) (lb /gal) (lb /gal) 154.0 11.20 9.00 Permafrost Sandstone 1901.0 12.00 9.00 Permafrast Sandstone 5030.0 16.00 9.00 T /Cosh 1 Shale 7249.0 16.00 9.00 Shale 10507.0 16.00 9.00 Shale 12369.0 16.00 9.00 Shale Geothermal Temperature Profile MD ND Temperature Gradient (ft) (ft) (degF) (degF /100ft) 0.0 0.0 20 0.0 1901.0 1869.6 32 0.6 4631.0 3795.9 50 0.8 9035.0 6656.6 95 1.1 12369.1 9780.4 210 1.9 I I Page 6 OP23 -WW02 cfw; O2 -22 -2010 ; LoadCase 71n Liner (a) Version wcs- cem453_10 • • Client : Eni Petroleum Well : 0P23 -WWO2 Schlimlirger String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) ft degF (x 1000) ft _ 0 250 n 9 5 5.0 7.5 -- Geoth.Profile 1 — Hon. Depart. : I 1 1 1111 - — J CN , -1- i hi mil 0 \ I 1---1 co _ El 1 — \- — ; ►' Ui III in by iUi!IFiiIih _ II IU 111 l o (0 ul1lI IIII - , 1 x 11 o— a_ I I I _ _ 1 , III1 - o 11 , { 1 o • , , 0 Lf) Temperature Hori. Departure Section 2: fluid sequence Job Objectives: Zonal Isolation: TOC at Liner Hanger 8,800' MD Original fluid Mud 11.00 lb/gal k : 1.08E -2 Ibf.s ^n /ft2 n : 0.506 Ty : 15.43 lbf/100ft2 Displacement Volume 289.8 bbl Drill Pipe Volume 156.3 bbl Total Volume 433.0 bbl TOC 8800.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (1b/gal) 1 MUDPUSH 11 40.0 817.6 7982.4 13.40 k:2.26E -2 lbf.sAn/ft2 n:0.435 Ty:13.81 lbf/100ft2 Liner Slurry 103.2 3569.0 8800.0 15.80 k:3.93E -3 Ibf.s ^n /ft2 n:0.903 Ty:26.99 lbf/100ft2 Mud 289.8 0.0 11.00 k:1.08E-2 lbf.s^n/ft2 n:0.506 Ty:15.43 Ibf/100ft2 Page 7 OP23- WW02.cfw;02 -22 -2010; LoadCase7 in Liner (a); Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 Schiumberger String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Static Security Checks : Frac 1622 psi at 9087.4 ft Pore 798 psi at 9035.0 ft Collapse 3972 psi at 12289.0 ft Burst 7240 psi at 12289.0 ft Csg.Pump out 73 ton ft (x 1000) psi o _ 0 • 9 - Hydrostatic - - Frac - ----- Pore am - MI o kr) Ill o_ 1111 o _ I CD - o _ o- ■ 0 C - Fluid Sequence Static Well Security+ Section 3: pumping schedule Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl /min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 4.0 40.0 10.0 40.0 80 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 16 -Start Mixing Tail Slurry Liner Slurry 4.0 103.2 25.8 103.2 80 9 -Start Cement Slurry Pause 0.0 0.0 5.0 0.0 80 36 -Drop Dart Mud 7.0 250.0 35.7 250.0 80 19 -Start Displacement Mud 4.0 39.8 10.0 289.8 80 19 -Start Displacement Total 01:31 433.0 bbl hr:mn End Job: Bump Plug; Check floats Dynamic Security Checks : Frac 881 psi at 12369.0 ft Pore 692 psi at 9035.0 ft Collapse 3972 psi at 12289.0 ft Burst 5846 psi at 8800.0 ft Page 8 OP23 -W W02.cfw : 02 -22 -2010: LoadCase 7in Liner (a); Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 Seklimii String : 7 District : Prudhoe Bay, Alaska t Country : US Loadcase : 7in Liner (a) Temperature Results BHCT 157 degF Simulated Max HCT 210 degF Simulated BHCT 117 degF Max HCT Depth 12369.0 ft CT at TOC 108 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time (hr:mn) (hr:mn) Geo. Temp. Top of Cement (degF) (degF) 93 degF Bottom Hole , (degF) (degF) 210 degF O - Cal °. WHP o — Cale. Pump Press. x to to Th_.:,....... 0 20 40 60 80 100 Time (min) o _ Fluids at 12369 ft - -- •. — Acquired 0 Out —Acquired 0 In r - 0 Out '- — • — //r r 0In r till 0 20 40 60 80 100 Time (min) Page 9 OP23- WW02.ctw; 02 -22 -2010 ; LoadCase 7in Liner (a) Version wcs- cem453 10 0 • Client : Eni Petroleum Well : OP23 -WW02 Sekli jj�� l fj 1 String : 7 District : Prudhoe Bay, Alaska {E Country : US Loadcase : 7in Liner (a) * CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : 7" Liner District : Prudhoe Bay, Alaska Country : US Depth = 9035 ft Depth = 12369 ft N. r _ Fore - ra Pore op — — namcatic co namc Hy Hydrostatic u) _ to I d- - ', . co o U 3 N — 1 2 N C 3 : 1 Q r J m Q_I Q_ o O O N 1 . O 0 U c_— ._.._.__ i -7 -.. _— ___.._- , -_ - - -. _ co , , 3 0 20 40 60 80 100 0 20 40 60 80 100 Time (min) Time (min) a 0 Total Depth = 12369.0 ft Top of Cement = 8800.0 ft *Mark of Schlumberger SchlImberpr Page 10 OP23- WW02.cfw ; 02 -22 -2010 ; LoadCase 7in Liner Ial ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 Schlott' bailer String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Section 4: centralizer placement Top of centralization :8800.0 ft Bottom Cent. MD :12364.0 ft Casing Shoe :12369.0 ft NB of Cent. Used :105 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint ( %) (ft) 8849.0 1 1/1 NW- ST- 7 -6 -ST A1A 92.4 8844.0 9969.0 56 2/1 NW- ST- 7 -6 -ST A1A 86.0 9009.0 12369.0 48 4/5 NW- ST- 7 -6 -ST A1A 80.2 9986.5 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) NW- ST- 7- 6 -STA1A 7 9.610 8.232 No Hannover 8.500 442.87 4586.10 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 OD specifications Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer /Formation :0.25 Total Drag Force :24 ton Hook load Down Stroke :98 ton Hook Toad Up Stroke :146 ton / /4� ft =-- 81 :8 92 96 100 Between Cent. - 414 Cent. '1 T -_.. i -- 11 - ■ — 111 1 11 N -1 I I III III I �� � 1111._ ' -- lino AAA _ so , ..- ...t.... -- -., _/ min= 1 i II Pipe Standoff Page 11 OP23- WW02.cfw,02 -22 -2010, LoadCase7in Liner (a): Version wcs- cem453_10 • Client : Eni Petroleum Well : OP23 -WW02 Sc l rger String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) I I Page 12 OP23-WW02.cfw , 02-22-2010 ; LoadCase7 in Liner (a), Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 SchIinrgnr String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) * CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : 7" Liner District : Prudhoe Bay, Alaska Country : US ton ft o 0 25 50 75 100 125 150 — Hooldoad Up \ — — Hooldoad Dow n i \ Weight \ -- -- Drag Force \ 1 l f \ O 1 o 1 \ 1 \ a - 1 \ E I u \ 6 1 \ o I I \ \ > O 1 \ \ F. m O 1 \ \ \ Fa 1 \ 0 1 • 0 o O f o g O 3 Running Forces 2 o Friction Factor = 0.25 Total Depth = 12369.0 ft Top of Cement = 8800.0 ft *Mark of Schlumberger Sch'U ePpr Page 13 OP23- WW02.cfw ; 02 -22 -2010 ; LoadCase 7in Liner (a); Version wcs- cem453_10 • • Client : Eni Petroleum Well : OP23 -WW02 Seib leper String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (al Section 5: WELLCLEAN II Simulator ft 7 01 .5 90 95 100 Std Betty. Cent . - Cement Coverage I I _ 1 .■ U ".■ S ■■�: ■ :i!IIr::::pii L.n II PR — ;■■■ ■ ■; 1 I 1 11 1 1! i ■ 1 riTtrril ' Ti 1 11 I 11 O - 47 Cement Coverage Risk Mud on the Wall Fluids Concentrations z . z° 9000 9000 9000 9000 9500 9500 9500 9500 10000 10000 10000 10004 r 10500 10500 z r 10500 10500 t a a ° 11000 11000 ° ° 11000 11 000 ° 11500 11500 11500 11500 , z000 12000 12000 -t 12000 • 3 • 4 z ° INN Mud I I High ® Low Liner Slurry I I Medium I I None I I MUDPUSH II Page 14 OP23 -V V02.cfw ; 02 -22 -2010 ; LoadCase 7in Liner (al ; Version wcs- cem453_10 • • Client : Eni Petroleum Well : 0P23 -WW02 SI rie1 String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Section 6: fluid description Mud DESIGN Fluid No: 1 Density : 11.00 lb/gal Rheo. Model : HERSCHEL_B. k : 1.08E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.506 Ty : 15.43 lbf/100ft2 Gel Strength : (lbf/100ft2) MUD Mud Type : OBM Job volume : 289.8 bbl Water Type : Fresh VOLUME FRACTION Solids : 4.0 % Oil : 85.0 % Water : 11.0 % MUDPUSH II DESIGN Fluid No: 2 Density : 13.40 lb/gal Rheo. Model : HERSCHEL_B. k : 2.26E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.435 Ty : 13.81 lbf/100ft2 Gel Strength : (lbf/100ft2) Job volume : 40.0 bbl Liner Slurry DESIGN Fluid No: 6 Density : 15.80 lb/gal Rheo. Model : HERSCHEL_B. k : 3.93E -3 lbf.sAn/ft2 At temp. : 80 degF n : 0.903 Ty : 26.99 lbf/100ft2 Gel Strength : (lbf/100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid : 5.081 gal /sk Job volume : 103.2 bbl Dry Density : 199.77 lb /ft3 Yield : 1.16 ft3 /sk Quantity : 497.92 sk Sack Weight : 94 lb Solid Fraction : 41.6 % BASE FLUID Type : Fresh water Density : 8.32 lb /gal Base Fluid : 5.081 gal /sk Additives Code Conc. Function D046 0.200 %BWOC Antifoam D065 0.300 %BWOC Dispersant D153 0.200 %BWOC Antisettling D167 0.350 %BWOC Fluid loss D800 0.300 %BWOC Retarder Page 15 OP23- WW02.cfw,02 -22 -2010; LoadC,ase 7in Liner (a), Version wcs-cem453_10 • 1 Client : Eni Petroleum Well : 0P23 -WW02 S I rger String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Sect 7: operator summary Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl /min) (bbl) (min) (bbl) MUDPUSH II 4.0 40.0 10.0 40.0 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 16 -Start Mixing Tail Slurry Liner Slurry 4.0 103.2 25.8 103.2 9 -Start Cement Slurry Pause 0.0 0.0 5.0 0.0 36 -Drop Dart Mud 7.0 250.0 35.7 250.0 19 -Start Displacement Mud 4.0 39.8 10.0 289.8 19 -Start Displacement Total Pumping Time : 01:31 hr:mn End Job: Bump Plug; Check floats TOTAL MATERIAL REQUIREMENTS Mix Water Requirements : Fresh water 89 bbl MIXING PREPARATION MUDPUSH II Volume : 40.0 bbl Density : 13.40 Ib /gal Code Quantity Design Fresh water 28.459 bbl D046 19.890 Ib 0.200 %BWOW D182 170.757 Ib 6.000 Ib /bbl of base fluid U066 80.000 gal 2.000 gal /bbl of spacer F103 80.000 gal 2.000 gal /bbl of spacer D031 11150.049 Ib 278.75 Ib/bbl of spacer Liner Slurry Volume : 103.2 bbl Density : 15.80 Ib /gal Yield : 1.16 ft3 /sk Dry Phase Liquid Phase Blend : (Ib) Design Mix Water 60.2 bbl 10.0 bbl LAS Design G 46804.348 Ib Fresh water 60.239 bbl 10.001 bbl D046 93.609 Ib 0.200 %BWOC D065 140.413 Ib 0.300 %BWOC D153 93.609 Ib 0.200 %BWOC D167 163.815 Ib 0.350 %BWOC D800 140.413 Ib 0.300 %BWOC Page 16 OP23- WW02.cfw,02 -22 -2010; LoadCase7in Liner Cal , Version wcs- cem453_10 • S Client : Eni Petroleum Well : OP23 -WW02 Sc IIrger String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : 7" Liner District : Prudhoe Bay, Alaska Country : US Annulus ID : 7.000 in - OD : 8.835 in O CD N — Mud NUDPUSHII - Liner Slurry O O u7- O (n a 3 4 � > C O O C O v u7 1.6 2.0 2.4 2.8 32 3.6 4.0 4.4 4.8 5.2 5.6 6.0 6.4 Flow Rate (bbl /min) O ■ Mud Herschel : k = 1.08E-2Ibf.s ^n /ft2 n = 0.506 Ty = 15.43 Ibf /100ft2 MUDPUSH II Herschel : k = 2.26E-2 Ibf.s ^n/ft2 n = 0.435 Ty = 13.81 Ibf /100ft2 II Liner Slurry Herschel : k = 3.93E-3 Ibf.sM/ft2 n = 0.903 Ty = 26.99 Ibf /100ft2 *Mark of Schlumberger SCh'I ePp• Page 17 OP23 -W W02.cfw ; 02 -22 -2010 ; LoadCase 7in Liner (a) ; Version wcs-cem453_10 . 1 nil Petit ice^ O liktok Point OP2 Nikaitchuq Field enn I, WW02 (P5) North Slope - Alaska DIR / LWD FORM DEPTH HOLE CASING MUD INFO WL Logging MWD MD 1 TVD CEMENT SIZE SPECS Hazards Cement to Surface 20 " Hole Angle X -65 0° 20" Conductor Shoe 160' 160' N/A Welded / Driven N/A Quad Combo Surface Csq Dir / PWD 10.7# 13 -3/8" AS LITE 68 Ibs /ft Wellbore Stability Mud Motor L -80, BTC 9.2 -9.6 ppg Lost Circulation Hole Cleaning KOP:958' DLS: 1.5 -2.75 deg /100' 12.0# DeepCrete Hole Angle 50 13 - 3/8" Casing Point 4,631' 3,768' E3" 16" 50 F SPUD Quad Combo Inter. Casing Wellbore Stability 9 -5/8" Lost Circulation Motor 47 lbs/ft 9.2 -9.6 ppg Hole Cleaning L -80, BTC -M Sail Angles: 9-5/8" 50 degrees 47 Ibs /ft 13Cr, Vam Top Ali 15.8# Class G TOL 8,800' 6,475' • Hole Angle f ► 50 9 - 5/8" Casing Point 9,035' 6,628' 12 - 1/4" 95° F LSND Quad Combo Jurassic Wellbore Stability ` •``' Lost Circulation Production Liner Hole Cleaning Sag D 15.8# EEE • 7" smi iiiiiIiiiiiiiiii Class 26Ibs /ft me Motor T/ Ivishak iiiiiiiiiiiiiiii G 13Cr, Vam Top R3 10.5 -11.0 ppg MDT: ^> Kuparuk Jurassic B/ Ivishaq I vishak 7" Liner Hole Angle 15 Proposed TD 12,369' 9,753' 8 -1/2" 210" F MOBM • Formation Integrity And Leak Off Test Procedure Drilling Operations 1. After cementing casing and nippling up BOP Equipment, RIH to top of cement and pressure test the casing to the test pressure specified in the well plan (usually 2500 - 3000 psi) for 30 minutes and record on a chart (AOGCC required casing integrity test). The slowest possible pump rate is preferred to allow detection of leaks. Pump rates of 1/4 to 1 BPM are typical; however, adjust the pump rate to match the test pump capability to maintain a constant pump rate. Record pressures approximately every 1/4 bbl on the Pressure Integrity Test (PIT) Form (you can locate on the drilling N drive). Plot the casing pressure test (volume versus pressure), and indicate how long the pressure is held on the casing. Verify that the test data forms a straight line and there is no air entrained in the mud, or leaks in the system. Repeat the casing pressure test if needed, especially if a straight line cannot be established at the higher test pressures. 2. Drill 20' to 50' of new hole below the casing shoe. 3. Circulate the hole to establish a uniform mud density throughout the system (required for a good downhole pressure test). Pick up into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill string at a rate approximating that used to test the casing in Step No. 1. Lower pump rates are preferred in order to minimize friction pressures losses (especially with long strings of small drillpipe) which are ignored in the calculations; however, adjust the pump rate to match the test pump capability and maintain a constant pump rate. Pump rates between 1/4 and 1 -1/2 BPM are typical, with higher rates applicable to tests conducted with large intervals of open hole. 6. On the PIT Form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure. Record pressures approximately every 1/4 bbl pumped. The data points should initially form a straight line with a similar slope to the casing integrity test as the system compressibility's are similar. Eventually, the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate and the data points will deviate from the straight line. The first, sustained occurrence of this departure is the leak -of point (see Figure 1). Pump an additional 3 bbls after the suspected leak -off point is reached to assure continued decreasing slope on the pressure versus volume plot. If a straight line cannot be established during initial pumping (suggesting a surface leak or air in the system) or a clear leak -off point is not indicated, consider re- running the test. Be sure to bleed all pressure off the system prior to re- running the test. A slightly higher pump rate may be considered if a clear departure is not indicated on the pressure versus volume plot. Small filtration fluid losses can cause a slope change, especially at slow pump rates, and confuse the identification of a more definitive leak off point. Note: If the maximum EMW specified in the wellplan is reached without indication of leak -off, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a leak off test (LOT) 7. Shut down when the leak -off point is observed and 3 bbls of mud have been pumped into the formation. Record the instantaneous shut -in pressure (ISIP). With the pump shut down, monitor and record a 15 second and 30 second shut -in pressure and the shut -in pressures for a minimum of 10 minutes (at 30 second intervals) or until the shut -in pressure stabilizes. Plot the information and record the LOT point or FIT point on the PIT Form. Bleed the pressure off and record the fluid volume recovered if possible. If in doubt of the leak off point, contact the Drilling Superintendent to discuss and evaluate the test. Upon completion of the test, forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the proper Agencies. • • NOTE: Pumping to the leak -off point plus 3 bbls is less critical for casing shoes other than surface casing, but it is important to pump enough to ensure a good LOT and not a spurious departure. 8. Corrective measures will be performed if the open hole pressure integrity fails to meet predetermined standards. The Drilling Supt. is to be notified immediately of any LOT or FIT that results in less than adequate formation integrity as defined in the Well Plan. Do not drill ahead until the inadequate formation integrity is addressed. "1 ' al LOT 1 1 c Maximum Pressure c 1 e c S h V � Formation Oa' Breakdown con Pressure Anticipated Pressure En �/ Fracture I L____ a Leak Off Point 0 o Propagation • t Pressure � Shut In o gwpr 1 o o Fracture • I � o c ,w❑ O Closure ISIP ❑ ❑ ❑ f Pressure Instantaneous ❑ ❑ ❑ ❑ ❑ Y ❑ ❑ ❑ ❑ Shut In Pressure Volume and Shut -in Time • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4 -24 2 12/23/0e JFC JMS Add New Well Conductor OP26 Oliktok fl OLIKTOK 5 O� Point INTAKE DOCK OPP �► THIS 1 MODULE 0¢ P� /5 ;, SURVEY , 0 A _� or N = : ,t,,,..-,,,.., g yea, DS -3R DEW url� /9 SITE 0 STP � - - • OLIKTOK PO1NI MODULES ; ' N' STAGING AREA', T13N, R9E ' . DS-30 � 18 .\ ' • 5 1" SCAi50' 06,30 ..yam : u j 4E 2� 19 LU ? 21) \` ._, J6. STP PAD \ VICINITY MAP o ,.3 \ \ SCALE: 1" = 1 Mile O O 'or o -O \' O , ���0 c, cp or \ .: -o 00.0 "3 096 0 0°__0s`� -0 o ` � o°o o . �' \ Z V 3- P •• \ � y ti 1 O . OLIKTOK \ 0 POINT PAD \ o 0 ,0 \ ll, \ \ \ 0 ) 0 \ / \ \ SEE SHEET 3 FOR NOTES / \ \ / LOUNSBURY \ o Existing Conductor �' • Conductor Asbuilt this survey & assoc� INC. / S RS MINE= EER9 PLANNERS / AREA: MODULE: UNIT: E ■ OLIKTOK POINT PAD nil Petroleum WELL CONDUCTOR �_ =`' ASBUILT LOCATIONS CADD FILE NO. 1 DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80 -d1 I 1 OF 3 I 2 • REV DATE BY CK APP DESCRIPTION REV DAZE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4 -24 2 12/23/08 JFC JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN , AK STATE PLANE (NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'Y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP -I1 6,036,332.70 1,656,791.89 70° 30' 39.015" 149° 51' 57.587" 2,052 1,519 12.1 4.0 OP -12 6,036,328.85 1,656,784.83 70° 30' 38.977" 149° 51' 57.795" 2,056 1,526 12.2 4.0 0P03 -P05 6,036,325.10 1,656,777.76 70° 30' 38.940" 149° 51' 58.004" 2,059 1,533 12.2 4.0 0PO4 -P07 6,036,321.43 1,656,770.69 70° 30' 38.904" 149° 51' 58.212" 2,063 1,541 12.2 3.8 OP05 6,036,317.71 1,656,763.67 70° 30' 38.868" 149° 51' 58.419" 2,067 1,548 12.2 3.7 OP06 6,036,313.96 1,656,756.55 70° 30' 38.831" 149° 51' 58.629" 2,070 1,555 12.2 3.6 OP07 6,036,306.41 1,656,742.45 70° 30' 38.757" 149° 51' 59.045" 2,078 1,569 12.2 3.5 OP08 6,036,302.66 1,656,735.36 70° 30' 38.720" 149° 51' 59.254" 2,082 1,576 12.2 3.5 OP09 6,036,298.90 1,656,728.32 70° 30' 38.683" 149° 51' 59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70° 30' 38.647" 149° 51' 59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70° 30' 38.610" 149° 51' 59.878" 2,093 1,597 12.2 3.8 OP12 6,036,287.63 1,656,707.14 70° 30' 38.573" 149° 52' 00.086" 2,097 1,604 12.2 4.0 OP13 6,036,276.37 1,656,685.97 70° 30' 38.463" 149° 52' 00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70° 30' 38.426" 149° 52' 00.920" 2,112 1,633 12.2 3.5 OP15 6,036,268.88 1,656,671.79 70° 30' 38.389" 149° 52' 01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70° 30' 38.353" 149° 52' 01.337" 2,119 1,647 12.2 3.3 OP17 6,036,261.36 1,656,657.70 70° 30' 38.316" 149 52' 01.645" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70° 30' 38.279" 149° 52' 01.753" 2,127 1,681 12.2 3.1 OP19 6,036,250.09 1,656,636.50 70° 30' 38.205" 149° 52' 02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246.31 1,656,629.41 70° 30' 38.168" 149° 52' 02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70° 30' 38.132" 149° 52' 02.586" 2,141 1,889 12.2 1.9 OP22 6,036,238.82 1,656,615.39 70" 30' 38.095" 149° 52' 02.793" 2,145 1,696 12.2 1.7 OP23 6,036,235.05 1,656,608.27 70° 30' 38.058" 149° 52' 03.003" 2,149 1,703 12.2 1.5 OP24 6,036,231.36 1,656,601.27 70° 30' 38.022" 149° 52' 03.209" 2,153 1,710 12.2 1.3 I DISPOSAL WELLS 1 1 AK STATE PLANE (NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'Y' 'x NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP25 6,036,004.35 1,656,510.91 70° 30' 35.791" 149° 52' 05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70° 30' 35.867" 149° 52' 05.456" 2,372 1,787 12.2 -2.7 ...,W LOUNSBURY & ASSOCIATES, INC. SORVEYORS ENGINEERS PLANNERS . AREA: MODULE: UNIT: ■ ((fi� -I I- r OLIKTOK POINT PAD CI�III Pet WELL CONDUCTOR f 1n8 ASBUILT LOCATIONS CADD FILE NO. I DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80 -di 2 OF 3 I 2 a REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4 -24 2 12/23/Oe JFC JMS *Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L -2539 FOR NA027 INFORMATION. .................. SURVEYOR'S CERTIFICATE „ ; � ,• �, 1 • I HEREBY CERTIFY THAT ! AM PROPERLY .' ' * �� REGISTERED AND LICENSED TO PRACTICE , - ' TO LAND SURVEYING IN THE STATE OF 0 "' : ALASKA AND THAT THIS PLAT REPRESENTS I cc` J. ROOKUS I &/ I A SURVEY DONE BY ME OR UNDER MY . ♦'� ' :, LS - 8O3 ,pp ,s� DIRECT SUPERVISION AND THAT ALL S •• ''t�,,,,, ,fiv✓•••• p • DIMENSIONS AND CORRECT AS OF DECEMBER 23, 2008. ', itM \∎`tom •• • `• LOUNSBURY & ASSOCIATES, INC. VRYEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: _ Eni Petroleum WELL O CONDUCTOR Bo D Boll ASBUILT LOCATIONS CADD FILE NO. I DRAWING NO: N 6.80-di I PART: I REV: LK680D1 10/9/08 3 OF 3 2 • • Page 1 of 2 Schwartz, Guy L (DOA) From: Longo Joseph [joe.longo @enipetroleum.com] Sent: Wednesday, March 03, 2010 9:28 AM To: Schwartz, Guy L (DOA) Cc: Brink Jason Subject: RE: OP23 -WW02 (PTD 209 -032) Guy, The completion will consist of a Chrome shrouded ESP. We are going to shroud the ESP in chrome 7 -5/8" which will sting into the 7" liner hanger packer assembly. This will not allow flow to the inner annulus and mitigate the need to run a full string of chrome 9 -5/8 ", the bottom —300' of the 9 -5/8" Intermediate string will be 13Cr. We will be running Chrome 4 -1/2 ", 12.6 #, Vam Top Production Tubing. Currently we are planning on taking MDT Pressures and Samples of the Kuparuk and Jurassic sands in the OP23- WW02PB1 well bore. When we reach TD of OP23 -WW02 we are planning on taking MDT pressures and samples in the Ivishak. Currently we are planning on running these drill pipe conveyed. Once the well is cased we are planning on running a VSP if time allows for vibe trucks to get on the ice. If you need any further clarification please do not hesitate to ask. Regards, Joseph Longo Drilling Engineer Eni US Operating Co. Inc Anchorage, AK Office: (907) 865 -3323 Cell: (907) 947 -4323 Email: Joseph.Longo@enipetroleum.com From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Wednesday, March 03, 2010 8:04 AM To: Brink Jason Cc: Longo Joseph Subject: RE: OP23 -WW02 (PTD 209 -032) Jason /Joseph: I also noticed on the procedure several E -line rig -ups. Can you detail what logs are planned to be run on each of the rig -ups? Thanks in advance, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Tuesday, March 02, 2010 4:04 PM To: 'Brink Jason' Subject: OP23 -WW02 (PTD 209 -032) Jason, 3/3/2010 • • Page 2 of 2 There is very little detail on the ESP completion in the PTD. Do you have a packer planned ? Tubing size etc. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. I I 3/3/2010 • • TRANSMITTAL LETTER CHECKLIST WELL NAME A 4 / l �' l C E�� �_� - t,V(Vc z (31< PTD# 20 27,0 Development t Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: / /�� C <4� E ' POOL: /�/ `K �t I ti )61 i Circle Appropriate Letter / Paragraphs to be Included in Transmittal Lette CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , Permit No. (If last two digits in API No. . Production / injection should API number are continue to be reported as a function of the original API number between 60 -69) stated above. PILOT HOLE In accordance with 20 AAC 25.005(D, all records, data and logs acquired fort pilot hole must beclp41y differentiated in both well name (�(, t4 CV W Vti ZPH) and API number (50- 6 - L9 - 0.341// from records, data an logs acquired f o r well a/, ' f l � � � 2 k(l ( ) 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. Should conventional core be acquired in this well, representative chip samples from each foot of core must be submitted to the Commission in accordan with 20 AAC 25.071. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed 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 program. Rev: 2/1/2010 k,,` ; e .Field & Pool NIKAITCHUQ, IVISH UNDEF WTRSP - 561125 Well Name: NIKAITCHUQ OP23 -WW02 Program SER Well bore seg ❑ PTD #:2090320 Company ENI PETROLEUM Initial Class/Type SER / 1WINJ GeoArea 890 Unit 11400 On /Off Shore On Annular Disposal Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surface loc in ADL 373301; passes thru ADL 355024; top water supply interval & TD in ADL 390616 3 Unique well name and number Yes 4 Well located in a defined pool No NIKAITCHUQ, IVISH UNDEF WTRSP - 561125; Ivishak formation water source well. 5 Well located proper distance from drilling unit boundary Yes Top of water supply interval will lie within ENI 100% lease, >500' from external boundary of Nikaitchuq Unit. 6 Well located proper distance from other wells Yes Only Ivishak well in Section 32. 7 Sufficient acreage available in drilling unit Yes 1 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 113 Can permit be approved before 15-day wait Yes FD 3/2/2010 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For Yes OPO4 -P07 • 15 All wells within 1/4 mile area of review identified (For service well only) Yes I16 Pre - produced injector: duration of pre production Less than 3 months (For service well only) No I 17 Nonconven, gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 18 Conductor string provided Yes Engineering 119 Surface casing protects all known USDWs NA All aquifers exempted, 40 CFR 147.102 (b)(3). 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No 22 CMT will cover all known productive horizons Yes 7 liner cemented back to tieback. 123 Casing designs adequate for C, T, B & permafrost Yes I24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well. '25 If a re-drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Traveling cylinder path calculated. I27 If diverter required, does it meet regulations Yes Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum anticipated formation pressure 10.5 EMW. MW planned up to 11.0 ppg. GLS 3/2/2010 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP calculated at 3693 psi. 5000 psi BOP test planned. 31 Choke manifold complies w /API RP -53 (May 84) Yes • 1 32 Work will occur without operation shutdown No Well will be idle until facilities are in place and started up. 33 Is presence of H2S gas probable No H2S is not reported in this area. Rig equipped with sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA Although this is a service well, it is a water supply well. 35 Permit can be issued w/o hydrogen sulfide measures Yes Geology 1 136 Data presented on potential overpressure zones Yes Expected pressure in Sag is 10.5 ppg EMW, 9.8 ppg in Ivishak, 10.2 ppg in Kup. Will be drilled with 10.5 -11.0 Appr Date 37 Seismic analysis of shallow gas zones NA ppg mud. Gas hydrates may be encountered. Mitigation measures in Drilling Hazards Summary. SFD 3/2/2010 38 Seabed condition survey (if off-shore) NA 139 Contact name /phone for weekly progress reports [exploratory only] NA ■ Geologic Engineering Pub ' Ivishak formation water supply well. Commissioner: Date: Commissioner Date Comm ' Date RE- ISSUE: due to change of landing point and TD. SFD 3/2/2010 DTS CPF //c:, JK 11111 " . a ''ry" -7 III 111 1\ ''' i r t t 0 LF µ , y I L /k L P \\ � ) IA\ SARAH PALIN, GOVERNOR ALASKA OIL AND GAS d / 333 W 7th AVENUE, SUITE 100 CONSERVATION COMl1IISSION � / PHONE 907)279-1433 FAX (907) 276 -7542 Maurizio Grandi Well Operation Project Manager ENI US Operating Co. Inc. 3800 Centerpoint Dr. Ste 300 Anchorage AK 99503 Re: Nikaitchuq Field, Ivishak Undefined Water Supply Pool, OP23 -WW02 ENI US Operating Co. Inc. Permit No: 209 -032 Surface Location: 3130' FSL, 1704' FEL, S5, T13N, R9E, UM Bottomhole Location: 1070' FSL, 807' FEL, S32, T14N, R9E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced service 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, , Daniel T. Seamount, Jr. Chair DATED this 25 day of March, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. • le RECEIVED STATE OF ALASKA A / 0 FEB 2 3 2009 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska 011 & Gas Cons. Commissicr, 20 MC 25.005 Anchorage 1a. Type of Work: 1b. Current Well Class: Exploratory ❑ Development Oil ❑ 1c. Specify if well is proposed for: Drill Q Re -drill ❑ Stratigraphic Test ❑ Service El . Development Gas ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -entry ❑ Multiple Zone ❑ Single Zone ❑ Shale Gas ❑ 2. Operator Name: 5. Bond: LJ Blanket ❑ Single Well 11. Well Name and Number: ENI US Operating Co. Inc. Bond No. RLB0008627 . OP23 - WW02 . 3. Address: 6. Proposed Depth: 12. Field /Pool(s): / 3800 Centerpoint Drive Suite 300, Anchorage 99503 MD: 10507' TVD: 9754' Nikaitchuq / Ivishak /(' Cc 4a. Location of Well (Governmental Section): 7. Property Designation: 4 )71::: S r ,Scj SHL: 3130 FSL 1704 FEL S5 T13N R9E UM ADL 373301, 355024, 390616 >' ° / 7, " Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 902 FSL 855 FEL S32 T14N R9E UM ADL 417493 4/1/2009 ' Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1086' FSL BHL:1070 FSL 807 FEL S32 T14N R9E UM 1,280' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x 516577 . y 6036483.06 ' Zone 4 (Height above GL): 53.2 Well within Pool: NA - 16. Deviated wells: Kickoff depth: 400' MD ft. , 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 35.55° Downhole: 4704 psig • Surface: 3742 psig ' 18. Casing Program Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X -65 Welded 118 36 36 154 154 pre - installed 16" 13 -3/8" 68 L -80 BTC 4190 35 35 4225 3703 Lead 695sk - Arctic Sel Lite 10.7ppg/ 4.33 ft3 /sk Tail 218sk - DeepCRETE 12ppg/ 1.61 ft3 /sk 12.25" 9 -5/8" 47 L -80 BTCM 6916 33 33 6949 6372 365sk - Class "G" 15.8ppg/ 1.16 ft3 /sk 12.25" 9 -5/8" 47 13CrL80 Vam Top 300 6949 6372 7249 6573 8.5" 7" 26 13CrL80 Vam Top 3458 7049 6378 10507 ' 9754 484sk - Class "G" 15.8ppg/ 1.16ft3/sk 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor /Structural Surface Intermediate Production Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ❑ BOP Sketch IO Drilling Program 0 Time v. Depth Plot ❑ Shallow Hazard Analysis 0 Property Plat CI Diverter Sketch 151 Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements SI 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joseph Longo @ 907 865 - 3323 Printed Name Maurizio Grandi Title Well Operation Project Manager /� Signature 0 Phone (907) 865 -3320 Date 2/20/2009 Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ,79 39 C ) L - 50- J c�4 2,73 (r .- d Date: • 5. O (/' for other requirements Conditions �� be used Si of approval : If box is checked, well may not bd to explore for, test, or produce coalbed mthea , gas h drates, or gas contained in shales: 9+V O \t�∎V∎CIN' C.S �\- Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No Other :i� 12S rfteasures: Yet ❑ No [ Directional svy req'd: Yes [l No 9 3 0 ps i t`i■\'.. �.�tt+..c1.v."\.tSc . r C .T r'> 5A�N. CIN, 4 = ' 1 Sys, 3 /z---5 � / APPROVE) to THE COMMISSION DATE: COMMISSIONER Form 10 -401 Revised 12/200 ! } 1 Submit in Duplicate A 3. / 7 -6`' • . R ECEIV ED Alaska pit & Gas Eni Petroleum Cons. Commission Anchora 3800 Centerpoint Drive Suite 300 Anchorage, Alaska 99503 Maurizio Grandi Phone (907) 865 -3320 Email: Maurizio .Grandi @enipetroleum.com February 19, 2009 Alaska Oil and Gas Conservation Commission 333 West 7` Avenue, Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill Producer OP23 -WW02 Dear Commissioners, ENI US Operating Co. Inc. hereby applies for a Permit to Drill for the onshore Water Source well OP23- WW02. The well will be drilled and completed using Nabors rig 245E. The planned spud date for OP23- WW02 is March 25, 2009. ENI US Operating Co. Inc. would like to request a Two (2) Week BOP Test schedule for OP23 -WW02 and all subsequent wells. Please advise if this is satisfactory and how to proceed. Please find attached for the review of the Commission forms 10 -401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information, please contact Joseph Longo at 907 - 865 -3323 or Jason Brink at 907 - 865 -3321. Sincerely, t1.7 $..4)4.....1 Maurizio Grandi Well Operation Project Manager • • Application for Permit to Drill, Well OP23 -WW02 Eni Petroleum Final Version 20-Feb-09 Application for Permit to Drill Document Water Source OP23 -WW02 Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005 (0 3 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) 3 Please see Attachment 7: Surface Platt 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 AAC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005 (c)(4) 4 5. Procedure for Conducting Formation Integrity Tests 4 Requirements of 20 AAC 25.005 (c)(5) 4 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 5 7. Diverter System Information 6 Requirements of 20 AAC 25.005(c)(7) 6 8. Drilling Fluid Program 6 Requirements of 20 AAC 25.005(c)(8) 6 Surface Hole Mud Program (Fresh Water Spud Mud) 6 12 -1/4 "Intermediate Hole Mud Program (LSND) 7 8 -1/2 "Production Hole Mud Program (LSND) 7 9. Abnormally Pressured Formation Information 7 Requirements of 20 AAC 25.005 (c)(9) 7 10. Seismic Analysis 7 Requirements of 20 AAC 25.005 (c)(10) 7 11.Seabed Condition Analysis 7 Requirements of 20 AAC 25.005 (c)(11) 7 12. Evidence of Bonding 7 OP23 -WW02 PERMIT Page 1 of 9 Printed: 20- Feb -09 • • Application for Permit to Drill, Well 01323-MO2 i Petr oeum Fi nal Version 20-Feb-09 tni Requirements of 20 AAC 25.005 (c)(12) 7 13. Proposed Drilling Program 8 Requirements of 20 AAC 25.005 (c)(13) 8 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 Requirements of 20 AAC 25.005 (c)(14) 9 15. Attachments 9 Attachment .1 Directional Plan 9 Attachment 2 Drilling Hazards Summary 9 Attachment 3 BOP and Diverter Configuration 9 Attachment 4 Cement Loads and CemCADE Summary 9 Attachment 5 Well Schematic 9 Attachment 6 Formation Integrity And Leak Off Test Procedure 9 Attachment 7 Surface Platt 9 1 OP23 -WW02 PERMIT Page 2 of 9 Printed: 20- Feb -09 1 • Application for Permit to Drill, Well OP23 -WW02 En Final Version 20- Feb -09 ent 1. Well Name Requirements of 20 AAC 25.005 (0 Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC25.040(b). Fora well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as OP23 -WW02. 2. Location Summary Requirements o f 2 0 AAC 25, 005(c) (2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3130 FSL 1704 FEL S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.2' AMSL Northings: 6,036,483' • Eastings: 516,577' ' Pad Elevation 12.2' AMSL • Location at Top of Ivishak 902 FSL 855 FEL S32 T14N R9E UM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9,692' Northings: 6,039,535' Eastings: 517,409' Total Vertical Depth, RKB: 8,958' Total Vertical Depth, SS: 8,905' Location at Total Depth 1070 FSL 807 FEL S32 T14N R9E UM ASP Zone 4 NAD 27Coordinates Measured Depth, RKB: 10,507' Northings• Eastings: 517,456' Total Vertical Depth, RKB: 9,754' Total Vertical Depth, SS :: 9,700' Please see Attachment 7: Surface Platt and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application fora Permit to Drill (Form 10 -401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed we //bore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed welibore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. OP23 -WW02 PERMIT Page 3 of 9 Printed: 20- Feb -09 • • Application for Permit to Drill, Well OP23 -WW02 Eni F inal Version 20- Feb -09 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the fo /lowing items, except for an item a /ready on file with the commission and identified in the application; (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; Please see Attachment 3: BOP and Diverter Configuration 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downho/e pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; Expected Reservoir Pressures: Formation TVDss Pressure (psi) Gradient (psi /ft) Kuparuk 7254 3576 0.49 . Sag River 8701 4704 • 0.54 Ivishak 9329 4499 0.48 The highest expected reservoir pressure is in the Sag River Formation. At a depth of 9329' TVDss a 0.54 psi /ft gradient is expected or a 10.4 ppg EMW (equivalent mud weight). v The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient and methane gradient of (0.11): MPSP = (8701 TVDss)(0.54 - 0.11 psi /ft) = 3742 psi (5) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormal /y geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application; (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); Please see Attachment 6: Formation Integrity And Leak Off Test Procedure OP23 -WW02 PERMIT Page 4 of 9 Printed: 20- Feb -09 • • Application for Permit to Drill, Well 0P23 -WW02 Eni Petroleum Final Version 20- Feb -09 nr em 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An applicat /on for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre - perforated liner, or screen to be installed; OP23 -WW02 PERMIT Page 5 of 9 Printed: 20- Feb -09 • • Application for Permit to Drill, Well OP23 -WW02 Final Version r0}! 20- Feb -09 au Casing and Cementing Program See also Attachment 4: Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TYD MD/TVD OD (in) (in) (Ib/ft) Grade Connection (ft) (ft) (ft) Cement Program 20 N/A 178.89 X -65 Welded 118 36' / 36' 154' / 154' pre - installed Lead 695sk - Arctic Sel Lite 13 -3/8 16 68 L -80 BTC 4190' 35' / 35' 4225' / 3703' 10.7ppg/ 4.33 ft3 /sk Tail 218sk - DeepCRETE 12ppg/ 1.61 ft3 /sk 9 -5/8 12 -1/4 47 L -80 BTC -M 6916' 33' / 33' 6949' / 6372' 365sk - Class "G" 15.8ppg/ 1.16 ft3 /sk 9 -5/8 12 -1/4 47 13CrL80 Vam Top 300' 6949' / 6372' 7249' / 6573' 7" 8 -1/2 17 L -80 Vam Top 3458' 7049' / 6378' 10507' / 9754' 484sk -Class "G" 15.8ppg/ 1.16ft3 /sk 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please see Attachment 3: BOP and Diverter Configuration A 21 -1/4 ", 2000 psi diverter with a 16" diameter diverter line and valve will be the diverter system used for drilling the surface hole. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (Fresh Water Spud Mud) Seud to Base of Permafrost Base of Permafrost to Casing Point Initial Value Final Value Initial Value Final Value Density (PPg) 8.6 9.2 9.2 9.6 • runnel viscosity (seconds) 250 250 150 200 Yield Point 35 45 45 60 (Ib/ 100 sf) Plastic Viscostiy (CP) 30 55 30 55 pH 9 9.5 9 9.5 API Filtrate NC 8 < 6.0 < 6.0 (cc / 30 min)) OP23 -WWO2 PERMIT Page 6 of 9 Printed: 20- Feb -09 • • Application for Permit to Drill, Well OP23 -WW02 Eni Petr oleum Fi Version 20- Feb -09 em 12 -1/4" Intermediate Hole Mud 8 -1/2" Production Hole Mud Program Program (LSND) (LSND) 13 -3/8" Csg Shoe to 9 -5/8" Csg Point 9 -5/8" Csg Point to 7" Csg Point Value Value Density (ppg) 9.2 -9.9 Density (ppg) 10.0 -10.7 Plastic Viscostiy 12 -22 Plastic Viscostiy (CP) 12 -18 (CP) Yield Point 18 -28 Yield Point 18 -24 (lb/100 sf) (lb/100 sf) API Filtrate API Filtrate 4 - 6 < 6 (cc / 30 min) (cc / 30 min) pH 9.0 -10.0 pH 9.0 -10.0 MBT < 18.0 MBT < 18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An appl /cation for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10.Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom- founded structure, jack -up rig, or floating dri /ling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item a /ready on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding }have been met; Evidence of bonding for ENI is on file with the Commission. OP23 -WW02 PERMIT Page 7 of 9 Printed: 20- Feb -09 1 Application for Permit to Drill, Well OP23 -WW02 ��xx r ern Eni 13. Proposed Drilling Program Requirements of 20 AAC25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematic. 1. Move in / rig up Nabors 245E. Install 21 -1/4" Annular with 16" diverter line and function test. 2. Spud and directionally drill 16" hole to casing point at +/- 4,225' MD / 3,703' TVD as per directional plan. Run Gyro and MWD tools as required for directional monitoring. 3. Run and cement 13 -3/8 ", 68 #, L80, BTC casing to surface. Displace cement with mud, hold 500 psi over circulating pressure. Perform top job if required. 4. Remove diverter system, install and test wellhead to 5000 PSI. 5. Nipple up 13 -5/8" 5K BOP and test to 5000 PSI. Notify AOGCC 24 hrs before test. 6. Pressure test casing to 2500 psi for 30 minutes and record results. 7. PU 12 -1/4" bit and 8" directional drilling assembly with MWD, LWD and PWD. 8. Drill out cement and between 20' and 50' of new hole. Perform Leak Off Test, recording results. 9. Directionally drill to 9 -5/8" casing point at 7,249' MD / 6,573' TVD. Pull out of hole backreaming to the surface casing shoe. 10. Run and cement 9-5/8 ", 47# L80, BTC Mod casing to surface (Chrome 9 -5/8 ", 13CrL80 Vam Top Casing will be run throughout the 7" liner lap). Pump cement and displace with mud, land casing hanger and bump plug. 11. Install 9 -5/8" packoff and test to 5000 psi. 12. Flush 13 -3/8" x 9 -5/8" annulus with water, followed by diesel. 13. Pressure test casing to 3000 psi per AOGCC regulations. Record results. 14. PU 8 -1/2" bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 15. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. 16. Directionally drill 8 -1/2" hole to TD at +/- 10,507' MD / 9,754' TVD as per directional plan. 17. RU run wire line logs. 18. PU and run 7 ", 26# 13CrL80, Vam Top Liner to TD. 19. Land liner, set liner hanger with 200' Liner lap inside the 9 -5/8" intermediate casing. POOH laying down DP as required. 20. Test casing and liner to 3000 psi and record. 21. Run cased hole wire line logs and perforate. 22. PU ESP completion as required and RIH to depth, before landing tubing spot corrosion inhibited brine throughout entire inner annulus. Sting into liner top and test backside. Land tubing. Set BPV 23. Nipple down BOP, nipple up tree and test. Pull BPV. 24. Shear Shear out valve and Freeze protect well with diesel. 25. Set BPV and move rig off. OP23 -WW02 PERMIT Page 8 of 9 Printed: 20- Feb -09 • Application for Permit to Drill, Well OP23 -WW02 • En 20- Feb -09 ern 26. Rig up wire line unit. Pull BPV. 27. Set dummy valve in mandrel. Use ESP to clean up well. 28. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of dril ling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of by injection down an Oliktok Point Class I disposal well or by hauling the fluids to the Prudhoe Bay Grind and Inject Facility. All cuttings generated will be disposed of either down an Oliktok Point Class I grind and inject disposal well or hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 BOP and Diverter Configuration Attachment 4 Cement Loads and CemCADE Summary Attachment 5 Well Schematic Attachment 6 Formation Integrity And Leak Off Test Procedure Attachment 7Surface Platt OP23 -WW02 PERMIT Page 9 of 9 Printed: 20- Feb -09 Eni Petroleum Schlumberger OP23 -WW02 (P3b) Proposal Report Date: February 19, 2009 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: ENI Vertical Section Azimuth: 15.400° Field: Nikaitchuq Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: Oliktok Point / OP23 '� Study TVD Reference Datum: Rotary Table Well: OP23 -WW02 ���1 TVD Reference Elevation: 53.20 ft relative to MSL , Borehole: 0P23 -WW02 Sea Bed 1 Ground Level Elevation: 12.20 ft relative to MSL • UWIIAPI0: 50029 � Magnetic Declination: 22.278° Survey Name l Date: OP23 -WW02 (P3b) / February 19, 2009 Total Field Strength: 57682.293 nT Tort I AHD 1 DDI 1 ERD ratio: 61.078° / 3353.47 ft / 5.344 / 0.344 Magnetic Dip: 80.932° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: April 19, 2009 Location LatlLong: N 70.51086102, W 149.86435227 Magnetic Declination Model: BGGM 2008 Location Grid NIE YIX: N 6036483.060 ftUS, E 516576.840 ftUS North Reference: True North . Grid Convergence Angle: +0.12787579° Total Corr Mag North a True North: +22.278° • Grid Scale Factor: 0.99990031 Local Coordinates Referenced To: Well Head Measured Vertical Ma I Grev Directional Comments Inclination Azimuth Sub Sea TVD TVD NS EW DLS Northing EasBn Latitude Longitude 9 9 9 Depth Section Tool Face Difficulty (ft) I (deg) I (deg) (ft) I (ft) I (ft ) I (ft ) I (ft ) I (deg) (deg/100ft) Index (ftUS) (ftUS) RTE 0.00 0.00 340.00 -53.20 0.00 0.00 0.00 0.00 -- 0.00 0.00 6036483.06 516576.84 N 70.51086102 W 149.86435227 WRP 41.00 0.00 340.00 -12.20 41.00 0.00 0.00 0.00 - 0.00 0.00 6036483.06 516576.84 N 70.51086102 W 149.86435227 20" Conductor 154.20 0.00 340.00 101.00 154.20 0.00 0.00 0.00 - 0.00 0.00 6036483.06 516576.84 N 70.51086102 W 149.86435227 KOP Bld 1.5/100 400.00 0.00 340.00 346.80 400.00 0.00 0.00 0.00 340.00M 0.00 0.00 6036483.06 516576.84 N 70.51086102 W 149.86435227 Bld 2/100 500.00 1.50 340.00 446.79 499.99 1.07 1.23 -0.45 340.00M 1.50 0.29 6036484.29 516576.39 N 70.51086438 W 149.86435593 600.00 3.50 340.00 546.69 599.89 4.62 5.33 -1.94 340.00M 2.00 1.30 6036488.38 516574.89 N 70.51087557 W 149.86436814 700.00 5.50 340.00 646.37 699.57 11.02 12.70 -4.62 HS 2.00 1.87 6036495.75 516572.19 N 70.51089571 W 149.86439009 SV4 728.77 6.08 340.00 675.00 728.20 13.38 15.43 -5.62 HS 2.00 2.00 6036498.47 516571.19 N 70.51090316 W 149.86439821 800.00 7.50 340.00 745.73 798.93 20.24 23.34 -8.49 HS 2.00 2.27 6036506.38 516568.29 N 70.51092477 W 149.86442177 Cry 3/100 900.00 9.50 340.00 844.62 897.82 32.29 37.23 -13.55 47.43R 2.00 2.58 6036520.25 516563.21 N 70.51096272 W 149.86446313 SV3 961.34 10.83 347.23 905.00 958.20 41.50 47.60 -16.55 40.32R 3.00 2.76 6036530.62 516560.18 N 70.51099106 W 149.86448772 1000.00 11.74 350.92 942.91 996.11 48.28 55.03 -17.98 36.70R 3.00 2.86 6036538.04 516558.74 N 70.51101135 W 149.86449936 1100.00 14.25 358.22 1040.35 1093.55 69.30 77.38 -19.97 29.58R 3.00 3.10 6036560.39 516556.70 N 70.51107242 W 149.86451563 1200.00 16.93 3.31 1136.67 1189.87 95.31 104.23 -19.51 24.68R 3.00 3.30 6036587.23 516557.10 N 70.51114575 W 149.86451 SV2 1229.68 17.74 4.53 1165.00 1218.20 103.97 113.05 -18.90 23.51R 3.00 3.36 6036596.06 516557.69 N 70.51116985 W 149.86450 1300.00 19.69 7.03 1231.60 1284.80 126.22 135.49 -16.60 21.15R 3.00 3.48 6036618.50 516559.94 N 70.51123116 W 149.86448812 1400.00 22.51 9.86 1324.89 1378.09 161.95 171.08 -11.26 18.51R 3.00 3.64 6036654.10 516565.20 N 70.51132839 W 149.86444443 1500.00 25.38 12.08 1416.27 1469.47 202.41 210.91 -3.50 16.48R 3.00 3.78 6036693.94 516572.87 N 70.51143719 W 149.86438092 1600.00 28.26 13.87 1505.51 1558.71 247.48 254.86 6.66 14.87R 3.00 3.91 6036737.91 516582.93 N 70.51155726 W 149.86429776 1700.00 31.17 15.36 1592.35 1645.55 297.04 302.81 19.20 13.58R 3.00 4.03 6036785.88 516595.36 N 70.51168826 W 149.86419519 SVI 1780.08 33.51 16.38 1660.00 1713.20 339.88 344.02 30.92 12.72R 3.00 4.12 6036827.11 516606.99 N 70.51180082 W 149.86409923 1800.00 34.10 16.62 1676.55 1729.75 350.96 354.64 34.07 12.52R 3.00 4.14 6036837.74 516610.12 N 70.51182984 W 149.86407348 End Cry 1849.56 35.55 17.17 1717.23 1770.43 379.24 381.72 42.30 -- 3.00 4.19 6036864.83 516618.28 N 70.51190382 W 149.86400616 Top UGNU (UG4) 2160.23 35.55 17.17 1970.00 2023.20 559.78 554.29 95.62 - 0.00 4.37 6037037.50 516671.22 N 70.51237525 W 149.86356982 UG2 Coal Bed Marker 2744.03 35.55 17.17 2445.00 2498.20 899.04 878.58 195.83 - 0.00 4.58 6037361.98 516770.69 N 70.51326116 W 149.86274978 L UGNU 3567.51 35.55 17.17 3115.00 3168.20 1377.57 1336.00 337.17 - 0.00 4.77 6037819.67 516911.00 N 70.51451076 W 149.86159297 Schrader Bluff 3825.62 35.55 17.17 3325.00 3378.20 1527.56 1479.37 381.48 - 0.00 4.82 6037963.13 516954.98 N 70.51490242 W 149.86123036 Top N Sand 3899.36 35.55 17.17 3385.00 3438.20 1570.41 1520.34 394.13 - 0.00 4.83 6038004.12 516967.54 N 70.51501433 W 149.86112675 WellDesign Ver SP 2.1 Bld( doo40x_100) OP23 \0P23- WW02\OP23- WW02\OP23 -WW02 (P3b) Generated 2/19/2009 3:22 PM Page 1 of 2 Measured Vertical Mag /Gray Directional Comments Inclination Azimuth Sub -Sea TVD TVD NS EW DLS Northing Easting Latitude Longitude Depth Section Tool Face Difficulty (ft) (deg) (deg) (ft) (ft) (ft) I (ft) I (ft) (deg) (deg/100ft) Index (ftUS) (ftUS) Base N Sand 3954.67 35.55 17.17 3430.00 3483.20 1602.55 1551.06 403.63 - -- 0.00 4.84 6038034.86 516976.96 N 70.51509826 W 149.86104905 Target 4089.87 35.55 17.17 3540.00 3593.20 1681.12 1626.16 426.83 - -- 0.00 4.86 6038110.00 517000.00 N 70.51530341 W 149.86085910 Top OA Sand 4089.88 35.55 17.17 3540.01 3593.21 1681.13 1626.16 426.84 - 0.00 4.86 6038110.01 517000.00 N 70.51530343 W 149.86085908 Base OA Sand 4139.03 35.55 17.17 3580.00 3633.20 1709.69 1653.47 435.27 -- 0.00 4.87 6038137.32 517008.38 N 70.51537802 W 149.86079002 4224.82 35.55 17.17 3649.80 3703.00 1759.54 1701.12 450.00 - -- 0.00 4.89 6038185.01 517022.99 N 70.51550820 W 149.86066949 13 -3/8 "Csg 4224.83 35.55 17.17 3649.81 3703.01 , 1759.55 1701.13 450.00 - 0.00 4.89 6038185.01 517023.00 N 70.51550822 W 149.86066947 Cry 2/100 4244.82 35.55 17.17 3666.07 3719.27 1771.16 1712.23 453.43 179.19L 0.00 4.89 6038196.12 517026.40 N 70.51553855 W 149.86064139 4300.00 34.44 17.14 3711.28 3764.48 1802.80 1742.47 462.77 179.17L 2.00 4.91 6038226.38 517035.67 N 70.51562115 W 149.86056497 4400.00 32.45 17.09 3794.71 3847.91 1857.88 1795.14 478.99 179.12L 2.00 4.94 6038279.08 517051.77 N 70.51576504 W 149.86043219 4500.00 30.45 17.03 3880.02 3933.22 1910.03 1845.01 494.29 179.07L 2.00 4.98 6038328.98 517066.96 N 70.51590127 W 149.86030691 4600.00 28.45 16.96 3967.10 4020.30 1959.16 1892.02 508.66 179.01L 2.00 5.01 6038376.02 517081.23 N 70.51602970 W 149.86018928 4700.00 26.45 16.88 4055.84 4109.04 2005.24 1936.11 522.08 178.94L 2.00 5.04 6038420.14 517094.54 N 70.51615015 W 149.86007945 4800.00 24.45 16.79 4146.14 4199.34 2048.19 1977.23 534.52 178.86L 2.00 5.06 6038461.28 517106.90 N 70.51626248 W 149.85997755 • 4900.00 22.45 16.69 4237.87 4291.07 2087.96 2015.33 545.99 178.77L 2.00 5.09 6038499.40 517118.27 N 70.51636657 W 149.85988371 5000.00 20.45 16.57 4330.94 4384.14 2124.52 2050.37 556.45 178.65L 2.00 5.11 6038534.45 517128.66 N 70.51646227 W 149.85979804 5100.00 18.45 16.42 4425.23 4478.43 2157.81 2082.29 565.91 178.51L 2.00 5.13 6038566.39 517138.04 N 70.51654947 W 149.85972065 5200.00 16.45 16.24 4520.63 4573.83 2187.78 2111.06 574.34 178.34L 2.00 5.16 6038595.18 517146.41 N 70.51662808 W 149.85965162 5300.00 14.45 16.00 4617.01 4670.21 2214.42 2136.65 581.74 178.11L 2.00 5.17 6038620.79 517153.75 N 70.51669798 W 149.85959105 End Cry 5399.38 12.46 15.70 4713.65 4766.85 2237.54 2158.89 588.06 - 2.00 5.19 6038643.04 517160.02 N 70.51675874 W 149.85953930 Top HRZ 7070.09 12.46 15.70 6345.00 6398.20 2598.10 2506.01 685.63 -- 0.00 5.25 6038990.34 517256.81 N 70.51770699 W 149.85874044 Base HRZ 7146.90 12.46 15.70 6420.00 6473.20 2614.68 2521.97 690.12 -- 0.00 5.25 6039006.30 517261.26 N 70.51775058 W 149.85870371 9 -5/8" Csg . 7249.32 12.46 15.70 6520.00 6573.20 , 2636.78 2543.24 696.10 - 0.00 5.25 6039027.59 517267.19 N 70.51780871 W 149.85865474 Top Kupauuk 7336.37 12.46 15.70 6605.00 6658.20 2655.57 2561.33 701.18 - 0.00 5.25 6039045.69 517272.23 N 70.51785811 W 149.85861311 LCU 7353.78 12.46 15.70 6622.00 6675.20 2659.33 2564.95 702.20 - 0.00 5.25 6039049.31 517273.24 N 70.51786800 W 149.85860479 Base Kuparuk 7402.94 12.46 15.70 6670.00 6723.20 2669.94 2575.16 705.07 - -- 0.00 5.26 6039059.53 517276.09 N 70.51789590 W 149.85858128 SAG D 9348.79 12.46 15.70 8570.00 8623.20 3089.88 2979.44 818.71 - 0.00 5.31 6039464.01 517388.82 N 70.51900029 W 149.85765075 Shublik 9451.21 12.46 15.70 8670.00 8723.20 3111.98 3000.71 824.70 -- 0.00 5.32 6039485.30 517394.75 N 70.51905842 W 149.85760177 Ivishak 9691.88 12.46 15.70 8905.00 8958.20 3163.92 3050.72 838.75 -- 0.00 5.32 6039535.33 517408.70 N 70.51919501 W 149.85748667 Target 10301.24 12.46 15.70 9500.00 9553.20 3295.43 3177.32 874.34 - -- 0.00 5.34 6039662.00 517444.00 N 70.51954086 W 149.85719524 Ka vik Shale 10306.36 12.46 15.70 9505.00 9558.20 3296.53 3178.38 874.64 - -- 0.00 5.34 6039663.06 517444.30 N 70.51954377 W 149.85719279 Echooka 10454.86 12.46 15.70 9650.00 9703.20 3328.58 3209.24 883.31 - 0.00 5.34 6039693.93 517452.90 N 70.51962805 W 149.85712177 TD/ 7" 10506.44 • 12.46 15.70 9700.36 9753.56 . 3339.71 3219.95 , 886.32 - -- 0.00 5.34 6039704.66 517455.89 N 70.51965732 W 149.85709710 Survey Error Model: SLB ISCWSA version 24 * ** 3 -D 95.00% Confidence 2.7955 sigma Surveying Frog: MD From (ft) MD To (ft) EOU Freq Survey Tool Type Borehole -> Survey 0.00 41.00 1/100.00 SLB_MWD +GMAG ^A1 -Depth Only OP23 -WW02 -> OP23 -WW02 (P3b) 41.00 4224.82 1/100.00 SLB_MWD +GMAG^ ^1 OP23 -WW02 -> OP23 -WW02 (P3b) 4224.82 7249.32 1/100.00 SLB_MWD +GMAG ^ 2 OP23 -WW02 -> OP23 -WW02 (P3b) 7249.32 10506.44 1/100.00 SLB MWD +GMAG ^ 3 OP23- WW02- >OP23- WW02(P3b) Legal Description: Northing (Y) fftUSl Easting (X) fftUSl Surface : 3130 FSL 1704 FEL S5 T13N R9E UM ' 6036483.06 • 516576.84 ' Schrader Target : 4756 FSL 1272 FEL S5 T13N R9E UM 6038110.00 517000.00 Top Ivishak : 902 FSL 855 FEL S32 T14N R9E UM 6039535.33 517408.70 Ivishak Target : 1027 FSL 819 FEL S32 T14N R9E UM 6039662.00 517444.00 BHL : 1070 FSL 807 FEL S32 T14N R9E UM 6039704.66 517455.89 WellDesign Ver SP 2.1 Bld( doc40x_100) OP23 \OP23- W.NO2 \OP23- WW02 \OP23 -WW02 (P3b) Generated 2/19/2009 3:22 PM Page 2 of 2 • 0 iff#, Eni rit'Aroieum Schlumberger WELL FIELD OP23-WW02 (P3b) I STRUCTURE Nikaitchuq Oliktok Point Magneta Parameters Surface Locabon NAID27 Alaska Slate Planes, Zone 04. US Feet Miscellaneous Model BOOM 2008 Pp 90932 Date Add 19. 2009 Lat. 570 30 39 100 NorMing. 603648306 ((US And Cone +012787579 Slot OP23 TIM Rot Rotary Table (53209 atom MSL) Mag Dec 022 278) FS 579022 nT Lon. W149 51 511368 Easting: 516576 84 SOS Sule Fed. 0.509900121 Plan 0P23-WW02 (PM) Stvy Data: February 19.2030 - 1200 0 1200 2400 3600 RTE 0 I L 0 20" Conductor KOP Bid 1.5/100 Bid 2/100 — ChT37TO , • V3 — ... — — — — 1200 ......-- -----------.--w-- . Tied■Wole.N.W.Mee.WAIWAM11170W.,11,74".....11,VAIVAI,,Weede eareeareearreArawera.erarreareear aweiwenaeeeareear,earrearrt.o 1200 - - - •- - - -• - EnciSre - - - _. _ 2400 2400 . G2 Coal Bed Marker — ...... - .. — ... — — — - 1* - • UGNU *get 1. • r . . C 13-3/5" Csg Cry 2/100 ...... 0 0 (N ,—. ...:--: C , ...7.- 4800 4800 II End Cie w (C o c) 0 6000 6000 - ... 9-5/1P7Csg • — - V I ER! 7 — z . - - :** - ,-AiKuparuk ...: 7200 7200 8400 8400 as ..). as si LC. as is • htlIik — — Target 9600 - .. Mit" — - - 9600 '-'4AVV02 (P3h) -1200 0 1200 2400 3600 Vertical Section (ft) Azim = 15.4°, Scale = 1(in):1200(ft) Origin = 0 N/-S, 0 E/-V • • Eni Petroleum Schlumberger Ertl WELL FIELD STRUCNRE OP23 -02 (P3b) I Nikaitchuq O liktok Point Magnabc Parameters Surface Location NAD27 Alaska State Planes, Zone 04. US Feet Miscellaneous Model'. BGGM 2008 Dip 80932° Dale April 19,2009 Lab N70 30 39 100 NoMirg'. 60364433 06 PUS Grid Gem: •012767579° I Slot OP23 ND Ref' Rotary Table (53.206 above MSL) Mag Dec. ♦22278° FS. 57682 3 nT Lon' W149 51 51 668 Easbnng 51857684 BUS Scale Fact. 09999003121 Plan. OP23 -WWO2 (P3b) Sr, Date. February 19. 2009 -500 0 500 1000 1500 ENI _ease Line (616) 2 3500 1 3500 TD / T• Ta • - • • 23- WMIO2 (P3 P) 3000 3000 N ../...) ' ■-- 9518••1Cs 2500 P 2500 End Cry ` A ENI Lease Line (615) 1 '=NI Lease Line (616) 2 A Z 2000 2000 O O L1) Cry 2H00 c 133/5• C • Target / II 01 8 1500 r 1500 u) v v v 1000 r 1000 500 500 End Cry Cry 3/100 0 Bid 2/100 KOP Bid 1.5/100 " 0 i 20" Conductor RTE -500 0 500 1000 1500 «< W Scale = 1(in):500(ft) E >» 0 0 ANTICOLLISION SUMMARY REPORT Client: ENI Slot: OP23 Field: Nikaitchuq Well: OP23 -WW02 Structure: Oliktok Point Borehole: OP23 - WW02 Subject Trajectory: OP23 - WW02 (P3b) (PLAN) Rpt Date: February 17, 2009 Analysis Method: Normal Plane Depth Interval: Every 100.00ft MD EOU Type: Oriented EOU used. Min Pts: All local minima indicated. ProbColMax: 1:25959 Mag Model: BGGM 2008 Offset Trajectory Sep. Allow Sep. Subject Trajectory Separation Factor Alert Status Ct -Ct (ft) Dev. (ft) Fact. MD (ft) I TVD (ft) Alert I Minor I Major Oliktok Point I -1 (DEF SW PASS 208.54 206.04 44407.65 0.20 0.20 MinPt -CtCt 342.26 331.131 59.001 991.01 987.31 MinPt -O -SF 862.91 838.061 57.751 1945.31 1848.34 MinPt -O -SF 1180.51 1147.251 57.451 2330.33 2161.60 MinPt -O -SF 5915.2711 5785.9111 69.911 5274.55 4645.55 MinPts Oliktok Point 1 -2 (DEF SW) PASS 124.091 110.42 16.34 1178.53 1169.30 MinPts 124.69 110.77 16.06 1201.98 1191.77 MinPt -O -SF 10096.33 9981.901 135.271 5115.48 4493.10 MinPt -O -SF OP03 -P05 (DEF SW) PASS 191.96 189.45 40832.52 0.00 0.00 Surface 192.15 188.08 180.19 300.00 300.00 MinPt -O -ADP 534.53 509.42 35.311 2126.78 1995.99 MinPt -O -SF 2076.14 2008.281 47.591 4281.26 3749.06 MinPt -O -SF 2210.93 2141.051 49.161 4745.87 4150.25 MinPt -O -SF 7251.75 7151.361 111.081 6149.92 5499.67 MinPt -O -SF OP03- P05PB1 (DEF SW) PASS 191.96 189.45 40832.52 0.00 0.00 Surface 192.15 188.08 180.19 300.00 300.00 MinPt -O -ADP 534.53 509.42 35.311 2126.78 1995.99 MinPt -O -SF 2076.14 2008.28 47.591 4281.26 3749.06 MinPt -O -SF 2313.1311 2111.751 17.43 4923.16 4312.49 MinPts OP03- P05PB2 (DEF SW) PASS 191.96 189.45 40832.52 0.00 0.00 Surface 192.15 188.08 180.19 300.00 300.00 MinPt -O -ADP 534.53 509.42 35.311 2126.78 1995.99 MinPt -O -SF 2076.14 2008.271 47.591 4281.26 3749.06 MinPt -O -SF 2210.93 2141.0 1 49.161 4745.87 4150.25 MinPt-O-SE 5118.60 5015.141 76.011 5567.09 4930.57 MinPt-O-SE OPO4 -P07 (P6c) (DEF PLN) PASS 183.99 181.48 39115.59 0.00 0.00 Surface 183.99 179.30 124.59 300.00 300.00 MinPt -CtCt 184.60 178.96 86.94 399.99 399.99 MinPt -O -ADP 223.99 212.271 36.031 904.45 902.22 MinPt -O -SF 354.05 334.36 30.67 2013.12 1903.51 MinPt -O -SF 8483.43 8399.88 156.96 6317.60 5663.40 TD OP26 -DSPO2 (DEF SW) PASS 1 237.911 235.13 1267.08 99.99 99.99 MinPt -CtCt 179.60 165.69 23.27 1326.46 1309.65 MinPts 182.75 168.081 22.231 1417.06 1393.82 MinPt -O -SF 382.95 351.33 19.591 2325.61 2157.76 MinPt -O -SF 1 1 2172.131 2072.9011 33.641 7505.34 6823.16 MinPts Version DO 4.0 ( doc40x_100) SP 2.1 - ANTICOLLISION SUMMARY REPORT Generated 2/17/2009 10:41 AM Page 1 of 1 0 0 S chlumberger TRAVELING CYLINDFR PLO T Client: ENI NoGo Region EOU's based on Well: OP23 -WW02 Oriented EOU Dimension N Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anticollision rule used: Minor Risk - Separation Factor A Date: April 17, 2009 ', f.. 1 North 350 0 10 340 20 330 30 0 320 '. aim illivi 40 Olikto Poin_I -2 J � '' tok Point I -2 310 50 300 '.% NW 60 290 i lliMpr op , 70 80 280 iiit 2 0 ® ' ,1•44. , 260 100 t■*csb � �c� O 250 110 � ,r , 240 • � � S. 120 100 230 130 *111101111111101110 , 220 140 210 150 200 160 190 180 170 Well Ticks Type: MD on 01 02 (P3 b) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH = 50.00 ft • . Drilling Hazards Summary 16" Open Hole / 13 -3/8" Casing Interval Hazard Risk Level Mitigation Strategy Broach of Conductor Low Monitor continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Lecithin. Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 12 -1/4" Open Hole / 9 -5/8" Casing Interval Hazard Risk Level Mitigation Strategy Running Sands and Low Maintain planned mud parameters, Increase Gravels mud weight, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Lecithin. Stuck Pipe Low Good hole cleaning, pre - treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low ✓ BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 8 -1/2" Open Hole / 7" Liner Interval Hazard Risk Level Mitigation Strategy Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Abnormal Reservoir Moderate ✓ Stripping drills, shut -in drills, increased mud Pressure weight. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming Hole Surge on Casing run Moderate Monitor running speeds, proper hole fill, ciruculation 02 OP23 -WW02 Drilling Hazards Summarydoc 2/6/2009 9:34:00 AM �( l l I HYDRIL 13 -5/8" 5K PSI GK ANNULAR BOP 4' -6" LATCHED HEAD 5K FLANGE CONNECTION I 54 -1/2" LENGTH \ J • =411 — — 1110= 4" 10,000/ WP CAMERON TYPE "F" HYDRIL 13 -5/8" 5K PSI GATE VALVE MPL DOUBLE GATE 13' -411" 1 3' -i" WP 4" 10,0001 WP STUDDED CONNECTION 4" 10,0001 CAMERON HCR VALVE / CAMERON HCR VALVE — 011 - -e- IP= DRILLING SPOOL 4" CHOKE LINE ...6._ III + ii■ 4I\ �e - 3" KILL LINE 2 ' -2 " 13- 5/8 " -5K PSI FLANGED ■II III II 4 " -10K PSI FLANGED OUTLETS 4 "x3 " - 26" EST. LENGTH 4" 10,0001 WP I J — CAMERON TYPE "F" HYDRIL 13 -5/8" 5k PSI F MPL SINGLE GATE ......H_ ......H_ — GATE VALVE � - - � - - I Y FLANGED CONNECTION 36 -1/4" LENGTH I 1---. • NABORS ALASKA RIG 245E 13 -5/8" 5K BOP STACK CONFIGURATION °`�"° ""�°" `"'"°" -'"°" w'w" I MYd9MIH� — Mchwa9a. N r 98505 -2939 907 -2 —9000 FICUECT NABORS ALASKA RIG 245E ma BLOW -OUT PREVENIER 13 -5/8' 5K STUDDED STACK CONFIGURATION NMI 13144R08 A .01 JA ISSUED J (E ALSTON JOE A LSION /MOM 61 JOE AISTON A 0900 N I' V' 0[seRv0ox 3WE N/A ntvi N 2008 ""F M0. 245L0002-50 of d 1 I . I I I I 1 • ' I I NA MS I I INILTII inn up V/ I 1 CONNETOR I i+ CELLAR I I l LI I HYDRIL 13 -5/8' SK PSI M II GK ANNULAR B I P i 4' -6}' LATCHED HEAD O i 5K FLANGE CONNECTION 1 I 54 -1/2" LENGTH l : o41 - - IP — 4" 10.000/ NP _ - • CAMERON TYPE "F" GATE VALVE HYDRIL 13 - 5/8" 5K PSI ,� .__ MPL DOUBLE 13 -41" I 3 -�" STUDDED CONNECTION ti+:I♦d1ll' :; WP CAMERON � VALVE o 41 - 0 —� CAMERON VALVE 4 - 7/8" LENGTH ii:i:;I .. DN �� _ DRILLING SPOOL 4' CHOKE LINE IMP' �II ' + III 'II 'III� - J' KILL LINE p•_2• 4 13-5/8"-5K 10K PSI FLANGED OUTLETS -_ .� 26' EST. LENGTH 4' 10,0001 WP 1 I CAMERON TYPE 'F' HYDRIL 13 - 5 /E' Sk PSI 90 , - 0 " ESTIMATED GATE VALVE + J , N " MPL SINGLE GATE LENGTH FLANGED CONNECTION 16" DIVERTER LINE - - - _ _ I I 36 - 1/4" LENGTH \� I ' I + 13-5/8" 5K BOP STACK CONFIGURATION DIVERTER LINE ROUTING NABORS ALASKA RIG 245E ENI NIKAITCHUQ PROJECT 21 -1/4' 2,000/ WP SHAFFER 2, 000 / STUDDED TOP 4' -4 t /2' 21 -1/4' 2,000/ F LA N GED BOTTOM H2S TRIMMED ANNULAR DIVERTER SYSTEM ■ _■ m 3/16' �� SURFACE DIVERTER 16" -150/ FLG PIPING CONFIGURATION PLAN VIEW II I 2. -0. 24' DN. ne s maxew" ocsw a r•aoAS wr s IN iwoxs a 0®iM 6 "A•49iL OILY f .Y111G® M -- \-1r 0 KNIFE GATE 25 00 W/ HYD. ACTUATOR AM Nabors Alaska zszs c s�,.. swee zao KNIFE o t Al Igsor2a38 PROJECT NADORS ALASKA RIG 245E 2 . -0 . MILE BOP STACK AND DIVERTER CONFIGURATION ENI NIKAICHUQ PROJECT SURFACE DIVERTER CONFIGURATION 9JULY06 A .M J4 ISSUED DRWi ;& ALSTON JOE N"•°"°' JOE ALSTON it' A o In°' ° SY ` "e7 DESCRIPTION 'O"` N/A "" JULY 2008 245E.0.301- t*AITCHUO '" 1 of I 1 . ..., 1 .,..,., , A , . ,t •_.,,, .. ,:t., • ,.,. ..., 1 iiii « ill -.,* " , Material List ... Item Description 1-15 4-1/16" 10M Cameron Manual Gate Valve • ' ,. 16 2-1/16" 10M Cameron Manual Gate Valve ., .. . , A,B 4-1/16" 10M Cameron H2 Manual Choke . C 3-1/16" 10M Shaffer Hydraulic Choke . . .... , . , .-- - .... .. :.,_. ... To Gas 0 41 (I) ( '..-- - -- - - --- ' - *' 7 , %.4 / p i 1 ■ /a ' ;, 410 70 111_ ( , l a IF „ - IF t liSIF . . _,...,_.,,..„ ......„_. . ., 411111,41--,_w al - .,. iit __,, . t . 1 ivi, , _ID , . __.... From BOP's Legend , . , ...,-- -- .....-- 0/ J.' ftw .-- --' . ,.,. a L White Handle Valves 717 Normally Open . . .- ..... — - . ci" "eserve Pit Red Handle Valves E3 Normally Closed , ODS A Date: 6-1-01 Rev. 1 a __ . .... ., .. .. I I • • Schlumberger C emCAD E * well cementing recommendation for 13 -3/8" Surface Casing Operator : Eni Petroleum Well : OP23 -WW02 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr. Joe Longo Location : Oliktok Point Proposal No. : Draft v2 Service Point : Prudhoe Bay, Alaska Date Prepared : 2 -19 -2009 Business Phone : 907 - 659 -2434 FAX No. : 907 - 659 -2538 Prepared by : Tony Stafford Phone : 907 - 273 -1700 E -Mail Address : tstafford@slb.com 420 P* O At 16 )0 1 ' &ATE Disclaimer Notice' This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services Freedom from infringement of patents of Schlumberger or others is not to be inferred. 1 * Mark of Schlumberger I. • • Client : E Petroleum Well SchluO6erger Well OP 23 -WW02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 4225.0 ft BHST : 50 degF Bit Size : 16 in ft (x 1000) psi 0 2 4 .=,- ! i L Frac l — — Pore " • t 1 - • • • • • Permafrast } . ; t 1 r CD O N % ., _t_ Shale T /Cosh 1 • f i _ t . 0 ci o 0 Well Lithology Formation Press. Page 2 OP23- WW02.cfw,02 -19 -2009, LoadCase13 -3 /8in Surface Casing. Version wcs-cem452_07 • Client : Eni Petroleum Well : 0P23 -WW02 Sahl String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Previous String MD OD Weight ID (ft) (in) (Ib /ft) (in) 154.0 20 169.0 18.376 Landing Collar MD : 4145.0 ft Casing /liner Shoe MD : 4225.0 ft Casing /Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb /ft) (in) (psi) (psi) 4225.0 13 3/8 40.0 68.0 12.415 L -80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 84.4 % Mean OH Equivalent Diameter: 17.918 in Total OH Volume : 1269.6 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) ( %) (in) 1901.0 16.000 150.0 19.279 4225.0 16.000 35.0 16.822 Page 3 OP23 -WW02 cfw, 02 -19 -2009; LoadCase 13 -3 /8in Surface Casing, Version wcs- cem452_07 • • Client : Eni Petroleum Well : 0 W P23 -W02 1` 1 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Max. Deviation Angle : 36 deg Max. DLS : 3.037 deg /100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 0.0 0.0 0.0 340.0 0.000 41.0 41.0 0.0 340.0 0.000 100.0 100.0 0.0 340.0 0.000 155.2 155.2 0.0 340.0 0.000 200.0 200.0 0.0 340.0 0.000 300.0 300.0 0.0 340.0 0.000 400.0 400.0 0.0 340.0 0.000 500.0 500.0 1.5 340.0 1.500 600.0 599.9 3.5 340.0 2.000 700.0 699.6 5.5 340.0 2.000 728.8 728.2 6.1 340.0 2.016 800.0 798.9 7.5 340.0 1.994 900.0 897.8 9.5 340.0 2.000 961.3 958.2 10.8 347.2 3.001 1000.0 996.1 11.7 350.9 3.004 1100.0 1093.5 14.3 358.2 2.994 1200.0 1189.9 16.9 3.3 3.006 1229.7 1218.2 17.7 4.5 2.991 1300.0 1284.8 19.7 7.0 2.998 1400.0 1378.1 22.5 9.9 2.998 1500.0 1469.5 25.4 12.1 3.008 1600.0 1558.7 28.3 13.9 2.991 1700.0 1645.5 31.2 15.4 3.002 1780.1 1713.2 33.5 16.4 3.000 1800.0 1729.7 34.1 16.6 3.037 1849.6 1770.4 35.5 17.2 2.994 1900.0 1811.5 35.5 17.2 0.000 2000.0 1892.8 35.5 17.2 0.000 2100.0 1974.2 35.5 17.2 0.000 2160.2 2023.2 35.5 17.2 0.000 2200.0 2055.5 35.5 17.2 0.000 2300.0 2136.9 35.5 17.2 0.000 2400.0 2218.3 35.5 17.2 0.000 2500.0 2299.6 35.5 17.2 0.000 2600.0 2381.0 35.5 17.2 0.000 2700.0 2462.3 35.5 17.2 0.000 2744.0 2498.2 35.5 17.2 0.000 2800.0 2543.7 35.5 17.2 0.000 2900.0 2625.1 35.5 17.2 0.000 3000.0 2706.4 35.5 17.2 0.000 3100.0 2787.8 35.5 17.2 0.000 3200.0 2869.1 35.5 17.2 0.000 3300.0 2950.5 35.5 17.2 0.000 3400.0 3031.9 35.5 17.2 0.000 3500.0 3113.2 35.5 17.2 0.000 3567.5 3168.2 35.5 17.2 0.000 3600.0 3194.6 35.5 17.2 0.000 3700.0 3276.0 35.5 17.2 0.000 3800.0 3357.3 35.5 17.2 0.000 3825.6 3378.2 35.5 17.2 0.000 3899.4 3438.2 35.5 17.2 0.000 3900.0 3438.7 35.5 17.2 0.000 Page 4 OP23- WW02.cfw, 02 -19 -2009, LoadCase 13 -3 /8in Surface Casing, Version wcs- cem452_07 0 • Client : Eni Petroleum Well : OP23 -WW02 Sahl ( H String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 3954.7 3483.2 35.5 17.2 0.000 4000.0 3520.0 35.5 17.2 0.000 4089.9 3593.2 35.5 17.2 0.000 4100.0 3601.4 35.5 17.2 0.000 4139.0 3633.1 35.5 17.2 0.000 4200.0 3682.8 35.5 17.2 0.000 4225.0 3703.1 35.5 17.2 0.000 Formation Data MD Frac. Pore Name Lithology (ft) (lb /gal) (lb /gal) 154.0 11.20 9.00 Permafrost Sandstone 1901.0 12.00 9.00 Permafrast Sandstone 4225.0 16.00 9.00 T /Cosh 1 Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF /100ft) 0.0 0.0 20 0.0 1901.0 1812.3 32 0.7 4225.0 3703.1 50 0.8 ' Page 5 OP23- VVVV02.cfw, 02 -19 -2009 ; LoadCase 13 -3 /8in Surface Casing , Version wcs- cem452_07 • . Client : Eni Petroleum Well : 0P23 -WW02 Wrier String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing ft degF (x 1000) ft a ,_ 0 1 40 60 1 1 I e 1.2 1.6 2.0 - Geoth.Profile - Hori. Depart. - +4-4- - II - ` - - o 111111111§111. i •• - \ 14 : # le IBM Lill Milli III / ■ #i•lf u mina $ M _ u wuutru•■ ■urea 1 •.. a� I e-- -- (D \\ I ; I..ma::'lsa ,■ ii. 0 1 u_ � _. O CA il 81 s i I i I ° o � . ■ inn ■■ � i 1111 u•uii > N t�i4' ■r$ \1111111�NNW l as - \ cNi ':' l>i: � 1 1 • c , 1 , _- , , ; , a M i c6 umuu m■11 � m ■ at o a. ni cl _ an a_ U _ 1 IMO, U Temperature Hori. Departure Section 2: fluid sequence Job Objectives: ArcticSET Light cement to Surface, 500' 12.0 ppg DeepCRETE Slurry Tail Original fluid Mud 9.20 lb/gal k : 1.08E -2 Ibf.s ^n /ft2 n : 0.506 Ty : 15.43 Ibf /100ft2 Displacement Volume 620.6 bbl I Total Volume 1318.5 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH 11 100.0 0.0 10.20 k:2.26E -2 Ibf.s ^n /ft2 n:0.435 Ty:13.81 Ibf /100ft2 Lead Slurry 535.4 3725.0 0.0 10.70 k:1.24E -2 Ibf.s ^n /ft2 n:0.412 Ty:9.87 Ibf /100ft2 Tail Slurry 62.5 500.0 3725.0 12.00 k:8.21 E -2 lbf.s ^n /ft2 n:0.350 Ty:6.54 lbf/100ft2 Mud 620.6 0.0 9.20 k:1.08E-2 lbf.s^n/ft2 n:0.506 Ty:15.43Ibf/100ft2 Page 6 OP23- WW02.cfw;02 -19 -2009, LoadCase13 -3 /8in Surface Casing ; Version wcs- cem452_07 • . Client : E Petroleum Well SC*1011 r Well OP W 23 -W02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Static Security Checks : Frac 4 psi at 154.0 ft Pore 14 psi at 154.0 ft Collapse 1839 psi at 4145.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 87 ton ft (x 1000) psi ._ < 1 � � 0 4 Hydrostatic __I _ `— Frac — Pore o _ a o – II� __ 1 its .__ I I 1i Ilk --- in– Fluid Sequence Static Well Security I Page 0P23- WW02.cfw.02 -19 -2009, LoadCase 13 -3 /8in Surface Casing; Version wcs- cem452_07 0 • Client : Eni Petroleum Well : OP23 -WW02 i iMir String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Section 3: pumping schedule Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl /min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 7 -Start Pumping Spacer Pause 0.0 0.0 10.0 0.0 80 4 -Drop Bottom Plug Lead Slurry 5.0 535.4 107.1 535.4 80 13 -Start Mixing Lead Slurry Tail Slurry 5.0 62.5 12.5 62.5 80 16 -Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 18 -Drop Top Plug Mud 8.5 580.0 68.2 580.0 80 19 -Start Displacement Mud 3.0 40.6 13.5 620.6 80 21 -Bump Top Plug Total 03:56 1318.5 bbl hr:mn End Job: Bump Plug; Check floats Dynamic Security Checks : Frac 2 psi at 154.0 ft Pore 2 psi at 154.0 ft Collapse 1839 psi at 4145.0 ft Burst 4629 psi at 0.0 ft Temperature Results BHCT 64 degF Simulated Max HCT 63 degF Simulated BHCT 63 degF Max HCT Depth 4225.0 ft CT at TOC 59 degF Max HCT Time 03:56:21 hr:mn:sc Static temperatures : At Time ( hr:mn) (hr:mn) Geo. Temp. Top of Cement (degF) (degF) 20 degF Bottom Hole I (degF) (degF) 50 degF Page 8 OP23 -UM/02 cfw, 02 -19 -2009 , LoadCase 13 -3 /Bin Surface Casing , Version wcs-cem452_07 • Client : Eni Petroleum Well SciI 1 ger Well l O W P23 -W02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing o o — Calc. WHP — Cale. Pump Press. N ,- 0 50 1 150 2 250 Time (min) a • °- Fluids at 4225 ft ▪ - - Acquired Q Out • —Acquired 0 In . —Q Out Q In r = y cc IX i t LL 0 50 100 150 200 250 Time (min) Page 9 OP23- WW02.cfw ; 02 -19 -2009 ; LoadCase 13 -3 /8in Surface Casing ; Version wcs- cem452_07 • Client : Eni Petroleum p Well : 0P23 -WW02 1 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing * CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Depth = 154 ft N - Depth = 4225 ft N —1-rac Frac — Pore — Pore 8 — Hydrostatic _ — Hydrostatic co — Dynanrc uynamc in r d. in i { 0 in 0 ° ern 1 m mot_ m E .o 0 M a = u) N S u),- ) N >" • 0_to i a t` i7,3 e U QQ ...-- /".----"-7/--: ii Oi 1 —J U 7. • 8 0 250 0 250 3 Time (min) Time (min) tl o Total Depth = 4225.0 ft Top of Cement = 0.0 ft *Mark of Schlumberger te e` Page 10 OP23 -W W02.cfw; 02 -19 -2009 , LoadCase 13 -3 /8in Surface Casing ; Version wcs- cern452_07 Client : Eni Petroleum Well : OP23 -WW02 1 Wig String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Section 4: centralizer placement Top of centralization :100.0 ft Bottom Cent. MD :4205.0 ft Casing Shoe :4225.0 ft NB of Cent. Used :14 NB of Floating Cent. :14 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint ( %) (ft) 185.0 2 1/1 NW -TR -13 3/8 -8 -TR 3 W304 0.0 179.1 3745.0 0 0/0 0.0 185.0 4225.0 12 1/1 NW -TR -13 3/8 -8 -TR 3 W304 0.0 3753.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW -TR -13 3/8 -8 -TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 OD specifications Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer /Formation :0.3 Total Drag Force :5 ton Hook load Down Stroke :137 ton Hook load Up Stroke :146 ton Page 11 0P23 -WW02 cfw ; 02 -19 -2009 , LoadCase 13 -3 /8in Surface Casing , Version wcs- cem452_07 Client : Eni Petroleum S �rg�r Well : OP23 -WW02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing ft _ 0 9n l0 60 80 100 -- Between Cent. 11111111111111.1.11111111- + +At Cent. _I lei +— 111111111111111 1I . __. 11111111111111111 iminor 1 . 1111 - I IIII � _ ° ° ° Pipe Standoff Page 12 OP23- WW02.cfw;02 -19 -2009; LoadCase 13-3/8in Surface Casing; Version wcs-cem452_07 • • Client : Eni Petroleum Well SiI kerger Well W OP23 -W02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US ton ft p 0 25 50 75 100 125 150 — Hookload Up — — Hookload Down \ - Weight \ — — Drag Force - 1 \. I �. _ \. - I \ • C.! I \ Op I \ CV CVJ I \\ • I \ U I \ • u \ I \\ U 1 \ 8 p O s p Running Forces Friction Factor = 0.3 Total Depth = 4225.0 ft Top of Cement = 0.0 ft i 'Mark of Schlumberger Widow Page 13 OP23- VVW02.cfw, 02 -19 -2009; LoadCase 13 -3 /8in Surface Casing, Version wcs- cem452_07 • • Client : E Petroleum Well SChl1mberger Well OP 23 -WW02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Section 5: WELLCLEAN II Simulator ft % _ 0 9n 4 0 60 SO 100 - -- Std Betw. Cent. { _ — Cement Coverage 'U - i II 1 1N _ - 11111. . I - . N 11111111111 - f .� _- us 4"- . -1111. O 11 11 - 1 d 1111 1111 1111 1111. 1111. 1111 Q rrl - Cement Coverage Fluids Concentrations Risk Mud on the Wall 0-I ' -0 0 0 500 540 500 - 500 1000- -1000 1 000 1000 r- , 1500 1500 r „ 1500- -1500 , .- 2000- -2000 = s 2000 2000 r a 2500- -2500 o a 2500 2500 Ti. 3000- i -3000 3000 3000 3500 - 3500 3500 3500 4000- -4000 4000 4000 I f ; a o a� a o a o 2 2 Mud FT Lead Slurry = High M. Low I I Tail Slurry n MUDPUSH II ® Medium ® None Page 14 OP23- WW02.cfw : 02 -19 -2009 ; LoadCase 13 -3 /8in Surface Casing ; Version wcs- cem452_07 • • Client : Eni Petroleum Well : OP23 -WW02 • I M String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Section 6: fluid description Mud DESIGN Fluid No: 1 Density : 9.20 lb/gal Rheo. Model : HERSCHEL_B. k : 1.08E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.506 Ty : 15.43 lbf/100ft2 Gel Strength : (Ibf /100ft2) MUD Mud Type : WBM Job volume : 620.6 bbl Water Type : Fresh VOLUME FRACTION Solids : 4.0 % Oil :0.0% Water : 96.0 % MUDPUSH II DESIGN Fluid No: 2 Density : 10.20 lb/gal Rheo. Model : HERSCHEL_B. k : 2.26E -2 lbf.s ^n /ft2 At temp. : 80 degF n : 0.435 Ty : 13.81 lbf/100ft2 Gel Strength : (Ibf /100ft2) Job volume : 100.0 bbl Lead Slurry DESIGN Fluid No: 3 Density : 10.70 lb/gal Rheo. Model : HERSCHEL_B. k : 1.24E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.412 Ty : 9.871bf/100ft2 Gel Strength : (Ibf /100ft2) DESIGN BLEND SLURRY Name : B809 Mix Fluid : 19.043 gal /sk Job volume : 535.4 bbl Dry Density : 105.47 lb /ft3 Yield : 4.33 ft3 /sk Quantity : 694.47 sk Sack Weight : 188 lb Solid Fraction : 41.2 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 19.043 gal /sk Page 15 OP23- WW02.cfw, 02 -19 -2009, LoadCase 13 -3 /8in Surface Casing , Version wcs- cem452 • • Client : Eni Petroleum n Well : OP23 -WW02 . String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing Tail Slurry DESIGN Fluid No: 4 Density : 12.00 lb/gal Rheo. Model : HERSCHEL_B. k : 8.21E-2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.350 Ty :6.541bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND SLURRY Name : 12.0 PPG Lit Mix Fluid : 5.232 gal /sk Job volume : 62.5 bbl Dry Density : 110.20 Ib /ft3 Yield : 1.61 ft3 /sk Quantity : 217.44 sk Sack Weight : 100 lb Solid Fraction : 56.7 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.082 gal /sk Additives Code Conc. Function D046 0.200 %BWOB Antifoam D185A 0.050 gal /sk blend Dispers. LT D186 0.100 gal /sk blend Accelerator D153 1.500 %BWOC Antisettlinq Sect 7: operator summary Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl /min) (bbl) (min) (bbl) MUDPUSH II 5.0 100.0 20.0 100.0 7 -Start Pumping Spacer Pause 0.0 0.0 10.0 0.0 4 -Drop Bottom Plug Lead Slurry 5.0 535.4 107.1 535.4 13 -Start Mixing Lead Slurry Tail Slurry 5.0 62.5 12.5 62.5 16 -Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 18 -Drop Top Plug Mud 8.5 580.0 68.2 580.0 19 -Start Displacement Mud 3.0 40.6 13.5 620.6 21 -Bump Top Plug Total Pumping Time : 03:56 hr:mn End Job: Bump Plug; Check floats TOTAL MATERIAL REQUIREMENTS Dead Volumes Mix Water Requirements : Fresh water 518 bbl Page 16 OP23- WW02.cfw;02 -19 -2009, LoadCase 13-3/8in Surface Casing, Version wcs-cem452_07 • • Client : Eni Petroleum Well S� I�rger Well OP23 -WW02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing MIXING PREPARATION MUDPUSH II Volume : 100.0 bbl Density : 10.20 Ib /gal Code Quantity Design Fresh water 92.162 bbl D182 552.971 Ib 6.000 lb /bbl of base fluid D031 10081.871 Ib 100.82 Ib /bbl of spacer Lead Slurry Volume : 535.4 bbl Density : 10.70 Ib /gal Yield : 4.33 ft3 /sk Dry Phase Liquid Phase Blend : 167453 Ib Design Mix Water 403.8 bbl 10.0 bbl LAS Design Tail Slurry Volume : 62.5 bbl Density : 12.00 Ib /gal Yield : 1.61 ft3 /sk Dry Phase Liquid Phase Blend : 18078 Ib Design Mix Water 22.3 bbl 10.0 bbl LAS Design I � Page 17 OP23 -WW02 cfw , 02 -19 -2009, LoadCase 13 -3 /8in Surface Casing, Version wcs- cem452_07 s • Client : Eni Petroleum Well ScI kerger Well W OP23 -W02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 13 -3 /8in Surface Casing CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : Surface Casing District : Prudhoe Bay, Alaska Country : US Annulus ID : 13.375 in - OD : 16.000 in U, Ml1DPUSHII - Mid ° - Tail Slurry Lead Slurry U f0 O + f0 LO 2 1 LO O O O E d Y O 3 4 N d c 0 O U O U 'C - M O • M $ N 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbl /min) o IN Mid Herschel : k = 1.08E-2 Ibf.s^n/ft2 n = 0.506 Ty = 15.43 lbf /100ft2 ■ MUDPUSH II Herschel : k = 2.26E2 lbf.s ^n /ft2 n = 0.435 Ty = 13.81 Ibf /100ft2 3 Lead Slurry Herschel : k = 1.24E2 Ibf.s^n /ft2 n = 0.412 Ty = 9.87 Ibf /100ft2 ■ Tail Slurry Herschel : k = 8.21E2 lbf.s ^n /ft2 n = 0.350 Ty = 6.54 Ibf /100ft2 'Mark of Schlumberger SCNEknil Page 18 0P23- WW02.cfw, 02 -19 -2009, LoadCase 13 -3 /8in Surface Casing; Version wcs- cem452_07 • Schlumberger C em CAD E * well cementing recommendation for 9 -5/8" Intermediate Casing Operator : Eni Petroleum Well : OP23 -WW02 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr. Joe Longo Location : Oliktok Point Proposal No. : Draft v2 Service Point : Prudhoe Bay, Alaska Date Prepared : 2 -19 -2009 Business Phone : 907 - 659 -2434 FAX No. : 907 - 659 -2538 Prepared by : Tony Stafford Phone : 907 - 273 -1700 E -Mail Address : tstafford @slb.com 4 c0 R 'UATE Disclaimer Notice: This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred * Mark of Schlumberger • • Client : E Petroleum Well Schlumbergcr Well OP 23 -WW02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 7249.0 ft BHST : 95 degF Bit Size : 12 1/4 in ft (x 1000) psi • 0 4 6 Rae ? — — Pore • Permafrast - Shale T /Cosh 1 1 Shale ( ' 6 � IL=11 I I l III ti t c co_ Well Lithology Formation Press. Page 2 OP23- WW02.cfw; 02 -19 -2009; LoadCase 9-5/8 Intermediate Casing Cal; Version wcs- cem452_07 • • Client : Eni Petroleum Well W 0P23 WO2 , 1 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 4225.0 13 3/8 68.0 12.415 Landing Collar MD : 7169.0 ft Casing /liner Shoe MD : 7249.0 ft Casing /Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 7249.0 9 5/8 40.0 47.0 8.681 L -80 4760 6870 BTCM Page 3 0P23 -WW02 cfw, 02 -19 -2009, LoadCase 9-5/9 Intermediate Casing (a), Version wcs- cem452_07 • • Client : Eni Petroleum W Well : OP23 -W02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Mean OH Diameter : 12.250 in Mean Annular Excess : 25.0 % Mean OH Equivalent Diameter: 12.823 in Total OH Volume : 483.0 bbl (including excess) Max. Deviation Angle : 36 deg Max. DLS : 3.037 deg /100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 4225.1 3703.1 35.5 17.2 0.000 4225.1 3703.2 35.5 17.2 0.000 4245.1 3719.4 35.5 17.2 0.000 4300.0 3764.4 34.5 17.1 -2.002 4400.0 3847.9 32.5 17.1 -2.000 4500.0 3933.2 30.5 17.0 -2.000 4600.0 4020.2 28.5 17.0 -2.000 4700.0 4109.0 26.5 16.9 -2.000 4800.0 4199.3 24.5 16.8 -2.000 4900.0 4291.0 22.5 16.7 -2.000 5000.0 4384.1 20.5 16.6 -2.000 5100.0 4478.4 18.5 16.4 -2.001 5200.0 4573.7 16.5 16.2 -2.001 5300.0 4670.1 14.4 16.0 -2.001 5399.7 4767.1 12.5 15.7 -1.998 5400.0 4767.4 12.5 15.7 0.000 5500.0 4865.0 12.5 15.7 0.000 5600.0 4962.7 12.5 15.7 0.000 5700.0 5060.3 12.5 15.7 0.000 5800.0 5158.0 12.5 15.7 0.000 5900.0 5255.6 12.5 15.7 0.000 6000.0 5353.2 12.5 15.7 0.000 6100.0 5450.9 12.5 15.7 0.000 6200.0 5548.5 12.5 15.7 0.000 6300.0 5646.2 12.5 15.7 0.000 6400.0 5743.8 12.5 15.7 0.000 6500.0 5841.5 12.5 15.7 0.000 6600.0 5939.1 12.5 15.7 0.000 6700.0 6036.8 12.5 15.7 0.000 6800.0 6134.4 12.5 15.7 0.000 6900.0 6232.1 12.5 , 15.7 0.000 7000.0 6329.7 12.5 15.7 0.000 7070.1 6398.2 12.5 15.7 0.000 7100.0 6427.3 12.5 15.7 0.000 7146.9 6473.2 12.5 15.7 0.000 7200.0 6525.0 12.5 15.7 0.000 7249.0 6572.8 12.5 15.7 0.000 Page 4 OP23- WW02.cfw ; 02 -19 -2009 , LoadCase 9 -5/8 Intermediate Casing (a), Version wcs- cem452_07 • • Client : Petroleum Well Schlumberger Well l 0P OP23 -WW02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Formation Data MD Frac. Pore Name Lithology (ft) (Ib /gal) (lb /gal) 154.0 11.20 9.00 Permafrost Sandstone 1901.0 12.00 9.00 Permafrast Sandstone 4225.0 16.00 9.00 T /Cosh 1 Shale 7249.0 16.00 9.00 Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF /100ft) 0.0 0.0 20 0.0 1901.0 1812.3 32 0.7 4225.0 3703.1 50 0.8 7249.0 6572.8 95 1.1 ft degF (x 1000) ft _ 0 I 100 n 1 2 3 Geoth.Profile Hod. Depart. I I ( i i I - I ___ ._ CV — \ 4 fl II � . \ \ «.._ I ss t t 1 t S co 1 — ___ _ 1 r 1 \ k c. co_ Temperature Hori. Departure Page 5 OP23- WW02.cfw : 02 -19 -2009: loadCase 9 -5/8 Intermediate Casing (a), Version wcs- cem452_07 • I Client : Petroleum Well Schlumburgcr Well 0P OP23 -WW02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Section 2: fluid sequence Job Objectives: 1,000' of Fill; Zonal Isolation Original fluid Mud 9.80 lb /gal k : 1.08E -2 Ibf.s ^n /ft2 n : 0.506 Ty : 15.43 lbf/100ft2 Displacement Volume 524.8 bbl Total Volume 640.4 bbl TOC 6249.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb /gal) MUDPUSH II 40.0 573.7 5675.3 12.80 k:2.26E -2 Ibf.s ^n /ft2 n:0.435 Ty:13.81 lbf/100ft2 Inter. Tail 75.6 1000.0 6249.0 15.80 k:3.93E -3 Ibf.s ^n /ft2 n:0.903 Ty:26.99 lbf/100ft2 Mud 524.8 0.0 9.80 k:1.08E-2 lbf.s^n/ft2 n:0.506 Ty:15.43 lbf/100ft2 Static Security Checks : Frac 1193 psi at 4225.0 ft Pore 154 psi at 4225.0 ft Collapse 4068 psi at 7169.0 ft Burst 6870 psi at 0.0 ft Csq.Pump out 118 ton ft (x 1000) psi 0 9 4 6 L_ Hydrostatic Frac 1 ' Pare I .1 I ° ° ao — Fluid Sequence Static Well Security Page 6 OP23 -WW02 cfw, 02 -19 -2009, LoadCase 9-5/8 Intermediate Casing (a), Version wcs- cem452_07 • • Client : Eni Petroleum Well : 0P23 -WW02 Sahl ""' String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Section 3: pumping schedule Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl /min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 4.0 40.0 10.0 40.0 80 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4 -Drop Bottom Plug Inter. Tail 4.0 75.6 18.9 75.6 80 9 -Start Cement Slurry Pause 0.0 0.0 5.0 0.0 80 18 -Drop Top Plug Mud 8.5 490.0 57.6 490.0 80 19 -Start Displacement Mud 3.0 34.8 11.6 524.8 80 21 -Bump Top Plug Total 01:48 640.4 bbl hr:mn End Job: Bump Plug; Check floats Dynamic Security Checks : Frac 1020 psi at 4225.0 ft Pore 154 psi at 4225.0 ft Collapse 4068 psi at 7169.0 ft Burst 6205 psi a 0.0 ft Temperature Results BHCT 89 degF Simulated Max HCT 95 degF Simulated BHCT 60 degF Max HCT Depth 7249.0 ft CT at TOC 61 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time (hr:mn) (hr:mn) Geo. Temp. Top of Cement I (degF) (degF) 1 80 degF Bottom Hole (degF) (degF) 95 degF 1 Page 7 OP23- WW02.cfw, 02 -19 -2009, LoadCase 9-5/8 Intermediate Casing (al. Version wcs- cem452_07 • • Client : Eni Petroleum Well Schl rger Well l W OP23 -W02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9-5/8 Intermediate Casing (a) ° ° -Cale. WHP I __. _ ° — Cala Pump Press. 1 - Elwin --- - . _I ,___ l ' - i_._:-.....„ .. , ii . , ,_ . , 0 20 40 60 60 100 120 Time (min) -- Fluids at 7249 ft - Acquired 0 Out - Acquired 0 In "" T Sa - 0 Out as o I 0 20 40 60 80 100 120 Time (min) Page 8 0P23- WW02.cfw,02 -19 -2009, LoadCase9- 5/ 8 Intermediate Casing (a): Version wcscem452_07 Client : Eni Petroleum Well SdIbirger Well W OP23 -W02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) * CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US n Depth = 4225 ft n Depth = 7249 ft_ • • — Frac ,— — Frac — Fbre — Pore — Hydrostatic — Hydrostatic • — uynamc — uynamc in_ in mr _ V c E as im co cm y co a a Li o g Ii U a) a) co 120 0 30 60 90 0 30 60 90 120 t Time (min) Time (min) s 1 Total Depth = 7249.0 ft Top of Cement = 6249.0 ft E *Mark of Schlumberger I Page 9 OP23- VVVV02.cfw; 02 -19 -2009; LoadCase 9 -5/B Intermediate Casing (a); Version wcs- cem452_07 • • Client : Eni Petroleum Well : OP23 -WW02 I' String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Section 4: centralizer placement Top of centralization :6249.0 ft Bottom Cent. MD :7029.0 ft Casing Shoe :7249.0 ft NB of Cent. Used :20 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint ( %) (ft) 7049.0 20 1/1 541 - STL -9 5/8 -6 -36 (.171") 3.0 6269.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (Ibf) 541 - STL -9 5/8 -6 -36 9 5/8 13.126 9.720 No Houma 12.250 238.30 1690.56 (.171 ") (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 OD specifications Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer /Formation :0.3 Total Drag Force :6 ton Hook Toad Down Stroke :159 ton Hook load Up Stroke :170 ton Page 10 0823- WW02cfw, 02 -19 -2009, LoadCase9- 5/ 8 Intermediate Casing (a): Version wcs- cem452_07 • 0 Client : Eni Petroleum S rg�r Well : 0P23 -WW02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) * CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US ton ft c 0 25 50 7 100 125 150 175 — Hookload Up I – – Hookload Dow n I - - - - Weight - 1 – – Drag Force S 1 \. I \- I \, 1 \ • . I \. E I \. 1 I I \ I \'. 1 \ u I \'. • E 1 \ I \ I \. v 1 \' W - s .t Running Forces O Friction Factor = 0.3 Total Depth = 7249.0 ft Top of Cement = 6249.0 ft O 'Mark of Schlumberger SdiMillir Page 11 OP23-WW02.cfw , 02-19-2009 , LoadCase 9-5/8 Intermediate Casing (a), Version wcs-cem452_07 • Client : Petroleum Well Schlumberger Well 0P OP23 -WW02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9-5/8 Intermediate Casing (a) ft °!o 0 I JO 60 80 100 - Between Cent. __- I I +Pt Cent. 0 oo - Pipe Standoff Page 12 0P23- WW02.cfw:02 -19 -2009; LoadCase 9-5/8 Intermediate Casing (a); Version wcs- cem452_07 S 0 Client : E Petroleum Well Schlumberger Well l OP 23 -WW02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Section 5: WELLCLEAN II Simulator ft aye 41 .1 80 100 Std Betw. Cent. -- Cement Coverage 0 0 o - I ___- ti oN7 0 1 ' 0 0 Cement Coverage Fluids Concentrations Risk Mud on the Wall z I 6300 z -800 5300- 6300 5400- 6400 4444 _8404 6500 - 6500 6540 _ 6500 _ 6600 6600 6600 - 6600 6700 - 6700 --- `- 6 - 8700 c s r 2 8 '. asoo 6800 v • B$00 8 i ° 6900 - 6900 ° ° 6900 - 6900 ° 7000- 7000 7000 7000 7100 7100 7100 —7 100 7200= 7200 7200 -7200 O ` f mi G ti o z z Mud ® High Low 1 ---- 7 Inter. Tail FT Medium Iii None F1 MUDPUSHII Page 13 0P23 -W W02.cfw , 02 -19 -2009 , LoadCase 9 -5/8 Intermediate Casing (a) , Version wcs- cem452_07 • Client : Eni Petroleum Well : 0P23 -WW02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9-5/8 lntermediate Casing (a) Section 6: fluid description Mud DESIGN Fluid No: 1 Density : 9.80 lb/gal Rheo. Model : HERSCHEL_B. k : 1.08E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.506 Ty :15.431bf/100ft2 Gel Strength : (Ibf /100ft2) MUD Mud Type : WBM Job volume : 524.8 bbl Water Type : Fresh VOLUME FRACTION Solids : 4.0 % Oil : 0.0 % Water : 96.0 % MUDPUSH II DESIGN Fluid No: 2 Density : 12.80 lb/gal Rheo. Model : HERSCHEL_B. k : 2.26E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.435 Ty : 13.81 lbf/100ft2 Gel Strength : (Ibf /100ft2) Job volume : 40.0 bbl Inter. Tail DESIGN Fluid No: 5 Density : 15.80 lb/gal Rheo. Model : HERSCHEL_B. k : 3.93E -3 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.903 Ty : 26.99 Ibf/100ft2 Gel Strength : (Ibf /100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid : 5.100 gal /sk Job volume : 75.6 bbl Dry Density : 199.77 lb/ft3 Yield : 1.16 ft3 /sk Quantity : 364.98 sk Sack Weight : 94 lb Solid Fraction : 41.4 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.100 gal /sk Additives Code Conc. Function D046 0.200 %BWOC Antifoam D065 0.300 %BWOC Dispersant D153 0.200 %BWOC Antisettling D167 0.350 %BWOC Fluid loss Page 14 OP23- WW02.cfw, 02 -19 -2009, LoadCase 9-5/8 Intermediate Casing (al, Version wcs- cem452_07 Client : Eni Petroleum Well : 0P23 -WW02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) Section 7: operator summary Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl /min) (bbl) (min) (bbl) MUDPUSH II 4.0 40.0 10.0 40.0 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 4 -Drop Bottom Plug Inter. Tail 4.0 75.6 18.9 75.6 9 -Start Cement Slurry Pause 0.0 0.0 5.0 0.0 18 -Drop Top Plug Mud 8.5 490.0 57.6 490.0 19 -Start Displacement Mud 3.0 34.8 11.6 524.8 21 -Bump Top Plug Total Pumping Time : 01:48 hr:mn End Job: Bump Plug; Check floats TOTAL MATERIAL REQUIREMENTS Mix Water Requirements : Fresh water 77 bbl MIXING PREPARATION MUDPUSH II Volume : 40.0 bbl Density : 12.80 Ib /gal Code Quantity Design Fresh water 33.169 bbl D182 199.015 Ib 6.000 lb/bbl of base fluid D031 9714.372 Ib 242.86 lb /bbl of spacer Inter. Tail Volume : 75.6 bbl Density : 15.80 Ib /gal Yield : 1.16 ft3 /sk Dry Phase Liquid Phase Blend : (Ib) Design Mix Water 44.3 bbl 10.0 bbl LAS Design G 34308.496 Ib Fresh water 44.322 bbl 10.001 bbl D046 68.617 Ib 0.200 %BWOC D065 102.925 Ib 0.300 %BWOC D153 68.617 Ib 0.200 %BWOC D167 120.080 Ib 0.350 %BWOC Page 15 0P23 -VVW02 cfw; 02 -19 -2009, LoadCase 9-5/8 Intermediate Casing (a), Version wcs- cem452_07 • Client : Eni Petroleum Well 0 SchIiherger P23 -WW02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Loadcase : 9 -5/8 Intermediate Casing (a) CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : Intermediate Casing District : Prudhoe Bay, Alaska Country : US Annulus ID : 9.625 in - OD : 12.823 in co CO - MUDPl1SH II Mud - Inter. Tail CD O Co O Co cD N O E co I Y 2 co > ▪ 2 C 0 C 0 € LL V- cO M i9 i I i i I i i i I I i 4.8 5.2 5.6 6.0 6.4 6.8 7.2 7.6 8.0 8.4 8.8 9.2 Flow Rate (bbl /min) s I • ■ Mid Herschel : k = 1.08E-2 Ibf.s ^n /ft2 n = 0.506 Ty = 15.43 Ibf /100ft2 ■ MJDPUSH II Herschel : k = 2.26E-2 Ibf.s ^n/ft2 n = 0.435 Ty = 13.81 Ibf /100ft2 ■ Inter. Tail Herschel : k = 3.93E-3 Ibf.s ^n /ft2 n = 0.903 Ty = 26.99 lbf/100ft2 *Mark of Schlumberger Page 16 0P23- 1NW02.cfw. -19 -2009, LoadCase 5/ 8 Intermediate Casing lal , Version wcs- cem452_07 • • Schlumberger C em CAD E *well cementing recommendation for 7" Liner Operator : Eni Petroleum Well : OP23 -WW02 Country : US Field : Nikaitchuq State : Alaska Prepared for : Mr. Joe Longo Location : Oliktok Point Proposal No. : Draft v2 Service Point : Prudhoe Bay, Alaska Date Prepared : 2 -19 -2009 Business Phone : 907 - 659 -2434 FAX No. : 907 - 659 -2538 Prepared by : Tony Stafford Phone : 907 - 273 -1700 E -Mail Address : tstafford@slb.com � c 40 AT E Disclaimer Notice This information is presented in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perform these services Freedom from infringement of patents of Schlumberger or others is not to be inferred. Mark of Schlumberger • . Client : Eni Petroleum P R IP l chu b Well : 0P23 -WW02 S .. '�! :!! J. J • String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Section 1: well description Configuration : Liner Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 10507.0 ft BHST : 210 degF Bit Size : 8 1/2 in ft (x 1000) psi 0 6 9 Frac Pore Permafrast S; Shale T /Cosh 1 — CD • a 4 o co Shale ti t 0 N Well Lithology Formation Press. Page 2 OP23- WW02.cfw; 02 -19 -2009; LoadCase 7in Liner (a); Version wcs- cem452_07 • • Client : Petroleum Well Schl krger Well 0P OP23 -WW02 String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Previous String MD OD Weight ID (ft) (in) (lb /ft) (in) 7249.0 9 5/8 47.0 8.681 Drill Pipe MD OD Weight ID Grade Collapse Burst (ft) (in) (lb /ft) (in) (psi) (psi) 7049.0 5 19.5 4.276 E -75 9960 9500 Liner Hanger : 7049.0 ft Landing Collar MD : 10427.0 ft Casing /liner Shoe MD : 10507.0 ft Casing /Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb /ft) (in) (psi) (psi) 10507.0 7 40.0 26.0 6.276 L -80 5410 7240 LTC , Page 3 OP23 -WW02 cfw , 02 -19 -2009 , LoadCase 7in Liner (a) , Version wcs- cem452_07 • • Client : Eni Petroleum Well : OP23 -WW02 SOIMIl String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Mean OH Diameter : 8.500 in Mean Annular Excess : 25.0 % Mean OH Equivalent Diameter: 8.835 in Total OH Volume : 247.1 bbl (including excess) Max. Deviation Angle : 36 deg Max. DLS : 3.037 deg /100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg /100ft) 7700.0 7013.2 12.5 15.7 0.000 7800.0 7110.9 12.5 15.7 0.000 7900.0 7208.5 12.5 15.7 0.000 8000.0 7306.1 12.5 15.7 0.000 8100.0 7403.8 12.5 15.7 0.000 8200.0 7501.4 12.5 15.7 0.000 8300.0 7599.1 12.5 15.7 0.000 8400.0 7696.7 12.5 15.7 0.000 8500.0 7794.4 12.5 15.7 0.000 8600.0 7892.0 12.5 15.7 0.000 8700.0 7989.6 12.5 15.7 0.000 8800.0 8087.3 12.5 15.7 0.000 8900.0 8184.9 12.5 15.7 0.000 9000.0 8282.6 12.5 15.7 0.000 9100.0 8380.2 12.5 15.7 0.000 9200.0 8477.9 12.5 15.7 0.000 9300.0 8575.5 12.5 15.7 0.000 9348.8 8623.2 12.5 15.7 0.000 9400.0 8673.2 12.5 15.7 0.000 9451.2 8723.2 12.5 15.7 0.000 9500.0 8770.8 12.5 15.7 0.000 9600.0 8868.5 12.5 15.7 0.000 9691.9 8958.2 12.5 15.7 0.000 9700.0 8966.1 12.5 15.7 0.000 9800.0 9063.7 12.5 15.7 0.000 9900.0 9161.4 12.5 15.7 0.000 10000.0 9259.0 12.5 15.7 0.000 10100.0 9356.7 12.5 15.7 0.000 10200.0 9454.3 12.5 15.7 0.000 10300.0 9552.0 12.5 15.7 0.000 10301.3 9553.2 12.5 15.7 0.000 10306.4 9558.2 12.5 15.7 0.000 10400.0 9649.6 12.5 15.7 0.000 10454.9 9703.2 12.5 15.7 0.000 10500.0 9747.2 12.5 15.7 0.000 10507.0 9754.1 12.5 15.7 0.000 Page 4 OP23 -WW02 cfw, 02 -19 -2009, LoadCase 7in Liner (a), Version wcs- cem452_07 • • Client : Eni Petroleum Well Schlumdergur Well OP23 -WW02 String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Formation Data MD Frac. Pore Name Lithology (ft) (Ib /gal) (lb /gal) 154.0 11.20 9.00 Permafrost Sandstone 1901.0 12.00 9.00 Permafrast Sandstone 5030.0 16.00 9.00 T /Cosh 1 Shale 7249.0 16.00 9.00 Shale 10507.0 16.00 9.00 Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF /100ft) 0.0 0.0 20 0.0 1901.0 1828.9 32 0.7 4225.0 3725.4 50 0.8 7249.0 6589.4 95 1.1 10507.0 9770.7 210 1.9 ft degF (x 1000) ft Q_ 0 250 1 2 3 4 — Geoth.Profile I — Hon. Depart. N \ O O - \ - a 1 n Li-) O \ \ I \ O O `— (o x o 0 O — N CO k co rn 0 0 0 cv Temperature Hari. Departure Page 5 OP23- WW02.cfw ; 02 -19 -2009 ; LoadCase 7in Liner (a), Version wcs- cem452_07 • • Client : Petroleum Well Schlemberger Well 0P OP23 -WW02 String . 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Section 2: fluid sequence Job Objectives: Zonal Isolation: TOC at Liner Hanger 7,049' MD Original fluid Mud 10.00 lb /gal k : 1.08E -2 Ibf.s ^n /ft2 n : 0.506 Ty : 15.43 Ibf/100ft2 Displacement Volume 254.5 bbl Drill Pipe Volume 125.2 bbl Total Volume 394.6 bbl TOC 7049.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb /gal) MUDPUSH II 40.0 817.6 6231.4 13.00 k:2.26E -2 Ibf.s ^n /ft2 n:0.435 Ty:13.81 Ibf /100ft2 Liner Slurry 100.2 3458.0 7049.0 15.80 k:3.93E -3 Ibf.s ^n /ft2 n:0.903 Ty:26.99 lbf/100ft2 Mud 254.5 0.0 10.00 k:1.08E-2 lbf.s^n/ft2 n:0.506 Ty:15.43 lbf/100ft2 Static Security Checks : Frac 1871 psi at 7249.0 ft Pore 526 psi at 7249.0 ft Collapse 3771 psi at 10427.0 ft Burst 7240 psi at 10427.0 ft Csg.Pump out 70 ton ft (x 1000) psi 0 9 Hydrostatic 1 — Frac Pore o v o OD 0 o- 0 cv Fluid Sequence Static Well Security Page 6 0P23- WW02.cfw:02 -19 -2009; LoadCase 7in Liner (a), Version wcs-cem452_07 • . Client : E Petroleum Well I ier Well OP W 23 -W02 String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Section 3: pumping schedule Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Pumping Schedule Name Flow Rate Volume Stage Time Cum.Vol Inj. Comments (bbl /min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 4.0 40.0 10.0 40.0 80 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 16 -Start Mixing Tail Slurry Liner Slurry 4.0 100.2 25.0 100.2 80 9 -Start Cement Slurry Pause 0.0 0.0 5.0 0.0 80 36 -Drop Dart Mud 6.0 220.0 36.7 220.0 80 19 -Start Displacement Mud 3.0 34.5 11.5 254.5 80 36 -Drop Dart Total 01:33 394.6 bbl hr:mn End Job: Bump Plug; Check floats Dynamic Security Checks : Frac 1268 psi at 10507.0 ft Pore 342 psi at 7249.0 ft Collapse 3771 psi at 10427.0 ft Burst 5740 psi at 7049.0 ft Temperature Results BHCT 157 degF Simulated Max HCT 210 degF Simulated BHCT 135 degF Max HCT Depth 10507.0 ft CT at TOC 113 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time I (hr:mn) (hr:mn) I Geo. Temp. Top of Cement (degF) (degF) 92 degF Bottom Hole (degF) (degF) 210 degF Page 7 0P23- WW02.cfw , 02 -19 -2009 , LoadCase 7in Liner (a) , Version wcs- cem452_07 0 • Client : E Petroleum Well Schl rger Well OP W 23 -W02 String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) °c (--.1 — Calc. WHP i i C — Calc. Pump Press. -___ c i. __ 1 - .. t I i i t r ;! N ' I O. I I I 1 / 0 0 20 40 60 80 100 Time (min) Fluids at 10507 ft a. - - - -- - - - - -- .. — — Acquired 0 Out ti, — Acquired 0 In — Q Out - Q In I cu cu ■ it ) i f \` i LT o r 0 20 40 60 80 100 Time (min) Page 8 OP23- WW02.cfw : 02 -19 -2009 ; LoadCase 7in Liner (al ; Version wcs- cem452_07 • 0 Client : Eni Petroleum Well OP 23 -WW02 Schhokair String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) * CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : 7" Liner District : Prudhoe Bay, Alaska Country : US Depth = 7249 ft _ Depth = 10507 ft — Frac - Frac - Pore - Fbre f0 - Hydrostatic - Hydrostatic uynamc - uynamc c co m c rn o E N N 4 co N co N cu (NI a 1 a c U O O IA 8 co co d g 0 20 40 60 80 100 0 20 40 60 80 100 A Time (min) Time (min) 0 Total Depth = 10507.0 ft Top of Cement = 7049.0 ft II I *Mark of Schlumberger Sdilinbillir Page 9 OP23- WW02.cfw ; 02 -19 -2009 ; LoadCase 7in Liner (a) ; Version wcs- cem452_07 • • Client : Eni Petroleum Well : OP23 -WW02 1 ' 1 MI pi String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Section 4: centralizer placement Top of centralization :7049.0 ft Bottom Cent. MD :10377.0 ft Casing Shoe :10507.0 ft NB of Cent. Used :66 NB of Floating Cent. :0 Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth (ft) Joint ( %) (ft) 8627.0 26 2/3 NW- ST- 7 -6 -ST A1A 75.1 8587.0 10227.0 32 4/5 NW- ST- 7 -6 -ST A1A 80.8 8644.5 10387.0 8 2/1 NW- ST- 7- 6 -STA1A 95.4 10377.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (Ibf) (Ibf) NW- ST- 7 -6 -ST A1A 7 9.610 8.232 No Hannover 8.500 442.87 4586.10 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 1 OD specifications Running Force Calculations: Travelling Block Weight :33 ton Friction Factor Centralizer /Formation :0.3 Total Drag Force :14 ton Hook load Down Stroke :110 ton Hook load Up Stroke :138 ton Page 10 OP23- WW02.cfw, 02 -19 -2009 , LoadCase 7in Liner (a), Version wcscem452_07 0 0 1 Client : Eni Petroleum SchI rgcr Well : 0P23 -WW02 String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) * CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : 7" Liner District : Prudhoe Bay, Alaska Country : US ton ft 0 0 _ 20 40 60 80 100 _120 140 t — Hookbad Up 1 — — Hookload Down 1 - - - - Weight \ N. — — Drag Force \ 1 \ 1 \ 1 \ • 1 \ 1 1 1 \ ., 1 1 E I \ V - I \ I \ I I \\ >` 1 I v I \ U I \ \ § I I \ \ N 7, s 8 A Running Forces 0 Friction Factor = 0.3 Total Depth = 10507.0 ft Top of Cement = 7049.0 ft *Mark of Schlumberger kiiiirpr Page 11 OP23- WW02.cfw; 02 -19- 2009; LoadCase 7in Liner (al ; Version wcs- cem452_07 I s • Client : E Petroleum Well Schlumhurgcr Well OP 23 -WW02 String 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) ft % 75 Rfl 90 95 100 Between Cent. I + +At Cent. 1 , I 11 _ ... . I III I 111 1 111u11111111 ill 1111 111 CD __ —_ 111111111 1 1. II ► -. I i._,_ I] N Pipe Standoff Page 12 OP23- WW02.cfw , 02 -19 -2009 , LoadCase 7in Liner (a) , Version wcs- cem452_07 • • Client : E Petroleum Well Schlem erger Well OP 23 -WW02 String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Section 5: WELLCLEAN II Simulator ft % 75 nn 05 90 95 100 L Std Betw. Cent . I I I 1 - Cement Coverage II 4 a 1 1 Ilh -4- 1111111111101100 ill nu 1 ._., ui :nnIr ! i o iiiiIIi„�, I r t I ' I . ■ r■■ c Cement Coverage Fluids Concentrations Risk Mud on the Wall g z g 2 7000 -1 -7000 7000 7000 7500- -7500 7500 7500 8000- -8000 8000 8000 8500 -8500 - t 0500 8500 Z. j _ S t L I- 9000- -9000 a m 9000 9000 a 0 0 0 a 9500 -9500 9500 9500 10000- -10000 113000 10000 105001 - 10500 10500 10500 3 • o z z Mil Mud I ( Hitch NM Low I I Liner Slurry ( I Medium I i None ri MUDPUSHII Page 13 OP23 -W W02 cfw , 02 -19 -2009 , LoadCase 7in Liner la) , Version wcs- cem452 • • Client : Eni Petroleum ,I Well : 0P23 -WW02 wpi String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Section 6: fluid description Mud DESIGN Fluid No: 1 Density : 10.00 lb/gal Rheo. Model : HERSCHEL_B. k : 1.08E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.506 Ty :15.431bf/100ft2 Gel Strength : (Ibf/100ft2) MUD Mud Type : WBM Job volume : 254.5 bbl Water Type : Fresh VOLUME FRACTION Solids : 4.0 % Oil : 0.0 % Water : 96.0 % MUDPUSH II DESIGN Fluid No: 2 Density : 13.00 lb/gal Rheo. Model : HERSCHEL_B. k : 2.26E -2 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.435 Ty : 13.81 lbf/100ft2 Gel Strength : (lbf/100ft2) Job volume : 40.0 bbl Liner Slurry DESIGN Fluid No: 6 Density : 15.80 lb/gal Rheo. Model : HERSCHEL_B. k : 3.93E -3 Ibf.s ^n /ft2 At temp. : 80 degF n : 0.903 Ty :26.99lbf/100ft2 Gel Strength : (Ibf /100ft2) DESIGN BLEND SLURRY Name : G Mix Fluid : 5.081 gal /sk Job volume : 100.2 bbl Dry Density : 199.77 lb/ft3 Yield : 1.16 ft3 /sk Quantity : 483.24 sk Sack Weight : 94 lb Solid Fraction : 41.6 % BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.081 gal /sk Additives Code Conc. Function D046 0.200 %BWOC Antifoam D065 0.300 %BWOC Dispersant D153 0.200 %BWOC Antisettling D167 0.350 %BWOC Fluid loss D800 0.300 %BWOC Retarder Page 14 OP23- WW02.cfw, 02 -19 -2009, LoadCase 7in Liner (a), Version wcs- cem452_07 • • Client : Eni Petroleum II Well : OP23 -WW02 n String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) Sect 7: operator summary Start Job: Circulate Two Hole Volumes; Safety Meeting; Test Surface Equipment Operator Pumping Schedule Name Flow Rate Volume Stage Time Cum Vol Comments (bbl /min) (bbl) (min) (bbl) MUDPUSH II 4.0 40.0 10.0 40.0 7 -Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 16 -Start Mixing Tail Slurry Liner Slurry 4.0 100.2 25.0 100.2 9 -Start Cement Slurry Pause 0.0 0.0 5.0 0.0 36 -Drop Dart Mud 6.0 220.0 36.7 220.0 19 -Start Displacement Mud 3.0 34.5 11.5 254.5 36 -Drop Dart Total Pumping Time : 01:33 hr:mn End Job: Bump Plug; Check floats TOTAL MATERIAL REQUIREMENTS Mix Water Requirements : Fresh water 91 bbl MIXING PREPARATION MUDPUSH II Volume : 40.0 bbl Density : 13.00 Ib /gal Code Quantity Design Fresh water 32.885 bbl D182 197.309 lb 6.000 lb/bbl of base fluid D031 10151.336 Ib 253.78 lb /bbl of spacer Liner Slurry Volume : 100.2 bbl Density : 15.80 Ib /gal Yield : 1.16 ft3 /sk Dry Phase Liquid Phase Blend : (Ib) Design Mix Water 58.5 bbl 10.0 bbl LAS Design G 45424.867 Ib Fresh water 58.464 bbl 10.001 bbl D046 90.850 Ib 0.200 %BWOC D065 136.275 Ib 0.300 %BWOC D153 90.850 Ib 0.200 %BWOC D167 158.987 Ib 0.350 %BWOC D800 136.275 Ib 0.300 %BWOC Page 15 OP23- WW02.cfw , 02 -19 -2009 , LoadCase 71n Liner (a) , Version wcs- cem452_07 • • Client : Eni Petroleum Well rger Well OP23 -WW02 String : 7 District : Prudhoe Bay, Alaska Country : US Loadcase : 7in Liner (a) CemCADE Client : Eni Petroleum Well : OP23 -W W 02 String : 7" Liner District : Prudhoe Bay, Alaska Country : US Annulus ID : 7.000 in - OD : 8.835 in 0 0 N - NUDPUSH II - Mud - Liner Slurry u7 0 0 0 LO o Q- Lo csi (/) 4 o a >" c 0 0 0 • U- 3' u7 n 1.6 2.0 2.4 2.8 3.2 3.6 4.0 4.4 4.8 5.2 5.6 6.0 6.4 Flow Rate (bbl /min) 0 ■ M.id Herschel : k = 1.08E-2 Ibf.s ^n /ft2 n = 0.506 Ty = 15.43 lbf/100ft2 ■ MUDPUSH II Herschel : k = 2.26E2 lbf.s ^n /ft2 n = 0.435 Ty = 13.81 Ibf /100ft2 ■ Liner Slurry Herschel : k = 3.93E-31bf.s ^ n /ft2 n = 0.903 Ty = 26.99 Ibf /100ft2 'Mark of Schlumberger Page 16 OP23- WW02.cfw, 02 -19 -2009: LoadCase 7in Liner (a) Version wcs- cem452_07 0 • Oliktok Point Cin P tlroo I IC�LuInn1 O P23 -WW02 t�ng North Slope - Alaska DIR I LWD FORM DEPTH Est. Spud Date HOLE CASING MUD INFO Cased/ Open Hole MWD MD I TVD April 1 -15, 2009 SIZE _ SPECS Log Info Top of Permafrost 0' 0' 20" 20" Conductor Shoe 154' 154' N/A Welded / Driven N/A MWDIGR 7)o x RES /APWD 0 o 0 Surface Csg n N n 13 -3/8" m Cr) 68 lbs/ft r r- - r L -80, BTC KOP:400' B/ Permafrost 1,901' 1,812' m m 9 -9.2 ppg 9.2 -9.6 ppg DLS: 1.5 -3 °/100' EOB:1850 MD © Top of Tail 3,725' 3,296' 35.55° 0 0 m x m n n m m m m m '� 13-3/8" Casing Point 4,225' 3,703' ■ 16" 50 F WBM MWD /GR/ 1 RES /APWD ` Inter. Casing 9 -5/8" 47 lbs/ft 9. - 9. 9 ppg L -80, BTC -M 9 -5/8" Drop © 4245' MD Top of Cement 6,249' 5,596' 47 lbs/ft DLS: 2 °/100' 13CrL80, Vam Top EOD: 5400' MD © n 7` 12.46° r ill' D€ olp) r, x0' :A rn 7 TOL 7,049' 6,378' 9 -518" Casing Point 7,249' 6,573' 12 -1/4" 95 " F WBM MWD /GR/ RES /APWD Sail Angle: 12.46° , l;t°1 Production Liner 7 „ 26 lbs/ft +/ -10.0 ppg CI 01 13CrL -80, Vam Top Sag D 9,349' 8,623' N'N x-16 �' T/ Ivishak 9,692' 8,958' CI '' B/ Ivishaq 10,306' 9,558' Proposed TD 10,507' 9,754' 8 -1/2" 210 F WBM • 1 Formation Integrity And Leak Off Test Procedure Drilling Operations 1. After cementing casing and nippling up BOP Equipment, RIH to top of cement and pressure test the casing to the test pressure specified in the well plan (usually 2500 - 3000 psi) for 30 minutes and record on a chart (AOGCC required casing integrity test). The slowest possible pump rate is preferred to allow detection of leaks. Pump rates of 1/4 to 1 BPM are typical; however, adjust the pump rate to match the test pump capability to maintain a constant pump rate. Record pressures approximately every 1/4 bbl on the Pressure Integrity Test (PIT) Form (you can locate on the drilling N drive). Plot the casing pressure test (volume versus pressure), and indicate how long the pressure is held on the casing. Verify that the test data forms a straight line and there is no air entrained in the mud, or leaks in the system. Repeat the casing pressure test if needed, especially if a straight line cannot be established at the higher test pressures. 2. Drill 20' to 50' of new hole below the casing shoe. 3. Circulate the hole to establish a uniform mud density throughout the system (required for a good downhole pressure test). Pick up into the shoe. 4. Close the blowout preventer (ram or annular). 5. Pump down the drill string at a rate approximating that used to test the casing in Step No. 1. Lower pump rates are preferred in order to minimize friction pressures losses (especially with long strings of small drillpipe) which are ignored in the calculations; however, adjust the pump rate to match the test pump capability and maintain a constant pump rate. Pump rates between 1/4 and 1 -1/2 BPM are typical, with higher rates applicable to tests conducted with large intervals of open hole. 6. On the PIT Form, plot the fluid pumped (volume or strokes) vs. drill pipe pressure. Record pressures approximately every 1/4 bbl pumped. The data points should initially form a straight line with a similar slope to the casing integrity test as the system compressibility's are similar. Eventually, the formation begins to take fluid; at this point the pressure will continue to rise, but at a slower rate and the data points will deviate from the straight line. The first, sustained occurrence of this departure is the leak -of point (see Figure 1). Pump an additional 3 bbls after the suspected leak -off point is reached to assure continued decreasing slope on the pressure versus volume plot. If a straight line cannot be established during initial pumping (suggesting a surface leak or air in the system) or a clear leak -off point is not indicated, consider re- running the test. Be sure to bleed all pressure off the system prior to re- running the test. A slightly higher pump rate may be considered if a clear departure is not indicated on the pressure versus volume plot. Small filtration fluid losses can cause a slope change, especially at slow pump rates, and confuse the identification of a more definitive leak off point. Note: If the maximum EMW specified in the wellplan is reached without indication of leak -off, shut down and hold the pressure there. This becomes the data for a formation integrity test (FIT) instead of a leak off test (LOT) 7. Shut down when the leak -off point is observed and 3 bbls of mud have been pumped into the formation. Record the instantaneous shut -in pressure (ISIP). With the pump shut down, monitor and record a 15 second and 30 second shut -in pressure and the shut -in pressures for a minimum of 10 minutes (at 30 second intervals) or until the shut -in pressure stabilizes. Plot the information and record the LOT point or FIT point on the PIT Form. Bleed the pressure off and record the fluid volume recovered if possible. If in doubt of the leak off point, contact the Drilling Superintendent to discuss and evaluate the test. Upon completion of the test, forward the data to the Drilling Engineer in Anchorage. The Drilling Engineer will forward the information to the proper Agencies. • • NOTE: Pumping to the leak -off point plus 3 bbls is less critical for casing shoes other than surface casing, but it is important to pump enough to ensure a good LOT and not a spurious departure. 8. Corrective measures will be performed if the open hole pressure integrity fails to meet predetermined standards. The Drilling Supt. is to be notified immediately of any LOT or FIT that results in less than adequate formation integrity as defined in the Well Plan. Do not drill ahead until the inadequate formation integrity is addressed. Tic a 1 LOT 1 � Maximum Pressure #1/4 — 4 0 Formation Breakdown Pressure 1 Anticipated Pressure Mil A Fracture Leak Off Point wippro o ' Propagation , Pressure Shut In maim . °. °o� Fracture PM.--- In ° ❑ ❑ Pressure Instst ants -ous "No ❑ ❑ ❑ ❑ ❑ ❑ Pressure Volume and Shut -in Time • • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4-24 2 12/23/oe JFC JMS Add New Well Conductor OP26 Oliktok 0 OLIKTOK Point 5 014 1 INTAKE DOCK \ OPP 'y ' THIS MODULE (t -4 e * SURVEY • v■ *3 \ , , _LJ N • .---: - 9 sz ''. ' It, DS-3R RONIt . , 1 CM %. i __ ....a . • ' DEW LAE ..'' SITE k ../.. `-,.... i l K ---4L - OLIKTOK POINT MODULES I 7. N IC STAGING T13N, R9E SCALE: 4 1 = 150' ., D-3O ., ! ' . - .. . 1! / .. (15-i 1 .?., . STP PAD \ VICINITY MAP \ o SCALE: 1" = 1 Mile -c, \ 0 ,r) o r 0 \ Q.,-0 0 0 Ora 090 c o A \ 0 \\\N -oi \ -•0 09. o L K> o- 0 .0 l• („34- .• \ 0 \ / \ 0 • ,_. . OLIKTOK \ 0 POINT PAD \ .3 ,D 6) \ o • 0 \ \ ' \ ) 0 \ / \ \ SEE SHEET 3 FOR NOTES / \ \ • / / • Existing Conductor /*----' 1 LOUNSBURY & ASSOCIATES. INC. • Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS lo i AREA: MODULE: UNIT: Einill Petroleum OLIKTOK POINT PAD WELL CONDUCTOR Elillr,-. ........- ..... . ASBUILT LOCATIONS CADD FILE NO. I DRAWING NO: I PART: I REV: LK680DI 10/9/08 I NSK 6.80-d1 1 OF 3 I 2 0 • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductors 4 -24 2 12/23/08 JFC JMS Add New Well Conductor OP26 PROTRACTED SECTION 5, T. 13 N., R. 9 E., UMIAT MERIDIAN AK STATE PLANE (NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. 'y' 'X NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP -I1 6,036,332.70 1,656,791.89 70° 30' 39.015" 149° 51' 57.587" 2,052 1,519 12.1 4.0 OP -12 6,036,328.85 1,656,784.83 70° 30' 38.977" 149° 51' 57.795" 2,056 1,526 12.2 4.0 0P03 -P05 6,036,325.10 1,656,777.76 70° 30' 38.940" 149° 51' 58.004" 2,059 1,533 12.2 4.0 0PO4 -P07 6,036,321.43 1,656,770.69 70° 30' 38.904" 149° 51' 58.212" 2,063 1,541 12.2 3.8 OP05 6,036,317.71 1,656,763.67 70° 30' 38.868" 149° 51' 58.419" 2,067 1,548 12.2 3.7 OP06 6,036,313.96 1,656,756.55 70° 30' 38.831" 149° 51' 58.629" 2,070 1,555 12.2 3.6 OP07 6,036,306.41 1,656,742.45 70° 30' 38.757" 149° 51' 59.045" 2,078 1,569 12.2 3.5 OP08 6,036,302.66 1,656,735.36 70° 30' 38.720" 149° 51' 59.254" 2,082 1,576 12.2 3.5 OP09 6,036,298.90 1,656,728.32 70° 30' 38.683" 149° 51' 59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70° 30' 38.647" 149° 51' 59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70° 30' 38.610" 149° 51' 59.878" 2,093 1,597 12.2 3.8 OP12 6,036,287.63 1,656,707.14 70° 30' 38.573" 149° 52' 00.086" 2,097 1,604 12.2 4.0 0P13 6,036,276.37 1,656,685.97 70° 30' 38.463" 149° 52' 00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70° 30' 38.426" 149° 52' 00.920" 2,112 1,633 12.2 3.5 OP15 6,036,268.88 1,656,671.79 70° 30' 38.389" 149° 52' 01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70° 30' 38.353" 149° 52' 01.337" 2,119 1,647 12.2 3.3 OP17 6,036,261.36 1,656,657.70 70° 30' 38.316" 149° 52' 01.545" 2,123 1,654 12.2 3.2 OP18 6,036,257.62 1,656,650.62 70° 30' 38.279" 149° 52' 01.753" 2,127 1,681 12.2 3.1 OP19 6,036,250.09 1,656,636.50 70° 30' 38.205" 149° 52' 02.170" 2,134 1,675 12.2 2.5 OP20 6,036,246.31 1,656,629.41 70° 30' 38.168" 149° 52 02.379" 2,138 1,682 12.2 2.2 OP21 6,036,242.57 1,656,622.39 70° 30' 38.132" 149° 52' 02.586" 2,141 1,689 12.2 1.9 OP22 6,036,238.82 1,656,615.39 70° 30' 38.095" 149° 52' 02.793" 2,145 1,696 12.2 1.7 OP23 6,036,235.05 1,656,608.27 70° 30' 38.058" 149° 52' 03.003" 2,149 1,703 12.2 1.5 OP24 6,036,231.36 1,656,601.27 70° 30' 38.022" 149° 52 03.209" 2,153 1,710 12.2 1.3 I i ( j DISPOSAL WELLS I i j i E AK STATE PLANE (NAD83) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD O.G. WELL NO. "1" 'X NAD83 NAD83 OFFSET ELEV. ELEV. F.N.L. F.E.L. OP25 6,036,004.35 1,656,510.91 70° 30' 35.791" 149° 52 05.885" 2,380 1,802 12.2 -2.7 OP26 6,036,012.10 1,656,525.47 70° 30' 35.867" 149° 52' 05.456" 2,372 1,787 12.2 -2.7 LOUNSBURY & ASSOCIATES, INC. S ORYSYORS RNGINESRS PLANNERS ..,$.. AREA: MODULE: UNIT: f -, _ E i etro(Ie tum WELL CONDUCTOR POINT TOR D ASBUILT LOCATIONS CADD FILE NO. I DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80 -d1 2 OF 3 I 2 • REV DATE BY CK APP DESCRIPTION REV DATE BY CK APP DESCRIPTION 1 12/16/08 MRT AJR Add New Well Conductos 4-24 2 12/23/06 JFC JMS Add New Well Conductor OP26 NOTES 1. COORDINATES SHOWN ARE A.S.P. ZONE 4, NAD 83. DISTANCES SHOWN ARE TRUE HORIZONTAL DISTANCES. 2. GEODETIC COORDINATES SHOWN ARE NAD 83. 3. BASIS OF LOCATIONS ARE DERIVED FROM OPUS SOLUTIONS. 4. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 5, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 5. ALL ELEVATIONS SHOWN ARE B.P.M.S.L. DATUM. 6. SEE LOUNSBURY DOCUMENT L -2539 FOR NAD27 INFORMATION. • SURVEYOR'S CERTIFICATE „ • '•• ��, '• ♦� I HEREBY CER77FY THAT I AM PROPERLY � � h / \ ,• ♦� REGISTERED AND LICENSED TO PRAC77CE / , LAND SURVEYING IN 7HE STATE OF 0 �o •" ♦ r" - J . ROOKUS / 81 ALASKA AND THAT THIS PLAT REPRESENTS ♦ °. L S ♦ • • fi A SURVEY DONE BY ME OR UNDER MY ♦ -603 ,r. DIRECT SUPERVISION AND THAT ALL *" ". CORRECT AS , Pi +s DIMENSIONS AND OF DECEMBER 23, 2008. t ♦ �1� ii�►��� LOUNSBURY & ASSOCIATES, INC. ORS ENGINEERS PLANNERS AREA: MODULE: UNIT: • ' �� OLIKTOK POINT PAD ! . : _ no Petr oleuin WELL CONDUCTOR Eni ASBUILT LOCATIONS CADDFILE 0D1 10/9/08 I DRAWING NO: NSK 6.80 -d1 I PART: 3 OF 3 l REV: 2 1 Maunder, Thomas E (DOA) From: Province Robert [robert .province @enipetroleum.com] Sent: Friday, March 06, 2009 5 :34 PM To: Maunder, Thomas E (DOA); Brink Jason; Gennings Tom; Grandi Maurizio; Longo Joseph Cc: Roby, David S (DOA); Davies, Stephen F (DOA) Subject: RE: ENI Operations: Requires Immediate Action for change of Operator Attachments: DOO.PDF Dear Mr. Maunder: Attached, please find a copy of Designation of Operator forms signed by Eni that were previously sent to Steve Davies at AOGCC. Should additional information be needed or a new form 10 -411 need to be completed and submitted, please advise. Thank you, Robert Province From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, March 04, 2009 8:59 AM To: Brink Jason; Gennings Tom; Grandi Maurizio; Longo Joseph; Province Robert Cc: Roby, David S (DOA); Davies, Stephen F (DOA) Subject: RE: ENI Operations: Requires Immediate Action for change of Operator Thanks again Jason. I will check with my colleagues here about the paperwork. Tom From: Brink Jason [ mailto :jason.brink @enipetroleum.com] Sent: Wednesday, March 04, 2009 8:52 AM To: Maunder, Thomas E (DOA); Gennings Tom; Grandi Maurizio; Longo Joseph; Province Robert Cc: Roby, David S (DOA); Davies, Stephen F (DOA); Brink Jason Subject: ENI Operations: Requires Immediate Action for change of Operator Importance: High Tom 1. The disposal well has been perforated. I am working the 10 -407 and you will have the details on this well by early next week. The EPA witnessed the entire operation and verbally approved the well. We are currently completing their lengthy completion report summary and will submit to them next week. All operations were witnessed and performed successfully. ENI expects no difficulties having this disposal well approved by the EPA. 2. 1 suspected you would ask about a change of Operator. We submitted this request to our Land department on January 27th, 2009 (your initial request) and were told that ENI filed a change of operator notice about one year ago or so. Our Land department will follow up on this immediately. Jason Brink Drilling Engineer • Page 2 of 3 ENI Alaska Office: 907 - 865 -3321 Cell: 907 - 947 -3790 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Wednesday, March 04, 2009 8:20 AM To: Brink Jason; Gennings Tom; Grandi Maurizio Cc: Roby, David S (DOA); Davies, Stephen F (DOA) Subject: RE: ENI Operations Thanks much Jason. Some additional questions ... 1. Has the disposal well been perforated and all the EPA verifications performed? 2. Regarding the Kerr -McGee wells, our records still show KM as the operator. It is probably appropriate to file a change of operator notice for those wells. Call or message with any questions. Tom Maunder, PE AOGCC From: Brink Jason [mailto:jason.brink @enipetroleum.com] Sent: Tuesday, March 03, 2009 5:30 PM To: Maunder, Thomas E (DOA); Gennings Tom; Grandi Maurizio Cc: Roby, David S (DOA); Davies, Stephen F (DOA) Subject: RE: ENI Operations Tom, Answers to your questions: 1. Nabors 245 is currently being cold stacked as we speak. Completion of the cold stack procedure will be next week. 2. (permit 1) OP03 -P05 is completed and shut -in with BPV installed and VR plugs installed in the annular valves. This producer will be put on production as production facilities are commissioned in late 2010. (permit 2) OP26 -DSPO2 is completed and shut -in with BPV installed. I am currently writing the completion 10 -407 summary for the AOGCC. This disposal well could be utilized for disposal this year. ENI is currently decisioning whether or not to commission grind and injection facilities this year or in 2010. (permit 3) OPO4 -P07 will not be drilled this year but will be drilled in the first quarter of 2010. _ 3. (permit request 4) Please continue to process this application. ENI plans to drill this water source well in the first quarter of 2010. 4. ENI wishes to not rename the two Oliktok Point wells drilled by Kerr - McGee. Please let me know if you have further questions. Jason Brink Drilling Engineer ENI Alaska Office: 907 - 865 -3321 Cell: 907 - 947 -3790 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] I I Sent: Tuesday, March 03, 2009 11:35 AM To: Gennings Tom; Brink Jason 3/17/2009 • • Page 3 of 3 Cc: Roby, David S (DOA); Davies, Stephen F (DOA) Subject: ENI Operations Tom and Jason, Sorry that the current economic climate has so drastically affected your operations. I have a couple of questions 1. When will rig operations be halted? 2. You have received permits for 3 new wells. What will the status of these wells be at the completion of rig operations? 3. We have received an application for a 4th well, do you desire the Commission to continue processing it? 4. In an earlier email I asked if it was intended to rename the two Oliktok Point wells drilled by Kerr - McGee. I received an acknowledgement of that question; however no decision has been communicated to me. would appreciate hearing of the decision. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. This message may contain information that is confidential, and is being sent exclusively to the Recipient. If you are not the designated Recipient, you are prohibited from utilizing, copying or divulging the information contained in this message,or taking any action whatsoever on the basis of the information herein. If you have received this message by mistake, we ask you to kindly inform the Sender and to delete the message. It is understood that, with regard to messages sent by its network, the Company is not responsible for any statements made or opinions expressed, that are not strictly related to the Company's operations. 3/17/2009 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 AEO 2 J • 6000000 OP-23 (surface) AEO 1 5950000 5900000 40 CFR 147.102 (b)(3) • • • 5850000 400000 500000 600000 700000 800000 • 1 TRANSMITTAL LETTER CHECKLIST WELL NAME 1 IS /0 It) C ��- PTD# 2 9 . � Development ` Service Exploratory Stratigraphic Test Non - Conventional / Well / / FIELD: /1 /. f - (/LLL. POOL: 44 Li /-�'� ( 7-- t (. Circle Appropriate Letter / Paragraphs to be Included in+'IVanittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER 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(0, 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. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed 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 program. Rev: 1/11/2008 , ± Field & Pool NIKAITCHUQ, IVISH UNDEF WTRSP - 561125 Well Name: NIKAITCHUQOP23 —WW02 Program SER Well bore seg PTD #:2090320 Company ENI PETROLEUM __. — Initial Class /Type SER / PEND GeoArea 890 Unit 11400 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA I2 Lease number appropriate Yes Surface loc in ADL 373301; passes thru ADL 355024; top disposal interval & TD in ADL 390616 3 Unique well name and number Yes 4 Well located in a defined pool No NIKAITCHUQ, IVISH UNDEF WTRSP - 561125; Ivishak formation water source well. I5 Well located proper distance from drilling unit boundary Yes Top of water supply interval will lie within ENI 100% lease, >500' from external boundary of Nikaitchuq Unit. I6 Well located proper distance from other wells Yes Only Ivishak well in Section 32. 17 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 3/17/2009 • 14 Well located within area and strata authorized by Injection Order # (put10# in comments) (For Yes OPO4 -P07; OP26 DSP02 15 All wells within 1/4 mile area of review identified (For service well only) Yes 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) No 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A -D) NA 18 Conductor string provided Yes Engineering 19 Surface casing protects all known USDWs NA All aquifers exempted, 40 CFR 147.102 (b)(3). 120 CMT vol adequate to circulate on conductor & surf csg Yes I 21 CMT vol adequate to tie -in long string to surf csg No 22 CMT will cover all known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes 124 Adequate tankage or reserve pit Yes Rig equipped with steel pits. No reserve pit planned. All waste to approved disposal well. 25 If a re-drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Traveling cylinder path calculated. 27 If diverter required, does it meet regulations Yes Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Maximum anticipated formation pressure 10.4 EMW. MW planned up to 10.7 ppg. TEM 3/24/2009 29 BOPEs, do they meet regulation Yes '30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP calculated at 3754 psi. 5000 psi BOP test planned. �j�� 11 '\ 31 Choke manifold complies w /API RP -53 (May 84) Yes � 32 Work will occur without operation shutdown No Well will be idle until facilities are in place and started up. • 133 Is presence of H2S gas probable No H2S is not reported in this area. Rig equipped with sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA Although this is a service well, it is a water supply well. '35 Permit can be issued w/o hydrogen sulfide measures Yes Geology 36 Data resented on potential overpressure zones Yes Expected ressure in Sag 10.4 EMW, and 9.3 in Kup and Ivishak. Will be drilled with up to 10.7 P P P pressure 9 is ppg ppg P P ppg Appr Date 1 37 Seismic analysis of shallow gas zones NA mud. Gas hydrates may be encountered. Mitigation measures in Drilling Hazards Summary. SFD 3/17/2009 I 13 Seabed condition survey (if off - shore) NA 139 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Ivishak formation water supply well. Commissioner: Date: Commissioner: Date �ssioner Date erfp.tie " 32 ¢ ©9 lit �.Zf" S 55 / • • Well History File APPENDIX Infolrnation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of infor mation. • C � � a v c�nn CIn ll P &tir'©o Ikk uirt'nl FINAL WELL REPORT MUDLOGGING DATA NIKAITCHUQ OP23 -WW02 OLIKTOK POINT, ALASKA • y Provided by: CANRIG Approved by: Andrew Buchanan Compiled by: John Lundy Dan Grunwald Ralph Winkelman Emil Opitz Distrihution May 19, 2010 Date: April 29, 2010 • (),2 Nikaitchuq OP23 -WW02 eni • TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW 2 1.1 Equipment Summary 2 1.2 Crew 3 2 WELL DETAILS 4 2.1 Well Summary 4 2.2 Hole Data 4 3 GEOLOGICAL INFORMATION 5 3.1 Hole Information 5 3.2 Daily Activity Summary 6 3.3 Target and Reference Well Correlation Points 10 3.4 Lithostratigraphy 11 3.5 Mudlog Summary 12 3.6 Connection Gases 36 3.7 Trip (Wiper) Gases 36 3.8 Sampling Program / Sample Dispatch 37 3.9 Approved Sample Plan OP23 -WW02 38 • 4 PRESSURE / FORMATION STRENGTH DATA 39 4.1 Pore Pressure Gradient Evaluation 39 4.2 Quantitative Methods 40 5 DRILLING DATA 42 5.1 Survey Data 42 5.2 Bit Record 48 5.3 Mud Record 49 6 MORNING REPORTS 52 Enclosures 2 "/100' Formation Log (MD/TVD) 2 "/100' LWD Combo Log (MD/TVD) 2 "/100' Gas Ratio Log (MD/TVD) 5 "/100' Formation Log (MDTVD) (3400' to 4500' ; 11,500' to TD)2 "/100' Drilling Dynamics Log (MD &TVD) Show Reports Final Data CD • CANRIG 1 Nikaitchuq OP23 -WW02 eni • 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Total Parameter Equipment Type / Position Comments Downtime Cable to 1502 transducer for BOP Casing Pressure tests only. Computer — Drill Floor Monitor Azonics Computer — Pit Monitor Azonics Computer for Company Man Rigwatch Remote (HP Compaq) Computer for Mud Engineer Rigwatch Remote (HP Compaq) Computer for Toolpusher Rigwatch Remote (HP Compaq) Data editing, Rigwatch Master, and Computers for Mudloggers (3) Rigwatch Remote (all HP Compaq) QGM Agitator (Mounted in possum belly) Ditch gas • (FID) Ionization Detector ( ) Total Gas and Chromatography. Hook Load / Weight on bit Drilling Line Sensor on Rig Floor Derived from Strokes /Minute and Mud Flow In Pump Output Mud Flow Out Flow line Sensor Pit Volumes, Pit Gain /Loss 10 radar pit sensors Pump Pressure Standpipe Transducer Pump stroke counters (2) 2 proximity sensors Crown Fast Sheave proximity Rate of penetration sensors RPM PLC feed Torque PLC feed Inteq LWD Computer to Rigwatch Wits In (LWD Data) Master Computer • W-u vRIG 2 Nikaitchuq OP23 -WW02 eni • 1.2 Crew Unit Type • Arctic Unit Number : ML014 Years Days Mudloggers , , Sample Catchers Years Days Technician Days John Lundy 18 35 Dean Kekaualua 2 32 Allen Williams 5 Dan Grunwald 2 23 Sameer Baral 1 32 Howard Lamp 3 Ralph Winkelman 19 14 Emil Opitz 2 3 *1 Years experience as Mudlogger -2 Days at welisite between spud and completion at a total depth of 12,384 feet. Two loggers remained at the rig until completion. • • CANZIG 3 lik Nikaitchuq OP23 -WW02 eni • 2 WELL DETAILS 2.1 Well Summary Well: Nikaitchuq OP23 -WW02 API Index #: 50- 029 - 23411 -00 -00 Field: Nikaitchuq Surface Co- Ordinates: Lat. 70.51086102 Long. - 149.86435227 Borough: North Slope Primary Targets: Ivishak State: Alaska Primary Target Depth: 11556'MD/- 8735.7' TVDSS Rig Name / Type: Nabors 245E /Arctic Triple TD Depth: 12,323'MD/ 9496.7'TVDSS Spud Date: April 5, 2010 Ground Elevation: 12.2 FT MSL TD Date: April 29, 2010 RT Elevation: 53.20 FT MSL Days Drilling: 25 TD Formation: Kavik Shale Classification: Water Well III 2.2 Hole Data The Borehole extends from the surface to a TD at 12,323'MD/9549.91'TVD and has three sections designated by hole diameter: the 16" Surface Borehole; the 12 -1/4" Intermediate Borehole; and the 8 -1/2" Production Lateral Borehole (Lateral Borehole). The well was designed as a water well with the potential of oil production and to provide data for future well design and direction. FIT Maximum Depth TD Mud Shoe Depth LOT Hole Dev. Casing/ Formatio Weight (ppg) g ° inc ) Liner Section ( MD TVD n (ppg) MD TVD (ft) (ft) (ft) (ft) Conductor 160 160 Recent 8.7- 0 C -20" 160 160 N/A 16" Surface Schrader 12.82 4607 3779.0 9.3 53.39 C -13 3/8" 4595 3771.45 Borehole Bluff LOT 16.25 12.25" 9120 6633.24 Kalubik 9.8 49.14 C -9 5/8 9087 6613.08 LOT 8.5" 12323 9550 Kavik 10.3 7.07 7" Liner 12323 9550 N/A • CA RIG 4 eni Nikaitchuq OP23 -WW02 • 3 GEOLOGICAL INFORMATION 3.1 Hole Information Additional Comments: The well was spudded on the 4 of April 2010, entering a pre set conductor pipe at a depth of 160' and 16" hole was drilled to a depth of 4607'. There was one trip for bit and LWD failure during the drilling of the surface hole. 13 3/8" surface casing was set at 4595'. The float equipment and shoe were drilled out and new hole was drilled to 4625'. A Leak Off Test (LOT) was performed to 12.82 ppg The intermediate section was drilled with a hole diameter of 12.25" to 9120'. No well control problems were encountered while conditioning the hole for casing at this depth. 9 5/8" Casing was set from surface to 9087'. After drilling out to 9120' a Leak Off Test (LOT) was performed to 16.25 ppg. The hole was completed drilling 8.5" hole to a depth of 12323' For additional detail, see daily summary below. • • I 5 Phs e Nikaitchuq OP23 -WW02 1110 3.2 Daily Activity Summary 4/01/2010: Continue rig up and test equipment, finished assembling Gas Trap and other components. Set up Gas Trap in Possum Belly. 4/02/2010: Continued rig up: troubleshoot RigWatch virus problem, mount pill pit mud level sensor; mount secondary gas trap. 4/03/2010: Continued rig up; hoist replacement hydrogen cylinders to unit atop rig and lower empty cylinders; calibrate gas equipment; troubleshoot RigWatch virus problem. 4/04/2010: Continued rig up - test gas trap, troubleshoot RigWatch issues; rig repairs - repair knife valve. 4/05/2010: Continued replacement and repair of stack valve; work performed on diverter line; pressure test lines and pumps; wash out conductor; begin drilling ahead at report time; additional mudlogging activity - isolate RigWatch computers, update antivirus software and purge malicious software. 4/06/2010: Spud in with dumb iron and drill 257' of rat hole to accommodate LWD tooling; Pull out of the hole and pick up BHA #2 with full tool string; Run into hole and drill ahead to 927'. 4/07/2010: Drill ahead from 972' to 2115' MD; extraneous mudlogging activity — recalibrate gas detection equipment and block height. 4/08/2010: Drill ahead from 2115' to 3078' MD. 4/09/2010: Drill ahead to 3666' MD; pump 20 bbl slug to clean bit; Pull out of the hole for bit inspection; Lay down BHA #2. 4/10/2010: Continue laying down BHA #2; Pick up BHA #3 with new bit and mud motor; clear blockages in line from shakers to cuttings tank; Run into hole, stopping to circulate bottoms up every 1000'; wash hole from 3350' to 3666' and drill ahead; miscellaneous mudlogging activity - calibrate gas detection equipment. 4/11/2010: Drill ahead from 3684' MD to 4440' MD; slow drilling at 3865' MD - pump Nut Plug sweeps with little variation in rate of penetration. 4/12/2010: Drill ahead to surface casing point at 4607' MD; circulate bottoms up; pump Nut Plug sweep; circulate bottoms up; wiper trip to 3168'; RIH to 4500'; circulate bottoms up x3; pump high viscosity NutPlug sweep; pump dry job; POOH. Lay down BHA. Download MWD /LWD. 4/13/2010: Lay down remainder of BHA; Rig up casing equipment; Run into hole with 13 3/8" casing, breaking circulation every 1000'; land hanger. 4/14/2010: Circulate and condition mud for cement job; rig up cement equipment; pump cement job; Lay down cement head; nipple down diverter stack. 4/15/2010: Nipple down flow -line crossover and riser; clean and clear cellar; install wellhead, riser and crossover; nipple up BOP's, make up crossover, set on wellhead, and torque up BOP's; nipple up choke and manual kill, put in blind rams; pressure up Koomey, function test rams; connect hole fill and bleed down lines; miscellaneous mudlogging activity - purge computer virus from RigWatch network and add hardware to accommodate more RigWatch monitors. 4/16/2010: Complete nipple up BOP's. Test BOPS. 5000 psi body test leaked at VETCO GRAY packings, retightened, OK. Test BOP's 250 psi low, 5000 psi high witnessed by AOGCC rep. Make up BHA. Load nuke • CAMI] 6 II eni Nikaitchuq OP23 -VVW02 • sources. miscellaneous mudlogging activity - recalibrated gas equipment. 4/17/2010: Finish p/u BHA. Clear drill floor. Circulate, condition mud and surface test MWD tools. P/U 30 joints drill pipe. Service rig/ top drive/ crown. Trip in hole to 4268', fill pipe every 20 stands. Ream/ wash 4268' - 4509', tag cement. Circ/ condition mud at 4500'. Pressure test casing to 2500 psi for 30 min. UD test equipment. Drill out shoe tract and new formation to 4625'. Change out mud system. Perform FIT = 12.82 EQMW. Drill from 4625' - 4635', MWD failure. Trip out of hole, lay down BHA. 4/18/2010: Lay down BHA. Unload nuke sources. Continue LD BHA. Change out bit. Download MWD tools. Pick up BHA. Load nuke sources. Clean rig floor. Broken shear pin on SADN8 LWD tool. Wait on parts. Service rig etc while waiting on parts. Continue to pick up BHA without SADN8 tool. RIH and pulse test MWD tools. TIH to 4535', service rig, top drive etc. Wash from 4535' to 4635'. Drill 4635' to 5110'. Slide 5110' to 5142'. Rotate 5142' to 5300' at report depth. 4/19/2010: Drill from 5300' to 6600'. Circulate and condition mud, CBU. POOH from 6600' to 4535'. Service rig, top drive, blocks, DWS, crown. Calibrate RigWatch block height. Trip in hole to 6547'. Wash from 6547' to 6600', drill 6600' to 6720' at report time. 4/20/2010: Drill from 6720' to 7200', sliding on occasion. Continue to drill from 7200' to 7704'. Slide 7704' to 7725'. Rotate 7725' to 8000'. Slide 8000' to 8010', bleed in 290 bbls LSND spike fluid with Resinex. Circulate and condition, lost 500 psi. No apparent pump problems. All checks negative. Test surface equipment to 2000 psi. OK. Stage pumps back up to full. Started at 2700 psi and returned to 3200 psi. Continue slide 8010' to 8020'. Rotate 8020' to 8320' at report time. 4/21/2010: Drill from 8320' to 9120'. Confirm with geologist casing point. Circulate and condition, take on bottom survey with MWD. Pump hi vis sweep around. POOH 9120' to 6600'. No problems on trip. Trip in hole 6600' to 9037'. Wash down 9037' to bottom. Circulate and condition. Pump hi vis nut plug sweep around. Circulate till hole clean. Pull 2 stands, pump slug, continue POOH to 4535' at report time. 4/22/2010: Continue POOH to top of BHA at 703'. PJSM for laying down BHA. Lay down BHA. Clean rig floor, cellar, service rig, top drive etc. while waiting on wireline personnel. PJSM for rig up wireline. Rig up wireline. Make up logging tools and load nuke source. RIH with logging tools, Platform Express/ Sonic Scanner/ PPC's to 9118'. Logging out from 9118' to 2500' at report time. 4/23/2010: Continue open hole logging. PJSM to lay down wireline. Rig down wireline equipment. Pull wear bushing. Test BOP's. Change out bottom rams to 9 5/8" rams. Test BOP's bottom rams 250psi low, 5000psi hi for 5 minutes. Dummy run 9 5/8" hanger as per VETCO. PJSM for casing run. Rig up casing tools. Pick up shoe and float joints, check as per program, OK. Continue run 9 5/8 ", fill every joint, top off every 10 and CBU every 1000'. CBU at 6000' report time. Max gas so far, 109 units while CBU at 6000'. 4/24/2010: Continue run 9 5/8" casing from 6000' to 9049', filling every joint, top off every 10 and CBU every 1000'. CBU at 7000', 8000' and 9049'. Pick up hanger and landing joint and land casing. Rig down Franks casing tools. Make up cement head and circ lines. CBU and condition. PJSM for cementing. Pressure test lines to 4000psi. Pump 40bbls mud push. Drop bottom plug. Pump 80 bbls 15.8ppg cement. Drop top plug. Pump 10bbls water followed by 666bb1s oil base mud. Plug did not bump. Bleed off and check floats, floats holding. Rig down cement head. Remove csg elevator and install drill pipe elevators. Pick up packoff running tool. Suck out stack and and rinse top of hanger. Set packoff and test to 5000psi per VETCO GRAY. Finish lay down casing tools. Set test plug. Change out bottom 9 5/8" rams back to 3 1/2x6 variable rams. Test BOP's. 4/25/2010: Finish BOP test. Lay down test tool and testing equipment. Blow down choke and kill lines. Install wear ring. Pressure test casing to 3000psi for 30 minutes. Good test. Blow down lines. Trip in with drill collars, jars and 2 HWDP. Slip and cut 96' drill line, adjust brakes, reset crown and floor saver. Service top drive, draw works and crown. Repair TQ boost. Fix leaks on top drive and HPU. Lay down last of 12 1/4" BHA. Misc • Chu RIG 7 eni Nikaitchuq OP23 -WW02 operations in prep for oil base mud. Load pipe shed with drill pipe. PJSM for 8 1/2" BHA. Pick up BHA, load sources. Trip in hole with HWDP. Pick up drill pipe to 1000'. Test MWD, good test. Continue pick up pipe and trip in hole at report time. 4/26/2010: Pick up pipe and trip in hole from 1600' to 3949'. Trip in stands 3949' to 9009' filling pipe every 3000'. Drill cement, float equipment 9009' to 9120'. Drill 9120' to 9170'. CBU. POOH to 9021'. Perform Leak Off Test to 16.25 EQMW. Drill 9170' to 9451' rotate and slide as per directional plan. CBU at 9451' cuttings chute packed off, clear. Drag chain jumped off sprocket, repair same. Continue drill 9451' to 9692', rotate and slide as per directional plan. 4/27/2010: Drill from 9692' to 11380', slide and rotate as per directional plan. 4/28/2010: Drill from 11380' to 11847'. Pick up for flow check at 11500', gas max 780 units. Flow up to 26% - 30% from 1 8%. Hole started taking fluid at 11799', 35 bbls an hour. Spot 25 bbls of 40 lb/gal LCM pill. Lost 161 bbl A.M. tour. POOH from 11847' to 10937'. Circulate and condition, work pipe and monitor losses of 9.5 bbls. Trip in to 11799', wash to bottom at 11847'.Drill from 11847' to 12090' at report time. Pump LCM pill at 11880'. 4/29/2010: Drill from 12090' to 12323' TD. CBU, pump hi vis sweep. Monitor well for 10 minutes, pump dry job. POOH from 12323' to 9021'. Hole in good shape. CBU. Service rig, top drive, blocks, crown and draw works. Trip in hole to 12287', wash down to 12323'. CBU. POOH to BHA, Drop 2.25" rabbit on stand 105, recover at jars. PJSM for lay down BHA with MWD nuke source. Lay down BHA. 4/30/2010: L/D BHA and unload nuclear source; clear and clean rig floor; P/U and M/U open -hole logging tools; TIH from 143' to 8230' with drill pipe conveyed logging tools, filling drill pipe every 10 stands; TIH to 9060', M/U side entry sub; RIH to 11568'; open hole logging. 41) 5/01/2010: Continued downhole pressure testing at predetermined depths with drill pipe conveyed tools. Pressure testing at 11301' at 0000hrs, and continuing downward to 12155' at 1500hrs. POOH, collecting fluid samples at selected depths. 1 attempt to obtain fluid sample at 12018' is unsuccessful. POOH to 11677' and RIH to 12018'; collect fluid sample. Attempt to collect fluid sample at 11863' is unsuccessful as of midnight. Miscellaneous Mudlogging activity — troubleshoot mud pit sensors in the trip tank and pill pit; sample catchers en route to Anchorage. 5/02/2010: TOOH from 11683' to 9059'. Pull wireline out of drill pipe. POOH and pump dry job. L/D logging tools and clean rig floor. Pull wear bushing and suck out BOPE. Test BOP's. Drain stack and install wear bushing. P/U BHA for clean -out run. 5/03/2010: Make up BHA for clean -out run, TIH to 503 ft with HWDP; TIH from 503 ft to 3217 ft; P/U 9 ?" casing scraper; RIH from 3223 ft to casing shoe @ 9029 ft, filling drill pipe @ 3287 ft, 6252 ft, and 9029 ft; cut and slip drilling line, service top drive and drawworks; TIH from 9029 ft to 10,850 ft; perform clean -out run and tag bottom @ 12,323 ft; CBU 7x, 107 units trip gas; POOH to 10040 ft as of midnight; miscellaneous mudlogging activity - service gas trap. 5/04/2010: POOH from 10040' to 3217'. L/D scraper and crossover sub. POOH from 3217' to 503'. Stand back HWDP, LID 2 joints HWDP and remainder of BHA. Clear and clean rig floor. Remove wear bushing. Test BOP's to 5000 psi with 7" test joint, install wear bushing. R/U to run casing. RIH with 7" liner. M/U hanger. Circulate liner volume. 5/05/2010: Continue to circulate out production liner volume. TIH with liner on drill pipe, filling pipe every 10 stands. M/U cement head and R/U cement lines. Circulate and condition mud. PJSM for cement job. Pump mud push and cement. Flush cement lines. Bump cement plug, set packer, CBU. Rig down cementing equipment. POOH from 8858' to 8665', CBU. POOH from 8665' to 4905'. RIH with 4 stands HWDP to • CANRIG 8 eni Nikaitchuq OP23 -WW02 4111 subsequently lay down same. 5/06/2010: TOH, UD HWDP from 5281' to 4905'. POOH from 4905', UD liner running tool. Run casing /cement pressure test; casing /shoe pt liner and liner lap to 1500 psi for 30 minutes. Cased hole logs; R/U wireline. Load shed with logging tools. RIH with VSP. Clean pits. Clean /maintenance on rig. 5/07/2010: Rig released to completion 08:00. cANRIG 9 WI Os en i Nikaitchuq OP23 -WW02 • 3.3 Target and Reference Well Correlation Points OP23 -WW2 Oliktok EHB St Thetis MPU Surface Prognosis Point 1 1 Island Tuvaaq Kigun Nik 1 Nik 2 KRU -L1 MD TVDSS TVDSS TVDSS TVDSS TVDSS TVDSS TVDSS TVDSS TVDSS Permafrost Base -1664 -1664 -1637 -1566 -2058 Ugnu Top (UG4) 2066 -1963 -1692 -1433 -1550 -1964 -1965 -2352 -2435 -2442 L Ugnu 3713 -3120 -2839 -2540 -2548 -3110 -3143 -3621 -3653 -3741 Schrader Bluff 4067 -3350 -3035 -2754 -2811 -3358 -3398 -3887 -3911 -3955 N Sand Top 4180 -3423 -3130 -2786 -2883 -3455 -3495 -3981 - 4008 -4032 N Sand Bottom 4249 -3468 -3167 -2822 -2924 -3482 -3531 - 4012 -4044 -4059 OA Sand Top 4414 -3575 -3247 -2902 -3048 -3599 -3647 - 4128 -4154 -4172 OA Sand Base 4475 -3615 -3286 -2928 -3072 -3637 -3690 - 4168 - 4195 -4207 Torok Top 7989 -5896 -5305 -5504 -5506 Torok Base 8338 -6122 -5466 -5598 -5636 HRZ 8753 -6392 -5880 -5866 -6009 -6352 -6382 -7023 -7060 -6557 HRZ Base 8848 -6453 -5991 -5981 -6109 -6461 -6505 -7023 -7060 -6624 Kalubik Marker 8958 -6525 -6107 -6085 -6171 -6544 -6636 -7062 -7074 -6702 Kuparuk Top 9159 -6660 -6228 -6130 -6301 -6605 -6684 -7267 -7349 -6981 LCU 9251 -6725 -6257 - 6144 -6328 -6609 -6688 -7276 -7353 -6983 Kuparuk Base 9306 -6765 -6348 -6179 -6334 -6644 -6730 -7314 -7425 -7125 Jurassic Top 9386 -6825 Jurassic Base 9516 -6925 Sag Top 9175 -8401 -8088 -7926 -7584 -7878 -8227 -8633 -8840 -8813 Shublik 11068 -8443 -8179 -8029 -7717 -7996 -8340 -8742 -8948 -8896 Ivishak 11311 -8678 -8401 -8263 -7967 -8228 -8582 -9002 -9180 -9092 Kavik Shale Top 11998 -9342 Final Top Picks; LWD tops and bases refer to provisional picks by the wellsite geologist. CANRIG 10 WS eni Nikaitchuq OP23 -WW02 • 3.4 Lithostratiqraphv ENI PROGNOSED LWD PICK FORMATION MD TVD MD TVD/TVDSS (ft) (ft) (ft) (ft) Permafrost Base 1801.0 1778.0/ -1724 1784.0 1775.0/- 1721.8 Ugnu Top (UG4) 2066.0 2016.2/ -1963 2039.0 2017.7/- 1964.5 L Ugnu 3713.0 3173.2/ -3120 3615.8 3160.0/- 3106.8 Schrader Bluff 4067.0 3403.2/ -3350 3917.0 3353.6/- 3300.4 N Sand Top 4180.0 3476.2/ -3423 4054.0 3440.3/- 3387.1 N Sand Bottom 4249.0 3521.2/ -3468 4117.0 3480.3/ - 3427.1 OA Sand Top 4414.0 3628.2/ -3575 4300.0 3592.1/-3538.9 OA Sand Base 4475.0 3668.2/ -3615 4352.0 3624.0/- 3570.8 Canning 4352 3624.0/- 3570.8 11, Torok Top 7989.0 5949.2/ -5896 8120.0 5979.3/- 5926.1 Torok Base 8338.0 6175.2/ -6122 8606.0 6295.9/- 6242.7 HRZ 8753.0 6445.2/ -6392 8838.0 6448.8/- 6395.6 HRZ Base 8848.0 6506.2/ -6453 8941.6 6516.5/- 6463.3 Kalubik Marker 8958.0 6578.2/ -6525 9059.9 6593.9/- 6540.7 Kuparuk Top 9159.0 6713.2/ -6660 9263.0 6721.9/- 6668.7 LCU 9251.0 6778.2/ -6725 9368.0 6790.1/- 6736.9 Kuparuk Base 9306.0 6818.2/ -6765 9368.0 6790.1/- 6736.9 Jurassic Top 9386.0 6878.2/ -6825 9538.5 6906.8/- 6853.6 Jurassic Base 9516.0 6978.2/ -6925 9719.5 7040.6/- 6987.4 Sag Top 10961.0 8393.2/ -8340 11228.5 8466.0/- 8412.8 Shublik 11068.0 8496.2/ -8443 11327.0 8563.5/- 8510.3 Ivishak 11311.0 8731.2/ -8678 11556.0 8788.9/- 8735.7 Kavik Shale Top 11998.0 9395.2/ -9342 12185.0 9413.0/- 9359.8 • cA vRIG 11 Tais eni Nikaitchuq OP23 -WW02 • 3.5 Mud log Summary The Permafrost section of the OP23 -VVVV2 consists of moderate beds of sand, conglomerate and claystone with thinner clay interbeds, particularly near the surface. This material is almost entirely included in the permafrost section, contained no notable gas peaks and no hydrocarbon shows. Permafrost Section; Recent/Quaternary Deposits - Surface to 2039' MD/1964.5 `TVDSS Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 610 6 137.6 373 0 30.4 This interval extends from surface down to the top of the Ugnu at 2039' MD and is comprised of a thick sequence of sands, conglomerates and claystones with occasional thin to massive siltstone and poorly developed coals and carbonaceous remains. Sand dominates the upper part of the section with claystone becoming predominant with depth Discrete fragments of sandstone were rarely observed, samples were typified by loose sand and conglomeritic pebble fragments with irregular globular clay masses. Clay masses commonly contained trace to abundant sand mechanically worked into the clay by drilling, circulation and shaker action and had a surface coating of imbedded loose sand. Formation consists of moderate to thick beds with locally abundant thinner interbeds. No unforeseen problems were encountered drilling this section, and no marketable hydrocarbons were found. Sand (160' - 250') = samples consist of loose sand with subordinate clay; the sand is well sorted and predominantly lower medium- to upper fine- grained, with a full range of grain sizes from upper coarse- to upper very fine- grained; the sand is salt and pepper colored, consisting primarily of very light gray to very pale yellow translucent quartz with lesser amounts of black Iithics; grains are subangular to angular with moderate sphericity on average; minor amounts of subangular reddish orange Iithics and well rounded blue -green glauconite are present; the surfaces of the quartz grains are etched and pitted; the clay is light olive gray and displays excellent plasticity; clayey cuttings come across the shakers as solid clots and as clumps of sand bound by clay. Clay (160' - 300') = light to medium gray; soft; dull earthy luster; smooth clayey to silty /gritty texture; samples consists of 1" to 2" diameter globular clay balls with mechanically imbedded sand; moderately cohesive; slightly to moderately adhesive; occurs as thin to moderate interbeds in associated sand. Sand (300' - 410') = medium to medium light gray with a slight yellowish secondary hue; salt and pepper appearance; unconsolidated; moderately to poorly sorted; fine upper to lower grain predominates; trace medium lower and coarser grains; trace small pebbles and pebble fragments; common very fine sand; angular to sub - angular to trace sub - spheroidal; some slightly pitted; individual grains about evenly divided between medium dark gray Iithics and translucent white to clear quartz; slight trace light orange brown limonite cemented sandstone fragments; trace brown silty lignite; common medium to light gray siltstone. Siltstone (400' - 500') = medium light gray with a slight brownish secondary hue; soft; sandy /gritty texture; grainy luster; very sandy; grades to silty /clay matrix sandstone; slightly cohesive /adhesive; appears to occur as thin interbeds in associated sands. Sand (410' - 530') = medium to medium light gray; soft to dis- aggregated; dirty salt and pepper appearance; friable; fine lower to fine upper and very fine upper grain; occasional trace medium lower grain sand, small pebbles and fragments; angular to sub - angular; about evenly divided between gray Iithics and clear to translucent white quartz sand; trace dark gray Iithics /mafic material and clastic coal fines; vertically sorted, coarsening with increasing depth through the interval. Siltstone (530' - 700') = samples come across the shakers as a slurry of disaggregated silt with minor clay and loose sand; the material is medium light gray and displays excellent cohesion yet poor to moderate 411 CAIWIG 12 eni Nikaitchuq OP23 -WW02 4110 plasticity; intact siltstone cuttings are scattered throughout the slurry; the cuttings are Tight brownish gray, dense to brittle, massive to somewhat tabular, with irregular broken surfaces; fresh surfaces display an earthy to waxy luster underlain by a silty texture; the siltstone contains lowermost very fine- grained sand, and lenses and /or laminae of upper fine- to upper very fine- grained sand are represented by loose salt and pepper colored sand; the loose sand consists of light gray to pale yellow translucent quartz with lesser black Iithics and minor blue -green glauconite; the sand grains are subrounded and display moderate sphericity on average; trace rounded pebbles occur within the samples also, as well as rare, small bits and flakes of partially pyritized organic material; samples become increasingly clayey in the middle of this interval, and the aggregate material displays high plasticity; at the base of this interval, clay content decreases once again, and the loose sand is fine to very fine- grained and very well sorted. Sand (700' - 780') = samples consist of a medium gray slurry of loose sand; the sand is homogeneous and very well sorted; grains are predominantly lower fine- grained, with a range from upper fine- grained through lower very fine- grained; the sand is primarily composed of very light gray, translucent to transparent quartz; with minor amounts of black Iithics that give the sand a salt and pepper appearance under the microscope; grains are subangular to subrounded, with moderate sphericity on average; trace amounts of pale orange quartz, blue -green glauconite, and pyrite are present as well. Sand (780' - 880') = samples consist of a dark brownish gray slurry of moderately sorted loose sand with variable amounts of clayey clots; the sand is mostly upper medium- to upper fine- grained, with traces of coarse and very fine sand; roughly half of the sand is comprised of translucent to transparent very light gray quartz, while the remainder consists of medium to dark brown, sub - blocky to slightly tabular Iithics that give the sand a salt and pepper appearance under the microscope; grains are subangular with poor sphericity to subrounded with moderate sphericity; pyrite is common on the surface of the Iithics, while quartz grains are etched; all grains display some signs of impact abrasions. Claystone (880' - 915') = samples consist of up to 2 inch medium gray clots of clay in a slurry of sand; no • intact cuttings appear to be present; the clay exhibits excellent cohesion, high plasticity, and modest adhesion. Sand (915' - 1070') = samples consist of a dark gray slurry of loose sand containing small ( to % inch) clots of medium gray clay and some hard sandstone cuttings; the sand is well sorted with grain sizes ranging from lower medium- to upper very fine- grained; the lithified sandstone contains very fine sand; the sand is mostly composed of translucent very light gray quartz with subordinate medium to very dark brown to black Iithics that give the sand a salt and pepper appearance; the sand is subangular to subrounded with moderate sphericity on average; well rounded gravel occurs throughout this interval; trace amounts of blue -green glauconite, pyrite, shell fragments, and occasional re- crystallized calcite can be found in the sand as well; scattered intact sandstone cuttings are hard and dense, well sorted, and cemented by calcite; the overall samples are calcareous as well. Claystone (1070' - 1120') = samples consist of clots of medium to dark gray clay coming across the shakers; the clay is firm and displays excellent cohesion and very high plasticity, along with modest adhesion; samples have a dull, earthy luster underlain by a smooth, clayey texture; the clay is extremely pure, as samples contain virtually no sand nor silt. Claystone (1120' - 1210') = samples consist of firm clots of wet, dark gray clay coming across the shakers; the clay exhibits excellent cohesion and high plasticity, yet only moderate adhesion; the clay displays a waxy to dull, earthy luster underlain by a smooth, clayey texture; very little silt and sand are contained within the samples. Claystone (1210' - 1300') = medium to dark gray to yellowish gray; soft to firm; sample collected as mechanically reworked globular masses and occasional small firm silty yellow -gray fragments; fragments are visibly micro - laminated and slightly silty; globular masses include mechanically reworked sand and silt; moderately cohesive /adhesive; slightly to moderately hydrophilic; occurs as moderate to thick clay beds with occasional stringers and thin interbeds of sand and siltstone; very slightly calcareous. CAMIG 13 eni Nikaitchuq OP23 -WW02 • Conglomeratic Sand /Conglomerate (1330' - 1420') = dark to medium dark gray; hard to firm; poorly sorted; medium upper to coarse lower predominates; common to abundant coarse upper and very coarse; occasional small pebbles; individual grains are dominantly dark gray to black chert with common medium to light gray chert; trace clear to translucent white quartz; trace black mafic mineral /chert grains; primarily moderately rounded in the larger grain, sub - spheroidal to angular in the finer grain material; occurs as moderate beds in associated claystones. Claystone (1300' - 1480') = medium to dark gray to yellowish gray; soft to firm; sample collected as mechanically reworked globular masses and occasional small firm silty yellow -gray fragments; fragments are more common in this interval and are reworked slightly silty and slightly sandy globular masses; moderately cohesive; slightly adhesive; slightly to moderately hydrophilic; occurs as moderate to thick clay beds with occasional stringers and thin interbeds of sand and siltstone; very slightly calcareous. Conglomeratic Sand /Conglomerate (1420' - 1480') = medium dark gray; dis- aggregated or unconsolidated; poorly sorted; medium upper to medium lower predominates; abundant coarse lower to coarse upper grains; trace small pebbles; larger grains commonly coated with clay residue; slightly rounded to sub - angular and sub - spheroidal in the larger grains; smaller grains sub - angular to angular; predominantly dark gray to black chert; common light to medium gray lithics and chert grains; appears to be at least partially matrix supported in light to medium gray clay; percentage of sand increases below 1480'; trace hard off white calcite cemented sandstone; very slightly calcareous; trace dull yellow mineral fluorescence; no oil indicators. Sand (1480' - 1570') = medium to medium light gray; dis- aggregated; dirty salt and pepper appearance; well to moderately well sorted; medium lower to fine upper grain; trace medium upper and coarse lower; angular to sub - angular; predominantly translucent white to clear quartz with abundant to 40% dark to medium gray and brown lithics; no visible pitting; no matrix residue noted; occurs as intermittent thin to moderate interbeds in associated clay /conglomerate material; trace fine calcite grains; very slightly calcareous; no oil indicators. Claystone (1480' - 1610') = medium to dark gray; soft to slightly firm sample collected as mechanically re- worked globular masses; globules coated with and contain re- worked sand; slightly silty to smooth clayey texture; dull earthy to silky luster; moderately cohesive; slightly adhesive; slightly to moderately hydrophilic; occurs as moderate to thick clay beds within associated conglomeratic sand /conglomerate; trace poorly decomposed wood fragments; trace fine grain calcite; very slightly calcareous; no oil indicators. Sand (1690' - 1740') = medium to medium light gray with a slight brownish secondary hue; moderately well to well sorted; medium lower to medium upper and fine upper grain; angular to sub - angular; predominantly translucent white to clear quartz; abundant to 30% dark gray to black lithic /mafic mineral grains; trace to common light gray lithics; trace poorly indurated fragments display abundant soft clay matrix; very slightly calcareous; no oil indicators. BASE OF THE PERMAFROST: 1784' MD/ 1721.8' TVDSS Below the permafrost, sands become generally finer grain and exhibit better sorting. Conglomeritic sand gradually diminishes to an occasional trace by 1700'MD. Siltstone also diminishes to an occasional trace or locally as abundant thin interbeds in the associated sands and claystones. Occasional carbonaceous remains are also seen. Sand (1740' - 1790') = samples consist of a medium gray slurry of loose sand containing scattered clots of medium to dark gray clay; the sand is very well sorted and fine to very fine grained, consisting of very light gray quartz and subordinate black lithics that impart a salt- and - pepper appearance to the sand; grains are subangular with moderate sphericity; trace blue -green glauconite. Claystone (1790' - 1970') = samples consist of clots of medium gray clay with variable amounts of entrained fine sand; the overall material displays good cohesion and plasticity, although the lower end of this interval is • CANNIG 14 eni Nikaitchuq OP23 -WW02 • characterized by lower plasticity where the sand grades into lowermost very fine- grained sand and abundant silt; the claystone is largely disaggregated, and the pasty clay exhibits a dull, earthy luster underlain by a clayey texture; the clay is revealed to be microcrystalline under high magnification; the sand in the upper portion of this interval is similar to the salt- and - pepper colored material seen above; grains are predominantly fine- grained sub angular light gray quartz with lesser amounts of black lithics; the very fine sand and silt appears to consist primarily of very light gray to pale yellow quartz with only trace black lithics; the upper sandy portion of this interval contains conspicuous very dark brown to black, soft, woody organic material that grades into a low grade coal; in addition to trace pyrite throughout, many of the woody bits have been partially altered to pyrite; the organics tend to be accompanied by minor amounts of well rounded coarse to very coarse sand. Sand (1970' - 2150') = samples consist of a medium gray slurry of loose sand containing small (%4 to % inch) medium to dark gray clots of clay; small very dark brown to black bits of woody organics are also scattered throughout the sand in the upper portion of this interval; the organic material grades into low grade coal and flakes of black shale are thinly interbedded with the organics; the sand is very well sorted, with predominantly upper fine- to lower medium - grained sand intermixed with a smaller amount of lower fine to upper very fine - grained sand; the bulk of the grains consist of translucent, very light gray quartz; the remainder mostly consists of black cryptocrystalline lithics that give the sand a salt- and - pepper appearance under the microscope; the quartz tends to be subangular while the black lithics are subrounded to subangular; minor rounded blue -green glauconite is contained within the sand, and rare pyrite is visible; the organics are commonly partially altered to pyrite; the organics are very soft; the lignite is harder, yet it occurs as smaller bits; the shale is much harder, and very siliceous shale cuttings occur up to % inch; the clay is very cohesive and exhibits high plasticity. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 1245 51 20195 1285 59 23323 1428 175 69173 1490 183 38440 1552 134 27520 1639 128 27242 1737 373 58555 2002 103 20206 Uqnu: 2039' MD/ 1964.5' TVDSS to 3917' MD/3300.4' TVDSS Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 441 1.5 118.5 73 tr 19.1 The Ugnu formation consists of two units, upper and lower Ugnu. The upper portion of the formation is essentially similar in nature and appearance to the overlying material. However, the sands are generally finer grain and exhibit slightly greater wear through transport/erosion. The section consists primarily of thickly bedded sand /sandstone occasionally grading to sandstone conglomerate and conglomerate. Moderate to thin claystone and siltstone interbeds occur throughout. No unforeseen problems were encountered drilling this section, and no marketable hydrocarbons were found. Claystone (2150' - 2265') = samples consist of 1/4 to % inch clots of medium gray clay with imbedded sand coming across the shakers; the aggregate material is moderately cohesive and displays modest plasticity; the clay exhibits a dull, earthy luster and a smooth, clayey texture; as the claystone appears to be entirely disaggregated, no structure is apparent; the sand is lower medium to lower fine grained and is composed of very Tight gray quartz with subordinate black cryptocrystalline lithics and minor amounts of translucent orange quartz and blue -green glauconite; quartz grains are largely subangular, while the black lithics are subangular to subrounded, and the glauconite grains are rounded; the quartz commonly displays impact features and abraded surfaces, while the black lithics display impact features also, but to a lesser degree. • CANRIG 15 n i Nikaitchuq OP23 -WW02 • Sand (2265' - 2390') = samples consist of a slurry of sand coming across the shakers with varying amounts of clayey clots contained within the samples; the sand is well sorted, with grain sizes primarily centered about lower medium to upper fine grained, with a full range from upper medium to upper very fine grained; the sand is predominantly composed of transparent to translucent very light gray quartz with a few scattered pale yellow and pale orange grains; the bulk of the remainder consists of cryptocrystalline black lithics which impart a salt - and- pepper appearance to the sand under the microscope; minor blue -green glauconite is also contained within the sand, and rare pyrite can be found; the clay is medium to dark gray when wet and medium to light gray when dry; clayey clots display good cohesion and moderate plasticity. Clay (2390' - 2470') = samples consist of %4 to % inch clots of clay coming across the shakers, with variable amounts of sand embedded in the clots; the aggregate material is cohesive and displays good plasticity; broken surfaces of the clay clots are slightly lighter colored and display a brown to yellow tint; the sand is similar to that described in the samples above; the sand is well sorted with a range of grain sizes from lower medium grained to upper very fine- grained; occasional rounded coarse grains and gravel occur over short intervals; the 2470 sample included very abundant multicolored angular medium upper to lower coarse grain sand with traces of blue -gray, green, yellow and gray lithics; trace coarse to very coarse; trace thinly fissile hard micaceous shale. Sand (2470 - 2590') = medium light gray; soft to dis- aggregated; well to moderately well sorted; medium upper grain in the top of the section; coarsens with depth to medium and coarse lower with scattered small pebbles and very coarse sand; angular to sub - angular; clear to translucent quartz; common dark mafic mineral grains; trace light to medium blue -gray, green, yellow and brown mineral grains and some lithics; trace coarse grain size micro - crystalline pyrite nodules; trace muscovite mica; occasion -al thin gray globular claystone interbeds; trace soft white kaolinite with imbedded very fine angular quartz sand; trace muscovite mica; no visible matrix residue or crystal overgrowth on sand grains; clays are hydrophilic; very slightly calcareous. Claystone (2600' - 2660') = light gray with a slight brownish secondary hue; soft to slightly firm; globular to slightly tabular fragments; dull earthy luster; gritty to silty texture; fragments coated with loose sand; commonly silty; trace coal fine inclusions; interbedded with and grading to medium grain clay matrix sandstone and conglomerate; common coarse lower fragments; common hard gray brown to black carbonaceous shale and sub - bituminous coal. Sand (2660' - 2815') = light to very light gray with a pronounced brownish secondary hue; soft to dis- aggregated; commonly recovered as globular masses of sand suspended in gelatinous hydrophilic clay; well to moderately well to moderately sorted; medium lower to fine upper in the top of the section, becoming less sorted and coarser grained with depth; trace to common small pebbles and pebble fragments; deeper samples contain increasing amounts of medium upper to coarse lower sand disaggregated and washed from the soft hydrophilic matrix; angular to sub - angular to very slightly rounded; clear to translucent quartz predominate; common to abundant smoky and smoky rose quartz; common dark gray to black mafic mineral and occasional lithic grains; trace blue -gray, green and brown grains; trace thinly cleaved clear muscovite mica; trace pyrite; trace to abundant gray lithic/chert grains; matrix is light to very light gray to occasionally white clay/ kaolinite; trace to non calcareous; no oil indicators. Sandstone (2815' - 3000') = samples consist of a slurry of loose sand coming across the shakers with scattered small (1/4 inch), amorphous, somewhat cohesive masses of clay, silt, and sand; the aggregate samples are medium olive gray when wet and light gray when dry; the clayey, silty blobs have a pale yellow tint; rare firmer, apparently intact cuttings of silt -rich very fine sandstone laminae have a vaguely tabular habit; the bulk of the sand consists of lower medium to upper fine- grained quartz with subordinate black, cryptocrystalline lithics, giving the sand a salt- and - pepper appearance under the microscope; the quartz grains are translucent very Tight gray to pale yellow, with a few transparent colorless grains; the quartz is subangular, while the black lithics are subrounded, and all display moderate sphericity on average; minor rounded blue - green glauconite and rare pyrite is also visible in the samples; very rare intact sandstone cuttings are grain supported, have a weak calcite cement, and display less than 5% porosity; bulk samples are slightly calcareous; coarse, rounded sand and angular chips are present locally in trace amounts; the samples at CANRIG 16 eni Nikaitchuq OP23 -WW02 2860' contains a few cuttings of white, dense yet soft ash; the samples at the top of this interval contain small amounts of nutplug; loose silt and clay content increases at the base of this interval. Sand (3005' - 3125') = samples consist of a slurry of loose sand with variable amounts of disaggregated, pulverulent clay and silt; the aggregate material is medium olive gray, while the sand has a salt- and - pepper appearance under the microscope; the sand consists mostly of transparent to translucent, very light gray to pale yellow quartz with lesser amounts of dark gray to black siliceous Iithics; the sand is well sorted, with grain sizes ranging from upper fine- grained to lower very fine- grained; grains are subrounded to subangular with moderate sphericity overall; minor blue -green glauconite is present; overall samples are only slightly calcareous; sparse rounded coarse grains and very coarse chips are in the samples at the base of this interval. Claystone (3125' - 3215') = samples consist of a medium grayish brown curdy mass of clayey clots coming across the shakers; the aggregate material is extremely cohesive and exhibits high plasticity; small amounts of very fine- to fine- grained sand and a little silt are embedded in the clay, and the sand content varies inversely with the level of plasticity; the claystone appears to be entirely disaggregated, so that no structure is apparent; the clayey mass has a dull, earthy luster underlain by a clayey, somewhat silty texture; a microcrystalline texture is barely perceptible under high magnification. Sand (3215' - 3270) = samples consist of a slurry of loose sand coming across the shakers with variable amounts of small, 1/4 inch clayey clots; the sand has a salt- and - pepper appearance as it consists of very light gray quartz with lesser dark grayish brown to black Iithics; the sand is lower medium to upper very fine - grained, and grains are subangular to subrounded; trace blue -green glauconite and orange Iithics are visible. Sand (3270' - 3330') = samples consist of a medium grayish brown slurry of loose sand, clay, and a small amount of silt coming across the shakers; the sand is composed of upper fine to upper very fine- grained very light gray quartz with lesser black Iithics; grains are subrounded to subangular with moderate sphericity on average; trace rounded blue -green glauconite is visible; no oil indicators. Claystone /Siltstone (3300' - 3400') =light to medium light gray to white; soft; slightly silty to sandy; dull earthy to fluffy white luster; sample collected as irregular globular masses coated with loose sand; hydrophilic; slightly to moderately cohesive; slightly adhesive; appears to occur as thin to moderate interbeds in associated sands; very slightly calcareous appears to be from very fine shell or calcite. Sand (3330' - 3460') = light to medium light gray; salt and pepper appearance; samples collected primarily as dis- aggregated loose sand and globular masses of sand suspended in water expanded hydrophilic clay matrix; moderately sorted; medium lower to fine upper; trace medium upper and coarse; common fine lower and very fine; sub - angular to angular; most larger grains display some degree of rounding on edges due to transport; translucent to clear quartz predominates; common to abundant light to dark gray mineral /lithic grains; trace dark gray to black mafic mineral /Iithics; common gray - green, blue -gray and light to medium brown; matrix is light brownish gray to white hydrophilic clay; trace to very slightly calcareous; no oil indicators. Claystone /Siltstone (3500' - 3600') = light to medium light gray to white; soft; slightly silty to sandy; dull earthy luster; sample collected as irregular globular masses coated with loose sand; variable amounts of sand worked into the clay /silt masses by mechanical action; hydrophilic; slight to moderate cohesion; slightly to non- adhesive; appears to occur as thin to moderate interbeds in associated sands; very slightly calcareous due to shells or fine calcite. L Ugnu 3616' MD /- 3106.8' TVDSS Sand (3500' - 3750') = light to medium gray; salt and pepper appearance; soft to dis- aggregated; sample recovered as about equal parts loose sand and soft clay supported sandstone fragments with occasional small clay /silt masses; moderately to moderately well sorted; medium upper to medium lower, fine upper and coarse lower grain; trace very fine; angular to sub - angular to very slightly rounded; translucent white to clear quartz predominates; abundant light to medium gray and gray brown chert/lithics trace to common black clastic coal • CA RIG 17 eni Nikaitchuq OP23 -WW02 • fines trace coarse chert fragments; primarily supported in clean white kaolinitic clay matrix; matrix is hydrophilic and easily washed away in wash water; trace visible oil stain in samples; no odor; 30 to 40% dull yellow fluorescence; slow cut to bright yellow white improves with crush; slight brown residue with medium yellow gold fluorescence; cuts instantly to yellow white; very slightly calcareous. Sand (3750' - 3850') = samples consist of a slurry of loose sand coming across the shakers with variable small amounts of cohesive clayey clots; the aggregate material is medium olive gray when wet and Tight gray when dry; the sand is moderately sorted, with grain sizes ranging from upper medium to lower fine- grained sand with locally variable coarse and fine sand; the sand is primarily composed of translucent, very light gray quartz with subordinate black siliceous lithics that give the sand a salt and pepper appearance; grains are subangular with moderate sphericity; trace glauconite and pyrite can be seen; very slight oil sheen and trace fluorescence on mud; trace dull yellow fluorescence in mud; slow sample cut to yellow white improves with crush; slight brownish residue with dull gold fluorescence cuts immediately to yellow white; very slightly calcareous; trace shell fragments. Peaks Depth TG C1 C2 C3 C4I C4N C51 C5N 2132 42 7842 2258 55 10782 2583 58 11296 3050 52 10073 3100 50 9914 3152 74 13538 3702 59 12676 Schrader Bluff: 3917'MD/3300.4' TVDSS to 4352' MD/3570.8 TVDSS Drill Rate (ft/hr Total Gas (units) Maximum Minimum Average Maximum Minimum Average 253.6 2.4 96.2 653 TR 129.7 The upper portion of the Schrader Bluff is a series of moderately thick sand beds separated by intervening siltstone interbeds. The lower part of the formation gradually becomes dominated by siltstone and claystone with minor sand interbeds. Some problems due to flocculated mud and mobile cuttings beds were encountered while drilling to casing point at 4607'. Two zones of interest, the "N" and "OA sands produced significant oil shows. Sand (3850' - 4000') = light to medium light gray; soft to dis- aggregated; moderately to moderately well sorted; medium upper to lower to coarse lower in the upper portion becoming medium lower to fine upper and medium upper with depth; trace very coarse; sub - angular to angular and sub spheroidal; most grains slightly rounded and frosted by transport; no crystalline overgrowth noted; translucent smoky to white and clear quartz predominates; trace to common dark to light mineral /lithics; trace brown; common fine to coarse coal fines; trace pyrite; 30% to 80% dull yellow sample fluorescence; bright yellow white cut fluorescence improves on crush; slight brown residue with dull gold fluorescence; very slightly calcareous. TOP "N" SAND AT 4054' MD/ -3387' TVDSS Sand (4000' - 4100') = light to very light gray with a slight brownish to olive secondary hue; soft to dis aggregated; well to moderately well sorted; fine upper to fine lower and medium lower grain; sub angular to angular and sub rounded grains; translucent to smoky and clear quartz predominate; abundant dark gray to black lithics; trace blue jade; occasional small pebble and common fine grain clastic coal; matrix supported in very light olive brown hydrophilic siltstone /claystone; sample recovered as amorphous globular masses and some loose sand; fragments immediately collapse in water; 80% to 100% medium yellow sample fluorescence and fast streaming cut to yellow white; slight brownish residue becomes medium brown at 4060'; medium • IG 18 VIS e n- 1 Nikaitchuq OP23 -WW02 • yellow residue fluorescence cuts to yellow white; trace free oil overall, abundant in the 4050' to 4070' interval; slight to moderate oil odor; slightly Siltstone (4100' - 4200') = very light olive brown to brownish white; soft; irregular globular masses; moderately to very sandy; contains fine lower to very fine upper and medium lower of the same angularity and general mineral distribution as the associated sand; grades to and interbedded with associated sand; slightly calcareous; trace to common brownish white shell fragments with black stain on original shell exterior. BOTTOM "N" SAND 4117' MD/ -3427' TVDSS Siltstone (4200' - 4410') = samples consist of a slurry of loose silt and sand in variable proportions; the aggregate samples are medium olive gray when wet and light gray when dry, with fair to good cohesion and no plasticity with the exception of sporadic intervals containing minor clay; the sand is very well sorted lowermost very fine- grained sand with the exception of fine- grained sandy intervals immediately beneath 4200' and 4300'; the very fine sand consists almost entirely of subangular to subrounded light gray quartz that grades into silt -sized particles; fine- grained sand has a salt and pepper appearance as it consists of very light gray quartz with lesser dark gray to black siliceous Iithics, minor blue -green glauconite, and trace pyrite; the fine- grained sand is subrounded with moderate sphericity overall; rare intact, hard sandstone cuttings are cemented by white calcite; overall samples are moderately calcareous; trace light brown oil stain and rare microscopic tarry blobs; no odor; nearly imperceptible sheen; 30% to 40% even dull yellow fluorescence in fluid portion of samples, and 10% to 20% scattered dull yellow fluorescence in solid cuttings beginning at 4300' and continuing through to the sample at 4410'; slow dark straw cut fluoresces bright white; moderate brown cut residue fluoresces moderate yellow; higher gas levels correspond with grain size. TOP "OA" SAND 4300' MD/ - 3575' TVDSS Siltstone (4410' - 4520') = samples consist of a slurry of silt containing minor very fine- grained sand and trace • amounts of fine sand; the disaggregated silt is medium olive gray when wet and light gray when dry; bulk samples exhibit moderate cohesion but poor plasticity; grades to very fine- grained quartz sand; the very fine sand is a translucent to transparent very light gray to pale yellow; grains are subangular to subrounded and exhibit moderate to good sphericity; the fine sand has a salt and pepper appearance as it consists of mostly light gray translucent quartz with subordinate black siliceous Iithics; grains are subrounded to subangular and exhibit moderate sphericity on average; fluid portions of the samples fluoresce a faintly perceptible white to yellow; no fluorescence in solid cuttings. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 3941 68 11281 70 4037 334 90981 864 509 511 390 361 372 4101 485 64757 795 361 361 216 322 4163 323 41735 449 258 193 164 190 4208 156 19878 195 183 111 37 _ 187 4289 239 26271 334 360 300 468 345 92 4309 653 68802 859 952 351 1123 640 506 • 19 C7 VOs eni Nikaitchuq OP23 -WW02 • Canning; 4352' MD/3570.8' TVDSS to 8120' MD/5926.1' TVDSS Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 333.8 7.3 143.2 290 TR 54.8 The Canning, as found in this well, consisted of two distinct sections; an upper sandy section extending from the base of the "OA" sand to about 5100' MD after which the lithology became gradually dominated by siltstones and claystones. Throughout, the formation consists of interbedded sands, silts and clays some in apparent gradational contact. No problems were encountered drilling this section and no hydrocarbon reservoirs were identified. Siltstone (4520' - 4610') = samples consist of a slurry of silt containing a very slight amount of very fine - grained sand and traces of fine sand; the aggregate samples are medium olive gray when wet and light gray when dry; the very fine sand is very well sorted and grades into silt -sized particles; both the sand and silt are comprised of translucent very light gray quartz that is subangular to subrounded; no structure is apparent as the samples appear to be entirely disaggregated; a very faint, even, white to pale yellow fluorescence is visible in the fluid portion of samples; no fluorescence in solid cuttings. Sandstone (4607' - 4730') = light to very light gray; slight brownish secondary hue in part; soft to slightly firm; silty to sandy texture; dull earthy luster; slight micro - sparkly appearance in part; slightly cohesive /adhesive; commonly interbedded with sandy siltstone and silty clay matrix sandstone; sandstone has 10% medium yellow fluorescence and 10% bright blue -white paint fluorescence; slight instantaneous cut to blue white; slight brownish residue cuts to blue white; very slightly calcareous. Siltstone (4700' - 4840') = light gray to very light gray with very light brown to light brownish gray secondary hues; very soft; irregular to sub - blocky cuttings; silty to slightly gritty texture; dull earthy to slightly sparkly luster; poor adhesiveness; poor to fair cohesiveness; slight to moderately calcareous; commonly grades to sandy siltstone/ silty sandstone; trace coal; trace to 10% dull yellow fluorescence; no visible cut or cut fluorescence. Sand /Sandstone (4780' - 4900') = medium to medium light gray overall with individual grains dominantly clear to translucent quartz, light to medium gray, medium to dark gray with greenish gray hues, trace white, black and rust Iithics; very fine lower to medium lower, dominantly very fine upper to fine upper; angular to subrounded, dominantly subangular; fair to good sorting; dominantly unconsolidated; trace dull gold mineral fluorescence; no oil indicators present. Claystone (4840' - 4920') = light gray to light brownish gray; very soft; irregular to globular, shapeless cuttings; silty to clayey to slightly gritty texture from abundant suspended sands; dull luster; very soluble; hydrophilic; slight to moderately expansive; non to slightly calcareous; poor cohesiveness; poor to fair adhesiveness; trace dull yellow mineral fluorescence; no oil indicators present. Sand /Sandstone (4900' - 5020') = medium to medium light gray overall with individual grains dominantly clear to translucent quartz, light to medium gray, medium to dark gray with greenish gray hues, trace white, black and rust Iithics; very fine lower to coarse lower, dominantly very fine upper to fine upper; angular to subrounded, dominantly subangular; fair to good sorting; dominantly unconsolidated; trace to 20% bright yellowish white with instant light straw cut and bright gold residual cut starting in 4930' sample and decreasing in later samples; mud additive lube 776 added to mud system; no heavy gasses detected ;no other oil indicators present. Siltstone (4980' - 5080') = light gray to very light gray with very light brown to light brownish gray secondary hues; very soft; irregular to sub - blocky cuttings; silty to slightly gritty texture; dull earthy to slightly sparkly luster; poor adhesiveness; poor to fair cohesiveness; slight to moderately calcareous; commonly grades to sandy siltstone/ silty sandstone; trace to 10% yellow fluorescence from mud additive; no other oil indicators • 20 CA11�IG eni Nikaitchuq OP23 -WW02 • present. Sand (5060' - 5110') = medium to medium light gray with light greenish gray secondary hue, individual grains dominantly clear to translucent quartz, light to medium greenish gray, dark gray, black, trace pale rose, rust and bluish green; very fine upper to trace coarse lower, dominantly fine lower to medium lower; angular to subangular; poor to fair sorting; unconsolidated; trace pyrite; 30% dull gold fluorescence; no vis cut; very slow, weak milky white cut fluorescence; no residual ring or ring fluorescence; poor oil indicators. Claystone (5130' - 5220') = light gray to light brownish gray; very soft; irregular to globular, shapeless cuttings; silty to clayey to slightly gritty texture from abundant suspended sands; dull luster; very soluble; hydrophilic; slight to moderately expansive; non to slightly calcareous; poor cohesiveness; poor to fair adhesiveness; trace dull yellow mineral fluorescence; trace pyrite; no oil indicators present. Claystone /Siltstone (5200' - 5300') = medium light to light gray with light grayish brown secondary hues; very soft; shapeless to globular cuttings; silty to clayey texture; dull to slimy luster; moderate to very soluble; slight to moderately expansive; hydrophilic; poor cohesiveness; fair to good adhesiveness; non calcareous; siltstone commonly grades to a sandy siltstone/ silty sandstone; very fragile; soft; light brown to light brownish gray; no to trace dull gold sample fluorescence; no cut or cut fluorescence; no oil indicators present. Siltstone (5260' - 5350') = light gray to very light gray with very light brown to light brownish gray secondary hues; very soft; irregular to sub - blocky cuttings; silty to slightly gritty texture; dull earthy to slightly sparkly luster; poor adhesiveness; poor to fair cohesiveness; slight to moderately calcareous; commonly grades to sandy siltstone/ silty sandstone; trace dull gold mineral fluorescence; no oil indicators present. Claystone (5330' - 5420') = light brown to light brownish gray; very soft; irregular to globular, shapeless cuttings; silty to clayey to slightly gritty texture from abundant suspended sands; dull luster; very soluble; hydrophilic; slight to moderately expansive; non to slightly calcareous; poor cohesiveness; poor to fair • adhesiveness; trace dull yellow mineral fluorescence; trace shell fragments; no oil indicators present. Claystone (5400' - 5490') = light gray to very light brownish gray with light brown secondary hues; very soft; very sticky; shapeless, globular to amorphous cuttings; silty to clayey texture; slimy to dull luster; hydrophilic; very soluble; moderate to very expansive; poor cohesiveness; good to very good adhesiveness; non calcareous; trace to scattered fine grain suspended sands; trace shell fragments; no sample fluorescence; no oil indicators present. Siltstone (5440' - 5520') = light gray to very light gray with very light brown to light brownish gray secondary hues; very soft; irregular to sub - blocky cuttings; silty to slightly gritty texture; dull earthy to slightly sparkly luster; poor adhesiveness; poor to fair cohesiveness; slight to moderately calcareous; commonly grades to sandy siltstone/ silty sandstone; trace dull gold mineral fluorescence; no oil indicators present. Claystone /Siltstone (5500' - 5620') = medium light to light gray with light grayish brown secondary hues; very soft; shapeless to globular cuttings; silty to clayey texture; dull to slimy luster; moderate to very soluble; slight to moderately expansive; hydrophilic; poor cohesiveness; fair to good adhesiveness; non calcareous; siltstone commonly grades to a sandy siltstone/ silty sandstone; very fragile; soft; light gray to light brownish gray; no sample fluorescence; no oil indicators present. Siltstone (5620' - 5700') = light gray to very light gray with very slight brownish secondary hue; very soft to slightly firm; irregular globular to vaguely tabular cuttings habit dull earthy to slightly sparkly luster; silty to slightly sandy texture; slightly to moderately cohesive; moderately adhesive; hydrophilic; contains slight to moderate amounts of very fine grain sand; trace darker sand grains and very fine coal grains; trace very light tan shell fragments; trace to common white calcite fracture fill; trace light gray clay and occasional very light brownish gray sandstone interbeds; trace medium yellow fluorescence with a poor crush cut to yellow white; no other oil indicators; slightly to very slightly calcareous. Siltstone (5700' - 5800') = light gray to very light gray with very slight brownish secondary hue; very soft to • CANRIG 21 eni Nikaitchuq OP23 -WW02 • slightly firm; irregular globular to vaguely tabular cuttings habit dull earthy to slightly sparkly luster; silty to slightly sandy texture; slightly to moderately cohesive; moderately adhesive; hydrophilic; contains slight to moderate amounts of very fine grain sand; trace darker sand grains and very fine coal grains; rare very light tan shell fragments; trace to common white calcite fracture fill; trace light gray clay and occasional very light brownish gray sandstone interbeds; trace medium yellow fluorescence with a poor crush cut to yellow white; no other oil indicators; slightly to very slightly calcareous. Sandstone (5800' - 5890') = very light to light gray with a slight brownish secondary hue; friable; soft to disaggregated; very fine upper to very fine lower grain; moderately sorted; very to slightly silty; trace visible porosity; slightly to moderately rounded to sub - angular; translucent white to smokey and clear quartz predominate; trace dark gray to black mafic mineral grains; trace brown and brick red grains; trace coal fines; trace to common calcite fracture fill; trace shell fragments, some fairly large; slightly to very slightly calcareous; trace dull yellow fluorescence with a slight cut to yellow white; no other oil indicators. Siltstone (5890' - 6010') = light gray to very light gray with very slight brownish secondary hue; very soft to slightly firm; irregular globular to vaguely tabular cuttings habit dull earthy to slightly sparkly luster; silty /clayey slightly sandy texture; slightly to moderately cohesive; moderately adhesive; hydrophilic; contains slight to moderate amounts of very fine grain sand; trace darker sand grains and very fine coal grains; trace very light tan shell fragments; trace to common white calcite fracture fill; trace light gray clay and occasional very light brownish gray sandstone interbeds; trace medium yellow fluorescence with a poor crush cut to yellow white; no other oil indicators; slightly to very slightly calcareous; Sandstone (5890' - 5610') = very light to light gray with a slight brownish secondary hue; friable; soft to disaggregated; very fine upper to very fine lower grain; moderately sorted; very silty; visible porosity; matrix supported slightly to moderately rounded to sub - angular; translucent white to smokey and clear quartz predominate; trace dark gray to black mafic mineral grains; trace brown and brick red grains; trace coal fines; trace to common calcite fracture fill; trace shell fragments; slightly calcareous; trace dull yellow fluorescence with a slight cut to yellow white; no other oil indicators. Siltstone (5890' - 6100') = light gray to very light gray with very slight brownish secondary hue; very soft to slightly firm; irregular globular cuttings habit; dull earthy to slightly sparkly luster; silty to clayey and slightly sandy texture; moderately cohesive; moderately adhesive; hydrophilic; contains moderate amounts of very fine grain sand; trace darker sand grains and fine to medium grain coal grains; trace very light tan shell fragments; common to occasionally abundant white calcite fracture fill; trace hard white clay thinly interbedded in coal fragments; common thin very light brownish gray sandstone interbeds; common to locally abundant light brownish gray claystone interbeds; trace dull yellow fluorescence cuts to yellow white; no other oil indicators; slightly calcareous. Sandstone (6220' - 6310') = very light to light gray with a slight brownish secondary hue; friable; soft to disaggregated; moderately to poorly sorted; very fine upper to fine lower and medium grain; sub - angular to sub - rounded in the finer grain material; angular to sub - angular in the medium grain; translucent white to smokey quartz predominates; trace medium to dark gray lithics, brown and brick red grains all in the medium sand size range; trace to abundant dark gray to black fine upper to medium lower grain size coal fines; trace to common white calcite fracture fill fragments; occasional tan shell fragment; trace to common small, microcrystalline pyrite nodules; occurs as thin interbeds in the associated siltstone /claystone complex; trace dispersed brown oil stain with a dull yellow fluorescence and a slight yellow white cut; no other oil indicators; slightly calcareous. Siltstone (6100' - 6340') = light gray to very light gray with very slight brownish secondary hue; very soft to slightly firm; irregular globular cuttings habit; dull earthy to slightly sparkly luster; silty to clayey and slightly sandy texture; moderately cohesive; moderately adhesive; hydrophilic; contains abundant very fine to medium grain sand; trace darker sand grains and fine to medium coal grains; occasional tan shell fragments; common to occasionally abundant white calcite fracture fill; trace small microcrystalline pyrite nodules; common thin very light brownish gray sandstone interbeds; occurs as a complex of massive to moderate beds with thin sand and claystone interbeds; material appears to generally be in gradational contact; very slightly to slightly • Chu MIG 22 eni Nikaitchuq OP23 -WW02 calcareous. Sandstone (6310' - 6600') = very light to light gray with a slight brownish secondary hue; friable; soft to disaggregated; moderately to poorly sorted; very fine upper to fine lower and medium grain; sub - angular to sub - rounded in the finer grain material; angular to sub - angular in the medium grain; translucent white to smokey quartz predominates; trace medium to dark gray lithics, brown and brick red grains all in the medium sand size range; trace to abundant dark gray to black fine upper to medium lower grain size coal fines; trace to common white calcite fracture fill fragments; trace tan shell fragment; trace to common small, microcrystalline pyrite nodules; occurs as thin interbeds in the associated siltstone /claystone complex; trace dull yellow fluorescence with a slight yellow white cut; no other oil indicators; slightly calcareous. Siltstone (6370' - 6600') = light gray to very light gray with very slight brownish secondary hue; very soft to slightly firm; irregular globular cuttings habit; dull earthy to slightly sparkly luster; silty to clayey and slightly sandy texture; moderately cohesive; moderately adhesive; hydrophilic; contains abundant very fine to medium grain sand; trace darker sand grains and fine to medium coal grains; occasional tan shell fragments. Sandstone /Sand (6600' - 6720') = light to light medium gray with light brown secondary hues overall with individual grains dominantly clear to translucent quartz, trace dark gray to black and bluish green grains; firm to brittle; blocky to platy fragments; very fine lower to fine lower; angular to subangular; very well sorted; moderately well consolidated with very light gray clay/ silt supporting matrix; non calcareous; present as very thin interbeds in dominantly siltstone formation; no sample fluorescence; no oil indicators present. Siltstone (6700' - 6800') = light gray to very light gray with very light brown to light brownish gray secondary hues; very soft; shapeless, globular cuttings; silty to clayey to occasionally gritty texture; dull earthy to slightly sparkly luster; poor adhesiveness; poor cohesiveness; commonly grades to sandy siltstone/ silty sandstone; no sample fluorescence; no oil indicators present. • Sandstone /Sand (6760' - 6880') = light to light medium gray with light brown secondary hues overall with individual grains dominantly clear to translucent quartz, trace dark gray to black and bluish green grains; firm to brittle; blocky to platy fragments; very fine lower to fine lower; angular to subangular; very well sorted; moderately well consolidated with very light gray clay/ silt supporting matrix; non calcareous; present as very thin interbeds in dominantly siltstone formation; trace shell fragments; no sample fluorescence; no oil indicators present. Siltstone (6850' - 6940') = light gray to very Tight brownish gray; very soft; shapeless, formless cuttings; silty to clayey to slightly gritty texture from very fine grain suspended sands; slimy to greasy luster; hydrophilic; moderate to very soluble; poor cohesiveness; poor to fair adhesiveness; trace to scattered very light gray sandstone interbedded with very light gray clayey supporting matrix; non calcareous; siltstone commonly grades between silty sandstone and sandy siltstone; trace shell fragments; no sample fluorescence. Sand/ Sandstone (6920' - 7040') = light to medium light gray with light brown to light brownish gray secondary hues overall, individual grains dominantly clear to translucent quartz, trace dark gray to black lithics, scattered light to medium greenish gray; very fine lower to rare medium upper, dominantly fine lower to very fine upper; angular to subrounded, dominantly subangular; moderately well to very well sorted in fine, fair sorting in medium range; dominantly unconsolidated with very light gray clay as supporting matrix; dominantly present as free suspended grains in siltstone; sandstone commonly grades to silty sandstone to sandy siltstone; non calcareous; trace shell fragments; no sample fluorescence; no oil indicators observed. Siltstone (7000' - 7120') = light gray to very light gray with very light brown to light brownish gray secondary hues; very soft; shapeless, globular cuttings; silty to occasionally gritty texture; dull earthy to slightly greasy luster; poor adhesiveness; poor cohesiveness; slight to non calcareous; commonly grades between sandy siltstone and silty sandstone; no sample fluorescence; no oil indicators present. Siltstone (7070' - 7140') = light gray to very light brownish gray; very soft; shapeless, formless cuttings; silty to clayey to slightly gritty texture from very fine grain suspended sands; slimy to greasy luster; hydrophilic; • I] 23 VIA eni Nikaitchuq OP23 -WW02 • moderate to very soluble; poor cohesiveness; poor adhesiveness; no sample fluorescence. Claystone / Siltstone (7110' - 7200) = very Tight gray with a slight brownish secondary hue; soft to very slightly firm; silky to slightly gritty luster; slightly silty clayey texture to gritty slightly sandy siltstone; locally very sandy; contains variable amounts of loose very fine to fine and occasionally medium grain sand; sand is dominantly clear quartz with some darker grains; trace to common small microcrystalline pyrite nodules; common very fine coal grains and remnants of carbonaceous micro - lamina; trace calcite fracture fill; occasional small tan shell fragments; very slightly calcareous primarily from point sources; material flocculates readily on application of HCI; no oil indicators. Claystone / Siltstone (7200' - 7350) = very light gray with a slight brownish secondary hue; soft to very slightly firm; silky to slightly gritty luster; slightly silty clayey texture to gritty slightly sandy siltstone; locally very sandy; contains variable amounts of loose very fine to fine and occasionally medium grain sand; sand is principally clear quartz with some darker grains; trace very thin (1 mm + -) clean indurated fine grain sandstone with fair porosity; trace small microcrystalline pyrite nodules; common very fine coal grains and remnants of carbonaceous micro - lamina; trace calcite fracture fill; occasional small tan shell fragments; non to trace calcareous; primarily point source effervescence; slow flocculation on application of HCI; no oil indicators. Claystone /Siltstone (7350' - 7400') = very light gray with a slight brownish secondary hue; soft to very slightly firm; silky to slightly gritty luster; slightly silty clayey texture to gritty slightly sandy siltstone; locally very sandy; contains variable amounts of loose very fine to fine and occasionally medium grain sand; sand is principally clear quartz with some darker grains; common very fine coal grains and remnants of carbonaceous micro- lamina; trace fine calcite fracture fill; occasional small tan shell fragments; non to trace calcareous; primarily point source effervescence; slow flocculation on application of HCI; no oil indicators. Sand /Siltstone (7510' - 7600) = light to very light gray with a slight brownish secondary hue in part; moderately sorted in the sand range; poorly sorted overall; fine lower to fine upper and very fine; trace medium lower grain; sub - angular to angular; translucent white to clear quartz predominate in the finer material; medium grain tends to be mostly medium to light dark gray and light to medium brown lithics; trace to common coal fines and micro - lamina shards; occasional trace pyrite; common to abundant calcite fracture fill fragments in the medium upper to fine upper size range; trace to common tan shell fragments; appears to be primarily matrix supported in fine clay /silt; no visible porosity; slightly calcareous overall abundant point source effervescence; no oil indicators Siltstone (7600' - 7690) = medium light gray to very light gray with a slight brownish secondary hue; soft to slightly firm and occasionally firm; dull earthy to slightly grainy to very sandy texture; slightly adhesive; slightly cohesive in part; becoming Tess hydrophilic; common slightly firm to firm medium gray angular irregular fragments; interbedded with soft brownish gray clayey siltstone as seen in the upper sections; common thin fine grain sandstone interbeds; trace to common white to very light gray -white calcite fracture fill in the fine to medium sand size range; occasional shell fragment; slightly to moderately calcareous; no oil indicators. Sand /Sandstone (7570' - 7750) = light to medium gray with a slight brownish secondary hue; soft to disaggregated; moderately sorted; fine upper to fine lower and very fine; locally abundant medium lower grain; sub - angular to angular; about evenly divided between clear to translucent white quartz and light to medium gray lithics/ mineral grains; common dark gray lithics; trace brown lithics; generally supported in a clayey /silty matrix; no apparent porosity; no oil indicators; slightly to moderately calcareous. Siltstone (7700' - 7850) = medium Tight gray to very light gray with a slight brownish secondary hue; soft to slightly firm and occasionally firm; dull earthy to slightly grainy; to very sandy texture; slightly adhesive; slightly cohesive in part; moderately hydrophilic; common slightly firm to firm medium gray angular irregular fragments; interbedded with soft brownish gray clayey siltstone as seen in the upper sections; common thin fine grain sandstone interbeds; trace to common white to very light gray -white calcite fracture fill in the fine to medium sand size range; occasional shell fragment; slightly to moderately calcareous; no oil indicators. • CANR1G 24 en i Nikaitchuq OP23 -WW02 • Siltstone /Claystone (7850' - 7980') = light gray to light olive gray with yellowish gray secondary hues; very soft; very sticky; shapeless, globular, amorphous cuttings; silty to clayey to very slightly gritty texture from very fine grain suspended sands; slimy to pasty; dull to greasy luster; hydrophilic; very soluble; slightly expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; siltstone commonly grades between a sandy siltstone and silty sand stone; no sample fluorescence; no oil indicators observed. Sand /Sandstone (7920' - 8020') = light gray to light brownish gray overall, individual grains dominantly clear to translucent quartz with trace dark gray and black lithics; very fine lower; subangular to subrounded; very well sorted; flat, tabular cuttings; firm to fragile; common very light gray clayey supporting matrix; non calcareous; commonly grades to sandy siltstone/ silty sandstone; no sample fluorescence; no oil indicators. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 4393 239 22347 270 433 312 681 406 4461 262 27137 756 4526 280 No Analysis 4726 218 62772 57 27 15 11 5036 122 21952 83 5049 122 21801 130 5100 290 44742 453 91 5493 110 20927 129 6064 109 22022 160 6160 86 17972 177 6240 68 14252 79 Torok; 8120'MD/5926.1' TVDSS to 8838'MD/6395.6' TVDSS • The Torok was represented by a series of moderate shale and siltstone beds with intervening thin silty sands. No problems were encountered drilling this section and no hydrocarbon reservoirs were identified. Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 248.7 21.4 120.6 132 25 59.2 Siltstone /Claystone (7980' - 8080') = light gray to Tight olive gray with brownish gray secondary hues; very soft; very sticky; shapeless, globular, amorphous cuttings; silty to clayey to very slightly gritty texture from very fine grain suspended sands; slimy to pasty; dull to greasy luster; hydrophilic; very soluble; slightly expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; siltstone commonly grades between a sandy siltstone and silty sand stone; trace fine to medium lower coal grains; trace shell fragments; no sample fluorescence; no oil indicators present. Sand (8060' - 8170') = light gray overall with individual grains dominantly clear to translucent quartz, trace black, rust and greenish gray; very fine Tower to rare medium lower, dominantly very fine upper; subangular to subrounded; moderately well sorted; unconsolidated; present as loose grains in dominantly siltstone/ claystone formation; trace coarse frosted white and fine tan shell fragments; trace to common black coal fines; no sample fluorescence; no oil indicators present. Siltstone /Claystone (8120' - 8270') = light gray to light olive gray with brownish gray secondary hues; very soft; very sticky; shapeless, globular, amorphous cuttings with trace slightly firm tabular cuttings; very fragile; silty to clayey to gritty texture from fine suspended sands; slimy to pasty; dull to greasy luster; hydrophilic; very soluble; slightly expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; siltstone commonly grades between a sandy siltstone and silty sand stone; trace fine to medium lower coal grains; trace shell 411 G 25 eni Nikaitchuq OP23 -WW02 fragments; no sample fluorescence; no oil indicators present. Sand (8220' - 8320') = light gray overall with individual grains dominantly clear to translucent quartz, trace black, rust and greenish gray; very fine lower to rare medium lower, dominantly very fine upper; subangular to subrounded; moderately well sorted; unconsolidated; present as loose grains in dominantly siltstone/ claystone formation; trace coarse frosted white and fine tan shell fragments; trace to common black coal fines; trace very weak, dull gold fluorescence; no visible cut or cut fluorescence; Resinex mud additive being added to system; no oil indicators present. Siltstone (8310' - 8440') = medium to light gray to light olive gray with brownish gray secondary hues; very soft; very sticky; shapeless, globular, amorphous cuttings with trace slightly firm tabular cuttings; very fragile; silty to clayey to gritty texture from fine suspended sands; slimy to pasty; dull to greasy luster; hydrophilic; very soluble; slightly expansive; poor cohesiveness; fair to good adhesiveness; non calcareous; siltstone commonly grades between a sandy siltstone and silty sand stone; trace fine pyrite nodules; trace shell fragments; no sample fluorescence; no oil indicators present. Sand /Sandstone (8400' - 85201 = light to medium light gray overall with individual grains dominantly clear to translucent quartz, trace amounts of dark gray to black, medium to dark greenish gray and rust; present as loose grains in dominantly siltstone/ claystone formation; very fine lower to rare medium lower, dominantly very fine lower to fine lower; subangular to subrounded; moderately well sorted; dominantly unconsolidated with scattered sandstone fragments; medium light to light gray; very fine grain; subangular; very well sorted firm to fragile; commonly grain supported non calcareous; trace shell fragments; trace pyrite nodules; trace weak, pale gold fluorescence from mud additives; no other fluorescence noted; no visible cut or cut fluorescence; no other oil indicators present. Siltstone (8500' - 86401 = light to medium gray with light brown to brownish gray secondary hues; amorphous, shapeless to scattered wedge and tabular shaped cuttings; very soft to moderately firm; silty to slightly gritty texture; slimy to dull luster; soluble in part; hydrophilic; poor to fair cohesiveness and adhesiveness; non calcareous; trace shell fragments; siltstone commonly grades to a light brown to light grayish brown silty sandstone/ sandy siltstone; very weak, dull gold fluorescence from mud additives floating on sample; no cutor cut fluorescence; no residual ring or ring fluorescence; no other oil indicators present. Shale (8590' - 8710') = medium light to medium gray; slightly firm; coarsely fissile blocky to thin angular fragments; dull earthy to grainy luster; silty to smooth shaly texture; thinly interbedded in associated sandy siltstone; non to very slightly calcareous. Siltstone /Sandstone (8620' - 8820') = medium gray to medium light brownish gray and light gray with a brownish secondary hue; slightly to moderately firm; sandy /gritty texture throughout; grades to and interbedded with a light brownish gray sandstone; occasional medium to light gray silty shale interbeds; slightly cohesive; non to slightly adhesive; crumbly; contains abundant fine lower to fine upper and occasional medium lower grain sand; sand is generally angular to subangular clear to translucent white quartz; common light to medium gray lithic /mineral grains; trace bluish gray, green and orange; trace shell fragments and calcite; trace very dull yellow fluorescence in samples, no cut; no oil sheen in pits scattered floaters in water on sample trays show no fluorescence; no other oil indicators; adding biocide and Resinex to mud; mud taking on a brownish color; non to very slightly calcareous. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 8353 62 12220 361 123 8671 106 20728 715 310 79 8737 130 22965 943 425 101 93 HRZ; 8838'MD/6395.6' TVDSS to 8838'MD/6395.6' TVDSS • CANIRIG 26 eni Nikaitchuq OP23 -WW02 Drill Rate (ft/hr Total Gas (units Maximum Minimum Average Maximum Minimum Average 273.3 16.9 115.7 231 trace 103.3 The HRZ consisted of thinly bedded /interbedded shale and carbonaceous shale with trace amounts of hard bituminous coal. No problems were encountered drilling this section and no hydrocarbon reservoirs were identified Shale (8800' - 8920) = medium to medium light gray; moderately firm to slightly firm; fissile; thin small platy cuttings habit; occasional blocky thinly laminated fragments; dull earthy to slightly sparkly luster; shaly to slightly silty texture; trace to abundant orange to dark tan flaky material; apparent graded contact with the overlying siltstone; heavily micro - laminated with lighter material separating the lamina; trace pyrite above the upper contact, none noted below the contact; trace very dull yellow fluorescence, no odor stain or cut; abundant white calcite fracture fill; very calcareous. Shale (8920' - 8980) = medium to medium light gray; moderately firm to slightly firm; fissile; thin small platy cuttings habit; occasional blocky thinly laminated fragments; dull earthy to slightly sparkly luster; shaly to slightly silty texture; abundant orange to dark tan flaky material; heavily micro - laminated with lighter material; abundant finely fissile carbonaceous shale fragments; trace to common hard bituminous coal; abundant orange flakes and dark tan shale; abundant white calcite fracture fill; very calcareous; trace very dull yellow fluorescence; no stain, odor or cut. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 8935 231 37874 1878 1869 222 380 88 42 • 9028 187 30801 1478 1001 188 324 68 7 Kalubik 8941' MD/6463.3' TVDSS to 9263' MD/6668.7' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 363.9 9.2 111.6 102 2 30.6 The Kalubik consists of moderate beds of shale, carbonaceous shale and siltstone with rare thin sandstone interbeds. No problems were encountered drilling this interval and no hydrocarbon reservoirs were identified. Shale (8920' - 8980) = medium to medium light gray; moderately firm to slightly firm; fissile; thin small platy cuttings habit; occasional blocky thinly laminated fragments; dull earthy to slightly sparkly luster; shaly to slightly silty texture; abundant orange to dark tan flaky material; heavily micro - laminated with lighter material; abundant finely fissile carbonaceous shale fragments; trace to common hard bituminous coal; abundant orange flakes and dark tan shale; abundant white calcite fracture fill; very calcareous; trace very dull yellow fluorescence; no stain, odor or cut. Kalubik Marker 9060 MD/6540.7' TVDSS Shale (9070' - 9120') = evenly divided between medium gray carbonaceous shale and very light brownish gray shale at 9070' becoming dominated by carbonaceous shale at 9120'; moderately to slightly firm; platy fissile in the lighter material, sub - fissile in the darker; clean to slightly silty; grades to similar shaly siltstone in part; occasional thin sandy intervals; trace pyrite; common white to light brownish calcite fracture fill; very slight trace very dull yellow fluorescence; no stain, odor or cut. 27 CANRIG Ana Nikaitchuq OP23 -WW02 • Shale (9120' - 9200) = medium dark to medium gray with a distinct brownish secondary hue; very firm to firm; coarsely to trace finely fissile; silty clean shaly texture; micro - sparkly to dull earthy luster; common PDC bit gouge trace to common fine pyrite; common very fine mica; trace medium grain medium gray moderately rounded sandstone; trace to common brown to Tight gray siltstone interbeds; very slightly calcareous; expansive in water; flocculates in HCL; no oil indicators. Siltstone (9200' - 9300) = medium dark to medium gray with a distinct brownish secondary hue; very firm to firm; silty to clayey texture; non to slightly fissile; mottled appearance in part; trace to common brown to light gray slightly shaly siltstone interbeds; occasional thin fine grain sandstone interbeds; common to abundant pyrite; micaceous; beginning at 9260/70' fine upper to medium lower, sub - angular clear quartz sand very slight brown stain on some grains; very slightly calcareous; no notable increase over background fluorescence; no other oil indicators present. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N NONE Kuparuk; 9263' MD/6668.7' TVDSS to 9539 MD/6853.6 TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 305.7 12.2 120.8 62 6 22.2 The Kuparuk is represented by a series of siltstones and sandstones interbedded with minor shale and carbonaceous shale. The Lower Cretaceous Unconformity represents the lower contact between the Kuparuk and Jurassic (Miluveach). No problems were encountered drilling the Kuparuk and no petroleum reservoirs • were identified. Sand /Sandstone (9300' - 9400') = dominantly light gray overall with individual grains dominantly clear to translucent quartz; very fine lower to rare coarse lower, dominantly fine grain; angular to subrounded, dominantly subangular; well sorted in fine range, fair to poor sorting in medium to coarse; dominantly unconsolidated with scattered sandstone pieces with abundant blue/ green glauconite nodules interbedded in fine grain sandstone in 9370' sample; trace bright yellowish white fluorescence in 9370'- 9390' samples; instant bright yellowish white cut fluorescence and medium light brown cut; bright yellow residual ring; Tight brown stain on very fine sandstone pieces that fluoresce; no odor above oil base mud; no free oil observed. Carbonaceous Shale (9370' - 9460') = medium to medium brown; firm; platy to scooped appearance from bit cutting action; planar fracture dominant; silty to slightly gritty texture; earthy luster; commonly interbedded with light gray siltstone; trace pyrite along bedding planes; trace sandstone with interbedded glauconite nodules; trace bright yellow fluorescence; trace light brown stain; yellowish white cut fluorescence; light straw cut; trace pale yellow residual ring fluorescence; fluorescence associated with glauconitic sandstone; no free oil detected. Peaks Depth TG C1 C2 C3 C41 C4N C5I C5N 9367 62 11187 220 104 9419 54 10234 195 54 9545 25 4253 117 73 Jurassic; 9538.5' MD/6853.6 TVDSS to 11228'MD/8412.8' TVDSS G 28 CANRI eni Nikaitchuq OP23 -WW02 M Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 304 9.1 141.4 93 TR 27.5 The Jurassic was recovered here as a series of moderate to massive beds of sandy to very sandy siltstone grading to similar silty sandstone. The material contained numerous thin shale and carbonaceous shale interbeds and was primarily matrix supported with rare grain supported fragments recovered. No problems were associated with the drilling of this section and no recoverable hydrocarbons were found. Sand /Sandstone (9460' - 9590') = dominantly light gray overall with individual grains dominantly clear to translucent quartz; very fine lower to rare coarse lower, dominantly fine grain; angular to subrounded, dominantly subangular; well sorted in fine range, fair to poor sorting in medium to coarse; dominantly unconsolidated with trace sandstone pieces with scattered blue/ green glauconite nodules interbedded in fine to medium grain sandstone; trace to common pyrite nodules; trace calcite grains; trace pinpoint bright yellowish white fluorescence; slow milky white cut fluorescence no residual ring or ring fluorescence; no other fluorescence above oil base mud background; no other oil indicators. Siltstone (9560' - 9690') = medium gray to medium light gray and light to medium brown; firm to slightly hard; platy to splintery to irregular curved and gouged from bit action shaped cuttings; silty slightly gritty texture; dull to earthy luster; siltstone commonly grades to a medium gray silty sandstone/ sandy siltstone; non to slightly calcareous; commonly interbedded in medium to medium dark brown shale/ siltstone; no sample fluorescence above oil base mud background; no other oil indicators present. Carbonaceous Shale (9660' - 9750') = medium to medium brown; firm; platy to scooped appearance from bit cutting action; planar fracture dominant; silty to slightly gritty texture; earthy luster; commonly interbedded with light gray siltstone; trace pyrite along bedding planes; no sample fluorescence above oil base mud background; no other oil indicators present. Sand /Sandstone (9700' - 9790') = dominantly light gray overall with individual grains dominantly clear to translucent quartz; very fine lower to rare coarse lower, dominantly fine grain; angular to subrounded, dominantly subangular; well sorted in fine range, fair to poor sorting in medium to coarse; dominantly unconsolidated with trace sandstone pieces; friable; moderately calcareous cement; no sample fluorescence above oil base mud background. Siltstone (9780' - 9870') = medium to medium dark brown with medium grayish brown secondary hues; irregular, massive to platy and splintery cuttings with pdc bit action scooped shape; firm to moderately hard; brittle at times; silty to slightly gritty texture; dull to earthy luster; non calcareous; note abundant Safe Carb mud additive contamination (crushed marble); no sample fluorescence above oil base mud background levels; no oil indicators present. Sand /Sandstone (9800' - 9900') = dominantly light gray overall with individual grains dominantly clear to translucent quartz; very fine lower to rare coarse lower, dominantly fine grain; angular to subrounded, dominantly subangular; well sorted in fine range, fair to poor sorting in medium to coarse; dominantly unconsolidated with trace sandstone pieces; friable; moderately calcareous cement; no sample fluorescence above oil base mud background. Siltstone (9900' - 10000') = medium to medium dark gray with a moderate brownish secondary hue; very firm to firm; angular irregular to slightly splintery and occasionally blocky cuttings habit; dull earthy luster; silty to shaly texture; coarsely fissile; common pdc bit gouge; occurs as moderate to thick beds with common thin silty sand interbeds; slightly calcareous; expansive in water; flocculates immediately in hcl; note; abundant white Safe Carb (calcium carbonate) mud additive; no sample fluorescence above oil base background; no stain or other oil indicators. • I] 29 en i Nikaitchuq OP23 -WW02 • Sandstone /Sandy Siltstone (10000' - 10100') = medium light to medium brownish gray; sample recovered as blocky to irregular silt matrix sandstone and abundant to trace loose moderately sorted; fine upper to very fine upper to medium lower grain; subangular to angular to rare moderately well rounded; translucent to clear quartz sand; trace darker grains no cemented fragments showing grain support; primarily matrix supported in light to medium light gray /brown silt; interbedded in and grading to associated siltstone; slightly to moderately calcareous; trace to common Safe Carb contamination; no oil indicators. Sandstone /Sandy Siltstone (10100' - 10200') = medium light to medium brownish gray; sample recovered as common loose disaggregated sand and minority silty sandstone fragments; moderately to moderately well sorted; fine upper to medium lower and very fine upper; trace medium upper and coarse; sub - angular to angular grain; clear to translucent white quartz predominate; trace dark brown and black mineral /lithics; no matrix residue or crystal overgrowth noted on loose grains; trace dispersed pyrite and occasional small pyrite nodules; trace dead oil stain on lamina in associated siltstone; slightly to moderately calcareous; abundant Safe Carb contamination; no raw oil odor; very slight increase in sample fluorescence; no other oil indicators. Siltstone (10100' - 10190') = medium to medium dark gray with a moderate brownish secondary hue; very firm to firm; angular irregular to slightly splintery and occasionally blocky cuttings habit; dull earthy luster; silty to shaly texture; coarsely fissile; common pdc bit gouge; occurs as moderate to thick beds with common thin silty sand interbeds; slightly calcareous; trace fine crystalline pyrite and occasional small pyrite nodules; expansive in water; flocculates immediately with application of hcl; note; abundant white to clear Safe Carb (calcium carbonate) mud additive; no sample fluorescence above oil base background; no stain or other oil indicators. Sandstone /Sandy Siltstone (10190' - 10310') = medium light to medium brownish gray; sample recovered as trace loose dis- aggregated sand and silty sandstone fragments; moderately well sorted in the sand range; poorly sorted overall; very fine upper to fine lower grain; trace medium upper; subangular to angular clear to translucent white quartz predominates; trace darker grains; entirely matrix supported in recovered fragments; no visible crystal overgrowth noted on loose grains; trace dispersed pyrite and occasional small pyrite nodules; trace dead oil stain on lamina in associated siltstone; slightly to moderately calcareous; abundant Safe Carb contamination; no raw oil odor; very slight increase in sample fluorescence; no other oil indicators. Siltstone (10330' - 10480') = medium to medium light gray with a slight brownish secondary hue; minority light to medium grayish brown; very firm to firm; dull earthy luster; mottled /banded appearance in part; silty to sandy texture; generally slightly to very sandy; contains very fine upper to lower grain sand; grades to and interbedded with associated thin sandstone; trace dead oil in some fragments; trace fine crystalline pyrite and occasional pyrite nodules; no raw oil odor; no significant change in background fluorescence; no notable spot fluorescence in samples; slightly calcareous; trace to abundant Safe Carb contamination. Siltstone (10330' - 10480') = medium to medium light gray with a slight brownish secondary hue; trace light to medium grayish brown; very firm to firm; dull earthy luster; mottled /banded appearance in part; silty to sandy texture; generally non to slightly sandy; contains very fine upper to lower grain sand; grades to and interbedded with associated thin sandstone; trace dead oil in some fragments; trace fine crystalline pyrite and occasional pyrite nodules; no raw oil odor; no significant change in background fluorescence; no notable spot fluorescence in samples; slightly calcareous; trace to abundant Safe Carb contamination. Siltstone (10480' - 10670') = medium to medium light brownish gray; trace medium brown; very firm to firm; dull earthy to slightly sparkly appearance; mottled to banded appearance in part; coarsely fissile; very slightly to slightly sandy; grades to thin silty sandstone interbeds; trace thin ash /clay interbeds; trace disseminated fine pyrite and occasional pyrite nodules; trace dead oil in some fragments; common to abundant Safe Carb contamination; trace visible outgassing; no raw oil odor or other oil indicators; slightly calcareous. Siltstone (10670' - 10760') = medium to medium light brownish gray; trace medium brown; very firm to firm; dull earthy to slightly sparkly appearance; mottled to banded appearance in part; coarsely fissile; very slightly to slightly sandy; grades to thin silty sandstone interbeds; trace very fine disaggregated sand; trace thin ash /clay fragments; trace disseminated fine pyrite crystals and occasional small pyrite nodules; trace, • CAMG 30 eni Nikaitchuq OP23 -WW02 becoming rare dead oil on bedding planes and fractures common Safe Carb contamination; trace visible outgassing; no raw oil odor or other oil indicators; slightly calcareous. Siltstone (10760' - 10830') = medium to medium light brownish gray; trace medium brown; very firm to firm; dull earthy to slightly sparkly appearance; mottled to banded appearance in part; coarsely fissile; slightly to very slightly sandy; grades to thin silty sandstone interbeds; common very fine disaggregated sand; trace shell fragments; trace disseminated fine disaggregated sand; trace thin ash /clay fragments; trace disseminated fine pyrite crystals and occasional small pyrite nodules; trace dead oil stain in some fragments; common to trace Safe Carb contamination; trace visible outgassing; no raw oil odor or other oil indicators; trace blue white point mineral fluorescence; slightly calcareous. Sand /Sandstone (10850' - 10940') = medium light gray overall with individual grains dominantly clear to translucent quartz, frosted white, trace dark gray to black; very fine lower to rare coarse lower, dominantly fine lower to upper; angular to rare subrounded, dominantly subangular; fair to good sorting in fine range; dominantly unconsolidated with light to medium gray sandstone; very fine lower; commonly grading between silty sandstone and sandy siltstone; irregular shaped cuttings; firm to friable; slightly calcareous; trace fine shell fragments; continued Safe Carb contamination; no sample fluorescence above oil base mud background levels; no other oil indicators present. Siltstone (10940' - 11050') = medium to medium Tight gray with light brown secondary hues; common dark brown banding and alternating shades of gray; firm to slightly hard; massive; irregular shaped cuttings with bit gouging common; silty to slightly gritty texture; dull, earthy to slightly sparkly luster; hydrophilic; soluble and expansive when exposed to water; slight to moderately calcareous; siltstone commonly grades to very fine silty sandstone/ sandy siltstone; very dull gold sample fluorescence no sample fluorescence above oil base mud background levels; no oil indicators. Sand /Sandstone (11020' - 11130') = medium light to medium gray overall, individual grains dominantly clear • to translucent quartz, white, trace dark gray to black; very fine lower to rare coarse lower, dominantly fine lower to upper; angular to rare subrounded, dominantly subangular; fair to good sorting in fine range; dominantly unconsolidated with light to olive gray sandstone; very fine lower; commonly grading between silty sandstone and sandy siltstone; irregular shaped cuttings; firm to friable; slightly calcareous; trace fine shell fragments; continued Safe Carb contamination; no sample fluorescence above oil base mud background levels; no other oil indicators present. Siltstone (11120' - 11230') = medium to olive gray with light brown secondary hues; common dark brown banding and alternating shades of lighter gray; firm to slightly hard; massive; irregular shaped cuttings with bit gouging common; silty to slightly gritty texture; dull, earthy to slightly sparkly luster; hydrophilic; soluble and expansive when exposed to water; slight to moderately calcareous; siltstone commonly grades to very fine silty sandstone/ sandy siltstone; trace loose pyrite nodules and pyrite along bedding planes; continued Safe - Carb mud additive contamination; no sample fluorescence above oil base mud background levels; no oil indicators. Peaks Depth TG C1 C2 C3 C4I C4N C5l C5N 11085 93 15666 350 225 TR 75 Sag; 11228'MD/8412.8' TVDSS to 11327' MD/8510.3' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 185.5 44.4 111 120 32 80.4 The sag consisted of a thin section of sand and siltstone interbeds with traces of shale. The formation yielded some weak oil indicators but none were considered shows. No problems were associated with the drilling of 31 CANRIG Pk en i Nikaitchuq OP23 -WW02 • this formation and no recoverable hydrocarbon reservoirs were found. Sand /Sandstone (11210' - 11320') = medium to medium brownish gray overall, individual grains dominantly clear to translucent quartz, trace dark gray to black, white and bluish green glauconite nodules; very fine lower to rare coarse lower, dominantly fine lower to very fine upper; angular to subrounded, dominantly subangular; moderately well sorted; loosely grain supported; friable to fragile; trace pyrite nodules; the 11300' sample has 40% dull gold fluorescence above background levels; scattered dark brown stain; no free oil or odor; slow milky white cut fluorescence; no to weak, slow pale straw visible cut; trace yellowish white residual ring fluorescence. Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 11285 110 20234 692 430 TR 162 11296 121 19555 663 415 TR 161 Shublik; 11327' MD/8510.3' TVDSS to 11556'MD/8735.7' TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 181 12.5 68.5 780 13 45.8 The lithology of the Shublik formation consisted primarily of moderate to massive beds of varicolored calcareous siltstone grading to silty limestone. The section was heavily interbedded with thin calcareous glauconitic sands. No engineering problems were encountered while drilling the Shublic. Traces of oil stain and fluorescence were found but no productive reservoirs were identified. • Siltstone (10310'- 10380') = medium gray to medium brown to brownish gray; firm to moderately hard; irregular, massive cuttings with bit gouging common; silty to slightly gritty texture; dull, earthy luster; alternating bands of light gray, dark brown common; moderately calcareous; hydrophilic; soluble and moderately expansive when exposed to water; continued Safe Carb mud additive contamination trace dull gold sample fluorescence above background levels; weak, pale straw visible cut; slow, milky yellow cut fluorescence; trace dark brown stain on sandstone pieces; very fine grain with abundant glauconite; no free oil observed; no other oil indicators present Limestone (11430' - 11510') = pinkish gray to yellowish gray, light brown to light to medium gray to grayish brown; mottled appearance with alternating thin bands of different shades of gray and brown; firm to friable and fragile; irregular shaped cuttings to platy and splintery; waxy luster; earthy to gritty texture; very strong hcl reaction; no sample fluorescence above oil base mud background levels; no free oil; no other oil indicators present. Siltstone (11510' - 11570') = medium to medium light gray; mottled appearance; moderately firm to firm; angular irregular to blocky and splintery fragments; dull earthy luster; silty to very sandy texture; coarsely fissile; crumbly in part; grades to very silty limestone and silty sandstone; all contain white calcareous inclusions; very calcareous overall; trace shell fragments; abundant pyrite as a secondary cementing agent; trace to common pyrite nodules; no increase in background fluorescence; trace white mineral fluorescence; no oil indicators. 1 Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 11370 62 11715 402 235 TR 86 11446 72 12934 541 317 TR 123 11479 780 135780 5188 2589 261 682 11523 80 15719 640 308 31 99 • IG 32 eni Nikaitchuq OP23 -WW02 Ivishak; 11556'MD/8735.7' TVDSS to 12185' MD/9359.8' TVDSS Drill Rate (ft/hr) Total Gas (units Maximum Minimum Average Maximum Minimum Average 235 1.6 77 174 TR 28.7 The Ivishak formation produced an immediately identifiable change in lithology. The upper sands were silty grading to sandy siltstone with traces of ash /clay and abundantly pyritic, were primarily matrix supported with some local zones of porosity and were very calcareous. The calcite content decreased and visible porosity increased with depth as made apparent by the condition of the recovered material. A weak oil show was encountered in the upper sand but was not considered to be of economic interest. This section was typified by slow to moderate loss of drilling fluid to formation and continued poor returns. Sandstone /Sandy Siltstone (11570' - 11660') = medium Tight gray; slight brownish secondary hue; firm to disaggregated; friable in part; sample recovered primarily as loose sand and occasional silty fragments; medium lower to fine upper grain; sun - angular to subrounded and angular; translucent white to clear quartz predominate; trace to common dark mineral /lithic grains; common white calcareous inclusions; trace white ash /clay; very calcareous; common medium yellow fluorescence primarily in the silty sandstone fragments; medium streaming cut to yellow white; very slight brownish residue ring yellow white residue fluorescence in the center of the spot; cuts to yellow white; trace dark brown dead oil blebs; no raw oil odor; trace stain in silty fragments. Sandstone (11660' - 11740') = light to very light brownish gray to yellowish white; slightly firm to firm to disaggregated; friable/ crumbly; fine upper to medium lower grain; moderately rounded to sub - rounded to sub - angular; translucent white to clear quartz; trace very fine dark mineral grains; mixed matrix and grain supported; matrix is very light gray to white clay; slight yellowish secondary hue; material is mottled with orange /rust colored stain; interbedded with thin clay and occasional medium gray shale /siltstone; upper contact contains some shell fragments; very slightly calcareous; slight trace oil stain and dead oil at upper contact; no oil indicators below 11710'. Sandstone /Sand (11710' - 11800') = very light gray -white with a slight yellowish secondary hue; unconsolidated to moderately firm; primarily grain supported; locally clay supported as seen above; fine upper to medium lower and very fine grain; sub - angular to angular and sub - rounded; translucent to clear and yellow quartz; trace fine to medium upper grain black lithic /mineral grains; abundant very fine pyrite adhering to sand grains; trace small pyrite nodules; trace brick red splintery fragments; note: abundant Safe Carb mud additive in samples; scattered dull yellowish white fluorescence above background levels; no visible cut and no cut fluorescence above background levels; no free oil present; no other oil indicators, Siltstone (11880' - 11990') = present as thin beds in dominantly sand formation; several colors present; medium olive gray to brownish gray; firm; irregular shaped cuttings; silty to clayey texture; earthy luster; non calcareous; reddish brown; slightly firm to pulverulent; fragile; irregular shaped cuttings; silty to slightly gritty texture; earthy luster; non calcareous; yellowish white to grayish white; irregular shaped; fragile to pulverulent; silty to clayey texture; waxy to slightly sparkly luster moderately calcareous; scattered bright yellow mineral fluorescence; no other fluorescence above oil base mud background levels; no oil indicators present note: continued Safe Carb and other lcm materials in samples. Sand /Sandstone (11980' - 12090') = light gray to grayish white to light to medium Tight gray and medium reddish brown overall color with changes in color of siltstone, individual grains dominantly clear to translucent quartz, dark gray to black and trace pale rose and rust lithics; very fine lower to scattered very coarse black lithics, dominantly fine upper to lower; angular to subangular; well sorted in fine range; dominantly unconsolidated with abundant light grayish white and pinkish gray clayey/ ashy supporting matrix common; moderate to very calcareous; scattered yellowish white mineral fluorescence; no cut fluorescence above oil • CANRIG 33 VA eni Nikaitchuq OP23 -WW02 • base mud background levels. Siltstone (12090' - 12180') = medium to medium light gray and medium dark brown to reddish brown; irregular with common bit gouging to subplaty and occasionally splintery; silty to clayey to slightly gritty texture; dull, earthy luster; moderately soluble and expansive when exposed to water; non to slightly calcareous note overall color change to a reddish brown in 12080' sample and returning to dominantly light medium gray in 12170' sample with 10% - 20% reddish brown siltstone present; scattered yellowish white mineral fluorescence; no other cut or fluorescence above oil base mud background levels; no oil indicators present Peaks Depth TG C1 C2 C3 C41 C4N C51 C5N 11568 83 16698 624 303 94 62 10 18 11616 154 27525 813 224 26 103 48 90 11688 174 31878 994 356 42 113 14 22 11800 64 10056 261 206 20 10 12107 36 6982 352 • • CANRIG 34 eni Nikaitchuq OP23 -WW02 Kavic Shale; 12185' MD/9359.8' TVDSS to TD (il 12323' MD/9550.6' TVD -RKB Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 93.7 13.2 58.2 22 6 14.1 Siltstone (12090' - 12180') = medium to medium light gray and medium dark brown to reddish brown; irregular with common bit gouging to subplaty and occasionally splintery; silty to clayey to slightly gritty texture; dull, earthy luster; moderately soluble and expansive when exposed to water; non to slightly calcareous note overall color change to a reddish brown in 12080' sample and returning to dominantly light medium gray in 12170' sample with 10% - 20% reddish brown siltstone present; scattered yellowish white mineral fluorescence; no other cut or fluorescence above oil base mud background levels; no oil indicators present Sand /Sandstone (12170' - 12260') = medium to olive gray overall with individual grains dominantly clear to translucent quartz, dark gray to black, trace pale rose, dusky red and dark greenish gray; very fine lower to rare very coarse black lithics, dominantly fine grain; angular to subangular; moderately well sorted in fine range, poor to fair in medium to coarse; medium gray sandstone commonly grades to silty sandstone/ sandy siltstone; non to slightly calcareous; trace to common Icm in samples; no sample fluorescence above oil base mud background levels; no oil indicators Siltstone /Shale (12260' - 12323' -TD) = medium to medium light gray to mottled medium dark gray; slight reddish brown secondary hue in part; firm to very firm and soft; dull earthy to slightly sparkly luster; silty to shaly and slightly sandy texture; coarsely fissile overall; common medium to medium dark gray shale and light brownish gray very fine grain sandstone as thin interbeds; trace loose very fine grain sand; trace hard white ash /clay, brick red sideritic siltstone and white to light brown calcite fracture fill; very CANRIG 35 rifik ni Nikaitchuq OP23 -WW02 • 3.6 Connection Gases lunit = 0.05% Methane Equivalent Depth Gas over BGG Depth Gas over BGG (feet) (units) (feet) (units) 4152 185 11510 86 11708 186 11712 Swab 72u 11798 113 11848 Swab 56u 3.7 Trip (Wiper) Gases lunit = 0.05% Methane Equivalent Depth Trip to Gas (feet) (feet) (units) 3666 Surface 13 6600 3660 170 9120 4585 329 11847 10842 64 12323 9120 90 • CANRIG 36 rtfOs ena Nikaitchuq OP23 -WW02 • 3.8 Sampling Program / Sample Dispatch Set Type / Purpose Frequency Interval Dispatched to Unwashed Samples, (Iso- 3311 Data Solutions 3311 S. US Hwy 77 A lars) with preservative 30' -10' and 1000 -12323 Set owner: ENI per plan Schulenburg, TX 78956 Washed /wet Samples, Fugro Data Solutions B (whirl pack) 30' -10' 1000 -12323 3311 S. US Hwy 77 Set owner: ENI per plan Schulenburg, TX 78956 Fugro Data Solutions C Washed- and -dried 30' -10' 1000'- 12323' 3311 S. US Hwy 77 Samples Set Owner ENI per plan Schulenburg, TX 78956 Washed- and -dried AOGCC D Samples Set Owner State per p an 1000'- 12323' 333 W. 7 AVE, SUITE 100 of Alaska Anchorage, AK 99501 1 Washed, spin -dried Fugro Data Solutions 30'/l0' 3311 S. US Hwy 77 E samples(vials) Set Owner, per plan 1000'- 12323' Schulenburg, TX 78956 ENI Washed, spin -dried AOGCC F samples(vials) Set Owner, 30'/10' 1000' -12323 333 W. 7 AVE, SUITE 100 State of Alaska per plan Anchorage, AK 99501 Weatherford Laboratories G Gas Samples in Iso- 500' and 1000'- 12323' 8845 Fallbrook Drive Tubes, Set Owner, ENI per plan Houston, TX 77064 • 37 CANNG Vis e Nikaitchuq OP23 -WW02 • 3.9 Approved Sample Plan OP23 -WW02 Dry samples: 2 Sets every 30' from 1000' to TD. Note: increase to 10' intervals on shows and zones of interest ( "ZOI "). Wet Samples: 1 Set every 30' from 1000' to TD; Note: increase to 10' intervals on shows and zones of interest ( "ZOI "). Iso- Tubes: Every 500' from shoe to TD. Note: increase to 30' intervals on shows and zones of interest ( "ZOI "). Canned Cuttings Samples: (In Iso -Jars) Every 30' from 1000' to TD. Note: no increase for ZOI and shows. Canned Mud samples: Every n1000' from shoe to TD. Take these samples from the possum belly only. Canned Condensate and oil sheen samples: Whenever oil sheen is seen in pits or possum belly; Take 2 (TWO) samples. 1 Sample from the possum belly, skimming to increase oil content. 1 Sample from the suction pit — get the mud hand to help. Label these samples as in this example: 4400 in - 4400 out (use the lag depth current at the time.) Note: if significant quantities of oil are visible in the pits, a set of samples as above should be taken from Pit #7 (return pit) and from Pi t#1 (suction pit) as above. ZOI (Zones of Interest) • In ZOI, sample frequency is increased as specified, beginning 100' above the listed "Top" and continuing to 30' past the predicted base of the ZOI. Math already done use the intervals below. Schrader Bluff, 2 zones 3960 to 4260 and 4300 to 4500. Kuparuk 9100 to 9390 (Combine these zones = 9100 to 9560) Jurassic 9200 to 9560 Ivishak 11200 to 12000 CANRIG 38 • enl Nikaitchuq OP23 -WW02 4 PRESSURE / FORMATION STRENGTH DATA Connection gas peaks were rarely encountered and generally were not significantly large. The pore pressure gradient (PPG) is estimated to have varied from 9.6 in the TBA 15.5 in the Kuparuk. Problems with the well "breathing" ie: episodes of lost circulation and flow from the same intervals and at the same mud weights indicate down hole fracture /fault complications which make pore pressure evaluation difficult. 39 ANRIG • • • Ills eni Nikaitchuq OP23 -WW02 4.1 Pore Pressure Gradient Evaluation Primary Secondary Interval Tops Pore Pressure (EMW) Formation Trend Lithology Lithology MD TVDSS Min Max Interval Trend Indicators Primary( %) Secondary( %) (ft) (ft) (ppg) (ppg) Permafrost Sand /Cong 60% Sltst/Cylst 40% 8.7 9.25 Up BG,CG Clyst/Sltst/Sh Ugnu Sand /Cong 60% 2039' - 1964.5' 9.2 9.35 Flat BG,CG,TG 40% Schrader Bluff Sand 60% Sltst 40% 3717' - 3300.4' 9.2 9.6 Up BG,CG Sst/Sn 20% BG,CG,TG, Canning Clyst/Sltst 80% 4352' - 3570.8' 9.0 9.8 Up FIT Sh /Clyst/Sltst Sst/Sn 20% Torok 8120' - 5926.1' 9.8 9.8 Flat BG,CG,WG 80% HRZ Sh /Sltst 100% Sst/Sn TR 8838' - 6395.6' 9.8 9.8 Up BG,CG Sh /Sltst/Cyyst Sst TR Kalubik 8942' - 6463.3' 9.8 10.4 Up BG,CG,WG 100% Kuparuk Sh /Sltst 70% Sst/Sn 30% 9263' - 6668.7' 10.3 10.3 Flat BG,CG Jurassic Sh /Sltst 80% Sn /Sst 20% 9539' - 6853.6' 10.3 10.35 Up BG,CG Sag Sltst/Sh 65% Ss /Sst 35% 11229' - 8412.8' 10.4 10.4 Flat BG,CG Shublik Sltst 55% Sst/Ls /Sh 35% 11327' - 8510.3' 10.4 10.4 Up BG,CG Ivishak Sst/Sn 70% Sltst/Ls 30% 11556' - 8735.7' 10.3 10.4 Dn BG,CG,LC Sst/Sh 30% BG,CG,WG, Kavik Sltst 70% 12185' - 9359.8' 10.3 10.45 Flat TG 40 CANRIG • i • Nikaitchuq OP23 -WW02 NOTE: Clyst = Claystone /Clay, Sd = Sand, Cong = Conglomerate, Sltst = Siltstone, Sh = Shale, Sst = Sandstone, Ls = Limestone 4.2 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective circulating density (ECD), including increases in background gas (BG), appearance and trends of connection gas (CG), lost circulation (LC), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic data, provided by client, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Epoch, and then modified using the indicators described above, and DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD — (0.6- ((.001 *TLGSU) +(0.05 *DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping establish a PPG range, when establishing trends, as with DXC data, with data points in shale intervals. 41 CANRIG Vil Iiii eni Nikaitchuq OP23 -WW02 1 10 5 DRILLING DATA 5.1 Survey Data Measured True Latitude Departure Vertical Dogleg Incl. Azim. Depth (0) ( °) Vertical (ft) (ft) Section Rate (ft) Depth (ft) N( +), S( -) E( +), W( -) (ft) ( ° /100ft) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 242.51 0.50 39.43 242.51 0.82 0.67 0.87 0.21 276.39 0.20 284.85 276.39 0.95 0.71 1.00 1.80 307.59 0.13 4.20 307.59 1.00 0.66 1.05 0.70 337.57 0.03 287.61 337.57 1.03 0.65 1.09 0.42 368.38 0.34 215.42 368.38 0.96 0.59 1.01 1.08 401.57 0.35 29.89 401.57 0.97 0.59 1.02 2.08 430.06 0.36 270.28 430.06 1.04 0.54 1.09 2.15 459.28 0.13 77.59 459.28 1.05 0.48 1.09 1.67 • 491.87 0.05 47.61 491.87 1.07 0.53 1.11 0.28 523.84 0.17 97.43 523.84 1.07 0.58 1.12 0.45 612.99 0.03 107.94 612.99 1.05 0.74 1.11 0.16 704.70 0.49 106.47 704.69 0.93 1.14 1.02 0.50 804.60 0.72 123.00 804.59 0.47 2.07 0.65 0.29 867.33 0.22 65.24 867.32 0.30 2.51 0.52 1.01 902.92 0.49 27.12 902.91 0.47 2.64 0.69 0.97 967.22 0.97 23.12 967.20 1.21 2.98 1.47 0.75 1003.75 0.90 353.23 1003.73 1.78 3.07 2.04 1.33 1029.30 1.64 355.93 1029.27 2.34 3.02 2.60 2.90 1094.23 3.00 339.46 1094.15 4.86 2.36 5.05 2.31 1191.37 5.75 334.70 1190.99 11.64 -0.61 11.55 2.85 1285.68 8.81 337.49 1284.53 22.59 -5.40 22.03 3.27 1380.48 10.58 337.99 1377.97 37.37 -11.44 36.23 1.87 1478.01 10.39 337.92 1473.88 53.82 -18.10 52.03 0.20 • CAMIG 42 VA e n i Nikaitchuq OP23 -WW02 • Measured True Latitude Departure Vertical Dogleg Incl. Azim. Depth (0) Vertical (ft) (ft) Section Rate (ft) Depth (ft) N( +), S( -) E( +), W( -) (ft) 0100ft) 1571.46 9.20 337.84 1565.96 68.54 -24.09 66.18 1.27 1666.91 10.78 337.31 1659.96 83.85 -30.41 80.88 1.66 1762.08 10.72 339.72 1753.46 100.36 -36.91 96.76 0.48 1857.28 15.75 345.91 1846.11 121.21 -43.13 116.99 5.48 1952.83 19.48 346.63 1973.16 149.30 -49.97 144.38 3.91 2049.25 22.41 346.79 2027.20 182.84 -57.89 177.10 3.04 2145.23 24.45 350.86 2115.27 220.27 -65.23 213.75 2.71 2243.01 27.91 354.78 2203.01 263.06 -70.53 255.91 3.95 2337.89 32.30 357.46 2285.08 310.52 -73.67 302.92 4.84 2435.53 36.33 359.68 2365.71 365.53 -74.99 357.60 4.32 2529.00 38.74 0.87 2439.82 422.47 -74.70 414.35 2.69 2624.82 41.25 3.33 2513.23 483.99 -72.41 475.84 3.10 • 2719.99 44.91 3.52 2582.73 548.87 -68.52 540.81 3.85 2815.43 48.03 6.59 2648.46 617.77 -62.38 609.98 4.01 2911.11 50.67 7.06 2710.79 689.84 -53.75 682.53 2.78 3007.64 50.09 8.23 2772.35 763.53 -43.86 756.80 1.11 3103.34 49.73 6.16 2833.98 836.16 -34.69 829.96 1.70 3200.18 50.49 5.56 2896.08 910.07 -27.10 904.25 0.92 3293.79 50.04 5.97 2955.92 981.70 -19.87 976.23 0.59 3390.53 51.09 6.72 3017.37 1055.95 -11.61 1050.92 1.24 3486.68 50.33 7.77 3078.26 1129.77 -2.23 1125.28 1.16 3579.59 51.02 6.20 3137.14 1201.11 6.50 1197.10 1.50 3604.35 50.61 7.04 3152.78 1220.17 8.71 1216.29 3.11 3701.02 51.20 6.97 3213.74 1294.64 17.86 1291.27 0.61 3795.07 48.59 7.94 3274.33 1365.96 27.18 1363.13 2.89 3891.67 49.92 6.23 3337.38 1438.58 36.20 1436.26 1.92 3988.48 51.07 6.96 3398.96 1512.78 44.78 1510.93 1.32 4081.40 50.43 7.17 3457.75 1584.19 53.63 1582.83 0.71 Measured Incl. Azim. True Latitude Departure Vertical Dogleg • 43 CANR IG Wis �� • Nikaitchuq OP23 -WW02 • Depth ( °) ( °) Vertical (ft) (ft) Section Rate (ft) Depth (ft) N( +), S( -) E( +), W( -) (ft) ( ° /100ft) 4179.49 52.48 4.06 3518.88 1660.52 61.11 1659.53 3.24 4273.14 52.74 5.97 3575.75 1734.64 67.61 1733.93 1.64 4370.52 51.58 6.50 3635.49 1811.08 75.96 1810.81 1.27 4464.80 52.64 3.84 3693.40 1885.17 82.65 1885.20 2.49 4534.04 53.39 4.79 3735.05 1940.32 86.82 1940.51 1.54 4638.94 53.30 5.04 3797.68 2024.17 94.03 2024.66 0.21 4671.22 53.34 4.64 3816.96 2049.97 96.21 2050.55 1.00 4735.67 53.03 5.32 3855.58 2101.37 100.69 2102.15 0.97 4832.10 53.10 4.71 3913.53 2178.15 107.43 2179.22 0.51 4925.31 53.05 4.68 3969.53 2252.41 113.53 2253.74 0.06 5022.27 52.86 4.28 4027.94 2329.57 119.57 2331.12 0.38 5119.59 52.45 5.58 4086.98 2406.65 126.22 2408.49 1.14 5208.71 51.94 7.82 4141.61 2476.57 134.43 2478.87 2.0.7 5312.49 51.98 7.26 4205.56 2557.60 145.15 2560.52 0.43 5408.40 52.04 7.87 4264.59 2632.53 155.10 2636.03 0.51 5503.36 52.06 6.61 4322.99 2706.81 164.54 2710.85 1.05 5600.53 52.19 6.85 4382.65 2782.98 173.53 2787.52 0.24 5694.09 52.11 6.47 4440.06 2856.36 182.10 2861.36 0.33 5791.04 52.28 5.93 4499.49 2932.51 190.37 2937.95 0.47 5887.58 52.13 4.03 4558.65 3008.51 196.99 3014.23 1.56 5983.37 52.40 5.85 4617.28 3083.98 203.52 3089.98 1.53 6077.23 52.39 6.04 4674.56 3157.93 211.22 3164.33 0.16 6174.42 52.56 5.49 4733.76 3234.62 218.96 3241.40 0.48 6267.16 51.37 4.68 4790.90 3307.38 225.44 3314.44 1.46 6363.70 51.09 3.49 4851.35 3382.45 230.80 3389.70 1.00 6459.34 51.14 4.37 4911.39 3456.72 235.91 3464.13 0.72 6556.10 51.18 4.51 4972.07 3531.87 241.74 3539.49 0.12 6654.26 51.50 4.46 5033.39 3608.28 247.73 3616.14 0.33 6750.35 50.18 3.49 5094.07 3682.60 252.90 3690.63 1.58 Measured Incl. Azim. True Latitude Departure Vertical Dogleg Depth ( °) ( °) Vertical (ft) (ft) Section Rate • CANRIG 44 em Nikaitchuq OP23 -WW02 • (ft) Depth (ft) N( +), S( -) E( +), W( -) (ft) ( ° /100ft) 6845.23 49.84 3.04 5155.05 3755.18 257.05 3763.29 0.51 6942.66 49.72 2.95 5217.96 3829.47 260.93 3837.64 0.14 7036.01 49.90 2.47 5278.20 3900.70 264.30 3908.89 0.44 7132.39 49.83 2.12 5340.33 3974.33 267.25 3982.50 0.29 7227.47 49.79 2.99 5401.68 4046.89 270.49 4055.06 0.70 7324.45 49.39 4.65 5464.55 4120.56 275.41 4128.88 1.37 7417.80 49.12 4.98 5525.48 4191.04 281.34 4199.61 0.39 7512.71 49.64 4.59 5587.27 4262.82 287.35 4271.65 0.63 7610.74 49.65 4.59 5650.75 4337.29 293.33 4346.35 0.01 7705.59 49.90 5.40 5712.00 4409.43 299.64 4418.77 0.70 7801.40 49.55 5.32 5773.94 4482.21 306.47 4491.86 0.37 7898.59 49.73 5.15 5836.88 4555.96 313.22 4565.92 0.23 7994.57 49.97 6.04 5898.77 4628.97 320.38 4639.28 0.75 8088.34 50.08 6.70 5959.01 4700.39 328.35 4711.12 0.55 8184.35 50.17 6.17 6020.56 4773.60 336.61 4784.78 0.43 • 8282.83 50.35 6.49 6083.52 4848.87 344.96 4860.48 0.31 8378.29 48.92 5.05 6145.35 4921.23 352.28 4933.20 1.89 8474.14 48.47 5.22 6208.62 4992.94 358.72 5005.21 0.49 8564.51 48.54 4.82 6268.49 5060.37 364.64 5072.89 0.34 8665.89 48.78 5.33 6335.46 5136.19 371.38 5149.01 0.45 8762.39 48.75 4.91 6399.06 5208.47 377.85 5221.58 0.33 8857.33 49.16 4.83 6461.41 5279.81 383.93 5293.18 0.44 8953.58 49.14 4.83 6524.36 5352.36 390.06 5365.99 0.02 9033.38 49.14 4.54 6576.57 5412.51 394.99 5426.34 0.27 9142.94 51.88 2.99 6646.24 5496.87 400.52 5510.86 2.73 9238.50 50.41 3.33 6706.19 5571.17 404.62 5585.23 1.56 9331.13 49.36 3.08 6765.87 5641.90 408.58 5656.04 1.15 9429.57 47.35 2.36 6831.28 5715.37 412.08 5729.54 2.11 9525.42 45.19 2.46 6897.53 5784.57 414.99 5798.72 2.25 Measured Incl. Azim. True Latitude Departure Vertical Dogleg Depth ( °) ( °) Vertical (ft) (ft) Section Rate 0 CAMIG 45 r" eni Nikaitchuq OP23 -WW02 • (ft) Depth (ft) N( +), S(-) E( +), W( -) (ft) ( ° /100ft) 9621.18 42.88 3.14 6966.37 5851.04 418.23 5865.23 2.46 9716.85 39.25 6.43 7038.50 5913.65 423.41 5928.05 4.41 9813.02 34.87 9.61 7115.23 5971.02 431.41 5985.90 4.97 9909.97 31.17 7.59 7196.51 6023.23 439.35 6038.61 3.98 10005.56 27.73 6.65 7279.74 6069.86 445.20 6085.56 3.63 10101.40 23.51 7.87 7366.14 6110.96 450.40 6126.96 4.44 10198.60 19.07 6.97 7456.68 6145.94 454.98 6162.21 4.58 10293.77 14.51 8.90 7547.77 6173.17 458.72 6189.66 4.83 10388.70 12.28 9.50 7640.11 6194.88 462.22 6211.59 2.35 10485.83 11.91 10.12 7735.09 6214.93 465.69 6231.87 0.40 10579.02 11.39 10.36 7826.36 6233.45 469.03 6250.61 0.56 10674.81 10.80 11.11 7920.36 6251.56 472.46 6268.95 0.63 10771.89 10.67 11.54 8015.74 6269.29 476.02 6286.92 0.16 10866.97 10.51 12.04 8109.20 6286.40 479.59 6304.28 0.19 10964.46 10.01 12.62 8205.13 6303.36 483.29 6321.50 0.52 • 11060.34 9.09 13.39 8299.68 6318.86 486.87 6337.25 0.97 11154.80 8.34 15.15 8393.05 6332.73 490.38 6351.38 0.84 11248.58 7.89 12.44 8485.89 6345.58 493.55 6364.45 0.63 11345.26 9.04 3.76 8581.52 6359.64 495.48 6378.63 1.77 11441.16 8.60 2.93 8676.28 6374.32 496.34 6393.33 0.48 11537.68 8.18 2.64 8771.77 6388.39 497.02 6407.40 0.44 11636.52 8.10 2.54 8869.61 6402.37 497.65 6421.38 0.08 11730.24 7.95 2.82 8962.42 6415.44 498.27 6434.45 0.17 11824.78 7.83 2.99 9056.06 6428.40 498.92 6447.42 0.13 11919.03 7.83 2.89 9149.43 6441.22 499.58 6460.25 0.01 III W-u vRIC] 46 P n i Nikaitchuq OP23 -WW02 e • Measured True Latitude Departure Vertical Dogleg Incl. Azim. Depth (0) ( °) Vertical (ft) (ft) Section Rate (ft) Depth (ft) N( +), S( -) E( +), W( -) (ft) ( ° /100ft) 12015.86 7.72 2.64 9245.37 6454.31 500.21 6473.34 0.12 12113.75 7.62 2.85 9342.39 6467.36 500.84 6486.40 0.11 12209.18 7.54 2.24 9436.98 6479.93 501.40 6498.98 0.12 12254.55 7.07 1.79 9481.98 6485.70 501.60 6504.74 1.04 • • CANRIG 47 • • I TA eni Nikaitchuq OP23 -WWO2 5.2 Bit Record Avg. Jets / Depth In Total Ft Bit WOB RPM PP Bit Size Make Type / S# ROP Wear BHA TFA MD / Drilled Hrs (Klbs) (avg) (psi) (ft/hr) 3x20, 1 16 HC MX -1 #6075099 160 125 2.0 100.9 13.4 63 2032 0 -0 1 1x16 3x20, 1RR 16 HC MX -1 #6075099 285 3381 46.8 100.9 13.4 63 2032 2- 1- WT- A- E- 4 -RG -TQ 2 1x16 3x20, 2 16 HC MX -1 #6074140 3666 941 20.1 129 14.1 56 2151 1- 1- WT- A- E- 1 -NO -TD 3 1x16 MSX619S -A2D 3 12.25 Hycalog 6x14 4607 28 0.7 40 11.1 55 1770 0- 3- BT- S- X- 2- CT -DTF 4 #220296 MSX619S -A2D 4 12.25 Hycalog 6x14 4635 4485 46.0 97.5 15.0 77 3300 1- 3- BT- A- X- 1 -BU -TD 5 #225024 DTX519M 5 8.5 Hycalog 6x13 9120 3203 45.58 70.3 10.0 90 3000 0- 1- WT- S- X- 1 -NO -TD 6 #126427 7 48 CANRIG 1 1 • • • ph en, Nikaitchuq OP23 -WW02 5.3 Mud Record Contractor: MI SWACO Mud Type: SPUD MUD 160' TO 4625', LSND 4625' TO 9120'. OBM Versa Clean 9120' TO 12323' MW VIS FL Sols O/W Sd CI Ca Date Depth PV YP Gels FC MBT pH (ppg) (s /qt) (cc) ( %) Ratio ( %) (m1/1) (mI /I) 4/04/2010 NO MUD 4/05/2010 135 8.7 77 4/06/2010 795 9.0 188 12 65 46/47/49 13.5 5 0.75 17.5 9.3 1700 40 4/07/2010 1998 9.2 72 15 24 24/32/37 9.5 4 6 1/94 0.75 18 8.6 1400 60 4/08/2010 2961 9.4 85 27 27 17/40/50 6 3 6 1/94 0.2 220 8.3 1000 50 4/09/2010 3666 9.6 95 27 27 12/41/50 6 3 0.1 22.5 8.0 900 60 4/10/2010 3666 9.7 110 39 34 18/43/55 5.5 3 8 1/91 0.5 22.5 8.0 1200 70 4/11/2010 4345 9.3 109 16 28 21/46/49 6 2 8 2/91 0.1 20 8.4 1300 40 4/12/2010 4607 9.5 81 23 22 14/38/43 7.5 3 8.5 1/91 0.1 21 8.0 1200 40 4/13/2010 4607 9.3 60 17 14 16/24/31 7 4 8 1/91 18.5 8.0 1000 60 4/14/2010 4607 9.6 55 18 15 4/15/2010 4607 9.6 55 18 15 4/16/2010 4607 9.0 42 6 17 8/9/10 11.5 <1/ 9.4 200 30 4/17/2010 4607 9.0 42 6 17 8/9/10 11.5 <1/ 9.4 200 30 4/18/2010 4896 9.1 41 8 16 7/10/12 6.5 <1/ 6 1/94 3 10.0 500 60 4/19/2010 5970 9.5 51 14 24 12/19/27 6 <1/ 8 1/92 12.5 9.7 700 30 49 CANRIG • 0 S lia era Nikaitchuq OP23 -WW02 MW VIS FL Sols O/W Sd CI Ca Date Depth PV YP Gels FC MBT pH (ppg) (s /qt) (cc) ( %) Ratio ( %) (m1/1) (m1 /1) 4/20/2010 8212 9.8 71 21 21 9/32/40 4.5 1/ 10 1/89 12.5 9.7 1200 40 4/21/2010 9120 9.9 74 20 22 9/32/40 4.5 1/3 11 3/87 20 9.4 1000 40 4/22/2010 9120 9.8 48 16 16 6/10/22 4.8 1/ 9.5 2/89 20 9.4 1200 40 4/23/2010 9120 9.9 78 16 15 10/15/30 4.5 1/ 10 2/88 20 9.4 1000 40 Salt Lime Invert 9120 Oil H2O Alk % lb/bbl 4/24/2010 9120 10.4 60 23 11 6/15/18 68 16 13.93 81/19 32.4 2.6 49000 2 4/25/2010 9120 10.4 60 23 11 6/14/19 68 16 16 81/19 32.4 2.6 49000 2 4/26/2010 9636 10.3 68 23 18 14/25/30 65 19 14 77/23 28.75 2.73 49000 2.1 4/27/2010 11300 10.4 62 24 16 15/23/34 67 16.5 16.5 80/20 33.87 2.73 54000 2.1 4/28/2010 12042 10.5 62 27 9 6/20/26 67 17 16 80/20 0.25 27.88 2.99 42000 2.3 4/29/2010 12323 10.4 57 23 6 5/15/19 66 17 14.73 79/21 0.25 26.42 2.6 39000 2 4/30/2010 12323 10.1 55 22 5 5/16/19 66 20 12.49 79/21 0.25 25.32 2.6 39000 2 5/01/2010 12323 10.4 53 15 6 6/12/ 66 19 14.7 78/22 0.25 24.78 .46 40000 .35 5/02/2010 12323 10.4 53 16 6 6/12/16 66 19 13.43 78/22 0.25 24.78 1.3 40000 1 5/03/2010 12323 10.3 68 22 14 15/22/24 60 24 11.36 71/29 0.25 28.12 2.86 60000 2.2 5/04/2010 12323 10.3 70 28 12 7/19/23 62 22 13.62 74/26 n/a 29.21 3.25 58000 2.5 5/05/2010 12323 10.3 80 27 13 7/15/20 63 21 13 75/25 n/a 29.44 2.86 56000 2.2 5/06/2010 12323 10.4 100 31 11 6/17/21 62 26 10.35 74/26 n/a 26.24 3.12 50000 2.4 50 CANRIG • • las eni Nikaitchuq OP23 -WW02 Abbreviations MW = Mud Weight Gels = Gel Strength Sd = Sand content ECD = Effective Circulating Density WL = Water or Filtrate Loss CI = Chlorides VIS = Funnel Viscosity FC = Filter Cake Ca = Hardness Calcium PV = Plastic Viscosity Sols = Solids O/W = Oil to Water ratio YP = Yield Point 51 CANRIG Daily Report Page 1 of 1 ENI Petroleum • Nikaitchuk DAILY WELLSITE REPORT Ei EPOCH OP23 -WW02 REPORT FOR Bobby Wells, Scott Beauchamp DATE April 2nd 2010, Report Period April 01,2010 DEPTH 0 PRESENT OPERATION Rigging Up TIME 00:00 YESTERDAY 0 24 HOUR FOOTAGE 0 CASING INFORMATION DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA NA NA NA NA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA NA NA NA NA NA NA NA NA NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA © NA NA @ NA NA NA FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH MW NA VIS NA PV NA YP NA FL NA Gels NA CL- NA FC SOL SD OIL MBL pH Ca+ CCI • MWD SUMMARY INTERVAL NA TO NA TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA © NA NA @ NA NA TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) NA © NA NA © NA NA CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Finished assembling Gas Trap and other components. Set up Gas Trap in Possum Belly. EPOCH PERSONNEL ON Dan Grunwald, Sameer Baral, John Lundy, DAILY 2250.00 BOARD Dean Kekaualua COST REPORT BY Sameer Baral • file: / /C: \Documents and Settings\EpochAdmin \My Documents \My Wells\ENI\20100402.htm 4/2/2010 Daily Report Page 1 of 1 • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT n EPOCH OP23 -WW02 REPORT FOR Jack Keener, Bobby Walls DATE Apr 03, 2010; report period Apr 02, 2010 DEPTH 0 PRESENT OPERATION Rigging up TIME 00:00 YESTERDAY 0 24 HOUR FOOTAGE 0 CASING INFORMATION NA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA NA NA NA NA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA NA NA NA NA NA NA NA NA NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA © NA @ NA NA KLBS ROTARY RPM NA © NA © NA NA RPM PUMP PRESSURE NA © NA © NA NA PSI DRILLING MUD REPORT DEPTH NA MW NA VIS NA PV NA YP NA FL NA Gels NA CL- NA FC NA SOL NA SD NA OIL NA MBL NA pH NA Ca+ NA CCI NA all MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA © NA © NA TRIP GAS NA CUTTING GAS NA © NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA © NA © NA CONNECTION GAS HIGH NA ETHANE (C -2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C -4) NA @ NA © NA CURRENT BACKGROUND /AVG NA PENTANE (C -5) NA © NA © NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Continued rig up: troubleshoot RigWatch, mount pill pit mud level sensor; mount secondary gas trap EPOCH PERSONNEL ON S. Baral, D. Grunwald, D. Kekaualua, J. DAILY $3500 BOARD Lundy COST (est.) REPORT BY D. Grunwald • file: / /C: \Documents and Settings\EpochAdmin \My Documents \My Wells\ENI\20100403.htm 4/3/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH NikaRChuq DAILY WELLSITE REPORT OP23 -W W 02 REPORT FOR Jack Keener, Scott Beauchamp DATE Apr 04, 2010 DEPTH 0 PRESENT OPERATION Rigging up TIME 00:00 YESTERDAY 0 24 HOUR FOOTAGE 0 CASING INFORMATION NA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA NA NA NA NA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA NA NA NA NA NA NA NA NA NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH NA MW NA VIS NA PV NA YP NA FL NA Gels NA CL- NA FC NA SOL NA SD NA OIL NA MBL NA pH NA Ca+ NA CCI NA MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA ID ETHANE (C-2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C -4) NA @ NA @ NA CURRENT BACKGROUND /AVG NA PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Continued rig up; hoist replacement hydrogen cylinders to unit atop rig and lower empty cylinders; calibrate gas equipment; troubleshoot RigWatch. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3030; RigWatch $2650 REPORT BY D. Grunwald 411 file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells\EN1\20100404.htm 4/4/2010 Daily Report Page 1 of 1 Petroleum 0 ENI Pum EPOCH Ni etroV q DAILY WELLSITE REPORT OP23 -W W 02 REPORT FOR G. Gorlic, Jack Keener DATE Apr 05, 2010 DEPTH 0 PRESENT OPERATION Rig repairs TIME 00:00 YESTERDAY 0 24 HOUR FOOTAGE 0 CASING INFORMATION NA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA NA NA NA NA BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA NA NA NA NA NA NA NA NA NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH NA MW NA VIS NA PV NA YP NA FL NA Gels NA CL- NA FC NA SOL NA SD NA OIL NA MBL NA pH NA Ca+ NA CCI NA MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA • ETHANE (C -2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C -4) NA @ NA @ NA CURRENT BACKGROUND /AVG NA PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Continued rig up - test gas trap, troubleshoot RigWatch issues; rig repairs - repair knife valve EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3030; RigWatch - $2650 REPORT BY D. Grunwald • ■ file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\20100405.htm 4/5/2010 Daily Report Page 1 of 1 II ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT El OP23 -W W02 REPORT FOR Jack Keener, Gary Goerlich, Andrew Buchanan DATE Apr 06, 2010 DEPTH 160 PRESENT OPERATION Spudding in TIME 00:00 YESTERDAY 0 24 HOUR FOOTAGE NA CASING INFORMATION 20" @ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA NA NA NA NA BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 16" Hughes Christensen 6075099 3x20, 1x16 0 NA NA 0.2 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 160.00000 0 @ 160.00000 0.0 FT /HR SURFACE TORQUE 0 @ 160.00000 0 @ 160.00000 00 AMPS WEIGHT ON BIT 0 @ 160.00000 0 @ 160.00000 0.0 KLBS ROTARY RPM 0 @ 160.00000 0 @ 160.00000 0.0 RPM PUMP PRESSURE 0 @ 160.00000 0 @ 16000000 0.0 PSI DRILLING MUD REPORT DEPTH 135 MW 8.7 VIS 77 PV n.r YP n r. FL n.r. Gels n.r. CL- n.r. FC n.r. SOL n.r. SD n.r. OIL n.r MBL n.r. pH n.r Ca+ n.r CCI n.r. MWD SUMMARY INTERVAL 0 TO 160 TOOLS (no tools in drill string) GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 160.00000 0 @ 160.00000 0.0 TRIP GAS NA CUTTING GAS 0 @ 160.00000 0 @ 160.00000 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) 0 @ 160.00000 0 @ 160.00000 0.0 CONNECTION GAS HIGH 0 • ETHANE (C -2) 0 @ 160.00000 0 @ 160.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 160.00000 0 @ 160.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 160.00000 0 @ 160.00000 0.0 CURRENT BACKGROUND /AVG 0 PENTANE (C -5) 0 @ 160 00000 0 @ 160.00000 0.0 HYDROCARBON SHOWS (none) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY (conductor slough - sand and clay) PRESENT LITHOLOGY sand DAILY ACTIVITY Continued replacement and repair of stack valve; work performed on diverter line; pressure test lines and pumps; wash out conductor; begin drilling ahead at report time; additional SUMMARY mudlogging activity - isolate RigWatch computers, update antivirus software and purge malicious software. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3030; RigWatch - $2650 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/6/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH Nikaitchuq chuq DAILY WELLSITE REPORT H OP23 -W W 02 REPORT FOR Jack Keener, Gary Goerlich, Andrew Buchanan DATE Apr 07, 2010 DEPTH 972.00000 PRESENT OPERATION Drilling Ahead TIME 00:00:00 YESTERDAY 160.00000 24 HOUR FOOTAGE 812 CASING INFORMATION 20" @ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 867.33 0.5 n.r 867.3 BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B/C PULLED 1 16" Hughes Christensen 6075099 3x20, 1016 0 NA 767 9.9 NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 543.2 @ 533.00000 6.0 @ 889.00000 115.3 135.82855 FT /HR SURFACE TORQUE 5351 @ 937.00000 8 @ 945.00000 14091 1865.99817 AMPS WEIGHT ON BIT 29 @ 937.00000 0 @ 726.00000 7.7 16.04344 KLBS ROTARY RPM 37 @ 595.00000 0 @ 957.00000 30.6 33 48698 RPM PUMP PRESSURE 1497 @ 937.00000 9 @ 279 00000 673.7 1208.70459 PSI DRILLING MUD REPORT DEPTH 795 MW 9.0 VIS 188 PV 12 YP 65 FL 13.5 Gels 46/47/49 CL- 1700 FC 5/ SOL - SD 0/75 OIL - MBL 17.5 pH 9.3 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 967.00000 0 @ 961.00000 0.1 TRIP GAS 0 CUTTING GAS 0 @ 972.00000 0 @ 972.00000 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 0 @ 972.00000 0 @ 972.00000 0.0 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ 972.00000 0 @ 972.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 972.00000 0 @ 972.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 972.00000 0 @ 972.00000 0.0 CURRENT BACKGROUND /AVG 0 PENTANE (C -5) 0 @ 972.00000 0 @ 972 00000 0.0 HYDROCARBON SHOWS (none) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 60% sand, 20% sdtstone, 20% clay /claystone PRESENT LITHOLOGY 70% sand, 30% claystone DAILY ACTIVITY SUMMARY Spud in with dumb iron and drill 257' of rathole to accomodate LWD tooling; POOH and P/U BHA #2 with full toolstring, RIH and drill ahead to 927'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3080; RigWatch $2650 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN \MY DOCUMENTS\MY WEL... 4/7/2010 Daily Report Page 1 of 1 • ENI Petroleum El EPOCH Nikaitchuq DAILY WELLSITE REPORT OP23 -W W 02 REPORT FOR Jack Keener, Gary Goencch, Andrew Buchanan DATE Apr 08, 2010 DEPTH 2115 00000 PRESENT OPERATION Drilling ahead TIME 00:00:00 YESTERDAY 972.00000 24 HOUR FOOTAGE 1143 CASING INFORMATION 20"0 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 1952.83 19.44 346.95 1937.11 BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 16" Hughes Christensen 6075099 3x20, 1x16 160 NA 1955 22.5 NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 610.6 @ 1349.00000 6.2 @ 2026.00000 152.5 50.60160 FT /HR SURFACE TORQUE 9807 @ 1307.00000 0 @ 1955.00000 850.8 0.00000 AMPS WEIGHT ON BIT 44 @ 1585 00000 0 @ 1755.00000 16 0 29.96000 KLBS ROTARY RPM 41 0 1385.00000 0 @ 1221.00000 10.7 0 52707 RPM PUMP PRESSURE 1580 0 1978.00000 172 @ 1276.00000 1204.7 1278.83130 PSI DRILLING MUD REPORT DEPTH 1998 MW 92 VIS 72 PV 15 YP 24 FL 9.5 Gels 24/32/37 CL- 1400 FC 4/ SOL 6 SD 0.75 OIL 1/94 MBL 18 pH 8.6 Ca+ 60 CCI - MWD SUMMARY INTERVAL 160 TO 2115 TOOLS Gamma, Resistivity, Neutron Density, Sonic Velocity GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 373 @ 1737.00000 0 @ 1051.00000 51 3 TRIP GAS NA CUTTING GAS 0 @ 2115.00000 0 @ 2115.00000 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 70947 @ 1729.00000 42 @ 2115.00000 11117.0 CONNECTION GAS HIGH 0 IP ETHANE (C-2) 0 @ 2115.00000 0 @ 2115.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 211500000 0 @ 2115.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 2115.00000 0 @ 2115.00000 0 0 CURRENT BACKGROUND /AVG 20 PENTANE (C -5) 0 @ 2115.00000 0 @ 2115.00000 0.0 HYDROCARBON SHOWS (none) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 50% claystone, 30% loose sand, 10% conglomeratic sand /conglomerate, 5% siltstone, moor coal and carbonaceous shale PRESENT LITHOLOGY 70% loose sand, 30% claystone DAILY ACTIVITY SUMMARY Drill ahead from 972 to 2115' MD; extraneous mudlogging activity - recalibrate gas detection equipment and block height. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3080; RigWatch - $2650 REPORT BY D. Grunwald 1 10 file: / /C:\Documents and Settings'EpochAdmin\lVly Documents\My Wells\ENIPMoming Rep... 4/8/2010 Daily Report Page 1 of 1 • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT EPOCH OP23 -W W 02 REPORT FOR Jack Keener, Gary Goerlich, Andrew Buchanan DATE Apr 09, 2010 DEPTH 3078.00000 PRESENT OPERATION Drilling ahead TIME 00:00:00 YESTERDAY 2115.00000 24 HOUR FOOTAGE 963 CASING INFORMATION 20" @ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3007.64 50.09 8 81 2772.11 BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 16" Hughes Christensen 6075099 3x20, 1x16 160 NA 2918 37.6 NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 441.4 @ 2415.00000 7.0 @ 2871.00000 123.5 129 10629 FT /HR SURFACE TORQUE 17423 @ 2700.00000 0 @ 2514.00000 28722 3534.26831 AMPS WEIGHT ON BIT 56 @ 2653.00000 0 @ 2957.00000 16 1 8.53493 KLBS ROTARY RPM 53 @ 2657 00000 0 @ 2769 00000 21.5 34.37451 RPM PUMP PRESSURE 2078 @ 2858.00000 1276 @ 2116.00000 1703 7 1729.52344 PSI DRILLING MUD REPORT DEPTH 2961 MW 9.4 VIS 85 PV 27 YP 27 FL 6 Gels 17/40/50 CL- 1000 FC 3/ SOL 6 SD 02 OIL 1/94 MBL 22 pH 8.3 Ca+ 50 CCI - MWD SUMMARY INTERVAL 160 TO 3078 TOOLS Gamma, Resistivity, Neutron Density, Sonic Velocity GAS SUMMARY (unds) HIGH LOW AVERAGE DITCH GAS 58 @ 2583.00000 0 @ 2806.00000 18.2 TRIP GAS NA CUTTING GAS 0 @ 3078 00000 0 @ 3078.00000 0 0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 • METHANE (C -1) 18004 @ 2209.00000 40 @ 2609.00000 3973 7 CONNECTION GAS HIGH 0 ETHANE (C -2) 0 @ 3078.00000 0 @ 3078.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 3078.00000 0 @ 3078.00000 0.0 CURRENT 0 BUTANE (C -4) 0 @ 3078.00000 0 @ 3078.00000 0.0 CURRENT BACKGROUND /AVG 20 PENTANE (C -5) 0 @ 3078.00000 0 @ 3078.00000 0.0 HYDROCARBON SHOWS (none) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 70% sand /sandstone, 25% claystone, minor siltstone, conglomerate /conglomeratic sand, and carbonaceous shale, PRESENT LITHOLOGY 70% sand /sandstone, 20% siltstone, 10% claystone DAILY ACTIVITY SUMMARY Drill ahead from 2115 ft. to 3078 ft. MD. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $2980; RigWatch - 2620 REPORT BY D. Grunwald S file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/9/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT HI OP23 -W W02 REPORT FOR Jack Keener /Dave Morris /Andrew Buchanan DATE Apr 10, 2010 DEPTH 3665.00000 PRESENT OPERATION Laying down BHA TIME 183422 YESTERDAY 3078.00000 24 HOUR FOOTAGE 587 CASING INFORMATION 20" @ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3579.59 51.02 620 3137.14 BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 1 16" HTC MX -1 Milltooth Bit 6075099 3x20, 1x16 160 3666 3506 48.0 NA BIT DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 278.8 @ 3242.00000 1.5 @ 3662.00000 1123 4.80190 FT /HR SURFACE TORQUE 18021 @ 3655.00000 0 @ 3193 00000 4951.8 5853.68018 AMPS WEIGHT ON BIT 51 @ 3560.00000 0 @ 3151.00000 16.1 30.14645 KLBS ROTARY RPM 51 @ 3532.00000 0 @ 3575.00000 36.8 37.98870 RPM PUMP PRESSURE 2436 @ 3473.00000 1625 66 3086.00000 1979.2 2382.19971 PSI DRILLING MUD REPORT DEPTH 3666 MW 96 VIS 95 PV 27 YP 27 FL 6 Gels 12/41/50 CL- 900 FC 3/ SOL - SD 0.1 OIL - MBL 22.5 pH 6.0 Ca+ 60 CCI - MWD SUMMARY INTERVAL 160 TO 3666 TOOLS Gamma, Resistivity, Neutron Density, Sonic Veolcity GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 73 @ 3152.00000 0 @ 3437.00000 202 TRIP GAS NA CUTTING GAS 0 @ 3665.00000 0 @ 3665.00000 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 13537 @ 3152.00000 44 @ 3437.00000 4018.0 CONNECTION GAS HIGH 0 • ETHANE (C-2) 0 @ 3665.00000 0 @ 3665.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 3665.00000 0 @ 3665.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3665.00000 0 @ 3665 00000 0.0 CURRENT BACKGROUND /AVG 5 PENTANE (C -5) 0 @ 3665 00000 0 @ 3665.00000 0 0 HYDROCARBON wea show, 3640' - ?' SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 3600' - ?' sandstone/sand 5u Trace medium brown stain, no odor, 30% - 40% dull gold fluorescence, clear cut, slow white to yellow cut fluorescence, pale yellow residual cut and pale yellow residual cut fluorescence. LITHOLOGY 50% sand /sandstone, 30% claystone, 20% sdlslone, trace conglomerate PRESENT LITHOLOGY 100% sand /sandstone DAILY ACTIVITY SUMMARY Drill ahead to 3666 ft. MD; pump 20 bbl slug to clean bit; POOH for bit inspection; L/D BHA. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $2980; RigWatch - $2620 REPORT BY D. Grunwald 40 file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/10/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH DAILY WELLSITE REPORT Ell 0P23 -W W 02 REPORT FOR Jack Keener /Dave Morns /Andrew Buchanan DATE Apr 11, 2010 DEPTH 3684.00000 PRESENT OPERATION Drilling ahead TIME 00:00.00 YESTERDAY 3666.00000 24 HOUR FOOTAGE 18 CASING INFORMATION 20" @ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 3604.35 50.67 7.24 3152 83 BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 16" HTC MX -1 Milltooth Bit 6074140 3x20, 1x16 3666 NA 18 1.0 NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 307.7 @ 3667.00000 6.1 @ 3669 00000 105.8 88.29589 FT /HR SURFACE TORQUE 8138 @ 3671.00000 5867 @ 3666 00000 3013.9 0.00000 AMPS WEIGHT ON BIT 28 0 3683 00000 0 0 3675.00000 11.7 2241173 KLBS ROTARY RPM 61 0 3669.00000 0 0 3682.00000 24.6 0.44663 RPM PUMP PRESSURE 2382 0 3683.00000 2111 0 3668.00000 2386.6 2340.47046 PSI DRILLING MUD REPORT DEPTH 3500 MW 9.7 VIS 110 PV 39 YP 34 FL 5.5 Gels 18/43/55 CL- 1200 FC 3/ SOL 8 SD 0.5 OIL 1/91 MBL 22.5 pH 8.0 Ca+ 70 CCI - MWD SUMMARY INTERVAL 160 TO 3684 TOOLS Gamma, Resistivity, Neutron Density, Sonic Velocity GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 14 @ 3684.00000 4 @ 3678 00000 6 7 TRIP GAS 13 CUTTING GAS 0 @ 3684.00000 0 @ 3684.00000 0.0 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 2976 @ 3684.00000 1091 @ 3678.00000 1499 2 CONNECTION GAS HIGH 0 • ETHANE (C -2) 0 @ 3684.00000 0 @ 3684.00000 0.0 AVG 0 PROPANE (C -3) 0 @ 3684.00000 0 @ 3684.00000 0.0 CURRENT 0 BUTANE (C-4) 0 @ 3684.00000 0 @ 3684.00000 0.0 CURRENT BACKGROUND /AVG 5 PENTANE (C -5) 0 @ 3684.00000 0 @ 3684.00000 0 0 HYDROCARBON weak show (continued) 3600 -'+ SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION 3600 sandstone /sand 15u Trace medium brown stain, no door, 30% - 40% dull yellow fluorescence, clear to weak pale yellow cut, slow bright white to yellow cut fluorescence, pale yellow residual cut and pale yellow residual cut fluorescence. LITHOLOGY 90% sand /sandstone, 10% claystone PRESENT LITHOLOGY 90% sand /sandstone, 10% claystone DAILY ACTIVITY L/D BHA #2; P/U BHA #3 with new bit and mud motor; clear blockages in line from shakers to cuttings tank; RIH, stopping to circulate BA1 every 1000'; wash hole from 3350' to 3666' and SUMMARY drill ahead; miscellaneous mudlogging activity - calibrate gas detection equipment. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $2980; RigWatch - $2620 REPORT BY D. Grunwald S file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY WEL... 4/11/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH Ni Petroleum DAILY WELLSITE REPORT OP23 -W W 02 REPORT FOR Jack Keener /Dave Morris/ Andrew Buchanan DATE Apr 12, 2010 DEPTH 4440.00000 PRESENT OPERATION Drilling ahead TIME 00:00:00 YESTERDAY 3684.00000 24 HOUR FOOTAGE 756 CASING INFORMATION 20" @ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4370.52 51.64 6.57 3635.49 BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB /C PULLED 2 16" HTC MX -1 Milltooth Bit 6074140 3x20, 1x16 3666 NA 774 17.1 NA NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 285.8 @ 3728.00000 2.4 @ 4156.00000 104.2 52.59774 FT /HR SURFACE TORQUE 13455 @ 3870 00000 11 @ 4175.00000 6096.7 8260 25098 AMPS WEIGHT ON BIT 40 @ 4306.00000 0 @ 4047.00000 11.4 8.13414 KLBS ROTARY RPM 70 @ 3861.00000 0 @ 3692.00000 45.9 58.59274 RPM PUMP PRESSURE 2410 @ 3847 00000 1778 @ 4166.00000 2017.9 2033.64868 PSI DRILLING MUD REPORT DEPTH 4345 MW 9.3 VIS 109 PV 16 YP 28 FL 6 Gels 21/46/49 CL- 1300 FC 2/ SOL 8 SD 0.1 OIL 2/91 MBL 20 pH 8.4 Ca+ 40 CCI - MWD SUMMARY INTERVAL 160 TO 4440 TOOLS Gamma, Resistivity, Neutron Density, Sonic Velocity GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 653 @ 4309.00000 0 @ 3877.00000 96.9 TRIP GAS NA CUTTING GAS 0 @ 4440.00000 0 @ 4440 00000 00 WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 90981 @ 4037.00000 67 @ 4440.00000 12944.7 CONNECTION GAS HIGH 185 el ETHANE (C-2) 899 @ 4429 00000 0 @ 3919.00000 138 8 AVG 23 PROPANE (C -3) 953 @ 4312.00000 0 @ 4245.00000 716 2 CURRENT 0 BUTANE (C-4) 1680 @ 4314.00000 0 @ 3895.00000 207.4 CURRENT BACKGROUND /AVG 100 PENTANE (C -5) 1263 @ 4344.00000 0 @ 4246.00000 116.7 HYDROCARBON SHOWS (1) trace show (cen't.) 3600' - 3700', (2) fair show 4010' - 4095'; (3) fair show 4305 - 4410' INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION (1) 3600' - 3700'; (2) 4010' - (1) sandstone /sand; (2) (7) 86, (2) (1) Trace medium brown stain, no odor, 30% - 40% dull yellow fluorescence, clear to weak pale yellow cut; (2) slight to moderate 4095', (3) 4305' - 4410' sandstone /sand; (3) sandstone/sand 108; (3) odor, 80% to 100% medium yellow sample fluorescence, fast streaming cut to yellow white; (3) trace light brown stain, rare tarry 300 bits, scattered dull yellow fluorescence, slow dark straw cut fluoresces moderate yellow. LITHOLOGY 60% sand /sandstone, 25% siltstone, 10% claystone, 5% congbmeratic sand, trace carbonaceous shale PRESENT LITHOLOGY 60% sand/sandstone, 40% siltstone DAILY ACTIVITY SUMMARY Drill ahead from 3684 ft MD to 4440 It MD; slow drilling at 3865' MD - pump Nut Plug sweeps with little variation in ROP EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $4225; RigWatch $2650 REPORT BY D. Grunwald • file: / /C:\Documents and Settings\EpochAdmin\My Documents\My Wells\ENI\Morning Re... 4/14/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT OP23 -W W02 REPORT FOR Jack Keener /Dave Morris /Andrew Buchanan DATE Apr13, 2010 DEPTH 4607.00000 PRESENT OPERATION L/D BHA #2 TIME 00'00:00 YESTERDAY 4440.00000 24 HOUR FOOTAGE 167 CASING INFORMATION 20" @ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4534.04 53.39 4.79 3735.09 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 16 HTC MX -1 Milltooth Bit 6074140 3x20, 1516 3666 4607 941 20.1 n.r. TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 207.1 @ 4538.00000 16.7 @ 4441.00000 86.0 45.55117 FT /HR SURFACE TORQUE 12127 @ 4550 00000 11 @ 4484.00000 5467 6 7961 21582 AMPS WEIGHT ON BIT 42 @ 4488.00000 6 @ 4513.00000 22.6 23.46420 KLBS ROTARY RPM 62 @ 4548.00000 0 @ 4477.00000 40.4 56.36506 RPM PUMP PRESSURE 2219 @ 4557.00000 1900 @ 4441 00000 20817 2145 45654 PSI DRILLING MUD REPORT DEPTH 4607 MW 9.5 VIS 81 PV 23 YP 22 FL 7.5 Gels 14/38/43 CL- 1200 FC 3/ SOL 8.5 SD 0.1 OIL 1/91 MBL 21 pH 80 Ca. 40 CCI - MWD SUMMARY INTERVAL 160 TO 4607 TOOLS Gamma, Resistivity, Neutron Density, Sonic Velocity GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 279 @ 4526.00000 6 @ 4495.00000 114.6 TRIP GAS NA CUTTING GAS 0 @ 4607 00000 0 @ 4607.00000 0.0 WIPER GAS 256 CHROMATOGRAPHY (ppm) SURVEY 0 METHANE (C -1) 28402 @ 4523.00000 67 @ 4606 00000 3127.3 CONNECTION GAS HIGH 0 • ETHANE (C-2) 648 @ 4446.00000 0 @ 4512.00000 82 3 AVG 0 PROPANE (C-3) 546 @ 4446.00000 0 @ 4512.00000 71.5 CURRENT 0 BUTANE (C-4) 808 @ 4461.00000 3 @ 4495.00000 111.5 CURRENT BACKGROUND /AVG 150 PENTANE (C -5) 842 @ 4523.00000 0 @ 4512.00000 98.7 HYDROCARBON SHOWS (none) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 80% sittstone, 20% sand/sandstone PRESENT LITHOLOGY 80% siltstone, 20% sand /sandstone DAILY ACTIVITY Drill ahead to surface casing point at 4607 ft MD; CBU; pump Nut Plug sweep; CBU, wiper top to 3168 ft; RIH to 4500 ft; CBU x3; pump high viscosity NutPlug sweep; pump dry job; SUMMARY POOH; L/D BHA EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $5835; RigWatch - $2650 REPORT BY D. Grunwald S file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\DESKTOP\NIGHT BACKUP... 4/13/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH Nikait DAILY WELLSITE REPORT till OP23 -WW02 REPORT FOR Jack Keener /Dave Morris /Andrew Buchanan DATE Apr 14, 2010 DEPTH 4607.00000 PRESENT OPERATION Rig up cementing equipment TIME 0428:50 YESTERDAY 4607.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4534 04 53.39 4 79 3735.09 BIT INFORMATION INTERVAL CONDITION REASON NO SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 2 16 HTC MX -1 Milltooth Bit 6074140 3X20, 1X16 3666 4607 941 20.1 - TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 2400 MW 9.3 VIS 60 PV 17 YP 14 FL 7 Gels 16/24/31 CL- 1000 FC 4/ SOL 8 SD - OIL 1/91 MBL 18.5 pH 8.0 Ca+ 60 CCI - MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA • ETHANE (C-2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C-4) NA @ NA @ NA CURRENT BACKGROUND /AVG NA PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS (none) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY LID remainder of BHA; R/U casing equipment; RIH with 13 3/8" casing, breaking circulation every 1000 feet; and hanger. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3045; RigWatch $2650 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/14/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT 0P23-00NO2 REPORT FOR Jack Keener /Dave Morris /Andrew Buchanan DATE Apr 15, 2010 DEPTH 4607.00000 PRESENT OPERATION Nippling down diverter stack TIME 00'00:00 YESTERDAY 4607 00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13.375" @ 4595' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 453404 53.39 4.79 3735.09 BIT INFORMATION INTERVAL CONDITION REASON N0. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH n.r. MW 9.6 VIS 55 PV 18 YP 15 FL n r Gels n.r. CL- n r FC n.r. SOL n.r SD n.r OIL n.r. MBL n.r. pH n.r. Ca+ n.r. CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA III ETHANE (C -2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C-4) NA @ NA @ NA CURRENT BACKGROUND /AVG NA PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS (none) INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY SUMMARY Circulation and condition mud for cement job; rig up cement equipment; pump cement job; L/D cement head; nipple down deserter stack. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3145; RigWatch $2650 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/15/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nikaitchuq DAILY WELLSITE REPORT OP23 -W W02 REPORT FOR Jack Keener /Dave Morris/Andrew Buchanan DATE Apr 16, 2010 DEPTH 4607.00000 PRESENT OPERATION Nippling up BOP equipment TIME 00:00:00 YESTERDAY 4607.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 60' 13.375" @ 4595' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4534.4 53.39 4 79 3735.09 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS 1 WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 4593 MW 9.6 VIS 55 PV 18 YP 15 FL n.r Gels n.r. CL- n.r. FC n.r. SOL n.r. SD n.r. OIL n r. MBL n.r. pH n.r. Ca* n r. CCI - MWD SUMMARY INTERVAL NA TO NA TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA III ETHANE (C-2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C-4) NA @ NA @ NA CURRENT BACKGROUND /AVG NA PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS none INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Nipple down flowline crossover and riser, clean and clear cellar; install wellhead, riser and crossover; nipple up BOP's, make up crossover, set on wellhead, and torque up BOP's; nipple up SUMMARY choke and manual kill, put in blind rams; pressure up Koomey, function test rams; connect hole fill and bleed down lines, miscellaneous mud logging activity - purge computer virus from RigWalch network and add hardware to accomodate more RigWatch monitors. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3045; RigWatch - $2650 REPORT BY D. Grunwald 0 file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/16/2010 Daily Report Page 1 of 1 ENI Petroleum • Nikaitchuq DAILY WELLSITE REPORT EPOCH OP23 -W W 02 REPORT FOR Jack Kenner /Dave Morris/ Andrew Buchanan DATE Apr 17, 2010 DEPTH 4607.00000 PRESENT OPERATION Pick up/ test BHA TIME 00:00:00 YESTERDAY 4607.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 60' 13.375" @ 4595' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4534.4 53.39 4.79 3735.09 1 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25 Hycalog MSX619S -A2D 220296 6x14 4607' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH Surface, new mud MW 9.0 VIS 42 PV 6 YP 17 FL 11.5 Gels 8/9/10 CL- 200 FC <1/ SOL nr SD nr OIL nr MBL nr pH 9.4 Ca+ 30 CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Complete nipple up BOPS. Test BOPS. 5000 psi body test leaked at VETCO GRAY packings, retightened, OK. Test BOPS 250 psi low, SUMMARY 5000 psi high witnessed by AOGCC rep. Make up BHA. Load nuke sources. misc mudlog activity - recalibrated gas equipment. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3045; RigWatch $1150 REPORT BY Ralph Winkelman • file: / /C:\Documents and Settings\EpochAdmin\MVly Documents\My Wells\EN1\Morning Re... 4/17/2010 Daily Report Page 1 of 1 • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT EPOCH OP23 -W W 02 REPORT FOR Jack Kenner /Dave Morris /Andrew Buchanan DATE Apr 18, 2010 DEPTH 4635.00000 PRESENT OPERATION L/D BHA TIME 00:00:00 YESTERDAY 4607.00000 24 HOUR FOOTAGE 28 CASING INFORMATION 20" @ 60' 13.375" @ 4595' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 4534.4 536.39 4.79 3735.09 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25 Hycalog MSX619S -A2D 220296 6x14 4607 4635 28 0.7 MWD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 169.0.0 @ 4608 16.1 @ 4621 40.0 103.19917 FT /HR SURFACE TORQUE 13376 @ 4615 8128 @ 4633 11119.4 12165.67285 AMPS WEIGHT ON BIT 16 @ 4609 3 @ 4626 11.1 5.59237 KLBS ROTARY RPM 74 @ 4633 40 @ 4619 55.3 68.73457 RPM PUMP PRESSURE 2052 @ 4615 1140 @ 4611 1770.2 1936.29309 PSI DRILLING MUD REPORT DEPTH NEW FROM PITS MW 9.0 VIS 42 PV 6 YP 17 FL 11.5 Gels 8/9/10 CL- 200 FC <1/ SOL nr SD nr OIL nr MBL nr pH 9.4 Ca+ 30 CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 11 @ 4624 0 @ 4619 3.4 TRIP GAS na CUTTING GAS 0 @ 4634 0 @ 4634 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 2267 @ 4624 360 @ 4633 654.6 CONNECTION GAS HIGH ETHANE (C -2) 0 © 4634 0 @ 4634 0.0 AVG PROPANE (C -3) 0 @ 4634 0 © 4634 0.0 CURRENT BUTANE (C-4) 0 @ 4626 0 @ 4634 0.0 CURRENT BACKGROUND /AVG na PENTANE (C -5) 0 @ 4634 0 @ 4634 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 60% sand/sandstone, 40% siltstone PRESENT LITHOLOGY 60% sand /sandstone, 40% siltstone DAILY Finish p/u BHA. Clear drill floor. Circ, condition mud and surface test MWD tools. P/U 30 jnts drill pipe. Service rig/ top drive/ crown. Trip in hole ACTIVITY to 4268', fill pipe every 20 stands. Ream/ wash 4268' - 4509', tag cement. Circ/ condition mud at 4500'. Pressure test casing to 2500 psi for 30 SUMMARY min. L/D test equipment. Drill out shoe tract and new formation to 4625'. Change out mud system. Perform FIT = 12.82 EQMW. Drill from 4625' - 4635', MWD failure. Trip out of hole, lay down BHA. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3045; RigWatch $1150 REPORT BY Ralph Winkelman • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\IVIY DOCUMENTS\MY WEL... 4/18/2010 Daily Report Page 1 of 1 • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT EPOCH OP23 -WW02 REPORT FOR Joe Longo /Dave Morris /Andrew Buchanan DATE Apr 19, 2010 DEPTH 5300 PRESENT OPERATION Drilling ahead TIME 00:00:00 YESTERDAY 4635 24 HOUR FOOTAGE 665 CASING INFORMATION 20" @ 160' 13.375" @ 4595' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 5119.6 52.42 5.98 4087.2 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 3 12.25 Hycalog MSX619S -A2D 220296 6x14 4607 4635 28 0.7 0- 3- BT- S- X- 2- CT -DTF MWD FAILURE 4 12.25 Hycalog MSX619S -A2D 225024 6x14 4635 665 6.13 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 262.2 @ 5210 7.3 @ 4635 150.7 154.95868 FT /HR SURFACE TORQUE 12778 @ 4686 13 @ 5118 8094.9 8630.72852 AMPS WEIGHT ON BIT 29 @ 4977 1 @ 5210 14.1 4.63700 KLBS ROTARY RPM 73 @ 4656 0 @ 5141 66.8 69.72298 RPM PUMP PRESSURE 2281 @ 5291 1845 @ 4636 2075.4 2243.86401 PSI DRILLING MUD REPORT DEPTH 4896' MW 9.1 VIS 41 PV 8 YP 16 FL 6.5 Gels 7/10/12 CL- 500 FC <1/ SOL 6 SD nr OIL 1/94 MBL 3 pH 10.0 Ca+ 60 CCI MWD SUMMARY INTERVAL TO O TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 290 @ 5100 6 © 4635 61.3 TRIP GAS 20 CUTTING GAS 0 @ 5300 0 @ 5300 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 364116 © 4727 3 @ 5300 11675.8 CONNECTION GAS HIGH ETHANE (C -2) 458 @ 5101 0 @ 4638 44.7 AVG PROPANE (C -3) 168 @ 4727 0 @ 4912 2.7 CURRENT BUTANE (C-4) 163 @ 4727 0 @ 4689 0.6 CURRENT BACKGROUND /AVG 38/45 PENTANE (C -5) 0 @ 5300 0 @ 5300 0.0 HYDROCARBON SHOWS i INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 30% claystone, 40% siltstone, 30% sand /sandstone 4 % claystone, 40 % siltstone, 20% sand/ sandstone PRESENT LITHOLOGY 0 / y , DAILY Laydown BHA. Unload nuke sources. Continue LD BHA. Change out bit. Download MWD tools.Pick up BHA. Load nuke sources. Clean rig ACTIVITY floor. Broken shear pin on SADN8 LWD tool. Wait on parts. Service rig etc while wait on parts. Continue pick up BHA without SADN8 tool. RIH SUMMARY and pulse test MWD tools. TIH to 4535', service rig, top drive etc. Wash from 4535' to 4635'. Drill 4635' to 5110'. Slide 5110' to 5142'. Rotate 5142' to 5300' at report depth. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3045, RigWatch $1150 REPORT BY Ralph Winkelman 0 1 file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/19/2010 Daily Report Page 1 of 1 ill ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT El EPOCH OP23 -W W02 REPORT FOR Joe Longo /Dave Morris /Andrew Buchanan DATE Apr 20, 2010 DEPTH 6720 PRESENT OPERATION Drilling ahead TIME 00:00:00 YESTERDAY 5300 24 HOUR FOOTAGE 1420 CASING INFORMATION 20" @ 160' 13.375" @ 4595' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 6459.34 51.10 4.54 4911.74 6654.26 51.41 5.05 5033.84 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 12.25 Hycalog MSX619S -A20 225024 6x14 4635 2085 18.88 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 333.8 @ 5401 10.9 @ 6642 156.5 55.30973 FT /HR SURFACE TORQUE 13982 @ 6534 8 © 6261 9684.1 12194.65820 AMPS WEIGHT ON BIT 30 @ 5971 0 @ 6502 12.5 15.56003 KLBS ROTARY RPM 85 @ 5874 0 @ 6268 77.3 80.79597 RPM PUMP PRESSURE 3087 @ 6662 1683 @ 6638 2580.9 3055.81128 PSI DRILLING MUD REPORT DEPTH 5970 MW 9.5 VIS 51 PV 14 YP 24 FL 6 Gels 12/19/27 CL- 700 FC <1/ SOL 8 SD nr OIL 1/92 MBL 12.5 pH 9.7 Ca+ 30 CCI MWD SUMMARY INTERVAL TO • TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 110 @ 5493 0 @ 6629 55.9 TRIP GAS CUTTING GAS 0 @ 6720 0 @ 6720 0.0 WIPER GAS 170U CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 22021 @ 6064 44 @ 5703 10953.4 CONNECTION GAS HIGH ETHANE (C -2) 180 © 6162 0 @ 6629 66.3 AVG PROPANE (C -3) 0 @ 6720 0 @ 6720 0.0 CURRENT NA BUTANE (C-4) 0 @ 5398 0 @ 5976 0.0 CURRENT BACKGROUND /AVG 30/ 23 PENTANE (C -5) 0 @ 6720 0 @ 6720 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 30% sand/ sandstone, 70% siltstone PRESENT LITHOLOGY 20% sand/ sandstone, 80% siltstone DAILY ACTIVITY Drill from 5300' to 6600'. Circulate and condition mud, CBU. POOH from 6600' to 4535'. Service rig, top drive, blocks, DWS, crown. SUMMARY Calibrate RigWatch block height. Trip in hole to 6547'. Wash from 6547' to 6600', drill 6600' to 6720' at report time. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3045, RigWatch $1150 REPORT BY Ralph Winkelman • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/20/2010 Daily Report Page 1 of 1 ENI Petroleum ill Ninaitchuq DAILY WELLSITE REPORT EPOCH OP23 -WW02 REPORT FOR Joe Longo.Dave Morris /Andrew Buchanan DATE Apr 21, 2010 DEPTH 8320 PRESENT OPERATION Drilling ahead TIME 00:00:00 YESTERDAY 6720 24 HOUR FOOTAGE 1600 CASING INFORMATION 20" @ 160' 13.375" @ 4595' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 8184.00' 50.13 6.58 6021.03' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 12.25 Hycalog MSX619S -A2D 225024 6x14 4635 3685 37.03 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 332.8 @ 7888 9.1 @ 7999 134.5 143.15254 FT /HR SURFACE TORQUE 18704 @ 7226 3 @ 6758 10688.2 14211.76855 AMPS WEIGHT ON BIT 34 @ 7409 0 @ 7315 18.1 20.86013 KLBS ROTARY RPM 93 @ 8230 0 @ 6745 74.3 92.74012 RPM PUMP PRESSURE 3490 @ 7967 2907 @ 6834 2970.3 3302.95288 PSI DRILLING MUD REPORT DEPTH 8212 MW 9.8 VIS 71 PV 21 YP 21 FL 4.5 Gels 9/32/40 CL- 1200 FC 1/ SOL 10 SD nr OIL 1/89 MBL 12.5 pH 9.7 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 71 @ 7117 20 @ 7315 39.3 TRIP GAS NA CUTTING GAS 0 @ 8320 0 @ 8320 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 14716 @ 7117 4292 @ 7318 7859.5 CONNECTION GAS HIGH NA ETHANE (C -2) 305 @ 8269 9 @ 7318 128.6 AVG PROPANE (C -3) 107 @ 8269 2 @ 7326 29.6 CURRENT BUTANE (C-4) 0 @ 7410 0 @ 7383 0.0 CURRENT BACKGROUND /AVG 41/ 35 PENTANE (C -5) 0 @ 8320 0 @ 8320 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 20% sand/ sandstone, 80%siltstone. trace claystone PRESENT LITHOLOGY 20% sand/ sandstone, 80%siltstone. trace claystone DAILY Drill from 6720' to 7200', sliding on occasion. Continue to drill from 7200' to 7704'. Slide 7704' to 7725'. Rotate 7725' to 8000'. Slide 8000' to ACTIVITY 8010', bleed in 290 bbls LSND spike fluid with Resinex. Circulate and condition, lost 500 psi. No apparent pump problems. All checks negative. SUMMARY Test surface equipment to 2000 psi. OK. Stage pumps back up to full. Started at 2700 psi and returned to 3200 psi. Continue slide 8010' to 8020'. Rotate 8020' to 8320' at report time. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3045, RigWatch $1150 REPORT BY Ralph Winkelman 1 10 file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/21/2010 Daily Report Page 1 of 1 ill ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT EPOCH OP23 -W W 02 REPORT FOR Joe Longo /Dave Morris /Andrew Buchanan DATE Apr 22, 2010 DEPTH 9120 PRESENT OPERATION POOH TIME 00:00:00 YESTERDAY 8320 24 HOUR FOOTAGE 800 CASING INFORMATION 20" @ 160' 13.75" @ 4595' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9033.38 49.12 4.82 6577.71 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 12.25 Hycalog MSX619S -A2D 225024 6x14 4635 9120 4485 46.0 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 273.3 @ 9036 16.9 @ 9037 121.3 90.43400 FT /HR SURFACE TORQUE 21958 @ 8551 26 @ 8383 15921.7 14892.30400 AMPS 1 WEIGHT ON BIT 26 @ 8486 0 @ 8998 15.6 16.14500 KLBS ROTARY RPM 92 @ 8320 0 @ 8388 84.9 90.70900 RPM PUMP PRESSURE 3493 @ 8836 3160 @ 8391 3351.9 3438.18800 PSI DRILLING MUD REPORT DEPTH 9120 MW 9.9 VIS 74 PV 20 YP 22 FL 4.5 Gels 9/32/40 CL- 1000 FC 1/3 SOL 11 SD nr OIL 3/87 MBL 20 pH 9.4 Ca+ 40 CCI MWD SUMMARY INTERVAL TO III TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 231 @ 8935 0 @ 9054 76.4 TRIP GAS CUTTING GAS 0 @ 9120 0 @ 9120 0.0 WIPER GAS 329 CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 38696 @ 8934 76 @ 9050 13902.0 CONNECTION GAS HIGH NA ETHANE (C -2) 1905 @ 8934 3 @ 9054 541.2 AVG PROPANE (C -3) 1869 @ 8935 2 @ 9054 305.8 CURRENT BUTANE (C-4) 611 @ 8934 0 @ 8533 107.6 CURRENT BACKGROUND /AVG 23 PENTANE (C -5) 132 @ 8934 0 @ 9054 10.1 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 20% carbonaceous shale, 20% siltstone, 60% shale PRESENT LITHOLOGY 40% carbonaceous shale, 60% shale DAILY ACTIVITY Drill from 8320' to 9120'. Confirm with geologist casing point. Circulate and condition, take on bottom survey with MWD. Pump hi vis sweep SUMMARY around. POOH 9120' to 6600'. No problems on trip. Trip in hole 6600' to 9037'. Wash down 9037' to bottom. Circulate and condition. Pump hi vis nut plug sweep around. Circulate till hole clean. Pull 2 stands, pump slug, continue POOH to 4535' at report time. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3045, RigWatch $1150 REPORT BY Ralph Winkelman • file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/22/2010 Daily Report Page 1 of 1 • EM Petroleum Nikaitchuq DAILY WELLSITE REPORT Hil EPOCH OP23 -WW02 REPORT FOR Joe Longo /Dave Morris /Andrew Buchanan DATE Apr 23, 2010 DEPTH 9120 PRESENT OPERATION Wireline logging TIME 00:00:00 YESTERDAY 9120 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13.375" @ 4595' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9033.38 49.12 4.82 6577.71 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 4 12.25 Hycalog MSX619S -A2D 225024 6x14 4635 9120 4485 46.0 1- 3- BT- A- X- 1 -BU -TD TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9120 MW 9.8 VIS 48 PV 16 YP 16 FL 4.8 Gels 6/10/22 CL- 1200 FC 1/ SOL 9.5 SD nr OIL 2/89 MBL 20 pH 9.4 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS III GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY Continue POOH to top of BHA at 703'. PJSM for laying down BHA. Lay down BHA. Clean rig floor, cellar, service rig , top drive etc while SUMMARY waiting on wireline personel. PJSM for rig up wireline. Rig up wireline.. Make up logging tools and load nuke source. RIH with logging tools,Platform Express/ Sonic Scanner/ PPC's to 9118'. Logging out from 9118' to 2500' at report time. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3045, RigWatch $1150 REPORT BY Ralph Winkelman I I • file: / /C:\Documents and Settings\EpochAdminWly Documents\My Wells\EN1\1VIorning Re... 4/23/2010 Daily Report Page 1 of 1 • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT H EPOCH OP23 -WW02 REPORT FOR Joe Longo /Dave Morris/ Andrew Buchanan DATE Apr 24, 2010 DEPTH 9120.00000 PRESENT OPERATION CBU @ 6000' run csg TIME 00:00:00 YESTERDAY 9120.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13.375" @ 4595' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9033.38 49.12 4.82 6577.71 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9120 MW 9.9 VIS 78 PV 16 YP 15 FL 4.5 Gels 10/15/30 CL- 1000 FC 1/ SOL 10 SD nr OIL 2/88 MBL 20 pH 9.4 Ca+ 40 CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 109 @ Approx 6000' @ TRIP GAS 109 @ 6000' CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG 10 PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY Continue open hole logging. PJSM to lay down wireline. Rig down wireline equipment. Pull wear bushing. Test BOP's. Change out bottom rams ACTIVITY to 9 5/8" rams. Test BOP's bottom rams 250psi low, 5000psi hi for 5 minutes. Dummy run 9 5/8" hanger as per VETCO. PJSM for casing run. SUMMARY Rig up casing tools. Pick up shoe and float joints, check as per program, OK. Continue run 9 5/8 ", fill every joint, top off every 10 and CBU every 1000'. CBU at 6000' report time. Max gas so far, 109 units while CBU at 6000' EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3045, RigWatch $1150 REPORT BY Ralph Winkelman • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/24/2010 Daily Report Page 1 of 1 ENI Petroleum • Nikaitchuq DAILY WELLSITE REPORT ti EPOCH OP23 -W W02 REPORT FOR Joe Longo /Dave Morris /Anfrew Buchanan DATE Apr 25,2010 DEPTH 9120.00000 PRESENT OPERATION Test BOP's TIME 00:00:00 YESTERDAY 9120.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13.375" @ 4595' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9033.38 49.12 4.82 6577.71 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9120' Versa Clean MW 10.4 VIS 60 PV 23 YP 11 FL nr Gels 6/15/18 CL- 49000 FC nr SOL 13.93 SD nr OIL 68 MBL nr pH nr Ca+ nr CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS 117 CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Continue run 9 5/8" casing from 6000' to 9049', filling every joint, top off every 10 and CBU every 1000'. CBU at 7000', 8000' and 9049'. Pick up 1 hanger and landing joint and land casing. Rig down Franks casing tools. Make up cement head and circ lines. CBU and condition. PJSM for DAILY cementing. Pressure test lines to 4000psi. Pump 40bbls mud push. Drop bottom plug. Pump 80 bbls 15.8ppg cement. Drop top plug. Pump ACTIVITY 10bbls water followed by 666bb1s oil base mud. Plug did not bump. Bleed off and check floats, floats holding. Rig down cement head. Remove SUMMARY csg elevator and install drill pipe elevators. Pick up packoff running tool. Suck out stack and and rinse top of hanger. Set packoff and test to 5000psi per VETCO GRAY. Finish lay down casing tools. Set test plug. Change out bottom 9 5/8" rams back to 3 1/2x6 variable rams. Test BOP's. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3045, RigWatch $1150 REPORT BY Ralph Winkelman file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN \MY DOCUMENTS\MY WEL... 4/25/2010 Daily Report Page 1 of 1 IP ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT EPOCH OP23 -WW02 REPORT FOR Joe Longo /Dave Morris /Andrew Buchanan DATE Apr 26, 2010 DEPTH 9120.00000 PRESENT OPERATION Pick up drill pipe TIME 00:00:00 YESTERDAY 9120.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 4595' 9 5/8" @ 9087.5' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9033.38' 49.12 4.82 6577.71' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 5 8 1/2" Hycalog DTX519M 126427 6x13 9120' DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION @ @ FT /HR SURFACE TORQUE @ @ AMPS WEIGHT ON BIT @ @ KLBS ROTARY RPM @ @ RPM PUMP PRESSURE @ @ PSI DRILLING MUD REPORT DEPTH 9120' MW 10.4 VIS 60 PV 23 YP 11 FL nr Gels 6/14/19 CL- 49000 FC nr SOL 16 SD nr OIL 68 MBL nr pH nr Ca+ nr CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS @ @ TRIP GAS CUTTING GAS @ @ WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) @ @ CONNECTION GAS HIGH ETHANE (C -2) @ @ AVG PROPANE (C -3) @ @ CURRENT BUTANE (C-4) @ @ CURRENT BACKGROUND /AVG PENTANE (C -5) @ @ HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY Finish BOP test. Lay down test tool and testing equipment. Blow down choke and kill lines. Install wear ring. Pressure test casing to 3000psi for DAILY 30 minutes. Good test. Blow down lines. Trip in with drill collars, jars and 2 HWDP. Slip and cut 96' drill line, adjust brakes, reset crown and floor ACTIVITY saver. Service top drive, draw works and crown. Repair TO boost. Fix leaks on top drive and HPU. Lay down last of 12 1/4" BHA. Misc SUMMARY operations in prep for oil base mud. Load pipe shed with drill pipe. PJSM for 8 1/2" BHA. Pick up BHA, load sources. Trip in hole with HWDP. Pick up drill pipe to 1000'. Test MWD, good test. Continue pick up pipe and trip in hole at report time. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3125, RigWatch $1150 REPORT BY Ralph Winkelman • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/26/2010 Daily Report Page 1 of 1 ENI Petroleum 1111/ ENI DAILY WELLSITE REPORT EPOCH OP23 -WW02 REPORT FOR Joe Longo /Dave Morris /Andrew Buchanan DATE Apr 27, 2010 DEPTH 9692.00000 PRESENT OPERATION Drill ahead TIME 00:00:00 YESTERDAY 9120 24 HOUR FOOTAGE 572 CASING INFORMATION 20" @ 160' 13 3/8" @ 4595' 9 5/8" @ 9087.5' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 9621.00' 42.82 3.16 6966.61' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 5 8 1/2" Hycalog DTX519M 126427 6x13 9120' 8.2 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 363.9 @ 9137 9.2 @ 9213 125.0 136.00000 FT /HR SURFACE TORQUE 12345 @ 9313 0 @ 9446 6468.1 0.00000 AMPS WEIGHT ON BIT 47 @ 9338 0 @ 9671 9.2 35.51549 KLBS ROTARY RPM 112 @ 9351 0 @ 9335 69.8 0.00000 RPM PUMP PRESSURE 3223 @ 9446 2233 @ 9121 3026.7 3096.58691 PSI DRILLING MUD REPORT DEPTH 9636 MW 10.3 VIS 68 PV 23 YP 18 FL Gels 14/25/30 CL- 49000 FC SOL 14 SD OIL 65 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS • GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 62 @ 9367 2 @ 9122 18.0 TRIP GAS CUTTING GAS 0 @ 9692 0 @ 9692. 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 11187 @ 9367 28 © 9692 3350.3 CONNECTION GAS HIGH ETHANE (C -2) 220 @ 9367 3 @ 9129 77.4 AVG PROPANE (C -3) 104 @ 9367 0 @ 9253 23.0 CURRENT BUTANE (C-4) 0 @ 9692 0 @ 9692 0.0 CURRENT BACKGROUND /AVG 8 / 11 PENTANE (C -5) 0 @ 9692 0 @ 9692 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 30% sand/ sandstone, 30% siltstone, 40% carbonaceous shale/ shale PRESENT LITHOLOGY 20% sand/ sandstone, 40% siltstone, 40% shale / carbonaceous shale DAILY Pick up pipe and trip in hole from 1600' to 3949'. Trip in stands 3949' to 9009' filling pipe every 3000'. Drill cement, float equipment 9009' to ACTIVITY 9120'. Drill 9120' to 9170'. CBU. POOH to 9021'. Perform Leak Off Test to 16.25 EQMW. Drill 9170' to 9451' rotate and slide as per directional SUMMARY plan. CBU at 9451' cuttings chute packed off, clear. Drag chain jumped off sprocket, repair same. Continue drill 9451' to 9692', rotate and slide as per directional plan. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $ 3125, RigWatch $1150 REPORT BY Ralph Winkelman 11 ) file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/27/2010 Daily Report Page 1 of 1 • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT n EPOCH OP23 -WW02 REPORT FOR Joe Longo /Dave Morris /Andrew Buchanan DATE Apr 28, 2010 DEPTH 11380 PRESENT OPERATION Drill ahead TIME 00:00:00 YESTERDAY 9692 24 HOUR FOOTAGE 1688 CASING INFORMATION 20" @ 160' 13 3/8" @ 4595' 9 5/8" @ 9087.5' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11345.26' 9.02 4.49 8581.56' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 5 8 1/2" Hycalog DTX519M 126427 6x13 9120' 25.05 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 304.0 @ 10407 9.1 @ 9981 136.6 29.14036 FT /HR SURFACE TORQUE 16737 @ 11328 0 @ 10203 10082.7 13017.05664 AMPS WEIGHT ON BIT 36 @ 9693 0 @ 9788 7.4 13.16617 KLBS ROTARY RPM 116 @ 11338 0 © 11258 81.3 101.37112 RPM PUMP PRESSURE 3406 @ 11247 2898 @ 9912 3200.5 3193.40405 PSI DRILLING MUD REPORT DEPTH 11300 MW 10.4 VIS 62 PV 24 YP 16 FL Gels 15/23/34 CL- 54000 FC SOL 16.5 SD OIL 67 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO • TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 120 @ 11296 0 @ 10403 32.2 TRIP GAS CUTTING GAS 0 @ 11380 0 @ 11380 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 20359 @ 11273 28 @ 11380 5627.2 CONNECTION GAS HIGH ETHANE (C -2) 692 @ 11285 0 @ 10403 141.0 AVG PROPANE (C -3) 430 @ 11285 0 @ 10401 82.2 CURRENT BUTANE (C -4) 162 @ 11285 0 @ 10665 21.2 CURRENT BACKGROUND /AVG 9 / 17 PENTANE (C -5) 0 @ 11380 0 @ 11380 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 20% sand/ sandstone, 70% siltstone, 10% claystone/ shale PRESENT LITHOLOGY 30% sand/ sandstone, 70% siltstone DAILY ACTIVITY SUMMARY Drill from 9692' to 11380', slide and rotate as per directional plan. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3125 RigWatch $1150 REPORT BY Ralph Winkelman • file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/28/2010 Daily Report Page 1 of 1 • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT n EPOCH OP23 -W W 02 REPORT FOR Dave Morris /Gary Goerlick/Andrew Buchanan DATE Apr 29, 2010 DEPTH 12090 PRESENT OPERATION Drill ahead TIME 00:00:00 YESTERDAY 11380 24 HOUR FOOTAGE 710 CASING INFORMATION 20" @ 160' 13 3/8" @ 4595' 9 5/8" @ 9087.5' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 11730.24' 8.09 3.28 8962.40' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 5 8 1/2" Hycalog DTX5198M 126427 6x13 9120 40.15 DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 234.7 @ 11714 1.6 @ 11893 78.5 53.54274 FT /HR SURFACE TORQUE 18314 @ 12073 11730 @ 11477 15227.6 15589.16895 AMPS WEIGHT ON BIT 15 @ 12085 2 @ 11608 10.4 15.50581 KLBS ROTARY RPM 112 @ 11764 74 @ 11509 100.2 96.45934 RPM PUMP PRESSURE 3389 @ 11562 1693 @ 11847 2885.4 2380.68701 PSI DRILLING MUD REPORT DEPTH 12042' MW 10.5 VIS 62 PV 27 YP 9 FL Gels 6/20/26 CL- 42000 FC SOL 16 SD OIL 67 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 780 @ 11479 0 @ 11770 35.5 TRIP GAS CUTTING GAS 0 @ 12090 0 @ 12090 0.0 WIPER GAS 65u @ 11847' CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 135789 @ 11479 75 @ 11770 6755.4 CONNECTION GAS HIGH 186u @ 11703 ETHANE (C -2) 5188 @ 11479 6 @ 11769 284.1 AVG 128 PROPANE (C -3) 2588 @ 11479 0 @ 11846 93.8 CURRENT 0 BUTANE (C-4) 942 @ 11479 0 @ 11817 36.8 CURRENT BACKGROUND /AVG 14 / 8 PENTANE (C -5) 146 @ 11614 0 @ 11655 8.1 HYDROCARBON 11595' - 11700'MD, 8829' - 8933'TVD, See show report #4 SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION 11595' - 11700 Sandstone/ sandy siltstone = medium light gray;medium lower Before 80u medium yellow white fluor in siltstone/ sandstone to fine upper; subangular to subrounded; clear quartz dominant; max 173u after fragments; medium streaming cut to yellow white; very trace white/ ashy clay, very calcareous. 21 ave 81 slight brownish res ring; trace dark brown stain in silty fragments LITHOLOGY 70% sand/ sandstone, 30% siltstone PRESENT LITHOLOGY 50% sand/ sandstone, 40% siltstone, 10% ash, limestone, shale DAILY Drill from 11380' to 11847'. Pick up for flow check at 11500', gas max 780 units. Flow up to 26% - 30% from 18 %. Hole started taking fluid at ACTIVITY 11799', 35 bbls an hour. Spot 25 bbls of 40 lb /gal LCM pill. Lost 161 bbl A.M. tour. POOH from 11847' to 10937'. Circ and condition, work pipe SUMMARY and monitor losses of 9.5 bbls. Trip in to 11799', wash to bottom at 11847'.Drill from 11847' to 12090' at report time. Pump LCM pill at 11880'. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $ 3125 RigWatch $1150 REPORT BY Ralph Winkelman • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/29/2010 Daily Report Page 1 of 1 • ENI Petroleum Nikaitchuq DAILY WELLSITE REPORT EPOCH OP23 -W W 02 REPORT FOR Dave Morris /Gary Goerlick/Andrew Buchanan DATE Apr 30, 2010 DEPTH 12323 PRESENT OPERATION Lay down BHA TIME 00:00:00 YESTERDAY 12090 24 HOUR FOOTAGE 233' CASING INFORMATION 20" @ 160' 13 3/8" @ 4595' 9 5/8" @ 9087.5' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12254.55 7.07 1.79 9481.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T /B /C PULLED 5 8 1/2" Hycalog DTX519M 126427 6x13 9120' 12323 3203' 45.58 TD DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 94.3 @ 12104 13.2 @ 12187 56.6 63.50999 FT /HR SURFACE TORQUE 20268 @ 12301 12890 @ 12187 17095.6 18357.64453 AMPS WEIGHT ON BIT 16 @ 12157 7 @ 12206 13.9 12.76798 KLBS ROTARY RPM 115 @ 12252 80 @ 12209 98.4 108.06813 RPM PUMP PRESSURE 2467 @ 12209 2260 @ 12276 2373.8 2387.57715 PSI DRILLING MUD REPORT DEPTH 12323' MW 10.4 VIS 57 PV 23 YP 6 FL Gels 5/15/19 CL- 39000 FC SOL 14.73 SD OIL 66 MBL pH Ca+ CCI MWD SUMMARY INTERVAL TO • TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 36 @ 12106 6 @ 12151 13.5 TRIP GAS CUTTING GAS 0 @ 12323 0 @ 12323 0.0 WIPER GAS 90u CHROMATOGRAPHY (ppm) SURVEY METHANE (C -1) 6982 @ 12106 1149 @ 12176 2493.1 CONNECTION GAS HIGH ETHANE (C -2) 351 @ 12106 57 @ 12151 180.9 AVG PROPANE (C -3) 0 @ 12323 0 @ 12323 0.0 CURRENT BUTANE (C-4) 0 @ 12323 0 @ 12323 0.0 CURRENT BACKGROUND /AVG PENTANE (C -5) 0 @ 12323 0 @ 12323 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY 30% sand/ sandstone, 70% siltstone PRESENT LITHOLOGY 10% sandstone, 20% shale, 70% siltstone DAILY ACTIVITY Drill from 12090' to 12323' TD. CBU, pump hi vis sweep. Monitor well for 10 minutes, pump dry job. POOH from 12323' to 9021'. Hole in good SUMMARY shape. CBU. Service rig, top drive, blocks, crown and draw works. Trip in hole to 12287', wash down to 12323'. CBU. POOH to BHA, Drop 2.25" rabbit on stand 105, recover at jars. PJSM for lay down BHA with MWD nuke source. Lay down BHA. EPOCH PERSONNEL ON BOARD 4 DAILY COST DML $3125 RigWatch $1150 REPORT BY Ralph Winkelman • file: / /C:\DOCUMENTS AND SETTINGS \EPOCHADMIN\MY DOCUMENTS\MY WEL... 4/30/2010 Daily Report Page 1 of 1 • ENI Petroleum EPOCH Nikait DAILY WELLSITE REPORT OP23 -W W 02 REPORT FOR Dave Moms /Gary Goerlich DATE May 01, 2010, report period Apnl 30, 2010 DEPTH 12323.00000 PRESENT OPERATION Open -hole logging TIME 00.00:00 YESTERDAY 12323.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 4595' 95/8" @ 9087.5 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12254.55 7.70 1.79 9481.98' BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 12323 MW 10.1 VIS 55 PV 22 YP 5 FL n.r. Gels 5/16/19 CL- 39000 FC n.r. SOL 1249 SD 0.25 OIL 79/21 MBL - pH - Cal- - CCI - MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA ill ETHANE (C -2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C -4) NA @ NA @ NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY L/D BHA and unload nuclear source; clear and clean rig floor; P/U and M/U open -hole logging tools, TIH from 143' to 8230' with drill pipe conveyed logging tools, filling drill pipe every 10 SUMMARY stands; TIH to to 9060', M/U side entry sub; RIH to 11568'; open hole logging EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3145; RigWatch - $1150 REPORT BY D. Grunwald S file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/1/2010 Daily Report Page 1 of 1 ENI Petroleum EPOCH Nika:tchuq DAILY WELLSITE REPORT OP23 -W W02 REPORT FOR Jack Keener /Gary Goencch/Andrew Buchanan DATE May 02, 2010; report period May 01, 2010 DEPTH 12323.00000 PRESENT OPERATION Open hole logging TIME 00:00.00 YESTERDAY 12323.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 4595 95/8" @ 9087.5 DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12254.55 7 70 1.79 9481.98 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 12323 MW 10.4 VIS 53 PV 15 YP 6 FL - Gels 6/12/- CL- 40000 FC -/- SOL 147 SD 0.25 OIL 78/22 MBL - pH - Ca+ - CCI - MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA II ETHANE (C-2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C-4) NA @ NA @ NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY Continued downhole pressure testing at predetermined depths with drill pipe conveyed tools - pressure testing at 11,301 ft at 0:00 hrs, and continuing downward to 12155 ft at 1500 hrs, POOH, SUMMARY collecting fluid samples at selected depths; 1st attempt to obtain fluid sample at 12018 ft a unsuccessful; POOH to 11677 ft, and RIH to 12018 ft, and collect fluid sample, attempt to collect fluid sample at 11863 ft is unsuccessful as of midnight; miscellaneous mudlogging activity - troubleshoot mud pa sensors in the tnp tank and pill pit; sample catchers en route to Anchorage EPOCH PERSONNEL ON BOARD 4 DAILY COST DML - $3060; RigWatch - $1150 REPORT BY D. Grunwald • file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/2/2010 Daily Report Page 1 of 1 III ENI Petroleum El EPOCH Nikaitchuq DAILY WELLSITE REPORT OP23 -WW02 REPORT FOR Jack Keener /Gary Goerlich/Andrew Buchanan DATE May 03, 2010; report period May 02, 2010 DEPTH 12323.00000 PRESENT OPERATION P/U BHA TIME 00:00:00 YESTERDAY 12323.00000 24 HOUR FOOTAGE 0 CASING INFORMATION 20" @ 160' 13 3/8" @ 4595' 9 5/8" @ 9087' DEPTH INCLINATION AZIMUTH VERTICAL DEPTH SURVEY DATA 12254.55 7 70 1.79 9481.98 BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS TB /C PULLED NA DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION NA @ NA @ NA NA FT /HR SURFACE TORQUE NA @ NA @ NA NA AMPS WEIGHT ON BIT NA @ NA @ NA NA KLBS ROTARY RPM NA @ NA @ NA NA RPM PUMP PRESSURE NA @ NA @ NA NA PSI DRILLING MUD REPORT DEPTH 12323 MW 104 VIS 53 PV 16 YP 6 FL - Gels 6/12/16 CL- 40000 FC - SOL 13.43 SD 025 OIL 78/22 MBL - pH - Ca. 1.3 lb/bbl lime CCI - MWD SUMMARY INTERVAL TO TOOLS NA GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS NA @ NA @ NA TRIP GAS NA CUTTING GAS NA @ NA @ NA WIPER GAS NA CHROMATOGRAPHY (ppm) SURVEY NA METHANE (C -1) NA @ NA @ NA CONNECTION GAS HIGH NA • ETHANE (C -2) NA @ NA @ NA AVG NA PROPANE (C -3) NA @ NA @ NA CURRENT NA BUTANE (C-4) NA @ NA @ NA CURRENT BACKGROUND /AVG 0 PENTANE (C -5) NA @ NA @ NA HYDROCARBON SHOWS NA INTERVAL LITHOLOGY /REMARKS GAS DESCRIPTION LITHOLOGY NA PRESENT LITHOLOGY NA DAILY ACTIVITY TOOH from 11,863 ft to 9,059 ft, pull wireline out of doll pipe, POOH and pump dry job; L/D logging tools and clean rig floor; pull wear bushing and suck out BOPE; test BOP's; drain SUMMARY stack and install wear bushing; P/U BHA for clean -out run. EPOCH PERSONNEL ON BOARD 2 DAILY COST DML - $2285; RigWatch - $1150 REPORT BY D. Grunwald S file: / /C:\DOCUMENTS AND SETTINGS\EPOCHADMIN\MY DOCUMENTS\MY WEL... 5/3/2010 • CANRIG SHOW REPORT NO. 1 DRILLI \4 TF.(.HNOLO(.Y Lru ENI Petroleum OP23 -WW02 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 3600 TO 3700 (MD) TOTAL FTG 100 3150 TO 3213 {TVD) BIT INFORMATION: BIT HTC MX -1 Milltooth Bit BIT HOURS- 48 AVERAGES: BEFORE DURING AFTER I MAXIMUM ROP (fph) 110 86 162 150 WOB 21 17 6 48 RPM 37 30 59 43 MUD WT 9.2 9.2/9.6 9.6 9.6 CHLORIDE 1200 900 900 1200 TOTAL GAS 12 8 27 10 0 Cl (ppm) 65914 1964 5900 3409 C2 (ppm) 0 0 0 0 C3 (ppm) 0 0 0 0 C4 (ppm) 0 0 0 0 C5 (ppm) 0 0 0 0 RATIO ROP INCREASE TO GAS INCREASE: ( -0.78 / -0.67) SAMPLE CUTTINGS FLUORESENCE%: 30 -40 COLOR Yellow INTENSITY: dull CUT: slow, improves with crush MUD FLUORESCENCE dull yellow fluorescence once beyond visibly stained cuttings FORMATION DESCRIPTION: Sand = light to medium gray; salt and pepper appearance; soft to dis- aggregated; sample recovered as about equal parts loose sand and soft clay supported sandstone fragments with occasional small clay /silt masses; moderately to moderately well sorted; medium upper to medium lower, fine upper and coarse lower grain; trace very fine; angular to sub - angular to very slightly rounded; translucent white to clear quartz predominates; abundant light to medium gray and brown chert/ lithics; trace to common black clastic coal fines; trace coarse chert fragments; primarily supported in clean white kaolinite clay; hydrophilic; easily washed away in wash water; trace visible stain; no odor; 30% to 40% dull yellow fluorescence; slow cut to bright yellow white, improves with crushing; slight brown residue with medium yellow gold fluorescence; cuts instantly to yellow white; very slightly calcareous. SHOW RATING: (T,P,F,G) TRACE 0 LOGGING GEOLOGIST(S): Daniel Grunwald, John Lundy • CANRIG SHOW REPORT NO. 2 DRILLI \G TEA HNOLUUI Lru ENI Petroleum OP23 -WW2 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 4010 TO 4095 (MD) TOTAL FTG 85 3412 TO 3466 {TVD) BIT INFORMATION: BIT Bit#2 HC MX -1 Milltooth BIT HOURS- 10 AVERAGES: BEFORE DURING MAXIMUM I AFTER Average ROP (fph) 175 108 251 80 WOB 6.6 9.1 28 2.5 RPM 63 61 61 63 MUD WT 9.3 10.3 10.3 10.3 CHLORIDE TOTAL GAS 71 137 334 153 C1 (ppm) 13716 25430 90981 19675 C2 (ppm) TRACE 864 252 C3 (ppm) 141 508 111 C4 (ppm) 228 901 204 C5 (ppm) 87 373 144 RATIO ROP INCREASE TO GAS INCREASE: 76/263 SAMPLE CUTTINGS FLUORESENCE%: 80 -100 COLOR YELLOW INTENSITY: MEDIUM CUT: FAST STRMING MUD FLUORESCENCE DULL GREENISH YELLOW, NO FREE OIL, NO POPS, SLIGHT SHEEN FORMATION DESCRIPTION: Sand; light to very light gray with a slight brownish to olive secondary hue; soft to dis- aggregated; well to moderately well sorted; fine upper to fine lower and medium lower grain; sub - angular to angular and sub rounded; translucent smokey to white and clear quartz predominate; abundant dark gray to black mineral /lithics; to white and clear quartz predominate; abundant dark gray to black mineral /lithics; trace blue jade; occasional small pebble; common fine grain clastic coal fines; matrix supported in very light olive brown to olive silt/clay; 80% to 100% medium yellow sample fluorescence; fast streaming cut to yellow white; slight brownish residue becomes medium brown at 4060 sample; immediate reidue cut to yellow - white; trace free oil overall, abundant at 4050 to 4070' interval; slight to moderate oil odor; slightly calcareous; trace shell fragments. SHOW RATING: (T,P,F,G) fair LOGGING GEOLOGIST(S): John Lundy • CANRIG SHOW REPORT NO. 3 DKLu.IXG TF:CHYU IR;7 LTD. ENI Petroleum OP23 -WW2 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 4305 TO 4410 (MD) TOTAL FTG: 105 3595 TO 3659 {TVD) BIT INFORMATION: BIT TYPE- Bit#2 HC MX -1 Milltooth BIT HOURS- 12.5 DURING AVERAGES: BEFORE AVERAGE MAXIMUM I AFTER I ROP (fph) 64 80 127 77.4 WOB 32.7 11.2 40 6.3 RPM 67 61 64 61 MUD WT 9.3 9.3 9.3 9.3 CHLORIDE TOTAL GAS 65 223 653 125 C1 (ppm) 7207 22392 68801 10638 C2 (ppm) 90 298 874 452 C3 (ppm) 99 370 953 420 C4 (ppm) 190 737 1680 635 C5(ppm) 120 395 1263 522 RATIO ROP INCREASE TO GAS INCREASE: 16/588 SAMPLE CUTTINGS FLUORESENCE%: 10% - 20% COLOR YELLOW INTENSITY: DULL CUT: DARK STRAW ( WHITE FLUORESCENT MUD FLUORESCENCE DULL YELLOW, NO FREE OIL ON PITS, SLIGHT SHEEN ON MUD FORMATION DESCRIPTION: Sand: consists of a slurry of loose silt and sand; medium olive gray; fair to good cohesion; no plasticity except in clayey zones; very well sorted; lower very fine - to locally fine - grained; finer fraction almost entirely light gray quartz grading to silt; larger grains have a salt and pepper appearance and consists of very light gray quartz with lesser dark gray to black siliceous lithics; minor blue -green glauconite, and trace pyrite; fine - grained sand is subrounded with moderate sphericity; rare intact hard sandstone cuttings are cemented by white calcite; overall moderately calcareous; trace light brown oil stain and rare microscopic tarry blobs; no odor; nearly imperceptible sheen; 30% to 40% even dull yellow fluorescence in fluid portion and 10% to 20% scattered dull yellow fluorescence in cuttings; dark straw fluorescence cuts bright white; moderate brown residue with moderate yellow fluorescence; high gas = coarser grain. SHOW RATING: (T,P,F,G) FAIR • LOGGING GEOLOGIST(S): Dan Grunwald /John Lundy • ANRIG SHOW REPORT NO. 4 DRILLI\G TECHNOLOGT LTD. ENI Petroleum Date: 4/28/2010 OP23 -WW2 Nikaitchuq, Oliktok Point, Alaska DEPTH INTERVAL: 11595 TO 11700 (MD) TOTAL FTG 105 8829 TO 8933 (TVD) BIT INFORMATION: BIT TYPE- HYCALOG DTX519M, 6x13 BIT HOURS- 31 DURING AVERAGES: BEFORE AVERAGE MAXIMUM ( AFTER I ROP (fph) 131.8 118 192 76 WOB 6.3 8.2 10 10.9 RPM 105 110 111 114 MUD WT 10.4 10.4/10.35 10.4 9.35 CHLORIDE TOTAL GAS 82 81 173 21 • C1 (ppm) 17003 15652 34884 3530 C2 (ppm) 592 518 1106 335 C3 (ppm) 255 172 395 91 C4 (ppm) 140 85 172 3.4 C5 (ppm) 50 35 146 0 RATIO ROP INCREASE TO GAS INCREASE: 61/91 SAMPLE CUTTINGS FLUORESENCE%: 10% COLOR YELLOW INTENSITY: Medium CUT: Yellow -White MUD FLUORESCENCE Slight increase over backgound oil bas mud fluorescence FORMATION DESCRIPTION: Sandstone /sandy siltstone; Medium light gray; slight brownish scondary hue; firm to dis aggregated; sample recovered primarily as loose sand and occasional silty fragments; medium lower to fine upper grain ; sub - angular to sub - rounded and angular; translucent white to clear quartz sand predominates; trace to common dark mineral /lithic grains; common white calcareous inclusions; trace white ash /clay; very calcareous; common medium yellow fluorescence primarily in siltstone /sandy siltstone fragments; medium streaming cut to yellow white; very slight brownish residue ring, yellowish white residue fluorescent in the ring; medium yellow residue fluorescence in the center of the spot; cuts to yellow white; trace dark brown oil stain in silty framgents. SHOW RATING: (T,P,F,G) poor • LOGGING GEOLOGIST(S): John Lundy
