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211-032
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. cal [ - 03a Well History File Identifier Organizing(done) ❑ Two-sided II II IIIIII liii ❑ Rescan Needed III IthU 11111 FiSCAN DIGITAL DATA OVERSIZED (Scannable) /C'olor Items: ❑ Diskettes, No. ❑ Maps: ,❑/Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by VV a Large Scanner E Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: q/I/It.fr /s/ III P � Project Proofing II Illhl II III II III BY: Date: 1-7h pit. /s/ ili P Scanning Preparation 4. x 30 = (QO + 10 = TOTAL PAGES /0 (Count does not include cover sheet) riti BY: ACM Date: /� /s/ Production Scanning 11111111111111111 Stage 1 Page Count from Scanned File: 7/ (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: riI j /(-f' lsl VVI 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. 111111111111111 ReScanned I IIIIIIIIIIIIIII BY: Maria Date: /s! Comments about this file: Quality Checked II 111111111 11111 FO ,_ - T =o Z Z ZC..4 P., J 0 p co u�it) 03 E m EMZ o a o c• I i1fl >cin C L fl2 o °u V' S m� a ° Z Z Z QL 92 O L L p (0 < -E- o2 j 0 a m I o v 2 m a° 0 0 >I ° ° m U U Z 2 co o) a) re ce ce re U 0 - w Z Z Z • y o _ N Z Z Z w E 11 CI z w c _ _ E } } } m LL N O U V C7 co ca a tco 0 u .--.._. To co H U co vN a m £ m *�� �W NNZ O 0 Ce 0. O c «II' oi @ LL E N'I — N V O W m_ m m rn a j V Z > E J E co W C Vco N N // IICEZ 6. Zo Z re oo a m N _ 1 J a 'o m .CD 7 -0 ..._ co'0 c ZI Jm• 2 Nlelb Oa) m cc cc cc to coE a o U 03 J N } } } l' 0 oCD 0 I_— I u) o co m c Z, 1 C a W 0 M C O T ,,.. 1 /= = N III w t0 Y_ I C C O r J Z O@ U N Q a ZI ! oo 03 O Z O o o T £ U o O 2 co m 2 d Z Z Z + o Z C Z Z Z 'ZI5` rnw , G C N > OZ J y I W1. t0 'd meso W E a d N O O p W C Z d W O m H 10 O. m p C t2 > Z2 V £ •C+ £ W E O N N p` a)v N Z H . F m I N v CI o y Q 2 c o W u. m N G d ` o p c ca — - I Z W p O n .� •� E G H J 0 P. 0 0 F m d o)�° a d O E o aa) E o d D 12; 3 J G H 3 z 0 d 0 0 10 McMains, Stephen E (DOA) VINE= From: Davies, Stephen F (DOA) Sent: Thursday, April 21, 2011 4:41 PM To: McMains, Stephen E (DOA) Subject: FW: OP15-08 Permit No: 211-032 -Withdraw FYI 1f t1 — J3_ From: Longo Joseph f mailto:joe.longo@enipetroleum.coml Sent: Thursday, April 21, 2011 4:09 PM To: Davies, Stephen F (DOA) Subject: OP15-08 Permit No: 211-032 - Withdraw Steve, Eni US Operating Co. Inc. would like to withdraw the permit to drill for OP15-08 (Permit No: 211-032). The slot location has been changed to OP18-08. I apologize for any confusion. If you have any questions please do not hesitate to ask. Regards, Joseph Longo Drilling Engineer Anchorage, AK Office (Anchorage): (907) 865-3323 Office (North Slope): (907) 685-1226 Cell: (907) 947-4323 Email: Joseph.Longo©enipetroleum.com Message for the recipient only, if received in error, please notify the sender and read http://www.eni.it/disclaimer/ This message may contain information that is confidential, and is being sent exclusively to the Recipient. .w 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. 1 . ........... . fit �� LP\ a SEAN PARNELL,GOVERNOR rA\ O ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSIONT 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 Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Schrader Bluff Oil Pool, OP15-08 ENI US Operation Co. Inc. Permit No: 211-032 Surface Location: 3163.8' FSL, 1639.8' FEL, SEC. 05, T13N, R9E, UM Bottomhole Location: 798' FSL, 1220' FEL, SEC. 26, T14N, R8E, UM Dear Mr. Grandi: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 40) Danie . Seamount, Jr. Ch,it DATED this( day of March, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALP , OIL AND GAS CONSERVATION COM SION PERMIT TO DRILL 20 AAC 25.005 1 a.Type of Work: lb. Proposed Well Clax Development-Oil 1:1, Service- Winj ❑ Single Zone 0 1 c.Specify if well is proposed for: Drill 0•RedrillEl Stratigraphic Test ElDevelopment-Gas ElService-Supply 0 Multiple Zone ElCoalbed Gas ElGas Hydrates El Re-entry❑ Exploratory ❑ Service- WAG 0 Service-Disp 0 Shale Gas 0 2.Operator Name: 5. Bond: Blanket Q Single Well 0 11.Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627 • OP15-08 • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 18930' • TVD: 3437' • Nikaitchuq jIK 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): 454LC.f 0,1 Surface: 3163.8 FSL 1639.8 FEL S5 T13N R9E UM ADL 355024,373301,391283,388577 • AD 3.1 7/ Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 2908 FSL 1636 FEL 36 T14N R8EUM ADL 417493 4/1/2011 Total Depth: 9,Acres in Property: 14. Distance to Nearest Property: 798 FSL 1220 FEL 26 T14N R8EUM 1280 6079'to unit boundary 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 53.2 feet 15. Distance to Nearest Well Open Surface:x 516640 • y- 6036517• Zone- 4 GL Elevation above MSL: 12 feet to Same Pool: 1965'East to OP17-02 16.Deviated wells: Kickoff depth: 300 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 90° degrees Downhole:1544 psig . Surface: 1158 psig • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling _ Length MD TVD MD TVD (including stage data) Driven 20" 178.89 X-65 Welded 84 36 36 120 120 pre-installed 16" 13-3/8" 68 L-80 BTC 2655 35 35 2690 2173 1223 sx 10.7#ASL,230 sx 12.5#Deeperete 12.25" 9-5/8" 40 L-80 Hydril 563 13066 33 33 13099 3499 717 sx 12.5#Deeperete 8.5" 5.5" 17 L-80 Hydril 521 6031 12899 3481 18930 3437 Slotted liner in open hole 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect. Depth MD(ft): Effect. Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat 0 BOP Sketch ❑✓ Drilling Program Q Time v. Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report ❑Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct. Contact Jason Brink @ 907-865-3321 Printed Name Maurizio Grandi Title Well Operation Project Manager Signature NIL t_ Phone Date 2 (2 L 14 I Commission Use Only Permit to Drill �7 API Number: �' Permit Ap val See cover letter for other Number: 2//d�i� 50-02-.9-2.34/V, Date: r6 1 li j requirements. Conditions of approval: If box is checked,wellelmaay not be used to explore for,test,or produce coalbed methane, as hydrates,or gas contained in shales: Other: • 3500 la.5- 13O P I st,--�-' Samples req'd: Yes❑ No[' Mud log req'd: Yes 0 No[t1 A zoo p S L A ri K tt,(a-ir !e$1 t(Fl... ,H2S measures: Yes❑ Nod Directional svy req'd: Yes []/No 0 - b Jut.r 4--t-fp 1n/�i u .,0 r,ru Z c dl Z 0 3 S Ch)(z) - SYS r /€z.t-C PY%.e,r•J ca.rloIra vJ p 20 /10'C 2 5.Z6 S �a) 0 )1 ] /(( DATE: S-f"---r°'" APPROVED BY THE COMMISSION ,COMMISSIONER Fon,1 - (kepis AN9ALThis permit is valid for 24 months om the date of approval j2 AAC 25.005(g)) Submit i tate V4' RECEIVED liosi II i ') ttroIIaulm PEB 28 Alii Alaska Oil&Gas Canso Consnission anchorage 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi@enipetroleum.com February 25,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer OP15-08 Dear Commissioners, ENI US Operating Co. Inc.hereby applies for a Permit to Drill for the onshore production well OP15-08. The well will be drilled and completed using Nabors rig 245E. The planned spud date is 4/1/2011. • 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. Sincerely, AilL 4"ALS Maurizio Grandi Well Operation Project Manager I Oliktok Point Nikaitchuq Field o ' en petolleum OP15-08 (P7) Alaska DIR I LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD I TVD SIZE SPECS Hazards Cement to Surface 20" X-65 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res ,I Surface Csq Dir v 13-3/8" Ca Base Permafrost 2,025' 1,778' y 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor r L-80,BTC 8.8-9.5 Lost Circulation Hole Cleaning L13-318"Casing Point 2,690' 2,173' i 16" 50°F WBM GR/RES PWD Inter.Casing Wellbore Stability 9-5/8" Lost Circulation Powerdrive X5 40 lbs/ft MW(ppg) Hole Cleaning L-80,Hydril 563 9.2-9.6 Torque&Drag TOC 10,818' 3,248' — ir- 11: "N"Sand Top 11,818' 3,376' .1111111.7-- TOL 12,899' 1 MEM 9-518"Casing Point 13,099' 3,499' 12-1/4" 85"F LSND GR/RES Periscope/PWD Wellbore Stability Neutron/Density Lost Circulation Schrader Bluff Slotted Liner Hole Cleaning Lateral 5-1/2" Torque&Drag 17 lbs/ft MW(ppg) Xceed 675 L-80,Hydril 521 9.4 (Geo-Steering) 5-1/2"Slotted Liner TD/5-112"Lnr 18,930' 3,436' 8-3/4" 85"F MOBM riffs tr ieui _eat Application for Permit to Drill Saved:25-Feb-11 Application for Permit to Drill Document Producer Well OP15-08 Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(t) 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 4 Requirements of 20 AAC 25.005(c)(5) 4 6. Casing and Cementing Program 4 Requirements of 20 AAC 25.005(c)(6) 4 7. Diverter System Information 4 Requirements of 20 AAC 25.005(c)(7) 4 8. Drilling Fluid Program 5 Requirements of 20 AAC 25.005(c)(8) 5 Surface Hole Mud Program (extended bentonite) 5 Intermediate Hole Mud Program(LSND) 5 Lateral Mud Program (MI VersaPro LS Mineral Oil Base) 5 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005(c)(9) 5 10.Seismic Analysis 6 Requirements of 20 AAC 25.005(c)(10) 6 11.Seabed Condition Analysis 6 Requirements of 20 AAC 25.005(c)(11) 6 OP15-08 PERMIT Document.doc Page 1 of 7 Printed:25-Feb-11 ...... Timot Eni - tir .Ieui lent Application for Permit to Drill Saved:25-Feb-11 12.Evidence of Bonding 6 Requirements of 20 AAC 25.005(c)(12) 6 13.Proposed Drilling Program 6 Requirements of 20 AAC 25.005(c)(13) 6 14.Discussion of Mud and Cuttings Disposal and Annular Disposal 7 Requirements of 20 AAC 25.005(c)(14) 7 15.Attachments 7 Attachment 1 Directional Plan 7 Attachment 2 Drilling Hazards Summary 7 Attachment 3 BOP and Diverter Configuration 7 Attachment 4 Cement Loads and CemCADE Summary 7 Attachment 5 Well Schematic 7 Attachment 6 Formation Integrity And Leak Off Test Procedure 7 Attachment 7 Surface Platt 7 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(6). 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 assigned to the well by the commission. Well Name: OP15-08 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 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 fines. (5)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 3163.8 FSL 1639.8 FEL S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.2'AMSL Northings 6036516.89', Eastings: 516640.37 • Pad Elevation 12'AMSL Location at Top of / Productive Interval 2908 FSL 1636 FEL 36 T14N R8EUM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 13099' Northings: 6041524.6' Eastings:506205.2' Tota/Vertical Depth, RKB: 3499' Total Vertical Depth, 55: 3446' OP15-08 PERMIT Document.doc Page 2 of 7 Printed:25-Feb-11 Igik . ,- - _ JL limp troII Urn Application for Permit to Drill Saved:25-Feb-11 Location at Total Depth 798 FSL 1220 FEL 26 T14N R8EUM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 18930' Northings: 6044691.7 Eastings: 501338.5 Total Vertical Depth, RKB: 3436' Total Vertical Depth, SS:: 3384' Please see Attachment 7: Surface Platt and (D)other information required by 20 AAC 25.050(6); 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 wellbore (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 already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 MC 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 downhole pressure that may be encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressure in the Schrader Bluff sand is 0.44 psi/ft, or 8.5 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 OA sand formation is: MPSP = (3511 ft TVD)(0.44 - 0.11 psi/ft) = 1,158 psi 1 (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and OP15-08 PERMIT Document.doc Page 3 of 7 Printed:25-Feb-11 *14 - ' 0 [111111 ' tr4eur _en_ Application for Permit to Drill Saved:25-Feb-11 (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. 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 MC 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 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 MC 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) (Ib/ft) Grade Connecti (ft) (ft) (ft) Cement Program on 20 178.89 X-65 Welded 120 36/ 36 120'/ 120' Cemented to surface Cemented to Surface with 1223 sx 10.7#ASLite Lead j Yield 2.33-cu. Ft./sk, 13-3/8 16 68 L-80 BTC 2655' 35/ 35 2690'/ 2173' 230 sx 12.5# DeepCRETE Tail --Yield 1.54 cu.ft./sk Cement Top planned @ 10818'MD H drll Cemented w/717 sx 12.5# 9-5/8 12-1/4 40 L-80 563 13066' 33/ 33 13099'/ 3499' YieId1 54cu.DeepCRETEftsk 8-3/4"OA Hydril ./5-1/2 Sand 17 L-80 521 6031' 12899'/ 3481' 18930'/ 3437' Slotted Liner-no cement Lateral 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 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); Please see Attachment 3: BOP Configuration. / ENI requests that AOGCC waive diverter requirements per 20 MC 25.035. (h). (2). ✓ ��c OP15-08 PERMIT Document.doc Page 4 of 7 Printed:25-Feb-11 l.... Enli - trHeurn ..ent Application for Permit to Drill Saved:25-Feb-11 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 9.5 Funnel Viscosity 150 250 200 300 (seconds) Yield Point 50 70 30 50 (Ib/100 sf) Plastic Viscostiy 30 55 15 20 (CP) pH 9.0 9.5 9.0 9.5 API Filtrate NC 8.0 8.0 8.0 (cc/30 min)) Intermediate Hole Mud Program(LSND) Lateral Mud Program (MI FazePro LS Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point _ Value Value Density(ppg) 9.4 • Density(ppg) 8.8 - 9.5 4 Plastic Viscostiy 15-25 • Funnel Viscosity (CP) 45 - 60 (seconds) Yield Point 15-20 Plastic Viscostiy 12 - 18 (lb/100 st) (CP) HTHP Fluid loss Yield Point 18.24 (ml/30 min @ <5.0 (lb/100 st) 200psi& 100°F API Filtrate Oil/Water Ratio 75/25 (cc/30 min)) 4 - 6 Electrical >600 Chlorides(mg/1) <500 Stability pH 9.0- 10.0 MBT <18.0 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 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: (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 25.0330; Not applicable: Application is not for an exploratory or stratigraphic test well. OP15-08 PERMIT Document.doc Page 5 of 7 Printed:25-Feb-11 w. Enii - tir o Ileum ient Application for Permit to Drill Saved:25-Feb-11 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 MC 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 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. 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. ' btJ tr ln/'2- ` . 2. Spud and directionally drill 16" hole to casing point 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. Pump cement and displace with mud, land casing hanger and bump plug. • 4. Install and test wellhead to 5000 PSI. - 5. Nipple up 13-5/8"5K BOP and test to 3500 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 directional drilling assembly with MWD, LWD and PWD. • 8. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording • results. 9. Directionally drill to 9-5/8"casing point per directional plan. Pull out of hole backreaming to the surface • casing shoe. 10. Install 9-5/8"casing rams in the BOP and test to 3500 PSI. - 11. Run and cement 9-5/8", 40# L80, Hydril 563 casing. Pump cement and displace with mud, land casing - hanger and bump plug. 12. Install 9-5/8"packoff and test to 5000 psi. OP15-08 PERMIT Document.doc Page 6 of 7 Printed:25-Feb-11 1rPlitt, • EnH (IF . H � Iuurn' Application for Permit to Drill Saved:25-Feb-11 13. Flush 13-3/8"x 9-5/8"annulus with diesel freeze protect. 14. Pressure test casing to 3000 psi per AOGCC regulations. Record results. • 15. PU 8-3/4"bit and directional drilling assembly including MWD, LWD, PWD and rotary steerable tool. RIH, clean out cement to top of float equipment. 16. Drill out cement and between 20'and 50' of new hole. Perform formation integrity test, recording . results. 17. Directionally drill 8-3/4" hole to TD as per directional plan. Pull out of hole backreaming to casing shoe. .• 18. PU and run 5-1/2"slotted 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. PU ESP completion as required and RIH to depth. Land tubing. Set BPV 21. Nipple down BOP, nipple up tree and test. Pull BPV. • / • ENI requests that the AOGCC waive surface safety valve requirements per 20 AAC 25.265. (c). ✓ (1). • The Vetco horizontal wellhead utilized physically prevents locating the SSV in the vertical run of the tree as there is no vertical tree on this wellhead. • Wellhead schematics should be on file with the AOGCC. 22. Freeze protect well with diesel by pumping into 4-1/2"x 9-5/8"annulus, taking returns from tubing. 23. Set BPV and Move rig off. 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 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. 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 OP15-08 PERMIT Document.doc Page 7 of 7 Printed:25-Feb-11 M O Cm g M rM rrM R-022 n m M nN 0 2,'z!;`4,7 :12;28 mdmM 8 mmm m m W r m °2..,2( mm d Y GOImhill Um NNoN NOm WWroWW mz0N )NC W d b N m N m N b m N h m N h m N m h N N N N N N m b y N m m m N O C b N m V)N m N • Q N N^ m N O M N W N W 'm O r d n N H.:::, ^m m m W FNg000 !!:!! 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Q� p"O 1„ssest O • bSis S6fI ' •�16fsr °�� • 00. °�yrb • O0 N r4 N Wf. Sf I afi • 11 i' I '• r •°� r !rb • v1 leer Nr a • •el` 0 00 SL 0 _ �,s •e4 0 o 0 = sr Q V O°9f'f M I!36f " t F ili, • C C �' •e� rbf '° a0 7�9Gbf CO 84 c0 ° •o q,. • �ID 9fda' ��z6r,.f f • °41 O. I off I Q � 0 0 0 0 0 " o CO(O N s 0 11 «< N (3D)000Z:(u!)I. = a!eoS s >>> row* no Schlumberger WE" OP15-08 (P7) F'a° Nikaitchuq S1RUCTURE Oliktok Point MOOS Pere 0M2 Su8leca L®tim NI°D1]Aleeae Stele Ple0 Zane b.US Feel Mbcelbrean MOO. BGGM 2010 Dig: 81004° Vele. n1031011 let- N ]03038431 E..l g: Bro881009 US GM Cdx:011838851° P00 OP15 ND Rat: Rabo702.212aeao,MSL) Meg Dec: 21.1]8° FS: 57840 3n7 Lan'. W 148 51 48 784 Ewa, 518810.V it. Sc.fact:0 NO90031 Plan: OPIO.(P7) Srv]0.114 F.,,,,02.2011 OP23-WW02 0P08-04PB1 -800 -600 -400 -200 0 0P08-04 200 0P09-S03(P2) 1200 - el1. P3aP12:0 ( )- - \ : IPB1 1200 O0407 6P26-DSP02 0 4�0• OP10-09(P6) 5wnm • OP14-07PB1 499TVD • 2g99;ND • 1000 -\\\ N r— 2999 rvD. 1000 I® I►` 1 249TVD • 74F 19• TVD • ti1 e'-' k 800 - \ - 800 0 ok Point 1-2 A ,:•�• A •li' •k Point I-2PB �D • 952 t 1999 ND• Z • Oli' •k Point I-2P:', \ , OP10-09 w• ng OP21-WW01 (P1b) $ 600 - L - 600 O , �D N OI 1: v •` 11.r 0' -08(' II kilikill o. 1a99• .� 2�9 TVD •• �s,, 9 P03-P05 U400 - `' ' __,..+a9ry 400 Ill ` \ X494' a • IT 0P03-P05PB1 OP17-1'-:1i ` •..•ND • ,Soo OP03-P05PB2 D I v OP17-021., 99�D A 1,.. . o 200 � _ _ • lik.... .. ..T_ , • 200 0118-07(- � �• ,�,, '�ri� 0107-04 ......141, V iir. i , c ti \ : , ,h Cliktok Point I-1 OP16-03(P6) .� . \, �;r;1 •. t iktok Point I-1M06(P5) I $ g h 5 �• S OP05-06 IWO k g OP05-06PB1 m OP05-06PB2 999TVD• OP26-DSPO2 0106-05(P9) -200 _. I I - -200 -800 -600 -400 -200 0 200 <<< W Scale = 1(in):200(ft) E >>> Schlumberger OP15-08 (P7) Anti-Collision Summary Report Analysis Date-24hr Time: February 15,2011-07:47 Analysis Method: Normal Plane Client: ENI Reference Trajectory: OP15.08(P7)(Def Plan) Field: Nlkaitchuq Depth Interval: Every 5.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: D&M AntiCollision Standard Slot: OP15 Min Pts: All local minima indicated. Well: OP15.08 Borehole: OP15.08 Offset Trajectories Summary Offset Selection Criteria Wellhead distance scan: Restricted within 41010.5 ft Selection filters: Definitive Surveys-Definitive Plans-Definitive surveys exclude definitive plans -All Non-Def Surveys when no Del-Survey is set in a borehole-All Non-Def Plans when no Def-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major OP16-03(P6)(Del Plan) Warning Alert 7.99 6.76 4.66 N/A 0.00 0.00 Surface 7.99 5.39 466 4.91 245.00 245.00 OSF<5.00 Enter Alen 1 7.41 3.22 1.74 2.09 390.05 390.01 MinPt-CtCt 7.73 2.66 0.73 1.69 424.96 424.84 MInPt-O-EOU 8.00 2.69 0.64 1.66 434.92 434.77 MinPt-O-ADP 8.16 2.74 0.65 1.651 439.89 439.73 MinPt-O-SF 65.81 51.67 45.20 5.00 884.23 852.34 OSF>5.00 Exit Alert 1224.95 978.67 856.02 4.99 11124.55 3288.79 OSF<5.00 Enter Alert 686 641 398.74 255.28 2.39 13883.45 3503.81 MinPt-CtCt 696 87 384.421 228.69 2.23 14936.28 3455.12 MinPt-O-EOU 697.26 3844 L 228.601 2.23 14952.38 3454.74 MInPt-O-ADP 697.99 384.84 228.75 2.231 14972.51 3454.26 MinPt-O-SF 862.4611 538.051 376.34 2.66 16204.83 3451.28 MinPt-O-EOU 862.64 538.061 376.2611 2.68 18210.31 3451.27 MinPt-O-ADP 11® 485.86 308 15 2.37 17737.62 342128 MinPt-CtCt 846 70 478.98]®�, 18291.65 3429.27 MinPts 0114-08(P2)(Def Plan) Warning Alert 8.04 6.82 4.72 N/A 0.00 0.00 Surface 8.04 5.45 4.72 4.96 245.00 245.00 OSF<5.00 Enter Alert 541 4.70 4.83 250.00 250.00 MinPt-CtCt 8.1.MIIKI 4.47 4.30 284.97 284.97 MinPt-O-EOU 8.11 5 28 MIMIED 4.27 289.97 289.97 MinPt-O-ADP 8.1 jjilill 446 4.22 309.95 309.95 MinPt-O-EOU 8.19 529 4 46 4.16 329.93 329.93 MinPt-O-ADP 8.2'MEM 4.44 4.09 359.89 359.87 MinPt-O-EOU 8.26 5.30 4.44 4.07 364.88 364.86 MinPt-O-ADP 9.4r. 4.89. 3.25 2.49 484.45 484.07 MinPt-O-EOU 10.38 161 2.55 2.08 534.19 533.38 MinPt-O-EOU 11.30 4.91 I® 1.95 568.96 567.71 MinPt-O-ADP 11.60 5.04 2.37 11111 578.88 577.49 MinPt-O-SF 12.79 5.65 2.6•IIIMIEZ 613.60 611.60 MinPt-O-SF 48.26 37.62 32 92 5.00 1093.45 1060.41 OSF>5.00 Exit Alert 281.3'Iliiiiiiiii "O'1 220.06 6.97 3066.74 2290.37 MinPt-O-EOU 282.40 240.3 11 1111.11:01 6.86 3098.71 2296.35 MinPt-O-ADP 383.66 306.13 267.86 5.00 4616.57 2485.85 OSF<5.00 Enter Alert 953.47 67449 535 50 3.43': 12001.63 3397.00 MinPt-O-SF I 1037.580 667.23) 482.5 2.81 17909.86 3423.45 MinPts 0113-03(P3)(Def Plan) Warning Alert 16.04 14.81 12.71 N/A 0.00 0.00 Surface 16.04 13.40 12.70 10.51 250.00 250.00 MinPt-ClCI 16.1011 8 12.43 9.10 294.93 294.93 MInPI.O-EOU 16.16 12.40 8.83 309.90 309.90 MinPt-O-EOU 16.22 13.25 MEM 8.60 324.88 324.88 MinPt-O-ADP 16.40]® 12.40 8.18 354.82 354.81 MinPt-O-EOU 16.64 13.37 I® 7.55 379.72 379.69 MinPt-O-ADP 17.63 MBE 11.72 5.25 439.47 439.31 MinPt-O-EOU 17.85 1329 11.63 4.99 449.42 449.22 OSF<5.00 Enter Alert 18.76 13.501 4.35 484.27 483.88 MinPt-O-ADP 19.711 �„ 11.22 3.82 514.12 513.51 MinPt-O-EOU I 27. 'IIMIECig 6.36 1.98 673.08 669.67 MinPt-O-EOU 32.84 14.08® 1.80 742.09 736.38 MinPt-O-ADP 37.33 15.83 5.70 111 786.31 778.70 MinPt-O-SF 39.00 16.55 5.94 jlE 801.02 792.70 MinPt-O-SF 338.22 269.42 235.63 4.99 1799.21 1606.33 OSF>5.00 Exit Alert 3634.57 3351.43 3210.351' 12000.03 3396.80 MinPt-0-SF 3688.13 3400.92 3257.81:MIKE 12188.50 3418.23 MinPt-O-SF 4022.74 3675.51 3502.38 15672.14 3436.85 MinPt-O-SF 3066.68 2668.47 2469.86 7.72 18930.43 3436.20 TD ]MMIMMil 3667.30 3500.56 12.00 14957.55 3454.62 MinPt-CtCt 4004.16 3664.0 3494.44 11.80 15161.36 3449.32 MinPt-0-EOU 4005.87 3664.31 3494.0. 11.76 15225.20 3447.44 MinPt-O-ADP ]I®] 3666 27.MIME man 15417.54 3441.07 MinPte 0118-07(P7)(Def Plan) Warning Alert 23.98 22.76 20.65 N/A 0.00 0.00 Surface Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P15-08\0P15-08\OP15-08(P7) 2/15/2011 7:47 AM Page 1 of 6 1 • Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert 1 Minor I Major • 23.98 21.34 20.64 16.11 250.00 250.00 MinPt-C1Ct 24.01 21.27 20.50 14.98 275.06 275.06 MinPt-O-EOU 24.03 21.27 20.50 14.83 280.07 280.07 MinPt-O-ADP • 24.33 21.501 20.69 14.388 330.19 330.18 MinPt-O-SF 26.04 22.4ta 21.19 10.26 425.63 425.51 MinPt-O-ADP 29.62 24.1 22.04 6.70 510.93 510.34 MinPt-O-ADP 33.49 25.71 22.43 4.92 570.98 569.71 OSF<5.00 Enter Alert 54.73 35.77 26.911 3.021 781.20 773.83 MinPt-OSF 98.00 77.36 67.65 4.98 1105.73 1071.14 OSF>5.00 Exit Alert 333.86 288.81 266.89 ;I 2608.44 2134.84 MinPt-O-SF 2162.05 1886.71 1749.53 ' 11939.43 3389.32 MinPt-O-SF 1.111M1J 1466181®; 96 15492.91 3438.80 MinPts 1875.35 1544.91 1380.18 MIZE 16209.27 3451.27 MinPt-o-SF 1916.36 1578.27 1409.72 111111111113; 16591.98 3450.56 MinPt-O-SF 1963.14 1615.18 1441.70 Ziali 17096.25 3452.04 MinPt-O-SF 2017.71 MIME 1446.50®j 18770.50 3434.47 MinPts OP12-01(Def Survey) Wareing Alert MEM 38.801 36.691 152396.28 2.62 2.62 MinPts MEM 36.71 35.86 22.75 287.45 287.45 MinPt-CtCt 40.45 MEM 34.35 12.06 421.82 421.71 MinPt-O-EOU 40.86 36.06 MEE 11.08 441.69 441.52 MinPt-O-ADP 55.84 43.60 38.09 4.96 682.49 678.81 OSF<5.00 Enter Alert 69.56 53.39 45.9.�' 1 797.61 789.46 MinPt-O-SF 103.28 79.67 68. . 995.17 972.95 MinPt-OSF 126.19 96.82 82.75 EN= 1090.49 1057.82 MinPt-O-SF 159.23 126.37 110.55 4.99 1217.09 1166.12 OSF>5.00 Exit Alert 3813.94 3592.90 3482.8:' 10177.15 3171.90 MinPt-OSF 4380.38 4128.04 4002. 11381.96 3320.54 MinPt-O-SF OP17-02(Def Survey) Warning Alert 1 15.97 14 50 12.651 N/A 0.00 0.00 MinPts 16.54, 14 51 13.22 18.86 198.94 198.94 MinPt-O-EOU 16.64 14.50 13.31 16.84 208.93 208.93 MinPt-O-EOU 26.96 21.72 19.71 MIKE. 442.61 442.44 MinPt-O-SF 190.49 171.43 162.52®''- 1064.42 1034.88 MinPt-O-SF 652 231 630.66 620.41 31.76 2687.60 2170.74 MinPts t 9 1 803.34 590.59 24.67 3058.01 2288.63 MinPt-CtCI 629.9 603.201_ 590.33 24.44 3074.38 2291.86 MinPt-O-EOU 630.02 603.22.1 24.37 3079.36 2292.81 MinPt-O-ADP 806.53 724.84 684.48=KM 6905.60 2768.26 MinPt-O-SF 634.06._ 551.02 509.99 7.71 8499.79 2964.95 MinPt-CtCt 644.39 540.42 488.93 6.25 8747.02 2995.45 MinPt-O-EOU 663.26 544.40 485.461 5.62 8920.14 3016.81 MinPl-O-ADP 720.73 575.62 503.55 4.99 9161.12 3046.54 OSF<5.00 Enter Alen 888.30 694.39 597.931 4.6J 9837.38 3129.98 MinPt-O-SF 1114.26 890.51 779.12 5.00 10431.99 3203.34 OSF>5.00 Exit Alert 2470. `NEM 1995.05 7.81 13698.77 3503.70 MinPt-O-EOU 2470.69 2153.2 1995.03. 7.80 13707.65 3503.65 MinPt-O-ADP 2473.56 2147.80 1985.41 7.81 14032.65 3501.56 MinPt-CtCt 2474.5 2146.411 1982 81 7.56 14129.92 3497.55 MinPt-O-EOU 2475.45 2146.60 1982.671 7.55 14157.71 3495.80 MinPt-O-ADP 1987.00 1588.81 1390.21 5.00 17503.86 3432.03 OSF<5.00 Enter Alert FT-1968 1569.091 1370.071 4.941 17538.91 3429.71 MinPts OPt7-02PB1(Def Survey) Warning Alert 1 15.97 14.75 12.651 261527.42 0.00 0.00 MinPts 16.46 14 371 13.13 17.52 188.94 188.94 MinPt-O-EOU 16.641--777 13.31 14.64 208.93 208.93 MinPt-O-EOU 26.47 21 26 19.26 437.70 437.54 MinPt-O-SF 190.49 171 40 162.46' 1064.42 1034.88 MinPt-O-SF 652.23F 630 651__ 620 39 31.74 2687.60 2170.74 MinPts 629 81 603.33 590.59 24.67 3058.01 2288.63 MinPt-CtCt 629.93 603 20 590.33 24.43 3074.38 2291.86 MinPt-O-EOU 630.02 603.222 r 24.37 3079.36 2292.81 MinPt-O-ADP 806.53 724 84 684 49 9 981 6905.60 2768.26 MinPt-O-SF 634.06 551 01 509 98 7.71 8499.79 2964.95 MinPt-CtCt 656.79 IIIIIIEMS 475 67 5.46 8922.23 3017.07 MinPt-O-EOU 674.02 538.30 470.94 5.009079.73 3036.50 OSF<5.00 Enter Alert 683.68 540.8711 469.96 4.81 9164.16 3046.92 MinPt-O-ADP 795.14 614.45 524 591 4.4 9674.47 3109.88 MinPt-O-SF 1144.11 914.37 799.95 5.00 10587.31 3222.50 OSF>5.00 Exit Alert 2408.77 2091.26 1933.00 7.61 13697.87 3503.70 MinPt-O-ADP 2452.27 2121.31 mom 7.43 14233.50 3490.07 MinPt-O-ADP II 245111 2108.19 193723 7.17 14725.63 3460.00 MinPt-CtCt 2451.971 2107.661 1936.00 7.14 14780.60 3458.73 MinPt-O-EOU 1974.19 1578.44 1381.06 5.00 17390.08 3439.55 OSF<5.00 Enter Alen II 1704 181 1287.071 1079.011 4.091 18264.13 3428.97 MinPts OP21-WW01(P1b)(Def Plan) Pass 55.97 54.75 52.64 N/A 0.00 0.00 Surface r 51.86 44.53 41.47 8.29 561.08 559.95 MinPt-CtCt 52.87 43.42 39.31 6.28 614.99 612.96 MinPt-O-EOU 53.81 43.59 39.10 5.85 634.41 631.97 MinPt-O-ADP 59.36 46.87 41.24 5.161 697.36 693.23 MinPt-O-SF 8784.44 8758.87 8746.58 357.24 2931.64 2257.95 TD OP23-WW02(Def Survey) I Pass Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP15-08\OP15-08\OP15-08(P7) 2/15/2011 7:47 AM Page 2 of 6 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft) EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 65.43 58.06 54.99 10.46 595.62 593.96 MinPt-CtCt 66.79 56.80 52.42 7.48 659.05 656.02 MinPt-O-EOU 67.80 56.99 52.19 6.94 678.57 675.01 MinPt-0-ADP 70.34 58.52 53.23 8.52 712.43 707.80 MinPt-O-SF 1099.74 1081.54 1073.06 64.71 2297.93 1960.47 MinPt-0-SF 9306.30 9257.23 9233.19 193.51 4771.60 2504.97 TD • OP10-09 working(Non-Def Survey) Pees 1 56.021 54.801 52.701 283237.12 4.07 407 MinPte 56.42 54.33 53.09 63.78 199.07 199.07 MinP1-0-EOU 107.60 88.02 78.8 ',1111111111111111. 803.38 794.94 MinPt-0-SF 112.92 92.42 82.78 MEE 826.56 816.91 MinP1-0-SF 694.61 660.81 644.52 21.28 1870.34 1658.11 TD 0107-04(Def Survey) Pass 80.0 MIISMII76.69 N/A 3.88 3.88 MinPte 80.211 76.31 59.10 273.69 273.69 MinPt-0-EOU 80.24 76.98 NEM 58.07 283.62 283.62 MinPt-0-ADP 124.26 113.66 109.321 700.24 696.01 MinPt-0-SF 2307.63 2286.73 2277.231 5 2144.49 1856.16 MinPt-0-SF 2386.47 2364.94 2355.1.IME1131 2168.12 1872.94 MinPt-0-SF 3221.52 3191.42 3177.33 MEE 2361.02 2000.02 MinPt-0-SF 4373.61 4339.00 4322.66 M'' 2599.97 2130.78 MinPt-0SF 4982.28 4944.78 4926.91=gm 2773.93 2205.71 MinPt-0-SF 5432.94 5393.00 5373.92=nit 2900.13 2248.73 MinPt-0-SF 5463.41 5423.27 5404.07 NUM 2909.02 2251.39 MinPt-O-SF 5802.60 5759.98 5739.55 141.98 3028.44 2282.35 MinPt-0-SF 6827.94 6777.33 6752.91® 3480.70 2345.71 MinPt-0SF 7829.09 7770.13 7741.5 =UM 3940.63 2402.45 MinPt-0SF 9404.10 9329.83 9293.2 ',mEg6'i 4731.02 2499.97 MinPt-0SF OP09-S03(P2)(Def Plan) Pass 64.01 62.79 60.69 N/A 0.00 0.00 Surface Min 61.38 60.67 44.46 250.00 250.00 MinPt-CtCt 64.16 IIMED 60.34 36.28 304.65 304.65 MinPt-0-EOU 64.29 61.23®0• 34,35 324.52 324.51 MinPt-O-ADP 118.55 106.07 100. 764.30 757.88 MinPt-0-SF 129.67 116.02 109.80 mum 800.08 791.81 MinPt-0SF 358.98 323.22 305.9 1214.44 1163.90 MinPt-0-SF 4247.32 4185.38 4154.91 Man. 3575.47 2357.40 MinPt-O-SF 4384.56 4320.71 4289.2+=11111E. 3657.26 2367.49 MinPt-0-SF 4470.34 4405.27 4373.2 pjpp))136L!1 3708.38 2373.80 MinPt-0-SF 4556.13 4489.83 4457.1 j))))))))13 , 3759.50 2380.10 MinPt-0SF 5474.30 5394.52 5355.1 69.46 4306.44 2447.58 MinPt-0-SF I6553.39416405.36 6331.84 44.56 7819.65 2881.03 MinPt-CtCt 6553. 6404.6 6330.72 44.23 7873.85 2887.72 MinPt-0-EOU 6554.70 6404. 6330.551 44.05 7903.41 2891.37 MinPt-O-ADP 7615.72 723455 704445 20.03 1848221 3431.34 TD 7998.66 7675.02 7513.6924.791 15317.53 3444.51 MinPt-0-SF 799857 7674.951 7513.621 24.79 15331.62 3444.04 MinPte 7998.57 7674.95 7513.62 24.79 15334.43 3443.95 MinPt-CtCt 1 7999631 7675.751 7514.311 24.771 15418.92 3441.02 MinPte OP08-04(Def Survey) Pass 1 72.00 70.7/ 68.671 N/A 0.00 0.00 MinPts MinPt- 72.31` 70.12 68.98 74.12 183.90 183.90 O-EOU 146.99 127.75 118.74 MEC 801.88 793.53 MinPt-OSF 3588.07 3543.57 3521.81 MIKE, 3269.88 2319.69 MinPt-O-SF 3646.19 3600.98 3578.87 mEgs 3308.30 2324.43 MinPt-0-SF 4617.67 4562.98 4536.12 MEE 3829.58 2388.75 MinP1-0-SF 5541.43 iMBE 5407.09 62.32 5384.89 2580.64 MinPt-O-EOU 5542.18 5451 71 5406.96 61.92 5409.81 2583.71 MinPt-0-ADP 5561.84 5461.02® 55.70 5836.90 2638.41 MinPt-0-ADP 5668.39 5531.76 5463.94 41.78 7249.70 2810.71 MinPt-O-ADP 5681.97 5537.46 5465.70 MEW] 7548.27 2847.55 MinPt-0-SF OP08-04PB1(Def Survey) Pass 1 72.01 70.77 68671 N/A 0.00 0.00 MinPts 72.31 70.12 68.98 74.12 183.90 183.90 MinPt-0-EOU 146.99 127.75 118.74 8.09 801.88 793.53 MinPt-0-SF 3588.07 3543.57 3521.80 82.42 3269.88 2319.69 MinPt-0SF 3646.19 3600.98 3578.861_82.42 3308.30 2324.43 MinPt-0-SF 4617.67 4562.98 4536.121 85.95 3829.58 2388.75 MinPt-0-SF 5495.49 5410.03 5367.801 65.05 5181.38 2555.53 MinPt-0-5F 0106-05(P9)(Def Plan) Pass 96.01 94.79 9269 N/A 0.00 0.00 Surface 96.01 93.38 92.67 67.09 250.00 250.00 MinPt-CtCt 96.13®"maim55.46 299.53 299.53 MinPte 144.94 134.74 13024 16.00 700.79 696.55 MinPt-OSF 580.91 569.15 563.87'. 54.98' 1102.49 1068.31 MinPt-O-SF 2825.59 2808.26 2800.1,r- 1309.14 1241.29 MinPt-0-SF 2726.36 2709.58 2701.7311MM 1314.69 1245.73 MinPt-0-SF 5658.71 5624.17 5607.43!, 169.04 1337.88 1264.10 MinP1-0-SF 6186.95 6150.31 6132.491) 1428.48 1333.60 MinPt-0-SF 6860.07 6817.20 6796.26 4 1644.22 1492.95 MinPI-0-SF 714432 7097.29 7074.26',1111111111111 1757.00 1575.52 MinP1-0SF Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P15-08\0P15-08\0P15-08(P7) 2/15/2011 7:47 AM Page 3 of 6 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 7722.57 7666.02 7638.24 138.96 1990.07 1744.91 MinPt-O-SF 7983.51 7924.65 7895.71 137.921 2078.91 1809.01 MinPt-O-SF 8268.87 8208.58 8178.93 139.401 2148.89 1859.30 MinPt-O-SF 8373.84 8312.50 8282.32 138.73 2167.07 1872.20 MinPt-O-SF 9259.39 9191.28 9157.71 137.93 2336.41 1984.83 MinPt-O-SF 10101.99 10027.23 9990.35 136.9 2525.56 2093.41 MinPt-O-SF 1 10990.95 10909.34 10869.03 136.31 2776.44 2206.66 MinPt-O-SF 11161.12 11078.19 11037.224 136.1 2830.33 2226.14 MinPt-O-SF Oliktok Point I-2PB1(Def Survey) Pass 128.52 127.41 125.20 N/A 0.00 0.00 Surface ® 127.4111 125.2011 N/A 40.00 40.00 MinPts migm 121.49 119.91 39.33 488.68 488.27 MinPt-CtCt 118.3411 104.2811 97.81 9.06 840.62 830.17 MinPts 116.87 100.72 93.20 7.70 1290.90 1226.65 MinPt-CtCt 116.98 100.601 92.97 7.59 1312.11 1243.67 MinPt-O-EOU 117.19 100.64 92.93 7.52 1326.42 1255.05 MinPt-O-ADP 130.09 11068 101.53 7.05 1546.06 1420.77 MinPt-O-SF 163.23 mai 119.76 5.74 2061.63 1796.56 MinPt-O-EOU 164.03 134.02 MEM 5.64 2080.28 1809.99 MinPt-O-ADP 171.00 138.73 123.15 i8 2154.17 1863.06 MinPt-0-SF 309.22 255.41 229.0.] at] 3096.36 2295.94 MinPt-O-SF 1251.34 1162.28 1118.24 14 20 6487.29 2716.65 TD Oliktok Point 1-2(Def Survey) Pass 12852 127.41 125.20 NA 0-00 0-00 Surface ® /2741j1 125.2011 N/A 40.00 40.00 MinPts al 121.49 119.91 39.33 488.68 488.27 MinPt-CtCt M, 104 9.06 840.62 830.17 MinPts mum 100.72 93.20 7.70 1290.90 1226.65 M1nPt-CtCt 116.98 10060 92.97 7.59 1312.11 1243.67 MinPt-O-EOU 117.19 100.64 mzcm 7.52 1328.42 1255.05 MinPt-O-ADP 130.09 110.68 101.53 1546.06 1420.77 MinPt-O-SF 163.24 133.88 119.76 5.74 2061.63 1796.56 MinP1.0-EOU 164.03 134.02 119.57 5.64 2080.28 1809.99 MinPt-O-ADP 171.00 138.73 123.15 5.45 2154.17 1863.06 MinPt-O-SF 309.22 255.41 229.00 5.84 3096.36 2295.94 MinPt-O-SF 1438.66 1285.80 1209.85.. 9.47 7924.92 2894.02 MinPt-O-SF 2409.83 2180.83 2066.81 10.56 10305.95 3187.79 MinPt-O-SF 3103.36 2829.09 2692.45 11.35 11961.06 3391.99 TD Oliktok Point I-2P02(Def Survey) +$ ' Pass 128.52 127.54 125.20 N/A 0.00 0.00 Surface 1 127.41=MC1 N/A 40.00 40.00 MinPts mew 121.52 119.95 39.66 488.68 488.27 MinPt-CtCt 111J MIME 9.06 840.82 830.17 MinPts 100.72 93.21 7.70 1290.90 1226.65 MinPt-CtCt 116.98 100.61 92.98 7.59 1312.11 1243.67 MinPt-O-EOU 117.19 100.65 MEE 7.52 1326.42 1255.05 MinPt-0-ADP 130.09 11068 101.5 :IMO 1546.06 1420.77 MinPt-O-SF 163.23' 133 88 119.77 5 74 2061.63 1796.56 MinPt-0-EOU 164.03 134.02 119.57 5.64 2080.28 1809.99 MinPt-0-ADP 171.00 138.73 123.16 5.451 2154.17 1863.06 MinPt-0SF 309.22 255.42 229.01 5 8 3096.36 2295.94 MinPt-OSF 1438.66 1285.80 1209.86 94 77924.92 2894.02 MinPt-OSF 2009.41 1810.90 1712.13 10.17 9258.79 3058.59 TD OP05-06(Def Survey) Pass 103.77 101.89 100.45 155.09 153.94 153.94 MinPts 10a84 101.84 100.51 132.21 173.94 173.94 MinP1-0-EOU 189.11 158.93 154.45 MEE 699.06 694.87 MinPt-0SF 9300.10 9220.30 9180.89=Ho 1737.80 1561.49 MinPt-0-SF 9522.60 9440.81 9400.41 MEM 1785.25 1596.14 MinPt-0-SF 9733.17 9649.84 9608.6615 0 1826.82 1626.44 MinPt-0-SF 10042.61 9956.80 9914.381_'-r8- 1886.35 1669.74 MinPt-0SF 12467.77 12368.26 12319.00 126.54 2325.13 1977.76 TD 0P05-06P81(Def Survey) Pass 103.77 101.89 100.45 155 09 153.94 153.94 MinPts 103.84 101.8 100.51 132.21 173.94 173.94 MinPt-O-EOU 169.11 158.93 154.45 MEM 699.06 694.87 MinPt-O-SF 1720.39 1708.33 1702.81 155.74 1363.94 1284.49 TD n Il 1725.317'11___. ..j17(17.74 1151363.93 1284.49 MinPts OP05-06PB2(Def Survey) Pees 103.77 101.89 100.45 155.09 153.94 153.94 MinPts 103,84 101.84 100.51 132.21 173.94 173.94 MinPt-0-E01.J 169.11 158.93 154.45 MOM 699.06 694.87 MinPt-0-SF 9300.10 9220.30 9180.891MMO 1737.80 1561.49 MinPt-O-SF 9522.60 9440.81 9400.41 IMIE 1785.25 1596.14 MinPt-0-SF 9733.17 9649.84 9608.67;/ 1826.82 1626.44 MinPt-0-SF 10042.61 9956.80 9914.39 mug; 1886.35 1669.74 MinPt-O-SF 11069.59 10977.59 10932.0 min 2075.78 1806.75 MinPt-0SF 11121.58 11029.20 10983.50 121.67 2087.85 1815.44 TD OP03-P05PB7(Def Survey) IPass 1111111111111111311'-�- 118.62 116.60 1604.26 64.00 64.00 MinPts • • : Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\0P15-08\0P15-08\0P15-08(P7) 2/15/2011 7:47 AM Page 4 of 6 Offset Trajectory Separation'' Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft EOU EOU(ft) Dev.(ft)_ Fact. MD(ft) I TVD(ft) Alert I Minor I Major 120 03 117.80 116 7 118.47 244.00 244.00 MinPts 120 06 117.74 116.73 109.09 263.83 263.83 MinPt-O-EOU 175.12 164.23 159.391 723.29 718.29 MinPt-O-SF 4074.93 4053.90 4043.91 mg= 1756.33 1575.03 MinPt-O-SF 4547.80 4523.15 4511.36 MEM 1970.75 1730.93 MinPt-O-SE OP03-P05(Def Survey) Pass ® 118.62 116 601604 26 64.00 64.00 MinPts 120.03 117.801 116.701 11847 244.00 244.00 MinPts 120.06 117.74 116.73 109.09 263.83 263.83 MinP1-0-EOU 175.12 164.23 159.391 723.29 718.29 MinPt-O-SF 4029.05 4008.47 3998.711MMal 1734.54 1559.11 MinPt-O-SF 4473.51 4448.07 4435.: MHZ 1959.04 1722.45 MinPt-O-SF 5110.96 5081.11 5066.6:=ME 2170.39 1874.54 MinPt-O-SF 5518.03 5486.43 5471,1 1, 2253.69 1931.54 MinPt-O-SF 6005.13 5970.78 5954,091 2342.07 1988.35 MinPt-OSF 6224.27 6188.66 6171.351 2375.42 2008.77 MinPt-O-SF 6320.10 6283.98 6266.421 2394.89 2020.42 MinPt-O-SF 6359.73 6323.40 6305.731 2402.96 2025.19 MinPt-O-SF 6451.04 6414.05 6396.041.E 2420.73 2035.57 MinPt-O-SF 6757.15 6718.38 6699.491 2485.95 2072.25 MinPt-O-SF 7149.06 7107.63 7087.411'. 2590.45 2126.17 MinPt-O-SF 7284.83 7242.61 7222.00 176.66 2631.86 2145.83 MinPt-O-SF 8835.84 8783.45 8757.76 50 3119.52 2299.90 MinPt-O-SF 9436.70 9379.12 9350.8311 3392.85 2334.87 MinPt-O-SF OP03-P05PB2(Def Survey) '-' : k,7x/4,•t T Pass 1 118.62 116.60 1604.26 64.00 64.00 MinPts 120.0 117.8. 1167. 118.47 244.00 244.00 MinPts 120.06 117.74 116.73 109.09 263.83 283.83 MinPt-O-EOU 175.12 164.23 159.39 17.98 723.29 718.29 MinPt-O-SF 4029.05 4008.47 3998.71 206.41 1734.54 1559.11 MinPt-OSF 4473.51 4448.07 4435.84 182.89 1959.04 1722.45 MinPt-0SF 5110.96 5081.11 5066.68`7703 2170.39 1874.54 MinPt-O-SF 5518.03 5486.44 5471.13 180.25 2253.69 1931.54 MinPt-O-SF 6005.13 5970.78 5954.0 179.91 2342.07 1988.35 MinPt-O-SF 8224.27 6188.66 6171.35.. 179.71 2375.42 2008.77 MinPt-O-SF 6316.15 6280.06 6262.50, 179.88 2394.07 2019.93 MinPt-O-SF 6359.73 6323.40 6305.73. 179.88 2402.96 2025.19 MinPt-O-SF 6451.04 6414.05 6396.04 179.10 242073 2035.57 MinPt-0SF 6757.15 6718.39 6699.4 2485.95 2072.25 MinPt-O-SF 7129.42 7088.22 7068.1 2583.75 2122.90 MinPt-O-SF 7408.10 7365.05 7344.02 176,11/ 2665.63 2161.14 MinPt-O-SF OPO4-07(Def Survey) Pass 111.24 108.77 107.91 88.39 258.74 258.74 MinPts 111.25 108.73 107.93 84.54 273.57 273.57 MinPt-O-EOU 177.38 164.99 159.411 797.69 789.54 MinPt-O-SF 6392.55 6326.51 6293.9. -ziE'. 4365.94 2454.92 MinPt-O-SF 7109.81 7035.84 6999.351i 4755.20 2502.95 MinPt-O-SF 7369.44 7292.53 7254.56.1 4899.51 2520.75 MinPt-O-SF 8332.66 8243.75 8199.78 94.765489.45 2593.54 MinPt-O-SF 9587.27 9486.84 9437.12 96.40 6064.96 2664.55 MinPt-O-SF OPO4-07PB1(Def Survey) Pass 111.24 108.77 107.91 88.39 258.74 258.74 MinPts 111.25 108.73 107.93 84.54 273.57 273.57 MinPt-O-EOU 177.38 164.99 159.411 797.69 789.54 MinPt-O-SF 6392.55 6326.52 6294.0.i 4365.94 2454.92 MinPt-O-SF 7114.08 7040.07 7003.561. 4757.58 2503.24 MinPt-O-SF 7369.44 7292.54 7254.58®'' 4899.51 2520.75 MinPt-OSF 7851.09 7768.32 7727.42 95.981 5184.57 2555.92 MinPt-O-SF 8171.44 8085.17 8042.5211 5359.15 2577.46 MinPt-OSF OP10.09(P6)(Def Plan) Pass 56.02 54.80 52.70 N/A 0.00 0.00 Surface 1 53.39 52.69 38.95 249.07 249.07 MinPt-CtCt 56.12® 52.46 33.86 283.88 283.88 MinPt-0-EOU 56.18 53.291 32.93 293.83 293.83 MinPt-O-ADP 105.67 87.19 78.57 802.95 794.54 MinPt-O-SF 143.94 119.11 107.301 944.16 926.47 MinPt-O-SF 220.76 181.98 163.201 1142.48 1102.94 MinPt-OSF 4582.65 4360.24 4249.5 1-'., 9753.36 3119.61 MinPt-O-SF 4720.24 4491.68 4377.8.1 10159.18 3169.68 MinPt-O-SF 5120.84 4860.70 4731.1 111MM 12000.12 3396.81 MinPt-O•SF 5578.63 5250.93 5088.58IMM 15545.81 3437.73 MinPt-O-SF 4738.11 4350.67 4157.45 12.26 18905.28 3435.93 TD 5544 80 5226 55 5067.92 17.47 15060.11 3452.07 MinPt-CtCt 5545 52 5225.8 5066.48 17.40 15124.88 3450.34 MinPt-O-EOU 5546 22 5225.9: 5066 • 17.37 15151.88 3449.59 MinPt-0-ADP I1 5563 01IMMEI 5076.9._1 15416.41 3441.11 MinPts 0111-01(Def Survey) Pass 47.85 46.15 44.53 97.87 138.95 138.95 MinPts 48.22 45.89 44.89 42.36 258.91 258.91 MinPt-O-EOU 81.40 71.97 67.86 701.70 697.43 MinPt-O-SF 87.85 77.80 73.3'1 734.36 728.95 MinPt-0SF 235.54 203.53 188.13 man 1223.10 1171.12 MinPt-O-SF Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP15-08\0P15-08\0P15-08(P7) 2/15/2011 7:47 AM Page 5 of 6 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor Major 3085.69 3013.75 2978.27 43.4 4299.87 2446.77 MinPt-O-SF 3372.26 3295.21 3257.56 44.76 4556.44 2478.43 MlnPt-O-SF 4524.96 4364.24 4284.761 28.46 8460.37 2960.08 MinPt-O-SF OI11-01PB1(Def Survey) Pass 47.85 46.15 44.53 97.87 138.95 138.95 MinPts 48.22 45.89 44.89 42.36 258.91 258.91 MinPt-O-EOU 81.40 71.97 67.86 1111=8/1 701.70 697.43 MinPt-0-SF 87.85 77.80 73.3: 711:11 734.36 728.95 MinPt-O-SF 235.54 203.53 188.13 ieI 1223.10 1171.12 MinPt-O-SF 3085.69 3013.75 2978.27� 4299.87 2446.77 MinPt-O-SF 3787.15 3702.57 3660.77 IMIE 502220 2535.89 MinP1-0-SF Oliktok Point I-1(Def Survey) Pass 13656 134.64 133.23 N/A 0.00 0.00 Surface 136.56 134.64 133.23 378569.24 40.10 40.10 MinPts 136.86 134.54 133.34 652.56 84.20 84.20 MinPt-O-EOU 227.30 216.33 211 80 ME 701.40 697.13 MinPt-O-SF 2066.83 2052.41 2046.16 165.15 1266.73 1207.05 TD 7715.0. 7660.40 7634.05® 1194.98 1147.60 MinPts Oliktok Point 1-1A-106(P5)(Def Plan) Pass 136.56 134.64 133.23 N/A 0.00 0.00 Surface 136.56 134.64 133.23 378569.24 40.10 40.10 MinPts 136.66 134.54 133.34 652.55 84.20 84.20 MinPt-O-EOU 227.30 216.33 211.80 ME= 701.40 697.13 MinPt-O-SF 11646.80 11541.76 11489.7 =111111:E 1656.94 1502.29 MinPt-0SF 12216.07 12106.62 12052.391MN9s 1765.89 1582.02 MinPt-O-SF 13388.52 13269.66 13210.72 113.57 1971.48 1731.45 TD OP26-DSP02(Def Survey) Pass 11 295.571 293551 29224 N/A 3.99 3.99 MinPts 240.11 225.89 219.74 19.371 1040.72 1013.83 MinPt-O-SF 227.31 214.58 209.17 20.84 1222.47 1170.60 MinPt-O-ADP 227.26 214.58 209.19 20.93 1226.62 1174.04 MinPt-O-EOU 1 227.22 214.63 209.30 21.12 1234.88 1180.89 M1nPt-CtCt 624.80 604.46 595.2 MEM 2138.29 1851.71 MInPt-OSF 5271.61 5219.19 5193.86 104.03; 4552.45 2477.94 MinPt-O-SF OP25-DSPO1(P1)(Def Plan) Pass 1 309.64 307.02 306.20 188 92 250.00 250.00 MinPt-CtCt 310.00 306 591 305.38 127.58 377.88 377.85 MinPt-O-EOU 310.61 306.52 304.97 99.66 435.85 435.70 MinPt-O-EOU 311.37 306.67 304.82 83.60 479.10 478.75 MinPt-O-ADP 316.74 307.99 304.10 40.63 625.61 623.37 MinPt-O-ADP 320.31 309.17 304.09 31.44 683.19 679.49 MinPt-O-ADP 329.81 31573 309.18 25.111 803.27 794.84 MinP1-0SF 4441.46 4424.21 4416.07 272.94 2862.71 2236.99 TD • Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP15-08\OP15-08\OP15-08(P7) 2/15/2011 7:47 AM Page 6 of 6 Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OP 15-08 Oriented EOU Dimension .T/ Field Nikaitchuq Structure: Oliktok Point NoGo Region Anti-Collision WileA �' Date: February 02,2011 used:Minor Risk-Separation Factor / T North 0-1000' MD 350 0 10 Sao 20 3300® 60 lietia 30 I320 40 310 ITJT, 300 ' /ijr;;:::,4%-:1:411; �'i .• I �;OP10-09 working t4lik 290 `!l ',,�4/1 70 illaiiii&111* ,Jj 0,6 +llt �, 280 ,s .,,, ‘. \� I .,x,80 ����), \..-.A�I•111 01 P81 270Imo/ �_ �";`• �i�,`_�,`�`�=�4' 90 lifiZAT611111101-4*.÷:".•:,.." i� IV& WeP4 �; 100 260Raw---P „'_�,�►� _lt,, �' _ it ,,4., owl. X114-I: 250 le ,,`/"41 , S`� �A m 110 111,4 ak __It, 240 1 �4�-�•` Alh 20 -1k.!11111‘ dp NI 701 A p / 230,�.�'•,• `. .k_1:41�i- 4\` /. 130 NtAIIPA‘ - 220 �/A1 �I� � 11044 ,,ao 210 r� (►�® 150 OP 200 Wt1► ,,1611 OP1743:116-03(P6) ian oP_21-WW011R1b) Well Ticks Type: MD on OP15-08(P7) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH=20.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: ENI NoGo Region EOU's based on: Well: OP 15-08 Oriented EOU Dimension Field Nikaitchuq Structure: Oliktok Point NoGo Region Anti-Collision WileA �' Date: February 02,2011 used:Minor Risk-Separation _ Factor It, ,I North 350 0 10 1000' MD - TD 340 /7���.,,2�0 330 , ��� 30 320ilk '�*. 40 310 1111 10)11% � NIVI. vrao,„„ ik 4, �,' , , i� �?'� �iktok Point II-?DB2 300 ' -'! ill� �;��` 60 441,1 44 290/404iplk/*VI 60 \1 .-`E i °••1,. 70 OW IS A 41001 Ma Ark*At P12-01 AtaWi 280 NS* e ik I I - �•. : I�r� 80 270 isti...„,..,,,,„ -.„ -.#-,,. ire" , . Itil90 I 11 II I 1111 III rill I'�� a 280 cline:_� �f►� 100 oo f 1404 00 V1r0%141,*4fpN*sii„I 250 lki? '- 4..Wv4..._1111.0p-f1.1:W114A.l4 4N41741IIIii AvW.A . i 110 1r1 -,O 240 .', �i1 ` 120 r 230 I��,�••�� 130 2 , �,4 � 4 14 20 � �;,` 0 21`� 0 150 200 ' r60P16-03(P6) 190 180 170 Well Ticks Type: MD on OP15-08(P7) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: IN=%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 8-3/4" Open Hole / 5-1/2" Liner Interval Hazard Risk Level Mitigation Strategy Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low 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.doc 2/25/2011 11:02:00 AM a. iikilligli r o O0 O � CO m v 411 , e t„,_, , ,, , , „,,,,, ........ \ O1 . e O m0 ka eil a) a) U - • t t O i- . 0 U p o , E. (LS (LS C f a) a0 c0 Na © Cl) Ili 2 2 2 7 1 ccs c c c w 7 '' ' IF i cn , cc (13 O O OO +y+ O O , H E E E ca ~ _.I as as ct 3 U U U co 16k.. c 2 2 w .2 o o o 0 ` N 4415 a a) V) 2 •i cD cD c0 (fl �f` a) C) T T T T as ... (7 > cn \ \ \ \ 0 (n'' > c (zs a) T T T T �/ O r N 4 M m CQ O • CO - U > N (� >, C >+ N O) _ cc To m J w E I E `n c° Q U > Z cc Z o a+ — T ub 117 ® o 1 < 8 4s fiif ll § i 5 � a 1 W g il 0 'A 0 12 la P 111—tall,-- WW m az; MI o g WZa int I w Q CX A I " I I IL Z4d H dd N INIM:-_p,„7,;-_;; R ,,, : . —_ ..1 kIlu ct . Lwi ® Iii: 1 = 01' I $o 2 `' earl __ � Ctoz �1 o - Ili o WI g� a '.,:.,-g• mtZO Qo gW\42 -P1 7.0 l 8 ,0 � . $53 5§ E 3i P §0,q �o , > U� 3�33 I X %. c� A 7,_, V ■ ■ • AnZIuuii • /ui — w / Z U 3 < n W---- Ini" HIiIin :'I ' : Ui:iili: Z w Y U w co U ■ ■ ■A, ■ oLI LI 'fiIN h 1 V n T.AI + n ,fel 1-,B O ( . ; IS R., r §\� r ^ § § " PI! . / \ §// / o\ /-� '¥ q| . D-5 o o_ Z �� a_ ® $ 1 n \ �\_\\ /\\\ \�\\ /\\\ II % � k ya®®a y=*a »®aa y 4 0 C �5 // ��\d ®J®~ 5532li ?/%zm ¢9©y \»/® \/»w | /§ I \j�\¢ \�\\ \/\/ \\\% )eh /| \® ~^ \%R® ~�»^ \ 3~ % LC) % ® \'`:1) % LL... ®\ § | / \ $ � � � G E N «,¥ Q/ «,w i\ *7 / ��k \ Lu \| ■CS, 106 ' \ jI .\CD Qf ) G« I r- / , \ , - � - 0 , LLI Z $ O �� ~ 3 01 « � u � �_J L 2 E- cc - - - 0 - 0 + ƒ in 2 y� I I r— ��2 I c� 2 CO 0 m y / 1 in: 0 14 CI _ I _ _ I _ 4X__, y « C0e. - - v:‹ 1 - 4 CO & Lu CO Q§ Lu Qk �{ LuI +�< \9 K //$ . a 3 w0o 0 z 1 N \\ -r 4§ _ � - 5 Schlumberger CemCAD E* well cementing recommendation for 13.375" Surface Casing Operator : Eni Petroleum Well : OP15-08 Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Joe Longo Location : North Slope-Alaska Proposal No. : Draft v2 Service Point : Prudhoe Bay,Alaska Date Prepared : 2-08-2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLong1©slb.com 014 O I c l -141/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 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 : OP15-08 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 1 : well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 2691.0 ft BHST : 54 degF Bit Size : 16 in ft (x 1000) psi '0020.in !�160ft C 0 n 5 1.0 1.5 _ �. — — — — Frac _Siltstone-= Pore .Sandstone.'.'.' Siltstone__ 0D 13.4in 7 _ 2891 ft • • •Sandstone • • . . . . . . . . . . . . . ' —_Siltstone— LC E2811 ft --Siltstone— t ::.'Sandstone'.'.'. .'.'.Sandstone.'.'.' ` E Well Lithology Formation Press. Page 2 op15-08 2-8-11.cfw,02-09-2011, LoadCase Surface Casing;Version wcscern481_08 Client : Eni Petroleum Well : OP15-08 Scilimierger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 160.0 20 169.0 18.376 Landing Collar MD : 2611.0 ft Casing/liner Shoe MD : 2691.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2691.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 180.6% Mean OH Equivalent Diameter: 19.882 in Total OH Volume : 971.9 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 2100.0 16.000 225.0 20.724 2691.0 16.000 35.0 16.822 Page 3 op15-082-8-11.cfw;02-09-2011; LoadCase Surface Casing Version wcs-cem4tl_08 Client : Eni Petroleum Well : OP15-08 Sillitorger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 65 deg Max. DLS : 3.773 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 310.0 0.000 250.0 250.0 0.0 310.0 0.000 300.0 300.0 0.8 310.0 1.500 350.0 350.0 1.5 310.0 1.500 400.0 399.9 3.4 310.0 3.760 500.0 499.5 7.1 310.0 3.750 600.0 598.3 10.9 310.0 3.750 650.0 647.2 12.8 310.0 3.740 700.0 695.8 14.5 307.4 3.758 722.6 717.6 15.3 306.5 3.751 800.0 791.7 18.1 303.8 3.749 900.0 885.7 21.8 301.4 3.744 980.9 960.0 24.8 299.9 3.754 1000.0 977.3 25.5 299.6 3.773 1100.0 1066.1 29.2 298.3 3.741 1200.0 1151.8 32.9 297.2 3.751 1276.8 1215.2 35.7 296.5 3.761 1300.0 1234.0 36.6 296.3 3.727 1400.0 1312.3 40.3 295.6 3.748 1453.2 1352.2 42.3 295.2 3.747 1500.0 1386.8 42.4 294.9 0.502 1600.0 1460.5 42.7 294.3 0.500 1700.0 1533.8 42.9 293.7 0.501 1800.0 1606.9 43.2 293.0 0.503 1900.0 1679.7 43.5 292.4 0.504 1925.6 1698.2 43.5 292.3 0.467 2000.0 1752.1 43.7 291.8 0.504 2100.0 1824.2 44.0 291.2 0.502 2139.0 1852.2 44.1 291.0 0.498 2200.0 1895.2 46.4 291.4 3.745 2300.0 1961.8 50.1 292.1 3.757 2344.3 1989.7 51.7 292.4 3.739 2400.0 2023.4 53.8 292.8 3.746 2500.0 2079.9 57.5 293.4 3.751 2600.0 2130.8 61.2 293.9 3.748 2691.0 2172.2 64.6 294.4 3.752 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 360.0 11.00 8.43 Surface Siltstone 723.0 11.00 8.43 SV-4 Sandstone 981.0 11.00 8.43 SV-3 Siltstone 1277.0 11.00 8.43 SV-2 Sandstone 1926.0 11.00 8.43 SV-1 Siltstone 2100.0 11.00 8.43 Permafrost Base Siltstone 2344.0 12.00 8.43 UG-4 Sandstone 2692.0 12.00 8.43 TD Sandstone Page 4 op15-082-8-11.cfw;02-09-2011; LoadCase Surface Casing Version wcs-cem4€1_08 Client : Eni Petroleum Well : OP15-08 ScMhmlorgcr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1867.0 1655.7 32 0.7 2241.0 1923.1 50 1.6 2685.0 2169.6 54 1.6 2686.0 2170.1 54 1.6 2691.0 2172.2 54 1.6 2691.0 2172.2 54 1.6 2692.0 2172.6 54 1.6 ft degF 15 20 25 30 35 40 45 50 55 60 65 70 75 80 85 0- I I I I I I I l f 0 o- u7 0 0 O O 0 8 0— N Geoth.Rofile -Tubular Fluids -Annulus O O �— N O O O Temp. Profile At 203 min Page 5 op15-082-8-11.cfw.02-09-2011, LoadCase Surface Casing,Version wcs-cem4Sl_O8 Client : Eni Petroleum Well : OP15-08 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost Original fluid Mud 9.50 lb/gal k : 8.28E-2 Ibf.s^n/ft2 n : 0.262 Ty: 0.48 Ibf/100ft2 Displacement Volume 390.9 bbl Total Volume 1060.9 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04 Ibf/100ft2 Lead Slurry 507.0 2186.5 10.70 k:1.08E-2 Ibf.s^n/ft2 n:0.482 Ty:10.26 lbf/100ft2 12.5 DeepCRETE 63.0 504.5 2186.5 12.50 k:1.53E-2 Ibf.s^n/ft2 n:0.771 Ty:0.57 Ibf/100ft2 Mud 390.9 0.0 9.50 k:8.28E-2Ibf.s^n/ft2 n:0.262 Ty:0.48 lbf/100ft2 Static Security Checks: Frac 2 psi at 160.0 ft Pore 19 psi at 160.0 ft Collapse 2038 psi at 2611.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 52 ton Page 6 op15-08 2-8-11.cfw;02-09-2011; LoadCase Surface Casing,Version wcscem461_08 Client : Eni Petroleum Well : OP15-08 Scilillikrger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing * CemCADE Client : Eni Petroleum Well :OP15-08 String : 13.375"Surface Casing District : Prudhoe Bay,Alaska Country :USA ft lb/gal o 8 9 10 11 12 13 —Hydrostatic — — —Mn.Hydrostatic o — Max.Dynanic —Mn.Dynanic 0 - Frac t —Pore 0 0 0 Sr 0 ,n- 2 > I U 8- ci N n 0 m \\''''N.NN J _ cv N 0 N C � M— Fluid Sequence Dynamic Well Security ■MUDPUSH II 100.0 bbl 10.10 lb/gal Herschel:k=2.54E-2 Ibf.s^n/ft2 n=0.420 Ty=13.04 Ibf/100ft2 3 Lead Slurry 507.0 bbl 10.70 lb/gal Herschel:k=1.08E-2 Ibf.s^n/ft2 n=0.482 Ty=10.26 Ibf/100ft2 ■12.5 DeepCREfE 63.0 bbl 12.50 lb/gal Herschel:k=1.53E-2 Ibf.s^n/ft2 n=0.771 Ty=0.57 Ibf/100ft2 ■NLd 390.9 bbl 9.50 lb/gal Herschel:k=8.28E-2 lbf.s^n/ft2 n=0.262 Ty=0.48 Ibf/100ft2 Total Depth = 2691.0 ft Top of Cement= 0.0 ft 'Mark of Schlumberger Sadler Page 7 op15-08 2-8-11.cfw,02-09-2011, LoadCase Surface Casing;Version wcs-cem461.08 o Client : Eni Petroleum Well : OP15-08 ScIimikrpr String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : 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 Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 Drop Bottom Plug Lead Slurry 5.0 507.0 101.4 507.0 80 Start Mixing Lead Slurry 12.5 DeepCRETE 4.0 63.0 15.8 63.0 80 Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Pause 0.0 0.0 5.0 0.0 80 Swap to rig pumps Mud 8.5 390.9 46.0 390.9 80 Rig Pumps To Displace Shut-In 0.0 0.0 5.0 0.0 80 Bleed-off and check floats Total 03:18 hr:mn 1060.9 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks: Frac 1 psi at 160.0 ft Pore 9 psi at 160.0 ft Collapse 2037 psi at 2611.0 ft Burst 4815 psi at 0.0 ft Temperature Results BHCT 67 degF Simulated Max HCT 73 degF Simulated BHCT 73 degF Max HCT Depth 2636.1 ft CT at TOC 61 degF Max HCT Time 03:18:08 hr:mn:sc Static temperatures: At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 61 degF 120 degF Bottom Hole (degF) 73 degF 54 degF Page 8 op15-082-8-11.cfw:02-09-2011: LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 Sell�mkrger String : 13.375 District : Prudhoe Bay,Alaska WW W_ Country : USA Loadcase : Surface Casing ECD Profile at Shoe: Depth= 2691 it O N -Hydrostatic 1;2.1 Dynamic Frac -Fore O 71--"" � cd cd 0 30 60 90 120 150 180 210 Time (min) ECD Profile at Previous Shoe: Depth= 160 ft Fluids at 2691 ft co Hydrostatic CS Dynamic Frac Fore d— rn Ts 4kJI _ 0 30 60 90 120 150 180 210 Time (min) Page 9 op15-08 2-8-11.cfw:02-09-2011; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 Schlmberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing BHCT Temperature Simulation: g —Fo add $- d i mo _8 r _g .--,.. r_ in. g- -First Sack Depth �- First Sack Temp. 8 N N Last Sack Temp. -Last Sack Depth I1-N Lq R N in F8 —T--T— —T--T---T 1 I N.N 0 20 40 60 80 100 120 140 160 180 200 220 Time (min) Treating Pressure Simulation: Calc.Pump Press. 1-! Calc.WHP Q 2V_I §1 I • 8 8. \ \ of I _1 0 30 60 90 120 150 180 210 Time(min) Page 10 op15-08 2-8-11.cfw:02-09-2011, LoadCase Surface Casing,Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 Moberg" String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing U-Tube Prediction: Fluids at 2691 ft Dour — Q In c0- r--- (0_ 2 N Il - N- — 0 30 60 90 120 150 180 210 Time (min) Annular Velocity Model: Depth= 2691 ft -Annular Velocity 8- R r 8- 8- 05- 9- 0 -f7- 9-O O 30 60 90 120 150 180 210 Time(min) Page 11 op15-082-8-11.cfw,02-09-2011, LoadCase Surface Casing:Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 Schlumburgur String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 4: centralizer placement Top of centralization :100.0 ft Bottom Cent. MD :2684.3 ft Casing Shoe :2691.0 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) 211.0 1 1/2 NW-TR-13 3/8-8-TR 3 W304 0.0 208.1 2211.0 0 0/0 0.0 211.0 2611.0 10 1/1 NW-TR-13 3/8-8-TR 3 W304 0.0 2213.5 2691.0 3 3/2 NW-TR-13 3/8-8-TR 3 W304 79.2 2631.0 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) (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 ft 20 40 60 80 100 O — Between Cent. I + +At Cent. + 0 N _ _ — t O O - Ln N •0 O O Well Pipe Standoff Page 12 opl S-082-8-11.cfw:02-09-2011, LoadCase Surface Casing,Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 Scbluollberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 5: WELLCLEAN II Simulator % % ft 0 0 20 40 60 80 100 0 20 40 60 80 100 - 1 r I -I---- .. I —— Std Betw.Cent. — Mud Contarrnation —Cement Coverage — Uncontaminated Slurry O— L I /--"\ Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall z° g g i 3 0i r 0 a 0 500- I 540 504 500 1000— 1000 r 1DO0 1000 T .. ti+ ..- .. . 4-- --E - s r s s n 1500- 1500 a a 1500 1500 a • o • o 2000- 2000 2000 2000 2500 2500 2500 2500 1 1 a 3 a 4 s X 0 3 X o X 2 2 111 Mud I Lead Slurry = High = Looe 12.5 DeepCRETE 11111 MUDPUSH II I I Medium I I None Page 13 op15-08 2-0-11.cfw,02-09-2011; LoadCase Surface Casing;Version wcscem461_08 Client : Eni Petroleum Well : OP15-08 Schhmkerger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 6: fluid description Mud DESIGN Fluid No: 1 Density :9.50 lb/gal Rheo.Model : HERSCHEL_B. k :8.28E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.262 Ty :0.48 lbf/100ft2 Gel Strength :6.40 Ibf/100ft2 MUD Mud Type :WBM Job volume : 390.9 bbl Water Type : Fresh VOLUME FRACTION Solids :4.0% Oil :0.0% Water :96.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.10 lb/gal Rheo. Model : HERSCHEL_B. k :2.54E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.420 Ty : 13.04 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 : 1.08E-2 lbf.s^n/ft2 At temp. :65 degF n :0.482 Ty : 10.261bf/100ft2 Gel Strength : 10.25 Ibf/100ft2 DESIGN BLEND SLURRY Name : B809(100 lb Mix Fluid : 10.367 gal/sk Job volume :507.0 bbl Dry Density : 106.26 lb/ft3 Yield :2.33 ft3/sk Quantity : 1223.29 sk Sack Weight : 100 lbs Solid Fraction :40.4% BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 10.367 gal/sk Page 14 op15-082-8-11.cfw,02-09-2011, LoadCase Surface Casing,Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 Schlumberger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing 12.5 DeepCRETE DESIGN Fluid No:6 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 1.53E-2 Ibf.s^n/ft2 At temp. : 74 degF n : 0.771 Ty : 0.57 lbf/100ft2 Gel Strength : 17.22 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid : 5.175 gal/sk Job volume : 63.0 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity : 230.03 sk Sack Weight : 100 lbs Solid Fraction : 55.0% BASE FLUID Type : Fresh water Density : 8.32 lb/gal Base Fluid : 5.175 gal/sk Additives Code Conc. Function D046 0.129%BWOB Antifoam D065 0.250%BWOB Dispersant D167 0.250%BWOB Fluid loss D153 0.100%BWOB Antisettling Page 15 opt 5-08 2-8-11.cfw;02-09-2011, LoadCase Surface Casing,Version wcs-cem461_08 Schlumberger CemCAD E*well cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : OP15-08 Country : USA Field : Oliktok Point State : Alaska Prepared for : Mr.Joe Longo Location : Nabors 245E Proposal No. : Draftv2 Service Point : Prudhoe Bay,Alaska Date Prepared : 2-09-2011 Business Phone : 907-659-2434 FAX No. : 907-659-2538 Prepared by : Jeff Long Phone : 907-273-1778 Cell : 907-223-0093 E-Mail Address : JLongl©slb.com O +n C 4OAT 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 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 : OP15-08 Schlumberger String : 9-5/8 District Prudhoe Bay,Alaska Country : USA 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 : 13099.0 ft BHST : 87 degF Bit Size : 12 1/4 in ft (x 1000) psl OD 20.in o— @ 160ft - t Frac Pore OD 13.4 in • • •Sandstone••••• - @2691ft 0 �n Shale OD 9.62 in - @ 13099ft .:. • • •Sandstone- - LC @13019 ft _ MMIIIMEIMW 0 u-i Well Lithology Formation Press. Page 2 opt 5-082-8-11.cfw,02-11-2011: LoadCase 9-5/8 Intermediate Casing(al,Version wcscem461_08 Client : Eni Petroleum Well : OP15-08 ScIskrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2691.0 13 3/8 68.0 12.415 Landing Collar MD : 13019.0 ft Casing/liner Shoe MD : 13099.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 13099.0 9 5/8 40.0 40.0 8.835 L-80 2780 4920 HYD 563 Page 3 op15-08 2-8-11.cfw;02-11-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 Sclmerger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Mean OH Diameter : 12.250 in Mean Annular Excess : 50.0 % Mean OH Equivalent Diameter: 13.371 in Total OH Volume : 1885.7 bbl (including excess) Max. Deviation Angle : 85 deg Max. DLS : 3.795 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 310.0 0.000 250.0 250.0 0.0 310.0 0.000 300.0 300.0 0.8 310.0 1.500 350.0 350.0 1.5 310.0 1.500 400.0 399.9 3.4 310.0 3.760 500.0 499.5 7.1 310.0 3.750 600.0 598.3 10.9 310.0 3.750 650.0 647.2 12.8 310.0 3.740 700.0 695.8 14.5 307.4 3.758 722.6 717.6 15.3 306.5 3.751 800.0 791.7 18.1 303.8 3.749 900.0 885.7 21.8 301.4 3.744 980.9 960.0 24.8 299.9 3.754 1000.0 977.3 25.5 299.6 3.773 1100.0 1066.1 29.2 298.3 3.741 1200.0 1151.8 32.9 297.2 3.751 1276.8 1215.2 35.7 296.5 3.761 1300.0 1234.0 36.6 296.3 3.727 1400.0 1312.3 40.3 295.6 3.748 1453.2 1352.2 42.3 295.2 3.747 1500.0 1386.8 42.4 294.9 0.502 1600.0 1460.5 42.7 294.3 0.500 1700.0 1533.8 42.9 293.7 0.501 1800.0 1606.9 43.2 293.0 0.503 1900.0 1679.7 43.5 292.4 0.504 1925.6 1698.2 43.5 292.3 0.467 2000.0 1752.1 43.7 291.8 0.504 2100.0 1824.2 44.0 291.2 0.502 2139.0 1852.2 44.1 291.0 0.498 2200.0 1895.2 46.4 291.4 3.745 2300.0 1961.8 50.1 292.1 3.757 2344.3 1989.7 51.7 292.4 3.739 2400.0 2023.4 53.8 292.8 3.746 2500.0 2079.9 57.5 293.4 3.751 2600.0 2130.8 61.2 293.9 3.748 2691.0 2172.2 64.6 294.4 3.753 2700.0 2176.0 65.0 294.4 3.795 2800.0 2215.4 68.7 294.9 3.745 2900.0 2248.7 72.4 295.3 3.753 3000.0 2275.8 76.1 295.7 3.752 3100.0 2296.6 79.9 296.1 3.743 3181.8 2308.8 82.9 296.5 3.752 13049.2 3495.1 85.0 289.8 0.000 13099.2 3499.4 85.0 289.8 0.000 Page 4 op15-082-8-11.cfw;02-11-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 360.0 11.00 8.43 Surface Siltstone 723.0 11.00 8.43 SV-4 Sandstone 981.0 11.00 8.43 SV-3 Siltstone 1277.0 11.00 8.43 SV-2 Sandstone 1926.0 11.00 8.43 SV-1 Siltstone 2100.0 11.00 8.43 Permafrost Base Siltstone 2344.0 12.00 8.43 UG-4 Coal 4392.0 12.40 8.43 UG2 Sandstone 9333.0 12.50 8.43 L Ugnu Shale 11311.0 12.50 8.43 Schrader Bluff Sandstone 11469.0 12.50 8.43 N Seq Top Shale 11822.0 12.50 8.43 N Sand Top Sandstone 12112.0 12.50 8.43 N Sand Bottom Sandstone 12450.0 12.50 8.43 N Seq Bottom Shale 12975.0 12.50 8.43 OA Sand Top Sandstone 13049.0 12.50 8.43 OA Slb 2 Shale 13100.0 12.50 8.43 TD Shale Geothermal Temperature Profile MD TVD Temperature Gradient (ft) (ft) (degF) (degF/100ft) 0.0 0.0 20 0.0 1823.0 1623.7 32 0.7 2272.0 1943.6 50 1.5 8448.0 2958.8 77 1.9 10928.0 3264.9 83 1.9 13099.2 3499.4 87 1.9 13100.0 3499.5 87 1.9 degF ft o 10 20 30 40 50 60 70 80 90 k______,...s... .._,,i,,s_ -----1 ._ O_ - Geoth.Profila -Tubular Fluids �Q - -Annulus M �Qj� P Temp. Profile At 192 min Page 5 op15-08 2-8-11.cfw,02-11-2011, LoadCase 9-5/8 Intermediate Casing(al,Version wcs-cem4Ol 08 Client : Eni Petroleum Well : OP15-08 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 2: fluid sequence Job Objectives: Zonal Isolation,TOC @ 10,822'(1,000'above the"N"sand) Original fluid Mud 9.30 lb/gal k : 5.97E-3 Ibf.s^n/ft2 n : 0.616 Ty: 8.86 Ibf/100ft2 Displacement Volume 987.2 bbl Total Volume 1253.8 bbl TOC 10822.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 836.6 9985.4 10.50 k:5.23E-2 Ibf.s^n/ft2 n:0.324 Ty:12.92 Ibf/100ft2 DeepCRETE 196.6 2277.0 10822.0 12.50 k:1.61 E-2 Ibf.s^n/ft2 n:0.774 Ty:0.96 Ibf/100ft2 Mud 987.2 0.0 9.30 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 lbf/100ft2 Static Security Checks: Frac 231 psi at 2691.0 ft Pore 87 psi at 2691.0 ft Collapse 2595 psi at 13019.0 ft Burst 4920 psi at 0.0 ft Csg.Pump out 59 ton Page 6 op15-082-8-11.cfw;02-11-2011; LoadCase 9-5/8 Intermediate Casing(a) Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 SchIberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA 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 lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 70.0 14.0 70.0 80 Spacer Ahead 3.0 0.0 80 Drop Bottom Plug 3.0 0.0 80 Begin Mixing Slurry DeepCRETE 5.0 196.6 39.3 196.6 80 Mix&Pump Cement Slurry(3 to 7 BPM) 5.0 0.0 80 18-Drop Top Plug Mud 8.5 10.0 1.2 10.0 80 Kick-Out Plug 5.0 0.0 80 Swap to Rig Pumps Mud 8.5 967.2 113.8 977.2 80 Rig pumps to displace Mud 5.0 10.0 2.0 987.2 80 Bump Plug 5.0 0.0 80 Pressure Test Casing Shut-In 0.0 0.0 1.0 0.0 80 Bleed off/Check Floats Total 03:11 hr:mn 1253.8 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks Frac 164 psi at 2691.0 ft Pore 87 psi at 2691.0 ft Collapse 2449 psi at 105.6 ft Burst 4480 psi at 0.0 ft Temperature Results BHCT 84 degF Simulated Max HCT 87 degF Simulated BHCT 79 degF Max HCT Depth 13099.0 ft CT at TOC 78 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures: At Time 00:00 hr:mn 00:01 hr:mn Geo.Temp. Top of Cement 76 degF 78 degF 1 83 degF Bottom Hole 76 degF 79 degF 87 degF Page 7 op15-082-8-11.cfw,02-11-2011: LoadCase 9-5/8 Intermediate Casing(a).Version wcs-cem4fil.08 Client : Eni Petroleum Well : OP15-08 ScIlmberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) CemCADE Client :Eni Petroleum Well :OP15-08 String :9-5/8"Intermediate Casing District : Prudhoe Bay,Alaska Country : USA ft lb/gal o 8 9 10 11 12 13 I —Hydrostatic —Mn.Hydrostatic —Max.Dynanic 00 j j —Mn.Dynamic — Frac oCN 3 j — Pore O - I o— I j 3 ( - I O_ co U v O v o a O J N_ O • r O - o � 3 Fluid Sequence Dynamic Well Security ■MUDPUSH II 70.0 bbl 10.50 lb/gal Herschel:k=5.23E-2 lbf.s^n/ft2 n=0.324 Ty=12.92 Ibf/100ft2 ° ■DeepCRErE 196.6 bbl 12.50 lb/gal Herschel:k=1.61 E-2 Ibf.s^n/ft2 n=0.774 Ty=0.96 Ibf/100ft2 ■Mud 987.2 bbl 9.30 lb/gal Herschel:k=5.97E-3 Ibf.s^n/ft2 n=0.616 Ty=8.86 Ibf/100ft2 Total Depth =13099.0 ft Top of Cement=10822.0 ft *Mark of Schlumberger Page 8 op15-08 2-8-11.cfw,02-11-2011, LoadCase 9-5/0 Intermediate Casing(al,Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 SchIldirger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ECD Simulation at shoe: O Depth= 13099 ft LoN o Hydrostatic Dynamic -Frac tl) Pore - u7 O O \i\i- , - in D7- p O co I 0 30 60 90 120 150 180 210 Time (min) ECD Simulation at previous shoe: Depth= 2691 ft Fluids at 13099 ft inN 0 N- o -Hydrostatic _ Dynamic Frac -Pore O i 1 n O O- 4i in —Li 0 coil l ,TJ-1 0 ad 0 30 60 90 120 150 180 210 Time (min) , Page 9 op15-08 2-8-11 cfw,02-11-2011, LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 ScIMmlierger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) • Cement Placement Temperature Simulation: c -- 0 PN P- i i 8- .dr* . r ff A I:' -co g. 8- 0 -First Sack Depth —� _ — First Sack Temp. -Last Sack Temp. -Last Sack Depth r � r O 30 60 90 120 150 180 210 Time(min) Surface Pressure Model: Calc.Pun-p Press. Calc.WHP O g ....: : ISN / ___ —\ 8- 0 O 30 60 90 120 150 180 210 Time(min) Page 10 op15-08 2-8-11 cfw;02-11-2011: LoadCase 9-5/8 Intermediate Casing(a(:Version wcs-cem481_08 Client : Eni Petroleum Well : OP15-08 SclMmkerger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) U-Tube Simulation: rn _ Fluids at 13099 ft -Q Out -Qh CO, (0- C Il0- M- N- O O 30 60 90 120 150 180 210 Time (min) Anullar Velocity Simulation: Depth= 13099 ft -Annular Velocity 8 7- 1 R- 0 I — O 30 60 90 120 150 180 210 Time(min) Page 11 op15-08 2-8-11.cfw,02-11-2011, LoadCase 9-5/8 Intermediate Casing lal.Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 Schlumhcrgcr String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 4: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :13089.0 ft Casing Shoe :13099.0 ft NB of Cent. Used :46 NB of Floating Cent. :46 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 11339.0 0 0/0 0.0 11356.8 13019.0 42 1/1 Spiral Glider W090 52.5 11359.0 13099.0 4 2/1 Spiral Glider W090 82.3 13099.0 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) Spiral Glider W090 9 5/8 11.75 9.7 Yes Weatherford ft 0 20 40 60 80 100 o - — Between Cent. O + 4A Cent. O - O O I O t— O N r - O u7- N r - O - O M O - 0 LO M Well Pipe Standoff Page 12 opt 5-08 2-8-11.cfw,02-11-2011, LoadCase 9-5/8 Intermediate Casing Ial,Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: WELLCLEAN II Simulator ft % % 0 0 20 40 60 80 _ 100 0 20 40 60 80 100 o 0 0 o- N r- - N LTh M i - - Std Betw.Cent. Mud Contarrination g _ — Cement Coverage — Uncontaminated Slurry Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall '3 i z° g 10000 +oaoo 1000c)-Li ^--10000 105001 10500 10500 3 0500 1 v 11000 I , 11000 11000- i -++000 1.7"r 11500 11500 = r 11500- J -11500 r a ., i n m d O O D O 12000 12000 12000- -12000 12500 12500 12500- -12500 13000 1 5000 13000- -1 5000 W b 0 5 z z MN Mud 0 High Low 1----i DeepCRETE 0 Medium = None iiiig MUDPUSH II Page 13 op15-08 2-8-11.cfw,02-11-2011: LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem461_08 Client : Eni Petroleum Well : OP15-08 Schlohrger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 6: fluid description Mud DESIGN Fluid No: 1 Density :9.30 lb/gal Rheo. Model : HERSCHEL_B. k :5.97E-3 Ibf.s^n/ft2 At temp. :80 degF n :0.616 Ty :8.86Ibf/100ft2 Gel Strength :32.02 Ibf/100ft2 MUD Mud Type :WBM Job volume :987.2 bbl Water Type : Fresh VOLUME FRACTION Solids :6.0% Oil : 1.0% Water :93.0% MUDPUSH II DESIGN Fluid No:2 Density : 10.50 lb/gal Rheo. Model : HERSCHEL_B. k :5.23E-2 Ibf.s^n/ft2 At temp. :65 degF n :0.324 Ty : 12.921bf/100ft2 Gel Strength :40.56 lbf/100ft2 Job volume : 70.0 bbl DeepCRETE DESIGN Fluid No: 7 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 1.61E-2 Ibf.s^n/ft2 At temp. : 78 degF n :0.774 Ty :0.961bf/100ft2 Gel Strength : 19.00 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid : 5.180 gal/sk Job volume : 196.6 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity : 717.49 sk Sack Weight : 100 lbs Solid Fraction : 55.0 BASE FLUID Type : Fresh water Density :8.32 lb/gal Base Fluid : 5.160 gal/sk Additives Code Conc. Function D167 0.250%BWOB Fluid loss D046 0.129%BWOB Antifoam D065 0.250%BWOB Dispersant D153 0.100%BWOB Antisettling D110 0.020 gal/sk blend Retarder Page 14 op15-08 2-8-11.cfw,02-11-2011, LoadCase 9-5/8 Intermediate Casing Cal,Version wcs-cem461_08 ENI S.p.A. SPEO IDENTIFICATION CODE PAG 206 OF 338 Eng E&P Division REVISION STAP-P-1-M-6140 0 1 15. LEAK OFF TEST PROCEDURE A Leak-Off Test (LOT) will be performed On Wild-Cat wells at each casing shoe after setting the surface casing. LOTs are also recommended to be carried out on both appraisal and development wells. Leak Off Test and Formation Integrity Test (FIT), also termed the Limit Test, are for formation strength pressure tests made just below the casing seat prior to drilling ahead. These tests are carried out to: • Investigate the cement seal around the casing shoe which should be at least as high as the predicted fracture pressure for the area. • Investigate the wellbore capability to withstand pressures below the casing shoe in order to allow proper well planning with regard to the setting depth of the next casing, mud weights and alternatives during well control operations. • Collect regional information on formation strengths and stress magnitude for different applications including optimisation of future well planning, hole stability analysis and modelling, reservoir application. Prior to a test, a decision should be made to either increase the pressure until leak off occurs (as in the LOT) or to stop at a predetermined pressure for a (FIT). It should be noted that: • FIT does not obtain information on stress magnitude. • A LOT is designed and should be performed to determine, in a better way, the desired data without breaking down the formation. When a Formation Integrity Test is required, the maximum pumping pressure is often expressed in terms of`Equivalent Mud Weight' (EMW): Imperial units EMW= P +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight (PPG) Metric units EMW = Px10 + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight (kg/I). 119* ENI S.p.A. SPEO IDENTIFICATION CODE PAG 207 OF 338 Evil E&P Division REVISION STAP-P-1-M-6140 0 1 LOTts or FITs can be carried out in any open hole section and at any time while drilling the hole, even if it is customary to have it performed some metres (6-15 metres) below the casing. For instance, the casing seat can be in a shale and the first sand formation may be encountered several hundred feet deeper. This will certainly be more permeable than the shale, and a test can be performed to ascertain the maximum pressure this sand can hold. If it is lower than the shale just below the casing seat, this sand becomes the limiting factor. Note Information obtained from leak-off tests in straight holes is not applicable to deviated holes in the same field and vice versa. 15.1 TEST PROCEDURE Prior to performing a formation strength test, prepare a sheet of graph paper to record pressure, versus cumulative mud volume. 1) Drill out the float equipment, clean the rat hole and drill 5m of new hole. 2) Circulate a mud quantity equal to the internal string volume plus the new hole plus 50m internal casing volumes. This mud shall be cleaned and conditioned to the density and filtrate as indicated in the Mud Programme to be used for the next drilling phase. 3) Pull the bit back into the casing shoe. 4) Rig up the cementing unit to the drill pipe. The unit shall be equipped with high precision, low pressure gauges. The range of the pressure gauge shall be selected based on the actual mud weight and the estimated (LOT) or predetermined (FIT) pressure. A pressure recorder should be used during the test. The use of the rig pumps for making these tests is unsuitable. 5) Fill and test the lines with mud. 6) Break circulation with the cementing unit to make sure that the bit nozzles are clear. Stop pumping when circulation is established. 7) Close the top pipe rams or the annular. 8) In surface well head both flanged and multistage wellheads, open the annulus of the previous casings. In sub sea well head pay attention to not excide the burst pressure of the previous casing. 9) Pump slowly and in continuous way, until pressure builds up to approximately half the anticipated maximum surface pressure. 10) Once pressure is established, pump uniform volumes of mud and wait for the time required for the pressure to stabilise. The flow rate range is from 1/8 bbl/min (20 1/min) up to a maximum of 1 bbl/min (160 I/min), however values of 0.25 bbl (121/4" and smaller holes) or 0.50 bbl (171/2" hole) are commonly used. 11) Note the cumulative mud volume pumped, the final pumping and final static pressure. 12) Repeat steps (9) and (10) above and plot pressure versus cumulative mud volume for each increment of pumped volume. ENI S.p.A. SPEO IDENTIFICATION CODE PAG 208 OF 338 Em E&P Division REVISION STAP-P-1-M-6140 0 1 13) Continue this procedure until: • Two or three points on the plot are reached where the pressure deviates and falls below the approximate straight line (or if the pressure does not increase with the injected volume). The point on the plot where the curve begins to bend away from the straight line is called Leak Off Point (Refer to Figure 15-1) • Or the predetermined test pressure is reached. 14) Stop pumping, shut in the well, record and plot pressure versus time until stabilisation (usually it takes 15-20min). In the early stage (2-3min) one value every 15-30sec should be collected while for the remaining a value of pressure every 30- 60sec may be sufficient. The use of PACR or an equivalent device, if available, is preferred. 15) Bleed off the pressure and record the quantity of fluid returned into the cementing unit. Compare it to the volume used for the test to obtain the amount of fluid lost to the formation. 16) Open the BOP and calculate the formation strength in terms of `Equivalent Mud Weight' using the lowest between leak off point pressure and stabilised pressure. 17) Collect the data recorded during the test in a data sheet together with the following information: borehole diameter, depth of test, depth and type of the last casing, mud density, plastic viscosity, filtrate and gels (refer to the example on the next page). Note: The LOT pressure doesn't exceed the pressure which the casing was tested. Note: When a good zonal isolation behind the casing is imperative, the Leak- off test should be carried out with a retrievable packer to avoid pressurising the casing which may cause possible permanent damage to the cement bond by the creation of micro annuli in the cement. Note: The pumping rate should be kept within the limits described in step 9). If the rate is too low, filtration losses will mask any leakage loss, or, if the rate is too high the formation may suddenly break and the leak off pressure will not be determined. Also, the longer the open hole section, the higher should be the injection rate. If the initial pumping rate is not sufficient, the well should be depressurized and the test restarted with a higher rate. Note: If a float valve is used in the drilling string, the test can not be carried out by pumping down the drill pipe. In this case rig up the cementing unit to the choke or kill line, fill and test the lines against the fail-safe and establish circulation through the riser. Close the BOP and perform the formation strength test pumping down the annulus. ENI S.p.A. SPEO IDENTIFICATION CODE PAG 209 OF 338 Em E&P Division REVISION STAP-P-1-M-6140 0 1 [16101 LEAK-OFF TEST REPORT Report N' Date: WELL NOME: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m): 825 Mud Type: FWGELS Rig type: J.UPs Hole Dameter(in): 12"114 Weight(KgA): 1.3 R.K.B.elevation(m): 26 Last Csg.Shoe(m): 797 Marsh Uscosity(sec/Ot): 44 Water Depth(m): 24 Csg.diameter en): 13"3/8 P.V.(cps): 19 Pumps: 12.P.160 Grade: .1.55 Y.P.(lb/100ha): 5 Liners(in): 6.5" Weight Qb/t): 61 Gelsgb/100 1'): 2/8 Flow Rate(bpi): 0.25 Max.Burst pres(psi): 3103 W.L(ccI30 min): 10.5 Litholog y Shale Expected EMW 1.68 Kg/cm2I10 m Time Vol Lin e Pressure Time Volume Pressure Time Vdume Pressure (min) (bb) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 9 2 490 16 2 435 2 050 100 95 2 480 3 0.75 200 10 2 470 4 1D0 300 10.5 2 463 5 125 400 11 2 465 6 1.50 500 11.5 2 460 7 1.75 570 12 2 446 8 200 600 13 2 440 8 200 550 14 2 437 8.5 200 505 _ 15 2 435 Nate: Pumped with a constant low rate of(bbl): 'blume pumped(bbl). \Polume returned(bbl): (pot) 1000 900 sotp0 PS stop pump P 700 ` e 600 shut in curve S 500 r � S _ •-+—•-'• • • • • LI 400 r- 8 minutes e 300 200 100 0 0 0,25 0,5 0,75 1 1,25 1,5 1,75 Z 1 2 3 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbf) I I 10 Time mins RESULTS:(Press.mw+Press.,.o.)x10/Depth=[(1.3 x 797 110)+(430 x 0.07)]x10 1797=1.68(Kg/cm2/10 m) Note: I Company Representable ' Figure 15-1 - Leak-Off Test Report 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 01 iktok OLIKTOK 50� et Point It NTAKE DOCK OPP THIS l MODULE , ok a P�9 t. ?SURVEYS5 0 . N �•,,pP�`9 *N,,DS-3R DEW LINE y9 O � SITE f=3S I STP f , TANK ��aa OLIKTOK POINT MODULES NDC STAGING AREA T13N, R9E ' DS-3Q 1 18 `� 1 `1;121-'/-* rv^^ �� 15 SCALE: imx--) I Ll..: ig , 1" = 150' ' � ( os 30 11 19 �: 29l\\\\ ,-,- - STP \ M STP PADVICINITY MAP 0 \'\ SCALE: 1" = 1 Mile 0 o°-o$ °0 0\C, \ o poo--o N-3 \ ,,\,\ \ r'O 0 • t� O '- - 0° p °OOp�'; \\\:\ O "3 00� S \00 -o q'O� > ° � S Ca ro \0 --0 ��Q Z OO�� Pa3 1) \ • ( -7 \. O \ \• �� OLIKTOK , 0 POINT PAD \ o, \ G• o \ as \ \ o 1 'O% \ J \ / \ \ SEE SHEET 3 FOR NOTES / \\ O Existing Conductor r\ LOUNSBURY s / • Conductor Asbuilt this survey SURVEYORS n INC.cNEss / AREA: MODULE: UNIT: pm Ena Pet�roilkum OLIKTOK POINT PAD WELL CONDUCTOR Ent' ASBUILT LOCATIONS CAD LK680D1 10/9/08 DRAWING NO: NSK 6.80-d1 PART: 1 OF 3 I REV: 2 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-11 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 OPOS 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°52'01.545" 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 DISPOSAL WELLS AK STATE PLANE(NAD83) LAT1TUDE(N) LONGITUDE(W) SEC. LINE PAD 0.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 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: EN PeZrOIIeur OLIKTOK POINT WELL CONDUCTOR PAD ASBUILT LOCATIONS CADD FILE NO. DRAWING NO: PART: REV: LK680D1 10/9/08 NSK 6.80-di 2 of 3 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 12/23/08 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. ••-\ OF 4L9`4.� : TRANSMITTAL LETTER CHECKLIST v/ WELL NAME / K4/IC 0/2/5-03 PTD# 21/ 0%2-_ ✓ Development Service Exploratory Stratigraphic Test Non-C ventional Well • FIELD: 1,� / POOL: 1 ... frail-r- 4141 I / Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter Di 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(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well . SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate andproduce / 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 I from where samples are first caught and 10' sample intervals through target zones. 1 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. 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