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211-041
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 4direct inspection of the file. b -1 L - 04_1 Well History File Identifier Organizing (done) ❑ Two-sided I 11111 III IIID ❑ Rescan Needed II 111118 ff111 RES N DIGITAL DATA OVERSIZED (Scannable) Col Items: ❑ Diskettes, No. ❑ Maps: reyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Maria Date: Lkatil I /s/ 1/14e Project Proofing I 11E11111 11111 BY: Maria Date: 6/ g I /s/ u • Scanning Preparation oZ x 30 = lob + 1 1 = TOTAL PAGESAM / (Count does not include cover s eet) BY: Date: a(i `� /s/ 61 Production Scanning 111111111111011111 Stage 1 Page Count from Scanned File: 7A (Count does include cov sheet) Page Count Matches Number in Scanning Pre aration: YES NO BY: ( a ) Date: CoiaLt /t-f- /s/ rylio 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. 1111111111111 I ReScanned H111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked Mil 111 III III o o .6 o I 2 I I m Ca V m 2 M Z Q N CP U iI N o*-E ;rnE ea °U0 C7m a 41 /l Z i m $ 0.4, Z Z W W � i 2 fA Z Ce 0. O c c. W N a> d > U Z '- W CD Z d a ' ° zo Q R � Z ° N C J Q ea _ c ' O cn of rn c T E C- N g Z 2 in 0 c � G N a ' N y a) 0 m I UN E E sN I J Ii (0I Q x1 I o I a �I 2 IIS C� 00 To � G O j 4' II' _� Cl) =• a) _ 2 z ° j j t.4 Q d ai ZI ! c) 0 • ° d U o ; a r , z c !I a) a) 1c E cH : cc3 Z ° is N Z °f y E O5. O � 0 J y y jG 2 F -Z Z Z m N ZO O w W O Z d 0 } } } d Z Ca J o O u = rn v y z Q a cyi .Y. d' Z W 92 —cm0 O 1:12O O y N ! d ~E -aH J U H 0 a T.� E E a w Q >. a, me >, m Q i U ¢� U U 1 CLi o I 3 -Jo � 3 6 - SEAN PARNELL, GOVERNOR ALASKA. OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Jason Brink Drilling Engineer ENI US Operating Co. Inc. 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503 Re: Nikaitchuq Field, Nikaitchuq Pool, OP09-S03 ENI US Operating Co. Inc. Permit No: 211-041 Surface Location: 3194' FSL, 1583' FEL, SEC. 05, T13N, R9E, UM Bottomhole Location: 931' FSL, 1234' FEL, SEC. 24, T14N, R8E, UM Dear Mr. Brink: We are in receipt of your request to withdraw t. above referenced permit. Based upon your request we have withdrawn an. ca elled the permit. Since 111n Com' is 'oner DATED this/ day of April, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) Page l of 2 i� Schwartz, Guy L (DOA) From: Brink Jason [jason.brink@enipetroleum.com] Sent: Tuesday, April 12, 2011 11:29 AM To: Schwartz, Guy L(DOA) Cc: Davies, Stephen F(DOA) Subject: RE: 211-041 Guy ENI would like to request that the AOGCC withdraw OP09-S03 (PTD 211-041). Jason Brink From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Tuesday, April 12, 2011 10:35 AM To: Brink Jason Cc: Davies, Stephen F (DOA) Subject: RE: 211-041 Jason, As you know a decision to submit a new PTD for OP14-S3 was made after the emails below... Can you make a written request by email response to withdraw OP09-S03 ( PTD 211-041) ? Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Schwartz, Guy L (DOA) Sent: Thursday, March 31, 2011 10:50 AM To: 'Brink Jason' Cc: Davies, Stephen F(DOA) Subject: RE: 211-041 Jason, A revised PTD will need to be submitted. Anything that changed due to the Surface location should be included. Make sure you mark the 401 application with "REVISED " on the top. The well name can be changed on the 401 application also. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Brink Jason [mailto:jason.brink@enipetroleum.com] Sent: Wednesday, March 30, 2011 4:24 PM To: Schwartz, Guy L (DOA) Subject: PTD: 211-041 Guy: 4/12/2011 • Page 2 of 2 1 Regarding this approved permit for OP09-S03. ENI wants to change the surface location of this well to conductor slot 14. This would change the name to OP14-S3. The directional plan stays the same except for the surface location. What information would you need to proceed to change this permit name and profile? I can provide whatever is necessary. Please let me know. Jason Brink Drilling Engineer ENI Alaska Office: 907-865-3321 Cell: 907-947-3790 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. 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. 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. 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. 4/12/2011 fook z Enli tro c loll _kn �) -, _. �•. ) ar •t ' ' a ', 3800 Centerpoint Drive Suite 300 Anchorage,Alaska 99503 4:1',i Maurizio Grandi 1;.;i 4 r i H r Phone(907)865-3320 '-4i3 gc, Email: Maurizio.Grandi@enipetroleum.com April 6,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer OP14-S3 Dear Commissioners, Eni US Operating Co. Inc.hereby applies for a Permit to Drill for the onshore production well OP 14-S3. This well will be drilled and completed using Nabors rig 245E. The planned spud date could be as early as « w i.i(, j .r'+� 4/21/2011. The intent of this application is to r place the onshore production well OP09-S03 APD# ,�. 211041,API#50-029-23446-00-00 approved on March 21,2011. Although the intent of this application for permit to drill is to replace OP09-S03 the primary change is only to the surface location resulting in minor depth changes to the original well path. Eni US Operating Co. Inc. acknowledges the AOGCC's efforts and will strive to provide adequate time for future applications. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Joseph Longo at 907-865-3323. Sincerely, pv.07/.—.f._. , Nelso, Car sal o Oliktok Point Drilling and Completion Superintendent ITIFa O SEAN PARNELL,GOVERNOR SifaTE ALASKA OIL AND GAiS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMIIIISSION 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, Nikaitchuq Pool, OP09-S03 ENI US Operating Co. Inc. Permit No: 211-041 Surface Location: 3194' FSL, 1583' FEL, SEC. 05, T13N, R9E, UM Bottomhole Location: 931' FSL, 1234' FEL, SEC. 24, 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. Si cere •// / 1 0 e . .-a _ , issi•ner DATED this 1' day of March, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVELD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION '+AAR 14 7�ii' PERMIT TO DRILL 20 AAC 25.005 Ira id&Gas ions. ®n�nission 1 a.Type of Work: 1 b. Proposed Well Cla:Development-Oil Q• Service- Winj 0 Single Zone El/ Specify if well' ons 'for: Drill ❑Q . Redrill Stratigraphic Test 0 Development-Gas ❑ Service-Supply ❑ Multiple Zone 0 r'JlCoalbed Gas 0 Gas Hydrates 0 Re-entry❑ Exploratory ❑ Service- WAG 0 Service-Disp ❑ ; Shale Gas 0 2.Operator Name: 5. Bond: Blanket 0 Single Well 0 11.Well Name and Number: ENI US Operating Co Inc Bond No. RLB0008627 OP09-S03 • 3.Address: 6. Proposed Depth: 12. Fiel. •ool(s): 3800 Centerpoint Drive Suite 300,Anchorage 99503 MD: 20732' . TVD: 3661' • Nikaitchuq 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): . . Surface: 3194 FSL 1583 FEL S5 T13N R9E UM ADL 355024,373301,390616,39128 Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: 181 FSL 2588 FEL 29 T14N R9EUM ADL 417493 4/5/2011 Total Depth: 9.Acre- •roperty: 14. Distance to Nearest Proeerty: 931 FSL 1234 FEL 24 T14N R8EUM 2.286' - 0a `S.n.6461'to unit boundary 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10. KB ation above ' L: 53.2 feet 15. Distance to Nearest Well Open Surface:x 516697• y- 6036547 • Zone- 4 GL 1 : ation abo - MSL: 12 feet to Same Pool: 946'SW to OP08-04 16.Deviated wells: Kickoff depth: 300 feet 17. 1 1• m A cipated Pressures in psig(see 20 AAC 25.035) • Maximum Hole Angle: 90° degrees Di hole:17r psig , Surface: 1280 psig • 18. Casing Program: Specificati ns V T.. - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight _ Grad j/Co piing Lengt MD ik TVD MD TVD (including stage data) Driven 20" 178.89 X- 5 Welded 36 120 120 pre-installed 16" 13-3/8" 68 L BTC r!P9 • 35 2327 2173 1038 sx 10.7#ASL,266 sx 12.5#Deeperete 12.25" 9-5/8" 40 0 Hydril 5'•3 11! 9775 t! ; 33 9808 _ 3862 977 sx 12.5#Deeperete I fi • 5.5" 17 L-80 d it 5' 111,• ', `• j 3848 20732 3661 Slotted liner in open hole 19.$ T 3•f?•i1 PRESENT W L COND T • '4 MMA- (To yil omplete• for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): I •1 g (mea- red io Effect. .-: h D(ft): Effect. Depth TVD(ft): Junk(measured): Casing Length 'ze` , fr t Volume MD TVD Conductor/Structural Surface (r I Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat Q BOP Sketch Q Drilling Program 2 Time v. Depth Plot ❑ Shallow Hazard Analysis Q Diverter Sketch 0 Seabed Report [Thrilling Fluid Program Q 20 AAC 25.050 requirements❑✓ 21. Verbal Approval: Commission Re.resentative: Date 22. I hereby certify that the foregoing s true and correct. Contact Jason Brink @ 907-865-3321 Printed Name Maurizio Gr.ndi Ja c,- br i.k For WI.&itle Well Operation Project Manager Signature / Phone Date j/1/// Commission Use Only Permit to Drill API Number Q '/ Permit Aproa 11 , Seeqcover letter for other Number: �f 0 / 50-027. 237' '� Date: `5 requirements. Conditions of approval: If box is l checked, may not be used to explore for,test,or produce coalbed methane as hydrates,or gas contained in shales: d Other: A 3500 ps:. fez+ Samples req'd: Yes❑ No[" Mud log req'd: Yes ❑ No El it- 2-rap I pr.: A yel..u44•t_ # 6144.,. I-I2S measures: Yes❑ No[v' Directional svy req'd: Yes d No 0 - alp U)Q;ds re, 20 A.4c z s 0 35(0(2) SVSP I4.u.......-- -Lppmw& Pa` Za A 5• A(0) I) APPROVED BY THE COMMISSION DATE:3�Z/�// 11'. CO MISSIONER 0R1G 4S •/7!i 3 7V1 Pnrrn 10-am rRP"i�pd 7nnna\ This hermit is valid for 24 mnnthc from the data of an'rnval 190 AA -95 01151M ...... ii* • e a, Imp trolleurn REC IVE \tFah, , il J, Aill 3800 CentAnchorage, Drive Suite 300 meske 00 81 Eos Cons.Emission Anchorage,Alaska 99503 �llh�ie� Maurizio Grandi Phone(907)865-3320 Email: Maurizio.Grandi@enipetroleum.com March 3,2011 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 RE: Application for Permit to Drill Producer OP09-503 Dear Commissioners, ENI US Operating Co.Inc.hereby applies for a Permit to Drill for the onshore production well OP09-S03. The well will be drilled and completed using Nabors rig 245E. The planned spud date could be as early as • 4/5/2011. This Producer may be drilled before the recently submitted PTD request for OP 15-08. ' Please fmd 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, Maurizio Grandi Well Operation Project Manager Jasai r..•-1 ror vA. Cr. ....* Oliktok Point Nikaitchuq Field 2 'o I p trroleium OP09-S03 (P3) Alaska DIR I LWD FORM DEPTH HOLE CASING MUD INFO Drilling MWD MD TVD SIZE SPECS Hazards Cement to Surface 20" X-65 20"Conductor Shoe 160' 160' N/A Welded/Driven N/A 0 GR/Res L.+ Surface Csq Dir a 13-3/8" co Base Permafrost 2.025' 1.778' D 68 lbs/ft MW(ppg) Wellbore Stability Mud Motor r L-80.BTC 8.8-9.5 Lost Circulation Hole Cleaning i 13-318"Casing Point 2.327' 2,173'l K. 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 6.678' _.,:j! "N"Sand Top 7,678' 3,596' TOL 9,608' 9-518"Casing Point 9,808' 3,862' 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/5-1/2"Lnr 20,732' 3,661' 8-3/4" 85 F MOBM • En Petirolleum enil Application for Permit to Drill Saved:8-Mar-11 Application for Permit to Drill Document Producer Well OP09-S03 Table of Contents 1. Well Name 2 Requirements of 20 AAC 25.005(f) 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 (Ml 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 OP09-S03 PERMIT Document.doc Page 1 of 7 Printed:8-Mar-11 • Enien o Petirolleum Application for Permit to Drill Saved:8-Mar-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: OP09-S03 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 p/at identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 3194 FSL 1583 FEL S5 T13N R9E UM ASP Zone 4 NAD 27 Coordinates RKB Elevation 53.2'AMSL • Northings 6036546.91 Eastings: 516696.9 Pad Elevation 12'AMSL Location at Top of Productive Interval 181 FSL 2588 FEL 29 T14N R9EUM ("OA"Sand) ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 9808' Northings: 6044089.71' Eastings: 515652.34' Total Vertical Depth, RKB: 3861' Total Vertical Depth, SS: 3809' 0P09-S03 PERMIT Document.doc Page 2 of 7 Printed:8-Mar-11 cot • En Petirolleuim ein 11 Application for Permit to Drill Saved:8-Mar-11 Location at Total Depth 931 FSL 1234 FEL 24 T14N R8EUM ASP Zone 4 NAD 27 Coordinates Measured Depth, RKB: 20731' • Northings: 6050105.3 Eastings: 506598.7 Total Vertical Depth, RKB: 3660' Total Vertical Depth, S5: 3608' • Please see Attachment 7: Surface Platt and (D)other information required by 20 MC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill(Form 10-401)must (1)include a plat, drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed 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 MC 25.036, or 20 MC 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; R The expected reservoir pressure in the Schrader Bluff sand is 0.44 psi/ft or 8.5 nng 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 = (3880 ft TVD)(0.44 - 0.11 psi/ft) = 1,280 psi • (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. • and OP09-S03 PERMIT Document.doc Page 3 of 7 Printed:8-Mar-11 trot EnD Deno Application for Permit to Drill Saved:8-Mar-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 25.0300; 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 1038 sx 10.7#ASLite Lead Yield 2.33 cu. Ft./sk, 13-3/8 16 68 L-80 BTC 2292' 35 / 35 2327'/ 2173' 266 sx 12.5# DeepCRETE Tail Yield 1.54 cu.ft./sk Cement Top planned @ 6678'MD Cemented w/977 sx 12.5# 9-5/8 12-1/4 40 L-80 H563i1 9775' 33 / 33 9808'/ 3862' Yield 1.54 C ETE sk ./ 8-3/4"OA Hydril 5-1/2 Sand 17 L-80 521 11,124' 9608'/ 3848' 20732'/ 3661' 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). 6(L . OP09-S03 PERMIT Document.doc Page 4 of 7 Printed:8-Mar-11 Enli �• Application for Permit to Drill Saved:8-Mar-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 MC 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 (lb/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 (Ml FazePro LS Mineral Oil Base) 13-3/8"Csg Shoe to 9-5/8"Csg Point Value Value Density(ppg) 9.4 V • Density(ppg) 8.8 - 9.5 Plastic Viscostiy Funnel Viscosity (CP) 15 25 (seconds) 45 - 60 Yield Point Plastic Viscostiy (lb/100 sf) 15 20 (CP) 12 - 18 HTHP Fluid loss Yield Point 18-24 (ml/30 min @ <5.0 (lb/100 sf) 200psi& 100°F API Filtrate Oil/Water Ratio 75/25 (cc/30 min)) 4 - 6 Electrical Stability >600 Chlorides (mg/I) <500 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 25.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well. OP09-S03 PERMIT Document.doc Page 5 of 7 Printed:8-Mar-11 0.0 "" ' En� Petirolleum �� 2�1i � Application for Permit to Drill Saved:8-Mar-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 MC 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 MC 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. 2. Spud and directionally drill 16" hole to casing point as per directional plan. Run Gyro and MWD tools as required for directional monitoring. D;,,,„ 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. OP09-S03 PERMIT Document.doc Page 6 of 7 Printed:8-Mar-11 • Tivs, enD Eni Petirolleum Application for Permit to Drill Saved:8-Mar-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 MC 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 OP09-S03 PERMIT Document.doc Page 7 of 7 Printed:8-Mar-11 M n O CNppv2-0M222O 28222NMAm0n4t2 VNaNrO�10b 24L--,2!'-' 7,22?-2m ER Mp � 0 )0 0000 0 . — momm00N.M... rr)Nn0)0p00 ' 00N,.. .-0 .220dW m0pm )0)0 )0.M1lOVV rit00O 2220m 22mm0 0002 01°°1°0 00000 1010101010 00000 •001000 000010 0001010 ..... 0m000 ..... Q mm 0) O^ 0 OON�O N°N71N71'70 0002100 II1 I0 N 1000NN� nOF Om))0�md 1000i0N N C N O)OIYmN N p �p R 1p � C 5 v0av0m rO.� 0000). 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( {i 7 § Nt 0 0 0 08 08 08 ^ m ` Umg4WL =mnsati «000 L:6L =poS ani rilis Schlumberger era WELL FIELD STRUCTURE OP09-S03 (P3) Nikaitchuq Oliktok Point Magnetic Parameters Sullace Location 99021 Alaska State Plane.Zone 04,US Feel Miscellaneous Model BOOM 2010 Dip 81010' Dale J2y 20,2011 Lel N 103039.725 Northing 603654691 BUS Grid Co..,:012580519' Slot 0509 TVD Ref. Rotary Taak(5223 above MSL) Mag Dec. 21.019' ES. 57638.971 Co... 1495148.127 Eas1419 516696901115 Scale Fact:099990032 Plan: 0509-S03(P3) Srvy Date.Feduary 28.2011 -10000 -8000 -6000 -4000 -2000 0 OP09-S03(P3) End Cry 14000 i. n — 14000 OP09S03 Tgt 21 Cry 2/100 End Cry a TD 0P09.503 Tgt 19 Cry 2/180 • End Cry Entl Cry OP09503 Tgt 17 0509503 1gt 20 Cry 2/100 Cry 2/100 End Cry End Cry OP09S03 Tgt 18 0509503 Tot 15 Cry 2/100 12000 Cry 2/180 4iid'Cry — 12000 End Cry • 0509-003 1g(16 i 0509503 Tgt 13 aN Cry 000 . Cry 2/100 End Cry End Cry 0P09503 Tgt 1/ . OP09S03 Tgt 11 e� (1'4 Cry 2/100 End Cry Cry 2(100 ,,��y OP09S03 Tgt 18 End Cry F11 • Cry 2/1130 OP09583 Tgt 9 End Cry Cry 21100 End Cry 10000 OP.O.R,S03.7gt.1t/.. QJ?St..Q7.Tgt 7....... 10000 Cry 2/190 Cry 2neRd cry End Cry 0509503 Tot 5 0509503 Tgt 8 Cry 2/109 Cry 2/100 End Cry End Cry :0P09S03 Tgt 3 OP09-503 TO 6 . Cry 2/150 Cry 000 nd Cry Alid •�, • . OP09S03 Tgt 1 A OPO@501 Tgt 4 • _ Cry 2/100 8000 OK; EHd'Cry ' .. .. "' RdGry 8000 Z Cry 2/100 0509-503 Tgt 2: Cry 2/106 O 9-5 8"Csg O O CV OP09SOJ Heel C End Cry II CD 6000 6000 V Cry 3.75/100 CO CO V V V 4000 4000 2000 2000 End Cry 13-3/8"Cs. Cry 3.5/100 Cry 0.5/100 't ' Old 2.75/100 f 0 0 KOP Old 1.5/100 RTE -10000 -8000 -6000 -4000 -2000 0 «< W Scale=1(in):2000(ft) E >>> kilmierger OP09-S03 (P3) Anti-Collision Summary Report Analysis Date-24hr Time: March 03,2011-12:13 Analysis Method: Normal Plane Client: ENI Reference Trajectory: OP09-S03(P3)(Def Plan) Field: Nikaitchuq Depth Interval: Every 5.00 Measured Depth(ft) Structure: Oliktok Point Rule Set: D&M AntiCollision Standard Slot: OP09 Min Pts: All local minima indicated. Well: OP09-S03 Borehole: OP09-S03 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 Def-Survey is set in a borehole-All Non-Def Plans when no Del-Plan is set in a borehole Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)1 EOU(ft)_Dev.(ft) Fact. MD(ft) I TVD(ft)_ Alert I Minor I Major OP10.09(Def Survey) Warning Alen 7.17 476 3.85 4.98 244.07 244.07 OSF<5.00 Enter Alert I 5.89 2.98 2.14 2.77 349.01 349.01 MinPt-CtCt 5.97 2.93 2.02 2.61 368.99 368.99 MinPt-O-EOU 6.09 2.96 2.01 2.55 378.98 378.98 MinPt-O-ADP 7.65 3.62 221 2.24 438.91 438.91 MinPt-O-SF 64.60 42.64 32.32 3.06 1018.10 1011.85 MinPt-O-ADP 90.63 56.10 39.45 2.6811 1248.75 1230.88 MinPt-O-SF 186.51 148.14 129.57 4.99 1676.84 1619.00 05F>5.00 Exit Alert 3260.27 3126.63 3060.3. irl0.. 7103.06 347548 MinP1-0-SF 3471.42 3329.53 3259.01 'LIS 7454.47 3548.18 MinPt-O-SF 3538.52 3384.19 330751 MEI, 8443.96 3742.03 MinPt-O-SF 3534.86 3380.68 3304..•=Ea 8456.55 3744.01 MinPN-0-5F 3479.23 3332..-jjjjjjj 5 23.79 8787.34 3788.97 MinPt-O-ADP 3478.8 AIME 3258.99 23.83 879624 3789.99 MinPt-0-EOU 111.M1p 3332.69 3260.44 . 24.06 8840.80 3794.88 MinPt-CtCt ' '-1 2149.71 2033.96 10.29 13737.51 3791.14 MinPt-CtCt 2383. :MOW 2031.94 10.19 13864.05 3788.86 MinPt-O-EOU 2384.81 2031_45 10.15 13925.85 3785.78 MinPt-O-EOU 2389.8'Mlni. 2028.90 9.96 14120.48 3774.52 MinPt-O-E01./ 2391.02 2149.. 9.92 14165.43 3771.92 MinPt-O-ADP 2391.80 2149.47 2028.7'jjjjjjjjjjjjjj-.11:11 1419159 3770.41 MinPt-OSE 2393.6 Man 2030.64 9.91 14379.46 3763.12 MinPt-0-EOU 2398.64 2152.2'�. ' 9.77 14544.38 375858 MinPt-O-ADP 2405.90 2156.14 2031.711M1:135'., 14679.14 375488 MinP1-0-SF 2408.79 2160. : 2036.6. 9.73 14894.95 3749.93 MinPt-O-ADP 2424.26 2169.48 2042.5'... 15149.34 3744.83 MinPt-O-SF 2427.61 w1t1111901 2051.64 9.71 15408.08 3743.84 MinPt-O-EOU 2429.50 2177.0 ognir 966 15467.93 3744.48 MinPt-O-ADP 2436.0 jSr: 2047 361: 11§1 15752.70 3747.50 MinPts 1986.42 1836.81 7.64 17895.65 3702.29 MinPt-CtCt 2287.6. 1984.6. 1833.56 7.57 18010.43 3703.83 MinPt-O-EOU j2288.43 1984 75 1833.40] 7.56 18035.42 3704.17 MinPt-O-ADP 2301.7 1991 40 1836 72 7.44 18294.99 3707.66 MinPt-0-EOU 2303.26 1971.70 WIC 7.41 18343.99 3708.56 MinPt-O-ADP 2547.63 2175.30 1989.6 111111111n 20731.70 3660.30 MinP1-0-SF 0107-04(Def Survey) WWarning Alert I 16.00 14.781 12.64 351004.00 3.88 3.88 MinPts 15.89 11.93 10.56 5.36 494.19 494.17 MinPt-CtC1 15.95 11.84 10.40 5.10 519.26 519.24 MinPt-0-EOU 16.02 11.85 10.381 503 529.29 529.26 MinP1-0-ADP 16.06 11.87 10.38 5.00 534.31 534.27 OSF<5.00 Enter Alert 38.25 25.87 20.29® 878.89 876.27 MinPt-0-SF 158.00 125.19 109.40 4.96 1372.39 1344.65 OSF>5.00 Exit Alert 524.78 449.6. 51m 2251.51 2114.01 MinPls 1221 76 1173.12 13.56 6048.85 3257.40 Miept-CIC) 1320.16 man 1172.82 13.52 6068.64 3261.50 MinPt-0-EOU 1320.33 1221.6 mum 13.50 6078.52 3263.54 MinPt-0-ADP sum. 1218.66 1164.53 12.26 6682.04 3388.39 MinPt-CtCt 1328.1.man. 116415 1222 6706.74 3393.50 MinPt-0-EOU 1328.38 1218.5.MEM 12.19 6721.55 3396.56 MinPt-0-ADP 1 1327.72' 1200.47 1137.33 10.51 7667.17 3592.18 MinPt-CtCt 1328.2 1200 01136.39 10.43 7719.08 3602.92 MInPI-0-EOU 1330.95 1200.36 1135.5 10.26 7849.55 3629.91 MinPt-O-ADP 1335.64 1202.42 1136.31 10 091 7975.29 3655.92 MinPt-0-SF 3106.49 2986.25 2926 62 26 04 9747.20 3857.59 TD 0111-01(Def Survey) Warning Alen 15.99 14.771 12.61 58276.32 3.95 3.95 MinPts 15.08 11.53 10.37 5.96 428.86 428.86 MinPt-CIC) 15.22 11.41 10.12 5.42 458.77 458.77 MinPt-0-EOU 15.54 11.48 10.051 5.03 488.67 488.66 MinP1-0-ADP 15.61 11.50 10 05 4.98 493.66 493.64 OSF<5.00 Enter Alert 97.40 55.29 34.851 2.351 1249.51 1231.59 MinPt-O-SF 233.88 185.88 16249 4.97 1875.16 1795.79 OSFx5.00 Exit Alert 1345.71 1247_89 1199.47E 13.891 5759.50 3197.54 MinPt-0-SF 1396.15f[ 1290.89 123914r 13.47 6148.81 3278.08 MinPts Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP09-S03\0P09-S03\0P09-S03(P3) 3/3/2011 12:13 PM Page 1 of 7 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ftp I EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major 1445.90 133500 1280.4/- 13.23 6457.48 3341.93 MinP1-0-SF 2265.97 2146.91 207827 16.64 8538.12 3756.39 MinPt-O-SF 2220.05 2093.1 203057 17.73 9017.86 381160 MinPt-O-ADP 2217.3 2092.661 2031.19 16.02 9078.06 3816.26 MinP1-0-EOU 2352.35 2218.81 2152 8411 17 8211 9824.82 3862.33 MinPt-O-SF NEW 2224.32 2159.76 18.23 10942.79 3879.31 MinPt-CICt 2356.6 =MC, 2155.94 17.75 11018.83 3876.46 MinPt-O-EOU 2357.8 ' 1®'�i 11255.20 3865.76 MinPts NEM 2141 99 2066 93 15 27 12233.16 3815.15 MinPt-CICt 2294.04®MMIll MEE 12316.43 3810.21 MinPts OI11-01981(Def Survey) Warning Alert riatillimmitimEml 58276.32 3.95 3.95 MinPts 111111 5 11.53 10.37 5.96 428.86 428.86 MinPt-CtCt 15.221 10.12 542 458.77 458.77 MinPt-O-EOU 15.54 11.48=I 5.03 488.67 488.66 MinPt-O-ADP 15.61 11.50 10.05 4.98 493.66 493.64 05945.00 Enter Alert I97.40 55.29 34.851 2.35' 1249.51 1231.59 MinPt-O-SF 233.88 185.88 162.49 4.97 1875.16 1795.79 OSF>5.00 Exit Alen • 1345.71 1247.88 1199. • r, 5759.50 3197.54 MinPt-O-SF 1451.84 1341.07 1286.1 111111MEE 6483.95 3347.41 MinPt-O-SF 1544.57 1428.39 1370.79 13.40 6765.84 3405.72 TD 0P03-P05PB1(Def Survey) Warning Alen IMMO 5461 52.58 739.11 64.00 64.00 MinPts 56.0. 53.79 52.69 54.78 244.00 244.00 MinPts 56.1 53651 52.83 42.65 299.00 299.00 MinPt-O-EOU 56.1' 53.65 52.86 41.74 30400 304.00 MinPt-O-EOU 77.24 64 41 58.611 6.55 952.77 948.48 MinPt-O-ADP t 83.50 65.75 57.49 4.98 1054.16 1046.60 OSF<5.00 Enter Alert 88.67 66.88 MZEZ 4.25 1119.56 1109.17 MinPt-O-ADP 109.40 78.10 63.061'i1 1248.22 1230.39 MinPt-O-0F 163.58 129.69 113.36 4.97 144422 1409.70 OSF>5.00 Exit Alen 2626.81 2562.59 2530.9 MaIRE 462020 2961.86 MinPt-O-SF OP03-P05(Del Survey) Warning Alen 5461 52 58 739.11 64.00 64.00 MinPts =721 53.7 526 54.78 244.00 244.00 MinPts 5616_ 5365 52.83 4265 29900 299.00 MinP1-0-EOU 56.19 53.65 52.86 41.74 304.00 304.00 MinPt-O-EOU 77 24 64.41 58.611 6.55 952.77 948.48 MinPt-O-ADP 83.50 65.75 57.49 4.98 1054.16 104660 OSF<5.00 Enter Alert 88.67 66.8811IME 4.25 1119.56 1109.17 MinPt-O-ADP 109.40 78.10 63.061 1248.22 1230.39 MinPt-O-SF 163.58 12969 113.36 4.97 1444.22 1409.70 OSF>5.00 Exit Alert 2542.2.MUM 2444.72 39.49 4609.81 2959.71 MinPt-O-EOU 2542.92 2477.01 39.15 4645.36 2967.07 MinPt-O-ADP M=1:1. 2407.80 2365.19 29.25 5864.10 3219.18 MinPt-CtCt 2495.0 ' 1 2363.64 28.68 5968.33 3240.74 MinPt-O-EOU 2496.54 2407.4.IIIIIMIR 28.31 6038.01 3255.16 MinPt-O-ADP 1. 2626.461. 2445.74 21.91 7642.22 3587.02 MinPt-O-EOU MO 2499.40 2435.94 20.69 7993.35 3659.64 MinPl-CtCt 2627.41 2499.151 2435.52 20.64 8033.10 3687.72 MinPt-O-EOU 2627.45 2499.1611IEME20.63 8036.89 3668.49 MinPt-O-ADP 2628.27 2499.78 2436.0.9'''.. 8065.56 3674.22 MinP1-0-5F 3608.15 3487.47 3427.62 30.14 8943.24 3805.10 TD OP03-P08PB2(Def Survey) Warning Alert 5 91 54.61 52.58 739.11 64.00 64.00 MinPts 56.02 53.797 5269 54.78 244.00 244.00 MinPts 5616 53.65 52.83 42.65 299.00 299.00 MinPt-0-EOU 56.19 53.65 52.86 41.74 30400 304.00 MinPt-O-EOU 77.24 64.41 58.611 6.55 95277 948.48 MinPt-O-ADP 83.50 65.75 57.49 4.98 1054.16 1046.60 OSF<5.00 Enter Alen 88.67 66.8•Mal 4.25 1119.56 1109.17 MinPt-O-ADP 109.40 78.10 63.061 1248.22 1230.39 MinPt-0-SF 163.58 129.69 113.36 4.97 1444.22 1409.70 OSF>5.00 Exit Alert 2542.2.=MM. 2444.71 3949 4609.81 2959.71 MinP1-0-EOU 2542 92 2477.01 39.15 4645.36 296707 MinPt-O-ADP L 2494 021 2407.80 2365.19 29.25 5864.10 3219.18 MinPt-CtCt 2495.071111111111'. 2363.64 28.68 5968.33 3240.74 MinPt-O-EOU 2496.54 2407.4 . 28.31 6038.01 3255.16 MinPt-O-ADP 2626 46 1 2445.74 21.91 7642.22 3587.02 MinPt-O-EOU MIME. 2499.40 2435.94 20.69 7993.35 3659.64 MinPt-CtCt 2627.38 2435.54 20.64 8029.31 3666.96 MinPI-O-EOU 2627.39 2499.16=.'i 20.64 8031.20 3667.34 MinPl-0-ADP 2628.25 2499.88 2436.1•11111111SIE 8065.55 367422 MinP1-0SF 2656.28 2527.49 2463.58 20.78 8196.23 3699.34 TD 0912-01(Def Survey) Warning Alen ® 22151 49.85 13262 132.62 MinPts 23.93 Wain1 20.60 33.08 172.62 172.62 MinPt-O-EOU 24.05 20.73 28.00 192.61 192.61 MinP1-0-EOU 25.03 22.25111118= 15.30 287.56 287.56 MinPt-O-ADP 50.79 39.61 3463 4.98 760.67 759.71 OSF<5.00 Enter Alert 123.60 90.79 75.00 1110.39 1100.43 MinPt-O-SF 208.20 165.52 14479 4.99 1349.63 1323.92 OSF>5.00 Exit Alert 3982.20 3828.72 375247 Il 8606.24 3766.10 MinPt-O-OF Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP09-S03\OP09-S03\0P09-S03(P3) 3/3/2011 12:13 PM Page 2 of 7 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 3881.48 3738.45 3667.43 27.32 8991.53 3809.40 MinPt-O-ADP 3881.01 3738 3f 3667.56 27.39 9002.47 3810.32 MinP1-0-EOU 1 3880 46 3738 92 3668.65 27.60 9032.82 3812.81 MinPt-CtCt 3614 97 3451.71 3370.5 MEM 11795.21 3844.09 MinPt-O-SF 3108.16 2868.02 2748.4- 12991 14181.65 3770.98 MinPt-O-SF 3054 06 2808 0. 2685 47''® 14906.91 3749.69 MinPts OPO4-07(Del Survey) Warning Alert 47 21 44 641 43.8 34.01 278.84 278.84 MinPts 47 32 44 56 43.79 30.00 318.84 318.84 MinPt-O-EOU 47.45 44 55 43.7 28.26 338.84 338.84 MinPt-O•ADP IL 48.15 4384 42.30 15.24 560.34 560.28 MinPt-CICt 48.29 43 70 42.02 13.98 590.62 590.51 MinP1-0-EOU 48.78 43.77 41.87 12.56 626.09 625.90 MinPt•0•ADP 67,46 55.87 50 69l-n3.91 1064.50 1056.53 MinPt-O-SF 246.81 196.58 171.95 4.99 5520.16 3148.03 OSF<5.00 Enter Alert 240.56 171.87 138.01 3.54 5986.47 3244.50 MinPl-C1Ct 249.2 164,16 122.1444444 2.95 6382.98 3326.52 MinP1-0-EOU 261.75 166.87 120.2 2.79 6621.99 3375.97 MinPt-O-ADP 278.96 176.33 125.50 2.731 6846.50 3422.41 MinPt-O-SF 336 06 218 71 160.5 2.8 7376.12 3531.97 MinPt-0-SF 1 365.5 234 59 169.62 2.81 7996.85 3660.36 MinPt-CICt 365 6 234 51 169.45 2.80 8013.22 3663.70 MinPt-O-EOU 365.64 234.511 169. 2.80 8017.31 3664.53 MinPt-O•ADP 365.91 234.65 169.51 2.801 8033.67 3667.84 MinPt-O-SF 616.74 492.42 430.75 4.99 8754.06 3785.10 OSF>5.00 Exit Alert 2991,85 2879.39 2823.64 26.83 10441.19 387843 TD 0PO4-07P81(Del Survey) Warning Alen 47.21 44.67 34.01 278.84 278.84 MinPts 47.3 44.56 43.79 30.00 318.84 318.84 MinPt-O-EOU 47.45 44.5 43.771 28.26 338.84 338.84 MinPt-0•ADP 48.1 43.84 42.30 15.24 560.34 560.28 MinPt-CtCt 48.29 43.70 42.02 13.98 590.62 590.51 MinPt-O-EOU 48.78 43,77 41.87 12.56 626.09 625.90 MinPt-O-ADP 67.48 55.87 50.6 6.34 1064.50 1056.53 MinPt-O-SF 246.81 196.59 171.97 4.99 5520.16 3148.03 OSF<5.00 Enter Alert I 240. 171.88 138.03 3.54 5986.47 3244.50 MinPt-CtCt 249:0 164.171 122.15 2.95 6382.98 3326.52 MinPt-O-EOU 261.15 166.8 120.2 120.2 2.79 6621.99 3375.97 MinPt-O-ADP 278.96 176.33 12561 2.73 6846.50 3422.41 MinPt-O-SF 336.06 218.72 1605 2. 7376.12 3531.97 MinPt-0-SF 1 365,52 234.61 169.64 2.81 7996.85 3660.36 MinPt•CtC1 365.60 234.521 16947 2.80 8013.22 3663.70 MinPt•O-EOU 365.64 234.5 169.46 2.80 8017.31 3664.53 MinPt-0-ADP 365.91 234.66 169.5 2.801 8033.67 3667.84 MinPt-O-SF 616,74 49243 430.77 4.99 8754.06 3785.10 OSF>5.00 Exit Alert 1737.43 1613.88 1552.59 14.17 9891.57 3866.13 TD OP08-04P51(Def Survey) Warning Alert I 7.98 6.76 4.651 193944.70 0.00 0.00 MinPts 8.361 6.10 5.04 6.85 188.89 188.89 MinPt-O-EOU 9.43 6.54 5.71 4.93 238.86 238.86 OSF<5.00 Enter Alert 12.68 8.91 7.6 L 298.72 298.72 MinPt-O-SF 19.49 14.60 12.77 4.98 378.36 378.36 OSF>5.00 Exit Alert 46.05 35.83 31.33 4.98 813.44 811.88 OSF<5.00 Enter Alert 47.51 36.33 31.36 4.65 915.68 912.31 MinP1-0-EOU I 48.55 36.5 311 4.40 1007.71 1001.80 MinPt-O-ADP 62.10 45.71 38.1 4.011 1248.24 1230.41 MinPt•0•SF 90.55 71.42 62.47 4.99 1516.59 1475.03 OSF>5.00 Exit Alert 121.38 97.86 86.7.MEM 1903.06 1820.53 MinPt-O-SF 138.72 109.96 96.19 4.99 2255.73 2117.32 OSF<5.00 Enter Alert 138.4.jjjjjjjjj) r 0 r 0,: 4.77 2303.74 2154.47 MinPts 90.36 70.95 3.33 2634.68 2384.92 MinPt-CtCt 130.5- 70.00 3.26 266924 2406.17 MinPt-O-EOU 130.90 89.91 69.91 3.25 2683.90 2415.01 MinPt-0-ADP 131.91 90.48 7026 jjjjjjjjjjjjjjEIEE 2708.12 2429.40 MinPt-O-SF 180.37 143.33 125.31 4.98 2934.29 2549.52 OSF>5.00 Exit Alert 283.82 226.09 197.71 4.98 7120.85 3479.17 OSF<5.00 Enter Alert 259. 177.02 136.41 3.18 7413.27 3539.66 MinPt-CICt 263.81 171.8 126.33 2.89 7492.03 3555.95 MinPt-O-EOU 268.83 172.84 125.36 2.82 7523.92 3562.55 MinPt-O-ADP 302.75 190.61 135.03 2.711 7672.92 3593.37 MinP1.0-SF 662.67 528.99 462.64 4.99 8522.56 3754.09 OSF>5.00 Exit Alert 714.61 583.39 518.28 5.48 8656.46 3772.87 TD OP08-04(Del Survey) Warning Alert 7.98 6.761 4651 193944.67 0.00 0.00 MinPts 8.341 6.10 5.04 6.85 188.89 188.89 MinPt-O-EOU 9.43 6.54 5.71 4.93 238.86 238.86 OSF<5.00 Enter Alert 12.68 8.91 7.6 MIME 298.72 298.72 MinPl-OSF 19.49 14.60 12.77 4.98 378.36 378.36 OSF>5.00 Exit Alert 46.05 35.83 31.33 4.98 813.44 811.88 OSF<5.00 Enter Alert 47.51 MEM 31.36 4.65 915.68 912.31 MinPt-0-EOU 48.55 36.57 M', 4.40 1007.71 1001.80 MinPt-O-ADP 62.10 45.71 38.1 1248.24 1230.41 MinPt-0•SF 90.55 71.42 62.47 4.99 1516.59 1475.03 OSF>5.00 Exit Alert 121.38 97.86 86.7 =EZZ 1903.06 1820.53 MinPt-0.SF Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP09-S031OP09-S03\0P09-S03(P3) 3/3/2011 12:13 PM Page 3 of 7 I 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 138.72 109.9696 19 4.99 2255.73 2117.32 OSF<5 00 Enter Alert 136.4.jj)5ii a• 4.77 2303.74 2154.47 MinPts pppp)j) 90 36 70 95 3.33 2634.68 2384.92 MinPt-CtCt 130.5.p)� 70 00 3.26 2669.24 2406.17 MinPt-0-EOU 130.90 89.91®' 3.25 2683.90 2415.01 MinPt-0-ADP 131.91 90.48 70.26'. 2708.12 2429.40 MinPt-0-SF 180.37 143.33 125.31 4.98 2934.29 2549.52 OSF>5.00 Exit Alert 28382 226.09 197.72 4.98 7120.85 3479.17 OSF<5.00 Enter Alen 259.2 177.02 136.41 3.18 7413.27 3539.66 MinPt-CIC. 263.81 171.83 126.34 2.89 7492.03 3555.95 MinPt-O-EOU 268.83 1728 1253 2.82 7523.92 3562.55 MinPt-0-ADP 302.75 190.62 135.01 2.711 7672.92 3593.37 MinPt-O-SF 656.94 524.24 458.38 4.98 8586.81 3763.39 OSF>5.00 Exit Alert 1020.19 894.79 832.5: 10282.47 3876.69 MinPt-0-SF 1019.9.1 895.89 834.34 8.28 10779.97 3881.59 MinPt-CtCt 1023.5r''_ 827.55 786 10914.06 3880.09 MinPt-0-EOU 1026.95 893.1. 826.67 T72 10969.15 3878.45 MinPt-0-ADP 1053.13 911.68 841.4• 6 11248.87 3866.05 MinPt-0-SF 1062.73 922.15 852.35® 11489.51 3856.22 MinPt-0-SF 0106-05(P9)(Def Plan) , Pass 32.00 30.78 2867 N/A 0.00 0.00 Surface _ 28.97 28.06 17.03 300.00 300.00 MinPt-CIC. !MECO 26.98 12.06 475.29 475.28 MinPt-CtCt 28 6 26 3206_1MM 26.94 11.87 490.31 490.30 MinPt-0-EOU 32.07 28.2 .MEIC 11.82 495.31 495.30 MinPt-O-ADP 32.26 NEE= 26.76 10.90 520.29 520.26 MinPt-0-EOU 32.47 28.23 MEM 1936 535.24 535.20 MinPt-0-ADP • 41.23 35.00 32. .NM= 663.43 663.12 MinPt-O-SF 372.47 347.94 336. ,..MEIZE. 1270.03 1250.66 MinP1-0-SF 4240.55 4170.2• 61.18 4165.27 2867.75 MinPt-0-ADP wpm 3809 7 c.IIMIIM. 8084.31 3677.93 MinPts 4045.28 3904.90 3835.2.1iii111111M 8175.32 3695.44 MinPt-0-SF 5467.14 5320.94 5248.33 37.64 8980.61 3808.45 TD OP75.08(P7)(Def Plan) Pass 64.01 62.79 60.69 N/A 0.00 0.00 Surface MOD 61.38 60.67 44.46 250.00 250.00 MinP1-CtCt 64.16=3Erj 60.34 36.27 305.00 305.00 MinP1-0-EOU 64.26 61.22®'' 34.79 320.00 320.00 MinPt-O-ADP 98.63 88.3783.7.IE, 693.07 692.61 MinPt-0SF 110.13 98.70 93.60--- 74091 740.12 MinPI-0-SF 252.83 230.21 219.51_ 1085.35 1076.51 MinP1-0-6F 316.38 288.01 274.4 I_ 1184.20 1170.40 MinPt-0SF 360.19 327.94 312A 1- 1242.99 1225.52 MinPt-0-SF 3224.73 3170.79 3144.3 ,_ 3404.92 2710.46 MinPl-0-SF 9450.06 9308.01 9237.47' 60.991 7028.22 3460.00 MinPt-0-SF 6998.00 6842.37 6765.0 1.111111E1 8899.28 3800.90 MinPt-0-SF 7700.55 7307.63 7111.66 19.64 20731.70 3660.30 TD 7610.88 7336.24 7199.41,_ 15201.81 3743.95 MIOPI-0-SF • 7619.21'.M5IZE= 7199.36',jjjjjj11M; 15758.24 3747.56 MinPts Oliktok Point I-2PB1(Del Survey) Pees 64.51 63.39 61.18 N/A 0.00 0.00 Surface '_ 63.39 M N/A 40.00 40.00 MinPts MEE 46,68 43.68 8.79 695.04 694.58 MinPt-CtCt 53.87_ 43.51 8,56 709.95 709.40 MinPt-O-E01.1 53.94 46.61®" 8.49 714.92 714.33 MinPt-O-ADP 123.45 104,58 95.7011111111111111110 1051.83 1044.36 MinPt-OSF 3941.49 3857.94 3816.6 I*"' 4783.73 2995.69 MinPt-0-SF 4253.09 4163.04 4118.51_ 5056.34 3052.08 MinPt-0-SF O5ktok Point 1-2(Del Survey) Pass 64.51 63.39 61.18 N/A 0.00 0.00 Surface OEM 63.3'_. N/A 40.00 40.00 MinPts _ 46.68 43.68 8.79 695.04 694.58 MinPt-CtCt 53.87_ 43.51 8.56 709.95 709.40 MinPt-0-EOU 53.94 46.61 ME 8.49 714.92 714.33 MinPt-O-ADP 123.45 104.58 95 70 6.89 1051.83 1044.36 MinPt-0SF 5733.96 5575.13 5496.2.1_. .i 8598.19 3764,98 MinPI-0-SF 1 441565®®I_, 15555.05 3745.40 MinPts I Oliklok Point I-2PB2(Def Survey) Pass 64 51 63.53 61.18 N/A 0.00 0.00 Surface MI101. 63.39 MEM N/A 40.00 40.00 MinPts _ 46.70 43.72 8.83 695.04 694.58 MinPt-CtCt 53.87 Nom43.55 8.59 709.95 709.40 MinPt-O-EOU 53.94 46.63_ 8.53 714.92 714.33 MinPt-O-ADP 123.45 104.58 95.71_ 1051.83 1044.36 MinPt-0-SF 5733.96 5575.13 5496.21 6*lr 8598.19 3764,98 MinPt-0-SF r 4895.2 I 4700 7.1 4604.07,_, 12743.26 380594 MinPts 0114.08(P3)(Def Plan) Pass L_6856.681 6626.74 6512.26 29.94 15714.38 3747.09 MinPt-CtCt 55,97 54,74 52.64 N/A 0.00 0.00 Surface 55.97 53.14 52.33 34.04 275.00 275,00 MinPt-CtCt 56.06 53.011 52.10 29.97 315.00 315.00 MinPt-0-EOU Drilling Office 2.0.930.0 Nikaitchttq\Oliktok Point\OP09-S03\0P09-S03\OP09-S03(P3) 3/3/2011 12:13 PM Page 4 of 7 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 56.15 53.02 52.07 28.88 330.00 330.00 MinPt-O-ADP 130.23 113.81 10621 8.49 885.48 882.74 MinPt-0SF 282.29 249.58 233.8 8.9 1249.16 1231.27 MinPl-0SF 8115.65 7967.64 78541 55.2 8777.34 3787.83 MinPt-O-SF 8094.88 7949.9 7877.91 56.21 8895.07 3800.48 MrnPt-O-ADP 8094.71 7949.87 7877.94 56.26 8900.26 3800.99 MinPt-O{OU 8094.54 7950.03 7878.26 56.39 8911.94 3802.13 MinPt-CtCt 6510.27 6251.25 6122.24 25.23 17677.80 3701.04 MinPt-CtCt 6510.73 6250.7 6121.31 25.14 17722.80 3701.08 MinPt-O-EOU 6511.35 6250.90 6121.17 25.09 17747.79 3701.10 MinPt-O-ADP 6740.33 6428.29 6272 77 21.67 20160.75 3691.01 TD 6857.3 6626 881MEEMINEM 15797.98 3747.79 MinPts OP05.06PB2(Del Survey) Pass 39.76 37.88 36.43 58.32 153.94 153.94 MinPts 39.82 37.83 36.50 49.86 173.94 173.94 MinPI-0-EOU 135.21 119.10 111.66 9.00 968.02 963.33 MinP1-0-SF 158.56 139.98 131.3. ,4 1027.49 1020.91 MinPt-O-SF 193.85 171.62 161.11 4 110720 1097.40 Mirl141-0SF 5374.58 5338.93 76.38 5017.35 3044.02 MinPt-C1C] 5447.0211.1M 76.08 5041.96 3049.11 MInPI-O-EOU 50.73 7.24 53744 _5338.66 5 . 75.90 5258,91 3094.1600 MinPt-0-ADP 72.85 5258,96 3094.00 MinPI-O-EOU 5451.20 5375 0 72.49 5283.51 3099.08 MinPI-O-ADP 5485.51 5398.1.ME= 63.46 5912.02 3229.10 MinPt-O-ADP 5491 0•�'- '. 5351.52 59.45 6255.05 3300.06 MinPt-0-EOU MUM5202.22 5138.65 41.91 8028.03 3666.70 MinPt-CtCI 5330.36,1111=11MIEri 41.91 8029.20 3666.94 MinPts 5400.03 5268.36 5203.0. 8211.51 3702.17 MinPt-O-SF 5433.99 5301.17 5235.2 MICESZI. 8258.43 3710.69 MinPt-O-SF 6135.23 5996.04 5926.94 44.39 8669.21 3774.54 TD 0005-06PB1(Del Survey) Pass 39.76 37.88 36.43 58.32 153.94 153.94 MinPts 39.82 37.83 36.50 49.86 173.94 173.94 MinPt-O-EOU 135.21 119.10 111.66 9.00 968.02 963.33 MinPt-0-SF 158.56 139.98 131.3. 1027.49 1020.91 MinPt-O-SF 193.85 171.62 161.11 mug 1107.20 1097.40 MinPt-O-SF 5066.24 5019.96 4997 32 '11.83 3129.42 2631.42 TO OP05-06(Del Survey) Pass 39.76 37.88 36.43 58.32 153.94 153.94 MinPts 39.82 37.83 36.50 49.86 173.94 173.94 MinPt-0-EOU 135.21 119.10 111.66 9.00 968.02 963.33 MinPt-O-SF 158.56 139.98 131.3.1®r1 102749 1020.91 MinPt-OSF 193 85 171.62 161.11 MEM 1107.20 1097.40 MinPt-0-SF • ®J 5374.59 5338.94 76.38 5017,35 3044.02 MinPt-CtCt ' 5447.021j 5338.66 76.08 5041.96 3049.11 MinPt-0-EOU 5447.24 5374.5.')) 8] 75.90 5056.71 3052.16 MinPt-O-ADP 545a 73a2=1 5337.54 72.85 5258.96 3094.00 MinPt-0-EOU 5451.20 5375.0-0)p 72.49 5283.51 3099.08 MinPt-O-ADP 5485.51 5398.1.' 1 63.46 5912.02 3229.10 MinPt-0-ADP 5491...{))))) 'ii' 5351.53 59.45 6255.05 3300.06 MinPt-O-EOU 5202.22 5138.64 41.91 8028.03 3666.70 MinPt-CtCt 5330.3.)))))))M21,)��I. 41.91 8029.20 3666.94 MinPts 5400.03 5268,35 5203.0.') 8211.51 3702.17 MinP1-0-SF 5433.99 5301.16 5235.2 MUM 8258.43 3710.89 MinPt-O-SF 6983.82 6840.21 6768.90 48.96 8943.18 3805.09 TD OP21-WW01(P1 b)(Del Plan) Pass 119.98 118.76 116.66 N/A 0.00 0.00 Surface I 119.98 116.17 114.87 45.85 400.00 400.00 MinPI-CtCt 120.17 115.99 114.52 40.26 443.99 443.98 MinPt-O-EOU 120.44 116.05 114.47 37.65 468.42 468.41 MinPt-O-ADP 201.68 183.40 174.88 11.761 1232.51 1215.74 MinPt-O-SF 6610.79 6555.39 6528.18 121.47 6909.19 3435.38 TD OP16-03(P6)(Del Plan) Pass 72.00 70.78 68.67 WA 0.00 0.00 Surface EI 68.19 66.89 27.33 400.00 400.00 MinPt-CIC. 72.05 M.312 66.80 26.40 414.80 414.80 MinP1-0-EOU 72.08 68.14 66 79 26 12 419.73 419.73 MinPt-0-ADP 183.40 166.98 159 3811111:01 968.16 963.46 MinPt-O-SF 214.97 195.92 187.00 Min 1032.24 1025.49 MinPt-O-SF 10663.03 10531.67 104664•. 6871.35 3415.14 MinPt-O-SF 8681.55 8527.42 8450.8 1 56 68 9864.01 3864.63 MinPt-O-SF 9429.39 9272.64 9194.75 8627.35 3768.98 MinPt-O-SF 8533.06 8390.34 8319.4: 60.20 9078.10 3816.26 MinPt-O-SF 8536.37 8368.67 8285.31, 11795.35 3844.08 MinPl-O-SF MEW 8009.98 7895.77 36.07 13514.49 3791.22 MinPt-CtCt 8239.5' 8009 731 7895 35 36.00 13522.27 3791.18 MinPt-0-EOU 8239.84 8009.811 7895 281 35.97 13526.15 3791.16 MinPt-O-ADP 8368.11 8103.85 7972 21=OW 15773.72 3747.69 MinPt-O-SF 8353.52 8091.50 7960 99 32.00 15922.79 3746.30 MinPt-O-ADP 8353.37 809148 706103 32.01 15930.41 3746.10 MinPt-0-E05 ® 8091.61 7961.28 32.04 15945.67 3745.65 MinPt-CtCt 8350 98 8086.14 7954.22 31.65 16221.40 3732.53 MinPt-CtCt 835228 8085 Obi 7951.94 31.37 76354.62 3727.22 MinPt-O-EOU Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP09-S03\0P09-S03\0P09-S03(P3) 3/3/2011 12:13 PM Page 5 of 7 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor Alert Status Ct-Ct(ft)I EOU(ft) Dev.(ft), Fact. MD(ft) I TVDsft) Alert I Minor I Major 8353.56 8085.33. 7951.70 31.25 16409.24 3726.59 MinPt-O-ADP 8585.11 8206.95 8018.37 22.76 20731.70 3660.30 TD 83433. 8087.2•', 7959.77 32.71 15420.04 3743.97 MinPt-O-EOU 8344.42 8087. 7959.56 32 60 15454.99 3744.34 MinPt-O-ADP 8332.84 8086.08 7963.1•i`.11 14325.55 3764.62 MinPt-O•SF 8391 53 8136 94 8010.1 14726.02 3753.63 MinPt-O-SF 8371.3,' 8106821�� 15756.33 3747.54 MinPts 0113.03(P3)(Def Plan) Pass 47.97 46.75 44.65 N/A 0.00 0.00 Surface Ilinal 45.34 44.63 33.08 250.00 250.00 MinPt-CtC1 48.26 44.89 43.82 21.99 369.98 369.98 MinPt-O-EOU 48.37 44.91 43.80 21,11 384.96 384.96 MinPt-O-ADP 48.6 44 96 43.73 19.24 409.84 409.84 MinPt-O-EOU 48.92 45.03 43.69 17.86 42468 424.68 MinPt-O-ADP 256.70 206.69 182 30 gm. 1251.25 1233.21 MinPl-O-SF 4775.93 4613.14 4532.231ME1.1I 8652.96 3772.41 MinPt-O-SF 4613.43 4466.7• 4393.8.1 31.66 9122.18 3819.33 MinPt-O-ADP 4612.2' 4466.50 439410 31.84 9141.37 3820.58 OIMEMI 4463 95 4385.27 29.37 9868.67 3864.90 MinPt-CtCI 4393.34 422A 18111EMC.MOE 11747.42 3846.25 MinPts 3953.0 3713.70 3594.50 16.58 13577.96 3791.01 MinPt-CtCt 3883.0 3608.87 3472.29 14.21 16284.39 3729.42 MinPt-CtCt 3879.47 3584.10 3436.90 13.17 17272.51 3702.23 MinPl-CtCt 3880.9 3581.99' 3433.02 13.02 17561.18 3700.94 MinPl•0-EOU 3881.92 3582.1 3432.8 3432.8 12.999J 17621.16 3700.99 MinPt-O-ADP 4133.81 3785.64 3612.0 11.901 20731.70 3660.30 MinPt-O-SF OP23-W W02(Def Survey) Peas ® 132.51=HEE 112.86 267.98 267.98 MlnPts ® 132.21 131.46 89.17 329.00 329.00 MinPt.GtCt 3_,01�. 131.29 80.58 364.00 364.00 MinPt•O-EOU MEC 131.88 130.93 70.32 408.77 408.77 MinPt-CtCt 135.03 130.87 68.34 418.52 418.52 MinPt-O-EOU 135.06 131.85=Ea67.38 423.39 423.39 MinPt-O-ADP 135.40 131.9!INEKEz 61.22 457.51 457.51 MinPt-O-ADP 250.58 232.38 223.89 mom 1249.88 1231.94 MinPt-O-SF j 22.72 2695.96 2422.21 MinPis 505.48 482.21 471.1.® 2708.18 2429.43 MinPI-0-SF 5817.30 5761.35 5733.86 105.81 8776.15 378769 TO Oliktok Point I-IA-106(P5)(Dei { Plan) •Pass 72.55 70.63 6922 N/A 0,00 0,00 Surface 72.55 7063 69.22 198426.11 40.10 40.10 MinPts 72.85 7053 69.32 342.39 84.20 84.20 MinPt-O-EOU 300.03 267.11 251.60 1251.29 1233.26 MinPt-O-SF 6456.34 8389.15 6356.04 97.50 4444.90 2925.60 MinP1A•EOU 6456.40 6389.16 6356.04 97 44 4448.82 2926.41 MinPI-O-ADP 6573.87 6427.33 6354.55 45.16 7966.98 3654.20 MinPt-O-ADP 7081.48 6911.08 6826.38 41.91 8469.39 3746.01 MinPt-O-SF 8189.68 8005.07 7913.26 44.59 8859.99 3796.91 TD Oliklok Point I-1(Def Survey) Pass 7255 70.63 69.22 N/A 0.00 0.00 Surface 72,55 70,63 69.22 198426.11 40.10 40.10 MinPts 72.65 70.53 69 32 342 39 84.20 84.20 MinPt-O-EOU 300.03 267.11 251 60! 9 81 1251.29 1233.26 MinPt-O-SF 6233.85 maim 6089 0 MEE 5009.18 3042.33 MinPts 0118-07(P8)(Def Plan) Pass 87.99 8c,- 84.67 N/A 0.00 0.00 Surface MEMO 85.36 84.65 61.43 250.00 250.00 MinPt-CtCt 88.06 imEgEo 84.51 55.92 275.00 275.00 MinPt-O-EOU 88.09 85.29 IMEMO 55.11 280.00 , 280.00 MinPt-O-ADP 16499 153.98 149 09 781.58 780.40 MinPt-OSF 470.18 440.47 426.22 Marl 1249.79 1231.86 MinPt-O-SF 5406.46 5352.17 5325.5. 3404.22 2710.31 MinPI.O-SF 10481.33 10385.84 103385'mum 5166.28 3074.83 MinPI.O-SF 8391.34 8229.84 8149.51 SW* 9856.33 3864.20 MinPt-O-SF 8242.79 8093.20 8018.'.®, 9076.34 3816.13 MinPt-O-SF 9464.57 9224.05 9104.21. 13456.83 3791.61 MinPt-O•SF 9650.88 9305.77 9133.70 28.04 20731.70 3660.30 TD 9927.33 9658.91 95251•lIMMIE 15750.43 3747.48 MinPt-O•SF OP26-DSP02(Def Survey) Pass mgin=Er"• y. 347.99 N/A 3.99 3.99 MinPts mom 325.98 32171 39.16 904.34 901.22 MinPt-CtCt 337.07 mom 320.59 34.52 952.40 948.13 MinPt-O-EOU 338.08 325.6:igigml 32.05 983.01 977.88 MinPt-O-ADP 340.02 326.30 28.65 1026.72 1020.17 MinPt-O-ADP 347.58 328.9:.. 20.72 1153.19 1141.11 MinPt•O•ADP 363.76 338.33 326.57T® 1340.84 1315.90 MinPt.O-SF 496.15 459.69 442.41�� 2324.22 2170.05 MinPt-0-SF 522.98 484.55 466.22® 2582.30 2351.64 MinPt-0SF 528.55 489.71 471.18® 2631.99 2383.24 MinPI-O-SF 3430.85 3379.94 3355.36[- 6656.04 3383.01 MinPt-O-SF Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP09-S03\OP09-S03\OP09-S03(P3) 3/3/2011 12:13 PM Page 6 of 7 Offset Trajectory Separation Allow Sep. Reference Trajectory Separation Factor AlertStatus Ct-Ct(ft)1 EOU(ft) Dev.(ft) Fact. MD(ft) I TVD(ft) Alert I Minor I Major OP25-DSPO1(P1)(Def Plan) en 1 366.13 362.25 360.80 125.93 400.00 400.00 MinPt-CtCt 366.29 362.11 360.52 114.51 431.79 431.79 MinPt-O-EOU 366.44 362.14 360.48 110.18 44542 445.41 MinPt-O-ADP 535.44 519.98 512.75 36.941 1251.28 1233.24 MinPt-OSF 4131.18 4113.19 4104.69 242.90 3104.10 2621.98 TD OP17.02(Del Survey) Pass =. 79.00 76.66 N/A 0.00 0.00 MinPts 80.74 77.41 77.95 223.92 223.92 MinPt-O-EOU 81.41 78.63 A aa{ 51.53 273.87 273.87 MIOPI-O-ADP 83.43 79.24iii8 378.68 378.68 MinPt-O-ADP 107.86 99.74 96 21 655.11 654.83 MinPt-O-SF i 262.56 246.35 238.86'!MEM 1109.51 1099.60 MinPt-0-SF 339.18 318.18 308.2.,MMICE 1251.15 1233.12 MinPt-O-SF 7038.78 6879.77 8800.76:01 8557.38 3759.19 MinPt-O-SF 7032.35 6873.49 6794.56 M:111: 8567.92 3780.71 MinPt-O-SF 6976.75 6819.26 6741.01 MEM 8654.17 3772.57 MinPt-O-SF 8741.63 6597.7:. • 47.18 9087.42 3816.93 MinPt-O-ADP 6739.41,1 6527.04 47.80 9130.36 3819.87 51inP1-0-EOU NZ}Mirk 5033.62 4884.72 17.90 17685.10 3701.05 MinPt-CtC1 5333.3 'il0•=1 4882.95 17.80 17755.07 3701.11 MinPt-O-EOU 5334.47 5032.99882.751 17.75 17790.04 3701.14 MinPt-O-ADP 5517.95 5170.47149-9-i 22J 15.92 19802.29 3721.08 MinP1-0-ADP 5516.2 5161.15 4984.12 15.58 19898.23 3707.74 MinPt-CtCt 5517.3 5160.03 4981.88 15.48 19983.13 3702.33 MinPt-O-EDU 5521.5 5158.75 4977.84 15.26 20192.57 3688.99 MinPt-O-EOU 5522.52 5158.941, 4977,63 15.23 20222.16 3687.13 MinPt-O-ADP 5595.72 5218.65 5030.61 14.881 20731.70 3660.30 MinP1-0-SF OP17-02P81(Def Survey) I Pass 7/99 ® N/A 0.00 0.00 MinPts • 60.41 7716 89.46 193.94 193.94 MinPt-O-EOU 80.74 MEM 7741 68.30 223.92 223.92 MinPt-O-EOU 81.33 7847 49.10 268.88 268.88 MinP1-0-ADP 83.43 79.13 26.71 378.68 378.68 MinPt-O-ADP 102.90 95.01 91 68®I 626.97 626.79 MinPt-O-SF 110.56 102.10 98.48® 669.21 668.88 MinPt-O-SF 262.56 246.22 238 661.1.116:1 1109.51 1099.60 MinPt-O-SF 339.18 318.08 308.1•;'"„ 1251.15 1233.12 MinPt-O-SF 6983.45 6825.71 6747.3•111== 8643.87 3771.20 MinPt-O-SF 6741.63 6597.7'MIIMEEI 47.18 9087.42 3816.93 MinPt-O-ADP 6739.4• , 6527.03 47.80 9130.36 3819.87 MinPt-O-EOU 5386.6' 5094.05 4948.22 18.47 17437.44 3700.83 MinPt-CtCt 5387.5.MESE 4946.73 18.37 17497.42 3700.88 MinPt-O-EOU 5402.23 5095.717.68 17981.44 3703.44 MinPt-O-ADP 5407.06 5096.0 4941.07, 17.44 18156.32 3705.79 MinPt-O-EOU 5408.58 5096.31' 4940 66; 17.37 18206.27 3706.47 MinPt-O-ADP • 5544.86 5194.42 5019 7(11 15.86 19706.82 3718.14 MinPt-O-ADP 5666.72 5289.29 5101 06 15.05 20731.70 3660.30 TD It 5717.4011 5458 20) 5329 091n-1122 1 15148.13 3744.86 MinPts Drilling Office 2.0.930.0 Nikaitchuq\Oliktok Point\OP09-S03\0P09-S03\0P09-S03(P3) 3/3/2011 12:13 PM Page 7 of 7 Schlumberger TRAVELING CYLINDFlt PLOT Client: ENI NoGo Region EOU's based on: Well: OP09-S03 Oriented EOU Dimension N Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti-Collision rul: �,�'�= Date: February 28,2011 used:Minor Risk-Separation Factor ♦4 North 1 0- 1500'md350 0 10 340 I1...UI....0A4► , --4—; 20 330 .`.mil� 4. If\ 0111Ik-W- r1A ..�fl���:til\\,�' Alt A Amm",r4 A30 320 `�ic�l00%woe�'.. gl , �.�` � oI._ 310 2= ,•,g'���'�►�1��e% � ♦♦'�``�;��•.� �r1j so AllOV300 / I V kki A -' 1��'.�\I,0 ti �.�%#1,0 40 �it �r;11 ..u�;A' : so 1 � ' � ,�/` �!! ��/�/ ':I�y%1�`t�!;:, :r �a�ES�P03-PO5P82 290 �b��` ip,�� ,� � .— -, � ,i ?;` ,,,a ,; get,** 70 VIP4i4a >. "All 44 0,11.* 'At,WA 1 , 'As;.'4:.''.1V �,.� ice\ .- f�!•••Gain 1 / I•s �i -tea:% l Ti",, VVA 280 �Nitwit'� ���A.i:� �;���. �►� �� 1 ,"A�i♦,'��.-_- _ '��' ��� t,�'-14 80 �►�i%'iraviirX414� 144 1i J x.4.4,1 tji j�le ffs li�41 � ,��_,�, ��•-...444 AIM moi/ �_ �����.* cr•i u,. 4164 wrip 11115140 %VAN— IlL 270 �� �I���'��il'_ei1�'7P '\ .��� j��\\ 44-11240.:;J ���•�r�.Is.•7,—e���.\at+1.."No: 90 erit 4 i .'=_..4. ♦a I ',fin: /°,: i. �`i' \Q + il 7111-1:4•-'17, .14 . I ! 11 260 �►��►!1' ,''►,q� ` s ���' �,�/l►8 Apar r_,.,1 ='-�:� �►iw;+.. ►moi► W 250 1n itvpA4rAiN*1 Il /ft, man mii 'k*."'""N....,:m0110.- i 0107-04 l,, \ I:0MS* 20 23074 / ��' ilrjIIIIIII 4*--4k /mar* `,a4'�130 ��12p/tar , 0106-0 5(P9) 220 10111141:0 210 20011111411111111 150 ,so 1Qn _ 17n Well Ticks Type: MD on OP09-S03(P3) Calculation Method: Normal Plane Ring Interval: 10.00 ft Azimuth Interval: 10.00 deg Scale: 1 INCH=20.00 ft Schlumberger TRAVELING CYLINDER PLOT Client: ENI ___ NoGo Region EOU's based on: Well: OP09-S03 Oriented EOU Dimension N Field: Nikaitchuq Structure: Oliktok Point NoGo Region Anti-Collision ruleA =_ Date: February 28,2011 used:Minor Risk-Separation Factor c011 North 1500-TDmd 350 0 10 • 340 l efT lC -r♦ • .� 20 330 330 i3.41ViriV ,. IGG . i�0%.; %i - - 320 �/�• ��1K ,�ir1�d��')(l9�/ �I�n�i��, 40 •t,,, • :;tiitiltl �/1 iii �.,�1'I v/���' ��• 310 �,- Int k \ it`i\ ��1.7•241t �IF it �e tfri�����/�I`•,����/ .71,40 V', , �����,:� .i �.r,�. Stu. I �� r ♦/ � .��/ 300 44 verges*,►:�.�` �_� = �iSy� I ♦ 1 illjii���iI'��,/'�i\,t•`t4%� ' 'Il 60 irk4s, 0140.-iv-_-.41,k,--4 :7.:-..1.-... 'rvediwkitositiirflowis ,/,it; e-ovet vivl 290 ►,I { A , x;411114 �.• � :4114 h ``11i14� I i'� i/ l r� v � r♦ Ems:> / I%i'�, .\,'<t':,1/ir'y //111% ��, k � � 1/ / I r ''�. � 7(1 �—if‘Z�� 'e����V//��IN*_._k/�.�ts't.'...•-='-`�� tf,,; //i'. +��L t v "�1/1/�Of \,•4 ��• Wit\`• ���r«u ice' ,Ovit ,rII I IIIib'i��ogr •PO4-07PB1 .�.. s .-• =G � "wily II►u� �� /1I 280 � \ .�0 n`I � ��o lil t �. , IIII 1 t\ t . 111 .cud! y I �,�, \�\�\\� it Ork.trA��Q. 1 �►�;. .40 40:. �::�\`yet •rI �� 1. e ; ,i ,goo , +. Q�1�I� ♦ „may,, .�.�rI`wi�,.�� �► / emro►tiwa�,;�p�I��00_,,,,i, /:• `i_i_'1t,.-.,I, ,�jl,l►� <,,:,;aitio ►.r►w'e;�,, 270 i O0W, - taiqinpir. \�u:, i�. ,.r! �/�/►/ Awa /�II' • - , �A 1l�t!�/i Av��••' ■■ \k\\ ����`/i, e 1 ������/l,. '�►,� ��,/,v tom!`4ip. \.\v�.U'aaa�' t wwiriir 260 .0.� ���r•rrO:IS•Iq���� ;` ��. �•taV���.�.� .►� ►� � I/ ,v4Iliiiiiii � PC \ ��� a 100 ,1'.Ip-dam kmpmss t ...k 7*♦y•�J�, ' � �►/Ilk '/�ut \o-.4-,,:z7,-;41-1.!= 4 250 \ AIM � 10 � � '/..` ; • � ��i��►.i�\►� \ an - -.;,.;w#.;.. .. 110 ipso►% :- ,i / p ..'`. il0�...;� I� 4frowv 1 1v,,, �� ►�� % ,,xj...-zt, IIP OP03-P05PB2 OW4. .fr.4.%, ,•.►lel►_► ,�Ar 1111 • I L sii,* �. 240 4 ♦ / I `1' 4 /► / •♦ ,..a/120 15, w901 -'" 230 �N ,��j_I,r iterV/Avg"/1'I�b \ #--.10...de � jikgougiatliim /ii:t�/,,jor. fit.linTAMM/17.111II/Elk; WI 00 - v 220 ��,�� � ►.'�4:S,ut..�; �1�►t 101ao PrifrO, 210 ",�►j. :,I...'I,, a 150 19t :.i 170 Well Ticks Type: MD on OP09-S03(P3) Calculation Method: Normal Plane Ring Interval: 20.00 ft Azimuth Interval: 10.0 deg Scale: 1 INCH= 100.00 ft Drilling Hazards Summary 16" Open Hole / 13-3/8" Casing Interval HazardRisk Level Mitigation Strateg 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 _ _ _ O oOp ti. v I IA 1 8 , , , fr... ,,i;,,, . \ .,_ - 8 P 07 .... , ,a t..►. w 41111111110 . sir: \, 01111 1--1,`x . li CO � U.1 1 • VWTi" _ 0.1 ....if ►� t �..1� , ►)1 ,,�' 1, © �...1r &' 1161P414 ti lir IF, 0 - ( 0 AIMS ca c» ro 0 0 c c 2 U © 8 0 as c» CV a x 0 = 7 t .0 g C c c � ,, , i CO' 0 O O - ` ' o .o 0 N E E E t , , \ d}- • J Ct � ca 3 I 74 U 0 0 CO as c o o 0 0 co a > so r T ; ro > M r �'� 0t > c cs a) a) 0 4 N 4" D4 a > o r 2 c o _ U C) 5 >., c >, 0 a 2 E ccs Trs cc ',. w E = E o -c o El 0 o ,-in o U Z cc z T 6 aL ED ilj L7 0 J c ti i la W 0 I 1 `.1.' hi N o, tin We P k w ` I- �� d n IU I I=iZ N E E. }}nn W u -- I _ lin ce it a I• I [Ili::i:'Ui O I I ^-1 ='-- le z � 1 _ ® 1 `i z�,.1I1 + I ==e_ 6 IR CO oVw % A m<ig is .$-h xj I . ; k\lt & \ ( q 1 w i�ah , CZ E | K a. f �u0 /§ a. § k | § � /E \$ /CD\E\ /\^\ A\\\ § $| § §# - ZZZ s z,. E-/E y�kE | # ' 33ZG/ �2±y //� /§� ?2%z® /�% \ /\ ? �% | Ii ~n. ^ »7±2� 202 777\ »®B� 11e h1 / ��®3$ ¢RI »»Q-% ¢2± >� ^�»® \7 © $� Y� \ / I % . ��� » § | I �\ _ » -Ni w m %§ «, &\ „it &\ ±® "® ±Li® \\ / k_ ■ 7 eL k - . §Lo �5 j� .)CD &§ r G) 1 G--Ar, - A - , _ _ - — w 1 1 . r i g 0 4�- �_ I © I C--__I2 I c- g 4 M - - - - + ƒ ga © & -- I n I r'--12 E_ .� _ » q co t 0 2 0 _ 1 _ _ i 4\___ I � U) 4 � I O ® . CO_ 4 0 &\ $ %k 0/ Lu L.,1.,.., w 2 6 0 IC = 3 w Z �CO% - CO CC -§ «r - \- Schlumberger CemCAD E*well cementing recommendation for 13.375" Surface Casing Operator : Eni Petroleum Well : OP09-S03 • Country : USA Field : Nikaitchuq State : Alaska Prepared for : Mr.Jason Brink Location : North Slope-Alaska Proposal No. : Draft v1 Service Point : Prudhoe Bay,Alaska Date Prepared : 2-4-2011 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 • c 04, �IVATE 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 : OP09-S03 SihmMerger 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 : 2327.1 ft BHST : 37 degF Bit Size : 16 in ft (x 1000) psi OD 20.in 0 1 1.0 1.5 o– @ 160ft NI — — 1—Frac — — —Pore —Siltstone— o o– — — OD 13.4 in . o @23271t �\ ; ,Sandstone.'.', , o_ — 1 Siltstone- 0 M . . .'.Sandstone. LC V247 ft . . . . . . . . . . . . II 0 o—Coal - ME Shale . 0 0 In N– Well Lithology Formation Press. Page 2 op09-s03 3-4-11 v1.cfw,03.04-2011: LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S03 SI II drier 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 : 2247.0 ft Casing/liner Shoe MD : 2327.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (lb/ft) (in) (psi) (psi) 2327.0 13 3/8 40.0 68.0 12.415 L-80 2270 5020 BTC Mean OH Diameter : 16.000 in Mean Annular Excess : 187.6 Mean OH Equivalent Diameter: 20.016 in Total OH Volume : 843.4 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. (ft) (in) (%) (in) 1900.0 16.000 225.0 20.724 2327.0 16.000 35.0 16.822 Page 3 op09-s03 3-4-11 v1 cfw;03-04-2011; LoadCase Surface Casing;Version wcs-cem461_00 Client : Eni Petroleum Well : OPO9-S03 Sierger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Max. Deviation Angle : 41 deg Max. DLS : 3.503 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 11.0 0.000 100.0 100.0 0.0 11.0 0.000 200.0 200.0 0.0 11.0 0.000 300.0 300.0 0.0 11.0 0.000 400.0 400.0 0.0 11.0 0.000 500.0 500.0 1.8 11.0 1.750 600.0 599.9 3.5 11.0 1.750 700.0 699.5 6.3 11.0 2.750 800.0 798.6 9.0 11.0 2.750 900.0 897.0 11.8 11.0 2.750 1000.0 994.3 14.5 11.0 2.750 1100.0 1090.5 17.3 11.0 2.750 1200.0 1185.3 20.0 11.0 2.750 1300.0 1278.4 22.8 11.0 2.750 1380.7 1352.2 25.0 11.0 2.751 1400.0 1369.7 25.1 11.0 0.518 1500.0 1460.1 25.6 11.0 0.500 1600.0 1550.1 26.1 11.0 0.500 1700.0 1639.7 26.6 11.0 0.500 1800.0 1729.0 27.1 11.0 0.500 1900.0 1817.8 27.6 11.0 0.500 1938.8 1852.2 27.8 11.0 0.489 2000.0 1905.8 29.8 9.7 3.503 2100.0 1991.1 33.2 7.9 3.500 2200.0 2073.1 36.6 6.4 3.499 2300.0 2151.6 40.0 5.1 3.501 2327.1 2172.2 40.9 4.8 3.487 Formation Data MD Frac. Pore Name Lithology (ft) (lb/gal) (lb/gal) 714.0 11.00 8.43 SV-4 Siltstone 965.0 11.20 8.43 SV-3 Sandstone 1244.0 11.50 8.43 SV-2 Siltstone 1761.0 11.80 8.43 SV-1 Sandstone 1900.0 12.00 8.43 Permafrost Base Shale 2149.0 12.30 8.43 Ugnu Top(UG4) Coal 2327.1 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 1900.0 1817.8 32 -1.5 2327.1 2172.2 37 -1.0 Page 4 op09-s03 3-4-11 v1 cfw.03-04-2011 LoadCase Surface Casing:Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S03 Scihnierier String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 2: fluid sequence Job Objectives: Cement to Surface in Permafrost and a competent shoe for drilling ahead. Original fluid Mud 9.50 lb/gal k : 8.28E-2 Ibf.s^n/ft2 n :0.262 Tv: 0.48 Ibf/100ft2 Displacement Volume 336.4 bbl Total Volume 939.9 bbl TOC 0.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (Ib/gal) MUDPUSH II 100.0 0.0 10.10 k:2.54E-2 Ibf.s^n/ft2 n:0.420 Ty:13.04Ibf/100ft2 Lead Slurry 430.5 1827.0 0.0 10.70 k:1.08E-2 Ibf.s^n/ft2 n:0.482 Ty:10.26 Ibf/100ft2 12.5 DeepCRETE 72.9 500.0 1827.0 12.50 k:5.75E-3 Ibf.s^n/ft2 n:0.890 Ty:14.35 Ibf/100ft2 Mud 336.4 0.0 9.50 k:8.28E-2 lbf.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 2030 psi at 2247.0 ft Burst 5020 psi at 0.0 ft Csg.Pump out 52 ton Page 5 op09-s03 3-4-11 v1 cfw 03-04-2011; LoadCase Surface Casing;Version wcs-cem4fi_08 Client : Eni Petroleum Well : OP09-S03 Schiler er 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 lnj. Comments (bbl/min) (bbl) (min) (bbl). Temp. (degF) MUDPUSH II 5.0 100.0 20.0 100.0 80 7-Start Pumping Spacer Pause 0.0 0.0 5.0 0.0 80 4-Drop Bottom Plug Lead Slurry 5.0 430.5 86.1 430.5 80 13-Start Mixing Lead Slurry 12.5 DeepCRETE 4.0 72.9 18.2 72.9 80 16-Start Mixing Tail Slurry Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.5 336.4 39.6 336.4 80 49-Rig Pumps To Displace Shut-In 0.0 0.0 5.0 0.0 80 Static period after Placement Total 02:53 hr:mn 939.9 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 2030 psi at 2247.0 ft I Burst 4812 psi at 0.0 ft Temperature Results BHCT 58 degF Simulated Max HCT 74 degF Simulated BHCT 74 degF Max HCT Depth 2279.5 ft CT at TOC 67 degF Max HCT Time 02:53:54 hr:mn:sc Static temperatures: At Time (hr:mn) 00:05 hr:mn Geo.Temp. Top of Cement (degF) 67 degF 20 degF Bottom Hole (degF) 74 degF 37 degF I Page 6 op09-s03 3-4-11 v1 cfw,03-04-2011; LoadCase Surface Casing;Version wcs-cem461_DB Client : Eni Petroleum Well : OP09-S03 ScIINMier String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing * CemCADE Client : Eni Petroleum Well :OP09S03 String : 13.375"Surface Casing District : Prudhoe Bay,Alaska Country : USA ft lb/gal 8 9 10 11 12 13 0- E- > ' I— I- --H —Hydrostatic -Mn.Hydrostatic r -Max.Dynamic -Mn.Dynamic • Frac o - O- rn E� O g- E 3 Pbre- C > 0 U, U t N U g N c O in N— 1 Fluid Sequence Dynamic Well Security o ■MUDPUSH II 100.0 bbl 10.10 lb/gal Herschel:k=2.54E-2 lbf.s^n/ft2 n=0.420 Ty=13.04 lbf/100ft2 3 Lead Slurry 430.5 bbl 10.70 lb/gal Herschel:k=1.08E-2 Ibf.s^n/ft2 n=0.482 Ty=10.26 Ibf/100ft2 111 12.5 DeepCRETE 72.9 bbl 12.50 lb/gal Herschel:k=5.75E-3 Ibf.s^n/ft2 n=0.890 Ty=14.35 Ibf/100ft2 ■Mud 336.4 bbl 9.50 lb/gal Herschel:k=8.28E-2 Ibf.s^n/ft2 n=0.262 Ty=0.48 of/100ft2 Total Depth = 2327.1 ft Top of Cement= 0.0 ft 'Mark of Schlumberger Sdillialir Page 7 op09-s03 3-4-11 vl.cfw;03-04.2011; LoadCase Surface Casing;Version wcs-cem461 08 Client : Eni Petroleum Well : OP09-S03 Sillerger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 4: 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 :336.4 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. : 75 degF n :0.482 Ty : 10.26 lbf/100ft2 Gel Strength : 11.40 Ibf/100ft2 DESIGN BLEND SLURRY Name : B809(100 lb Mix Fluid : 10.367 gal/sk Job volume :430.5 bbl Dry Density : 106.26 lb/ft3 Yield :2.33 ft3/sk Quantity : 1038.71 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 8 op09-s03 3-4-11 v1 cfw,03-04-2011, LoadCase Surface Casing,Version wcs-cem461_0B Client : Eni Petroleum Well : OP09-S03 Sile1 ger 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 : 5.75E-3 Ibf.s^n/ft2 At temp. : 74 degF n : 0.890 Ty : 14.35 lbf/100ft2 Gel Strength :49.10 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid :5.175 gal/sk Job volume :72.9 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity :266.28 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 9 op09-s03 3-4-11 vi cfw,03-04-2011, LoadCase Surface Casing;Version wcs-cem461_0B Client : Eni Petroleum Well : OP09-S03 Schluderier String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing ECD Simulation at the shoe: Depth= 2327 ft o 11 I in i N o Hydrostatic Dynamic in Frac 1 - Pore e- CS i 31 I to li O I to U 0 ll 1 . al- I in I co- I_ 1 0 0 20 40 60 80 100 120 140 160 180 200 Time(min) ECD Simulation at the previous shoe: Depth= 160 ft Fluids at 2327 ft 1 coI 01 j-- Ln N d- � to l b O O f O M_ 1 Hydrostatic Dynamic O Frac Or . iiiii Pore I I I— r od 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 10 op09-s03 3-4-11 vi cfw;03-04-2011; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S03 le1 String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Simulated Pump and Wellhead Pressure: Calc.Pump Press. Calc.VVHP P i 1 8- 8- 0 20 40 60 80 100 120 140 160 180 200 Time (min) Temperature Model: 1 —To N 8_ First Sack Depth E O W First Sack Temp. I Last Sack Temp. TY �p Last Sack Depth O f�_ (p fa 1 �p-i i ` [-cc". I� ' O n N C -0 r- = ic 1 CO 10 IN �- / N '�� r N c —T —T — N 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 11 op09-s03 3-4-11 v1 cfw,03-04-2011, LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OPO9-SO3 SCOW!" String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Rate of Returns: Fluids at 2327 ftf— ooutl Ca In 1`i I 1 I ! (0 I C M1 N- A-- i 0 20 40 60 80 100 120 140 160 180 200 Time (min) Anullar Velocity: Depth= 2327 ft Annular Velocity 8 F I 8 8 cq 8— 0 -I 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 12 op09-s03 3-4-11 v1 cfw,03-04-2011, LoadCase Surface Casing,Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S03 String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 5: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :2307.0 ft Casing Shoe :2327.0 ft NB of Cent. Used :34 NB of Floating Cent. :34 Centralizer Placement Bottom MD Nbr. Cent./ Cent. Name Code Min.STO @ Depth (ft) Joint (%) (ft) 1927.0 24 1/2 NW-TR-13 3/8-8-TR 3 W304 18.0 667.0 2327.0 10 1/1 NW-TR-13 3/8-8-TR 3 W304 74.5 2327.0 Centralizer Description Centralizer Tests Cent.Name Code Casing Max. Min.OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force (in) (in) (lbf) (lbf) NW-TR-13 3/8-8-TR 3 W304 13 3/8 16.654 15.394 No Hannover 16.000 283.26 2832.59 (1)-Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft % 10 20 30 40 50 60 70 80 90 100 O 1 I I I I I I - - Betw een Cent. + +At Cent. + + O J rf+ ++ - ++ ++ ++ ++ ++ + + ++ - + — N O O N Well Pipe Standoff Page 13 op09-s03 3-4.11 v1.cfw;03-04-2011; LoadCase Surface Casing;Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S03 Sekholerger String : 13.375 District : Prudhoe Bay,Alaska Country : USA Loadcase : Surface Casing Section 6: WELLCLEAN II Simulator ft % 0 20 40 60 80 100 0 20 40 60 80 100 O { — I --T-- ---- — Std Betw.Cent. Mud Contamination— Cement Coverage — Uncontaminated Slurry 1 3' ...w-- } §— e--- ----.$ __. _______ ----_ _ gi_ _____ ....._.,___,..... 1 1 _ Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall z° g g z° 3 0 h ' 0 0 0 200— 200 200 200 400— r 400 400 ___ : A00 S00— _ 600 S00 600 800- 800 800 Sao :, 1000- 1000 ;, 1000 a 1000 4 1200— 1200 a o 1200 ` 1200 a 0 1400- 1400 0 0 1400 1400 A 1600— 1600 1600 1600 1600- 1800 1800 1800 2000 2000 2000 t 2000 2200 ' 2200 2200 2200 '41 3 a 3 c z z IN Mud IT Lead Slurry ME High = Low 11111 12.5 DeepCRETE 1111 MUDPUSH II • Medium = None Page 14 op09-s03 3-4-11 vi cfw,03-04-2011, LoadCase Surface Casing;Version wcs-cem481 08 Schlumberger CemCAD E*well cementing recommendation for 9-5/8" Intermediate Casing Operator : Eni Petroleum Well : OP09-S03 Country : USA Field : Oliktok Point State : Alaska Prepared for : Mr.Jason Brink Location : Nabors 245E Proposal No. : Draftvl Service Point : Prudhoe Bay,Alaska Date Prepared : 03-04-2011 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 Q CI 0'L 174(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 : 0P09-S03 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 : 9808.0 ft BHST : 70 degF Bit Size : 12 1/4 in ft (x 1000) psi OD 20.in 0 2 3 o- @ 180ft 111 ,—Frac —Slltstone— —Pore CD CD o— (NI 0013.4 in NIII Coal Q 2327ft o o— •:•Sandstone•• • • o_ 0D 9.62 in / • •. •. •.•. •• o @ 9808ft Shale I - mriiipirirermnip sm.o o ••Sandstone• • • • co iirmintwirwirwirinnrom LC Q9728 ft j_. Shale II o 0 o- 0 o- 0 0 N Well Lithology Formation Press. Page 2 op09-s03 3-4-11 v1 cfw,03-07-2011; LoadCase 9-5/0 intermediate Casing(a) Version wcs-cem461_08 Client : Eni Petroleum Well : 0P09-S03 Scil■11�p ipn String : 9-5/8 District : Prudhoe Bay,Alaska Y1 Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Previous String MD OD Weight ID (ft) (in) (lb/ft) (in) 2 32 7.0 13 3/8 68.0 12.415 Landing Collar MD : 9728.0 ft Casing/liner Shoe MD : 9808.0 ft Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) . 9808.0 9 5/8 40.0 47.0 8.681 L-80 4760 6870 HYD 563 Page 3 -1 .03-07-2011 op09-s03 3-4 1 v 1 cfw, , LoadCase 9-5/8 Intermediate Casing ,Version wcs-cem461 1a1 _OB Client : Eni Petroleum Well : OP09-S03 MOM 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 : 1299.2 bbl (including excess) Max. Deviation Angle : 87 deg Max. DLS : 3.508 deg/100ft Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. (ft) (ft) (deg) (deg) (deg/100ft) 0.0 0.0 0.0 11.0 0.000 100.0 100.0 0.0 11.0 0.000 200.0 200.0 0.0 11.0 0.000 300.0 300.0 0.0 11.0 0.000 400.0 400.0 0.0 11.0 0.000 500.0 500.0 1.8 11.0 1.750 600.0 599.9 3.5 11.0 1.750 700.0 699.5 6.3 11.0 2.750 800.0 798.6 9.0 11.0 2.750 900.0 897.0 11.8 11.0 2.750 1000.0 994.3 14.5 11.0 2.750 1100.0 1090.5 17.3 11.0 2.750 1200.0 1185.3 20.0 11.0 2.750 1300.0 1278.4 22.8 11.0 2.750 8300.0 3718.1 79.9 345.6 3.498 8400.0 3735.0 80.6 342.1 3.493 8500.0 3750.7 81.3 338.6 3.505 8600.0 3765.2 82.0 335.1 3.498 8700.0 3778.5 82.8 331.7 3.501 8800.0 3790.4 83.5 328.3 3.503 8900.0 3801.0 84.3 324.8 3.494 9000.0 3810.1 85.2 321.4 3.503 9100.0 3817.8 86.0 318.0 3.502 9158.8 3821.7 86.5 316.0 3.496 9200.0 3824.2 86.5 316.0 0.000 9300.0 3830.3 86.5 316.0 0.000 9400.0 3836.4 86.5 316.0 0.000 9500.0 3842.5 86.5 316.0 0.000 9600.0 3848.6 86.5 316.0 0.000 9700.0 3854.7 86.5 316.0 0.000 9758.8 3858.3 86.5 316.0 0.000 9800.0 3860.8 86.5 316.0 0.000 9808.8 3861.3 86.5 316.0 0.000 Page 4 op09-s03 3-4-11 v1 cfw,03-07-2011, LoadCase 9-5/8 Intermediate Casing(a) Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S03 SiIkerger 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) 714.0 11.00 8.43 SV-4 Siltstone 965.0 11.20 8.43 SV-3 Sandstone 1244.0 11.50 8.43 SV-2 Siltstone 1761.0 11.80 8.43 SV-1 Sandstone 1900.0 12.00 8.43 Permafrost Base Shale 2149.0 12.30 8.43 Ugnu Top(UG4) Coal 2327.1 12.50 8.43 Surf. Csg Shoe Shale 2900.0 12.00 8.43 UG-2 Coal 5988.0 12.50 8.43 L Ugnu Sandstone 7187.0 12.50 8.43 Schrader Bluff Shale 7446.0 12.50 8.43 N Seq Top Sandstone 7678.0 12.50 8.43 N Sand Top Sandstone 8191.0 12.50 8.43 N Sand Bottom Sandstone 8471.0 12.50 8.43 N Seq Base Sandstone 9458.0 12.50 8.43 OA Sand Top Shale 9736.0 12.50 8.43 OA Sbl 2 Sandstone 9809.0 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 1900.0 1815.8 32 0.7 2327.0 2171.2 37 0.8 9808.8 3861.3 70 1.3 9809.0 3861.3 70 1.3 Page 5 op09-s03 3-4-11 v1 chv;03-072011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : 0P09-S03 SiIinkergor String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ft degF deg c,_ 0 'n 60 90 0 1 60 90 Geoth.Profile —Deviation —Tubular Fluids —k nulus cv o v 0 — 0 o— m — 0 o ' (N Temp. Profile At 179 min Deviation Section 2: fluid sequence Job Objectives: Zonal Isolation,TOC @ 6,678'(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 lbf/100ft2 Displacement Volume 712.2 bbl Total Volume 1049.9 bbl TOC 6678.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology (bbl) (ft) (ft) (lb/gal) MUDPUSH II 70.0 836.6 5841.4 10.50 k:5.23E-2 Ibf.s^n/ft2 n:0.324 Ty:12.92 Ibf/100ft2 DeepCRETE 267.7 3130.0 6678.0 12.50 k:1.14E-2lbf.s^n/ft2 n:0.884 Ty:17.99Ibf/100ft2 Mud 712.2 0.0 9.30 k:5.97E-3 lbf.s^n/ft2 n:0.616 Ty:8.86 lbf/100ft2 Page 6 op09-s03 3-0-11 vt.cfw.03-01-2011, LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S03 Ybrie1 String : 9-5/8 District : Prudhoe Bay,Alaska �j Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Static Security Checks: Frac 356 psi at 2759.6 ft Pore 98 psi at 2327.0 ft Collapse 4489 psi at 9728.0 ft Burst 6870 psi at 0.0 ft Csg.Pump out 75 ton 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 70.0 14.0 70.0 80 Spacer Ahead Pause 0.0 0.0 3.0 0.0 80 Drop Bottom Plug Pause 0.0 0.0 3.0 0.0 80 Begin Mixing Slurry DeepCRETE 5.0 267.7 53.5 267.7 80 Mix&Pump Cement Slurry(3 to 7 BPM) Pause 0.0 0.0 5.0 0.0 80 18-Drop Top Plug Mud 8.0 712.2 89.0 712.2 80 Kick-Out Plug Pause 0.0 0.0 5.0 0.0 80 Swap to Rig Pumps Pause 0.0 0.0 5.0 0.0 80 Pressure Test Casing Shut-In 0.0 0.0 1.0 0.0 80 Bleed off/Check Floats Total 02:57 hr:mn 1049.9 bbl End Job: Bump Top Plug, Bleed-off PSI, Check floats Dynamic Security Checks : Frac 197 psi at 9808.0 ft Pore 98 psi at 2327.0 ft Collapse 4359 psi at 341.9 ft Burst 6369 psi at 0.0 ft Temperature Results BHCT 75 degF Simulated Max HCT 70 degF Simulated BHCT 60 degF Max HCT Depth 9808.0 ft CT at TOC 60 degF Max HCT Time 00:00:00 hr:mn:sc Static temperatures : At Time (hr:mn) 00:01 hr:mn Geo.Temp. Top of Cement (degF) 60 degF 61 degF Bottom Hole (degF) 60 degF 70 degF Page 7 op09-s03 3-4-11 vtcfw,03-07-2011, LoadCase 9-5/8 Intermediate Casing(a),Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S03 SW111118r String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing la) CemCADE Client : Eni Petroleum Well :OP09-S03 String :9-5/8"Intermediate Casing District : Prudhoe Bay,Alaska Country : USA Ib/gal ft 8 9 10 11 12 13 -Hydrostatic -Mn.Hydrostatic -Max.Dynamic -Mn.Dynamic - Frac 0 -Wre o— N or m O • .4- C 2 O- U CD E ▪ 0 • O CD U 0 • 0 Fluid Sequence Dynamic Well Security o ■MUDPUSH II 70.0 bbl 10.50 lb/gal Herschel:k=5.23E-2 Ibf.s^n/ft2 n=0.324 Ty=12.92 Ibf/100ft2 $ DeepCRETE 267.7 bbl 12.50 lb/gal Herschel:k=1.14E-2 Ibf.s^n/ft2 n=0.884 Ty=17.991bf/100ft2 Mud 712.2 bbl 9.30 Ib/gal Herschel:k=5.97E-3 Ibf.s^n/ft2 n=0.616 Ty=8.86 Ibf/100ft2 Total Depth = 9808.0 ft Top of Cement= 6678.0 ft *Mark of Schlumberger Sc'' i'pr Page 8 op09-s03 3-4-11 v1 cfw;03-07-2011; LoadCase 9-5/B Intermediate Casing lal,Version wcs-cem461 08 Client : Eni Petroleum Well : OP09-S03 Salm String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) ECD Simulation at the shoe: O Depth= 9808 ft__ c4 to Hydrostatic O Dynamic N- Frac F Pore lA CC r to O Of- O I in od- o cd — 0 20 40 60 80 100 120 140 160 180 200 Time(min) ECD Simulation at the previous shoe: Depth= 2327 ft Fluids at 9808 ft N Hydrostatic O Dynamic N— Frac Pore try r I O- O orU cd cd 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 9 op09-s03 3-4-11 vt.cfw;03-07-2011; LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S03 I String : 9-5/8 District : Prudhoe Bay,Alaska ■� Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Simulated pump and wellhead pressure: Calc.Pump Press. --- ---- — Calc.WHP g t . .%%.,..,,.. \N o — -- — — -- \ _..... 0 20 40 60 80 100 120 140 160 180 200 Time(min) Temperature Model: 8 --- --- -- 10 8- First Sack Depth --- First Sack Temp. -Last Sack Temp. t0_ Last Sack Depth -N 1� -M i83- r e 1 :: )-cog_ i pl I W 11:2 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 10 op09-s03 3-4-11 vi.cfw,03-07.2011; LoadCase 9-5/8 Intermediate Casing(a):Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S03 Sberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Returns Rate: rn _— -- Fluids at 9808 ft Q Out QIn c ttn N— 0 –I- 0 T 0 20 40 60 80 100 120 140 160 180 200 Time(min) Annular Velocity: Depth= 9808 ft Annular Velocity 8- pp8- I�– p E 8 8- O_ 0 20 40 60 80 100 120 140 160 180 200 Time(min) Page 11 op09-s03 3-4-11 v1 cfw;03-07-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461 08 Client : Eni Petroleum Well : OP09-S03 ScIimirger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 4: 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 : 8.861bf/100ft2 Gel Strength : 32.02 Ibf/100ft2 MUD Mud Type : WBM Job volume : 712.2 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 : 12.92 lbf/100ft2 Gel Strength :40.56 Ibf/100ft2 Job volume : 70.0 bbl DeepCRETE DESIGN Fluid No:7 Density : 12.50 lb/gal Rheo. Model : HERSCHEL_B. k : 1.14E-2 Ibf.s^n/ft2 At temp. :68 degF n :0.884 Ty : 17.99 lbf/100ft2 Gel Strength : 56.57 Ibf/100ft2 DESIGN BLEND SLURRY Name : D972 Mix Fluid :5.180 gal/sk Job volume :267.7 bbl Dry Density : 119.32 lb/ft3 Yield : 1.54 ft3/sk Quantity :977.22 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 12 • op09-s03 3.4-11 vl.ctw,03-07-2011: LoadCase 9.5/8 Intermediate Casing(a),Version wcs-cem461_08 Client : Eni Petroleum Well : 0P09-S03 Schlumberger String : 9-5/8 District : Prudhoe Bay,Alaska Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 5: centralizer placement Top of centralization :7100.0 ft Bottom Cent. MD :9788.0 ft Casing Shoe :9808.0 ft NB of Cent. Used :62 NB of Floating Cent. :62 Centralizer Placement Bottom MD Nbr. Cent.I Cent. Name Code Min. STO @ Depth (ft) Joint (%) (ft) 8208.0 27 1/1 HYDROFORM HFD 0.0 8194.0 8408.0 0 0/0 0.0 8208.0 9808.0 35 1/1 HYDROFORM HFD 0.0 8422.0 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) HYDROFORM HFD 9 5/8 12.250 12.250 Yes Weatherford N.A. N.A. N.A. ft 0 20 40 60 80 100 I Between Cent. +At Cent. O 0 N O O_ 0 V O O 0_ CO O o3 O O o_1 Well Pipe Standoff Page 13 op09-s03 3-4-11 vl.ctw;03-07-2011; loadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_08 Client : Eni Petroleum Well : OP09-S03 SiII� r String : 9-5/8 District : Prudhoe Bay,Alaska Y Country : USA Loadcase : 9-5/8 Intermediate Casing(a) Section 6: WELLCLEAN II Simulator ft 0 20 40 60 80 100 0 20 40 60 80 100 § — r _ Std Betw.Cent. I — }— 1 a—_i_�— — Mud _____ I Cont — Cement Coverage — Uncontamnated Slurry _ r-- , - —"I••.. •._ '.. .."---L-1--. 1- 1- 1 Cement Coverage Uncontaminated Slurry Fluids Concentrations Risk Mud on the Wall 'a I g g i g 1 7500 - 7500 7500 7500 8000 8000 9000 8000 I 9500 8500 s a 8500 8500 b • O 9000 9000 9000 9000 9500 9500 9500 9500 • B • • P • B -15 o W s z m Mud MI High MI Low DeepCRETE EvE Medium 111.1 None 1111.1 MUDPUSH II Page 14 op09-s03 3-4-11 v1 cfw;03-07-2011; LoadCase 9-5/8 Intermediate Casing(a);Version wcs-cem461_08 SPEO IDENTIFICATION CODE PAG 206 OF 338 ENI S.p.A. En' 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= +MW 0.052 x TVD where: P = Pumping Pressure (psi) TVD = True Vertical Depth (ft) MW = Actual Mud Weight(PPG) Px10 Metric units EMW = + MW TVD where: P = Pumping Pressure (kg/cm2) TVD = True Vertical Depth (m) MW = Actual Mud Weight(kg/I). SPEO IDENTIFICATION CODE PAG 207 OF 338 ENI S.p.A. E11I 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. SPEO IDENTIFICATION CODE PAG 208 OF 338 ENI S.p.A. Eni 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 _ En6 E&P Division REVISION STAP-P-1-M-6140 0 1 LEAK-OFF TEST REPORT Report N' Date: WELL NPME: WELL CODE: CONTRACTOR: RIG NAME: RIG CODE: Open hole depth(m). 825 Mud Type: FWGELS Rig Noe: J.UPs Hole 0ameter(in) 17'114 Weight(KgA): 1.3 R.K.B.elevation(m): 26 Last Csg.Shoe(m): 797 Marsh Uscosiry(sec/Ot): 44 Water Depth(m): 24 Csg.diameter(n). 13'3/8 P V.(cps): 19 Pumps: 12-P-160 Grade: J56 Y.PGNI 00 ft): 6 Liners(in). 6.6 Weight(blt): 61 Gels0b1100 t': 2/8 Flow Rate(bpi): 0.25 Max.Burst pres(psi). 3103 W.L(cc.00 min): 10.5 `log Y Shale _ Expected EMW 1.68 Kgfcm2/1 0 m l Time Vol une Pressure Time Volume Pressure Time Vdume Pressure (min) (bbl) (Psi) (min) (bbl) (Psi) (min) (bbl) (Psi) 1 025 50 0 2 490 16 2 435 2 050 100 95 2 480 3 075 200 10 2 470 4 100 300 10.5 2 483 5 125 400 11 2 455 6 150 500 11.5 2 460 7 1.75 570 12 2 445 8 200 600 13 2 440 8 2D0 550 14 2 437 8.5 200 505 15 2 435 Nd e: Pumped with a constant low rate of(bbl) W lune pumped(bbl) Wlume returned(bbl): (psi) 1000 900 800 stop pump • 700 I e 600 - ` shut in curve S 500 y C �� _.___.—._._, • U 400 r 8 minutes e 300 200 100 — r 0 0,25 0,5 0,75 1 1,25 1,5 1,75 / 1 2 3 , 4 5 6 7 8 9 10 11 12 Cumulative Volume(bbt) 41 II. Time mins RESULTS: (Press.,,,,,,+Press.t-o.)x101Depth=[(1.3x797!10)+(430x0.07)]x10!797=1.68(Kg/cm2/10 m) Note. I Company Representative 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 Oliktok OLIKTOK 9 014 el Point INTAKE DOCKit OPP THIS I MODULE a P . P� 5 J SURVEY •ittra . - .1- S __O N pr0 DS-3R .ko 411P Q DEW ur� SITE STP 1 •0' OUKTOK JOINT MODULES I - NSC STAGING AREA•. T13N, R9E DS-30 J ' 18 - 1 �I : , 'O �! 15 SCALE: ' 1" = 150' \u, it DS-30 19 -25'; 21� x,.22 STP P A VICINITY MAP qo SCALE: 1" = 1 Mile op°-0 0 0.00\^3� \ 0 0,0-v o s o S bcP 0000<A \, OoaN.3N. 0 SP O-o o �� 090''00�00LA G� \ J1 OOo\\\3\\ Oo i9o�ti‘ \''2, o • 0 00,0 01(5\ ' -A \ Z / \' 000 \ ._ OLIKTOK POINT PAD \ a� \ \ \\ 0 ° / \ '\ SEE SHEET 3 FOR NOTES / \\ / LOUNSBURY o Existing Conductor j & ASSOCIATES, LNC. • Conductor Asbuilt this survey / SURVEYORS ENGINEERS PLANNERS / AREA: MODULE: UNIT: •— Ent] P tiroIIeui� OLIKTOK CO DIUC ORD alp ASBUILT LOCATIONS CAD LK680D1 10/9/08 DRAWING NO: NSK 6.80-d1 I 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 1 PAD 0.G. WELL NO. ^(' '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 OP08 6,036,302.66 1,656,735.36 70°30'38.720" 149°51'59.254" 2,082 1,576 12.2 3.5 OP09 6,036,298.90 1,656,728.32 70°30'38.683" 149°51'59.462" 2,085 1,583 12.2 3.5 OP10 6,036,295.16 1,656,721.26 70°30'38.647" 149°51'59.670" 2,089 1,590 12.2 3.7 OP11 6,036,291.38 1,656,714.21 70°30'38.610" 149°51'59.878" 2,093 1,597 12.2 3.8 OP12 6,036,287.63 1,656,707.14 70°30'38.573" 149°52'00.086" 2,097 1,604 12.2 4.0 OP13 6,036,276.37 1,656,685.97 70°30'38.463" 149°52'00.711" 2,108 1,626 12.2 3.6 OP14 6,036,272.66 1,656,678.89 70°30'38.426" 149°52'00.920" 2,112 1,633 12.2 3.5 OP15 6,036,268.88 1,656,671.79 70°30'38.389" 149°52'01.129" 2,115 1,640 12.2 3.4 OP16 6,036,265.11 1,656,664.75 70°30'38.353" 149° 52'01.337" 2,119 1,647 12.2 3.3 OP17 6,036,261.36 1,656,657.70 70°30'38.316" 149°52'01.545" 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) LATITUDE(N) LONGITUDE(W) SEC. LINE PAD0.G. WELL NO. 'Y' 'x NAD83 NAD83 OFFSET ELEV. IELEV..... 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 0 SBU RY &LOUNASSO STEB INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: J�-�-ro�e��� OLIKTOK POINT PAD ���� 'r �t� WELL CONDUCTOR Cil. 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. soomitii.•� pFq �' SURVEYORS CERTIFICATE ; •:• •• , �\ :: .j$ I HEREBY CERTIFY THATI AM PROPERLY • h f REGISTERED AND LICENSED TO PRACTICE �0 ,., �� 0 LAND SURVEYING IN THE STATE OF j��: Or ROOKUS �i ALASKA AND THAT THIS PLAT REPRESENTS •�s° LS_ RO A SURVEY DONE BY ME OR UNDER MY �� , .• edit/ DIRECT SUPERVISION AND THAT ALL 1��'c�p ..iz j 3 .. :+� CORRECT ASIONS SND OTHER DETAILS ARE OF DECEMBER 23, 2008. /+,1 l�"t r���•• 0 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: MODULE: UNIT: Orga Eno 'r etiroIIeui OD WELL CONDUCTOR CII ASBUILT LOCATIONS _ CAD LK68001 10/9/08 DRAWING NO: NSK 6.80-d1 PART: 3 OF 3 REV: 2 TRANSMITTAL ETTER CHECKLISST WELL NAME l h / 0fØ- Ø 3 PTD# 2(/ O `7 Development Service Exploratory Stratigraphic Test Non-Conventional Well / FIELD: /V /44/GC POOL: IKGL/? 'c £Jr4 Je t 4%,e l Circle Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTILATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 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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