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210-156
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c Q - / --. 31 Well History File Identifier Organizing(done) ❑ Two-sided 111111111111111 ❑ Rescan Needed III 1111111 I III III RES N DIGITAL DATA OVERSIZED (Scannable) Col r Items: ❑ Diskettes, No. ❑ Maps: Greyscale 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: tkilLt / /s/ 144p Project Proofing III IIIIIIIM II III BY: 4122. Date: /s/ iMe Scanning Preparation ) x 30 = 3 0 + = TOTAL PAGES 3 1-/- (Count does not include cover sheet)/, 4 BY: Maria Date: /s/ Production Scanning III 111111IIIII 11 111 Stage 1 Page Count from Scanned File: 3 5 (Count does include cover sheet) Pa•e Count Matches Number in Scanning Preparation: CES NO BY: al. Date: 1-1- Li• /Li- /s/ ri4 p 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. III 11111111111 11111 ReScanned III 11111111111 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111III IIII III o c 0 o 2 N 03 CO o z D 1 oU N 2 �I 0,-1 ,1 NI 3 c :1 oto Th. E >, co E 0 cu o Zo U Y. Q c o 0 a) O 0 > I d U W U E z c � E I y Ca 00 E co Q U Y o 0 /�/ 0 A/ Q c co m z z0 N g $ 70,....ETo N E >-a JU 1 N = LU , d co z d , c t 0Ce UO % 0 LU z V 0 0 o C.) a) N Z c aa) Q o oo o Z` H o c Jas a) o o a m i 0 = •@ °� c E Hf i N a) , a) If O M o o. I 0 M I I fI V 0 0as —I J v. N co� M QJ N Z a 1 Mr ~ - N II > j� coW > d ce 1c 7 d Y - t �/� V/ rs I Na. Q a CC m 0 I— • rD OI v 11 G Z o ..E U - I I Il 1 co v z c 2I co C 3 M Z 'a+o 1 1a co Z 0 E ccoo U p ya ° z z z m E c Q N }c° wGz' w o > > 3 a) a) Of= Cu .. 0. d L.I. c,. > I, u_ ' < o E E E o I' ) E. Cu 0 II z m ; ° a`� z Q �. a) O O v 5 a z u �• c 2 W LL °� c 0 2 o O o c _ a) yco Q' Z W J U H U >, E a F. 0 a 1- c. y a `2 c. y o - t c aa) o 0 a o 3 � o � 3 Q 5 U aX U U II siforE [0 if AttAmirr-,\ 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 G. C. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2L-328 ConocoPhillips Alaska, Inc. Permit No: 210-156 Surface Location: 230' FNL, 909' FEL, SEC. 22, T1ON, R7E, UM Bottomhole Location: 1412' FSL, 1188' FWL, SEC. 23, T10N, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Z43' Daniel T. Seamount, Jr. Chair DATED this day of October, 2010. cc: Department of Fish 85 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ftECEIVED STATE OF ALASKA OCT 2J 2010 ALASKA OIL AND GAS CONSERVATION COMMISSION ofiltailliancesisaCgavimen PERMIT TO DRILL Anchorage 20 AAC 25.005 1 a.Type of Wgck100Upl 19 11 b.Proposed Well Class: Development-Oil ❑ Service-Winj ❑ Single Zone Elc.Specify if well is proposed for: Drill X Re-drill [ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ 1 Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' 2L-328 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:7518' TVD: 5555' ' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:230'FNL,909'FEL,Sec.22,T1ON,R7E,UM • ADL 380052,380051 ' Tarn Oil Pool . Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1174'FSL, 1680'FWL,Sec.23,T1ON,R7E, UM 4600,4599 11/15/2010 Total Depth: 9.Acres in Property: 14.Distance to 1412'FSL, 1188'FWL,Sec.23,T1ON,R7E, UM . 2560 Nearest Property: �/ .E'mile to CRU r lciY 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 155 feet 15.Distance to Nearest Well Open Surface:x- 460742 • y- 5927617 ' Zone- 4 GL Elevation above MSL: 115 feet to Same Pool: 2L-325,1080'at 6705 16.Deviated wells: Kickoff depth: 1800 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 53° deg Downhole: 1573 psig ' Surface:992 psig ' 18.Casing Prciram: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 24" 16" 164.8# B-35 Welded 120' Surf. Surf 120' 120' Driven 13.5" 10.75" 45.5# L-80 BTC 2423' Surf. Surf 2463' • 2400' • 500 sx ASLite,300 sx DeepCRETE 9.875" 7.625" 29.7# L-80 BTCM 7478' Surf. Surf 7518' 5555' 710 sx GasBLOK Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) Casing Length Size Cement Volume MD TVD _ Conductor/Structural Surface Intermediate Production _ Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑✓ 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Steve Shultz @ 263-4297 Printed Name G. C. Alvord Title Alaska Drilling Manager Signature A c „,,, ,, Phon 2s-Z' Date 10 a Z(2.0 f O Commission Use Only Permit to Drill API Number: Permit Approval See cover letter /C)/�� Number: 50-fU3 2.5't-O Date: .IU - ,3-1 1 i 0, for other requirements Conditions of approval: If box is checked,wellot be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: [i 4350o rsz 4SOP 1e j1- Samples req'd: Yes ❑ No [ZI Mud log req'd: Yes ❑ No Er Other: 4(ZSlO NSA Rbin ;�,/ .4 142 measures: Yes 2 No ElDirectional svy req'd: Yes Er No ❑ � / / APPROVED BY THE COMMISSION /z_-7,,'/'O DAT•."1�. COMMISSIONER P1 . P1 I fi i A I Post Office Box 100360 ConocoPhillips Anchorage,Alaska 99510-0360 Chip Alvord Phone(907)265-6120 Email: Chip.Alvord@conocophillips.com October 22,2010 - 1! ice. Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 UL 013 Anchorage,Alaska 99501 :• .i iris= +,� ,,1 t Mt n: h+r' I i, RE: Application for Permit to Drill 2L-328(Libra) ,�' � f. Dear Commissioners, ConocoPhillips Alaska,Inc hereby applies for a Permit to Drill for the onshore production well 2L-328. The well will be drilled and completed using Doyon Rig#15. The planned spud date for 2L-328 is Nov. • 15`h,2010. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. If you have any questions or require further information,please contact Steve Shultz 263-4297. Sincerely, A,C I*(24241 to Chip Alvord Drilling Manager 2L-328 Injector ConocoPhillips 0 Drillers 3-1/2" Completion String ConocoPhilli,,s i • iiii 3 '/" Camco'DS'Nipple w/2.875"No-Go Profile,EUE 8RD 16" 164.82# I. mod,at–500'MD SCH100 `; , r @+/- 110'MD i. 3 1/2"9.3#L-80 EUE 8RD mod tubing 11 i ' Arcticset Lite @ 10.7 ppg to surface 1 Top of 12 ppg Tail Slurry @ 1,530'MD 44. a if::: ...... ti :':•'T GLM# Type Setting Depth(TVD-RKB) Valve Type I 1 KBMG 2,500' Dummy 10-3/4"45.5#L-80 BTC @ J 2 KBMG 4,736' Dummy +/-2,462'MD/2,400'TVD r3 KBMG 5,236' SOV 1 TOC 15.8 ppg @+/-5,300'MD — 3-W' KBMG-LTS Chemical Injection Madrel(Placed below bottom GLM)with 3/8"encapsulated control line to surface iJ O 3-'/2" Baker'CMU'Sliding Sleeve(closed)with Camco 2.813" 'DS'profile,EUE 8RD mod,located 1 joint above PBR J!)!_ 'M" 3-1/2"x 7-5/8"Baker FHL Packer with PBR,EUE 8RD mod, placed<200'MD above the perforated interval 4 r � 3-1/2"Camco'D'Nipple w/2.75"No-Go Profile and RHC plug, EUE 8RD mod,located 1 full joint below packer j 3 'h"Wireline Entry Guide,EUE 8RD mod,located 50'MD above top of Bermuda ----c..-- ® _ / 7-5/8"29.7#L-80 BTCM @ 7,518'MD/5,555'TVD ` t G L N L ration for Permit to Drill,Well 2L-328 Saved:22-Oct-10 Permit It — Tarn Well 2L-328 (Libra) Application for Permit to Drill Document Ma ell Maximize Well V IuE 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 Requirements of 20 AAC 25.050(b) 2 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 3 Requirements of 20 AAC 25.005(c)(5) 3 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 4 Requirements of 20 AAC 25.005(c)(8) 4 9. Abnormally Pressured Formation Information 5 Requirements of 20 AAC 25.005 (c)(9) 5 10. Seismic Analysis 5 Requirements of 20 AAC 25.005 (c)(10) 5 11. Seabed Condition Analysis 5 Requirements of 20 AAC 25.005 (c)(11) 5 12. Evidence of Bonding 5 Requirements of 20 AAC 25.005 (c)(12) 5 13. Proposed Drilling Program 5 Requirements of 20 AAC 25.005(c)(13) 5 2L-328 APD Page 1 of 7 Printed:22-Oct-10 1 ation for Permit to Drill,Well 2L-328 Saved:22-Oct-10 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 6 Requirements of 20 AAC 25.005(c)(14) 6 15.Attachments 6 Attachment 1 Directional Plan 6 Attachment 2 Drilling Hazards Summary 6 Attachment 3 Well Schematic 6 Attachment 4 Cement Summary 6 1. Well Name Requirements of 20 AAC 25.005(f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2L-328. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section 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 229'FNL, 909'FEL, Sec 22, T10N,R7E,UM • NAD 1927 RKB Elevation 155.4'AMSL • Northings: 5,927,617.40 Eastings: 460741.94 Pad Elevation 115.4'AMSL • Location at Top of Productive Interval 1,174'FSL, 1,680'FWL, Sec 23,T1ON,R7E,UM (Bermuda) Nad 1927 Measured Depth,RKB: 7,165' Northings: 5,924,165.81 Eastings: 462,711.21 Total Vertical Depth,RKB: 5,285' Total Vertical Depth, SS: 5,130' Location at Total Depth 1,412'FSL, 1,188'FWL, Sec 23,T1ON,R7E,UM Nad 1927 Measured Depth,RKB: 7,518' • Northings: 5,923,968.50 Eastings: 462,825.43 Total Vertical Depth,RKB: 5,555' • Total Vertical Depth, SS: 5,400' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed 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. 2L-328 APD Page 2 of 7 Printed:22-Oct-10 ORIGINAL , ation for Permit to Drill,Well 2L-328 Saved:22-Oct-10 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 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 15. 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The bottom hole pressures from the 2L-328's offset wells are: Well Type SBHP MW TVD Distance Direction Shut in (perfs) Time 2L-325 Producer 1,450 psi 5.2 ppg 5340' 1850' E/SE 1432 hrs ✓ 2L-327 Producer 1,148 psi 4.2 ppg 5304' 1900' N/NE 69 hrs 2L-315 Producer 1,574 psi 5.6 ppg • 5377' 2300' E 48 hrs The distances seen on the attached"Closest in POOL"are taken from the closest point from line to line(wellbore to wellbore)of the offset well to 2L-328 from the top of the C-37 formation to TD(a span of+/-1800'). Using these distances skews the results in the fact that they are not representative of the actual points of interest when it comes to evaluating pressures for that area. As can be seen the distances are greater when using distances from the point where the well actually intersects the Bermuda Sand. The above distances are from each offset well to 2L-328 and are taken from the point where the wellbore intersects the top of the Bermuda Sand. Given the above range of pressures,2L-328 is expected to have a BHP range of 1148 psi to 1574 psi at the reservoir depth of 6,285'TVD. This gives a mud weight range of 3.5 ppg—4.8 ppg for 2L-328. Equivalent Mud Weight @ top of the Bermuda= 1,574/(5,278*.052)=5.73 ppg=0.298 psi/ft The maximum potential surface pressure(MPSP)while drilling 2L-328 is calculated using the higher end of the predicted reservoir pressure 1,574 psi,a 0.11 psi/ft gas gradient,and a Bermuda sand top TVD of 5,278'(estimated • top of reservoir in 2L-328). MPSP =(5,278 ft TVD)*(0.298-0.11 psi/ft) =992 psi (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; Please see Attachment 2-Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(f); Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 2L-328 APD Page 3 of 7 GI M A I Printed:22-Oct-10 ation for Permit to Drill,Well 2L-328 Saved:22-Oct-10 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 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed; Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) _ (Ib/ft) Grade Conn. (ft) (ft) (ft) Cement Program , Driven 16 24 164.8 B-35 Welded 120' Surf 120'/120' Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 BTC 2,423' Surf 2,463'/2,400' 500 sx ASLite Lead 10.7 ppg, 300 sx Tail Slurry 12.0 ppg Cement Top planned @ 5,300'MD/ 7-5/8 9-7/8 29.7 L-80 BTCM 7,478' Surf 7,518'/5,555' 4,141'TVD. Cemented w/ 710 sx GasBLOK Class"G"15.8 ppg 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 15. 7. 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.fuid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done using mud systems having the following properties: Surface WBM 120'—2,463 ' Density(ppg) 8.8—9.5 • Funnel Viscosity(seconds) 75 -250 Yield Point(cP) 60—80 pH 9.0—9.5 API Filtrate(cc) NC—8.0 Chlorides(mg/l) <1000 Intermediate/Production OBM 2,463'— 7,518' Density(ppg) 9.1— 10.0 Yield Point(cP) 18—28 HTHP Fluid Loss(ml/30min) <5 OWR 75:25—80:20 Electrical Stability(my) >600 Diagram of Doyon 15 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 2L-328 APD Page 4 of 7 Printed:22-Oct-10 MINI A I ation for Permit to Drill,Well 2L-328 Saved:22-Oct-10 8. 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( ; N/A-Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A-Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(b); N/A-Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025(Bonding)have been met; • Evidence of bonding for ConocoPhillips Alaska,Inc.is on file with the Commission. 12. 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 to Attachment 3:Well Schematic. 1. MIRU Doyon 15 on 2L-328 Conductor. 2. NU and function test diverter system and prepare spud mud. . • 3. Warning signs will be placed on location indicating the rig has diverter equipment rigged up. • • 4. Spud and directionally drill 13-1/2"hole to the 10-3/4" surface casing point(2,463'MD/2,400'TVD) • according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. 5. Run and cement 10-3/4"45.5#L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. Displace cement with oil base mud. Perform top job if required to bring cement to surface. 6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Notify state of BOP test. Record results. • 7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. 8. Drill out cement and 20'minimum to 50'maximum of new hole.Perform LOT. 9. Directionally drill 9-7/8"hole to+/-7,518'MD/5,555'TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring an 7;7—illation data gathering. 10. POOH with DP and rack back. Run 7-5/8"29.7#L-80 BTCM casing to+/-7,518'MD/5,555' TVD and cement. 2L-328 APD Page 5 of 7 Printed:22-Oct-10 ation for Permit to Drill,Well 2L-328 Saved:22-Oct-10 11. Run 3-1/2"completion tubing with packer and set at+/-7,000'MD/5,166'TVD. 12. LD DP and associated equipment. 13. ND BOP and rig up tree. Test tree and freeze protect annulus. Rig down and move out rig. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill mustc 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 hauling the fluids to a KRU Class II • disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous substances,and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at a later date provided the well meets the regulatory requirements. 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary it 2L-328 APD Page 6of7 r-. 2 a a Printed:22-Oct-10 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2L Pad Plan: 2L-328 (Libra) 2L-328 Plan: 2L-328 (wp02) Standard Proposal Report 21 October, 2010 HALLIBURTON Sperry Drilling Services R GINAL L° 'DI-. OO) - O V 't't Nc,-.-o —N p z- LL'O h.N N _ b a,<V OoO 5 - G �C C�ol�� O Iq y _ O St?, 2, - O ?d9 C —O Rc $Z 6, ....e m_ _ m m3 en°� �a rna�� \Vl d C 0 O tii y zs� e , R 3'5': S dem Z h o� —vp 6 W ��z Q w Op r- - O v C77 CI-. O —� Cel U el tee- O - O o Z e, - F F -G eg QNMNy - lVFM - O r0 M0^ (-4 - v N O.n O _ c1 - O N F p N vii O O n O b• '-- F. z c _cc O F in -v N o +o N o w Z© �, 1-4- N -o W. 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"O 1 ' 1I01 III1OO,{yII I11q' 1 I IIl 0 0 0 0 �" 1 I I 1110 0 N Il1 ILCI I1��`/ N I M I I IIIII I11I IIIII11II111I11 ' ilo 1 I ' 1 I I I 1 I'I _ �J I I i I m 111 Z I ' I I ' m 111 M O I I I � m 1 1 I V 0 I , I I m m I i 1 ; —0 II4 I I I I 1°-° 11 I I Ii h U h v Nt C? 11ll Y ` 1 11co 0 0 0 C.) \ 1 , 1 1, / 1 N � 1 iIII/ - l I 0M1 I I I I I I I I I I I I I I I I I I IIII I I I I I I I I I I I I I I I I I I I I Ili I I I I I I II I`I 1I I I I I I 8 J0 0 0 0 0 0 0 0 0 0 0 0 0 0 J 0 0 0 0 0 0 0 0 0 0 0 0 p0p 0 ._ 0 N 0 M R R N In fD 4 (u!/i�0000 4idea !eo!peA anal Halliburton -Sperry HALLIBURTON Standard Proposal Report tom. . • •�,�.� .�,.�� .• Database: EDM 2003.16 Single User Db Local Co-ordinate Re Well Plan:2L-328(Libra) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-328 @ 155.40ft(Doyon 15(40+115.4)) Project: Kuparuk River Unit MD Reference: ." :,.- Plan:2L-328 @ 155.40ft(Doyon 15(40+115.4)) Site: Kuparuk 2L Pad North Reference: True • Well: Plan:2L-328(Libra) Survey Calculation Method: Minimum Curvature Wellbore: 2L-328 ' Design: 2L-328(wp02) Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 2L Pad . ,� ��. ���,� .�...ww, � ��•�T�. . -;.�:_ .,.•:. �s„-=.ham. �..w�,�, Site Position: Northing: 5,927,695.13ft Latitude: 70°12'48.272 N 'From: Map Easting: 461,077.91 ft Longitude: 150°18'50.048 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.30 ° Well Plan:2L-328(Libra) Well Position +N/-S 0.00 ft Northing: 5,927,617.40 ft • Latitude: 70°12'47.491 N.I +E/-W 0.00 ft Easting: 460,741.94 ft• Longitude: 150°18'59.791 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 115.40ft Wellbore 2L-328 .t .A.- C e ;..mix..�;,.:.... .:z -s: ,. v.�Rar- ram...-...,-*.,,,,.......- 77,77777.7177 . nom,.A4..s7:477 Magnetics Model Name Sample Date { sr1 #t mdrr ng e , - BGGM2009 11/25/2010 21.15 80.71 57,650 Design 2L-328(wp02) Audit Notes: 'Version: Phase: PLAN Tie On Depth: 40.00 Vertical Section: Depth From(TVD) +N/S +E/-W Direction 7 (ft) (ft) (ft) (°) 40.00 0.00 0.00 149.98 Plan Sections Measured Vertical TVD '' ;-•- -'f':"'..- - r Dogleg Build Turn _ Depth Inclination Azimuth Depth System +N/-S +EI-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°I100ft) (°1100ft) (°) i 40.00 0.00 0.00 40.00 -115.40 0.00 0.00 0.00 0.00 0.00 0.00 340.00 0.00 0.00 340.00 184.60 0.00 0.00 0.00 0.00 0.00 0.00 490.00 1.50 345.00 489.98 334.58 1.90 -0.51 1.00 1.00 0.00 345.00 990.00 1.50 345.00 989.81 834.41 14.54 -3.90 0.00 0.00 0.00 0.00 1,140.00 0.00 0.00 1,139.79 98439 16.44 -4.40 1.00 -1.00 0.00 180.00 1,540.00 0.00 0.00 1,539.79 1,384.39 16.44 -4.40 0.00 0.00 0.00 0.00 2,870.89 53.24 150.07 2,687.29 2,531.89 -481.95 282.52 4.00 4.00 0.00 150.07 6,838.53 53.24 150.07 5,062.02 4,906.62 -3,236.55 1,868.37 0.00 0.00 0.00 0.00 7,165.00 40.18 149.63 5,285.40 5,130.00 -3,441.64 1,987.38 4.00 -4.00 -0.13 -178.74 7,335.15 40.18 149.64 5,415.40 5,260.00 -3,536.36 2,042.87 0.00 0.00 0.00 98.28 7,518.39 40.18 149.64 5,555.40 5,400.00 -3,638.37 2,102.63 0.00 0.00 0.00 0.00 10/21/2010 2:17:52PM Page 2 COMPASS 2003.16 Build 69 IGI ► L Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-328(Libra) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-328 @ 155.40ft(Doyon 15(40+115.4)) Project: Kuparuk River Unit MD Reference: Plan:2L-328 @ 155.40ft(Doyon 15(40+115.4)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-328(Libra) Survey Calculation Method: Minimum Curvature Wellbore: 2L-328 Design: 2L-328(wp02) r-- Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -115.40 40.00 0.00 0.00 40.00 -115.40 0.00 0.00 5,927,617.40 460,741.94 0.00 0.00 Surface Location:229'FNL,909'FEL-Sec22-T10N-R07E 100.00 0.00 0.00 100.00 -55.40 0.00 0.00 5,927,617.40 460,741.94 0.00 0.00 200.00 0.00 0.00 200.00 44.60 0.00 0.00 5,927,617.40 460,741.94 0.00 0.00 300.00 0.00 0.00 300.00 144.60 0.00 0.00 5,927,617.40 460,741.94 0.00 0.00 340.00 0.00 0.00 340.00 184.60 0.00 0.00 5,927,617.40 460,741.94 0.00 0.00 400.00 0.60 345.00 400.00 244.60 0.30 -0.08 5,927,617.71 460,741.86 1.00 -0.30 490.00 1.50 345.00 489.98 334.58 1.90 -0.51 5,927,619.30 460,741.45 1.00 -1.90 500.00 1.50 345.00 499.98 344.58 2.15 -0.58 5,927,619.55 460,741.38 0.00 -2.15 600.00 1.50 345.00 599.95 444.55 4.68 -1.25 5,927,622.09 460,740.72 0.00 -4.68 700.00 1.50 345.00 699.91 544.51 7.21 -1.93 5,927,624.62 460,740.05 0.00 -7.21 800.00 1.50 345.00 799.88 644.48 9.73 -2.61 5,927,627.15 460,739.39 0.00 -9.73 900.00 1.50 345.00 899.84 744.44 12.26 -3.29 5,927,629.68 460,738.72 0.00 -12.26 990.00 1.50 345.00 989.81 834.41 14.54 -3.90 5,927,631.96 460,738.12 0.00 -14.54 1,000.00 1.40 345.00 999.81 844.41 14.78 -3.96 5,927,632.20 460,738.06 1.00 -14.78 1,100.00 0.40 345.00 1,099.79 944.39 16.30 -4.37 5,927,633.72 460,737.66 1.00 -16.30 1,140.00 0.00 0.00 1,139.79 984.39 16.44 -4.40 5,927,633.86 460,737.63 1.00 -16.43 1,200.00 0.00 0.00 1,199.79 1,044.39 16.44 -4.40 5,927,633.86 460,737.63 0.00 -16.43 1,300.00 0.00 0.00 1,299.79 1,144.39 16.44 -4.40 5,927,633.86 460,737.63 0.00 -16.43 1,380.61 0.00 0.00 1,380.40 1,225.00 16.44 -4.40 5,927,633.86 460,737.63 0.00 -16.43 Base Perm 1,400.00 0.00 0.00 1,399.79 1,244.39 16.44 -4.40 5,927,633.86 460,737.63 0.00 -16.43 1,500.00 0.00 0.00 1,499.79 1,344.39 16.44 -4.40 5,927,633.86 460,737.63 0.00 -16.43 1,540.00 0.00 0.00 1,539.79 1,384.39 16.44 -4.40 5,927,633.86 460,737.63 0.00 -16.43 1,600.00 2.40 150.07 1,599.78 1,444.38 15.35 -3.78 5,927,632.77 460,738.25 4.00 -15.18 1,700.00 6.40 150.07 1,699.46 1,544.06 8.70 0.05 5,927,626.10 460,742.04 4.00 -7.51 1,800.00 10.40 150.07 1,798.37 1,642.97 -3.96 7.34 5,927,613.41 460,749.26 4.00 7.10 1,900.00 14.40 150.07 1,896.02 1,740.62 -22.56 18.05 5,927,594.75 460,759.87 4.00 28.57 2,000.00 18.40 150.07 1,991.93 1,836.53 -47.03 32.13 5,927,570.21 460,773.83 4.00 56.80 2,100.00 22.40 150.07 2,085.64 1,930.24 -77.23 49.52 5,927,539.92 460,791.06 4.00 91.65 2,200.00 26.40 150.07 2,176.69 2,021.29 -113.03 70.13 5,927,504.02 460,811.48 4.00 132.95 2,300.00 30.40 150.07 2,264.63 2,109.23 -154.24 93.85 5,927,462.69 460,834.98 4.00 180.50 2,400.00 34.40 150.07 2,349.05 2,193.65 -200.66 120.58 5,927,416.13 460,861.47 4.00 234.07 2,462.70 36.91 150.07 2,399.99 2,244.59 -232.33 138.81 5,927,384.37 460,879.54 4.00 270.62 10 3/4"Casing @ 2463'MD,2400'TVD:462'FNL,770'FEL-Sec22,T10N-R07E 2,462.71 36.91 150.07 2,400.00 2,244.60 -232.34 138.82 5,927,384.37 460,879.54 4.00 270.62 10 3/4" 2,500.00 38.40 150.07 2,429.52 2,274.12 -252.08 150.18 5,927,364.57 460,890.80 4.00 293.40 2,600.00 42.40 150.07 2,505.66 2,350.26 -308.24 182.51 5,927,308.25 460,922.83 4.00 358.20 2,700.00 46.40 150.07 2,577.09 2,421.69 -368.86 217.42 5,927,247.45 460,957.42 4.00 428.15 2,712.10 46.88 150.07 2,585.40 2,430.00 -376.49 221.80 5,927,239.81 460,961.77 4.00 436.95 C-80 2,800.00 50.40 150.07 2,643.47 2,488.07 -433.66 254.72 5,927,182.47 460,994.38 4.00 502.92 2,870.89 53.24 150.07 2,687.29 2,531.89 -481.95 282.52 5,927,134.04 461,021.92 4.00 558.64 2,900.00 53.24 150.07 2,704.71 2,549.31 -502.15 294.15 5,927,113.77 461,033.45 0.00 581.95 10/21/2010 2:17:52PM Page 3 COMPASS 2003.16 Build 69 fl R ! fl h Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-328(Libra) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-328 @ 155.40ft(Doyon 15(40+115.4)) Project: Kuparuk River Unit MD Reference: Plan:2L-328 @ 155.40ft(Doyon 15(40+115.4)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-328(Libra) Survey Calculation Method: Minimum Curvature Wellbore: 2L-328 Design: 2L-328(wp02) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-5 +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,609.17 3,000.00 53.24 150.07 2,764.57 2,609.17 -571.58 334.12 5,927,044.15 461,073.06 0.00 662.07 3,100.00 53.24 150.07 2,824.42 2,669.02 -641.01 374.09 5,926,974.52 461,112.66 0.00 742.18 3,200.00 53.24 150.07 2,884.27 2,728.87 -710.43 414.06 5,926,904.89 461,152.27 0.00 822.29 3,300.00 53.24 150.07 2,944.12 2,788.72 -779.86 454.03 5,926,835.27 461,191.87 0.00 902.40 3,400.00 53.24 150.07 3,003.98 2,848.58 -849.29 494.00 5,926,765.64 461,231.47 0.00 982.51 3,500.00 53.24 150.07 3,063.83 2,908.43 -918.72 533.97 5,926,696.01 461,271.08 0.00 1,062.62 3,600.00 53.24 150.07 3,123.68 2,968.28 -988.14 573.94 5,926,626.39 461,310.68 0.00 1,142.73 3,700.00 53.24 150.07 3,183.53 3,028.13 -1,057.57 613.91 5,926,556.76 461,350.29 0.00 1,222.84 3,800.00 53.24 150.07 3,243.39 3,087.99 -1,127.00 653.88 5,926,487.13 461,389.89 0.00 1,302.95 3,900.00 53.24 150.07 3,303.24 3,147.84 -1,196.42 693.85 5,926,417.50 461,429.50 0.00 1,383.06 4,000.00 53.24 150.07 3,363.09 3,207.69 -1,265.85 733.82 5,926,347.88 461,469.10 0.00 1,463.17 4,100.00 53.24 150.07 3,422.94 3,267.54 -1,335.28 773.79 5,926,278.25 461,508.70 0.00 1,543.28 4,200.00 53.24 150.07 3,482.79 3,327.39 -1,404.70 813.76 5,926,208.62 461,548.31 0.00 1,623.39 4,300.00 53.24 150.07 3,542.65 3,387.25 -1,474.13 853.73 5,926,139.00 461,587.91 0.00 1,703.50 4,400.00 53.24 150.07 3,602.50 3,447.10 -1,543.56 893.70 5,926,069.37 461,627.52 0.00 1,783.61 4,496.74 53.24 150.07 3,660.40 3,505.00 -1,610.72 932.36 5,926,002.01 461,665.83 0.00 1,861.11 C-50 4,500.00 53.24 150.07 3,662.35 3,506.95 -1,612.99 933.67 5,925,999.74 461,667.12 0.00 1,863.72 4,600.00 53.24 150.07 3,722.20 3,566.80 -1,682.41 973.64 5,925,930.11 461,706.73 0.00 1,943.83 4,700.00 53.24 150.07 3,782.06 3,626.66 -1,751.84 1,013.61 5,925,860.49 461,746.33 0.00 2,023.94 4,800.00 53.24 150.07 3,841.91 3,686.51 -1,821.27 1,053.58 5,925,790.86 461,785.93 0.00 2,104.05 4,900.00 53.24 150.07 3,901.76 3,746.36 -1,890.69 1,093.55 5,925,721.23 461,825.54 0.00 2,184.16 5,000.00 53.24 150.07 3,961.61 3,806.21 -1,960.12 1,133.52 5,925,651.61 461,865.14 0.00 2,264.27 5,100.00 53.24 150.07 4,021.47 3,866.07 -2,029.55 1,173.49 5,925,581.98 461,904.75 0.00 2,344.38 5,200.00 53.24 150.07 4,081.32 3,925.92 -2,098.97 1,213.46 5,925,512.35 461,944.35 0.00 2,424.49 5,273.65 53.24 150.07 4,125.40 3,970.00 -2,150.11 1,242.89 5,925,461.07 461,973.52 0.00 2,483.50 C-40 5,300.00 53.24 150.07 4,141.17 3,985.77 -2,168.40 1,253.42 5,925,442.72 461,983.96 0.00 2,504.60 5,400.00 53.24 150.07 4,201.02 4,045.62 -2,237.83 1,293.39 5,925,373.10 462,023.56 0.00 2,584.71 5,500.00 53.24 150.07 4,260.88 4,105.48 -2,307.26 1,333.36 5,925,303.47 462,063.16 0.00 2,664.82 5,600.00 53.24 150.07 4,320.73 4,165.33 -2,376.68 1,373.33 5,925,233.84 462,102.77 0.00 2,744.94 5,674.64 53.24 150.07 4,365.40 4,210.00 -2,428.50 1,403.17 5,925,181.88 462,132.33 0.00 2,804.73 Top of Pool @ 5675'MD,4365'TVD:2622'FSL,491'FWL-Sec23-710N-R07E-C-37 5,700.00 53.24 150.07 4,380.58 4,225.18 -2,446.11 1,413.30 5,925,164.22 462,142.37 0.00 2,825.05 5,800.00 53.24 150.07 4,440.43 4,285.03 -2,515.54 1,453.27 5,925,094.59 462,181.98 0.00 2,905.16 I 5,900.00 53.24 150.07 4,500.29 4,344.89 -2,584.96 1,493.24 5,925,024.96 462,221.58 0.00 2,985.27 6,000.00 53.24 150.07 4,560.14 4,404.74 -2,654.39 1,533.21 5,924,955.34 462,261.19 0.00 3,065.38 6,100.00 53.24 150.07 4,619.99 4,464.59 -2,723.82 1,573.18 5,924,885.71 462,300.79 0.00 3,145.49 6,200.00 53.24 150.07 4,679.84 4,524.44 -2,793.25 1,613.15 5,924,816.08 462,340.39 0.00 3,225.60 6,300.00 53.24 150.07 4,739.70 4,584.30 -2,862.67 1,653.12 5,924,746.45 462,380.00 0.00 3,305.71 6,400.00 53.24 150.07 4,799.55 4,644.15 -2,932.10 1,693.09 5,924,676.83 462,419.60 0.00 3,385.82 6,500.00 53.24 150.07 4,859.40 4,704.00 -3,001.53 1,733.06 5,924,607.20 462,459.21 0.00 3,465.93 6,600.00 53.24 150.07 4,919.25 4,763.85 -3,070.95 1,773.03 5,924,537.57 462,498.81 0.00 3,546.04 6,700.00 53.24 150.07 4,979.10 4,823.70 -3,140.38 1,813.00 5,924,467.95 462,538.42 0.00 3,626.15 L 6,800.00 53.24 150.07 5,038.96 4,883.56 -3,209.81 1,852.97 5,924,398.32 462,578.02 0.00 3,706.26 10/21/2010 2:17:52PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL r Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-328(Libra) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-328 @ 155.40ft(Doyon 15(40+115.4)) Project: Kuparuk River Unit MD Reference: Plan:2L-328 @ 155.408(Doyon 15(40+115.4)) Site: Kuparuk 2L Pad North Reference: True Well: Plan:2L-328(Libra) Survey Calculation Method: Minimum Curvature Wellbore: 2L-328 Design: 2L-328(wp02) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (') (ft) ft (ft) (ft) (ft) (ft) 4,906.62 6,838.53 53.24 150.07 5,062.02 4,906.62 -3,236.55 1,868.37 5,924,371.49 462,593.28 0.00 3,737.12 6,900.00 50.78 150.00 5,099.85 4,944.45 -3,278.52 1,892.56 5,924,329.40 462,617.25 4.00 3,785.57 7,000.00 46.78 149.88 5,165.74 5,010.34 -3,343.61 1,930.23 5,924,264.13 462,654.58 4.00 3,860.77 7,100.00 42.78 149.73 5,236.71 5,081.31 -3,404.48 1,965.65 5,924,203.08 462,689.67 4.00 3,931.19 7,125.26 41.77 149.70 5,255.40 5,100.00 -3,419.15 1,974.22 5,924,188.36 462,698.16 4.00 3,948.18 Top Berm 7,165.00 40.18 149.63 5,285.40 5,130.00 -3,441.64 1,987.38 5,924,165.81 462,711.21 4.00 3,974.24 S8 Target @ 7165'MD 5285'TVD:1609'FSL,1073'FWL-Sec23-T10N-R07E-2L-328 S8(wp02) 7,200.00 40.18 149.63 5,312.14 5,156.74 -3,461.13 1,998.79 5,924,146.27 462,722.52 0.00 3,996.82 7,256.61 40.16 149.81 5,355.40 5,200.00 -3,492.66 2,017.21 5,924,114.64 462,740.77 0.20 4,033.34 Base Berm 7,300.00 40.18 149.64 5,388.54 5,233.14 -3,516.79 2,031.41 5,924,090.44 462,754.84 0.26 4,061.34 7,322.01 39.89 153.45 5,405.40 5,250.00 -3,529.24 2,038.16 5,924,077.96 462,761.52 11.22 4,075.49 C-35 7,335.15 40.18 149.64 5,415.40 5,260.00 -3,536.36 2,042.87 5,924,070.81 462,766.20 18.80 4,084.02 2L-328 C-35(wp02) 7,387.51 40.18 149.64 5,455.40 5,300.00 -3,565.51 2,059.95 5,924,041.58 462,783.13 0.00 4,117.80 K-3 7,400.00 40.18 149.64 5,464.94 5,309.54 -3,572.46 2,064.02 5,924,034.61 462,787.16 0.00 4,125.86 7,500.00 40.18 149.64 5,541.35 5,385.95 -3,628.13 2,096.64 5,923,978.77 462,819.48 0.00 4,190.37 7,518.38 40.18 149.64 5,555.39 5,399.99 -3,638.37 2,102.63 5,923,968.51 462,825.42 0.00 4,202.23 7 5/8" 7,518.39 40.18 149.64 5,555.40 ' 5,400.00 -3,638.37 2,102.63 5,923,968.50 462,825.43 0.00 4,202.24 TD at 7518'MD,5555'TVD:1412'FSL,1188'FWL-Sec23,T10N-R07E Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (0) (0) (ft) (ft) (ft) (ft) (ft) 2L-328 S8(wp02) 0.00 0.00 5,285.40 -3,441.64 1,987.38 5,924,165.81 462,711.21 -plan hits target center -Point 2L-328 TD Qtr Mile 0.00 0.00 5,555.20 -3,638.91 2,102.82 5,923,967.96 462,825.61 -plan hits target center -Circle(radius 1,320.00) 2L-328 C-37 Qtr Mile 0.00 0.00 4,365.26 -2,428.87 1,403.28 5,925,181.50 462,132.44 -plan hits target center -Circle(radius 1,320.00) 2L-328 C-35(wp02) 0.00 0.00 5,415.40 -3,536.36 2,042.87 5,924,070.81 462,766.20 -plan hits target center -Point 10/21/2010 2:17:52PM Page 5 COMPASS 2003.16 Build 69 CRGNAL Halliburton -Sperry HALLIBURTQN Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:2L-328(Libra) Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:2L-328 @ 155.40ft(Doyon 15(40+115.4)) 4.Vit-Al Project: Kuparuk River Unit MD Reference: Plan:2L-328 @ 155.40ft(Doyon 15(40+115.4)) Site: Kuparuk 2L Pad North Reference: , y True Well: Plan:2L-328(Libra) Survey Calculation Method: Minimum Curvature Wellbore: 2L-328I Design: 2L-328(wp02) a Casing Points Measured Vertical 's „ _e ' . 1 Casing Hole w Depth Depth : i,1 Diameter Diameter . (ft) (ft) Name _. (") (.1 2,462.71 2,400.00 10 3/4" 10-3/4 13-1/2 7,518.38 5,555.39 7 5/8" 7-5/8 9-7/8 Formations Measured Vertical ' Vertical g � ' `' : Dip Depth Depth .Depth SS" A Dip Direction (ft) (ft) " ft •;4111114.61F,..r: Name` § 40) (0) 7,256.61 5,355.40 Base Berm 0.00 5,273.65 4,125.40 C-40 0.00 7,125.26 5,255.40 Top Berm 0.00 2,712.10 2,585.40 C-80 0.00 1,380.61 1,380.40 Base Perm 0.00 4,496.74 3,660.40 C-50 0.00 7,387.51 5,455.40 K-3 0.00 5,674.64 4,365.40 C-37 0.00 7,322.01 5,405.40 C-35 0.00 Plan Annotations Measured Vertical Local Coordinates x. Depth Depth +N/-S +E/-VU i' (ft) (ft) (ft)'17A V (ft) Comment 40.00 40.00 0.00 0.00 Surface Location:229'FNL,909'FEL-Sec22-T10N-R07E 2,462.70 2,399.99 -232.33 138.81 10 3/4"Casing @ 2463'MD,2400'TVD:462'FNL,770'FEL-Sec22,T10N-R07E 5,674.64 4,365.40 -2,428.50 1,403.17 Top of Pool @ 5675'MD,4365'TVD:2622'FSL,491'FWL-Sec23-T10N-R07E 7,165.00 5,285.40 -3,441.64 1,987.38 S8 Target @ 7165'MD 5285'TVD:1609'FSL,1073'FWL-Sec23-T10N-R07E 7,518.39 5,555.40 -3,638.37 2,102.63 TD at 7518'MD,5555'TVD:1412'FSL,1188'FWL-Sec23,T10N-R07E 10/21/2010 2:17:52PM Page 6 COMPASS 2003.16 Build 69 f11NL 2 o � I— a 3E mo J J t Q = a N to CLU _ E I. • _ - C C Cu) o c. w N O O d d a o y 0 u O �1 m N a o ill ZD: Nf 6 — O W _1 a- W Oom — N N Z Z M tD N \V uN O I Q II MI ;5,,, ME = d a• o w vnv w m • w CA n I 1u• iII }C re O d w IMMO 0 r 11 T W_ = o a o y LL J a v e0i °- .. C O N a z i E S •c #11 mi.sr ■— N to W V, Y p, _N pf J E ate. M z U 0. O IL LL N t • N F1 R. ya a o V E N N G. 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Rig: Doyon 15 Location: Tarn Client: CPAI Revision Date: 10/19/2010 Volume Calculations and Cement Systems Prepared by: Mike Martin Volumes are based on 50% excess. The topof the tail slurrydesigned to be Location:Anchorage,AK is g Phone: (907)263-4207 -5,301' MD. Mobile: (907)748-6900 email: martin13@slb.com Tail Slurry Minimum pump time: -200 min. (pump time plus 120 min.) 15.8 ppg Class G +2.0 gps D600G + 0.2%D46, 0.6%D65, 0.03 gps D177- 1.17 ft3/sk 0.2148 ft3/ft x (7801 -5301)x 1.50 (50% excess) = 806 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 21 ft3 806 ft3 + 21 ft3= 827 ft3 827 ft3/ 1.17 ft3/sk= 707 sks Previous Csg. Round up to 710 sks < 10-3/4",45.5.#casing at 2,463'MD BHST = 136°F, Estimated BHCT = 110°F. "l (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW101 5.0 40.0 8.0 8.0 MPII-OBM 5.0 40.0 8.0 16.0 Drop bottom plug 0.0 0.0 5.0 21.0 GasBLOK Slurry 6.0 147.1 24.5 45.5 Drop top plug 0.0 0.0 5.0 50.5 Water 2.0 10.0 5.0 55.5 Switch to rig 0.0 0.0 3.0 58.5 Water 8.0 338.5 42.3 100.8 < Top of Cement at Slow and bump plug 3.0 6.0 2.0 102.8 5,301'MD MUD REMOVAL r' Expected Oil Based Mud Properties:9.0 ppg, Pv< 22, Ty< 12 < 7-5/8",29.7#casing l in 9-7/8"OH Spacer Properties: 11.5 ppg MudPUSH* II, Pv=20-25, Ty= 35-40 0 ‹ii Centralizers: As per COP program ? TDat7 MD ' (5,556'TVD) wird...) MD len C2 . /^- /0 •Z7. /0 * Mark of Schlumberger ORIGINAL 2L-328 Libra) Schlumberger CemCADE Preliminary Job Design 10-3/4" Surface Casing WP-01 V1 Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 15 Volume Calculations and Cement Systems Location: Tarn Volumes are based on 300% excess in the permafrost and 50% excess below the Client: CPAI Revision Date: 10/19/2010 permafrost. The top of the tail slurry is designed to be at 1663' MD. Prepared by: Mike Martin Location:Anchorage,AK Lead Slurry Minimum pump time: 245 min. (pump time plus 120 min.) Phone: (907)263-4207 ARCTICSET Lite @ 10.7 ppg-4.51 ft3/sk Mobile: (907)748-6900 email: martinl3©slb.com 0.6381 ft3/ft x (80')x 1.00 (no excess)= 51 ft3 0.3637 ft3/ft x (1500-80')x 4.00 (300% excess)= 2066ft3 < TOC at Surface Previous Csg. 0.3637 ft3/ft x(1663- 1500)x 1.50 (50% excess) = 89 ft3 51 ft3+ 2066 ft3+89 ft3= 2206 ft3 2206 ft3/4.51 ft3/sk= 490 sks Round up to 500 sks Have additional ASL on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 175 min. (pump time plus120 min.) < 16 62.6#casing 12.0 ppg DeepCRETE + additives- 1.64 ft3/sk at 80'MD - --- 0.3637 ft3/ft x(2463- 1663)x 1.50 (50% excess) = 436 ft3 0.53997 ft3/ft x 80' (Shoe Joint)= 43 ft3 436 ft3+43 ft3 = 479 ft3 479 ft3/ 1.64 ft3/sk= 292 sks Round up to 300 sks BHST = 77°F, Estimated BHCT = 73°F. (BHST calculated using a gradient of 2.1°F/100 ft. from surface) < Base of Permafrost at 1,500 MD(1,500'TVD) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (min) CW 100 5.0 50.0 10.0 10.0 MUDPUSH II 5.0 50.0 10.0 20.0 < Top of Tail at Drop bottom plug 0.0 0.0 5.0 25.0 1,663'MD ASL 6.0 392.9 65.5 90.5 DeepCRETE 6.0 85.4 14.2 104.7 Drop top plug 0.0 0.0 5.0 109.7 CW101 2.0 10.0 5.0 114.7 Switch to rig 0.0 0.0 3.0 117.7 t MOBM 8.0 213.2 26.7 144.4 Slow&bump plug 3.0 6.0 2.0 146.4 < 10-3/4",45.5#casing in 13-1/2"OH MUD REMOVAL Expected Mud Properties:9.6 ppg, Pv<25, Ty< 35 TD at 2,463 MD (2,400'TVD) Displacement Mud (MOBM): 9.0 ppg, Pv<22, Ty< 12 Spacer Properties: 10.5 ppg MudPUSH* II, Pv,20-25, Tv 30-35 Centralizers: As per CPAi program. * Mark of Schlumberger ORIGINAL 2L-328 Drilling Hazards Summary 13-1/2" Hole/ 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate If observed-control drill,reduce pump rates,reduce drilling fluid temperatures,Additions of Lecithin. Gravel/Sand Sloughing Moderate Increase mud weight/viscosity,High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of Trips trip sheets),Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur-reduce pump rates and mud rheology,use LCM 9-7/8" Hole/7-5/8" Casing Interval Event Risk Level Mitigation Strategy Shale stability in HRZ and K-1 Moderate Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD higher MW's required tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills,PWD Tools,Increased mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates,Mud rheology,LCM. Use GKA LC decision tree. 2L-328 Hazards.doc r, 1 1p 1 rS Prepared by Mike Greener int Page 1 of 1 TRANSMITTAL LETTER CHECKLIST WELL NAME K/eL( Z/ PTD# `Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: t LPOOL: • Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(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. Rev: 1/11/2008 ❑ To corn 0 a> n co N a) O o `m T) c Q c O 7 o) m E a) c C O) O U U a co m o w• U Z' uu n) u)) O pO -o a) a) O C U U 70) CD CD n E O o O O n f° O a c 0 o c m m _Li '3 a w w C 0 o X aa) o o �' O r) N, a a E O --I V D V) (0, O •3. 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