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212-010
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 1b direct inspection/� of the file. _1, - V 4 0 Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RESC N: OVERSIZED: NOTES: 1 of Items: ❑ Maps: ra scale Items: ❑ Logs: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Cr:ti2......1.4) Date: dr 0 /s/ 44 I Project Proofing v'iFBY: AM Date: 9 / t. /s/ Scanning Preparation x 30 = + = TOTAL PAGES 4, 'T (Count does not include cover sheet) BY: Date: 7t?l/it /s/ Production Scanning Stage 1 Page Count from Scanned File: a (Count does include covers eet) Page Count Matches Number in Scanning Preparation: YES NO BY: AIM Date: `Lk /s/ki4 f3 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc o o 0 N 9 < < < cr,O n Z Z Z w co :o Z c >- >- >- O N on 0 yl 2 a) _ r >o T co I tEs N Q clo M O Za r °Z 3 r o F- I Y. II v) y aoQ I 1 To m aa o 03 o 2 o U -J W_ U O dN c Z w o •a) Co d £o ' Z Z 3 J co E > > > h 1 Ce 0 m CO 1 li N o U co• it .J.r x >co _ y E rn aso W = m . Z ° a) a m ° N rn m Ce - E LL co ✓ v i1tL rnQ m I. N o o J a c ° E J °o 2 CL v ° ZI c O N r 0 N C K a a-m O i E a Q H UQ) U (p m w0 J m� ' �' z° > >- E E as az Q mr NII, 0 ct R. w ° as e- o s E m C� Z J g co al N cI G > rn To m E Co re o o c co o E Y JV) •� ° • m w - O W I l6 To N v a) c a. O _ E' o Q c I— • m c U a TD. °I ° m O Q Z 0 Z ° o m U T £ U o 0 2 0 CO Z Z - 2 N m m O 3 3 E O Z N w Z CNA - O) £ } } > o a z O « c 0 C > O J N Q •� > = N ~ Q r c d "o E c -• E Co O .- 2 ZO w w G Z d W O ° y a' Q m o. m W o c N = O £ - £ E Z m m w as p .. J = c Z c m O 1W Od v ` o o ULL m o o a c Z W o 2 V 2 y o J •P •C o. a m m (0T a EE O ` � 0a w a m ) 0.v a' aa r 0 1 J 0 E- ? aci U o I o 0 N.1- N 9 F I o o b o N Z 0 o� 0 4 C•1 cA In VT T caO zci z Q 1 tI 1 cc E. X 0 w z_ d J co G LL Q C O N '5 NO. = O m : U C. J_ W = 1 0 0 W z 1 \---\—..._.) V V (... i..Z Q t N J o co CL u) T 0 O N X a X E o V N w O) o U o JN CO Ilt et N 1 (...-- --....---4 bh 0. w r 1--- H 5 z >. /2 W re' A cc Q a a (-----L- o. 0 o ICC c E o CI of U E asz m 3 o j m o N N N I N Iw IY 0 V O lC U .a U E a a o oQ • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, February 17, 2012 8:46 AM To: 'Winfree, Michael Alex (Jr.)' Subject: RE: 1E-24B CTD Operations(PTD 212 010) Mike, Your naming convention is fine... good luck with the rest of the well. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Winfree, Michael Alex (Jr.) [mailto:Michael.A.Winfree@conocophillips.com] Sent: Thursday, February 16, 2012 4:56 PM To: Schwartz, Guy L (DOA) Subject: 1E-24B CTD Operations (PTD 212 010) Guy, While drilling the 1 E-24BL1-01 lateral, off of an aluminum billet set at 7,572' MD in the 1 E-24BL1 lateral, the BHA became stuck at 7,540'MD during a wiper trip, -32' above the billet. The BHA was pulled free. A cleanout assembly was picked up and multiple attempts to recover the hole were unsuccessful. The clean out assembly was only able to get to a depth of 7,288' MD corresponding to a fault. The 1 E-24BL1 lateral was drilled to a depth of 9,430' MD and slotted liner run back to the L1-01 kick off point at 7,572'for a total lined length of 1,858'. The hole collapse at 7,288' MD has isolated both the L1 and L1-01 laterals and no production is expected from either wellbore. The plan forward is to re-drill the laterals kicking off at 6,950' MD out of the L1 lateral, -338' MD before the hole collapse at the fault. Shale intervals at 6,970' MD and 7,150' MD,just below the proposed kick off point, are expected to collapse further preventing any production from below. The wellbore names will be: 1 E-24BL1 becomes 1 E-24BL1 PB1 (API Number 50-029-20857-70) 1 E-24BL1-01 becomes 1 E-24BL1 PB2 (API Number 50-029-20857-71) The purpose of this e-mail is to confirm that the AOGCC requires no additional information for the operations listed above and the naming conventions for the plug backs are correct. We are currently running in the hole with the billet and will perform a BOP test before picking up our drilling assembly to re-drill the lateral. Thanks, -Mike Mike A. Winfree Drilling Engineer 907.265 6820 Direct 907.242.0246 Cell 2/17/2012 g' 4 i eq % of '.„,,t LI • -I vm 0 a co W � 5 rn g" D vv N W 1 - o o C r w o. N (\`' 0v o 02, Cal , o0 4) fry o \ 0 W(„, . -4I� ,w��j- W O n � -D �� H � _o S v5 w � y m � O V en 0 m y y Cn 1V' 61 W "NI i . / i . 13Bo cn CD 0'9 "V g01 f , N r. v / A fl. // c,.. e // n S N 1 m \ O W CO IW W W \ n 0 O d5 y 0 N -, N N N \\ O Co W O 2 CD fn O - 03\ \ O . N U) # CO -0 x X r —1 co T) j0 o yy a m X a \ \ w nP oo n FIT m x \ 9' m a) a g s oOm on cn 6 iI I Pnv .Na. I I W CA 3 9,5)' m ` cp bp o m W O0sN aN nA g ' 0 Oa 03 N N W CflN N oN o cm O d W g fD i' QTal O v� 03 o) 0 o N N N 0 c c\ \ 11i L 1 [r `,\) �,„,_ i,,, SEAN PARNELL,GOVERNOR \\, FC 0 FA\ 1LAs ] ,A ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMNIISSION ANCHORAGE,ALASKA 99501-3539 PHONE 907 279-1433 FAX (907)276-7542 Lamar Gantt CTD Engineering Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-24BL1-01 ConocoPhillips Alaska, Inc. Permit No: 212-010 Surface Location: 171' FSL, 226' FEL, SEC. 16, T11N, R10E, UM Bottomhole Location: 448' FSL, 825' FEL, SEC. 22, T11N, R10E, UM Dear Mr. Gantt: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1E-24B, Permit No 211- 151, API 50-029-20857-02. Production should continue to be reported as a function of the original API number stated above. 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 revoca 'en or suspension of the permit. '1• C 4e -ly 4 , r . Norma o • loner DATED this2'ay of January, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED ALA ,OIL AND GAS CONSERVATION COMMI. _N .SAN 2 a 2017 PERMIT TO DRILL 20 AAC 25.005 iluka liii Ai (,as Lons. Commission 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑Q , Service- Winj ❑ Single Zone ❑✓ . 1 c.Specify if,well,j sed for: Drill Redrill D , Strati ra hic Test Development-Gasda ❑ ❑ g p ❑ p 0 Service-Supply 0 Multiple Zone ❑ Coalbed Gas �� a5 Hydrates ❑ Re-entry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: ❑✓ Blanket ❑ Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 - 1E-24BL1-01 - 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage AK 99510-0360 MD: . 9385 TVD: • 6185 Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk River Oil Pool . Surface: 171'FSL, 226'FEL, Sec 16, T11N,R10E,UM ADL 25651 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1394'FNL, 1182'FWL, Sec 22, T11N,R10E,UM_ 2657 2/6/2012 Total Depth: 5�c LZ, T//As', /42k LC'/t,( 9.Acres in Property: 14.Distance to Nearest Property: 448'FSL, 825'FEL, S , 2560 18,600'to KPA Boundary /'24/;..-- 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above I 95 feet 15.Distance to Nearest Well Open Surface x- 550,300 - y- 5,959,760 Zone-4 GL Elevation above I 67 feet to Same Pool: 1E-24, 180' Z 16.Deviated wells: Kickoff depth:75-75._4,990-feet / t�17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) • /- /•u-/L Maximum Hole Angle: '70 ...36:6-degrees Downhole: .399A-'ilD ,p Surface: 3292 3YYf J r` 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 3" 2-3/8 4.7 ppf L-80 STL 2,672 6708 6121 9380 6185 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth ND(ft): Junk(measured): 6940 6411 6837 6195 Casing Length Size Cement Volume MD ND Conductor/Structural 77 16 326 sx AS II 112 112 Surface 2,398 10-3/4 1400 sx AS III,250 sx AS I 2398 2398 Intermediate 4,914 7 700 sx Class G with Adds 4914 4536 Production 1,775 5-1/2 179 sx Class G with Adds 6456 5911 Liner 649 3-1/2 72 sx Class G with Adds 6937 6196 Perforation Depth MD(ft): Perforation Depth ND(ft): 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program O 20 AAC 25.0 0 requi m nts Q 21. Verbal Approval: Commission Representative: Date 1/18/2012 MAW i �l(Z 22. I hereby certify that the foregoing is true and correct. Contact Mike A.Winfree I� Printed Name Lamar Gantt Title CTD Engineering Supervisor Signature lean )e t fziouL Phone 263-4021 Date 1/18/2012 Commission Use Only Permit to Drill 7 / API Number: / Permit Approval See cover letter for other Number: / L��L� 50�Z�`� J� l �C� Date: 21 1?_ requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,g s hydrates,or gas contained in shales: [K Other: r gdoo,S` LIa s Samples req'd: Yes❑ No Mud log req'd: Yes ❑ No Ltd' H2S measures: Yes[KNo❑ Directional svy req'd: Yes 2/No ❑ 0/ , -"LVED BY THE COMMISSION DATE: Of,//3/7//:4•••'------- /y7/ / .,...„./ ,COMMISSIONER (-Z6'-12___ fj:,k. 4 f( ° r"h ) nk ! 1 Form 10-401(Revised 7/2009) This permit is valid`fof 24 rtnonthstfrloM fhe d�t 'of approval(20 AAC 25.005(g)) Submit in Duplicat 1 itlfG' s Conoco hillip Alaska RF-rPIVFD P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 .1 A N 2 3 2012 desks tm & 686 buns. Commission January 18th, 2012 AOLN?rcTle Commissioner-State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD) applications to drill and complete four laterals from Kuparuk well 1E-24B (PTD# 211-151). Coiled tubing drilling (CTD) operations are scheduled to begin as early as February 6, 2012, using the rig, Nabors CDR2-AC. The objective of the CTD project is to improve A-Sand sweep efficiency and oil recovery within the target pattern by drilling lateral sidetracks. Two laterals are planned from the lower casing exit and two laterals are planned fomr the upper casing exit out of the 3-1/2" liner in the parent wellbore 1E-24B. The parent wellbore will have no producing sections; it will be considered "suspended". For that reason, the laterals will then be named: 1E-24BL1, 1E-24BL1-01, 1E-24BL2, 1E-24BL2-01Y` A,9 Cir'/ dti,c2r . (-Z4/. 1Z_ Attached to this application are the following documents that explai the proposed job operations: - Permit to Drill Application Forms for 1 E-24BL1, 1 E-24BL1-01, 1 E-24BL2, 1 E-24BL2-01 - Directional Plans for 1E-24BL1, 1E-24BL1-01, 1E-24BL2, 1E-24BL2-01 - Current Wellbore Schematic - Proposed Wellbore Schematic If you have any questions or require additional information please contact me at my office 907-265-6820. Sincere) Mike A. Winfree ConocoPhillips Alaska Coiled Tubing Drilling Engineer KuparukCTD Laterals NABOBS ALASKA�� mighty 1 E-24BL1, 1 E-24BL1-01, 1 E-24BL2, 1 E-24BL2-01 V/"ijl , &We Application for Permit to Drill Document 2nc 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(t)and 20 AAC 25.005(b)) 2 2. Location Summary 2 (Requirements of 20 AAC 25.005(c)(2)) 2 3. Blowout Prevention Equipment Information 3 (Requirements of 20 AAC 25.005(c)(3)) 3 4. Drilling Hazards Information and Reservoir Pressure 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 3 (Requirements of 20 AAC 25.005(c)(6)) 3 7. Diverter System Information 4 (Requirements of 20 AAC 25.005(c)(7)) 4 8. Drilling Fluids 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 Summary of Operations 5 Pressure Deployment of BHA 6 Liner Running 7 14. Disposal of Drilling Mud and Cuttings 7 (Requirements of 20 AAC 25.005(c)(14)) 7 15. Directional Plans for Intentionally Deviated Wells 7 (Requirements of 20 AAC 25.050(b)) 7 16. Quarter Mile Injection Review(for injection wells only) 7 (Requirements of 20 AAC 25.402) 7 17. Attachments 7 Attachment 1: Directional Plans for 1E-24BL1, 1E-24BL1-01, 1E-24BL2, 1E-24BL2-01 7 Attachment 2: Current Well Schematic for 1 E-24B 7 Attachment 3: Proposed Well Schematic for 1 E-24BL1, 1 E-24BL1-01, 1E-24BL2, 1 E-24BL2-01 7 Page 1 of 7 ` t w 1/18/2012 PTD Application: 1 E-24BL1, 1 E-24BL1-01, 1 E-24BL2, 1 E-24BL2-01 1. Well Name and Classification (Requirements of 20 AAC 25.005(f)and 20 AAC 25.005(b)) The proposed laterals described in this document are 1 E-24BL1, 1 E-24BL1-01, 1 E-24BL2, and 1 E-24BL2-01. All four of these laterals will be classified as"Development- Oil'wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This wellbore is planned to be a lateral targeting the A sand package in the Kuparuk reservoir. Location at Surface 171' FSL, 226' FEL, Sec 16, T11N, R10E, UM NAD 1927 RKB Elevation 95 AMSL Northings: 5959760 Eastings: 550300 Pad Elevation 67 AMSL 1 E-24BL1 Location at Top of Productive Horizon 1478' FNL, 474' FWL, Sec 22, T11N, R10E, UM (Kuparuk A4) NAD 1927 Measured Depth, RKB: 6,800' Northings: 5958116 Eastings: 551016 Total Vertical Depth, SS: 6,184" Location at Total Depth 1116' FNL, 2457' FEL, Sec 22, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 9,375' Northings: 5958494 Eastings: 553360 Total Vertical Depth, SS: 6,223' 1 E-24BL1-01 Location at Top of Productive Horizon 1394' FNL, 1182' FWL, Sec 22, T11N, R10E, UM (Kuparuk A5) NAD 1927 Measured Depth, RKB: 7682' Northings: 5958204 Eastings: 551723 Total Vertical Depth, SS: ,6154' Location at Total Depth 448' FSL, 825' FEL, Sec , ' • 1,JR02-7W JM NAD 1927 Measured Depth, -KB: 9385' ' Northings: 5958486 Eastings: 553377 Total Vertical Depth, SS: 6185' 1 E-24BL2 Location at Top of Productive Horizon 1479' FNL, 454' FWL, Sec 22, T11N, R10E, UM (Kuparuk A4) NAD 1927 Measured Depth, RKB: 6800' Northings: 5958114 Eastings: 550996 Total Vertical Depth, SS: 6180' Location at Total Depth 1454' FNL, 1183' FEL, Sec 21, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 8550' Northings: 5958128 Eastings: 549357 Total Vertical Depth, SS: 6222' 1 E-24BL2-01 Location at Top of Productive Horizon 1447' FNL, 22' FEL, Sec 21, T11N, R10E, UM (Kuparuk A5) NAD 1927 Measured Depth, RKB: 7350' Northings: 5958143 Eastings: 550518 Total Vertical Depth, SS: 6187' Location at Total Depth 1363' FNL, 1140' FEL, Sec 21, T11N, R10E, UM NAD 1927 Measured Depth, RKB: 8500' Northings: 5958219 Eastings: 549400 Total Vertical Depth, SS: 6174' Gt4 1 € ' ii Page 2 of 7 1/18/2012 PTD Application: 1E-24BL1, 1E-24BL1-01, 1E-24BL2, 1E-24BL2-01 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005 (c)(3)) Please reference blowout prevention (BOP)schematics on file with the Commission for Nabors CDR2-AC. BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations. — Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. Using the maximum pressure in the area of 4060 psi. the maximum potential surface pressure, assuming a gas gradient of 0.1 psi/ft,would be 3443 psi. See the"Drilling Hazards Information and Reservoir Pressure" section for more details.) — The annular preventer will be tested to 250 psi and 2500 psi. 4. Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005(c)(4)(a)) While drilling 1E-24B with Doyon 141 (December 2011), the fluid weight at TD (6940'MD/6411'TVD)at which the reservoir (both A and C sands combined) remained static was 11.8 ppg. Based up on this static data, the anticipated bottomhole pressure at the kickoff point (KOP) is 3,819 psi, an 11.8 ppg equivalent mud weight (EMW). -- The maximum downhole pressure in the 1E-24B pattern is near injector 1E-23. 1E-23 has been shut-in since September 2011. An-updated static bottomhole pressure (BHP) reading was obtained on 11/9/2011, indicating a pressur of 4060 psi at 7676' MD/6073' TVDSS. This would be the equivalent Of 12.9ppg fluid. Using this pressures themaximum possible,in 1E-24B, the maximum potential surface`pressure, assuming a gas gradient of 0.1 psi/ft,would ,,,e 3,443 psi. Potential Gas Zones (Requirements of 20 AAC 25.005(c)(4)(b)) No specific gas zones will be drilled; however, 1 E pad did have some wells on miscible gas injection (Ml) so encountering Ml gas is a possibility. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The largest, expected risk of hole problems in the 1E-24B laterals will be at fault crossings. 3 of the 4 laterals will encounter faults with throws in the 30'-40' range. After seeing the first fault, the subsequent geologic interpretation of the folloing lateral can be adjusted to minimize the risk of drilling out of zone. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) N/A for this thru-tubing drilling operation. According to 20 AAC 25.030(1), thru-tubing drilling operations need not perform additional formation integrity tests. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) New Completion Details Liner Top Liner Btm Liner Top Liner Btm Lateral Name MD MD TVDSS TVDSS Liner Details 1 E-24BL1 7575' 9370' 6167' 6222' 2%", 4.7#, L-80, ST-L slotted liner; anchored aluminum billet on top. 2%", 4.7#, L-80, ST-L slotted liner; 1E-24BL1-01 6708' 9380' 6121' 6185' shorty deployment sleeve on top. • 1 E-24BL2 7350' 8545' 6187' 6222' 2Y", 4.7#, L-80, ST-L slotted liner; anchored aluminum billet on top. 1 E-24BL2-01 6685' 8495' 6101 6173 23/", 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. 1 1NiA Page 3 of 7 1/18/2012 PTD Application: 1 E-24BL1, 1 E-24BL1-01, 1 E-24BL2, 1 E-24BL2-01 Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD TVD psi psi Conductor 16" 62.55 H-40 Welded 0' 112' 0' 112' 1640 630 Surface 10-3/4" 45.5 K-55 BTC 0' 2,399' 0' 2,399' 3580 2090 Casing 7" 26 K-55 BTC 0 4,914 0' 4,630' 4980 4330 Liner 5-1/2" 15.5 L-80 Hydril 563 4,682' 6,459' 4,435' 6,007' 7000 4990 Liner 3-1/2 " 9.3 L-80 Hydril 511 6,288' 6,937' 5,843' 6,408' 10160 10,540 Tubing 3-1/2 " 9.3 L-80 EUE 8rd-mod 0' 6,274' 0' 5,853' 10160 10,540 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A for this thru-tubing drilling operation. Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a diverter system is not required. 8. Drilling Fluids Program (Requirements of 20 AAC 25.005(c)(8)) Diagram of Drilling System Diagram of Nabors CDR2-AC mud system is on file with the Commission. Description of Drilling Fluid System — Window milling operations: Chloride-based Biozan brine(8.6 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (9.5-10.5 ppg). While this mud weight does not hydrostatically overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 1 E-24B contains a subsurface safety valve (SSSV). The SSSV will be used to pressure deploy the liner in lieu of loading the well with completion fluid. In the event that the SSSV becomes inoperable, the well will be loaded with 12.0 ppg Sodium Bromide completion fluid in order to maintain managed pressure on open reservoir while running completions. — Emergency Kill Weight fluid: Two well bore volumes (-170 bbl),of 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. I this situation, a "wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. Managed Pressure Drilling Practice Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on the openhole formation throughout the coiled tubing drilling (CTD) process. Maintaining a constant BHP promotes wellbore stability, particularly in shale sections, while at the same time providing an overbalance on the reservoir. Through experience with drilling CTD laterals in the Kuparuk sands, 11.8 ppg has been identified as the minimum EMW to ensure stability of shale sections. Since this well is proposed as an infield development candidate in an actively water flooded field, expected reservoir pressures can be difficult to estimate. In this case, however, a constant BHP target of 11.8 ppg (target may change based on base fluid weight and acceptable choke pressure for MPD operations), targeted at the window, is available based on data from the recently drilled 1E-24B parent wellbore. The constant BHP target will be adjusted to maintain overbalanced v conditions if increased reservoir pressure is encountered during drilling. The constant BHP target will be maintained utilizing the surface choke. Any change of circulating friction pressure due to change in pump rates or change in depth of circulation will be offset with back pressure adjustments. ORIGINAL Page 4 of 7 1/18/2012 • , PTD Application: 1 E-24BL1, 1 E-24BL1-01, 1 E-24BL2, 1 E-24BL2-01 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an exploratory or stratigraphic test well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) Summary of Operations Background Kuparuk well 1 E-24A was sidetracked and completed as 1E-24B in December 2011 as a set-up for the four CTD laterals that this application covers. The liner across the reservoir was cemented in place and has not been perforated. The plan for the parent wellbore is to leave it as "suspended"; i.e. not open the parent up to production. At this time, the only production from 1 E-24B will come from the CTD laterals. Drilling CTD laterals and redeveloping the 1E-24B producer-centered pattern will improve productivity and increase oil recovery in this historically underperforming A-sand pattern Pre-Rig Work 1. Perform drift and tag. 2. Perform a dummy whipstock drift to ST depth. 3. Install dummy valve in GLM 5 and pressure test. 4. Perform GR/CCL/RCBL log for tie-in purposes to confirm KOP is spaced between collars and cement evaluation. 5. Set whipstock pre-rig at 6,713' MD (+/- 10'to adjust for actual collar locations). 6. Set BPV and prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. If the whipstock was not set pre-rig, set whipstock at 6,713' MD (+/- 10' to adjust for actual collar locations). 3. Mill a 2.80", single string window exit oriented 20° LOHS (340°) 4. Drill 1E-24BL1 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4 sand to a TD of 9,375' MD b. Run 2%" slotted liner from TD to—7,575', utilizing the SSSV for deploying the liner Rig Work Continued on next page.... Page 5 of 7 1/18/2012 PTD Application: 1 E-24BL1, 1 E-24BL1-01, 1 E-24BL2, 1 E-24BL2-01 Rig Work Continued 5. Drill 1E-24BL1-01 Lateral a. Drill 2.70"x 3" bi-center lateral in the A5 sand to a TD of 9,385' MD / b. Run 2%" slotted liner from TD to inside the tubing at—6,708', utilizing the SSSV for deploying the liner 6. Set upper whipstock at 6,695' MD (+/- 10'to adjust for actual collar locations). rib 7. Mill a 2.80", single string window exit oriented to 15° ROHS (15°) 8. Drill 1E-24BL2 Lateral a. Drill 2.70"x 3" bi-center lateral in the A4 sand to a TD of 8,550' MD b. Run 2%" slotted liner from TD to —7,350', utilizing the SSSV for deploying the liner 9. Drill 1E-24BL2-01 Lateral a. Drill 2.70"x 3" bi-center lateral in the A5 sand to a TD of 8,500' MD b. Run 2%" slotted liner from TD up into the 3.5" tubing (to—6665' MD). 10. POOH swapping well over to brine. Freeze protect. 11. Set BPV. ND BOPE. RDMO Nabors CRD2-AC. 12. Handover to Production group. Post-Rig Work 1. Pull BPV and install gas lift design. 2. Put on production. Pressure Deployment of BHA The double swab valves, double deployment rams, double ball valves and one set of double check valves in the BHA, and a slick line lubricator are used to deploy/undeploy the BHA under pressure. The Managed Pressure Drilling technique is used to maintain an overbalance on the formation, pumping below the swab valve, during the deployment procedure. The pressure control equipment listed ensures there are always two barriers to reservoir pressure during the BHA deploy/undeploy process. When the lubricator is installed and the BHA is spaced out above the tree, the double swab valves are closed and provide isolation to reservoir pressure. When the BHA is spaced out for access to the double ball valves, the set of double check valves and the double ball valves in the bottom hole assembly are preventing wellbore pressure communication up the BHA. The double deployment rams and lubricator are annular barriers to reservoir pressure with the BHA in this position. The lubricator can be removed once pressure is bled off above the deployment rams. Two barriers are still maintained with the double deployment rams on the annulus and the double check valves and double ball valves in the BHA. With the coil made up to the BHA, the double ball valves open in the BHA, and the riser installed, the BHA can continue to be safely run in the hole. Page6of7 , ,,� i x" 1/18/2012 PTD Application: 1 E-24BL1, 1 E-24BL1-01, 1 E-24BL2, 1 E-24BL2-01 Liner Running — Since 1E-24B is equipped with a SSSV, the 1E-24B CTD laterals will not need to be displaced to an overbalancing fluid prior to running liner unless the SSSV fails to operate properly. See the "Drilling Fluids"section for more details. — While running 2%" slotted liner, a joint of 2%" non-slotted tubing will be standing by for emergency deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a deployment drill with this emergency joint on every slotted liner run. The 2%" rams will provide secondary well control while running 2%" liner. 14. Disposal of Drilling Mud and Cuttings (Requirements of 20 AAC 25.005(c)(14)) — No annular injection on this well. — Class II liquids to KRU 1R Pad Class II disposal well — Class II drill solids to Grind & Inject at PBU Drill site 4 — Class I wastes will go to Pad 3 for disposal. 15. Directional Plans for Intentionally Deviated Wells (Requirements of 20 AAC 25.050(b)) — The Applicant is the only affected owner. — Please see Attachment 1: Directional Plan — Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. — MWD directional, resistivity, and gamma ray will be run over the entire openhole section. - Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance 1 E-24BL1 18,600' 1 E-24BL1-01 18,600' 1 E-24BL2 20,750' 1 E-24BL2-01 21,000' — Distance to Nearest Well within Pool(toe measured to offset well) Lateral Name Distance Well 1 E-24BL1 100' 1 E-24 1 E-24BL1-01 180' 1E-24 1 E-24BL2 300' 1E-29 1 E-24BL2-01 300' 1E-29 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A for this well because it will be put on production service. 17. Attachments Attachment 1: Directional Plans for 1E-24BL1, 1E-24BL1-01, 1E-24BL2, 1E-24BL2-01 Attachment 2: Current Well Schematic for 1E-24B Attachment 3: Proposed Well Schematic for 1E-24BL1, 1E-24BL1-01, 1E-24BL2, 1E-24BL2-01 Page 7 of 7 1/18/2012 ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E-24 1 E-24BL1-01 Plan: 1 E-24BL1-01_wp02 Standard Planning Report 10 January, 2012 r�rr BAKER HUGHES N.,' ConocoPhillips or its affiliates «k ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 E-24B @ 93.80ft(D141 (26.8+67)) Site: Kuparuk 1 E Pad North Reference: True Well: 1 E-24 Survey Calculation Method: Minimum Curvature Wellbore: 1E-24BL1-01 Design: 1 E-24BL1-01_wp02 Project Kuparuk River Unit 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 1 E Pad Site Position: Northing: 5,959,760.24ft Latitude: 70°18'3.022 N From: Map Easting: 549,889.51 ft Longitude: 149°35'45.358 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.38 ° Well 1 E-24 Well Position +NI-S 0.00 ft Northing: 5,959,760.73 ft Latitude: 70°18'2.999 N +E/-W 0.00 ft Easting: 550,300.55 ft Longitude: 149°35'33.373 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 67.00 ft Wellbore 1E-24BL1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2011 2/15/2012 16.45 79.91 57,375 Design 1E-24BL1-01_wp02 Audit Notes: Version: Phase: PLAN Tie On Depth: 7,575.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) -67.00 0.00 0.00 80.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +EI-W Rate Rate Rate TFO (ft) (0) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (0) Target 7,575.00 91.50 67.69 6,167.03 -1,610.44 1,315.79 0.00 0.00 0.00 0.00 7,675.00 101.50 67.69 6,155.73 -1,572.76 1,407.59 10.00 10.00 0.00 0.00 7,775.00 92.98 72.97 6,143.13 -1,539.46 1,500.90 10.00 -8.52 5.29 148.00 7,875.00 89.54 63.58 6,140.92 -1,502.49 1,593.65 10.00 -3.44 -9.39 250.00 8,010.00 83.26 75.56 6,149.44 -1,455.53 1,719.60 10.00 -4.65 8.87 118.00 8,145.00 89.07 87.78 6,158.50 -1,436.11 1,852.57 10.00 4.31 9.05 65.00 8,345.00 89.88 67.79 6,160.35 -1,394.00 2,047.04 10.00 0.40 -9.99 272.20 8,645.00 89.89 97.79 6,160.96 -1,356.79 2,341.28 10.00 0.01 10.00 90.00 8,945.00 84.19 68.29 6,176.79 -1,321.10 2,635.29 10.00 -1.90 -9.83 258.50 9,045.00 87.67 77.69 6,183.91 -1,291.97 2,730.55 10.00 3.48 9.40 70.00 9,145.00 89.99 87.42 6,185.95 -1,279.03 2,829.56 10.00 2.32 9.73 76.70 9,270.00 89.99 99.92 6,185.96 -1,287.00 2,954.06 10.00 0.00 10.00 90.00 9,385.00 89.99 88.42 6,185.98 -1,295.34 3,068.56 10.00 0.00 -10.00 270.00 1/10/2012 11:12:34AM Page 2 COMPASS 2003.16 Build 69 1 L ti-' ConocoPhillips or its affiliates Ir/ii ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 E-24 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-24B @ 93.80ft(D141 (26.8+67)) Site: Kuparuk 1E Pad North Reference: True Well: 1 E-24 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-24BL1-01 Design: 1 E-24BL1-01_wp02 Planned Survey I Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/.W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 7,575.00 91.50 67.69 6,167.03 -1,610.44 1,315.79 1,016.15 0.00 0.00 5,958,159.29 551,626.961 TIP/KOP 7,600.00 94.00 67.69 6,165.83 -1,600.96 1,338.89 1,040.54 10.000.00 5,958,168.92 551,649.99 7,675.00 101.50 67.69 6,155.73 -1,572.76 1,407.59 1,113.10 10.00 0.00 5,958,197.58 551,718.50 2 7,700.00 99.38 69.03 6,151.20 -1,563.70 1,430.44 1,137.18 10.00 148.00 5,958,206.79 551,741.29 1 7,775.00 92.98 72.97 6,143.13 -1,539.46 1,500.90 1,210.77 10.00 148.24 5,958,231.51 551,811.57 3 7,800.00 92.12 70.62 6,142.01 -1,531.65 1,524.62 1,235.49 10.00 -110.00 5,958,239.46 551,835.24 7,875.00 89.54 63.58 6,140.92 -1,502.49 1,593.65 1,308.54 10.00 -110.10 5,958,269.08 551,904.07 4 7,900.00 88.36 65.79 6,141.38 -1,491.81 1,616.25 1,332.64 10.00 118.00 5,958,279.92 551,926.59 8,000.00 83.71 74.67 6,148.30 -1,458.08 1,710.00 1,430.83 10.00 117.96 5,958,314.27 552,020.10 8,010.00 83.26 75.56 6,149.44 -1,455.53 1,719.60 1,440.73 10.00 117.34 5,958,316.88 552,029.69 5 8,100.00 87.11 83.72 6,157.00 -1,439.44 1,807.73 1,530.31 10.00 65.00 5,958,333.56 552,117.70 8,145.00 89.07 87.78 6,158.50 -1,436.11 1,852.57 1,575.05 10.00 64.31 5,958,337.20 552,162.51 6 8,200.00 89.29 82.28 6,159.29 -1,431.34 1,907.34 1,629.81 10.00 -87.80 5,958,342.33 552,217.24 8,300.00 89.69 72.29 6,160.18 -1,409.36 2,004.76 1,729.57 10.00 -87.72 5,958,364.96 552,314.50 8,345.00 89.88 67.79 6,160.35 -1,394.00 2,047.04 1,773.88 10.00 -87.63 5,958,380.60 552,356.68 7 8,400.00 89.88 73.29 6,160.47 -1,375.69 2,098.88 1,828.11 10.00 90.00 5,958,399.26 552,408.39 8,500.00 89.88 83.29 6,160.68 -1,355.42 2,196.68 1,927.94 10.00 89.99 5,958,420.18 552,506.04 8,600.00 89.89 93.29 6,160.88 -1,352.44 2,296.51 2,026.77 10.00 89.97 5,958,423.82 552,605.83 8,645.00 89.89 97.79 6,160.96 -1,356.79 2,341.28 2,070.11 10.00 89.95 5,958,419.78 552,650.64 8 8,700.00 88.80 92.40 6,161.59 -1,361.67 2,396.04 2,123.19 10.00 -101.50 5,958,415.26 552,705.42 8,800.00 86.84 82.59 6,165.40 -1,357.32 2,495.75 2,222.14 10.00 -101.44 5,958,420.28 552,805.08 8,900.00 84.98 72.74 6,172.54 -1,336.04 2,593.06 2,321.67 10.00 -101.06 5,958,442.21 552,902.25 8,945.00 84.19 68.29 6,176.79 -1,321.10 2,635.29 2,365.84 10.00 -100.36 5,958,457.43 552,944.36 9 9,000.00 86.09 73.47 6,181.46 -1,303.16 2,687.05 2,419.93 10.00 70.00 5,958,475.72 552,996.00 9,045.00 87.67 77.69 6,183.91 -1,291.97 2,730.55 2,464.72 10.00 69.56 5,958,487.19 553,039.42 10 9,100.00 88.94 83.04 6,185.53 -1,282.77 2,784.73 2,519.67 10.00 76.70 5,958,496.75 553,093.53 9,145.00 89.99 87.42 6,185.95 -1,279.03 2,829.56 2,564.47 10.00 76.54 5,958,500.80 553,138.331, 11 9,200.00 89.99 92.92 6,185.96 -1,279.19 2,884.54 2,618.59 10.00 90.00 5,958,501.01 553,193.31 9,270.00 89.99 99.92 6,185.96 -1,287.00 2,954.06 2,685.69 10.00 90.00 5,958,493.66 553,262.871 12 9,300.00 89.99 96.92 6,185.97 -1,291.39 2,983.73 2,714.15 10.00 -90.00 5,958,489.46 553,292.57 9,385.00 - 89.99 88.42 6,185.98 -1,295.34 3,068.56 2,797.01 10.00 -90.00 5,958,486.08 553,377.42 TD 1110/2012 I1:12:34AM Page 3 COMPASS 2003.16 Build 69 ;..' RR f 1 1-1 ConocoPhillips or its affiliates 11E411 ConocoPhillips Planning Report BAMIES Alaska Database: EDM Alaska Prod v16 Local Co-ordinate teeerence:' Well 1 E-24 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-24B @ 93.80ft(D141 (26.8+67)) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-24 Survey Calculation Method: Minimum Curvature Wellbore 1E-24BL101 Design: 1E-24BL1-01_wp02 ,rte ...Etetott .� A.M.... Targets ' 'q Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) (1 (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1E-24BL1,BL1-01_Pc 0.00 0.00 0.00 -1,430.24 602.15 5,958,334.70 550,912.20 70°17'48.933 N 149°35'15.821 W -plan misses target center by 6208.15ft at 7700.00ft MD(6151.20 TVD,-1563.70 N,1430.44 E) -Polygon Point 1 0.00 -1,430.24 602.15 5,958,334.70 550,912.20 Point2 0.00 -1,447.86 846.06 5,958,318.71 551,156.20 Point 3 0.00 -1,558.19 893.33 5,958,208.71 551,204.20 Point4 0.00 -1,310.52 1,549.06 5,958,460.74 551,858.20 Point5 0.00 -1,172.79 2,195.05 5,958,602.78 552,503.19 Point6 0.00 -1,092.44 3,046.69 5,958,688.82 553,354.19 Point7 0.00 -1,077.80 3,251.81 5,958,704.83 553,559.19 Point 8 0.00 -1,439.98 3,272.40 5,958,342.83 553,582.20 Point 9 0.00 -1,429.68 2,926.43 5,958,350.81 553,236.20 Point 10 0.00 -1,481.50 2,296.01 5,958,294.78 552,606.20 Point 11 0.00 -1,555.84 1,743.45 5,958,216.75 552,054.21 Point 12 0.00 -1,710.71 1,270.37 5,958,058.73 551,582.22 Point 13 0.00 -1,874.102 .2 1 0 5 5 5,957,893.72 551 338.22 Point 14 0.00 -1,975.44 772.55 5,957,790.70 551,086.23 Point 15 0.00 -1,848.17 584.37 5,957,916.70 550,897.22 Point 16 0.00 -1,430.24 602.15 5,958,334.70 550,912.20 1E-24BL1-01_Fault2 0.00 0.00 6,161.00 -1,336.95 2,348.95 5,958,439.66 552,658.17 70°17'49.847 N 149°34'24.903 W -plan misses target center by 20.69ft at 8650.88ft MD(6160.98 TVD,-1357.56 N,2347.11 E) -Polygon Point 1 6,161.00 -1,588.22 2,084.25 5,958,186.65 552,395.18 Point 2 6,161.00 -1,320.59 2,145.03 5,958,454.65 552,454.17 Point 3 6,161.00 -1,140.95 2,201.23 5,958,634.65 552,509.16 1E-24BL1-01_T1 0.00 0.00 6,145.00 -1,535.82 1,432.53 5,958,234.68 551,743.19 70°17'47.893 N 149°34'51.617 W -plan misses target center by 25.73ft at 7711.66ft MD(6149.40 TVD,-1559.63 N,1441.22 E) -Point 1E-24BL1-01_T6 0.00 0.00 6,186.00 -1,242.63 3,047.66 5,958,538.65 553,356.16 70°17'50.772 N 149°34'4.536 W, -plan misses target center by 52.94ft at 9361.64ft MD(6185.97 TVD,-1295.51 N,3045.21 E) -Point 1E-24BL1-01_T5 0.00 0.00 6,184.00 -1,271.50 2,729.43 5,958,507.65 553,038.16 70°17'50.489 N 149°34'13.812 WI -plan misses target center by 20.26ft at 9047.32ft MD(6184.00 TVD,-1291.48 N,2732.82 E) -Point 1E-24BL1-01_T2 0.00 0.00 6,141.00 -1,467.49 1,533.00 5,958,303.68 551,843.18 70°17'48.565 N 149°34'48.689 W -plan misses target center by 56.98ft at 7832.72ft MD(6141.12 TVD,-1519.98 N,1555.17 E) -Point 1E-24BL1-01_T4 0.00 0.00 6,161.00 -1,336.95 2,348.95 5,958,439.66 552,658.17 70°17'49.847 N 149°34'24.903 W -plan misses target center by 20.69ft at 8650.88ft MD(6160.98 TVD,-1357.56 N,2347.11 E) -Point 1E-24BL1-01_T3 0.00 0.00 6,158.00 -1,395.38 1,816.51 5,958,377.67 552,126.18 70°17'49.274 N 149°34'40.424 W -plan misses target center by 42.97ft at 8112.05ft MD(6157.55 TVD,-1438.24 N,1819.70 E) -Point 1/10/2012 11:12:34AM Page 4 COMPASS 2003.16 Build 69 OhIbINALi • --' ConocoPhillips or its affiliates «a ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-24 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1E-24B @ 93.80ft(D141 (26.8+67)) Site: Kuparuk 1E Pad North Reference: True Well: 1E-24 Survey Calculation Method: Minimum Curvature Wellbore: 1E-24BL1-01 Design: 1 E-24BL1-01_wp02 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C') (") 2,385.80 2,291.94 10 3/4" 10-3/4 13-1/2 6,458.00 5,912.68 5 1/2" 5-1/2 7 6,966.00 6,195.63 3-1/2" 3-1/2 4-1/8 9,385.00 6,185.98 2-3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +El-W (ft) (ft) (ft) (ft) Comment 7,575.00 6,167.03 -1,610.44 1,315.79 TIP/KOP 7,675.00 6,155.73 -1,572.76 1,407.59 2 7,775.00 6,143.13 -1,539.46 1,500.90 3 7,875.00 6,140.92 -1,502.49 1,593.65 4 8,010.00 6,149.44 -1,455.53 1,719.60 5 8,145.00 6,158.50 -1,436.11 1,852.57 6 8,345.00 6,160.35 -1,394.00 2,047.04 7 8,645.00 6,160.96 -1,356.79 2,341.28 8 8,945.00 6,176.79 -1,321.10 2,635.29 9 9,045.00 6,183.91 -1,291.97 2,730.55 10 9,145.00 6,185.95 -1,279.03 2,829.56 11 9,270.00 6,185.96 -1,287.00 2,954.06 12 9,385.00 6,185.98 -1,295.34 3,068.56 TD 1/102012 11:12:34AM Page 5 COMPASS 2003.16 Build 69 a H N N N a a c 2 :...1- m o o N coco r O C M ^�` LoJ © N © m Wa` a - N _ N V • 't M csi U O m p I in I W D N oo a (..%7,(%) E )it),, H Om m 2 m N a W I °i OD arn c m H H N -C • _ U © c X IAD -, W _L N\ 71 \ O C ", m CC W x EL H J X \ m W N V COO \ (n 6) = p 0-) CO \\ N CV N N y Y o N \ C co co O U \ A M M J m m c O 1 E a / M a V coi . // Oci 411111121111'' a co io Iol 4 ____, 4„ ›,,,, c:), _( *CD _ Ud O gn /1 M N � O COL. i‘.,:_LA co co as Ii' YOQ ink m ca cp I III co a) El n a2 0 U e p O © // t lc cv en d c I O 11 i a'a O oo I L.aa' o io in - in .- in i..-' r ( N �` N V cD Q J N O m M N 2 U..117., E co al n m2o - M C4 a m rn — W a - H ORIGINAL ■ ...._q 1/ iim iF ` r g Alt! , ' �- -\illai = I it .7 = I � }q q rr : �� ■:� i-! moi: Y - �■i'_a �. ■_'voi M � , i tet: � + 111V A � - 1 -� i' ._ tai l.-hi • �{ I I •t i t 1— -I '--+ rAAi • ~ U all i . r aaai bh N ' -� ■ ■a.aaw�■O h g f �� Mang r �''r„ �77:g�E Ellin1 ' 4-!7- , IIIc` ..4::f. ` h i 12 Pk III i ,_,,,,;.. • ,_ K fp7f K K§ 1illi �■NN 1-,.4, ► ■■■q.•Morm ,,,,, F..1..4..::, .;,,.,,,,,,,__, ,,,tr.-.1.t4_,i.lir1�Nm■ ■{qp��■ + _ . , - aaA'4rG„As■,v • Ell a as w ■ a ■ ■qislaa ■ ■ ■t g wall .:___...21.: _t_. :,_.17, _:__. _ , — i y -i.- i -F f-I 1 �I� 1. - �_-t' - 11L ti ii1i- , 1- Ho w c4• d ins 1 ai'I i_H7 \ / N L a I z; I 1,17. , '_`. �1 : ■ E ■■I� s O ,g O \ 1 ■ ■■a■1 1 ■ q _■NGV7r �■J■�. ao il puokinuE x P- CO 1.• 12 4. 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F l 1 F. �: -; m • 0 - --- is ta.=' ' $ ® • '1 ` ; 14 !I f•rail !, LiOM : j - I I iOO. ,qa I 1 _ ar; ; • 11111 IImIImtm�:�t q ■q Mall o_ 1}� ma Ln • _ .t ' 4' t 1 •-;•V +q__4.4- , 8 •_ YO 7 g O O O C V O - O O8 C N ' G N N G O $ 'r: ' C q O N N , . O U w 4 (4101/pRIOAtotwOmnos y mNQ£ W d.� , KUP 1E-24B • ConocoP ilhips . ie""• Well Attributes Max Angle&MD TD Ab, Wellbore API/UWI Field Name Well Status Incl(") (MD(RKB) Act Btm(RKB) 500292085702 KUPARUK RIVER UNIT PROD 37.04 I 3,894.82 Comment H25(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date ••- Wall ContO IE 248 l/5/20122:50:02 PM SSSV:TRDP 90 9/152010 Last WO: 32.30 12/13/1982 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag RKB 5,307.0 12/3/2011 Rev Reason:ADD SIDETRACK ninam 1/5/2012 HANGER,23 Casing Strings II Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd tee. 5.5 LINER 5 1/2 4.950 4,679.2 6,458.0 6,006.5 15.50 L-80 HYD563 Liner Details Top Depth (TVD) Top Incl Noml... Top(R1(13) (RKB) P) Item Description Comment ID(In) 4,679.2 4,433.5 31.99 TIEBACK TIW X-PACK TIE BACK EXPANDER 4.940 4,683.4 4,437.0 32.01 HANGER TIW X-PACK LINER HANGER 4.875 4,688.8 4,441.7 32.03 NIPPLE TIW SPACE NIPPLE 4.906 is is 4,693.4 4,445.6 32.05 NIPPLE 'TIW SPACE NIPPLE 4.906 Casing Description String 0... String ID...Top(RKB) Set Depth(1...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR, 3.5 LINER 3 1/2 2.992 6,262.8 6,937.0 6,408.8 9.20 L-80 HVD511 35712 Liner Details Top Depth (WD) Top Incl Noml... it Top(RKB) 10KB) C) Item Description Comment ID(In) SAFETY VLV, 6,262.8 5,844.1 32.72 PACKER BAKER HR ZXP LINER TOP PACKER 3.000 1,755i 6,288.5 5,865.5 33.22 HANGER BAKER FLEX LOCK LINER HANGER 2.980 Tubing Strings SURFACE._ Tubing Description0... String ID...Top IRKB) Set Depth f Set Depth(TVD)...String Wt...String...String Top Thrd 33-2,398 String (... TUBING 31/2 2.992 22.6 6,274.0 5,853.5 9.30 L-80 EUE&dABMOD GAS LIFT. Completion Details 25aTop Depth (WD) Top Incl Nomi... Top(RKB) (RKB) (°) Rem Description Comment ID(in) 22.6 22.6 -0.03 HANGER FMC TUBING HANGER 3.500 1,785.2 1,785.1 0.72 SAFETY VLV SCHLUMBERGER TRMAXX-CMT-5-SR SAFETY VALVE 2.813 6,215.0 5,803.7 31.80 NIPPLE CAMCO X NIPPLE 2.813 GAS LIFT, 6,257.5 5,839.7 32.62 LOCATOR BAKER LOCATING COLLAR 2.970 3.709 --_-_. Ir 6,258.0 5,840.1 32.63 SEAL ASSY SEAL ASSEMBLY FOR BOT 80-40 SEAL BORE EXTENSION HALF 3.010 SW MUILE SHOE • • GAS LIFT. I I 4.772 WHIPSTOCK 4,913 CEMENT, 4,080 GAS LIFT, 5,449 GAS LIFT, 6,001 NIPPLE.6,215 SEAL ASSY, W, 6,256 i 5.5 LINER, y 4,679-6,458 ■ .2034,937 I i` 8.260-240), i TD(1 E-2460 6ION, PRODUCTION, 32.7,395 III 4aia - II III Illt TMEFr- ME i NIBill I II ihUnitrel Details Top Depth Top Port (WD) Incl OD Valve Latch Size TRO Run Stn Top(RKB) (RKB) (1 Make Model (In) Sery Type Type (in) (psi) Run Date Com... 1 2,504.1 2,504.0 0.99 CAMCO KBG-2-9 1 GAS LIFT DMY DK-1 0.000' 0.0 12/29/2011 2 3,709.3 3,638.6 31.73 CAMCO KBG-2-9 1 GAS LIFT DMY DK-1 0.000 0.0 12/29/2011 3 4,772.1 4,512.1 32.71 CAMCO KBG-2-9 1 GAS LIFT DMY DK-1 0.000 0.0 12/29/2011 4 5,448.9 5,092.9 19.50 CAMCO KBG-2-9 1 GAS LIFT DMY 0K-1 0.000 0.0 12/29/2011 5 6,001.0 5,615.3 25.40 CAMCO KBG-2-9 f GAS LIFT SOV DCK-3 0.000 0.0 12/292011 TRANSMITTAL LETTER CHECKLIST WELL NAME K--2 Lk ( E — z c46 LI —� I PTD# ( Z //-} Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: 4,e (i..-v tic L I Lrt POOL: M�' G£ /—e4 - 0/ Check Box for 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 sewnent of existing well K-2_(( / - / (If last two digits in Permit No. )-/t /61,API No. 50- �- 'S 7 -(_)2.- 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 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:9/09/2011 O m D D "i) m -a o I- s m 'b S o m 0 0 cn • v 'a ; r 13 3 CD — 3 M' No 0 3 m N o N_(0 A 0 o) G A a O O s, c c) N 0 N w i-,-) 0 O N O (D O tp O • -1 N N N 01 W W CO W W W W W W W N N N N N N N N N N A .� CO Oo V.._O CO A WN c0o 0 W V C) COW N -+ O C0 03 V 0) 01A W N -, O CO COCb COC) 01 A W N -+ O V ,- m co O\ cn OQUI(D0 � * O WW -,, D 0, D n n n n - D m n 'b< 'a0yO O Q m m C� (DCD Z nro 0 CD O ., ooO -0 . ° v ° _I _ C o 1 3 m0 y CD Nm 30 'o - 2 . 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