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212-072
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 b direct inspection offirg, the file. 1 c - 0 _ Well History File Identifier Organizing (done) ❑ Two-sided ❑ Rescan Needed 7r RE AN: OVERSIZED: NOTES: EX I IRE,? WB.LL C for Items: ❑ Maps: Grayscale Items: ❑ Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: 1 111,Lti 1 if /s/ iti P Project Proofing BY: deP Date: 1 1 1 1 9, isi (HP Scanning Preparation x 30 = + = TOTAL PAGES ca7 • (Count does not include cover sheet) BY: Maria Date: l I Li (k s/ Production Scanning � I Stage 1 Page Count from Scanned File: U (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES NO BY: � Date: I J 1 ` `4 /s/ '4Y 6 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 Page 1 of 1 Schwartz, Guy L (DOA) From: Winfree, Michael Alex(Jr.) [Michael.A.Winfree@conocophillips.com] Sent: Tuesday, June 19, 2012 3:22 PM To: Schwartz, Guy L (DOA) Cc: Allsup-Drake, Sharon K; Gantt, Lamar L Subject: 2M-01A Operations Update (Sundry Number 312-179) (PTD Number 212-072 and 212-073) Guy, .�..... As we discussed on the phone earlier today, we have made a decision to suspend CTD operations on 2M-01. After a failed attempt to exit the 7" casing off of a whipstock set in a cement pilot hole, the pilot hole was re-cemented and an attempt to drill another pilot hole was unsuccessful. With no favorable alternative kick off point, the decision was made to rig down the CTD rig and move off of 2M-01. We are currently evaluating other methods to develop the resource at 2M-01 such as a Rig Workover or a Rotary Sidetrack to set up CTD laterals. All of the work performed to date has been under the approved sundry (312-179). No operations were performed under the approved permit to drill (212-072, 212-073). A 10-407 will be submitted leaving the well suspended. Please let me know if you need any additional information regarding 2M-01 CTD operations. Thanks, -Mike Mike A. Winfree D'iI/ii g Engineer 907 265 6820 Direct 907 242 0246 Cell 6/19/2012 ,�,,_ .^1 . n ALAsEA ,L , 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 L. Gantt Alaska CTD Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2M-01A ConocoPhillips Alaska, Inc. Permit No: 212-072 Surface Location: 114' FSL, 19' FWL, SEC. 27, T11N, RO8E, UM Bottomhole Location: 2158' FNL, 2267' FWL, SEC. 29, T11N, RO8E, UM Dear Mr. Gantt: 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. O' rly, Jo• . N•rman •m • loner DATED this •C day of June, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA MAY 2 5 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 1 a Type of Work: • 1 b.Proposed Well Class: Development-Oil El' Service-Winj ❑ Single Zone ❑✓ lc.Specify if well is proposed for: Drill ❑ Re-drill ❑i Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name. 5. Bond: U Blanket ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 2M-01A • 3.Address 6 Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 12295'. TVDSS: 5965' Kuparuk River Field 4a. Location of Well(Governmental Section): 7 Property Designation(Lease Number). Surface: 114'FSL, 19'FWL,Sec.27,T11N,RO8E,UM ADL 25586,25585 Kuparuk River Oil Pool • Top of Productive Horizon: 8 Land Use Permit: 13.Approximate Spud Date 1134'FSL, 1234'FEL,Sec.29,T11N,RO8E,UM 2672,2671 '.-675724342.24417_0111_, t-- Total Depth: 9 Acres in Property: 14.Distance to / 2158'FNL,2267'FWL,Sec.29,T11N, RO8E, UM 2560 Nearest Property 2187' • 711"'" 4b Location of Well(State Base Plane Coordinates-NAD 27). 10.KB Elevation above MSL: • 147 feet 15 Distance to Nearest Well Open Surface:x- 487859.5- y- 5948986 - Zone- 4 GL Elevation above MSL: feet to Same Pool: 2M-28,2600' 16 Deviated wells: Kickoff depth. 9435 - ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle: 94° , deg Downhole:4588 psig , Surface:3984 psig 18 Casing Program Specifications Top - Setting Depth -Bottom Cement Quantity,c.f or sacks Hole Casing Weight Grade Coupling Length MD TVDSS MD TVDSS (including stage data) 3" 2.375" 4.7# L-80 ST-L 2695 9600' 5954' 12295' 5965' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft) Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft) Junk(measured) 9800 6331 9697' 6248' Casing Length Size Cement Volume MD TVD Conductor/Structural 76' 16" 225 sx PF C 117' 117' Surface 3305' 9.625" 564 sx Perm E,600 sx CI G 3346' 2748' Intermediate Production 9752' 7" 198 sx Class G 9785' 6319' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 9435-9489' 6044'-6085' 20 Attachments. Property Plat❑ BOP Sketch❑ Dnlling 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: \\i'r"-- 22 I hereby certify that the foregoing is true and correct Contact J. Gary Eller @ 263-4172 Printed Name., L. G ntt Title Alaska CTD Supervisor Signet?' "1"9„,/..eiposive.. /1 LL G Phon 265-6120 Date S -2_5- /Z Commission Use Only Permit to Drill / • API Number / / / Permit Approval l See cover letter Number ( Z� 7L�+ 50-��� 1� (JC'c C Date. (IA 1 I ' Ifor other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: El Ag- LLdp p s evt" 1e...31-Samples req'd. Yes ❑ o Q• I ud log req'd: Yes ❑ No ZOther: / H2S measures: Yes NoEl i Dir; ion.1 svy req'd: Yes d No ❑ -It-ZSDb isA-,.,./K TSr- C,K,:,,) "Iir 6 �j,DA'�— Q R G I - ' r-ROVED BY THE COMMISSION ,COMMISSIONE Form 10-401 (Revised 7/2009) This permit is valid for 24 months from the date of approvalI1 G.y.12-- L9 W VA\n 25.E 5(g)) / t� it in Duplicate 251..p RECEIVED ConocoPhillips MAY 2 5 2012 Alas P.O. BOX 100360 ka AOGCC ANCHORAGE,ALASKA 99510-0360 May 25, 2012 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 2M-01A and 2M-01AL1 from Kuparuk well 2M-01 (PTD# 192-103). Coiled tubing drilling (CTD)operations are scheduled to begin as early as June 4, 2012 using the Nabors CDR2-AC rig. The objective of the CTD project is to improve A and C Sand sweep efficiency and oil recovery within the target pattern by drilling lateral sidetracks. A sundry application has already been approved (312-179)to plug the existing KRU 2M-01 perforations in preparation for the 2M-01A CTD sidetrack. Once CTD operations are completed then a 10-407 will be submitted to classify the 2M-01 completion as `Abandoned'. Attached to this application are the following documents that explain the proposed job operations. A BOP schematic for slimhole CTD operations from Nabors CDR2 is already on file with the Commission. — Drilling program summary — Permit to Drill Application Forms for 2M-01A and 2M-01AL1 — Directional Plans for 2M-01A and 2M-01AL1 — Current Wellbore Schematic — Proposed Wellbore Schematic If you have any questions or require additional information please contact me at my office 907-263-4172. Si erely, U 11111110 J. G Eller Co oPhilli. : aska Coiled Tubing Drilling Engineer Kuparuk CTD Laterals NABOB^5KA 2M-01A and 2M-01AL1 CIJA "P Application for Permit to Drill Document 2AC 1. Well Name and Classification 2 (Requirements of 20 AAC 25.005(f)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 2 (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information and Reservoir Pressure 2 (Requirements of 20 AAC 25.005(c)(4)) 2 5. Procedure for Conducting Formation Integrity tests 2 (Requirements of 20 AAC 25.005(c)(5)) 2 6. Casing and Cementing Program 2 (Requirements of 20 AAC 25.005(c)(6)) 2 7. Diverter System Information 3 (Requirements of 20 AAC 25.005(c)(7)) 3 8. Drilling Fluids Program 3 (Requirements of 20 AAC 25.005(c)(8)) 3 9. Abnormally Pressured Formation Information 4 (Requirements of 20 AAC 25.005(c)(9)) 4 10. Seismic Analysis 4 (Requirements of 20 AAC 25.005(c)(10)) 4 11. Seabed Condition Analysis 4 (Requirements of 20 AAC 25.005(c)(11)) 4 12. Evidence of Bonding 4 (Requirements of 20 AAC 25.005(c)(12)) 4 13. Proposed Drilling Program 4 (Requirements of 20 AAC 25.005(c)(13)) 4 Summary of Operations 4 Pressure Deployment of BHA 5 Liner Running 6 14. Disposal of Drilling Mud and Cuttings 6 (Requirements of 20 AAC 25.005(c)(14)) 6 15. Directional Plans for Intentionally Deviated Wells 6 (Requirements of 20 AAC 25.050(b)) 6 16. Quarter Mile Injection Review (for injection wells only) 6 (Requirements of 20 AAC 25.402) 6 17. Attachments 6 Attachment 1: Directional Plans for 2M-01A and 2M-01AL1 6 Attachment 2: Current Well Schematic for 2M-01 6 Attachment 3: Proposed Well Schematic for 2M-01A and 2M-01AL1 6 Page 1 of 6 f L May 24,2012 PTD Application fol KRU 2M-01A and 2M-01AL1 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 KRU 2M-01A and 2M-01AL1. 2M-01A will be a sidetrack- from the 2M-01 motherbore, and 2M-01AL1 will be a horizontal lateral branching off the 2M-01A. Both laterals will be classified as "Development- Oil'wells. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) These laterals will target both the A and C sands in the Kuparuk reservoir. See the attached 10-401 forms for surface and subsurface coordinates of the 2M-01A and 2M-01AL1 laterals. 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 4500 psi. Using a maximum potential formation pressure of 4588 psi, the maximum potential surface pressure is 3984 psi assuming a gas gradient of 0.1 psi/ft. 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)) The most recent static BHP measurement in well 2M-01 was taken in March 2012 recording a pressure of 3040 psi at 9460' MD, 6063' TVD for a 9.7 ppg gradient. We are drilling these laterals away from any other production or injection wells, so our expectation is that we will encounter similar formation pressures as we drill west. The most likely sources of elevated formation pressure, if we encounter such, would be from wells 2M-03 or 2M-05 which both have recently measured formation pressure gradients of 12.7 ppg. Maximum potential formation pressure is based on the 2M-06 injection well. In March 2012 it had measured formation pressure of 4526 psi at 10,110' MD, 5966' TVD for a pressure gradient of 14.6 ppg. In 2M-01A this gradient equates to a maximum potential formation pressure of 4588 psi (9435' MD, 6044' TVD) and a maximum potential surface pressure of 3984 psi assuming a gas gradient to surface. Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b)) No specific gas zones will be drilled; however, 2M pad does have some wells on miscible gas injection (MI) so encountering MI gas is a possibility. Potential Causes of Hole Problems (Requirements of 20 AAC 25.005(c)(4)(c)) The major expected downhole risk in the 2M-01 laterals is hole stability in the lower cretaceous unconformity (LCU) between the A and C sands. The LCU can be a rubble area with loose rocks and chert. There is also the possibility of exiting the top of the C sand into the Kalubik shale. We will mitigate hole instability by maintaining target ECD of 12.0 ppg at the window while drilling the CTD laterals. 5. Procedure for Conducting Formation Integrity tests (Requirements of 20 AAC 25.005(c)(5)) The 2M-01A and 2M-01AL1 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so formation integrity tests are not required. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Page 2 of 6 ORIGINAL May 24, 2012 PTD Application for KRy 2M-01A and 2M-01AL1 New Completion Details Lateral Liner Top Liner Btm Liner Top Liner Btm Liner Details Name MD MD TVDSS TVDSS 2M-01A 9600' 12,295' 5954' 5965' 2'/", 4.7#, L-80, ST-L slotted liner; aluminum billet on top 2M-01AL1 9370' 12,240' 5848' 5950' 2%", 4.7#, L-80, ST-L slotted liner up inside 3'/" tubing tail 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 H-40 Welded 0' 117' 0' 117' Surface 9%" 36 J-55 BTC 0' 3346' 0' 2749' 3520 2020 Casing 7" 26 J-55 BTC 0' 9785' 0' 6319' 4980 4320 Tubing 3W 9.3 J-55 EUE 8rd-mod 0' 9375' 0' 5999' 6990 7400 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Nabors CDR2-AC will be operating under 20 AAC 25.036 for thru-tubing drilling operations so no diverter system is 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 or used drilling mud (-8.8 ppg) — Drilling operations: Chloride-based Flo-Pro Flo Vis mud (8.8 ppg). While this mud weight does not hydrostatically overbalance formation pressure, overbalanced conditions will be maintained using MPD practices described below. — Completion operations: 2M-01 contains a subsurface safety valve (SSSV) at 1818' MD. 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 pressure over-balance while picking up liner. — Emergency Kill Weight fluid: Two well bore volumes (-215 bbl) of 13.1 ppg emergency kill weight fluid will be within a short drive to the rig during drilling operations. 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 pressure over- balance to the formation. In the 2M-01 laterals we will target a constant BHP of 12.0 ppg EMW at the window. If increased formation pressure is encountered, mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability but not necessarily for well control. Page 3 of 64/ R I G I NL' L May 24, 2012 PTD Application fur KRU 2M-01A and 2M-01AL1 Pressure at the 2M-01A Window (9435' MD, 6044' TVD) Using MPD Pumps On (1.5 bpm) Pumps Off A& C-sand Formation Pressure (9.8 ppg) 3080 psi 3080 psi Mud Hydrostatic (8.8 ppg) 2766 psi 2766 psi Annular friction (i.e. ECD, 0.095 psi/ft) 896 psi 0 psi Mud + ECD Combined 3662 psi 2766 psi (no choke pressure) (overbalanced (underbalanced —580 psi) —314 psi) Target iP at Window(12.0 ppg) 3771 psi 3771 psi Choke Pressure Required to Maintain 110 psi 1005 psi Targe 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 Well KRU 2M-01 is an A and C sand producer equipped with 3W tubing and 7" casing. Two proposed A and C sand CTD laterals will increase reservoir exposure and improve waterflood sweep. Prior to drilling, the existing perfs in 2M-01 will be squeezed with cement to provide a means to kick out of the 7" casing. A separate sundry request has been submitted and apedfor the abandonment of the original 2M-01 completion, which requires a variance from the plugging requirement of 20 AAC 25.112(c)(1). SGcn.le 312_,-t7q After plugging off the existing perfs with cement, a pilot hole will be drilled thrdugh the cement to 9485' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2M-01A sidetrack will exit the 7" casing at 9435' MD and will target the A3 sand west of the existing well with a 2860' lateral. The hole will be completed with a 2%' slotted liner to the TD of 12,295' MD with an aluminum billet at 6900' MD. The 2M-01AL1 lateral will kick off from the aluminum billet at 9600' MD and will target the C sand west of the existing well with a 2640' lateral. The hole will be completed with a 2%" slotted liner to the TD of 12,240' MD with the final liner top located just inside the 3W tubing at 9370' MD. Pre-CTD Work 1. RU slickline. Tag fill. Get updated static BHP survey. 2. RU e-line. Perf holes in 3W tubing tail at 9357' MD. RD e-line. ORIGINAL Page 4 of 6 May 24, 2012 PTD Application for KRU 2M-01A and 2M-01AL1 3. RU coil. Mill out the D-nipple at 9362' to 2.80" ID. 4. RU coil. Plug all perfs with cement from —9558' up to the tubing tail perfs at 9357' MD. RD coil. 5. RU slickline. Tag top of cement. RD slickline. 6. Prep site for Nabors CDR2-AC, including setting BPV Rig Work LiQoops- -v `r 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 2M-01A Sidetrack (Aland, west) f ,4 S'"-- a. Drill 2.80" high-side pilot hole through cement to 9485' MD'. 3/Z-171 b. Drift pilot hole with whipstock dummy c. Set whipstock at 9435' MD with high-side orientation. d. Mill 2.80"window at 9435' MD. '<p e. Drill 2.70"x 3" bi-center lateral to TD of 12,295' MD f. Run 2%" slotted liner with an aluminum billet from TD up to 9600', using the SSSV as a barrier to formation pressure 3. 2M-01AL1 Lateral (C4 sand, west) 1 a. Kick off of the aluminum billet at 9600' MD b. Drill 2.70"x 3" bi-center lateral to TD of 12,240' MD c. Run 2%" slotted liner from TD up to 9370' MD, up inside the 3W tubing tail. Will use the SSSV as a barrier to formation pressure while picking up liner. 4. Freeze protect. Set BPV, ND BOPE. 5. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV and install gas lift design. 2. Perform static BHP survey 3. Put on production. Pressure Deployment of BHA The planned bottomhole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on the Christmas tree. Because of this, MPD operations require the BHA to be lubricated under pressure using a system of double swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the BHA, and a slickline lubricator. This pressure control equipment ensures there are always two barriers to reservoir pressure, both internal and external to the BHA, during the deployment process. During BHA deployment, the following steps are observed. — Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is installed on the BOP riser with the BHA inside the lubricator. — Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and the BHA is lowered in place via slickline. — When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from moving when differential pressure is applied. The lubricator is removed once pressure is bled off above the deployment rams. — The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole. During BHA undeployment the steps listed above are conducted in reverse. Page 5 of 6 May 24, 2012 PTD Application for KRU 2M-01A and 2M-01AL1 Liner Running — Since 2M-01 is equipped with a SSSV, the CTD laterals will not need to be displaced to an over-balancing fluid prior to running liner unless the SSSV fails. In that case, fluid of sufficient density to over-balance the formation will be used to provide well control. 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%" pipe rams 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)) — There are no other affected owners — Please see attached directional plans for each lateral. — 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 and nearest well in the same pool. Distance Distance to Directional to Unit Nearest Lateral Name Plan Boundary Well Nearest Well 2M-01A WP06 2187' 2600' 2M-28 2M-01AL1 WP04 2187' 2600' 2M-28 16. Quarter Mile Injection Review (for injection wells only) (Requirements of 20 AAC 25.402) N/A for these laterals since they are intended to serve as producers. 17. Attachments Attachment 1: Directional Plans for 2M-01A and 2M-01AL1 Attachment 2: Current Well Schematic for 2M-01 Attachment 3: Proposed Well Schematic for 2M-01A and 2M-01AL1 Page 6 of 6 I ` May 24,2012 • o _------6s H r b :IVvAn yc Mu 8 4 8 my 9 OVG2 N G- N O ry N 8 * 8 o ^ - t^ csi N R - ti ? pO +/ G �JS Ro @1 • n• 1 O ,g- 1118 2 An }tea. 1Ifl 8 -r�N O N 9>„l < ,8 N 4 " % n ry 8 Q Q G '„ VD N• O M p 0OinI N� q .P V `i O J LJ i N 0 8 CA Ce ~ N O V 580 ,000000 0 of P,' § N N NNNS� N n O„ - O^ G „ r ---`-- --8 0 .41 rn O o c (110J Ca)(+)guON/(-) nos _ to LU RI Q N • O U l'-▪' Ori z p o--' co r O a • ..x lm- 7vww ,mrn:2.1=V:219 N „ O „ 1 -6 to n ~ tri A Opl m"1,pl I�g,mG m.76 1.W l4�'t00i o8 �!tnm1�N 1�N1� ppp „ .... 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Well Attributes Max Angle&MD TD Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(CAB) Alaska.Inc �,r>,..,rl,nsr_. 501032018500 KUPARUK RIVER UNIT PROD 61.81 2,801.74 9,800.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(R) Rig Release Date "' SSSV:TRDP 25 10/28/2011 Last WO: 46.02 10/30/1992 Well Conk/.-2M-01 4/2012012 2'36'.46 PM schematic-Actual Annotation Depth(CAB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,528.0 3/12/2012 Rev Reason:GLV C/O,TAG ninam 4/20/2012 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.060 41.0 117.0 117.0 62.58 H-40 WELDED Casing Description String 0... String ID..,Top(ttKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd HANGER,3a SURFACE _ 95/8 8.765 40.5 3,345.7 2,748.9 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String.. String Top Thrd PRODUCTION 7 6.276 33.4 9,785.1 6319.2 26.00 J 55 BTC Tubing Strings . Tubing Description String 0... String ID...Top(ftKB) Set Depth(f,,,Set Depth(ND),,,String WL„String... String Top Thrd TUBING [String I 2.992 37.6 I 9,375,2 I 5,999.3 I 9.30 I J-55 ABM-eue Completion Details Top Depth (ND) Top Incl Nomi.,. Top(ttKB) (ftKB) (°) Rem Description Comment ID(In) 37.6 37.6 0.03 HANGER FMC GEN IV TUBING HANGER 3.500 - 1,818.8 1,782.1 23.12 SAFETY VLV CAMCO TRDP-4A SSSV 2.812 CONDUCTOR, 9,338.4 5,972.1 42.72 SEAL BAKER GBH-22 SEAL ASSY w/5'EXTRA SPACER TUBE OD 5.0",ID 4.000 41-117 4.0" _ 9,339.2 5,972.7 42.72 PACKER BAKER FB-1 PACKER 4.000 9,362.6 5,989.9 42.58 NIPPLE CAMCO D NIPPLE 2.750 ---- . 9,374.3 5,998.6 42.44 SOS BAKER SHEAR OUT.TTL ELMD @ 9362 SWS LET 11/3/1992 2.992 SAFETY VLV, 0 1'819 Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(CAB) Btm(ttKB) (ftKB) (ftKB) Zone Date (oh-- Type Comment 9,435 9,489 6,043.8 6,084.6 C-4,A-3,2M-01 12/18/1992 4.0 IPERF 4 1/2"Csg Gun,180 deg.phasing Notes:General&Safety End Date Annotation 3/8/2011 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE, J l 40-3,346 GAS LIFT, -- 3,450 ` GAS LFT 6.839FT -{It r GAS LIFT, Com.. 8,545 GAS LIFT. _- 9,119 r GAS LIFT. _ 9.286 SEAL,9,338 PACKER,9,339 - NIPPLE.9,363 �� IP WE SOS,9,374 Mandrel Details Top Depth Top Port (ND) Incl OD Valve Latch Sloe TRO Run Stn Top(ftKB) (ftKB) (') Make Model (in) Sery Type Type (in) (psi) Run Date Com... 1 3,449.8 2,803.4 58.73 CAMCO FMHO 1 GAS LIFT GLV BK 0.156 1,288.0 4/8/2012 • (PERF, 2 6,839.4 4,514.6 60.65 CAMCO FMHO 1 GAS LIFT GLV BTM 0.250 1,434.0 4/8/2012 9,435-9,4891111 II 3 8,545.0 5,414.9 50.92 CAMCO FMHO 1 GAS LIFT OV BK 0.250 0.0 4/7/2012 4 9,119.1 5,810.5 42.70 CAMCO FMHO 1 GAS LIFT DMY BK 0.000 0.0,12/18/1992 5 9,286.2 5,933.7 42.62 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.012/10/2000 PRODUCTION, T0,9,7800 ' ORIGINAL n z N a) > O 3 M a2 a ❑ N oN CV if7 CD p Q N O in Z a5 UOQ H - -o v ao aU N oaD V N 4 O m .OO a al E 11 a3 O_ a O p0 @V N 0 Q 0O' N4- --�40 V V M- MQ N d)7u) .712 M- (Dp dcO NO - -a a� O) (p C0cnp as mlJ /��> N IL JN@fn 'O y Na)c�1 C p- ill Q O) fn a) �.- r- o d j O N C nT co Uo C13 ! flI 7) N N N Z\ -NY N =N co co f`7 ch m m M ch / I IT) ai ami O 215 ~ C N O co-- co- M N �I Ri� :f3..="s:.:,s. .3......w. n� fi "`"y` �' t'�+a. t,� y.r '.,..04" �+'-.v ,rsk_ �� Q We+"ti.,,?x'+<skk+,�� v T1s CO :' : a Q U 13 m I N t 6 O 0 o ;, I a) M a0 E a)a I _` _ o 0 N CV CD OL a) co a) 2 uu? in U v o_b) p Or L O N O a) a ao 4 G _ .- aka c co C6rn Napo C co- Q CA L N� V U� 1--0~i N co a) 5o co n u) Y oti C) coo Tr Co N2 m0 o o am co N d ORIGINAL ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2M pad 2M-01 2M-01A Plan: 2M-01A_wp06 Standard Planning Report 23 May, 2012 ru BAKER HUGHES 1.- ConocoPhillips or its affiliates «- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2M-01 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-01 ©147.00ft(2M-01) Site: Kuparuk 2M pad North Reference: True Well: 2M-01 Survey Calculation Method: Minimum Curvature Wellbore: 2M-01A Design: 2M-01A_wp06 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 2M pad Site Position: Northing: 5,948,985.89ft Latitude: 70°16'18.578 N From: Map Easting: 487,859.45ft Longitude: 150°5'53.484 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.09° Well 2M-01 Well Position +N/-S 0.00 ft Northing: 5,948,985.87 ft Latitude: 70°16'18.578 NII +EI-W 0.00 ft Easting: 487,859.47 ft Longitude: 150°5'53.483 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 2M-01A Magnetics Model Name Sample Date Declination Dip Angle Field Strength I (°l (°) (nT) 1 BGGM2011 6/20/2012 16.04 79.84 57,358 Design 2M-01A_wp06 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,423.50 Vertical Section: Depth From(TVD) +N/$ +E/-W Direction (ft) (ft) (ft) (1 0.00 0.00 0.00 320.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 9,423.50 41.38 279.09 5,888.17 983.99 -6,386.64 0.00 0.00 0.00 0.00 9,435.00 41.23 279.34 5,896.80 985.21 -6,394.13 1.94 -1.30 2.17 132.36 9,456.00 44.17 279.34 5,912.24 987.52 -6,408.18 14.00 14.00 0.00 0.00 9,536.00 80.17 279.34 5,948.97 998.81 -6,476.85 45.00 45.00 0.00 0.00 9,595.00 90.70 303.83 5,953.73 1,020.34 -6,531.01 45.00 17.85 41.50 68.00 9,695.00 94.10 313.24 5,949.54 1,082.49 -6,609.07 10.00 3.40 9.42 70.00 9,795.00 94.09 317.25 5,942.40 1,153.31 -6,679.28 4.00 -0.01 4.01 90.00 9,945.00 90.22 321.84 5,936.75 1,267.32 -6,776.48 4.00 -2.58 3.06 130.00 10,095.00 90.22 327.84 5,936.17 1,389.90 -6,862.81 4.00 0.00 4.00 90.00 10,745.00 87.70 301.96 5,948.15 1,844.77 -7,319.16 4.00 -0.39 -3.98 264.30 10,945.00 87.73 309.97 5,956.14 1,962.04 -7,480.78 4.00 0.01 4.00 90.00 11,445.00 90.05 329.84 5,965.96 2,342.51 -7,801.11 4.00 0.46 3.97 83.60 11,845.00 90.04 313.84 5,965.64 2,655.99 -8,047.47 4.00 0.00 -4.00 270.00 12,295.00 90.04 331.84 5,965.29 3,013.13 -8,318.20 4.00 0.00 4.00 90.00 5/23/2012 10:33:03AM Page 2 COMPASS 2003.16 Build 69 ORIGINAL ►-' ConocoPhillips or its affiliates 13"--- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2M-01 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-01 @ 147.00ft(2M-01) Site: Kuparuk 2M pad North Reference: True • Well: 2M-01 Survey Calculation Method: Minimum Curvature Wellbore: 2M-01A Design: 2M-01 A_wp06 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 9,423.50 41.38 279.09 5,888.17 983.99 -6,386.64 4,859.03 0.00 0.00 5,949,980.06 481,475.07 TIP 9,435.00 41.23 279.34 5,896.80 985.21 -6,394.13 4,864.78 1.94 132.36 5,949,981.29 481,467.58 KOP 9,456.00 44.17 279.34 5,912.24 987.52 -6,408.18 4,875.58 14.00 0.00 5,949,983.62 481,453.53', 3 • 9,500.00 63.97 279.34 5,937.93 993.27 -6,443.16 4,902.47 45.00 0.00 5,949,989.43 481,418.56 9,536.00 80.17 279.34 5,948.97 998.81 -6,476.85 4,928.37 45.00 0.00 5,949,995.03 481,384.89 4 9,595.00 90.70 303.83 5,953.73 1,020.34 -6,531.01 4,979.67 45.00 68.00 5,950,016.64 481,330.77 End of 45 dls 9,600.00 90.87 304.30 5,953.66 1,023.14 -6,535.15 4,984.48 10.00 70.00 5,950,019.44 481,326.63 9,695.00 94.10 313.24 5,949.54 1,082.49 -6,609.07 5,077.46 10.00 70.01 5,950,078.91 481,252.82 Start of RSM 9,700.00 94.10 313.44 5,949.18 1,085.91 -6,612.70 5,082.42 4.00 90.00 5,950,082.34 481,249.19 9,795.00 94.09 317.25 5,942.40 1,153.31 -6,679.28 5,176.84 4.00 90.01 5,950,149.83 481,182.73• 7 9,800.00 93.96 317.40 5,942.05 1,156.98 -6,682.66 5,181.83 4.00 130.00 5,950,153.51 481,179.351 9,900.00 91.38 320.47 5,937.38 1,232.28 -6,748.26 5,281.68 4.00 130.01 5,950,228.91 481,113.88 9,945.00 90.22 321.84 5,936.75 1,267.32 -6,776.48 5,326.66 4.00 130.15 5,950,263.99 481,085.72 8 I 10,000.00 90.22 324.04 5,936.54 1,311.21 -6,809.62 5,381.59 4.00 90.00 5,950,307.93 481,052.65 10,095.00 90.22 327.84 5,936.17 1,389.90 -6,862.81 5,476.06 4.00 90.01 5,950,386.70 480,999.59 9 10,100.00 90.20 327.65 5,936.15 1,394.13 -6,865.48 5,481.01 4.00 -95.70 5,950,390.93 480,996.93 10,200.00 89.80 323.66 5,936.15 1,476.68 -6,921.89 5,580.51 4.00 -95.70 5,950,473.57 480,940.66 10,300.00 89.41 319.68 5,936.84 1,555.11 -6,983.89 5,680.44 4.00 -95.70 5,950,552.09 480,878.801 10,400.00 89.01 315.70 5,938.22 1,629.05 -7,051.18 5,780.33 4.00 -95.67 5,950,626.13 480,811.64 10,500.00 88.62 311.72 5,940.28 1,698.12 -7,123.43 5,879.69 4.00 -95.62 5,950,695.31 480,739.50 10,600.00 88.24 307.74 5,943.01 1,762.00 -7,200.29 5,978.03 4.00 -95.54 5,950,759.31 480,662.751 10,700.00 87.87 303.75 5,946.41 1,820.38 -7,281.39 6,074.88 4.00 -95.43 5,950,817.81 480,581.76 10,745.00 87.70 301.96 5,948.15 1,844.77 -7,319.16 6,117.84 4.00 -95.29 5,950,842.26 480,544.03• 10 10,800.00 87.71 304.16 5,950.35 1,874.75 -7,365.21 6,170.41 4.00 90.00 5,950,872.31 480,498.03 j 10,900.00 87.72 308.16 5,954.35 1,933.70 -7,445.87 6,267.41 4.00 89.91 5,950,931.38 480,417.48 10,945.00 87.73 309.97 5,956.14 1,962.04 -7,480.78 6,311.56 4.00 89.75 5,950,959.77 480,382.61 11 11,000.00 87.97 312.15 5,958.20 1,998.14 -7,522.22 6,365.85 4.00 83.60 5,950,995.94 480,341.24 11,100.00 88.43 316.13 5,961.34 2,067.73 -7,593.93 6,465.26 4.00 83.52 5,951,065.64 480,269.65 11,200.00 88.89 320.10 5,963.68 2,142.15 -7,660.66 6,565.15 4.00 83.39 5,951,140.16 480,203.04 11,300.00 89.36 324.08 5,965.21 2,221.02 -7,722.08 6,665.06 4.00 83.30 5,951,219.12 480,141.75 11,400.00 89.83 328.05 5,965.91 2,303.97 -7,777.89 6,764.47 4.00 83.24 5,951,302.15 480,086.08 11,445.00 90.05 329.84 5,965.96 2,342.51 -7,801.11 6,808.93 4.00 83.21 5,951,340.73 480,062.93 12 11,500.00 90.05 327.64 5,965.91 2,389.52 -7,829.65 6,863.28 4.00 -90.00 5,951,387.78 480,034.47 11,600.00 90.05 323.64 5,965.83 2,472.05 -7,886.08 6,962.78 4.00 -90.00 5,951,470.39 479,978.17 11,700.00 90.05 319.64 5,965.75 2,550.45 -7,948.14 7,062.72 4.00 -90.00 5,951,548.88 479,916.2511 11,800.00 90.04 315.64 5,965.67 2,624.32 -8,015.51 7,162.61 4.00 -90.01 5,951,622.85 479,849.01 11,845.00 90.04 313.84 5,965.64 2,655.99 -8,047.47 7,207.42 4.00 -90.01 5,951,654.57 479,817.10 13 11,900.00 90.04 316.04 5,965.59 2,694.84 -8,086.40 7,262.20 4.00 90.00 5,951,693.48 479,778.23 12,000.00 90.04 320.04 5,965.52 2,769.18 -8,153.25 7,362.13 4.00 90.00 5,951,767.92 479,711.51_ 5/23/2012 10:33:03AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL �•, ConocoPhillips or its affiliates (f' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2M-01 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-01 @ 147.00ft(2M-01) Site: Kuparuk 2M pad North Reference: True Well: 2M-01 Survey Calculation Method: Minimum Curvature Wellbore: 2M-01A Design: 2M-01A_wp06 Planned Survey i Measured TVD Below Vertical Dogleg Toolface Map Map 1 Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 12,100.00 90.04 324.04 5,965.44 2,848.00 -8,214.76 7,462.04 4.00 90.00 5,951,846.84 479,650.14 12,200.00 90.04 328.04 5,965.37 2,930.93 -8,270.61 7,561.47 4.00 90.01 5,951,929.84 479,594.42 12,295.00 - 90.04 331.84 5,965.29 - 3,013.13 -8,318.20 7,655.02 4.00 90.01 5,952,012.11 479,546.98 TD at 12295.00 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting j -Shape r) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2M-01A Fault 1 0.00 0.00 5,950.00 5,780.60 -8,115.52 5,954,778.97 479,754.09 70°17'15.387 N 150°9'49.932 W -plan misses target center by 2774.92ft at 12295.00ft MD(5965.29 TVD,3013.13 N,-8318.20 E) -Polygon Point 1 5,950.00 5,780.60 -8,115.52 5,954,778.97 479,754.09 Point 2 5,950.00 -31.47 -9,605.00 5,948,969.89 478,255.39 2M-01A T2 0.00 0.00 5,936.00 1,395.22 -6,863.39 5,950,392.02 480,999.02 70°16'32.269 N 150°9'13.334 W -plan misses target center by 2.36ft at 10099.81ft MD(5936.15 TVD,1393.97 N,-6865.38 E) ' -Point 2M-01A T4 0.00 0.00 5,965.00 2,980.98 -8,355.09 5,951,980.02 479,510.03 70°16'47.850 N 150°9'56.822 W -plan misses target center by 47.76ft at 12285.65ft MD(5965.30 TVD,3004.91 N,-8313.76 E) -Point 2M-01 CTD Polygon 0.00 0.00 150.00 2,592.02 -8,937.54 5,951,592.04 478,927.02 70°16'44.018 N 150°10'13.772 W -plan misses target center by 5863.29ft at 12200.00ft MD(5965.37 TVD,2930.93 N,-8270.61 E) -Polygon Point 1 150.00 2,592.02 -8,937.54 5,951,592.04 478,927.02 Point 2 150.00 4,114.75 -8,593.04 5,953,114.06 479,273.94 Point3 150.00 1,466.70 -6,059.38 5,950,462.19 481,803.07 Point 4 150.00 581.49 -6,729.97 5,949,578.15 481,131.12 2M-01A T1 0.00 0.00 5,954.00 1,013.73 -6,522.74 5,950,010.02 481,339.02 70°16'28.520 N 150°9'3.406 W -plan misses target center by 1.35ft at 9584.85ft MD(5953.69 TVD,1015.00 N,-6522.37 E) -Point 2M-01A Fault 2 0.00 0.00 5,950.00 5,780.60 -8,115.52 5,954,778.97 479,754.09 70°17'15.387 N 150°9'49.932 W -plan misses target center by 2774.92ft at 12295.005 MD(5965.29 TVD,3013.13 N,-8318.20 E) -Polygon Point 1 5,950.00 5,780.60 -8,115.52 5,954,778.97 479,754.09 Point 2 5,950.00 2,031.21 -3,914.86 5,951,023.19 483,948.28 2M-01A T3 0.00 0.00 5,965.00 2,179.90 -7,732.74 5,951,178.02 480,131.03 70°16'39.978 N 150°9'38.672 W -plan misses target center by 33.015 at 11274.11ft MD(5964.89 TVD,2200.19 N,-7706.70 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C') (") 12,295.00 5,965.29 2-3/8" 2-3/8 3 5/23/2012 10:33:03AM Page 4 COMPASS 2003.16 Build 69 lGTMA --` ConocoPhillips or its affiliates VG ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2M-01 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2M-01 @ 147.00ft(2M-01) Site: Kuparuk 2M pad North Reference: True Well: 2M-01 Survey Calculation Method: Minimum Curvature Wellbore: 2M-01A Design: 2M-01A_wp06 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,423.50 5,888.17 983.99 -6,386.64 TIP 9,435.00 5,896.80 985.21 -6,394.13 KOP 9,456.00 5,912.24 987.52 -6,408.18 3 9,536.00 5,948.97 998.81 -6,476.85 4 9,595.00 5,953.73 1,020.34 -6,531.01 End of 45 dls 9,695.00 5,949.54 1,082.49 -6,609.07 Start of RSM 9,795.00 5,942.40 1,153.31 -6,679.28 7 9,945.00 5,936.75 1,267.32 -6,776.48 8 10,095.00 5,936.17 1,389.90 -6,862.81 9 10,745.00 5,948.15 1,844.77 -7,319.16 10 10,945.00 5,956.14 1,962.04 -7,480.78 11 11,445.00 5,965.96 2,342.51 -7,801.11 12 11,845.00 5,965.64 2,655.99 -8,047.47 13 12,295.00 5,965.29 3,013.13 -8,318.20 TD at 12295.00 5/23/2012 10:33:03AM Page 5 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2M Pad 2M-01 2M-01A 2M-01A_wp06 Travelling Cylinder Report 22 May, 2012 r& ur BAKER HUGHES ORIGINAL �, ConocoPhillips or its affiliates Fr' ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-01 Project: Kuparuk River Unit TVD Reference: 2M-01 @ 147.00ft(2M-01) Reference Site: Kuparuk 2M Pad MD Reference: 2M-01 @ 147.00ft(2M-01) Site Error: 0.00ft North Reference: True Reference Well: 2M-01 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2M-01A Database: EDM Alaska Prod v16 Reference Design: 2M-01A_wp06 Offset TVD Reference: Offset Datum Reference 2M-01A_wp06 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of referE Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,423.50 to 12,295.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,414.80ft Error Surface: Elliptical Conic Survey Tool Program Date 5/22/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 163.85 9,423.50 2M-01 (2M-01) GCT-MS Schlumberger GCT multishot 9,423.50 12,295.00 2M-01A_wp06(2M-01A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 12,295.00 6,112.29 2-3/8" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 2M Pad 2M-01 -2M-01 -2M-01 9,449.99 9,450.00 0.30 1.24 -0.91 FAIL-Major Risk 2M-01 -2M-01AL1 -2M-01AL1_wp04 9,624.98 9,625.00 0.63 0.50 0.32 Pass-Minor 1/10 2M-06-2M-06-2M-06 Out of range 2M-28-2M-28-2M-28 Out of range 2M-29-2M-29-2M-29 Out of range 2M-31-2M-31 -2M-31 Out of range 2M-33-2M-33-2M-33 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/22/2012 3:24:29PM Page 2 of 7 COMPASS 2003.16 Build 69 0E IUgg \ ; I t 4 ',: a �i d. ConocoPhillips or its affiliates ConocoPhillips Travelling Cylinder Report BAKER HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2M-01 Project: Kuparuk River Unit TVD Reference: 2M-01 @ 147.00ft(2M-01) Reference Site: Kuparuk 2M Pad MD Reference: 2M-01 @ 147.00ft(2M-01) Site Error: 0.00ft North Reference: True Reference Well: 2M-01 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 2M-01A Database: EDM Alaska Prod v16 Reference Design: 2M-01A_wp06 Offset TVD Reference: Offset Datum Reference Depths are relative to 2M-01 @ 147.00ft(2M-01) Coordinates are relative to:2M-01 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927,Alaska Zone 4 Central Meridian is 150°0'0.000 W° Grid Convergence at Surface is:-0.10° Ladder Plot 240 I I 1 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 1 I I I I I I C 180 I I I I I g I I I I I 1 I I I I I t (B I I I I I I m I I I I I I rn 1 1 I 1 I I I I tI I I I I I cu 1 20 I I I I I 11 I ' I I I I I I I ,. • O I I I I I 1 I I I I 1 J J J __ __J_ C I I I I I V I CI) I I I I I I I U I I I I I I 60 I I I I I 1 I I I I I I I I I I I 1 I I I I I I J I I I I I I I I I I I I I I I I 1 I I I I 0 I I 11 0 2000 4000 6000 0000 10000 12000 M easured Depth LEGEND 2M-01.2M-01.2M-01 VI 2M-01.2M-01AL1,2M-01AL1_wp041A CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 5/22/2012 3:24:29PM Page 7 of 7 COMPASS 2003.16 Build 69 0RI GIN u. . 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VI ' 1 _ - NNmm•NlmmNiilinlaaamaW- -i--` '--1- N + ._ _ NNBN••NNNN•N•N••••■N -.- . isimiainumfmmungewt ,a I N $SH$$H$S$B$ $E , .,4`=iT g .1�_ lmm�ma m�m�m "• Vim + L - NNN••■•NN•• •N•N .. - .L" �!m!lma�a!l� aaa0m�a : I. 1•B e.. •NN••••••BpNpgN•N•N••N .. ; ._.- _ h $ q V :i Ctxz 1 1 t 11 . .o o O 8' a 8 P, s .r o .1 8 o ,ryA g... ^ o N o'' ^ o'' N o o `o 'p�� v, v, V, 2. to m en to N N N N �AQ 0 0(R/U\°6 LII N 2v TRANSMITTAL LETTER CHECKLIST WELL NAME (-( PTD# 2-/ Z-4 7Z Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: /G-c L'&l POOL: K z- 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 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 produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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